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Home My WebLink About200-202Joe Engel for Sean McLaughlin By Grace Christianson at 7:34 am, Sep 12, 2025 Digitally signed by Joseph Engel (2493) DN: cn=Joseph Engel (2493) Date: 2025.09.11 15:43:39 - 08'00' Joseph Engel (2493) 325-554 DSR-9/12/25 10-407 A.Dewhurst 16SEP25 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. Open hole window milling not to exceed 15'. JJL 9/24/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.24 15:35:58 -08'00'09/24/25 RBDM JSB 092625 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 11, 2025 Re:C-33A Sundry Request Sundry approval is requested to set a whipstock in the C-33A wellbore as part of the drilling and completion of the proposed C-33B CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN- nipple. Coil will perform a 3-1/2”x7” IA cement squeeze to aid in the dual string exit. E-line will set a 3-1/2" whipstock. If unable to set the whipstock pre-rig, the rig will perform that work. See C-33B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 3-1/2" whipstock and mill a single string 2.80" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 3 and 2, landing in Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start September 2025) 1. Slickline : Dummy GLMs, SL Whipstock Drift, CT drift and Caliper 2. Fullbore : MIT-IA and/or MIT-T (2,500 psi min) 3. Service Coil : SQZ IA at KOP. Plug ~10,800', Punch ~10,795' and ~10,650', Set retainer ~10,790' and sqz 145' of IA (~4 bbls of 15.8 ppg Class G cement). Mill XN. 4. Eline : Set 3-1/2” Packer Whipstock* 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: x Reference C-33B Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,420 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.80” Dual String 3-1/2"x7" Window 3. Drill build section: 3.25" OH, ~259' (24 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~2,550' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr solid liner 6. Make up 1" CS Hydril cementing string with ORCA system and run in to PBTD. 7. Pump primary cement job*: 19.5 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 8. Only if not able to do with service coil extended perf post rig – Perforate Liner with 1" CS Hydril perf string 9. Freeze protect well to a min 2,200' TVD. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig CBL and perforate (~500-800’) - see extended perf procedure attached. 4. Testing : Portable test separator flowback. * Alternate plug placement variance request per 20 AAC 25.112(i) Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 113' 10,778' 10,778' 10,778' 10,778' 113' Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 7. 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 C-33A Mill Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-202 50-029-22373-01-00 13372 Conductor Surface Intermediate Liner Liner 8917 80 3574 10396 7187 2564 12295 20" 13-3/8" 9-5/8" 7" 2-3/8" 8886 35 - 115 35 - 3609 33 - 10429 4063 - 11250 10808 - 13372 35 - 115 35 - 3191 33 - 8392 3543 - 8858 8657 - 8917 12295 470 2260 4760 5410 11780 12295 1490 5020 6870 7240 11200 11870 - 13320 3-1/2" 9.2# 13cr80, L80 31 - 10878 8877 - 8913 Structural 4-1/2" Baker S3 Packer 10830, 8669 10559, 10830 8494, 8669 Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com 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 0028304 31 - 8696 N/A N/A 242 371 22510 15641 24 40 700 1650 788 1200 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer 10559, 8494 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 No SSSV Installed By Grace Christianson at 10:24 am, May 10, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.10 06:24:37 -08'00' Torin Roschinger (4662) ACTIVITY DATE SUMMARY 4/22/2023 ***WELL S/I ON ARRIVAL***(profile modification) DRIFTED LINER W/ 30" x 1.74" DRIFT TO DEVIATION @ 11,262' SLM. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 4/26/2023 LRS CTU #2 1.5" Blue Coil. Job Scope: Mill CIBP MIRU & MU 1-11/16" YJ milling BHA with 1.73" 5-blade junk mill. Tag in LTP at 10802' CTMD and unable to spin though. POOH and size down to a 1.70" flat bottomed junkmill. RIH. ...Continued on WSR 4-27-23.... 4/27/2023 LRS CTU #2 - 1.5" Blue Coil. ***Cont. from WSR 4-26-23*** Job Scope: Mill CIBP Continue RIH with 1.70" mill and tag top of LTP. Time mill into LTP mandrel. Tag CIBP at 11954' CTMD. Mill plug and push to ~ 12301' CTMD. POOH and freeze protect the well to 2500' TVD with diesel. RDMO. ***Job Complete*** Daily Report of Well Operations PBU C-33A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI:,_.JN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations H Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: 5 tf- G i OP d' 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 200-202 3. Address: P.O.Box 196612 Anchorage, Development H Exploratory El AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22373-01-00 7 Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU C-33A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: RECEIVED Total Depth: measured 13372 feet Plugs measured 10950,12295 feet i� true vertical 8917 feet Junk measured 12295 feet AUG 1 7 2015 Effective Depth: measured 11949 feet Packer measured See Attachment feet true vertical 8879 feet Packer true vertical See Attachment feet AJ G C C Casing: Length: Size: MD. TVD. Burst: Collapse: Conductor 79 20"91.5#H-40 35-114 35-114 1490 470 Surface 3574 13-3/8"68#L-80 35-3609 35-3191 5020 2260 Production 10394 9-5/8"47#NT8OS 33-10427 33-8391 6870 4760 Liner 6179 7"26#L-80 4063-10242 3543-8246 7240 5410 Liner 1006 7"29#NT-80 10250-11256 8252-8860 8160 7020 Liner 2569 2-3/8"4 6#L-80 10803-13372 8654-8917 11200 11780 Perforation Depth: Measured depth: 11870 11900 feet 12130-12214 feet 12214-12244 feet 12390-12680 feet 12720-12980 feet 13010-13070 13130-13320 feet True vertical depth: 8877-8878 feet 8882-8882 feet 8882-8884 feet 8886-8893 feet 8894-8900 feet 8898-8895 8899-8913 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED , . Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 333 25126 42 0 788 Subsequent to operation: 296 19693 38 0 954 14.Attachments:(required per 20 AAC 25 070 25 071,a 25 283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development H Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16 Well Status after work• Oil H Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhays,Nita M( '/RO Technologies) Title Petrotechnical Data Manager /117I Signat - // �//��5 ��/ Phone +1 907 564-4035 Date 08/17/2015 j Form 10-404 Revised 5/2015 liT L /'G 9/2-A.,,./ /f� RBDMSSr�9AUGn Only 9 2015 Daily Report of Well Operations PBU C-33A ACTIVITYDATE SUMMARY CTU #8 w/ 1.5" CT ( CTV=24.4) Objective-Set 2-3/8" CIBP/60' of add perfs MIRU. Load well with 120 bbls of 1% KCI w/safelube and cap with 10 bbls of 50/50 methanol. RIH w/PDS MGR/CCL and BOT 1.73" CIBP Drift. Did not tag CIBP which was supposed to be @ 11949'. RIH and tag at 12295'. It appears CIBP has moved downhole. Contact Pad Engineer. Log from bottom up to 10700' @ 40 fpm. Stop and paint yellow flag 11900' and white flag 11700'. 5/28/2015 ***Job in Progress*** CTU #8 w/ 1.5" CT ( CTV=24.4) Objective-Set 2-3/8" CIBP Logged up to 10700. POOH. APE verified that original CIBP had moved downhole. He requested that a new CIBP be set @ 11950' and postponed the perforating portion of the job until after OPS has obtained a well test. Download PDS data. Make (-) 1'correction in reference to SLB MCNL/GR/CCL dated Jan-28-2001. RIH w/turned down 2-3/8 BOT CIBP. Set CIBP @ 11950'. POOH. FP wellbore with 22 bbls of 50/50 methanol. RD. 5/29/2015 ***Job Complete*** Fluids Summary BBLS Type 183 1% KCL W/SAFELUBE 66 50/50 METH 249 'Total (3) U) • coO O O O O O O coC) M LC N- NO O N V LC) 0 0 U N0 0 0 0 0 O O o i 0) N N ' CO O O O • V 0 CO N ; m c CD N- 00 O O r � CD O N- N (fl O- 0) - O N- 0) - co N co 0) in co co co co co co CO 00 i H CO N 0) LO LC) CO V LC) Lf> CO co co co L() N CO M LC) M CO CO CO N CD N 00 0 N LC) N- N-co V N N M CO 00 O O CO O O C.) C1 0 I I I I I I i ▪ Q Q M O co CD MLn Lf) CO CD N 0o M L M CO CO O O O M O CO � � � m I- a OO opo 0000 000 � °oU °o = J 1- 00 i J M J lzk Z H N * co 4 �# ZN •N _• O *k d (-N. a7 M. op O _ O _ U O - N N CO - N O M N` - ch N N N i co M L +- V V O CO O O CT)d7 f� O 1"-- O CO V C N. In M c- O LC) O (1) CO O CO r N O N J Z D)O O C H w 'NOVO O O O a. Z Z Z (3OW WWmp21 O D c Z Z_ Z_ D D O Cn J J J H H Packers and SSV's Attachment PBU C-33A SW Name Type MD TVD Depscription C-33A PACKER 4063 3543.38 7" Baker C-2 ZXP LT Packer C-33A PACKER 10258 8258.1 7" Baker C-2 ZXP LT Packer C-33A PACKER 10570 8501.87 3-1/2" Baker S-3 Packer C-33A PACKER 10803 8653.65 3-1/2" Baker Liner Top Packer C-33A PACKER 10830 8669.22 3-1/2" Baker S-3 Packer Tom= 3/8"CNV FLS C-3 3A = S. Y NOTES:WELL ANGLE>TO°@ 11210'"' 1AILHFADFMC ACTUAT0f2= BAKER C CROME TBG"'"AS OF 11/08/08,TOP PKR DAMAGE) KB. = 67.T DURING FISHING.LTP SUCCESSFULLY DRIFTED L. w/1.72-TOOLSTRING'""' BF.B_EV= 37.5 KOP= 1156' ' , 1995' H 3-1/2"HES X NP,D=2.813" _Max Angie= 95"@ 12654' Datum MD=- 11336' Datum DVDs= 8800'SS 4063' -�9-5/8"X 7"BKRN G2 ZXP LDP,D=6.290" 20"CONDUCTOR,91.5#,1.40,D=19.124" H 78' j teen ►�� r,_( 4081' H9-5/8"X 7"BKR FLEX LOCK HGR,D=6.300' 1 X11 13-3/8"CSG,68#,BTC,L-80,D=12.415" -- 3809* 111, III• GAS LIFT MANDRELS /1I ►1F ST MD we DEV TYPE VLV LATCH FORT DATE 1/ 11 7"SCAB LNR 26#,L-80 BTGM1 — 10247 V. <•1'� 2 4469 3860 40 MCCOM£ RK 16 11/15/14 %. •• 1 7515 6188 39 WING DOME IRK 16 11/15/14 D=6.276" 10 / TOP OF 7 LNR —{ 10251' 10251' H9-5/8"X r BKR LTP w/TE BACK SLV,ID=6.280' 10263' —7"BKR I-MC LNR HGR D 6.30" 9-5/8"CSG, 47#,NT-80S NSCC,ID=8681" —1 10429' ' 10536' —13-1/2'HES X NIP,D=2.813" Minimum ID = 1.75" 10803' 10557' H3-1/2"x 4-1/2"x0,ID=2.992" SEAL ASSEMBLY ►t1� MI 1055W --17"x 4-1/2"BKR S-3 PKR,D=3.870" I 10563' H4-1/2"X 3-1/2"XO,ID=2.992" I 10684' H3-1/2" ' 1063T —I3-112"HES XN NP,D=2.75" 3-1/2"TBG,9.2#,13CR-80 VAM TOP, —{ 10658' .0087 bpf,D=2.992" 1 10660' —17"X 3-1/2"UNIQUE OV ERSHO 3-1/2"TBG STUB(01-31-08) — 1 5? _� CM 10803' —13-3 -13-9r2"BKR.s�T�r'w D r SEAL ASSY, =1.75" I.TOP OF 2-318"LNR —I 10808' I 10808' H 8KR DEPLOY SLV 10818' —{3-1/2'HESX NP,D=2.75" BEHIND i' I 10828' H3-1/2"x 4-112"XO,D=2.937" PIPE p i 10830' —I 7"X4-1/2"BKR S-3 PKR D=3.920" 3-1/7'TBG,9.2#,L-80,Tub, H 10878' 0087 bpf,D=2.992"HNBY10834' 14-1/2"x3-1/r XO,D=2.937" TOP OF CT(TAGGED 11/16/01) —I 11142' I i ! 10855'_ 13-1/2"HES X NP,D-2.75" 10866' H3-1/2"FES X NP,D=2.75" BEHIND SP(12/23/00) H 11290' 10878' --i 3-1/2"WLEG,D=2.990' PIPE PERFORATION SUMMARY 10874' -1TTL EMD-LOGGED 10/18/95 REF LOG: CM./GR/CCL MEMORY LOG ON 01/28/2001 ANGLE AT TOP PERF: 88°@ 11870' MELOUT WINDOW(C-33A) 11250'-11256' Note:Refer to Production D8 for historical perf data ..47,1k.4,-4.1;%., SIZE SPF INTERVAL n/ SHOT SQZ 4'*` *`‘ OP ' . 11950' H2-3/8"BOT CUP(05/29115) 1-9/16" 6 11870-11900 0 07/30/12 ��_ 1-9/16" 6 12130 12244 C 11/08/08 �t s, —12296' —FISH:GBP PUSHED DH(05/29/15) 1-11/16' 4 12390-12680 C 01/28/01 12295' -I1-11/16"BKR UP(11/08/08) 1-11/16" 4 12720-12980 C 01/28/01 /fir PBTD —I 13320' 1-11/16" 6 13010-13070 C 01/19/06 4.1. 1-11/16" 4 13130-13320 C 01/28/01 'i #t''Kw i 7"LIZ,29#,NT-80 NSCC,-0371 bpf, D=6.184" — 11770' * *+ 2-318'LNR 4.6#,L-80 FL4S,.0039 bpf,D=1.992" — 13372' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY U1JT 07/09/93 FARGO ORIGINAL COMPLETION 11/14/14 CJN/PJC GLV GO WELL: C-33A 10/10/95 D16 RWO 11/15/14 CJN/PJC GLV 00&TBG PKR CORRECTION PERMIT No: 2002020 02/01/01 CDR-1 CTD(C-33A) 04/06/15 DIYJMD TREE00(04/05/15) API No: 50-029-22373-01 02/12/08 N4E5 RWO 06/19/15 ATO/JMJ SET CUP&FSH(05/29/15) SEC 19,T11N,R14E,700'FNL&1277'FEL 08/01/12 FES/JMD SET CUP&ADPERF(07/30/12) 11/15/14 TLM/PJC GLV 00 BP Expioration(Alaska) AAA OIL AND G S OF CONSERVATION COMMION RECEIVED REPORT OF SUNDRY WELL OPERATIONS AUG 3 0 2012 1. Operations Abandon U Repair Well U Plug Perforations U Perforate L] i'` a iir CIBP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well} 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Na me: BP Exploration (Alaska), Inc Development is Exploratory ❑ - 200 -202 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 " 50- 029 - 22373 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028304 N PBU C -33A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13372 feet Plugs measured See Attachment feet true vertical 8916.77 feet Junk measured None feet Effective Depth measured 11950 feet Packer measured See Attachment feet true vertical 8878.99 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20" 91.5# H-40 35 - 114 35 - 114 1490 470 Surface 3574 13 -3/8" 68# L -80 35 - 3609 35 - 3190.79 5020 2260 Intermediate None None None None None None Production 10394 9 -5/8" 47# NT8OS 33 - 10427 33 - 8390.7 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11870 - 11900 feet 12130 - 12214 feet 12214 - 12244 feet 12390 - 12680 feet 12720 - 12980 feet 13010 - 13070 feet 13130 - 13320 feet True Vertical depth 8876.69 - 8877.79 feet 8882.42 - 8882.2 feet 8882.2 - 8884.01 feet 8886.04 - 8892.81 feet 8893.81 - 8899.98 feet 8897.82 - 8894.91 feet 8898.88 - 8913.32 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment 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): x . Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 244 20260 19 0 907 Subsequent to operation: 1838 10309 114 0 436 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL Development s - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 0 Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature /L I ..At (1, Phone 564-4424 Date 8/30/2012 ®MS AUG 3 ��` /- A' -Wu- Form 10-404 Revised 10/2010 Submit Original Only • • C -33A 200 -202-0 Plugs Attachement SW Name Date MD Description C -33A 7/31/2012 10950 2 -3/8" BOT CIBP C -33A 11/10/2008 12295 1- 11/16" Baker IBP • • Packers and SSV's Attachment ADL0028304 SW Name Type MD TVD Depscription C -33A PACKER 4063 3475.68 7" Baker C -2 ZXP LT Packer C -33A PACKER 10258 8190.4 7" Baker C -2 ZXP LT Packer C -33A PACKER 10570 8434.17 3 -1/2" Baker S -3 Packer C -33A PACKER 10803 8585.95 3 -1/2" Baker Liner Top Packer C -33A PACKER 10830 8601.52 3 -1/2" Baker S -3 Packer Casing / Tubing Attachment ADL0028304 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" 91.5# H-40 35 - 114 35 - 114 1490 470 LINER 6179 7" 26# L -80 4063 - 10242 3543.38 - 8245.7 7240 5410 LINER 1006 7" 29# NT -80 10250 - 11256 8251.9 - 8859.68 8160 7020 LINER 2569 2 -3/8" 4.6# L -80 10803 - 13372 8653.65 - 8916.77 11200 11780 PRODUCTION 10394 9 -5/8" 47# NT8OS 33 - 10427 33 - 8390.7 6870 4760 SURFACE 3574 13 -3/8" 68# L -80 35 - 3609 35 - 3190.79 5020 2260 TUBING 10640 3 -1/2" 9.2# 13Cr80 31 - 10671 31 - 8572.09 10160 10530 • TUBING 212 3 -1/2" 9.2# L -80 10666 - 10878 8568.82 - 8696.08 10160 10530 • TREE = CNV Y NOTES: "'•3 -1i2" CHROME IBC"' • ACTUATOR= BAKER C C -3 3A FISHING. OF 11/08/08, TOP FKR DAMAGED DUG FISFG. LTP SUCCESSFULLY DRFTED w /1.72" TOOLSTRING KB. ELEV = 67.7' BF. ELEV = 37.5' VVELL ANGLE1I2> 70' C� X NP 1121 0 "'CtfROME NPPLES "' KOP = 1156' , I 1995' _IL �3 " HES - PL), D = 2.813" Max Angle = 95° @ 12654' GAS LIFT MANDRELS Datum MD = 11351' ST MD ND DEV TYPE VLV LATCH FORT DATE -- L Datum NDss= 8800' SS 2 4469 3860 40 MG DOME RK 16 02/19/08 20" CONDUCTOR 91 54, 1+40, ID = 19.1 78' 1 1 7515 6188 39 MMG SO RK 20 02/19/08 113 -3/8" CSG, 68#, BTC, L -80, D = 12.415" — 3609' IN In 4063' — 9-5/8" X 7" BKR G2 ZXP LTP, D = 6.290`, VI IN 4 4 '� • 081' 4 1— 9-5/8" X 7" BKR FLEX LOCK LNR HGR D = 6.300" 1 7' SCAB L142, 26#, L -80 BTC-M, { 10242' �� b • e • D = 6.276" . • �� /4 I 10251' - - 9-5/8" X 7' BKR LTP w /TE BACK SLV , ID = 6 780" I [TOP OF 7" LNR —[ 10251' • i • r 10263' 1 BKR FMC LNR HGR, D 6.30" 9 -5/8" CSG, 47 #, NT -80S NSCC, D 87681" — 10429' 10536' H3 Ifs X NP (9 - CR), D = 2.813" IC4 ��4 10559' — 17" X 3 BKR S PKR (9 - C!t), ID = 3.870" 10584' I- 3 H S X NP (9 - CPL), ID = 2 813' 3 -1/2' TBG, 9 2#, 13CR - VAM TOP, — 10658' 1063T — { 3 112" FfS XN NP CPL), D = 2.725" .0087 bpf, D = 2992" -- — 10660' — 17" X 3-1/2' UNQUE OVERSHOT (9 - CIS I 3-1/2" MG STUB (01- 31 -08) --- 10666 -"- co 10803' I 13 -1/2" BKR LTPw / SEAL ASSY, D= 1 75 " 1 ill 10808' -- I BKR DEPLOY SLV [TOP OF 2-3/8" LI'R I-1 10808' I' 10818' —13-1/2" F ES X MI', D = 2.75" Minimum ID = 1.75" @ 10803' 10828' H3 -1/2" x 4 - 1/2" XO, D= 2.937" SEAL ASSEMBLY -, „ 10830' — 1 7' X 4-1/2' BKR S-3 PKR D= 3.920" BEHIND 10834' H4 -1/2" x 3 -1/2' XO, D = 2.937" PIPE 3-1/2" TBG, 9.2#, L -80, TDS, —I 10878' .0087 bpf, D = 2.992" 10855' HI 3-1/2" HES X NP, D - 2.75" TOP OF CEMENT( TAGGED 11/16/01) H 11142' 10866' — I 3-1/2" IFS X NIP D = 2.75' IBP (12/23/00) H 11290' 10878' — I3 - 1/2" WLEG, D = 2.990" PERFORATION SUMMARY REF LOG: CNJGR/CCL MEMORY LOG ON 01/28/2001 10874' — I TTL E3MD - LOGGED 10/18/95 ANGLE AT TOP PERE: 88° @ 11870' Note: Refer to Production DB for historical perf data ,--. -LOUT WrpOW (C - 33A) 11250' - 11256' SIZE SPP INTERVAL Cpn /Sqz DATE — 1 -9/16" 6 11870 - 11900 0 07/30/12 4 �...p..- 11949' I BOT CBP (07/30/12) 1 -9/16" 6 12130 - 12244 C 11/08/08 / � �.r�r/ ------- 1 - 11/16" 4 12390 12680 C 01/28/01 12295' -- 11/16" BKR BP(11 /08108) 1-11/16" 4 12720 - 12980 C 01/28/01 4O� `� ( PBTD —I 13320' 1-11/16" 6 13010- 13070 C 01/19/06 1- 11/16' 4 13130 - 13320 C 01/28/01 .1 7" LNR 29#, NT -80 NSCC, .0371 bpf, ID = 6.184" I- 11770' 2 LNR 4.6#, L -80 FL4S, .0039 bpf, ID= 1.992" — 13372' DATE REV BY COMMENTS DATE REV BY COAT+ENTS I PRUDHOE BAY UNIT 07/09/93 FARGO ORIGINAL COMPLETION 08/01 /12 F$S/JMD SET CIBP & ADPERF (07/30/12) WELL. C-33A 10/10/95 016 RWO PERKY Mx '2002020 02/01/01 CDR - CTD(C - 33A) AR No: 50- 029 - 22373 -01 02/12/08 N4ES R11VO SEC 19, T11 N, R14E, 700' FNL & 1222' Fa - 11/20/08 GLMrTLH PERE & PULUSET EP (11/08/08) 03/04/09 SANJM) DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 AUG 3 1 ?Rif Mr. Tom Maunder �t�ka Off & ��s cry. co Oil and Gas Conservation Commission 333 West 7 Avenue richerhgA Mission Anchorage, Alaska 99501 j,60 Subject: Corrosion Inhibitor Treatments of GPB C -Pad Dear Mr. Maunder, e -3 A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator S • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -278 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 _ 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 ~~ J L R f~ ft~l/ ProActive Diagnostic Services, inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~~ y ,1. RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services:,. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 /~-~S5 6 1) Coil Flag ~7 ~/ .~ C-33A 2) Reprint Corrected API # Signed Print Name: E~ 50.029-22371-01 Date : _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907245-88952 E-AAAIL _. ~.... ,_ WEBSITE: ., >; .,~:`si .~ C:\Documerts and Settings\Owner\pesktoplTransmit_BP.docx ProActi.ve Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/ Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: 1) Coil Flag 2) Signed: Print Name: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd Anchorage, Alaska 99508 and �'A-NMED FEB 11. 0 2009 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 07 -Nov -08 C -33A EDE 50-029-22373-00 Date . x=p-9 s) 3 0039 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL: odsalacehoragn(Qm�asd or§ ,✓loci.com WEBSITE: Nlpm.me93€€ mate --om e CADmuments and Settings\Owner\Desk,-top\Tmwmit_HP.doc ~~ • ~ STATE OF ALASKA ~~~~ ~~V~~~~D ALA OIL AND GAS CONSERVATION COMON REPORT OF SUNDRY WELL OPERATIONS MAR 0 7 2a~8 1. Operations Performed: ^ ® ^ ^ ^ ~ Abandon Repair Well Stimulate Plug Perforations Re-Ent d Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~ 200-202 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-22373-01-00~ 7. KB Elevation (ft): ,~ 67 T ~ 9. Well Name and Number: , l P BU C-33A - 8. Property Designation: 10. Field /Pool(s): ~ADL 028304 ~ ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 13372 feet true vertical 8917 ~ feet Plugs (measured) 10700 Effective depth: measured 13320 feet Junk (measured) None true vertical 8913 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3609' 13-3/8" 3609' 3191' 4930 2270 Intermediate 10429' 9-5/8" 10429' 8392' 6870 4760 Production Liner 999' 7" 10251' - 11250' 8253' - 8858' 8160 7020 Liner 2553' 2-3/8" 10804' - 13372' 8654' - 8917' 11200 11780 Liner 6179' 7" 4063' - 10242' 3543' - 8246' P rf i D h MD ft ' ' ~~~ APR ~. ~ ~~~~ ~ orat on ( e ept ): 12390 - 13320 ;r Perforation Depth TVD (ft): 8886' - 8913' 3-1 /2", 9.2# 13Cr80 / L-80 10878' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 3-1/2" Baker'S-3' packer; 10559'; 7" x 4- 1/2" Baker'S-3' packer ~- ' ° 10830' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 10659'. Set RPB and dump sand on top (-10324'). Run 7" scab liner, cement w/ 176 Bbls Class 'G' (988 cu ft / 852 sx . Circulate out sand and retrieve bride lu .Run new Chrome tubin to 10660'. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564-4387 307-379 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: Signature Phone 564-4628 Date ~7,t~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~~~~~~~ ~ F J ~( Submit Original Oniy .~ / U ~~ t~ • • C-33A Well History Date Summary 12/26/2007 T/IA/OA= SSV/0/220 Temp SI PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T: Stung into test void to check pressure (0 psi). Functioned LDS "ET style" and torqued to 450 Ib/ft. Pumped through void until clean returns achieved. Pressured void to 5000 psi for 30 minute test, lost 200 psi in 15 min, lost 75 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void to check pressure (0 psi). Functioned LDS "ET style" and torqued to 450 Ib/ft. Pumped through void until clean returns achieved. Pressured void to 3500 psi for 30 minute test, lost 100 psi in 15 minutes, lost 0 psi in second 15 minutes (PASS). Bled void to 0 psi. 1/4/2008 WELL S/I ON ARRIVAL. DRIFT W/ 2.25 CENT, S-BAILER, T_AG BB PLUG @ 10675' SLM, RECOVERED -1/2 CUP OF HYDRATES AND SLUSH. .~ 1/5/2008 CALIPER TUBING FROM 10692' SLM TO SURFACE (good data). SET 3 1/2" JUNK CATCHER C~ 10692' SLM. LEFT WELL S/I. 1/7/2008 WELL SHUT IN ON ARRIVAL. T/I/0=500/0/200. RUN 1) SMALL TUBING PUNCH SHOT AT 10636 FT TO ESTABLISH TxIA~OMMUN.ICATION. DID NOT SEE PRESSURE EQUALIZATION ON SURFACE, TOLD TO HOLD FOR PUMP TRUCK TO CONFIRM TxIA COMMUNICATION. CHANGE OF PROGRAM 1 HOUR LATER, CALLING FOR JET CUTTER. RUN 2) 2.5" POWERCUTTER, 2 WEIGHT BARS, SHOCK ABSORBER, CCL. CORRELATED W/ TBG TALLY, DID NOT TAG PLUG. CUT PERFORMED C~ 10654 FT, APPROX. 10 FT BELOW FIRST FULL JOINT ABOVE PLUG SET @ 10700 FT. PRESSURE NEVER EQUALIZED. WELL LEFT SHUT IN ON DEPARTURE: T/I/0= 300/0/200. JOB COMPLETE. 1/17/2008 T/I/0=0/0/220. Circ-out (Pre RWO). Pumped 5 bbls 60/40 meth water and 220 bbls 9.8 NaCI Brine down Tbg through Tbg cut up IA taking returns down flowline. 1/18/2008 Circ-Out/Bullhead 9.8 ppg NaCL Brine (Pre RWO) Pumped 350 bbls 9.8 NaCL Brine and 5 bbls diesel down Tbg while taking returns to IA down flowline. RD from Tbg, RU to IA. Bullheaded 465 bbls 9.8 ppg NaCL Brine and 31 bbls diesel down IA. RD form IA, RU to OA. Bullheaded 220 bbls 9.8 ppg NaCL Brine and 26 bbls diesel down OA. Freeze protected flowline with 10 bbls meth and 123 bbls crude (WOA Recipe), tail end with 15 bbls diesel. FWHP's=VacNac/20 upon deparure. Annulus valves tagged and open to gauges. Note: OAP on steady decline of pressure. 1/21/2008 T/I/O=VAC/0/O..Set 4-1/16" CIW "H" BPV. (Pre 4-ES). 1/27/2008 T=vac; Pull 4-1/16" CIW "H" Bpv thru tree, no problems; 1-2' ext. used, tagged C~ 102". COMPLETE. BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/12/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task ,Code' NPT ~ .Phase Description of Operations 1/26/2008 23:00 - 00:00 1.00 RIGD I P PRE PJSM. Rig down rig and rig components off of L2-06. 1/27/2008 00:00 - 03:00 3.00 RIGD P PRE Continue to rig down rig and rig components, scope down and lay over derrick. 03:00 - 12:00 9.00 MOB P PRE PJSM. Move rig, camp and rig components from L2-06 to C-33, 15 mile move. 12:00 - 17:00 5.00 RIGU P PRE PJSM. Spot camp, rig sub and rig components. Raise and scope up derrick. Accepted rig at 17:00 hrs 1/27/2008. 17:00 - 18:00 1.00 RIGU P PRE RU hard lines to tree. 18:00 - 19:30 1.50 RIGU P PRE Held crew change and performed pre-tour checks. Continued RU lines to tree. Filled rig pits with hot 9.8 ppg brine. 19:30 - 20:30 1.00 WHSUR P DECOMP PUMU lubricator. Tested lubricator to 500 psi. Pulled and LD 20:30 - 22:00 1.50 KILL P DECOMP RU lines for tiger tank while waiting for same. 22:00 - 00:00 2.00 KILL P DECOMP Spotted and bermed tiger tank. Finished RU lines to tank. 1/28/2008 00:00 - 00:30 0.50 KILL P DECOMP Continued RU lines to tiger tank. 00:30 - 06:00 5.50 KILL P DECOMP Tested lines to 250 si low / 3500 si hi h. Held PJSM. Opened well, tbg pressure 0 psi and annulus pressure 0 psi. Initially pumped 10 bbls 9.8 ppg brine down annulus, had no returns from tubing. Lined up to circulate 9.8 ppg brine the long way, displacing diesel freeze protect and well fluid. Pumped 3-5 bpm, 840 psi - 1400 psi tbg pressure, 130 psi - 310 psi annulus pressure. Circulated through choke and micro motion meter. Lost 1-1/2 bpm while pumping 5 bpm. Pumped total of 820 bbls, getting warm 9.7 ppg back. 06:00 - 06:30 0.50 KILL P DECOMP Shut down, (50 bbls left in pits). Monitor well, both sides on vacuum. Inspect derrick, service rig, check PVT system, OK. 06:30 - 07:30 1.00 KILL P DECOMP PJSM. Line up and circulate 9.8 ppg brine to 9.8 ppg returns, 150 bbls C~3 4 bpm / 1150 psi. Shut down, monitor well, both sides on a vacuum. 07:30 - 08:30 1.00 WHSUR N SFAL DECOMP PJSM. Tee bar in 2 way check valve. Test from the top to 3500 psi, not holding. Pick up lubricator, test to 500 psi, OK. Pull 2 08:30 - 11:30 3.00 WHSUR N SFAL DECOMP Wait on well support to get done at Nordic and bring another 2 way check. 11:30 - 13:00 1.50 WHSUR N SFAL DECOMP PJSM. Set two way check, test from above ~ 3500 psi, bled to 3200 in 10 minutes and flat lined at 3200 psi. Attempt to test from below, pumping 4 bpm / 250 psi, open needle valve on top of tree to check for communication, check valve leaking (badly). FMC verifies it is not leaking around the tubing hanger. P/U lubricator, test C~3 500 si OK. Pull two wa check valve. 13:00 - 15:00 2.00 WHSUR N SFAL DECOMP PJSM. Notify town. Call for slickline. Set 3rd two wav check. attem t to test from the to , no ood. P/U lubricator, test to 500psi, OK. Pull two way check. 15:00 - 18:00 3.00 WHSUR N SFAL DECOMP Wait on Schlumberger slickline. 18:00 - 18:30 0.50 WHSUR P DECOMP Held crew change /PJSM with SWS personnel. Performed pre-tour checks. 18:30 - 19:30 1.00 WHSUR N SFAL DECOMP Spotted slickline equipment. Waited for delivery of slickline lubricator extension. 19:30 - 22:30 3.00 WHSUR N SFAL DECOMP RU slickline equipment. 22:30 - 00:00 1.50 WHSUR N SFAL DECOMP Tested slickline lubricator to 500 psi. RIH with 2.75" slickline plug. Set plug in nipple at 2171' WLM. 1/29/2008 00:00 - 01:00 1.00 WHSUR N SFAL DECOMP Sheared off slickline plug, POH with slickline. Printed: 2/27/2008 2:57:10 PM • • BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/12/2008 Rig Name: NABOBS 4ES Rig Number: Date ~~ From - To Hours ' Task Code NPT Phase Description of Operations 1/29/2008 01:00 - 02:30 1.50 WHSUR N SFAL DECOMP Tested slickline lu from above to 3500 si for 10 minutes. filled IA with 50 bbls 9.8 ppg brine. Tested plug from below by pumping down IA at 3 bpm and 400 psi for 30 minutes. 02:30 - 04:30 2.00 WHSUR N 04:30 - 06:00 1.50 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 08:30 2.00 BOPSUfj P 08:30 - 13:30 5.00 BOPSU P 13:30 - 14:30 1.00 DHB N 14:30 - 16:00 1.50 DHB N 16:00 - 21:00 5.00 DHB N 21:00 - 22:30 1.50 DHB N 22:30 - 00:00 I 1.501 DHB I N 1/30/2008 00:00 - 01:00 1.00 DHB N 01:00 - 02:00 1.00 DHB N 02:00 - 02:30 0.50 PULL P 02:30 - 03:00 0.50 PULL P 03:00 - 05:30 2.50 PULL P 05:30 - 06:00 0.50 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 08:30 I 2.001 PULL I P 08:30 - 09:00 0.50 PULL P 09:00 - 15:30 6.50 PULL P 15:30 - 16:30 1.00 PULL P 16:30 - 17:00 0.50 PULL P 17:00 - 17:30 0.50 PULL P 17:30 - 18:00 0.50 PULL P 18:00 - 18:30 0.50 CLEAN P 18:30 - 21:00 2.50 CLEAN P 21:00 - 00:00 3.00 CLEAN P 1/31/2008 00:00 - 05:00 5.00 CLEAN P 05:00 - 11:00 6.00 CLEAN P 11:00 - 12:30 I 1.501 CLEAN I P Pumped total of 146 bbls 9.8 ppg brine. SFAL DECOMP RD slickline equipment. RD and blew down lines. DECOMP Bled void and control lines. ND tree. DECOMP Service rig, check PVT system, crown o matic, derrick inspection, OK. DECOMP PJSM. N/U BOPE. DECOMP Conduct full test on all BOPE. Witnessing of test waived by AOGCC rep John Crisp, (24 hour notice given). All tests 250 low pressure, 3500 high pressure. No failures. SFAL DECOMP PJSM. N/U shooting flange. SFAL DECOMP Wait on Schlumberger slick line. SFAL DECOMP PJSM. Rig up Schlumberger slickline to retrieve plug @ 2117'. SFAL DECOMP Pressure test lubricator to 500 psi, Tested OK. RIH w/ prong & equalize plug. SFAL DECOMP Change out tools &RIH w/ retreiving tool. Pull plug @ 2117'. POOH & UD same. SFAL DECOMP R/D slickline equip. SFAL DECOMP N/D shooting flange. N/U flow nipple & air boot. DECOMP P/U & M/U X-over into hanger 9 turns. BOLDS. P/U & pull ; han er to floor. Came free w/ 103K. P/U pull w/ 93K. DECOMP Cut control lines. Break out & UD hanger. DECOMP M/U circulating head. Circulate bottoms up. Filled hole w/ 52 bbls. Pump 6 BPM @ 900 psi. Pumped total of 725 bbls. Lost DECOMP POOH & UD 3 1/2" completion. DECOMP Service rig, check crown o matic, PVT system, derrick inspection, OK. DECOMP PJSM. Continue to POOH w/ 3 1/2" and dual control lines. Recovered 40 stainless steel bands, missing 3. DECOMP PJSM. Rig down Schlumberger spooling unit. DECOMP PJSM. Continue to POOH w/ 3 1/2" completion string. Tubing is in good shape. Double displacing while POOH. Started getting returns while displacing late in the tri ,well still taking fluid. O/A is on a vacuum. Recovered 346 jts of tubing, (2) GLMs, (1) SSSV & 9.64' of cut off jt. Jet cut looked good. DECOMP R/U tools to handle 3 1/2" DP. - DECOMP Clear & clean rig floor. DECOMP P/U running tool & set Wear Bushing. DECOMP R/U hydraulic spinners. DECOMP Crew change. Check PVT alarms. Inspect derrick. DECOMP P/U & M/U BHA #1 to dress tubing stub as follows: MM Dress Off Shoe, Ext, MM Mill, W/O Boot Basket, XO, Scraper, XO, Bumper Sub, Jars, 9` 4 3/4" DCs, Pump Out Sub. TL = 319.94'. DECOMP P/U 3 1/2" DP 1x1 &RIH w/ BHA #1. RIH w/ 115 jts. DECOMP Con't to P/U 3 1/2" DP 1x1 &RIH w/ BHA #1. P/U 310 jts. (9965') DECOMP Change out reels. Cut & slip drilling line. Hle fill 30 bph while changing out drilling lines ool. DECOMP PJSM. Continue in hole w/ 3 1/2" DP. Tag 29' in on # 319, top Printed: 2/27/2008 2:57:10 PM • • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/12/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To I, Hours Task Code NPT Phase Description of Operations 1/31/2008 11:00 - 12:30 1.50 CLEAN P DECOMP of 7" liner, 10,243'. Continue in and tap fill ~ 10,540'. 12:30 - 15:30 3.00 CLEAN P DECOMP PJSM. Pick up kelly, establish parameters. 175K up wt, 101 K down wt. 126K rotating wt. 8500 ft/Ibs off bottom torque, rotating at 60 RPM, pumping 5 bpm / 1250 psi. Clean out fill to top of 3 1/2" tubing stub. Located top of stub C~? 10,659'. Dress off stub w/ 2 - 4K WOB, mill about 1' to shoe depth of 10,666'. Pump (1) 40 bbl hi vis sweep while milling and another after dressing off stub. Verify able to get over stub by picking up and swallowing tubing stub w/o rotating, OK. 15:30 - 18:00 2.50 CLEAN P DECOMP PJSM. Circulate sweep around at 5 bpm / 1250 psi. Saw some amount of sand back w/first sweep, and not very much with second sweep. 18:00 - 23:00 5.00 CLEAN P DECOMP R/U & reverse circulate hole clean. Pump 3 BPM C~ 560 psi. Pumped total of 710 bbls. 23:00 - 00:00 1.00 CLEAN P DECOMP Blow down lines & set back kelly. UD 2 singles. POOH & stand back 3 1/2" DP. 2/1/2008 00:00 - 05:00 5.00 CLEAN P DECOMP Con't to POOH & stand back 3 1/2" DP. 05:00 - 06:30 1.50 CLEAN P DECOMP Stand back DCs. Break out & UD BHA #1. 06:30 - 08:00 1.50 CLEAN P DECOMP Clear /clean rig floor. 08:00 - 09:00 1.00 DHB P DECOMP PJSM. M/U Halliburton 7" RBP & running tool and (9) 4 3/4" DCs. 09:00 - 12:00 3.00 DHB P DECOMP RIH w/ RBP BHA on 3 1/2" DP. 12:00 - 12:30 0.50 DHB P DECOMP PJSM. Crew change, service rig, check crown o matic, PVT system, OK. 12:30 - 16:00 3.50 DHB P DECOMP Continue in the hole w/ 3 1/2" DP. With Halliburton RBP just inside 7" liner, (TOL) ~ 10243', hanging up. Set down 10K, not going down. 175K up wt, 92K down wt inside 9 5/8". Rig up to circulate, circulate C~ 3 bpm /not helping, rotate to the right while setting down, worked thru (tight spot?), OK. Continue in hole, 108 stands total. Set Hallibuton RBP, top of bridge plug C~ 10,362'. Set down 10K to verify set, overpull 10K, OK. Release from bridge plug, POOH (1) stand and got through setting motions to verify RBP released OK. (Middle of element C~ 10366') 16:00 - 18:00 2.00 DHB P DECOMP PJSM. Dump 17 sacks, (850 Ibs), of 20/40 river sand. Wait 30 min & allow sand to fall. RIH & tag top of sand C~ 10324'. 18:00 - 23:30 5.50 DHB P DECOMP POOH & stand back 110 stands. 23:30 - 00:00 0.50 CLEAN P DECOMP Clear & clean rig floor. 212!2008 00:00 - 00:30 0.50 CLEAN P TIEBi Finish clearing & cleaning rig floor. 00:30 - 02:00 1.50 CLEAN P TIEB1 PJSM. P/U & M/U BHA #2 as follows: Polish Mill, Spacer Sub, Top Dressing Mill, PUP, XO, 2' Boot Baskets, XO, Jars, 9 ` 4 3/4" DCs, Pump Out Sub, 58 stands DP, XO, Csg Scraper, XO. TL = 4487.61' 02:00 - 04:30 2.50 CLEAN P TIEB1 RIH w/ BHA #2 + 10 stands. Took weioht C~ 6723.88' & hung up. P/U 31 K over & pulled free. P/U Wt = 114K, S/O Wt = 75K. 04:30 - 05:30 1.00 CLEAN C TIE61 POH & UD 9 5/8" scraper. 05:30 - 06:00 0.50 CLEAN C TIEBi RIH & verify scraper was not causing tight hole problem. 06:00 - 06:30 0.50 CLEAN C TIEB1 Service rig, check crown o matic, PVT system, OK. Derrick inspection, OK. 06:30 - 09:00 2.50 CLEAN C TIEB1 PJSM. POOH w/ 3 1/2" DP. 09:00 - 11:00 2.00 CLEAN C TIE61 PJSM. Stand back DCs, lay down polish mill assembly, pick up tapered mill assembly. Marks on polish mill assembly indicate a restriction of around 7 1/2" ID in the 9 5/8" casing. Printed: 2/27/2008 2:57:10 PM • • BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/12/2008 Rig Name: NABOBS 4ES Rig Number: ' Date From - To ; Hours Task Code NPT Phase Description of Qperations i 2/2/2008 11:00 - 14:00 3.00 CLEAN C TIE61 PJSM. RIH w/ milling BHA on 3 1/2" DP. Tag up 58' in on stand . # 69 C~ 6720'. 14:00 - 17:00 3.00 CLEAN C TIE61 PJSM. Stand back #69, pick up a single, kelly up & establish parameters. 121 K up wt, 77K down wt, 94K rotating wt. Engage rotary table, off bottom torque = 5000 fUlbs, rotating ~ 70 RPM. Pumping 4 bpm @ 525 psi. Mill from 6720' to 6721' w/ 1-2K WOB seeing torque increase with every slight slack off of the brake handle. Make slow progress but finally fell through. Stand back kelly. 17:00 - 18:00 1.00 CLEAN C TIEB1 PJSM. Run in hole w/ stands to ensure no further obstructions in the immediate area. Tag up @ 6834', another tight spot. Kelly up. 18:00 - 22:30 4.50 CLEAN C TIEB1 Mill thru tight spot in 9 5/8" casing from 6834 to 6835'. Then fell thru. P/U Wt = 119K, S/O Wt = 80K, Rot Wt = 95K. WOB 1-3K, 37-80RPMs 4 BPM ~ 450 psi. Torq 4.5-6.5K ft-Ibs. 22:30 - 23:00 0.50 CLEAN C TIEB1 Set back kelly &RIH. Tagged up hard ~ 6953'. (71 stds + 11') 23:00 - 00:00 1.00 CLEAN C TIEB1 P/U kelly break circulation & begin milling C~ 6951'. 4 BPM C~3 450 psi. 2/3/2008 00:00 - 05:30 5.50 CLEAN C TIEB1 Con't to mill tight spot in 9 5/8" casing C~3 6951'. P/U Wt = 120K, S/O Wt = 80K, Rot Wt = 95K. 35-75 RPMs, 4 BPM ~ 450 psi. WOB 1-3K. Stalling when weight exceeds 3K. Torq = 4.5-6.5K. Milled from 6951 to 6952', then mill fell thru tight spot. Rotate kelly down, then P/U & go down w o rotation. Blow down & set back kelly. 05:30 - 06:00 0.50 CLEAN C TIE61 RIH w/ stands tagged up ~ 7183' (73 stands + single + 25') L/D excess jts & kelly up. 06:00 - 06:30 0.50 CLEAN C TIE61 Service rig, check crown o matic, PVT system, derrick inspection, OK. 06:30 - 08:30 2.00 CLEAN C TIE61 PJSM. Mill tight spot in 9 5/8" casing @ 7183". P/U Wt = 120K, S/O Wt = 80K, Rot Wt = 95K. 35-75 RPMs, 4 BPM ~ .450 psi. WOB 1-3K. Stalling when weight exceeds 3K. Torq = 4.5-6.5K. Milled from 7183' - 7185", then mill fell thru tight spot. Rotate kelly down, then P/U & go down w/o rotation. Blow down & set back kelly. 08:30 - 09:30 1.00 CLEAN C TIEB1 PJSM. RIH w/ 3 1/2" DP, tag another tight spot C~ 7323'. Kelly up. 09:30 - 10:30 1.00 CLEAN C TIE61 PJSM. Mill tight spot in 9 5/8" casing (~ 7323'. P/U Wt = 120K, S/O Wt = 80K, Rot Wt = 95K. 35-75 RPMs, 4 BPM ~ 450 psi. WOB 1-3K. Stalling when weight exceeds 3K. Torq = 4.5-6.5K. Milled from 7323' - 7324", then mill fell thru tight spot. Rotate kelly down, then P/U & go down w/o rotation. Blow down & set back kelly. 10:30 - 12:30 2.00 CLEAN C TIEB1 PJSM. RIH slowly watching for more tigtht spots. Li htl to to of 7" liner Ca3 10 241' DPM. 12:30 - 13:00 0.50 CLEAN C TIEB1 Clear % clean floor. Prep to POOH. 13:00 - 17:30 4.50 CLEAN C TIEB1 PJSM. POOH w/ string mill assembly and 3 1/2" DP, watching for overpulls at tight spots, no overpulls. 17:30 - 18:00 0.50 CLEAN C TIEB1 PJSM. Stand back collars. 18:00 - 18:30 0.50 CLEAN C TIEBi Break out & L/D BHA. Empty boot Baskets. Recovered 1.5 pals of metal millings. Check mill, in gauge. 8 1/2". 18:30 - 19:30 1.00 CLEAN P TIE61 Clear & clean rig floor. 19:30 - 20:30 1.00 CLEAN P TIEB1 P/U & M/U BHA #4 as follows: P li h Space sub, Top dressing mill, Pup, XO, 2' Boot baskets, XO, Jars, 9' 4 3/4" Printed: 2/27/2008 2:57:10 PM BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/12/2008 Rig Name: NABORS 4ES Rig Number: Date 'From - To Hours Task Code I NPT I, Phase Description of Operations 2/3/2008 19:30 - 20:30 1.00 CLEAN P TIE61 DCs. 20:30 - 00:00 3.50 CLEAN P TIEB1 RIH w/ BHA # 4. Ran 58 stands, then P/U XO, Scraper, XO & con't to run stands of 3 1/2" DP. 2/4/2008 00:00 - 00:30 0.50 CLEAN P TIEBi Finish RIH w/ BHA #4. to polish liner recepticle. Ran 106 stands. 00:30 - 01:30 1.00 CLEAN P TIEB1 P/U kelly & break circulation. Pump 3.5 BPM 1470 psi.,Polish liner rece ticle from 10242 to 10247'. P/U Wt = 169K, S/O Wt = 101 K, Rot Wt = 124K. 60-80 RPMs, Torq = 8-9.5K. WT on mill = 0-2K. Scraped casing 4495-4513'. 01:30 - 02:00 0.50 CLEAN P TIEB1 Blow down & Set back kelly. R/U circulating head. Reverse circulate3 BPM C~3 480 psi. 02:00 - 03:00 1.00 CLEAN P TIEB1 Hold wekly safety meeting. 03:00 - 04:00 1.00 CLEAN P TIEB1 Con't to reverse circulate hole clean. 3 BPM ~ 480 psi. Pump 3 DP volumes. No solids over shaker. Losses nealiaible. 04:00 - 06:00 2.00 CLEAN P TIEB1 POOH & stand back 3 1/2" DP. 06:00 - 06:30 0.50 CLEAN P TIEB1 Service rig, check crown o matic, PVT system, derrick inspection, OK. 06:30 - 08:30 2.00 CLEAN P TIEB1 Continue to POOH w/ 3 1/2" DP, UD scraper assembly & continue to POOH. 08:30 - 10:00 1.50 CLEAN P TIEB1 PJSM. Stand back drill collars, UD polish mill assembly. Clear / clean rig floor. 10:00 - 11:00 1.00 EVAL P TIEB1 JSM. M/U RTTS w/ (9) 4 3/4" DCs below it. 11:00 - 13:00 2.00 EVAL P TIE61 PJSM. RIH w/ RTTS assembly on 3 1/2" DP, set RTfS w/ 1 1/2 right hand turns & set down 20K. Middle of elements 4488'. 13:00 - 15:00 2.00 EVAL P TIEBi PJSM. Fill hole, close pipe rams, rig up test chart. Pump 55 stks and test 9 5/8" casing from surface to 4488' for 30 minutes ood test, charted, photo of chart sent to town. Check O/A at end of test before bleeding off pressure, O/A showed sli ht vacuum then no pressure as it has in the past. Bleed off all pressure, open pipe rams, rig down test equipment. 15:00 - 16:00 1.00 EVAL P TIEB1 PJSM. POOH w/ 3 1/2" DP. 16:00 - 16:30 0.50 EVAL P TIEB1 PJSM. UD RTTS, stand back drill collars. 16:30 - 18:00 1.50 EVAL P TIE61 Clear /clean rig floor. 18:00 - 18:30 0.50 EVAL P TIE61 Crew change. Inspect derrick. Check PVT alarms. 18:30 - 19:30 1.00 CASE P TIE61 R/U to tools to run 7" liner 19:30 - 20:00 0.50 CASE P TIEB1 Hold PJSM. Review running order & liner running procedures. Assign tasks to specific personnel. 20:00 - 00:00 4.00 CASE P TIEB1 Run 7" 26#, L80, BTC-M liner as per program. Fill every 5 jts. Baker-locked 1st 3 connections. Installing 1 floating centralizer per jt. Ran in hole w/ 40 jts. 2/5/2008 00:00 - 06:00 6.00 CASE P TIEBi Con't to RIH w/ 7" 26#, L-80, BTC-M, liner. Fill every 5 jts. Install 1 floating centralizer per jt. Ran in w/ 125 its. 06:00 - 06:30 0.50 CASE P TIEB1 Crew changeout and pre-tour HSE meeting. Service rig: grease blocks, drawworks and crown, daily derrick inspection and check PVT's. 06:30 - 12:45 6.25 CASE P TIEB1 RIH w/DP from derrick. 12:45 - 13:45 1.00 CASE P TIE61 Spaceout liner to tie-back receptacle. PUMU Baker cementing head. 13:45 - 15:00 1.25 CASE P TIEB1 Circulate well with 9.8-ppg brine to warm up hole. PJSM: Rigging up Schlumberger cementers. Rig up cementers. Circulating returns ~ 68F. Shut down circulating. Printed: 2/27/2008 2:57:10 PM • • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/5/2008 15:00 - 15:30 C-33 C-33 WORKOVER NABOBS ALASKA DRILLING I NABOBS 4ES Hours Task Code NPT Spud Date: 6/13/1993 Start: 1 /23/2008 End: Rig Release: 2/12/2008 Rig Number: Phase ', Description of Operations 0.501 CASE I P I I TIEBi 15:30 - 18:00 2.50 REMCM P TIE61 18:00 - 18:30 0.50 REMCM P TIEB1 18:30 - 20:00 1.50 REMCM P TIEB1 20:00 - 21:30 1.50 REMCM P TIEB1 21:30 - 22:30 1.00 REMCM P TIE61 22:30 - 23:30 1.00 REMCM P TIEB1 23:30 - 00:00 0.50 DRILL P TIEB1 2/6/2008 00:00 - 00:30 0.50 DRILL P TIE61 00:30 - 01:30 1.00 DHB P TIEB1 01:30 - 03:30 2.00 DHB P TIEBi 03:30 - 05:00 1.50 BOPSUF~P TIEB1 05:00 - 07:00 2.00 WHSUR P TIEB1 07:00 - 09:30 I 2.501 WHSUR I P I ITIEBI 03:00 - 17:00 4.00 BOPSU~P TIE61 PJSM: Reviewed cementing procedure with all. Reminded all of hazards associated with high pressure pumping. Also discussed walking/working surfaces and traction device requirements. Prime up pumping equipment. Pumped 5-Bbls. fresh water. P/T lines to 500-psi Lo and 4500-psi Hi. Batch mix slurry to 15.8-ppg. Start pumping cement taking returns through choke to rig pits. Pumped 176-Bbls. 15.8-ppg Class "G" cement C~3 3-6 bpm while holding 1200-psi backpressure . Shut down and drop DP dart. Displace cement with 9.8-ppg brine. Did not see DP dart pick up liner wiper plug. Displaced cement and bumped plug with 259-Bbls. brine. Raised pressure to 2300-psi to verify plug on landing collar. Bled off pressure. Slackoff and bury ports on liner tie-back stem in liner tie-back receptacle. Pressured up to 3100-psi to set liner hanger and then to 4500-psi to set liner top packer. Bled pressure off and picked up string to leave 20K downweight on liner running tool. Turned DP 15 turns to the right. Picked up 2' and pressured up DP to 1000-psi. Pulled liner running tool out of liner top while pumping C~ 4-5 BPM. Pumped 20-bbls. to lift cement up hole away from liner top. Closed annular preventer and reversed out cement. Con't to Reverse out. Pumped 6 BPM @ 1300 psi. Reversed total of 135 bbls. Fluid returns clean. Blow down & rig down lines. UD cementing manifold. POOH & stand back 3 1/2" DP. Break out & UD liner running assy. Clear & clean rig floor. M/U BHA # 5 as follows: 6 1/8" Bit, Bit Sub, 2- Boot Baskets, , 9 - 4 3/4" DCs, XO, Jars, XO. TL = 301.29'. Finish P/U & M/U BHA # 5. RIH on 10 stands of DP. P/U HES storm packer, RIH & set C~ 29' w/ 23K down wt. R/U circulating pin. Pressure test storm packer from below w/ 1000 psi, for 30 min. Test good. Back out landing jt w/ 21 left hand turns & UD landing jt. dose in blind rams. Pressure up to 1000 psi & test storm packer from above for 30 min. Test good. Monitored OA during test No pressure observed..OA on vacuum. R/D test equip. Drain stack. Split BOP stack & set back. Bleed pressure off casing packoff void. BOLDS. Remove tubing adapter spool and old 9-5/8" casing packoff. Prep new packoff and casing stub. Install new packoff, set old tubing spool on casing head and flange up studs with Sweeney torque wrench. RILDS. P/T casing packoff void to 5000-psi for 30-min. Note: This wellhead has a mandrel casing hanger so that the 5000-psi test pressure was against the slick neck of the hanger and the packoff elastomer seals and not directly on the casing which has a collapse pressure of 4750-psi. Good test. Set test plug in tubing adapter spool. NU BOPE. P/T BOPE per AOGCC/BP requirements: 250-psi Lo/3500-psi Hi. Annular would not test. Manual choke valve no test. 250-psi Lo/3500-psi Hi. States right to witness test was waived Printed: 2/27/2008 2:57:10 PM • • BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING i Rig Release: 2/12/2008 Rig Name: NABOBS 4ES Rig Number: Date I From - To Hours Task Code NPT I Phase L Description of Operations 2/6/2008 13:00 - 17:00 4.00 BOPSU P TIEB1 by Lou Grimaldi. 17:00 - 18:00 1.00 BOPSU N SFAL TIEB1 R/D test equip. Prep for working on annular & manual choke valve. 18:00 - 00:00 6.00 BOPSU N SFAL TIEB1 Replace annular preventer rubber sealing element_& install r 2/7/2008 00:00 - 04:30 4.50 BOPSU N SFAL TIE61 Con't to replace annular preventer rubber element & replace manual choke valve. 04:30 - 07:30 3.00 BOPSU P TIEB1 Con't to test BOPE. Test annular 250/3500 psi. Test manual choke valve 250/3500. Test Koomey. Rig down test egpt. and pull test plug. 07:30 - 08:45 1.25 BOPSU P TIEB1 RIH w/RTTS pulling tool. Release RTTS packer. POH VD RTTS packer and pulling tool. 08:45 - 12:30 3.75 REMCM P TIEBi RIH w/DP from derrick. Tag cement C~ 10169'. 12:30 - 13:30 1.00 CASE P TIEB1 Close pipe rams and stab TIW valve. Pressure test 9-5/8 x 7" casing to 3500- si for 30 charted minutes. Good test. 13:30 - 18:00 4.50 REMCM P TIEB1 Kelly up. establish drilling parameters: PUW = 173K, SOW = 101 K, Rot Wt. = 125K, RPM = 65-70, WOB = 5-10K, Torque = 350-400 amps. Mix 1 drum EP Mudlube in 25-bbl. pill and pump same to reduce rotating torque. Qrillina cement.. 18:00 - 00:00 6.00 REMCM P TIEB1 Con't to drill landing collar, cement & float collar. Drill from 10182 to 10242'. P/U Wt = 157K, S/O Wt = 110K, Rot Wt = 130K. Pump 4 BPM C~ 770 psi. Swept hole w/ 40 bbl Hi-Vis pill. Torq = 4.5-5K. 85 RPMs, 5-12K WOB.210 2/8/2008 00:00 - 01:00 1.00 REMCM P TIEB1 Drill from 10242 to 10252'. 106 stands + single + 25'. P/U Wt = 157K, S/O Wt = 110K, Rot Wt = 130K. Pumped 4 BPM C~ 770 psi. 5-6K WOB, 75-85 RPMs, Torq 5K. 01:00 - 03:30 2.50 REMCM P TIEB1 Pump 40 bbl Hi-Vis sweep & circulate well clean. Pump 5 BPM C~ 1200 psi. Pumped total of 535 bbls. Had cement returns in swee .Blow down & set back kelly. 03:30 - 09:00 5.50 REMCM P TIEB1 POOH & stand back 3 1/2" DP. BO/LD BHA #5. Recovered -2 gallons cement and misc. small pieces metallic debris in boot baskets. 6-1/8" bit measures full gauge, but it appears that bearings are worn on one wheel. 09:00 - 10:00 1.00 REMCM P TIE61 Clear and clean rig floor. PJSM -makeup BHA #6 and RIH. 10:00 - 14:45 4.75 REMCM P TIEB1 PUMU BHA #6: 6" mill shoe, 5-1/2" RCJB, 2' 4-3/4" boot baskets, XO, oil jar and 9 ' 4-3/4" drill collars. Total length = 313.43'. RIH on DP from derrick. Tag up at 10250'. 14:45 - 17:00 2.25 REMCM P TIEB1 Tag at 10250'. Kelly up obtain parameters: P/U Wt. = 173K, S/O Wt. = 101 K, Rot Wt. = 125K, 65 RPM. Pumped 4.5 BPM ~ 920-PSI. Washed to 10252' and hit hard bottom.. P/U, broke off kelly and dropped ball. M/U kelly and pump ball on seat at 3 BPM. Took 17 minutes to pump ball on seat. Increased pump rate to 5-1/2" BPM C~2 1800-PSI. Milled cement from 10252' to 10255'. CBU. Recovering cement cuttings over shaker screen. 17:00 - 18:30 1.50 REMCM P TIEB1 Cut & slip 84' of drilling line. 18:30 - 23:30 5.00 REMCM P TIEB1 POOH & stand back 108 stands of 3 1/2" DP. 23:30 - 00:00 0.50 REMCM P TIE61 POOH & stand back DCs & BHA. 2/9/2008 00:00 - 00:30 0.50 REMCM P TIE61 Break out & UD BHA. Clean out RCJB & boot baskets. Recovered 2 pc of Aluminum & 1 gal of cmt & 3 cmt chunks. 00:30 - 01:00 0.50 REMCM P TIEB1 M/U BHA #7 as follows: 6" Bit, 2 Boot Baskets, 7" Csg Scraper, XO, Jars, 9 - 4 3/4" DCs. TL = 01:00 - 05:30 4.50 REMCM P TIEB1 RIH w/ BHA #7. Tag TOC C~ 10255'. Printed: 2/27/2008 2:57:10 PM • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Start: 1 /23/2008 Rig Release: 2/12/2008 Rig Number: Spud Date: 6/13/1993 End: Date 'From -"To Hours Task Code NPT 2/9/2008 05:30 - 00:30 19.001 REMCM P 08:30 - 10:30 2.00 R 10:30 - 14:30 4.00 R 14:30 - 15:30 1.00 R 15:30 - 16:00 0.50 R 16:00 - 16:30 0.50 R 16:30 - 18:00 1.50 R 18:00 - 18:30 0.50 R 18:30 - 21:00 2.50 R 21:00 - 21:30 0.50 R 21:30 - 23:30 2.00 R 23:30 - 00:00 0.50 R 2/10/2008 00:00 - 00:30 0.50 R 00:30 - 02:00 1.50 R 02:00 - 11:00 9.00 R 11:00 - 12:00 1.00 R 12:00 - 13:00 1.00 13:00 - 14:30 1.50 14:30 - 15:00 0.50 15:00 - 18:00 3.00 18:00 - 19:30 I 1.50 19:30 - 00:00 4.50 2/11/2008 00:00 - 06:00 6.00 06:00 - 06:30 I 0.50 Phase Description of Operations TIEB1 Kelly up. Establish drilling parameters: P/U Wt = 173K, S/O Wt = 101 K, Rot Wt = 125K, RPM = 65, 6 BPM C~ 1800-PSI. Drill hard cement and stringers to 10300'. wash to TOS C~ 10324'. Make connection and wash without rotating to 10330'. TIEB1 P/U to 10320' and circulate hole clean C~2 6 BPM ~ 1800-PSI. TIEB1 PJSM. POH standing DP in derrick. TIE61 POH standing drill collars in derrick. BO/LD 6" bit boot baskets, oil jar and 7" casing scraper. Recovered 1 gallon TIE61 Clear and clean rig floor. TIEB1 PJSM -RIH w/DP from derrick. TIE61 IH w/RBP overshot on DC's and DP from derrick. TIE61 Crew Change. Inspect derrick. Check PVT alarms. TIEB1 Con't to RIH w/ Retrieving tool on stands of 3 1/2" DP. RIH w/ 107 stands. TIE61 P/U 2 singles & kelly. RIH & tag sand ~ 10337'. P/U 5' & set slips. TIEB1 Close in annular & displace 9.8 ppg brine w/ clean seawater by reversing. Pumped 4 BPM C~3 1650 psi. Pumped total of 535 bbls until wt in =wt out ~ 6.4 ppg. TIE61 RIH & to sand C~ 10035. Reverse out sand on to of RBP to 10362'. Reverse out 2 DP volumes until DP clear of sand. TIEB1 Engauge RBP. P/U & insure latched. Put 2 1/2 Rt turns in DP & P/U to 177K. RBP unset. Allow rubbers to relax. Con't to Pull W/ 10-15K over-pull. Put additiuonal 1/2 turn in DP. & P/U. RBP, tool fully unlatched. S/O to below setting depth & insure complete movement. Pull & L/D 1 single. Fluid level remained static. P/U Wt = 160K, S/O Wt = 105K. TIEB1 Circulate bottoms up & insure no gas below RBP. Pump 4 BPM ~ 1220 psi. Pumped total of 445 bbls bbls. No Losses were noted. TIEB1 POOH & L/D 3 1/2" DP. TIEB1 POH L/D 4-3/4" DC's and 7" Halco RBP. Pull wear ring. No fluid losses to well while POH. TIEBi Clear & clean rig floor. RUNCMP Rig up floor and 3-1/2" tubing handling equipment. RUNCMP PJSM :Reviewed 'Running Chrome Tubing" procedure. RUNCMP RIH w/3-1/2" chrome tubing completion per well plan running order and Baker Packer representative. Baker-Lok'd all connections below packer including breaking collar off top of full joint below packer and Baker-Lok'ing it. Torque turned all connections and used Jet Lube Seal Guard thread compound. 34 jts. RIH C~ 1800-hrs. RUNCMP Hold weekly safety meeting, Pre-tour meeting. Review completion running order. Check PVT alarms & inspect derrick. RUNCMP Con't to RIH w/ 3 1/2" 9.2#, Cr-13, Vam Top completion. Torque turn all connections to 2900ft-Ibs. Use Jet Lube Seal Guard thread compound on all connections. RIH w/ 152 jts &Q 24:00 hrs. RUNCMP Con't to RIH w/ 3 1/2" Cr-13, 9.2#, Vam Top Completion. Torque turn all connections to 2900 ft-Ibs. Use Jet Lube Seal Guard Thread compound on all connections. RIH w/ 280 jts C~ 06:00 hrs. RUNCMP Pre-tour HSE meeting. Service rig, check PVT's, derrick Printed: 2/27/2008 2:57:10 PM ` • • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/12/2008 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task i Code ~~ NPT Phase Description of Operations 2/11/2008 06:00 - 06:30 0.50 BUNCO RUNCMP inspection and environmental walkaround. 06:30 - 07:00 0.50 BUNCO RUNCMP Weekly rig HSE meeting with core rig crew members. Reviewed various HSE bulletins, discussed ADW plans for 2008 and general safety and housekeeping discussion. 07:00 - 11:00 4.00 BUNCO RUNCMP Resume RIH w/ 3 1/2" Cr-13, 9.2#, Vam Top Completion. Torque turn all connections to 2900 ft-Ibs. Use Jet Lube Seal Guard Thread compound on all connections. 300 jts. RIH 08:30-hrs. Tag fill C~? 4' in on it. # 332 (10,604'). 11:00 - 17:00 6.00 BUNCO RUNCMP Rig up to circulate well. Circulate C~ 3.0-BPM C~ 250-PSI and wash down to 10,606'. Close annular preventer and reverse circulate ~ 3.0-BPM C~ 480-PSI. Wash jt. #332 down to 10,632. CBU. River sand and several small pieces of aluminum in returns. P/U it. #333 and wash down reverse circulating to 10,663'. Top of stum C~ 10,658'. CBU with 17:00 - 18:00 I 1.00 18:00 - 21:00 ( 3.00 ~ RU 21:00 - 21:30 0.50 RU 21:30 - 22:00 0.50 RU 22:00 - 00:00 I 2.00 2/12/2008 00:00 - 01:30 1.50 eavy returns of river sand and formation sand and several small pieces of rubber. P/U_jt. #334 and wash down to 10,662' ~ here Unique overshot appears to be bottoming out with pump pressure increasing from 550-PSI to +1200-PSI. Did not see s ear screws s ear. riction drag rom pipe sliding through annular preventer element distorts slack off weight. Pick back up and pump pressure decreases to 550-600 PSI. S/D pump and open annular preventer. Verify swallow of stub with Unique O/S. Pump 40-Bbl. hi-vis sweep @ 3.0-BPM ~ 550-PSI. to clean up tubing. RUNCMP Perform acker s aceout. UD Jt #s: 334, 333, & 332. Bury 7.75' pup jt below Jt# 332. M/U hanger, landing jt & circulating head.. RUNCMP Cloae in annular. Reverse circulate 420 bbls of 130 degree seawater down annulus. Pumped 3 BPM ~ 280 psi. . RUNCMP Land com letion. RILDS. R/D circulating head & lines. RUNCMP .Drop Ball/Rod & allow to fall on seat.Back out & UD landing jt. RUNCMP I Pressure up to 3500 psi on tubing & set Baker S-3 packer Hold ressure & test tubing for 30 min. Bleed tubing to 1500 psi & SI. Pressure up on annulus to 3500 psi & Test annulus. Test failed, pressure equalized betwenn Tbg/Ann in _ 4 min. Repeate & attempted to retest annulus, same result, NO Good. Bleed off annulus & then tbg to 0 psi. Report to town engineer. RUNCMP Pressure up tubing to 4500 psi & Hold test for 30 min. Bleed off tubing pressure to 1500 psi & SI. Pressure up on annulus to 3500 si & test for 30 min. Tubing pressure remained flat after annulus was ressured u .Annulus pressure was lat or 10 min & then bled off 80 psi in next 15 min. Chart pressure then oieq ott aoo si on annulus in iu min. i ne gauges on n me ng did not show an decrease in ressure. Possible load cell roblem w/ recorder. Bled off tubing pressure & shear DCR @ 1000 psi. Bled off tbg/ann to 0 psi. Pumped thru DCR both ways & insure clean shear. Notifiy town engineer. 01:30 - 03:30 2.00 BUNCO RUNCMP Dry rod TWC in hanger. Found leak in test hose. Pressure test C from~ielow to 3500 psi for 30 min as per town engineer. Good test. Pressure test TWC from top to 1500 psi for 30 min, good test. Printed: 2/27/2008 2:57:10 PM • • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: C-33 Common Well Name: C-33 Spud Date: 6/13/1993 Event Name: WORKOVER Start: 1/23/2008 End: Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 2/12/2008 Rig Name: NABORS 4ES Rig Number: Date 'From. = To ..Hours I Task Code NPT Phase ~' Description of Operations 2/12/2008 03:30 - 06:00 2.50 BOPSU P RUNCMP Drain BOP stack. Remove choke & kill lines. N/D BOPE. 06:00 - 08:30 2.50 WHSUR P RUNCMP NU adapter flange and Tree. P/T hanger void and Tree to 5000-psi. pad operator verified Tree orientation. 08:30 - 09:30 1.00 WHSUR P RUNCMP P/U lubricator and P/T to 500-PSI. Pu(I TWC. UD lubricator. 09:30 - 10:30 1.00 WHSUR P RUNCMP MIRU LRS. P/T lines to 3500-PSI. PJSM -All crew review high pressure pumping. 10:30 - 12:00 1.50 WHSUR P RUNCMP Pump 150-Bbls. 80F diesel down IA Q 2.0-BPM. 12:00 - 13:00 1.00 WHSUR P RUNCMP Allow diesel to u-tube from IA to tubing for one hour. Verified zero pressure on tubing and IA before setting BPV. 13:00 - 14:00 1.00 WHSUR P RUNCMP FMC wellhead technican dry rod set BPV. LRS P/T BPV to 500-PSI for 5 charted minutes. 14:00 - 18:30 4.50 RIGD P PRE Release riq C~ 14:00-hrs. ,Scope down and lay over derrick. Move pipe shed and pits. Pull sub off well. Move to DS03-11 Printed: 2/27/2008 2:57:10 PM • • C-33A Well History Date Summary 2/13/2008 T/I/O=VAC/0/0. Pulled 4-1/16" CIW "H" BPV. (Post 4-ES). 2/19/2008 WELL S/I ON ARRIVAL, (Post RWO). PULLED B&R FROM RHC BODY AT 10638' SLM PULLED RK-DGLV AT ST#1 (7515'), PULLED RK-DCR AT ST#2 (4469'). SET RK-LGLV AT ST#2 AT (4469') AND RK-OGLV AT ST#1 (7515'). PULLED EMPTY RHC BODY FROM XN NIPPLE AT 10634' MD. 2/20/2008 RIH W/3-1/2" GS TO 10,663' SLM, ATTEMPT TO LATCH JUNK CATCHER. RIH W/2-1/2" x 10' P.BAILER TO 10,663' SLM (-1/2 GAL OF MUD/METAL DEBRIS). 2/21/2008 BAILED MUD/METAL DEBRIS (7 GALS) FROM 10,664' TO 10,681' W/2-1/2" P.BAILER. RIH W/ 3-1/2" GR TO 10,681' SLM, LATCH & BEGIN POOH W/JUNK CATCHER. 2/22/2008 PULLED 3-1/2" JUNK CATCHER FROM 10681' SLM (--1 GAL OF MUD). ATTEMPTED TO PULL HES BB EO.PRONG C~ 10691' SLM..000LDN'T LATCH. BAILED - 1-1/2 GALLONS OF MUD FROM 10692' SLM W/2-1/4" P.BAILER. 2/24/2008 ATTEMPTED TO PULL HES BB EO. PRONG C~ 10,693' SLM..UNABLE TO LATCH. BAILED - 1-1/2 GALLONS OF MUD FROM 10,693' SLM W/ 2.50" P-BAILER. PULLED HES BB EO. PRONG FROM 10,694' SLM, NO PRESSURE CHANGE. ATTEMPT TO PULL 3-1/2" HES BB PLUG FROM 10,699' SLM..UNABLE TO LATCH. RIH W/ 2.475" CENT & 1.25" P-BAILER TO 10699' SLM (--1-1/2 CUPS OF MUD & ICE). 2/25/2008 RIH W/ 2.70" CENT & 1.25" P-BAILER TO 10,702' SLM (-1-1/2 CUPS MUD). RIH W/ 2.50" x 10' P- BAILER TO 10,967' SLM (FLUID ONLY), METAL MARKS ON BAILER. RIH W/ 3-1/2" PK-2 PULLING TOOL, POOH W/ 3-1/2" HES BB PLUG FROM 10,700' MD. RIH W/ 2.0" CENT, 2-7/8" BRUSH, 1.70" GRAB TO 10,717', POOH W/ 1/2 OF LO L RIH W/ 2-1/2" BAILERS TO 10,722'SLM, RECOVERED REST OF ELEMENT & -2 GALS MUD. RDMO. TREE= 4-1/16" CNV WELLHEAD= 13-5/8" FMC SA NOTES: ACTUATOR= BAKER C-33A KB. ELEV...- 67.T ~ '~L BF. ELEV...- 37.5' KOP- 1156' ~ ~ ' 1995' 3-1/2" X NIP, ID 2.813" Max Angle = 95 @ 12654' Datum MD = i 1351' Datum TVDss= 8800'SS 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" 78' 13-3/8" CSG, 68#, BTC, L-80, ID = 12.415" 3609' 9-5/8" x 7" Scab Liner Hanger 4063' TOP OF 7" LNR 10251' 9-5/8" CSG, 47#, NT-80S NSCC, ID = 8.681" ~~ 10429' 3-1/2" TBG, 9.2#, 13Cr-80, VAM TOP, 10$5$' .0087 bpf, ID = 2.992" 10~-70~ 3-1/2" HES BB PLUG (06/21/07) 10803' I-I3-1/2"BKRLTPw/SEALASSY,ID=1.75" 10808' -~ BKR DEPLOY SLV TOP OF 2-3/8" LNR ~ 10808' Minimum ID = 1.75" @ 10830' SEAL ASSEMBLY 3-1/2" TBG, 9.2#, L-80, TDS, 10877' 0087 bpf, ID = 2.992" TOP OF CEMENT( TAGGED 11/16/01) 11142' IBP(12/23/00) 11290' PERFORATION SUMMARY REF LOG: CNL/GR/CCL MEMORY LOG ON 01/28/2001 ANGLE AT TOP PERF: 87 @ 12390' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 12390 - 12680 O 01/28/01 1-11/16" 4 12720 - 12980 O 01/28/01 1-11/16" 6 13010 - 13070 O 01/19/06 1-11/16" 4 13130 - 13320 O 01/28/01 7" LNR, 29#, NT-80 NSCC, .0371 bpf, ID = 6.184" ~ 11 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4469 7515 3700 6200 41 40 MMG MMG DOME SO RK RK 16 20 02/19/08 02/19/08 10251' ~ 9-5/8" X 7" BKR LNR HGR, 10258' 9-5/8" X 7" BKR LTP, ID= 6.280" 10263' 7" BKR HMC LNR HGR , ID 6.30" 10538° 3-1/2" X Nipple, ID 2.813" 10559' 7" x 3-1/2" Baker S3 Packer 105$4° 3-1/2" X Nipple, ID 2.813" ~...._ 10634' 3-1/2" XN- nipple, ID 2.75" 1065$' 3-1/2" Unique overshot 10818' ~~ 3-112" HES X NIP, ID = 2.75" 10828' 3-1/2" x 4-1/2" XO, ID = 2.937" 10830' 7" X 4-1/2" BKR S-3 PKR, ID = 3.920" 10834' 4-1/2" x 3-1/2" XO, ID=2.937 BEHIND PIPE 10855' 3-1/2" HES X NIP, ID - 2.75" 10866' 3-1/2" HES X NIP, ID = 2.75" 10878' 3-1/2" WLEG, ID = 2.990" 10874' TTL ELMD -LOGGED 10/18/95 MILLOUT WINDOW (C-33A) 11250' - 11256' !PJIII~II'ii a i'' IdpiHll~, 'ili ~I I~ ~I i Iltl h~ii ~, ilil II i p ~~~. ~~0~~4,1~11u1~'':,,,, 13320 PBTD ' ~:, IIh'i ~ ,y ~, d II'` ' III~'l~~ III",,i,~': ~~„a V' I~Iri, ', ~ 2-3/8" LNR, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.992" 133 DATE REV BY COMMENTS DATE REV BY COMMENTS 07/09/93 FARGO ORIGINAL COMPLETION 02/16/08 /TLH CORRECTIONS 10/10/95 D16 RWO 02/19/08 CJN/TLH GLV GO 02/01/01 CDR-1 CTD (C-33A) 02!02/07 O0B/PJC CTD (02/01/01 )CORRECTIONS 07/27/07 SPF/SV BB PLUG SET (06/21/07) 02/12/08 N4ES RWO PRUDHOE BAY UNIT WELL: G33A PERMIT No: 2002020 API No: 50-02922373-00 SEC 19, T11 N, R14E BP Exploration (Alaska) • ~ ~ ~ ~~ ~~ ~ ~ ~~~ ~~~ ~,t ~ ~ SARAH PAL1N, GOVERNOR ALASKA OIL nusu G~-S 333 W. 7th AVENUE, SUITE 100 CO1~T5ER'QA~`IO1~T COMMISSIOIIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc PO Box 196612 ~1~,~~'~~ ~~C ~ .~ Z0~7 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-33A Sundry Number: 307-379 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of December, 2007 Encl. ~~ ~ ~ ~ Sincerely, r .~_~ ~°` ~ ~ ~~~'i/ ~ 12-I l~o STATE OF ALASKA / ~~ ALASKA OIL AND GAS CONSERVATION COMM SION ~~- • ~~~ 1 ZOO1 APPLICATION FOR SUNDRY APPROVAI~~~~v~SEI ~ ~~ ~ ,,, r::~zi~1li~s31a~ 20 AAC 25.280 1. T e of Re uest: " `~ ~``"'~ ~" YP q ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-202 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22373-01-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-33A- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): - ADL 028304' 67.7'. Prudhoe Bay Field / Prudhoe Bay Pool 12- PRESENT WELL CONDITION SUM MARY Total Depth MD (ft}: Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured}: Junk (measured): 13372 ~ 8917 13320 8913 10700 None sin. Len th Size MD TV Burst Colla se Structural nductor 11 20" 110' 11 1490 47 Surface 3609' 13-3/8" 3609' 3191' 4930 2270 Intermediate 10429' 9-5/8" 10429' 8392' 6870 4760 Producti n Liner 999' 7" 10251' - 11250' 8253' - 8858' 8160 7020 Liner 2553' 2-3/8" 10804' - 13372' 8654' - 8917' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12390' - 13320' 8886' - 8913' 3-1/2", 9.2# L-80 10878' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 10830' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 21, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Nam _ avid Re Title Engineering Team Leader Prepared By NamelNumber: Signature Phone 564-5743 Date /Z j~ ~.~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~ _ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~ `~ p y \ ~`~ ~~ ~~ ;~~ ~~.,, I.~C ~ ~~ 2007 Subsequent Form Required: ~~A1 APPROVED BY / ~ ~i ~~ 7 A roved B C IONER THE COMMISSION Date ` Form 10-403 Revised 06/2006 ~./ l5!/ Submit In buplicate ORIGINAL • by GP ~ • C-33A Rig Workover ,~ ~ r Scope of Work: Cut & Pull 3-1/2" L-80 completion, run 7" retrievable plug, run premium threaded 2' scab liner to 4000' MD and cement, changeout 9-5/8" packoffs, run 3'/2" Chrome completion. MASP: 2385 psi Well Type: Producer Estimated Start Date P_re-ri~prep_work: January 21, 2008 O 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. S 2 Cali er 4-1/2 tubin to BB plu set at 10700' S 3 Set ~unk catcher on to of BB lu E 4 Chemical cut @ 10660', -10' below collar of 1S full joint above the BB plug. Use a Chem cutter to minimize debris in and around the 2-3/8" CT liner Ref: 10/10/95 tubin summar F 5 Circulate/bullhead 9.8 KWF thru the cut. Load OA w/ 9.8# brine and diesel cap. Bleed WHP's to 0 si. O 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow fine. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 4es. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid with kill weight brine through the cut. 2. Pull and LD 3-1/2" tubing string, 3. Run and seta 7" RBP at 10300'. 4. Run and fully cement a 7" scab liner with Baker liner top packer set at -4000' MD. 5. Test well to 3500 psi. Replace the 9-5/8" casing packoffs. 6. Drill out landing collar and cleanout to the RBP. 7. Pull RBP. 8. Run new 3-1/2" Chrome tubing completion with packer at -10610' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test IA to 3500 psi. Freeze protect to 2200' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. ~~~ t~ ~~~ TREE= 4-1/16" CIW WELLHEAD= 13-5/8" FMC ACTUATOR= BAKfft KB. ELEV = 67.T BF. ELEV = 37.5' KOP = 1156' Max Angle = 95 (~ 12654' Datum MD = 11351' DatumNDss= 8800' SS CONDUCTOR, 91.5#, H-40, D = 19.124" ~-~ 71 13-3/8" CSG, 68#, BTC, L-80, D = 12.415" 3 TOP OF 7" LNR -~ 1 19-5/8" CSG, 47#, NT-80S NSCC, D = 8.681" I-i 10429' Minimum ID = 1.75" ~ 10830' SEAL ASSEMBLY TOP OF 2-3/8" LNR 10808' 3-1/2" TBG, 9.2#, L-80, TDS, .0087 bpf, D = 2.992" TOP OF CI3MQJT( TAGGED 11 /16/01) IBP (12/23/001 PERFORATDN SUMMARY REF LOG: CNUGR/CCL M3MORY LOG ON 01 !28/2001 A NGLE AT TOP PERF: 87 ~ 12390' Note: Refer to Production DB for historical perf data SIZE SPF IJTEE2VAL Opn/Sqz DATE 1-11/16" 4 12390 - 12680 O 01/28!01 1-11/16" 4 12720 - 12980 O 01/28/01 1-11!16" 6 13010 - 13070 O 01/19/06 1-11/16" 4 13130 - 13320 O 01/28!01 7" LNR, 29#, NT-80 NSCC, .0371 bpf, D = 6.184" C-33A • 13-1/2" HES SSSV N~, D = 2.750" I GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 4992 8388 4258 6865 41 40 MMG MMG DMY DMY RK RK 0 0 06/06/07 06/06/07 10251' H 9-5/8" X 7" BKR LNR HGR, 10258' 9-5/8" X 7" BKR LTP, D= 6.280" 10263' 7" BKR HMC LNR HGR , D 6.30" 13-1/2" HES BB PLUG (06/21/07) I 11142' 10803' I-j3-1/2"BKRLTPw/SEALASSY,ID=1.75" 1080$' BKR DEPLOY SLV 10818' -{3-1/2" HES X NIP, D = 2.75" 10828' 3-1/2" x 4-1/2" XO, D= 2.937" 10830' 7" X 4-1/2" BKR S-3 PKR, D = 3.920" 10834' 4-1/2" x 3-1/2" XO, D = 2.937" BEHIND PIPE 10855' 3-1/2" HES X N~, ID - 2.75" 10$66' 3-1/2" HES X NIP, D = 2.75" 10878' 3-1/2" WLEG, D= 2.990" 10874' TTL ELMD -LOGGED 10/18/95 MLLOUT WNJDOW (C-33A) 11250' - 11256' PBTD I-i 13320' 4.6#, L-80 FL4S, .0039 bpf, D = 1.992" ~-1 13372• DATE REV BY COMMENTS DATE REV BY COMMENTS PRIDHOE BAY UNR 07/09193 FARGO OI~GINAL COMPLtT1ON 04107/07 OOB/PJC GLV CORRECTIONS WELL: G33A 10/10/95 D16 RWO 06/06/07 CJNIPAG GLV GO PERMT No: e2002020 02/01/01 CDR-1 CTD (C-33A) 06/26/07 008/PJC DEPfH CORRECTIONS API No: 50-02922373-00 11101/Ot WB/TP SURF LOC CORRECTDN 07/27/07 SPF/SV BB PLUG SET (06/21/07) SEC 19, T11N, R14E 01/19/06 KEY/PAG PERFS 02/02/07 OO6/PJC CTD (02/01/01)CORRECTIONS BP Expkuatan (Alaska) TR1=E= 4-1/16" CMI WELLHEAD= 13-5/8" FMC ACTUATOR= BAKER KB. ELEV = 67.7' BF. ELEV = 37.5' KOP = 1156' Max Angle = 95 C~ 12654' Datum MD = 11351' Datum TVDss= 8800'SS I20" CONDUCTOR, 91.5#, H-40, ID = 19.124" ~- 13-3/8" CSG, 68#, BTC, L-80, ID = 12.415" - 9-~'3" -" scab Liner Hanger 78' 3609' I TOP OF 7" LNR 19-5/8" CSG, 47#, NT-80S NSCC, ID = 8.681" I~ 10429' -1/2" TBG, 9.2#. 13Cr-80 ~~AM Tl)P I .0087 bpf. ID = 2.992" TOP OF 2-3/8" LNR --~ Minimum ID = 1.75" @ 10830' SEAL ASSEMBLY 3-1/2" TBG, 9.2#, L-80, TDS, 10877' .0087 bpf, ID = 2.992" TOP OF CEMENT( TAGGED 11/16!01) 11142' IBP(12/23l00) 11290' PERFORATION SUMMARY REF LOG: CNUGR/CCL MEMORY LOG ON 01 /28/2001 ANGLE AT TOP PERF: 87 (d1 12390' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 12390 - 12680 O 01/28/01 1-11/16" 4 12720-12980 O 01/28101 1-11/16" 6 13010 - 13070 O 01/19/06 1-11/16" 4 13130 - 13320 O 01/28/01 7" LNR, 29#, NT-80 NSCC, .0371 bpf, ID = 6.184" ~ 11770' DATE REV BY COMMENTS DATE REV BY COMM 07/09!93 FARGO ORIGINAL COMPLETION 04/07/07 OOB/PJC GLV CORRECTIO 10/10195 D16 RWO 06/06/07 CJN/PAG GLV C!O 02/01/01 CDR-1 CTD (C-33A) 06/26/07 006/PJC DEPTH CORRECTI 11/01/01 WB/TP SURF LOC CORRECTION 07/27/07 SPF/SV BB PLUG SET (06 01/19/06 KEY/PAG PERFS 02/02/07 OOB/PJC CTD (02/01/01)CORRECTIONS SA 2167' I~ 3-1 /2" X NIP GAS LIFT MANDREL S ST MD TVD DEV TYPE VLV LATCH PORT DATE •, ~, ~. -,r, ,,; 10251' I~ 9-5/8" X 7" BKR LNR HGR, 10258' ~9-5/8" X 7" BKR LTP, ID= 6.280" I 10263' 7" BKR HMC LNR HGR , ID 6.30" 10600' 3-1 i2" X Nipple 10610' 7" x 3-112" Baker S3 Packer 10650' 3-112" X- nipple 10660' 3- t i2" Unique overshot 10803' 3-1/2" BKR LTPw / SEAL ASSY, ID = 1.75" I 10808' I 10818' 113-1 /2" HES X NIP, ID = 2.75" 10828' 3-1 /2" x 4-1 /2" XO, ID = 2.937" 10830' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.920" 10834' a-v2" x 3-1/z^ xo, ID = 2.937" BEHIND PIPE 10855' 3-1/2" HES X NIP, ID- 2.75" 10866' 3-1 /2" HES X NIP, ID = 2.75" 10878' 3-1/2" WLEG, ID=2.990" 10874' TTL ELMD -LOGGED 10/18!95 L MILLOUT WINDOW (C-33A) 11250' - 11256' I 2-3/8" LNR, 4.6#, L-80 FL4S, .0039 bpf, ID = 1.992" ENTS PRUDHOE BAY UNfT NS WELL: C-33A PERMrT No: 2002020 ONS API No: 50-02922373-00 /21/07) SEC 19, T11N, R14E BP Exploration (Alaska) C-33A Proposed Completion · STATE OF ALASKA ) ALA~ ,} OIL AND GAS CONSERVATION COMrvl. _ ~ION REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 200-2020 6. API Number: 50-029-22373-01-00 9. Well Name and Number: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 'ß?! Stratigraphic D Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 67.7 KB C-33A 8. Property Designation: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool ADL-028304 11. Present Well Condition Summary: RECEIVED None None FFB 2 7 2006 Alaska 0;1 & Gas Cons Com . . · m'SSIon Anchorage Collapse 470 2270 4760 7020 11780 Total Depth feet, (j' PI~S (measured) fee,t . . ...'^.. .. C, 'Ç n ?1 lj :¿\j~k (measured) ~~Et) (¡,.IJ ~ feet measured 13372 true vertical 8916.77 Effective Depth measured 13335 true vertical 8914.32 Casing Conductor Surface Production Liner Liner Length 80 3576 10395 1000 2524 Size 20" 91.5# H-40 13-3/8" 68# L-80 9-5/8" 47# NT80S 7" 29# NT -80 2-3/8" 4.6# L-80 MD 34 - 114 33 - 3609 32 - 10427 10250 - 11250 10833 - 13357 TVD 34 - 114 33 - 3190.79 32 - 8390.7 8251.9 - 8857.97 8670.93 - 8915.78 Burst 1490 4930 6870 8160 11200 Perforation depth: Measured depth: 12390 - 12680 True Vertical depth: 8886.04 - 8892.81 12720 - 12980 8893.81 - 8899.98 13010 - 13070 8897.82 - 8894.91 13130 - 13320 8898.88 - 8913.32 Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 31 - 10878 Packers and SSSV (type and measured depth) 7" Liner Top Packer 3-1/2" Baker S-3 Packer 10258 10830 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl FEB 2 8 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 15357 10 0 19918 9 0 15. Well Class after Droposed work: Exploratoryr Development;;¡ 16. Well Status after proposed work: Oil P' Gas r WAG r Oil-Bbl 362 294 Tubing pressure 746 839 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations r Service x WDSPL r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal k Printed Name Sharmaine Vestal Title Data Mgmt Engr Signatu Phone 564-4424 Date 2/24/2006 Form 10-404 Revised 04/2004 Submit Original Only ) ') C-33A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/19/2006 CTU # 9 w/1.5" CT. *** Continue from 1-18-06 WSR *** Knock WHP down with 88 bbls 1 % KCL and cap w/20 bbls 60/40 meth. RIH with PDS logging tools. Make tie in pass from 13200' - 12750' ctmd at 40 fpm. Flag pipe @ 12975' ctmd. POOH. Surface. Confirm PDS data. Tie in to SLB MCNL 1/28/01. Add 6" for correction. Make up Gun # 1 - 1.56" OD 6 spf x 30' gun and RIH to flag and correct to top shot. RIH and perforate from 13040' to 13070'. POOH. All shots fired. MU Gun # 2 - 1.56" aD 6 spf x 30' gun and RI H to flag and correct to top shot. Perforate from 13010' - 13040'. Good indication of guns firing. POOH. Freeze protect tubing with 22 bbls of 60/40 methanol and hang tag on tree. Surface. *** Continue on 1-20-06 WSR *** 1/20/2006 CTU # 9. *** Continue from 1-19-06 WSR *** Surface. All shots fired from Gun # 2. Recover ball. RD. Notified pad operator of well status and release all equipment. Well might need a poorboy jumper to kickoff. *** Job Completed *** FLUIDS PUMPED BBLS 149 60/40 Meth 105 1% KCL 254 TOTAL 'if~u". 'IIo~."'-:-""" "" " '. ": -' ~.~ ?>~ " - , MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2002020 MD 13357~'''' TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT C-33A Operator BP EXPLORATION (ALASKA) INC 8916 -? Completion Dat 2/1/2001 ? Completion Statu l-OIL Current Status l-OIL APl No. 50-029-22373-01-00 UIC N REQUIRED INFORMATION Mud Log N_Q Sample N._~o Directional Survey ~ \/,~.~, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments Directional Survey Directional Survey Directional Survey Directional Survey ~off~'~nsated Neutron Log CNL/GR ~...10066 ~..J~-'VD GR Lis Verification FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL FINAL Ct0697 CI'0697 (-1-1250 10697 1O697 10697 11250 11250 13317 13317 13372 13317 13317 13317 13372 13372 Case 6/22/2001 10156~'10697-13317 Case 5/29/2001 10066 ~-~f0697-13317 Open 8/30/2001 10249u~ 1250-13372 ch 3/7/2001 Directional Survey Digital Data ch 3/712001 Directional Survey Paper Copy 4/5/2001 Directional Survey Paper Copy 4/5/2001 Directional Survey Digital Data ch 6/1/2001 10697-13317 BL, Sepia ch 6/1/2001 ~0066 CH 6/22/2001 ~1'~6 oh 8/27/2001 oh 8/27/2001 ch 8/2712001 ~49 oh 8/27/2001 10697-13317 Digital Data 10697-13317, Digital Data 11250-13372 BL, Sepia 11250-13372 BL, Sepia LIS Verification Digital Data Lis Verification, ff-/b/~ (-/~____. Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION DATA SUBMITTAL COMPLIANCE REPORT 41112003 Permit to Drill 2002020 Well Name/No. PRUDHOE BAY UNIT C-33A Operator BP EXPLORATION (ALASKA) INC MD 13357 TVD 8916 Well Cored? Y/~ Chips Received? ~ Analysis ~ Received? Completion Dat 2/1/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~}1 N Formation Tops ~)/N APl No. 50-029-22373-01-00 UIC N Comments: Compliance Reviewed By: Date: Transmittal Form HUGHES: Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Pmdhoe Bay North Slope, Alaska C-33A 1 LAS Format disk'~.~....:~"i:.:::i:..':.::'i:~ 1 Film 1 Measured Depth 1 TVD-GR print ................................................ :2': ............. :~:'i~.:.~!i!ii~::!i!.'.~i'. ....... Sent ~. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Date: Aug 23, 2001 Date: <~/c~'?/?~ / Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 , i'~_ --- i-- -:'- i -.- ! ~- ~!: Y-:}-~ '7 ' 9--" ..... _: -- - n ..... ...... . ~_ _ , -~ ,, _.._ ..... - ~_ ........ ~: ...... 7_.. _2 .: ........... ~i~ .... 2_-:_-2__ .£__12_', .'- :.__ - ......... _ ; .- _. . _--._ :.-y: ............. :_.f ~1 a_ ~ _ _--_ £,' ~.. ............ _~-__.- _.-~ ............. : ..... ............. --.-% ..... :-:-- - i -- - --- ..... ~- : .iX_,, .-~ ..... ~- ....... _ 06/19/01 Schlmberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. t23t Company: S~ate of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field:' Prudhoe'Bay Color Well Job # Log Description - Date Blueline Sepia.. Prints CD ~),22A ~¢~'~_ 20~ 21287 SCMT 05123101 p.S. 1t-35 ~rq. 0~T,,~ 21286 SCMT 06122/01 [;;-23A ~.-~]o I~f'~ 21279 MCNL 05127101 I . - I 1 'D.S. 2-03B '~,{l~" ~--t"~ 21278 MCNL 06130101 1. I 1 0-33A ~_OD --.'}.D~. 21068 MCNL (REDO) 01128/01 '1 *REDO - Changed depth shift edits - remove below KOP of A well. .. -. -. . . . .- , -_ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petmtectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SchlUmberger GeoQuest 3940 Arctic Blvd' Suite 300 RECEIVED _ Anchorage, AK 99503-5711 ATTN: Sherrie ' · -' JUN 2'2 2001 · . . · ~.. Re~v~ STATE OF ALASKA C[ ALASK ,.~IL AND GAS CONSERVATION ,JMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other CTD-Prep, Ann-Comm 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 697' FNL, 1221' FEL, Sec 19, T11N, R14E, UM At top of productive interval 659' FNL, 2052' FEL, Sec 17, T11N, R14E, UM At effective depth (n/a) At total depth 141' FSL, 2594' FWL, Sec 08, T1..1N, R14E, UM 5. Type of well:. . IX] Development [] Exploratory [] Stratigraphic [] Service (asp's 664141, 5960514) (asp's 668453, 5965931) (asp's 667800, 5966718) 6. Datum Elevation (DF or KB) KBE = 67.70 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C-33A 9. Permit Number / Approval No. 200-202 10. APl Number 50- 029-22373-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 13357' BKB 8916' 13320' BKB 8913' Length Structural Conductor 110' Surface 3578' Intermediate 10398' Production Liner 999' Sidetrack Liner 2553' feet feet feet feet Plugs (measured) Junk (measured) KOP @ 11250' - 11256'. 7" abandoned from 11250' to 11770.' Size Cemented 20" x 30" 280 c.f. AS 13-3/8" 2207 c.f. PFE & 487 c.f. Class 'G' 9-5/8" 1657 c.f. Class 'G' 7" 370 c.f. Class 'G' 2-3/8" 18.5 c.f. Class 'G' MD TVD BKB 141' 141' 3609' 3609' 10429' 8392' 10251'-11250' 8253'-8858' 10804'-13357' 8654'-8916' ., Perforation depth: measured true vertical Open Perfs 12390'-12680', 12720'-12980', 13130'-13320' Open Perfs 8886'-8893', 8894'-8900', 8899'-8913' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 tubing to 10830' with 3-1/2" tailpipe to 10878'. Packers and SSSV (type and measured depth) 9-5/8" Baker Liner Top Packer @ 10258'; 7" Baker S-3 Packer @ 10830'. 3-1/2" HES SSSVLN @ 2167'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure RECEIVED dON 05 2001 Alaska 0il & Gas Cons. Commission Anchorage 14. Pdor to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing 'Pressure 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed scott LaVo,e~,~~'~ ~--~'~ Title Technical Assistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 0 i'~ I [~ i t";~'~l P~ L. Date ~/.~"/~/ DeWayne~chnor['56~-5174 Submit In Duplica[~ C-33A (" DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/31/2001 02/09/2001 02/10/2001 04/10/2001 CTD-PREP WORK: RIG JOB ( FISH PKR ASS. FROM SVLN) CTD-PREP WORK: SET GENERIC GLVS (POST CTD) -IN PROGRESS CTD-PREP WORK: SET GENERIC GLV'S (POST CTD ANN-COMM: IA ICE PLUG SUMMARY 01/31/2001 FISHED PKR ASS. FROM SVLN, BRUSHED NIPPLE, DRIFTED THROUGH NIPPLE W/2.72" 7' DRIFT, WORKED DRIFT UP & DOWN THROUGH NIPPLE, STOOD-BY WHILE RIG RERAN PKR ASS. THROUGH SVLN. 02/09/01 ASSIST DSM IN PULLING BPV. SET 3 1/2" CATCHER ON LINER TOP @ 10798' WLM. PULL 1 1/2" DGLV & RK FROM STA #1 @ 8385' WLM. PULL 1 1/2" DGLV & RK FROM STA #2 @ 4982' WLM. LDFN. LEFT WELL SHUT IN & TAGGED. NOTIFIED OPERATOR OF STATUS. 02/10/01 SET 1 1/2" GENERIC LGLV & RK (1500# TRO- 1/4" PORT) IN STA #2 @ 4982' WLM. SET 1 1/2" OGLV & RK (5/16" PORT) IN STA #1 @ 8385' WLM. PULLED 3 1/2" CATCHER FROM TOP OF LINER @ 10798' WLM. RDMO. LEFT WELL SHUT IN. NOTIFIED OPERATOR OF STATUS. 04/10/01 PUMP NEAT DOWN IA PUMP HOT DIESEL DOWN TUBING .... Fluids Pumped BBLS. Description 102 DIESEL 15 NEAT 117 TOTAL Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1164. Company: Stats of Alaska Alaska Oil & Gas COns Comm Attn: Lisa Weepie 333 West 7th Ave, Suits 100 Anchorage, AK 99501 Field: Prudhoe Bay 05129101 Well Job # Log DescriptiOn Date Bluelins CD Color 'Sepia- Prints D.S. 2-14/'~O O/.~~' 21233 RST 04m'/'101 t I 1 D.S. 4-01 / "70"(~./~ 21134 CNTG 03104/01 I t 1' D.S. 16-38 1~4"/0%/ 99050 MCNL 09119/08 I .1 1 e-04 )"l[~)r- O ?~ 21230 CNTO 04/20/01 t' t 1 C-33A ~. ~,.-,~ 0o~ 21058 MCNL 0t/28/0t t t t D-28ALt ~,~?~O,_,.~ 21236 RST .. 05/02/01 E-0?A 21164 MCNL 0.3121/0t t I I '. F-O3A _~1- ~,~ 21234 MCNL 04/26/0t I I t F-45 ~' ~l,.-~,.,~c.~ ~' 21235 RST 05/02/01 I 1'' 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petmtectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508' Date Delivered: RECEIVED JUN 0 1 2001 AJadm 0il & Gm Cons..Comauion Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503~5711 ATTN: Sherrie - Receiv~ STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ['~ Gas O Suspended D Abandoned O Service D 2. Name of Operator ~T 7. Permit Number BP Exploration (Alaska), Inc."",'-,~,,,,.,,r~otVl~mFF~ i 200-202 3. Address _~;.-~;~ ! 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612; ~ '~Jf-.~-.~-'~ :~. ,,r~...,.,.._~ ~ 50-029-22373-01 4. Location of well at surface ~ ,.......2~.~_.....~,,~,~.,...~,~ 9. Unit or Lease Name 697' FNL, 1221' FEL, Sec. 19, T11N, R14E, UM (asp's 664141, 5960514) ...'-.: .. Prudhoe Bay Unit At Top Producing Interval v ', '.' .10. Well Number 659' FNL, 2052' FEL, SEC 17, T11 N, R14E, UM (asp's 668453, 5965931) ..~Z,,.'../':~ /~, C-33A At Total Depth ; ;;.'i....' ' 11. Field and Pool 141' FSL, 2594' FWL, SEC 8, T11N, R14E, UM (asp's 667800, 5966718) i,. ..... ,-~... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 67.7 feetI ADL 28304 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions January 18, 2001 January 26, 2001 February 1, 2001 I N/A feet MSL 1 ! 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost 13357' MD/8916' TVD 13320' MD/8913' TVD YES r~ No D'1 2167' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR & Mem GR/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE v~rr. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 280 cuft AS 13-3/8" 68# L-80 Surface 3609' 16" 2207 cuft PFE & 487 cuft Class G 9-5/8" 47# NT-80S Surface 10429' 12-1/4" 1657 cuft Class G 7" 29# NT-80 10251' 11250' 8-1/2" 370 cuft Class G 2-3/8" 4.6# L-80 10804' 13357' 3" 18.5 bbls Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (all shots w/1-11/16" carriers) 3-1/2" 10878' 10258' 12390' - 12680' MD; 8886' - 8893' TVD; @ 4 SPF Zone lA 10830' 12720' - 12980' MD;~ 8894' - 8900' TVD; @ 4 SPF Zone lA 10804' 13130' - 13320' MD; 8899' - 8913' TVD; @ 4 SPF Zone lA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 12, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 2/14/2001 4.0 Test Period >I 1346 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -286 psi 24-Hour Rate > 1364 1836 33 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or wafer. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved December 21,2000 (Permit ~Y200-202) RECEIVED Form 10-407 Rev. 7-1-80 Submit in duplicate Alaska 0il & Gas Cons. Commissior,~ Anchorage · GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Sag River Sand 10377' 8351' Top of Shublik 10423' 8387' Top of Sadlerochit 10514' 8459' Top of Zone 1B 11492' 8871' Top of Zone 1A 11253' 8884' .31. LIST OF A'FrACHMENTS Summary of C-33A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Sig~e~ ~''~ M~*"'~ Title Co,ITubin~Drlllln,qEn,qlneer Date ~~~/ Larnar Gantt ~ Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ORIGINAL Form 10-407 RECEIVED MAR 0 9 Z001 Alaska 0il & Gas Cons. Commission Anchorage (" (' RI:::'CEiVED BP EXPLORATION MAR 0 9 ~1~§~ 1 of 9 Operations Summary Report Alaska Oil & Gas Cons. Commission Anc. hnr~P. Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: ;Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDP,-1 Rig Number: 1 Date From-To Hours Task Sub Code Phase Description of Operations 1/13/2001 00:00 - 10:00 10.00 MOB PRE RD CTD equipment. Prepare for move. Move sub from 04-41A. Clean location. 10:00 - 14:00 4.00 MOB PRE Move rig equipment from DS #4 to C-pad and spot rig loads. 14:00 - 18:00 4.00 MOB PRE Spot rig loads. 18:00 - 00:00 6.00 MOB PRE Rig up equipment. 1/14/2001 00:00 - 13:00 13.00 MOB PRE Rig accepted 01/14/2001 at 10:00 hrs. (Koomey control modifications on 4-41a). Set pit liner and return tanks. 13:00 - 19:00 6.00 MOB PRE Nipple up of BOP. Remove kill line check, install HCR. Function test all rams. Set pit liner and upright tanks. 19:00 - 00:00 5.00 MOB WTHR PRE Wait on methanol & hardline manifold due to weather conditions. 1/15/2001 00:00 - 03:00 3.00 RIGU WTHR PRE Road access poor. Wait for arrival of hose manifold and meth/wtr. 03:00 - 09:00 6.00 RIGU TEST PRE Repair leaks associated w/new stack configuration being cooled and heated w/rig move. 09:00 - 18:00 9.00 RIGU PRE Test BOP equipment. Test witness waived by AOGCC inspector John Crisp. 18:00 - 19:00 1.00 RIGU PRE PJU DSM lubricator. Pull BPV. R/D DSM lubricator. Meanwhile carried out ASA - satisfactory performance. 19:00 - 19:30 0.50 STMILL WEXIT Held pre-spud and pre-job safety meetings with night crew. 19:30 - 21:30 2.00 STMILL WEXIT Service injector. 21:30 - 22:30 1.00 STMILL WEXIT Displace CT to KCL. Rack back and circulate coil. 22:30 - 00:00 1.50 STMILL WEXIT P/U & M/U BHA # 1.2-3/8" motor w/1.75 ABH, D-331 & GR. OAL = 106.91'. Surface test orientor - OK. 1/16/2001 00:00 - 00:15 0.25 STMILL WEXIT Complete M/U of BHA#1 00:15 - 01:00 0.75 STMILL WEXIT Run in hole w/BHA #1, OAL--- 106.91'. Shallow hole test is good. 01:00 - 02:00 1.00 STMILL WEXIT Repair broken hydraulic hose on coil reel. 02:00 - 04:00 2.00 STMILL WEXIT Continue RIH. 04:00 - 05:50 1.83 STMILL WEXIT Log Gl:{ tie-in, (-32' correction) to 11,000'. 05:50 - 06:30 0.67 STMILL WEXIT Orient to Iow side, 160R, RIH milling @ 60 fph. 06:30 - 06:50 0.33 STMILL WEXIT Hold Pre-spud for day crew. Safety first! 06:50 - 07:30 0.67 STMILL WEXIT See cement top at 11~.~.. Encounter hard cement @ 11157'. Make 11164', pick up for orientation. Bit-stuck. 07:30 - 08:15 0.75 STMILL JUNK WEXIT Dump coil pressure, pull 45k# and come free. Establish full returns. 08:15 - 09:00 0.75 STMILL WEXIT Resume milling operations. 09:00 - 09:30 0.50: STMILL WEXIT Orient TF to 170R. Pump 10 bbl pill of 1-1/2# Biozan. 09:30 - 11:00 1.50' STMILL WEXIT Mill cement at @ 30-40fph, 1.6 bpm, 3300~3600 ctp, 17k# string weight, 37k# up weight. Pump 10 bbl biozan pill. 11:00 - 12:00 1.00 STMILL WEXIT Stop at 11242'. Allow BHA to drill off. 12:00 - 12:20 0.33 STMILL WEXI~ Orient TF to high side. 12:20- 12:40 0.33 STMILL WEXIT ~ .Mill rampto casing. 11242'to 11248'. See TF torque when hitting casing. 12:40 - 13:00 0.33 STMILL WEXIT Pull up hole to tie in with gamma Ray. 13:00 - 14:15 1.25 STMILL WEXIT Log GR tie-in (+2'). Paint EOP flag. Dry tag, confirm btm & add 2' to ramp. 14:15 - 17:30 3.25 STMILL WEXIT POOH BHA#1. 17:30 - 19:30 2.00 STMILL WEXIT Lay down BHA #1. M/U BHA #2, 2.5 deg. fixed bend w/2.4" one-step window mill. OAL~106.65' 19:30 - 22:00 2.50 STMILL WEXIT Run in hole w/BHA #2'. Shallow hole test - OK. RIH to EOP flag (-22ft correction). 22:00 - 00:00 2.00 STMILL FILL WEXIT Orient to pass TOC (@11142') into pilot hole. No success. 1/17/2001 00:00 - 01:30 1.50 STMILL FILL WEXIT Attempted to pass 11142' with various T.F. No success. 01:30 - 04:00 2.50 STMILL FILL WEXIT POOH BHA #2. Paint EOP flag @ 10700'. 04:00 - 05:00 1.00 STMILL FILL WEXIT Lay down BHA #2. P/U BHA #3, 2-3/8" motor wi 1.75 ABH, D-331 & GR. OAL~106.91'. Surface test orientor - OK. Printed: 2/26/2001 3:07:36 PM -Ui-i Vt'L7 BP EXPLORATION Page 2 of 9 UAR 0 9 Operations Summar Report Alaska Oil & Gas Con,. Commi.~.~i~n Legal Well Name: C-33 Anchorage Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Date From - To Hours Task Sub Phase Description of Operations Code 1/17/2001 05:00 - 07:15 2.25 STMILL FILL WEXlT Run in hole w/BHA #3. Shallow hole test - OK. Correct to EOP flag (-36') 07:15 - 10:45 3.50 STMILL FILL WEXlT Attempt to engage pilot hole at minimum pump rate w/o success. Bring pump up to rate of 1.6 bpm, TF @ 30R. Set down 11134'. Get one click and enter pilot hole w/TF of 70R. RIH 2 800 fph. to 11240'. Get two clicks. Back ream pilot hole entrance around the Tool Face Clock. Drift with high side TF at 1/2 bpm, 1/4 bpm and with no pumps. Entrance and pilot hole clean. 10:45 - 12:00 1.25 STMILL FILL WEXlT PUH and log GR tie in. (+4') Pump Biozan pill. 12:00 - 12:45 0.75 STMILL FILL WEXlT Drop 5/8" ball to circulate out 7" liner. Ball on seat @ 34Bbls away. Circulate 7"w/Biozan pill at 2.5 bpm. Flag EOP. 12:45- 15:40 2.92 STMILL FILL WEXlT '~ POH forwindow mill. 15:40 - 17:00 1.33 STMILL FILL WEXlT Lay down BHA #3. P/U BHA 84 (window mill) 17:00 - 20:00 3.00 STMILL FILL WEXlT Run in hole w/BHA #4, OAL 106.65'. Shallow hole test good. Correct to EOP flag (-22') 20:00 - 20:45 0.75 STMILL FILL WEXlT Tag 11250'. Orient TF to high side. 20:45 - 00:00 3.25 STMILL WEXlT Pick up 1' slack and begin time milling sequence. 1.7 bpm, 3300 ctp, 20k# string wt. 20L tool face. 1/18/2001 00:00 - 06:30 6.50 STMILL FILL WEXlT Follow time-milling schedule. Not seeing motor work. Lock brake. No drill off. Pick up, no drop in circ. pressure. 06:30- 09:30 3.00 STMILL FILL WEXIT POH to inspect BHA. 09:30 - 10:00 0.50 STMILL FILL WEXlT L/D BHA #4. No problem w/motor. Side of mill worn. Mill gages 2.72" O.D. 10:00 - 11:15 1.25 STMILL BARR WEXlT Install new seleoid to remotely operate new kill line HCR with Cyber controls. Test system. 11:15 - 12:15 1.00 STMILL FILL WEXlT M/U BHA #5.' Newwindow mill and 2.5 deg motor. 12:15-14:45 2.50 STMILL FILL WEXlT RIHw/BHA#5. OAL=106.65'. Shallow hole test ok. - ~Tag bottom @ 11253'. P/U and check orientation. TF 30L. RIH and 14:45 15:55 1.17 STMILL WEXIT J resume milling. Stack weight to 14.6k# and gain 200# motor DP. Lock brake and allow to drill off. 15:55 - 16:00 0.08 STMILL WEXlT IStall @ 11254', 15k# string wt. Pick up and ease back to bottom. Stall again@ 11252.3', 18k# string wt. P/U and ease in again. 16:00 - 17:00 1.00 STMILL WEXIT Making head way. Drilling formation from 11255'? 1.7 bpm, 3150/3250 '""ctp, 14k# string weight. 20 to 30 fph. Stack and stop at 11265'. Pump 10 bbl biozan pill on bottom. 17:00 - 17:45 0.75 STMILL WEXlT Pull up hole slowly to 11100'. Run back to bottom. See slight weight bobble at 11256'. Tag up @ 11265'. PUH for tie-in log. 17:45 - 18:15 0.50 STMILL WEXIT Log GR tie-in. (+2') Paint EOP flag. 18:15 - 21:00 2.75 STMILL WEXlT POOH BHA#5. 21:00 - 21:30 0.50 STMILL WEXlT L/D BHA #5. Meanwhile displace coil to methanol/water. 21:30 - 23:30 2.00 STMILL WEXIT Cut 24' of coil. Weld on new connector. Pull and pressure test - OK. 23:30 - 00:00 0.50 STMILL WEXlT P/U & M/U BHA # 6. 2-3/8" motor w/1.75 ABH, Crayola & GR. OAL = 57.47'. 1/19/2001 00:00 - 00:15 0.25 STMILL WEXlT Finish M/U of BHA #6. 00:15 - 02:55 2.67 STMILL WEXIT RIH w/BHA #6. Shallow hole test good. Tie into EOP flag (-29') 02:55 - 03:40 0.75 STMILL WEXIT Log GR tie-in, (+3'). 03:40 - 04:25 0.75 STMILL WEXIT RIH and tag at 11256' (BOW) PUH to check TF. Orient tool face to 40L. 04:25 - 05:00 0.58 STMILL WEXlT RIH and tag up again at TOW. Get 1 more click and get same results. 05:00 - 05:30 0.50 STMILL WEXIT Bring on pump at 1.7 bpm. Ease in hole and stall @ 11255.1'. 05:30 - 08:00 2.50 STMILL WEXlT Time mill through TOW at 1/10 ft. per 2 minutes. See slight motor work at 11256'. Tag and stall motor at 11263'. Try to make hole w/o Success. Printed: 2/26/2001 3:07:36 PM BP EXPLOI:b~TIONMAR0 ~) ~.O(~:'~age 3 of 9 Operations Summary ReportAlaska Oil & Gas Cons. Commission Anchorage Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 1/19/2001 08:00 - 09:00 1.00 STMILL WEXIT Swap hole over to new batch of Flopro. Get bottoms up. Log GR tie in to check depth. (+0') GR tool acting up. Not reliable. 09:00 - 10:50 1.83 STMILL WEXIT Drift through pilot hole and window to bottom without pump. Clean. Back ream bottom of window at 60R, 60L and 30L. Drift window without pump again. Clean. 11:00 - 14:00 3.00 STMILL WEXIT Pull out of hole for Build assembly. 14:00 - 14:30 0.50 STMILL WEXIT Lay down BHA ~6. 14:30 - 15:00 0.50 DRILL PROD1 P/U BHA #7, build assemebly. 15:00 - 17:30 2.50 DRILL PROD1 RIH, shallow hole test, OK. 17:30 - 18:00 0.50 DRILL BHA PROD1 AttemPt to log tie in w/gamma, no pulses and circ. pressure high, 400'0 psi @ 1.4 bpm. Shallow hole done @ 1.6 bpm, 3300 psi. Circulate a various rates, try back up pump, no change. Suspect trash on pulser. 18:00 - 21:30 3.50 DRILL BHA PROD1 POOH, check @ 5000', still high pressure, Iow rate, no pulses. 21:30 - 22:15 0.75 DRILL BHA PROD1 Break down BH^, green tape found in bit..came off MWD battery pack. Check & clean all BH^ components. 22:15 - 22:45 0.50 DRILL BH^ PROD1 M/U BHA #8, to drill build section. 22:45 - 00:00 1.25 DRILL BHA PROD1 RIH, shallow hole test, OK. 1/20/2001 00:00 - 01:45 1.75 DRILL BHA PROD1 Continue to RIH W/build section BHA. 01:45 - 02:30 0.75 DRILL PROD1 Log tie in w/gamma, subtract 1' correction. 02:30 - 03:00 0.50 DRILL PROD1 RIH, pumps off, tag window @ 11,255', orient to 50L & thru window, OK. Tag @ 11,265'. 32K up wt, 24K dn. 03:00 - 04:00 1.00 DRILL PROD1 Drill ahead to 11,290', TF 40L. 3500 psi freespin @ 1.5 bpm, 2-3K WOB, 200-300 dp on motor, ROP 60 fph. 04:00 - 04:15 0.25 DRILL PROD1 Seeing 85 deg Inc, 35 deg dogleg coming off ramp. Orient to 90L. 04:15 - 06:15 2.00 DRILL PROD1 Drill ahead to 11,397', ROP up to 130 fph. 06:15 - 06:45 0.50 DRILL PROD1 Short trip to window. 06:45 - 09:15 2.50 DRILL PROD1 'Drill ahead to 11,592, TF 80-100L. Avg ROP 100 fph. 09:15 - 10:15 1.00 DRILL PROD1 Short trip to window. 10:15 - 11:30 1.25 DRILL PROD1 Drill ahead to 11,683'. TF 60L, ROP 90 fph, 300 dp on motor, 3-4K WOB. Believe fault @ 11,660'. 11:30 - 12:00 0.50 DRILL PROD1 Orient TF to 120L 12:00 - 15:00 3.00 DRILL PROD1 Dril ahead f/11,683'-11,861'. Avg ROP 100 fph. 300 dp on motor, 3-4K WOB. Build & turn complete, in zone lA. 15:00 - 18:00 3.00 DRILL PROD1 POOH BH^#8 f/1 deg motor to drill lateral section, paint EOP flag @ 10700'. ,18:00 - 19:30 1.50 DRILL PROD1 Observe well @ 500' - OK. PJSM. Continue POOH BHA#8. 19:30- 21:30 2.00 DRILL PROD1 Changeout to l deg motor & M/U BHA #9. OAL~57.38'. 21:30 - 00:00 2.50 DRILL PROD1 RIH BHA#9. Shallow hole test good. Correct to EOP flag (-37'). 1/21/2001 00:00 - 00:30 0.50 DRILL PROD1 ' Continue to tie in w/gamma, no correction. 00:30 - 00:45 0.25 DRILL PROD1 Orient to 40-50L 00:45 - 01:15 0.50 DRILL PROD1 Continue in hole, thru window OK. Tag @ 11,861'. 01:15 - 01:45 0.50 DRILL PROD1 Orient around to 90L. 01:45 - 03:20 1.58 DRILL PROD1 Drill ahead fl 11,861'-11,956'. TF 85-100L. 1.6 bpm @ 3600 psi freespin, 300 dp on motor. WOB 2-4K, ROP 100 fph. 03:20 - 03:45 0.42 DRILL PROD1 100' wiper trip. 03:45 - 04:00 0.25 DRILL PROD1 Orient to 90R. 04:00 - 07:45 3.75 DRILL PROD1 Drill ahead f/11,956'. Sticky @ 12,000', 10K overpull, pump 30 bbl new mud sweep. Continue drilling (~ 100 fph to 12,204', TF 80-110R. 07:45 - 09:30 1.75 DRILL PROD1 Wiper trip to window. Pump 30 bbl new mud sweep. 09:30 - 09:45 0.25 DRILL PROD1 Drill ahead to 12,222', TF 150R. Consensus is that fault @ 11,660' didn't drop us down the 15' expected. Intent is to drop another 10' TVD & look for marker indicating top of zone lA. 09:45 - 10:00 0.25 DRILL PROD1 Orient around to 120L. Printed: 2/2612001 3:07:36 PM (., (..... RECEi ,;.ED , I ,IL--,~-...n w n....n~ BP EXPLORATION MAD 0 9 4 of 9 Operations Summa Repo Alaska 0il & Gas Cons. Commission Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE StaK: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code ~/2~/200~ ~0:00 - ~0:15 o.25 DRILL PROD1 Drill ahead to 12,241',..stuck,..new mud being mixed. 10:15 - 10:30 0.25 D~ILL DS P~OD1 ~elax pipe, pumps down, wait 10 rain, pull 10K over (2) times & 3rd time pull 10K over & bring on pump, pulled free. 10:30 - 11:15 0.75 D~ILL P~OD1 Drill f/12,241'-12,288'. TF 90L. 32K up ~, 17K dn. 4K WOB ~OP 90 fph. 3500 psi freespin ~ 1.5 bpm, 300 dp on motor. 11:15 - 12:30 1.25 DRILL PROD 1 Wiper trip to window. Marker obse~ed ~ 12,250', indicative of top of zone lA. 12:30 - 12:45 0.25 DRILL PROD1 Orient TF around to 120L. 12:45- 13:15 0.S0 DRILL PROD1 Drill ahead to 12,324', .... stuck. 13:15 - 14:30 1.25 DRILL DS PROD1 Relax pipe & shut down pumps. Pull up to 15K over up ~. Unable to 3ul[ free. No pulses ~ MWD. Sta~ new mud around, and affempt to 3u[I free a~er mud out bit & past window, N~. Call for crude. 14:30 - 16:30 2.00 DRILL DS PROD1 Continue pumping new mud around, 1.5 bpm ~ 3500 psi, still no discernible pulse f/MWD. T~ eve~ 1/2 hour w/I~K overpull, no 16:30 - 17:00 0.50 DRILL DS PROD1 Pre job on pumping crude & conducing REID vapor pressure test. Test done, less than 1.5 psi...(.9 psi). Emphasis on leak free conne~ions & close monitoring of lines w/pumping crude. 17:00 - 17:45 0.75 DRILL DS PROD1 Pump 7 bls crude & chase. W/2-3 bbls out bit slow pump rate to .5 bpm & pull 14K over up ~ (1) time, pulled free. 17:45 - 19:00 1.25 DRILL PROD1 Wiper trip to window & circulate crude out. Pulses back ~ 11,900' 19:00 - 19:30 0.5O DRILL PROD1 Log tie in w/gamma, add 8' correction. 1 ~:30 - 20:15 0.75 D~ILL P~OD1 ~un back in hole, pulses not discernibl~ ~ 11,9~0'. 20:15 - 21:15 1.00 DRILL PROD1 Troubleshoot w/slowly POOH. Check transdu~r ~ su~a~, plugging off due to i~, debris, clean same & ~BIH. Signal OK. 21:15-21:30 0.25 DRILL PROD1 OrientTFto 120L. 21:3O - 23:OO 1.5O DRILL PROD1 Drill ahead f/12,324'-12,378', TF 140L. 23:00 - 23:15 0.25 D~ILL P~OD1 Orient (2) clicks, some trouble getting clicks. 23:15 - 00:00 0.75 DRILL ~ROD1 Drill ahead to 12,436'. TF 100-115L. ROP 90-120 fph. Freespin 1.6 bpm ~ 3300 psi, 200-300 dp on motor. 31K up ~, 19K dn. 1/22/2001 00:00 - 00:30 0.50 DRILL PROD1 Drill ahead f/12,436'-12,452'. TF 100L, freespin 3350 psi ~ 1.6 bpm. 31K up ~, 19K dn. 00:30 - 00:45 0.25~ DRILL PROD1 Orient 00:45 - O3:00 2.25 DRILL PROD1 Drill ahead f/12,452'-12,533' w/140L TF, then to 12,598' ~ 40-60L. 03:00 - 04:15 1.25 D~ILL P~OD1 Wiper trip to window. 04:15 - 04:30 0.25 DRILL PROD1 Orient to 90L. O4:3O - 05:15 0.75 DRILL PROD1 Drill ahead f/12,598'-12,658'. Angle building w/90-95L TF. 05:15 - 05:30 0.25 DRILL PROD1 Orient to 120-130L. 05:30 - 07:45 2.25 DR;LL PROD~ Drill ahead f/~2,658'-12,785'. TF 120-140L, ROP 90 fph. 4OO dp on motor, WOB 3-5K. 07:45 - 08:O0 0.25 D~ILL DS P~OD1 Stacked weight & got stuck. Slack off & pumps off, 10 min. Pick up to 15K over up ~ (3) times, kicked pump on holding 15K over & popped free. 08:00 - 09:00 1.00 DRILL PROD1 Sho~ trip to window, pump 10 bbl new mud sweeper. 09:00 - 10:00 1.00 DRILL TDRV PROD1 Inje~or a~ing up, pull into cased hole & troubleshoot. Counterbalance valve. 10:00 - 13:00 3.00 D~ILL P~OD1 Injector OK. Decision made to POOH · test BOPE. Radiator lea~ing on ~2 mud pump, remove same & send in f/repair. 13:00 - 14:00 1.00 DRILL , PROD1 Pe~orm weekly maintenance on inje~or. 14:00 - 15:00 1.00 DRILL PROD1 UD BHA~9. 15:00 - 16:00 1.00 DRILL PROD1 Displa~ coil to meth/water 16:00 - 00:00 8.00 DRILL PROD1 Carried out weekly BOPE testing, witnessed by AOGCC inspe~or, Lou ~rimaldi. ~ebuilt leaking choke manifold valve ~12 and retested same - Printed: 2/26/2001 3:07:36 PM (' ( REGEiVEO BP EXPLORATION MAR 0 9 001 Page 5 of 9 Operations Summary ReportAlaska Oil & Gas Cons. Commission Anchorage Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Date From-To Hours Task Code Phase Description of Operations 1/22/2001 16:00 - 00:00 8.00 DRILL PROD1 OK. Meanwhile repaired leaking radiator on mud pump #2. 1/23/2001 00:00 - 02:00 2.00 DRILL PROD1 Finish testing BOPE. (2) failures, (1) choke valve...repaired it w/testing rams & annular preventor, & manual kill line valve failed .... replaced same w! new valve. 02:00 - 02:15 0.25 DRILL PROD1 Pre Job, HNHM on cutting coil. Focus on body positioning & good communication. 02:15 - 05:00 2.75 DRILL PROD1 Cut 150' off of coil, weld on new connector, pressure test & pull test same, OK. 05:00 - 06:45 1.75 DRILL PROC PROD1 Attempt to displace coil to FIo Pro, unable to due to blockage, trouble shoot same. Investigation reveals coil not totally displaced to methanol @ onset of BOP test. 1-3 bbls of KCL/water left in coil. 06:45 - 07:00 0.25 DRILL :~ROC PROD1 Pre Job on cutting coil. HNHM. Emphasis on body positioning & use of good communication techniques. 07:00 - 12:00 5.00 DRILL PROC PROD1 Cut 130' off of coil, observe meth/water draining, weld on new connector, pull/pressure test same, OK. M/U to well, unable to circulate, RIH to 1000' & pressure coil, break circulation @ 2900 psi, OK. Note: Stripper leaking & will need to be replaced prior to RIH w/drilling BHA. 12:00 - 13:30 1.50 DRILL PROD1 Circulate coil to FIo Pro & POOH. 13:30 - 13:45 0.25 DRILL PROD1 Pre Job, HNHM on changing out stripper element. Focus on good communication techniques. 13:45 - 17:00 3.25 DRILL PROD1 Replace Hydril Compact stripper element & function test same, OK. 17:00 - 17:45 0.75 DRILL PROD1 M/U BHA #10 to continue drilling lateral section. Replaced motor, MWD, & MHA. 17:45 - 21:15 3.50 DRILL PROD1 RIH, shallow hole test, OK. EOP flag correction subtract 38'. 21:15 - 22:45 1.50 DRILL PROD1 Log tie in, add 5' correction. 22:45 - 23:45 1.00 DRILL PROD1 Adjust floor motor clutch. 23:45 - 00:00 0.25 DRILL PROD1 Continue in hole, thru window wi HS toolface, OK. 1/24/2001 00:00 - 01:15 1.25 DRILL PROD1 Continue in hole, tag @ 12,785'. 01:15 - 02:30 1.25 DRILL PROD1 Drill ahead @ 10R f/15', then 30R f/27', then 80-90R, to bring angle up & flatten out. ROP 100 fph w/3K WOB. 3500 freespin @ 1.6 bprn, 300 dp on motor. 31K up wt, 19K dn. 02:30 - 02:45 0.25' DRILL DS PROD1 Stuck @ 12,838' Slight loss rate, .3 bph. Slack off, pumps off, wait 15 minutes, (relax), P/U pipe free. 02:45 - 03:15 0.50 DRILL PROD1 Wiper trip to 12,500'. 03:15 - 03:30 0.25 DRILL PROD1 Drill ahead to 12,870' @ 80-90R. TF flopped to 120R. 03:30 - 04:15 0.75 DRILL PROD1 Orient to 90R. 04:15 - 04:30 0.25 DRILL PROD1 Drill ahead to 12,895'. TF flopped to 120R. 04:30 - 05:10 0.67 DRILL PROD1 Re oreint to 60-70R. 05:10 - 06:00 0.83 DRILL PROD1 Drill ahead to 12,927'. ROP 100 fph. 06:00 - 07:45 1.75 DRILL PROD1 Short trip to window. 07:45 - 08:00 0.25 DRILL PROD1 Drill ahead to 12,944'. TF 100R. Need to come up about 1-3', 7VD. 08:00 - 08:30 0.50 DRILL PROD1 Orient around to 40R. 08:30 - 10:30 2.00 DRILL PROD1 Drill ahead 12' @ 10R, 12' @ 30R, & 20' @ 60R. Drill on to 13,018' @ 90R. New mud ordered. 10:30 - 12:00 1.50 DRILL PROD1 2 clicks & drill on to 13,062' @ 110-120R. Weight transfer becoming a problem. Stacking & stalling. 12:00 - 13:30 1.50 DRILL PROD1 Short trip to window. 13:30 - 15:45 2.25 DRILL PROD1 Drill ahead, new mud going around. Weight stacking Drill to 13,106'. TF 120-140R. 15:45 - 16:15 0.50 DRILL PROD1 Orient TF around to 90R. 16:15 - 15:45 23.50 DRILL PROD1 Drill ahead to 13,183'. TF 100R. ROP 40-60 fph. Angle leveling out @ 84.6 deg. 15:45 - 16:15 0.50 DRILL PROD1 Orient around to maintain angle of 85-86 deg. Printed: 2/26/2001 3:07:36 PM (' RECEIVED BP EXPLORATION MAR 0 D Zi~I~e 6 of 9 Operations Summa Report ^laska Oil & Gas Cons. Commission , ~l ,v, ,v, Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 112412001 16:15 - 17:30 1.25 DRILL PROD1 Drill ahead with TF 90R, ROP = 50 fph, starting to see some stacking 17:30 - 18:00 0.50 DRILL PROD1 Orient TF around from 90R to 30R 18:00 - 18:30 0.50 DRILL PROD1 Drilling at 30RTF with ROP = 50 fph, some stacking 18:30 - 18:45 0.25 DRILL PROD1 Drilling at 60R TF and stacking 18:45 - 18:55 0.17 DRILL PROD1 Made 100' wiper trip from 13196' 18:55 - 19:20 0.42 DRILL PROD1 Trying to drill, stacking and unable to orient TF 19:20 - 19:40 0.33 DRILL PROD1 No pulse detected at MWD shack, Steam MWD transducer, 19:40 - 21:40 2.00 DRILL PROD1 Lost MP#1 Pump, liner, PUH while working on MP#I 21:40 - 22:20 0.67 DRILL PROD1 Tie- using MP#2 @ 10950' corrected +10', set counters 22:20 - 00:00 1.67 DRILL PROD1 Orient TF @ TOO & RIH. 112512001 00:00 - 01:15 1.25 DRILL PROD1 Orient around to 60-70R. Trouble w/MWD signal decoding. Pump up pulsation dampner. 01:15 - 03:15 2.00 DRILL PROD1 Drill ahead fl 13,217'-13,278'. Freespin 4000 psi @ 1.5 bpm, 400-500 psi. Excessive pressure w/new mud due to .... ? 03:15 - 06:45 3.50, DRILL PROD1 POOH to check BHA. 06:45 - 08:00 1.25 DRILL PROD1 IJD BHA #10, no indication of blockage in any BHA components. P/U new motor, MWD, MHA, & orienter. Flush all tools. 08:00 - 08:30 0.50 DRILL PROD1 Work on Cyber. 08:30 - 11:00 2.50 DRILL PROD1 RIH, shallow hole test, OK. 11:00 - 11:30 0.50 DRILL PROD1 Log gamma tie in, add 6' correction. 11:30 - 13:00 1.50 DRILL PROD1 Orient above TOC, thru window & tag @ 13,278'. 13:00 - 16:15 3.25 DRILL PROD1 Mud engineer finds yield high, mud dehydrated ,add KCL/water. Continue drilling, weight transfer & ROP improving, freespin down to 3650 @ 1.6 bpm. 16:15 - 19:55 3.67 DRILL PROD1 Drilling TF 80R, ROP 20 to 35 fph, 13320 sliding decreased 19:55 - 21:05 1.17 DRILL PROD1 Wiper trip to below window, RIH and pumped 10 bbl clean rio-pro sweep and displaced to bit 21:05 - 22:00 0.92 DRILL PROD1 Driling with bit stacking Drilling at 80 to 85R TF 22:00 - 23:50 1.83 DRILL PROD1 Working CT to get it to drill, stack without motor work. Pumped 10 bbl 5% lubetex pill to assist in sliding 23:50 - 00:00 0.17 DRILL PROD1 Working CT and spotting Lubetex pill 1/26/2001 00:00 - 00:30 0.50 DRILL PROD1 LubeTex pill out of bit and unable to slide. TD wel at 13372' MD uncorrected. 00:30 - 01:30 1.00 DRILL PROD1 Wiper trip to sweep hole and Tie-In above window 01:30 - 02:10 0.67 DRILL PROD1 Tie-in (0' correction) 02:10 - 03:15 1.08 DRILL PROD1 RIH to cleanout to bottom. 03:15 - 03:35 0.33 DRILL PROD1 Ream shales at 13100' 03:35 - 03:40 0.08 DRILL PROD1 RIH and tagged TD at 13372' 03:40 - 08:00 4.33 DRILL PROD1 POOH to run liner, flag EOP @ 10,853' & 8619'.Observe well @ 500'. 08:00 - 09:15 1.25 DRILL PROD1 L/D BHA #11. 09:15 - 09:30 0.25 CASE COMP Pre job meeting on picking up liner. Identify hazards & means of mitigating associated risks. Emphasis on good communication. 09:30 - 16:30 7.00 CASE COMP P/U liner jewelry & 79 its 2 318" FL4S tbg. 16:30 - 18:00 1.50 CASE COMP RU to run 1" CSH 18:00 - 22:30 4.50 CASE COMP PU 82 Jts 1" CSH 22:30 - 23:30 1.00 CASE COMP Spaced out 1" CSH with 1.81' PJ. Stabbed into top joint Filled backside with 2% KCL water RU to PT LC Seal assembly 23:30 - 00:00 0.50 CASE COMP Work on PLO for MP#2, No throttle control 112712001 00:00 - 02:00 2.00 CASE COMP Rig Repair on PLC for MP#2 ~ 02:00 - 03:10 1.17 CASE COMP PT seal assembly to 500 psi, OK, Installed Bakers deployment sleeve and RU to stab on CT, BHA L= 2544', Set counters 03:10 - 04:55 1.75 CASE COMP RIH with Liner to top flag. Set counters to flag +23' 04:55 - 06:15 1.33 CASE COMP RIH and tagged bottom at 13372', Work CT and circulate wellbore Printed: 2/26/2001 3:07:36 PM I.(I- L.;I- I V I- BP EXPLORATION Page 7 of 9 Operations Summary Report MAR 0 9 Z001 · ,__,._ ,-,:l o r,..,, r',-,ne ~mrnieeinn /"~l~;IOl~l ~..~11 ~ -~.~z,,~ vv ...... Legal Well Name: 0-33 Anchorage Common Well Name: C-33A Spud Date: 6/,13/1993 Event Name: REENTER+COMPLETE Start ,1/,13/200'1 End: Contractor Name: NABOR$ TRAN$OCEAN Rig Release: Group: COIL Rig Name: CDR-'1 Rig Number: ,1 Sub Phase Description of Operations Date From-To Hours Task Code 1/27/2001 o4:55 - 06:15 1.:3:3 CASE COMP clean prior to dropping 5/8" ball. Up wt :39K, 16K 06:15 - 06::30 O.25 CASE COMP Crew change: Pre job on dropping ball. Stress on communication & body positioning. 06:$0 - 08:00 1.50 CASE COMP Drop 5/6" ball & circulate down. Shear off @ 4:300 psi. Pick up to verify, :31K up, OK. Set down 5-8K on liner & circulate lbpm @ :3800 psi, 1:1 returns. 08:00 - 08:45 0.75 CASE COMP Batch mix cement. 08:45 - 09:00 0.25 CASE COMP Pre job, HA/HM. P,eview cementing & displacement plan. Focus on communicating & staying clear of hardline. 09:00 - 10::30 1.50 CASE COMP PT lines to 4500 psi, OK. Pump 5 bbls KOL/water, 16.5 bbls cement & displace w/:39.5 bbls KOL/water. Final circ pressure w/displacing, .7 bpm @ 4200psi. 1:1 returns throughout job. 10::30 - 12:45 2.25 CASE 'COMP CIP @ 10::30. Sting out of flapper, lay in remaining cement in liner w/ POOH to 11,500'. P,BIH contaminating cement w/biozan & tag flapper @ 1:3,:336', see pressure increase w/pumping @ .5 bpm. Cleanout liner w/remaining 12:45 - 16:00 :3.25 CASE COMP POOH, circulating above liner @ 1 bpm, 2100 psi. (1) pass by each OLM. 16:00 - 21:00 5.00 CASE COMP Break off & rack back injector. P,ack back 82 jts CS Hydril & L/D stinger. 21:00 - 22:0O 1.00 CASE COMP Flush out BOP stack 22:O0 - 22:15 O.25 CASE COMP ,JSA on PU CNL tools and source material 22:15 - 00:00 1.75 CASE COMP P`IH with SWL Memory CNL and 8:3 jts 1" CSH tubing. 1/28/2001 '00:00 - 0:3:00 :3.00 CASE COMP P,IH with memory CNL to 10700' CTM 0:3:00 - O:3:10 0.17 CASE COMP Corrected -4O' to ensure depth control while P,IH through liner top and ;LC 0:3:10 - 04:45 1.58 CASE COMP P, IH at $0 fpm logging with SWS Memory CNL. Tagged flapper valve at 1:3:3:31' Uncorrected. 04:45 - 06::30 1.75 CASE COMP PUH logging with Memory CNL at :3O fpm 06::30 - 10::30 4.00 CASE COMP POOH laying in new 150,000 LSP,V Fig Pro. Flag pipe @ 8214' EOP. 10::30 - 14:00 :3.5O CASE COMP P,ack back injector & rack back 8:3 jts 1" CS Hydril 14:00 - 15::30 1.50 CASE COMP Download data f~ Icg & prep guns for perforating. Log shows corrected PBTD, (flapper valve), to be @ 1:3,:320', TOL @ 10,808'. 15::30 - 15:45 O.25 CASE COMP Pre job on testing the liner lap. ,Job positions & assigned tasks. Dowell lab report indicates compressive strength of cement @ 05:00 1-28-01. 15:45 - 16:45 1.00 CASE COMP Test liner lap. Inner annulus, 0 psi, outer annulus, 200 psi. Liner lap bled f/2000 to 1000 psi in 8 minutes. No change in annulus pressures. Confirmed with town on way forward. Will look into running Liner Packer following the perforating segment ( ID restriction of 1.81:3" with Packer placed in deployment sleeve 16:45 - 17:00 0.25 CASE COMP P,JSM on picking up perf guns. Emphasis on communication and line of sight w/operating winch. 17:00 - 20:00 :3.00 CASE COMP PU 95:3' of 1-11/16" TCP guns 20:00 - 22:00 2.00 CASE COMP PU and P,IH w/5:3 jts CSH 22:00 - 00:00 2.00 CASE COMP P,IH with SWS perforating BHA 1/29/2001 00:00 - 0O:O9 0.15 CASE COMP P, IH to 1:310' with perf guns, conducted wt check PU = 00:09 - 00::30 0.$5 CASE COMP P,IH and tagged the LC at 1:3:3:35'/1:3:320' PU = O0::30 - 00:45 O.25 CASE COMP Conducted Salty and Operational meeting concerning perforating. 00:45 - 01:17 0.5:3 CASE COMP SD Pumps, dropped 1/2" ball and pressured up to 1:300 psi and launch down. Displaced ball at 1.2 bpm at :3500 psi, at :30 bbl pumped, slowed Qp down to 0.6 bpm and ball on seat. Pressured up to :3480 psi and guns fire Printed: 2/26/2001 3:07:36 PM BP EXPLORATION MAR 0 9 Z001 Page 8 of 9 Operations Summary Report Alaska Oi~ & Gas Cons. Commission ,Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 1/29/2001 01:17 - 02:20 1.05 CASE COMP POOH to monitor wellbore stability 02:20 - 02:40 0.33 CASE COMP Monitored wellbore while cir at 1 bpm. Lost 1.5 bbl in 20 minutes 02:40 - 05:10 2.50 CASE COMP POOH while keeping hole full. 05:10 - 05:25 0.25 CASE COMP Held Safety and Operational meeting on handling CSH tubing 05:25 - 08:00 2.58 CASE COMP POOH standing back CSH tubing. Monitor well, well taking approximately .5 bbls/hr above displacement. 08:00 - 08:15 0.25 CASE COMP Safety meeting on laying down perf guns, keeping the hole full, good communication & line of sight when operating winch. 08:15 - 11:30 3.25 CASE COMP Lay down spent perf guns, ASF. Hole still taking approximately .5 bph above displacement. 11:30 - 13:30 2.00 CASE COMP Displace coil to methanol/water. Prep to displace coil to nitrogen prior to coil reel changeout. 13:30 - 16:00 2.50 CASE COMP Continue to make preparation f/reel change out. N2 pumper delayed. 16:00 - 16:30 0.50 CASE COMP Pre job meeting on displacing coil to N2. Job assignments, communication, monitoring of returns & cellar. Manual choke operation. 16:30 - 18:30 2.00 CASE COMP Purge coil of fluid by pumping N2. Take returns thru choke & outside. 13:30 - 23:00 9.50 CASE COMP PJD to change out reel 23:00 - 00:00 1.00 CASE COMP Swap Reel '1/30/2001 00:00 - 06:00 6.00 CASE COMP Reel Swap, New reel is in place, RU hardline and cables 06:00 - 11:00 5.00 CASE COMP Stab pipe, cut 5' & dress end of pipe. Attempt to M/U redressed 1.25" ID coil connector, unable to insert completely into coil. Examine same, needs further redressing. 11:00 - 12:15 1.25 CASE COMP Begin laying down CS Hydril tubing while coil connector gets redressed. 12:15 - 14:41 2.43 CASE COMP M/U & weld 1.25" ID coil connector on coil. Pull tested to 25k, OK 14:41 - 21:00 6.32 CASE COMP Pump 7~8" ball and dart. Dart locked up in CTC. Pumped out, recovered all dart. Filled hole using 3 bbl of 2% KCL 21:00 - 21:30 0.50 CASE COMP PU Halliburton GHP retrievable liner top pack with seal assembly. 21:30 - 22:45 1.25 CASE COMP 'RIH, tagged the SSSV at 2167'. Worked though and unable to PUH. Work and at 15k over pull, Tool free, POOH 22:45 - 00:00 1.25 CASE PACK COMP POOH and left packer and seal assembly in the hole at 2184', LD Halco running tools 1/31/2001 00:00 - 01:30 1.50 CASE PACK COMP Wait on Halliburton WL to retrieve the liner top packer 01:30- 04:45 3.25 CASE PACK COMP RU Halliburton WL 04:45 - 05:05 0.33 CASE PACK COMP RIH with WL 3-1/2" PRT and tagged the top of the packer at 2167' Stung into packer and jarring. Came loose, gained string wt, 05:05 - 05:30 0.42 CASE PACK COMP POOH with WL and fishing tools 05:30 - 05:55 0.42 CASE PACK COMP OOH and close MV, Fishing tool sheared out of FN Re-pinned and stab on well, open MV 05:55 - 06:06 0.181 CASE PACK COMP RIH with WL fishing tools 06:06 - 06:30 0.40 CASE PACK COMP Tagged top of fish 2167' Set "GS" and jarred on fish twice and gained string wt. 06:30 - 06:50 0.33 CASE PACK COMP POOH and recovered fish. Halco took packer into shop and serviced same. 06:50 - 09:00 2.17 CASE PACK COMP Repaired WL and sheaved configuration 09:00 - 09:20 0.33 CASE PACK COMP RIH and brushed SSSV nipples. 09:20 - 10:00 0.67 CASE PACK COMP POOH and PU 2.72" drift 87" long 10:00 - 11:00 1.00 CASE PACK COMP RIH and worked 2.72" drift throught several times, always setting down on Iowere profile Looked up old surveys on Web and discovered 5.6 DLS at the SSSV nipple. 11:00 - 11:30 0.50 CASE PACK COMP POOH, stand back WL lubricator, 11:30 - 17:00 5.50 CASE PACK COMP Wait on Halliburton to redress liner top packer 17:00 - 18:50 1.83 CASE PACK COMP RU Halco Liner top packer with 2 joints of CSH 18:50 - 20:16 1.43 CASE COMP RIH with BHA and passed SSSV (2167'), RIH Printed: 2/2612001 3:07:36 PM BP EXPLORATION Page 9 of 9 Operations Summa Report Legal Well Name: C-33 Common Well Name: C-33A Spud Date: 6/13/1993 Event Name: REENTER+COMPLETE Start: 1/13/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code ,, 1/31/2001 20:16 - 22:45 2.48 CASE COMP RIH with liner top packer Stopped at 10700' PUH, wt = 35k 22:45 - 23:05 0.33 CASE COMP RIH and tagged the packer at 10858' CTMD. Stung into packer with 3.0k down, PUH and located ball drop 23:05 - 23:20 0.25 CASE COMP Dropped 1/2" delron ball and launched using 1100 psi, RIH and stung into packer at 10858' CTMD/10808 ECTMD 23:20 - 00:00 0.67 CASE COMP With 38 bbl pumped, ball on seat, pressure up to 3800psi and mandel sheared. PUH and Liner top packer is set with the MOE @ 10806' and top of packer at 10804' correct back to CTEMD 2/1/2001 00:00 - 04:45 4.75 CASE COMP POOH with HES packer running tool. FP the top 2000' and surface lines with MEOH 04:45 - 05:15 0.50 CASE COMP OOH and closed MV, Vp= 67 bbl MEOH RECEIVED MAR 0 001 Alaska 0il & Gas Cons. Commission Anchorage Printed: 2/26/2001 3:07:36 PM ObP BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amooo Field: Prudhoe Bay Site: PB C Pad Well: C-~ wd~path: C-33A Date: 2/13/2001 Time:. 10:51:13 Page.' I Co-ordtaate(NF.) Referenee: Well: C-33, True North Vertical (TVD) Referonee: 40: 33 6/311993 00:00 67.7 Section (VS) Referonee: Well (0.00E,0.0ON,0.00Azi) Survey Caicnlatlon Method: Minimum Curvature Db: Oracle FIeM: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1666) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Cen~'e Geomagnetic Model: BGGM2000 Site: PB C Pad RECEIV TR-11-14 UNITED STATES: North Slope Site Position: Northing: 5957218.72 ft Latitude: 70 17 From: Map Easting: 662550.03 ft Longitude: 148 41 Position Uncertainty: 0.00 ft North Reference: Ground Level: 0.00 ft OrM Convergence: Alaska Oi! & ~as Cons. Com, 22.367 N /~nchorage 2.797 W True 1.24 deg Well: C-33 Slot Name: 33 C-33 Well Position: +NI-S 3260.68 ft Norming: 5960514.33 ft Latitude: 70 17 54.434 N +E/-W 1681.89 ff Easttng: 664140.92 ff Longitude: 148 40 14.352 W Position Uncertainty: 0.00 ff Wellpath: C-33A Drilled From: C-33P61 500292237301 Tie-on Depth: 11250.00 ft Current Datum: 40: 33 6/311993 00:00 Height 67.70 ft Above System Datum: Mean Sea Level Magnetic Data: 11/29/2000 Declination: 26.82 deg Field Strength: 57476 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +NI-S +K/-W Direction fl ff ff deg 0.00 0.00 0.00 0.00 Survey: MWD Start Date: 1/26/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 11250.00 6857.97 Kick-off Point 13372.00 8916.77 Projected to TD Survey MD ' 'Inel" ", Azim ,. ' TVD " $STVD '.:'N/S ,' E/W ' MapN MapE '., DLS 'VS ft,." .' . deg deg' It ' ft ft,', ft 'ft, ' '.. ft . deg/100ft ·ft 11250.00 72.49 45.29 8857.97 8790.27 4438.46 4610.59 5965052.12 668653.15 0.00 4438.46 11305.00 88.70 35.30 8866.94 8799.24 4479.72 4645.43 5965094.14 668687.08 34.45 4479.72 11351.00 88.40 30.00 8868.11 8800.41 4518.43 4670.23 5965133.37 668711.03 11.54 4518.43 11396.00 68.00 23.70 8869.52 8801.82 4558.54 4690.54 5965173.91 668730.45 14.02 4558.54 11446.00 89.70 16.30 8870.53 6802.83 4605.48 4707.62 5965221.21 668746.51 15.18 4605.48 11478.00 89.70 11.70 8870.70 8803.00 4636.52 4715.36 5965252.41 668753.58 14.37 4636.52 11524.00 88.30 4.00 6871.50 8803,80 4682.05 4721.64 5965298.06 668758.85 17.01 4682.05 11558.00 87.40 0.50 8872.78 8805.08 4715.99 4722.97 5965332.03 668759.44 10.62 4715.99 11598.00 68.00 354.50 8874.38 8806.68 4755.90 4721.23 5965371.89 668756.82 15.06 4755.90 11656.00 92.70 347.50 8874.03 8806.33 4813.13 4712.17 5965428.90 688746.51 14.53 4813.13 116g7.00 92.70 341.50 8872.09 8804.39 4852.58 4701.23 5965468.10 668734.71 14.62 4852.58 11736.00 89.50 337.40 8871.35 6803.65 4889.08 4687.54 5965504.29 668720.24 13.33 4689.08 11780.00 87.10 332.90 8872.65 8804.95 4928.98 4669.07 5985543.77 668700.90 11.59 4928.98 11834.00 87,30 323.50 6875.30 8807.60 4974.76 4640.68 5965588.92 668671.52 17.39 4974.76 11862.00 88.10 320.40 6876.42 8808.72 4996.79 4623.44 5965810.57 668653.80 11.43 4996.79 11894.00 87.80 315.80 8877.56 8809.86 5020.59 4602.08 5965633.89 668631.93 14.40 5020.59 11930.00 88.60 310.20 8878.70 8811.00 5045.12 4575.78 5965657.84 668605.10 15.71 5045.12 11967.00 90.70 309.50 8878.92 6811.22 5068.82 4547.38 5985680.92 668576.19 5.98 5068.82 Obp BP Amoco Baker Hughes INTEQ Survey Report INTEQ ComptBy: BP Amoco Date: 2/13/2001 Time:. 10:51:13 Page: 2 Fidd: Prudhoo Bay Coordinate(NE) Reference: Well: C-33, True North SIM: PB C Pad Vertical (TVI)) Reference:. 40: 33 6/3/1993 00:00 67.7 Well: G-33 Section (rs) Rereremce: Well (O.OOE, O.OON,O.OOAzi) Wdlpath: C-33A Survey Caltuhtion Method: Minimum Curvalure Db: Oracle Survey MD Iud Azlm TVD SSTVD N/S EAV MapN MapE DLS VS 12003.00 89.80 316.50 8878.76 8811.06 5093.36 4521.06 5965704.87 668549.35 19.60 5093.36 12032.00 87.20 322.80 8879.52 8811.82 5115.44 4502.30 5965726.53 668530.11 23.49 5115,44 12074.00 87.50 331.30 8881.47 8813.77 5150.62 4479.51 5965761.20 668506.55 20.23 5150.62 12107.00 89.30 336.90 8882.39 8814.69 5180.28 4465.10 5965790.54 668491.51 17.82 5180.28 12151.00 91.70 343.60 8882.01 8814.31 5221.66 4450.25 5965831.58 668475.75 16.17 5221.66 12184.00 90.30 346.70 8881.43 8813.73 5253.55 4441.79 5965863.28 668466.60 10.31 5253.55 12220.00 86.10 352.40 8882.56 8814.86 5288.91 4435.27 5965698.49 668459.31 19.66 5288.91 12255.00 87.40 346.70 8884.55 8816.85 5323.26 4428.93 5985932.69 668452.22 16.68 5323.26 12299.00 90.60 341.10 8885.32 8817.62 5365.50 4416.74 5985974.65 668439.11 14.66 5365.50 12339.00 91.00 338.00 8884.76 8817.06 5402.98 4402.76 5966011.81 668424.32 7.81 5402.98 12376.00 87.20 334.40 8885.34 8817.64 5436.81 4387.64 5986045.31 668408.66 14.15 5436.81 12407.00 86.90 329.90 8886.94 8819.24 5464.18 4373.38 5966072.35 668393.61 14.53 5464.18 12444.00 86.50 323.90 8889.07 8821.37 5495.11 4353.22 5966102.83 668372.78 16.23 5495.11 12478.00 88.90 319.00 8890.43 8822.73 5521.67 4332.05 5986128.92 668351.04 16.04 5521.67 12507.00 87.20 316.90 8891.42 8823.72 5543.19 4312.64 5966150.01 668331.17 9.31 5543.19 12539.00 83.70 312.60 8893.96 8826.26 5565.64 4290.00 5966171,95 668308.04 17.29 5565.64 12573.00 87.20 310.20 8898.65 8828.98 5588.05 4264.56 5966193.80' 668282.14 12.47 5588.05 12616.00 92.80 305.60 8898.66 8828.96 5614.44 4230.67 5966219.45 668247.67 16.85 5614.44 12654.00 94.80 301.00 8894.14 8826.44 5635.25 4198.99 5966239.56 658215.54 13.17 5635.25 12693.00 89.20 297.50 8892.78 8825.08 5654.29 4165.00 5966257.65 668181.15 16.93 5654.29 12741.00 64.30 289.10 8895.50 8827.80 5673.23 4121.05 5966275.82 668136.79 20.23 5673.23 12771.00 83.20 264.50 8898.77 8831.07 5681.64 4092,51 5966283.81 668108.07 15.68 5681.64 12799.00 86.40 283.80 8901.31 8833.61 5688.68 4065.47 5966290.04 668080.89 11.70 5688.68 12832.00 90.20 289.40 8902.29 8834.59 5698.08 4033.68 5966298.76 668049.11 20.50 5698.08 12657.00 88.50 295.80 8902.68 6834.98 5711.52 4001.59 5966311.50 668016.53 18.92 5711.52 12899.00 90.10 301.00 8903.07 8835.37 5726.73 3973.45 5986326.09 687988.07 17.00 5726.73 12938.00 92.00 309.10 8902.36 8834.68 5749.11 3941.56 5966347.76 667955.70 21.33 5749.11 12974.00 94.20 313.00 8900.41 8832.71 5772.71 3914.45 5966370.76 667928.09 12.42 5772.71 13022.00 94.00 321.40 6896.97 8829.27 5607.81 3881.95 5966405.14 687894.83 17.46 5807.81 13065.00 91.30 327.80 8894.98 8827.28 5642.80 3857.09 5986439.58 687869.21 16.14 5842.80 13101.00 64.80 333.70 8895.21 8828.51 5674.16 3839.52 5966470.64 667850.96 24.37 5674.16 13146.00 64.60 339.00 8900.37 8832.67 5915.19 3821.55 5966511.17 687632.11 ' 11.74 5915.19 13178.00 83.10 344.60 8903.80 6836.10 5945.40 3811.62 5968541.15 687821.51 18.02 5945.40 13213.00 85.80 347.80 8907.18 8839.48 5979.22 3803.31 5966574.78 687812.47 11.93 5979.22 13243.00 87.10 351.30 8909.04 8641.34 6008.68 3797.68 5966604.08 687806.40 12.42 6008.68 13292.00 68.90 356.00 8911.61 8843.91 6057.35 3793.32 5986852.67 687800.78 13.68 6057.35 13316.00 68.20 1.20 8913.05 8845.35 6081.31 3793.16 5966676.61 667800.09 13.62 6081.31 13372.00 86.20 1.20 8916.77 8849.07 6137.17 3794.33 5966732.49 687800.04 0.00 6137.17 BP Afil~O WELLPA TH DETAILS C-3~A Parent Wellimth: C.~ZPB1 Vertlcal ~lfon Origin : Ve~fcal Seclfon Angle: R~: CDR 1 Dep~ RWeren~: 4~ : 33 613/1~3~0.~ · J · .M,4aBnctic Noflh: 26.82° Sircn~h: $747§nT Dip An$1c: 80.77° Date: 1112912000 REFERENCE INFORMATION Co~xclna~ (N/E) Relureflce: Wdl Centre: C-33, True Noflh Ve~cal (TVDJRef'"'"'"'"'"'~enoe: System: Mean Sea Level Seclion (VS) Reference: Slot - 33 (0.00,0.00) Measured Depth I~sfermce: 40: 33 6/3/1993 GO:O0 67.7 Cafculalion Method: Mrknu'n CLrvatu'e A~qOTATIONS 14) ~ 87~0.27 1125O.OO 8849.07 11~7Z0~ Pr~dtoTD 4....'; ...... ~ ....... i ....... .[ ....... i ....... ;- ...... 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[ ] [ l: , I .:i , i J I J J i J: i J J i J i : J , i ] J J iii: i I j j j j ~KKIO 3500 4000 4500 5000 5500 6000 i J i ! W.t(-)/Emt(+) [600it/in] , J i i · i i i ' il ' ' !I'Jl ' ' ' t · i ! 4000 4500 5000 5500 6000 6500 7000 7500 8000 Verlic.l Soctk)n .t 0.00° [S00tt/in] Pk)t 2/1312001 11:01 AM CONSERYA~ION CO--SION / TONY KNOWLES, GOVERNOR 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit C-33A BP Exploration (Alaska) Inc. Permit No: 200-202 Sur Loc: 700'SNL, 1222'.WEL, Sec. 19, T1 IN, R14E, UM Btmhole Loc. 611'NSL, 2687'EWL, Sec. 08, TllN, R14E, UM Dear Mr. ,McCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does nOt exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other' .required permitting determinatiOns are made. BlowoUt prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the COmmission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by Contacting the Commission petroleum field inspector on the Noah Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION DATED this '~ / ~ day of December, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/0 encl. PERMIT TO DRILL 20 AAC 25.005 I a. Type of work B Drill [] Redrill J lb. Type of well Re-Entry [] Deepen [] Service [][] DevelopmentEXpl°rat°ry Gas []1~1 StratigraphiCsingle Zone Test [][] MultipleDevel°pmentzone Oil I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 67.70' Prudhoe Bay Field / Prudhoe 3. Address .6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6812 !~,zE,-~>~'~'AQI~028304 4. Location of well at surface i7. Unit or PF6perty"e-~ Name ! 1. Type Bond (See 2O AAC 25.025) 700' SNL, 1222' WEL, SEC. 19, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3351' NSL, 2933' EWL, SEC. 17, T11N, R14E, UM C-33A Number 2S100302630-277 At total depth 9. Approximate spud date 611' NSL, 2687' EWL, SEC. 08, T11 N, R14E, UM 12/10/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028305, 611' MDI No Close Approach 2560 13821' MD / 8788' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11250' MD Maximum Hole Angle 101 ° Maximum surface 2470 psig, At total depth (TVD) 8800' / 3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casina Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include st~e data) 2-3/4" 2-3/8" 4.6# L-80 FL4S 2991' 10830' 8602' 13821' 8788' 95 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summaryRECEIVED Total depth: measured 12561 feet Plugs (measured) true vertical ess0 feet NOV ~0 ~000 Effective depth: measured 12561 feet Junk (measured) true vertical 8880 feet AlasJfa 0il & Gas Cons. Commission Casing Length Size Cemented Anchorage MD TVD Structural Conductor 110' 20" 280 cu ft Arcticset 110' 110' Surface 3574' 13-3/8" 2207 cuft PF 'E', 487 cu ft Class 'G' 3609' 3191' Intermediate Production 10396' 9-5/8" 1657 cu ft Class 'G' 10429' 8392' Liner 1519' 7" 370 cu ft Class 'G' 10251' - 11770' 8253' - 8917' Slotted Liner 865' 4-1/2" Uncemented Slotted Liner 11696' - 12561' 8919' - 8880' Perforation depth: measured 11299'- 11304', 11332'- 11353', 11401'- 11421', 11612'- 11702' Slotted Section: 11761' - 12512' true vertical 8872' - 8874', 8881' - 8886', 8897' - 8901', 8922' - 8919' Slotted Section: 8917'- 8881' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements "Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Tar/ia Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge /~ / Signed Thomas McCa~-----'"~,_.,,~F ~("'.~"~7"~' Title CT Drilling Engineer Date ~ Permit Number I APl Number Approval Date See cover letter ~ -- ~---4~0- 029-22373-01 ./_~',~ --'~J -" O~ for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes I~rNo Hydrogen Sulfide Measures ,~'Yes [] No Directional Survey Required .l~'Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~.5K psi for CTU Other: (.)F~.tGINAL SIGNED BY by order of Approved By D T avlor Seamount Commissioner the commission Date /~;~-, Form 10-401 Rev. 12-01-85 ORI61NAL Submit In Triplicate BPX C-33a Sidetrack Summary of Operations: C-33 is being sidetracked to target lower Zone I reserves. This sidetrack will be conducted in two phases. " Phase 1: P&A existing perforations, mill window off cement plug: Planned for Dec. 4-5, 2000. L,, · A Mec,,hanical Integrity Test will be performed. ) · A 2.75' drift will be run. // · Service coil will be used to cement the existing perforations and pressure test. %, · Service coil will be used to mill the window off of a cement ramp. Phase 2: Drill and Complete sidetrack: Planned for Dec 10, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase l& 2: Seawater · Phase 3: FIo-Pro (8.5 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 3/8", 4.6#, L-80, FL4S liner will be run from TD to approx. 10,830' MD (TOL) and cemented with approx. 17 bbls. To bring the top of cement to approx. 10,950'md (TOC). The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys wili be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A Memory CNL will be run in cased hole. Hazards One fault is expected to be crossed with a medium risk of lost circulation. Res. pressure is normal. C-Pad is not an H2S Pad - No test on this well. Reservoir Pressure Res. pressure is approx. 3350psi @ 8800ss. Max. surface pressure with gas (0.1 psi/ft) to surface is 2470 psi. RECEIVED NOV 2000 Alaska 0il & Gas Cons. Commission ' Anchorage C-33a Potential Drilling Hazards Post on Rig 1. Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S is not expected on this well. C-Pad is not an H2S Pad - No test on this well. 3. BHP is expected to be 3350psi (7.32ppg) @ 8800ss. 4. Maximum anticipated well head pressure w/full column of gas 2470psi. 5. Lost circulation risk is medium with one anticipated fault in the polygon. 1 The well is planned not to penetrate the Kavik, but there is a chance of accidentally penetrating the Kavik due to regional depth uncertainty. The Kavik could cause some drilling difficulties (sticky shale). RECEIVED NOV ~0 2000 Alaska Oil & Gas Cons. Commission Anchorage ( TREE: 4" - 5M ClW WELLHEAD: 13-5/8" - 5M FMC ACTUATOR: BAKER C-33 KB. ELEV = 72.5' GRND EL = 37.5' RT-TS = 31.00 New RT-TS=21.40 13-3/8', 68#, L-80, I R RN_{I' I BTC . SSSV LNDG NIPPLE I 2,167' I HES ( 2.750" ID) KOP ~521' Max Angle 94 ~12137 MMG W/1-1/2" RK LATCH II MD IT VD Deall I I 18,388'16,865'14°11 3-1/2", 9.2#, L-80, NSCT Tbg. Tubing ID: 2.992' Capacity : 0.0087 Bbl / ft TIW 9-5/8 x 7 Liner I 10.25'~'1 Hanger w/TBE Baker 95/8" Liner top Packer I 10,258' 9-5/8", 47# NSCC ~ [2.75"1D) I 10.817' 7'x3.5- Baker "S-3"Pkr. 110,830" W I No Latch 3.5" HES X-Nipple (2.75" ID) 110,855" HES X-Nipple (2.75" ID) ! 10.866" WLEGI 10.878' ELMO I 10,874" I PERFORATION SUMMARY DP CONY PERFS --.STRAP MEASUREMENT ISIZE [SPF INTERVAL OI 'ENISQZ'D 2.5" I 4 11,299 - 11,304 Open 2.5" } 4 11,332 - 11,353 Open 42.~' 4511,401-11,421 Open 11612-11T.2 MD OPEN ' 7x3-1/2 TIW HBBP ,I 11,300' 3.960 ID SWS nipple at 74' I 11,311' 2.750 ID WLEG I 11.316' ELMD I 11,320' TIW Soeup Head Min ID=4.001 7" x 4-1/2" TIW SSPacker MinlD=4.001 I 11.710' I 7", 29~, NT80 Liner I 11,'~O' I NOTE: SLOTTED LINER 4-1/2"L-80 slotted Liner I 12.5{,1' Packoff Shoe DATE 7-§-g3 10/7/94 10/11/95 10/18/95 IREV. BY I COMMENTS FAR(30 1 INITIAL COMPLETION l C. Michel I Add perfs MDG I RWO Tubing Change Out Completion J. Sharp I Post RWO Add Perfs PRUDHOE BAY UNIT WELL: C-33 (17111114E) APl NO: 50-029-22373 BP/ARCO PBU DRILLING I..t.J T. EE= 4"-5MC~V I Propo~..d completion diagram C-33~" WELLHEAD= 13-5/8" -5M FMC I ._K._B_._~.~_,=.. ............... ..7....2,:_5..'' ............................................. 1 · .~.~.'-.~,~-~ ............... ..3.....7...:...s..i ............................................ ! KOP = 521' I Max Angle = 94 @ 12,137' - 2167' ~ I I 13-3/8', 68#, L-80 BTC I I3609. I Minimum ID = 2.75" 3-1/2", 9.2#, L-80, NSCT Ito 10874' (elmd)I I TNVg'5/8"x7"liner I I Hanger with TBE 10,251' Baker 9-5~8" liner I 10,258' top packer I 9-5/8", 47#, NSCC 1 I 10,429' PERFORATION SUMMARY REF LOG: ANGLE AT TOP RE~F: I I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.5" 4 11,299-11,304 Opn 2.5" 4 11,332-11,353 Opn 2.5" 4 11,401-11,421 Opn 2.5" 5 11612-11702 Opn I 7"x3-1/2" TIVV HBBP I 3-112"SWSNippIe I @ 74deg (2.75"id) I ~", ~#,"~° Liner I 11,3oo' I 11,320' I 1.1,77o' I 11761- 12512 I ~,~' ', Slotted liner SAFETY NOTES ] I HES SSSV (2-75"id)1 GAS LIFT MANDRB. S ISTAI MD I T~,:, I DEVlTY'~MANI LATCH I ~ 2 14,gg2'1,~,256'1 4113.5"Camco1~-~2"~ 1 I 8,388'16,665'1 4013.5" Camcoll-1/2"F~<I RECEIVED I~OV ~0 ~000 Naska 0it & Gas Cons. c0mmissi0~ Anchor~e I 3.5" HES X Nipple 10,817' (2.75"id) I 7" x 3'1/2" Baker S- I 10,830' 3 Packer I 3,5" HES X Nipple 10,855' (2.75" id) I 3.5" HES X Nipple 10,866' (2.75"id) 11,250' 2.8" Window in 7" liner off of cement ramp, cement top to be brought to -10,950' I 2-3/8", FL4S I I~ 13,489'I I4-1/2" L-80, slotted DATE REV BY COMMBY'I'S 11/16/00 McCarty Proposed Completion Diagram for CTD Sidetrack PRUDHOE BAY UNIT WFIL: C-338 PI-3:',MIT No: APl No: Sec., N, E, FEL, FNL BP Exploration (Alaska) BI" Amoco WELl. PATH DETAILS Planfl2 C~3A Parenf Wellpath: C.33PB1 Tie on MD: Vertical ~ectlon Origin: Slot. 33 (0.00,0.00) Verifcal Section Angle: tOO' ~ m,r,,~ ~o: ~ m,m oo..oo ~.Ton REFERENCE INFORMATION Mlr4nz~ Cuw~lum 67./ ' I 2300 · ..... ~ ........ ~ ......... ~--.--.-~ ....... ~ ....... i ........ ! ........ i ....... -...' ....... 2875 3450 4025 4600 West(-)/East(+) [R] 4502 4752 5002 5252 5175 5750 ! 5502 5752 Vertical Section at 0.00' [fi] i i' : 6002 6252 6502 6752 BPAmoco BP Amoco BHI Planning Report ~HES Company: BP Amoco Field: Pmdhoe Bay Site: PB C Pad. Well: ~ ' .. Wellpath: Plarl#2 C-33A Survey: Start Date: Company: Engineer: Tool: Tied-to: Date: . 11/29/2000 Time: "10:51:56 ' Page: . ! · Co-ordinate(NE) Reference:" Well: !3,33, True. N°rth Vertical.(TVD) Reference: 40:33 6/.311993 00:00 67.7 Section (va)'Reference: Well '(0.00E,0.00N,0.00Azi) . Survey. Calculation Method: Minimum CurVature. Db: . SYbase Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ft 5957218.72 ft Latitude: 70 17 22.367 N 662550.03 fl Longitude: 148 41 2.797 W North Reference: True Grid Convergence: 1.24 dug Well: C-33 Slot Name: 33 C-33 Well Position: +NI-S 3260.68 ff Northing: 5960514.33 ft Latitude: 70 17 54.434 N +E/-W 1661.89 ft Resting: 664140.92 ft Longitude: 148 40 14.352 W Position Uncertainty: 0.00 ft Wellpath: Plan#2 C-33A Drilled From: C-33PB1 500292237301 Tie-on Depth: 11250.00 ft Curreut Datum: 40: 33 6/311993 00:00 Height 67.70 ff Above System Datum: Mean Sea Level Magnetic Data: 11/2912000 Declinatiou: 26.82 deg Field Strength: 57476 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff fl deg 0.00 0.00 0.00 0.00 Plan: Plan #2 Date Composed: 11129/2000 500292237301 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ............................................................................................................................. .i ....... ' ~:'::":' :' ':":' .......,,....~,:':,. :" ::t ~. ~ ~i~ ............ Annotation 11210.08 8545.59 Tie-inPoint 11250.00 8857.97 Kick-off Poi~ 11380.00 8877.71 1 11730.00 8877.70 2 12055.00 8878.13 3 12455.00 8879.78 4 12855.00 8882.72 5 12970.00 8872.26 6 13070.00 8859.16 7 13170.00 8855.70 8 13820.00 8855.70 TD RECEIVED NOV ;50 2000 Naska 0il & Gas Cons. Commission Anchorage BPAmoco BP Amoco BHI Planning Report ~RHE,~ · -Company: BP Amoco' Field: . Prudhoe Bay Site: PB C Pad · :,.Wdl: 'C-33 Wellpatit: ' Plafi#2 C-33A. Date: ' 11/29/2000:, Time: 10:51:56 Page: 2 .Co-ordinate(N~-)'Reference: Well: C-33, True North VerticM (T3~) ReFerence: 40: 33 6/3/199300:00 67.7 Section OrS) Reference:. Well (0.00E,0.00N,0.00Azi) surVey Calculation Method: Minimum Curvature Db: Sybase Plan Section Information ': MD." ' 'Incl" ........ Azim ' TVD +NFS' +F./-W DLS Build Turn TFO Target · '. ft .'.'."deg .... deg ......ft ft :.." ft deg/100ft deg/100fl.deg/100ft..' deg ..: 11210.08 71.39 45.38 8845.59 4411.78 4583.60 0.00 0.00 0.00 0.00 11250.00 72.49 45.29 8857.97 4438.46 4610.59 2.76 2.76 -0.23 355.54 11380.07 90.00 40.20 8877.70 4532.56 4697.38 14.00 13.46 -3.91 343.51 11730.07 90.00 351.20 8877.70 4859.33 4789.23 14.00 0.00 -14.00 -90.00 12055.07 89.86 305.70 8878.13 5129.06 4623.61 14.00 -0.04 -14.00 -90.20 12455.07 89.69 345.70 8879.79 5452.83 4402.75 10.00 -0.04 10.00 90.32 12855.07 89.50 305.70 8882.75 5776.59 4181.90 10.00 -0.05 -10.00 -90.40 12970.57 101.05 305.70 8872.15 5843.59 4088.65 10.00 10.00 0.00 0.00 13070.57 93.91 312.77 8859.12 5906.26 4011.99 10.00 -7.14 7.07 135.00 13170.57 90.00 321.98 8855.70 5979.71 3944.40 10.00 -3.91 9.21 112.83 13820.57 90.00 26.98 8855.70 6592.55 3885.18 10.00 0.00 10.00 90.00 Survey MD lncl · True Azi SSTVD D~S ........... Build ............... 11210.08 71.39 45.38 8777.89 4411.78 4583.60 5965024.87 668626.75 0.00 0.00 0.00 0.00 11250.00 72.49 45.29 8790.27 4438.46 4610.59 5965052.13 668653.15 2.76 2.76 -0.23 355.54 11275.00 75.85 44.27 8797.09 4455.53 4627.53 5965069.56 668669.71 14.00 13.43 -4.10 343.51 11300.00 79.21 43.27 8802.49 4473.16 4644.41 5965087.55 668686.20 14.00 13.45 -3.98 343.79 11325.00 82.58 42.30 8806.44 4491.27 4661.17 5965106.03 668702.57 14.00 13.46 -3.89 344.00 11350.00 85.95 41.34 8808.94 4509.81 4677.76 5965124.92 668718.74 14.00 13.47 -3.83 344.16 11375.00 89.31 40.39 8809.98 4528.69 4694.10 5965144.16 668734.66 14.00 13.48 -3.80 344.25 11380.07 90.00 40.20 8810.00 4532.56 4697.38 5965148.09 668737.86 14.05 13.53 -3.81 344.27 11400.00 90.00 37.41 8810.00 4548.09 4709.87 5965163.89 668750.00 14.00 0.00 -14.00 270.00 11425.00 90.00 33.91 8810.00 4568.40 4724.44 5965184.51 668764.13 14.00 0.00 -14.00 270.00 11450.00 90.00 30.41 8810.00 4589.56 4737.75 5965205.96 668776.97 14.00 0.00 -14.00 270.00 11475.00 90.00 26.91 8810.00 4611.49 4749.73 5965228.15 668788.47 14.00 0.00 -14.00 270.00 11500.00 90.00 23.41 8810.00 4634.12 4760.36 5965251.00 668798.60 14.00 0.00 -14.00 270.00 11525.00 90.00 19.91 8810.00 4657.35 4769.59 5965274.42 668807.32 14.00 0.00 -14.00 270.00 11550.00 90.00 16.41 8810.00 4681.10 4777.38 5965298.34 668814.59 14.00 0.00 -14.00 270.00 11575.00 90.00 12.91 8810.00 4705.28 4783.70 5965322.65 668820.38 14.00 0.00 -14.00 270.00 11600.00 90.00 9.41 8810.00 4729.81 4788.54 5965347.27 668824.68 14.00 0.00 -14.00 270.00 11625.00 90.00 5.91 8810.00 4754.58 4791.87 5965372.11 668827.47 14.00 0.00 -14.00 270.00 11650.00 90.00 2.41 8810.00 4779.51 4793.69 5965397.07 688828.74 14.00 0.00 -14.00 270.00 11675.00 90.00 358.91 8810.00 4804.50 4793.97 5965422.06 668828.48 14.00 0.00 -14.00 270.00 11700.00 90.00 355.41 8810.00 4629.47 4792.74 5965446.99 668826.70 14.00 0.00 -14.00 270.00 11725.00 90.00 351.91 8810.00 4654.31 4789.97 5965471.77 668823.40 14.00 0.00 -14.00 270.00 11730.07 90.00 351.20 8810.00 4859.33 4789.23 5965476.77 668822.54 14.00 0.00 -14.00 270.00 11750.00 89.99 348.41 8810.00 4878.94 4785.70 5965496.30 668818.59 14.00 -0.05 -14.00 269.80 11775.00 89.98 344.91 8810.01 4903.27 4779.94 5965520.49 668812.29 14.00 -0.05 -14.00 269.80 11800.00 89.97 341.41 8810.02 4927.19 4772.69 5965544.25 668804.53 14.00 -0.05 -14.00 269.80 11825.00 89.95 337.91 8810.04 4950.63 4764.01 5965567.49 668795.33 14.00 -0.05 -14.00 269.80 11850.00 89.94 334.41 8810.06 4973.49 4753.90 5965590.12 668764.73 14.00 -0.05 -14.00 269.81 11875.00 89.93 330.91 8810.09 4995.69 4742.42 5965612.07 668772.77 14.00 -0.05 -14.00 269.81 11900.00 89.92 327.41 8810.12 5017.16 4729.61 5965633.24 668759.49 14.00 -0.05 -14.00 269,81 11925.00 89.91 323.91 8810.16 5037.80 4715.51 5965653.57 668744.95 14.00 -0.04 -14.00 269.82 11950.00 89.90 320.41 8810.20 5057.54 4700.17 5965672.97 668729.19 14.00 -0.04 -14.00 269.82 11975.00 89.89 316.91 8810.25 5076.30 4683.66 5965691.37 668712.27 14.00 -0.04 -14.00 269.83 12000.00 89.88 313.41 8810.30 5094.03 4666.04 5965708.70 668694.26 14.00 -0.04 -14.00 269.83 12025.00 89.87 309.91 8810.36 5110.64 4647.36 5965724.90 668675.23 14.00 -0.04 -14.00 269.64 12050.00 89.86 306.41 8810.41 5126.09 4627.71 5965739.91 668655.25 14.00 -0.04 -14.00 269.85 12055.07 89.86 305.70 8810.43 5129.06 4623.61 5965742.80 668651.08 14.00 0.02 -14.00 270.07 12100.00 89.64 310.19 8810.55 5156.68 4588.19 5965769.64 668615.07 10.00 -0.05 10.00 90.32 12150.00 89.81 315.19 8810.70 5190.57 4551.45 5965802.72 668577.60 10.00 -0.05 10.00 90.31 12200.00 89.78 320.19 5227.54 4517.81 5965838.94 668543.16 10.00 -0.05 10.00 90.29 BP Amoco BHI Planning Report BJ~HES Company: BP.Amoco Field: Prudhoe Bay Site: 'PB C Pad Wall: C-33 Wellpath: Plan02 C-33^ Date: 1i/29/2000 · Time: 10:51:56 Page: 3 Co-ordinate(NE)Reference: . Well:"C-33, Tree North · ' YerltCal (T1v~)Referea~:'' . .~10: 33 6/311993 00:00.67.7 Se~tlen (VS) Eeferenee: 'Well (0.00E,0.00N~0.00Azi). Survey Calcuhti°n Method: Minimum Curvature ' ' Db: :Sybase Survey I MD . Incl True Azi SSTVD 'N/S · ~ 'i'ASP Y.-. ': .'ASP. X ." 'DLS" ":Build'. Turn · 'rFo ' . ft deg deg ft . .. ft. .....i. ...ff. ':' .:.ft .:.'.'.' .'-'::':':."ft.. ' ""degllOOft'deg/iOOft. degllOOft :"' · deg - ....,. ... .. . .. . . . 12250.00 89.76 325.19 8811.08 5267.30 4487.51 5965878.02 668512.01 10.00 -0.05 10.00 90.27 12300.00 89.74 330.19 8811.30 5309.54 4460.80 5965919.67 668484.38 10.00 -0.04 10.00 90.25 12350.00 89.72 335.19 8811.53 5353.96 4437.87 5965963.57 668460.49 10.00 -0.04 10.00 90.23 12400.00 89.70 340.19 8811.79 5400.20 4418.89 5966009.38 668440.51 10.00 -0.03 10.00 90.21 12450.00 89.69 345.19 8812.05 5447.92 4404.02 5966056.76 668424.60 10.00 -0.03 10.00 90.18 12455.07 89.69 345.70 8812.09 5452.83 4402.75 5966061.65 668423.22 10.00 0.03 10.00 89.83 12500.00 89.66 341.21 8812.35 5495.89 4389.96 5966104.41 668409.49 10.00 -0.07 -10.00 269.60 12550.00 89.63 336.21 8812.66 5542.46 4371.81 5966150.57 668390.33 10.00 -0.06 -10.00 269.63 12600.00 89.60 331.21 8812.99 5587.27 4349.67 5966194.88 668367.22 10.00 -0.06 -10.00 269.66 12650.00 89.57 326.21 8813.35 5629.98 4323.70 5966237.02 668340.33 10.00 -0.05 -10.00 269.69 12700.00 89.55 321.21 8813.74 5670.27 4294.12 5956276.64 668309.87 10.00 -0.04 -10.00 269.73 12750.00 89.53 316.21 8814.13 5707.82 4261.13 5966313.47 668276.08 10.00 -0.04 -10.00 269.76 12800.00 89.52 311.21 8814.55 5742.36 4225.00 5966347.20 668239.21 10.00 -0.03 -10.00 269.80 12850.00 89.51 306.21 8814.97 5773.61 4186.00 5956377.60 668199.53 10.00 -0.02 -10.00 269.85 12855.07 89.50 305.70 8815.05 5776.59 4181.90 5966380.48 668195.37 9.99 -0.13 -9.99 269.28 12900.00 93.99 305.70 8813.68 5802.79 4145.44 5966405.88 568158.35 10.00 10.00 0.00 0.00 12950.00 98.99 305.70 8808.03 5831.77 4105.11 5966433.97 668117.39 10.00 10.00 0.00 0.00 12970.57 101.05 305.70 8804.45 5843.59 4088.65 5966445.42 668100.68 10.00 10.00 0.00 0.00 13000.00 98.96 307.81 8799.34 5860.93 4065.43 5966462.25 668077.09 10.00 -7.09 7.16 135.00 13050.00 95.39 311.33 8793.09 5892.53 4027.21 5956493.00 668038.19 10.00 -7.15 7.05 135.37 13070.57 93.91 312.77 8791.42 5906.26 4011.99 5966506.40 668022.68 10.01 -7.19 6.99 135.86 13100.00 92.76 315.49 8789.71 5926.71 3990.90 5966526.39 668001.15 10.00 -3.89 9.23 112.83 13150.00 90.80 320.09 8788.15 5963.72 3957.34 5966562.65 667966.79 10.00 -3.92 9.20 112.99 13170.57 90.00 321.98 8788.00 5979.71 3944.40 5966578.35 667953.50 10.00 -3.91 9.20 113.03 13200.00 90.00 324.92 8788.00 6003.35 3926.88 5966601.60 667935.47 10.00 0.00 10.00 90.00 13250.00 90.00 329.92 8788.00 6045.47 3899.96 5966643.12 667907.64 10.00 0.00 10.00 90.00 13300.00 90.00 334.92 8788.00 6089.78 3876.82 5966686.91 667883.54 10.00 0.00 10.00 90.00 13350.00 90.00 339.92 8788.00 6135.93 3857.63 5966732.63 667863.35 10.00 0.00 10.00 90.00 13400.00 90.00 344.92 8788.00 6183.58 3642.54 5966779.93 667647.22 10.00 0.00 10.00 90.00 13450.00 90.00 349.92 8788.00 6232.36 3831.65 5966828.47 667835.28 10.00 0.00 10.00 90.00 13500.00 90.00 354.92 8788.00 6281.91 3825.06 5966877.85 667827.60 10.00 0.00 10.00 90.00 13550.00 90.00 359.92 8788.00 6331.85 3822.82 5966927.72 667824.27 10.00 0.00 10.00 90.00 13600.00 90.00 4.92 8788.00 6381.79 3824.93 5966977.69 667825.29 10.00 0.00 10.00 90.00 13650.00 90.00 9.92 8788.00 6431.35 3831.39 5967027.38 667830.66 10.00 0.00 10.00 90.00 13700.00 90.00 14.92 8788.00 6480.16 3642.14 5967076.42 667840.35 10.00 0.00 10.00 90.00 13750.00 90.00 19.92 8788.00 6527.85 3857.11 5967124.42 667854.27 10.00 0.00 10.00 90.00 13800.00 90.00 24.92 8788.00 6574.06 3876.17 5967171.03 667872.32 10.00 0.00 10.00 90.00 13820.57 90.00 26.98 8788.00 6592.55 3885.18 5967189.71 667880.92 10.00 0.00 10.00 90.00 .. Rig Floor CDR1 Drilling Wellhead [' tail ~ CT Injector Head Otis Q.C. thread half Traveling plate 20.63' 1.95' 7" lubricator 3.8' Traveling Plate 7" O.D. Jacking Frame 4---" Top Stationary Plate .17' I - ~'~ Annular BOP Annular BO,P, 7 /1LZ--ZZl Ii,ShafferDualGa[te! B°tt°m2"pipes I Hydril, "B" 5,000 psi L ~ Top 2"s ipsI R_a_.[n Type Dual Gate BOPE ~ WTM ~ Bottom 2 3/8" pipes I Manual Master Valve ~ Tubing Hanger 9-5/8" Annulus 7.35' 0.66' ~ Matt Ground Level 13-3/8" Annulus H 1 7 7 3 5 6 ~ o/3o/oo oo 1773.56 VENDOR ALASKASTAT 10 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET O:aSO0 CK 10:aSOOF 100. O0 100. O0 HANDL]:NG ZNST: S/H - TERRZE HUB]lEE X4b2B , ATTACHED C#~-CA S IN PA~.,~,.T FCeq,,'T;;;; OiiG~;~.~ ABOVE. . ~II]I-~IB = : 1 OO. OO 1 OO. OO :PAY' .. o~E..': ~ ;":.~,.: ::/~..oo,,~'*..~~'~-.-~', ~i~..*',,-'"*,.**~*...:~":..*~ .:~'~, oo~,:..'. :,.'.....'. '¥"":"'::"':':.!' ' '. . ." DATE", , '.':;?i!:;' '"!'::?':i`:':'''?!:'' :''~ '~'.:' ..A'i,i:i;AMOUNT"" ";'' '" '" :' ',':' .,o, ~o,olo ........f.......~ '.'.":1 '.."'::"."... :".."'.".""~ .': :'.: ."."" .'." oo.. !.......oo .'! ', , , 9*50 ii, ;i, ? ? :~ 5 Ell' I:O t, i, E'O :tp, q 51: O0ft t, t, I, ,. WELL PERMIT CHECKLIST COMPANY WELL NAME ~- -.~ ~/'~ PROGRAM: exp FIELD & POOL ~DMINISTRATION INIT CLASS 1. Permit fee attached ....................... 2. Lease number appropriate~._ ................ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available .in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ Permit can.be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided .................... II I~N~INEERING 14. Surface casing protects all known USDWs. ' CMT vol adequate to circulate on conductor & surf csg ...... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons. Casing designs adequate for C, T, B & permafrost ...... Adequate tankage or reserve pit. ' ' · ..... If a re-drill, has a 10-403 for abandonment been approved. Adequate weilbore separation proposed. ' If diverter required, does it meet regulations ..... . ... '. Drilling fluid program schematic & equip list adequate 25. BOPEs, do they meet regulation ' · ..... 26. BOPE press rating appropriate; test to ~O · psig; 27.. Choke manifold complies w/APl RP-53 (May 84) ' 28. Work Will occur without operation shutdown. ' 15. 16. .'.' 17. 18. 19. '20. 21; 22. 23. 24. DATE 29. 'is presence of H2S gas probable .... ' .. ........ , · , · 30. Permitcan be issued wlo hydrogen sulfide measures...... ' Y,~. "'.-" ' ' ' ' ' ' '' ' 31. Data presented on potential overpressure zones..'..... : · ' Y~,,N'. ,~,~"~/''/'~-'-:~'""~'=/r" .~5~ ~y..~, ,Zb. 32..Seismic analysis of shallOw gas zones... "...~ . . '... '..' ..._ ~'"'Y' .N' " ' ' "''~'~' "" ' 33. Seabed condition survey (if off-shore) .". ....... ; i .'-.,--'/~ f' Y N " 34.' Contact name/phone for weekly progress reports [ex..p~or~.only] Y N. . ." ,. GEOLOGy ..... dev ,-'"'redrll /,'" serv wellbore seg ann. disposal para req GEOLAREA J~>~'~) UNIT# ~:::)//~:,~-~--~:~_.~ ON/OFF SHORE ~ y N. N Y N Y N N . ' ' " ., N N ' ' N ' · " ;" '"" ' : ' ". ,.N '" ~. . , ' ' ., . ~ . ' .. ,..' . . ' . ' ' . . ...".' ,,., ,, .",. ,,..', ... YN ANNULAR DISPOSAL35. With proper cementing .records, this plan (A) Will .contain waste in a suitable receiving zonei ' ' DATE' ... (B) will not contaminate.freshwater; or cause drilling waste .. .... to surface; ..... (C) will'nOt impair mechanical integrity Of the well used' for disposal;. Y' 'N (D) will not damage producing formation. o!~ impair recovery.from a .. Y N ' ' pool; and. ' "' c:Xmsoffice\Wordian~i'anaXchecklist (reVi 111011100) .: . will not circur~vent 20 AAc 25.'252 or 20'AAc 25.412.. ' ' Y N '.. .. GEOLOGY: ' ENGINEERING:. ' UICdAnnular., COMMISSION: .,. , . . ' ". ' .', .' ,' , ' 'Comment~llnstructions: .., .., , ,.,, ' , .. ,,, ,: ,....:. ',... , ,.',.: ',., , , ~'~i, - l~-I '-OO. ,, JMH _,;~__ ,zl z.o l oo . . . ,. ..,. , = ' . .. , . . · . . ' , , , '. . ,. ,., , .',. . .. . , , , . , , ,. , . ., .... ,. ... . . '.. . O Well History File APPENDIX Information of detailed nature that is not particularly germane to, the Well Permitting Process but is part of the history' file, To improve {he readability of the Well History file and to simp!ify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically · organize this category of information. **** REEL HEADER **** MWD 01/08/17 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 00/11/21 110266 01 1.75" NaviGarana - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block %MNEM.UNIT Data Type CWLS log ASCII Standard -VERSION 1.20 One line per frame Information STRT.FT 11250.500: Starting Depth STOP.FT 13354.000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration Inc. WELL. WELL: C-33A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 700' NSL, 1222' WEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gan~na Ray DATE. LOG DATE: 13-Jan-01 API. API NYUMBER: 500292237301 -Parameter Information Block #MNEM.UNIT Value Description SECT. 19 : Section TOWN.N lin : Township RANG. 14E : Range PDAT. MSL : Permanent .Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 67 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 67 : Elevation of Kelly Bushing EDF .F N/A' : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gam~ua Ray data (GRAX) presented is realtime data. (4) Well C-33A was kicked off @ 11250' MD (8790' SSTVD) from a window in the casing of Well C-33. (5) Well C-33A was drilled to TD @ 13372' MD (8849' SSTVD) ON RUN 11. (6) The interval from 13354' MD (8848' SSTVD) to 13372' MD (8849' SSTVD) was not logged due to sensor to bit offset. (7) Baker Hughes Inteq runs 1-5 utilized directional and gamma services t¢ mill the casing window at 11250 ft MD (8790 ft SSTVD), and to drill formation from 11250 to 11265 ft MD (8790 to 8794 ft SSTVD). (8) Baker Hughes Inteq run6 utilized directional and gamma services to dress the window. (9) No logging was performed on run 7 due to a BHA pack off. (10) Baker Hughes Inteq runs 8-11 utilized directional and gan~a services from 11265 to 13372 ft MD (8794 TO 8849 ft SSTVD). (11) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BP Exploration (SWS, 01-26-01). (12) A Magnetic Declination correction of 26.82 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SSTVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL i 17.93 ft 2 17.67 ft 3 17.93 ft 4 17.67 ft 5 17.67 ft 6 17.67 ft 7 18.54 ft 8 18.66 ft 9 18.31 ft 10 18.32 ft 11 18.31 ft CURVE SHIFT DATA BASELINE, MEASURED, 11264.9, 11267.7, 11289 11301 11309 11327 11347 11366 11376 EOZ 6, 11294.0, 1, 11303.3, 7, 11313.9, 5, 11331.2, 6, 11352.3, 7, 11374.4, 5, 11384.5, 22.91 ft. 22.65 ft. 22.91 ft. 22.65 ft. 22.74 ft. 22.74 ft. 23.51 ft. 23.65 ft. 23.30 ft. 23.31 ft. 23.30 ft. DISPLACEMENT 2.74121 4.44434 2.22266 4.19727 3.7207 4.7002 7.6377 8.0293, Tape Subfile: I 94 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN WN FN COUN STAT BP EXPLORATION Inc. C-33A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 26-Jan-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ...... 1 GR GRAXl0 2 ROR ROPS10 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GR MWD 2 ROP MWD ODEP 0.0 0.0 Code Samples Units Size 68 1 API 4 68 1 F/HR 4 Total Data Records: 51 Tape File Start Depth = 11250.500000 Tape File End Depth = 13354.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minirmzmrecord length: Maximum record length: **** FILE HEADER **** MWD .002 60 records... 54 bytes 4124 bytes Length 4 4 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP EXPLORATION Inc. WN C-33A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP --- I GRAX GRAX 0.0 2 ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datu~u Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool GRAX MWD ROPS MWD Code Samples Units Size Length 68 i API 4 4 68 1 F/HR 4 4 Total Data Records: Tape File Start Depth Tape File End Depth 51 = 11250.500000 = 13354.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 60 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 00/11/21 110266 01 **** REEL TRAILER **** MWD 01/08/17 BHI O1 T~pe Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: Tape Subfile 2 is type: DEPTH 11250.5000 11251.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200 0000 12300 12400 12500 12600 12700 12800 12900 0000 0000 0000 0000 0000 .0000 .0000 13000.0000 13100.0000 13200.0000 13300.0000 13354.0000 LIS LIS GR -999.2500 -999.2500 22.3525 24.2590 124.2430 52.2210 32.3640 18.9340 21.0840 21.8440 22.9490 23.7260 57.4500 45.3580 60.7460 37.8510 77.8740 33.9220 44.5810 114.5330 81.1420 38.3970 30.7060 48.7650 ROP -999 -999 73 111 98 97 123 87 119 26 116 88 113 95 93 124 48 125 143 64 43 65 31 44 .2500 .2500 .5733 .6400 .0420 .4760 .6480 .1890 .2500 .7970 .2530 .6930 .1190 .1430 .6320 .9780 .0000 .7200 .7230 .2710 .8940 .9480 .5790 .2820 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = feet 11250.500000 13354.000000 0.500000 Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 11250.5000 32.3940 0.2740 11251.0000 29.6660 0.2790 '11300.0000 19.8440 71.4780 11400.0000 22.6000 115.2570 11500.0000 39.7730 107.8060 11600.0000 61.8950 97.8220 11700.0000 24.3090 111.5890 11800.0000 21.4430 92.9900' 11900.0000 41.5460 116,6840 12000.0000 24.0270 114,7200 12100.0000 21.6630 48.5910 12200.0000 26.0280 93.8450 12300.0000 53.7380 115'.4180 12400.0000 46.4170 116.1900 12500.0000 61.4970 93.6920 12600.0000 38.3670 83.7210 12700.0000 83.7190 71.4170 12800.0000 32.5680 107.9840 12900.0000 43.8540 117.2350 13000.0000 66.3400 56.8330 13100.0000 100.1200 34.8220 13200.0000 121.8990 54.0950 13300.0000 115.1560 33.0310 13354.0000 31.2420 53.5260 Tape File Start Depth = 11250.500000 Tape File End Depth = 13354.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS