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199-059
• • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,August 7, 2017 8:36 AM To: AK, GWO Well Integrity Engineer;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GC1 OSM;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A;AK, RES GPB West Wells Opt Engr;AK, OPS Well Pad EKG;AK, RES GPB East Wells Opt Engr;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J; Regg,James B (DOA);Wallace, Chris D (DOA);AK, OPS GC1 Facility OTL;AK, OPS Well Pad DG;AK, OPS Well Pad YP;Ak, Ops West Area IL;Alatalo,Travis; Cerveny, Philip F; Derrick, Laurie R; Frankenburg,Amy; Haffener,Jordan;Oshiro,Joleen Cc: AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep; Derrick, Laurie R; Daniel, Ryan;AKIMS App User;AK,GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer E-27 (PTD# 1990590) Well Barriers Restored All, Producer E-27 (PTD#1990590)was made under evaluation on 7/25/17 after the inner annulus casing pressure exceeded NOL. On 8/3/17 slickline performed a gas lift change out and the well passed a subsequent TIFL on 8/4/17. Follow up monitors of the IA pressure show no signs of repressurization. The well now has two competent barriers and is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer nit Office: 907-659-8110 SC psp� Cell: 907-341-9068 JW+�• WO global woe*o•gamissore From: AK, GWO 1- - •rity Engineer Sent: Tuesday, July 25, 2017 .- To: AK, GWO Well Integrity Engineer; A', . 0 Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 I, ••d Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; A', :• Well Pad EKG; AK, RES GPB East Wells Opt Engr; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie, •ntgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington, Aras J; 'Regg, James B (DOA) (jim.reg•`'1,laska.gov)'; 'chris.wallace@alaska.gov'; AK, OPS GC1 Facility OTL; AK, OPS Well Pad DG; AK, OPS Well Pad YP; Ak, Ops • Area TL; Alatalo, Travis; Cerveny, Philip F; Derrick, Laurie R; Frankenburg, Amy; Haffener, Jordan; Oshiro, Joleen • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday,July 25, 2017 1:49 PM To: AK, GWO Well Integrity Engineer;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS GC1 OSM;AK, OPS GC1 Field O&M IL;AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A;AK, RES GPB West Wells Opt Engr;AK, OPS Well Pad EKG;AK, RES GPB East Wells Opt Engr;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski,Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J; Regg,James B (DOA);Wallace, Chris D (DOA);AK, OPS GC1 Facility OTL;AK, OPS Well Pad DG;AK, OPS Well Pad YP;Ak, Ops West Area TL;Alatalo,Travis; Cerveny, Philip F; Derrick, Laurie R; Frankenburg,Amy; Haffener,Jordan; Oshiro,Joleen Cc: AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep; Derrick, Laurie R; Daniel, Ryan;AKIMS App User;AK,GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer E-27 (PTD# 1990590) High Inner Annulus Pressure Over NOL All, Producer E-27 (PTD# 1990590)was reported to have sustained inner annulus casing pressure above NOL on 7/24/17. The pressures were reported to be TBG/IA/OA= 20/2020/940psi. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Plan Forward: 1. Slickline: C/O GLV's 2. Ops: Pop well 3. DHD: Warm TIFL 4. WIE: Additional Diagnostics as Needed Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 c�pp, AUG 0 9 R-01', Harmony 4530 ,1r^" 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, August 14, 2015 8:59 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M IL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad EKG; AK, RES GPB East Wells Opt Engr; Derrick, Mackie;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA) Subject: NOT OPERABLE: Producer E-27A (PTD# 1990590) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer E-27A (PTD# 1990590) TIO Plot.docx All, Producer E-27A(PTD# 1990590) was reported to have sustained inner annulus casing pressure above MOASP on August 10, 2015.The pressures were reported to be TBG/IA/OA= SSV/2100/280 psi. At this time,the well has been reclassified as Not Operable until integrity can be verified or restored. Plan Forward: 1. Downhole Diagnostics:TIFL 2. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GWGlobal Welk O'garntat;o,1 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 • Producer E-27A(PTD#1990590) TIO Plot August 14, 2015 Well E 27 +n. f Y --OW .q .tt 04.111-5 62tI5 06]41515 IS 0'2". 0205 MOS OiEY15 t°l°t•059 _ zroi% ,A`- BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal fo COMPANY BP Exploration Alaska Inc BP Exploration (Alaska) Inc. (mandatory) Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME E-27A 900 E. Benson Blvd. '7/29/2015 vt. K. BENDER (mandatory) Anchorage, Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough ^e tLOE RPM-Wireline (mandatory) REC (mandatory) STATE Alaska �UL c �$1 RICT Alaska (mandatory) (mandatory) LOG DATE: June 5,2015 �or±(`� TODAYS DATE: 28-Jul-15 (mandatory) AOGCC DISTRIBUTION LIST AUTHORIZED BY: CANIZARES EMAIL: (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS #Ur NKIN 15 #OF COPIES#OF COPIES#OF COPIES#OF COPIES V' v v v v v 1 ConocoPhillips Alaska Inc. 2 1 1 1 Attn:Ricky Elgaricio = E-27A_MRPM_RAW_05JUN2015_BHI.meta ATO 3-344 700 G Street = '(Folder 1 on cd/dvd) E-27A_MRPM_RAW_05JUN2015_B Anchorage,AK 99510 I rninar / nn rninvn t — " _ "" _ ,^•_ '-' '-•,. 2 ExxonMobil,Alaska 1 1 1 1 iAttn:Lynda M.Yaskell and/or Lisa Boggs '3201 C Street,Suite 505 Anchorage,AK 99503 3 State of Alaska-AOGCC I 1 I 1 I 1 1 l Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 4;DNR-Division of Oil&Gas 0 0 1 1 'Attn:Sean Clifton 1550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5I I I I I SCANNED JUL 3 0 2015 TOTALS FOR THIS PAGE: 3 4 4 0 0 TOTALS FOR ALL PAGES: 4 3 4 4 0 0 STATE OF ALASKA 4. ALASKA OIL AND GAS CONSERVATION COMMIS JN • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 2. Operator Name. BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 199-059 3 Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number. 50-029-21760-01-00 7 Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU E-27A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: `�// RECEIED Total Depth. measured 11090 feet Plugs measured feet '" true vertical 9025 feet Junk measured feet JUL Ul L 0 6 2015 Effective Depth: measured 11027 feet Packer measured See Attachment feet true vertical 9023 feet Packer true vertical See Attachment feet pQ G C c Casing: Length: Size: MD: TVD: Burst: Collapse. Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet SCANNED i U 21;i F True vertical depth. See Attachment feet See Attachment See Attachment See Attachment Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 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 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 397 5093 22 400 183 Subsequent to operation: 653 7635 153 1740 202 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work. Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O Exempt: Contact Catron,Garry R(Wipro) Email Garry Catron@bp com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature )1/�.,t�, 0(;: ..... Phone +1 907 564 4424 Date 7/6/15 ._.- ._`."_'.__ 'IV V TL 71/51/ RBDMSA\ JUL - 7 2015 Packers and SSV's Attachment PBU E-27A SW Name Type MD TVD Depscription E-27A PACKER 8527.08 8046.7 4-1/2" Baker S-3 Perm Packer E-27A PACKER 8666.25 8167.58 4-1/2" TIW HBBP Packer 0) Q 0 0 0 0 0 0 ca N I� CO CO N- co 0 0 CO CO I� V cr.) l!') Ln N- O N V V LOf� I� U N o o 0 0 0 o o CO CA 00 47 NV m co co co co co CO O 00 N LO N r O V N CO CO CO V 0o O N N N CO CO O CO CO H O V 00 CO CA Co CO LO N N CO LC) CO cr CO r N N N 00 CO CO CD (A O CO (b V O f� 0") LC) (` O CA CO Co 00 r O V ti CO N N CO O CO CO V 0 +J Q 2 < N co c0 co CNI O O 00 LO NCOU COC7 7 CD , vwvchr-- r--- OM = w N CO CO CO H cno 0000 C? co O O CO CO O J CO. CO. O J co U J J 00 _ CL) N N *k J CO CO N _ V CV CO • O _ oci c� co N - o , cncn � N N 2 2 d d N V � z CS)O (A Oo ON N N Lo CD p0) C 00 (b CO .- CO ~ c) Cc) i[) G) - '- N co CO N '- c0 J LU 12 H < Q a)O 0 0 CU w w w w u_ u_ CCQ' � ZZ Z w w w w ODD ~ ~ Z Z D D UCf) C/) J � � a) N Ca m O) 01 CO LU LU LU LU CO N c, U) cv Q U7 N- C) 6 N O N N CO N O) O w OO d) 0 0 0 c- v- r- v- N O O) d) 0 0 CD 0 0 0 0 cD 0 0 0 OD LU O) 6) O) d) O) O) O) 6) 0) H 0 a > Q 0 0 W H LU O) CO LU V LU LU - N- co LU J W L N- UD ( OO U) CD N- UJ O W J U Z fl- O M C) 6 6 O N N CO O) O < W CD 0 LU O) CD O O O N p p U J p 0 O) 6) CD O O O O O O O C) O W W Z U J p J W 0 OO OD 6) O) O) O) O) O) O) O) O) H H Q = w a H 1 > F g a 0 W O LU Z HZO O OJ W a -j a < .j < LU ( C 2 O 0 O (n U n a a) N N CO t O f- O) O) U7 O 0) LU N N- O ++ O. O N- 0) CO 0) N LU N U7 C) U7 C CO O O CD CD O O 0 O) O) O) O) O) CDcoN a) a) (n Y = ~ HH0 d J O (� < 2 2 2 0 U U U (n (n 03 Q• N 0. LLQ o H cv O U) O CO 0 0 LU _ Q- ON- LC) M CSO O N U) O) O) c) p 0) 0, 0) O) °) 0 0 0 CO 0 0 C▪- m rn rn rn 00c 00 CI= L d O 4- L a) Q. y 0 � W O J U D w H 0 LL LL LL LL IL W W W' OC Q' OC a ULu m d d d W a d d W W W W W O 0 p a7 Q Q Q Q Q Q Q a a L J J Z W Z W a a Q LU W 0 W W W J LU W 0C Z a C7 ° U W W W W a m 0 E E J DD W LU Q Q C] m W E (n co a s rn rn rn rn rn r- o 0 0 0 0 0 CD CD CD CD CD C o 0 0 0 0 0 0 2 N N CN CN (V (V N CO V V M M Nin in in in N N N N N O_ CO M M M (M C) C) I- r- r- r- W a (n 0 LL N W J O < < m m U u U) U) a s a) E m Z « «Q Q Q Q Q Q Q Q Q N- N- N- N- N- N- ti N- N- ti N- r- cn N N N N N N N N N N N N W W W W W W W W W W W • 0) I a E = c k 0 $ 2 0°\ / �fE \ - 0 / a a CO < co \ \ \ \ \ k ƒ 2oG � � n = 0- ® P. P CO o - - a = 9 c m \ ecw _ U) / ƒ a m & I Ic i_ a « O 0a u) \ « \ / a ± § )- ') • 0_ \ E CO < i a0 20 f Ee CD > 0 0 \ % / % CL D 02 ( E \ -o ® _O < / & ± 0 ts \ O 2 \ 0 3 CI) Csi \ . / Ec a_ @ RW 20 . / \ G / + � a \ e = ) \ - ; / ZN / - / \ 6 . - e - 0 • / \ \ V G \ z . t — _G \ E @ IX \ % 2 / t / / < % G t / N- \ _ II H / - \ \ / / \ E / co $ k \ / \ \ \ \ p — 000u) (-) 0\ / / 2 § 2 © 0 5 0 / k nm - 05 O / / 6 / / E / / \ \ \ / E 2 o i / / _ - e = - 2 C o k 8`' r)£ \ / o a « \ 9 § ° ® ® § / $ CO E ® C. t _w a o c ® 0 D o N . e a_ co \ 6 ® < j k G j ) / \ \ j $ 6 j 2 / / 0 f 2 O \ O y 2 \ y c 2 \ / f 2 \ 4=, o / / / / 0 2 .f~ 2 ° 2 .\ oAE62o7o00 __ o0 a / Y g = 2 . 0 H -Oroco = U \ 5 � � $ aJ 0 0 \ i 0 0 : \ \ -0 o 0 0 i I $ 2 { � r ,- ± I- < r r r 0 / \ \ / $ 2 \ > 7 r 7 I ,- -- p o $ e O < TREE_ # CNV viaLHEAD= McEVOY S f NOTES: WELL ANGLE>70°@ 9628' _______ C E-27A "'4-1/2"CHROME TUBING"' ACTUATOR- BAKER C OIB.ELEV= 67.5' BF.EBV= 31.08' KOP= 4200' 13-3/8"CSG,72#, H 1888' �- :-/". 4` I Max Angle= 92`@ 10195' L-80 XO TO S 95 )4 f 4 Datum MD 9478' )c'I 1 1 4+� 2089' H4-1/2"FES Xtom,D=3.813" Datum ND= 8800'SS ���e 044. 2095' H9-5/8"HES CEMENTER 0.0 9-5/8'CSG,47#,L-80 TCI XO TO L-80 BTC H 2080' , GAS LIFT MANDRELS 9-5/8"CSG,47#,L-80 TC-11,ID=8.681" H 2145' ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3411 3409 3 MMG DOME RK 16 10/06/07 13-3/8'CSG,72#,S-95,ID=12.347" —{ 2677' ii 3 5829 5696 30 MMG SO RK 20 10/06/07 X 2 7451 7096 28 MMG DMY RK 0 09/22/07 9-5/8"CSG,47#,L-80 NSCC XO TO L-80 BTRS H 4443' VI 1 8403 7939 29 MMG DIM' RK 0 09/22/07 Minimum ID =2.387" @ 8740' 1 1 8483' H4-1/2"HES x NP,D=3.813" 2-7/8" XO PIN 2C 8514' H9-5/8"X 4-1/2"TNV FI3BP PKR,ID=4.75" I I 8549' -14-1/2"FES X NP,D=3.813" 4-1/2'TBG,12.6#,13CR-S0 VAM TOP, — 8621' 1-...,_,„__ .0152 bpf,ID=3.958" I 1 8621' —19-5/8"X 4-1/2"LNQUE OVERSHOT $645' H4-1/2"PBR SEAL ASSY 4-1/2"TBG STUB(09-17-07) H 86155' 8665' —{9-5/8"X 4-1/2"TM/HBBP PKR,ID=4.75" I 8709' H4-1/2"OTIS X NP,D=3.813" TOP OF 7"LNR 8726' 8726' —17'BROWN LNER HANGER HII 8736' —13-3/4"DEPLOY SLEEVE,D=3.00" TOP OF 2-7/8"LNR —j 8736' II 8740' H2-7/8"XO RN 1 II 8752' —14-1/2"OTIS XN NP,D=3.725"(BatIND PIPE) 4-172"TBG, 12.6#,L-80,.0152 bpf,D=3.958' —{ 8787' 8787' —14-1/2"WLEG w/SFEAROUT Sly,D=3.958" / 9-5/8"CSG,47#,L-80 BTRS,D=8.681" -1 8977' ' 8791' --i ELAND TT LOGGED 11/21/87 TOP OF WHIPSTOCK H 9400' RA TAG --I 9410' • 9003' Hr MARKER JOINT PERFORATION SUMMARY REF LOG:SPEFRRY SUN MVVD ON 07/21/03 ANGLE AT TOP PERF: 80'@ 9770 MLLOUT WINDOW(E-27A)9404'-9409' Note:Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz SHOT SOZ 2" 6 9770-9800 0 6/6/2015 2" 6 9852-9877 0 03/04/05hillil\ 41144, 2" 6 9914-9989 0 03/03/05 10949• 4I414, 2' 6 10000- 10050 0 03/03/05 40.0.1.0.0.0.144411* 2" 4 10050- 10379 0 07/25/99 ��0.0.0.0.0.041 2' 4 10393- 10418 0 07/25/99 4�0.0�1�0.010.4 11027' —MID 2" 4 10490- 10652 0 07/25/99 40.0.0.0.0.0./ •i� ! 2" 4 10700-10937 0 07/25/99 �.��•�•j•j•j•j/ 2" 4 10945-10950 0 07/25/99 04������������� �4.4.4.4�4�4�40 2-7/8"LNR,6.16#,L-80 STL, .0058 bpf,D=2.441" —I 11090' r"LNR,26#,L-80,.0383 bpf,D=6.276' H 9775' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/09/87 AID 2 ORIGINAL COMPLETION 06/24/15 SRLYJMD ADPE.RF(06106/15) WELL: E 27A 07/01/99 DOW SIDETRACK(E-27A) PEWIT No:'1990590 09/23/07 016 RWO AR No: 50-029-21760-01 10/06/07 KSB/TLH GLV CJO SEC 6,T11N,R14E,1819'ANL&882'FEL 01/30/09 ?/JMD DRLG DRAFT CORRECTIONS 02/11/09 RM-VPJC DRLG DRAFT CORRECT1ON5 BP Exploration(Alaska) • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, January 14, 2011 10:34 PM 5�1cy 1 (Z4 ( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570) C -15A (PTD #2090520) E -17A PTD #2042040) - (P 1 #1990591» 1`'� F -046 04B ' ' if: ° 1 ) W -01A (PTD #2031760) W -16A (PTD #2031000) W -21A (PTD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 09 -34A (PTD #1932010) M -21A (PTD #1930750) N -22B (PTD #2061610) All the wells listed above will be classified as Not Operable until start -up operations commence and are stable or the well passes a pressure test proving integrity. After start-up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. 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 1/24/2011 STATE OF ALASKA ~/OJ6-~D~ ALA O1L AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS ~~~E~ Y ~D t; l~ 1 6 2007 Alaska Oii & Gas Cons. Cott~nission 1. Operations Performed: All>rtlOfag@ ^ Abandon ~~® Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~.~ ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 199-059 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21760-01-00 7. KB Elevation (ft): 67 5' - 9. Well Name and Number: . ~ Psu E-2~a - 8. Property Designation: 10. Field /Pool(s): ADL 028304 - Prudhoe Say Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11090 ' feet true vertical 9025 feet Plugs (measured) None Effective depth: measured 11027 feet Junk (measured) None true vertical 9023 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2677' 13-3/8" 2677' 2676' 4930 2670 Intermediate 8977' 9-5/8" 8977' 8441' 6870 4760 Production Liner 678' 7" 8726' - 9404' 8220' - 8811' 7240 5410 Liner 2354' 2-7/8" 8736' - 11090' 8229' - 9025 13450 13890 Tieback Liner 2120' 9-5/8" 2145' 2145' 6870 4760 ~t ~~ ~~:' NCV ~ 2D07 ~~`~ Perforation Depth MD (ft): 9852' - 10950' Perforation Depth TVD (ft): 8994' - 9020' 4-1/2", 12.6# 13Cr80 / L-80 8787' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; --- - -- 8514'; 9-5/8" x 4-1/2" TIW'HBBP' packer 8665' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and fin al pressure: Cut and pull tubing from 8615'. Cut and pull 9-5/8" casing from 2141'. Run new 9-5/8", 47#, L-80 tieback to surface and cement with 151 Bbls Class'G' 848 cu ft / 731 sx . Run new Chrome com letion. 13. Re resentative Dail Avera a Production or in'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 307-275 Printed Name Terrie Hubble Title Drilling Technologist f I Preparetl By Name/Number: / ~(~ ! Signature •---_•..-.... Phone 564-4628 Date I Terrie Hubble, 56a-4628 Form 10-404 Revised 04/2006 ('~ ~ I ~ (~ A ~'~-~ ~~'~~~~ ~ °,~j~ ~ ` Submit Original Only U //"\~ ~ d ~ 1 \O ,~ Digital Well File • ~ Page 1 of 2 Well: E-27 Well History Well Date Summary E-27A 8/24/2007 T/I/O = 660/700/0 Assist Slick line with brush and flush. Pumped 216 bbls of crude down tubing. FWHPs = 200/850/20 ( IA/OA casing and needle valves open to gauges at time of departure) E-27A 8/24/2007 ***WELL SHUT IN ON ARRIV*** DRIFTED TO 9100' SLM W/ 2.25" CENT. & SAMPLE BAILER DRIFTED TO & SAT DOWN ON SCHMOO @ 433' SLM W/ 3.80" GAUGE RING BRUSH AND FLUSH W/ 5.5" BLB AND 4.5" GAUGE RING MADE HOLE TO AND TAGGED 5-1/2"x4-1/2" XO @ 2513' MD B&F DOWN TO LNR TOP @ 8736' MD W/BRUSH AND 3.75" GAUGE RING ***JOB CONT. ON 8/25/07"' E-27A 8/25/2007 ***JOB CONT. FROM 8/24/07**' PREFORM CALIPER SURVEY AS PER PROGRAM *'"'WELL TURNED OVER TO DSO*`* E-27A 9/1/2007 **'WELL SHUT-IN ON ARRIVAL**' LRS PUMPED LOADED WELL WITH 260 BBL 1%KCL. T/1/O 0/770/0. BAKER EZ DRILL BRIDGE PLUG SET MID-ELEMENT IN 2-7/8" LINER AT 8 967 FT. 500 SMALL TUBING PUNCH OVER INTERVAL 8,582-8,584 FT. RIH W/ 2 STRAND X 12 FT STRING SHOT. DEVIATION AT PLUG SET 28 DEGREES. DEPTHS CORRELATED TO TUBING TALLY DATED 7- NOV-1987. JEWLERY INCONSISTANT WITH TUBING TALLY, NEW DEPTHS VERIFIED WITH CLIENT. ****CONTINUED 2-SEPT-2007**** E-27A 9/1/2007 T/I/0= 425/650/0 Temp= S/I Assist E-line, Load well (RWO prep) Pumped 5 bbls meth spear followed by 263 bbls 1 %KCL capped with 41 bbls crude and 6 bbls diesel and 5 bbls meth for freeze protect, Final W H P's 1100/750/0 E-line still on well upon departure, Annulus casing valves tagged & left open E-27A 9/1/2007 T/I/0=0/725/0 temp=Sl Assist E-line with CMIT Tx to PASSED to 3500 psi (RWO Prep) Pumped 14 bbls crude down TBG and 73 bbls crude down IA to reach pressure of T/I 3400/3500. T/I lost 100/100 psi in first 15 minutes and 40/40 psi in second 15 minutes. For a total of 140/140 psi in 30 minutes. Bled back 30 bbls crude. Casing valves left in normal position at departure. E-line on well at departure. Operator notified of results. FWHP's=900/480/0 E-27A 9/2/2007 ***CONTINUED FROM 1-SEP-2007*** /O 100/490/0 RUN 2 STRAND X 12 FT STRING SHOT OVER INTERVAL 8620-8632 FT. PERFORM 3-5/8" CHEMICAL CUT OF 4-1/2" TUBING AT 8630 FT. MINOR WASHOUT OF CUTTER HEAD < 1/4" DEE WIDE, APPROX 3 " OF HEAD CIRCUMFERENCE. FINAL T/I/0 220/450/0 DEVIATION AT CUT 28 DEGREES. DEPTHS CORRELATED TO TUBING TALLY DATED 7-NOV-1987. JEWLERY INCONSISTANT WITH TUBING TALLY, NEW DEPTHS VERIFIED WITH CLIENT. ***JOB COMPLETE*** E-27A 9/2/2007 ****CONTINUED FROM 1-SEP-2007"'*' ALREADY COMPLETED BRIDGE PLUG SET, TUBING PUNCH. T/I/O 100/490/0 2 STRAND X 12 FT STRING SHOT OVER INTERVAL 8620-8632 FT. 3-5/8" CHEMICAL CUT OF 4-1/2" TUBING AT 8630 FT. MINOR "SMILEY FACE" WASHOUT OF CUTTER HEAD < 1/4" DEEP AND WIDE, APPROX 3 " OF HEAD CIRCUMFERENCE. FINAL T/I/0 220/450/0 DEVIATION AT CUT 28 DEGREES. DEPTHS CORRELATED TO TUBING TALLY DATED 7-NOV-1987. JEWLERY INCONSISTANT WITH TUBING TALLY, NEW DEPTHS VERIFIED WITH CLIENT. **'*JOB COMPLETE"'* E-27A 9/4/2007 T/I/0=200/400/0 temp=Sl Circ-out well/ Freeze Protect Flow Line (RWO Prep) Pumped 10 bbls neat methanol spear, 865 bbls 1 % kcl and 145 bbls diesel down TBG taking returns up IA to hard line jumper to Flow Line. Let U-tube for 2 hrs. Freeze protected Flow line with 5 bbls neat methanol, 31 bbls crude and 10 bbls diesel tail for clean Flow Line removal. Bled pressure down. Tagged Wing and Master valve. All casing valves left in normal position. FWHP's=0/0/0 E-27A 9/5/2007 T/I/0=0/0/0, Temp=Sl. PPPOT-T (FAIL), PPPOT-IC (PASS). Pre rig. PPPOT-T: Open bleeder screw to verify 0 psi in test void, bled to 0 psi (gas). Remove internal check and install Alemite external check. Function LDS, all moved freely with no sign of bent or broken pins. Stung into test port with high pressure bleeder tool. Pumped through void until clean tluid was achieved. Pressure void to 5000 psi for 30 min test, lost 500 psi in 15 min, lost 300 psi in second 15 min (FAIL). http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/16/2007 Di ital Well File Pa e 2 of 2 g PPPOT-IC:~en bleeder screw to verify 0 psi in test void. Remo~rnal check and install Alemite g external check. Function LDS, all moved freely with no sign of bent or broken pins. Stung into test port with high pressure bleeder tool. Pumped through void until clean fluid was achieved. Pressure void to 3500 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). E-27A 9/6/2007 Set 6" CIW Pre Rig E-27A 9/7/2007 T/I/0=0/0/0, Temp=Sl. PPPOT-T (FAIL). Eval Tubing hanger test void to determine which seals are leaking. PPPOT-T: Open bleeder screw to verify 0 psi in test void (0 psi). Internal check installed. Function LDS, all moved freely. Stung into test port with high pressure bleeder tool. Pumped through void until clean fluid was achieved. Pressure void to 5000 psi for 30 min test, lost 500 psi in 15 min, lost 300 psi in second 15 min (FAIL). Test void pressure bled to 4200 psi in 30 min, and remained there for 60 min. Monitored Tubing head adapter neck seal test ports during test, both upper and lower remained at 0 psi indicating that the failure is at the primary seal. Print Date: 10/16/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 10/16/2007 • E-27A E-27A WORKOVER DOYON DRILLING INC DOYON 16 BP EXPLORATION Page 1 of 8' Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 9/14/2007 Start: 9/14/2007 Rig Release: 9/24/2007 Rig Number: Spud Date: End: ~ :Hours Task Code NPT i Phase Description of Operations rom - To j 00:00 - 13:00 13.00 MOB I C 13:00 - 23:00 10.00 MOB P 23:00 - 00:00 1.00 MOB P 9/15/2007 00:00 - 01:00 1.00 MOB ( P 01:00 - 04:00 3.00 MOB ~ P 04:00 - 06:30 2.50 MOB P 06:30 - 11:00 4.50 MOB P 11:00 - 17:30 6.50 RIGU P 17:30 - 18:00 1 0.501 KILL I P 18:00 - 19:00 1.00 KILL P 19:00 - 20:30 1.50 KILL P 20:30 - 22:30 I 2.00 I KILL I P 22:30 - 23:00 0.50 KILL P 23:00 - 00:00 1.00 WHSUR P 9/16/2007 00:00 - 00:30 0.50 WHSUR P 00:30 - 02:00 1.50 WHSUR P 02:00 - 02:30 0.50 WHSUR P 02:30 - 04:30 2.00 BOPSU P 04:30 - 05:30 1.00 BOPSU P 05:30 - 06:30 1.00 BOPSU P 06:30 - 12:00 5.50 BOPSU P 12:00 - 12:30 ' 0.501 BOPSUF~ P 12:30 - 13:00 0.501 WHSUR P 13:00 - 13:30 0.501 PULL P PRE Continued to remove, inspect and repack wheel bearings. i Reinstalled ring and inside drivers side tire, spreader beam, and cellar equipment. Cleaned up area around 05-40. Install rear booster tires, front gooseneck and booster tires. Lay out mats on DS-05 access road. i PRE Move the Rig from DS-05 to E-Pad. PRE Lay mats on E-Pad Access Road. I PRE Continue to wait for Rig Mats to be laid on Access Rd ~ PRE Jack up Rig Crib under tires Pull Rig onto matting boards on I E-pad. ~, PRE Wait for Rig Mats to be Laid around reserve pit to Well E-27A. PRE Stage Rig to install BOPS and Raise Derrick. j PRE Begin spotting the Rig on well slot E-27A. At 12:00 hrs, had a hydraulic oil leak resulting in 3-4 quarts in secondary containment and a light mist/spray on the gravel. The cause i . was a fitting failure on a hydraulic hose on our jacking cylinder. Non-emergency spill hotline (x-5700) was notified immediately as well as Workover Superintendent, Drilling HSE Adviser and Pad Operator. Work on repairing the hoses. Traction report #2007-IR-2407389 was generated. Continue RU on well slot E-27A. Lay herculite and rig mats. Stage Tree, Adapter Flange and Tubing Spool behind the well. Back the Rig over well slot E-27A. Install double valve on the IA. RU Slop Tank. Begin taking on heated seawater into the Pits. ~ DECOMP Take on sea water and mix 20 bbl Hi-Vis sweep. Rig Accepted at 17:00 hrs. DECOMP R/U DSM Lubricator Test to 500 psi. Puli BPV. R/D DSM. DECOMP R/U Circulating Lines, Test lines to 3,500 psi. R/U 3" hoses ~ from the Cuttings tank to drillers side of the rig, Also rig up Vacuum truck to Cellar box as a precaution. DECOMP PJSM, Pump 20 bbl sweep followed by 653 bbls of clean sea water @ 6.5 bpm w/600 psi. Monitor well. DECOMP B/D R/D Circulating Lines. DECOMP R/U and Set TWC with Cameron Tech, Test f/below to 1,000 psi. And Test f/above to 3,500 psi, good test. DECOMP B/D Circulating lines and drain Production Tree. DECOMP N/D Production Tree and Adapter Flange. DECOMP Work LDS, Check and M/U Hanger XO iJ4S, M/U 6.25 Rounds. DECOMP N/U BOPE, Turn Buckles, Flow Riser. DECOMP Change Out Lower Rams to 3.5"x 6" VBRs DECOMP R/U BOP Test Equipment. DECOMP Pressure test BOPE to 250 psi / 3,500 psi per BP / AOGCC i Regulations. The test was witnessed by the BP W SL and ~ Toolpusher. The state's right to witness the test was waived by Lou Grimaldi at 12:00 hrs on 9/14/2007. All components passed. DECOMP RD BOPE Test Equipment. DECOMP RU Lubricator with Drill Site Maintenance Techs. Pressure test Lubricator to 200 psi - OK. Pull TWC. RD Lubricator. DECOMP MU Landing Joint with 7" IJ4S XO to the Tubing Hanger. Screw into Tubing Hanger with 6 turns. BOLDS with Cameron rep. Pull on the Completion and it began moving at 140K and Printed: 10/3/2007 2:22:46 PM w • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: E-27A E-27A WORKOVER DOYON DRILLING INC DOYON 16 Start: 9/14/2007 Rig Release: 9/24/2007 Rig Number: Date From - To Hours i Task I Code NPT ' Phase Page2of8~ Spud Date: End: Description of Operations 9/16/2007 ', 13:00 - 13:30 0.50 PULL P i DECOMP pulled the Hanger to the Floor with 150K. Inspect Hanger with I Cameron rep - OK. 13:30 - 14:30 1.00 PULL P DECOMP ! CBU at a rate of 13.5 bpm 1910 psi. Pumped a total of 465 j bbls. Monitor well dead - OK. RU Schlumberger Spooling Unit i while CBU. ', 14:30 - 16:30 2.00 PULL P i DECOMP LD Tubing Hanger. POOH with existing 5-1/2" Tubing laying ~ down in the Pipe Shed 1 x 1. Spooling up dual contro line i, while POOH. At 17:00 hrs, reached the SSSV Nipple. Recovered 13 of 24 Clamps, 2 of 4 Bands and the dual lines down to Joint #34 of 50. Consult with Anchorage Engineering and decision made to run a RCJB prior to dressing off the ; Tubing Stump. Continue POOH with existing 5-1/2" x 4-1/2" ' Tubing laying down in the Pipe Shed. ! 16:30 - 17:00 0.50 PULL P I DECOMP R/D Control Line Spooling Unit. 117:00 - 18:30 I 1.50 PULL P ~ DECOMP Continue to L/D 5.5" Tubing to 6,113' Gained 3 bbls. Checked for flow, suspect the Well was swabbed, Stabbed XO and Floor i Safety Valve, Observed well. Fluid level Dropped 10 bbls. Filled ~ the hole with 10 bbls, Well Stable. ! 18:30 - 20:00 1.50 PULL P DECOMP i Circulate Bottoms Up while Monitoring Fluid Levels. 20:00 - 22:30 2.50 PULL P DECOMP Pull 1 jt of 5.5" Tubing, Change over to 4.5" Tubing handling equipment POOH U5,770' when pulling the 1st GLM out of the ; hole began to Swab. Pulled GLM to Rig Floor and recovered Large wad of Control Line and 7 Control Line Clamp Rubbers 22:30 - 00:00 1.50 PULL P DECOMP Continue to L/D 4.5" Tubing to 5,649' 9/17/2007 00:00 - 04:00 4.00 PULL P DECOMP Continue to lay down 4.5" completion f/5,649' to surface. 62 jts ', of 5.5" tubing, general condition good .Boxes and Pins in good , condition slight pitting on the inside of tubes. 151 jts of 4.5" ` Tubing in good condition on Tubes, Boxes, Slight erosion on ~ I ' Pin Ends. 1-SSSV, 4-GLMs, 1-Sliding Sleeve, and 1-Cut Jt lenght=18.70' and OD of flare is 4.5" with a clean cut. Total i recovery of Control line Clamps is 21 and a partial out of 24 and 2 stainless steel bands out of 4 run. 04:00 - 04:30 0.50 PULL P DECOMP R/D Tubing Tongs, Clear and Clean Rig Floor. Flush Flow Line, Remove and Clean Flow Paddle, Remove Control Line Clamp from under Rotary table, Flush BOP Stack. i 04:30 - 05:00 0.50 CLEAN P DECOMP Install Wear Ring. ' 05:00 - 07:00 2.00 CLEAN P DECOMP P/U M/U BHA #1, Dress Off Shoe Assembly, BHA Consists i of:Dress Off Shoe, Wash Pipe, Wash Over Boot Basket, Double Pin Sub, 2-Junk Baskets, 9 5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, Pump Out Sub, XO, 9-6 1/4" Drill ~ Collars, XO. BHA = 338.67 " 107:00 - 15:00 8.OO CLEAN P DECOMP HT-38 Drill Pipe from the Pipe Shed 1 x TIH with BHA #1 on 4 15:00 - 16:00 1.00 CLEAN P ~ DECOMP 1. In with 262 Joints of 4" Drill Pipe. UW = 182K , DW = 160K. j Break circulation at a rate of 4 bpm / 275 psi. Established RW = 171 K with 30 RPMs and 5,000 ft-Ibs of torque. Tagged junk ~i at 13' in on Joint #262 (8,613') and pushed down to hard tag at ', 24' in on Joint #262 (8,624'). POH and RIH dressing off Tubing 'i Stump with 5-10K WOM with 40 RPMs and 5-10K ft-Ibs of , torque. Dress off approximately 2' off the top of the Tubing 16 00 17 00 ~ 1 00 ~ CLEAN P i ~ i ~ DECOMP I Stump. The Tubing Stump is at 8,615' 16MD. th T bi th IA d 20 bbl hi i d d P : - : . -v own u up e umpe s sweep e ng an a s ~ { I j I I I at a rate of 13 bpm i 2,700 psi. Magnets on surface were Printed: 10/3/2007 2:22:46 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: E-27A Common Well Name: E-27A Event Name: WORKOVER Start: 9/14/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 9/24/2007 Rig Name: DOYON 16 Rig Number: i Date From - To Hours Task Code NPT 9/17/2007 I, 16:00 - 17:00 I 1.00 ~ CLEAN (P 17:00 - 18:00 ! 1.00 CLEAN P 18:00 - 20:00 it 2.00 CLEAN P 20:00 - 21:00 1.00 CLEAN P 21:00 - 21:30 0.50 !CLEAN ~ P 21:30 - 22:30 1.00 EVAL P 22:30 - 00:00 1.50 EVAL P 9/18/2007 00:00 - 01:00 ' 1.00 EVAL P 01:00 - 09:00 8.00 EVAL P 09:00 - 10:00 j 1.00 EVAL P 10:00 - 11:30 ' 1.50 EVAL P 11:30 - 12:00 ' , 0.50 EVAL P 12:00 - 13:00 1.00 EVAL P 13:00 - 13:30 0.50 EVAL P 13:30 - 14:00 0.501 EVAL P 14:00 - 16:00 2.00 EVAL P 16:00 - 16:30 I 0.501 EVAL I P 16:30 - 18:30 j 2.00 EVAL P 18:30 - 19:00 I 0.50 EVAL P 19:00 - 19:30 0.50 FISH P 19:30 - 20:00 ', 0.50 FISH P 20:00 - 21:30. 1.50 FISH P 21:30 - 22:30 I 1.001 FISH I P 22:30 - 00:00 I 1.501 FISH I P 9/19/2007 00:00 - 03:30 ', 3.501 CASE ~ P Page 3 of 8 ~ Spud Date: End: Phase Description of Operations DECOMP covered with very fine metal shavings. Not much seen in the sweep across the Shakers. DECOMP Slip and Cut Drilling Line. DECOMP POOH with 4" Drill pipe. DECOMP Stand Back Drill Collars, UD Casing Scraper, and Dress Off Assembly, Serviced Junk Basket. Recovered 1/2 gal Metal Shavings in Junk Basket, And Two Large Pieces of Rubber Control Line Clamp = 1 Clamp. Positive indicaton of Dress Off on Dress Off Mill. DECOMP Clear and Clean Rig Floor. DECOMP N/D flow riser, N/U shooting flange for USIT logging ops. DECOMP Spot E-Line unit, PJSM with Loggers and Rig Crew, R/U SLB E-line Equipment. DECOMP Continue to R/U E-liners w/USIT Logging tools. DECOMP RIH to 8,585' w/USIT Logging Tools and Log Up as per program. H2S Drili conducted by D-Crew wiith excellent response. Field pick TOC = 2,175'. Discuss with Anchorage Engineering and decision made by Engineer to cut the 9-5/8" @ 2,140 in the middle of the first full Joint above TOC. Plan to set the RBP at approximately 2,800' which is below the 13-3/8" ,Shoe. Continue logging in hi-res mode over TOC and corrosion spots. DECOMP RD E-line. DECOMP ND Shooting Flange. NU Flow Riser. TIEB1 MU 9-5/8" RBP with Halliburton rep. TIEB1 TIH with 9-5/8" RBP on 4" Drill Pipe from the Derrick. TIEB1 In with 29 stands (87 Joints) of Drill Pipe. UW = 78K , DW = 80K. Set the 9-5/8" RBP 32' in on stand #30 from the Derrick = 2,802' COE. Set 20K and pull 5K over to confirm set - OK. TIEB1 RU Test Equipment. Pressure test the 9-5/8" Gasing~gainct the RBP to 1 500 si for 10 charted mins. It took 2.2 bbls to reach test pressure. RD Test Equipment. TIEB1 Dump 2,200 Ibs of 20/40 river sand on top of the RBP. Flush the DP with seawater to clear all the sand. Tag TOS @ 2,762' (40' of sand on top of RBP). TIEB1 PJSM with WSL, Toolpusher, Doyon Crew, CH2MHill Vac Truck Drivers, Halliburton rep and MI Engineer. Swap the well to 120 degree 9.8 ppg brine. TIEB1 POOH with RBP Setting Tool laying down Drill Pipe in the Pipe Shed. TIEB1 Clear and Clean Rig Floor. DECOMP M/U Cutter Assemby, BHA Consist of 8.25" Multi String Cutter, Stabilizer, XO, Pump Out Sub. BHA Length=11.48' DECOMP RIH with Cutter Assembly to 2,164'. DECOMP Obtain Parameters, Attempt to locate casing collars f/2,007' to 2,164' with 500 psi to 1,100 psi on knives. DECOMP Cut 9 5/8" Casing at 2,140' w/1340 psi , 50 RPM w/3,000 to 12,000 ft-Ibs of torque. DECOMP PJSM R/U Little Red Tested Lines to 3,000 psi. Close Bag Open OA Valve to Slop Tank, Pump 120 bbls of 120 deg 9.8 ppg brine, at 7 bpm with 1160 psi, Followed by 120 bbls of 120 deg Diesel @ 2 bpm with 620 psi. DECOMP Shut In 9 5/8"x13 3/8" Annulus, R/D Little Red, Spot Vacuum Printed: 10/3/2007 2:22:46 PM • BP EXPLORATION Qperations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 4 of 8 E-27A E-27A Spud Date: WORKOVER Start: 9/14/2007 End: DOYON DRILLING INC. Rig Release: 9/24/2007 DOYON 16 Ria Number: Hours I Task Code' NPT ! Phase ', Description of Operations Date ,From - To 19/19/2007 100:00-03:30 03:30 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 15:00 3.50 CASE P DECOMP Truck to Load f/Slop Tank, Tight Location had to stage in trucks. Pump 24 bbls 120 deg 9.8 ppg Brine to Clear Drill Pipe at 6 bpm w/ 740 psi. Shut in 9 5/8"x13 3/8" Annulus and Allowed Diesel to Soak for 30 Minutes. Pumped 20 bbl Safe Surf-O Sweep followed by 20 bbls Hi-vis Sweep at 4 bpm with ', 300 psi. Chased Sweeps with 120 bbls 120 deg 9.8ppg Brine. Closed in Annulus Valve and Circulated Drill Pipe x 9 5!8" Volume 124 bbls at 10 bpm with2200 psi. Pumped 10 bbl Dry 3.501 I CASE ~ P ~ DECOMP Job. POOH L/D 69 jts of Drill Pipe and Multi-String Cutter. 1.00 WHSUR' P I ~ DECOMP Pull Wear Ring. Clear and clean Rig Floor. 0.50 PULL P ~ DECOMP MU 9-5/8" Spear Assembly with Baker rep. BHA consists of: Bull Nose, Pack Off, XO, ITCO Spear, XO, Stop Sub, XO, XO. OAL = 17.04'. Engage the Casing. BOLDS with Cameron rep. 0.50 PULL P DECOMP Pull on the 9-5/8" Mandrel Hanger and released at 225K. Pull the Hanger to the Floor with UW = 125K. 0.50 PULL P DECOMP CBU at a rate of 9 bpm / 100 psi. Pieces of scale and rubber observed across the Shakers. Continue circulating until clean returns. Quality of brine unchanged throughout the whole ~ circulation. Pumped a total of 250 bbls. 0.50 j PULL ~ P I DECOMP Break out and lay down Spear Assembly with Baker rep. 0.50 ~ PULL ~ P l1 DECOMP RU 9-5/8" Handling Equipment. 4.50 PULL ! P f I DECOMP POOH with 9-5/8" NSCC Casin .The connections are 15:00 - 16:00 1.00 j PULL P 16:00 - 18:30 2.50 CLEAN P i 18:30 - 19:00 0.50 CLEAN P 19:00 - 21:30 2.50 CLEAN P 21:30 - 00:00 I 2.501 CLEAN I P 19/20/2007 00:00 - 01:30 ~ 1.50 CLEAN P 01:30 - 02:00 ' 0.50 CLEAN P 02:00 - 03:00 1.00, CASE P breaking at 30-40K ft-Ibs. The pipe is in real good condition and the outside is clean of any crude. Recovered a total of 54 Joints and (1) cut Joint = 12.67'. The last Joint to have a Centralizer was Joint #53 which would mean that the cut Joint would not have a Centralizer. DECOMP RD 9-5/8" Handling Equipment. Clear and clean Rig Floor. RU 4" DP Handling Equipment. DECOMP Bring BHA Components to the Rig Floor. MU BHA #4 as follows: Dress Off Shoe, Washpipe Extension w/ Dress Off Mill inside, Top Sub, Double Pin Sub, Junk Basket, Junk Basket, 13-3/8" Scraper, Bit Sub, XO, Float Sub w/ Float, Bumper Sub, Jar, Pump Out Sub, XO, (9) 6-1/4" Drill Collars, XO. OAL = 319.07'. DECOMP TIH with BHA #4 on 4" Drill Pipe from the Derrick. DECOMP Obtain Parameters: Up Weight-88,000#, Down Weight=88,000#, Rotating Weight=86,000#, 50 RPM, 1,500 ft-Ibs Torque, Tagged at 2,140' Top of Csg Stub, Dressed off to 2,141', with 5,000 WOB, 2,500 ft-Ibs Torque, 6 bpm with 200 psi . Work the bottom of the BHA (Washover Shoe) to a final depth of 2,145'. The BHA has a total swallow of 4' (the Casing Patch has 3' of swallow) putting the top of the 9-5/8" Stump at 2,141'. Re-confirmed depth of the Stump by washing back down over the Stump without rotation to a Shoe depth of 2,145'. DECOMP Circulate 20 bbl Hi-Vis Sweep at 13 bpm w/1,000 psi Heavy Scale and Metal Cutting in Crude Coming over Shakers. DECOMP Stand Back 6.25" Drill Collars. UD Dress Off BHA. DECOMP Clear and Clean Rig Floor. TIEB1 R!U to Run 9 5!8" Csg, Change Elevators, R(U Torque Turn equipment. Printed: 10/3/2007 2:22:46 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: I Rig Name: E-27A E-27A WORKOVER DOYON DRILLING INC. DOYON 16 Start; 9/14/2007 Rig Release: 9/24/2007 Rig Number: Task Code I NPT ~ Phase Date From - To Hours ~- 9/20/2007 ~~ 03:00 - 09:30 6.50 ~ CASE i P ~' ' TIEB1 i 09:30 - 11:00 1.50 CEMT P ~ TIEB1 11:00 - 12:00 I 1.001 CEMT I P I TIE61 12:00 - 12:30 ~ 0.50 CEMT P I TIEB1 12:30 - 13:15 0.75 CEMT P I I TIE61 I I i 13:15 - 14:00 0.75 CEMT P i i I TIEB1 14:00 - 15:00 1.00 CEMT P TIEB1 15:00-16:001 1.OOIWHSURIP i ITIEBI 16:00 - 17:00 1.00 WHSUR P !TIEB1 Page 5 of 8 Spud Date: End: Description of Operations M/U and Run 9 5/8", 47#, L-80, TC-II Connection Casing, Using Jet Lube Seal Guard Thread Compound and Torque Turning All Connections, Ran 9 5/8"Baker Casing Patch, HES Baffle Plate with Plug on Seat, 1-Casing Pup, 1 jt of 9 5/8" BTC casing, 1 Pup JT 9 5/8", HES Cementer, XO jt to TC-II, and 52 jts of 9 5/8", 47#, L-80, TC-II Casing Using 1 Free Floating Centrilizer Per jt Casing. Avg Make up Torque for BTC was 9,500 ft-Ibs to Make up Mark, Avg Make up Torque for TC-II was 17,500 ft-Ibs. Filling the Pipe every 5 Joints. Had to change out (2) Joints due to a damaged box that galled the pin end on another Joint (Joint #s 48 and 49). In with 52 Joints of 9-5/8", 47#, L-80, TC-II Casing. UW = 120K , DW =124K. MU 9-5/8" TC-II x BTC Crossover. RD Short Bails and RU Long Bails. MU Cement Head with Halliburton rep. RU Schlumberger Cementers. Tag 9-5/8" Stump 35' in on Joint #52 = 2,141' with 3' swallow on the Baker Patch. Set 25K down to verify on the Stump. Pull test the Casing to 250K - OK. Slack off to 220K to maintain 100K overpull. RU Test Equipment. Pressure test the Casing to 1,700 and 2,000 psi for 5 charted mins each - OK. Bleed pressure off. Increase pressure to shear open ES Cementer per HaNiburton rep. See the Cementer shear at 2,900 psi. Pump 50 bbls of 110 degree 9.8 ppg brine down the Casing prior to cementing at a rate of 6 bpm / 300 psi. PJSM with WSL, Toolpusher, Rig Crew, Schlumberger Cementers, MI Engineer, Halliburton rep and CH2M Hill Vac Truck Drivers. Pressure test to 4,000 psi with Cementers. Break circulation with Schlumberger down the 9-5/8" Casing with 15.8 ppg Class "G" Cement with GasBlok Additive at a rate of 5 bpm / 700 psi with 300 psi at the Floor. Pump a total of 150 bbls of Cement. Shut down the Pumps and drop the E Cementer Closing Plug with the Halliburton rep. Tattle-tell on the Cement Head shows positive indication of Plug dropping. Break circulation with Rig Pump down the 9-5/8" Casing with 9.8 ppg brine to dispace the Cement into the 9-5/8" x 13-3/8" Annulus. Displacing at a rate of 5 bpm / 200 psi. Cement returns to surface after 124 bbls of displacement pumped. Close the Choke on the return line and hold 800 psi backpressure for 10 bbls to attempt to squeeze some Cement into the leak in the 13-3/8" Casing. Open the choke and maintain a rate of 2 bpm f 820 psi. Bump the Pflug and increase pressure to 2,100 psi per Halliburton rep. it took 153 bbls of 9.8 ppg brine to fully displace the Cement and bump the Plug. Total of 29 bbls of cement returns to surface. CIP @ 14:00 hrs. RD the Cement Head and XO with Halliburton rep. Confirm no flow up the 9-5/8" indicating the ES Cementer closed properly. RD Schlumberger Cementers. Raise the ROPE and Tubing Spool from the Casing Spool. Set 9-5/8" McEvoy Slips and energize them with 100K with the Cameron rep. RILDS. RU Wachs Cutter with Cameron rep. Cut the 9-5/8" Casing and lay down the excess Casing. Cut Jt length = 25.79'. Printed: 10!3/2007 2:22:46 PM • • BP EXPLORATION Page 6 of 8 Operations Surnrnary Report Legal Well Name: E-27A Common Well Name: E-27A Spud Date: Event Name: WORKOVER Start: 9/14/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 9/24/2007 Rig Name: DOYON 16 Rig Number: Date ,From - To Hours I Task '~ Code' NPT Phase I Description of Operations 9/20/2007 i 17:00 - 19:00 2.00 BOPSU P i TIEB1 I ND the BOPE Stack from the Tubing Spool and set back. 9/21 /2007 19:00 - 20:30 1.50 BOPSU P ' TIEB1 20:30 - 21:30 1.00 BOPSU P TIEB1 ; 21:30 - 23:00 1.50 CLEAN P CLEAN 23:00 - 00:00 1.00 CLEAN P ~ I CLEAN 00:00 - 00:30 0.50 CLEAN P CLEAN 00:30 - 06;00 5.50 CLEAN P I CLEAN 06:00 - 10;00 ~ 4.00 CLEAN P I CLEAN 10:00 - 10:30 0.50 CLEAN P i CLEAN 10:30 - 11:30 i.00 CLEAN P CLEAN i 11:30 - 13:30 2.00 CLEAN P CLEAN 13:30 - 14:30 1.00 CLEAN P i CLEAN 14:30 - 15:30 1.00 CLEAN P CLEAN 15:30 - 16:30 1.00 CLEAN P CLEAN i 16:30 - 17:00 0.50 CLEAN P CLEAN 17:00 - 18:30 1.50 CLEAN P , CLEAN 18:30 - 20 30 2 00 CLEAN P CLEAN : . , i ~ 20:30 - 21:00 0.50 CLEAN P CLEAN 21:00 - 22:00 ~ 1.00 CLEAN P i I CLEAN Install New Tubing Spool and Pack Off N/U and Test Pack Off To 3,800 psi for 30 minutes. '; N/U BOPE, Turn Buckles, Flow Riser. R/U and Test BOPs at Tubing Spool Connection to 250 psi Low Test and 3,500 High Test, R/D Test Equipment, Install Wear Ring. i M/U Drill Out Assembly, BHA Consist of 8.5" Bit, 2-Junk Baskets, Bit Sub, Bumper Jar, Oil Jar, Circ Sub, XO, 9-6 1/4" Drif{ Collars, XO. BHA = 316.95'. WOC RIH to 1,806' ,Obtain SPRs #1 pump 20 spm=40 psi, 40 spm=70 psi. #2 Pump 20 spm=40 psi, 40 spm=90 psi. At 01:00 UCA 137 psi. Circulate Well Bore @ 3 bpm, 110 psi With Pipe Movement while WOC. Perform Light Maintenance and work orders. At 104:30 UCA 764 psi. At 06:00 SLB Called and Confirmed 1,000 i psi UCA. Establish parameters: UW = 80K, DW = 85K. Break rotation at 60 RPM and establish free rotational torque of 2,000 ft-Ibs and RW = 80K. Break circulation at a rate of 6 bpm / 200 psi. Tag cement at 2,087'. Slowly drill out the cement and Closing Plug @ 2,093' with 10-15K WOB. Getting cement and small pieces of rubber across the Shakers. Continue drilling on cement to a .depth of 2,124' (full stand in the hole). Mix and pump a 10 bbl hi-vis sweep at a rate of 7 bpm / 350 psi to clean out the wellbore. RU Test Equipment. Test the 9-5/8" Casing to 3,500 psi for 30 charted mins - OK. RD Test Equipment. i Continue drilling out cement down through the Baffle Plate. Control drill at 70 RPMs with 1-2K WOB and 2,000 ft-Ibs of torque. Circulating at a rate 5.5 bpm / 230 psi. At 12:30 hrs, tag the Baffle Plate @ 2,139'. Drill out 1' and fall through. Pump a 10 bbl hi-vis sweep to clean out the wellbore at a rate of 7 bpm 1300 psi. RIH and tag top of junk /sand 49' in on stand #26 = 2,742'. Tag again to confirm depth. I TOH with BHA #6 standing back DP in the Derrick. On surface with BHA. Break out and lay down BHA components. Inspect junk baskets and recovered small amounts of cement and rubber plus a small piece of an aluminum ring. MU BHA #7 as follows: 7-7/8" Reverse j Circulating Junk Basket, Junk Basket, Junk Basket, 9-5/8" Casing Scraper, Bit Sub, Bumper Sub, Jar, Pump Out Sub, XO, (9) 6-1/4" Drill Collars, XO. OAL = 329.87'. TIH with BHA #7 on 4" Drill Pipe from the Derrick. ~' Tag up on Sand at 2,742' Work Reverse Circ Junk Basket to 2,763' At 4 bpm, 1,200 psi, 30 rpm, Torque=1,500 ft-Ibs, 1,000 to 7,000# i Pump 20 bbl Hi-V is Sweep @ 6 bpm with 2,200 psi, Displaced i Wellbore with 8.5 ppg Seawater, Drop ball and rod to open Circ ISub at 1,250 psi. POOH Stand Back Drill Collars, empty Reverse Circ Junk Basket, Printed: 10/3/2007 2:22:46 PM • BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: E-27A Common Well Name: E-27A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 Date I From - To Hours I Task 'Code j _ i _, 9/21/2007 i 21:00 - 22:00 1.00 ~ CLEAN ~ P 22:00 - 22:30 22:30 - 23:00 23:00 - 00:00 9/22/2007 00:00 - 00:30 00:30 - 01:00 01:00 - 01:30 01:30 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 06:30 06:30 - 07:30 I i j 07:30 - 10:30 10:30 - 11:30 11:30 - 12:30 12:30 - 13:00 i 13:00 - 13:30 ~ 13:30 - 23:00 j 23:00 - 00:00 9!23!2007 j 00:00 - 01:30 01:30 - 02:00 02:00 - 05:30 0.50 CLEAN P 0.50 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 1.00 CLEAN P 3.00 CLEAN P 1.00 CLEAN P 1.00 BUNCO P 0.50 ~ BUNCO P 0.50 BUNCO P 9.501 BUNCO 1.00 BUNCO 1.50 BUNCO 0.50 BUNCO P 3.50 BUNCO P Spud Date: Start : 9/14/2007 End: Rig Release: 9/24/2007 Rig Number: NPT j Phase Description of Operations CLEAN Recovered 5 gals of Cement, Rubber Pieces, Aluminum Debris, Bottom of Wiper Plug and 1-9 5/8" Centrilizer. Empty 2 other Junk Baskets approx 1 gal of Cement. CLEAN M/U Reverse Circulating Basket Assembly CLEAN RIH to 2,763'. CLEAN Work Reverse Circ Junk Basket, f/2,763' to 2,787' ,with 5 bpm, 1,120 psi, 35 rpm, 1,000 ft-Ibs Torque CLEAN Circulate Hi-Vis Sweep @ 7 bpm with 2170 psi, Washing Top of Sand Plug CLEAN Drop Ball and Rod pump open Circ Sub. 8/D Top Drive. CLEAN POOH w/Reverse Circ Junk Basket f/2,787' to 326'. CLEAN VD 6 1/4" Drill Collars and RCJB Assembly,Recovered Metal Shaving, Sand, Aluminum Approx 2 gals. CLEAN Clear and Clean Rig Floor. CLEAN PU HES RBP Running Tool and RIH. CLEAN Establish retrieving parameters: UW = 77K , DW= 82K. Tag and latch 9-518" RBP @ 2,797'. Attempt to Reverse Circulate to clean Sand from Top of RBP, Pumped Down The drill pipe at 7 bpm w/1,000 psi. CBU with a hi-vis sweep to get all the sand out of the wellbore. CLEAN Unseat the 9-5/8" RBP at 88K. CBU to ensure no trapped gas beneath the RBP at a rate of 7 bpm / 1,090 psi. Shut the Pump and monitor well - OK. CLEAN POOH with 9-5f8" RBP LDDP 1 x 1 in the Pipe Shed. CLEAN On surface with the RBP. LD 9-5/8" RBP with Halliburton rep. Close the Blind Rams and RU Test Equipment. Pressure test the 9-5/8" Casing to 3,500 psi for 30 charted mins - OK. RD Test Equipment. RUNCMP RU to run 4-1/2" Completion. RU Torque Turn and Compensator. Verify all jewelry with WSL and Baker Completions rep. RUNCMP PJSM with WSL, Toolpusher, Crew, Doyon Casing rep and Baker Completions rep. RUNCMP RIH with 9-5/8" x 4-1/2" Unique Machine Overshot Assembly, (1) Jt of 4-U2", 12.6#, 13Cr, Vam Top Tubing, "X" Nipple Assembly with RHC-M, Baker S-3 Packer Assembly, "X" Nipple ~ Assembly, (1) Jt of 4-1/2", 12.6#, 13Cr, Vam Top Tubing, GLM #1 with DGLV. All connections below the Packer were Bakerlok'd with Baker rep. RUNCMP RIH with 4-1/2", 12.6#, 13Cr, Vam Top Tubing, Torque-Turning all connections to optimum torque of 4,440 ~ ft-Ibs. Utilizing Jet Lube Seal Guard on all connections. Using stabbing guide and starting each connection by hand and aided by Compensator. RUNCMP Continued to RIH and Space out Tubing, Tagged Tubing Stub at 8,617', Sheared Overshot Pins at 8,622', NO GO On Overshot at 8,626', Confirmed Depths. VD jts # 200, #199, P/U 3.70' pup jt, jt#199 and hanger. PUW = 137K ,SOW = 125K. ~ ~ RUNCMP M/U Tubing Hanger and Landing jt. RUNCMP Land Tubing Hanger, Attempt to reverse Circulate, Unable to ~ Circ, Insure all Surface Equipment is Clear, BOLDS, Pull Hanger To Rig Floor. RUNCMP Close Annular Preventer, Reverse Circulate in 135 bbls 140 Printed: 10/3/2D07 2:22:46 PM • BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: E-27A Common W ell Name: E-27A Spud Date: Event Nam e: WORKO VER Start : 9/14/2007 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 9/24/2007 Rig Name: DOYON 16 Rig Number: Date I From - To ' Hours l Task Code NPT I!, Phase Description of Operations 9/2312007 02:00 - 05:30 1 3.50 I BUNCO P I ` RUNCMP - _- - deg Sea Water at 3 bpm and 130 psi followed by 465 bbls of ~ 140 deg Inhibited Sea Water. 05:30 - 06:30 1.00 BUNCO P RUNCMP R/D Circulating Lines, VD Landing Jt, Replace Hanger Seal i assembly, M/U Landing jt. ', 06:30 - 07:00 ~ 0.50 BUNCO P RUNCMP Land Tubing Hanger, RILDS. 07:00 - 07:30 0.50 BUNCO P RUNCMP Drop Ball and Rod with Baker Completions rep. RU Test Equipment. 07:30 - 09:00 1.50 BUNCO P RUNCMP Pump down the Tubing to set the Packer at 2,500 psi. Test the ' j Tubing to 3,500 psi for 30 charted mins - OK. Bleed the Tubing to 1,600 psi. Pump down the 4-t/2" x 9-5/8" Annulus and pressure test to 3,500 psi for 30 charted mins - OK. Bleed the Tubing and observe the DCR Shear Valve shear at 1,100 psi on the Tubing (2,400 psi differential). Pump down the Tubing at a rate of 2 bpm / 120 psi and down the 4-1/2" x 9-5/8" Annulus at a rate of 2 bpm / 180 psi to confirm the shearing of the DCR Shear Valve. 09:00 - 10:30 1.50 WHSUR P RUNCMP Set TWC with Cameron rep. RU Test Equipment. Test from above and below to 1,000 psi for 10 charted mins - OK. RD I Test Equipment. 10:30 - 12:00 i 1.50 BOPSU P ~ RUNCMP ND 13-5/8" 5M BOPE. 12:00 - 13:30 ~ 1.50 ~ WHSUR P RUNCMP NU new Adapter Flange and new Tree. 13:30 - 15:00 ~ 1.50 ~ W HSUR P ~ RUNCMP Pressure test Hanger Void and Adapter to 5,000 psi for 30 I mins with Cameron rep - OK. Fill the Tree with diesel and pressure test to 5,000 psi - OK. 15:00 - 16:00 1.00 W HSUR P RUNCMP RU Lubricator with Well Support Techs and pressure test to i 500 psi. Pull TWC. RD Lubricator. 16:00 - 18:00 2.00 BUNCO P RUNCMP PJSM with Little Red. Freeze protect the we11 to -2,200' by pumping 150 bbls of diesel at a rate of 2 bpm / 400 psi with Little Red down the 4-1/2" x 9-5/8" Annulus. ' 18:00 - 22:00 4.00 BUNCO P ' RUNCMP R/U Lines and U-Tube for 1 hr, R!D Lines, Open Master Valve ~ and Wellbore still out of Balance. R/U Lines and allow to U-Tube for 45 minutes. Called out DSM .PJSM R/U Lubricator ' and Set BPV. 22:00 - 22:30 0.50 BUNCO P RUNCMP R/D DSM ,Tested BPV to 1,000 psi, B/D and R/D Lines and Little Red. 22:30 - 00:00 1.50 BUNCO P RUNCMP R/D Double Annulus Valve, Clean out Cuttings Tank. Rig I Released at 00:00 hrs on 9/24/2007. Printed: 10/3/2007 222:46 PM TREE= 4-1/16" CM/ WFLLHEAD= McEVOY ACTUATOR = AXELSON KB. REV = 67.5' BF. ELEV = 31.08' KOP = 4200' Max Angle = 92 @ 10195' Datum MD = 9478' Datum ND = 8800' SS DRLG DRAFT 9-5/8" CSG, 47#, L-80, TC-II, ID = 8.681" 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2141' I Minimum ID = 2.38" @ 8736' 2-7/8" G FISHING NECK ', 4-1/2" TBG, 12.6#, 13Cr80, .0152 bpf, ID = 3.953" $61 E-27A SURF 2089' 14-1/2" HES X N~, ID = 3.813" I GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DA T" 4 3411 3409 3 MMG DOME RK 16 10/OF 3 5829 5696 30 MMG SO RK 20 10/OF. 2 7451 7096 28 MMG DMY RK 0 09/21 1 8403 7939 29 MMG DMY RK 0 09/22 8483' -~4-1/2" HES X NIP, ID = 3.813" 8514' ~ 9-518" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 8549' 4-1/2" HES X NIP, ID = 3.813" 86~ UNIQUE MA CHINE OVERSHOT 8645' 4-1/2" PBR SEAL ASSY TOP OF 7" LNR I~ 8726' TOP OF 2-7/8" LNR $736' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" $787' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8976' TOP OF WHIPSTOCK 9400' PERFORATION SUMMARY REF LOG: SPERRY SUN MWD ON 07/21/03 A NGLE AT TOP PERF: 82° @ 9852' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9852 - 9877 O 03/04/05 2" 6 9914 - 9989 O 03/03/05 2" 6 10000 - 10050 O 03/03/05 2" 4 10050 - 10379 O 07/25/99 2" 4 10393 - 10418 O 07/25/99 2" 4 10490 - 10652 O 07/25/99 2" 4 10700 - 10937 O 07/25/99 2" 4 10945 - 10950 O 07/25/99 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 9775' 8709' ~~ 4-1 /2" OTIS X NIP, ID = 3.813" 8736' 2-7/8" G FISHING NECK, ID = 2.38" 8752' 4-1/2" OTIS XN NIP, ID = 3.80" $7$7' 4-1 /2" TBG TAIL, ID = 3.958" 8791' ELMD TT LOGGED 11/21(87 MILLOUT WINDOW 9404' - 9409' 9410' RADIO TAG ~~ I~ 11027' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" I~ 11090' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/09/87 ORIGINAL COMPLETION 10/06/07 KSB/TLH GLV GO 07101!99 DDW SIDETRACK (E-27A) 03/06/02 RN/TP CORRECTIONS 02/18/05 TTW/PJC FISHING NECK CORRECTION 03!05/05 KCF/TLH ADD PERFS & CORRECTIONS 09123107 D16 RWO PRUDHOE BAY UNR WELL: E-27A PERMIT No: 199-0590 API No: 50-029-21760-01 SEC 6, T11 N, R14E BP Exploration (Alaska) 09!27!07 ti7~i~~~~p`r~ Alaska Data 8, Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99603-2838 ATTN: Beth ~~t~~l~"911~ 4411 V t~ G~ 2tlU~ Well Jah # Laa Description N0.4437 Company: State of Alaska Alaska Oil 8< Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date 13L Color CD • 15-29A 11686783 SCMT O 09!05/07 1 05-25B 11630496 SCMT _ < 08/30/07 1 02-33A 11813082 SCMT 08/31/07 1 15-28A 11686782 SCMT 09/04!07 1 N-27 11824345 SCMT - <. 09/12/07 1 05-22A 11813086 SCMT 09118!07 1 S-400A 11855508 USIT - 09/18/07 1 E-27A 11676963 USIT (CEMENT) 09118107 1 E-27A 11676963 USIT (CORROSIONS 09118107 1 MPG-07 11594520 USIT S - ' 08/29/07 1 MPS-37 N/A SCMT - 09!08/O7 1 PLEASE AGKNOWLEOGE KEGEIP f t3Y SIGNING AND RETURNING ONE DOPY EAGN TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ 1!""-' ~~ w ~i ~ 1 Anchorage, Alaska 99508 ti Date Delivered: -., e-- -, r.,, - ~r ~,, ,., • Alaska Data & Consulting Serv es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ATTN: Beth r~ ~. _~_... Received b ' ~~ ~ -.,. · . ~"IT ~ "IT Œ (ill ~ !Æ ~!Æ ~ æ!Æ / SARAH PAUN, GOVERNOR I AJ.A.SIi& OIL AND GAS / CONSERVATION COMMISSION / 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-27A Sundry Number: 307 -275 SCANNED AUG 2 32007 , qq - ÓS-cr Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ay of August, 2007 Encl. 20 MC 25.280 't£ 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension ~ Q".... C «:'" 0/1 o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended ~ O-?", -~ > 9! ·c o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other ~Q ,. r.~ 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 199-059 ,- ... 3. Address: D Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21760-01-00/ ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU E-27 A ./ Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): , ADL 028304 - 67.5'r Prudhoe Bay Field / Prudhoe Bay Pool 12..> ..... I .... ... ./...>{{.. ·/f.i./i .. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11 090 / 9025 . 11027 9023 None None Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 20" 110' 110' Surface 2677' 13-3/8" 2677' 2676' 4930 2670 Intermediate 8977' 9-5/8" 8977' 8441' 6870 4760 Production Liner 678' 7" 8726' - 9404' 8220' - 8811' 7240 5410 Liner 2354' 2-7/8" 8736' - 11090' 8229' - 9025 13450 13890 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9852' - 10950' 8994' - 9020' 5-1/2",17# x 4-1/2",12.6# L-80 8787' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP' packer I Packers and SSSV MD (ft): 8665' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal D BOP Sketch D Exploratory ~ Development D Service D Detailed Operations Program 15. Estimated Date for 1,7 16. Well Status after proposed work: Commencinç¡ Operations: Augustxr. 2007 ~Oil o Gas o Plugged D Abandoned 17. Verbal Approval: Date: DWAG OGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed Name ~vid Reem Title Engineering Team Leader gC¡¿O(JÁ~_ Date 812-zjo'~ Prepared By Name/Number Signature Phone 564-5743 Terrie Hubble, 564-4628 Commission Use On Iv I Sundry Number:..... *"1J. F " ~ 717 Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test D Mechanical Integrity Test D Location Clearance Other: 3S"OOV'?'\ ßO V> ~~~ - Subsequent Form Required: ~r!J Ut APPROVED BY <ð- 23 -D¡- Approved Bv: -, A COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 V1 ( Submit In Duplicate f~ 6,7,,3'0// t)(7-..J [f / z..ø¡ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVAL OR\G\NÄ R8DMS BFl AUG 2 3 2D07 ~ß ~.P1~-P? ~ '.' ~"" <t I' ~..... ~ )') ." q)' .,,?~ C -1&<)"' ~~ ¿ ~. ~-? ~~ I . . E-27A Rig Workover Scope of Work: Pull 5-W x 4-%" completion, cut and pull 9-5/8" casing, run and cement to surface new 9-5/8" casing, run 4-W 13Cr-80 completion. 3 \ ~ç ~~\ ~ <6<;<\ t..\ \....Jd-0 MASP: 2245 psi + ~ ~C)"~~ Well Type: Producer Estimated Start Date: August 30, 2007 Pre-ri S 1 E 2 F 3 W 4 0 5 0 6 <'0 ~'\ E \J\ W &~~ -()~ <a I;);> re work: Drift thru 5-%" x 4-%" tubing for tubing cut. Drift 2-7/8" liner to 9000' MD. Run caliper log from -8736' to surface. Set 2-7/8" composite plug in the 2-7/8" liner at -8950' MD. CMIT T x IA to 3500 psi. Punch and string shot tubing prior to chem cut. Chem cut 4-%" l-80 tubing at 8635' MD, in the middle of the first full 'oint above the TIW HBBP acker. Reference tubin tall dated 11/09/87. Circulate well with kill wei ht fluid and diesel thru the cut. . Do NOT MIT ...oA, known SC leak. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time. PPPOT-T & IC. Set a BPV in the tubin han er. Remove the well house & flow line. level the ad as needed for the ri . Pro Dosed 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 5-W x 4-%" tubing string to the cut. 3. Run US IT log to determine top of cement in the 9-5/8" casing. 4. Cut and pull 9-5/8" above TOC. 5. Run and fully cement new 9-5/8" c'asing to surface. 6. Run 4-%" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at -8700' 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 = ACTUA TOR = KB. ElEV = BF ElEV KOP= Max Angle = Datum MD = Datum1VD = 6-3/8" crw McEVOY 67.5' 31.08' 4200' 92 @ 10195' 9478' 8800' SS E-27 A I SAFETY NOTES: 70° @ 9628' & 900@ 10104' ., 2021' -15-1/2" OTIS HRM LA NDING NIP, ID = 4.562" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" lOP OF 4-1/2" TBG I 13-3/8" CSG, 72#, L-80. 10= 12347" I Minimum ID = 2.38" @ 8736' 2-7/8" G FISHING NECK I TOP OF 7" LNR H 8726' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.953" H 8787' 2513' -15-1/2" X4-1/2" XO I GAS LIFT MANDRELS ST MD 1VD DEV TY PE VLV LA TCH PORT DATE 4 2998 2929 4 OT DOME RA 16 10/11/00 3 6177 5927 31 OT DOME RA 16 10/11/00 2 8369 7842 29 OT OMY RA 0 07/25/99 1 8516 7970 30 OT SO RA 20 10/11/00 8585' -14-1/2" BAKER L SLIDING SLV, ID = 3.813" I 8736' -14-1/2" PBR SEAL ASSY I 8665' -19-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.75" 8709' -14-1/2" OTIS X NIP, 10 = 3813" I 8736' 8752' 8787' 8791' 9-5/8" CSG, 47#, L-80, ID = 8.681" I I TOP OF WHIPSTOCK I ÆRFORA liON SUMMARY REF LOG. SÆRRY SUN rvlWD ON 07/21/03 ANGLE AT TOP PERF 82° @ 9852' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 9852 - 9877 0 03/04/05 2" 6 9914 - 9989 0 03/03/05 2" 6 10000 - 10050 0 03/03/05 2" 4 10050 - 10379 0 07/25/99 2" 4 10393 - 10418 0 07/25/99 2" 4 10490 - 10652 0 07/25/99 2" 4 10700 - 10937 0 07/25/99 2" 4 10945 - 10950 0 07/25/99 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9775' DATE 11/09/87 07/01/99 03/06/02 02/18/05 03/05/05 REV BY COMMENTS ORIGINAL COMPLETION DDW SIDETRACK (&27 A) RNfTP CORRECTIONS 1lW/PJC FISHING NECK CORRECTION KCFfTLH ADD PERFS & CORRECTIONS MILLOUT WINDOW 9404' 9409' 9410' -1 RADIO TAG I 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" H 11090' I DATE REV BY COMMENTS PRUDHOE BA Y UNIT WElL: E-27 A PERMIT No: 199-0590 API No: 50-029-21760-01 SEC6, T11N, R14E BP Exploration (Alaska) A Proposed Com¡tetion l'REE= WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = 6-3/8" CrN McEVOY AXELSON 675' 31.08' 4200' 92 @ 10195' 9478' 8800' SS SURFAC -i TOP OF CEMENT -2000' -14-1/2" HES X NIP, ID = 3.813" 19-5/8" CSG, 47#, L-80 13-3/8" CSG, 72#, L-80, ID = 12.347" 1 GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 4 3 2 1 Minimum 10 = 2.38" @ 8736' 2-7/8" G FISHING NECK 14-1/2"TBG, 12.6#, 13Cr80, .0152bpf, ID=3.953t- -14-1/2" HES X NIP, ID = 3.813" I -8700 -P-5/8" X 4-1/2" BAKER S-3 PKR, ID- -14-1/2" HES X NIP, ID = 3.813" I -I UNIQUE MACHINE OVERSHOT -14-1/2" PBRSEAL ASSY 1 -19-5/8" X 4-1/2" TrN HBBP PKR, ID - 4.75" -14-1/2" OTIS X NIP, ID = 3.813" 1 -12-7/8" G FISHING NECK, ID = 2.38" -14-1/2" OTIS XN NIP, ID = 3.80" 1 -14-1/2" TBG TAIL, ID = 3.958" 1 H ELMD TT LOGGED 11/21/87 1 8645' 8665' 8709' 8736' 8752' 8787' 8791' I TOP OF 7" LNR H 8726' TOP OF 2- 7/8" LNR 1 8736' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" 1-1 9-5/8" CSG, 47#. L-80, ID = 8.681" I I TOP OF WHIPSTOCK 1 ÆRFORA TION SUMMARY REF LOG: SÆRRY SUN MWD ON 07/21/03 ANGLE AT TOP ÆRF: 82° @ 9852' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 9852 - 9877 0 03/04/05 2" 6 9914 - 9989 0 03/03/05 2" 6 10000 - 10050 0 03/03/05 2" 4 10050 - 10379 0 07/25/99 2" 4 10393 - 10418 0 07/25/99 2" 4 10490 - 10652 0 07/25/99 2" 4 10700 - 10937 0 07/25/99 2" 4 10945 - 10950 0 07/25/99 8787' MILLOUT WINDOW 9404' - 9409' 9410' -1 RADIO TAG 1 2-7/8"LNR,6.16#,L-80,.00579bpf,ID=2.441" H 11090' 1 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9775' PRUDHOE BA Y UNIT WELL: E-27A ÆRMIT No: 199-0590 API No: 50-029-21760-01 SEC6, T11N, R14E DATE 11/09/87 07/01/99 03/06/02 02/18/05 03/05/05 REV BY COMMENTS ORIGINAL COMPLETION DDW SIDETRACK (E-27A) RN/TP CORRECTIONS TTW/PJC FISHING NECK CORRECTION KCF/TLH ADD ÆRFS & CORRECTIONS DATE REV BY COMMENTS BP Exploration (Alaska) . . Page 1 of 1 Maunder, Thomas E (DOA) From: Chan, Paul (PRA) [PauI.Chan@bp.com] Sent: Wednesday, August 22,20076:26 PM To: Maunder, Thomas E (DOA); Reem, David C Subject: RE: PBU E-27 A Tom The estimated tinish date for the Pl-17 R WO was accelerated from Aug 30 to Aug 27 due to no problems encountered decompleting the well or running the scab liner. The rest is my fault for not sending you the Sundry App sooner to take into account the fact that the P 1-17 wen could be finished sooner than estimated. I can give you a ca1l tomorrow if you would like to discuss this further. Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) ---~----~---~_._----~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 22, 2007 3:58 PM To: Chan, Paul (PRA); Reem, David C Subject: PBU E-27A Paul and Dave, Covering all bases. I left voice messages about the sundry submitted for this well. Please respond with information regarding the need for a "rush approval". Thanks in advance. Tom Maunder, PE AOGCC 8/23/2007 E-27 A (pTD # 1990590) Failed MIT -OA wi N2 - SC Leak . . . Subject: E-27A (pTD #1990590) Failed MIT-OA w/N2 - SC Leak From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sat, 16 Joo 2007 09:46:34 -0800 To: "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "GPB, Area Mgr Central (GC1I3/FS3)" <GPBAreaMgrCentral@BP.com>, "GPB, GCl OTL" <GPBGC10TL@BP.com>, "GPB, GCl Wellpad Lead" <GPBGCl WellpadLead@BP.com>, "GPB, Prod Controllers" <GPBProdControllers@BP.com>, tom_maooder@admin.state.ak.us, James Regg <jimJegg@admin.state.ak.us>, "Randall, Jaclyn S" <Jaclyn.Randal12@BP.com>, "Engel, Harry R" <Harry.Engel@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP .com> CC: ''NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>, "Holt, Ryan P (ASRC)" <Ryan.Holt@BP.com>, "Roschinger, Torin T." <Torin.Roschinger@BP.com> All, Well E-27A is a gas lifted producer that has been identified with crude in the cellar. A recent MIT-OA w/N2 failed with bubbling noted in the cellar when a 400 psi OA pressure was reached during the diagnostic on 06/15/07. The well status has been changed form "Operable to "Not Operable." The well must be shut in may not be returned to production until the surface casing leak is mitigated. Please call if you have any questions or concerns. Thank you, Paul Austin for Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 5CANNEtJ: JUN 1 8 2007 From: Holt, Ryan P (ASRC) Sent: Saturday, June 16, 20079:15 AM To: N5U, ADW Well Integrity Engineer Subject: E-27 Failed MIT-OA wI N2 Paul, E-27 failed an MIT-OA w/N2, bubbling in the SC x Conductor annulus was noted at 400 psi. Recommend swapping the well status to non operable. DHD will monitor the WHP for the next few days to ensure the SC leak remains inactive. Thanks, CRyan 1foft BP Alaska Wells Group Well Site Leader 907.659.5098 Office 943.5028 Cell 10fl 6/18/20079:06 AM ) STATE OF ALASKA) REC:::;!f·· ,,~ ALASKA OIL AND GAS CONSERVATION COMMISSION MAY. VEÐ REPORT OF SUNDRY WELL OPERATIONS 062005 1. Operations Performed: Alooka Oi¡ 8t Gas Cor's. Commiss' Abandon 0 Repair WellO PluÇJ PerforationsD Stimulate 0 Acntrnu~e Alter CasingD Pull TubingD Perforate New Pool 0 WaiverD Time ExtensionL Change Approved ProgramD Operation Shutdown 0 Perforate [[] Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development Œ] ExploratoryD 5. Permit to Drill Number: 199-0590 6. API Number 50-029-21760-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 67.50 8. Property Designation: ADL-028304 11. Present Well Condition Summary: Stratigraphic 0 serviceD 9. Well Name and Number: E-27 A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 11090 feet true vertical 9025.3 feet Effective Depth measured 11027 feet true vertical 9023.4 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 36 116 36.0 116.0 1490 470 Liner 678 7" 26# L-80 8726 - 9404 8219.9 - 8811.0 7240 5410 Liner 2354 2-7/8" 6.16# L-80 8736 - 11090 8228.7 - 9025.3 13450 13890 Production 8941 9-5/8" 47# L-80 35 - 8976 35.0 - 8440.3 6870 4760 Surface 2641 13-3/8" 72# L-80 36 - 2677 36.0 - 2676.4 4930 2670 Measured depth: 9852 - 9877,9914 - 9939,9939 - 9964,9964 - 9989, 10000 -10025,10025 -10050,10050 -10379 10393 - 10418, 10490 - 10652, 10700 - 10937, 10945 - 10950 True vertical depth: 8993.69 - 8997.23, 9001.6 - 9003.83, 9003.83 - 9005.56, 9005.56 - 9007.18, 9008.04 - 9010.48, 9010.48 - 9012.78 9012.78 - 9012.16,9012.61 - 9013.72,9016.17 - 9017.9,9019.46 - 9019.85,9020.06 - 9020.21 TubinÇJ ( size, ÇJrade, and measured depth): 5-1/2" 17# L-80 4-1/2" 12.6# L-80 @ 33 @ 2513 2513 8787 ·';ï,.\Nl'\iEJ) M/.'Y 1. 1 2005 Packers & SSSV (type & measured depth): 4-1/2" TIW HBBP Packer @ 8665 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 4.8 15 726 4.8 48 686 13 Prior to well operation: Subsequent to operation: Oil-Bbl 497 2126 Tubing Pressure 186 196 Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] Service 0 14. Attachments: Signature Garry Catron Garry Catron E~ Ct~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 5/3/05 Form 10-404 Revised 4/2004 (1 /......\ r i\ , t_ RBDMS BFL MAY ] 0 Z005 ) ) E-27 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/02/05 Perforate 10025'-10050' 6 SPF 03/03/05 Perforate 99391-9964' 6 SPF, 9964'-9989' 6 SPF, 10000'-10025' 6 SPF 03/04/05 Perforate 9852'-9877' 6 SPF, 9914'-9939' 6 SPF FLUIDS PUMPED BBLS 287 60 / 40 Methonal/W ater 287 TOTAL Page 1 · ¡::;' ,.'., ~ I 2513' 2513' 2677' ~ L TREE = "'WELLHEÄD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max An~l~ ~" Datum MD = ..,.,.,..,.,.".....,..",,,.., ...... Datum TVD = 6-3/8" CIW McEVOY AXELSON 67.5' 31.08' 4200' 9~,~ 10195' 9478' 8800' SS ) 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" l-t I TOP OF 4-1/2" TBG l-i 13-3/8" CSG, 72#, L-80, ID = 12.347" 1--1 Minimum ID = 2.38" @ 8736' 2-7/8" G FISHING NECK I TOP OF 7" LNR l-i 8726' 1 TOP OF 2-7/8" LNR l-i 8736' 1 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.953" l-i 8787' E-27A I I L J SAr 1 NOTES: 70° @ 9628' & 90° @ 10104' 2021' 1-i5-1/2" OTIS HRM LANDING NIP, ID = 4.562" 1 2513' l-i 5-1/2" x 4-1/2" XO 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH 4 2998 2929 4 OT DOME RA 3 6177 5927 31 OT DOME RA 2 8369 7842 29 OT DMY RA 1 8516 7970 30 OT SO RA PORT DATE 16 10/11/00 16 10/11/00 o 07/25/99 20 10/11/00 8585' 1-i4-1/2" BAKER L SLIDING SLV, ID = 3.813" 1 8645' 1-i4-1/2" PBR SEAL ASSY 1 :8: z--1 8665' 1-19-5/8" x 4-1/2" TIW HBBP PKR, ID = 4.75" I I I 8709' 1-i4-1/2" OTIS X NIP, ID = 3.813" 1 11 11 I f , 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 8976' ~ I TOP OF WHIPSTOCK l-i 9400' PERFORA TION SUMMA RY REF LOG: SPERRY SUN MWD ON 07/21/03 ANGLE AT TOP PERF: 82° @ 9852' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 9852 - 9877 0 03/04/05 2" 6 9914 - 9989 0 03/03/05 2" 6 10000 - 10050 0 03/03/05 2" 4 10050 - 10379 0 07/25/99 2" 4 10393 - 10418 0 07/25/99 2" 4 10490 - 10652 0 07/25/99 2" 4 10700 - 10937 0 07/25/99 2" 4 10945 - 10950 0 07/25/99 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 9775' DATE 11/09/87 07/01/99 03/06/02 02/18/05 03/05/05 REV BY COMMENTS ORIGINAL COM PLETION DDW SIDETRACK (E-27A) RN/TP CORRECTIONS TTW/PJC FISHING NECK CORRECTION KCF/TLH ADD PERFS & CORRECTIONS DATE COMMENTS REV BY 8736' 8752' 8787' 8791' l-i 2-7/8" G FISHING NECK, ID = 2.38" 1 l-i 4-1 /2" OTIS XN NIP, ID = 3.80" 1 1-i4-1/2" TBG TAIL, ID = 3.958" 1 l-i ELMD TT LOGGED 11/21/87 1 ~ MILLOUT WINDOW 9404' - 9409' 9410' l-i RADIO TAG 1 2-7/8"LNR,6.16#.L-80..00579bpf,ID=2.441" l-i 11090' 1 PRUDHOE BAY UNrT WELL: E-27 A PERMIT No: 199-0590 API No: 50-029-21760-01 SEC 6, T11 N, R14E BP Exploration (Alaska) 11/26/03 Schlumberger NO. 3048 Alaska Data & Consulting Services Company: State of Alaska 3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ( Well Job # Log Description Date Blueline Prints CD D.S.15-01A \c\<;:3'~;:J~ 10703946 SCMT 10/31/03 2 NK-62;\ (4C:~ '-f) l..\ ~ 10572999 MCNL 05/30/03 1 1 J)::J ~j( 0 E-27A '-1~) -OF-:jq 10558568 MCNL 08/09/03 1 1 ~~-5Le:s G-03A I~f-:¡ -07-C) 10563449 MCNL 06/04/03 1 1 I~~J j../ F-16A }L\ lo - I {() {ì 10558547 MCNL 05/08/03 1 1 ~:~1 "'.J H-27A ,~O,~--()<c)C1 10700004 MCNL 09/30/03 1 1 ~I~ . ~ E-05A -1L.f "-f... Or--sr; 10672314 RST-SIGMA 09/16/03 1 1 ~f 'q n E-04A ''-\ Ö'.... \ ~ \ 10662949 RST-SIGMA 09/15/03 1 1 (~,':<' =¡- ( PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotechnical Data Center LR2-1 3940 Arctic Blvd, Suite 300 900 E, Benson Blvd, ~:):¡::::('~ -.. Anchorage, AK 99503-5711 Anchorage, Alaska 99508 1\< ATTN: Beth D ,'" ~.. C::' Date Delivered: . EC :¿::~ Received by:' ,.\~~... ,~---\--')~ ,'t~~t''\f'-.. AiaSKii VI. ~. '. ¡.\n::.~.~~, . S(Ç?\~H\~NEC' \JA~~ 2 @ 2004- ~~\'f\.~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/18/03 No. 2963 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-17A I c~ -~ .t ~ ~ MEM PROD PROFILE 08/13/07 E-27A '1 ~ (~ - (~.~"~ MEM PROD PROFILE 08109103 D.S. 43-08A ~q~-~ GLS 09/04103 E-~S [~ ~--I.~ LOL o~os~o3 ~O.S. 3-09 ~ ~q ~~ PSP PROD PROFILE 08105103 o.s. ~-~ [~ '~,~ ,.~c~,o...o~,~ 0~s~0= '~'Ec ,~.~-~, sa"" 0~,0~ ~-z~ t ~ ~ ~ ~ ~ RST-C G~VEL PACK 09107103 D.S. ~5~8A ~ ~~ PSP LDL 08130103 MPS-06 ~ ~ ~ ~ TEMPE~TURE LOG 08/30/03 J-3510-25 -~ ~ - ! ~ c~ PROD PROFILE/DEFT/GHOST 09/14/03 ~-20B 23076 OH EDIT MWD SLIMPULSE & ARC DATA 10114/02 J.20B 23076 MD VISION RESISTIVI~ ~0114102 J.20B 23076 ~DVISION RESISTIVI~ 10114102 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 Date Delivered: RECEIVED ., . ~':"'::~--~ 2005 Aiaska u~ & G~.o uu.,o. Commia~ion An~or~e Schlumberger GeoQuest 3940 Arctic-Blvd, Suite 300 Anchorage, AK 99503-5711 A'i-I'N: Beth Received ~\~'~..JN~ ~ 199-059-0 PRUDHOE BAY UNIT E-27A 50- 029-21760-01 Roll#l: Start: Stop MD 11090 TVD09025 . Roll #2: Start Stop Completion Date.&""7/25/99 Completed Status: 1-OIL BP EXPLORATION (ALASKA) INC Current: T Name D 9515 t~ L NGP-MD L NGP-TVD R SRVY LSTNG R SRVY RPT Interval 1-3 SPERRY GR [~J 9410-11090 ~,I,.PflqAL 8748-8947 ~HI 9300-11090. ~PERRY 9300-11090. Sent Received T/C/D OH 3/14/00 3/14/00 OH 2/5 3/14/00 3/14/00 D OH 2/5 3/14/00 3/14/00 OH 8/12/99 8/12/99 D OH 8/12/99 8/12/99 D Wednesday, June 20,2001 Page 1 of 1 To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Cms Conmrvation Cow_re. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' March 14, 2000 E-27A, AK-MW-90139 E-27A: 2" x 5" ~MD Ganm~a Ray Logs' 50-029-21760-0i 2" x 5" TVD Gamma Ray Logs' 50-029-21760-01 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNLNG 3_N!) R~'_~!l_LR..NTLN~.G A COPY OF LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · -, , .rEiVED ,.,,,AR 4 2000 Date: '-..~, ~,,.,, ...... ~ns. CQmmission i:,i-,cn0rag0 BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way. Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska March I4, 2000 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 \ ' ~,, ~ ~ -'~ MWD Formation Evaluation Logs E-27A, AK-MW-90139 1 LDWG formatted Disc with verification listing. API#: 50-029-21760-01 PLEASE ACKNOWLEDGE _RECEIPT_ BY SIGNLN~.G A_NI) RE. TU!~_NLNG A COPY OF _THE. ~TR~ &NS.MAI~AL LETTER TO THE. ATYE. NTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 ECEIVED ?JAR ! 4 2000 Date: ...... ."~ Gas Cons. Ccmmms;or Anchorage BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil i--I Gas [] Suspended [] Abandoned [-1 Service .:' 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 99-059 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21760-01 4. Location of well at surface :r, .............. 9. Unit or Lease Name 1819' SNL, 882' WEL, SEC. 06, T11N, R14E, UM ,i ..., ,PATF~., ~ . · ~ .-Prudhoe Bay Unit At top of productive interval ~ ~ '.~1!~i~ il 0. Well Number i -~"~1;;~ E-27A 2169'SNL, 3427'WEL, SEC. 06, T11N, R14E, UM i V'E~ i At total depth ;i~, _~l~. ~__ ~ fl 1. Field and Pool 844' SNL, 3916' WEL, SEC. 06, T11 N, R14E, UM ............. ~ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 67.50' AMSLI ADL 028304 12. Date Spudded7/21/99 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Water depth' if Offsh°re I 16' NO' °f COmpletiOns7/23/99 7/25/99 N/A MSL, One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11090 9025 FTI 11 027 9023 FTI [] Yes [] No (Nipple) 2021' MD 1900' (Approx.) 22. Type Electric or Other Logs Run GR, ROP 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP DO,q-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" Insulated Conductor Surface 110' 8 cu yds Concrete 13-3/8" 72# L-80 / S-95 Surface 2677' 17-1/2" 1863 cu ft PF 'E', 2325 cuft Permafrost 9-5/8" 47# L-80 Surface 8977' 12-1/4" 1822 cuft Class 'G' 7" 26# L-80 8726' 9404' 8-1/2" 360 cuft Class 'G' 2-7/8" 6.16# L-80 8736' 11090' 3-3/4" 112 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 5-1/2", L-80 2513' MD TVD MD TVD 4-1/2", 12.6#, L-80 2513'-8787' 8665' 10050' - 10379' 9013' - 9012' 10393' - 10418' 9013' - 9014' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10490' - 10652' 9016' - 9018' 10700' - 10937' 9019' - 9020' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10945' - 10950' 9020' - 9020' 2000' Freeze Protect with 35 Bbls of MeOH 27. PRODUCTION TEST ORIGIki i Date First Production I Method of Operation (Flowing, gas lift, etc.) ' ' August 1, 1999I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD i Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ?b ~ . ,¢""-;~~' ,,¢,~ ,-';,~' ~.~ . Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. 23 / 22N 9450' 8848' 21N 9510' 8887' Sadlerochit / Zone 1 [] 9610' 8938' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the f egoing is true and correct to the best of my knowledge , ned Terrie Hubble ' Title Technical Assistant III Date ' E-27A 99-059 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GEU£RAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: E-27A Accept: 07/16/99 Field: Prudhoe Bay Spud: 07/21/99 APl: 50-029-21760-01 Release: 07/25/99 Permit: 99-059 CTD Unit: Nordic #1 07/17/99 1 Move in rig and spot over well. Raise windwalls and derrick. PU injector head and stab CT. NU BOP. Test BOP, Chuck Scheve/AOGCC waived witnessing test. Bullhead kill well w/315 bbl seawater. Install pack-off. Install CT Connector, pull test to 30,000#. Fill CT w/seawater and pressure test connector to 3500 psi. PU Cementing BHA, TIH. Accepted Rig 7-16-99 19:30 hrs. 07/18/99 2 Finish RIH with cementing BHA circulating SW with 2/3 returns. Tag whipstock, corr +3'. PUH 15-20K over while in liner and into tubing with normal pulling wt loss. DS pump 20 bbls 15.8 ppg Class G with Perfect Seal. Displace with seawater. Lay in cement from just above whipstock pulling 15-20K over. PUH into tubing and let cement set 1 hour. PT @ 1500 psi for 30 min and lost 360 psi thru leaking wing valve. RIH jetting biozan thru cement to just above whipstock. Attempt to PUH and were stuck both ways at 9379'. WO acid. DS pump 11 bbls 15% HCl and displace with seawater. No progress. Circ out spent acid. Work pipe. Drop dis- connect ball, displace w/seawater. Ball on seat and sheared at 4880 psi. Pull to 73,000#, pipe started moving. POOH w/20-24,000# overpull. Began to lose overpull at +/- 6500'. POOH, PU Fishing BHA. TIH, checking weight up and down each 1000'. Pick up weight began drastic increase between 6,000' and 7,000'. Suspect corkscrewed production tubing. Shoot fluid level in IA. Fluid level at 6549'. Work pipe and check weights. 07/19/99 3 Finish checking string wts while RIH. Gained 29K up weight between 6000-8000'. Assume corkscrewed tubing. POOH (59K at 8000') with fishing assy. RU Halliburton wireline. Set catcher sub and pull screened orifice at 6177'. RU HB&R. Fluid pack IA with 320 bbls seawater and freeze protect with 100 bbls diesel. RIH with WL and pull GLV at 2998'. Set DGLV's in both stations. Pull catcher sub. Pressure IA to 1000 psi to check DGLV's. RDMO WL. PU Fishing BHA, TIH. Weight checks indicated 25,000# less pick-up weight at 8000'. Latch fish, POOH, LD Fishing BHA and fish. PU Window Milling BHA, TIH. Tag up at XN Nipple, correct depth (+15'), mill through XN Nipple, continue TIH. Mill cement above whipstock. Pressure increased, possibly chunks from motor stator. POOH to check motor. 07/20/99 4 Finish POOH to check BHA for pressure increase. Found 2 of 3 nozzles plugged from bottom with steel junk and scars on full face. Change mill. RIH with milling BHA #2 (3.80" dimple mill and flex it). Mill up junk and then mill window from 9404-9409' ELMD. POOH. LD dimple mill and flex it. Junk damage on face of mill. MU 3.625" formation mill and string reamer. RIH with milling BHA #3. Mill on window, making very little progress. POOH to check mill. Mill completely worn and slick on face, junk damage on OD. Change out mill, TIH. Begin milling, slow progress. E-27A, Coil Tubing Drilling' Page 2 07/21/99 5 9421' Continue milling. Acts like formation and good motor work, but no progress. POOH. Nose on formation mill bald, metal chunk in water course. RIH with venturi junk basket. Work JB in window. POOH. LD JB. Mule shoe worn, casing metal in barrel, good formation core sample. MU and RIH with Hughes parabolic diamond mill and new string mill. Milled f/9386-9403' (CT depth). Worked mill through window at 0.5 bpm. POH. PU 1.5° motor assembly. FIIH. Ran Tie- in log. (+13' correction). RIH. Tagged bottom at 8417'. Drilled to 9421' 07/22/99 6 10058' Drilled build f/9421-9732. POOH for lighter bend motor to drill horizontal section. RIH. Drilled tangent f/9732-9855'. Short Tripped to window. Drilled to 9976'. Trouble getting surveys. Short Tripped to window. Drilled to 10056'. Tripped for more aggressive build assembly. 07/23/99 7 11060' RIH w/1.3° motor assembly. Drilled f/10058-10296'. Short trip to window. Drilled to 104957'. Made 100' MAD pass to verify GR. Drilled to 10658'. Short trip to window. Drilled to 10838'. Short trip to window. Drilled to 11060'. 07~24/99 8 11090' Short trip to window. GR log for correlation, correct depth (+5'), TIH and drill to TD of 11090'. POOH for liner. Ran 77 its of 2-7/8" 6.4# L80 STL liner. OAL: 2354.30'. Ran liner to 11090'. Released liner running tool. Displaced well to 2% KCL. Cemented liner wi 20 bbls 15.8 ppg slurry. Bumped plug. Floats held. CIP: 2100 hrs 7-23-99. POH while circulating 2% KCI. No cement in returns. LD liner running tool. PU nozzle & 78 its 1-1/4" CSH. RIH. Tagged Latch collar. Spotted 150 LSRV FIo-Pro liner. POH w/nozzle. 07/25/99 9 11090' POH w/nozzle assembly. MU & RIH w/Perf Gun assembly. Tagged Latch collar at 11027'. Spotted bottom shot at 10950'. Perforated 10050-10379', 10393-10417', 10490-10652', 10700- 10937', 10945-10950' at 4SPF 60° phasing w 2" PJ2006 perf guns. Misfired 10379-10393 & 10937-10945' (22' total). POH. Stood back 1-1/4" CSH. LD peff guns. Freeze protected well to 2000'. POH. Blew down coil w/Nitrogen. RD injector. Prep for reel change out. ND BOPE. NO well. NU tree cap. RR 0500 hfs 7/25/99. Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOA E Pad, Slot E-27 E-27A Job No. AKMW90139, Surveyed: 23 July, 1999 SURVEY REPORT 16 August, 1999 ORIGINAL Your Ref: API500292176001 Surface Coordinates: 5975237.99 N, 664104.89 E (70° 20' 19.2233" N, Kelly Bushing: 67.50ft above Mean Sea Level 148° 40' 06.0094" W) 0 R I L L! N I~ S E R VI C El E; Survey Ref: svy8672 A tlALL][SURTON COMPANY Sperry-Sun Drilling Services Survey Report for E-27A Your Ref: A PI500292176001 Job No. AKMW90139, Surveyed: 23 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9300.00 30.900 278.412 8654.93 8722.43 9400.00 32.280 277.610 8740.11 8807.61 9426.71 37.120 279.900 8762.06 8829.56 9441.58 39.730 280.960 8773.71 8841.21 9476.96 48.250 283.000 8799.15 8866.65 9491.41 51.060 283.190 8808.50 8876.00 9531.29 56.600 284.770 8832.03 8899.53 9565.06 60.470 296.080 8849.69 8917.19 9592.88 63.720 305.170 8862.73 8930.23 9627.81 68.200 312.020 8876.97 8944.47 9669.26 72.690 323.100 8890.88 8958.38 9702.68 76.200 326.970 8899.85 8967.35 9732.07 78.750 335.930 8906.23 8973.73 9771.64 79.980 337.160 8913.53 8981.03 9814.14 81.120 343.310 8920.52 8988.02 9874.69 82.000 346.830 8929.41 8996.91 9902.94 83.670 345.420 8932.93 9000.43 9948.29 86.000 340.410 8937.02 9004.52 9971.69 86.570 339.620 8938.53 9006.03 9993.92 85.600 334.520 8940.05 9007.55 10017.84 83.900 334.030 8942.24 9009.74 10067.19 85.960 332.240 8946.60 9014.10 10103.99 90.090 329.780 8947.87 9015.37 10132.37 90.700 335.050 8947.67 9015.17 10157.39 91.490 337.860 8947.20 9014.70 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (fi) (ft) 408.98 S 2342.87W 5974777.84 N 661771.53 E 401.68 S 2394.74W 5974784.00 N 661719.51 E 399.35 S 2409.76W 5974786.00 N 661704.44 E 397.68 S 2418.85W 5974787.48 N 661695.32 E 392.55 S 2442.85W 5974792.08 N 661671.21 E 390.05 S 2453.58W 5974794.34 N 661660.43 E 382.26 S 2484.80W 5974801.44 N 661629.05 E 372.18 S 2511.70W 5974810,93 N 661601.93 E 359.65 S 2532.81W 5974822.99 N 661580.56 E 339.75 S 2557.69W 5974842.35 N 661555.24 E 310.95 S 2583.96W 5974870.57 N 661528.35 E 284.57 S 2602.39W 5974896.54 N 661509.35 E 259.39 S 2616.08W 5974921.41 N 661495.11 E 223.72 S 2631.56W 5974956.74 N 661478.86 E 184.28 S 2645.72W 5974995.85 N 661463.83 E 126.42 S 2661.15W 5975053.36 N 661447.14 E 99.21 S 2667.87W 5975080.42 N 661439.83 E 56.06 S 2681.14W 5975123.27 N 661425.62 E 34.11 S 2689.12W 5975145.04 N 661417.16 E 13.69 S 2697.76W 5975165.26 N 661408.08 E 7.76 N 2708.09W 5975186.49 N 661397.27 E 51.61 N 2730.31W 5975229.84 N 661374.10 E 83.77 N 2748.13W 5975261.60 N 661355.58 E 108.92 N 2761.26W 5975286.45 N 661341.90 E 131.85 N 2771.26W 5975309.16 N 661331.41 E Alaska State Plane Zone 4 PBU_WOA E Pad Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 1.443 18.764 18.102 24.410 19.472 14.254 30.757 31.136 22.021 27.407 15.320 30.996 4.358 14.524 5.931 7.712 12.142 4.157 23.300 7.394 5.521 13.060 18.693 11.664 2105.22 2156.84 2171.85 2181.01 2205.44 2216.41 2248.52 2277.21 2301.14 2330.93 2364.74 2390.37 2411.10 2436.76 2462.32 2494.71 2509.44 2535.28 2549.60 2564.07 2580.48 2615.05 2641.86 2662.06 2678.59 TIE ON SURVEY WINDOW POINT Continue~.. 16 August, 1999.8:53 - 2- DrillQuest B.P. Exploration (True) Structure · Pad E Field : Prudhoe Bay Well · E-27A, 50-O29-21760-01 Location : North Slope, Alaska <- West (feet) 4000 9800 3600 3400 ,:5200 3000 2800 2600 2400 2200 2000 1800 1600 I I [ I I I I [ [ I I I I I I I [ I I I I I 1 I I 8500 ~ Tie-in Point 8600 ~Tie-in Point ' 900~ ... Projected to TD ~' 4~:~,' ~.. ~,.~~~ . ~, ,~ . ~; .....,. ,,,~. /i "'1 i~.:h~, i ,~' i i i i i [ i i i i i i ' i i i i i i i i i i i i I i i i i i i i i i ,~'~ 1 0 0 0 ~;Ii~'~;0 200 ~ 00 400 500 600 700 800 900 1000 11 O0 1200 1 ~00 1400 1500 1600 1700 '~;~:' "<" ' ......... '" Vertical Section (feet) -> .6~::1' ..% Azimuth 550.26 with reference 409.48 S, 2542.78 W from E-27 Brij Potnis Dote plotted : 30-Ju1-1999 Plot Reference i~ E-27A. Coordinotes are in feet reference £-27, True Vcrticol D,cpth~ arc reference RKB - MSL = 6'/.5 fi;. --- Raker Hughe. INT[Q --- ~ec,ed to TD ~ IGINA.L 1200 1000 800 60O A I 4oo Z o 200 Z:F O d) -4- 200 400 600 B.P. Exploration (True) Pad E E-27A E-27 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker ~{ughes INTEQ Your ref : E-27A Our ref : svy195 License : 50-029-21760-01 Date printed : 30-Ju1-1999 Date created : 30-Ju1-1999 Last revised : 30-Ju1-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 664940.580,5977074.330,999.00000,N Slot location is n70 20 19.214,w148 40 6.007 Slot Grid coordinates are N 5975237.000, E 664105.000 Slot local coordinates are 1818.63 S 875.87 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad E,E-27A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : E-27A Last revised : 30-Ju1-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing 9300.00 30.90 278.40 8654.93 9400.00 32.28 277.61 8740.11 9426.71 37.12 279.90 8762.06 9441.58 39.73 280.96 8773.71 9476.96 48.25 283.00 8799.15 409.48S 2342.78W 0.62 0.00 661771.95 5974776.10 402.19S 2394.66W 1.44 32.06 661719.94 5974782.25 399.86S 2409.67W 18.76 41.53 661704.87 5974784.25 398.19S 2418.76W 18.10 47.50 661695.75 5974785.72 h93.06S 2442.77W 24.41 63.86 661671.64 5974790.32 9491.41 51.06 283.19 8808.50 9531.29 56.60 284.77 8832.03 9565.06 60.47 296.08 8849.69 9592.88 63.72 305.17 8862.73 9627.81 68.20 312.~2 8876.97 390.56S 2453.49w 19.47 71.35 661660.86 5974792.58 382.77S 2484.72W 14.25 93.60 661629.48 5974799.68 372.69S 2511.62W 30.76 115.69 661602.37 5974809.16 360.16S 2532.72W 31.14 137.04 661580.99 5974821.22 340.26S 2557.61w 22.02 166.67 661555.67 5974840.57 9669.26 72.69 323.10 8890.88 9702.68 76.20 326.97 8899.85 9732.07 78.75 335.93 8906.23 9771.64 79.98 337.16 8913.53 9814.14 81.12 343.31 8920.52 311.46S 2583.87w 27.41 204.70 661528.79 5974868.79 285.08S 2602.31W 15.32 236.75 661509.78 5974894.75 259.90S 2615.99w 31.00 265.40 661495.54 5974919.62 224.23S 2631.47w 4.36 304.06 661479.28 5974954.94 184.79S 2645.64w 14.52 345.33 661464.25 5974994.05 9874.69 82.00 346.83 8929.41 9902.94 83.67 345.42 8932.93 9948.29 86.00 340.41 8937.02 9971.69 86.57 339.62 8938.53 9993.92 85.60 334.52 8940.05 126.93S 2661.06W 5.93 403.22 661447.56 5975051.56 99.72S 2667.78w 7.71 430.18 661440.24 5975078.61 56.57S 2681.05w 12.14 474.23 661426.03 5975121.46 34.62S 2689.03w 4.16 497.25 661417.57 5975143.22 14.20S 2697.67w 23.30 519.26 661408.48 5975163.45 10017.84 83.90 334.03 8942.24 10067.19 85.96 332.24 8946.60 10103.99 90.09 329.78 8947.87 10132.37 90.70 335.05 8947.67 10157.39 91.49 337.86 8947.20 7.25N 2708.01W 7.39 543.02 661397.68 5975184.67 51.10N 2730.22W 5.52 592.11 661374.51 5975228.02 83.26N 2748.04W 13.06 628.87 661355.98 5975259.77 108.41N 2761.18W 18.69 657.22 661342.30 5975284.62 131.34N 2771.17W 11.66 682.09 661331.80 5975307.32 10194.92 91.76 343.14 8946.13 10224.67 90.55 344.32 8945.53 10252.62 90.18 350.34 8945.35 10284.29 91.05 353.86 8945.01 10331.29 90.97 355.27 8944.18 166.69N 2783.69W 14.08 718.99 661318.51 5975342.39 195.24N 2792.02W 5.68 747.92 661309.55 5975370.75 222.49N 2798.15W 21.58 774.62 661302.83 5975397.~6 253.86N 2802.50W 11.45 804.02 661297.79 5975429.12 300.64N 2806.95W 3.00 846.84 661292.31 5975475.79 10362.22 88.82 359.04 8944.24 10401.92 87.71 5.64 8945.44 10421.54 86.57 10.26 8946.42 10454.09 87.80 6.87 8948.02 10483.09 89.74 7.92 8948.65 331.52N 2808.49W 14.03 874.42 661290.09 5975506.63 371.15N 2806.87W 16.85 908.02 661290.84 5975546.28 390.55N 2804.16W 24.22 923.53 661293.12 5975565.73 422.69N 2799.32W 11.07 949.03 661297.25 5975597.97 451.44N 2795.59W 7.61 972.15 661300.35 5975626.79 10550.09 90.53 359.31 8948.49 10607.49 88.33 355.27 8949.06 10634.59 88.33 355.44 8949.85 10671.27 87.80 346.61 8951.09 10701.24 88.77 344.95 8951.99 518.25N 2791.36W 12.90 1028.06 661303.10 5975693.67 575.56N 2794.08W 8.01 1079.17 661299.13 5975750.91 602.56N 2796.27W 0.63 1103.70 661296.34 5975777.85 638.74N 2801.98W 24.10 1137.95 661289.83 5975813.89 667.77N 2809.34W 6.41 1166.81 661281.84 5975842.76 10728.29 89.85 340.60 8952.31 10768.42 90.03 337.26 8952.35 10802.97 90.03 333.33 8952.34 10835.24 90.00 329.60 8952.33 10872.89 90.61 326.61 8952.13 693.60N 2817.35W 16.57 1193.21 661273.27 5975868.40 731.04N 2831.78W 8.34 1232.87 661258.02 5975905.51 762.43N 2846.21W 11.37 1267.28 661242.90 5975936.57 790.77N 2861.62W 11.56 1299.54 661226.87 5975964.56 822.73N 2881.52W 8.11 1337.16 661206.28 5975996.08 10910.57 90.00 322.57 8951.93 10924.02 88.86 322.22 8952.06 10963.87 87.98 317.82 8953.16 10995.12 87.27 313.08 8954.46 11017.07 87.45 310.97 8955.47 853.44N 2903.34W 10.84 1374.65 661183.78 5976026.29 864.09N 2911.55W 8.87 1387.97 661175.35 5976036.76 894.61N 2937.14W 11.26 1427.16 661149.09 5976066.71 916.85N 2959.04W 15.32 1457.34 661126.71 5976088.46 931.53N 2975.32W 9.64 1478.16 661110.11 5976102.78 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from E-27 and SSTVD from R/qB - MSL = 67.5 ft. Bottom hole distance is 3186.55 on azimuth 287.82 degrees from wellhead. Vertical section is from tie at S 409.48 W 2342.78 on azimuth 330.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad E,E-27A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : E-27A Last revised : 30-Ju1-1999 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C O O R D S C O O R D I N A T E S Deg/100ft Sect Easting Northing 11051.12 87.98 306.40 8956.82 11069.74 88.77 304.64 8957.35 11090.00 88.77 304.64 8957.79 952.79N 3001.87W 13.50 1509.79 661083.10 5976123.45 963.60N 3017.02W 10.36 1526.69 661067.72 5976133.92 975.12N 3033.69W 0.00 1544.96 661050.80 5976145.07 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from E-27 and SSTVD from RKB - MSL = 67.5 ft. Bottom hole distance is 3186.55 on azimuth 287.82 degrees from wellhead. Vertical section is from tie at S 409.48 W 2342.78 on azimuth 330.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad E,E-27A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 3 Your ref : E-27A Last revised : 30-Ju1-1999 Comments in wellpath MD SSTVD Rectangular Coords. Comment 9300.00 8654.93 409.48S 2342.78W Tie-in Point 11090.00 8957.79 975.12N 3033.69W Projected to TD , NO PROPOSAL TONY KNOWLE$, GOVERNOR ALAS OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Julv 15. 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit E-27A BP Exploration (Alaska) Inc. Permit No: 99-59 Sur Loc: 1819'SNL. 882"vVEL. Sec. 06. T11N, R14E. UM Btmhole Loc. 862'SNL. 4007%VEL. Sec. 06, T11N, R14E, UM Dear Mr. Stagg: Enclosed is thc approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to xvitness a test of BOPE installed prior to drilling new hole. Notice max' be given bx' contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ,~,-AND GAS CONSERVATION COM_,~,ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l-'l Drill I~Redrill lb. Typeofwell I--IExploratory [-I Stratigraphic Test I~ Development Oil [] Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 67.50' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028304 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAO 25.025) 1819' SNL, 882' WEL, SEC. 06, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2241' SNL, 3135' WEL, SEC. 06, T11N, R14E, UM E-27A At total depth 9. Approximate spud date Amount $200,000.00 862' SNL, 4007' WEL, SEC. 06, T11N, R14E, UM 07/21/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028299, 862'I No Close Approach 2560 11198' MD / 8955' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9400' MD Maximum Hole Angle 90° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 8730' 8156' 11198' 8955' 118 cuft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary .'.~' (~i! '~ Total depth: measured 9775 feet Plugs (measured) true vertical 9119 feet ~ ,~.. r~ Effective depth: measured 9710 feet Junk (measured) Fill at 9710' (02/90) A~85~¢~' ~Ji GaS 00~$, true vertical 9065 feet Anch0rag¢ Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 8 cu yds Concrete 110' 110' Surface 2641' 13-3/8" 1863 cu ft PF 'E', 2325 cu ft PF 2677' 2677' Intermediate 8941' 9-5/8" 1822 cu ft Class 'G' 8977' 8441' Production Liner 1049' 7" 360 cu ft Class 'G' 8726' - 9775' 8220' - 9119' Perforation depth' measured 9555'- 9560' 9570'- 9654', 9666'- 9676', E ;?,4AL , true vertical subsea 8870' - 8969' (three intervals) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ' Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that ~,~e~ foT~rue and correct to the best of my knowledge Signed Ted Stagg ~¢..~¢~ Title CT Drilling Engineer Date Commission Use Only Number I APl Number Approval Date_~ I See cover letter Permi,~_~.~I 50-029-21760-01 ~ "' J'~"" -~'~'I for other requirements Conditions of Approval: Samples Required []Yes _.~_No Mud Log Required .I--lYes ~[~rNo Hydrogen Sulfide Measures J~Yes'~N° Directional Survey Required )~_.Yes ~No Required Working Pressure for MOPE [] 2K; [] 3K; ~4K; [] 5K; I--I 10K; b~ 15K Other: ORIGINAL SIGNED BY by order of /...~ Approved By Rnh~.rt N C, hri.~tc.n.~r~n Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX E-27a Sidetrack Summary of Operations: E-27 production performance has fallen off due to gas coning. The sidetrack, E-27a, will target the lower Zone 1 sand, 13P, while maintaining standoff from the 12N shale. This sidetrack will be conducted in two phases. Phase 1: Set whipstock: Planned for July 15, 1999. · A Tubing Integrity Test will be performed. · A Kinley caliper will be run over the tubing and liner. · A permanent whipstock will be set on ELine at approximately 9,400' MD. Phase 2: Squeeze Perfs, Mill Window and Drill Directional Hole: Planned for July 21, 1999. Directional drilling coiled tubing equipment will be rigged up and utilized to squeeze perfs, mill the window and drill the directional hole as per attached plan to planned TD of 11,198' MD (8,955' TVDss). Mud Program: - Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.8 ppg) Disposal: - No annular injection on this well. - All drilling and completion fluids and all other Class II wastes will go to CC-2a for injection. - All Class I wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,730' MD and cemented with approx. 21 bbls. cement to bring cement 200 ft above the window. The well will then be perforated with coiled tubing conveyed guns. Well Control: BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,400' MD (8,740' TVD ss) -TD: 11,198' MD (8,955' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. TREE: CIW 6-3/8 WELLHEAD: McEVOY ACTUATOR: AXELSON 13-3/8", 72 #/ft, L-80, BTRS F¢ KOP: 4000' MAX ANGLE: 32° @ 6400' 4-1/2", 12.6#/ft, L-80, IPC TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT E- 27a Proposed Completion KB. ELEV = 67.50 BF. ELEV = 31.08 O~SSSV LANDING NIPPLE (OTIS "HRM")(4.562" ID) I 2021 5-1/2" X 4-1/2" CROSSOVER 2513 GAS LIFT MANDRELS (OTICJ "LBD" W/ :~A I ATCH~ N° MD(BKB) TVDss 4 2998 2929 3 6177 5927 2 8369 7842 1 8516 7970 SLIDING SLEEVE BAKER "L" J ( 3.813" MIN. ID) 8585 TOP OF LINER 9-5/8", 47#/ft, 18976 L-80, BTRS L PBR SEAL ASSY. 9-5/8" PACKER ( TIW "HBB")(4.75"ID) 4-1/2 ", 12.6#/ft,TAILPIPE 4-1/2 ....X" NIPPLE (OTIS) ( 3.813" ID) 4-1/2 ....XN" NIPPLE (OTIS) ( 3.725" ID) 4-1/2" TBG TAIL ( BOT ) (ELMD) 8645 8665 8709 8752 8787 8791 2 7/8" liner cemented to 200 ft above whipstock PERFORATION SUMMARY REF: LOG: BHCS 11-5-87 ISIZE SPF INTERVAL I)PEN/SQZ'D 3-3/8 4 9555-9560 SQZ/RESHOT 3-3/8 4 9570-9574 SQZ/RESHOT 3-3/8 4 9574-9590 OPEN/RESHOT 2-7/8 4 9590-9600 OPEN 1/20/88 3-3/8 4 9600-9615 OPEN/RESHOT 2-7/8 4 9615-9654 OPEN 1/20/88 2-7/8 4 9666-9676 OPEN 1/20/88 Abandonment cement downsqueezed past whipstock PBTD 9732 7", 26#/ft, L-80, IJ4S I 9775 Section 500 Path Distance (Feet) 1,000 1,500 2,000 2,500 3,000 I I I I I IE-27a Case 103 Angle @ K.O.= 32 deg MD:9400 ~' 8955SS Marker Depths ~Dri~l Wellbore TsGR I 8,397J TvD TZ2C TSAD I 8,938] 8,642Jrt TVD 8,498 Jrt TVD 8,938~ft TVD Kick Off I 8,740Jrt TVD 9,400Jrt MD JDeprtr @KO 2,443 ft I MD KO Pt 9,400I MD New Hole 1798I I Total MD 11,198I TVD TD 8,955J DLS deg/100 Tool Face Len~lth Curve 1 6 0 Curve 2 18 25 324 Curve 3 18 90 381 Curve 4 18 45 14 Curve 5 8 -90 1,049 1,798 Drawn: 6/9/99 7:26 Plan Name: Case 103 E-27 I I I - -2,500 -2,000 -1 ,~ 500 1050 ft at 8938ss, with 900 ft inside the polygon 4-- Land ~ 8938ss about 150 ft before polygon 0 E-27a Case 103 X distance from Sfc Loc - 1,000 [Well Name E-27 I CLOSURE IDistance 3,272 ft [ Az 286 de~l NEW HOLE E/W (X) N/S (Y) Kick Off -2,385 -455 TD -3,149 888 State Plane 660,956 5,976,125 Surface Loc 664,105 5,975,237 DLS deq! 100 Tool Face Length Curve 1 6 0 ~30 Curve 2 18 25 324 Curve 3 18 90 381 Curve 4 18 45 14 Curve 5 8 -90 1,049 1,798 Drawn: 6/9/99 7:26 Plan Name: Case 103 E-27a CT Drilling & Completion BOP 2 3/8" CT -~ I i i I 10,000 psi Pack-Off 12" 36" 7 1/16" Annular 7 1/16' 5000 psi I I "' ...... I 22.5" 1 SI' 38" Blind/Shear 7 1/16" Pipe/Slip --- 2 3/8" ,7 1,/,16: ~x S,O_O0. p. si, ~ Slips ~ -~ 2 7/8" 7 1/16" Pipe I -~ 2 3/8" SWAB OR MASTER VALVE I VENDOR AI_ASKAST 14- O£ DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 051 lC~5 CF~051 lC)c2C 100. 0¢ 100. 0£ HANDL INQ INST- ,. THE A~ACHED CHECK IS IN PAYMEm FOR ~MS DE~RIBED ABOVE. ~ 100. O~ 1 OO. O~ :: :', ANC'HORAGE;.~ALASKA'.::: 99519-6612 El'FIST 'NATIoN~'L: BANIfOF ASH~:AND .', :" ' ,' C ~£VEILAND QHIO ., .:: ' :.'i. ": ' :i;i:;'56.389 .': ,'i" 412 No., ':H :, 8 2,:3. PAY To The : ALA$14,A STATE::.DEpT;:~:'OF REVENUE ::::i::~OO :I'::;i::::PORCUP TNE!::;O~.' :!?:'. ANCHORAQE :NE: H~DRE~i;'~ &:::::::~:O0/100-~-*~'*:*~-~'*~"~'~"~*~'~-*~**~*~*:~'~'~'~* ':'us; DOLLAR ::I!I :~:' ~'~ : ~:' ":"'::'" ~:: ...... ~ :'~::,~:~ ~' DATE ,?:::~;~: ""'~ :''/' ;'"'" ~"::~'~'~ ~AMouNT . :. '.~:; ' :...L:' NOi:~ALID A~ER 120 DAYS " ·" /':.'::': "' ... , . :,...,.. ,'~51,88~,' ~:Ot,~EO~SqS': OOat, t, WELL PERMIT CHECKLIST FIELD & POOL COMPANY ~,2~ WELL NAMEfz~ ~-~"~-~/'?~ PROGRAM: exp lu, c ss N N N N N N N N N N N N N ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 13. II ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. APPR DATE 26. ,(~ ~;f~'~/'~ 27. 28. 29. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... /'Y~ N Surface casing protects all known USDWs ........... ~y N CMT vol adequate to circulate on conductor & surf csg ..... N CMT vol adequate to tie-in long string to surf csg ........ Y N CMT will cover all known productive horizons .......... ~'~ N Casing designs adequate for C, T, B & permafrost ....... ~Y.<~ N Adequate tankage or reserve pit ................. ~ N If a re-drill, has a 10-403 for abandonment been approved... N Adequate wellbore separation proposed ............. ~ N If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... ~.~ N BOPEs, do they meet regulation ................ ~ N BOPE press rating appropriate; test to ~ ~C,3Q-~ psig. Q~ N Choke manifold complies w/APl RP-53 (May 84) ........ (~ N Work will occur without operation shutdown ........... ~ N Is presence of H2S gas probable ................. N GEOLOGY Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones ............. yN Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory_y~nly] Y N 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste i~uitable receiving z.~ne;' ....... Y N (B) will not conta, p~fiate freshwater; or ca..gse"drilling waste...., Y N to surfac. -' / _ (C) will ~. c. al in.~eg'fi~ of the wel! used for~sposal; Y U (D) ~formation or impair recovery from a Y N I~ool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N dev .yredr.,I.l.l~ serv wellbore seg o¢:~.~¢~) UNIT# ann. disposal para req ON/OFF SHORE _f~o'[~ GEOLOG¥~ ENGINEERING: UlC/Annular COMMISSION: JDH ~ RNC--"t'~ co ~ ff~/~ , Comments/Instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun DYilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 10 13:13:28 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services 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 NITMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUATD LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW-90139 S. LATZ PARKER/HUPP RECEIVED MAR 14 2000 Alaska Oit & Gas Cons. ,,,,,,,,m~ton Anchorage E-27A 500292176001 BP Exploration (Alaska) , Inc. Sperry Sun 10-MAR-00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING MWD RUN 2 MWD RUN 3 AK-MW- 90139 AK-MW-90139 S. LATZ S. LATZ P~LRKER/HUPP PARKER/HUPP 6 lin 14E 1819 882 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9400.0 3.750 3.750 67.50 .00 29.30 REMARKS: $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/10 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 SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9400.0 11067.5 ROP 9416.0 11090.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 10 9400.0 9732.0 20 9703.5 10056.5 30 10030.0 11090.0 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 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9400 11090 10245 3381 ROP MWD FT/H 17.86 943.64 110.469 3349 GR MWD API 15.67 270.88 62.2644 3336 First Reading 9400 9416 9400 Last Reading 11090 11090 11067.5 First Reading For Entire File .......... 9400 Last Reading For Entire File ........... 11090 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/10 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 ....... 00/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9400.0 ROP 9416.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGD 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) : STOP DEPTH 9703.0 9732.0 21-JUL-99 Insite 0 Memory 9732.0 32.2 76.2 TOOL NUMBER TLG 001 3.750 9400.0 FLOPRO 8.50 65.0 9.4 21500 6.8 RESISTIVITY (OHMM) A~I'~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 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 kPI 4 1 68 8 3 .0 142.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9400 9732 9566 665 ROP MWD010 FT/H 17.86 943.64 87.6726 633 GR MWD010 API 15.67 270.88 38.3135 607 First Reading 9400 9416 9400 Last Reading 9732 9732 9703 First Reading For Entire File .......... 9400 Last Reading For Entire File ........... 9732 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/10 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 ....... 00/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE N-UMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9703.5 ROP 9732.5 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AlgD 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: STOP DEPTH 10029.5 10056.5 22-JI/L- 99 Insite 0 Memory 10056.0 80.0 86.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER TLG 001 TOOL STAlgDOFF (IN) : EWR FREQUENCY (HZ) : 3.750 9400.0 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 FLOPRO 8.55 65.0 9.2 21000 6.0 .000 .000 .000 .000 .0 142.0 .0 .0 Frame Spacing - 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 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 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9703.5 10056.5 9880 707 ROP MWD020 FT/H 25.04 351.99 95.3839 649 GR MWD020 API 33.73 180.56 74.3588 653 First Reading 9703.5 9732.5 9703.5 Last Reading 10056.5 10056.5 10029.5 First Reading For Entire File ..... , ..... 9703.5 Last Reading For Entire File ........... 10056.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/10 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 NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10030 . 0 11067 . 5 ROP 10057.0 11090.0 $ LOG HEADER DATA DATE LOGGED: 23 - JUL- 99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11090.0 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 Loggin9 Direction ................. Down Optical log depth units ' Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 85.7 91.8 TOOL NUMBER TLG 002 3.750 9400.0 FLOPRO 8.65 56.0 9.0 21000 5.8 .000 .000 .000 .000 .0 154.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10030 11090 10560 2121 ROP MWD030 FT/H 23.34 317.43 122.187 2067 GR MWD030 API 36.08 201.44 65.4632 2076 First Reading 10030 10057 10030 Last Reading 11090 11090 11067.5 First Reading For Entire File .......... 10030 Last Reading For Entire File ........... 11090 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
