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195-114
• STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS510N ' 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 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Convert to Producer p 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 195-114 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service m 6. API Number: 50-029-21429-03-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number. PBU 09-36C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: Total Depth: measured 9545 feet Plugs measured 9091/9490 feet SEP 2 8 2017 true vertical 9031 feet Junk measured 8933/9509/9536 feet Effective Depth: measured 9091 feet Packer measured 8857 feet / OGC true vertical 8723 feet Packer true vertical 8589.97 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8272 9-5/8"47#L-80 32-8304 32-8199 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9033-9078 feet feet 9106-9116 feet 9116-9126 feet 9296-9304 feet 9352-9368 feet 9376-9386 feet 9410-9430 feet 9500-9515 feet 9520-9535 feet True vertical depth: 8691-8716 feet feet 8731-8736 feet 8736-8741 feet 8833-8838 feet 8872-8883 feet 8889-8897 feet 8915-8931 feet 8991-9004 feet 9008-9022 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRDP-4A SSSV 2204 2204 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED DEC 1 4 N iz 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -11066 1180 1136 Subsequent to operation: 1616 6400 603 780 465 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development m Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Iv7 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: 317-347 Authorized Name: Stechauner,Bernhard Contact Name: Stechauner,Bernhard Authorized Title: FS2 Lead PE Contact Email: Bernhard.Stechauner@bp.com Authorized Signature: J" Date: / �@Z7/17 Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2017 V i O!/` ✓ f l T B D M S t �' OCT ~ ' 207 /'l/lb/�� lSubmit Original Only • • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 SEP 282017 AOGCC BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 27, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Conversion to Producer covered under Sundry # 317-347 for Well 09-36C, PTD # 195-114. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • m aO O O O O O O o M N- CO N CO O N CO N- O O '� N LU N N r- LO CO I-- V 00 0 0 0 0 p. 0 0 0 i Oa co ti O O tt co V N- O) CO r N N- N- M V CO 00 CO N- N CO d- CA U) O r O LC) CA O) O) r CO t LO LO 'Cr Nr CO O CO CO CO N CO 00 CO O CO CI III 1111111 H O LO L() Ln Ln N LO C)) CO O V' LO CO CO L1) CO O d' (0 CO CO CO CO CO CO In O O NO .4 in a)) Ln -4 co N N LO CO CO O) L N CO CO O) C)) CO C.) 0 C I I I I I I I I I I 2 Q4a CO M Ln Lf) N Co) O LM O - Ln M CO LO CO N- O) CO CO CO = 0) co co co I— O L1) O O CI_ Ln00 wOCoOCOU CY) 2 Y -I CO U J j M • N N N Z • �$ U N6) co ° N00NN _ p I Ch - - - N N CO CO N I 46 _ N-O N N f� N C CO NV N LU LU `- O d N 00 LO O CO J w a)O Q D .7) UWww U0 � wtYk � 2' ZZZ Z w w w W m m O D D H Z _Z Z D D j U U) (n Z J J J H • • Packers and SSV's Attachment PBU 09-36C SW Name Type MD TVD Depscription 09-36C SSSV 2203.84 2203.81 4-1/2" Camco TRDP-4A SSSV 09-36C PACKER 8081 8007.06 4-1/2" KB Straddle Packer 09-36C PACKER 8117 8038.43 4-1/2" KB Straddle Packer 09-36C PACKER 8137.91 8056.56 7" Baker H Packer 09-36C TBG PACKER 8856.95 8589.97 4-1/2" Baker SABL-3 Packer • s Cl)• s N CD0) O) 07 2 2' CC 1 co _c o d' fX2 CC Lt M. 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U I- U f U F- co" U F- : U H C a) a (II W 6) N �' a) N O Q' a N C' a1 N 6) CN ai N C' a1 N (n W J O J O Cr) J o 2 J C) 2 U J o t J o 2 J O 2 J 0 2 J 0 2 > J Op W H < N- N- N- N- N- I 1 N- N- ti rr ,- r <- r r r r r Hco O co 0 co CV o O o O N N N N N N N N 0 rn -8_5 Q • • k_ k_ .E .E / E \ k 5 k 5 C C O O (13 O O . D 0 U % o % cri ± 2 a 5 6 0 a o m = co n Lc) m r E o f ƒ % $ % k k k / k / = C = C 5 -o 5 5 - \ $ 5 - 5 _ $ § 5 5 sU 5U O 0 O % O m ) ) 3 ® / ® (0 (0 / ( $ _ / I / � CO � \ k o C co O \ o2 02 ' / (N 73 20 w ƒ 0 » ^ 2 $ § o_7 - o_ 7 ,- 9 \ / $ / k \ 7 / / 7 � \ CA \ . m 3 n c § .§ � § / § \ �� � �� � f C p E m c E 3 E as S 2 0 2 0 2 0 E E $ E o 6. f f \ f & w f g & 2 / o e / o / 0. CL c CL o ,- 0_ o ,- ° » ° 0 U 0 0 7 . / 0 \ / \ = / / = \ 70 g f .E O £ / .E % o ° ° 'o ƒ / � \ / ° _ _ � _ R � .E .Ek / Em .7\ mo \ 0 \ _JO On \ \ C) tC t \ / � WU � G o o (Doc R ® e& ® t � � I >,I � �� � 3 _ I o ± !- O & _ _ _ � o = — o CL = n - n -6 = — = m # Ge3o aa ° ° ° ° 9 ±- 9I ce / • 0$ f $ f Eo 0 0 » 0 / 2 / ct 2 \ / \ fX \ \ ƒ • \/ \/ 0 C3 : TREE= 6-3/8"CaV • S NOTES: —CHROME TBG&LNR"** V4131..tIEAD= FIX., 09-36C 9_36C *STRADDLE PATCH @ 8081'IS ISOLATING GIM#6. ACTUATOR= AXELSON NITTAL KB.ELE 55' BF.ELEV= NA KOP= 6775' 13-3/8"CSG,68#, H 65' 1 I li 31' H7"X 5-1/2"X 4-1/2"XO,D=3.958" Max Angle= 58°@ 9128' K-55,0=12.415" Datum MD= 9326' / 0 2200' --{4-1/2"CAMA ROR4A TRSSSV,0=3.812" Datum TVDss= 8800'SS GAS LIFT atANDRS ST MD TVD DEV TY FE VLV LSTCH POR DATE 20"CONDUCTOR 91.5#,H-40,D=19-124" H 113' 1 3454 3454 2 TETGFD ME RK 16 05/31/17 2 5456 5455 1 TE TGFD SO RK 20 05/31/17 13-3/8"CSG,72#,L80,D=12.347" H 2496' ___Ail 3 6573 6573 2 Th-TGFD DMI' FSC 0 04/11/93 Minimum ID = 2.313" @ 8883' illr 4 7060 7050 15 TETGFD Dan RK 0 11/13/97 4-1/2" X NIPPLE REDUCER 5 7596 7564 20 TE-TGPD Dan RK 0 09/14/94 6 8096 8020 29 TETGPD *SO — 12/16/95 i= =' *GLM#6=NO LATCH ON SO IN GLM#6(POGLM) H 8081'-8121' —4-1/2"STRADDLE PATCH ASSY, 7" 9-5/8"X BKR TIEBACK SLV.D= —I 7.500" 8126' I 0=2.375"(08/20/12) 9-5/8"X 7"BKR"H"FKR,D H=6.18T 8134' l Er 9-5/8"X 7"BKR LNR IiGR,D=6.375" H 8139' �� 9-5/8"aLLOUT WIDOW(09-36A) 8300'-8350' 9-5/8"CSG,47#,L80 BUTT,ND=8.681" H 8300' 7",29#,NT80S XO TO 13CR-80 NSCC —1 8698' 'c }c 8795' —f 4-1/2"PARKER SVVS NP,D=3.813" 8852' H4-1/2"ANCHOR SEAL ASSY M ( 8853' Hr X 4-1/2"BKR SABL-3 FKR,D=3.875" 8883' —4-1/2"PARKER SWS NP,D=3 813" 411 8873'ELM D LOGGED(10122/95) 8883' 114-1/2"X 2-7/8"MP REDUCER, RS}-t 2 SLPS&2 ELEMENTS MISSING FROM H ??? 0=2.313"(08/20/12) DWP(08/18/12) 8933' —I 3-3/4"BKR DEPLOY SLV,D=3.00" 7"MARKER JOINT —1 8971' 1 8939' —13-1/2"X 2-7(8"XO,D=2.387" $979' 14-1/2'PARKER SINN N8?D=3.80" 4-1/2"TBG-FC,12.6#,13CR NSCT, H 8992' CT&MILLED OUT(138-IND.0152 bpf,ID=3.958" ; ( ) 8992' H4-1/2"WLEG(B13-1114D CT) 7"LNR,29#,13CR-80 NSCC, — —9270 7 —� — 037i bpf,D=6.184" 0 8982' H ELMD TT LOGGEIJ 04/26/93 8—' 9091'ELM —12-7/8"WFD EXT RANGE CEP(06/05/17) PERFORATION SUMMARYCI REF LOG:BHCS ON 04/06/93 T PLLOUT WIDOW(09-36C) 9270'-9277' ANGLE AT TOP PERF:56°@ 9033' Note:Refer to FYoduction DB for historical perf data 9490' —SET BKR CEP(07/14/04) SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2" 6 9033-9078 0 06/05/17 4.••.. ` 9487'slm FLSH-BROKEN 1-11/16" 4 9106-9116 C 01/12/98 l.�4�4�I�II4•1• TEL FINGER(07/13/04) 2" 6 9106-9126 C 11/22/01 `�, 9536' —2-7/8"CEP ALLED 2-118" 4 9106-9126 C 09/27/97 I� 444 &FUSF® M'1 HOLE OLE 2" 6 9296-9304 C 03/18/04 2" 6 9352-9368 C 07/15/04 (11/21/00) 2" 6 9376-9386 C 07/15/04 /,ir 2" 6 9410-9430 C 07/14/04 2-7l8"FOR]ED RP JOINT9540' p 2-1/8" 4 9500-9515 C 11/05/95 � •4/ 2-1/8" 4 9520-9535 C 10/22/95 2-7/8"LNIR,6.5#,L-80, .0058 bpf,D=2.387' — 9545' DATE REV BY COHABITS DATE REV BY COMVENTS PRUDHOE BAY UNIT 05/25/86 POOL 6 IMTIAL COMPLETION 08/24/12 GJB/JaD PULL AVA,SET PATCH,FISH(08/18-20/1 WELL 09-36C 04/11/93 N2ES SIDETRACK(09-36A) 03/04/13 JHJM) SET XX PLUG(03/01/13) PERMIT No: 1951140 10/12/94 CTU CTD ST(09-36A)-FAILURE 06/08/17 BSE/JMD PULLED XX PLUG(05/30/17) AA No: 50-029-21429-03 08/27195 WEB CTD SDTRACK(09-36C) 06/08/17, JFK/JM) GLV C/O(05/31/17) SEC 2,TION,R15E 1874'FSL&37'FEL 11/06/05 KDCITLH GLV C/O(10/30/05) 06/08/17 MRD/JM)SET CIBPADFERFS(06/05/17) 07/28/11 'KAU PJC ELM)LOGGED NP 10/22/95 I 1 BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, September 8, 2017 3:21 PM To: AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OIL; AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington, Aras J Subject: OPERABLE: Producer 09-36 (PTD#1951140) Injector to Producer Conversion All; Well 09-36(PTD#1951140)has been converted from an injector to a producer and has an approved Sundry from the AOGCC. A MIT-IA&MIT-T passed on May 24th 2017 verifying two competent well barrier envelopes. At this time the well is classified as Operable. Be mindful of fluid packed annuli when bringing the well on line. Plan Forward: 1. Portable Test Separator&Ops: Flowback Well—When finished, freeze protect with diesel only. Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 S f�E® c p j 9 7.01.7, Cell 907-980-0552 Harmony 4530 Fro . GWO Well Integrity Engineer Sent: Satur.. my 22, 2017 4:02 PM To: AK, GWO Well -•rity Engineer; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops ;-d; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AKOpsProdEOCTL; AK, GWO SUPT Slickline; AK, GWO SUPT Special • :'-cts; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; - RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.•: ' Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT We stegrity; AKIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis 3; Munk, Corey; Obri• 'tch, Beau; Sternicki, Oliver R; Worthington, Aras J Subject: NOT OPERABLE: Injector 09-36 (PTD #1951140) Cessa • of Temporary Injector Flowback All, Injector 09-36 (PTD#1951140)was made under evaluation on 06/24/17 to temporarily flo •.ck to assess SAG River rich gas per approved sundry 317-187 for up to 14 days. Today,7/22/17,concludes the flowbac this injector. At this 1 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISON AUG 2 4 2017 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed A�(�/�) (�`�s�_ Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 OpeAQ l d�Cib►r C ❑ Suspend 0 Perforate H Other Stimulate 0 Alter Casing0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: FlowCTest 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Num66ber: 195-114 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21429-03-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number PBU 09-36C 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: Total Depth: measured 9545 feet Plugs measured 9091/9490 feet true vertical 9031 feet Junk measured 8933/9509/9536 feet Effective Depth: measured 9091 feet Packer measured 8857 feet true vertical 8723 feet Packer true vertical 8589.97 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8272 9-5/8"47#L-80 32-8304 32-8199 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9033-9078 feet feet 9106-9116 feet 9116-9126 feet 9296-9304 feet 9352-9368 feet 9376-9386 feet 9410-9430 feet 9500-9515 feet 9520-9535 feet True vertical depth: 8691-8716 feet feet 8731-8736 feet 8736-8741 feet 8833-8838 feet 8872-8883 feet 8889-8897 feet 8915-8931 feet 8991-9004 feet 9008-9022 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRDP-4A SSSV 2204 2204 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED DEC 0 5 2017, 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: 11 905 6709 1405 297 Subsequent to operation: 1544 5000 1184 1723 524 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service H Stratigraphic 0 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: 317-187 Authorized Name: Ohms,Danielle H Contact Name: Ohms,Danielle H Authorized Title: Pe Engineering/DDis "'/e Lead Alaska Contact Email: Danielle.Ohms©bp.com Authorized Signature: � Date: —Z 7_/ Contact Phone: +1 907 564 5759 Form 10-404 Revised 04/2017 r� l d/Hit ��"°' AUGL u 2017 Submit Original Only .fit Cb7/4/i1 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572RECEIVED AUG 242017 RE: BP Exploration (Alaska), Inc. ACC Report of Sundry Well Operations Summary August 23, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug, Adding of Perforations and then Flow Back Production Testing covered under Sundry Approval # 317-187 for Well 09-36C, PTD # 195-114. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • a) ca 0000000000 COcts N- CO N N — CO CD N CO I� O O ch N 0[) 0 N N O CO f� C.) e 0 0 0 0 0 0 0 0 0 O) O M I- CO CO j N- CO CO CO N N CO to Tr co O Cr) M (O N CO CO CO O) CO CI I 1 1 1 1 1 1 1 1 1 0 U) LO U) 1.7 N (f) O) M 0 LO M CO 0 Cr) O d' (D M Cr) Cr) CO CO CO LO N 00 00 ON) O) M M CO Co) CI Qco M M U) . CONMOMO ..cr � M M 'f) CO — N. 0) Cr) M M 0 CO CO CO 0 M_ W O 00 GIU700 � (n000000° U ' Y J _j O CO 0J U M CD *k N N r- Z M M *k • • � N U7 CO U NM M N N N N - i i In - - I� - CV N O N ' - LOt w 0 C 00 N N CO N00 U7 u7 CO W Ct Cr)0 C H W W ° W oau_ u_ wwcczzZ Z ct Et W W W W m m m O D D H Z_ Z Z D D D U (n (nZ =111 F- I • • Packers and SSV's Attachment PBU 09-36C SW Name Type MD TVD Depscription 09-36C SSSV 2203.84 2203.81 4-1/2" Camco TRDP-4A SSSV 09-36C PACKER 8081 8007.06 4-1/2" KB Straddle Packer 09-36C PACKER 8117 8038.43 4-1/2" KB Straddle Packer 09-36C PACKER 8137.91 8056.56 7" Baker H Packer 09-36C TBG PACKER 8856.95 8589.97 4-1/2" Baker SABL-3 Packer • • m CO N N- 0) I,- CO CO i[) CO et U et CO CD yU) 'CDet et et vvva et LIn d N 8) F- 7 U) V) O) inr M NcNi OC j O O O O O O O O N O O O C r C4 U • 2 G) as in M V NrMNCDCnNU) CA C) N M e- CO U) O) O) N Co O O N N O C) U) ce) r O H 0 O O O O O x 0 0) 0 c0 I ti - Q) d j m C, r CO O O M 0 0 0 0 0 0 0 0 0 0 O W o o co o O O O O _O O O O O LL U) U) U) CO CD 2 U) CO (O 2 2 2 Il Cn R 0 .2 CO CD I- N CD CD CO N U) CriM Co N r 0 • N- N M N O r N O 3U) 0 (NNNN � OrO C r r r . . . . . LL 0 NN- N ti ti N- N- NN- N- n N N CC 0 0 0 O 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N O N CO CO et U) CO N 00 0) CD N N N ILI N. N- N N- N. N ti N- N- N- N- N- N 0 0 0 0 0 0 0 0 0 0 0 0 0 C, I— 0 • u) c co.o II 5 c o o -0u) M6 E a) a co I` J a) (0 a) o � a) a * a . w U) -0 rn 0 c rn CO y Q-N c c -J 0 I-- Ill QO.. CB Q a) N (Ni CO fn F- Cn _• N _a [n � 'C O N O O �O 'C 0 O J Q- _� C CO a a C o M a H Cti d } rn CO * N N CO a) $ Q 2 V Z Q 0 0 N •.V) N Q E N O (n a N •� M _ � o co CN E � w2 (� v CO © t 0 rn �n .5 II L � � o YMZ U) M N D O a _I N O E "0 C ,- •C 0 VLLI C10 2 a) 77 0 O 2 0O 0Cp E a) = a0 F- v, -a- CD-• .- v as a) 2H J Q _ � m � co N N N (7 . •� c) W J a u) cnCN w a I- a) 1- ao Q eL.- w O Z U)U) QM Q o .- ._ ' Co � M � Q a aooH. CD 0 z O O E 4_ - o o Q Q ao H. '++ W IL N a Q c O 0 Q Q-� N o IJi 00 0 V wa d 0 Q is N W 0 N m O a ct O a) c2 H - N Q m 0) II f- 13 Q , M 0 E �`') N 'a M III (n M 0 p O0cnILCaa - a -0200) of -0o co in' N � � � Q � o2 ohm _1w �'? 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Ucn 5 � > * ZD = oD = DJwJZ * aCO > ixN >� w Q (0 ia w Oc' O a) � c (,.d I= u) * wd. 0ccd CCLoa W * ctHNU) J0 > J : co3JUJLLo U 3J to N- N- r-- N-• I N- N- 0 ap O o 0 0 o O N N NN N N N N v 0 0 op a) 0 .- N N- O c0 if) N I` • • -0N- ate) ate) a) , ►� ,_ � ,- N- � N- ,- � a) r = = = r r r r r C 'Cr C C C a8 a? 8 p w? � a' c":1 a' C C C N N N- N N N N N N N N O D 0 0 E � E � E � E � E Tp_izz Ems' U O O O O O O a `p j `O N- O I `O N U j U j U j U j U j U 0 > r , r , r > > > > > U m e rn Q CO rn c '- c r c ti C '- C .....1- - 0 o O .- o CO CD o o o o o co co 0 TD- 7 a)- N- a) N- a) r- j j = = (Ni = N = .c 3i 3c 3Q' c r c r c ti c C i0 _ U .5 � .. � -55 (n .c? � U � O ( U � U SCA O o O o O o - a) • a) cow coo caw Eu, E , E , E u E g E MF- M C ch •C M C OO OO OO OO OO OC O a) O C O C O C -a — ,2 — ,2 — -a —0 -a — -a C - TI"- ) 0 U a) U 2 0 2 m 3 0 2 m 2 m 2 O c C Ona c 3 c 3 c 3 U = U 5 U 5 U 5 U 5 U a) E i rn 3 3 3 O O O O O O E o Y o Y_O Y o Y Y Y Y Y Y— = O- W Ud a3 N - N ,.0r.- O4— 0 ,� 0Cfl 0 000COCO NCO 0 CU 0 0 >N (nom 0. N L � C I co CO -0M > fA — co 30 oF- OF- OF- 00 00 00 00 o0 O N z C? U a N N N N N N N > NNNNN O > > > > CD N a _ I .. I I z _ .- 0 = 0 C C s .`c(Ni -C t - .0 a) a) a) a� s 0 Qm ±-. _ f ,-2 (NI rn rn °' 0' rn _rn rn rnct a = _ =r =r = = Y i _ i _ = Y = _,,-- O. O. L a' ` s ': ai i- (0 CU i- � i 0 '- m o O 3 O a) O a) o N o n o f o D o _o o _o o o ce tea) 3 a 6a iQ 03 ; ; a) 5 75 a' E' 0E of a) E ,a) O .a) o a) 0 m0 .12) 0 a) 0 �' c c o c o c o cL� cIi cli cu ELL cI- .� 3 � 3U s 3U 3S 3S 30 3S 3S 3 Cl or; or- o ON.: oc oc oc oc _oc oc LI ,- COL ,- L ,- LL LI c 1 .c IJ 1LI .c IJ c ON M6 -4 o ca o Cp O cp o (15o (Ij o r r r cor C C C izz: C N C - E }; 'E �; 'C +: 'C �; 'C �; m ct = ix = ce = D ND N D CO n can) DI/ D CO tncn AC NC 17) U AI- ' F- tri F- in' H in F- in' C=. o H F- F- N � a) � a) a� a� a� W O W O O W O W > U U >cc - c > c U _ai J 4- -J 4- J 4 J .. J L L C t -Ccc - L Q N- N- N- N- N- N- N- N- N- N.- .- r - r r r r r r r N N N N N N N N N N N CO Cr '4) CSO N- CO O) O '- ( CO .4' NCO r r r r r r r N N N I = Y 6-3/8"CMV S "9-nY NOTES: "'CHROME TBG&LNR' V1ELLHEAD= FMC 09-36C 9_36C *STRADDLE PATCH @ 8081'IS ISOLATING GLM#6, 1 ACTUATOR= AXELSON INTIAL KB.EE 55' BF. KOP 677755'' 13-3/8"CSG,68#, —I-65' I. J III 31' —1 7"X 5-112"X 4-1/2'XO,D=3.958" Max Angle= 58°@9128' K-55,0=12.415" Datum MD= 9326' 2200' (—4-112"CRM TRDP 4A TRSSSV,D=3.812" 1i Datum TVDss= 8800'SS GAS LIFT MY\NDR>3S ST MD TVD DEV TYPE VLV LTCH PORT DATE ' 20"CONDUCTOR 91,5#,H-40,D=19-124" — 113' , 1 3454 3454 2 TE TGIIJ DOME RK 16 05/31/17 13-3/8"CSG,72#,L80,D=12:347" H2496' 2 5456 5455 1 TE-TGFD SO FE 20 05/31/17 3 6573 6573 2 TE-TGFD DMY RK 0 04/11/93 Minimum ID = 2.313" @ 8883' 1111 4 7060 7050 15 T&TGPD DMY RK 0 11/13/97 4-1/2" X NIPPLE REDUCER 5 7596 7564 20 TE TGPD DMY RK 0 09/14/94 I 6 8096 8020 29 TE-TGFD *SO 12/16/95 =' *GLM#6=NO LATCH ON SO IN GLM#6(POGLM) 8081'-8121' —4-1/2"STRADDLE PATCH ASSY, 9-5/8"X 7"BKR T1E3ACK SLV.ID=7.500" — 8126' —i I D=2.375"(08/20/12) 9-5/8"X 7"BKR"Er NKR,I)=6.187" '—{ 8134' — J 9-5/8"X 7"BKR LNR HGR ID=6.375" H 8139' --------1 9-5/8"MLLOUT WINDOW(09-36A) 8300'-8350' 9-5/8"CSG,47#,L80 BUTT,ID=8.681" H 8300' 7",29#,NT80S XO TO 13CR-80 NSCC — 8698' �c x 8795' —4-1/2"PARKER SWS NP,I)=3.813" 8852' —4-1/2"ANCHOR SEAL ASSY 8853' —7"X 4-1/2"BKR SABL-3 NKR,ID=3.875" 8883' —4-1/2"PARKER SWS NP,D=3.813" 8873'BAD LOGGED(10/22/95) 8883' —4-1/2"X 2-7/8"NP REDUCER, FISH:2 SLPS&2 ELEMENTS MISSING FROM H ??? D=2.313"(08/20/12) DWP(08/18/12) 8933' H3-3/4"BKR DEPLOY SLV,ID=3.00" 7"MARKER JOMJT -- 8971' I — 8939' H3-1/2"x 2-7/8"xo,ID=2.387" 8979' 4-1/2"PARKERSWN NP,D=3.80" H 4-112"TBG PC,12.6#,13CR NSCT, 8992' i (BEHIND CT&MILLED OUT) .0152 bpf,ID=3.958" 7"LNR 29#,13CR-80 NSCC, — —9270 \ \� 8992' —4-1/2"WLEG(BEHIND Cl) 0371 bpf,ID=6.184" ' 8982' —ELM)TT LOGGED 04/26/93 — — 9091'ELM H2-7/8"WED EXT RANGE CUP(06/05/17) PERFORATION SUM+AARY REF LOG:BHCS ON 04/06/93 ' 7"MLLOUT VVI DOW(09-36C) 9270'-9277' ANGLE AT TOP PERF:56°@ 9033' Nate:Refer to Production DB for historical pert data 9490' —SET BKR CEP(07/14/04) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 9033-9078 0 06/05/17 �����t� ` 9487'slm —FISH-BROKEN � 1-11/16" 4 9106-9116 C 01/12/98 '4••�•�•�•#1••• I TEL FINGER(07/13/04) 2' 6 9106-9126 C 11/22/01 411* 411k 9536' —2-7/8"CBPMLLED 2-118" 4 9106-9126 C 09/27/97 2" 6 9296-9304 C 03/18/04 /f444,4 ,` &RISHED DOWN HOLE 2" 6 9352-9368 C 07/15/04a (11/21/00) 2" 6 9376-9386 C 07/15/04 2" 6 9410-9430 C 07/14/04 2-7/8"PORTED PUPJOM H 9540' p 2-1/8" 4 9500-9515 C 11/05/95 � •1'i 2-1/8" 4 9520-9535 C 10/22/95 2-7/8"LM,6.5#,L-80,.0058 bpf,ID=2.387" — 9545' DATE REV BY COMMENTS DATE REV BY COIf,U'fTS PRUDHOE BAY UMT 05/25/86 POOL 6 IMTIAL COMPLETION 08/24/12 GJB/JM ) PULL AVA,SET PATCH,FISH(08/18-201' WELL 09-36C 04/11/93 N2ES SIDETRACK(09-36A) 03/04/13 JMJMD SET XX PLUG(03/01/13) PERMT No: 1951140 10/12/94 CTU CTD ST(09-36A)-FAILURE 06/08/17 BSEJMD PULLED XX PLUG(05/30/17) API No: 50-029-21429-03 08/27/95 N2ES CTD SDTRACK(09-36C) 06/08/17 JFK/JM) GLV C/O(05/31/17) SEC 2,TION,R15E 1874'FSL&37'FEL 11/06/05 KDCIILH GLV C/O(10/30/05) 06/08/17 MRLYJMD SET CBP/ADPERFS(06/05/17) 07/28/11 I KAU PJC ELMD LOGGED NP 10/22/95 BP Exploration(Alaska) OFT44, • THE STATE Alaska Oil and Gas 7;1, of® TTA S KA Conservation Commission - k 'S itt _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "ra Main: 907.279.1433 of ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Danielle Ohms AK PE Discipline Lead and DS 16 PE SCANNED AUG 1 1 20 7, BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-36C Permit to Drill Number: 195-114 Sundry Number: 317-347 Dear Ms. Ohms: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair J DATED this 1 day of August, 2017. RBDMS V-AUG - 9 2017 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Convert to Producer Er ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 195-114 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 6. API Number. 50-029-21429-03-00 • 99519-6612 Stratigraphic 0 Service a• 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I! PBU 09-36C ' RECEIVED 9. Property ADL Designation(Lease Number): 10. 0 2832 PRUDHOE BAY,PRUDHOE OIL • r/---:rJU 26 N17 11. PRESENT WELL CONDITION SUMMARY `1/i Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): 9545 ' 9031 ' 9091 8723 9091/9490 8933/9509/9536 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8272 9-5/8"47#L-80 32-8304 32-8199 6870 4760 Production Liner , See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"Camco TRDP-4A SSSV 2204, 2204 12.Attachments: Proposal Summary a Wellbore Schematic a 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development m . Service 0 14.Estimated Date for Commencing Operations: 8/21/17 15. Well Status after proposed work: Oil RI • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Danielle Ohms be deviated from without prior written approval. Contact Email: Danielle.Ohms@bp.com Authorized Name: Danielle Ohms Contact Phone: 564-5759 Authorized Title: AK P %is-'pline Lead and DS 1 •E Authorized Signature: ' Date: /,7 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No Subsequent Form Required: I t/ APPROVED BYTHE Approved by: 41-g---- COMMISSIONER COMMISSION Date:Ce it It VT"— /-11 ! t.Y-- O'``�,� RIGINAL RBDMSL` AUG - 91017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate /- 7 �7 • Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUL 2 6 2017 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) OGCC July 20, 2017 To Whom it May Concern: Attached please find the Sundry Application for Convert to Producer for Well 09-36C, PTD 195-114. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • PBU Well 09-36C (API# 50-029-21429-03) 10-403 Sundry Request to Convert to Production Current Status: 09-36C is currently an injector. This well was converted from producer to injection in 2006 as part of the Updip Victor Guard Well strategy. There is no longer benefit to this well as an injector and with recent Z4 perf production success in the FS2 area, this well was identified as a uphole perf candidate. The Zone 4 in this well has never been injected into. Prior to performing surface work to return the original production and gas lift lines back to service, a flow back test of the Zone 4 only perfs was performed. The Zone 3 and 2 perfs that had previously been injected into were plugged back and Zone 4 was perforated (details provided in 10-403 Sundry #317-187 approved on 5/17/17). A flowback test, with the well Under Evaluation, has been ongoing since 7/8/17. Through a portable test separator(and collaborated with the Pad test separator), the well has Had the following Welltests: WH WH Sep Sep Oil Water / Formation Lift Gas Total Test Start duration Pres Temp Pres Temp Rate Rate Gas Rate Rate FGOR GOR Oil H2S Date/hrs (hrs) Test Unit (psi) (deg F) (psi) (deg F) (bopd) (bwpd) wc°/ (mmscfpd)(mmscfpd) (scf/stb) (scf/stb) API (ppm) 7/22/2017 0:00 12 LRS Unit 6 506 86 377 84 1041 1005 49.1 5.6 2.0 5344 7265 35.7 7/21/2017 0:00 12 LRS Unit 6 503 85 375 84 1024 996 49.3 5.5 2.0 5395 7348 35.7 7/19/2017 0:00 12 LRS Unit 6 475 92 366 90 1182 1140 49.1 6.1 0.0 5174 5174 31.1 7/18/2017 0:00 12 LRS Unit 6 474 91 365 90 1255 1060 45.8 6.1 0.0 4852 4852 29.8 7/16/2017 0:00 12 LRS Unit 6 465 90 360 88 1242 1006 44.8 5.9 0.0 4764 4764 29.6 7/14/2017 0:00 12 LRS Unit 6 473 91 363 89 1321 1023 43.7 6.0 0.0 4561 4561 29.2 7/13/2017 2:00 10 LRS Unit 6 467 90 366 88 1252 980 43.9 6 0 4408 4407 29.8 7/13/2017 2:04 12 DS 9 TS 264 251 90 1273 1130 47.0 6 0 4541 4541 32.1 400 7/12/2017 14:00 8 LRS Unit 6 457 90 355 89 1019 1243 53.0 5.5 0.0 5372 5372 29.8 7/11/2017 0:00 32 500 7/10/2017 4:00 18 LRS Unit 6 524 86 393 84 1544 1184 43.4 5.0 2.0 3260 4560 29.6 The well still has gas lift mandrels which will be needed for kickoff. Once kicked off, the well is capable of producing without lift gas, however tests indicate gas lift may further enhance rate. While the well has shown indications of IA repressurization in the past, BP MIT's on 5/24/17 passed (MIT-T to 2446 psi, MIT-IA to 2434 psi, and MIT-OA to 1140 psi) Plan forward: 1. Obtain Sundry for Conversion to Producer 2. Complete inspection of Production and Gas Lift line Integrity, pipe supports 3. If fit for service, unblind and reconnect lines. (schedule repairs if needed) 4. Notify BP Well Integrity Superintendent of change in well type (for AKIMS modification). 5. Place on Production. 6. Monitor IA and OA for repressurization IOW • aT Q o 0 0 o O o c) o o Oo M N- CD N N O N N d Oti o LO CO N- U N O O o o O O o O O O m r- M d' O 00 M ti ti 000 d' O LOO I Lo O m m .- M d to I� L0d' ,- d 00 o M M O N co co co O CO I iI H OLOW W d- LO N LO C) M O d' LO M M W M O d- CO M M M O O 00 4.0 Lo m O O O � d' d• �o to d M N- N LO M M 0) N 00 CO C3) o) 00 0 cc Qm M M C7 tO d• �n N M O M O d• Ln M M Lo M = N- 0) M M M aa) mMM C p m mm O O 00 O a " czo0D o LU Fs C) Y J J 00 L L CU7 N * N N ti Z .- *k U - w w N w N N p , - N M M O N N 12) , CDCNI CTO 4 Ns- O CA O N N iO c,`-- CC) W ca O C U W OOW OOLLLLWacrZZZ Z W W W W W W E E E O D D H Z Z Z D D D • • a) co co m CO LC) CO 0) M N- M r- U) .1f N N 00 t OO O. M ,-,- co M CO M 1- O r- N- NI' co OD o) M O N Q CO CO Cb CO 00 CO o) 0) > L-- O.2 0 I- CV MM N I` N NOD L (0 N- LC) N co N G. O O co c O LC) O 00 O W• 6) 01 [...... ,n N- OD Y- CD O W a CO CO CO '" CO CO CO CO 0) 0 in 0 W Z co W LL1 L.1.1 O H J °g U >H 0 m Y N- m H n. 00 CO CO V OO CO O LC) LC) J J J Q Q u") W +J C. N- c- N O co CO M r- C) Q Q Q W 0_ 0_ U Z U • Cu C) c- c- Co CO CO Cf L1) LC) o_ U_ 0_ J W W 0 O 0) O 0) O O) O O) ()) Z Z Z O J J _1 p CD 0 0 W E 0 0 0 UJ c Z Q Z F- H < J < ✓ 0 2 2 2 O cn cn <n cn cn cu CD Q MI 0. O) 2 c LC) (0 CO CO N (0 O O C) Q M O CJ) LC) N O N O M ° O V- Y- N CO CO d" LC) LC) W 0 o) O) o) O 6) CA 6) CA O) W cJ = U O cn ct 2 O co co can u) co d a. 0 0 c 2LL Cn U) C/) Cn Cl) Cl) Cl) Ci) y Q CO m m CO CO m m CO a 0 0) d o a W J 0 UJ cu a co H 0 �0 J m N ti ti r- ti ti ti r- N- 0 ° Q o ,- ,- = r- r • O O O O O O O O o Z W 0_ a. < W W O▪ N N N N N N N N N 0 tY W N N ti co t\ in in L` LL Lf) in L` Lo p uj a L0U U U W W CC O O O O CO Co O O O O < 0 p p W W C[ W CO o a' Cr J J CI O W W Q < CO CO LL LL CO (n 0_ CC c) E • co co co co co co co C9 UP MM COM COCOCOCOCON , ci) , 0, 0! W 0_ co O LL. N a• it 0 0 0 0 0 0 0 0 0 < < CO CO L.1_ LL 0 C/)° 0_ cc • 10 Packers and SSV's Attachment PBU 09-36C SW Name Type MD TVD Depscription 09-36C SSSV 2203.84 2203.81 4-1/2" Camco TRDP-4A SSV 09-36C PACKER 8081 8007.06 4-1/2" KB Straddle Packer 09-36C PACKER 8117 8038.43 4-1/2" KB Straddle Packer 09-36C PACKER 8137.91 8056.56 7" Baker H Packer 09-36C TBG PACKER 8856.95 8589.97 4-1/2" Baker SABL-3 Packer TREE W 6-3/8"CM1 smirr NOTES: ""'CHt90ME TBG&LNR"" WELLHEAD= FMC • 09-36C " DDLE PATCH @ 8081 IS ISOLATING GLM#6. ACTUATOR= AXELSON INMAL KB. ELE 55' BE ELEV= NA KOP= 6775' 13-3/8"CSG,68#, H 65' I›..r. II 31° H7"X 5-1/2"X 4-1/2"XO,ID=3.958" Max Angle= 58°@ 9128' K-55,D=12.415" Datum MD= 9326' / 0 2200' —I4-112"CAM-TRDP-4A TRSSSV,D=3.812" Datum TVDss= 8800'SS GAS ST MD TVD DEV TYLFT FE VLVMANDRELSTCH PORT DATE L 20"CONDUCTOR 91.5#,H-40,D=19-124" H 113' ® 1 3454 3454 2 TE.TGR)DOME RK 16 05/31/17 13-3/8"CSG,72#,L80,D=12.347" H 2496° 2 5456 5455 1 TE-TGR) SO RK 20 05/31/173 6573 6573 2 IE-TGR) DM' RK 0 04/11/93 Minimum ID = 2.313" @ 8883' 111F1 4 7060 7050 15 TE TGFD DMY RK 0 11/13/97 5 7596 7564 20 TE-TGR) DMY RK 0 09/14/94 4-1/2" X NIPPLE REDUCER 1 1 6 8096 8020 29 TETGPD `SO - - 12/16/95 7;' , *GLM#6=NO LATCH ON SO IN GLM#6(POGLM) 8081' -8121' —4-1/2"STRADDLE PATCH ASSY, 9-518"X 7"BKR TIEBACK SLV, D=7.500" --i 8126' I D=2.375"(08/20/12) 9-5/8"X 7^BKR"H FCR,D=6.187' H 8134' — — 9-5/8"X 7"BKR LNR HGR,D=6.375^ —j 8139' 7r 9-5/8"MLLOUT WINDOW(09-36A) 8300'-8350' 9-5/8"CSG,47#,L80 BUTT,D=8.681" -1 8300' 7",29#,NT80S XO TO 13CR-80 NSCC —I 8698' rc 8795' H4-1/2"PARKER SW5 NP,D=3.813" 8852' H4-1/2"ANCHOR SEAL ASSY 8853' H7"X 4-1/2"BKRSABL-3 Fi4R,D=3.875" 8883' —4-1/2"PARKER SVS NP,I)=3.813" 8873'E-M D LOGGED(10/22195) 8883' —4-1/2"X 2-7/8"NIP REDUCES FSFt 2 SLPS&2 ELEMBYTS MSSNG FROM ??? � D=2.313"(08/20/12) t3WP(08/18/12) 8933' --I 3-3/4"BKR DEPLOY SLV,D=3.00" 7711 7"MARKER JON- 8939'8971' 8939' —13-1/2"X 2-718"XO,ID=2.387^ tom?D=3.80 4-1/2"TBG PC,12.6#,13CR NSCT, -� 8992' (4 1/2'8E1M)PARKER CT&MILLSWNE30Uf) .0152 bpf,ID=3.958" 7"LNR,29#,13CR-80 NSCC, — -9270 / \— 8992'8979' —14-1/2"VVLEG(BB-IND CT) .0371 bpf,ID=6.184" 8982' —i ELM)TT LOGGED 04126!93 49091'ELM H2-7/8"WFD EXT RANGE C BP(06/05/17) PERFORATION SUMMARY REF LOG:BRCS ON 04/06/93 7"MLLOUT WINDOW(09-36C) 9270'-9277' ANGLE AT TOP PERF:56°@ 9033' Note:Refer to Production DB for historical perf data 9490' HSET BKR CIBP(07/14104) SOLE SPF INTERVAL Opn/Sqz SHOT SOZ 2" 6 9033-9078 0 06/05/17 /•4 9487'WinFISH-BROKEN 1-11/16' 4 9106-9116 C 01/12/98 ��..4.4.�.�.•*v TEL FINGER(07/13/04) 2' 6 9106-9126 C 11/22/01 9536' —2-7/8"aBPMLLED 2-1/8" 4 9106-9126 C 09/27/97 2" 6 9296-9304 C 03/18/04 I &R 1561 Dowty HOLE 2" 6 9352-9368 C 07/15/04 (11/21/00) 2" 6 9376-9386 C 07/15/04 If, 2" 6 9410-9430 C 07/14/04 ( 2-7/8"PORTED PUP JOINT -r 9540' p 2-1/8" 4 9500-9515 C 11/05/95 y •�4/ 2-1/8" 4 9520-9535 C 10/22/95 I 2-7/8"LW,6.5#,L-80,.0058 bpf,D=2.387" -{ 9545' 1 l DATE REV BY CONIKENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/25/86 POOL 6 INTIAL COMPLETION 08/24/12 GJB/JMD FULL AVA,SET FATCH,FISH(08/18-20/' WELL 09-36C 04/11/93 N26 SIDETRACK(09-36A) 03/04/13 JM'JMD SET XX R.UG(03/01/13) PERMT No: 1951140 10/12/94 CTU CTD ST(09-36A)-FAILURE 06/08/17 BSEIJMD PULED XX FLOG(05/30/17) AR No: 50-029-21429-03 1 08/27/95 —N26 CTD SDTRACK(09-36C) 06/08/17 JFK/JVD GLV C/O(05/31/17) SEC 2,TION,R15E 1874'FSL&37'FEL 11/06/05 KDCITLH GLV GO(10/30/05) 06/08/17 MR<YJMD SET CBRADFERFS(06/05/17) 07/28/11 KAU PJC CM3 LOGGED NP 10/22/95 BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,July 22, 2017 4:03 PM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL;AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J Subject: NOT OPERABLE: Injector 09-36 (PTD#1951140) Cessation of Temporary Injector Flowback All, Injector 09-36 (PTD#1951140)was made under evaluation on 06/24/17 to temporarily flow back to assess SAG River rich gas per approved sundry 317-187 for up to 14 days. Today,7/22/17,concludes the flowback of this injector. At this time the well is classified as Not Operable and must be shut in before 5pm on 7/22/17 or as soon as operationally possible. Plan Forward: 1. Flowback—Shut in well,freeze protect with diesel only. 2. Production Engineer: Develop plan forward for injector to producer conversion Please reply with any questions, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 SCANNED A1-11;- �l� o 9 2311�l Cell 907-980-0552 Harmony 4530 1 • • • ti OF 7.4 \ //j"TTHE STATE Alaska Oil and Gas OfLAS <:A Conservation Commission A it#i 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ...,` Main: 907.279.1433 OF ALAS*P Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner SUMO MA': 2 FS2 Lead PE BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 09-36C Permit to Drill Number: 195-114 Sundry Number: 317-187 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this 17 a y of May, 2017. RBDMVIS l,- i°._.;' 1 9 1917 RECEIVED • STATE OF ALASKA • MAY ALASKA OIL AND GAS CONSERVATION COMMISSION 9 2017 APPLICATION FOR SUNDRY APPROVALS AOGCO 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations g • Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate lid . Other Stimulate 0 Pull Tubing0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Flow Back Injector m 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 195-114 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service 0. 6. API Number: 50-029-21429-03-00 - 7. If perforating: n What Regulation or Conservation Order governs well spacing in this pool? �` ''D°' 3L,1/47-- 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ SIO p PRUDHOE BAY UNIT 09-36C - s-!// 9. Property Designation(Lease Number): 110. Field/Pools: ADL 0028327 PRUDHOE BAY,PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: I Effective Depth TVD: MPSP(psi):(psi) Plugs(MD): Junk(MD): 9545 • 9031 . 8883 8606 8883/9490 8933/9509/9536 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 8272 9-5/8"47#L-80 32-8304 32-8199 6870 Production 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): See Attachment P ( ) Tubing Size: I Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"Camco TRDP-4A SSSV 2204, 2204 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ® • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ hi jf' WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stechauner,Bernhard be deviated from without prior written approval. Contact Email: Bernhard.Stechauner@bp.com Authorized Name: Stechauner,Bernhard Contact Phone: +1 907 564 4594 Authorized Title: FS2 Lead PE Authorized Signature: Date: _C/9ii2 I / COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ 31-7- `cd 7 Other: ASG 5 le q I+ Post Initial Injection MIT Req'd? Yes 0 No V/ Spacing Exception Required? Yes 0 No l SSubsequent Form Required: I d .11-c+ Approved by:ai,47 /- APPROVED BYTHE COMMISSIONER COMMISSION Date:S./7,/7 VVT- 5J'�/' - ` ORIGINAL RDDMS - MAY 1 9 2017 . L'i'r./.. /7. /(., -77 Form 10-403 Revised 04/2017 Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED MAY 0 9 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary May 9, 2017 To Whom it May Concern: Attached please find the Sundry Application for 09-36C, PTD # 195-114 to set a plug, add perforations and then conduct a flow test on Zone 4. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.O,Deg Ltfa,E4Z.SPG 10/12/15) General Information • Well Name: 09-36C Well Type: Water Injection Weil API Number: 50-029-21429-03 Well Activity Conventional 4 Classification: Activity Description: Injector Flowback • Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK ^ 12 Month Avg IOR, bopd: Job Type: Add Peri+WSO-Plug Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION • Other regulatory None Sundry Form 10-403 requirements? Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Bernhard Stechauner Contact numbers: (907)564-4594 (907)360-7485 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Danielle Ohms Contact numbers: (907)564-5759 (907)440-9082 Date Created: April 19,2017 Revisions(date,who,what changed): I Current Well Status Information Water Rate or Gas Rate or Date Oil Rate fnj Rate Gas Injection GOR FTP or Injection Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 4/17/2017 0 3 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) NA Recent H2S (date,ppm) 12/12/2001 50 ppm / Maximum Deviation(Angle and — Depth) 58° 9,128'MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 26° 9,323' MD Reservoir pressure(date, psig) 7/13/2009 3,350 psi Minimum ID and Depth 2.313" 8,883' MD Reservoir Temp,F 156°F Shut-in Wellhead Pressure 50 psi Known mech.integrity TxIA,patch over GLM#6, but has passing MIT-T and MIT-IA, plus LDL found no leak. problems(specifics) Last downhole operation (date, operation) 3/13/2013 EL LDL from surface to 8,867' MD. No leak found. Most recent TD tag (date,depth, toolstring OD) 2/28/2013 9,133' MD INo tag, no sample.2.25"Cent, 1-3/4"s.bailer drift Well is currenity an injector. Plan to test flowback as producer. If successful, Surface Kit Fit-for-Service? NO If No,Why? will need to be re-connected to its old production line Comments,well history, This is another injector where we found Z4 uphole pert potential that had never been injected into.This / background information, well was converted to injection in 2006 as part of the Updip Victor Guard Well strategy.There is no more etc: benefit to this well as an injector and with recent Z4 pert success in the FS2 area this is another great candidate. The well still has gas lift mandrels and thus will not need N2 for kick off. 4/- 4/ The current proposal is to shut off al cisting perforation,shoot the top of the reservoir and test the wells performance thyro=portable test separator.As a future upside,there is an option to re open the top of • • Zone 3 in the future when the 09-15A MIST well gets close to 09-36C to capitalize on those benefits also. A permanent re-conversion to producer is not in the scope of this SOR and will be evaluated after r the flowback results. • S Well Intervention Details Please contact the SOR author if. 1.There is a change in work scope to the approved SOR 2 For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Undesireable injector Specific Intervention or Well Objectives: 1 Shut-off all existing perforations and shoot top of reservoir to test wells potential as a producer. 2 3 Key risks,critical issues: Mitigation plan: 1 Potential for very high H2S->injector flowback Ensure all personnel are wearing H2S monitors and discuss H2S risks in pre-job meeting 2 Trouble RIH in the past Last intervention swaged and broached a lot but was able to pull and re-set patch. 3 Perforating close to CIBP and tight tolerances WSL discretion if CIBP is set before or after perfs 4 Representative SBHPS Get SBHPS as last SL step to allow well to equalize Summary Ste # Service Line Activity P 1 DHD MIT's to confirm integrity per pumping schedule. 1 S Pull XX plug, drift to CIBP @ 9,490' MD, install generic GL design for K0, SBHPS 2 E Add perf, set CIBP @ 9,092' MD (WSL discretion to perf or plug first due to short distance) 3 T Flow back well for -1 week, take frequent samples, and coordinate with lab to get oil/water/gas sample once well is flowing stable Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 500 MMSCFD: 5 BWPD: 1000 Expected Production Rates: FTP(psi): 300 Choke setting: PI(bfpd/psi dp) Post job POP instructions: POP well to portable separator and flow for-1 week to evaluate well performance. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc • • Well: 09-36C MD GR a (FEET) O 0 GAPI 150 9025- 42N -9050- 42P 9,033-9,078'and 4S'add pert in Z4A. _ _ I iI -9075- 41P I 31N =910fl= (fs PERF PERF -9125- 31P _91511- - - - r -9175- z rd - 27P • • Ttc ,... PERFORATION RECORD schiumberger 2 1/8" DS 4 SPF 22-OCTOBER-1995 COMPANY ARCO ALASKA INC WELL D S 9 - 36C FIELD PRUDHOE BAY BOROUGH NORTH SLOPE STATE - i ALASKA Other SCNICCS: r i AT StJAFAC:7 r IL I L L a 0 4 ' API SERIAL NO SECT TWP, RANGE g .,..' 50-029-21429-03 12 , 10N I 15E Permanent Datum MS. Eby 0 0 F Elev.:K.B.S3 0 F Log Masc./red From PKB 530 1 above Perm.Datum DF Drilling Measured From RB GL Date 12-C,C7-199'. Run No. ONE. — - Depth Driller 454t)U Depth Logger(Sch1.) 9537 0 , Btrn Log Interval PPYI7 0 -.- — Top Log Interval 8780 0 F FINAL Type Fluid in Hole WATER CP.ME Sal nity NeCI Denalty Fluid Level . . Max Flee Temp Deviation ',7,iP .4 . - . Logger on Bottom Equip Location S3 t' Recorded 8y EA_Et — _ w tnessed By ,yACK sAN- BOREHOLE RECORD Bi'S ze 1 IN.F 'Tve N,.., .•-E-i•IN....) L.t.ii_ - ..,.. Oaptn ..__ . . CASING& TUBING RECORD S re 1-• -fp ,4gz 2?8' :ryetgt.it 25 DOM L3,f 4290000 LB '2 ta(X)0,8,1' 6 Casing Top.,Dr,iler 8125 . ;C 0 f- 3CF 8993 Casing-op Logger Casing Shoe-D,iller 4.•, 3: : • i e9c4‘o Cast ng.logger • • T - b 1 ' SCbL-- ttt - ,,_ ..: • 8900 T I ---""4 : , 3 1/2 X 2 f i matxwm &xx 4 t 9000 3 1 I - , . Add Perf: 9,033 9,078' MD . Set CIBP . 9,092' MD i f ii _ . i j I ._ 5C`C1L-_- . 9100 ,. ---GP, 1 H I it-------- • ,.. t { . t _ i Lq , { . . i ' i - __.. . . _ 9200 • Q.o 0 0 0 0 0 0 0 0 0 t4 M t� O N N O CO Co N CO p N N r- I - T C CND r- U N 0 0 0 0 0 0 0 0 0 0) O CO N- CO CO �` M N- 0) CO r c- N N-m M cc) co 00 r- CO Lc) 0) to (A O x- 07 07 a1 M V f� N CO CCO COO 00) M CO CO H LO Low inN � CMCr) Nt IC) Cr) (t) CO O Cr CO CO CO CO CO CO CO = U cc M E Lo �nrnoo � vv1n (0 (o ct co t� N Lo co co O) .co N (b CO 0) 0) (0 CU i i i 1 I Z 1- CO CO Nr (-NI N co O co co •4t tf) co co (o M0) M co co (0 (0 CO CO co .Q W �-- Wtf) o O \ O O oo 0 cn 0 0 0 00 � C2 C2 U .N ?? N � NN. NM � M 4t c LL CA 60 -do 00 N N CO N - Q. O M Cr) N N _ ti - CV N M M t� N r O ti N 1.0CNI L CO CV "r N- CNI CO r'sO d CO N N 00 Co to CO co J W F— Q C O W W ° W UOWtiEccta ZZZ Z ct W W W W m m m O J J Z Z Z Z D J j Ucn (n _ JJJF— I-- • • a) N m CO LC) CO (3) CC) x- Cr) v- t • V: N N CO V' CO f� 0. M ‘- O M (O r M r N N. d' co co a) co O (NI 0 co N- co co co a) O O a CO CO O CO CO a) 0 I-- O. O t N-• `- Cr) c N d' O N S co cO MN- co a) O LW 0 ti Cp 0 0 0 CA a) O O O CO CO CO a) 0 I- LULu CC 0 0 CIu)I-LIZ W W 0 W 0 a) I- I- J W m 0 0 Q C) O U m u) cn - U U ~ cc2 C • d 111 co v" N co M M c) to cc) < < < W a CL o _Z 0 0 0 0 0 a1 a) C) a) O U_ U_ _0 J W W J D CD 0) N Z Z Z 0 p 0 J a J E O 2 Q Q Q 2 a 0 a a- _ F— 2 000W oe ce Z 0 Z W W W a F F < J < Z G 2 2 O In cn u) v) (A co Q O F" C < f. (0 (.0 (.0 CNC0000 O CO „ O ,- C}) ON ON N CO M O O {w 0 CO O CS) O CO CO 0 a) L p aO ) O I a u) Y 0 0 CO a a 2 2 O ca c i can (1) can Q. CL a G. U c Ocn cn u) u) u) Cl) U) Cl) coaCI. aaaaaa Qmmmmmmmm 0 t a) a a) - a M M M M M M M M 0 0 0 0 0 0 0 0 0 0 Z W z N N N N N N N N Q W O. M M M M M M M M a W 0 m o p es -1 J J O W a Q Q a u) LI m cn a cf m E ZcCOccccccCO (0cCDCUOCO CO CO CO CO CO CO CO M w a u) 0 W N CC C_ C) Cai0) 0) CCC3) m a a a U J 00w a OOOOOOOO QQComwLT. cnu) aa • 0 Packers and SSV's Attachment PRUDHOE BAY UNIT 09-36C SW Name Type MD TVD Depscription 09-36C SSSV 2203.84 2203.81 4-1/2" Camco TRDP-4A SSSV 09-36C PACKER 8081 8007.06 4-1/2" KB Straddle Packer 09-36C PACKER 8117 8038.43 4-1/2" KB Straddle Packer 09-36C PACKER 8137.91 8056.56 7 Baker H Packer 09-36C TBG PACKER 8856.95 8589.97 4-1/2" Baker SABL-3 Packer TREE= 6-3/8"CIW • NOTES: '""CHROME TBG&LNR""" WELLFEAD= FMC 09-36C 9-3 �jL/C "STRADDLE PATCH @ 8081'IS ISOLATING GIM#6. ACTUATOR= AXELSON NMAL KB.ELE 55' BF.ELEV= NA KOP= 6775' 13-3/8"CSG,68#, H 65' 1 I 31' —7"X 5-112"X 4-1/2"XO,D=3.958" Max Angle= 58'@9128' K-55,ID=12.415" Datum MD= 9326' ® 2200' —[4-1/2"CAM TROP 4A TRSSSV,D=3.812" Datum TVDss= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 20"CONDUCTOR 91.5#1,H-40,D=19-124" 1— 13' 11/ � 1 3454 3454 2 TE-TGFD DMY RK 0 10/30/05 13-3/8"CSG,72#,L80, =12.347" H 2496' 2 5456 5455 1 TE TGR? DMY RK 0 10/30/05 D 3 6573 6573 2 TE TGPD DMY RK 0 04/11/93 Minimum ID = 2.313" @ 8883' ( 4 7060 7050 15 TE TGFD DMY RK 0 11/13/97 4-1/2" X NIPPLE REDUCER I 5 7596 7564 20 TE TGFD DMY RK 0 09/14/94 I 6 18096 8020 29 TE-TGR) *S0 — -- 12/16/951 i' *GLM#6=NO LATCH ON SO IN GLM#6(POGLM) 9-5/8"X 7"BKR TIEBACK SLV.D=7.500" --1 8126' I 8081 -8121' —4-1/2"STRADDLE PATCH ASSY, 9-5/8"X 7"BKR"H'FKR,D=6.187" —I 8134' l J D=2.375"(08/20/12) 9-5/8"X 7"BKR LNR HGR,D=6.375" H 8139' -�� 9-5/8"MLLOUT WINDOW(09-36A) 8300'-8350' 19-5/8"CSG,47#,L80 BUTT,ID=8.681" --I 8300' 7",29#,NTBOS XO TO 13CR-80 NSCC — 8698' sc x 8795' H4-1/2"PARKER SWS MR 13=3.813" 8852' —I4-1/z ANCFDR SEAL ASSY �� 8853' --17"X 4-1/2"BKR SABL-3 FKR,D=3.875" 12-7/8"OTIS XX PLUG(03/01/13) 8883' 8883' —4-1/2"PARKER SINS NP,D=3 813" 8873'HAD LOGGED(10/22/95) 8883' —4-1/2"X 2-7/8"NIP REDUCER, RSH:2 SLIPS&2 ELEMENTS MISSING FROM H ??? D=2.313"(08/20/12) DWP(08/18/12) 8933' — 3 3/4"BKR DEFtOY SLV,D=3.00" I 11\ 7"MARKER JOINT --J 8971' $939' —i 3 112"X 2-7/8"XO,ID=2.387" 4-1/2"TBG-FC,12.6#,13CR NSCT, H 8992' 8979' —4 112"PARKER SWN NP,D=3.80" Oi 52 bpf,lD=3.958" (BERN)CT&MILLED OUT) 7"LNR,29#,13CR-80 NSCC, —I —9270 8992' I—4-1/2"WLEG(BEHIND CT} .0371 bpf,D=6.184" 8982' —I ELMD TT LOGGED 04/26/93 I 0 7"ILILLOUT WINDOW(09-36C) 9270'-9277' PERFORATION SUMMARY REF LOG:BRCS ON 04/06/93 I 9490' N SET BKR CEP(07/14/04) ANGLE AT TOP FERE:57°@ 9106' Note:Refer to Production DB for historical pert data 194$7'slm FISH-BROKEN SIZE SPF INTERVAL Opn/Sqz SHOT SQZ #v4#'•.t. TEL FINGER(07/13/04) 1-11/16" 4 9106-9116 0 01/12/98 1#•# •#•#••••••, `4\ip` I 9536' I—2-7/3"CEP MLLED 2" 6 9106-9126 0 11/22/01 2-1/8" 4 9106-9126 0 09/27/97 414.14, &RUSHED DOWN HOLE 2" 6 9296-9304 0 03/18/04 olly ` (11/21/00) 2" 6 9352-9368 0 07/15/04 ` 2" 6 9376-9386 0 07/15/04 2" 6 9410-9430 0 07/14/04 2-7/8"PORTED PUP JOINT —I 9640' /4/ 6. 2-1/8" 4 9500-9515 C 11/05/95 ,,A#0I 2-1/8" 4 9520-9535 C 10/22/95 2-7/8"LNR,6.5#,L-80,.0058 bpf,D=2.387" —J 9545' DATE l REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 05/25/86 POOL 6 INITIAL COMPLETION 11/06/05 KDC/TLH GLV 00(10/30/05) WELL: 09-36C 04/11/93 N2ES SIDETRACK(09-36A) 07/28/11 KALI PJC ELMD LOGGED NP 10/22/95 PERMIT No: 1951140 10/12/94 CTU CTD ST(09-36A)-FAILURE 08/24/12 GJB/JMD PIAL AVA,SET PATCH,FISH(08/18-20/' AR No: 50-029-21429-03 08/27/95 N2ES CTD SDTRACK(09-36C) 03/04/13 JNYJM, SET XX FLUG(03/01/13) SEC 2,TON,R15E 1874'FSL&37'FEL 7/13-14/04 LDK/KAK ADFERFS 07/14/04 I LDK/KAKtSETCUP — BP Exploration(Alaska) Pat 05C 1161146 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Ce iI71 +3 Sent: Monday, January 07, 2013 1:03 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; AK, OPS EOC Specialists; Daniel, Ryan; Weiss, Troy D; Brooks, Phoebe L (DOA) Y Y ( ) Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: Injector 09 -36C (PTD #1951140) IA Repressurization Post Bleed Attachments: 09 -36C TIO 01- 07- 12.docx All, Injector 09 - 36C (PTD #1951140) exhibited slow IA repressurization while on produced water injection after bleeds performed on 12/11/2012 and 12/22/2012 as seen in the attached TIO Plot. The IA was bled again on 01/06/2013 from 840 psi to 500 psi to evaluate for TxIA communication and the IA has repressurized 200 psi on the next day monitor. Current tubing /IA /OA pressures are equal to 990/700/100 psi. At this time the well is reclassified as Under Evaluation and may remain on injection. The well passed an AOGCC witnessed MIT -IA on 09/16/2012 after a tubing patch was set to repair TxIA communication. Plan forward: 1. WIC: Monitor TIO for 5 -7 days for IA stabilization 2. APE: Evaluate for Leak Detect Log /Pull & Re -set tubing patch - A current TIO and Injection Plot is attached for reference: «09 - 36C TIO 01 07 12.docx» >- At this time the well will remain on the AOGCC Monthly Injection Report. Thank you, Mehreen Vazir SCANNED APR 112013 BPXA Well Integrity Coordinator 907- 659 -5102 From: AK, D &C Well Integrity Coordinator Sent: Saturday, September 29, 2012 8:38 PM To: 'Regg, James B (DOA)'; Chris Wallace (chris.wallace0alaska.gov); AK, • 'S FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC T K, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Dan*: , Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; Brooks, Phoebe L (DOA) (•hoebe.brooks . aiaska.•. ) Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD W- ntegrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M Subject: OPERABLE: Injector 09 -36C (PTD #195 0) Passed Witnessed MIT -IA Post Tubing Patch Repair 1 • • P4E3U 09 -36C PTD #1951140 1/7/2013 TIO Pressures Plot 11�lK � 001 3000 —6 - 0 2CW - 00 ■ •• 'to, Ak Aii i kak_____MI1 &A Fr v 10011, 101;012 4 — , 00'2 111012 110 1 00012 1 1/0112 1210012 12•502 11221. t22002 01212 Injection Plot Yi 63 1.600- .17000 ".. 1.50p- 16000 1500C 1a,000 1.300 - 200 - ►� - lzoa -12000 10.000 I 569 9.000 — 900- ti G1 , - &000 R 0 - 6.000 " 5.000 100 .1 000 00 - -1.000 xe • 2000 . 100 -1000 101102 1010n2 102172 14112 11i102 5,012 112412 129012 120%12 12+1512 1222 12 120512 010513 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, September 29, 2012 8:38 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere; Brooks, Phoebe L(DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M Subject: OPERABLE: Injector 09-36C (PTD#1951140) Passed Witnessed MIT-IA Post Tubing Patch Repair Attachments: MIT PBU 09-36C 09-16-12.xls; 09-36C (PTD#195114)wellbore schematic.pdf; 09-36C (PTD #1951140)wellbore schematic.pdf; MIT-T PBU 09-36c 08-21-12.xls; CMIT PBU 09-36c 08-19-12.xls All, SCANN ED JUL. 2 9 2013 Injector 09-36C (PTD#1951140) passed a AOGCC witnessed MIT-IA to 2426 psi on 09/16/2012 with the well on produced water injection. The passing test confirms the presence of two competent barriers in the well. The well is reclassified as Operable. A copy of the MIT-IA and wellbore schematic are included for reference. «MIT PBU 09-36C 09-16-12.xls» «09-36C(PTD#195114)wellbore schematic.pdf>> Please call if you have any questions. Thank you, Gerald Murphy BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, September 04, 2012 3:31 PM To: 'jim.regg @alaska.gov'; 'chris.wallace @alaska.gov'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; Vazir, Mehreen; Murphy, Gerald L Subject: UNDER EVALUATION: Injector 09-36C(PTD #1951140)Tubing Leak Repaired with Downhole Patch All, 1 • • Injector 09-36C (PTD# 1951140) passed a CMIT-TxIA on 08/19/2012 to 2386 psi, and a MIT-T on 08/21/2012 to 2424 psi after installing a Baker tubing patch over a leaking gas lift mandrel in the well.The passing tests indicate the presence of two competent barriers in the well. The well is reclassified as Under Evaluation. Plan forward: 1. Operations: Return well is water injection 2. Fullbore: AOGCC witnessed MIT-IA once well has thermally stabilized A copy of the MITs and wellbore schematic have been included for reference. <<09-36C (PTD#1951140)wellbore schematic.pdf>> <<MIT-T PBU 09-36c 08-21-12.xls» «CMIT PBU 09-36c 08-19- I2.xls>> Please call if you have any questions or concerns. Thank you Shane Wills filling in for Mehreen Vazir BP Alaska - Well Integrity Coordinator ft- WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, August 03, 2011 4:51 PM To: 'Maunder,Thomas E (DOA)'; 'Regg,James B(DOA)'; 'Schwartz, Guy L(DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D&C Well Integrity Coordinator; Walker, Greg (D&C) Subject: NOT OPERABLE: Injector 09-36C(PTD #1951140)Tubing Patch Leak Identified By Leak Detect Log All, Injector 9-36C (PTD#1951140)was identified as having a leak located at the tubing patch during a Leak Detect Log on 8/1/2011. The well has been secured with kill weight fluid. The well is reclassified as Not Operable pending repair of the tubing patch. Please call if you have any questions. Thank you, 2 • Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office(907)659-5102 Cell (907)752-0755 Pager(907)659-5100 Ext. 1154 i Coordinator From: AK,D&C Well Integrity Coo d ato r Sent: Monday,July 04,2011 10:01 PM To: 'Maunder,Thomas E(DOA)';'Regg,James B(DOA)';'Schwartz,Guy L(DOA);AK,OPS FS2 OSM;AK,OPS FS2 DS Ops Lead;AK,OPS FS2 Facility OTL; AK,OPS FS2 DS Operators;AK,OPS PCC EOC TL;AK,D&C Wireline Operations Team Lead;AK,D&C Well Services Operations Team Lead;Cismoski,Doug A; Daniel,Ryan;AK,RES GPB East Wells Opt Engr;AK,RES GPB West Wells Opt Engr;Longden,Kaity Cc: AK,D&C Well Integrity Coordinator;King,Whitney;Walker,Greg(D&C) Subject: UNDER EVALUATION:Injector 09-36C(PTD#1951140)Slow IA Repressurization All, Injector 09-36C (PTD#1951140) has exhibited slow IA repressurization while on produced water injection since a bleed on 04/25/2011. The well has had a tubing patch installed since 1995. The well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: MIT-IA to 2500 psi 2. WIE: Pending results of MIT-IA, evaluate for a leak detect log A TIO plot and wellbore schematic have been included for your reference. Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907)659-5102 Cell (907) 752-0755 Pager(907)659-5100 Ext. 1154 3 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(8ialaska.gov; doa.aoocc.prudhoe.bav @alaska.gov: phoebe.brooks(cialaska.gov; tom.maunder(olalaska.gov OPERATOR: BP Exploration(Alaska),Inc. FIELD/UNIT/PAD: Prudhoe Bay/PBU/DS-09 DATE: 09/16/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-36C Type Inj. W TVD 8,588' Tubing 661 670 679 _ 683 Interval p P.T.D. 1951140 Type test P _ Test psi 2147 Casing 27 2510 2443 2426 P/F P Notes: MIT-IA post patch to repair TxIA communication OA 4 10 11 11 Pumped 5.7 bbls methanol to reach test pressure Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT PBU 09-36C 09-16-12.xds !WE= 6-3/8"CM • SAFETY NOTES: •'"CHROME MG&LW*" vu-EAD= RAC' 09-36C I STRADDLE PATCH Q 8081'IS ISOLATING GLM#6. ACTUATOR= AXB_SON KB.ELEV= 53.0', BF.BEV= NA p liri MI 31' --17"X 5-1/2"X 4-1/7 X0,D=3.958" I 6775 13-3/8"CSG,68#, --I 65' KOP= Max Angle= 58° .,9128' .K-55,1)=12.415" 22°°. 1-14-112 GA"CAS LM-IFTIRDFL4MANDRE_ATRSSS Datum MD= 9326' I SV,D=3.817 ST AID ND DEV TYPE VLV LTCH PORT DATE Datum TVDss= 8800'SS Ili 20"CONDUCTOR 91.5#,1440,ID=19-124" —I 113' 1 3454 3454 2 TE-TGFD OMY RK 0 10/30/05 k 2 5456 5455 1 TE-TGED OW FE 0 10/30/05 [13-3/8"CSG,72#,L80,0=12.347" 1--1 2496' I-4 3 6573 6573 2 TE-TGII) OMY IRK 0 04/11/93 Minimum ID = 2.376" @ 8081' -8121' nig 4 7060 7050 15 TE-TGR) CAW RK 0 11/13/97 5 7596 7564 20 TE-TGR) OMY FE 0 09/14/94 . . 4-1/2" STRADDLE PATCH ASSY 1 1 6 8096 8020 29 TE-TGPD "SO — 12/16/95 • 7, 7, "GLM#6=NO LATCH ON SO IN GLM#6(POGLM) 8081'-8121' —4-1/2'STRADDLE PATCH ASSY, 19-5/8"X 7"BKR TIEBACK SLV.ID=7.500' H 8126' I--- 1)=2.375"(08/20/12) 19-5/8"X r BKR"H'A(R,ID=6.187" 1-1 8134' I • , a 3 9-5/8"X 7"BKR LNIR HGR,ID=6,375" — 8139' 9-5/8"MLLOUT WINDOW(09-36A) 8300'-8350' 9-5/8"CSG,47#,1.80 BUTT,10=8.681" --1 8300' I 7',29#,NT8OS XO TO 13CR-80 f4S(X H 8698' I 8795' F—4-1/2'PARKER SWS MP,1)=3.813" II 8852 I—4-1/2"ANCHOR SEAL ASSY 1 8853' I--17'X 4-1/2"BKR SABL-3 PKR,0=3.875' _II 8883' j—4-1/2'PARKER SWS IV,D=3.813" log 8873'EL M 0 LOGGED(10/22/95) 8883' 1-14 4,7 X MP WDUCTR t)-?Tr'(0812012) FISH 2 SLPS&2 ELEMENTS MISSING FROM —1 ??? 8933' H - 'BKR DEFLOY SLV,ID=3.00" DWP(08/18/12) I= I 8939'I —13-1f2"X 2-7/8"XO,ID=2.387" 8979' —4-1/2"PARKER SWN NP,D=3.80' [r MARKER JOIT I— 8971' k III (BEHIND CT&MILLED OUT) 4-1/7 TI3G-FC,12.6#,13CR NSCT, H 8992' lit 8992' —14-1/2-WLEG(BB-IIN)CT) 1 .0152 bpf,ID=3.958" 1 8982' --IELMD TT LOGGED 04/26/93 I 7"Lre,29#,13CR-110 NSCC, —I —9270 .0371 bpf,ID=6.184" I 7'MLLOUT VVIADOW(09-36C) 9270'-9277' PERFORATION SUMARY 4, 9490' HSET BKR GBP(07/14/04) 0 0*. REF LOG:BHCS ON 04/06/93 galar Wm —FISH-BROKEN TEL ANGLE AT TOP FERE:57°@ 9106' FINGER(07/13/04) ■, Note:Refer to Production DB for historical pert data 40.0.0.0.0.0.04 SIZE SPF INTER'VAL Opn/Sqz DATE 0 0 0 0 0 0 0 0 ■, 95360 —2-7/8"CBP 1-11/16' 4 9106-9116 0 01/12/98 44,...........4 4•4 4 4 I I•I MLL'D&FUSHED 2' 6 9106-9126 0 11/22/01 .4 1944140p DOWN HOLE(11/21/00) 2-1/8" 4 9106-9126 0 09/27/97 % 9540' —2-7/8"FORTH) , 2" 6 9296-9304 0 03/18/04 2" 6 9352-9368 0 07/15/04 A 2" 6 9376-9386 0 07/15/04 2" 6 9410-9430 0 07/14/04 '.**■;*// 2-1/8" 4 9500-9515 C 11/05/95 2-7/8"LNR,6.5#,L-80,.0058 bpf,ID=2.387" —1 9545' 2-1/8" 4 9520-9535 C r 10/22/95 DATE REV BY COMMENTS DATE REV BY COFMENTS PRUDHOE BAY UNT 05/25/86 POOL 6 ORIGINAL COMPLET101 11/06/05 KDC/TLH GLV C/0(10/30/05) WEI.L. 09-36C 04/11/93 N2EB SIDETRACK(09-36A) 07/28/11 KAU PJC ELK)LOGGED NP 10/22/95 FERMT 141:r1951140 10112/94 - CTU CTI)ST(09-36A)-FAILU 02/03/12 PL /PJC FISI-1/CBP CORRECTIONS AR No: 50-029-21429-03 08/27/95 WES CID SIDTRACK(09-36C 08/24/12 GJE3/JM) FULL AVA,SET PATO-I,X NIP,FISH(08/18-20/12)SEC 1,BON,R15E 1874'FSL&37'Fa 7/13-14/04 LCK/KAK ADFERFS 07/14/04 LDK/KAK SET CIBP _ RI'aploration(Alaska) titUtIVMU STATE OF ALASKA A OIL AND GAS CONSERVATION COMMI.N SEP 1 8 2012 REP OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations LE Perforate U Other Patch Performed: Alter Casing 0 Pull Tubing0 Stimulate - Frac 0 Waiver 0 Time Extension❑ Change Approved Program 0 Operat. Shutdown❑ Stimulate - Other 0 Re -enter Suspended WeIe 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development El Exploratory ❑ 195 -114 -0 3. Address: P.O. Box 196612 Stratigraphid Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21429 -03 -00 7. Property Designation (Lease Number): 8. Well Name and Number: s ADL0028327 PBU 09 -36C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9545 feet Plugs measured 9490 feet true vertical 9030.69 feet Junk measured See Attachment feet Effective Depth measured 8873 feet Packer measured See Attachment feet true vertical 8599.65 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 85 20" 91.5# H-40 26 - 111 26 -111 1490 470 Surface 2441 13 -3/8" 72# L -80 82 - 2523 82 - 2522.97 4930 2670 Intermediate None None None None None None Production 8276 9 -5/8" 47# L -80 24 - 8300 24 - 8195.07 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9106 - 9116 feet 9116 - 9126 feet 9296 - 9304 feet 9352 - 9368 feet 9376 - 9386 feet 9410 - 9430 feet 9500 - 9515 feet 9520 - 9535 feet 9520 - 9535 feet True Vertical depth 8730.73 - 8736.1 feet 8736.1 - 8741.45 feet 8833.3 - 8838.28 feet 8871.52 - 8883.29 feet 8889.27 - 8896.83 feet 8915.42 - 8931.41 feet 8990.62 - 9003.83 feet 9008.28 - 9021.71 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" Camco TRDP -4A SSV 2200 2199.97 SSSV 12. Stimulation or cement squeeze summary: _ 2 f� B Z[113 Intervals treated (measured): SCANN�C) ,`6 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: 11 905 6709 1405 297 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ` Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: oil.. U Gas U WDSPLU GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG0 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 312 -054 Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature J? a -__r Phone 564 -4424 Date 9/17/2012 RRDMS SEP 2 0 I. 15'1 t-- Form 10-404 Revised 11/2011 (O / /� Submit Original Only • • 09 -36C 195 -114 -0 Junk Attachment SW Name MD Date Description 2 Slips & 2 Elements Missing 09 -36C 8933 8/18/2012 From DWP 09 -36C 9509 7/11/2004 Broken TEL Finger 09 -36C 9536 11/21/2000 Milled CIBP . • • Packers and SSV's Attachment ADL0028327 SW Name Type MD TVD Depscription 09 -36C SSSV 2200 2146.97 4 -1/2" Camco TRDP -4A SSV 09 -36C PACKER 8081 7954.06 3 -1/2" KB Straddle Packer 09 -36C PACKER 8117 7985.43 3 -1/2" KB Straddle Packer 09 -36C PACKER 8134 8000.18 7" Baker H Packer 09 -36C PACKER 8853 8534.57 4 -1/2" Baker SABL -3 Packer Casing / Tubing Attachment ADL0028327 Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 20" 91.5# H -40 26 - 111 26 - 111 1490 470 LINER 40 3 -1/2" 9.3# L -80 8081 - 8121 8007.06 - 8041.9 10160 10530 LINER 1144 7" 29# NT- 13Cr80 8126 - 9270 8046.24 - 8818.62 8160 7020 LINER 612 2 -7/8" 6.5# L -80 8933 - 9545 8634.56 - 9030.69 10570 11160 PRODUCTION 8276 9 -5/8" 47# L -80 24 - 8300 24 - 8195.07 6870 4760 SURFACE 2441 13 -3/8" 72# L -80 82 - 2523 82 - 2522.97 4930 2670 TUBING 9 7" 26# L -80 22 - 31 22 - 31 7240 5410 • TUBING 8961 4 -1/2" 12.6# 13Cr80 31 - 8992 31 - 8667.6 8430 7500 • Daily Report of Well Operations ADL0028327 ACTIVITYDATE I SUMMARY VT • V. � ac •g finer TAG TRDP -4A TRSSSV W/ 3.84" NO -GO CENT @ 2182' SLM (2200' MD) MADE FLAPPER CHECKER RUN TO TRDP -4A. FLAPPER IS IN THE OPEN POSITION RAN 3.80" LIB & TAGGED TOP OF PATCH @ 8076' SLM (8094' MD) CLEAR IMPRESSION OF TOP OF PATCH 8/13/2012 * * *CONT ON 08/14/12 WSR * ** * * *CONT FROM 08/13/12 WSR ** *(Patch Tbg /Liner) LRS PUMPS 125 BBLS OF 180* DIESEL DOWN TBG BRUSH W/ 4 -1/2" BLB & 3.79" G.RING TO PATCH @ 8076' SLM (8094' MD). NO • OBSTRUCTIONS JARRED ON 4 -1/2" AVA DWP TBG PATCH W/ 4 -1/2" PRT FOR A TOTAL OF 3 HRS. NO MOVEMENT 8/14/2012 * * *CONT ON 08/15/12 WSR * ** * * *CONT FROM 08/14/12 WSR * ** (Patch Tbg /Liner) BEGIN COMING OOH WI 4 -1/2" AVA DWP TBG PATCH AFTER - 5 HOURS ADDITIONAL JARRING LEFT PATCH IN ST#4 @ 7046' SLM AFTER 15 MIN. OF JARRING (GS SHEARED) 8/15/2012 ** *CONT. ON 08/16/12 WSR * ** ** *CONT. FROM 08/15/12 WSR * ** (Patch Tbg /Liner) HUNG UP W/ 4 -1/2" AVA DWP TBG. PATCH IN ST #2 @ 5436' SLM FREE 4 -1/2" AVA DWP TBG. PATCH FROM AROUND ST #2 @ 5447' SLM (AFTER -5 HRS OF JARRING) HUNG UP IN 4 -1/2" TRSV W/ PATCH @ 2182' SLM (JARRED ON FOR -2 HRS) 8/16/2012 * * *CONT. ON 08/17/12 WSR * ** • Daily Report of Well Operations ADL0028327 ** *CONT. FROM 08/16/12 WSR * ** (Patch Tbg /Liner) RELEASED PATCH WHILE ATTEMPTING TO SHEAR GS @ TRSV (PATCH STOPPED @ ST #3, 6541' SLM) PUSH PATCH DOWNHOLE TO 8910' SLM DURING UNSUCCESSFUL ATTEMPT TO SHEAR PRT ATTEMPT TO PULL PATCH & HANG UP IN TRSV © 2183' SLM (PASSED THRU TBG. & GLM W/O PROBLEMS) LOST PATCH AGAIN AFTER ATTEMPTING TO WORK PATCH OUT OF TRSV @ 2179' SLM RAN 3.80" CENT. & 3.805" G. RING & WORKED RESTRICTION @ 2179' SLM (ABLE TO BEAT • UP & DOWN THRU TRSV) BRUSHED RESTRICTION IN TRSV W/ 3.77" WRP DRIFT & 4 -1/2" BRUSH RAN 3.80" CENT. & 3.805" G. RING & WORKED RESTRICTION @ 2179' SLM (ABLE TO BEAT UP & DOWN THRU TRSV) RAN 3.80" SWAGE & 3.81" SWAGE TO TRSV @ 2179' SLM (UNABLE TO PASS W/ 3.81" SWAGE) 8/17/2012 ** *CONT. ON 08/18/12 WSR * ** ** *CONT. FROM 08/17/12 WSR * ** (Patch Tbg /Liner) RAN 3.80" SWAGE BARBELL THRU RESTRICTION IN TRSV @ 2179' SLM (TOOLS PASS RELATIVELY EASY) RAN 3.805" BELL GUIDE DRIFT & WORKED RESTRICTION IN TRSV @ 2179' SLM RECOVERED 4 -1/2" AVA PATCH FROM 8918' SLM. MADE SEVERAL BRUSH & WIRE GRAB RUNS TO DEPLOYMENT SLEEVE @ 8933' SLM (RECOVERED 1" x 1/2" PIECE OF RUBBER ELEMENT) RAN 2.68" MAGNET TO DEPLOYMENT SLEEVE @ 8933' SLM (NOTHING RECOVERED) • 8/18/2012 ** *CONT. ON 08/19/12 WSR * ** ** *CONT. FROM 08/18/12 WSR * ** (Patch Tbg /Liner) RAN 2.25" CENT. DRIFT 100' INTO DEPLOYMENT SLEEVE @ 9033' SLM (CLEAR) SET 4 -1/2" 4 -1/2" x 2 -7/8" NIPPLE REDUCER IN X- NIPPLE @ 8875' SLM/8873' ELM (MIN ID = 2.313 ") RAN CHECK SET INDICATING GOOD SET SET 2 -7/8" XX PLUG IN NIPPLE REDUCER @ 8877' SLM LRS CMIT -T x IA TO 2500 PSI, PASSED RAN 20' x 3.70" DMY WHIPSTOCK DRIFT TO 8500' SLM W/O ISSUE 8/19/2012 ** *CONT. ON 08/19/12 DC -4 DSL WSR * ** Daily Report of Well Operations ADL0028327 ti * ** * * * � .., CONT. FROM 08/19/12 WSR*** (Patch Tbg /Liner) TAG 4 -1/2 X NIPPLE REDUCER @ 8883' SLM W/3.50 LIB, (GOOD IMPRESSION) CORRELATED TO SLB PATCH SETTING RECORD 16- DEC -1995 USING DIGITAL SLICKLINE SET 4 1/2" BAKER LOWER PATCH ANCHOR @ 8121' MD (Center Element) AS PER PROGRAM OAL LENGTH OF LOWER ANCHOR - 11.83' TAG TOP OF LOWER PKR ANCHOR WITH 3.50" LIB @ 8086' SLM 8/20/2012 ** *CONT. ON 08/21/12 WSR * ** ** *CONT. FROM 08/20/12 WSR * ** (Patch Tbg /Liner) SET BAKER UPPER STRADDLE PACKER & PATCH IN LOWER ANCHOR @ 8044.8' DSLM UPPER PKR + PATCH = 35.41' OAL. OVER ALL LENGTH OF PATCH WITH LOWER ANCHOR = 45.94' (40' E,EMENT TO ELEMENT) MIT -T TO 2500 PSI (pass). PULL 2 -7/8" PLUG FROM NIPPLE REDUCER @ 8855' SLM. 8/21/2012 ** *WELL TURNED OVER TO DSO * ** • TREE = 63!8" CON • 09 -36C C DDLE NOTES: Wl3Lt-EAD =, FMC ATCH @ 8081' IS ISOLATING GLM # 6. ACTUATOR= AXE3..SON KB. ELEV = 53.0' BF. REV = NA 13 -3/8" CSG, 68#, --I 65' , P 1 ri r 31' - 17 - X 5 - 1/2" X 4 - 1/2 - XO, D = 3.958" KOP = 6775' Max aX Angle = 58° @ 91128' K -55 , D = 12.415" Datum M3 = 9326' 2200' H4 -1/2" CAM TRDP - 4A TRSSSV, ID = 3.812" Datum NDss = 8800' SS O GAS LFT MANDRaS ST MD ND DEV � TYPE V LY LTCH FORT DATE 20" CONDUCTOR 91.5#, H-40, ID = 19 -124" --{ 113' 1 3454 3454 2 TE -TGPD DMY RK 0 10/30/05 i s 113 -3/8" CSG, 72#, L80, D = 12.347' -I 2496' I- ill 2 5456 5455 1 TE TGPD DMY RK 0 10/30/05 3 6573 6573 2 TE TGPD DMY RK 0 04/11/93 IP 4 7060 7050 15 TE TGPD DMY RK 0 11/13/97 Minimum ID = 2.376" 8081' - 8121' 5 7596 7564 20 TE TGFD DMY RK 0 09/14/94 4 -1/2" STRADDLE PATCH ASSY 0 6 8i9 802.0 29 TE -TGFD *SO - ° 12/16/95 * GLM #6 = L TbH (d Sa ifs G 'G 8081' - 8121' — 4-1/2" STRADDLE PATCH ASSY , 19 -5/8" X 7" BKR TIEBACK SLY. D l = 7.500" I- 8126' I I A 1 D = 2.375' (08/20/12) 9-5/8" X 7" BKR "M FKR, D = 6.187" H 8134' I 19 X 7" BKR LW HGR, D = 6.375" 8139' I---------T 9-5/8" MLLOUT WINDOW (09 -36A) 8300' 80 350° 9-5/8" CSG, 47 #, L80 BUTT, ID= 8.681" H 8300' I- 7" , 29#, NT80S XO TO 13CR 80 NSCC H 8698' I-- x li r 8795' I-- I4 - 1/2" PARKER SINS NP, D = 3.813" 8852' I-4-1/2" ANCHOR SEAL ASSY 8853' I--17" X 4-1/2" BKR SABL -3 IKR, ID= 3.875" I 8883' - 41/2" PARKER SWS NP, D = 3.813" 8873' ELM D LOGGED (10/22/95) 8883' H4 -1/2" X NP REDUCER D = ? ? ?? (08/20/12) FISH 2 SLIPS & 2 ELEMENTS MISSING FROM H ? ?? 8933' - 13 -3/4" BKR DEPLOY SLV, D = 3.00" I DWP (08/18/12) — — 8939' - I3 -1/2" X 2 -7/8" XO, ID = 2,387' I7" MARKER JONT H 8971' I--.. 8979' — 4112" PARKER SINN NIP, D = 3.80" (BB-IND CT & MILL® OUT) 4 -1/2" TBG R ,12.6#, 13CR NSCT, -I 8992' I. 8992' H4 -1/2" WLEG (BB- D CT) .0152 bpf, ID = 3.958" �� 8982' --I ELM) TT LOGGED 04/26/93 I 7" LM , 29#, 13CR-80 NSCC, -I - 9270 .0371 bpf, ID= 6.184" I 7" MLLOUT WNDOW (09 - 36C) 9270' - 9277' PERFORATION SUM+MRY 4 9490' —I SET BKR CEP (07/14104) - REF LOG: BHCS ON 04/06/93 �•�•�•. • ••••. ■ ` 9487' Am FISH - BROKEN TEL ANGLEAT TOP P82F:57° @9106' *•••••■ •1111•♦ ■ FINGER (07 /13/04) Note: Refer to Production DB for historical pert data �*�1�...4 •* ` 1 ..4 4 9536' — 2 -7 /8" CEP SCE SPF NTfftVAL Opn/Sgz DATE •••••••• ...O. */ 1- 11/16" 4 9106 - 9116 0 01/12/98 �1�1 ` MLL'D & Pl1SFH3 2" 6 9106 - 9126 0 11/22/01 /� DOWN HOLE (11/21/00) 2 -1/8" 4 9106 - 9126 0 09/27/97 ` 9540' — 2 -7/8" FORTH) 2" 6 9296 - 9304 0 03/18/04 ` RP 2" 6 9352 - 9368 0 07/15/04 .' 2" 6 9376 - 9386 0 07/15/04 2" 6 9410 - 9430 0 07/14/04 *�4�i 2 -1/8' 4 9500 - 9515 C 11/05/95 2 -7 /8" LNR 6.5#, L -80, .0058 bpf, ID = 2.387" - I 9545 2 -1/8" 4 9520 - 9535 C ' 10/22/95 DATE REV BY COMuH'ITS DATE REV BY COMMENTS PRUDHOE BAY t1NT 05/25/86 POOL 6 ORIGINAL COMPLET10 11/06/05 KDCTTLH GLV C/O (10/30/05) WELL: 09-36C 04/11/93 N2ES SIDETRACK (09 -36A) 07/28/11 KAU PJC ELM) LOGGED NP 10/22/95 FERMT No: '1951140 10/12/94 CTU CTD ST (09 -36A) -FAIL 02/03/12 HMS/ PJC FISH/ CEP CORRECTIONS AR No: 50- 029 - 21429 -03 08/27/95 N2ES CTD SDTRACK (09 -36C 08/24 /12 GJB/JMD PULL AVA, SET PATCH, X NP,FISH (08/18- 20/12) SEC 1, T1ON, R15E 1874' FSL & 37' FEL 7/13 -14/04 LDK/KAK ADPERFS 07/14/04 LDK/KAK SET OBP BP Exploration (Alaska) • • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.coml Sent: Tuesday, September 04, 2012 3:31 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; Vazir, Mehreen; Murphy, Gerald L Subject: UNDER EVALUATION: Injector 09 -36C (PTD #1951140) Tubing Leak Repaired with Downhole Patch Attachments: 09 -36C (PTD #1951140) wellbore schematic.pdf; MIT -T PBU 09 -36c 08- 21- 12.xls; CMIT PBU 09 -36c 08 -19 -12.x1 All, 05 Injector 09 - 36C (PTD # 1951140) passed a CMIT -TxIA on 08/19/2012 to 2386 p si, and a MIT -T on 08/21/2012 to 2424 psi after installing a Baker tubing patch over a leaking gas lift mandrel in the well. The passing tests indicate the presence of two competent barriers in the well. The well is reclassified as Under Evaluation. Plan forward: SCANNED 114AY 0 7 2013 1. Operations: Return well is water injection 2. Fullbore: AOGCC witnessed MIT -IA once well has thermally stabilized A copy of the MITs and wellbore schematic have been included for reference. «09 -36C (PTD #1951140) wellbore schematic.pdf» «MIT -T PBU 09 -36c 08- 21- 12.xls» «CMIT PBU 09 -36c 08-19 - 12.xls» Please call if you have any questions or concerns. Thank you Shane Wills filling in for Mehreen Vazir BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com Direct Cell: 832.651.5253 Direct Email: Mehreen.Vazir@BP.com From: AK, D &C Well Integrity Coordinator 1 Sent: Wednesday, August 03, 20111 PM • To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA) ; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: NOT OPERABLE: Injector 09 -36C (PTD #1951140) Tubing Patch Leak Identified By Leak Detect Log All, Injector 9 -36C (PTD #1951140) was identified as having tubing a leak located at the tubin patch during a Leak Detect Log on 8/1/2011. The well has been secured with kill weight fluid. The well is reclassified as Not Operable pending repair of the tubing patch. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, July 04, 2011 10:01 PM To: 'Maunder, Thomas E (DOM.; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector 09 -36C (PTD #1951140) Slow IA Repressurization All, Injector 09 -36C (PTD #1951140) has exhibited slow IA repressurization while on produced water injection since a bleed on 04/25/2011. The well has had a tubing patch installed since 1995. The well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: MIT -IA to 2500 psi 2. WIE: Pending results of MIT -IA, evaluate for a leak detect log A TIO plot and wellbore schematic have been included for your reference. Please call if you have any questions or concerns. 2 Thank you, • • Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 3 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regq(rD.alaska.gov; doa .aogcc.prudhoe.bavaalaska.gov; phoebe.brooks(d)alaska.gov; OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT / PAD: Pruhdoe Bay / PBU / 09 DATE: 08/21/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -36C Type Inj. N TVD 8,588' Tubing 340 2501 2443 2424 Interval 0 P.T.D. 1951140 Type test P Test psi 2147 Casing 500 580 580 580 P/F P Notes: MIT -T Repair TxIA communication pre POI OA 0 0 0 0 After patch installed _ Well Type lnj. TVD Tubing Interval P.T.D._ Type test Test psi Casing P/F Notes: OA Well T pe In'. TVD Tubin. Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing_ Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1 = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 (Revised 06/2010) MIT -T PBU 09-36c 08- 21- 12.xls • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rem alaska.gov; doa. aogcc .prudhoe.bay(rD_alaska.gov; phoebe.brooks(d).alaska.aov; OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT! PAD: Pruhdoe Bay / PBU / 09 DATE: 08/19/12 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -36C Type Inj. N TVD 8,588' Tubing _ 273 2522 2515 2510 Interval ID P.T.D. 1951140 Type test P Test psi 2147 Casing 47 2397 2390 2386 P/F P Notes: CMIT TxIA - Repair TxIA communication pre POI OA 0 0 0 0 Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06 /2010) CMIT PBU 09 08 19 12.xls IH EE= 6-3/8" CNV NOTES` ""CHROMETBG & LW** WE LLt-EAD = FIB 09-36C DOLE PATCH CO 8081' IS ISOLATING GLM if 6. ACTUATOR = AXELSON K$. ELEV = 53.0' I BF. E_EV = 13-318" CSG 68# 65 31' J 1 1 " KOP = 6775' 7 X 5 12^ X a -112• X ©, D= 3.958" 1 M a x Angle - 58" 9128' , K - 5 5 , 0 = 1 2 . 4 1 5 " Datum = 9326 2200' H4 -1/2" CAM - TROP -4A 1FSSSV, D = 3.812' 1 Datum NDss = 8800' SS L? GAS LFT MAN CRElS ST MD TVDIDEV TYPE VLV LTCH FORT ATE II 20" CON3UCTOR, 91.5#, H-40, D = 19-124" H 113' 1 3454 3454 2 TE -TGPC) DMY FE 0 10/30/05 2 5456 5455 1 TE TGFD DMY RK 0 10/30/05 1 13-3/8" CSG, 72 #, L80, D = 12.347 H 2496' 3 6573 6573 2 " TE -TGR) DMY RK 0 04/11/93 Minimum ID = 2.376" @ 8081' - 8121' 4 7060 7050 15 TE TGR) ` DMY FE 0 11/13/97 5 7596 7564 20 TE: TGR) DMY RI( 0 09/14/94 .4-1/2 STRADDLE PATCH ASSY I 1 6 8096 8020 29 TE-TGR) SO 12/16/95 r * GLM Si = NO LATCH ON SO IN GLM #6 (POGLM) BKR 7 - r F8ACK SLV. I) = 7.500' J 8126' 8081' - 8121' 1- 4-1/2" STRADDLE PATCH ASSY, 1 9 518" X 1 l 1 D= 2.375" (08/20/12) 19 -5/8" X 7" BKR "Fr PKR, D = 6.187" H 8134' 1 ■ 19 -5/8" X 7" BKR LM HGR, D = 6.375" H 8139' i a ' 9-5/8' MLLOUT VVrDOW (09-36A) 8300' 8350' 9-5/8" CSG, 47 #, L80 BUTT, D = 8.681" H 8300' 1 • 7" , 29#, NT80S XO TO 13CR -80 NSCC H 8698' I 8795' H41/2" PARKER SWS NIP, I) =3.813" 1 8852' 1 - 112" ANCHOR SEAL ASSY 1 i IC4 0 8853' 7" X 4-1/2" BKR SABL-3 FKR, D = 3.875" 1 . 8883' J-- 4-1/2" PARKER SWS NP, D = 3.813" 8873' BAD LOGGED (10/22/95) 8883' 1 - 112' X MP F DlJ HR. 1) 7777 (08120112) FISF# 2 SLIPS & 2 R.EiVENTS MISSING FROM H ??? 8933' H3 -3/4" BKR DE FLOY SLV, D = 3.00" 1 DWP (08/18/12) ' •• 8939' --i3 - 1/2' X 2 -7/8" XO. D =2.387" I 8979' 4-1/2" PARKER SWN NP D = 3.80" 1 r MARKER JOINT H 8971' il (BEHIND CT & MILLED 0111) 4-112` TF3GPC,12.6#,13CR NSGT, H 8992' Ile 8992' H4 -1/2" 1 N..EG (89.121) CT) .. 0152 bpi, D = 3.958" 8982' H EAU Tr LOGGB) 04/26/93 1 7" LNR 29#, 13CR4 -80 NSCC - — 9270 .0371 bpf, D = 6.184" I 7' MLLOUT Y T'L)OW (09 -36C) 9270' - 9277' PERFORATION SLiP MARY 10, 9490' SET BKR CEP (07/14/04) 1 REF LOG: BHCS ON 04/06/93 �1 11111 ♦ 9487 slm --FISH - BROKEN TEL ANGLE AT TOP F NF: 57" @ 9106' ►1111 11111111 ANGER (07/13/04) Refer to Production DB for historical pert data X ` ►111 SIZE SPF INTERVAL Opn/SI}z DATE � 11111111 11 ■ 1 � , 1° M1'D B� 1 1- 11/16" 4 9106 - 9116 0 01/12/98 1 1 1 111111111 2' 6 9106 -9126 0 11/22/01 /� DOWN HOLE (11/21/00) 2 -118" 4 9106 - 9126 0 09/27/97 ` 9540' — 2 -7/8' FIDRTTH) 2' 6 9296 - 9304 0 03/18/04 ■ PUP 2" 6 9352 - 9368 0 07/15104 A 2' 6 9376 - 9386 0 07/15/04 2' 6 9410 - 9430 0 07/14/04 `,1 2 -118" 4 9500 - 9515 C 11/05/95 1 2-7/8" LNRI� 6.5#, L -80, .0058 bpf, D = _ 2.387" —1 9545' 4 '� / 2 -1/8" 4 9520 - 9535 C • 10/22/95 DATE REV BY COMMINYTS CATE REV BY COMMENTS PRU HOE BAY UMT 05125186 POOL 6 ORIGINAL COM PL • 11/06/05 KDCYTLH GLV C/O (10 /30/05) WELL: 09-36C 04/11/93 N2P,5 SIDETRACK(09 -36A) 07/28/11 KAL/ PJC ELMD LOGGED NP 10/22/95 FERMI' No: 1951140 10/12/94 CTU CTD ST (09 -36A) -FAIL 02/03/12 NMS/ PJC FISH/ CIBP'CORRECTIONS AR No: 50- 029 - 21429 -03 08/27/95 NIL'S CTD SDTRACK (09 -36C 08/24/12 GJB/JM) RJLL AVA, SET PATCH, X WASH (08/18 - 20/12) SEC 1, TICNV, R15E 1874' FSL & 37' FE L 7/13 -14/04 LDK/KAK'ADPERFS 07/14/04 LDK/KAK SET CDP BP Exploration (Alaska) • • c „ . DIF SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chidiebere Igbokwe Petroleum Engineer t l BP Exploration (Alaska), Inc. VT P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09 -36C Sundry Number: 312 -054 Dear Mr. Igbokwe: SONNEDFEB 1 3 LOIZ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, r� Daniel T. Seamount, Jr. ,� _ " Chair DATED this / Oday of February, 2012. Encl. STATE OF ALASKA yr " ALASKAIL AND GAS CONSERVATION COMMISSI• 2...../Dr 19-- ,a7-7-4.? APPLICATION FOR SUNDRY APPROVALS "3` y , � o'% 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: Patch El " 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 195 -1140 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service Ei , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21429 -03 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09 -36C Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO - 028327- PRUDHOE BAY Field / PRUDHOE OIL Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9545 • 9030.69 ' 9540 9026.2 9490 9536, 9509 Casing Length Size MD TVD Burst Collapse Structural Conductor 85 20" 91.5# H -40 26 111 26 111 1490 470 Surface 2471 13 -3/& 68#/72# K- 55/L -80 25 2496 25 2496 3450/5380 1950/2670 Production 8276 9 -5/8" 47# L -80 24 8300 24 8195 6870 4760 Liner 1144 7" 29# NT- 13Cr80 8126 9270 8046 8818 8160 7020 Liner 612 2 -7/8" 6.5# L -80 8933 9545 8635 9031 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 7" 26# L -80 22 31 - 4 -1/2" 12.6# 13Cr80 31 8992 Packers and SSSV Type: 4 -1/2" Camco TRCF -4A SSV Packers and SSSV MD and TVD (ft): 2200 2200 7" Baker H Packer 8134 8053 4 -1/2" Baker SABL -3 Packer 8853 8588 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/17 /2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ r ' GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chidiebere Igbokwe Printed Name Chidiebere Igbokwe Title PE Signature 46 ‘ Phone Date . 564 -4795 2/3/2012 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry • Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance • RECEIVED Other: FEB 0 6 2012 Alaska Oil & Gas Cons. Commission Subsequent Form Required: /0— y011 �_ � A.nchoragt APPROVED BY Approved by: N li COMMISSIONER THE COMMISSION Date: 2_ (10 1 t Z eeo :1° 2. Y*1LO R 1 G I N A L �, - � .� Form 10-403 Revised 1/2010 Submit in Duplicate 09 -36C 195 -114 - PERF - ATTACHMENT Sw Name Operation Date '' Perf Operation Code ; Meas Depth Top !�, Meas Depth Base Tvd Depth Top i Tvd Depth Base 09 -36C 10/22/95 PER I 9,520. 9,535. 9,008.28 9,021.71 09 -36C 1 11 /5 /95;APF 9,500. 9,515. 8,990.62 9,003.83 09 -36C 11/22/95 , APF 9,106. 9,126. 8,730.73 8,741.45 09 -36C 9 /27 /97,APF 9,106. 9,126. 8,730.73 8,741.45 09 -36C 11/25/97 BPS 9,500. 9,535. 8,990.62 9,021.71 1 09-36C 1 1/12/98 RPF I 11/21 00 BPP 9,106.1 500. 9,535. 8,990.62 9,021.71 09 -36C 9,021.71 09 -36C 3/18/04 APF 9,296. 9,304. 8,833.3 8,838.28 09 -36C 7/14/04 APF 9,410. 9,430. 8,915.42 8,931.41 09-3 6C 7/14/04 BPS 9,490. 9,535. 8,981.91 9,021.71 09 -36C 7/15/04 APF 9,352. _ - - 9 1 8,871.52 8,883.29 09 -36C 7/15/04 APF - -/- 1 9,377 1 6.', 9,386. 8,889.27 8,896.83 AB ABANDONED PER PERF 1 APF ADD PERF RPF REPERF REMOVED BPP BRIDGE PLUG PULLED , _ SL SLOTTED LINER BPS �� BRIDGE PLUG SET SPR (SAND PLUG REM VED FCO FILL CLEAN OUT SPS SAND PLUG SET 1 FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ I SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED LEAK STO STRADDLE PACK, OPEN MLK MECHANICAL LE - OH OPEN HOLE III • • kip To: J. Bixby /R. Liddelow Date: February 3, 2012 AK D &C Wireline Team Leads From: Chidi Igbokwe AFE: APBNRWOS DS 04 & 09 PE Est Cost: $ 160 M Subject: 09 -36C Patch Set - Chrome IOR: 50 bopd Step Unit Operation 1 S Pull 4 -1/2" AVA DWP patch from 8094' MD/ Set Nipple reducer W/ TTP 2 E Run lower packer of patch with element at 8121' MD 3 S Run Snap latch /Upper packer with E -Fire 4 F MIT -T to 2500 psi, LLR all failures 5 SP Pull TTP if MIT -T passes Current Status: Shut -In Injector Max Deviation: 58° @ 9123' and Last Test: RIR: 5000 bwpd BHP: 3350 -psi @ 8800 SS Min. ID: 2.387" @ 8939' (3 -1/2" x 2 -7/8" FL4S LNR XO) Last TD tag: Tag plug @ 9493' MD on 5/13/2009 Last DH Ops: 08/1/2011: TecWeL LDL- Confirm Patch leaking Last H2S: 151 -ppm on 07/19/2004 OBJECTIVE Mitigate TxIA by pulling and resetting a new patch Background: Well 09 -36C was initially completed in September 1995 with 4 -1/2" chrome tubing and 7" L -80 liner. It was completed as a dedicated Lower Romeo producer, but it performed poorly. In September 1995, shortly after the sidetrack, the well developed tubing by Inner Annulus communication through Gas lift mandrel number 6. This was patched with a 4 -1/2" AVA DWP tubing patch set in December 1995. A small frac job of 37K# was placed in December 1995 and the well produced 600 bopd. Zone 3 perforations were shot in September 1997 but the rate did not change. A CIBP was placed at 9175'MD in November 1997 to isolate the Zone 1 and Zone 2 perforations; however this resulted in 100% water -cut production. Also a mud acid stimulation was pumped in August 1998 without any change in rates in addition to several WSO and perforation attempts. Unfortunately, 09 -36C remained uncompetitive and was finally shut -in for low oil production in July 2004. In May 2006 09 -36C was converted to a produced water injector as part of a project to increase water handling ability for FS2 as well as mitigate gas tonguing from the Updip Victor Area. This injector as well as 09-31C and 09 -32 were all converted as Updip Victor Guard Wells. Over 09 -36C Patch Set • • time, the wells were perfed throughout section where offset wells are producing and the injectors became secondary injectors in their patterns. This has led to excessive water injection and production in the northeast corner of DS09 and many shut -in producers. In 2006 an IPROF run showed -60% injection going down past the CIBP into Zone 1. A static tag in 2009 found the plug in the right location. Over the period of April -July, 2011 the well required at least 5 IA bleeds. 09 -36C passed an MIT -IA in June 2011 and PPPOT -T three days later. A TecWel LDL on 08/01/2011 found a small leak existed around currently set patch at 8094' MD. This well seems to have some value in its pattern hence, a patch set to fix TxIA is considered rather than an AA to keep this online. Contact Chidi Igbokwe @ 564 -4795 (W), 206 - 790 -2449 (C) with any questions or comments. Cc w/ att: Well File Patch Spec: 4 -1/2" Snaplatch /Slickstick 40' length, whichever is available. All components 13Cr ** *Ensure all patch assemblies are drifted w/ 2 -7/8" locks (2.313" OD) prior to RIH * ** Slickline: 1. RIH w/ braided line and pull AVA DWP patch at 8094' MD (patch has been in the ground since 1995 and may prove difficult to get out, do not spend more than 2 -days on patch / pull). If patch can't be removed with PRT or other method we may regroup and try coil or chemical cutting it with a -line. 2. RIH with 2 -7/8" profile nipple reducer and TTP, set in SWS Nipple @ 8883' MD E -Line: 3. RIH and correlate to SLB Patch Setting Record dated 16- DEC -1995. 4. Set lower packer element of 4 -1/2" patch w/ the element at 8121' MD per manufacturer's recommendation. RDMO Slickline: 5. RIH w/ Snaplatch and upper packer element 6. Land top patch assembly in snap latch placing top element at 8081' MD. Set w/ E -fire. Fullbore: 7. MIT -T to 2500 psi, obtain LLR if fails. Slickline: 8. Pull TTP from nipple reducer (if MIT -T passes) 09 -36C Patch Set • • TREE= 6-3/8" CM) , WELLHEAD = FMC SAFETY NOTES: ** *CHROMETBG &LNR"** ACTUATOR = AXELSON 09 -36C 'AVA TBG PATCH @ 8094' IS ISOLATING GLM # 6. KB. ELEV = 53.0' BF. ELEV = NA l I KOP 6775' ( l --x1-1 31' H7° X 5 -1/2" X 4 -112 X0, D= 3.958" M ax Angle = 58 @ 9128' 13 -3/8" CSG, 68#. -I 65' �' ` Datum MD = 9326' K -55 , D = 12.415" I 2200' H4 -1 /2" CAM - TRDP -4A TRSSSV, D = 3.812" Datum TVDss = 8800' SS GAS LIFT MANDRELS ST MD 1VD CEV TYFE VLV LTCH PORT DATE 20" CONDUCTOR 91.5#. 1+40, ID = 19 -124" 113' , 1 3454 3454 2 TE -TGPD DMY RK 0 10/30/05 13-3/8" CSG, 72 #, L80, D = 12.347" H 2496' 2 5456 5455 1 TE -TGPD DMY RK 0 10 /30 /05 3 6573 6573 2 TE -TGPD DMY RK 0 04/11/93 4 7060 7050 15 TE -TGPD DMY RK 0 11/13/97 Minimum ID = 2.387" @ 8939' 7596 7564 20 TE -TGPD DMY RK 0 09114/94 3-1/2" X 2 -718" FL4S LNR XO 6 8116 8020 29 TE -TGPD _ *SO - RK 20 10/30/05 1 " ' GLM = BEHIND AVA PATCH I9 -5/8" X 7" BKR TEBACK SLV. D = 7.500° H 8126' -- \ 1 8094' I- 4 -1/2" AVA DWP TBG PATCH I9 -5/8" X 7" BKR "H" PKR D = 6.187' H 8134' I- (SET 12/16/95). ID = 2.441" kr I9 -5/8" X 7" BKR LNR HGR D = 6.375" I 8139 7 17" NSCC XO TO BUTT, D = 6.184" H 8145' I � , • ■ LOUT WINDOW i ' " "I I - 8350' /` /- 1 I 19 -5/8° CSG, 47 #, L80 BUTT, D = 8.681" H 8300' II,- �� i 8795' H 4 -1 /2" PARKER SWS ND, D = 3.813" I 8852' I-14112° ANCHOR SEAL ASSY I ixi i i 4.-- 8853' H 7" X 4 -1 /2" BKR SABL -3 PKR D = 3 .875" I I ' I 8883' I- 4- 1 /2" PARKER SWSNF'.D= 3.813" ^ , I3 -3/4" BKR DEPLOYMENT SLV, D = 3.00" H 8933' I 8873' ELM LOGGED (10/22/95) L 1/2" X 2 -7/8" X0, D= 2.387" H 8939' I I 8979' I - 4-1/2" PARKER SWN f, D= 3.80" (801*D CT & MILLED OUT) 14 -1/2" TBG PC,12 13Cr, .0152 bpf. D = 3.958" I 8991' I 8992' H4 -1/2" WLEG (BB-IND CT) 898 ELMD TT LOGGED 04/26/93 I PERFORATION SUM8MRY REF LOG: BRCS ON 04/06/93 7" MLLOUT WNDOW (09 -36C) 9270' - 9277' I ANGLE AT TOP PERF: 57° @ 9106' Note: Refer to Production DB for historical pert data SIZE SFF NTERVAL Opn /Sqz DATE 1 -9487 -I FISH - BROKEN TEL FINGER I 1- 11/16" 4 9106 -9116 0 01/12/98 • • ,. • • • , t , ••••• 2" 6 9106 -9126 0 11/22/01 ••••••■ 9490' H SET BKRCIBP (07/14/04) I 2 -1/8" 4 9106 - 9126 0 09)27/97 •••••••I ••••••• ` •••••••• 44044 11 9536' 2-718" CEP MLL'D & PUSHED II 2" 6 9296 - 9304 0 03/18/04 1111111 1111 D.H. ON 11/21/00 2 6 9352 - 9368 0 07/13/04 • • • • • �� 2" 6 9376 - 9386 0 07/13/04 ••••••• ` 44 11P 9540 2 -7/8" PORTED PUP I 2" 9410 - 9430 0 07/14/04 • 1111111 11111111 11111111 2 -1/8" 4 9500 - 9515 0 11/05/95 • • 1 • • • • • • • 1 1 1 1 4 i� 2 -1/8" 4 9520 - 9535 0 I ' 10/22/95 / 1 1 1 / 1 / 1 1 1 1 1 / ' 40/ 1111111 11111111 111 /111111111 /1i 1 2 -7/8" LNR 6.5#, L- 80..00579 bpf, D = 2.387" 9545' 1 11111111 17" LNR, 29 #, 13•CR - 80, D = 6.184" I 9532' 11.40.111.04. DATE REV BY COMMENTS DATE REV BY COS PRUDHOE BAY MET 05/25/86 POOL 6 ORIGINAL COMPLETION 11/06/05 KDC/TLH GLV C/O (10/30/05) WELL. 09 -36C 04111193 N2ES SIDETRACK (09 -36A) 05/29/06 DFR/DTM CSG CORRECTIONS (11/24/04) PERMIT No: F 1951140 10/12/94 CTU CTD SDTRK(09.36A)- FAILURE 06 /09/08 PJC DRAWING CORRECTIONS AR No. 50- 029 - 21429 -03 OR/97196 N9FS CTn SDTRACK 1119 -'teC1 07/28/11 KAI / P. in R toll) I onnin SWS NIP 10/22/08 SFr: 1 TK)N R15F 1974' FRI R 37' FR 09 -36C Patch Set • • 07- e 6 PATCH SETTING RECORD AVA DWD 4 1/2" schluniberger 16-DECEMBER-1995 COMPANY ARCO ALASKA, INC. WELL D.S. 9- 36C 7. g FIELD PRUDHOE BAY L BOROUGH NORTH SLOPE STATE ALASKA Other Services: 2 E 5 3 FSL & 37fEL cst \ t " NONE .g AT SURFACE F- API SERIAL NO. SECT. TWP. RANGE 50-029-21429-03 2 10N' 5E Permanent Datum MSL Elev. 0_0 F Elev.: K.B,59.0 F Log Measured From RKB 59.0 F above Perm. Datum D.F.58.0 F Drilling Measured From RKB G.L.21.0 F ". Date 16-DEC-1995 Run No. ONE Depth Driller 9700,0 F Depth Logger (Schl.) Log Interval 8250 F FINAL Top Log Interval 7540.0 F Type Fluid in Hole WATER/DIESEL Salinity NaCI Density Fluid Level Max. %C. Temp. Deviation 57 DEG Logger on Bottom SCE LOO Equip, I Location 8331 - {PRUDHOE BAY F _ , Recorded By BAILEY Witnessed By STEVE WYSOCKI BOREHOLE RECORD Bit Size CASING LINER TUBING COIL TBG , . Depth CASING & TUBING RECORD Size 95:8' 7' 4 1 2 2 7 8° Weight 47 0000 LSF 29.0000 LB F 12 6000 6 5000 LIMF Casing Top-Driller 0.0 F 8126.0 F 31 0 F 8933.0 F Casing Top-Logger 09-36C Patch Set • • 7900 i E _ , iimeniiiiiiinimmo . . r -__SC L vri ` f1 i ____ ._ _ ri Log: SLB patch setting record I Date: 12/16/95 EiMil Pass: Set tie -in strip 8000 El i ° ` tt , EL 1 t .... , t i I ■ m 211111111=1111111111111=1 . use; = = - 111 == iri I * _ 7 .... , ._+__ - _ mom --j mom 1 .. M mown * � , --I- __ __ �. f .. --- m/ 1 - ._ + - *—} 6100 mir-AMM w i Ma 1111=1 e _ .. . .4 ,__ —S 4 4 e rnt k C.CL� - . IIINIIIIIIIIIIIIII 09 -36C Patch Set ' • III F inal Job Report Archer PI Manufacturer. TecWel AS r�cwa` - )ocument no. . LEAK- 2011 - 08-181 Revision 1 Appendices 1.1 Dynamic Log — 4 -1/2" AVA DWP Tubing Patch @ 8,094' MD Leaking. CcL J .....I . 4.— WLD -A 1 ix _..._ .... Olfferertlal Temperature — , _- -_ W wLn-a w _ ___ _._- 1 - - - -.J _ : __ { ..._ -.`. - Temperature' —v.• -- : „.?. WLD C 14■ Ternperature1 4 4 I e 4--LMeSpeed ' -.. j _ _ . r — 4 ' 4 8ob6 r ' : LEAK SIGNATURE GLM46 _______ _ _�._- - 8100 - �, -- — - Patch f r - - -- - - - -- -- J I _.._._ -.. 1 e" i , __.._ . -_ 8200 __._.. i t__..._. I 1 I 16000 CCL -1700 140 Temperature (degF) 160 0 Lute Speed (8/min) - 200 -3 Differential Temperature (degF) 1 20 Temperature (degF) 220 0 WLD-A 70000 0 WLD -B 70000 0 WLD -C 70000 Table Below: Tubing tally description showing proposed packer set depth 12 its 4 -1/2" 13 Cr NSTC Tbg 7614.6' MD- 8086.36' MD 4 -1/2" XO Pup 8086.36' MD- 8095.87 MD 4 -1/2" x 1 -1/2" Merla TGPD w/ Dmy & RK latch #1 8095.87' MD- 8105.31' MD 4 -1/2" XO Pup 8105.31' MD- 8114.97' MD 7 jts, 4 -1/2" 13 Cr NSTC Tbg 8114.97' MD- 8785.08' MD *Lower KB Packer Set Depth * proposed set depth 09 -36C Patch Set • • -., . 09- &cDA 1 -I- -f e Le.r-114\r -- r or , r 1304orn 411 risc 1. . 90 Sncu.ov S99'I. 92 'VIZ N &cr.. xi '3 C • il (ttl I o . i 5 ?SE°. 93 4' -471, 3 iz.5 7..t. . (17 \-{ C. IF14 ‘\ f, ''? 5 ca 979.O2 ... '29g0. q3 7,2_t VOI.0? Z = .ss. 0.i; itc1z 4.*k i.iso Tbe I ‘ 7 ? . 93 '%% 94 ‘ed q973 2-( 1 -0z: ?..(,,..:. r3cv- re.,6* -- 9 .131 Wi?S.4. 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L17(.74, 76,14. 4,0 goS6, ato '4 4 er-Itc, - 1.) - Stri.-15 NS CT-12 9. 5( 7(p.05. o.-I 7&,v4 , Go 76,05,04 - 1 4 z:k 6 — 17 ,T „-.r - Nscr- 15 9.1.z. 7586.04 _ 5 q = - 7 0 .ffq 79g. 0 _. 7b72. 59 -1`tt:'-A-Oz:‘,‘J 0,..,„,/ wK.L.f.•,-.1., u-3 9 c-lo 7059,67 v 70(04 .01 ct , (.5 7050.0Z. 70.59.(pi I L457, (0 6, (c N Sc_7 P 9, 50 (.052z '34 675'12,34 t-1 . xllz.le..44 -76 PD:)-lo....,, R--L0 Ail 4 q 9 , (4z. G)573 , Lit-/ ( 0 52 Z• ` Tubing Tally 09-36C Patch Set • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission I Q LfY 333 West 7 Avenue Anchorage, Alaska 99501 6 a Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09-01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09 -02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09-10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09-11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09-12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09-13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09-14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09-16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09-17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09-19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09-20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09-22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09-23 1980440 50029210667100 2.2 NA 22 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09-25 1840280 50029210830000 3.2 NA 32 NA 23.0 7/8/2010 09-26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover , NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 02 NA 02 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 - 3' 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 102 9/16/2010 09-45 1901150 50029220830000 0.2 NA 02 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover , NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 3Q2011 Not Operable Injector Report Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 3Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip } �R _ , , , • Tom, Jim, Phoebe and Guy, Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly In.1'-e-�ction Report: 09 -36C (PTD #1951140):) Leak found in tubing patch 13 -17 (PTD #1820260): Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000): Identified TxIA communication with leak detect log S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reck: alaska.gov, doa.aoocc.prudhoe.bay( alaska.aov; phoebe.brooksaalaska.aov; tom.maunder..alaska..ov OPERATOR: BP Exploration (Alaska), Inc. Z(zZll, FIELD / UNIT / PAD: Prudhoe Bay / PBU / DS09 f 1 DATE: 07/06/11 `"( OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -36C T pe In'. W ' TVD 8,588' Tubing 700 700 700 700 Interval p P.T.D. 1951140 ''IMII P J 2147 FM 1800 2500 2450 2445 ' P/F P Notes: Under Eval for IA repressuriztion OA 40 160 160 160 2 bbls of fluid to pressure up Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (descnbe in notes) Form 10 -426 (Revised 06/2010) MIT PBU 09 - 36C 07 - 07 - 11 .xls Monthly Injection Report for GPB,MA, Northstar, Milne Point & Endicefor August... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, September 03, 2011 4:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for August 2011 Attachments: AOGCC lnj Report 09- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the August 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 09- 11.zip» Notes on wells: Added to Report: y , "` li P 8 nit None Taken off Re • ort 09 -36C PTD #1951140) Reclassified as Not Operable and added to Quarterly Not Operable Report after LDL identified patch leaking. R -02 (PTD #1781000): Reclassified as Not Operable and added to Quarterly Not Operable Report after MIT -IA failed. L -119 (PTD #2020640): Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressurization noted. L -210 (PTD #2031990): Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressurization noted. W -03 (PTD #1971390): Monitored for IA repressurization reported February, 2011. No repressurization noted. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 9/6/2011 Monthly Injection Report for GPB,PMA, Northstar, Milne Point & Endic1for July 20... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeUIlntegrityCoordinator @bp.com] Sent: Thursday, August 04, 2011 8:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for July 2011 Attachments: AOGCC Inj Report 08- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the July 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 08- 11.zip» O i4: Notes on wells: Added to Report: 09 -36C (PTD #1951140): Under Evaluation for IA repressurization. A - 8 (PTD #19 : Exhibited IA repressurization. Repressurization mitigated after SSSV change out. To be left on Monthly Injection Report for monitoring for 2 months. NS -27 (PTD #2010270): Under Evaluation for IA repressurization. R -02 (PTD #1781000): Under Evaluation for IA repressurization after a UIC bleed Taken off Report: U -10 (PTD #1851970): Successful AOGCC witnessed MIT -IA after tubing patch repair Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 8/8/2011 Well 09 -36C Injection Plot Well: 09-36C o Pressure vs. Rate o TIO Plot p D: 1951140 0 0 0 N • emu' N IA Well Under Eval for slow IA o • • o _ OA repressurization • 0 o a ° o o •►M•Y •• •• M • n °0 � AIWA O .. 4 o •• • L° • Lo • •• • Last 90 days • Last Month [± , _ r 0 2,000 4,000 6,000 8,000 10,000 12,000 2/19/11 5/12/11 8/2/11 10/23/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 08/01/11 3,845 1,491 08/01/11 1,491 950 20 07/31/11 3,018 469 07/31/11 469 950 20 07/30/11 1,929 176 07/30/11 176 400 20 07/29/11 0 -8 07/29/11 0 220 20 07/28/11 0 -8 07/28/11 0 220 20 07/27/11 0 -8 07/27/11 0 220 20 07/26/11 0 -9 07/26/11 0 220 20 07/25/11 0 -9 07/25/11 0 220 20 07/24/11 0 -10 07/24/11 0 220 20 07/23/11 0 -9 07/23/11 0 220 20 • 07/22/11 3,271 596 07/22/1 596 540 220 07/21/11 4,650 783 07/21/11 783 540 220 07/20/11 4,804 789 07/20/11 789 540 220 07/19/11 4,910 784 07/19/11 784 500 220 07/18/11 5,320 808 07/18/11 808 1,200 220 07/17/11 4,859 771 07/17/11 771 1,200 180 07/16/11 4,958 764 07/16/11 764 1,180 120 07/15/11 5,239 761 07/15/11 761 1,180 120 07/14/11 5,299 744 07/14/11 744 1,180 120 07/13/11 4,737 698 07/13/11 698 1,140 80 07/12/11 4,865 685 07/12/11 685 800 20 07/11/11 5,118 645 07/11/11 645 1,100 20 07/10/11 2,213 237 07/10/11 237 650 20 07/09/11 1,081 282 07/08/11 571 650 20 07/08/11 2,987 571 07/07/11 698 650 20 07/07/11 4,999 698 07/06/11 727 1,650 20 07/06/11 5,759 727 07/05/11 696 1,650 20 07/05/11 5,974 696 07/04/11 633 1,350 20 07/04/11 5,153 633 07/03/11 583 1,900 20 07/03/11 4,372 583 07/02/11 249 500 20 07/02/11 2,224 249 07/01/11 0 500 20 NOT OPERABLE: Injector 09 -36C (PTD #1951140) Tubing Patch Leak Identified By L... Page 1 of 2 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Wednesday, August 03, 2011 4:51 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: NOT OPERABLE: Injector 09 -36C (PTD #1951140) Tubing Patch Leak Identified By Leak Detect Log All, Injector 9 -36C (PTD #1951140) was identified as having a leak located at the tubing patch during a Leak Detect Log on 8/1/2011. The well has been secured with kill weight fluid. The well is reclassified as Not Operable pending repair of the tubing patch. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Auk, s tj it Office (907) 659- 5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 m: AK, D &C Well Integrity Coordinator Sent: . nday, July 04, 2011 10:01 PM To: 'Maunde , omas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS - DS Operators; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Da Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; Ki • hitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector 09 -36C #1951140) Slow IA Repressurization All, Injector 09 -36C (PTD #1951140) has exhibited slow IA repr- - riza • while on produced water injection since a bleed on 04/25/2011. The well has had a tubing patch ' - ailed since 19 • . e well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: MIT -IA to 2500 • 2. WIE: Pending re of MIT -IA, evaluate for a leak detect log A TIO - • and wellbore schematic have been included for your reference. 8/4/2011 RE: UNDER EVALUATION: Inje.09 -36C (PTD #1951140) Slow IA R,ssurization Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, July 19, 2011 11:36 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Injector 09 -36C (PTD #1951140) Slow IA Repressurization Attachments: 09 -36C TIO Plot 07- 19- 11.doc Hi Tom, Injector 09 -36C (PTD #1951140) passed an MIT -IA to 2500 psi on 07/06/2011. Our plan is to run a Tecwel LDL in an attempt to find the source of the slow repressurization on the IA. If a leak is not found we will pursue an Administrative Approval. The well will remain on injection as we conduct diagnostics and we will send a follow up email once the Tecwel LDL is complete and results obtained. Attached is an updated TIO and Injection Plot for your reference. «09 -36C TIO Plot 07- 19- 11.doc» Thank you, M ehreen _ (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells TM � ; - Z('�'� Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, July 04, 2011 10:01 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Longden, Kaity Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C) Subject: UNDER EVALUATION: Injector 09 -36C (PTD #1951140) Slow IA Repressurization All, Injector 09 -36C (PTD #1951140) has exhibited slow IA repressurization while on produced water injection since a bleed on 04/25/2011. The well has had a tubing patch installed since 1995. The well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: MIT -IA to 2500 psi 2. WIE: Pending results of MIT -IA, evaluate for a leak detect log 7/19/2011 RE: UNDER EVALUATION: Inje. 09 -36C (PTD #1951140) Slow IA Ressurization Page 2 of 2 A TIO plot and wellbore schematic have been included for your reference. « File: Injector 09 -36C (PTD # 1951140) TIO and Injection Plot.doc » « File: Injector 09 -36C (PTD # 1951140) wellbore schematic.pdf » Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 i 7/19/2011 • Injector 09 -36C (PTD # 1951140) TIO Plot 07 -19 -2011 Wan.% 4.000 - 3000- -0- TN -0- IA 2 • -A OA ODA + -000A ▪ On 1.000 • 04/23/11 04730/11 0507711 05/14.11 0 05/20/11 06/04/11 06/11/11 06/18.111 06/25/11 07/22/11 37 07/16/11 Injector 09 -36C (PTD # 1951140) Injection Plot Web: 0436 1 BOO 9.500 1 700 I/ J � 1 9500 1.600 - 8 6005 1 80 7.500 1,'0. 7000 6.550 1100 - 1100 1 6000 1,000 5.500 E -001411 - - 000 `' / \ / v 5.000 — ; N 3 800 - � 4 -� -OM 4.00D - On 700 3500 603. 000 2500 400 2.000 320 1.500 200 1 000 / 100 • 500 04/23,11 04/30/11 05/01/11 05/14/11 05721/11 05/287/1 06/64711 05/11711 06/16/11 0625/11 07252/11 07/09/11 05;16/15 I ' AOGCC MITIA Forms for 03-36760600), 03-12 (1790580), 03-37 (20990), 04-10 (... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 01, 2010 5:06 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 03-36 (1760600), 03-12 (1790580), 03-37 (2091390), 04-10 (1760420), 04-43 (1940130),04-44 (1940100),09-16 (1770370),09-19 (1770400), 09-31C (1960640), 09-36C (1951140), 09-37 (1940280) Attachments: June 2010 MIT Forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 03-06 (PTD #1760600) 03-12 (PTD #1790580) -enclosed are 2 tests; original test from 6/12 /2010 and retest on 6/29/2010. 03-37 (PTD #2091390) 04-10 (PTD #1760420) 04-43 (PTD #1940130) 04-44 (PTD #1940100) 09-16 (PTD #1770370) 09-19 (PTD #1770400) 09-31 C (PTD #1960640 09-36C PTD #1951140) /~ 09-37 (PTD #1940280) «June 2010 MIT Forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ti 7/2/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov l OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS-09 06/12/10 Jerry Murphy John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-19 Type Inj. W TVD 8,689' Tubing 1,480 1,480 1,480 1,480 Interval 4 P.T.D. 1770400 Type test P Test psi 2172.25 Casing 540 2,280 2,230 2,230 P/F P Notes: MIT-IA to 2300 for 4 year UIC OA 40 90 180 240 Pumped 7.2 bbls MEOH to achieve test psi Well 09-31C Type Inj. W TVD 8,487' Tubing 800 800 800 800 Interval 4 P.T.D. 1960640 Type test P Test psi 2121.75 Casing 440 2,320 2,300 2,300 P/F P Notes: MIT-IA to 2300 psi for 4 year UIC OA 30 30 30 30 Pumped 3.9 bbls of MEOH to achieve test psi Well 09-36C Type Inj. W TVD 8,588' Tubing 1,000 1,000 1,000 1,000 Interval 4 P.T.D. 1951140 Type test P Test psi 2147 Casing 610 2,300 2,260 2,250 P/ P Notes: MIT-IA to 2300 psi for 4 year UIC OA 130 300 300 310 Pumped 7 bbls of MEOH to achieve test psi Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test J~~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 09-19 09-31 09-36 06-12-10.x1s MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~~~ ~~z~ l I~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 15, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-36C PRUDHOE BAY UNIT 09-36C Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv J '~ Comm Well Name: PRUDHOE BAY UNIT 09-36C API Well Number: 50-029-21429-03-00 Inspector Name: John Crisp - Insp Num: mitJCr100614102035 Permit Number: 195-114-0 Inspection Date: 6/12/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 09-36C~TYpe Inj. ~'~ TVD ssas IA 610 > 2300 %- 226o zzso I - - ]951140 ~T eTest sPT i ~-2147 QA P.T.D; _~ YP Test psi i Interval aYRTST p~F P - Tubing - 130 300 I 300 310 looo ! looo looo ~ looo - ~ Notes: '7 bbls meth pumped for test. Tuesday, June 15, 2010 Page 1 of 1 12/11/06 Schlumberger NO. 4070 Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska 011 & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Prudhoe Bay Well Job # Log Description Date BL Color CD V-211 40011188 OH EDIT OF MWD/LWD 11/17/04 2 1 S-213A 40011201 OH EDIT OF MWD/LWD 12/11/04 2 1 DS 09-13 11491394 MEM PROD PROFILE 11/24106 2 14-3OA 11485775 MEM PROD PROFILE 11/21/06 2 DS 09-36C 1149225 INJECTION PROFILE 11/23/06 2 W-12A 11418301 MEM PROD PROFILE 09/10/06 2 Y-29A 11485776 MEM PROD PROFILE 11/25/06 2 NK-43 11414407 PROD PROFILE W/DEFT 10/26/06 2 6-13A 11212899 USIT 11/05/06 1 14-3OA 11485775 SCMT 11122/06 1 DS 02-39L 1 11491395 SCMT 11/25/06 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2~ 1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered DEC 1 3 ZOOt) . Received by: All <; '" Qì\~.' i'\'.~ '\.JI!! I,~ !::+a$,~' An('ih(~~~ ~GA£'\!!~Ü ..:. U.lC- lL10-I/L/ a STATE OF ALASKA _ ALA~ OIL AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS 1 . Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other [] Convert to Inj Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 6/25/2006 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 195-1140 3. Address: P.O. Box 196612 Stratigraphic D Service M 6. API Number: Anchorage, AK 99519-6612 50-029-21429-03-00 7. KB Elevation (ft): 9. Well Name and Number: 53 KB 09-36C 8. Property Designation: 10. Field/Pool(s): ADL-028327 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9545 feet Plugs (measured) 9490, 9536 true vertical 9030.69 feet Junk (measured) 9487 "CAI\I~I¡:;f) PI! ::.'J > . ,..".....' 1,..i \) l.... ¡,' Effective Depth measured 9540 feet true vertical 9026.2 feet Casing Length Size MD TVD Burst Collapse Conductor 85 20" 91.5# H-40 26 - 111 26 - 111 1490 470 Surface 2471 13-3/8" 68#/72# K-55/L 25 - 2496 25 - 2495.97 3450/5380 1950/2670 Production 8276 9-5/8" 47# L-80 24 - 8300 24 - 8195.07 6870 4760 Liner 1144 7" 29# NT -13Cr80 8126 - 9270 8046.24 - 8818.62 8160 7020 Liner 612 2-7/8" 6.5# L-80 8933 - 9545 8634.56 - 9030.69 10570 11160 Perforation depth: Measured depth: 9106 - 9126 9296 - 9304 9352 - 9368 9376 - 9386 9410 - 9430 9500 - 9515 9520 - 9535 True Vertical depth: 8730.73 - 8741.45 8833.3 - 8838.28 8871.52 - 8883.29 8889.27 - 8896.83 8915.42 - 8931.41 8990.62 - 9003.83 9008.28 - 9021.71 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 31 - 8992 Packers and SSSV (type and measured depth) 4-1/2" Cameo TRCF-4A SSV 2200 7" Baker H Packer 8134 4-1/2" Baker SABL-3 Packer 8853 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: R8DMS BFL JUL 27 2006 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 6049 420 869 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory D Development D Service M Daily Report of Well Operations 16. Well Status after proposed work: OilD Gas D WAG 0 GINJ WINJ M 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: 305-361 Contact Sharmaine Vestal P'oled N,me Sh'~';oe V.,,,, ~ k Title Data Mgmt Engr Signat~~ Phone 564-4424 Date 7/27/2006 Form 10-404 Revised 04/2004 Submit Original Only MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Reggv ,;> .;";'. 7/751)( P.I. Supervisor i" t;/!'''l . f- I ~~. " { DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-36C PRUDHOE BA Y UNIT 09-36C \q6-,Wt FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: .,,-:-:~ P.I. Suprv -.J ;-5f2- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 09-36C· API Well Number 50-029-21429-03-00 Inspector Name: Jeff Jones Insp Num: mitlJ060711203313 Permit Number: 195-114-0 Inspection Date: 7/6/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-36C ¡Type Inj. ! w TVD 8588 I IA I 300 I 2300 ! 2245 2230 i r , I I P.T. 1951140 fTypeTest I SPT Test psi 2147 lOA I 480 690 ! 690 690 I ! I : I Interval INITAL P/F P .../ Tubing! 1340 1340 1340 1340 ! I I Notes 4.4 bbls methanol pumped. 1 well house inspected; no exceptions noted. " \-:>'f' -r.:i ",i... Wednesday, July 12,2006 Page 1 of 1 . TREE - 6-3/8" crw WELLHEAD = FMC SAFETY NOTES: ***CHROMETBG & 7" LNR*'* A CTUA TOR = AXELSON 09-36C *AVA TBG PATCH@ 8094' IS ISOLATING KB. ELEV = 53.0' GLM # 6. BF. ELEV = NA KOP- 6775' \ ) I 31' -17" X 5-1/2" X 4-1/2" XO, 10 = 3.958" I Max Angle - 58 @ 9128' Datum MD - 9323' I 2200' -14-1/2" CAM- TRDP-4A TRSSSV, 10 = 3.812" I . I Datum TVDss = 8800' SS ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LTCH PORT DATE ~ ~ 1 3454 3454 2 TE- TGPD DMY RK 0 10/30/05 113-3/8" CSG, 68#, K-55 / 72#, L80, 10 = 12.347" I 2496' 2 5456 5456 1 TE- TGPD DMY RK 0 10/30/05 3 6573 6572 2 TE- TGPD DMY RK 0 04/11/93 U 4 7060 7050 15 TE- TGPD OMY RK 0 11/13/97 Minimum ID = 2.387" @ 8939' 5 7596 7565 20 TE- TGPD DMY RK 0 09/14/94 3-1/2" X 2-7/8" FL4S LNR XO 6 8096 8020 29 TE- TGPD SO RK 20 10/30/05 I 8094' 4-1/2" AVA DWPTBG PATCH I I BAKER TIEBACK SLEEVE, 10 = 7.500" 1- 8126' (SET 12/16/95), 10 = 2.441" 19-5/8" X 7" BKR H PKR, 10 = 6.187" 1- 8134' --~ ~ 19-5/8" X 7" BKR LNR HGR, 10 = 6.375" 1- 8139' 9-5/8" CSG SECTION MILL WINDOW 8300' - 8350' ( 09-36A ) I 9-5/8" CSG. 47#, L80, 10 = 8.681" H 8300' ~ I . I 8795' H 4-1 /2" PA RKER SWS NIP, 10 = 3.813" , U ., 8852' 1-14-1/2" ANCHOR SEAL ASSY I III '-' "-" I 8853' l-i 7" X 4-1/2" BKR SABL-3 PKR, 10 = 3.875" I I . 8883' 1-i4-1/2" PARKER SWS NIP, 10 = 3813" I 13-3/4" BKR DEPLOYMENT SLV, 10 = 3.00" I 8933' . I 13-1/2" X 2-718" XO, 10 = 2,387" I 8939' I I 8979' 4-1/2" PARKER SWN NIP, 10 = 3.80'1 (BEHIND CT & MILLED OUT) I 4-1/2" TBG-PC, 12,6#, 13Cr, .0152 bpf, 10 = 3.958" I 8991' 1 8992' 1-14-1/2" WLEG (BEHIND CT) I I 8982' H ELMO TT LOGGED 04/26/93 I PERFORA TION SUMMARY REF LOG: BHCS ON 04/06/93 7" LNR SIDETRACK WINDOW ANGLEAT TOP PERF: 58 @ 9106' 0 9270' - 9277' (OFF CMT RAMP) Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE ~rH FISH - BROKEN TEL FINGER I 1-11/16" 4 9106-9116 0 01/12/98 2" 6 9106 - 9126 0 11/22/01 ~ 9490' H SET BKR CIBP (07/14/04) 1 2-1/8" 4 9106-9126 0 09/27/97 2" 6 9296 - 9304 0 03/18/04 9536' 2-7/8" CIBP MILL'D & PUSHED I 2" 6 9352 - 9368 0 07/13/04 / DH ON 11/21/00 2" 6 9376 - 9386 0 07/13/04 I 9540' 1-12-7/8" PORTED PUP I 2" 9410 - 9430 0 07/14/04 2-1/8" 4 9500 - 9515 0 11/05/95 ~ 2-1/8" 4 9520 - 9535 0 10/22/95 ~ r J 2-718" LNR, 65#, L-80, .00579 bpf, 10 = 2.387" -i 9545' I I 7" LNR, 29#, 13-CR-80, 10 = 6.184" I 9532' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 04/11/93 ORIGINAL COM PLETION 113-14/0 LDKlKA K ADÆRFS WELL: 09-36C 10/13194 CTD SIDETRACK (09-368) 07/14/04 LDKlKAK SET CIBP ÆRMIT No: ~951140 09109195 CTD SIDETRACK (09-36C) 01/07/02 RN/TP CORRECTIONS 03/25/04 MDClTLH PERFS 07/12/04 RWUKA FISH 11/06/05 KDClTLH GL V C/O (10/30/05) 05/29/06 DFR/OTM CSG CORRECTIONS (11/24/04) API No: 50-029-21429-03 SEC 1, TION, R15E 1874' NSL & 37' WEL BP Exploration (Alaska) @Tiu .~.~,\.if rei Þ æ) :llrüU lb e TìJ' ~ ~ n. fC'I (~ U1J U W lbl¡-ü æJ e f{;\ Lr.J FRANK H. MURKOWSKI, GOVERNOR A"~ASIiA OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Victoria Imeh Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU 09-36C Sundry Number: 305-361 8CANNEU DEC 162005 Dear Ms. Imeh: 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. Please provide at least twenty-four (24) hours 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 '1 day of December, 2005 Enc!. 1. Type of Request: c;p:¡. I]; 4,/ W f) ( _ STATE OF ALASKA iHl"5.2..171 AL~ OIL AND GAS CONSERVATION COM SIÔN S APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: FtfÉ~E'vEõS DEC 0 6 2005 Abandon Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: Suspend Repair well D Pull Tubing D Alaska Oil & Gas Cons. Waiver nchorage Other .¡ Stimulate D Time Extension D Revised document Re-enter Suspended Well D Convert to Injector 5. Permit to Drill Number: 'on Development Stratigraphic [] D Service Exploratory D D .,..' 6. API Number: 50-029-21429-03-00 !!(, P.O. Box 196612 Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 53 KB 9. Well Name and Number: 09-36C 8. Property Designation: 10. Field/Pools(s): ADL-028327 Prudhoe Bay Field/Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9545 9030.69 9536 9022.61 9490, 9536 9487 Casing Length Size MD TVD Burst Collapse Structural Perforation Depth MD (ft): 9106-9535 Packers and SSSV Type: Perforation Depth TVD (ft): 8730.73-9021.71 Tubing Size: 4-1/2" 12.6# 111 111 1490 470 2496 2496 3450 1950 8300 8195 6870 4750 9270 8819 8160 7020 9545 9031 10570 11160 Tubing Grade: Tubing MD (ft): 13CR80 8992 2200;8136;8853 Conductor Surface Production Liner Liner 85 20" 91.5# H-40 57 13-3/8" 72# L-80 8276 9-5/8" 47# L-80 1144 7" 29# NT-13CR80 6122-7/8" 6.5# L-80 4-112" CamcoTRCF-4A SSV; 7" Baker H Packer; 4-1/2" Baker Sabl 3 Packer 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: .¡ 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: 12/20/2005 Oil D Gas D Plugged D WAG D GINJ D WINJ [] Service [] 16. Verbal Approval: Commission Representative: Date: Abandoned WDSPL D D 17. I hereby cert Printed Name Signature that the foregoing is true and correct to the best of my knowledge. Contact Vi toria Imeh Title Production Engineer Prepared by Sharmaine Vestal 564-4424 Victoria Imeh Phone Date 12/5/2005 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: :5Jç:. Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D '-lctv'Ít.U-tt:.Z . ~ ~f y(J tlB- J. Other: PM' t° ltA:-c 7J5. 4-12. Lb)) f£U¥.W ck-r~ RBDMS 8FL DEC 0 7 2005 COMMISSIONER APPROVED BY THE COMMISSION -of" Form 10-403 Revised 07/2005 n ",..,j' AL Submit in Duplicate e e bp o BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 November 17, 2005 Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Application for conversion to injection service: DS 9-36C Dear Mr Aubert: Enclosed is an Application for Sundry Approval to convert DS producer 9-36C to injection service. The following supporting documentation is included for your review: · Application for Sundry Approval · Map showing wells within ~ mile radius · Cement bond log (SCMT) · Wellbore schematic · Conversion procedure Please do not hesitate to call if you require additional information. S¡dY, Victoria Imeh East Waterflood Production Engineer 564-5233 o .. c n III r I n p e e I ~ i ì I I ! j Company: t f ¡ ! , Schlumberger BP EXPLORATION (ALASKA) Well: Field: ;,j ':1E D.S.09-36C PRUDHOE BAY I \,. , Borough: NORTH SLOPE State: ALASKA I· t SUM CEMENT MAPPING TOOL , I ~ I ...J ! W ~ W/GRADIO MEASUREMENT i I..L ~ <0 ~ 06-NOV-2005 0 ,...: 2 . !w >- (') 0 KB. 53 ft < ( cð ~ 1874.03' FSL & 37.06' FEL Elev.: e 00 ...J Ü SURFACE LOCATION G.L 22ft en 2 w I..L CD 9 r¡n 0 (v) (') 0 D,F. 53ft . r!~ :r: 0 en a.. ~ a .¢ 0 >< !a: :> en w 9 Permanent Datum: MSL Elev.: Oft 10 ..... a: (X) 0 a... 12 a... ,... 00 Log Measured From: RKB 55.0 ft above Perm. Datum I,.. >- Drilling Measured From: RKB iTh c c 0 co II a ~ Q. '0 E API Serial No. Section Township Range -i ,'- Qj ã5 0 .3 0 \00 it ~ Ü 50-029-21429-03 1 10N 15E ~ LoQQinQ Date 6-Nov-2005 I, Run Number ONE ~' " Depth Driller 9487 ft , Schlumberger Depth 9484 ft j Bottom Log Interval 9484 ft .. Top Log Interval 8900 ft 1 Casing Fluid Type 1 % KCL , Salinity , Density 8.7 Ibm/gal Fluid Level BIT/CASING/TUBING STRING Bit Size 4.500 in . ,- From 9270 ft It II To 9545 ft ~ Casing!Tubing Size 2.875 in ,,- I Weight 6.5 Ibm/ft ,[ Grade L-80 From 8939 ft To 9545 ft Maximum Recorded Temperatures 154 degF I I Logger On Bottom I Time 6-Nov-2005 I 19:00 I Unit Number I Location 2145 I PRUDHOE BAY I Recorded By J. WIBLE , Witnessed Bv J. BOYLES ,. ) .'"1 ~~~:: . ~''J.I1. · I · I · · , I , · , ¡ , J . , · · , I , , · I · · , , · · 9éoo , · · , , · · I , · , · , · , 1 , , , , , It,p. PLl~ ~ 9~ · · · , I , I , · · · · · , , , · · · , · , , · , · · - ~ -... .... I -- 4=, ~ ...- " I' '" .... ~ 'I \ """I -. r ,.... ..J ...- - ..... rr - { '- ~ -- - '....-- - "- ..... "- .-' :y .... -. "/ ..; ~ / " - ~ - - , '" - .... ",-:;:;;0-- ... .L ..... .......-, ,} ... ..;. ..... "-- '" ...... \ ~ ... } -....: -- - ,/ ... .... - ) rl . tit' '- ::.- ..... "",--s.'- !- ... v ,-_ " - " I .... ~ ,., L......... II!:: ;,.- / ~ - " " \ { T ..... .....- - ( '\,C' .,., ,. ~ 7 - ...... . .;. l .-.='" '- ....: .:- "" r_ -> -~ --- " - _...; t' -.. ,- ¡,."" / I --' - ~ ~ ~ "- /' "- '- ~ ~ - r-- -, . a -- - - - '';'' ~ - );: "- ...... TOP OF CEMENT-8948' III!U'HUHlHH 105 MV FREE PIPE '~ {THEORETICAL TRANSIT TIME , - ,,<~~~I';.;.i~_ \ -_~~c" _ -- '\ ~ - i..- ... ;'.....1 JIØ' - - !!o.. - '" '7 ...... r ....... ~ 7 ~ " .... - --' .. ,- /' - /' - T ... -....;:-- ;;"'- .. ~ - -.. ..- -- '. ~I/ lll. ..: - ,- , .. -. .. c::. ..- .. '-;.- ), T S- ;:7 ~ ., -- -- .--- . - ~ .... .... .. c .. ..- .. ,,-:' ::: ~.;;; ::::: ".:..;: :v·':i ,~.: r:::: ".:. N. -;;r-'-" ;:., . · ------- I . _______ · ------- II . _______ · ------- · ------- · ------- t1. . _______ ------ ------ ~ ------- ~.... -!!!!---- -PIII----- , . ,- , " -- I" 1_ . i -' . - ." . -. f/ ..' . -. " ..' - ~ ... . : j .. _pO .",",...' , ! ,~ : ¡ , ., ," ' ,. :,;:; j, t ,', ',:' : ::, 1 , " . , " : : _I· '. , i : , : . , ,. :- -, " ,"'~~;-~'.": ' ,!!,),i_in.i"~ .,=" , , : "1 . , ., ,i . ¡ . . ( . bp ,\tAt/. ..~~ ~~. .~~ ~. .",¡,- e e To: J, Bixby/D. Cismoski Date: October 10, 2005 GPB Well Ops Team Leaders PECT: PBD09WL36-M From: Vickie Imeh Production Engineer lOR: 300 Subject: 9-36C - Conversion to Injection Est. Cost: $1.75M 1 S Dummy GL Vs 2 F AOGCC to witness MIT-IA to 2500 psi Current Status: Max Deviation: Min.ID: Last TD Tag: Last Downhole OP: Latest H2S Value: L TSI, Converting to injection 58 degrees @ 9128' md 2,387" LNR XO @ 8939' md 07/15/2004 07/15/2004 - Additional perfs 151 ppm - 7/19/2004 We1l9-36C was initially completed in September 1995 as a dedicated Lower Romeo producer. But it performed poorly. A small fracture of 37K# was placed in December 1995, and the well produced 600 bopd. Zone 3 perforations were shot in September 1997 but the rate did not change. A CIBP was placed at 9175'MD in November 1997 to isolate the Zone 1 and Zone 2 perforations; however this resulted in 100% water-cut production. Also a mud acid stimulation was pumped in August 1998 without any change in rates in addition to several WSO and perforation attempts. Unfortunately, 9- 36C remained uncompetitive and was finally shut-in for low oil production in July 2004, 9-36C is currently being converted to a water injector pending completion of surface conversion. It is hoped that the actual surface conversion will be completed by 4Q of this year. This program requests well preparation and MITIA to confirm integrity in inner annulus. 9-36 is ready for injection as soon as the IA test is completed, and appropriate state approval has been obtained. Contacts Victoria Imeh Office 564-5233 Cell 748-4961 Home 748-4961 cc: w/a: Well File Victoria Imeh TREE - 6-3/8" Cr-N WELLHEAD = FMC SAFETY NOTES: '''CI-ROM ETOO & 7" LNR'" ACTl.IA.TOR = AXELSON 09-36C 'AVA TOO PATCH@ 8094'15 ISOLATING KB. ELEV = 53.0' GLM # 6. BF. ELEV = NA KOP- 6775 \ ) I 31' 7" X 5-1/2" X 4-1/2" XO, ID = 3.958" Max Ange - 58 @ 9128' Datum MD = 9323' 2200' 1- 4-112" CAM- TRDP-4A TRSSSV, D - 3.812" Datum TVDss - 8800' SS .. ~ GA S L IFf MIl. l[)RELS ST MD lVD DEV TYPE VLV LTCH PORT D6. TE ~ ~ 1 3454 3454 2 TE-TGFO DOME ~ 16 12/08/97 113-3/8" CSG, 72#, LBO, ID = 12.347" 2496' 2 5456 5456 1 TE-TGFO 810 ~ 24 12/08/97 3 6573 6572 2 TE-TGFO OJ ~ 0 04/11/93 Minimum ID = 2.387" @ 8939' I U 4 7060 7050 15 TE-TGFO OJ ~ 0 11/13/97 5 7596 7565 20 TE-TGFO OJ ~ 0 09114/94 3-1/2" X 2-7/8" FL4S LN R XO 6 8096 8020 29 TE-TGFO 810 ~ 20 04/12/93 I 8094' 4-112" AVA DWP1BG PATCH I I BAKER TIEBACK SLEEVE, ID = 7.500" I- 8126' (SET 12/16/95), ID = 2.441" 9-5I8" X 7" BKR HPKR,ID =6.187" 1- 8134' --~ ~ 19-518" X 7" BKR LNRHGR, D =6.375" 1- 8139' 9-5/8" CSG SECTION MLL WNDON 8300' - 8350' (09-36A) 19-518" CSG, 47#, L80, ID - 8.681" H 8300' r- - . I 8795' 1- 4-1 12" PA~ERSWS NlP,ID -3.813" J ì 8852' 1-14-112" ANQ-IOR SEAL ASSY II "'-' 8853' I- 7" X 4-1/2" BKR SABL-3 PKR, ID = 3.875" I I I 8883' 4-112" PA~ERSWS NlP,ID - 3.813" I 13-3/4" BKRDEPlOYIvENT SLV, ID =3.00" 8933' 13-1/2" X 2-7/8" XO, ID = 2.387" 1 8939' /' íé>L ~q49 8979' 4-112" PA~ERSWN t\lP,ID = 3.80" (BB-il l[) CT & MILLED OUT) 4-1/2"1BG-PC, 12.6#, 13Cr, .0152 bpf,lD = 3.958" 8991' 8992' 1-14-112" WLB3 (BEHlNDCl) I 8982' H ELMD TT LOGGED 04/26/93 I PffiFORA TION SUfv1\i1ARY REF LOG: BHCS ON 04/06/93 7" Lt'oR SIDETRACK WNDON ANGLE AT TOP PERF: 58 @ 9106' ] 9270' - 9277' (OFF (}.,1TRA~) NJte: Refer to Production DB for historical perf data SI1:E SPF INTER\! AL OpnlSqz D6. TE ~~ ~~.~ FISH - BRa<EN TEL RNGER 1 1-11/16" 4 9106-9116 0 01/12/98 2" 6 9106 - 9126 0 11/22/01 9490' H SET BKR ClBP(07/14/04) 2-1/8" 4 9106 - 9126 0 09/27/97 2" 6 9296 - 9304 0 03/18/04 ," 9536' JÎ~-7/8" ClBPMILL'D& RJSHED 2" 6 9352 - 9368 0 07/13/04 / DH ON 11/21/00 I 2" 6 9376 - 9386 0 07/13/04 I 9540' 1"12-7/8" PORTS) RJP 2" ^ 9410 -9430 0 07/14/04 2-1/8" 4 9500 - 9515 0 11/05195 ~ 2-1/8" 4 9520 - 9535 0 10/22/95 Y / I 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID - 2.387" 9545' 1 17" LNR, 29#, 13-CR-80, ID = 6.184" 9532' I D6.TE REV BY COMv1ENTS DATE REV BY COMIvENTS PRUDHOE BAY UNIT 04/11193 ORIGINAL COM PLETION /13-14/0< LDK/KAK AŒ'ffiFS WELL: 09-36C 10/13194 CTD SIDETRACK (09-36B) 07/14/04 LDK/KAK SET ClBP PffiMrr NJ: 1951140 09K19195 CTD SIDETRACK (09-36C) AA No: 50-029-21429-03 01Kl7102 RN/W CORRECTONS SEC 1, TION, R15E 1874' NSL & 37' WEL 03125104 MOC/1lH PERFS 07/12104 RWLlKA K FISH BP Exploration (Alaska) e e e e bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 December 1, 2005 Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. ¡th Avenue, Suite 100 Anchorage, AK 99501 RE: Request for variance in packer depth for conversion to injection: DS 9-36C Dear Mr Aubert: Following an application for sundry approval to convert DS 9-36C producer to injection service, this is a request for variance in packer placement depth requirement. This is in order to meet the requirement as per 20 MC 25.4128 which states that a packer must be placed within 200 feet measured depth above the top of the perforation, unless the commission approves a different placement depth as is considered appropriate given the thickness and depth of the confining zone. DS 9-36C currently has a packer 253 feet above the top of injection zone. Thank you for your consideration and please do not hesitate to call if you require additional information. Sincerely, Victoria Imeh East Waterflood Production Engineer 564-5233 7000 5C(XJ ( !±lId) ( !±lId) ( I\IbfId ) (M) - fun Of Prtd ( IIIW ) ...........\J'IJ;itf!l'OJI:(%) Gas I 01 Ratio ( 1\IbfI!±I ) &xJ 100 . ..I &J 10. . 5 0.5 0.1 1995 95 97 95 99 2000 01 02 03 04 05 Dáe e e MECHANI CAL INTEGRITY REl'ORT' ...... 5?UD DA!E:: Q./4/Qr:; ~IG REL~~S~: q/~/qç- OPER & FIELD E P pe fÁ ì-:-:ELL NUMBER 0 q ,.. S&L:.. ¡qt;--1/4 :'-loi::g: 711 2,1/¡" Shoe: qS4¿; MD qD~1 4 // II . ( 2 Packer JO¡ql . HI) TD: ~}{f).. 90 ~ I TVD i PBTD: 95 ~(p MD 902"5 TVD ld/¡Jow ..s.àee: q 270 HD TVD¡ DV: MD ·TV'U :ri!;.LL DATA Casing: ,;".:...:;er: TVD¡ :CP: -N~ ~ HD Rio ~ç :7D TVDj Set at ¡f~-; to qç~ç- .'. /).'/,11 ::ole Size ~ ' L1 ""1' II anå ¡ " Perf's 9/00> :-:ECr.Þ~'r!:C;'.l... INTEGRITY - PART ¡ 1 Annulus Press Test: ~p 15 m~n 30 min COW!!lents: flirT }dõvJ ~ J ' ",- ~ CHÞ..NI CAL INTEGRITY - PART ¡ 2 Cement: Volumes :'. Þ-.mt. Liner to hbl5 Csg i DV C~t ~ol to cover per=,S 7 kJlol l:" p u\t.t--/ Y-µ·V ~cc~ + ~ o9!J ~i.u(..~, 1 Theore tical Toe {f ~ 4 I Cement Bond Log (Yes or No) 0/ CBL ~valuation. zone above perfs 1:'0.A/ '1010', ; In AOGCC File . vr AcIøí~:t( ~'Y\ d-/v~cJ 11ft' ~é t".hJ Proåuc..tion Log: Type Evaluati.on .. . ¡ 1 ì CONC;LUSIONS: ? ar; : 1: ~'lr:T (~7/'"A ~tJ", ' . ?ar:: ¡Z, 1~ I\~~"b ~Jt'J~L¿Ð{' _~ <.lA.b),l;¡l~¿CM.T. 0- ~/?- ,~ C t!M.AA{<-{ IHr ~f,.t;ì - ~/", ~.f¡(AUA..~ ctI¡?J.1NÇ4A. . _ .Wút\-- Ivll {2Æ)))""- . ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 2. Operator Name; 3. Address: Repair Well 0 Pull TubingO Operation Shutdown 0 Stimulate 0 OtherO WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 195-1140 6. API Number 50-029-21429-03-00 PluQ PerforationslK! Perforate New Pool D Perforate IKJ 4. Current Well Class: Development [!] BP Exploration (Alaska), Inc. 53.00 8. Property Designation: ADL-0028327 11. Present Well Condition Summary: Total Depth measured 9545 feet true vertical 9030.7 feet Effective Depth measured 9490 feet true vertical 8981.9 feet P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Casing Conductor Liner Liner Production Surface Surface Length 85 1144 612 8276 57 2441 Perforation depth: ExploratoryD StratigraphicD ServiceD 9. Well Name and Number: 09-36C 10. FieldlPool(s): Prudhoe Bay Field / Prudhoe 011 Pool Plugs (measured) Junk (measured) 9490 9536,9509 Size 20" 91.5# H-40 7" 29# NT-13Cr80 2-7/8" 6.5# L-SO 9-5/8" 47# L-SO 13-3/8" 68# K-55 13-3/8" 72# L-80 MD TVD Burst Collapse 26 111 26.0 - 111.0 1490 470 8126 - 9270 8046.2 - 8818.6 8160 7020 8933 - 9545 8634.6 - 9030.7 10570 11160 24 - 8300 24.0 - 8195.1 6870 4760 25 82 25.0 - 82.0 3450 1950 82 - 2523 82.0 - 2523.0 4930 2670 Measured depth: 9106 - 9116,9116 - 9126,9296 - 9304, 9352 - 9368,9376 - 9386,9410 - 9430 True vertical depth: 8730.73 - 8736.1,8736.1 - 8741.45,8833.3 - 8838.28,8871.52 - 8883.29, 8889.27 - 8896.83, 8RECI:ivE 0 Tubing ( size, grade, and measured depth): 7" 26# L-SO @ 22 31 4-112" 12.6# 13Cr80 @ 31 8992 SEP 1 5 2004 Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-3 Packer 4-1/2" Cameo TRCF-4A SSV 7" Baker H Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0.4 6544 2000 0.4 6704 2000 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron }j~ r~. 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations. Signature Form 10-404 Revised 4/2004 @ 8853 @ 2200 @ 8134 Alaska Oil & Gas Cons. Commission Anchorage Oil-Bbl 21 23 Tubing Pressure 343 305 ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Development ŒI ServiceD Title Production Technical Assistant Phone 564-4657 Date 9/14/04 ~~!GINAL SEP 1 5 20U4 RBDMS BFL ~ ~ 09-36C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/11/04 ***WELL SHUT-IN UPON ARRIVAL*** ( PRE-ADPERF-CIBP) DRIFTED WITH 2.25" CENT., 2" DUMMY GUN AND T.E.L., AND SAMPLE BAILER. TAGGED BOTTOM @9,475' SLM. (T.E.L. FINGER STILL IN HOLE LOST @8,056' SLM) RDM 07/12/04 ***WELL WAS SHUT-IN UPON ARRIVAL***. RAN 2.25" CENT. AND 2.25" LIB. SAT DOWN @8,923' SLM. RAN 2.34" CENT. AND POCKET POKER. (WENT RIGHT THROUGH PATCH AND DEPLOYMENT SLV) DRIFTED TO 8,955' SLM NO PROBLEM. RAN 2.36" MAGNET AND RETRIEVED APPROX. 1/3 OF BOTTOM PORTION OF FINGER. (SAT DOWN @9,487' SLM, AND UNABLE TO WORK PAST) RAN 2.36" MAGNET AGAIN AND ONLY RETRIEVED SMALL METAL FRAGMENTS. (SAT DOWN @9,487' SLM) RAN 2.34" CENT. AND 2.25" LIB. HAD HARD TIME GETTING THROUGH TOP OF PATCH. SAT DOWN @9,487' SLM. LAY DOWN EQUIPMENT FOR THE NIGHT.. ***LEFT WELL SHUT-IN*** 07/13/04 T/I/0=1950/1950/0. TEMP=SI. TBG FL AT 6090' (326 BBLS). FOR ElL. 07/13/04 ***WELL SHUT-IN UPON ARRIVAU SSV STROKED OUT*** MAKE DRIFT RUN TO TOP OF PATCH WITH 3.75" LIB @8,069' SLM. CLEAN MARKS OF TOP OF PATCH. MAKE DRIFT RUN WITH 2.34" CENT., 2.25" LIB. MADE IT THROUGH TO 07/14/04 Perforate 9410'-9430' 6 SPF 07/14/04 SET CIBP @ 9500' 07/15/04 PERFORATED 9376'-9386' AND 9352'-9368' WITH 2" POWERJET 6 SPF, PENE 18.6", EH 0.20", GMS 6.5. CORRELATED TO SWS PERF RECORD DATED 10-22-95. FLUIDS PUMPED BBLS I No Fluids Pumoed 0 I TOTAL Page 1 ~ TREE = 6-318" CrN W8...LHEAO - FMC ACTUA. TOR = AX8...SON KB. ELEV = 53.0' BE ELEV - NA KOP- 6775' Max Angle = 58 @ 9128' Datum MO = 9323' OatumTVOss = 8800' SS 13-3/8" CSG, 72#, LBO, 10 = 12.347" Minimum ID = 2.387" @ 8939' 3-1/2" X 2-7/8" FL4S LNR XO BAKER TIEBACK SLEEVE, 10 = 7.500" 9-518" X 7" BKR H PKR, 10 = 6.187" 9-518" X 7" BKR LNR HGR, D = 6.375" 8126' 8134' 8139' 8300' 19-518" CSG, 47#, L80, 10 = 8.681" H r- 3-1/2" X 2- 7/f!' XO, 10 = 2.387" 4-1/2" TBG-PC, 12.6#, 13Cr, .0152 bpf, 10 = 3.95f!' 8991' PERFORATION SUMMARY REF LOG: BHCS ON 04/06/93 ANGLE AT TOP PERF: 58 @ 9106' f\bte: Refer to Production OB for historical perf data SIZE SPF INTERV AL OpnlSqz D<\TE 1-11/16" 4 9106 - 9116 0 01/12/98 'Z' 6 9106 - 9126 0 11/22/01 2-1/8" 4 9106 - 9126 0 09127/97 'Z' 6 9296 - 9304 0 03118/04 'Z' 6 9352 - 9368 0 07113104 'Z' 6 9376 - 9386 0 07113104 'Z' ^ 9410 - 9430 0 07/14/04 2-1/8" 4 9500 - 9515 0 11/05195 2-118" 4 9520 - 9535 0 10/22/95 7" LNR. 29#, 13-CR-80, 10 = 6.184" 9532' 09-36C 31' 2200' ST MO lVO 1 3454 3454 2 5456 5456 3 6573 6572 4 7060 7050 5 7596 7565 6 8096 8020 8094' ~ SAFErY NOTES: *"CHROM ETOO & 7" LNR'** *AVA TOO PATCH@ 8094'15 ISOLATING GLM # 6. 7" X 5-1/2" X 4-lI'Z' XO, 10 = 3.958" 4-112" rAM- TRDP-4A TRSSSV, D = 3.812" GAS LIFT M<\NDR8...S OBI TYPE VLV LTCH POR 2 TE-TGFÐ OOME R< 16 1 TE-TGFÐ SlO R< 24 2 TE-TGFÐ OJ R< 0 15 TE-TGFÐ OJ R< 0 20 TE-TGFÐ OJ R< 0 29 TE-TGFÐ SlO R< 20 D<\ TE 12/08/97 12/08/97 04/11/93 11/13197 09114/94 04/12/93 4-112" AVA OWPTBGPATCH (SET 12/16/95), 10 = 2.441" 9-5/8" CSG SECTION MLL WNOOW 8300' - 8350' (09-36A) 8853' 8883' 8979' 8992' 8982' 4-112" R\R<ERSWS t\lP,IO =3.813" 4-112" R\R<ERSWN t\lP,IO = 3.80" (BB-IIND CT & MILL EO OUT) 4-112" WLB3 (BEHNOC1) H ELMO TT LOGGEO 04/26/93 1 7" LNR SlOErRACK WNOOW 9270' - 9277' (OFF GMT RA MP) D<\ TE RBI BY COMMENTS OATE REV BY COMMENTS 04111193 ORIGINAL COMPLErION 113-14/0. La</KAK AœERFS 10113194 CTD SIDETRACK (09-36B) 07/14/04 LOOKAK SEI" OBP 09109195 CTD SIDETRACK (09-36C) OHJ7tU2 RNITP CORREeTONS 03125iU4 MDCITLH PERFS 07/12iU4 RWL/KAK FISH 2- 718" PORTED RJP PRUDHOE BAY UNIT WELL: 09-36C PERMIT f\b: 1951140 AA No: 5O-029-21429-{)3 SEe 1, TION, R15E 1874' NSL & 37' WEL BP Exploration (Alas ka) .. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 2. Operator Name: Suspend 0 RepairWellD Pull TubingD Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate ŒI WaiverD Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 195-1140 OtherD BP Exploration (Alaska), Inc. Development [!] Stratigraphic D 9. Well Name and Number: 09-36C 10. FieldlPool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD 6. API Number 50~29-21429~3~0 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 53.00 8. Property Designation: ADL~028327 11. Present Well Condition Summary: Total Depth measured 9545 feet Effective Depth feet Plugs (measured) Junk (measured) None true vertical 9030.7 feet measured 9545 9536 true vertical 9030.7 feet Casing Length Size MD TVD Burst Collapse Conductor 85 20" 91.5# H-40 26 111 26.0 . 111.0 1490 470 Liner 1144 7" 29# NT-13Cr80 8126 - 9270 8046.2 - 8818.6 8160 7020 Liner 612 2-7/8" 6.5# L-80 8933 - 9545 8634.6 - 9030.7 10570 11160 Production 8276 9-5/8" 47# L-80 24 - 8300 24.0 - 8195.1 6870 4760 Surface 57 13-3/8" 68# K-55 25 82 25.0 - 82.0 3450 1950 Surface 2441 13-3/8" 72# L-80 82 - 2523 82.0 - 2523.0 4930 2670 Perforation deDth: Measured depth: 9106 - 9116,9116 - 9126,9296 - 9304,9500 - 9515,9520 - 9535 True vertical depth: 8730.73 - 8736.1,8736.1 - 8741.45, 8833.3 - 8838.28,8990.62 - 9003.83,9008.28 - 9021.'RECE IVE 0 Tubing (size, grade, and measured depth): 7" 26# L-80 @ 22 31 APR Q 1 4-1/2" 12.6# 13Cr80 @ 31 8992 ~ 2004 Packers & sssv (type & measured depth): 4-1/2" Baker SABL-3 Packer @ 8853 Alaska Oil & G 4-1/2" Camco TRCF-4A SSV @ 2200 as Cons. (;ommiss;on 7" Baker H Packer @ 8134 Anchor:tge 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Me! Water-Bbl Casing Pressure 0.9 109 1815 13 33 0.6 5595 0 Tubing Pressure 451 341 Prior to well operation: Subsequent to operation: Oil-Bbl 171 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D Oil[!] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. ISUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Daily Report of Well Operations ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron l:1~ ~ Signature Phone 564-4657 Date 4/14/04 Form 10-404 Revised 12/2003 'f3\ßf»¡~~~ '~Fl Oq,r-,\NAL IAVOOJ <R" ~ <':\1'~,Ç," ,!'f"f\~ é- ¿ ~>;" ... 09-36C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/16/04 DRIFT WITH 2" DUMMY GUN TO 9505' (SLM) PAST TARGET DEPTH OF 9310'. 03/18/04 Perforate 9296'-9304' 6 SPF FLUIDS PUMPED BBlS No Fluids Pumped 0 ITOT Al Page 1 " . TREE = 6-3I8"CIW WB.LHEAD = FMC A CTl.IA. TOR = AXB.SON KB. ELEV = 53.0' BF. ELEV = NA KOP = 6775' Max Ange = 58 @ 9128' DatumMD= 9323' Datum TVDss = 8800' SS 113-3/8" CSG, 72#, L80, ID = 12.347" H Minimum ID = 2.387" @ 8939' 3-1/2" X 2-7/8" FL4S LN R XO BAKERTlæACKSLŒVE, ID=7.500" H 19-518" X 7" BKR H PKR, ID = 6.187" H 19-518" X 7" BKR LNR HGR, D = 6.375" H 19-5/8" CSG, 47#, L80, ID = 8.681" H 3-3I4"BKRD8='LOYMENTSLV,ID=3.00" H 13-1/2"x2-7'f!:'XO,'D=2.387" H 14-1/2" mG-pc, 12.6#, 13Cr, .0152 bpf, ID = 3.958" H 2496' r--JI 8126' I l 8134' I X 8139' ~ 8300' -- 8933' 1 8939' 1 8991' 1 PERFORATION SU\1MA. RY REF LOG: BHCS ON 04/06193 ANGLE AT TOP ÆRF: 58 @ 9106' IIbte: Refer to A"oduetbn œ for historieal perf data SIZE SPF INTERVAL OpnlSqz I)ð. TE 1-11/16" 4 9106 -9116 0 01/12/98 2" 6 9106-9126 0 11/22¡{)1 2-118" 4 9106-9126 0 09/27/97 2" 6 9296 - 9304 0 03/18104 2-118" 4 9500-9515 0 11105/95 2-118" 4 9520-9535 0 10/22/95 17" LNR, 29#, 13-CR-80, ID = 6.184" H D<\TE 04/11193 10/13194 09109195 01107102 03/25104 COMMENTS ORIGINAL COMPLErION CTD SIDETRACK (09-36B) CTD SIDETRACK (09-36C) RN/lP CORREeTONS MDC/TLH PERFS RBI BY 9532' DATE 09-~,~C \ ) . ---'= J ~ u r SAFErY NOTES: ."CI-ROM ETBG & 7" LNR'** .AVA TBG PATCH@ 8094'15 ISOLATING GLM # 6. 31' H7"X5-1/2"X4-1/2"XO,ID=3.958" 1 2200' H4-1/2" CAM-TRDP-4A TRSSSV, 0=3.812" I GAS LIFT MA.NDRB.S DB! lYPE VLV LTCH PORT 2 TE-TGAJ DOME RK 16 1 TE-TGAJ SlO RK 24 2 TE-TGAJ DJ RK 0 15 TE-TGAJ DJ RK 0 20 TE-TGAJ DJ RK 0 29 TE-TGAJ SlO RK 20 ST MD lVD ,¡, 1 3454 3454 . 2 5456 5456 3 6573 6572 4 7060 7050 5 7596 7565 6 8096 8020 I)ð. TE 12108197 12108197 04/11/93 11/13197 09/14/94 04/12193 I ~ 8094' H4-1/2" AVA DWPmGPATCH I (SET12116195),ID= 2.441" 9-5/8" CSG SECflON MLL WNDON 8300' - 8350' (09-36A) 8795' H4-1/2" PARKERSWS NP, ID =3.813" 1 8852' H4-1/2" ANŒiORSE'ALASSY 1 8853' H7"X4-1/2"BKRSABL-3PKR,ID=3.875" I 8883' H4-1/2" PARKERSWS NP, ID =3.813" I 8979' H4-1/2" PARKERSWN NP, ID =3.80" I I (BB-IIND cr & MILLED OUT) 8992' H4-112" WLEG (BEHNDCl) 1 8982' t-l ELMD TT LOGGED 04/26/93 1 REV BY 7" LNRSIŒTRAO< WINDOW 9270'-9277' (OFFCMTRAMP) H2-718" OBPMILL'D& FUSHED I ID.H. ON 11/21/00 9540' H2-7/8" PORTED FUP I I 2-718" LNR, 6.5#, L-80, .00579 bpf, ID = 2.387" H 9545' 1 COMWENTS PRLDI-OE BAY lJ\Irr WELL: 09-36C PIRMIf lib: 1951140 AA No: 50-029-21429-03 SEe 1, TION, R15E 1874' NSL & 37' WEL BP Exploration (Alaska) TIlE 3 ,00 "-- STATE OF ALASKA .... ,-~SKA OIL AND GAS CONSERVATION COMMISS, _-~ REPORT OF SUNDRY WELL OPERATIONS · Operations performed: Operation Shutdown_ Stimulate~ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 5. Type of Well: Development_X Exploratory _ Stratagrapic _ Service _ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 1874' NSL, 37' WEL, Sec2, T10N, R15E, UM. At top of productive interval: 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM. At effective depth: At total depth: 3275' NSL, 123' EWL, Sec 1, T10N, R15E, UM. 12. Present well condition summary Total Depth: measured 9545 feet Plugs (measured) true vertical 9031 feet Effective Depth: measured 9175 feet Junk (measured) true vertical 8767 feet Casing Length Size Cemented 6. Datum of elavation (DF or KB feet): 53' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 9-36C 9. Permit number/approval number: 95-114 10. APl number: 50-029-21429-03 1. Field/Pool: Prudhoe Bay Oil Pool ClBP Set at 9175' MD (11/25/97). Measured depth True vedical depth Conductor 113' 20" 1810# Polyurethane Surface 2443' 13-3/8" 2175 Sx PFE & 400 Sx PFC Production 8247' 9-5/8" 500 Sx Class G & 300 Sx PFC Liner 1151' 7" 354 cuft Class G Liner 612' 2-7/8" 10 Bbls LARC 113' 2496' 8300' 9277' 9545' 113' 2496' 8195' 8822' 9031' Perforation Depth measured 9106 - 9126'; [Isolated below CIBP: 9500- 9515'; 9520- 9535'] true vertical 8731 - 8741'; [Isolated below CIBP: 8991 - 9004'; 9009 - 9021'] ORIGINAL Tubing (size, grade, and measured depth) 5-1/2", Tbg @ 31' MD; 4-1/2", 12.6#, 13CR Tbg @ 8992' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8853' MD; Camco TRDP-4A SSSV @ 2200' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see attached A/aska Oil & Gas Cons. Anchorage 14. Prior to well operation Subsequent to operation OiI-Bbl 57 392 Representitive Daily Average Production or Injection Data Gas-Mcf Water-Bbl 697 8 1529 1042 Casing Pressure Tubing Pressure - 287 247 5. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~j~-~ %, ~ Title: Engineering Supervisor Date SUBMIT IN DUPLICA~ Form 10-404 Rev 06/15/88 9-36C DESCRIPTION OF WORK COMPLETED FULLBORE ACID STIMULATION TREATMENT 8/29/98: Performed a Fullbore Acid Stimulation to increase production capacity as follows: MIRU & PT equipment. Pumped the treatment fluids fullbore through the open perforation interval located above the CIBP at: 9106- 9126' MD (Z3/4) Ref. Log: BHCS 4/6/93. Pumped: a) 42 bbls 70% Diesel / 20% Xylene / 10% Musol @ 3 - 10 bpm, followed by b) 100 bbls 12% HCI w/10% Xylene & 3% Acetic Acid @ 4 bpm, followed by c) 50 bbls 9% HCI - 1% HF & 3% Acetic Acid @ 3 bpm, followed by d) 50 bbls 12% HCI w/10% Xylene & 3% Acetic Acid @ 3 bpm, followed by e) 183 bbls 2% NH4CI Water @ 3.0 - 4.4 bpm, followed by f) 140 bbls Crude @ 2.5 - 3 bpm, followed by g) 10 bbls Diesel, followed by h) Shutdown. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. - :~- .... STATE OF ALASKA ~,~SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_X Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 50' RKB 3. Address: Exploratory_ 17. Unit or Property: P.O. Box 100360 Stratagrapic _ Anchora~e~ AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1587' NSL, 998' WEL, Sec 2, T10N, R15E, UM. 9-31C At top of productive interval: 9. Permit number/approval number: 2526' NSL, 2187' WEL, Sec 2, T10N, R15E, UM. 96-64 At effective depth: 10. APl number: 50-029-21396-03 At total depth: 11. Field/Pool: 984' FNL, 2602' FEL, Sec2, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10946 feet Plugs (measured) CIBP #3 Set at 9489' MD (5/28/98). true vertical 8824 feet CIBP #2 Set at 10000' MD (2/4/97). Effective Depth: measured 9489 feet Junk (measured) CIBP #1 Set at 10531' MD (10/12/96). true vertical 8853 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 111' 20" 1800# Polyurethane 111' 111' Surface 2483' 13-3/8" 2500 Sx CS III & 2533' 2533' 400 Sx CS II Production 8355' 9-5/8" 500 Sx Class G & 8405' 8136' 300 Sx CS I Liner 820' 7" 264 cuft Class G 9054' 8734' Liner 2129' 2-7/8" 17.5 Bbls Class G 10945' 8824' Perforation Depth measured 9206 - 9226'; 9236 - 9254' [Isolated below CIBP's: 9710 - 9765; 10250 - 10270'; 10273- 10298'; 10300- 10325'] true vertical 8827 - 8833'; 8835 - 8838' [Isolated below CIBP's: 8850- 8846; 8841 - 8841'; 8841 - 8841'; 8841 - 8841'] Tubing (size, grade, and measured depth) 5-1/2", Tbg @ 37' MD; 4-1/2", 12.6#, 13CR Tbg @ 8843' MD. Packers and SSSV (type and measured depth) Baker SABU3 Packer @ 8774' MD; Camco TRCF-4A SSSV @ 2096' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached A~'~k~a'g'fl' Intervals treated (measured) 14. Representitive Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 15167 1850 Subsequent to operation 5102 1809 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil _X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~ % ~ Title: Engineering Supervisor Date -- Form 10-404 Rev 06/15/68 SUBMIT IN DUPLICATE 9-31C DESCRIPTION OF WORK COMPLETED ClBP #3 INSTALLATION, ADD PERFORATIONS, & ACID STIMULATION 5/28198: RIH & set a CIBP in the 2-7/8" liner at 9489' MD (mid element), to isolate the open perforations at: 9710- 9765' MD (Z2) POOH w/setting tools. RIH w/perforation guns & shot 55' of Add Perforations at: 9206- 9226' MD (Z2) 9236 - 9254' MD (Z2) Used 2-1/8" carriers & shot all the perforations at 4 spf at 60 degree phasing at overbalanced pressures. POOH w/perf guns. Noted all shots fired. RD. Placed the well on PWI. 7/18/98: A Fullbore Mud Acid Stimulation Treatment to increase injection rates was performed as follows: MIRU & PT equipment. Pumped treatment fluids through the open perforations (listed above). Pumped: a) 100 bbls 2% NH4CI Water, followed by b) 70 bbls 50% Diesel- 50% Xylene, followed by c) 50 bbls 12% HCI w/10% Xylene, followed by d) 10 bbls Diverter Stage w/0.5 ppg Benzoic Acid Flakes, followed by e) 100 bbls 12% HCI w/10% Xylene, followed by f) 50 bbls 9% HCI- 1% HF, followed by g) 50 bbls 12% HCI w/10% Xylene, followed by h) 400 bbls 2% NH4CI Water Flush, followed by i) Shutdown. Noted Initial injectivity: 3.8 bpm @ 3850 psi pumping 2% NH4CI. Rigged down. Returned the well to PWI & obtained a valid injection rate. Note: Final injectivity: 3.8 bpm @ 1550 psi. Remaining future events to complete the EOR project sequence on this well: * Set a fourth ClBP to isolate all perf intervals. * Add Z3 & Z4 perforations & place the well on production. STATE OF ALASKA ~,~SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic _ Anchorage~ AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1874' NSL, 37' WEL, Sec 2, T10N, R15E, UM. 9-36C At top of productive interval: 9. Permit number/approval number: 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM. 95-114 At effective depth: 10. APl number: 50-029-21429-03 At total depth: 11. Field/Pool: 3275' NSL, 123' EWL, Sec 1, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: true verticalmeasured 90319545 feetfeet Plugs(measured) ClBP Setat 9175' MD (11/25/97). 0!~-~1[ ~"'*ii'k?, ?~;' [..~ Effective Depth: measured 9175 feet Junk (measured) true vertical 8767 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 113' 20" 1810# Polyurethane 113' 113' Surface 2443' 13-3/8" 2175 Sx PFE & 2496' 2496' 400 Sx PFC Production 8247' 9-5/8" 500 Sx Class G & 8300' 8195' 300 Sx PFC Liner 1151' 7" 354 cuft Class G 9277' 8822' Liner 612' 2-7/8" 10 Bbls LARC 9545' 9031' Perforation Depth measured 9106 - 9126'; [Isolated below ClBP: 9500- 9515'; 9520- 9535'] true radical 8731 - 8741'; [Isolated below ClBP: 8991 - 9004'; 9009 - 9021'] Tubing (size, grade, and measured depth) 5-1/2", Tbg @ 31' MD; 4-1/2", 12.6#, 13CR Tbg @ 8992' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8853' MD; Camco TRDP-4A SSSV @ 2200' MD. il\~') '~' C ~ j V ~r" ~'~ 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) J~as~,a Oil & Gas Cons. Comml,. sior~ 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 214 966 741 - 261 Subsequent to operation 216 845 696 - 261 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil X Gas Suspended Service_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~'~'~ ~'"~ . ~ Title: Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-36C PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/12/98: MIRU & PT equipment. RIH w/perforating guns & shot 10' of perforations as follows: Reperforated: 9106 - 9116' MD (Z4) Ref. Log: BHCS 4/6/93. Used a 1-11/16" carrier & shot 4 spf at 0 degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. ,~--- STATE OF ALASKA " .... AL, A OILAND GAS CONSERVATION COMMISSIO~!. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ StimulateX Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB 3. Address: Exploratoi'y_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1874' NSL, 37' WEL, Sec 2, T10N, R15E, UM. 9-36C At top of productive interval: 9. Permit number/approval number: 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM. 95-114 At effective depth: 10. APl number: 50-029-21429-03 At total depth: 11. Field/Pool: 3275' NSL, 123' EWL, Sec 1, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9545 feet Plugs (measured) CIBP Set at 9175' MD (11/25/97). true vertical 9031 feet Effective Depth: measured 9175 feet Junk (measured) true vertical 8767 feet Casing Length Size Cemented Measured depth True vertical deplh Conductor 113' 20" 1810# Polyurethane 113' 113' Surface 2443' 13-3/8" 2175 Sx PFE & 2496' 2496' 400 Sx PFC Production 8247' 9-5/8" 500 Sx Class G & 8300' 8195' 300 Sx PFC Liner 1151' 7" 354 cuft Class G 9277' 8822' Liner 612' 2-7/8" 10 Bbls LARC 9545' 9031' Perforation Depth measured 9106 - 9126'; [Isolated below CIBP: 9500- 9515'; 9520- 9535'] true vertical 8731- 8741'; [Isolated below CIBP: 8991- 9004'; 9009- 9021'] ! Tubing (size, grade, and measured depth) 5-1/2", Tbg @ 31' MD; 4-1/2", 12.6#, 13CR Tbg @ 8992' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8853' MD; Camco TRDP-4A SSSV @ 2200' MD .... 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached0RIGINAL Intervals treated (measured) 14. Representitive Bally Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 216 1168 127 270 Subsequent to operation 246 923 1327 257 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . Signed .('"~Ok/'W',,DJ% ¢ , ,/~V~-F""~t:~' I~ ~ (~ Title: Engineering Supervisor. Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-36C DESCRIPTION OF WORK COMPLETED CAST IRON BRIDGE PLUG INSTALLATION & PERFORATION BREAKDOWN TREATMENT 11/13/97: RIH & tagged top of fill at 9418' MD. 11/25/97: MIRU & PT equipment. RIH w/Cast Iron Bridge Plug & set in tubing at 9175' MD to isolate the lower open perforation intervals located at: 9500- 9515' MD (Z1A) 9520- 9535' MD (ZlA) Ref, Log: BHCS 4/6/93. POOH. Rigged down. 12/7/97: Performed a Non Reactive Perforation Breakdown Treatment to initiate flow as follows: MIRU & PT equipment. Pumped the treatment fluids fullbore through the upper perforation interval located above the CIBP at: 9106- 9126' MD (Z3/4) Ref. Log: BHCS 4/6/93. Pumped: a) 75 bbls Crude at 10 bpm, followed by b) 50 bbls 60% Diesel / 30% Xylene / 10% Musol at 10 bpm, followed by c) 135 bbls Crude, followed by d) 33 bbls Diesel, followed by e) Shutdown. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. r---.. STATE OF ALASKA -~' , JKA OIL AND GAS CONSERVATION COMMISS, ,. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate~ Plugging _ Perforate _X Pull tubing Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development_X 53' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 1874' NSL, 37' WEL, Sec 2, T10N, R15E, UM. 9-36C At top of productive interval: 9. Permit number/approval number: 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM. 95-114 At effective depth: 10. APl number: 50-029-21429-03 At total depth: 11. Field/Pool: 3275' NSL, 123' EWL, Sec 1, T10N, R15E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9545 feet Plugs (measured) true vedical 9031 feet Effective Depth: measured 9545 feet Junk (measured) true vertical 9031 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 113' 20" 1810# Polyurethane 113' 113' Surface 2443' 13-3/8" 2175 Sx PFE & 2496' 2496' 400 Sx PFC Production 8247' 9-5/8" 500 Sx Class G & 8300' 8195' 300 Sx PFC Liner 1151' 7" 354 cu ft Class G 9277' 8822' Liner 612' 2-7/8" 10 Bbls LARC 9545' 9031' Perforation Depth measured 9106 - 9126'; 9500 - 9515'; 9520 - 9535' true vertical 8731 - 8741'; 8991 - 9004'; 9009 - 9021' Tubing (size, grade, and measured depth) 5-1/2", Tbg @ 31' MD; 4-1/2", 12.6#, 13CR Tbg @ 8992' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8853' MD; Camco TRDP-4A SSSV @ 2200' MD. 13. Stimulation or cement squeeze summary 0RJClNAL Intervals treated (measured) see attached ..... :,.,,~.~ , ,.~- . Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 253 1028 165 290 Subsequent to operation 238 881 447 271 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Bally Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢/(,,~ '"~. ~ Title: Engineering Supervisor Date /zCz - ,/¢ - '~ "~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 9-36C PERFO_ _RATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/27/97: MIRU & PT equipment. RIH w/perforating guns & shot 20' of add perforations as follows: Added perforations: 9106 - 9126' MD (Z4) Ref. Log: BHCS 4/6/93. Used a 2-1/8" carrier & shot 4 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. ,:'ii e o 'J o g ~' c a 'l i4 a !:: e r' 'i' a i s I n v e n-i: o r' y F'ERkiZT ?'/',T" T B .,.., T,.., PL..lIS 95 ...... i i..".,~ PERF RCD '.~/.. SEPZA 1'i/'5/95 .-'::, r" e d r' y d ¥ t c h s a rn p 'i e s r' e q u '¥ .... ~- . .... " bi,:as 't:he we]'J cor"e-..t? yes i~~ai ys"is & descr":l'p't:'¥orl r'ec:',.'i'ved? --- '/~-~ A r'.e v,/e 'J 'J i... e s 'i; s r'e q t,..!-'( r'e d "? ,/i ~/... s ~3 ~,,',,'e'J ] 'iS x(iq coJ'np 'J '¥ a ace i iq -"i 't.:-'¥ a 'l C O H H E i",.t T :5 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10211 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 5;/28/96 Field: Prudhoe Bay Well 1-6A D.S. 3-24 D.S. 4-29 D.S. 6-8 6-19 D.S. 9-32 D.S. 9-32 D.S. 9-32 'D.S. 9-36C :).S. 9-47 Anadrill Anadrill Anadrill Floppy Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter ]'ER RECORD 9 51 I 1 3 I 1 95112O I 1 ~ RECORD 9511 13 1 1 :{ RECORD 9 51 I 1 6 1 1 RECORD 951121 1 1 ___ --{ECORD 9 51 1 1 5 I I ,,, ~{ECORD 9 51 1 1 6 1 1 ._ {ECORD !9 51 I 1 8 I 1 :IECORD 9 51 I 0 5 I 1 ~ECORD 9 51 I I 5 I 1 ....... .-- -- I CHEIVilCAL CUTTER IjEWELRY LO -- TUBING CU~"-i~'i~ TUBING CUTLER TLIBING PATCH PERFORA-RNG "ERFORA-flNG PERFORA-nN< PERFORA'nO , PERFORA"no ',, ............ SIGNED' DATE: r~ I:! I I_1_ I ~ G S E I::tL~ I r' Ec: WELL LOG TRANSMITTAL To: State of Alaska May 24, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 09-36C AK-MW-50074 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ynn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 29 1996 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company _ 5/7/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10177 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Anadrill Anadrill Anadrill Well Job # Log Description Date BL RF Sepia Survey Program Performance Calculation Letter D.S. 1-15 ?~'-0 u '/ TUBING CUT RECORD 951223 I 1 D.S. 1-22A ~',f'-/J'~"' IBPSETrlNG RECORD 951026 I 1 D.S. 2-11 77-,0~ PROD PROFILE 960419 1 1 --. D.S. 3-11 ?"~-0~'1 PERFRECORD 951224 I 1 D.S. 3-13 7~'{-~)~ PERFRECORD 951 21 0 I 1 D.S. 5-06A ~'" 0o~f POGLM SET'rING RECORD 951 030 I 1 -- D.S. 5-06A ~[~;'-0~ TUBING PUNCHER RECORD 951 026 1 1 · D.S. 5-23 ~r~., ~.-~ f PERF RECORD 951 020 1 1 .__ D.S. 6-19 '°'1'-I,~/ CHEMICAL CUTTER RECORD 960420 I 1 .__ ,D.S. 6-24 ,~-"lq7 PERFRECORD 951 226 I 1 D.S. 6-24 ~ 3.-I q'/ PERF RECORD 960423 I 1 D.S. 9-17 '27 - 0_~_~ PERF RECORD 960422 I 1 D.S. 9-17 77-0~ INJECTION PROFILE 960422 I 1 D.S. 9-18 _ '? ) - 0 } ~{ PERF RECORD 951 208 I 1 D.S. 9-25 ~I ~{ -(~ ;~ PERF RECORD 951 208 I 1 -- D.S. 9-36C r~ J"-II~( PATCH SETTING RECORD 951 21 6 1 1 D.S. 9-36C qJ'-(lfl PERF RECORD 951 022 I 1 D.S. 9-38 ~q' 0Z I PERF RECORD 951 209 I 1 D.S. 12-15 ~.~- 0~ X. INFLATABLE BRIDGE PLUG 951020 I I SIGNED' . _.' ................................................................... DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 I:t I I--I-- I I~] G S I::: I:! L~ I r" I~ S WELL LOG TRANSMYFFAL To: State of Alaska April 17, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Larry Grant 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 09-36C, AK-MW-50074 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 09-36C: ~ / 2"x 5" MD Gamma Ray Logs: 50-029-21429-03 2" x 5" TVD Gamma Ray Logs: 50-029-21429-03 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia V 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, inc. Company .... ' STATE OF ALASKA ~' AL/-L,...,,A OIL AND GAS CONSERVATION COb,.:. .. $SlON WELL COMPLETION OR REOOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS E~ SUSPENDED r--] ABANDONED F'~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-114 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-21429-03 4 Location of well at surface , ' . ' : ~ 9 Unit or Lease Name 1874' NSL, 37' WEL, Sec 2, T10N, R15E UM At Top Producing Interval I ~'/,~ j''/9. {- PRUDHOE BAY UNIT ......! '.!.(~"~1 :' ' .'"";~ ! 10 WellNumber 2915'NSL, 51'EWL, Sec1,T10N, R15E UM "~::'~ !}ii.;i~! 9-366 At Total Depth ~ - - . ~ ~ 11 Field and Pool 3275' NSL, 123' EWL, Sec 1, T10N, R15E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 53' ADL 28327 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Apand. 15 Water Depth, if offshore 116 No. of Completions 9/5/95. 9/7/95. 10/22/95 (Comp). N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 9545' MD / 9031' TVD 9545' MD / 9031' TVD YES ['~ NO E~I 2200' feet MDI 1900' (approx) 22 Type Electric or Other Logs Run GR & MWD Survey 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADEi TOP BOTTO~ HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5 # H-40 Surf 113' 30" 1810 # Polyurethane 13-3/8" 72 #/68 # L-80/K-55 Surf 2496' 17-1/2" 2175 sx PF "E" & 400 sx PF "C" 9-5/8" 47.0 # L-80 Surf 8300' 12-1/4" 500 sx G & 300 sx PF "C" 7" 29.0 # NT-80/13CR 8126' 9277' 8-1/2" 354 cuft Class "G" 2-7/8" 6.5# L-80 8933' 9545' 3.75" 10 bbls LARC 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 8992' 8853' 9500 - 9515' M D; 8991 - 9004'TVD; in Z l A @ 4 spf. 9520 - 9535' M D; 9009 - 9021'TVD; in Z1A @ 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Qperation (Flowing, gas lift, etc.) 10/24/95.I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1/9/96 (post-Frac) 3.0 TEST PERIOD ¢I 898 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 274 24-HOUR RATE ¢ 616 553 119 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. *Note: 9-36c Coil Tubing Sidetrack Drilling Operations summary attached. . * This 10-407 submitted as directed per 10-401 approved on 7/27/95 (Permit # 95-114). Form 10-407 ~,~ duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MAFII~RS FORMATIoN TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEP-I'H TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9037' 8693' N/A Top of Zone 3 9104' 8730' Top of Zone 2 9180' 8770' 31. LIST OF ATTACHMENTS Summary of 9-36C Coil Tubing Sidetrack Drilling, Tubing Patch Installation, & Zone 1A Fracture Treatment Operations. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge SigneV,.j/~/~3 C. Title Engineering Supervisor Date INSTRUCTIONS Form 10-407 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain .... Item 28: If no cores taken, indicate "none". ~'~'-' ~ /~s~:,a Oi! ~ C~..s ConS. Corn~iss'lon 9-36C DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING, TUBING PATCH, & ZIA FRAC TREATMENT 9/4/95: MIRU CTU & PT equipment. MU & RIH w/CT milling BHA & tagged cement plug top at 9232' MD. pilot hole through cement to 9268' MD. Drilled 9/5/95: POOH w/milling BHA. MU & RIH w/window milling BHA. Started milling a window in the 7" liner at 9270' MD. Completed milling bottom of window at 9277.4' MD, then drilled formation to 9282' MD. Backreamed window & circulated OOH w/BHA. 9/6/95: MU & RIH w/drilling BHA. Swapped well to FIo-Pro & started drilling 3.75" hole to 9339' MD. w/BHA. MU & RIH w/drilling BHA & resumed drilling to 9341' MD. POOH 9/7/95: Drilled to TD at 9545' MD. MU liner assembly. Obtained a survey back to window. POOH w/BHA jetting up from 9280' MD. 9/8/95: RIH w/2-7/8" liner assembly. Landed liner at 9545' MD. Pumped 10 bbls of Latex Acid Resistive Cement to set liner from 8933' to 9545' MD. Released from liner & POOH w/CT. RIH w/nozzle & tagged up on GLM at 8100' MD; could not pass. POOH w/CT. MU & RIH w/milling BHA to TD. Circulated through liner w/biozan. POOH w/CT displacing weltbore w/150 bbls Seawater. RDMO CTU. 9/14/95: RIH & tagged PBTD at 9535' MD. 10/22/95: MIRU CTE. RIH w/CTE perforation gun & shot initial perforations in the 2-7/8" liner at: 9520 - 9535' MD (Z1A) Ref. Log: GR 9/7/95. Used a 2-1/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressure. Rigged down. POOH w/perf gun. 11/4/95: RIH & tagged PBTD at 9504' MD. 11/5/95: MIRU CTE. RIH w/CTE perforation gun & shot add perforations in the 2-7/8" liner at: 9500- 9515' MD (Z1A) Ref. Log: GR 9/7/95. ,-~,,,,,~,~-l*"-'~'*Oii~' Ga~';C°ns' C°?:"~mis$i°r~.* Anchorage Used a 2-1/8" carrier & shot 4 spf at 180 degree phasing at overbalanced pressure. PU for injectivity test to 2000 psi; no leakoff. POOH w/perf gun. Rigged down. 12/16/95: RIH & set a 2.441" ID AVA DWP Tubing Patch from 8094' to 8110' MD (seal to seal), in the 4-1/2" tubing, across GLM #6. POOH. Rigged down. 12/28/95: Pumped a Pre-Frac Fullbore High Pressure Breakdown treatment as follows: MIRU & PT equipment to 8200 psi. Treated the perforation intervals (above) pumping 14 bbls Warm Diesel @ 5 bpm, followed by 270 bbls Seawater @ 10 bpm, followed by Shutdown. ISIP @ 2250. Resumed pumping an additional 41 bbls Seawater @ 5 bpm, followed by 30 bbls Crude, & 10 bbls Diesel Flush, followed by Shutdown. Rigged down. 9-36C DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING, TUBING PATCH, & ZlA FRAC TREATMENT 12/29/95: Pumped a Hydraulic Fracture Treatment to initiate flow as follows: MIRU & PT equipment to 9500 psi. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the open perforation intervals (listed above). Pumped: a) 35 bbls Gelled Scouring Stage w/1 ppg proppant @ 15 bpm, followed by b) 230 bbls 20# Gelled Pre Pad @ 15 bpm, followed by c) Shutdown. ISIP @ 2664. Resumed pumping: d) 120 bbls 40# Crosslinked Pad @ 15 bpm, followed by e) 231 bbls Crosslinked Slurry w/proppant stages @ 1 - 10 ppg, followed by f) 135 bbls Flush, followed by g) Shutdown. Placed a total of 38,454 lbs of proppant in the formation. 12/30/95: RIH w/CT & jetted a proppant fill cleanout to 9532' MD. 1/1/96: RIH & tagged PBTD at 9362' MD. Rigged down. Placed the well on production w/gas lift & obtained a valid welltest. sPi Y-SUN DRILLING SERVICES ~'~ ANCHORAGE ALASKA ARCO ALASKA INC PBU/9-36C 500292142903 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/9 DATE OF SURVEY: 090795 MWD SURVEY JOB NUMBER: AK-MW-50074 KELLY BUSHING ELEV. = 53.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9217 8790.00 8737.00 57 39 N 11.70 E .00 1189.90N llg.00E 9277 8822.22 8769.22 57 22 N 11.90 E .54 1239.44N 129.35E 9323 8850.87 8797.87 45 37 N 11.45 E 25.52 1274.71N 136.65E 9340 8863.29 8810.29 45 0 N 12.62 E 5.87 1287.00N 139.27E 9353 8872.30 8819.30 43 14 N 11.92 E 14.55 1295.53N 141.13E 1188.73 1239.34 1275.36 1287.92 1296.66 9370 8885.04 8832.04 41 39 N 10.69 E 10.33 1306.96N 143.41E 9385 8896.54 8843.54 40 31 N 10.69 E 7.48 1316.81N 145.27E 9400 8907.65 8854.65 38 56 N 10.87 E 10.96 1325.88N 147.00E 9415 8919.34 8866.34 37 31 N 11.04 E 9.50 1334.92N 148.75E 9430 8931.41 8878.41 35 46 N 10.34 E 12.02 1343.75N 150.42E 1308.31 1318.33 1327.56 1336.77 1345.75 9444 8943.18 8890.18 34 0 N 10.16 E 12.29 1351.83N 151.88E 9460 8956.20 8903.20 32 26 N 10.90 E 10.41 1360.21N 153.43E 9475 8969.18 8916.18 31 12 N 10.34 E 8.34 1368.13N 154.92E 9492 8983.80 8930.80 29 37 N 9.28 E 9.84 1376.58N 156.38E 9507 8996.67 8943.67 28 23 N 8.93 E 8.43 1383.63N 157.51E 1353.95 1362.48 1370.53 1379.11 1386.24 9517 9005.74 8952.74 27 13 N 6.43 E 16.05 1388.37N 158.15E 9530 9017.40 8964.40 26 6 N 6.96 E 8.85 1394.18N 158.84E 9545 9030.52 8977.52 26 6 N 6.96 E .00 1400.56N 159.61E 1391.00 1396.83 1403.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1409.63 FEET AT NORTH 6 DEG. 30 MIN. EAST AT MD = 9545 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 11.96 DEG. TIE IN POINT 9217' INTERPOLATED WINDOW POINT 9277' INTERPOLATED DEPTH 9545' .Y-SUN DRILLING SERVICES g2q'CHOR~GE ALASKA PAGE 2 ARCO ALASKA INC PBU/9-36C 500292142903 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/95 DATE OF SURVEY: 090795 JOB NUMBER: AK-MW-50074 KELLY BUSHING ELEV. = 53.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TV-D VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9217 8790.00 8737.00 9545 9030.52 8977.52 1189.90 N 119.00 E 427.00 1400.56 N 159.61 E 514.48 87.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPL .Y-SLrN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC PBU/9-36C 500292142903 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/95 DATE OF SURVEY: 090795 JOB NUMBER: AK-MW-50074 KELLY BUSHING ELEV. = 53.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9217 8790.00 8737.00 9326 8853.00 8800.00 9456 8953.00 8900.00 9545 9030.52 8977.52 1189.90 N 119.00 E 427.00 1276.74 N 137.09 E 473.08 46.08 1358.20 N 153.05 E 503.34 30.26 1400.56 N 159.61 E 514.48 11.14 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS .Y-SUN DRILLING SERVICES ANCHOP~AGE ALASKA ARCO ALASKA INC PBU/9-36C 500292142903 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/9 DATE OF SURVEY: 090795 MWD SURVEY JOB NUMBER: AK-MW-50074 KELLY BUSHING ELEV. = OPERATOR: PAGE 53.00 FT. ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9217 8790.00 8737.00 57 39 N 11,70 E .00 1189.90N l19.00E 9277 8822.22 8769.22 57 22 N 11.90 E .54 1239.44N 129.35E 9323 8850.87 8797.87 45 37 ,N 11,45 E 25.52 1274.71N 136.65E 9340 8863.29 8810.29 45 0 N 12.62 E 5.87 1287.00N 139.27E 9353 8872.30 8819.30 43 14 N 11.92 E 14.55 1295.53N 141.13E 1188.73 1239.34 1275.36 1287.92 1296.66 9370 8885.04 8832.04 41 39 N 10.69 E 10.33 1306.96N 143.41E 9385 8896.54 8843.54 40 31 N 10.69 E 7.48 1316.81N 145.27E 9400 8907.65 8854.65 38 56 N 10.87 E 10.96 1325.88N 147.00E 9415 8919.34 8866.34 37 31 N 11.04 E 9.50 1334.92N 148.75E 9430 8931.41 8878.41 35 46 N 10.34 E 12.02 1343.75N 150.42E 1308.31 1318.33 1327.56 1336.77 1345.75 9444 8943.18 8890.18 34 0 N 10.16 E 12.29 1351.83N 151.88E 9460 8956.20 8903.20 32 26 N 10.90 E 10.41 1360.21N 153.43E 9475 8969.18 8916.18 31 12 N 10.34 E 8.34 1368.13N 154.92E 9492 8983.80 8930.80 29 37 N 9.28 E 9.84 1376.58N 156.38E 9507 8996.67 8943.67 28 23 N 8.93 E 8.43 1383.63N 157.51E 1353.95 1362.48 1370.53 1379.11 1386.24 9517 9005.74 8952.74 27 13 N 6.43 E 16.05 1388.37N 158.15E 9530 9017.40 8964.40 26 6 N 6.96 E 8.85 1394.18N 158.84E 9545 9030.52 8977.52 26 6 N 6.96 E .00 1400.56N 159.61E 1391.00 1396.83 1403.24 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1409.63 FEET AT NORTH 6 DEG. 30 MIN. EAST AT MD = 9545 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 11.96 DEG. TIE IN POINT 9217' INTERPOLATED WINDOW POINT 9277' INTERPOLATED DEPTH 9545' O.RI6 NAL SPE .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC PBU/9-36C 500292142903 NORTH SLOPE BOROUGH COMPUTATION DATE: 9/19/95 DATE OF SURVEY: 090795 JOB NUMBER: AK-MW-50074 KELLY BUSHING ELEV. = 53.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9217 8790.00 8737.00 9545 9030.52 8977.52 1189.90 N 119.00 E 427.00 1400.56 N 159.61 E 514.48 87.48 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE S-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU/9-36C 500292142903 NORTH SLOPE BOROUGH COMPUTATION DATE: 9 / 9/95 DATE OF SURVEY: 090795 JOB NUMBER: AK-MW-50074 KELLY BUSHING ELEV. = 53.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9217 8790.00 8737.00 1189.90 N 119.00 E 427.00 9326 8853.00 8800.00 1276.74 N 137.09 E 473.08 46.08 9456 8953.00 8900.00 1358.20 N 153.05 E 503.34 30.26 9545 9030.52 8977.52 1400.56 N 159.61 E 514.48 11.14 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS September 19, 1995 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: MWD Survey Data - 9-36C, 14-44, 2-18A, 18-31 Dear Mr. Grant, Enclosed are two hard copies of the above mentioned survey(s). Well 2-18APB1 ell 2-18APB2 Well 2-18APB3 {~/x i0~ Well I8-31PBI ii ,/~~9-36C ,/.- Well 14-44PB1 Redistributing - previous survey TVD was incorrect. Destroy previous data for this survey. Tied in at 10,100', window point 10,125', interpolated depth is 10,232' Redistributing - previous survey TVD was incorrect. Destroy previous data for this survey. Tied in at 10,100', window point 10,125', interpolated depth is 11,125' Redistributing - previous survey TVD was incorrect. Destroy previous data for this survey. Tied in at 10,100', window point 10,125', interpolated depth is 11,413' Surface to interpolated depth of 10466' Tie in point interpolated at 10059', interpolated depth 10556' Tie in point 9217', interpolated window point 9277', interpolated depth 9545' Surface to 12910' Tied in at 12407.14' to 14-44PB1, kick off point at 12497' Please call me at 563-3256 if you have any questions. Sincerely, Sandra tldfi~ Department Specialist Enclosures. RECEIVED S EP 2 0 1995 Alaska Oil & Gas Cons. Commission Anchorage ~- 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ' CONSERVATION COMMISSION , ALASKA OIL AND GAS / 3OOl PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 27, 1995 James Cawvey Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 9-36C ARCO Alaska, Inc. Permit No. 95-114 Sur. Loc. 1874'NSL, 37'WEL, Sec. 2, T10N, R15E, UM Btmnhole Loc. 3293'FSL, 5154'FEL, Sec. 1, T!ON, R15E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commi~ ctor on the North Slope pager at David~ Johnston~ Chairman~~_~J BY ORDER OF THE COI~MISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ..... STATE OF ALASKA AD._,~ OIL AND GAS CONSERVATION COMN,,...~ION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill __ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test _ 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 ARCO Alaska, Inc. RKB 53' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28327 Prudhoe Bay/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11.' Type Bond (see 20 AAC 25.025) 1874' NSL, 37' WEL, Sec 2, T10N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2915' NSL, 51' EWL, Sec 1, T10N, R15E, UM 9-36C #U-630610 At total depth 9. Approximate spud date Amount 3293' FSL, 5154' FEL, Sec 1, T10N, R15E, UM July, 1995 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28324:1794 feet No Close Approach 2560 Acres 9537' MD / 9029' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 9270' MD Maximum hole angle 58° Maximum surface 2100psig At total depth (TVD) 3 4 5 0 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.5 L-80 FL4S 280' 9257' 8812' 9537' 9029' 5 bbls Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9700 feet Plugs (measured) true vertical 9049 feet Effective depth: measured 9644 feet Junk (measured true vertical 9018 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 1 1 3' 2 0" 1810 # Polyurethane 1 1 3' 1 1 3' Surface 2443' 13-3/8" 2175 sx PF E/400 sx PFC 2496' 2496' Production 8247' 9-5/8" 500 sx CIG & 300 sx PFC 8300' 81 95' Liner 1406' 7" 354 cuff CIG 9532' 8957' Perforation depth: measured Open Hole: 9452 - 9627' true vertical Open Hole: 8917 - 8998' 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch _ Drilling program ~ Drilling fluid program __ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Sign ~' Titlle Date 7/~ Only Permit Numbe¥ APl n'bf/11~r See letter for ~'~,~"'"-,,,'",,,'/~ 5 0- ~,~_.'~ _ ,~.f ~'¢2- ~_ 4:~,~ "///~--) ~///~ ,5 other requirements Conditions of approval Samples required .~Y e s ~ N o Mud log required__ Y e s .,~ N o Hydrogen sulfide measures ~ Y e s N o Directional survey required ~ Yes __ N o Required working pressure forBOPE __2M; __ 3M' __ SM' __ 1 0M' __ 1 5 M 3500 psi for CTU Other:Original Signed By David W. Johnstonbyorder of//t/ ('f ~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 9-36C CT Sidetrack and Completion Intended Procedure Objective' Directionally drill a twin well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure' Mill window in 7" casing at-9270' md. Drop angle to -25° at 17°/100' to TD. · Directionally drill twin well to access Zone 1 reserves. · Run and cement 2-7/8" liner to TD. · Perforate selected intervals. Return well to production. RECEIVED ~UL' 2 71 !9e:''~ gia~-l(a .0ii .& Gas Cons. Commission July 14, 1995 DS 9-36C CT Sidetrack 3-3/4" open hole with 2-7/8" liner cemented in place 4-1/2" Tubing 7" Liner Top - 8126' ~~[, SWS Nipple 8795' Packer 8853' SWS Nipple 8883' ' SWN Nipple 8979' Tbg Tail 8982' New window cut @~ 9Z70 - 97.80' ' 9-5/8" Casing ~-- Window @ 8300 - 8350' Top of 2-7/8" Liner in 4-1/Z" Tubing tail Cement kickoff plug -- top at ~ 9ZZ5' MD 3-3/4" open hole-- plugged with I~laraseal gel/c~,-,~,~/- 7" Csg. Shoe @ 9532' DS9-36C Potential Drilling Hazards POST ON RIG · No H2S production. BHP: 3550 psi @ 8800' ss (7.8 ppg EMW), BHT 190 °F (estimated values based on offset wells). No over pressured zones are anticipated. · Maximum anticipated WHP w/ full column of gas: 2100 psi. Expected gas/oil contact is 8677' ss. A gas underrun exists in Zone 2A at approximately 8869' ss. Waterflood breakthrough is significant in Zone 2A at approximately 8890' ss and in Zone lB at approximately 8933' SS. · There are multiple thin conglomerate beds in Zones lB and 2B. C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7' WLA Quick Connect 5-1/8" ID CT BOP Stack 10,000 psi Working Pressure ~,~ j Flanged Fire Resistant Kelly Hose To Dual ChokeManifold Flanged / / Manual Valve HCR ~~~_..~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I' ' I I' 2" Pumpoln I i i Cutters or Combination Cutter/Blinds '~~ Slip/Pipe rams Drilling spool 7-1/16", 5M by 5-1/8", 10M Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Ram Type Dual Gate BOPE~ Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams 0.458' (5.5") ~ Manual Master Valve Manual Valves (3-1/2' Valves) 9' from GL to top of MV /Tubing Hanger 9-5/8" Annulus 13-3/8" Annulus ~Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree J~l!'eJ/lueuJd!nb::t 6U!ll!Ja Il@MOa .0 09S-6 sa u! §U!ll!Ja .LO Joj ~,no/[e-I lueuJd!nb3 Jo!elAI peJJeteJd )peJ ad!el/ '1x3 woo~l dwnd xldJ/ 01~/09 SJel!O~] len._-I doqs Anadrill Schlumberger Alaska 1111 East ":;!.:':. ~ '"'-,~ ~c,~orageo lqd~: 99518 , 349-2487 :;X 3,, CTION~ WELL PLAN for SHARED SERVICES DRIL~,LN~ Well ......... : DS-9-36C (P2} =: ~ ~-... ~ield ........ : PR~HOE ~Y, DSO 9 -, ~: "c,-> ~/ ~T 70.247 8~05 N ~;~ urface ~n~.; 148. 23605488 W ~CATI~ - a~ Zone: 4 ~gal ~scription X-C~ Y- C~rd Surface ...... : 1874 FSL 37 ~ S02 TI~N ~ ~ 718~28.8~ 594~3%0.65 Target ....... : 3287 FSL ~155 ~ ~01 TlON ~SE ~ 7184%8.26 ~47~8.32 ~ .......... : 3293 ~L 5154 ~ SOl T10N ~SE ~ 718449.14 5944764.37 Prepared ..... : 07/14/95 Section at...: 11.96 KB ~leva~ion.: 53.00 is Nag~etf~ DcL~: 29.521 E Scale Factor.: 0. ~9995~.15 Collve~~..: +1.66021985 STATION ID~I~TIFICATIO[~ TI£- II~ ~Y 9217 ~p OF ~ 9265 ~P~P. 17/100 9270 : 9300 . ,' .. .. 9400 ..~ .~ '~:. ~ . j .': . ~.< ~,~J' . _,~- 3-":.. "" < ?.'; '. ':]' '~:. , . ...~ '< . { . .. . .. '.." , . A/~ILE A~ ~U'I"H BII[B SUB-fl DiI~T 57 . 66 11.79 8790 8737 1189 57 . 43 11 . 95 8816 8763 1229 57,41 11.96 . 8818 8765 123] S2.31 11.96 8836 8783 1258 35.31 11.96 6907 8854 -2s.s~- 25.54 1189.91 N llB. ~2~.2~ N I27.2~ ~33.33 ~ I28.08 1257.32 N 133 ~I6 718413 . 23 !. 5944533.45 7184:10 . 35 ]~,944572 . 97 718421 ~' mlmm 150R 1327. 1324.80 N · , 1386.90 N mmm* ~/ <T~ 0.SS 0.55 17.00 17.00 ,. 153~49 ~;,-.L?.~~¢;~.:..5~44.~97.7'~-:'.':. >.' j.' 17..~o ~A~LL-';~. ': .: .... NOT PPROVED FOR ER UT. ION .... S H A R E.D..,]i~E R V~ C E ~_'.,' DR Z LL I NG,' I~mrker Identification MO A) T{E-iN SU~V£¥ 9217 B) T~ ~ WI~W 926~ D) E~ 17/1~ ~ 9457 E) Ti~ 9457 F) TO 9537 I B790 ttS9 57,66 88i6 8BiB tzar. ~7 t3~ .-~,~ ~7 I3M. '~.: ~,~ 0S09,36C~((p2) .. 'VERTICAL 'SECTION VIEW _ _ m · m-~ -. · . ' · ' -- -- '.' '.'_ Oep-S cate '. t ~nc~ · IZO0 feet.. I · .. ·, . ... ........... ...,..... f.~..-:;,,7~'. ,2?: . ~ ._'~ _ { · ,4nadrYJ] m · · I ....... J_lS L' .... · · ~ , , , ; .AI';JAD'R]L L .AK,~--DPC i "FEA, ½1 B IL ITy PLAN .... '-,iOT I"'a" I "~ 0 V i [ --:_-_- ._: ..... -- ~.-.m,"~.-'"~ '. , ] ............ i ,,, ...... ~ ........................... . .... :'-7',( 7' i · ! .. } .... i ............ '..- i ) - ~ .... · i .......... , : . , 'i ]..';)'.,!. { ~- -,, ........ ., _ . I ' I :, , ~m;,-,,o,':' - I I , ......... ,...,~.._.{ : .... :;i' ' _ ..... .,, - : - · . : ', .. { i : I :,..o.~,~00 ' ..~) SH A RE D "-s~-Fi-V':[ c E~S [)RZLLING .... .,i. ,___,,_ " I ........... (P2) ' ~ ,,~ ,~- ~7.,~. [ /..VERTICAL SECTION' VIEH 9Z~ ~$~ S~' .57,45 - ' , .... ~..,,_, .___ ',, , · ...... F~ TO ~a~ 9o~ ~ m'~" ~ ~ale.: $ ~nch · ~ feet I '- ......... '-:' -SHARED'"--~BER'v TI2ES DR TLLIN$ ....... i i iii i I . i _ _JllJ i .... . i i ...... I i II """"""'"'"'"':"'~' "° "" ~'" DS09-36C. (P2) ,,~,~,,,~ ~ ,~--..-,, ~ -:.....-.. oi E~ tT/~oo ~ ~? ~a~ ~a .... . ......... It TARGET g457 ~35) m CLOSU~ ..... '-1395 feet.., at:'~lZieuth 6,6I SCALE. · 1 Inch !:',':~0'"feet O~'. · o~/!al~?. ~-'~.j';~." · :, 8".".~ ~.'~..'4' '.-. :2 "' -. ' ~';.-' ~'.9:?" ';: ¢;-"'~ ...... . ,%:.. ~.,.;, .' , i ..' .. . - ' '. ' _ ' _'_':.T.J~.%;"~; ~'i,~' -, ~na~r~ ] ] SChJumb~rger' tffiO-- ~ ..... ~....... ! ~ -- . ..... ~ ............. ~ ....... i, 11t ........ i i5O0- ~ : ~ _ .. .-, . ~ - . . ~-- - ~ ..... t ~ ' ~ AN ~DRIL~ AKA. DPC ,~o-- i' ~ ' "N:OT APPF D F( }R ~ ~ .... Bs:~:<'"~'-~; }." I " ' ........... . ~ · .~ :-. ,. -..:'~.'-; ~ r .' ' ,.. · ' o- ~ -- ~ ---_. [_ - ~ ............ :~'.,... ........ ~ . ~ I q';' :: ' . <- ~[SI ' EAST -> :' I ' SHAREB' SERVZC-ES 'DR~LLTN6 ......... .... i i · i L - ' - I i · -- -%1_ f I II I I I _. I ~rkee [~l~nt~ f ~clt ~n ~ N/~ E/~ DS09-36C (P2) ,,,~.,,~, .,,. ,,. PLAN VIEW e~ ,~ ~.~, · '"~ I1~ ;CLOSe. · ~396 feet 6~ Azimuth 6,6t E~ T~T . . 9457- t~. t53 OECLZNATION,' 2g.5~t E F) TO ,... 9537 ~7. ,SCALE ' t ~nch - 50 feet .,: O~N ' 07/~4/95 ... . . i ill 14~--- , ......... J. ~ I ~ '. ~52- _ .......... ~ * ........... ~0 ..... . ! ............ ~---~ ' ' --J I ANAD~iLL' i ....... ;KX:D~ ,.o , ' ,~;" ,! --rEASI'E;ILI~ ' / i NOT AF'PR~ED FO ' i r LAhI ¢;~ ~', I~:: ~ .... t .~ .... . t , ~,~ ...~ [ ....... - '~~' , ~.~. .... 1~- -, i .- I ~.~ /' ~ ~ , ~= ~_ ~ . , , ~ _ .~ .. ,' . I ' I I ! , ,'" tl~ -, .... t , ~I ' ,, ~ - ' ~ I 1 0 2~ ~ tS' tOO 125 t~o ~ ~5 ~ ~5 ~50 ~75 300 <- ~ST' EAST-> .... ,, .... : ICATION FOH UNUHY A Abandon ~ Suspend Operation shutdown Alter casing Repair well Plugging X Change apprc~Ved program Pull tubing Vadance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development ,, X Exploratory Stratigraphic Service 4. Location of well at surface 1874' NSL, 37' WEL, Sec. 2, T10N, RISE, UM. At top of productive interval 2915' NSL, 51' EWL, Sec. 1, T10N, R15E, UM. At effective depth At total depth 3410' NSL, 148' EWL, Sec. 1, T10N, R15E, UM. Re-enter ~bsp( I'ime extension Perforate , 6. Datum of elevation(DF or KB) 53 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-36BL 9. Permit number 94-125 10. APl number 50 - 029-21429-62 11. Field/Pool Prudhoe Bay Oil Pool feet Total depth: measured 9627 feet Plugs(measured) true vertical 8998 feet n D i F2_I ^ / Effective depth: measured 9627 feet true vertical 8998 feet Junk(measured) . Casing Length Size Cemented Measured depth True vertical depth Conductor 113' 20" 1810# Polyurethane 113' 113' Sudace 2443' 13-3/8" 2175 sx PF 'E'& 400 sx PF 'C' 2496' 2496' Production 8247' 9-5/8" 500 sx G & 300 sx PF 'C' 8300' 8195' Liner 1406' 7" 354 cu ft 'G' 9532' 8955' RECEIVED Perforation depth: measured Openhole: 9452-9627' JUN 2 9 1995 true vertical Openhole: 8917-8998' Alaska Oil & Gas Cons. Commission Anchor~ -,* Tubing (size, grade, and measured depth) 7", NSCC, Tbg @ 31' MD; 4-1/2", 12.6~t, 13 CR, Tbg @ 8992' MD. Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 8853' MD; Camco TRDP-4A SSSV @ 2200' MD. 13. Attachments Description summary of proposal .x Detailed operations program BOP sketch x 14. Estimated date for commencing operation July, 1995 16. If proposal was verbally approved Oil x Gas. Name of approver Date approved Service 17. I he%r~,by certify that the foregoing is true and correct to the best of my knowledge. . FOR COMMISSION USE ONLY Conditionsket/approval: Notify/Com~sei~on so representative may witness Plug integrity , 'F' BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- gO 7' Approved Copy Original signea By Returned ~ Approved by order of the Commissioner [},Vid W. J0[Irlst01] "?~~"~i~,e, 15. Status of well classification as: Suspended Date J Approval No.¢..S_.._r/''~ 7 Form 10-403 Rev 06/15/88 SLW cc: KZ, JWP NELL PERMIT CHECKLIST COMPANY WELL NAME GEOL AREA PROGRAM: exp [] dev [] redrll ~ aery [] / ~MINISTRATION tPPR ~ATE/ 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approva[.. 13. Can permit be approved before 15-day wait ....... ENGINEERING N N N N 14. Conductor string provided ................ Y N) , 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~p N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N press rating adequate; test to ~gOd-~ psigQ 26. BOPE N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y / ~ ./~ 32. Seismic analysis 9f shallow gas zones .......... Y// N 33. Seabed condition survey (if off-shore) ........ /'~ N ~ ' 34. Contact name/phone for weekly progress reports . . . ~ . Y N [exploratory only) GEOLOGY: Comments/Instructions: HOW/jo - A:~FORMSt, cheklist rev (33/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LaS TAPE HEADER PRUDHOE BaY I/NIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 6635.00 B. JAHN GOODRICH D.S. 9-36C 500292142903 ARCO ALASKA INC. SPERRY-SUN DRILLING SERVICES 20-MAY-96 MWD RUN 2 B. JAHN MOONEY MWD RUN 3 B. JAHN VENHAUS/BAS S MWD RUN 4 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WORTHINGTON VENHAUS/BASS WELL CASING RECORD 2 10N 15E 1874 37 53.00 .00 .00 Date ~.~-~~~~ OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2496.0 9.625 8300.0 7.000 9268.0 3.750 9549.0 MWD - GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1 THROUGH 4 WERE DIRECTIONAL WITH GAMMA RAY (NGP/SGRD). ALL GAMMA RAY DATA WAS ACQUIRED WITH NATURAL GAMMA PROBE, SCINTILLATION TYPE DETECTOR (NGP/SGRD) . WELL WAS KICKED-OFF THROUGH A WINDOW CUT IN 7" CASING FROM 9268 - 9277'. THE DATA HAS NOT BEEN DEPTH SHIFTED AS THERE IS NO ~G~,~v~D WIRELINE GAMMA DATA AVAILABLE, PER A CONVERSATION BETWEEN A. TURKER (Sperry) AND DICK OWENS (ARCO ALASKA INC.) ON 28-MAR-96. 29 1996 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 GR 9216.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 9527.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 9237.0 9272.0 2 9272.0 9286.0 3 9286.0 9343.0 4 9343.0 9549.0 MERGED MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 9-36C : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 * DATA RECORD (TYPE# 0) · Total Data Records 1014 BYTES * Tape File Start Depth = 9549.000000 Tape File End Depth = 9216.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2002 datums Tape Subfile: 2 100 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9216.0 $ 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: STOP DEPTH 9250.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MI/D 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 1. 05-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 9272.0 9237.0 9272.0 0 57.4 57.6 TOOL NUMBER NGP 110 3.750 9268.0 BIOZAN/SEAWATER .00 .0 .0 0 .0 .000 .0 .000 137.5 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 9-36C : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 9275.000000 Tape File End Depth = 9216.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 358 datums Tape Subfile: 3 65 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9246.0 $ 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: STOP DEPTH 9260.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 2. 06-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 9286.0 9272.0 9286.0 0 57.4 57.4 TOOL NUMBER NGP 110 3.750 9268.0 BIOZAN/SEAWATER .00 .0 .0 0 .0 .000 .0 .000 154.4 .000 .0 .000 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA INC. D.S. 9-36C PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 2 Tape File Start Depth = 9290.000000 Tape File End Depth = 9240.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2306 datums Tape Subfile: 4 65 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9259.0 $ 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: STOP DEPTH 9319.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 3. 07-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 9343.0 9286.0 9343.0 0 45.6 45.6 TOOL NUMBER NGP 110 3.750 9268.0 FLO-PRO 8.90 66.0 9.0 39000 5.8 .000 .000 .000 .000 .0 129.0 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA INC. D.S. 9-36C~ PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 3 Tape File Start Depth = 9345.000000 Tape File End Depth = 9255.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 5 Minimum record length: Maximum record length: 902 datums 66 records... 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9258.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: MAXIM UMANGLE: STOP DEPTH 9527.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. 08-SEP-95 MSC 1.32 DEP 2.042 / NGP 5.74 MEMORY 9549.0 9343.0 9549.0 0 26.1 45.0 TOOL NI/MBER NGP 110 3.750 9268.0 FLO- PRO 9.00 70.0 9.4 39000 5.4 .000 .000 .000 .000 .0 133.3 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA INC. D.S. 9-36C PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 9549.000000 Tape File End Depth = 9255.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4074 datums Tape Subfile: 6 71 records... Minimum record length: Maximum record length: 18 bytes 1014 bytes Tape Subfile 7 is type: LIS 96/ 5/20 01 **** REEL TRAILER **** 96/ 5/2~ 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 21 MAY 96 4:48a Elapsed execution time = 0.83 seconds. SYSTEM RETURN CODE = 0
