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Home My WebLink About196-153Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: GraYScale, halftones, pictures, . graphs, charts- Pages: Poor Quality Original- Pages: Other Pages: DIGITAL DATA Diskettes, No. Other, No/Type 'OVERSIZED [3 COMMENTS: .Logs of various kinds Scanned by~"M~ .,~.D'a,~U'., Nama. Lowal [] TO RE-SCAN N°tes: Re-Scanned by: Beve~ a~ Darelha Nathan Lowell Date: /si Y 3%'.:.`✓..u.+.� �e9...:�.ve.••.•. —.w+ `w.. -. L.. ,. ..W.,...i3 wis.YrxSiu.xd...t�'s.R1Wn.es.r - V 6 t' #u1.3 ^iex'S2 L1+.t:ti OV'F,;:A01: HAA \ A'i.i.I Anchorage Aia,ka99-)0 3.572 f � � Moir i: 9(m 273 John McMullen SCANNED AUG 2 02044. Engineering Team Leader iq6 - ISS BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-14A Sundry Number: 314-116 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / / Cathy P. roerster Chair DATED this (��y of March, 2014. Encl. STATE OF ALASKA RECEIVE • ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL FEB 2 7 2014 20 AAC 25.280 07-S�ail� 1. Type of Request: d"► ❑Abandon ®Plug for Redrill ' 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 196-153 • 3. Address: 6. API Number: ®Development 0 Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20450-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU D-14A • Will planned perforations require a Spacing Exception? 0 Yes ®No 9. Property Designatior 10.Field I Pool(s): ADL 028285 • Prudhoe Bay Field/Prudhoe Bay Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10920' • 9013'• 10886' 9022' 10077', 10730' Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20"x 30" 110' 110' Surface 2685' 13-3/8" 2685' 2685' 4930 2670 Intermediate 8895' 9-5/8" 8895' 8370' 6870 4760 Production Liner - 1' 7240 5410 992' 7" 8408' 9400' 7913' 885 Liner 2510' 2-7/8" 8410'- 10920' 7915'-9013' 13450 13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9936'- 10880' 9022'-9023' 4-1/2",12.6#: 7" 26#x 4-1/2",12.6# 13Cr80; L-80 8258';8328' 8458' Packers and SSSV Type: 9-5/8"x 4-1/2" Baker S-3 Packer; Packers and SSSV 8159'/7679'; 9-5/8"GUIB Polar Packer MD(ft)and TVD(ft): 8354'/7862' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch 0 Exploratory 0 Stratigraphic ®Development 0 Service 0 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation July 1,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG IN Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Boltz,564-5750 Printed Name: Joh /c h , / Title: Engineering Team Leader Em il: Tra is.Boltz@bp.com rilli ''Signature: ' Phone: 564-4711 Date: 22-1 /' y Commission Use Only Conditions of-•proval: Notify Commission so that a representative may witness ` Sundry Number: V.4. — \\.Co ❑Plug IntegrityLJ BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: i.3 1' 71-057 O 35-6C Ps i \ A lfzr�a 71•r p ' vJ Iola C w?zl-v2 �f�pro vccl err ,gyp �� C ZS--l�21 � , Spacing Exception Required? 0 Yes U No Subsequent Form Required: 4 " 'SONS MAY 1 0 2014 o 9/ (.4.% ) APPROVED BY 3-6, `t // Approved By: , COMMISSIONER THE COMMISSION Date: 3- _i Tsy\''' Form 10-403 Revised 10/012 Ap c i t12 months from the date of approval Submit In Duplicate To: Alaska Oil & Gas Conservation Commission r bpFrom. Tvi Boltza s CTD Engineer Date: February 20, 2014 Re: D-14A Sundry Approval Sundry approval is requested to plug the D-14A perforations as part of the drilling and completion of proposed D-14B, a coiled tubing sidetrack. History and current status: D-14 was originally complete in 1980. It was coil sidetracked in 1997 to D-14A as a Z2A well. In 2002 the well developed a TxIA communication. A patch was set and the well returned to production. In 2002 the well was shut in due to a SC leak. A RWO was completed in 2006 which replaced the tubing and repaired the SC leak. The well 7 has low remaining value and no remaining wellwork options. Proposed plan: Sidetrack D-14A to the D-14B location using Nordic 1 Coiled Tubing Drilling rig on or around August 1, 2014. The D-14B sidetrack will exit the existing 7" liner and kick off in the Ivishak Zone 2, and target a Zone 2A lateral, to target Zone 2A reserves southwest of parent wellbore. This sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8" L-80 liner which will be cemented and selectively perforated. If we cannot cut and pull tubing at 9,012' MD we will set the whipstock higher and run 3 -1/4" liner across the Kingak and drill a 3" hole to target in the Ivishak. This Sundry covers plugging the existing D-14A perforations via the primary cement job to top of the liner or a liner top packer if the liner lap test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. •. welt waif w.'T 4 q GOER of froJCI A qfc� 2.0 /f G h,9,qtr t co.iw(. 'Tilt P rhpn Th q pqo< a wos, 4n f'f0'� brie of no ;itrDv•h r 1-4e4 � iP1 wcl� w /e '/C 540fri'J 4//dw �r ��''n�'o•� Cyc�r�• ° ,"y ' 'f recovery -raw r4P Pre-Rig Work (scheduled to begin July 1, 2014) 1. S Drift for CIBP, DMY GLVs, (Load IA with Crude and MIT-IA 2,500 psi) 2. E Set 2-7/8" CIBP 9,110' MD, MIT-T to 3,000 psi 3. E Cut Liner 9,012' MD Confirm Cut Tubing (Catch & Release) at 9,012'MD and Circ 1.5 Btms 4. C up w/ 1% KCL and F.P. from 2500' to surface 7. V PT MV, SV , WV, Set TWC (pending MIT-T 8. 0 Remove Welihouse and level pad Rig Work (scheduled to begin August 1, 2014) Plan A (Able to pull tubing cut at 9,012' MD) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,365psi) 2. Pull Liner (Cut at 9,012' MD) 3. Caliper Well to 9,010' MD and Drift. 4. Set 4-1/2"x 7" Delta Whipstock TOWS at 8,990' MD 5. Mill 3.8" window and 10' of rathole. 6. Drill build: 4.25" OH, 1001'MD (20 dgree DLS) 7. Drill lateral: 4.25" OH, 1315'MD (12 degree DLS) 8. Run 3-1/2" X 3-1/4" x 2-7/8" L-80 liner leaving TOL at 8,200' MD. 9. Pump primary cement job: 51 bbls, 15.8 ppg, TOC at 8,2001.* 10. Perform liner cleanout and MCNL/GR/CCL log. 11. Perform liner lap test to 2,400 psi _ 12. Perforate liner based on log interpretation (-200'). 13. Freeze protect well to 2,500' MD. 14. Set TWC; RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) Rig Work(scheduled to begin August 1, 2014) Plan B (If Unable to pull tubing cut at 9012' MD) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,365psi) 2. Pull Liner (-9000MD) 3. Caliper Well to 9,010' MD 4. Set 4-1/2"x 7" Delta Whipstock TOWS at 8,960' MD 5. Mill 3.8" window and 10' of rathole. 6. Drill Intermediate: 4-1/4" OH, 48' -9,008' MD Set 3-1/4" w/4-1/2" Liner Hanger L-80 protective liner to cover the Kingak 7. TOL 8,225' 8. Drill Build: 3" OH, 996' (20 deg DLS) 9. Drill lateral: 3" OH, 1310' (12 degree DLS) 10. Run 2-3/8" L-80 Liner w/4-1/2" Receptacle leaving TOL at 8,210' MD. 11. Pump primary cement job: 15 bbls, 15.8 ppg, TOC at 8,210'.* 12. Perform liner cleanout and RPM/GR/CCL log. 13. Perform liner lap test to 2,400 psi 14. Perforate liner based on log interpretation (-200'). 15. Freeze protect well to 2,500' MD. 16. Set TWC; RDMO. Post-Rig Work: 1. Re-install wellhouse, flowline and pull TWC. 2. Set liner top packer with slickline* if liner lap test fails. *Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) Travis G. Boltz CTD Engineer 564-5750 CC: Well File Joe Lastufka TREE= 6"CIW WELLHEAD= 13-3/8"FMC SAFETY NOTES:WELL ANGLE>70°@ 9557'***4- ACTUAT_OR=_—CIW OTIS D-1 4A 1/2"CHROME JOINT TO PASSBG***COIL REQ'D KNUCKLE THRU 8328'(AWGRS 11/11/09). NITIAL KB.EEE ----71.50' BF.EL V- ___________46.72' KOP= __30_00' ii 4 ,4 iii 21' H13-3/8"CSG PATCH(07/14/06) Max_Angle_=_ 108.4716§-2-0T 10920' •. Datum MD= -9422' i •,, Datum 7V D=— 8800'SS / , ' .� 2103' —I 4-1/2-HES X Ni?D =3.813 20"CONDUCTOR H ?? r/ i•t �j i • .4 2163' ELM—I DV PACKER 9-5/8"CSG,47#,L-80 TC-1,D=8.835" H 2194' •• �• 2684' H FOC a GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,ID=12.347" 2685' ST MD TVI) DEV TY PE VLV LATCH PORT DATE lin 4 3217 3211 10 MAG DOME RK 16 12/18/13 3 5724 5482 29 MAG DOME RK 16 12/18/13 2 7306 6893 26 MVO DMY RK 0 07/22/06 Minimum ID =2.387" @ 8410' 1 8048 7574 21 MMG DMY RK 0 07/22/06 2-7/8" LNR, PIN END I ' 8128' —j4-1/2"HES X NP,D =3.813 X 8159' H9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.870" I I 8193' —14-1/2"HES X NP,D =3.813 4-1/2"TBG,12.6#,13-CR VAM TOP, H 8258' - / \ 8258' —+4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" 7"TBG STUB H 8328' 8331' —IGUIBERSON FBR,li. ?" 7"TBG,26#,L-80,.0383 bpf,D=6276" H 8355' 8354' H7"X 4-1/2"XO RSH-ECLPSE PKR RUBBER(07/20/06) H ?? g g` 8354' —9-5/8"GUB POLAR PKR,D=3.833" ' , 8396' H4-1/2"OTIS X NP,D=3.813" TOP OF 7"LNR H 8408' 0 0 8410' —I 2-7/8"BKR GS DEPLOY SLV,D=8410' TOP OF 2-7/8"LNR H 8432' I 7 i 8427' —14-1/2"OTIS XN NP,D=3.725" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" --' 8468' -/ \- 8458' 1--14-1/2"WLEG,ID=3.958" BEHIND 8474' —I ELMD TT LOGGED 10/17/80 CT LNR 9-5/8"CSG,47#,L-80,ID=8.681" H 8896' • , 7"LNR,26#,L-80,.0383 bpf,ID=6276" H 9407' PERFORATION SUMMARY MLLOUT WNDOW(D-14A)9400'-9407' REF LOG:SFERRY-SUN MVVI YGR ON 05/27/97 ANGLE AT TOP PERF:81°@ 9936' R Note:Refer to Production DB for historical perf data SIZE SR= INTERVAL Opn/Sqz SI-OT SQZ 2" 4 9936-9966 O 11/15/09 d 10077' --I2-7/8"CEP(11/14/09) 2" 4 9971-10001 0 11/15/09 1-2/3" 4 10500-10560 C 05/29/97 1-2/3" 4 10600-10660 C 05/29/97 1-2/3" 4 10800-10880 C 08/02/99 8 10730' —II-ES CIBP CI 108e6' H FBTD 2-7/8"LNR,6.16#,L-80,.0058 bpf,ID=2.372" --1 10920' ---.4a DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHDE BAY UNIT 06/80 ORIGINAL COMPLETION 12/27/13 WEC/JM)GLV C/O(12/18/13) WELL: D-14A 05/29/97 D16 CTD SIDETRACK(D-14A) FERMI No:9961530 07125/06 D14 RWO AR No: 50-029-20450-01 06/26/06 TLWPJC TOP OF LNR CORRECTION SEC 23,T1114,R13E 2569'FSL&1067'FEL 11/16/09 DBMPJC SET CBF/FERE(11/14/09) 07/21/13 MUM)GLV CJO(07/10/13) BP Exploration(Alaska) Page 1 of 1 11iEE= 6'CV/ MRI/FAD= 13518i D-146 1C 01ETBGm 4- AM/MR= MI OM N IELE?V= 7152 Proposed CTD Sidetrack -101141 TOPA.' 111141411/MDAW(04S111111$I1 BE aEV= 4672 NIP= 3000' .. .4 21' —I13311'MG HATCH(07114106) MK A = 0 Q 10427 ::, o imaio= 9422' : IA D III=1V0= 8800 SS i, of _ 2103" —4-711i x1.13 =3313 . 0. ZO'COFI]UCIOR ?? fii N is 2163•EL II—w PACKERPAC 9-52r GSC.402.L-60 LGN D=2639' — 2194' .: V a _ 2684' — FOG LS 113-316'GSG.781-L-110.13=12347' H 260 0: 1% 1D TVD DEV TYPE VLV LATCH roar DATE 4 3217 3211 10 MG my III( 0 03117111 3 5724 5482 29 NIG CIO' 1110 0 03117111 2 7306 6893 26 MG DRY RK 0 07/22106 1 6048 7574 21 NIG DNY ILK 0 07/22106 Mil. an=2�87"ft 8410' I 2-718'LNR,PN END 8128' —4-VrHES XPM:D=3313 21 ir/ 01SW H9-518'X4-11rDKR S3F1QLD=337r TOL 2-3/8"/TOC-8,200'MD w/4-117'receptacle ---d____ _ 8193' —4-i11 iiesxmit D =3313 4-112'TEG,12611,13-CR VAN TOP, —I Mr I 1 1 82518 -4-112 MEG,D=3958' _0152 bpi,U=3.956' r MG STUB — 0321 I I $ GI, OII I R 11: 7-TUG,2Si,1_-80,_0363 bp4;D=6276' — 8355- Il / .. ( 8354• HrX4-112'xo 8354' —9-518'QM FOIAR RQZ_D=3333' 8396 —4-1/2'0116X f..D=3313' TM'OF7'LM —I NOW l TOL 3.114 8,415 MD -, J ' XN• Mdl to 3.80"wI F. , WINS 3-114"x 4-1/2"Liner Hander 542' —4-V2'011S 2311V,L1 3.725' 4-112 121G.17_02_1-60__0152 bpi_D=3_998' — 8458' I a458' H4-1r7 MII±6,D=3_958 BEaND Y518'CSG_471. -60-111=6.861' 8894' I , 8474• -am)TT DOGGED 10/17180 CI«R ,- _ :Most° l,E,d 0'MD I r um,zes,Lao, 0383 epi,o=6278. H 940T I 21' T SAG 8,988'MD 3.1/4"L•80 Shoe 9008'MD 2-3/8"L.80 Liner PERFORATION ..lb 9,014'MD gp 11,335'MD REF 100_SPERRYSIIN NMIDIGR OM 05127197 ' SRP-9100'MD ( � ' ' ANGLE AT TOP PERF:66 Ita 10500' i Nolo-Refer Io PDI D8 Tor eir•l pelf di SEE SPF I(IEWA[ Opa1Sqz DATE 11' 7 4 9936-9966 0 11!15109 r 4 9971-10001 0 1111509 =LOUT MNOOW(B-14A)9400'-940T 1-213' 4 10500-10560 C' 051291ST 1-213' 4 10600-10660 t: 05129197 ' 10071 —2-716'CRP(11114109) 1-21.3 4 10600-10660 I` 06102198 10738' HI Ps G16P I 10866 IH Ism 2-716'LFR 6_1618-LAW_0058 bpi_D=2372' — 10921] DATE REV BY COMMENTS DATE REV BY COMMIS PR HOE BAY LMT r ifM 0RI6 1AL CIANLEIIUN 1111609 IIBWPJC SET C DPT IgiF(1111409) WELL I3-14A 00I 7 1)18 CTD SIDETRACK(D-14A) 11116109 DBNIPJC DRAWING CORRECTORS PERIN1 No:'1961530 117/75 5 1114 RWO 03126111 DAVIPJC GLV CO(03/17111) API No: 50-029-20450-01 0612606 TiWPJC TOP OF INR CORRECTION SEC 23,111N,R13E,25C_49'FSL&106701'FEL 0610406 CAUPJC GLV CA 03109107 NW PJC DR8G DRAFT CCIRRECTON BP Eipioratian(Mudd) file://S:\Wells\Well Files\1 Planned Wells\Coiled Tubing Drilling\D-14B\1 - AFE and Pro... 2/20/2014 TRS= 6"CNV YVaLI EA© 13318"FMC D-1 4 S12" _CHROME TBG **COIL REQ'D KNUCKLE"4 ACTUATOR= CIW OTIS KB.ELEV= _71.52' Proposed CTD Sidetrack JOINT TO PASS THRU 8328'(AWGRS 11/11/09)_ BF._ELEV= 46.72' k-61-5--- 3000' i 4 ,4 Max Angle= )8 @ 10920' .� 4 / 21' -113-3I8"CSG PATCH(07114/06) Datum ND= 9422' ►�• �� 4 Datum-1\1D= 8800'SS :. 2103' -�4-1/2"HES X NIP,D =3.813 ►� ,*. 20"CONDUCTOR - ?? • � i �4 2163' ELM H DV PACKER 9-5/8"CSG,47#,L-80 TC-N,D=8-835" H 2194' Q Ili 2684' FOC vtilx S 13-3/8"CSG,72#,L-80,D=12.347" 2685' " 0 T MD TVD DEV TY FE VLV LATCH FORT DATE 4 3217 3211 10 MIG DMY RK 0 03/17/11 3 5724 5482 29 MviG DMY RK 0 03/17/11 2 7306 6893 26 MMG DMY RK 0 07/22/06 1 8048 7574 21 MMG DMY RK 0 07/22/06 Minimum ID =2.387" @ 8410' 2-7/8" LNR, PIN END 8128' -4-1/2"HES X NP,ID =3.813 0/ M/ 8159' H9-5/8"X 4-1/2"BKR S-3 PKR,D=3.870" TOL 3-1/2"x 3-1/4"x 2-7/8' L-80/TOC-8,200'ML 8193' -I4-1/2"HES XNP,D =3-813 4-1/2"TBG,12.6#,13-CR VAM TOP, H 8258' 8258' H4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" } 7 TBG STUB -I 8328' -; 8331' -IGUBERSON FBR,0=77 7"TBG,26#,L-80,.0383 bpf,D=6.276" H 8355' ` 'alb 8354' H7"X 4-1/2"XO FISH-ECLPSE PKR RUBBER(07/20/06) H ?? ► ►M-4 . 8354' -19-5/8"GUIB POLAR PKR,D=3.833" 8396' H4-1/2"OTIS X NP,ID=3.813" TOP OF7"LNR -I 8408' ' -XN-Mill to 3.80"(w/Rig) A 8427' HI4-1/2"OTIS XN NP,D=3.725" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 8438' I 1 8458' -14-1/2"WLEG,D=3.958" BEHIND 8474' H ELM)TT LOGGED 10/17/80 CT LNR 9-5/8"CSG,47#,L-80,0=8.681" H 8895' 3-1/2"x 3-1/4"XO 8,960' MD 7"LNR,26#,L-80,-0383 bpf,D=6-276" H 9407' 21° ' TSAG 8,988'MD 2-7/8" L-80 Liner @ 11,337'MD Baker Whipstock 8,990' MD (w/2 pups evenly spaced) Top of 2-7/8"Stub 9,014'MD I 1 CIBP-9100'MD PERFORATION SUMMARY 2' 3-1/4"x 2-7/8"XO 10,200 MD REF LOG:SPERRY-SUN MWD/GR ON 05/27/97 ANGLE AT TOP PERF:86 @ 10500' Note: Refer to Production DB for historical perf data 10077' H2-7/8"CEP(11/14/09) SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9936-9966 0 11/15/09 10730' HI-ES CIRP 2" 4 9971 -10001 0 11/15/09 1-2/3" 4 10500- 10560 05/29/97 MLLOUT WINDOW(D-14A)9400'-9407' 1-2/3" 4 10600- 10660 05/29/97 1-2/3" 4 10800 10880 08/02/99 10886' PBI U 2-7/8"LNR,6-16#,L-80,-0058 bpf,ID=2.372" -1 10920' DATE REV'BY COMMaITS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/80 ORIGINAL COMPLETION 11/16/09 DBIWPJC SET CIBP/PERF(11/14/09) WELL: D-14A 05/29/97 D16 CTD SIDETRACK(D-14A) 11/16/09 DBMPJC DRAWING CORRECTIONS FERMT No:9961530 07/25/06 D14 RWO 03/26/11 DAV/PJC GLV CIO(03/17/11) API No: 50-029-20450-01 06/26/06 TLI-I/PJC TOP OF LNR CORRECTION SEC 23,T11 N,R13E,2569.49'FSL&1067.01'FEL 09/04/06 CJWPJC GLV GO 03/09/07 MW/PJC DRLG DRAFT CORRECTION BP Exploration(Alaska) . c III Y ` * W � . Fa ioy$ " -1 Q $� LL 1K I 11" Fib — S =CCZ 1.1 9 1 — s o i- t 1 _$ u oyle ip ey 5 J gL'8. ,E ° •j .1 I �II� I �- (1 i 0 -NpumtENNE — a` gu tgi$ . U '., 1 2 il i q a g em — 2 O n g m V H SYv` a O i a $ Q g$i8 Ki u 11 CI .. ' m o m I II01 i II O I g. I ilii OLL 1 —\ Q . I Z 0 3 I I 1 ® ® 1111 c5i v Q 1 U () C C w J ' I Z 1 8 U > > Ogg N : _ u J 81 p E U. 111 O ir �j q ~3 .�� u U - • re , 1M., I-ISI 1 o ' J ! © • 111 r. $ II� W E In LL I.I. F _LIJ . U 0 O O L S I11 W II o Y 0) li • I o IT 1 U C9 i ! 3 J 1 $i V i , 1 U a 1 • 000 I ZS 1 ,� p z a 1 1 1 a Ili .1 o 1II ' 11111'' i1 m N cg L 1 ® f) 111 > I ® 11 a o Fil 1 I >> U Z " II Q ? 1u i it=jil III ° 111 \ 1 Y • �TI� mais30 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] (ZZ1 �13 Sent: Sunday, April 21, 2013 8:56 AM 1 To: AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Meixueiro, Paulina; AK, OPS Well Pad DG; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C DHD Well Integrity Engineer; Holt, Ryan P; Walker, Greg (D &C); Weiss, Troy D Subject: Operable: Producer D -14A (PTD #1961530) Sustained Inner Annulus Pressure Above MOASP Good Morning, Producer D -14A (PTD# 1961530) passed a MIT -IA to 2500 psi on 04/16/2013 confirming two competent barriers in the wellbore. The well has been reclassified as Operable, and can be returned to production. Regards, Laurie Climer /t'f't 1uIL : ..uc.'k Disbrow) SCANNED JUL 0 2U13 BP Alaska - Well Integrity Coordinator .?�.A�� GIN Wei urganLezit WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator PBP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, April 09, 2013 5:12 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Meixu- •, 'aulina; AK, OPS Well Pad DG; 'jim.regg @alaska.gov'; 'Schwartz, Guy L (DOA)' Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; H. , Ryan P; Walker, Greg (D &C); Weiss, Troy D Subject: UNDER EVALUATION: Producer D -14A (PTD #1961530) Sustain Inner Annulus Pressure Above MOASP All, Producer D -14A (PTD #1961530) had confirmed sustained ca. ng pressure above MOASP. The wellhead pressures were tubing /IA /OA equal to 2496/2012/72 on 04/08/2013. Th= A pressure has been bled off. The well is reclassified as Under Evaluation and placed on a 28 -day clock. Proposed plan forward: 1. Wellhead: PPPOT -T 2. Fullbore: MITIA to 3000 psi A TIO plot and wellbore schematic are included for reference. 1 P 11) 1 q'l53o Regg, Janles B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, April 09, 2013 5:12 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Meixueiro, Paulina; AK, OPS Well Pad DG; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Holt, Ryan P; Walker, Greg (D &C); Weiss, Troy D Subject: UNDER EVALUATION: Producer D -14A (PTD #1961530) Sustained Inner Annulus Pressure Above MOASP Attachments: Producer D -14A (PTD #1961530) TIO Plot.docx; Producer D -14A (PTD #1961530) Wellbore Schematic.pdf All, Producer D -14A (PTD #1961530) had confirmed sustained casing pressure above MOASP. The wellhead pressures were tubing /IA /OA equal to 2496/2012/72 on 04/08/2013. The IA pressure has been bled off. The well is reclassified as Under Evaluation and placed on a 28 -day clock. Proposed plan forward: 1. Wellhead: PPPOT -T 2. Fullbore: MITIA to 3000 psi A TIO plot and wellbore schematic are included for reference. Please call with any questions. SCS'— 7.c; Thank you, 14 yvr = 66/Cps; Jack Disbrow t✓t:PYp = 2 q, 3 - BPAlaska Well Integrity Coordinator W JUL 1 U `al3 GW Ort�aniZc tion SCOW Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinatorna bp.com 1 PBU D -14A PTD #1961530 4/9/2013 TIO Pressures Plot Well: D -14 • I 3.000 - i #- Tbp —III— IA —A— OA L. ' OOA —4— 000A of) 1. COO - • 01/12113 01119/13 01/26/13 02102113 02/09113 02/16/13 02/23/13 03/02/13 03/09/13 03/16/13 03/23/13 03/30113 04/06+13 • TREE = 6" CMV • WELLHEAD = 13-3/8" FMC SARI IOTES: WELL ANGLE >70 @ 9557' * ** 4 - OR = OW OTIS KB. ELEV 71.52' D-1 4A JOINT TO PASS Ij THRU 83328' R (AWGRS 1 1 9). KB.ELE w BF. ELEV = 46.72' . ��.. , KOP= 3000' I! g p!, 0 I 21' H 13 -3/8" CSG PATCH (07 /14/06) I Max Angle = 108 @ 10920' ► �� C Datum MD = 9422' • � • Datum TV D = 8800' SS ► I I ■: 1 HES X NIP, ID = 3.813 I 120" CONDUCTOR I ?? k ! Q 2163' ELMI —I DV PACKER I 19 -5/8" CSG, 40 #, L -80 TC-II, ID = 8.835" H 2194' 2684' F OC ' H I 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2685' GAS LIFT MANDRELS ST MD TV D DEV TYPE VLV LATCH PORT DATE M 4 3217 3211 10 MMG DMY RK 0 03/17/11 3 5724 5482 29 MMG DMY RK 0 03/17/11 2 7306 6893 26 MMG DMY RK 0 07/22/06 Minimum ID = 2.387" @ 8410' 1 8048 7574 21 MMG DMY _ RK 0 07/22/06 2 -7/8" LNR, PIN END 1 1 I 8128' H4- 1 /2 " HES X NIP, ID = 3.8131 Z 7 I 8159' I I9 -5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.870" I 1 I 8193' H4-1/2" HES X NIP, ID = 3.813 I 4 -1/2" TBG, 12.6 #, 13-CR VAM TOP, H 8258' I- -/ \ - 1 8258' H 4-112" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" 17" TBG STUB H 8328' I-- 8331' H GUIBERSON PBR, ID = ?? I 17" TBG, 26 #, L -80, .0383 bpf, ID = 6.276" H 8355' �-- I 83r � I I7" X 4 -1/2" XO I FISH - ECLIPSE PKR RUBBER (07/20/06) H ?? � l 8354' I- I9 -5/8 GIB POLAR PKR, ID = 3.833" I !TOP OF7 "LNR I-1 8408' a li I 8396' I— I4 -1/2" OTIS X NIP, ID = 3.813" I 8410' H 2 -7/8" BKR GS DEPLOY SLV, ID = 8410' I I TOP OF 2 -7/8" LNR I 8432' I r I 8427' (— {4 -1/2" OTIS XN NIP, ID = 3.725" I 14 -1/2" TBG,12.6 #, L -80, .0152 bpf. ID = 3.958" I--I 8458' I - / '' I 8458' I-I4 -112" WLEG, ID = 3.958" I BEHIND I CT LNR 8474' H ELMD TT LOGGED 10/17/80 ATV = 6670PS! 19 -5/8" CSG, 47 #, L -80, ID = 8.681" 1 8894' I-- 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H 9407' I PERFORATION SUMMARY MILLOUT WINDOW (D -14A) 9400' - 9407' REF LOG: SPERRY -SUN MWD /GR ON 05/27/97 ANGLE AT TOP PERF: 86 @ 10500' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 10077' H 2 -7/8" CIBP (11/14/09)1 2" 4 9936 - 9966 0 11/15/09 2" 4 9971 - 10001 0 11/15/09 1 -2/3" 4 10500 - 10560 C 05/29/97 1 -2/3" 4 10600 - 10660 C 05/29/97 ( 10730' 1-1 HES CIBP 1 -2/3" 4 10800 - 10880 C 08/02/99 I 10866' H PBTD I 12 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.372" Fl 10920' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT r 06/80 ORIGINAL COMPLETION 11/16/09 DBM/PJC SET CIBP / PERF (11/14/09) WELL: D-14A 05/29/97 016 CTD SIDETRACK (D -14A) 11/16/09 DBM/PJC DRAWING CORRECTIONS PERMIT No: '1961530 07/25/06 014 RWO 03/26/11 DAV /PJC GLV C/O (03/17/11) API No: 50- 029 - 20450 -01 06/26/06 TLH/PJC TOP OF LNR CORRECTION SEC 23, T11 N, RI 3E, 2569.49' FSL & 1067.01' FEL 09/04/06 CJN/PJC GLV C/O 03/09/07 MW /PJC DRLG DRAFT CORRECTION BP Exploration (Alaska) OPERABLE: Producer D -14A (PTD #1530) Passing MITIA - Tubing integ. restored Page 1 o Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] -ra 3 f s f ct Sent: Wednesday, March 23, 2011 8:55 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Stone, Christopher; Daniel, Ryan Cc: King, Whitney; Walker, Greg (D &C) Subject: OPERABLE: Producer D -14A (PTD #1961530) Passing MITIA - Tubing integrity restored All, 1 Producer D -14A (PTD #1961530) passed an MITIA on 03/21/11 after slickline set dummy gas lift valves. The passing test verifies that tubing integrity has been restored. The well has been reclassified as Operable and may be placed on production when convenient for operations. Please be careful of fluid expansion when placing the well on production as the IA is fluid packed. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, March 14, 2011 8:43 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (KAY; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker/Greg (D &C) Subject: UNDER EVALUATION: Producer D -14A (PTD #196 30) All, Producer D -14A (PTD #1961530) has confirmed stained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to :SV/2100/200 on 3/12/2011. The well has been reclassified as Under Evaluation. The well ma remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Slickiline: Dummy gas lift valves 2. Fullbore: MIT -IA to 3000 psi 3/25/2011 UNDER EVALUATION: Producer Dip (PTD #1961530) • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 161 I( Sent: Monday, March 14, 2011 8:43 PM ( 7 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Stone, Christopher Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Producer D -14A (PTD #1961530) Attachments: Producer D -14A (PTD #1961530) TIO Plot.doc; Producer D -14A (PTD #1961530) wellbore schematic.pdf All, Producer D -14A (PTD #1961530) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to SSV/2100/200 on 3/12/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. lF Plan forward: �° T,,YiA u ��` 1. Slickiline: Dummy gas lift valves 2. Fullbore: MIT -IA to 3000 psi A TIO P lot and wellbore schematic have been included for reference. «Producer D -14A (PTD #1961530) TIO Plot.doc» «Producer D -14A (PTD #1961530) wellbore schematic.pdf» Please call if have any questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 3/16/2011 PBU D -14A PTD #1961530 3/14/11 TIO Pressures Plot Well: D -14 4,000 - 3,000 - -0- Tbg f IA 2,000 - OA 00A -4-- 000A O n 1,000 \ no _ _ _ - -- • 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 TREE = 6" CM/ WELLHEAD = 13 -3/8" FMC • SAFETY WELL ANGLE >70 @ 9557' * ** 4 - ACTUATOR= CIW OTIS D _1 /� 4 A 1/2" CHR 11, TBG * ** COIL REQ'D KNUCKLE KB. ELEV = 71.52' JOINT TO PASS THRU 8328' (AWGRS 1 1/11/0 9). BF. ELEV = 46.72' R � KOP = 300 P ' P 21' J-- 113 - 3/8" CSG PATCH (07/14/06) I Max An = 108 @ 10920' / ► * :.• Datum MD -m 9422`* N . Datum TV D = 8800' SS ; I I w 2103' —14-1/2" HES X NIP, ID = 3.813 20" CONDUCTOR ?? �� • � DV PACKER d ■ �� 2 163' ELM /-1 ♦ N 9 -518" CSG, 40 #, L -80 TC-H, ID = 8.835" HI 2194' : +` �' 2684' H FOC 1 13 -318" CSG, 72 #, L -80, ID = 12.347" 1-1 2685' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE lir 4 3217 3211 10 MMG DOME RK 16 09/04/06 3 5724 5482 29 MMG SO RK 20 09/04/06 2 7306 6893 26 MMG DMY RK 0 07/22/06 Minimum ID = 2.387" @ 8410' 1 8048 7574 21 MMG DMY RK 0 07/22/06 2 -7/8" LNR, PIN END I I I 8128' 1-- 14 -1/2" HES X NIP, ID = 3.813 I X 1 8159' I - 19 X 4 -1/2" BKR S -3 PKR, ID = 3.870" I I 1 8193' 1--1 -1/2" HES X NIP, ID = 3.813 I 4 -1/2" TBG, 12.6 #, 13 -CR VAM TOP, --I 8258' I \ — I 8258' H4 -1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" I7" TBG STUB H 8328' I 8331' _1 GUIBERSON PBR, ID = ?? 7" TBG, 26 #, L -80, .0383 bpf, ID = 6.276" H I 8355' I / I 8354' H 7" X 4-1/2" XO I FISH - ECLIPSE PKR RUBBER (07/20/06) I"'°1 ?? g 8354' I I9 -5/8" GUIB POLAR PKR, ID = 3.833" 1 1 ' I 8396' H4 -1/2" OTIS X NIP, ID = 3.813" I I TOP OF 7" LNR H 8408' I ini 8410' H 2 -7/8" BKR GS DEPLOY SLV, ID = 8410' I TOP OF 2 -7/8" LNR H 8432' I I— I 8427' H4-1/2" OTIS XN NIP, ID = 3.725" 1 14 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" I — I 8458' J - I 8458' I — I4 - 1/2" WLEG, ID = 3.958" I BEHIND I 8474 H ELMD TT LOGGED 10/17/80 I CT LNR 19 -5/8" CSG, 47 #, L -80. ID = 8.681" H 8894' I---- - ( 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H I 9407' I PERFORATION SUMMARY MILLOUT WINDOW (D -14A) 9400' - 9407' REF LOG: SPERRY -SUN MWD /GR ON 05/27/97 , ANGLE AT TOP PERF: 86 @ 10500' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 10077' I - 12 - 7/8" CIBP(11/14/09) ( 2" 4 9936 - 9966 0 11/15/09 2" 4 9971 - 10001 0 11/15/09 1 -2/3" 4 10500 - 10560 C 05/29/97 1 -2/3" 4 10600 - 10660 C 05/29/97 I 10730' I — I HES CIBP 1 -2/3" 4 10800 - 10880 C 08/02/99 I 10866' H PBTD 1 2 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.372" I — I 10920' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT • 06/80 ORIGINAL COMPLETION 11/16/09 DBM/PJC SET CIBP / PERF (11/14/09) WELL: D-14A 05/29/97 016 CTD SIDETRACK (D -14A) 11/16/09 DBM/PJC DRAWING CORRECTIONS PERMIT No: 1961530 07/25/06 D14 RWO API No: 50- 029 - 20450 -01 06/26/06 TLH/PJC TOP OF LNR CORRECTION SEC 23, T11 N, R13E, 2569.49' FSL & 1067.01' FEL 09/04/06 CJN /PJC GLV C/O 03/09/07 MW /PJC DRLG DRAFT CORRECTION BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. ;q Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 l '7 —/3 March 06, 2011 MAC ? I� f /fit A Mr. Tom Maunder Alaska Oil and Gas Conservation Commission MCPka West 7 Avenue ' Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB D Pad �ori� CL�nss Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03 /04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11 B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 � D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 , NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 • D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 D -29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D-31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 STATE OF ALASKA RECEIVED i ALASWOIL AND GAS CONSERVATION COMMISSN NOV 1 8 7 009 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate $1189111‘91 ?St ties Dons. Uommissic n Performed: Alter Casing Pull Tubing Perforate New Pool Waiver El Time Extensi4 Anchorage Change Approved Program Operat. Shutdown Perforate 0 Re'tnter Suspended WC 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: "!y. Permit to Drill Number: Name: Development 0 Exploratory 196 -1530 3. Address: P.O. Box 196612 Stratigraphic❑ Service A. API Number: Anchorage, AK 99519 -6612 50-029-20450-01-00 Property Designation (Lease Number) 9. Well Name and Number: ADLO- 028285 PBU D -14A \p Field /Pool(s): PRUDHOE BAY FIELD PRUDHOE OIL POOL 11. Present Well Condition Summary: iti Mt1 Total Depth measured 10920 feet Plugs (measured) 10060' 10730' feet true vertio X1.2.78 feet"$ I$ Junk (measured) UNKNOWN DEPTH feet Effective Depth measured 10730 feet Packer (measured) 8159 8354 true vertical 9034 feet (true vertical) 7679 7862 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE 110 SURFACE 110 Surface 2684 13 -3/8" 72# L -80 SURFACE 2684 SURFACE 2684 4930 2670 Intermediate Production 8894 9 -5/8" 47# L -80 SURFACE 8894 SURFACE 8369 6870 4760 Liner 983 7" 26# L -80 8417 9400 7922 8851 8160 7020 Liner 2488 2 -7/8" 6.16# L -80 8432 10920 7936 9013 13450 13890 Perforation depth: Measured depth: SEE ATTACHED True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR80 SURFACE 8258 SURFACE 7772 4 -1/2" 12.6# L -80 8332 8458 7838 -7960 7" 26# L -80 8328 -8355 7838 -7862 Packers and SSSV (type, measured and true vertical depth) 9- 5/8 "X4 -1/2" BAKER S -3 PKR 8159 7679 9 -5/8" GUIB POLAR PKR 8354 7862 12. Stimulation or cement squeeze summary: t�YA� Intervals treated (measured): tilANNEL NQ 1/ 2 7 r� 200 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Servic[] Daily Report of Well Operations X �6. Well Status after work: Oil 0 Gas WDSPL GSTOR WAG GINJ❑ WINJ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble i Alf Title Data Management Engineer Signature Phone 564 -4944 Date 11/17/2009 Form 10 -404 Revised 7/2009 7 4 FO I t 1 1 1 Pt ti Submit Original Only D -14A 196 -153 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D -14A 5/29/97 PER 10,500. 10,560. 9,031.21 9,032.05 D -14A 5/29/97 PER 10,600. 10,660. 9,032.46 9,033.27 D -14A 5/29/97 PER 10,800. 10,880. 9,033.77 9,023.19 D -14A 1/31/98 MIS 8,316. 8,352. 7,826.24 7,860.17 D -14A 8/2/99 BPS 10,730. 10,830. 9,033.88 9,031.4 D -14A 6/20/03 MIR 8,316. 8,352. 7,826.24 7,860.17 D -14A 6/25/03 MIS 8,305. 8,340. 7,815.88 7,848.85 D -14A 7/28/03 MLK 8,353. 8,354. 7,861.11 7,862.06 D -14A 11/14/09 BPS 10,060. 10,062. 9,032.79 9,032.67 D-14A 11/15/09 APF V 9,940. 9,970. 9,022.91 9,027.59 D -14A 11/15/09 APF 9,975. 10,005. 9,028.33 9,032.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 1 D -14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4A �l�i 4 A '�`J'':n t tr: •a y 9- :t "C t, ,4 xfi 1 'i p' r' I P ^a%�. �1�A:�: a�, o "r�'�: w sir, o !s^k k4. §'"x+�;.-' "'d''4?, ":��::'S` y .5•,b�. °'1: :.ra .t A`e .z1 11/11/2009:CTU #5 1.75" CT Job Scope: (ADPERF) MIRU CTU, **Stop RU OPS for Contractor Leadership Team Audit. Complete RU and MU WFD MHA w/ ,SWS 2.20" Carrier GR/CCL Logging Tools and 2.25" Nozzle. Open swab and 'kill well. *Continue on WSR 11/12/09 11/12/2009 CTU #5 1.75" CT (Job Scope. (ADPERF) Continue from WSR 11/11/09. Continue killing well and RIH. Tagged at 8346' ctmd this could be the 7" tbg `stub. New completion left a 70' gap between the 4.5" TT and the 7" tbg stub. Several attempts (pumping not pumping) to get past failed. Log up from 8346' to 7900' and POOH. Bend pipe, add 3 stingers and tapered 2.25" JSN nozzle below carrier. Tag same area 8349'. Pump down coil and go past. Tag high 10430'. Could not jet past. Log GR/CCL from 10430' -7900' w/ ;flag 9999.6'. Re- attempt to pass through. Same as earlier, only pass with pumping 1.8 bpm down CT. OOH with good data -10' correction. MU CIBP BHA. Kill /Fluid pack well w/ 1.5 vol 1% KCL and RIH to set CIBP 10,060. Ran past 8346' clean and tagged at 8448' (possibly the 2 -7/8" liner top or X -O. `Several attempts to get past failed, POOH to inspect CIBP. *Job continued on WSR 11/13/09 11/13/2009 CTU #5 1.75" CT Job Scope. (ADPERF) Continue from WSR 11/12/09. Continue POOH to inspect CIBP. CIBP lower set of slips were stripped off the CIBP and there are some deep scratches on the bull nose that run up the side of the CIBP. MU /RIH w/ jars /2 1/8" motor /2.25" burn shoe. Work Venturi from 8351'- 10080'. Had 1 stall 8446'. Dry drift 8351'- 10080'. Had one tag 8445' 60 fpm. Clear at 30 fpm. Tried to dry drift and tagged at same :spot 2 out of 5 tries. Made 4 more up down passes that were clean /no motor work and tried dry drifting again and tagged again. POOH to PU 2.28" String Mill. OOH and Venturi was plugged of with 3 large pieces of rubber. MU ;Tappered 2.28" Cut -Rite Mill on motor and RIH *Job continued on WSR 11 /14/09 11/14/2009 CTU #5 1.75" CT Job Scope. (ADPERF) Continue from WSR 11/13/09. Continue RIH with tapered mill. RIH and never tagged with 2.28" mill dry or pumping. RIH to 10,080' clean POOH.MU RIH w/2.240" C)BP. No problems entering PBR or Liner. Tie -in to flag. Set CIBP (a. 10060'. Good set. OOH, LD CIBP setting BHA and prep to cut pipe, change Pack -Offs and check Chains. MU MCNL Logging BHA *Job continue on WSR 11/15/09 11/15/2009 CTU #5 1.75" CT Job Scope. (ADPERF) Continue from WSR 11/14/09. RIH w/ MCNL to CIBP and log 2 passes up to 8,900' POOH. MU /RIH w/ Gun #1: .30' of 2" 6 spf. Tie into flag 10000'. Shpt interval 9975'- 10005'. MU /RIH w/ Gun #2: 30' of 2" 6 spf PJ2006 HMX and tie in to flag at 10,000' ctmd. Shoot 30' interval from 9940' to 9970'. *Job continued on WSR 11/16/09* 11/16/2009 CTU #5 1.75" CT Job Scope. (ADPERF) Continue from WSR 11/15/09. Continue POOH. OOH with spent guns all shots fired. FP well to 2300' with 35 bbls of 60/40 Meth. Blow down reel and RDMO CTU to shop to swap pipe *Job Complete FLUIDS PUMPED BBLS 1046 1% KCL W /SAFELUBE 450 60/40 METH 1496 Total TREE 6" CM/ WECLHEwAD 13 -3/8" FMC S TES: WELL ANGLE >70° 9557' 4 KB. ELEV OR OW OTI 71.52 D -1 4A JOINT TO PASSE H RU 8328' (AWGRS 11/11 /09). KB. ELE2' BF. ELEV 46.72' POSSIBLE 71' GAP BETWEEN 4 -1/2" TT 7 LNR KOP 3000' �1 V 7 I 21' H13-3/8" CSG PATCH (07/14/06)1 Max Angle 108 10920 N F Datum MD 9422' i Datum TVD 8800' SS 1 210 -I4 1/2" HES X NIP, ID 3.813 3 20" CONDUCTOR 1 I j N O 2163' ELMH PACKER` 9 -5/8" CSG, 40 L -80 TC-II, ID 8.835" H 2194' 26$4 H FOC 1 13 -3/8" CSG, 72 L -80, ID 12.347" H 2685' 14 GAS LIFT MANDRELS ST MD 'ND DEV TYPE VLV LATCH PORT DATE C 4 3217 3211 10 MMG DOME RK 16 09/04/06 3 5724 5482 29 MMG SO RK 20 09/04/06 2 7306 6893 26 MMG DMY RK 0 07/22/06 Minimum ID 2.387" 8410' 1 8048 7574 21 MMG DMY RK 0 07/22/06 2 -7/8" LNR PIN END i 1 8128' 1— I4 -1/2" HES X NIP, ID 3.813 2K 0 1 8159' I 19 5/8" X 4 -1/2" BKR S -3 PKR, ID 3.870" I 1 1 1 8193' H4 -1/2" HES X NIP, ID 3.813 1 4 -1/2" TBG, 12.6 13 -CR VAM TOP, --I 8258' I J 8258' H4 -1/2" WLEG, ID 3.958" 1 .0152 bpf, ID 3.958" 7" TBG STUB H 8328' 1-- 8331' H GUIBERSON PER, ID FISH ECLIPSE PKR RUBBER (07/20/06) H 1 1 ii. J 8332' H 7" X 4-1/2" XO 1 7" TBG, 26 4, L- 80..0383 bpf. ID 6.276" 1 83551? 2 8354' I I9 5/8" GUIB POLAR PKR, ID 3.833" I 8396' I 14 1/2" OTIS X NIP, ID 3.813" 1 TOP OF 7" LNR 1-1 8408' 1 8410' 1--12 7/8" BKR GS DEPLOY SLV, ID 8410' I TOP OF 2 -7/8" LNR H 8432' 1 I 8427' I- 14 -1/2" OTIS XN NIP, ID 3.725" I 1 4-1/2" TBG,12.6 L -80, .0152 bpf, ID 3.958" H 8458' 1 7 i 8458' 1 /2" WLEG, ID 3.958" BEHIND 8474' H ELMD TT LOGGED 10/17/80 1 CT LNR 9 -5/8" CSG, 47 L -80, ID 8.681" H 8894' I f 7" LNR, 26 L -80, .0383 bpf, ID 6.276" H 9407' 1 PERFORATION SUMMARY MILLOUT WINDOW (D -14A) 9400' 9407' REF LOG: SPERRY -SUN MWD /GR ON 05/27/97 ANGLE AT TOP PERF: 86 10500' Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn /Sqz DATE 10077' H2 -7/8" CIBP(11/14/09) 2" 4 9936 9966 0 11/15/09 2" 4 9971 10001 0 11/15/09 1 -2/3" 4 10500 10560 0 05/29/97 1 -2/3" 4 10600 10660 0 05/29/97 1 -2/3" 4 10800 10880 C 08/02/99 l 1 10730' i- j HES CIBP 1 0 1 10866' H PBTD 1 2 -7/8" LNR, 6.16 L -80, .0058 bpf, ID 2.372" H 10920' i BY PRUDHOE BAY DATE REV B COMMENTS DATE REV BY COMMENTS NIT U R 06/80 ORIGINAL COMPLETION 11/16/09 DBM/PJC SET CIBP/ PERF (11/14/09) WELL: D-14A 05/29/97 D16 CTD SDTRACK (D -14A) 11/16/09 DBM/PJC DRAWING CORRECTIONS PERMIT No: 1961530 07/25/06 D14 RWO API No: 50- 029 20450 -01 06/26/06 TLWPJC TOP OF LNR CORRECTION SEC 23, T11 N, R13E, 2569.49' FSL 1067.01' FEL 09/04/06 CJN/PJC GLV C/O 03/09/07 MW /PJC DRLG DRAFT CORRECTION BP Exploration (Alaska) Schl~u~tlbergeP aska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage,AK 99503-2838 TN: Beth Well Job # NO. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 02-31A 17-09 12-30 17-09 13-27A JX-02A MPJ-19A L-103 W-217 8148-00087 63SQ-00042 69RH-00003 AWJB-00047 BALL-00009 AWJI.00065 AP3~-00075 BALL-00010 AYKP-00056 SCMT ( - TBG. CUT/FLOW DETECTION _ LDL .- G MEM LDL USIT MEM LDL - USIT _ RST/WFL - C CH EDIT PDC USIT _ 12/24/09 01/05/10 12/26/09 01/03/10 12/31/09 12/29/09 12/29/09 01/06/10 11/27/09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 12-05AL7 V-224 D-14A 11-27 3-27/M-33 B2NJ-00025 AYKP-00059 AWJh00060 AP3Q-00068 88K5-00012 MCNL CH EDR PDC USIT MCNL - ~. _ RST 'jj - ~ RST 09/29/09 12/14/09 11/15!09 11/06/09 11/18/09 1 1 1 1 1 1 1 1 1 ASE ACKNOWLEDGE RFC FIDT wv sir_uw r_ earn oeTno~nw~r_ nun ni.nv r..... ~..._ :xploration (Alaska) Inc. technical Data Center LR2-1 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 i ~'1 • i ffc ~¡)/Ica STATE OF ALASKA . ALA~ Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED AUG 1 6 2006 1. Operations Performed: Anchorage o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 196-153 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20450-01-00 7. KB Elevation (ft): 71.5' 9. Well Name and Number: PBU D-14A 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10920 feet true vertical 9013 feet Plugs (measured) 10730 Effective depth: measured 10730 feet Junk (measured) Unknown Depth true vertical 9034 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2684' 13-3/8" 2684' 2684' 4930 2670 Intermediate 8894' 9-5/8" 8894' 8369' 6870 4760 Production Liner 983' 7" 8417' - 9400' 7922' - 8851' 8160 7020 Liner 2488' 2-7/8" 8432' - 1 0920' 7936' - 9013' 13450 13890 <!('A~1\tiÞn (~t) f) .' l:J ::. \;) J ¡.,.ji¡J- ; .w........ Perforation Depth MD (ft): 1 0500' - 10880' Perforation Depth TVD (ft): 9031' - 9023' 4-1/2", 12.6# & 13Cr80 & 8258' & Tubing Size (size, grade, and measured depth): 7" 7ô# x 4-1/::>" 17 Ô# I-RO R~?R' - R4fiR' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' packer; 8159' 9-5/8" GUIB Polar Packer 8354' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut & pull 7" tubing from 8328'. Cut & pull 9-5/8" casing from 2192'. Cut & pull-50' of 13-3/8" casing. Run 13-3/8" casing patch back to surface. Cmt w/6.4 Bbls Class 'G' (36 cu ft). Run 9-5/8" casing tieback to surface. Cmt w/138 Bbls Class 'G' (775 cu ft). Run new chrome completion. 13. Recresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory ~ Development o Service 16. Well Status after proposed work: ~ Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o 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 Doug Cismoski, 564-4303 306-231 Printed Name Terrie Hubble Title Technical Assistant Signature /fâ.A fLi...b rL W-e 08 fi ' Ie. Prepared By Name/Number: Phone 564-4628 Date I ~ ~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2000 RIG I N A L RBDMS 8Ft Ave 1 8 10D6 Submit Original Only D-14A Completion . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rig Number: Spud Date: Sfi/1997 End: 716/2006 09:00 - 09:30 0.50 MOB P PRE Hold PJSM and Move Rig Off of Well D-15a. 09:30 - 10:30 1.00 MOB P PRE Spot Rig Over Well D-14a. 10:30 - 12:30 2.00 MOB P PRE Spot and Set Pump Module, Generator Module, And Set Cuttings Tank. Install Secondary Annulus Valve. Rig Accepted at 12:00 hrs 12:30 - 13:30 1.00 MOB P DECOMP Take on Heated Seawater, RlU to Circulate Well. 13:30 - 14:00 0.50 MOB P DECOMP Pre-Spud Meeting, Incident Review. 14:00 - 15:00 1.00 KILL P DECOMP RlU DSM Lubricator, Pull BPV, RID Lubricator. 15:00 - 17:00 2.00 KILL P DECOMP Test Lines to 3,000 psi, Circulate Freeze Protect Out of Tubing. Pump 40 bbl SafeSurf Viscous Sweep. 8 bpm at 1,640 psi. 17:00 - 17:30 0.50 KILL P DECOMP Monitor Well, BID and RID Lines. 17:30 - 00:00 6.50 WHSUR P DECOMP NID Tree, Bleed and Terminate Control Lines. Nipple Down Adaptor Flange. Adaptor Flange Would Not Pull Free. Change RlU and Pull 20,000# on Adaptor Flange Would Not Move. Continue to Heat Adaptor Flange and Work Flange. 7/7/2006 00:00 - 00:30 0.50 WHSUR P DECOMP Attempt to RID Adaptor Flange. Adaptor Flange Stuck. RlU Porta-Powers and Jack Against Adaptor Flange. Pull 20,000#, Adaptor Flange Came Free. 00:30 - 05:00 4.50 WHSUR P DECOMP Inspect Wellhead, Grind Out Tips of 4 LDS's That Will Not Back Out. Hanger Threads Look Good. 05:00 - 08:00 3.00 BOPSU DECOMP Nipple Up BOPE, Change Lower Rams to 7" 08:00 - 10:00 2.00 BOPSU DECOMP Test BOPE, Choke Manifold, Floor Valve to 250 psi Low Pressure, 3,500 psi High Pressure. Each Test was Held for 5 Minutes. Test was Witnessed by Jeff Jones AOGCC, Doyon Toolpusher and BP WSL. 10:00 - 13:00 DECOMP RlU to Relieve Trapped Pressure Below Lower Rams. During Testing, Pressure was Trapped Below 7" Rams with No Way to Relieve Pressure. Pull and Inspect Test Joint. Retest 7" Rams. 13:00 - 17:30 DECOMP Continue to Test BOPE, Choke Manifold, Floor Valve to 250 psi Low Pressure, 3,500 psi High Pressure. Each Test was Held for 5 Minutes. Test was Witnessed by Jeff Jones AOGCC, Doyon Toolpusher and BP WSL. Perform Koomey Test. No Equipment Failures. 2 LDS Leaked on Wellhead. 17:30 - 18:00 0.50 BOPSU DECOMP BID and RID Test Assembly. 18:00 - 19:30 1.50 PULL DECOMP RlU 7" Tubing Handling Equipment, Control Line Spooler and Landing Joint. 19:30 - 20:30 1.00 PULL P DECOMP RlU DSM Lubricator and Pull TWC. RID Lubricator. 20:30 - 21 :30 1.00 PULL P DECOMP Screw Landing Joint Into Hanger. Back Out LDS's, Unseat Hanger and Pull to Rig Floor. Hanger Unseated at 245,000# and Tubing Pulled Free at 260,000#. Up Weight 250,000#. 21 :30 - 23:00 1.50 PULL P DECOMP Terminate Control Line. BIO and UD Hanger. Circulate Bottoms Up. 23:00 - 00:00 1.00 PULL P DECOMP POOH Laying Down 7" Tubing. 7/8/2006 00:00 - 02:00 2.00 PULL P DECOMP POOH Laying Down 7" Tubing. 02:00 - 02:30 0.50 PULL P DECOMP UD SSSV, RID Control Line Spooler. Recovered 4 Stainless Steel Bands and 25 Rubber Clamps. 3 Clamps Were Missing Pins. 02:30 - 08:00 5.50 PULL P DECOMP POOH Laying Down 7" Tubing. Recovered 217 Jts of 7" IJ4S Tubing and a 21.85' Cut Jt of Tubing. 08:00 - 08:30 0.50 PULL P DECOMP Clear Casing Tools from Rig Floor, Pump Out BOP Stack. 08:30 - 10:30 2.00 PULL P DECOMP RlU and Run Rope Spear to Recover Control Line Sheathing from BOP Stack. 10:30 - 13:00 2.50 PULL P DECOMP P/U DP and Flush BOP Stack at 12 bpm. Recovered Additional Printed: 7/24/2006 11 :21 :04 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rjg Number: Spud Date: 8/7/1997 End: 15:00 - 16:00 1.00 DECOMP 16:00 - 17:30 1.50 TIEB1 17:30 - 00:00 6.50 EVAL P TIEB1 71912006 00:00 - 00:30 0.50 EVAL P TIEB1 00:30 - 01 :30 1.00 EVAL P TIEB1 01 :30 - 03:30 2.00 EVAL P TIEB1 03:30 - 07:00 3.50 EVAL Ip TIEB1 07:00 - 08:00 1.00 EVAL P TIEB1 08:00 - 09:30 1.50 EVAL P TIEB1 09:30 - 11 :00 1.50 EVAL P TIEB1 11 :00 - 15:30 4.50 EVAL P TIEB1 15:30 - 16:30 1.00 EVAL P TIEB1 16:30 - 17:30 1.00 CLEAN P TIEB1 17:30 - 18:00 0.50 CLEAN P TIEB1 18:00 - 19:30 1.50 DHB P TIEB1 19:30 - 20:30 1.00 DHB P TIEB1 20:30 - 21 :30 1.00 DHB P TIEB1 21 :30 - 22:30 1.00 DHB P TIEB1 22:30 - 00:00 1.50 DHB P TIEB1 7/10/2006 00:00 - 02:00 2.00 DHB P TIEB1 02:00 - 02:30 0.50 FISH P TIEB1 02:30 - 03:30 1.00 FISH P TIEB1 03:30 - 04:30 1.00 FISH P TIEB1 04:30 - 05:30 1.00 FISH P TIEB1 05:30 - 14:00 8.50 FISH P TIEB1 Rubber Clamp. Install Test Plug and Test to 1,000 psi. CIO Lower Rams to 3.5" x 6" Varibles, Test Rams to 250 psi Low and 3,500 psi High. Hold Each Test for 5 Minutes. RID Test Assembly, Pull Test Plug and Install Wear Bushing. P/U BHA #1, 6" Bit, Bit Sub, 1 x 4 3/4" DC, XO, Double Pin Sub, Boot Basket, 9 5/8" Csg Scraper, Bit Sub, Bumper Sub, Oil Jar, XO, 9 x 6 1/8" DC, XO. BHA = 350.03' RIH, Picking Up 4" DP from 350' to 8,017' RIH, Picking Up 4" DP from 8,017' to 8,300' Establish Parameters, Up Weight 188,000#, Down Weight 152,000#, Rotating Weight 175,000#. Torque Off Bottom 4,000 ftllbs at 20 rpm. Pump Pressure 340 psi at 4.5 bpm. Wash Down and Find Top of 7" at 8,342', Find 7" x 4 1/2" XO at 8,357'. Pump 40 bbl High-Vis Sweep followed by Heated Seawater. 3,350 psi at 14 bpm. Monitor Well, POOH from 8,357' to 350' Stand Back Drill Collars, UD BHA #1. RlU SWS Wireline Unit, Shooting Flange and Lubricator. RIH with USIT Log to 8,320' Log Up from 8,320' RID SWS Wireline Equipment. Move DC's in Derrick and M/U RBP. Perform Rig Service. RIH with RBP and Set at 3,250'. Up Weight 85,000#, Down 85,000#. Displace Well to Heated 9.8 ppg NaCI Brine. RlU and Test RBP to 2,500 psi for 15 Minutes. Good Test. RID Test Equipment and Blow Down Lines. POOH from 3,250' to Surface. RlU 7" Handling Equipment and P/U 1 Joint of 7" Casing. Dump 2,200# of 20/40 Mesh River Sand Down 7" Casing Joint. Finish Dumping 20/40 Mesh River Sand on Top of RBP. UD 7" Casing Joint. Change Handling Equipment to 4". Line Cellar Box with Herculite. M/U Baker Multi String Casing Cutter. RIH with Cutter Assembly to 2,150'. Get Parameters, 72,000# Up Weight, 72,000# Down Weight. 1 ,020 psi at 4 bpm. Back Pumps to 1 bpm at 130 psi. Slack Off and Locate Collars at 2,154' and 2,192'. P/U to 2,172' PJSM, Cut 9 5/8" Casing at 2,172'.90 rpm at 3,500 ftllbs of Rotary Torque. 3.5 bpm at 780 psi. At Cut Through, Rotary Torque Increased to 5,000 ftllbs and Pump Pressure Dropped to 420 psi Line to Take Returns Up 9 5/8" x 13 3/8" Annulus to Tiger Tank. Circulate Out Artie Pack. Establish Circulation 1 bpm at 1,700 psi. Pump 27 bbls of heated Diesel Up OA and Let Set, Pump 150 bbls of Heated 9.8 NaCI Brine Up OA at 2,340 psi. Follow with 80 bbls of Heated Diesel,Let Diesel Soak, Displace Diesel with Heated 9.8 NaCI Brine. Pump 100 bbl Safe Surf Pill and Chase with 170 bbls of Heated 9.8 ppg NaCI Brine, 12 bpm at 2,380 psi. Printed: 7/24/2006 11 :21 :04 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rig Number: Spud Date: 8/7/1997 End: Monitor Well and POOH with Cutter, Good Indications on Cutter Knives. 15:00 - 16:30 1.50 TIEB1 Pull Wear Bushing, Install Test Plug, Change Lower Rams to 9 5/8" and Test Door Seals to 250 psi Low and 3,500 psi High. 16:30 - 17:30 1.00 FISH P TIEB1 M/U 95/8" Spear Assembly. 17:30 - 19:00 1.50 FISH P TIEB1 BOLDS, Pull 9 5/8" Pack-Off and Hanger to Floor. Pulled Up to 325,000#, Pumped 16 bpm with 1,100 psi to Help Hydraulic Casing Out of Hole. 19:00 - 20:30 1.50 FISH P TIEB1 RlU Casing Equipment and UD Hanger. 20:30 - 00:00 3.50 FISH P TIEB1 Attempt to Pull 9 5/8" Casing, Pulling Tight, RID Side Door Elevators, CIO Bails and P/U 350 Ton Spiders. 7/11/2006 00:00 - 00:30 0.50 FISH P TIEB1 Work 9 5/8" Casing. Pull Up to 350,000#. Unable to Pull Pipe. Call Work Over Engineer and Discuss Options. 00:30 - 02:00 1.50 FISH C TIEB1 Rig Down 350 Ton Spiders and Long Bails. RlU Short Bails and 9 5/8" Side Door Elevators. 02:00 - 03:30 1.50 FISH C TIEB1 Wait on Cameron and WACH's Casing Cutter. 03:30 - 05:30 2.00 FISH C TIEB1 RlU WACH's Cutter, Cut 9 5/8" Casing, RID Wach's Cutter. UD 10' Cut Casing. 05:30 - 06:30 1.00 FISH C TIEB1 M/U 9 518" Casing Spear to Spear Casing and Set Back Down on Stub at 2,172'. UD Spear Assembly. 06:30 - 08:00 1.50 FISH C TIEB1 PJSM, MIU 11-7/8" String Mill Assembly. RIH to top of 13-3/8" Spool. 08:00 - 09:00 1.00 FISH C TIEB1 Rig Service 09:00 - 10:00 1.00 FISH C TIEB1 Mill Top of 13-3/8" casing with 11-7/8" string mill. Pump rate 2 bpm at 40 psi, 80 rpm's at 2,000 ft-Ibs torque. 10:00 - 11 :00 1.00 FISH C TIEB1 UD Mill Assembly and P/U 2 DC's. M/U Mill Assembly again. Needed weight of collars to elimate chatter from mill. 11:00 - 13:00 2.00 FISH C TIEB1 Mill across 3' of 13-3/8" casing right at surface. BIO and UD Mill and DC's. 13:00 - 14:00 1.00 FISH C TIEB1 MIU 9-5/8" Spear Assembly and Spear into 9-5/8" casing. 14:00 - 15:00 1.00 FISH C TIEB1 Pull Casing to Floor. See Excessive Drag. Unable to get casing any higher than before cut. Try to SIO and set Casing back down, unable to S/O. 9-5/8" Casing Stuck at top of 13-3/8" Casing. 15:00 - 15:30 0.50 FISH C TIEB1 BIO Joint of DP and Bumper Sub from Casing Spear. Call out for surface jars and consult town. 15:30 - 16:30 1.00 FISH C TIEB1 M/U Surface Jars, Bumper Sub and 10' pup. 16:30 - 17:30 1.00 FISH C TIEB1 Jar on Casing in attempt to get down. Took 20 plus licks and approximately 100,000 Ibs force to get casing out of top of 13-3/8". Once casing was free still required use of jars to force casing down to top of cut. 17:30 - 18:30 1.00 FISH C TIEB1 BIO and UD BHA 18:30 - 19:30 1.00 FISH C TIEB1 Clear and Clean Rig Floor. 19:30 - 21:00 1.50 FISH C TIEB1 P/U and M/U 12 1/4" String Mill BHA. 21 :00 - 22:00 1.00 FISH C TIEB1 Mill Across 3' of 13 3/8" Casing Right at Surface. 22:00 - 23:00 1.00 FISH C TIEB1 Wait One Hour to See if Casing Collapses. Ran 12 1/4" String Mill Through Milled Area. No indication of Drag. 23:00 - 00:00 1.00 FISH C TIEB1 BIO and UD 12 1/4" Milling Assembly. 7/12/2006 00:00 - 01 :00 1.00 FISH C TIEB1 M/U 95/8" Spear Assembly. 01 :00 - 02:00 1.00 FISH C TIEB1 Spear Into Cut 9 5/8" Casing and Pull to Rig Floor. Max Pull 250,000#. UD Cut Joint of 9 5/8" Casing with Spear. 02:00 - 13:30 11.50 FISH C TIEB1 UD 9 5/8" Casing, Connections Taking Between 30,000 - 45,000 ftllbs to Break Out. Taking pulls of 200,000 - 250,000 Printed: 7/24/2006 11 :21 :04 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rig Number: Spud Date: 8/7/1997 End: 7/12/2006 02:00 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 17:30 17:30 - 00:00 7/13/2006 00:00 - 04:00 04:00 - 07:00 07:00 - 09:00 09:00· 10:00 10:00·12:00 12:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 20:30 20:30 - 00:00 11.50 FISH C 1.50 FISH C TIEB1 TIEB1 2.00 FISH C TIEB1 0.50 FISH C TIEB1 6.50 WHSUR C TIEB2 4.00 CLEAN C 3.00 CLEAN C TIEB2 TIEB2 2.00 FISH C TIEB1 1.00 BOPSU C TIEB2 2.00 WHSUR C TIEB2 2.50 WHSUR C TIEB2 0.50 WHSUR C TIEB2 1.00 WHSUR C TIEB2 1.00 WHSUR C TIEB2 1.00 WHSUR C TIEB2 1.00 WHSUR C 0.50 WHSUR C 1.00 WHSUR C 3.50 WHSUR C TIEB2 TIEB2 TIEB2 TIEB2 Ibs to pull free. POOH and UD 52 of 55 Joints. Unable POOH with Joint 53. PJSM; MIU Circ Head and attempt to Circulate. Unable to Ciruculate Fluids down 9-5/8" Casing and Back Up. Able to Circulate from Kill Line and Lower Annulus Vavle. Attempt to Rotate Pipe, Apply up to 12,000 Ft-Ibs torque and unable to rotate. Attempt to P/U again with Pipe up to 250,000 Ibs. Able to P/U another 3 feet, then stopped again. Noticed on Last P/U that 13-3/8" and top plate on conductor had come up 6 inches. Casing Box too high to RID Circ Head and R/U Surface Jars. RlU Wach's Cutter and Cut Casing Above Floor. RID Cutter and M/U Spear, Bumper Sub, and Surface Jars. Attempt to Jar 9-5/8 in hole with surface jars. When P/U String to make Stroke Jars, P/U BOP's and Wellhead as Well. P/U Wt - 90,000Ibs. PJSM; Investigate where 13-3/8" casing is parted. Found Casing Parted at Flutes, able to see 9-518" casing. Also Look in BOP Stack to see if cement is holding 9-518" inplace inside BOP's. Open Ram Doors and Found a large volume of big cement chunks. Break Out and Remove Cement Chucks from BOP Stack Split Wellhead and Remove Cement. RlU Wach's Cutter and Cut 133/8" Nipple from Starting Head. Set Bell Nipple back in place, Set Master bushings, set false bowl in place. BIO joint of DP and Surface Jars, M/U 4-1/2" Lift Sub to Spear. . POOH and UD 9-5/8" casing. Last Joint and Cut Joint had good size sheath of cement on one side. POOH and UD 55 Joints and 1 Cut Joint. Length of cut Joint = 18.09' Pull Riser and Bell Nipple. Set BOP's on Pedestal. Clean Out Drip Pan. Clean and Clear Rig FLoor. Inspect Derrick and Top Drive. Continue to Clean and Clear Rig Floor and Cellar Area. Remove 13-3/8 Fluted Hanger. Suck Remaining Fluids from Cellar Box. Clean Cement out of Cellar Box. Pull Herculite. Report 1 bbl of fluid to Enviromental and SRT for fluids that leaked under Herculite. Clear Cellar of more gravel and level out. Install new Double Layer of Herculite and Secure to out side of conductor with banding straps. RIH wI 1-1/4" CS Hydril in between 13-3/8" and Conductor. Found Top of Cement at 26.8' in from top of Conductor. M/U BHA #4 12-1/4" Bit, 12-1/4" String Mill, Bumper Sub, Oil Jars, 3 DC's. Total Length = 131.34 ft. RIH with Bit and String Mill Assembly to 700 ft. No Restrictions seen. POOH wI 12-1/4" Bit and String Mill BHA. Stand Back DP and LI D BHA. Cut and Slip 75' of Drilling Line. Clear Rig Floor. Wait on 16" Washpipe. Flat on Transfer Truck. M/U 16" Washpipe and Shoe. RIH and Tag at 55 ft. from RKB. 26' From 20" Conductor. UD 16" Washpipe. M/U Dress -Off Tool and UD in Pipe Shed. Printed: 7/24/2006 11 :21 :04 AM " . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rig Release: 7/23/2006 Rig Number: Spud Date: 8/7/1997 End: 7/14/2006 00:00 - 01 :00 1.00 WHSUR C TIEB2 M/U Multi String Cutter, RIH to 48" from RKB. 01 :00 - 03:00 2.00 WHSUR C TIEB2 Cut 133/8" Csg. 80 rpm with 3,000-4,000 ftllbs Torque. 1,035 psi at 3 bpm. Take Returns into Lined Cellar Box. 03:00 - 04:00 1.00 WHSUR C TIEB2 POOH with Multi String Cutter, UD Cutter Assembly. UD 19.5' Cut Joint of 13 3/8" Casing. No visible signs of a hole in casing other than from the pinch point on the collar from the fluted hanger. No obvious corrosion evident as well. 04:00 - 05:00 1.00 WHSUR C TIEB2 P/U Dress-Off Assembly from Pipe Shed and Dress 13 3/8" Stub. 40 rpm 2,000-2,500 ftllbs Torque. 3 bpm at 30 psi. 05:00 - 06:00 1.00 WHSUR C TIEB2 POOH UD Dress Off Assembly 06:00 - 06:30 0.50 WHSUR C TIEB2 RlU Casing Tools. 06:30 - 09:00 2.50 WHSUR C TIEB2 P/U one Jt 133/8",68#, L-80, BTC Casing, M/U Casing Patch, and 10' Pup. RIH and Tag to of 13-3/8 Casing Stub. SIO on Casing Casing Stub 4 feet - full length of swallow on patch. Seat Patch on 133/8" Stub at 48' from RKB, 19.5' from Top of Conductor with 10,000 Ibs down weight. After Patch Seated P/U 10,000 Ibs over string weight to confirm set. 09:00 - 10:00 1.00 WHSUR C TIEB2 RlU Schlumberger and Pump 3 bbls of Water and 6.4 bbls of 15.8 ppg Class G Cement. RID and Flush Lines. 10:00 - 21 :00 11.00 WHSUR C TIEB2 Wait on Cement. Perform General Service and Maintainance on Rig 21 :00 - 00:00 3.00 WHSUR C TIEB2 RlU Wach's Cutter and Cut 133/8" Casing, UD Cut Joint, Prep Casing for Wellhead. Install FMC 133/8" Slip Lock Well Head. 7/15/2006 00:00 - 01 :30 1.50 WHSUR C TIEB2 Install FMC 133/8" Slip Lock Well Head. Test Seal Integrity to 800 psi for 15 Minutes. 01 :30 - 02:30 1.00 WHSUR C TIEB2 Nipple Up Tubing Spool 02:30 - 04:30 2.00 BOPSU C TIEB2 Nipple Up BOP Stack. 04:30 - 05:30 1.00 BOPSU C TIEB2 M/U Test Assembly and Fill BOP Stack and Choke Manifold 05:30 - 09:00 3.50 BOPSU C TIEB2 Test BOPE to 250 psi Low and 3,500 psi High. Hold Each Test for 5 Minutes. AOGCC Witness of Test Waived by Chuck Scheve. Test Witnessed by Doyon Toolpusher and BP WSL. 09:00 - 09:30 0.50 BOPSU TIEB2 Rig Down BOP Test Equipment. Blow Down Choke and Kill lines. 09:30 - 10:30 1.00 FISH C TIEB2 M/U BHA #8; 12-1/4" Bit, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, 96-1/4" DC's. Total Length = 316.74' 1 0:30 - 12:00 1.50 FISH C TIEB2 RIH to 9-5/8" Casing Stub. Tag Up at 2165'. 12:00 - 13:00 1.00 FISH C TIEB2 Drill on Cement from 2165' - 2172'. Pump 20 bbl High Vise Sweep and Chase Out of Hole at 9 bpm and 700 psi. Returns had drilled cement with very little Arctic Pack. 13:00 - 15:00 2.00 FISH C TIEB2 POOH and Stand Back DP and DC's. UD 12-1/4" Bit and Boot Baskets. 15:00 - 16:00 1.00 FISH C TIEB2 M/U BHA #9. 8-1/2" Bit, 1 4-3/4" DC, 13-3/8" Casing Scraper, Bumper Sub, Jars, 96-1/4" DC's. Total Length = 346.72' 16:00 - 17:00 1.00 FISH C TIEB2 RIH to top of 9-5/8" Casing Stub at 2172'. 17:00 - 17:30 0.50 FISH C TIEB2 Drill Through 2 feet of Cement in 9-5/8" Casing with 8-1/2" Bit. Continue in hole with Bit and Bottom 13-3/8" Casing Scraper on 9-518" Casing Stub. With Scraper on Stub Bit at 2208'. 17:30 - 19:00 1.50 FISH C TIEB2 PJSM with Little Red. Pump 125 bbls of 120 Deg Diesel at 5 bbls per minute. Chase Diesel with 20 bbl High Vise Pill and 315 bbls of 9.8 ppg Brine. 7 bpm at 260 psi. 19:00 - 19:30 0.50 FISH C TIEB2 POOH from 2,172' to 346' 19:30 - 20:30 1.00 FISH C TIEB2 UD Clean Out BHA 20:30 - 21 :00 0.50 FISH C TIEB2 Clear Rig Floor. Printed: 7/24/2006 11 :21 :04 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rig Number: Spud Date: 8fi/1997 End: 7115/2006 21 :00 - 23:00 2.00 FISH C TIEB2 M/U BHA #10, 11.75" WP Shoe, 1 x Jt 11.75" WP, Washover Boot Basket, XO, Bumper Sub, Oil Jar, XO, 9 x 6.125" Drill Collars, XO = 341 .31 ' 23:00 - 00:00 1.00 FISH C TIEB2 RIH with 4" DP from 341' to 1,007' 7/16/2006 00:00 - 00:30 0.50 FISH C TIEB2 RIH with BHA #10 to 2,153' 00:30 - 02:00 1.50 FISH C TIEB2 Establish Parameters, Up Weight 87,000#, Down Weight 88,000#, Rotating Weight 87,000#. 30 rpm with 1,500 ftIlbs Torque. 5 bpm at 160 psi. Wash Down see Top of Stub at 2,172'. Washover 9 5/8" Stub, 60 rpm at 4,000 - 6,000 ftIlbs of Torque, 9 bpm with 570 psi, WOM 2,000 - 5,000#. Washover to 2,204' 02:00 - 02:30 0.50 FISH C TIEB2 Circulate 20 bbl Hi-Vis Sweep Around. 02:30 - 03:30 1.00 FISH C TIEB2 POOH with 4" DP to 341'. 03:30 - 05:00 1.50 FISH C TIEB2 UD BHA #10. 05:00 - 05:30 0.50 FISH C TIEB2 Clear Rig Floor. 05:30 - 07:00 1.50 FISH P TIEB2 PJSM wI E-Line, RlU SWS Wireline Equipment and String Shot. 07:00 - 07:30 0.50 FISH P TIEB2 RIH wI E-Line and 12' - 3 Strand 80 Grain Sting Shot. Collar at 2194'. Shoot Sting Shot from 2188' - 2200'. 07:30 - 08:30 1.00 FISH P TIEB2 POOH with E-Line and Rig Down. 08:30 - 10:00 1.50 FISH P TIEB2 M/U BHA #11 - Back Off BHA. Mule Shoe, 96-1/4" DC's, Blanking Sub, Bottom Anchor, Back Off Tool, Upper Anchor, Pump Out Sub. Total Length= 328.26 ft. 10:00 - 12:00 2.00 FISH P TIEB2 RIH wI Back Off BHA on DP to 2295'. Tag Up on Something in Hole. MIU Top Drive and Rotate Slowly. Unable to Make Hole. Unable to Pump through Mule Shoe With Back Off Tool. Drop Dart, Open Pump Out Sub, and Establish Circulation. 12:00 - 14:00 2.00 FISH P TIEB2 POOH, Stand Back DP. UD Back Off Tool and Anchors. Stand Back DC's. 14:00 - 15:30 1.50 FISH P TIEB2 M/U BHA 12; 8-1/2" Bit, 2 Boot Baskets, Bumper Sub, Jars, and 9 DC's. Total Length = 312.1 ft 15:30 - 16:30 1.00 FISH P TIEB2 RIH with 8-1/2" Bit BHA to 2290'. 16:30 - 18:00 1.50 FISH P TIEB2 Establish Parameters. Up Wt = 83,000 Ibs, Down Wt = 87,000 Ibs, Rot Wt = 87,000 Ibs. Pump Rate 8 bpm at 530 psi, 2,000 ft-Ibs torque at 40 rpms. Wash down and Ream Cement at 2296',2330', & 2610'. Continue in hole to 3175'. Nothing Seen below 2610'. 18:00 - 19:00 1.00 FISH P TIEB2 Circulate Around 20 bbl High Sweep at 10 bpm and 800 psi. 19:00 - 20:00 1.00 FISH P TIEB2 POOH and Stand Back DP to 312' 20:00 - 21 :00 1.00 FISH P TIEB2 UD BHA #12. Clear Rig Floor. 21 :00 - 22:00 1.00 FISH P TIEB2 M/U BHA #13 - Back Off BHA. Mule Shoe, 96-1/4" DC's, Blanking Sub, Bottom Anchor, Back Off Tool, Upper Anchor, Pump Out Sub. Total Length= 328.26 ft. 22:00 - 00:00 2.00 FISH P TIEB2 RIH with Back-Off to 2,427' 7/17/2006 00:00 - 01 :00 1.00 FISH P TIEB2 Pressure Up to 1,000 psi and Set Bottom Anchor, Pressure Up to 2,000 psi and Set Top Anchor. Pressure Up to 950 psi Pipe Broke Free. Continue to Cycle Back-Off Tool Until Pipe has Been Backed Out 5 1/2 Turns. Drop Dart and Open Circulating Sub. Sub Sheared at 1,400 psi. Pump 23 bbls Brine 4 bpm at 210 psi. 01 :00 - 01 :30 0.50 FISH P TIEB2 POOH and Stand Back 4" DP to 328' 01 :30 - 02:30 1.00 FISH P TIEB2 UD Back-Off BHA. 02:30 - 03:00 0.50 FISH P TIEB2 Clear Rig Floor. Printed: 7/24/2006 11 :21 :04 AM ,- . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rig Release: 7/23/2006 Rig Number: Spud Date: 8n/1997 End: 7117/2006 03:00 - 03:30 0.50 FISH P TIEB2 M/U BHA #14, Bullnose, Spear Pack-Off, ITCO Type Spear (8.681" Grapple), Extension, Stop Sub, Bumper Sub, Oil Jar, XO. BHA Length = 35.13' 03:30 - 04:00 0.50 FISH P TIEB2 RIH with 4" DP to 2,134' 04:00 - 04:30 0.50 FISH P TIEB2 M/U Top Drive, Establish Parameters. 71,000# Up Weight, 74,000# Down Weight, 73,000# Rotating Weight. Slack Off and Engage Casing Stub at 2,172'. P/U to 74,000# and Rotate to the Left 6 Turns. Stub Came Free. 04:30 - 05:30 1.00 FISH P TIEB2 POOH and Stand Back 4" DP. 05:30 - 06:00 0.50 FISH P TIEB2 UD Casing Stub and Spear BHA. Cut Joint of 9-5/8" Casing = 20.87' Tube Body and Collar. 9-5/8" Casing Stub will have Pin End Looking Up. Cut Joint was in good shape, Collar was shaved on top quarter the rest of the collar was in good shape. 06:00 - 07:30 1.50 BOPSU P TIEB2 Pull Wear Ring. Set Test Plug. Change Out Pipe Rams to 9-5/8" and Test to 250 psi Low and 3500 psi High for 5 mins each - Good Test. Pull Test Plug. 07:30 - 09:00 1.50 CASE P TIEB2 RlU False Table, Side Door Elevators, Power Tongs, Turque Turn. Bring Up ES Cementer, Centrilizers, and Cement Head to Floor. 09:00 - 15:00 6.00 CASE P TIEB2 PJSM on Running Casing. M/U Baker Tripple Connect Screw In Sub, Baffle Collar, 1 Jt of 9-5/8" 40# BTC Casing, ES Cementer, 1 Jtof 9-5/8" 40 # BTC Pin x TC-II Box Casing and 54 Joints of 9-5/8" 40# TC-II L-80 Casing. Use Jet Seal Lube Guard Dope on TC-II Connections. All Connections Torque Turned and M/U to Optimal Torque of 12,600 ft-Ibs. Free Floating Centrilizers were placed on every joint above ES Cementer Except #54. 15:00 - 16:00 1.00 CASE P TIEB2 M/U Joint #54. Take Initial Parameters; Up Wt = 115,000 Ibs, SIO Wt = 122,000 Ibs, Rot Wt = 121,000 Ibs with 10 rpms and 2,000 ft Ibs. Slack Off Joint #54 while rotating at 10 rpm's. Slowly tag top of casing Stub at 2194'. Continue to rotate slowly while slacking off and M/U Screw In Sub to Casing Stub. Work Torque up to 13,000 ft-Ibs at surface and SIO pipe up to 30,000 Ibs weight to transfer torque to screw in connection. Once 13,000 ft-Ibs Torque was applied P/U instages from 150,000 Ibs to 250,000 Ibs to confirm connection of Screw- In Sub 16:00 - 17:00 1.00 CASE P TIEB2 RlU Pressure test line and Chart. Pressure test Casing intially to 1000 psi and confirm holding. Bring Pressure Up to 2000 psi and Hold for 30 mins. Good Test. Continue to bring pressure up and shear ES Cementer at 2800 psi. 17:00 - 18:00 1.00 CEMT P TIEB2 Rig Up HES Cement Head to 9-5/8" TC-II x BTC XO. Rig Up Cement Hose. RlU Dowell Cementers. PJSM with Dowell, Rig Crew and Vac Truck Drivers on Cement Job. 18:00 - 20:00 2.00 CEMT P TIEB2 Prime Up Cement Unit. PT lines to 4500 psi. Close Pipe Rams and Open OA Valve to 400 bbl tank. Confirm Circulation to Tank with Water and Pump 133 bbls of 15.8 Class G Cement at 5 bpm and 620 psi. Drop HES Closing Plug and Pump 5 bbls Cement and Chase with 9.8 ppg brine at 6 bpm. Slow Pump Rate to 2 bpm at 920 psi. Bump Plug with 158 bbls of displacement. Pressure Up to 1,920 psi. 1,000 psi Over Circulating Pressure to Close ES Cementer. Positive Indication That ES Cementer Closed at 1,840 psi. CIP at 19:40. Bleed Off Printed: 7/24/2006 11 :21 :04 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rjg Number: Spud Date: 8/7/1997 End: 7/17/2006 18:00 - 20:00 2.00 CEMT P TIEB2 Pressure and what for flow back - holding. Positive confirmation of cement to surface, approximately 10 bbls in returns. 20:00 - 20:30 0.50 CEMT P TIEB2 Flush and Blow Down Lines. 20:30 - 22:00 1.50 WHSUR P TIEB2 RID CMT Head, Split Stack, Suck Out Landing Jt. Set Slips with 100,000# 22:00 - 23:00 1.00 WHSUR P TIEB2 RlU Wach's Cutter and and Cut 9 5/8" Casing. 23:00 - 00:00 1.00 WHSUR P TIEB2 UD Cut Joint, Set Back BOP Stack and Install 95/8" Pack-Off. 7/18/2006 00:00 - 03:30 3.50 WHSUR P TIEB2 Install 9 5/8" Pack-Off, Torque Lockdown Screws to 450 ftIlbs. Test Pack-Off to 2,400 psi for 30 Minutes. 03:30 - 05:30 2.00 BOPSU P TIEB2 NIU BOP Stack. Change Lower Set of Rams from 9 5/8" to 3 1/2" x 6" Variables. 05:30 - 06:30 1.00 BOPSU P TIEB2 Body Test and Lower Rams to 250 psi Low and 3,500 psi High. Hold Each Test for 5 Minutes. Test with 4" and 4.5" Test Joints. Tests Were Witnessed By the DDI Toolpusher and the BP WSL. 06:30 - 07:00 0.50 BOPSU P TIEB2 Rig Down Test Equipment, Pull Test Plug and Install Wear Ring. 07:00 - 09:00 2.00 CEMT P TIEB2 WOC. CIO Saver Sub on Top Drive. Grease Crown, Blocks, Draw Works and Top Drive. 09:00 - 10:00 1.00 CEMT P TIEB2 M/U 8-1/2" Bit, Bumper Sub, Jars, DC's. Total Length of BHA = 322 ft 10:00 - 11 :30 1.50 CEMT P TIEB2 RIH with 8-1/2" Bit on DP Derrick. Tag Top of Cement at 2099'. 11 :30 - 12:45 1.25 CEMT P TIEB2 Drill Cement Soft Cement From 2099' to 2145'. Drill ES Cementer from 2145' to 2148'. Took 1 hr 15 mins to drill Cementer wl5k - 15K WOB, 60 rpm's, 3-5k Torque. Varied Pump Rate From 1.5- 9.0 bpm. Pump Pressure at 9.0 bpm = 530 psi. 12:45 - 14:30 1.75 CEMT P TIEB2 Drill Hard Cement Below ES Cementer. Best ROP with 15k WOB, 80 rpm's, 3-5k Torque and 8-9 bpm. Drill Cement to 2185'. 14:30 - 15:30 1.00 CEMT P TIEB2 Circulate around 20 bbl High Vise Sweep at 10 bbl per min at 600 psi. 15:30 - 16:30 1.00 CEMT P TIEB2 P/U One Stand Off Bottom and Rig Up Pressure Test Equipment and Chart. Pressure Test Casing to 3500 psi for 35 mins. - Good Test. 16:30 - 17:00 0.50 CEMT P TIEB2 Drill Out More Cement and Baffle Collar at 2190'. 17:00 - 18:30 1.50 CEMT P TIEB2 Trip in hole to top of sand. Found Top of Sand at 3188'. Washed and Reamed to 3,188' at 1 bpm and 60 psi,60 rpm and 2-4,000 ft-Ibs Torque. 18:30 - 19:30 1.00 CEMT P TIEB2 Swap Well Over to Clean Seawater. 19:30 - 20:30 1.00 CEMT P TIEB2 POOH f/3,177', to 312'. 20:30 - 21 :00 0.50 CEMT P TIEB2 BIO & UD 8.5" Clean Out Assembly. 21 :00 - 21 :30 0.50 CEMT P TIEB2 M/U Reverse Circulating Basket BHA. 21 :30 - 22:30 1.00 CEMT P TIEB2 RIH f/320' and Tagged Up at 3,188'. 22:30 - 00:00 1.50 CEMT P TIEB2 Washed and Reamed f/3, 188' to 3,194' wlReverse Circulating Basket 7/19/2006 00:00 - 01 :00 1.00 CEMT P TIEB2 Washed Down to Sand at 3,200' wlReverse Circulating Basket. Had to work Reverse Basket down. Still Seeing Junk in Hole. 01 :00 - 02:00 1.00 CEMT P TIEB2 POOH To BHA 02:00 - 03:00 1.00 CEMT P TIEB2 Handle BHA. BIO Reverse Circ Basket and Boot Baskets. Reverse Circulating Basket Plugged with rubber and a solid Printed: 7/24/2006 11 :21 :04 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rjg Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rjg Release: 7/23/2006 Rjg Number: Spud Date: 8fi/1997 End: 7119/2006 02:00 - 03:00 1.00 CEMT P TIEB2 core chunk of cement. Boot Baskets contained metal pieces and cement. 03:00 - 04:30 1.50 CEMT P TIEB2 RIH wI Rev Circ Basket to 3,213' 04:30 - 05:00 0.50 CEMT P TIEB2 Reverse Circulate f/3,213' to 3,240'. Hole Seems Clean - No junk present to rotate over. 05:00 - 06:00 1.00 CEMT P TIEB2 Circulate Bottoms Up 06:00 - 07:00 1.00 CEMT P TIEB2 POOH and Stand Back DP and Collars. 07:00 - 08:00 1.00 CEMT P TIEB2 BIO and UD Reverse Circ Basket and Boot Baskets. Nothing Found in Reverse Basket. Boot Baskets contained big pieces of brass shear bolts and smaller pieces of aluminum mixed with cement pieces. 08:00 - 08:30 0.50 CLEAN P DECOMP P/U HES Retrieval Tool for 9-5/8" RBP and M/U to DP. 08:30 - 09:30 1.00 CLEAN P DECOMP RIH with Retrieval Tool to 3160'. 09:30 - 10:00 0.50 CLEAN P DECOMP M/U Top Drive, Establish Parameters. Up Wt 87,000 Down Wt 81,000 Ibs. Pump Rate = 6.7 bpm at 350 psi. Tag up on RBP and Watch Pressure Build to 490 psi at same pump rate. Set Down 10K Ibs under String Wt and make 1/4 turn to Rt. Pick Up, No Over Pull Seen and Pump Pressure Decreased. RIH again to Depth, Set Down 15K Ibs under String Wt, Pump Pressure Increase Same. Pick Up, See - 5K Ibs Over Pull. RIH to confirm and not taking wt at set depth. Have RBP. 10:00 - 11 :00 1.00 CLEAN P DECOMP Circulate 20 bbl High Vise Sweep Surface to Surface at 8 bpm and 430 psi. A small volume of sand and small cement pieces seen over the shakers with sweep. 11 :00 - 12:30 1.50 CLEAN P DECOMP Flow Check and POOH. Stand Back DP in Derrick. 12:30 - 14:00 1.50 CLEAN P DECOMP UD HES RBP. UD 6-1/4" DC's. 14:00 - 15:00 1.00 CLEAN P DECOMP M/U 4-1/2" SL Adapter and 2-7/8" PAC BHA. WOT Eclipse Ret Tool, 4" GS Spear, 3 Joints of 2-7/8" PAC, Pump Out Sub, 9-5/8" Casing Scraper, Bit Sub, Bumper Sub and Jars. Total Length = 131.03 ft. 15:00 - 19:00 4.00 CLEAN P DECOMP RIH wI Eclipse Ret Tool on 4" DP from Derrick. P/U 9 jts DP f/Pipe Shed. 19:00 - 22:00 3.00 DHB P DECOMP Tagged up at 8,411' Attempted to Stack Weight On Eclipse Packer. Continued in Hole to 8,429' Able to Stack 10,000#, Pulled to Neutral Weight No Confirmed Latch, Repeat Process twice No Confirmed Latch. Washed Down and Circulated on Packer w/3 bpm and 2,200 psi. Confirmed Latch with 6,000# Over Pull. Dropped Shifting Ball and Rod, Opened Circulating Sub at 2,100 psi. Pulled Packer Out of 4.5" Tubing. Well Began Taking Fluid at 180 bbl, Losses Tappered of to 81 bph, 22:00 - 00:00 2.00 CLEAN P DECOMP Circulate Bottoms Up at 8 bpm,and 1,270 psi, Losses Approx 135 bph. 7/20/2006 00:00 - 06:30 6.50 CLEAN P DECOMP Laying Down 4" Drill Pipe, Retrieving Eclipse Packer. Losses at 81 bph. 06:30 - 07:30 1.00 CLEAN P DECOMP BIO and UD Bumper Sub, Jars, and Xo's. BIO and UD Eclipse Packer. Packer and Tail Pipe Assembly Complete Except Missing Rubber Element From Packer. 07:30 - 08:30 1.00 CLEAN P DECOMP BIO and UD 3 Stands of DP from Derrick. 08:30 - 10:00 1.50 RUNCO RUNCMP Clean and Clear Rig Floor. Rig Up Tubing Handling Equipment and Torque Turn Equipment. Double Check Completion Jewlery and Running Order. 10:00 - 12:30 RUNCMP M/U and RIH wI Completion. 4-1/2" WLEG, X Nipple wI RHC-M, Baker S-3 9 Cr Pkr, X-Nipple, 4-1/2" MMG GLM, and Printed: 7/24/2006 11 :21 :04 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: 7/5/2006 Rig Release: 7/23/2006 Rjg Number: Spud Date: 8/7/1997 End: 18 Joints of 4-1/2", 12.6#, 13Cr80VamTopTbg. HMAN Dropped 4-1/2", 12.6# Completion String in Hole, 18 Jts of Tubing Plus all Jewelry. Investigate on what happened; D-Ring connecting compensator and pick up slick caught handle of hand slips as blocks were being picked up to pick up to pull next joint off the pipe skate. Call Safety Meeting; Discuss with Crew about Incident and Working Safe. 13:30 - 14:00 0.50 RUNCO HMAN RUNCMP RID Tubing Handling Equipment and Torque Turn Equipment. 14:00 - 14:30 0.50 FISH N HMAN DECOMP Safety Brief with Tod Toddle of DDI in Dog House. 14:30 - 20:00 5.50 FISH N HMAN DECOMP Wait on Orders, Procedures, and Equipment. Load Drill Pipe in Shed and Lay Herculite and Mat Boards on next location. 20:00 - 00:00 4.00 FISH N HMAN DECOMP Load Pipe Shed with 4.5" NSCT Tubing Work String, Tally and Drift all Jts. 7/21/2006 00:00 - 06:00 6.00 FISH N HMAN DECOMP Continue Loading, Drifting, and Tallying 4.5",12.6#, L-80, NSCT Work String in Pipe Shed. Heavy Scale In Tubing Difficulty Drifting. 06:00 - 06:30 0.50 FISH N HMAN DECOMP PJSM-Picking Up and M/U 4.5" Work String. RIH 06:30 - 14:00 7.50 FISH N HMAN DECOMP RIH wI 4-1/2" NSCT Work String and Screw In Assembly. Screw In Assembly = 7.86' Skirt OD= 7-5/8". 14:00 - 15:00 1.00 FISH N HMAN DECOMP Establish Parameters; Up Wt = 126,000 Ibs, Dw Wt = 105,000 Ibs, Rot Wt = 117,000 Ibs. See Wt at -7400', unable to screw into push fish to bottom trying to screw into. Tag Up and able to screw into fish at 7475', bottom of fish at 8365'. Rotate at 10 rpms and screw into fish. Work 4,000 ft-Ibs Torque down to Fish. 15:00 - 16:30 1.50 FISH N HMAN DECOMP POOH wI fish. Pulling up to 20,000 Ibs over, After 10 jts only 10,000 Ibs over. 16:30 - 18:00 1.50 FISH N HMAN DECOMP Reverse Circulate at 4.0 bpm and 170 psi. Loosing approx 3/4 bpm. 18:00 - 00:00 6.00 FISH N HMAN DECOMP POOH fl7,094' and UD, 4.5" 12.6#, L-80, NSCT Work String. 7/22/2006 00:00 - 00:30 0.50 FISH N HMAN DECOMP Continue to POOH and UD 4.5" Work String f/820' 00:30 - 02:30 2.00 FISH N HMAN DECOMP UD Skirted Screw In Sub, POOH and UD w/4.5" Vam Top Tubing. 02:30 - 03:00 0.50 FISH N HMAN DECOMP UD 1-4.5" x 1.5" GLM, 1-X-Nipple, 18 jt Tubing, S-3 Packer 9-518" x 4-1/2" , 1-X-Nipple wI RHC-M, 1 Wire Line Entry Guide. Packer Element and Slips all accounted for and in good shape. WLEG had worn groove approx. 2.5" from tip, due to the rotation required to screwing into top of fish with retrieval tool. 03:00 - 03:30 0.50 N HMAN DECOMP Pull Wear Ring. 03:30 - 06:00 2.50 HMAN RUNCMP Clear and Clean Rig Floor, RlU to Run Completion. RlU Power Tongs, Elevators, Compensator, and Single Joint Clamp and Sling. Load, Strap, Drift and Talley New Completion Jewelry and 18 joints of 4-1/2" Vam Top 12.6# 13Cr80 Tbg. 06:00 - 16:30 RUNCMP Held PJSM With Rig Crew, Casing Crew and Baker Packer Hand, P/U and Run 4.5" 12.6#, 13CR80, Vam Top Completion. Using Jet Lube Seal Guard Pipe Dope, Avg M/U 4,400 ftllbs Torque using Torque Turn. WLEG, 3 X Nipples, 1 Baker S-3 Perm 9 Cr Packer, 4 GLM Assemblies, and 190 Joints of Tubing. 16:30 - 17:00 0.50 RUNCO RUNCMP M/U FMC Tubing Hanger 13-5/8"x4-1/2" Tbg Hanger, 4-112" TC-II Landing Threads. M/U 4-1/2" TC-II Landing Joint to Hanger and Circulating Head. Printed: 7/2412006 11 :21 :04 AM · ' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-14A D-14A WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 7/5/2006 7/23/2006 Spud Date: 8fi/1997 End: 1 qt Seawater Leak, Reported at 16:35. Leak occured from a coiled up hose as it was laid out in prep for Hot Seawater Trucks. 17:00 - 17:30 0.50 RUNCMP Rig Up Circulating Manifold and to IA and to Cement Line. Wait On Hot Seawater Trucks. 17:30 - 18:30 1.00 RUNCMP All Hot Seawater Trucks on Location. Land Tubing Hanger and RILDS. Final Wts before Landing. P/U Wt = 136,000 Ibs, SIO Wt = 115,000 Ibs. 18:30 - 22:30 RUNCMP PJSM with Rig Crew, Baker Packer, FMC, Veco Truck Drivers On Displacing Well to Corrosion Inhibited Seawater. Tested Lines to 3,500 psi. Pumped 130 bbl of 140 deg Sea Water, Followed By 460 bbls Corrosion Inhibited Sea Water. At 3 bpm and 110 psi. 22:30 - 23:00 RUNCMP Dropped Ball and Rod, Set Packer to 3,500 psi TC-II Connection Leaked, RID Landing Jt R/U to Test Tubing Under Blind Rams. 23:00 - 00:00 RUNCMP RID Landing Jt RlU to Test Tubing Under Blind Rams. 7/23/2006 00:00 - 00:30 RUNCMP Test Tubing to 3,500 psi for 30 Minutes Good Test. 00:30 - 01 :00 RUNCMP Bleed Tubing to 1,500 psi, Pressured up on Annulus, At 1,700 psi Tubing Pressure Tracked Annulus Pressure, Bled Off Pressure, Both Tubing and Annulus Pressure Bled to O. Re-Tested With Same Results. 01 :00 - 02:00 RUNCMP Checked and Tested Surface Equipment to Trouble Shoot Communication Issue. 02:00 - 03:00 RUNCMP RlU Landing jt Pressured up On Tubing to 1,500 psi, Then Pressured up On Annulus at 1,700 psi Tubing Pressure Tracked Annulus Pressure to 2,500 psi Shut Down Pump Pressure Stable. 03:00 - 04:00 RUNCMP Established Leak Rate Pumping Down Annulus of 3 bpm w/300 psi. Pressured Up On Tubing Side to 1,500 psi and Shut in Pressure. Pressured Up On Annulus Side to 1,800 psi and Tubing Pressure Track with Annulus Pressure Continued Pumping to 3,500 psi and Held For 30 Minute Test 04:00 - 04:30 0.50 RUNCMP RID UD Landing Jt and Test Equipment 04:30 - 05:00 0.50 RUNCMP Set TWC and Test to 1,000 psi, Blow Down Pumps and Manifold. 05:00 - 06:00 1.00 RUNCMP NID BOPE. 06:00 - 09:00 3.00 RUNCMP NIU Adapter Flange And Tree, Test adapter flange to 5,000 psi f/30 min. 09:00 - 10:00 RUNCMP Test Tree to 5,000 psi f/30 min - Chart Recorded. Tree alignment and Pressure Test witnessed by WSL and D-Pad Operator. 10:00 - 10:30 RUNCMP Pull TWC RID DSM. 10:30 - 11 :00 RUNCMP RlU tp Freeze Protect Well, Held PJSM Pressure Test Lines to 2,500 psi. 11 :00 - 13:00 2.00 RUNCMP Reverse Circulate in 180 bbls of Diesel, @ 2 bpm w/620 psi. 13:00 - 15:00 2.00 RUNCMP U-Tube Well. 15:00 - 15:30 RUNCMP RlU DSM Set BPV. 15:30 - 16:00 RUNCMP Pressure Test BPV to 1,000 psi. Good Test. 16:00 - 16:30 RUNCMP RID BID Secure Well. Rig Released 16:30 hrs. Printed: 7/24/2006 11 :21 :04 AM lì",., ~ vUI" ¡'/L ,\ ; Jv' L ,- ,-¡ :~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report PTD#: 1961530 DATE: 71712006 Contractor/Rig No.: Doyon 16 Operator: BP EXPLORATION (ALASKA) INC Type Operation: WRKOV Type Test: WKL Y MISe. INSPECTIONS: P/F P P P P P P P NA Location Gen.: Housekeeping: PTD On Location Order Posted Well Sign Drl. Rig Hazard Sec. Misc FLOOR SAFTY VALVES: Quantity P/F 1 P 1 P 1 P 1 P o NA Upper Kelly Lower Kelly Ball Type Inside BOP FSV Mise Test Results Number of Failures: 1 Operator Rep: 1. Willingham Rams: Annular: Valves: Reviewed By: ' P.I. Suprv :.~7/25'kt, Comm Inspector Jeff Jones Rig Rep: K. Wahrung Insp Source Ins peetor Test Pressure: 250/3500 250/3500 250/3500 Inspection No: Related Insp No: bopJJ060711205703 TEST DATA MUD SYSTEM: ACCUMULATOR SYSTEM: Visual Alarm TimefPressure P/F Trip Tank P P System Pressure 2925 P Pit Level Indicators P P Pressure After Closure 1900 P Flow Indicator P P 200 PSI Attained 0:15 P Meth Gas Detector P P Full Pressure Attained 1:08 P H2S Gas Detector P P Blind Switch Covers: All P ~---- MS Mise NA NA Nitgn. Bottles (avg): 5 @2100 P ACC Mise 0 NA BOP STACK: Quantity Size <\.nnular Preventer 1 13 5/8 Pipe Rams 1 7 Lower Pipe Rams 0 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 2 Check Valve 0 none BOPS Mise 2 13 5/8 Blind 31/8 31/8 31/8 ......-~ P/F P P NA P P P P NA FP CHOKE MANIFOLD: Quantity P/F No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P CH Misc 0 NA Remarks The flange between the BOPE stack and the tubing spool and 2 tubing spool Jockdown screws failed the pressure tests, These items were tightened and passed the re-tests, ",,(" Á:'.~~;~ j , ~",.i"\./,r~ '~,,J :;~'.H"· e 0 og escrlptlon ate oor 15-12A 11211420 ,,~ ",,,,",vcL PACK 06/25/06 1 17-08 11211509 INJECTioN PROFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-o6A 11217266 INJECTION PROFILE 07/12/06 1 P2-o1 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-o8 11217256 PROD PROFILE W/GHOST & DEFT 06/06/06 1 16-o4A 11217245 PROD PROFILE W/DEFT 05/08/06 1 05-40 11223123 LDL 07/07/06 1 17-09 11211412 PROD PROFILE WID EFT & GHOST 06/26/06 1 MPC-07 NIA SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 1.!-51 11212873 USIT 06/28/06 1 04-31 11217264 USIT 07/07/06 1 D-14A 11217265 US IT 07/09/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2-18A 11217234 MCNL 04/06/06 1 1 L5-o9 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 12"()1 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30/04 1 Scblunlberger Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ¡Ct0 - 153 WII J b# L D D BL ;.(J Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 07/19/06 NO. 3880 Company: State of Alaska Alaska Oil & Gas Cons Comm Artn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay CI CD e e Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth e e :-::J l~ j 1 ;1 :1 j 1 ~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~c""NhlED JUN ~i ( Re: Prudhoe Bay Field, Prudhoe Bay OiLPocl,PBU D-14A Sundry Number: 306-231 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisZ.f day of June, 2006 Encl. \1 &/'07/0(; D~ 6/1f(. "jvh W6A- tp/1.s{?polç> \~ 0 . STATE OF ALASKA 14'10' i ' RECEIVED ~~\ ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 7 2006 , APPLICATION FOR SUNDRY APPROMtß~'&G 20 MC 25.280 a I A a~ Cons. Commission nc orage 1. Type of Request: 0 Abandon 181 Repair Well o Plug Perforations o Stimulate o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended W 2. Operator Name: 4. Well Class Bef07Work: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development 0 Exploratory 196-153 ,- 3. Address: o Stratigraphic o Service 6. API Number: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20450-0 1-00 7. KB Elevation (ft): 71.5' 9. Well Name and Number: PBU D-14A .,r" 8. Property Designation: 10. Field / Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Pool 111\;',.<,> f...... . < !i ..' ....... f';! :. .....f WI-II ~I ',f .i ii! <. 212'E'ii·c'Ci.i·!..'!'¡ii!. .i' Total Depth MD 1ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 10920 9013 10730 9034 10730 None Casing Length Size MD / TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2684' 13-3/8" 2684' 2684' 4930 2670 Intermediate 8894' 9-5/8" 8894' 8369' 6870 4760 Production Liner 983' 7" 8417' - 9400' 7922' - 8851' 8160 7020 Liner 2488' 2-7/8" 8432' - 10920' 7936' - 9013' 13450 13890 Perforation Depth MD (ft); I Perforation Depth TVD (ft): I WSize: Tubing Grade: Tubing MD (ft): 10500' - 10880' / 9031' - 9023' -1/ . 12.6# L-80 8458' Packers and SSSV Type: 9-5/8" GUIB Polar Packer ,--,=", I Packers and SSSV MD (ft): 8354' /. 12. Attachments: 13. Well Class after proposed work: / ~ Description Summary of Proposal 0 BOP Sketch o Exploratory ~ Development o Service o Detailed Operations Program ~'" 14. Estimated Date for J~y 15, 106 15. Well Status after proposed work: Commencing Operations: ~Oil o Gas o Plugged o Abandoned 16. Verbal Approval: D~ o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski. 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Siqnature / ~~'L . Date /j., //'I/. Prepared By Name/Number: Phone 564-4303 Terrie Hubble, 564-4628 ¿::1' Commission Use Only . I Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: m n .. ~~I . o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Tel7 t BoPf tv ~ c;vo , RBDUS 8Ft JUN 2 9 2006 Other: fe....· Subsequent Form Required: \0 - (La ~MMISSIONER APPROVED BY 6/zJ) ð6 Approved By: --~ THE COMMISSION Date Form 10-403 Revised 07/2005 L/ '-C/ \.. S,.6bmit In Duplicate (JR1Gl~JAI e e Obp G~ D-14A Rig Workover Scope of Work: Pull 4-W' completion, cut and pull 9-5/8" casing, run and cement to surface new 9-5/8" casing, run ~:W" 13CR-80 completion. MASP:~2(Ybsi Well T~roducer Estimated Start Date: July 15, 2006 Pre-ria [ reD work: F 1 Verify LOS for movement. PPPOT T & IC. E 2 Chemical cut tubinq @ 8328' - DONE 5/20/2006 0 3 Circulate well with seawater and FP with diesel. CMIT TxlA to 3500 psi. MITOA to 2000 psi.- DONE on 5/31/2006. 0 5 Set BPV. 0 6 Remove the wellhouse & flow line. Level the pad as needed for the rig. ProDosed Procedure / 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 7" tubing string to the cut. 3. US IT Log 9-5/8" casing for top of cement (TOC) 4. Cut the 9-5/8" above the TOC and retrieve / 5. Run and fully cement new 9-5/8" casing to surface 6. Run 4-W' 13CR-80 completion with Baker S-3 packer. Position packer at -8250' MD. 7. Displace the IA to packer fluid and set the packer. / 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 9. Set BPV. NO BOPE. NU and test tree. RDMO. TREE = WELLHEAD = ACTIJA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum 1\1[) = Datum lVD = 6"ON OCT CNV 0115 71.52' 46.72' 3000' J8@ 10020' 9422' 8800' SS D-14A SAFETY NOTES: HORIZONTAL WELL - 70° @ 9557' AND 90° @ 10043' 2035' 7" OTIS SSSV LANDING NIP, ID = 5.962" 113-318" CSG, 72#, L-80, 10 = 12.347" H 2685' . 2684' -i FOC I TOP OF 2-7/8" LI'IR CHEM CUT (05121/06) Minimum ID = 2.387" @ 8410' 2-7/8" LNR, PIN END 17" TBG, 26#, L-80, .0383 bpf, ID = 6.276" 8355' 7" X 4-112" XO 9-5/8" GUIB POLAR PKR, ID = 3.833" TOPOF4-112"TBG I I TOP OF 7" LNR I 8432" 8432' -12-7/8" BKRGS DEPLOYMENTSLV 8427' 4-112" 0115 XN NIP, 10 = 3.725" (BEHIND 2-7/8" LNR) 4-112" TAILPIPE, 12.6#, L-80, ID = 3.958" 8458' 8458' 4-112" TBG TAIL, ID = 3.958" (BEHIND 2-7/8" LNR) 8474' H ELMDTTLOGGED10/17/80 1 9-5/8" CSG, 47#, L-80, ID - 8.681" 8894' ÆRFORA TION SUI\IMARY REF LOG: SPERRY -SUN I\IMICVGR ON OS1271'ð7 ANGLE AT TOP ÆRF: 86 @ 10500' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 1-213" 4 10500 - 10560 C 05129197 1-213" 4 10600 - 10660 C 051'29/97 1-213" 4 10800 - 10880 C 0Sf02J99 I MlLLOUT WMXNV 9400' - 9407' 9813' 9863' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.372" 939T I TOP OF BKR WHIPSTOCK I CEMENT PLUG H 9447' DATE 06180 05129197 06125103 01129104 02I10f05 02I10f05 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK COM PETlON PULL 1 RUN PATCH BY fTl.P AJLAR PKRIXO CORRECTIONS JLIWTLH PATCH PULLED 912004 NBFfTl.H PACKER SET 1124105 DATE REV BY COMM:NTS 05121106 GJBlPJC CHEM CUT @ 8328' PRUDHOE BAY UNIT WELL: [)'14A PERMIT No: '1961530 API No: 50-029-20450-01 SEC23, T11N, R13E. 2569.49' FSL & 1067.01' Fa. BP Exploration (Alaska) = 6" ON OCT ON OTIS 71 .52' 46.72' 3000' )8@ 1œ2O' 9422' 8800' SS INELLHEAD = AClUA TOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum I'vO = Datum lYO = 113-318" CSG, 72#, L-80, ID = 12.347" H 2686' Minimum ID = 2.34" @ 8410' 2-7/8" LNR, STL PIN CONN 17" TBG, 26#, L-80, .0383 bpf, ID = 6.276" ! 8355' TOP OF 4-1/2" TBG TOPOF7" LNR I 8432' 8408' TOPOF2-7/8" LNR I roposed Completion -14-112" HES X NIP, ID .. 3.813" I GAS LIFT MANDRELS iIID lYO œv lYPE VLV LATCH PORT ~TE -8250 4-112" HES X NIP, ID = 3.813" 4-1/2"HESXNIP,ID"'3.813" -17" X 4-112" XO I -19-5/8" GUIB POLAR PKR, ID" 3.833" 8396' H4-1I2"HESXNIP,ID=3.813" I 8432' 2-718" BKR G DEPLOYMENT SLV 8427' 4-112" HES XN NIP, ID = 3.725" (BEHIND 2-7/8" LNR) 14-112" TAILPIPE, 12.6#, L-80, ID = 3.958" I 9-518" CSG, 47#, L-80, ID = 8.681" I 8458' 4-112" TaG TAIL, ID = 3.958" (BEHIND 2-7/8" LNR) 8474' H ELMDTTLOGGED10/17/80 I PERFORA TtON SUMlllARY REF LOG: SPERRY -SUN IINV[YGR ON OS/27/97 ANGLE AT TOP PERF: 86@ 10500' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz ~TE 1-213" 4 1 0500 - 10560 C C'l5f2!3197 1-2/3" 4 10600 - 10660 C D5129197 1-2/3" 4 10800 -10880 C 08102199 I CEMENT PLUG H 9447' 9813' 9863' 7" LNR, 26#. L-BO. .0383 bpf, ID = 6.276" REV BY COMMENTS ORIGINAL COMPLErION HlTL SIDETRACK COM PEnON BJIWKK RJLL J RlA'J PATCH BY ITLP POLAR PKRlXO CORRECTlOf'ß JliWT'LH PATCH RJLLED 912004 NBFITLH PACKER SET 1/24105 I MLLOUT WINDOW 9400' - 9407' I 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.372" DATE REV BY COMMENTS OS/21 f06 GJBfPJC CHEM CUT @ 8328' PRlDHOE BAY UNIT' WELL: D-14A FERMlT No: "1961530 AA No: 50-029-20450-01 SEC23, T11N, R13E, 2569.49' FSl & 1067.01' FEL BP Exploration (Alaska) 08105103 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2933 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Well Job # Log Description Date Blueline Prints CD D.S. 9-04A I ~ ~.~'{'~'~-~. Z~ PROD PROFILE/DEFT 07/31/03 NK-38 ' ! ~ ~ ~/'~_~ STATIC PRESSURE SURVEY 08101/03 E-10A ~ ~/~ ~'~L.[, ~) LDL 07~07~03 C-16I ~-'~ ~ ~ G~VEL PACK W/RST-C 04~30~03 D.S. ~-16 ~ ~ [~"~:~ PROD PROFILE/DEFT/GHOST 06~05~03 R'34 ~ ~ ~' ~ ~ INJECTION PROFILE 05/~7/03 D.S. 7-21 ~ ~ ~ -~ LDL 07/30/03 D-~4A i ~( ~" ~ ~5.~ LDL 07/28/03 "=-0~ ~ ~ ~'C~lq C""" 0~/0~/0~ A-0S I ~~'~ ~ ~ PROD PROFiLE/DEFT 05/~7/03 D.S. 4-~A ~q ~' ~,~'~ LDL 07/2~/03 3-25/M-27 t ~C;~ ~ SCMT (REPRINT-DEPTH SHIFTED) 01/04/03 ~s-~ss ~d-~--~ 234~4 CH aKa ~R (PDC) 03/0~/03 *{PRINTS SENT OUT 5/08/03) ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest ... -',,, 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'i-I'N: Beth Received b:yl STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] SuspendF1 Operation Shutdownr-1 Perforate[-1 VarianceE] Annuar Disposal['-~ After CasinqD Repair Well[] Plu¢~ Perforationsr-] StimulateE] Time Extension E] OtherE] Change Approved Program[~ Pull Tubingr'l Perforate New PoolE~] Re-enter Suspended weliF~ PULL/SET PATCH 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development [ ExploratoryE] 196-153 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 StratigraphicE~ serviceE] 50-029-20450-01-00 7. KB Elevation (ft): 9. Well Name and Number: 71.52 D-14A 8. Property Designation: 10. Field/Pool(s): ADL 028285 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10920 feet true vertical 8941 feet Plugs (measured) H ES CIBP @ 10730' (08/02/1999). Effective Depth measured 10730 feet Junk (measured) true vertical 9034 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 135' 135' 40K 520 Surface 2660' 13-3/8" 2685' 2684' 80K 2670 I nterm ediate 8869' 9-5/8" 8894' 8369' 80 K 4760 Liner 463' 7" 9400'-9863' 8850'-9010' 80K 7020 Sidetrack Liner 2510' 2-7/8" 8410'-10920' 7915'-9013' 80K 11160 Perforation depth: Measured depth: Open Perfs 10500'-10560', 10600'-10660'. Peris below CIBP 10880'-10880'. True vertical depth: Open Peris 8959'-8960', 8961 '-8962'. Peris below ClBP ~.~E Tubing: (size, grade, and measured depth) 7" 26# L-80 TBG @ 8354'. 7"x 4-1/2" XO @ 8354'.JUL 0 ?., 2.003 4-1/2" 12.6# L-80 TBG @ 8458'. Packers & SSSV (type & measured depth) 9-5/8" x 7" GUIB Polar Packer @ 8354'. J~laSk8 0il ~'' 7" Otis SSSV Landing Nipple @ 2035'. A~'~ch0rage ,12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: Exploratory r~ Development ~ service Copies of Logs and Surveys run _ 16. Well Status after proposed work: Oil[] GasE] WAGE] GINJE] WINJE] WDSPLE] Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeWa.vne R. Schnorr ,, Title Techical Assistant Signature ~~~~~,P h~n em 907/564-5174 Date June 30, 2003 .............. ~, - Form10-404 Revised~'~~~`''~ JUL S ZUU; U I . Rlil 8 JUL o 3 ZOO O5/28/2OO3 05/29/2003 O6/O4/2OO3 O6/O5/2OO3 O6/O6/2OO3 06/08/2003 06/18/2003 06/19/2003 06/19/2003 06/20/2003 O6/2O/2O03 06/21/2003 06/22/2003 O6/23/2OO3 06/25/2003 06/26/2003 06/27/2003 06/29/2003 O5/28/O3 05/29/03 06/04/03 O6/O5/O3 D-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING TAIL PLUG PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING PATCH TUBING / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: / LINER: DRIFT/TAG; TUBING TAIL PLUG DRIFT/FAG; PATCH TUBING / CASING; TUBING PATCH TUBING / CASING PATCH TUBING / CASING PATCH TUBING / CASING PATCH TUBING / CASING FISH; PATCH TUBING / CASING FISH DRIFT/TAG; PATCH TUBING / CASING; TUBING AC-FLUID LEVEL DRIFT/TAG; PATCH TUBING / CASING TUBING TAIL PLUG TUBING TAIL PLUG AC-FLUID LEVEL; AC-MONITOR PATCH TUBING / CASING PATCH TUBING / CASING SSSV C/O OR STROKE AC-EVAL; AC-IVlITIA EVENT SUMMARY <<< WELL SI UPON ARRIVAL >>> PRE DRIFT TO 7" INSERT. PULL 7" INSERT @ 2035'MD. TURN WELL OVER TO DSO - DO NOT FLOW WELL. RDMO. <<< PATCH IN HOLE, XX PLUG IN HOLE >>> <<< WELL S/I UPON ARRIVAL >>> DRIFT W/5.95 GUAGE RING. RUN 7" PRT (OAL=72") (3 TIMES). BRUSH W/4.5" BRAIDED LINE BRUSH. ATTEMPT TO PULL PATCH W/PRT FAILED DUE TO PRT PULLING OUT OF PROFILE. WILL RETURN W/RELEASABLE SPEAR. TURN WELL OVER TO PAD OPERATOR/LEAVE WELL S/I. <<< PATCH & TUBING TAIL PLUG IN HOLE >>> SET LONG VERSION OF RELEASABLE SPEAR. UNLOCKED PATCH. PULLED LONG SPEAR.AND SWAP TO SHORT SPEAR. RUN SHORT RELEASABLE SPEAR, LATCH PATCH @ 8319' SLM. START BEATING UP W/4 1/2" CS. JOB IN PROGRESS. ATTEMPTING TO PULL 16' X 7' DWP PATCH WITH RELEASABLE SPEAR SET UP. GOT PATCH TO MOVE UP HOLE 6'. RAN BACK IN WELL AGAIN WITH LONG SPEAR.TO INSURE FULLY UNLOCKED. PATCH DROPPED 25', TO CROSSOVER @ 8336' SLM. SHEAR OFF PULL LONG SPEAR W/3 1/2" INTERNAL FISHING NECK. RAN BACK IN WELL AGAIN WITH SHORT SPEAR AND WITH 4 1/2" INTERNAL FISHING NECK TO START BEATING UP WARD. PATCH MOVED 4' UP. JOB IN PROGRESS. Page 1 O6~O6/O3 06/O7/O3 06/07/03 (CONTINUED) 06/18/03 06/19/03 06/19/03 06~20/03 06/20/03 D-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS CONTINUE ATTEMPTING TO PULL 7" HES DWP PATCH PATCH W/SLICKLINE. SWITCH TO BRAIDED LINE. LATCH W/5 1/2" X 4 1/2" G- RELEASABLE SPEAR @ 8339' SLM. THREE HOURS OF BEATING @ 3500# OJ LICKS. JOB IN PROGRESS. RESUME ATTEMPTING TO PULL 7" HES DWP PATCH. WITH 5 1/2" OUTER & 4 1/2" INNER FISHING NECK, RELEASABLE SPEAR @ 8338' SLM. WORK TOTAL 6+ HRS WITH BRAIDED LINE @ 3800# + OJ LICKS, UNABLE TO MOVE PATCH UP. PULLED SHORT RELEASABLE SPEAR, INSPECTED, RERAN SPEAR, 3.5' LONG. PATCH IS 16'. GAVE WELL BACK TO PAD OP. LEAVE WELL SHUT-IN FOR COIL TO PULL PATCH .... NOTE: TTP STILL IN HOLE. FISH DWD PATCH- MIRU DS CTU #9. RIH WITH BAKER 3-3/8" FISHING TOOLS: JARS AND 4" GS SPEAR. LATCHED FISH @ 8370' CTM DOWN WT. HAD A 10K OVERPULL BEFORE POOH WITH FISH. PULLED UP HOLE 400' TO 7971' CTM AND HUNG UP, UNABLE TO JAR FREE. RBIH TO 8370'. COCKED JARS AND PUH. GOT HUNG UP @8332'. ATTEMPTED TO START JARRING, NO MOVEMENT UP OR DOWN, JARS NOT OPERATING PROPERLY. RELEASED FROM FISH. POOH. RBIH WITH NEW JARS PLUS ACCELLERATOR AND WEIGHT BARS. LATCHED FISH, JARRED 34 GOOD LICKS (+32K#). POOH WITH PATCH. POOH WITH PATCH. TRAPPED FISH IN MASTER VALVE. FLAGGED AND TAGGED TREE. RD DS CTU #9. <<< JOB COMPLETE >>> <<< WELL SHUT IN >>> (PRE PATCH) ATTEMPTING TO PULL PATCH OUT OF TREE. TIC= 50/0/0 (FOR SL) IA FL @ 930'. PULLED TBG PATCH FROM MASTER VALVE (MISSING PIECES OF RUBBER ELEMENTS). RUN 7" BRUSH W/4-1/2" WIRE GRAB TO X-OVER @ 8341' SLM (NOTHING IN TOOLS). RUN 3.625" CENT. W/4-1/2 WIRE GRAB TO PLUG @ 8402' SLM (NOTHING IN TOOLS). RAN 4-1/2 EQ. PRONG TO PLUG @ 8402' (SMALL CHUNK OF RUBBER CAME BACK IN EQ. PRONG). RAN 2.50" LIB TO 8402' (IMP. INCONCLUSIVE, NO IMP. OF EQ. DEVICE IN PLUG). HAD FLUID LEVER SHOT ON TBG. (FL. LEV. TBG. @ 900' ). MADE 2 RUNS TO PULL W/GR PULLING TOOL W/NO SUCCESS. MADE 2 RUNS TO PULL W/GS PULLING TOOL W/NO SUCCESS (LOOKS LIKE PLUG CAME UP 4' AND HUNG UP). NOTE---> FLUID LEVEL @ 950'WLM. <<< LEFT WELL SHUT IN >>> <<< PLUG BODY STILL IN HOLE @ 8398' SLM >>> Page 2 D-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/21/03 <<< WELL S/I ON ARRIVAL >>> (PRE PATCH). PULLED 4-1/2" XX PLUG FROM TOP OF 2-7/8" LINER @ 8419 WLM (PLUG PACKED W/RUBBER AND 2 SLIP KEYS FROM PULLED PATCH). 06122/03 TO 7" X 4-1/2" XOVER @ 8346 SLM (NO PROBLEMS). <<< LEFT WELL SHUT IN 06/23/03 T/I/O = 20/20/0, TBG FL @ 1,495', IA FL @ 39' FOR EL. O6/25/O3 SET 7" WEATHERFORD ARROW PAC TUBING PATCH. CENTER OF LOWER ELEMENT SET AT 8340 FT MD. DEPTH CORRELATED TO SWS GR/CCL CORRELATION LOG DATED 20-JAN-1998 (WITH CLIENT APPROVAL) REFERENECED TO THE SWS PATCH SETTING RECORD DATED 31-JAN-1998. RIH W/UPPER PACKER ASS'Y. 06/26/03 SET UPPER PATCH ELEMENT. CENTER OF UPPER ELEMENT (2ND RIH) SET AT 8305 FT MD. DEPTH CORRELATED TO SWS GR/CCL CORRELATION LOG DATED 20-JAN-1998 (WITH CLIENT APPROVAL) REFERENECED TO THE SWS PATCH SETTING RECORD DATED 31-JAN-1998. PATCH SET FROM 8305- 8340' MD. <<< WELL LEFT SHUT IN >>> 06/27/03 <<< WELL SHUT-IN ON ARRIVAL >>> SET DSSSV @ 2065' SLM (OAL=42", 2 SET OF PACKING, TOP OD=5.930, NO-GO=6.10, ID=4.65). <<< GIVE WELL BACK TO PAD OPERATOR >>> O6/29/O3 TIO= 0/VAC/0. MIT- IA TO 2000 PSI. INCOMPLETE (POST PATCH). IA FL INCONCLUSIVE. PUMPED 10 BBLS OF DIESEL DOWN THE IA IN 45 MINUTES WITH NO INCREASE IN PRESSURE. SHUT DOWN PUMP AND CHECKED IA PRESSURE. IA IS STILL ON A VAC & FL IS INCONCLUSIVE. R/D & RE- EVALUATE. FINAL WPH's = 0+/VAC/0. FLUIDS PUMPED BBLS 2 DIESEL FOR PRESSURE TEST- SURFACE PRESSURE EQUIP. (2 TESTS) 10 DIESEL 42 50/50 METHANOL WATER 55 1% KCL WATER 5 FLOPRO 114 TOTAL Page 3 TREE = 6" CIW D 14A ACTUATOR ~ OTIS m 90° ~ 1~43' ~. ~ = 71.52' KOP= 30~' ~tum~xAngle= i08~i0920'~ = 94~' ~tum~D= 88~'~ ...... 113-3/8" CSG, 72~, L-~, iD=12.347' H 2685' ~inimum I~: 2.387" ~ 84~0' , /(BE. ND 2-7/8" LNR) I ~5/8' roG, 47~, L-80, ID= 0.681" H 0894' I P~FO~TION SUGARY ~F L~: Spe~y Sun MWD/GR ON 05/27/97 A~LEATT~ ~RR 86 ~ 10500' ~te: R~er to Production DB for historical ~rf da~ ~LLO~ WIN~W SEE SPF I I~E~AL ~WS~ ~ I ~00'- 9407' 1-~3" 4 10~0 -10560 O 05/29~7 1-~3" 4 10600 -10~0 O 05/29~7 c I 9397' HTO"O~"~"'~T~ , ~ ~ ~o08o' I I~ H 9813' ~ 7' LNR, 26~, L-80, .0383 bpf, ID= 6.276" ~ 9863' I DATE R~ BY ~TS ~ R~ BY COM~N~ ~HOE BAY UN~ 0~80 ORIGINAL ~L~ION W~L: ~14A 05/29/97 WHELOW SID~CK COM~DN PEr. No: 196-1530 02/07/01 SI~SLT ~T~ TO ~AS APINo: 50-029-20450-01 03/08/01 SI~LG RNAL SEC23, T11N, R13E 01/30/02 R~TP ~TIONS BP ~ploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 1-2/3" 4 10500 -10560 O 05/29/97 1-2/3" 4 10600 -10660 O 05/29/97 1-2/3" 4 10800 -10880 C 08/02/99 DATE REV BY COMMENTS DATE REV BY COMIVENTS 06/80 ORIGINAL COIVPLETION 05129197 WHITLOW SIDEfRACK COMPETION 02/07/01 SIS-SLT CONVB:tTED TO CANVAS 03/08/01 SIS--LG RNAL 01/30/02 RN/TP CORRECTIONS ----- STATE OF ALASKA ALASK¢-, ..)IL AND GAS CONSERVATION C,,.. MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2710' SNL, 1067' WEL, SEC. 23, T11N, R13E At top of productive interval 1038' SNL, 701' EWL, SEC. 24, T11 N, R13E At effective depth (n/a) At total depth 1828' SNL, 1875' EWL, SEC. 24;T11N, R13E RST Log 5. Type[~ well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 71.52' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-14A 9. Permit Number / Approval No. 96-153 10. APl Number 50- 029-20450-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10920 feet true vertical 8941 feet Effective depth: measured 10850 feet true vertical 8957 feet Casing Length Structural Conductor 110' Surface 2659' Intermediate 8869' Production Liner 463' Sidetrack Liner 2510 Size Plugs (measured) Junk (measured) KOP (window) 9400' - 9407'. 7" Liner abandoned from 9400' to 9863'. Haliburton CIBP @ 10730'. (08/02/99) Cemented MD TVD 20"x 30" 126 c.f. 13-3/8" 3270 c.f. 9-5/8" 1350 c.f. 7" 330 c.f. 2-7/8" 112 c.f. Class 'G' 135' 2684' 8894' 9400'-9863' 8410'-10920' 135' 2684' 8369' 8850'-9010' 7915'-9013' .. Perforation depth: measured true vertical Open Perfs 10500'-10560',10600'-10660' Perfs Below CIBP 10800'-10880' Open Perts 8959'-8960', 8961'-8962' Perfs Below CIBP 8961'-8945' Tubing (size, grade, and measured depth) 7", 26#, Lo80 tubing to 8354' with 4-1/2" tailpipe to 8458'. AVA DWP Retrievable Patch from 8314' - 8330'. Packers and SSSV (type and measured depth) 9-5/8" GUIB. PKR (Polar) @ 8354', 4-1/2" Otis SSSVLN @ 2035'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl , . Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed SoottLaVo,e~_.~~~l~~ Title TechnicalAssistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Date (.¢,/~'"-/~'/ De Wayne Schn°rr 564-5174 Submit In Duplicate.~ D-14A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/28/2001 RST: RST/BORAX SUMMARY 01/28/01 COMPLETED CTE RST W/BORAX. FIELD PICK GOC IS INCONCLUSIVE, DERRERING TO TOWN FOR FURTHER ANALYSIS. BORAX PASSES SHOW EXTENSIVE CHANNELING. WELL WAS LOGGED WITH KCL RATHER THAN CRUDE DUE TO CRUDE TANKER SHORTAGE. **** WELL WAS LEFT SHUT-IN AND FREEZE PROTECTED, WILL PROBABLY REQUIRE N2 LIFT TO UNLOAD **** Fluids Pumped BBLS. Description 900 1% KCL WATER 115 MEOH 1015 TOTAL PERMIT DATA AOGCC Individual Well Geological Materials Inventory 96-153 96-153 96-153 96-153 96-153 ~3 OD ~nnT ~~- ' .......... _ , - EOW SRVY 6/5/97 NGP-TVD NGP-MD 8086 PATCH SET RCD T DATA PLUS ................... ~/8786-8941 % 13-1o92o ' 7523-8312 Page: 1 Date: 06/07/99 T / RUN RECVD D BOX .............. 07/25/97 FINAL09/03/97 FINAL09/03/97 1-808/27/97 FINAL02/12/98 ~ .......... 2,'30 · -' I ~-.~.z'-~ U~/ ~'~/ ~ 02126198 0%G 96-153 LEAK ..... 5n ~+ 200-8400 10-407 ~R~OMPLETION DATE © < ~g/~/ DAILY WELL OPS R @,>//~/~/~/ TO Are dry ditch samples required? yes ~And received? Was the well cored? yes Analysis & description received? Are well tests required? yes '~.qo~R%ceived? Well is in compliance I~it~al CO~ENTS yes no ~ IAI I- ~1- ALASKA ALASF~-OIL AND GAS CONSERVATION COMMISSICf- ' REPORT C. SUNDRY WELL OPEr. ATIONS Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well__ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 53' NSL, 673' WEL, SEC. 2, TION, R15E At top of productive interval 1154' NSL, 889' EWL, SEC. 12, TION, R15E At effective depth 945' NSL, 907' EWL, SEC. 12, TION, R15E At total depth 893' NSL, 912' EWL, SEC. 12, TION, R15E 5. Type of Well: Development fixploratory Stratigraphic Service 6. Datum elevation (DF or KB) KB=54' 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number D- 14A 9. Permit number/approval number 96-153 / 397-220 10. APl number 50- 029-20450-01 11. Field/Pool Prudhoe Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 113' 2664' 11013' 9309' 10685' 9020' Size feet feet feet feet Plugs (measured) Fill Tagged at 10685' MD 3/18/94) 2 0" 13-38" Junk (measured) Cemented Measured depth True vertical depth BKB 250 sx Arctic Set 113' 113' 3950 sx Arctic Set 2718' 2718' 10921 9-5/8" 1500 sx 'G', 115 sx measured 10500;10560~ 10600;10660~ 10800;10880' true vertica§ubsea 8951'-8962' R EC E I V,C -O JUL 20 1998 Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 7", 26#, 13Cr80 to 2931'; 5-1/2", 17#, 13Cr802931;10148', 5-1/2" 17#, L-80, 10154;10278' Packers and SSSV (type and measured depth)Camco Bal-O SVLN at 2219'; TIW HBBP packer at 10075'; Baker SAB packer at 10169' 13. Stimulation or cement squeeze summary See attachment Intervals treated (measured) Treatment description including volumes used and final pressure ORiGIi' AL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure SI 1518 Tubing Pressure 0 70 0 195 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oilx Gas__ Suspended 17. I hereb~y ~J th~/t~the Xgoing is ;Tnrd correct to the best of my knowledge. Signed /// (__~/r.,,~_~,,~ 4~.,_~/_~~ Title TechnicalAssistant III Form 10-404 Rev 06/15/88 Service Date SUBMIT IN DUPLICATE D-14A DESCRIPTION OF WORK COMPLETED TUBING PATCH 01/31/98 SUMMARY Rig in hole with CCL and 7" AVA tubing patch. Set patch with top at 8314', slips at 8316' (2' below collar), and top element at 8318' elmd (4' above leak). Did not tag patch after setting on advice of Dresser representative. FLUIDS PUMPED BBLS DESCRIPTION 2/2O/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11842 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe.Bay (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape C- 12 PERFORATE RECORD 9 8 0 2 0 8 I 1 ,. C-24 PERFORATE RECORD 9 8 0 2 0 8 1 1 D- 14 A LEAK DETECTION LOG 9 8 0 213 I 1 N- 11 A :PERFORATE RECORD 9 8 0 21 1 I 1 R-32A WHIPSTOCK SET RECORD 9 8 0 2 0 9 I 1 ., ........ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11791 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 2/9/98 Well Job # Log Description Date BL RF Sepia LIS Tape 7o.oo~ B-01 o PRODUCTION LOG 9 8 01 2 2 1 1 B- 12 o PRODUCTION LOG 9 8 01 2 3 I 1 B-33A , PRODUCTION PROFILE 9801 30 1 1 B-33A · DEFT LOG 9 8 01 3 0 I 1 C-24 · PERFORATING RECORD 9 8 01 2 8 I 1 D-14A · PATCH SET RECORD 9 801 31 I 1 F-21 · PERFORATING GPJCCL LOG 9 8 01 2 9 I 1 Q-07 · WHIPSTOCK SET RECORD 9 801 3 0 I 1 R- 13 o BAKER IBP SETTING RECORD 9 8 01 3 0 1 I -- Y-36. PERFORATING RECORD 9801 28 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~l~~~ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'II'N: Sherrle NO. 11758 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 1/28/98 Well Job # Log Description Date BL RF Sepia LIS Tape .~c~. OOCl N-11A · ~ '~ '~ Oc;~ 98020 RST-SIGMA 980108 I 1 1 N-1 lA · GAS LIFT SURVEY 9801 09 I 1 C-34 ~ PRODUCTION PROFILE 980111 I 1 C-38 ~ LEAK DETECTION LOG 980110 1 1 D-14A ~ GR/CCL CORRELATION 980120 1 1 H- 0 8, PERFORATING RECORD 9 71 22 7 I 1 H- 33 f PERFORATING RECORD/GR-CCL 9 801 05 I 1 J-10 · PERFORATING RECORD 9 80106 1 1 M-09A · PRODUCTION FLUID SAMPLER 980112 I 1 'M-09A ~ PERFORATE RECORD 980115 1 1 N- 14 · CHEMICAL CU'FrER 98 01 18 I 1 'R-05 .- WHIPSTOCK SE'R'ING RECORD 980111 I 1 R-25A * ORIENTED WHIPSTOCK SET 971228 I 1 ~S-22B /'''' PERFORATING RECORD 971229 1 1 W-22 * FULL surrE PRODUCTION LOG 980116 I 1 X-6 / INJECT. PROF. W/WARMBACKS 9 801 18 1 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASKA O,,. AND GAS CONSERVATION COM~,.. 5SION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 53' NSL, 673' WEL, SEC. 2, T10N, R15E At top of productive interval 1154' NSL, 889' EWL, SEC. 12, T1 ON, R15E At effective depth 945' NSL, 907' EWL, SEC. 12, T10N, R15E At total depth 893' NSL, 912' EWL, SEC. 12, T10N, R15E Type of well: [] Development [] Exploratory [--I Stratigraphic I--IService 6. Datum Elevation (DF or KB) KBE - 54' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number D-14A 9. Permit Nur~el~ 10. APl Number O] 50-029-~ c~O/'~5 "'" 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11013 feet Plugs (measured) 9309 feet 10685 feet Junk (measured) 9020 feet Fill Tagged at 10685' MD (3/18/94) 0RI$1NAL Length Size Cemented MD TVD 113' 20" 250 sx Arctic Set 113' 113' 2664' 13-3/8" 3950 sx Arctic Set 2718' 2718' 10921' 9-5/8" 1500 sx 'G', 115 sx Arctic Set 10975' 9275' RECEIVED Perforation depth: measured 10500' - 10560', 10600' - 10660', 10800' - 10880', true vertical 8951' - 8962' Alaska 0ii & Gas Cons. ComfflisS~J Anchorage Tubing (size, grade, and measured depth) 7", 26#, 13Cr80 to 2931 '; 5-1/2", 17#, 13Cr80 2931' - 10148', 5-1/2" 17#, L-80, 10154' - 10278' Packers and SSSV (type and measured depth) Camco BaI-O SVLN at 2219'; TIW HBBP packer at 10075'; Baker SAB packer at 10169' 13. Attachments [] Description summary of proposal ~l Detailed operations program [] BOP sketch 4. Estimated date for commencing operation 115. Status of well classifications as: 1 [] Oil [] Gas I--] Suspended Service 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Prepared By Name/Number: Michael Williams 564-4657 17. I hereby~ ce~ify/)that t,h~oregoing is true and correct to the best of my knowledge Signed ~._~ f~ (~e Hurliman .-P~-~ '~'-Of. ~'~r~; ~ Title Supervisor Gravity Drainage Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness I Approval No.~' Plug integrity_ BOP Test __ Location clearance Mechanical Integrity Test Subsequent form required~10-/-/ Approved by order of the Commission 0avid W. J0hnst0~*'¢'l ..... ' ';* ¢~4~°mmissi°ner Form 10-403 Rev. 06/15/88 . l l . ~.:;~ ~~ Date , '-~, /~ ~ Submit In Triplicate ~¢¢.... ' -L D-14A Request for Variance No Alaskan company can currently supply a tubing patch for 7" tubing. PTA no longer represent AVA (who manufacture most of our patches), and AVA do not yet have another agency. Halliburton do not have a patch for 7" tubing, but are developing one. We aim to procure and mn a patch when available. Meanwhile we do not want to close in a well that last tested at 1334 bopd with a GOR of 6528 scf/stb. STATE OF ALASKA . ", ALASKA ('--'- AND GAS CONSERVATION Cr- "MISSION WELL COMPLETION RECOMP LETION . EPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 96-153 3. Address P. O. Box 196612, Anchoraqe, Alaska 99519-6612 4. Location of well at su trace 2710' SNL, 1067' WEL, Sec.23, T11N, R13E At Top Producing Interval 1038'SNL, 701' EWL, Sec.24, T11N, R13E At Total Depth 1828' SNL, 1875'EWL, Sec.24, T11N, R13E 5. Elevation in feet (ind 71.52 12. Date Spudded 5/24/97 8. APl Number 50- 029-20450-01 9. Unit or Lease Name Prudhoe Bav Unit 0. Well Number D- 14A 1. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool icate KB, DF, etc.) 16. Lease Designation and Serial No. I 028285 13. Date T.D. Reached '14. Date Comp., Susp. or Aband. 15. Water Depth, if offsh ore 116. No. of Completions l 5/27/97 I 5/29/97 n/a feet MSL I one 18. Plug Back Depth (MD+T VD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafro st I 10850, 8957'TVDss YES [] NO [] I 2035 feet MD Approx 1900' 17. Total Depth (MD+TVD) 10920, 8941' TVDss 22. Type Electdc or Othe GR r Logs Run 23. CASING SIZE 2-7/8" CASING, LINER AND CEMENTING RECORD SETTING DEPTH ME; WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORE AMOUNT PULLED 6.16# L-80 8411 10,850 3-3/4 112 c.f. 24. Perforations c )en to Production (MD+TVD of Top and Bottom and TUBING RECORD interval, size and number ) 10500-10560' 8959-8960', 1-11/16" 4 spf 10600-10660' 8961-8962' 1-11/16" 4 spf 10800-10880' 8961-8945' 1-11/16" 4 spf i25. SIZE DEPTH SET (MD) PACKER SET (MD) 26. ACID, FRACTURE, CEMENT SOJEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED !27. PRODUCTION TEST Date First Production ing, gas lift, etc.) 6/2/97 Date of Test Hours Tested Flow Tubing Casing Pressure Press. Method of Operation (Flow FL PRODUCTION FOR OIL-BBL TEST PERIOD I~ CALCULATED OIL-BBL 24-HOUR RATE ~ 28. IBrief GAS-MCF GAS-MCF WATER-BBL WATER-BBL ICHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) CORE DATA ology, porosity, fracture s, apparent dips, and pre sence of oil, gas or wate r. Submit core chips. description of lith Form 10-407 ORIGINAL Rev. 7-1-80 CONTINUED ON REVERSE SIDE 0il & Gas Cons Anch0rag¢. 29. 30. '~ ' , GEOLOGIC MARKERE ,:~MATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTI- TRUE VERT. DEPTI- GOR, and time of each pha se. TSAD 9120 8495 Z3 9313 8695 31. LIST OF A'FI-ACHMENTS 32. I hereby certify that the foregoing is true and co rrect to the best of my k nowledge Signed '~t~ ~.~IcL_ ~~ Title ~..ni, T, xhinn I'~rill/n.r7 TA Date "~L.~(.~)IOl -'~ INSTRUCTIONS General: This form is des igned for submitting a co mplete and correct well c ompletion report and Icg on all types of lands and le ases in Alaska. Item 1: Classification of Service Wells: Gas injec tion, water injection, st eam injection, air inject ion, salt water disposal, water sup ply for injection, observ ation, injection for in-s itu combustion. Item 5: Indicate which el evation is used as refere nce (where not otherwise given in other spaces on this form and in any atta chments. shown) for depth measurem ents Item 16 and 24: If this completion), so state in in item 27. Submit a sep data pertinent to such in well is completed for sep item 16, and in item 24 s arate form for each addit terval. arate production from mcr how the producing interva ional interval to be sepa e than one interval (mult iple Is for only the interval reported rately produced, showing the Item 21: Indicate whether from ground level (GL) o r other elevation (DF, KB , etc.). Item 23: Attached supplem ental records for this we ing and the location of t he cementing tool. II should show the detail s of any multiple stage c ement- Item 27: Method of Operat jection, Gas Injection, S Item 28: If no cores take Form 10-407 ion: Flowing, Gas Lift, R hut-in, Other-explain. n, indicate "none". od Pump, Hydraulic Pump, Well: D-14A Accept: 5/22/97 Field: Prudhoe Bay Spud: 5/23/97 APl: 50-029-20450-01 Release: 5/29/97 Permit: 97-153 CTD Unit: Nordic #1 Date Day Depth 5/23/97 1 9408 MIRU DS/N #1. Accept rig for operation at 1200 hrs 5/22/97. NU BOPE. Fill mud pits with used FIo Pro. Test BOPE-AOGCC waived witnessing. MU BHA. RIH w/BHA #1. Well on vac. 5/24/97 2 9752 RIH w/BHA #1. Tagged top of WS at 9442' (Uncorrected). Set counter to Eline WS setting at 9397' Orientated to 10R. Window at 9407' initially. Drilling and trying to keep 10 R TF. Had problems keeping TF @ HS right. Drilling. Drilled to 9647' and POOH for motor. Change bit and motor. RIH with BHA #2. Tie-in at GR marker-add 9'. RIH to TD. Drill from corrected 9652' to 9752'. POOH for motor. Change bit, motor bend. RIH w/BHA #3. 5/25/97 3 10062 RIH w/BHA #3. Tagged bottom at 9752', Drilling, Orientate Drilling. ST to window 200' at 9928'. Drilled to 9980' POOH to change motor setting to 1.2 and MWD. OOH and changed Motor, MWD and Bit.. RIH with BHA CfA (1.2° motor). Swap out used FIo Pro for new mud while drilling from 9980-10020'. Not getting enough build to stay above HOT. POOH for motor. Change bit and motor. RIH with BHA #5 (2.25° motor). Drill from 10020-062' building angle to 94° at bit. POOH for motor. Change bit, motor. RIH with BHA#6 (1.0° motor). 5/26/97 4 10590 RIH with BHA #6 (1.0° motor). Tagged bottom, Drilling, Survey and Drilling Started drilling at 80R and BR at 6.6deg/100' Turned TF to 112' and BR at 3.73°/100'.. Formation soft and hard to keep and AP on the motor. LS TF are building angle, At 10284', turned TF to 160R to get TVD in High 8950'. Reactive torque on this well is right hand rotation. Reactive torque in the SW quadrant is correct (LH). TVD break over at 10316' MD. Drilled to 10402' and short trip to 10200'. Drilled to 10465', short tripped to window Clean. Drilling with HS tool face to 10489'. Not building enough to stay out of HOT and need more turn. POOH for motor. Tie- in, add 5'. Change bit, motor and MWD. Service CTC. RIH w/BHA #7 (1.8° motor). Drill from 10489-590' building and turning to left. MWD toolface acting erratic. POOH to check MWD. OOH, check MWD. Found HOT at 8960' drill samples, prognosis called it at 8970' TVD. could be transition zone (top) 5/27/97 5 10920 Check MWD-no obvious problem (no backup). Change orientor. MU same assembly. RIH w/BHA #7RR. Tagged bottom and corrected to 10590'. Orientated TF at 65L. Drilling. Drilled 134', having trouble sliding. Short trip to window. Drilling. Having trouble sliding at 10777' Worked through. Drilling. Losing circulation at 2.5 BPH, Added 75 bbl of mud to system. Drilled to 10885' MD. Last TVD 8950' TVD. Pump hi-vis sweep, short trip to window. Tie-in, subtract 19'. RIH. Drill from corrected TD to 10920' (final TD). Short trip 100'. POOH for liner-hole is clean. LD drilling BHA #7RR. Safety meeting. RIH w/float shoe, float collar, one joint, seal bushing and 80 joints 2-7/8" 6.16# L-80 STL liner. Install Baker GS sleeve. RU to run workstring 5/28/97 6 10920 RU to run workstring. RIH with 75 jts 1-1/4" CS Hydril and stung in PO Bushing. Space out, install CTLRT. RIH with liner on CT and tagged bottom at 10920' Corrected. Dropped ball and sheared CTLRT seat at 3000 psi, RU cementers and Held Safety and Operational meeting. Pump 20 bbls cement followed by dart. Displace with mud to seal bushing. Unsting, shear out at 4050 psi. PUH while circ cement out of liner. Park above liner top and circ while WOC. RIH jetting liner and tag seal bushing at 10886'. POOH leaving clean FIo Pro in liner. Displace used mud in wellbore with SW. POOH for perf guns. LD CTLRT. Stand back 37 stands of workstring. WO perf guns. Load guns in pipeshed. Crew change/Safety meeting. .... .- 1997 4las~ .Oil & Gas Cons. 60mmiss~'- Anchorage 5/29/97 ? Safety meeting. M/U 380 ft of I 11/16" SWS loaded guns and blanks. RIH with 34 stands of CSH above perf guns. M/U BKR swivel, disconnect and XO. Deploy guns on CT. Sat down with firing head at top of liner. Could not get by. POOH to investigate. Stand back workstring. Found square shoulder on bottom of firing head (2.125" OD to 1.69" OD). Bevel bottom of another firing head. RIH with perf guns on workstring. RIH on CT. No weight loss at TOL with firing head. Tag seal bushing, load ball. Park at shooting depth and pump ball to seat. Fired guns, monitor well. Lost 0.6 bbls in 5 minutes. POOH with perf guns. Stand back workstring. LD per guns-all shots fired. FP wellbore with MeOH to 500'. Secure well. Replace packoff. ND BOPE. Perforated 10500-560', 10600-660' and 10800-880' with SWS 1-11/16" guns at 4 SPF, 20J UJ Chg, 3.2 gm, 90° phase _~-14AEOW. xls u-14 A END OF WELL SURVEYS 6/5/97 4:30 PM EXPLORATION ALASKA INC. END OF WELL SURVEY REPORT FOR THE D-14A SIDETRACK JUNE 5, 1997 j j j VERTICAL SECTION USED J 125.87° RELATIVE TO TRUE NORTH j , j RKB J t J -71.5' t I I I J : GRID ~S ~D ~ OFFSETS ~E REQUIRED FOR GEOLOGICAL ~RK j J j J: ALL ~IMU~ V~UES ~E RE~TI~ TO TRUE NORTH J ' j J J j : OFFSETS ARE CALCU~D TO GRID ~D TRUE NORTH AS INDICATED J J G~DCONV~GENCE , j J: 1'17~ J ' J i ~GN~IC DEC. TO TRUE NORTH J' 28'42° I J ~ J i I i PREPARED BY:r J -' ' · DR,L~r [ i J ~ J ~ I ] ~D CO. J j SPERRY SUN I I COMMENTS j MD Inc. Dirj ~ DEPT VSJ TRUE TRUE Build Turn j i o.oo o.ooi o.oo , ooo,.oo i ~.~oi =~.~ ~.~ ~=.~o =,.=oi ~.~oi ~s~.~oI~ ~.~oI ~.~o ~.,o ~.oo ~,~oo~.oo~,~.~o ~ ~00.50~ 50.~ 88.57 ~.00~ 6~.50 ~.30 ~aa6.00~ . , 1723.10 1851.20r5960015.00, 655959.80 . 19~.50 34.10~ -3.20~ 34.20 1723.90 1873.601 5960016.00J 655982.30 , ~ ~ I I ' 9557.20~ 70.10 ~.07~ ~89.60 102.20 16~.80 1957.~ 32.10 13.40 34.30 1723.40 1922.80 5960016.00 656031.40 j ~.00~ 79.30 1.01.071 ~.~ 125.~ 1~0.~ 1~.10 33.10 21.60 39.10 1720.20 1949.30 5960013.00 656058.00 ~15.~ ~.20 '1~.27 ~1.t0 154.10~ 1672.10 2013.20 19.30 26.90 32.90 1712.90 1978.60 5960005.00 656087.30 96~.~ ~.20 1t7.37 8904.~ 188.~ 1658.t0 2~.60 0.~ 22.90 22.80 1699.60 2011.30 5959992.00~ 656119.90 ~ ~85.60 89~.90' 222.~ ~ 18.20 ~ ~.43 123.67 16~.~ 2075.40 0.70 18.10 1682.70 2041.40 5959975.00 656150.00 ~ 9715.~ ~ ~.60 128.77 ~.~ ~ 2~. 10 1622.80~ 2~.70 -6.~ 16.80 17.80 1665.30 2066.10 5959957.00 656174.70 128.97 8913.~ 281.50~ 16~.~ 2t21.~ J 9744.70 79.80 0.70~ 13.20 1647.90 2088.60 5959940.00 656197.30 9772.40 -13.20 78.~ 13t.77 ~19.20~ 3~.70~ 1587.30 2142.~ -5.40 10.10 11.30 1630.70 2109.70 5959923.00 656218.30 ~ 9798.70 77.70 1~.57 ~24.70~ 334.20~ 1569.~ 2161.~: -2.~ 6.80 7.10 1613.70 2129.00 5959906.00 656237.60 98~.50 77.~l 1~.27 ~32.001 367.90J 1~6.20 0.60j 2.00~ 2.00 1590.60 2153.g0 5959883.00j 656262.60 78.~j 136.17 89~.20 1521.50 5959859.00 656287.60 j 9~.~J ~.ooj ~36.87j 89~.~j ~3.~ t~8.80J 2232.10J 3.80j 2.20j 4.30J 1544.10 2201.00 5959837.00j 656309.60 j ~28.~I 81.04J 1~.271 ~.~J ~9.20, 1479.10 2250.10 3.80 5.20 6.40 1524.80 2219.40 5959817.00J 656328.00 ~.30 ~8.20 1~.~ ~ ~58.2oj 80.~' 1~.37J 22~.~ ~.501 7.00 6.90 1502.50 2239.30 5959795.00 656347.90 ~ 99~.20 142.17 J 4.10j 82.20 ~.~J 518.70 t~1.80 2289.~ 5.60 6.90 1478.30~ 2259.60 5959771.00 656368.20 j l~.~j 91.30 140.57 ~l.~J ~9.~ 1~0.60 j 2322.20 17.20 -3.00i 17.50 1437.80 2293.30 5959730.00 656401.90 100~.~J ~.39 1~.27j ~0.~ 595.~ t370.30j 2339.70 11.50 -8.60 14.40 1417.80 2311.10 5959710.00 656419.70 j 10104.10 j ~.50 137.77 j ~7.40 628.80 13~ ~ 23~.50 6.20 -1.50 6.30 1392.90 2334.50 5959685.00 656~3.10 ~.40 1318.80 2385.70 -0.60 3.40 3.40 1367.30 2358.30 5959660.00 656466.80 ~.30 138.97 663.~ r ~ 97.40 12~.~ 101~.~ 1~.37 ~.~ 69t.~ 24~.70 3.70 4.70 6.00 1345.30 2377.70 5959638.00 656486.30 j 10195.~ ~.~j 1~.77 ~46.~J 716.30 1275.~j 2420.~ -5.70 16.80 17.60 1325.00 2393.g0J 5959617.00 656502.50 ~ 10225.80J 93.40 145.87J 8944.~J 7~.30 1250.~J 2438.00 -8.10j 3.60 8.90 1300.10 2411 .g0 5959592.00 656520.50 8.30 1272.20 10259.~J 93.16 1~.67 8~2.~j 776.60 1222.30J 2~6.20 ~.70J 8.30 2430.60 5959564.00 656539.30; j 1~2.70j 85.87 152.37J 8943.~[ 8~.70j 1139.60j 24~.00 -4.80J ~] 9.60: 1190.50 2475.10 5959483.00 656583.80 8947.t0i 10~0.40 84.20 1~.77 893.70 J t106.80 2517.10J ~.40J ~,90j 8.20 1158.00 2494.00 5959450.00 656602.60 10426.~j 82.10 149.17 8~1.~J 926.~J 1075.80 2~5,40 -5.80j -1.70J 6.00 1127.40 2512.80 5959420.00 656621.40 1~61.10 J 82.88 8~6.~ - 15.10 1~,97 J 958.60 1047.30j 2554.20 2.30 15.10 1099.30 2532.30 5959392.00 656640.90 ~ ~ 142.07 J J l~.~J ~,60 ~59.30 ~.~ 1021.10J 2573.~ 8.30 -5.80 10,10 1073,50 2552.50 5959366.00 656661.10 i10522 90 ~.~J 1~.47J ~.60 1017.80 998.~J 2~2.~ 11.~ -12.50 17.20 1051.70 2571,40 5959344.00 656680.00 J 1~.50 ~.97 J 1~.67 8~.60 1047.70 976.~J 2612.60 6.30: 0.70 6.40 1029.20 2592.10J 5959322.00 656700.70 10~1.~ 88.~ 134.97 89~.60 1075.30 955.~ 2~1.80 -7.20j -13.20 15.00 1009.10 2611.70 5959302.00 656720.30 10611.~j ~.~ 130.87 ~1.10 11~.30J 934.~ 26~.00 1.20J -13.50~ 13.60 988.90 2634.30 5959282.00 656742.90 nRIGINAL -,'-14AEOW. xls L~-14 A END OF WELL SURVEY5 6/5/97 4:30 PM .4~IMENTS i MD ~n~.I Did SS D~T vsl ff , d~/lO0 degllO0 degllO0 NI~ ~-W ~ ASP 1143.30 911 .~ 2~4.30 -0.30 [ 106~.~ 89.20~ 123.57~ 8961.60j -19.20[ 19.20 966.60 2665.00 5959259.00 656773.60 ~ ~0~7.s0~ ~.~ ~,.071 ~2.,0~ ~.so ~ss.~o~ 272~.~0 ~.~, -~,.soi ~.~0 ~.,0 ~707.,0 ~7.00 ~ ~0725.~01 ,0.~t ~07.~7~ ~.~ ~2~7.~ 57~.~1 27~2.20 ~.sol -2,.s01 2~.~0 ~.~0 27~.~0 ~.00i ~,~.~0 , ' ~.~7i ' 27~.00 -z.70j -~.~0~ ~,.~0 ~.~0 ,~.~0 , ~07ss.~o[ ~ 52~ ~2.~! ~2~.~0~ 572 ~0 929.s0~ ~959~.00 ~{ 95.60~ 84.67 ~0.50l, 1301-~I 870.~] · , 928.90 5959222.00~ ~57.40 874.20 12 20 -17.30~ ~s.~l ~.~ ~.17~ ~7.~ ~.~0~ ~0.~2922.60 ~sol 9.s0~ ~5.s0 ~,0.00 ~,0,.00 595~33.00 ~570~2.~0 TD ~ 1~20.~j 107.59 87.97' 8~1.~J~ ~370.00~[ 88~.~ 2042.80 ~2.00~ ~3.30~ ~7.90 94~.00 2924.20 5059234.00 057032.80 f ~ ~D~PUT~O , . I J ~ I ~ DlSTEICT ~NAGER - DEILEX SYSTE~, INC, ~ , TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 18, 1996 Ted Stagg, Coiled Tubing Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit D-14A BP Exploration (Alaska), Inc. 96-153 2710'SNL, 1067'WEL, Sec 23, T11N, R13E, UM 1523'SNL, 1471'EWL, Sec 24, T11N, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-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 ~vitness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659- 3607. Si Chairman BY ORDER OF THE COMMISSION dlf/encl c' Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASI4 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.0O5 la. Type of work Drill [] Redrill[]llb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenCII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration 71.52 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorac~e. Alaska 99519-6612 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.o25) 2710' SNL, 1067' WEL, Sec.23, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1038'SNL, 701'EWL, Sec. 24, Tl lN, R13E D-14A 2S100302630-277 At total depth 9. Approximate spud date Amount 1523' SNL, 1471EWL, Sec.24, T11N, R13E Oct. 1,1996 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 028286 @ 3577 feet no close approach feet 2560 10, 799MD, 8941 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~9~ MD feet Maximum hole angle 9o o Maximum surface 2400 psig At total depth (TVD) 8800'/3380 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 3 3/4" 2 7/8" 6.16 L-80 ST-L 2388' 8411' 7844' 10799' 8941' 90 cu. ft. 19. To be completed for Redrill, Re-entry, and Deepen Operations. · ~.,..~ J Present well condition summary ----,.., oRIGINAL true vertical 9300 feet Effective depth' measured 9689 feet Junk (measured) true vertical 9129 feet Casing Length Size Cemented Measured depth True Vertical depth Structural BKB Conductor 110' 20x30 14 cu. yd 135 135 S u trace 2659 13 3/8" 3270 cu. ft. 2684 2684 I n t e r m ed i at e 8869 9 5/8' 1350 cu. ft. 8894 8368 Production Lin e r 1446' 7" 330 cuft 8417-9863 7921-9297 Perforation depth: measured 9479-9496', 9504-9520', 9530-9540', 9555-9603' true vertical 8855-8975'ss(four intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify ~at the foregoing is true and correct to the best of my knowledge Signed ~--~.~ Title Coiled Tubing Drillin~ EnEineer Date 8/23/96 Commission Use Only Perm~ Number IAPI number IApprov,,al date_. . ISee cover letter ~'(~ -/',_,A'",~ 15 0- ,P 2...?- .2. ~:~ ~',~ - o / J ~'/~'~--~' Jfor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes ~ No Hydrogen sulfide measures 1~ Yes [] NO D~rectional survey requ~rea [] Yes [] NO Required working pressure for BOPE []2M; I-I@M; 1-15M; r-I10M; I-I15M; ~ Other: by order of Approved by Original SJa.n~d By Commissioner me comm,ssion Date/~-- Form 10-401 Rev. 1291E~ W. Johaston Submit in triplicate D-14A Proposed Sidetrack Program Current Status Well D-14A is a high GOR producer that will be sidetracked to achieve lower GOR production. Existing Ivishak perforations will be squeezed in preparation for sidetracking with coiled tubing. The sidetrack will be conducted in two phases. Phase 1: Mill Window (planned for Sept. 15-20, 1996.) Existing Ivishak perforations will be squeezed. A thru-tubing whipstock will be set on E- line and coiled tubing will be used to mill a window in the 7" liner at 9391' MD. Phase 2: Drill Sidetrack (planned for Oct. 1-12, 1996) A 3 3/4" hole will be drilled with coiled tubing to 10,799' MD per the attached directional plan. An MWD will be used for directional control and surveys will be taken every 30 ft. No gyro will be run. Drilling Fluid Program: Phase 1: Seawater with Biozan sweeps. Phase 2: Solids Free FIo-Pro (8.8 ppg to provide approx. 500 psi overbalance) Logging Program: A Gamma Ray log will be used in geosteering while drilling and will be run over the entire drilled section. Liner ! Completion Program: A 2 7/8", ST-L, L-80 liner will be run to TD and cemented with 90 cu.ft cement. A PBR at the top of the liner will be located in the existing 4 1/2" tubing tail at approximately 8411' MD. The liner will be perforated with CT conveyed thru-tubing guns. Well Control: BOPE schematics for the drilling and completion operations are attached. TREE: WELLHEAD: ACTUATOR: 6" CIW OCT OTIS .. D-14A Proposed Sidetrac~_~ KB. ELEV = 71.52' BF. ELEV = 46.72' SSSV LANDING NIPPLE I ( OTIS )( 5.962" ID) 2035' 13-3/8", 72#/ft, L-80, BTRS 12685'1 FOC KOP: 2800' MAX ANGLE: 29o/5400' 7", 26#/ft, L-80, IJ4S TUBING TUBING ID: 6.276" CAPACITY: .0383 BBL/FT 7" LINER 8408' 9-5/8", 47#/ft, L-80, BTRS Top of Whipstock = 9380' MD TUBING SEALASSY. I 8331'1 ( POLAR ) (3.833"1D) 8354' 4 1/2", 12.6 #/ft, L-80 TAILPIPE 41/2 X"NIPPLE .... I I (OTIS) (3.813" ID) 8396' 41/2 XN"NIPPLE .... I I (OTIS)( 3.725" ID) 8427' 41/2" TBGTAILI 8458'1; (GUlB)(SOS) 8479'1 Top of squeeze cement -- 9400' MD I 9433' I MARKER JOINT PERFORATION SUMMARY REF LOG: SWS- BHCS- 6-24-80 SIZE SPF INTERVAL OPEN/SQZ'D 3 1/8 4 9479'- 9496' Sqzd 4-12-90 3 1/8 4 9504'- 9520' Sqzd 4-12-90 3 3/8 6 9516'- 9524' Open 1-6-96 3 1/8 4 9530'- 9540' Sqzd 4-12-90 3 3/8 4 9555'- 9603' Sqzd 4-12-90 3 3/8 4 9582'- 9603' Open 4-17-90 3.75" open hole PBTD ~ 7", 29#/ft, L-80, IJ4S TREE: WELLHEAD: ACTUATOR: 6" ClW OCT OTIS ~-14A Proposed Completi~-~-- KB. ELEV = 71.52' BF. ELEV = 46.72' SSSV LANDING NIPPLE (OTIS)(5.962" ID) I 2035' I 13-3/8", 72#/ft, L-80, BTRS 12685'1 FOC KOP: 2800' MAX ANGLE: 29o/5400' 7", 26#/ft, L-80, IJ4S TUBING TUBING ID: 6.276" CAPACITY: .0383 BBL/FT TOP OF 7" LINER 8408' 9-5/8", 47#/ft, L-80, BTRS I 8894'1~ Top of Liner Cement = 9180' MD Top of Whipstock = 9380' MD TUBING SEALASSY. I 8331'1 9-5/8" GUIB. PACKER (POLAR)(3.833"19) I 8354' I 4 1/2", 12.6 #/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE (OTIS) (3.813" ID) 4 1/2 .... XN" NIPPLE (OTIS)( 3.725" ID) 4 1/2" TBG TAIL (GUIB)(SOS) (ELMD) 8396'I 8427'I 8458' I 8479'1 2 7/8" ST-L Liner Top of squeeze cement = 9400' MD 9433' J MARKER JOINT PERFORATION SUMMARY REF LOG: SWS-BHCS- 6-24-80 SIZE SPF INTERVAL OPEN/SQZ'D 3 1/8 4 9479'- 9496' Sqzd 4-12-90 3 1/8 4 9504'- 9520' Sqzd 4-12-90 3 3/8 6 9516'- 9524' Open 1-6-96 3 1/8 4 9530'- 9540' Sqzd 4-12-90 3 3/8 4 9555'- 9603' Sqzd 4-12-90 3 3/8 4 9582'- 9603' Open 4-17-9(: '~%~%~%~%~%~ '~%~%~%~%~% '~%~%~%~%~%~ '~%~%~%~%~% '~%~%~%~%~%~ %%%% , %~%~%~%~%~ '~%~%~%~%~%~% '~%~%~%~%~%~ '~%~%~%~%~%~ ,~%~%~%~%~% '~%~%~%~%~%~% '~%~%~%~%~%~%: '~%~%~%~%~%~%, '~%~%~%~%~%~%, ~%~%~%~%~ PBTD ~ 7", 29#/ft, L-80, IJ4S LU 12" 36" 22.5"I 2 3/8" CT ~ I Pack-Off Lubricat°r~ I 7 1/16" Annular 7 1/16' 5000 psi Blind/Shear 7 1/16" Pipe/Slip 7 1/16' x 5,000 psi FLOW CROSS 7 1/16'x 5,000 psi Blind/Shear 7 1/16" Pipe/Slip 1/16' x 5,000 psi CT-Drilling BOP Drilling & Liner Cementing ~rrrlTrlT~ 2 7/8" I ITnmn~ ~ 27/8" I SWAB OR MASTER VALVE 8/12/96 I 3/4" or 2 3/8" CT ~.~ I 10,000 psi Pack-Off Lubricator~ I CT COMPLETION BOP Perforating 5 1/8' x 10,000 psi 5 1/8' x 10,000 psi Blind/Shear 5 1/8" Pipe/Slip 5 1/8' x 10,000 psi ]nTrm~ ~ I 3/4" or 2 3/8" J ]mTmTn] ~ I 314" or 2 3/8" I SWAB VALVE WING VALVE / FLOWLINE SSV MASTER VALVE 7/25/96 1,800 1,600 1,400 1,200 1,000 80O 600 4OO 1,200 1,4oo 1,6oo 1,800 D-14 Plan 2,000 2,200 2,400 2,600 2,800 3,000 3,200 x distance from Sfc Loc Well Name D-14 I Distance 2,802 ft Az 6 4 deq NEW HOLE Kick Off TD State Plane Surface Loc E/W (X) N/S (Y)] "~71 "7~°I' 2,5~I ~,2~.I 656,6221 5,959,53oI 654,109 5,958,291 Az Ch, MD (ft) o.~ 14.0 285 $.0 250 -5.0 400 5.0 45O 0.0 1 0.0 1 0.0 I Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,408 Drawn: 8/2 2/96 7:43 Plan Name: Case 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well ~ Plugging x Time extension__ Stimulate Change approved program ~ Pull tubing ~ Variance ~ Perforate ~ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2710' SNL, 1067' WEL, SEC. 23, T11N, R13E, UPM At top of productive interval 1038'SNL, 701' EWL, SEC. 24, T11N, R13E, UPM At effective depth 1011'SNL, 862'EWL, SEC. 24, T11N, R13E, UPM At total depth 1006' SNL, 906' EWL, SEC. 24, T11N, R13E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE= 71.52 7. Unit or Property name Prudhoe Bay Unit 8. Well number D-14 9. Permit number 80-22 10. APl number 50- 029-20450 11. Field/Pool Prudhoe 0/I Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9866 feet 9300 feet 9689 feet 9129 feet Casing Length Size Structural -- Conductor 11 O' 20X30" Surface 2659' 13 3/8" Intermediate 8869' 9 5/8" Production -- Liner 1446' Perforation depth: Plugs (measured) Junk (measured) Cemented 14 C.Y. 3270 C.F. 1350 C.F. 7" 33O C.F. measured 9479'-9496', 9504'-9520', 9530'-9540', 9555'-9603' true vertical subsea 8855'-8975'(four intervals) Tubing (size, grade, and measured depth) 7" L-80 to 8354' with 4 1/2" tailpipe to 8458' Measured depth 135 2684 8894 8417-9863 True vertical depth BKB 135 2684 8368 7921-929 7 Packers and SSSV (type and measured depth) 9 5/8" Guiberson Polar packer at 8354'; 4 1/2 SSSV. & /nsert..at2035 ....... · ~,rr' ~"~:' . )''' ~,~,':.;'" 'J'~"" 13. Attachments Description summary of proposal × Detailed operations program~ BOP sketch 14. Estimated date for commencing operation Sept. 15, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title Coiled Tubing Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission IApproval No. Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL LOG TRANSMITTAL To: State of Alaska September 3, 1997 Alaska Oil and Gas Conservation Corran. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs D-14A, AK-MW-70148 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ Fan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D-14A: 2" x 5" MD Gamma Ray Logs: 50-029-20450-01 2"x 5" TVD Ganm~a Ray Logs: 50-029-20450-01 1 Blueline 1 Rev Folded Sepia 1 Blueline /. 1 Rev Folded Sepia SE? 0 5 1997 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska August 27, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - D-14A, AK-MW-70148 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.' Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20450-01. RECEITE AUG 2 7 199~' Oil & Gas ~nso Oommi~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company · WELL PERMIT CHECKLIST COMPANY F1ELD & POOL ' INIT CLASS ADbliNiSTR~,¥1ON ................. DATE 1. Permit fee attached ....................... 2. Lease number appropriate .................... 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from ddg unit boundary .... 6. Well located proper distance from other wells ........ 7. Sufficient acreage available in ddlling unit. .......... 8. If deviated, is wellbore plat included ............. 9. Operator only aff~ 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. ........ WELL NAME/~_/~---¢' z¢2-// GEOL AREA dev~' reddl serv [] wellbore seg [] ann. dispo,.~ para req Fl UNIT# ON/OFF SHORE ~ ~ REMARKS ENGINEERING APPR _~ 14. Conductor s~'ing provided ................... Y N 15. Surface casing protects ail known USDWs .......... Y N 16. CMT vol adequate to circulate on conductor & surf csg .... Y N - 17. CMT vol adequate to tie-in long s~'ing to surf csg ....... Y N 18. CMT will cover ail known productive horizons ......... ~ N 19. Casing designs adequate for C, T, B & permafrost. ..... (~ N 20. Adequate tankage or reserve pit. ............... ~))N 21. if a re-drill, has a 10-403 for abndnmnt been approved .... Y N 22. Adequate wellbore separation proposed ........... L.~..N. ^ 23. If diverter required, is it adequate ................ 24. Drilling fluid program schematic & equip list adequate .... (~N 25. BOPEs adequate ........................ ,,i-,~,,,,,N 26. BOPE press rating adequate; test to "~ ~-~-~ psig.¢~) N 27. Choke manifold complies w/AP! RP-~ (May 84} ....... ~N 28. Work will occur without operation shutdown .......... ,~N 29. Is presence of H2S gas probable .............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N / 31. Data presented on potenfial overpressum zones ....... Y .,~ 32. Seismic analysis of shallow gas zones ............ :~k~. Soat:~ condition survey (if off-shore) .......... .~.. Y N D TE 34. Contact name/phone for weeid~ pro(jre~, repo~,.../'... Y N _ ~, lex~wmm~on~j /' GEOLOGY: ENGINEERING: COMMISSION: JDH JDN Comments/Instructions: t~ o .. HOW/Ij~ - A,~-OR~ rev 4/96 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. Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 26 09:51:56 1997 Reel Header Service name ............. LISTPE Date ..................... 97/08/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Cemments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/08/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... LrNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-70148 STEVE LATZ HILDRETH/SEV REOEIVED AUG 27 199~' Alaska Oil & Gas r.;ons, ~mmi~ Anchorage 500292045001 BP EXPLORATION (ALASKA) , INC. SPERRY-SUN DRILLING SERVICES 26 -AUG- 97 MWD RUN 2 MWD RUN 3 AK-MW-70148 AK-MW-70148 STEVE LATZ STEVE LATZ HILDRETH/SEV HILDRETH/SEV JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-70148 STEVE LATZ HILDRETH/SEV MWD RUN 5 MWD RUN 6 AK-MW-70148 AK-MW-70148 STEVE LATZ STEVE LATZ HILDRETH/SEV HILDRETH/SEV JOB NI/MBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 7 AK-MW-70148 STEVE LATZ HILDRETH/SEV MWD RUN 8 AK-MW-70148 STEVE LATZ H I LDRETH / SEV SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 23 lin 13E 2710 1067 71.50 .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2685.0 9.625 8894.0 7.000 9407.0 3.750 10920.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 8 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND GREG BERNASKI OF BP EXPLORATION (ALASKA), INC. ON 25 AUGUST, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10920'MD, 8941'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE S~MARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9386.5 10893.0 ROP 9413.5 10920.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP 1 9413 0 2 9653 0 3 9752 0 4 9980 0 5 10023 0 6 10064 0 7 10489 0 8 10590 0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9653 0 9752 0 9980 0 10023 0 10064 0 10489 0 10590 0 10920 0 Name Service Order Units Size NsamRep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9386.5 10920 10153.2 3068 9386.5 GR 17.62 1166.7 32.9735 3014 9386.5 ROP 13.76 3096 130.104 3014 9413.5 Last Reading 10920 10893 10920 First Reading For Entire File .......... 9386.5 Last Reading For Entire File ........... 10920 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI/MBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9386 . 5 9625 . 5 ROP 9413 . 5 9652 . 0 $ LOG HEADER DATA DATE LOGGED: 23 -MAY- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 16.5 MAXIMUM ANGLE: 85.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE NGP SPC 239 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 BOREHOLE CONDITIONS MUD TYPE: FLO-PRO MUD DENSITY (LB/G) : 8.80 MUD VISCOSITY (S) : 65.0 MUD PH: 9 . 0 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): . 000 MUD AT MAX CIRCULATING TERMPERATURE: .000 63.3 MSC 1.32 NGP 5.74, DEP 2.041, MEMORY 9653.0 9413.0 9653.0 42 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ) REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9386.5 9652 9519.25 532 9386.5 GR 17.62 562.82 38.689 479 9386.5 ROP 29.32 594.37 60.126 478 9413.5 Last Reading 9652 9625.5 9652 First Reading For Entire File .......... 9386.5 Last Reading For Entire File ........... 9652 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ARIMBER: 2 DEPTH INCREMENT: .5000 FILE SIIMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9620.5 9725.0 ROP 9654.0 9751.5 $ LOG HEADER DATA DATE LOGGED: 24-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.6 MAXIMUM ANGLE: 85.4 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9752.0 9653.0 9752.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ · BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER NGP SPC 239 3 .750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (O~R4M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 65.0 9.0 6.0 .000 .000 .000 .000 77 .3 NEUTRON TOOL I~3NTRIX: i~[ATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9620.5 9751.5 9686 263 9620.5 GR 18.18 63.79 25.4369 210 9620.5 ROP 29.42 99.44 67.3301 196 9654 Last Reading 9751.5 9725 9751.5 First Reading For Entire File .......... 9620.5 Last Reading For Entire File ........... 9751.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service n~me ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NLTMBER: 3 DEPTH INCREMENT: .5000 FILE S~Y VENDOR TOOL CODE START DEPTH GR 9726.0 ROP 9753.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9953.0 9979.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 24-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 9980.0 9752.0 9980.0 77.7 81.0 TOOL NUMBER NGP SPC 239 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3 .750 3.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHlViM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 '65.o 9.0 6.0 .000 .000 .000 .000 63.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units... .................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9726 9979.5 9852.75 508 9726 GR 17.89 54.52 24.9235 455 9726 ROP 13.76 3096 108.177 453 9753.5 Last Reading 9979.5 9953 9979.5 First Reading For Entire File .......... 9726 Last Reading For Entire File ........... 9979.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... ST~LIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9953.5 ROP 9981.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9996.0 10022.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 24-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10023.0 9980.0 10023.0 80.9 82.2 TOOL NUMBER NGP SPC 288 3 .750 3.8 FLO-PRO 8.90 65.0 9.0 5.6 .000 .000 .000 .000 65.6 .3 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9953.5 10022.5 9988 139 9953.5 GR 20.13 46.14 28.7419 86 9953.5 ROP 52.45 135.81 95.6714 83 9981.5 Last Reading 10022.5 9996 10022.5 First Reading For Entire File .......... 9953.5 Last Reading For Entire File ........... 10022.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA START DEPTH STOP DEPTH 9997.0 10037.0 10024.5 10063.0 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH:' MUD CHLORIDES {PPM) : FLUID LOSS {C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 25-MAY-97 MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10064.0 10023.0 10064.0 82.2 91.3 TOOL NUMBER NGP SPC 288 3.750 3.8 FLO-PRO 8.70 65.0 9.5 6.4 .000 .000 .000 .000 63.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 GR MWD 5 AAPI 4 1 68 ROP MWD 5 FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 9997 10063 10030 133 GR 19.54 60.11 29.1881 81 ROP 93.09 352.62 218.801 78 First Last Reading Reading 9997 10063 9997 10037 10024.5 10063 First Reading For Entire File .......... 9997 Last Reading For Entire File ........... 10063 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10040 . 5 10462 . 0 ROP 10065 . 0 10488.5 $ LOG HEADER DATA DATE LOGGED: 25-MAY- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10489.0 10064.0 BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 10489.0 82.1 97.4 TOOL NUMBER NGP SPC 288 3.750 3.8 FLO-PRO 8.90 65.0 9.0 5.6 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Readin~ DEPT 10040.5 10488.5 10264.5 897 GR 19.24 1166.7 36.1529 844 ROP 30.14 1545.3 132.431 848 10040.5 10488.5 10040.5 10462 10065 10488.5 First Reading For Entire File .......... 10040.5 Last Reading For Entire File ........... 10488.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10458.5 10563.0 ROP 10486.5 10589.5 $ LOG HEADER DATA DATE LOGGED: 26-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMI/M ANGLE: 85.6 MJ~XIMIJM ANGLE: 91.0 TOOL STRING (TOP TO BOTTOM) MSC 1.32 NGP 5.74, DEP 2.041, 42 MEMORY 10590.0 10489.0 10590.0 VENDOR TOOL CODE NGP $ TOOL TYPE NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 239 3.750 3.8 FLO-PRO 8.90 65.0 9.0 5.6 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10458.5 10589.5 10524 263 10458.5 GR 20.86 40.21 28.236 210 10458.5 ROP 56.13 289.08 126.506 207 10486.5 Last Reading 10589.5 10563 10589.5 First Reading For Entire File .......... 10458.5 Last Reading For Entire File ........... 10589.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH' INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10564 . 5 10893 . 0 ROP 10591 . 5 10920 . 0 $ LOG HEADER DATA DATE LOGGED: 26-MAY- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.5 MAXIMUM ANGLE: 107.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP $ NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): MSC 1.32 NGP 5.74, DEP 2.041, MEMORY 10920.0 10590.0 10920.0 TOOL NUMBER NGP SPC 239 3 .750 3.8 42 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 FLO-PRO 8.90 65.0 9.0 5.6 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 72.6 First Name Min Max Mean Nsam Reading DEPT 10564.5 10920 10742.2 712 10564.5 GR 19.63 160.49 35.2861 658 10564.5 ROP 31.28 2844 206.939 658 10591.5 Last Reading 10920 10893 10920 First Reading For Entire File .......... 10564.5 Last Reading For Entire File ........... 10920 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/08/26 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/08/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNtqNOWN Comments ................. STS LIS Writing Technical Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/08/26 Origin ................... STS Reel Name ................ IZNIGqOWN Continuation Number ...... 01 Next Reel Name ........... UNYK_NOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File