The URL can be used to link to this page

Home My WebLink About198-214MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 11, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-25A PRUDHOE BAY UNIT S-25A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/11/2025 S-25A 50-029-22077-01-00 198-214-0 W SPT 8557 1982140 2200 447 452 452 448 173 230 233 234 REQVAR P Guy Cook 5/3/2025 2 year MITIA to maximum anticipated injection pressure per AIO4F.005. Max PWI header pressure at 2200 psi. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT S-25A Inspection Date: Tubing OA Packer Depth 411 2454 2389 2373IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250503065800 BBL Pumped:6.2 BBL Returned:4.5 Wednesday, June 11, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.06.11 15:36:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-25A PRUDHOE BAY UNIT S-25A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 S-25A 50-029-22077-01-00 198-214-0 W SPT 8557 1982140 2139 575 574 570 569 136 223 225 224 REQVAR P Sully Sullivan 5/1/2023 2 year mit per AIO 4f.005 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT S-25A Inspection Date: Tubing OA Packer Depth 357 2500 2466 2454IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230501181604 BBL Pumped:5.6 BBL Returned:5 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 15:43:55 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 26, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S -25A PRUDHOE BAY UNIT S -25A Sre: Inspector Reviewed By: P.I. Supry JT)�Z— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S -25A API Well Number 50-029-22077-01-00 Inspector Name: Lou Laubenstein Permit Number: 198-214-0 Inspection Date: 5/25/2021 Insp Num: mitLOL210526080026 Rel Insp Num: Wednesday, May 26, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-25AType Inj W 'TVD 8557 Tubing! 859 859 - 858 _ 858 PTD 1982140 Type Test SPT' Test psi2139 476 IA 2400 2375 2366 BBL Pumped: 4.1 BBL Returned: 4.1 --- OA 236 351 1 352 350 - Interval REQVAR - PAF p — Notes: MIT -IA every 2 years per AA AIO 4F.005 i Wednesday, May 26, 2021 Page I of 1 MEMORANDUM TO: Jim Regg 7 e r Sa P.I. Supervisor ' FROM: Bob Noble Petroleum Inspector Well Name PRUDHOE BAY UNIT S -25A Insp Num: mitRCN190507141024 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 8, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. S -25A PRUDHOE BAY UNIT S -25A Src: Inspector Reviewed By: P.I. Supry .B2— Comm API Well Number 50-029-22077-01-00 Inspector Name: Bob Noble Permit Number: 198-214-0 Inspection Date: 5/72019 - Packer Depth Pretest _ Well E- s -25A ''Type [nj 1 W- FTVD assn - Tubing 80> PTD 9azlao Type Test SPT Test psi '-139 IA '05 - BBL Pumped: 51 ' BBL. Returned: h 8 OA 133 - Interval REQVAR P/F Notes: AA 417.005 required every iMIT to the maximum injection pressure of 2000 psi. I&.-( Initial 15 Min 30 Min 45 Min 60 Min RN' 806- � � 606 '_.100 2372 - 8362 - -� 302 301 299 Wednesday, May 8, 2019 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,May 16,2017 P.I.Supervisor �(?2', �( L Z( SUBJECT: Mechanical Integrity Tests 1I. BP EXPLORATION(ALASKA)INC. S-25A FROM: Chuck Scheve PRUDHOE BAY UNIT S-25A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-25A API Well Number 50-029-22077-01-00 Inspector Name: Chuck Scheve Permit Number: 198-214-0 Inspection Date: 5/11/2017 Insp Num: mitCS170511192506 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-25A ' Type Inj W-TVD 8557 TU nl g 865 865 , 869 869 - PTD 1982140 - Type Test SPT Test psi 2139 - IA 302 2497 - 2473, 2464_ BBL Pumped: 5.1 - BBL Returned: 4.7 - OA 126 295 - 294 - 291 Interval REQVAR 1P/F iz Notes: Tested per AIO 4F.005 %MINED Ait, 1 1201-ff Tuesday,May 16,2017 Page 1 of 1 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, October 02, 2015 12:40 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S; Bergene, Matthew;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA) Subject: OPERABLE:Injector S-25A (PTD#1982140) Administrative Approval Recieved - Place Well on Injection Attachments: S-25 aio4f-005.pdf All, BP has received approval to operate injector S-25A (PTD# 1982140)from the AOGCC. The well will now inject under Administrative Approval AIO 4F.005 for slow tubing by inner annulus pressure and is to be operated on water service only. The requirements of approval include flagging all bleeds and a two year witnessed AOGCC MIT-IA cycle. The well has been reclassified as Operable and has been added to the monthly AOGCC Injector Report. Please use caution when placing the well on injection as the annuli are fluid packed. Attached is a copy of the Administrative Approval for reference. Thank you, Whitney Pettus (Alternate:Kevin Parks) I1�� V SC ED AUG 0 4 2016 BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D& ntegr• oordinator Sent: Thursday, July 09, 2015 7:3 To: AK, OPS GC2 OSM; AK, OPS GC2 Field 0& OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead AK.,D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WEL PI SAD 5; Munk, Corey; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C-Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Weiss, Troy D; AK, D&C Wells Slickline Coordinator; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: NOT OPERABLE: Injector S-25A (PTD #1982140) Diagnostics Complete All, tgc6 - 1\21 2c009s G WELL LOG TRANSMITTAL li• DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. Ctr/5/2015 K BENDER To: AOGCC y t .'E I V E D Makana Bender ��''11!! ''ll��rr �a!! 333 W. 7th Ave AUG4 Zu i! Suite 100 Anchorage, Alaska 99501 AOGCC(907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2-1 900 Benson Blvd. Anchorage, AK 99508 gancpdca.bp.com and ProActive Diagnostic Services, Inc. SCANNED Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 18-Jun-15 S-25A BL/CD 50-029-22077-01 2) Signed : / Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Achrves\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmn docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, July 09, 2015 7:33 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Munk, Corey;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney;Weiss, Troy D; AK, D&C Wells Slickline Coordinator; Regg, James B (DOA) Subject: NOT OPERABLE:Injector S-25A (PTD #1982140) Diagnostics Complete Attachments: image001.png; image002.png All, Injector S-25A (PTD#1982140)was recently placed on injection to facilitate diagnostics for slow tubing by inner annulus communication. BP has completed all necessary evaluations. At this time, the well has been reclassified as Not Operable and added to the Quarterly Not Operable report. The well was secured with a downhole plug on June 17, 2015 during diagnostics. Plan Forward: 1. Slickline: Pull downhole plug 2. Well Integrity Engineer: Additional diagnostics as needed to evaluate for an Administrative Approval Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) %A$NED JUL 1 3 2015 BP Alaskajf -Well Integrity Coordinator GWYd WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AI;C, D&C Well Integrity Coordinator Sent: Sun e 14, 2015 3:24 PM To: AK, OPS GC2 OSM; A , 2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline flperations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East We'tts-Qpt Engr; AK, OPS WELL PAD S; Munk, Corey Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD l-Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Marley; Weiss, Troy D; AK, D&C Wells Slickline Coordinator Subject: UNDER EVALUATION: Injector S-25A (PTD #1982140) Ready • .ce on Injection All, 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, May 22, 2015 9:59 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Shrider, James; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Pettus, Whitney; Weiss, Troy D Subject: NOT OPERABLE: Injector S-25A (PTD #1982140) Tubing x Inner Annulus Communication Attachments: image003.png; image001.png;Injector S-25A (PTD#1982140) TIO and Injection Plot.docx All, Injector 5-25A (PTD#1982140) passed a MIT-IA on May 12, 2015 but continues to demonstrate slow tubing by inner annulus communication while on injection. A PPPOT-T performed on May 15, 2015 also passed. As the aforementioned diagnostics indicate two competent barriers in the wellbore,the well will be reviewed for an AA request. However, due to unseasonably large river runoff, the pad has become temporarily unavailable for permitting. At this time, the well has been reclassified as Not Operable until further diagnostics can be performed. The well has been added to the Quarterly Not Operable report and an updated TIO and injection plot has been attached for reference. Please call with any questions or concerns. Thank you, Whitney Pettus % WED MAY 2 8 2015 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GINO'ganllzdtG''I WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D&--C Wettintegrity Coordinator Sent: Saturday, May 09, 2015 9:19 AM__ To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL AK,9PS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Shrider, James; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK,-D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) (jim.regg@alaska‘gov) Subject: UNDER EVALUATION: Injector S-25A (PTD #1982140) Possible Inner Annulus communication 1 Injector S-25A(PTD# 1982140) TIO and Injection Plot May 22, 2015 it f.- , y-V Ao —0005 —Oe r..__--- w.H eme \i ......_,,=" .-E X. xi o —O. comm102 AOC 5144 V05'4 4Y.'Y owe 44e ro 0{944 Vmn VANS 64414 V IDn..45'.44 amm mean Monro Ma!mmn}675 VTn mu,60tH 644 m0N4 644 6b»mum awn mom.atom mime _Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 09, 2015 9:19 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S; Shrider,James;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector S-25A (PTD#1982140) Possible Inner Annulus communication Attachments: image001.png;Injector S-25 (PTD#1982140) 110 plot.docx All, Injector S-25A(PTD#1982140) has shown signs of anomalous inner annulus pressure trends while on MI injection.The well has been reclassified as Under Evaluation and is placed on a 28 day clock for additional diagnostics. Plan Forward: 1. DHD: Perform MIT-IA to 2,500 2. DHD: Bleed down IA and obtain a BUR 3. W: PPPOT-T 4. WIE:Additional diagnostics as needed S�N14�� IV LV( �� A copy of the TIO plot has been included for reference. Please call with any questions. Thank you, Kevin Parks 'AJteo nate Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator(a)bp.com 1 Injector S-25(PTD#1982140)TIO plot A-D - OA 0 • oof • 6.+(R15 021615 02-1315 031215 O30Yts 231615 2372 5 0330',5 (*WS 0*13,15 00015 O4?55 0512:‘,15 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,March 05,2015 P.I.Supervisor 611 3/6/%5 SUBJECT: Mechanical Integrity Tests ( BP EXPLORATION(ALASKA)INC S-25A FROM: Lou Grimaldi PRUDHOE BAY UNIT S-25A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1-64— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-25A API Well Number 50-029-22077-01-00 Inspector Name: Lou Grimaldi Permit Number: 198-214-0 Inspection Date: 2/13/2015 Insp Num: mitLG150213160505 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' S-25A ype Inj G TVD 8557 - Tubing 2503 2503 2507 2510 - 2517 7 2528 PTD1 1982140 ' I Type Test SPT Test psi] 2139 • IA 925 927 930 - 932 - 2292 - 2290 Interval '4YRTST PAF P ✓ OA 143 143 -I 144 144 • 152 152 Notes: 1st part of MIT on this well today to satisfy observance of 500 psi(or greater)differential pressure between IA and tubing.No fluid pumped during this test.I observed fluid to surface in IA when rigging up.2nd part of MIT (pressure test of casing IA and packer)on this well today to satisfy mechanical integrity to.25(or greater)gradient 3 0 Bbl's 60/40 MeoH pumped and 2 7 Bbl's returned during this test.I observed fluid to surface in IA when rigging up 1-3-o f)resg.s eis PIS (A Q&& Sc1�2r& 4 Thursday,March 05,2015 Page 1 of 1 Atiit Iai5,o2.v5(605-05- Lower 5(6OS05Lower Upper BARO Chassis Module Module Module Left Scale Right Scale Serial Number 072721 073142 073115 073142 073115 Model NV 10KPSI 10KPSI Message Store IAP TBG Userspan 1.00090 1.00000 Datatype Lower Upper Units PSI G PSI G PSI G PSI G Run Index 1 Run Start Time 13-Feb-15/09:38:31 Run Duration 1 hour 16 minutes 13 seconds Run Tag Run#2 Logging Interval 1.0 Data Points Point# Time OA psiG IA psiG Tubing psiG 1 00:00 143 927 2503 1944 00:32 144 933 2510 2703 00:45 154 2306 - 2515 3603 01:00 152 2292 2517 4503 01:15 152 2289 . 2528 • 4574 01:16 152 2289 2530 OAP S-25 MIT-IA to 2300 psi IAP&OAP AOGCC 2-13-15 IAP/Tub 160 1 ..-.. _... — 2500 150 — 2300 7,-------------------- 2100 14030 minute observation for>500 psi IA/Tubing outer ✓ — 1900 130 differential Inner — 1700 Tubing 120 — 1500 1300 110 - — 1100 100 900 Ix 00 rt, bg ,�0 Co,b00 ry 00. ^a. �0. R�• h•\. '�rl 'L6 O� OC). Off. O OP. 0 0 Elapsed Time hh:mm:ss -, A.A8226 +I'' i H 1 I 1-1 Z,.:. I .,-.!. .F: F f „. I . , I ., i tS 1 r. t-.• . i 1 • 1 1 ; ...,...• -1 '(....'. ) r 7.1. F.; :: : • -. . --- TREE= 4-1116'OW SAFETY NOTES:H2S READINGS AVERAGE 125 ppm iWELLHEAD= FMC S-25A WHEN ON MI WELL REQUIRES ASSSVWHEN ONMl !ACTUATOR= OTISI ' PORTIONS OFTI-EWB_LFLOWLINEARE 3"& OKB.ELEV= 65.75'!1 I I SUBJECT TO EROSION.GC SHOULD BE NOTIFIED OF ANY BF.ELEV= 36.15' WELL OPERATIONS THAT COLLO INCREASE TI-E FLOW KOP= 5000 OF EROSION RATES"'WILL ANGLE>700 @ 9350""' Max Angle= 92`Q 10996'I 1 2117' J• 14-112'HES X NP.ID=3.813" I Datum MD= 9241' ' Datum TVD= 8800'SS [13-3/8'CSG,68#,L-80 BTRS,D=12.415' 2674' GAS LIFT MANDRELS TE I 1 379 95�'D0/ITY MMGIDMY� RK-A 1_PORT]1/1 3/06Ii _ Minimum ID=, 2.37"@ 8923' 87W a-i/z"HES X NP,ID=3.813= I3-3/4 X 2 7/8 LNR XO I I +� �- ---- — J Z. 8827' 9-5/8'X 4-1/2_BKR S-3 PKR,ID=3.870'j I C_8851' -1 4-1/2'HES X NP,IID=3,8131 ' r 8872' 1--1.11,2"HESXN NP,D=3.7251J 103:. ^8884,J-{9-5/8'X 4-1/2"BKR R�D=3.99' 4-1/2'TBG,12 6#,L-80,TC-11,1 -r- 1 - 8891' .0152 bpf,ID=3.958' 1 8891' 1—L4-1/2'MULE SHOE,D=3.958 1 121 L.8918• J-13-3/4"BKR LNR DEPLOY SLV,D=3.00"„j TOP OF 2-7/9-LNR,D=2.37' 8923' 8923' 3-3/4'X 2-7/8'XO,D=2.37'1 i 1 r 8940l-lit-1/2”PARKER SWS NP,D3.813" ] I I i 8981 4-1/2'ORS XN PI_D=3.725" BEHIND C 1/2_TBG,12.6#,L-80,.0152 bpf,D=3.958',—C_ $874' - } •____L 8974' 4-112'WLEG, 3.9 = 56' CT LNR 19-5/13'CSG,47#,NT-80S,NSCC,D=8.681' 9140' \ , `-8980' i--[9.7.,M0 TT LOGGED 11/09/90 1!"WHPSTOCK w/RA TAG 9171'J--C 9167 " T WINDOW (S-25A) 9162'-91671T 1—LLN , pf,D=8.276 --9182' [ 7MLLOU -_ -® 26#,L-80 TC4S,.0383 b----.- _. -_. —— - PERFORATION SLI#RY REF �'�•�'�' ` LOG:BAKER MWD RE51STNfTY ON 11/11/98 '•••••• A NGLE AT TOP PERF:86'@ 10500' '••••**•••••.: Note:Refer to Ftoducbon DB for historical perf data i•••••••••••• ` KIM((EP) 1148r J SEE SPF _M_B21/AL ^OpNSgz SHOT SQZ !•,.•!•!•!•!A 2' 6 10500-10530 O a-a02/03/15 .__. 2" 6 10990-11020 0 02/03/15 ir 2' 6 11020-11050 0 02/02/15 la ,i 2' 4 11364- 11434 0 11/24/98 '114110f 2-7/8•LNR,6.16#,L-80 SR, — 11554'J __._.___ .___ .. __ ._ _ . -_ .0058 bpf,D---2.441 DATE REV BY- CO S DATE REV BY e - COMMENTS F LX)HOE BAY UNT 08/17/90 If ORIGINAL COMPLETION 01/19/12 T t4'JMD ADDED H2S SAFETY NOTE WELL: S-25A 11/24/98 - CTD SIDETRACK 06/24/14 AD UR ATB)WBS PER TALLES PERMIT No:'1982140 11120106 NM IMO 01/03/15 BLS/PJC ADFIERFS(02/02-02/03/15) AR No: 50-029-22077-01 12/13/06 KWA/PJC DRLG DRAFT CORRECTIONS SED 35,T12N,R12E,1633'FN. &1120'FWL 12117/06 DAV/PJC GLV C/O(12113/06) — A o- _ 02/15/11 MB/JMD ADDEDSSSV SAFETY NOTE BP Exploration(Alaska) RECEIVED STATE OF ALASKA A. AKA OIL AND GAS CONSERVATION COMA ,ON MAR 0 3 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ElRepair Well U Plug Perforations ❑ Perforate❑ Other ❑ AOGCC Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ WaiverE lime Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other E Re-enter Suspended WE 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory 198-214-0 3 Address P O Box 196612 Stratigraphic ❑ Service1 6.API Number Anchorage,AK 99519-6612 50-029-22077-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028257 PBU S-25A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 11691 feet Plugs measured 11485 feet true vertical 9006 48 feet Junk measured None feet Effective Depth measured 11485 feet Packer measured See Attachment feet true vertical 9017 83 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 32-112 32-112 0 0 Surface 2642.19 13-3/8"68#L-80 31 5-2673 69 31 5-2673 58 5020 2260 Intermediate 9111 1 9-5/8"47#NT8OS 29 6-9140 7 29 6-8780 37 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10500-10530 feet 10990-11020 feet 11020-11050 feet 11364-11434 feet True Vertical depth 9014.43-9016 14 feet 9019 27-9018 15 feet 9018 15-9017.29 feet 9017 89-9017 5 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"MCX I-SSV 2119 2118 92 SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) 7 �� ). .h x u Treatment descnptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 928 0 480 3092 Subsequent to operation 0 6271 0 900 2571 14.Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 2 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG O GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C O.Exempt N/A Contact Garry Catron Email Garrv.Catronn.BP.Com Printed Name Garry Catron Title PDC PE Signature 40444 Phone 564-4424 Date 3/3/2015 �1 v rt-- 37/i // s RBDMS 3\k MAR - 5 2015 at 7A 1K Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028257 SW Name Type MD TVD Depscription • S-25A SSSV 2119 2118.92 4-1/2" MCX I-SSV S-25A PACKER 8828.58 8508.19 4-1/2" Baker S-3 Perm Packer S-25A PACKER 8884.79 8557.98 4-1/2" Baker SB3 Packer Q, 000) 000 M N O "Ch to N r• N- V TO; 0 cDS cD0 0 0o N O m CD Ln 00 CO • N to CO N CO LC) O) CO Ln IC) - O 00 LC) MLU CD - O O) CO M N- O CD CO CD CO CO CA N CO CO r O 00 N co Li? LC) O) co O 0) CO N CO °M N 000 (1) NA— NqctM � Er • CD h` O) N CD CO O) O) O) N 00 CO CO E N cD u) CD N co M M CO M CO N CO C ▪ O � J ▪ Qo aaoo coo co OOo CO H coCD J J J J i C d -o CD Z J CD co CO co C 4tCD N N N� U) V „cr CD r,- V N M A— A— O N ' 44 C)O A O CO v COD O) CD 0 O) N CO CO 00 CO W C C i- Q W W U V40 p c Du_ Z Z Z W W W m m Z Z OU Z J J Cn H I- O O Q = O * -c O O .E co 0) C (J") V O (0 01N _ O c' _o _ _C cl Q O O I p0 Q 2 ( O Z O2 QNB I0a m .- (6 � a Q' a 2 a) J O J_ O -0 Q _J U a)� a) v— a-' w m w in C o 0) C M C C V) V) 4- J O - - 0) O 7 '( O Cl) a) O cn co (n N ch 0- C Q Q N w Q m a) L _0 D Oc p f a) C W w 7 ) — Ln a & O . jZ N o E _ N Oo , O N > CO 0.O 1— IQ i (�co C CO O u IQ F- co L' E in o � O c � cflO E c ) `° O I� CO • rn� rn 4 H J > (n = to • !z� � < O � O OO co (-13 N 0-O in o fn Lf7 E O C I I Cl) 0)O— M 2 C I-- (V) * CO Q N �� O QI— O a.0 M C C O m O 0 > ,- cn (d N O) (0 Q-— O ✓r) o O a) u O O C < (I) X C Q O � oa � 3 � � - oO ' .E 3 C > c 0QJ X10 0)) O ~ O C J O .0 L[) J O II O ra D II * * a) Lo020 O 30 Z OC- c N -a Co a) 3 (o ,- 'Cr)N di O o c 0o oZ -- NT. 0-0 N ° c Lin ° Y = U o Lin ° _ D fl ~ 2 p ~ a) 2 O c : .- c NN c cn * m o D * po 2 ,• w c * O J a) o a) o _ � NO o0c) ' O _ * _- � * t I � F- U -0 a) Za — -0 0 J CCS QU & cn Ov � Ln 0 < n "' (n rn - u) CL ca rn c >> t Q _ > v d O N N Q. XO N NOCn a) � O a) NOc, ( 8 Ln -0 � � O > � 02 ©� cc II = `0) co = 5j it) c (I I= 0)C_, O .. o D IC) 1 0 > N > O O > a) N ' > a) (B C d co E N J •V' * Q 0) Z >` H 0_ I- N 2 N I— in " a . N a— LL Li" N LL I— 0 U U Y 30 UYc\I ° U) co * Ea E N HO ¢ O 0 H a e H � o 0 rod c F- � o .c_ OLn * o _ aEv c oow4w U a o U -(13 Q.1. , m U a N a) J 05o " * -0 1.0 ,7 O � -0 O Z I`• 7 �' Co- C -� (6 0 L) 1.0 7 O � N -' a) N * C O N O o Z X Z _ _ E 5C.-) a) a N '5 o „ 4* o QAC/) (32o c = OZNZ x— LL ,- L- 2 � N � 0 N LL w Q C Ln E .— W Q N (� '— C 3 -c c o c Q _ c O O 3 6 1 3 ai S N o U) 3 ai m 0)c U o a- ° w > o o U U k v U co >* .3 c QO >,o co 1 .c -- a) 0 Q * D co 0 m _o 0 co Lu w oO a) - Ea c) a) -• oo � o N = O o2 O 0 2 O0O < 2 o. - 000co tn .E * * 0 0.2LL * * w * w * - Ln to Ln Ln Ln in ► O O O O O O N N N N N N ",... c- '1”CO V Ln Ln , N N N N N N \ E o 2 - - / / % = m 2 / < mj O = 0 0 ' ) \ § / ( -® / & 0--0 \ o ƒ ® 0 2 / 2 % 0 1 ¥ 5 q \ _1 o O g \ o CO \ O 2 2 2\ § . / / / $ / \ \ � k -c / • < < IL 0) G • / •E rm % o / w _J - 0) E 2 \ \.0 / / Eq > 1I(13 / / / 2 � / a 3 u E .a 0 u) £ / / / •\ 2 •> _@ r 0 . 2 > C ¥ / 2 R 6 § / ® \ 7 / % k 0 7 m / 2 ƒ / CI \ 2 o m - / b 2 = co \ L A § \/ \ .g / I = » m @ 0 I % a \ o I r 0 $ 2 < Q > ,- R O Cf) ° '2)(13 - \\ 9 / \ / \ o 00 EE II _ � � 3ag / " / ff / 7 / � a = ƒ \ b \ / 0 CO / E ± 2 = - % $ e E < # / 12 \ A @ 0 t »_ \ § / \ } E / \ / Q " ± 0 _j) CN ' / \ is % / / / $ � � < 0 -00 \ § t o G p\ 2 R x ƒ .$ \ / a # » k \ 0 ,- gi ® _9- 0 « & m E / ) b b % \ c � / \ ƒ / a _ \ 7 y 7 CD 0 co / \ / / / e E . 0 5 \ E 2 1i > 2 G r k o - 0 •6 o ° ..- 16 0 6 \ CNI oE \ \ / \ E d' : \ _\ $ \ / / \ \ ƒ .■ R I e o f 6 = e ® _ 2 \ 2 o \ \ / - \ / cN2 / / / pus - \/ .E > a - > mo LLLk2 � O \ = 6 & _II '� E� / \ �/ / II R L ± O I E R = k CO 0) ± ¥ o a a © > / / \ \ \ f. E \ \ \ / � % 6 / \ $ 7 _ \ / / E ± ƒ 2 U u_ 0 I I e / E E ^ \ > 3@3411 = "I11oe � odII2011 (X \ w ƒ / * * \ / 2 �N \ \ \ \ 2 ( \ 2 > i 2 CO W ± t i i 2 ± & .§ / t E e m - .g co R m r e r o in / \ \ \/ / / CO # e_ & m \ \ \ TREE= , 4-1/16"CIW S 2 5 A SAF TOTES:F¢S READINGS AVERAGE 125 ppm WE-LHFAD= FMC WHB...N MI***WELL REQUIRES A SSSV WHEN ON MI ACTUATOR= OTIS ***"PORTIONS OF THE WELL FLOWLINE ARE 3"& OKB. B-EV= 65.75' I I SUBJECT TO EROSION.GC SHOULD BE NOTIFIB)OF ANY BF.B EV= 36.15' WELL OPERATIONS THAT COULD INCREASE THE FLOW KOP= 5000 OF EROSION RATES***WELL ANGLE>700 @ 9350' Max Angle= 920 @ 10996' , Datum MD= 9241' 2117' —14-112'HES X NP,ID=3.813" Datum TVD= 8800'SS 13-3/8"CSG,68#,L-80 BTRS,D=12.415" 2674' GAS LFT MANDRELS LI ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3795 3795 0 MMG DMY RK 0 12/13/06 Minimum ID = 2.37"@ 8923' (3-3/4" X 2-7/8" LNR XO 8764' -{a-1n"HES X NP,D=3.813" 8827' —19-5/8"X 4-112"BKR S-3 PKR,D=3.870" I I 8851' —14-1/2"HES X MP,113=3.813" ' ' • 8872' H4-1/2"HES XN NP,0=3.725" 8884' —I9-5/8'X 41/2"BKR PKR,D=3.99" 41/2"TBG 12.6# L-80 TC-11 H 8891' .0152 bpi,ID=3.958" 8891' }—4-1/2"MULE SHOE,D=3.958 TOP OF 7"LINER —{ 8911' s 8916 3-3/4"BKR LNR DEPLOY SLV,13=3.00" } TOP OF 2-7/8"LNR,D=2.37" —1 8923' 8923' —13-3/4"X 2-7/8"XO,D=2.37" I I 8940' I--4-1/2'PARKER SWS NP,D=3.813" ' ' • 1 8961' 41/2"OTIS XN NP,D=3.725" , BEHIND 4-1/2"TBG,12.64,L-80,.0152 bpi,D=3.958" --f 8974' ------ CT LNR ' N 8974' H4-1/2"WLEG,D=3.958' 19-5/8"CSG,47#,NT-80S,NSCC,D=8.681" H 9140' J\ 8980' H ELMD TT LOGGED 11/09/90 7"WHPSTOCK w/RA TAG @ 9171' —I 9162' 7"MLLOUT WINDOW (S-25A) 9162'-9167' 7"LNR,26#,L-80 TC4S,.0383 bpi,D=6.276" ^4I62' a PERFORATION SUMMARY ---•- REF LOG:BAKER MWD F261STNffY ON 11/11/98 •••••••••••• ANGLE AT TOP FEFF:86"@ 10500' �•�•�•�•�•�• ••••••i•i•i4 ` FI3TD(CEP) —I 11487' Note:Refer to Production DB for historical perf data �•�•�•�•�•�• SIZE SPF IJT RVAL Opn/Sqz SHOT SQZ •�•i•�•�•�•4 2" 6 10500-10530 0 02/03/15 2" 6 10990-11020 0 02/03/15 �� 2" 6 11020- 11050 0 02/02/15 Ar o% 2" 4 11364- 11434 0 11/24/98 4.��f 2-7/8"LNR,6.16#,L-80 STL, —I 11554' .0058 bpf,D=2.441" DATE REV BY COMMENTS DATE REV BY COM ENTS PR DHOE BAY UNIT 08/17/90 I-F ORIGINAL COMPLETION 01/19/12 TMNYJMDADDED H2S SAFETY NOTE WELL: S-25A 11/24/98 CTD SIDETRACK 06/24/14 JMD UPDATED WBS PER TALLES PERMIT No:9982140 11/20/06 N7P.5 MVO 01/03/15 BLS/PJC ADPERFS(02/02-02/03/15) API No: 50-029-22077-01 12/13/06 KWA/PJC DRLG DRAFT CORRECTIONS SEC 35,T12N,R12E,1633'FNL&1120'FVVL 12/17/06 DAV/PJC GLV C/O(12/13/06) 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, February 23, 2011 Jim Regg ;ltt P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -25A FROM: John Crisp PRUDHOE BAY UNIT S -25A Petroleum Inspector Src: Inspector Reviewed 13y: P.I. Suprv- NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT S - 25A API Well Number: 50 - 029 - 22077 - 01 - 00 Inspector Name: John Crisp Insp Num: mitJCr110221071055 Permit Number: 198 - 214 - Inspection Date: 2/20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-25A Type Inj. W ✓ TVD I 8507 IA 110 2500 2470 2460 - P.T.D! 1982140 TypeTest S Test psi 2126 - OA 140 280 280 290 - Interval - p/F P - Tubing 1300 1320 1320 1320 Notes: 4.8 bbls pumped for test. � Y APR 1 3 2.011 Wednesday, February 23, 2011 Page 1 of 1 • ~ ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 " Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ ~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, y~~'tyils~~~Iis~ yFLl~ ~ aC.~ P ~~+v~i Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report af Sundry Operations (10-404) Spad ~ nnm fil25/2009 Wetl Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Conosion inhibitor Corrosion inhibitod sealant date ft bbls it na al S-Oi8 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-O6 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26J2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27I2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 7.7 5/27/2009 S-12A 1851930 0.25 NA 025 NA 1.7 6/1/2009 5-73 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/7J2009 S-79 1861160 0.75 NA 0.75 NA 22 5/19I2009 S-20A 2010450 025 NA 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 1901270 025 fYA 025 NA 1.7 5/25/2009 S-2aB 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1962140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 Nq 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960720 0 NA 0 NA 0.85 5/27/2009 S3o 1900660 0.5 NA 0.5 Nq 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .SSin 5/31/2009 5-36 7921160 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 125 NA 125 NA 17.9 5/27/2009 S-38 1921270 0.25 NA 025 NA 702 5/27/2009 5-47 1960240 1.5 NA 7.5 NA 11.t. 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001150 125 NA 125 NA 11.9 5/29/2009 5-102Lt 2031560 125 NA 125 NA 11.7 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 1.75 NA 7.75 NA 15.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20I2009 5-106 2010120 1625 NA 7625 NA 174.3 6/2/2009 5-107 2071130 225 NA 225 NA 28.9 5/18/2009 S-ioe 2017000 3.5 NA 3.5 NA a0 5/30/2009 S-709 2022450 2 NA 2 NA 27.3 5/30/2009 5-110 2011290 11.75 NA 71.75 NA 98.6 5/30/2009 S-17~ 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/3W2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-1t4A 2021980 1.25 NA 125 NA 702 5/30/2009 5-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-716 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28I2009 S-119 2041620 7 NA 1 NA 5.2 5/30/2009 S-720 2031980 5.5 NA 5.5 NA 67.2 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 5-122 2050810 3 NA 3 NA 27.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA 71.9 5/26I2009 5-125 2070830 2.25 NA 225 NA 20.4 5/28l2009 S-t26 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 1.25 NA 7 25 NA 14.5 5/28/2009 5-207 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 73.6 5/29/2009 5-2~5 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29l2009 S-21~ 2070950 025 NA 0.25 NA . 77 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-aot 2060780 16 NA 16 NA 99.5 6/2/2009 S-50a 0 NA 0 NA 0.85 5/28/2009 S-25A ? • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, June 03, 2009 11:04 AM To: 'Prebte, Gary B (SAIC)' Subject: RE: S-25A ? l ~~ Page 1 of 1 Gary, A 403 is not required for a HPBD. Tom Maunder, PE AOGCC From: Prebte, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Wednesday, June 03, 2009 10:39 AM To: Maunder, Thomas E (DOA) Subject: S-25A ? Tom, Is a 10-403 is required for a pert breakdown by water on an injector well? Thanks Gary Prebte Petrotechnical Data Team Coordinator Science Applications International Corporation Office 907.564.4944 Mobile 907.350.6879 preblegb~bp.com 6/4/2009 MEMORANDUM . TO: Jim ReggKeðq ~')..3/ò 7 P.I. Supervisor II FROM: Lou Grimaldi Petroleum Inspector State of Alaska . tq~Jcf-~lf Reviewed By: P.I. Suprßt;P- Comm Well Name: PRUDHOE BAY UNIT S-25A Insp Num: mitLG0702 1 7072748 ReI Insp Num Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 21, 2007 SUBJECT: Meehanicallntegrity Tests BP EXPLORATION (ALASKA) INC S-2SA PRUDHOE BAY UNIT S-25A Src: Inspector NON-CONFIDENTIAL Permit Number: 198-214-0 Inspector Name: Lou Grimaldi Inspection Date: 2/16/2007 API Well Number 50-029-22077-01-00 Packer -- Well i $-25A ¡Type Inj. i W TVD -- P.T. 1982140 !TypeTest! SPT Test psi Interval INITAL P/F P Notes 25 barrels pumped, 2 barrels returned upon bleed down_ Post workover test 2390 15 Min. 30 Min. 45 Min. 60 Min. --,--~-- Depth 8600 Pretest Initial : IA 870 2400 I . , -I--"-'---~-~---"-- I OA 390 540 540 2400 2390: i ---¡------~r---·-~- 540 i I ---+-------+------- ---- 2000 Wednesday, February 21, 2007 ..-.'------------ Tubing 2000 2000 2000 f¡~~NED FES 2 '1 2007 Page 1 of 1 .. . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COMMWION REPORT OF SUNDRY WELL OPERATIONS D D D Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic ~? 01 ;,.:¡p.I!)., 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: fon P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Exploratory Service P" / 198-2140 / 6. API Number: / 50-029-22077-01-00 3. Address: 9. Well Name and Number: 65.75 KB S-25A / ADLO-028257 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Pool 8. Property Designation: Total Depth measured true vertical 11691 9006.48 feet feet Plugs (measured) Junk (measured) 11487 None Effective Depth measured 11474 feet true vertical 9018 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20"x30" Surface - 110' Surface - 110' ,",,'-'-;'-"---- Surface 2674' 13-3/8" 68# NT-80 Surface - 2674' Surface - 2674' 4930 2270 Intermediate 9141' 9-5/8" 47# NT-80 Surface - 9141' Surface - 8781' 6870 4760 Liner 253' 7" 26# L-80 8912' - 9165' 8582' - 8801' 7240 5410 Liner 2638' 2-7/8" 6.16# L-80 8916' - 11554' 8586' - 9016' 13450 13890 Perforation depth: Measured depth: 11364 - 11434 True Vertical depth: 9017.89 - 9017.5 - Sí'~EÐ fEB 2 1 2007 - Packers and SSSV (type and measured depth) 4-1/2" 12.6# L-80 4-1/2" 12.6# L-80 9-5/8"X4-1/2" Baker S-3 9-5/8"X4-1/2" Baker Packer o o Surface - 8891' 8884' - 8973' 8827' 8885' o o Tubing: (size, grade, and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8Ft Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 9 100 o ~ 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG P" Tubing pressure 1185 2025 13. Service P" x WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: r3Dt"J- CLf8 Contact Gary Preble Title Data Engineer Phone 564-4944 Date 2/15/2007 Form 10-404 Revised 04/2006 ORll~ ['~jj\ 'A-?- [J , Submit Original Only ';, . . S-25A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8, FCO/Acid; Road unit from shop. MIRU CTU #8. Cont' on WSR 2/0 CTU #8, FCO/Acid; Cont' from WSR 2/04/07... Continue RU CTU #8. RIH with 2.0" JSN. Sat down at 10506' ctmd. PU clean. Try jetting w/2% XS KCL Ultimately work down to 10595' ctmd but encounter over pulls and junk following us. Pump flo pro sweep and chase OOH. MU WFRD 1-11/16" PDM w/2.25" OD 3 blade junk mill and RIH. Displace 60/40 from coil. Stall motor at 10,356' ctmd. Working on junk. Continue milling and working junk downhole to 11460' ctmd. Cont' on WSR 2/06/07 ... #8, FCO/Acid; Cont' from 2/05/07... Clean out with motor 2.25" mill to 11460' ctmd. Sweep hole with FloPro. POOH. Found metal marks on face of mill. Tools had a coating of Schmoo. RIH with 2.0" JSN assy. Coil checks not holding, POOH. MU new BHA w/2.0" OD JSN and RIH to 11,440' ctmd. PUH and make up/dn pass with KCL at 1.1 BPM @ 2115 psi WHP. Once acid hit, saw slight back, then increase in WHP and final break back with increased rate. Injectivityat end of acid 1.2 BPM at 2055 psi. Final injectivity index was 0.57 BPD/PSI. FP well down backside w/60/40 meth while POOH. Perform short injectivity test down tubing 720 BPD @ 1648 psi, 1008 BPD @ 2749 psi, 1152 BPD @ 2920 psi. Well left shut-in. Contacted Pad Opr and PCC with well status. *** JOB COMPLETE *** FLUIDS PUMPED BBLS 227 2% XS KCL 171 60/40 METHANOL 10 USED FLOPRO 21 12% HCL ACID 429 TOTAL . . SARAH PALIN, GOVERNOR AII.4.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279·1433 FAX (907) 276·7542 Don Brown P.E. BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-25A Sundry Number: 307-048 Ô"'\.\" \~~' Dear Mr. Brown: SCANNED FEB 12 2007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of February, 2007 Encl. 1. Type of Request: 3. Address: (jIf 2-~¡' 'D 1 ~ . STATE OF ALASKA .-S.o~_ AL AOILANDGASCONSERVATIONCOMMI N j"~ECEIVED APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Suspend U Repair well D Pull Tubing D Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Developm ent 0 Stratigraphic 0 Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 11. Total Depth MD (It): 11691 j Casing Conductor Surface Intermediate Liner Liner Perforation Depth MD (It): 11364-11434 Packers and SSSV Type: No D 10. KB Elevation (ft): 11. FieldlPools(s): 65.75 KB J Prudohe Bay Field / Prudhoe Bay Pool / PRESENT WELL CONDITION SUMMARY I Effective Depth MD (It): Effective Depth TVD (It): IPlugs (measured): I 11474 9018 I 11487 Size MD TVD Burst ADLO-028257 ¡ rTotal Depth TVD (It): 9006.48 Length 110' 20"x30" 2674' 13-3/8" 68# NT-80 9141' 9-5/8" 47# NT-80 253' 7" 26# L-80 2638' 2-7/8" 6.16# L-80 Perforation Depth TVD (It): 9017.89 - 9017.5 - - o 2 2007 Perforate I I, ,,'. yja)'¡ter ~ Other U L."""\;s"ka 011 & baS r;:~ns. Commls~,L, Stimulate 0 time Exten~ion ,~ .B.nc~ age Re-enter Suspended WelT _ 5. Permit to Drill Number: 198-2140/ Exploratory 0 Service ø 6. API Number: I 50-029-22077-01-00 / 8. Well Name and Number:! PBU S-25A Junk (measured): None Collapse Surface 110' Surface 110' Surface 2674' Surface 2674' 4930 2270 Surface 9141' Surface 8781' 6870 4760 8912' 9165' 8582' 8801' 7240 5410 8916' 11554' 8586' 9016' 13450 13890 Tubing Size: 4-1/2" 12.6# 4-1/2" 12.6# Tubing Grade: L-80 L-80 Tubing MD (It): Surface - 8891' 8884' - 8973' - - Packers and SSSV MD (It): 8827' 8885' o 0 o 0 13. Well Class alter proposed work: ' Exploratory 0 Developm ent 0 12. Attachments: DescriDtive Sum mary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 9-5/8" x 4-1/2" Baker S-3 9-5/8" x 4-1/2" Baker Packer Commencing Operations: 16. Verbal Approval: Commission Representative: 2/15/2007 II î ~ate:~1 \-0 ~ Service ø 15. Well Status alter proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG ø GINJ 0 WINJ 0 WDSPL 0 Prepared by I.:Ocuy t'ltmle 564-4944 Conditions of approval: Notify Commission so that a representative may witness 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Don Brown Title P.E. Signature Oo-r> é1~ Phone 564-4323 COMMISSION USE ONLY Plug Integrity D BOP Test S- Mechanical Integrity Test D Other: \.I 0 C'2 ,00 Q">\' ~\"'\ ""-'\..\,)""" "JO\> ~H::'''"?\- S"_"'" F"~ R',"""", 4G~' M App~""by (ltYf¡~~:~IO"y ~ Form 10-403 Revised 06/2006 Contact Don Brown Date 2/1/2007 SUndry Number: 307- 04-8 Location Clearance D s~BDMS 8Ft 1 2 2007 APPROVED BY THE COMMISSION Date: 't rg/ () 1 ORIGINAL Submit in Duplicate To: . . Jerry Bixby/Clark Olsen Well Ops TL Date: January 19, 2007 From: Don Brown S-Pad Engineer Subject: Cost Code: S-25A D & T; Acid Stimulation PBSPDWL25-C lOR: 200 Please run drift and tag followed by an acid stimulation on injector S-25A. 1. S Drift and tag to TO, no recent TO tag depth 2. C FCO (if necessary), pump acid. Test separator not required. SI after 12/2006 RWO, well will not inject 92 degrees @ 10996' 70° @ 9350' and goes horizontal @ 9650' 2.37" @ 8923' - 2-7/8" liner top 12/13/06, drift to deviation @ 9388' SLM, no recent tag 12/13/06; pull ball and rod, set dummy valve in station #1 Produced water injector. Beware of the potential for H2S in any returns 11364' to 11434' MD ~-'c)':) ~-~5' ~ Historv: This well was originally drilled in 1995 and then sidetracked in 1998. The well injected both PW and MI from 12/98 to 6/00. Typical injection rates initially ranged from 2000 to 4000 bwpd tapering off to -1500 to 2000 bwpd before being shut-in. Wellhead pressures ranged from -700 to 1200 psi. The well was shut-in in 2000 due to a leak in the tubing. A patch was attempted without success. A RWO was completed November, 2006 for a tubing swap. On 12/25/06, the well was POI without success at WHP's of 1185 psi and 1826 psi. An MIT-T to 4000 psi was achieved on 11/17/06 after completing the RWO. Well Status: Max Deviation: Safety Note: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S value: Perf Depths: Objective: To determine if perforations are covered and pump acid to re-establish injection. Well has not taken injection since recent RWO to replace tubing. Recent Events: 11/17/06: MIT-T and MIT-IA passed to 4000 psi 11/18/06: RWO completed for a tubing change out with stacker packer completion 12/13/06: Rand DGLV in station #1 12/02/06: MITIA passed to 1500 psi 12/25/06: Attempted injection at WHP of 1185 psi and 1826 psi, no rate . . Procedure: 1. Drift and tag well to TD to ensure that no obstruction exists in the wellbore nor any fill is across the perforations. 2. RU CTU 3. FCO (pending 0 & T). 4. Jet the following across the perfs located at 11364' to 11434' MD: A. 10 bbls of 2% KCI B. 20 bbls of 12% HCL C. 20 bbls of 2% KGI ** Do not circulate acid to surface to prevent H2S release. 5. Begin injection into the formation until at least a 2.1 bpm rate is achieved. Do not inject above 4000 psi WHP. 6. POI @ 3000 bwpd. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. If you have any questions or concerns regarding this program, please contact Don Brown at 564- 4323, at 745-8386 (h), 351-7108 (c). Thank you. . . s 5A $AFEIY tID'Il¡)S; IroRTICNH'FTItC'M:!.L RC4\t.KARE :¡"&$JJIjJir:TTOmœOO, G1':;$WJ!.UmC!II0WRíOF Aflf W€.L CÆR¡\ ~ l1"A T COILD ~SE 'TU€ fi!.J:J# OF~ R!\ TCR W!l.L [Xcæ::;s 7(1' @Mm' & oom~AL@91'JEl¡'. 14'112"l'EìG,12611J>fíi],,0152bþf, [¡",lBaa" H B973' th&\1> {;"93,4i7ít, NT<YJS, mcc, D dß81' H 9140' 2117' 4-112" Hill XNP,ID- :.t813" 0-12415" 9-s,'a'X.MJ2"2KRj};;¡?K1t ilh<3.£I70" :8S51' 4'H2' ,H£S XN:IPJD'" JU1i13\" æ72" 4-112" hill DUll", ()w 'l,nS" ·æs.4' H9-SIð" K4dl2" .R~ 11)", ;399" I H4-112' M1.L€SI«)E, -0 "',3JW8 I "KE" or 2,,?1f5' LN!\ -0 "'2 31" 4'112" UN::; TAIL WIL€G Ha.mTTLOO3!ÐHÆi9Æ!i) I TŒ'OFWHPSTCCX IRA MA~CRH "71' I 7" MILLCUI' WKJo.v {S<25A} 91&2'· 91!!7' prnf<C<R¡\Ta¡ Si.M\iARY REF LOO; BAK rn Ml'KJ HŒ STW ITY a¡ 1 íl11l9a AWL LA T TC4'pmp !lI @ 113M' I 1" LNR, 2i!i1!, L·,OO, 01\13 ~, 11)", 6,27a' H 1Iß4S' ~, "" 2,]m'L!IIR:. a,1ß#, LAW, ZTI., .QOO8~j,()"'2A4i1' H t1~ ¡:FlœtŒBAY LN!r \'IIlli.; $>.251\ Œ~!r!lb;1!j98214(¡ APiN.:J; M·l!2~2XJì7~1 sœ35, Tl21; RI2E, lß33'SN. & 4il&1l'Wi!:L BP &p lMatioo ¡A1B~ æ} Re: S-25A . . Don, I have looked at your procedure and you have "verbal approval" to proceed. Please submit the sundry paperwork on Monday. Call or message with any questions. Tom Maunder, PE AOGCC Brown, Don L. wrote, On 2/2/2007 4:36 PM: 1 of 1 2/5/20074:45 PM " 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver 1.1.. E:CE/VEO;' ()If' D I:'C ' ... .1 2 2006 Si(Ei Ú;/ & G 4nchofllllA·. . ORe-Enter Suspenaef.MlVell o Other 110' 2674' 9141' 253' 2638' o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 65.75' ADL 028257 11. Present well condition summary Total depth: measured 11691 9006 11487 9018 _ STATE OF ALASKA . AlfWA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS (ssian 99519-6612 o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: o Development 0 Exploratory 198-214 o Stratigraphic 181 Service 6. API Number: 50-029-22077-01-00 9. Well Name and Number: PBU S-25A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 11487 feet Junk (measured) None feet Size MD TVD Burst 20" x 30" 110' 110' 13-3/8" 2674' 2674' 4930 9-5/8" 9141' 8781' 6870 7" 8912' - 9165' 8582' - 8801' 7240 2-7/8" 8916' - 11554' 8586' - 9016' 13450 ""Çbj\J~D >i;;;" "tii..,~· Collapse 2270 4760 5410 13890 1. Operations Performed: o Abandon 8. Property Designation: Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 11364' - 11434' 9018' - 9018' 4-1/2", 12.6# L-80 8891' & Tubing Size (size, grade, and measured depth): 9-5/8" x 4-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker packer 8827' 8885' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Tubing cut and pulled at 8884'. Run new tubing to 8891'. 13. Oil-Bbl Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 0 Oil 0 Gas 181 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Ken Allen, 564-4366 306-326 Printed Name Terrie Hubble Title Technical Assistant Date ~ ;zJ, Terrie Hubble, 564-4628 Submit Original Only Prepared By Name/Number: Signature Form 10-404 Revised 04/2006 ORIGINAL Phone 564-4628 R-BDMS BFt DEC 1 4 2006 , TREE = 4-1/16" CrN . SAF~"ES: PORTIONS OF THE WELL FLOWLINE ARE 3" WELLHEAD - FMC S-25A & SUBJ TO EROSION, GC SHOULD BE NOTIFIED OF ANY ACTUATOR = OTIS WELL OÆRA TIONS THAT COULD INCREASE THE FLOW OF KB. ELEV = 65,75' PJC EROSION RATES. WELL EXCEEDS 70° @ 9350' & GOES BF. ELEV = 36.15' DRAFT HORIZONTAL @ 9650'. TOOLS LOST ON 06/02/00, KOP= 5000' Max Angle = 92 @ 10996' I I 2117' H4-1/2" HES X NIP, ID - 3.813" I Datum MD = 9253' DatumTVD= 8800'SS 113-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" I 2674' µ ~ GAS LIFT MANDRELS U 1 ST I MD I TVDI DEVITYÆI VLVI LATCH 1 PORT DATE I 1 1 13795137951 0 I MMG 1 OCR 1 RKP 1 - 111/17/061 Minimum ID = 2.37"@ 8923' 2-7/8" LNR TOP I I 8764' H4-1/2"HESXNIP,ID-3.813"I 8: 2S. 8827' -17-518" X 4-1/2" BKR S-3 PKR, ID = 3.870" I I I 8851' H4-1/2"HESXNIP,ID-3.813" I I 8872' H4-1/2" HES XN NIP, ID - 3.725" I 14-1/2" TBG, 12.6#, L-80, TC-11, 8891' ~ ,0152 bpf, ID = 3.958" ~ W 8884' H 9-5/8" X 4-1/2" BKR PKR, ID - 3,99" I ~ 1 TOP OF 7" LINER I 8911' I- I II 8891' H4-1/2" MULE SHOE, ID= 3.958 I ì 8916' -13-3/4" BKR LNR DEPLOY SL V, ID - 3,00" I I TOP OF 2-718" LNR, ID = 2.37" I 8923' I 8923' -1 3-3!4" x 2-7/8" XO, ID - 2,37" I 8940' -14-1/2" PARKER SWS NIP, ID - 3.813" I 8961' H4-1/2" OTIS XN NIP, ID - 3,725" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3,958" 8973' L -14-1/2" TUBING TAIL WLEG I 8974' 19-5/8" CSG, 47#, NT-80S, NSCC, ID = 8,681" 9140' ~ I 8980' -J ELMDTT LOGGED 11/09/90 I .. I TOP OF WHIPSTOCK 9162' " I RA MARKER 9171' ~ I 7" MILLOUTWINDOW (S-25A) 9162' - 9167' I ÆRFORA TION SUMMARY ~ REF LOG: BAKER MWD RESISTIVITY ON 11/11/98 /lPBTD(CIBP) H I ANGLEATTOPÆRF: 90@ 11364' 11487' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE ~ 2 4 11364 - 11434 0 11/24/98 ~ ~ r I 7" LNR, 26#, L-80, ,0383 bpf, ID = 6.276" I 9648' r 12-7IS" LNR.6.16#, L-OO, STL, .0058 bpI, ID"2~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/17/90 HF ORIGINAL COM PLETION WELL: S-25A 11/24/98 CTD SIDETRACK PERMIT No: "1982140 11/20/06 N7ES RWO API No: 50-029-22077-01 11/22/06 ?I PJC DRLG DRAFT CORRECTIONS SEC 35, T12N, R12E, 1633' SNL & 4158' WEL BP Exploration (Alaska) Digital Wellfile Well Events for SurfaceWell - s.t Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> S -> S-25 Date Range: 08/Sep/2006 to 11/Nov/2006 Data source(s): DIMS, AWGRs . Page 1 of 1 Events Source Well Date DIMS 5-25 11/11/2006 AWGRS s-25A 11/11/2006 DIMs S-25 11/10/2006 AWGRS s-25A 11/07/2006 AWGRS S-25A 11/06/2006 AWGRS S-25A 11/05/2006 Description Move On, Rig up, Displace Well, Nipple Down Tree, Nipple Up BOP. PULLED A 4 CIW BPV AFTER RIG MOVED ON WELL. M/O. Wait on Site Prep. T/I/O= Vac/Vac/85. Temp= SI. WHP's post-bleed (pre-rig). Integral installed on IA. Well house has been removed. Tubing and lAP went on vac. OAP increased 85 psi overnight. T/I/O=0/0/280. Temp=SI. Bleed WHPs to 0 psi (pre-rig). TBGP & lAP @ 0 psi upon arrival. Bled OAP from 280 psi to 0+ psi in 1 hr. SI monitored for 30 min. Final WHP's 0/0/0+. T/I/O=200/190/180 (pre-RWO) CMIT T x IA to 4000 psi= PASSED. MIT OA to 2000 psi=FAILED w/LLRT=l bpm @ 1250 psi. Took 9.1 bbls meoh to pressure T x IAup, Held pressure for 1 hr to show stabilization. T/IA Pressure losses= -25 psi/-30 psi in 1st 15 min. and -10 psi/ -10 psi in last 15 min. Pumped 12 bbls crude down OA for LLRT. Bled all pressures to 0 psi, Bled 3 bbls back off OA to get pressure to 0 psi. Final WHP=O/O/O AWGRS S-25A 11/05/2006 Awgrs continued from previous day. ( CMIT Tx IA / MlTx OA ) CMIT Initial Press. =2490/2480/160. 15 min press.=2450/2460/150. 30 min press.=2430/2440/130. CMIT is a Pass. MIT x OA is Cancelled. Bleed back OA Press.FWHP=400/400/360. DHD To Bleed Well To o Psi. AWGRS S-25A 11/04/2006 T/I/O=360/370/0 Continued from previous Awgers. / U-Tube Tx IA. / CMIT Tx IA. Intial Press.= ( Awgers continued on 11-05-06 ) AWGRS S-25A 11/04/2006 T/I/O=100/300/200 Circ-out Well (Pre-RWO) Pumped 5 bbls neat, 700 bbls 1% KCL, and 14 bbls diesel from mod to well down tbg taking returns from ia to S-26 flowline. Pumped 152 bbls diesel down ia taking returns from tbg. Freeze Protected jumper line to 5-26 w/ 1 bbl diesel. U-tube T x IA freeze protect. ***Job Continued on next WSR.*** AWGRS S-25A 09/29/2006 WELL SHUT IN ON ARRIVAL. SSV OPEN. FUSIBLE CAP ON THE SSV REMOVED FOR OPERATIONS WITH PERMISSION OF THE PAD OPERATOR. POWERJET CUT THE 4.5" TUBING AT 7030' IN THE MIDDLE OF THE 10' PUP ABOVE THE TUBING PATCH. MAXIMUM TOOL OD=3.65. TOTAL TOOLSTRING LENGTH=l7'. WELL SHUT IN ON DEPARTURE. SSV OPEN. FUSIBLE CAP RE-INSTALLED. ****JOB COMPLETE**** AWGRS S-25A 09/28/2006 RAN 3.65" JET CUTTER TO 7030'. TAGGED PATCH AT 7044'. CUTTER FAILED DUE TO DETONATOR FAILURE. PE SAID TO RIG DOWN DUE TO LACK OF HOURS WITH 24HR RULE AND NO REPLACEMENT CREW DUE TO RIG ACTIVITY. TRUCK TO RETURN TO SHOP FOR SCHEDULED MAINTENANCE, JOB TO BE COMPLETED BY UNIT 2158 FOLLOWING DAY, AWGRs s-25A 09/25/2006 T/IA/OA=SI/300/200 Pre- rig MIT PPPOT-IC Passed 3800 for 30 minutes. Cycle all LDS on casing spool, FMC ET all OK Test IC hanger on FMC well head to 3800. Repaired gland nut leaks. Bled off test void to 0 psi. *** NOTE Hoke valve on offside of test port. No tag or record to verify if had been packed or Seal Tite in past *** AWGRS S-25A 09/24/2006 *** WELL S/I ON ARRIVAL *** DUMP BAIL SLUGGITS (PRE RWO) DRIFT THRU PATCH W/ 2.80" CENT. DUMP 50 LBS OF sLUGGITS ON 2.875" XX PLUG @ 8776' SLM. DRIFT FRO E- LINE TO TAG PATCH W/ 3.80" GAUGE RING @ 7033' sLM. *** WELL LEFT 5/1 *** AWGRs S-25A 09/12/2006 ***WELL 5/1 ON ARRIVAL *** DRIFT WITH 3.705 CENT. AND S.B TO PATCH @ 7030' SLM, 7048' MD.(no sample recovered) DRIFT WITH 2.80 CENT 5' 1.5 STEM AND 2 7/8 B.L.B, BRUSH X-NIP @ 8876' sLM RIH W/ 2 7/8 X-LINE AND 2 7/8 XX- PLUG, WITH 4 EA. 1/8" EQ. PORTS. SET AT 8876' sLM, DRAW DN. TBG. FROM 375 PSI TO 175 PSI. ***LEFT WELL 5/1*** PAD OP NOTIFIED AWGRS S-25A 09/08/2006 T/IA/OA = SI/300/175 (Pre Rig Inspection) PPPOT-T = Passed Bled Tubing hanger void to 0 psi. Functioned/Torqued Lockdowns to 450 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 5,000 psi. for 30 mins. - Passed http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 12/12/2006 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-25 S-25 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/10/2006 11/18/2006 Spud Date: 8/2/1990 End: 11/10/2006 18:30 - 21 :00 2.50 MOB P PRE Break services lines at interconnect. Move pit module from sub base and stage on pad. PJSM. Move sub base off well S-124i and stage on pad. 21 :00 - 23:00 2.00 MOB N WAIT PRE Wait on gravel to be delivered to level site on S-25a. 23:00 - 00:00 1.00 MOB N WAIT PRE Roads and pads spread and leveled one load of gravel. Note: Well site was shoot for grade at 10:00 hrs. Equipment and gravel had been ordered to arrive at 14:00 hrs. Equipment showed up on location at 20:00 hrs. More gravel needed to bring site to grade. 11/11/2006 00:00 - 02:00 2.00 MOB N WAIT PRE Wait on gravel to be delivered to level site on S-25a. 02:00 - 08:00 6.00 MOB N WAIT PRE Roads and pads spread and leveled five loads of gravel to bring site to grade. Changed out Top Drive wash pipe packing and saver sub while waiting for site prep. 08:00 - 10:30 2.50 MOB P PRE Lay matting boards, Spot sub base over S-25. 10:30 - 11 :30 1.00 MOB P PRE Spot pit modual. 11 :30 - 12:00 0.50 MOB P PRE Level pit modual. 12:00 - 14:00 2.00 MOB P PRE Make up service lines at interconnect for pit modual. Berm cellar area in. Take on 100 degrees 8.5 ppg sea water in mud pits. Rig accepted on S-25 at 14:00 hrs, 11/11/2006. 14:00 - 17:00 3.00 WHSUR P DECOMP Install secondary annulus valves on OA and IA. Calibate and test H2S and LEL detection equipment. 17:00 - 17:30 0.50 WHSUR P DECOMP Pre spud safety meeting with all personal. 17:30 - 18:00 0.50 WHSUR P DECOMP Rig up DSM lubricator. Pull BPV. Rig down DSM lubricator. IA = 0 psi. OA = 120 psi. 18:00 - 21 :30 3.50 WHSUR P DECOMP Rig up circulating lines and PT same to 4000 psi. Reverse circulate at 3 bbl/min 190 psi pumping 8.5 ppg sea water, displacing 34 bbls of diese. Shut down and pump down the tubing, Pump 35 bbl Safe-Surf 0 soap sweep. Circulating bottoms up at 4 bblslmin 160 gpm at 175 psi. Displacing 118 bbl of diesel. Recovered 152 bbls of diesel. 21 :30 - 22:00 0.50 WHSUR P DECOMP Monitor well to verify dead. Blow down lines. 22:00 - 22:30 0.50 WHSUR P DECOMP Install TWC. 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM. Test IA and TWC to 2000 psi for 30 minutes. Test OA to 1000 psi for 30 minutes. 11/12/2006 00:00 - 00:30 0.50 WHSUR P DECOMP Blow down and rig down lines. 00:30 - 02:30 2.00 WHSUR P DECOMP PJSM. Bleed control lines down to 0 psi. Nipple down tree and adapter flange. Terminate control lines. Hanger threads galled too bad to screw TDS cross over into hanger with out damaging threads on cross over. o psi on OA. 02:30 - 05:00 2.50 BOPSU P DECOMP Nipple up BOP. 05:00 - 06:00 1.00 BOPSU P DECOMP Rig up test equipment. 06:00 - 11 :30 5.50 BOPSU P DECOMP Test BOPs and all associated valves to 250 psi low 4000 psi high. Utilizing 41/2" test joint. Wittness of BOP test waived by AOGCC rep Jeff Jones. Test Wittnessed by BP WSL Duncan Ferguson, Nabors Toolpusher Larry Wurdeman. 11 :30 - 13:00 1.50 BOPSU P DECOMP Blow down lines. Rig down test equipment. 13:00 - 14:00 1.00 PULL P DECOMP PJSM. Rig up DSM lubricator and pull TWC. Rig down DSM Printed: 11/20/2006 10:36:19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-25 S-25 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/1 0/2006 11/18/2006 Spud Date: 8/2/1990 End: 11112/2006 13:00 - 14:00 1.00 PULL P DECOMP lubricator. 14:00 - 15:00 1.00 PULL P DECOMP Make up Bakers spear assy. Engage hanger. Back out lock down screws. Hanger pulled off seat at 115k up wt. Pull Hanger to floor at 100k. 15:00 - 15:30 0.50 PULL P DECOMP Release spear and lay down same. Terminate control lines on tubing hanger. Break and lay down hanger. 15:30 - 16:30 1.00 PULL P DECOMP PJSM. Rig up Nabors casing equipment. Rig up SchlumbergerlCamco control line spooling unit. 16:30 - 19:00 2.50 PULL P DECOMP Rig up circulating lines. Circulate a 50 bbl Safe-Surf 0 soap sweep followed by 538 bbls of 110 degrees 8.5 ppg sea water at 252 gpm, 275 psi 19:00 - 22:00 3,00 PULL P DECOMP Lay down 4 1/2" 12.6# L-80 TDS tubing to SSSV. Recovered 53 joints of tubing, 4 SSCL bands, 26 clamps with pins. 22:00 - 22:30 0.50 PULL P DECOMP Rig down Schlumberger/Camco control line spooling unit. 22:30 - 00:00 1.50 PULL P DECOMP Continue laying down 41/2" 12.6# L-80 TDS tubing. 11/13/2006 00:00 - 03:00 3.00 PULL P DECOMP Lay down 4 1/2" 12.6# L-80 TDS tubing. Recovering 176 joints of 41/2" tubing, 1 SSSV, 3 GLMs, 4.80' cut off on pup jt below GLM #3, 03:00 - 03:30 0.50 PULL DECOMP Rig down Nabors casing equipment. 03:30 - 04:00 0.50 PULL DECOMP Clean rig floor. 04:00 - 04:30 0.50 BOPSU DECOMP Install test plug and rig up 4" test joint and equipment. 04:30 - 05:30 1.00 BOPSU DECOMP Test lower pipe rams, upper pipe rams to 250 psi low, 4000 psi high. Hydril 250 psi low, 3500 psi high. Witnessed by BP WSL Wade Frame, Nabors Toolpusher Biff Perry. 05:30 - 06:00 0.50 BOPSU DECOMP Rig down test equipment. Blow down lines. Install wear bushing, 06:00 - 09:30 3.50 FISH P DECOMP Make up BHA #2 consiting of 8 3/8" Outside cutter, (2) joints of 81/8" Wash pipe, 8 1/8" Drive bushing and Cross over = 76'. 09:30 - 12:00 2.50 FISH P DECOMP Run in the hole with BHA #2 from 76' to 1988'. Picking up 4" HT-40 drill pipe from pipe shed. 12:00 - 13:00 1.00 FISH P DECOMP Pull out of the hole from 1988' to 171'. Racking 19 stands 1739' of 4" HT-40 drill pipe back in derrick. 13:00 - 17:00 4.00 FISH P DECOMP Run in the hole with BHA #2 from 171' to 2720'. Picking up 4" HT-40 drill pipe from pipe shed. 17:00 - 17:30 0.50 FISH N DPRB DECOMP Taking 15k down wt. at 2720'. Break circulation at 252 gpm, 190 psi. Work thru tight area from 2720 to 2790'. with out rotation. Consult with engineering in town. 17:30 - 22:00 4.50 FISH P DECOMP Run in the hole with BHA #2 from 2720' to 7021'. Picking up 4" HT-40 drill pipe from pipe shed. 22:00 - 22:30 0.50 FISH P DECOMP Obtain parameters. 130k Up wt, S/O wt. 130k, Rot wt. 132k, 68 gpm, 50 psi 40 rpm, 1 k rotary tq. Tag top of fish at 7037' DPM. Wash over fish and swallow fish to 7103'. Locate tubing collar at 7083'. 22:30 - 23:00 0.50 FISH P DECOMP Begin tubing cutting operations at 7081',40 rpm, 1k rotary tq, 68 gpm, 50 psi. After 15 minutes into operation no increase in rotary tq, rotaion was stopped and string was lowered to 7103' in an attempt to relocate collar. At that point drill pipe pressure increased to 900 psi, pumping was stopped and pressure bleed off. Rotation was attempted but stalled the drill string at 5k rotary tq. Picked up to 175k with no pipe movement 45k overpull. Still unable to circulate thru drill string with out pressuring up. Increase rotary tq to 10k and work string up to 175k. Rotation was regained with 6k tq. and no circulation. Lost Printed: 11/20/2006 10:36:19 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-25 S-25 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/1 0/2006 11/18/2006 Spud Date: 8/2/1990 End: 11/13/2006 22:30 - 23:00 0.50 FISH P DECOMP 25k up weight while rotating and picked up 20k in string wt, rotary tq. fell to 4k. Still unable to circulate thru drill string. Up wt 150k. 23:00 - 00:00 1.00 FISH P DECOMP Monitor well bore for 15 minutes with a static loss rate of 10 bbls/hr. Pull out of the hole to 6479', Slowly. 11/14/2006 00:00 - 07:00 7.00 FISH P DECOMP Pull out of the hole from 6479' to 362', Slowly. Loss rate 10 bbl/hr. From 2770' to 2690' 5 to 10k overpull, From 2690' to 2652' 5k over pull was encountered. 07:00 - 09:00 2.00 FISH P DECOMP Gas breaking out of sea water in drill pipe. Install TIW valve and shut in drill pipe. Rig up head pin and lines to choke manifold. Monitor pressure for 15 minuntes. Pressure bulit from o psi to 15 psi. Bleed pressure off and continue sequence until pressure bleed to 0 psi. 09:00 - 10:00 1.00 FISH P DECOMP Pull out of the hole from 362' to 76'. 10:00 - 15:00 5.00 FISH P DECOMP PJSM. Break fish at tubing collar and rig up and monitor pressure while breaking down 8 1/8" wash pipe and stripping 4 1/2" tubing from wash pipe in the mouse hole. Inspection of wash pipe showed that the Drive sub/Triple connection had started to thread the 4 1/2" tubing stub making one full thread. Tubing pressure increased to 18 psi. Pressure was bleed off. Attempt to reverse circulate. Pressured up to 480 psi. Bled off pressure. Consult with engineering. 15:00 - 16:00 1.00 FISH P DECOMP Rig up and attempt to pump down tubing, pressure up 1000 psi. Bleed off pressure. Monitor tubing pressure 16:00 - 18:30 2.50 FISH P DECOMP Mobilize Schlumberger E-line unit. 18:30 - 20:30 2.00 FISH P DECOMP PJSM with Schlumberger personal. Rig up Schlumberger E-line. Arm 1.560" OD small charge tubing punch, 2 per shot, 6 shot per ft in a 6' carrier. 20:30 - 21 :30 1.00 FISH P DECOMP Run in the hole with CCL and 1.560" tubing punch. Punch holes in 4 1/2" tubing from 1732' to 1734' ELM. Monitor well bore. Tubing on a vacuum. Static loss rate 8 bbl/hr. 21 :30 - 22:00 0,50 FISH P DECOMP Pull out of the hole with tubing punch. 22:00 - 22:30 0.50 FISH P DECOMP Rig down Schlumberger lubricator and equipment. 22:30 - 00:00 1.50 FISH P DECOMP Rig up and pump 10 bbls of 8.5 ppg sea water down tubing. Confriming the abilty to circulate. Pump 10 bbls of Safe Surf-O soap sweep at 167 gpm, 150 psi. Circulate 80 degree 8.5 ppg seawater until clean returns, dumping 168 bbls of 8.5 ppg seawater. Monitor well bore, Mud wt. In 8.5 ppg. Out 8.5 ppg. Rig up Nabors Casing equipment. Static loss rate 8 bbl/hr. Total sea water lost in 24 hr time frame = 191 bbls 11/15/2006 00:00 - 06:30 6.50 FISH P DECOMP Lay down 41/2" 12.6# L-80 TDS tubing. Using rig tongs to break tubing connections due to excessive torque of 18k ftIpds. Recovered 43 joints 4 1/2" tubing, 2 GLM and "K" Anchor. 06:30 - 07:00 0.50 FISH P DECOMP Clean and clear rig floor. 07:00 - 09:30 2.50 CLEAN P DECOMP Pick BHA #3 consiting of a 8 1/2" Tapper mill, 95/8" Casing scraper, Boot basket, Bit sub, 8 1/2" String mill, Bumper sub, Oil jar, X-O, (3) 6 1/4" Drill collars, (2) x-O = 137'. 09:30 - 11 :30 2.00 CLEAN P DECOMP Run in the hole from 137' to 2621. 11 :30 - 13:30 2.00 CLEAN P DECOMP Obtain parameters. Up wt. 74k, SIO wt. 75k, 50 Rpm, Tq 1 k, 400 gpm 470 psi. Ream and work tight area from 2660' to 2717'. At 2690' took 8k SIO wt. to work thru. 5K while working up thru tight area. Ream area from 2690' to 2717' a total of 5 times. Rotary tq got as high as 5k while reaming tight area. Printed: 11/20/2006 10:36:19AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-25 S-25 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/1 0/2006 11 /18/2006 Spud Date: 8/2/1990 End: 11115/2006 11 :30 - 13:30 2.00 CLEAN P DECOMP Rotation was stopped and BHA passed thru tight area with no increase in drag. 13:30 - 16:30 3.00 CLEAN P DECOMP Run in the hole from 2812' to 8885' DPM. Lighly tagging top of 9 5/8" packer with 5k. 16:30 - 18:30 2.00 CLEAN P DECOMP Circulate a 24 bb110.0 ppg Hi-Vis sweep around at 400 gpm 1120 psi until clean. Sweep brought back a small amount of parafin and scale. Monitor well bore. Static loss rate 6 bbl/hr. 18:30 - 22:00 3.50 CLEAN P DECOMP Pull out of the hole from 8880' to 137'. 22:00 - 23:00 1.00 CLEAN P DECOMP Stand back drill collars and lay down clean out assy. Both mills full gauge with no wear. Boot basket empty. 23:00 - 23:30 0.50 CLEAN P DECOMP Clear and clean rig floor. 23:30 - 00:00 0.50 DHB P DECOMP PJSM. Make up HES 9 5/8" Retrievable Bridge plug. Total sea water lost in 24 hr time frame = 143 bbls 11/16/2006 00:00 - 01 :00 1.00 DHB P DECOMP Make up HES 9 5/8" Retrievable Bridge plug and 1 stand of 6 1/2" drill collars to 1 03' 01 :00 - 01 :30 0.50 DHB P DECOMP Service top drive and crown. Inspect top drive for loose components. 01 :30 - 05:30 4.00 DHB P DECOMP Run in the hole from 103' to 8,834'. 05:30 - 07:00 1.50 DHB P DECOMP Set Retrievable Bridge Plug. Test plug and 95/8" casing to 4,000 psi. Hold & chart for 30 minutes. Good test. First attempt at tesing RBP and casing failed due to surface leak. Changed a bad low torque valve. 07:00 - 07:30 0.50 DHB P DECOMP Rig down and blow down lines. 07:30 - 08:30 1.00 DHB DECOMP Make up Halliburton 9 5/8" RTTS and set at 6' below ground level. Test to 1000 psi. 08:30 - 09:00 0.50 BOPSU P DECOMP Pull wear bushing. 09:00 - 10:00 1.00 DHB P DECOMP Make up packoff retrieving tool. Back out lock down screws. Engage 9 5/8" pack off and pull to rig floor. 15k over pull. Inspection of pack off showed no signs of being plastic packed. 10:00 - 14:30 4.50 DHB N DPRB DECOMP Install new 9 5/8" pack off and attempt to test to 5000 psi. Not holding any pressure. Consult with engineering and FMC in town. Pull 9 5/8" pack off. Add spacer to pack off below seals. 14:30 - 18:00 3.50 DHB P DECOMP Install new 9 5/8" pack off. Attempt to test to 5000 psi, Pressure bleeding off. Bled off pressure. Back out 3 lock down screws and change gland packing. Pressure test to 5000 psi, pressure bled to 4650 psi and stablized and held at 4650 psi for 30 minutes. 18:00 - 19:00 1.00 BOPSU P DECOMP Install wear bushing. 19:00 - 19:30 0.50 DHB P DECOMP PJSM. Retrieve Halliburton 9 5/8" RTTS and lay down. 19:30 - 20:00 0.50 DHB P DECOMP Run in the hole to 8835' and unseat Halliburton 9 5/8' retrievable bridge plug. Monitor well bore. Static loss rate 3 bbl/hr 20:00 - 22:00 2.00 CLEAN P DECOMP Circulate bottoms up at 252 gpm, 490 psi. Mud wt In 8.5 ppg. Out 8.5 ppg. Monitor well bore. Static loss rate 3 bbl/hr. Pump dry job. 22:00 - 22:30 0.50 CLEAN P DECOMP Pull out of the hole laying down 4" HT-40 drill pipe from 8835' to 8609'. 22:30 - 23:30 1.00 CLEAN N RREP DECOMP Trouble shoot and replace bad relay in control panel for pipe skate. 23:30 - 00:00 0.50 CLEAN P DECOMP Pull out of the hole laying down 4" HT-40 drill pipe from 8609' to 8035'. Printed: 11/20/2006 10:36:19 AM J " . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-25 S-25 WORKOVER NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 11/10/2006 11/18/2006 Spud Date: 8/2/1990 End: 11116/2006 23:30 - 00:00 0.50 CLEAN P DECOMP 11/17/2006 00:00 - 06:00 6.00 CLEAN P DECOMP 06:00 - 07:00 1.00 CLEAN P DECOMP 07:00 - 07:30 07:30 - 09:30 09:30 - 23:00 23:00 - 00:00 Note: SIMOPS Pumping 135 bbls of dead crude down 9 5/8" x 133/8" Annulus with Uttle Red Hot. DECOMP Pull wear bushing. Make dummy run with hanger. RUNCMP PJSM. Rig up Nabors casing torque turn equipment. PJSM with Baker personal. RUNCMP Run in the hole with 4.5" 12.6# L-80 TC-II completion. Baker-Lok all connections from Bakers S 3 packer to muleshoe. OD on N-Go 8.25". Optimum Torque 3850 ftllbs. RUNCMP Rig down comensator. Pick up joint # 211, Make head pin and kelly up, break circulation at 3 bbl/min 129 gpm at 57 psi. Confrim tag up at 8885' by pressure increase of 23 psi and 10k S/O weight. Repeat process with same results. 0.50 BOPSU 2.00 RUNCO 13.50 11/18/2006 00:00 - 01 :00 RUNCMP 01 :00 - 02:00 1.00 RUNCO RUNCMP 02:00 - 02:30 0.50 RUNCO RUNCMP 02:30 - 06:00 3.50 RUNCO RUNCMP 06:00 - 08:00 RUNCMP 08:00 - 09:00 1,00 WHSUR P RUNCMP 09:00 - 10:30 1.50 BOPSU P RUNCMP 10:30 - 15:30 5.00 WHSUR P RUNCMP 15:30 - 16:00 0.50 WHSUR P RUNCMP 16:00 - 17:00 1.00 WHSUR P RUNCMP 17:00 - 20:00 3.00 WHSUR P RUNCMP 20:00 - 21 :00 1.00 WHSUR P RUNCMP 21 :00 - 22:00 1.00 WHSUR P RUNCMP 22:00 - 00:00 2.00 WHSUR P RUNCMP Total sea water lost in 24 hr time frame = 36 bbls. Pull out of the hole laying down 4" HT-40 drill pipe from 8035' to 103' Lay down (3) 6 1/4" drill collars and Halliburton 9 5/8" retrievable bridge plug. Clear and clean rig floor. Total sea water lost in 24 hr time frame = 13 bbls. Space out. lay down joint #211 and 210. Pick up 1 space out pup 9.83', and joint #210. Ran a total of 210 joints + (1) 9.83' space out pup. Make up landing joint and hanger. Land hanger. Mule shoe inserted 3.30' into 9 5/8" packer. Up wt. 117k. S/O 116k. Run in lock down screws. Reverse circulate 105 bbls of 8.5 ppg sea water followed by 272 bbls of inhibited sea water. Spot inhibited sea water with 203 bbls of 8.5 ppg sea water at 3 bbl/min 126 gpm 200 psi. Drop 1 7/8" ball and rod, allow to fall. Pressure up on tubing to 2800 psi to set Bakers S-3 packer. Continue pressuring up to 4000 psi and test packer for 30 minutes. Bleed pressure down to 1900 psi. Pressure annulus to 4000 psi. Chart and hold for 30 minutes. Bleed annulus pressure then tubing pressure. Shear DCK valve with 2330 psi by pumping down the annulus. Pump 5 bbls each way to confirm DCK valve sheared. Install TWC and test to 1000 psi from below. Good test. Nipple down BOP. Nipple up adapter flange and tree. Test adapter flange to 5000 psi. Good test. Test tree to 5000 psi. Good test. Rig up DSM lubricator, Pull TWC. PJSM. Rig up Hot Oil and pressure test lines to 3000 psi. Good test. Reverse circulate 150 bbls of diesel at 70 dgrees. Allow freeze protect to U-tube. Rig up DSM lubricator. Install BPV. Lay down DSM lubricator. Test BPV from below to 1000 psi. Good test. Rig down and blow down lines. Remove residual fluid from mud pits. Remove secondary annulus valve. Secure tree. Rig Released from S-25a at 23:59 hrs. 11-18-2006. Printed: 11120/2006 10:36:19 AM . . FRANK H. MURKOWSKI. GOVERNOR AJ1ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 1966J2 Anchorage, AK 99519-6612 ~qt6 -~~1f Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU S-25A Sundry Number: 306-326 SCANNED SEP 2 '7 2006 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Cathy P. Foerster Commissioner 25~ . DATED this_ day of September, 2006 Encl. ~)QÎ . ~ ~\t¡JJ I I1f¿ .'/2-5/06 RE~e\1eOW04- STATE OF ALASKA ALAS Oil AND GAS CONSERVATION COM SION SEP 2 5 2006 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cans. Commission 20 AAC 25 280 A 1. Type of Request~bandon o Suspend o Operation Shutdown o Perforate o Time Extension '... o Alter Casing ~(iA- œtRepair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program ~UII Tubing o Perforate New Pool o Waiver o Other ì t 2. Operator Name: 4. Current Well Class: 5. Permit To ~ Number " / BP Exploration (Alaska) Inc. o Development o Exploratory 198-214 3. Address: o Stratigraphic 181 Service 6. API Number: ./ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22011-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU S-25A / Spacing Exception Required? DYes 181 No 9. Property Designation: 10. KB Elevation (ft): 11. Field 1 Pool(s): ADL 028257 65.75' Prudhoe Bay Field 1 Prudhoe Bay Pool 12tY .... ,if.', .i·.ii·.... /. //..,'y '/.' .. IIVVI-I ,fj'.·} ..........' ........../ .... ..·...'/,}iij;j, .,,'.' .'" ,.iiyi:'j··.... Total Depth MD (ft): Total Depth TVD (ft):Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11691 9006 11487 / 9018 11487 None Casino Lenoth Size MD { TVD Burst Collanse Structural Conductor 110' 20" x 30" 110' 110' Surface 2674' 13-3/8" 2674' 2674' 4930 2270 Intermediate 9141' 9-5/8" 9141' 8781' 6870 4760 Production Liner 253' 7" 8912' - 9165' 8582' - 8801' 7240 5410 Liner 2638' 2-7/8" 8916' - 11554' 8586' - 9016' 13450 13890 Perforation Depth MD (~I Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft): 11364'-11434' 9018'-9018' 4-1/2", 12.6# L-80 8973' / Packers and SSSV Type: 9-5/8" Baker packer I Packers and SSSV MD (ft): 8885' // 13. Attachments: 14. Well Class after proposed work: /' 181 Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program 15. Estimated Date for 9rlp.\-. ~ì, / 16. Well Status after proposed work: vJ6~ Commencinç¡ Operations: Oðt6~u d, 1006 o Oil o Gas o Plugged ~andoned 17. Verbal Approval: Date: o WAG oGINJ ØWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: ~~// Date '1~ Signature . u/'JP-J~;, ~ Phone 564-4166 Terrie Hubble, 564-4628 / Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:"'3Df n '" /)..!J { IJ o Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance Other: Tf'Ç.t ßoPE f-o ~ODO ,ok , 1,.Ill \ V ¡'!ö vvt' \At ð . RBDMS BFl SEP 2 6 2006 Subsequent Form Required: lO - 404. Approved BV:r;~. ¡/~_ r£ APPROVED BY Date 9'" Z.s-" t> þ COMMISSIONER THE COMMISSION Form 1 0-403 Revise~6/2006 . Submit In Duplicate ORIGINAL . . Obp GL-JJJr.6rAY To: Winton Aubert - AOGCC Date: September 25, 2006 From: Ken Allen - BPXA GPB Rotary Drilling S-25A Application for Sundry Approval - RWO Subject: The S-25A RWO is currently scheduled for Nabors 7ES beginning around Octob r 15,2006. The pre-rig work for this sidetrack will be priority scheduled after the Application for Sundry is \~~pJoved. Well Status: Shut-in Ivishak WAG injector. The well has confirmed tubing by inner annulus communication. The leak path is believed to be through a hole in the tubing -7,062' md. A permanent patch was installed over this leak, but there were problems setting the patch. A leak path still exists in this ~ area of the tubing. Proposed work: Retrieve the existing tubing and tubing patch above the current production packer. Re- complete the well with 4-1/2",12.6#, L-80 TCII tubing. Provide AOGCC field inspectors 24 hour notices, as required, to witness BOP and post packer setting pressure tests. Scope Pre-Ria Work: 1. Rig up slickline, drift 4-1/2" tubing through 2-7/8" X nipple. Set XX-plug in 2-7/8" X nipple. 2. Dump -50 Ibs of sluggets on top of 2-7/8" plug. / ("'/ 3. Jet cut the 4-1/2" tubing a , 30' MD (middle of joint above top patch). 4. Pressure test T X fA to ,000 si for 30 minutes. Pressure test the OA to 2,000 psi for 30 minutes. / 5. Circulate the well to sea ... er through the cut. Freeze protect the IA and tubing with diesel to -2,200'. 6. Bleed OA, IA & TBG to zero. 9-5/8" pack-off has been plastic packed and cannot be tested. Test ~ tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 7. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 8. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace wel~seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing w/GLM's from above pre-rig cut at -7,030'. 5. PU Baker outside cutter and enough wash over pipe to cut at a depth of least 7,080' MD. POOH w/4- ./ 1/2" tubing with patch inside. 6. PU 4-1/2" work string with overshot. Swallow the tubing stub. 7. RU e-line. RIH w/chemical cutter and cut tubing at the top of the 1st pup joint below GLM# 1. Cut / should be -1' below connection at 8,859' MD. POOH & LD work string. RD e-line. 8. RIH picking up 4" DP with a 4-1/2" overshot grapple. POOH and LD tubing. 9. PU 1 joint of 2-7/8" DP with mule shoe and junk catcher BHA. RIH on 4" DP to -3,000' and hang off /' string on Storm Packer (RTTS). Test RTTS. S-25A Application for Sundry . . 10. Change out 9-5/8" PO. Note: The 9-5/8" PO was plastic packed and will require a nipple down to clean "'" out the bowl area. 11. Lay down RTTS. Continue in the hole and wash cutter debris and sluggets from the top of the 2-7/8" plug. Pump viscous sweeps to ensure well bore is clean. POOH. 12. RIH with 4-1/2" work string and overshot. Swallow tubing stub. 13. RU slick-line. RIH, equalize pressure and pull 2-7/8" plug. RIH with GS tool and latch into 4-1/2" x 2- 7/8" reducer. POOH with re~er. RD slick-line. Note: Ensure rig team is prepared for possible gas / and or for the well to start 10 sing fluid. 14. PU Overshot dressing mill nd scraper on DP. RIH, washover to clean possible fill behind tubing stub and dress tubing cut. 15. Run 4-1/2", 12.6# L-80 TC-II completion and Unique Machine custom overshot. Swallow 4-1/2" tubing ..--- stub at 8,859'. Space out overshot -2' above no-go point. RILDS. Circulate inhibited sea water. " 16. Drop ball and rod, set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes each. Record each test. Note: Well will require 1 GLM. 17. Set and test TWC to 1000 psi. 18. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. Pull TWG. / 19. Freeze protect the well to -2,000' TVD. 20. Set BPV. 21. Secure the well. 22. Rig down and move off. Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod I RHC plug from 'X' nipple below the new production packer. Estimated Pre-rig Start Date: 09/27/06 Estimated RWO Date: 09/29/06 Ken Allen Operations Drilling Engineer 907-564-4366 s-25A Application for Sundry TREE = WELLHEAD = ACTUATOR = KB. EL8I = BF. EL8I = KOP= Max Angle = Datum MD = Datum lVD = . 4-1/16" CrN FMC OTIS 65.75' 36.15' 5000' 92 @ 10996' 9253' 8800' SS 113-3/8" CSG, 68#, NT-80, BTRS, 10 = 12.415" H 2674' Minimum ID = 2.37"@ 8923' 2-7/8" LNR TOP I 2-7/8" xx Rug X profile I TOP OF 7" LINER I 8911' I TOP OF 2-7/8" LNR, 10 = 2.37" I 8923' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 8913' 9-5/8" CSG, 47#, NT-80S, NSCC, 10 = 8.681" I ÆRFORA TION SUMMARY REF LOG: BAKER MWO RESISTIVITY ON 11/11/98 ANGLE AT TOP ÆRF: 90 @ 11364' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2 4 11364 - 11434 0 11/24/98 I 7" LNR. 26#, L-80, .0383 bpf, 10 = 6.276" I 9648' DATE 08117190 11124198 12/04198 01/20/99 OS/27/00 06/27/01 R8I BY COMMENTS HF ORIGINAL COM PLETION CTD SIDETRACK KSBfTLP GLV C/O (ADDBJ 11/08104) GLM UPDA TE TO PC KSBITLP SET NIPPLE (ADDED 11/06/04) CHlTP CORRECTIONS S-25A Current / SAFAOTES: PORTIONS OF WEll R.OWLlNE ARE 1IrNc SUBJECT TO EROSION. GC SHOULD BE NOTIFIED OF ANY WELL OPERATION THAT COULD INCREASE THE R.OW OR EROSION RATES. WEll EXCEEDS 70° @ 9350' & GOES HORIZONTAL @ 9650'. TBG PATCH. TOOLS LOST ON 06/02/00. . 2091' -i 4-1/2" OTIS SSSV LANOING NIP, ID = 3.813" GAS LIFT MANDRELS D8I TYÆ VLV FúRT LATCH o OTIS DMY RA 10 OTIS DMY RA 24 OTIS OMY RA 27 OTIS DMY RA 27 OTIS DMY RA - ST MD lVD 5 3102 3036 4 5217 5149 3 7016 6812 2 8622 8258 1 8848 8459 OATE 12/04/98 12/04/98 09/22/04 11/27/98 11/27/98 I I 7048'-1074'-1 4-112" HES ÆRMANENTTBG PATCH I 8817' -i 4-1/2"PARKERSWSNIP,10=3.813" I -14-1/2" X 2-7/8" X NIP, ID = 2.313" SET OS/27/00 BAKER TUBING ANCHOR 9-5/8" BAKER PKR, 10 = 3.99" I 8916' -i 3-3/4" BKR LNR DEPLOY SL V, ID = 3.00" 8940' 4-1/2" PARKER SWS NIP, 10 = 3.813" 8914' 8980' 4-1/2" TUBING TAIL WLEG ELMD IT LOGGBJ 11/09/90 8961' 4-1/2" OTIS XN NIP, 10 = 3.725" I 7" MILLOUT WINDOW 9162' - 9167' I PBTD(CIBP) I ~ 2-7/8" LNR, 6.16#, L-80, ST-L, .0068 bpf, ID = 2.37" I~ OA TE REV BY COMMENTS 09/22104 KSBITLP A.JLL FISH, SET DGLVs 03/16/05 PClPJC CSGITBGlLNR CORRECTIONS ffiUDHOE BA Y UNfT WELL: S-25A ÆRMfT No: 1982140 AR No: 50-029-22077-01 SEC35, T12N, R12E, 1633' SNL & 4158'WEL BP Exploration (Alaska) TREE : W8..LHEAD: ACTUATOR: KB. 8..EV : BF. 8..EV : KOP: Max Angle: Datum MD : Datum1VD: 4-1/16" CrN FMC OTIS 65.75' 36.15' 5000' 92 @ 10996' 9253' 8800' S8 . 113-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" H 2674' Minimum ID = 2.37"@ 8923' 2-7/8" LNR TOP Jet Cut - -7030' 50# Sluggets (-7') 2-7/8" xx Plug X profile I TOP OF 7" LINER I 8911' I TOP OF 2-7/8" LNR, ID = 2.37" I 8923' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 8913' 9-5/8" CSG, 47#, NT-80S, NSCC, 10 = 8.681" I S-25A Pre-Rig SAFAOTES: PORTIONS OF WELL ROW LINE ARE 1IrND SUBJECT TO EROSION. GC SHOULD BE NOTIRED OF ANY WELL OPERATION THAT COULD INCREASE THE ROW OR EROSION RATES. WELL EXCEEDS 700 @ 9350' & GOES HORIZONTAL @ 9650'. TBG PATCH. TOOLS LOST ON 06/02/0a. . 2091' -I 4-1/2" OTIS SSSV LANDING NIP, 10= 3.813" GAS LIFT MANDRELS DEV TYPE VLV PORT LATCH o OTIS DMY RA 10 OTIS DMY RA 24 OTIS DMY RA 27 OTIS DMY RA 27 OTIS DMY RA t- ST MD TVD 5 3102 3036 4 5217 5149 3 7016 6812 2 8622 8258 1 8848 8459 DATE 12/04/98 12/04/98 09/22/04 11/27/98 11/27/98 , / 71 1 7048'-7074' ~ 4-1/2" HES ÆRMANENTTBG PATCH I 8871' -I 4-1/2" PARKER SWS NIP, 10 = 3.813" I -14-112" X 2-7/8" X NIP, ID = 2.313" SET OS/27/00 BAKER TUBING ANCHOR 9-5/8" BAKER PKR, 10 = 3.99" I 3-3/4" BKR LNR DEPLOY SL V, ID = 3.00" 8940' 4-1/2" TUBING TAIL WLEG 8..MD IT LOGGED 11/09/90 4-1/2" PARKER SWS NIP, ID = 3.813" 8961' 4-1/2" OTIS XN NIP, ID = 3.725" I ÆRFORA TION SUMMARY REF LOG: BAKER MWD RESISTIVITY ON 11/11/98 ANGLEATTOPÆRF: 90 @ 11364' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 4 11364 - 11434 0 11/24/98 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 9648' DATE 08117190 11124198 12/04/98 01/20199 OS/27/00 06/27/01 REV BY COMMENTS HF ORIGINAL COM PLETION CTD SIDETRACK KSBITLP GLV C/O (ADDED 11/08/04) GLM UPDA TE TO PC KSBITLP SET NIPPLE (ADDED 11/06/04) CHITP CORRECTIONS DATE 09/22/04 03/16/05 09/22/06 8974' 8980' 7" MILLOUT WINDOW 9162' - 9167' I I I PBTD (CIBP) I ~ 2-7/8" LNR, 6.16#, L-80, ST-L, .0068 bpf, 10 = 2.37" I~ REV BY COMMENTS KSBITLP PULL FISH, SET DGL V s PClPJC CSGrrBG/LNR CORRECTIONS kw a Pre-Rig PRUDHOE BA Y UNIT W8..L: S-25A PERMIT No: ~982140 API No: 50-029-22077-01 SEC 35, T12N, R12E. 1633' SNL & 4158' W8.. BP Exploration (Alaska) TREE = W8..LHEAO = ACTUA TOR = KB. 8..81 = BF. 8..81 = KOP= Max Angle = Datum MD = Datum lVD = 4-1/16" CrN FMC OTIS 65.75' 36.15' 5000' 92 @ 10996' 9253' 8800' SS . 113-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" H 2674' r Minimum ID = 2.313" 2-7/8" X-Nipple TBG Stub - -7030' Outside Mechanical Cut - -7080' 50# Sluggets (-7') 2-718" xx Rug X profile I TOP OF 7" LINER I 8911' I TOP OF 2-7/8" LNR, ID = 2.37" I 8923' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9-5/8" CSG, 47#, NT-80S, NSCC, ID = 8.681" I DATE 08/17190 11/24198 12/04/98 01/20/99 OS/27/00 06/27101 8913' PERFORA TION SUMMARY REF LOG: BAKER MWD RESISTIVITY ON 11/11/98 ANGLE AT TOP PERF: 90 @ 11364' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2 4 11364 - 11434 0 11/24/98 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 9648' R8I BY COMMENTS HF ORIGINAL COM PLETION CTD SIDETRACK KSBITLP GLV C/O (ADDED 11/08/04) GLM UPDATE TO PC KSBITLP SET NIPPLE (ADDED 11/06/04) CHfTP CORRECTIONS DATE 09/22/04 03/16/05 09/22/06 S-25A Decamp 1 SAFA,OTES: PORTIONS OF WELL ROWLlNE ARE~D SUBJECT TO EROSION. GC SHOULD BE NOTIRED OF ANY WELL OPERATION THAT COULD INCREASE THE ROW OR EROSION RATES. WELL EXCEEDS 70° @ 9350' & GOES HORIZONTAL @ 9650'. TBGPATCH. TOOLS LOST ON 06/02/00. , I 1/ "7 , 7048'·7074' -f 4-1/2" HES PERMANENTTBG PATCH , -I 4-1/2" PARKER SWS NIP, ID = 3.813" I -14-1/2" X 2-718" X NIP, ID = 2.313" SET 05/27/00 BAKER TUBING ANCHOR 9-5/8" BAKER PKR, ID = 3.99" I 8916' -I 3-3/4" BKR LNR DEPLOY SLV, ID = 3.00" 8940' -I 4-1/2" PARKER SWS NIP, ID = 3.813" -I 4-1/2" OTIS XN NIP, ID = 3.725" I -i 4-1/2" TUBING TAIL WLEG 1-1 8..MD TT LOGGED 11109/90 8961' 8974' 8980' 7" MILLOUT WINDOW 9162' - 9167' -1 TOP OF WHIPSTOCK -I RA MARKER I I PBTD(CIBP) I ~ 2-7/8" LNR, 6.16#, L-80, ST-L, .0068 bpf, ID = 2.37" I~ REV BY COMMENTS KSB/TLP AJLL FISH, SET DGL V s PClPJC CSGfTBG/LNR CORRECTIONS kw a Decompletion step 1 PRUDHOE BA Y UNIT WELL: S-25A PERMIT No: '1982140 AR No: 50-029-22077-01 SEC 35, T12N, R12E, 1633' SNL & 4158' W8.. BP Exploration (Alaska) TREE = WB..LHEAD = ACTUATOR = KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = Datum1VD= . 4-1/16" crw FMC OTIS 65.75' 36.15' 5000' 92 @ 10996' 9253' 8800' SS 113-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" H 2674' r Minimum ID = 2.313" 2-7/8" X-Nipple TBG Stub - -7080' Chemical Cut - -8859' 50# Sluggets (-7') 2-7/8" xx Aug X profile I TOP OF 7" LINER I 8911' I TOP OF 2-7/8" LNR, ID = 2.37" I 8923' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8973' 9-5/8" CSG, 47#, NT-80S, NSCC, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BAKER MWD RESISTIVITY ON 11/11/98 ANGLE AT TOP ÆRF: 90 @ 11364' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2 4 11364 -11434 0 11/24/98 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 9648' DATE 08117190 11124/98 12/04/98 01/20199 OS/27/00 06/27/01 REV BY COMMENTS HF ORIGINAL COM PLETION CTD SIDETRACK KSBITLP GLV C/O (ADDED 11/08/04) GLM UAJA TE TO PC KSBITLP SET NIffi..E (ADDED 11/06/04) CH/TP CORRECTIONS DATE 09/22/04 03/16/05 09/22/06 S-25A Decamp 2 SAFAiOTES: PORTIONS OFWELL R.OWLlNE ARE ~D SUBJECT TO EROSION. GC SHOULD BE NOTIAED OF ANY WELL OPERATION THAT COULD INCREASE THE R.OW OR EROSION RATES. WELL EXCEEDS 70° @ 9350' & GOES HORIZONTAL @ 9650'. TBGPATCH. TOOLS LOST ON 06/02/00. , "/ / / '" 8877' -1 4-1/2" PARKER SWS NIP, ID = 3.813" I -14-1/2" X 2-7/8" X NIP, ID = 2.313" SET OS/27/00 BAKER TUBING ANCHOR 9-5/8" BAKER PKR, ID = 3.99" I 8916' -1 3-3/4" BKR LNR DEA...OY SL V, ID = 3.00" 8940' 4-1/2" PARKER SWS NIP, ID = 3.813" 8914' 8980' 4-1/2" TUBING TAIL WLEG ELMD TT LOGGED 11/09/90 8961' 4-1/2" OTIS XN NIP, ID = 3.725" I 7" MILLOUT WINDOW 9162' - 9167' I PBTD(CIBP) I ~ 2-7/8" LNR, 6.16#, L-80, ST-L, .0068 bpf, ID = 2.37" ]~ REV BY COMMENTS KSBITLP PULL FISH, SET DGL V s PClPJC CSG/TBG/LNR CORRECTIONS kw a Decompletion step 2 ffiUDHOE BA Y UNIT WB..L: S-25A PERMIT No: ~982140 AA No: 50-029-22077-01 SEC 35, T12N, R12E, 1633' SNL & 4158' WB.. BP Exploration (Alaska) TREE = WB...LHEAO = ACTUATOR = KB. B...EV = BF. B...EV = KOP= Max Angle = Datum MD = Datum ND = I. S-25A / Proposed Completion 4-1/16" CrN FMC OTIS 65.75' 36.15' 5000' 92 @ 10996' 9253' 8800' SS 113-3/8" CSG, 68#, NT-80, BTRS, ID = 12.415" I.., 2614' r 4-1/2", 12.6#, L-80 TCII Tubing 4-1/2" HES X Nipple, ID = 3.813" 9-5/8" x 4-1/2" BKR 83 PKR 4-1/2" HE8 X Nipple, ID = 3.813" Unique Overshot Assy / wI Top TBG stub -8,859' I TOP OF 7" LINER I 8911' I TOPOF2-7/8"LNR,ID=2.37" I 8923' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8973' 9-5/8" CSG, 47#, NT-80S, NSCC, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BAKER MWD RESISTNITY ON 11/11/98 ANGLE AT TOP ÆRF: 90 @ 11364' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 411364-11434 0 11/24/98 I 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 9648' .. DATE 08117190 11124198 12/04/98 01/20/99 OS/27/00 06/27/01 DATE 09/22/04 03/16/05 09/22/06 REV BY COMMENTS HF ORIGINAL COM PLETION CTD SIDETRACK KSBfTLP GLV C/O (ADDED 11/08104) GLM UPDATE TO FÇ KSBfTLP SET NIPPLE (ADDED 11/06/04) CH/TP CORRECTIONS II sAF!AOTES: PORTIONS OF WELL FLOWLINE ARE JlrND SUBJECT TO EROSION. GC SHOULD BE NOTIRED OF ANY WELL OPERATION THAT COULD INCREASE THE FLOW OR EROSION RATES. WELL EXCEEDS 70° @ 9350' & GOES HORIZONTAL@ 9650'. TBG PATCH. TOOLS LOST ON 06/02/00. -2100' - 4-1/2" HE8 X Nipple, ID = 3.813" 3800' rvD / - 3800' MD - Gas Lift Mandrel #1 8877' -1 4-1/2" PARKER SWS NIP, ID = 3.813" I BAKER TUBING ANCHOR 9-5/8" BAKER PKR, ID = 3.99" I 3-3/4" BKR LNR DER.OY SLY, ID = 3.00" 8940' 4-112" TUBING TAIL WLEG B...MD TT LOGGED 11/09/90 4-1/2" PARKER SWS NIP, ID = 3.813" 8961' 4-112" OTIS XN NIP, ID = 3.725" I 8974' 8980' 7" MILLOUT WINDOW 9162' - 9167' I PBTD (CIBP) I ~ 2-7/8" LNR, 6.16#, L-80, ST-L, .0068 bpf, ID = 2.37" I~ REV BY COMMENTS KSBfTLP PULL FISH, SET DGL V s PClPJC CSG/TBG/LNR CORRECTIONS kw a Proposed Completion PRUDHOE SA Y UNIT WB...L: S-25A ÆRMIT No: ~982140 API No: 50-029-22077-01 SEC 35, T12N, R12E. 1633' SNL & 4158' WB... BP Exploration (Alaska) • • Maunder, Thomas E (DOA) From: GPB, Well Integrity Engineer [ GPBWelllntegrityEngineer @bp.com] Sent: Friday, March 16, 2001 6:56 PM To: Maunder, Thomas E (DOA) Subject: Low OA Fluid Levels Hello Tom. During routine outer annulus bleed operations on well S -30, the fluid level in the 9 -5/8" x 13 -3/8" annulus was noted to be near the 13 -3/8" casing shoe. This initiated a review of wells Prudhoe Bay field -wide and the following wells have been identified with OA fluid levels near the surface casing shoe: - J -08: OA FL @ 2590', shoe @ 2691' __ - S -25: OA FL @ 2526', shoe @ 2680' c._S - a-SP01 - 1 - S -30: OA FL @ 2544', shoe @ 2681' - W -11: OA FL @ 3222', shoe @ 3217' - Z -10: OA FL @ 3190', shoe @ 3186' Evaluation is ongoing on these wells and we will keep you informed of progress. Please call if you have any questions. Joe Joe Anders, PE / Kevin Yeager Well Integrity Engineer a MAR 201 F v BP Exploration, Alaska Inc. (907) 659 -5102 - Work (907) 659 -5100, x1154 - Pager 1 a 4 Maunder, Thomas E (DOA) From: GPB, Well Integrity Engineer [ GPBWellIntegrityEngineer @bp.com] Sent: Monday, December 18, 2000 2:59 PM To: Maunder, Thomas E (DOA) Subject: RE: S -25A Status (PTD 198 -214) Hi Tom. S -25 was SI 3 days prior to attempting to set the patch. It was not put back on injection after the patch was run. Joe Original Message From: Tom Maunder [mailto :tom maunder @admin.state.ak.us] Sent: Monday, December 18, 2000 2:59 PM To: GPB, Well Integrity Engineer Subject: Re: S -25A Status (PTD 198 -214) MAR 0 2 2011 Joe /Kevin, Was the well shut in after sticking the setting tool? Tom "GPB, Well Integrity Engineer" wrote: > Hello Tom. This is a summary of well S -25A (PTD 198 -214) status. It is > an injector SI due to holes in the tubing. The well failed an MITIA on 2/18/00. > A patch and setting tool are stuck across the hole at 7062'. Injection > stopped 05/31/00. Below is a listing of recent events: > > 02/18/00: MITIA failed, LLR 2.0 BPM @ 2000 psi > > 03/06/00: LDL found leak at 7062' > > 03/06/00: Verbal from AOGCC until remedial plan approved, no MI injection > > 03/11/00: Kinley caliper > > 06/02/00: While setting perm patch, setting tool would not release. > > 08/08/00: MITIA Failed > The well is scheduled for a rig workover to replace the tubing. > > Please call if you have any questions > Joe > Joe Anders, P.E. / Kevin Yeager > Well Integrity Engineer > BP Exploration Alaska, Inc. > (907) 659 -5102 > email: GPBWelllntegrityEngineer @bp.com 1 r y ( 0 .., '.‘•c'.' .p.,..,0,•,:....fi• -.t.',--:, 3 z w �, � d i ate* �`iy3 _ x -3 f q � ,d y 't • k b' £ a P az y :�a � t+ � _ ' i . a b ^ 'P .t' .:-.......":,..."..1:1.",..„,;;.::,:_,.,1,:i..:,:,,,,,,,,:,,,,,,,,,,,„,,,,,-. ' -. . S MICROFILMED 7/30/02 • DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Sav as M : /weepie/microfilm marker. GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al'tN: Sherrie NO. 121291 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 3/20/00 Well Job # Log Description Date Blueline Sepia Color CD Prints R-15A t,,,.~.r.... ~ °tM~. '"l, ci' 20113 U$1T PDC/GR 990428 1 R'15A ,].,,, ~ C~"1. % 99273 MCNL 990614 1 1 S-25A .~C~q'T"l 20030 RST 990929 i 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: . BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotectnical Data Center MB3-3 3940 Arctic Blvd, Suite 300 900 E. Benson Blvd. Anchorage, AK 99503-5711 Anchorage, Alaska 99519-6612 RECEIVEDM ~- 8 2~000 A1ZN'. Sherrie Date Delivered'. Received b Alaska 0il & Gas Cons. C;ommission Anchorage GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 121273 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 3/10/00 Well Job # Log Description Date Blueline Sepia Color CD Prints S-25A I~ ~-- LEAK DETECTION LOG 000306 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Schlumberger GeoQuest Petrotectnical Data Center MB3-3 3940 Arctic Blvd, Suite 300 900 E. Benson Bivd. Anchorage, AK ,9-9~03-5711 Anchorage, Alaska 99519-6612 RECEIVED A'FI'N: Sherrie Date Delivered: ~A~ "~ ~00~ Received b~~ ~ ~ -- Alaska Oil & Gas Co,Is. Commission Anchorafle STATE OF ALASKA ALASk~?iL AND GAS CONSERVATION COM,.~..~.:;.SION 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 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 ,. 4. Location of well at surface ~' ,,// ',/' 1633' SNL, 1120' EWL, SEC. 35, T12N, R12E, UM At top of productive interval 39' NSL, 1465' EWL, SEC. 26, T12N, R12E, UM At effective depth 756' NSL, 3312' EWL, SEC. 26, T12N, R12E, UM At total depth 791' NSL, 3514' EWL, SEC. 26, T12N, R12E, UM t5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service ;6. Datum Elevation (DF or KB) KBE = 65.76' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-25Ai 9. Permit Number 198-214,-/ 10. APl Number 50- 029-22077-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11691 feet 9006 feet 11485 feet 9018 feet Length Size Plugs (measured) Junk (measured) Cast Iron Bridge Plug Set at 11485' (11/98) Cemented MD TVD 110' - 20" x 30" 2642' 13-3/8" 3291 cu ft Arcticset I & II 9111' 9-5/8" 1865 cuft Class 'G' 253' 7" 263 cu ft Class 'G' 2638' 2-7/8" 140 cuft Class 'G' 110' 110' 2674' 2674' 9141' 8781' 8912'-9165' 8582'-8801' 8916'-11554' 8586'-9016' Perforation depth: measured 11364' - 11434' true vertical 9018' - 9018' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 8974' RECEIVED DEC 0 7 2000 Alaska Oil & 0as Cons. C01TIFi1JSsJ0t~ Anchorage Packers and SSSV (type and measured depth) SSSV Landing Nipple at 2092'; 9-5/8" Baker Packer at 8885' 13. Attachments [] Description Summary of Proposal 14. Estimated date for commencing operation December 13, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Barbara Holt, 564-5791 [] Detailed Operations Program [] BOP Sketch I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection (Converting to WAG Injection Post RWO} Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that t.,h.¢ foregoi..qg is true and correct to the best of my knowledge / ~ /. ¢ ,, --, S,gned' ~j/ -'~ ~.,,~¢ Title Senior Drilling Engineer Date //---¢//~//'~ Dan Ston%/7 ~~ ./' Conditions of Approval: Notify Commi§sion so representative may ~iiness ........... ' ................ j _ ~' ' ,., : of',-z"x Plug integrity__ BOP Test ~. Location clearance I Approva~ No.. - Mechanical integrity Test .'~. Subsequent form required 10- ORIGINAL SIGNED BY Date; Approved by order of the Commission D T~ytor ,~fmmn~mt Commissioner Subm In Triplicate Form 10-403 Rev. 06/15/88 ~ j ~ i [Q jj ~ j'A.l Project Scope: The project scope includes pulling the existing 4-1/2" completion, which has a tubing patch stuck at 7030' MD, and recompleting the well with 4-1/2" L80 NSCT tubing and a stacker-packer assembly. Pre-Riq Work 1. Pull bottom GLV at 7016' and circulate the well with seawater. 2. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the 9 5/8" packoff tests, completely back out and check each 9-5/8" and 4-1/2" lock down screw for breakage (check one at a time). If tested recently, e-mail or fax in test report. 3. Load tubing with two tubing volumes of seawater at max rate to sweep gas followed by 150 bbls viscous fluid (FIo-Pro or Equivalent). 4. Freeze protect tbg & casing with diesel from 2000' to surface. 5. Set a BPV and remove wellhouse. 6. Clear and level pad in preparation of the rig move. Assure annuli are freeze protected. Ri.q 1. Workover Procedure (11.5 days) MIRU. ND tree, NU and test BOPE. Circulate out freeze protect fluid and circulate well to clean seawater through GLM @ 7016'. (1 day) 2. PU 2-3/8" H-I- SLH-90 drill pipe and fishing BHA. RIH and jar setting tool free from tbg patch. (1 day) 3. POH and LD fish. (1/2 day) 4. RU e-line. RIH and chemical cut tbg 5 ft below GLM #3 (top of GLM @ 7016'). RD e-line. (1/2 day) 5. Pull 4-Y2" tubing down to the tubing cut @ 7031'. (1/2 day) 6. RIH w/3-1/2" drill pipe and 60' of washpipe and an outside cutter to cut the tbg below the patch at 7090'. (1 day). 7. Fish tbg w/obstruction. (1/2 day) 8. RIH w/4 1~,, tubing with overshot. (1 day) 9. RU e-line. RIH and chemical cut tbg @ 8867' 10 ft above the SWS nipple. (Top of SWS nipple @ 8877'). RD e-line. (1/2 day) 10. POH. LD fishing assembly and cut tbg. (1 day) 11. RIH w/9-5/8" Retrievable packer and test 9-5/8" casing to 3000 psi for 30 minutes. (1 day) 12. Run new completion of 4-1/2" L80 NSCT. (1-1/2 day) 13. RU slickline and make drift run in tbg. Run RHC sleeve. (1~ day) 14. Drop ball and set stacker- packer near 8835' 15. Freeze protect permafrost zone thru top GLM. (Y2 day) 16. Set BPV, ND BOPE, NU and test tree. RDMO. (1/2 day) Post Riq Procedure 1. Install flow line and Reset wellhouse. 2. RU slickline and retrieve RHC sleeve. 3. Replace RP shear valve with dummy gas lift valve. RECEIVED D£¢ 0 7 2000 Alaska Oil & Gas Cons. Commission Anchorage WELLHEAD: 13-5/8" 5M FMC ' BF. ELEV = 36.15 ACTUATOR: OTIS '~l SSSV LANDING NIPPLE 12,092, Open ~ ~ ~ (OTIS)(3.8131 D) Annulus 13-3/8", 68#/ft, k GAS LIFT MANDRELS NT-80CYHE, BTRS OTIS W/1-1/2" RA LATCH) No MD(BKB) TVDss DEV IKOP: 5000 MAX ANGLE: °28 5 3102 3036 0 4 5217 5149 10 3 7016 6812 24 4-1/2", 12.6#/ft, L-80, TDS r~'~ I ~ 2 8622 8258 27 NON-IPC TUBING'~[I 1 8848 8459 27 TUBING ID: 3.958" ~ ..-~- CAPACITY: 0.0152 BBL/FT 4-1/2 .... sws" N~PPLE I 8,877 /'- (PARKER) (3.813" ID) B~ERTUB~NG I 8,882 ANCHOR Liner-2 7/8"6.16 #/ft, L-80, ST-L /' _ 9-5~8" PACKER BOdYcapacity:lD-2.441"0.0058TJ ID-2.37"bbl/ft ~' r ~;~ ~ (Baker)(3.99" ID) I s,ss I Liner Top @ 8916' ~ -.,~ i -- 4-1/2", ,"SWS" NIPPLE I 8,94 I I ~,PARKER, (3.813" ID) I ~ 4-1/2" "XN" NIPPLE (ELMD) I 8,080 I W"ipstock Top - 9162' ~ RA Marker- 9171' 7"26 #Iff. L-80 Liiner -r'O~/- qleS' ~'~_ I(Permenantly Aband°ned) Survey Depth Angle ~ -~-~:.~ S--~ 9162 31.6 i PORTIONS OF THIS WELL'S I 9286 49.6 i FLOWLINE ARE 3" AND ! 9341 64.4 : I SUBJECT TO EROSION. THE GC 9393 79.7 SHOULD BE NOTIFIED OF ANY 9654 88.9 i WELL OPERATION WHICH : I COULD INCREASE THE FLOW i - PERFORATION SUMMARY I OR EROSION RATES. REF: LOG: Baker MWD Resistivity I SIZE SPF INTERVAL OPEN/SQZ'D ! i [ ICast Iron Bridge Plug - Top @ 11485' 2.00 4 11364-11434 Open PBTD DATE REV. BY COMMENTS PRUDHOE BAY UNIT o8-17-9o H F ORIGINAL COMPLETION WELL: S-25 (24-26-12-12) 11-98 CT Sidetrack APl NO: 50-029-22077-01 1-20-99 GEM Update to PC SEC 35; T12N; RG12E BP EXPLORATION (ALASKA) Survey Depth Angle 9162 31.6 9286 49.6 9341 64.4 9393 79.7 9654 88.9 SIZE SPF INTERVAL OPEN/SQZ'D 2.00 4 11364-11434 Open BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 9, 1999 Mr. Robert Christenson Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Request to Commingle Test Production from S-200 andW-20OWells :~:-:~' Dear Chairman Christenson: As you are aware, BP as PBU WOA Operator on behalf of the lease owners, has drilled two Schrader test wells in the PBU WOA and requested approval of a Pilot Production Plan. S-200 (aka SB-01) bottomed on T12N-R12E UM Sec. 27 within ARCO/Exxon lease ADL 28258. W- 200 (aka SB-02) bottomed on Sec. T11N-R12E Sec. 21 within Mobil/Phillips/Chevron lease ADL 28263. Both wells have been briefly tested from various Schrader Bluff formation intervals, but additional appraisal completion or testing work remains to be performed before the pilot period. Both wells will be completed in the Schrader Bluff formation, no approval is requested for downhole commingling with formations other than the Schrader Bluff. The wellwork is expected to be performed in September and October 1999. Production testing is not expected to exceed seven days per well. Consistent with existing practices, BP requests approval by the AOGCC on behalf of ARCO/Exxon and Mobil/Phillips/Chevron to commingle production with other pools for processing at PBU Gathering Center 2 during the testing period. Production allocation will be based on the existing well test methodology approved by the AOGCC, based on well tests conducted at S and W pads. Similar approval was granted by letter of 12/18/97. BPX will undertake to advise the Division of the status of well operations in a timely manner. If you have any questions, please contact Steve Deckert at (907) 564-4128. Sincerely, Central North Slope- Western Developments CC~ K. Boyd - Department of Natural Resources M. Evans - Exxon Company, U.S.A. W. Fennell- Chevron U.S.A., Inc. J. Hollier- Mobil Exploration & Production U.S., Inc. J. Johnson - Phillips Petroleum Company J. Pilkington - Department of Revenue G. Pospisil - ARCO Alaska, Inc. State of Alaska, AOGCC Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: S-25AI Field: County: State: Prudhoe Bay Unit North Slope Alaska Date: 01/27/99 API No: 500292207701 BHI Job#: 102275 Enclosed is the following data as listed below: Log Type Bluelines Navig~mma USMPR MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navig~mma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks : LIS Verification Report & Listings : Depth Shift Monitor Plot : Upon Receipt, Please sign and return to: Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, ~~~. Anchorage, Alaska__~~SD~ 0 ] ]~ ~ec · D~aO~!~ State of Alaska, AOGCC Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: S-25AI Field: Prudhoe Bay Unit County: North Slope State: Alaska Date: 01/27/99 API No: 500292207701 BHI Job#: 102275 Enclosed is the following data as listed below: Log Type Bluelines Navig~mma USMPR MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navig~mma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks : LIS Verification Report & Listings : Depth Shift Monitor Plot : Received Upon Receipt, Please sign and fax to' Baker Hughes INTEQ State of Alaska, AOGCC Lori Taylor 3001 Porcupine St. Anchorage, AK 99501 Well Reference Data: Well No: S-25AI Field: Prudhoe Bay Unit County: North Slope State: Alaska Date: 01/27/99 API No: 500292207701 BHI Job#: 102275 Enclosed is the following data as listed below: Log Type Bluelines Navig~mma USMPR MDL/MNP DPR/MDL/MDP TOTALS: Log Type Navig~mma USMPR MDL/MNP DPR/MDL/MDP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks : LIS Verification Report & Listings : Depth Shift Monitor Plot : Upon Receipt, Please sign and return to: Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 9~~6~2~.~, :i~-~? ~ OF:III--I--lNG To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 January 27, 1999 MWD Formation Evaluation Logs S-25A& S-25APB1 AK-MW-90015 S-25A: 2" x 5" MD Gamma Ray Logs: 50-029-22077-01 2" x 5" TVD Gamma Ray Logs: 50-029-22077-01 S-25A PB1: 2"x 5"MD Gamma Ray Logs: 50-029-22077-70 2" x 5" TVD Gamma Ray Logs: 50-029-22077-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A'ITACHED COPIES OF THE TRANSMITYAL LETTER TO THE ATYENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED AJa~,a Oit & Gas Cons.~n Anohomge BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Si 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALASK/ !LAND GAS CONSERVATION COMM' ION WELL COIVi~:"-ETION OR RECOMPLETION REPORT'-~.:',ID LOG CT Sidetrack well "i'. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. ~.l ~,~9 98-214 3. Address ~,~.~ 8. APl Number P.O. Box196612, Anchorage, Alaska 99519-6612 50-029-22077-01 4. Location of well at surface i ~--' ::': .,v ....... ~~~-.~.--~ 9. Unit or Lease Name Prudhoe Unit 1633'SNL,4158'WEL,SEC. 35, T12N,R12E/x¢,,~.~ ''%~:~ :"';¢".,j:k~'I '.2_'~ ~.~¢ ~ Bay At top of productive interva 10. Well Number 5243'SNL,3814'WEL, SEC.26,T12N,R12E S-25Ai 523' EWL, Sec 26, T12N, R12E :' 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay 51 Elevation' in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KEF=e5.75, ADL 028257 12. Date Spudded 113. DateT. D. Reached I 14. Date Comp., Susp., or Aband. 115. Water depth, ifoffshore 16. Ne. of Completions 11/6/98 11/21/98 11/23/98 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional SurveyI 20. Depth where SSSV set~l. Thickness of Permafrost 11691 8932 FT 11487 8942 FT [~ Yes [] No I 2092 MD ! 1900' (Approx.) ........ 22. Type Electric or Other Logs Run GR Resistivity/GR 23. CASlNG~ LINER AND CEMENTING RECORD CASING SE-I-FIN(:. DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-I-I'OM SIZE CEMENTING RECORD AMOUNT PULLED 20X30 Surface 110 13-3/8" 68# L-80 Surface 2674 17 1/2" 3291 cu ft Arctic Set 9-5/8" 47# NT80S Surface 9153 12-1/4" 1865 cu ft Class G 7" 26# L-80 8912 9650 8-1/2" 263 cu ft Class G 2-7/8" 6.16# L-80 8916 11691 3-3/4" 140 c.f. 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD ..... and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 8974 MD TVD 11364-11434 8943-8942 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ....... ,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/21/98 PW Date of Test Hours Tested PRODUCTION OIL-BBL GAS-MCF WATER-DEL CHOKE SIZE tGAS-OIL RATIO I FOR TEST Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RA-~E 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 ORIGINAL Submit In Duplicate 29. Geologic Markers ..... 30. '. .... Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag 9144 8783 Shublik 9190 8822 Zone 4 9267 8888 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby c~ify that the foregoing is true and correct to the best of my knowledge Signed TheresaMi,,s Title Coiled Tubing Drilling TA Date Q.-. Prepared By Name/Number: Theresa Mills 564-5894 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'. ~[..C~!~ ~'~ Form 10-407 Rev. 07-01-80 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs January 20, 1999 S-25A PB1 AK-MW-90015 1 LDWG formatted Disc with verification listing. API#: 50-029-22077-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING TIlE ATrACHED COPIES OF THE TRANSMITF~ LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Alasba Oil & Gas C(ms.~n BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signed:~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company CI I~! I I_L_ I N CS S ~l~l~JI r- ~ S WELL LOG TRANSMITrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs January 20, 1999 S-25A AK-MW-90015 1 LDWG formatted Disc with verification listing. API#: 50-029-22077-01 PLEASE ACKNOWLEDGE RECEIVF BY SIGNING AND RETURNING THE ATFACHED COPIES OF THE TRANSMITTAL LETTER TO THE A~ITENTION OF: Sperry-Sun Drilling Services Atto: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED AlaskaOil & C~s Cons. ~n BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 9951945612 Sign 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: 5herrie NO. 12224 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1/12/99 Field: Prudhoe Bay (Cased Hole) Color Well Job # Log Description Date Print Blueline Sepia LIS Tape H-30 99009 USIT 971126 1 R-03A CBT 981007 1 1 W-200 PRODUCTION LOG 981221 1 1 Q-02A (REDO) MCNL ~ ~'~'~ 970825 ! 1 1 REDO-TO SHIFT TO MWD-GR BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E, Benson Bivd, Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: ,IAgl 'i~lQOo Alaska Oil & Gas Cons, Commission Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AWN: S~-. 198-214-0 PRUDHOE BAY UNIT S-25A 50- 029-22077-01 BP EXPLORATION (ALASKa) ]NC Roll #1: Start: Stop Roll #2: Start Stop MD 11691 TVD 08932 Completion Date: 11/23/98 Completed Status: 1WINJ Current: Name Interval Sent Received T/C/D c 9477 D 8837 D 8838 D 8873 L DGR-MD L DGR-MD L DGR-TVD L DGR-TVD L INJP-PNL/B L LEAK L RES/GR-MD L RES/GR-TVD R SRVY LSTNG R SRVY LSTNG 1 SCHLUM RST 1,2,4 SPERRY GR PB 1 1-13 SPERRY GR BH PROP RES/GR FINAL 9167-11691 FINAL 9167-9755 PBI FINAL 8737-8928 FINAL 8737-8870 PB1 FINAL 8700-11460 FINAL 400-8900 FINAL 9172-11553 FINAL 8741-8942 BI-II 9095.95-11691. BHI 9095.95-9755. PB1 CH 3/20/00 3/28/00 OH 1/20/99 1/20/99 OH 1/20/99 1/20/99 OH 1/27/99 1/29/99 OH 1/27/99 1/27/99 OH 1/27/99 1/27/99 OH 1/27/99 1/27/99 OH 1/27/99 1/27/99 CH 5 3/20/00 3/28/00 CH 2/5 3/10/00 3/14/00 OH 1/27/99 2/1/99 OH 1/27/99 2/1/99 OH 1/20/99 1/22/99 OH 1/20/99 1/22/99 Tuesday, January 09, 2001 Page 1 of 1 WELLHEAD: 13-5/8" - 5M I SSSV I_ANDING NIPPLE I 2,091 Open 13-3/8", 68#/ff, ~J k GAS LIFT MANDRELS NT-80CYHE, BTRSI"-~-~- I - (t')TIS W/1-1/?" ~A I ATC. H~ DEV KOP: 5000 MAX ANGLE: 028 5 3102 3036 0 4 5217 5149 10 3 7016 6812 24 : 4-1/2", 12.6#/ft, L-80, /' 2 8622 8258 27 TDS TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 4-1/2 .... SWS" NIPPLE I 8,877 ; .~~ 9 BAKER TUBINGt 8,882 Liner-2 7/8" 6.16 #/ft, L-80, ST-L ' -5/8" PACKER Body ID-2.441" TJ ID-2.37"~ r~;~ ~ (Baker)(3.99"1D)I 8,884 Capacity: 0.0058 bbl/ft ~]..__.-.--~'""""4-1/2'" 12.6 #/ft, L-80 TAILPIPE Liner Top~ 8916' : 4-1/2 .... SWS"NIPPLE I I "~ ~(PARKER) (3.813" ID)I 8,940 TOP OF7" L,NERIS,$09 I ~: ",~ ~ 4-1/2 .... XN" NIPPLE ::i! ::?, (OTIS) (3.725" ID) 9-5/8", 47#/ft, i8,730 l~' ii:':i:i [' 4-1/2"WLEG 18,973 ":" (E L M D) I 8,980 I Whipst°ckT°p-9162' ~i ~ RA Marker - 9171' 7" 26 #/ft, L-80 Liiner (Permenantly Abandoned) PERFORATION SUMMARY REF: LOG: Baker MW D Resistivity SIZE SPF INTERVAL OPEN/SQZ'D 2.00 4 1364-11434 NOTE: 3" FLOWLINE IN SKID PORTIONS OF THIS WELL'S FLOWLINE ARE 3" AND SUBJECT TO EROSION. THE GC ! SHOULD BE NOTIFIED OF ANY WELL OPERATION WHICH NORIZONTAL COMPLETION ~ I 11487'1 I:~i~ ~CastlronBridgePlug-Top@ 11485' TD I ~1691,1 '- DATE REV, BY COMMENTS PRUDHOE BAY UNIT 08-17-90 H F COMPLETION WELL: S-25 08/19/92 M BW RE-PERF 7-1-93 J. Eckstein Add Sa.q River Perfs APl NO: 50-029-22077-01 7-7-95 MFH Reperf 9310'- 9370' SEC 35; T12N; RG12E 1-6-96 SFM Update Well Bore Dia with CT,.,.~ EXPLORATION 11/98 CT Sidetrack Well' S-25Ai Accept: 11/6/98 Field: Prudhoe Bay Spud' 11/9/98 APl: 50-029-22077-01 Release: 11/24/98 Permit: 98-214 CTD Unit: Nordic #1 Date Day Depth 11/6/98 Move DS/N #1 from S-31ai to S-25. Spot over well. RU misc equipment. RU hardline to slop tank. Begin NU BOPE. 11/7/98 Accept rig at 0630 hrs 11/6/98. NU BOPE. Perform initial BOP test. Install Baker CTC. Fill CT with SW and pump dart thru new CT. Check well for pressure, none. MU milling assembly. RIH with BHA #1 (dimple mill and flexjt). Mill XN nipple at 8968'. RIH and tag cement at 9144' CTD. Drill cement and mill window to 9167' CTD. POOH for second milling assy. RIH with BHA #2 (dia mill and string reamer). Attempt to dress window, but made no progress past 9167'. POOH for mill/motor. RIH with BHA #3 (3.65" formation mill and string reamer). 11/8/98 3 Dress window with formation mill and string reamer. About 2' of reservoir drilled. Swap to mud. POOH. MU drilling assembly (BHA #4:2.0 deg motor; M-09 bit). RIH. Tag TD at 9167' est (electronic counter malfunction). Clean through window. Drill 9167' - 9234'. Not getting required build. POOH for motor. Tie-in at window, add 8.0'. Change out bit, motor and MWD tool. RIH with BHA #5 (2.3 deg motor). Drill in Shublik from corrected TD to 9275'. Drilling ahead 11/9/98 4 9375 Drill build 9275'- 9375'. Landed. POOH. MU BHA #~ (1.0 deg motor; DS49 bit). RIH. At 9248' bit depth, coil split at weld just as it was coming off reel. Secure coil, align ends, weld split sleeve on coil. POOH. LD drilling BHA. Blow down reel with N2. Remove reel for transport. Install used reel. Pull CT to rig floor. 11/10/98 5 9755 Hold safety meeting. Pull CT to floor. Stab pipe. MU BHA #7 (w/shock sub, 1.0 deg motor, DS49). RIH and tie-in. Drill 9375' - 9475'. Bumped into base of Shublik. Orient to drop and drill 9475'- 9570'. Turn TF right. Started losing about 0.3 BPM (geo says fault). Drill 9570'- 9704'. Backream to window. Had trouble getting back thru 9460'. Drill from 9704- 9755' where losses immediately increased to 1.4 BPM. Backream to window while WO mud. Discuss. POOH to plugback. LD drilling BHA. Static losses were 0.7 BPM. Rehead CTC. RIH with BHA #8 (BPX cementing dart catcher on two its tubing). Losses still 0.7 BPM static. RIH and couldn't get past planned kickoff point at 9350'. PUH 20k over to 9250'. Packing off. PUH to window to pump cement. Circ, wo cementers. 11/11/98 6 9260 With nozzle at 9190', pump 9 bbls cement, load dart, chase with 4 bbls H20 and mud. Returns at 25%. Adjust choke to bullhead cement into open hole. Shear dart seat. Returns improved to 80% circ and 100% filling but cement gone. RIH clean to 9350' and sat down in Shublik. No cement in returns. RU cementers again. Lay in 10 bbls cement from 9350' - 8975' at nearly full returns. Pull to safety. Returns at 100%. SI choke and pressure well to 350 psi -- no losses. Wash excess cement to 9180'. PUH and check returns. Est 2 bbls cement lost to fault. POOH. LD cementing BHA. MU CTC. MU drilling BHA. RIH with BHA #9 (2.0 deg motor). Tag cement at 9184'. Orient to Iow left and search for hard cement. Drill medium firm cement to 9231' until stall. On depth with RA marker, returns 1/1. Begin kickoff at 9231' and drill 150L until 9245'. Orient and drill in stages to resume build to 9260'. 1/12/98 7 9411 Drill to 9292'. Need more build. POOH for motor. MU BHA #10 w/2.5 deg motor. RIH to TD. Drill 9292' - 9411'. Landed. Project 85 deg at 8871' TVD in Zone 4 at bit. POOH. LD BHA. Blow down coil with N2. Swap reels (525,000 RF on used reel). Fill CT with mud. Pump dart and seated at calc displacement. MU drilling BHA. 11/13/98 8 9620 RIH with BHA #11. Drilled 9414' - 9572'. Hit fault and lost returns. PUH and monitor-- returns improved to 50%. Drilled 9572'- 9620'. Stable losses. POOH filling. LD drilling BHA. MU BHA #12 (cement nozzle). RIH to TD. BJ mix 19.5 bbls Magne Plus cement at 13.0 ppg (9.5 neat, 10 w/5#/bbl Perfect Seal). Displace with 4BW and rig mud. Lay cement from TD to window with partial closed choke. Close choke and displace Perfect Seal to loss zone. Check returns and were 1/1. POOH for drilling BHA. Perform weekly BOP test. MU drilling BHA. RIH with BHA #13 (1.1 deg motor). Tag cement in 7" liner at 9140'. Drill thru firm Magne Plus to window. Work thru window (1 hr). Get thru at 19R. Drill firm cement to 9177'. Orient to stay in original hole. 11/14/98 9 9844 Drill/wash Magna Plus LCM 9177'- 9568'. Started seeing some losses (0.5 BPM). Drill Magna Plus to TD at 9620'. Drill new hole 9620' - 9814'. Hit second fault. Losses 100% at 2.5 BPM. Drill to 9844'. POOH. LD drilling BHA. Losing 1.0 BPM static. MU cementing BHA (2 jts tbg w/noz). RIH with BHA #14 to TD. Hole is clean. DS pump 15 bbls Magne Plus cmt (5 bbl neat, 10 bbls w/5#/bbl Perfect Seal). Displace with mud. Lay neat in open hole from TD to 9530'. Close choke and hold 500 psi WHP as cement was displaced. POOH to safety. Monitor returns at 0.5/0.2 and 1.0/0.7 BPM in/out. Discuss. POOH for drilling BHA. LD cementing BHA. Check loss at 0.1 BPM static. MU drilling BHA. RIH with BHA#15 (0.9 deg motor). 11/15/98 10 10072 RIH with drilling assembly, returns at 80%. Sat down at 9570'. Punched through. Wash to TD. Drilled 9847' - 9920', returns at 70%. Near next fault. Decide to deal with existing losses now. POOH. MU cementing BHA. RIH. RU BJ. Safety meeting. Mix and pump 2 bbls H20, 4 bbls neat Magna Plus, 7 bbls Magna w/8 ppb perfect seal, 3 bbls H20. Lay in from 9810'- 9110'. Pull to safety. Circulate at minimum rate. Drank it all. No apparent improvement. POOH. LD cementing BHA. Static loss at 0.3 BPM. MU drilling BHA. RIH w/BHA #17 (0.9 deg motor). Tie-in with flag. RIH thru window and precautioary ream to TD. Washed Magne Plus from 9680' to TD. Drill ahead at 88 deg/8903' TVD losing 0.4 BPM to 10037'. Backream to window. Drill from 10037-10072' with losses steady at 0.6 BPM at 2.4 BPM. 1t/16/98 11 10317 Drilled horizontal 10,072' - 10,260' with steady losses (2.4 BPM in; 1.7 BPM out). Wiper trip to window. RIH. Tight in shale at 10050'. Drilled 10260-317' (2.5/1.8). Can't get survey, losses excessive. POOH to pump LCM pill. LD drilling BHA. MU cementing BHA. RIH with BHA #18 (2 jts tbg w/nozzle) to 10000' (above sticky shale). DS mix and pump 15 bbls 11.5#/gal bentonitic cement (5 B neat, 10 B w/5#/bbl Perfect Seal, 4 BW). Displace to nozzle and lay in open hole from 10000-9400'. Adjust choke to put into loss zones. Check returns at 1/1. POOH for drilling BHA. LD cementing BHA. MU drilling BHA. Hole staying full. RIH with BHA #19 (0.8 deg motor). Tie-in to flag. RIH thru window and ream at 1.8 BPM while circ mush from 9460' to 10000' with full returns. RIH to 10041' and work to get thru shale 10027-60' w/o success. Backream to window to clean up hole, losing 0.2 BPM. RIH to 10025' and resume working thru shale. Get thru, backream to clean it up (2.2 BPM in, 2.0 BPM out). 11/17/98 12 '10535 Continue reaming in hole 3 times 10020 - 10243. Fight shales 10248, 10297. Drill 10319' - 10383'. Having trouble with MWD stability. Make wiper trip to window. Tie-in to RA tag at 9171 ', Correct by +3ft. Drill 10386' - 10411 '. Having trouble with orientor. Loss rate increased to 0.6 bpm while 20 - 30ft off bottom. Surface lines blocked with returns. Drain Pit 3 and clean solids. PUH above window and blow through surface lines. Found several holes in fine mesh on screens. Install new mesh. Check out orientor above window. Working 5 times, then 2 failures. Complete checks on power pack charge pressures. Decide to run in and drill more hole to confirm losses before POOH. Drill 10412 - 10433'. Getting fine magnaplus cement in returns. Losses healed to 0.4 bpm. POOH for new orientor. Change bit and orientor, drop stabilizer, add shock sub. Minimal fluid loss while CCH. RIH with BHA #20 (0.8 deg motor) clean to 10250'. Work to get thru shale from 10240-270' (1.5 hrs). Drill from 10433-535'. Attempt survey-nope. Backream to window. Losing 0.3 BPM. 11/18/98 '13 '1 '1069 RIH. Work through shales at 10250'. Orient and drill from 10535 - 10650'. Make wiper trip to window. Tie-in to RA tag at 9171 '. Correct by + 1.5ft. Drill from 10652 - 10765'. Losses temp inc to 0.5 bpm. Make wiper trip to window. Seeing some white clay in sample from 10680 area. Tie-in to RA tag @ 9171'. Correct by + 2ft. Ream in hole. Sticky through 10250. Ream up and down. Drill 10767 - 11069 w/shod trips. Losing 0.3 - 0.5 bpm. Pipe stuck at 11069'. Work pipe ane spot dead crude. 11/20/98 15 11691 Change out Orientor, MWD tools, Motor. TIH, GR Icg for correlation, correct depth (-3'). Tag up at 10265', orient and work thru tite spot. Drill ahead, have to pump up surveys-survey quality questionable. Losses increased at +/-11600'. Drill ahead to 11691 '. Discuss options with town. Decide to POOH for cementing BHA. RIH with combo cementing nozzle. Lay 36 bbls of G plus bentonite with 12ppb Perfect Seal in lead 10 bbls. Injectivity checked at 0.8 bpm @ 450 psi WHP on neat FIoPro. Displace cement with chokes closed and open chokes when first pressure spiked to 100psi, at 2 bbls out of nozzle. Lay in remainder of cement and POOH to above window. Ramp pressure to 500 psi. Pressure fell off to zero in 5 minutes. Hesitate 30 mins. Pressure to 680 psi, and pressure fell to zero in 15 minutes. Injectivity checked at 0.2 bpm at 480 psi. Jet wash over whipstock and down into open hole. POOH. Losses healed to <0.2 bpm at normal circulating pressure. 11/2'1/98 '16 1 '1550 PU Bit and Motor, wash in hole to clean out LCM cement. Hole tite at 10050', 10256', 10265', 10275'. Work and wash thru tite hole to clean up. Shod trip from 11175', hole clean. Wash to 11550', losing <0.2 bpm. POOH. LD 2its pipe. Rerun bit and straight motor. RIH Baker Inteq MWD with MPR package (Multiphase Resistivity) with orienter left out. Tie-in to RA tag at 9171 '. Correct by - 2.5ft. Log down at 180ft/hr 11/22/98 17' Run Baker-lnteq MWD Logs (Resistivity/GR). Log down from window to 11554' at 3.0 fpm. Log up from 11554' to 11400' at 6.0 fpm. POOH. LD MWD tools. Data looks stable. MU 81 jts liner with 60 inline turbos and mid joints all the way up. MU Baker LR tools. RIH with liner. Land and dispace mud with 2%KCl water. 11/23/98 18 Displace hole to 2% KCI water. Mix and pump 25 bb115.8 ppg cement, drop dart, pump 2 bbl, check dad is gone-OK. Displace calculated CT volume, no pressure increase. Continue displace to calculated volume to bump Liner Wiper Plug, no pressure increase. Pull out of liner and wash top. Circ. bottoms up while POOH. Saw +/-10 bbl of cement contamination (max. 9.4 ppg). OOH, Liner Wiper Plug was still attached to CTLRT, CT Dad was inside Liner Wiper Plug but wings were torn and body worn fiat from rubbing on wall of CT(indicates wings of CT Dart failed while displacing). PU mill, 1 11/16" motor, and 1 ¼' CS Hydril pipe. TIH, wash into liner to 11487' PBTD. Appeared to be hitting cement stringers last 50'. POOH. Attempt to PT liner. Injecting 0.6 bpm @ 2250 WHP. LD CSH. MU Baker stinger assembly to test inside top of 2.7/8 liner. RIH with stinger. 11/24/98 19 RIH with liner test stinger. Set down 10k on liner top. Attempt to pressure test inside 2.7/8 liner without success. PT external 2.7/8 liner top to 2300psi. Injectivity is steady at 0.6 bpm (~ 2300 psi. POOH. MU cast iron bridge plug. PU 1.1/4" CS Hydril. RIH and set down on float shoe at 11487'. Pump ball and shear setting tool at 3550 psi. PU free of ClBP. Set down solid. Top of ClBP = 11485 ft BKB. PT liner to 2200 psi and chart. Good test. POOH. LD ClBP setting tools. MU SWS guns with 70' loaded. MU CSH workstring. RIH and tag top of ClBP and correct to 11485' BKB. Load ball. PU and position gun with Top Shot at 11364', Bottom Shot at 11434' BKB. Pump ball with excessive CT pump pressure indicating a blockage in the string somehwere. Ball was late at 68 bbls and pressure increase was slow. Firing head sheared at 4200psi. Good signs of firing. Wait on bottom 5 mins. No obvious sign of fluid loss. PU through liner with no problems. POOH. 11/25/98 20 OOH. LD guns. All shots fired. TIH to 2000' and freeze protect tubing w/50-50 MeOH, top 100' pure MeOH. Purge CT w/N2. Clean pits, ND BOP. Perforated Interval: 11,364' - 11434' Release Rig: 11/24/98 19:00 hrs J JJJJJJ J J JJJJJJ J~~JJ~JJJJJ BP Exploration, Inc. Well: S-25Ai & S-25Apb Prudhoe Bay North Slope, Alaska Rig: Nordic #1/CTU #7 End of Well Survey Report Provided in: True - Grid - ASP BHI Rep: M. Miller, H. Wagoner Job Number: AFE Number: 1O2275 4P1213 Reviewed by: BAKER HUGHES INTEQ B.P. Exploration Structure · Pad S Field · Prudhoe Bay Well · S-25 Location · North Slope, Alaska East (feet) -> 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 ,.3000 I 1 I I I I I I I I I I t I I I I I I I I I I I I I I I I I I I I ~ I 8250 - 8400 8550 0 8700 > 88~o F-- 9000 I 9150 IP - 9095.95 MD, 8676.35 Tvd P - 9170 MD, 8759.63 Tvd _ TIP - 9095.95 MD, 8676,35 Tvd i i I I i I i i i i i i i I i i i i I i ii i II i it I I I i I I I I I I ii i 150 0 150 300 450 600 750 900 1050 1200 1350 1500 1650 1800 1950 21 O0 2250 2400 2550 2700 2850 Vertical Section (feet) -> Azimuth 65.16 with reference 1592.77 N, 280.64 E from S-25 3000 2800 26O0 24oo 2200 2000 1800 1600 1400 B.P. Exploration Pad S S-25Ai S-25 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : S-25Ai Our ref : svy381 License : Date printed : 1-Dec-98 Date created : 1-Dec-98 Last revised : 1-Dec-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 618134.580,5981470.630,999.00000,N Slot location is n70 21 12.960,w149 1 52.992 Slot Grid coordinates are N 5979855.000, E 619282.000 Slot local coordinates are 1615.63 S 1147.42 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is Grid North B.P. Exploration Pad S,S-25Ai Prudhoe Bay, North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 9095.95 9162.00 9191.03 9224.43 9231.00 9251.40 9285.68 9314.27 9341.75 9371.91 9393.11 9438.05 9478.85 9511.25 9548.47 SURVEY LISTING Page 1 Your ref : S-25Ai Last revised : 1-Dec-98 R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 30.82 23.00 8676.35 1592.77N 280.64E 1.47 0.00 619562.64 5981447.77 31.63 24.88 8732.83 1624.05N 294.54E 1.92 25.76 619576.54 5981479.05 41.41 23.66 8756.13 1639.79N 301.61E 33.78 38.79 619583.61 5981494.79 47.58 22.67 8779.94 1661.31N 310.80E 18.59 56.17 619592.80 5981516.31 49.29 22.50 8784.30 1665.85N 312.69E 26.10 59.79 619594.69 5981520.85 41.67 21.77 8798.60 1679.31N 318.17E 37.44 70.42 619600.17 5981534.31 49.60 19.42 8822.55 1702.24N 326.75E 23.64 87.84 619608.75 5981557.24 57.44 17.85 8839.53 1724.01N 334.08E 27.77 103.63 619616.08 5981579.01 64.40 16.60 8852.88 1746.93N 341.18E 25.64 119.70 619623.18 5981601.93 74.89 12.85 8863.36 1774.25N 348.32E 36.68 137.66 619630.32 5981629.25 9580.30 9618.13 9654.25 9688.50 9714.15 9755.05 9786.63 9825.40 9865.85 9889.27 9929,17 9964.67 10007.20 10035.10 10067.33 79.74 12.67 8868.02 1794.41N 352.89E 22.89 150.27 619634.89 5981649.41 83.70 18.84 8874.49 1837.18N 364.97E 16.19 179.20 619646.97 5981692.18 84.85 23.07 8878.56 1875.08N 379.48E 10.69 208.30 619661.48 5981730.08 84.84 22.26 8881.48 1904.86N 391.92E 2.49 232.09 619673.92 5981759.86 84.93 23.95 8884.79 1938.95N 406.46E 4.53 259.61 619688.46 5981793.95 85.29 24.13 8887.51 1967.92N 419.38E 1.26 283.50 619701.38 5981822.92 86.87 31.00 8890.10 2001.35N 436.84E 18.59 313.39 619718.84 5981856.35 88.90 33.47 8891.43 2031.88N 456.09E 8.85 343.69 619738.09 5981886.88 88.37 40.51 8892.25 2059.21N 476.68E 20.61 373.85 619758.68 5981914.21 88.11 45.62 8893.03 2077.94N 494.18E 19.94 397.60 619776.18 5981932.94 86.08 50.03 8895.11 2105.35N 524.44E 11.86 436.58 619806.44 5981960.35 87.14 50.73 8896.98 2125.46N 548.72E 4.02 467.06 619830.72 5981980.46 89.26 54.61 8898.19 2148.95N 579.53E 11.40 504.88 619861.53 5982003.95 88.11 58.13 8899.12 2171.34N 613.19E 9.15 544.84 619895.19 5982026.34 87.83 61.01 8899.95 2183.20N 633.37E 12.35 568.13 619915.37 5982038.20 10103.72 10142.85 10178.58 10211.05 10239.38 10297.92 10331.50 10376.70 10411.28 10449.10 89.07 66.59 8901.03 2200.80N 669.15E 14.32 607.99 619951.15 5982055.80 89.69 68.18 8901.42 2214.45N 701.91E 4.81 643.46 619983.91 5982069.45 89.25 73.64 8901.81 2228.35N 742.09E 12.88 685.76 620024.09 5982083.35 88.90 74.35 8902.26 2236.04N 768.90E 2.84 713.32 620050.90 5982091.04 87.93 79.10 8903.15 2243.44N 800.25E 15.04 744.88 620082.25 5982098.44 86.26 81.57 8905.00 2249.54N 836.07E 8.19 779.95 620118.07 5982104.54 83.79 77.34 8908.39 2256.67N 874.39E 12.48 817.71 620156.39 5982111.67 83.88 76.99 8912.23 2264.56N 909.02E 1.01 852.46 620191.02 5982119.56 83.88 75.40 8915.69 2272.26N 940.37E 4.87 884.15 620222.37 5982127.26 84.05 73.47 8918.67 2279.82N 967.51E 6.80 911.95 620249.51 5982134.82 10479.72 10507.17 10567.10 10625.29 10669.57 84.49 69.59 8924.52 2298.27N 1022.75E 6.64 969.83 620304.75 5982153.27 84.05 64.65 8927.87 2311.26N 1053.52E 14.70 1003.21 620335.52 5982166.26 84.49 65.36 8932.38 2330.26N 1094.28E 1.84 1048.18 620376.28 5982185.26 86.50 64.53 8935.10 2344.86N 1125.51E 6.29 1082.65 620407.51 5982199.86 88.11 61.48 8936.88 2362.01N 1159.17E 9.11 1120.40 620441.17 5982217.01 10706.42 10739.52 10795.52 10833.90 10887.82 86.55 56.97 8938.31 2377.65N 1185.44E 15.57 1150.81 620467.44 5982232.65 86.43 57.61 8939.99 2392.46N 1208.49E 2.37 1177.95 620490.49 5982247.46 88.46 60.60 8942.66 2423.19N 1259.86E 6.03 1237.48 620541.86 5982278.19 88.73 65.54 8944.09 2449.53N 1311.71E 8.50 1295.60 620593.71 5982304.53 89.05 71.03 8944.94 2465.90N 1352.82E 12.42 1339.78 620634.82 5982320.90 90.57 73.64 8945.07 2477.09N 1387.93E 8.20 1376.34 620669.93 5982332.09 90.40 75.40 8944.79 2485.92N 1419.83E 5.34 1409.00 620701.83 5982340.92 89.45 79.87 8944.86 2497.91N 1474.51E 8.16 1463.66 620756.51 5982352.91 88.63 83.86 8945.50 2503.34N 1512.49E 10.61 1500.41 620794.49 5982358.34 90.03 90.00 8946.13 2506.22N 1566.31E 11.68 1550.45 620848.31 5982361.22 All data in feet unless otherwise stated. Calculation uses minimum curvatUre method. Coordinates from S-25 and TVD from rkb - MSL = 65.75 ft. Bottom hole distance is 3417.95 on azimuth 43.63 degrees from wellhead. Vertical section is from tie at N 1592.77 E 280.64 on azimuth 65.16 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes !NTEQ B.P. Exploration Pad S,S-25Ai Prudhoe Bay, North Slope, Alaska SuRvEY LISTING Page 2 Your ref : S-25Ai Last revised : 1-Dec-98 Heasured Inc[in Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 10932.92 90.97 90.85 8945.74 2505.89N 1611.40E 2.81 1591.24 620893.40 5982360.89 10961.97 91.19 94.96 8945.19 2504.42N 1640.40E 14.17 1616.94 620922.40 5982359.42 10996.42 92.33 96.55 8944.13 2500.96N 1674.66E 5.68 1646.58 620956.66 5982355.96 11037.27 91.63 102.89 8942.72 2494.07N 1714.88E 15.61 1680.18 620996.88 5982349.07 11095.75 90.00 104.24 8941.89 2480.36N 1771.72E 3.62 1726.00 621053.72 5982335.36 11169.67 88.33 101.12 8942.97 2464.14N 1843.82E 4.79 1784.61 621125.82 5982319.14 11234.79 90.93 99.72 8943.39 2452.36N 1907.86E 4.53 1837.78 621189.86 5982307.36 11272.10 89.78 97.02 8943.16 2446.93N 1944.76E 7.87 1868.99 621226.76 5982301.93 11307.67 90.09 97.28 8943.20 2442.50N 1980.06E 1.14 1899.16 621262.06 5982297.50 11344.72 90.25 93.19 8943.09 2439.13N 2016.94E 11.05 1931.21 621298.94 5982294.13 11387.57 90.31 92.50 8942.88 2437.00N 2059.74E 1.62 1969.16 621341.74 5982292.00 11429.37 90.37 89.34 8942.63 2436.33N 2101.53E 7.56 2006.80 621383.53 5982291.33 11464.91 89.07 92.02 8942.80 2435.91N 2137.06E 8.38 2038.87 621419.06 5982290.91 11499.36 90.93 85.80 8942.80 2436.56N 2171.49E 18.84 2070.38 621453.49 5982291.56 11532.91 92.02 84.85 8941.94 2439.29N 2204.91E 4.31 2101.87 621486.91 5982294.29 11568.33 93.27 82.65 8940.31 2443.15N 2240.08E 7.14 2135.40 621522.08 5982298.15 11604.41 94.33 77.21 8937.91 2449.44N 2275.52E 15.33 2170.20 621557.52 5982304.44 11651.81 94.32 73.18 8934.34 2461.51N 2321.20E 8.48 2216.73 621603.20 5982316.51 11672.36 93.91 71.07 8932.86 2467.80N 2340.71E 10.43 2237.07 621622.71 5982322.80 11691.00 93.54 69.17 8931.65 2474.13N 2358.20E 10.36 2255.60 621640.20 5982329.13 Att data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from S-25 and TVD from rkb - MSL = 65.75 ft. Bottom hole distance is 3417.95 on azimuth 43.63 degrees from wellhead. Vertical section is from tie at N 1592.77 E 280.64 on azimuth 65.16 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration Pad S S-25 S-25 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : S-25Ai Plug back Our ref : svy200 License : Date printed : 18-Dec-98 Date created : 1-Dec-98 Last revised : 4-Dec-98 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 618134.580,5981470.630,999.00000,N Slot location is n70 21 12.960,w149 1 52.992 Slot Grid coordinates are N 5979855.000, E 619282.000 Slot local coordinates are 1615.63 S 1147.42 E Projection type: alaska - Zone 4, Spheroid: Clarke o 1866 Reference North is Grid North B.P. Exploration Pad S,S-25 Prudhoe Bay, North Slope, Alaska Measured Depth SURVEY LISTING Page 1 Your ref : S-25Ai Plug back Last revised : 4-Dec-98 Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing 9095.95 30.82 23.00 8676.35 1592.77N 280.64E 1.47 0.00 619562.64 5981447.77 9162.00 31.63 24.88 8732.83 1624.05N 294.54E 1.92 25.76 619576.54 5981479.05 9170.00 34.32 24.48 8739.54 1628.01N 296.35E 33.73 29.07 619578.35 5981483.01 9191.03 41.41 23.66 8756.13 1639.79N 301.61E 33.80 38.79 619583.61 5981494.79 9224.43 47.58 22.67 8779.95 1661.31N 310.80E 18.59 56.17 619592.80 5981516.31 9269.88 59.49 21.69 8806.91 1695.10N 324.55E 26.26 82.84 619606.55 5981550.10 9304.93 69.43 21.32 8822.00 1724.49N 336.13E 28.38 105.69 619618.13 5981579.49 9332.30 75.95 23.24 8830.14 1748.65N 346.04E 24.74 124.83 619628.04 5981603.65 9362.00 82.74 19.90 8835.63 1775.78N 356.75E 25.39 145.95 619638.75 5981630.78 9371.18 84.85 18.89 8836.62 1784.39N 359.78E 25.45 152.32 619641.78 5981639.39 9406.90 88.19 21.66 8838.79 1817.82N 372.13E 12.14 177.57 619654.13 5981672.82 9436.10 90.84 25.18 8839.04 1844.61N 383.74E 15.09 199.36 619665.74 5981699.61 9466.18 93.74 32.41 8837.84 1870.93N 398.20E 25.88 223.54 619680.20 5981725.93 9516.00 89.96 33.29 8836.23 1912.75N 425.21E 7.79 265.62 619707.21 5981767.75 9534.48 87.14 36.11 8836.70 1927.94N 435.72E 21.58 281.54 619717.72 5981782.94 9568.40 81.94 29.41 8839.93 1956.30N 453.98E 24.93 310.02 619735.98 5981811.30 9621.48 82.03 41.22 8847.35 1999.11N 484.31E 22.03 355.53 619766.31 5981854.11 9655.73 80.88 45.45 8852.44 2023.74N 507.55E 12.67 386.97 619789.55 5981878.74 9696.85 78.06 51.92 8859.97 2050.42N 537.89E 16.92 425.70 619819.89 5981905.42 9726.23 80.79 56.02 8865.36 2067.40N 561.24E 16.57 454.03 619843.24 5981922.40 9755.00 80.79 56.02 8869.96 2083.28N 584.79E 0.00 482.07 619866.79 5981938.28 AIl data in feet un[ess otherwise stated. Calculation uses minimum curvature method. Coordinates from S-25 and TVD from rkb - MSL = 65.75 ft. Bottom hole distance is 2163.80 on azimuth 15.68 degrees from wellhead. Vertical section is from tie at N 1592.77 E 280.64 on azimuth 65.16 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes !NTEQ EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Company: B.P. Exploration Rig: Nordic #1/CTU #7 Job No: 102275 Well: S-25Ai Field: Prudhoe Bay, Alaska AFE No: 4P-1213 Calculation Method: Minimum Curvature Mag. Declination: 27.680 BHI Rep: H. Wagoner, M. Miller Vertical Sect. Plane: 66.060 TRUE Grid Correction: 0.900 Job Start Date: 07-Nov-98 Vertical Sect. Plane: 65.160 GRID Total Correction: 26.780 Job End Date: 19-Nov-98 Measured Depth from: RKB RKB Height: 65.800 True Vertical Depth: Sea level Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) (deg) (deg) (ft) (TIP) °/100ft. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) 9095.95 30.82 23.90 8676.35 0.00 0.00 1588.17 305.62 23.00 1592.77 280.64 5981447.77 619562.64 9162.00 31.63 25.78 8732.83 25.76 1.92 1619.23 320.01 24.88 1624.06 294.54 5981479.06 619576.54 9191.03 41.41 24.56 8756.13 38.79 33.78 1634.86 327.33 23.66 1639.80 301.61 5981494.80 619583.61 9224.43 47.58 23.57 8779.95 56.17 18.59 1656.22 336.86 22.67 1661.31 310.80 5981516.31 619592.80 9231.00 49.29 23.40 8784.31 59.79 26.10 1660.73 338.82 22.50 1665.85 312.69 5981520.85 619594.69 9251.40 41.67: 22.67 8798.60 70.42 37.44 1674.11 344.51 21.77 1679.31 318.17 5981534.31 619600.17 9285.68 49.60 20.32 8822.55 87.84 23.64 1696.90 353.45 19.42 i 702.24 326.75 5981557.24 619608.75 9314.27 57.44 18.75 8839.54 103.63 27.77 1718.55 361.12 17.85 1724.01 334.08 5981579.01 619616.08 9341.75 64.40 17.50 8852.89 119.70 25.64 1741.36 368.58 16.60 1746.94 341.18 5981601.94 619623.18 9371.91 74.89 13.75 8863.37 137.66 36.68 1768.56 376.15 12.85 1774.25 348.32 5981629.25 61963{). 32 9393. I I 79.74 13.57 8868.02 150.27 22.89 1788.65 381.03 12.67 1794.42 352.89 5981649.42 619634.89 9438.05 83.70 19.74 8874.50 179.20 16.19 1831.22 393.78 18.84 1837.18 364.97 5981692.18 619646.97 9478.85 84.85 23.97 8878.57 208.30 10.69 1868.89 408.89 23.07 1875.08 379.48 5981730.08 619661.48 951 1.25 84.84 23.16 8881.48 232.09 2.49 1898.47 421.79 22.26 1904.86 391.92 5981759.86 619673/~' 9548.47 84.93 24.85 8884.80 259.61 4.53 1932.33 436.87 23.95 1938.96 406.47 5981793.96 619688.':-. 9580.30 85.29 25.03 8887.51 283.51 1.26 1961.09 450.24 24.13 1967.92 419.39 5981822.92 619701.39 9618.13 86.87 31.90 8890.10 313.39 18.59 1994.25 468.22 31.00 2001.36 436.84 5981856.36 619718.84 9654.25 88.90 34.37 8891.43 343.69 8.85 2024.47 487.95 33.47 2031.88 456.09 5981886.88 619738.09 9688.50 88.37 41.41 8892.25 373.85 20.61 2051.47 508.97 40.51 2059.22 476.68 .5981914.22 619758.68 9714.15 88.11 46.52 8893.04 397.60 19.94 2069.92 526.76 45.62 2077.94 494.18 5981932.94 619776.18 9755.05 86.08 50.93 8895.11 436.58 11.86 2096.86 557.45 50.03 2105.36 524.44 598196{).36 619806.44 9786.63 87.14 51.63 8896.98 467.06 4.02 2116.58 582.04 50.73 2125.46 548.73 5981980.46 619830.73 9825.40 89.26 55.51 8898.20 504.88 11.40 2139.58 613.21 54.61 2148.95 579.53 5982003.95 619861.53 9865.85 88.11 59.03 8899.13 544.84 9.15 2161.45 647.23 58.13 2171.35 613.20 5982026.35 619895.20 9889.27 87.83 61.9 8899.96 568.13 12.35 2 ! 72.98 667.59 61.01 2183.20 633.38 5982038.20 619915.38 9929.17 89.07 67.49 8901.04 607.99 14.32 2190.02 703.63 66.59 2200.80 669.15 5982055.80 61995 I. 15 9964.67 89.69 69.08 8901.42 643.46 4.81 2203.15 736.61 68.18 2214.45 701.92 5982069.45 619983.92 10007.20 89.25 74.54 8901.81 685.76 12.88 2216.42 777.00 73.64 2228.35 742.09 5982083.35 620024.09 10035. I 0 88.90 75.25 8902.26 713.32 2.84i 2223.69 803.93 74.35 2236.05 768.90 5982091.05 620050.90 10067.33 87.93 80.00 8903.16 744.88 15.04' 2230.60 835.39 79.10 2243.44 800.25 5982098.44 620082.25 Meas. Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP ~ Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S{-) E(+)/W(-) · (de[~) (de~) (ft) (TIP) °/100ft. Lat. (Y) Dep. (X) (de~) Lat. (Y) Dep. (X) Lat. (Y) l)ep. (X) 10103.72 86.26 82.47 8905.00 779.95 8.19 2236.13 871.31 81.57 2249.54 836.08 5982104.54 62()I 18.08 10142.85 83.79 78.24 8908.40 817.71 12.48 2242.66 9{)9.73 77.34 2256.67 874.39 5982111.67 620156.39 i{)178.58 83.88 77.89 8912.23 852.46 1.01 2250.01 944.48 76.99 2264.56 909.02 5982119.5(-, 620191.02 1{)211.05! 83.88 76.30 8915.69 884.15 4.87 2257.22 975.95 75.40 2272.27 940.38 5982127.27 620222.38 10239.38 84.05 74.37 8918.67 911.95 6.80 2264.35 1003.20 73.47 2279.83 967.51 5982134.83 620249.51 i{)297.92 84.49 70.49 8924.52 969.83 6.64 2281.93 1058.72 69.59 2298.28 1022.75 5982153.28 620304.75 10331.50 84.05 65.55 8927.87, 1003.21 14.70 2294.43 1089.70 64.65 2311.26 1053.52 5982166.26 620335.52 10376.70 84.49 66.26 8932.39 1048. i 8 1.84 2312.79 I 130.75 65.36 2330.27 1094.29 5982185.27 620376.29 1{)411.28 86.50 65.43 8935.10 1082.65 6.29 2326.90 1162.21 64.53 2344.86 1125.51 5982199.86 620407.51 10449.10 88.1 i 62.38 8936.88 1120.40 9.11 2343.51 i 196.13 61.48 2362.01 1159.17 5982217.01 620441.17 10479.72 86.55 57.87 8938.31 1150.81 15.57 2358.74 1222.64 56.97 2377.66 1185.44 5982232.66 62{)467.44 10507.17 86.43 58.51 8939.99 1177.95 2.37 2373.18 1245.93 57.61 2392.46 1208.49 5982247.46 620490~.,'" _ 10567. I 0 88.46 61.50 8942.66 1237.48 6.03 2403.1 ! 1297.77 60.60 2423.20 1259.86 5 :)8___78 .._{) 62054 I'% 1 {)625.29 88.73 66.44 8944.09 1295.60 8.50 2428.63 1350.02 65.54 2449.53 1311.71 5982304.53 620593.71 10669.57 89.05 71.93 8944.95 1339.78 12.42 2444.35 1391.39 71.03 2465.91 1352.82 5982320.91 620634.82 10706.42 90.57 74.54 8945.07 1376.34 8.20 2454.98 1426.67 73.64 2477.09 1387.93 5982332.09 620669.93 10739.52 90.40 76.3{} 8944.79 1409.00 5.34 2463.31 1458.70 75.4{) 2485.92 1419.83 5982340.92 620701.83 10795.52 89.45 80.77 8944.86 1463.66 8.16 2474.44 15 i 3.57 79.87 2497.91 1474.52 5982352.91 620756.52 10833.9{) 88.63 84.76 8945.51 1500.41 10.61 2479.27 1551.63 83.86 2503.34 1512.50 5982358.34 620794.50 10887.82 90.03 90.90 8946.14 1550.45 11.68 248 I. 31 16{)5.48 90.00 2506.23 1566.31 5982361.23 620848.3 I 10932.92 90.97 91.75~ 8945.74 1591.24 2.81 2480.27 1650.57 90.85 25{)5.89 1611.40 5982360.89 620893.41) 10961.97 91.19 95.86~ 8945.20 1616.94 14.17 2478.34 1679.54 94.96 2504.42 1640.41 5982359.42 620922.41 10996.42 92.33 97.45 8944.14 1646.58 5.68 2474.35 1713.74 96.55 2500.97 1674.66 5982355.97 620956.66 11037.27 91.63 103.79 8942.73 1680.18 15.61 2466.83 1753.85 102.89 2494.08 1714.88 5982349.{)8 62{)996,88 I 1095.75 90.00 105.14 8941.89 1726.00 3.62 2452.23 1810.46 104.24 2480.36 1771.72 5982335.36 621 {)53.72 I 1169.67 88.33 102.02 8942.97 1784.61 4.79 2434.88 1882.30 101.12 2464.14 1843.82 5982319.14 621125.82 i 1234.79 90.93 100.62 8943.39 1837.78 4.53: 2422.10 1946.14 99.72 2452.37 1907.86 5982307.37 621189.86 11272.10 89.78 97.92 8943.16 1868.99 7.87 2416.09 1982.96 97.02 2446.94 1944.77 5982301.94 621226.77 11307.67 90.09 98.18 8943.20 1899.16 1.14 2411.11 2018.18 97.28 2442.51 1980.06 5982297.51 621262.06 I 1344.72 90.25 94.09 8943.09 1931.21 11.05 2407.15 2055.01 93.19 2439.13 2016.95 5982294.13 6212981' I 1387.57 90.31 93.40 8942.88 1969.16 1.62 2404.35 2097.77 92.50 2437.00 2059.74 5982292.00 621341 .'~, 11429.37 90.37 90.24 8942.63 2006.80 7.56 2403.02 2139.54 89.34 2436.33 2101.53 5982291.33 621383.53 I 1464.91 89.07 92.92 8942.81 2038.87 8.38 2402.04 2175.06 92.02 2435.91 2137.07 5982290.91 621419.07 11499.36 90.93 86.70 8942.81 2070.38 18.84 2402.15 2209.49 85.80 2436.56 2171.49 5982291.56 621453.49 11532.9 92.02 85.75 8941.94 2101.87 4.31 2404.36 2242.96 84.85 2439.30 2204.92 5982294.30 621486.92 I 1568.33 93.27 83.55 8940.31 2135.40 7.14 2407.66 2278.19 82.65 2443.15 2240.09 5982298.15 621522.09 I 1604.4 94.33 78.1 I 8937.92 2170.20 15.33 2413.40 2313.71 77.21 2449.44 2275.52 5982304.44 621557.52 11651.8 94.32 74.08 8934.34 2216.73 8.48 2424.75 2359.58 73.18 2461.51 2321.20 5982316.51 621603.20 11672.36 93.91 71.97 8932.86 2237.07 10.43 2430.74 2379.19 71.{)7 2467.81 2340.71 5982322.81 621622.71 11691.001 93.54 70.07 8931.65 2255.60 10.36 2436.78 2396.77 69.17 2474.13 2358.20 5982329.13 621640.20 EOW Survey Calculations Coordinates provided in: TRUE and GRID relative to Wellhead and ALASKA STATE PLAN Company: B.P. Exploration Rig: Nordic #1/CTU #7 J ob No: 102275 Well: S-25Ai Plugback Field: Prudhoe Bay, Alaska AFE No: 4P-1213 Calculation Method: Minimum Curvature Mag. Declination: 27.680 BHI Rep: H. Wagoner, M. Miller Vertical Sect. Plane: 66.060 TRUE Grid Correction: 0.900 Job Start Date: 07-Nov-98 Vertical Sect. Plane: 65.160 GRID Total Correction: 26.780 Job End Date: 19-Nov-98 Measured Depth from: RKB RKB Height: 65.80{I True Vertical Depth: Sea level { Meas. Incl. TRUE Snbsea Vertical DLS Coords. - TRUE GRID Coords. - GRID Coords. - ASP Depth Angle Azi. TVD Section N(+)/S(-) E(+)/W(-) Azi. N(+)/S(-) E(+)/W(-) N(+)/S(-) E{+)/W(-) (deg) (deg) (ft) (TIP) °/100ft. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) 9095.95 30.82 23.90 8676.35 0.00 0.00 1588.17 305.62 23.00 1592.77 280.64 5981447.77 619562.64 9162.00 31.63' 25.78 8732.83 25.76 1.92 1619.23 32{).0 i 24.88 1624.06 294.54 5981479.06 619576.54 9170.00 34.32 25.38 8739.54 29.07 33.73 1623.16 321.89 24.48 1628.01 296.36 5981483.01 619578.36 9191.03 41.41 24.56 8756.14' 38.79 33.80 1634.86 327.33 23.66 1639.80 301.61 5981494.80 619583.61 9224.43 47.58 23.57 8779.95 56.17 18.59 1656.22 336.86 22.67 1661.31 310.80 5981516.31 619592.80 9269.88 59.49 22.59 8806.91 82.84 26.26 1689.80 351.14 21.69 1695.10 324.56 5981550.10 619606.56 9304.93 69.43 22.22 8822.01 105.69 28.38 1719.00 363.18 21.32 1724.49 336.13 5981579.49 619618.13 9332.30 75.95 24.14 8830.15 124.83 24.74 1743.00 373.46 23.24 1748.66 346.04 5981603.66 619628.04 9362.00 82.74 20.80 8835.64 145.95 25.39 1769.96 384.60 19.90 1775.78 356.75 5981630.78 619638.75 9371.18 84.85 19.79 8836.63 152.32 25.45 1778.52 387.77 18.89 1784.39 359.78 598 i 639.39 619641.78 9406.90 88.19 22.56 8838.80 177.57 12.14 1811.76 400.64 21.66 1817.83 372.14 5981672.83 619654.14 9436.10 90.84 26.08 8839.04 199.36 15.09 1838.36 412.67 25.18 1844.61 383.74 5981699.61 619665.74 9466.18 93.74 33.31 8837.84 223.54, 25.88 1864.45 427.54 32.41 1870.93 398.20 5981725.93 619680.20 9516.0{) 89.96 34.19 8836.23 265.62 7.79 1905.84 455.20 33.29 1912.76 425.21 5981767.76 619707( 9534.48 87.14 37.01 8836.70 281.54 21.58 1920.86 465.95 36.11 1927.94 435.72 5981782.94 619717.:'t 9568.40 81.94 30.31 8839.93 310.02 24.93 1948.93 484.66 29.41 1956.31 453.99 598181 1.31 619735.99 9621.48' 82.03 42.12 8847.36 355.53 22.03 1991.26 515.66 41.22 1999.12 484.31 5981854.12 619766.3 I 9655.73 80.88 46.35 8852.45 386.97 12.67 2015.53 539.28 45.45 2023.75 507.55 5981878.75 619789.55 9696.85 78.06 52.82 8859.97 425.70 16.92 2041.73 570.03 51.92 2050.43 537.89 5981905.43 619819.89 9726.23 80.79 56.92 8865.36 454.03 16.57 2058.34 593.64 56.02 2067.41 561.24 5981922.4 i 619843.24 9755.00 80.79 56.92 8869.97 482.07 0.00 2073.84 617.44 56.02 2083.28 584.79 5981938.28 619866.79 BP EXPLORATION Date: Nov. 4, 1998 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska. 99501 Attention' Re: Blair Wondzell Sr. Reservoir Engineer Well S-25ai Permit to Drill The coil drilling unit is currently completing a sidetrack on well S-31ai ahead of schedule. The next well, S-25ai, has been issued a ,Sundry to permit perforation abandonment but the Permit to Drill has not yet been issued. This Permit to Drill application was submitted on Oct, 9, 1998. The rig is expected to move to S-25ai tonight. If there is a problem with this Permit to Drill applioation please advise in order that we may work the problem. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center ,or ~ 0!1 & C~as Cons. commission TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 4. 1998 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re' Prudhoc Bay Unit S-25Ai BP Exploration (Alaska) Inc. Permit No: 98-214 Sur. Loc. 1633'SNL. 4158'WEL, Scc. 35, T12N, R12E. UM Btmhole Loc. 4288'SNL. 1598'WEL. Sec. 26. T12N. RI2E. UM Dear Mr. Stagg: Enclosed is the approved application for permit to rcdrill thc abovc rcfcrcnccd xvell. The permit to redrill does not exempt you from obtaining additional permits required bv lax',' from othcr govcrnmcntal agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. Thc blowout prevention cquipmcnt (BOPE) must be tcstcd in accordance with 20 AAC 25.035: and the mechanical intcgrits.' (MI) of thc injection wells must bc dcmonstratcd 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 thc BOPE tcst performed before drilling below the surface casing shoe. must bc given so that a rcprcscntativc of thc Commission ma',' witness thc tcsts. Notice ma',' be given bv contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. Chairman BY ORDER OF TIlE COMMISSION dlffEnclosure CC: Dcpartmcnt of Fish & Game. Habitat Scction w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASFOt IL AND GAS CONSERVATION Cf MISSION PERMIT TO DRILL 20 AAC 25.005 CT Sidetrack well [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development oil la. Type of work [] Re-Entry [] Deepenl [] Service [] Development Gas [~ Single Zone D Multiple Zone 2. Name of Operator i5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE=65.75 Prudhoe Bay Field / Prudhoe 3. Address !6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1633'SNL,4158'WEL,SEC. 35, T12N,R12E ....... Prud..hoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 5243'SNL,3814'WEL, SEC.26,T12N,R12E S-25Ai At total depth 9. Approximate spud date Amount $200,000.00 4288' SNL, 1598'WEL, Sec. 26, T12N, R12E 11/12/98 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028258 @ 3681'I No Close Approach 2560 11871', 8940'TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9170' Maximum Hole Angle 110° Maximum surface 3350 psig, At total depth (TVD) @8800', 3825psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2 7/8" 6.16# L-80 ST-L 2921' 8950 8549 11871 8940 145 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 0~,~,/G/~kL Total depth: measured 9650 feet Plugs (measured) ,../~-,: %,¢;3 . true vertical 9207 feet Effective depth: measured 9607 feet Junk (measured) true vertical 9171 feet Casing Length Size Cemented MD TVD Structural Conductor 110 20x30 140 140 Surface 2644 13-3/8" 3291 cu ft Arctic Set 2674 2638 Intermediate 9123' 9-5/8" 1865 cu ft Class G 9153 8755 Production Liner 9620' 7" 263 cu ft Class G 8912-9650 8546-9171 Perforation depth: measured 9144'-9194',9268'-9300',9310'-9370' Sqzd{9370'-9452} true vertical subsea 8717'-8760',8823'-8850',8858'-8909' Sqzd{8909'-8978} 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Pict [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Ted StaaQ t'-,,. Title Coiled Tubing Drilling Engineer Date / -- '(" /n' Commission Use Only Permit Number APl Number [ Approval Date I See cover letter ,~'~-.2.///~' 50- ~.,T~'- "2-"2'4:::~;~2''°/I //""~" ~''~~ for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Requiredl~ Yes~ No Hydrogen Sulfide Measures :!~ Yes [] No Directional Survey Required ~ Yes [] No Pressure forBOPE [] 2k; [] 3k; [] ~k~ [] 5k; [] 10k; [] 15k Required Working Other: Approved By 0 i'i~ii*t ~! ~';~;.t.,, ,~, ...... ~ by order of ....... ,_ ~,...._ ~ Commissioner the commission Date -' Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX S-25ai Sidetrack Summary of Operations: S-25 is an existing injection well that is being sidetracked to improve injectivity into the Sag R and Zone 4 intervals. This sidetrack will be conducted in two phases. Phase 1: set whipstock, abandon existing perfs, mill window: Planned for 10126/98. · S-25i has been tested for mechanical integrity, drifted for the whipstock and a Kinley caliper has been run to evaluate liner and tubing condition. · A Schmoo-Be-Gone treatment has been performed to eliminate mung from the wellbore. · Existing perforations will be abandoned with approx. 20 bbls cement. Abandonment cement will be downsqueezed past a mechanical whipstock set within Sag R. perforations at approx.9,145'. Abandonment cement will be squeezed to 1500 psi with AOGCC witness. This procedure is described in more detail in the Form 10-403. · Service coil will mill the window utilizing a flowline to the GC for all fluid returns. The service coil will conduct a full BOPE test, with AOGCC witness, prior to the milling operation. Phase 2: Mill Window and Drill Directional Hole: Planned for 11/12/98. Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan. Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,950' MD and cemented with approx. 28 bbls. cement. The top of cement will be designed to be a minimum of 200 ft above the window. A Cement Evaluation Log will be run across the upper portion of the liner and pressure testing will be carried out to confirm mechanical integrity. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,170' MD (8,740' TVD ss) - TD: 11,871' MD (8,940' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A Cement Evaluation Log will be run in the upper portion of the 2 7/8" liner. TREE: 4-1/16"-5M CIW WELLHEAD: 13-5/8"- 5M FM,. ~ S-258i Proposed Completio_· ACTUATOR: OTIS KB. ELEV = 65.75 BF. ELEV = 36.15 13-3/8", 68#/ft, NT-80CYHE, BTRS OPEN 12,88ol KOP: 5000 MAX ANGLE: °28 OTIS SSSV LANDING NIPPLE I 2,091 (OTIS)(3.8131 D) GAS LIFT MANDRELS (OTIS W/1-1/2" RA LATCH) MD(EKE) TVDss No 3102 5217 7016 8622 8848 3O36 5149 6812 8258 8459 4-1/2", 12.6#/ft, L-80, TDS NON-IPC TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT TOP OF TIW I 8,509 7" LINER 9-5/8", 47#/ft, NT-80S, NSCC I 8,730 [ 2 7/8" Cemented Liner Whipstock Abandonment Cement PERFORATION SUMMARY REF: LOG: 08/17/90 CBT SIZE J SPF 3-3/8111 4 3-3/8,,I 6 3-3/8 I 6 3-3/8"J 4 3-3/8"J 4 INTERVAL OPEN/SQZ'D 9,144 - 9194' 9,268 - 9,310 9,310' - 9,370' Open 7-1-93 Reperf 8/92 SQZ/Reperf 9,370 - 9,418 SQZ 9,432 - 9,452 SQZ PBTD 7", 26 #/ft, L-80, TC4S I 9,604 I 19,671 I e,877 I BAKER TUBING I 8,882 J ANCHOR 9-5/8" PACKER (Baker) (3.99"1D) I 8,8841 4-1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4-1/2", 12.6#/ft, L-80 TAILPIPE - 0.5417"- 4-1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 8,940 0.5417"- 4-1/2 .... XN" NIPPLE (OTIS) (3.725" ID)I 8,961 ~--4-1/2"WLEG I 8,973 I (E L M D) J 8,980 J 8__ Liner cement to be 200 ft :.;.:.:.;.;.:.;.;.;.;.;.:.;,:.:-;.;.;,;.;.;.>;.;. S-25 Vertical Section 8700~ ---TSAG 5OO 1,000 Path Distance (Feet) 1,500 2,000 2,500 3,000 3,500 8750 8800 8850 89OO 895O 9000 Angle @ K.O.= 32 deg MD:9170 Marker Depths @Orig Wellbore TSAG I 8,7181ft TVD TSHU I 8,7571ft TVD S,eS01, D TSAD I 8,8231ftTVD i 9,1701ft MD Deprtr @KO 1,670 ft MD KO Pt 9,170 MD New Hole 2701 Total MD 11,871 TVD TD 8,940 DLS degll00 Tool Face Length Curve 1 30 -10 183 Curve 2 8 90 819 Curve 3 8 -94 269 Curve 4 8 90 469 Curve 5 8 0 114 Curve 6 8 -90 384 Curve 7 8 125 114 Curve 8 8 90 349 2,7Ol Drawn: 10/9/98 10:49 Plan Name: Case 101 2,700 ~ 2,200 ._~ 1,700 1,200 0 500 S-25 1,000 1,500 2,000 X distance from Sfc Loc 2,500 3,000 3,500 Well Name S-25 I CLOSURE Distance 3,666 ft I I Az 43 deg NEW HOLE E/W (X) NIS (Y) Kick Off 296 1,628 TD 2,516 2,666 State Plane 621,798 5,982,521 Surface Loc 619,282 5,979,855 DLS deg/100 Tool Face Length Curve 1 30 -10 183 Curve 2 8 90 819 Curve 3 8 -94 269 Curve 4 8 90 469 Curve 5 8 0 114 Curve 6 8 -90 384 Curve 7 8 125 114 Curve 8 8 90 349 2,701 Drawn: 10/9/98 10:49 Plan Name: Case 101 22.5" 2 318" CT -~ ho,ooo p;rl L Pack-OWl / Blind/Shear 7 1/16" Pipe/Slip 1/16" x 5,000 1/16" x 5,000 Slips 7 1/16" Pipe 1/16" x 5,000 318" 27/8" 2 318" SWAB OR MASTER VALVE BPX S-25ai Sidetrack Summary of Operations: S-25 is an existing injection well that is being sidetracked to improve injectivity into the Sag R and Zone 4 intervals. This sidetrack will be conducted in two phases. Phase 1: set whipstock, abandon existing perfs, mill window: Planned for '10/26/98. ,. · S-25i has been tested for mechanical integrity, drifted for the whipstock and a Kinley caliper has been run to evaluate liner and tubing condition. · A Schmoo-Be-Gone treatment has been performed to eliminate mung from the wellbore. · Existing perforations will be abandoned with approx. 20 bbls cement. Abandonment cement will be downsqueezed past a mechanical whipstock set within Sag R. perforations at approx.9,145'. Abandonment cement will be squeezed to 1500 psi with AOGCC witness. This procedure is described in more detail in the Form 10-403. · Service coil will mill the window utilizing a flowline to the GC for all fluid returns. Th'e service coil will conduct a full BOPE test, with AOGCC witness, prior to the milling operation. Phase 2: Mill Window and Drill Directional Hole: Planned for '11112198. Directional drilling coil tubing equipment will be rigged up and utilized to drill the directional hole as per attached plan. Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,950' MD and cemented with approx. 28 bbls. cement. The top of cement will be designed to be a minimum of 200 ft above the window. A Cement Evaluation Log will be run across the upper portion of the liner and pressure testing will be carried out to confirm mechanical integrity. The well will then be perforated with coil tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,170' MD (8,740' TVD ss) - TD: 11,871' MD (8,940' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run.over all of the open hole section. · A Cement Evaluation Log will be run in the upper portion of the 2 7/8" liner. · WELL PERMIT CHECKLIST :IELD & POOL COMPANY ..,~'~.~ · .~'-.2-._~'",'~./'~. PROGRAM: exp [] dev [] redrli~v~wellbore segl, ann. disposal para req I..~ INIT CLASS /- -- V' ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well Iocaled proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... R D~TE/, ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. cur vol adequate to tie-in long string to surf csg ........ 18. CMr will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B 8, permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a ~0-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If d/verier 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 /-~f~O ps,g. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... GEOL AREA ~"3 UNIT# 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y, y 31. Data presented on potential overpressure zones ....... ~ ,4' 32. Seismic analysis of shallow gas zones ..... ' ........ ~.. ,N, ~ ~_ 33. Seabed condition survey (if off-shore) ............. / Y m 34. Con. tact.nam, e/phon.e.for weekly progress reports ....... / Y N lexpmra~ory on~y] APPR DATE GEOLOGY APPR With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not conlaminate freshwater; or cause drilling waste... Io surface; (C) wii~'~bt.impai[._rnechanical integrity of the well used for disposal; (P) will not damage Producing formation or impair recovery from a pool; and ~ AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ............ RNC JDH/.~--- CO ~ '~/ ANNULAR DISPOSAL 35. APPR DATE ON/OFF SHORE Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N 4bN ,~,'¢). N C. N N Comments/Instructions: M:chel~lisl Ir(;v 05129/98 rill C ~rn~nfli('~:~wofdiml~dinn;J\, h,'~ I h,,I Y N Y N Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Jan 15 12:38:31 1999 Reel Header Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical 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 1 AK-MW-90015 B. JAHN SEVCIK/MCMUL S-25A PB1 500292207770 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 15-JAN-99 MWD RUN 2 MWD RUN 4 AK-MW- 90015 AK-MW- 90015 B. JAHN B. JAHN SEVC I K/MCMIIL SEVCIK/MCMUL 35 12N 12E 1633 4158 65.80 RECEtVED JAN 20 19W Alast(a Oil l Gas Cons. Coma s m DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 8730.0 5.500 10314.0 4.500 8973.0 3.750 9755.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD). 3. MWD RUNS 1-4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS (SOALR 175). 4. MWD RUN 3 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D. DOUGLAS FOR S. JONES OF BP EXPLORATION (ALASKA), INC ON 0~/06/99. THIS DATA IS CONSIDERED PDC. 6, MWD RUNS 1, 2 AND 4 REPRESENT WELL S-25A PB1 WITH API#: 50-029-22077-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9755'MD, 8870'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 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 9160.0 9726.5 ROP 9167.5 9755.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 9167.0 9240.0 2 9240.0 9375.0 4 9375.0 9755.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9160 9755 9457.5 1191 9160 ROP 2.57 134.06 66.1183 1176 9167.5 GR 28.03 887.7 174.241 1134 9160 Last Reading 9755 9755 9726.5 First Reading For Entire File .......... 9160 Last Reading For Entire File ........... 9755 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 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 ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9160.0 ROP 9167.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9216.5 9240.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MLTD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP_ATLTRE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 07-NOV-98 INSITE 4.0 SOLAR MEMORY 9240.0 9167.0 9240.0 31.6 47.6 TOOL NUMBER SOLAR GM 77113 3.750 3.8 FLO-PRO 8.90 .0 9.0 5.8 .000 .000 .000 .000 58.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REFLARKS: $ 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9160 9240 9200 161 9160 GR 64.42 190.27 89.6271 114 9160 ROP 2.57 127.84 41.494 146 9167.5 Last Reading 9240 9216.5 9240 First Reading For Entire File .......... 9160 Last Reading For Entire File ........... 9240 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 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 ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE N-UMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9224.5 ROP 9248.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9351.0 9375.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 08-NOV-98 INSITE 4.0 SOLAR MEMORY 9375.0 9240.0 9375.0 59.5 75.8 TOOL NUMBER SOLAR GM 69702 3.750 3.8 FLO-PRO 8.90 .0 9.0 5.8 .000 .000 .000 .000 60.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA1W-DOFF (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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9224.5 9375 9299.75 302 9224.5 GR 32.62 887.7 190.119 254 9224.5 ROP 17.57 134.06 52.9904 254 9248.5 Last Reading 9375 9351 9375 First Reading For Entire File .......... 9224.5 Last Reading For Entire File ........... 9375 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW 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 GR 9351.5 ROP 9376.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9726.5 9755.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MI/D PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3kTURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 09-NOV-98 INSITE 4.0 SOLAR MEMORY 9755.0 9375.0 9755.0 78.0 93.7 TOOL NUMBER SOLAR GM 77113 3.750 3.8 FLO-PRO 8.80 .0 9.4 7.0 .000 .000 .000 .000 60.7 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 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9351.5 9755 9553.25 808 9351.5 GR 28.03 818.71 182.945 751 9351.5 ROP 15.86 133.56 75.5924 759 9376 Last Reading 9755 9726.5 9755 First Reading For Entire File .......... 9351.5 Last Reading For Entire File ........... 9755 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/01/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Mon Jan 18 14:31:51 1999 Reel Header Service name ............. LISTPE Date ..................... 99/01/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/01/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 90015 B. JAHN SEVCIK/MCMUL RECEIVED JAN 20 Ala Oil & Gas Cons. Cmmnis n S-25A ~ 500292207701 BP EXPLORATION (ALASKA), INC. SPERRY-SUNDRILLING SERVICES 18-JAN-99 MWD RUN 2 AK-MW- 90015 B. JAHN SEVCIK/MCMUL MWD RUN 5 AK-MW- 90015 B. JAHN SEVCIK/MCMUL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MW-90015 D. LONG SEVCIK/MCMUL MWD RUN 7 AK-MW-90015 D. LONG SEVCIK/MCMUL MWD RUN 8 AK-MW-90015 D. LONG SEVCIK/MCMUL JOB N-UMBER: LOGGING ENGINEER: MWD RUN 9 AK-MW-90015 D. LONG MWD RUN 10 AK-MW-90015 D. LONG MWD RUN 11 AK-MW-90015 D. LONG OPERATOR WITNESS: SEVCIK/MCMUL SEVCIK/MCMUL SEVCIK/ANGEL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 13 A/<-MW-90015 S. LATZ PARKER/ANGEL MWD RUN 12 ~K-MW-90015 D. LONG SEVCIK/ANGEL 65.80 .00 .00 35 12N 12E $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.625 8730.0 2ND STRING 5.500 10314.0 3RD STRING 4.500 8973.0 PRODUCTION STRING 3.750 11691.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 1,2 & 5-13 ARE DIRECTIONAL WITH DGR (DUAL GAMMA RAY) UTILIZING GEIGER-MUELLER TUBE DETECTORS (SOALR 175). 4. MWD RUN 3 MADE NO FOOTAGE AND IS NOT PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM D. DOUGLAS FOR S. JONES OF BP EXPLORATION (ALAS~) , INC ON 01/06/99. THIS DATA IS CONSIDERED PDC. 6. MWD RUNS 1,2 & 5-13 REPRESENT WELL S-25A PB1 WITH API#: 50-029-22077-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9755'MD, 8870'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. 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 9160.0 11667.0 ROP 9167.5 11691.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD 1 MWD 2 MWD 5 MWD 6 MWD 7 MWD 8 MWD 9 MWD 10 MWD 11 MWD 12 MWD 13 $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP 9167.0 9224.0 9231 0 9291 0 9411 0 9620 0 9844 0 9920 0 10317 0 10433 0 11485 0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9231.0 9231.0 9291.0 9411.0 9620.0 9844.0 9920.0 10317.0 10433.0 11485.0 11691.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 9160 11691 10425.5 5063 GR 19.39 588.54 48.0163 5015 ROP 0.05 1620.7 82.6345 5048 First Reading 9160 9160 9167.5 Last Reading 11691 11667 11691 First Reading For Entire File .......... 9160 Last Reading For Entire Fil~ ........... 11691 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 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 ....... 99/01/18 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE STA/~T DEPTH STOP DEPTH GR 9160.0 9216.5 ROP 9167.5 9230.5 $ LOG HEADER DATA DATE LOGGED: 07-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9240.0 TOP LOG INTERVAL (FT) : 9167.0 BOTTOM LOG INTERVAL (FT) : 9240.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MLTD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type ................... 0 Data Specification Block Type ..... 0 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 31.6 47.6 TOOL NLTMBER SOLAR GM 77113 3.750 3.8 FLO-PRO 8.90 65.0 9.0 5.8 .000 .000 .000 .000 58.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 9160 9230.5 9195.25 142 GR 64.42 190.27 89.6271 114 ROP 2.57 127.84 40.4634 127 First Reading 9160 9160 9167.5 Last Reading 9230.5 9216.5 9230.5 First Reading For Entire File .......... 9160 Last Reading For Entire File ........... 9230.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 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 ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N-UMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9224 . 5 9230 . 5 $ LOG HEADER DATA DATE LOGGED: 08 -NOV- 98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9375.0 TOP LOG INTERVAL (FT) : 9240.0 BOTTOM LOG INTERVAL (FT) : 9375.0 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 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 59.5 75.8 TOOL NUMBER SOLAR GM 69702 3.750 3.8 FLO-PRO 8.90 65.0 9.0 5.8 .000 .000 .000 .000 60.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 9224.5 9230.5 9227.5 13 9224.5 Last Reading 9230.5 GR 135.77 147.04 141.744 13 9224.5 9230.5 First Reading For Entire File .......... 9224.5 Last Reading For Entire File ........... 9230.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NTJMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9231.0 9265.0 ROP 9231.0 9290.5 $ LOG HEADER DATA DATE LOGGED: Il-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9291.0 TOP LOG INTERVAL (FT) : 9231.0 BOTTOM LOG INTERVAL (FT) : 9291.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 41.7 MAXIMUM ANGLE: 49.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/~DOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Dowu/ 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 TOOL NUMBER SOL/UR GM 77113 3.750 3.8 FLO-PRO 8.80 65.0 10.0 7.2 .000 .000 .000 .000 58.9 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9231 9290.5 9260.75 120 9231 GR 65.75 500.82 151.77 69 9231 ROP 10.82 70.16 36.4498 120 9231 Last Reading 9290.5 9265 9290.5 First Reading For Entire File .......... 9231 Last Reading For Entire File ........... 9290.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE N/3MBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9266.5 9386.0 ROP 9291.0 9411.0 $ LOG HEADER DATA DATE LOGGED: Il-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9411.0 TOP LOG INTERVAL (FT) : 9291.0 BOTTOM LOG INTERVAL (FT) : 9411.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 49.6 MAXIMUM ANGLE: 74.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 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 TOOL NUMBER SOLAR GM 77113 3.750 3.8 FLO-PRO 8.80 65.0 10.0 7.2 .000 .000 .000 .000 60.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9266.5 9411 9338.75 290 9266.5 GR 23.22 588.54 100.025 240 9266.5 ROP 9.53 79.42 56.6364 241 9291 Last Reading 9411 9386 9411 First Reading For Entire File .......... 9266.5 Last Reading For Entire File ........... 9411 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name.~ ..... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9386.5 9589.5 ROP 9412.0 9620.0 $ LOG HEADER DATA DATE LOGGED: 12-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9620.0 TOP LOG INTERVAL (FT) : 9411.0 BOTTOM LOG INTERVAL (FT) : 9620.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM AI~GLE: 83.7 MAXIMUM ANGLE: 85.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY $ BOREHOLE ~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STA/gDOFF (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 SOLAR GM 77113 3.750 3.8 FLO-PRO 8.80 65.0 10.0 7.2 .000 .000 .000 .000 60.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9386.5 9620 9503.25 468 9386.5 GR 23.08 66.95 35.8191 407 9386.5 ROP 14.98 196.46 112.847 417 9412 Last Reading 9620 9589.5 9620 First Reading For Entire File .......... 9386.5 Last Reading For Entire File ........... 9620 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEA/PER FILE NI/MBER: 7 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9590.5 9814.0 ROP 9620.5 9844.0 $ LOG HEADER DATA DATE LOGGED: 13-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWN-HOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9844.0 TOP LOG INTERVAL (FT) : 9620.0 BOTTOM LOG INTERVAL (FT) : 9844.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIM~ ANGLE: 88.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 77113 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MTJD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (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 3.750 3.8 FLO-PRO 8.80 65.0 9.8 8.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel- DEPT FT 4 1 68 0 1 GR MWD 8 API 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 60.6 First Name Min Max Mean Nsam Reading DEPT 9590.5 9844 9717.25 508 9590.5 GR 21.25 55.29 31.3804 448 9590.5 ROP 32.67 177.77 75.3322 448 9620.5 Last Reading 9844 9814 9844 First Reading For Entire File .......... 9590.5 Last Reading For Entire File ........... 9844 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9818.0 9889.5 ROP 9845.5 9920.0 $ LOG HEADER DATA DATE LOGGED: 14-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0i DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9920.0 TOP LOG INTERVAL (FT) : 9844.0 BOTTOM LOG INTERVAL (FT) : 9920.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 88.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 77113 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MIlD 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 3.750 3.8 FLO-PRO 8.80 65.0 9.8 8.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 API 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 60.6 First Name Min Max Mean Nsam Reading DEPT 9818 9920 9869 205 9818 GR 26.19 44.92 34.6384 144 9818 ROP 16.17 360.28 62.3864 150 9845.5 Last Reading 9920 9889.5 9920 First Reading For Entire File .......... 9818 Last Reading For Entire File ........... 9920 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9892 . 0 10288 . 5 ROP 9920 . 5 10317 . 0 $ LOG HEADER DATA DATE LOGGED: 15-NOV- 98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10317.0 TOP LOG INTERVAL (FT) : 9920.0 BOTTOM LOG INTERVAL (FT) : 10317.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 83.8 MAXIMUM ANGLE: 89.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 77113 $ 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 (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 3.750 3.8 FLO-PRO 8.80 65.0 9.5 8.4 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 API 4 1 68 4 2 ROP MWD 10 FT/H 4 1 68 8 3 58.9 First Name Min Max Mean Nsam Reading DEPT 9892 10317 10104.5 851 9892 GR 24.29 206.54 57.0208 794 9892 ROP 12.29 204.46 63.3487 794 9920.5 Last Reading 10317 10288.5 10317 First Reading For Entire File .......... 9892 Last Reading For Entire File ........... 10317 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10292.5 10407.5 ROP 10318.5 10433.0 $ LOG HEADER DATA DATE LOGGED: 16-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10433.0 TOP LOG INTERVAL (FT) : 10317.0 BOTTOM LOG INTERVAL (FT) : 10433.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.0 MAXIMUM ANGLE: 86.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NLIMBER DGR DUAL GAMMA RAY SOLAR GM 77113 $ 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 (OH]MM) AT TEMPEP=ATURE (DEGF) MUD AT MEASURED TEMPER3%TURE (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 3.750 3.8 FLO-PRO 8.80 65.0 9.8 8.8 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 API 4 1 68 4 2 ROP MWD 11 FT/H 4 1 68 8 3 59.4 First Name Min Max Mean Nsam Reading DEPT 10292.5 10433 10362.8 282 10292.5 GR 20.41 47.27 31.0635 231 10292.5 ROP 4.72 294.32 119.372 230 10318.5 Last Reading 10433 10407.5 10433 First Reading For Entire File .......... 10292.5 Last Reading For Entire File ........... 10433 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEA3DER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10408.0 11458.0 ROP 10434.0 11485.0 $ LOG HEADER DATA DATE LOGGED: 19-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWNHOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11485.0 TOP LOG INTERVAL (FT) : 10433.0 BOTTOM LOG INTERVAL (FT) : 11485.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 86.4 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY SOLAR GM 77113 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 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 3.8 FLO-PRO 8.90 65.0 9.5 6.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 API 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 60.6 First Name Min Max Mean Nsam Reading DEPT 10408 11485 10946.5 2155 10408 GR 19.39 103.75 41.6473 2101 10408 ROP 0.05 1620.7 89.9016 2103 10434 Last Reading 11485 11458 11485 First Reading For Entire File .......... 10408 Last Reading For Entire File ........... 11485 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Phgsical Record..65535 ~±le Type ................ LO Next ~ile Name ........... STSBIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11464.0 11667.0 ROP 11487.0 11691.0 $ LOG HEADER DATA DATE LOGGED: 19-NOV-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 4.0 DOWN-HOLE SOFTWARE VERSION: SOLAR DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11691.0 TOP LOG INTERVAL (FT) : 11485.0 BOTTOM LOG INTERVAL (FT) : 11691.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/gGLE: 90.9 MAXIMUM ANGLE: 93.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA P~AY SOLAR GM 69702 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT) : 3.8 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: MI/D 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 FLO-PRO 8.80 65.0 9.0 6.2 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 API 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 74.4 First Name Min Max Mean Nsam Reading DEPT 11464 11691 11577.5 455 11464 GR 23.7 117.54 42.8146 407 11464 ROP 12.03 188.48 89.0381 409 11487 Last Reading 11691 11667 11691 First Reading For Entire File .......... 11464 Last Reading For Entire File ........... 11691 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/01/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/01/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 99/01/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File Tape Subfile 1 is type: LIS **** REEL HEADER **** MAD 99/ 1/25 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MAD 99/ 1/25 102275 01 3 1/8" USMPR Resistivity & Gamma Ray Log Data LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ Remark File Version 1.000 Extract File: header.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block ~MNEM.UNIT Data Type STRT.F STOP.F STEP.F NULL. COMP WELL FLD LOC CNTY STAT SRVC TOOL REF DATE API ~Parameter Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame Information 9145.0000: Starting Depth 11555.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: BP Exploration WELL: S-25AI FIELD: Prudhoe Bay LOCATION: N 70deg 21min 12.960sec COUNTY: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 3 1/8" USMPR JOB REFERENCE: 102275 LOG DATE: 21 Nov 98 API NUMBER: 500292207701 #MNEM.UNIT Value Description W 149deg 01min 52.992se : Field Location 35 : Section 12N : Township 12E : Range MSL : Permanent Datum KB : Log Measured From 61.5 : Feet Above Perm. Datum KB : Drilling Measured From 61.55 : Elevation Of Kelly Bushing N/A : Elevation Of Derrick Floor N/A : Elevation Of Ground Level 9172 : Casing Depth Directional : Other Services Line 1 FL SECT. TOWN.N RANG PDAT LMF FAPD FT DMF EKB F EDF F EGL F CASE F OSl -Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data & Resistivity data presented is memory data. (4) Well S-25AI is represented by run 1, which is a Measurement After Drilling (MAD) Pass with Directional, Gamma Ray & Resistivity recorded in memory while logging down. (5) ROP was controlled to aprox. 180 ft./hr, in order to have 6 points/ft. (11) Resistivity data, and 3 points/ft. Gamma Ray data, stored in the memory. 6) The window existed in the 4 1/2 in. tubing with the top at 9165' MD (8736' TVD) and the bottom of the window at 9172' MD (8741' TVD). 7) The interval above 9172' MD (8741' TVD) was logged behind casing. 8) Depth was calibrated to a radioactive tag set at the bottom of the casing window at 9171' MD (8740' TVD). 9) The Gamma ray interval from 11530' MD (8942' TVD) to 11553' MD (8940' TVD) and the Resistivity interval from 11522' MD (8942' TVD) to 11553' MD (8940' TVD) was not logged due to sensor to bit offsets. 10) The directional surveys, used to plot the TVD logs and the TVD trace, were acquired from Sperry-Sun Drilling Services. The depths on this final log have been edited, from the field print, to match the Gamma ray log provided by Sperry-Sun Drilling Services, dated November 7-19, 1998. ~Mnemonics -> GRAM = -> ROPS = -> TVD = -> RACLM = -> RPCLM = -> RACHM = -> RPCHM = -Sensor Offsets RUN GAMMA 1 22.95' Gamma Ray MWD-API [RWD] (MWD-API units), Memory Rate of Penetration (ft/hr) True Vertical Depth (feet) Resistivity Compensated 400 KHz Attenuation Resistivity Long Spaced Borehole Corrected [RWD] (ohm-m), Memory Resistivity Compensated 400 KHz Phase Difference Resistivity Long Spaced Borehole Corrected [RWD] (ohm-m), Memory Resistivity Compensated 2 MHz Attenuation Resistivity Long Spaced Borehole Corrected [RWD] (ohm-m), Memory Resistivity Compensated 2 MHz Phase Difference Resistivity Long Spaced Borehole Corrected [RWD] (ohm-m), Memory RESISTIVITY DIRECTION 30.49' 45.22' Tape Subfile: 1 78 records... Minimum record length: 14 bytes Maximum record length: 132 bytes Tape Subfile 2 is type: LIS **** FILE HEADER **** MAD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN BP Exploration WN S-25AI FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!! !! ! ! !!!!!! !!! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BP Exploration. 3. The PDC used is the Sperry-Sun Drilling Services' Gamma Ray Log, dated November 7, 1998 through November 19, 1998. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR 2 ROP 3 RAS 4 RAD 5 RPS 6 RPD * FORMAT RECORD (TYPE~ 64) GRAM ROPS RACHM RACLM RPCHM RPCLM Entry Type 1) Size 1) Repcode(66) Data record type is: 0 Entry Type 2) Size 1) Repcode(66) Datum Specification Block Type is: 0 Entry Type 3) Size 2) Repcode(79) Datum Frame Size is: 28 bytes Entry Type 4) Size 1) Repcode(66) Logging direction is down (value= 255) Entry Type 5) Size 1) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type 8) Size 4) Repcode(68) Frame spacing: 0.500000 Entry Type 9) Size( 4) Repcode(65) Frame spacing units: IF ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 36 Entry Type(13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 0.0 0.0 0.0 0.0 0.0 0.0 Rep Code Count Bytes 68 6 24 Sum: 6 24 24 fndun a IF ] 1.00000000 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: API API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 GR MAD 68 1 API 4 2 ROP MAD 68 1 4 3 RAS MAD 68 1 4 4 RAD MAD 68 1 4 5 RPS MAD 68 1 RPS 4 6 RPD MAD 68 1 4 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 24 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 135 Tape File Start Depth = 9135.000000 Tape File End Depth = 11555.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 33895 datums Rep Code: 79 2 datums Tape Subfile: 2 142 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** MAD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU LCC 150 CN BP Exploration WN S-25AI FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!!!!!!!!!! ! !!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAM GRAM 0.0 2 ROPS ROPS 0 . 0 3 RACH RACHM 0.0 4 RACL RACLM 0.0 5 RPCH RPCHM 0 . 0 6 RPCL RPCLM 0 . 0 * FORMAT RECORD (TYPE~ 64) Entry Type( 1) Size 1 Data record type is: Entry Type( 2) Size 1 Datum Specification Block Entry Type( 3) Size 2) Datum Frame Size is: Entry Type( 4) Size 1) Logging direction is down Entry Type( 5) Size 1) Optical Log Depth Scale Units: Feet Entry Type( 8) Size 4) Repcode Frame spacing: 0.500000 ) Repcode 66) 0 ) Repcode 66) Type is: 0 Repcode 79) 28 bytes Repcode 66) (value= 255) Repcode 66) 68) Entry Type( 9) Size( 4) Repcode(65) Frame spacing units: IF ] fndun c IF ] 1.00000000 3 Entry Type(11) Size( 4) Repcode(68) Number of frames per record is: 36 Entry Type( 13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Datum Specification Block Sub-type is: 1 Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 6 24 Sum: 6 24 24 fndun a [F ] 1.00000000 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size 1 GRAM MAD 68 1 4 2 ROPS MAD 68 1 4 3 RACH MAD 68 1 4 4 RACL MAD 68 1 4 5 RPCH MAD 68 1 4 6 RPCL MAD 68 1 4 * DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 134 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 4 99 995 99 1 24 Tape File Start Depth = 9145.000000 Tape File End Depth = 11555.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 33755 datums Rep Code: 79 2 datums Tape Subfile: 3 141 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MAD 99/ 1/25 102275 01 **** REEL TRAILER **** MAD 99/ 1/25 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 25 JAN 99 4:52p Elapsed execution time = 1.92 seconds. SYSTEM RETURN CODE = 0 [] Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR RPS RPD 9135.0000 -999.2500 -999.2500 -999.2500 9135.5000 -999.2500 -999.2500 -999.2500 9200.0000 54.0050 92.7310 64.9940 9300.0000 6.4860 51.0140 8.0210 9400.0000 5.7120 34.9270 6.8120 9500.0000 5.9060 27.6190 5.7310 9600.0000 3.6810 33.4440 3.8680 9700.0000 4.9520 27.4550 5.4930 9800.0000 4.3780 30.7030 5.0860 9900.0000 4.6580 24.3590 5.4450 10000.0000 7.4370 39,2800 7.3020 10100.0000 5.8140 25.1710 5.9920 10200.0000 4.1470 136,-4660 4,8100 10300.0000 5.5360 35.0680 5,9770 10400.0000 4.6250 32,3270 4,6770 10500.0000 3.4840 30.7030 3.6680 10600.0000 4.0280 33.9510 4.2860 10700.0000 3.5430 35.3720 4.2410 10800.0000 4.8660 31.9720 4.5090 10900.0000 5.5050 61.0520 5.7420 11000.0000 4.6160 29.8910 4.2830 11100.0000 3.4340 28.2670 3. 6210 ROP -999.2500 -999.2500 181.1840 171.0290 175.7150 167.2390 169.8540 166.4380 184. 6260 176.5490 179.9780 179.9780 182.2450 176.7290 180.0710 181.7780 171.0240 177.0170 177.1900 176.1880 182.7710 179.9780 184.4870 RAS -999.2500 -999.2500 66.0530 9.2710 7.3660 5.3480 3.7890 5.6530 5.1540 6.1350 7.3730 6.0490 5.1880 5.9130 4 5100 3 9050 4 4870 4 5470 4 2910 5 8940 3 9130 3.7200 6.1530 RAD -999.2500 -999.2500 36.8810 8.2200 8.0960 5.1740 3.7730 6.1060 5.5300 5.9380 7.0150 5.7050 5.1020 5.9710 4.3710 3.5950 4.2340 4.7450 4.1360 5.2880 3.8000 3.9460 6.0040 11200.0000 50.1910 5.7570 6.1490 11300. 0000 26. 2880 179. 9770 5.2170 5.5740 11400.0000 57.9050 179.9780 6.1770 6.6650 11500.0000 30.0430 177.3740 6.6660 6.8270 11555.0000 -999.2500 -999.2500 -999.2500 -999.2500 5.4530 6.6600 6.4690 -999.2500 5.7960 6.5480 6.1750 -999.2500 Tape File Tape File Tape File Tape File Tape Subfile 3 Start Depth = 9135.000000 End Depth = 11555.000000 Level Spacing = 0.500000 Depth Units = Feet is type: LIS DEPTH GRAM ROPS RPCH RPCL 9145.0000 -999.2500 9145.5000 -999.2500 9200.0000 32.7220 9300.0000 16.8600 9400.0000 5.8400 9500.0000 4.4960 9600.0000 4.1730 9700.0000 3.3720 9800.0000 4.1750 9900.0000 4.4000 10000.0000 8.4540 10100.0000 5.3190 10200.0000 4.5050 10300.0000 6.4770 1O400.0000 4.5340 10500.0000 4.5440 10600.0000 6.9960 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 101.3580 36.7900 57.4730 144.3940 14.1770 176.3350 46.9540 7.0070 176.2950 53.5520 5.0100 176.1210 30.1960 3.9110 178.4770 28.0640 4.0160 181.8740 27.9120 4.9990 188.9760 30.1960 4.9820 173.4540 48.3640 7.8250 174.6600 28.2670 5.8820 179.9780 125.3010 4.9040 184. 6260 29.8910 6.9080 184.2520 27.1000 4.6650 175. 6290 28.8760 3.9140 179.9780 36.0320 6.3070 175.6920 RACH -999.2500 -999.2500 28.0470 12.0850 7.3840 5.2620 3.6160 4.2150 5.6720 5 1410 7 1060 6 1610 4 9180 7 0890 4 5950 3.6820 5.8860 RACL -999.2500 -999.2500 41.9560 7.6900 8.1570 5.2500 3.2190 5.3270 5. 6020 5.3010 6.8380 6.0720 4.9730 6.5480 4.3980 3.5300 4. 6730 10700.0000 30.8550 173.6470 4.6980 4.8180 3.5570 4.2380 10800.0000 27.7600 4.8480 4.6160 179 9780 10900.0000 57.4990 4.7940 5.2940 176 0410 11000.0000 28.7240 4.6910 4.2740 176 0410 11100.0000 28.7340 3.8400 4.0310 184 2630 11200.0000 58.3110 6.8060 6.4400 175 9070 11300.0000 27.9120 5.0940 5.5230 179 9780 11400.0000 35.0680 6.7420 7.1780 175 9070 11500.0000 32.1240 6.3820 6.6010 179 9780 11555.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9145.000000 Tape File End Depth = 11555.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet Tape Subfile 4 is type: LIS 4.4180 5. 6390 3.9580 4.3730 6.0980 5.6540 7.0030 6.4550 -999.2500 4 2590 5 3140 3 7010 4 3530 5 6160 5 8900 6.7950 6. 1750 -999.2500