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Home My WebLink About199-00703/20/08 Schlum~er~ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~,~(~ CHAR ~ ZC~~ WPII .Inh # Inn r]accrinfinn n~re NO. 4633 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.eay, Niakuk al r..I.,, rn 2-20 11963084 MEM PPROF p tt () 03/15108 1 1 J-12 12031462 LDL _ 03/10/08 1 1 NK-65A 12017488 PRIMARY DEPTH CONTROL 03/17/08 1 1 09-42A 12014004 USIT ~ 03/19/08 1 1 O-05B 40016311 OH MWD EDIT J ~ ~ 01/30/08 2 1 rLLf1VL MVI~IYV Yr LLYVG nG~rGlr' 1 01 AI~.YIYIIYt7 MIVU AC 1 Vr1IYIIVU VIVO l.Vr'T CNl.r1 1 V: BP Exploration (Alaska) Inc. ; - -, - - Petrotechnical Data Center LR2-1 ~ ~ ~ ~~~ ` ' ~" ~ ~ m --~ - 900 E. Benson Blvd. Anchorage, Alaska 99508 { (~ )) Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suit 4 Anchorage, AK 99503-2 ATTN: Beth Received by: f 09-42 RWO Scope Change • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 3:46 PM To: 'Frazier, Nicholas B' Subject; RE: 09-42 RWO Scope Change Nick, I conhrm our conversation. Anew sundry is not needed. You have developed information while working on the well that was unavailable to you when the original work scope was determined. It is appropriate to change the scope for the repair of the leak(s) identified. Regardless, the intent is to restore well integrity. 1 will place a copy of this message in the file. Call or message with any questions. Tom Maunder, PE AOGCC From: Frazier, Nicholas B [mailto:Nicholas.Frazier@bp.com] Sent: Tuesday, March 18, 2008 3:35 PM To: Maunder, Thomas E (DOA) ~~~~.~~ MAR 2 4 2QQ$ Subject: 09-42 RWO Scope Change Mr. Maunder- ` During the course of the RWO on we1109-42 (PTD # 1990070) in Prudhoe Bay, we have discovered that the integrity of the 9-5/$" casing is not compromised as originally thought. It is the existing 7-5/8" liner which has multiple leaks. This changes the scope of work which we wish to do on this RWO in order to remediate the finer Ieaks.The original plan was to extend the 7-5/8" scab liner up to 4,100' MD. Since, the 9-5/8" casing has been proven competent, we wish to run a 4-1/2" scab liner instead from 9,720' MD - 6,800' MD, Attached is a proposed change of scope along with proposed schematics which depict each scenario. Per our conversation, I don't think we need another Sundry. If you think we do need another one after reading the scope change then please let me know and I can get the process started. Thanks for your time and please let me know if you have any questions. «09-42A AOGCC Scope Change.zip» Nick Frazier BP RWO Engineer 564-5633 (work) 229-4596 (cell) ail gi2oas • by G~f~,~~~~~~ 09-42A Rig WOrkover Scope. of Work: Pull 5-'/2' x 4-'/" completion, run 7 %e' retrievable plug, run-and cement new scab liner to _ comment [pci]: Hen ie~ei wer<~e« _. _ _ - _ __ 6800' MD or to 4,100' MD, changeout 9%d' packoffs, and run 5-'/2 x 4 '/i' 13Cr80 completion. ofwo~~over scope MASP: 2376_psi _ - ~~~ Comment [pc2]: [sHP - v. i psi~ft x _ __ Well Type: Producer - __ _ xsoo~ Tv~ss)1 -~ ~ Comment [pt3]: Outline of workover Proposed Procedure _ _ _ __... _- -- _ -- - -- -. _. - - Protean, 1. MIRU Doyon 14. 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. DONE 2. Pull and LD 5-'/~' x 4 '/2' tubing string. DONE 3. Run and seta 7-5/e' RBP at -6,975'. DONE Found leaks in existing 7-'/," Liner. The 9 s/e" casing above 7-5/s" Liner top at 8938' MD passed a pressure test to 3500 psi. A USIT is currently being run in corrosion mode in order to identify any highly corroded sections of 9-518" casing. If USIT shows the 9-5/8" casing is not corroded then the following change in scope is proposed: 4. Run and fully cement a 4-'/z' scab liner with Baker liner top packer set at -6,800' MD. 5. Test well to 3500 psi. Replace the 9-5/8" casing packoffs and tubing spool. 6. Drill out landing collar and cleanout to the top of sand plug at _9,750' MD. 7. Run new 5-'/2" chrome tubing completion with packer at _6,775' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test IA and Tubing to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. See attached schematic #1 If USIT shows areas of highly corroded 9-5/8" casing then the following plan is proposed: 11. Run and fully cement a 4-'/2 scab liner with Baker liner top packer set at -6,800' MD. 12. Run and fully cement a 7-%e' scab liner with Baker liner top packer set at -4,100' MD. 13. Test well to 3500 psi. Replace the 9-5/8" casing packoffs. 14. Drill out landing collar and cleanout to the RBP. 15. Pull RBP. 16. Run new 5-'/i' x 4-'/z Chrome tubing completion with packer at 6,775' MD. 17. Displace the IA to packer fluid and set the packer. 18. Test IA and Tubing to 3500 psi. Freeze protect to 2200' MD. 19. Set BPV. ND BOPE. NU and test tree. RDMO. See attached schematic #2 Post Ria Work O 1 Install wellhouse and flowline. Pull BPV. S 2 Pull Ball and Rod, set GLVs, and ull RHC. C 3 Cleanout sand to 10,618' MD bottom e • .C= -31S NR.CtlVY VCIV4 LLHEAD- CAMERON TUATOR= ... _ ... OT5 ..................... _................... ............_.._ _ ELEV = 52' ELEV = ._.......... P = 1100' x Ankle..° ...... .....................53 @, t 0534'. . :Ian MD = 10488' um TVD- 8800'SS 13-3l8" CSG, 88M, L-801K-55, ID = 12.415" X Proposed 09-42A 9759' 4112" X Nipple ID = 3.81" TOP OF 31f2'LNR 9e71' Minimum ID = 1.~5 ~ 10415' TOP OF 2~B" LNR 412" TB0,12.BY, 13-CR-80, .0152 bpf, ID=3.958" 9674' 7-518" CSG, 29.78, NT-95, D=8.675" 9979' TOP of F 7~ X19' • saFEn rorE:: cxeoee rec. em~srouc 19 CEMENT Im PW6. 2 6416 I5600I 36 iris' 9.5x8" X 5.12" BAKER SA BL3 PKR 6925' 9-518"X7-518°LINER SBP RCR 9720' 7.5.8"x412" Unique Overshot 9912' 9971' 7-518" X 412" BAKER SABL-3 PKR 3-12° DEPLOYNIENT SLEEVE g$qy' 9K2' 4117' HES X NIP (BEHIND LNR) 412" HES XN NIP (BEHIND LNR) 9STO' 412" NULESHOE TT (BEHND LNR) ~7Y 7-5.8"X7" BAKER TIE BACK SEAL ASSY -~3-12"X3-3!18"X0 ~ 7" X 9-518° WAJDCWV 9979' 9-58" C56, PERFORATION SUMMARY Rff LOG: NJDUCTION LOG Ohl D41D5199 ANGLE AT TOP PERT 45 ~ 10420' Note: Refer to Prodl-IGion DB for historical art date SIZE SPF INTERVAL OpnlSgz DATE 1-11 M 6" 4 10420 - 1043D O 04118!99 1-11 M 6" 4 10488 -10506 0 04M 8199 9 -11 M 6" 4 10555 -10566 O 04M Bf~ 1-11 M 6" 4 10608 -10616 0 04M 6199 OF 3-3718° LNR i~ 99!2' TOP OF 2-318' LNR ~~ 33118' LNR, 8.21M, L-80, .0078 bpf, ID - 2.80" " LNR 4.811 L-80 .0039 b f ID = 1.996" DATE REV BY CONAEJTS DATE REV BY COMNENTS 1990 ORIONAL COMPLETION 04709199 SDETRACK® 0182191 SIS-MD FWAL 02AI8A2 RNlfP CORRECTIOt45 03730193 CJStfLH SANDBACK 05730108 DTM WELLHEAD OORRECTIgV PRUDHOE BAV LrJIT VI£LIL 09-42A PERMT No: 1990070 API No: 50-029-22099-01 SEC 2 Tt ON Ri 5E 2154.49 FEi 5270.fi BP E~wlion WdW n Schematic #I : Planned completion if USIT shows no corrosion in 9-5/8" casing • • TREE _ -3J8" MCEVOY OEN 4 LLFE'AD= CAMERON ACTUATOR = OTI"a KB. EiEV = 52' BF. ELEV = KOP = 1100' Max Afx~e_.= ..... .......................53 10534' Datum MD = 10488' Datum TVD = 8800' SS 13.318" CSG, 88Y. L-801K-55, N = 12.415" 4-12" TBG, 1 2.6A, 17-CN-M, .0232 bpf, D = TOP OF 7-S18" LNR 470D' ,.., Prapased D9-42A $7S$' 412" X Npple ID = 3.81" TOP OF 372"LNR 9D31~ Minimum ID = 1.996 ~ 10415' TOP OF 2 3B" LNR 412" TB0,12.BM, 13-C R-80, .0152 bpf, ID = 3.958" $$74' 7-518" CSO. 29.7X. NT-95. ID=8.875" ~ ~19~- LIFETI1WTEg CtMOlIE T$& MI~STOCKM CEMENT Ito PWG. = 4582" 2 6416I5600I 36 -6T75~ 9-518" X 7-516"" BAKER SABL3 PKF $$'j5' 972$' &516"X7-518"LINER SBP PICR T-518"x412" Unique Overshot g$7p 7-518" X412" BAKF3t SABL-3 PKR 9$31' 3-12" DEPLOYMENT SLEEVE J$4§' 412" HES X NIP (BEHIND LNR) ~2' 41fY' HES XN NIP (BEHND LNR) g$7q' 412" MULESHOE TT (BEHND LNR) NN12' 7-5A" X7" BAKER TIE BACK SEAL ASSY ~3-12"X3-311C'XO 7" X 9-516" WINDOW 9979' 8-5/8" CSO, 47X, L-80, ID = 29M, L-80, .0371 bpf, D = PERFORATbN SUMMARY Rff LOG: 4JDLX:TX)N LOG ON 04X5199 ANGLE AT TOP PERF: 45 ~ 10420' Nate: Refer to Produd'wn ~ for histw'ical dale SIZE SPF INTERVAL OpnSgz DATE t-11ns" a 1aazD-1Da3D o o4nsss 9 -11 n 6" 4 10488 -10506 0 04n 8f99 1-11 n 6" 4 10555 -1056 0 04n 8189 1-11 n 6" 4 10608 -10616 0 04M 8199 0087 bpf, D = 3.3118" LNR, 8.2/, .OWB bpf, b = 2.81 DATE REV BY COMMEIJTS DATE REV BY COMaENTS 1990 ORKYNAL COMPLETION 04N9r89 SDETRACK® 01 f221D1 SISMD FNAL 02A&112 RNJfP CgiftECTIONS 031301U3 CJSITLH SANDBACK O.Sf30N6 DTM VvELLHEAD ODRRECTION =1.aw° PRUDHOE BAY L%'UT WELL: 09-02A PERNIT ND:'199D070 API No: 50-029-22098-01 SEC 2 T10N R15E 2154.49 FEL 470.E ". $P E1gdw~nWd9q Schematic #2: Proposed completion if USIT shows areas of 9-5/8" casing which are highly corroded. ~ • Page 1 of 1 Hubble, Terrie L From: Maunder, Thomas E (DOA) [tom.maunder@alaska.gov] Sent: Sunday, May 25, 2008 12:55 PM To: Hubble, Terrie L Subject: FW: DS 09-42A (199-007) I got a bounceback from Sondra. Yes, I am in here on Sunday. The phone is not ringing. Hope you have a good weekend. ,.... .: Tom _.... ..... From: Maunder, Thomas E (DOA) Sent: Sunday, May 25, 2008 12:52 PM To: Frazier, Nicholas B 4_ ~~~E^ Cc: 'Stewman, Sondra D'; 'Dave Reem' ~~~`~~;~~~~~~,;: ~`.`i~i:t ~ Subject: DS O4-42A (199-007) Nick, I am reviewing the 404 submitted for the workover recently completed in March. It does not appear that the new 4-1/2" scab liner is included in the detail in block 11. Also, the completion drawing submitted appears to be "pre-workover". Would you work with Sondra to revise and send in the correct information? Thanks in advance. Email will be fine. Call or message with any questions. Tom Maunder, PE AOGCC ~ ~~~ ~ ~c~ ~ ~ ~ ~. c~-~- ~,(,~ D . ~o~~o~c ~,S ~ ~~t~.~ ~ `~-~- S~, ~ ~.a s ~ ~~~~s~~ ~~ ~ ~~~ ~~ ~rs , ~~e~~ ~~e~~ ~~ s~ ~ ~ ~~s~- ~ ~ ~ ~s c~ ~~ ~ r~m is cc~~ r~2 c~-~- .`t~ ~k ~ n ~e~~~ ~ ~ . y ~~.~- ~. ~ ~~.~ 5/27/2008 STATE OF ALASKA ~c ~ a~~ ALAS~IL AND GAS CONSERVATION ~R~RA ~+~ REPORT OF SUNDRY WELL OPE~~TI~~l~ppg Corrected: 05/28/08 1. Operations Performed: ~jE~ ~?~ G,~, G0~1S• ~~~i ` ~~~ ^ Abandon ~ Repair Well ~ ^ Plug Perforations Stimu~i~~rpf~a~~~ Re-Enter Suspended 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 Dritl Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 199-007 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-092-22059-01-00 7. KB Elevation (ft): 52, 9. Well Name and Number: PBU 09-42A 8. Property Designation: 10. Field / Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10820' feet true vertical 9082' feet Plugs (measured) 9749' (Top of Sand) .~_ Effective depth: measured 10785' feet ~ Junk (measured) N/A true vertical 9055' feet a- Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 3984' 13-3/8" 3984' 3585' 4930 2270 Intermediate gg7g~ g-5/8" 9979' 8479' 6870 4760 Production Liner 3054' 7-5/8" x 7" 6925' - 9979' 6008' - 8479' 8160 5120 Liner 584' 3-1/2" x 3-3/16" 9831' - 10415' 8355' - 8802' 10160 10530 Liner 425' 2-3/8" 10395' - 10820' 8789' - 9082' 11200 11780 -~ Scab Liner 2927' 7-5/8" x 4-1/2" 6804' - 9731' 5911' - 8273' 6890 4790 Perforation Depth MD (ft): 10420' - 10618' Perforation Depth TVD (ft): 8806' - 8934' 5-1/2", 17# 13Cr80 6834' Tubing Size (size, grade, and measured depth): 4-112" 12B# Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker S3 Packer 6728' 7-5/8" x 4-1/2" Baker SABL-3" packer 9812' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 9720'. Run 7-5/8" x 4-1 /2" (29.7# / 12.6#, L-80) scab liner from 6804' to 9731'. Cement w/ 100 bbls Class 'G' 561 cu ft/ 484 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 50 0 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 Nick Frazier, 564-5633 308-050 Printed Name Terrie Hubble Title Drilling Technologist ~p Prepared By Name/Plumber: ~ Signature Phone 564-4628 Date `ti (~STerrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ~ ubmit Original Only ~ ~~- ~'~~'~ ~ ~ 2?D° ~l~-~'~ TREE = 6-3/8" CNV WFILHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV - _52 BF. ELEV _ KOP = 1100' Max Angle = 53° @ 10534' Datum MD = 9961' Datum ND = 8800' SS ~ 13-3/8" CSG, 68#, -j 50~ r K-55, ID = 12.415" 20" CONDUCTOR, 94#, H-40, ID = 19.124" 112~ 13-3l8" CSG, 68#, L-80 BTC, ID = 12.415" 3983~ 5-1/2" HES X NIP, ID = 4.562" Minimum ID = ~.995 @ 10395~ 6728~ 9-5/8"X5-1/2"BKRS-3PKR,ID=4.75" TOP OF 2-3~8~~ LN R 6752~ 5-1/2" HES X NIP, ID = 4.562" 9-5/8" X 7-5/8" BRK HRD ZXP LTP 6804' 6811 ~ 5-1 /2" HES XN NIP, ID = 4.455" wlBKR FLEX LOCK LNR HGR, ID = 6.77" 5-1/2" TBG, 17#, 13CR-80 VAM TOP, 6834' 6834~ 5-1/2" MULESHOE, ID = 4.892 .0232 bpf, ID = 4.892" 6836~ 7-5/8" X 7" XO, ID = 6.25" TOP OF 7-5/8" SCAB LNR 6925~ 6837' 7" X 4-1/2" XO, ID = 3.958" 4-1/2" LNR,12.6#, 13CR-80 NSCT XO TO L-80 BTC 9601' 6925~ 9-5/8" X 7-5/8" BPK SBP PKR 4-1/2" LNR,12.6#, L-80 BTC, .0152 bpf, ID = 3.958" 9716~ w/ FLIX-LOCK LNR HGR, ID = 6.88" 4-1/2" TBG CUT (03/14/08) 9720' 9731~ 7-5/8" X 4-1/2" UNIQUEOVERSHOT SANDBACK TAGGED 03/09/08 9749' 9751 ~ 4-1/2" HES X NIP, ID = 3.813" ( ) TOP OF 3-112" LNR 9831' 9812~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.88" 4-1/2" TBG,12.6#, 13CR-80, .0152 bpf, ID = 3.958" 9874' 9831~ 3-1/2" DEPLOY SLV, ID = 3.00" 7-5/8" SCAB LNR, 29.7#, NT95HS, 9920' 9845~ 4-1/2" HES X NIP, ID = 3.958" gEHIND 0459 bpf, ID = 6.875" 9$62' 4-1/2" HES XN NIP, ID = 3.813" CT LNR 9-5/8" X 7" BKR TIE BACK SEAL ASSY 9921' 9874~ 4-1/2" MULESHOE, ID = 3.958" 9-5/8" X 7" BKR BOT "H" LTP 9929' 9920~ 7-5/8" BKR TIE-BACK SEAL ASSY, ID = 6.19" w/ BOT HY DRO LNR HGR, ID =? 9972' 3-1 /2" X 3-3/16" XO, ID = 2.786" 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" 9972~ 7" X 9-5/8" MILLOUT WINDOW (09-42A) 9979' 9-5/8" CSG, 47#, L-80 BTC, ID = 8.861" 10239~ l 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10688' 10395~ 2-3/8" DEPLOY SLV, ID = 1.995" PERFORATION SUMMARY REF LOG: INDUCTION LOG ON 04/05/99 ANGLE AT TOP PERF: 92° @ 10420' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn(Sqz DATE 1-11(16" 4 10420 - 10430 C 04/18/99 1-11/16" 4 10488 - 10508 C 04/18/99 1-11/16" 4 10555- 10565 C 04/18l99 1-11/16" 4 10608 - 10618 C 04/18/99 TOP OF THE 2-3/8" LNR ~~ 10395~ 09-42A 3-3/16" LNR, 6.2#, L-80, I~ 10415, .0076 bpf, ID = 2.80" ~ 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.995" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/90 N28E ORIGINAL COMPLETION 07/31/94 D16 RWO 04/09/99 N28E CTD SIDETRACK "A" 03/26/08 D-14 RWO 04/15/08 NBF/PJC DRLG DRAFT CORRECTIONS 04/18/08 /TLH GLV C/O (03/31/O8) PBTD I-I 10784' PRUDHOE BAY UNff WELL: 09-42A PERMff No: 1990070 API No: 50-029-22059-01 SEC 2, T10N, R15E, 1939' FSL & 1073' FEL BP 6cploration (Alaska) SAFEf TES:*** 4-1/2" CHROM ETBG **WHIPSTOCK IN CEJI~KO PLUG. 5-1/2" HES X NIP, ID = 4.562" ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 4000 6677 3812 6049 32 33 MMG MMG DOME SO RK RK 16 20 3/31 /08 3/31 /08 ~ -~~ ~?~:~1~I~J'~t~ ~~ STATE OF ALASKA ~ f'1~~~ ~I' ALAS~IL AND GAS CONSERVATION COMMI N APR 2 1 2008 "~ REPORT OF SUNDRY WELL OPERATIONS ~~iaska Oil ~ Gas Cons. Com~nission 1. Operations Pe med: f~C~10f~@ ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved P ram ^ Operation Shutdown ^ Perforate ^ Time E~ension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 199-007 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, ska 99519-6612 50-092-22059-01-00' 7. KB Elevation (ft): 2, ~ 9. Well Name and Number: PBU 09-42A ` 8. Property Designation: .~i ~ 10. Field / Pool(s): . ADL 028324 do?1T3o2~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10820 ' eet true vertical 9082 ~ t Plugs (measured) 9749' Effective depth: measured 10875 fee Junk (measured) N/A true vertical 9123 feet Casing Length Size MD ND Burst Collapse Structural Conductor 112' 20" 112' 112' 1490 470 Surface 3984' 13-3/8" 3984' 3585' 4930 2270 Intermediate gg7g~ g_5/8" 9979' 8479' 6870 4760 Production Liner 3054' 7-5/8" x 7" 6 '- 9979' 6008' - 8479' 8160 5120 Liner 584' 3-1/2" x 3-3/16" 983 10415' 8355' - 8802' 10160 10530 Liner 425' 2-3/8" 10395 820' 8789' - 9082' 11200 11780 ~~~~~~~~~ ~~; 1` or ~.:: PerForation Depth MD (ft): 10420' - 10618' ' ' ~ f~~ ~%r~ Perforation Depth TVD (ft): 8806 - 8934 ~„~ : _ ~_.: =~-, 5-1/2", 17# 13Cr80 6834' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker S3 Packe 6728' 7-5/8" x 4-1 /2" Baker SABL-3" pa r 9812' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 9720'. Run 7-5/8" (29.7#, L-80, TC-I I) scab liner from 6804' to 9920'. ment w/ 100 bbls Class 'G' (561 cu ft/ 480 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera e Production or 'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casi Pressure Tubin Pressure Prior to well operation: 0 0 0 0 Subsequent to operation: 0 0 0 ' 50 0 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Develo ent ^ Service ~ Daily Report of Well Operations ~ 6. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ J ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number o/A if C.O. Exempt: Contact Nick Frazier, 564-5633 30 50 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Nam Number: ~"~~"~~ nature -~ Phone 564-4750 Date , Sondra Stewman, 5-4750 Form 10-404 Revised 04/2 Submit Orig al Only ~~a~ • TREE = 6-3/8" CIW WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 52' BF. ELEV - KOP = 1100' Max Angle = 53° @ 10534' Datum MD = 9961' Datum ND = 8800' SS 13-3/8" O~G, 68#, K-55, ID -~.415" ~20" CONDUCTOR, 94#, H-40, ID = 19.124"~ 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" Minimum ID = 1.995 @ 103 TOP OF 2-3/8" LN R 9-5/8" X 7-5/8" BRK HRD ZXP LTP w/BKR FLIX LOCK LNR HGR, ID = 6.77" 5-1/2" TBG, 17#, 13CR-80 VAM TOP, .0232 bpf, ID = 4.892" TOP OF 7-5/8" SCAB LNR 4-1/2" LNR,12.6#, 13CR-80 NSCTXO TO L-80 BTC 4-1/2" LNR,12.6#, L-80 BTC, .0152 bpf, ID = 3.958" 4-1/2" TBG CUT (Q3/14/08) SANDBACK (TAGGED 03/09/08 ) TOP OF 3-1/2" LNR 4-1/2" TBG,12.6#, 13CR-80, .0152 bpf, ID = 3.958" 7-5/8" SCAB LNR, 29.7#, NT95HS, .0459 bpf, ID = 6.875" 9-5/8" X 7" BKR TIE BACK SEAL ASSY 9-5/8" X 7" BKR BOT "H" LTP w/ BOT HYDRO LNR HGR, ID =? ~ I 50' I 112' 3983' ~ sl so~' I 9716' 9~ 831, I 9874' 9920' I 9921' I 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" ~-~ 9972~ 9-5/8" CSG, 47#, L-80 BTC, ID = 8.861" ~-~ 10239~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: INDUCTION LOG ON 04/05/99 ANGLE AT TOP PERF: 92° @ 10420' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 10420 - 10430 C 04/18/99 1-11/16" 4 10488 - 10508 C 04/18/99 1-11/16" 4 10555 - 10565 C 04/18/99 1-11/16" 4 10608 - 10618 C 04/18/99 TOP OF THE 2-3/8" LNR ~ 10395~ 3-3/16" LNR, 6.2#, L-80, -~ .0076 bpf, ID = 2.80" SAFET TES:*** 4-1/2" CHROM E TBG **WHIPSTOCK ~ IN C~KO PLUG. 5-1/2" HES X NIP, ID = 4.562" !]A C I IFT AAG Nf1RFl C ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4000 6677 3812 6049 32 33 MMG MMG DOME SO RK RK 16 20 3/31/08 3/31 /08 5-1/2" HES X NIP, ID = 4.562" 9-5/8" X 5-1/2" BKRS-3 PKR,ID= 4.75" 5-1/2" HES X NIP, ID = 4.562" 5-1/2" HES XN NIP, ID = 4.455" 5-1/2" MULESHOE, ID = 4.892 7-5/8" X 7" XO, ID = 6.25" 7" X 4-1/2" XO, ID = 3.958" 9-5/8" X 7-5/8" BPK SBP PKR w/ FLIX-LOCK LNR HGR, ID = 6.88" 7-5I8" X 4-1/2" UNIQUE OVERSHOT 4-1/2" HES X NIP, ID = 3.813" 9812~ --I7" X 4-1/2" BKR S-3 PKR, ID = 3.88" 9831~ 3-1/2" DEPLOY SLV, ID=3.00" 9845~ 4-1/2"HESXNIP,ID=3.958" IND gEH 9$62' 4-1/2" HES XN NIP, ID = 3.813" CT LNR 9874' 4-1/2" MULESHOE, ID = 3.958" gg2p' 7-5/8" BKR TIE-BACK SEAL ASSY, ID = 6.19" ' gg72' 3-1/2" X 3-3/16" XO, ID = 2.786" 7" X 9-5/8" MILLOUT WINDOW (09-42A) 9979' `'?~ T ,~f~#1G,3.~' ~~~ D ~~ .,..-~.,~.,~.,..><,~. - ~...~.,-• , 10395' 2-3/8" DEPLOY SLV. ID = 1.995" 10415, ( \~ ~Tp 10784' 2-3/8" LNR, 4.6#, L-80, .0039 bpf, ID = 1.995" ~-~ 10822~ DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/90 N28E ORIGINAL COMPLETION 07/31/94 D76 RWO 04/09/99 N28E CTD SIDETRACK "A" 03/26/08 D-14 RWO 04/15/08 NBFlPJC DRLG DRAFi' CORRECTIONS 04/18/08 /TLH GLV GO (03/31/08) PF2UDH0 AY UNff WELL: 09 2A PERMff No: 199 70 API No: 50-02 -22059-01 SEC 2, T10N, R15E, 1939' FSL & 1073' FEL BP Exploration (Alaska) 09-42A pigital" Well File ~ ~ Well: 09-42 Well History Well Date Summary 09-42A 3/3/2008 T/IA/OA=O/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU HP bleed tool onto THA test void 1500 psi bled to 0 psi. Pressure void to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi cycle and torqued LDS "Standard" all moved with no problems. RD test equipment re installed Alemite cap. PPPOT-IC RU HP bleed tool onto IC test void 50 psi to 0 psi. Pressure void to 3500 psi for 30 minute test, 3500/ 15 mins, 3500/ 30 mins. Bleed void to 0 psi Did not cycle LDS " N style " all were in good visual condition. RD test equipment re-installed Alemite cap. 09-42A 3/3/2008 T/I/O =?/50/0+. Temp = SI. Shoot TBG & IA FL and monitor WHPs (pre-Coil for RWO). A/L spool dropped. IA FL C~ 216' (10 Bbls). 'Note: Unable to get TP or Tbg FL.' 09-42A 3/3/2008 CTU #8 Sand clean out for RWO. MIRU coil tubing unit 09-42A 3/3/2008 T/I/O = 220/50/0+. Temp = SI. Shoot TBG & IA FL's and monitor WHP's (pre-Coil for RWO). TBG FL C~3 570' (14 bblsl. IA FL @ 220' (10 bbls). OA FL near surface. Small amount of crude found in cellar @ the 12 o'clock position o t e tree. eater placed in cellar to thaw frozen gravel. DSO has been notified. 09-42A 3/4/2008 CTU #8 Cont' WSR from 3/3/08 (Sand plug clean out for RWO ) Ta sand to at 9320'. Clean out down to 9852z With 2.5" DJ nozzle. Freeze protect well to 2500' with 60/4 met . ttemqt to trest remaining _ sand plug to 1500 psi failed. Stand injector back to allow slickline access to rig up for rid~~`~o~in progress" ' 09-42A 3/4/2008 CTU #8 Conf WSR from 3/3/O8 Sand plug clean out for RWO 09-42A 3/4/2008 CTU #8 Conf WSR from 3/3/08 (Sand plug clean out for RWO ) Ta sand to at 9320'. Clean out down to 9852. Freeze protect well to 2500' with 60/40 meth. Attempt to trest remaining san p ug to 1500 psi failed. Stand injector back to allow slickline access to rig up for drift. ""job in progress"' 09-42A 3/4/2008 T/I/0= 09-42A 3/4/2008 "' WELL SHUT IN ON ARRIVAL"' RAN 3.70" CENT. & 3.80" LIB S/D C~3 9,308' SLM. RAN 3.70" CENT. & 3.70" LIB S/D C~3 9,318' SLM ~,,.~ ., ~„~~ ,.~.~r ~„ ~„~~ ~~~ ~,~ ~„,.~,,, ~~ .. 09-42A 3/4/2008 CTU #8 Cont~ WSR from 3/3/08 Sand plug clean out for RWO'~~~~~~~Job in progress ~~~~"~~~~ 09-42A 3/5/2008 "'CONT. WSR FROM 03-04-08"'" RAN 3.25" CENT. & 2.80" LIB. S/D @ 9,675' SLM. MARKS AROUND OUTSIDE OF BLOCK. (TUBING BUILD-UP) RAN 2.5" CENT. & 1.750" LIB. S/D G 9.675' SL.~4. ~ UNKNOWN MARK ON OUTER EDGE OF BLOCK. `"'NOTIFY DSO"~ 09-42A 3/5/2008 CTU #8, FCO; Cont` WSR from 3/4/08 ... Slickline is drifting well to confirm clean out depth. Slickline unable to get past 9675` W/ 2.80" LIB or 2.50" LIB. Suspect scale. RIH with WFD 2 3/8" PDM with 3.80" 3-blade bullnose junk mill. Drv tap down at 9708' ctmd. Was_hed easilv down to 9855' ctmd, siqnificantly deeper than the 3 1/2" liner to 9831' md . Several dry tags indicate a moving bottom, possibly sand. Som- e de~inite ove~rii it sta s were also encountered while PUH. Elect to POOH with mill and RBIH with nozzle to do additional FCO. OOH. No visible wear on mill. RIH with 2.50" JSN. ConY on 3/6/08 WSR ... 09-42A 3/5/2008 CTU #8 Conf WSR from 3/4/08 Slickline is drifting well to confirm clean out depth STBY."""~~~~~"Job in progress`"""`` 09-42A 3/5/2008 Travel to location 09-42A 3/6/2008 CTU #8 FCO "'Job ConY from 3/5/08 WSR'** InterACT publishing RIH with 2.50" JSN. Dry Tag @ 9710' ctmd. Jet fill with 10 bbis FloPro to 9855' ctmd. Repeat pass with 10 bbl FloPro pill. POOH C~3 80%. Freeze protect well from 2000' with 60/40 methanol. RDMO. Notify operator of well status. "'Job Complete*" 09-42A 3/6/2008 "*WELL SHUT IN ON ARRIVAL'*' DRIFTED W/ 3.695" SWAGE, 1.5" SAMPLE BLR TO 9725' SLM. 'BAILER EMPTY, NO MARKS' DRIFTED W/ 3 1/2" BRUSH 2 5" CENT 1 5" SAMPLE BLR TO 9725' SLM_ `BAII FR Flll I c~F SAND' CURRENTLY RUNNING IN W/ 4.4" LIB TO TAG XO "`CONTINUE WSR ON 3-7-08"' 09-42A 3/6/2008 Standby for CTU to complete FCO. Called to asisst slickline on END4-04. Will return post CTU rig down. Page 1 of 2 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 4/19/2008 Digital Well File 09-42A 3/6/2008 T/I/0= 160/80/0 Temp=S/I MIT OA PASSED to 2000 psi (PRE RWO) Pressured up OA to 2000 psi w/ 4.4 bbls crude. 1st 15 min OAP lost 40 psi, 2nd 15 min OAP lost 10 psi with a total of 50 psi loss in 30 min test. Bled back 3 bbls crude. Final WHP's= 160/80/0 "Annulus casing valves tagged and left open on departure" 09-42A 3/7/2008 "'CONTINUED FROM WSR 3-6-08'*' RAN 4.4" LEAD IMPRESSION BLOCK TO TRSSSV, COULDN'T SKIP PAST. RAN 4.0" GAUGE RING TO 5 1/2" X 4 1/2" CROSSOVER C~ 6884' MD. 6872' SLM. 12' CORRECTION. RIG DOWN "'WELL LEFT S/I, DSO NOTIFIED'*~ 09-42A 3/7/2008 '""WELL SHUT-IN UPON ARRIVAL"' RAN 3.65" SCP POWER CUTTER TO 9720' AND CUT TUBINC. TAGGED SAND TOP AT 9749' DEPTH REFERENCED TO TUBING TALLY. CONFIRMED CUTTER FIRED AFTER POOH, RDMO, DSO NOTIFIED WELL SHUT-IN AND SECURE. FINAL T/I/0 = 100/100/0 *"JOB COMPLETE*" 09-42A 3/7/2008 Load and travel. Stand by for Hardline "*Continued on 3-8-08"' 09-42A 3/8/2008 T/I/0=300/100/0 Circ ouUBullhead - Freeze protect. LLR IA of 1.0 bpm @ 2200 psi [Pre RWO] Pumped 5 bbls neat meth, 310 bbis 9.8# NaCI brine & 5 bbl diesel cap down tubing to IA through jumper line down flowline.. Bullhead 354 bbls 9.8# NaCL brine & 10 bbl diesel cap down IA through PC leak. Freeze Protected flowline w/ 5 bbls neat meth, 76 bbls crude and flushed S-Riser w/ 10 bbls diesel. . FWHP's=O+Nac/0 "Wellhead valves checked for position and tags hung upon departure`* 09-42A 3/9/2008 Set 6 3/8" CIW BPV# 421 C~ 108" for Pre-Rig. T/I/O/=200/0/0 09-42A 3/12/2008 Pull 6" ciw bpv thru tree Rig job 09-42A 3/13/2008 Pulled 6" CIW J TWC post BOP test for poyon 14. 1-2' ext. tagged @ 114"...no problems. 09-42A 3/25/2008 T=O; Pulled 6-3/8" CIW "J" TWC thru tree, 1-2' ext. used, tagged @ 108'; "'Complete"" (Best/Wortham) 09-42A 3/25/2008 T=O; Set 6-3/8" CIW "J" BPV thru tree; 1-2' ext used, tagged @ 108"; ""Complete"' (BesUWortham) 09-42A 3/30/2008 '"'WELL S/I ON ARRIVAL'"' (POST RWO) STANDING BY FOR VECO TO PULL BPV. "*CONT. WSR ON 03/31/08*" 09-42A 3/30/2008 T/I/0=0/0/0; Pulled 6-3/8" CIW 'J' BPV thru tree; 1-2' ext. used, tagged C~ 108"; "'Complete"' (BesUWortham) 09-42A 3/31/2008 ""CONT. WSR FROM 03/30/08"' PULLED BALL & ROD FROM 6,780' SLM. PULLED STA #2 1.5" RKP VALVE. PULLED STA #1 1.5" DUMMY VALVE. SET 1.5" DOME VALVE, 16/64" PORTS, TRO 1500, STA #2. SET 1.5" SCREENED ORFICE, 20/64" PORTS. STA #1. PULLED 5.5" RHC PLUG BODY FROM 6783' SLM. RIG DOWN TURN WELL BACK TO DSO. "' NOTIFY DSO OF DEPARTURE*". Print Date: 4/19/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer. aspx Page 2 of 2 4/19/2008 ~ ~ BP EXPLORATION Page 1 of 11 Operations Summary Report Legal Well Name: 09-42 Common Well Name: 09-42 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 ~ ~ ~ ~ ~ 3/11/2008 I 12:00 - 14:00 I 2.001 RIGD I P 14:00 - 16:00 2.00 MOB P 16:00 - 17:30 1.50 RIGU P 17:30 - 18:00 I 0.50I RIGU I P 18:00 - 00:00 I 6.00 I WHSUR I P 3/12/2008 00:00 - 00:30 0.50 WHSUR P 00:30 - 02:30 2.00 WHSUR P 02:30 - 05:30 I 3.001 WHSUR I P 05:30 - 06:00 0.50 WHSUR P 06:00 - 07:30 1.50 WHSUR P 07:30 - 09:30 I 2.001 WHSUR I P 09:30 - 10:30 I 1.001 WHSUR I P 10:30 - 14:30 ~ 4.00 ~ BOPSU F~ P 14:30 - 19:30 ~ 5.00 ~ BOPSU F~ P 19:30 - 20:30 I 1.001 BOPSURN 20:30 - 23:30 3.00 BOPSU N 23:30 - 00:00 0.50 BOPSU P Spud Date: 7/17/1990 Start: 3/9/2008 End: 3/26/2008 Rig Release: 3/26/2008 Rig Number: NPT Phase Description a# Operations PRE -Blow down lines in cellar -RD circulating lines -Skid rig floor to moving position PRE Move rig f/ well 09-23A to well 09-42A. Spot rig over well PRE -Shim rig -Lay herculite. Spot and berm rock washer -Skid rig floor to drilling position PRE RU rig floor. Prepare pits to take in fluids. Accept riq Ca~ 18:00 3-11-2008 DECOMP -RU double valve in IA -RU hard line to tiger tank. Blow air through line and then warm up lines. -RU to circulate out freeze protect -RU lubricator and test to 500 psi. Pull BPV. RD lubricator SIMOPS: load 4" DP in pipe shed. Take 9.8 ppg brine in pits. DECOMP Test hard line w/ air. Test w/ water to 3,500 psi. Good test DECOMP Displace out freeze protect: -Pump 20 bbls 9.8 ppg brine down IA, taking returns through tubing out to tiger tank. 168 gpm / 560 psi -Swap lines. Pump 40 bbls 9.8 brine down tubing, taking returns from IA out to tiger tank. 168 gpm / 540 psi -Shut down pump. Let diesel migrate for 30 min -Pump 30 bbls 9.8 ppg brine down tubing, taking returns from IA out to tiger tank. 168 gpm / 620 psi DECOMP -RU lines to take returns back to pits -Circulate well w/ 9.8 ppg brine surface - surface. 168 gpm / 420 psi -Blow down lines DECOMP Confirm well dead. _Install TWC DECOMP -Test TWC f/ below to 1,500 psi x 30 min on chart, bullheadinq 36 bbls ~ +/- 1 bpm. -Fill tree. Test TWC f/ above to 3,500 psi x 10 min on chart DECOMP -Vac out tree -ND tree. Remove tree f/ cellar DECOMP -Cameron tech cut control line and install bullplugs in tubing hanger -ND adapter flange DECOMP NU spacer spool, BOP stack, riser and flow line. C/O choke line spool f/ 12" to 18". Install mouse hole. MU floor valves in preparation for testing. Center up BOP stack DECOMP Test BOP and related eauipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3,500 psi high x 5 min each on chart. Test w/ 4" test joint. Test top rams w/ 4" test joint and 5-1/2" test joint. Perform koomey test. Test witnessed by WSL, Toolpusher and AOGCC rep. (Chuck Scheve). - Top rams test failed when testing w/ 5-1/2" test joint. RREP DECOMP -Vac out stack -Pull top rams -C/O 3-1/2" x 6" inserts in top rams -Install top rams RREP DECOMP IBOP not actuating. C/O IBOP DECOMP RU to test top rams w/ 5-1/2" test joint. Printed: 4/11/2008 1228:51 PM ~ ~ BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code N'PT Phase Description of Operations 3/13/2008 00:00 - 01:30 1.50 BOPSU P DECOMP Test top rams, IBOP and manual choke valve to 250 psi low - 3,500 psi high x 5 min each on chart. Test top rams w/ 5-1/2" and 4" test joints. Test witnessed by WSL and Tourpusher. 01:30 - 02:00 0.50 BOPSU P DECOMP RD testing equipment. PU lubricator, rods and hydraulic lines 02:00 - 04:00 2.00 WHSUR P DECOMP -Set lubricator extension. MU rods and RU DSM lubricator. 04:00 - 04:30 0.50 WHSUR P DECOMP RD DSM lubricator, rods, hydraulic lines and lubricator extension. 04:30 - 05:00 0.50 PULL P DECOMP -Blow down choke line, choke manifoid and kill line -RU to pull tubing hanger: install bales and 4" DP elevator. 05:00 - 06:00 1.00 PULL P DECOMP -PU 4" DP jt. MU XOs -RIH and screw in tubing hanger -Back out LDS -Attempt to pull tubing hanger to rig floor. Pull max. 273k 06:00 - 07:00 1.00 PULL P DECOMP -Check LDS and observe one broken -Vac out stack _Rcmnva nlan ni~T Ramnva hmkan 1 I~S 07:00 - 07:30 I 0.501 PULL I P 07:30 - 09:00 I 1.501 PULL I P 09:00 - 10:00 1.00 PULL P 10:00 - 10:30 0.50 PULL P 10:30 - 20:00 I 9.501 PULL I P 20:00 - 21:00 1.00 PULL P 21:00 - 22:00 1.00 CLEAN P 22:00 - 22:30 0.50 WHSUR P 22:30 - 00:00 1.50 CLEAN P 3/14/2008 00:00 - 02:30 2.50 CLEAN P 02:30 - 04:00 1.50 CLEAN P 04:00 - 07:30 I 3.50 I CLEAN I P 07:30 - 09:30 ~ 2.00 I CLEAN ~ P 09:30 - 12:00 2.50 CLEAN P 12:00 - 12:30 0.50 CLEAN P DECOMP Pull to 310k and shear LDS portion. Pull tubing hanger to rig floor DECOMP Pump Hi-vis sweep followed by Safe Kleen and Safe Scav pills. Circulate surface-surface, 510 gpm / 550 psi DECOMP Back out and LD tubing hanger. LD 4" DP jt. DECOMP -RU to LD tubing and completion equipment. -RU control line spool DECOMP Pull and LD tubing and completion equipment: -Recover control line and 12 clamps -Tubing LD: 170 jts 5-1/2" 17# 13Cr80 FOX + 68 jts 4-1/2" 12.6# 13Cr80 NSCT + 1 g.82' cut off 4-1/2" jt. -Flare at cut: 4-3/4" -Jewelry: 5-1/2" safety valve, 2 5-1/2" GLMs, 5 4-1/2" GLMs DECOMP Clean and RD tubing equipment. Clear rig floor DECOMP Mobilize Baker BHA tools to rig floor DECOMP Install wear bushing DECOMP MU Dress Off BHA w/ washover shoe and 7-5/8" casinq scra er er Baker re . DECOMP RIH w/ Dress Off BHA on 4" DP 1x1 f/ pipe shed to +/- 2,250' DECOMP Cut and slip drilling line (59.5'). Service top drive, blocks and crown DECOMP Cont. RIH w/ Dress Off BHA on 4" DP 1x1 f/ pipe shed from 2,250' to 6,938' DECOMP Taq TOL @ 6.938'. Attempt to run through TOL. Screw in top drive. Break circulation 126 gpm / 180 psi. Rotate 1/4 turn and slack off 5k, enter TOL. Cont RIH w/ pump to 7,025'. ,Jvlake several passes w/ scraper C~? 6,975' (scraper depth) DECOMP Cont. RIH f/ 7,025' to 9,713'. Make several passes w/ scraper DECOMP Taa iunk C~3 9.713'. Screw in top drive and break circulation. Wash down and taq top of stub (~ 9,720'. Work w/ washover shoe and swallow 9.5' of stub in washpipe extensions until tagging top of stub w/ dress off mill. Dress off top of stub with dress off mill to 9 721' dress off mill de th . 100 RPM / TQ 4-6k Nrintea: anvzuos 1'L:'LS:SI F'M ~ • BP EXPLORATION Page 3 of 11 Operations Summary Repart Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date` From - To Hours Task Code NPT Phase Description of Qperations 3/14/2008 12:30 - 14:30 2.00 CLEAN P DECOMP PU and circulate Hi-vis sweep surface - surface. 330 gpm / 1540 psi. R&R @ 30 RPM / TQ 2K. -PUW: 187k / SOW: 147k / ROTW: 162k 14:30 - 20:00 5.50 CLEAN P DECOMP POOH to BHA. Stand back DCs. 20:00 - 21:30 1.50 CLEAN P DECOMP LD BHA. Clean junk baskets (metal, oily sand). Clear rig floor of BHA tools. 21:30 - 22:00 0.50 DHB P DECOMP PU and MU 7-5/8" RBP 22:00 - 00:00 2.00 DHB P DECOMP RIH w/ 7-5/8" RBP on 4" DP to +/- 3,300' 3/15/2008 00:00 - 02:30 2.50 DHB P DECOMP Cont. RIH w/ 7-5/8" RBP on 4" DP f/ 3,300' to 7,001'. Set RBP_ er Halliburton re . -Top of tool C~ 6,991' / COE (~ 6,995'. -Rack back stand. PUW: 145k / SOW: 120k 02:30 - 03:00 0.50 DHB P DECOMP Obtain leak rate above RBP: -Close top rams -Establish pump rate @ 1 bpm. Pressure stabilized @ 1,600 psi -Increase pump rate to 1.4 bpm. Pressure stabilized ~ 2,100 psi -18 bbls total pumped away during test. 03:00 - 05:30 2.50 DHB P DECOMP PJSM - Dump 16 sxs (800 Ibs) of 20/40 river sand (for +/-30' sand pluq in 7-5/8" liner on top of RBP) in DP C«? +/- 2 min/ 50 Ibs sx. Screw in top drive and pump 36 bbls ~ 1 bpm. Let sand settle x 1/2 hr. Tag top of sand plug ~ 6,943' 05:30 - 06:30 1.00 DHB P DECOMP POOH f/ 6,943' to 5,971'. Brine flowing out of balance through pipe. 06:30 - 07:30 1.00 DHB P DECOMP CBU and ba{ance columns. 441 gpm J 1,150 psi 07:30 - 10:00 2.50 DHB P DECOMP Cont. POOH f/ 5,971' to surface. 10:00 - 11:00 1.00 CLEAN P DECOMP -LD RBP running tool -Mob. 9-5/8" casing scraper and polish mill to rig floor -MU BHA w/ polish mill, 9-5/8" casing scraper and junk baskets. 11:00 - 13:30 2.50 CLEAN P DECOMP RIH on 4" DP to 3,950' 13:30 - 14:30 1.00 CLEAN P OECOMP Pass 9-5/8" scraper 5x up and down in int. 3,950'-4,200' while , pumping 325 gpm / 520 psi. No rotation. -PUW: 105k / SOW: 95k 14:30 - 15:30 1.00 CLEAN P DECOMP Cont. RIH f/ 4,200' to top of liner C~ 6,938' 15:30 - 16:00 0.50 CLEAN P DECOMP -Run polish mill into top of liner and polish 7' inside. -Dress off top of liner / 5-15k WOB. -20 RPM / TQ 4k. 135 gpm / 100 psi. PUW: 145k / SOW: 120k / ROTW: 132k 16:00 - 17:00 1.00 CLEAN P DECOMP Pump Fii-vis sweep and circulate surface-surface until hole clean. -600 gpm / 2,300 psi. 20 RPM / TQ 4k 17:00 - 19:30 2.50 CLEAN P DECOMP POOH to BHA 19:30 - 21:00 1.50 CLEAN P DECOMP LD polish mill BHA. Clear rig floor -Polish mill brought piece of inetal band. 21:00 - 21:30 0.50 CLEAN P DECOMP MU 9-5/8" RTTS 21:30 - 23:00 1.50 CLEAN P DECOMP RIH w/ 9-5/8" RTTS on 4" DP to 4,145' I~ 23:00 - 00:00 1.00 CLEAN P DECOMP -Set 9-5/8" R7TS ~ 4,145' -Test 9-5/8" casing above RTTS to 3,500 psi x 30 min on chart. Good test 3/16/2008 00:00 - 00:30 0.50 CLEAN P DECOMP RD testing equipment. Release RTTS ' 00:30 - 01:30 1.00 CLEAN P DECOMP RIH w/ 9-5/8" RTTS f/ 4,145' to 6,487'. Set RTTS C~ 6,487' rnmea: aii ueuuo 1G:LG:J 1 rm ~ • BP EXPLORATIO'N Page 4 of 11 Operations Surnrnary Report Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Qperations 3/16/2008 01:30 - 02:30 1.00 CLEAN P DECOMP -RU testing equipment -Attempt to test below RTTS. Pressure up to 1,100 psi w/ 1.8 s pump , not consis en with expected. Rapid bleed off. -Pressure up casing above RTTS to 3,500 psi and hold. Test consistent with previous test ~ 4,145'. 02:30 - 03:00 0.50 CLEAN P DECOMP Release RTTS. RIH f/ 6,487' to 6,836'. Set RTTS C~ 6,836' 03:00 - 03:30 0.50 CLEAN P DECOMP -RU testing equipment -Attemp to test below RTTS. Pressure up to 1,350 psi w/ 3 bbls pumped, not consistent with expected. -Pressure u casing above RTTS to 3,500 psi and hold x 30 min. Chart. Good test -RD testing equipment 03:30 - 04:00 0.50 CLEAN P DECOMP Release RTTS. RIH f/ 6,836' to 6,926' (12' above TOL). Set RTTS C~ 6,926' 04:00 - 05:00 1.00 CLEAN P DECOMP -RU testing equipment -Test casing above RTTS to 3 500 psi x 30 min on chart. Gooc test. -RD testing equipment. 05:00 - 05:30 0.50 CLEAN P DECOMP -Release RTTS -Blow down choke line and kill line 05:30 - 08:00 2.50 CLEAN P DECOMP PO w/ 9-5/8" RTTS to surface. 08:00 - 08:30 0.50 CLEAN P DECOMP -LD 9-5/8" RTTS. Mobilize off rig floor. -Clear rig floor -Clean rig mats 08:30 - 09:00 0.50 CLEAN P DECOMP -Mobilize 7-5/8" Champ 4 packer. -MU Champ 4 packer 09:00 - 13:00 4.00 CLEAN P DECOMP RIH w/ 7-5/8" Champ 4 packer to top of 7-5/8" liner 13:00 - 17:30 4.50 CLEAN P DECOMP -Enter 7-5/8" liner and set packer C~ 6,953' (COE) w/ 20k weight on packer -Pressure up below packer and aqainst RBP to 3,500 psi, -Release packer and PU out of liner. Attempt to reset it but could not pass from 6,947'. Try w/ circulation ~ 255 gpm, and reverse circulation C~ 320 gpm while rotating, but could not get ast 6 947' 17:30 - 20:00 2.50 CLEAN P DECOMP POOH w/ 7-5/8" Champ 4 packer to surface 20:00 - 21:00 1.00 CLEAN P DECOMP -Check packer coming out of the hole. Slips stuck in the set position, which was preventing the packer from re-entering the liner -PU and MU 7-5/8" RTTS 21:00 - 00:00 3.00 CLEAN P DECOMP RIH w/ 7-5/8" RTTS to 6,650' 3/17/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Cut and slip drilling line (59.5'). Service top drive, blocks, crown and drawworks. 01:30 - 02:00 0.50 CLEAN P DECOMP Cont. RIH f/ 6,650' to 6,920'. PU single f/ pipe shed. 02:00 - 04:00 2.00 CLEAN P DECOMP -Set 7-5/8" RTTS ~ 6,962' (COE ~ 6,959') -Test RBP below RTTS to 3,500 psi. Pressure bleeds 100 psi in 5 min. -Pressure up above RTTS to 2,100 psi C~ 1.6 bpm x 5 min. Rapid bleed off to 1,000 psi. Test consistent with leak rates Nnnteo: anvzuua icza:5i rrvi ~ ~ BP EXPLORATION Page 5 of 11 Operations Sumnnary Report Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Operations 3/17/2008 02:00 - 04:00 2.00 CLEAN P DECOMP -Test again below RTTS to 3,500 psi. Pressure bleeds off 200 psi in 7.5 min. 04:00 - 04:30 0.50 CLEAN P DECOMP RD testing equipment. Blow down cement line, choke line and kill line 04:30 - 05:00 0.50 CLEAN P DECOMP Release 7-5/8" RTTS. Run down and taq sand C~ 6,970' 05:00 - 07:00 2.00 CLEAN P DECOMP POOH f/ 6,970' to surface 07:00 - 07:30 0.50 CLEAN P DECOMP Service break and LD 7-5/8" RTTS 07:30 - 09:30 2.00 CLEAN P DECOMP Clear and clean rig floor. Service drawworks and iron roughneck, while waiting for instructions on next operations. 09:30 - 12:00 2.50 CLEAN P DECOMP -MU 7-5/8" RBP runnin tool -RIH to 6,935' 12:00 - 13:00 1.00 CLEAN P DECOMP -Screw in top drive and break circulation -Run down to top of sand ~ 6,971'. Wash sand away f/ 6,971' to to of RBP ~ 6 991'. -Circulate Hi-vis sweep surface - surface. -590 gpm / 2,250 psi 13:00 - 15:30 2.50 CLEAN P DECOMP -Latch on RBP C~ 6,991' and release same -Set RBP ~ 9,710' COE C~ 9,707') 15:30 - 19:00 3.50 CLEAN P DECOMP POOH to surface. 19:00 - 19:30 0.50 CLEAN P DECOMP -LD RBP running tool -MU 7-5/8" RTTS 19:30 - 22:00 2.50 CLEAN P DECOMP RIH w/ 7-5/8" RTTS to 6,990' 22:00 - 00:00 2.00 CLEAN P DECOMP -Break circulation to ensure all air out, 155 gpm / 130 psi -Set 7-5/8" RTTS ~ 6,994' (COE) w/ 20k weight on packer gTest 7-5/8" liner below RTTS, against RBP, to 3,500 psi on chart. Monitor for 30 min. Pressure drops 300 psi in 30 mir -Bleed off pressure. Release RTTS. Run down and set RT -Test 7-5/8" liner below RTTS, against RBP, to 3,500 psi on 3/18/2008 00:00 - 00:30 0.50 CLEAN P DECOMP -RD testing equipment -Release 7-5/8" RTTS -Blow down cement line 00:30 - 02:30 2.00 CLEAN P DECOMP POOH f/ 7,099' to surface 02:30 - 03:00 0.50 CLEAN P DECOMP LD 7-5/8" RTTS. Clear rig floor 03:00 - 04:00 1.00 EVAL C DECOMP -ND Flow line, riser and bell nipple -NU shooting flange 04:00 - 12:00 8.00 EVAL X WAIT DECOMP Schlumberger on location ~ 04:00. Wait on weather (tem .-41 F) to RU Schlumberger 12:00 - 15:00 3.00 EVAL X WAIT DECOMP Cont. waiting on weather (temp. -40 F) to RU Schlumberger 15:00 - 21:00 6.00 EVAL C DECOMP RU Schlumberger e-line and pressure control. Test e-line pressure control to 500 psi x 5 min. 21:00 - 22:00 1.00 EVAL C DECOMP RIH w/ USIT log on corrosion mode to 2,800'. USIT tool malfunctioning. POOH to troubleshoot tool 22:00 - 00:00 2.00 EVAL X DFAL DECOMP Troubleshooting USIT tool. 3/19/2008 00:00 - 04:00 4.00 EVAL X DECOMP Cont. troubleshooting USIT tool. Repair wire in head pin. 04:00 - 14:30 10.50 EVAL X WAIT DECOMP Wait on weather (extreme cold temperatures) to resume running USIT log 14:30 - 15:30 1.00 EVAL C DECOMP RU USIT tool. 15:30 - 22:30 7.00 EVAL C DECOMP RIH w/ USIT to 6,900'. Take USIT lop in corrosion mode f/ 6,900' to surface. Make high resolution pass in int. 5,500' - 6,020'. Printed: 4/11/2008 12:28:51 rM • ~ ` BP EXPLORATION' Page 6 of 11 Operations Summary Report ` Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date' ` From - To Hours Task Code NPT Phase Description of Qperations 3/19/2008 22:30 - 00:00 1.50 EVAL C 3/20/2008 00:00 - 01:30 1.50 EVAL C 01:30 - 02:00 0.50 EVAL C 02:00 - 06:00 4.00 CLEAN P 06:00 - 06:30 I 0.501 CLEAN I P 06:30 - 09:00 I 2.501 CLEAN I P 09:00 - 09:30 I 0.501 CLEAN I P 09:30 - 10:30 ~ 1.00 ~ CLEAN ~ P 11~:00 - 12:00 1~.00 BOPSUR P 12:00 - 14:30 I 2.501 BOPSURP 14:30 - 15:00 I 0.50 I W HSUR I P 15:00 - 22:30 I 7.501 BOPSUR P 22:30 - 23:00 I 0.501 WHSUR I P 23:00 - 00:00 I 1.001 CASE I P ~ 3/21 /2008 I 00:00 - 01:30 ~ 1.50 ~ CAS E ~ P 01:30 - 08:00 I 6.501 CASE I P DECOMP RD Schlumberger e-line and pressure control. DECOMP Finish RD Schlumberger e-line pressure control DECOMP -ND shooting flange -NU bell nipple, riser and flow line DECOMP -MU RBP retrieving tool -RIH w/ RBP retrieving tool on 4" DP to 9,681' DECOMP Screw in TD -Obtain parameters -Enaaae RBP at 9.698' - Release per HES Re~. - DECOMP ~ Observe well (static) -POH to 2,000' DECOMP Secure well -Shut down for safety / performance discussion w/ Workover Field Supt. James Willingham DECOMP Continue POH -LD RBP assembly DECOMP Pull wear ring - Install test plug and 4" test joint DECOMP Fill stack w/ water RU test equipment DECOMP Begin testing BOP -Test plug leaking - Set weight down on test plug w/ Top Drive -Test plug set down 2-3" - Attempt to pressure up w/ no success -Pull test plug and inspect -Damaged test plug due to "burr" insde tubing spool where a LDS had been previously sheared DECOMP Install new test plug -Pressure up -Energize LDS DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3,500 psi high x 5 min each on chart. Test w/ 4" test joint. Test top rams w/ 4" test joint and 5-1/2" test joint. Perform koomey test. Test witnessed by WSL and Toolpusher. AOGCC Rep. Lou Grimaldi waived witness of test. - When testing choke and kill manuals with top rams closed, observed leak on top rams. Drained stack, opened top rams and changed top seals on rams (Single mechanical barrier test plug - 9.8 ppg KW brine as second barrier) Closed top rams and continued testing. DECOMP -RD testing equipment -Install wear bushing DECOMP RU to run 4-1/2" scab liner: -C/O bales and elevators -RU compensator. DECOMP Cont. RU to run 4-1/2" scab liner: -RU tongs and torque turn equipment. -Mobilize centralizers to rig floor -MU XO for floor valves DECOMP PJSM - MU and run 4-1/2" scab liner: -MU 7-5/8" x 4-1/2" Unique Overshot w/ pup jt and Ball Seat Sub w/ pup jt. Install ball. Dump 2 sxs of river sand (100 Ibs Printed: 4/11/2008 12:28:51 PM ~ • $P EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 I Rig Name: DOYON 14 Rig Number: , Date From - To Hours Task Code NPT Phase Description of Operations 3/21/2008 01:30 - 08:00 6.50 CASE P DECOMP total) on top of ball. -Cont. MU shoe track: 1 jt 4-1/2" 12.6# L-80 IBT w/ 4- 1" holes on pin end + 4-1/2" Float Collar + 1 jt 4-1/2" 12.6# L-80 IBT w/ centralizer + 4-1/2" Landing Collar w/ XO pup jt. Bakerlok all connections in shoe track to landing collar. I~ -MU and run 4-1/2" 12.6# 13Cr80 NSCT liner w/ 1 centralizer I per jt. Torque turn all NSCT connections to 3,975 ft-Ibs. Ran ' total of 71 'oints NSCT. , 08:00 - 10:30 2.50 CASE P DECOMP LD compensator, long bales, 4 1/2" elevators I -RU short bales and 4" elevators -MU 9 5/8' x 7 5/8" liner hanaer and ZXP nacker w/ XO's to 4_ 10:30 - 11:00 0.50 CASE P DECOMP Circulate liner volume w/ 168 gpm 110 psi -PUW, SOW = 87k -Clear casing equipment f/ rig floor 11:00 - 15:30 4.50 CASE P DECOMP RIH on 4" DP to 9700' - Fill every 20 stands 15:30 - 16:30 1.00 CASE P DECOMP Screw in T.D.- Obtain parameters - PUW 177k, SOW 137k -Taq toq of 4 1/2" stub at 9719' -Attempt to go over w/ no success - PU, turn pipe 1/2 turn left - No success -PU to up to 170k - 1 turn left - No success -Hitting down w/ 5-25k making progress - Total swallow 12.5' to 9 731' 16:30 - 17:30 1.00 CASE P DECOMP LD single - PU Baker cement head -RU cement lines -RU Schlumberger 17:30 - 18:00 0.50 CASE P DECOMP Break circulation w/ 5.5 bpm 700 psi PJSM w/ all hands involved w/ cement job 18:00 - 19:00 1.00 CASE P DECOMP Give it to Schlumberger: -Pump 5 bbls of water. Test lines to 4,500 psi -Pump 100 bbls 15.8 ppg class "G" cement @ 3-5 bpm -Kick out dart w/ 5 bbls of water 19:00 - 19:30 0.50 CASE P DECOMP Switch to rig pumps: -Displace cement w/ 9.7 ppg brine @ 5-6 bpm. ICP: 160 psi / FCP: 1,400 psi -Slow pump rate to 3 bpm before shearing liner wiper plug and before bumping plug -Observe liner wiper plug shear at 618 stks up mped. Bump -CIP ~ 19:20 19:30 - 20:00 0.50 CASE P DECOMP -Pressure up to 2,800 psi after bumpinq pluq and set liner han er -Slack to 6Qk to confirm liner hanger set. -Bleed pressure off and check floats. Floats holding -Pressure u to 4 500 si to set liner to acker. -Bleed off pressure and turn DP 15x to the right to release running tool. -Pressure up to 1,000 psi. PU and observe pressure bleed off. -Bottom of 4-1/2" scab liner (Unique Overshot) ~ 9,731'. Top 20:00 - 20:30 0.50 CASE P DECOMP Circulate out excess cement, 440 gpm / 1,700 -No rotation, no reciprocation -20 bbls cement to surface. Printed: 4/11/2008 12:28:51 PM • • BP EXPLORATION 4perations Summary l Legal Well Name: 09-42 Common Well Name: 09-42 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 I"1..a..'.~. I C..i..~.,. T.. I LJ....:... I T...~..1. ~.I !'.~ ~.4.J.. I 3/21/2008 20:30 - 21:00 0.50 CASE P 21:00 - 22:30 1.50 CASE P 22:30 - 00:00 I 1.501 CASE I P 3/22/2008 00:00 - 00:30 0.50 CASE P 00:30 - 02:00 1.50 CASE P 02:00 - 03:30 1.50 CASE P 03:30 - 04:00 0.50 CASE P 04:00 - 04:30 0.50 CASE P 04:30 - 05:30 1.00 CLEAN P 05:30 - 06:00 0.50 CLEAN P 06:00 - 08:00 2.00 CLEAN P 08:00 - 11:00 3.00 CLEAN P 11:00 - 11:30 0.50 CLEAN P 11:30 - 13:30 2.00 CLEAN P 13:30 - 14:30 1.00 CLEAN P 14:30 - 15:00 0.50 CLEAN P 15:00 - 16:00 I 1.001 DHB I P 16:00 - 16:30 0.50 CLEAN P 16:30 - 17:00 0.50 WHSUR P 17:00 - 18:00 1.00 BOPSU P 18:00 - 21:00 3.00 WHSUR P 21:00 - 22:00 1.00 BOPSU P 22:00 - 23:00 1.00 BOPSU P 23:00 - 23:30 I 0.501 DHB I P 23:30 - 00:00 0.50 CLEAN P 3/23/2008 00:00 - 00:30 0.50 CLEAN P Page 8 of 11 port Spud Date: 7/17/1990 Start: 3/9/2008 End: 3/26/2008 Rig Release: 3/26/2008 Rig Number: NPT Phase : Description of Operations DECOMP LD cement head and cement hose DECOMP Circulate nut plug sweep surface - surface to clean DP and casing of cement. -600 gpm / 2150 psi -Reciprocate DP. No rotation DECOMP -Pump dry job -POOH and LD 4" DP to pipe shed. DECOMP Finish LD 4" DP to pipe shed. 87 jts total LD DECOMP Cut and slip drilling line (59.5'). Service top drive DECOMP Cont. POOH 4" DP by stands w/ liner running tool to surface DECOMP Seroice break and LD liner running tool. Clear rig floor. -Check liner running tool. Everything looking OK. DECOMP -MU flush tool. RIH and flush BOP stack. -Blow down top drive. DECOMP Mobilize tools and handlinq equipment for cleanout BHA and 2-7/8" PA DP. DECOMP RU tongs, handling tools for 2 7/8" DECOMP PU 9-3 1/8" DC's and cleanout BHA DECOMP PU 90 jts 2 7/8" PAC DP 1x1 f/ pipeshed DECOMP MU XO's & pumpout sub -Change out handling tools to 4" DECOMP RIH w/ 4" DP to +-6,650' DECOMP CBU w/ 5.7 bpm / 3,340 psi DECOMP RU & test 9 5/8" x 4 1/2" wellbore to 1 000 si f/ 10 min on chart Good test - RD test equip. DECOMP PU HES 9 5/8" Storm Packer -RIH 1 stand below rotary table -Set acker w/ 1/4 turn ri ht -Back out running tool w/ 20 turns left -POH - LD Running tool DECOMP RU & test acker from to to 1 000 i f Good test. DECOMP -Pull wear bushing -Blow down lines to stack DECOMP ND BOP DECOMP -ND tubing spool -Test packoff and tubing spool to 5,000 psi x 30 min per Cameron. DECOMP NU BOP DECOMP -Test breaks in BOP to 250 psi low - 3,500 psi hiqh x 5 min each on chart -RD testing equipment. -Pull test plug. Install wear bushing DECOMP -MU RTTS retrieving tool to 1 stand 4" DP -RIH and screw into storm packer. -Release storm acker. Pull to rig floor DECOMP -RU to test casing -Testin 9-5/8" x 4-1/2" wellbore to 3 500 si x 30 min on chz DECOMP -Finish testing 9-5/8" x 4-1/2" wellbore to_ 3,5Q0 psi. Good te~ -RD testing equipment. Blow down lines Printed: 4/11/2008 12:28:51 PM • • BP EXPLORATION Page 9 afi 11 Operations Sumrnary Report Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Qperations 3/23/2008 00:30 - 01:30 1.00 CLEAN P DECOMP Cont. RIH w/ 4" DP f/ 6,650' to 9,440'. Tag cement stringers 01:30 - 04:00 2.50 CLEAN P DECOMP -Screw in top drive. Obtain parameters PUW: 170k / SOW: 130k / ROTW: 150k -Cleanout cement stringers f/ 9,440' to 9,596'. 3 bpm / 1,240 psi. 40 RPM ( TQ 4k. 0-5k WOB _Tan nlunc Ct~ 9 F,QR' 04:00 - 15:00 11.00 CLEAN P DECOMP Control Drilling plugs and landing collar w/ 5-7k 60 rpm 3 bpm 1200 psi 4-7k tq -Drill cmnt - Ta F.C. at 9 638' Control driil w/ same parameters -Clean out & tag ball seat sub at 9,701' - Drill out w/ same parameters as above 15:00 - 15:30 0.50 CLEAN P DECOMP Rotate through 4 1/2' stub at 9,720' w/ no issues Stop rotary - Wash down through "X' nipple at 9,750' w/ no issues _T~n canri aT Q 7RR' 15:30 - 19:00 3.50 CLEAN P DECOMP -Started displacing well to seawater. PUW: 190k / SOW: 130k / ROTW: 155k -While reciprocating pipe worked up through tight point ~ 9,729'. Attempt to go back down and tag C~3 9,729'. -Mill down with slow progress f( 9,729' to 9,740'. 3-10 WOB. 60-90 RPM / 5-9k TQ w/ top drive stalling at times. 65 - 212 gpm / 450 - 2,370 psi. -Cont. dis~lacina to seawater while millinq obstruction. 19:00 - 20:30 ~ 1.50 I CLEAN ~ P 20:30 - 23:00 ~ 2.50 ~ CLEAN ~ P 23:00 - 00:00 I 1.00 I CLEAN ~ P 3/24/2008 00:00 - 02:30 2.50 CLEAN P 02:30 - 03:30 1.00 CLEAN P 03:30 - 04:30 I 1.00 I CLEAN I P 04:30 - 05:00 0.50 CLEAN P 05:00 - 07:00 2.00 CLEAN P 07:00 - 07:30 0.50 CLEAN P -Pull out to 9,680' (out ot tubing stub- in scab liner). Upserve 20-30k overpull f/ 9,740' to 9,729'. PUW back to normal observed above 9,729'. DECOMP -Drop dart to open pump out sub. Pump out sub shear open l~ 2,720 psi. -Pump Hi-vis sweep and circulate through pump out sub surface - surface until hole clean. 540 gpm / 2,000 psi. -R&R pipe on 30' f/ 9,680' - 9,710'. Pump out sub located ~ +/- 6,620' DECOMP -Pumpdryjob. -POOH and stand back 4" DP DECOMP -RU 2-7/8" DP handling equipment -Circulate to balance columns. DECOMP LD 90 jts 2-7/8" PAC DP DEGOMP -LD 9 3-1l8" DCs -Check and LD string mill, junk basket and junk mill -String mill: worn, but still with tungsten carbide left in blades. -Junk basket: broken. Pieces of inetal band, control line, pieces of the junk basket itself and other metallic trash inside. -Junk mill: completely worn out. Blades with tugsten carbide on the face are completely gone. DECOMP -RD stacked tongs and 2-7/8" PAC handling equipment -Clear rig floor of vendor tools -RU 4" DP handling equipment DECOMP -RIH 3 stands of 4-3/4" DC w/ pertorated mule shoe DECOMP RIH w/ 4" DP f/ derrick to 6,720' DECOMP -Screw in top drive and obtain parameters PUW: 155k / SOW: Nrinteo: aniiLUUa 1L:LG:S~ rm ~ ~ B'P EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: 09-42 Common Well Name: 09-42 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date Frorn - To Hours Task ` Code NPT 3/24/2008 07:00 - 07:30 0.50 CLEAN P 07:30 - 08:30 1.00 CLEAN P 08:30 - 14:30 6.00 CLEAN P 14:30 - 15:00 0.50 WHSUR P 15:00 - 16:30 1.50 RUNCO 16:30 - 00:00 7.50 RUNCO 3/25/2008 00:00 - 04:00 4.00 RUNCO 04:00 - 06:30 2.50 RUNCO 06:30 - 07:00 0.50 RUNCO 07:00 - 10:00 3.00 RUNCO 10:00 - 10:30 0.50 RUNCO 10:30 - 12:00 1.50 RUNCO 12:00 - 14:00 2.00 RUNCO 14:00 - 14:30 0.50 RUNCO 14:30 - 16:30 2.00 RUNCO 16:30 - 21:30 5.00 RUNCO Spud Date: 7/17/1990 Start: 3/9/2008 End: 3/26/2008 Rig Release: 3/26/2008 Rig Number: Phase Description of Operations DECOMP 118k -Wash down into to of liner to 6 836'.: 210 gpm / 350 psi DECOMP CBU. 600 gpm / 2,590 psi DECOMP -POOH and LD 4" DP to pipe shed f/ 6,836' to 2,551' -RIH w/ 4 stands 4" DP remaining f/ derrick -Finish POOH and LD 4" DP and 4-3/4" DCs DECOMP PuH wear bushing RUNCMP RU to run 5-1/2" tubin and com letion e ui ment: -C/O bales and elevators -RU compensator -RU tubing tongs. Install torque turn equipment RUNCMP -MU and RIH tail pipe assy: 6-1/2" x 5-1/2" wireline entry guide w/ XO pup jt+ XN nipple (RHC-M plug in) w/ XO pup jts + 1 jt 5-1/2" 17# 13Cr80 Vam Top HC tubing + X nipple w/ XO pup jts + Baker S-3 packer w/ XO pup jts + X nipple w/ XO pup jts.+ GLM assy w/ Dummy on top of tail pipe assy Bakerlok all connections below packer. Torque turn connections.. -Cont. MU and RIH 5-1/2" 17# 13Cr80 Vam Top HC tubing w/ completion equipment per running order to +/-3,880'. Torque turn all connections RUNCMP Continue to M/U and RIH 5-1/2" 17# 13Cr Vam Top HC Tbg & Completion Assy. -Run from 3,880' to 6,738' md (165 jts in the hole). -Utilize "Jet Lube Seal Guard thread compound" -Optimum torque C~ 6,580 fUlbs. -PUW= 165K, SOW= 120K. RUNCMP Enter Top Of Liner and continue running inside liner hanger. -Tag 7-5/8" x 7" XO C~3 6,839' md (run jts 166, 167 and 168). -Space out: LD 3 jts of tubing. P/U and M/U pup jts on top of jt. 165. -M/U jt 166 - Total jts run: 166. M/U Hanger. Drain stack. Land Tbg. RILDS. RUNCMP R/U to reverse circulate hot Seawater. RUNCMP Reverse circulate 160 bbls of hot (120 F) Seawater. -Reverse circulate 300 bbls of hot Seawater w/ corrosion inhibitor. -Pump ~ 126 gpm ! 250 psi. RUNCMP Dro Ball & Rod. R/U to test Tb . RUNCMP Set Packer w/ 3,500 psi hold for 30 minutes. -Bleed off Tb to 1,500 si. -Pressure u on IA to 3,500 si hold for 30 minutes. -Bleed Tbg to 1,300 psi. -Observe Shear of DCR valve ~ 2,200 psi differential. -Establish circulation rate ~ 63 gpm / 120 psi. -Increase rate to 126 gpm ! 380 psi. RUNCMP Lstall TWC & test from the bottom C~? 1,000 psi f/ 10 minutes - Pass. -Test TWC from above C«? 3 500 si f/ 10 minutes - Pass. RUNCMP Blow down lines to BOP's & suck out Stack w/ vacuum. RUNCMP Nipple down Riser, Choke, Flowline. -Nipple down Stack. RUNCMP Nipple up Adaptor flange & test to 5,000 psi f/ 30 minutes - Pass. Pfintetl: 4/11/LUUtl 1'L:'Lt3:S1 F'M ~ ~ ~ BP' ExPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: 09-42 Common Well Name: 09-42 Spud Date: 7/17/1990 Event Name: WORKOVER Start: 3/9/2008 End: 3/26/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 3/26/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ' Description of Qperations 3/25/2008 16:30 - 21:30 5.00 RUNCO RUNCMP -Nipple up Tree & test to 5,000 psi f/ 10 minutes - Pass. 21:30 - 23:00 1.50 RUNCO RUNCMP PJSM. Rig up Hot Oil. -Transfer 150 bbls of diesel from Tanker to pump truck. -Test lines to 2,500 psi - Pass. 23:00 - 00:00 1.00 RUNCO RUNCMP Freeze protect well with 150 bbis of diesel ~ 1~0 F. -Reverse pump rate 84 gpm / 900 psi. 3/26/2008 00:00 - 00:30 0.50 RUNCO RUNCMP Pump 100 F diesel (6.8 ppg) to freeze protect well. -Reverse pump rate 84 gpm! 1,100 psi. 00:30 - 02:00 1.50 RUNCO RUNCMP R/U jumper line. -U-tube diesel freeze protect. 02:00 - 03:00 1.00 RUNCO RUNCMP WU DSM Lubricator & test 500 psi. -Set BPV. Test from bottom 1,000 psi / 10 minutes - Pass. 03:00 - 05:00 2.00 RUNCO RUNCMP Suck back lines & R/D Hot Oil. -Remove secondary valve. Install blank flanges. -Install gauges. -Pressure on OA= 0 psi, IA= 0 psi & Tbg= 0 psi. 05:00 - 06:00 1.00 RUNCO RUNCMP Clean & clear Rig floor. Pnnted: 4/lli'LUU~3 1'L:'Li5:~1 YM • • .~ ~ ~~. ~ ALASKA OIL ~1QD G~.S COlYSLRQATIOIIT COMI-IISSIOK SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 700 ANCHORAGE, ALASKA 9950 7-3 539 PHONE (907) 279-7433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. ,,~'~ PO Box 196612 'o Anchorage, Alaska 99519-6612 Q~ ~~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 09-42A Sundry Number: 308-050 Dear Mr. Reem: ~'L"~~ FEB ~ ~ 20f~P 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. Sincerely, Daniel T. Seamount, Jr. Chair s ~`- DATED this? ~ day of February, 2008 Encl. (~ ,off ~ ~~~~ ~1 STATE OF ALASKA _ ~ ~~~ ALASKA OI~ AND GAS CONSERVATION COMMISSION ~~~~ ~~B ~ ~ ~ ~~ ? ~~ ~~~ APPLICATION FOR SUNDRY APPROVAL ~~~~~~ ~~~ & ~~~ C~r~. ~~~, scion 20 AAC 25.280 n„„1,,.,,„,,„, 1. Type of Request: ^ 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 199-007 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-092-22059-01-00 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 09-42A Spacing Exception Required? ^ Yes No 9. Property Designation: ~ 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028324 Oo~~3%?7 52' - Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL GONDtTION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10820 - 9082 _ 10875 9123 9554 N/A asin Len th Size MD TVD Burst Colla se Structural nd r 112' 20" 112' 112' 1490 470 Surface 3984' 13-3/8" 3984' 3585' 4930 2270 Intermediate 9979' 9-5/8" 9979' 8479' 6870 4760 Production Liner 3054' 7-5/8" x 7" 6925' - 9979' 6008' - 8479' 8160 5120 Liner 584' 3-1/2" x 3-3/16" 9831' - 10415' 8355' - 8802' 10160 10530 Liner 425' 2-3/8" 10395' - 10820' 8789' - 9082' 11200 1178 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10420' - 10618' 8806' - 8934' S-1/2", 17# x 4-1/2", 12.6# 13Cr80 9874' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker SABL-3" packer Packers and SSSV MD (ft): 9812' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 25, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Nick Frazier, 564-5633 Printed Na a avid R Title Engineering Team Leader y Prepared 8y Name/Number: Signature Phone 564-5743 Date ,?I// Q$ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity IL1~aOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~ ~S`~ ~'d~ ~`~~ Subsequent Form Required: '~ t--, APPROVED BY rJ L ~ ~~ A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 06 Submit In Duplicate QRIGINAL ~_.~~~~~Q~ by c,,~~,, 09-42A Rig Workover Scope of Work: Pull 5-'/2" x 4-~h" completion, run 7 5/s" retrievable plug, run and cement new 7 5/s" scab liner to ~ 4,100' MD, changeout 95/8' packoffs, and run 5-~h x 4-'/z" 13Cr80 "stacker-packer" completion. MASP: 2376 psi Well Type: Producer Estimated Start Date: March 25, 2008 Pre-riq prep work: 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. C 2 Cleanout sand to ~ 9,850' MD. Pressure test remainin sand lu to 1500 si. E 3 Jet cut C~ 9,770', -10' below collar of 1 S full joint above the Packer. (Ref: 7/24/1994 tubing summa F 4 Circulate 9.8 ppg brine through the cut. Load OA w/ 9.8# brine and diesel cap. MIT-OA to 2000 si. MIT-IA to 3000 si, LLR when fails. Bleed WHP's to 0 si. O 5 Set a BPV in the tubin hap er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Doyon 14. 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 5-'/z" x 4-1/z" tubing string. 3. Run and seta 7-5/a" RBP at 6,975'. 4. Run and fully cement a 7 5/e" scab liner with Baker liner top packer set at 4,100' MD. 5. Test well to 3500 psi. Replace the 9-5/8" casing packoffs. 6. Drill out landing collar and ceanout to the RBP. 7. Pull RBP. 8. Run new 5-'/2" x 4-'/2" Chrome tubing completion with packer at 9,700' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test IA and Tubing to 3500 psi. Freeze protect to 2200' MD. 11. Set BPV. ND BOPE. NU and test tree. RDMO. Post Rig Work O 1 Install wellhouse and flowline. Pull BPV. S 2 Pull Ball and Rod, set GLVs, and ull RHC. C 3 Cleanout sand to 10,618' MD bottom erf TREE = 6-3/8" MCEVOY GEN 4 WELLHEAD ~ CAMERON ACTUATOR = _. OTIS - KB. EI,EV = ,, 52' BF. ELEV = KOP = 1100' Max Angle = 53 @ 10534' Datum MD = 10488' Datum TV D = 8800' SS 113-3/8" CSG, 68#, L-80/K-55, ID = 12.415" I 3980' Minimum ID = 1.995 @ 10415' TOP OF 2-3/8" LNR 5-1/2" TBG, 17#, 13-CR-80, .0232 bpf, ID = 4.892" 6884' TOP OF 4-1 /2" TBG 6884' TOP OF 7-5/8" LNR -~ 6925' OF 3-1/2" LNR ~ 9831' 4-1/2" TBG,12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~ 9874' 7-5/8" CSG, 29.7#, NT-95, ID = 6.875" 9919' TOP OF 7" CSG 9919' '~ tTYNOTES: CHROMETBG. WHIPSTOCKIN 9VT KO PLUG. 2206' -i 5-1/2" HES TRSSSV, ID = 4.562" GAS LIFE MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4385 3923 33 LBSPM T2 2 6505 5672 36 LBSPM T2 3 7370 6367 35 KBMGSPM BKP 4 7988 6871 36 KBMGSPM BK 5 8607 7371 37 KBMGSPM BK 6 9224 7865 37 KBMGSPM BK 7 9645 8203 36 KBMGSPM BK 6884' -~5-112" X 4-1/2" XO 6925' 9-5/8" X 7-5/8" LINER SBP PKR 9554' SANDBACK (03/30/03) 9751' 4-1/2" HES X NIP, ID = 3.813" 9812' 7-5/8" X 4-1/2" BAKER SABL-3 PKR 9831' 3-1/2" DEPLOYMENTSLEEV~ 9845' 4-1/2" HES X NIP (BEHIND LNR) 9862' 4-1/2" HES XN NIP (BEHIND LNR) 9874' 4-1/2" MULESHOETT (BEHIND LNR) 9912' 7-5/8" X 7" BAKER TIE BACK SEAL ASSY J--~ 3-1 /2" X 3-3/16" XO 7" X 9-5/8" WINDOW 9979' 1~03~ 2-3/8" DEPLOYMENT SLEEVE 9-5/8" CSG, 47#, L-80, ID = 8.861" ~ 10239' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10688' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: INDUCTION LOG ON 04/05/99 ANGLE AT TOP PERF: 45 @ 10420' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 10420-10430 O 04/18/99 1-11/16" 4 10488 - 10508 O 04/18/99 1-11/16" 4 10555 - 10565 O 04/18/99 1-11/16" 4 10608 - 10618 O 04/18/99 I 9972' I TOP OF 3-3/16" LNR ~-1 9972' I TOP OF 2-3/8" LNR 10395' 3-3/16" LNR 6.2#, L-80, 1041 .0076 bpf, ID = 2.80" PBTD 1.0784' 2-318" LNR, 4.6#, L-80, .0039 bpf, ID = 1.995" 10~ DATE REV BY COMMENTS DATE REV BY COMMENTS 1990 ORIGINAL COMPLETION 04/09/99 SIDETRACKED 01/22/01 SIS-MD FINAL 02/08/02 RN/TP CORRECTIONS 03/30/03 CJSlTLH SANDBACK 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNff WELL: 09-42A PERMIT No: 1990070 API No: 50-029-22059-01 SEC 2 T10N R15E 2154.49 FEL 5270.65 FNL BP Exploration (Alaska) • 09-42A GEN 4 WELLHEAD= CAMERON ACTUATOR = OTIS KB. ELE\(= 57 BF. ELEV = KOP = 1100' Meoc Angle = 53 ~ 10534' Datum MD = 10488' Datum TVD = 8800' SS Proposed 09-42A 13-3/8" CSG, 68#, L-80/K-55, ID = 12.415" 3880' 5-112" TBG, 17#, 13-CR-80, .0232 bpf, ID = 4.892" -4000 TOP OF 7-5/8" LNR 4100' 4000 5-1/7' X 41/7' XO / 9~/$"x7~/$"ZXP LNER PKR ^4100' Minimum ID = 1.995 ~ 10415' TOP OF 2-318" LN R TOP OF 3-112" LNR 4-1/2" TBG,12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~-1 8874, 7-5/8" CSG, 2s.7#, Nr-95. ID = 6.875" 89'19' TOP OF T' CSG ~ 8918' 6925' ~ 9-518" X 7-5/8" LINER SBP PKR ~ 8700' 7-5l8" X 4-1/2" BAKER SABL3 PKR 8751' 4-1/2" HES X NIP, ID = 3.813" 8812' 7-5i8" X 4-1/2" BAKER SABL-3 PKR 9831' 3-1/2" DEPLOYMENTSLEEVE 8846' 4-1/2" HES X NIP (BEHIND LNR) 9862' 4-1/2" HES XN NIP (BEHIND LNR) 8874' 4-1/2" MULESHOE TT (BEHIND LNR) 9912' H 7-5/8" X T' BAKER TIE BACK S EA L ASSY (~3-1/2" X 3-3/16" XO 7" X 9-518" WINDOW 9979' 10396' 2-3/8" DEPLOY MENT SLEEV E 9-5/8" CSG, 47#, L-8o, ID = 8.861" ~ 10238' T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10688' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" E-i 9972' PERFORAT~N SUMMARY REF LOG: INDIX;TiON LOG ON 04/05/99 ANGLEATTOP PERF: 45 ~ 10420' Note: Refer to Product~n ~ for historical pert data S¢E SPF INTERVAL Opn/Sgz DATE 1-11!18" 4 10420 - 10430 O 04/18/99 1-11/16" 4 10488 - 10508 O 04/18/99 1-11/16" 4 10555 - 10565 O 04/18/99 1-11/16" 4 10608 - 10618 O 04/18/99 OF 3-3/16" LNR H 9872' TOP OF 2-3/8" LNR 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" DATE REV BY COMMENTS .DATE REV BY CONNENTS 1990 ORDINAL COMPLETION 04!09/99 SIDETRACKED 01!22/01 SIS-MD FINAL 02/08/02 RN/TP CORRECTIONS 03/30/03 CJSlTLH SANDBACK 05/30/06 DTM WELLHEADCORRECT~N I 10415' I PBTD j- j 10784' ~.%sss° 7°" PRUDHOE BAY UNff WELL: 09-42A PERMIT No: 1990070 API No: 50-029-22059-01 SEC 2 T10N R15E 2154.49 FEL 5270.65 FNL BP Exploration (Alaska) ~Y NOTES: CHROME TBG. WHIPSTOCK IN CEMENT KO PLUG. ^'2200 H 5-1 /2" HES X-NIP, ID = 4.562" GAS LIFT MANDRELS 5T MD TVD DEV TYPE VLV LATCH PORT DATE 1 4061 3650 33 2 6416 5600 36 3 7532 6500 35 4 8271 7100 36 5 8956 7650 37 6 9645 8203 37 199-007-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD ~0820 TV!~09082 Completion Date: 09-42A 50- 029-22059-01 Start Stop /*'q~18/99 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: T Name c 9156 ~ D 9084 D 9503 c L GR-MD L GR-MD L GR-TVD L GR-TVD Interval 1 SCHLUM RST BH GR PB1 SPERRY GR FINAL 9979-10803 PBI FINAL 9989-10794 FINAL 8427-9007 PB1 FINAL 8436-9012 L INDUCTION 1 LGR 9670-10701 L INDUCTION J FINAL 9670-10701 L RST/SL~~ FINAL 10350-10765 R GYRO CONT. MULTI R SRVY LSTNG C--'~'- GYRODATA TBNG 0-8775. BH 9980-10834 PB1 BH 9980-10820 R SRVY LSTNG~....-' Sent Received T/C/I) CH 5/13/99 5/19/99 OH 11/30/99 1/12/00 OH 1/25/00 2/17/00 OH 2/5 11/30/99 1/12/00 D OH 2/5 1/25/00 2/17/00 D OH 2/5 11/30/99 1/12/00 OH 2/5 1/25/00 2/17/00 OH 4/20/99 4/20/99 OH 5/13/99 5/13/99- CH 5 5/13/99 5/19/99 C CH 4~26~99 4/26/99 OH 5/10/99 5/10/99 OH 5/10/99 5/10/99 Wednesday, March 28, 2001 Page I of 1 AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99510 Well Reference Data: Well No: 09-42A Field: Prudhoe Bay Unit County: North Slope State: Alaska Date: 01/25/00 API No: 500292205901 BHI Job~: 104006 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR DPR/MDL/MDP TOTALS: Log Type Navigamma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks :1 LIS Verification Report & Listings :1 Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Receive~ ~y: Attn: r 1 and FEB 17 ?00 Date: Alaska Oil & Gas Co'ns. Oommissiot~ Anchorage AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99510 Well Reference Data: Well No: 09-42APB1 Field: County: State: Date · Prudhoe Bay Unit 11/3o/99 API No- 500292205970 BHI Job#' 104006 North Slope Alaska Enclosed is the following data as listed below: Log Type Bluelines Navig~mma USMPR MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navigamma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 1 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias 1 Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks :1 LIS Verification Report & Listings :1 Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to' Received by: Baker ~H~g. hes INT~_EQ Fax# Attn' Stuart Sutherland 5/13/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie NO. 12578 Compan~ Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay ~. Well Job # Log Description Date BL Sepia CD-R D.S. 9-42A '~ ~I~{~o 99183 RST 990416 ] ! ] D.S. 9-50 1~ ~-~ 99210 RST 990502 ] ] ] D.S. 11-28 ~ ~:3~t5~ 99193 CNTD 990421 ] ] ] D.S. 11-31A ~F ~;~3~ 99196 RST 990419 ] ] ] D,S. 14-28 ~i~ C~{~O 99192 RST 990420 ] ] ] D.S. 14-31 1~ q ~ ~ J 99182 RST-SIGMA 990417 I ] ] D.S. 15-45 ~I~. C~ I {~ 99191 RST-SIGMA 990702 ] 1 ] SIGNEI~,~ DATE: i.'i/'\'i~ 'i ~'i 'l")~)~ , Alaska Oil 6,.. (~as C{~t~s. c~:'a'~t~:~i~,tt ~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6~1~[1~k you I =LL TR ITT L ProActive Diagnostic Services, Inc. TO' ARCO Alaska, Inc. AOGCC Lori Taylor RE' Distribution-Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge reCeipt by returning a signed copy of this transmittal letter to the attention of: Carl Jablonski/Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LOG DIGITAL MYLAR / BLUE WELL DATE TYPE DATA SEPIA FILM LINE PRINT(S) Open Hole I I 1 /-/,~ ~ /--¢- ¢--- ¢ .~ Res' Eval. CH Signed' Print Name ~': ~"'~ RECEIVED Date · Gas Cons. Commi~k;)rt .~hora~e ProActive Diagnostic Services, Inc., Pouch 340112, Pruclhoe Bay, AK 99734 Phone: (907) 659-2307 Fax: (907) 659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com C:kMy DocumentskExcel_Word_DocumentskDistribution_FormskArco_pb_form.doc STATE OF ALASKA ALAS~v~, OIL AND GAS CONSERVATION COMI~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~] Gas F~ Suspended F~ Abandoned D Service E~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-007 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22059-01 4. Localion of well at surface 9. Unit or Lease Name 3339' FNL, 1072' FEL, SEC. 2, TION, R15E, UM .. ;: :. -, !~ ~ Prudhoe Bay Unit At Top Producing Interval ' ' : ' ' ' i~ 10. Well Number 5151' FNL, 2460' FEL, SEC 36, T11N, R15E, UM ' . 09-42A . At Total Depth; ' r''' ';'~.~..~__ ~ "~"' i'. ! I:i 11. Field and Pool 5273' FNL, 2157' FEL, SEC 36, T11N, R15E, UM .. . ~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 52 feelI ADL28324 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 March 14, 1999 April 7, 1999 April 18, 1999I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10820' MD /9082' TVD 10770' MD /9044' 'I'VD YES r~ No DI 2206' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & GR/CCL/Induction-Resistivity/RST 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 112' 30" 55 Sx AS 13-3/8" 68# L-80 Surface 3984' 17-1/2" 250SxCS 11,2500 SxCS 111,&600SxClas.~ ~ ~ E 9-5/8" 47# L-80 Surface 9979' 12-1/4" 425SxClassG :~% ~,, ~ L ~ ~r ~,_..-~_:¢. 7" 29# L-80 9921' 9979' 8-1/2" 158 Sx Class G 3-1/2"/3-3/16" 9.2#/6.2# L-80 9831' 10415' 3.8" 7 bbls 15.8 ppg Class G i", i,'~/~,J 2-3/8" 4.6# L-80 10393' 10820' 3.8" 5.5 bbls 15.8 ppg Class G 24. Per/orations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORDA, IRska 0[( ~' Gas Corls, interval, size and number) SIZE DEPTH SET (MD) PACKE~~i 5-1/2" 6884' 6925' 4-1/2" 9874' 9812' 10420' - 10430' MD; 8806' - 8813' TVD; @4 SPF 10488' - 10508' MD; 8852' - 8865' TVD; @4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10555' - 10565' MD; 8894' - 8900' TVD; @4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10608' - 10618' MD; 8927' - 8934' TVD; @4 SPF (See Sidetrack Summary for details) Date First Produclion Method of Operation (Flowing, gas lift, etc.) ~ I ~, I ~ I ~i ~ ~ April 21, 1999 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I 4/27/1999 3.3 Test Period > I 2893 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. -380 psi 24-Hour Rate > 1006 2910 6019 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved January 27, 1999 (Permit #~99-007) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of Sadlerochit Top of Zone 2B Top of Zone 2A Top of Zone lA Base of Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH 10361' 10398' 10555' 10649' 10716' TRUE VERT. DEPTH 8766' 8791' 8894' 8956' 9004' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of 09-42A CT Sidetrack Drilling Operations + Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. - · Bruce E. Smith, P.E. Date INSTRUCTIONS Prepared by Paul Rauf 263-4990. 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". Form 10-407 09-42A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 3/13/1999: 3/14/1999: 3/15/1999: 3/16/1999: 3/17/1999: 3/18/1999: 3/19/1999: 3/20/1999: 3/21/1999: 3/22/1999: 3/23/1999: 3/24/1999: 3/25/1999: 3/26/1999: 3/27/1999: 3/28/1999: 3/29/1999: 3/30/1999: 3/31/1999: 4/01/1999: MIRU CTU. PT BOPE. RIH & milled XN nipple @ 9852' MD. Tagged Whipstock @ 9936'. Began milling 7"x 9-5/8" casing window off Whipstock. Milled to 9946'. POOH. RIH & reamed to 9946' MD. Pumped Biozan sweep & POOH. RIH & milled to 9958' MD. Pumped Hi Vis Sweep & POOH. RIH to 10442' MD but unable to locate Whipstock. Whipstock fell downhole - lost window. POOH. RIH w/CT & pumped 17 bbls of 17 ppg Class G Cement to form a cement KO plug. PUH to 9000' & jetted TT w/Biozan. POOH w/CT. WOC. RIH w/CT & tagged TOC @ 9855' MD. Milled pilot hole to 9940'. Milled pilot hole to 9979' & POOH. Performed rig maintenance. RIH w/BHA. Milled window fl 9979' to 9988'. Drilled FM to 9990'. POOH. RIH. Dressed window area & POOH. RIH & drilled to 9994'. Backreamed to 9978'. POOH. RIH & drilled to 10022'. New mud. Performed LOT to EMW of 10.6 ppg. Drilled to 10180'. POOH. PT'd BOPE. RIH & drilled to 10302'. Drilled to 10545'. Swapped out mud. Drilled to 10615'. Drilled to TD @ 10835'. Backreamed to window & POOH. RIH & reamed f/10230' to 10300' & 10250'- 10255'. Pumped Hi Vis Sweep. POOH. RIH & conditioned OH for liner. POOH. Pin holed pipe @ 9985'. C/O CT reel. RD CTU. C/O CT reel. RU ELU & RIH w/logging tools but unable to go through window. POOH w/ logging tools. RD ELU. RU CTU. MU 3-3/16" liner. RIH w/liner. Unable to get beyond 10122' so POOH w/liner. RIH & reamed tight spots. Stuck BHA @ 10262'. POOH leaving bit, transmission, & rotor in hole as fish. RIH & pumped 8 bbls 17 ppg Class G Cement to form Cement KO plug. Contaminated Cement w/Biozan and jetted contaminated. POOH w/nozzle. WOC. PT'd BOPE. WOC. RIH & tagged TOC @ 9993'. Milled Cement to 10001' & POOH. Weather delay. Weather delay. RIH & drilled to 10038'. Drilled to 10163' MD. Drilled to 10205' & POOH. RIH & drilled to TD @ 10415' MD. Conditioned hole & POOH. Sidetrack Summary Page I 09-42A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 3/13/1999: 4/02/1999: 4/03/1999: 4/04/1999: 4/05/1999: 4/06/1999: 4/07/1999: 4/08/1999: 4/09/1999: 4/15/1999: 4/16/1999: 4/18/1999: MIRU CTU. PT BOPE. RIH w/3-3/16" & 3-1/2" liner & landed it @ 10415'. Pumped 7 bbls of 15.8 ppg Class G Cement to cement liner in place. Contaminated Cement w/Biozan & cleaned contaminated Cement from the wellbore. Unstung f/liner & POOH. WOC. RIH & washed through soft Cement to 10249'. Milled Cement to 10350' (Cement not rock hard). PT'd liner to 1075 psi - held solid for 15 min. WOC. Drilled to 10381' but unable to penetrate further. POOH. RIH & tagged FC @ 10381'. Drilled through float collar & float shoe. Drilled into FM to10420' & POOH. Tested BOPE. RIH & tagged BTM. Performed FIT to EMW of 9.6 ppg. Drilled to 10712' MD. Backreamed to 10420' & POOH. RIH & ran GR/CCLFFemp/CTIL-Resistivity Logs f/10415' - 10713' & POOH. RIH & drilled to 10770'. Drilled to TD @ 10820' MD & POOH. RIH w/2-3/8" FL4S liner & landed liner @ TD. Unable to confirm liner was released f/tool. POOH w/o liner. Mu fishing tools. RIH & fished out the 2-3/8" liner f/the hole. RIH & reamed / backreamed OH. POOH. RIH w/ 2-3/8" FL4S liner & landed liner @ TD. Dropped ball. TOL=10393'. PBTD = 10783'. Released f/liner. Pumped 5-1/2 bbls of 15.8 ppg Class G Cement to cement liner in place. Contaminated Cement w/Biozan & jetted contaminated Cement f/wellbore. POOH. FP well. RDMOL. RIH & tagged PBTD @ 10770' MD. RIH & logged well f/10768' to 10350' MD. MIRU ELU. PT equip. RIH w/Perf guns to PBTD & shot 50' of Initial Perforations f/: 10420' - 10430' MD (Zone 2B) Ref Log: RST 4/16/1999 10488' - 10508' MD (Zone 2B) 10555' - 10565' MD (Zone 2A) 10608' - 10618' MD (Zone 2A) Used 1-11/16" carriers & shot all Perfs @ 4 SPF, 0° phasing, balanced & random orientation. POOH w/guns. ASF. RD. Placed well 09-42A on initial production & obtained a valid well test. Sidetrack Summary Page 2 8000 8100 8200 8300 8400 8500 86oo 8700 F-- 88oo I 8900 9O0O 9100 ARCO A aska, lac. Structure : D.S. 9 Well : 09-42A Plugbock #1, APl 50-029-2205g-70 Field : Prudhoe Bay Location : North S ope, A asks Eos~r (feet) -> 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 I I I 1 I I I t I I I I I I I I I I I I I I I Tie on - 34.51 Inc, 9800.00 Md, 8277.64 Tvd, 900.29 Vs Tie on - 8277.64 Tvd, 3234.34 N, 9200 I [ I I I I I I I I I I I I ' I I I r I I I i I I 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 1800 Verficol Section (feet) -> Azimuth 126.91 with reference 0.00 $, 0.00 E from 9-42A ORIGINAL 3700 3600 3500 5400 A 3300 I 3200 3100 '-~ 3000 2900 2800 2700 260O Created' by planner ' Dote plotted: 6-May-99 Plot Reference is 9-42A Version I~;~ Dove Meson. Coordinates ore in feet reference g-42A. Tr,',e Vertical Depths are reference rkb - IdSL - 52ft. --- Baker H'ughel INT['Q --- ~CO Alaska, Inc. D.S. 9 09-42A Plugback #1 9-42A Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 9-42A Plugback #1 Our ref : svy89 License :API 50-029-22059-70 Date printed : 6-May-99 Date created : 23-Mar-99 Last revised : 6-May-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 718421.270,5941468.860,999.00000,N Slot location is n70 14 52.681,w148 14 39.929 Slot Grid coordinates are N 5943376.500, E 717291.200 Slot local coordinates are 1939.67 N 1074.37 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 9,09~42A Plugback #1 Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page Your ref : 9-42A Plugback Last revised : 6-May-99 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C O O R D S · C 00 R D I N A T E S Deg/100ft Sect Easting Northing 9980.00 32.26 52.08 8427.92 10029.00 25.90 87.40 8471.04 10054.00 25.50 97.60 8493.57 10084.00 30.70 106.70 8520.04 10115.00 38.00 111.30 8545.62 3296.47N 3632.38E 1.38 924.66 720826.38 5946776.68 3305.06N 3653.57E 36.78 936.43 720847.30 5946785.88 3304.59N 3664.36E 17.75 945.34 720858.10 5946785.73 3301.54N 3678.11E 22.42 958.17 720871.94 5946783.07 3295.79N 3694.61E 24.98 974.82 720888.59 5946777.80 10148.00 45.40 113.40 8570.24 10178.00 51.20 115.50 8590.19 10209.00 50.00 117.30 8609.87 10241.00 49.40 121.10 8630.57 10274.00 50.10 124.00 8651.90 3287.42N 3714.88E 22.82 996.05 720909.10 5946770.03 3278.14N 3735.25E 20.03 1017.92 720929.73 5946761.34 3267.49N 3756.71E 5.93 1041.47 720951.49 5946751.32 3255.59N 3778.01E 9.25 1065.64 720973.12 5946740.04 3242.04N 3799.23E 7.03 1090.75 720994.73 5946727.11 10305.00 50.00 127.10 8671.81 10336.00 50.00 128.90 8691.73 10367.00 51.00 132.70 8711.46 10398.00 54.90 134.20 8730.13 10429.00 57.30 135.20 8747.42 3228.23N 3818.56E 7.67 1114.51 721014.45 5946713.86 3213.61N 3837.28E 4.45 1138.25 721033.58 5946699.79 3197.98N 3855.37E 9.99 1162.10 721052.12 5946684.70 3180.96N 3873.33E 13.16 1186.68 721070.55 5946668.21 3162.86N 3891.61E 8.19 1212.17 721089.35 5946650.65 10460.00 54.40 136.30 8764.82 10491.00 52.20 138.70 8783.35 10522.00 50.00 138.70 8802.81 10552.00 48.70 140.50 8822.36 10582.00 46.60 141.20 8842.57 3144.49N 3909.51E 9.80 1237.52 721107.78 5946632.80 3126.17N 3926.31E 9.43 1261.94 721125.10 5946614.98 3108,05N 3942.23E 7.10 1285.56 721141.54 5946597.33 3090.72N 3956.98E 6.28 1307.76 721156.79 5946580.43 3073.53N 3970.98E 7.21 1329.28 721171.28 5946563.66 10613.00 44.70 142.20 8864.24 3056.14N 3984.72E 6.55 1350.71 721185.51 5946546.67 10644.00 43.20 142.60 8886.55 3039.09N 3997.85E 4.92 1371.45 721199.13 5946530.01 10675.00 41.90 142.90 8909.39 3022.40N 4010.54E 4.24 1391.61 721212.30 5946513.70 10705.00 40.30 140.80 8932.00 3006.89N 4022.71E 7.04 1410.66 721224.92 5946498.55 10737.00 37.60 141.20 8956.88 2991.26N 4035.37E 8.47 1430.17 721238.02 5946483.30 10768.00 33.30 142.20 8982.13 2977.16N 4046.52E 14.00 1447.55 721249.57 5946469.52 10797.00 29.60 142.60 9006.86 2965.18N 4055.75E 12.78 1462.13 721259.15 5946457.81 10834.00 25.70 143.20 9039.63 2951o49N 4066.11E 10.57 1478.64 721269.90 5946444.43 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 9-42A and TVDss from rkb - MSL = 52ft. Bottom hole distance is 5024.40 on azimuth 54.03 degrees from wellhead. Vertical section is from wellhead on azimuth 126.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 9,09-42A Plugback #1 Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : 9-42A Plugback #1 Last revised : 6-May-99 Targets associated with this wellpath Target name Geographic Location TVDss Rectangular Coordinates Revised 9-42bhs 721109.000,5%46672.000,999.00 8703.00 3183.64N 3911.87E 12-Jan-99 · ~CO Alaska, Inc. D.S. 9 09-42A 9-42A Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : 9-42A Our ref : svy123 License :API 50-029-22059-01 Date printed : 6-May-99 Date created : 22-Apr-99 Last revised : 6-May-99 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 718421.270,5941468.860,999.00000,N Slot location is n70 14 52.681,w148 14 39.929 Slot Grid coordinates are N 5943376.500, E 717291.200 Slot local coordinates are 1939.67 N 1074.37 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. D.S. 9,09-42A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : 9-42A Last revised : 6-May-99 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth 9980.00 32.26 52.08 8427.92 10000.00 28.58 64.70 8445.18 10030.00 27.80 67.20 8471.63 10080.00 29.10 64.20 8515.59 10113.00 31.90 69.20 8544.02 R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S . C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 3296.47N 3632.38E 1.38 924.66 720826.38 5946776.68 3301.80N 3640.93E 36.78 928.29 720834.77 5946782.26 3~07.58N 3653.87E 4.72 935.16 720847.53 5946788.41 3317.39N 3675.56E 3.86 946.62 720868.93 5946798.84 3323.98N 3690.95E 11.44 954.96 720884.12 5946805.88 10175.00 44.70 69.10 8592.58 10214.00 50.00 67.30 8618.99 10245.00 50.10 73.00 8638.91 10276.00 51.10 76.80 8658.59 10312.00 50.30 79.80 8681.40 3337.63N 3726.78E 20.65 975.41 720919.54 5946820.56 3348.30N 3753.39E 14.01 990.29 720945.83 5946831.99 3356.36N 3775.73E 14.10 1003.31 720967.92 5946840.70 3362.59N 3798.85E 10.01 1018.05 720990.85 5946847.60 3368.24N 3826.12E 6.82 1036.46 721017.95 5946854.04 10349.00 47.50 88.20 10385.00 48.20 92.50 10429.00 45.20 89.60 10466.00 48.10 92.00 10504.00 50.10 93.10 8705.74 3371.20N 3853.80E 18.70 1056.82 721045.52 5946857.79 8729.91 3371.03N 3880.48E 9.07 1078.25 721072.19 5946858.40 8760.08 3370.42N 3912.48E 8.34 1104.20 721104.20 5946858.72 8785.48 3370.03N 3939.38E 9.15 1125.94 721131.10 5946859.11 8810.36 3368.75N 3968.07E 5.70 1149.65 721159.81 5946858.66 10534.00 52.80 91.60 10578.00 51.80 96.10 10607.00 47.60 95.40 10642.00 44.40 93.50 10673.00 44.00 96.00 8829.05 3367.79N 3991.51E 9.81 1168.97 721183.27 5946858.38 8855.97 3365.47N 4026.23E 8.40 1198.13 721218.04 5946857.06 8874.72 3363.25N 4048.23E 14.60 1217.05 721240.10 5946855.48 8899.03 3361.28N 4073.32E 9.94 1238.30 721265.23 5946854.24 8921.26 3359.50N 4094.86E 5.77 1256.59 721286.81 5946853.08 10722.00 44.40 95.60 10763.00 41.60 95.90 10797.00 40.50 97.90 10820.00 40.50 97.90 8956.39 3356.04N 4128.85E 1.00 1285.84 721320.88 5946850.61 8986.37 3353.24N 4156.66E 6.85 1309.76 721348.77 5946848.62 9012.01 3350.57N 4178.83E 5.04 1329.09 721371.00 5946846.59 9029.50 3348.51N 4193.62E 0.00 1342.16 721385.85 5946844.96 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 9-42A and TVDss from rkb - MSL = 52ft. Bottom hole distance is 5366.47 on azimuth 51.39 degrees from wellhead. Vertical section is from S 0.00 E 0.00 on azimuth 126.91 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 9,09~42A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : 9-42A Last revised : 6-May-99 Targets associated with this wellpath Target name Geographic Location TVDss Rectangular Coordinates Revised 9-42bhs 721109.000,59~6672.000,999.00 8703.00 3183.64N 3911.87E 12-Jan-99 · TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januars., 27, 1999 Bruce E. Smith, P.E. AAI Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Prudhoe bay Unit 9-42A ARCO Alaska, Inc. Permit No: 99-007 Sur Loc: 3339'FNL, 1072'FEL, See. 2, T10N, R15E, UM Btmholc Loc. 422'FNL, 2410'FEL, Sec. 1, T10N, R15E, UM Dear Mr. Smith: Enclosed is thc approved application for permit to redrill the above referenced well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required bx' 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 d inspector on the North Slope pager at 659-3607. David W. John,,ston Commissioner ~,.__.~ ; BY ORDER OF THE COMMISSION dlffEnclosures ce; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enel. STATE OF ALASKA ..... t% ALASKA OIL AND GAS CONSERVATION COMMISSION R~,~,,. PERMIT TO DRILL 20 AAC 25.005 ~, °','*~,¢/ la. Type of work: Drill~ Redrill~ lb. T~e of well. E~loratow ~ Stratigr~hicTestD Developm;~~ Re-entw D Deepen B Se~ice Development Gas D Single Zone ~ Multiple Zo,e B % - 2. Name of Operator 5. Dat,m elevation (DF or KB) 10. Field and Pool ~~ ARCO Alaska, Inc. RKB 52 feet ,¢u¢~, 3. Address 6. Prope~ Designation Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 AD L 28327~ Prudhoe Bay Oil Pool 4. Location of well at sudace 3339' FNL, 1072' FEL, SEC. 2, T10N, R15E, UM At top of productive interval 5190' FNL, 2517' FEL, SEC. 36, T11N, R15E, UM At total depth 422' FNL, 2410' FEL, Sec 1, T10N, R15E, UM 12. Distance to nearest property line I 13. Distance to nearest well feet I No Close Approach 16. To be completed for deviated wells Kickoff depth: 9940' MD 18. Casing )rogram size Hole Casing 4-1/8" 3-3/16" Maximum hole angle 55° TCII 7. Unit or property Name Prudhoe Bay Unit 8. Well number 09-42A 9. Approximate spud date January 31, 1999 11. Type Bond (see 20 AAC 25.0251) Statewide Number #U-630610 Amount $200,000 14. Number of acres in property 15. Proposed depth (MD and 'fVD) feet 10864' MD /9088' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2600 psig At total depth (TVD) 3500 psi~ @ 8800' To Settin( Bottom TVD 10864' 9088' Quantity of Cement (include stage data) 10 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical Effective Depth: measured true vedical Casing Length Size Conductor 112' 20" Surface 3932' 13-3/8" Production 10187' 9-5/8" Liner 767' 7" 10693 feet Plugs (measured) 9113 feet 10214 feet Junk (measured) 8683 feet Cemented 55 Sx AS 250 Sx CS II, 2500 Sx CS III, & 600 Sx Class G 425 Sx Class G 158 Sx Class G PBTD tagged @ 10214' MD (8/07/1998) Measured depth True Verticaldepth 112' 112' 3984' 3585' 10239' 8705' 10688' 9108" Perforation depth: measured true vertical 10294'-10300'; 10440'-10446'; 10512'-10540'; 10544'-10566'. 8754'-8759'; 8885'-8891'; 8950'-8975'; 8979'-8998'. ORt®tN 20. Attachments Filing tee r~ Property Plat r~ BoP Sketch r~ Diverter Sketch F~ Drilling program Ddlling fluid program Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements 21. I hereby cedify that the foregoing is true and correct to the best of my knowledg6 Signed ~, ~ 1~1272_. ~¢.,~3~... ~y~ Title: ~1 Coil Tubing Drilling Supervisor Bruce E. Smith, P.E. Questions? Call Dan Kara @ 263-4837. Date /-'/'~ -- ¢¢ Prepared by Paul Rauf 263-4990 Permit Number Conditions of approval Samples required F~ Yes ~] No Hydrogen sulfide measures ~ Yes FI No Required working pressure for DOPE r--~2M; F~ 3M; BI iOther: Original Signed icy David W. Johnston ....Approved by Commission Use Onl~ APl number I Approval date See coverletter 50- i~) A ~ - A ~-~ ~ ~'"' O I~I /"o~ "~" ¢ '~ for other requ rements Mud log required ~'~ Yes ~. No Directional survey required ~:] Yes [] No 5M; [~ 10M;F-1 r~ 3500 psi for CTU Commissioner by order of the commission Date /"'~2~'~''' F¢ Form 10-401 Rev. 12/1/85- Submit in triplicate DS 9-42A CT Sidetrack and Completion Intended Procedure Objective: P&A well with 15.8 ppg cement. Mill window from mechanical whipstock. Directionally drill a twin replacement well from the existing wellbore. Complete with 3-3/16" cemented liner. Perforate appropriate intervals. Intended Procedure: Install mechanical whipstock. P&A existing perfs with 15.8 ppg cement. Clean out cement to whipstock tray. Mill window in 7" liner and 9-5/8" casing at 9940' md from whipstock Drill 10' of formation and perform leak-off test to 10.5 ppg, 0.5 ppg above the highest anticipated mud weight (10 ppg FloPro). · Directionally drill a 4-1/8" well to access Zone 2 and Zone 1 reserves. · Run 3-3/16" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into disposal wells at Pad 3 or CC2A. January13,1999 · 'DS 09-42A CTD Procedure DS 9-42A Potential Drilling Hazards POST ON RIG The well produces H2S. Highest H2S measurement was 150 ppm in 1977. Ensure H2S equipment is operational. BHP: 3500 psi @ 8800' ss (7.6 ppg EMW), BHT 180 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2600 psi. High perm, gas saturated intervals are expected across the Sadlerochit. No major faults are anticipated. Drilling will be done with 10 ppg mud for shale control. This could create loss circulation conditions when drilling in zone. DS 9-42A CT Sidetrack Proposed Wellbore 5-1/2" SSSV @ 2206' 12" GLM'S 5-112" x 4-112" xo 6884' 4-112" X Nipple 9751' & 9845' 7" Liner Top 9919' tied back Tbg Tail @9874' 6925' 9-5~8" x 7-5/8" Pkr 4-112" GLM'S 7-5~8" Scab Liner 9812' 7-5~8" x 4-1/2" Pkr 3-3116" liner top in 4-112" TT 9862' 4-1/2" XN Nipple Window cut in 7"& 9-518" @ ctq4° 4.125" open hole with 3-3/16" liner cemented in place 9-5~8" Casing shoe @ 10239' Existing perfs cmt. sqz'd TD 7" csg. Shoe . @ 1O688' 8200 1 . 8300 ~ 840(.~ '- 8500 -4-- (D 8600 8700 ._ > 8800 %.. ii. 8900 90C)0 (,-) '1 O0 9'20O Field · Prudhoe Bay Location · North Slope, Alaska 3520 5560 3600 5640 Fie orl - 54..51 [nc, 9800.00 Md, 8277.64 Tvd, 14~54.57 Vs ~!~ I<OP --. 9940 MD, 82494.20 TVl')ss 9--4-2bhs TVDss "\ 4 8948' 'lVDss '[,O. &' l[r~d of Hold - 28.45 Inc, 10864-.00 Md, 9035.88 'Ivd, 1926.77 Vs 00 '1400 1500 1600 1700 1800 196)0 2(300 :7 I 0(') 2200 Vertical Section (feet) ->. Azimuth 120.54 with reference 0.00 S, 0,00 E from 9-42A --- Boker Hughes INTEQ --- East (feet) -> 5680 5720 5760 5800 5840 5880 3920 3960 4000 I · ---J--$ ...... /___~.___I__L__L___L-- L ..... I I _~__~_____L____ 54,I0 · · . KOP - 9940 MD, 8594-.20 TVDss /, - lio on - 8277.64 lvd, 3:254.3.1 N, 3555.74 E 865~0' TVDss 5 - 8705' TVDss 9-42bhs 4 -. 8948' TVDss 'F,D. & End of Hold - 9035.88 '[vcl, 29 18.87 N, 5940.92 E :';360 5520 5280 524.0 ~'~ 2 0 0 z 5160 3120 db 3080 5040 5000 2960 2920 288O INTEQ Company: Well: Calculation Method Vertical Sect. Plane: Vertical SecL Plane: Measured Depth from True Vertical Depth Proposal Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN ARCO Alaska, Inc. 9-42A Version ~2 Minimum Curvatur 120.340 TRUE 118.680 GRID Sea level Rig: Nabors 3s/CTU #4 Field: Prudhoe Bay, Alask: Mag. Declination: 28.030 Grid Correction 1,660 Total Correction 26.370 Dip: 80.750 RKB Height: 52.00 Coords. TRUE Coords. - ASP Coords. GRID N(+)tS(-) Lat. (Y) 5946712.34 E(+)aV(~ 720751.07 5946721.64 720761.68 5946730.82 720772.24 5946739.89 720782.75 5946748.83 720793.21 5946757.66 720803.63 5946762.90 720809.86 5946766.37 720814.18 5946774.92 720826.44 5946783.24 720840.73 5946791,26 5946798.89 720874.79 59468OO.89 5946805.59 720894.05 5946810.04 720913.94 5946812.13 720934.24 5946812.22 720936.85 5946811.83 720954,69 5946810.45 720967.22 5946809.14 720974.96 5946804.10 720994.76 5946801.42 721002.55 721013.80 5946787.57 721031.57 721047.85 5946763.62 721062.51 5946749.14 721075.40 5946735.95 5946733.16 721086.40 5946715.84 721095.42 5946697.32 721102.37 5946677.80 721107.18 5946671.34 721108.27 5946657.72 721110.30 5946638.08 721113.22 5946618.98 721116.05 7211 5946582.47 721121.41 5946565.11 721123.94 Job No: AFE No: API No: BHI Rep: Job Start Date: Job End Date: (°/100ft) 0.00 0.92 0.96 0.96 1.00 0.96 1.07 24.00 20.64 16.92 14.16 12.20 Conmlent., Tie in Positon Kick off Point 3 Meas. Incl. TRUE GRID Subsca Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Conunent., (de~) (des) (de~) (ft) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) Lat. (Y) Dela. (X) (°/100ft) (°/100ft) (°/100ft) 10600.00 41.57 173.47 171.81 8813.92 3059.57 3925.62 5946548.38 721126.35 3171.88 3835.15 8.00 178.00 1842.50 -8.00 0.24 10625.00 39.57 173.53 171.87 8832.91 3043.42 3927.46 5946532.28 721128.66 3155.78 3837.46 8.00 178.00 1852.24 -8.00 0.24 10650.00 37.57 173.59 171.93 8852.46 3027.93 3929.21 5946516.85 721130.86 3140.35 3839.66 8.00 178.00 1861.58 -8.00 0.24 10675.00 35.57 173.67 172.01 8872.54 3013.13 3930.86 5946502.10 721132.94 3125.60 3841.74 8.00 178.00 1870.48 -8.00 0.32 10700.00 33.57 173.75 172.09 8893.12 2999.03 3932.41 5946488.05 721134.90 3111.55 3843.70 8.00 178.00 1878.94 -8.00 0.32 10725.00 31.57 173.84 172.18 8914.19 2985.65 3933.87 5946474.72 721136.74 3098.22 3845.54 8.00 178.00 1886.96 -8.00 0.36 10750.00 29.57 173.94 172.28 8935.71 2973.01 3935.22 5946462.13 721138.46' 3085.63 3847.26 8.00 178.00 1894.51 -8.00 0.40 10764.05 28.45 174.00 172.34 8948.00 2966.23 3935.94 5946455.37 721139.37 3078.87 3848,17 8.00 0.00 1898.55 -7.97 0.43 4 10775.00 28,45 174.00 172.34 8957.63 2961.05 3936,48 5946450.20 721140.07 3073170 3848.87 0.00 0.00 1901.65 0.00 0.00 10800.00 28.45 174.00 172.34 8979.61 2949.20 3937,73 5946438.40 721141.66 3061.90 3850.46 0.00 0.00 1908.70 0.00 0.00 10825.00 28.45 174.00 172.34 9001.59 2937.36 3938.97 5946426.60 721143.24 3050,10 3852.04 0,00 0.00 1915.76 0.00 0.00 10850.00 28.45 174.00 172,34 9023.57' 2925.51 3940,22 5946414.79 721144.83 3038.29 3853.63 0.00 0.00 1922.82 0,00 0.00 10864.00 28.45 174,00 172.34 9035.88 2918.88 3940,91 5946408.18 721~45.72 3031.68 3854.52 0.00 0.00 1926.77 0.00 0.00 T.D, C T Drilling Wellhead Detail Methanol Injection Otis 7" WLA Quick Connect ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR Man Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus .RCO Alaska, Inc. , ,~r Check/EFT#: 0 0 ? 1 2 ~l~l PAYABL[~8 Date: 01/12, Page OfoolooUTf~2 '.O. Box 1 02776 Pay Entity: ,nchorage, AK 99510 o2o~ N00072020221 01/11/ 99 VR011199SJH02 C020P 019'. SJIq 100.00 100.00 FILING FEE FOR PERMIT TO ~RILL SIDET][ACK WELL 09-42A : ~?/:%!;i~ii~}~!ii;~i;!~:~;iii~;i!iS~i ..................................................................... ..................................................................... ........................................................................ ~ lo0.0o loo.oo ........ uestions regarding this rermttance can be made by calling or wining: .~T 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 .ATLS907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 4CS 907/265-6080 P.O. BOX 103240, Anchorage, AK 99510-3240 IAL 907/263-4422 Detach check before depositing :'"':-'-.'"? ~t:~z:f;5':}~;7.-.?'..';9.~.> : ................. -...-. ..... · ................. C'!;-/: ':?S;.Y'fi'.-..:;!":;:..;'!~:'~:~;:::' '"'.:~;::i?" ":::- ~"~! .r..-: ~.~[:~i~i: ~},i;~81, rz ......... ' ........................ · ::::...::.! .... ii~. :~:. ..... ... '. ~; i.i ::?.:i: .:.':" :: :!..'::~. :.::. :!i'i;. :~;. '"':!:: :.:~ ':... !:: !:i ::-.':'.:!:' ':: ':: .i~ :: .::: % 'i~-'-! ':::- .::~ ;::.' -?-:-i' ':::":: ::::: :~:':::. ':!. '::: ':~ t;~. :.i ::; .::-:i:' !:'- :i ~ !- :::. ::iR...~p'~!ic ..l~a. ~: ,.~,.'~.ti~ql. ~;;-~-~5:-.i :::. t! ii-: :~: :::' .:: W':C-" :::-i-':i '::. :! ::!::":;i'"' "~. /'::6i~::m~D.r~or, r-~ms '~'m ~O::CE~rS ' :;: ~: :"- ~;'i :':: :!::' . :"' ~ :::!. ':;::i '::i:::~i :~' :' ::: '~:: }';: i ::: : :::iI :}~!i':i:-:: !'n.~l- n::n.-7:,l.: rb} :Pay : ~ : · : : : :: i :: : ~: ! ::: :'.:. :! tJ .L I~t tJ t .L :F__. J i ' ('~Amount Not To Exceed ~75,000.00") To the order of: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 01-12-99 **************100.00' Date Amount void after 90 days · : :::: 0T~ :~'~a rea 'red ,"OOO0[OO?i,~"' ~:OB~qO[,~: .Oq qOOOO," WI~LL PERMIT CHECKLIST COMPANY ~ ):~(~ WELL NAME ~ c~ _ ~ o~ /~ PROGRAM: exp __ dev Y,- redrtl /v,. serv __ wellbore seg ann. disposal para req __ FIELD & POOL ~ "~ (~ I _.C O INIT CLASS ~ ~ v t -- O i [ GEOL AREA ~ ~ ~ UNIT# ! ( (~ ~' (3 ON/OFF SHORE ~ Aj ADMINISTRATION 1. ~ N N N DATE ENGINEERING DATE 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 ddlling 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 ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................... 15. Surface casing protects all known USDVVs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equil~list adequate ..... 25. BOPEs, do they meet regulation ........ ._~._.~. .... 26. BOPE press rating appropriate; test to'~.t~L~,~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. /~N N N N N Y N ~qg-oco GEOLOGY A~,,~R DATE ANN[JLA. R_ DIS____POSAL APPR DATE 30. 31. 32. 33. 34. 35. Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones .... Y N Seismic analysis ofsh~ ............ Y N S~f off-shore) ............. Y N Con act name/phone for weekly progress reports [exploratory only] Y N With proper cementing records, this plan will contain waste in a sui~ble.,, receiving~; ....... Y N (A) (B) will not contaminate freshwat'eq or c.~e drilling waste... Y N to surface; ~ (C) will not impair mechanical in~rity ~,t,~e well used for disposal; Y N (D) will not damage prod..u~c~' ~formation or'lm, p,.air recovery from a Y N pool; and .,..,..-~" ~ (E) will not circuli~'~nt 20 AAC 25.252 or 20 AAC 2'&';~12. Y N GEOL?~Y: ENGINEERING: UlC//~9_glar COMMISSION'.~,,- RPC~ ~ ?/.~r~, ~-~ -~ DWI ~ JDH~ -- ( RNC co Comments/Instructions: 0 0 c:\msoffice\wordian\diana\checklist 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 the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile i is type: LIS 4-*** REEL HEADER **** I-1WD 99/11/30 BHI O1 LIS Custoraer Format Tape "* TAPE HEADER 99/11/30 104006 01 i 3/4" I,iaviGamma, Gamma Ray data LIS COM~dEI,tT RECORD (s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 Remark File Version !.000 Extract File: Header.las ~Version Information VERS. 1.20: ?IRAP. NO: -PJell Infsrmation Block tfMI,IEM. Ui,IIT Data Type STRT.F 9870.0000: STOP.F 10830.0000: STEP. F 0. 5000: NULL. -999. 2500: COMP. COMPANY: ~',!E L L. ~JE LL: Find . FIELD: LOC . LOCATiOiq: C},!TY. COUi,!TY: STAT. STATE: SR'..,'C. SERVICE COi-4~ANY: TOOL. TOOL i,~f~',iE & TYPE: REF . JOB REFEREiqCE: DATE. LOG DATE: API . API NUMBER: CNLS log ASCii Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value ARCO Alaska, inc. 09-42APB1 Prudhoe Bay Unit 3339' FNL North Slope Alaska Baker Hughes INTEQ 1 3/4" NaviGa~a - Ga~a Ray 104006 24 Mar 99 500292205970 ~Parameter Information Block #MlqEM. UNiT Value ~ - FL SECT T O~;'!N P DAT EPD F bPI F FAPD F DI'4 F EKB F EDF F EGL F CASE F OS1 -~ Roma ~'ks Description 1072' FEL : Field Location 02 : Section i0N : Township i5E : Range I'4SL : Permanent Datum 52' : Elevation Of Perm. Dat~mr~ NB : Log Measured From 52 : Feet Y~ove Perm. Dat~uar~ KB : Drilling Measured From 52' : Elevation O~ Kelly Bushing i,IA : Elevation Of Derrick Floor NA : Elevation Of Ground Level 9984 : Casing Depth DIRECTIONAL : Other Services Line ! All depths are Measured Depths (MD) unless otherwise noted. Ail depths are Bit Depths unless otherwise noted. Ail Gamma Ray data (GR~{) presented is Memory data recorded while irilling. ~'{eil 09-42APB1 is represented by Run 6 and Run 7, which are RECEIVED 1 2 2000 ~a Oil & Gas Cons. Commission Anchorage Directional with Ga~La Ray. (5 Runs 1 to 5 were railling runs and the Ga~a Ray acquired was from the cased hole of Well 09-42. {6 Well 09-42APB1 was kicked off @ 9984' MD (8427' SSTVD), from the wellbore of originally drilled for Well 09-42. (l Well 09-42APBi was drilled to TD @ 10834' MD (9007' SSTVD) on Run 7. A depth adjustment of +10' has been applied r~o TD after a r~ie-in. (8 The interval from 10803' MD (9007' SSTVD) to 10824' MD (9007' SSTVD) was not logged due to sensor to bit offset. (9 The Gamma Ray log has been depth shifted to match the PDS' GR DIL _ open hole Gamma Ray logged en March 1999. {!0) A Hagnetic Declination correction of 27.98 degrees has been applied ts the Directional Surveys. ~Hnemcnics GR.AP[ -> Gamma Ray Memory [{~D-API [HWD] {MWD-API units) ROPS -> Rate of Penetration, ft/hr TVD -> Suhsea True Vertical Depth, ft. ~Senscr Offsets RUN G}2{HA DIRECT I ONAL 6 21.54 ft. 26.35 ft. ? 21. 66 ft. 26.47 ft. Tape Subfiie: t 70 records... PIinimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER MWD .00 i i024 ~*~ INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 09-42APB1 FN Prudhoe Bay Unit COUN North Slope STAT Alaska RECEIVED !,LJ'i 12 2000 _Atmka 0ii & Gas C s. Com LIS COMMENT RECORD(s): ~23456789~~234~6789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ! ! ! ! ! [ ! ! ! ! ! ! ! ! ! ! ! ! ! Remark File Version 1.000 I. The data presenned here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the PDS' GR DIL open hole Gan-~a Ray data, dated March 1999. _ INFORMATION TABLE: CIFO !qN EH C HAN DIMT CN_Ai~ ODE P 1 GR GRAPi 0.0 2 ROP ROPS 0.0 FORMAT RECORD (TYPE# 64) EnuL-y Type( 1) Size( i Repcode( 66 Data record type is: 0 Entry Type( 2) Size( i Repcode( 66 Dat~ra Specification Block Type is: 0 Enr_ry Type( 3) Size{ 2 Repcode( 79 Dar_urn Frame Size is: 12 bytes Eu.,~iry Type ( 4 ) Size ( ! Repccde ( 66 Legging direction is down (value= 255) Entry Type( 5) Size( 1 Repcode( 66 Optical Log Depth Scale Units: Feet Entry Type( 8) Size( 4 Repcode( 68 Frame spacing: 0. 500000 Entry Type( 9} Size( 4 Repcede{ 65 Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type( 11) Size( 4) Repcode( 68) Number of frames per record is: 84 ENt.uy Type( ]_3) Size{ !) Repcode( 66) Or:e depr~h per frame (value= 0) Er,~ry Type{ i6) Size( i) Repcode[ 66) Da:~um Specification Block Sub-type is: Entry Block terminator. Sumraary of entry types encountered: i 2 3 4 5 6 7 8 9 10 il 12 13 14 15 16 i ! i 1 t 0 0 i 1 0 1 0 i 0 0 1 Rep Code Count Bynes 68 2 8 S ufa: 2 8 8 fI-ldull a [ F ] i . 00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 C~2rves: AP1 API AP1 AP1 Log Crv Crv Name Toc! Code Samples UniZs Size Length T}io T!/~ Cls Mod 1 GR MWD 68 i AP1 4 4 99 995 99 i 2 RO~ MWD 68 i 4 4 99 995 99 i DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 23 RECEIVED Tape File Start Depth = 9875.000000 Tape File End Depth = 10840.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER **** LIS representation code decoding su~ary: Rep Code: 66 ! datum Rep Cede: 68 5797 datums Rep Code: 79 2 datums Tape Suhfile: 2 30 records... Hiniraum record length: 54 bytes Ma}:imum record length: 1014 bytes [] Tape Subfiie 3 is tpe: LIS FILE HEADER MWD .0 01 1024 +++ iNFORHATION TABLE: CONS MN EM VA LU LCC 150 CN ARCO Alaska, Inc. P~N 09-42APB1 FI,! Prudhce Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! Remark File Version !.000 i. The data presented here is the unedited field raw data. INFORMATION TABLE: C!FO MN El'4 CHAN DiMT CNA/~ ODE P i GR.~/q GRAP[ 0.0 2 ROPS ROPS 0.0 '~ FORHAT RECORD (TYPE# 64 Enury Type( i) Size ! Da~ta record hype is: Entry Type( 2) Size 1 Datum Specification Block Entry Type( 3) Size 2 Datum Frame Size is: Entry Type( 4) Size 1 Logging direction is down Enhry Type( 5) Size 1 Repcode{ 66) 0 Repcode( 66) Type is: 0 Repcode( 79 12 bytes Repcode( 66 (value= 255) Repcode 66 Optical Log Depth Scale Units: Feet Enuuy Type( 8) Size 4 Repcode Frame spacing: 0.500000 Ennry Type( 9) Size 4 Repcode Frame spacing units: F ] fndun c [F ] 1.00000000 Entry Type( 11) Size( 4) Repcode Number of frames per record is: Entry Type( 13) Size( 1) Repcode( 66) One depEh per frame (value= 0) Er~try Type( 16) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: 68 65 3 84 Entry Block terminator. Summary cf entry types encountered: i 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 i ! 1 i 1 0 0 1 1 0 ! 0 ! 0 0 1 RECEIVED Rep Code Coun~ By. es 68 2 ~ Sum: 2 fndun a [ F ] [] FR.~i4E SPACE = 8 I. 00000000 0. 500 * F ONE DEPTH PER FRAi-'iE Tape depth iD: F 2 Curves: Narae Tool Code Samples Units Size ! GRM.,i MWD 68 1 4 2 ROPS MWD 68 1 4 DATA RECORD (TYPE# 0) Total Data Records: 23 1014 BYTES * Tape File Start Depth = 9875.000000 Tape File End Depth = 10835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER **** LIS representation code decoding su~tary: Rep Code: 66 i datum Rep Code: 68 5767 datums Rep Code: 79 2 datums Tape Subfile: 3 30 records... i-'H. niraum record length: 54 bytes Maximum record iengt_h: 1014 bytes Tape Subfite 4 is type: LIS ~'*+* TAPE TRAILER Mt, ID 99/11/30 104006 01 AP1 AP1 API AP1 Log Crv Crv Length T-,~ Tkp Cls Hod 4 99 995 99 i 4 99 995 99 i RECEIVED +*** REEL TRAILER MWD 99/11/30 BHI 01 Tape Subfile: 4 2 records... }.'ii nimum record ienguh: 132 bytes Na:.:imum record length: 132 bytes End of execution: T~ae 30 NOV 99 2:47a Elapsed execution time ~ 1.37 seconds. SYSTEM RETiiRI,! CODE = 0 RECEIVED 2OOO ~I~t~0~ &G~ C~s. Com~ [] Tape Subfile 1 is t)£pe: LIS [] Tape Subfi!e 2 is type: LIS DEPTH 987~ 9875 9900 i0000 i0i00 10200 10300 10400 10500 10600. 10700. 10800. 10840. 0000 5000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 GR -999 -999 68 141 421 283 363 37 146 31 76 17- -999 ROP .2500 -999 2500 -999 6530 -999 0610 16 1240 43 5210 17 3680 46 2220 33 9380 20 5140 24 75O0 45 9580 38 2500 -999. 2500 2500 2500 0980 4120 6280 8920 1540 7310 5070 9570 7090 2500 Tape File Start Depth = 9875.000000 Tape File End Depth = 10840.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH 9875 9875 ~qO0 10000 i0100 10200 10300 10400 10500 10600 10700 10800 10835 GR~4 0000 -999 5000 -999 0000 60 0000 144 0000 477 0000 333 0000 349 0000 48 0000 129 0O00 30 0000 i21 0000 173 0000 -999 ROPS 2500 -999.2500 2500 -999.2500 7410 -999.2500 2760 16.3900 7420 52.1740 5320 18.6340 3030 47.3810 9440 42.6530 4010 23.1320 4300 24.3880 8490 43.2320 2350 41.5740 2500 -999.2500 Tape File Start Depth = 9875.000000 Tape File End Depth = 10835.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Taee Suhfiie 4 is type: LiS RECEIVED 1 2 2000 Tape Subfile 1 is type: LIS **** REEL HEADER MWD **/ 1/ 3 BHI O1 LIS Customer Format Tape **** TAPE HEADER MWD 00/01/03 104006 01 1 3/4" NaviGamma - Gamma Ray data LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ Remark File Version 1.000 Extract File: Header.las -Version Information VERS. 1.20: W~AP. NO: -Well Information Block #MNEM.UNIT Data T~vpe - STRT.F 9900.0000: STOP.F 10830.0000: STEP.F 0.5000: NULL. -999.2500: COMP. COMPanY: WELL. WELL: ELD . YIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: REP . JOB REFERENCE: umi~. ~ u~'i'A: API . API NUMBER: CWLS log ~QOTT ~=~'~N -VERSION 1,20 One line per frame Information Starting Depth Ending Depth Level Spacing ~sent V ARCO Alaska, inc. 09-42A Prudhoe Bay Unit 3339' FNL North Slope Alaska Baker Hughes INTEQ 1 3/4" NaviGamma - Gamma Ray 104006 ~ ~i 99 500292205901 -Parameter Information Block #MNE:M. UH i T Va i u e #- FL SECT. ~ ,.~,'~. N RANG, P DAT. FAPD . F LM F . FAPD'. F DH F EDP F EGL F ,~,.~ ~ ~Remarks Descri.=, Li .... I072' PRT. : m4~l~ 02 : Section i0N : Township i5E : Range MSL : Permanent Datum 52' : Elevation Of Perm. Datum 52 : Feet ~ove Perm. Datum KB : Drilling Measured From 52' : Elevation Of Kelly Bushing N/'A : Elevation Of Derrick Floor N/A : Elevation Of Ground Level 9'-qR'-q : ............. +~. u±nn',,z~,_a'~r.~ : Other Services Line i (1) All depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) presented is realtime data. (4) Well 09-42A is represented by runs 11 through 16, which are all Directional with Gaum~a Ray. RECEIVED FEB l 7 .000 Alaska Oil & Gas Cons. Commission Anchorage 5 The well 09-42A was kicked-off from the wellbore of Well 09-42APB1 @ 9989' MD (8835' SSTVD). Further details could be obtained from the logs for Well 09-42APB1. 6Well 09-42A was drilled to TD @ 10820' MD (9010' SSTVD) on Run 16. 7 The interval from 10794' MD (9010' SSTVD) to 10820' MD (9010' SSTVD) was not logged due to the Gamma Ray sensor to bit offset. 8) The Gamma ray log presented here has been depth shifted to match the PDS' GR DIL open hole Gamma Ray logged on March 1999. 9) A Magnetic Declination correction of 27.98 degrees has been applied to the Directional Surveys. -Mnemonics ROPS -> Rate of Penetration (ft/hr) GRAX -> Ga~aa Ray MWD-API [MWD] (MWD-API units) SSTVD -> Subsea True Vertical Depth, feet ~Sensor Offsets RUN GAN~4A 11 28.44 ft 12 26.36 ft 13 26.73 ft 14 26.28 ft 15 25.99 ft 16 26.49 ft DIRECTIONAL 32.86 ft. 21.38 ft. 21.75 ft. 21.30 ft. 20.97 ft. 21.47 ft. Tape Subfiie: i 70 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS FILE HEADER **** MWD .001 1024 INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 09-42A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ __ ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the PDS' GR DiL open hole gamma ray data, dated March 1999. _ *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i G R GPJ~'2{ 0.0 2 ROP :_-:_,.~ F ~ 0.0 FORMAT RECORD (TYPE~ 64] Entry Type 1) Size( 1) Repcode( 66 Data record type is: 0 Entry Type 2) Size, 1) Repcode( 66 Datum Specification Block Type is: 0 Entry Type 3) Size 2) Repcode( 79 Datum Frame Size is: 12 bytes Entry Type 4) Size 1) Repcode( 66 Logging direction is down (value= 255) Entry Type 5) Size 1) Repcode( 66 Optical Log Depth Scale Units: Feet Entry Type 8) Size 4) Repcode( 68 Frame spacing: 0.500000 Entry Type 9) Size 4) Repcode( 65 Frame spacing units: IF ] fndun c [F ] 1.00000000 3 Entry Type( 1!) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type( 13) Size( 1) Repcode( 66) One depth per frame (value= 0) Entry Type( 16) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: blame Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR MWD 68 1 API 4 2 ROP P~D 68 i 4 4 99 995 99 1 4 99 995 ~q ~ DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 23 Tape File Start Depth = 9900.000000 Tape File End Depth = 10830.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5587 datums Rep Code: 79 2 datums Tape 30 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes [] Tape Subfile 3 is type: LIS FILE HEADER MWD .001 1024 INFORMATION TABLE: CONS MN EM VALU LCC 150 CN ARCO Alaska, Inc. WN 09-42A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! !! ! Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i GPSZ~ GR~{ 0.0 2 ROPS ROPS 0.0 FORMAT RECORD (TYPE# 64 Entry Type( 1) Size 1 Data record type is: Entry Type 2) Size 1 Datum Specification Block Entry Type 3) Size 2 Datum Frame Size is: Entry Type 4) Size 1 Logging d rection is down Entry Type 5) Size 1 Repcode( 66 0 Repcode( 66 Tpe is: 0 Repcode( 79 12 bytes Repcode( 66 (value= 255) Repcode( 66 Optical Log Depth Scale Units: Feet Entry Type 8) Size 4 Repcode( 68 Frame spacing: 0.500000 Entry Type 9) Size 4 Repcode( 65) Frame spacing units: F ] fndun c IF ] 1.00000000 3 Entry Type( 11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type( 13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type( 16) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 fndun a IF ] FRAME SPACE = 8 1. 00000000 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size GRAX HWD 68 i 4 ROPS ?-~D 68 i 4 DATA RECORD (TYPE# 0) Total Data Records: 23 1014 BYTES Tape File Start Depth = 9900.000000 Tape File End Depth = 10830.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 5587 datums Rep Code: 79 2 datums Tape Subfi!e: 3 Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER MWD 00/01/03 104006 01 AP1 AP1 API AP1 Log Crv Crv Length Tp Typ Cls Mod 4 99 995 99 i **** REEL TRAILER MWD **/ 1/ 3 BHI O1 Tape Subfiie: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 3 JAN ** 4:08p Elapsed execution time = 1.43 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR 9900.0000 -999 9900.5000 -999 10000.0000 152 10100.0000 339 10200.0000 396 10300.0000 377 10400.0000 27 10500.0000 39 10600.0000 134 10700.0000 61 10800.0000 -999 10830.0000 -999 2500 -999 2500 -999 8800 16 1050 18 2400 11 0000 36 1800 100 2600 21 9800 23 8780 28. .2500 19. · 2500 -999. 25OO 2500 4000 3000 3000 0000 0000 0590 5000 5490 6220 2500 Tape File Start Depth = 9900.000000 Tape File End Depth = 10830.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 3 is type: LIS DEPTH 9900 9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10830 GRAX ROPS 0000 -999.2500 -999.2500 5000 -999.2500 -999.2500 0000 168.1130 40.8000 0000 360.9840 17.1860 0000 396.2400 8.5000 0000 368.1600 36.1330 0000 25.6700 100.0000 0000 34.7300 25.3670 0000 129.8600 26.6230 0000 63.4040 33.3000 0000 -999.2500 19.1000 0000 -999.2500 -999.2500 Tape File Start Depth = 9900.000000 Tape File End Depth = 10830.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS RECEIVED FEB i 7 2000 Alaska Oil & Gas Cons. Commission Anchoraga