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Home My WebLink About192-136MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-34 PRUDHOE BAY UNIT S-34 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/01/2024 S-34 50-029-22305-00-00 192-136-0 W SPT 8330 1921360 2082 576 576 575 575 87 220 219 215 4YRTST P Sully Sullivan 1/9/2024 tested with 120 deg diesel 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-34 Inspection Date: Tubing OA Packer Depth 60 2305 2260 2252IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240110133200 BBL Pumped:4.4 BBL Returned:4.4 Friday, March 1, 2024 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg��-{5 q DATE: Thursday, February 6, 2020 P.I. Supervisor ! 1-1 �6)� SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. S-34 FROM: Bob Noble PRUDHOE BAY UNIT S-34 Petroleum Inspector Ste: Inspector Reviewed By: P.1. Supry 7� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-34 Insp Num: mitRCN200111150714 Rel Insp Num: API Well Number 50-029-22305-00-00 Permit Number: 192-136-0 Packer Depth Well S-34 Type Inj W "TVD 8330 PTD 1921360 •IType Test SPT Test psi 2082 BBL Pumped: 5 2 'BBL Returned: 5 Interval11 e 4vRTST �p/F P ✓ Notes: Inspector Name: Bob Noble Inspection Date: 1/10/2020-' Pretest Initial 15 Min 30 Min 45 Alin 60 Min nbing 5 -IU - 539 536 536 IA �6 1.600 2578 - %510 QA 09 335 - 352' 349 -- Thursday, February 6, 2020 Page I of I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,February 18,2016 C� P.I.Supervisor \?C Z!l 'q i i @ SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-34 FROM: Jeff Jones PRUDHOE BAY UNIT S-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry. NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-34 API Well Number 50-029-22305-00-00 Inspector Name: Jeff Jones Permit Number: 192-136-0 Inspection Date: 1/9/2016 Insp Num: miIJJ160110123943 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-34 Type Inj '' TVD 8330 Tubing 299 299 - 299 - ( 299 - PTD 1921360 ,Type Testi SPT Test psi 2082 - IA 894 2505 2471 - 2467 Interval INITAL P/F P ✓ OA 500 676 - 672 - 670 - Notes: Post RWO MIT-IA.3.1 BBLS diesel pumped. 1 well house inspected,no exceptions noted. SCANNED SEP. 2 7 Z016 Thursday,February 18,2016 Page 1 of 1 _9 v• • • M N e�� f 1/49 cfl - 0 2 � V _c) r Y N _IDo 11 • F- (L p�� Z txo F- > (o O (o d 0 ,-) > E �+ O S2 O O O '6 - s] O D FW- 0 }° CO fl- Q 0 0 J W In c0 c0 c0 c0 O O MO E .- Cr) I- ig H O O (Ca m R R C //j0 0 C O C co N Z ) -) -. ) - . Z E (o (n Fw- M o o ti N a, N -O Q- j V) Z Q N C. (6 V Q a) Z < 0 i J -p E O >, ctc V +-, I-- ,_ . _c ,_ , D c7, ''' ro C 0 0 0 0 0 0 0 0 ,-+ U s= s= U.' 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V U U U V 0 00 a C m m Q O N M O O O cD O O O O O O O O u N u) O) O) N 6) O M ,- 1 co N v N M C_ m M co (0 O r co N N N 0 0 r r M M 0 in 0 N N N N N N N N N a- U n 6) O O 6 O O) O O) O xiO NNNNNNNIN a 7,-,01 O O O O O O O O 0 0 0 0 0 0 0 0 .- .- in co co in u•) 10 u) U, �, 3 a) CO E.5 e�-1 •C a u C = rz m E u ea u o) a > N�{ Q Q w V O N c,) o w 3 a ty. • m M M M r N N O E a F_ 2 a Q• " N Y Y 0- o cc Z IV Q. topp +' •1. Q. .s�-ti Cu n Ct. CO an coo 8 C/7 L I .t. F- a a s MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 14,2016 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-34 FROM: Jeff Jones PRUDHOE BAY UNIT S-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-34 API Well Number 50-029-22305-00-00 Inspector Name: Jeff Jones Permit Number: 192-136-0 Inspection Date: 1/10/2016 Insp Num: mitJJ160110123943 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill S-34 Type In' w TVD 8505 Tubing 299 . 299 299 299 ' PTD 1921360 , Type Test SPT Test psi 2126 - IA 894 2505 • 2471 . 2467 T- Interval !VITAL - P/F P ;/ OA 500 676 . 672 . 670 Notes: Post RWO MIT-IA.3.1 BBLS diesel pumped. 1 well house inspected,no exceptions noted. ty SCANNED Thursday,January 14,2016 Page 1 of I • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday,January 10, 2016 8:14 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;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; '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; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric;Glasheen, Brian P; Regg,James B (DOA) Subject: OPERABLE:Injector S-34(PTD#1921360)AOGCC MIT-IA Passed Attachments: S-34 2010-July TIO &Injection plots.doc; S-34 WBS.pdf All, Injector S-34(PTD#1921360) passed an AOGCC witnessed MIT-IA to 2500 psi on January 09, 2016. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED SEP 1 5 2016 BP Alaska-Well Integrity Coordinator 0 tGlifti mac.► VV,n;r; Y Y C-(14-.:.ton WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, December 31, 2015 10:14 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; 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; '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; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Regg, James B (DOA) (jim.reqg©alaska.gov) Subject: UNDER EVALUATION: Injector S-34 (PTD #1921360) Rig Workover Complete MIT-IA Passed Ready to be put on injection All, Injector S-34(PTD#1921360) underwent a rig Workover completed on November 16, 2015. The tubing was replaced during the rig Workover to repair the tubing x inner annulus communication. A MIT-T and a MIT-IA passed on November 16,2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Under Evaluation so the well can be put on injection. S • Plan Forward: 1. Operations: Place well on injection 2. DHD: Perform AOGCC witnessed MIT-IA once well is thermally stable Use caution while placing well on injection due to fluid packed annuli and the potential for annular fluid expansion. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator Global Wells 11 IGW Orgarttzatior Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent:Tuesday, July 13, 2010 8:44 AM To: AK, D&C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, D&C WL&Completions Coordinator; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Ohms, Danielle H; Cismoski, Doug A; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Cc: Sayed, Mohamed; King, Whitney; Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Injector S-34 (PTD #1921360) Failed MIT-IA All, Injector S-34 (PTD#1921360)failed a MIT-IA on 07/12/10 and no longer meets the AOGCC requirements to remain on injection. It has been shut in and reclassified as Not Operable. A TIO plot, injection plot, and wellbore schematic are included for you reference. The well has been added to the quarterly report of shut-in injectors sent to the AOGCC. The plan forward is to: 1. D: Liquid leak rate IA 2.W: PPPOT-T 3. Production Engineer: Evaluate results to plan either a repair or secure Please call Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907)659-5102 cell: (253) 576-6153 tiffg0(a�bp.com 2 •• Injector S-34 (PTD #1921360)TIO 14/6t11-36 4.000 { 3400 —01—Mg —II-1A 2,000• —46—OA -+--00A t 0004 rama On 1,000• er 01/17/10 04/24/10 P3/Oino IE/OB/10 05/19/10 05/22/10 00/79/10 04N6/0 06/12,00 06/19/10 06/14/10 07/63/10 07/10/10 Injector S-34 (PTD #1921360) Injection Plot Welk 5-34 560 4,800 5+p 4,600 520 4.400 500 1100 400 460 4,000 440 3200 420 3,000 400 3.100 380 3200 360 3,000 310 320 2.800 —WHIP 300 2600 a —PW 200 2,400 260 2100§ - -0614 240 2000 On 220 1.000 1043, 1,600 180 160• 1.400 140. 1100 120• 1,000 100 800 80 600 6D 400 40- 20 200 04/17/10 042410 05/01/10 05,06/10 05/15/10 05/12/10 0529/10 06/0.5/10 06/12/10 06/19/10 06/26/10 07/03/10 07/10,00 • • het s-34- Regg, James B (DOA) e at/34,0 From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> `z,, Sent: Thursday, December 31, 2015 10:14 AM '`�,,/r To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS `13AK Prod Controllers;AK, OPS PCC Ops Lead; 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; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Glasheen, Brian P; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector S-34 (PTD #1921360) Rig Workover Complete MIT-IA Passed Ready to be put on injection Attachments: S-34 2010-July TIO &Injection plots.doc; S-34 WBS.pdf All, Injector S-34 (PTD#1921360) underwent a rig Workover completed on November 16, 2015. The tubing was replaced during the rig Workover to repair the tubing x inner annulus communication. A MIT-T and a MIT-IA passed on November 16, 2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Under Evaluation so the well can be put on injection. Plan Forward: 1. Operations: Place well on injection 2. DHD: Perform AOGCC witnessed MIT-IA once well is thermally stable Use caution while placing well on injection due to fluid packed annuli and the potential for annular fluid expansion. Please call with any questions or concerns. Thank you, Kevin Parks BP Alaska-Well Integrity Coordinator i ai Weft 'SCANNED rgarniatior Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, July 13, 2010 8:44 AM To: AK, D&C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, D&C WL &Completions Coordinator; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Ohms, Danielle H; Cismoski, Doug A; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Cc: Sayed, Mohamed; King, Whitney; Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Injector S-34 (PTD #1921360) Failed MIT-IA 1 • • Injector S-34 (PTD #1921360) TIO Plot WOtS-34 4.000 ' 3000. i- —b 2000 + 00A +000* On 1.000• 1 r _ /1 004/17/10 04/24/10 0641/10 05/09/10 05/15/10 05/72/0 05/29/10 06/061 /1 Injector S-34 (PTD #1921360) Injection Plot We16-31 500-. 4,800 540 • 4.600 520- 500 4.400 480• 4200 400, 4,000 440 3000 420• 3,603 400- 3,/00 300 3,200 360- 3.000 340 320- 2800 -W1YP 4300. 2800 -SW 200- 2,400 -M 200- 2200 -01 24 2.000 ••• •On 220 1,900 200• 100• 1.600 100- 1.400 "--) 140• 1,200 120- 1,000 00 80 --.� 800 600 W- a0- 400 20- 200 0//17/10 04/24/10 05/01/10 09/0800 05/15/10 05/2200 0529/10 05/05/10 0607/10 06/19/10 0026/10 07/0./10 07/10/10 • 0 TREE= 7-1/16"5M CIW WELLHEAD= 13-3/8"McEVOY SAFETY NOTES: ALL 7"PKR • ACTUATOR= OTB S-34 ASSY DEPTHS ARE E LINE NO KB. ELEV= 70.44' BF. ELEV= 28.65' KOP= 3503' I Max Angle= 45 @ 5264' 2079' —5-1/2"OTIS SSSV LAND. NIP ID=4.562" Datum MD= 10247' 0 Datum TVD= 8800'SS 1 13-3/8"CSG,68#,L-80, D=12.415" H 2901' GAS LIFT MANDRELS ST MD TV D DEV TYPE VLV LATCH FORT DATE 5 2977 2906 1 OTIS RA 4 5180 4905 47 OTIS RA Minimum ID = 3.725" @ 9896' 3 7303 6401 44 OTIS RA 4-1/2" PARKER SWN NIPPLE 2 8875 7522 33 OTIS RA 1 9812 9310 25 OTIS RA I I 9831' —14-1/2" PARKER SWS NIP, D=3.813" R X 1 9848' —19-5/8"x 5-1/2"11W HBBP PKR, ID=4.75" I 9879' —14-112" PARKER SWS NIP, D=3.813" I 1 9896' —14-1/7 PARKER SWN NIP, ID=3.725" 15-1/2"TBG, 17#, L-80, 0.0232 bpf, D=4.892" 1-1 9906' \ 9906' —15-1/2"W/LEG TOPOF7"LNR H 9907 9910' H ELMD TT LOGGED 03/10/93 1 1 9-5/8"CSG,47#, NT-80S, D=8.681" H 10114' 1 PERFORATION SUMMARY REF LOG: SWS BHCS ON 12/31/92 ANGLEAT TOP PERF:22 @ 10117' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE g 'ZI—_ 10193' —17"x 4" BAKER FB-1 PKR, D=4.0" 3-3/8" 4 10117-10157 0 06/30/93 i ' I 10205' —4-1/2"X NIP, ID=3.813" 1 3-3/8" 6 10258-10300 0 04/29/93 3-3/8" 6 10300-10354 0 04/29/93 I I 1, 10208' —14-1/2"XN NP, ID=3.725" 1 / \ ( 10211' —14-1/2"W/LEG 1 PBTD 10551' 41 .414 11111• . 17" LNR,26#, L-80 NSCC,0.0383 bpf, ID=6.276" H 10629' (......0, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/14/93 ORIGINALCOMFLE11ON WELL: S-34 03/09/01 SIS-M-1 CONVERTED TO CANVAS PERMIT Nb: 92-1360 03/12/01 SIS-MD FINAL API Nb: 50-029-22305-00 09/07/01 RN/TP CORRECTIONS Sec. 35,T12N,T12E BP Exploration(Alaska) STATE OF ALASKA � OALASKA OIL AND GAS CONSERVATION COMMIS�fON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing Q Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Il Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 192-136 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service RI 6. API Number: 50-029-22305-00-00 7. Property Designation(Lease Number): ADL 028257 8. Well Name and Number: PBU S-34 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: Cement Evaluation PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10635' feet Plugs measured None feet DEC1 f1 true vertical 9226' feet Junk measured None feet E 6 2015 Effective Depth: measured 10551' feet Packer measured 9656',10193' feet true vertical 9150' feet Packer true vertical 8330',8822' feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 76 20" 35-111 35-111 1490 470 Surface 2868 13-3/8" 34-2902 34-2900 5020 2260 Intermediate 10085 9-5/8" 31 -10115 31 -8750 6870 4760 Production Liner 723 7" 9907-10630 8559-9221 8160 7020 Perforation Depth: Measured depth: 10117-10354 feet ofi't; True vertical depth: 8752-8970 feet Tubing(size,grade,measured and true vertical depth) 5-1/2",17#,L-80;4-1/2" 29-9750;10193-10211 29-8415;8822-8838 Packers and SSSV(type,measured and 5-1/2"HES TNT Packer 9656' 8330' true vertical depth) 4"Baker FB-1 Packer 10193' 8822' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 100 250 Subsequent to operation: 0 0 0 0 14.Attachments:(required per 20 AAc 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory ❑ Development 0 Service IRI. Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG IZI GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-010 . Contact Warren,Abigail M Email Abigail.Warren@bp.com Printed Name Joe LastufkTitle Drilling Technologist 64_0.. Signature 1 \� Phone +1 907 564 4711 Date 121,(p/15 V Form 10-404 Revised 5/2015 �` 1/�o��F7 L RBDMS PrC. 2.1 7015 Submit Original Only • • S-34 Well History (Pre-Rig Workover) tin.,,, ., ... J.. ***WELL SHUT IN ON ARRIVAL***(SLB E-LINE: JET CUT) INITIAL T/I/O =450/500/0 MIRU. PT. RIH WITH 4.15" POWER CUTTER. TUBING CUT @ 9725'. CONFIRM SHOT AT SURFACE. RDMO. FINIAL T/I/O = 350/300/0 7/3/2015 ***JOB COMPLETE. WELL SHUT IN ON DEPARTURE*** T/I/0=260/322/0. (CMIT TxIA to 2500 psi/ Pre-RWO) CMIT TxIA to 2500 psi. PASSED. T/I lost 15/13 psi in first 15 minutes & 12/12 psi in second 15 minutes Total loss= 27/25 psi. Bleed T/I pressure down to 189 psi FWHP T/I/O 126/129/0 SV/SSV/WV= shut 7/5/2015 IA/OA OTG. T/I/0 = SSV/160/0. Temp = SI. Cement C & B lines (Pre Rig). No AL. Pumped 2.5 gallons of hydraulic fluid down each of the control and balance lines to ensure communication. Pumped 3 gallons of squeeze crete (D163 Microfine cement, 1.5 gallons each)down the control and balance lines. Displaced each line to the needle valve with hydraulic oil. FWP's =SSV/160/0. 7/6/2015 SV, WV, SSV = C. MV= 0. IA, OA = OTG. 1220 hrs. T/I/O = SSV/170/0. Temp =SI. PT C & B lines -Passed- (Pre RWO). No AL. Pressured up the Control line to 2549 psi w/ hydraulic fluid. The Control line lost 32 psi in 5 minutes (PASS). Pressured up the Balance line to 2569 psi w/ hydraulic fluid. The Balance line lost 53 psi in 5 minutes (Pass). Bled C & B line pressure. Tags hung. FWP's = 7/10/2015 SSV/170/0. T/I/0 = 136/200/0 Circ Out( Pre-RWO ) Pumped 5 bbl Neat Spear followed by 83 bbl 1% Kcl and the Hardline Developed a leak, Well Support arrived to change the Leaking Swing. Dispatched 60 bbl 1% Kcl to make up for the already pumped Volume. Resume pumping down TBG 791 bbls 1% KCL followed by 194 bbls diesel. F/P Hardline to S-3 W/ 1 bbl MEOH then U-Tube TBG IA for a hr .. FWHP,s = 147/161/25 Valve 7/12/2015 positions SV , SSV, WV,= C, MV= 0 , IA, OA=OTG, Notified Pad Operater of T/I/O = SSV/Vac/Vac. Temp = SI. MIT-OA to 1200 psi (pre RIG). OA FL near surface. 7/14/2015 ***WSR continued from 7-14-15.*** T/I/0 = SSV/Vac/Vac. Temp = SI. MIT-OA PASSED to 1200 psi (pre RIG). OA FL near surface. Used 3 bbls of AMB DSL to pressure up OAP to 1201 psi. OA lost 38 psi in the 1st 15 minutes & 15 psi in the 2nd 15 minutes, for a total loss of 53 psi in 30 minutes. Bled OAP to 0 psi (2.3 bbls). Hung tags &AFE sign. Final WHP's = SSV/Vac/0. SV, SSV= Closed. WV= LOTO'ed. MV= Open. IA& OA= OTG. NOVP. 04:30 7/15/2015 T/I/O = SSV/0/0, Temp: SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre RWO PPPOT-T: Stung into test void, (50 psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued LDS to 500 ft/lbs. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Stung into test void, (0+ psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued LDS to 500 ft/lbs. Pumped through void, good returns. Pressured test void to 3,500 psi for 30 minute test. Lost 100 9/13/2015 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. 10/22/2015 T/I/O = ! ! S-34 Well History (Pre-Rig Workover) T/I/O=Twc/220/0. Remove 6" CIW Upper Tree. Install 6" CIW Dry hole#99. Install 2" IA CIW piggy back valve#4. Install 3" OA FMC piggy back#82. Torque all flanges to API SPECS. P/T Dry hole to 300 low. 5000 high (PASSED) Charted and retaiend. P/T IA and OA to 300 low, 3500 high for 5 min each (PASSED). Charted and retained. Bleed IA to 0 10/24/2015 PSI. SEE LOG FOR DETAILS. RDMO ***JOB COMPLETE*** Final T/I/O=TWC/0/0. T/I/0=200/200/0. RU CIW lubricator with 6"J-plug TWC#408. Stabbed onto tree and ran down plug , tagging @135". Confirmed LTT and removed lubricator. RDMO***Job in 10/24/2015 Progress***. SEE LOG FOR DETAILS. Final T/I/O=TWC/200/0. Hung TWC signage T/I/O =TWC/10/5. Temp = SI. WHPs (Pre Rig). WH, flowlines, and scaffolding removed. No SSV or wing valve. Double casing valves on IA& OA. Unable to verify 6" valve positions above tubing hanger. 10/29/2015 IA, OA = OTG. 03:30. T/I/O =TWC/10/5. Temp =SI. WHPs (Pre Rig). WH, flowline, and scaffolding removed. No SSV or wing valve. Double casing valves on IA& OA. Integral flanges installed on IA&OA casing valves. Unable to verify 6"valve positions above tubing 10/29/2015 hanger. • • North America-ALASKA-BP Page 1 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X401161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34©70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/8/2015 12:00 - 16:30 4.50 RIGD P PRE RIG DOWN AND PREPARE TO MOVE TO S-34 -BLOW DOWN AND RIG DOWN ALL LINES -RIG DOWN RIG FLOOR FOR SKIDDING -SKID RIG TO MOVING POSITION -FINISH CHECKLIST FOR RIG MOVE 16:30 - 17:30 1.00 RIGD P PRE MOVE RIG OFF OF GC-1D -PJSM -FUNCTION TEST ESD IN CELLAR FOR RIG MOVE -MOVE RIG OFF OF WELL AND ON STAGE AT FACILITY ENTRANCE 17:30 - 19:00 1.50 RIGD P PRE INSTALL BOOSTERS ON RIG FOR MOVE -PJSM -INSTALL FRONT AND REAR BOOSTERS ON RIG 19:00 - 19:30 0.50 MOB P PRE PJSM FOR RIG MOVE 19:30 - 00:00 4.50 MOB P PRE MOVE RIG FROM GC-1D TO S-34 -GC1 ACCESS ROAD LEFT ON K PAD ROAD -K PAD ROAD LEFT ON TO SPINE ROAD AT 18:30 -STAGED ON J-PAD FOR TRAFFIC TO GO AROUND AT MIDNIGHT. 11/9/2015 00:00 - 10:00 10.00 MOB P PRE MOVE RIG FROM GC-1D TO S-34 -STAGED ON J-PAD FOR TRAFFIC TO GO AROUND AT MIDNIGHT -CROSSING EAST KUPARUK RIVER BRIDGE AT 03:30 -CROSSING WEST KUPARUK RIVER BRIDGE AT 05:00 -HOLD FOR TRAFFIC ON WEST SIDE OF KUPARUK RIVER AT 05:30 -ON S-PAD ACCESS ROAD AT 06:30 -PULL ON TO S-PAD AT 10:00 AND STAGE ON EDGE OF PAD 10:00 - 12:00 2.00 RIGD P PRE REMOVE FRONT AND REAR BOOSTER WHEELS AND PREP RIG TO SPOT OVER S-34 -PJSM -REMOVE BOOSTER WHEELS AND STAGE ON EDGE OF PAD -LINE UP RIG MATS TO SPOT RIG OVER WELL. 12:00 - 13:00 1.00 MOB P PRE SPOT RIG OVER WELL S-34,SHIM AND LEVEL RIG. -PJSM -CHECK PRESSURES ON TREE:TUBING/IA=0 /0 PSI -TEST ESD FOR MOVING SYSTEM IN CELLAR -JOCKEY RIG AROUND AND SPOT OVER WELL 13:00 - 14:00 1.00 RIGU P PRE SKID RIG FLOOR -PJSM -SKID RIG FLOOR INTO DRILLING POSITION Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 2 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:30 2.50 RIGU P PRE RIG UP FOR WORKOVER OPERATIONS -PJSM -RIG UP RIG FLOOR -COVER WELL CELLAR WITH PLYWOOD -SPOT ROCKWASHER AND RIG UP -PREP PITS FOR FLUID ***ACCEPT RIG AT 16:30 HRS ON 11/09/2015*** 16:30 - 18:00 1.50 RIGU P PRE STAGE TOOLS IN CELLAR FOR TESTING TWC AND NIPPLING DOWN/NIPPLING UP -LOAD PITS WITH 290 BBLS 8.5 PPG SEAWATER 18:00 - 18:30 0.50 RIGU P PRE H2S/RIG EVACUATION DRILL AND AAR -TESTED AUDIBLE RIG EVACUATION ALARM AND ESD -MUSTER WITH 3RD PARTIES AT PRIMARY MUSTER AREA -AAR:ALL EQUIPMENT WORKED AND EVERYONE ACCOUNTED FOR 18:30 - 21:00 2.50 DHB P PRE RIG UP AND PRESSURE TEST TWC -250/4000 PSI FOR 5/5 CHARTED MIN -TEST MET ASSURANCE CRITERIA -RIG DOWN TEST EQUIPMENT -SUCK OUT TREE FROM NIPPLE DOWN SIMOPS: -REMOVE BOOSTER CRADLE -PREP TOP DRIVE AND FLOOR VALVES FOR BOP TEST -GREASE CHOKE MANIFOLD 21:00 - 00:00 3.00 WHSUR P DECOMP NIPPLE DOWN TREE AND ADAPTER FLANGE -PJSM WITH RIG CREWAND CAMERON WELLHEAD REPRESENTATIVE -BLEED OFF VOID AND CONTROL LINES -ATTEMPT TO BREAK ADAPTER FLANGE FROM TREE;UNABLE TO SEPARATE -INSTALL FLANGE SPREADERS AND ATTEMPT AGAIN;NO SUCCESS -HEAT ADAPTER FLANGE WITH STEAM FOR 30 MIN -SEPARATE ADAPTER FLANGE AND TREE -LAY DOWN TREE AND ADAPTER FLANGE -INSTALL 7"IJ4S CROSSOVER-6 1/2 TURNS TO THE RIGHT -INSPECT HANGER THREADS-OK -CHECK LOCK DOWN SCREWS AND GLAND NUTS. Printed 11/30/2015 1:26:18PM • I North America-ALASKA-BP Page 3 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/10/2015 00:00 - 06:00 6.00 BOPSUR P DECOMP NU BOPE 13-5/8"5M -PJSM -NIPPLE UP AND CENTER BOPE STACK -INSTALL RISER AND NIPPLE UP FLOW LINE -NU BOPE STACK WITH FOUR PREVENTER CONFIGURATION:ANNULAR,3-1/2"BY 6" VBR'S,BLIND SHEARS,MUD CROSS,3-1/2" BY 6"VBR'S AND 2'SPACER SPOOL. - PJSM FOR MAKING UP CHOKE AND KILL LINES -NU CHOKE LINE AND KILL LINE. -CHANGE UPPER PIPE RAMS TO 3 1/2"x 6" VBR -REDRESS VBR WITH NEW PACKING ELEMENTS PRIOR TO INSTALL -INSPECT BLIND/SHEAR RAMS -INSTALL NEW NEW BLIND/SHEAR RAMS 06:00 - 09:00 3.00 BOPSUR P DECOMP RIG UP TO TEST BOP'S AS PER THE WELL PLAN -PJSM FOR RIGGING UP TEST EQPT 09:00 - 16:00 7.00 BOPSUR P DECOMP PRESSURE TEST ALL BOPE AS PER AOGCC REGS,SUNDRY#315-488,AND GP 10-45. -PJSM,REVIEW DDI SOP AND PRESSURE CROSSCHECK WITH CONFIRMATION OF CORRECT RESPONSES. -VERIFY LINE UP AND FILL STACK AND CHOKE MANIFOLD. -TEST BOPE TO 250/4000 PSI FOR 5/5 CHARTED MIN. -TEST ANNULAR TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST BLOWOUT PREVENTERS AND ALL ASSOCIATED BOPE. -UPPER 3-1/2"X 6"VBR'S TESTED WITH 4" AND 5-1/2"TEST JOINTS. -LOWER 3-1/2"X 6"VBR'S TESTED WITH 4" AND 5-1/2"TEST JOINTS. -ANNULAR TESTED WITH 4"TEST JOINT. -BLIND/SHEAR RAMS TESTED -TEST CHOKE MANIFOLD VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES. -TEST MANUAL AND HYDRAULIC IBOP'S ON TOP DRIVE. -TEST FLOOR AND DART VALVES -PERFORM DRAW DOWN TEST OF ACCUMULATOR. -FUNCTION BOPE FROM REMOTE PANEL AND MAIN UNIT. -TEST GAS ALARMS. -ALL TESTS WITNESSED BY TOOLPUSHER AND WSL AOGCC GIVEN NOTIFICATION OF BOPE TEST 10/09/2015 03:00 HRS. *AOGCC INSPECTOR JEFF JONES WITNESSED BOPE TEST Printed 11/30/2015 1:26:18PM • 11111 North America-ALASKA-BP Page 4 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 16:30 0.50 BOPSUR P DECOMP RD TEST EQUIPMENT -BLOW DOWN CHOKE AND KILL LINES -PJSM -BLEW DOWN CHOKE AND KILL LINES AS PER DOYON SOP -LINE UP CHOKE MANIFOLD 16:30 - 17:30 1.00 BOPSUR P DECOMP RIG UP LINES FOR CIRCULATING OUT FREEZE PROTECT TO FLOW BACK TANK -PJSM -RIG UP LINES FOR CIRCULATING OUT TO FLOW BACK TANK AS PER DOYON SOP _ 17:30 - 19:30 2.00 WHSUR P DECOMP RU DUTCH RISER/LUBRICATOR AND PRESSURE TEST -PJSM WITH DSM REPS -INSTALL LUBRICATOR W/QUICK TEST SUB -PT LUBRICATOR AND QUICK TEST SUB 250 PSI LOW/4000 PSI HIGH FOR 5 MINUTES EACH-GOOD LEAK TIGHT TEST -PULL TWC-0 PSI ON WELL -RIG DOWN LUBRICATOR/DUTCH RISER/ LD TOOLS AND EQUIPMENT 19:30 - 21:00 1.50 WHSUR P DECOMP RIG UP&FLUID PACK FOR CIRCULATING OUT FREEZE PROTECT -PJSM -RIG UPAS PER DOYON SOP PRESSURE TEST SURFACE LINES FOR CIRCULATING OUT FREEZE PROTECT -PJSM -PRESSURE TEST 250 PSI LOW FOR 5 MINUTES -PRESSURE TEST 4,000 PSI HIGH FOR 5 MINUTES 21:00 - 00:00 3.00 WHSUR P DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT -PJSM FOR CIRC OUT:DISCUSS PROPER LINE UP,SPILL HAZARDS,AND EXPECTED PRESSURES -WSLAND TP VERIFY CORRECT LINE UP WITH THE DRILLER PRIOR TO PUMPING -CIRCULATE 75 BBLS DOWN THE IA TAKING RETURNS UP TUBING OUT TO THE FLOW BACK TANK -6 BPM,W/1850 PSI -CIRCULATE OUT 215 BBLS DOWN THE TBG TAKING RETURNS OUT THE IA TO THE FLOW BACK TANK -6 BPM,960 PSI, -FLWO CHECK THE WELL 10 MIN-NO FLOW SIM OPS: -BRING UP CONTROL LINE SPOOLER& CASING EQUIPMENT 11/11/2015 00:00 - 01:00 1.00 BOPSUR P DECOMP CONT:PICKING UP CASING EQUIPMENT -PU&MU SAFETY JOINT WITH 5-1/LIFT SUB PU&MU LANDING JNT -PU 1-JNT OF 4"DP&MAKE UP 7-5/8"IJ4S XO -PJSM FOR MAKING UP LANDING JOINT TO THE HANGER:REVEW CAMERON PROCEDURE FOR MAKE UP AND PULL HANGER FREE. -RIH&MAKE UP TO HANGER W/7-1/2 TURNS Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 5 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 02:00 1.00 WHSUR P DECOMP PULL TUBING HANGER BACK OUT LOCK DOWN SCREWS -PJSM FOR BOLDS,ENSURE CAMERON PROCEDURE IS REVIEWED AND CORRECT LDS MEASURMENTS ARE NOTED -PULL HANGER FREE WITH 225K,-25-30K OVERPULL -PUW-205K 02:00 - 06:00 4.00 PULL P DECOMP CIRCULATE BOTTOMS UP -SHUT THE ANNULAR AND CIRCULATE BOTTOMS UP THROUGH THE CHOKE&GAS BUSTER -6 BPM,75 PSI. -FLUID OUT OF BALANCE,CIRC SURFACE TO SURFACE 06:00 - 09:30 3.50 PULL P DECOMP LAY DOWN LANDING,HANGER,AND XO'S -PJSM -LAY DOWN AS PER DOYON SOP MAKE UP SAFETY JOINT WITH 5-1/2"LIFTER -PJSM -MAKE UP SAFETY JOINT AS PER DOYON SOP PULL AND LAY DOWN 5-1/2"17#L-80 TUBING PJSM -POOH AS PER DOYON SOP -F/9690'MD,TO 7,630'MD -PUW=170K TERMINATE CONTROL LINE F/OTIS HRQ SSSV AND L/D -PJSM 09:30 - 10:00 0.50 PULL P DECOMP CLEAR RIG FLOOR FOR SPOOLER -PJSM -HANGER AND BAND REMOVAL EQUIPMENT -26 STAINLESS STEEL BANDS RECOVERED 10:00 - 12:00 2.00 PULL P DECOMP POOH AND LAY DOWN 5-1/2"TUBING -PJSM -POOH AS PER DOYON SOP -F/7630'TO 5,635'MD -PUW=150K -MONITOR TRIP ON TRIP TANK-HOLE TAKING CORRECT HOLE FILL FLOW CHECK WELL -WELL STATIC -OA PRESSURE=0 PSI Printed 11/30/2015 1:26:18PM I North America-ALASKA-BP Page 6 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 18:00 6.00 PULL P DECOMP CONTINUE POOH,LAYING DOWN 5-1/2" TUBING -PJSM -POOH AND LAY DOWN AS PER DOYON SOP -F/5,635'TO 2,700' -MONITOR TRIP ON TRIP TANK-HOLE TAKING CORRECT HOLE FILL PIT AND FLOW INCREASE,FLOW CHECK WELL -WSL SIMULATED INFLUX-KICK WHILE TRIPPING DRILL HELD -AFTER ACTION REVIEW CONTINUE POOH AND LAYING DOWN 5-1/2" TUBING -PJSM-POOH AND LAY DOWN AS PER DOYON SOP -F/2700'TO SURFACE -TOTAL: 241-JTS AND 1-CUT JOINT=2.10' WITH 6.25"FLARE -4-GLM'S,1-SSSV, 18:00 - 19:00 1.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR CLEAN ALL 5-1/2"HANDLING EQUIPMENT -PJSM -BEAVER SLIDE OPS REMOVING HANDLING EQUIPMENT FROM RIG FLOOR 19:00 - 22:00 3.00 WHSUR P DECOMP CHANGE OUT 9-5/8"INNER CASING PACK OFF -PJSM WITH DDI,CAMERON WELLHEAD SPECIALIST:REVIEW PROCEDURE& DISCUSS HAZARDS ASSOCIATED -DRAIN THE STACK,MU PACK OFF PULLING TOOL RIH AND ENGAGE PACK OFF. -CIW BACKED OUT LOCK DOWN SCREWS LOOKING FOR SIGNS OF CASING GROWTH. -PULLED IC PACK OFF FREE:PULLED FREE W/8K OVERPULL -PULLED ABOVE THE ROTARY TO EXAMINE THE PACK OFF. -CIW REP IDENTIFIED THE PACK OFF HAD PARTED LEAVING THE LOWER SEAL ASSEMBLY STILL IN THE WELL HEAD. DISCUSS PLAN FORWARD WITH ANCHORAGE ODE: 22:00 - 00:00 2.00 WHSUR P DECOMP MOBILIZE BAKER FISHING BHA -PJSM FOR PICKING UP BHA -PU FISHING BHA TO THE RIG FLOOR -LOAD AND STRAP 6-1/4"DRILL COLLARS IN THE PIPE SHED -INSTALL WEAR RING W/9.25"ID 11/12/2015 00:00 - 01:00 1.00 CLEAN P DECOMP CONTINUE PREP WORK FOR PICKING UP OVERSHOT BHA -FILL STACK,-MONITOR WELL ON TRIP TANK-ZERO GAIN/LOSS -STRAP&TALLY 6-1/4"DRILL COLLARS. -VERIFY LIFTING TOOLS AND RATINGS FOR PICKING UP BHA. Printed 11/30/2015 1:26:18PM S • North America-ALASKA-BP Page 7 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/me:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. LAI:500292230500 Active datum:S-34©70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 03:00 2.00 CLEAN P DECOMP PICK UP AND MAKE UP OVERSHOT BHA TO 232' -PJSM FOR BHA MAKE UP:DISCUSS RED ZONE&DROPPED OBJECTS, NON-SHEARABLES ACROSS THE STACK -MAKE UP OVERSHOT BHAAS DIRECTED BY BOT REP 5-1/2"DRESS OFF GUIDE W/EXTENSION, 5-1/2"GRAPPLE OVERSHOT,BUMPER SUB, JAR,PUMP OUT SUB,XO,(6)6-1/4"COLLARS, XO EXCELLERATOR,XO TO DP -TOTAL LENGTH-232.6',PUVV-68K MONITOR TRIP ON TRIP TANK 03:00 - 05:00 2.00 CLEAN P DECOMP SINGLE IN THE HOLE WITH OVERSHOT BHA FROM 232'TO—2200' -MONITOR TRIP ON TRIP TANK-CORRECT DISPLACEMENT OBSERVED 05:00 - 07:00 2.00 CLEAN P DECOMP PICK UP MAKE UP AND SET RTTS -PJSM FOR PICKING UP&SETTING RTTS. -PU&RIH WITH RTTS AND SET ONE FULL STAND BELOW THE ROTARY. -SET RTTS AS DIRECTED BY HALLIBURTON REP. -PJSM FOR PRESSURE TESTING THE RTTS: REVIEW SOP,VERIFY LINE UP,DISCUSS PRESSURE CROSS CHECK LIST. -PRESSURE TEST 250 PSI LOW,3500 PSI HIGH.5 MIN EACH CHARTED-GOOD TEST -RELEASE FROM TOOL AND STAND BACK STAND OF DP. 07:00 - 08:30 1.50 CLEAN P DECOMP NIPPLE DOWN BOP STACK. -PJSM FOR ND OPERATIONS:SOP REVIEW, DISCUSS HAZARDS AND MITIGATIONS -BARRIERS IN PLACE FOR STACK BREAK PX PLUG,RTTS, -SET STACK BACK IN CRADLE AND INPSECT TUBING SPOOL FOR DAMAGE-NO DAMAGE OBSERVED 08:30 - 10:00 1.50 DHB P DECOMP INSTALL NEW 9-5/8"INNER CASING PACK OFF -PJSM WITH CAMERON AND DDI CREW: REVIEW CIW PROCEDURE -PULL OUT REMAINING PIECES OF THE PACK OFF AND REPLACE WITH NEW PACK OFF PER THE CIW PROCEDURE 10:00 - 11:00 1.00 BOPSUR P DECOMP NIPPLE UP BOP STACK&TUBING SPOOL. -PJSM FOR NU OPEATIONS:REVIEW SOP, DISCUSS HAZARDS AND MITIGATIONS -NU PER DDI PROCEDURE 11:00 - 13:00 2.00 WHSUR P DECOMP ENERGIZE PACK OFF SEAL WITH GREASE PACK: -PJSM FOR PRESSURE TESTING:DISCUSS PRESSURE CRITERIA AND HAZARDS ASSOCIATED -PRESSURE TEST THE PACK OFF PER THE RWO PROGRAM:300 PSI LOW 5 MIN,3500 PSI HIGH F/15 MIN(CHARTED) -GOOD TEST -RIG DOWN CAMERON TEST EQUIPMENT -INSTALL WEAR RING Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 8 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/me:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34(4170.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 15:00 2.00 DHB P DECOMP RETRIEVE RTTS -PJSM FOR RTTS RETRIEVAL:REVIEW HALLIBURTON SOP:DISCUSS TRAPPED PRESSURE HAZARDS -RIH WITH 4"DP STAND AND ENGAGE THE RTTS,INSTALL FOSV,VERIFY NO PRESSURE ON THE DRILL STRING -CLOSE ANNUALR AND RELEASE THE RTTS, VERIFY NO PRESSURE BELOW THE ANNULAR,OPEN THE ANNULAR&PULL OUT OF THE HOLE&LAY DOWN THE RTTS TO THE PIPE SHED. 15:00 - 22:30 7.50 CLEAN P DECOMP SINGLE IN THE HOLE WITH OVERSHOT FISHING BHA -PJSM FOR PICKING UP DP -SINGLE IN THE HOLE WITH FISHING BHA ON 4"DP FROM—2,200'TO 9,718' -ESTABLISH PARAMETERS -60 RPM,5K FREE TQ, -SPR'S AT 9718'MD WITH 8.5 PPG SEAWATER -#2 30/40 SPM,100/200 PSI -MONITOR TRIP ON TRIP TANK-CORRECT DISPLACEMENT OBSERVED. 22:30 - 23:00 0.50 CLEAN P DECOMP RIG SERVICE: -GREASE&INSPECT TOP DRIVE. 23:00 - 00:00 1.00 FISH P DECOMP PICK UP SINGLE RIH AND TAG TOP OF FISH AT 9,726'MD -PUW-225K,SOW-163K,RTW-185K, -4 BPM,220 PSI,60 RPM,5K TQ -DRESS OFF TOP OF 5-1/2"TUBING AT 9,726' AS DIRECTED BY BAKER REP --4 BPM,220 PSI,60 RPM,5K TQ,1-2K WOB W/5-9K TQ 11/13/2015 00:00 - 02:30 2.50 FISH P DECOMP CONTINUE-DRESS OFF TOP OF 5-1/2" TUBING AT 9,726'AS DIRECTED BY BAKER REP - 4 BPM,220 PSI,60 RPM,5K TQ,1-2K WOB W/5-9K TQ SHUT DOWN AND ATTEMPT TO ENGAGE TUBING STUB WITH OVERSHOT -SET DOWN 15-20K -SEVERAL ATTEMPTS UNSUCCESSFUL -PICK UP AND CONTINUE DRESSING OFF STUB -ATTEMPT TO ENGAGE STUB WITH SAME RESULTS: -BAKER REP CALLED SUPERVISOR FOR PLAN FORWARD: -ENGAGED TUBING STUB DOWN TO 9,738' TO NO GO,INDICATING POSITIVE SIGN OF GRAPPLE ENGAGEMENT.PU 10K OVER PU WEIGHT TO VERIFY -MAKE SEVERAL HITS WITH THE JARS. -25K OVER X 2 -50K OVER X 2 -75K OVER X 2 -SLACK OFF TO 215K(30K)OVER ROT WEIGHT,ROTATE TO THE RIGHT AND RELEASE K-ANCHOR. -CONFIRM FREE WITH PU,FLUID DROPPING, WELL ON VAC Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 9 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X401161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UV I:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 04:00 1.50 FISH P DECOMP BULL HEAD OPERATIONS -PULLED THE 5-1/2"TUBING FREE FROM THE K-ANCHOR -MONITORED THE WELL-OBSERVED FLUID LEVEL DROPPING IN THE STACK -CLOSED THE ANNULAR PER THE WELL PLAN AND BULLHEADED 50 BBLS -9 BPM,ICP-870 PSI,FCP-920 PSI -SHUT DOWN,VERIFIED NO PRESSURE UNDER ANNULAR ATTEMPT TO CCBU THROUGH THE GAS BUSTER,FLUID LOSS RATE TOO FAST TO CBU, -SHUT DOWN,VERIFY NO PRESSURE BELOW THE ANNULAR,OPEN ANNULAR -SWITCH OVER TO THE TRIP TANK AND TURN ON HOLE FILL&ESTABLISH STATIC LOSS RATE OF 35-40 BPH. 04:00 - 13:00 9.00 FISH P DECOMP POOH WITH 5-1/2"TUBING TAILPIPE FROM 9,726'TO 232' -PJSM FOR POOH:REVIEW DDI PROCEDURE,DISCUSS WELL CONTROL& HOLE FILL PRECAUTIONS -LAY ONE SINGLE DOWN FOR EVEN STANDS. -SWITCH HOLE FILL OVER TO THE ACTIVE TO HELP WITH FLUIDS MANAGEMENT -MONITOR WELL PRIOR TO PULLING OFF BOTTOM- STATIC LOSS RATE-40 BPH -LAY DOWN BAKER BHA F/232' -PJSM FOR LAYING DOWN BHA,BREAK&LD BHA UP TO THE GRAPPLE,BREAK&LD TAILPIPE ASSEMBLY -SERVICE BREAK THE 5-1/2"GRAPPLE,PULL &LAY DOWN GRAPPLE ATTACHED TO CUT JOINT -PJSM FOR USE OF TUBING PUNCH PUNCH HOLE ABOVE PX PLUG,NO PRESSURE OBSERVED -FINISH BREAKING DOWN THE TAILPIPE ASSY -WELL STILL ON 40-45 BPH LOSSES 13:00 - 13:30 0.50 CASING P DECOMP CLEAN AND CLEAR RIG FLOOR -PJSM FOR BEAVER SLIDE OPERATIONS: DISCUSS DROPPED OBJECT HAZRDS. Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 10 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Time:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 20:30 7.00 EVAL P DECOMP MOVE IN RIG UP SLB E LINE UNIT FOR USIT LOG RUN -PJSM WITH SLB AND DDI CREW:REVIEW PROCEDURE AND DISCUSS HAZARDS OF RIG UP -DISCUSS WELL CONTROL PLAN WITH WIRELINE IN THE HOLE -RU ELINE TOOLS AND ADJUST SHEAVES, MAKE UP LINE WIPER AND LINER CUTTER -SURFACE TEST ELINE TOOLS-GOOD SURFACE TEST. -RIH WITH LOG TO 9845'MD -MAKE USIT LOG PASS FROM 9,845'TO 2,700' PSI -SEND DATA TO ODE -CONTINUE POOH WITH USIT TOOL FROM 2,700' -CONTINUOUS HOLE FILL W/8.5 PPG SEAWATER AT45 BPH DURING ELINE OPERATIONS 20:30 - 22:00 1.50 EVAL P DECOMP RIG DOWN ELINE OPERATION -PJSM FOR LAYING DOWN ELINE TOOLS, -RIG ELINE TOOLS AS DIRECTED BY SLB REP,LAY DOWN TO GROUND -RIG DOWN REAMINDER OF ELINE EQUIPMENT AND CLEAR RIG FLOOR -CONTINUOUS HOLE FILL WITH 8.5 PPG SEAWATER AT 45 BPH DURING RIG DOWN *SIM OPS:STAGE 9-5/8"RTTS STORM PACKER IN PIPE SHED TO WARM UP 22:00 - 00:00 2.00 CLEAN P DECOMP MAKE UP 9-5/8"HALLIBURTON STORM PACKER(RTTS) -PJSM FOR RUNNING AND SETTING RTTS -PICK UP,MAKE UP&RIH WITH RTTS ON 4" DP FROM THE DERRICK.F/15'TO 775' -PUW-75K,SOW-75K -MONITOR TRIP ON TRIP SHEET-WELL STILL ON 45 BPH LOSS RATE -FILL HOLE W/8.5 PPG SEAWATER AT 45 BPH 11/14/2015 00:00 - 06:00 6.00 CLEAN P DECOMP CONT RIH WITH HES RTTS ON DP -PJSM FOR RUNNING AND SETTING RTTS -PICK UP,MAKE UP&RIH WITH RTTS ON 4" DP FROM THE DERRICK.F/775' T/9820' -PUW-205K,SOW-160K -MONITOR TRIP ON TRIP SHEET-WELL STILL ON 45 BPH LOSS RATE -FILL HOLE W/8.5 PPG SEAWATER AT 45 BPH -SET RTTS ON DEPTH AT 9,820'MD -2-1/2 RH TURNS -RU CIRC LINE TO IA Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 11 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/me:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 07:00 1.00 CLEAN P DECOMP RU AND PERFORM CASING PRESSURE TEST -PJSM FOR CASING TEST WITH HES REP -REVIEW CORRECT LINE UP AND VERIFY HOLE FILL DOWN THE DP UNDER THE PACKER. -PT 300 PSI/5 MIN-5 STKS(.5 BBL),4000 PSI/30 MIN,88 STKS(8.8 BBLS) -WTL APPROVED BOTH TESTS-GOOD TEST PER CRITERIA C -BLED OFF PSI BACK TO PITS-7.8 BBLS RETURNED 07:00 - 08:30 1.50 CLEAN P DECOMP RELEASE RTTS -PJSM WITH HES REP -RELEASE RTTS PER HES REP,ALLOW ELEMENT TO RELAX -ESTABLISH SCR'S -MONITOR WELL FOR 10 MINUTES-WELL ON LOSSES -BLOW DOWN CHOKE LINE 08:30 - 10:30 2.00 CLEAN P DECOMP SLIP AND CUT DRILL LINE -PJSM FOR SLIP AND CUT OF DRILL LINE -SLIP AND CUT 54'OF DRILL LINE -INSP SAVER SUB/DEADMAN ANCHOR -SERVICE BLOCKS AND TOP DRIVE -CONTINOUS HOLE FILL @ 30 BPH WITH 8.5 PPG SEAWATER 10:30 - 12:00 1.50 CLEAN P DECOMP POOH WITH RTTS ON DP LD SINGLES -PJSM FOR POOH -POOH F/9820'T/8746' -PUW=190K SOW=150K -MAINTAIN CONTINUOUS HOLE FILL W/8.5 PPG SEAWATER AT-30 BPH 12:00 - 12:30 0.50 CLEAN P DECOMP RIG SERVICE -SERVICE AND INSPECT TOP DRIVE, DRAW WORKS AND SKATE 12:30 - 17:30 5.00 CLEAN P DECOMP CONT LD DP SINGLES IN THE PIPE SHED -LD DP F/8746'MD T/3100' -PUW=97K -MAINTAIN CONTINUOUS HOLE FILL W/8.5 PPG SEAWATER AT-30 BPH 17:30 - 18:00 0.50 CLEAN P DECOMP RIG SERVICE -SERVICE DRAWORKS,TOP DRIVE,SKATE 18:00 - 18:30 0.50 CLEAN N RREP DECOMP CODE 8 RIG REPAIR -REPLACE 2EA HYDRAULIC LINES ON IRON ROUGHNECK 18:30 - 21:00 2.50 CLEAN P DECOMP CONT POOH WITH DP AND LD RTTS -POOH LAYING DOWN DP F/3100 T/ SURFACE -LD RTTS TO PIPE SHED -MAINTAIN CONTINUOUS HOLE FILL W/8.5 PPG SEAWATER AT-30 BPH 21:00 - 22:30 1.50 CLEAN P DECOMP CLEAN&CLEAR RIG FLOOR AND - REMOVE WEAR RING -PJSM FOR REMOVING WEAR RING -MU SAFETY JOINT -BEAVER SLIDE OPS 22:30 - 00:00 1.50 CLEAN P DECOMP PU AND RU DOYON CASING EQUIP -RU DOYON CASING WITH TORQUE TURN SERVICES -READY PIPE SHED FOR RUNNING 5-1/2"17# L-80 TCII COMPLETION TUBING Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 12 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/Tme:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/15/2015 00:00 - 01:00 1.00 RUNCOM P RUNCMP CONT RU 5.5"DOYON CASING HANDLING EQUIP -COMPLETE RU DOYON CASING HANDLING EQUIPMENT -VERIFY CORRECT TONG HEAD SIZE -MAKE UP LIFTING EQUIPMENT DRILLER AND LEAD FLOOR HAND VERIFY CORRECT SIZE& RATING -MAKE UP THE TUBING HANGER XO TO THE HANGER-7-1/2 TURNS TO MAKE UP 01:00 - 12:00 11.00 RUNCOM P RUNCMP RIH WITH 5-1/2"17#L-80 TCII COMPLETION TUBING WITH 9-5/8"X 5-1/2"HES'TNT' PACKER -PJSM FOR RIH WITH COMPLETION TUBING -WSL,TP,HALLIBURTON REP VERIFIED PIPE COUNT IN PIPE SHED PRIOR TO RUN -WELL CONTROL DISCUSSION WITH LOSSES.ENSURE CORRECT XO FOR THE TC-II THREAD IS MADE UP TO THE TIW -RIH WITH 5-1/2"17#L-80 TCII F/SURFACE' T/2527'MD -MAINTAIN CONTINUOUS HOLE FILL-AVG LOSS RATE WHILE RIG=20-25 BPH -PUW=90K SOW=95K -BAKER-LOK ALL CONNECTIONS BELOW THE PACKER -JET LUBE SEAL GUARD ON ALL OTHER CONNECTIONS -TORQUE-TURN ALL CONNECTIONS -MAKE UP TORQUE FOR 5 1/2"TCII CONNECTIONS:5500 FT-LBS -90 FPM MAX RUNNING SPEED -RECORD PU AND SO WEIGHTS EVERY 10 JTS -CLEAN BOX AND PIN ON EACH JOINT,PIPE DOPE DRY ON PIN **HAVING TO CLEAN AND BUFF EACH PIN END DUE TO HARD DEBRIS ON THE THREADS MAKING IT DIFFICULT TO GET THE PROPER SHOULDER&NOSE SEAL MAKE UP** 12:00 - 12:30 0.50 RUNCOM P RUNCMP RIG SERVICE -INSPECT AND SERVICE TOP DRIVE, DRAWWORKS AND SKATE Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 13 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/me:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. WWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 00:00 11.50 RUNCOM P RUNCMP CONT RIH WITH 5-1/2"17#L-80 TCII COMPLETION TUBING -RIH WITH 5-1/2"17#L-80 TCII F/2527'T/ 8744'MD -MAINTAIN CONTINUOUS HOLE FILL-AVG LOSS RATE WHILE RIG=20-25 BPH -PUW=185K SOW=160K -JET LUBE SEAL GUARD ON ALL OTHER CONNECTIONS -TORQUE-TURN ALL CONNECTIONS -MAKE UP TORQUE FOR 5 1/2"TCII CONNECTIONS:6500 FT-LBS-MAX *TORQUE VALUE RAISED FROM 5500 TO 6500 FT-LBS -90 FPM MAX RUNNING SPEED -RECORD PU AND SO WEIGHTS EVERY 10 JTS -CLEAN BOX AND PIN ON EACH JOINT,PIPE DOPE DRY ON PIN -BAKER MACHINE SHOP OUT TO INSPECT PIN AND BOX *TOOL BOX MEETING @ 1800 HRS *TABLE TOP KICK WHILE DRILLING DRILL, KICK WHILE TRIPPING DRILL 11/16/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP RIG SERVICE -SERVICE AND INSPECT TOP DRIVE, DRAWWORKS,SKATE -INSPECT 5.5"HANDLING EQUIPMENT 00:30 - 01:30 1.00 RUNCOM P RUNCMP CONT RIH WITH 5-1/2"17#L-80 TCII COMPLETION TUBING WITH 9-5/8"X 5-1/2" HES'TNT'PACKER -PJSM FOR RIH WITH 5-1/2"17#L-80 TCII COMPLETION TUBING -RIH WITH 5-1/2"17#L-80 TCII F/8744'T/ 9714'MD -MAINTAIN CONTINUOUS HOLE FILL-AVG LOSS RATE WHILE RIG=20-25 BPH -MAKE UP TORQUE FOR 5 1/2"TCII CONNECTIONS:6500 FT-LBS -90 FPM MAX RUNNING SPEED -PUW=203K SOW=170K -RECORD PU AND SO WEIGHTS EVERY 10 JTS -CLEAN BOX AND PIN ON EACH JOINT,PIPE DOPE DRY ON PIN 01:30 - 02:00 0.50 RUNCOM P RUNCMP CHANGE OUT ELEVATORS -PJSM FOR CHANGING OUT ELEVATORS -DRILLER AND LEAD FLOOR HAND VERIFIED CORRECT SIZE ELEVATORS -RIG DOWN 5.5"ELEVATORS AND SAFETY JOINT. -CHANGE OUT ELEVATORS TO 4"DP ELEVATORS Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 14 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/me:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34 @70.44usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 04:00 2.00 RUNCOM P RUNCMP MAKE UP HANGER AND RIH AND LAND -PJSM FOR MAKING UP HANGER AND RIH WITH CAMERON REP -PICK UP 5.45'PUP JOINT,HANGER& HANGER PUP (CIW13"X7"TCIITOPANDBTM). -LAND HANGER,CAMERON REP RILDS AND TORQUE D TO 500 FT-LBS,TORQUE D GLAND NUTS TO 450 FT-LBS -FINAL PICKUP WEIGHT=203 K,SLACKOFF= 170 K -HES TNT PACKER AT 9,654'MD. -'X'NIPPLE AT 9690'MD HAS RHC-M PLUG INSTALLED. -NOTE:ALL CONNECTIONS BELOW PACKER ARE BAKER-LOK'D. 04:00 - 09:30 5.50 RUNCOM P RUNCMP PJSM FOR PUMPING CORROSION INHIBITED 8.5 PPG SEAWATER&DIESEL FREEZE PROTECT -PJSM WITH DDI AND LRS FOR PUMPING OPERATIONS AND SETTING OF THE PACKER. LINE UP AND BULLHEAD 425 BBLS OF 110 DEG CORROSION INHIBITED SEAWATER DOWN IA -2.5 BPM-100 PSI -3 BPM-500 PSI -4 BPM-600 PSI -6 BPM-760 PSI -CAUGHT FLUID AT 17 BBLS AWAY -BULLHEADED TOTAL OF 425 BBLS OF CORROSION INHIBITED SEAWATER AWAY IN THE IA -LINE UP AND PUMP 60 BBLS OF 100 DEG DIESEL FREEZE PROTECT DOWN THE TUBING,DROP THE BALL&ROD -2 BPM,500 PSI,FCP SWITCH OVER AND PUMP 110 BBLS DOWN THE IA. -2 BPM,500 PSI FCP SWITCH OVER TO THE TUBING AND SET THE PACKER AS DIRECTED BY THE HALLIBURTON REP. 09:30 - 12:30 3.00 RUNCOM P RUNCMP SET AND TEST PACKER -WITH LANDING JOINT STILL INSTALLED, DROP BALL AND ROD 1.875" -SET PACKER WITH LRS PUMP UNIT- OBSERVED PACKER SET AT 2200 PSI -PRESSURE TEST TUBING,300 PSI LOW 5 MIN,4000 PSI HIGH FOR 30 MIN-PUMPED 2.15 BBLS TO GET PRESSURE,BLED BACK 2.0 -PRESSURE TEST IA,300 PSI LOW 5 MIN, 4000 PSI HIGH FOR 30 MIN-PUMPED 8.66 BBLS TO GET PSI,GOT 8.0 BBLS BACK -GOOD TEST - RECEIVED AUTHORIZATION TO PROCEED FROM WTL -C.SHEAVE,AOGCC INSPECTOR,WAIVED WITNESS FOR MIT-IA TEST Printed 11/30/2015 1:26:18PM • • North America-ALASKA-BP Page 15 of 15 Operation Summary Report Common Well Name:S-34 AFE No Event Type:WORKOVER(WO) Start Date:11/8/2015 End Date:11/17/2015 X4-01161-E:(2,400,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 14 Spud Date/me:12/15/1992 12:00:00AM Rig Release:11/17/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292230500 Active datum:S-34(4170.44usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 13:30 1.00 RUNCOM P RUNCMP RIG DOWN AND BLOW DOWN ALL LINES -RIG DOWN LRS -LAY DOWN LANDING JOINT -SUCK OUT STACK -CLEAR FLOOR OF TUBING HANDLING EQUIPMENT 13:30 - 15:30 2.00 WHSUR P RUNCMP SET 6"J STYLE TWC -PJSM FOR RIGGING UP DUTCH RISER,DSM LUBRICATOR&PRESSURE TESTING- -NU DUTCH RISER SYSTEM AND DSM LUBRICATOR AND TEST -250 PSI LOW,4000 PSI HIGH FOR 5 CHARTED MIN-GOOD TEST. -LUBRICATE IN TWC AND PT --250 PSI LOW,4000 PSI HIGH FOR 5 CHARTED MIN-GOOD TEST. 15:30 - 16:30 1.00 WHSUR P RUNCMP RIG DOWN DUTCH RISER,DSM LUBRICATOR -PJSM FOR RIG DOWN OPERATIONS. 16:30 - 20:30 4.00 BOPSUR P RUNCMP NIPPLE DOWN THE 13-5/8"BOP STACK -PJSM FOR RIG DOWN- -REMOVE RISER,RIG DOWN CHOKE&KILL LINES -CHANGE OUT THE UPPER RAMS FROM 3-1/2"X 6"(VBR)TO 7-5/8"(SBR) -STAND BACK ON STUMP FOR RIG MOVE 20:30 - 00:00 3.50 WHSUR' P RUNCMP NIPPLE UP ADAPTER FLANGE AND 7-1/16", 5000 PSI CAMERON DRY HOLE TREE AND TEST -PJSM WITH RIG CREW AND CAMERON WELLHEAD REPRESENTATIVE -NIPPLE UP ADAPTER FLANGE 11/17/2015 00:00 - 02:00 2.00 WHSUR P RUNCMP INSTALL DRY HOLE TREE. -PJSM,STEAM AND CLEAN ADAPTER FLANGE RINGE GROOVE FOR INSTALLATION OF DRY HOLE TREE. -INSTALL AND TORQUE DRY HOLE TREE. -TEST TREE W/DIESEL&PT 250 LOW,5000 PSI HIGH,VISUAL LEAK TEST.-NO LEAK (PRESSURE TEST CRITERIA(100218) 5A -ADD DIESEL ADDITIVE ON TOP OF THE TWC FOR FREEZE PROTECT. 02:00 - 03:00 1.00 WHSUR P RUNCMP TEST DRY HOLE TREE. -PJSM,ADD 2 QUARTS OF DIESEL ADDITIVE AND FILL TREE WITH DIESEL. -TEST TREE WITH DIESEL TO 300 PSI LOW AND 5000 PSI HIGH FOR 5 MINUTES EACH. -CONFORM TO LEAK TIGHT TESTAS PER PRESSURE TEST CRITERIA 100218. -OBTAIN GOOD LEAK TIGHT TEST. -RIG DOWN TEST EQUIPMENT AND STORE EQUIPMENT. 03:00 - 03:30 0.50 WHSUR P RUNCMP DRESS DRY HOLE TREE AND SECURE CELLAR. -INSTALL JEWELRY AND GAUGES ON DRY HOLE TREE AND ANNULUS'S. -CONFIRM FINAL PRESSURES OF TBG/IN OA.0/0/0. -RIG RELEASED AT 03:30 ON 11/17/2015. -RIG DOWN FOR RIG MOVE TO S-40 Printed 11/30/2015 1:26:18PM TREE= CNV WH LHEAD= McEVOY • SA Y NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER C Sm134 WHEN ON MI""WELL REQUIRES A SSSV WHEN ON IAL KB.ELEV 70.44' MI"" IN BF.ELEV= 28.65' K PAngle= 50 @ 3503' 20"CONE, H 110' ' 1_._ 2107' J�5-1/2"FE5'X'NP,D=4.562"J 91.5#,H-40, Datum MD= 10247' D=19.124" Datum ND= 8800'SS 13-3/8"CSG,68#,K-55/L-80,ID=12.415" --( 2901' 9-518"CSG,47#,L-80 BTC,D=8,681" -I 3907' >< x 9-5/8"CSG,53.5#,L-80 BTC,D=8.535" --f 6938' I—x >G ' , [ 9624^_j--15-112"FES'X'NP,D=4.562" Minimum ID = 3.726" @ 10208' 4-1/2" XN NIPPLE j Z IX 1..._._„9666' 1-19-5/8”X 5-1/2"HES TNT PKR D=4.801"j , I 9692' j-{5-1/2"FES'X'NP,D=4.562" 5-1/2'TBG,17#,L-80 TCI,.0232 bpf,D=4.892" H 9750' _7 \ 9750' -{5-1/2"WLEG,D=4.892" TOP OF 7"LNR H 9907' i 9907' -9518"X 7"LIP,7'TACK SLV &LNR HGR D=? 9-5/8"CS(,47#,L-80 BTC,D=8.681" H 10115' I _ L 10193'elmd -17"X 4"BKR FB-1 FCR,D=4.00" PORATION Ry R ' 10205'elmd -14-1/2"OTIS X MP,D=3.813" FEF LOG:SINS BRCS ON 12/31/92 i T- ANGLEATTOP PERF:22°@10117 I' ill 10208'elmd H4-1/2"OTISXNNP,D=3.725" Note:Refer to Production DB for historical perf data SCE SFF INTERVAL Opn/Sgz SHOT SQZ 3-3/8" 4 10117-10157 0 06/30/93 10212'elmd -I 4-1/2"VVLEG,D=3.958" 3-3/8" 6 10258-10300 0 04/29/93 3-3/8" 6 10300-10354 0 04/29/93 MID --I 10551' 11111111 111111111111111 7"LNR 29#,L-80 NSCC,.0371 bpf,D=6.184" -1 10630' 1I.1.0A0.0, DATE REV BY COMMENTS DATE REV BY COMvENTS PRUDHOE BAY UMT 01/04/93 N28E INITIAL COMPLETION WELL: S-34 11/16/15 0-14 RWO J PERMIT No:9921360 11/24/15 JM) DRLG HO CORRECTIONS AR No: 50-029-22305-00 12/04/15 AW/JM)FINAL ODEAFPROVAL SEC 35,T12N,T12E, 1645'FNL&1782'FWL BP Exploration(Alaska) pro 192 -136, Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Tuesday, May 12, 2015 11:08 AM To: 'Kirchner, Carolyn J' Subject: RE:S-34 - Pre-rig work(PTD 192-136, Sundry 315-010) Carolyn, 2000 psi plus a USIT log is sufficient. Victoria Victoria Loepp r�p��© ;N, 0 i L'115 Senior Petroleum Engineer SW's State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria Loepp(a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Kirchner, Carolyn 3 [mailto:Carolyn.Kirchner@bp.com] Sent:Tuesday, May 12, 2015 10:53 AM To: Loepp, Victoria T(DOA) Subject: S-34- Pre-rig work update Hi Victoria, We were unable to pull the bottom packer of the tubing patch in S-34 during the pre-rig work.We tried with both SL and service CT. Because we cannot remove the lower packer,we also can't pull the nipple reducer, preventing a full size IBP that can be tested to 4000 psi. Currently the pre-rig has been updated to run a 2.5" IBP that can be safely tested to 2000 psi in the 7" liner. We will still be running a USIT log with the rig to check for cement behind pipe.We will also be testing the casing from below the new packer setting depth to surface.The 7" LTP will have been tested to 2000 psi. If you would like a 4000 psi test we have a few options: 1) Once we pull the K-anchor we can RU EL to run an IBP and then RU SL to pull an IBP adding at least 2 days of rig time at$450k 2) Mill the packer and run an RTTS run to test the LTP up adding about a day and a half at$350k. Please let me know if you require the test to 4000 psi or if 2000 psi plus a USIT log is sufficient. 1 I r!", of Tye,, �yj,�4, THE STATE Alaska Oil and Gas s��='� of Conservation Commission - -- ALAS :A • 4 t __i _ 333 West Seventh Avenue Rr GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov David Bjork (00 pEngineering Team Leader lc) BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-34 Sundry Number: 315-010 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /°"951,—va 4---- , Cathy P. oerster Chair DATED this 15y of February, 2015 Encl. �IcJ'a"'�- ' �_t' .6 - STATE OF ALASKA RECEIVED ALAS'.,,OIL AND GAS CONSERVATION COMMIL,,,ION JAN 0 5 2015 APPLICATION FOR SUNDRY APPROVAL ,// n^ 20 AAC 25.280 AOGcc 1. Type of Request' ❑Abandon 0 Plug for Redrill 0 Perforate New Pool •®Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 192-136 • 3. Address. ❑Development ®Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22305-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU S-34 • Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10.Field/Pool(s): ADL 028257 • Prudhoe Bay/Prudhoe Bay " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft) Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth ND(ft): Plugs(measured): Junk(measured). 10635' • 9226' • 10551' 9150' 9831' None Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 20" 35'- 111' 35'- 111' 1490 470 Surface 2867' 13-3/8" 34'-2901' 34'-2899' 3450/4930 1950/2270 Intermediate 10084' 9-5/8" 31'- 10115' 31'-8750' 6870 4760 Production Liner 723' 7" 9907'- 10630' 8559'-9221' 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size' Tubing Grade: Tubing MD(ft)* 10117'- 10354' 8752'-8970' 5-1/2", 17#L-80;4-1/2" 9906,10193'-10211 8558';8822'-8838' Packers and SSSV Type: 9-5/8"x 5-1/2"TIW HBBP Packer; Packers and SSSV 9848'/8505'; 7"x 4-1/2"Baker F Permanent Packer MD(ft)and ND(ft): 10193'/8822' 12 Attachments. 13.Well Class after proposed work: ® Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development IS Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation February 15,2015 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: ®WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Carolyn Kirchner,564-4190 Printed Name: David Bjork S4A St,,E,k .cc,e-Title: Engineering Team Leader Email: Carolyn.Kirchner@bp corn Signature: C M 1(•�,` Phone: 564-5683 Date: i/S/ (s Commission Use Only Conditions of approval. Notify Commission so that a representative may witness / Sundry Number: \s-d\U ❑Plug Integrity L`/BOP Test Mechanical Integrity Test 0 Location Clearance Other: aci, ,'e5/ ../_6 35-----0(,/,5 , ( v P 5 p r'5 <f ' ? r i ) p� 11l�rv,u/av ��j�I�rv ¢ry i---r 5r ,ZS 1)5: \ d /i, jcc fig . J/Gr t-Y vYi tn�'SS rc/ � 1 T- i i �t�q�vi' r d <c fir✓ f g b ' r� ;.4"14,1-aa wa%V6r%3 ranrrc/ fo a11ow paciccr t!J be placrdc,-#W'a bova f-/-i zicop J7c f(A0A4-CZr•4/LL6)� eel. F `I 5/s. " Gu5i� rrryvire 1. Co talc rc5�/ts �oUcc Spacing Exception Required? 0 Yes 0 No Subsequent Form Required: /C — 4c .4- r MIT the 1-TP anti NuS,hq,/ foci° ✓ ac/cr. w/ .2-op scl- ii., 71. liner.LPcPectt Qt- 2'1' ahc) 4yr- MuvL•-! If botiz P45-5.K9 f1- 'n eon-1-7`r>ue r^'/ .4 yr 44 iT evelc r rretuirei JtveYidiv,q ov, c!oL re5✓/ijyJ APPROVED BY f/ Approved By: COMMISSIONER THE COMMISSION' IDate: Z�/5/ , Form 10-403 Revised 10/ 12 "or drOcitiNisAlififor 12months from the date of approvar//i�p7 I4 , - 9'AS Submit In Duplicate Vr� /13/,s V RBDM 1 d i, G- mss`" 9J FEB 1 3 20 5 by Date: 02/18/2015 From: Carolyn Kirchner,RWO Engineer Subject: 5-341 prep work v3 MSPS:2497 psi Background: S-34 was completed in 1993 as a vertical Zone 4 and Sag River injector. It supports S-21, S-16 (Currently not operable but RWO approved &scheduled), and S-23 (Currently not operable with a SH leak and work on the WBL to eval). In recent events it passed a CMIT-TxIA to 2500 psi with a plug below the packer indicating there is a leak between the tubing and IA only.MIT-T post plug set failed and IA tracked. An LDL was run in July 2013 and found a leak at 9780' MD via STP. In November 2013 a patch was set from 9765-9800'MD to patch a 0.75 bpm leak noted from a STP run in July 2013. After the patch was set a series of integrity pressure tests were conducted and failed again to prove two barriers.A passing MIT-IA was not obtained. Another LDL was run to assess the failed MIT-IA post patch, and noted 3 different smaller leaks above the patch. Leaks were found at 8252', 7540' and 5220'. After reviewing the log and cost of additional patches it was decided to pursue a RWO to swap the tubing. Integrity summary: Passing CMIT-TxIA proving integrity of the production casing. TxIA communication in 4 different spots-9780' MD @ .75 bpm leak and 3 other pin hole leaks at at 8252', 7540'and 5220'. Tubing is in good condition other than the leaks.A 2011 caliper indicates the 5.5 inch tubing logged appears to be in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 33%recorded in pup joint 73.1 at(2,978 ft.).Additional wall penetrations ranging from 20%to 23%wall thickness are recorded in 8 of 254 joints analyzed. Recorded damage appears in the form of isolated pitting.No significant areas of cross-sectional wall loss are recorded throughout the interval logged. CMIT-TxIA failed with plug at 9879' but passed with plug at 9831'. The likely culprit is a leaking TIW packer setting port. Pre Rig Prep Work: W 1 Check the tubing hanger lock down screws for free movement. PPPOT-T&IC. S 2 Pull WFD ER patch at 9760'MD.Attempt to fish patch for"'1-2 days. Pull plug and nipple reducer at 9831'MD(if patch is pulled). E 3 Set 3.38"Baker IBP mid-joint in the first full jt below the LTP at-9945'MD. F 4 EL assist:Load tubing with 1%KCL and diesel Freeze protect.Pressure test IBP with a CMIT to 4000 ✓ psi. /z t v 1 C w w / A-6 C7 C C S 5 Pull IBP.Set 5-1/2"Baker Composite bridge plug in 6 ft pup above packer. E 6 Jet cut tubing at-9835'MD,2 ft down from top of 8 ft pup joint below nipple&above packer. 0 7 Plug control and balance lines with squeeze-crete cement. 0 8 Pressure test control and balance lines after waiting on cement to 2500 psi. F 9 MIT-OA to 1200 psi.Circulate well with 1%KCI.FP w diesel to 2200'MD.Bleed T/I/O to 0 psi. V 10 Set Type J TWC.Install Dry Hole Tree.Configure Annular Valves. Rig Scope of Work: • MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular,3- 1/2"x 6"VBR's,blind shears, mud cross and 3-1/2"x 6"VBR's). Test the VBR's to 4,000 psi and the annular to 3,500-psi. • Pull 5-1A"L-80 tubing from tubing from '9,835'MD. • Test casing to 4000 psi. • Overshot the stub and release packer anchor. • RU EL and run USIT log from existing packer at 9848'MD to^'4000'MD to locate 9-5/8"TOC. R''vi rw wV • Run 5-34" 17#L-80 TC-II tubing with HES TNT packer.Set the packer at-9,700'MD. /t-O[zC C- • Test tubing and IA to 4,000-psi. Freeze protect to 2,500'MD. • Set TWC. ND BOPE. NU and test tree. RDMO. • USIT log to be reviewed by State to determine injection MIT criteria for operation. Post Rig Work: W 1 ND dry hole tree,NU production tree,Pull BPV. S 2 Pull ball and rod and RHC.Pull IBP. IFS= 4 6-3/8"CNV FLS SI 'NOTE: H2S READINGS AVERAGE 125 ppm WELLHEAD= McEVOY ACTUATOR= BAKER C �—34 WHtw ON MI.WELL REQUIRES A SSSV WHEN ON MI. ALL 7"PKR ASSY DEPTHS ARE E-LINE MD PITIAL KB.ELEV 70.44' BF.ELEV= 28.65' I KOP 3503' 20"COP), —I 110' I: Max Angie= 50°@ 5270' 91.5#,H-40, Datum MD= 10247' 2079' —15-1/2"OTIS SSSV NP,D=4.562" Datum 1 D= 8800'SS D=19.124" V 13-3/8"CSG,68#,K-55/L-80,D=12.415" —I 2901' ST MD TVD DEV TYPE VLV LATCH PORT' DATE 9-5/8"CSG,47#,L-80 BTC,D=8.681' —I 3907' I—x ' I >G 5 2977 2975 1 OTIS DMY RA 0 05/18/94 4 4 5180 4927 48 OTS DMY RA 0 05/18/94 9-5/8"CSG,53.5#,L-60 BTC,D=8.535" —I 6938' I—>G x 3 7303 6445 44 OTIS DMY RA 0 05/18/94 XO TO 47#,L-80 BTC 2 8875 7633 32 OTS DMY RA 0 05/18/94 1 9812 8472 24 OTIS DMY RA 0 05/18/94 5-1/2"WFD BR PATCH w ANLEG, — 9760'-9800' D=2.875"(12/13/13) • • 9831' --15-1/2"PARKER SWS NP,D=4.562" 9831' —15-1/2"X 3-1/2"MPREDUCB,D=2.75" Minimum ID = 2.76" @ 9831' 9831' —12.75"PX PLUG(11/15/13) 4.1/2" SWS NIPPLE REDUCER Z 9848' -9-5/8"x5-12"T /M3BPPKI,13=4.75" ' ' 9879' —5-12"PARKER SWS MP,13=4.562' I I L— 9896' -j5-12"PARKER SWN MP,D=4.550" 5-1/7 TBG, 17#,L-80 NSCC,.0232 bpf,D=4.892" H 9906' I---/ \�___----, 9906' H 5-1/2"W/LEG,13=4.920" 9910' — RMD TT LOGGED 03/10/93 TOP OF T'LNR —i 9907' 9907' —9-5/8"X 7"LTP,7'TIEBACK SLV &URHGR,D= .-- y ` �, /mooic- fay f)-lY 9-5/8"CSG,47#,L-80 BTC,D=8.681" —1 10115' I—, 10193' —17"x 4"BKR FB-1 PKF,D=4.0" PERFORATION SUIVMARY IZff LOG:SWS BRCS ON 12/31/92 ,...!...--1,2i 10205' H4-12"X NP,D=3.813" ANGLE AT TOP PERF:22°@ 1011T Pete:Refer to Reduction DB for historical perf data 10208' H4-1/2"XN I'P,D=3.725" SIZE SFF NTERVAL Opn/Sgz SHOT SOZ I 3-3/8" 4 10117-10157 0 06/30/93 \\ 3-3/8" 6 10258.10300 0 04/29/93 10211' —{4 12"WLEG,D=3.958" 3-3/8" 6 10300-10354 0 04/29/93 F'BTD —I 10551' .......♦ si0.,.. W7"L 26#,L-80 USCG,.0383 bpf, =6.276' — 10630' 1 PI, ID DATE REV BY COM I TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/04/93 N28E IMTIAL COMPLETION 11/18/13 JLS/JMD SET PPREDUCER/PX PLUG(11/15/1 VVELL S-34 02/15/11 MB/JMD ADDED SSSV SAFEI Y NOTE 12/11/13 ATO/J1.43 SET WFD ER PKR(1125/13) PERMIT No: 1921360 08/15/11 ICM PJC DRAWING CORRECTIONS 12/11/13 DU'JMD TREE C/O(12/05/13) API No: 50-029-22305-00 08/22/11 SET/PJC SET PX PLUG(08/19/11) 12/20/13 EIYJMD SET VWD ER PATCH(12/13/13) SEC 35,T12N,T12E,1645'FTL&1782'FVVL 01/19/12 TMNfJMD FI2S SAFETY NOTE 11/13/13 JLS/PJC PILL.PX RUG BP Exploration(Alaska) TREE= 6-3/8"CAN FLS S Y NOTES: H2S READINGS AVERAGE 125 ppm ,WELLHEAD= McEVOY PRO,- JS E D S-34 Wtmr ON MI.WELL REQUIRES A SSSV WHEN ON ACTUATOR= BAKER C MI. ALL 7"PKR ASSY DE'THS ARE E LINE MD INITIAL KB.ELEV 70.44' BF.ELEV= 28.65' LKOP= 3503' 20"031413, H 110' V 2,200' H5-112'HES'X'NP,D=4.562" Max Angle= 50"@ 5270' 91.5#,H-40, Datum MD= 10247' D=19.124" Datum ND= 880(Y SS 13-3/8"CSG,68#,K-551 L-80,0=12.415" -I 2901' 9-5/8"CSG,47#,L-80 BTC,D=8.681' —{ 3907' 9-5/8"CSG,53.5#,L-80 BTC,D=8.535" —{ 6938' I— XO TO 47#,L-80 BTC 9,675' –5-1/T HES'X'NP,D=4.562" Minimum ID = 2.76" @ 9831' , OP A 7 newkf 4-1/2" SWS NIPPLE REDUCER P ga ►�. 91,716• -19-58"x 5-1/2"HES•TM'RCR,D=—" 1 ,i9,740' H5-1/2"FES'X PP,D=4.562" 5-1/2"TBG,17#,L-80 V AM TOP HC, H 9748• �'”_ 41 9748' N5-12"WLEG,D= " .0232 bpf,D=4.892" I';':: 9848'9, 9-5/8"x 5-1/2"TPKR,D=4.75" CJk,-) t1,:N ►x/ TPNHBBP /x < \i-s tx, I . • 9879' H 5-1/2"PARKER SWS MP,D=4.562 ..—_ 9896' H5-1/2" 5-12'TBG,17#,L-80 NSCC,.0232 bpf,D=4.892' 9907' 99Q7' H5-1/2"WIG,D=4.920" 9910' H ELMD TT LOGGED 03/10/93 TOP OF 7"LNR H 9907' 9907' 19-5/8"X r LTE,7'TEBACK SLV 111V Qc \' I8 LNR HGR D=? Iovt . a. 9-5/8'CSG,47#,L-80 BTC,D=8.681" H 10115' 10193' 1-17'X 4"BKR FB-1 PCR,D=4.00" PERFORATION SI/M AARY (4. 10205' 4-12"X NP,D=3.813" RE=LOG:SWS BRCS ON 12/31/92 p ANGLE AT TOP R3RF:22"@ 10117 �� 10208' —14-1/T XNNP,D=3.725' Note:Refer to Production DB for historical pert data SIZE SPF MERVAL Opn/Sqz SHOT SO2 3-3/8' 4 10117-10157 0 06/30/93 10212' —14-1/2"WLEG,D=3.958' 3-3/8" 6 10258-10300 0 04/29/93 I 3-3/8" 6 10300-10354 0 0429/93 I PBTD -I 10551' l 4•••/•••1 7'LNR,29#,L-80 NSCC,.0371 bpf,D=6.184' H 10630' 1.1......A DATE REV BY COMMENTS DATE REV BY OOMiEt•ITS PR DHOE BAY RMT 01/04/93 N28E IPIT1AL COMPLETION WELL: S-34 10/02/14 JMD BLILT PROPOSED FERMT No:'1921360 AR No: 50-029-22305-00 SEC 35,T12N,T12E,1645'FPL&1787 FAL BP Exploration(Alaska) S. • gg � O :.- o• N 5 :2 N R. i \ _ 11 B 4'1w ¢¢ ai el 6 G LL N N • F. o cf o w 2 w 0 :4 N w a a a 4 E 07 = o = O z 07 5N eseeaoe he 5111 ri irii o 41,...-.01 i, illigps- ?2. 1111/- x § 0 ♦ $p7 1O .4E4* LaY -4M111111.01 a >R O n =Q =, ♦ Y N M _�-I m ffi J - U H � _ 2 O -O _yam �I _41 1 N IMNIA -a - -4111111h r2W , m z w s p iro2 cp s smO og <o_ Wei ,, mr. X smx rNj as amsN d y x JF ■$ o g § o6aN $ p'7 § 1,3 � ofII \ n II Pf N IIIo i i w $ i 4. 1 ,. lA Z 0 lUll'S' oISIlIIIIIHIIII. a ir � . . ir ...... Oil* �V . S 0 43 CC '— I ¢a 0 n § �� T1 W V 81. •� r O� by 0 Date: 02/10/2015 From: Carolyn Kirchner, RWO Engineer Subject: S-34i prep work v2 MSPS:2497 psi Background: S-34 was completed in 1993 as a vertical Zone 4 and Sag River injector. It supports S-21, S-16 (Currently not operable but RWO approved & scheduled), and S-23 (Currently not operable with a SH leak and work on the WBL to eval). In recent events it passed a CMIT-TxIA to 2500 psi with a plug below the packer indicating there is a leak between the tubing and IA only.MIT-T post plug set failed and IA tracked. An LDL was run in July 2013 and found a leak at 9780' MD via STP. In November 2013 a patch was set from 9765-9800'MD to patch a 0.75 bpm leak noted from a STP run in July 2013. After the patch was set a series of integrity pressure tests were conducted and failed again to prove two barriers.A passing MIT-IA was not obtained. Another LDL was run to assess the failed MIT-IA post patch, and noted 3 different smaller leaks above the patch. Leaks were found at 8252', 7540' and 5220'. After reviewing the log and cost of additional patches it was decided to pursue a RWO to swap the tubing. Integrity summary: Passing CMIT-TxIA proving integrity of the production casing. TxlA communication in 4 different spots - 9780' MD @ .75 bpm leak and 3 other pin hole leaks at at 8252', 7540'and 5220'. Tubing is in good condition other than the leaks.A 2011 caliper indicates the 5.5 inch tubing logged appears to be in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 33%recorded in pup joint 73.1 at(2,978 ft.).Additional wall penetrations ranging from 20%to 23%wall thickness are recorded in 8 of 254 joints analyzed. Recorded damage appears in the form of isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the interval logged. CMIT-TxIA failed with plug at 9879' but passed with plug at 9831'. The likely culprit is a leaking TIW packer setting port. Pre Rig Prep Work: W 1 Check the tubing hanger lock down screws for free movement. PPPOT-T&IC. S 2 Pull WFD ER patch at 9760' MD.Attempt to fish patch for—1-2 days. Pull plug and nipple reducer at 9831'MD(if patch is pulled). E 3 Set 3.38" Baker IBP mid-joint in the first full jt below the LTP at'9945' MD.CMIT.Jet cut tubing at ^'9835'MD,2 ft down from top of 8 ft pup joint below nipple&above packer. F 4 EL assist: MIT-OA to 1000 psi.CMIT-TxIA to 2000 psi after setting IBP. Circulate well with 1%KCI.FP w diesel to 2200' MD. Bleed T/I/O to 0 psi. V 5 Set Type J TWC.Install Dry Hole Tree.Configure Annular Valves. Rig Scope of Work: • MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2"x 6"VBR's, blind shears, mud cross and 3-1/2" x 6" VBR's). Test the VBR's to 4,000 psi and the annular to 3,500-psi. • Pull 5-W' L-80 tubing from tubing from "9,835' MD. • Overshot the stub and release packer anchor. • Test casing to 4000 psi. • Run 5-1/2" 17#L-80 TC-II tubing with HES TNT packer.Set the packer at 9,700' MD. • Test tubing and IA to 4,000-psi. Freeze protect to 2,500'MD. • Set TWC. ND BOPE. NU and test tree. RDMO. Post Rig Work: W 1 ND dry hole tree,NU production tree,Pull BPV. S ` 2 Pull ball and rod and RHC.Pull IBP. by 0 Date: 10/2/2014 From: Carolyn Kirchner, RWO Engineer Subject: S-34i prep work Background: S-34 was completed in 1993 as a vertical Zone 4 and Sag River injector. It supports S-21, S-16 (Currently not operable but RWO approved & scheduled), and S-23 (Currently not operable with a SH leak and work on the WBL to eval). In recent events it passed a CMIT-TxIA to 2500 psi with a plug below the packer indicating there is a leak between the tubing and IA only. MIT-T post plug set failed and IA tracked. An LDL was run in July 2013 and found a leak at 9780' MD via STP. In November 2013 a patch was set from 9765-9800'MD to patch a 0.75 bpm leak noted from a STP run in July 2013. After the patch was set a series of integrity pressure tests were conducted and failed again to prove two barriers.A passing MIT-IA was not obtained. Another LDL was run to assess the failed MIT-IA post patch, and noted 3 different smaller leaks above the patch. Leaks were found at 8252', 7540' and 5220'. After reviewing the log and cost of additional patches it was decided to pursue a RWO to swap the tubing. Integrity summary: Passing CMIT-TxIA proving integrity of the production casing. TxIA communication in 4 different spots - 9780' MD @ .75 bpm leak and 3 other pin hole leaks at at 8252', 7540'and 5220'. Tubing is in good condition other than the leaks.A 2011 caliper indicates the 5.5 inch tubing logged appears to be in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 33%recorded in pup joint 73.1 at(2,978 ft.).Additional wall penetrations ranging from 20%to 23%wall thickness are recorded in 8 of 254 joints analyzed. Recorded damage appears in the form of isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the interval logged. - CMIT-TxIA failed with plug at 9879' but passed with plug at 9831'. The likely culprit is a leaking TIW packer setting port. Pre Rig Prep Work: W 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage(check one at a time). PPPOT-T&IC. S 2 Pull WFD ER patch at 9760'MD.Attempt to fish patch for^'1-2 days. Pull plug and nipple reducer at 9831'MD(if patch is pulled). E 3 Set 5-1/2" Baker Composite bridge plug in 6 ft pup above packer.Jet cut tubing at^'9835'MD,2 ft down from top of 8 ft pup joint below nipple&above packer. F 4 EL assist: MIT-OA to 1000 psi.CMIT-TxIA to 2000 psi after setting composite bridge plug. Circulate well with 1%KCI. FP w diesel to 2200'MD. Bleed T/I/O to 0 psi. V 5 Set Type J TWC. Install Dry Hole Tree.Configure Annular Valves. Rig Scope of Work: • MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6" VBR's, blind shears, mud cross and 3-1/2" x 6"VBR's). Test the VBR's to 4,000 psi and the annular to 3,500-psi. • Pull 5-'/:" L-80 tubing from tubing from 9,835'MD. • Overshot the stub and release packer anchor with composite bridge plug. • Test casing to 4000 psi. • Run 5-1A"17#L-80 TC-II tubing with HES TNT packer.Set the packer at^'9,700'MD. • Test tubing and IA to 4,000-psi. Freeze protect to 2,500' MD. • Set TWC. ND BOPE. NU and test tree. RDMO. Post Rig Work: W 1 ND dry hole tree, NU production tree,Pull BPV. S 2 Pull ball and rod and RHC. bp 0 RECEIVED JAN 15 2015 Date: 10/2/2014 AOGCC From: Carolyn Kirchner, RWO Engineer Subject: S-34i prep work MSPS:2497 psi Background: S-34 was completed in 1993 as a vertical Zone 4 and Sag River injector. It supports 5-21, 5-16 (Currently not operable but RWO approved & scheduled), and S-23 (Currently not operable with a SH leak and work on the WBL to eval). In recent events it passed a CMIT-TxIA to 2500 psi with a plug below the packer indicating there is a leak between the tubing and IA only. MIT-T post plug set failed and IA tracked. An LDL was run in July 2013 and found a leak at 9780' MD via STP. In November 2013 a patch was set from 9765-9800'MD to patch a 0.75 bpm leak noted from a STP run in July 2013. After the patch was set a series of integrity pressure tests were conducted and failed again to prove two barriers.A passing MIT-IA was not obtained. Another LDL was run to assess the failed MIT-IA post patch, and noted 3 different smaller leaks above the patch. Leaks were found at 8252', 7540' and 5220'. After reviewing the log and cost of additional patches it was decided to pursue a RWO to swap the tubing. Integrity summary: Passing CMIT-TxIA proving integrity of the production casing. TxIA communication in 4 different spots - 9780' MD @ .75 bpm leak and 3 other pin hole leaks at at 8252', 7540'and 5220'. Tubing is in good condition other than the leaks.A 2011 caliper indicates the 5.5 inch tubing logged appears to be in good to fair condition with respect to corrosive and mechanical damage, with a maximum wall penetration of 33% recorded in pup joint 73.1 at(2,978 ft.).Additional wall penetrations ranging from 20%to 23%wall thickness are recorded in 8 of 254 joints analyzed. Recorded damage appears in the form of isolated pitting.No significant areas of cross-sectional wall loss are recorded throughout the interval logged. CMIT-TxIA failed with plug at 9879' but passed with plug at 9831'. The likely culprit is a leaking TIW packer setting port. Pre Rig Prep Work: W 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage(check one at a time). PPPOT-T&IC. S 2 Pull WFD ER patch at 9760'MD.Attempt to fish patch for"'1-2 days. Pull plug and nipple reducer at 9831'MD(if patch is pulled). E 3 Set 5-1/2" Baker Composite bridge plug in 6 ft pup above packer.Jet cut tubing at'9835'MD,2 ft down from top of 8 ft pup joint below nipple&above packer. F 4 EL assist: MIT-OA to 1000 psi.CMIT-TxIA to 2000 psi after setting composite bridge plug. Circulate well with 1%KCI. FP w diesel to 2200'MD. Bleed T/I/O to 0 psi. V 5 Set Type J TWC. Install Dry Hole Tree.Configure Annular Valves. Rig Scope of Work: • MIRU Doyon 16. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6" VBR's, blind shears, mud cross and 3-1/2" x 6"VBR's). Test the VBR's to 4,000 psi and the annular to 3,500-psi. • Pull 5-'/2" L-80 tubing from tubing from 9,835'MD. • Overshot the stub and release packer anchor with composite bridge plug. • Test casing to 4000 psi. • Run 5-'/2"17#L-80 TC-Il tubing with HES TNT packer.Set the packer at 9,700'MD. • Test tubing and IA to 4,000-psi. Freeze protect to 2,500' MD. • Set TWC. ND BOPE. NU and test tree. RDMO. Post Rig Work: W 1 ND dry hole tree, NU production tree,Pull BPV. S 2 Pull ball and rod and RHC. From: Kirchner, Carolyn 3 [mailto:Carolyn.Kirchner@bD.com] Sent:Tuesday, February 17, 2015 2:39 PM To: Loepp, Victoria T(DOA) Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010)Workover; Packer depth variance Victoria, On further inspection, I have reviewed the cement report for the well. It looks like 392 bbls total cement was pumped and with 30% losses that would put the cement top at 4598' MD. We are not required to log the 9-5/8" to my knowledge and while some of it was logged, I can't say the tool was configured correctly in the log I sent you as they were also logging the 7" liner. I would like to set up a time to call you in the next two days. When are you available? Thanks, Carolyn From: Loepp, Victo 'a T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, Febru• • 10, 2015 1:59 PM To: Kirchner, Carolyn 3 Subject: RE: PBU S-34(PTD 192- • Sundry 315-010) Workover; Packer depth variance Carolyn, Thank you for your response. Will this well also be on gas inje .•n? Have you considered a water flow log? Thanx, Victoria From: Kirchner, Carolyn 3 [mailto:Carolyn.Kirchner@bp.com] Sent: Monday, -. uary 09, 2015 10:55 AM To: Loepp, Victoria T :GA) Cc: Lastufka, Joseph N Subject: RE: PBU S-34(PTD 19 6, Sundry 315-010) Workover; Packer depth variance Victoria, There is currently no AA in place for S-34.The ext- 'ng packer does not meet the requirements of regulation 20 AAC 25.412(b) nor would the new stacker packer with the 'acker set at 9650' MD. Due to the lack of cement behind the 9- 5/8" it would be prudent to test the casing condition belo the packer to ensure we are not injecting out of zone. To do this, I propose setting an IBP in the 7" liner and performing a . IT to test the LTP and casing below the packer. Post- RWO, the well would be put on a regular 4 yr MIT cycle, with a sp ial CMIT to test the casing from LTP to Packer using an IBP. Please let me know if this plan is sufficient. Thank you, Carolyn N, From: Loepp, Victoria T(DOA) [mailto:victoria.loeDD@alaska.gov] Sent: Thursday, February 05, 2015 7:59 AM To: Kirchner, Carolyn J Cc: Lastufka, Joseph N Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010)Workover; Packer depth variance 2 Loepp, Victoria T (DOA) From: Kirchner, Carolyn J <Carolyn.Kirchner@bp.com> Sent: Thursday, February 12, 2015 8:38 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010)Workover; Packer depth variance Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, This well has been and will be on gas injection. The water flow log can be used in place of setting an IBP in the 7" to determine if fluid is going out of zone. I propose a 4 year logging interval. Please let me know what you think. Thanks, Carolyn From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 10, 2015 1:59 PM To: Kirchner, Carolyn J Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010) Workover; Packer depth variance Carolyn, Thank you for your response. Will this well also be on gas injection? Have you considered a water flow log? Thanx, Victoria From: Kirchner, Carolyn 3 [mailto:Carolvn.Kirchner@bp.com] Sent: Monday, February 09, 2015 10:55 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010) Workover; Packer depth variance Victoria, There is currently no AA in place for S-34.The existing packer does not meet the requirements of regulation 20 AAC 25.412(b) nor would the new stacker packer with the packer set at 9650' MD. Due to the lack of cement behind the 9- 5/8" it would be prudent to test the casing condition below the packer to ensure we are not injecting out of zone.To do this, I propose setting an IBP in the 7" liner and performing a CMIT to test the LTP and casing below the packer. Post- RWO,the well would be put on a regular 4 yr MIT cycle, with a special CMIT to test the casing from LTP to Packer using an IBP. Please let me know if this plan is sufficient. Thank you, Carolyn From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@)alaska.gov] Sent:Thursday, February 05, 2015 7:59 AM 1 • To: Kirchner, Carolyn 3 Cc: Lastufka, Joseph N Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010)Workover; Packer depth variance Carolyn, The issue with this well is that the packer placement is at 467' MD above the top perf and the 9-5/8"TOC is well below that. It would be straight forward to grant a variance to the regulation if the TOC was above the packer. How can you test the integrity of the 9-5/8" where you have injection fluids below the bottom packer and no cement? Do you have any proposals to verify the integrity of this casing or verify that fluids are not flowing behind the 9-5/8"? Is there an Administrative Approval in place to inject into this well?This injection well is more complicated than typical. These questions will need to be addressed before a variance is granted and the sundry is approved. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work. (907)793-1247 Victoria LoeppRalaska goy CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepo@alaska.gov From: Kirchner, Carolyn 3 [mailto:Carolyn.Kirchner@bp.com] Sent: Monday, January 26, 2015 4:10 PM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010) Workover; Packer depth variance Victoria, I forgot the log! Carolyn From: Kirchner, Carolyn 3 Sent: Monday,January 26, 2015 3:47 PM To: 'Loepp, Victoria T(DOA)' Cc: Lastufka, Joseph N Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010) Workover; Packer depth variance Hi Victoria, Here is the information for the S-34 variance for the packer being set more than 200 ft above top perfs. 2 The packer will be set"'9,650 ft MD above top perf at 10,117' MD. This is"'467' MD above the top perf. TOC is at 9986' MD behind the 9-5/8" casing. The 9-5/8" casing shoe is at 10,115' MD. Please let me know if you need anything else to file the variance. Thanks, Carolyn Carolyn Kirchner RWO Engineer, Alaska Office: 907-564-4190 Cell: 907-227-6169 Carolyn.kirchnei'bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Tuesday,January 20, 2015 4:14 PM To: Kirchner, Carolyn 3 Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010)Workover; Packer depth variance Carolyn, Yes,the new packer is 411 ft above the top perf.The cement quality and TOC will need to be verified. Thanx, Victoria From: Kirchner, Carolyn J [mailto:Carolyn.KirchnerObp.com] Sent: Tuesday, January 20, 2015 3:49 PM To: Loepp, Victoria T(DOA) Subject: RE: PBU S-34(PTD 192-136, Sundry 315-010) Workover; Packer depth variance Victoria, The original packer is 269 ft above the top perfs due to the 7" liner top packer depth. Due to this fact, do we still need to file for the variance? I am happy to do so,just clarifying. Thanks Carolyn From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, January 20, 2015 3:43 PM To: Kirchner, Carolyn J Subject: PBU S-34(PTD 192-136, Sundry 315-010)Workover; Packer depth variance Wrong well in the subject line. Regulation pertains to injector PBU 5-34. Thanx, Victoria From: Kirchner, Carolyn 3 [mailto:Carolyn.Kirchner@bp.com] Sent:Tuesday,January 20, 2015 3:32 PM 3 To: Loepp, Victoria T(DOA) Subject: • : •:_ :. : ..r: • tt . ; - ::• e - :-: - . '. - Hi Victoria, Please correct me if I am wrong, but I believe this regulation only applies to injectors and 09-48 is a production well. If I still need to file for the variance, please let me know and I will do so. Thank you, Carolyn From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov] Sent:Tuesday,January 20, 2015 9:02 AM To: Kirchner, Carolyn J Subject: •:_ _ •••: e : •-:.' •• •. - :-:• - . '. _- Carolyn, The packer setting depth Is outside what is allowed by regulation.The regulation 20 AAC 25.412(b) says"The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone." A variance to this regulation must be requested and should include a review of the 9-5/8"cementing information and TOC determination. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria LoeopCo�alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.LoeoQ@alaska.gov 4 • CD • 3N3H OIOd — vI—.O O J zw w CO I- F--1 4 U W a, g 0 ac, cYZ LUletCe V t 4 w . smoa J oc < w w I0 N 4 m ° 2 wNmcmp OD t-J w O h-_•)CO m J < 4,dmd 2 I- LLI Z U u_ N- Z < w H 0 Lu g W E f•- " a • O t M. 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GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op, „ Anchorage, Alaska 99501-3572 ALASY' Main: 907.279.1433 p� 11 i } +% Fax: 907.276.7542 Brian Glasheen �a(W�-� Fry Petroleum Engineer BP Exploration (Alaska), Inc. c� — P.O. Box 196612 ��"�" Anchorage, AK 99519-6612 v� Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-34 Sundry Number: 313-403 Dear Mr. Glasheen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair /M- DATED this / — DATED day of August, 2013. Encl. ti C.Lic• • • AC/Y 01-5 x, 517- STATE OF ALASKA JUL 2 5 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION y�� APPLICATION FOR SUNDRY APPROVALS AO 4 " 'i 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well ell • Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other-vbInq pR fc er 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number./ Vu": BP Exploration(Alaska),Inc. Development El Exploratory ❑ 192-136-0 • JCS`/3 3.Address: '❑ Service 0 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22305-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 3419 PBU S-34 • Will planned perforations require a spacing exception? Yes 111 No LE 1 '3? . "Y` c 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028257 ' PRUDHOE BAY, PRUDHOE OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10635 • 9226 • 9896 8549 None None Casing Length Size MD ND Burst Collapse Structural Conductor 76 20"91.5#H-40 34-110 34-110 Surface 2865 13-3/8"68#L-80 36-2901 36-2899.21 5020 2260 Intermediate None None None None None None Production 10082 9-5/8"47#L-80 33-10115 33-8749.89 6870 4760 Liner 705 7"29#L-80 9925-10630 8575.06-9221.32 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 15 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 15 14.Estimated Date for 15.Well Status after proposed work: 9/1/13 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR Cl SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brian Glasheen Email Brian.Glasheen( BP.com Printed Name Brian Glasheen Title PE Signature Ar 'hone Date 564-5905 7/25/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 3- '7 LJ O3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RSDMS OCT 1 0 2 Other: Spacing Exception Required? Yes ❑ No © Subsequent Form Required: / -4-6'L �� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: g_/6 - /3 , Form 10-403(��ed1/2010 Appro Oa cItiG4 ct nonths from the date of approval. Suubmit in Duplicate n J- slis/t 3 ��////// 777777 ��` 11 VVVVVV -if 77�1 • • • S-34 by 0 To: T. Norene /C. Olsen: GPB Well Services Ops Date: April 1, 2013 Team Leads From: Brian Glasheen: B&S Pad PE AFE: APBINJEC Reviewed: Subject S-34 Eline Patch IOR: 80 BOPD Job Sequence 1 FB CMIT-TXIA 2500 psi 2 S Pull PX plug at 9896' MD, Set 2-7/8" nipple reducer at 9896' MD ( Pending a passing CMIT-TXIA) 3 E Set WFD lower packer ( Pending a passing CMIT-TXIA) 4 S Set Upper packer, MIT-IA Current Status Injector. Not Operable. Last Test 07/12/2010 1027 bwpd at 383 WHP Last Tag 08/19/2011 Tagged plug at 9877'SLMD Last Downhole Op 07/04/2013 Ran LDL and found leak in the tubing SBHP/T 3393 psi on 8/18/2011 Max Deviation 50° at 5270' MD Min ID 5-1/2" Nipples ID 4.562" at 2079',9831',9879' Latest H2S value INJ Tie In Log SLB LDL on 07/03/2013 Contacts Brian Glasheen B&S Pad PE Desk: 564-5905 Cell: 907-545-1144 Objective The objective of the procedure is to set a patch over the leak in the tubing to restore integrity of the well. Well History S-34 was completed in 1993 as a vertical zone 4 and sag injector. It supports S-21 S-16 (Currently not operable but has a RWO schedule) and S-23 (Currently not operable with a SH leak). In recent events it passed a CMIT-TXIA to 2500 psi with a plug below the packer indicating we have a leak between the tubing and IA only. MIT-T post plug set failed and IA tracked. Page 1 of 4 • • • S-34 A LDL was run in July 2013 and found a leak at 9780' MD via STP. During the LDL a CMIT was done and failed. After a review of the OMIT it is believed to have been a false test. Before running the atch a CMIT will be erformed to make sure we have PC integrity. If 9 p p that passes a patch will be run to restore the integrity of the well. Procedure FB —CMIT-TXIA 1 . Perform a CMIT-TXIA to 2500 psi 2. If the CMIT-TXIA fails Call APE. If the CMIT-TXIA passes notify SL to set nipple reducer. SL- Pull plug and set nipple reducer 3. Pull PX plug at 9896' MD 4. Before setting the nipple reducer below. Drift patch with 3-1/2" x lock 5. Set 3-1/2" Nipple reducer at 9896' MD 6. Inform ELINE the lower packer is ready to be set. Eline— s7: .Packer ` 7. PJSM. R/U Eline 8. RIH with WFD lower ER packer and set at 9800' MD • Patch schematic is attached below. • Tie in using SLB LDL on 07/03/2013 9. RDMO 10. Inform SL the upper packer is ready to be set. SL Set Upper Packer 11 . RIH with WFD upper packer a spacer pipe. Sting into lower packer and set upper packer at 9765' MD. • Patch schematic is attached below. • Tie in using SLB LDL on 07/03/2013 12. Perform a MIT-IA to 2500 psi 13. RDMO Page 2 of 4 • • • S-34 Client BP Rig/Platform Field Field Prudhoe Bay Lease/OCS-# 5 Pad Well Number 5-34 IlVeathertord Company Man Phone Brian Glasheen State Alaska 907-5E4-5905 Country USA Type of Operation ER Patch LIH BHA to Surface Now Tool Description Tool O/D(in) Tool I/D(in) Length(ft) Asset No. Connection 35'Spacing COE to COE 1 Upper ER Packer 1.500 3.000 1.80 WLAK X WLEG 10.000 9 Release Top Of Packer To COE 4.25' 2 3 1/2 Spacer Pipe 3.500 2.992 29.09 BP 3 1/2 NU IORD Pin X Pin 3 5.5 RS Anchor 1.500 2.880 1.16 3 1/2 NU lORD Box 10-Brass screws 18.100#Release 4 Lower ER Packer 4.500 3.000 4.97 WLAK X WLEG 10.000#Release Top Of Packer To COE 4.25' Page 3 of 4 THRU TUBING PACKER INTERVENTION ... S 0 ' S-34 111EE= 7-1716"5N1 OW SAFETY NOTES: R2S READINGS AV MACE 126 ppm %NFU KA D= NtFVCIY WHEN ON ML WELL REQUIRES A SSW WHEN ON ACTUATOR- OTIS S'.34 103, B/ 70 44 MI ALL r PKR ASSY EtEPTHS ARE E-LINENIO * ' IV Et. V= 2996" KOP= X503' Max Ano. 50'6 S270' 20"COW 110 j) 91 sti,Fi-iiil Det•irn NO' 1020. 4 air 1-fs-i a ons SSSV P4P 0*4 582' i ID a 19 124" 0 Datum TVD= 8eCO'SS 13 349'MO,MO K W/L 80,ID-12418* I 1 2901' --. _ ST IUD IVD OEV TYPE VLV LATCH PORT GATE . ,., 0 AlLsiAtaA CSC,47#,L 6O OTC ID-6 SW j-t 3907' ..---.... ... IV , . 5 2977 2975 1 GM CM( ry‘ '.' .‘"*.--°--- 4 5180 4927 48 OTIS COO RA F. 0 0541894 9-5/8" 0,53511 i -41iourcu.s 6938. —:–_-_, 3 7303 8445 44 0118 CW RA : 0 (16418194 2 0375 MCI 32 0116 CAW RA 1 0 0511594 1 9812 8472 24 0118 CM( RA ' 0 05718194, „... „ Minimum ID - 3.725 aj 10208 - 1 I 9831' -15-177 PARKER 5WS NIP,0=4 562' I 4-112" HES XN NIPPLE -..- s---1 984, H9.5t8"x 5.117'TIIN 11-13BP P(R,0=4.761 ir----- 1N179" H5-177 PARKER DNS 74P,10*-'4 587 I 1E4u-1 Mr H5-1/7 PARKER MN KIP,10*4 550" I -----1-1 98W H1!2'PX RAG marl on 1) 5 H7 IBC 17# L 80 NSCC, 02321M7 110*47 9909' '. , 9CLIIOr H5.11'IMLEG,OD*4.G L 9___IUti• --I ELMO TI LOGGED 03/10093 9907' ; j w c-Mr F--9-871t x 7'LIP I'It-BACK SIN 9 LNII I-OR ID=? 091,C80,479 L-801310,ID 0 9 98I" i 1011/,' --41 ■ FEFFORADON SUMMARY REF LOG SW'S 81-CS ON 12131/92 1 101.31 HT"X 4*WI F I B-1 FXR.0-4 o" ANGLE AT TOPFESF n'0 mi.ir 0 IIfl 18205. H4-117 X MP,D=3813" Not rblvter ict Prodmon CS t of hasIonctA pert Mt* SVC SEC MEWL Own" DA Tr /01I 102W" H4-117 KNOW',00 3 725"1 3-343' 4 10117-10157 0 06133153 10211r H4-17 1NLE0 Eve aor 1 3-378' 6 10258-103C0 0 0412963 33 6 10300 113354 0 04729733 1 P91___Pi-i 10991' Vir4.41.414.4v 4####### 4444444. r LNR 78$ L-80 NSCO 0383 010.10=e 278.10.30. ■„11,,4111.4.0.01,1', 'IA ry nee BY coidussms 114'1- : RIAt R' CONNI-N I S PRSSOF BAY LW 02714793 Nn E ORIGINAL COMPLETION i WELL 9-34 02115/11 MAO ADOED S ,'SV SAFETY'',07E- ! 111Z4VITN, 921380 0871 5111 VOW 0.10 CRAWN13 EiE)RRECTIONIS I AP Peo 50-029-22305-03 COMO 1 Sri PJ 0 SET FX PLUG(08(13711) 80,35,TIM,T12E,1845"FNL&1787 Mk aysti? ,mrc ho'Ammo Fei 5A--I Y NIC I- ' I gyp epkirmlan(Alas k a) Page 4 of 4 • • Perforation Attachment ADL0028257 Well Date Perf Code MD Top MD Base TVD Top TVD Base S-34 8/19/11 BPS 10117 10157 8752 8789 S-34 8/19/11 BPS 10258 _ 10278 8882 8900 S-34 8/19/11 BPS 10278 10300 8900 8920 S-34 8/19/11 BPS 10300 - 10354 8920 8970 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF MINIM t Casing Summary ADL0028257 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 76 20" 91.5# H-40 34 110 34 110 1490 470 H-40 LINER 705 7"29#L-80 9925 10630 8575 9221 8160 7020 L-80 PRODUCTION 10082 9-5/8"47# L-80 33 10115 33 8750 6870 4760 L-80 SURFACE 2865 13-3/8"68# L-80 36 2901 36 2899 5020 2260 L-80 TUBING 18 4-1/2" 12.6# L-80 10193 10211 8822 8838 8430 7500 L-80 TUBING 9874 5-1/2" 17# L-80 32 9906 32 8558 7740 6280 L-80 • • 1 • • Packers and SSV's Attachment ADL0028257 Well Facility Type MD Top Description TVD Top S-34 PACKER _ 9848 _5-1/2"TIW HBBP Packer 8505 S-34 PACKER 10193 4" Baker FB-1 8822 ! • ~p BP Exploration (Alaska) Ina ~~ ~ ~ ` Attn: Well Integrity Coordinator, PRB-20 ~ Post Office Box 196612 ,. F 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, ~, ~• ~~rr;~ , .~ ~~~~~~~~% ~iU~.. ~, .. ~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ , BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad Date 6/25/2009 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls fl na al S-O~B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20l2009 S-a4 1830790 0 NA 0 NA 0.9 SI25l2009 S-05A 7951890 0 NA 0 NA 0.9 5/2612009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-O88 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-118 1990530 0.25 NA 025 NA 1.7 5/27I2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-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 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 SQOA 2010450 025 NA 025 NA f.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 5-23 1901270 025 NA 025 NA 1.7 5/25/2~9 5-248 2031630 0.5 NA 0.5 NA 2.8 5/25/2009 S•25A 7982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2037680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/31I2009 S-29A11 7960720 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.1 5l31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 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 5-34 1921360 ~ 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .e51n 5/31/2009 S-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S-37 1920990 1.25 NA 1.25 NA 17.9 5/27/2009 5-38 1921270 0.25 NA 025 NA 102 5/27I2009 5-47 1960240 1.5 NA 1.5 NA 11.1 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 5/2&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 5-101 2001150 125 NA 125 NA 11.9 5/29/2009 5-102L1 2031560 125 NA 125 NA 11.1 5/3V2009 S-103 2001680 1.5 NA 1.5 NA 7t.9 5/18/2009 5-104 2001960 1.75 NA 7.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.~ 5/20/2009 5-106 2010120 1625 NA 1625 NA 17a.3 6/2/2009 S-1W 2011t30 2.25 NA 2.25 NA 28.s 5/18/2009 5-108 2017 WO 3.5 NA 3.5 NA a0 5/30/2009 S-t09 2022450 2 NA 2 NA 27.3 5/30/2009 S-t~0 2011290 i175 NA 11J5 NA 98.6 5/30/2009 5-111 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-173 202t430 1.75 NA 1.75 NA 22.1 5/18/2009 S-11aA 2021980 125 NA 125 NA 70z 5/30I2009 5-115 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 5-116 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-718 2032000 5 NA 5 NA 76.5 5/2&2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 S-t20 2037980 5.5 NA 5.5 NA 672 5/29/2009 S-72t 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 5-122 2050810 3 NA 3 NA 2~3 5/29/2009 5-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-t24 2061360 175 NA 175 NA 11.9 5/26/2009 5-125 2070830 225 NA 225 NA 20.4 5/28I2009 S-726 20710970 125 NA 125 NA 15.3 6/1/2009 5200 1972390 125 NA 125 NA 14.5 5/28/2009 S-20t 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA /8.7 &1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA i6 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 ~1'9 vq~ \~ 'Z:'Ç- e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~ '''''Ii \ -' ,') 2" ' ~~~~Jt'1 ",' t ( Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudoe Bay I PBU IS-Pad 07/15/06 Jack Winslow Packer Depth Pretest Initial 15 Min. 30 Min. We1l1S-34 I Type Inj. I W TVD I 9,848' Tubing 760 430 400 400 Intervall 4 P.T.D.11921360 I Type test I P Test psi! 2462 Casing 640 2,500 2,400 2,360 P/FI P Notes: MIT-IA for Reg. Camp. OA 280 430 400 370 Chuck Scheve declined to witness We1l1S-104 I Type Inj. I W I TVD I 6,853' Tubing 3,100 3,100 3,100 3,100 Intervall 4 P.T.D.12001960 I Typetest I P I Test psi I 1713.25 Casing 630 1,800 1,780 1,770 P/FI P Notes: MIT-IA for Reg. Camp. OA 0 30 30 30 Chuck Scheve declined to witness Weill Type Inj.1 I TVD I Tubing Interval P.T.D·I I Type testl I Test psi Casing P/F Notes: OA Weill I Type Inj.1 I TVD I Tubing I Intervall P.T.D.I Type test I Test psi Casing I P/F Notes: OA I Weill I Type Inj. TVD I I Tubing Interval P.T.D.I I Type test Test psi! I Casing P/F Notes: I OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) \~K~ ~,:':'"~~;.~¥.;f-V-'\ t,;rW'¡-¡';; " ; t,;¡¡.,:,..,;' ...... MIT PBU S-34,104 07-15-06,xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair DATE: July 20, 2002 THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests bpx S,Pad 15, 34 PBU Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. i .vV, ellI s-15 Type lnj.I S I T.V.D. I 8241 I Tubingl 500 I 500 I500 1500 I lnterVall 4 P.T.D.I 1840710 TypetestJ P 'lTestpsil 2060 ICasingI 220 I 229~) J 2230I 2210I P/F I P Notes: Annulus not fluid packed; injection temp. 117F Well} S-34 I Typelnj. I S I T.V.D. I 8505 I Tub,..I ~o I ~,o I ~,o I ~0 l lntervalJ 4 I P.T.D.} 1921360 Type testI P I Testpsil 2126 I Casingl 25O I 2300 I 2250 I 2240 I P/F I -P, I Notes: Annulus not fluid packed; injection temp. 110F I WellI . P.T.D.I Notes: WellI P,.T.D.I Notes: WellI . P.T.D.I .... Notes: J Type Inj. Type test! Type Inj. J ' J I I Tubing I' I I I J lntervali Type testI I Test psiI I Casing I I I I I P/F I IType Inj. , Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Slight bleed down possibly caused by pumping cold fluids and not having the annulus fluid packed prior to commencing the MIT. M.I.T.'s performed: _2 Attachments: none Number of Failures: 0 Total Time during tests: 1.5 hrs cc: none SCANNED AUG 0 1 2002 MIT report form 5/12/00 LG. MIT PBU S-PAD 7-20-02 JSJ.x]s 7/24/2002 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julia Heusser,~'~ DATE: Commissioner Tom Maunder, JJ/~'~~'~'~UBJECT: ,. u.erv, o 't FROM: John H Spaulding, Petroleum Inspector January 16, 2000 Safety Valve System Tests BPX / PBU Misc. WAG well Prudhoe Oil Pool January 16, 2000: I traveled to BPX's Prudhoe Bay Unit to witness WAG wells SVS test on various pads. These are well that normally come due in this portion of the 6 month cycle. The AOGCC SVS teSt report is attached for reference. As noted 4 pads were visited with 5 wells being tested. All surface equipment passed quite readily but 3 out 5 SSSV's failed. These have been added to the wireline list for tomorrow 1-17-01, and should be ready to be retested by no later than 1-18-01. Merv Littelow and helpers did a very good job considering that this was the helpers first time in conducting these tests. ,SUMMARY: I witnessed the SVS test on BPX's Prudhoe Bay Unit: PBU S pad 2 wells 6 components, 2 failures PBU M pad 1 well 3 components,, 0 failures PBU P pad 1 well 3 components, 1 failures PBU X pad 1 well 3 components, 0 failures Attachment: svs bpX m pad 1-16-01js Svs bpx p pad 1-16-01 js Svs bpx x pad 1-16-01js Svs bpx s pad 1,16-01js Non Confidential Well Permit Separ Set L/P Test Test Test Date oil, wac, c~J, Number Number PSI PSI Trip Code Code Code Passed GAS Or CYCLE Wells: Components: FailUres: Failure Rate: [] 9o var Remarks: Page 2 of 2 svs-bpx-m-pad 1-16-Olj s.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Merv Littelow AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld ~ Date: Field/Unit/Pad: Prudhoe Bay / PBU/,~-pad Separator psi: LPS HPS 1/16/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE P~01 1920920 ' P-02 1930840 P-03A 1972280 P-04 1910760 P-05A 2000510 P-06A 1972240 P-07 1941640 P-08A 2000850 P-09 1930580 P-10 1910520 2bO0 1950 P V 9 ~-11 1910290 I P-12A 1950220 P-13 1901110 P-14 ·1910070 P-15 1901760 · P-16 1901630 - P-17 1901550 P-18 '1901450 P-19 1901360 ~-20A 1960040 P-21B 1970640 P-22 1931210 ~-23 1931120 , P-24 1970540! P-25 1970260 P-26 1962000 ,, Wells: Components: Failures: Failure Rate: [] 9o var Remarks: 1/1 St/n1 Paae 1 of 1 svs-bpx-p-pad 1-16-01js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Littlelow - AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit~ad: Prudhoe Bay / PBU / X-pad Separator pSi: LPS HPS 1/16/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI · Trip Code Code Code Passed GAS or CYCLE X~01 1790540 ' X-02 1790690 X-03A 1980860 X-04 1790890 X-05 1791040 X-06 18OOO9O , X-07 1800130 · X-08 1800360 X-09 1800280 ' ' . X-10 1800430 X-11A 1990780 X-12 1800440. X-13A 1930650 X-14A 1921430 X-15 1800740 X-16 1811720 · , · X-17 1811690 . X-18 1~11620 , X-19B 1961300 X-20 1940670 X-21A 1991080 X-22 1931300 , iX-23 1840610 X-24A 1991250 :X-25 1840340 i~-26 1840300 X-27 1840690 X-28 1~31140 2000 2000 P' P P WAG , X-29 1931390 ~-30 1950410 " X-31 1931980 X-32 1931620 X-34 1931720 X-35 ' 1931990 1/18/01 Page 1 of 2 svs-bpx-x-pad 1-16-01js.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE X-36 1961670 Wells: Components: Failures: Failure Rate: [] 9o Day Remarks: 1/18/01 Page 2 of 2 svs-bpx-x-pad 1-16-0 ljs.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: BPX Operator Rep: Merv Littlelow AOGCC Rep: John H. Spaulding' Submitted By: John H. Spauld' Date: Field/Unit/Pad: Prudhoe Bay / PBU / S-pad Separator psi: LPS HPS 1/16/01 Well Permit Separ - Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GASorCYCLe S-01B 1'952020 ' S-02A 1941090 S-03 1811900 S-04 1830790 S-05A 1951890 S-06 i:~!: i)ii:ii 821650' ':: 2000 1950 P P P "WAG S-07A 1920980 S-08A 1982280 S-09 1821040 ~1 lB 1990530 ' S-12A 1851930 S-13 1821350 S-14 1821290 S-15 1840710. S-16 1840840 S-17A 1911190 8'-18 1841250 · S-19 [861160 " S-20 '1861470 S-200 1972390 S-21 i900470' S-23 1901270 I S-24A 1982450 S-26 1900580 S-27A 1951000 S-28A i951730 S-29A i96OllO ' 8-30 1900660 S-32 1901490 S-33 1921020 S-34 1921360 2000 2000 P P 9 WAG S-35 1921480 ~-36 ]921160 S-37 1920990 1/1 g/01 Page 1 of 2 svs-bpx-s-pad 1-16-0 ljs.xls Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed (;AS or CYCLE S-38 1921270 S-40A 1961250 S-41 1960240 S-42 19605~40 S-43 1970520 , S-44 1970060 ,. Wells: Components: Failures: Failure Rate: [390 var Remarks: Page 2 of 2 svs-bpx-s-pad 1-16-0 ljs.xls .~---_. ON OR BEFO W c:tO~ PERMIT DATA AOGCC Individual Geological Materials T DATA_PLUS Well Inventory Page' 1 Date' 01/09/95 RUN DATE_RECVD 92-136 5508 T 10128-10395 RFT 92-136 5507 T 9468-10648 BCS/DTE&CH/GR 92-136 SURVEY R 0-10096 MWD SPERRY SUN 92-136 DWOP R 12/15/92-01/05/93 92-136 407 R COMP DATE:02/13/93 92-136 SSTVD L 10102-10621 92-136 SBT L 9500-10540 92-136 RFT L 10128-10395 92-136 PROD L 10540-10542 92-136 PAS L 10029-10309 92-136 PAS L 10000-10260 92-136 PFC L 10230-10511 92-136 PFC L 10255-10549 92-136 PERF L 10100-10259 92-136 DIL/FL/GR L 10120-10621 92-136 CCL L 9580-10400 92-136 BHC/GR L 10120-10621 i 01/25/93 i 01/25/93 03/09/93 03/09/93 03/09/93 I 01/25/93 I 01/26/93 1 01/25/93 1 03/30/93 1 07/27/94 1 04/29/94 1 05/10/93 I 03/04/93 1 07/12/93 1 01/25/93 1 01/26/93 1 01/25/93 Are Was Are well dry ditch samples require d? yes the well c~ Analysis.& ~escription received? well tee required? yes no Received? yes no is in compliance n~i~~al ~~3'~ ~_ i~. ~_-~- COMMENTS no yes no ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 19 July 1994 RE: .~. Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ECC No. %%- [o5 E-27 /1 PLS ST4~r/~C FINAL BL 1 PLS STATIC RF SEPIA Run ~ 1 6233.00 Run ~ 1 ~.~ PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA Run ~ 1 5856.07 Run # 1 /,~ PLS STATIC FINAL BL 1 PLS STATIC RF SEPIA Run ~ 1 6173.01 Run $ 1 x-os ,.--1 PLS GAS/L FINAL BL /~ PLS S~"~d~IC FINAL BL 1 PLS GAS/L RF SEPIA 1 PLS STT~f~C RF SEPIA Run # 1 Run # '1 Run # 1 Run # 1 6234.00 ~"'~LS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 5748.01 Run # 1 E-08 (22-32-12-14) CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA PLS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 5922.02 Run # 1 Run # 1 5607.06 Run # 1 ,,-~PLS/GL FINAL BL 1 PLS/GL FINL.RF SEPIA Run # 1 6236.00 , Run $ 1 Cont/ /1 PLS FINAL BL 1 PLS FINAL RF SEPIA Run $ 1 5848.01 Run # 1 Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaslca ~508 Received by Date RECEIVED APP, ~. 9 19,-94 Alaska 1)~1 & gas {~g~, Ce~ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: Sent by: 21 April 1994 Transmittal of Data Dear Sir/Madam, Enclosed, please find the data as described below: WELL S-34 5)-- 2-q' M-o9 DESCRIPTION /PLS STATIC FINAL BL 1 PLS STSC RF SEPIA /PLS STATIC FINAL BL 1PLS ST~ RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ~ ~._-q~ S-37 (32-35-12-12) PLS S~C RF SEPIA PLS ST~ RF SEPIA /1 PLS STATI~ FINAL BL 1PLS S~2~fIC RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ~%-I 2~ R-22 1 PLS STATIC FINAL BL /1 PLS s~ RF SEPIA 1PLS STATI/~>FINAL BL PLS ST~KTIC RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 ~[_~ M-04 (23-31-12-13) 1 PLS STATIC FINAL BL /1 PLS ~C RF SEPIA Run # 1 Run # 1 (~ 5-I~g~. R-23 (42-33-12-13) 9~100 U-14 (11-20-11-13) ~0""l~ F-14 (33-35-12-13) 1PLS STATIC FINAL BL PLS S~C RF SEPIA 1 PLS STATIC FINAL BL 1 PLS STSC RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 1CN/GR FINAL BL Run # 1 CN/GR FINAL RF SEPIA Run # 1 1PFC/GR/CCL FINAL BL PFC/GR/CCL RF SEPIA Run # 1 Run # 1 ECC No. 5856.06 2187.03 6169.00 6173.00 5879.06 5617.05 4880.03 2097.05 6102.01 6014.02 5810.02 959.04 Cont/ ~__<,.~: --< /'~ D-27 (24-14-11-13) '~ A-23 ! PFC/PERF FINAL BL 1 PFC/PERF FINAL BL / /1 PFC/PERF RF SEPIA 1 PLS STATIC FINAL BL / '/1 PLS STATIC RF SEPIA ~ PL STATIC FINAL BL /1 ~L'STATIC RF SEPIA · 1 PLS FINAL BL / / 1 PLS FINAL RF SEPIA Run # 1 5785.02 Run # 1 Run # 1 Run # 1 5132.01 Run # 1 4979.03 Run # 1 Run # 1 6162.00 Run # 1 Run # 1 5783.03 Run # 1 Please sign and r~turn to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMMISSIC~ REPORT SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other 3( 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Sewice 4. Location of well at surface 1645' SNL, 1782' EWL, SEC. 35, T12N, R12E At top of productive interval 3397' SNL, 229' EWL, SEC. 26, T12N, R12E At effective depth 3288' SNL, 5092' EWL, SEC. 26, T12N, R12E At total depth 3264'SNL, 167' EWL, SEC. 26, T12N, R12E 6. Datum elevation (DF or KB) KB E= 70. 44 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-34(13-26-12-12) 9. Permit number/approval number 92-136 / 10. APl number 50- 029-22305 11. Field/Pool Prudhoe Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length .. 10635' feet Plugs (measured) 9229' feet 10551' feet Junk (measured) 9152' feet Size Cemented Measured depth 76 20 11 yds Arcticset 111 2865 13 3/8 2049/472c. f cs III/11 2901 10082 9 5/8 2215 c.f. Class "G" 10115 -. 705 7 240 c.f. Class "G" 9925-10630 measured 10258'-10354' True vertical depth BKB 111 2897 8748 8573-9219 true vertical subsea 8881'- 8970' Tubing (size, grade, and measured depth) 5 1/2", L-80 @ 9906'& 4 1/2", 10211' Packers and SSSV (type and measured depth) Packer 9 5/8" @9848 & 7"@ 10193', SSSV@2079 RECEIVED 13. Stimulation or cement squeeze summary 5/22/94 Converted well to water injector Intervals treated (measured) Treatment description including volumes used and final pressure NOV -3 1994 AJaska Oil & Gas Cons. Commission Anchorc.~, 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injector 17. , hereby ce~that the ~reg(~g is true and correct to the best of my knowledge. D/~~.../~' Signed ~'~/~~./~ Title Supervisor Waterflood and Miscible Flood Form 10-404 Rev 06/15/88 ~/ SUBMIT I'N DOPLICATE STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMMISSIC~', REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1645' SNL, 1782' EWL, SEC. 35, T12N, R12E At top of productive interval 3397' SNL, 229' EWL, SEC. 26, T12N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE--70.44 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-34(13-26-12-12) 9. Permit number/approval number 92-136 / At effective depth 3288' SNL, 5092' EWL, SEC. 26, T12N, R12E At total depth 3264' SNL, 167' EWL, SEC. 26, T12N, R12E 12. Present well condition summary Total depth: measured true vertical 10635' feet 9229' feet Plugs (measured) 10. APl number 50- 029-22305 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10551' feet true vertical 9152' feet Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 76 20 11 yds Arcticset 111 Surface 2865 13 3/8 2049/472c. f cs III/11 2901 Intermediate 10082 9 5/8 2215 c.f. Class "G" 10115 Production -- Liner 705 7 240 c.f. Class "G" 9925-10630 Perforation depth: measured 10258;10354' True vertical depth BKB 111 2897 8748 8573-9219 true vertical subsea 8881'- 8970' Tubing (size, grade, and measured depth) 5 1/2", L-80 @ 9906'& 4 1/2", 10211' Packers and SSSV (type and measured depth) Packer 9 5/8" @9848 & 7"@ 10193', SSSV@2079 13. Stimulation or cement squeeze summary See Attachment RECEIVED JUN 2 Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. Anchorase 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1040 849 573 1080 1650 ~'/'t 1662 324 1026 16. Status of well classification as: Oil X Gas Suspended Tubing Pressure 255 248 Service 17. I hereby c.,ertify that the forego.~.ing is true and correct to the best of my knowledge. Signed ~ ~ . ~ Title Senior Technical Assistant I Form 10-404' Rev 06/15/88 // I Date ~//4 t//(~ ~ I SUBMIT IN DUi~LI(~ATE 4/29/93 5/03/93 06/30/93 fjh 6/20/94 WELL S-34(13-26-12-12) FRAC/ADDPERF/REPERF The following interval were reperforated using 3 318" guns, 6 SPF, random orientation and 60° phasing. 10258' - 10278' MD 10278' - 10300' MD Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: 400 BBLS 20~ GEL DATA FRAC: 20 BBLS 40~ GEL PREPAD TO ESTABLISH RATE 110 BBLS 40# X-LINK GEL PAD W/*.*% ESL (*** GAL) 234 BBLS 20# GEL DATA FRAC FLUSH 100 BBLS DSL TO FREEZE PROTECT WELL FRAC: 20 BBLS 40# GEL PREPAD TO ESTABLISH RATE 68 BBLS 40# X-LINK GEL PAD W/*.*% ESL (*** GAL) 27 Dirty 1 PPG 5 2 PPG 7 3 PPG 9 4 PPG 11 5 PPG 13 6 PPG 14 7 PPG 76 8 PPG 50 8 PPG 57 10 PPG 235 20# LINEAR GEL FLUSH The following additional interval were perforated using 3 3/8" guns, 4 SPF, random orientation and 60°/120° phasing. 10117' - 10157' MD RECEIVED N 2,3 1994 Gas Cons. Commissior, Anchorase BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/07/93 T# 84739 BPX/PBUOLOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-40q~'lq PERF 06/28/93 #1 F-18%c~l-IIq PRODUCTION LOG 06/26/93 91 F-1~ PRODUCTION LOG 06/26/93 91 N-20 ~-5~ PERF 07/01/93 91 S-2498~5 PERF s-2590-tO~ PERF S-33q~.' ~0~- PERF S- 3 4 ({~..,,-"l~'~.~ P ERF S-35 qZ. Iq~ PERF S-36 ~%-~ PERF S-38~%- %~1 PERF z-19qz.Z% Ps~ 07/01/93 91 07/01/93 #1 07/03/93 91 06/30/93 #1 06/30/9~:. #1 06/28/93 #1 07/01/93 #1 06/30/93 91 9200.00-10194.00 ATLAS 5 " 10980.00-12361.00 ATLAS 5 " 10980.00-12361.00 ATLAS 5 " 9915.00-10056.00 ATLAS 5 " 9700.00- 9950.00 ATLAS 5 " 9058.00- 9253.00 ATLAS 5 " 90-0Q,00- 9200.00 ATLAS 5 " 10100.00-10259.00 ATLAS 5 ". 9500.00- 9702.00 ATLAS 5 " 9765.00- 9986.00 ATLAS 5 " 9200.00- 9350.00 ATLAS 5 " 13940.00-14224.00 ATLAS 5 " Information Control Well Records .L RECEIVED ,., JUL 1 2 1993 Alaska 011 & (;as Cons, 00mmleei0n Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 05/04/93 T# 84544 BP/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. i~B-347~lGAS LIFT SURVEY C-ii 7~.~& PRODUCTION LOG 04/30/93 #1 6 ~./&oPFc ....... ~E-0275'.~ PRODUCTION LOG E-29 ~?'~3 PROD-F ,G-06 7~-.1~. LEAK DET H-19 g=-a,3 PRODUCTION LOG H-20~.O? PDK-100 N-12 ~/-/y PRODUCTION LOG ! 04/29/93 #1 04/21/93 #1 04/28/93 #1 04/27/93 #1 04/27/93 #1 04/30/93 #1 04/28/93· #1 04/28/92 #1 04/28/93 #1 04/23/93 #1 04/27/93 #1 04/23/93 #1 05/01/93 #1 04/29/93 #1 9350.00-10062.00.ATLAS 2200.00-10332.00 ATLAS Information Control ~ell Records 11414.00-11768.00 ATLAS 11500.00-12054.00 ATLAS 11500.00-12054.00 ATLAS 9800.00-10232.00 ATLAS 9500.00- 9970.00 ATLAS 11500~00-11680.00 ATLAS 9600.00- 9994.00 ATLAS 11950.00-12214.00 ATLAS 9350.00- 9590.00 ATLAS 11100.00-11525.00 ATLAS 9600.00-10225.00 ~ATLAS 9500.00- 9842.00 ATLAS 10230.00-10511.00 ATLAS II 2+5" 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " 5 " BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 03-16-93 T# 84385 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. J_23.~\ CL 03/08/93 #1 LEAK DET 03/08/93 #1 M-20--~'~ PRODUCTION LOG 03/08/93 #1 S-01~ PDK-100 03/07/93 #1 S-34~.~PRODUCTION LOG 03/10/93 #1 S-35q~-~ PRODUCTION LOG 0.3/11/93 #1 W-18~-~ GR 03/11/93 #1 W-25~%~ GR 03/11/93 #1 9170.00-10309.00 ATLAS 5 " 5900.00- 9800.00 ATLAS 5 " 9300.00- 9808.00 ATLAS 5 " 9950.00-10620.00 ATLAS 5 " 9700.00-10540.00 ATLAS 5 " 9150.00- 9929.00 ATLAS 5 " 8600.00- 9250.00 ATLAS 5 " 10270.00-10556.00 ATLAS 5 " Information Control Well Records RECEIVED Alaska 011 & Ga8 Cons. Commi~8lon Anchorage ~ STATE OF ALASKA '~ AN~,~~' ALAsKA'OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMP LETION REPORT _ _ _G 1. Status of Well Classification of Service Well OIL IXl GAS [] ~ [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 92-136 3. Address B. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 so- 029-22305 4. Location of well at surface 9. Unit or Lease Name SNL, 1782' EWL, SEC. 35, T12N, R12~ Prudhoe Bay Unit 1645' At Top Producing Interval l._~> ~"~://~, I LOCATIONS 3397'SNL, 229'EWL, SEC, 26, T12N, R12Et ~-'~' VERtFIED S-34 (13-26-12-12) At Total Depth 11.PrudhoeFieid and Pool Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE= 70.44' I ADL 28257 12. Date Spudded 13. Dele T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, il offshore 116. No. of Completions 12/15/92 12/31/92 2/14/93I N/Aeet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10635' MD/9229' TVD 10551' MD/9152' TVD YES [:7 NO []I 2079(eet MD I 1900' (Approx.) 22. Type Electric or Other Logs Run Run# 1 Dual Sonic/GR Run #2 RFT 23. CASING, LINER AND CEMENTING RECORD SETRNG DEPll-I MD CASING SIZE WT. PER FT. GRADE TOP Bo'rFOM HOLE SIZE CEM~ RECORD AMOUNT PULLED 20' 91.5# H-40 Surface 76' 30" 11 yds Arcticset 13-3/8' 681t L-80 36' 2901' 16" 2049 cu fl CS 111/472 cu ft CS II 9-5/8' 47# L-80 33' 10115' 12-1/4" 2215 cu fl Class "G" 7' 29# L-80 ' 9925' 10630' 8-1/2" 240 cu fl Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) '-' SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 4 spf 5-1/2", L-80 9906' 9-5/8"-9848'MD 10258'-10354' 8881'-8970' 4-1/2" 10211' 7"- 10193' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,, 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 2/15/93 " I Gas Lift Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF iNATER-BBL CHOKESIZE IGAS-OIL RATIO ~ PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF ~/ATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. AAR - 9 1993 Alaska Oi) & Gas Gons. Gom~uts$~uU 7~nch0rage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate I ~ ~ ! 30. 29. GEOLOG~ MARKERS '- ~-ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VF_.RT. DEPTH GOR, and time of each phase. Sag River 10115' 8750' S hublik 10157' 8788' Top Sadlerochit 10257' 8881' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,_ .... Title Drilling Engineer Suoervisor Date _ _ / ! - 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. R E ~ E ~V ~ D Item 28: If no cores taken, indicate "none". Form 10-407 tvl/kR - 9 199i5 Alaska 0ii & Gas Cons. C0mmlss't0n Anchorage BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: S-34I BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/14/92 12:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 28E WO/C RIG: NABORS 28E 12/15/92 ( 1) TD: 245'( 0) 12/16/92 (2) TD: 1190' ( 945) 12/17/92 ( 3) TD: 2903'(1713) 12/18/92 ( 4) TD: 2903'( 0) 12/19/92 (5) TD: 3718' ( 815) 12/20/92 (6) TD: 5260' (1542) DRILLING AT 245 MW: 8.7 VIS: 45 NU HYDRIL. RIG UP. TAKE ON WATER. NU RISER & FLOW LINE. SPUD 0230 HRS. DRILL TO 136'. PU STAB & ORIENT. DRILL TO 245'. DRILLING MW: 9.1 VIS:300 DRIL TO 449'. POOH. RIH. DRILLED & SURVEYED TO 841'. DRILLED & SURVEYED TO 1190'. SHORT TRIP TO RUN CASING MW: 9.6 VIS:243 DRILLED AND SURVEYED TO 2903'. CBU. SHORT TRIP TO RUN 13-3/8 CASING. N/U WELLHEAD. MW: 9.7 VIS: 47 POOH. RIH. CBU. POOH. RIH W/ 13-3/8" CSG. CIRC. PUMP 100 BBLS WATER, 365 BBLS (1067 SX) CSIII @ 12.2 PPG, 84 BBLS (480 SX) CSII @ 14.9 PPG. BUMP PLUG W/ 2000 PSI. TOP JOB W/ 45 BBLS (240 SX) CS II @ 15 PPG. N/D DIVERTER. N/U WELLHEAD. DRILLING MW: 9.1 VIS: 39 SCREW ON WELLHEAD. NU BOPE. RU TO TEST. RU TO PUMP SECOND TOP JOB. PUMPED 45 BBL H20. PUMPED 21 BBLS (110 SXS) COLD SET 2@ 15 PPG. CEMENT TO SURFACE. TSTD BOPE TO 250/5000 PSI. TSTD ANNULAR TO 250/3500 PSI. TEST WITNESSED BY JERRY HERRING W/AOGCC. HAD TO REPLACE GATE VALVE IN TUBING HEAD. PU BHA AND RIH. TESTED 13-3/8" TO 2500 PSI FOR 30 MINUTES. DRILLED OUT FLOAT EQUIPMENT AND 10' OF RATHOLE. CIRC AND CONDITION MUD TO 9.0 PPG. PERFORMED LOT TO 690 PSI. LOT = 13.6 PPG EMW. DRILLED & SURVEYED 2913 TO 3718'. ADT 2-1/4 HRS. AST 2 HRS. DRILLING MW: 9.9 VIS: 40 DRILLED/SURVEY 3718'-4450'. ADT 1-3/4 HRS. AST 1-1/2 HRS. PUMP SWEEP. CBU. SHORT TRIP 16 STNDS. DRILLED AND SURVEYED TO 5210'. ADT 4-1/2 HRS. AST 2 HRS. PUMP SWEEP. CBU. POOH TO CHANGE BHA. TESTED MWD. RIH TO SHOE. CUT AND SLIP DRILLING LINE. RIH TO TD. DRILLED 5210'-5260'. MAR - 9 199;) Alaska. Oil & Gas Cons. com~tSs'~on Anchorage WELL : S-34I OPERATION: RIG : NABORS 28E PAGE: 2 12/21/92 (7) TD: 6515'(1255) 12/22/92 (8) TD: 7450' ( 935) DRILLING MW:10.0 VIS: 42 DRILLED AND SURVEYED 5260'-6424' ADT 14-1/4 HRS. AST 2 HRS. SHORT TRIP 13 STANDS. NO PROBLEMS. DRILLED AND SURVEYED TO 6515'. ADT 1 HR. AST 3/4 HR. CIRCULATE MW:10.2 VIS: 42 DRILLED & SURVEYED 6515'-7450'. ADT. CBU FOR BIT TRIP. 12/23/92 (9) TD: 7480' ( 30) 12/24/92 (10) TD: 8287' ( 807) DRILLING @ 7480' MW:10.3 VIS: 43 POH. SERVICE WEAR RING. CHANGE STAB. PU MAGNET & RIH TO 7420'. WASH 30' TO BOTTOM. POH & L/D MAGNET. MU MILL. MILLING F/7450 TP 7454'. POH. L/D BHA. RIH W/BIT. REAM F/7370' TO 7454'. DRILL F/7454' TO 7480' DRILLING AT 8287 MW:10.3 VIS: 41 12/25/92 (11) TD: 8743' ( 456) 12/26/92 (12) TD: 9542' ( 799) 12/27/92 (13) TD: 9727' ( 185) DRILLING AT 8743 MW:10.4 VIS: 44 DRILLING TO 8457' CBU. DROP SURVEY & PUMP PILL. POH. RIH TO 8382'. REAM TO 8457'. DRILL TO 8743'. RIH MW:10.4 VIS: 43 DRILLING TO 9443' SHORT TRIP. DRILL TO 9542'. CBU. POH. TEST BOPE. RIH. RIH W/BIT #8 MW:10.3 VIS: 40 RIH TO 9542'. DRILL TO 9727'. CBU. POH. RIH. 12/28/92 (14) TD: 9908' ( 181) 12/29/92 (15) TD:10126' ( 218) 12/30/92 (16) TD:10126' ( 0) 12/31/92 (17) TD:10585' ( 459) DRILLING AT 9908 MW:10.4 VIS: 44 REAM TO 9727'. DRILL TO 9808'. CBU. POH. TEST BOP. RIH TO 941'. RIH TO 9689'. REAM TO 9809'. DRILL TO 9908' L/D BHA. MW:10.4 VIS: 45 DRLG F/ 9908'-10126'. CBU. SHORT TRIP TO 9000'. CBU. POOH. L/D BHA. M/U BHA. MW:10.4 VIS: 44 RIH W/ 9-5/8" CSG. ATTEMPT TO CIRC. HOLE PACKOFF. WORK CSG. CIRC. LAND CSG. PUMP 50 BBLS ARCO SPACER, 333 BBLS LEAD CMT, 61 BBLS TAIL CMT. DISP W/ MUD. NO BUMP PLUG. L/D LAND JT. INSTALL PACKOFF. TEST SAME. CLEAR FLOOR. M/U BHA #10. DRLG. MW: 9.0 VIS: 41 RIH. WASH F/ 9057'-10030' CBU. TEST CSG. OK. DRLG CMT, FC, CMT, FS. CIRC. DRLG ~/ 10126'-10485'. RE¢£1VED - 9 199) A~aska Oil & Gas Cons. Comm'tss'ton Anchorage WELL : S-34I OPERATION: RIG : NABORS 28E PAGE: 3 01/01/93 (18) TD:10635' ( 50) 01/02/93 (19) TD:10635 PB: 0 01/03/93 (20) TD:10635 PB:10551 01/04/93 (21) TD:10635 PB:10551 01/05/93 (22) .TD:10635 PB:10551 TRIP IN HOLE MW: 9.1 VIS: 44 DRILL FROM 10585' TO 10635'. CIRC BOTTOM UP. WIPER TRIP. CIRC BOTTOM UP W/SWEEP. TRIP OUT OF HOLE. RU SCHLUMBERGER & RUN LOG. RIH W/RFT. LOGGING RUN #2. SERVICE WEAR BUSHING. TRIP IN HOLE. CUT & SLIP DRILLING LINE, TRIP IN HOLE FOR WIPER TRIP. POOH MW: 9.1 Seawater TRIP IN HOLE FOR WIPER TRIP. CIRC BOTTOM UP W/ SWEEP. DROP DRIFT. RU & MAKE UP 18 JOINTS OF 7" CASING. TRIP IN HOLE W/7" LINER. CIRC TWO BOTTOMS UP. PRESSURE TEST LINES. REALEASE FROM HANGER & REVERSE CIRC. TRIP OUT OF HOLE. CASED HOLE LOGS MW: 8.5 Seawater STRAP & MAKE UP BOTTOM HOLE ASS. TRIP IN HOLE. CIRC. PRESS TEST. DISPLACE WELL. RETEST CASING. POOH. CIRC. TOOH. RIG UP E-LINE. RUN #1 SBT. RERUN #1 SBT. SHEAR RP VALVE MW: 8.5 Seawater LOGGING RUN #1 SBT. RUN #2. RERUN #2. MAKE UP & RUN PACKER. RIG UP & RUN 5-1/2" COMPLETION. MAKE UP 5-1/2" HRQ BALL VALVE NIPPLE. RUN 5-1/2" COMPLETION. SPACE OUT & MAKE UP TUBING HANGER. RIG & SET TIW 9-5/8" HBBP PACKER. RIG RELEASED MW: 8.5 Seawater CAMCO SHEAR VALVE FAILED. RUN #1 RIH & PULL SSSV DUMMY. RUN #2 RIH & PULL SHEAR VALVE. RUN #3 RIH & SET DUMMY, M/U 5" LANDING JT. PRESS TEST. SLICKLINE RUN #4. RIH & PULL TOP GLM DUMMY. RIH & SET DUMMY IN SSSV. PUMP DIESEL. SET TWO WAY CHECK & NIPPLE. RIG RELEASED 1/4/93 2030 HRS. SIGNATURE: (drilling superintendent) DATE: RECEIVED MAR - 9 199 Alaska 0il a Gas 0ohs. OommissiO~ Anchorage S~RY-SUN DRILLING SERVICES'~ ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING ORIG PBU/S-34 5OO2923O5OO NORTH SLOPE COMPUTATION DATE' 12/28/92 INAL DATE OF SURVEY: 122892 MWD SURVEY JOB NUMBER: AK-MW-20095 KELLY BUSHING ELEV, = 70,44 OPERATOR: BP EXPLORATION FT, TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS DIRECTION DEGREES DG./IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT, SECT, 0 ,00 -70,44 0 0 156 156,00 85,56 0 0 388 387,99 317,55 0 36 519 518,99 448,55 0 42 609 608,97 538,53 1 0 N .00 E .00 N .00 E ,00 N 76.00 E ,26 N 84,30 E ,10 S 75,00 E ,47 .OON ,OOE ,00 ,OON ,OOE ,00 .29N 1,18E -,21 .54N 2,64E -,57 .39N 3,95E -1,23 700 699,96 629,52 1 12 855 854,90 784,46 1 54 1012 1011,82 941.38 1 47 1203 1202,71 1132,27 2 0 1394 1393,54 1323,10 2 47 N 86,50 E .44 N 89,80 E .46 S 82,50 E ,17 S 43,40 E .67 S 17,70 E ,69 .24N 5,66E .35N 9,85E .04N 14,90E 2.773 20.17E 9.643 23,87E -2.06 -3,65 -5,97 -10,66 -18,44 1585 1584,29 1513,85 3 0 1775 1774,02 1703,58 3 5 1967 1965,73 1895,29 3 17 2158 2156.42 2085,98 3 12 2349 2347,25 2276,81 1 6 S 22,60 E .17 S 14.50 E ,23 S 18,00 E .15 S 13,30 E .15 S 20.40 E 1.11 18.70S 27,21E 28.263 30,41E 38.54S 33,42E 48.963 36.34E 55.873 38.21E -28,08 -38,12 -48,74 -59,45 -66.52 2604 2602,20 2531,76 1 6 2823 2821,17 2750,73 0 54 3043 3041.13 2970,69 1 12 3234 3232,03 3161,59 3 24 3422 3419.10 3348,66 7 48 S 17,20 E ,02 S 9,40 E .11 S 1,70 E ,15 N 61,30 W 2.17 N 43,40 W 2.49 60.503 39,78E 64.203 40,69E 68.213 41,04E 67.493 36,13E 55.543 22,46E -71 .40 -75, 15 -78,96 -76,33 -59,88 3613 3607.18 3536.74 12 6 3804 3791,96 3721,52 17 6 3964 3943,59 3873,15 20 6 4155 4120.33 4049.89 24 23 4346 4289,28 4218,84 31 6 N 38.80 W 2.29 N 35.00 W 2.66 N 31.70 W 1.99 N 28.80 W 2.32 N 25.40 W 3.60 30.513 1,00E 8.12N 27,66W 50.79N 55,6lW 113.32N 91.88W 192.55N 132,09W -28,33 18.57 68.89 140,73 229,44 4535 4448,94 4378.50 33 35 4726 4601,71 4531.27 40 5 4886 4722,16 4651,72 42 12 5075 4856.58 4786.14 47 5 5270 4986,04 4915,60 49 42 N 22.70 W 1.53 N' 20.60 W 3.47 N 21.50 W 1.36 N 22.60 W 2.62 N 22.90 W 1.34 284.90N 173,22W 391.36N 215,31W 489.59N 253,13W 612.64N 303,03W 747.10N 359,42W 330,54 444,93 550,08 682,80 828,58 5397 5070.25 4999.81 47 12 5492 5135.64 5065,20 45 47 5556 5180.69 5110.25 44 42 5746 5314.93 5244,49 45 24 5872 5405.24 5334,80 43 0 N 23.30'W 1.98 N 24.70 W 1.82 N 25.40 W 1.89 N 25.20 W .38 N 25.20 W 1.90 834.50N 396.70W 897.45N 424.71W 938.63N 443,95W 1060.19N 501.42W 1139.66N 538.81W 923,60 992,50 1037.94 1172,35 1260,15 MICROFILMED Date l D l l l - I RECEIVED MAR - 9 199 Alaska Oil & Gas Cons. Commission Anchorage S~RY-SUN DRILLING SERVICES.~,--,~ ANCHORAGE ALASKA PRUDHOE BAY DRILLING PBU/S-34 50029230500 NORTH SLOPE COMPUTATION DATE: 12/28/92 PAGE DATE OF SURVEY: 122892 MWD SURVEY JOB NUMBER: AK-MW-20095 KELLY BUSHING ELEV. = 70.44 OPERATOR: BP EXPLORATZON FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG HN DEGREES DG/IO0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT, SECT, 6062 5544,64 5474,20 6254 5686,20 5615,76 6349 5756,47 5686,03 6541 5898,02 5827,58 6635 5967.27 5896,83 42 35 N 25,00 W ,22 42 24 N 22,70 W ,82 42 12 N 23,40 W ,54 42 47 N 26,00 W ,97 42 17 N 25,60 W ,60 1256,56N 593,57W 1389,20 1375,17N 646,01W 1518,89 1434,00N 671,05W 1582,82 1551,81N 725,25W 1712,48 1609,04N 752,92W 1776,01 6793 6081,49 6011,05 6889 6149,31 6078,87 7079 6284,01 6213,57 7268 6419,41 6348,97 7375 6496,83 6426,39 45 5 N 25,40 W 1,77 45 0 N 25,20 W ,18 44 42 N 23,10 W ,80 43 47 N 19,50 W 1,41 43 30 N 20,60 W ,76 1707,56N 799,90W 1885,10 1768,98N 828,94W 1953,02 1891,23N 883,76W 2086,99 2014,05N 931,68W 2218,71 2083,42N 957,00W 2292,41 7555 6626,86 6556,42 7649 6694,98 6624,54 7776 6787.18 6716,74 7904 6880,10 6809,66 8032 6973,72 6903,28 44 0 N 21,8© W ,54 43 5 N 20,80 W 1,21 43 47 N 23,50 W 1,56 43 5 N 22,00 W ,97 42 54 N 19,90 W 1,13 2199,46N 1002,01W 2416,75 2259,80N 1025,54W 2481,45 2340,66N 1058,47W 2568,73 2421,83N 1092,52W 2656,74 2503,34N 1123,73W 2743,92 8160 7067,10 6996. 8288 7161,31 7090, 8447 7281.75 7211. 8606 7407.78 7337, 8765 7539,60 7469. 66 43 24 N 18,50 W ,84 87 41 47 N 17,40 W 1,38 31 39 42 N 16,50 W 1,37 34 35 24 N 19,40 W 2,92 16 32 35 N 23,10 W 2,19 2586,01N 1152,51W 2831,17 2668,42N 1179,22W 2917,36 2767,67N 1209,49~ 3020.40 2859,85N 1239,22W 3116,75 2942,71N 1271,34W 3205.52 8893 7647.91 7577, 8988 7729,13 7658, 9115 7839,42 7768, 9209 7922,56 7852. 9336 8036,70 7966, 47 31 47 N 24,00 W ,73 3005,24N 69 30 42 N 24,50 W 1,19 3050,17N 98 28 42 N 24,50 W 1,57 3107,42N 13 26 53 N 24,90 W 1,93 3147,25N 26 25 6 N 26,30 W 1,50 '3197,45N 1298,58~ 1318,82W 1344,91W 1363,22W 1387,25W 3273,73 3323,01 3385,92 3429,74 3485,38 9430 8122.23 8051, 9493 8180.00 8109, 9615 8292,05 8221, 9657 8330,48 8260, 9778 8440,72 8370, 79 23 53 N 27,10 W 1,32 3232,28N 56 23 6 N 28,00 W 1,39 3254,55N 61 23 30 N 29,10 W ,48 3296,94N 04 24 6 N 29,10 ~ 1,43 3311,75N 28 24 36 N 27,00 W ,83 3355,77N 1404.76W 1416.38W 1439.44W 1447.68W 1471.13W 3524.30 3549,37 3597,45 3614,33 3664,07 9875 8529,12 8458, 9970 8616.08 8545. 10034 8674,88 8604, 10096 8732,09 8661, 68 24 0 N 26,40. W ,67 3391,43N 63 23 30 N 26,10 W ,54 3425,74N 44 23 0 N 25,00 W 1,03 3448,53N 65 22 17 N 24,50 W 1,17 3470,22N 1489.07W 1505.99W 1516.89W 1526.89W 3703,93 3742,16. 3767,41 3791,2'8 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD, HORIZONTAL DISPLACEMENT = 3791,28 FEET AT NORTH 23 DEG, 44 MIN, WEST AT MD = 10096 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION'COMPUTED ALONG 336,'25 DEG, ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S-34 50029230500 NORTH SLOPE COMPUTATION DATE: 12/28/92 DATE OF SURVEY: 122892 JOB NUHBER: AK-MW-20095 KELLY BUSHING ELEV. : 70.44 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -70.44 .00 N .00 E 1000 999.82 929.38 .09 N 14.53 E 2000 1998.67 1928.23 40.35 S 34,00 E 3000 2998.14 2927.70 67.31 S 41.01 E 4000 3977.31 3906.87 61.56 N 62.18 W .00 .18 .18 1.33 1.15 1.86 .53 22.69 20.83 5000 4804.60 4734.16 562.65 N 282.43 6000 5499.01 5428.57 1218.53 N 575.84 7000 6227.86 6157.42 1840.11 N 861.95 8000 6950.28 6879.84 2482.86 N 1116.31 9000 7739.44 7669.00 3055.75 N 1321.36 195.40 172.71 500.99 305.60 772.14 271.15 1049.72 277.58 1260.56 210.83 10000 8643.59 8573.15 3436.49 N 1511.26 W 10096 8732.09 8661.65 3470.22 N 1526.89 W 1356.41 95,86 1363.91 7.49 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/S-34 50029230500 NORTH SLOPE COMPUTATION DATE: 12/28/92 DATE OF SURVEY' 122892 JOB NUMBER' AK-MW-20095 KELLY BUSHING ELEV, = 70,44 OPERATOR' BP EXPLORATION FT, INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 ,00 -70,44 7O 70,44 ,00 170 170,44 100,00 270 270,44 200,00 370 370,44 300,00 ,00 N ,00 E ,00 ,00 N ,00 E ,00 ,00 ,00 N ,00 E ,00 ,00 ,01 N ,04 E ,00 ,00 ,25 N 1,00 E ,01 ,01 470 470,44 400,00 570 570,44 500,00 670 670,44 600,00 770 770.44 700.00 870 870,44 800,00 ,48 N 2,05 E ,55 N 3,31 E ,21N 5,05 E ,33 N 7,15 E ,35 N 10,37 E ,01 ,01 ,02 ,01 ,04 ,02 ,06 ,02 ,11 ,05 970 970,44 900.00 1070 1070,44 1000,00 1170 1170,44 1100,00 1270 1270.44 1200.00 1370 1370,44 1300,00 ,21 N 13,61 E ,16 ,05 ,20 S 16,73 E ,21 ,05 ,96 S 19,39 E ,27 ,06 ,49 S 21,79 E ,33 ,06 ,56 S .23,53 E ,43 ,10 1470 1470,44 1400,00 1571 1570,44 1500,00 1671 1670,44 1600,00 1771 1770,44 1700,00 1871 1870,44 1800,00 13,22 S 25,02 E 18,03 S 26,93 E 22,87 S 28,95 E 28,08 S 30,36 E 33,33 S 31,74 E ,55 ,12 ,69 ,13 ,82 , 14 ,97 , 15 1 ,12 ,15 1971 1970.44 1900,00 2071 2070,44 2000,00 2172 2170.44 2100.00 2272 2270,44 2200,00 2372 2370,44 23'00,00 38,8O S 33,50 E 44,28 S 35,23 E 49,72 S 36,52 E 54,49 S 37,69 E 56,28 S 38,36 E 1 ,28 ,17 1 ,45 ,17 1 ,60 ,16 1 ,73 ,13 1 ,75 ,02 2472 2470.44 2400,00 2572 2570,44 2500,00 2672 2670.44 2600,00 2772 2770,44 2700.00 2872 2870.44 2800,00 58,O9 S 39,03 E 59,92 S 39,60 E 61,75 S 40,17 E 63,42 S 40,56 E 64,97 S 40,81 E 1 .77 ,02 1 ,79 ,02 1 .81 .02 1 .82 ,01 1 .84 ,01 2972 2970,44 2900,00 3072 3070,44 3000,00 3172 3170.44 3100,00 3272 3270,44 3200.00 3372 3370,44 3300.00 66,73 S 40,99 E 68,70 S 40,92 E 68,74 S 38,80 E 66,10 S 33,95 E 59,91 S 26,76 E 1 ,85 ,02 1 ,87 ,02 1 ,90 ,O3 2,06 ,16 2,52 ,46 PAGE PRUDHOE BAY DR:[LL]:NG PBU/S-34 50029230500 NORTH SLOPE COMPUTAT]:ON DATE: 12/28/92 DATE OF SURVEY: 122892 JOB NUMBER: AK-MW-20095 KELLY BUSHZNG ELEV, = 70,44 OPERATOR: BP EXPLORATZON FT, ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNAT NORTH/SOUTH EAST/WE ES MD-TVD VERTZCAL ST DIFFERENCE CORRECTZON 3473 3470.44 3400.00 3575 3570.44 3500.00 3677 3670.44 3600.00 3781 3770.44 3700.00 3886 3870.44 3800.00 49,95 S 17.35 36,39 S 5,79 19,03 S 7,94 2,81 N 23,92 29,10 N 41,83 E 3,46 ,94 E 5,04 1,58 W 7,47 2,43 W 11,08 3,61 W 16,02 4.94 3992 3970,44 3900,00 4100 4070,44 4000,00 4210 4170.44 4100,00 4324 4270,44 4200,00 4441 4370,44 4300.00 59,34 N 60,83 94,12 N 81,17 134.29 N 103.12 182,47 N 127,27 238,14 N 153.05 22.22~ 6.19 30.04 7.82 40.03 10.00 53.66 13.63 70.98 17.33 4560 4470,44 4400,00 4685 4570,44 4500,00 4816 4670,44 4600,00 4952 4770,44 4700,00 5095 4870,44 4800,00 298,32 N 178,79 367.37 N 206,19 446,00 N 235,97 531,53 N 269.83 626.48 N 308,80 90,51 19,52 115,11 24,60 145,78 30,66 181,65 35,88 224.98 43.33 5245 4970.44 4900,00 5397 5070.44 5000,00 5541 5170,44 5100.00 5682 5270.44 5200.00 5824 5370,44 5300,00 730,27 N 352,32 834,69 N 396.78 929.46 N 439.60 1019.38 N 482.21 1110.30 N 524.99 W 275.54 50.56 W 326,84 51,30 W .371,13 44,30 W 412.20 41.07 W 453.98 41.78 5961 5470,44 5400,00 6097 5570.44 5500.00 6232 5670,44 5600,00 6367 5770.44 5700,00 6503 5870,44 5800.00 1194.67 N 564.69 1278,06 N 603.60 1361,90 N 640.46 1445,63 N 676,08 1528,85 N 714.05 490.71 36.73 526.60 35.89 562.22 35.61 597.42 35.21 632.97 35.55 6639 5970.44 5900,00 6777 6070,44 6000,00 6918 6170,44 6100,00 7059 6270,44 6200,00 7199 6370,44 6300,00 1611.65 N 754.16 1697.60 N 795.17 1788.10 N 837.93 1878.87 N 878.49 1969,72 N 915,41 668,85 35,88 706,95 38,10 748,44 41,49 789,47 41,02 829.53 40,06 7338 6470,44 6400,00 7476 6570.44 6500,00 7615 6670,44 6600,00 7752 6770.44 6700,00 7890 6870,44 6800.00 2059.98 N 948.18 2148,88 N 981.79 2238,32 N 1017,37 2325.94 N 1052.07 2413,45 N 1089,13 W 868.17 38.64 W 906.14 37.96 W 944.94 38.80 W 982.37 37.43 W 1020.32 37.96 PAGE 6 S~,RY-SUN DRZLLZNG SERVZCES ~"'% ANCHORAGE ALASKA PRUDHOE BAY DRTLLTNG PBU/S-34 50029230500 NORTH SLOPE COMPUTAT~'ON DATE: 12/28/92 DATE OF SURVEY: 122892 JOB NUMBER: AK-HW-20095 KELLY BU'SHZNG ELEV. = 70.44 FT. OPERATOR: BP EXPLORATZON ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTZCAL VERTZCAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDZNATES NORTH/SOUTH EAST/WEST DTF MD-TVD VERTZCAL FERENCE CORRECTZON 8027 6970.44 6900.00 2500.48 N 1122.69 W 1057.09 36.76 8164 7070.44 7000.00 2589.00 N 1153.51 W 1094.16 37,07 8300 7170.44 7100.00 2676.20 N 1181.66 W 1129.80 35.65 8432 7270.44 7200.00 2758.67 N 1206.82 W 1161.87 32.06 8559 7370.44 7300.00 2834.17 N 1230.41 W 1189.39 27.52 8682 7470.44 7400.00 2900.58 N 1254.24 8801 7570.44 7500.00 2960.85 N 1279.07 8919 7670.44 7600.00 3018.00 N 1304.26 9036 7770.44 7700.00 3072.49 N 1328,99 9150 7870.44 7800.00 3122.87 N 1351.95 1211.79 22.40 1231.16 19.38 1249.07 17.90 1265,61 16.54 1279.92 14.31 9262 7970.44 7900.00 3169.24 N 1373.44 9373 8070.44 8000.00 3211.62 N 1394.26 9482 8170.44 8100.00 3250.95 N 1414.46 9591 8270.44 8200.00 3288.73 N 1434.87 9700 8370.44 8300.00 3327,37 N 1456.38 1292.23 12.31 1302.82 10.59 1312.16 9.34 1320.99 8.83 1330.34 9.34 9810 8470.44 8400.00 3367.90 N 1477.31 W 9920 8570.44 8500.00 3407.91 N 1497.25 W 10029 8670.44 8600.00 3446.83 N-.,;~q 1516.09 f(2 10096 8732.09 8661.65 3470.22 N/ ' 1526 89 fO"?THE CALCULAT'rON PROCEDUR E A L]"NEAR ~'NTERPOLAT THE NEAREST 20 FOOT MD ('FROM MTNTMUM CURVATURE') 1340.25 1349.79 1358.74 1363.91 ZON BETWEEN POZNTS 9.92 9.54 8.95 5.17 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 02/23/93 T# 84337 BP/PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. M-26 q0-0% PFC 02/19/93 #1 P-06 q%' ~% CCL 02/16/93 #1 S-34 9~'~FC 02/14/93 #1 T-07 ~%'~ CCL 02/18/93 #1 T-07~~'~ PRODUCTION LOG 02/18/93 #1 X-14A~\~PFC 02/15/93 #1 X-14A q~,w%~~~ 02/14/93 #1 Y-15Z~,~ CA ~ 02/16/93 #1 Information Control C ~ Well Records 11450.00-11710.00 ATLAS 5 " 9600.00-10306.00 ATLAS 5 " 9760.00-10522.00 ATLAS 5 " 8525.00- 9680.00 ATLAS 5 " 8525.00- 9680.00 ATLAS 5 " 11685.00-11940.00 ATLAS 5 " 11550.00-12034.00 ATLAS 5 " 9985.00-10272.00 ATLAS 5 " AOGCC GEOLOGmCAL MATERIALS INVENTORY LIST PERMIT # ~,.,, - )tJ~, WELL NAME Pr~L,~ COMPLETION DATE -,~ Ii (~ % I~ CO. CONTACT' acheck off or list data as it is re~e~edo*l!st re.ired date for 407. if not rqquired list as NR 407 I*' !~,1 drii,ii~ll, histo. ~ .,i surveyl i% I iwell testsll ~ I core des rmp't'°d cored Interva,!l,S corel~nam)rsis p~Lm aal dray,ditch Inte~ams digital data i i i i i ii i iii i i i i i ................ ~, u~ I LOG TYPE RUN INTERVALS SCALE ,1 NO. (to the near, est foot] pnchll00') i i iii ilmll i il i i · ~ ii i i iii iii k ii ii i mm m m m m m mm mm m mm m ~ J~ mmm m - ~ i i i i iiii i i ii i iiii ii ii i i i i i iiii i i i iii iiii , I , otoo o %, 5 i i Illllll I I I I I I I ] II I I BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/11/93 T9 84215 BP/ PBU CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. B-08 PRODUCTION LOG 01/02/93 91 C-02 SPINNER 01/02/93 91 F-08 ~'// STATIC 01/02/93 91 F_15 ~'/-~$,° ~-/'l'/~ STATIC 01/04/93 91 F-47 STATIC 01/04/93 #1 S-03~/'/~ PRODUCTION LOG 01/01/93 91 SBB 01/03/93 ~1 9200.00- 9655.00 ATLAS 5 " 9805.00-10136.00 ATLAS 5 " 10900.00-11241.00 ATLAS 5 " 9150.00- 9745.00 ATLAS 5 " 8500.00- 9381.00 ATLAS 5 " 11700.00-12101.00 ATLAS 2/5" 1980.00-11210.00 ATLAS 2/5" 9850.00-10400.00 ATLAS 5 " 9500.00-10540.00 ATLAS 5 " Information Control Well Records / RECEIVED JAN 2 6 1993 Alaska Oil & Gas Cons. Com~lpll Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/11/93 T# 84217 BP/ PBU OH LOGS Enclosed is your copy of the materials listed below. If you have any questionS, please contact BP Well Records at (907) 564-4004. S-34I SS TVD 12/31/92 #1 10120.00-10621.00 SCH S-34I RFT 12/31/92 #1 10128.00-10395.00 SCH S-3 4I DIL/fF~/~ 12/31/92 #1 10120.00-10621.00 SCH Information Control Well Records 1/2" 5 " 2/5" 2/5" Alaska Oil & Gas (~o~s. Corniness|on AnCbm'age BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/12/93 T# 84219 BP/ PBU MAGNETIC TAPES Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. I S-34I · OH/BHC 9468.00-10648.00 API#5002922305!00 10128.00-10395.00 APZ#500292230500 FIN 12/31/92 #1 1600BPI 9216->TP# FLD 12/31/92 #1 1600BPI 9217->TP# SCH REF#92740 SCH REF#92740 Information Control Well Records MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Leigh Gri i~n~/~'/['~ 3 Commissioner date: file: December 28, 1992 JER12182.DOC thru: Blair E Wondzell Sr Petr Engineer from: ~orry Herring Petr Inspector subject: BOP Test-Nabors 28E BPX Well S-34[ Prudhoe Bay Unit PTD #92-136 Friday, December 18, 1992: I witnessed a B.O.P. Test on Nabors Rig 28E on Prudhoe Bay Well S-341 The 13 3/8" casing was set at 2988 ft. The test started at 12:30 a.m. and was completed smoothly. Only minor discrepancies were noted. The well sign needed to be posted and additional nitrogen was required for the accumulator. Tool Pusher Mike Downey and crew were well organized. The rig was clean and in good shape. SUMMARY: The B.O.P. Test was completed .successfully. There were no system failures. The test took 2 112 hours. ~Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Wkvr Drlg,./ Operator Well 5 - Drlg contrctr I% Location (general) Housekeeping (general ft Rep Permit # Well sign Rig Rsrve pit. ~A fUO SYSTEMS: Visual Trip tank Pit gauge Flow monitor V~ Gas detectors s BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve TEST: Initial ~ Weekly, Other -- 13 ~ Location= Sec 5~- T IZN R I Z6 M ACCUMULATOR SYSTEM: Upper Kelly J Test Pressure Lower Kelly J ~-~) ' ~0 Ball type 2,_,,~'"~) ' ~(~ Inside BOP ~_~0 ' ~~ Choke manifold ~-~-~ ' ~'-~(~ Number valves ~"'~:~ ° ~3C) Number flanges ~'-~3 ' ~"~04~ Adjustable chokes A Hydraulically operated choke Full charge pressure ~)(~) Press after closure {~'(~0 Pump incr c)os press 200 psig min Full charge press attained ,,, I min N2 ~ ~oTTLE.~3 psig Controls: Master xy/~ ~ Remote ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: psig psig ~,~.__~S e c Test pressure Test pressure Test pressure Test pressure Test.pressure TEST RESULTS: Failures 0 Test time ~j~ hrs Repair or replacement of failed equipment to be made within '7 days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/92) 24-HR NOTI C~ i VEN? yes ~ no Waived by: Witnessed by: ~W~b~ AOGCC phone 279-1 FAX~ WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION December 14, 1992 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 Michael Zanghi Drilling Engineer Supervisor BP Exploration (alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S-34i BP Exploration (Alaska) Inc. Permit No: 92-136 Sur. Loc. 1645'SNL, 1782'EWL, Sec. 35, T12N, R12E, UM Btmhole Loc. 3132'SNL, 5152'WEL, Sec. 26, T12N, R12E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt yOu from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ', Chairman BY ORDER OF THE COMMISSION dlf/Enclosure cc~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ~'"'"~ ALASKA OIL AND GAS CONSERVATION COMMISSION PER.iT TO DRILL 20 AAC 25.005 la. TYpe of work Drill [] Redrilll-illb. Type of well. Exploratoryl-! Stratigraphic Test I-1 DeVelopment Oil [] Re-Entry [] Deepen !-iI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) '10. Field and Pool BP Exploration KBE = $2'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28257 4. Location of well at surf-ace 7. Unit or property Name il 1. Type Bond(,~e 2o ^^c 25.025) 1645, SNL, 1782' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3225' SNL, 5110' WEL, SEC.'26, T12N, R12E S-34i (13-26.12-12) 2S100302630-277 At total depth !9. Approximate spud date" Amount 3132' SNL, 5152' WEL, SEC. 26, T12N, R12E 12/13/92 $200,000.00 i~5'. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 28278-126' feet S-10/37' @ 150'MD feet 2560 10704' MD/9231' TVD'eet i16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.o35 (e)(2)) Kickoff depth ;~oo3~eet Maximum hole ancjle ,~3.~ ° Maximum surface 3330pslg At total depth (TVD) 8800'/4390psig 18. Casing program Settin~~g Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD ~. TVD (include stage data) ...30" 20" 91.5~ H-40 Weld 80' 32' 32' 110' 110' 11 yds Arcticset 16" 13-3/8" 68# L-80 BTC 2872' 31'i ' 31' 2903' 2900' 1067sx CS 111/730 sx CS II ..... 1,2-1/4" 9-5/8" 47# L-80 NSCC 10119' 30'I 30' 10149' 10149' 779sx "G"/3OO sx "G" 8-1/2" 7" 26# L-80 NSCC 734' 9969' 8573' 10703' 9230' 204 sx Class "G" ,, i1'9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductoriRFCEIVED Surface Intermediate ~ .- Production ~'~'~ Liner ,~S!~:~ ()it Z: Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drillincj fluid program E'I Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-! certif that t e foregoing is true and correct to the best of my knowledge 21. i hereby ~ .~.~~ Si~ned . Title Drilling Engineer Supervisor Date~ 'z_.- ~.- Commission Use Only Permit Number' IAPI number IAppro. qval date _ ISee cover letter ~.2.-/',~ ]5 0 -c3 ~ ? - ~-~ ~.~ o..,z" I /~. "/"~"~'~' Ifor other requirements COnditions of approval Samples required [] Yes ~]'NO Mud log required []Yes J~ No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~reo '~3 Yes [] No Required working pressure for ,13~P.E,.,,~] · · ~5M; · l'315M; Other: Orlg~81~g''~ ~j~, 1-13M, []10M, Approved by D~,~t~ci W. johnStorl by order of Commissioner me commission Date/~,~/,/~/~,~ Form 10-401 Rev. 12-1-85 ... Submit in' WELL PLAN S-34 Injector [13-26-12-12] PBU. LOCATION: Surface: Target: T.D.: 1645 FNL, 1782' FWL, Sec. 35, T12N, R12E 3225 FNL, 5110' FEL, Sec. 26, T12N, R12E 3132' FNL, 5152' FEL, Sec. 26, T12N, R12E ESTIMATED START: Dec 13, 1992 OPR. DAYS TOCOMPLETE: 21 (17 days drilling, 4 days completion) ~RACTOR: Nabors 28E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 43.5deg/N23.6W/3003'/2.0&1.5/4139' Estimated Ground level elevation is 36.04' AMSL. KB to ground level elevation is 32'. Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR 8 0 8 0 8.5 13-3/8" SHOE 2900 2903 9.1 TOP UGNU SANDS 3 6 6 8 3 6 7 7 9.1 SEABEE 5268 5586 9.8 KUPARUK 6 6 6 8 751 6 1 0.2-1 0.5 9-5/8" SHOE 8713 10149 SAG RIVER SANDSTONE 8 71 3 1 01 4 9 9.0 - 9.5 TOP SADLEROCHIT 8 851 1 0 29 8 9.0 - 9.5 TARGET 8950 10404 9.0-9.5 TOTAL DEPTH 9 231 1 0 70 4 9.0 - 9.5 CASING PROGRAM: .Hole Csa Wt Grade Conn Len_oth Tog Btm 30" 2,0" 91.5# H-40 WELD 80 32 110 16" 13-3/8" 68# L-80 BTC 2872 31 2903 12-1/4" 9-5/8" 47# L-80 NSCC 10119 30 10149 8-1/2" 7" 26# L-80 NSOC 734 9969 10703 COMPLETION: Tubing' 5-1/2" 1 7# L-80 LTC-M 9890 29 9919 GLMs: 6.5-1/2" x 1-1/2" with 5 dummies and 1 RP shear(2800 psi) in top station Packer: PERM/LATC 9-5/8" x 5-1/2" Baker set at 9919' or +/- 50' above TOL Isolation Pkr: 7" x 4-1/2" w/ 4-1/2" tail assy w/ X & XN nipples, L-80 I_OC~ING PROG~: Ooen Hole- Cased Hole 12-1/4" Hole: None 8-1/2" 'Hole: DIL/CNL/GR/SP/SDT, Optional' LDT/GR, RFT ATLAS SBT IN 7" AND 9-5/8" before running tubing No gyro is planned. RECEIVED DEC - 7 Alaska 0ii & (~as Co~s, 00~-~,mJsst0n PROPOSED DRILLING AND COMPLETION PROGRAM S-34 I Procedure 1. MIRU drilling rig. N/U diverter and function test same. o Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. . PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. 4. Drill intermediate hole to intermediate casing point. . MU and run 9-5/8 casing string and cement as per well plan. Bump cementing plug with mud. 6. RIH and drill 8-1/2" hole through reservoir to TD. 0 RU and run e-line logs. ... 8. MU 7" liner on 5" DP. RIH to TD. Cement same. excess cement from wellbore. POOH. Set liner hanger and packer. Circulate 9. MU casing scraper & clean out 7" liner. 10. RU e-line and run cement bond log through liner and bottom of 9-5/8" csg. Set 7" isolation packer on e-line. 11. 12. Run 5-1/2", L-80 and packer assembly with SSSV. and casing to 3500 psi. NU tree and test to 5000 pSi. Release drilling rig. Freeze protect with diesel. Test tubing o Anticipated BHP: ° Maximum Anticipated Surface Pressure: o Planned Completion Fluid: 3600 psi @ 8800' TVD SS 2800 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. Based on previous logs on S Pad, no potential productive zones are anticipated above 3669' TVD (Ugnu). d. No potential hazardous levels of H2S are anticipated in this 'well. RECEIVED DEC - 7 lr392 Alaska Oil & 6~s Ccr~s. Commission A,qchora98 Prudhoe Prudhoe S-PAD S-34 Bay Drilling Bay HITHI VERTICAL VIEW SCALE 1000 Yt, / DIVISION REFERENCE: WELL HEAD 0 0 -22 -65 0.00° @ 0 MD R,K.B. 68' (ABOVE SEA LEVEL) 0.00' ~ 200 MD 8:88: ~ ~88 ~B BEGIN NUDGE BUILD RATE, 1.OO ~EG/100 FT 2.00' @ 700 MB s,oo' e12oo .D ~:~8: ~ 1~8~ ~B BEGIN DRO~ BACK TO VERTICAL DROP RATE, 1.00 DEG/IO0 FT 3.00- e 17oo .D t. O0' @ 1900 MD MD BASE OF eERMFRDST 1 0000 i -lO00 -B 699 980 4.00' e 3203 MD 8.00' @ 3403 MD 12.00' e 3603 MIl 13.48' ~ 3677 MI) UGNU IB.O0' @ 3903 MD 22.00' @ 41 03 MD 26.00' @ 4303 MD 30.00' ~ 4503 MD 34.00' ~ 4703 MD 38.00' @ 4903 MD ~. 42.00' e 5103 MD ~. 43.49' e 5178 MD END OF BU[LD ~86 MD TDP OF SEABEE ~ ' -~3~' e 7585 MD IKRU/LCU . - ~ 43.49' ~ 8839 MD START OF ~RDP ~l.5/lO0 DRDP RATE, 1.50 DEG/IO0 FT 3219 ~ 40.4g' e 9039 MD - ~ 37.49' e 9239 MD RECEIVED ' ~ 31.49' e 9639 MD ~ ~8.49' e 9839 MD ~5.49' ~ 10039 MD ~ aO.O0' e 10405 Ho TARGET FIC~ --7 ~QO ~ 20.00' e lOSS4 MD ORGINAL OWC aO. 00' e 10704 MD TOTAL DEPTHAlaska Oil a Gas Cons. Cornmissio¢ 4140 Anchmag~ 0 l 000 2000 3000 4000 5000 VERTICAL SECTION PLANE: 336,40° IBHL DATA TVD 9230,94 MD 10703.8q VS 4139.5~ No. th 3793.2~ [E~St -1657.4~ Trove/ ( lng Cyt inder - Normal ReFerence TVD', 0 - 9P31 Ft, Intervet, AL t B irections Ret to True P/oune 50 Ft, Nor'th (ISmIT IC)O 30' 60' 60s ~70° 8Oo 90' ~40° lEO' 210· 600 150 150' 180'* RECEIVED Alaska Oil a Gas Cc~':s, (;ommission Anchora(~,a Smith International, Inc. Travelling Cylinder Report Computed by the Sii Win-CADDS System Normal Plane Method Date: Page 1 12/1192 REFERENCE WELL: Prudhoe Bay Dritting Prudhoe Bay S'PAD S-34 S-341NP4 TVD, N/S and E/W are measured from the WELLHEAD We[[path Slot Distance sO1 S-01 1026.79 sOlr S-OIR 1026.85 sO2 S-02 858.79 sO3 S-03 803.42 sO4 S-04 695.47 sO5 S-05 484.98 sO6 S-06 458.61 sO7 S-07 328.08 sO8 S-08 256.24 sO9 S-09 145.62 sl0 ... s-10 37.02 sll S-ll 62.39 s12 S-12 171.58 s12a S-12A 159.57 s13 S-13 279.05 s14 S-14 375.32 s15 S-15 250.53 s16 S-16 174.53 s17 S-17 1198.09 s17a S-17A 1197.90 s18 S-18 1261.85 s19 S-19 882.42 s20 S-20 754.96 s21 S-21 770.03 s22 S-22 988.20 s23 S-23 837.82 s24 S-24 197.83 s25 S-25 597.21 s26 s-26 537.95 s27 S-27 549.85 s28 S-28 512.58 s29 S-29 220.57 s30 S-30 343.70 s31 S-31 329.43 s32 S-32 69.76 s-33m~d S-33 279.89 S-35WP4 S-35 33.29 S36MI~:) S-36 106.66 S-37N~IO S-37 140.28 S-38MIJD S-38 98.28 S-38WP S-38 101.98 Closest Points Direction Ref MD Ref TVD 270.89 50.00 50.00 270.~ 50.00 50.00 253.87 3710.33 3700.00 270.76 550.00 550.00 270.71 550.00 550.00 217.69 4640.94 4550.00 247.93 4024.68 4000.00 239.76 2453.17 2450.00 270.03 550.00 550.00 268.78 600.01 600.00 271.06 150.00 150.00 55.97 1301.78 1300.00 68.49 2003.17 2000.00 61.83 2703.17 2700.00 75.42 1853.16 1850.00 78.'71 2303.17 2300.00 339.70 5974.94 5550.00 344.53 67~3.09 6100.00 246.64 2703.17 2700.00 246.65 2703.17 2700.00 237.98 0.00 0.00 250.55 4132.17 4100.00 240.8? 4465.90 4400.00 270.87 150.00 150.00 270.90 500.00 500.00 270.83 500.00 500.00 18.42 4949.48 4800.00 247.60 4465.90 4400.00 240.24 4465.90 4400.00' 271.10 450.00 450.00 270.89 500.00 500.00 270.58 500.00 500.00 238.00 3762.01 3750.00 270.85 550.00 550.00 274.22 650.02 650.00 245.26 4024.68 4000.00 68.19 900.33 900.00 90.87 0.00 0.00 91.08 0.00 0.00 243.05 3918.67 3900.00 249.04 3866.16 3850.00 RECEIVED Smith International, Inc. Proposal Report Calculated using the Minimum Curvature Method Computed by the Sii Win-CADDS System Vertical Section Plane: 336.40 deg. Survey Reference: tJELLHEAD Reference World Coordinates: Lat. 70.21.12.86 N - Long. 149.01.33.64 S4 Reference GRID System: Alaska State PLane Zone: ALaska 4 Reference GRID Coordinates: (feet): 5979854.96 N 619944.03 E Vertical Section Reference: 14ELLHEAD Closure Reference: i4ELLHEAD North Aligned To: TRUE NORTH Prudhoe Bay Drilling Page i Date: 12/1/92 IJe[[path ID: S-34II4P Program ~1o: 4 Last Revision: 12/1/92 Prudhoe Bay S-PAD S-34 S-341UP4 Measured Incl Drift TVD Subsea T 0 T A L Depth Dir. Depth Rectangular Offsets (ft) (deg.) (deg.) (ft) (ft) (ft) (ft) Geographic Coordinates Latitude / Longitude GRID Coordinates Closure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. Vertical '~ Section (ft) (dg/lOOft) R.K.B. 68' (ABOVE SEA LEVEL) 0.00 0.00 0.00 0.00 '68.00 0.00 N 0.00 E 100.00 0.00 0.00 100.00 32.00 0.00 N 0.00 E 200.00 0.00 0.00 200.00 132.00 0.00 N 0.00 E 70.21.12.8561 N 149.01.33.6425 70.21.12.8561 N 149.01.33.6425 70.21.12.8561 N 149.01.33.64~5 5979854.96 619944.03 0.00 5979854.96 619944.03 0.00 5979854.96 619944.03 0.00 a 0.00 a 0.00 a o.oo 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 232.00 0.00 N 0.00 E 400.00 0.00 0.00 400.00 332.00 0.00 N 0.00 E BEGIN NUDGE 500.00 0.00 0.00 500.00 432.00 0.00 N 0.00 E 70.21.12.8561 N 149.01.33.6425 70.21.12.8561 N 149.01.33.6425 70.21.12.8561 N 149.01.33.6425 5979854.96 619944.03 0.00 a 0.00 5979854.96 619944.03 0.00 a 0.00 5979854.96 619944.03 0.00 a 0.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 1.00 156.40 599.99 531.99 0.80 S 0.35 E 700.00 2.00 156.40 699.96 631.96 3.20 S 1.40 E · 800.00 3.00 156.40 799.86 751.86 ?.20 S 3.14 E 70.21'12.8482 N 149.01.33.6323 70.21.12.8246 N 149.01.33.6017 70.21.12.7853 N 149.01.33.5506 5979854.17 619944.39 0.87 5979851.79 619945.48 3.49 59798~?.82 619947.29 7.85 156.40 -0.87 1.00 156.40 -3.49 1.00 156.40 -7.85 1.00 900.00 4.00 156.40 899.68 831.68 12.79 S 5.59 E END OF NUDGE 1000.00 5.00 156.40 999.37 931.37 19.98 S 8.73 E 1100.00 5.00 156.40 1098.99 1030.99 27.97 S 12.22 E 1200.00 5.00 156.40 1198.60 1130.60 35.95 S 15.71 E 1300.00 5.00 156.40 1298.22 1230.22 43.94 S 19.20 E 1400.00 5.00 156.40 1397.8~ 1329.84 51.93 S 22.69 E .70.21.12.7303 N 149.01.33.4792 70.21.12.6596 N 149.01.33.3874 70.21.12.5811 N 149.01.33.2854 70.21.12.5025 N 149.01.33.1834 70.21.12.4240 N 149.01.33.0814 70.21.12.3454 N 149.01.32.9794 59798~2.26 619949.82 13.96 5979835.13 619953.08 21.80 59?9827.20 619956.69 30.52 5979819.27 619960.31 39.23 5979811.34 619963.93 4?.95 5979803.41 619967.54 56.67 a 156.40 -13.96 1.00 a 156.40 -21.80 %00 a 156.40 -30.52 156.40 -39.23 0.00 156.40 -47.95 0.00 156.40 -56.67 0.00 BEGIN DROP BACK TO VERTICAL 1500.00 5.00 156.40 1497.46 1429.46 59.91 S 26.18 E 1600.00 4.00 156.40 1597.15 1529.15 67.10 S 29.32 E 1700.00 3.00 156.40 1696.97 1628.97 72.70 S 31.76 E 70.21.12.2669 N 149.01.32.8774 70.21.12.1961 N 149.01.32.7856 70.21.12.1411 N 149.01.32.7141 5979795.48 619971.16 5979?88.34 619974.42 5979782.79 619976.95 65.38 a 156.40 -65.38 0.00 73.23 a 156.40 -75.23 1.00 79.33 ~ 156.40 -79.33 1.00 1800.00 2.00 156.40 .1796.87 1728.87 76.69 S 33.51 E 1900.00 1.00 156.40 1896.83 1828.83 79.09 S 34.55 E IASE OF PERMAFROST 1946.1? 0.54 156.40 1943.00 1875.00 79.66 S 34.80 E 70.21.12.1018 N 149.01.32.6631 70.21.12.0782 N 149.01.32.6325 70.21.12.0726 N 149.01.32.6252 5979778.82 619978.76 5979776.44 619979'85 5979775.87 619980.10 83.69 a 156.40 -83.69 1.00 86.31 a 156.40 -86.31 1.00 86.93 a 156.40 -86.93 1.00 ~ND OF DROP 2000.00 0.00 0.00 1996.83 1928.83 79.89 S 34.90 E 70.21.12.0704 N 149.01.32.6223 g 5979775.6~ 619980.21 87.18 a 156.40 2100.00 0.00 0.00 2096.83 2028.83 79.89 s 34.90 E 70.21.12.070~ N 149.01.32.6223 ~ 5979775.64 619980.21 87.18 a 156.40 2200.00 0.00 0.00 2196.83 2128.8~ 79.89 S 34.90 E 70.21.12.0704 N 149.01.32.6223 g 5979775.64 619980.21 87.18 a 156.40 -87.18 1.00 -87.18 0.00 -87.18 0.00 Smith International, Inc. Proposal Report Page; Date: 12/1/9; ~ettpath ID: S-341~i Measured Inct Drift TVD Depth Dir. (ft) (deg.) (deg.) (ft) 2400.00 0.00 0.00 2396.83 2500.00 0.00 0.00 2496.83 2600.00 0.00 0.00 2596.83 2700.00 0.00 0.00 2696.83 2800.00 0.00 0.00 2796.83 2900.00 0.00 0.00 2896.83 13 3/8" CSG. PT. 2903.17 0.00 0.00 2900.00 3000.00 0.00 0.00 2996.83 KOP @ 2'/100 3003.17 0.00 0.00 3000.00 Subsea Depth (ft) TOTAL Rectangular Offsets (ft) (ft) 2328.83 79.89 S 34.90 2428.83 79.89 S 34.90 2528.83 79.89 S 34.90 2628.83 79.89 S 34.90 E 2728.83 79.89 S 34,90 E 2828.83 79.89 S 34.90 E 2832.00 79.89 S 34.90 E 2928.83 79.89 S 34.90 E 2932.00 79.89 S 34.90 E 3103.17 2.00 336.40 3099.98 3031.98 3203.17 4.00 336.40 3199.84 3131.84 3303.17 6.00 336.40 3299.45 3231.45 3403.17 8.00 336.40 3398.70 3330.70 3503.17 10.00 336.40 3497.4? 3429.47 3603.17 12.00 336.40 3595.62 3527.62 UGNU 3677.38 13.48 336.40 3668.00 3600.00 3703.17 14.00 336.40 3693.06 3625.06 3803.17 16.00 336.40 3789.64 3721.64 3903.17 18.00 336.40 3885.27 3817.27 4003.17 20.00 336.40 3979.82 3911.82 4103.17 22.00 336.40 4073.17 4005.17 4203.17 24.00 336.40 4165.21 4097.21 4303.17 26.00 336.40 4255.84 4187.84 4403.17 28.00 336.40 4344.94 4276.94 4503.17 30.00 336.40 4432.39 4364.39 4603.17 32.00 336.40 4518.11 4450.11 4703.17 34.00 336.40 4601.97 4533.97 4803.17 36.00 336.40 4683.88 4615.88 4903.17 38.00 336.40 4763.74 4695.74 5003.17 40.00 336.40 4841.45 4773.45 5103.17 42.00 336.40 4916.92 4848.92 END OF BUILD 5177.88 43.49 336.40 4971.78 4903.78 5277.88 43.49 336.40 5044.32 4976.32 5377.88 43.49 336.40 5116.87 5048.87 5477.88 43.49 336.40 5189.41 5121.41 5577.88 43.49 336.40 5261.96 5193.96 78.29 S 34.21 E 73.50 S 32.11 E 65.51 S 28.62 E TOP OF SEABEE 5586.21 43.49 336.40 5268.00 54.34 S 23.74 E 40.01 S 17.48 E 22.53 S 9.84 E 7.53 S 3.28 E 1.91S 0.83 E 21.80 N 9.53 g 48.59 N 21.24 78.42 N 34.27 111.26 N 48.62 147.06 N 64.27 185.79 N 81.19 227.38 N 99.36 271.81 N 118.77 319.00 N 139.40 368.90 N 161.20 421.46 N 184.17 476.61 N 208.26 534.27 N 233.46 594.38 N 259.73 640.85 N 280.03 703.92 N 307.59 766.99 N 335.15 830.06 N 362.71 893.13 N 390.27 5200.00 898.38 N 392.56 Geographic Coordinates Latitude / Longitude 70.21.12.0704 N 149.01.32.6223 70.21.12.0704 N 149.01.32.6223 70.21.12.0704 N 149'01.32.6223 70.21.12.0704 N 149.01.32.6223 70.21.12.0704 N 149.01.32.6223 70.21.12.0704 N 149.01.32.6223 70.21.12.0704 N 70.21.12.0704 N 70.21.12.0704 N 70.21.12.0861 70.21.12.1332 70.21.12.2118 70.21.12.3216 70.21.12.4626 70.21.12.6345 149.01.32.6223 149.01.32.6223 149.01.32.6223 149.01.32.6427 149.01.32.7039 149.01.32.8059 149.01.32.9486 149.01.33.1316 149.01.33.3549 70.21.12.7821 70.21.12.8373 70.21.13.0705 149.01.33.5465 149.01.33.6182 149.01.33.9211 70.21.13.3340 70.21.13.6274 70.21.13.9503 149.01.34.2633 ~ 149.01.34.6443 ~ 149.01.35.0637 ~ 70.21.14.3025 70.21.14.6833 70.21.15.0925 149.01.35.5210 149.01.36.0156 149.01.36.5470 70.21.15.5294 70.21.15.9935 70.21.16.4843 149.01.37.1144 149.01.37.7172 149.01.38.3546 70.21.17.0012 70.21.17.5436 70.21.18.1107 149.01.39.0259 149.01.39.7303 149.01.40.4668 70.21.18.7019 N 149.01.41.2347 70.21.19.1589 N 149.01.41.8282 70.21.19.7792 N 149.01.42.6338 70.21.20.3995 70.21.21.0198 70.21.21.6401 149.01.43.4395 149.01.44.2451 149.01.45.0508 70.21.21.6918 N 149.01.45.1179 g GRID Coordinates Northing Easting (ft) (ft) 5979775.64 619980.21 5979775.64 619980.21 5979775.64 619980.21 Ctosure Dist, Dir. (ft) deg. Vertical DLS Section (ft) (dg/lOOft) 5979775.64 619980.21 5979777.23 619979.48 5979781.99 619977.31 5979789.92 619973.69 5979801.01 619968.64 5979815.24 619962.15 5979832.60 619954.23 5979847.49 619947.44 5979853.06 619944.89 5979876.61 619934.15 5979903.20 619922.02 5979932.82 619908.51 5979965.42 619893.64 5980000.97 619877.42 5980039.41 619859.89 5980080.71 619841.05 5980124.82 619820.93 5980171.67 619799.56 5980221.22 619776.96 5980273.40 619753.16 5980328.15 619728.18 5980385.40 619702.07 5980445.08 619674.85 5980491.21 619653.80 5980553.83 619625.24 5980616.45 619596.68 5980679.07 619568.12 5980741.69 619539.56 5980746.90 619537.18 5979775.64 619980.21 5979775.64 619980.21 5979775.64 619980.21 87.18 5 156.40 -87.18 0.00 5979775.64 619980.21 87.18 5 156.40 -87.18 0.00 5979775.64 619980.21 87.18 5 156.40 -87.18 0.00 87.185 156.40 -87.18 0.00 87.18g 156.40 -87.18 0.00 87.185 156.40 -87.18 85.44 5 156,40 -85.44 2.00 80.20 @ 156.40 -80.20 2.00 71.49 5 156.40 -71.49 2.00 59.30 5 156.40 -59.30 2.00 43.66 @ 156.40 -43.66 2.00 24.58 5 156.41 -24.58 2.00 8.21 5 156.43 -8.21 2.Ob 2.09 5 156.54 -2.09 2.00 23.79 5 336.38 23.79 2.00 53.03 @ 336.39 53.03 2.00 85.58 5 336.39 85.58 2.00 121.42 @ 336.39 121.42 2.00 160.49 @ 336.39 160.49 2.00 202.75 @ 336.40 202.75 ~ ~ O0 248.15 @ 336.40 248.15 ~00 296.63 @ 336.40 296.63 2.00 348.13 @ 336.40 348.13 2.00 402.59 5 336.40 402.59 2.00 459.94 5 336.40 459.94 2.00 520.12 5 336.40 520.12 2.00 583.05 5 336.40 583.05 2.00 648.65 @ 336.40 648.65 2.00 699.36 5 336.40 699.36 2.00 768.19 @ 336.40 768.19 0.00 837.02 @ 336.40 837.02 0.00 905.84 5 336.40 905.84 0.00 974.67 @ 336.40 974.67 0.00 980.41 @ 336.40 980.41 O.QQ 87.18 5 156.40 -87.18 0.00 87.18 5 156.40 -87.18 0.00 87.18 5 156.40 -87.18 0.00 Smith International, Inc. Proposal Report Page, Date: 12/1/9; Wettpath ID: S-34IWI Measured Inct Drift TVD Depth Oir. (it) (deg.) (deg.) (it) Subsea Depth (ft) 5777.88 43.49 336.40 5407.05 5339.05 5877.88 43.49 336.40 5479.59 5411.59 5977.88 43.49 336.40 5552.13 5484.13 6077.88 43.49 336.40 5624.68 5556.68 6177.88 43.49 336.40 5697.22 5629.22 6277.88 43.49 336.40 5769.77 5701.77 6377.88 43.49 336.40 5842.31 5774.31 6477.88 43.49 336.40 5914.86 5846.86 6577.8& 43.49 336.40 5987.40 5919.40 6677.88 43.49 336.40 6059.95 5991.95 6777.88 43.49 336.40 6132.49 6064.49 6877.843 43.49 336.40 6205.03 6137.03 6977.88 43.49 336.40 6277.58 6209.58 7077.88 43.49 336.40 6350.12 6282.12 7177.88 43.49 336.40 6422.67 6354.67 7277.88 43.49 336.40 6495.21 7377.88 43.49 336.40 6567.76 7477.88 43.49 336.40 6640.30 TOTAL Rectangular Offsets (ft) (ft) 1019.27 N 445.38 1082.34 N 472.94 1145.41 N 500.50 1208.48 N 528.06 1271.55 N 555.62 1334.62 N 583.18 1397.69 N 610.74 1460.76 N 638.30 1523.83 .N 665.86 1586.90 N 693.42 1649.97 N 720.97 1713.04 N 748.53 1776.11 N 776.09 1839.18 N 803.65 1902.25 N 831.21 6427.21 1965.32 N 6499.76 2028.39 N 6572.30 2091.46 N KUPARUK/PUT RIVER 7516.06 43.49 336.40 6668.00 6600.00 2115.54 7577.88 43.49 336.40 6712.85 6644.85 2154.53 [KRU/LCU 7584.98 43.49 336.40 6718.00 6650.00 2159.01 7677.88 43.49 336.40 6785.39 6717.39 2217.60 7777.88 43.49 336.40 6857.93 6789.93 2280.67 7877.88 43.49 336.40 6930.48 6862.48 2343.74 7977.88 43.49 336.40 7003.02 8077.88 43.49 336.40 7075.57 8177.88 43.49 336.40 7148.11 6935.02 2406.81 7007.57 2469.88 7080.11 2532.94 8277.88 43.49 336.40 7220.66 7152.66 2596.01 8377.88 43.49 336.40 7293.20 7225.20 2659.08 8477.88 43.49 336.40 7365.75 ' 7297.75 2722.15 8577,88 43.49 336.40 7438.29 7370.29 2785.22 1~577.88 43.49 336.40 7510,83 7442.83 2848.29 8777.88 43.49 336.40 7583.38 7515.38 2911.36 858,77 886.33 913.89 START OF DROP 91.5°/100 8838.54 43.49 336.40 7627.38 8938.54 41.99 336.40 7700,82 9038.54 40.49 336.40 ~6.01 Geographic Coordinates Latitude / Longitude 70.21.22.8807 70.21.23.5010 70.21.24.1213 70.21.24.7416 70.21.25.3619 70.21.25.9822 70.21.26.6025 70.21.27.2228 70.21.27.8431 70.21.28.4634 70.21.29.0837 70.21.29.7040 7559.38 2949.62 N 7632.82 3011.81 N 7708.01 3072.22 N 70.21.30.3243 70.21.30.9446 70.21.31.5649 70.21.32.1852 70.21.32.8055 70.21.33.4258 N 924.41 W 70.21.33.6627 N 941.45 g 70.21.34.0461 N 943.40 ~ 70.21.34.0902 N 969.01 N 996.56 N 1024.12 N 149.01.46.6621 W N 149.01.47.4678 W N 149.01.48.2734 W 70.21.34.6664 70.21.35.2867 70.21.35.9070 N 149.01.49.0791 W N 149.01.49.8848 W N 149.01.50.6905-W N 1051.68 W 70.21.36.5273 N 1079.24 W 70.21.37.1476 N 1106.80 ~ 70.21.37.7679 N 149.01.51.4962 W N 149.01.52.3019 W N 149.01.53.1076 W N 1134.36 W 70.21.38.3882 N 1161.92 W 70.21.39.0085 N 1189.48 W 70.21.39.6288 N 149.01.53.9133 N 149.01.54.7191 N 149.01.55.5248 N 1217.04 g 70.21.40.2491 N 1244.59 W 70.21.40.8694 N 1272.15 ~ 70.21.41.4897 N 149.01.56.3305 W N 149.01.57.1363 W N 149.01.57.9421 W 1288.87 1316.05 1342.44 N 149.01.58.7478 N 149.01.59.5536 N 149.02.00.3594 9138.54 38.99 336.40 7857.90 7784.90 3130.81 N 1368.04 9238.54 37.49 336.40 7931.43 7863.43 3187.53 N 1392.83 9338.54 35.99 336.40 8011.56 7943.56 3242.35 N 1416.78 N 149.02.00.6670 W N 149.02.01.1651 W N 149.02.01.2224 W N 149.02.01.9709 N 149.02.02.7767 N 149.02.03.5825 149.02.04.3884 149.02.05.1942 149.02.06.0000 149.02.06.8058 W 149.02.07.6117 W 149.02.08.4175 W N 149.02.09.2234 W N 149.02.10.0292 W N 149.02.10.8351 W 70.21.41.8660 N 149.02.11.3239 70.21.42.4776 N 149.02.12.1186 70.21.43.0718 N 149.02.12.8904 70.21.43.6480 N 149.02.13.6390 70.21.44.2058 N 149.02.14.3638 70.21.44.7450 N 149.02.15.0643 GRID Coordinates C[osure Northing Easting Dist. Dir. (ft) (ft) (ft) deg. 5980866.92 619482.44 1112.33 @ 336.40 5980929.54 619453.88 1181.16 @ 336.40 5980992.16 619425.32 1249.98 @ 336.40 5981054.78 619396.76 1318.81 @ 336.40 5981117.40 619368.20 1387.64 @ 336.40 5981180.02 619339.64 1456.47 @ 336.40 5981242.64 619311.08 1525.30 @ 33'6.40 5981305.26 619282.53 1594.13 @ 336.40 5981367.88 619253.97 1662.95 @ 336.40 5981430.49 619225.41 1731.78 @ 336.40 5981493.11 619196.85 1800.61 @ 336.40 5981555.73 619168.29 1869.44@ 336.40 5981618.35 619139.74 1938.27 @ 336.40 5981680.97 619111.18 2007.09 @ 336.40 5981743.59 619082.62 2075.92 @ 336.40 5981806.21 619054.07 2144.75 @ 336.40 5981868.83 619025.51 2213.58 @ 336.40 5981931.45 618996.95 2282.41 @ 336.40 5981955.36 61'8986.05 2308.69 @ 336.40 5981994.07 618968.40 2351.23 @ 336.40 5981998.52 618966.37 2356.12 @ 336.40 5982056.70 618939.84 5982119.32 618911.29 5982181.94 618882.73 2420.06 @ 336.40 2488.89 @ 336.40 2557.72 @ 336.40 2626.55 @ 336.40 2695.37 @ 336.40 2764.20 @ 336.40 5982244.56 618854.18 5982307.18 618825.62 5982369.80 618797.07 5982432.42 618768.51 5982495.04 618739.96 5982557.66 618711.40 2833.03 @ 336.40 2901.86 @ 336.40 2970.69 @ 336.40 5982620.28 618682.85 3039.51 5982682.91 618654.30 3108.34 5982745.53 618625.74 3177.17 336.40 336.40 336.40 5982783.51 618608.42 5982845.26 618580.27 5982905.24 618552.92 5982963.41 618526.40 5983019.73 618500.72 5983074.16 618475.90 3218.92 @ 336.40 3286.79 @ 336.40 3352.72 @ 336.40 3416.65 @ 336.40 3478.55 @ 336.40 3538.37 @ 336.40 Vertica[ DLS Section (it) (dg/lOOft) 1112.33 0.00 1181.16 0.00 1249.98 0.00 1318.81 0.00 1387.64 0.00 1456,47 0.00 1525.30 0.00 1594.13 0.00 1662.95 0.00 1731,78 ',00 1800,61 ,00 1869.44 0.00 1938.27 0.00 2007.09 0.00 2075.92 0.00 2144.75 0.00 2213.58 0.00 2282.41 0.00 2308.69 0.00 2351.23 0.00 2356.12 0.00 2420.06 0.00 2488.89 0.00 2557.72 .~.00 2626.55 ~.00 2695.37 0.00 2704.20 0.00 2833.03 0.00 2901.86 0.00 2970.69 0.00 3039.51 0.00 3108.34 0.00 3177.17 0.00 3218.92 0.00 3286.79 1.50 3352.72 1.50 3416.65 1,50 3478.55 1.50 Smith International, Inc. Proposal Repod Page Date: 12/1/9 ~e[tpath ID: S-341~ Measured lnc[ Drift TVD Subsea T 0 T A L .... Oegql'oDhic Coordinates .GRID CnnrHinnt~ f'ln~4mp v~rtir= DLS Depth D~ ......... Dept~" Recta~gutar Offsets Latit~e / Longi t~e Northing Easting Dist. Dir. Sectioa (ft) (deg.) (deg,,) (fl) (ft) (ft) (ft) (ft) (ft) (ft) deg. (ft) (dg/lOOft) 9438.5 34.~9 336.~0 80~'~.23 8025.23 3295.22 N 1439.88 g 70.21.45.2650 N 149.02.15.~99 g 5983126.66 618451.9~ 3596.08 8 336.40 3596. 8 1.50 9538.5 32.~ 336.~0 81;'6.38 8108.38 3346.12 N 1462.13 g 70.21.45.7656 N 149.02.16.3903 g 5983177.20 618428.92 3651.62 9 336.40 3651. 1.50 9638.5 ~ 31. ~ 336.~0 82~0.95 8192.95 3395.01 N 1483.49 ~ 70.21.46.24~ N 149.02.17.0150 ~ 5983225.74 61~06.~9 3704.97 ~ 336.40 3704. ~7 1.50 9~8.5 'Z · Zg.~ ~6, ~0 83z6.90 8278.90 3441.85 N 1503.96 ~ 70.21.46.7071 N 149.02,17.6136 ~ 5983272.25 618385.59 3756.09 g 336.40 3756.)9 1.50 9838.5~ 28.1~9 336.,0 8414.15 8366.15 3486.62 N 1523.52 ~ 70.21.47.1474 N 149.02.18.1856 ~ 5983316.70 618365.32 3804.95 9 336.40 3804. 1.50 ~38.5'~ 26.~ 336. ~0 85;2.65 8454.65 3529.28 N 1542.16 ~ 70.21.47.5669 N 149.02.18.~07 ~ 5983~59.05 618346.01 3851.50 9 336.40 3851.~0 1.50 10038. 25..~9 336.,0 86'2.34 8544.34 3569.79 N 1559.86 ~ 70.21.47.9655 N 149.02.19.2485 ~ 5983399.28 618327.67 3895.72 9 336.40 3895. ~2 1.50 10138.5~'~ 336.~0 87(~.16 8635.16 3608.15 N 1576.62 ~ 70.21.48.3427 N 149.02.19.~86 ~ 5983437,37 618310.31 3937.57 9 336.40 3937.~7 1.50 E~<< Is cs~ p+ 10149.3~i~'~:~ 336. ~0 87~.00 8645.00 3612.15 N 1578.37 g 70.21.48.3820 N 149.02.19.7897 ~ 5983441.34 618308.50 3941.94 ~ 336.40 3941. ~.50 TOP SHUBL K 10196.1~ ~3 336.~,0~ ~ 87~6.00 8688.00 3629.27 X 1585.85 g 70.21.48.5504 N 149.02.20.0084 ~ 5983458.33 618300.75 ~960.62 9 336.40 3960.;2 1.50 10238.5~ ~9 336.~,~ 87~5.04 8727.04 3644.31 N 1592.42 g 70.21.48.6983 N 149.02.20.2007 ~ 59834~.27 618293.94 3977.03 9 336.40 3977. 1.50 TSAD/Z4B , 10298.9 21~9 336.,~ ~51.00 8783.00 3665.07 ~ 1601.49 ~ 70.21.48.9025 N 149.02.20.4660 ~ 5983493.89 6182~.54 39~.69 8 336.40 3999.~.9 1,50 10338.5, ~9 336. ;(~ ~7.92 8819.92 3678.26 X 1607.25 g '70.21.49;0322 N 149.02.20.6345 ~ 5983506.98 6182~8.57 4014.08 9 336.40 4014.,~8 1.50 TARGET 10404.8 ~0 336., 895 ).00 8882.00 3699.52 N 1616.55 g 70.21.49.2414 N 149. 02 . 20 . 9062 ~ 5983528.09 618268.94 4037.29 9 336.40 4037. :9 1.50 00 9041.9~ 8975.97 3~0.86 N 1630.24 ~ 70.21.49.5496 N 149.02.21.3067 ~ 5983559.21 618254.76 4071.49 ~ 336.40 4071.~9 0.00 10504.8' .,~ Z2C 10505.9' ~6.~ 9041~.00 8977.00 3~1.21 N 1630.39 g 70.21.49.5530 N 149.02.21.3111 g 598~559.55 618254.60 4071.86 ~ 3~6.40 40~1. 0.00 ORGINAL "C ~ -- O< 10553.8[ 0 ~6.~, 9093.00 9022.00 3746.22 N 1636.95 g 70.21.49.7006 N 149.02.21.5029 g 5983574.46 618247.81 4088.24 a 336.40 4088.,4 0.00 10703.8( 0 6. ~ 923).95 9162.95 3793.23 N 1657.49 g 70.21.50.1629 N 149.02.22.1036 g 5983621.13 618226.53 4139.55 9 336.40 4139.'. 5 .00 i i i i i ii i i i i iii i ii ~11_ ~ i MUD PROGRAM: Well S-34 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casino Point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.5 Funnel Viscosity sec/qt ,,,300 <1 00 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH - 8.5- 10 8.5- 10 APl Fluid loss mi/30 min 1 5- 2 5 1 5 - 2 5 Hardness mg/I < 200 <200 MUD, SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top of Sag River Sandstone: LSND Gel/Water System Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid Loss mi/30 min pH Hardness mg/I MUD SPECIFICATIONS-PRODUCTION 9.5-9.8 Toto the LCU 10.2-10.5 thru Kuparuk to Casing Point 10 - 15 5-10 10 - 20 <15 through Kuparuk (6800' tvd) <6 in Jurassic Shales below 6800' tvd 8.5 - 10.0 NC-no control .R E C E I V E D Watered back mud system used in intermediate hole. Mud Weight ppg 9.0- 9.5 Yield Point Ibs/100ft2 8 - 13 10secGel Ibs/100ft2 5 - 10 10 min Gel Ibs/100ft2 7 - 15 APl Fluid loss mi/30 min pR -- Hardness m g/I t r 6.0 - 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales 8.0 - 9.0 < 4000 The mud salinity should be compatible with the Reservoir logging program. The mud should be run at less than 3500 ppm chlorides. 13-3/8" SURFACE CASING CEMENT PROGRAM - BJ Services CASING SIZE. 13-3/8", 68# CIRC, TEMP 38°F LEAD CEMENT TYPE: Cold Set III ADDITIVES: retarder WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx MIX WATER: 10.5 gps APPROX #SACKS: 1067 THICKENING TIME: 4:30 hrs TAIL CEMENT TYPE: Cold Set II ADDITIVES' as required . ,. . WEIGHT: 14.9 ppg YIELD: .96 ft3/sx MIX WATER: 3.89 gps. APPROX #SACKS: 480 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Cold Set II ADDITIVES' retarder WEIGHT: 14.9 Ppg YIELD:0.96 ft3/sx MIX WATER' 3.89 gps APPROX #SACKS: 250 SPACER: 75 bbls fresh water ahead of.lead slurry. CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two bow type centralizers spaced 10" and 20' above conductor shoe 4. Do not run cement baskets. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 480 sx 3. Top job volume 250 sx. RECEIVED DEC ? A,,l~ska ..., & ,:.~::.. Cor:s. Corm'nission S-38 Conventional December5, 1992 15:36 Page 13 9-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ Services CIRC. TEMP: 130° F SPACER: 50 bbls Arco Spacer, weighted I ppg above mud current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 2.0% A-2 + 0.5% Gel + 0.7% R-18 + 1 ghs FP-6L WEIGHT: 12.0 ppg YIELD: 2.40 ft3/sx MIX WATER: 14.2 gps APPROX #SACKS: 779 THICKENING TIME: 5 hrs TAIL CEMENT TYPE:, CLASS G ADDITIVES: .3% FL-52 + 0.5% CD-32 + o.1% A-2 + 1 GHS FP-6L for 3-4 hrs thickening time. WEIGHT: 15.8ppg YIELD: 1.15ft3/sx MIX WATER: 5.00 gps APPROX #SACKS: 300 THICKENING TIME: 4 hrs CENTRALIZER PLACEMENT: 1. 1 turbulator centralizer per joint on shoe joints (2 required) 2. 1 turbolator per joint on every third joint to 500' above shoe(4 required) 3. 1 straight blade rigid centralizer every third joint from 300' below to 300' above Kuparuk (7516' md to 7584'md + 600'= 6 required) 4.2 turbolators spaced out 100' and 200' above surface shoe (2 required) OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. CEMENT VOLUME: 1. Lead G neat slurry to 500'md above top of Ugnu with no excess. 2. Tail G slurry to 1000' md above casing point with no excess. 3. 80' md 9-5/8", 47# capacity for float joints. NOTE: The intermediate casing string should be isolated from the Ugnu/Cretaceous interval. RECEIVED AJaska OJi & dzs Co~"~s. Commission 7" PRODUCTION LINER CEMENT PROGRAM - BJ Services CIRC. TEMP 140o F o Bottom Hole Static Temperature -- 226 degrees F at 8800' SPACER: 75 bbls Arco preflush + 1% S-400. CEMENT TYPE: CLASS G ADDITIVES: 0.8% BA-10 + 0.6% FL-32 + 0·2% CD-30 + 0·3% A-2 + 0·35% R-1 + 1 ghs FP-6L WEIGHT: 15.7 ppg YIELD:1.18 ft3/sx MIX WATER: 5.03 gps APPROX #SACKS: 204 THICKENING TIME: 4.5 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe.· OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry· Fluid loss should be 40cc or less. Displace @ 8-10 bpm. LINER CEMENT VOLUME: · 1 Open hole + 150% excess + excess for surface volume lost (adjust if a caliper log is run and it indicates severe washouts)· 7", 26#. casing capacity below landing collar. 150' liner lap 200' of cement on top of the liner in the 9-5/8" casing. RECEIVED DE O - 7 ~,,?,oo Anchorage S-34 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SIPRESSURE 1 4 2900 2111 Burst S.F. 1.63 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind 'the surface casing is 9.5 ppg .: Mud Wt. (ppg) TVD (FT) Collapse press 9.5 2900 1433 Collapse S.F. 1.58 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 2905 PBYS Tension S.F. 6.33 Mud Wt. 9.5 ppg TJYS 7.70 String Wt. (#) 168857 P ECEIVED S-34 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SlTP 9.7 9.5 351 2 3420 2.06 Burst S.F. Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight-behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 9230 0.1 3973 1.36 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 704 Mud Wt. String Wt. (#) 10.2 15450 Tension S.F. PBYS TJYS 39.09 43.17 R[CEIVED S-34 Casing Design PRODUCTION LINER 7", 26#,L-80,NSCC Casing GRADE BURST L-80 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SlTP 9.7 9.5 351 2 3420 2.06 Burst S.F. Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 9230 0.1 3973 1.36 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 704 Mud Wt. String Wt. (#) 10.2 15450 Tension S.F. PBYS TJYS 39.09 43.17 RECEiVeD DEC- Alaska Oil & Gas Cons. Anchorage TO FLARE CAVE[M UNrT 1 :SHAKER ~CREEN CA¥1EM UNIT 2 CHOKE MANIFOLD TRIP TANK 170 88L FILL LINE ; TRAP c tN T'R.'UQ g PIONEER MK I TO PIT VOLUME TANK 137 D8L EQ. DL81 ~UT)ON DF1'CH 131BBL DESILTER ,Aeons DEQASSER DR/..CO BEEF.LOW TO STAND PIPE & KILL LINE : VOLUME TANK 180 BBL SUCTION 117 BBL MUD PUMPS RECEIVED Auchorag~ I TO DI3TRIBUTION WATER 87 OUL MUD HOPPERS & MIX}NG PUMPS SUCTION 134 BBL NABOR8 DRILUNQ LTD RIG No. 28E MUD SYSTEM SURFACE FACILITIES TOTAL ACTIVE SYSTEM: 800 DDL TOTAL ,SURFACE CAPACITY : 970 BBL NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP UNE RISER FLOWLINE I 10" B~ I_ VALVE · J 10" BALL VALVE J ONLY ONE VALVE OPE_~ AUTOMATICALLY WHEN THE DiVERTER CLOSES, THE ~ VALVE W1LL REMAIN CLOSED UNLESS CONDrYK3NS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE ~ USING ~ LOCATED AT THE ACCUMU~T~ THIS IS THIS IS A VAR:lANCE FROM 20AAC25.035. RESERVE PIT 10" VENT UNE 1(7' VENT LINE ALL TURt,,~ ARE TARGETED TEES. Alaska 0ii & Gas Co~s. ^.chorag~ NABORS 28E 13 5/8" 5,000 psi Stack ~ 2.42 10.93 4.50 4.82 1.5'1 3~ O7 2.13' 1.13 1.5 GROUND LEVEL HYDRIL · PIPE RAM , KR TQ RF _RI(~_ FL©OR 13.18 5.58 BLIND RAM 8.06 t MUD CROSS PiPE RAM 12.58 MUD 'CROSS 1 TBG SPOOL ...j 16.25 17.33 T RECEIVE) Alaska 0il & Gas Co~-~s. ,A, nsl~orag~ 19.75 State: Alaska Borough: Well: S-341 Field: Prudhoe Bay St. Perm ~ 92-136 Date 12/10/92 Engr: M. Minder S-341CSG.XLS Casing Interval Interval Size Bottom Description escription escripfion Tension Top Length 1A 13.375 2900 31 2872 2A 9.625 10149 30 10119 3A 7 9230 8573 734 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs ~ Thread Lbs 68 ~ BTC 0 47 L-80 NSCC 0 26 L-80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I'~G draulic radient ppg psi/ft 1B 9.5 0.494 2B 10.2 0.530 3B 10.2 0.530 4B 0.0 0.000 5B 0.0 0.000 6B 0.0 0.000 7B 0.0 0.000 8B 0.0 0.000 9B 0.0 0.000 1019 0.0 0.000 Maximum Minimum Pressure Yield psi ~ BDF 3330 1.0 3330 6870 2.1 3330 7240 2.2 0 0 #DIV/O.! 0 0 #DIVIO! 0 0 #DIV/O.I 0 0 #DIVIO! 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIV/O.I Tension Strength K/Lbs K/Lbs 1C 195.296 ~ 2C 475.593 1086 3C 19.084 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 TDF 5.47 2.28 604 31.65 0 #DIV/O! 0 #DIV/O.I 0 #DIV/O! 0 #DNKt! 0 #DIV/O! 0 #DIV/O.I 0 #DIV/0! Collapse Collapse Pr-Bot-Psi Resist. 1433 5383 4896 0 0 0 0 (:DF 4~ 1.361 ~ IO,~.f,~,~ ~u~I 0.882 5410 1.1~ 0 ~D~! 0 ~D~ 0 #DIV/O! 0 #DIV/O.I 0 #DIV/O! S-341C~T.XLS State~ Well: Field: State Permit it S-$41 PEt/Df/DE Ecl Y Engineer:. Work Sheet: Date: 12/'18/E2 Casing T~ Casing Size Casing Length Hole Diemetef Cement- Sacks Cement- Yield Cement.- Cubic ft Cement- Cubic ft Cement- Sacks Cement- Yieid Cement- Cubic ft Cement- Cubic ft Cement- Sacks -Inches -Feet. -Inche~ 111 111 111 111 112 112 112 112 113 Cement- Yield113 Cement- Cubic ft 113 Cement- Cubic ft 113 Cement- Cubic ft / Vol Cement- Fill Factor 0.000 ~7.~ 1.~1 Surface 13.375 2,872.000 16.000 1,067.000 1.920 2,048.640 2,048.640 730.000 0.960 700.8O0 0.000 0.000 0.1300 0.000 2,749.440 2.276 Lina 7.00O 734.000 8.500 204.000 1.180 240.720 240.720 0.000 0.000 0.000 O.00O 240.720 2.586 Ca¢mg T ~ Casing Size -Inches Casing Depth - Feet Hole Diamete~-Inches Cement- Sacks111 Cement- Yield111 Cement-Cubic R 111 Cement- Cubic ft 111 Cement- Sacks112 Cement- Yield112 Cement- Cubic ft 112 Cement-Cubic fl II2 Cement- Sacks113 Cement- Yield113 Cement- Cubic fi 113 Cement- Cubic tt 113 Cement- Cubic ft / Vol Cement-Interval fi Top of Cement- Feet Intermediate 111 · 0.000 0.0010 0.0O 0.00 0.0O 0.0O 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/O! itDIVlO! Inte~me6ete 112 0.000 0.00O 0.0O0 0.0O 0.00 0.0O 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIWO! itDIV/O! Production 9.625 10,149.000 12250 779.00 2.40 1,869.60 1,869.60 3OO. OO 1.15 345.00 345.00 0.00 0.00 0.00 0.00 2,214.60 7,071.29 3,077.7 Measured Depth ITEM (1) Fee (2) Loc -':* CHECK LIST FOR NEW WELL PERMITS AP~PROVE DATE (3) Admi n ~ l~t~/~. ,,, , [10 & 13] Company YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. 3. Is well located proper distance from property line ................... .. 4. Is well located proper distance from other wells ..................... ~ 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ .x~_. 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is 1 ease ntrnber appropriate .......................................... 13. Does well have a unique name & nt~nber ................................ NO REMARKS (4) Casg ,~/~,~, ~,~'/~-¢'-z-~-14. Is conductor string provided ......................................... [14 thru 22] 15. Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water ............. · ..... 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wellbore ................... 21. Is old wel lbore abandonment procedure included on 10-403 ............. /~..~, 22. Is adequate wellbore separation proposed ............................. (5) BOPE /.~-/~-~-- 23. Is a diverter system required ........................................ [23 thru 28] 24. Is drill ing fluid program schematic & list of equipment adequate ..... 25. Are necessary diagrams & descriptions of diverter g BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to ~'o~ psig ..... 27. Does choke manifold comply w/API RP-53 (May 84) ...................... 28. Is presence of H2S gas probable ...................................... (6) Other ~ / ,~_~.~_/~?~_~ 2 9. [29 thru 31'] 30. (7) Contact., 32. [32] (8) Addl -~.~.~. ~%~-?~-~,- 33. geology · eng i neer i nq ' DWd-~ MTM~' RAD~ ! z - RP~" BEW JDH~/! LAG rev 08/18/92 jo/6.011 FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions p~esented... Name and phone ntrnber of contact to supply weekly progress data ...... Add i t i onal requi rements ........................................... ~ ~/~;~, ~/ ~/~ ?/ ~. ~'~. '_] Additional r~rks: _~~j ~~~/~_ ~' N/ P~L C~SS STATUS AR~ ~ SHORE /~'~ :' ~ ~ /X~/' ~/~/~ ~r ~:r ~--:r~,~/~X~ ~m m z 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, informati;3n 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. ALASKA COaPUTING CENTER *------- SCHLUMBERGE~ ~mmmmmmmmmm~mmmm~mmmm~m~mmm~ COMPANY NANE ~ B.P. EXPLORATION WELL NAME : 8-34 ! FIELD NA~£ : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API N[!~BER : 50-029-22305-00 REFERENCE NJ! ~ 92740 RECEIVED JAN 2 5 199~ Alaska 011 & 6as Cons. Commission Anchorage Tame Verilicat!on bistinq ;chlumberger AlasKa Comouti, ng Center 9-JAM-1993 12:29 **** REEL HEADER **** SERVICE NAHUM ~ EDIT DATE ; 93101/ 9 O~!CI~ : FLIC RE~L NA~E : 92740 CONTINUATION ~ : PREVIOUS REEL : CO~N%' : B,D, EXPLORAT!OM,PRUD~OE BAY,S'34 1,50-029-22305-00 **** TAPE HEADER .**** SERVICE ~AME : EDIT ORICIN ~ FLIC TAPE NA~E : 92740 COMT!NUATIGM # : ~ PREviouS TAPE : CO~E~T : B.P, EXPLORATION,P~UDMOE BAY,S-34 PRU~HOE BAY UNIT OPE~ HOLE WIRELINE bOGS AP1 ~UMBEP: OPEPATOR: LOGGING COMPANY: TAPE CREATION DAT~: TOw F ~'~L ~.SL ~U~BER: GING ENGINEER: R~TOR WIT~ESS: E LOCATIO~ ?ION: NS~!P: GE: VhTIONfFT F~OU KELLY B~SBI~G: G~OtlhD LEVEb; CASIMG !ST STRING P~H STmI~G 1,50-029-22305-00 92740 G. SARBER CARLIbE S-34 I 500292230500 B,P. EXPLORgT!ON SChLUmBERGER ~ELL 9-J~M-93 RUN 2 35 12N 12E le45 1782 70.40 6E.90 36.0O SIZE (I~!) SIZE: (li~) oEPTH (FT) 1 ). 5.,, 0 SERVICES RUD~ 3 JAN 2 5 199 5 Alaska Oil & Gas Cons. Commission -. Anchorage ~chlumberqer A~lasr, a Computind Center 9-dAN-1993 12:29 3RD STRING P~DD[!CTIO~ 8T~!SG FIELD ENGI!~EE~'S RE~A~KS: $ $ PAGE~ **** F!LE HEADER **** S~VICE : FLOC VERSION : O0~A07 DATV : 93101/ ~a× REC SIZE : FILE TYPE : LO LA. ST FILE : FILE HEADER ~!1 tool strln~s; DEPTH I~CRE~ENT FILF SUMMARY P~U TOOL CODE $ BASELINE CURVE FOR CURVE SHIFT DATA ! DePth Shifted and 0,500O START DEPTH 10572.0 10590.0 106~0.0 clipped STOP DEPTH 10120,0 10120,0 10122,0 curves: SNIFTSI GR (~EASURED DEPTN) --- ....... EOUIVALENT UNSHTFTED ¢ASEL!HE DEPTh OCS OTB SP 0 88888.0 88~87.5 8~R86.5 ~o55a,5 10558.0 10557.5 10557.5 !0552.0 10550.5 10533,0 10533,0 10530,5 lr~530,5 105~7,0 10526.5 10523,0 1~)52~.0 10522.5 1o522.0 ~0522.0 10511.5 ~.051!.0 1050a.5 10504.0 10504.~ 10504.0 10478.5 10478.5 ~0471.5 1u47!.0 1n455.0 tOa55.n !0449,n 10449.0 all runs merged; DEPTH ........ no cased hole data, ~IS Tare Verification ListinO ;chl. umberqer Alaska Computing Center 9-JAN-!993 12:29 PAGE: 1042] 0 ]0399:0 10398,5 10373,0 ~0373,0 10364,0 10364,5 10355,0 io355,0 1033l'0 10330,5 !0330o0 10330°5 i02 .0 10284.0 10284.5 10251.5 10250.5 10251,0 10250.5 ~020~.0 10201,5 1019~,5 10198,5 1.0t77.0 1015~.$ !0157,0 ~.0155.5 10153,5 10147.0 10115.5 10001 5 $ # ME~ED DATA SOURCE PBU TOOL CODE RUN NO. $ REMARKS: THE D~PT}i ADJUST~!ENTS TO G~ LIS FO~AT DATA PASS 10422.5 i03S8.0 10373,0 1~314 0 10264.5 10147.5 10115.0 10092 0 .~ERGE .... ASE SHOWN ABOVE REFLMCT DT TO GR, (CARF~:YIMG ALL OTHER DTE CURVES), O, ~EC[)[vD ** 1 66 0 2 66 0 3 73 52 i 66 1 5 66 6 73 7 65 ~ 6b 0,5 9 65 FT lis TaPe ver~.ficati, on LiSt!hq ;chlumberoer AlasKa ComputinO Center 12:29 PAGE: P. REPR CDDE VALUE 11 6,6 13 66 0 !4 GS 15 66 68 16 66 1 0 66 0 TYPE - CNA SERVICE A ORDL, # L PI AP!.. AP1 API FILE"~ NU~.B NUMB SIZE REPR P OG TYPE CLASS ~CD NUMB S'"" . DEPT FT 599458 O0 O0 DT BCS US/F 599458 O0 O0 GR BC8 GAPI 599458 O0 O0 TENS BCS LB 599458 O0 O0 TEND BCS LB 599458 O0 00 IDPH DTE OE~ 599458 O0 I~P~q DTE OH~ 599¢5~ O0 O0 ILD DTE ON~k 599458 O0 O0 ILM DTE 0~ 599458 00 O0 SFL DT~ 59945~ O0 O0 SP DTE ~V 599458 O0 O0 MTE~ DTK DEGF 599458 O0 O0 599458 O0 O0 MRE$ DTE OHNM 0 00 0 I 1 1 4 68 0 00 0 ! 1 ! 4 68 0 00 0 I 1 1 4 68 0 00 0 ! 1 ! 4 68 0 O0 0 1 l 1 4 68 0 0 0 0 1. I i 4 68 0 00 0 I ! 1 4 68 O O0 0 1 1 1 4 68 0 O0 0 1 i 1 4 68 0 O0 0 1 1 ! 4 68 0 O0 0 1 1 1 4 68 0 O0 0 O0 ROCE$$ (HEX) ~m~m~ 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0 1 1 1 4 68 0000000000 0 I. 1 1 4 68 0000000000 ** DATA ** DEPT, 10630,000 DT,BCS TEND.BCS 811,27~ IDPH,DTE TL~,DTE -999,250 SFL,DTE ~RES,DTE 1,195 DEPT, 10600.000 OT.EC8 TFND.BCS 846.829 !DPit,DTE TLV,DT~ 2,072 SFG,OTE M~ES.DTE 1.1o5 DFP?. 10500,000 DT,BCS T~!gD,BCS 822.623 IDP:I,~T~: IL~,D'FE 3,039 SFL,~...T~ M~ES.DT~ 1,202 DEPT, 10400.000 DT,BC8 TEND,BCS $32.~3 !DPH.Dr~ IL~.DT~ 3.~37 SFI.,.DT~ ~RES.DTK 1.2!u -999,250 GP.BCS -999 250 TENS,BCS -999,250 IMPH,DTE -999,"~50 ILDoDTE -999.250 SP.DTE -999,250 MTEM,DTE -999.250 GR.BCS =999.250 TENS,BCS 1,830 IMPH.DTE 2, 01 9 IbD,DTE 4.35) SP,DTE -83,313 MTEM,DTE 83.100 Ga 'C~ , .. , .~.~ 18 614 TENS BC8 2.895 IMPH,DTE 3.136 ILD,DTE 11.148 SP.DTE -87,446 MTEMoDTE 90.200 G~.BCS 21.060 TENS.BCS 3.153 I~:FH.DTE 3.519 ILD.DTE 12.~53 SP,DTE -83,079 MTE~,DTE 5205 000 -999:2so 184,735 .000 444~,797 184.755 4270 000 2:841 183.175 4245.000 3.133 1~2.631 ~I8 TaDe Verificat~on bistin~ ;cblumberger Alaska Computinq Cer~t. er 9-JA~-!,993 1~:29 DEPT. 10300.000 bT.ECS TEND.BC$ 868.637 ![)PH.DTE IL~.DTE 2.3.373 SFL.I)TE DEPT. 10200.000 DT.BCS T~LiD.BCS 1032'316 IDPH.DTE tL~.DTE 13.406 SFh. DTE ~RES,DTE 1.2~8 ** END OF DATA ** B6.400 GR.BCS 16.0©0 I~PH.DTE 25,52~ SP.OTC 76. 063 GR. BC$ 22. 730 SP,~)TC 94.500 GR.BC$ 0.420 I}~P8.DTE 7.827 SP'DTE 25.922 13.999 -7~.750 9-1214.86 7.631 84.516 1.185 -16.3~8 TE~$.BC$ ILD,DTE MTEM.DTE TENS ~4TE~,DTE TEN$.BCS ILD.DTE MTEM,DTE 4260,000 15. 498 1,81~623 12, 180,266 ,. 4445,000 0.616 178'669 **** FILE FILE ~A~E SERVICE VERSION DATE ~AX REC SIZE F!L~ TYPE L~ST FILE TRAILER **** EDIT .001 FLJC 0O!A07 93/01/ q !024 LO FIL~ NA~E SERVICE VERSION DATE ~aX REC SIZE FTLF TYPF LLST FILE HgAD~R **** EDIT .002 FLIC 00]A07 93/01/ 9 10~4 EDITED CASED HOLE DeDt~ P~$$ DEPTH INCREMENT FJbF PBU TOOL COOE 3 0.5000 curves for opem ~ole lo<is run STOP L~EPTH into casing. ;chlumberoer Alaska Co~mputinq Center q-jAN-1993 12:29 PAGE; t0~.07,5 1009Q, 0 10094,5 ~0087,5 ~0081.0 !006~,0 100,0 B~~' .... -~ . oFLIS~M CURVE FO~ S.I.F'TS: GR,BCS CURVE SHt.~ ~. DATA (~ASURFD DEPTH) 10100.5 10096,5 ~ 0O80.0 10076,0 99,5 THE DEPTH ADJUST~E~TS SHOWN ABOVE REFLECT GRCM TO GR IN TUE OVERLAP SECTIO~ AND A bLOCK SMI~T ~PPLIED TO THE RE~AINING UPHOLE G~ AT THE RATE OF THE L~ST SHIFT IN THE OVERLAP, T~'{E CASED ~OLE DAT~ WAS T~EN CLIPPED AT FIRST READIMG, S [,IS F(3R~T DATA ** D~TA FORMAT SPECIF!CA, TI~]N RECOPD ** V ** SET T PE 64EB ** TYPE REPF' CODE VALUE 1 66 0 2 66 0 3 73 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1~ 66 4~ ~2 13 66 0 14 65 15 66 6~ 16 6~6 1 o 66 ! Tare verlficatlor~ bistinq chlumber.qer Alaska Co putinq Center 9-JAN-1993 1~:29 p~ AGE~ I D ORPE D~P~ FT 5904 GRC~ ECS GAPI 5994 T~ND ECS LF 5994 TENS SCS LB 5 M~FS ECS OH~ 5 ~TE~ ECS DEGF 5 ~"~;~"~T";;T'';~';~"~"U~'''N~;~'';"~"'""'"""'''"iZ. REPR pROCEss 5~ O0 000 O0 0 2 1 t, 4 68 0000000000 58 OC 000 O0 0 ~ 1 1 4 68 0000000000 5~ O0 000 O0 0 2 1 1 4 68 0000000000 DEPT. 10114.000 ~!RES,BC8 1.261 DEPT. i0i00,000 ~ES.BC8 !,258 DEPT lO000.nO0 DEPT, 9900,000 ~RES.~CS 1,39¢ DEPT. 9800.000 ~$.BCS 1,427 DEPT. 9700,000 ~"RE~.~CS 1.432 DEPT. ~ES.~CS 1,441 DEPT. 9500.000 ~gS.BCS 1.460 DFPT. 946g.000 NRES.8CS 1.467 GRCH,BC$ 9 2 TENU,~.~,,~,o 104.] 316 TENS BCS RCHECS 57,664 TENO,BCS 1009 625 TENS BCS ,TE~:BCS 173,452 ~ ' ' ...... CS 166: 878 GRCh,t~C,.~ 45 ~90 TEND BCS 927 191 TENS BCS ~!TEM.~SCS !64,919 ' * ' * GRCH,BCS 59.65~ TPND, ECS 922 384 TENS MTE~.~. ECS 163.510 ..... ' GRCH. E~C8 57.098 TKNO,BCS 942,300 TENS.ECS gTEi~. BC8 161,899 GRCR.BCS 60.05~ TEND.ECS 917.754 ..... ~.,r,. ECS 16! .232 4395,000 4445,000 4425,000 4460..000 4175,000 4215,000 4170,000 4105o000 4025.000 ** E~.3D OF DATA Verification Llstin~ ~Chlumheraer ~l. askaComputin~ Ce.ret F!L? ~h~E : EDIT .002 SERVICE : FLIC D~T~i : 93/01/ 9 ~aX REC SIZE : 1024: F~LF TYPE : LO D~ST FILE 9-dAN-1993 12129 PAGE: **** FILE MEADER **** FII,~ ~A~E : EDIT ,003 SERVICE : FDIC VERSlO~ : 001A07 DA~F : 93/0!/ 9 FILM TYPE : LO L~S~ FILE : FILE HEADER F!LS? N[!gBE¢ 3 Curves and 1o~ header data for ~ach ru~ and tool strl. nq tn separete files; Sadlerochlt run preseBted first (Drlmarg depth control' string USed tO de~th lntervol) followed DV file~ ~or other maln pass strings Cer run. RUN NtJ~RER: ~ TOO[~ STPING NUMBED: 1 PASS IqOM~ER: 2 DEPTH I~CREMEN?: 0.5000 F!L~ SUMMARY VENDOR TOOT, CODE START DEPTH C~. ~o572.0 RHC 10590.0 DTE 10622.0 $ LOG HE^DER DATA DATE LOGGED: SOFTWARE TIs~ CIRCULATID~ T!UE LOGGED ON WD DRI;,L~ (FT): TD LOGGFP(FT): TOP LOG INTerVAL POTTO~ LOG !t!TE~VAL (FT): I.,OGGI~q SPEED mOOD STEI~G (Trip VE~DOP TOOL CODE TOf']L TYPE S~OP DEPTH 10063,0 lOOb3,O 10063,0 31-DFC-92 5C0-423 1100 3t-DEC-92 1657 31-DEC-92 106~5.0 10629,0 10120,0 10621.0 2400.0 TOol String #! fo shift the'Sadler ~IS Tape Veriflcatio~ hlstlng ~chlumberoer Alaska ComDutinO Center 9-JAN-1993 !~:~9 B~C DTE TELE~qETRY CARTRIDGE BORE!'~OhE S(}~<!IC CAPT', BOR EH,.'3LE SONIC DOAb I?4DUCTtQN CART. DUAl, INDUCTION SONDE AM~-AA 712 ECH-KC 228t SGC-SA 5O SBC-UA 278 SLS-WA 2004 DIC-EB 377 DIS-HB 379 FOPE~OLE AND CASING DATA OPEm ~OLE BIT SIZE (IN)I DRILLERS CASING I>MPT~{ (mT): LOGGERS CASING DEPTH (FT): 8,500 10115.0 10120.0 ~OREHOLE COND!TIO~S MUD TYPE: MUD DENSITY (LB/G): ~[JD VISCOSITY (S): ~UD FLUID bOSS (C3): M~XIMU~ RECORDED TEMPERATURE (DEGF)I RESISTIVITY (OHMS) 'AT TE~PERATURE (DEGF): ~UU AT MEASURED TEMPERATURE (MT): ~UD AT BOTTOM HOLE TEMPERATURE MUD FILTRATE AT ~IJD FILTRATE AT ~UD CAKE AT MUD CAKE AT 9.00 42,00 9,40 6.10 !85'0 3.340 3,720 2.660 68.0 68,0 68,0 M EI..'TRON TOOL TRIO!: TYPE (EPITMERMAI, ~AT~IX: ~ATI~IX DENSITY: HOLE CORRECTION LIMESTONE 2.71 ~EMARKS: 1.5" ~UBEER AND TEFL1N STANDOFFS USED OM THE DIL AND BPC. A 2~.5' ROBBER MOLE FINOER WAS ALSO USED, $ LIs FORMAT DAT~ ** DATA FnR.AT SPECIFICATIO~ ~ECO~D ** Tape verificat!oD 5istlmq ~chlumberqer Alaska Computimq Center 12:29 3 73 ~.32 4 66 5 66 6 73 7 65 8 68 0 5 11 66 7 12 68 13 66 0 14 65 FT !5 66 68 i6 66 0 66 ! ** SET TYPE - CHAN ** NA~F SERV UNIT S~]RV~CE API ~PI API API FILE NUM~ NUMB SIZE REPR PROCESS ~D ORDER # [JOG TYPE CLASS .MOD NUmB SA~P ELE~ CODE (HEX) DEDT FT 599458 00 000 00 0 ] 1 1 4 68 DT BHC U$/F 599458 00 000 00 0 3 1 ! 4 68 TT1 ~HC US 599458 00 000 O0 0 ] 1 1 4 68 TT2 ~HC US 599458 O0 000 O0 0 3 ~ 1 4 68 TT3 BHC US 59945~ 00 O00 00 0 3 1 1 4 68 TT4 BHC US 599458 00 00O 00 0 3 1 I 4 68 SP BHC ~ 599458 00 00(~ 00 0 3 1 1 4 68 G~ BHC GAPI 59~458 00 000 00 0 3 I 1 4 68 T~NM EHC LB 599458 00 000 O0 0 ~ 1 l 4 68 ~TE~ 8HC DEGF 599458 00 000 00 0 3 1 1 4 68 ~R~iS ~C DH~M 599~58 00 000 00 0 3 1 1 4 68 ~TEL~ BHC L~ 59945~ 00 000 O0 0 ] I 1 4 68 CIPU DTE M~HO 59~458 00 000 00 0 ~ 1 I 4 68 IDPH DT~ OH6i~ 599456 O0 000 00 0 3 1 i 4 68 CIMP DT~ ~HO 599458 00 000 00 0 ] 1. 1. 4 68 I~PU DT~: OH~? 599458 00 000 00 0 3 l 1 4 68 CILD DTE M~HO 599458 00 000 00 0 3 I 1 4 68 ILP DTE ONioN 59~45~ O0 000 O0 0 3 I I 4 68 CIl," DTE M~HO 599458 0o 000 00 o 3 1 1 4 68 ILM UTE O~ 599458 00 000 00 0 3 1 1 4 68 IPOW DTE 59945~ 00 000 O0 0 3 I I 4 68 I~<)F DTE 599458 O0 000 00 O 3 ! 1 4 68 IlPP UTE ~HO 599458 O0 00O O0 O 3 ~ 1 4 68 IIXO PT? M~}!O 599~5~ 0() 000 O0 0 3 1 1 4 68 II~~' DT~ ~HO 599458 00 O0t) 00 0 ] 1 1 4 68 IIX~ DTE ~MHO 599458 00 ag0 O0 0 3 1 1 4 68 SFLU DTE OH~ 59~458 0~ O0O CO 0 3 ! 1 4 68 SD DTE ~V 599458 00 O00 O0 O 3 ~ 1 4 68 GR DTE GAP! 5994~9 00 000 0O 0 3 ~ 1 4 68 T~NS DT~ LB 599~5~ 00 00(> O0 0 3 ~ I 4 68 ~TEu DTF DEGF 59945~ 00 000 O0 ~ ] 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000000 OOOO0O0000 O000O00000 0000000000 0000000000 O0O0000000 0000000000 GO00000000 0000000000 ~O0OO00000 ~IS Tape verification Llst~nq ;chlumDerqer ~las~a ComDutlng Center g-JAN-1993 !2~29 PAGE: 11 ID ~RDER # LOG TYPE CLASS ~Oi.) mUgB SAMP E[,E~ CODE (HEX) ''''''''''''''''''''''''"''''''''''''''''''''''''''~ DT . ~ °~5~ ~ ....... 0 o00 00 0 3 ..... 1 '''''''''''''''''''''''''''''''6 0000000000 HTEN DTE LB 59945~ O0 000 O0 0 3 ! i 4 68 0000000000 DATA ** 7T3,BHC 573,600 TT4,.B"C 39516Q0 SP,BSC TE~IS,BHC 2260.000 CIDP.DTE 592,255 IL)PH.DTE 1,688 Ci~P,DTE CILD.DTE 6~6,140 I[.D,DTE 1,623 CIL~,DTE IDOF.DTE 0,000 I~OF,DTE 0,000 II~D,DTE IIR~.DTE 5~,558 IIX~,DTE 40,4~4 SFLU,D~E G~.DTE ~2,,106 TEN$.,DTE 2260,000 MTE~,DTE }.!TEN.DTE 271.687 DEPT. 10600,000 DT,BHC 89,200 TT1 ,BHC 'rt~ . .,., . . - . . T .... 3 8NC 572 400 TT4 BHC 394 800 SP,~HC TEf~S' BHC 4445,000 MTE¢~, 6tlC 184'735 ~-~RES, 8HC ClPP,DTE 55,4, S ]6 IDPH.OTE 1,802 CI~P, DTE C!LD,DTE 563,979 IL~,PTE 1.773 C~L~4,DTE IDOF DTE 0 000 I~OF OTE 0 o00 IIRP,DTE , .,.. . .... . - DTL 449 ~ !iX~ u~, 36,011 8~Lb,DTE G~.DTE 1!2 106 TENS.DTE 4445,000 ~TE~q, DTE ~TEN, DTE 8461829 DEPT. !0500,000 PT.BlOC 83,500 TTI,EHC TT3.BHC 565,600 TT4,BHC 387 600 SP,BHC TEt~S.BHC 4270,000 ~TEM,bHC 183[175 ~RES,EHC CIDP.DTE 345,462 IDPH,DTE 2.895 CI~P,DTE CILD,DTE 351,985 ILD,DTE 2,~4~ CIL~{,DTE IDOF,DTE 0,OOO !~OF,DTE 0,000 IIRD,DTE II~.DTE 306,804 IIX~,OTE 24.221 SFLD,DTE GP,DTE 18,614 TEN$,DTE 4270,000 MTE~,DTE HTE~.DTE 822,623 DFPT. 10400,00o DT.BHC 89.900 TT!.EHC Tm3,BHC 579,600 TT4,B~C 401,600 SP,BHC TENS,BHC 4245,000 MTE~.~C 182,631 ~RES,BHC C!DP.D~E 317,!94 IDPH,DTE 3,153 CIYP,DTE CILD.DTE 319.2!7 ILD.DTE 3.!33 CIL~,DTE IDOW DTE 0,00O I~OF',DTE 0.000 IIRD,DT~ I!R~':DTE 271.9~4 IIX~,D~E 28,524 GP.DTE ~1.060 TEN$,DTE 4245.000 MTE~,DTE NTEN.DTE 832.883 DEPT. I0300,000 PT.B~C 8b,200 TTI,SHC TT3.BHC 564.400 TT4,BHC 3S8.400 SP,ENC TENS.b~C 4260.000 gTEH,BHC 1~J.623 N~ES.[%HC CIDP.DTE 61,409 IDPN,DTg 16.2~4 CI~P,DTiiE 589 600 "80 000 ! 195 577,065 576,105 480,450 6,485 !84,7~5 589.200 '84,125 1.195 479.843 487.627 447,410 4.371 184,735 562,800 -88,188 1,202 31.8,891 329,072 283.667 1!.148 183,175 581,200 -81,125 !.210 284.153 290,990 268.964 12.B53 182.631 565.200 -72.750 1.222 68.66b TT2 BHC GR:BHC MTEN,BHC I~PH,DTE IL~,DTE IIXD,DTE SP,DTE MRES,DTE TT2.BHC GR.BHC MTEN.BHC IMPH.DTE ILg. DTE IIXD.DTE SP.DTE MRE$,DTE TT2 BHC GR:BHC HTEN,BHC I~PH,DTE ILM,DTE IIXD,DTE SP,DTE ~E$.DTE TT2,BHC GR,BHC HTEN,BHC I~PH.DTE ILM.DTE IIXD,DTE SP,DTE MRES,DTE TT2,BHC GR.BHC HTEN,BHC IPPN,DTE 41,1,200 1~2':106 2. i'687 1,733 1,716 84,532 -80.000 1.,195 410 000 846,829 2. 084 2.051 68 '84 - 1 195 388.800 18,614 822,623 3,136 3.039 37,600 -88.188 1,202 405.200 21,060 83 .883 .519 .437 43,404 -81,125 1.210 389,200 25.922 868.637 14.563 Tope Verification List!hq ;chlumberqer Alaska Computlnc Center CI 0 DTE 63 28! ID F~DTE 0.000 I ~DF. DTE IIR~ PTF: 68.575 IIX~'' DTE G~.DTE 25.9~2 TENS. DTE HT~;~;~, DTE 868,637 DEPT. 10200,000 DT. BHC TT3.BHC 508. 800 TT4. BHC TE~S.BEC 4445.000 ~TEM'BHC CIDD.DTE 70.~.7 IDPg. DTE CII. D.DTE 74.245 ILg. DTE IDQF.DTE 0.000 I~QF.DTE II~.DTE 66.936 II×~.DTE G~.DTE 79.!27 TEN$.DTE HTEN.DTE !032..3~6 DEPT. 10100,000 I' 8HC TT3.BHC 388.800 TT4.B[{C TE[.!$.BHC 4330.000 }~TE~ BHC C!DP.D'....E. 59 066 IDP~iiDTE CILD.DTE 90~893 ILD.DTE IQOF.DTE 0.000 INQE.DTE IIR~.DTE -352.576 II×!q. DTE GR.DTE 56.644 TENS.DTE MTEN.DT~ 97!.839 DEPT 10061.500 DT.BHC TT3~[hC 999.250 ~I'.~ BBC TFM$.BHC 4]25.000 MTF~.BWC C!DP.DTE 59.066 IDPH.DTE CILD.DTE 81,295 !LO.DTE IDQF.DTE 0.000 I~OF.DTE I!R~.DTE -324.795 IIXM.PTE CR.DTE 58.040 TEN$.DTE }{T~.DT~ 977.9~9 END 07 DATA ** **** FILE FILE ~A~E SERVICE VE~S!O~ DATE ~AX ~EC SIZE FIL~ TYPE LAST FILE T~AILER **** EDIT ,003 F~IC 00lA07 93/0~/ 9 9-dAN-lO93 12129 15, ....... IL~,DIE 000~ !IRD,DTE I! SrL~l,p~.E 4260,0'0 ~TES TE 7~.000 TTI.BHC 35 .200 u !80,2~6 i4.242 CIMP.DTE !.3,469 CILM,DTE 0 0~0 IIRD,DTE 9:30 SFL~ OTE 64.2(:)0 TT~.BHC 275.200 $ ,8HC 178 ~8 ~ES.~HC 073.690 SFLU.DTE 4330,000 MTEg,DTE 7! g00 TTI,BHC -999~50 SP.,BHC I~.236 MRES.BHC .930 CIMP.DTE 12.301 CIL~.DTE 0.000 IIRD.DTE 797 488 SFLU.DTE 4325[000 MTEM,DTE 72 27 6504 52:~.800 .688 1.238 62.784 70.~ 7 66' ~2 257 266 392.400 -21.:625 1,263 -313.583 -360'52~ 80,649 9700.000 !78:128 -999 250 . :ooo 1.282 -313.583 -3~0.294 72.320 9700.000 177.236 ILM .. DTE IIXD 'DTE SP.DTE MRE$.DTE TT2,BHC GR.BHC HTEN,BHC I~PH.,DTE ILM.DTE IIXD,DTE SP.,DTE NRES,DTE TT2.BHC GR:iBHC HTEN.BHC I~PH.DTE ILM DTE IIXD:DTE SP.DTE MRES.DTE .BHC HTEN.BHC IMPH,DTE ILM.DTE IIXD.DTE SPDTE NRES~DTE PAGE: 12 -72, ~50 I, 22 ~5.928 14,173 4,849 ,688 277 600 56,644 971,839 1950.000 1950,000 '~I0'301 1,625 1,263 '999.250 58,040 977'939 1950.000 1950.000 -1 000 1.2~2 .,IS Tape Verlffcation Listinq ~chlumberger Alaska Computj. nq Cent:er 9~dAM-1993 i2:29 PAGE: **** FILE ME~DER **** FILM NAME : EDIT .004 SERVICE : FLIC DATE : 93/01/ 9 ~X PFC SIZE : FILE TYPE : LAST FILE FIL~ NO~BER 4 RAW OPE~ HOLE REPEAT PASSES Curves and log header data for each DaSS, tOO1. string, and run in separate files. TOOL STRING NUMBE~: P~$$ f,iU~BER~ ! DEPT;~ IMC~MMENT: 0.5000 FILE SUmmARY VENDOR TOOL CODE START DEPT~ g~C 10590.0 DT~: 10622.0 $ D~TE LOGGED: SOFTWARE VERSIOn! TIME C!RCULATIO~ ENDED~ WI~E LOGGER vD DRILLER WD LOGGER(FT): TOP bOG INTERVAL ~OTTOM LOG INTERVAL LOGGING SPEED (FPHR): STOP DEPTH 100~3,0 10063.0 · ODI, STRING [TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE DTE $ TELEMETRY CARTRIDGE GAN~A RAY BORF~OLE SGNIC CART. 8OREMOLE SONIC SONDE DUAL I~DUCTION CART. DOAL I~DUCTION SONDE BD~EHOLE AND CASING DATA OPEN HOLE BIT SIZE 31-DEC-92 BC0-423 1~00 3!-DEC-92 1657 3~-DEC-92 10635.0 10629,0 10120 0 2400.0 TOOL ECH-KC 225~ TCC-B 281 SGC-$A 50 SLC-DA 27~ SLS-WA 2004 DIC-E5 377 DI$-~M 379 8,500 lis Ta¢e Veriftcation bl. st!n(~ ~chlumberqer Alaska Computl~O Cent. er 9-dAN-1993 12:~9 DRILLERS CASING DEPTH LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS ~UD VISCOSITY '~UD FLUID LOSS MA×I~UM RECORDED TEMPERATURE RESISTIVITY (OH~M) AT TEMPERATURE (DEGF): ~UD AT MEASURED TEMPERATURE ~UD AT 80TTOM HOLE TEMPERATURE ~UD FILTraTE AT (MT): ~UD FILTPATE AT (BHT): ~UD CA~E AT ~UD CAKE AT NEUTRON TOOL .TOOL TYPE (EPIT~ER~Ab OR THERMAL): MATRIX: ~ATRIX HOLE CORRECTION (I~): 10!1~.0 1012 .0 LSND ~2.00 9,40 6 ~0 3.340 3,720 2.660 68.0 68.0 68.0 2.7I REMARKS: 1.5" RUBBER AND TEFLIN STANDOFFS USED ON THE DIL AND BEC. A 23.5' RUBBER HOLE FINDER WAS ALSO USED, $ LIS FORMAT DATA PAGE: 14 ** DATA FORNAT SPECIFICATION RECORD ** ** SET TYPE - 64E~ ** TY E. p REPR CODE VALUE 1 66 0 2 66 0 4 66 5 66 6 73 7 65 9 65 FT 1] 66 7 I? 65 13 6~ 0 14 65 FT 15 66 68 ,tS Taoe Verification [.,istlnq ~chlun, ber~er Alaska fo~put.inq Center 9-jAN-i993 !5:29 PAGE{ !5 DT BHR US/F TTI BMR US TT2 BHR US TT3 B~R US TT4 BMR US SP BHR MV GR BHM GAPI TENS BHR LB g?Eg BMR DEGF HTEN B~R LB CIDP DTR IDPH DTR OH~ C!~? DT~ gMHO iNP~ DTR OHN~ C![,D DTR ILD DTR SHMM CIL~ DTR M~HO IL~ DTR IDOF DTR I~F DTR I!~D 9TR M~HO IIR~ DTR ggHO IiX~ DTR SFLI) DTR OH~M S~ DTR MV GR DTR GAPI TENS DT~ LB gTE~ DTR DEGF MRES DTR OH~ BTFN DTR LB RV UNIT SERVICE D ORDER # LOG 599458 O0 000 599458 O0 000 599458 00 0C0 599458 O0 000 599458 O0 599458 00 00() 599458 00 000 599458 O0 OOO 599458 O0 000 599458 O0 000 599458 O0 000 599458 00 000 599458 00 000 599458 00 000 599458 O0 000 599458 00 599458 00 000 599458 O0 00© 599458 O0 000 599458 00 000 590458 O0 000 599458 O0 000 599q58 00 CO0 599458 O0 O00 599458 ~0 000 599458 O0 000 599458 O0 599458 O0 0~0 59945~ 00 000 59945~ O0 000 599458 O0 599458 O0 000 590q58 00 000 * AP1 API API FtL~ N!)~8 NUMB SiZE REPR PROCESS TYPE CLASS MOD NUMB gASP ELKS CODE (HEX) O0 0 4 1 I 4 6B 0000000000 O0 0 4 ! ! 4 68 0000000000 O0 0 4 1 I 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 ! 1 4 68 0000000000 O0 0 4 1 ! 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 6~ 0000000000 O0 0 4 1 ! 4 68 O00000000O O0 0 4 1 I 4 68 0000000000 O0 0 4 ! 1 4 68 0000000000 O0 0 4 ! I 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 I I 4 68 0000000000 O0 0 4 ! I 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 I 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 O000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 O 4 1 1 4 6B 0000000000 O0 0 4 1 1 4 68 0000000000 00 0 4 1 1 4 68 0000000000 O0 0 4 I 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 ! 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 I 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 O0 0 4 1 I 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mm.mmmmmm DFPT T F,,~ S. BHa CTDP.DTR CILD,DTR 106d~.500 588.000 616.612 054.671 TI4.BHR IDPH.DT~ ILD.DTR 91.200 TTI.BHR 590.400 TT2.BHR 407.20o SP.BHR -20.000 GR.BHR 160 9~3 ~RES,6HR 1,235 HTEN.BHR 1~6~2 CI~P,DTR 560.593 I~PH.DTR 1.527 CI[.,S.~TR 560.078 ILg.DTR 406.400 69.~99 757.402 1.784 1.785 ,IS Tape verification Listing ;chlumbergor Alaska ComDutim~ Center DEPT, !0600,000 DT, TT3,BMR 588,000 TT4, BMR TE~, B~{R 4365,000 ~TE~, BHR T CIDP.D.R 562,583 IDPH, CILD,DTR 577. 119 ILD,DTR IDOF.DTR 0 000 I~.~OF, DTR IIR~'DTR 481:812 IIx~.~.DTR G~.DTR 69,399 TENS,OTR DMPT. 10500,000 DT,BMR TT3.BMR 566,400 TT4,BMS' TENS,BHR 4260,000 MTEM,BHR IDP DT~ 339,764 IDPH,DTR I[,D~DTR 346.368 ILD,DTR ID~F,DTR 0,000 I~OF,DTR IIRM.DTR 29B,0~2 IIXM,DTR GR,DTR ~7,!18 TENS,DTR HTEM,DTR 84!,634 DEPT. 10400,000 TT3.BM~ 580,8~0 TT4,B~R TMMS.BMR 4185,O00 ~TE~,BH~ CIDP,DT~ 316,9.00 IDPH.DTR CILD,DTR 3~9,684 tLD,DTR ID~F.DTR 0.000 I~OF.DTR II~,DT~ 272.394 II×i~,DTR G~.DTR 24.130 TEN$.DTR ~EM.DTR 83!,435 DEPT. 10300,000 DT,B~R TT3,B~R 564,000 TT4,BMR TE~S,B~ 4295,000 CID~.DTR 61.744 IDPH,DTR CILD.DTR 63.656 II.D,bTR IDOF.DTR 0,000 I~F,DTR IT~".DTR 69.300 IIX~,DT~ GP.DTR ]9,979 TENS.DTR H~E~.DTR 883.496 DrPT. 10200,00© TT3.~R 507,600 TT4,8HR TF~iS.B~ 4475.00n ~TE~,BHK C!DP.DT~ 77.03~ IDPH,D~ C!LD.DTR ~!,993 ILD,DT~ IDO~.DTR O,000 If.~OF,DTR IIR~.DT~ 73.797 CD.~T~ 81,650 TEbiS.OTR ~TS~3.DT~ 10~7.775 9-JAW-t993 ~2:~9 0 000 IIRD,DTR 36~592 SFLU,[')'TR.'" 2300"000 ~TE~,DTR 90,600 TTi,BMR 406,400 SP,BHR i80.97~ 1,77, CIMP,DTR 1.733 CIL~!,DTR o 00 84.200 TT1.BHR 390,400 SP'BHR 180.700 2 3 CI~P,DTR 0 000 !IRD.DTR ~9:s67 4260,000 ~TEM,DTR 90.600 TTI.BHR 401 200 SP.BHR !SO 836 M~ES.BHR 3.156 CI~P.DTR 3,128 CILM,DTR 0,000 IIRD.DTR 23.9B0 SFLU,DTR 4~5,000 ~TEM,DTR 86.800 TT1,BHR 389,600 SP,BHR 179.207 MRES,BMR 16.196 CIMP,DTR 15.710 CILM,DTR 0.000 IIR~,DTR 6,587 SFLU,DTR 4295,000 ~TM~,DTR 75.700 TT1,BHR 364.000 SP,BHR !77.259 12,981 CIMP,DTR 12.!96 CILN.DTR O.000 XI~O.OTR 5,154 SFLU,DTR 4475.060 ~TE~,DT~ 6 081 50 . 629 ,. !80,973 588.400 -38,063 !, 235 523 79 455,637 4,629 180.973 ~6~,600 li.:°o° 234 313.02~ 3~9243 ~7 5B6 180,700 582,000 -71.750 .237 984 659 291!438 269 307 12,824 180.836 566.00o -70 625 ~:257 69 347 57,504 27,337 179.207 518.000 11.063 1,27~ 73.275 77,828 7~.902 21.967 177,259 IIXD,DTR SP'DTR MRE$,DTR TT2,BHR GR,BHR HTENiBHR IMPH,DTR ILM,DTR IIXD'DTR SP,DTR MRES'DTR TT~,BHR GR,.BHR IMPH-DTR ILM,DTR IIXD,DTR SPoDTR MRE$.DTR TT2,BHR GRBHR HT~:BHR I~PH.DTR Ib),DTR IIXD,DTR SP,DTR MRE$.DTR TT2.BHR GR.BHR HTEN.~HR IMPH.DTR ILM.DTR IIXD.DTR SP,DTR MREM.DTR TT2,BHR GR.BHR HTEN,BHR I"PH,DTR ILM.DT~ IIXD,DTR SP,DTR MRES.DTR - 0.0 1,235 405,600 69'399 850,870 !,898 80,217 -38,063~ 1'235 388'800 17,:18 841'134 !95 · - ~000 1'234 406,.400 831, 5 4i,520 -76,750 1,237 390,000 19,979 883,496 14,420 13,687 4,337 -70,625 1,257 356.400 13,647 12,849 2.921 11,063 1.278 ,,IS Teoe VerifI. catIon blst, lnq ;cbl%lmberger Alaska ComputiDg Center 9-JAN-1993 12:~9 DEPT, 10100. ©00 PT. BHN TT3 E}-tR 447 200 TT4 BHR TF ~,! S' ...... ' ' ~ .B. HR 43!0.000 CIDP.DTR 8!,601 IDPH.DTR GILD. DT~ 84. 864 ILD. DTR IDQF.DTR 0.000 IN~)F.DTR IIR~.DTR -396.050 IIXS.[>TR GR. DTR 52. 042 TENS. DTR HTEN.DTR 972.]65 DEPT. 10027.000 TT3.BBP 450.800 TT4.~HE TEN$.BNR 42~0,000 ~TEN"BHR CIDP.DTR 94,607 IDP~.!,DTR CIhD'DTR 82,763 IL!),DTR IDOF.hTR 0 ....O0 IgOF DTR IIR~.OTR -359.766 II×~,DTR G~.OTR 74.064 TE!~$.DTP HTE~.OTR 982.923 ** EMD OF DATA ** 70. 900 TTI. BHR ~75. 600 SP, ~. 75.748 i~,~25 C!~!P,DTR II.784 Ci[,v DTR 0.000 IIRD.DTR 958.0m4 8FLU,DTR 4310.000 MTEP4.DTR BT.~O0 TTI,.BHR 276,000 SP.BHR 173.738 ~RES.BHR 10,5~0 CI~P,DTR 12.0 3 CILM.OTR 0.000 IIRD.DTR 847 254 SFLU,DTR 4230:000 MTE~.DTR 393,~00 -23,~25 1,289 -397.945 -403,.703 75.776 9700.00O 175.748 450'400 -11.938 1,316 -373.341 77.914 9700.000 ~73.738 TT2.BHR GR.BHR HTEN.BHR IgPB.DTR IL~.DTR II×D.DTR SP,DTR ~RES.DTR TT2.BHR GR.BHR HTEN.BHR IMPH.DTR ILM.DTR IIXD.DTR SP.DTR NRES.DTR 278'4oo 52,042 972'365 1950,000 [950,000 433,651 '23'125 1,289 277,200 74,064 982'983 1950.000 000 ~950. 77 ;~33'~38 1,316 **** FILE TRAILER **** FIbE ~A~E : EDIT .004 SERVICE : FDIC V~RSION : 00IA07 DATE : 93/01/ 9 ~gX REC SiZE : !024 FILE TYPE : bO LAST FILE : **** FILE NEADER **** FIBF ~A~E : EDIT .005 SERVICE : FBIC VERSION : O01A07 DATE : 93/0~/ 9 MAX REC SIZE : 1024 FILE TYPE : LO L~ST FIBE t FILE Ni)~BER 5 RA~' CASED ~ObE ~hI;~ PASS Curves add loo meader data TOOL STRING ~U~BER~ 1 PASS Nt. IgBER~ 3 for opep hole lo~s run into casln~. Tape verification LlstID~ ;chlumberger Alaska Com~urinq Center 9-Jg~-I993 1~;29 PAGE: .! 8 DEPTE INCRE~EMT: -,5©00 FILE SUg~RY VENDOR TOOh CODE START DEPT~ o1 o-o S LOG HEADE~ DATA DATE L~GGED: MOFTWA~E VERSION: T1;~E CIRCULATION ENDED: TI~E LOGGE~ ON TD ORILLKR (FT): TD DOG~ER(FT): TOP LOG INTERVAL B[)TT0~ LOG !NTCRVa[, (FT): LOGGING SPEED (FPMa) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR BHC BHC DTE DTE $ AUXIbLIA~Y ME~$, MOD, DOWNHO~E TEIj~ETDy TELEMETRY CARTRIDGE GAMMA RAY BORE~OLE SONIC CART. 80REMObE SONIC SONDE DUAL I~DUCTIOW CART, DUAL INDUCTION SONDE STOP OEPTt~ 4~ 0 mOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CA~ING DEPT~ LOGGERS CASING DEPTN ~OREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): FLUID 6OS$ (C3): ~XIMU~ RECORDED TEMPERATURE (DEGF)I REStSTIVITY {OH~M) ~T TEmPEraTURE~ {DEGF): ~UD AT ~EASURED TE~':PERATURE (MT): ~IJD AT ~OTTON HOLE TEmPERATUrE ~UD FILTRATE AT ~UD CAKE AT ~i]O CAKE AT L;EUTRO~ TOOL TOOL TYPE (PPlTNER~AL OR T~!ERMAL): MATRIX: 31-DEC-92 5C0-423 1100 1657 10635,0 10629.0 1, o120.0 10621.0 2400,0 31-DEC-92 31-DEC-92 ToOL AN~-A~ 712 ECM-KC 2281 TCC-B SGC-SA 50 SI, C-UA 278 SL$-WA 2004 DIC-E5 377 DIS-ME 379 8,500 lOI15.0 10120.0 LSND 9,00 42.00 9,40 6 0 3,340 3,720 2,660 68.O 6~.0 68.0 I,I~ESTO~E ,!8 Tape verificatlom List!,nq ~cblumberger Alaska Computinq Center 9,,d A~.~- 19c~3 I[2:29 ~ ATR!X DENSITY: HOLE CORRECTI~'' . [> ?~ 2.71 TOO.L STAMOOFP (IN): DE!~AR~,S: ].,5" RUBBER AND TEFLI~ STANDOPF$ USED ON THE DIb AND SHC, A 23,5' RUBBER HOLE FINDER WAS ~L$O USED, $ bis FORMAT DATA ** [)AMA FORe, AT SPECIpIcATli'J~ RECORD ** SET TYPE - 64g5 ** -.----.------.-.-----.--,,-,-.,, ,. TYPE RE.R CODE .L E 2 66 0 ~ 7] 24 4 66 5 66 6 73 7 65 g 6~ 0,5 9 65 FT 11 66 42 13 66 0 14 65 PT 15 66 68 16 66' 0 66 ! ** SET TYPE - CHAN ** NAiF sER IT EV UN .: S R¥ICE API API AP1 API FILE NuMB IZE OCB NUM S REPR PR ESS ID ORDER ~ bOG TYP~ CLASS ~OO NUmB $AMp FI,EM CODE (HEX) DEPT.._ FT 59945~ O0 000 O0 0 5 1 ! 4 68 0000000000 GR CSG GAPT 599458 OO 000 O0 0 5 1 1 4 68 o000000000 HTE~ CSG LB 599458 O0 OOO O0 0 5 1 1 4 68 0000000000 TF~S CSG LB 599458 O0 OOO O0 0 5 1 1 4 68 0000000000 ~PES CSG OH~ 599458 O0 000 O0 0 5 I 1 4 68 0000000000 ~TE~ CSG DEGF 599458 O0 000 O0 0 5 1 1 4 68 0000000000 * * !) A T A * * 3IS Tape Veri. ficatton bistJ,.ng ;Chlumberoer A~las~a Computlnq Center 993 ! 2: 29 2O 10 ~ 70.000 GR,CSG 1.26! MTEM,CSG 0100.000 GR.CSG 00o0.000 Gp.CSG 1,341 ~TE~.CSG 9900. 000 GR. CSG !. 3Q1 N'~TE" CSG 9800,000 (~.CSG 1.42 ~ F~.T ~ ~, CSG 9700,000 GR.CSG 1,412 ~TE~.CSG 96OO,000 GR. CSG 1.441 ~TE.~.CSG 95oo.000 GR.CSG ~ .46(> ~TEM.CSG 9468. 000 GR.CSG 1.467 ~TE~i. CSG ~ES.CSG DEPT [)EPT ~ ~ ~.:s: cs~ DEPT. ~RES.CSG DEPT. ~, ES CSG DEPT. MRES.CSG DEPT. DEPT. MRES.CSG ** END O~ DATA ** 80 076 HTE~.~,t~.S~C t73~411 67.~31. ~JE~,CSG 173. 11 58,289 ~TE~!.CSG 172,448 73,737 ~69,037 52,938 ~66,878 49.927 HTE~i.CSG 164.919 53.122 HTE~i.CSG 163,510 61.424 HTEN,CSG !61.. 2 692.120 t002.598 89!.684 972.201 921.679 932.292 922.384 932.083 922.861 TENS.CSG TENS.CSG TEN$.CSG TENS.CSG TENS.CSG TENS'CSG TE~S.CSG TENS,CSG TENS.CSG 2460,000 4400'000 4425,000 4460'000 4.I75'000 4300,000 4170.000 4105.000 4025'000 **** FILE TRAIl,ER **** FILE t~AME : EDIT ,005 SERVICE : FLIC VF~SIOM : O01A07 D~TE : 93/01/ q MAX REC SIZE : 1024 FILF TYPE : LO LAST FILE : **** T~PE TRAILER **** SERVICE NAME : EDIt DATE : g3/0~/ 9 O~IGIN : FLIC TAPE NA~E : 92740 CO~TiNIjaTYO~ ~ : 1 P~EVIGUS T~PE 1,50-029-22305-00 .~IS Tape Ver!flcat~.oD bistinc ;ChlUmberger AlasKa Com~uting Center 9-JA~-! 993 12:29 SERvICM NA~E : D~TE : 93/01/ 9 ORIGIN ~ FLIC REEL ~,~A.~g : 9274o CO~]TINUATIO~J ~ : PREVIOUS REEL : CO~ENT : B,P, ~XPLORATIO~,PRUDHO~,, BA~':,S-34 1,50-029-2~305-00 ;chlumberger pa~e ALASKA DIVISION COMPUTER CENTER 500 W~iST INTERNATIONAL AIRPORT RO.AD AMCHORA~E, ALASKA 99518 907/562~654 ' . TAPE VERiFICATiON LISTING [,IS FOR~:~AT Job NU~ber Companv Name well Na~e ~leld ~a~e County State Service Order Number Date Acquired Run Number Date Processed F~l. es Inc].~]ded 92740 q P EXPLORATION ~]ORTH SLOPE ALASKA 59945~ 3%-DEC-92 9'J&N'93 FILEs .040, & .043 THRU .048 RECEIVED JAN 2 5 199~ Alaska Oil & Gas Cons. Commission Anchorage MICROFILMED ~ChlUmberger Page 3 LIST Commamd Listing KEY ! hIST SUmMArY ~MEMONICS Summary output is create~ by LIST/$U~ ~'" sumn~aries written for [oolcal bI$'~t uctUres: FILE (Abbrev: F) h!S logical file into t TAPF (Abbrev: T) LIS logical tape info t REEL (Abbrev~ R) bis logical reel info ! and for the entire [.~IS/A input logical Un~.t: LU (Abbrev: b) LIS/A logical unit info The field labels appear on some or all of these I summaries, as indicated by the abbrev, on riq~ht, Summary Fietd l,abe].s: ~EE[.,~ ~umber o~ logical reels on (L ) I TAPES Number of logical tapes on ([,R ) l FIDES Number o~ logical files on (b~T) ~PR ~umber of physical records (L..rr t ~..,R Number of logical records (LRTF ! ~DR Number of data records ( F) t ~:NC ~umber of encrypted records ( F) ! ~F~ ~umber of data frames ( F) t PI P~imarv index channel name_. ( F) I PI_Ub~ITS Primary index units ~nemonic ( F) ! ~AXPI Maximtlm primary index value ( F) MIMPI ~inimum primary index value ( F) ! ~I~IIII~II~I~III~II~I~IIIIi~IIIIII~I~IIIIII~I~I~I DEPTH OF' P~ESSURE TEST IS RECORDED AS CHA~,{NEb FDEP. FDEP iS ALSO LISTED IN "CONS" TABLE ON TESTS WHERE' THE CSU TABLES ~,~ERE DUMPED TO T,A,P~i FO~ FOR~ATION TEST FILES OE~T" INCLUDED IN THESE LISTINGS DOES NOT ~EFE~ TO DE~TH OF ~EASURE;~ENT ~UT IS AN INTERNAL COUNTER USED WHEN .~,~EASURING IN TI~E, IN AN ATTEMPT TO KEEP THIS LISTING TO ~ REASONABLE LENGTH, ONLY SPECIFIC CHANNELS AND CONSTANTS ARE LISTED' THIS LISTING DOES NOT iNCbllDE M~NY OF TNE CHANNELS ANP CONSTANTS INCLUDED OM THE FIELD TAPE. RECEIVED JAN 2 5 1995 Alaska Oil & ~as Cons. Commission Anchorage ;chlumber~er LIST ~U<-vI[]LI$A, ...~ ........... .... ~3 .... DAT. 9.-JA{~J-93 12:14{00 Paqe 4 ~ee! header ORIGIN : DLi$ R ..... EL NA~E : DE~ALL'I' CONTINUAT!F3N ~: 1 P~EVIOU$ REEL : Co~EMT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY Tape header DEFaUGT ** TAPE NEADER ** ORIGIN : OLIS TAPF ~E : DEFAI]LT CONTINUATION #: CO~EWT : PROCESSED By SCMLU~BE[~GER. DLI$ T© LIS CONVERTER UTILITY File header RFTB ,040 ** FILE MEADER ** ~ILE NAME : RFTB ,040 .SERVICE MA~E : STATIO VERSION ~ ~ 5C0-42] DATE : 92/I2/3! ~.~ REC bEN.: 8192 Table tv~e CO...~S btsttnO of set 7 t¥~e CONS OBJNA~ ST~T TUN! PUNI DESC VALH WOEP ALLO F F F' r ation DeP h 0Oo m t 3 , End o~ set Table tyDe CONS t, istln~ of set ~ tyre CO~S mmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmm OR,JNA~ STAT Tt]~! PUNI D~S~ V~l,l) ......... ..... . ~d~Seo t chlumberqer LIST Table type bisttno of set 9 type 0. NAM T I PUNI DK$C ~nd of set Data format s~ec{flcatio~ record bistin~ of set I t¥¢e 64E8 object 0 ' '' ''''''~ Co E SI' I 0 66 2 0 66 3 ~0~ 79 4 255 66 5 0 66 6 0 7~ 4 7 IN 65 8 ~00 7~ 4 9 ,5~$ 65 4 1~ 80 66 12 -999,25 68 4 !3 ! 66 14 ,5~S 65 4 1.5 73 66 16 1 66 0 66 0 9-JA~{-93 !2:14:00 Page 5 [,l$ttnq o~ set 0 type CflA~i m~m~m~m~m~mlmm~immmmm~m~m~ml~~m~mm~m~m~m~m~mm~m~~m~m~ N~MF $~R~ UNIT SERVICE API API API API FILE NUmB NU~8 SIZE REP PROCESS T9 ORDER # LOG TYP CbS ~OD NU~O ELE~ SAMP COD (HEX) ETI~ ~FT[~ S 63 621 0 36 1 1 4 68 0000000000 SGP ~FT~ PSI 8~ 400 0 36 ! ! 4 68 0000000000 pOUF ~FTB 81 400 0 36 1 ! 4 68 0000000000 DTEN ~FTB ~1 400 0 36 1 1 4 6~ 0000000000 PHU~ UFTP 91 400 0 36 J. 1 4 68 0000000000 PT~{O ~FTF $! 400 0 36 ~ ! 4 68 0000000000 End of set Data record tvoe 0 TI.E 1743~92~ ,5u6 ETIM 0, SGP 86,3838~ PONE 6, PTEN ~. P}-iU~} O. PTHO O, ichlU~er~er b!ST ~t.~0:[]5!SA DIT. 9-j~-~-93 !2:14:00 PaGe 6 Data record type 0 ...... ~G~ 135,4048 PONE 5, PTEN PHUN !, PT~iO 0 Data record type 0 TI~E 17639328 ~T!~ !('30,2 g~ -4,394897 P&~E -4. PTEN 0, PHIIN 0 PT}{O~ m~mmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmm Data record type 0 TI)4E 17739528 ,SMs ETI~ ' 0, 1! PO~E 8 PTE~ 3. PHUN' 1, PTHO O. Data record type 0 TI~E 17839728 .5~$ 20405'8Gp 2 t584 PO~E 5 £TI~ 0. . . .. PTEN O. PgU~ 2, PTMO O, Data record tvDe 0 T!~E 17939928 .- . ,. ~ 50 5 S~P .25. ~ PO~E 8, . PHUN 3. DTHO O, Data record type 0 T:I~E 18040128 .5~$ ETI~ 300.6 SGP 463.4056 PONE 3, PTEN 6. PHUN 4, PTIiO O, Data recora tvPe 0 Tlgf 18140328 .5~$ ~T!~ 350.7 SGP 598.655 PONE 8. PTEN 9, PH[IN 5, PT~O O. ~c'hlumberoer LIST ~ti~O:[].[,ISA,t.)AT; 9-jAN-93 12:14:00 Paqe 7 Data record type 0 TI~:E 1824052~ ,5~~ ....... . ~ ~P . . PTEN 3. E'T!M ,400 S SG~. 73~ 0032 PHUM 7, PTgO 0, Data record tv~e 0 TI~E i8140728 ,SMS ~TI~ 450,9 SGP 868,8767 P0N~ 8, PTEN 6, Data recor~ type 0 TI~E 18440928 ,5~$ ETT~{ 501. P PHUN 0, PTHO Data record tvme 0 T!t~g 18541128 ,5~S ETIM 551.,~ SGP )!~49,961 PONE 0, PTEN 5. PHU!~ i, PTHO 1. Data record tYoe 0 rl~E 18641328 ,SMS mmmmmmmJ~immm'mammmm~/~{mm{mmmmmmmmm{~mmmmmm~m~mmmmmmmmm~mmmmmm{~m{m~mm~"T 6 PONE g T~4 .2 SGP 12B8,063 nata record type 0 ~'?IM~ 18741528 ,5~S ~m~~m~m~mm~m~m~~~m~mm~~m~m~mmm~m~ ETIM 651o2999 SGP !424,663 P~NE 4, PTEN PHUN 4, PTHO 1, Data record tvme 0 TI~E 18841728 ,5MS ~m~m~m~m~mm~mm~m~mmm~m~~~m~mm~m~mm~m~~m~m~~mm~ ~TI~ 701,4 SGP 1559,2q9 PONE 9, PTEN 5. PHI)N 5, PT!tO 1. ;chlumherQer LIST ~!.3~½(iI[]b~S~.F3AT~ 9-JAN-93 12:!4;00 Page Data recor<t type 0 TI~!E 18941928 .... ri 6.92,6 3 ~H!J~ 6, PTH{3 1. Data record type 0 TI~E 19042128 ,5~S ETIM ~ol.6 SGP 1824,36 P~E 4, PTEN ~, Oata record type 0 Ti~E ~91423~8 .5~S ETT~ 851,7 SGP 19~7,919 PD~3 7, PTEN PHUN 9, ~THO Data record tYDe 0 TIt.~E 19242528 ,5~S ET!~ 9o)..7Q99 SGP 3.493019 PONE 3. PTEN 0° mmmmmmmm, mmmm~mmmmmmmmmmmmmsmmmmm~mmmm~mm~mmm~m~m~mm~mm~mm~mm~m~ Data record tvpe 0 TI~E 19342728. ,5~S .... .... '"'"'"'"'"'""'""" TI~ 951 9 SGP . 3I, 7 PONE !, PTEM 3. P.~IUt'~ 9, PTHO !, Data record type 0 TI~E 19442928 ,5~S ETTM 10()~, SGP ~q60,787 PO~E O. PTEN 6° PHUN 9, PTHD ~mm~mm~~m~m~m~m~mmmmm~m~m~mm~m~m~m~mm~~m~m~m~ ~ata record type 0 ~'r~[~; .... ' .... sGP''~'''.'~;~'''';;~''~~5, ~ ~ ..... '''''''PTEN ..... 5.'''''''''' PH. UN O. PTHO 2, ~mm~m~mm~m~mm~m~mmmm~mm~m~mmm~mmmm~mm~m~m~m~mmm~m~mm~mm~mmmmm~m~mmmm~m~ ~ch!u.;mberqer hiST :~i.3aO: []LISA.D;~T; 9-JAi~)-93 12:14:00 Paqe 9 Data record type 0 TI~4E 19643328 .5M$ Data record tvoe 0 TIME 19743528 ~T~ 115!.~ SGP 2219.855 POI~ 9, ¢TEN !, . Data record type 0 TI~E 19843728 .....,.,...............,..,............, ......... ................... ETI~:~ 2.~,4 ~C.p 2 93 PONE Data record t~pe 0 TI~E 19943928 ,5g$ ETI~ 1252.5 SGP 2)62,447 PONE 2. PTEN 6. PH!IN 3, PT}-{il 2o Data record type () TI~E 2004412R .5~S mmmm~mmmmmmmmmmmm~;~mmmmmmmmmmmmmmmmmmm~m~m~mmm~mmmmmmmm~mmmmmm~m~m ~T?~ !~02,6 $. 24~5,298 P0N~ 5, PTEN ~, PH!IN 4, PTH(I 2, Data record type 0 TIM~: 20144328 ~TIM 135~.7 ~GP 24gl.063 P[]NE 1. PT~N 9. ~m~m~mm~~m~m~~m~mm~m~~mm~mmmmm~mm~m~m~~mm~ Data record t¥oe 0 WINK 20244528 .5MS ~m~mm~~m~m~mm~mmm~m~m~mm~m~m~m~m~m~m~~m~mm~ ETTI4 1402.8 SGP 2559.R86 PONE 9. PTEN 5. PI!UN 5· PTqO 2, ~m~mm~m~~~m~m~mm~~mmm~m~~mm~mm~m~~m~mm~mm~ ~chl~mberger L~ ~ ....... .. 9-JA~t-93 I2:14:00 Page I0 Data record tvDe 0 TI~iE 20344728 .5~$ ~;~'rX~"~'''j 2 ~., .... SG?' .....263t,738''''''''''''''''''. PHIl!q 6o PT~() 2, Data record tyme 0 TIME 2044492~ E'TI;4 I503. SGP 2705.773~...."]~'~',~ 5, PTE~ 0. P~,~UN 7. PT~.!~ ~. Data record tvDe o ,rl~E 20645328 ETI~q !6o3.2 s(ip 2854.755 PONE Data record type 0 TI~E 2074552~ .5~S -----------------,,,--,-,---,,.---,,,.--------------.-..-------...-. ETTM !653,3 . 9 9,7 .... E 9, 'PTE~:I 2. Data recor4 tvve 0 TI~E 20B4572~ .5~$ ETIH 1703.4 SGP 3002.24 ~ONE ~. PTEN 0. P}iU~ O, PT}~f~ 3, chlu~b~.rger. LIeot ~ tl [.:..... ¢.) : [] LIS A. , :DaT~ 9-g A..M-93 ..... !2: i4: 06. Page ET!~ 1803.6 SGP 31.46,270 PONE 6, PTEN 4, P~.tt.!N 1., PTHO 3, Data record t~pe 0 , ETI~i 1~53.7 PHI.IN 2. mmmmmmmmmmmmmmmmmmmm~mmmmmmmmmm~m~mm~mmm~mmmmmmmm~mm~mmmmmmm~mmmm~, Data record type 0 TI~; 21246528 ETT~ lq03.~ SGP 32g1,163 PONE i, P:TEN 9. P H U ~' ... ..... ~ 2. PTHO 3, Data record type 0 TINE 2134672~ ,SMS ETI~ 1953.~ SGP 3361,823 PONE 1, PTEN 6, PH!IN 3. PTt..t~:'! 3. Data record type 0 TIME 21446928 ------------------,,--,-,,,--,-------.-,---.----...--..--.---....-.. ~TIM ~()0~, S 4 ~7 P[~E , PTE~ 3, Data record tvme (3 ~'INE~ 21547128 ,SwS ETI~ 2054.,1 SGP 3505,01~ PONK 5, PTEN O. Data record type 9 7'I~k: 2174752S .5~?,$ 5~, ] SGP' 3657 751 P~ ETI~ 2!~ ' . N~: 7. PTE~ 5. PHI.IN 6, PT~{O 3. Data record type 0 TI~E 21847728 .SMS ~['';''i~'2 G4 ..... SG~'''''''''''''''''''''''''''''''''''''''''''''''''''373~ 247. PO~.~. ~, pT~N . Date r~cord type 0 ~I~E 21947928 .5~S ~. ~ mmmmmmmmmmmmmmmm~mmmmm~ SGP 3820.702 P~NE 0 PTE~ PI.'~UN ~. PTHO 3. Data record type 0 TI~,E 2204812~ ,5~S 0 6 s 390 IjNE . PTEM O. PHUN 9. PT~IO 3. Data record type 0 T!~E 2214832g ET~ .G 3990.9 4 PONE .1. PTE~ 9. Data record type 0 TIME 22248528 ,5~S ET!~ 24()~.~ SGP 4077.322 PONE 7. PTEN 7. DH!.JH 0. PTHO 4, ;ch]..umberqer LIST Data record tvDe 0 I"Ii~4E 22448928 .5N$ ETI~ 2505. SGP 1!,15929 PONE l. PTEN 1. Data record type 0 'TIM~: 22649328 41 0 6 P't'~N 4. Data recorS true 0 TIME 22749528 ,5~$ . ETI~ 2655,3 SGP 4147,021 PlaNE 7, PTEN PHIJN I, PTHO 4, Data record true 0 TIME 2284972~ ,5~S ET 27 ., PTEN 4, PHUN I. PTHO 4. Data record type 0 TI~E 2294992~ .EMS ~TIM 2755,5 KGP 4146.451 PONE 6, PTEN 4. PHUN !, PTHO Data record tvDe 0 TI~E 23050128 ,5.8 ETIM 2805.6 8GP 4145,9~3 PONE 5. PTE~! 4. PHUN l, PTHO 4, ;chlumberaer hiST ~U~!.O:[]LIBA,DAT; 9-JAbJ-93 12:~l. 4:00 Page 2,4 Data record type 0 TIME 23150328 ~TT:~ 2855,7 $~P 4145,458 PONE 5, PTEN Oata record type 0 TINE 23250528 ,5~iS ETI~ 2905.~ SGP 4!44,97 P£t~E 5. PTEN 4. P~[)~ 1. PTHO 4, Data record type o Ti~E 2335072~ ETI~ 2g§5.9 SGP 4144,5~ PD~E PHUM I, PTNO 4, Data record type 0 TI~E 23450928 ,5~S ETIM 3006, S~P 4144,152 PONE 4, PTEN 4. P~UN 1. PT}~O 4. Data record type 0 TI~E 23551128 .5~S --....,,--......--....,...........-....-..--........................ ETI~ 3., 6,~ SGP .~43,773. PONE 3, PTEN 4, Data record type 0 TI)!E 23651328 ,5~i$ ~mm~m~~m~~m~mmm~m~~mmmm~m~m~m~mm~m~mmmm~~ ET!~ 3!06,~ SGP 4143.406 PON~ 3. PTEN 4. PHLIN 1. PT~{O 4. mmmmmmmmmmmmemmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmemmmmmmmmm Data record type 0 T!~7 23751528 .5M$ ~TIM 3156,3 SGP 4143,051 PONE 3. PTEN 4. PHI!N 1. PT)'!O 4, ;cblu.~er~er LIST ~!,~O:[]LI$~.DAT: 9-0AN-93 12:!4:00 Page !5 ETI~ 3206,.4 SGP 4!42.~9 P~NE 2. PT~N 4o PHUN ~, PTHO 4, File trailer RFT~ .040 ** FILE T~AILER ** FILE NA~E : ~FTB ,040 SERV!C~ MA~g : ST~TIO VERSION # : 5C0-423 u~,X. REC, bEN,: 8~92 ~ILM TYPE ~ Db ~M×T FILE ; [EOF) Tape trailer DEFAULT ** TAP~ TRA!LE~ ** SERVICE NA~E : F~FTB DAT'F : 92/12/3~ O~I~!N : DLIS TAP~ NA~E : DEF~U[.T CO~TI~UAT!O~ #: 1 hEXw TAPE : CO~ENT : PROCESSED BY SCMLU~OERGER DLIS TO LIS CONVERTER UTILITY ~eel trailer 12:14:00 Paqe D~TE : 921~2/3!. REE'b ~A~E : DEFAULT CONTIMUATI[OM ~: i CO~r~T : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY FILES T~PES #LR J. ! i63 173 ~eel header DEFAULT ** RFEL ~EADER ** SERVICE N~ME : RFTB DATF : 93/0!/01 ORIGIM : DLIS REEL NA~E : DEFAULT CONTINUATION ~: I P~EVIOUS REEL : CO~E~T : P~OCMSSED BY' SCMLU~BERGE~ DLIS TO LIS CONVERTER UTILITY Tape header DEFAULT ** TAPE HEADER DATE : 93/0l/0! O~ICIN : T~P~ W~qE : DEFA[JbT pREVIOUS TAPE : CO~ENT : PROCESSED BY SCHLUMBERGER PhIS TO LIS CONVERTER UTILITY (EOF) ~lle Leader ~FT8 .043 ** FILE HEADE~ ** FILE ~)A~E : RFTB ,043 SERVICE NA~E : STATIO V~RSIO~ . : 5CO-423 DAT~7 : 93/O1/01 "AX. REC. LEN.: ~192 ~IbE TYPE : DL PREVIOUS FILF : !6 blstln~ of set 7 type . ,, FDZP abLO F F Formation Depth Teble type CONS 5istlno of set 8 type CONS OBJ[~AM STAT TUNI PUNI DESC YAbLJ set 9 ty~e CONS DESC VALU Data format $~ecificatiom record bistlno o~ set 3 type 64~:B object 0 ~T~Y VAI,tJ~ ~EPCO[)F SIZE 1 0 66 1 2 0 66 3 102 79 2 4 255 66 5 0 66 $ 0 73- 4 7 !N 65 2 8 600 73 9 .5~S 65 4 11 80 66 12 -9~9.25 68 4 1~ ! 66 1 I4 .SMS 65 4 15 7~ 66 16 ~ 66 0 66 0 mmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmm End of set t7 ~chlumber(!er bi.ST ~TUB0:[]b!SA,DAT~ 9-J~J-9B !2:!4:00 Page Listina of set 0 type CHA~ ~l~i~ ERV L!N ~ C~ API ~PI ^PI aPI F~[,,~ ~U~i .... ~ $I REP TD ORDER # LOG TY~ CbS ~OD ~I.J~O ELEM S~M? COD (HEX) ......~;~'['~'"'~'"""'""';;"'~r';~ ~ ~ ..... ";;'"'""';""~"'""";;'"'""~. 6~ oooooooo $~P ~MTB PSI 8! 400 0 39 ! ~ 4 6~ 0000000000 PO~E ~FTB 8I 400 0 39 I. I 4 68 0000000000 PTE~ ~FTB 8! 400 0 39 ~ ! 4 68 0000000000 PMI]~ ~VT~ 81 400 0 39 I ! 4 68 0000000000 PT}~O ~FTB ~I 400 O 39 1 ~ 4 68 0000000000 ------------,,--,--,,-------------------------~, o ~ .... ............................ Data record true O TI~E 25254934 ,5M$ ETI~ O, SG~ 4194,524 PO¥~E 4. PHU~ t, PT~O 4, Data record type 0 TIME 25355134 ,5~S ETI~ 5o,1 4 ~E 8, PTEN 9. P}.!lJ{~ 1, PTHO Data record type 0 TI~E 25455334 .5~$ ETI~ !00.2 SGP 4201,.409 PONE 1, PTEN O. P)~UN 2, PT~O 4. Data record type 0 TI~E 25555534 ,5MS ~, 0 , NE PTEI'~ O. PHUN 2. PTHO 4. Data record type 0 T[,~i 25655734 ,5~$ ETI~ 200.4 SGP 4230,622 PONE O. PTEN PH!.!~ 2, PT~ICi 4. ~.chlu~berger LIS? ~I)S0:[]I~.!SA.t)AT; 9-J~..~-g3 !2:14:00 Page Data record type 0 TISE 25755934 .5~S ZT~M 250,~ SGP 42~3,706 PONE P}{UN 2. DTHO 4o Data record type o TI~ 25856~34 ,5M$ ~TI~ 300.6 SGD 4228,47 PO~H~ 8, PTE~,~ 2 PH~N 2, PT~O 4. Data record type 0 TI~E 25956334 .5~S ~'''''~':~'''''''''''''''''''''''''''''''''''''''''''~''~'''''''''''' ~ .... P 4212.9~ PDNE 2. PT ~ ." PHUN 2. PT~,{O 4. . Data record type 0 TI~E 26056534 · R' 8 $~P 4218.314 PO~ 8, PTEN t q'I~ 400, . PHUN 2. PTHO 4. Data record type 0 TI~E 26156734 .5~$ ....---.--..-......-...-..,.,,....,-...,..-.-....--.-..-............ ETI~ 45o.~ SGP 4222 8 ' O~E . PTEN 2. ~HU~ 2, PT{tO 4. Data record type 0 TIME 26256934 .5~S ~T~ 501. SGP 4234.419 PONE 4, PTEN 3. PHUN 2o PT~O 4, Data record tvme o TI~E 26357134 .5~S ;chlUmberqer LIST ~!.JBOI[]I.~ISA.DAT; 9-JA;N-93 !2:14:00 Paqe 20 Data record type o TI~E 264.57334 T~M 601,2 $ P~II.IN 5, PT~f3 3. Data record type 0 TIME 265575~4 ETIM 651,2q99 SGP 3524,044 PONE 4, PTEN 2. PHI!~ 5, PT~O 3. Data record t?me 0 TIME 26657734 .5~S ETI~ 701,4 SG~ 3 ~7. 0 PTEN 2. P~UN 5. PTMO 3. ~~~ ~m~m~m~~m~m~m~m~mm~m~m~m~m~~m~m~m~mmm~~m~m Data record tvve 0 TI~E 26757934 ,5~8 ETIM 751,5 SG~ 35~9,56 PONE 9. PTEN 2. 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PTEN 0 ET!~ 110~,~ SGP 42 4. ...... · II~ , PTHO 4e Data record type o TI~E 27559534 ,5~ ETIM 1!52,3 SGP 4208,573 PONE 8, P EN 0, PNt,I.N 2, PT!~tr.l 4, Data record type 0 T!~Fi 27659734 . . 'G 491 PONE 6. PTE~' 0. ETIM 1.202 4 s~P 4206. ~lle trailer ~chlumberoer LIST ~UB0..'. []L/SA.PAT; 9-JAi~-93 12:14:00 Paoe 22 ** FILM TRAILE~ ** ~ILE ~AME : RFTB ,043 SERVICE ~iAME : ST~TIO VERSION # : 5C0-423 DATE : 93/0~/01 ~AX, REC, LED,: FILE TYPE : DL ~EXT FILE ~iLE SUMMARY #hR ~P~ #ENC ~DR ~FM PI PI.UNITS MA~PI MINP! 75 85 0 51 4068 TIME ,5MS ~5254934 276951~4 [EOF) Ta~e trailer DEFAULT ** TAP~ TRAILER ** SERVICE NAME : FRFTB DATE : 93/01/0! O~l~I~ : DLI$ TLp~ NA~E : DEFAULT CONTI~I~ATION ~: 1 N~XT TAPE : CO~EMT : PROCESSED SY $CMLUMBE~GE~ DLIS TO L~S CONVERTER UTILITY ~eel trailer DEFAULT ** ~FKL TRAILER ** SERVICE NA~E : DATE : 93/01/01 REEL NA~E : DEFAULT CONTI~UAT!ON #: 1 NEXT PEEL CO~"E~T : PROCESSED MY SCMLO~ERGER DLIS TO bis CONVERTER DTIbITY SchlumberGer LIST ~UBO,'[]L!$A.DAT/ 9-J~:I~3-93 !.2:14100 Page {eel bea~er DEFAULT ** RE~EL HEADER DATE : 93/01/0!. ORIGIN : DLIS CO~TINIJAT!OM ~: P~EVIOUS ~EEL : C[]~ENT ~ PROCESSED BY SC~bU~BERGE~ DLIS TO bis CONVERTER UTILITY Ta~e header DEFAULT SERVICE NA~E : FRFTB DATE : 93/01/01 ORIGIN : DLIS T~PE ~AME : DEFAULT CONwINO~TION ~: PREVIOUS TAPE COMMENT : PROCESSED 8Y SCHLUMBERGER DLiS TO LIS CONVERTER UTILITY [EOF) Wile header RFT8 ,044 ** FILE HEAOER ** FILE NAME ~ RFTB ,044 SERVICE NA~E : ST~TIO VERSION # : 5C0-423 DATE ,: 9]/01/0! ~AX. REC, LEN,~ ~192 ~ILM TYPE : DL P~EvIou$ FILE : Table tyDe CONS bistinq of set 7 type ORJNAM STAT TUNI DUNI DESC VALU FDEP AbLO F F Formation DePth0271 4, End of set Table type CONS blst~no o~ set $ type CO~S mmmmmmmmemmmmmmmmmmmmmmmmmmmmmmmm OBJNA~ S'raT TONI PUNI D~SC VALU 5chlumberqer LIST ~.~,BO:[]LISA. [Cable type Listlno o[ set 9 type CO~S OBjNA~ ST~T TUNI PtJ{~I D~SC VABU ~nd of set Data format spec~ficatlon record Listl. no of set 5 ty~e 64~B object 0 EgTRY V~L[.]E PEPCOD~ SIZ~ 1 0 66 2 0 66 ! 3 10~ 79 4 255 66 5 O 66 6 0 73 4 7 IN 65 8 600 73 4 9 .5~S 65 4 1~ 80 66 1 ~2 -999,~5 68 4 13 I 66 1 14 .5~S 65 4 1,5 73 66 1 16 t 66 0 66 0 mm{~;mmm~w~mmmmmmmmmm#mmmmm~mmmm End f ~et 9-dA~-93 12:14:00 Page 24 L!stlno of set 0 tyue ........... ............ .... ..... ..-.,...-.,.,...,,...................... ~,~.~ ~ SE~V.. UUIT~, SERVICE APl .PI. APl AP1 ILE N ~ N ~B SIZE REP PROCESS mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm mmm .mmmmmmmmmmmmmmmmmmmmmmm ETI~ ~FT~ S 63 6~1 0 40 1 1 4 68 0000000000 SGP PFTB PSI 81 400 0 40 ! ! 4 6~ 0000000000 PO~E ~FTB 81 400 O 40 I I 4 68 0000000000 PTEN ~FT~ 81 400 0 40 ! 1 4 68 0000000000 PgU~ PFT~ 8! 400 0 40 ~ 1 4 68 0000000000 PT~O ~FTS 81 400 0 40 ! 1 4 6~ 0000000000 End of set Data record type 0 TI~E 28035174 ,5~S ~mm~m~m~mmm~mm~mmm~mmm~mm~mm~m~mmmm~~mm~mm~m~m~m~mm~m~m~ ET~4 0, S~P 424!,096 PD~}E 1, PTEN 4, PH[)~ 2. PTHO 4, ~chlumber~er 5Is!r ~US0:[]bISa,DAT; 9-JAN-93 12:14:00 Paqe 25 Data record type 0 TI~'E 28135374 ,5MS E.TIM 50,1 GP 423~,O7. PDN~ B,4 PTE~.~ 3, PHUN 2, PT~O 4, Data record t~De 0 ~T~ 100,~ SGP 4235,544 PO~E 5, PTE~ 3. PHUN 2, PT!~O 4, Data record type 0 TI~E 2~335774 .SMS ETI~ 150,3 SGP 4233,91 PON~ 3, PTEN ]. PHUN 2, PTHO 4, Data record type 0 TINE 28435974 ,5MS ego 653 POME 2 PTEN 3. ET~ 200,4 ~.~ 4232. , PHUN 2, PTHO 4, Data record type 0 TIME 28536174 ETI~ 250,5 SGP 42]2,!04 PONE 2, PTEN DHUN 2. PTHO 4, ~m~mm~m~~m~~m~~m~~m~~m~m~mm~m~mm~m~mm~ Data record type o TIgE 28636374 ,5M$ ~mm~~~~~mm~m~~~m~mmm~m~mm~mm~mmm~m~m~m~ ETIM 300,6 $~P 3135,483 PON~ 5, PTEN 3. PH!IN ~, PTHO 3, Data record type 0 TIME 28736574 ,5~S ~TI~4 350,7 SGP 3203,95 PON~ 4, PTEN 0, PH[.!~ 2, DTHO 3· ~chlumber~er LIST ~[]~<):[]l..,ISA.[~.a!I 9 jA~-93 !2:14:00 Page 26 Data record tvoe 0 Ti~ 288]6774 E~IM SGP 3293.8~3 PE . ........... ~g PTEM 0 PHUM 2. PT!iO 3. Data record t~me 0 TiME 28936974 ETI~ ~50.9 $~P 3204.018 PON~ 4. PTEM 0. PM!Ia' 2, PTHO 3, .Data record tvDe 0 TIME 29037174 ,5~S ETI~ 501. SGP 320,3,973 PONE 4. PTEN 0. PHUM 2. PTHO 3, Data record type 0 TI~E 29137374 ,5~S ETIM 551.1 $~? 4230,!~9 PONE 0, PTE~ 3. P~UN 2, PT~{O 4, File trailer RFT8 .044 ** FILE TRAILER ** FIt, M NA~M : ~FTB ,044 SERVICE MA~E : STATIO VE~S!OM # : 5C0-423 ~ATE : 93/01/01 ~AX. REC, ~I[.,E TYPE : DL MC×T FILE : m~m~m~~m~~m~m~m~mmm~mm~mmm~m~~~mm~mm~mm~m~m~m~ ~EMC #DR #P"M PI PI.lIMITS MAXPI ~IN~I m~mm~m~m~mmmmm~m~mmm~mmm~m~mm~m~~~m~~mmm.m~~m~m~m [EOF) T~De trailer DEF4])bT ;chlumberoer LIST ~UBQ:[]51$A.DAT; 9-JA~1-'93 !2:14:00 Page 27 ,, T~P~i TRA!LEP ** SERVICE ~J ~ ~ O~IGII~ : [)LIS CmNTI:~UAT!ON ~EXT 'rAPE : ,, CO~:~E~T : PRO(.,.ESo ..... ) 8Y SCHLUMBERGER DLIS TO LIS CONVERT.~R UTILITY TAPE SU~ MARY '''''''''''''''''''''''''''# I,, R ~eel trailer DEFA~ILT ** ~]EL TRAILER ** SERVICE NA~4E : RFTB DATE : 93/01/01 ORIGIN : OLIS RMEb MA~E : DEFAULT CONTIWUATION ~: ! MEXT PEEL : , ., ~ ..... . Cr.)M~EUT : PROC~SSEL BY SCHLUMBERGE~ Obis TO bis CONVERTER UTILITY ~eel header ** Rw~EL HEADER ** S~TRVIC? ~A~E : RFTB DATE : 93/01/01 REEL ~.'A~4E : DEFAOLr COMTIMUATION ~1 1 Co~R~,,T : PR(]C~7.~SED BY SCHLtI~<BERGER DLIS TO LIS CO~qVERTER UTILITY Tape h~.ader IJ{~]FAt]I.,T -~chlumberaer LIST ~US0:[]LISA.DAT; 9-JAN-93 12:1.4:00 Page 28 SERVICM F!~ P~E : D~TM : 93/0~/0~ ORIGIN : DLIS CO~TI~,~UaTIOM ~: PREVIOUS TAPE CO~'~E~T : P~OCESSED ~Y SC~bUMBERGER DLiS TO LIS CONVERTER UTILITY header RFTB .045 ** ~IbE HEADER ** SERVICE MA~E : STAT!O VERSIOU ~ : 5C0-4~3 DATE : 93/01/01 '~'AX. aEC. LEN.~ 8192 ~tt.~: TYPE ~ DL ~REV~OUS FILK ~ Table type CONS LfStlnq o~ set 7 type OBJNA~a S',.~ T TU I PUN[ DESC VALU ''''''''''''''''''''''''''''''''''''''''''''''FDEP ~bLO F F D th ~ind of set. Table tvPe CONS blstln~ of set 8 type ..---........;;.. ..... OBJNA~ STaT NI PUNt OKSC VA U ..--.--.~...~...~......~...~...... .~nd of set 'Fable t,y~e CoNS Ll. stin~ of set 9 type CONS ~.--.--~...--~..~.................. .............~...~...~....~..... End of set $chlumberoer LIST t~UB0:[)LISA.DAT~ 9-JAN-93 2,2:14:00 Page 29 [)ata format specif~.catlon record Listing of set 7 type 64EB object 0 E~TRY VAL[I~'~ ~EPCOD~ SIZE 1 0 66 2 0 4 255 66 5 0 66 6 0 73 4 8 60O 7 ] 4 9 5~$ 65 4 16 1 66 0 66 0 bl~tlnq of set 0 tYPe CHAN ID ORDER # LOG TYP CbS ~OD NU~B ELEM SA~P COD CHEX) ETI~ RFTB S 6] 62~ 0 41 ! 1 4 68 0000000000 SGP RFT?~ PSI 81 400 0 41 1 1 4 68 0000000000 PONR ~FTB 8! 400 0 41 1 ! 4 68 0000000000 PTEN PFTB 81 400 0 41 1 1 4 68 0000000000 PMU5~ UFTB 81 400 0 41 ! I 4 68 0000000000 PT~O ~F~g 81 400 0 41 1 ~, 4 68 0000000000 End of set Oata record type 0 TI~E 29515580 .5MS ETTM O. SGD 4301.88 PONE 1. PTEN O. PHUg 3. PTHO 4. Data record type 0 TI~E 29615780 .5~S ~TIN 50.1 SGP 4300.361 PONE 0, PTEN O. 5chlun~herger LIST ~t. 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PTHO 4. · ~.~,le tra~...ler .Fu~B ,045 ** FISE TRAILER ** ~iI.,E NA~!E : RFTB .045 SERVIC~I MAME : STATIO vERSI:ON ~ ~ 5C0-42] ~TE : 9]/01/01 WIbE TYP...~ : Ob NEXT FILE ~ FIlE SU~iMARY {LR ~PR ~E~JC #DR #FM ~I ~I.UNITS ~XPI MINPI ''''''''''''~''''''''''''''''''''''''''''''''''''''''~''''''''''''''''5 0 21 !638 Ti~E ,SMS 49 80 Tape trailer DEFAULT ** TAPE TRAILER ** SERVICE NAME : F~FTB DATE : g3/OllOl DPI~IN : Db!S TAP~ NA~E : D~FAULT CnNTIt4U~TIO~ #: I N~X~ T~PE : Co~uEt':~T : PROCESSED BY SCHb[I~BERGER DLiS TO [,IS CONVERTER UTILITY ~eel traller D~FAULT 5chlu~,berger LIST t~UBO:[]bISA.DATI 9-JA~-93 !2:!4:00 Paqe 32 ** R~EL TRAILE~ ** SERVICE N~NE : RFTB D.aTE : ORIGI~ : DLIS CONT!~UATIOM ~: COMME~-~T : PROCESSED BY SCHLtI~,~ERGE~ DLIS Tf3 LIS CONVERTER UTILITY Reel Leader DEFAULT ** REEL ~EADER ** SERVJCV ~,'IE : RFTB DATE : 93/01/01 OR IGI ~,~ : ObIS REEL WAME : CONTI~?UATION ~1 1 COM'~MT : PROCESSED BY SCHbUr~!~ERGER DLIS TO bis CO~JVE',RT~R UTILITY header DEFAiJLT ** TAPE HEADER ** SERVICE NAME : FRFTS DATE : 9]/01/0! OPI~It'I : DLIS TAPF ~!A~E : DEFAOLT C~TINUAT!OM ~: ! PPF:VIOUS TAPE : CnN~E~T : PROCESSED BY SCMbU~BEpG~R Phis TO LIS CONVERTER UTILITY (EOF) Wile header RFT~{ .046 ** WILE HEADER ** wILE ~A~E : ~FTB .046 SEPVICM SAME : STATIC] VEtS!ON # I 5C0-423 DAT~ : 93/0!./01 wII, E TYPE : DL D~EVIO~;S MILE : .. ~chlumberger LIST NUBO:[]LISA,DAT: g-gAN-9] 12:14:00 Page Table type CONS Listing of set 7 type CONS OBJNA~ STAT TI, IN! PUNI [)~ C V.AI,U ............?OEP ~LLO'''''';~ .... ~'';;;i'~'~;';''~;i;~:'or o . P h End o~ set Table type CO~S bisti~o o{: set 8 tv[>e CO~S OBJNAN ST~T TUNI Pd*.I DESC VAbU ~nd of set . Table Listtn~ of set 9 type CONS 0 g d N A ~nd of set Oata format, sDec~f!cation record bistln~ of set 9 type 64~B object 0 EMTRY VALUE REPCODE SiZ~ I 0 66 2 0 56 3 102 79 4 ~55 66 5 0 6 0 7] 4 8 600 73 4 9 .5~S 65 4 12 -999,25 68 4 13 1 66 14 .SuS b5 4 15 7! 66 16 ! 66 1 0 66 mmmmmmmm--mmmmmmmmmmmmmmmmmmmmm.-- End of set 3] ;chlumDeroer LIST ~!3~O:[]LIS.A.r)AT~ 9-d'A~!-93 12:14:00 Page 34 L~stioQ o~ set 0 type CHA~ ~A~ SERV !J~IT SERVICE API APl AP! API F'ILE NUmB NU~ SIZE REP PROCESS ID ORDER ~ bOG TYP CLS MOD NUMB ELE~ SA~P COD (HEX) ETI~ PFTB S 63 6~! 0 42 I 1 4 68 0000000000 SGP ~WT~ PSI 81 400 0 4~ I ~. 4 68 0000000000 POME ~FTE ~1 400 0 42 I I 4 68 0000000000 PTE~ DFTE Bl ~00 0 42 1 1 4 68 0000000000 P~!.!~ ~FTB 8t 400 0 42 I 1 4 68 0000000000 PTHO ~FT~ ~1. 400 0 42 1 1 4 68 0000000000 E~d of set Data record type 0 TI~.E 30929040 ,5M'S · ETII~! O, SG~ 4191,I04 PONE 1 PTEN 9. PHI;N 1, PT~IO 4, Data record type 0 Ti~E 310~9~40 .5MS · ~T~i 50,1 SGP 4!90,§9~ PBNE O, PTEN 9, PHUN 1, PT[~O 4, Data record type 0 TI~E 31129440 ,5M$ · ET!~ 100.2 SGP 4190,7 PONE O. PTEN 9. PHU~ 1. PT~IO 4. Data record type 0 TI~iE 31229640 ,5MS ~TY~ 150.3 $~P 4190.415 PONE O. PTE~ 9. P~!..IN 1, PTHO 4, Data record type o TIHE 31329840 .5~8 ETIM 200.4 SGP 4190.273 PONE O. PTEN 9. PHI!~ 1, PTHO ~, Schlumberger LIST ?~t~BO:£]L!$A,DAT~ 9-JA?t-93 12:14:00 ~a~e 35 Data record type 0 T!~E 31430040 ,5~$ ETIM 250,~ SGP 2602,0~5 PONE 2. PTE~ O, PHUN 6, PT~O 2, Data record type 0 TI~E 31530240 E~I~= 300.6 SGP 3005,25 PONE 5, PTEN O. P~[JN 6. ~.Ti.O 3, Data record type 0 TIME 31730640 ,5~$ ETIM 400.8 SGP 37~.2.85 POME 2. PTEN 1. mmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmm~m~m~~. . Data record type 0 TI~E 31B30840 ,5~S PHUN 7, PTHF) 3. Data record type 0 TIME 31931040 .5~5 ETI~ 501. SGP 37~7,124 PONE 7, PTEM 4. PHU~! 7. PTHO 3. Data record tvme 0 TI~E 32031240 ETI~ 55~'i SGD3756"BS~ PONE 6. PTEN 5. PHTIN 7. PTHO 3, ;chlumber~er LIST u~8~') IlL!SA.LA ~. 9 dAN-93 12:14:00 Page 36 Data record type 0 TIb.~E~ 32.131440 ETI~ 601.2 SGP 3764,109 PONE 4. PTEM 6, Data record type 0 ..,,,¢ 3~231640 .5MS ETIM 65!.2999 SGP 4!88,99~ PON~ 9, PTEN 8. P~N 1. ~T~ 4, Wi!e traller RFTB .046 ** FILE TRAILER ** FIhM MANE : RFTB ,046 SERVICE NANE : STATIO rEPS!BM # : 5C0-423 DATE ~ g]/o1/o1 ~A×. REC, L£N.: 8192 FILE TYPE : Db ~EXT FILE : Fit, Fi ~bR #PR #E~C ~DR #FM PI PI.UNITS NAXPI ~INPI 53 63 0 29 2303 TI~IE ,5N$ 30029040 32310240 Tame trailer DEFA!!bT ** ThPE TRAILER ** DATE: : 93/01/0! OPIGIN : DL!S TaP? NA~E : DKF.~ULT CONT1NU~TIOS ~: 1 Cf3~"E~T : ~ROC~$SED BY SCHL!JNBE~GE~ DLIS TO LIS CONVERTER UTILITY Reel t. ral!er D~Fa~JI.,T 12:14:00 Page 37, ** R~EL TRAILE~ t~P I(;I ~ : DLIS COt~TI~U~,,T!ON ~: 1 CO~J~E~,;T : PROCESSED BY SCHbI, t~4BER. GER DLIS TO bis CONVERTER UTILITY ~eel heade~ DEFAHLT ** REEl, HEADER SERVICE ~!AH~ : RFTB D~TE : 93/01/01 ORIGI~ : DLIS REEl, ~A~E : D~FAULT CONTINUATION ~: 1 P~EVI~U$ REEL : COMmEnT : PROCESSED BY SCHLU~BERGER DLIS TO LIS CONVERTER UTILITY TaRe header DEF~UL? ** TAPE HEADER SFRVICE N A ~.~E : DaTE : 93iOl/0~ OFTClN : D[.,I S TAPE NA~-~5 : DEFAUI.,T CO~4TINUATIO~? ~: 1 PREVIOUS TAPE : CO~4~f3P'T : PROCESSED BY SCHLU~BERGER Dials TO LIS CO?.~VERTER UTILITY [EOF) File header RFTb .047 FILE ~A~E : RFTB .047 SERVICE ~!A~E : STATIO VERSION # : 5C0-4~3 DATE : 93/0!/0! ~AX. REC. bEH.: §192 WILE TYPE : DL PREVIOUS FI[,E ~berger LIST ~..~U~.(),'.t]LIS~,DAT; 9-0AN-93 12:14:00 Paqe Table ty[>e CONS ngJNA ~T TUb'S! P[]NI D~SC VALU End of set Table type CO. NS LiStJ. Dq o'f set 8 ty[:~e CONS OBJNA~ ,~IAT TUNI P[]NI DESC VAL~ .~',nd of set Table type _bNS Llstin~ of set ~ type CONS . AT TUNI P'UN? DESC VALLI [)ate format scecif~cat:lot', record Listtn~ of set ~1 tvpe 64EB object 0 ENTRY VALUE ~EPCODE S!:ZE I 66 1 2 0 66 1 3 102 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 ,5~S 65 4 12 -999,25 68 4 13 ! 66 14 ,5~S 65 4 15 73 66 16 J 66 1 0 66 0 mmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmm End of set 38 ½chlu~bercer LI'ST N[I[~O,. [:]LiS~,D~T~ 9-JAN-~ 12:14;00 Pege 39 ~'D ORDE~ ~ LOG TYP CLS MOD NUmB ESE~ S~P COD (HEX) ETI~ ~FTB S 63 62! 0 43 I ~ 4 68 0000000000 SGP~ PFTB PSI 81 40{} 0 43 I I 4 68 0000000000 PONF PFT~ 8~. 400 0 43 I 1 4 68 0000000000 PTE~ PVTE 8l 400 0 43 1 ~ 4 68 0000000000 P~UN ~FTB 81 40C 0 43 1 ~.. 4 6B 0000000000 PT~O ~FTB ~!. 400 0 43 1 l 4 6¢ 0000000000 ~nd of set Data record type 0 T~!E 32488424 ,5MS S" 234 PD~IF 6. . . ET!~ O, ,~P 4186, PTEN 8 PHI. IN I, P~.H 4. Data record type 0 TI~E 32588624 ,SMS m~mmmm;:m~mmmmmmmMmm.~.mmmmm~m~m~mmm,mm~mmmm.~mm~m~mmmmmmmm~m~m~m~ ET!M 5 I. SGP 4184,141 PONE 4, PTEN 8, PHUN 1, PTHO ~, Data record type 0 T]~E 32688824 ,5M$ ... FTI~ !,,()C 2 SGP 4183,164 PINE 3, PTEN 8, P}!IJN !. ?THO 4. Data record tvDe 0 TIME 32789024 ,5~S ETI~ 150,3 S¢;P 4182,g94 PONF 3, PTEN 8. PHUN 1, PTHO 4, Data record type 0 TI~{E 32889224 ,5~S FTI~ 200.~ SGP 1575.576 PONE 5. PTEN 7. PHUN 5, PTBO immmmmmmmm, mmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmimmmmmmmm~mmmmmmm~m ~cblumber<~er [...~!ST ~4UB{,:[]LISA.,Dt~T~ 9-j~:;-n3 12114:00 Pa~e 40 Data reco~'d t¥~e o T]~; 32989424 ......... .... ' .................................... P~UN 5, PT~'{O 3, mmmmmmmmmmmmmm--mmmmmmmmmmmmmmmmmm.mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm, m Data recold type 0 TJ:M~ 33089624. ,5MS mmmmmmm.mmmm..mmmm..mmmmmmmmmm, mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm.m. ET]M 300.6 SGP 3553°509 PHUN 5, PTHO 3, Data record type 0 TINE 331.89824 ,5~8 ~'~;T~'''''""~''~T~['"'';3~'~7"'''' .......... P?EN ~. '""""' PHIJ~ 5, PTH{.~ ~. Data record t. vpe 0 T]:~E 33290024 . ETI~' 400.~ SGP 3574,938 PON~ 4, PTEN 7, PUl, IN 5, PTHO 3. .--~.''''~'''--'........~.~....'.~...--..~......~............~.~.....~. · . Data record type 0 TI~iE 33390224 ,5~4S ETIM----------------------------------------7---------------------------4`~`~ ~ . SGP 41~ . 3. PO 2 PTEN, . 8. PHUN 1,, PTHO 4, Data record type 0 TI~E 33490424 ,5.~!$ ET!M 501. PTEN 8. PHUN 1, PT!4O 4, .......~m~.sm~..~.mm~...............~m,..........~.............~........ File trailer RF.TR ,O47 .~c~luwberqer I,!ST ~tBO:[]LI8~ DAT: .~ , ...... .,.-93 !2:14:00 Paqe 4.! ** FIL~j TRA!LEL' ** SE~VI'CE NA~E ~ ST~TIO VERSIC~ ~ : 5C0-423 ~ATF', ~AX. REC. LE~.: FIL~] TYPE #LR #PR ~r~ ~DR #EM UN XPI ~INPI .................-................,,.-.-,-...-.,,..-..--.-....-......--.-. 46 56 ~ 22 ~7 T t~E , S 324~424 335~4424 [EOF ) Tape trailer DEFAULT ** TAPE TRAILE~ DaTM : 93/01/01 ORIGIN : DI,., I S TAPE NA~E : DEFAULT CONT!MUATIOM CO~'~ME;NT : PROCESSED BY SC~b{.~::~ERGER DLIS TO LIS CONVERTER UTILITY ~eel trailer SERVIC~ NAiF : RFTB DATE : 93/01/01 OPlGIN : DLIS CO~TIMi~TIOM #: sgX~ PEEL CO~E~T : P~OCf;SSED ~Y SCHL[t~BERGE~ Db!S T[3 bis CONVERTER UTILITY ~chlu~',berger LI$~i~ ~UB(;:[]LIS~.DAT; 9-JAN-93 12:14;00 Page 42 ~eel header DEFhULT ** REEL ME,hDER ** SERVICE ~J~E : RFT8 DATE : 9~!01/0! ORI~I~ : DLIS RFEL ~A~E : DEFAULT CO~TI~UATIOM ~: 1 C~ENT : PROCESSED BY 5C~b~)?4BERGE~ DLIS T0 LIS CONVERTER UTILITY Tape header DEFAULT ** TAPE HEADER ** SFRVICE N~E ; F~FT~ D~TF I 93101101 O~ICIN : DLIM TI~.PE N~ME : DEFAUhT P~EV~f~US T~PE : CO~:~u~.:;NT : PRDC~oS~D BY SC[~NBERGE~. PI, IS T0 LIS CONVERTER UTILITY File header RFTB ,048 ** FILE HEADER ** FILE NAME : RFTB ,048 SERVICE NAME : STATIO VERSIU~ ~ : 5C0-423 DA~'E ~ 93/0!/01 ~AX, REC. LEN,: 8192 FILE TYPE : DL Table type Llstino of set 7 type CONS OBjNA~z STAT TUMI PUNI DESC VALU ..... '"" ..... '"'"";;[;;'i'"" ..... FDED aLLO F ~' t on DePt~ 10 . End of set Table typ~ C[~MS Llstimo o~ set ~ type C0~$ O~JN~M ST~T TIJNI PUNI [>ESC VAI,U 5chlumberoer [~IS? ~I!3[40: [ ] LISA o PAT; Table ty~e CONS Listinn of set 9 type CONS OBJNAN $~'~T TUNI P!;NI D~SC VALU Pat~ format s~ec~fication record List~n~ of set 13 typo 64EB object, 0 -~ ...... ~ .......... ~.-.....~.-. 2 0 66 1 3 1.02 79 2 4 255 66 5 0 66 1 6 0 73 4 7 IN 65 8 600 73 4 9 .5~S 65 12 -999.25 6~ 4 13 1 66 14 .5~S 65 15 73 66 !6 I 66 0 66 0 nd of set 9-JA~-93 12:14:00 Page 43 Listin~ oi set 0 type CH~N ;-;~-~-;~---~;~--~-----~--~;--- ....... .-.....-...--...-.....;....~.....;~.... ~TT~ ~rm~ $ 63 621 0 44 ! 1 ~ 68 0000000000 SGP RFTB PSI 81 400 0 44 I l 4 68 0000000000 DONF PFT~ 81 400 0 44 1 1 4 68 0000000000 PTE~ ~FTB 81 400 0 44 ! 1 4 68 0000000000 p.u~ ~FT~ 81 400 0 44 1 ! 4 68 0000000000 ~'~ ~. ~! 2°~ ~ ~ ' ' ~ ~ 00020°000° ~nd o~ set Data record type 0 T!~E 336766.40 ,5~',S ETI~ o. 185 . E PTEN 8. PH!IN 1. PTHO 4. mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmMmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ~cblumber~er LIST .~{[!B0:[]LISA.D.AT; 9-JAN-93 !2:14:00 Paqe 44 Data record tvDe 0 TI~ 33776840 ,5~S ~[~';;T~ ...... ''''''''''''''''''''''''~''''''''''''''''~'''''''''''41~4 0,5 PT PBUN I. PT}lO 4. Data record ty~e 0 T!~!K 33877040 .SMS ET''''''''T~''''''''''''''''''''''''''''''''''''''''''''''''''''''''''M S(; 41. n .3.~ P~NE 4. PTE~ 8. PFII!N I. PT~O 4. Data record type 0 TIME 33977240 M S ,. , 3.89 PO'~,~ 3. PTEN 8. Pi'IU~ 1, PTHO 4. Data record tvoe 0 TINE 34077440 .5N$ · ETIM 200.4 SfgP 3417.356 PONE 7. PTEN I. P}{UN 4. PT~O 3. Data record type o TI~Fi 34177640 .SMS ETIM''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''. 250.5 S(;P 349 ,8. 2 PONE 2. PTEN' g. P!~UM 4. PT!tO 3. Data record tVoe 0 TIME 34277840 .SMS ETIM 300.6 SGP 3496 72 P N'E 6'.6 [.,~ PTEN 9. P!i!.!N 4, PTHO 3. Data record type 0 TI~E 34378040 .5~S ........ETI,~ .... 35o'~. .............. SGP 3~.~~ .... ~;~'~T''''''''''PTEN. 9. ''''''' ~HUN 4. PTaO 3. .;chlumber~er LIST ~UB¢~:[]LISA.D~T; 9-dAN-93 12:14:00 Page 45 Data record type 0 TIME 34478240 .SM;S ~TI~ 400.8 SOP 3495.624 PONE 8. PTE~ 9. ~Ht!N 4. PT~O 3. Data record type O TI~E 34578440 ,SNS ETIN 450.9 SGP 349e.988 PONE 9. PT~N PH[]N 4, PT~{O 3. Data record tvPe 0 TI~E 34678640 .SMS ETI~ 501. SOP 3499,249 PONE 9. PTEN 9.~ ~UN 4. PTHO 3. · Data record type 0 TIME 34778840 ETIM 55~.1 SGP 3.499.~ PONE 9. PTEN 9. PHUN 4 PT~O 3 ETIM 601.2 SGP 3499,473 PONE 9. PTEN 9. PHUN 4. PTNO 3. ~a.t.a r. ec.o.rd, t¥~e. 0 TINE 34979240 ~TTM 651.2999 SGP 4183.677 PON~] 3. PTE~ 8. PHUN ~. PT;{O 4. Data record type 0 TI~E 35079440 .5gS ETIM 70~.4 SGP 41~2.989 PONE 3. PTE~ 8' PHUM 1. PTHC~ 4. mmmmmm~mmmmmmmmmmmmmmmm.mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ~chlumber~er hIST ~,Ug¢i~:[]blSA.[)AT; 9-JAN;-~3 12:14:0(3 Paqe 46 Data record type 0 TIME 35279840 ~TI~801'6 $GP4~2'787 PONE 2. PTEN 8. PMUN 1, PTRO 4. F~le tra~ler NFTB .048 ** ~ILE TPAILER ** Flb~7 MANE : ~FT~ .048 SERVICE ~A~E : STAT!O VER$IO~ ~ : 5C0-423 ~ATE~ : 93/01/0~. ~AX. REC. LE~.: F!SE ~YPE ~ Db ~×T ~ISE : 59 69 0 35 2798 TI~E ,5~$ 3]676640 35354840 (EOF) Tape trailer DEFA!JLT ** TAPE TRAibER ** SERVICE ~A~M : FRETS DaTE : 93/01/01 O~!CIN : DL!S TaPE MA~E : DEFAULT CONTINUATION #1 ! NE~T TAPE : C[~N~F~T : PR[~CESSED ~Y SCHL!J~BE~GER DJ, IS TO LIS CONVERTER UTILITY ~eel tra~ler [;,EFAUI,1~ .;chlumbercter LIST ~-,~3R0:[~LISA.DAT.~ 9-dAlai-93 !.2:14100 Paoe 47 SERVICE NA~E : HFTR DA. TM : 93/01/01 O~IGI~ : DL!$ REEL ~A~E : DEFAULT NEXT ~FEL COB!~E~YT : P~UCESSED BY SC~LU,~E~GER OLIS T~;~ bis CO~4VERTER UTIblTY FILES TAPES #LR #P~ End of llstinq MUSO:[JLISA.DA~,