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204-144
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Hilcorp North Slope, LLC DATE: 01/14/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU W-27A (PTD 204-144) Reservoir Performance Monitor 07/31/2021 Includes Analysis Please include current contact information if different from above. Received By: 01/20/2022 37' (6HW By Abby Bell at 9:04 am, Jan 20, 2022 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU W-27A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-144 50-029-21894-01-00 12205 Conductor Surface Intermediate Production Liner 9046 80 2661 10732 359 1693 12168 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9040 40 - 120 39 - 2699 38 - 10767 10506 - 10865 10512 - 12205 40 - 120 39 - 2699 38 - 8576 8399 - 8643 8403 - 9046 11820 2260 4760 5410 10530 None 5020 6870 7240 10160 11161 - 11810 4-1/2" 12.6# L80 36 - 10569 8795 - 8962 Structural 4-1/2" TIW Packer 10425 10425 8345 Stan Golis Sr. Area Operations Manager Brian Glasheen Brian.Glasheen@hilcorp.com 907.564.5277 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028262 No SSSV Installed 36 - 8442 8345 N/A N/A 145 218 1634 1237 2145 2321 1600 1610 247 271 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 8:58 am, Oct 11, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.08 18:10:43 -08'00' Stan Golis (880) DSR-10/11/21SFD 10/11/2021MGR11OCT2021 RBDMS HEW 10/11/2021 ACTIVITY DATE SUMMARY 10/3/2021 T/I/O = 1350/1600/250 (Assist E-line) 4 bbls 60/40, 190 bbls crude pumped to load the tubing. 48 bbls pumed to assist E-line down hole. FWHP = 300/1525/150, E-line still on well upon departure. 10/3/2021 ***WELL ONLINE ON ARRIVAL, DSO NOTIFIED***(adperf) RIH W/ HES 2" x 23' MAX FORCE GUNS PERFORATE 11475'-11498' USING 2", 6 SPF, 60 DEG MAXFORCE CHARGES. RIH W/ HES 2" x 23' MAX FORCE GUNS PERFORATE 11161'-11184' USING 2", 6 SPF, 60 DEG MAXFORCE CHARGES. CORRELATED TO SLB PERFORATION RECORD DATED 6-AUG-2009. ***WELL LEFT S/I, TURNED OVER TO DSO*** Daily Report of Well Operations PBU W-27A STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISN 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 ® 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 ❑ Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-144 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21894-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU W-27A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 12205 feet Plugs measured feet true vertical 9046 feet Junk measured 11820 feet JUN 13 2017 Effective Depth: measured 12168 feet Packer measured 10439 feet true vertical 9039 feet Packer true vertical 8354 feet AOGC/ Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 40-120 40-120 Surface 2661 13-3/8"68#NT-80 39-2700 39-2700 5020 2260 Intermediate 10732 9-5/8"47#L-80 38-10770 38-8578 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 40-10572 40-8444 Packers and SSSV(type,measured and 4-1/2"TIW Packer 10439 8354 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JUL 2 4 2017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 226 522 791 1633 263 Subsequent to operation: 529 1451 3375 1596 272 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development ® Service 0 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 ❑ WAG 0 GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleum En.' eer Contact Email: Cale.Peru@bp.com Authorized Signature: 7, / Date: 6//3.l 17 Contact Phone: +1 9075644522 Form 10-404 Revised 04!2017 e ��/� V 'Ft- 711-1`J RB DMS l,' J U 6N 1 3 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 JUN 13 2017 RE: BP Exploration (Alaska), Inc. OGOO Report of Sundry Well Operations Summary ' ' June 12, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well W-27A, PTD #204-144. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. 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JOe4q) CCa a) aavCDCCU_ ricooOCam o acLpiiQ LLI _1 > 03 '-- w O O O O •m > 0McnZJZz W fxZuCLixZuCCcrZuCCcep ¢ : < : : -JCCCC2E0Cca0Ua0Cu) c) aa.. cCu) c) a0Ccco0Ua * : as cCv>iQ W I-- Q '- I,- '- } 0 0 ~ r ' N N _> r r I= n tp to -Co U Q • ! z 0 L cc w N d co = W Z E E N co w = CD m H Q J * u) 0W • — ti cc LT- 0 N Q Q d z Tr 0 re 0 r 9+ Q' Z 0 W = CL cnZ O W o a2 0 <z a) 0 Z I- 0 N- N N N co M m N 1 U, 11-41:t= , I/16"MCE.VOY • WELLHEAD= FMC l-27A SAFETY NOTES;WELL ANGLE>70°@11554'. ACTUATOR= BAKER OKB,ELEV= 90.87.1 I BF ELEV= 52 72' KOP= 3000' Max Angie= 82'@ 11168' l-•'CONDUCTOR, I ? I 2116' I-4-1/2"OTIS SSSV tom',D=3.813" J [1 Datum P1)= 11606' .._._.#• Datum TVD= 8800'SS ID=19 124" 13-3/8"CSG,68#,L-80,D=12.415" 1-j 2699' - GAS LFT MANDRELS ST M) TVD DEV TYPE VLV I LATCH PORT DATE 6 3006 3005 8 MERLA DOME RM 16 01/22/16 5 6087 5358 44 MERLA DOME RM 16 01/22/17 4 8074 6779 49 MERLA DOME RM 16 01/22/16 Minimum ID =2.44" @ 11866' 140. 3 9239 7547 47 MERLA MYj RA 0 08/25/04 !TOP OF 2-7/8" LINER 2 9929 8007 47 MERLA SO ! RM 24 01/22/17 <' 1 10270 8239 47 MERLA "DMY RM 0 02/16/15 44 IIN 4 STA#1=CEMENTED 40 -10224' -TOP OF CMT 1V IA(01/15/16) 44 4 10375' 4-1/2"OTIS SLD SLV,D=3.813" '110425' j-4-112"TBGSEALASSY 10425' 9-5/8"x 4-1/2"TNV PKR D=4.0" CMT SHEATH TOC,D=2.71"(01/31/16) - 10493' " 10493' 4-1/2"OTOSX NP,D=3.813' TOP OF 7"LNR H 10506' HTOPOF3-112"X3-3/16X2-7/8"LNR(CEMENT D) H 10512' t 10517 3-1/2'SKR DEPLOY SLV,D=3.00" iN N. Illi K. 10531' 4-1/2"O11S XN NP,MLLE)TO 3.80"(BAND LNR) 13-1/2"LNR,8.81#,L-80,.0087 bpf,D=2.99" H 10561' ' ' 11; fiF 10551' _I-3-i/2"X NP,D=2.813" 14611 4-1/2"1130,12.6#,L-80,.0152 bpf,D=3.958" H 10569' t ESP' ig 311. 9-5/8"CSG,47#,L-80,D=8.681" - 10767' ' 10561' I-3-1/2"X 3-3/16-XO,D=2.786" 10669' _-I4 1/2"VVLEG,D BEHIND =3.958" GT LNR 7"MECHANICAL VVHFSTOCK j- 10865' w/RA PIP TAG @ 10870' I 10671' ' Hu LOGG®08/11/92 7"LNR,26#,L-80, .0383 bpf,D=6.276" - 10865' MLLOUT WINDOW(W-27A) 10865'-10870' '/� 11820'CTM -FISH:CBP MILL&RSH(01/31/16) r/111 ` *'/. 11865' -3-3/16- 2-718"XO, PERFORATION SUMMARY 0=2.44" REF LOG:IvICri1JCC/GR OF 8/24/2004 �'� � 41. TE-IN LOG:GEOLOGY FOC LOG alta ANGLE AT TOP FERE:81'@ 11201' Note:Refer to Production C8 for historical perf data SIZE SPF INTERVAL -Opn/Sqz SHOT SQZ 3-3/16-LNR H11865' ` + 6.2#,L-80 SR, -SEEM 2 FOR FORE SUMMARY- ' , 0076 bpf,D=2.80" PBTD - 12170' I I I I I 2-7/8"LNR,6 16#,L-80,.0058 bpf,D=2.441" JH 12205' DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY MIT 11/23/88 GRV ORIGINAL COMPLETION JJ 02/14/17 ZVIJM) GLV CIO(01/22/17) WELL: W-27A 08/25/04,JLMIPJC CTD SIDETRACK(W-27A) 05/18/17 BTIWJM}ACFERFS(05/12/17) PERMT No: 2041440 01/26/16 CJS/TLH SET PLUG(01/03/16) _ API No. 50-029-21894-01 01/27/16 JGUTLH CMT A/MILL PLUG(01/15/16) SEC 21,T11N,R12E,910'FNL&1445'FEL 02/15/16 SJW/JMJ CMT SHEATH(01/31/16) 12/28/16 JUJMD GLV C/O(12/23/16) i BP Exploration(Alaska) TREE= 7 116"MCEV OY I — •WELLFEAD= FMC W-27A SAFETY NOTES:WELL ANGLE>70°@ 11554'. ACTUATOR= BAKER OKB.ELEV= 90.87' ( i BF.ELEV= 52 72' KOP= 3000 Max Angle= 82°@ 11168' r/ Datum PU= 11606' Datum TVD= 8800'SS i. It 4 lir 1 ki I I pi 4 V go '! d 4. PERFORATION SUMMARY 0 REF LOG-MC>•t/CCJGR OF 8/24/2004 , 1E-1N LOG:GEOLOGY FOC LOG A NGLE AT TOP PERF:81°@ 11201' 1 Nate:Refer to Production DB for historical perf data r SIZE SPF INTERVAL 1Opn/Sgz SHOT SOZ ' nI 2" 6 11201-11231 0 05/12/17 k 41 2' 6 11272-11302 0 05/12/17 2" 6 11357-11387 0 05/12/17 2" 6 11377-11429 0 05/12/17 &)111 , 2" 6 11436-11456 0 12/23/16 , 2" 6 11555-11560 0 08/07/09 2" 6 11585-11595 0 08/07/09 2" 6 11610-11620 0 05/08/06 f 2" 6 11621 -11640 0 05/08/06 r 2' 6 11670- 11700 0 08/24/04 '� 2" 6 11740-11810 0 08/24/04 W'' Aye`*+ N, lik 440,.. N 14444 P 4�av DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDI-OE BAY UNIT 11123/88 GEN Of4GINAL COMPLETION 02/14/17 ZV/JM) GLV C/O(01/22/17) WELL_ W-27A 08/25/04 JIM/PJC CTD SIDETRACK(W-27A) 05/18/17 BTNJM)ADPERFS(05/12/17) PERMIT No 2041440 01/26/16 CJS/TLH SET PLUG(01/03/16) AR No 50-029-21894-01 101/27/16 JGLITLH CMT LA/MILL PLUG(01/15/16) SEC 21,T11N,R12E,910'FNL&1445'FEL 102/15/16 SJW/JM)CMT SHEATH(01/31/16) 112/28/16 JL/JM) GLV C/O(12/23/16) BP Exploration(Alaska) RECEIVEU STATE OF ALASKA I JAN 12 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® 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: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 204-144 3. Address: P.O.Box 196612 Anchorage, Development f] Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21894-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PRUDHOE BAY UNIT W-27A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12205 feet Plugs measured feet true vertical 9046 feet Junk measured 11865 feet Effective Depth: measured 12168 feet Packer measured 10439 feet true vertical 9039 feet Packer true vertical 8354 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 40-120 40-120 Surface 2661 13-3/8"68#NT-80 39-2700 39-2700 5020 2260 Intermediate 10732 9-5/8"47#L-80 38-10770 38-8578 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11436-11456 feet 11555-11560 feet 11585-11595 feet 11610-11620 feet 11621-11640 feet 11670-11700 feet 11740-11810 feet True vertical depth: 8844-8847 feet feet 8874-8875 feet 8884-8887 feet 8892-8895 feet 8896-8901 feet 8910-8920 feet 8934-8962 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 40-10572 40-8444 Packers and SSSV(type,measured and 4-1/2"TIW Packer 10439 8354 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED MAS, 6 8 n i', 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 219 297 1038 1732 249 Subsequent to operation: 245 360 1309 1737 263 14.Attachments:(required per 20 AAC 25 070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations fa Exploratory ❑ Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro)/� Title PDC Principal Engineer Signature V. Phone +1 907 564 4424 Date 1/12/17 �� TL 2/« / /3- �p Form 10404 Revised 5/2015 ���� RBDMS 1 V 2017 Submit Original Only S m Q, 000 CDO CO RI (112 C N e tt 01 V O O O O up O OD CV Tr Tr co op m Lo CO y- O O 00 07 r- T- CO Tr f— Tt07OoTr V CV r- up CO Tr CD O d' T- CV 00 OD co OD CD O Ch f,- T- O CD CO O O M OD O (( 000000 C '*r a E .' 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ACTUATOR= BAKER OKB.ELEV= 90.8T BF ELEV= 52.72 1 KOP= 3000' Mu(Angle= 82°@ 11168' _,"CONDUCTOR, — 7 Ma2116' 1—4-112"OTIS SSSV NP,D=3.813" lirl Datum MD= 11606' v#, , Datum TVD= 8800'SS ID=19.124" 13-3/8"CSG,68#,L-80,ID=12.415' --I 2699' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 6 3006 3005 8 MERLA DOME RM 0 01/22/16 5 6087 5358 44 MERLA DOME RM 0 01/22/16 ►' N 4 8074 6779 49 MERLA DOME RM 0 01/22/16 Minimum ID =2.44" @ 11865' 3 9239 7547 47 MERLA DMY RA 0 08/25/04 TOP OF 2-7/8" LINER 2 9929 8007 47 MERLA SO RM 0 01/22/16 1;04 491 1 10270( 8239 47 MERLA "DMY RM 0 02/16/15 STA#1=CEMENTED —10224' TOP OF CMT N IA(01/15/16) 0 10375' 4-1/2'OTIS SLD SLV,D=3.813" 1 I I p 4 10425' 4-1/2"TBG SEAL ASSY 1 .Z!: F...774110425' }—9-5/8"x 4-112"11WR<R D=4.0" PM Ey. CMT SHEATH TOC,D=2.71'(01/31/16) H 10493' P11144`- 1j 10493' 4-112"OTIS X NP,D=3.813" TOP OF 7"LNR 10506' / r 1 .' 1 .' TOP OF 3-1l2"X 3-3/16"X 2-7/8"LNR(CEMENTED) —{ 10512' ►i1 1 • ' 10512' }—3-1/2"BKR DEFLOY SLV,D=3.00 r I147.'• 10531' }—4-1/2"OTIS XN NP,MLL®TO 3.80"(BEHIND LNR) 3-1/2"LN2,8.81#,L-80,.0087 bpf,D=2.99" H 10561' �01 10551' 3-1/2"X NP,D=2.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" 10569' ;(, oh4 9-5/8"CSG,47#,L-80,ID=8.681" 10767' X4N , %' 10561' 3-1/2"X 3-3/16"XO,ID=2.786" 10569' 4-1/2"WLEG,13=3.958" BEHIND CT LNR 7"MECHANICAL WHPSTOCK 10865' 10571' H SMD TT LOGGED 08/11192 ' 10 w/RA PIP TAG-, 10870' 7"LNR,264,L-80,.0383 bpf,D=6.276" 10865' MILLOUT WINDOW(W-27A)10865'-10870' PERFORATION SUArf MRY 'J' 11820'CTM 1—FISH CBP RILL&PUSH(01/31/16) REF LOG:MCNUCC/GR OF 8/24/2004 1 '' TEN LOG:GEOLOGY RDC LOG '4 11865' —3-3/16"X2-7/8"XO, ANGLE AT TOP PERF:81'@ 11436' ' �'oto ID=2.44" Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ iii2" 6 11436-11456 0 12/23/16 .4:,..,. ..„.�.Nr,,�, 2" 6 11555-11560 0 08/07/09 �! _ X44' 2" 6 11585-11595 0 08/07/09 3-3/16"LNR, H 11865' 2" 6 11610-11620 0 05/08/066.2#,L-80 STL, 2" 6 11621-11640 0 05/08/06 .0076 bpf,D=2.80" PBTD — 12170' 2" 6 11670-11700 0 08/24/04 2" 6 11740- 11810 0 08/24/04 2-7/8"LNR,6.16#,L-80,.0058 bpf,ID=2.441" H 12205' DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/23/88 GRV ORIGINAL COMPLETION 01/26/16 JK/TLH GLV C/Os(12/31/15&1/21/16) WELL: W-27A 08/25/04,JLM/PJC CTD SIDETRACK(W-27A) 01/26/16 CJS/TLH SET PLUG(01/03/16) PERMIT No:' 041440 03/01/13 KUJMD SCHEMATIC CORRECTIONS 01/27/16 JGL/TLH CMT IA/MLL PLUG(01/15/16) AR No: 50-029-21894-01 02/20/15 PJC REFORMAT CSG/TBG 02/15/16 SJW/JMD CMT SHEATH(01/31/16) SEC 21,T11 N,R12E,910'FM..&1445'FEL 04/11/15 GRC/PJC OKB DEPTH CORRECTION 12/28/16 JL/JMD GLV GO(12/23/16) 01/26/16 DLW/TLH SET/PULL PLUG(9/12/15&01/01/16) BP Exploration(Alaska) CD4-‘4� ECEINi ‘ • • 2_1-62-imp rd.allWeign3 BAKER DEC 2 0 201' PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME W-27A 900 E.Benson Blvd. M Kms'/2p1 Z hA.K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE November 28,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares a(�bakerhughes.com TODAYS DATE December 19,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: FIELD/ COMPANY FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO$ LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OFnPRINTS #UI-I'KIN I S - r#OF COPIES #OF COPIES #OF nCOPIES V V V V V V V 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 1 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 I 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stam. "confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 0 I 0 I 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMN 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 IZI Plug for Redrill 0 Perforate New Pool 0 Repair Well I1 Re-enter Susp Well 0 Other:Set LTP/Cmt LT or LTP 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-144 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21894-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number: PBU W-27A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: � ,, Total Depth: measured 12205 feet Plugs measured feet " ED true vertical 9046 feet Junk measured 11820 feet FEB 1 1 6 2016 Effective Depth: measured 12168 feet Packer measured 10435 feet L f� U true vertical 9039 feet Packer true vertical 8351 feet O GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 41 -121 41-121 0 0 Surface 2661 13-3/8"68#NT-80 41 -2701 41-2701 5020 2260 Intermediate 10732 9-5/8"47#L-80 38-10770 38-8578 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11555-11560 feet 11585-11595 feet 11610-11620 feet 11621-11640 feet 11670-11700 feet 11740-11810 feet True vertical depth: 8874-8875 feet feet 8884-8887 feet 8892-8895 feet 8896-8901 feet 8910-8920 feet 8934-8962 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 36-10568 36 a 8441 Packers and SSSV(type,measured and 4-1/2"TIW Packer 10435 8351 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): In IA 10224'-10425'. o l 't Treatment descriptions including volumes used and final pressure: scNED 324 Bbls KCL,35.5 Bbls 15.8 ppg Cement,75 Bbls PowerVis,140 Bbls Fresh Water,100 Bbls Methanol/Water,812 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 320 1197 1336 1437 289 Subsequent to operation: 1225 0 2036 1620 288 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development QI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IZI 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: 315-217/315-711 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer - Signature 44/14°T Ct7& Phone +1 907 564 4424 Date 2/16/16 Form 10-404 Revised 5/2015 17 ` 7l!(� 3 l it r l L Submit Original Only Y RBDMS w FEB 1 8 2016 • • N0 0 0 0 Q m O — 00 O O N 11) Io m I� U 0 i N N- Ln O 3 O N- M g m m CO O I-- -a' co 00 v N ti l() CO v 6) O N 00 CO CO CO CO H I� - A- 00 O O M M O V- M V V O M MMMM w Ou7MM r- f� M O O O M N N- 00 In 00 N lf) - 000A- NO A- A- r A- O p m 2 lllllQ 4-0 QF 00 N U) N � � aoO CO (OM 1 V V M M IU M W O O O .- M • 03 I- a O co O CD M O00 O- H 00 00 00 W O J -6 *k N 'N N c M * W A- u) U � � N °o _ co " U � M _ - 176 M O M M N V pn O I� O 0 O M d O N O M = M O J � cC W C 0 Q ' 0 W W M D < 0 U (21 u_ CC D Z Z e[ W W W W w m O D H Z Z Z Z_ J U Z J 11 J J F- • • 7 0 0 > co vi Q o o) Q m aai o ° ° c r in a) -,L- c a) o � (D 7. 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N � . � ornoCC) O ti o 45 L �� s cn c aE) > 0 rn a�\o E co M@©@ a :- — co 3 0)COa � .c as * — ,,, ., 0) (J) * (nfAF- HHS ,F C O ' t C3) caH O a) (0w0_ w V d• . * COihtiwwL7N2 O U Cf) U C Q E 0 J O O * •- ca r- Z Z Z 4tJ -t mU 0)C ' N _H -a ,- O NZ _ ma � coV .- N CDN fnin inp • a * Qc'i O 2 ,— OU) ©©©H N `- V@O ON) CD Z v ow i O a 70 m Ea 0 UN Co O ZN (1 u) (\I O cDcn � O • N 3 0 _a ' C a) N w O M p *k J III 0 cn `— (‘:-2 � a) LoIT) a) > aNi � � :- Q O � �SN � H � � OHH000 0 � H >, N a 8 ca N p- Q-0 — _ (n (n0_ pZ (n (n C1 W . � �z m rn� � 6N coo � _ � Ho_ 2 2p � � 2 � � > CI U �' .c o E c=—° m HSN w � Z000HwwOOvcr � - w0 a) w H 0' o: co co co H E 0) vo0_ E � 73I is >,°) 3 a3 ZwmUc� wwaZ_ Z_ wwcOcocoNUa - cV Co 0 � Eo -2W Q � 0) HC O -. coa -I _--iwHHJJ » > J � � o) ca o �c � o- 17; ,a- z 3 0Hvc' _ CCH00000000 = r- Qas U U C E ` U -O C = (� H CV i i H J J J O N H a) C ca N O = E2 O a) 0- j ' 2 2 0 0 0 i i �* ami Dcn � � � o u E � � 2HH � 0: 0' � � � 0' 0_ � � � � � J � C C ECp -5 QO i. 0 � Lo - u) wILL . JJw (>A (>n J Jrx HO_ 0_ 0_ Jw J J Y » J J O ) O0- U C -45c? � NHCL ,- � x Q ( C) U) 0- 0_ 2 : : 0_ 0- U) U) U) U) 0- : CD CD CD CD a O O O O N N N � C Lr) O - N a- CVa— N N • • -0 = _ -o o & § § f C £ ° E 2c) 020 g e s E 0) o o/ o E o& = t \ \ § cu(3) co / 22c= E ¢\ o > g \ £ .s ,- -o \ @ 6 / o 0 o Cl E 2 E a % -o o o 2 \f / 5 / \ 2 § % $7 I \ % 2 $ r 2 \ / co r 2 & 5 & 2 a e O & E 2 CO 0_ 73 ©Lqw 0 M \ b 2 k k C \ q g 03 L.' ¢ 2 E \ k 3 ¢ O b a I E - 5 \ L'130 -c.~,5 m k / % o_ E = C \ \ $ 0 . \ ® G m n o = a 9 \ � % •oEa= \ f \ & J � .¥ m 2 o o $ 3 _ _0°--Es E\ > ( fE % 2 / �O O # la- 46 a E t m . 0 7 - 0 0 a) Q O \ . , EEE \ \ \ Q a -\ � E § o / 2 2 • JD \ \ _ 2 f_ -0 a) \ CO / cc b ƒ $ / E / E O \ —M co » « �2n• co cy) � 20 D o - _ > w \ 0 // O / co o7 \ oE / -/ R = f / = m - E - m I / ,- . a) -- ,-- - *- f / \ » \ G 2°)\ ® � r * 2 2 0 0 § & E c 0 't Q. $ _ . co, 0 \ ( kfU ,y5 0- DOQ-O $ o / / \/ \ kf = o ._ / @ / / / § 0 f \ / ?/ \ S f t / / CO o 2 / / O 2 t O t ± 2 e w \ E a e ; d O 2 y Y .- 0_ ± e ,- (0 e / d / ( L° CNCD ( \ CO \ CO (0 M A � TREE-=,. i/16"MC EVOY WELLHEAD= FMC - ' SAFt i Y NOTES:WELL ANGLE>70°@ 11554'. 1N 2 7A ACTUATOR= BAKER OKB.REV= 90.87' [I BF.ELEV= 52.72' Zi KOP= 3000' Max Angle= 82°©11168'' -"CONDUCTOR - ? Cil 2116' }--.4-1/2"OTIS SSSV NP,D=3.813" Datum MD= 11606 _....#:. Datum TVD= 8800'SS D=19.124" 13-3/8"CSG,68#,L-80,13=12.415" -1 2699' GAS LET MANDRELS ® MD TVD DEV TYPE VLV LATCH PORT DATE Ell6 3006 3005 8 MDOME RM DORM 0 01/22/16 5 6087 5358 44 MERLA DONE RM 0 01/22/16 , . `4-fl 4 8074 6779 49 MERLA DOME RM 0 01/22/16 Minimum ID =2.44" @ 11865' '.f,F.i3 9239 7547 47 MERLA DMIY RA 0 08/25/04 TOP OF 2-7/8" LINER . 2 9929 8007 47 MERLA SO RM 0 01/22/16 , 1 10270 8239 47 MEZLA `DMR' RM 0 02/16/15 ..'t., STA#1=c E? 1TEf ,f: j -10224' -TOP OF CMT N IA(01/15/16) ,Y. <` 10375" }-4-1/2"OTIS SLD SLV,D=3.813" f 10425' 4-1/2"TBG SEAL ASSY Amd 10425' 9-5/8"x 4-1/2"TNV PKR,D=4.0" CMT SHEATH TOC,D=2.71"(01/31/16) H 10493' iirii 10493' 4-1/2"OTIS X NP,D=3.813" TOP OF 7"LNR --I 10506' '—, 1 4 TOP OF 3-112"X 3-3/16"X 2-718"LNR(CEMENT®) 10512' '`1 X.' t 10512' 3-1l2"BKR DEPLOY SLV,D=3.00" A7 1.'.' � 10531' J--4-1/2"OTIS XN NP,MILLED TO 3.80"(BEHIND LNR) 3-1/2"LNR,8.81#,L-80,.0087 bpf,13=2.99" H 10561' 10551' H3-1/2"X NP,D=2.813" x 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" 10569' IM 9-5/8"CSG,47#,L-80,D .=8.681" H 10767' F x ' 10561' }-3-1/2"X 3-3/16"XO,0=2.786" BEHIND : : ti 10569' .1-4-1/2"WLEG,D=3.958" CT LNR 7"MECHANICAL WHPSTOCK 10865' x•.. >! 10571' -{ ELM)TT LOGGED 08/11/92 w/RA PIP TAG @ 10870' .,., 7"LNR,26#,L-80,.0383 bpf,D=6,276" -1 10865' •" x":>:::: MIL LOUT WINDOW(W-27A) 10865'-10870' PERFORATION SUMMARY . lir nib._ 111820'CTM —FISH CBP MLL&PUSH(01/31/16) I LOG:MC N JCCJGR OF 8/24/2004 tr. Ii TE-IN LOG:GEOLOGY PDC LOG M... '4� 11865' —3-3/16"X2-7/8"XO, ANGLE AT TOP PERF:71°©11555' �,1E ID=2.44" Nate:Refer to Atoduction D13 for historical perf dataPiN.,,. .„.„,,, ,,„,,,,,,, SIZE SR= INTERVALOpn1Sgz SHOT SQZ INTERVAL 2" 6 11555-11560 0 08/07/09 2" 6 11585-11595 0 08/07/09 2" 6 11610-11620 0 05/08/06 3-3/16"LNR -I 11865' 2" 6 11621-11640 0 05/08/06 o ' ',1 6.2#,L-80 STL, 2" 6 11670-11700 0 08/24/04MITILA-AL « .0076 bpf,D=2.80" PBTD H 12170' 2" 6 11740-11810 0 08/24/04 2-7/8"LNR,6.16#,L-80,.0058 bpf,D=2.441" H 12205' DATE REV BY C)k*&NTS DATE REV BY COMMENTS PRI UHOE BAY UNIT 11/23/88 GRV 'ORIGINAL COMPLETION 01/26/16 JK/TLH GLV C/Os(12/31/15&1/21/16) WELL W-27A 08/25/04 JIM/RIC CTD SIDETRACK(W-27A) 01/26/16 CJS/TLH SET PLUG(01/03/16) _ F RMT No:"?041440 03/01/13 KUJMD SCHEMATIC CORRECTIONS 01/27/16 JGUTLH CMTIA/MLL PLUG(01/15/16) AR No: 50-029-21894-01 02/20/15 PJC REFORMAT CSG/TBG 02/15/16 SJW/JME/CMTSHEATH(01/31/16) SEC 21,T11N,R12E 910'FNL&1445'FEL 04/11/15 GRC/PJC OKB DEPTH CORRECTION 01/26/16 DLWT LH SET/PUL RUG(9/12/15&01/01/16) BP Exploration(Alaska) OF 7�� • • �w���\I%%i�s� THE STATE Alaska Oil and Gas &0 `-sem 91 of///�/•�`y� TIAS ///./e��� Conservation Commission fir' -:-414. i .��'��i i u ffi}x - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 QFALASIO'' Fax: 907.276.7542 www.aogcc.alaska.gov Brenden Swenson SCANNED FEB 1 i 2016 Production Engineer 4-1+BP Exploration(Alaska), Inc. 0 - i P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-27A Sundry Number: 315-711 Dear Mr. Swenson: 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, /074-- - 07 Daniel T. Seamount, Jr. Commissioner DATED this 7 day of December, 2015 Encl. RBDMS' DECC 0 9 2015 OF RECEIVED E ALASKA OIL AND GASTCONS CONSERVATION COMMeN APPLICATION FOR SUNDRY APPROVALS Nn\ 2 0 7015 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well Q Operations shutdown[0 1/ Suspend ❑ Perforate ❑ Other Stimulate CI Pull Tabing CI Change Approved Program Lk1 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other Cemerltm.U1 r Top Q` C+` ` TT 2. Operator Name: BP Exploration(Alaska),Inc , 4. Current Well Class: 5. Permit to Drill Number 204-144 Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development Q, 3. 6. API Number: 50-029-21894-01-00 . 99519-6612 Stratigraphic ID Service ❑ 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 ❑ No l I PBU W-27A . 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028262 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12205 ' 9046 - 10408 . 8333 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 39-119 39-119 0 0 Surface 2660 13-3/8"68#NT-80 38-2698 38-2698 5020 2260 Intermediate 10731 9-5/8"47#L-80 35-10767 35-8576 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 4-1/2"12.6#L-80 L-80 33-10565 Packers and SSSV Type: 4-1/2"TIW Packer Packers and SSSV MD(ft)and TVD(ft): 10432, 8348.87 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary Q Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q, Service ❑ 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Q . WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Swensen,Brenden be deviated from without prior written approval. Email Brenden.Swensen@bp.com Printed Name Swensen,Brenden Title Production Engineer Signature e'''.. �`/ ✓. I'/ • ( Phone +1 907 564 4887 Date i 1 /2o /' COMMISSION USE ONLY / Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 316 ---11 I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes❑ No ❑ Spacing Exception Required? Yes 0 No Id Subsequent Form Required: /¢C.-" - V C'I APPROVED BYTHE Approved by: ?KZ COMMISSIONER COMMISSION Date: /Z.(7/LS ?/Z II/237/ o (� q•L� P. 45-.t.5-- 0 _l. �/3�, ......— ORIGINAL C- -C13\f RBDM& DEC 0 9 2015 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • N O O 0 0 Q CA lC N IT r NO O O 0 N eY U ''' 000 00 i N CO LOC) co cr O O N v cr m LO CO N- co m co 0) co CO d t— N O O) O) I,- CO CO CO N V' CO v- CO O co r O) CA O r (NI co co co co co Cs) co H O co r C)) co CO 6) O CO CO co co co co co co cr 00 O) CO CO CO CO CO CO co I La O up O O 0 coo) CO co co CO 0) N cc N O O N v- v- V- V- V- V- V- C) - V N 2 C 1 1 1 1 1 1 1 1 1 .-N CO n N 10 In Loc) N CO CO : : : :CO O II CO C Z COO J O J -I C Z N N O CO N CO co N c0 v� U ° _ N _°° - CV V o f NMO i C7 i M M r cn O Co M O O) OCD CD CO O co 0 CO N O �F V M O V W � Q C 0 U W Z W W W W W W m O D ' Z Z Z Z Z D U Cf Z J J J J J I— • • a, N a7 m r r r I. CN LO L CO N N N CD CD C(j N LO r O N N. 00 O CD N CO p 00 O0 00 O) C) C) ❑ 00 00 co o0 CO CO I- O. O CO N O) r r CO « CO CO CD In CO Cl M C`7 N O V' a) N. CO CA O) r M W ❑ CO CO CO CO CA CD ❑ CO CO CO CO CO CO 0 ~ w W C] W gg Q o0 J CL W rn Y O O CO 6 0 0 0 0 O O J U V LLijcc L.L.1 CO CD N O r J J J Q Q V) W CC = QLOLOCOCONCO < < < W a _ • r r r r r r U_ _U U W W co)CD Z Z Z O Jp p J = a W a 0 0 0 W e Q Z cj Z W W W CL I— H Q J Q C.) 2 2 2 O CO cn cn cn cn ao C r IDLUCD - 00 p, 6f) CO r N N. O Q LO LO CO CO CO I� `N N r r r r r r N L. O - cn = IU— 0 W J a 2 2 2 O cn cn cn <n co d a, O U O• Cn u) u) u) Cl) u) a 0_ d ❑.. Cl Q O ;Emmmmmm Cl O a, m a a) I— io LO LO Ln LO CO LO :•D ❑ r r r r r ❑ D D c 0 0 0 O O O W J J Z O N N N N N N Z 1 0 Q W N N N N N g W ❑ W W N W te`, z a ) J ) U W L.L. W O rn rn rn rn rn rn m O D j w J J J D (L E z Q Q Q Q Q Q N. ti N. N. N N N N N N N W LL u) O LL N LL � � � � � m m00accaQ 0 � TREE= WELLFEAD_1116" (3�Y • W-2 7A I say NOTES:WELL ANGLE'70°@ 11554'. ACTOKS.ELEV= 90.87' 1 I SF.ELEV= 52/2 Z KOP= 3000' _ Max Angle 82°@ 11168 -"CONDUCTOR - ? Q 2116' 1- 41/2'OTIS SSSV NIP,ID=3.813" Datum MD= 11606' s,#, , Datum TVD= 8800'SS ID=19.124" 1 13-3/8"CSG,68#,L-80,D=12.415" 2699" GAS LIFT MA1`Df2f3S ST PAD IVO DEV TYPE VLV LATCH PORT( DATE I 6 3006 3005 8 MERLA DMY RM 0 02/16/15 5 6087 5358 44 MERLA 'DMY RAA 0 02/16/15 4 8074 6779 49 NBRLA DMA' RM 0 02116/15 Minimum ID =244" @ 11865' 3 9239 7547 47 MERLA DMf RA 0 08/25/04 TOP OF 2-718" LINER 2 9929 8007 47 NERLA DMA' RA 0 08/25/04 1 10270 8239 47 MIERLA 'DMN RM 0 102/16/15 STA#5 =USE CLOCK&DECENTRALIZE?TO PULL&SET-10:30 STA#1=USE CLOCK&DECENTRALIZER TO RLL&SET-11:00 ( I ' 10375' 1—4-1/2"OTIS SLD SLV.D=3.813' ■ I 10425' —4-1/2"TBG SEAL ASSY �j V, ; 10425' _j9-5/8'x 4-1/2"TNN FKR,D=4.0" 10493' p—4-1/2"OTIS X NP D=3.813' TOP OF 7"LNR H 10506' TOP OF 3-1/2"X 3-3/16"X 2-7/8"LNR(02343?} ---{ 10512' I 10517 1-3-112 BKR DEPLOY SLV,D=3.00" 1 II 10531' ,1--4-1/2"OTIS XN NP,MLLE)TO 3.80"MUM LNR) II N' 10551' H3-1/2"X NP,D=2.813' 3-1/2"LNR,8.81#,L-80,.0087 bpf,D=2.99" 10561' III' 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958' 10569' ih • 9-5/8"CSG,474,L-80,D=8.681' H 10767' '" ' 10661' 3-1/2"X 3-3/16'XO,D=2.786"". BEH .r-: ! 10669' _-14-1/2'WLEG,D=3.958' 1 CT LNR ND 7'MECHANICAL w 'STOCK 's*. 10865' t.. ''' 10671' --1 t3MD TT LOGGED 08/11/92 w/RA PIP TAG(fa 10870' 7"LNR,264,L-80,.0383 bpf,ID=6.276" 10866' +. ►'t+ MLLOUT WNDOW(W-27A)10865'-10870' w,+ * R FORAT1ON SUNVIARY ' ~~ 'i FEF LOG:MChE/CC/GR OF 8124/2044 �' °'4 I 11866' H 3-3/16'X2-7/8"XO,D=2.44" P111'1411114 ' TEN LOG:GEOLOGY PDC LOG t.P111'141111. :'. y ANGLE ATTOP J :71°(.' 11555' .. Note:Refer to Ptaduction DB for historical perf data ilk64 , SIZE SPF NTERVAL Opn/Sqz SHOT SOZ �s 2" 6 11555-11560 0 08/07/09 . 2" 6 11585-11595 0 08/07/09 2" 6 11610-11620 0 05/08/06 at 3-3/16"LNR, lH 11865' 2" 6 11621-11640 0 05/08/06 l•4W4TON 62#,L-80 STL, 2" 6 11670-11700 0 08/24/04 i4444,444412170" .0076 bpf,D=2.80" PBTD ' , ' 2" 6 11740-11810 0 08/24/04 2-7/8'LNR,6.16#,L-80, 0058 bpf,D=2.441" H 12205' DATE FEV BY CONVENTS DATE REV BY COMFITS PRUD OE BAY UNIT 11/23/88 GRN ORIGINAL COMPLETION 02/18/15 G I3/PJC SET WFD ISO BRIDGE RUG WALL W-27A 08/25/04 JLM/PJC CTD SIDETRACK(W-27A) 02/20/15 PJC REFORMAT CSG/TBG PERMIT Pb: 2041440 09/29109 MV/SV ACPERF(08/07/09) 04/11/15 GRC/PJC OKB DEPTH CORRECTION AR No- 50-029-21894-01 03/01/13' KUJMD SCHEMATIC CORRECTIONS 08/10/15 TBLYJMD PULLED ISO BRIDGE RUG SEC 21;T111' R12E,910'FNL&1445'FEL. 02/10/15 JTG/JMD GLV GO(02/05/15) 02/16115 GJS/PJC GLV GO BP Exploration(Alaska) t • • p Soto To: AOGCC Date: April 9, 2015 From: Brenden Swensen, Orion PE 907-564-4887 Subject: W-27A Integrity Repair - Liner Top Packer Step Unit Operation 1 S Pull plug, reset plug 2 F CMIT-TxIA 3 S Contingent set LTP 4 F Contingent MIT-IA UPDATE 11/20/2015: Added the contingency if the liner top packer fails to pump cement into the IA to regain integrity. HISTORY W-27A was originally completed in 1988 and was coil drilling side tracked in 2004. Since being side tracked, the well has been relatively uncompetitive in the EWE LDF (East-West Eileen Large Diameter Flowline) and has remained shut in for a large portion of its life. The well produces at 80- 90% water cut and a TGOR of —12-14,000 scf/bbl. Since the opening of the U-Pad jumper, the EWE LDF's marginal TGOR has been 15-17,000 scf/bbl making W-27A competitive in the system. The well was brought back online mid-January of 2015. Since then, the well has failed multiple TIFL's, 2 being recorded at the-packer (10,425') on 2/7/15 and 2/12/15. The well subsequently failed a MIT-IA and CMIT-TxIA. The failed TIFL's, MIT-IA and CMIT-IA are believed to be due to a leaking packer. The leak by the packer is thought to be communicating with the tubing via the 3.5" liner top at 10,512'. There is —296' of cement inside the 7" liner between the tubing tail at 10,569' and the mill out window at 10,865'. There is another —690' of cement between the mill out window and the first perforations at 11,555'. This program seeks to pressure test the cement via a CMIT-TxIA to establish it as a competent barrier and forgo a packer repair. If the leak is indeed through the 3.5" liner top, a liner top packer will be set to re-establish tubing integrity. A MIT-IA will then be performed to re-confirm IA integrity and no TxIA communication. The alternative fix for the leaking packer is to open the sliding sleeve at 10,375' and circulate cement on top of the packer at 10,425'. This cement plug would only give an additional 144' of standoff from the current cement at 10,561' and is a more expensive fix that can complicate options for future sidetracks and rig work overs. If this program is successful, this option can be avoided. OBJECTIVE /Confirm inner annulus (IA) integrity by setting a plug in the 3.5" liner and perform a combined mechanical integrity test of the tubing and inner annulus (CMIT-TxIA). Upon a passing test, set a liner top packer (LTP) at 10,512' and perform a MIT-IA to confirm IA integrity. • • PROCEDURE 1. MIRU slick line and fullbore. Hold PJSM. 2. Pull bridge plug at 10,477'. 3. Set plug in x-nipple at 10,551'. 4. Fluid pack tubing and IA. Perform CMIT-TxIA to 2500psi. CONTINGENT IF PASS 5. Pull plug at 10,551'. X v,-( ('1'`-6 6. Set LTP at 10,512'. 7. Perform MIT-IA to 2500psi. 8. If pass, set live gas lift design. CONTINGENT IF FAIL (added 11/20/2015) 9. Slickline pull plug at 10,551'. 10. Eline set composite plug between 10560-10650' MD 11. Coil pump cement into IA via leaking liner at 10512'. Target TOC at -935.0° MD. ' a. Hold cement in place via hydrostatic differentials between IA and tubing _ • 12. Wait on cement, MIT-IA to 2500psi. 13. Mill out composite plug. Attachments A. W-27A Wellbore Schematic B. W-27A Proposed Well Barriers (assuming passing integrity tests) • • Attachment A: W-27A Wellbore Schematic F-4-1-. 116"MCFV OY W1LF[AD- 1MC W_27 A SAFETY NOTES:WELL ANGLE>70"@11554' ACTUATOR= BAKER 1 // OKB.EPV= 90.9' BF.ELEV- 52.72 KOP= 3000' 1 2116' —14-1/7 OTIS SSSV NP,D=3.813" Max Angle- 82 @ 11168' �'i'7 Datum MD- 11606' Datum ND= 8800'SS [13-3/8"CSG,68#,L-80.U=12 415" H 2699' GAS LFT MANDRELS lir ST MD TVD OW TYPE i VLV LATCH PORT DATE 6 3006 3005 8 NERLA 1 ILW Fa4 0 02/16/15 5 6087 5358 44 ME2LA I'DMY RM 0 02/16/15 Minimum ID=2.44"@ 11865' 4 8074 6779 49 ME LA DAM AIN 0 02/16/15 TOP OF 2-7/8"LINER 3 9239 7547 47 MERLA DAM RA 0 08/25/04 2 9929 8007 47 NERLA' DMY RA 0 08/25/04 1 10270 8239 47 /ARIA 1'DMY RM 0 02/16/15 STA#5 =USE CLOCK&DECFMRALI7 ER TO PULL&SET-10-30 STA#1=USE CLOCK&DECENTRALRH2 TO FULL&SET-11:00 If 10375' 441/2'OTIS SLID SLV,D=3.813" 1 10425 'r---4-1/2"TBG SEAL ASSY_ C 64 k CI MI 10425' -9-518'x 4-117 TIW 202,D=4.0" • _ 10477"ELM H4-1/2"4Yf D ISO BF�GE PLUG(2118x15) p 10493' —4-1/2"OTTS X NP D=3.813" L'G'A.:-.1e2 Ci"i t TOP OF T LM2—{ 10506' 1 a` I"iF ;T 3 V"k 1-S:6"X 2-7/8'LNR(CEMENTED) 10512' _ 10517 3-12"BKR DEPLOY SLV,D=3.00' 10631' (4-12'0716 XN t'MILLED TO3.60'(B8UM0 LI4 i 3-112'LIN;8.81#,L-80,.0087 bpf,D=2.99' 10561' 1, 10537- 3-1r2- ND did-NN,ID=Z.813^ ' ?� '4 N 1 re.[4-12'TBG.12.64.1-80..0152 bpf,D-3.958" 10569' M (IIIi i('' 9-5/8'CSG,47#,L-80,ID=8.681" H 10767' r 10561' 1-13-1/7 X 3-3116'X0,10=2.786' 11 BIND + 41 10569' 44-12'W-EG.D=3.958" i CTE LNR NR,26#,L-80,.0383 bpf,ID=6.278 10865 f 10571' ELM)TT LOGGED 08/11/92 7'MECHANICAL W FSTOO< H 10865' vi y w!RA PIP TAGS 10870' p I MLyOUTyyt,DOW(W-27A)10865' 10870' • FURFORATION St M 4A RY REF LOG:MCMJCC/GR OF 8/24/2004 • •''' 11866' H 3-3/18'X2-7/8'X0.D=2A4' TE-N LOG:GEOLOGY WC LOG1.1 ANGLE AT TOP PERP 71'®11555' ` `�'. Note:Refer to Production DB for historical pert data 16 tel., SIZE SPF INTERVAL Opn/Sqz SHOT SOZ `� 2' 6 11555-11560 0 08/07109 • � 2" 6 11585-11595' 0 08/07/09 4'4'4" 2" 6 11610-11620 0 05/08/06 go( 3-3/16"LHR, —{ 11885' 2' 6 11621-11640 0 05/08/06 ,�Maw 6.2#.L-80 STL, 2 6 116/0-11/00 O 0824/04 1 it "liei�i1i1i" .0076 bpi.D=2.80' RITE 12170' •. 2" 6 11740-11810 0 08/24/04 2-7/8"LW,6.168,L-80, 0058 bpi,ID=2441" — 12205' DATE REV BY COMM NTS DATE REV BY COM1,43173 PRIAi DC DAY UNIT 11/23/88 GM/ ORIGINAL COMPLETION 02/18/15 GJB/PJC SET WT)ISO BRIDGE PLUG WELL: W-27A 08/26/04 JLM/PJC CTD SIDETRACK(W-27A) ,02/20/15 PJC REFORMAT CSC/TBG POINT M,:204-144 09/29/09 W/SV ADFERF(08/07/09) AR Ni' 50-029-21894-01 03/01/13 KL/JM) SCHEMATIC CORRECTIONS SEC 21,T11N,R12E,910'FPL&144,5'FEL 02/10/15 JTG/JMD GLV C70(02/05115) 02/16/15 GJB'PJC GLV 00 BP Exploration(Alaska) • • Attachment B: W-27A Proposed Well barriers (assuming passing integrity tests) 1.41 = 116'REVVOY '1hiu(AD; l'I C VV-27A SAFETY NOTES:WELL ANCIE>70•(11554'. ACrUAIOK- HAKE/ OKB ED/- 90.9' BF.ELEV', 52,72 K(]P❑ 300; — AAuI Argle- 82' 11188 �C11 2116' 4-1rr orb SSSSv NP,D=3 81 7 Opium 1A3- 11606' Dllum TVD= M00'S.5 11:1-3/8-CSC:,661 --80,3=17 415' I-I 2691' ' GAS I F l MAFERR..S IffT MO TVD DEV TYFE ' VLV LATCH PORT DATE 6 3006 3005 8 1413.1A 1.3W Fill 0 02/16/15 ___- 5 6087 5358 44 M6LA s'D1& ill 0 02/16/15 Minimum ID=2.44"@ 11866' i 4 8074 6779 49 I&T&A I am RM 0 02/16/15 TOP OF 2-718" LINER 3 9239 7547 47 kE LA' CIM RA 0 08f2504 -„ 2 9929 8007 47 MH11A DMM F7A 0 0821.^04 1 10270 823+9 47 MULA 'DIM Fid 0 02/16/15 STA 65 =tLSFClOCK&Ot33YrRA11/FRTORa1 ASFT-10'30 STA111=USE CLOCK 8 DECENTRALFZER TO PULL&SET-11.00 10375' -44.162'0715 S.0 SLY.D•3.813' I MI Primary Barrier t. 10425 4-1?TBG SEAL ASST = Secondary Barrier 1 1042 9518'!4-112 11W PIED=I.2/ i _ i 10477"ELMH412'NfDRSOBROGERID(2)len5) I 10493' 4-1 rr OTIS x P41-,,,U=3.813' ,, i,. , 's" 1050h 1 E 11;1'/.lF s,rr a.ti.i-+e•x; ''''1. rvlt(. -' -ral- - 10517 -.-. ' 10512' =I'll/r WLRL131.C1Y 54_;,U-3,.00' ! 10631' I4 1/2'OTE)0NP,WILED TO 3.80'memo LT4R)I 3-112'LAR 0 018,L-83..0007 WT.D-2,98' 1•, .1' • • ,I 10561' s ire-x NY,u=2311 4-1/2'TBG,12.01 D ,L-80..0152 bpf, -1-965' 10SE9' I Ir, t I .9. 10561' 3-117 x 3-316-xo,D=2186' l 518'CSG,411,L80 D 8.681' 1076T I BEHIND I r ire,MI 1--50,.0883 Opt.D=6 278' J 10866' 10569 --I4 t?1A1J9Ci.D=3.958' CT LNR _._. L.._ I 10571' - RIAD TT LoGGEDEwil,S2 J 1-4ECFaN(AL Ina—s....la C -I 10686 40/RA PAP TAG®10070' q,(LOUTyf1DQW(W-VA)10565'.10870^ Wil F3RFORATDN&Ib1ARY "2'' kol‘o 41 ....."...1.2' 0•��� . . �: Fife LOG:MK7 � ■CpGR OF 8124/2004 • �+Gf .> 11866' ' 3-3/16'X2-716'XO,17=1.44' I -I 1E-N LOU.GEOLOGY MC LOG +1..6.414:44 A1411-A 110444!6 11'42;11»Y T k, NoesWW1 le F'roduellan 1E1 for flkloneal pert calla .>1, •. . 'SIZE SPF NFERVAL 'C n/Sgz S1CT S(IZt_4_' '"., 2- 6 11555-11560 0 081073Y9 `•_ �._� 2' 6 11585-11595 0 08707.99 '..•x. 2' 6 11610.11620 0 05/118.96' iii 3-115'Ira, -1186551 •'%,... A' ay e 2' 6 11621-11640 0 057061)6' ►q f' 4V1 6 25.-40 371-, ' `' 2' 6 11610-11/00 U L4/'/4,114 M44/0 A: 007G bpf,D-2.80' MIL ' 12170' �' `i=s 2' 6 11740-11810 0 08/24104 2..116'11%44,6 15. 11,-60. 0058 Opt,ID=7441'I� 12206'__.. I]4)T1 REV BY 00A4&141 S LA It REV BY 1 4NN,Q4TZ rcart IDC DAY LET 11/23/68 GRV 'OFIGINAL COMPLETION 02,18/15 GI&PJC SET'MD GORIO K''FRin Nei 1 1N-27A 061264)4 JLAIIPJC CTD 0CETRACK(W-27A) 0120115 PJC F* O1A41T G:iCI TOG PERM Nx 204-144 39/294)9 14)1 SV AF}FJY';084)7/091 AIR 147' 50-029-71894-01 33/01/13 KIJJM0'SC}f3.NTlC COf -CTP3PiS SEC 21,T11 P;R12E,910'TNL 8 1445'Fa 31/1615 JIG/At)G.V GO(C12/0):'15) 32/16/15 GIC.PJC GLV CO - OP Exploration Weak.) • • Schwartz, Guy L (DOA) From: Swensen, Brenden <Brenden.Swensen@bp.com> Sent: Tuesday, December 01, 2015 10:07 AM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T (DOA); Catron, Garry R(Wipro) Subject: RE:W-27A Repair( PTD 204- 144) Sundry 315-711 Hello Guy, Apologies for the late reply. I was out for most of the holiday and did not get to this yesterday. 1. The leak rate on the CMIT was 2.5 BPM at 1400psi. 2. I do not believe a CBL was run, but the cement did go as planned. 3. In the original plan, we did consider just running the LTP but for internal reasons decided against it. We did however complete running the plug to the nipple at 10551'and passed a CMIT on 7/12/2015 confirming the cement on the backside of the liner between the IA and the reservoir section is competent as a barrier. 4. An LDL was run on 9/27/2015 and found a leak at GLM#2 and an anomaly at the sliding sleeve.The plan is to change out GLM #2 and re-MIT the tubing. If it passes,we can proceed with the original LTP plan. If it fails (or any subsequent test fails), it is simpler to bring cement above both leaks.There will be a series of diagnostics to attempt to optimize this to a lower depth, but most likely cement will still be brought above the sliding sleeve at a minimum. 5. Yes,attachment B does not have the LTP drawn in, but it would be a component of the blue primary barrier similar to a tubing patch. 6. Some work has been done, but due to the leaks in the tubing the majority of the plan is the same (add a few diagnostics/steps to regain tubing integrity).When we added the cementing piece we would need a sundry for it, but since we already had one that outlined 90%of the plan it was easier from our side to"modify" it rather than start from scratch. However, if it is easier from your side to withdraw the first sundry and utilize this new one, I can do that instead. I will work with Garry Catron for this,as it is best for internal tracking that I put all sundry requests through him. Thank you for the kudos.This has been an odd one,so I made an extra effort to make everything as clear as I could. Thanks, Brenden Swensen Wells Group Production Engineer Office: 1907 564 4887 Cell: 1907 748 8581 brenden.swensen@bp.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, November 25, 2015 10:16 AM To: Swensen, Brenden Cc: Loepp, Victoria T(DOA) Subject: W-27A Repair( PTD 204- 144) Sundry 315-711 Brenden, I am covering for Victoria this month. I had a couple of questions regarding this wellwork on W-27A. • • 1. What was the leak rate during the last CMIT against the plug set at 10477' md. (this should be the leak rate past the packer at 10425' assuming the plug is holding) 2. Has a CBL been run to verify cement placement on outside of the 3 3/16" liner( CTD liner)?? Did CTD 3 3/16" liner cement go as planned? 3. Have you considered just running the LTP first and see if it passes a MIT-IA test?? (ie skip CMIT with lower plug) 4. For cementing contingency(cement IA) are you setting a retainer as well as bottom plug? Explain why you are planning on bringing cement up so high in the IA(9350' MD ) 5. The well sketch labeled " Proposed Well Barriers( attach B) should have LTP shown correct? 6. Could you send email requesting to withdraw the first sundry(#315-217). This new sundry covers everything and would be easier retract first one since you have not started the work. Good job on writing this up...very clear on objective and setting up the well history. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). 2 • • PTD Z01— /41- Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, December 01, 2015 11:37 AM To: Swensen, Brenden Cc: Loepp,Victoria T (DOA); Catron, Garry R (Wipro) Subject: RE:W-27A Repair( PTD 204- 144) Sundry 315-711a Follow Up Flag: Follow up Flag Status: Flagged Brenden, I thought more about question 6 below regarding retracting the original sundry. Go ahead as you planned ...you won't need to retract sundry 315-217 as I suggested. Just make sure the 10-404 report closes out both sundries. (315-217 and 315-711) Thanks for the clarifications below. You are good to go. Regards, Guy Schwartz SHED SEP 2 0 2016 Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy_schwartzaloskq.gov). From: Swensen, Brenden [mailto:Brenden.Swensen@bp.com] Sent: Tuesday, December 01, 2015 10:07 AM To: Schwartz, Guy L(DOA) Cc: Loepp, Victoria T(DOA); Catron, Garry R (Wipro) Subject: RE: W-27A Repair( PTD 204- 144) Sundry 315-711 Hello Guy, Apologies for the late reply. I was out for most of the holiday and did not get to this yesterday. 1. The leak rate on the CMIT was 2.5 BPM at 1400psi. 2. I do not believe a CBL was run, but the cement did go as planned. 3. In the original plan,we did consider just running the LTP but for internal reasons decided against it. We did however complete running the plug to the nipple at 10551'and passed a CMIT on 7/12/2015 confirming the cement on the backside of the liner between the IA and the reservoir section is competent as a barrier. 4. An LDL was run on 9/27/2015 and found a leak at GLM #2 and an anomaly at the sliding sleeve.The plan is to change out GLM #2 and re-MIT the tubing. If it passes,we can proceed with the original LTP plan. If it fails (or any subsequent test fails), it is simpler to bring cement above both leaks.There will be a series of diagnostics to attempt to optimize this to a lower depth, but most likely cement will still be brought above the sliding sleeve at a minimum. 1 5. Yes,attachment B does nave • the LTP drawn in, but it would be a component of the blue primary barrier similar to a tubing patch. 6. Some work has been done, but due to the leaks in the tubing the majority of the plan is the same (add a few diagnostics/steps to regain tubing integrity).When we added the cementing piece we would need a sundry for it, but since we already had one that outlined 90%of the plan it was easier from our side to "modify" it rather than start from scratch. However, if it is easier from your side to withdraw the first sundry and utilize this new one, I can do that instead. I will work with Garry Catron for this,as it is best for internal tracking that I put all sundry requests through him. Thank you for the kudos.This has been an odd one,so I made an extra effort to make everything as clear as I could. Thanks, Brenden Swensen Wells Group Production Engineer Office: 1 907 564 4887 Cell: 1 907 748 8581 brenden.swensen@bp.com From: Schwartz, Guy L (DOA) [ -juy.schwartz@alaska.govj Sent: Wednesday, November 25, 2015 10:16 AM To: Swensen, Brenden Cc: Loepp, Victoria T(DOA) Subject: W-27A Repair( PTD 204- 144) Sundry 315-711 Brenden, I am covering for Victoria this month. I had a couple of questions regarding this wellwork on W-27A. 1. What was the leak rate during the last CMIT against the plug set at 10477' md. (this should be the leak rate past the packer at 10425' assuming the plug is holding) 2. Has a CBL been run to verify cement placement on outside of the 3 3/16"" liner( CTD liner)?? Did CTD 3 3/16" liner cement go as planned? 3. Have you considered just running the LTP first and see if it passes a MIT-IA test?? (ie skip CMIT with lower plug) 4. For cementing contingency(cement IA) are you setting a retainer as well as bottom plug? Explain why you are planning on bringing cement up so high in the IA(9350' MD ) 5. The well sketch labeled "Proposed Well Barriers( attach B) should have LTP shown correct? 6. Could you send email requesting to withdraw the first sundry(#315-217). This new sundry covers everything and would be easier retract first one since you have not started the work. Good job on writing this up...very clear on objective and setting up the well history. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 2 i 2c, 3'4 t WELL LOG TRANSMITTAL DATA LOGGED PROACTivE DiAgNosTic SERVICES, INC. lO/A/2015 M.K.BENDER To: AOGCC E Makana Bender 333 W. 7th Ave Suite 100 CIC.1 9 2015 Anchorage, Alaska 99501 (907) 793-1225 A 8/ l/r w RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 ,, ....-..�_...___._...... . 900 Benson Blvd. Anchorage,AK 99508 gancpdcabp.corn and ProActive Diagnostic Services, Inc. 5GA►NNED SSP 1 5 201 Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 27-Sep-15 W-27A BL/CD 50-029-21894-01 2) Signed : Maget-tuk117) ..E:���e �Plt Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx F T��(,<cs , I//�ys THE STATE Alaska Oil and Gas ' —t..44 A O Conservation Commission _ - fALASIc:A *A, - - 333 West Seventh Avenue is. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 IT"' Main: 907.279.1433 ALAS- Fax• 907.276.7542 www.aogcc.alaska.gov Brendan Swensen atAEU = -'- Production Engineer BP Exploration(Alaska), Inc. a04- -___:„0-°÷ P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-27A Sundry Number: 315-217 Dear Mr. Swensen: 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, i°1 -ifil' Cathy P Foerster Chair DATED this (7 day of April, 2015 Encl. RECEIVED • STATE OF ALASKA APR 1 0 201 • ALASKA OIL AND GAS CONSERVATION COMMISSION / S 4(!7 t 13 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request' Abandon❑ Plug for Redrill❑ Perforate New Pool C] Repair WeII❑' . Change Approved Program Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing Other. Set LTP 0 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 ' 204-144-0 ' _ 3.Address: Stratigraphic El Service ❑ 6.API Number: P O.Box 196612,Anchorage,AK 99519-6612 50-029-21894-01-00 • 7.If perforating: 8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU W-27A • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028262 ' PRUDHOE BAY, PRUDHOE OIL • 1 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)' 12205' 9046 10477 8380 10477 None 1 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 38.65-118.65 38.65-118.65 Surface 2660 13-3/8"68#NT-80 38.15-2698.46 38 15-2698.36 5020 2260 Intermediate 10731 9-5/8"47#L-80 35.35-10766.77 35.35-8575.84 6870 4760 Production None None None None None None 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 4-1/2"12.6#L-80 L-80 33.15-10564.66 Packers and SSSV Type: 4-1/2"TIW Packer Packers and SSSV MD(ft)and TVD(ft): 10431.74,8349.21 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program E BOP Sketch ❑ Exploratory El Development 0 ' Service ❑ 14.Estimated Date for / 15.Well Status after proposed work: Commencing Operations: L5/I / S Oil El • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brenden Swensen Email Brenden Swensen@BP.Com Printed Name Brenden Swensen Title Production Engineer Signature ' • one 564-4887 DateW/I 0 >( Prepared by Garry Catron 564-4424 Ai. 4Ilb COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 IS^217 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No E Subsequent Form Required: ur, _ 4 (, 4 APPROVED BY Approved by: &ii COMMISSIONER THE COMMISSION , y-/7'-/5 Date: +..../ 7._./5" R44 Form 10-403 Revised 10/2012 O A L.validfor 12 months from the date of approval. Submit Form and Attachments in Duplicate x. V rL 4/i -/j , BDMSJ APR 2 0 2015 I./ ,/// - "`--) u, /. - /K- -aa O O O o 0 0 co o c� CCCCCCO 1 CO J J J J CD J Z J a) Q O N O O O O Coal O N LO O� CO O r_ ti N N- U 0 O 0 O O O O CO D co Nt N CO O co m CO N- 00 Ln a0 a) u) (B co c- co V N- N CO O) CO I,- CO V- CO CO N O CO LO O O CO 'Cr O CO V O = CO 00 CT CO CO CO N CO H Q 01- O) CO NY ~ O) LO CO CO O O CO CO CO a M co V O M V 00 CO CO >> > CO CO CO CO CO L I N E (.0 a) E N (I) r— u) tnu) — c Lo 00 ,...,a) cocoacooLO cooa) c CO N N— ocN � CD " CO O o c" O Ecn J a '- Cl) O Lo N in Q cocoCp = C° (� Hrn � � � � aoch 0 pc� choao2OLococo 2 • O cO o O O co co 0o co ao O 0o J J O J O F- J n ti J * 00 Z a) -a *k N CO J s-- J cc (1) O V Cfl cc CO CD 0) CO U _ N _ N • N O Cr) M CO N c) V M OO N CD O Cn O CO CD CO O N0 v• CO C CO Jco In c- N CDW 0)O Ct 0 ' 5 0 LLJ W U CO 0 U Q Z ZUJWWUJWW m O H z z z ZZ DD O Z J J J J J U) I- Perforation Attachment ADL0028262 Well Date Perf Code MD Top MD Base TVD Top TVD Base W-27A ' 2/17/15 BPS 11555 11560 8874 8875 W-27A 2/17/15 BPS 11585 11595 8884 8887 W-27A 2/17/15 BPS 11610 11620 8892 8895 W-27A 2/17/15 BPS 11621 11640 8896 8901 W-27A 2/17/15 BPS 11670 _ 11700 8910 8920 W-27A 2/17/15 BPS 11740 11810 8934 8962 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF by 0 To: AOGCC Date: April 9, 2015 From: Brenden Swensen, Orion PE 907-564-4887 Subject: W-27A Integrity Repair - Liner Top Packer Step Unit Operation 1 S Pull plug, reset plug 2 F CMIT-TxIA 3 S Contingent set LTP 4 F Contingent MIT-IA HISTORY W-27A was originally completed in 1988 and was coil drilling side tracked in 2004. Since being side tracked, the well has been relatively uncompetitive in the EWE LDF (East-West Eileen Large Diameter Flowline) and has remained shut in for a large portion of its life. The well produces at 80- 90% water cut and a TGOR of —12-14,000 scf/bbl. Since the opening of the U-Pad jumper, the EWE LDF's marginal TGOR has been 15-17,000 scf/bbl making W-27A competitive in the system. The well was brought back online mid-January of 2015. Since then, the well has failed multiple TIFL's, 2 being recorded at the packer (10,425') on 2/7/15 and 2/12/15. The well subsequently failed a MIT-IA and CMIT-TxIA. The failed TIFL's, MIT-IA and CMIT-IA are believed to be due to a leaking packer. The leak by the packer is thought to be communicating with the tubing via the 3.5" liner top at 10,512'. There is —296' of cement inside the 7" liner between the tubing tail at 10,569' and the mill out window at 10,865'. There is another —690' of cement between the mill out window and the first perforations at 11,555'. This program seeks to pressure test the cement via a CMIT-TxIA to establish it as a competent barrier and forgo a packer repair. If the leak is indeed through the 3.5" liner top, a liner top packer will be set to re-establish tubing integrity. A MIT-IA will then be performed to re-confirm IA integrity and no TxIA communication. The alternative fix for the leaking packer is to open the sliding sleeve at 10,375' and circulate cement on top of the packer at 10,425'. This cement plug would only give an additional 144' of standoff from the current cement at 10,561' and is a more expensive fix that can complicate options for future _ sidetracks and rig work overs. If this program is successful, this option can be avoided. OBJECTIVE Confirm inner annulus (IA) integrity by setting a plug in the 3.5" liner and perform a combined mechanical integrity test of the tubing and inner annulus (CMIT-TxIA). Upon a passing test, set a liner top packer (LTP) at 10,512' and perform a MIT-IA to confirm IA integrity. PROCEDURE 1. MIRU slick line and fullbore. Hold PJSM. 2. Pull bridge plug at 10,477'. 3. Set plug in x-nipple at 10,551'. 4. Fluid pack tubing and IA. Perform CMIT-TxIA to 2500psi. CONTINGENT IF PASS 5. Pull plug at 10,551'. 6. Set LTP at 10,512'. 7. Perform MIT-IA to 2500psi. 8. If pass, set live gas lift design. Attachments A. W-27A Wellbore Schematic B. W-27A Proposed Well Barriers (assuming passing integrity tests) Attachment A: W-27A Wellbore Schematic TREE= /16"MCEVOY _._._ WELLFCA D= FMC W-2 7 A SAFETY NOTES:WEU-ANGLE>70°@ 11554'. ACTUATOR= BAKER OKB.ELEV= 90.9' BF.REV- 52.72' KOP= 3000' I 21164-VT o-ns SSSV NP,D=3.813'J Max Angle= 82'@ 11168' Ira Datum‘13 11606' Datum TVD= 8800 SS 13-3/8"CSG,68#,L-80,U=12.415 I-{ 2888' A GAS LIFT MANDRELS lin -ST MD TVD DIV TYPE I VLV LATCH FORT DATE 6 3006 3005 8 LERLA; OW RN 0 02/16/15 5 6087 5358 44 U8.A 'DAfY RM 0 02/16(15 Minimum ID=2.44"@ 11865' 4 8074 6779 49 MERLA. DMY RM 0 02/16/15 TOP OF 2-7/8" LINER 3 9239 7547 47 MHit.A i DAN RA 0 08/25(04 2 9929 8007 47 AERLA I DAY RA 0 0825104 1 10270 8239 47 AETL.A 1'DAN Fl 0 02/16/15 STA#5 =ISE CLOCK&DFCFNTRAI_VERTORu &SET-10'.30 STA#1=USE CLOCK&OECENTRALQB2 TO R.LL&SET-11:00 10375' H4-1/2.OTIS SLD SLV,D=3.813" 10425' —4-12"TBG SEAL ASSY MI ��� 10425—9-5/8"x 4-12"TW F G,D=4.0" ,._ i 1047T'ELM—4-1/2"WFD ISO BROGE RUG(2/18/15) 10493' I--4-1/7 OTIS X MP D=3.813' TOP Cf 7't NR— 10606' r; TOP OF 3-1/2"X 3-3(16'X 2-7/8'LNR(CEMENTED) 10517 1:.:4 ;" 10512' 3-1/7 BKR DHLOY SLV,U.31X1" 10631' J4-12"OTE XN NFP,MILLED TO 3.80'(BEHIND LNR) J 3-112'1141.8.81#,L-80,.0087 bpf,D=299' - i. 10561' 7„ 10551” 13-VI X NP,D=2.813" • q 04-12'TBG,12.84.L-80..0152 bpf,D-3.959- 10569' I � q 9-5/8'CSG,47#,L-80,D=8.681" — 10767' 1; 10561' 3-12"X 3-3/16"XO,D=2 786' I Zile, BEHIND ►jr 10569' H4-12-WIG.ID=3.958" � CT LNR �7'LNR 26#,L-80,.0383 bpf,D=6.278- 10865' i`/ 10571' '—I ELM)TT LOGGED OW11/92 7'MECHANI[AL WHIPSTOCK —I 10865' N WI RA P6+TAG a 10870' elle ii.VI BOUT WPDOW(W-27A)10865' 10870' PERFORATION SUMMARY '``1‘.0.0._„,- '', 11866' 3-3/16"X2-7/8'X0,D=2A4' REF LOG MCN/C OGR OF 8/24/2004 a (1111'1'1'1'1 r�" '. TEN LOG:GEOLOGY FDC LOG 1..1.0.4.0. •i� ANGLE AT TOP RU /1"rn 11555' `�Vbs.''t�, Note Refer to Production DB for historical perf data ""4 �••tp SIZE SFT INTERVAL Opn/SqzSHOT 502 �� '.a.M ill 7 6 11585-11595 0 08/07/09 �`` �'ra►�• °6�a_ 7 6 11555-11560 0 08/07/09 7 6 11610-11620 0 05/08106'' 3-3/18'LNR, -L 11885 I �, .� 7 8 11621-116401 0 05/08/06 r 41 / 6.28.L-80 SIL. '••r` ~ 7 6 116/0-11/001 Cl 08/24/04 ��1�1�1�1�1�A .0076 bpf,D=2.80' PITC 1217(1 C•,. 7 6 11740-11810? 0 08/24/04 2-7/8'LNR,6.164,L-B0, 0058 bpf,ID=2 441' — 12205' DATE REV BY CONVENTS DATE REV BY CONVENTS PRUDIIOC DAY UYf 11123/88 GRV ORIGINAL COMPLETION 102/18/15 GJB/PJC SET WFD ISO BRIDGE Rt1G IND': W-27A 08/25/04 JLM/PJC CTD SIDETRACK(W-27A) 02/20/15 PJC REFORMAT CSG/TBG FEFIT Ab: 204-144 09/29/09 MV/SV ADPERF(08/07/09) AR MT 50-029-21894-01 03/01/13 KL/JM) SCI-EMAT1C CORRECTIONS SEC 21,T11A{R12E,910'FN-&1445'FEL 02/10/15 JTG/JM)GLV CO(02/05115) 02/16115 G18/PJC GLV CO BP Exploration(Alaska) Attachment B: W-27A Proposed Well barriers (assuming passing integrity tests) TRH-,, /1576tiVOY Y1/13.1tEAD- MC W-2 7 0 SALTY NOILS.WELL ANGEL>70'ad 11554'. ACTUATOR= BAKER r r 0103 13E/= 90.9' 8F.H_EV- 52.72 KOP= 107X7 Mu Argk- 8r VP 11168 -----f 2110 —4a-i47 oils&,,,s ,41- 14 ,t 1 s- r7 —. Cilium LU- 11608 DOum IVO- &8017 SS 1! 1,13"c sc,,1 80 U T7 4151-4 2699' GAS LFT MAIC EIS E —QST LD IVO DEV TWEE j VLV LATA-1 PORT DATE 6 36X763 3005 8 AMA CON 144 0 02/16115 • 5 6087 5958 44 /AMA •38765/ P9l 0 02418415 Minimum ID =2.44"@ 11866' • 4 8074 6779 49 /MA DAY RAI 0 02/16415 TOP OF 2-718" LINER 3 0034 7547 47 0,010A 1),e' RA a 08125/1)4 2 9929 8007 47 MHia DAN RA 0 0842L404 1 10270 8239 47 .M�,�BAm�'OAA 1l 0 02/16/15 STA 45 =l[SF(7(NX II +.a�YTRAi C/FR TO P111 R SFT-1(T 30 STA 41=USE Q.000 a OECENTRALIZER TO Flit&SET-1100 { 1037r —14-U7 OTOS 3&D 5_5/.13.3.813- Primary Barrier ► 104,2$' --4-1R'18G SEAL ASSY MI Secondary Barrier aiii10425' •—9-SM x 4-11Y TAN Kit,IU=4 r 1 1047r ELM H412'Y1i'D so ORAE P-UG(218/15)1 I 10493' —4-1/r0116xPCID=3813' n»OFr L11R _10506' 1F014,41- 1 •rr a 3 1,1,-x 7-4/8.1114(cC-51-67 _ 10517 I' . ,I 10517 --�3-17r Ebtut OEPLOY SLY,00- =3 o 10631' �--,412'OTE KP14P,IALLE)TO380'1 MD LAIR) 13-1/7 LW.8 618,L-80_.0087 bp!.0 ---2.89' 10661' II 10667 1-13-Ire x to 17=2.e14- [4-VY THOU 1200.L-80,-0152 bp!,0-3-958' i--- 10549' I,: I I 10561 3-112"x 3.3/16-xO,C)=2 7r 9-578'CSG,4/9,L-80 U-8-681"H 10757' ' �� BEHIND I r l Pit,760 ,-60, 0083 apt,T)-8 775' 1-1 10665' 10569' 41rt HUG,D-3.958' CT TNR I 10571' ',--I El.LDTTLOGGED 08/11/92 4'MIEGIAP4A- L 048Ps R.XX 10865' W 4 RA PIP TAGS 10670' LI..LOUT 1AU)OW(1N-T7A)10865' 10870 FT#`ORA110NSUb6AR1' 'rAj- .. REF LOG LCWJOaGR OF 812442004 : !.•% .. 11866' ,.—3-3/16•x2-7'a'x0,U=2.44- i 'C . TEN LOG:GEOLOGY PDC LOG '49.4119144.411.4 �.� ANGIE AT TOP PERP 1T®11569 T �.�'14%, �.� Now It11fr i1)P►oducl on DB for timorlrsl pert Cata �tit - �•'� SEE,SPF 14117IVAL !Opn/Sgx SIM SO2 "'I,. .` .. 7 6 11555-115601 0 08/071091 • N.'N.,... yam.," 2' 6 11565-11595' 0 06/07,'09 '''..N.4....‘. .`A 2' 6 11610-11620 0 05/}8106 3/18-1 NFL, 11i6S I _ .''.• 2" 0 11621-11640 0 053/0&'06 4'0'0'0'4 8.20 -80 5Th. •`-•,.- %- 2' 6 11643-9.1(00 U 6411!4.614 WAWA 0076 opf.0-2,80' I B1C 12170' � AZ- •:- 7 6 11740-11810 0 08424!04 I2-7/6'LAR,6 152,1-80. DOSS bpi.ID=2441'H 12206' DATE RBI BY COMIENTS DATE REV BY O)8&O4T0 I'f4.1011000AY LRar 11113168 0611 Oti01NAI.00MPLEftor4 02118115 OJB3PJC SET Wf0190BRD0E PLUG WR 1-114.27A 0&2604 JLMIPJC3CTD SIDETRACK(W-274) 102120/15 PJC REFORMAT C501 TBG FtJ3IT Mx 204-144 09'29609 IW/SV A (06417/99i AH PS 50-029-71894-01 33701/13 KLJJ6D SOV RTIC CORRECTIONS SEC 21,T11P{R12E,910'FIt&1445'FI_ 02/10/15 JTG/JAQ GLV CO(02/0515) 02116115'OMPJC OLV CO 8P Exploration(Alaska) PTO 7o4 - / if Loepp, Victoria T (DOA) From: Swensen, Brenden <Brenden.Swensen@bp.com> Sent: Wednesday,April 08,2015 4:47 PM To: Loepp,Victoria T(DOA) Subject: W-27A Barrier Questions Attachments: W-27A Barrier Explanation.pptx Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, I attempted toput some of mythoughts in writingand figures. Maynot becomplete, but I can fill in the blanks if you P g g P have these to look at for our conversation tomorrow. Thanks, Brenden Swensen L&V Series 2xx(Orion)Production Engineer Office: 1907 564 4887 Cell: 1907 748 8581 brenden.swensen@bp.com SC aN*I TREE= /16'MCEVOY WaLFEAD= FMC W-27A SAFETY NOTES:WELL ANGLE>70°@ 11554'. ACTUATOR= BAKER OKB.BFV= 90.9' BF.aEV= 52.72 1 KOP= 3000' Max Angle= 82' 11168' �-� 2116' 1-1412"0715 SSSV NP,D=3.813' Datum IJV- 11606 [)atum ND= 8800'SS 1 13-3/8'(SG,68#,L-80,U=12.415"J-j 2699' GAS LFT MANDRI3S IN —LST MD TVD DEV TYPE y VLV LATCH FORT DATE 6 3006 3005 8 kERLA IJJN 1111 0 02/16/15 I 5 6087 5358 44 MERLA 'MY RM 0 02/16/15 Minimum ID =2.44" @ 11865' 4 8074 6779 49 Ml3iLA i OW RM 0 02/16/15 TOP OF 2-718" LINER 3 9239 7547 47 MERLA! DAM RA 0 08/25/04 2 9929 8007 47 MERLA 1 DAM RA 0 08/25/04 1 10270 8239 47 PUI..A I'DMY RM 0 02/16/15 STA#5 =USE CLOCK 8 DEC�ITRAL1Z TO FULL 8 SET-10730 P r o o s e d STA#1=IJSE CLOCK 8.DFITRAL1Z62 TO PILL 8 SET-11:00 m 1 10375' H4-1/2"0715SLD SLV,D=3.813' I leak path „,.., 10425 9-518”x 4-12'TAN PIR,ID-4.D' _ ril 10477"ELM H4-12"'M D ISO BRIDGE PUJ)(2/18/15) 10493' H4-1/2"OT1S XMP ID=3.813' TOP OF 7't NR - 10506' TOP OF 3-12'X 3-3/16'X 2-7/8"LNR(CEMENTED) I 10517 g II" 10512' H3.12'BKR DB'LOY SLV,D=3.00' 10631 f-14-12"OTE XNSIR MILEDTO3.80"WHIM LNR)I' i 3-1/2'LAIR.8.81#.L-80..0087 bpi.D=299' 10561' /I" 10551- H3-1rr x W U=2.813" i Ill 412'TBG.12.61,L-80..0152 bpf.D-3.958' -1 10569' S y ell 10561' -3-12"X 3-3/16'XO,ID=2786' 9-5/8'CSG,47#,L-80,D=8.681' - 10767 eA , mi BEHIND j� i,%.--,i 10569' H4-1/7 WLEG.D=3.958" BE LNR r LNR,26#,L-80,.0383 bpf,ID=6.276' --I 10865' \ �I �,'t., k 1.1441 10571' - ELMJTTLOGGED 08/11/921 7'MECHANICAL WI�PSTOO( 1_, 10865' 4P 4 WI RA PIP TAG@ 10870' 44 ecr BOUT WNDOW(W-27A)10865'-10870' a PERFORATION SUP/MARY rj ■ ••a,. •'' 11866' 3-3/16'X2-718'X0.D=2.44' Fid LOG:AACAl1CCIGR OF 8/24/2004 � :. ,a V ' Vttivil TLOG:GEOLOGY PDC LOG SA 1.1.4.4.0.4 N ENr`j A , ANGLE AT TOP PERF:71'n 11555' -•411111' dpiW- 114,1.4•., A 'la Note:Refer to Roduction DB for historical perf datax . ' WE SW NTDRVAL OpnlSgz SEDT I SCIZ �`011►'-.�.' '' 2" 6 11555-11560 0 08107/09 • N.%` ..�+` 2" 6 11585-11595 0 08/07/09 -r1,� -�a. 2" 6 11610-11620 0 05/08/06 Opt 3-3/16'LW, 1865' I N.. ` "aN r 6 11621-11640 0 05/08/06 'q4'q.94.1 6.2#.L-80 STL. 4�a �" 2" 6 116/0-11/00 U 081'14104 l'Invii Oa�i4Di .0076 bpf,D=2.80' I pgTC J� 12170' ..... 7 6 11740-11810 0 08/24/04 2-7/8'LP,6.168,1-80, 0058 bpf,D=2 441' - 12205' DATE REV BY COIVIANTS DATE REV BY CflAm:NTG FRU01IOCDAY UNT 11123/88 GRN ORIGINAL COMPLETION 02/18/15 GJB/PJC SET WFD ISO BRIDGE RUG WELL: W-27A 08/25/04 JLMIPJC CTD SIDETRACK(W-27A) 02/20/15 PJC FORMAT CSG/TBG F F T Nx 204-144 09/29/09 MV/SV ADPBiF(08/07/09) AR Nb: 50-029-21894-01 03/01/13 KL/JAiD SCF113AAT1C CORRECTIONS SEC 21,T11 N,R12E,910'FNL&1445'Fa 02/10115 JTG/JMD GLV CIO(02/05/15) 02/16/15 GBfPJC GLV CIO BP Exploration(Alaska) TREE= 116"MCEVOY WELLHEAD= FMC W-2 7 A SAFETY NOTES:WELL ANGLE>70°@ 11654'. ACTUATOR= BAKER OKB.EEV= 90.9' BF.ELEV= 52.72 - KOP= 3000' Max Angle= 82'0 1110' 2116" H4-1/2"OTE SSSV NP,D=3.813' Oatum MD= 11606' Datum TVD= 8801Y SS [13-318'EEG,68#,L-80,U=12.415" H 2e9' GAS LFT MANDRBS ST M) TVD DEV TYPE 1 VLV LATCH PORT DATE 6 3006 3005 8 MT35A 1 OMY RM 0 02/16/15 5 6087 5358 44 MERA 1 "DMY RM 0 02/16/15 Minimum ID =2.44" @ 11865' 4 8074 6779 49 MERLA i DMY RM 0 02/16/15 TOP OF 2-718" LINER 3 9239 7547 47 AERLA DMY RA 0 08/25/04 S 2 9929 8007 47 MENA DMY RA 0 0825/04 1 10270 8239 47 MERLA 1`DMY RM 0 02/16/15 STA#5 =USE CLOCK 8 DECRORALIZERTO PILL 8 SET-10:30 Pro o s e d STA#1=USE CLOCK&DECB4TRAL1ZB2 TO PLLL&SET-1100 I ' I 10376' H4-1/Y OT6 SLD SLV.D=3.813' I Barriers 10425 —4-12"TBG SEAL ASSY _ 10425• H9 5/8'x 412 TPN Rff{ID=4.0' _ 10477"ELM—4-12GE"WED ISO BRDPLUG(2118/15) 10493' I—I4-12"OTE NIP,ID=3.813" TOP OF 7'I NR — 10606' TOP OF 3-1/7 X 3-3(16'X 2-7/8'LNR(CB1al NT®) ]- I 1051r I 10517 —13-12'BKRIJHLOY SLV,D=3.00' 'I 10631' H4 12'OTE XN WP,MLLEDTO3.80"SND LNR-TI D 10561' „ 10551' H3-1rr x NIP,u=2.813- 41/2'1BG,12.64.L-80..0152 bpf,D-3.958" — 10569' IN h I � ' 9-5/8'CSG,47#,L-80,D=8.68f — 10767' i` I 10561' 1-131/7'X 33116'X0,10=2.786' I BEHIND 10567 H4-12'WLEG,D=3.958' ! CT LNR r LNR,26#,L-80,.0383 bpf,D=6.278" — 10866' 10571' — TIM)TT LOGGED 08/11/92 7"MECHANICAL WHIPSTOCK I—{ 10865' vs/RA PIP TAGS 10870' 1MLLOUT WINDOW(W-27A)10865'-10870' h...- PBTFORATION Sl1CvMARY '% REF LOG:MCNLlC(7GR OF 824!2004 R '- It# 11865' 3-3/16"X2-7(8'XO.13=2.44' I TEN LOG:GEOLOGY PUC LOG x'11'1'1”'Irt - 44.4.4.4.4.4.4.4 �- 'i ANGLE AT TOP PBS:71"@ 11555' --......._ \ Note:Refer to Production DB for historical pert data - �'ti. SIZE SW INTERVAL I Opn/Sqz SHOT j SOZ _, '„. �� 2" 6 11555-11560 0 08107109' 2" 6 11585-11595 0 08/07109: b .` 2" 6 11610-11620 0 05/08106' 3-3/18"LNR, 11865' 1 -N.-, 4L . 2' 6 11621-11640 0 05/08/061 1,q,)''q1' 6-24.1-4°511, 1.y t:No . 2" 6 11670-11/00 O 08/24/04 ht4i4a4i4i4i4Di .0076 bpf,ID-2.80" F87L J—{ 12170' ter. Y 6 11740-11810 0 08/24/04 2-7/8'LNR,6.161,L-80, 0058 bpf,D=2.441' —I 12205' DATE REV BY COM ENTS f DATE REV BY C5MdO'TT0 ---- PRODUCE DAY UNIT 11/23/88 01W ORIGINAL COMPLETION i 02/18/15 GJB/PJC SET WFD GOBRIDGE PLUG WELL' W-27A 08/25/04 JLM/PJC CTD SIDETRACK(W-27A) 102/20/15 PJC REFORMAT CM TBG FU7MT No: 204-144 09/29/09 W/SV ADFERF(08/07/09) AR No: 50-029-21894-01 03/01/13 KLJJM) SCHEMATIC CORREC T10NS SEC 21,T11 N,R12E,910'FNL&144E FEL 02/10/15 JTG/JMD GLV CIO(02/05115) 02/16/15.GIB/PJC GLV(70 i BP Exploration(Alaska) W-27A • Packer at 10425' believed to have failed based on TIFL's and failing MIT-IA — Most likely fluid path is past packer and back up the 3.5" liner top • Diagnostics plan is to set plug at 10551' — CMIT-TxIA against plug and cement • If passes, would confirm competent cement on backside • If pass, repair is to set LTP to repair tubing integrity — MIT-IA against LTP and cement to confirm both barriers hold Cont . • Cement from 10569' to 10865' (296' ) in 7" liner — Cement from 10865' to first perf at 11555' (690') e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q Y- - lif '4- Well History File Identifier Organizing (done) o Two-sided 11111111111" 11111I o Rescan Needed 11111111111 II 11111I R~CAN ¢' Çolor Items: ~reYSCale Items: o Poor Quality Originals: DIGITAL DATA ~iskettes, No. I o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date q, ~/6b o Other:: BY: c:... Mari~ .... Isl ~p BY: ~. Maria ~ ~ 1111111111111111111 Date c¡ / :J-'í5 / 0 b 1& IMP I X 30 = '30 + ~~ = TOTAL PAGES <~3 Date q, '~ / b b (Count does not ;~~I;~I~ I~;~;I;~~; MP Project Proofing Scanning Preparation BY: ~~ Maria) Production Scanning Stage 1 Page Count from Scanned File: 5~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY ~ Date~ dv?i lOb Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 lAÆ f1 NO BY: Maria Date: Isl 11111111111I11 1111I Scanning is complete at this point unless rescanning is required. ReScanned III 1111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~;~~~~~~ ~~ ~,~.i~; ~ ~ ~'~~9 1. Operations Abandon ~ Repair Weli ~ Plug Pertorations ~ Stimulate~ ~Q~~{~~~ ~, `;~ e~~~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pooi ~ Waiver~ Time Extension ~ c_ Change Approved Program ~ Operat. Shutdown [] t,; _i Perforate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment I~ Exploratory ~~ 204-1440 ~ 3. Address: P.O. Box 196612 StfBtlgPBphIC T~~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-21894-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 90.9 KB - PBU W-27A - 8. Property Designa6on: 10. Field/Pool(s): , ADLO-028262 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pooi 11. Present Well Condition Summary: Total Depth measured 12205 ' feet Plugs (measured) None true verticai 9045.74 ~ feet Junk (measured) None Effective Depth measured 12168 ~ feet true vertical 9039.37 - feet Casing Length Size MD ND Burst Coliapse Conductor 110 20"91.5# H-40 38 - 148 38 - 148 1490 470 Surface 2661 13-3/8"68# L-80 38 - 2699 38 - 2699 5020 2260 Production 10729 9-5/8" 47# L-80 38 - 10767 38 - 8576 6870 4760 Liner 359 7" 26# L-80 10506 - 10865 8399 - 8643 7240 5410 Liner 49 3-1/2"8.81# L-80 10512 - 10561 8403 - 8437 10160 10530 Liner 1304 3-3/16" 6.2# L-80 10561 - 11865 8437 - 8982 8520 7660 Liner 340 2-7/8" 6.16# L-80 11865 - 12205 8982 - 9046 10570 11160 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 36' - 10569' 0 0 - Packers and SSSV (type and measured depth) 9-5/8" TIW PKR 10425' 0 _ _ : . . - .. .... 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~'~`~a:~'~°a~:Lw,..~ !-~,i~ , '?; ~t~~,fJ ~ Treatment descriptions including vo{umes 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: 24 153 905 263 Subsequent to operation: 14. Attachments: 15. Weil Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ De~elopment ~- SenACe ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' - Gas ~~ WAG ~" GINJ ~ WINJ ~` WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble ~'~ . ~ ~~~ ~ _ w ~ ~ ~~a~ Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 ~ Date 8/12/2009 I Form - - ~~ S s3t4bE ~ ~~~/~ W-27A 204-144 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-27A 8/25/04 PER 11,670. 11,700. 8,910.31 8,920.02 W-27A 8/25/04 PER 11,740. 11,810. 8,934.46 8,962.05 W-27A 5/7/06 APF 11,621. 11,640. 8,895.51 8,901.27 W-27A 5/8/06 APF 11,610. 11,620. 8,892.09 8,895.21 W-27A 8R/09 APF 11,555. 11,560. 8,873.66 8,875.31 W-27A 8/6/09 APF 11,585. 11,595. 8,883.82 8,887.21 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ ~ ~ W-27A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 DIESEL 3 MEOH 4 Total • • ;~~ .jYi -. b.d~~ -' s'r~ ~. MICROFILMED 03/01 /2008 w~= ~:- DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Markerdoc ~\~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041440 Well Name/No. PRUDHOE BAY UNITW-27A Operator BP EXPLORATION (ALASKA) INC 5,,-, cL ('I ~ Â() b4 API No. 50-029-21894-01-00 MD 12205,/ TVD 9046 "....-- Completion Date 8/25/2004 /' Completion Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Current Status 1-01L Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL Well Log Information: Log/ Data f!f.TY. ED pt ED Electr Digital Dataset Med/Frmt Number D Asc D ]:e~, s. Name Directional Survey Directional Survey 12782 Induction/Resistivity LIS Verification µ ~u, Neutron 13728 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Þ¡nalysis ~ Received? Comments: -- Compliance Reviewed By: ~ (data taken from Logs Portion of Master Well Data Maint -- Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 10847 12205 Open 9/14/2004 IIFR 10847 12205 Open 9/14/2004 IIFR 10788 12204 Open 10/20/2004 GRlEWR4/ROP 10788 12204 Open 10/20/2004 GRlEWR4/ROP/DSN 12782 2 Blu 10282 12098 Case 2/3/2005 cnl/mem gr/ccl/ 10880 12205 Open 2/22/2006 ROP NGP EWR plus Graphics Sample Interval Set Start Stop Sent Received Number Comments . Daily History Received? ~N Formation Tops (þ Date: T:, ~~ #6 9k//õ6':. RECEIVED . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 1 9 2006 REPORT OF SUNDRY WELL OPERA TI0H6 Oil & Gas Cons. Commisfon 1. Operations Performed: Anchor.aCJe Abandon 0 RepairWellO Pluç PerforationsD Stimulate 0 OtherL1 Alter CasingD Pull TubingO Perforate New PaolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownO Perforate I!] Re-enter Suspended WellD 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development ŒJ ExploratoryD 204-1440 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-21894-01-00 7. KB Elevation (ft): 9. Well Name and Number: 90.90 W-27 A 8. Property Designation: 10. Field/Pool(s): ADL-028262 Prudhoe Bay Field I Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 12205 feet true vertical 9046.0 feet Effective Depth measured 12168 feet true vertical 9039.0 feet Casing CONDUCTOR SURFACE PRODUCTION LINER LINER LINER LINER Perforation depth: Length 110 2661 10729 359 49 1304 Plugs (measured) Junk (measured) None None Size 20" 91.5# H-40 13-3/8" 68# L-80 9-5/8" 47# L-80 7" 26# L·80 3-1/2" 8.81# L-80 3-3/16" 6.2# L-80 2-7/8" 6.16# L-80 TVD Burst Collapse 470 2260 4760 5410 10530 7660 11160 MD 148.0 2699.0 8576.0 8643.0 8436.5 8981.6 9046.0 1490 5020 6870 7240 10160 8520 10570 38 38 38 10506 10512 10561 11865 148 - 2699 · 10767 · 10865 - 10561 · 11865 - 12205 38.0 38.0 38.0 8399.0 8403.0 8436.5 8981.6 Measured depth: 11610-11620,11621-11640,11670-11700,11740-11810 True vertical depth: 8892-8895.2,8895.5-8901,8910-8920,8934-8962 Tubinç ( size, ç rade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2"12.6# L-80 @ 36 10569 9-5/8" TIW Packer @ 10425 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr ::::s_ ~~~Jìf;mA; Form 10-404 Revised 4/2004 R L 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ¡~BDMS 8Ft SEP2 5 2006 Oil-Bbl 28 269 Representative Daily Averaoe Production or Inìection Data Gas-Met Water-Bbl Casing Pressure 872 1704 10,296 1884 Tubing Pressure 300 633 ~ 15. Well Class after proposed wor!<: Exploratory(] 16. Well Status after proposed work: OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. SUndry Number or N/A if C.O. Exempt: NIA DevelopmentŒ ServiceD Title Phone Petroleum Engineer 564-5174 Date 9/6/06 . . W-27 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/07/06 INITIAL TIIIO 1800/1620/0. PERFORATED INTERVAL 11,621-11,640 FTWITH 2" HSD POWERJET-OMEGA, 6 SPF, 60 DEGREE PHASING. PUMPED DOWN AT 2.5 BPM LOG CORRELATED TO SLB CNL DATED 24-AUG-2004. 05/08/062" HSD POWERJET-OMEGA, 6 SPF, 60 DEGREE PHASING PERFORATED INTERVALS 11,610-11,620 AND 11,621-11,640 FT. PUMPING NECESSARY AT 2.5 BPM TO ACHIEVE REQUIRED DEPTH. WELL LEFT SHUT-IN. GASLlFT LEFT SHUT-IN. CORRELATION LOG SLB CNL DATED 24-AUG-2004 05/14/06 TESTEVENT --- 269 STBO, 1884 BWPD, 10,296 Mscf FLUIDS PUMPED BBLS 1 PT Surface Equipment 5 Methanol 10 Diesel 336 Crude 352 TOTAL Page 1 TREE = 4-1/16" MCEVOY W8..LHEAD = FMC . ACTUATOR = BAKER KB. 8..EV = 90.87' SF. 8..EV = 52.72' KOP = 3000' III1ax Angle = 50 @ 8200' Datum MD = 11199' Datum TVD = 8800' SS . 13-3/8" CSG, 68#, L-80,ID= 12.415" H 2699' I Minimum ID = 2.377" @ 11884' TOP OF 2-7/8" LINER I TOP OF 7" LNR H 10506' /TOPOF3-1/2"x3-1/16"X2-7/8"LNR H 10512' 13-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.99" l-i 10561' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10569' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 10767' W-27A . ~ L I I I '-!NOTES' 2116' H4-1/2" OTIS SSSV NIP, ID = 3.813" I . GAS LIFT MANDR8..S DEV TYÆ VLV LATCH 8 MERLA DOME RA 45 MERLA DOME RA 49 MERLA DOME RA 47 MERLA DMY RA 47 MERLA DMY RA 47 MERLA SO RA PORT DATE 16 11/19/04 16 11/19/04 16 11/19/04 o 11/19/04 o 11/19/04 20 11/19/04 ST MD 6 3006 5 6087 4 8074 3 9239 2 9929 1 10270 TVD 3005 5358 6779 7546 8007 8240 I 10375' -- 4-1/2" OTIS SLIDING SLV, ID = 3.813" I J t:=:j 10425' 1-14-1/2" TBG SEAL ASSY I 10425' 1-19-5/8" x 4-1/2" TNV A<R ID = 4.0" I .. ~ 10493' 1-14-1/2"OTISXNIP,ID=3,813" 10512' -- 3-1/2"SKRDEA...OYSLV,ID=3.00" I 10512' HEST. TOP OF CEMENT 10531' 1-14-1/2" OTIS XN NIP, MILLED ID = 3.80" (BÐiIND PIPE) I 10551' H3-1/2"XNIP,ID=2.813" 10561' H3-1/2" X 3-3/16" XO, ID = 2.786" I I 10569' H 4-1 12" WLEG, ID = 3.958" I ~ .. I 10571' H 8..MDTTLOGGED08/11/92 MECHANICAL WHIPSTOCK H 10865' ~ I RA PlPTAG H 10870' r L IBP(08/81/04) H 10601' r MARKER JOINT H 11207' I PBTD H 11664' 7" LNR, 26#, L-80, 10 = 6.276" H 11707' ÆRFORA TION SUMMARY REF LOG: MCNLlCClGR OF 8/24/2004 TIE:-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP ÆRF: 72 @ 11670' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 6 11610 - 11620 0 05/08/06 2 6 11621 - 11640 0 05/08/06 2 6 11670 - 11700 0 08/24/04 2 6 11740-11810 0 08/24/04 DA TE REV BY COMMENTS 11/23/88 GRV ORIGINAL COMPLETION 08/25/04 JLM/PJC CTD SIDETRACK (W-27A) 08/?/04 TLHlTLP CHA NGE 13-3/8" CSG DEPTH 11/19/04 RMt-VPJC GLV C/O 09/13/05 ITLH CORRECTIONS 05/13/06 RLM'PAG ÆRFS (05/08/06) I MILLOUT WINDOW 10865' - 10870' I I 11865' H3-3/16" x 2-7/8" XO, 10 = 2.44" I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.8" H 11865' I PBTDH 12170' I 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" H 12205' DA TE REV BY COMMENTS PRUDHOE BA Y UNIT W8..L: W-27A ÆRMIT No: 204-144 API No: 50-029-21894-01 SEC 21, T11 N, R12E. 910' FNL & 1445' F8.. BP Exploration (Alaska) . . WELL LOG TRANSMITTAL JDA- /44- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 ) Vld-~ RE: MWD Formation Evaluation Logs W-27A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 W-27A: LAS Data & Digital Log Images: 50-029-21894-01 1 CD Rom ~ ¿Y{ ')'01 Dlo Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well Job # /£f ~!7c C-29A 10715422 Ff1~ tJ¡ E-25 10715423 ,q$-óZJ G-02A 10715424 ifH-fN W-27A 10670031 ~e-ð%4D-25A r<, 10854314 /fq·ObVDS 15-25A' "'" 10715428 ~.Ø'fc.E-39A "\ 10715430 02-16B 10928597 I 15- 0 { C-25A 10928598 :)01.(.:1.01 E-17 A 10928602 J.t)i'¡:-i~~ C-41A j 10928606 ít7(;' -ùì.fr DS 07-30A 10715445 . '.(/ffe,DS 15-38A 10715446 ..' 'H-i{P{ 02-28A 10928607 rqj- (~3 ~ D-11A 10928608 ZeYI-2-I?) DS 05-24A 10928609 .·(prints~ only-Job not complete) /) /" . . / ~vt-IC¡T 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 08/20/04 1 08/21/04 . 1 08/23/04 1 08/24/04 1 08/27/04 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL 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, Alaska 99508 Date Delivered: c2ß ;0;; Alaska Data & Consulting Services 2525 Ga. mbell Street, Suit.r400 ..... ~. Anchorage, A~9950 2838 1} ATTNC ~. ¿¿ '/ 1./ Rece!i!d by: J~ /! ' (/ ¡ (/ . . c1ô c(--- jrt{ WELL LOG TRANSMI1TAL I )./& .- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: W-27 A, 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21894-01 ~ ¡, October 15, 2004 AK-MW-3233637 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date 10f~ ~!ß~/l!d~ð-V- RECEIVED OCT 2 (·2004 AJaska Oil & Gas Cons. CommÚNrJ... Anchorage ""'!YO · STATE OF ALASKA e ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 MGR I CCL I CNL CASING, liNER AND CEMENTING RECORD SrnINGDePTI-I MD SertlNG DEPTH "'tVI) 'lOP BOTTOM Top BOTtoM Surface 110' Surface 110' Surface 2699' Surface 2699' Surface 10767' Surface 8576' 10506' 10865' 8399' 8643' 10512' 12205' 8403' 9046' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 910' SNL, 1445' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 2288' SNL, 1978' WEL, SEC. 20, T11N, R12E, UM Total Depth: 2007' SNL, 2481' WEL, SEC. 20, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 611789 y- 5959343 Zone- ASP4 TPI: x- 606001 y- 5957881 Zone- ASP4 Total Depth: x- 605493 y- 5958155 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: SGRC Combined GR & EWR, 22. WT.. PER FT. 20" Conductor 13-3/8" 68# 9-518" 47# 7" 26# 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.2# /6.16# L-80 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 11670' - 11700' 8910' - 8920' 11740' - 11810' 8934' - 8962' One Other 5. Date Comp., Susp., or Aband. 8/25/2004 6. Date Spudded 8/19/2004 7. Date T.D. Reached 8/22/2004 8. KB Elevation (ft): 90.9 9. Plug Back Depth (MD+ TVD) 12168 + 9039 10. Total Depth (MD+TVD) 12205 + 9046 11. Depth where SSSV set (Nipple) 2116' MD 19. Water depth, if offshore NIA MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-144 13. API Number 50- 029-21894-01-00 14. Well Name and Number: PBU W-27 A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028262 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 8 cu yds Concrete 17-1/2" 3984 cu ft Cold Set III & II 12-1/4" 2341 cu ft Class 'G' 8-112" 325 cu ft Class 'G' 4-1/8" x 3-3/4" 112 cu ft Class 'G' SIZE 4-1/2", 12.6#, L-80 25. DEPTH SET (MD) 10569' PACKER SET (MD) 10425' DEPTH INTERVAL (MD) 2500' AMOUNT & KIND OF MATERIAL USED Freeze Protected with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 18, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE I GAS-Oil RATIO 9/19/2004 4 TEST PERIOD ... 17 168 199 1760 10,016 Flow Tubing Casing Pressure CALCULATED --... Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 332 1,555 24-HoURRATE""" 101 1,010 1,194 29.1 27. CORE DATA . ~ r- \\ IC' , Brief ~escriptio~ o~ ~ithology, por~~ity, f~actures, apparent dips and prese~:: Of?il, gas or water (attac~~~b6t~f ~sary). Submit core ChipS, If~one, state none. t~~ft., SEP ~ St.? 2, 11\)Û~ .' None . ~' Ai a.::: ¡ ~.. . \. r'. q,._.,../\ I COn'.mìSSIOr. , ''"' <'" d . u { ~ ¡ f' I' i -~. ¡ . & GaS Cons" ~ ~1 ~ßFl' . . i(."'.~ ,~ii\J¡~ '. I..., A\aSKsQ¡\ r.,t\chof3\16 e::,f , Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE b 28. -- GEOLOGIC MARKERS NAME MD rvD Shublik A 10806' 8602' Shublik B 10882' 8655' Shublik C 10916' 8678' Eileen 10945' 8699' Sadlerochit 10992' 8730' 42N 11457' 884 7' 41N 11558' 8875' 41P 11579' 8882' Top CGL I Zone 3 11705' 8922' Zone 2C I Base CGL I 27P 11841' 8974' 26N 12060' 9022' e 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECE\V~D "£? 4þ 1[0\.\4 . S . Comro\$S\QíI . & Gas \,Q\"\S> ~\a$~íl (h\ þ,nthOU1\}e 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I ~erebY certify that the fo~oin= is true and correct to the best of my knowledge. Signed Terrie Hubble /}fA,J\.c..( ~ Title Technical Assistant Date W - f;( I ·Ot.{ PBU W -27 A 204-144 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Sean McLaughlin, 564-4694 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IrEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IrEM 4b: TPI (Top of Producing Interval). IrEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IrEM 20: True vertical thickness. IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IrEM 27: If no cores taken, indicate "None". IrEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/15/2004 05:00 - 07:00 2.00 MOB P PRE PJSM. Move rig off well to edge of pad. 07:00 - 07:15 0.25 MOB P PRE PJSM for rig move. 07:15 - 00:00 16.75 MOB P PRE Move rig down spine road to W pad access road. Fall through road mulitple times. 8/16/2004 00:00 - 00:30 0.50 MOB P PRE Drive out of hole. Move rig to widespot in the road. 00:30 - 19:00 18.50 MOB N WAIT PRE Mobilize rig mats to mat rest of the way to W pad. 19:00 - 20:00 1.00 MOB P PRE Move rig to W-Pad. 20:00 - 21 :30 1.50 MOB N SFAL PRE Bleed pressure off well. - Could not establish injection with Little Red. Well pressured up. - Pressure not bleeding to zero psi. - Whitey valve trying to hydrate off. - Discovered Swab and Master valve leaking. - Shut well in. Release bleed trailer. 21 :30 - 23:15 1.75 MOB N SFAL PRE Wait on grease crew to get on location. 23:15 - 00:00 0.75 MOB N SFAL PRE Grease tree valves. - Swab tested from above to 4000 psi. - Master tested from above to 4200 psi. - Master tested from below to tubing pressure (1100 psi). 8/17/2004 00:00 - 00:30 0.50 MOB N SFAL PRE Continue to grease valves. Rig down greasers. 00:30 - 02:00 1.50 MOB N DPRB PRE RU boom truck for BPV installation. RU lubricator. Run BPV. RD lubricator. RD boom truck. 02:00 - 02:30 0.50 MOB P PRE Move platform. Install spill dykes. 02:30 - 03:30 1.00 MOB P PRE PJSM. Move rig over well. RIG ACCEPT: 03:30 AM 08/17/2004 03:30 - 06:00 2.50 BOPSUF P PRE NU BOPE. Off Critical Path: - Set cuttings tank, camp, tech limit shack, etc. 06:00 - 10:00 4.00 BOPSUF P PRE PT BOPE to 250 / 3,500 psi. Send test report to AOGCC. 10:00 - 10:30 0.50 KILL P WEXIT Cut off DS CTC. MU Baker CTC. Pull test to 35,000 Ibs and PT to 3,500 psi. 10:30 - 11 :30 1.00 KILL P WEXIT Load and launch dart. Pump volume dart. Hit at 57 bbls. 11 :30 - 12:30 1.00 KILL P WEXIT Pull BPV with lubricator. - 1100 psi on tubing. 12:30 - 14:30 2.00 KILL P WEXIT Bring tools to rig floor for milling operation. MU 3.8" HC D331 milling BHA. MU injector head. Test to 3000 psi. OK. - Announce gas venting on W-27. - Flag off area around rig while venting gas. Open Master. 14:30 - 16:00 1.50 KILL P WEXIT RIH with milling BHA at 100 fpm. - Limit returns to 150 psi on tiger tank. Printed: 8/30/2004 9:45: 13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/17/2004 14:30 - 16:00 16:00 - 16:30 16:30 - 17:00 17:00 - 18:45 18:45 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 23:30 23:30 - 00:00 8/18/2004 00:00 - 01:1 0 01:1 0 - 02:45 02:45 - 03:00 03:00 - 03:30 03:30 - 03:45 03:45 - 04:45 1.50 KILL P WEXIT 0.50 CLEAN P WEXIT 0.50 CLEAN P WEXIT 1.75 CLEAN P WEXIT 0.25 CLEAN P WEXIT 0.50 CLEAN P 0.50 ZONISO P WEXIT WEXIT 1.50 ZONISO P WEXIT 1.50 ZONISO P 0.50 ZONISO P WEXIT WEXIT 0.50 ZONISO P WEXIT 1.17 ZONISO P WEXIT 1.58 ZONISO P WEXIT 0.25 ZONISO P WEXIT 0.50 ZONISO P WEXIT 0.25 PERF P WEXIT 1.00 PERF P WEXIT - At 10,525' MD, tubing pressure at 0 psi. Tag XN nipple on depth at 10,531' MD. Mill through XN nipple at 1.2 fpm from 10,525' MD to 10,535' - Minimizing WOB to prevent stalling. - Pump at 2.45 bpm, 2150 psi. - Steady returns of crude to tiger tank. RIH to 10,910' MD and circulate hole to 2% KCI. - Circ at 2.82 bpm. - Taking returns to tiger tank. - Reciprocating pipe to prevent excessive casing wear. POOH with miling BHA at 70 fpm to 10,000', then 120 fpm to surface. - No motor work at XN nipple. - Pumping at 2.77 / 2.50 bpm at 2570 psi. At surface, check for flow. well dead. Holding fluid level at surface. Layout milling BHA. Recover 100%. SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS E-Line equipment and Baker IBP. Rig up SWS E-Line unit and equipment. M/U Baker IBP, CCL and setting tool to SWS E-Line tools. CCL to center of IBP element was 22.6 ft. RIH with Baker 3-3/8" IBP for setting in T' liner. Log CCL tie-in at tailpipe. Correct CCL depth to 10,571'. Log Tie-in with 7" collars at 10800-10900'. On depth with 3 collars. 2600# up wt. Set Baker IBP center of element at 10,910'. Inflate with Baker setting tool. Approximate 75 min. inflate time Inflate Baker IBP with E-Line setting tool. Setting tool shorted out after 80 min. of inflate time. IBP element is set, but upper check valve is left open, by design, when pull release is required, 1000 # overpull release. Pull release with 4200# up wt, [1600# overpull), not able to log up, BKR CCL is also shorted out. IBP is set. Center of element at 10,910'. Top of tool at 10,902'. POH with BKR setting tool on E-Line. Layout BKR setting tool. Determine short to be SWS adaptor to BKR tools. Inner O-ring failed. Press test well. Pump 1 bbl to 1650 psi initial press, Lost 100 psi in 4 min. lost 220 psi in 10 min. Lost 400 psi in 20 min. Final press after 20 min. = 1250 psi. Fluid loss of about 0.1 bbls per 10 min. to lower perfs. Talked to Anc. Eng. and determined that fluid loss across 1/4" ID by 6" long open port in Baker IBP would be minimal. Will add 3 bbls to cement volume to allow for fluid loss across the IBP. Will leave 50 ft cement above whipstock to allow for fluid loss. SAFETY MEETING. Review procedure, hazards and mitigation for M/U and RIH with SWS 10 ft. perf gun. Re-head SWS line. Printed: 8/30/2004 9:45:13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/18/2004 03:45 - 04:45 1.00 PERF P WEXIT M/U 10 FT, 3-3/8" Power Jet perf gun, 6 SPF, with CCL. 04:45 - 06:00 1.25 PERF P WEXIT RIH with 10ft perf gun. Tie-in with CCL. Tag top of Baker IBP at 10,902'. Pick up 4.5 ft and fire guns. Perf from 10,887.5-10.897.5'. Good indication gun fired. Log up thru tailpipe. 06:00 - 07:00 1.00 PERF P WEXIT POOH with perf guns. - Lined up to circulate across the top of the hole. - No losses from perf job. 07:00 - 08:15 1.25 WHIP P WEXIT MU whipstock setting assembly. - Set to orient at 15 deg LOHS. 08:15 - 10:00 1.75 WHIP P WEXIT RIH with whipstock assembly. 10:00 - 10:30 0.50 WHIP P WEXIT Tie into collars at 10,847 and 10,808' MD. - Required 3.5' correction. Tag IBP at 10,903' MD. PUH to place TOWS at 10,865' ELM. Set Whipstock. - Good indications of Whipstock setting. - Whipstock set at 25 degress left of high side. - Pip tags located at 10,875' MD. 10:30 - 12:45 2.25 WHIP P WEXIT POOH with whipstock setting assembly.. Rig down SLB E-line crew. 12:45 - 13:15 0.50 REMCM-P WEXIT MU cement nozzle. MU injector head. 13:15 - 15:00 1.75 REMCM-P WEXIT RIH with cement nozzle and stinger. - Tag Whipstock at 10865' MD. No correction required. - PUH Flag pipe at 10,815' MD. 15:00 - 15:30 0.50 REMCM-P WEXIT Perform Injectivity test: - Stage up pressure to 2 bpm. - Straightline pressure increase to 2700 psi -- no injectivity. - Pressure schedule as follows: Minutes Pressure 2 2120 4 2000 6 1880 15 1650 - Bleed off pressure. - Zero injectivity. Discuss plan forward with anchorage while monitoring pressure. 15:30 - 15:45 0.25 REMCM-P WEXIT PJSM. Pressure test lines to 4000 psi. 15:45 - 16:15 0.50 REMCM-P WEXIT Pump cement. - Batch up cement. - Pump 2 bbls fresh water. - Zero "in" MM. - Pump 5 bbls 15.8 ppg Class G cement with silica flour at 1.7 bpm, 850 psi. - Pump 5 bbls of fresh water. - Pump 30 bbls of 2 ppb biozan water. - Pump rate at 2.75 bpm, 1500 psi. 16:15 -16:30 0.25 REMCM-P WEXIT Spot cement. Printed: 8/30/2004 9:45: 13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/18/2004 16:15 - 16:30 0.25 REMCM-P WEXIT - At 2bbls of cement out of the nozzle, begin PUH at 80%. - With 5 bbls of cement out of the nozzle, shut down pumps. - PUH to safety at 10,650' MD. 16:30 - 17:00 0.50 REMCM-P WEXIT Wait on cement to settle on whipstock. - Circulating at minimum rate. 17:00 - 17:30 0.50 REMCM-P WEXIT Apply 500 psi WHP. Continue to WOC. 17:30 - 18:00 0.50 REMCM-P WEXIT RIH to flag at 10,815' MD, contaminating cement with biozan. - RIH at 30fpm. - 2.58 bpm. - Hold 500 psi on WHP. 18:00 - 20:15 2.25 REMCM-P WEXIT POOH at 3 bpm taking returns to the tiger tank. Treat cement returns at surface for PH. Doyon 16 parked in middle of W pad access road re-arranging rig mats on access road. Road is blocked. 20: 15 - 20:45 0.50 REMCM-P WEXIT Layout cementing BHA. Jet stack. 20:45 - 21 :00 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U BKR milling BHA. 21 :00 - 21 :30 0.50 STWHIP P WEXIT M/U BKR window milling BHA. 21 :30 - 23:20 1.83 STWHIP P WEXIT RIH with milling BHA #2. 3.80" HC diamond window mill and string reamer. BKR extreme straight motor and 2 jts PH6 tbg with MHA. OAL = 82.61'. Tag cement at 10820'. 23:20 - 23:30 0.17 STWHIP P WEXIT Mill soft cement at 7 fpm to 10,860'. 2000# WOB. Cement still soft. 23:30 - 00:00 0.50 STWHIP P WEXIT Wait on cement. Cement in place at 1630 hrs. 8/19/2004 00:00 - 00:30 0.50 STWHIP P WEXIT Wait on cement. 00:30 - 01 :00 0.50 STWHIP P WEXIT Milled firm cement at 40 fph with 2000# WOB. 2.7/2.7 bpm, 1860 psi, Milled from 1 0860-1 0870'. Tagged pinch point of whipstock at 10870'. Flag coil. 01 :00 - 02:30 1.50 STWHIP P WEXIT Milling 3.80" window thru 7", 26#, L-80 Liner. 2.7/2.7 bpm, 1840/2240 psi, 2-3000# WOB. Mill at 1 fph. Milled to 10,871.8' . 02:30 - 05:00 2.50 STWHIP P WEXIT Milling window. 2.7/2.7 bpm, 1840/2240 psi, 3000# WOB. Mill at 1 fph. Milled to 10,875'. Exit liner at 10,875'. 05:00 - 06:00 1.00 STWHIP P WEXIT Milled formation to 10,885 ft. 2.7/2.7 bpm, 2000/2300 psi, 20 fph, 4K WOB. Doyon 16 rig clear of W pad access road at 0530 hrs. 06:00 - 09:00 3.00 STWHIP P WEXIT Dress window. Swap well over to flo-pro. 09:00 - 10:45 1.75 STWHIP P WEXIT POOH with milling BHA at 80 fpm. 10:45 - 11 :30 0.75 STWHIP P WEXIT LD window milling BHA. 11 :30 - 12:00 0.50 DRILL P PROD1 Pick up build BHA. - 1.37 deg motor. - HC 4.1/8" bicenter. 12:00 - 13:00 1.00 DRILL P PROD1 MU coil connector. - Pull test to 3500 Ibs. - Pressure test to 3500 psi. 13:00 - 13:45 0.75 DRILL P PROD1 RIH with build BHA #3 at 100 fmp circulating at minimum rate. Printed: 8/30/2004 9:45:13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/19/2004 13:00 - 13:45 0.75 DRILL P PROD1 Shallow hole test MWD and orienter at 3300' MD. - Orienter failed to respond after multiple attempts at varios pump rates. 13:45 - 14:15 0.50 DRILL N DFAL PROD1 POOH to change out orienter. - Orienter was used 56 hours last well (working fine). - After J-25A, sent to the shop for inspection (passed). 14:15 - 15:00 0.75 DRILL N DFAL PROD1 Change out orenter. 15:00 - 15:45 0.75 DRILL N DFAL PROD1 RIH with build BHA #4 to 3300' MD. Shallow hole test OK. 15:45 - 17:00 1.25 DRILL P PROD1 RIH to 10,790' MD for tie in. 17:00 . 17:30 0.50 DRILL P PROD1 Tie in to BSAG at 10,806' MD. - Correct depth -5'. RIH through window. Tag bottom at 10,880' MD. 17:30-19:15 1.75 DRILL P PROD1 Drill ahead in Shublik formation at TF = 15L from 10,880' MD. 2.6/2.6 bpm, 2900 - 3900 psi, 46 deg incl, 15L TF, 20 fph. Drilled to 10903'. 19:15 - 22:00 2.75 DRILL P PROD1 Drill build section in Shublik. 2.6/2.6 bpm, 2900-3800 psi, 46 degincl, 10fph. 10L TF, Drilled to 10,930'. 22:00 - 23:45 1.75 DRILL P PROD1 Drill build section in Shublik. 2.6/2.6 bpm, 2900-3800 psi, 46 deg incl, 10 fph. 10L TF, Drilled to 10,941'. 23:45 . 00:00 0.25 DRILL P PROD1 Orient TF. 8/20/2004 00:00 - 00:30 0.50 DRILL P PROD1 Orient TF. Not getting clicks. Pull up into 7" liner. No clicks. 00:30 - 01:15 0.75 DRILL P PROD1 Log GR tie-in with RA tag to BHCS/GR log. Adjust RA tag to 10,869' BKB. [-6 ft CTD]. Top of whipstock at 10,859'. Top of window at 10,864'. Bottom of Window at 10,869'. 01:15 - 03:20 2.08 DRILL N DFAL PROD1 Orient TF in 7" liner, getting 1/2 clicks by RIH while Orient and stop pump for 1-1/2 min. Orient TF to 50L. Not able to get last 2 clicks needed. Tag TD at 10,942'. 03:20 - 05:00 1.67 DRILL N DFAL PROD1 POH for a failed orienter. 05:00 - 05:55 0.92 DRILL N DFAL PROD1 C/O orienter and MWD Probe. Check bit. Bit at 0,1,1. Check scribe - OK. 05:55 - 08:00 2.08 DRILL N DFAL PROD1 RIH with build MWD BHA #5, 1.37 deg motor, re-run HC, 4.125" bi-center bit #4. SHT Tools at 3000 ft. Continue to RIH to 10,760' MD. 08:00 - 08:15 0.25 DRILL P PROD1 Orient Highside for window entry. RIH to bottom at 10,942' MD. 08:15 - 09:00 0.75 DRILL P PROD1 Stall out at bottom. Reactive torque causing orientation to move. Re-orient to required TF of 10L. Repeat multiple times trying to get a bite. 09:00 - 12:15 3.25 DRILL P PROD1 Drill ahead in Shublik at 5L TF from 10,9424 - 11,006' MD. ·2.57/2.68 bpm. - 3000 psi (2700 psi free spin). - ROP 20-30 fph. 12:15 - 12:30 0.25 DRILL P PROD1 PUH to 11,002' MD. Pump up a survey to check magnetic interference. Bad data. RBIH to 11,006' MD. Attempt to pump up a survey. Bad data. Still getting magnetic interference. 12:30 - 15:15 2.75 DRILL P PROD1 Drill ahead at 10L TF from 11,006 - 11,103' MD. - 2.37 / 2.48 bpm. - 3050 psi. Printed: 8/30/2004 9:45:13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/19/2004 8/25/2004 N1 Spud Date: 12/1/1988 End: 8/25/2004 8/20/2004 12:30 - 15:15 2.75 DRILL P PROD1 - 30-50 fph. - TSAD = 10,992' MD, 8,639' SS -- 4' high of prognosed. - 25' Fault at 10,916' MD (8,588' SS). No evidence while drilling. - No apparent losses. 15:15 - 15:45 0.50 DRILL P PROD1 Wipe hole section. Hole in good condition. 15:45 - 16:30 0.75 DRILL P PROD1 Drill ahead at 1 OL TF from 11,103' - 11,173' MD. ·2.48/2.58 bpm. ·3100 psi. ·30-50 fph. 16:30 - 17:00 0.50 DRILL P PROD1 Orient to 90L TF. 17:00 - 19:00 2.00 DRILL P PROD1 Drill ahead at 90L TF from 11,173' MD. - 2.44 / 2.58 bpm. - 3100 psi. - Average ROP at 50 fph. - Drilled to 11195'. 19:00 - 20:30 1.50 DRILL P PROD1 Driil build section in Z4. 2.7/2.7 bpm, 3100 - 4000 psi, 82 deg incl, 107L, 40 fph, Drilled to 11,250'. Note: Geo and Sperry determined that RA tag is at 10,870'. One foot shift deeper. Top of whipstock at 10,860'. Top of window at 10,865'. Bottom of window at 10,870'. 20:30 - 20:45 0.25 DRILL P PROD1 Wiper trip to window, clean hole. RIH. 20:45 - 23:00 2.25 DRILL P PROD1 Drilling Z4 build section, 2.7/2.7 bpm, 3100-3900 psi, 110L, 79 deg incl, 60 fph, Drilled to 11,350'. 23:00 - 23:20 0.33 DRILL P PROD1 Orient TF to right side. 23:20 - 00:00 0.67 DRILL P PROD1 Drilling Z4 build section, 2.7/2.7 bpm, 3100-3900 psi, 80R, 79 deg incl, 60 fph, Drilled to 11,375'. 8/21/2004 00:00 - 00:20 0.33 DRILL P PROD1 Drilling Z4 build section, 2.7/2.7 bpm, 3100-3900 psi, 80R, 79 deg incl, 60 fph, Drilled to 11,400'. 00:20 - 01:1 0 0.83 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 01:10-03:15 2.08 DRILL P PROD1 Drilling Z4 build section, 2.7/2.7 bpm, 3100-3900 psi, 140R, 80 deg incl, 60 fph, Drilled to 11,485'. 03:15 - 04:30 1.25 DRILL P PROD1 Orient TF around 2 times, went too far first time. 04:30 - 05:20 0.83 DRILL P PROD1 Drilling Z4 build section, 2.7/2.7 bpm, 3100-3900 psi, 120R, 76 deg incl, 30 fph, Drilled to 11,505'. 05:20 - 06:00 0.67 DRILL P PROD1 Orient TF to 100R. 06:00 - 07:30 1.50 DRILL P PROD1 Drilling Z4 build section, 2.7/2.7 bpm, 3100-3900 psi, 100R, 74 deg incl, 50 fph. Drilled to 11,550' MD. 07:30 - 09:00 1.50 DRILL P PROD1 Wiper trip to 7" liner to clean cuttings out of low energy annulus. Cleaned up hole considerably (7k Ibs decrease in PU). Clean hole. RIH. - Window looks good. 09:00 - 09: 15 0.25 DRILL P PROD1 Orient TF to 90R. 09:15 - 10:30 1.25 DRILL P PROD1 Drilling Zone 4 turn section to 11,593' MD. - 2.4 / 2.5 bpm. - 3300 psi (3000 psi free spin). -40-60fph 10:30 - 10:45 0.25 DRILL P PROD1 Orient to 70L 10:45-11:15 0.50 DRILL P PROD1 Drilling Zone 4 turn section to 11,640' MD. - 2.49/2.62 bpm. Printed: 8/30/2004 9:45: 13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/21/2004 10:45 -11:15 0.50 DRILL P PROD1 - 3400 psi (3100 psi free spin). - 50 - 70 fph 11:15 -11:30 0.25 DRILL P PROD1 Orient to 120R 11 :30 - 14:15 2.75 DRILL P PROD1 Drilling Zone 4 turn section to 11,700' MD - 2.48 / 2.60 bpm. - 3500 psi (3000 psi free spin). - 50 - 60 fph - White clays evident from 11,490' - 11,535' and 11,550 - 11,570' MD. 14:15 - 15:30 1.25 DRILL P PROD1 Wiper trip up to 7" annulus. Clean hole. - Mud check shows 0.9 solids 162,000 LSRV I 820' drilled. 15:30 - 17:00 1.50 DRILL P PROD1 Drilling Zone 4/Zone 3 turn section to 11,723' MD - TF at 130R - 2.44/2.59 bpm. - 3000 psi - 20-30 fph - Zone 3 transition. Top Zone 3 at 11,705' MD. 17:00 - 17:15 0.25 DRILL P PROD1 Orient TF to 90R 17:15 - 20:00 2.75 DRILL P PROD1 Drilling Zone 3 conglomerate. - TF at 90R - 2.4 I 2.5 bpm. - 3100 psi. - 20 - 30 ROP - Begin mud swap (19:00 hrs) at 11,740'. 860'on re-conditioned FloPro. - Drilled to 11,750'. 20:00 - 21 :30 1.50 DRILL P PROD1 Drilling Z3 Conglomerate. 2.7/2.7 bpm, 3000 - 3900 psi, 20 fph, 110R, 68 deg incl, Drilled to 11,778'. 21 :30 - 23:00 1.50 DRILL P PROD1 Drilling Z3 Conglomerate. 2.7/2.7 bpm, 3000 - 3900 psi, 20-5 fph, 110R, 68 deg incl, Drilled to 11,787'. ROP went to zero. Drilled 2/3 of Z3, 85 ft md. 23:00 - 00:00 1.00 DRILL P PROD1 POH for new bit and RES tool. 8/22/2004 00:00 - 01 :30 1.50 DRILL P PROD1 POH for new bit and RES tool. 01 :30 - 01 :45 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation to C/O BHA. 01 :45 - 03:30 1.75 DRILL P PROD1 C/O Sperry MWD Probe, M/U new HC BC Bit #5, Bit #4 gradded a 8,8,3, Motor was OK, left it at 1.37 deg, M/S Sperry RES tool and test at surface. Check Orienter. MWD RES BHA OAL = 89.82'. 03:30 - 06:15 2.75 DRILL P PROD1 RIH with MWD RES BHA # 6. 1.37 deg motor and re-build HC 4.125" BC bit. SHT tools, OK. RIH. Correct -19 ft to flag. Orient TF to high side. RIH to TD. 06:15 - 07:00 0.75 DRILL P PROD1 Log up with Sperry Resistivity / GR tool at 1200 FPH to 10,953' MD. 07:00 - 08:25 1.42 DRILL P PROD1 Tie in to RA Tag. RIH. - + 16' correction. 08:25 - 08:30 0.08 DRILL P PROD1 Tag TD at 11,794' MD Orient TF to 60R. 08:30 - 11 :15 2.75 DRILL P PROD1 Drill ahead in Zone 2 to 11,950' MD. - 2.5/2.57 bpm. - 3300 psi (2800 psi free spin) - Top Zone 2 at 11,841' MD. Printed: 8/30/2004 9:45: 13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/22/2004 08:30 - 11: 15 2.75 DRILL P PROD1 - ROP picking up. 11 :15 - 12:00 0.75 DRILL P PROD1 Wiper trip to window. - 40k PU - Clean hole. · Occasional motorwork - not correlating to shales. 12:00 - 12:45 0.75 DRILL P PROD1 Drill ahead in Zone 2 to 12,000' MD. · 2.49 / 2.56 bpm - 3200 psi - 80 - 1 00 fph 12:45 - 13:00 0.25 DRILL P PROD1 Orient to 90L 13:00-14:15 1.25 DRILL P PROD1 Drill ahead in Zone 2 to 12,097' MD. - 2.49 / 2.56 bpm - 3200 psi - 80 - 130 fph 14:15 - 15:45 1.50 DRILL P PROD1 Wiper trip to 7" low energy annulus. - Overpull 5k at 11,200' MD. · PU 36K; SO 20K 15:45 - 16:00 0.25 DRILL P PROD1 Orient TF to 100L. 16:00 - 17:30 1.50 DRILL P PROD1 Drill ahead in Zone 2 to 12,200' MD. Called uncorrected TD at 12,201' MD. · 2.46 / 2.52 bpm - 3300 psi (3000 psi free spin). - Sperry MWD Resistivity shows 3-6 Ohms indicating water in Zone 2. 17:30 - 18:30 1.00 DRILL P PROD1 Final wiper trip. Tie in at RA tag. - 2.52 / 2.31 bpm. - 3000 psi - 40k PU. 18:30 - 19:00 0.50 DRILL P PROD1 Log GR tie-in with RA tag at 10,870'. Added 4.6 ft to CTD. 19:00 - 19:40 0.67 DRILL P PROD1 RIH to TD. Clean hole. Tag TD at 12,205 ft. 19:40 - 22:30 2.83 DRILL P PROD1 POH. Flag CT at 10,400' and 8700' EOP. 22:30 - 00:00 1.50 DRILL P PROD1 Layout MWD BHA and download Memory RES data. Bit graded at 6,5,1. 8/23/2004 00:00 - 01 :00 1.00 CASE P RUNPRD Prepare rig floor to run liner. Send RES Data to town GEO and discuss plan forward. 01:00-01:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running liner. 01:15·04:30 3.25 CASE P RUNPRD M/U BKR Fit / Guide Shoe, 1 jt 2-7/8 STL, BKR Fit Cllr, Bkr Latch Cllr, 9- Jts, 2-7/8" STL Tubing, TIW LSL Sub, 42 jts, 3-3/16", TCII tubing, XO, 3-1/2" Pup, Otis 3-1/2" "X" Nipple, 1 Jt 3-1/2" STL Tubing, 3-1/2" STL pup and Baker 3.70 x 3.00" Deployment Sleeve. 53 total joints. Liner total length = 1,693.12 ft. 04:30 - 05:00 0.50 CASE P RUNPRD Cut off SWS CTC. M/U BKR CTC. Pull test with 36K. 05:00 . 05:40 0.67 CASE P RUNPRD Pump Dart thru coil. Dart on seat at 56.3 bbls. Press test CTC with 3200 psi. 05:40 - 05:50 0.17 CASE P RUNPRD M/U CTC to Baker CTLRT. M/U injecter head. 05:50 - 07:50 2.00 CASE P RUNPRD RIH with liner on CT at 100 fpm. Circ. at 0.3 bpm. - Correct to flag at 10,399' MD. - Up Wt = 40.5k PU - Down Wt = 22k SO - Tag TD 3 times to confirm. Printed: 8/30/2004 9:45: 13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/19/2004 8/25/2004 N1 Spud Date: 12/1/1988 End: 8/25/2004 8/23/2004 07:50 - 08:30 0.67 CASE P RUNPRD Drop 5/8" steel ball to release from liner. - Pump down at 2.43 bpm / 2350 psi. - Slow rate at 40 bbls to 0.5 bpm / 1000 psi. - Ball on Seat at 43 bbls. - Ball seat sheared at 3600 psi. - PU to confirm release (32k PU). OK. 08:30 - 10:30 2.00 CEMT P RUNPRD Swap well to 2% KCI, double slick. - 2.67 / 2.62 bpm - 11 00 psi - Mix Bio pill - PJSM for Cement job. 10:30 - 10:50 0.33 CEMT P RUNPRD Batch mix cement. Fill lines with 2 bbls Fresh Water. Pressure test cement lines to 4000 psi. 10:50 - 12:00 1.17 CEMT P RUNPRD Cement liner in place. - Pump 2 bbl fresh water. Zero MM in. - Pump 20 bbls 15.8 ppg Class G cement. - Load dart. Clear lines. - Pump 30 bbls bio water. - Follow with 2% double slick KCI at 2.8 bpm / 1600 psi. - Zero MM out with cement at float shoe. - Slow pump rate at 50 bbls away to 1.25 bpm 1300 psi. - Latch LWP at 56.6 bbls (coil volume 56.3). - Displace at 2.1 bpm / 1300 psi. - Bumped plug at 68.3 bbls away (calculated 68.4 bbls). - MM out showed 19.7 bbls returns. - Pressure up to 1000 psi. - Bleed pressure. Check floats. OK. - Pressure up 200 psi. Unsting. - Flush hardline. - No losses during cement job. 12:00 - 13:30 1.50 CEMT P RUNPRD POOH with CTLRT at 1 :1. 13:30 - 14:00 0.50 CEMT P RUNPRD LD CTLRT. Clear rig floor. 14:00 - 14:45 0.75 CEMT P RUNPRD Prep GR/CCUMCNL logging tools. Bring equipment to rig floor. 14:45 - 16:15 1.50 CEMT P RUNPRD PJSM for PU BHA. PU GR/CCUMCNL logging and cleanout BHA. - 55 joints of CSH required in BHA. 16:15 - 18:00 1.75 CEMT P RUNPRD RIH to 10,400' MD with GR/CCUMCNL logging and cleanout BHA. -100fpm. - Circulate at minimum rate (0.25 bpm I 250 psi). 18:00 - 21 :15 3.25 CEMT P RUNPRD WOC to reach 500 psi compressive strength. High temperature cement, so longer set time. Cement at 500 psi at 2115 hrs. 21:15-22:45 1.50 EVAL P LOWER1 Log down from 10,360' at 30 fpm, circ. at 1.3 bpm. Entered top of line clean. Log down. Circ. in 15 bbls of new high vis FloPro perf pill. Tag PBTD at 12,169 ft CTD. Correct to 12,168'. 22:45 - 23:30 0.75 EVAL P LOWER1 Circ. high vis FloPro pill to bottom, had trouble getting high vis pill to pump. pump 1.5 bpm, Printed: 8/30/2004 9:45:13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 8/19/2004 8/25/2004 N1 Spud Date: 12/1/1988 End: 8/25/2004 8/23/2004 23:30 - 00:00 0.50 EVAL P LOWER1 Log out of hole at 60fpm while laying in 15 bbls FloPro perf pill. Log up to 10,360'. Liner is clean. 8/24/2004 00:00 - 02:45 2.75 EVAL P LOWER1 Pump 5/8" ball to open circ sub. POH while circ. at 2.5 bpm. Had contaminated cement returns to surface. Dump contaminated returns. Circ. well clean with new KCL water. 02:45 - 03:45 1.00 EVAL P LOWER1 Stand back 27 stds of CSH workstring. 03:45 - 04:00 0.25 EVAL P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for UO of SWS memory CNUGR. 04:00 - 05:00 1.00 EVAL P LOWER1 Layout SWS memory CNUGR logging tools. UO CSH workstring, motor and mill. Jet stack. 05:00 - 07:00 2.00 EVAL C LOWER1 Baker ELRT test. Change out upper pipe/slip rams in stack to 3-1/2" pipe/slips. Attempt to press test rams. Need a XO. 07:00 - 08:00 1.00 EVAL P LOWER1 Pressure test liner lap to 2000 psi for 30 min. Time (min) Pressure Delta 0 2080 5 2065 15 10 2051 14 15 2036 15 20 2026 10 25 2021 5 30 2014 6 08:00 - 08:30 0.50 EVAL C LOWER1 Pressure / pull test 3-1/2" rams. Found XO. 08:30 - 09:00 0.50 EVAL C LOWER1 PJSM. 09:00 -11:15 2.25 EVAL C LOWER1 Surface Test of Baker ELRT. - Bring tools and equipment to the rig floor. - RIH with 5 joints 3-1/2 STL, deployment sleeve and GSLRT. - MU 10' of lubricator, including a pump-in sub. - No-go at packott. Available stroke length = 7.3' - RIH. Set 3-1/2" combi's. PUlSO 10k Ibs to ensure rams are holding. - SO 5k Ibs and re zero. - Circulate at 1.5 bpm. Confirm returns. SD pumps. Attempt to PU. No go. - Circulate at 1.75 bpm (945 psi). Confirm returns. SD pumps. PU 3.3'. - Pump. Taking returns out pump in sub -- flapper is closed, we are released. 11:15-12:00 0.75 EVAL C LOWER1 POOH. Repin. RIH. Surface test ELRT. - PJSM - POOH with running tool to re-pin. 12:00 - 12:45 0.75 EVAL C LOWER1 Re-pin Baker ELRT. - M/U re-pinned ELRT. - Strip down with lubricator over tools. - M/U lubricator. 12:45 - 13:20 0.58 EV AL C LOWER1 Stack 5 K on ELRT - OK. Pull 10 K on ELRT - OK. Stack 6K. Pump at 1.5 bpm, Pick up, Still have liner. Stack 6K. Pump at 1.75 bpm, 940 psi, Pick up free. ELRT is released from liner. Stack 8K on ELRT. Circ. 80 bbls, 2% KCL water at 2.8 bpm thru ELRT. 2.8 bpm, 2325 psi, Increase pump to 3.1 bpm at 30 bbls. 2700 psi, Printed: 8/30/2004 9:45: 13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/24/2004 13:20 - 13:45 0.42 EV AL C LOWER1 Pick up 4 ft and had 2000 Ib up WI to shear free with ELRT. Pump 7 bbls to annulus. 1.25 bpm, 500 psi. RIH and stack 5K down WI. Pump thru coil to pump off LWP. LWP sheared free at 500 psi, 14:45 - 16:00 1.25 EVAL C Pump LWP to latch collar at 0.45 bpm, 50 psi. LWP bumped, pressure up to 640 psi and sheared sliding sleeve to circ. LOWER1 Circ. at 0.5 bpm, Pickup ELRT out of deployment sleeve, clean. Bump up with CTC to pack-off. slack of 2 ft. shut down pumps. Drain lubricator. Break off lubricator. Recover ELRT. UO lubricator sections. Use ELRT to fish deployment sleeve and liner. Pull bottom of Deployment sleeve to 3' above rig floor. Set hand slips on 3-1/2" liner. Check slip rams marks on 3-12" liner, OK, some marking but liner is not deformed. UO ELRT with deployment sleeve and 3 ft pup. LOWER1 Recover 5 jts of 3-1/2", STL liner and Baker shear out landing collar. Recover 100% of tools from well. Close swab valve. LOWER1 Pull 3-1/2" pipe/slip rams and Install 2-3/8" pipelslip rams in stack. Function and pressure test 2-3/8" pipe/slip rams. 13:45 - 14:30 0.75 EVAL C 14:30 - 14:45 0.25 EV AL C Baker ELRT test complete. 10 hours total. Tool worked well. 2 small modifications will be done. 1. Set LWP shear release pins with a higher shear, to provide a clear indication of release and to prevent possible early release. 16:00 - 16:15 0.25 PERFOB P 2. Raise the circulation ports in the LWP stinger, to be spaced above the Aluminum insert when stung out, to reduce circulating pressure. LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for running SWS, 2" perforating guns. LOWER1 M/U SWS, 2" perforating guns. M/U SWS firing head with 1/2" ball seat, will take 5/8" ball. Dropped 5/8" ball thru BKR Hyd Disconnect, OK. M/U BKR Hyd Disconnect. LOWER1 M/U 27 stds of 1-1/4" CSH workstring. M/U SWS MHA and CTC. Perforating BHA OAL = 1,832.24'. LOWER1 RIH with perforating BHA. SWS 2" PJ perf guns, 6 SPF. Circ. at 0.3 bpm. Tag PBTD 2x @ 12170'. Pull to P/U WI & correct CTD to 12168' (PBTD as per MCNL log). PUH to ball drop postion @ 11810.7'. Hook-up PSSD (portable seismic shot detection) sensor to WHD. 16:15 - 17:00 0.75 PERFOB P 17:00 - 17:45 0.75 PERFOB P 17:45 - 20:00 2.25 PERFOB P Printed: 8/30/2004 9:45:13 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-27 W-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/19/2004 Rig Release: 8/25/2004 Rig Number: N1 Spud Date: 12/1/1988 End: 8/25/2004 8/24/2004 20:00 - 20:45 0.75 PERFOB P LOWER1 Pump a total of 10bbls perf pill ahead. Load 5/8" AL ball. Blow ball into CT with 5bbls perf pill behind. Position guns for btm shot @ 11810'. Chase ball @ 2.0bpm/2300psi. Slow to 0.8bpm/350psi @ 40bbls. Ball on seat after 51.3bbls away. RBIH to 11815'. PUH very slowly & ramp up to 2900psi with btm shot @ 11810'. Observe guns fire with good pressure drop indication & vibration on PSSD. Perforated interval = 11670' - 11700' & 11740' - 11810'. PVT '" 279bbls. 20:45 - 21 :00 0.25 PERFOB P LOWER1 POOH with perf gun BHA @ 40-60fpm pumping down the CT @ 2.0bpm & 1600-2000psi. POOH to 10409' (above TOL). PVT = 272bbls - Obbllosses while POOH to 10409'. 21 :00 - 21 :30 0.50 PERFOB P LOWER1 SID pump & flowcheck well for 30 mins - well stable. 21 :30 - 23:35 2.08 PERFOB P LOWER1 Continue POOH with perf gun BHA @ 65fpm pumping across the WHD @ 0.70bpm & 100psi WHP. PVT = 224bbls - total of Obbllosses. 23:35 - 00:00 0.42 PERFOB P LOWER1 OOH. Held PJSM for RIB 1-1/4" CSH. Meanwhile SID pump & flowcheck well - stable. 8/25/2004 00:00 - 01 :00 1.00 PERFOB P LOWER1 SIB injector. UD MHAs & RIB 27stds of 1-1/4" CSH tbg. Held valve drill while R/B CSH. 01 :00 - {J1:15 0.25 PERFOB P LOWER1 Held PJSM for UD perf guns. 01:15 - 02:00 0.75 PERFOB P LOWER1 R/U & UD perf guns. ASF! UO perf guns. 02:00 - 02:45 0.75 RIGD P POST MIU & RIH with nozzle BHA to 2500'. Start pumping MeOH. 02:45 - 03: 15 0.50 RIGD P POST Lay in MeOH @ 60/40 from 2500' to 300'. Circulate 100% MeOH to surface. 03:15 - 03:30 0.25 RIGD P POST OOH. SIB injector & UD nozzle BHA. SI swab. 03:30 - 03:45 0.25 RIGD P POST PJSM for ND BOP. 03:45 - 05:00 1.25 RIGD P POST N/D BOP. N/U & P/test tree cap. 05:00 - 06:00 1.00 RIGD P POST Clean out pits & tanks. Release rig @ 06:00Hrs on 8/25/04. Printed: 8/30/2004 9:45:13 AM . . 06-Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well W-27A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,847.99' MD 10,860.00' MD 12,205.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. :::eh;~g~8~ Signed Ji~~Q ()JU Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) )t ùv( -I clef Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA W Pad W-27A Job No. AKMW32333637, Surveyed: 22 August, 2004 Survey Report 27 August, 2004 Your Ref: API 500292189401 Surface Coordinates: 5959343.02 N, 611788.93 E (70017'52.3685" N, 149005'40.9246" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959343.02 N, 111788.93 E (Grid) Surface Coordinates relative to Structure Reference: 2120.74 N, 1905.28 E (True) Kelly Bushing Elevation: 90.90ft above Mean Sea Level Kelly Bushing Elevation: 90.90ft above Project V Reference Kelly Bushing Elevation: 90.90ft above Structure Reference SpE!r"r"Y-SU:1! DFtIL.L.tN.G seAVtCSS A Halliburton Company DEFINITIVE e e Survey Ref: svy4358 Halliburlon Sperry-Sun Survey Report for PBU_WOA W Pad - W-27A Your Ref: API 500292189401 Job No. AKMW32333637, Surveyed: 22 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 10847.99 46.300 268.130 8540.19 8631.09 1262.28 5 5171.41 W 5958003.95 N 606636.87 E 4712.42 Tie-on Point MWD Magnetic 10860.00 45.910 268.240 8548.52 8639.42 1262.56 S 5180.06 W 5958003.55 N 606628.22 E 3.314 4720.75 Window Point 10889.22 45.530 270.910 8568.92 8659.82 1262.71 5 5200.98 W 5958003.08 N 606607.31 E 6.670 4741.01 10919.23 46.140 273.530 8589.83 8680.73 1261.885 5222.48 W 5958003.60 N 606585.79 E 6.584 4762.08 e 10950.52 45.880 276.140 8611.56 8702.46 1259.98 S 5244.91 W 5958005.16 N 606563.34 E 6.058 4784.30 10980.15 49.040 278.490 8631.59 8722.49 1257.195 5266.56 W 5958007.63 N 606541.65 E 12.160 4805.98 11010.00 53.820 280.750 8650.20 8741.10 1253.28 5 5289.56 W 5958011.20 N 606518.60 E 17.071 4829.24 11042.76 60.640 277.320 8667.93 8758.83 1248.99 5 5316.74 W 5958015.08 N 606491.35 E 22.598 4856.66 11073.47 66.620 273.980 8681.56 8772.46 1246.30 5 5344.11 W 5958017.36 N 606463.95 E 21.771 4883.86 11104.21 72.070 269.410 8692.41 8783.31 1245.475 5372.84 W 5958017.76 N 606435.21 E 22.531 4911.94 11135.59 79.010 264.840 8700.24 8791.14 1247.01 S 5403.16 W 5958015.77 N 606404.92 E 26.224 4940.98 11168.12 82.350 263.080 8705.51 8796.41 1250.39 S 5435.08 W 5958011.92 N 606373.05 E 11.572 4971.13 11198.57 81.300 256.230 8709.84 8800.74 1255.80 S 5464.71 W 5958006.07 N 606343.51 E 22.532 4998.58 11231.10 81.210 252.360 8714.79 8805.69 1264.50 S 5495.65 W 5957996.91 N 606312.69 E 11.762 5026.50 11263.96 79.190 245.860 8720.39 8811.29 1276.03 S 5525.89 W 5957984.93 N 606282.63 E 20.437 5053.05 11295.41 78.490 242.340 8726.48 8817.38 1289.51 S 5553.64 W 5957971.04 N 606255.08 E 11 .204 5076.71 11327.60 77.260 235.140 8733.25 8824.15 1305.82 S 5580.53 W 5957954.33 N 606228.44 E 22.198 5098.85 11366.33 78.660 238.300 8741.33 8832.23 1326.60 S 5612.19 W 5957933.08 N 606197.10 E 8.760 5124.55 11399.64 81.210 243.220 8747.15 8838.05 1342.61 S 5640.80 W 5957916.65 N 606168.73 E 16.434 5148.44 11430.41 81.470 248.850 8751.79 8842.69 1354.96 S 5668.58 W 5957903.89 N 606141.13 E 18.108 5172.41 11462.16 78.490 254.300 8757.32 8848.22 1364.85 S 5698.23 W 5957893.56 N 606111.63 E 19.333 5198.78 e 11493.80 74.880 259.040 8764.61 8855.51 1371.95 S 5728.17 W 5957886.01 N 606081.80 E 18.510 5226.12 11523.06 72.770 263.080 8772.76 8863.66 1376.32 S 5755.92 W 5957881.23 N 606054.12 E 15.094 5251.99 11553.85 70.840 268.710 8782.38 8873.28 1378.42 S 5785.08 W 5957878.70 N 606024.99 E 18.466 5279.77 11583.22 69.700 274.860 8792.31 8883.21 1377.57 S 5812.70 W 5957879.14 N 605997.37 E 20.087 5306.77 11614.95 71.890 273.100 8802.74 8893.64 1375.49 S 5842.59 W 5957880.77 N 605967.45 E 8.664 5336.28 11644.26 72.770 270.820 8811.64 8902.54 1374.54 S 5870.50 W 5957881.31 N 605939.53 E 7.997 5363.59 11675.60 71.980 275.920 8821.14 8912.04 1372.78 S 5900.30 W 5957882.62 N 605909.70 E 15.712 5392.93 11706.78 69.260 280.140 8831.49 8922.39 1368.69 S 5929.42 W 5957886.29 N 605880.53 E 15.461 5422.17 11741.82 68.110 287.340 8844.24 8935.14 1360.95 S 5961.10W 5957893.55 N 605848.73 E 19.420 5454.79 27 August, 2004 - 14:38 Page 20f4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA W Pad - W-27A Your Ref: API 500292189401 Job No. AKMW32333637, Surveyed: 22 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11773.96 66.520 287.810 8856.63 8947.53 1351.99 S 5989.37 W 5957902.08 N 605820.33 E 5.128 5484.38 11806.14 65.990 290.980 8869.59 8960.49 1342.22 S 6017.15 W 5957911.45 N 605792.41 E 9.166 5513.70 11838.51 69.430 298.030 8881.88 8972.78 1329.78 S 6044.37 W 5957923.47 N 605765.01 E 22.777 5543.12 11872.56 72.330 299.440 8893.03 8983.93 1314.32 S 6072.57 W 5957938.52 N 605736.58 E 9.372 5574.23 11910.64 76.560 310.190 8903.27 8994.17 1293.38 S 6102.61 W 5957959.00 N 605706.23 E 29.367 5608.44 e 11940.15 79.910 315.650 8909.29 9000.19 1273.71 S 6123.75 W 5957978.36 N 605684.80 E 21.374 5633.71 11970.97 79.300 319.350 8914.85 9005.75 1251.37S 6144.23 W 5958000.39 N 605664.00 E 11.973 5658.99 12003.44 79.650 326.050 8920.79 9011.69 1225.99 S 6163.56 W 5958025.48 N 605644.29 E 20.315 5683.88 12036.52 79.560 317.940 8926.77 9017.67 1200.37 S 6183.58 W 5958050.80 N 605623.89 E 24.115 5709.50 12075.69 79.910 314.590 8933.75 9024.65 1172.53 S 6210.22 W 5958078.24 N 605596.84 E 8.463 5742.09 12109.57 81.850 309.480 8939.13 9030.03 1150.14 S 6235.06 W 5958100.26 N 605571.67 E 15.954 5771.61 12141.21 80.530 305.080 8943.97 9034.87 1131.21 S 6259.93 W 5958118.82 N 605546.52 E 14.361 5800.32 12171.58 80.090 302.960 8949.09 9039.99 1114.46 S 6284.74 W 5958135.20 N 605521.46 E 7.032 5828.44 12205.00 80.090 302.960 8954.84 9045.74 1096.55 S 6312.36 W 5958152.70 N 605493.58 E 0.000 5859.58 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 284.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12205.00ft., The Bottom Hole Displacement is 6406.90ft., in the Direction of 260.145° (True). e 27 August, 2004 - 14:38 Page 3 of4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA W Pad - W-27A Your Ref: API 500292189401 Job No. AKMW32333637, Surveyed: 22 August, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10847.99 10860.00 12205.00 8631.09 8639.42 9045.74 1262.28 S 1262.56 S 1096.55 S 5171.41 W 5180.06 W 6312.36 W Tie-on Point Window Point Projected Survey e Survey tool prOf/ram for W-27 A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10847.99 0.00 10847.99 8631.09 12205.00 8631.09 BP High Accuracy Gyro (W-27) 9045.74 MWD Magnetic (W-27A) e 27 August, 2004 - 14:38 Page 4 of4 DrillQuest 3.03.06.006 TREE = 4-1/16" MCEVOY -.- . WELLHEAD = FMC A CTUA TOR = BA KER ""-_."."-,,,,,,,,,,,,,-==--,-,.~,,,,,.,~'-~,,,,,,,,,,,,,,,~' KB. ELEV = 90.87' BF. ELEV = 52.72' e Max Angle = e¿>6@11 Ù38' Datum MD = 11605' Datum TVD = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" H 2699' Minimum ID:::: 2.37" @ 11 X~OVER SUB, STl TOPOF 3-112" x 3-3/16" x 2-l/8" LNRH 10511' I BOT DEPLOY SLEEVE. 6' LONG, 37":0 H 1051 l' 135" X NiP 2.813" IDH 10550' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10569' ESTTOPOFCEMENT H 10511' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 10767' I MECHANICAL WHIPSTOCKH 10860' MILLOUTWINDOW H 10865'· 10870' I I Rl\ P\PT/\G H HìS70' I PERFORA TION SUMfVARY REF LOG: MCNLlCCUGR OF 8/24120Q4 TIE-IN LOG: GEOLOGY PIX LOG ANGLE AT TOP PERF: 72" @ 11670' _ Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DA TE 2" 6 11670' - 1HOO' Opn 03/24/04 2" 6 11740' - 11810' Opn 08/24/04 I PBTD H 11664' 7" LNR, 26#, L-80, .0383 bpf, ID == 6.276" H 11707' -27 I S.NOTES: FROM - DRAFT . - ~ ~ ST MD 6 3006 5 6087 4 8074 3 9239 2 9929 1 10270 L - 2116' H4-1/2"OTISSSSVNIP,ID=3.813" I TVD 2914 5276 6688 7455 7916 8148 GAS LIFT MANDRELS DEV TYPE VLV LATCH 9 MERLA DOME RA 45 MERLA DOME RA 49 MERLA DOME RA 47 MERLA DMY RA 47 MERLA DMY RA 47 MERLA SO RA PORT DA TE 16 08/17/03 16 08/17/03 16 08/17/03 o 08/17/03 o 20 08/17/03 I I I 10375' H4-1/2" OTIS SLIDING SLEEVE, ID == 3.813" I - í z ì z I 10425' H4-1/2" TBG SEAL ASSY I 10425' 10493' 10506' 10531' 10561' 10569' 10571' H9-5/8" x 4-1/2" TrN PKR, ID == 4.0" I H4-1/2" OTIS X NIP, ID == 3.813" I H TOP OF 7" LINER - 4-1/2" OTIS XN NIP, 10 == MilLED TO 3.3" - '"-1t?" X 3,"/16" V_O'¡>:q \ ....> ,<,_. ....h) /\. '-. " L..f, - 4-1/2" TBG TAIL, 10 = 3.958" H ELMO TT LOGGED 08/11/92 I 11865' H LSL SUB. 3-3/16" x 2-7i8" X-OVER I 3-1/2" x 3-3/16" x 2-7IB" LNR: CIV1I'ED & ?ERFED H 12205' I 10945' CTM H CSG DAMAGE - 3.60" RESTRICTION I 11207' H MARKER JOINT I I 11306' H4" X 1-3/4" X 3/8" TEL FINGER I DA TE REV BY COMMENTS DA TE REV BY COMMENTS 11/23/88 GRV ORIGINAL COMPLETION 08/25/04 ,J. U. E NORDIc.1 CTDSIDETRACK 09/09/01 RNlTP CORRECTIONS 07/22/03 JBMlKK GL V C/O 08/17/03 RWL/KK GLV C/O 11/01/03 KCFITLP CHANGE MIN ID INFORMATION 07/07/04 SRB/KAK CASING DAMAGE PRUDHOE BA Y UNfT WELL: W-27A ÆRMfT No: 204-144 API No: 50-029-21894-01 SEC 21, T11 N, R12E, 910' FNL & 1445' FEL BP Exploration (Alaska) ~, I~ u . f / ¡ l FRANK H. MURKOWSKI, GOVERNOR ~1#.4.SIiA. ORAND GAS CONSERVATION COMMISSION l í , ! l ¡ 1 ! 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519·6612 Re: Prudhoe Bay W-27A BP Exploration (Alaska) Inc. Permit No: 204-144 Surface Location: 910' SNL, 1445' WEL, SEC. 21, TIIN, RI2E, UM Bottomhole Location: 1819' SNL, 2815' WEL, SEC. 20, TIIN, RI2E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to itness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 7 ager). BY ORDER OF THE COMMISSION DATED this "Y day of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. W61\- 1/ ~o I ¿COf o Drill II Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 910' SNL, 1445' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 2176' SNL, 1438' WEL, SEC. 20, T11N, R12E, UM Total Depth: 1819' SNL, 2815' WEL, SEC. 20, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 611789 y- 5959343 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 10865 feet Maximum Hole Angle: 81 I STATE OF ALASKA I ALASKA I AND GAS CONSERVATION COM ISSION PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class 0 Exploratory II Development Oil 0 Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: II Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU W·27A / 6. Proposed Depth: 12. Field I Pool(s): MD 12600 TVD 902055 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028262 / 8. Land Use Permit: 9. Acres in Property: 2560 13. Approximate Spud Date: September 1, 2004 / 14. Distance to Nearest Property: 11,350' Hole 4-1/8" x 3-3/4· Casing 3-3116· x 2-7/8" Weight 6.2# 16.16# 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 90.9 feet W-35i is 1575' away 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.0~ Downhole: 3575 Surface: 2695 ant' G.f. Coupling Length MD TVD MD TVD (including stage data) TCIII STL 2100' 10500' 8395' 12600' 9020' 93 cu ft Class 'G' Grade L-80 Junk (measured): 11306 Structural Conductor 110' 20" 8 cu yds Concrete Surface 2699' 13-3/8" 3984 cu ft Cold Set III & II Intermediate 10767' 9-5/8" 2341 cu ft Class 'G' Production Liner 1201' 7" 325 cu ft Class 'G' 110' 2699' 10767' 110' 2699' 8576' 10506' - 11707' 8399' - 9303' 20. Attachments II Filing Fee, $100 II BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): 8982' - 9036' II Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report II Drilling Fluid Program II 20 AAC 25.050 Requirements Perforation Depth MD (ft): 11315' -11383' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name S~an McLaughlin Title CT Drilling Engineer S·^-/ /1.1\ tt/\...:.- Phone 564-4694 Date: Contact Sean McLaughlin, 564-4694 Date Prepared By Name/Number: Terrie Hubble, 564-4628 PermitTo Drill Permit Approva,h tl. Number;20s-'- /9"7' 50- 029-21894-01-00 Date: b iI' Conditions of Approval: Samples Required DYes gNo Mud Log Required Hydr e Sulfide Measures ~Yes D No Directional Survey Required ?[ 500 fÇi pér C.O,.S ¡to. 000 , See cover letter for other requirements DYes ~No ~Yes D No Approved B : Form 10-401 ORIGINAL APPROVED BY THE COMMISSION Date ~kl¡; (,? %bZln" D~licate . BP W-27a Sidetrack . CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement and perforate Mud Program: · Well kill: 8.4 - 8.9 pp~ne · Milling/drilling: 8.5 ~ppg used PIo Pro or biozan for milling, new PIo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class n wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 33116" x 2 7/8" solid cemented liner compl~AO,500'-12,600'. / · The liner cement volume is planned to be ~blS of 15.8 ppg class G. CasingfLiner Information Ç;P OJ' 13 3/8", L-80, 68#, Burst 5020 psi; collapse 2260 psi 95/8", L-80 47#, Burst 6870, collapse 4750 psi 7", L-80, 26#, Burst 7240, collapse 5410 psi 4 Y2" L-80, 12.6#, Burst 8430 psi; collapse 7500 psi planned 33116" L-80 TCn, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") / 27/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size ].75") Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular pre venter will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 81deg. / · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property 11,350 ft · Distance to nearest well within pool 1575 ft to W-35i Logging · MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. · MCNL will be run cased hole. Hazards · W pad is .E.QLdesignated as an HzS pad. · One planned fault crossing above TSAD. No losses occurred when drillingthe parent well. · Lost circulation risk is considered low-medium. ,,/ Reservoir Pressure · Res. press. is estimated to be 3575 psi at 8800'8S (7.81 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2695 psi. / TREE = , 4-1/16" MCEVOY WELLHEAD = FMC 'ACTUA TOR = BAKER KB. ELEV = 90.87' SF. ELEV = 52.72' KOP = 3000' Max Angle = 50 @ 8200' Datum MD = 11199' Datum ìVD = 8800' SS . 13-3/8" CSG, 68#, L-80, ID = 12.415" H 2699' Minimum ID = 3.725" @ 10531' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR H 10506' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10569' I I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10767' I ÆRFORA TION SUMMARY REF LOG: BHCS ON 12/19/88 ANGLE AT TOP PERF: 38 @ 11315' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11315 - 11325 0 08/09/90 3-3/8" 6 11326 - 11342 0 07/16/94 3-3/8" 4 11343-11383 0 01/04/89 I PBTD H 11664' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 11707' DA TE REV BY COMMENTS DA TE REV BY 11/23/88 GRV ORIGINAL COM PLETION 09/09/01 RNlTP CORRECTIONS 07/22/03 JBMlKK GLV C/O 08/17/03 RWLlKK GLV C/O 11/01/03 KCF/TLP CHANGE MIN ID INFORMATION 07/07/04 SRB/KAK CASING DAMAGE W-27 . ~ L I I i 1 :g: Z' .} ~. .. ~ :5 G. -, ~ ~OTES: 2116' H4-1/2" OTIS SSSV NIP, ID = 3.813" I ~ ST MD 6 3006 5 6087 4 8074 3 9239 2 9929 1 10270 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 9 MERLA DOME RA 45 MERLA DOME RA 49 MERLA DOME RA 47 MERLA DMY RA 47 MERLA DMY RA 47 MERLA SO RA PORT DATE 16 08/17/03 16 08/17/03 16 08/17/03 o 08/17/03 o 20 08/17/03 ìVD 2914 5276 6688 7455 7916 8148 1 10375' H4-1/2" OTIS SLIDING SLEEVE. ID = 3.813" I 10425' H4-1/2" TBG SEAL ASSY I 10425' H9-5/8" x 4-1/2" TIW A<R, ID = 4.0" I 10493' H4-1/2" OTIS X NIP, ID = 3.813" 1 10531' H4-1/2" OTIS XN NIP, ID = 3.725"1 10569' H4-1/2" TBG TAIL, ID = 3.958" I 10571' H ELMDTT LOGGED 08/11/92 I 110945' CTM H CSG DAMAGE- 3.60" RESTRICTION I I 11207' HMARKERJOM J I 11306' I--! 4" X 1-3/4" X 3/8" TEL FINGER COMMENTS PRUDHOE BA Y UNrr WELL: W-27 PERMrr No: 1881470 API No: 50-029-21894-00 SEe 21, T11N. R12E. 910' FNL & 1445' FEL BP Exploration (Alaska) 13-3/8" CSG, 68#, L-80, ID == 12.415" H 2699' ~ DA TE REV BY COMMENTS DATE REV BY 11/23/88 GRV ORIGINAL COMPLETION 09/09/01 RN/TP CORRECTIONS 07/22/03 JBM/KK GLV C/O 08/17/03 RWL/KK GLV C/O 11/01/03 KCFrrLP CHANGE MIN ID INFORMATION 07/07/04 SRB/KAK CASING DAMAGE TREE==' 4-1/16" MCEVOY WELLHEAD == FMC 'ACTUATOR == BAKER KB. ELEV == 52.72' KOP == 3000' Angle == Datum MD == 11199' Datum"ND == 8800' SS Minimum ID::: 3.125" @ 10531' 4~1/2" OTIS XN NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID == 3.958" \~ 9-5/8" CSG. 47#, L-80, ID == 8.681" H 10767' 10569' H PERFORA TION SUMMARY REF LOG: BHCS ON 12/19/88 ANGLE AT TOP PERF: 38 @ 11315' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11315 11325 3-3/8" 6 11326 - 11342 3-3/8" 4 11343 - 11383 I PaTD H 11664' 7" LNR, 26#, L-80, .0383 bpf, ID == 6.276" H 11707' . 2116' t-l4-1/2" OTIS SSSV NIP, 10= 3.813" I L ~ ST MD 6 3006 5 6087 4 8074 3 9239 2 9929 1 10270 "ND 2914 5276 6688 7455 7916 8148 GAS LIFT MANDRELS DEV TYPE VLV LATCH 9 MERLA DOME RA 45 MERLA DOME RA 49 MERLA DOME RA 47 MERLA DMY RA 47 MERLA DMY RA 47 MERLA SO RA PORT DA TE 16 08/17103 16 08/17103 16 08/17/03 o 08/17/03 o 20 08/17/03 I I I 10375' H4-1/2" OTIS SLIDING í ì :8: :8: II 10425' H4-1/2" rsG SEAL ASSY I 10425' H9-5/8" x 4-1/2" TMJ 10493' H4-1/2" OTIS X NIP, ID ",3.813" J 10531' 10569' 1-14-1/2" TBG TAIL, ID== 3.958" I 10571' H ELMDTILOGGED08111/92 ¡ - I I úI~ 10945'CTMH CSGDAMAGE-3.60" RESTRICTION· I I 11207' H MARKER JOINT I I 11306' H4" X 1-3/4" X3/8"TELFINGER I COMMENTS PRUDHOE SA Y UNIT WELL: W-27 PERMIT No: 1881470 APf No: 50-029-21894-00 SEC21, T11N, R12E,910' FNL& 144;5'FEL BP Exploration (Ala¡;;ka) ObP . . ... SA.... .. IN·l'I?Q BP-GDB Baker Hughes INTEQ Planning Report Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clar1<e 1866) Sys Datum: Mean Sea Level --- ~_._---._._------- Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 ----.------.---.--_.____~.__~._.,,________._._______ __ ________._______m..____n_'._.__,_____ -----_...~----- ..----..--,- Site: W Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 47.83 ft 5957194.18 ft 609919.18 ft Latitude: 70 17 Longitude: 149 6 North Reference: Grid Convergence: 31.506 N 36.343 W True 0.84 deg -----~-_._-_.._._---- _'______m'.______"'._._·'______. ______,_._.___,_____.,_._______,. _____._,_._~____.~_.__ -.------,..- +N/-S 2121.45 ft Northing: +E/-W 1901.13 ft Easting: Position Uncertainty: 0.00 ft W-27 W-27 Well Position: Well: Slot Name: 27 70 17 52.368 N 149 5 40.925 W 5959343.02 ft 611788.93 ft Latitude: Longitude: --. -----_._--...__.~-- -- - ----_.._----...._------~----_._..-._-_._---_.__.._----...----- -------...------.- _________n__._.._____ __ __.,_,_______n.___ .~_________.________., '___ ~.._--_._-_._._._---_._-~-_._----~.__._-"--~-"----~--- -.-- Wellpath: Plan#3 W-27A 500292189401 Current Datum: 35: 27 12/1/198800:00 Magnetic Data: 7/27/2004 Field Strength: 57590 nT Vertical Section: Depth From (TVD) ft 37.90 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 W-27 1 0862.45 ft Mean Sea Level 24.91 deg 80.79 deg Direction Height 90.90 ft 284.00 ----,._--_.._-~---------,-----_..,------ ." -----,,-._-----.- ..--~-----,-,-,----- -- "-------~'_._- Targets W-27A Polygon3.1 0.00 -1486.57 -5966.22 5957768.00 605846.00 70 17 37.725 N 149 8 34.805 W -Polygon 1 0.00 -1486.57 -5966.22 5957768.00 605846.00 70 17 37.725 N 149 8 34.805 W -Polygon 2 0.00 -930.38 -6711.09 5958313.00 605093.00 70 1743.189 N 149 8 56.529 W -Polygon 3 0.00 -806.26 -6583.22 5958439.00 605219.00 70 1744.411 N 149 8 52.805 W -Polygon 4 0.00 -1272.06 -5930.02 5957983.00 605879.00 70 17 39.835 N 149 8 33.755 W -Polygon 5 0.00 -1487.25 -5786.19 5957770.00 606026.00 70 17 37.720 N 149 8 29.559 W W-27A Fault 1 0.00 -859.21 -5981.89 5958395.00 605821.00 70 17 43.895 N 149 8 35.277 W -Polygon 1 0.00 -859.21 -5981.89 5958395.00 605821.00 70 17 43.895 N 149 8 35.277 W -Polygon 2 0.00 -1913.31 -4510.28 5957363.00 607308.00 70 17 33.538 N 149 7 52.366 W W-27A Regional Fault 2 0.00 -531.88 -7546.33 5958699.00 604252.00 70 17 47.100 N 149 9 20.884 W -Polygon 1 0.00 -531.88 -7546.33 5958699.00 604252.00 70 17 47.100 N 149 9 20.884 W -Polygon 2 0.00 -830.97 -5661.41 5958428.00 606141.00 70 17 44.175 N 149 8 25.936 W W-27A Regional Fault 1 0.00 -378.94 -8078.16 5958844.00 603718.00 70 17 48.599 N 149 9 36.391 W -Polygon 1 0.00 -378.94 -8078.16 5958844.00 603718.00 70 17 48.599 N 149 9 36.391 W -Polygon 2 0.00 -2034.03 -5875.34 5957222.00 605945.00 70 17 32.341 N 149 832.144 W -Polygon 3 0.00 -2318.92 -4810.37 5956953.00 607014.00 70 17 29.547 N 149 8 1.104 W -Polygon 4 0.00 -2034.03 -5875.34 5957222.00 605945.00 70 17 32.341 N 149 8 32.144 W W-27A T3.1 8819.00 -1397.46 -5904.88 5957858.00 605906.00 70 17 38.602 N 149 8 33.020 W ·Plan out by 7.69 at 8819.00 -1405.08 -5903.83 5957850.41 605907.16 70 17 38.527 N 149 8 32.989 W W-27 A T3.2 8881.00 -1355.75 -6019.28 5957898.00 605791.00 70 1739.011 N 149 8 36.355 W ·Plan out by 38.55 at 8881.00 -1345.96 -6056.56 5957907.24 605753.58 70 17 39.107 N 149 8 37.442 W W-27A T3.3 9020.00 -915.39 -6842.85 5958329.00 605161.00 70 17 43.337 N 149 8 54.540 W -Plan out by 10.62 at 9020.00 -906.02 -6647.87 5958338.29 605155.84 70 17 43.429 N 149 8 54.687 W ObP . . B.. ..... (NT ItQ BP-GDB Baker Hughes INTEQ Planning Report Annotation 10862.45 8550.22 TIP 10865.00 8552.00 KOP 10885.00 8565.73 End 9 DLS / Begin 15 DLS 11066.15 8653.53 4 11216.15 8695.28 5 11426.15 8754.67 6 11516.15 8779.40 7 11666.15 8819.79 8 11766.15 8852.54 9 11841.15 8881.53 10 11944.66 8910.00 End 15 DLS / Begin 12 DLS 12069.66 8930.96 12 12269.66 8965.07 13 12600.00 9019.95 TD " " -----_._-_.._,-----~ -""'-~----- .-.._-~._-------. "___'_·w______._,_.._______ ______'w".,__~______._______ Plan: Plan #3 Date Composed: 7/27/2004 Identical to Lamar's Plan #3 Version: 2 Principal: Yes Tied-to: From: Definitive Path __n._.',,______._ -----'- . --------- Plan Section Information 10862.45 45.83 268.26 8550.22 -1262.58 -5181.75 0.00 0.00 0.00 0.00 10865.00 45.77 268.29 8552.00 -1262.63 -5183.57 2.50 -2.35 1.18 160.29 10885.00 47.51 267.66 8565.73 -1263.15 -5198.11 9.00 8.70 -3.16 345.00 11066.15 74.00 260.60 8653.53 -1280.43 -5353.66 15.00 14.62 -3.90 345.00 11216.15 74.10 237.18 8695.28 -1331.97 -5487.13 15.00 0.07 -15.61 267.00 11426.15 73.90 269.99 8754.66 -1388.14 -5677. 70 15.00 -0.10 15.62 95.00 11516.15 74.35 255.96 8779.40 -1398.72 -5763.37 15.00 0.51 -15.59 270.00 11666.15 74.81 279.30 8819.79 -1404.62 -5906.71 15.00 0.30 15.56 92.00 11766.15 67.10 292.93 8852.54 -1378.72 -5997.26 15.00 -7.71 13.63 123.00 11841.15 67.56 305.12 8881.53 -1345.21 -6057.62 15.00 0.62 16.25 90.00 11944.66 80.50 314.07 8910.00 -1281.80 -6133.89 15.00 12.50 8.65 35.00 12069.66 80.31 298.86 8930.96 -1208.77 -6232.70 12.00 -0.15 -12.17 268.00 12269.66 80.34 323.21 8965.07 -1080.36 -6380.23 12.00 0.02 12.18 92.00 12600.00 81.31 283.05 9019.95 -906.10 -6647.56 12.00 0.29 -12.16 268.00 Survey MD ft 10862.45 268.26 8550.22 -1262.58 -5181.75 5958003.62 606626.98 4722.38 0.00 TIP 10865.00 268.29 8552.00 -1262.63 -5183.57 5958003.54 606625.15 4724.14 2.50 KOP 10875.00 267.97 8558.92 -1262.87 -5190.79 5958003.19 606617.94 4731.08 9.00 MWD 10885.00 267.66 8565.73 -1263.15 -5198.11 5958002.80 606610.63 4738.12 9.00 End 9 DL 10900.00 266.89 8575.65 -1263.68 -5209.34 5958002.10 606599.41 4748.89 15.00 MWD 10925.00 53.32 265.73 8591.21 -1264.95 -5228.87 5958000.55 606579.91 4767.53 15.00 345.51 MWD 10950.00 56.97 264.66 8605.49 -1266.67 -5249.30 5957998.52 606559.50 4786.94 15.00 346.23 MWD 10975.00 60.63 263.68 8618.44 -1268.84 -5270.57 5957996.03 606538.27 4807.05 15.00 346.84 MWD 11000.00 64.29 262.77 8630.00 -1271.46 -5292.58 5957993.09 606516.30 4827.77 15.00 347.35 MWD 11025.00 67.95 261.92 8640.12 -1274.51 -5315.23 5957989.70 606493.70 4849.02 15.00 347.77 MWD 11050.00 71.63 261.10 8648.75 -1277.97 -5338.43 5957985.89 606470.56 4870.69 15.00 348.12 MWD 11066.15 74.00 260.60 8653.53 -1280.43 -5353.66 5957983.21 606455.36 4884.87 15.00 348.40 4 11075.00 73.93 259.22 8655.97 -1281.92 -5362.04 5957981.60 606447.01 4892.64 15.00 267.00 MWD 11100.00 73.80 255.31 8662.92 -1287.21 -5385.46 5957975.96 606423.68 4914.08 15.00 267.38 MWD 11125.00 73.73 251.41 8669.91 -1294.08 -5408.45 5957968.75 606400.79 4934.73 15.00 268.47 MWD 11150.00 73.74 247.50 8676.91 -1302.50 -5430.92 5957959.99 606378.45 4954.49 15.00 269.56 MWD 11175.00 73.82 243.60 8683.90 -1312.44 -5452.76 5957949.74 606356.76 4973.29 15.00 270.65 MWD 11200.00 73.97 239.70 8690.84 -1323.84 -5473.90 5957938.02 606335.80 4991.03 15.00 271.74 MWD 11216.15 74.10 237.18 8695.28 -1331.97 -5487.13 5957929.70 606322.69 5001.90 15.00 272.83 5 ObP . . B.. BAICa. ...... INTEQ BP-GDB Baker Hughes INTEQ Planning Report 11225.00 73.99 238.56 8697.71 -1336.49 -5494.33 5957925.07 606315.56 5007.80 15.00 95.00 MWD 11250.00 73.72 242.45 8704.67 -1348.31 -5515.23 5957912.94 606294.84 5025.22 15.00 94.62 MWD 11275.00 73.53 246.36 8711.72 -1358.67 -5536.86 5957902.26 606273.37 5043.70 15.00 93.54 MWD 11300.00 73.41 250.27 8718.83 -1367.53 -5559.12 5957893.07 606251.24 5063.16 15.00 92.44 MWD 11325.00 73.36 254.18 8725.98 -1374.84 -5581.93 5957885.42 606228.55 5083.52 15.00 91.33 MWD 11350.00 73.38 258.09 8733.14 -1380.58 -5605.18 5957879.34 606205.39 5104.69 15.00 90.21 MWD 11375.00 73.48 262.00 8740.28 -1384.72 -5628.77 5957874.85 606181.86 5126.58 15.00 89.08 MWD 11400.00 73.64 265.91 8747.35 -1387.24 -5652.61 5957871.97 606158.06 5149.10 15.00 87.97 MWD 11425.00 73.89 269.81 8754.35 -1388.14 -5676.60 5957870.72 606134.10 5172.15 15.00 86.86 MWD 11426.15 73.90 269.99 8754.66 -1388.14 -5677.70 5957870.70 606132.99 5173.23 15.00 85.77 6 11450.00 73.93 266.26 8761.28 -1388.89 -5700.60 5957869.61 606110.11 5195.26 15.00 270.00 MWD 11475.00 74.03 262.36 8768.18 -1391.27 -5724.51 5957866.87 606086.24 5217.88 15.00 271.03 MWD 11500.00 74.21 258.47 8775.02 -1395.28 -5748.21 5957862.52 606062.60 5239.92 15.00 272.11 MWD 11516.15 74.35 255.96 8779.40 -1398.72 -5763.37 5957858.85 606047.50 5253.79 15.00 273.17 7 11525.00 74.31 257.33 8781.79 -1400.68 -5771.66 5957856.76 606039.24 5261.36 15.00 92.00 MWD 11550.00 74.24 261.23 8788.56 -1405.16 -5795.30 5957851.94 606015.67 5283.22 15.00 91.63 MWD 11575.00 74.24 265.13 8795.36 -1408.02 -5819.18 5957848.73 605991.83 5305.70 15.00 90.57 MWD 11600.00 74.30 269.02 8802.14 -1409.24 -5843.21 5957847.14 605967.83 5328.72 15.00 89.51 MWD 11625.00 74.44 272.91 8808.87 -1408.84 -5867.28 5957847.19 605943.76 5352.17 15.00 88.46 MWD 11650.00 74.64 276.80 8815.54 -1406.80 -5891.28 5957848.87 605919.73 5375.95 15.00 87.41 MWD 11663.13 74.78 278.83 8819.00 -1405.08 -5903.83 5957850.41 605907.16 5388.54 15.00 86.37 W-27A 11666.15 74.81 279.30 8819.79 -1404.62 -5906.71 5957850.82 605904.28 5391.44 15.00 85.84 8 11675.00 74.09 280.46 8822.17 -1403.15 -5915.11 5957852.16 605895.86 5399.95 15.00 123.00 MWD 11700.00 72.09 283.78 8829.44 -1398.14 -5938.49 5957856.83 605872.40 5423.85 15.00 122.69 MWD 11725.00 70.15 287.17 8837.53 -1391.83 -5961.28 5957862.79 605849.52 5447.49 15.00 121.72 MWD 11750.00 68.27 290.64 8846.40 -1384.26 -5983.39 5957870.03 605827.31 5470.77 15.00 120.63 MWD 11766.15 67.10 292.93 8852.54 -1378.72 -5997.26 5957875.37 605813.35 5485.57 15.00 119.39 9 11775.00 67.11 294.37 8855.98 -1375.45 -6004.73 5957878.53 605805.84 5493.61 15.00 90.00 MWD 11800.00 67.20 298.44 8865.69 -1365.21 -6025.36 5957888.46 605785.06 5516.11 15.00 89.44 MWD 11825.00 67.39 302.50 8875.35 -1353.51 -6045.23 5957899.85 605765.02 5538.21 15.00 87.86 MWD 11839.75 67.55 304.89 8881.00 -1345.96 -6056.56 5957907.24 605753.58 5551.04 15.00 86.29 W-27A 11841.15 67.56 305.12 8881.53 -1345.21 -6057.62 5957907.97 605752.51 5552.25 15.00 85.38 10 11850.00 68.65 305.93 8884.83 -1340.44 -6064.31 5957912.64 605745.75 5559.89 15.00 35.00 MWD 11875.00 71.75 308.18 8893.30 -1326.27 -6083.07 5957926.53 605726.78 5581.52 15.00 34.70 MWD 11900.00 74.87 310.35 8900.48 -1311.11 -6101.61 5957941.41 605708.02 5603.18 15.00 33.93 MWD 11925.00 78.02 312.45 8906.34 -1295.04 -6119.83 5957957.21 605689.56 5624.75 15.00 33.31 MWD 11944.66 80.50 314.07 8910.00 -1281.80 -6133.89 5957970.23 605675.31 5641.59 15.00 32.82 End 15 11950.00 80.48 313.42 8910.88 -1278.16 -6137.70 5957973.82 605671.45 5646.17 12.00 268.00 MWD 11975.00 80.39 310.38 8915.04 -1261.70 -6156.04 5957990.01 605652.86 5667.95 12.00 268.11 MWD 12000.00 80.33 307.34 8919.23 -1246.23 -6175.23 5958005.18 605633.45 5690.31 12.00 268.61 MWD 12025.00 80.30 304.30 8923.43 -1231.81 -6195.21 5958019.30 605613.25 5713.19 12.00 269.12 MWD 12050.00 80.29 301.25 8927.65 -1218.48 -6215.93 5958032.33 605592.34 5736.52 12.00 269.63 MWD 12069.66 80.31 298.86 8930.96 -1208.77 -6232.70 5958041.78 605575.43 5755.13 12.00 270.15 12 12075.00 80.29 299.51 8931.86 -1206.20 -6237.30 5958044.28 605570.80 5760.22 12.00 92.00 MWD 12100.00 80.20 302.55 8936.10 -1193.51 -6258.41 5958056.66 605549.50 5783.77 12.00 91.89 MWD 12125.00 80.14 305.60 8940.36 -1179.71 -6278.81 5958070.16 605528.90 5806.91 12.00 91.37 MWD 12150.00 80.11 308.64 8944.65 -1164.84 -6298.45 5958084.72 605509.05 5829.56 12.00 90.86 MWD 12175.00 80.11 311.69 8948.94 -1148.96 -6317.27 5958100.32 605489.99 5851.66 12.00 90.33 MWD 12200.00 80.13 314.73 8953.24 -1132.10 -6335.21 5958116.91 605471.80 5873.15 12.00 89.81 MWD 12225.00 80.18 317.78 8957.51 -1114.31 -6352.24 5958134.45 605454.51 5893.98 12.00 89.29 MWD 12250.00 80.26 320.82 8961.76 -1095.63 -6368.31 5958152.88 605438.17 5914.09 12.00 88.77 MWD 12269.66 80.34 323.21 8965.07 -1080.36 -6380.23 5958167.97 605426.02 5929.35 12.00 88.25 13 ObP . . .Ii. 8AKD IIUIGIIIS IN'T8.Q BP-GDB Baker Hughes INTEQ Planning Report Survey 12275.00 80.32 322.56 8965.97 -1076.16 -6383.41 5958172.12 605422.78 5933.45 12.00 268.00 MWD 12300.00 80.23 319.52 8970.19 -1057.00 -6398.90 5958191.05 605407.01 5953.12 12.00 268.11 MWD 12325.00 80.18 316.47 8974.44 -1038.70 -6415.39 5958209.10 605390.25 5973.54 12.00 268.62 MWD 12350.00 80.14 313.43 8978.72 -1021.30 -6432.82 5958226.24 605372.57 5994.66 12.00 269.14 MWD 12375.00 80.14 310.39 8983.00 -1004.85 -6451.14 5958242.41 605354.00 6016.42 12.00 269.66 MWD 12400.00 80.16 307.34 8987.27 -989.39 -6470.32 5958257.58 605334.60 6038.77 12.00 270.18 MWD 12425.00 80.21 304.30 8991.53 -974.98 -6490.29 5958271.69 605314.41 6061.64 12.00 270.70 MWD 12450.00 80.29 301.25 8995.77 -961.64 -6511.01 5958284.72 605293.50 6084.96 12.00 271.22 MWD 12475.00 80.40 298.21 8999.96 -949.42 -6532.41 5958296.62 605271.93 6108.68 12.00 271.74 MWD 12500.00 80.53 295.17 9004.11 -938.35 -6554.43 5958307.36 605249.74 6132.73 12.00 272.25 MWD 12525.00 80.68 292.14 9008.19 -928.45 -6577.02 5958316.92 605227.01 6157.04 12.00 272.75 MWD 12550.00 80.87 289.10 9012.20 -919.77 -6600.11 5958325.27 605203.79 6181.55 12.00 273.25 MWD 12575.00 81.07 286.07 9016.12 -912.31 -6623.65 5958332.37 605180.15 6206.19 12.00 273.73 MWD 12600.00 81.31 283.05 9019.95 -906.10 -6647.56 5958338.23 605156.16 6230.89 12.00 274.21 TO BP Amoco WELLPATH O11TAILS Pflln#3 W-:t1A 5002921&9401 Pfl-twflt W..llpath: W-'J:7 Ti. ern MD: 10862.46 Rig: Nordic 1 Ref.O,,¡!!um: 35,27121111983 OO:UO eO.90ft v.s~: o..~~ ';~~= 2IU.OO' 0.00 0.00 ~~:~ $7,-&0 -"~--~'^^------ -'-'~"---~-'- REFERENCE INFORMATION ---~,-- ~-_.~-.- SECTION ÐETAIt.S TV. Ithg fi'm Tafgl'>t , 1081>2..4:> 4$.83 268.26 5550.22 ·i26:l.58 -$181.7a M. 0,00 :i::~~ 210835.00 ...,., 2$8,29 8$52."00 ·1262'.63 »5183.57 .'" 160.29 ~ ~~i:~ 47.51 267.a8 8505.73 -1263,15 -<51f18,H .... 345.00 473$.12 7~" 200.60 86SS,S3 4260.43 ~~:~ .~.. ,..... JSS4AI7 5 1121a.15 74,10 231.1ß :::~ :~ ~:t~~ .~.. 2~gg :~~:~~ ¡ Hi!H! n.. 2$.99 -$617.7:0 15.00 7~" m.s,j)ß 877-9.40 _13$&.72 --.5763.37 !~ä 2~~~ 5253.,7-9- 74.81 =:~5 5~ii _1404.62 !~ii 53$1.44 ;, 117$8,15 -67.10 :n~~~ 1:11:3.00 ;::~; 10 Hð41.15 ß'1.5ð ::gg 1111ß44.66 ...'" 314..07 891oAto _1281.80 -6133.$ 11Ulo 5641.$9 12121169,68 aU.31 29$.8.8 S$3tM16 -120&.77 <6232.70 .".. 21'16.00 Jl755.1$ 1:3 i:nß9.64 80.34 323.21 8ß65.01 -1000.3$ -4380.;U .".. .".. i!i92Q.:;!5 1412600.00 81.31 U3.05 901!Mi5 ·906.10 ..;reA7.56 .".. 264.00 6230.89 to I' ""mo l;:!,. i fd OD..' ".'. " D ~ I' ,. Sad 15 DLS f Sf>q1'1t 12 Þ S " 13 ,TO i ANNOTATiONS tal) Al'f ¡O~t¡-o~ l;!10ae:2M ,. " " t' 11 .. 1S .. " ,. ,. )7 ~_._...J5 8350 8400 8450 ....8500 c: ~ 8550 o an 8600 .... ;5 8650 a. GI &:::i 8700 ~ 8750 i 8800 > GI 8850u e ¡.. 8900 8950 9000· 9050 9100 LEGEND T Azimuths to True North Magnetic North: 24,91' Ma9netic Field Strength: 57590nT Dip Angle: 80.79' Date: 7/27/2004 Model: bggm2004 Plan: Plan #3 (W-27/Plan#3 W-27A) Created By: Brij Potnis Date: 7/27/2004 -100 -200 -300 .... c: ~ o o 'I/" .... -7400 -7300 -7200 -71 00 -7000 -6900 -6800 -6700 -6600 -6500 -6400 -6300 .ß200 -6100 .ß000 -5900 -5800 -5700 -5600 -5500 -5400 -5300 -5200 -51 00 -5000 -4900 -4800 West(-)/East(+) [100ft/in] 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 5950 6000 6050 6100 6150 6200 6250 6300 6350 6400 6450 6500 6550 6600 Vertical Section at 284.00· [50ft/in] . 7/2712004 1Z;ZlRM - All Measurements are from top of Riser 7/23/2004 "- Q) en .- cr: W-27A top of bag BAG 71/16" 5000 psi. bttm of bag middle of slips Blind/Shears .......................... middle of pipes 23/8" combi ram/slips I I TOTs I ..................·····7 1/16" 5000psi ..' ............. ............. middle of flow cross Mud Cross Mud Cross 71/16" 5000psi 0.......- ---' middle of blind/shears I variable bore pipe 3 1/2"-2 7/8" I ,.. ........................ middle of pipelslips TOTs 23/8" combi ram/slips L..........············7 1/16" 5000psi Flow Tee . . TERRIE L HUBBLE BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 130 "Mastercard Check" DATE PAY TO THE ORDER OF l'~' /····X'\/) ,,\\ fìh \ .. ,.'~c.~,>\\~ íl FirsfNational Bank Anchorage, AK 99501 $ ( "'- -, .........~=~......~.==..===..=,,=~.~ J() "'d__ DOLLARS MEMO (~4 /J(ß~? I:. 25 2000bOI:~~ . I.'" b 2 27"1.55b"- 0.:10 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /It/Æ (~-77A PTD# 2nLj-/~~ X Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn The permit is for a new welJbore segment of existing wen· , . Permit No, .' API No. Production. should continue to be reponed as a function 'of the original API Dumber. stated above. HOLE ID accordance with 20 AAC 25.005(f), aU records, data aDd Jogs acquired for tbe pilot hole must be dearly differeDtiated ID both name (name on permit plus PH) and API Dum ber (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.0SS~ Approval to perforate and produce is contingent UPOD issuance of ~ conservation order approving a spacing eneptioD. . (Company Name) assumes tbe liability of any protest to Ihe spacing .exception that may occur. AlJ dry dilcb sampJe sets submitted to tbe Commission must be in no greater ·tban 30' sampJe inlervaJs from beJow tbe permafrost or from where sampJes are first caugbt and J 0' sampJe inter:vaJs througb target ZODes. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT W-27 A PTD#:2041440 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV 11-01L GeoArea 890 Unit J1650 1 P~m)ilfee attacheß . _ _ _ _ . . . . . . . . . . _ _ _ . . . . . Y~s _ . . . . . . . . . . . _ . . . 2 leas~.number.apRrORriate_... .......Y~s.. ....... ._.... ___... ..._.. ............ 3 _U.nique weILn.a!Tl~.a[1d oumb.er . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ Y~s _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ . . . _ . . _ . _ _ . _ _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ . . _ _ _ . . . _ _ _ _ _ _ _ _ _ . . . . _ 4 WeJIJQcat~d ina.d.efineø'pOol. . . . . . . . . . . . . . . . Y~s . . . . _ _ . _ . . . . . . . . . . . _ _ . . . . . . . . 5 WellJQcat~d proper .distance. from driJling unitb91.lI1dary_ . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . _ . . . _ _ _ . _ . 6 WeJIJQcat~d proper distance_ from Qtber wel!s. . . . _ . . . . . . Y~s . . . . _ _ _ _ . . . . . . 7Sutficient .acrea9.e.ayailable in.dJilliog unjt. _ _ _ _ . .. ....... _ . _ . . . . Y~s . . _ _ . . . . _ _ _ _ . . . _ . _ . . . . _ . . . . . . . . . . 8 Itd~viªted, js weJlbQre platiocJu.ded . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . _ _ . . . . . . . . . . . . . . . . . _ _ _ . _ . . . . . . _ _ 9 .O'pe~atof onl}' affected party _ . _ _ . . _ . . . . . . . . Yes . _ _ . . . . . . . . . . _ _ _ _ . _ . . . . . . . . . . . . _ . . . . . . . . 10 _O'pe~atof bas_appropriate. Qond inJorce _ _ _ _ _ _ _ _ _ _ . . . .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . Y~s . . _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ . . 11 P~rmit c.a[1 be issued witbout co.nserva.tion order _ . . . _ _ _ . . . . . . . . . Yes . . _ _ _ _ . . _ _ . . . . . . . . . _ _ Appr Date 12 P~rmit ca[1 be issued wjtbQut administratillea'pprovaJ . . . . . . _ . Y~s . . - _ . _ . . . . . . . . - . . _ . . . . . . - RPC 7/30/2004 13 Can perm it be approved before 15-day wait Yes 14 WellJQcatedwithil1 area and. strata auU1Qrized by lojectioo Ord.er #(PullO#in_cOIJl!Tl~ots).(For NA...... _. .. _... _ _.. _. . _. _. _ . _...... _. _.. ....... 15 A!lwel!s_wit]1in.1l4-'11iLe.afea_ofreyiewjdeotified(For$eNj~we[lonl}'L _ _ _ _ _ _ _... _ _ _ _ _NA _ _ _ _ _ _ _... _ _.. _ _ _ _ _ _ _. _ _ _ _ _ _. _ _ _ _ _ _ _ _. _... _.. _ _ _ _ _ _ _ _ _ _. _ _. _. _ _ _ _ _ _ _ _. _ _ _ _. 16 PJe-produ.cect i[1jector; øuratio.n.of pre-.proøucìioo I~s$ than:3 months. (For.service well QnJy) . .NA . . . . . . _ _ _ . . . . . . _ . _ _ _ _ . . . . _ . _ . . . . 17 ACMPF.indjng.ofCon~i~te[1cyh_asÞeeJlj$sued.fortbisp~oiect .. _. _. _ . NA ...... 18 _C90du.ctor string.PJovided . . . . _ _ _ _ . . . _ _ . . . . . . NA . . . . . . . . 19 .S.urfaceca$ing.pJQtect$ all.known USDWs . . . . . . . . . _ _ . _ _ . NA _ _ _ . . . . _ . . . . . 20 _CMTv_oLadequ.ateto circ.uLateoJl.cood_uctor.& SUJt~g . _ . . . _ _ . . . NA . . . . _ . _ _ . . . . . . _ . . _ _ . . . . _ _ 21CMTv.oLadequ.atetotie-inlongstringtosurfC$g. . . . . . . . . _. . _ _ . NA _ _. . . . _ _ _ . . . . _ . . _. . _ 22 .CMTwil! coyeraJ koo.wn.Pfo_ductiYe bQrizon.s_ _ _ . . _ . . . . . . _ . Y~s. . . . . _ _ . . . . . . _ _ . . . . . . _ . . _ _ _ _ . . . _ 23 _C_asiog de.sign$ actequa.te for C..T, B&.p'ermafrost. . . . . . Y~s. _ _ _ _ . . . _ _ . . . . . _ _ . . . . . . . . . . . . _ . . . . . . . . . . . . . . 24 Aøequatetan.kage_oJ re_serve pit . . . . . . . . . . . . . . . . . . . Yes. . . . CTDU.. _ _ . . . . . . . _ _ _ _ _ _ . . . . _ _ . _ . . . 25 ItaJe-ørill" bas. a_ tOA03 for abandon.me.nt been apPJoved . . . . . . . _ . Yes _ . . _ _ _ _ 26 _Mequatewellbofe $eparatjoJl_pr0.pose¡:t _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _Y~s _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ . . _ _ . . . _ _ _ . _ _ _ _ _ . _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ 27 Itdjverter JectuiJed, dQes jt meet reguJatioos. . . . . _ _ _ . . . . . . .NA . . Sidetrack. . _ _ . . . . . . _ _ . . . _ _ . . . . Appr Date 28 _DJilIiog flujd.p.rogram schematic.&equiplist.adequate. . . . . . . . . . . . . . . Y~s. . MaxMW8,9RP9._ _ . . . . _ . _ _ _ _ . . _ WGA 7/30/2004 29 BOPEs, do they meet reguJatipn . . . . . . . . _ _ . . _ _ . Yes _ . . . . . . _ . . _ . _ _ . . . _ _ _ _ _ _ . . . . . . . . . . . . _ . _ . _ . . _ _ . 30 .B.OPEpfesHatiog ap.propriate;.testlo(pu.t psig in.commeots). . _ _ _ . . . . Y~s. . Test to_3500.RSi.MS~ 2695 psi. _ . . . . . . . . . _ . . . . . . . . . 31Choke_manjfold cQmpJies w/APLR~-5:3 (May B4L _ . Y~s _ . . _ _ _ _ . . . . _ . 32 Work will occur withoYLoperatjo_nsbutdown_ _ _ . . . . . Yes. _ _ 33 Is Rresence.Qf H2S gas RroQaþle. . . . . _ . . . . . . . . . No. . 34 Mecbanical.cooctition of wells within ,ð,OR yerified (For.s.ervjœ welJ only). . . . NA . . _ _Program DEV On/Off Shore On Well bore seg Annular Disposal Administration Engineering - - - - -- ~ - - - - - - - ~ - - - - - - - -- - - - - - - . . NoLan H2S pact. _ - - - ~ - - - - - - - - - - - - - - - - - - - - -- - - - - -- Geology 35 Permit can be issued wfo hyd~ogen. sulfide meas!Jres.. ...... 36 _D_ata_PJeseotect on_ Rote_ntial oveJRreSsure .zooe~ .. _ _ . . . _ . 37 _S~lslJlicanalysjs. Qf sbaJlow gas_zooes_ . . . . . . . . 38Se<lbed .condjtioo survey (if off-shore) . . . _ _ . _ _ . . . . . . 39 . CQnta_cl namelphoneJorwee~ly progre$s.reRorts [eXRloratory .only]. - - - - - - . . . . . . No .NA. . .NA . NA .NA. _. - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - Appr RPC Date 7/30/2004 - - - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- - - - - -- - - - - - -- Geologic Commissioner: Engineering Commissioner: þ' Date ~~f'C Date Date: ors lSJ6//f o o . . e e 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. . . ~{)(~/cfC¡ $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 13 14:40:47 2004 ) ).)~V Sperry-Sun Drilling Services LIS Scan Utili.ty ~ Reel Header Service name.............LISTPE Date................ .....04/10/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/l0/13 Origin...................STS Tape Name................UNKNOWN Continuation Number.. ....01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA W-27A 500292189401 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 13-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003233637 B. JAHN B. HOLT 1 R. MWD RUN 2 MW0003233637 B. JAHN B. HOLT 1 R. MWD RUN 3 MW0003233637 B. JAHN R. WHITLOW 1 # SURFACE LOCATION SECTION: TOWNSHI P: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 UN 12E 910 1445 90.87 # WELL CASING RECORD RECEIVED 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 10569.0 nrT ') n "fl04 ~j;",.' i Lt.., Lv # REMARKS: .~aska 0" & Gas Cons. Commission .Anchorage 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . . . 3. W-27A WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 10860'MD AND THE BOTTOM WAS AT 10870'MD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. UPHOLE SGRD TIE-IN DATA WERE MERGED WITH RUN 1 MWD DATA. 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). A MAD PASS WAS MADE OVER THE OPEN-HOLE INTERVAL (11794'MD - 10860'MD) PRIOR TO DRILLING RUN 3. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN ON 24 AUGUST 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 22 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL W-27A WITH API#: 50-029-21894-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12205'MD/8955'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ SHIFT-DERIVED RESISTIVITY (SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHI FT- DERIVED RESISTIVITY (DEEP File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10788.0 10854.5 10854.5 10854.5 10854.5 10854.5 10881. 5 STOP DEPTH 12159.0 12172.5 12172.5 12172.5 12172.5 12172.5 12204.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10788.0 10790.5 10799.5 10805.0 10811. 0 10815.5 10819.0 10851. 5 10853.5 10864.0 10867.5 10869.0 10872.0 10877.5 10883.5 10885.0 10887.5 10896.5 10901. 0 10905.0 10909.5 10911.5 10918.0 10924.0 10932.0 10934.5 10938.5 10941.5 10945.5 10953.0 10957.5 10962.5 10972.0 10974.0 10979.0 10990.0 10992.5 10995.5 10998.0 10999.5 11004.0 11007.0 11009.5 11014.0 11017.0 11029.5 11033.0 11035.0 11037.5 11043.0 11046.0 11049.0 11061.0 11063.0 11066.5 11069.5 11076.5 11080.0 11098.0 11100.5 11107.5 11122.0 11141.0 11145.5 11147.5 11154.5 11160.0 11170.5 11178.0 11191.5 11205.5 11212.0 11220.0 11235.5 . . GR 10790.0 10792.5 10799.0 10805.5 10811. 5 10815.0 10817.5 10852.5 10855.5 10864.5 10868.5 10870.0 10871.5 10877.5 10882.5 10884.5 10887.5 10896.5 10900.5 10904.5 10909.0 10911.0 10915.0 10922.0 10930.0 10932.0 10937.0 10939.5 10943.0 10951.5 10955.5 10960.5 10970.0 10972.0 10977.5 10988.0 10990.5 10993.0 10995.5 10998.5 11002.5 11005.5 11007.5 11012.0 11015.5 11 027 . 5 11030.5 11033.0 11035.5 11042.0 11044.5 11047.5 11058.5 11061.5 11065.0 11067.5 11075.0 11078.5 11095.0 11098.5 11104.5 11123.0 11140.5 11145.5 11147.5 11153.0 11158.5 11167.0 11176.0 11191.0 11203.0 11211. 5 11219.5 11234.5 . . 11250.0 11259.5 11266.0 11268.0 11273.0 11277.0 11281. 5 11302.0 11306.0 11319.5 11330.5 11335.0 11348.0 11353.0 11365.0 11368.5 11382.0 11391. 5 11396.5 11409.5 11422.5 11428.0 11441. 0 11445.5 11453.5 11468.0 11470.0 11477.0 11511.0 11513.5 11519.0 11522.0 11524.0 11528.0 11540.5 11557.5 11562.0 11566.0 11574.0 11576.5 11585.0 11589.5 11600.0 11605.0 11612.0 11621.5 11624.5 11627 . 0 11632.0 11635.0 11640.0 11645.5 11651.0 11655.5 11667.0 11683.5 11694.0 11704.0 11713.0 11725.0 11727.5 11730.0 11759.5 11798.0 11821.5 11839.5 11850.5 11852.5 11854.5 11869.0 11889.5 11891.5 11894.0 11902.5 11904.5 11248.5 11258.0 11264.0 11266.0 11271. 5 11275.5 11280.0 11301.0 11306.0 11317 . 5 11330.5 11335.5 11348.5 11352.5 11365.0 11367.5 11381.0 11391. 5 11396.0 11408.0 11420.0 11426.5 11442.0 11448.0 11454.5 11471. 0 11472.0 11478.0 11509.5 11514.0 11519.0 11522.0 11523.0 11527.0 11541.0 11555.5 11560.5 11564.5 11571.5 11575.0 11583.0 11587.0 11598.0 11603.5 11609.0 11620.0 11624.5 11626.0 11631. 5 11635.5 11639.5 11645.0 11650.0 11654.5 11665.5 11680.5 11691.0 11702.0 11710.5 11724.0 11726.5 11729.0 11758.0 11801. 0 11823.5 11840.5 11851. 5 11854.5 11856.5 11870.5 11892.5 11894.5 11898.0 11907.5 11909.0 . . 11911.0 11915.5 11928.5 11935.5 11938.0 11941.5 11944.5 11952.5 11969.5 11977.5 11996.5 12008.0 12013.5 12017.5 12030.0 12052.5 12059.0 12068.0 12072.0 12204.0 $ 11915.0 11917.5 11929.5 11937.5 11940.5 11943.0 11945.5 11952.0 11967.5 11975.5 11995.5 12009.0 12013.5 12018.0 12031.0 12051. 5 12059.5 12068.0 12073.0 12205.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 10790.0 10942.0 11794.0 MERGE BASE 10942.0 11794.0 12205.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................. Down Optical log depth units. .., ..... ..Feet Data Reference Point.. ......... ...Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10788 12204 11496 2833 10788 12204 ROP MWD FT/H 0.09 1260.94 53.7884 2646 10881. 5 12204 GR MWD API 16.17 655.88 52.9422 2691 10788 12159 RPX MWD OHMM 0.75 2000 26.3924 2637 10854.5 12172.5 RPS MWD OHMM 2.16 2000 31.1374 2637 10854.5 12172.5 RPM MWD OHMM 2.24 2000 34.6247 2637 10854.5 12172.5 RPD MWD OHMM 2.22 2000 38.733 2637 10854.5 12172.5 FET MWD HOUR 0.33 62.66 23.2762 2637 10854.5 12172.5 First Reading For Entire File..........10788 Last Reading For Entire File...........12204 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... . Version Number...........l.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOl Conwent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 10790.0 10881. 0 STOP DEPTH 10912.0 10942.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): 19-AUG-04 Insite 7.75 Memory 10942.0 10880.0 10942.0 45.5 45.9 TOOL NUMBER TLG005 4.125 10569.0 Flo Pro 8.60 .0 9.0 20000 7.6 .000 .000 .000 .000 .0 158.0 .0 .0 . . EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .IIN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.......... . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Code Offset o 4 8 Channel 1 2 3 Service Order Units FT FT/H API Size 4 4 4 Nsam I 1 1 Rep 68 68 68 MWD010 MWD010 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10790 10942 10866 305 10790 10942 ROP MWD010 FT/H 0.12 36.91 10.5179 123 10881 10942 GR MWD010 API 35.23 655.88 170.559 190 10790 10912 First Reading For Entire File..........10790 Last Reading For Entire File...........10942 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 10912.5 10942.5 STOP DEPTH 11 763.5 11794.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 21-AUG-04 Insite . DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point.......... ....Undefined Frame Spacing.......... ......... ..60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 7.75 Memory 11794.0 10942.0 11794.0 45.9 82.4 TOOL NUMBER TLG 011 4.125 10569.0 Flo-Pro 8.60 .0 9.4 18000 5.9 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 175.4 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10912.5 11794 11353.3 1764 10912.5 11794 ROP MWD020 FT/H 0.09 1260.94 46.5129 1704 10942.5 11 794 GR MWD020 API 17.17 362.34 51. 5622 1703 10912.5 11763.5 First Reading For Entire File..........l0912.5 Last Reading For Entire File...........11794 File Trailer Service name........ .... .STSLIB.003 . Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 10856.5 10856.5 10856.5 10856.5 10856.5 11764.0 11794.5 STOP DEPTH 12173.5 12173.5 12173.5 12173.5 12173.5 12160.0 12205.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 22-AUG-04 Insite 4.3 Memory 12205.0 11794.0 12205.0 66.5 81. 9 TOOL NUMBER 78012 171170 4.125 10569.0 Flo Pro 8.60 65.0 9.4 18000 5.9 .120 .048 .173 .105 65.0 173.3 65.0 65.0 . . # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction...... .,. ........Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record........ .... .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10856.5 12205 11530.8 2698 10856.5 12205 ROP MWD030 FT/H 5.2 135.51 76.0572 822 11794.5 12205 GR MWD030 API 16.17 69.56 27.1295 793 11764 12160 RPX MWD030 OHMM 0.75 2000 23.7929 2635 10856.5 12173.5 RPS MWD030 OHMM 2.16 2000 28.8152 2635 10856.5 12173.5 RPM MWD030 OHMM 2.24 2000 33.0343 2635 10856.5 12173.5 RPD MWD030 OHMM 2.22 2000 37.3699 2635 10856.5 12173.5 FET MWD030 HOUR 0.32 62.66 23.162 2635 10856.5 12173.5 First Reading For Entire File..........10856.5 Last Reading For Entire File...........12205 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/13 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name... ..........LISTPE Date.....................04/10/13 Origin...................STS Tape Name................UNKNOWN Continuation Number.. ... .01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer . . . . Service name.............LISTPE Date.....................04/10/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... .......UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
