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199-123
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector 16-10A (PTD #199123) TxIA communication Date:Monday, April 15, 2024 10:03:20 AM Attachments:16-10.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, April 14, 2024 6:36 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Injector 16-10A (PTD #199123) TxIA communication Mr. Wallace, Injector 16-10A (PTD #199123) injection rate was increased on 04/13 and a subsequent IA pressure increase was noted. IA pressure was bled from ~1400 psi to 550 psi and observed to increase to 1400 psi within 2 hours which is indicative of TxIA communication. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR 2. Well Integrity: Repair or secure Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector 16-10A (PTD #199123) TxIA communication Date:Tuesday, April 16, 2024 3:47:01 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, April 16, 2024 2:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: RE: UNDER EVALUATION: Injector 16-10A (PTD #199123) TxIA communication Mr. Wallace, Injector 16-10A (PTD #199123) failed MIT-IA on 04/15 with liquid leak rate of ~2 gpm. The well is now shut in and classified as NOT OPERABLE until well integrity is restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Sunday, April 14, 2024 6:36 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Injector 16-10A (PTD #199123) TxIA communication Mr. Wallace, Injector 16-10A (PTD #199123) injection rate was increased on 04/13 and a subsequent IA pressure increase was noted. IA pressure was bled from ~1400 psi to 550 psi and observed to increase to 1400 psi within 2 hours which is indicative of TxIA communication. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR 2. Well Integrity: Repair or secure Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg��, P.I. Supervisor FROM: Bob Noble Petroleum Inspector (c((C4-e.d7.0 NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 15, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 16-1OA PRUDHOE BAY UNDP 16-IOA See: Inspector Reviewed By: p P.I.Soprv—J -.-- Comm Well Name PRUDHOE BAY UNIT 16-10A API Well Number 50-029-20506-01-00 Inspector Name: Bob Noble Insp Num: mitRCN200614154614 Permit Number: 199-123-0 Inspection Date: 6/14/2020 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - We ll 16-IGA Type In� W TVD 8725 Tubing 1860 - 1857 ' 1856 1858�- -- - -- 991z3o Type Test SPT Test psi z1s1 _IA s6a z713 2678 2662 Pum ed: a.6 BBL Returned: 46 'p OA 258 473 - 476 466 al - — 4YRTST P— Notes: ` Monday, June 15, 2020 Page 1 of I STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate I I Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 199-123 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service m 6. API Number: 50-029-20506-01-00 7. Property Designation(Lease Number): ADL 0028333 8. Well Name and Number: PBU 16-10A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 14180 feet Plugs measured 12124 feet RECEIVED true vertical 9079 feet Junk measured feet AUG n 2016 Effective Depth: measured 12124 feet Packer measured 9506 feet true vertical 9018 feet Packer true vertical 8723.48 feet AOGC C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94/11-1-40 26-105 26-105 1530 520 Surface 2694 13-3/8"72#L-80 25-2719 25-2719 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9850 9868 feet feet 9873-9893 feet 9899-9924 feet 11480-11500 feet 11560-11580 feet 11650-11670 feet 11730-11750 feet 11810-11830 feet 12209-14180 feet True vertical depth: 8990-9001 feet feet 9004-9016 feet 9019-9032 feet 9026-9025 feet 9022-9022 feet 9019-9018 feet 9017-9017 feet 9016-9016 feet 9023-9079 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 21 95661.., 21-8766 Packers and SSSV(type,measured and See Attachment See Attachment--.,,,.SOe,Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED (hj F,( �. s 2017;(¢ �, EIC ri 12(17; 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 11254 700 1537 Subsequent to operation: 4064 1045 500 14.Attachments:(required per 20 AAC 25.070.25.071,&25283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development 0 Service RI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 8/17/16 Form 10-404 Revised 5/2015 f 3 ] 1 C RBDMS VV k\t(30 8 2016 Submit Original Only • • 0 QO000000 CQ N CO CO N O O CO N- O O Cf) LC) 0 N to N- N N- C.)V ) 0 0 0 0 0 0 Co i CO M N- CL) CD M Cr) c co 0) CO A- A- Tr cr CO r4.41. CO 03 CO CO CO M N O CO A- 1.0O C- CO O N N- co O I� N CO CO 00 CA 00 1 1 1 1 1 1 I— C) Cal CO CCS C - '- CO A- N N N CO CO N- N C CO 1-0 O CD CO eh A- N CD M CO O 00 CnlC) N CO O) C7) co C.) ca Q 2 1 1 1 1 1 1 1 co r CO CC) M N C'7 U) A- 0) - 0 N N N N • Mr • W CCS a O co O 0 co i 00 00 1- J J O CO J J • C) = N *kfnJ (0co (%•� O o0 N - U o M N r r O 4 4 L C N- CO 0700 0 a) u N CO N W W Q Q C OF- W O O W W O 22 O u_ cerereZ Z W W W W Z Z D 0 (/) Z Z J • • Packers and SSV's Attachment PBU 16-10A SW Name Type MD ND Depscription 16-10A TBG PACKER 9505.92 8723.48 4-1/2" BAKER S-3 PERM PACKER 16-10A PACKER 9561.05 8765.56 4-1/2" BAKER ZXP PACKER • • # _ > 1- F- -I CO / ES k0 % / 0k $ < 2 ® < E \ % 0 w ƒ < 0 ƒ < o < ¥ ¥ w < w9 « O wd / ƒ <tm O 2U 2 � cc � o ; E o w q ƒ E 20 Lo ¥ ee / E � � � cC \ � � L HD 2 < k o 9 E -w0 O < < E % o 2 E N o < ® b \ � �, R ƒ / a. � f5c 2w0 0 = 0_ o = = = 20 co ¥ �mmm Wo / / m � % m -k � \ ¢ M ƒ \ ¥ \ z $ g o m R o m R w k 2 E Q T. - O c R L o w & o 2 L 0 CI ■ o = OwNL 5 & 2NwW o CO OQ / a� � m w -ISuJ � guJ0 -- % ƒ CO 2 - o , R � / QUA $ / " > 1- Nc ƒ % _5 CD \ CC 0 | aCV - CL / / 0 0 F- / E oD / MSS D � \ k ° ° / 0aUS \ tCO 2 > LI— > c / WR - �Cin� I ® W 0 2300 wOma. a > \ « co zDz / kk � 1 / / D , HDw / >+ / kEEq --- W2 big / E 2 CU O % 2 \ / ® 6 ® 3 6 $ 3 ƒ < o f 0 2 � - 003 ¥ 0 < 0- n « am ¥ w OD QX ¥ 2 = � � OI / 0 ƒ 002 « oz / / .- 1- 5 " ® / W k / E k 1_ 0 k 0 2 / . zR � _J / 2 _ --II � aI ® -I00001 -ja - LL� � 0 / kE2 / ccEE / oc \ � 2 � � LU F_ W w k 9 \ - -w ® �w 11E I \ w w R $ c 2 k z b W a O « ( § 3 § f k a % / R 7 k 0 % \ LL b E L I 0 L q o_ o » 8 cn I- 5 / d qCN > @ F: R ¥ « TREE= 4-1/16"CNN • WE LFE D= FMC SA•NOTES:H2S READINGS AVERAGE 125 ppm ACTUATOR= AXELSON 16-10A WHEN ON NIL ANGLE>70@9972ASSSV WHEN ON PA WELL BEEL.EV= KOP= 4600' Max Angle= 95°@ 10659' I I I 2179' i--L4-1/2"FSS X NP,D=3.81 Datum M)= 9694' Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2725' Minimum ID = 3.726" @ 9640' 4-1/2" HES XN NIPPLE 1 9-5/8'X 7"BOT LNR HANGER H 9238' f C 9608' —L7"X__4-1/2"BKR S-3 PKR D=3.858"] 9640' JH4-112"FES XN NP,ID=3.725"i 19-5/8"CSG,47#,L-80,D=8.681'1 9663' _ " IL I TOP OF 41/2"LN/2_1—d 9666' 9555' 1—7"X 4-1/2'BKR ZXP LTP w 1TEBA CK SLV&BKR HMC HGR,D=3.938' — 4-1/2"TBG,12.6#,L-80 NSCT, 9563' 1. - 9663' —14_-_1/2"yr vrtiEG,ID=4.00" .0152 bpf,D=3.958' 9669' HELM)TT LOGGED 02/22/00 I PERFORATION SUMMARY REF LOG: SPERRY-SUN MAD/GR OF 01/27/00 7"LNR MLLOUT WINDOW ANGLE AT TOP PERF: 49°g 9850' 9736'-9748'(OFF WHPSTOCK) Note:Refer to Roduction DB for historical perf data SIZE SPF N4TBZVAL Opn/Sgz DATE 2-7/8" 6 9850-9868 0 07/20/16 2-7/8" 6 9873-9893 0 07/20/16 2-7/8" 6 9899-9924 0 07/20/16 , 2-7/8" 6 11480-11500 0 01/07/06 2-7/8' 6 11560-11580 0 01/07/06 ,5 12131' —4-1/2"BKRAAK-1 2-7/8" 6 11650-11670 0 01/07/06 ,, CBP(01/07/06) 2-7/8" 6 11730-11750 0 01/07/06 '°'t'"$'4'$°• 5 2-7/8" 6 11810-11830 0 01/07/06 111111111 , 12162' BKR CTC ECP,D=3.875" 4-12" SLID 12209-14180 C 01/31/00 111111111 .1111111111111111 , 12209' —4-1/2'SLOTTED 40040 111111111 X11111111 �► LNRD=3.958' .1111111111111111 .i 7 X11111111111111111 111111111 \ 41111111 \ 1111111111111111 :i 1111111111111111 FES ES 12159' .• \`�" 1111111111111111 .\ 111111111 aMENTER \\ X11111111 1 7"LNR 29#,L-80,I)=6.184711_ 10680' hi1i1i1i1i1i1i1i1i MLL®TO . 3.75"ID - PBTD -f 14180' 4-1/2'SLO t I tU LNR 12.6#,L-80 BT,.0152 bpf,D=3.958" 14180' DATE REV BY COMMENTS DATE REV BY COMVENTS PRUDHOE BAY UNIT 11/10180 ORIGINAL COMPLETION 01/17/06 JRA/PAG CUP&PERFS(01/07/06) VEL: 16-10A 01/31100 RIG SIDETRACK 02/14/11 M31JM) ADDS)SSSV SAFETY NOTE PERMIT No: 1991230 01/04/01 SIS-OAA CONVERTED TO CANVAS 01/17/12 TM'YJMD ADDED HRS SAFETY NOTE AR No: 50-029-20506-01 02/22/01 SIS-LG REVISION 07/07/16 JM) TBG&LNR CLEAN(P SEC 24,T1ON,R15E,2006'SNL&613'EWL 1020/01 CWKAK CORRECTIONS 07/22/16 KFS/JM) ADPBRFS(07/20/16) 11/15/02 JBMKI( FCO BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim jtegg / DATE: Tuesday,June 28,2016 P.I.Supervisor( ? "(lig'? SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 16-10A FROM: Johnnie Hill PRUDHOE BAY UNIT 16-10A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-10A API Well Number 50-029-20506-01-00 Inspector Name: Johnnie Hill Permit Number: 199-123-0 Inspection Date: 6/26/2016 Insp Num: mitJWH160627112115 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 16-10A Type Inj I W'TVD 8725 Tubing 792 796 795 795 , PTD Type Test Test '. —_-- 1991230 SPT psi2181 IA 1 2491 2440 2421 - Interval j4YRTST P/F P ✓ OA 22 40 40 39 Notes: MITIA to 2500 psi 7.3bbls diesel used S Mt4W0 NOV 2 22016 Tuesday,June 28,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, June 04, 2016 2:39 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OIL; AK, OPS PCC EOC IL;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Sternicki, Oliver R; 'jim.regg@alaska.gov'; Ohms, Danielle H; Murphy, Josh T; Sayers, Jessica Subject: OPERABLE:Injector 16-10A (PTD#1991230) Post-VSM Repairs Al I, Injector 16-10A(PTD#1991230)was due for an AOGCC MIT-IA on 10/06/15. On account of surface constraints the well was not placed on injection before the due date and subsequently reclassified as Not Operable. Surface VSM repairs have since completed. The well is now reclassified as Operable and can be placed on injection. An AOGCC MIT-IA will be performed once on stabilized injection. Please mind the fluid packed annuli. Thanks! Jack Lau (Alternate:Adrienne McVey) �� y01 BP Alaska-Well Integrity Superintendent S 1 W: 907.564.5102 C: 907.943.0296 H: x2376 From: AK, D&C Well Integrity Coordinator Sent: Thursday, September 24, 2015 11:01 AM To: AK, OPS FQSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB . ells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Drotar, Mark; 'chris.wallac- - aska.gov' Cc: AK, D&C DHD Well Integrity Engineer; A .,D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer;SStenicki, Oliver R; 'jim.regg@alaska.gov' Subject: NOT OPERABLE: Injector 16-10A (PTD #1991231 'ue for AOGCC MIT-IA All, Injector 16-10A (PTD#1991230) is due for an AOGCC MIT-IA on October 06, 2015. < well will not be on injection for the test before the due date. The well is reclassified as Not Operable until the well is readyto be placed on injection and will be added to the quarterly Not Operable Injector Report . Thank you, 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ~- ! ~,~ File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA ~ Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: .~y~ianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Begerly Dianna Vincent Nathan Lowell Date: Isl I I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 03, 2011 TO: Jim Regg P.I. Supervisor l SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16 -10A FROM: Jeff Jones PRUDHOE BAY UNIT 16 -10A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 16 - 10A API Well Number: 50 029 - 20506 - 01 - 00 Inspector Name: JeffJones Insp Num: mitJJ111024130707 Permit Number: 199 - 123 - Inspection Date: 10/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-10A ' Type Inj, W TVD 8725 ' IA 800 2500 - 2480 2470 ' P.T 1991230 - TypeTest SPT Test psi ' 2181 OA 500 680 680 680 Interval 4 YRTST prn, P - Tubing 1200 1220 1220 1220 Notes: 1 well inspected; no exceptions noted. , ii Thursday, November 03, 2011 Page 1 of 1 MEMORANDUM TO: ~ JimRegg K~~ lC!~i~{~ / P.I. Supervisor FROM: $Ob NOble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday; October 10, 2007 SCBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-10A PRUDHOE BAY UNIT 16-10A Src: Inspector >`rn~r ! nN~'iilF1VTTAT. Reviewed By: P.I. Suprv Comm Well Name• PRUDHOE BAY UNIT 16-10A API Well Number: 50-02 9-20 506-0 1-00 Inspector Name: Bob Noble mitRCN07 1 0061 541 1 9 Insp Num: Permit Number: 199-123-0 Inspection Date: 1015/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ Well 16-10A iType In), i W I T~ 5735 IA 550 ~~ 2410 _~ ~ 3370 ~ 2370 ~ P.T. ' 1991230 1'I'ype'Test . SPT' Test psl ~; 2410 ~~ Q~ ~ ~~ 40 70 70 ~ 70 --F ~ ~_ 1- Interval 4YRTST P~F, P _ TubIDg ' 1400 1400 i i 1400 I 1400 -_ I i J~ Notes: ~,lt~ . ~t~ ~~ ~5~ p^~sS~v`+i? (.~ 1 Zt`b 1?Si /~ / T,,/I l_(~.~l.~i.~~(1 4~I~ 9(tCAC~r rr~~.,L~ +~jv/l/~L`r~ ~`p~L~k (,il~'.4~')~t} c~~P ~' L~ (zk.~'1.~ ~ Cf.•`~l 1.-'~( ~~c'~'fwNll ~ ~j (:ll~/~e-L~ / C.'ZLt 1~(~S LJr ~A-~i4L ~ rCU`~'Ee~ J ~,~~ NCV ~~ 9 2p07 Wednesday, October 10, 2007 Page I of I RECEIVED FEB 1 4 2006 a STATE OF ALASKA e AlAWA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS o o [] 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 64.3 KB 8. Property Designation: ADL-028333 11. Present Well Condition Summary: Total Depth measured 14180 true vertical 9078.78 Effective Depth measured 14180 true vertical 9078.78 Casing Conductor Surface Production Liner Liner Length 80 2696 9525 498 4625 Size 20" 94# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 4-112" 12.6# L-80 Perforation depth: Measured depth: 11480 - 11500 True Vertical depth: 9026.27 - 9025.33 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic D feet feet feet feet Stimulate 0 ' Gas Con~ C9fIiI . . WaiverD Time Extension DAnchora e JfII.IS Re-enter Suspended Well 0 g 5. Permit to Drill Number: 199-1230 R1 6. API Number: 50-029-20506-01-00 9. Well Name and Number: Exploratory Service 16-10A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) t·c·· F·' ~~~.\lIfi'" ,"T,'.d;í, ',I,,'i"'! "\oW' 'I ~¡; ,,;~, ........ MD 30 - 110 29 - 2725 28 - 9553 9238 - 9736 9555 - 14180 11560 - 11580 9022.45 - 9021.62 4-1/2" 12.6# ~"', ¡ ) TVD 30 - 110 29 - 2724.91 28 - 8759.41 8520.49 - 8903.55 8760.94 - 9078.78 11650 - 11670 9018.7 - 9018.15 L-80 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 5012 0 8245 0 15. Well Class after proposed work: Exploratory Development D 16. Well Status after proposed work: Oil D Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Title Data Mgmt Engr Phone 564-4424 12131 None Burst 1530 4930 6870 8160 8430 Collapse 520 2670 4760 7020 7500 11730 - 11750 9017.37 - 9017.1 11810 - 11830 9016.36 - 9016.12 22 - 9563 9508 9562 RBDMs 8Ft FEB .l 4 70D6 Tubing pressure 905 1145 Service R WINJ R WDSPl Date 2/9/2006 Submit Original Only e - 16-10A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVì~~bATE I SUMMARY 1/7/2006 CTU #9, CIBP/PERF; MIRU. MU/RIH wi mem GRICCL & 3.65" drift. Log from 12200'·11400'. Paintflags @ 12000' & 11400'. POOH. ... Job in Progress· Cant' on WSR 01/08/2006... 118/2006 CTU #9, CIBP/PERF; ... Cant' from WSR 01/07/2006 ... RIH with BKR 4.5" CIBP. Tie into flag at 12000'. Set CIBP at 12124' corrected ctmd. POOH. MU/RIH wi Perf BHA #1: 20' of 2-7/8" PJ 6 spf. Tie into flag & tag CIBP for depth correction. Shoot from 11810' - 11830'. POOH. MU/RIH wi Perf BHA #2, same. Tie into flag. Shoot from 11730'·11750'. POOH. Cut 600' pipe. ... Job in Progress· Cant' on WSR 01/09/2006... ADD PERFS: 11810'·11830',11730'·11750'. 1/9/2006 CTU #9, PERF; ... Cant' from WSR 01/08/2006... MU/RIH with PDS mem GR/CCL and 3.0" drift. Tag CIBP at 12155' ctmd up. Log from 12155' to 11400' ctmd. Paint flag at 11400' ctmd. POOH. MU/RIH wi Perf BHA #3: 20' of 2906 PJ, 6 spf. Tie into flag & CIBP, perf from 11650'-11670'. POOH. MU/RIH wi Perf BHA #4: 20' of 2906 PJ, 6 spf. Tie into flag, tag CIBP, perf from 11560'-11580'. POOH. MU/RIH wi Perf BHA #5: 20' of 2906 PJ, 6 spf. Tie into flag, perf from 11480'·11500' corrected ctmd. POOH. ADD PERFS: 11650'·11670', 11560'·11580', 11480'·11500'. 1/10/2006 CTU #9, CIBP/PERF; ... Cant' from WSR 01/09/2006... Injectivity test. 4.0 bpm at 1150 psi. RDMO. *** Job Complete *** FLUIDS PUMPED BBLS 389 160/40 Meth TOTAL 389 16-10A (PTD #I 991230) Passing MITIA Subject: 16-10A (P~1991230~ssing MITIA Date: Wed, 24 Sep 20D3-I9703:25 -0500 From: "Dube, Anna T" <Anna. Dube~BP.com> To: "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us> Attached is a MITIA form for 16-10A for your records. Let me know if you have any questions. <<MIT PBU 16-10A 09-21-03.xls>> Anna Dube Well Integrity Engineer 907-659-5102 I ~_)MIT PBU 16-10A 09-21-03.xlsi Type: Microsoft Excel Worksheet (application/vnd.ms-excel) 1 I :lEnc°ding' base64 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state. ak.us; Bob_Fleckenstein@admin.state. ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / DS 16 09/21/03 Anna Dube Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. 1991230 Type test P Test psiI 2181.25 Casin~l 1501 4,0001 3,9101 3,8501 p/FI P Notes: Pre-MI Injection Well P'T'D'I [ Typelnj. Notes: Well TVD Type tesll Casingl I I IInterval P/FI Notes: Well TVD Type teslI Casin~ll [ I IInterval P/FI Notes: TVD P/FI Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-092 I_M IT_P B U_I 6~10A_preinj.xls Permit to Drill No. 1991230 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. PRUDHOE BAY UNIT 16-10A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20506-01-00 MD 14180 TVD REQUIRED INFORMATION 9079 Completion Date 1/31/2000 Completion Status 1GINJ Current Status 1GINJ UIC Y Mud Log N._~o Samples Nc) Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Log Log Run Type Media Format Name.- Scale Media No .................................. i~S-i~Q;¢ -R~T ,~'GR/EWR-MD , 25 FINAL L--'"~DGR/EWR-TVD ' 25 FINAL (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH 30 14180 OH Dataset Received Number Comments 2/16/2000 SPERRY 9694.. ~'/JWL/BHP 5 FINAL R LIS Verification FINAL ,..,,,~ Warmback Survey FINAL 9717 14180 8888 9O78 9000 10010 12100 14080 OH OH O O CH CH CH 9/8/2000 7/17/00 TH RU 9/8/2000 1/17/00 THRU 8/30/2000 09599/ ~/' 9703-14121 / 9/5/2000 09801 ,/' 9703-14121 3/14/2000 2/27/2001 LIS Verification Paper Copy 1/3/2001 BL Interval Name Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored'? Y / ~ ,.An alysis. Ro~e~ved..~-Y-/4b,. Daily History Received? Formation Tops Receuived? Comments: Permit to Drill No. 1991230 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. PRUDHOE BAY UNIT 16-10A Operator BP EXPLORATION (ALASKA) 1NC APl No.. 50-029-20506-01-00 MD 14180 TVD 9079 i { Completion Date 1/31/2000 Compliance Reviewed By: ...............................~ Completion Status 1GINJ Current Status 1GINJ UIC Y Date: I ELL T IAIIISMff'I' IL ProActive Diagnostic Services, Inc. 1 State of Alaska AOGCC Lori Taylor 3001 Porcupine SL Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Robert Richey ProActive Oiagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petretechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG OIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT{S} OR CD-ROM FILM COLOR Open Hole I I 1 16-10Ai i ?-- ~ 7- o O Res. Eval. CH 1 )% .. 1 Mech. CH Caliper Survey Signed' ~~~~ Print Name: Date: RECEIVED Jk l 0 3 2001 Alask~ ~i & Gas Cons, Commi~ion /~chorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog, com Website: www.memor¥1og, com r'"l R ILL I i~1 I~ cn E R ~/I r-' E c:; To: State of Alaska Alaska-Oil and-~~~Com~ Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 5, 2000 RE: MWD Formation Evaluation Logs · D.S. 16-10A,. AK-MM-90224 The technical data listed below is being submitted herewith. Please address any problems or concerns to-theatterm'.'on of.' Jan Gal~_Sp.eny-Sun DdllingSerdces,~5631 Silverado Way,_#G, Anchorage~.AK 99518 D;S'. t 6-10A: 2"x 5:' M]~.,~,o,~y &- ~~-~ 50-029--20506-O1~ 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-205_06,01 1- Blueline }-Forded Sepia 1 Blueline 1. Folded. Sepia RECEIVEW SEP 08 2000 Alaska 0ii & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company Ci R I L..I_ I IM I~ SE~FtVICE~ p- To: State of Alaska August 31, 2000 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 16-10A, AK-MM-90224 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Tan GaMn, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20506-01. Note: This data replaces any previous data for well 16-10A_ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company D R I ~i,.,I I'll I~ C:;E~RVI C E 5 To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 AK-MM-90224 MWD Formation Evaluation Logs - D.S. 16-10A, August 25, 2000 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Yum Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20506-01. RECEIVE D AUG ,, 2000 Alaska 0il & Gas 0ohs. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Gas Injection 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 199-123 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20506-01 4. Location of well at surface ~ ~C'~?Li_'TI~N , ~~S-'~ 9. Unit or Lease Name 2006' SNL, 613' EWL, SEC. 24, T10N, R15E, UM I i.,y]J~ ! Prudhoe Bay Unit At top of productive interval At total depth .~t~ 10. Well Number 1839' SNL, 433' EWL, SEC. 25, T10N, R15E, UM i ...................... ~ ~~~ 16-10A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 64.30' ADL 028333 offshore 16. No. of Completions 1/19/2000 1/26/2000 1/31/2000 N/A MS L One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 14180 9079 FTI 14180 9079 FTI [] Yes [] NoI (Nipple) 2179' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'~rOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 110' 32" 300 sx Permafrost to surface 13-3/8" 72# L-80 Surface 2725' 17-1/2" 2300 sx Fondu, 200 sx Permafrost 9-5/8" 47# S00-95 / L-8¢ Surface 9553' 12-1/4" 500 sx Class 'G' 7" 29# L-80 9238' 9736' 8-1/2" .502 sx Class 'G' 4-1/2" 12.6# L-80 9555' 14180' 6" 456 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 9563' 9508' MD TVD MD TVD 12209'- 14178' 9023' - 9079' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 0RIGINAL Freeze Protect with 137 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 12, 2000 MI Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE ] GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River 9728' 8897' Shublik 9768' 8930' Sadlerochit / Zone 4 9863' 8998' 81. List of A~achments: Summa~ of Daily Drilling RepoMs, 8u~eys 88. I hereby ce~i~ that the foregoing is true and correct to the best of my knowledge Signed TerrieHubbie ~~ ~ Title Technical Assistantlll Date 16-10A 199-198 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number 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 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility Date/Time 06 Jan 00 07 Jan 00 08 Jan 00 PB DS 16 Progress Report Well 16-10A Page Rig Nab@rs 9ES Date 1 07 February O0 16:00-06:00 16:00-22:30 22:30 22:30-01:00 01:00 01:00-06:00 06:00-06:00 06:00-16:00 16:00 16:00-16:30 16:30 16:30-23:00 23:00 23:00-06:00 06:00 06:00-19:30 06:00-12:00 12:00 12:00-19:30 19:30 19:30-02:00 19:30-20:30 20:30 20:30-22:30 22:30 Duration 14hr 6-1/2 hr 2-1/2 hr 5hr 24 hr 10hr 1/2 hr 6-1/2 hr 7hr 13-1/2 hr 6hr 7-1/2hr 6-1/2m lhr 2hr Activity Move rig Rig moved 30.00 % Rig off station Move Pit Pit Module, camp and Workshop to drillsite 16. Rigged up Rig services Equipment work completed Rig moved 40.00 % Move fig from W pad along spine road and make it to J pad access by report time. Move rig (cont...) Rig moved 60.00 % Rig off station Move Substructure along spine road and stop at Sag River enttrance in Veco Yard. MaFirst 300 yards of Sag fiver matted as per Bob Llewellan Request. Matting completed while rig moving along spine. Held safety meeting Completed operations Hold Safety Meeting with all relevant parties to discuss ice road crossing. Rig moved 80.00 % At well location - Slot Move rig across ice road and arrive at well location @ 2100 hours. Lay herculite, mat and prepare to raise derrick. Rigged up Drillfloor / Derrick Equipment work completed Spot rig over well. Spot shop, camp and Pit Complex. Commence berming rig @ report time. Move rig (cont...) Rig moved 90.00 % At well location - Slot Berm Rig and Lay Herculite, Spot Cuttings box and connect mudlines. Prepare rig for acceptance. Able to take on fluid @ 1200 hrs. Installed Mud pumps Equipment work completed With rig in "start-up mode" work on assembling fluid ends of mud pumps. Concurrently replace top drive brake pads, hang bridal lines and lower blocks. Hook up top drive and function test same. Take on Water into pits. Wellhead work Rigged up High pressure lines Equipment work completed R/U Lines to test annulus. Accept Rig for normal operations @ 1930 hrs 8th January 2000. Tested Hanger plug Pressure test completed successfully - 1000.000 psi Test mudlines to 1500 psi with mud pump #1. Test annulus to 1000 psi up against BPV. ( Note had IIUWg.,IIg.,h..,I~k,,U W~,II VVIIIIU . Facility PB DS 16 Progress Report Well 16-10A Page 2 Rig Nabors 9ES Date 07 February 00 Date/Time 09 Jan 00 10 Jan 00 22:30-23:00 23:00 23:00-02:00 02:00 02:00-06:00 02:00-06:00 06:00-13:00 06:00-09:30 09:30 09:30-13:00 13:00 13:00-14:30 13:00-14:30 14:30 14:30-19:00 14:30-19:00 19:00 19:00-23:30 19:00-23:30 23:30 23:30-06:00 23:30-06:00 06:00 06:00-17:00 06:00-16:00 16:00 16:00-17:00 17:00 17:00-20:30 17:00-18:00 Duration 1/2 hr 3hr 4hr 4hr 7hr 3-1/2 hr 3-1/2 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 4-1/2 hr 6-1/2 hr 6-1/2 hr llhr 10hr lhr 3-1/2 hr 1 hr Activity Held safety meeting Completed operations Shut rig down and clean up all ice/water and slippage points around rig after rig up. Removed Xmas tree Equipment work completed Remove Xtree and install blanking plug for BOP test. BOP/riser operations - BOP stack Rigged up BOP stack N/U BOPE and commence installing rams @ 0500 hrs. BOP/riser operations - BOP stack (cont...) Installed BOP stack Equipment work completed Install Top and bottom Variable Rams ( 2.7/8" x 5") and Shear Rams. Rigged up Drillstring handling equipment Equipment work completed Clear rigflkoor. P/U Test equipment and M/U tools and test joint. Fill Lines and prepare to Test. AOGCC John Crisp - Witness. Repair Repaired Mud pumps Equipment work completed Attempt to pressure up on BOP- Fitting failure on BOP test pump. Troubleshoot and resolve same. Test well control equipment Tested BOP stack Suspended function test, problems encountered Test BOPE as per prog, 5000 psi. John Crisp from AOGCC witness. Unable to get satisfactory test on Blind/Shear. Repair Repaired Blind / Shear ram Equipment work completed Change out blind/shear rams. Test same to 5000 psi- good. Wellhead work Removed VR plug Equipment work completed Remove Blanking plug. Work on backing out Lockdown screws. 50% in bad shape. Great difficulty in removing same. At report all but one removed- will have to drill out. Wellhead work (cont...) Removed VR plug Equipment work completed Drilled out last remaining Lockdown bolt and retap. · Install replacement LDS. Removed Hanger plug Equipment work completed R/U and pull hanger plug. Flowcheck well- static. BHA run no. 1 Made up BHA no. 1 Facility PB DS 16 Progress Report Well 16-10A Page 3 Rig Nab@rs 9ES Date 07 February 00 Date/Time 11 Jan 00 12 Jan 00 18:00 18:00-19:00 19:00 19:00-20:30 20:30 20:30-00:00 20:30-00:00 00:00 00:00-02:15 00:00-02:15 02:15 02:15-06:00 02:15-06:00 06:00-12:30 06:00-12:30 12:30 12:30-16:30 12:30-16:30 16:30 16:30-06:00 16:30-06:00 06:00-13:00 06:00-13:00 13:00 13:00-14:30 13:00-14:30 14:30 Duration lhr 1-1/2 hr 3-1/2 hr 3-1/2 hr 2-1/4 hr 2-1/4 hr 3-3/4 hr 3-3/4 hr 6-1/2 hr 6-1/2 hr 4hr 4 hr 13-1/2 hr 13~1/2 hr 7hr 7hr 1-1/2 hr 1-1/2 hr Activity BHA no. 1 made up Make up BHA #1. Double spear assembly and engage tubing. Fished at 40.0 ft Fish came free Pull Tubing free- Upweight 148 klbs. L/D Hanger ( NORM same).and Fishing tools. Circulated at 9182.0 ft Obtained clean returns - 150.00 % hole volume Circulate out freeze protect and Bottoms up. Flowcheck 15 minutes- static. 4in. Packer assembly workstring run Set packer at 85.0 ft with 0.0 psi Packer set at 85.0 ft Pull 4 joints- NORM same- OK. M/U RTTS and set same at 85 ft. Test to 1000 psi from below- OK. Pull back one stand DP and blowdown TD. Nipple down BOP stack Rigged down BOP stack Equipment work completed N/D BOP and stand back. Wellhead work Removed Tubing head spool BOLDS until 0430 hrs. Remove tubing spool and pack@ff. Cleaning seal area @ report time. Wellhead work (cont...) Installed Tubing head spool Equipment work completed Clean seal area. Install 9.5/8" Pack-off and tubing spool. Test same to 5000 psi - good. Nipple up BOP stack Rigged up Well control Equipment work completed Level Rig and NFU BOP. Run test plug and fill stack. Prepare to test Tubing Spool/BOP flange to 5000 psi against Blind Rams. Repair Repaired Blind / Shear ram Unable to obtain test. Blind Ram piston seal failure. Unable to split bonnet. Replace Blind Ram door assembly. Testing same @ report time- looking good. Repair (cont...) Repaired Variable ram Blind Ram test Good. Unable to test Blind Door seal due to leaking Upper VBR's. Replace Ram blocks with 4.1/2" Rams. Test all BOP Rams as per AOGCC, John Crisp request- good. Pull Test -plug. Install wear ring. Equipment work completed 9-5/8in. Packer assembly workstring run Pulled out of hole to 0.0 ft At BHA RIH and sting into RTTS- check for pressure- zero. Release RTTS and recover same to rigfloor. Facility Date/Time 13 Jan 00 14 Jan 00 Progress Report PB DS 16 Well 16-10A Page 4 Rig Nabors 9ES Date 07 February 00 14:30-04:30 14:30-15:30 15:30 15:30-03:30 03:30 03:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-06:00 08:00-10:30 10:30 10:30-18:00 18:00 18:00-19:00 19:00 19:00-21:00 21:00 21:00-22:00 22:00 22:00-23:00 23:00 23:00-23:15 23:15 23:15-04:00 04:00 04:00-06:00 06:00-06:15 06:00-06:15 06:15 06:15-00:30 06:15-08:00 Duration 14hr lhr 12hr lhr 1-1/2 hr 1-1/2 hr 2 hr 2 hr 22 hr 2-1/2 hr 7-1/2 hr lhr 2 hr 1 hr lhr 1/4 hr 4-3/4 hr 2 hr 1/4 hr 1/4 hr 18-1/4 hr 1-3/4 hr Activity Pull Gas lift completion, 4-1/2in O.D. Rigged up Completion string handling equipment Equipment work completed R/U Control line spooling unit and Handling equipment to pull tubing. Laid down 9182.0 ft of Tubing Fish at surface POOH L/D Tubing. 25 SS bands recovered. 212 joints, 6 x GLM and 3.65 ft of cut off recovered. Cut in good shape. Rigged down Completion string handling equipment Equipment work completed R/D Handling equipment and clear rigfloor. BOP/riser operations - Top ram Rigged down BOP stack Equipment work completed Pull Wear ring and run test plug. Remove Top 4.1/2" Rams @ report time. BOP/riser operations - Top ram (cont...) Tested BOP stack Pressure test completed successfully - 5000.000 psi Test Top Rams to 5000 psi. Good. R/D Test string and install wear ring. BHA run no. 2 Made up BHA no. 2 BHA no.' 2 made up M/U BHA #2- 8.1/8" Overshot w/4.1/5" Grapple. Singled in drill pipe to 6390.0 ft Began precautionary measures Serviced Block line Line slipped and cut Singled in drill pipe to 9100.0 ft 285 joints picked up Continue RIH picking up 4" drillpipe. Fished at 9149.0 ft Fish came free Wash over fish @ 9,149'. Attempt several times to back out K anchor. No go. Jar out PBR w/130 klbs o/pull. Circulated at 9149.0 ft Obtained bottoms up (100% annulus volume) CBU @ 9 BPM/960 psi. Flow check Observed well static Pulled out of hole to 500.0 ft At BHA Laid down fish POOh BHA anbd L/D Fish- GLM and Seals. BHA run no. 2 (cont...) Laid down fish Complete fish recovered Lay out PBR seal assembly. No go OD 6.9/16". BHA run no. 3 Made up BHA no. 3 Facility PB DS 16 Progress Report Well 16-10A Page 5 Rig Nabors 9ES Date 07 February 00 Date/Time 15 Jan 00 08:00 08:00-13:00 13:00 13:00-17:00 17:00 17:00-19:00 19:00 19:00-00:00 00:00 00:00-00:30 00:30 00:30-06:00 00:30-02:00 02:00 02:00-05:00 05:00 05:00-06:00 06:00 06:00-15:30 06:00-06:30 06:30 06:30-07:00 07:00 07:00-07:30 07:30 07:30-09:00 09:00 09:00-13:30 13:30 13:30-15:30 15:30 15:30-03:30 15:30-16:15 16:15 16:15-19:45 19:45 19:45-20:15 20:15 Duration 5hr 4 hr 2 hr 5 hr 1/2 hr 5-1/2 hr 1-1/2 hr 3hr lhr 9-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 4-1/2 hr 2hr 12hr 3/4 hr 3-1/2 hr 1/2 hr Activity BHA no. 3 made up MFU BHA #3- 7" Milling Shoe and washover pipe. R.I.H. to 9170.0 ft At Top offish · 9170.0 ft RIH with Wash over assembly. Tag fish @ 9,177'. Milled Permanent packer at 9201.0 ft Completed operations Wash over and mill on Packer slips @ 9,198'. Mill down to 9,201'. 70 RPM/5 kftlbs. Observe slips breaking through. Push down 5 ft- unable to go deeper. Circulated at 9170.0 ft Obtained bottoms up (100% annulus volume) CBU. Well stable. Flowcheck. Pump Dry job. Pulled out of hole to 500.0 ft At BHA Pulled BHA BHA Laid out BHA laid out. No metal in boot basket. BHA run no. 4 Made up BHA no. 4 BHA no. 4 made up M/U Spear assembly. R.I.H. to 8100.0 ft Stopped · To service drilling equipment Serviced Block line Line slipped and cut BHA run no. 4 (cont...) Serviced Top drive Equipment work completed R.I.H. to 9184.0 ft At Top offish · 9184.0 ft Fished at 9184.0 ft Fish came free Engage fish and pull free with 125 klbs o/pull Circulated at 9184.0 ft Obtained bottoms up (100% annulus volume) Circulate bottoms up @ 560 GPM/1475 pai reciprocating pipe- Intermittent drag upto 100 klbs. Pulled out of hole to 300.0 ft At BHA POOH. Occaisonal drag. Laid down fish Partial fish recovered Stand back BHA. Recover barrel ( 6.9/16" OD). Fish pulled apart @ K-anchor. Packer still in hole. L/D fish and release spear. BHA run no. 5 Made up BHA no. 5 BHA no. 5 made up M/U Spear BHA w/4.805" grapple. R.I.H. to 9180.0 ft At Top of fish · 9180.0 ft Fished at 9200.0 ft Fish came free C~ .... l?'~.-k ~--.-,1 ..... 1. C ...... .'~-L l"3t'~ 1.1k ........ I1 o[Ju~O.l 11311 O,.llkl v~Jll'~ ll~.,~.~ I~'ltll ~-kJ lklL/b U¥~,llJUll. Facility Date/Time 16 Jan 00 17 Jan 00 PB DS 16 Progress Report Well 16-10A Page 6 Rig Nabors 9ES Date 07 February 00 20:15-00:00 00:00 00:00-03:30 03:30 03:30-06:00 03:30-06:00 06:00-09:00 06:00-09:00 09:00 09:00-06:00 09:00-11:30 11:30 11:30-15:00 15:00 15:00-17:00 17:00 17:00-17:30 17:30 17:30-19:15 19:15 19:15-20:15 20:15 20:15-22:30 22:30 22:30-00:00 00:00 00:00-01:30 01:30 01:30-04:00 04:00 Duration 3-3/4 hr 3-1/2 hr 2-1/2 hr 2-1/2 hr 3 hr 3hr 21hr 2-1/2 hr 3-1/2 hr 2hr 1/2 hr 1-3/4 hr 1 hr 2-1/4 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr Activity Very tight first two stands. Pulled out of hole to 300.0 ft At BHA Laid down fish Complete fish recovered L/D packer and tailpipe fish- total length 77.82 ft. L/D fishing tools and 6.1/4" collars. Clear rigfloor. BHA run no. 6 Made up BHA no. 6 MFU Cleanout BHA @ report time. Repair Repaired M.W.D. tool Equipment work completed Unable to communicate to MWD tool. Troubleshoot- broken electrical connection, change adaptor tips. BHA run no. 6 Made up BHA no. 6 BHA no. 6 made up M/U remainder of BHA- picking up 9 x 4.75" DC's and 18 x HWDP. Surface test MWD @ 1,017' R.I.H. to 9139.0 ft Began precautionary measures Washed to 9571.0 ft On bottom Wash down from 9,139'. Tag TOL ( 7" ) @ 9,232'. Rotate thru. Unable to slide thru. wash down into liner and tag TOC/junk @ 9,571 '- 96 ft higher than expected. Circulated at 9571.0 ft Obtained bottoms up (100% annulus volume) Tested Casing - Via annulus and string Pressure test completed successfully - 4000.000 psi Pull back above 7" liner @ 9,232'. Test casing to 4000 psi/30 minutes. 9.3 bbls pumped/returned. Held drill (Kick (well kill)) Completed operations Conduct Well Kill Drill. D5 holding 400 psi on wellbore Drilled cement to 9699.0 ft Drill stringers/junk down to 9,660' and hard cement down to 9,699' Stopped: To circulate Circulated at 9699.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean prior to drilling into perforations. ( Potential overpressure) Drilled cement to 9754.0 ft At Setting depth: 9754.0 ft Drill ahead to 9,754 correlating GR. Observe top Sag @ 9,734'. Circulated at 9754.0 ft Hole displaced with Water based mud - 110.00 % displaced Flowcheck- good. Displace well to 8.6 ppg Quikdrill while reciprocating pipe. Facility PB DS 16 Progress Report Well 16-10A Page 7 Rig Nabors 9ES Date 07 February 00 Date/Time 18 Jan 00 04:00-05:30 05:30 05:30-06:00 06:00-10:30 06:00-06:30 06:30 06:30-08:30 08:30 08:30-10:30 10:30 10:30-18:15 10:30-14:30 14:30 14:30-18:15 18:15 18:15-06:00 18:15-21:30 21:30 21:30-02:30 02:30 02:30-03:00 03:00 03:00-06:00 03:00-06:00 06:00-15:30 06:00-06:30 06:30 06:30-07:30 07:30 07:30-08:30 Duration 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 2 hr 2hr 7-3/4 hr 4 hr 3-3/4 hr 11-3/4 hr 3-1/4 hr 5 hr 3hr 3 hr 9-1/2 hr 1/2 hr lhr lhr Activity Pulled out of hole to 6250.0 ft Stopped: To service drilling equipment Some intermittent drag pulling out of liner. POOH. Serviced Block line Slip and Cut Drilline. BHA run no. 6 (cont...) Serviced Top drive Equipment work completed Pulled out of hole to 500.0 ft At BHA Pulled BHA BHA Laid out Laid out BHA. Both boot baskets full of scale and junk. Mill junk damaged on outside diameter. BOP/riser operations - Failsafe valves Installed Failsafe valves Equipment work completed Replace HCR choke valve. Tested BOP stack Pressure test completed successfully - 5000.000 psi Test BOPE to 5000 psi. John Spalding of AOGCC waived witness of test. R/D test equipment. Install wear ring. BHA run no. 7 Made up BHA no. 7 BHA no. 7 made up M/U Whipstock BHA, orientate and surface check MWD. PFLI Dc's and HWDP. R.I.H. to 9705.0 ft Began precautionary measures RIH @ moderate speed checking MWD @ 6570. Carefully go past liner top- no indication. Set tool face Completed operations Hook up top drive and orientate whiptosck. Set same @ 46 deg Left High side. Milled Casing at 9744.0 ft Continue milling casing 9744-9748'. Milled Casing at 9744.0 ft Mill Window from 9,736' to 9,744 @ report time sweeping hole. BHA run no. 7 (cont...) Milled Casing at 9748.0 ft (cont...) Mill Window from 9,736' to 9,744 @ report time sweeping hole. At Kick off depth: 9748.0 ft Window complete 9736' - 9748'. Drilled to 9760.0 ft Drilled OH below window 9748' - 9760'. PUW 190, SOW 170, RW 182. Stopped: To circulate Circulated at 9760.0 ft Pump LVS @ 320 gpm / 1530 psi (3 hi vis sweeps pumped while milling window). Recip pipe. j.. Facility PB DS 16 Progress Report Well 16-10A Page 8 Rig Nabors 9ES Date 07 February 00 Date/Time 19 Jan 00 20 Jan 00 08:30 08:30-12:30 12:30 12:30-14:30 14:30 14:30-15:30 15:30 15:30-06:00 15:30-17:00 17:00 17:00-18:00 18:00 18:00-18:30 18:30 18:30-01:00 01:00 01:00-02:30 02:30 02:30-03:30 03:30 03:30-06:00 03:30-06:00 06:00-06:00 06:00-00:30 00:30 00:30-02:00 02:00 02:00-03:30 Duration 4hr 2 hr 1 hr 14-1/2 hr 1-1/2 hr 1 hr 1/2 hr 6-1/2 hr 1-1/2 hr lhr 2-1/2 hr 2-1/2 hr 24 hr 18-1/2 hr 1-1/2 hr 1-1/2 hr Activity Obtained bottoms up (100% annulus volume) Pulled out of hole to 957.0 ft Pulled BHA Lay down BHA and download MWD. BHA Laid out Serviced BOP stack Flush BOP stack and blow down top drive .... . Equipment work completed ~:, BHA mn no. 8 Made up BHA no. 8 MWD failed - Continue M~ probe/software interface not responding. Se~iced M.W.D. tool Change out probe and re-test MWD Equipment work completed Made up BHA no. 8 Continue maMng up BHA 8. BHA no. 8 made up R.I.H. to 9192.0 ft PU and rabbit 3-1/2" DP. Shallow test / fill pipe ~ 2689'. Stopped: To service drilling equipment Se~iced Block line Slip 40', cut 80'. Service top drive. Line slipped and cut R.I.H. to 9658.0 ft Make up top drive. Orient ~. On bottom Drilled to 9780.0 ft P~ 180, SOW 165. Initiate Mck off, control drill. Drilled to 9780.0 fl Slide t~ough entire build section, some difficulty w/M~ data obver 60' interval in 9900' zone. Hole conditions good, no difficulty sliding. ART 5.5, AST 11.5. BHA mn no. 8 (cont...) Drilled to 10405.0 ft (cont...) Slide t~ough entire build section, some difficulty w/M~ data obver 60' interval in 9900' zone. Hole conditions good, no difficulty sliding. ART 5.5, AST 11.5. Began precautiona~ measures Circulated at 10405.0 ft Circulate 25-bbl hi-vis sweep ~ 238 gpm, 1650 psi (rot & recip). No appreciable increase in cuttings returned with sweep. Obtained clean returns - 110.00 % hole volume Pulled out of hole to 9866.0 ft Short trip to window, log 10,010 to 9935' (bit depth) ~ 200 fph to retrieve missing data required for remainder of drilling. 5Klbs max drag during trip. Facility PB DS 16 Progress Report Well 16-10A Page 9 Rig Nabors 9ES Date 07 February 00 Date/Time 21 Jan 00 22 Jan 00 03:30 03:30-04:00 04:00 04:00-05:15 05:15 05:15-06:00 06:00-06:00 06:00-12:00 12:00 12:00-00:00 00:00 00:00-06:00 00:00-06:00 06:00-06:00 06:00-12:00 12:00 12:00-00:00 00:00 00:00-06:00 Duration 1/2 hr 1-1/4 hr 3/4 hr 24 hr 6hr 12hr 6 hr 6hr 24 hr 6hr 12hr 6 hr Activity At Window · 9748.0 ft Se~iced Top drive Equipment work completed to o4o5.o :t , :.'::x¥ 0 9 000 RIH to TD, tie-in survey. Drilled to 10435.0 ft Continue drilling 10,435' to 10,670'. P~ 180, SOW 160, RW 172 AST 0.5, ART 5.0 Solids van apparently effective in reducing dilution. Increased lubricant to 4% (from 3%) to aid sliding. BHA mn no. 8 (cont...) Drilled to 10670.0 fl (cont...) Continue drilling 10,435' to 10,670'. P~ 180, SOW 160, RW 172 AST 0.5, ART 5.0 Solids van apparently effective in reducing dilution. Increased lubricant to 4% (from 3%) to aid sliding. Began precautionary measures Drilled to 11059.0 ft PUW 185, SOW 160, RW 175, TQ 5-K ftlbs ART 3.0, AST 7.0 Sliding left approx 400' to achieve driectional profile. Plan 14 dgr doglegs, achieving 16-20. Pumping hi-vis sweeps as required. Began precautionary measures Drilled to 11205.0 ft ART 2.5, AST 1.5 Continue drilling as per directional plan. Drilled to 11205.0 ft Continue ddling from 11,205 to 11,501' P~ 185, SOW 160, RW 175 TQ 5-6 on bottom, 4K ft-lbs off Two of four hi-vis sweeps pumped returned increased cuttings. AST 2.75 ~s, ART 7.25 hrs BHA mn no. 8 (cont...) Drilled to 11205.0 ft (cont...) Continue dfiling from 11,205 to 11,501' P~ 185, SOW 160, RW 175 TQ 5-6 on bottom, 4K ft-lbs off Two of four hi-vis sweeps pumped returned increased cuttings. AST 2.75 hrs, ART 7.25 hrs Began precautionary measures Drilled to 11909.0 ft ART 7 hrs, AST 2 ~s One sweep pumped Began precautionary measures Drilled to 11980.0 ft ART 1 hr, AST 2.75 hrs Facility PB DS 16 Progress Report Well 16-10A Page Rig Nabors 9ES Date 10 07 February 00 Date/Time 23 Jan 00 24 Jan 00 00:00-06:00 06:00-06:00 06:00-12:00 12:00 12:00-00:00 00:00 00:00-06:00 00:00-06:00 06:00-06:00 06:00-12:00 12:00 12:00-00:00 00:00 00:00-06:00 00:00-06:00 Duration 6hr 24 hr 6hr 12hr 6 hr 6 hr 24 hr 6hr 12hr 6hr 6hr Activity Upper apex of section at +/- 11,950'. Sliding Drilled to 11980.0 ft Continue drilling from 11,980 to 12,088'. Field interpretation suggests 20' throw fault crossed, resulting in cutting Shublik 3' vertical, -140' horizontal before dropping back into zone 4. ART 2.75 hrs, AST 6 hrs. BHA run no. 8 (cont...) Drilled to 12088.0 ft (cont...) Continue drilling from 11,980 to 12,088'. Field interpretation suggests 20' throw fault crossed, resulting in cutting Shublik 3' vertical, -140' horizontal before dropping back into zone 4. ART 2.75 hrs, AST 6 hrs. Began precautionary measures Drilled to 12585.0 ft Drill 12,088 to 12,585'. ART 7 hrs, AST 2 hrs Pumped hi vis sweep as required. Minor sets down and right to compensate for walking/building tendancy. Began precautionary measures Drilled to 12820.0 ft Continue drilling 12,820' to 13,084'. Pump hi-vis sweeps 12,665', 780', 908', and 13,015'. Sweeps generally effective. ART 2 hrs 45 min, AST 1 hr Drilled to 12820.0 ft Continue drilling from 12,585' to 12,820'. ART 4 hrs, AST 15 min. Hole conditions good, will refrain from short trip until indications deem it prudent. BHA run no. 8 (cont...) Drilled to 13084.0 ft (cont...) Continue drilling from 12,585' to 12,820'. ART 4 hrs, AST 15 min. Hole conditions good, will refrain from short trip until indications deem it prudent. Began precautionary measures Drilled to 13490.0 ft Drill 13,084 to 13,490' ART 8 hrs 15 min, AST 1 hr Occasional 15' slides to maintain inclination Began precautionary measures Drilled to 13630.0 ft Drill 13,490' to 13,630'. ART 3 hrs, AST 2 hrs Weights unchanged last 24 frs: PUW 190, SOW 150, RW 174, TQ 5500 ft-lbs. Reservoir drilled increasing in shale since last trough (-13,000'). Projected TD still 14,275'. Drilled to 13630.0 ft Continue drilling 13,630-13,652'. PUW 190, SOW 145, RW 174. Pick up off bottom after motor stall. At 200K up, },,~,~ j .... },,.u w/~L,-~-ing 'L,,~ .... ~,." ~,~, ,.~¢~ .... ,~,,,~' loss of Facility PB DS 16 Progress Report Well 16-10A Page Rig Nabors 9ES Date 11 07 February 00 Date/Time 25 Jan 00 06:00-09:00 06:00-09:00 09:00 09:00-21:00 09:00-09:30 09:30 09:30-18:30 18:30 18:30-21:00 21:00 21:00-23:30 21:00-21:30 21:30 21:30-23:15 23:15 23:15-23:30 23:30 23:30-06:00 23:30-01:30 01:30 01:30-02:30 02:30 02:30-03:00 03:00 03:00-06:00 03:00-06:00 06:00-06:00 06:00-09:30 Duration 3 hr 3 hr 12hr 1/2 hr 9 hr 2-1/2 hr 2-1/2hr 1/2 hr 1-3/4hr 1/4 hr 6-1/2 hr 2hr lhr 1/2hr 3hr 3hr 24 hr 3-1/2 hr Activity circulating pressure. Shut down pumps. BHA run no. 8 (cont...) Drilled to 13652.0 ft (cont...) Continue drilling 13,630-13,652'. PUW 190, SOW 145, RW 174. Pick up off bottom after motor stall. At 200K up, pipe jumped w/string loss of 55K and loss of circulating pressure. Shut down pumps. After backoff: PUW = 135, SOW = 130 Observed loss of 55.00 klb string weight Repair Repaired Drillpipe Screw back into drillpipe (estimated depth of back-off: 6500'). Torque up four times to 15K. Pick up: normal weight re-gained. Equipment work completed Pulled out of hole to 210.0 ft POH, visually checking all connections. 10-15K occasional drag in openhole. Did not encounter location of pipe back-off. At BHA Pulled BHA L/O Jars, adjust motor to 1.5 degree, remove bit. Dull: 3 2 WT ALL X IN ER PPT Download MWD LD MWD and motor BHA Stood back Test well control equipment Retrieved Wear bushing Equipment work completed Tested BOP stack Test rams 250/5000 psi, annular 250 / 3500 psi. Witness waived by Chuck Shieve, AOGCC RD test joint. Pressure test completed successfully - 5000.000 psi Installed Wear bushing Equipment work completed BHA run no. 9 Made up BHA no. 9 Upload new MWD, PU new jars, re-run bit. BHA no. 9 made up R.I.H. to 1268.0 ft Checking each connection for evidence of backoff. Stopped · To test equipment Tested MWD - Via string Function test completed satisfactorily R.I.H. to 4800.0 ft Continue checking connections R.I.H. to 4800.0 ft Breaking and checking each connection for evidence of back-off. Re-torqueing to 19.5K fi-lbs (upper end of torque range). BHA run no. 9 (cont...) R.I.H. to 9191.0 ft (cont...) Breaking and checking each connection for evidence · ~7 .../ix. u~ uacr~-u·t, lxc-tuttluc~l~; tu ~t-~u~ ~,Ul~l~C~ Progress Report Facility PB DS 16 Well 16-10A Page 12 Rig Nabors 9ES Date 07 February 00 Date/Time 26 Jan 00 09:30 09:30-11:00 11:00 11:00-13:00 13:00 13:00-13:30 13:30 13:30-14:30 14:30 14:30-15:00 15:00 15:00-15:15 15:15 15:15-15:45 15:45 15:45-16:30 16:30 16:30-17:30 17:30 17:30-20:00 20:00 20:00-00:00 00:00 00:00-06:00 06:00-06:00 06:00-16:30 16:30 16:30-18:30 Duration 1-1/2 hr 2hr 1/2 hr lhr 1/2 hr 1/4hr 1/2hr 3/4hr lhr 2-1/2hr 4 hr 6hr 24 hr 10-1/2 hr 2hr Activity end of torque range). Stopped · To service drilling equipment ~'-'i,= Serviced Block line and service top drive. Line slipped and cut r: ,: ~/ 0 9 200 R.I.H. to 10557.0 ft ' No indication of liner top, continue checkjgg ~. ~. ~..;:: :. . connections. ~'~"~' -. Stopped ' To take survey Took MWD survey at 10557.0 ft Check shot at low DL point· Acceptable survey obtained at 10500.0 ft R.I.H. to 12035.0 ft Discontinue breaking connections, re-torque only. Began precautionary measures Reamed to 12087.0 ft Shublik -11,950 - 12,120' No further resistance R.I.H. to 12200.0 ft Began precautionary measures Reamed to 12272.0 ft Shale interbed area, some packing off tendency. No further resistance R.I.H. to 13500.0 ft Wash by ledge at 12,700' Began precautionary measures Reamed to 13652.0 ft Tight and packing off in Shublik at end of well. On bottom Circulated at 13652.0 ft Establish full circulation, pump low/high vis sweep combo. Some cuttings returned w/bottoms' up, very little w/sweep. Obtained clean returns - 120.00 % hole volume Drilled to 13676.0 ft ART 1.25 AST 1.75 PUW 195 SOW 145 RW 172 Torque 5K off, 6-7 on bottom Sliding to drop out of Shublik, slow ROP even rotating. Began precautionary measures Drilled to 13745.0 ft ART 2 hrs AST 1.75 hfs ROP increasing with depth. BHA run no. 9 (cont...) Drilled to 14073.0 ft Continue drilling from 13,745' to 14, 073' MD (9070' TVD) ART 3 hrs, AST 4-1/2 hrs. ROP increasing to 80 fph rotating, 50 fph sliding. Hi vis sweeps every 3 hrs on average. Stopped: To correlate depth Circulated at 14073.0 ft CBU to collect cuttings sample for TD determination. Cuttings suggest HOT not penetrated. Facility PB DS 16 Progress Report Well 16-10A Page 13 Rig Nabors 9ES Date 07 February 00 Date/Time 27 Jan 00 18:30 18:30-21:00 21:00 21:00-00:00 00:00 00:00-01:15 01:15 01:15-02:30 02:30 02:30-04:30 04:30 04:30-05:30 05:30 05:30-06:00 05:30-06:00 06:00-15:30 06:00-08:30 08:30 08:30-09:30 09:30 09:30-13:30 13:30 13:30-15:30 15:30 15:30~06:00 15:30-15:45 15:45 Duration 2-1/2 hr 3hr 1-1/4 hr 1-1/4 hr 2hr 1 hr 1/2 hr 1/2 hr 9-1/2 hr 2-1/2 hr lhr 4 hr 2hr 14-1/2 hr 1/4 hr Activity Obtained bottoms up (100% annulus volume) Drilled to 14180.0 ft Rotate ahead another 10' vertical. ART 1.5 hrs. Projected at 14,180' MD TD: 86 degrees inclination 137 degrees azimuth 7079' TVD 4326' vertical section Reached planned end of run - Section / well T.D. Circulated at 14180.0 ft Pump lo / hi-vis sweep at TD. Obtained clean returns - 120.00 % hole volume Pulled out of hole to 11085.0 ft Monitor well, 26 stand short trip to 230' above uppermost tight Shublik zone. Max drag 10K. At top of check trip interval R.I.H. to 14180.0 ft No drag above 10K lbs. On bottom Circulated at 14180.0 ft Obtained bottoms up (100% annulus volume) Circulated at 14180.0 ft Spot 160-bbl liner running pill in openhole. (150K cp LSRV + 5% lubericant) Hole displaced with Water based mud - 103.00 % displaced Pulled out of hole to 13400.0 ft Drop 2.375" rabbit, SLM Pulled out of hole to 13400.0 ft Continue POH from 13,400'. Drop 2-3/8" rabbit, SLM. BHA run no. 9 (cont...) Pulled out of hole to 9530.0 ft (cont...) Continue POH from 13,400'. Drop 2-3/8" rabbit, SLM. Stopped: To service drilling equipment Serviced Block line Slip 40' and service top drive. Line slipped and cut Pulled out of hole to 200.0 ft Continue SLM out of hole, no correction. Monitor well at BHA. At BHA Pulled BHA Lay down BHA and download MWD. Clear rig floor. Bit condition unchanged since start of this run. BHA Laid out Run Liner, 4-1/2in O.D. Held safety meeting PJSM on running liner: pinch points, fluid transfers. Completed operations Facility PB DS 16 Progress Report Well 16-10A Page 14 Rig Nabors 9ES Date 07 February 00 Date/Time 28 Jan 00 15:45-16:30 16:30 16:30-22:30 22:30 22:30-22:45 22:45 22:45-01:30 01:30 01:30-02:00 02:00 02:00-05:30 05:30 05:30-06:00 05:30-06:00 06:00-10:00 06:00-07:30 07:30 07:30-08:30 08:30 08:30-10:00 10:00 10:00-13:00 10:00-10:30 Duration 3/4 hr 6 hr 1/4 hr 2-3/4 hr 3-1/2 hr 1/2 hr 4hr 1-1/2 hr 1 hr 1-1/2hr 3 hr 1/2 hr Activity Rigged up Casing handling equipment Equipment work completed Ran Liner to 4625.0 ft (4-1/2in OD) Guide shoe, 48 jts slotted liner, LC, CTC packer (at 12,162'), ES cementer, 63 joints solid liner w/1 ea. turbolator (minus window two joints), Baker hanger and ZXP packer. TOL 9555 - 181' liner lap. Stopped: To change handling equipment Rigged down Casing handling equipment Equipment work completed Pulled Drillpipe in stands to 9720.0 ft Pick up 21 singles 4" DP and run to window on stands in derrick. At Window: 9736.0 ft Circulated at 9720.0 ft Circulate pipe volume (106 bbls) at 220 gpm, 400 psi. PUW 162, SOW 150 Broke circulation Ran Drillpipe in stands to 14180.0 ft Make up cement head on 10' pup joint and stand back. RIH to TD, max drag 15-20K. Make up cement head. PUW = 182, SOW = 130. RU Dowell cementers. On bottom Circulated at 14180.0 ft Begin CBU. Circulated at 14180.0 ft Continue CBU w/liner in postion on bottom. 4.5 bpm, 800 psi, 225 bbls. Run Liner, 4-1/2in O.D. (cont...) Circulated at 14180.0 ft (cont...) Continue CBU w/liner in postion on bottom. 4.5 bpm, 800 psi, 225 bbls. Began precautionary measures Set Inflatable packer at 12161.0 ft with 1800.0 psi Drop first DP wiper dart, displace at 5.5 BPM, 880 psi. PU lower liner wiper plug 3 bbls early: sheared @ 3300 psi (2000 psi high). Displace to landing collar, set hanger with 1500 psi + 40K lbs down, inflate EPC with good indication of operating. Equipment work completed Open ES cementer at 3300 psi. Circulated at 12159.0 ft Continue CBU while batch mixing Dowell cement. Final circ 1000 psi @ 5.0 bpm. 120% bottoms' up total. Obtained bottoms up (100% annulus volume) Cement: Liner cement Pumped Fresh water spacers - volume 30.000 bbl Hold safety meeting, test dowell lines to 4000 psi, pump 9.2 ppg Alpha spacer, mixing on the fly. Progress Report Facility PB DS 16 Well 16-10A Page 15 Rig Nabors 9ES Date 07 February 00 Date/Time 29 Jan 00 10:30 10:30-11:00 11:00 11:00-11:30 11:30 11:30-13:00 13:00 13:00-21:00 13:00-18:30 18:30 18:30-20:00 20:00 20:00-21:00 21:00 21:00-06:00 21:00-22:30 22:30 22:30-23:45 23:45 23:45-06:00 23:45-06:00 06:00-11:00 06:00-11:00 11:00 11:00-13:00 11:00-11:30 11:30 11:30-12:30 Duration 1/2 hr 1/2 hr 1-1/2 hr 8 hr 5-1/2 hr 1-1/2 hr 1 hr 9 hr 1-1/2 hr 1-1/4 hr 6-1/4 hr 6-1/4 hr 5 hr 5 hr 2hr 1/2 hr lhr Activity Required volume of spacer pumped Mixed and pumped slurry - 65.000 bbl Batch mixed 67 and pumped 65 bbls 15.8 ppg class G. Cement pumped Displaced slurry - 130.500 bbl Drop top wiper dart, displace at 5 bpm. No indication of picking up wiper plug. Bumped 5 bbls early to calculated. Pressure to 3000 to close ES cementer. Bleed pressure to zero: no flow back. Release from hanger, simultaneous w/ circ.Release Dowell. Plug bumped Circulated at 9555.0 ft Weight-set ZXP packer while pumping 3 bpm, increase to 9.4 bpm and recip pipe while circulating out excess cement. PUW 170, SOW 165 (lost 30K lbs). Obtained clean returns - 130.00 % hole volume Discarded 200 bbls mud, increase in pH but no actual cement returns observed. Run Liner, 4-1/2in O.D. Laid down 5200.0 ft of 4in OD drill pipe Monitor well, POH LD excess drillpipe 168 joints laid out Pulled Drillpipe in stands to 0.0 ft Completed operations Retrieved Setting tools Lay down liner running tool, clear rig floor. Completed operations BHA run no. 10 Serviced Block line PJSM, slip and cut 80' drill line, service top drive. Line slipped and cut Made up BHA no. 10 3-3/4" mill, 3-1/8" motor. Surface test motor. Add 9DC's, 2-7/8" PAC, 7" casing scraper, PBL, 3-1/2" DP, Jars, 4" DP. BHA no. 10 made up R.I.H. to 4000.0 ft RIH, picking up 2-7/8" PAC. R.I.H. to 4000.0 ft Continue RIH to 9550' (5' above liner top) with tapered cleanout assy. BHA run no. 10 (cont...) R.I.H. to 9550.0 ft (cont...) Continue RIH to 9550' (5' above liner top) with tapered cleanout assy. Stopped · To pressure test Perform integrity test Held safety meeting PJSM on testing casing, responsibilities and high pressure safety. Completed operations Tested Casing 2.00, . _ Progress Report Facility PB DS 16 Well 16-10A Page 16 Rig Nabors 9ES Date 07 February 00 Date/Time 30 Jan 00 12:30 12:30-13:00 13:00 13:00-06:00 13:00-15:00 15:00 15:00-17:30 17:30 17:30-19:30 19:30 19:30-20:30 20:30 20:30-23:30 23:30 23:30-01:30 01:30 01:30-03:00 03:00 03:00-06:00 03:00-06:00 06:00-17:30 06:00-11:30 11:30 11:30-16:30 16:30 16:30-17:30 17:30 17:30-06:00 17:30-18:00 Duration 1/2 hr 17hr 2hr 2-1/2 hr 2hr 1 hr 3 hr 2hr 1-1/2 hr 3 hr 3 hr 11-1/2 hr 5-1/2 hr 5hr 1 hr 12-1/2 hr 1/2 hr Activity bbls. Record on chart. Zero pressure loss in 30 Pressure test completed successfully - 4000.000 psi Bleed down well Clear floor, blow down lines. Completed operations BHA run no. 10 R.I.H. to 12153.0 ft No indication of cement at liner top. Wash from 11,886 to 12,153' as precaution. At Float collar: 12153.0 ft second plug at ES cementer. No cement on top of plug. Milled DV collar at 12161.0 ft Mill top plug 12,153' to 12,161' Completed operations Milled Landing collar at 12209.0 ft Cement solid between ES cementer and landing collar Completed operations R.I.H. to 14080.0 ft Monitor well, RIH without resistance to 100' shy of TD. Stopped: To circulate Circulated at 14080.0 ft Pump 50 bbls SW, drop PBL opening ball, pump 50 bbls hi-vis sweep, 25 bbls SW. Open PBL port, continue circulation at top of 4-1/2" liner at 8.5 bpm, 2600 psi while rotating and reciprocating. Hole displaced with Seawater - 100.00 % displaced Cleared Mud shakers Cleanout shakers and 'possum bellys and offload fresh SW from vac trucks. Equipment work completed Circulated at 14080.0 ft Drop PBL closing ball, pump 100 bbls, close PBL port, pump 30 bbls lithium hypochlorite, displace to end of workstring with 96 bbls SW. Hole displaced with Seawater - 100.00 % displaced 360 bbls over hole volume pumped to achieve clean returns. Pulled out of hole to 11100.0 ft POH, LDDP. Pulled out of hole to 11100.0 ft Continue POH, LD 4" and 3-1./2" DP. Hole static. BHA run no. 10 (cont...) Pulled out of hole to 4567.0 ft (cont...) Continue POH, LD 4" and 3-1./2" DP. Hole static. At BHA Pulled BHA Lay down PBL sub, casing scraper, 138 joints 2-7/8" PAC, 9 ea. DC's, and motor/mill. BHA Laid out Rigged down Drillstring handling equipment Equipment work completed Run Tubing, 4-1/2in O.D. Retrieved Wear bushing Facility PB DS 16 Progress Report Well 16-10A Page Rig Nabors 9ES Date 17 07 February O0 Date/Time 31 Jan 00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-19:30 19:30 19:30-20:00 20:00 20:00-06:00 06:00 06:00-07:00 07:00 07:00-09:30 09:30 09:30-10:00 09:30-10:00 10:00 10:00-11:30 10:00-11:30 11:30 11:30-15:30 11:30-13:00 13:00 13:00-14:00 14:00 14:00-15:30 15:30 15:30-18:00 15:30-16:00 16:00 16:00-18:00 Duration 1/2 hr 1/2 hr 1/2 hr 1/2 hr lOhr 1 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 4hr 1-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 2hr Activity Equipment work completed Rigged up Tubing handling equipment Make up landing joint and rig up casing handling tongs Equipment work completed Serviced Block line Slip 40' drill line Line slipped Serviced Top drive Equipment work completed Held safety meeting PJSM on tubing running procedures and safety concerns (skate safety, pinch points, hole fill). Completed operations Ran Tubing to 9559.0 ft (4-1/2in OD) 233 joints 4-1/2" L-80 NSCT, Multi-make white compound, 4000 ft-lbs. 7" x 4-1/2" Baker S-3 packer + tailpipe+ X-nipple (sssv). No GLMs, two joints laid out for damage. 35' space out pups to land 4' into 6' tieback sleeve. PUW 137, SOW 125 Hanger landed Installed Tubing hanger RILDS and hook up circulating lines. Equipment work completed Reverse circulated at 9560.0 ft 400 bbls inhibited sea water @ 3.3 bpm, 200 psi. Hole displaced with Inhibited brine - 100.00 % displaced Wellhead work Retrieved Tubing landing string Set TWC. Completed operations Nipple down BOP stack Removed BOP stack Equipment work completed Wellhead work Installed Xmas tree NU adapter flange and tree, test same to 5000 psi. Equipment work completed Retrieved Hanger plug RU DSM, pull TWC. Equipment work completed Installed High pressure lines RU manifold for freeze protection / circulation Equipment work completed Fluid system Held safety meeting PJSM on pressure testing and circulating procedures. Completed operations Freeze protect well - 137.000 bbl of Diesel Test lines w/HB&R to 4500 psi. Reverse in diesel at 3 bpm, U-tube to tubing side, drop packer ... 0 9 2000 Facility PB DS 16 Progress Report Well 16-10A Page Rig Nabors 9ES Date 18 07 February 00 Date/Time 18:00 18:00-19:00 18:00-19:00 19:00 19:00-20:00 19:00-20:00 20:00 20:00-06:00 20:00-21:00 21:00 21:00-22:00 22:00 Duration lhr lhr 1 hr lhr 10hr lhr lhr Activity Completed operations Run Tubing, 4-1/2in O.D. Set Production packer at 9507.0 ft with 4000.0 psi Set Baker S-3 packer with 4000 psi down tubing. 9 bbls required. Record pressure on chart: lost 150 psi in 15 minutes, 250 psi after 30 minutes. Packer set at 9507.0 ft Perform integrity test Tested Casing Bleed tubing pressure to 1500 psi. Test annlus to 4000 psi, recorded on chart. Lost 50 psi after 15 minutes, <100 psi after 30 minutes. Test witness waived by Lou Grimaldi, AOGCC. Pressure test completed successfully - 4000.000 psi Wellhead work Removed High pressure lines Blow down lines, release HB&R, remove circ manifold. Equipment work completed Retrieved Hanger plug RU DSM, pull BPV. Secure tree. Release rig 22:00 hrs, 1/31/00 move to DS 17-15 Equipment work completed North Slope Alaska Alaska State Plane 4 PBU EOA DS 16 16-10A Surveyed: 26 January, 2000 SURVEY REPORT 10 February, 2000 ORIGINAL RECEIVED FEB 16 Alaska Oil & {~as Cons. Commissbn Anchorage Your Ref: AP!-500292050601 Surface Coordinates: 5928926.78 N, 719406.82 E (70° 12' 30.0183" N, 148° 13' 50.6410" W) Kelly Bushing: 64.30ft above Mean Sea Level rlRI L.'LI H G S E RVI r"'E S Survey Ref: svy9639 A ilA.L~IIILIRI'ON COM/~ANy North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Sperry-Sun Drilling Services p,E(: E IV E D Survey Report for 16- IOA Your Ref: API-500292050601 Surveyed: 26 January, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) FEB 16 _000 Alaska 0ii & Gas Cons. Commission Anchorage Alaska State Plane 4 PBU_EOA DS 16 9694.30 36.000 239.780 8805.27 8869.57 9735.00 34.910 240,080 8838.42 8902,72 9745.10 34.540 238.570 8846.72 8911.02 9783.40 38.990 233.510 8877.40 8941.70 9825.48 44.930 229.040 8908.68 8972.98 9845.37 48.020 227,210 8922.38 8986.68 9876.91 52.890 224.590 8942.46 9006.76 9908.58 58.570 222.250 8960.29 9024.59 9940.37 64.250 221.320 8975.49 9039.79 9971.52 70.070 219.710 8987.58 9051.88 10003.00 75.330 215.460 8996.94 9061.24 10033.30 79.610 211.580 9003.52 9067.82 10062.50 83.680 208,130 9007.76 9072.06 10094.40 87.570 203.040 9010.19 9074.49 10128.30 88.770 198.100 9011.28 9075.58 10155.60 89.170 197.670 9011.77 9076.07 10186.90 89.880 197.920 9012.03 9076.33 10218.10 90.520 198.040 9011.92 9076.22 10249.60 91.290 198.210 9011.42 9075.72 10280.00 91.780 197.870 9010.61 9074.91 10311.30 92.030 196.890 9009.57 9073.87 10346.80 90.610 196.570 9008.75 9073.05 10379.00 91.110 196.180 9008.26 9072.56 10410.00 91.780 196.590 9007.48 9071.78 10437.10 92.150 196.470 9006.55 9070.85 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/lOOft) (ft) Comment 1753.47 S 2091.65W 5927113.28 N 717367.00 E 1765.30 S 2112.08W 5927100.86 N 717346.92 E 1768.24 S 2117.02W 5927097.79 N 717342.06 E 1781.07 S 2135.99W 5927084.40 N 717323.48 E 1798.71S 2157,88W 5927066.14 N 717302.11E 1808.33 S 2168.61W 5927056.21N 717291.66 E 1825.27 $ 2186.06W 5927038.77 N 717274.72 E 1844.28 S 2204.02W 5927019.25 N 717257.31E 1865.09 S 2222.61W 5926997.91 N 717239.33 E 1886.91 S 2241.24W 5926975.56 N 717221.34 E 1910.72 S 2259.55W 5926951.22 N 717203.73 E 1935.37 S 2275.87W 5926926.10 N 717188.14 E 1960.42 S 2290.24W 5926900.65 N 717174.50 E 1989.10 S 2303.97W 5926871.59 N 717161.61 E 2020.81S 2315.87W 5926839.54 N 717150.64 E 2046.79 S 2324.25W 5926813.33 N 717143.01 E 2076.59 S 2333.82W 5926783.27 N 717134.32 E 2106.26 S 2343.45W 5926753.32 N 717125.55 E 2136.20 S 2353.25W 5926723.12 N 717116.63 E 2165.09 S 2362.66W 5926693.96 N 717108.06 E 2194.94 S 2372.00W 5926663.85 N 717099.59 E 2228.93 S 2382.22W 5926629.58 N 717090.36 E 2259.82 S 2391.30W 5926598.44 N 717082.19 E 2289.55 S 2400.04W 5926568.47 N 717074.31 E 2315.52 S 2407.74W 5926542.29 N 717067.36 E 458.65 2.712 458.55 9.271 458.59 14.046 460.10 15.795 464.28 16.906 467.18 16.714 473,00 18.944 480.35 18.051 488,94 19.281 498.38 21.099 509.70 18,860 522.75 18.190 537.13 20.043 554,96 14.989 576,34 2.151 594.54 2.4O5 615.44 2.087 636.20 2.503 657.10 1.962 677.30 3.230 698.36 4.100 722.56 1.969 744,65 2.534 765.91 1,435 784.44 Tie-in Survey Window Point Continued... 10 February, 2000 - 15:14 - 2 - DrillQuest 1.05. 04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 10473.80 92.860 196.400 9004.95 10501.50 93.020 196.380 9003.53 10532.20 93.230 196.160 9001.86 10562.70 93.820 196.060 8999.98 10594.40 94.250 196.000 8997.75 10625.20 94.590 195.760 8995.38 10659.10 94.710 193.080 8992.63 10691.30 92.860 188.320 8990.50 10718.80 91.450 183.110 8989.47 10752.70 90.310 177.920 8988.94 10782.00 89.690 176.690 8988.94 10811.20 90.740 171.130 8988.84 10842.40 92.710 165.630 8987.90 10873.20 93.920 162.420 8986.11 10903.10 94.710 160.550 8983.86 10934.70 94.450 154.660 8981.34 10964.90 93.050 148.590 8979.36 10994.80 92.180 143.790 8978.00 11030.10 92.770 139.300 8976.47 11061.20 93.170 138.850 8974.86 11086.20 92,250 138.210 8973.68 11121.60 91.420 138.440 8972.54 11152.00 90.580 137.350 8972.01 11180.30 90.620 137.960 8971.72 11213.30 91.080 138.200 8971.23 Sperry-Sun Drilling Services Survey Report for 16-10A ~ E E E IV E [~ Your Ref: API-500292050601 Surveyed: 26 January, 2000 kiask~ 0it & Gas C0,~s. c0mm'tssi0~ knchora[le Alaska State Plane 4 PBU_EOA DS 16 Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (ft) (ft) (fi) (ft) (fi) (°/100ft) Vertical Section (ft) Comment 9069.25 2350.69 S 2418.12W 5926506.84 N 717058.02 E 1.944 9067.83 2377.22 S 2425.92W 5926480.08 N 717050.99 E 0.582 9066,16 2406.65 S 2434.51W 5926450.42 N 717043.26 E 0.990 9064.28 2435.90 S 2442.96W 5926420.94 N 717035.66 E 1.962 9062.05 2466.29 S 2451.69W 5926390.30 N 717027.82 E 1.370 9059.68 2495.83 S 2460.09W 5926360.54 N 717020.28 E 1.350 9056.93 2528.55 S 2468.51W 5926327.58 N 717012.82 E 7.888 9054.80 2560.11 S 2474,47W 5926295.86 N 717007.77 E 15.829 9053.77 2587.44 S 2477.20W 5926268.46 N 717005.83 E 19.614 9053.24 2621.32 S 2477.51W 5926234.58 N 717006.51 E 15.673 9053.24 2650.59 S 2476.13W 5926205.37 N 717008.74 E 4.701 9053.14 2679.61 S 2473.03W 5926176.45 N 717012.68 E 19.377 9052.20 2710.15 S 2466.75W 5926146.11N 717019.84 E 18.717 9050.41 2739.70 S 2458.29W 5926116.81 N 717029.16 E 11.121 9048.16 2767.98 S 2448.83W 5926088.83 N 717039.44 E 6.773 9045.64 2797.09 S 2436.83W 5926060.08 N 717052.28 E 18.598 9043.66 2823.59 S 2422.52W 5926034.01 N 717067.36 E 20.585 9042.30 2848.40 S 2405.90W 5926009.69 N 717084.69 E 16.298 9040.77 2876.01 S 2383.97W 5925982.73 N 717107.41 E 12.817 9039.16 2899.47 S 2363.63W 5925959.86 N 717128.43 E 1.934 9037.98 2918.18 S 2347.09W 5925941.64 N 717145.50 E 4.481 9036.84 2944.61 S 2323.57W 5925915.91 N 717169.78 E 2.433 9036.31 2967.16 S 2303,19W 5925893.96 N 717190.81 E 4.526 9036.02 2988.08 S 2284.13W 5925873.60 N 717210.47 E 2.160 9035.53 3012.63 S 2262.08W 5925849.70 N 717233.22 E 1.572 809.56 828.54 849.61 87O.60 892.44 913.70 937.71 961.95 984.17 1013.27 1039.23 1065.85 1095.38 1125.17 1154.36 1185.54 1215.65 1245.45 1280.35 1310.88 1335.38 1370.06 1399.81 1427.49 1459.81 Continued... 10 February, 2000 - 15:14 - 3 - DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 11243.60 91.350 138.440 8970.59 11278.30 91.600 138.190 8969.69 11307.60 91.880 137.930 8968.80 11339.60 92.060 138.020 8967.70 11370.30 92.250 138.730 8966.55 11401.20 92.370 137.900 8965.30 11432.20 92.430 136.880 8964.00 11464.90 92.460 136.860 8962.61 11497.80 92.740 136.740 8961.12 11527.30 92.920 136.360 8959.66 11560.30 92.430 135.580 8958.12 11587.20 92.280 135.570 8957.02 11620.50 92.680 135.690 8955.57 11651.80 91,880 134.910 8954.33 11682.80 90.680 135.010 8953.64 11715.50 90.710 135.120 8953.24 11746.50 90.770 134.200 8952.84 11777.40 90.740 132.910 8952.43 11810.10 90.580 132.950 8952.06 11842.00 90.920 132.690 8951.64 11872.90 91.380 132.510 8951.02 11907,70 92.330 131.930 8949.89 11934.60 92.520 131.160 8948.75 11961.80 90.220 129.600 8948.10 11994.60 86.990 131.010 8948.90 Sperry-Sun Drilling Services SurveyReportfor16-10A &EcE[V Your Ref: API-500292050601 Surveyed: 26 January, 2000 FEB 16 DO0, Oil & 6~s Co,ns. 6om.missiot~ Anchom[ie Alaska State Plane 4 PBU_EOA DS 16 Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Northings Eastings Northings Eastings Rate Section (fi) (fi) (ft) (ft) (ft) (°/100ft) (ft) Comment 9034.89 3035.25 S 2241.94W 5925827.67 N 717254.01 E 1.192 1489.51 9033.99 3061.16 S 2218,87W 5925802.45 N 717277.82 E 1.019 1523.51 9033.10 3082.94 S 2199.29W 5925781.24 N 717298.02 E 1.304 1552.20 9032.00 3106.70 S 2177.88W 5925758.12 N 717320.11 E 0.629 1583.51 9030.85 3129.63 S 2157.51W 5925735.79 N 717341.15 E 2.393 1613.59 9029.60 3152.69 S 2136.97W 5925713.33 N 717362.34 E 2.712 1643.86 9028.30 3175.49 S 2116.00W 5925691.16 N 717383.96 E 3.293 1674.12 9026.91 3199.33 S 2093.67W 5925667.97 N 717406.98 E 0.110 1705.97 9025.42 3223.29 S 2071.17W 5925644.68 N 717430.17 E 0.926 1738.01 9023.96 3244.68 S 2050.91W 5925623.89 N 717451.04 E 1.424 1766.70 9022.42 3268.38 S 2028.00W 5925600.86 N 717474.63 E 2.789 1798.72 9021.32 3287.57 S 2009.18W 5925582.22 N 717494.00 E 0.559 1824.79 9019.87 3311.35 S 1985.92W 5925559.13 N 717517.94 E 1.254 1857.06 9018.63 3333.58 S 1963.92W 5925537.55 N 717540.58 E 3.568 1887.35 9017.94 3355.48 S 1941.99W 5925516.29 N 717563.13 E 3.884 1917.32 9017.54 3378.63 S 1918.90W 5925493,83 N 717586.89 E 0.349 1948.96 9017.14 3400.42 S 1896.85W 5925472.69 N 717609.56 E 2.974 1978.89 9016.73 3421.71 S 1874.46W 5925452.06 N 717632.56 E 4.176 2008.57 9016.36 3443.98 S 1850.52W 5925430.49 N 717657.14 E 0.504 2039.88 9015.94 3465.66 S 1827.12W 5925409.50 N 717681.16 E 1.342 2070.40 9015.32 3486.57 S 1804.38W 5925389.26 N 717704.50 E 1.599 2099.93 9014.19 3509.94 S 1778.62W 5925366.65 N 717730.92 E 3.198 2133.11 9013.05 3527.77 S 1758.51W 5925349.41 N 717751.55 E 2.946 2158.64 9012.40 3545.38 S 1737.79W 5925332.41 N 717772.76 E 10.216 2184.30 9013.20 3566.59 S 1712.79W 5925311.94 N 717798.37 E 10.744 2215.23 Continued... 10 Februar~ 2000- 15:14 -4 - DrillQuest 1.05.04e North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) 12026.80 87.380 131.590 8950.48 12057,50 88.490 130.620 8951.59 12089.50 88.630 130.170 8952.39 12121.30 87.480 130.720 8953.47 12152.40 85.720 133.760 8955.32 12183.00 86.180 134.270 8957.48 12213.80 87.080 134.450 8959.29 12245.00 87.450 133.740 8960.78 12277.40 87.540 133.260 8962.19 12308.00 86.770 133.670 8963.71 12339.00 85.880 134.500 8965.70 12370.30 85.970 134.210 8967.92 12400.90 86.280 133.800 8969.99 12432.10 86.550 133.310 8971.94 12463.70 86.860 133.240 8973.76 12495.00 87.140 133.270 8975.40 12526.30 87.380 132.920 8976.89 12555.60 87.810 132.880 8978.12 12588.20 87.820 133.460 8979.37 12616.70 87.140 135.100 8980.62 12650.30 87.850 136.500 8982,09 12682.40 88.740 137.920 8983.04 12711.90 89.020 136.950 8983.62 12745.70 89.630 136.890 8984.02 12775,70 88.000 135,390 8984.64 Sperry-Sun Drilling Service Survey Report for 16- IOA Your Ref: API-500292050601 Surveyed: 26 January, 2000 Alaska State Plane 4 PBU EOADS16 -- vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) Comment 9014.78 3587.81 S 1688.63 W 5925291.42 N 9015.89 3607.98 S 1665.51 W 5925271.93 N 9016.69 3628.72 $ 1641.15 W 5925251.92 N 9017.77 3649.33 S 1616.96 W 5925232.01 N 9019.62 3670.20 S 1593.98 W 5925211.82 N 9021.78 3691.41 S 1572.03 W 5925191.26 N 9023.59 3712.90 $ 1550.05 W 5925170.41 N 9025.08 3734.59 S 1527.67 W 5925149.38 N 9026.49 3756,87 S 1504,19 W 5925127.79 N 9028.01 3777.90 S 1482.01 W 5925107.42 N 9030.00 3799.42 $ 1459.79 W 5925086.56 N 9032.22 3821.24 S 1437.46 W 5925065.39 N 9034.29 3842.45 S 1415.50 W 5925044.82 N 9036.24 3863.91 S 1392.94 W 5925024.03 N 9038.06 3885.54 S 1369.97 W 5925003.08 N 9039.70 3906,96 S 1347.20 W 5924982.33 N 9041.19 3928.32 S 1324.37 W 5924961.65 N 9042.42 3948.24 S 1302.93 VV 5924942.35 N 9043.67 3970.53 S 1279.17 W 5924920.76 N 9044.92 3990.41 S 1258.78 VV 5924901.49 N 9046.39 4014.47 S 1235.38 W 5924878.11 N 9047.34 4038.02 S 1213.59 W 5924855.21 N 9047.92 4059.74 S 1193.64 W 5924834.08 N 9048.32 4084.43 S 1170,55 W 5924810.07 N 9048.94 4106.05 S 1149.77 W 5924789.06 N 717823.14 E 2.169 2245.74 717846.83 E 4.800 2274.82 717871.79 E 1.472 2305.01 717896.56 E 4.008 2335.01 717920,14 E 11.280 2364.62 717942.70 E 2.241 2394.01 717965.29 E 2.980 2423.66 717988.30 E 2.564 2453.68 718012.41E 1.506 2484.76 718035.20 E 2,850 2514,10 718058.03 E 3.922 2543.90 718080.98 E 0.968 2574.01 718103.55 E 1.677 2603.40 718126.73 E 1.790 2633.31 718150.32 E 1.006 2663.57 718173.69 E 0.900 2693.55 718197.13 E 1.355 2723.51 718219.15 E 1.474 2751.53 718243.54 E 1.778 2782.76 718264.50 E 6.224 2810.21 718288.59 E 4.668 2842.79 718311.06 E 5.219 2874.12 718331.63 E 3.422 2902.94 718355.42 E 1.813 2935.90 718376.82 E 7.383 2965.05 Continued... 10 February, 2000 - 15:14 - 5 - DrillQuest 1,05. 04e North Slope Alaska Measured Depth (ft) Azim. Sub-Sea Depth (ft) 12805.20 88,400 135.520 8985.56 12837.10 89.260 135.870 8986.22 12869.00 89.570 135.510 8986.54 12897.00 87.440 135.920 8987.27 12927.90 87.790 137.450 8988.56 12962.10 88.250 137.260 8989.74 12991.00 89.380 137.500 8990.34 13024.20 90.150 138.420 8990.47 13057.30 90,800 138.020 8990.20 13087.80 91.230 137.840 8989.66 13118.80 91.660 137.620 8988.88 13148.80 92.030 137.230 8987.91 13180.80 92,210 136.630 8986.73 13212.00 92.400 136.190 8985.47 13242,90 92.950 136.000 8984.03 13274.30 93.660 136.270 8982.22 13304.50 94.250 136.390 8980.14 13337.30 93.420 135.410 8977.94 13367.80 90.650 134.820 8976.86 13398.20 90.980 135.180 8976.43 13429,50 91.570 134.820 8975.73 13458.00 91.850 135.790 8974.88 13489.50 91.940 134.770 8973.84 13522,10 90,310 134.620 8973.20 13552.00 91.110 134.470 8972.83 Sperry-Sun Drilling Services Survey Report for 16-10A R ~ ~ ~ ~ ~j ~ D Your Ref: API-500292050601 Surveyed: 26 January, 2000 Alaska State Plane 4 PBU_EOA DS 16 Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (°/100ft) Vertical Section (ft) Comment 9049.86 4127.07 S 1129.09W 5924768.65 N 718398.11E 1.426 9050.52 4149.89 S 1106.81W 5924746.49 N 718421.04 E 2.911 9050.84 4172.71 S 1084.53W 5924724,32 N 718443.98 E 1.489 9051.57 4192.75 S 1064.99W 5924704.86 N 718464.09 E 7.747 9052.86 4215.21 S 1043.81W 5924683.02 N 718485.91 E 5.075 9054.04 4240.35 S 1020.65W 5924658,56 N 718509.79 E 1.455 9054.64 4261.62 S 1001.09W 5924637.88 N 718529.96 E 3.997 9054.77 4286.27 S 978.86W 5924613.88 N 718552.90 E 3.614 9054.50 4310.95 $ 956.80W 5924589.85 N 718575.66 E 2.306 9053.96 4333.59 S 936.37W 5924567.81 N 718596.74 E 1.528 9053.18 4356.52 S 915.53W 5924545.50 N 718618.25 E 1.558 9052.21 4378.60 S 895.24W 5924524.02 N 718639.17 E 1.791 9051.03 4401.96 S 873,40W 5924501.30 N 718661.67 E 1.956 9049.77 4424.54 S 851.91W 5924479.35 N 718683.81 E 1.535 9048.33 4446.78 S 830.50W 5924457.75 N 718705.86 E 1.883 9046.52 4469.38 $ 808.78W 5924435.79 N 718728.23 E 2.419 9044.44 4491.18 S 787.98W 5924414.61N 718749.65 E 1.993 9042.24 4514.68 S 765.20W 5924391.78 N 718773.10 E 3,910 9041.16 4536.27 S 743.70W 5924370.82 N 718795.23 E 9.285 9040.73 4557.77 S 722.20W 5924349.96 N 718817.34 E 1.606 9040.03 4579.89 S 700.08W 5924328.48 N 718840,10 E 2.208 9039.18 4600.14 S 680.04W 5924308.82 N 718860.71 E 3.541 9038,14 4622.51 S 657.89W 5924287.11 N 718883,51 E 3.249 9037.50 4645.44 S 634.72W 5924264.87 N 718907.33 E 5.021 9037.13 4666.41S 613,41W 5924244.52 N 718929.24 E 2.722 2993.63 3024.58 3055.53 3082.69 3112.77 3146.16 3174.38 3206.89 3239.32 3269.18 3299.49 3328.79 3359.98 3390.32 3420.32 3450.79 3480.10 3511.89 3541,38 3570.78 3601.05 3628.64 3659.13 3690.62 3719.47 Continued... 10 February, 2000 - 15:14 - 6- DrillQuest 1.05.04e North Slope Alaska Sperry-Sun Drilling Services Survey Report for 16- I OA Your Ref: API-500292050601 Surveyed: 26 January, 2000 FEB 16 A~c~°Ta~laska State Plane 4 PBU_EOA DS Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) Comment 13588.80 91.720 134.050 8971.92 9036.22 4692.08 S 587.06 W 13616.30 92.310 133.710 8970.95 9035.25 4711.13 S 567.25 W 13644.30 90.280 132.970 8970.32 9034.62 4730.34 S 546.90 W 13678.00 89.230 132.680 8970.46 9034.76 4753.25 S 522.18 W 13709.00 88.800 132.340 8971.00 9035.30 4774.20 S 499.33 W 13737.20 86.950 132.440 8972.04 9036.34 4793.19 S 478.52 W 13768.40 84.050 134.090 8974.49 9038.79 4814.51 S 455.87 W 13803.40 82.500 135.070 8978.59 9042.89 4838.90 S 431.11 W 13835.00 82.190 135.480 8982.80 9047.10 4861.15 S 409.08 W 13865.90 82.440 136.330 8986.93 9051.23 4883.15 S 387.77 W 13897.30 83.180 137.210 8990.86 9055.16 4905.85 S 366.43 W 13927.70 84.820 137.750 8994.04 9058.34 4928.13 S 346.00 W 13959.20 84.950 137.910 8996,85 9061.15 4951.38 S 324.94 W 13991.30 85.040 137.900 8999.65 9063.95 4975.11 S 303.50 W 14020.90 84.790 137.420 9002.27 9066.57 4996.90 S 283.64 W 14052.40 85.010 137.830 9005.07 9069.37 5020.08 S 262.49 W 14081.50 85.570 137.540 9007.46 9071.76 5041.53 S 242.97 VV 14113.70 85.970 137.150 9009.84 9074.14 5065.14 S 221.21 W 14122.50 86.030 137.120 9010.45 9074.75 5071.58 S 215,24 W 14180.00 86.030 137.120 9014.43 9078.73 5113.61 S 176.21 W 5924219.62 N 718956.32 E 5924201.16 N 718976.68 E 5924182.54 N 718997.58 E 5924160.36 N 719022.95 E 5924140.09 N 719046.40 E 5924121.71N 719067.76 E 5924101.06 N 719091.01 E 5924077.39 N 719116.47 E 5924055.79 N 719139.15 E 5924034.43 N 719161.08 E 5924012.36 N 719183.07 E 5923990.68 N 719204.14 E 5923968.05 N 719225.87 E 5923944.95 N 719247.99 E 5923923.75 N 719268.47 E 5923901.19 N 719290.28 E 5923880.32 N 719310.42 E 5923857.35 N 719332.86 E 5923851.09 N 719339.01 E 5923810.21 N 719379.25 E All data is in feet 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. Magnetic Declination at Surface is 27.443° (10-Jan-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 149.700° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14180.00ft., 2.012 3754.93 2.476 3781.38 7.716 3808.23 3.232 3840.48 1.768 3870.09 6.570 3897.00 10.686 3926.82 5.229 3960.38 1.617 3990.71 2.844 4020.45 3.645 4050.81 5.677 4080.36 0,653 4111.06 0,282 4142.36 1,823 4171.20 1,473 4201.88 2,166 4230.25 1,733 4261.61 0.762 4270.18 0.000 4326.17 Projected Survey 10 February, 2000 - 15:14 - 7- OrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 16- IOA Your Ref: API-500292050601 Surveyed: 26 January, 2000 North Slope Alaska The Bottom Hole Displacement is 5116.65ft., in the Direction of 181.974° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9694.30 8869.57 1753.47 S 2091.65 W Tie-in Survey 9735.00 8902.72 1765.30 S 2112.08 W Window Point 14180.00 9078.73 5113.61 S '176.21 W Projected Survey RECEIVED FEB 1 6 2000 AJask-: Oil & Gas Cons. Commissior~ Anchorage Alaska State Plane 4 PBU_EOA DS 16 10 February, 2000- 15:14 -8- DrillQuest 1.05.04e Schlumberger NO. 121240 3/2/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD I D.S. 12-32 PRODUCTION PROFILE 2/25/00 I 1 , , D.S. 12-32 DEFT 2/25/00 I 1 D.S. 14-20 LEAK DETECTION LOG 2/20/00 I 1 ........ D.S. 14-24 LEAK DETECTION LOG 2/22/00 I 1 =D.S. 16-10A JEWELRY LOG & SBHP SURVEY 2/22/00 I I ! I TI ! IJ MAR 1 4 2000 SlGNE · _ '- ,~.~ t DATE: ~aska 0it & Gas t;~i~,. ~,~,slt~t,'t$i0[I Anch0rag6 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson,~~0 DATE' February 25, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM' Lou Grimaldi, SUBJECT: Petroleum Inspector BOPE Test Nabors 3S ARCO, PBU, 15-13A PTD 199-124 NON-CONFIDENTIAL Friday, February 25, 2000' I witnessed the initial BOPE Test on the Nabors rig #3S located on Arco's well Drillsite 15 well #13A in the Prudhoe Bay field. This is the initial test since the coil unit had been split off from the rig.The test went well with one failure observed, this being the audible alarm for the H2S detectors. This was tracked down to a loose connection in the Sub base that was fixed during the test and retested "OK". The test time would have been shorter had it not been for a leaky test plug that caused a visual check of all possible leak paths during the test. The rig was in fair condition as was the location. SUMMARY: I witnessed the initial BOPE Test on Nabors 3S. 1 failure, 4 hours test time NON-CONFIDENTIAL CC; Shared Services Drilling Attachment: BOP Nabors 3S 2-25-00 LG.XLS BOP Nabors 3S 2-25-00 LG.doc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: blair_wondzell@admin.state.ak, us and john_spaulding@admin.state.ak.us Contractor: Nabors Rig No.' 3S DATE: 2/25/00 Rig Rep.: Jimmy Fritz Rig Phone: 9-5514 Rig Fax: Operator: Arco Op. Phone: 9-5515 Op. Fax: Rep.: Mark Johnson Well Name: 15-13A PTD # 199-124 Meridian: Umiat Location: Section: 2 Township: 11N Range: 14E Operation: Ddg: Workover: × Explor.' Test: Initial: X Weekly: Other: Test Pressure: Rams: 250/3000 Annular: 250/3000 Valves: 250/3000 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: P/F P/F Quantity P/F Location Gen.' P Well Sign P Upper Kelly Housekeeping' P DH. Rig P Lower Kelly PTD On Location P Hazard Se P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size P/F CHOKE MANIFOLD: Annular Preventer 1 13 5/8 P Quantity P/F Pipe Rams 1 13 5/8 P No. Valves 14 P Lower Pipe Rams None Manual Chokes 1 P Blind Rams 1 13 5/8 P Hydraulic Chokes 1 P Choke Ln. Valves 1 3" P HCR Valves 1 3" P ACCUMULATOR SYSTEM: Kill Line Valves 2 3" P Time/Pressure P/F Check Valve 0 System Pressure 3000 P MUD SYSTEM: Pressure After Closure 1450 P Visual Alarm 200 psi Attained :21 P Tdp Tank P P Full Pressure Attained 2:24 P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator Nitgn. Bottles (avg): 4(~2100 Meth Gas Detector P F H2S Gas Detector P P Test Results Number of Failures: 1_ Test Time: 4 Hours. Components tested 2_~5 Repair or replacement of equipment will be made within N/A days, Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: blair_wondzell@admin.state, ak.us Remarks: H2S Gas Detector horn inop, loose wires found and repaired. Retested OK No Kelly required for tubin~l swap, if picked up it will be tested. Distribution: STATE WITNESS REQUIRED? orig-Well File YES X NO c- Oper./Rig Waived By c- Database 24 HOUR NOTICE GIVEN c - Trip Rpt File YES X NO Witness Lou Grimaldi c- Inspector BOP Nabors 3S 2-25-00 LG.xls Re: [Fwd;~DS 15-13A & 18-07A change in Bop Sm~-"~nfiguration] i. Subject: Re: [Fwd: DS 15-13A & 18-07A change in Bop Stack configuration] Date: Tue, 22 Feb 2000 12:06:38 -0900 From: Tom Maunder <torn_maunder~admin.state.ak.us> Internal To: Bruce E Smith <BESMITH@mail.aai.arco.com>, Mark O Johnson <Mark O Johnson@mail.aai.arco.com>, 3S Supervisor PRB <P 1023@mail.aai.arco.com>, Stephen L Ward <SWARD@mail.aai.arco.com> CC: Blair Wondzell <blair_wondzell~admin.state.ak.us>, AOGCC North Sope Office <aogcc~rudhoe_bay@admin.state.ak.us>, John Spaulding <john_spaulding@admin.state.ak.us> Gentlemen: Blair is presently out on vacation. I have looked at the files we have regarding these wells and have talked to the rig to determine the schedule of activities. I understand that 3S could be moving to 15-13 as early as late today and then on to 18-07. In each case, the only work planned for 3S will involve replacing the existing tubing string on each well. The actual sidetracks will take place at a later date. As such all work will be under the authority of the respective sundries 399-252 for 15-13 and 300-036 for 18-07. From talking to Steve at the rig, I understand that the service coil has plugged 15-13 so the rig will be essentially moving onto a dead well. From my reading of what we have received on 18-07, it will likewise be plugged and abandoned when 3S moves on. The work proposed is essentially a workover and the 3 preventer stack you plan is one used routinely by 4ES at Milne. The only difference is they run the blind rams on top of rather than below the spool. I understand from conversations with Steve and Mark that the preference is to run the blinds on the bottom so that the spool is available for circulation if the pipe rams are closed. Given the work planned, this stack change and arrangement is acceptable for pulling the tubing on 15-13 and 18-07. No open hole operations may be performed with this arrangement. Please contact me at 793-1250 if further information is needed. Tom Maunder Petroleum Engineer AOGCC Blair Wondzell wrote: > Subject: Re: DS 15-13A & 18-07A change in Bop Stack configuration > Date: Sat, 19 Feb 2000 10:13:32 -1000 > From: "3S Supervisor PRB" <PlO23~mail.aai.arco.com> > To: blair wondzell~admin.state.ak, us > CC: "Bruce E Smith" <BESMITHSmail.aai.arco.com>, > "Stephen L Ward" <SWARDSmail. aai. arco. com>, > "Mark 0 Johnson" <Mark 0 JohnsonSmail. aai. arco. corn> > > Blair, > As per Steve Ward's note below, we will be nippling up the 13-5/8" stack to do > the workovers on Wells 15-13A and 18-07A. However, after measuring the wellhead > heights, Nabors Rig 3S rig floor elevation, and the height of the BOP stack, we > do not have enough distance under the rig floor to be able to rig up 2 sets of > pipe rams. The configuration that we will have to nipple up is as follows: > Annular Preventer > Pipe Rams > Mud Cross (kill and choke lines) 1 of 3 3/14/00 3:29 PM DS 15-13,A. & 18-07A change in Bop Stack configu-'~"n Subject: DS 15-13A & 18-07A change in Bop Stack configuration Date: Thu, 17 Feb 2000 11:03:55-1000 From: "Stephen L Ward" <SWARD@mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us CC: "Bruce E Smith" <BESMITH@mail.aai.arco.com>, "Mark O. Johnson" <MOJ@mail.aai.arco.com> Blair-- As per the permit to drill, AAI is going to perform tubing changeout workovers on 15-13( Permit # 199-124) and 18-07(submitted 2/03/00) prior to sidetracking operations (Coiled Tubing Sidetracks). However, in order to perform this operation, the Nabors 3S rig will have to utilize a 13 5/8" BOP stack configured as follows: Annular Preventor Pipe & Blind dual rams Flow cross (kill and choke lines) pipe rams This BOP stack was not included in both permits to drill. Only a 7 1/16" drilling stack was included in the permit request. Can you approve the above mentioned BOP stack for the workover operations? For the subsequent sidetrack operations, the 7 1/16" stack will be utilized. If we can provide further information please call me (265-1305) or Mark O. Johnson 265-1661 . Thanks Steve Ward 1 of 1 2/17/00 1:29 PM Re: [Fwd;.DS 15-13A & 18-07A change in Bop St,~--' ~nfigumtion] > Blind Rams > > Please let us know if this is acceptable. > Thanks, > > Steve Bradley > ARCO Rig Supervisor > 659-5515 > Bruce E Smith > 02/19/2000 09:02 AM > To: 3S Supervisor PRB/AAI/ARCO~ARCO ~ cc: > Subject: DS 15-13A & 18-07A change in Bop Stack configuration > Forwarded by Bruce E Smith/AAI/ARCO on 02/19/2000 09:02 >AM > > Stephen L Ward > 02/1 7/2000 11:03 AM > To: blair wondzellSadmin.state.ak, us -- > cc: Bruce E Smith/AAI/ARCOSARCO, Mark O. Johnson/AAI/ARCOSARCO > Subject: DS 15-13A & 18-07A change in Bop Stack configuration > Blair-- > > As per the permit to drill, AAI is going to perform tubing changeout workovers > on 15-13( Permit # 199-124) and 18-07(submitted 2/03/00) prior to sidetracking > operations (Coiled Tubing Sidetracks). However, in order to perform this > operation, the Nabors 3S rig will have to utilize a 13 5/8" BOP stack configured > as follows: > > Annular Preventor > Pipe & Blind dual rams > Flow cross (kill and choke lines) > pipe rams > > This BOP stack was not included in both permits to drill. Only a 7 1/16" > drilling stack was included in the permit request. Can you approve the above > mentioned BOP stack for the workover operations? For the subsequent sidetrack > operations, the 7 1/16" stack will be utilized. > If we can provide further information please call me (265-1305) or Mark O. > Johnson 265-1661 . > > Thanks > Steve Ward Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 3 3/14/00 3:29 PM 10-Feb-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 16-10A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,694.30' MD 9,735.00' MD 14,180.00' MD (if applicable) RECEIVED FEB 16 2.000 AJaska 011 & Gas Cons. Commission Anchorage Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re' Prudhoe Bay Unit 16-10A ARCO Alaska, Inc. Permit No: 199-123 SurLoc: 2006'SNL, 613'EWL, Sec. 24, T10N, R15E, UM Btmhole Loc: 1891'SNL, 487'EWL, Sec. 25, T10N, R15E, Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF THE C~)MMISSION DATED this ~).-~ ~ day of December, 1999 dlf/Enclosures Department of Fish & Game. Habitat Section x~/o encl. Department of Environmental Conservation w/o encl. -- STATE OF ALASKA ALAS. . OIL AND GAS CONSERVATION CC. PERMIT TO DRILL 20 AAC 25.005 ,/fISSION la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 70' 3. Address 6. Property Designation ¢"-v'v'J~ Prudhoe Bay Field / Prudhoe P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028333 ('.~..~..¢.~.¢~ Bay Pool 4. Location of well at surface ~/ v" ,/ 7. Unit or Property Name Z~ 11. Type Bond (See 20 AAC 25.025) 2006' SNL, 613' EWL, SEC. 24, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 4965' SNL, 1756' WEL, SEC. 23, T10N, R15E, UM 16-10A At total depth 9. Approximate spud date Amount $200,000.00 1891' SNL, 487' EWL, SEC. 25, T10N, R15E, UM 12/28/99 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and ']-VD) ADL 028332, 1891' MDI No Close Approach 2560 14275' MD / 8990 TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9735' MD Maximum Hole Angle 93° Maximum surface 3618 psig, At total depth (TVD) 8825' / 4500 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-M 4690' 9585' 8710' 14275' 8990' 542 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary PBTD Tagged at 9903' MD (11/25/95) Total depth: measured 10589 feet Plugs (measured) true vertical 9626 feet i,~AL measured 9903 feet Junk(measured) Effective depth: true vertical 9044 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 300 sx Permafrost 110' 110' Surface 2655' 13-3/8" 2300 sx Fondu, 200 sx Permafrost 2725' 2725' Intermediate Production 9483' 9-5/8" 500 sx Class 'C' 9553' 8760' Liner 1342' 7" 5o2sxcem E( E IV ED 9238'- 10580' 8522' - 9618' DEC 1 ¢ I1999 Perforation depth: measured 9728'- 9880' (Five Intervals) true vertical 8896' - 9019' A~t'~ Commission Oil & Gas Cons. Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: ,James Smith, 564-5026 Prepared By Name/Number: Terrie I-lubb/e, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,-~-~--~-;-?-- ~ Title Senior Drilling Engineer DanStone '~"'). Date ~f~,~'"', ~'~ Commission Use Only Permit Number _ I APl Number I -~ Approval Date See cover letter I I //¢?"-//~_;~ 50-029-20506-01 ~2~,-",j~,.~ ~ ~ for other requirements Conditions of Approval: Samples Required [] Yes .J~'No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures ~_[~__es [] No Directional Survey Required Di;~'Yes [] No Required Working Pressure for'BOPE I-I2K; 1'-13K; I-I4K; ~K; [] 10K; [] 15K Other: ORIGINAL SIGNED BY by order of Approved By Robert N P. hdst,=n~or'l Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate 16-10Ai Permit to Drill IWell Name: r 16-10Ai Sidetrack Plan Summary Type of Redrill (producer or injector): Surface Location: Target Location' Bottom Hole Location' I Injector 2006' FNL 613' FWL S24 T10N R15E 4965' FNL 1756' FEL S23 T10N R15E X=717126 Y-5925900 Z=8970TVDss 1891' FNL 487' FWL S25 T10N R15E X-719435 Y--5923760 Z=8990TVDss AFE Number: 14J0431 I Estimated Start Date:112/28/99 I Rig: I Nabors9ES I Operating days to.complete: 124.6 IMD: 114,275' 70' IWell Desitin (conventional, slimhole, etc.): I Horizontal Sidetrack Objective: I Horizontal Injector in Sag and Z4 of the Ivishak Formation Markers: Formation Tops MD TVDss Comments Sag River 9728' 8825' Kick-off Point 9735' 8834' Is in very top of Sag River Shublik 9753' 8848' Top Sadlerochit/Z4 9858' 8925' HOT 9927' 8965' Target 1 11125' 8970' Follows Dip of Z4 TD 14275' 8990' Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MDfrVD 6" 4 1/2" 12.6# L-80 IBT-M 4690' 958578710' 14275'/8990' Tubing 4 1/2" 12.6# L-80 NSCT 9548' -30?30' 9585'/8710' Mud Program: Production Mud Properties: QuickdriI-N 16" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.3 - 8.6 40-55 <20,000 cP 10-20 8.5-9.0 NOTE: The potential for residual overpressure from injection is present on this well, it may be necessary to increase the mud weight to overbalance residual pressure if present. 16-10Ai Permit to Drill Directional: KOP: I 9735' MD Maximum Hole Angle: Close Approach Well: 93 @ 1O8OO' None Logging Program: IProduction Hole(Horizontal) Drilling: MWD / GR / Resistivity / PWD--Real time Open Hole: None Cement Calculations: Liner Size 14 1/2" Production I Basis: Tail' Based on ' of 6" x 4.5" annulus over the solid cemented portion of the liner with 50% excess, 150' of 7" x 4.5" liner lap, and 200' of 7" x 3-1/2" DP annulus volume. Tail TOC: At liner top - 9585' MD T°talCementV°lume: I Tail 1111'9bbl/628ft~/542skofD°wellPremium'G'at15.8ppgandl.16cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: 4500psi @ 8825' TVDss - Sag (well is injector) · Maximum surface pressure: 3618psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel · Planned BOPE test pressure is 5000 psi since potential for overpressure exists due to the historical water iniection on this well (16-10). Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S · DS 16 is designated as an H2S drill site. The highest level of H2S measured on DS16 has been 92 ppm (on the 16-21 well in 2/99) with typical measurements near 60 ppm. Standard Operating Procedures for H2S precautions should be followed at all times. 16-10Ai Permit to Drill DRILLING CLOSE APPROACH: · There are no close approach wells in this well design. PRODUCTION SECTION: · Lost circulation risk is Iow since there are no faults identified in the wellpath. There is always the potential for small subseismic faulting, but those are not expected to cause problems. · Since the well must be drilled in 6" hole size (uphole casing will not pass 6-1/8" bit), the risk of losses due to ECD is increased. This well will utilize 3-1/2" DP for the interval below the existing 7" liner top (9238'MD) to TD to reduce ECD. In addition, PWD pressure monitoring equipment will be used on the well while drilling. · The kick tolerance for the whipstock exit point would be an infinite influx (annular volume) assuming an influx at section TD of 14,275' (or before TD) even considering the worst case scenario that the millout mud weight of 8.4 ppg encounters 9.8 ppg injection elevated reservoir pressures. · This is a worst case scenario based on an 9.8 ppg pore pressure, a minimum fracture gradient of 12.0 ppg at the 7" whipstock section , and 8.4 ppg mud in the hole. Calculated SIDPP is 1262 psi from this occurrence. Disposal: · No annular injection in this well. · Cuttings Handling: Class II drilling waste will be disposed at DS-4 grind and inject facility. Any Class I wastes generated will be taken to Pad 3 for disposal. SUMMARY SIDETRACK PROCEDURES Planned Pre-Riq Operations 1. Drift tubing, RU coil and P&A existing perforations with Class G cement at 15.8 ppg to place TOC at 9,710'MD. (Note: top perf at 9728') Tag and test to meet AOGCC requirements. 2. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the packoff on the 9-5/8" tests OK, completely back out and check each lock down screw for breakage (check one at a time). 3. Test the 9-5/8" casing to 3000 psi against packer and P&A plug. 4. Confirm that the well remains dead with a full column of 8.5 ppg seawater then punch the 4- 1/2" tubing near 9190' and chemical cut the 4-1/2" production tubing near 9185' (above PBR and production packer). 5. Set a BPV in preparation of the rig move. Assure annuli are freeze protected to near 2000'. Riq Sidetrackinq Procedure 1. MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater. 2. Pull 4 1/2" tubing down to the tubing cut at 9185'. 16-10Ai Permit to Drill . , , 9. 10. 11. 12. 13. Replace 9-5/8" packoff if necessary Pull PBR, Mill and retrieve production packer at 9215' PU Bit and whipstock mills for 7" 29# and stab for 9-5/8" 47#. RIH to tag/dress P&A cement to 9755' or as necessary to place KOP within the Sag River formation. Pressure test 9-5/8" and 7" liner to 4000 psi. RIH with bottom trip whipstock for 7" 29# casing. Whipstock sidetrack at +/-9735'. Drill 6" horizontal hole from 9735' to 14275' in Zone 4 and Sag River formation. Run MWD/GR/Res+PWD real time LWD. No other logs are planned. Run 4-1/2" 12.6# L80 IBT-Mod production liner and cement Pressure test casing strings to 4000 psi Perforate approx. 1500' of the horizontal well with Schlumberger high power guns. Run 4-1/2" 12.6#, L80, NSCT production/injection tubing. Set packer near 9500' Freeze protect permafrost zone thru single GLM. Set BPV, ND BOPE, NU and test tree. RDMO. I TREE: 16-10 Pro 13-3/8", 72 #/ft, L80, Top of 7" Liner at I 9238' I Peds 9728-9880 7", 29 #/ft, L80 ~ d P&A 4-1/2" 'QSS SSSV Nipple I 2238' I 4-1/2"x1-1/2 GLMs 4-1/2" 12.6# L-80, IPC Tubing Cut 4-1/2" Tubing at 9185' approx. (above PBR) ~ 9-5/8" x 4-1/2" Baker 'SAB' Production Packer @9215MD, top of PBR at 9193MD 4-1/2" 'XN' Landing Nipple, 3.725" No-Go ID @ 9530 +/- Plug Original well with Class G cement at 15.8 ppg from TD to 9710MD with Coil Unit TOC at 9710' approx. Perfs at 9728'+ 12/6/99 JES ~nmm~nf~ Proposed P&A of Orig. Well PRUDHOE BAY UNIT WELL: 16-10 APl NO' 50-029-205-060 Shared Services Drilling · 16-10Ai Proposed Completion WELLHEAD: 13-3/8", 72 #/ft, L80, BTC 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 22°°' I One 4-1/2"x1-1/2 GLM at +/-3500 4-1/2" 12.6# L-80, NSCT Tubing Top of 7" Liner at I 9238' Kick-off from Whipstock window at +/-9735' MD set bottom trip whipstock on P&A TOC at 9755'MD+/- J 7" x 4-1/2" HES TNT Production Packer @ 9500iMD+/- 4-1/2" 'XN' Landing Nipple, 3.725" No-Go ID @ 9530 +/- 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +/-9550' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 4-1/2" 12.6 #/ft, L-80, BTC-Mod TI:) at I +/~4275'1 Perfs 9728-9880 7", 29 #/ft, L80 I 1o58o'1 Fl~f~ R~v R.~ ~r~mrrlpnfci PRUDHOE BAY UNIT 12/14/99 JES Proposed (;;om[~letion WELL: 16-10Ai APl NO: Shared Services Drilling Shared Services Drilling 16-10A Wp03 Single Well Target Data for 16-10A WPS Measurement Units: ft Coordinate Target Point TVDrkb TVDss Northings Eastings ASP Y ASP X -Nam~ Type 16- IOA Wp03 Polygon EnU'y Point 2819.75 S 28~9,(X) W 5926024,(X) N 716591.(X) E Boundm'y Point A 2819.75 S 28~9.(X) W 5926024.(X) N 716591.(X) E B 5518.33 S 233.28 W 5923404,(X) N 719334,(X)E C 5120,07 S 245.49 E 5923816.00 N 719801.¢10 E D 2715,54 S 2250.70W 5926147,(X)N 717236.(XIE E 2343,88S 2267.91 W 5926518.1X) N 717208.(X) E F 2339,17S 2912.05W 5926504.00N 7165(~1-.00E 16-10AWplB TI Entry Point ~)40.{X) 897¢).00 2959.24 S 2367.83 W 5925~X).(X) N 717126.(X) E 16-1¢)AWp03 T2 Entry Point ~)20.(X) 8950,¢X) 3510.¢10 S 18{)7.15 W 5925365,76 N 717702.45 E 16-10AWp03 T3 Ent~' Point ~)45.(X) 8975.(X) 4160.(X)S 1145.47 W 5924735.26 N 718382.73 E 16-10AWp{B'I'4 Entry Point ~)30.(X) 8960.(10 4742,66 S 551.70W 5924170.09 N 718993.18 E 16-10AWp03T5 EnU'yPoint ~)60,(X) 8~)0.(X) 5165.42S 121,98W 5923760,(X)N 719435.(X)E DrillQuesf Proposal Data for 16-10A Wp03 Vertical Origin: Well Horizontal Origin: Well Measurement Units: ft North Reference: True North Dogleg severity: Degrees per 100ft Vertical Section Azimuth: 149.700° Vertical Section Description: Well Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 9735.00 35.061 240.041 8903.75 1763.66 S 2109,25W 458,56 9775.00 38,845 235.122 8935.71 1776,58 S 2129,51W 459.49 12.000 10154.07 93,120 198.619 9088.50 2051.79 S 2305.26W 608.44 16.500 10667.21 93.120 198,619 9060.57 2537.36 S 2468,85W 945.14 0.000 11125.00 91.481 134.489 9040.00 2959.24 S 2367,83W 1360.36 14,000 11125.00 91.481 134,489 9040.00 2959.24 S 2367.83W 1360.36 14.000 11886.52 91,481 134,489 9020.32 3492.71S 1824.76W 2094.95 0.000 11911.20 90.000 134.489 9020,00 3510.00S 1807.15W 2118.76 6.000 11937.69 88.411 134.490 9020.37 3528.56 S 1788.26W 2144.32 6.000 12812.59 88,411 134.490 9044.63 4141.44 S 1164.36W 2988.25 0.000 12839.08 90,000 134.489 9045.00 4160.00S 1145.47W 3013.80 6.000 12857.23 91.089 134.458 9044.83 4172.71 S 1132.52W 3031.32 6,000 13636.31 91.089 134.458 9030.03 4718.27 S 576.54W 3782.86 0.000 13671.12 89.000 134.489 9030.00 4742.66 S 551.70W 3816.44 6,000 13702.78 87,101 134.533 9031.08 4764.84 S 529.14W 3846,98 6.000 14274.68 87,101 134,533 9060.00 5165.42 S 121.98W 4398.26 0.000 8500 9000 - II .-- I I I I I I I I 500 1000 1500 2000 2500 3000 3500 4000 4500 Scale: linch = 500ft Vertical Section Section Azimuth: 149.700° (True North) OFtlL t_ING SEEI~Vlr'Es Shared Services Drilling 16-10A Wp03 Proposal Data for 16-10A Wp03 Verfieal Odgin: Horizontal Odgh: Measurement Un,ts; North Refere~lce: True North Dogleg severity: Degrees per 100ft Vertical Section Azimuth: 149.700° Vertical Section Description: Well Vertk::al Sectk>n Odgln: 0.00 N,O.O0 E Measured Incl. Azim. VerticalNorthings Eastings Vertical Dogleg Depth Depth SectionRate 9735.0035.061240.041 8903.75 ]763.66 S 210925 W 458.56 9775.f10 38.845235.122 8935.71 1776.58 S 2129.51 W459.49 12.000 10154.07 93.120198.619 908830 2051.79 S 2305.26 W6O8.44 16500 10667.21 93.120198.619 906037 253736 S 246835 W 945.14 0.000 11125.00 91.481134.489 9(MO.OD 295924 S 2367.83 W13f:~-~6 I4.0CO [ 1125.1}0 91.4811 .M-.489 904-0.00 295924 S 2367.~3 W1 _~o02,6 14.{~O 118563291.481134.489 9020.32 3492.71 S 1824.76 W2094.95O.IX}O 119112090.000134.489 9O2O.00 3510.00 S 1807.15 W2118.76 11937.69 88.411134.490 902037 3528.56 s 178826 w 2144.326.000 12812398&4ll 134.490 9044.63 4141_44 S 1164_~6 W298825 0.000 12839.O8 90.000LM.489 9045.C0 4100310 S 1145.47%'3013.806.OOO 128572391.0891_34.4589O44.83 4172.71 S 113232 W _303132 136363191.089134.458 903O.03 471827 S 57654 W 3782-.86 0.0(~0 13671.12 89.0ffl 134.489 9030.00 4742.66 S 551.70 W 3816.44 13702.78 87.101134.533 9031.08 4764.84 S 529.14 W 3846.986.000 14274.68 87.101134333 9(Y~O.tl) 5165.42 S 121.98 W 439826 0.000 Single Well Target Data for 16-10A WPS Measurement Units: fl 16-10A Wp03 Polygon Coordinate Point 16-IOA Wp03 TI 16-10A Wp03 T2 16-10A Wp03 T3 16-10A Wp03 T4 16-10A Wp03 T5 -1800 -- End Dir' 10154.07ft -2400 - Start Dir @ 14.00( 10667.21ft MD, 9( End Dir: 9040.00ff -3000 - End C~ -3600 -- .-- -4200 - -4800 -- o Z Entry Point Boundm3' Point ,~ C D Entry Point Emry Point Enuy Point Entry Point Entry Point I DrillQuesf '-.. -5400 -- -- 'rVDrkb TVDss Northings Eastings ASP Y ASPX 2819.75S 2899.00W 5926024,00N 716591.00E 2819.75S 2899.00%' 5926024.0ON 716591.0OE 5518.33S 233.28 W5923404. lO N 719334.1X1E 5120.07 S 245.49 E5923816.00 N 719801.00 E 2715.54S 2250.70W5926147.00N 717236.00E 2343.88sS 2267.91 wW 5926518.00N 717208.00E 2339.17 2912.05 5926504.00 N 716564.00 E 9040.00 8970.00 2959.24S 2367.83W5925900.0ON 717126.0OE 9020.0(I 8950.00 3510.00S 1807.15W5925365.76N 717702.45E eA)45.DO 8975.00 4160.00S 1145.47W5924735.26N 718382.73E 9030.00 8960.00 4742.66S 551.70W 5924170.09N 718993.18E 9060.00 8990.00 5165.42S 121.98W 5923760.00N 719435.00E Eastings -2400 -1800 -1200 -600 o I I I I I '~.~ KOP: Start Dir @ 12.000°/100ft: 9735.00ft MD, 8903.75ft TVD Dir Rate Increase @ 16.500°/100ft · 9775.00ft MD, 8935.71ft -I-VD /ID, 9088.50ft 1125.00ft MD, Start Dir @ 6.0000/` 11886.52, MD, 9020.3P_ft TVD Dir: 11937.69ft MD, 9020.37ft TVD '%~7.~~ Start Dir @ 6.000°/100ft: 12812.59ft MD, 9044.63ft -I-VD End Dir: 12857.23ft MD, 9044.83ft TVD Start Dir @ 6 O00°/lO0ft: 13636.31ft MD, 9030.03ft TVD % End Dir' 13702.78ft MD, 903; 08ft TVD~'oq%¢~'~'~~ / 14274.68 MD 9060.00 TVD - -1800 - -2400 -- -3000 - -3600 .~_ - -4200 - -4800 - -5400 '-.. -2400 -1800 -1200 -600 0 Scale: linch = 600ft Eastings Reference is True North Sp ?Y-Sun Drilling S )rvices Proposal Data- 16-10A WPS- 16-10A Wp03 ? .'!'."~Y!: /~0~67;'7'2:~'::i:i ~:~/~::~[![:R:3:.:~<~2~> :.~9:~ii:6~9--: ~06U;~'i5.7::::':.::::.':~:-~-~<;:9.3:-2.~3:-~::C:3~!!:::S" 2468:~:8S -l~:/.' :...0. 000 0. 000 945.14 ::C:'.7-~:--Jf:':'-f:':':'-::. '/4 7-:':::'.'-v::f-?v'(:.(+):kf.%L'.:.:.:'. ::.'.';:..=_.'.:..':.'_=:.:.::.-:.: y: - - ' ' ' ' .... ~[:~:~:::~:[~:[~[[~[~(:::~:[~2:5~[:~:~::::~.:~.::.:~:~}~:~.:~::~.9~.~:. 91. 481~ 134. 489 9040. O0 [--:::~:'.~':::.:2:~':~:~:[:'$~.::~ 959.24 S- 2367.83 W 14. 000 270. 132 1360.36 ................................... _--. :-::_.:.:...........--: :-:.-:..-.... . :I:::~:f~-;:::-:;:;:::~:~:~:~::~;:~:~:~:::-:-:~:::~-::~::::::~-~:~:~:~:-:~T::~:~8~-:-~:~:::~:-~::~:8~~ 9~'0.:~ U~::":-':':::.-::':.:~::'?::':0-.'?~0:::2-:9~9':~:2~.::'-_S :2367::;:83: ;W::~ 14.000 25 9.403 1360.36 .... :.....:::. ... ]::?.: -'-7' :-::::-:::'1'~'6'~::52'<":' ::~.61:-:~:.[E'~: -:.-:9:I¥.~8:I; :J:23~.~9:: ":-'0'. 000 0. 000 2094.95 . 90. 000 134. 489 i 9045. O0 ?:[:[[:[:[:[.::-i-:i::i!::P('[:i-~:.~ii~ 160.00 Si 1145.47 W~ 6. 000 359. 970 3013.80 3031.32 3782,86 3816.44 3846.98 4398.26 13 December, 1999- 10:15 - I - DrillQuest North Slope Alaska Alaska State Plane 4 PBU_ EOA DS 16, Slot 16- I OA WPS 16-10A WPS- 16-10A Wp03 PROPOSAL REPORT 13 December, 1999 Surface Coordinates: 5928926.78 N, 719406.86 E (70° 12' 30.0182" N, 148° 13' 50.6399" W) Kelly Bushing: 70. OOft above Mean Sea Level DRILLING SERVICES Proposal Ref: pro9526 Sperry-Sun Drilling Services Proposal Report for 16- I OA WPS - 16- I OA Wp03 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 9735.00 35.061 240.041 8833.75 9752.59 36.700 237.771 8848.00 9775.00 38.845 235.122 8865.71 9800.00 41.986 230.994 8884.75 9857.78 49.700 223.161 8925.00 9900.00 55.613 218.520 8950.61 9926.81 59.449 215.909 8965.00 10000.00 70.139 209.683 8996.15 10100.00 85.025 202.372 9017.62 10154.07 93.120 198.619 9018.50 10200.00 93.120 198.619 9016.00 10300.00 93.120 198.619 9010.55 10400.00 93.120 198.619 9005.11 10500.00 93.120 198.619 8999.67 10600.00 93.120 198.619 8994.22 10667.21 93.120 198.619 8990.57 10700.00 93.121 194.022 8988.78 10800.00 92.999 180.002 8983.41 10900.00 92.699 165.988 8978.42 11000.00 92.239 151.982 8974.09 11100.00 91.646 137.987 8970.68 11125.00 91.481 134.489 8970.00 11200.00 91.481 134.489 8968.06 11300.00 91.481 134.489 8965.48 11400.00 91.481 134.489 8962.89 Vertical Local Coordinates Global Coordinates Dogleg Depth Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (°/100ft) 8903.75 1763.66 S 2109.25 W 5927102.59 N 717349.74 E 8918.00 1768,98 S 2118.07W 5927097.01 N 717341.07 E 12.000 8935.71 1776.58 S 2129.51W 5927089.09 N 717329.87 E 12.000 8954.75 1786.33 S 2142.44W 5927078.96 N 717317.22 E 16.500 8995,00 1814.63 S 2172.60W 5927049.80 N 717287.90 E 16.500 9020.61 1840.03 S 2194.49W 5927023.77 N 717266.75 E 16.500 9035.00 1858.05 S 2208.16W 5927005.37 N 717253.62 E 16.500 9066.15 1913.68 S 2243.82W 5926948,72 N 717219,59 E 16,500 9087,62 2001.20 S 2286.36W 5926860,00 N 717179,61E 16,500 9088.50 2051.79 S 2305.26W 5926808,88 N 717162.18 E 16.500 9086.00 2095.26 S 2319.91W 5926765.01N 717148.80 E 0.000 9080.55 2189.88 S 2351.79W 5926669.50 N 717119.69 E 0.000 9075.11 2284.51 S 2383.67W 5926573.99 N 717090.57 E 0.000 9069.67 2379.13 S 2415.55W 5926478.47 N 717061.45 E 0.000 9064.22 2473.76 S 2447.43W 5926382.96 N 717032.33 E 0.000 9060.57 2537.36 S 2468.85W 5926318.77 N 717012.76 E 0.000 9058.78 2568.77 S 2478.05W 5926287.10 N 717004.48 E 14.000 9053.41 2667.63 S 2490.21W 5926187.93 N 716995.20 E 14.000 9048.42 2766.52 S 2478.06W 5926089.44 N 717010.22 E 14.000 9044.09 2859.54 S 2442.32W 5925997.49 N 717048.65 E 14.000 9040.68 2941.19 S 2385.11W 5925917.54 N 717108.20 E 14.000 9040.00 2959.24 S 2367.83W 5925900.00 N 717126.00 E 14.000 9038.06 3011.78 S 2314.35W 5925849.04 N 717180.99 E 0.000 9035.48 3081.83 S 2243.03W 5925781.09 N 717254.31E 0.000 9032.89 3151.88 S 2171.72W 5925713.13 N 717327.63 E 0.000 Alaska State Plane 4 PBU_EOA DS 16 Vertical Section (ft) 458.56 458.71 459.49 461.39 470.60 481.49 490.15 520.20 574.30 608.44 638.58 704.19 769.81 835.42 901.04 945.14 967.62 1046.84 1138.35 1236.70 1336.05 1360.36 1432.70 1529.17 1625.63 Comment KOP: Start Dir @ 12.000°/100ft: 9735.00ft MD, 8903.75ft TVD Shublik Dir Rate Increase @ 16.500°/100ft: 9775.00ft MD, 8935.71ft TVD TSAD-Z4B HO/T End Dir: 10154.07ft MD, 9088.50ft TVD Start Dir @ 14.000°/100ft: 10667.21ft MD, 9060.57ft TVD End Dir: 11125.00ft MD, 9040.00ft TVD Tarqet - 16-10A Wp03 T1, Geological Continued... 13 December, 1999 - 9:46 - 2 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 16- I OA WPS - 16- I OA Wp03 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 11500.00 91.481 134.489 8960.31 11600.00 91.481 134.489 8957.72 11700.00 91.481 134.489 8955.14 11800.00 91.481 134.489 8952.55 11886.52 91.481 134.489 8950.32 11900.00 90.672 134.489 8950.07 11911.20 90.000 134.489 8950.00 11937.69 88.411 134.490 8950.37 12000.00 88.411 134.490 8952.10 12100.00 88.411 134.490 8954.87 12200.00 88.411 134.490 8957.64 12300.00 88.411 134.490 8960.42 12400.00 88.411 134.490 8963.19 12500.00 88.411 134.490 8965.96 12600.00 88.411 134.490 8968.74 12700.00 88.411 134.490 8971.51 12800.00 88.411 134.490 8974.28 12812.59 88.411 134.490 8974.63 12839.08 90.000 134.489 8975.00 12857.23 91.089 134.458 8974.83 12900.00 91.089 134.458 8974.01 13000.00 91.089 134.458 8972.12 13100.00 91.089 134.458 8970.22 13200.00 91.089 134.458 8968.32 13300.00 91.089 134.458 8966.42 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9030.31 3221.94 S 2100.40W 5925645.18 N 717400.95 E 9027.72 3291.99 S 2029.09W 5925577.23 N 717474.27 E 9025.14 3362.04 S 1957.77W 5925509.28 N 717547.59 E 9022.55 3432.10 S 1886.46W 5925441.33 N 717620.91 E 9020.32 3492.71 S 1824.76W 5925382.54 N 717684.35 E 9020.07 3502.15 S 1815.14W 5925373.37 N 717694.23 E 9020.00 3510.00 S 1807.15W 5925365.76 N 717702.45 E 9020.37 3528.56 S 1788.26W 5925347.76 N 717721.87 E 9022.10 3572.21 S 1743.82W 5925305.41 N 717767.56 E 9024.87 3642.26 S 1672.51W 5925237.46 N 717840.87 E 9027.64 3712.31 S 1601.20W 5925169.51 N 717914.19 E 9030.42 3782.37 S 1529.89W 5925101.56 N 717987.50 E 9033.19 3852.42 S 1458.58W 5925033.61 N 718060.82 E 9035.96 3922.47 S 1387.27W 5924965.66 N 718134.13 E 9038.74 3992.52 S 1315.96W 5924897.71 N 718207.45 E 9041.51 4062.57 S 1244.65W 5924829.76 N 718280.76 E 9044.28 4132.62 S 1173.34W 5924761.81 N 718354.08 E 9044.63 4141.44 S 1164.36W 5924753.26 N 718363.31 E 9045.00 4160.00 S 1145.47W 5924735.26 N 718382.73 E 9044.83 4172.71S 1132.52W 5924722.92 N 718396.05 E 9044.01 4202.67 S 1101.99W 5924693.87 N 718427.43 E 9042.12 4272.69 S 1030.63W 5924625.95 N 718500.80 E 9040.22 4342.72 S 959.27W 5924558.02 N 718574.16 E 9038.32 4412.75 S 887.90W 5924490.10 N 718647.53 E 9036.42 4482.77 S 816.54W 5924422.18 N 718720.90 E Dogleg Rate (°/lOOff) 0.000 0.000 0.ooo o.0oo o.ooo 6.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_EOA DS 16 Vertical Section (ft) 1722.10 1818.56 1915.02 2011.49 2094.95 2107.96 2118,76 2144.32 2204.43 2300.89 2397.35 2493.81 2590.26 2686.72 2783.18 2879.64 2976.10 2988.25 3013.80 3031.32 3072.58 3169.04 3265.51 3361.97 3458.44 Comment Start Dir @ 6.000°/100ft: 11886.52ft MD, 9020.32ft TVD (~arget: 1,6-10A Wp03 T2, eolog~ca~ End Dir: 11937.69ft MD, 9020.37ft TVD Start Dir @ 6.000°/100ft: 12812.59ft MD, 9044.63ft TVD (~arget - 1.6-10A Wp03 T3, eo~ogica~ End Dir: 12857.23ft MD, 9044.83ft TVD Continued... 13 December, 1999 - 9:46 - 3 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 16- I OA WPS - 16- I OA Wp03 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 13400.00 91.089 134.458 8964.52 13500.00 91.089 134.458 8962.62 13600.00 91.089 134.458 8960.72 13636.31 91.089 134.458 8960.03 13671.12 89.000 134.489 8960.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9034.52 4552.80 S 745.18 W 5924354.26 N 718794.27 e 9032.62 4622.82 S 673.81 W 5924286.33 N 718867.64 e 9030.72 4692.85 S 602.45 W 5924218.41 N 718941.00 E 9030.03 4718.27 S 576.54 W 5924193.75 N 718967.64 E 9030.00 4742.66 S 551.70 W 5924170.09 N 718993.18 E 13700.00 87.268 134.529 8960.94 9030.94 4762.90 S 531.12 W 5924150.46 N 719014.34 E 13702.78 87.101 134.533 8961.08 9031.08 4764.84 S 529.14 W 5924148.58 N 719016.37 E 13800.00 87.101 134.533 8965.99 9035.99 4832.94 S 459.92 W 5924082.52 N 719087.54 E 13900.00 87.101 134.533 8971.05 9041.05 4902.98 S 388.73 W 5924014.58 N 719160.74 E 14000.00 87.101 134.533 8976.11 9046.11 4973.02 S 317.54 W 5923946.63 N 719233.94 E 14100.00 87.101 134.533 8981.17 9051.17 5043.06 S 246.34 W 5923878.69 N 719307.14 E 14200.00 87.101 134.533 8986.22 9056.22 5113.11 S 175.15 W 5923810.74 N 719380.33 E 14274.68 87.101 134.533 8990.00 9060.00 5165.42 S 121.98 W 5923760.00 N 719435.00 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Dogleg Rate (°/100ft) 0.000 0.000 0.000 0.000 6.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_EOA DS 16 Vertical Section (ft) 3554.90 3651.37 3747.83 3782.86 3816.44 3844.30 3846.98 3940.69 4037.09 4133.48 4229.87 4326.27 4398.26 Comment Start Dir @ 6.000°/100ft· 13636.31ft MD, 9030.03ft TVD Tamet - 16-10A Wp03 T4, Geological End Dir: 13702.78ft MD, 9031.08ft TVD Total Depth: 14274.68ft MD, 9060.00ft TVD 4 1/2" Liner (%~r[let: 1,6-10A Wp03 T5, o~og~ca~ The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 149.700° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14274.68ft., The Bottom Hole Displacement is 5166.86ft., in the Direction of 181.353° (True). Continued... 13 December, 1999 - 9:46 - 4 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 16- I OA WPS - 16- I OA Wp03 North Slope Alaska Alaska State Plane 4 PBU_EOA DS 16 Comments Measured Depth (fi) 9735.00 9775.00 10154.07 10667.21 11125.00 11886.52 11937.69 12812.59 12857.23 13636.31 13702.78 14274.68 Formation Tops Measured Depth (ft) 9752.59 9857.78 9926.81 Station Coordinates TVD (ft) 8903.75 8935.71 9088.50 9060.57 9040.00 9020.32 9020.37 9044.63 9044.83 9030.03 9031.08 9060.00 Northings (fi) 1763.66 S 1776.58 S 2051.79 S 2537.36 S 2959.24 S 3492.71S 3528.56 S 4141.44 S 4172.72 S 4718.28 S 4764.84 S 5165.42 S Eastings (ft) 2109.25 W 2129.51 W 2305.26 W 2468.85 W 2367.83 W 1824.75 W 1788.25 W 1164.36 W 1132.52 W 576.54 W 529.14 W 121.98 W Comment KOP: Start Dir @ 12.000°/100ft: 9735.00ft MD, 8903.75ft TVD Dir Rate Increase @ 16.500°/100ft: 9775.00ft MD, 8935.71ft TVD End Dir: 10154.07ft MD, 9088.50ft TVD Start Dir @ 14.000°/100ft: 10667.21ft MD, 9060.57ft TVD End Dir: 11125.00ft MD, 9040.00ft TVD Start Dir @ 6.000°/100ft: 11886.52ft MD, 9020.32ft TVD End Dir: 11937.69ft MD, 9020.37ft TVD Start Dir @ 6.000°/100ft: 12812.59ft MD, 9044.63ft TVD End Dir: 12857.23ft MD, 9044.83ft TVD Start Dir @ 6.000°/100ft: 13636.31ft MD, 9030.03ft TVD End Dir: 13702.78ft MD, 9031.08ft TVD Total Depth: 14274.68ft MD, 9060.00ft TVD Vertical Sub-Sea Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) 8918.00 8848.00 1768.98 S 2118.07 W Shublik 8995.00 8925.00 1814.63 S 2172.60 W TSAD-Z4B 9035.00 8965.00 1858.05 S 2208.16 W HO/T Continued,.. 13 December, 1999 - 9:46 - 5 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 16- I OA WPS - 16- I OA Wp03 North Slope Alaska Alaska State Plane 4 PBU_EOA DS 16 Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) <Run-TD> <Run-TD> Tar§ets associated with this wellpath Target Name 16-10A Wp03 Polygon Casing Detail 4 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 #5 #6 Mean Sea Level/Global Coordinates #1 #2 #3 #4 #5 #6 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 70.00 2819.75 S 2899.00 W 0.00 5926024.00 N 716591.00 E 70° 12' 02.2791" N 148° 15' 14.7514" W 70.00 2819.75 S 2899.00 W 70.00 5518.33 S 233.28 W 70.00 5120.07 S 245.49 E 70.00 2715.54 S 2250.70 W 70.00 2343.88 S 2267.91 W 70.00 2339.17 S 2912.05 W 0.00 5926024.00 N 716591.00 E 0.00 5923404.00 N 719334.00 E 0.00 5923816.00 N 719801.00 E 0.00 5926147.00 N 717236.00 E 0.00 5926518.00 N 717208.00 E 0.00 5926504.00 N 716564.00 E Target Target Shape Type Polygon Geological Continued... 13 December, 1999 - 9:46 - 6 - DrillQuest 1.05.04c Sperry-Sun Drilling Services Proposal Report for 16- I OA WPS - 16- I OA Wp03 North Slope Alaska Target Name Targets associated with this wellpath (Continued) 16-10A Wp03 T1 16-10A Wp03 T2 16-10A Wp03 T3 16-10A Wp03 T4 16-10A Wp03 T5 Geographical Coordinates #1 #2 #3 #4 #5 #6 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 9040.00 8970.00 9020.00 8950.00 9045.00 8975.00 9030.00 8960.00 9060.00 8990.00 70° 12'02.2791"N 148° 15'14.7514"W 70° 11'35.7427"N 148° 13'57.4056"W 70°11'39.6597"N 148°13'43.5191"W 70° 12'03.3063"N 148° 14'55,9425"W 70°12'06.9616"N 148°14'56.4451"W 70°12'07.0058"N 148°15'15.1352"W 2959.24 S 2367.83W 5925900.00 N 717126.00 E 70° 12'00.9090"N 148° 14'59.3387"W 3510,00 S 1807.15W 5925365.76 N 717702.45 E 70° 11'55.4935"N 148° 14'43.0675"W 4160.00 S 1145.47W 5924735.26 N 718382.73 E 70°11'49,1017''N 148°14'23.8684"W 4742.66 S 551.70W 5924170.09 N 718993.18 E 70°11'43.3716"N 148° 14'06.6426"W 5165.42 S 121.98W 5923760.00 N 719435.00 E 70°11'39.2138"N 148°13'54.1777"W Alaska State Plane 4 PBU_EOA DS 16 Target Target Shape Type Point Geological Point Geological Point Geological Point Geological Point Geological 13 December, 1999 - 9:46 - 7 - DrillQuest 1.05.04c Anti-Collision Scan Results Operator: ARCO Field: Prudhoe Bay Well: 16-10A Rig: Nordic3 Date : 20:41, 13 Dec 99 Scan of existing interference data set Search Parameters :- Minimum Search Depth(MD): 9700.00 ft Maximum Search Depth(MD): 14274.68 ft Search Radius at minimum search depth: 1000.00 ft Rate of Search Radius increase: 100.00 ft/1000ft Subject Well Plan Description : 16-10A Wp03 Subject Well Plan Data Points MD Inc Azm (ft) (deg) (deg) 9700 00 36 000 239.780 9735 00 35 9775 00 38 10154 07 93 10667 21 93 11125 00 91 11886 52 91 11911 20 90 11937.69 88 12812 59 88 12839 08 90 12857 23 91 13636 31 91 13671 12 89 13702 78 87 14274 68 87 061 240.041 845 235.122 120 198.619 120 198.619 481 134.489 481 134.489 000 134 489 411 134 490 411 134 490 000 134 489 089 134 458 089 134 458 000 134 489 101 134 533 101 134 533 North <ft) -1753 46 -1763 65 -1776 57 -2051 79 -2537 35 -2959 23 -3492 70 -3510 00 -3528 56 -4141.44 -4160 00 -4172 71 -4718 27 -4742 66 -4764 84 -5165 41 East (ft) -2091.69 -2109 28 -2129 54 -2305 30 -2468 89 -2367 86 -1824 79 -1807 19 -1788 29 -1164 40 -1145 51 -1132 56 -576.58 -551.74 -529.18 -122.02 TVD (ft) 8875 27 8903 8935 9088 9060 9040 9020 9020 9020 9044 9045 9044 9030 9029 9031 9060 DLS (deg/100ft) 2 718 75 12 71 16 5O 0 57 14 01 0 32 6 00 5 37 0 63 5 00 6 83 0 02 6 99 6 O7 0 00 0 000 50O 000 000 000 000 999 000 999 003 000 001 000 000 000 Subject Well Survey Programme Details: No Instrument Run Type 1 Photo-Gyro Multishot 2 MWD - Standard (declination corrected Planned Depths Start End Et) (ft) 100.00 9700.00 9735.00 20000.00 Well : 16-10 Wellbore : 16-10seql Survey : Definitive WDF - Composite Survey Description : Created by procedure WDFGEN2.2 Risk Criteria : Major/Minor-New SF Relative Surface Position Uncertainty : Object Well WDF Composition Details: No Instrument Run Type 1 Photo-Gyro Multishot O. O0 (ft) Actual Depths Start End (ft) (ft) 100.00 10589.00 Interference Detected: MINOR Risk Output Object Well Sub=ect Well Allow Planned Hside Rel Mininum Allowable MD SMA Unc MD SMA Unc for well Angle Azi tolerable deviation (lsd) (lsd) bias separation separation from plan (ft) (ft) (ft) (ft) (ft) (ft) (deg) (ft) (ft) 9700.00 125.16 9700 00 125 16 9800.00 127.90 9799 9900 00 130.56 9889 10000 00 133.24 9960 10100 00 135 93 10015 10200 00 138 63 10056 10300 00 141 34 10087 10400 00 144 07 10111 10500 00 146 80 10130 10589.00 149 25 10144 38 125 17 04 125 20 93 125 25 50 125 28 47 125 30 55 125 32 58 125 33 55 125 34 29 125 34 0 00 0 0 0 0 0 0 0 0 0 0.00 0 0 239 8 665 73 -134.78 00 5.50 151 00 37.34 156 00 90.47 158 00 157 98 158 00 234 90 159 00 317 99 159 00 405 21 159 00 495 27 158 00 577 14 158 4 22 4 16 2 11 9 7 1 4 1 2 0 0 8 359 7 358 5 676 1 674 1 663 4 648 5 639 3 630 5 625 1 623 0 622 55 -339 36 02 -322 25 36 -257 65 50 -167 56 32 -66 87 70 37 66 60 143 31 70 248 98 21 342 66 Summary of Contents Wellbore Name 16-10seql Survey Type Definitive WDF - Composite ** End of Summary ** Interference Yes Al aa ka .,.,hared : ervices rilling WELL NAME: DS 16-10Ai DRILLING PERMIT / SUNDRY / PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. r~DRILLING PERMIT ~]~Pe rmit DocL~ entatio~C~pared:ODE: ~_.,,~.,~ ~,¢.~ Date: ~;;~Permit Apl~ication Reviewed: S E/ES:~__~.~~ Date: ~Permit Applica~n S~b~it~ed: ~ ~ TA: ~~ ~~Date: F'--IPRE-RIG WORK ~-~Pre-Rig Memo Reviewed: SDE / ES: Date: r'~Pre-Rig Memo Sent to Slope: ODE: Date: ~-]Pre-Rig Sundry Documentation Prepared: ODE: Date: ~-~Pre-Rig Sundry Application Reviewed: SDE / ES: Date: [~Pre-Rig Sundry Application Submitted: TA: Date: F~APPLICATION FOR SUNDRY APPROVAL ~'JSundry Documentation Prepared: ODE: Date: F'-]Sundry Application Reviewed: SDE / ES: Date: ~'-ISundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK, USE PRE-RIG WORK SECTION AT BELOW LEFT Reason for Sundry (Check all that apply) Abandon Alter Casing Change Approved~.rogram Operation Shutdo~ Perforate ~ Plugging Pull Tubing Re-enter Suspended Repair Well Stimulate Su .en ~Time E~ension ~Variance IOther (Explain): Approved AOGCC Permit / Sundry Received Approval to Commence Operations TA: Date: SDE / ES: Date: STATE OF ALASKA ' ALASK, _)IL AND GAS CONSERVATION Ct.,MMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator ARCO Alaska Inc. !3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2006' SNL, 613' EWL, SEC. 24, T10N, R15E, UM At top of productive interval 1482' NSL, 1550' WEL, SEC. 23, T10N, R15E, UM At effective depth Type of well: I--] Development [~ Exploratory [] Stratigraphic [~ Service At total depth 6. Datum Elevation (DF or KB) 70' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 16-10 9. Permit Number 180-04 10. APl Number 50- 029-20506 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay 1287' NSL, 1893' WEL, SEC. 23, T10N, R15E, UM Pool 12. Present well condition summary ,__. /~ / , \ PB gged at 9903 MD (11/25/95) Total depth: measured 10589 feet Plugs (measured) \~ ~B/7'D..T.~g , ~ .. true vertical 9626 feet '~ // "~') Effective depth: measured 9903 feet Junk (measured) true vertical 9044 feet. ~. / Casing Length Size ~'~ Cemer~ et/ed MD ~ TVD Structural Conductor 110' 20" ..300 '_~x Permafrost/ ,~'110' 110' Surface 2655' 13~3/8" 2~,0~Fondu,/2~0 sx Permafrost \ ~2725' 2725' Intermediate ~, "' / ~. \ , Production 9483' 9-5/8;' 500 sx Class ~' .i~l'", 9553' 8760 Liner 1342' 7" ,'~'502 sx cem t , ~\ i ~ ~238' - 10580' 8522' - 9618' Perforat,o~ 9728,. 9880,~~',v'e interval/ ~~ / t rue va rt ical '"'~8 ~-"(~~.,.9~.._.)~ / {.---~'~ ~ (s~.e, grade, and measured de~th)4-1/2", 12.6.6~, L-80 to 9293' 113iAttachments [~]~criptionsummar~ofproposal__ / ~--J Detailed operations program ~--~ BOP sketch 114~.Es~.~ted date f°r corr~encinq opera~tion 15. Status of well classifications as: Dece~m'ber~22;1~/99 16. If proposal was verbally app'l~¥.,ed / [] Oil E~] Gas [] Suspended / / Service Water Injection Name of approver / Date approved contact Engineer Name/Number: ~l~rnes Smith, 564-5026 Prepared By Name/Number: 17. I hereby certify that the fore,gding is true and correct to the best of my knowledge Signed / Dan Stone ~=,... "r~. ~ Title Senior Drilling Engineer Terrie Hubble, 564-4628 Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate DATE INVOICE / CREDIT MEMO DE~RIPTION GROSS DISCOUNT NET 120999 CK120999 100.00 100.00 HANDL]iNO [NST' S/H TERR! HUBBLE ,, THE A~ACHED CHECK IS IN PAYMEm FOR ~MS DE~RIBED ABOVE. ~ 100. O0 100. O0 EXPLORATION (ALASKA)~i:INC, '..:: .;.: 'ANCHOrAGE;ALASKA? 99519-6612 ;! I~iRST ~TIoNAL BANI(' OF AsHE;AND '":':il ": '!: AN:AI~FI~IATE:OF ..... :' ..... ' . : :::':': ..: N~'CiONAL.~ITY,BAhK ::!"!: L: :; ::~.::': ', ·CLEVELAND OHiO :i ::'. :: ·. :.: .. ':: ,; :: : 2' : 'iili;.'5~-389.: .: :'":" ' :: :: :: ::.. ..: .., :;, 412 No., :.5 994 CONSOLIDATED COMMERCIA~:ACCOU'NT :{::: O015;~"7 :::?.': PAY TO: The' ... ORDER · : .. DATE . ::AMOUNT ' I 12/10/99 [ $100. O0 · :: ::'i :' :'i::.i:: i 'i: . . ':'. NOT:iVALID AFTER I:L~ DAYS ' :,. ;~':~-'~.. ANCHORAOE AK 99501 ~ "' :' .ALASKA OIL AND.OAS:.': C ONS~ VAT I ON '. C CIIff" I sS I ON 3001' PORCUP ] NE: DR 1' VE WELL PERMIT CHECKLIST CO M PAN'Y'~"/f~',," INIT CLASS ADMINISTRATION . 8. 9. 10. 11. DA'T'E. 12. ' WELL NAME/~/E/[) 6I//~ '-/~ PROGRAM: ENGINEERING Permit fee attached ....................... Lease number appropriate. .~ ................. Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................ .... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~-'OC)C-~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. exp __ AREA dev __ redrll t/ serv g"'"' wellbore seg __ann. disposal para req __ GEOLOGY 30. 31. 32. .RDATE 33. /2--. / (,, -~ 34. ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan ~ (A) will contain waste in a suitable re~,ceM-ng zone; ....... (B) will not contaminate freshw~; or cause drilling waste... to surface; ~ (C) will not impair mec/l:~nical integrity of the well used for disposal; (D) will not damag/e,15roducing formation or impair recovery from a pool; and ~ (E) will not circbmvent 20 AAC 25.252 or 20 AAC 25.412. Permit can be issued w/o hydrogen sulfide measures ..... Y N~ Data presented on potential overpressure zones ....... ,/'J'q Y N --- Seismic analysis of shallow gas zones ............. ,,2,4 Y N Seabed name/phone for weekly progress reports [e~ condition survey (if off-shore) .............. ,~ ~ N Contact Y N Y N Y N Y N GEOLOGY: ENGINEERING: UICL_Annular RP~,, BE .VV"----~ WM SFDT~/'7~~- JDH /y'~"'~ _ ' c:\msoffice\wordian\diana\¢hecklist (rev. 0~/27/~) COMMISSION: DWJ RNC CO (;~,~/~1~ Comments/Instructions: Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX, ,, No special'effort has been made to chronologically organize this category of information. o, Sperry-Sun Drillin9 Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Aug 17 14:00:53 2000 Reel Header Service name ............. LISTPE Date ..................... 00/08/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/08/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientifib Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 3 AK-MM- 90224 MARK HANIK PHIL SMITH 16-10A 500292050601 ARCO Alaska, Sperry Sun 17-AUG-00 MWD RUN 4 AK-MM-90224 MARK HANIK PHIL SMITH 24 i0N 15E 2006 613 64.30 Inc. RECEIVED Alaska Oil & (.'.as Cons. uomm~ss~on Anchorage DERRICK FLOOR: 27.80 GROI/ND LEVEL: 36.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 9735.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS A MARKER RUN WITH DUAL GAMMA RAY'(DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS TO LOG THROUGH CASING ON A CLEAN OUT RUN AND IS NOT PRESENTED. 3. MWD RUN 2 IS A DIRECTIONAL ONLY RUN TO SET THE WHIPSTOCK AND IS NOT PRESENTED. 4. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 5. GAP IN HATE OF PENETRATION (SROP) FROM 9939' MD, 9039'TVD TO 10001' MD, 9061' TVD DUE TO LOSS OF DEPTH CONTROL. INTERVAL WAS MADPASSED TO FILL IN MISSING MWD DATA. 6. DIGITAL AND LOG MWD DATA ARE TIED INTO THE PARENT WELLBORE 16-10. THIS WELL KICKS OFF FROM 16-10 AT 9735' MD, 8903' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1-4 REPRESENT WELL 16-10A WITH API 50-029-20506-01. THIS WELL REACHED A TOTAL DEPTH OF 14180'MD, 9079'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SH31LLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9703.0 14121.5 RPD 9710.0 14128.5 RPM 9710.0 14128.5 RPS 9710.0 14128.5 RPX 9710.0 14128.5 FET 9747.0 14128.5 ROP 9747.5 14165.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 9703.0 9717.0 9732.5 9746.5 9733.5 9748.0 14165.0 14180.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 $ REMARKS: MERGED MAIN PASS. $ EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined MERGE TOP MERGE BASE 9717.0 13652.0 13652.5 14180.0 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OH]MM 4 1 68 MWD OPRMM 4 1 68 MWD HRS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9703 14165 ROP MWD FT/H 0.01 694.92 GR MWD API 14.95 508.17 RPX MWD OHMM 0.15 2000 RPS MWD OHMM 0.14 2000 RPM MWD OHMM 0.13 2000 RPD MWD OPLMM 0.24 2000 FET MWD HRS 0.28 41.93 Mean 11934 67.0588 57.9997 37.9371 34.0976 38.6714 82.3243 1.79017 Ns am 8925 8711 8838 8838 8838 8838 8838 8764 First Readin9 9703 9747.5 9703 9710 9710 9710 9710 9747 Last Readin9 14165 14165 14121.5 14128.5 14128.5 14128.5 14128.5 14128.5 First Readin9 For Entire File .......... 9703 Last Readin9 For Entire File ........... 14165 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: R3kWMWD Curves and log header data for each bit run in separate files. BIT RLTNNUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9717.0 13607.0 RPX 9724.0 13614.0 RPD 9724.0 13614.0 RPS 9724.0 13614.0 RPM 9724.0 13614.0 FET 9761.5 13614.0 ROP 9762.0 13652.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASLrRED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 24-JAN-00 Insite 5.16 Memory 13652.0 39.0 94.7 TOOL NUMBER PB01411GRV4 PB01411GRV4 6.000 Water Based 8.70 38.0 9.0 24000 7.8 .190 .105 .180 .160 78.0 147.0 76.0 72.0 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ............. ~...Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HRS 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HRS Min Max Mean Nsam 9717 13652 11684.5 7871 0.01 694.92 66.1488 7656 14.95 508.17 58.2143 7781 0.15 2000 33.7264 7781 0.14 2000 29.2467 7781 0.13 2000 25.0606 7781 0.24 2000 43.732 7781 0.28 16.12 1.42009 7706 First Reading 9717 9762 9717 9724 9724 9724 9724 9761.5 Last Reading 13652 13652 13607 13614 13614 13614 13614 13614 First Reading For Entire File .......... 9717 Last Reading For Entire File ........... 13652 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NLTMBER: 3 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13607.5 14136 5 RPD 13614.5 14143 5 RPM 13614.5 14143 5 RPS 13614.5 14143 5 RPX 13614.5 14143 5 FET 13614.5 14143 5 ROP 13652.5 14180 0 $ LOG HEADER DATA DATE LOGGED: 26-JAN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 14180.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 82.2 MAXIMUM ANGLE: 89.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROM2%G. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER PB 01411GRV4 PB01411GRV4 6.000 Water Based MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.80 40.0 9.5 21000 8.0 .210 .130 .190 .310 Name Service Order' Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HRS 4 1 68 28 8 95.0 156.0 95.0 95.0 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HRS Min Max Mean Nsam 13607.5 14180 13893.8 1146 0.34 354.94 73.6086 1056 19.24 378.26 56.5118 1059 1.55 2000 68.8935 1059 2.1 2000 71.5567 1059 2.24 2000 138.71 1059 2.33 2000 367.664 1059 0.54 41.93 4.48578 1059 First Reading 13607.5 13652.5 13607.5 13614.5 13614.5 13614.5 13614.5 13614.5 Last Reading 14180 14180 14136 5 14143 5 14143 5 14143 5 14143 5 14143 5 First Reading For Entire File .......... 13607.5 Last Reading For Entire File ........... 14180 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/08/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/08/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Aug 30 17:13:54 2000 Reel Header Service name ............. LISTPE Date ..................... 00/08/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/08/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 3 AK-MM-90224 MARK HANIK PHIL SMITH 16-10A 500292050601 ARCO Alaska, Sperry Sun 17-AUG-00 MWD RUN 4 AK-MM-90224 MARK HANIK PHIL SMITH 24 I0N 15E 2006 613 64.30 Inc. ~ZM SIHL 'I0-90SOE-650-0S # IdU HLIM U0I-9I ~ZM LNZSZ~dZ~ ~-I SNZI~ GMM '£ 'qO~LNOD HLdZG ~0 SSO~ OL Z~ G_AL ,I906 'GM ,I000I (P~MZ) ~ ZSUHd XLIAILSISZ~ GNU S~OLDZLZG Z~fli ~Z~ZflM ~ZOIZO ©NIZI~IL~ (~0~) SI GNIf MDOLSdIHM 'GZLNZSZ~d LOM SI (INtf Nii~ L~O bltfZ~O OMIZI~IL~ :SMhnf~Z~ ©NIELS OMI~LS OMI~LS 08'£g :~OOq~ 000'£ (MI) ZZIS (~I) ZZIS SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9703 0 14121 5 RPD 9710 0 14128 5 RPM 9710 0 14128 5 RPS 9710 0 14128 5 RPX 9710 0 14128 5 FET 9747 0 14128 5 ROP 9747 5 14165 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 9703.0 9717.0 9732.5 9746.5 9733.5 9748.0 14165.0 14180.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 3 9717.0 MWD 4 13652.5 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin MERGE BASE 13652.0 14180.0 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HRS 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HRS Min 9703 0.01 14 95 0 15 0 14 0 13 0 24 0 28 Max 14165 694.92 508.17 2000 2000 2000 2000 41.93 Mean Nsam 11934 8925 67 0588 8711 57 9997 8838 37 9371 8838 34 0976 8838 38 6714 8838 82 3243 8838 1.79017 8764 First Reading 9703 9747.5 9703 9710 9710 9710 9710 9747 Last Reading 14165 14165 14121 5 14128 5 14128 5 14128 5 14128 5 14128 5 First Reading For Entire File .......... 9703 Last Reading For Entire File ........... 14165 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: ·5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9717 0 RPX 9724 0 RPD 9724 0 RPS 9724 0 RPM 9724 0 FET 9761 5 ROP 9762 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE A_ND 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: M3~TRIX DENSITY: STOP DEPTH 13607 0 13614 0 13614 0 13614 0 13614 0 13614 0 13652 0 24-JAN-00 Insite 5.16 Memory 13652.0 39.0 94.7 TOOL NUMBER PB01411GRV4 PB01411GRV4 6·000 Water Based 8.70 38.0 9.0 24000 7.8 · 190 .105 .180 .160 78.0 147.0 76.0 72.0 HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HRS 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HRS Min 9717 0.01 14 95 0 15 0 14 0 13 0 24 0 28 Max Mean Nsam 13652 11684.5 7871 694.92 66.1488 7656 508.17 58.2143 7781 2000 33.7264 7781 2000 29.2467 7781 2000 25.0606 7781 2000 43.732 7781 16.12 1.42009 7706 First Reading 9717 9762 9717 9724 9724 9724 9724 9761.5 Last Reading 13652 13652 13607 13614 13614 13614 13614 13614 First Reading For Entire File .......... 9717 Last Reading For Entire File ........... 13652 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13607 5 14136 5 RPD 13614 5 14143 5 RPM 13614 5 14143 5 RPS 13614 5 14143 5 RPX 13614 5 14143 5 FET 13614 5 14143 5 ROP 13652 5 14180 0 $ LOG HEADER DATA DATE LOGGED: 26-JAN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWN-HOLE SOFTWARE VERSION: 5.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 14180.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 82.2 MAXIMUM ANGLE: 89.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA I~IY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS TOOL NUMBER PB01411GRV4 PB01411GRV4 6.000 MI/D TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (0HMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Water Based 8.80 40.0 9.5 21000 8.0 .210 .130 .190 .310 95.0 156.0 95.0 95.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HRS 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HRS Min Max Mean Nsam 13607.5 14180 13893.8 1146 0.34 354.94 73.6086 1056 19.24 378.26 56.5118 1059 1.55 2000 68.8935 1059 2.1 2000 71.5567 1059 2.24 2000 138.71 1059 2.33 2000 367.664 1059 0.54 41.93 4.48578 1059 First Reading 13607 5 13652 5 13607 5 13614 5 13614 5 13614 5 13614 5 13614 5 Last Reading 14180 14180 14136 5 14143 5 14143 5 14143 5 14143 5 14143 5 mlTZ sI~ ~o puz ~0~ IemTSXq~ SeOT~eS IeOTUqO@i OT~TqU@TOS SemTm~@S IeOTUqOei OT~TqUeTOS · X~e~qTq 5UTqT~M SI~ SiS ................. squemmOD NMONDINI/ ........... smeN Iee~ qxeN I0 ...... ~eq-mnN uoTqenuTqUOD NMOND{Nfl ................ mmeN IeeH SAS ................... 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