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205-058
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 18-31A Set CIBP w/ Cement Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-058 50-029-22579-01-00 11804 Surface Intermediate Scab Liner Liner Liner 8710 3642 8698 4599 266 3279 8964 10-3/4" 7-5/8" 5-1/2" x 4-1/2" 5-1/2" 3-1/2"x3-3/16"x2-7/8" 8437 38 - 3680 37 - 8735 3883 - 8482 8581 - 8847 8525 - 11804 38 - 3662 37 - 8245 3865 - 8034 8116 - 8335 8070 - 8710 8800 2480 7150 6280 6280 7870 8800, 8980 5210 8180 7740 7740 8640 8680 - 8700 4-1/2" x 3-1/2" , 4-1/2" 12.6# 13Cr / 9.2# 13Cr /12.6# L80 8447, 8572 8198 - 8214 Conductor 80 20"40 - 120 40 - 120 1490 470 BKS S-3 PKR 8330 8330 7909 Bo York Sr. Area Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 0028307 8005, 8109 None Installed 7909 440 561 40039 33088 6 2 300 300 1135 1097 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 7:40 am, Oct 19, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.14 07:48:17 -08'00' Bo York SFD 10/20/2021 DSR-10/19/21MGR19OCT2021 RBDMS HEW 10/19/2021 ACTIVITYDATE SUMMARY 9/19/2021 ***WELL FLOWING ON ARRIVAL*** (profile mod) DRIFTED TO CBP @ 8,909' SLM W/ 12' x 2 1/2" BAILER (no issues) WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 9/21/2021 ***WELL S/I UPON ARRIVAL*** (Alaska Wireline CIBP & Cement Dump Bail) SET 3-3/16" ALPHA CIBP AT 8,800' MD.TOP OF PLUG ~ 8,799' MD. DUMP 11' (3.6 GAL) OF 17 PPG NEO SUPERSLURRY CEMENT (est. TOC ~ 8,788' MD). DUMP 11' (3.6 GAL) OF 17 PPG NEO SUPERSLURRY CEMENT (est. TOC ~ 8,777' MD). ALL LOGS TIED INTO SLB JEWELRY LOG DATED 27-MAY-2012. WELL TO REMAIN S/I FOR 72 HOURS FOR THE CEMENT TO CURE. PAD OP NOTIFIED. ***JOB COMPLETE ON 21-SEP-2021*** Daily Report of Well Operations PBU 18-31A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIAN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations H Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate El 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: 5-C/ 61 e Ir 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-058 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22579-01-00 7. Property Designation(Lease Number): ADL 0028307 8. Well Name and Number: PBU 18-31A 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: ��rw Total Depth: measured 11804 feet Plugs measured 8980 feet RECE 1 E D true vertical 8710 feet Junk measured 8712 feet .I I n 1I Effective Depth: measured 8964 feet Packer measured See Attachment feet l U true vertical 8437 feet Packer true vertical See Attachment feet � dawtf CC Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"91.5#1-1-40 40-120 40-120 1490 470 Surface 3645 10-3/4"45.5#NT-8 39-3684 39-3666 4560 1730 Intermediate 8701 7-5/8"29.7#S-95 37-8738 37-8245 8180 5120 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) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JUL 2 4 201?, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 139 4181 6902 840 597 Subsequent to operation: 921 32594 0 680 665 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development p Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stone,Christopher Contact Name: Stone,Christopher Authorized Title: DS 3&18 PE Contact Email: Christopher.Stone@bp.com Authorized Signature: �`y/y5r�� 3 Date:L11 20/o. Contact Phone: +1 907 564 5518 V Form 10-404 Revised 04/2017 7 V n- 7--/7--/`1-- R B D MS LL,J al 2 6 2017 Submit Original Only • S . Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED JUN 2 1 2017 RE: BP Exploration (Alaska), Inc. AOGCC Report of Sundry Well Operations Summary June 20, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations for Well 18-31A, PTD # 205-058. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment PBU 18-31A SW Name Type MD TVD Depscription 18-31A PACKER 3887.52 3869.75 7-5/8"Baker ZXP Top Packer 18-31A TBG PACKER 8335.1 7913.42 3-1/2" Baker SABL-3 Packer 18-31A TBG PACKER 8522.03 8067.25 4-1/2"TIW HBBP Packer 18-31A PACKER 8590.75 8124.2 5-1/2" Baker LT Packer • • Q 0 0 0 O 0 01 CV 03 03 0 0 0 0 5 T- 1U (0 CO Q 10 OO V L CD CO 000 Tr V O M O M T- d' cor- ;1.-) W (IS OD OOOOCAtiLOOO) M ,- CONOr Cr) r` CAD 0r- 01 O O CO O 00 00 M OD 00 I- O O C)) OD ti co CO O O Ns Ns Ns O v- T- Tr ti N TrMM000r- r- tiMCOO M 00 00 00 00 M OD C O Tr O Ns N LU Ns 0 N N N- O M 00 r` C3) Tr O 0) /47 r` UD r` - U') 00r- CO d' O co 00 00 CO O 00 Cr) CO CO Ci IR. I i Q M CO 1n N M LU N- M CD CD r` O N Ns 03 CD Tr Cn r- CCIO Cr M M M O OD O 0 Ch COQ) (D stem W O o O CL O 00 CD 0 CO COO 0 CO Cb V O � ZU) � JJ � JUOJ M l Itk 4t 4:k r 4teU1" Cq UP *k N ti • O • OON _NrV O _ (0N v- a) v (0 NO NU V CO N (N N . Ln L I fh In ti N r- O ti 01 Cr) N T-MO Tr O Tr co r` M Tr O 0 up Tr O M 0o0 T 't 0 N co N CO r- e u-i � Q c O w 0 13 U U O u_ CCCeCtrYc c Z Z Z Z Ct W w W W W W m m m ZZZZZDDD U U) Z J J J J J I- F- I- • • an In m co CO N- M M CO N N- to CO to '5.0. 0 N- to O N 0 CO N 00 M M Q. 4000N d 4 c V Nco � a) N N N N N NN 0 N 0 N- N- N- N- N- t` N- co 0- CO CO CO CO CO CO CO CO CO CO CO CO CO a. 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N. ¥ ¥ a H ( . \ k d 5 a a a N. \U) \ \ < • • z 0 0 w cC 0 0 a b g L o g % / 0 co \ kI b ƒ / % ƒ I Z W • c0 & f 0 ©a o 0 $ -J d 0_ 0 2 b < 0 © 0- \ 0 ® u® k § Z "" - LL % - 4 < 7 2 L — m (N a E co 2 O \ 2 co ^ 0 L E m • M Ep _ O / ? / / I- O Q � � w \ MO %(13 2 TD � N- � 0k � 1- U) 0o _ COG OD R L a 7 - _ q a. � o2 - Q » qc � o M $ 2 / 2 b R II ƒ \ O 0k goW0_, / 2CL ƒ a / 22a �0 ° % / / k ' R < Lo_ / H �&� ƒ ƒ k = E ZD ¥ Iubk \ / / w2 / O e Q g 9 6-1 Sb_ » E - QXOO4ZW ZS . R � � 09W < Zj k & � (Li) 09 k 0W / � / � / CectW / kO 5 ° _ 0- ' \ a n E g O _ § a) @ o 2 2 Z 2 Z w Q _, : _j % m £ 0 2 / q Ce / W R CL ƒ E < E 5 i b / \ 3 ¥ / 2qo \ n 18 31 A TREE,= RC • WELLHEAD= CNV � S NOTES: WELL ANGLE>70°@ 9322'"'41/2" -ACTUATOR.= BAKER C 8 3-1/2"CHROArE TBG'"' NTIAL KB.ELEV= 54.0' BF.ELEV= ? 2005' 4-1/2"FES X NP,ID=3.813" KOP= 1748' GAS LET MANDRELS Max Angle 95"@ 68ST MD TVD DEV TYPE VLV LATCH PORT DATE _. 119' ME 3 3497 3480 1 KBMG DOME BK 16 07/20/09 Datum MD= VA Datum TVD= 8800'SS ' MAY 2 6056 6005 24 KBG-2-9 Y 0 02/14/13 1 8249 7843 35 KBG-2-9 DMY M 0 07/01/09 10-3/4"CSG,45.5#,NT-80,13=9.953" --I 3680' 3692' H41/2"X 3-1/2"XO,D=2.992" 4-1/2"1BG,12.6#,13-CR,VAM TOP H 3692'_ 0152 bpf,D=3.958" !1 3883' I-7-5/8"X 5-1/2"BKR ZXP LW 41 441 w/BKR FLEXLOCKLNR HGR,D=4.90" 41 141 ') , i�, 8307' - 13-1/2"HES X NP,D=2.813" Minimum ID =2.377" @ 9495' 41 '4 " TOP OF2-718" LINER �1=4 ,:4 0,4 -��1/2 x31rz"BKRS3Ffa2D=2.79' �;1 • :+ 8353' H 3-1/2"HES X NP,D=2.75" �( '• ;�� 8405' H 3-1/2"HES XN NP,D=2.635" 5-1/2"LNR,17#,L-80 BTC-M H $426' 41 X41 0232 bpf,D=4.892" +1 OA 8427' H5-1/2"X 4-1/2"XO,D=3.958" 3-1/2"TBG,92#,13-CR VAM TOP, JH 8447' 8447' 1-13-1/2"MULESHOE,D=2.992" 0087 bpf,D=2.992" 8451' -ELMD TT LOGGED(05/27/12) 4-1/2"LMR,12.6#,13-CR ICI, 8469' 8482' -17-5/8"X 4-1/2"UNIQUE OVERSHOT .0152 bpf,D=3.958" _ 4-12"TBG STUB(07/09/09) H 8470' �� 8517' H7-5/8"X 4-1/2"TM/HBBRT PKR D=3.92" 3 NM, 8525' --3.70"BKR DEPLOY SLV,D=3.00" 3-1/2"LMR,8.81#,L-80 SIL, -I 8572' 8550' 14-12"HES XN NP 04/21/06 MILL .0087 bpf,D=2.992" D=3.80" (B@NND PIPE) 41/2"TBG,12.6#,L-80,_0152 bpf,D=3.958' 8572' , ill 8562' --13-1/2"FEB X NP,D=2.813" TOP OF 5-1/2"LNR H 8581' 8572' -14WENI ili li 112" LEG,D=3.958"(BN)PIPE) t•91 -11 .1". 8574' H 6 M)TT LOGGED 05/21/96(BRIM)PIPE) 7-5/8'CSG,29.7#,S-95,ID=6.875" H 8735' 1441 '•°4 41 41 I. 8572' -13-1f2"X 3-3/16"XO,D=2.80" TOP OF WHPSTOCK(TAGGED 422105 DMS) H 884r 0.44 ►4*/ 4/ 14 8600' HEST.TOP OF CEMENT(04/21/05 DMS) TWO RA TAGS(TAGG®04/22/05 DMS) --I 8857 1441 X44/ 5-1/2'LNR,17#,L-80,.0232 bpf,D=4.892" H 10556' �4�1 r• 7 I-FISH-IBP B 94�lTS 8 STFFBB2 14 Y441 /44/ RIC R (07/25/09) PERFORATDN SIA NARY 441` 4, 4.REF LOG: SPER2Y GIWROP ON 04/28/05 �4•, MLLOUT WEDOW 8847'-8855' ANGLEAT TOP FERE: 35"@ 868(7 ��� Note:(defer to Production DB for historical pert data ".4 8964' TOC(05/18/17) SIZE SPF INTERVAL Opn/Sgz DATE ,t!£4M44/,,1 2" 6 8680-8700 0 05/18/17 --- ��, -- 8980' -13-3/16"BKR�P(05/18/17) • 2" 6 9654-9684 C 05/29/12 "� 6 9495• X 2-7/8", 2" 6 9724-9754 C 05/29/12 • 13-3/16'XO,D=2.377" 2" 6 9824-9854 C 05/29/12 • 2" 6 10140-10230 C 04/29/05 3-3/16"LNR,6.2#,L-80 TCI, 9495' • • 2" 6 10270-10290 C 04/29/05 .0076 bpf,D=2.80" • • 2" 6 10320-10580 C 04/29/05 2" 6 10600-10780 C 04/29/05 4iS► 2" 6 11040-11230 C 04/29/05 STD H 11764' 4 2" 6 11270-11320 C 04/29/05 2" 6 11440-11490 C 04/29/05 2-718"LIR 6.16#,L-80 SIL, -I 11804' 2" 6 11530-11590 C 04/29/05 .0058 bpf,D=2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS Fi 1)HOE BAY INT 07/27195 ORIGINAL COMPLETION 08/10/09 AW/JMD DRLG DRAFT CORRECT1OM WELL: 18-31A 04/29/05 NORDICI CTD SIDETRACK(18-31A) 05/31/12 TTR/JMD ELM),ADFERFS(05/27-29/12) PEW No:"2050580 07/17/09 D14 IMO 02/20/13 MSS/JM)GLV CIO(02/14/13) AR No: 50-029-22579-01 07/30/09 JCM'PJC GLV C/O(07/20/09) 05/23/17 BTWJMD ADPERFS/CBFYCMT(5/18/17) SEC 24,T11 N,R14E,1561'EFL&64'FEL 07/30/09 DTRPJC RLL BP@ 8562'&FISH(07/25/09) 07/30/09 PJC DRLG HO CORWCTIONS 8P Exploration(Alaska) ~ '-' 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 ~ - 0 ~_<6 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1I1IIII11111II111II R~CAN \Ø' Color Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. , o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: o Other:: yrp III IIIIIIIII~ I11I1 ~ 151M 151 BY: C Maria) Date: ~ 3/ 07 Project Proofing BY: ~ Maria ') Date: 5,31 . 07 Scanning Preparation BY: ~." Maria) / x30=c10 Date:S: ~J, 07 + aD = TOTAL PAGES 50 (Count does not include cover sheet) Vvt 'I") 151 I ' t~ Production Scanning 11I11111111111 "III Stage 1 Page Count from Scanned File: 6/ (Count does include cover sheet) Page Count Matches Number in Scanl)ing Preparation: ~ES ~ Maria) Date:$" 31. 07 If NO in stage 1, page(s) discrepancies were found: _ YES NO ¡S¡Y\1 f BY: Stage 1 NO BY: Maria Date: 151 III II I1111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11I1111111 I 11111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11111111111I 1111111 10/6/2005 Well History File Cover Page.doc • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U ' Other Li Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ a 205 -058 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 22579 -01 — • a O 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028307 PBU 18 -31A,. 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11804 • feet Plugs measured NONE feet true vertical 8710 feet Junk measured 8712 feet Effective Depth measured 11764 feet Packer measured SEE BELOW feet true vertical 8710 feet true vertical SEE BELOW feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface SEE CASING / TUBING ATTACHMENT RECEIVED Production Liner JUL 31 2012 Liner Z t!S ' �AUG Sr U AOGCC Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet 4 -1/2" 12.6# 13 -CR 19' -3692' 19' -3674' 3 -1/2" 9.2# 13 -CR 3692' -8447' 3674' -8005' Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 8470' -8574' 8024' -8110' 5 -1/2" BKR ZXP LTP 3883' 3865' Packers and SSSV (type, measured and true vertical depth) - 1-1 / 2 " RxR 8 PKR R110' 7 9 0 9 ' 4 - 1/2" TTW HRRP - T 8517' 8061' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 472 3 3 3 7 7 10 1200 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development © o • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil © s . Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays Printed Name Nita Sum. erhays Title Petrotechnical Data Technician Signature 07 . // /r -, ���� Phone 564 4035 Date 07/27/2012 ,,,, .,,,/ I MS AUG 01 2012 v ' D 1Z Form 10-404 Revised 11/2011 V I Submit Original Only 9 \ rjjo�l 1, /110,904.—... Casing / Tubing Attachment ADL Casing Length Size MD TVD Burst Collapse CONDUCTOR 20" CONDUCTOR 22' - 110' 22' - 110' SURFACE 3659' 10 -3/4" 45.5# NT -80 21' - 3680' 21' - 3662' 5210 2480 PRODUCTION 8715' 7 -5/8" 29.7# 5 -95 20' - 8735' 20' - 8243' 8180 5120 LINER 4543' 5 -1/2" 17# L -80 3883' - 8426' 3865' - 7988' 7740 6280 LINER 42' 4 -1/2" 12.6# 13 -CR80 8427' - 8469' 7989' - 8023' 8430 7500 LINER 55' 3 -1/2" 8.81# L -80 8525' - 8572' 8070' - 8109' LINER 266' 5 -1/2" 17# L -80 8581' - 8847' 8116' - 8335' 7740 6280 • LINER 923' 3- 3/16" 6.2# L -80 8572' - 9495' 8109' - 8717' LINER 2309' 2 -7/8" 6.16# L -80 9495' - 11804' 8717' - 8710' 13450 13890 • • • 18 -31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/29/2012 * * * JOB CONTINUED FROM 28- MAY -2012* * * (ELINE PERFORATING) INITIAL T /I /O = 0/ 780/ 0 RUN 6: PERFORATE INTERVAL 9654- 9664FT WITH 2 ", 10FT POWERJET OMEGA 2006 HMX, 6SPF, 60 DEG PHASE. CCL TO TOP SHOT: 39 ". CCL STOP DEPTH: 9650.75FT. LRS ASSIST PUMPDOWN PERF ON ALL RUNS —3BPM. WELL SHUT IN ON DEPARTURE. FINAL T /I /O = 0/ 850/ 0 ** *JOB COMPLETE * ** 5/29/2012 T /I /O= 0 /820/0 Temp - SI (Assist E -Line with Perforating) Pumped a 3 bbl neat spear followed by 93 bbls 1% KCL /Safe Lube as directed to pump tool string to target depth. Pumped 10 bbls neat meth and 42 bbls of diesel to freeze protect the tubing. Final WHP= 0/850/0. E -line on well at departure. 5/28/2012 T /I /O = 0/812/0 Temp - SI , Assist E -line with perforating. Pumped a 3 bbl neat meth spear followed by 202 bbls of 1% KCL /Safe Lube as directed to pump tool string to target depth. Pumped 10 bbls neat meth to freeze protect surface line. FWHP= 0/838/0. E -line on well at departure. 5/27/2012 T /I /0= 2330/803/0 Temp =SI Assist E -line L &K (Perforating) Spear in to TBG w/ 5 bbls of neat followed by 141 bbls of 1% KCL w/ safe lube to kill Tbg. Pumped 150 bbls of 1% KCL w/ safe lube at E -Line direction to help them down hole. Pumped 10 bbls neat to FP kill line and Tree. SE -Line in control of well per LRS departure. FWHP's= vac /874/5 5/27/2012 * ** WELL SI ON ARRIVAL * * ** ( ELINE PERF) INITIAL T /I /O = 2,300/720/0 TOOLSTRING: HEAD /ERS/ROLLERS /1 WEIGHT BAR/ UPCT/ 2" HSD POWERJET OMEGA GUN /ROLLERS. MAX OD. 2.25. FISHING NECK 1.38 ". WEIGHT: 200LBS. LENGTH 32'. LOG CORRELATED TO: 5" MD SECTION OF THE SPERRY SROP -SGRD MD LOG DATED 27- APR -05. RUN JEWELRY LOG FROM 10000' TO 8100'. RIH TO 10000' FOR SHOOTING PASS. STOP AT SHOOTING DEPTH 9840.75'. CCL TO ME = 3.25'. CONFIRMED BY WSL. PERF INTERVAL 9844'- 9854'. ** *JOB IN PROGRESS AND CONTINUED ON 28 -MAY- 2012*** 12/22/2011 T /I /O = 1380/970/220. Temp =Hot. TBG,IA,OA FLs (E -line call -in). No AL. T BG FL @ surface, IAFL @ 5150' (140 bbls), OA FL @ surface. SV= Closed. WV,SSV,MV =Open. IA,OA =OTG. NOVP. (1130 hrs). 12/15/2011 ** *WELL FLOWING ON ARRIVAL ** *(pre adperf) DRIFT TO DEVIATION @ 9,407' SLM W/ 2.00" x 10' DUMMY GUN (No issues). ***WELL FLOWING ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** • • • FLUIDS PUMPED BBLS 44 DIESEL 41 METH 555 1% KCL 640 TOTAL • 18 -31 A PERF ATTACHMENT _ 205 -058 Sw Name Operation Date 'Pell Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 18 -31A 4/29/05 PER 10,140. 10,230. 8,722.52 8 18 -31 A 4/29/05 8,724.03 PER 11,530.'1 11,590. 8,718.38 8,717.34 18-31A 4/29/05 PER 11 270. 11,320. 8,724.61 8,722.88 18 -31A 4 /29 /05IPER 1 11,040. 11,230. 8,725.12 8,724.5 18 -31A 4/29/05 PER 11,440. 11,490. 8,718.6 8,718.35 18 -31A 4/29/05 PER 10,320. 10,580. 8,725.48 8,723.72 18-31A 4/29/05 PER 10,270. 10,290. 8,724.56 8,724.88 18 -31A 4/29/05 PER 10 , 600. 1 10, 780.1 8,723.49 8,724.11 18 -31A 4/19/09 BPS 8,512. 1 8,514. 8,058.95! 8,060.6 18 -31 A 7/25/09 BPP 7/25/09 _ - 8,512. 8,514 8,058.95, 8,060.6 • - - - - 18 -31A 5/28/12 APF -- - - - - - � - - 9,824 : 9,854. 8,721.37', 8,722.23 18 -31A 5/28/11 9,664. 9,684. 8,719.76 8,719.55 18 -31A 5/28/12 APF 9,724. 9,754. 8,719.78 8,719.97 18 -31A 5/29/12 APF 9,654. 9,684. 8,719.82 8,719.55 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 1 FILL SQF ' SQUEEZEFAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED 4 STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ' • TREE= FMC `)WB.LHEAD= CM/ • 18 -31 A Si•Y NOTES: WELL ANGLE >70° © 9322' "" 4-1/2" ACTUATOR = BAKER C & 3-1/2" CHROMETBG"' KB. ELEV = - 54.0' I BF. ELEV = 1 2005' H4-1/2' HES X NIP, ID = 3.813" I KOP= ---- _ GAS LIFT MANDRELS Max Angle = __ _ 95° et 11689' ST MD 1VD DEV TYPE VLV LATCH PORT DATE Datum MD = NIA 1 3497 3480 1 KBMG DOME BK 16 0720109 Datum 1VD = 8800' SS IIM 2 6056 6005 24 KBG -2 -9 SO INT 20 07/20/09 110 -3/4" CSG, 45.5#, NT-80, ID = 9.953" H 3680' 1 3 8249 7843 35 KBG-2-9 OMY BK 0 07/01/09 3692' H4-1/7 X 3-1/2" XO, ID = 2.992' I 41/2" TBG, 12.61, 13 -CR, VAM TOP N 3692' 0152 bpf, ID = 3.958" � 3883' 17-518" X 5-1/2' BKR ZXP LW ♦ 1 w /BKR FLEXLOCKLNR HGR, ID = 4.90" 1 4 1 •4 . • •4 t I 8307' H3-1/2" HES X NIP, O = 2.813" Minimum ID = 2.377" @ 9495' ! / • ';!i TOP OF 2 -7/8" LINER • , . . 8330' H5 -1/2" X 3-1/2" BKR S•3 PKR, ID = 2.79" I •••44 1 4 8353' H3-12" F ES X NIP, ID = 2.75" 1 11 ) ' �'.+ I 8405' J -1 /2" HES XN NIP, ID = 2.635" I 5-1/2' LNR 171, L -80 BTC-M 8426' •�1 • 0•1 0232 bpf, ID = 4.892 ,∎1 •!4 8427' H5 -12" X 412" X0, ID= 3.958" 1 3-1/2" TBG, 9.2#, 13-CR VAM TOP, -1 8447' 11 1 8447' H3-12" MULESHOE, ID = 2.992' I .0087 bpf, ID = 2.992' ir r il I 8451' H ELMD TT LOGGED (05127/12) I 4 -1/2' LNR, 12.6 #, 13- CRTCII, -L_ 8469' PA 1 84$2' I- 7.518" X 412 UNIQUE OVERSHOT ME .0152 bpf, ID= 3.958" ►�� ►�1 8517' H7 -5/8" X 412" 11W HBBP-T PKR, ID = 3.92' 1 I4 - 112" TBG STUB (07/09/09) H 8470' NI 8525' I- 1 3.70" BKR DEPLOY SLV, ID = 3.00" 1 3-1/2" LNR, 8.811, L -80 STL, - I 8572' , 8550' I 412" HES XN NIP, 04/21/06 MILL 0087 bpf, ID = 2.992" ID = 3.80" (BEHIND PIPE) 4-1/2" TBG, 12.61, L -80, .0152 bpf, ID = 3.958" 8572' , 8562' J- 13-1/2' HES X NIP, D = 2.813" I /TOP OF 5-1/2' LNR H 8581' i , 8572' - -141/2' WLEG, ID = 3.958" (BEHIND PIPE) I !Pei 44 ■ L 8574' H ELMD TT LOGGED 05/21/96 (B84ND PIPE) I 1 7-5/8" CSG, 29.7 #, S-95, ID = 6.875" H 8735' • • �1�1 I TOP OF WHIPSTOCK (TAGGED 4/22/05 DIMS) H 8847' . •.4 1'$4 ( 8572' EST. I-1 12" X 3 3115' XO, D = 2.80" . •4 ( 0 0 1 8800 TOP OF CEMENT (0421 /05 DAIS) I 'TWO RA TAGS (TAGGED 0422/05 DIMS) I 8857' •• • ( •/* 4 * 5 -1/2 LNR 17 6, L - 80, .0232 bpf, ID = 4.887' 10556' ) 4 # 1 1 ? I- FISH - IBP ELENENTS & STIFFENER •�•� •� RING (07/25/09) / PERFORATION SUMMARY 4 � . , REF LOG: SPERRY GR/ROP ON 04/28/05 G`� J 4v I ANGLE AT TOP PERF: 89° © 101 � c � MLLOUT WINDOW 8847' - 8855' Note: Refer to Roduction DB for histo ' perf data • •Y •••• SIZE SPF INTERVAL n/Sgz DATE ;4.1.1.4.1.1.4 2" 6 ('9654 - 9684 0 05/29/12 MID 2' 6 c 9724 - 9754 0 0529/12 ..fa 9495' I 33/16' X 2-7/8", 2' 6 24 - 0 0529/12 s ` X0, ID = 2.377" 2' 6 1 0 0429/05 3-3/16" LNR, 6.21, L -80 TCII, H 9495' I ` 2' ■ 6 10270 - 10290 0 04/29/05 .0076 bpf, ID= 2.80" ■ 2' 6 10320 - 10580 0 04/29/05 ■ 2' 6 10600 - 10780 0 04/29/05 2' 6 11040 - 11230 0 04/29/05 PBTD 11764' 9/05 .0,„„, �� 2' 6 11270 - 11320 0 04/29/05 2' 6 11440 - 11490 0 04/29/05 2' 6 11530 - 11590 0 0429105 2 -7/8" LNR 6.161, L -80 STL, -1 11804' .0058 bpf, ID = 2.441" DATE REV BY CON LENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/27/95 ORIGINAL COMPLETION 08/10/09 AW /JMD DRLG DRAFT CORRECTIONS WELL: 18-31A 04/29/05 NORDIC1 CTD SIDETRACK (18 -31A) 05/31/12 TTR/JMD ELMD, ADFERFS (0527 - 29/12) PERMIT No: ! 2 050580 07/17/09 D14 RIVO API No: 50 -029- 22579 -01 07/30/09 JCMIPJC GLV C/0 (07/20/09) SEC 24, T11 N, R14E, 1561' FNL & 64' FEL 07/30/09 DTR/PJC RILL IBP @ 8562' & FISH (0725/09) 07/30/09 PJC DRLG I-K) CORRECTIONS I BP Exploration (Alaska) STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPO T OF SUNDRY WELL OPE IONS ,~, ~ -~~~ ~ ~~~~~~~~~ ~U~ ~ 6 2009 1. Operations Performed: ,~~ 5, r~f;~ ~~~~~~ ~ ~1t ~ `"~; ~ ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate P~' ~ spen~e ell (~~e-En t~ll~~9;C~~~ ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 205-058 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22579-01-00 7. KB Elevation (ft): 54, 9. Well Name and Number: PBU 18-31A 8. Property Designation: 10. Field / Pool(s): ADL 028307 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 11804' feet true vertical 8710' feet Plugs (measured) None Effective depth: measured 11764' feet Junk (measured) None true vertical 8710' feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 SurFace 3645' 10-3/4" 3680' 3662' 5210 2480 Intermediate 8701' 7-5/8" 8735' 8243' 8180 5120 Production Liner 266' 5-1/2" 8581' - 8847' 8116' - 8335' 7740 6280 Liner 3279' s-~i2~~ x 3-3/16° x zaie° 8525' - 11804 8070' - 8710' Scab Liner 4599' 5-1/2" x 4-1/2" 3883' - 8482' 3865' - 8034' PerForation Depth MD (ft): 10140' - 11590' ~ ~'r,~+a~ w~x;..~. } I~ i t'" ``'~ '' ` ` c;.. p1 r~rl~.~ PerForation Depth ND (ft): 8723' - 8717' 4-1/2", 12.6# x 3-1/2", 9.2# 13Cr80 8447' & Tubing Size (size, grade, and measured depth): & 4-1/2", 12.6# L-80 8466' - 8574' Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" Baker'S-3' packer; 8330' 7-5/8" x 4-1/2" TIW 'HBBP-T packer 8517' 12. Stimulation or ce( ent sque jze summary: Intervals treated measured S~ ~~ ~ ~ ~ ' ~ : Treatment description including volumes used and final p ressure: Cut and pull tubing to ~8466'. Run 5-1/2" x 4-1/2" (17#, L-80 x 12.6#, 13Cr) scab liner and cement w/ 99 Bbls Class'G' (1.16 Yield). Run new Chrome com letion. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 992 24,216 15 900 1,310 14. Attachments: ~ Copies of Logs and Surveys run 15. WeN Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Aras WoRhington, 564-4102 309-103 Printed Name Te rie Hubble Title Drilling Technologist Prepared By Name/Number: ~ Signature Phone 564-4628 Date errie Hubble 564-4628 ~ Form 10-404 Revised 04/2006 `~ ~' Submit Original Only ~$~~~ ~L ~UG 1 '( 2~0~ {~z'(~~ = ~-"'"~~y'%`1~I` ~ ! 18-31A, Well History (Pre Rig Workover) Date Summary , 4/12/2009 WELL S/I ON ARRIVAL. RAN FLAPPER CHECKER TO 2191' SLM, 2210' MD (good test). 4/13/2009 PULLED P-PRONG FROM 8539' SLM PULLED PX PLUG BODY FROM 8548' SLM (8562' MDI. ATTEMPTED TO LOCK OUT 4 1/2" SERIES 10 TRSV, RAN FLAPPER CHECKER (flapper open). ATfEMPT TO PASS TRSV WITH 3.77" WRP DRIFT (unable). MADE MULTIPLE ATTEMPTS TO PASS THOUGH TRSV. TAGGED DEPLOY SLV WITH 3.67" CENTRALIZER. PAFiT WIRE C~ FLAPPER, RECOVERED ALL WIFiE. 4/13/2009 T/I/0=200/50/0 Temp=S/I Assist slickline w/ locking out & pulling SSSV. Speared into TBG w/ 5 bbls neat meth followed by 10 bbls crude to assist slickline. S/L on well upon departure. DSO notified. FWHP's=300/80/0 IA & OA open to gauges. 4/14/2009 T/I/0=600/50/0 Assist Slickline Pumped 26 bbls crude down Tbg. Slickline in control of well head on departure. 4/14/2009 ATTEMPTED TO LOCK OUT 4-1/2" SERIES 10 TRSV W/ LOCK OUT TOOL C 2186' SLM. RAN NO- GO CENT & BRUSH TO TRSV @ 2186' SLM. RECOVERED W HAT APPEARS TO BE THE TRSV LATCH RING, WHICH HOLDS TRSV LOCKED OPEN. SET HOLD OPEN SLEEVE THROUGH TRSV C~3 2188' SLM. FISHED TOOL STRING @ 8485' SLM & PULLED HOLD OPEN SLEEVE TOOL BACK OUT WITH FISH. WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 4/19/2009 WELL SHUT IN ON ARRIVAL. RAN 3.83" NOGO CENTRALIZER TO 2188' SLM. SET HOLD OPEN SLV ON X-LOCK C~3 2184' SLM. (190" OAL, 2.62" I.D.) RAN 4-1/2" CHECK SET, CAME BACK SHEARED. DRIFTED THROUGH HOLD OPEN SLV W/ 2.50" CENTRALIZER TO 2320' SLM, NO PROBLEMS WELL LEFT S/I, JOB COMPLETE. 4/20/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 300/80/0. SET BAKER 2 1/8" INFLATABLE BRIDGE PLUG AT 8512' (MID-ELEMENT) IN THE MIDDLE OF THE FIRST 10' PUP ABOVE THE PRODUCTION PACKER. WELL SHUT IN ON DEPARTURE. FINAL T/I/O = 200/100/0. JOB COMPLETE. 4/21/2009 T/I/0=250/80/0 MIT-T PASSED to 3500 psi Pumped down Tbg with 3 bbls meth and 3 bbls crude to reach test pressure for MITT. Tbg lost 200 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins for a total pressure loss of 240 psi in 30 min test. Bled Tbg. FWHP's=250/80/0. Swab shut, Wing shut, SSV shut, Master open and annulus valves open to gauges. Operator notified of well status. 4/22/2009 WELL SHUT IN ON ARRIVAL. CURRENTLY RUNNING IN HOLE W/ 2.5" DUMP BAILER OF SLUGGITS. 4/23/2009 DUMPED (2) 50# BAGS OF SLUGGITS ON TOP OF IBP Q 8488' SLM / 8512' ELM W/ 2.5" DUMP BAILER. PULLED HOLD OPEN SLEEVE C~3 2185' SLM. ESTIMATED TOP OF SLUGGITS C~ - 8500' MD. WELL LEFT S/I, JOB COMPLETE. 4/25/2009 T/I/0=0/0/0; Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0 psi). Functioned LDS, all moved freely (.75"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0 psi). Functioned LDS, all moved freely (.75"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 5/18/2009 T/I/0=650/100/0 Temp=Sl MIT-OA PASSED to 2000 psi. Pumped 5.5 bbls of crude down OA to achieve test pressure. OA lost 20 psi in 1 st 15 mins and 10 psi in 2nd 15 mins for a total loss of 30 psi in 30 mins. Bled OAP. Bled back (-2 bbls) Final WHP's=660/100/50 Tags hung. SV & WV = S/I SSV, MV, IA & OA = Open. Page 1 of 2 ~ • 18-31A, Well History (Pre Rig Workover) Date Summary 5/24/2009 WELL S/I ON ARRIVAL. SSV = C, WV = C, SV = C, MV = C. INITIAL T/I/O = 300/0/0, 600 PSI ON SSSV, WILL NOT HOLD ANY MORE. RIG UP ELINE. RIH WITH 3.65" SLB POWERCUTTER TO CUT 4.5" TUBING AT 8466' IN THE FIRST FULL JOINT ABOVE THE PRODUCTION PACKER. TUBING PRESSURE ROSE 600 PSI AFTER CUT WAS PERFORMED, IA PRESSURE HELD AT 100 PSI. SSSV DEPLOYMENT SLEEVE USED TO LOCK OPEN SSSV WHILE RIH AND POOH. ALL TOOLS CAME BACK IN GOOD CONDITION. WELL LEFT SHUT IN ON DEPARTURE. FINAL T/I/0=920/100/0 JOB COMPLETE. 5/27/2009 WELL S/I ON ARRIVAL. TAGGED TOP OF 4-1/2" OTIS SERIES 10 TRSV AT 2185'SLM W/ 3.84" CENT. 5/28/2009 SET HOLD OPEN SLEEVE IN 4-1/2" SERIES 10 TRSV C~ 2185' SLM. WELL LEFT S/I ON DEPARTURE. 6/29/2009 T/I/O = 1000/100/120 Temp = SI Circ-out. Pumped 5 bbls of neat methanol, followed by 129 bbls of 9.8 brine down TBG. SI IA valve to determine if PC leak is taking to much fluid to do circ-out. Pumped 16 bbls down TBG with IA closed at 2.0 bpm. at 1480 psi. through cut in tbg and into PC leak. PC leak taking to much fluid. Open IA and pump 169 bbls of 9.8 brine down TBG for a total of 290 bbis. Rig up to IA and bullhead 5 bbls of neat methanol, followed by 294 bbls of 9.8 brine. W ith 20 bbls pumped established LLR of 2.0 bpm C«~ 1480. With 46 bbls pumped established LLR of 1.0 bpm C~3 1000 psi. Freeze protect TBG and IA on well 31 with 8 bbis and 13 bbls of diesel. Total of 21 bbls. Freeze protect FL on well 30 with 1 bbi neat methanol and 2 bbls of diesel. DSO notified of tree valve positions as follows: SV, WV, SSV = closed. Master open. IA and OA open to gauges on well 31. SV, WV, SSV = closed. Master open. IA and OA open to gauges on well 30. Final WHP = 0/0/0. Page 2 of 2 ~ • '~~~ BP EXPLQRATIC~N ~'~~ Page 1 nf ~ 1~~~ :Operations Summary R~port Legal Well Name: 18-31 Common Well Name: 18-31 S~ud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - Tca Hours Task G~de NPT Phase Description of Operations 7/4/2009 06:00 - 00:00 18.00 MOB X WAIT PRE Released rig from DS 4-22a ~ 0600 hrs on 7-4-09 Clean and maintenance rig while waiting for 7-ES to move off DS 18 7/5/2009 00:00 - 02:30 2.50 MOB P PRE Prepare rig for move from DS 4-22a to DS 18-31 a -Move rock washer and enviro-vac -Skid rig floor -Jack rig and remove shims 02:30 - 03:00 0.50 MOB P PRE Move rig off of well -Pad operator, WSL, and Toolpusher present -Move to pad entrance and set on mats 03:00 - 06:00 3.00 MOB P PRE Remove cellar doors -Remove BOP's from pedestal in cellar -lnstall booster wheels and hook up hydraulic lines 06:00 - 15:30 9.50 MOB P PRE Move riq from DS 4-22a to DS 18-31a 15:30 - 20:00 4.50 MOB P PRE Remove rear Boosters. PU Stack. -Drive up on Mats. PU Mouse hole & hang Cellar doors. -Tool service finish pad prep. -Remove adjacent well house. 20:00 - 22:00 2.00 MOB P PRE Lay herculite and set mats around cellar. 22:00 - 23:30 1.50 MOB P PRE Move over well and shim rig level. -WSL, Toolpusher, and Pad operator present. 23:30 - 00:00 0.50 RIGU P PRE PJSM on skidding rig floor -Skid rig floor into drilling position 7/6/2009 00:00 - 00:30 0.50 RIGU P PRE Continue skidding rig floor into drilling position. 00:30 - 02:30 2.00 RIGU P PRE R/U floor - Connect hydraulics -Spot rock washer -Berm rig and rock washer 02:30 - 03:30 1.00 WHSUR P DECOMP P/U DSM lubricator -Test with diesel to 500 si for -Pull BPV Tub. on vac. T/IA/OA = 0/0/0 -Take on 9.8 ppg brine in pits ~ 0300 hrs ' '*Ri Acce ted ~ 0300 hrs*" , 03:30 - 05:00 1.50 WHSUR P DECOMP R/U lines to circulate out freeze protect ' -Install secondary annulus valve -Test lines with air then to 3000 psi with brine 05:00 - 06:30 1.50 WHSUR P DECOMP Displace out freeze protect -Pump 30 bbls down IA out tubing to slop tank - 3 bpm, 400 psi -Pump 50 bbls down tubing and out IA to slop tank - 3 bpm, 300 psi -Allow diesel to migrate - Pump 20 bbls , 06:30 - 08:00 1.50 WHSUR P DECOMP Divert returns to pits ' -CBU w/ 5 bpm, 800 psi -Blow down all lines 08:00 - 10:00 2.00 WHSUR P DECOMP FMC Re . d rod in TWC -Test TWC from below while rolling pumps w/ 2 bpm, 1000 psi f/ 10 min on chart -Test TWC f/ above to 3500 psi f/ 10 min on chart -RD test equip. 10:00 - 12:00 2.00 WHSUR P DECOMP PJSM on ND / NU with single barrier dispensation -ND tree, Adapter flange 12:00 - 16:00 4.00 WHSUR P DECOMP NU BOPE: Printed: 7/29/2009 3:04:53 PM ~ • BP EXPLQR~4TION Page 2 af 11 Operations Sumrnary R~port Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Descriptian of Operations 7/6/2009 12:00 - 16:00 4.00 WHSUR P DECOMP Configuration: Annular, 3 1/2' x 6" VBR, Blinds, Mud cross, 18" spacer spool and 2 7/8" x 5" VBR -Install choke line, riser, flow line & fill up line 16:00 - 16:30 0.50 WHSUR P DECOMP RU test equipment 16:30 - 22:00 5.50 WHSUR P DECOMP Test BOP's, Choke & associated valves: 29 components. ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Test Hydril to 250 low psi, 3500 high psi. -Test Hydril with 4 1/2" & 2 7/8" test Jts. -Test all valves w/ 4 1/2" test Jt. -Test lower Rams w/ 4 1/2" & 2 7/8" test Jts. -Test 250 low psi & 3,500 psi High psi. -Hold each test for 5 charted minutes. (All tests Passed.) Note: 30 seconds for 200 psi build up 2 min 21 seconds for full PSI 4 bottles X 2200 psi. -Test witnessed by T.P. & WSL. -Test witness waived by John Crisp with AOGCC. 22:00 - 22:30 0.50 WHSUR P DECOMP R/D test equip. -Center stack -Blow down all lines 22:30 - 00:00 1.50 WHSUR P DECOMP Install Dutch svstem and P/U lubricator -Test to 500 psi for 5 charted min. -Pull TWC No ressure -R/D lubricator 7/7/2009 00:00 - 00:30 0.50 WHSUR P DECOMP R/D Dutch system -Blow down choke & kill lines 00:30 - 01:30 1.00 PULL P DECOMP R/U and pull hanger off seat ~ 140K -Tubing pulled loose C~ 160K -P/U Wt. 145K 01:30 - 03:30 2.00 PULL P DECOMP CBU with 310 GPM ~ 420 PSI -R/U to L/D 4.5" 12.6# L-80 tbg 03:30 - 05:00 1.50 PULL P DECOMP UD hanger and start pulling tubing -Control line not pulling at same rate as tubing -Air spooler did not have enough power -Rig up hydraulic spooler 05:00 - 07:00 2.00 PULL P DECOMP Continue pulling and laying down tubing -4.5" 12.6# L-80 BTC-M tubinq from cut C~ 8466' to SSSV -Recovered only 7 SS bands (HES records indicate 28 ran). 07:00 - 08:00 1.00 PULL P DECOMP RD control line spool & sheaves -Schlumberger Slickline employees pull "Hold Open Sleeve" Printed: 7/29/2009 3:04:53 PM ~ • . , , . Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date FrQm - To Hours Task Gode NPT Phase Description of Operations 7/7/2009 07:00 - 08:00 1.00 PULL P DECOMP from SSSV. 08:00 - 13:00 5.00 PULL P DECOMP Continue LD 4 1/2 12.6# tubing -Recovered 197 jts + cut jt (10.65')\ -3 GLM, 1 SSSV -Cut flare = 4 7/8" OD 13:00 - 14:00 1.00 PULL P DECOMP RD tubing equipment -Clean, LD same 14:00 - 14:30 0.50 FISH P DECOMP Install wear ring 14:30 - 16:00 1.50 FISH P DECOMP Clear / Clean rig floor -Mob RCJB BHA to rig floor 16:00 - 17:00 1.00 FISH P DECOMP MU Dress off shoe / RCJB BHA. OAL = 236.9'. 17:00 - 23:00 6.00 FISH P DECOMP Single in hole with 4", 14# DP from 236' to 8290'. -Rack back 2 stands -Single in 6 DP -PU 1 stand and screw in top drive and estabiish parameters -PUW = 175K, SOW = 145K, Rot Wt = 160K, RPM = 50, Free Torque = 3-4K -Circulating parameters = 4 BPM / 520, 8 BPM / 1890 psi 23:00 - 00:00 1.00 FISH P DECOMP Drop ball and pump down at 4 BPM, pressure increased from 520 psi to 670 psi. -Increase rate to 8 BPM 2230 psi, wash and rotate down to 8450' at 20 RPM / 3K torque. 7/8/2009 00:00 - 01:00 1.00 FISH P DECOMP Wash down to top of 4.5" stump at 8469'. Ream over stump with 20 RPM / 3-4K rotatin tor ue to 8471'. -Circulate at 8.5 BPM / 2850 psi over stump -CBU at 8.5 BPM / 2850 psi 01:00 - 01:30 0.50 FISH P DECOMP Lubricate rig and inspect top drive. 01:30 - 03:00 1.50 FISH P DECOMP POH from 8471' to 5520' standing back in Derrick. 03:00 - 04:00 1.00 FISH P DECOMP Slip and cut 59.5' of drilling line 04:00 - 06:00 2.00 FISH P DECOMP Continue POH with Dress off / RCJB BHA from 5520'. 06:00 - 07:00 1.00 FISH P DECOMP Stand back DC's -LD BHA -Clean RCJB -Recovered 5 S.S. bands 07:00 - 08:30 1.50 FISH P DECOMP Mobilize BHA to rig floor -MU Dressoff BHA -RIH w/ 4 3/4" DC's 08:30 - 11:00 2.50 FISH P DECOMP RIH w/ DP to 8400' (Work scraper through est. ZXP packer area at 3900' x4). 11:00 - 12:30 1.50 FISH P DECOMP Screw in TD - Obtain parameters ', -PUW 175k, SOW 148, ROW 160K, 50 rpm w/ 2-3k tq ~ -Break circ w/ 6 bpm, 950 psi -Tag top of 4 1/2' tbg stub at 8469' -Wash over top and tag stub w/ internal mill (swallow 15') -Dress off 6" -Ream & backream over 4 1/2" stub -Work over w/ no rotary - Top clean ~ 12:30 - 14:00 1.50 FISH P DECOMP Pump H.V. sweep S.S. w/ 12 bpm 3150 psi while over stub -Sweep at surface - Clean -RU to rev. circ. -Rev. circ BU w/ 6.5 bpm, 540 psi -Losses while rev circ. = 15 bbls - -RD / blow down Printed: 7/29/2009 3:04:53 PM • • BP EXPL~RAT[UN Page 4 of 11 ' Qperation~ Summary Repar# Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/8/2009 14:00 - 16:00 2.00 FISH P DECOMP POH f/ 8370' to 2317' 16:00 - 19:00 3.00 FISH N RREP DECOMP Replace high drum chain on draw works 19:00 - 20:00 1.00 FISH P DECOMP Continue POH w/ 4" DP - -Stand back DC's 20:00 - 21:00 1.00 FISH P DECOMP LD BHA -Inspect Inner mill, good sign of dress off -Junk baskets recovered metal shavings -LD BHA equipment 21:00 - 21:30 0.50 EVAL P DECOMP MU RTTS with Halliburton rep on 6 ea 4-3/4" drill collars. 21:30 - 23:00 1.50 EVAL P DECOMP RIH to 4076' out of Derrick. 23:00 - 00:00 1.00 EVAL P DECOMP Set_RTTS. RU to test casing, shut_3-1/2" x 6" VBR on drill 7/9/2009 00:00 - 00:30 0.50 EVAL P 00:30 - 01:00 0.50 EVAL P 01:00 - 02:30 1.50 EVAL P 02:30 - 03:00 0.50 EVAL P 03:00 - 06:00 3.00 CASE P 06:00 - 08:00 I 2.00 I CASE ~ P 08:00 - 16:30 I 8.501 CASE I P 16:30 - 17:00 I 0.501 CASE I P 17:00 - 19:30 2.50 CASE P 19:30 - 20:00 0.50 CASE P 20:00 - 21:00 I 1.001 CASE I P 21:00 - 21:30 0.50 CASE C 21:30 - 00:00 2.50 CASE C - i cai ~.aan ~ w o avv ai wi ov i i m i ~i ~ai wu aa DECOMP Flnish testing 7-5/8" casing. Blow down equipment. DECOMP Lubricate rig. Inspect top drive. DECOMP Release RTTS as per Halliburton. POH standing back in Derrick. DECOMP LD collars and RTTS with Halliburton rep. DECOMP Mobilze sand, centralizers to rig floor -Count pipe -RU to run 5.5", 17" scab liner. -PJSM w/ all involved DECOMP PU 7 5/8" x 4 1/2" U.M.O.S. w/ pup, 4 1/2" pup w/ ball seat sub (drop 1 3/4" ball), 5 1/2" x 4 1/2" XO, 5 1/2" BTC pup jt. -Dump 300 # sand down pipe -PU 5 1/2" ported pup jt, HES F.C., 5 1/2" XO joint and 5 1/2" 17# BTC-M w/ L.C. insert. -Baker lock all connections below F.C. -Fill pipe - Check floats - OK DECOMP Run 107'ts. of 5 1/2" 17# L-80 BTC-M casin to 4572' -PU Baker 7 5/8" Flex lock liner hanger & ZXP packer assembly -PU 1 stand 4" DP DECOMP Obtain parameters - PUW 125k - SOW 115k -Circulate Liner vol. (105 bbls) -7 bpm, 530 psi DECOMP RtH w/ 4" DP from 4572' to 8400'. Mousehole top single of last stand. DECOMP MU Baker cement head to single -Screw in TD -Obtain parameters - PUW 180k - SOW 145k DECOMP Slack off and taa to~ of 4 1/2" stub at 8470' -Attempt to work over stub - setting down 10k -Turn 1/2 turn RH no-go - Attempt another 1/2 turn - Set down 15k -PU and work torque down hole - No success -Work 1 turn LH down hole - Set down 15k -Work 1 turn left at 1/8 turn increments - Set down 20k -No success DECOMP Mousehole single -LD Baker cement head DECOMP POH standing back 4" drilloine in Derrick. Printed: 7/29/2009 3:04:53 PM ! ~ BP EXPLORATION Page 5 c~f 11 Operations Summary Report Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Descriptior~ caf ~perations 7/10/2009 00:00 - 00:30 0.50 CASE C DECOMP Continue POH with 4" drillpipe. 00:30 - 01:30 1.00 CASE C DECOMP MU top drive and circulate Liner volume to clear air from pipe. (105 bbls) -6 bpm, 360 psi -RU to ull 5.5" casin 01:30 - 02:00 0.50 CASE C DECOMP LD Baker Flex Lock hanger and ZXP liner packer as per Baker rep. Changeout elevators. 02:00 - 02:30 0.50 CASE C DECOMP Inspect top drive. Lubricate rig. 02:30 - 09:00 6.50 CASE C DECOMP LD 107 jts 5.5", 17#, BTC-M casing. Pull seal rings and replace with new. -Break out shoe track -Stand back same in derrick 09:00 - 09:30 0.50 CASE C DECOMP RD liner equipment -Change elevators 09:30 - 10:00 0.50 CASE C DECOMP M b dressoff BHA to floor 10:00 - 11:00 1.00 CASE C DECOMP MU BHA -PU 3 DC's 11:00 - 14:00 3.00 CASE C DECOMP RIH w/ 4" DP to 8412' 14:00 - 15:30 1.50 CASE C DECOMP Screw in TD -Obtain Parameters - PUW 178k - SOW 144k -Dry tag at 8468' (2' high) -PU & break circ. w/ 5 bpm, 650 psi -Wash down & over stub w/ no issues - No weight -Continue to wash down to 8484' shoe depth -Observe 50-70 psi increase as nose entered 4 1/2' ID -River sand at BU 15:30 - 17:00 1.50 CASE C DECOMP Pump H.V. / nut plug sweep at 13 BPM / 3280 psi -Continue to ream & backream over stub -Work over stub w/ no pump, no rotary x4 -Sting over stub - Pump H.V, sweep S.S. -Recover sand back to pits 17:00 - 20:00 3.00 CASE C DECOMP POH with BHA standing back 4" drillpipe in Derrick. 20:00 - 21:30 1.50 CASE C DECOMP LD drill collars and BHA #3. Boot baskets empty. 21:30 - 22:00 0.50 CASE C DECOMP RU to run 5.5" scab liner. 22:00 - 23:30 1.50 CASE C DECOMP MU shoe track with XO joint and joint with landing collar (bakerlok connection). -Remove 1 shear screw from upper set of screws in Unique Overshot. -Check float and ball seat. OK 23:30 - 00:00 0.50 CASE C DECOMP RIH with 5.5", 17#, L-80 casing~ -Install 1 ea straight vane centralizer on every casing joint. -Fill every casing every 10 joints. 7/11/2009 00:00 - 00:30 0.50 CASE C DECOMP Lubricate rig. Inspect top drive and crown. 00:30 - 06:00 5.50 CASE C DECOMP Continue to RIH with 5.5", 17#, L-80 casing. -Install 1 straight vane centralizer on every casing joint. -Fill every 10 joints. -Ran total of 107 jts 06:00 - 07:00 1.00 CASE C DECOMP PU Baker 7 5/8" x 5 1/2" "Flex lock" liner hanger and ZXP liner top packer -Obtain parameters - PUW 125k - SOW 115k -PU 1 std 4" DP -Circ. liner vol (105 bbls) w/ 7 bpm, 530 psi Printed: 7/29/2009 3:04:53 PM • • BP EXP~C)RATIUN Fage 6 af 11 ' Operations Surnmary Report Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Gt~de NPT Phase Deseription of Operations 7/11/2009 07:00 - 09:30 2.50 CASE C DECOMP RIH w/ liner on 4" DP to 8460' -Fill every 15 stds -Drop top single from Std # 41 -Obtain parameters - PUW 185k - SOW 145k 09:30 - 10:00 0.50 CASE P DECOMP RU cement head on single -Screw in TD 10:00 - 11:00 I 1.00 I CASE I P 11:00 - 12:00 ~ 1.00 ~ CASE ~ P 12:00 - 12:30 I 0.501 CASE I P 12:30 - 13:00 I 0.50I CASE I P 13:00 - 14:00 1.00 CASE P 14:00 - 14:30 0.50 CASE P 14:30 - 16:30 2.00 CASE P 16:30 - 17:30 1.00 CASE P 17:30 - 19:30 2.00 CASE P 19:30 - 21:00 1.50 CLEAN P 21:00 - 22:30 1.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 7/12/2009 00:00 - 04:30 4.50 CLEAN P 04:30 - 05:00 I 0.501 CLEAN I P -Slack off & observe seals go over stub at 8470' -Observe 1 st shear w/ 7-8k at 8474' shoe depth -Observe 2nd shear w/ 5-6k at 8482' shoe depth -Bottom out O.S. on stub at 8485' shoe de th -PU up wt. + 2' DECOMP Break circ. w/ 7 bpm 960 psi -PJSM w/ all involved DECOMP Give to Schlumberger: -Pump 5 bbls H20 -Test lines to 4500 psi -Mix & um 99 bbls Class "G" cement at 15.8 1.16 cft/ ; -Drop DP wiper & kick out w/ 5 bbls H20 DECOMP Displace w/ 9.8 ppg brine using rig pumps -No latch observed at liner top -Caught up w/ cement at 63 bbls away - 7 bpm 700 psi -FCP 2070 psi w/ 4 bpm -Bum lu w/ 1370 stks. -CIP at 12:30 hrs -New liner top at 3883' MD_ DECOMP Pressure to 3200 psi to set hanger -Set down 30k - Press. to 4000 psi to set ZXP pkr (observe at 3800 psi) -Bleed press. - Check floats - OK -Release from hanger w/ 15 RH turns -Press. to 1000 psi - PU and observe press. drop -Pump 18 bbis at 10 bpm -Slow pumps to 2 bpm, 120 psi -Rotate w/ 20 rpm and set down 45k to confirm ZXP set -PU 30' -Circ. cement out w/ 9 bpm, 1000 psi -24 bbls contaminated c t DECOMP RD Cement lines and Baker cement head DECOMP Break circ. and Pump H.V. nut plug sweep surface to surface. DECOMP POH LDDP from 3980' to 2100' DECOMP Cut and slip 59.5' of drilling line. DECOMP Continue POH LDDP from 2100'. LD liner hanger running tool and inspect same. Clear rig floor. DECOMP PJSM. PU and mob BHA #4 and 2-7/8" runninq tools to floor. DECOMP MU BHA #4 with Baker rep. OAL of mill assembly = 205.5'. DECOMP RIH with BHA #4 on 2-7/8" HT PAC pipe 1x1 from pipe shed. DECOMP Continue to RIH with 2-7/8" HT PAC pipe 1x1. -Did not see 5.5" liner top when enterinp with 4-3/4" mill -Ran a total of 4453' of 2-7/8" HT PAC. DECOMP MU XO back to 4" HT-38 drillpipe. -Circ 2 7/8" DP volume -3 bpm, 940 psi Printed: 7/29/2009 3:04:53 PM • • BP EXPLQRATION Pac~e 7 of ~ ~ ' Operations Summary Report Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: ~ . I ~-- ~- 1,, I -'._ , I„_ . I .,~,..I ~.., _ I' r..__ .---_~----.___ 7/12/2009 05:00 - 06:30 1.50 CLEAN P DECOMP RIH with 4", 14#, HT-38 drillpipe from Derrick to 8250' 06:30 - 12:00 5.50 CLEAN P DECOMP Screw in TD - Obtain parameters -PUW 160k - SOW 130k - ROW 142k w/ 3-5k tq -Break circ. w/ 2 bpm 1000 psi -Tag cement stringers at 8256' -Wash & rotate down. Taq LC at 8355' -Drilling LC and cement to 8383' w/ 2-3.5 bpm, 70 rpm, 2-6k WOB - 12:00 - 13:30 1.50 CLEAN P DECOMP Continue clean out cement. -Ta F.C. at 8395' - Drill same -Continue clean out cement -Taq 5 1/2" x 4 1/2" XO at 8425'. 13:30 - 15:00 1.50 CLEAN P DECOMP Pump H.V. sweep -5 bpm, 2850 psi -Fine cement cuttings, rubber and nut plug back w/ sweep -Blow down 15:00 - 16:30 1.50 CLEAN P DECOMP POH w/ 4" DP to 4660' 16:30 - 17:30 1.00 CLEAN P DECOMP PJSM on standing back 2 7/8" DP in derrick -Review Doyon 14 procedures -Change elevators -RU handling tools 17:30 - 20:00 2.50 CLEAN P DECOMP POH standing back 2-7/8" PAC pipe in Derrick. -Wrap casinghead with herculite and apply steam. 20:00 - 20:30 0.50 CLEAN P DECOMP Stand back 3-1/8" drill collars and LD BHA #4. 20:30 - 22:00 1.50 DHB P DECOMP RU to test casing. Test casina / liner lan to 3.500 osi for 30 min. -Took 3 bbis to test, bled back 3 bbls. -Good test, charted and witnessed by WSL. -RD test equipment and suck out stack. 22:00 - 22:30 0.50 WHSUR P DECOMP Pull wear ring. Clear rig floor. -Bring tools and new casing pack-off to floor. 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM. MU pack-off puller with FMC rep. BOLDS. -Pull ack-off with 30K. -Heat was applied for 3 hrs prior to pulling. -Old 7-5/8" pack-off body and seals in good condition. -Prep to install new 7-5/8" pack-off. 7/13/2009 00:00 - 01:00 1.00 WHSUR P DECOMP Set new 7-5/8" pack-off. RILDS with FMC rep. -Test pack-off to 5,000 psi for 30 min. -LD landing joint and packer puller. 01:00 - 02:00 1.00 BOPSU P DECOMP RU to test BOPE. 02:00 - 07:30 5.50 BOPSU P DECOMP PJSM. Test BOP's, Choke & associated valves. ---BOP Configuration: -Hydril GK 13-5/8" 5000. -3-1/2" x 6" Variables. -Blind Rams. -Mud cross. -2-7/8" x 5" Variables. ---Test: -Test all components to 250 psi low / 3,500 psi high. Hold each test for 5 charted minutes. -Test Manual valves (Kill and Choke), HCR (Kill and Choke), Upper & Lower IBOP. -TIW and Dart valves (2-7/8" and 4"). Printed: 7/29/2009 3:04:53 PM ~ ~ BP EXPLORATION Page s af 11 Operat~ons Summary R~port Legal Well Name: 18-31 Common Weli Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Deseription of Operations 7/13/2009 02:00 - 07:30 5.50 BOPSU P DECOMP -Test Hydril with 2-7/8" test joint. -Test 2-7/8" x 5" VBR with 4-1/2" and 2-7/8" test joints. -Test 3-1/2" x 6" VBR with 4-12" test joint. -Test all valves with 4-1 /2" test joint. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 and 14. Note: 32 seconds for 200 psi build up - 2 min 47 seconds for full PSI - 4 bottles average 2100 psi. -Test witnessed by T.P. & WSL. -AOGCC rep Jeff Jones waived the state's right to witness BOPE test. 07:30 - 09:00 1.50 BOPSU P DECOMP RD test equipment -Blow down -Install wear ring 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM -Review Doyon 14 procedure for handling 2 7/8" from derrick -MU 3 3/4" 5 bladed M.M. mill, bumper sub, oil jar and P.O.S. -RIH w/ DC's 10:00 - 12:00 2.00 CLEAN P DECOMP RIH w/ 2 7/8" DP 12:00 - 12:30 0.50 CLEAN P DECOMP Lubricate rig -Inspect TD 12:30 - 14:30 2.00 CLEAN P DECOMP Continue RtH w/ 2 7/8" DP to 4688' -Change elevators -RIH w/ 4" DP to 8382' 14:30 - 22:00 7.50 CLEAN P DECOMP Screw in TD -Obtain parameters - PUW 160K - SOW 127K - ROW 144K w/ 3k tq -Break circ. w/ 3 bpm, 1150 psi -Wash down & taa 5 1/2" X 4 1/2" XO at 8425' -Clean out cement and ta Ball seat sub at 8447' -Drilling ball seat sub (1 hr) -Drilling cement from 8448' to 8465' slow. -Pump hi-vis sweep at 1945 hrs - returned cement, rubber, quarter size rocks, and sandy fill. -Drill 8465' for 1 hour and unable to make more hole. Confer with da WSL. 22:00 - 00:00 2.00 CLEAN P DECOMP POH with BHA #5 standing back 4" drillpipe in derrick. 7/14/2009 00:00 - 03:30 3.50 CLEAN P DECOMP PJSM for standing back 2-7/8" PAC. -POH standing back in Derrick. 03:30 - 04:30 1.00 CLEAN P DECOMP LD 3-1/8" drill collars. -LD bumper sub and jars. -LD Mill assembly. -Mill cuttinq edqes rounded off and 2 jets plugged with cement„ Pics in folder. 04:30 - 05:30 1.00 CLEAN P DECOMP Confer with Day WSL and RWO engineer. 05:30 - 06:30 1.00 CLEAN P DECOMP MU new 5 bladed M.M. mill on same assembly. 06:30 - 09:30 3.00 CLEAN P DECOMP Trip in the hole with the new BHA assembly to 8380'. 09:30 - 12:00 2.50 CLEAN P DECOMP Taq the cement at 8465' and mill to 8478'. 12:00 - 12:30 I 0.501 CLEAN I P -Up Wt. 158k / Down Wt. 130k / Rot. Wt. 140k -84-127 GPM at 850-2000 psi. -80 RPM C~ 2-5k TQ. DECOMP Wash down to the top of the sluggits ~ 8499'. Printed: 7/29/2009 3:04:53 PM ~ • BP EXPLORATIQN Page 9 of 11 Ca-perations Summary Report Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: ' Date Frorn - To Hours Task Code NPT Phase ~escriptian of Operatit~ns 7/14/2009 12:00 - 12:30 0.50 CLEAN P DECOMP -Up Wt. 160k / Down Wt. 130k -1.5 BPM ~ 280 psi 12:30 - 14:00 1.50 CLEAN P DECOMP Pump Hi-Vis sweep surface to surface at 5 bpm and 3010 psi. 14:00 - 18:00 4.00 CLEAN P DECOMP Pull out of the hole with 4" drill pipe. Change out the handling equipment to handle 2-7/8° and begin pulling out of the hole with 2-7/8" drill pipe. 18:00 - 19:00 1.00 CLEAN P DECOMP Laydown the 3-1/8" drill collars and break off the mill. Clear and clean the floor and prepare for the ne~ clean out run. 19:00 - 21:00 2.00 CLEAN P DECOMP Make up new cleanout assembly. onsists o : - 3-3/4" RCJB - Crossover sub - Bumper sub - Crossover sub - Pump out sub - (6) 3 1/8" Drill Collars 21:00 - 22:30 1.50 CLEAN P DECOMP Run in the hole on 2-7/8" drill pipe to 4697'. 22:30 - 00:00 1.50 CLEAN P DECOMP PJSM. Cut and slip the drilling line. Service the top drive. 7/15/2009 00:00 - 01:30 1.50 CLEAN P DECOMP Continue in the hole from 4,697' to 8,495' and establish parameters. -Up Wt. 165K/ Down Wt. 130K/ Rot Wt. 140K 01:30 - 02:00 0.50 CLEAN P DECOMP Dron the ball for the RCJB and pump down at 50 aom with 420 si. Working the pump up to 125 gpm with 1,340 psi. 02:00 - 03:30 1.50 CLEAN P DECOMP Wash down from 8.497' to 8,502'. Took 5-7K Wt. Rot at 40 RPM with 2-4K TQ. Pumped at 155 gpm with 2,230 psi. , -Once 8,502' reached, the wt. began to stack out and could not be drilled off. Consulted with the Day WSL and Town Engineer, decision was made to proceed as planned and come out of the hole laying down the drill pipe. 03:30 - 05:00 1.50 CLEAN P DECOMP Pump a 30 bbl Hi-Vis sweep followed by 290 bbls seawater at 205 gpm with 3500 psi. -50 rpm ~ 3k TQ. 05:00 - 09:00 4.00 CLEAN P DECOMP POH La in down 4" DP. 09:00 - 09:30 0.50 CLEAN P DECOMP RU to Lay down 2 7/8" DP. 09:30 - 12:00 2.50 CLEAN P DECOMP POH La in down 2 7/8" DP to 1 570' md. 12:00 - 12:30 0.50 CLEAN P DECOMP Service Rig 12:30 - 13:30 1.00 CLEAN P DECOMP POH, Laying down 2 7/8" DP from 1,570' to 240' md. 13:30 - 15:00 1.50 CLEAN P DECOMP C/O Elevators. -LD 3 1/8" DC's, Pump out sub, Jars, Bumper sub, XO's, & RCJB. -RCJB Full. control line and SSB balled up between cages. 15:00 - 15:30 0.50 CLEAN P DECOMP RU Dutch Lubricator System. 15:30 - 18:30 3.00 CLEAN P DECOMP SWS spot trucks. PJSM w/ SLB Wireline. -PU Slickline Tools, Lubricator, Pump in Sub & BOP's. -MU tools. -Test Lubricator to 500 si. 5 min / Charted - Pass. 18:30 - 21:00 2.50 CLEAN P DECOMP RIH w/ 3 1/2" Pump Bailer to 8,505' md. -Tight ~ 8,423' md. -Sluggits and small pieces of inetal in the Bailer. Printed: 7/29/2009 3:04:53 PM ~ • BP EXPLORATION Pa~e 10 of 11 Operations Summary Report Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase ' aescriptian of Operations 7/15/2009 21:00 - 22:30 1.50 CLEAN P DECOMP PJSM, RD SWS. 22:30 - 23:00 0.50 RUNCO RUNCMP Pull Wear Ring. 23:00 - 00:00 1.00 RUNCO RUNCMP LD Short Bales. -MU Compensator XO. -Pick up tubing running tools to the rig floor. 7/16/2009 00:00 - 02:00 2.00 RUNCO P RUNCMP RU to run 3 1/2" 9.2# 13CR X 4.5" 12.6# 13CR Com letion. 02:00 - 02:30 0.50 RUNCO P RUNCMP Service Rig 02:30 - 03:30 1.00 RUNCO RUNCMP Begin to run in the hole with the completion string. Consists of: - 3.5" 9.2# 13Cr80 Vam Top mule shoe - 3.5" XN Nipple (2.635") - 3.5" X Nipple (2.75") w/ RHC-M plug - Baker SABL-3 Production Packer - X Nipple (2.813") - 3.5" x 1" KBG-2-9 w/ DMY integ. Itch - Make Up TQ on 3.5" 92# 13Cr80 Vam Top was 2900 ff/Ibs. - Make Up TQ on 4.5" 12.6# 13Cr80 Vam Top was 4400 ft/Ibs. - Jet Lube Seat Guard on all joipts above the packer - All connections before the packer are Bakerlok'd 03:30 - 04:30 1.00 RUNCO SFAL RUNCMP Dump valve having issues on the power tongs, wait on new part to show up. 04:30 - 11:30 7.00 RUNCO RUNCMP Continue in the hole 3.5" 9.2# 13Cr80 Vam Top tubing. Consists of: - 69 3.5" 9.2# 13Cr80 Vam Top Jts. - 3.5" x 1" KBG-2-9 w/ DMY integ. Itch - 75 3.5" 9.2# 13Cr80 Vam Top Jts. - XO - 4.5" Vam Top x 3.5" Vam Top 11:30 - 12:30 1.00 RUNCO RUNCMP Change out all of the 3.5" handling equipment to 4.5" handling equipment. Clear and clean the rig floor and prepare to continue in the hole with completion. 12:30 - 18:00 5.50 RUNCO RUNCMP Continue in the hole with 4.5" 12.6# 13Cr80 Vam To tubin . Consists of: -(4) 4.5" 12.6# 13Cr80 Vam Top Jts. - 4.5" x 1" KBMG w/DCK Shear Valve -(35) 4.5" 12.6# 13Cr80 Vam Top Jts. - X Nipple (3.813") -(45) 4.5" 12.6# 13Cr80 Vam Top Jts. - 4.5" 12.6# 13Cr80 Vam Top Space Out Pups (19.88' and 9.83') -(1) 4.5" 12.6# 13Cr80 Vam Top Jt. - FMC 13 5/8" x 4 1/2" Hanger w/ Pup (landing threads are TC-11) 18:00 - 19:00 1.00 RUNCO P RUNCMP Rig up and circulate down the tubing at 2 bpm with 180 psi while stinging into the 5.5" x 4.5" XO. Saw an increase of 20 psi while entering the XO. Shut down the pumps and landed at 8447'. 19:00 - 21:00 2.00 RUNCO RUNCMP Reverse circulate 100 bbis of 120 deg seawater, followed by 60 bbls of 120 deg seawater with corrosion inhibitor, then 95 bbls of 120 deg seawater at 2.5 bpm with 430 psi. 21:00 - 22:00 1.00 RUNCO P RUNCMP Drop the ball and rod (1 5/16" ball with a 1 3/8" fishin neck , rig up to set and test the acker. 22:00 - 00:00 2.00 RUNCO P RUNCMP et and test the packer to 4500 psi for 30 minutes on_the Printed: 7/29/2009 3:04:53 PM • . -- _ BP EXPLORATION Pag~ 11 af 11 ' Operations Summary Report Legal Well Name: 18-31 Common Well Name: 18-31 Spud Date: 8/2/1995 Event Name: WORKOVER Start: 7/6/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 7/18/2009 Rig Name: DOYON 14 Rig Number: Date Fr~m - To Hours 7ask Code NPT Phase : Descrip#ian of Op~rations 7/16/2009 22:00 - 00:00 2.00 RUNCO RUNCMP pressure up on the annulus to 3500 psi and told for 30 minutes. Good test. Bleed off the tubing and shear the DCK valve. Pump both ways at 3 bpm with 900 psi. 7/17/2009 00:00 - 00:30 0.50 RUNCO P RUNCMP Rig down testing equipment, laydown the landing joint, and prepare to install the TWC. 00:30 - 01:30 1.00 RUNCO P RUNCMP install and test the TWC to 1000 si from below and 3500 si , from above. Both tests for 10 minutes, charted, and were passing tests. ', 01:30 - 03:30 2.00 BOPSU P WHDTRE Blow down the lines and suck out the stack. Pull the flow line, i riser, and remove the choke line. ' 03:30 - 11:30 8.00 BOPSU P WHDTRE Open the rams doors and pull all of the rams out. Clean the ' cement debris out of the ram cavities. Stand back the stack on the stump. 11:30 - 17:00 5.50 WHSUR P WHDTRE Nipple up the adapter flange and the tree. Test the adapter flange to 5000 psi for 30 minutes. Good Test. Rig up LRS and pressure test lines to 5000 psi. Good Test. Test the tree to 5000 psi for 10 minutes. 17:00 - 17:30 0.50 WHSUR P WHDTRE Ri u the lubricator and test to 500 si for 5 minutes. Good Test. Have DSM ull the TWC. 17:30 - 20:00 2.50 WHSUR P WHDTRE Have LRS pump 90 bbls of 60 degree diesel freeze protect at 3 bpm with 1650 psi down the IA taking returns out the tubing. Let the diesel U-tube for an hour, then drain and rig down the lines. 20:00 - 21:00 1.00 WHSUR P WHDTRE Rig up the lubricator and have DSM set the BPV. Have LRS test the BPV to 1000 si from below for 10 minutes. Good Test. _ 21:00 - 22:00 1.00 WHSUR P WHDTRE Clean and clear the cellar, secure the well. Prepare to move off of the well. 22:00 - 00:00 2.00 WHSUR P WHDTRE Skid the rig floor and prepare to move off of the well. Riq eleased at 24:00 hrs. Printed: 7/29/2009 3:04:53 PM ~ ' ~ ~ ~ 18-31 A Well Histor Post Ri Workover) ~ Y~ 9 Date Summary 7/19/2009 WELL SHUT IN ON ARRIVAL. PULL B&R FROM 8343' SLM. PULL STA #2 DGLV-INT FROM 6043' SLM (6055' MD) & STA#1 BEK-DCK FROM 3479' SLM (3497' MD). CURRENTLY RUNNING IN W/ LGLV TO SET IN STA.# 1. 7/19/2009 T/I/O=Vac/0/0. Pull 4-1/16" CIW H BPV thru tree, post rig. 1-2' ext used, tagged @ 98" No problems. 7/20/2009 SET STA #1 LGLV C«3 3479' SLM (3497' MD). SET STA #2 S/O GLV C~ 6043' SLM (6056' MD). PULLED RHC PLUG BODY C 8355' SLM (8353' MD). MADE MULTIPLE RUNS W/ 10' x 2.50" PUMP BAILER TOP OF FILL C~ 8495' SLM (RECOVERED, RUBBER/METAL CHUNKS & SLUGGITS). LAYED DOWN EQUIPMENT DUE TO HIGH WINDS. 7/22/2009 MADE SEVERAL RUNS W/ 10' x 2.5" PUMP BAILER W/ EQ- FLAPPER BOTTOIVI, -5 GALLONS OF SLUGGETTS RECOVERED. RAN 2.50" CENT, 2.25" EQ SLEEVE TO 8501' SLM. RAN 2.50" CENT, 2.25" EQ SLEEVE, 2" JUC TO 8501' SLM, SHEARED OFF. 7/23/2009 MADE 4 ATTEMPTS TO PULL 2-1/8" IBP C«~ 8500' SLM (SHEARED FN RING OFF IBP). 7/24/2009 PLANTED 2.60" OVERSHOT (1-3/8" GRAPPLE) W/ 4-1/2" x 2.33" EXT. ON 2-1/8" BAKER IBP G 8500' SLM. MADE SEVERAL ATTEMPTS TO PULL IBP, UNABLE. LEFT WELL S/I, SSV DUMPED, NOTIFIED PAD OP ON DEPARTURE. 7/25/2009 WELL S/I ON ARRIVAL. PULL 2-1/8" BAKEFi IBP FROM 8,500' SLM, MISSING 2 SEALING ELEMENTS AND STIFFENER RING. DRIFT W ITH 2.25" CENTRALIZER & 2 7/8" (2) PRONG W IRE GRAB TO 8,700' SLM. RETURN WELL TO DSO. (WELL LEFT SHUT IN.) Page 1 of 1 NELLHEAD = CNV ~CTUATdR= BAKERC ~ <B. ELEV = 54.0' ' 3F. ELEV = 31.87 COP = I 1748' ~1ax Angle = _ 95 @ 11689' _ )atum MD = --- WA )atum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 3680' 4-1/2" TBG, 12.6#, 13CR-80, VAM TOP 3692~ .0152 bpf, ID = 3.958" Minimum ID = 2.37" @ 9495' 3-3/16" X 2-7/8" XO 5 1/2" x 4-1/2" XO, ID = 3.958" 8425~ 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 8425' 3-1/2" TBG, 9.3#, 13CR-80, .VAM TOP I~ 8447' ~ .0087 bpf, ID = 2.992" 4-1/2" TBG STUB (05/24/09) 8466~ 3-1/2" LNR, 8.81#, L-80 STL, 8572~ .0087 bpf, ID = 2.992" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8572~ TOP OF 5-1/2" LNR 8581' 7-5/8" CSG, 29.7#, S-95, ID = 6.875" ~ TOP OF WHIPSTOCK (TAGGED 4/22/05 DIMS) ~ ~TWO RA TAGS (TAGGED 04/22/05 DIMS) ~ 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 10556~ PERFORATION SUMMARY REF LOG: SPERRY GR/ROP ON 04/28/05 A NGLE AT TOP PERF: 89° @ 10140' Note: Refer to Production DB for historical perf data SIZE SPF INTERVA~ Opn/Sqz DATE 2" 6 10140 - 10230 U 04/29/05 2" 6 10270 - 10290 O 04/29/05 2" 6 10320 - 10580 O 04/29/05 2" 6 10600 - 10780 C7 04/29/05 2" 6 11040 - 11230 O 04/29/05 2" 6 11270 - 11320 O 04/29/05 2" 6 11440 - 11490 C7 04/29/05 2" 6 11530 - 11590 O 04/29/05 3-3/16" LNR 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" 9495~ I~ 3-3/16" X 2-7/8" XO, ID = 2.377" ~aT~ --~ 11764' ~ 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11804' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/27/95 ORIGINAL COMPLETION 04/29/05 NORDICI CTD SIDETRACK (18-31A) 07/17/09 D14 RWO 07/30/09 JCNUPJC GLV C/O (07/20/09) 07/30/09 DTR/PJC PULL IBP @ 8562' & FISH (07/25/09) 07/30/09 PJC DRLG HO CORRECTIONS 1 V-31 A I SAFE~OTES: W ELL ANGLE 70° @ 9322' 2QQ5' ~4-1/2" HES X NIP, ID = 3.813" GAS LIFf MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3497 3480 1 KBMG DOME BK 16 07/20/0~ 2 6056 6005 24 KBG-2-9 SO INT 20 07/20/0~ 1 8249 7843 35 KBG-2-9 DMY INT 0 07/17/0~ 3692~ --~4-1/2" X 3-1/2" XO, ID = 2.992" ~ 3883~ 7-5/8" X 5-1/2" BKR ZXP LTP & ~ FLIX-LOCK HGR, ID = 4.90" ~ 8306~ 3-1 /2" HES X NIP, ID = 2.813" 8330~ 5 1/2" X 3 1/2" BKR S-3 PKR, ID = 2.79" • 8353~ 3-1/2" HES X NIP, ID = 2.75" 8445~ 3-1/2" HES XN NIP ID = 2.635" $447' 3-1/2" MULESHOE, ID = 2.992" $4$2' 7-5/8" X 4-1/2" UNIQUE OVERSHOT 8517' 7-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.92" 8525~ 3.70" BKR DEPLOY SLV, ID = 3.00" 8550~ 4-1/2" HES XN NIP, 04/21/06 MILL ID = 3.80" (BEJiIND PIP~ 8562~ 3-1/2" HES X NIP, ID = 2.813" $572' 4-1/2" WLEG, ID = 3.958" (BEHIND PIPE) 8574' ELMD TT LOGGm 05/21/96 (BEHINO PIP~ 8572~ 3-1/2" X 3-3/16" XO, ID = 2.80" 8600~ EST. TOP OF CEIv1ENT (04/21 /05 DIMS) ~ FISH - IBP ELEMENTS & STIFFNER RING (07/25/809) I MILLOUT WINDOW (18-31A) 8847' - 8855' ~ PRUDHOE BAY UNff WELL: 18-31 A PERMfT No: ~2050580 API No: 50-029-22579-01 SEC 24, T11 N, R14E, 1969.79' FEL & 4159.23' FN( BP Exploration (Alaska) • u~ ~ -- ~ SARAH PAL1N, GOVERNOR ,~ ~ r ~-7~ OII/ ~ ~ ~ 333 W. 7th AVENUE, SUITE 100 C01~5ERQA~`IO1~T COMIrII55IO1~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team header BP Exploration Alaska Inc. ~ ®~'"g PO Box 196612 c ~~ Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-31A Sundry Number: 309-103 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Cathy P. Foerster Commissioner DATED this ~S day of April, 2009 Encl. STATE OF ALASKA A~ OIL AND GAS CONSERVATIO APPLICATION FOR SUNDRY 20 AAC 25.280 ~~N J N COM SION ~ C APPROVAt~t ~IAF? ~ ~009~J ~ ~ ~ ~~- 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate Time S ~OftS, COf11l11jS ® Alter Casing . - ® Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Su@II ^ Change Approved Program .~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -® Development ^ Exploratory 205-058 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22579-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-31A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028307 - 54' _ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11804' - 8710' - 11764' - 8710' ' 8562' None C sin Len ize M TVD r II se r ral n r 11 2 11 1 4 urfa 10-3/4" 36 3 2' 521 2480 In ermediate 8701' 7-5/8" 873 ' 8243' 81 12 r i in r 266' S-1/2" 8581' - 8847' 8116' - 8335' 774 6 Liner 279' 3-'1~2" x 3-3/16" x 2ais" 2 ' - 11 4 807 ' - 8710' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10140' - 11590' 8723' - 871 T 4-1 /2", 12.6# L-80 8574' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW 'HBBP-T' packer Packers and SSSV MD (ft): 8517' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 30, 2009 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-x102 Printed Name avid Reem Title Engineering Team Leader Prepared By NameMumber: Signature ~. C$~~ Phone 564-5743 Date 3 _~ l_ Q Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: .~~0 S. ~~ ~ S°~- i ~ ~©~ ! 1 W~~ v~~+M.~J~"-~ GI~~`G~ P ~ Subsequent Form Required: ~~ ~ GI S APPROVED BY ~ _ ~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised 0/2006 Submit In Duplicate .. ~.~ • by GP,~~ 18-31 A Expense Rig Workover i Scope of Work: Pull 4-%2" completion, run and cement 5'h" scab liner over cretaceous leak. Run 4-%2" x 3'/2" 13Cr80 premium thread "stacker-packer" completion. MASP: 2570 psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: March 30, 2009 Nathan Sinyangwe Aras Worthington Pre-Ria Work Reauest: S 1 Pull PX Plu from 8562' MD. Drift tubin for 4-1/2" Jet Cutter and WRP. E 2 Set 4 '/" WRP @ 8512' MD in the middle of the first 10' pup joint above the production packer. MITT to 3500 psi to verify WRP as barrier. Jet Cut 4-1/2" 12.6# L-80 Tubing at -8466' MD (reference tbg tally 09/06/1995) in the upper 10' of the first full joint above the production packer. F 3 Circulate well through the cut with 9.8 ppg brine and FP with diesel the top 300'. MITOA to 2000 psi. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks a check one at a time . PPPOT-T & IC. V 5 Set BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure S~,c~ er~U~ `~,l~~G~~~ CL~-'~"~S~Z~'~ 1. MIRU. Circulate well to 9.8 ppg brine through the cut. ,~~~ 2. ND tree. NU BOPE including~2'r18'`~c.~,yBJ~S Pressure test to 3500 psi. 3. Pull and LD 4-%2" tubing string to the cut. 4. Run 7 5/8" casing scraper and dress off assembly. Dress off tbg stub. 5. Run and fully cement 5 1/2" scab liner to 3900'. Note: Casing rams will not be run because there is one tested barrier to the reservoir (WRP plug) and a full column of monitor-able KWF covering the cretaceous. ,S~,~C ~,n,~~~ 1 ~I ~ ~( , 6. Change out casing packoffs. Test packoffs to 3500 psi. ~7h~~ 7. Pressure test scab liner and casing and drill out shoetrack. 8. Clean out to retrievable bridge plug and retrieve same. 9. Run 4-%2" x 3 %2" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at -8300' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. • by • ~y 18-31 A Exp Rig Workover Scope of Work: Pull 4-' "completion, run and cement 5'/z" scab liner over cretaceous leak. Run 4-'/z" x 3'/z" 13Cr80 premium thr d "stacker-packer" completion. MASP: 2570 psi Well Type: Producer Estimated Start Date: March 30, Production Engineer: Nathan Sin Intervention Engineer: Aras Worth Pre-Rig Work Reauest: ~ rr , -off G.+t~~._..~... S 1 Pull PX Plu from 8562' MD. D ~ t tubin for 4-1/2" Jet Cutter and WRP. E 2 Set 4 ~/z" WRP ~ 8512' MD in th middle of the first 10' pup joint above the production packer. MITT to 3500 psi to verify RP as barrier. Jet Cut 4-1/2" 12.6# L-80 Tubing at 8466' MD (reference tbg tally 06/1995) in the upper 10' of the first full joint above the reduction acker. F 3 Circulate well through the cut with 9.8 pg brine and FP with diesel the top 300'. MITOA to 2000 si. W 4 Check the tubing hanger lock down screws or free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 5 Set BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad s needed for the ri . Proposed Procedure 1. MIRU. Circulate well to 9.8 ppg brine through the cut. 2. ND tree. NU BOPE. Pressure test to 3500 psi. 3. Pull and LD 4-'/z" tubing string to the cut. 4. Run 7 5/8" casing scraper and dress off assembly. Dress off tbg stu 5. Run and fully cement 5 1/2" scab liner to 3900'. Note: Pipe rams w I not be changed to 51/2" as the well have one tested barrier (WRP) to the reservoir. 6. Change out casing packoffs. Test packoffs to 3500 psi. 7. Pressure test scab liner and casing and drill out shoetrack. 8. Clean out to retrievable bridge plug and retrieve same. 9. Run 4-~/z" x 3'Iz" 13Cr-80 stacker packer completion with Baker S-3 packer. P ition packer at 8300' MD. 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = FMC WELLHEAD= CIW ACTUATOR BAKERC KB ELEV = 54.0' BF ELEV - KOP = 1748' Max Angle 95 @ 11689' Datum MD = WA Datum TV D = 8800' SS ~ 18-31A I I I ~TfT 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" ~~ 3680' • SAFETY NOTES: 70° @ 9322' 2210' 4-1l2" HES SERIES 10 TRSV SSSV NIP, ID = 3.812" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3724 3706 1 HES-TMPDX DMY BK 0 05!13/97 2 6297 6218 29 HES-TMPDX DMY BK 0 05/13/97 3 8439 7999 34 HES-TMPDX DMY BK 0 09/09/97 Minimum ID = 2.37" @ 9495' TOP OF 2-7/8" LINER 2.813" PX PLUG (05/03108) 8562' ~ 3-1l2" LNR, 8.81#, L-80 STL, 8572' .0087 bpf, ID = 2,992" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 8572' TOP OF 5-1/2" LNR 8581' - 7-5/8" CSG, 29.7#, S-95, ID = 6.875" 8735' TOP OF WHIPSTOCK (TAGGED 4/22(05 DIMS) $847' TWO RA TAGS (TAGGED 04/22/05 DIMS) 8857' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 10556' PERFORATION SUMMARY REF LOG: SPERRY GRIROP ON 04/28/05 ANGLE AT TOP PERF: 89 @ 10140' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10140 - 10230 C 04!29/05 2" 6 10270 - 10290 G 04/29/05 2" 6 10320 - 10580 C 04/29/05 2" 6 10600 - 10780 C 04/29!05 2" 6 11040 - 11230 C 04/29/05 2" 6 11270 - 11320 C 04/29/05 2" 6 11440 - 11490 C 04/29/05 2" 6 11530 - 11590 C 04/29!05 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" 9495' I~ 3-3/16" X 2-7/8" XO, ID = 2.441" ( ~ PBTD -i 11764' {~ 2-7l8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 11804' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/27(95 ORIGINAL COMPLETION 04/29/05 NORDIC! CTD SIDETRACK (18-31 A) 05/08/05 DFR/TLH WAIVERSAFETY NOTE 01(25/06 RPH/TLH WANERSAFETY NOTE 08/30/06 AS/TLH DRLGDRAFTCORRECTIONS 05/04/08 SEW/PJC SET" PX PLUG PRUDHOE BAY UNIT WELL: 18-31 A PERMIT No: 82050580 API No: 50-029-22579-01 SEC 24, T11 N, R14E, 1969.79' FEL & 4159.23' FNL BP Exploration (Alaska) $~ 517' 1~ 7-5/8" X 4-112" TIW HBBP-T PKR, ID = 3.92" 8525' 3.70" BKR DEPLOY SLV, ID = 3.00" 8550' 4-1/2" HES XN NIP, 04!21!06 MILL ID = 3.80" (BEHIND PIPE) 8562' 3-1/2" HES X NIP, ID = 2.813" 8572' 4-1/2" WLEG, ID = 3.958" (BEHIND PIPE) 8574' ELMD TT LOGGED 05/21/96 (BEHIND PIPE) $572' 3-1/2" X 3-3116" XO, ID = 2.80" ~-i EST. TOP OF CEMENT (04/21!05 DIMS) MILLOUT WINDOW (18-31 A) 8847' - 8855' TREE= FMC 1 8 ~ ~ P ~ SAFETY NOTES: 70° ~ 9322' ACTUATOR = BAKER C ' ro p o s e KB. ELEV 54.0' BF. ELEV = _? " " KOP= 1748' HES X Nipple ID = 3.813 "'2200 4-1/2 Max Angle = 95 @ 11689' GAS LIFT MANDRELS Datum MD = WA ST MD ND DEV TYPE VLV LATCH PORT DAl Datum ND = 8800' SS 1 3500 1 " ' ' 2 6000 4- /2 TBG, 12.6#, 13Cr80, .0152 bpf, ID = 3.958 ~-3700 " " ' 3 8000 10-3/4 CSG, 45.5#, NT-80, ID = 9.953 3680 4-1/2" x 3 1/2" XO ~3700' 5 1/2" x 7 5/8" ZXP Liner Top Packer 3-1/2" TBG, 9.3#, 13Cr-80, .0087 bpf, ID = 2.992" 4-1/2" HES X Nipple ID = 3.813" 5-1/2" Liner, 17#, L-80, .0232 bpf, ID = 4.892" 5 1/2" X 3 1/2" 5-3 Packer Fully Cemented Liner 4-1/2" HES X Nipple ID = 3.813" 5 1/2" x 4-1/2" XO 7-5/8" X 4-1/2" Unique Overshot 8517' 7-5/8" X 4-1/2" TIW HBBRT PKR, ~ = 3.92" 8525' 3.70" BKR DEPLOY SLV, ID = 3.00" 2.813" PX PLUG (05/03/08) $562' 8550' 4-1/2" HES XN Nom, 04121!06 MILL 3-1/2" LNR, 8.81#, L-80 STL, $572' ID = 3.80" (BBi1ND PIPq .0087 bpf, ID = 2.992" 8562' -~3-1/2" HES X Nom, ID = 2.813" 4-1/2" TBG 12 6# L f ID = 3 80 0152 b 958" 8572' ~ = 3 8572' 4-1/2" WLEG 958" (BE1iIND PIPq , . - , , , . p . . , ' " $574' ELMD TT LOGGED 05/21/96 (66~ND PIPS LNR $rj81 TOP OF 5-1/2 8572' 3-1/2" X 3-3/16" XO, ID = 2.80" 861)0' EST. TOP OF CEMENT (04/21!05 DIMS) 7-5/8" CSG, 29.7#, s-95, ID = 6.875" I--I 8735' Minimum ID = 2.37" @ 9495' TOP OF 2-7/8" LINER TOP OF WHIPSTOCK (TAGGED 4/22/05 DIMS) 8 ITWO RA TAGS (TAGGED 04/22/05 DMAS) I 15-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" I I 10556' l PERFORATION SUMMARY REF LOG: SPERRY GR/ROP ON 04/28/05 ANGLE AT TOP P6~F: 89 @ 10140' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 6 10140 - 10230 C 04/29/05 2" 6 10270 - 10290 C 04/29/05 2" 6 10320 - 10580 C 04/29/05 2" 6 10600 - 10780 C 04/29!05 2" 6 11040 - 11230 C 04/29/05 2" 6 11270 - 11320 C 04/29/05 2" 6 11440 - 11490 C 04/29/05 2" 6 11530 - 11590 C 04/29/05 3-3/16" LNR, 6.2#, L-80 TCA, .0076 bpf, ID = 2.80" MILLOUTWINDOW (18-31 A) 8847' - 8855' I 9495' I PBTD I-~ 11764' 7/8" LNR 6.16#, L-80 STL, .0058 bpf, ID = 2.441" ~ 11 3-3/16" X 2-7/8" XO, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/27/95 ORIGINAL COMPLETION 04/29/05 NORDICI CTD SIDETRACK (18-31A) 05/08/05 DFR/TLH WANER SA FEN NOTE 01/25/06 RPH/TLH WAVER SA FEN NOTE 08/30/06 AS/TLH DRLG DRAFT CORRECTIONS 05/04/08 SEW/PJC SET PX PLUG ~ Exploration (Alaska) PRUDHOE BAY UNfT WELL: 18-31A ', PERMff No: `2050580 API No: 50-029-22579-01 SEC 24, T11 N, R14E, 1969.79' FEL & 4159.23' FNL ~I • Page 1 of 3 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 14, 2009 1:34 PM To: 'Reem, David C' Cc: Regg, James B (DOA) Subject: RE: DS 18-31A (205-058) Workover Thanks much Dave. From: Reem, David C [mailto:ReemDC@BP.com] Sent: Tuesday, April 14, 2009 1:31 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 18-31A (205-058) Workover Tom, you are making a safe presumption here. I do not see a compelling reason to alter the ram configuration for this fine hole-in-the-ground. DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 14, 2009 1:23 PM To: Reem, David C Cc: Worthington, Aras J; Regg, James B (DOA) Subject: RE: DS 18-31A (205-058) Workover Dave, I am working through my "stack" and finalizing matters with this workover request. Referring to our email of earlier this morning on DS 13-13A which is also scheduled for Doyon 14, is it safe to presume that 1 set of 2-7/8" x 5" and 1 set of 3-1/2" x 6" rams will be employed here as well? I look forward to your reply. Tom Maunder, PE AOGCC From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Wednesday, April 01, 2009 11:12 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 18-31A (205-058) Workover Tom, As of now 18-31A is looking to start around mid-May by Doyon 14. Aras From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 01, 2009 11:05 AM To: Worthington, Aras J Subject: RE: DS 18-31A (205-058) Workover Aras, I am catching upon items and noticed that this workover was planned for March 30. When will it start? Also, which rig will do the work? Thanks in advance. Tom Maunder, PE 4/14/2009 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 14, 2009 1:23 PM To: 'Reem, David C' Cc: 'Worthington, Aras J'; Regg, James B (DOA) Subject: RE: DS 18-31A (205-058) Workover • Page 1 of 3 I am king through my "stack" and finalizing matters with this workover request. Referrin our email of earlier this morning on DS 13-13A which is also scheduled Doyon 14, is it safe to sume that 1 set of 2-7/8" x 5" and 1 set of 3-1 /2" x 6" rams will be toyed here as well? I look forward our reply. Tom Maunder, P AOGCC From: Worthington, Aras J [m ' to:Aras.Worthington@bp.com] Sent: Wednesday, April 01, 2009 :12 AM To: Maunder, Thomas E (DOA) / Subject: RE: DS 18-31A (205-058) Wo ver Tom, As of now 18-31A is looking to start around m' - ay Doyon 14. Aras From: Maunder, Thomas E (D [mailto:tom.maunder@alaska.gov Sent: Wednesday, April 01, 09 11:05 AM To: Worthington, Aras J Subject: RE: DS 18-3 (205-058) Workover Aras, I am catching on items and noticed that this workover was planned for March 30 Also, which r' will do the work? Thanks in dvance. Tom M nder, PE From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Wednesday, March 25, 2009 10:35 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 18-31A (205-058) Workover Tom, Here is the revised scope of work document as disucussed -assuming e-mail is ok...? Thanks! Aras I it start? 4/14/2009 • Page 2 of 3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 25, 2009 9:50 AM To: Worthington, Aras J Cc: Reem, David C Subject: RE: DS 18-31A (205-058) Workover Aras, Email is fine. Which rig will be doing the work? Tom From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Wednesday, March 25, 2009 9:36 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: DS 18-31A (205-058) Workover Tom, I'm sending a revised scope of work letter your way. However, the plan I am proposing is to nipple-up with 2 7/8" x 5" VBRs from the get-go, which will not cover the 5 1/2" scab liner. It is true that by has a "2 barrier" policy which covers operations such as removing well control equipment, tree, etc. But running in the hole with 5 1/2" liner, a single tested barrier to the reservoir, and a monitorable column of Kill-weight-fluid covering the cretaceous is in compliance with bp's policies. The reason we wish to NU 2 7/8" x 5" VBRs instead of 3 1/2" x 6" VBRs is that we will be running 2 7/8" Drillpipe to drill out the shoe track and retrieve our barrier to the reservoir (WRP plug) and we will need BOP ram coverage for that drillstring given we are exposed to the reservoir for a portion of that operation. Thanks and let me know if you would like to discuss further. Aras From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, March 24, 2009 9:54 AM To: Worthington, Aras J Subject: RE: DS 18-31A (205-058) Workover Thanks Aras. Yes, I would appreciate if you would provide a revised document. Tom From: Worthington, Aras J [mailto:Aras.Worthington@bp.com] Sent: Tuesday, March 24, 2009 9:49 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: DS 18-31A (205-058) Workover Tom, Thanks for pointing this out -yes the variable rams will cover the 5 1/2" scab liner to be run. My mistake in verbiage! 4/14/2009 Page 3 of 3 Would you like me to edit the "Scope of Work" procedural run-down to include this verbiage? Aras From: Reem, David C Sent: Friday, March 20, 2009 4:41 PM To: Worthington, Aras J Subject: FW: DS 18-31A (205-058) Workover From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, March 19, 2009 2:26 PM To: Reem, David C Subject: DS 18-31A (205-058) Workover Dave, Please forward to Aras, I am still having issues with my address book. In the procedure for this well, it is noted that the rams will not be changed to 5-1/2" since there will be ONE tested barrier to the reservoir. I understood that BP's policy was to have 2 mechanical barriers in a well. Also, won't 3" x 6" VBRs provide the necessary coverage for the tubulars used working over this well? Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC 4/14/2009 ,~~ , ~. .~ :,~~.. ,. .~~ 18-31A (PTD #2050580) Interna~aiver Cancellation -Not Operable We~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~(~~ l Z<<2~~~~ Sent: Friday, December 21, 2007 9:20 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS1 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R Cc: Senden, Leslie B; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Townsend, S. Eliot; Winslow, Jack L. Subject: 18-31A (PTD #2050580} Internal Waiver Cancellation -Not Operable Well All, .~` An internal waiver was issued for a PC Leak on well 18-31A (PTD #2050580) on 01/07/06. Although this well is under dispensation, the decision has been made to not repeat waiver compliance testing. Therefore the waiver is cancelled and the well is to remain shut-in until repaired. The well has been reclassified as Not Operable and will be secured. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. Please tail if you have any questions. Thank you, ~ ~ 3 ~QO~ ,~nna u6e, ~". ~~i~~ J p,N ell Integrity Coordinator GPB ells Group Phcane: (A7} 659-51Q2 Pager: (907} 659-1EtU x1154 .~na fie, ~'. E. ell Integrity Coordinator GPB ells Group Phone: {9q7} 659-51132 Pager: (907} 659-s1tJ x1'154 12/21 /2007 ).." rvt., DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2050580 Well Name/No. PRUDHOE BAY UNIT 18-31A Operator BP EXPLORATION (ALASKA) INC >,~J..<~ L~\- API No. 50-029-2257i:Õ1-00 MD 11804_" TVD 8710 _eO Completion Date 4/29/2005 Completion Status 1-01l Current Status 1-01l UIC N ~~ -----.. - --- REQUIRED INFORMATION Mud log No Samples No Directional Survey Yes -- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, EWR, MGR, CCl, CNl Well Log Information: (data taken from logs Portion of Master Well Data Maint Name Directional Survey Log Log Scale Media Run No Interval OH / Start Stop CH 8774 11804 Open e Log/ Data Type ~.. ¿e1S C Lis I~' I g ] ./ l;:( C -"'- ;::: ~::~:f:::O" Electr Digital Dataset Med/Frmt Number o Asc Received Comments 7/7/2005 Definitive 13382 Neutron 5 Blu 8288 11645 Case 11/21/2005 MCNl GRlCCUCNl 28- April 2005 MCNl Memory GRlCCLlCNl 28-April 2005 LIS Veri, GR ROP LIS Veri, GR ROP 13382 Neutron Name Interval Start Stop Sent 8400 11764 Case 11/21/2005 8793 11833 Open 1/29/2007 8793 11833 Open 1/29/2007 Sample Set Number Comments .-----,--.- Well Cores/Samples Information: Received ADDITIONAL INFORMATION Well Cored? Y Q Daily History Received? -.., 0Jß.¡ QJN - Chips Received? ~- Formation Tops Analysis Received? "'t-t1r -_._.."----~ ----~~-~--~~ ---~--"~ -------_....~-~ --'- Comments: Compliance Reviewed By: _ ~~ Date: /21 Me; ~ò~"7 -~--_._- ..--- . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmill. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 12, 2007 RE: MWD Formation Evaluation Logs: 18-31A, AK-MW-3667579 1 LDWG formatted CD rom with verification listing. API#: 50-029-22579-01 PLEASE ACK.l~OWLEDGE RECEIPT BY SIGNING AND RETù'R.l~ING A COPY OF THE TRA.NSMITT AL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed:~~ Date: ...--~....... goS--o~ 0 .4.f.. , ¿,.¡' 3 fA J". - ð . "'"",7 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date BL 02-30B 10980587 RST 07/17/05 1 PSI-07 10674389 RST 10/27/03 1 PSI-07 10679045 RST 12/26/03 1 L3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F·30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30/05 1 Z-15 10980580 RST 07/10/05 1 C·30 10980583 RST 07/13/05 1 W-39A 10928650 MCNL 10/16/05 1 18-31A ¿)Ó5 - 05B 10942210 MCNL 04/28/05 1 H-02A 10928622 MCNL 04/05/05 1 05-24A 10928609 MCNL '(PRINT SENT 1/24/05) , 12/22/04 K-06A 11075903 MCNL 07/30/05 1 L-03 10913041 OH LDWG EDIT FOR WIRELlNE DATA 08/01/05 2 B-02A 10889169 SCMT 09/22/04 H-05 10674407 CBL 01/21/04 G-13A 10563175 SCMT 06/17/03 E-06A 11051045 SCMT 05/19/05 W-20 10672389 US IT 06/03/04 MPF-87A 10708043 US IT 01/08/04 MPA-03 11058243 US IT 09/07/05 MPF-89 11051088 USIT 08/17/05 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~\~'\ç n(b( V 0 \ ,oct/;;; 11/17/05 NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. Color . CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 /335J 1 1 1 1 1 1 1 1 1 . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R~;"dbYt~~'6 · STATE OF ALASKA A ALASKÄ AND GAS CONSERV ATION COM~IONCE WELL COMPLETION OR RECOMPLETION REPORT AND LOG' ~ 1a. Well Status: aiD Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 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: 3719' NSL, 64' WEL, SEC. 24, T11 N, R14E, UM Top of Productive Horizon: 55' NSL, 1137'WEL, SEC. 13, T11N, R14E, UM Total Depth: 264' NSL, 3585' WEL, SEC. 13, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 691712__ y- _ 596030~ Zone-~P4__ TPI: x- 690597 y- 5961894 Zone- ASP4 Total Depth: x- 688145 y- 5962042 Zone- ASP4 -~------~---- ------~-------- ---------- 18. Directional Survey aiD Yes 0 No 21. Logs Run: MWD, GR, EWR, MGR, CCL, CNL 22. One Other 5. Date Comp., Susp., or Aband. 4/29/2005 6. Date Spudded 4/22/2005 7. Date T.D. Reached 4/27/2005 8. KB Elevation (ft): 54' 9. Plug Back Depth (MD+ TVD) 11764 + 8710 10. Total Depth (MD+TVD) 11804 + 8710 11. Depth where SSSV set (Nipple) 2210' MD 19. Water depth, if offshore N/ A MSL MAY 2 '6 ;;005 ~~,. . ,~~~~q¡a~i¡ .C.: C ..c:;i;:y;ír;c . .! Dr ÙèvëlóP~~~~:):tExpl?ratory o Stratigra jhic'J> ~"5ervlce 12. Permit to Drill Number 205-058 13. API Number 50- 029-22579-01-00 14. Well Name and Number: PBU 18·31 A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028307 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CASING SIZE WT. PER FT. GRADE 20" 91.5# H-40 10-3/4" 45.5# NT80 7-5/8" 29.7# USS-95 5-1/2" 17# L-80 3,1/2" x 3-3116" x 2·718" 8.81# /6.2# /6.16# L-80 CASING, LINER AND CEMENTING RECORD SElTlNG DEPTH MD SElTlNG DEPTH TVD HOLE lOP BoTTOM 'lOP BoTTOM SIZE CEMENTING RECORD Surface 110' Surface 110' 30" 260 sx Arctic Set (Approx.) 35' 3680' 35' 3662' 13-1/2" 1037 sx PF 'E', 573 sx Class 'G' 34' 8735' 34' 8243' 9-7/8" 340 sx Class 'G' 8581' 8847' 8116' 8335' 6-3/4" 228sxClass'G' 8525' 11804' 8070' 8710' 4-1/8" x 3,314" 201 sx Class 'G' 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 10140' - 10230' 8723' - 8724' 10270' - 10290' 8725' - 8725' 10320' - 10580' 8725' - 8724' 10600' - 10780' 8723' - 8724' 11040' - 11230' 8725' - 8725' 11270' - 11320 8725' - 8723' 11440' - 11490' 8719' - 8718' 11530' - 11590' 8718' - 8717' 26. Date First Production: May 8, 2005 Date of Test Hours Tested PRODUCTION FOR 5/10/2005 1.3 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 539 103 24-HoUR RATE"'" 24. SIZE 4-1/2", 12.6#, L-80 AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 8574' PACKER SET (MD) 8517' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected with MeOH PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBl 270 Oil -BBl 4,987 GAs-McF 8,287 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". fëë-'--~~···-· ,...... ~ ¡jet t:t'; I'~~ ~. None" CO.1. "~ HI,... t ( ~Z/~ : ~~,J Form 10-407- Rev¡šêd 12/2003 27. GAs-McF 449 WATER-Bsl -0- WATER-BBl -0- ORIGINAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO 85.57 1,662 Oil GRAVITY-API (CORR) RBDMS BFL JUN 0 6 2DD5 ÛV 28. GEOLOGIC MARKERS. NAME MD Sadlerochit 8779' Top CGL 8896' Base CGL 8968' 21TS 9163' Zone 1 B 9246' TDF / Zone 1A 9368' PGOC 9280' eRMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 29. 8279' None 8377' 8441' 8595' 8646' 8694' 8664' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 1J 11.11/J_ Ttl T h· IA . t t D te DS/,,?'_'QS Terrie Hubble ...-- I ~ (V~~ i e ec nlca 5515 an a '{ "c...J.9/C PBU 18-31 A 205-058 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Ted Stag''', 564-4694 Permit No. / 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-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. ITEM 4b: TPI (Top of Producing Interval). ITEM 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. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/19/2005 01 :00 - 04:00 3.00 RD and move off N20 and prepare to mob to DS18 Well 31 Replaced clutch flush pump on Nordic drive system 04:00 - 19:00 15.00 MOB P PRE Traveled from N20 to DS18 19:00 - 23:00 4.00 RIGU P PRE Spotted rig off to the side and RU LRHOT to fluid pack well31 with 2% KCL Rigged up LR and wait on KCL. Problem at HWP and my truck was bumped by the Wells Group 24 hrs RD to accepted and 17 hrs rig move with 1 hrs rig repair.. 23:00 - 00:00 1.00 RIGU P PRE Fluid packed well bore using 290 bbl 2% KCL at 5 bpm and 1200 psi. Injectivity test conducted at 2 bpm and 250 psi, Pump 5 bbl MEOH. SO 4/20/2005 00:00 - 01 :00 1.00 RIGU P PRE RD LR and make ready to move over well. Pad Operator RU Control Panel for TRSSSV 01 :00 - 01 :30 0.50 RIGU P PRE PJSM and move rig over well RIG ACCEPTED AT 01 :30 HRS 4/20/2005 01 :30 - 04:00 2.50 RIGU P PRE RU TT and associated outside equipment. Installed 4 ft lubicator on BOP 04:00 - 08:30 4.50 BOPSUP P PRE PT BOP's to 250/3500 psi. John Crisp wavered witness BOP test 08:30 - 10:30 2.00 BOPSUR P PRE PJSM. Cut off 1800' of coil. Off load coil to metal dumpster. 10:30 - 11 :15 0.75 BOPSUF P PRE Install CTC. Pull (35k) and pressure (3500 psi) test. 11:15-12:30 1.25 BOPSUF P PRE Pump volume dart. Hit at 57.3 bbls. 12:30 - 13:00 0.50 ZONISO P WEXIT MU cement nozzle BHA. MU injector. RIH to swab. Pressure test packoff to 3500 psi. Open master (23.25 turns) and swab (23.25 turns). - Well on a vac. 13:00 - 14:30 1.50 ZONISO P WEXIT RIH with cementing BHA #1. - SO 20k, PU 38k - Lightly tag whipstock. Correct depth to 8850' MD. - Paint flag at 8840' MD. 14:30 - 00:00 9.50 ZONISO N WAIT WEXIT Wait on cementers. Hole drinking 2 bpm with a full colum at 1200 psi. Circulate minimum rate while waiting. OS Cement crews went to bed at 2200hrs and will be on location at 0700 hrs 4/21/2005 4/21/2005 00:00 - 07:00 7.00 ZONISO N WAIT WEXIT Wait on cementers 07:00 - 07:30 0.50 ZONISO P WEXIT RU cementers on location. 07:30 - 08:00 0.50 ZONISO P WEXIT Establish rate/pressure with backside open. - Catch fluid with 3 bbls. Returns in 23.7 bbls. - Losing fluid at 1.7 bpm at 1450 psi. Shut in choke. - Pumping at 2 bpm, WHP at 140 psi. -- (PU 36k, SO 22k) 08:00 - 08:20 0.33 ZONISO P WEXIT PJSM for cement job. 08:20 - 09:40 1.33 ZONISO P WEXIT Cement WS in place. - Cementers priming up. - Pressure test cement lines to 4000 psi with 2 bbls freshwater. Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/21/2005 08:20 - 09:40 1.33 ZONISO P WEXIT - Zero in MM at cement (15.8 ppg) - Pump 37.7 bbls cement at 2.4 /1.0 bpm. - Reduce rate to 2 bpm, SI backside. WHP at 160 psi, flat-lined at 70 psi. - Reduce rate to 1.45 bpm at 72 bbls away (cement at perfs). WHP slowly decreasing to flatline at 22 psi. No squeeze pressure obtained. - Open choke at 85 bbls away, pump 2 bbls with returns. - Lay in remaining cement to put TOC at approx 8600' MD. 09:40 - 10:15 0.58 ZONISO P WEXIT POOH to safety at 6000' MD pumpng 0.5 bpm getting slight 0.25· ZONISO . P returns (getting 1: 1). 10:15 - 10:30 WEXIT SO pumps. Wait at safety. 10:30 -11:30 1.00 ZONISO P WEXIT Establish circulation, immediate returns. - 0.5 bpm. Full returns. - 1.0 bpm. Full returns. - 1.5 bpm. Full returns. - 2.0 bpm. Full returns. Pump pressure staying stable at 1100 psi. Circulating some gas-cut mud to surface, this is our first bottoms up since being on the well. - SO pumps. SI backside. Apply 800 psi to well (anticipated hydrostatic differential from circulating cement to surface) to ensure cement will not squeeze away. OK. Bleed off WHP. 11 :30 - 12:15 0.75 ZONISO P WEXIT Wash down to TOWS with 40 bbls BIO. 12:15 - 13:45 1.50 ZONISO P WEXIT POOH with cementing BHA. 13:45 - 14:00 0.25 ZONISO P WEXIT Stand back injector. LD nozzle. 14:00 - 14:45 0.75 ZONISO P WEXIT MU swizzle stick. Flush BOP stack. LD swizzle stick. 14:45 - 15:15 0.50 STWHIP P WEXIT PU window millig BHA #2. - New 3.8" pilot and string mills. 15:15 - 16:50 1.58 STWHIP P WEXIT RIH with window milling BHA. - Circulate minimum rate. 16:50 - 17:45 0.92 STWHIP P WEXIT Tag XN, correct depth +10.7' to 8550' MD. Mill. - Dry run through. 17:45 - 17:50 0.08 STWHIP P WEXIT RIH, tag WS. PU with overpull. Suspect pinch point. 17:50 - 18:00 0.17 STWHIP P WEXIT Mill window. 18:00 - 19:00 1.00 STWHIP P WEXIT Increased flow up the annulus to 3.5 bpm, PU SWI, SIP = 100 psi, Lined out to TT. Cir gas out to TT while maintaining 60-70 psi WHP at 2.00 bpm. Circulated out 145 bbl diesel crude mixture to TT 19:00 -19:10 0.17 STWHIP P WEXIT RIH to mill window 19:10 - 00:00 4.83 STWHIP P WEXIT Milling window as per SOP's Qp = 2.36/2.40 bpm Vp = 162 bbl Small amount of gas up at 8,854 ft, outside casing 4/22/2005 00:00 - 03:11 3.18 STWHIP P WEXIT Milling window as per SOP's Time drilled Qp = 2.36/2.40 bpm Vp = 325 bbl Stall at 8857.4 ft. (bottom of window) Geo AI checked sample, 40% Formation Pumped 26 bbl bio sweep Stall at 8,858.3 ft, 11 bbl Bio sweep out 03: 11 - 05:35 2.40 STWHIP P WEXIT Started mud swap drill formation "slow ROP in formation. ROP increased to 9 fph at 8,860.5 ft WOB at 8-12k Qp = 2.33 / 2.50 bpm at 3000 psi CTP Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Finished mud swap at 8868 ft Back reaming window from 8,867 ft to 8,850 ft. - Ream window 2 times. - Dry tag. POOH with window milling BHA. Lay down window milling BHA. - Pilot: 3.74 go /3.73 no-go - String: 3.76 go / 3.75 no-go. Circumferential crack at the string mill - Found cracked weld on adjuster ring on disconnect, call out for another. PU string mill and pilot to dress window. - New pilot: 3.80 go / 3.79 no-go - Used string: 3.78 go /3.77 no-go Wait for replacement disconnect. RIH with window milling BHA to dress window. - Ran smooth through XN nipple. At flag (8843.8'), begin dressing window. - 2.7 / 2.8 bpm at 2700 psi, no conclusive indication of motor work.. - Time milling at 0.5 ft/min to 8861.4' MD, suspect drilling new formation. - PU and confirm TO at 8861.4' MD. - Backream through window. - Ream one more time. - Dry tag, ok. POOH with window dressing BHA. Lay down window milling BHA. - Pilot: 3.80 go / 3.79 no-go - String: 3.78 go / 3.77 no-go MU CTC. PU build BHA. - DS100 C - 1.37 deg motor. RIH with build BHA. - SHT at 1180' MD. - Orient to low side prior to entering window. - Correct depth +6' to 8867' MD. PROD1 Drill ahead in Zone IV at 120 to 150L TF ROP 5 to 20 fph Q= 2.54 / 2.61 bpm, CTP 3100 / 3250 psi Vol p= 306 bbl IAlOA = 626/20 psi Adjusting TF and working on reactive torque limits with given TF Pumped up survey at 8912 ft Still magnetics from mother bore PROD1 Orien TF around PROD1 Drill ahead in Zone III at 60to 80 L TF ROP 5 to 20 fph IAlOA = 645/325 psi Vol p= 297 bbl PROD1 Drilling in ZIII at 80-90L TF Qp = 2.7 / 2.8 bpm CTP 3250/3420 psi ROP 2-15 fph Vp = 297 bbls 4/22/2005 03:11 - 05:35 2.40 STWHIP P WEXIT 05:35 - 07:45 2.17 STWHIP P WEXIT 07:45 - 09:15 1.50 STWHIP P WEXIT 09:15 - 09:45 0.50 STWHIP P WEXIT 09:45 - 10:15 0.50 STWHIP P WEXIT 10:15 - 11 :00 0.75 STWHIP N WAIT WEXIT 11 :00 - 12:30 1.50 STWHIP P WEXIT 12:30 - 14:00 1.50 STWHIP P WEXIT 14:00 - 15:00 1.00 STWHIP P WEXIT 15:00 - 15:30 0.50 STWHIP P WEXIT 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 18:30 2.00 DRILL P PROD1 18:30 - 22:05 3.58 DRILL P 22:05 - 22:20 22:20 - 00:00 0.25 DRILL P 1.67 DRILL P 4/23/2005 00:00 - 02:00 2.00 DRILL P Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/23/2005 00:00 - 02:00 2.00 DRILL P PROD1 Started lossing sum cir (off/on) at 8,948 ft (0.2 to 0.3 bpm). 100% returns at 8,952 ft Bleed IA/OD down from 650 / 350 psi to 350/ 166 psi 02:00 - 02:10 0.17 DRILL P PROD1 Pump up survey to check magnetics. Still have interference 02:10 - 02:20 0.17 DRILL P PROD1 PUH to tie-in 02:20 - 03:40 1.33 DRILL P PROD1 Tie-in at base of TSAD Logged from 8,835 ft up to 8,795 ft Corrected +3 ft RIH and tagged the bottom of the WS at 8,855 ft. PU, oriented TF from 119R to 170R. RIH tagged at TF milled. PUH oriented 1 click to 168L fell in, not much room. RIH to 8,900 ft. PUH logging RA Marker 03:40 - 03:50 0.17 DRILL P PROD1 RIH and tag bottom at 8964 ft TOWS @ 8,847 ft TOW @ 8,847.4 ft RA Marker @ 8,857 ft BOW @ 8,854.5 ft 03:50 - 04:00 0.17 DRILL P PROD1 Drilling in ZIII at 40L TF walked up to HS Qp = 2.7/2.8 bpm CTP 3250/3420 psi ROP 2-15 fph Vp = 288 bbls. lost 10 bbl on wiper trip 04:00 - 04: 15 0.25 DRILL P PROD1 Orient TF around to 70 L 04:15 - 06:00 1.75 DRILL P PROD1 Drilling in lower ZIII at 65L TF Qp = 2.7/2.8 bpm CTP 3250/3520 psi ROP 24 to 90 fph at 8993 ft Vp = 286 bbls Pump up survey at 8,981 ft Still mag interferences 06:00 - 07:00 1.00 DRILL P PROD1 Continue to drill ahead to 9033' MD. - Exit zone 3 at 8993' MD / 8408 TVD. - ROP increase to 50-100 fph. - 2.6/2.6 bpm at 3600 psi. - CTP 3150 free spin - TF at 60L 07:00 - 07:15 0.25 DRILL P PROD1 Orient TF to 80 L 07:15 - 08:45 1.50 DRILL P PROD1 Continue to drill ahead to 9100' MD. - ROP 50-100 fph. - 2.6/2.6 bpm at 3600 psi. - CTP 3150 free spin - TF at 80L 08:45 - 09:00 0.25 DRILL P PROD1 Wiper trip to window. - Hole in good condition 09:00 - 10:45 1.75 DRILL P PROD1 Continue to drill ahead to 9200' MD - ROP 50-100 fph. - 2.6/2.6 bpm at 3700 psi. - CTP 3150 free spin - TF at 55L 10:45 - 11 :00 0.25 DRILL P PROD1 Orient TF to 40L 11 :00 - 11 :45 0.75 DRILL P PROD1 Continue to drill ahead to 9250' MD - ROP 50-100 fph. - 2.6/2.6 bpm at 3600 psi. - CTP 3150 free spin - TF at 40L 11:45-12:15 0.50 DRILL P PROD1 Wiper trip to window. 12:15 - 15:30 3.25 DRILL P PROD1 Continue to drill ahead to 9355' MD. Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/23/2005 12:15 - 15:30 3.25 DRILL P PROD1 - ROP 20-50 fph. - 2.6/2.6 bpm at 3600 psi. - CTP 3100 free spin - TF at 10-45R - Formation has become shaley. - 4k-10k WOB. - Top of zone 1 at 9297' MD. 15:30 - 16:00 0.50 DRILL P PROD1 Orient to 70L. 16:00 - 17:15 1.25 DRILL P PROD1 Continue to drill ahead to 9,400' MD. - ROP 20-50 fph. - 2.6/2.6 bpm at 3,600 psi. - CTP 3,200 free spin - 4k-10k WOB. 17:15-18:00 0.75 DRILL P PROD1 Wiper trip to window. Tie in. Correct + 1.5'. 18:00 - 20:15 2.25 DRILL P PROD1 Drilling Zone IB at HS TF. Changed landing TVD to 8,660 ft ROP = 50-80 fph. Qp = 2.6 / 2.6 bpm CTP = 3,150/3,600 psi. WOB = 4k-1 Ok Lossing 0.2-0.3 bpm of fluid Landed at 9,525 ft / 8,662 ft TVD at 93 deg 20: 15 - 22:00 1.75 DRILL P PROD1 POOH 22:00 - 23:30 1.50 DRILL P PROD1 Changed out Bit, set new motor to 1.04 deg, MWD pulsar and serviced SLB MHA. 23:30 - 00:00 0.50 DRILL P PROD1 RIH, SHT at 500 ft TRSSSV at 4,000 psi IA lOA = 630 / 20 psi 4/24/2005 00:00 - 00:30 0.50 DRILL P PROD1 Orienter test at ,1800 ft. Had some problems getting tool to work 00:30 - 01 :05 0.58 DRILL P PROD1 Sperry's computer will not sink up with the tool in the hole. RIH and work on sinking the computers 01 :05 - 01 :20 0.25 DRILL P PROD1 Stopped at 5,050 ft and try sinking computers again. SINKED with good detection 01 :20 - 02:20 1.00 DRILL P PROD1 RIH. Added l' at flag Oriented TF to 155R, RIH and tagged, oriented to 165L tagged, orient 1 click, 154L Fell in with 0.75 bpm. RIH. Tagged PTD @ 9,525 ft 02:20 - 02:45 0.42 DRILL P PROD1 Orient TF to LS to drop hole angle to 88 deg 02:45 - 04:00 1.25 DRILL P PROD1 Drilling Zone IB at LS TF (161 R). Stilllossing fluid at 0.2 to 0.4 bpm ROP = 50 fph. Qp = 2.78 / 2.62 bpm CTP = 3,350 /3,650 WOB = 4k-10k Started mud swap at 9,527 ft 03:00 hrs Working to get STC QDM BC bit to drill. 04:00 - 04:05 0.08 DRILL P PROD1 Got 1 click at 9,564 ft 04:05 - 04:50 0.75 DRILL P PROD1 Drilling Zone IB at LS TF (171 L). Stilllossing fluid at 0.2 to 0.4 bpm ROP = 50 fph. Qp = 2.78 / 2.62 bpm CTP = 3,350/3,650 WOB = 4k·10k 04:50 . 05:00 0.17 DRILL P PROD1 Orient TF around to 90L 05:00·06:15 1.25 DRILL P PROD1 Drilling Zone IB at LS TF (103L-90L). Stilllossing fluid at 0.2 to 0.4 bpm Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/24/2005 05:00 - 06:15 1 .25 DRI LL P PROD1 Drill to 9634' MD. ROP = 40-70 fph. Qp = 2.78 / 2.62 bpm CTP = 3,350 /3,650 WOB = 2k-5k 06:15 - 07:00 0.75 DRILL PROD1 Wiper trip to window. 07:00 - 10:45 3.75 DRILL PROD1 Drilling Zone IB at LS TF (60 L). Losing fluid at approx 0.1 bpm. Drill to 9800' MD. ROP = 40-70 fph. Qp = 2.65 / 2.71 bpm CTP = 3,150 /3,400 WOB = 4k-10k 10:45 - 11 :45 1.00 DRILL PROD1 Wiper trip to window. 11 :45 - 12:00 0.25 DRILL PROD1 Orient TF 90 R 12:00 - 12:30 0.50 DRILL PROD1 Drilling ahead to 9845' MD. - Losses: 0.1 bpm. - ROP = 60-90 fph. - 2.6 / 2.6 bpm at 3500 psi - 3,100 free spin - WOB = 4k-10k 12:30 - 12:45 0.25 DRILL PROD1 Orient TF to 60R. 12:45 - 14:00 1.25 DRILL PROD1 Drill ahead to 9862' MD. - Losss at .01-.2 bpm - ROP = 60-90 fph. - 2.6/2.6 bpm at 3500 psi - 3,100 free spin - WOB = 4k-10k 14:00 - 14:30 0.50 DRILL PROD1 Attempt to drill ahead at 9860' MD, stall repeatedly. Conduct BHA wiper trip as required. Concerned it may be top of Kavik. Orient highside to drill ahead. 14:30 - 15:30 1.00 DRILL PROD1 Drill ahead at 20R, made 20 feet. Decide to orient 90R, would not drill. Orient back to 20R to continue drilling ahead. 15:30 - 16:30 1.00 DRILL PROD1 Drill ahead at 40R, orienting to 90R trying to keep drilling without stalling. Suspected we must have been drilling shale; however, GR reading shows sand. Made 100' since noon. Decision to POOH for bit. 16:30 - 18:45 2.25 DRILL PROD1 POOH. 18:45 - 19:30 0.75 DRILL PROD1 Changed out bit, checked HP motor (OK) changed out MWD probe 19:30 - 21:00 1.50 DRILL PROD1 RIH, SHT and orienter test MWD. RIH passed WS at 135 L. No Problem 21 :00 - 21 :30 0.50 DRILL PROD1 Tie-in to RA Marker from 8902 ft Corrected +3 21 :30 - 22:00 0.50 DRILL PROD1 RIH 22:00 - 22:15 0.25 DRILL PROD1 Tagged bottom at 9,908 ft corrected. Orient TF around to 130 L 22:15 - 00:00 1.75 DRILL PROD1 DrillingLower Zone 1A @ 130-90 L TF. Losing fluid at approx 0.2 bpm. Motor stalling as bit before. Took off drilling, was in a shale ROP = 70 to 125 fph. Qp = 2.65 /2.71 bpm CTP = 3,150 /3,400 WOB = 4k-10k 4/25/2005 00:00 - 00:25 0.42 DRILL P PROD1 Drilling Lower Zone 1 A @ 130-80 L TF ROP = 70 to 145 fph. Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/25/2005 00:00 - 00:25 0.42 DRILL P PROD1 Qp = 2.65 / 2.63 bpm. Still losing 0.1 to 2 bpm CTP = 3,150 /3,400 Lots stacking at 130 ft drilled, working to get WOB 00:25 - 01 :30 1.08 DRILL P PROD1 Wiper trip at 10,034 ft 01 :30 - 01 :50 0.33 DRILL P PROD1 Tagged bottom. Orient TF to 125R 01:50 - 02:10 0.33 DRILL P PROD1 Drilling Lower Zone 1 A @ 120R TF ROP = 110fph. Qp = 2.65 / 2.63 bpm. Still losing 0.1 to 2 bpm CTP = 3,150 /3,525 Added 100 bbl new mud to system 02:10 - 02:30 0.33 DRILL P PROD1 PU to pump up survey, Getting a lot of vibrations down hole Oriented around 02:30 - 02:58 0.47 DRILL P PROD1 Drilling Lower Zone 1A @ 96R TF. TF rolled around to 72L TF at 10,110 ft PU and TF wrapped around 240 deg ROP= >110fph. Qp = 2.61 /2.63 bpm. Still losing 0.1 to 2 bpm CTP = 3,050/3,425 02:58 - 03:05 0.12 DRILL P PROD1 Orient TF around to get back to 90Rand maintain 88 to 89 degs 03:05 - 03:20 0.25 DRILL P PROD1 Drilling Lower Zone 1A @ 85-120R TF. TF rolling right as we drill, hard to keep TF on righ side. ROP = > 120 fph. Qp = 2.61 /2.63 bpm. Still losing 0.1 to 2 bpm CTP = 3,050 /3,525 03:20 - 03:36 0.27 DRILL P PROD1 Orient TF around from 150L to 89R 03:36 - 03:45 0.15 DRILL P PROD1 Drilling Lower Zone 1A @ 90R TF. ROP = 150-180 fph. Qp = 2.61 /2.63 bpm. Still losing 0.1 to 2 bpm CTP = 3,050 /3,425 03:45 - 05:20 1.58 DRILL P PROD1 Wiper trip to WS. Clean 05:20 - 07:15 1.92 DRILL P PROD1 Drilling Lower Zone 1A @ 90R TF to 10,330' MD. At 10,241ft, ROP slowed to <70 fph ROP = >100 fph. Qp = 2.61 /2.63 bpm. CTP = 3,050/3,625 07:15 - 09:00 1.75 DRILL P PROD1 Wiper trip to window. 09:00 - 09:30 0.50 DRILL P PROD1 Orient TF to 30R. 09:30 - 09:45 0.25 DRILL P PROD1 Drill ahead to 10,375' MD. - 2.6/2.6 bpm at 3600 psi - 0.1 bpm losses - 3200 free spin - >100 fph ROP -WOB=10k 09:45 - 10:00 0.25 DRILL P PROD1 Orient to 90L 10:00 - 10:30 0.50 DRILL P PROD1 Drill ahead to 10,450' MD. - 2.6/2.6 bpm at 3800 psi - 0.1 bpm losses - 3200 free spin - > 1 00 fph ROP - WOB = 10k 10:30 - 12:15 1.75 DRILL P PROD1 Wiper trip to window - Slight overpull at 10,200' Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/25/2005 12:15 - 13:30 1.25 DRILL P PROD1 Drill ahead to 10,557' MD. - 80L TF - 2.6 / 2.6 at 3600 psi - 3200 psi free spin. - 0.1 bpm losses. - 10k WOB. - >100 fph ROP - ROP slows at 10,500' MD to -80 fph. 13:30 - 14:00 0.50 DRILL P PROD1 Orient 70R. - While orienting, stuck pipe (differential). Follow SOP. Free up after relaxing pipe. No crude required. 14:00 - 14:30 0.50 DRILL P PROD1 Drill ahead to 10,600'. 14:30 - 16:30 2.00 DRILL P PROD1 Wiper to window. 16:30 - 17:15 0.75 DRILL P PROD1 Drill ahead to 10,661' MD. - 45R TF - 2.6/2.6 at 3700 psi - 3300 psi free spin. - 0.1 -0.2 bpm losses. '10k WOR - 80-120 fph ROP 17:15 - 17:30 0.25 DRILL P PROD1 Orient to 70 R 17:30 - 18:00 0.50 DRILL P PROD1 Drill ahead 10,695' MD. - 2.63/2.58 at 3700 psi - 3350 psi free spin. - 0.1 -0.2 bpm losses. - 10k WOB. - 80-120 fph ROP 18:00 - 18:50 0.83 DRILL P PROD1 Orient TF 70L Having trouble keeping the TF at 100L. 18:50 - 19:00 0.17 DRILL P PROD1 Drilling Lower Zone 1A @ 100L TF ROP = 165fph. Qp = 2.50/ 2.46 bpm. Still losing 0.1 to 2 bpm CTP = 3,150/3,825 19:00 - 20:10 1.17 DRILL P PROD1 Wiper trip, tie-in Pulled a little tight at 10,310 ft and 10,260 20: 10 - 20:40 0.50 DRILL P PROD1 Tie in from 8,900 ft Corrected +9 ft 20:40 - 21 :45 1.08 DRILL P PROD1 RIH slow at reduced Qp. Vac truck loading at MI Adding 200 bbl to mud system Tagged and fell through at 10,147 ft, reduced Qp fell through 21 :45 - 22:00 0.25 DRILL P PROD1 Orient TF to 100L 22:00 - 00:00 2.00 DRILL P PROD1 Drilling Lower Zone 1 A @ 112L-90L-28L TF ROP = >100 fph. Qp = 2.50/2.46 bpm. Still losing 0.1 to 2 bpm CTP = 3,150/3,525 Crossed fault at approximately 10,687 ft, drop TVD 2 ft using 87 deg hole angle. 4/26/2005 00:00 - 00:10 0.17 DRILL P PROD1 Drilled to 10,900 ft 00:10 - 02:27 2.28 DRILL P PROD1 Wiper trip Little ratty at 10,320 ft when BHA coming through shale section at 10,235 to 10,260 ft. 02:27 - 02:40 0.22 DRILL P PROD1 Drilling Lower Zone 1 A @ 5L TF R Shale ROP = >100 fph. Qp = 2.60 / 2.63 bpm. Lossing 0.1-0.2 bpm CTP = 3,150 /3,725 Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/26/2005 02:27 - 02:40 0.22 DRILL P PROD1 Working with >100 deg reactive torque while drilling 02:40 - 03:15 0.58 DRILL P PROD1 Oriented TF , Drilling Lower Zone 1 A @ 100R. Target TVD at 8674 ft. This area is not good, need to climb to 8670 ft ROP = >100 fph. Qp = 2.60 / 2.63 bpm. Lossing 0.1-0.2 bpm CTP = 3,150 /3,725 03:15 - 03:30 0.25 DRILL P PROD1 Orient TF around to HS to climb 03:30 - 03:45 0.25 DRILL P PROD1 Drilling Lower Zone 1 A @ 17R. ROP = >130 fph. Qp = 2.60/2.63 bpm. Lossing 0.1-0.2 bpm CTP = 3,150/3,725 Started mud swap at 03:30 hrs 03:45 - 03:55 0.17 DRILL P PROD1 Orient TF to 85R after drilling at HS for 32 ft 03:55 - 04:00 0.08 DRILL P PROD1 Drilling Lower Zone 1A @ TF 74-90 R. 60 API sand ROP = >140 fph. Qp = 2.60/2.63 bpm. Lossing 0.1-0.2 bpm CTP = 3,150 /3,725 04:00 - 04:15 0.25 DRILL P PROD1 Orient TF to Left Side 04:15 - 04:30 0.25 DRILL P PROD1 Drilling Lower Zone 1A @ TF 74-90 L. 60-70 API sand ROP = >140 fph. Qp = 2.60 / 2.63 bpm. Lossing 0.1-0.2 bpm CTP = 3,150 /3,725 04:30 - 07:00 2.50 DRILL P PROD1 Wiper trip to WS 07:00 - 07:15 0.25 DRILL P PROD1 Drill ahead 11080' MD. - Orient TF to 60L. - ROP = 120 fph - 2.8 / 2.8 bpm at 3700 psi - Free spin 3450 psi. - 0.1 - 0.2 bpm losses 07:15 - 07:45 0.50 DRILL P PROD1 Orient to 100L. 07:45 - 09:00 1.25 DRILL P PROD1 Drill ahead to 11,200' MD - Orient TF to 60L. - ROP = 120 fph - 2.8 / 2.8 bpm at 3700 psi - Free spin 3450 psi. - 0.1 - 0.2 bpm losses 09:00 - 11 :45 2.75 DRILL P PROD1 Wiper trip to window. - Tie in. +8' correction. - Hole in good condition. 11:45 - 12:00 0.25 DRILL P PROD1 Orient TF to 75L 12:00 - 13:40 1.67 DRILL P PROD1 Drill ahead to 11350 - ROP = 120 fph - 2.5 / 2.5 bpm at 3400 psi - Free spin 3000 psi. - 0.1 - 0.2 bpm losses 13:40 - 16:15 2.58 DRILL P PROD1 Wiper to window. Clean trip. RIH. MW at 10260. 2.5 bpm @3100 PSI. 16:15 - 19:00 2.75 DRILL P PROD1 Drill ahead - ROP = 120 fph - 2.5 / 2.5 bpm at 3650 psi - Free spin 3300 psi. - 0.1 - 0.2 bpm losses 19:00 - 21 :15 2.25 DRILL P PROD1 Wiper to window. Clean trip. RIH clean. 2.5 bpm @3100 PSI. Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/26/2005 21:15 - 22:30 1.25 DRILL P PROD1 Drilling, 2.5/2.4 bpm, 10 bph mud loss, 3150 - 3800 psi, 75R, 92 deg incl, 140 fph, 22:30 - 00:00 1.50 DRILL P PROD1 Drilling, 2.5/2.4 bpm, 10 bph mud loss, 3150 - 3800 psi, 75L, 92 deg incl, 80 fph, 4/27/2005 00:00 - 01 :40 1.67 DRILL P PROD1 Wiper trip to window. Clean hole. 01 :40 - 02:00 0.33 DRILL P PROD1 Log GR tie-in at RA tag. Added 10' to CTD. 02:00 - 03:15 1.25 DRILL P PROD1 RIH. Reamed shales from 11650-11740'. Tagged at 11,666'. 03:15 - 05:15 2.00 DRILL P PROD1 Drilling Z1A. 2.5/2.4 bpm, 10 bph fluid loss, 3250 - 3900 psi, 90L, 91 deg incl, 120 fph. Made 2 short trips to ream shales at 11650-11740'. Stacking wt and getting overpulls in shales. Drilled to TO of 11,800'. 05:15 - 06:45 1.50 DRILL P PROD1 Wiper trip to window. 06:45 - 07:00 0.25 DRILL P PROD1 Tie - in correction 6'. 07:00 - 08:20 1.33 DRILL P PROD1 RIH on wiper trip. Tag at 11804. No problem form shales11630 - 11730. 08:20 - 10:45 2.42 DRILL P PROD1 POH to window lay in new mud for liner running. 10:45 - 11 :00 0.25 DRILL P PROD1 POH to surface. 11 :00 - 11 :30 0.50 DRILL P PROD1 LD BHA. Bit graded 0-2-1. 11:30 -12:00 0.50 DRILL P PROD1 Clear floor and PU baker tool from beaver slide. 12:00 - 12:15 0.25 CASE P RUNPRD PJSM for picking up and running liner. 12:15 - 16:30 4.25 CASE P RUN PRO PU and run liner 2-7/8 X 3-3/16. 16:30 - 17:00 0.50 CASE P RUN PRO PU injector. MU coil connector 17:00 - 18:30 1.50 CASE P RUN PRO RIH with liner. Corrected +8' at flag. 18:30 - 18:45 0.25 CASE P RUNPRD RIH thru window clean. 39K up wt, 19K down wt. RIH in open hole at 70 fpm, 0.2 bpm, 1500 psi, 13K down wt at 11400'. Landed liner at TO at 11,805' CTD. Pick up and set down 3 times. Up wt = 48K. Liner is at TO of 11,804'. 18:45 - 19:30 0.75 CASE P RUN PRO Insert 5/8" Steel ball and displace with FloPro. 2.1 bpm, 2530 psi. Ball on seat at 49.4 bbls, sheared at 4000 psi. Picked up clean off of liner at 35K. Stacked 10K on liner. 19:30 - 21 :45 2.25 CEMT P RUN PRO Circ. well to 2% KCL water. Haul FloPro to MI plant for reconditioning. Make up 50 bbl of 2# Biozan water. 21 :45 - 22:00 0.25 CEMT P RUN PRO SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. 22:00 - 22:30 0.50 CEMT P RUN PRO Batch mix cement to 15.8 PPG. Press test cement line to 4000 psi. 22:30 - 23:00 0.50 CEMT P RUN PRO Stage 42 bbls of 15.8 ppg G Cement. 2/1.7 bpm, 1600-2100 psi. Insert dart. Clean cement line with Biozan water. Zero in-totalizer. Cement has 5 hour thickening time 23:00 - 23:35 0.58 CEMT P RUNPRD Displace Dart and Cement with 2# Biozan water using rig pumps. 10 bbls displ, 3.2 bpm, 2300 psi, catch fluid. 20 bbls displ, 2.8 bpm in, 2.5 bpm out, 1900 psi, 30 bbls displ, 2.7 bpm in, 2.4 bpm out, 1500 psi Zero out-Micro with cement at shoe at 36 bbls displ. 40 bbls displ, 2.8 bpm in, 2.4 bpm out, 2100 psi. 50 bbls displ, 1.5 bpm in, 1.3 bpm out, 1200 psi. 57.9 bbls displ, Dart on LWP, sheared at 3800 psi. Printed: 5/2/2005 7:57:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 4/27/2005 23:00 - 23:35 0.58 CEMT P RUN PRO 60 bbls displ, 2.7 bpm in, 2.4 bpm out, 2900 psi. 70 bbls displ, 2.7 bpm in, 2.5 bpm out, 3250 psi, 75 bbls displ, 2.7 bpm in, 2.5 bpm out, 3250 psi. 76 bbls displ, 0.9 bpm in, 0.8 bpm out, 1700 psi. 77.6 bbls displ, bumped plug with 1700-2430 psi, calc vol to bump was 78.3 bbls. Out totalizer showed 38.6 bbls returned. Lost 3 bbls. Still had slight fluid loss just prior to bumping plug. 23:35 - 00:00 0.42 CEMT P RUNPRD Hold press 5 min. Bleed pressure to zero, check floats, OK. Sting out of liner with 32.5K up wt. POH replacing CT voidage only with Biozan water. 4/28/2005 00:00 - 01 :30 1.50 CEMT P RUN PRO POH with Baker CTLRT. Replace coil voidage only. 01 :30 - 02:00 0.50 CEMT P RUNPRD Layout Baker CTLRT. Recovered all tools. Well fluid level at about 30 ft below rig floor. 02:00 - 04:30 2.50 CEMT P RUN PRO WOC. Cement had 5 hour thickening time. Fluid level in well at about 100 ft. Lost 1 bbl in 3 hrs. 04:30 - 04:45 0.251 CEMT P RUN PRO SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS Memory CNUGR. 04:45 - 07:30 2.75 EVAL P LOWER1 M/U 2.30" diamond mill, straight motor, XO, 2 Jts 1 1/4" CSH, XO, SWS Carrier, Circ Sub, Hyd Disc, XO, 53 stds of CSH workstring, XO, Hyd disc, NRJ and CTC. BHA OAL = 3383'. 07:30 - 08:30 1.00 EVAL P LOWER1 RIH to 7000. 08:30 - 09:00 0.50 EVAL N WAIT LOWER1 Wait on cement. 09:00 - 11 :20 2.33 EVAL P LOWER1 RIH Log at 30 ft/min from 8400 to PBTD at 11764. 11 :20 - 13:00 1.67 EVAL P LOWER1 Log up to 8400'. POH to CSH. 13:00 - 15:00 2.00 EVAL P LOWER1 Stand back 54 stands of 1-1/4" CSH. 15:00 - 16:00 1.00 EVAL P LOWER1 LD Logging tools and down load data. Flush stack. 16:00 - 17:00 1.00 PERFOB P LOWER1 Load pipe shed. Review logging data found time data shift problem. Will fax initial data to town Geo. 17:00 - 18:00 1.00 PERFOB P LOWER1 Test liner lap to 2350 lost 150 psi in 30 min. Passed. 18:00 - 19:00 1.00 PERFOB N WAIT LOWER1 Wait on orders from town. Geo waiting for logs and looking at logs. 19:00 - 19:45 0.75 PERFOB P LOWER1 Prep rig floor to run perf guns. 19:45 - 20:00 0.25 PERFOB P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 2" perf guns. 20:00 - 21 :30 1.50 PERFOB P LOWER1 M/U SWS 2" Perf guns and blanks as per perforating program. Guns 1 blanks = 558.3 ft. 21:30 - 23:15 1.75 PERFOB P LOWER1 M/U Hyd Discon, xo, 45 stds of CSH and SWS MHA. OAL = 3351'. 23:15 - 00:00 0.75 PERFOB P LOWER1 RIH with SWS 2", PowerJet Perforating guns, loaded at 6 SPF. 4/29/2005 00:00 - 01 :30 1.50 PERFOB P LOWER1 RIH with 2" SWS PowerJet perf guns loaded at 6 SPF. Circ at .3 bpm, 180 psi. Tag PBTD of 11,763' at 11,761' up depth. Added 2 ft to CTD. Pull up to 11,595'. Circ. 10 bbls of FloPro HV perf pill into coil. 01 :30 - 02:20 0.83 PERFOB P LOWER1 Insert 1/2" AL Ball and displace with FloPro perf pill. Pumped 10 bbl of FloPro ahead and 5 behind ball. Circ. at 1.8 bpm, 1700 psi, slow to 1 bpm at 47 bbls. Ball on seat at 61 bbls. Fired guns on depth while pulling at 6 fpm. Firing head fired at 3400 psi. Good indication that guns fired. Printed: 5/2/2005 7:57:58 AM POH. circ at 1.5 bpm, 1500 psi. Flagged coil at 7,000' EOP for second perforating run. Load second set of guns in pipe shed. Stand back 45 stds of CSH workstring. SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired perf guns. Layout SWS fired perf guns. PJSM running pref guns. PU 550 of perforating guns PU 45 stands 1-1/4 CSH. RIH correct to flag 1.3'+. RIH to 10794 ball drop position. Pump 10 bbl perf pill. Launch ball with 5 bbl pill and displace with to firing head. Circulate 2.5 bpm at 2750 psi. At 50 bbl slow to 1. bpm @ 740 psi. Ball on seat at 55.5 bbl. Guns fired at 3200 psi on the fly. Good indication guns fired. LOWER1 POH to CSH. LOWER1 Stand back45 stands CSH. LOWER1 PJSM LD guns LOWER1 LD guns, all shots fired. A total of 900 ft of perforations were shot at 9 SPF. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-31 18-31 DRILL+COMPLETE NORDIC CALISTA NORDIC 1 4/29/2005 02:20 - 04:15 1.92 PERFOB P LOWER1 04:15 - 05:30 1.25 PERFOB P LOWER1 05:30 - 05:45 0.25 PERFOB P LOWER1 05:45 - 08:30 2.75 PERFOB P LOWER1 08:30 - 09:30 1.00 PERFOB P LOWER1 09:30 - 11 :00 1.50 PERFOB P LOWER1 11 :00 - 12:45 1.75 PERFOB P LOWER1 12:45 - 13:10 0.42 PERFOB P LOWER1 13:10 - 14:30 14:30 - 16:10 16:10 - 16:20 16:20 -18:30 1.33 PER FOB P 1.67 PERFOB P 0.17 PER FOB P 2..17 PERFOB P 18:30 - 19:45 1.25 WHSUR P POST 19:45 - 20:00 0.25 RIGD P POST 20:00 - 21 :00 1.00 RIGD P POST 21 :00 - 21 :30 0.50 RIGD P POST 21 :30 - 23:30 2.00 RIGD P POST 23:30 - 00:00 0.50 RIGD P POST Start: 4/18/2005 Rig Release: 4/29/2005 Rig Number: 1 Spud Date: 8/2/1995 End: 5/2/2005 PERFORATED INTERVALS: 10140-10230', 10270-10290', 10320-10580', 10600-10780', 11 040-11230' 11270-11320', 11440-11490', 11530-11590'. RIH and freeze protect 4-1/2" tubing from 2500' to surface with 23 bbls of MEOH. Close master valve. SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2 and displacing coil. Displace coil to N2. Bleed pressure to zero. Change out coil packoff. Stand back injecter head. Nipple down BOPE and clean rig pits. Nipple up tree cap and pressure test. RELEASED RIG AT 2400 HRS. 04/29/2005. 9 DAYS, 221/2 HOURS FROM RIG ACCEPT TO RIG RELEASE. Get ready for rig move to F-02A. 18 mile, derrick up rig move. Printed: 5/2/2005 7:57:58 AM I 1O~3/4" 7 ·5If3" ID 11III TRSV I ST 1 3124 3706 2 6297 3 8439 HESS- TMPDX x Halliburton Sperry-Sun North Slope Alaska BPXA 18-31A . Job No. AKMW3667579, Surveyed: 27 April, 2005 Survey Report 19 May, 2005 Your Ref: API 500292257901 Surface Coordinates: 5960305.65 N, 691711.72 E (70· 17' 45.9621" N, 148· 26' 51.0049" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 54.00ft above Mean Sea Level . SP'E!ï'ï"Y-S'Uï! Ei"RiL LING· !Ii ë¡iiv Ie:!5 5 A Halliburton Company Survey Ref: svy4612 Halliburton Sperry-Sun Survey Report fqr 18-31A Your Ref: API 500292257901 Job No. AKMW3667579, Surveyed: 27 April, 2005 North Slope Alaska BPXA 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) (0/100ft) 8774.66 34.600 327.700 8221.37 8275.37 1505.43 N 837.37 W 5961789.23 N 690836.22 E 965.39 Tie On Point 8847.00 34.450 328.460 8280.97 8334.97 1540.23 N 859.05 W 5961823.47 N 690813.67 E 0.630 990.02 Window Point 8882.51 29.180 322.000 8311.14 8365.14 1555.63 N 869.64 W 5961838.59 N 690802.68 E 17.652 1001.91 8915.19 26.980 316.000 8339.98 8393.98 1567.24 N 879.70 W 5961849.94 N 690792.33 E 10.947 1012.94 8947.30 28.480 310.000 8368.41 8422.41 1577.41 N 890.62 W 5961859.83 N 690781.15 E 9.865 1024.72 8979.92 29.710 304.300 8396.92 8450.92 1586.96 N 903.26 W 5961869.06 N 690768.27 E 9.292 1038.14 . 9010.43 32.300 299.070 8423.07 8477.07 1595.19 N 916.64 W 5961876.94 N 690754.69 E 12.242 1052.18 9043.83 35.070 294.210 8450.87 8504.87 1603.46 N 933.20 W 5961884.79 N 690737.93 E 11.567 1069.40 9073.51 36.650 285.780 8474.93 8528.93 1609.37 N 949.51 W 5961890.28 N 690721.47 E 17.457 1086.16 9104.58 40.250 280.150 8499.27 8553.27 1613.66 N 968.32 W 5961894.09 N 690702.55 E 16.153 1105.28 9136.48 43.940 276.640 8522.94 8576.94 1616.76 N 989.47 W 5961896.65 N 690681.33 E 13.715 1126.62 9167.14 47.990 274.530 8544.25 8598.25 1618.89 N 1011.40 W 5961898.22 N 690659.35 E 14.104 1148.65 9197.28 51.770 270.660 8563.67 8617.67 1619.91 N 1034.42W 5961898.65 N 690636.32 E 15.924 1171.67 9228.31 54.050 261.870 8582.41 8636.41 1618.28 N 1059.07 W 5961896.39 N 690611.71 E 23.750 1196.08 9261.16 59.060 261.520 8600.51 8654.51 1614.32 N 1086.19W 5961891.73 N 690584.71 E 15.277 1222.75 9291.91 65.130 263.980 8614.89 8668.89 1610.90 N 1113.13 W 5961887.64 N 690557.86 E 20.966 1249.29 9321.53 69.780 265.740 8626.25 8680.25 1608.46 N 1140.37 W 5961884.50 N 690530.70 E 16.630 1276.21 9356.16 73.740 266.270 8637.08 8691.08 1606.17 N 1173.17 W 5961881.37 N 690497.96 E 11.527 1308.69 9384.85 74.350 262.400 8644.97 8698.97 1603.45 N 1200.61 W 5961877.95 N 690470.60 E 13.142 1335.80 9418.31 77.260 261.170 8653.18 8707.18 1598.81 N 1232.72 W 5961872.50 N 690438.62 E 9.399 1367.37 9450.60 81.910 259.410 8659.01 8713.01 1593.45 N 1264.01 W 5961866.34 N 690407.48 E 15.366 1398.08 9481.04 86.400 258.530 8662.11 8716.11 1587.66 N 1293.72 W 5961859.79 N 690377.92 E 15.028 1427.17 9515.96 91.580 256.420 8662.73 8716.73 1580.09 N 1327.79 W 5961851.36 N 690344.06 E 16.016 1460.45 . 9549.59 89.650 258.880 8662.37 8716.37 1572.90 N 1360.64 W 5961843.33 N 690311.40 E 9.297 1492.55 9580.14 86.400 256.600 8663.42 8717.42 1566.42 N 1390.47 W 5961836.09 N 690281.75 E 12.992 1521.70 9610.80 87.360 253.960 8665.09 8719.09 1558.64 N 1420.07 W 5961827.56 N 690252.35 E 9.150 1550.52 9640.79 89.820 249.570 8665.83 8719.83 1549.26 N 1448.54 W 5961817.46 N 690224.13 E 16.775 1578.06 9673.94 90.790 244.120 8665.65 8719.65 1536.23 N 1479.01 W 5961803.66 N 690194.01 E 16.698 1607.27 9709.28 89.300 241.300 8665.62 8719.62 1520.03 N 1510.41 W 5961786.66 N 690163.03 E 9.025 1637.14 9745.31 89.740 245.170 8665.92 8719.92 1503.81 N 1542.57 W 5961769.62 N 690131.29 E 10.810 1667.77 9777.33 89.560 248.340 8666.12 8720.12 1491.17 N 1571.99 W 5961756.24 N 690102.21 E 9.916 1695.97 9811.01 87.800 254.840 8666.90 8720.90 1480.54 N 1603.92 W 5961744.80 N 690070.56 E 19.989 1726.85 9842.28 88.240 256.950 8667.98 8721.98 1472.93 N 1634.23 W 5961736.41 N 690040.45 E 6.889 1756.38 9879.48 91.670 264.160 8668.01 8722.01 1466.83 N 1670.89 W 5961729.38 N 690003.96 E 21.461 1792.38 9914.88 92.460 264.680 8666.73 8720.73 1463.39 N 1706.10W 5961725.04 N 689968.85 E 2.671 1827.15 19 May, 2005 - 14:28 Page 20f 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-31A Your Ref: API 500292257901 Job No. AKMW3667579, Surveyed: 27 April, 2005 North Slope Alaska BPXA 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) (0/100ft) 9947.22 89.560 260.640 8666.16 8720.16 1459.26 N 1738.16W 5961720.10 N 689936.90 E 15.375 1858.73 9986.38 89.650 255.370 8666.43 8720.43 1451.12 N 1776.45 W 5961710.99 N 689898.83 E 13.459 1896.17 10048.17 89.470 251.500 8666.91 8720.91 1433.51 N 1835.66 W 5961691.87 N 689840.09 E 6.270 1953.62 10090.44 88.240 254.140 8667.75 8721.75 1421.03 N 1876.04 W 5961678.36 N 689800.05 E 6.889 1992.75 10122.68 89.650 259.940 8668.34 8722.34 1413.80 N 1907.43 W 5961670.34 N 689768.84 E 18.511 2023.40 10164.00 88.510 260.460 8669.01 8723.01 1406.77 N 1948.15 W 5961662.27 N 689728.32 E 3.032 2063.34 . 10199.18 89.380 267.140 8669.66 8723.66 1402.98 N 1983.09 W 5961657.58 N 689693.48 E 19.145 2097.83 10229.80 89.210 272.240 8670.03 8724.03 1402.81 N 2013.70 W 5961656.64 N 689662.89 E 16.664 2128.30 10260.24 89.300 277.870 8670.43 8724.43 1405.49 N 2044.01 W 5961658.55 N 689632.53 E 18.496 2158.73 10293.20 88.940 282.440 8670.94 8724.94 1411.30 N 2076.44 W 5961663.53 N 689599.96 E 13.907 2191.54 10325.86 88.680 286.300 8671.61 8725.61 1419.40N 2108.06 W 5961670.82 N 689568.14 E 11.843 2223.75 10357.75 91.410 290.350 8671.59 8725.59 1429.43 N 2138.33 W 5961680.07 N 689537.63 E 15.315 2254.77 10392.35 91.760 290.350 8670.63 8724.63 1441.45 N 2170.76 W 5961691.26 N 689504.90 E 1.012 2288.13 10425.60 90.790 285.600 8669.89 8723.89 1451.71 N 2202.37 W 5961700.71 N 689473.04 E 14.577 2320.51 10458.24 90.260 282.960 8669.59 8723.59 1459.76 N 2233.99 W 5961707.95 N 689441 .22 E 8.249 2352.72 10491.35 89.470 277.340 8669.67 8723.67 1465.59 N 2266.57 W 5961712.95 N 689408.50 E 17.140 2385.68 10524.00 90.090 278.040 8669.80 8723.80 1469.96 N 2298.93 W 5961716.49 N 689376.05 E 2.864 2418.29 10556.58 89.910 272.590 8669.80 8723.80 1472.98 N 2331.36 W 5961718.68 N 689343.55 E 16.737 2450.86 10591.08 90.700 280.330 8669.61 8723.61 1476.85 N 2365.61 W 5961721.68 N 689309.21 E 22.551 2485.32 10623.87 91.140 285.070 8669.09 8723.09 1484.06 N 2397.58 W 5961728.07 N 689277.06 E 14.516 2517.80 10653.26 89.120 287.710 8669.02 8723.02 1492.35 N 2425.78 W 5961735.64 N 689248.67 E 11.310 2546.61 10687.82 88.770 293.340 8669.66 8723.66 1504.46 N 2458.12 W 5961746.92 N 689216.02 E 16.319 2579.89 10722.60 89.560 291.750 8670.16 8724.16 1517.80N 2490.24 W 5961759.43 N 689183.57 E 5.104 2613.05 . 10759.07 90.610 290.880 8670.11 8724.11 1531.05 N 2524.21 W 5961771.82 N 689149.27 E 3.739 2648.05 10791.68 88.680 287.540 8670.31 8724.31 1541.78 N 2555.00 W 5961781.76 N 689118.22 E 11.829 2679.66 10822.96 88.330 285.070 8671.13 8725.13 1550.56 N 2585.01 W 5961789.77 N 689088.00 E 7.973 2710.32 10854.50 87.630 282.260 8672.24 8726.24 1558.00 N 2615.64 W 5961796.43 N 689057.19 E 9.176 2741.47 10887.68 88.070 275.930 8673.49 8727.49 1563.24 N 2648.36 W 5961800.83 N 689024.35 E 19.110 2774.53 10920.77 90.880 279.800 8673.79 8727.79 1567.77 N 2681.13 W 5961804.52 N 688991.47 E 14.452 2807.57 10951.80 90.350 285.780 8673.45 8727.45 1574.63 N 2711.37 W 5961810.61 N 688961.06 E 19.346 2838.29 10986.75 91.670 288.940 8672.84 8726.84 1585.06 N 2744.72 W 5961820.18 N 688927.46 E 9.797 2872.42 11015.43 92.280 290.880 8671.85 8725.85 1594.82 N 2771.67 W 5961829.25 N 688900.27 E 7.087 2900.12 11048.54 90.700 289.640 8670.99 8724.99 1606.28 N 2802.72 W 5961839.92 N 688868.94 E 6.065 2932.05 11078.02 92.460 288.590 8670.18 8724.18 1615.93 N 2830.56 W 5961848.85 N 688840.86 E 6.951 2960.63 11110.77 90.260 285.950 8669.40 8723.40 1625.65 N 2861.82 W 5961857.77 N 688809.36 E 10.491 2992.62 19 May, 2005· 14:28 Page 30f5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-31A Your Ref: API 500292257901 Job No. AKMW3667579, Surveyed: 27 April, 2005 North Slope Alaska BPXA 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) (0/100ft) 11140.22 89.820 286.130 8669.38 8723.38 1633.79 N 2890.12 W 5961865.18 N 688780.86 E 1.614 3021.52 11172.40 89.120 281.210 8669.68 8723.68 1641.39 N 2921.38 W 5961871.99 N 688749.42 E 15.442 3053.32 11213.86 89.210 282.440 8670.28 8724.28 1649.88 N 2961.96 W 5961879.44 N 688708.64 E 2.974 3094.48 11249.69 89.300 277.340 8670.75 8724.75 1656.03 N 2997.24 W 5961884.69 N 688673.21 E 14.235 3130.17 11277.43 92.280 273.650 8670.36 8724.36 1658.69 N 3024.84 W 5961886.64 N 688645.55 E 17.096 3157.90 11308.79 91.930 280.330 8669.21 8723.21 1662.50 N 3055.93 W 5961889.66 N 688614.38 E 21.316 3189.20 . 11339.10 90.610 284.020 8668.54 8722.54 1668.89 N 3085.54 W 5961895.29 N 688584.61 E 12.927 3219.26 11369.48 92.460 289.470 8667.72 8721.72 1677.64 N 3114.61 W 5961903.29 N 688555.33 E 18.938 3248.98 11403.34 93.340 291.750 8666.01 8720.01 1689.54 N 3146.26 W 5961914.39 N 688523.38 E 7.210 3281.54 11434.26 91.410 290.350 8664.73 8718.73 1700.63 N 3175.09 W 5961924.74 N 688494.28 E 7.709 3311.23 11466.80 90.090 289.470 8664.30 8718.30 1711.71 N 3205.69 W 5961935.04 N 688463.42 E 4.875 3342.67 11508.17 89.380 286.300 8664.50 8718.50 1724.42 N 3245.05 W 5961946.73 N 688423.74 E 7.852 3382.99 11540.68 92.110 287.890 8664.07 8718.07 1733.97 N 3276.12 W 5961955.49 N 688392.44 E 9.717 3414.78 11579.69 90.000 293.510 8663.35 8717.35 1747.75 N 3312.59 W 5961968.34 N 688355.63 E 15.385 3452.31 11614.00 90.530 295.090 8663.20 8717.20 1761.87N 3343.85 W 5961981.65 N 688324.01 E 4.857 3484.69 11652.04 92.720 293.510 8662.12 8716.12 1777.52 N 3378.51 W 5961996.41 N 688288.97 E 7.098 3520.57 11689.21 94.830 290.350 8659.67 8713.67 1791.37 N 3412.91 W 5962009.38 N 688254.23 E 10.207 3556.05 11723.67 93.510 288.240 8657.16 8711.16 1802.72 N 3445.34 W 5962019.90 N 688221.52 E 7.209 3589.35 11751.44 92.020 286.660 8655.82 8709.82 1811.04 N 3471.80 W 5962027.54 N 688194.85 E 7.816 3616.43 11777.52 89.380 285.250 8655.50 8709.50 1818.21 N 3496.87 W 5962034.07 N 688169.61 E 11.476 3642.03 11804.00 89.380 285.250 8655.79 8709.79 1825.17 N 3522.42 W 5962040.38 N 688143.89 E 0.000 3668.09 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 275.0000 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11804.00fl., The Bottom Hole Displacement is 3967.20ft., in the Direction of 297.3910 (True). 19 May, 2005 - 14:28 Page 4 of5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 18-31A Your Ref: API 500292257901 Job No. AKMW3667579, Surveyed: 27 April, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8774.66 8847.00 11804.00 8275.37 8334.97 8709.79 1505.43 N 1540.23 N 1825.17N 837.37 W 859.05 W 3522.42 W Tie On Point Window Point Projected Survey . Survey tool proç ram for 18-31A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 11804.00 8709.79 MWD Magnetic (18-31PB1) . 19 May, 2005 - 14:28 Page 5 of 5 DrillQuest 3.03.06.008 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 18-31A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window I Kickoff Survey: Projected Survey: 8,774.66' MD 8,847.00' MD 11,804.00' MD (if applicable) 28-May-05 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. Anchorage, AK 99518 Date 7)~h.~) Signed 1hnJ J)1¡ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) /CJz Æ (I )- - a 5- g . . .~: ,"'> .. .. FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 18-31A BP Exploration (Alaska) Inc. Permit No: 205-058 Surface Location: 3719' NSL, 64' WEL, SEC. 24, TIIN, RI4E, UM Bottomhole Location: 119' NSL, 3512' WEL, SEC. 13, TIIN, RI4E, UM Dear Mr. Stagg: 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 witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ø~ Daniel T. Seamount, Jr. Commissioner DATED thisli day of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. o Drill !HI Redrill 1 a. 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: 3719' NSL, 64' WEL, SEC. 24, T11 N, R14E, UM Top of Productive Horizon: 5226' NSL, 903' WEL, SEC. 24, T11N, R14E, UM Total Depth: 119' NSL, 3512' WEL, SEC. 13, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 691712 y- 5960306 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 8850 feet Maximum Hole Angle: 92 degrees ) WGA- 4Il/2..t'o5 ALASKA all" ~~;~g:s~~.J:~ON COMMIS'N~EðEfvED PERMIT TO DRILL APR ~7 zaas ' 20 AAC 25.005 / ., 11 b. Current Well Class 0 Exploratory !HI DA~J.W<i GI~I"ZCDf!..~ ., o Stratigraphic Test 0 Service 0 Development G~ .. .-smtJfè ~8HJlIS.,g,) 5. Bond: 181 Blanket 0 Single Well 11. Well Name a~ rMler: Bond No. 2S100302630-277 PBU 18-31A / 6. Proposed Depth: 12. Field / Pool(s): MD 11750 TVD 8661ss Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028307 ~ 8. Land Use Permit: 13. APproximatæSpu ate: Ap' . 20 005 14. Distance to earest Property: 30,000' 9. Acres in Property: 2560 18. Casing Program: Size Hole Casing 4,1/8· x 3,3/4· 3,3/16· x 2-7/8· Weight 6.2# /6.16# Specifications Grade Couplinç¡ Lenç¡th L-80 STL 3220' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 54' feet 800' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3357 Surface: 2477 / Setting Depth . Quantity of CelTu,mt Top Bottom (c.f. or sacks) MD TVD MD TVD (including stage data) 8530' 8020' 11750' 8661' 145 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD(ft):1 10556 8694 10194 10194 8700 Casing Length Size Cement Volume MD Structural Conductor Surface Intermediate Production Liner Junk (measured): None TVD 110' 3645' 8701' 20" 10-3/4" 7-5/8" 260 sx Arcticset (Approx.) 1037 sx Permafrost 'E', 573 sx Class 'G' 340 sx Class 'G' 110' 3680' 8735' 110' 3662' 8243' 1975' 5-1/2" 228 sx Class 'G' 8581' - 10556' 8116' - 8694' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8716' - 8698' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements Perforation Depth MD (ft): 9520' - 10464' 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 ;:::::r:am:;:¡ ~ Co~;':~: :~:~:neer Date 1/105 ;'=~~~~a Permit To Drill I API Number: 1 Permit Appr0'f,1 i /" 1 See cover letter for Number:..2o.. «'- 058" 50- 029-22579-01-00 Date: i{ (" ù.s other requirements Conditions of Approval: Samples Required Yes .E"No Mud Log Require [J Yes ~NO Hydrogen Sulfide Measures J8Yes [J No Directional Survey Required )§Yes [J No Other: TI.; ~ ß (7 P E -/-t;' s 5" 0l'J P <:. t' . Approved Bv: Form 10-401 Revised 06/2004 Original Signed By DAN SEAMOUNT (lR"f"! " , ! ,...:.\!Ol );L APPROVED BY THE COMMISSION Date yjJ{/05 Submit In Duplicate . BP Prudhoe Bay 18-31A CTD Sidetrack . CTD Sidetrack Summary 1) Mill window off whipstock (8850' MD; -8283'ss) 2) Drill sidetrack in Zone 1. 3) Cement liner. Run MCNL. Perforate. Mud Program: · Well kill: 8.5 p~~.2 · Millingldrilling~pg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: .' · 33/16" x 2 7/8::ÆúÜy)cemented liner [8,530'MD (-8,020ss) to 11,750'MD (-8661ss)] / · A minimum o{30 Ð6ls 15.8 ppg cement will be used for liner cementing. CasiDlúLin~formation 10 3/4", NT-80, 45.5#, Burst 6450 psi; collapse 4020 psi 75/8", S-95 29.7#, Burst 8180 psi, collapse 5120 psi 5 1/2", L-80, 17#, Burst 7740 psi; collapse 6280 psi 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 preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 92 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property - 30,000 ft. · Distance to nearest well within pool -800 ft. Logging · MWD directional and Gamma Ray will be run over all of the open hole section. Hazards /-') · The maximum recorded H2S level on pad i~~P.PÍn (DSI8-17 on 212/05). Reservoir Pressure · Res. press. is estimated to be 3357psi at 88oo'ss (7.4 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2477 psi. / ,TREE= . WELLHEAD = ~~.< ,,~. w ~.~uuu ACTUA TOR = ~,uo"..^.,M u~~m KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD= FMC CrN U.M.., MMum BAKER C 'M' '^.u~,.u,"""",u~~, 54.0' . 18-31 ~NOTES: ? 1748' 94 @ 9659' NIA 8800' SS 2210' '1 4-1/2" HES SERIES 10 TRSV SSSV NIP, 10 = 3.812" . 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" H 3680' ~ . Minimum ID = 3.725" @ 8550' 4-1/2" HES XN NIPPLE L GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 1 3724 3706 1 HES-TMPDX BK 2 6297 6218 29 HES-TMPDX BK 3 8439 7999 34 HES- TMPDX BK ::8: &-----l 8517' H7-5/8" x 4-1/2" TrN HBBP-T PKR, ID = 3.92" I 8550' H 4-1/2" HES XN NIP, ID = 3.725" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8572' 8572' 8574' H 4-1/2" TBG TAIL WLEG, ID = 3.958" I H ELMDTTLOGGED05/21/96 I I TOP OF 5-1/2" LNR H 8581' .. 7-5/8" CSG, 29.7#, S-95, 10 = 6.875" H 8735' ~ ~ PERFORA TION SUMMARY REF LOG: DIFLlGRlSP ON 08/12/95 ANGLEATTOPPERF: 89 @ 9520' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9520 - 9595 0 08/28/95 3-3/8" 4 9665 - 10185 0 08/28/95 3-3/8" 4 10210 - 10464 C 12/24/96 1 10194' H IBP (SET 12/24/96) I 1 PBTD H 10556' ? 15-1/2" LNR, 17#, L-80, .0232 bpf, 10 = 4.892" H 10556' DATE 07/27/95 05/18/01 06/15/03 09/13/03 REV BY COMMENTS ORIGINAL COM PLETION RNlKA K CORRECTIONS CMOITLP KB ELEVATION & MAX ANGLE CMOITLP DATUM MD & PERF ANGLE DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 18-31 ÆRMIT No: 1951090 API No: 50-029-22579-00 SEC 24, T11N, R14E, 1969.79' FEL & 4159.23' FNL BP Exploration (Alaska) 10-314" !D I 4- íI2" mS2 10'" 3.958" 3680' 8572' LNR 8581' 7 -5!f3" 10 SUMMARY REF LOG: 08/12/95 AT TOP PERF: 89 9520' Note: to Production DB 4 3-3/8" 4 3-3/8" 9520 - 9595 9865 - 10185 10210 - 10464 10556' NOTES: 2210' 4-1/2" íOTRSV NIP,!O'" .. MD TVO DEV 1 3724 1 2 6297 6218 29 3 8439 7999 34 DATE HES- TMPDX HES- TMPDX HES- TMPDX ElK X 4- 1/2" TIW 8572' 8574' 11"' SEC LEGEND Azimuths to True North Magnetic North: 24.98~ Stm~~~~~6:¿~~ Dip ~gl.: 80.87" Date: 2128/2Q05 Modal: bggm2004 Plan: Plao fI.5 {16-31/Plan#S, 16-31Aj Cfeatii!d By: 8iU Michal.ili>on Date; 3/112005 -\,~.:"~ _,1'k>~ v.$/u:t!.... -. 27!1.o-.r ~~ 16-311>61 a774." 1Ui,3111'/M11S9ðWl>If3 ~ ~J!:; ::=I!.;tD t),.( Q 5II..t>o REFERENCE INFORMATION 200 300 400 500 600 700 $00 900 1000 1100 1200 1300 1400 1500 1$00 1700 1800 190020002100 22.00 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 390,04000 Vertical Section at 275.00' [100ftlln] 3/1/200G 1.21 PM ObP . . Baker Hughes INTEQ Baker Hughes INTEQ Planning Report .¡¡¡. BAKU IUGIIIS lNTEQ Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB OS 18 18-31 Plan#5,18-31A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 3/112005 Time: 14:23:24 Page: Co-ordinate(NE) Reference: Well: 18-31, True North Vertical (TVD) Reference: 58: 315/31/199608:5354.0 Section (VS) Reference: User (O.00N,O.OQE,275.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB OS 18 TR-11-14 UNITED STATES: North Slope Site Position: Nortbing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft 691583.44 ft Latitude: 70 17 Longitude: 148 26 North Reference: Grid Convergence: 35.252 N 55.555 W True 1.46 deg Well: 18-31 Slot Name: 31 18-31 Well Position: +N/-S 1089.29 ft Northing: 5960305.99 ft Latitude: 70 17 45.965 N +E/-W 155.86 ft Easting : 691711.48 ft Longitude: 148 26 51.012 W Position Uncertainty: 0.00 ft Wellpath: Plan#5, 18-31A 500292257901 Current Datum: 58: 31 5/31/1996 08:53 Magnetic Data: 2/28/2005 Field Strength: 57643 nT Vertical Section: Depth From (TVD) ft 38.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 18-31PB1 8774.66 ft Mean Sea Level 24.98 deg 80.87 deg Direction deg 275.00 Height 54.00 ft Plan: Plan #5 Copy Lamar's Plan#5 Principal: Yes Date Composed: Version: Tied-to: 2/28/2005 5 From: Definitive Path Targets Map Map <-- Latihtde '---> <-Longitude---> Name Description TVD +N/-S +EI-W Northing Easting D!JgMin Sêe Deg Min Seç Dip. Dir. ft ft ft ft ft 18-31A Plan#5 Polygon 54.00 1732.17 -1234.77 5962006.00 690433.00 70 18 3.000 N 148 27 27.010 W -Polygon 1 54.00 1732.17 -1234.77 5962006.00 690433.00 70 18 3.000 N 148 27 27.010 W -Polygon 2 54.00 1527.87 -2245.37 5961776.00 689428.00 70 18 0.989 N 148 27 56.472 W -Polygon 3 54.00 1742.31 -2965.18 5961972.00 688703.00 70 18 3.095 N 148 28 17.459 W -Polygon 4 54.00 1808.99 -3539.70 5962024.00 688127.00 70 18 3.749 N 148 28 34.210 W -Polygon 5 54.00 1599.88 -3460.00 5961817.00 688212.00 70 18 1.692 N 148 28 31.883 W -Polygon 6 54.00 1526.86 -2911.65 5961758.00 688762.00 70 18 0.977 N 148 28 15.896 W -Polygon 7 54.00 1255.22 -2263.33 5961503.00 689417.00 70 17 58.307 N 148 27 56.993 W -Polygon 8 54.00 1573.94 -1149.77 5961850.00 690522.00 70 18 1.444 N 148 27 24.532 W Fault1, 18-31A 54.00 1389.15 -3317.32 5961610.00 688360.00 70 17 59.621 N 148 28 27.721 W -Polygon 1 54.00 1389.15 -3317.32 5961610.00 688360.00 70 17 59.621 N 148 28 27.721 W -Polygon 2 54.00 1400.75 -2869.85 5961633.00 688807.00 70 17 59.736 N 148 28 14.676 W -Polygon 3 54.00 1560.32 -2458.62 5961803.00 689214.00 70 18 1.307 N 148 28 2.689 W Fault3, 18-31A 54.00 1668.69 -903.26 5961951.00 690766.00 70 18 2.376 N 148 27 17.345 W -Polygon 1 54.00 1668.69 -903.26 5961951.00 690766.00 70 18 2.376 N 148 27 17.345 W -Polygon 2 54.00 2187.83 -2586.67 5962427.00 689070.00 70 18 7.478 N 148 28 6.428 W Fault2, 18-31A 54.00 699.53 -3224.87 5960923.00 688470.00 70 17 52.839 N 148 28 25.017 W -Polygon 1 54.00 699.53 -3224.87 5960923.00 688470.00 70 17 52.839 N 148 28 25.017 W -Polygon 2 54.00 1572.49 -661.62 5961861.00 691010.00 70 18 1.430 N 148 27 10.300 W Fault4, 18-31A 54.00 2089.53 -2929.31 5962320.00 688730.00 70 18 6.510 N 148 28 16.417 W -Polygon 1 54.00 2089.53 -2929.31 5962320.00 688730.00 70 18 6.510 N 148 28 16.417 W -Polygon 2 54.00 2016.61 -3678.45 5962228.00 687983.00 70 18 5.790 N 148 28 38.258 W Fault5, 18-31A 54.00 2094.15 -3698.48 5962305.00 687961.00 70 18 6.552 N 148 28 38.843 W Company: Field: Site: Well: Wellpath: Targets ObP BP AmocO Prudhoe Bay PB OS 18 1.8-31 Plan#5. 18-31A . . Baker Hughes INTEQ Baker Hughes INTEQ Planning Report .Ii. 8AKBI IIIIGIIIS _._--- INTEQ Date: 3/1/2005 Time: 14:23:24 Page: 2 Co-ordinate(NE) Reference: Well: 18-31. True North Vertical (TVD) Reference: 58 : 31 5/31/199608:5354.0 Section (VS) Reference: User (0.00N,0.00E.275.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Map <- Latitude --> <- Longitude --> TVD +N/-S +E/-W Northing Easting Deg. Min See Deg Min See ft ft ft ft ft 54.00 2094.15 -3698.48 5962305.00 687961.00 70 18 6.552 N 148 2838.843 W 54.00 1607.83 -3614.86 5961821.00 688057.00 70 18 1.770 N 148 28 36.398 W 54.00 1367.0£ -3432.93 5961585.00 688245.00 70 17 59.403 N 148 28 31.091 W 8714.80 1680.62' -3448.94 5961898.00 688221.00 70 18 2.487 N 148 28 31.562 W 8719.00 1409.46 -2074.32 5961662.00 689602.00 70 17 59.825 N 148 27 51.484 W 8724.00 1645.8C -1300.00 5961918.00 690370.00 70 18 2.151 N 148 27 28.912 W Name Description Dip. Dir. Annotation MD ft 8774.66 8850.00 8870.00 8930.00 9506.51 9756.51 10031.51 10131.51 10331.51 10481.51 10731.51 11006.51 11231.51 11281.51 11531.51 11750.00 -Polygon 1 -Polygon 2 -Polygon 3 18-31A Plan#5 Tgt3 18-31A Plan#5 Tgt2 18-31A Plan#5 Tgt1 TVD ft 8275.37 8337.45 8354.12 8406.83 8723.92 8722.81 8720.54 8719.81 8719.14 8720.45 8724.43 8728.19 8729.01 8728.26 8721.18 8714.79 TIP KOP End 9DDLS 4 End 14DDLS 6 7 8 9 10 11 12 13 14 15 TO Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100fI degl100fI deg/100fI deg 8774.66 34.60 327.70 8275.37 1505.43 -837.37 0.00 0.00 0.00 0.00 8850.00 34.44 328.49 8337.45 1541.67 -859.94 0.63 -0.21 1.05 109.99 8870.00 32.64 328.49 8354.12 1551.09 -865.71 9.00 -9.00 0.00 180.00 8930.00 24.24 328.49 8406.83 1575.43 -880.63 14.00 -14.00 0.00 180.00 9506.51 90.00 261.64 8723.92 1646.60 -1299.32 14.00 11.41 -11.60 291.30 9756.51 90.50 231.64 8722.81 1548.61 -1526.22 12.00 0.20 -12.00 271.00 10031.51 90.42 264.65 8720.54 1447.65 -1777.93 12.00 -0.03 12.00 90.00 10131.51 90.41 252.65 8719.81 1428.00 -1875.79 12.00 -0.01 -12.00 270.00 10331.51 89.97 276.64 8719.14 1409.47 -2073.46 12.00 -0.22 12.00 91.00 10481.51 89.04 294.62 8720.45 1449.71 -2217.32 12.00 -0.62 11.98 93.00 10731.51 89.17 264.61 8724.43 1490.99 -2460.97 12.00 0.05 -12.00 270.00 11006.51 89.30 297.62 8728.19 1543.28 -2727.07 12.00 0.05 12.00 90.00 11231.51 90.29 270.63 8729.01 1597.68 -2943.25 12.00 0.44 -11.99 272.00 11281.51 91.43 264.74 8728.26 1595.67 -2993.18 12.00 2.28 -11.78 281.00 11531.51 91.74 294.75 8721.18 1637.50 -3236.67 12.00 0.12 12.00 89.00 11750.00 91.56 268.52 8714.79 1681.17 -3448.71 12.00 -0.08 -12.00 270.00 . . Bit. ObP Baker Hughes INTEQ BAICIIt IILIGIIU Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 3/1/2005 Time: 14:23:24 Page: 3 Field: Prudhoe Bay Co-ordioate(NE) Refereoee: Well: 18-31, True North Site: PB OS 18 Vertieal (TVD) Refereoee: 58:31 5/31/199608:5.354.0 Well: 18-31 Sedioo (VS)Refereoee: User (0.00N,O.Op¡:,275.00Azì) Wellpath: Plan#5, 18-31A Survey CaleuJatioo Method: Minimum Curvature Db: Survey MD Ioel Azim SSTVD N/S EfW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/10Oft ft deg 8775.00 34.60 327.70 8221.65 1505.59 -837.48 5961789.65 690835.92 0.00 965.51 0.00 MWD 8800.00 34.55 327.96 8242.24 1517.60 -845.03 5961801.46 690828.07 0.63 974.08 109.99 MWD 8825.00 34.49 328.23 8262.84 1529.63 -852.52 5961813.29 690820.27 0.63 982.59 109.77 MWD 8850.00 34.44 328.49 8283.45 1541.67 -859.94 5961825.14 690812.55 0.63 991.03 109.56 MWD 8870.00 32.64 328.49 8300.12 1551.09 -865.71 5961834.41 690806.53 9.00 997.61 180.00 MWD 8875.00 31.94 328.49 8304.34 1553.37 -867.11 5961836.65 690805.08 14.00 999.19 180.00 MWD 8900.00 28.44 328.49 8325.95 1564.09 -873.68 5961847.19 690798.24 14.00 1006.67 180.00 MWD 8925.00 24.94 328.49 8348.28 1573.66 -879.55 5961856.61 690792.13 14.00 1013.35 180.00 MWD 8930.00 24.24 328.49 8352.83 1575.43 -880.63 5961858.36 690791.00 14.00 1014.59 180.00 MWD 8950.00 25.38 322.40 8370.98 1582.33 -885.40 5961865.13 690786.06 14.00 1019.94 291.30 MWD 8975.00 27.13 315.53 8393.41 1590.65 -892.66 5961873.26 690778.59 14.00 1027.90 296.83 MWD 9000.00 29.17 309.50 8415.46 1598.59 -901.36 5961880.98 690769.69 14.00 1037.26 302.99 MWD 9025.00 31.45 304.24 8437.04 1606.14 -911.46 5961888.27 690759.41 14.00 1047.97 308.31 MWD 9050.00 33.92 299.64 8458.08 1613.26 -922.91 5961895.10 690747.77 14.00 1060.01 312.86 MWD 9075.00 36.54 295.61 8478.50 1619.93 -935.69 5961901.43 690734.83 14.00 1073.32 316.73 MWD 9100.00 39.28 292.05 8498.23 1626.12 -949.74 5961907.26 690720.62 14.00 1087.85 320.02 MWD 9125.00 42.11 288.90 8517.19 1631.81 -965.01 5961912.56 690705.22 14.00 1103.56 322.83 MWD 9150.00 45.02 286.08 8535.30 1636.98 -981.44 5961917.31 690688.66 14.00 1120.38 325.22 MWD 9175.00 47.99 283.53 8552.51 1641.60 -998.97 5961921.48 690671.02 14.00 1138.25 327.26 MWD 9200.00 51.02 281.22 8568.74 1645.66 -1017.54 5961925.07 690652.35 14.00 1157.10 329.02 MWD 9225.00 54.08 279.09 8583.94 1649.15 -1037.07 5961928.06 690632.74 14.00 1176.86 330.52 MWD 9250.00 57.19 277.12 8598.05 1652.06 -1057.50 5961930.44 690612.25 14.00 1197.46 331.82 MWD 9275.00 60.32 275.29 8611.02 1654.36 -1078.75 5961932.20 690590.95 14.00 1218.83 332.93 MWD 9300.00 63.47 273.57 8622.80 1656.06 -1100.73 5961933.34 690568.93 14.00 1240.87 333.88 MWD 9325.00 66.64 271.94 8633.34 1657.15 -1123.37 5961933.85 690546.28 14.00 1263.52 334.69 MWD 9350.00 69.83 270.39 8642.61 1657.61 -1146.57 5961933.72 690523.06 14.00 1286.68 335.38 MWD 9375.00 73.03 268.90 8650.57 1657.46 -1170.27 5961932.97 690499.38 14.00 1310.27 335.95 MWD 9400.00 76.25 267.46 8657.19 1656.69 -1194.36 5961931.58 690475.32 14.00 1334.21 336.43 MWD 9416.42 78.36 266.53 8660.80 1655.85 -1210.35 5961930.34 690459.35 14.00 1350.07 336.81 18-31A P 9425.00 79.47 266.06 8662.45 1655.31 -1218.76 5961929.58 690450.97 14.00 1358.39 337.01 MWD 9450.00 82.69 264.68 8666.33 1653.31 -1243.37 5961926.96 690426.42 14.00 1382.73 337.10 MWD 9475.00 85.92 263.33 8668.80 1650.72 -1268.11 5961923.73 690401.75 14.00 1407.15 337.32 MWD 9500.00 89.16 261.99 8669.88 1647.53 -1292.88 5961919.91 690377.08 14.00 1431.55 337.45 MWD 9506.51 90.00 261.64 8669.92 1646.60 -1299.32 5961918.82 690370.66 14.00 1437.89 337.51 MWD 9525.00 90.04 259.42 8669.92 1643.56 -1317.56 5961915.31 690352.51 12.00 1455.79 271.00 MWD 9550.00 90.09 256.42 8669.89 1638.33 -1342.00 5961909.46 690328.21 12.00 1479.68 271.00 MWD 9575.00 90.14 253.42 8669.84 1631.82 -1366.14 5961902.34 690304.24 12.00 1503.16 271.00 MWD 9600.00 90.19 250.42 8669.77 1624.07 -1389.90 5961893.98 690280.69 12.00 1526.16 270.99 MWD 9625.00 90.25 247.42 8669.67 1615.08 -1413.22 5961884.40 690257.60 12.00 1548.61 270.98 MWD 9650.00 90.30 244.42 8669.55 1604.88 -1436.05 5961873.63 690235.05 12.00 1570.46 270.97 MWD 9675.00 90.35 241.42 8669.41 1593.50 -1458.30 5961861.69 690213.09 12.00 1591.64 270.96 MWD 9700.00 90.39 238.42 8669.25 1580.98 -1479.94 5961848.61 690191.79 12.00 1612.09 270.94 MWD 9725.00 90.44 235.43 8669.07 1567.34 -1500.88 5961834.44 690171.20 12.00 1631.77 270.92 MWD 9750.00 90.49 232.43 8668.86 1552.62 -1521.08 5961819.21 690151.38 12.00 1650.62 270.90 MWD 9756.51 90.50 231.64 8668.81 1548.61 -1526.22 5961815.08 690146.35 12.00 1655.38 270.87 MWD 9775.00 90.50 233.86 8668.65 1537.42 -1540.93 5961803.52 690131.92 12.00 1669.07 90.00 MWD 9800.00 90.50 236.86 8668.43 1523.22 -1561.50 5961788.79 690111.73 12.00 1688.32 90.02 MWD 9825.00 90.50 239.86 8668.21 1510.10 -1582.78 5961775.14 690090.79 12.00 1708.37 90.05 MWD 9850.00 90.49 242.86 8668.00 1498.13 -1604.72 5961762.61 690069.16 12.00 1729.18 90.07 MWD 9875.00 90.48 245.86 8667.78 1487.31 -1627.26 5961751.22 690046.91 12.00 1750.69 90.10 MWD 9900.00 90.48 248.86 8667.57 1477.69 -1650.33 5961741.02 690024.09 12.00 1772.84 90.12 MWD 9925.00 90.47 251.86 8667.37 1469.29 -1673.87 5961732.02 690000.78 12.00 1795.56 90.15 MWD 9950.00 90.46 254.86 8667.16 1462.13 -1697.82 5961724.26 689977.02 12.00 1818.79 90.17 MWD . . B.. ObP Baker Hughes INTEQ BAKD. HIJGIIIS Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 3/1/2005 Time: 14:23:24 Page: 4 Field: Prudhoe Bay Co-ordlnate(NE) Reference: Well: 18-31, True Nort~ Site: PB OS 18 Vertical (TVD) Reference: 58: 31 5/31/199608:5354.0 Well: 18-31 SectIon (VS) Reference: User (O.00N,O.00E,275.00Azi) Wellpath: Plan#5, 18-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD IneI Azim SS TVD N/S EIW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/10OO ft deg 9975.00 90.45 257.86 8666.97 1456.24 -1722.11 5961717.75 689952.88 12.00 1842.48 90.20 MWD 10000.00 90.44 260.86 8666.77 1451.63 -1746.68 5961712.51 689928.44 12.00 1866.55 90.22 MWD 10025.00 90.42 263.86 8666.59 1448.31 -1771.45 5961708.56 689903.76 12.00 1890.94 90.24 MWD 10031.51 90.42 264.65 8666.54 1447.65 -1777.93 5961707.74 689897.31 12.00 1897.34 90.27 MWD 10050.00 90.42 262.43 8666.40 1445.57 -1796.30 5961705.19 689879.00 12.00 1915.46 270.00 MWD 10075.00 90.42 259.43 8666.22 1441.63 -1820.98 5961700.62 689854.42 12.00 1939.70 269.98 MWD 10100.00 90.42 256.43 8666.04 1436.40 -1845.43 5961694.77 689830.12 12.00 1963.60 269.96 MWD 10125.00 90.41 253.43 8665.86 1429.90 -1869.56 5961687.66 689806.16 12.00 1987.07 269.94 MWD 10131.51 90.41 252.65 8665.81 1428.00 -1875.79 5961685.60 689799.98 12.00 1993.11 269.92 MWD 10150.00 90.37 254.86 8665.68 1422.83 -1893.54 5961679.98 689782.37 12.00 2010.34 91.00 MWD 10175.00 90.32 257.86 8665.53 1416.94 -1917.83 5961673.47 689758.24 12.00 2034.03 91.02 MWD 10200.00 90.26 260.86 8665.41 1412.32 -1942.40 5961668.23 689733.80 12.00 2058.10 91.03 MWD 10225.00 90.21 263.86 8665.30 1409.00 -1967.18 5961664.27 689709.12 12.00 2082.49 91.05 MWD 10250.00 90.15 266.86 8665.23 1406.98 -1992.09 5961661.62 689684.27 12.00 2107.14 91.06 MWD 10275.00 90.10 269.86 8665.17 1406.26 -2017.08 5961660.27 689659.31 12.00 2131.97 91.07 MWD 10300.00 90.04 272.86 8665.14 1406.86 -2042.07 5961660.22 689634.31 12.00 2156.91 91.08 MWD 10325.00 89.98 275.86 8665.14 1408.76 -2066.99 5961661.49 689609.35 12.00 2181.91 91.08 MWD 10331.51 89.97 276.64 8665.14 1409.47 -2073.46 5961662.03 689602.86 12.00 2188.42 91.08 MWD 10350.00 89.85 278.86 8665.17 1411.96 -2091.78 5961664.05 689584.48 12.00 2206.88 93.00 MWD 10375.00 89.70 281.85 8665.27 1416.45 -2116.37 5961667.92 689559.79 12.00 2231.77 93.00 MWD 10400.00 89.54 284.85 8665.43 1422.23 -2140.69 5961673.07 689535.33 12.00 2256.50 92.98 MWD 10425.00 89.39 287.85 8665.67 1429.26 -2164.68 5961679.49 689511.17 12.00 2281.01 92.96 MWD 10450.00 89.23 290.84 8665.97 1437.54 -2188.26 5961687.16 689487.39 12.00 2305.23 92.94 MWD 10475.00 89.08 293.84 8666.34 1447.04 -2211.38 5961696.07 689464.04 12.00 2329.09 92.90 MWD 10481.51 89.04 294.62 8666.45 1449.71 -2217.32 5961698.59 689458.03 12.00 2335.23 92.86 MWD 10500.00 89.04 292.40 8666.75 1457.08 -2234.27 5961705.53 689440.90 12.00 2352.76 270.00 MWD 10525.00 89.05 289.40 8667.17 1466.00 -2257.62 5961713.84 689417.33 12.00 2376.80 270.04 MWD 10550.00 89.05 286.40 8667.59 1473.68 -2281.40 5961720.92 689393.36 12.00 2401.16 270.09 MWD 10575.00 89.06 283.40 8668.00 1480.11 -2305.56 5961726.72 689369.05 12.00 2425.78 270.14 MWD 10600.00 89.07 280.40 8668.40 1485.26 -2330.01 5961731.25 689344.47 12.00 2450.60 270.19 MWD 10625.00 89.09 277.40 8668.81 1489.13 -2354.71 5961734.49 689319.69 12.00 2475.53 270.24 MWD 10650.00 89.10 274.40 8669.20 1491.69 -2379.57 5961736.42 689294.77 12.00 2500.52 270.28 MWD 10675.00 89.12 271.40 8669.59 1492.96 -2404.53 5961737.04 689269.79 12.00 2525.50 270.33 MWD 10700.00 89.14 268.40 8669.97 1492.91 -2429.53 5961736.36 689244.81 12.00 2550.40 270.38 MWD 10725.00 89.16 265.40 8670.34 1491.56 -2454.48 5961734.37 689219.89 12.00 2575.14 270.42 MWD 10731.51 89.17 264.61 8670.43 1490.99 -2460.97 5961733.64 689213.42 12.00 2581.55 270.47 MWD 10750.00 89.17 266.83 8670.70 1489.61 -2479.40 5961731.79 689195.03 12.00 2599.80 90.00 MWD 10775.00 89.17 269.83 8671.06 1488.89 -2504.39 5961730.43 689170.08 12.00 2624.62 89.97 MWD 10800.00 89.18 272.83 8671.42 1489.47 -2529.38 5961730.37 689145.08 12.00 2649.57 89.92 MWD 10825.00 89.19 275.83 8671.78 1491.36 -2554.30 5961731.63 689120.12 12.00 2674.56 89.88 MWD 10850.00 89.20 278.84 8672.13 1494.55 -2579.09 5961734.18 689095.26 12.00 2699.53 89.84 MWD 10875.00 89.21 281.84 8672.48 1499.03 -2603.68 5961738.04 689070.56 12.00 2724.42 89.80 MWD 10900.00 89.22 284.84 8672.82 1504.80 -2628.00 5961743.18 689046.11 12.00 2749.15 89.75 MWD 10925.00 89.24 287.84 8673.16 1511.83 -2651.98 5961749.60 689021.95 12.00 2773.66 89.71 MWD 10950.00 89.26 290.84 8673.48 1520.10 -2675.57 5961757.27 688998.16 12.00 2797.87 89.67 MWD 10975.00 89.28 293.84 8673.80 1529.60 -2698.69 5961766.17 688974.81 12.00 2821.73 89.63 MWD 11000.00 89.30 296.84 8674.11 1540.30 -2721.28 5961776.29 688951.95 12.00 2845.17 89.60 MWD 11006.51 89.30 297.62 8674.19 1543.28 -2727.07 5961779.12 688946.09 12.00 2851.20 89.56 MWD 11025.00 89.38 295.40 8674.41 1551.53 -2743.61 5961786.94 688929.34 12.00 2868.40 272.00 MWD 11050.00 89.49 292.40 8674.65 1561.66 -2766.47 5961796.49 688906.24 12.00 2892.05 272.03 MWD 11075.00 89.60 289.40 8674.85 1570.58 -2789.82 5961804.80 688882.67 12.00 2916.08 272.05 MWD 11100.00 89.71 286.41 8675.00 1578.26 -2813.60 5961811.88 688858.70 12.00 2940.45 272.08 MWD . . Bit. ObP Baker Hughes INTEQ IIAICIIIt HUGMIS Baker Hughes INTEQ Planning Report INTEQ Company: BPAmoco Date: 3/1/2005 Time: .14:23:24 Page: S Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-31. True North Site: PB OS 18 Vertical (TVD) Reference: 58 : 31 5/31/1996 08:5354.Q Well: 18-31 Section (VS) Reference: User (O.00N.0.00E.275.00Azi) Wellpath: Plan#5.18-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim SSTVD N/S EIW MapN MapE DLS VS TFO Toòl ft deg deg ft ft ft ft ft deg/10Oft ft deg 11125.00 89.82 283.41 8675.11 1584.69 -2837.76 5961817.69 688834.39 12.00 2965.07 272.10 MWD 11150.00 89.93 280.41 8675.16 1589.85 -2862.22 5961822.22 688809.81 12.00 2989.89 272.11 MWD 11175.00 90.04 277.41 8675.17 1593.72 -2886.91 5961825.46 688785.02 12.00 3014.83 272.12 MWD 11200.00 90.15 274.41 8675.13 1596.30 -2911.78 5961827.40 688760.10 12.00 3039.82 272.12 MWD 11225.00 90.26 271.42 8675.04 1597.57 -2936.74 5961828.04 688735.12 12.00 3064.80 272.11 MWD 11231.51 90.29 270.63 8675.01 1597.68 -2943.25 5961827.99 688728.61 12.00 3071.30 272.10 MWD 11250.00 90.71 268.46 8674.85 1597.54 -2961.74 5961827.37 688710.13 12.00 3089.70 281.00 MWD 11275.00 91.28 265.51 8674.41 1596.22 -2986.70 5961825.42 688685.21 12.00 3114.45 280.98 MWD 11281.51 91.43 264.74 8674.26 1595.67 -2993.18 5961824.70 688678.75 12.00 3120.86 280.93 MWD 11300.00 91.47 266.96 8673.79 1594.33 -3011.62 5961822.89 688660.35 12.00 3139.11 89.00 MWD 11325.00 91.51 269.96 8673.14 1593.66 -3036.60 5961821.59 688635.40 12.00 3163.94 89.06 MWD 11350.00 91.56 272.96 8672.47 1594.30 -3061.58 5961821.59 688610.41 12.00 3188.88 89.13 MWD 11375.00 91.60 275.97 8671.78 1596.25 -3086.49 5961822.90 688585.46 12.00 3213.86 89.21 MWD 11400.00 91.63 278.97 8671.08 1599.49 -3111.26 5961825.51 688560.61 12.00 3238.83 89.30 MWD 11425.00 91.66 281.97 8670.36 1604.03 -3135.83 5961829.42 688535.93 12.00 3263.70 89.38 MWD 11450.00 91.69 284.97 8669.63 1609.85 -3160.13 5961834.62 688511.50 12.00 3288.42 89.47 MWD 11475.00 91.71 287.97 8668.89 1616.93 -3184.09 5961841.09 688487.36 12.00 3312.90 89.56 MWD 11500.00 91.72 290.97 8668.14 1625.26 -3207.65 5961848.81 688463.60 12.00 3337.10 89.64 MWD 11525.00 91.74 293.97 8667.38 1634.81 -3230.74 5961857.77 688440.28 12.00 3360.93 89.73 MWD 11531.51 91.74 294.75 8667.18 1637.50 -3236.67 5961860.30 688434.29 12.00 3367.07 89.83 MWD 11550.00 91.74 292.53 8666.62 1644.91 -3253.60 5961867.28 688417.17 12.00 3384.58 270.00 MWD 11575.00 91.73 289.53 8665.87 1653.88 -3276.92 5961875.65 688393.63 12.00 3408.59 269.93 MWD 11600.00 91.72 286.53 8665.11 1661.61 -3300.68 5961882.77 688369.69 12.00 3432.93 269.84 MWD 11625.00 91.70 283.53 8664.37 1668.09 -3324.81 5961888.64 688345.40 12.00 3457.54 269.75 MWD 11650.00 91.68 280.53 8663.63 1673.30 -3349.24 5961893.22 688320.84 12.00 3482.34 269.66 MWD 11675.00 91.66 277.53 8662.90 1677.22 -3373.92 5961896.51 688296.07 12.00 3507.26 269.57 MWD 11700.00 91.63 274.53 8662.18 1679.84 -3398.77 5961898.50 688271.17 12.00 3532.24 269.49 MWD 11725.00 91.60 271.53 8661.47 1681.16 -3423.72 5961899.18 688246.19 12.00 3557.22 269.40 MWD 11750.00 ,/ 91.56 268.52 8660.79 1681.17 -3448.71 5961898.55 688221.21 12.00 3582.11 269.31 MWD TERR'E L HUBBLE BP EXPLORA T'ON AK 'NC POBOX 196612 MB 7-5 ANCHOAAGE, AK 99519-6612 89-6/1252 192 DATE 04 -07-D.5 -1 $ lOa. 00 DOLlARs Mastercard Check ~~6'100~'~?~~ OO~q . ~<X Rlli.;,~ tY& crx® Anchorage, AK 99501 MEMO II ,. \ . . O¡Q2 ¡s Sb". b è 27'" III .: ¡ 25 èOOObO.:q q ¡ ~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /IJ¿¡ Jt - 3/ H PTD# 2() $' - t') ~t; 1 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well_, Permit No, API No. Production should continue to be reported as a function of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 04/01105 C\j ody\transm ittal_ checklist The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 18-31A Program DEV Well bore seg 0 PTD#: 2050580 Company BP EXPLORATION (ALASKA) INC Initial Classrrype DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 0 Administration 1 P~rmitfee attaçhed ~ ~ - - - - - - - - - - - - ~ ~ ~ Yes - - - - - - - - - 2 leas~ ~nIJmber ~apprORriat~ ~ y~s~ - - - - - - - 3 ~U~niqlJe welt n~am~ ~aIJd Ol!lTJb~er ~ ~ ~ ~ - - - - - ~ - - - - - - - - ~ ~ ~ ~ ~ ~ ~ ~ y~s ~ ~ - - - - - - - - - -- - - - - - - - - ~ - - - - 4 Well locat~d in~aßefined ~Pool - - - - - - Yes ~ ~ - - - - - - - - - - - - - 5 WeJUocat~d p(operdistançe~ from drilling IJr¡itbolJr¡d~ary ~~~~Yes~ - - - - - - 6 Well locat~d pr~oper ~distance~ from otheJ wells ~ ~ y~s - - - - - 7 ~S~u{ficienLacreage~aYailable indJilliog unjL - - -- - - - - y~s 8 Jtd~viated, js wellbore platincJuded ~ ~ - - -- ~ Yes - - - - - - - - - - - - - - 9 Operator Only affeçted party ~ ~ ~ - - - - - - - - - - - ~ Yes - - - - - - - - - - - - - 10 ~Op!'nator lJas~appn:>pria!e_ bond inJorce ~ . ~ ~ ~ ~ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - _Y~s - - - - - - - - - - - - - - - - - - - - - - - -- 11 P~rmit caIJ be issl!ed wjthou! co~nservaJion order _ ~ ~ ~ _ _ ~ ~ ~ ~ ~ ~ - y~s - - - - - - - - Appr Date 12 P~rmit call be iSSl!ed wjtbou! administratille_apprpval ~ _ _ _ Yes - - - - - - - - - - - RPC 4/8/2005 13 Can permit be approved before 15-day wait Yes 14 Well locat~d within area and strata ~authorized by l!ljectioo Ord~r # (pIJt 10# in c_o[1lm_e!lts)_ (For ~ NA - - - - - - - - - - - - . 15 _All wells_within JlÜDile_area_of review jd~ot[fied (Fpr servjc_ewellOnlYL ' _ _ _ _ _ _ _ _ _ . _ _ _ _NA - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector; _duralionof pre-productiOn I~ss than:3 months_ (For service well onJy) ~ NA - - - - - - - - - - - - - - - - - . 17 ~AÇMP Findjng 9f Con_slslency_h_as bee_n JssIJed_ for_ tbis pr_oject NA - - - - - - Engineering 18 C~o!ldu~clor stringprovlded ~ ~ - - - - - - - NA - - - - - - - - - - - - - 19 _S~urfac~ ~casing_pJotects all_known_ USDWs ~ ~ ~ _ _ ~ ~ - - - - - - _NA - - -- - - - - 20 _CMT vol ade<;Jl!a!e_to çirculateonconduçtor_& surfcsg ~ - - - - - - -- NA - - - - - - - - - - - - - 21 _CMT vol ade<Na!eJo tie-inJQngstring 10sIJrf csg~ _ _ ~ ~ ~ ~ _ _ ~ ~ ~ _ _ _ ~ ~ NA - - - - - - - 22 CMTwill coYer~aJl knownpro_dlJctiye bQri¡!:ons _ ~ ~ - - - - - - y~s - - - -- 23 _Casi!lg designs adeQua_te fpr CJ, B&perrnafr9st - - - - - - _ Yes - - - - - - - - - 24 ~Adequaletan_kageoJ reserve pit ~ - - - - - - - - - -- y~s CTDU. ~ _ - - - - - 25 J(aJe-d(ill~ bas a tOc403 for abandonment be~!l apPJoved ~ ~ y~s * - - - - - - -- - - - - - - - 26 _Adequale-"'\lellbore_separatjoÐ~propOsed_ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ - - - y~s - - - - - - - - - - - - - - - - - -- 27 JtdjverterJequired, does jtmeel regulations_ _ ~ ~ ~ _ _ _ ~ - - - - -- ~NA Sidet(açk. ~ Appr Date 28 DJiUi!lg fluid_ program schematic & eq~uip listadequate _ ~ ~ ~ ~ _ _ _ ~ ~ Yes Max MW8_.6 PP9, _ _ _ WGA 4/8/2005 29 _BOPEs,_dpthey .meet regulatiOn _ ~ ~ ~ ~ _Y~s - - - - - - - 30 BOPEpress raJi!lg approp(iate;test lo_(put psig Ln~com[1lents)_ y~s Test tp3500 psi.MS~ 2477 psi._ . 31 ~Choke_manjfold cQmplies w/APt R~-53. (May 84)_ _ ~ - - - - - - _ _ y~s '32 WQrk will OCCU( withOytoperation ~sbutdown_ ~ - - - - - - ~ ~ ~ y~s - - - - 33 Is presence Qf H2S gas_ probable _ - - - - -- _Y~s 20. ppm. 34 Meçba_nicalcolJditiolJ p{ wells within AOR yerifìed (for service welJ only) ~ _NA Geology 35 P~rmit call be iSSl!ed wlQ hyd(ogen sulfide measUres ~ No_ 36 D_atapreselJted on potential oveJpres_sureZOnes ~ ~ ~ _ _ ~ ~ - - - - - ~ NA Appr Date 37 _S~is[1licanalysis~ of sballow 9as_zpoes_ _ ~ . _NA - - - - -- RPC 4/8/2005 38 S~abedcondjtipo survey (if oft-shore) _ _ ~ _ _ _ _NA - - - - - - - - - - - - 39 ~ CQntact na.melphoneforweekly progress reports [exploratory _only] ~ _ _ _ ~ ~ ~ NA Geologic Engineering Date Public Commissioner: Date: Commissioner: Commissioner Date lJu 41¢" éf..-//,()~ . . 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. I i I To improve the readability of the Well History file and to simplify finding infonnation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . Sperry-Sun Drilling Services LIS Scan Utility RECEIVED $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 11 15:59:20 2007 JAN 2 9 Z007 Alaska on & Gas eons. commISSiOR Anchor8QØ Reel Heade:J; Service name. ........... .LISTPE Date.................... .07/01/11 Origin.................. .STS Reel Name............ ....UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. ........... .LISTPE Date.. .,..... ..... ...... .07/01/11 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 18-31A 500292257901 BP Exploration (Alaska) Inc. Sperry Drilling Services ll-JAN-07 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 MW0003667579 S. LATZ B. HOLT/D. H MWD RUN 2 MW0003667579 S. LATZ B. HOLT/D. H MWD RUN 3 MW0003667579 S. LATZ B. HOLT/D. H # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 24 llN 14E 3719 64 54.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 5.500 8847.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . .{;)DS--O~-1J .:8::. 143~ d . . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8847'MD/ 8281'TVDSS IN THE 18-31 WELLBORE. 4. MWD RUNS 1 -3 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A CASED-HOLE GAMMA RAY RUN ON 4/28/2005 IN 18-31A. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 12/14/06, AS AUTHORIZED BY ROGER FURLEY (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-3 REPRESENT WELL 18-31A WITH API #: 50-029-22579-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11804'MD/8655'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .07/01/11 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 ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8793.5 8894.5 STOP DEPTH 11803.0 11833.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8793.5 8794.5 8797.0 8803.0 8812.5 8818.5 8824.5 8827.5 8870.0 8879.0 8881. 0 8883.5 8887.5 8889.5 8904.0 8910.0 8915.0 8923.0 8931.0 8937.0 8941.5 8944.0 8960.0 8962.0 8979.5 GR 8772.0 8773.0 8775.0 8779.5 8791.0 8795.5 8800.0 8803.5 8845.0 8855.0 8856.5 8858.0 8863.5 8865.0 8880.0 8885.0 8890.0 8897.0 8906.0 8912.0 8916.5 8919.0 8934.5 8937.0 8954.5 . . 8995.0 9004.0 9040.0 9055.5 9067.0 9078.5 9095.0 9098.0 9100.5 9118.5 9124.0 9141.5 9159.5 9170.0 9208.5 9213.0 9216.5 9221. 5 9235.0 9243.0 9255.5 9260.0 9275.5 9284.5 9287.5 9292.5 9305.0 9309.5 9316.5 9326.5 9350.5 9382.5 9398.5 9411.0 9416.0 9421. 0 9435.5 9448.5 9464.0 9476.5 9482.0 9593.5 9597.0 9605.0 9641.0 9733.0 9918.0 9925.5 9931. 5 9960.5 9971.5 9974.5 9982.5 9992.0 10001.0 10011.0 10030.5 10034.5 10048.0 10090.5 10093.5 10208.5 10219.5 10248.0 10257.5 10264.5 10280.0 10286.0 10341.0 10378.5 10405.0 10432.0 10540.0 10582.5 10600.5 10618.0 8969.5 8978.0 9015.0 9029.0 9040.0 9052.5 9070.0 9072.5 9076.0 9093.5 9097.5 9116.5 9133.5 9144.0 9182.5 9187.0 9189.5 9195.5 9208.5 9215.5 9228.5 9232.5 9249.0 9257.0 9260.5 9265.5 9277.5 9282.0 9289.5 9299.5 9323.0 9356.0 9373.5 9384.0 9390.0 9394.5 9410.0 9423.0 9438.0 9449.5 9455.5 9568.5 9571.5 9579.5 9615.5 9710.0 9894.0 9900.5 9905.5 9935.5 9945.0 9948.5 9955.5 9968.0 9977 . 0 9986.0 10004.5 10008.5 10022.0 10066.5 10070.0 10184.0 10194.5 10222.0 10232.0 10238.5 10255.5 10262.5 10317.0 10353.0 10379.5 10404.0 10513 . 5 10555.0 10578.0 10594.5 10807.5 10817.0 10826.5 10840.5 10855.0 10867.5 10869.0 10875.5 10887.0 10889.0 10892.0 10912.0 10915.5 10920.0 10931.0 10946.0 10975.0 11021.5 11060.0 11066.5 11095.5 11143.0 11156.5 11167.0 11187.0 11192.5 11197.5 11203.5 11212.5 11214.5 11246.5 11258.5 11267.5 11271.0 11275.0 11278.0 11284.0 11288.5 11293.5 11300.0 11312.5 11406.0 11410.0 11414.0 11416.0 11418.0 11419.5 11428.5 11451. 5 11505.0 11521.0 11523.5 11528.5 11531. 0 11533.0 11539.0 11553.5 11555.0 11557.5 11563.5 11573.0 11586.5 11630.5 11833.0 $ # MERGED DATA SOURCE PBU TOOl, CODE MWD MWD MWD $ # REMARKS: . 10787.0 10796.5 10804.5 10819.0 10833.5 10846.0 10848.0 10854.5 10866.0 10868.0 10870.0 10889.0 10891.5 10895.5 10909.0 10923.5 10951.0 10999.0 11035.5 11042.0 11072 . 5 11119.0 11133.5 11142.5 11163.5 11169.0 11174.0 11180.5 11188.5 11192 . 0 11228.0 11237.5 11246.5 11250.0 11253.0 11256.5 11262.0 11266.0 11271.0 11280.0 11290.5 11380.5 11385.0 11389.0 11391.5 11393.5 11395.0 11404.0 11427.0 11478.0 11494.5 11497.0 11501.0 11504.5 11506.0 11512.5 11527.0 11529.0 11531.0 11535.5 11547.5 11560.0 11601.0 11803.5 BIT RUN NO 1 2 3 # MERGED MAIN PASS. $ MERGE TOP 8772.0 9525.0 9906.5 . MERGE BASE 9525.0 9906.5 11803.5 . . 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT API FT/H Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT GR ROP MWD MWD Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8793.5 11833 10313.3 6080 8793.5 11833 GR MWD API 18.76 1226.07 61.9215 5964 8793.5 11803 ROP MWD FT/H 0.1 423.3 93.6448 5878 8894.5 11833 First Reading For Entire File......... .8793.5 Last Reading For Entire File.......... .11833 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .07/01/11 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... ....07/01/11 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Previous File Name. . . . . . .STSLIB.001 Comment 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 8772.0 8870.0 STOP DEPTH 9494.5 9525.0 # 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): 23-APR-05 Insite 7.75 Memory 9525.0 8870.0 9525.0 . 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD010 ROP MWD010 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT API FT/H 34.5 86.4 TOOL NUMBER TLG002 4.125 8847.0 Flopro 8.70 .0 8.8 28000 .0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 129.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8772 9525 9148.5 1507 8772 9525 GR MWD010 API 18.76 1226.07 47.5843 1392 8772 9494.5 ROP MWD010 FT/H 0.1 235.92 48.1897 1311 8870 9525 First Reading For Entire File.. ........8772 Last Reading For Entire File.... ..... ..9525 File Trailer Service name.. .......... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .07/01/11 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...... .07/01/11 Maximum Physical Record. .65535 File 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 9495.0 9525.5 STOP DEPTH 9876.5 9906.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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.... ..............0 24-APR-05 Insite 7.75 Memory 9907.0 9525.0 9907.0 86.4 91.7 TOOL NUMBER TLG015 4.125 8847.0 Flopro 8.70 65.0 8.8 28000 5.8 .000 .000 .000 .000 .0 133.0 .0 .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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD020 ROP MWD020 Units FT API FT/H Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9495 9906.5 9700.75 824 9495 9906.5 GR MWD020 API 23.91 73.2 43.8649 764 9495 9876.5 ROP MWD020 FT/H 0.11 91.01 55.3345 763 9525.5 9906.5 First Reading For Entire File......... .9495 Last Reading For Entire File.......... .9906.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.... ...... .1.0.0 Date of Generation...... .07/01/11 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.... ...... .STSLIB.004 Physical EOF File Header Service name.. ...... .... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .07/01/11 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 GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9877.0 9907.0 STOP DEPTH 11773.5 11803.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27-APR-05 Insite 7.75 Memory 11804.0 9907.0 11804.0 87.6 . MAXI~UM 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 MATR~X: 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD030 ROP MWD030 Units FT API FT/H Size 4 4 4 Rep 68 68 68 Code Nsam 1 1 1 94.8 TOOL NUMBER TLG002 4.125 8847.0 Flopro 8.60 65.0 8.7 23000 5.8 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 . .0 154.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9877 11803.5 10840.3 3854 9877 11803.5 GR MWD030 API 32.5 341.87 70.4687 3794 9877 11773.5 ROP MWD030 FT/H 0.14 423.3 116.829 3794 9907 11803.5 First Reading For Entire File......... .9877 Last Reading For Entire File.......... .11803.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .07/01/11 Maximum Physical Record..65535 File Type... . . . . . . . . . . . . . LO Next File Name....... ....STSLIB.005 . . . Physical EdF Tape Trailer Service name.. ... ....... .LISTPE Date.................... .07/01/11 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.................... .07/01/11 Origin... ............... .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.. .............. .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EqF End Of LIS File
