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Home My WebLink About186-134MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 13, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 11-26 PRUDHOE BAY UNIT 11-26 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/13/2025 11-26 50-029-21628-00-00 186-134-0 W SPT 8146 1861340 2036 1776 1771 1761 1751 196 437 438 435 4YRTST P Sully Sullivan 1/18/2025 tested to 2548 for 500 psi DP 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 11-26 Inspection Date: Tubing OA Packer Depth 361 2548 2477 2457IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250118195848 BBL Pumped:4.2 BBL Returned:3.6 Thursday, March 13, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.03.13 11:55:06 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 11-26 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-134 50-029-21628-00-00 10945 Conductor Surface Intermediate Production Scab Liner 8968 2502 10910 5197 10600 13-3/8" 9-5/8" 7" 8658 28 - 2530 26 - 10936 4807 - 10004 25 - 2492 26 - 8960 4211 - 4153 none 2670 4760 5410 10600 , 10650 4930 6870 7240 10425 - 10779 4-1/2" 12.6# , 5-1/2" 17# L-80 23 - 9927 , 9993 - 10151 8500 - 8820 Structural 4-1/2" HES TNT , 9785 , 7933 No SSSV 9785 , 10031 7933 , 8147 Bo York Operations Manager David Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028325 23 - 8056 , 8114 - 8254 0 0 0 0 7001 18140 64 247 1772 1648 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" HES TNT , 10031 , 8147 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 3:57 pm, Oct 19, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.10.17 16:46:38 - 08'00' Bo York (1248) DSR-10/19/23WCB 3-14-2024 ACTIVITYDATE SUMMARY 9/3/2023 CTU 9 - 1.75" CT - .156" WT - Job Scope = Log, Sand Dump/Cement Cap Travel to 11-26. Begin RU @ 2100. ****Continue WSR to 9/4/23*** 9/4/2023 CTU 9 - 1.75" CT - .156" WT - Job Scope = Log, Sand Dump/Cement Cap RIH with 2.125" BOT MHA and HES GR/CCL Logging Assembly. Log from tag to 9500. POOH, M/U SLB cementing BHA, RIH, Load well with KCL. Tag bottom. Pump Sand/Gel Slurry. Tag TOS twice at 10750', Reload Sand Dump #2. ****Continue WSR to 9/5/23*** 9/5/2023 CTU 9 - 1.75" CT - .156" WT - Job Scope = Log, Sand Dump/Cement Cap Reload Sand Dump #2. Let Gel Break out. Tag TOS at 10640'. POOH to inspect spotting valve for possible shear. Spotting Valve re-dressed. RIH to pump cement cap. Tagged top of sand 10650, Spotted 4 bbls 15.4ppg Class G cement on top of sand. Top of Cement @ 10,600'. POOH, freeze protect well to 2,500' with 38bbls Diesel. L/D SLB cementing tools, Recovered 5/8" ball, RDMO 3 hours SLB NPT to clean Injector Sump ****Job Complete*** 9/22/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP TAG BOTTOM AT 10570.8' CORRELATED TO SLB INJECTION PROFILE DATED 28-JAN 2006 WITH 29' X 2-3/4" RAZOR GUN. PERFORATE 6 SPF, 60 DEG PHASED RAZOR GUN FROM 10539' - 10568' MD. CCL TO TS=6.8', CCL STOP DEPTH=10532.5' MD PERFORATE 6 SPF, 60 DEG PHASED RAZOR GUN FROM 10515' - 10546' MD, CCL TO TS=6.9'. CCL STOP DEPTH=10508.1' MD PERFORATE 6 SPF, 60 DEG PHASED RAZOR GUN FROM 10484' - 10515' MD, CCL TO TS=6.8, CCL STOP DEPTH=10477.2' MD ***JOB CONTINUED ON 9/23/2023*** 9/23/2023 ***CONTINUED FROM 9/22/2023 WSR*** PT PCE 250LP-3000HP TIE IN TO SLB INJECTION PROFILE DATED 28-JAN-2006. PERFORATE FROM 10453' - 10484' MD. CCL STOP DEPTH=10446.1' MD, CCL TO TS=6.9', WITH 2-3/4", 6 SPF, 60 DEG RAZOR CHARGES. PERFORATE FROM 10425' MD - 10453' MD. CCL STOP DEPTH=10415.2', CCL TO TS=9.8', WITH 2-3/4", 6 SPF, 60 DEG RAZOR CHARGES. ***WELL LEFT S/I, DSO NOTIFIED TO POP*** Daily Report of Well Operations PBU 11-26 gg Tagged top of sand 10650, Spotted 4 bbls 15.4ppg Class G cement on top ofgg sand. Top of Cement @ 10,600'. POOH PERFORATE FROM 10453' - 10484' MD. PERFORATE FROM 10425' MD - 10453' MD FROM 10484' - 10515' MD, FROM 10515' - 10546' MD FROM 10539' - 10568' MD MEMORANDUM TO: Jim Regg -,idI,3! , IOI2e21 P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Well Name PRUDHOE BAY UNIT 11-26 Insp Num: mitLOL210118170414 Rel Insp Num: Well - 11-26 PTD 1861340 BBL Pumped: State of Alaska Alaska Oil and Cas Conservation Commission DATE: Wednesday, March 3, 2021 SUBJECT: Mechanical Integrity Tests Hilcurp North Slope, LLC 11-26 PRUDHOE BAY UNIT 11-26 Ste: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm API Well Number 50-029-21628-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-134-0 Inspection Date: 1/17/2021 � Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Notes. Good test, no issues. Wednesday, March 3, 2021 Page 1 of 1 MEMORANDUM To: Jim Regg h z I-s'2UZI P.I. Supervisor 1\ l "'I FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, February 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC II -26 PRUDHOE BAY UNIT 11-26 See: Inspector Reviewed By: P.I. Supry J Comm Well Name PRUDHOE BAY UNIT 11-26 API Well Number 50-029-21629-00-00 Inspector Name: Lou Laubenstcin Permit Number: 186-134-0 Inspection Date: 1/17/2021 Insp Num: mi0,OL2101I8170414 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-26 Type Inj w- TVD 8146 - Tubing 1742 1745 - 1745 1745 PTD 1861340 Type Test SPT Test psi 2036 - IA 8 2550 - 2525 _ 2515 BBL Pumped: 14.5 BBL Returned: 4.3 OA 5 70 - 69 - 75 - Interval 4YRTST " PIF P Notes: Good test, no issues. Friday, February 5, 2021 Page 1 of I BAI-UGHES ® PRINT DISTRIBUTION LIST STATUS Final Replacement: No COMPANY ADDRESS (FEDEX WILL ROT DELIVER TO P.O, BOX) PERSON ATTENTION V �e6134 30 43 7 (Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE RPM:PNC3D-CO LOG DATE December 15, 2019 TODAYS DATE March 9, 2019 Revision Details: Rev. Requested by: --- FIELD/ FINAL CD/DVD a GE company O COMPANY BP Exploration Alaska Inc. (las, dlis, PDF, META, WELL NAME 11-26 LOGS FIELD Prudhoe Bay Unit (Compass) COUNTY PRUDHOE BAY 900 E. Benson Blvd. BHI DISTRICT Alaska # OF COPIES AUTHORIZED BY Frank Schwarzrock EMAIL frank.schwaLKEgck@bhge.com STATUS Final Replacement: No COMPANY ADDRESS (FEDEX WILL ROT DELIVER TO P.O, BOX) PERSON ATTENTION V �e6134 30 43 7 (Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE RPM:PNC3D-CO LOG DATE December 15, 2019 TODAYS DATE March 9, 2019 Revision Details: Rev. Requested by: --- FIELD/ FINAL CD/DVD FINAL O PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS -D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker CGM, Final Surveys) (Compass) # OF PRINTS 900 E. Benson Blvd. # OF COPIES # OF COPIES # OF COPIES 4 4 N 1 Br North Slope. 0 I 0 I O O O EOA, PBOC, PRB-20 (Office 109) -D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage, Alaska 99508 2 Conot dlhillips Alaska Inc. 0 0 1 0 0 Attn: Ricky Elgarko ATO 3-344 7Street Annchorage,, AK 99501 _ RECEIVED 3 ExxonMobil,Alaska 0 0 1M&R 12 2P 1 0 Attn: Lynda M. Yaskell and/or Lisa Boggs 3201 C Street, Suite 505 /� O `� �� ,Anchorage, AK 99503 j� 4 State of Alaska -AOGCC 0 1 1 0 0 Attn: Natural Resources Technician It 1333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division ofOil & Gas *•* 0 0 1 0 0 Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 •*• Stamp "confidential' on all material deliver to DNR 6 BP Exploration (Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 Attn: David Itter 0 TOTALS FOR THIS PAGE: 0 1 4 0 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 19,2017 TO: Jim Regg1- ."1 I Zo((� P.I.SupervisoSUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 11-26 FROM: Brian Bixby PRUDHOE BAY UNIT 11-26 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tr"- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 11-26 API Well Number 50-029-21628-00-00 Inspector Name: Brian Bixby Permit Number: 186-134-0 Inspection Date: 1/14/2017 Insp Num: mitBDB170114154049 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 11-26 ' Type Inj W TVD 7932 - Tubing 607 611 609 • 605 - PTD it 1861340 ' Type Test) SPT j Test psi 1983 - IA 345 2293 - 2249 - 2238 BBL Pumped: ' 3 BBL Returned: 3.3 - OA 556 774 - 772 772 • Interval 4YRTST P/F P Notes: SCANNED APR 0 6 201 Thursday,January 19,2017 Page 1 of 1 • • 2"'lc D MAY 17 2016 WELL LOG TRANSMITTAL#903127601 AOGCC To: Alaska Oil and Gas Conservation Comm. May 13, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED 5i1V2ow Anchorage, Alaska 99501 M.K.BENDER RE: Borax Log with TMD3D: 11-26 Run Date:2/17/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 11-26 Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-21628-00 Borax Log with TMD3D (Field Print) 1 Color Log 50-029-21628-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ' ✓ola,n4v / ..E%iti'-r'"C • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission l DATE: Monday, February 13, 2012 TO: Jim Regg 2 / 1 q J P.I. Supervisor fff SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 11 -26 FROM: Chuck Scheve PRUDHOE BAY UNIT 11 -26 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry <3 _ NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 11 -26 API Well Number: 50- 029 - 21628 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS120129174228 Permit Number: 186 - 134 - Inspection Date: 1/28/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11-26' Type Inj. W TVD I 7932 IA 59 - 2513 ' 2465 2451 ' P.T.D 1861340 ' TypeTest SPT Test psi 1983 - OA 13 25 26 25 Interval INITAL p/F P - Tubing 695 696 694 691 - Notes: Initial test Post rig workover. SOMED FEB e 2.ULL' Monday, February 13, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 02, 2012 TO: Jim Regg '' Z1 I l v P.I. Supervisor )� ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC I 1 -26 FROM: Chuck Scheve PRUDHOE BAY UNIT 11 -26 Petroleum Inspector Src: Inspector Reviewed By: 1 P.I. Supry (fl---- 1 NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 11 - 26 API Well Number: 50 029 - 21628 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS120129174228 Permit Number: 186 - 134 - Inspection Date: 1/28/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 11-26 . Type Inj. w' TVD 1 7932 IA 59 2513 ' 2465 2451 . P.T.D 1861340 'T ypeTest SPT Test psi 1983 ' OA 13 125 26 25 Interval INITAL - P/F P Tubing 6 696 694 691 Notes: Initial test Post rig workover. StatANNED FEB O 3 Z 01 Thursday, February 02, 2012 Page 1 of 1 OPERABLE: Injector 11 -26 (PTI61340) Resume Sea Water Injection Rig Work... Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 23, 2012 8:42 AM To: 'AK, D &C Well Integrity Coordinator' Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: OPERABLE: Injector 11 -26 (PTD #1861340) Resume Sea Water Injection Post Rig Workover Thanks Jerry. We will look forward to the "warm" MIT. Tom From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, January 20, 2012 9:11 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M Subject: OPERABLE: Injector 11 -26 (PTD #1861340) Resume Sea Water Injection Post Rig Workover All, Seawater injector 11 -26 (PTD #1861340) passed a MIT -IA to 4000 psi on 12/02/10 after a rig repaired TxIA communication and a production casing leak; the well has remained shut in since then. . Now that the sea water injection system repairs have been completed, this well may return to water injection. The well is reclassified as Operable. Once the well is thermally stable, an AOGCC witnessed MIT -IA will be required. Please be aware of the potential for annular fluid expansion. A wellbore schematic have been included for reference. «11 -26 (PTD 1861340) wellbore schematic .pdf>> , FEE 1 . LU1 Please call if you have any questions. Thank you, `' : Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/23/2012 PSti P7� /86,i340 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] ge I (01(Z, Sent: Friday, January 20, 2012 9:11 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS2 DS; Huebel, Ross Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M Subject: OPERABLE: Injector 11 -26 (PTD #1861340) Resume Sea Water Injection Post Rig Workover Attachments: 11 -26 (PTD 1861340) wellbore schematic .pdf All, Seawater injector 11 -26 (PTD #1861340) passed a MIT -IA to 4000 psi on 12/02/10 after a rig repaired TxIA communication and a production casing leak; the well has remained shut in since then. . Now that the sea water injection system repairs have been completed, this well may return to water injection. The well is reclassified as Operable. Once the well is thermally stable, an AOGCC witnessed MIT -IA will be required. Please be aware of the potential for annular fluid expansion. A wellbore schematic have been included for reference. «11 -26 (PTD 1861340) wellbore schematic .pdf» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator kiiibiNED FEE .L 611Z- Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 TREE = CIW • WELLHEAD = MCEVOY �� SAFETY N : CHROME JEWELRY IN 4.1/2 "TBG * ** ACTUATOR = BAKER C 1 1 KB. ELEV = 58' BF. ELEV =.R KOP = 1900' Max Angle= 48° @ 3900' I 2092' I— I4 -1/2" HES X NIP (9CR), ID = 3.813" I Datum MD = 10823' Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" —[ 2530' (TOP JOINT IS 68 #, K -55, ID = 12.415 ") 4807' I 9 -5/8" X 7" BKR C-2 ZXP LTP ITOPOF 4 -1/2" SCAB LNR H 4807' 1 ' w1 FLEX LOCK HGR, ID = 6.276" • • i 9755' H4 -1/2" HES X NIP (9CR), ID = 3.813" I Minimum ID = 3.725" @ 9895' • 4-1/2" HES XN NIPPLE o 9785' I--17" X4 -1/2" HESTNTPKR ID= 3.855" I CIO 1114 9822' H4 -1/2" HES X NIP (9CR), ID = 3.813" I • 44 1 1 9895' H4-1/2" HESXN NIP (9CR), ID = 3.725" I 4 -1/2" TBG, 12.6 #, L -80 TCII, 9927' ■ a, .0152 bpf, 0 = 3.958" 9927' H4 -1/2" WLEG (9CR), ID = 3.958" I • , 5-1/2" TBG STUB (11/24/10) I—I 9993' I-- -4 4 4 9978 ' I " 17" X 5-1/2" XO, ID = 4.870" I ....; ` e►! 10004 I-- I9- 5/8 " X5 -1/2 "UNIQUE OVERSHOT I • MI - r I 10031' H9 5/8" X 5 1/2" BKR SB -3 PKR, ID = 4.859" I 10046'J-{7-5/8" MILLOUT EXTENSION, ID = 6.875" I 10052' ]_J7-518 X5-1/2" XO, ID = 4.892" I 1 10135' 1-15-1/2" OTIS XN NIP, ID = 4.455" I 10150' H5-1/2" BAKER SHEAROUT SUB I 5 -1/2" TBG -PC, 17 #, L -80 AB MOD, --I 10151' I- -' I 10151' I I5 -1/2" TUBING TAIL, ID = 4.892" I .0232 bpf, ID = 4.892" ( 10148" IH ELMD TT LOGGED 07/31/87 1 PERFORATION SUMMARY 10548' H9 -5/8" MARKER JOINT I REF LOG: BHCS on 01/28/87 ANGLE AT TOP PERF: 26° @ 10733' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10733 -10754 S 08/25/89 ' 3 -3/8" 6 10760 -10780 C 04/25/96 3 -3/8" 4 10763 -10779 C 09/21/89 PBTD H 10891' ' 1 ' 1 ' 1 ' 1 ' 1 1 11111 11 N 11 1 • 11 1 9 -5/8" CSG, 47 #, L -80 BTC, .0733 bpf, ID = 8.681" I 10936' X 111 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 • 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 TD I--I 10945' . A �1�1� •8 � 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/04/87 PKR 141 ORIGINAL COMPLETION WELL: 11 -26 02/02/10 D16 RWO PERMIT No: ° 1861340 02/07/10 HB /PJC FINAL DRLG CORRECTIONS API No: 50- 029 - 21628 -00 SEC 28, T11 N, R15E, 343' FSL & 204' FEL 1 BP Exploration (Alaska) TREE= CIW • WELLHEAD = MCEVOY SAFETY : CHROME JEWELRY IN 4 -1/2" TBG*** ,ACTUATOR= BAKER C 1 1 -2 6 KB. ELEV = „ 58' BF." ELEV = KOP = 1900' Max Angle = 48° @ 3900' ' I 2092' H4 -1/2" HES X NIP (9CR), ID = 3.813" I Datum MD = 10823' Datum TVD = 8800' 'SS 13-3/8" CSG, 72 #, L -80 BTC, ID = 12.347" —I 2530' (TOP JOINT IS 68 #, K -55, ID = 12.415 ") 1 4807' I— � 9 -5/8" X 7" BKR C-2 ZXP LTP TOP OF 4 -1/2" SCAB LNR H 4807' .• w / FLEX LOCK HGR, ID = 6.276" I 4 • �: 9755' H4 -1/2" HES X NIP (9CR), ID = 3.813" I Minimum ID = 3.725" @ 9895' • 4 ' : � - 4-1/2" HES XN NIPPLE 4.17 4, �� 9785' I -17 "X4 -1/2 "HES TNT PKR I • 4 9822' H4_1/2" HES X NIP (9CR), ID = 3.813" I • • . • 1 .4 1 9895' H4 -1/2" HES XN NIP (9CR), ID = 3.725" 4 -1/2" TBG, 12.6 #, L -80 TCII, 9927' 2 .• 0152 bpf, ID = 3.958" 4 / 9927' — I4 -1/2" WLEG (9CR), ID = 3.958" I I5 -1/2" TBG STUB (11/24/10) H 9993' I Y4 I 9978' (1-17" X 5 -1/2" XO, ID = 4.870" I ■ • i , `� ( 10004' I— I9 -5/8" X 5 -1/2" UNIQUE OVERSHOT 1 =; 10031 1-19 5/ X 5 1/2" BKR SB -3 PKR, ID = 4.859" I 10046' —17-5/8" MILLOUT EXTENSION, ID = 6.875" I 10052' I-17-5/8 X 5 -1/2" XO, ID = 4.892" I ( 10135' 1-15-1/2" OTIS XN NIP, ID = 4.455" I 10150' H5 -1/2" BAKER SHEAROUT SUB I 5 -1/2" TBG -PC, 17 #, L -80 AB MOD, —I -- 10151' I ' . I 10151' 1-15-1/2" TUBING TAIL, ID = 4.892" I .0232 bpf, ID = 4.892" 1 10148" I-I ELMD TT LOGGED 07/31/87 1 PERFORATION SUMMARY 10548' H9_5/8" MARKER JOINT I REF LOG: BHCS on 01/28/87 ANGLE AT TOP PERF: 26° @ 10733' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10733 -10754 S 08/25/89 II 3 -3/8" 6 10760 -10780 C 04/25/96 3 -3/8" 4 10763 -10779 C 09/21/89 I PBTD H 10891' .A.A.A.A.A.A.A.A.A.�. 1 9 -5/8" CSG, 47 #, L -80 BTC, .0733 bpf, ID = 8.681" I 10936' 4000401 00000* TD I—I 10945' � a ��1�1�1 * DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/04/87 PKR141 ORIGINAL COMPLETION WELL: 11 -26 02/02/10 D16 RWO PERMIT No: 1861340 02/07/10 HB /PJC FINAL DRLG CORRECTIONS AR No: 50- 029 - 21628 -00 SEC 28, T11 N, R15E, 343' FSL & 204' FEL 1 BP Exploration (Alaska) STATE OF ALASKA 'III Y,C ALASKL AND GAS CONSERVATION COMMISON - REPORT OF SUNDRY WELL OPERATIONS r EB 2 2 2011 1. Operations Performed: Ati,w4m g 2 f is Cons" C0�. ❑ Abandon _'4 Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended age ® Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number. BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory ' 186 - 134 3. Address: IN Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 21628 - 00 - 00 7. Property Designation: 8. Well Name and Number. ADL 028325 —PBU 11 -26i 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 10945' feet Plugs (measured) None feet true vertical 8968' feet Junk (measured) None Effective depth: measured 10891' feet Packer. (measured) 9785' ! 10031' feet true vertical 8920' feet Packer. (true vertical) 7933' / 8147' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2530' 13 -3/8" 2530' 2492' 4930 2670 Intermediate Production 10936' 9-5/8" 10936' 8960' 6870 4760 Liner Scab Liner 5197' 7" 4807' - 10004' 4211' - 8123' 7240 5410 Perforation Depth: Measured Depth: 10760' - 10780' MAR 2 2 Z011 True Vertical Depth: 8802' - 8820' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# L-80 9927' MD 8056' TVD 5 -1/2 ", 17# 9993' - 10151' MD 8114' - 8254' TVD Packers and SSSV (type, measured and true vertical depth): 4-112" x 7 HES TNT packer 9785' M> 7933' TVD 9-5/8" x 5-1/2" BKR SB-3 packer 10031' MD 8147' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Set BP. Drilled up the BP. Cut and pulled 5-1/2" tubing from 9993'. Ran 7", 26#, L-80, scab liner and cemented the liner w /162 bbls Class 'G', (784 sx, yield 1.16). Ran new 4-1/2" tubing. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas - Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copes of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ❑ Development Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ ❑ OiI ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG r ® WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt Contact Hank Baca, 564 -5444 310 - 368 Printed Name Elizabeth Barker Atilt— Title Drilling Technologist Namenqumber Signature / j� Phone 564 -5674 Date By 4-56 g� // Elizabeth Barker, 564 -5674 I I Form 10-404 Revised 10 10 RBDMS FEB 2 2 2011 s�'�,I ., / 3 Z l /( Submit Original Only • . 11 -26 Well History Date Summary 10/31/2010 ** *WELL S/I ON ARRIVAL * ** DRIFT TO 5 -1/2" PXN PLUG @ 10,096' SLM (10,135' MD) W/ 4.50" CENT. PULLED P- PRONG @ 10,096' SLM (10,135' MD) MADE SEVERAL ATTEMPTS TO PULL 5 -1/2" PXN PLUG BODY @ 10,100' SLM (10,135' MD) ** *CONT. ON 11/1/10 WSR * ** 11/1/2010 — CONT. FROM 10/31/10 WSR * ** PULLED 5 -1/2" PXN PLUG BODY @ 10104' SLM (10135' MD) (4 PIECES OF PACKING MISSING.) DRIFT DOWN TO XN NIPPLE @ 10104' SLM (10135' MD) TUBING CLEAR TO XN NIPPLE. * ** RIG DOWN TURN WELL BACK TO DSO * ** * ** NOTIFY DSO OF DEPARTURE * ** 11/2/2010 T /I /O= 300/240/0. Temp= SI. T & IA FL (E- line). TBG FL @ 400' (10 bbls), IA FL @ surface. SV, WV= C. SSV, MV= 0. IA, OA= OTG. NOVP. 11/2/2010 T /I /0= 300/250/0 +, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS), RWO prep. PPPOT -T: Alemite external check installed. Stung into test void (100 psi), bled to 0 psi. Functioned LDS, all moved freely (2 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Alemite external check installed. Stung into test void (300 psi), bled to 0 psi. Functioned LDS, all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 11/3/2010 T /I /0= 240/50/0. Temp. = SI Assist E -Line with MIT T Passed to 500 psi. (RWO Prep) T pressured up to 500 psi with 4.8 bbls 60/40 methanol. T lost 20 psi in first 15 minutes and 5 psi in second 15 minutes. For a total of 25 psi in 30 minutes. FWHP's= 475/80/0 E -line on well at departure 11/3/2010 ** *WELL SHUT -IN UPON ARRIVAL * * * *(ELINE: PLUG &CUT) INITIAL T /I/0= 300/220/0. SET HLS 5.5" EZDRIL COMPOSITE PLUG AT 10115' AND JET CUT TUBING AT 9996' IN PREPARATION FOR RWO. FINAL T /I /0= 600/0/0. SSV=0, W =C, SWAB =C, M =0, CSG =OTG ** *JOB COMPLETE - -WELL SHUT -IN UPON DEPARTURE * ** 11/5/2010 T /I /0= 1000/220/20 Temp= SI Circ Out Well ( Pre RWO) Pumed 25 bbls 60/40 down tbg taking returns up IA to hardline jumper to well #24 to establish pump rate at pressure. Continued with 1091 bbls sea water and 135 bbls diesel. Start u -tube. ** *Continue WSR on 11/06/10 * ** 11/6/2010 T /I /O =SSV /290/0 +. Temp =Sl. WHP's (RWO prep). ** Electricians in control of well upon departure ** Page 1 of 2 • • 11 -26 Well History Date Summary 11/6/2010 ** *Continued WSR from 11- 05 -10 ** Circ -out/ CMIT TxIA Inconclusive (Pre RWO) U -tube for 1 hr. (T x IA). Freeze protect hard line jumper with 8 bbls 60/40 methanol. CMIT T/I pressured up to 500 psi with .7 bbls diesel. T/I lost 100/100 psi in 15 minutes and 100/100 psi in second 15 minutes. For a total of 200/200 psi in 30 minutes. VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV open, Master open, IA open, OA open - Well SI FW HP's= 300/300/20 11/6/2010 T /I /0= 300/280/20 Temp =S1 Circ out (Pre RWO) Pumped 2 bbls 60/40 methanol, 1005 bbls 9.8 brine and swaped to diesel. ** *Continue WSR on 11- 07 -10 * ** 11/6/2010 ** *WELL SHUT IN ON ARRIVAL * ** (pre rwo) PURGED CONTROL LINE W/ 3 GAL OF HYDRAULIC FLUID UNABLE TO PURGE BALANCE LINE, PRESSURED UP AFTER 0.5 GAL ** *WELL TURNED OVER TO DSO * ** 11/7/2010 T /I /O= SSV /60 /VAC. Temp =SI. OA FL FB call -in (pre RWO). No AL. OA FL =near surface ( <10 bbls). SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. 11/7/2010 T /I /O =0/0/0 Temp =S1 Circ -out (RWO prep) RU and PT surface line to 3500 psi. ** *Continue WSR on 11- 8 -10 * ** 11/7/2010 ** *Continued WSR from 11- 06 -10 * ** Circ -out (Pre RWO) Pumped 135 bbls diesel down tbg taking returns up IA to hardline jumper to well #24 flowline. U -tube for 1 hr. Freeze protected hardline with 5 bbls diesel. Bled pressure down. FWHP's =0/0/0 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SI 11/8/2010 ** *Continued WSR from 11- 07 -10 * ** Circ -out to flush diesel/ MIT OA Passed to 2000 psi (RWO prep) First test - OA pressured up to 2000 psi with 6.4 bbls diesel. OA lost 160 psi in first 15 minutes and 60 psi in second 15 minutes. For a total of 220 psi in 30 minutes. Second test - OA pressured up to 2000 psi with .1 bbls diesel. OA lost 80 psi in first 15 minutes and 20 psi in second 15 minutes. For a total of 100 psi in 30 minutes. Bled back - 3 bbls. Pumped 50 bbls diesel down IA taking returns up tbg to hardline jumper to well #24. Pumped 292 bbls 9.8# brine down tubing taking returns up IA to hardline jumper. Pumped 10 bbls diesel and let u -tube for 1 hr. Freeze protect hard line with 5 bbls 60/40 methanol. Bled all pressures down. FWHP's =0/0/0 VALVES in following positions - and operator notified of positions and result of job: Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SI 11/9/2010 T /I /O= Vac /0/0; Tested to 500 psi against SSV to qualify barrier test (passed); Shut in MV and installed lubricator; PT'd to 300 low and 3500 psi high for 5 min. against SSV (passed); Set 5 -1/8" FMC ISA BPV #538 thru tree for Doyon 16 pre -rig; 1 -2' ext. used, tagged © 108" S/I MV & SSV, RD lubricator and PT'd tree cap against SV to 3500 psi (passed) No problems Page 2 of 2 TREE = CM/ WELLHEAD = MCEVOY • SAFETY NO: CHROM E JEWELRY IN 4 -1/2" TBG ** ACTUATOR = BAKER C 11 - 26 KB. ELEV = 58' BF. ELEV KOP = 1900' I. J Max Angle = 48° @ 3900' 1 2092' H4-1/2" HES X NIP (9CR), ID = 3.813" 1 Datum MD = 10823' Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" -1 2530' (TOP JOINT IS 68 #, K -55, ID = 12.415 ") 1 4807' 1- 9 -5/8" X 7" BKR C-2 ZXP LTP TOP OF- 4-tt2" SCAB LNR H 4807' ' w / FLEX LOCK HGR, ID = 6.276" -/ 7" 74 r.z /•/ � � i � •4 .i 9755' H4-1/2" HES X NIP (9CR), ID = 3.813" 1 Minimum ID = 3.725" @ 9895' • • 4-1/2" HES XN NIPPLE 4 r 00 II 9785 7 "X4 -1/2 "HES TNT PKR (9CR), ID- - 3.855" 1 • � 4 9822' I I 4 -1/2" HES X NIP (9CR), ID = 3.813" 1 • i ' !• • • ti I 9895' H4 -1/2" HES XN NIP (9CR), ID = 3.725" 1 • 4 -1/2" TBG, 12.6 #, L -80 TCII, 9927' • 0152 bpf, ID = 3.958" 9927' 1--14 -1/2" WLEG (9CR), ID = 3.958" 1 1 5 1/2" TBG STUB (11/24/10) H 9993' 1 eV •;•4 I 9978' I-17" X 5-1/2" XO, ID = 4.870" 1 •�, rC�� 10004' 1- I9 -5/8" X 5-1/2" UNIQUE OVERSHOT / / 10031' 1-19 5/8" X 5 1/2" BKR SB -3 PKR, ID = 4.859" I 1 0046' - 1 7 -5/8" MILLOUT EXTENSION, ID = 6.875" 1 10052' H7 -5/8 X 5-1/2" X0, ID = 4.892" 1 1 10135' H5-1/2" OTIS XN NIP, ID = 4.455" 1 10150' H5 -1/2" BAKERSHEAROUTSUB 1 5 -1/2" TBG -PC, 17 #, L -80 AB MOD, -1 10151' 1-- / ■ 1 10151' H5 -1/2" TUBING TAIL, ID = 4.892" 1 .0232 bpf, ID = 4.892" 1 10148" I--I ELMD TT LOGGED 07/31 /87 1 PERFORATION SUMMARY 10548' H 9 -5/8" MARKER JOINT ( REF LOG: BHCS on 01/28/87 ANGLE AT TOP PERF: 26° @ 10733' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10733 -10754 S 08/25/89 1 3 -3/8" 6 10760 -10780 C 04/25/96 3 -3/8" 4 10763 -10779 C 09/21/89 1 PBTD H 10891' wef .,.,.,.,.,., v 111OTO 1 9 -5 /8" CSG, 47 #, L -80 BTC, .0733 bpf, ID = 8.681" H 10936' �� I TD H 10945' •••••••.•• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/04/87 PKR141 ORIGINAL COMPLETION WELL: 11 -26 ■ 02/02/10 D16 RWO PERMIT No: 1861340 02/07/10 HB /PJC FINAL DRLG CORRECTIONS API No: 50- 029 - 21628 -00 SEC 28, T11 N, R15E, 343' FSL & 204' FEL BP Exploration (Alaska) , 1 • ,cam � � Q j am _ ® � a °� g ' < 4,� .� r a r t_ 6 Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/20/2010 12:00 - 13:30 1.50 MOB P PRE PREPARE RIG FOR MOVE. 13:30 - 15:00 1.50 MOB P PRE PULL RIG OFF WELL AND STAGE ON PAD. 15:00 - 23:00 8.00 BOPSUR P PRE PJSM FOR WORKING ON BOPE. -BREAK DOWN BOPE. - INSTALL DOUBLE GATES. 23:00 - 00:00 1.00 MOB P PRE WORK ON RIGGING ON RIG FLOOR. - BRIDLE UP TO UD DERRICK. 11/21/2010 00:00 - 12:00 12.00 MOB P PRE PJSM AND UD DERRICK. - INSTALL REAR BOOSTERS. -SPOT RIG TO L/D DERRICK WITH WIND DIRECTION. -MOB RIG FROM DS 12 TO DS 11. SPOT RIG ON PAD - CHANGE OUT SRL HANGERS IN DERRICK. -PJSM AND RAISE DERRICK. 12:00 - 16:00 4.00 MOB P' PRE PJSM PICK UP <BOPE. - CHANGE OUT BOPE SPOOL. -PJSM START TO MOVE RIG OVER WELL 11 -26i WHEN STEERING HINGE BROKE. - PERFORM DERRICK INSPECTION. 16:00 - 19:30 3.50 MOB N RREP PRE REPAIR STEERING HINGE. 19:30 - 00:00 4.50 MOB P PRE SPOT RIG OVER DS11 -26i. SHIM RIG. -SPOT PUMP, MOTOR AND FUEL TANK MODS. -HOLD RIG EVAC DRILL WITH AAR. 3RD PARTY HAND WAS AT CAMP AND NOT ON RIG WILL MAKE SURE HE IS REPORTED TO DRILLER HIS LOCATION. 5 MIN DRILL 11/22/2010 00:00 - 00:30 0.50 MOB P PRE R/U HOSES IN CELLAR. -RIG UP HARD LINE AND CHOKE MANIFOLD TO POOR BOY DEGASSER FROM OA TO TIGER TANK. 00:30 - 02:00 1.50 MOB P PRE PJSM WITH DSM. -R/U LUBRICATOR. TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -PULL BPV. 0 PSI UNDER BPV. -UD DSM LUBRICATOR. Printed 2/22/2011 2:02:20PM 1 x c ¢ ¢ n r€ aye � f �:_ � � 0 3._ �. Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Site: PB DS 11 Project: Prudhoe Bay Rig Name /No.: DOYON 16 Rig Contractor: DOYON DRILLING INC. Spud Date/Time: Rig Release: 11/12/2010 UWI: Active Datum: 41:26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 02:30 0.50 KILLW P DECOMP RIG EVAC DRILL WITH NIGHT CREW. DRILL HAVE WAS CALLED BY THE DRILLER, ALL PERSONAL DISCU MUSTERED SION T CHANGE . -HELD SHACK A SROUND IN THE DRILL. TOOK HEAD COUNT FROM A THE HE SIGN AN IN ROSTER. A PEOEL COUNT FOR INCLUDING TRUCK RS DRIVERS. N AAR: - DISCUSSION LL ON DISTANCE AC OF SPOC ED SHACK. IT WAS LIZ REALIZED THAT WE COULD BE MOVED CLOSER TOZ THE RIG. TO BE BETTER UTILIZED FOR A MUSTER AREA AND STILL MAINTAIN A SAFE DISTANCE FOR THE ONCOMING TRAFFIC. - DURING THE REVIEW .IT WAS REAL THAT THE 'PROCEDURE NEEDED TO BE IZED UPDATED TO REFLECT THE RIGHT PERSON TO RE: IEVE THE R. -THE DILLER REALIZED SIGN THAT ROSTE ACCORDING TO PRCEDURE HE WAS IN SUPPOSED TO GRAB RADIO. 02:30 06:00 3.50 KILLW P DECOMP PJSM ON DISPLACING DIESEL FROM WELL. - PRESSURE TEST LINES. REVERSE CIRCULATE HOT 9.8 PPG BRINE DOWN IA TO DISPLACE DIESEL FROM TUBING GETTING RET BBLS . -PUMAWAYP RATE OF G6 BPM AND URNS 710 32 PSI. PUMPED A TOTAL OF 80 BBLS TO CLEAR IN TUBING OF DIESEL RA. -STOP AND RIG UP TO PUMP DOWN TUBING TAKING RETURNS OUT IA. PUMP 20 BBLS SAFE -SURF SWEEP FOLLOWED BY HOT 9.8 PPG BRINE AT 6 BPM AND 508 I. INCREASE RATE TO 7 AND 660 PSI. - MONITOR FLUID VOLUMES IN AND OUT DURING DISPLACEMENT. 140 BBLS OF DIESEL SENT TO PS HYDROCARBON RECYCLE @ MONITOR WELL. STATIC. 06:00 - 07:00 1.00 WHSUR P DECOMP BLOW DOWN CIRCULATION HOSES. GCII. -SET BP V. - ROL TST ON B TO 500 PSI FOR 10 MIN. GOOD . 0.50 07:00 - 07:30 DECOMP WHSUR P WELL TAKING FLUID. -FILL HOLE WITH E 1 BBLS. PV -BLOW PJSM DOWN N/D CIRCULATION TREE EQUIPMENT. 07:30 - 09:30 2.00 WHSUR P DECOMP O SINGLE BARRIER DISPENS F AT R ION. BARR M IS T C FR IER WO CRETACEOUS LEAK. -BLEED OFF OA. RIG UP GUAGE TO IA. BLEED DOWN HANGER VOID. -N /D TREE FROM TUBING SPOOL. -RAISE AND VERIFY HANGER SEALS ARE HOLDING. GOOD. -SET DOWN AND BREAK TREE FROM ADAPTER. Printed 2/22/2011 2:02:2OPM � rth Anl ?flea _ E . w i € � n [ p �� 1J peratio RI QY , � Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:30 1.00 WHSUR P DECOMP M/U BLANKING PLUG. -13 TURNS TO BUMP UP. 8 TURNS FOR RETRIEVAL TOOL TO M/U TO PLUG. - INSPECT LDS - 5" OUT AND 3" IN. 10:30 - 18:00 7.50 BOPSUR P DECOMP PJSM FOR N/U BOPE. - BOTTOM IS 3 -1/2" X 6" VBR'S, MUD X, BLIND SHEARS, 4 -1/2" X 7" VBR'S, BAG. -N /U BOPE THEN INSTALL THE VBR'S AND BLIND SHEAR RAMS AS STATED ABOVE. 18:00 - 19:00 1.00 BOPSUR P DECOMP SERVICE DRAW WORKS AND TOP DRIVE. 19:00 - 21:00 2.00 BOPSUR P DECOMP GATHER EQUIPMENT FOR SCREW IN TEST JOINTS. -R/U TEST EQUIPMENT. 21:00 - 00:00 3.00 BOPSUR P DECOMP TEST BOPE's. -TEST UPPER VBR'S WITH 4 -1/2" AND 7" TEST bD I JOINT TO 250 PSI LOW AND 4000 PSI HIGH. -TEST ANNULAR WITH4" T0250 PSI LOW 1r AND 3500 PSI HIGH. -LOWER RAMS TO BE TESTED AFTER POH WITH TUBING. -TEST WITNESSED BY BP WSL, DOYON TOUR PUSHER. -AOGCC REP BOB NOBLE DID NOT SHOW UP. HE WAIVED WITNESS. -TEST ALL VALVES TO 250 PSI LOW AND 4000 PSI HIGH. 11/23/2010 00:00 - 02:00 2.00 ` BOPSUR P DECOMP CONTINUE TO TEST BOPE EQUIPMENT. -BLIND SHEAR RAMS FAILED TO TEST TO 4000 PSI. 02:00 - 03:00 1.00 BOPSUR P DECOMP CONTINUED TESTING FLOOR VALVES. - TESTED LOWER IBOP, TIW & DART VALVES. ALL TESTS TO 250 PSI LOW AND 4000 PSI HIGH. -TOOL PUSHER RETRIEVED NEW SET OF BLIND SHEARS WHILE TESTING FLOOR VALVES - FILLED THE ANNULUS WITH 5 BBLS OF 9.8 PPG BRINE, AVG LOSS RATE (.45) /HR 03:00 - 04:00 1.00 BOPSUR P DECOMP HELD PJSM FOR CHANGING OUT THE BLIND SHEAR RAMS. CHANGED OUT BLIND SHEAR RAMS. 04:00 - 06:00 2.00 BOPSUR P DECOMP CONT TESTING BOPE - TESTING CHOKE MANIFOLD, ALL TESTS CONDUCTED ARE CHARTED WITH A 250 PSI LOW AND 4000 PSI HIGH TEST, ALL TESTS ✓ GOOD. 06:00 - 06:30 0.50 BOPSUR P DECOMP BLOW DOWN CHOKE MANIFOLD AND KILL LINE. 06:30 - 07:00 0.50 BOPSUR P DECOMP SERVICE RIG LUBE ALL VALVES. 07:00 - 07:30 0.50 BOPSUR P DECOMP PICK UP DUTCH RISER. - RILDS. _ _ -CLOSE ANN. AGAINST DUTCH RISER. 07:30 - 09:00 1.50 BOPSUR N WAIT DECOMP PICK UP LUBRICATOR. -ONE EAR WAS MISSING FROM LUBRICATOR DSM FOUND PART AND INSTALLED. 09:00 - 10:00 1.00 BOPSUR P DECOMP M/U TOOLS AND TEST PORT FITTINGS. -TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN. GOOD TEST. Printed 2/22/2011 2:02:20PM ,rth America AE S BP 1 .f 6,€ Operation SumC11d ReI©t € Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 11:00 1.00 BOPSUR P DECOMP RIH WITH LUBRICATOR AND FAILED TO RECOVER BPV. -RIH WITH LUBRICATOR A SECOND TIME AND RECOVER BPV TAKING 1 BBL TO FILL. 11:00 - 11:30 0.50 BOPSUR P DECOMP ` L/D LUBRICATOR AND DUTCH RISER. 11:30 - 12:00 0.50 CLEAN P DECOMP M/U HANGER SO TO DP. -M /U TO HANGER. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM FOR PULLING HANGER. - PULL HANGER AT 175K. 13:30 - 14:00 0.50 CLEAN N SFAL DECOMP ATTEMPT TO FILL LINES TO #2 PUMP. - FITTING TO MUD PUMP LEAKED 10 GAL. OF 9.8 PPG BRINE. 6 GALLONS IN CONTAINMENT. - STOPPED JOB AND REPORTED TO DRILL SUPERINTENDENT AND SPILL RESPONSE. -SPILL RESPONSE WILL CLEAN UP GRAVEL AFTER RIG MOVE. -HAMMER UNION WAS SEALED UP AND PAINT MARK WAS PLACED TO INSPECT IF FITTING IS COMING LOOSE. - PRESSURE TEST MUD PUMP #2 TO 3500 PSI. - GOOD. 14:00 - 16:30 2.50 CLEAN P DECOMP CIRCULATE 9.8 PPG BRINE SURFACE TO SURFACE THROUGH CHOKE. - INITIAL CIRCULATING PRESSURE 250 PSI AT 10 BPM AND FINAL CIRCULATING PRESSURE OF 380 PSI. 16:30 - 17:00 0.50 CLEAN P DECOMP MONITOR WELL. STATIC -BACK OUT AND LAY DOWN HANGER. - BLOW DOWN TOP DRIVE. 17:00 - 19:30 2.50 CLEAN P DECOMP POH WITH 5 -1/2" L -80 TUBING FROM 9996' TO 7780'. -UP WEIGHT OF 180K, DOWN WEIGHT OF 120K. -SPOOL UP DUAL CONTROL LINES 1/4" BARE. NO PLASTIC COATING SEEN. - RECOVERED 31 OF 32 SS CLAMPS REPORTED. 19:30 - 20:00 0.50 CLEAN P DECOMP BACK OUT AND LAY DOWN SSSV. - CLEAR RIG FLOOR OF CONTROL LINE AND SPOOL. 20:00 - 00:00 4.00 CLEAN P DECOMP POH WITH 5 -1/2" L -80 TUBING FROM 7780' TO 4224'. 11/24/2010 00:00 - 03:00 3.00 CLEAN P DECOMP POH WITH 5-1/2" TBG FROM 4224' TO SURFACE. - RECOVERED 251 JOINTS, 1 SSSV, 31 STAINLESS STEEL CLAMPS, 1 CUT JOINT. -CUT JOINT = 10.37' LONG AND CLEAN CUT FLARED TO 6 ". 03:00 - 04:00 1.00 CLEAN P DECOMP CLEAR AND CLEAN RIG FLOOR. -L /D POWER TONGS AND TBG EQUIPMENT. 04:00 - 05:00 1.00 BOPSUR P DECOMP TEST LOWER BOPE RAMS. p - 3 -1/2" X 6" VBRS TEST TO 250 PSI LOW AND L?I 4000 PSI HIGH. GOOD TEST. -TEST WITH 4" AND 4 -1/2" TEST JOINTS. GOOD TEST. -TEST WITNESSED BY BP WSL AND DOYON TOUR PUSHER. -RD TEST EQUIPMENT. 05:00 - 05:30 0.50 WHSUR P DECOMP INSTALL WEAR BUSHING. Printed 2/22/2011 2:02:20PM orth America &LAS - BP = of O peration Sum er, epowrt Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -000NV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 06:30 1.00 CLEAN P DECOMP BRING DRESS OFF BHA COMPONENTS TO RIG FLOOR AND STEAM, IN PREPARATION FOR MU OF DRESS OFF BHA. 06:30 - 07:30 1.00 CLEAN P DECOMP PU & MU DRESS OFF BHA AS FOLLOWS' -DRESS OFF SHOE, WASH PIPE, DRESS OFF MILL= 14', WASH OVER BOOT BASKET, CSG SCRAPER. -C /O ELEVATORS & PU 6 -1/4" COLLARS 07:30 - 08:00 0.50 CLEAN P DECOMP RIG SERVICE -GREASE RIG COMPONENTS 08:00 - 19:30 11.50 CLEAN P DECOMP _ TIH WITH DRESS OFF BI-IA ON 4" XT -39 DP. -RIH F/ 234' TO — 8,800' -RUN SCRAPER 3 TIME EACH FROM 4800' TO 5076'. SCRAPE 6604'. 19:30 - 20:00 0.50 CLEAN P DECOMP HELD UNANNOUNCED KICK WHILE TRIPPING DRILL. -DRILL WAS INITIATED BY WSL MANUALLY RAISING THE FLOW METER OUTPUT. -HELD AAR WHERE IT WAS DISCUSSED THAT DRILLER HAD THE ALARM PARAMETERS OFF ON THE FLOW RETURN. IT WAS DETERMINED BY THE CREW TO ASSIST DRILLER IN REMEMBERING WHEN THE PIT LINE UP IS CHANGED THAT THE PARAMETERS OF DRILLER CONSOLE NEED TO BE ADJUSTED. 20:00 - 22:30 2.50 CLEAN P DECOMP CONT TIH WITH DRESS OFF BHA ON 4" XT -39 DP. -TIH F/ —8,800' TO — 9,980' JOINT 306 TO OBTAIN PARAMETERS. -SPR'S : PUMP #1 30 SPM @ 120 PSI, 40 SPM © 180 PSI, PUMP #2 30 SPM @ 170 PSI, 40 SPM @ 270 PSI. -UP WT OF 217K, DOWN WT OF 144K, ROT WT OF 175K @ 60 RPM, PUMP RATE OF 5 BPM © 480 PSI. 22:30 - 00:00 1.50 CLEAN P DECOMP RIH AND TAG AT 9985' WITH 5 K. -P /U START ROT AT 60 RPM AND 13K FREE TQ. ABLE TO ROTATE PAST 9985' WITHOUT ISSUE. RIH AND TAG 9999' APPLY 10K WOB WITH 14K TQ, PUMP AT 5 BPM AND 480 PSI. -MILL DOWN TO 10004'. P/U 1 JOINT. SHUT DOWN PUMPS AND RIH TAG AT 10004'. -NO INDICATION OF TOP OF STUMP. -P /U AND BREAK CIRCULATION WITH 5 BPM AND 480 PSI. RIH AND TAG AT 10004' AND MILL DOWN TO 10007' WITH SAME PARAMETERS. P/U AND RIH WITH NO ROTATION AND PUMPS AT 5 BPM AND 480 PSI. TAG AT 10007' PUMP PSI INCREASED TO 650 PSI. -SPOKE WITH TOWN ENGINEER, LOOK AT MILL ONCE ON SURFACE TO SEE IF ANY INDICATION OF MILLING STUMP. 11/25/2010 00:00 - 01:00 1.00 CLEAN P DECOMP PUMP 20 BBL HI-VIS SWEEP SURFACE TO SURFACE. -PUMP RATE OF 8.5 BPM AT 1250 PSI. -SWEEP SHOWED NO METAL CUTTINGS AT SURFACE. Printed 2/22/2011 2:02:20PM of 15. Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 01:30 0.50 CLEAN P DECOMP RIH WITH NO PUMPS AND NO ROTATION. -RIH AND TAG AT 10007' WHICH PUTS TOP OF STUMP AT 9993'. -VERY CLEAN WHILE RIH ALL THE WAY TO 10007'. - MONITOR WELL. STATIC. 01:30 - 05:30 4.00 CLEAN P DECOMP POOH FROM 10007' TO 7000' AND RUN SCRAPER AT 7000' - CONTINUE TO POH TO 234'. 05:30 - 06:30 1.00 CLEAN P DECOMP LD 6- JTS.OF 6-1/4" DRILL COLLARS AND DRESS OFF BHA. -BOOT BASKET FULL OF METAL CUTTINGS. -INNER MILL HAS CIRCUMFERENTIAL WEAR PATTERN INDICATING GOOD DRESS OFF. 06:30 - 07:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR OF ALL UN- NECCESSARY TOOLS. 07:00 - 07:45 0.75 EVAL P DECOMP PU 9 -5/8" HES RTTS. MU CLOSED BOTTOM STACK WASHER TO BOTTOM OF RTES. -HOLD PJSM ON TRIPPING IN THE HOLE. REVIEW PROCEDURE AND DISCUSS HAZARDS ON RIG FLOOR AND PROPER PVT SETTINGS FOR MONITORING WELL. 07:45 - 10:00 2.25 EVAL P DECOMP RIH WITH 9 -5/8" HES RTTS ON 4" DP FROM DERRICK. OBTAIN PU AND SO WTS AT 4800'. PU WT = 110K -LBS, SO WT = 100K -LBS. - CONTINUE TO RIH TO 5080'. 10:00 - 14:00 4.00 EVAL P DECOMP STAB TIW VALVE AND CLOSE. - MAINTAIN HOLE FILL ACROSS THE HOLE WITH DRILLER & MOTORMAN MONITORING THE RIG. -CREWS CELEBRATE THANKSGIVING TOGETHER AT RIG CAMP. 14:00 - 16:30 2.50 EVAL P DECOMP PJSM FOR RIH WITH RTTS. ,@1L /R" RTTS FEOM 5080' To 7013 -SET RTTS WITH 145K UP AND 117K D• v ! . 16:30 - 17:30 1.00 EVAL P DECOMP PJSM. PRESSURE TEST CASING FROM 7013' DOWN TO 10,115' CBP. -TEST TO 250 PSI LOW FOR 5 MIN AND 2500 PSI HIGH FOR 10 MIN. GOOD TEST. -ALL TESTS CHARTED 17:30 - 19:00 1.50 EVAL P DECOMP MONITOR WELL STATIC. -POH FROM 7013' TO 5000'. -SET RTTS WITH 115K UP WT AND 100K DOWN. 19:00 - 19:30 0.50 EVAL P DECOMP R/U TEST EQUIPMENT. -WORK AIR OUT OF LINES. 19:30 - 21:00 1.50 EVAL P DECOMP PRESSURE TEST CASING FROM 5000' TO SURFACE. - PRESSURE TEST WITH 250 PSI LOW AND 4000 PSI HIGH FOR 30 MIN. GOOD TEST. -ALL TESTS CHARTED 21:00 - 22:30 1.50 EVAL P DECOMP RELEASE RTTS. - CONFIRM RELEASE P/U 15' AND S/0 PAST SETTING DEPTH. - MONITOR WELL STATIC. -CBU @ 5000', AT 5 BPM WITH 230 PSI. Printed 2/22/2011 2:02:20PM • I f�yT A� I BFI t P e 7` 5 C oon Summary.Report � �� , . Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -000NV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 23:00 0.50 EVAL P DECOMP BREAK OUT AND LD ONE JNT OF 4" DP. - DROPPED 2 -1/4" DRIFT DOWN THE DP - CONT TO LOAD DRIFT & TALLY 7" CSG 23:00 - 00:00 1.00 EVAL P DECOMP SLIP AND CUT 94' OF DRILL LINE. 11/26/2010 00:00 - 01:30 1.50 EVAL P DECOMP CONTINUE TO SLIP AND CUT DRILL LINE. - CONT TO LOAD AND STRAP 7" CASING - CONTINUOUS HOLE FILL, CIRCULATING OVER THE TOP WITH 9.8 PPG BRINE. 01:30 - 03:30 2.00 EVAL P DECOMP POOH WITH RTTS F/ 5,000' ON 4" XT -39 DP, RACKING BACK - BREAK OUT & LD 9 -5/8" (RTTS) PER HES REP. CONTINUOUS MONITORING OF FLUIDS TRIP SHEET, HOLE TAKING PROPER HOLE FILL FOR ENTIRE TRIP. RECOVERED THE DRIFT IN THE TOP OF THE RTTS 03:30 - 04:00 0.50 EVAL P DECOMP PREPARATION FOR 7" CSG SCAB LINER RUN. -, - PO & MU 10' & 15' XT -39 DP PUPS FOR CEMENT JOB 04:00 - 05:00 1.00 CASING P DECOMP RU_ FOR 7 ", 26# L -80 BTC-M SCAB LINER RUN. VERIFYING ALL TUBULAR COUNTS IN THE PIPE SHED 05:00 - 08:30 3.50 CASING P DECOMP PJSM FOR RUNNING 7" SCAB LINER RUN RIH WITH 7 ", 26# L -80 BTC-M SCAB LINER TO 1117'. - INSTALL 1- STRAIGHT BLADED, FREE FLOATING CENTRALIZER PER JOINT. -USE BEST 0 LIFE 2000 THREAD COMPOUND ON ALL CONNECTIONS. -BAKERLOK ALL CONNECTIONS BELOW LANDING COLLAR. -MU ALL BTC -M CONNECTIONS TO MARK. 08:30 - 09:00 0.50 CASING P DECOMP SERVICE AND INSPECT RIG FLOOR EQUIPMENT. 09:00 - 16:00 7.00 CASING P DECOMP CONTINUE TO RIH WITH 7" 27# L80 BTC-M SCAB LINER FROM 1117' TO 51681_ -PU WT = 154K -LBS, SO WT = 130K -LBS. - INSTALL 1- STRAIGHT BLADED, FREE FLOATING CENTRALIZER PER JOINT. -USE BEST 0 LIFE 2000 THREAD COMPOUND ON ALL CONNECTIONS. -MU ALL BTC-M CONNECTIONS TO MARK. 16:00 - 17:30 1.50 CASING P DECOMP - CHANGE OUT HANDLING EQUIPMENT FOR 4 ". -RD DOUBLE STACKED POWER TONGS. -MU X0 TO LINER RUNNING TOOL AND THEN RIH ON 1 -STD OF 4" DP. 17:30 - 18:30 1.00 CASING P DECOMP CIRCULATE A LINER VOLUME TO ENSURE IT IS CLEAR. -5 -BPM WITH 110 -PSI. 18:30 - 22:30 4.00 CASING P DECOMP RIH WITH 7" SCAB LINER ON 4" DP FROM DERRICK. - BREAKING CIRCULATION EVERY 10 STANDS - RIH W/ 49 STANDS TO —9,900' UP WT 154K, DOWN WT 130K 22:30 - 23:00 0.50 CASING P DECOMP PU & MU ONE 10' AND ONE 15' PUPS - RIH ON STAND 50 Printed 2/22/2011 2:02:20PM �s � r ti v ==== - 6 , u,r Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -000NV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 ©58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 CASING P DECOMP RIH TO TOP OF STUB - FIRST SHEAR SHOWED @ 9998' IN WITH A DOWN WT OF 5K, SECOND SHEAR SHOWED @ 10,006' WITH A DOWN WT OF 5 -6K , - INDICATED NO GO • 10,007' 11/27/2010 00:00 - 00:30 0.50 CASING P ._ DECOMP kT HEAD k PA • T T• • • LINER • 4,807' 00:30 - 01:30 1.00 CASING P DECOMP CIRCULATE SURF TO SURF VOL - CIRCULATE 8 BPM • 1200 PSI 01:30 - 02:00 0.50 CASING P DECOMP PJSM FOR CEMENTING OPERATIONS - PRESSURE TEST SURF LINES TO 4800 PSI e_ •"' WITH CEMENT PUMP- LINES TESTED GOOD. - VERIFY POP OFF OF CEMENT PUMP TO BE 7 t( 4900 PSI. 1, - STARTED BATCH MIXING CEMENT @ 01:50 - PUMP 5 BBLS OF FRESH WATER. /iK� r 02:00 - 02:30 0.50 CASING P DECOMP PUMPING 15.8 PPG , CLASS "G" CEMENT ( 1.16 CUFT / SK YIELD) - PUMP 171 BBLS OF 15.8 PPG CLASS G CEMENT MIXING ON THE FLY - PUMPING 3.5 - 6.5 BPM RATE @ 50 - 480 PSI - SAMPLE OF CEMENT SLURRY RECEIVED & PLACED IN THE DOG HOUSE. 02:30 - 03:30 1.00 CASING P DECOMP DROP CEMENT PLUG & START CEMENT DISPLACEMENT - CHASE PLUG W/ 5 BBLS OF FRESH H2O. - SWITCH OVER TO RIG PUMP # 2 FOR DISPLACEMENT - PUMPED TOTAL 235 BBLS OF DISPLACEMENT WITH 9.8 PPG BRINE. - DID NOT SEE A PRESSURE UP AT THE LATCH UP POINT, PUMPING 3 -7 BPM @ 80 - 250 PSI - PUMPED 100 BBLS BEFORE CATCHING CEMENT. - AFTER CATCHING CEMENT, PUMPED F/ 3 - 6 BPM @ 600 - 3800 PSI. - BUMPED PLUG @ 2346 STKS - 235 BBLS. - ( 03:22 ) CEMENT IN PLACE. - PRESSURED UP TO 3800 PSI & HELD FOR 10 MIN. - BLED PSI AND CHECKED FLOATS, FLOATS HOLDING 03:30 - 05:00 1.50 CASING P DECOMP RIG DOWN CEMENT LINE. - RELEASE FROM LINER. - PRESSURE UP TO 1000 PSI. PU 9' TILL PSI BLEED DOWN, PUMP 50 BBLS @ 6 BPM , 420 PSI - RIH TO TOP OF LINER TAG AND SET DOWN 54K & SET ZXP PACKER. - ROTATE ON TOP OF LINER , PU 12' & CIRC CEMENT OUT OF THE HOLE, PUMP 15 BBL CITRIC PILL. -23 -25 BBLS OF CEMENT WAS SEEM AT SURFACE. - FINISH CIRCULATING SWEEP OUT OF HOLE. Printed 2/22/2011 2:02:20PM h i r i AA L K A P � E . d �>Irn S ummary Repot ,, E.� Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Ba Site: PB DS 11 olect. y Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 06:00 1.00 CASING P DECOMP UD CEMENT HEAD AND 1 STAND. -R/U AND CIRCULATE AT 10 BPM WITH 700 PSI. - RECIPROCATE STAND 90' WHILE CIRCULATING. -MONITOR WELL- STATIC -B /D TOP DRIVE 06:00 - 08:00 2.00 CASING P DECOMP POOH STAND BACK 4" DP -LD LINER RUNNING TOOL -RUNNING TOOL DOG SUB SHEARED 08:00 - 08:30 0.50 BOPSUR P DECOMP M/U STACK WASHER TO A SINGLE JT OF DP - FLUSH & WASH STACK W/ 15 BBL CITRIC SWEEP 08:30 - 09:15 0.75 CASING P DECOMP_ PRESSURE TEST 7' TIE -BACK TO 250 Pte_ LOW CHARTED FOR 5 MIN & 1000 PSI HIGH CHARTED FOR 10 MIN -GOOD TESTS -R/D TEST EQUIPMENT & BLOW DOWN LINES 09:15 - 09:30 0.25 WHSUR P DECOMP PULL WEAR RING DRAIN STACK 09:30 - 10:00 0.50 BOPSUR P DECOMP PJSM VV/ RIG CREW & CAMERON DISCUSSED DROPPED OBJECT POTENTIALS, BODY POSITIONS, PROPER TOOL USE 10:00 - 12:00 2.00 BOPSUR P DECOMP ND BODE 2 BARRIERS FOR ND BOP STACK ARE 1) TESTED CBP AT 10,115' AND 2) TESTED 7" SCAB LINER SHOE TRACT. -N /D BOPE AND TUBING SPOOL. 12:00 - 14:00 2.00 WHSUR P DECOMP PJSM. -PULL OLD 13 -5/8" TUBING SPOOL. -PULL PACK OFF. 14:00 - 14:30 0.50 WHSUR P . DECOMP UD PACK OFF PULLING TOOL. -LJD DP AND XO. 14:30 - 15:00 0.50 WHSUR P DECOMP SERVICE RIG. - INSPECT CROWN AND TOP DRIVE. - CHANGE OUT CYLINDER ON GRABBER. 15:00 - 18:30 3.50 WHSUR P DECOMP INSTALL NEW PACK OFF -N /U TUBING SPOOL. -TEST PACK OFF TO 3800 PSI FOR 30 MIN. GOOD TEST. 18:30 - 22:30 4.00 BOPSUR P DECOMP CHANGE OUT SPACER SPOOL ON BOPE. -N /U BOPE. 22:30 - 23:00 0.50 BOPSUR P DECOMP INSTALL TEST PLUG. -HOLD AAR ON N/U BOPE. 23:00 - 00:00 1.00 BOPSUR P DECOMP RIG UP TEST EQUIPMENT. -BEGIN TESTING BREAKS IN BOPE TO 250 _ PSI LOW AND 4000 PSI HIGH. 11/28/2010 00:00 - 02:30 2.50 BOPSUR P DECOMP TEST BOPE BREAKS TO 250 PSI LOW AND 4000 PSI HIGH. -RESET TEST PLUG AND TIGHTENED LOCK DOWNS. -GOOD TEST. -PULL TEST PLUG. 02:30 - 03:30 1.00 CLEAN P DECOMP INSTALL WEAR RING. -CLOSE BLIND RAMS AND TEST 7" SCAB LINER TO 250 PSI LOW AND 4000 PSI HIGH FOR 30 MIN. GOOD TEST. Printed 2/22/2011 2:02:20PM dibrh America AL* g P ge 'of Operation Summa „Repo . , 5 Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -000NV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 05:00 1.50 CLEAN P DECOMP M/U 7" nRil I 011T RHA - 6 -1/8" USED BIT, SUB, MILL, DOUBLE PIN SUB, 4 -3/4" BOOT BASKETS, SUB, BUMPER SUB, OIL JARS, PUMP OUT SUB, 4 -3/4" DC, XO. 05:00 - 08:30 3.50 CLEAN P DECOMP RIH WITH 6 -1/8" DRILL OUT BHA ON 4" DP FROM 323' TO 9781'. -PU WT = 215K -LBS, SO WT = 132K -LBS. - CONTINUE TO RIH SLOWLY TO TAG POSSIBLE CEMENT STRINGERS AT 9819', SETTING DOWN 5K -LBS. 08:30 - 09:00 0.50 CLEAN P DECOMP OBTAIN SLOW PUMP RATES. -PUMP #1 30 -SPM = 200 -PSI, 40 -SPM = 310 -PSI. -PUMP #2 30 -SPM = 240 -PSI, 40 -SPM = 420 -PSI. - ADDITIONALLY, OBTAIN ULTRA SLOW PUMP RATES AS REQUESTED BY RWO SUPERINTENDENT. PRESSURES FOR BOTH PUMPS AT 1/2 AND 1 -BPM CIRCULATING NORMALLY AND THROUGH CHOKE. -WHILE OPENING SUPER CHOKE FOR ULTRA SLOW PUMP RATES, A LEAK WAS NOTED IN THE TOP OF THE CONNECTION ABOVE THE CHOKE BODY. 09:00 - 09:30 0.50 CLEAN P DECOMP STAND BACK 1 -STD OF DRILL PIPE TO PLACE L AT . -BLOW W DOWOW N TOP DRIVE. 09:30 - 10:00 0.50 CLEAN P DECOMP SERVICE RIG FLOOR EQUIPMENT AND CLEAN RIG FLOOR WHILE MECHANIC INSPECTS SUPER CHOKE. 10:00 - 14:00 4.00 CLEAN N SFAL 9,781.00 DECOMP REPLACE ENTIRE SUPER CHOKE SECTION OF CHOKE MANIFOLD. - MONITOR WELL BY CIRCULATING ACROSS THE TOP OF THE HOLE. WELL STATIC. - FINISH CLEANING PITS AND BRING ON 8.5 -PPG SEAWATER TO PITS 1,2 AND 4. -NEW SUPER CHOKE ON LOCATION AT 1400 -HRS. 14:00 - 17:30 3.50 CLEAN P DECOMP CONTINUE TO REPLACE SUPER CHOKE. 17:30 - 18:30 1.00 CLEAN P DECOMP TEST SUPER CHOKE CONNECTIONS TO 250 -PSI FOR 5- MINUTES AND 4000 -PSI FOR 5- MINUTES. -CHART BOTH TESTS. GOOD TEST. 18:30 - 19:00 0.50 CLEAN P -_ DECOMP BLOW DOWN KILL AND CHOKE LINES. -PJSM FOR DRILL OUT 7" CEMENT. 19:00 - 00:00 5.00 CLEAN P DECOMP RIH WITH STAND THAT WAS SET BACK ,ESTABLISH PARAMETERS. -SPR OF PUMP #1- 30 SPM @ 130 PSI, 40 SPM @ 250 PSI, #2 - 30 SPM @ 210 PSI, 40 SPM @ 380 PSI. -UP WT OF 212K, DOWN 133K, RT WT 166K. - WASHED DOWN TO 9818' AND TAGGED TOP OF CEMENT. P/U 10' AND BEGIN ROTATION AT 50 RPMS WITH 10 K FT /LB FREE TQ. DRILLED CEMENT TO 9854' WITH NO INDICATIONS OF LANDING COLLAR. DRILL AHEAD TO 9,888' WITH 3 -5K WOB. Printed 2/22/2011 2:02:20PM 1 1 5 - 7 a ` @P a��1 ® s Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/29/2010 00:00 - 02:00 2.00 CLEAN P DECOMP CONTINUE DRILLING THROUGH PLUGS AND. LANDING COLLAR AT 9888' WITH 5 -10K WOB, 60 RPM WITH 10K TQ, 5 BPM AT 680 PSI. -DRILL THROUGH FLOAT EQUIPMENT AT 9934'. -DRILL DOWN AND TAG 7" X 5 -1/2" XO AT 9977' WHILE PUMPING 10 BBL HI-VIS SWEEP WHILE DRILLING PLUGS. - PULLED UP ,STOPPED ROTATING, RIH & TAG AT 9,977' 02:00 - 03:00 1.00 CLEAN P DECOMP CIRCULATE 10 BBL HI-VIS SWEEP AT 10 BPM AND 2280 PSI. -HOLD PJSM FOR DISPLACING TO SEAWATER. -SWEEP PRODUCED A` SUBSTANTIAL AMOUNT OF RUBBER & CEMENT. 03:00 - 05:00 2.00 CLEAN P DECOMP DISPLACE WELL TO CLEAN 8.5 PPG SEAWATER. - 496 BBL HOLE VOLUME -PUMP 20 BBL HI-VIS SWEEP FOLLOWED BY CLEAN 8.5 PPG SEAWATER AT 7 BPM @ 1300 PSI. 05:00 - 08:30 3.50 CLEAN P DECOMP POOH WITH 7" SHOE TRACT DRILL OUT ASSEMBLY ON 4" XT -39 DP STANDING BACK. 08:30 - 09:30 1.00 CLEAN P DECOMP STAND BACK 3 -STDS OF 4 -3/4" DRILL COLLARS. -LD 7" SHOE TRACT DRILL OUT BHA. -CLEAN BOOT BASKETS AND RECOVER FINELY GROUND CEMENT, 2 SMALL SECTIONS OF O -RINGS & A 4" LONG X 2 -1/2" WIDE PIECE OF ALUMINUM INSERT LANDING COLLAR. 09:30 - 10:00 0.50 CLEAN P DECOMP CLEAR & CLEAN RIG FLOOR -PULL WEAR RING. 10:00 - 11:00 1.00 BOPSUR P DECOMP INSTALL TEST PLUG PRESSURE UP & SEAT TEST PLUG. RILDS. - R/U TO TEST BOPE 11:00 - 17:30 6.50 BOPSUR P DECOMP PFRFORM WEEKLY BOPE TEST. -TEST TO 250 PSI LOW / 4000 PSI HIGH ON ALL EQUIPMENT EXCEPT ANNULAR. TEST ANNULAR TO 250 -PSI LOW AND 3500 -PSI HIGH. -HOLD AND CHART EACH TEST FOR 5- MINUTES. -TEST 4 -1/2" X 7" VBRS WITH 4 -1/2" TEST JT. TEST 3 -1/2" X 6" VBRS WITH 4 -1/2" AND 4" TEST JTS. TEST ANNULAR WITH 4" TEST JT. - STATE'S RIGHT TO WITNESS WAIVED BY JOHN CRISP, AOGCC -ALL TESTS WITNESSED BY BP WSL DAVE JOHNSTON & DOYON TOOL PUSHER GLEN HERMAN. 17:30 - 19:00 1.50 BOPSUR P DECOMP R/D AND BLOW DOWN CHOKE AND KILL LINES. -L /D 4 -1/2" TEST JOINT. - RIG DOWN DART AND TIW. - CHANGE OUT O -RINGS ON DUTCH RISER SYSTEM. - PULL TEST PLUG & SET WEAR RING W/ 9.0 ID 19:00 - 19:30 0.50 BOPSUR P DECOMP R/U 2 -7/8" HANDLING TOOLS Printed 2/22/2011 2:02:20PM •orth America - ALASKA BP €:,- P jfl5 X16 ' ape ation SUm n ar lepo; €._ 45 Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum_ :_41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 22:00 2.50 CLEAN P DECOMP PJSM FOR M/U BHA. -MAKE UP 5 -1/2" DRILL OUT BHA: 4- 7/16" JUNK MILL, XO, BIT SUB, 6 JT OF 2 -7/8" HT PAC, XO, LUB BUMPER SUB, OIL JAR, 3 -1/2" PUMP OUT SUB, DC, XO 22:00 - 22:30 0.50 CLEAN P DECOMP SERVICE RIG. 22:30 - 00:00 1.50 CLEAN P DECOMP RIH WITH MILLING BHA ON 4" XT -39 DP FROM DERRICK FROM 500'. -RIH TO 2,793' 11/30/2010 00:00 - 02:00 2.00 CLEAN P DECOMP RIH TO 9977'. 02:00 - 04:00 2.00 CLEAN P DECOMP PJSM: -SLIP AND CUT 54' DRILLING LINE. 04:00 - 06:30 2.50 CLEAN P DECOMP PJSM FOR DRILLING ON CBP. PARAMETERS: 255 K UP WT, 132 K DOWN WT, ROT WT 165KAT 50 RPM, 12K OF FREE TORQUE - SPR'S : PUMP # 1, 30 SPM -130 PSI , 40 SPM -260 PSI' PUMP # 2, 30 SPM -260 PSI , 40 SPM-420 PSI MILLING CEMENT F/ TOP OF 7" X 5 -1/2" XO @ 9,977' TO 10085'. -FALL THROUGH AND TAG CBP AT 10104'. -MILL CBP FOR —5- MINUTES UNTIL IT BEGINS TO DROP. 06:30 - 07:00 0.50 CLEAN P DECOMP SPACE OUT TOOL JOINT, CLOSE ANNULAR AND BULLHEAD 95 -BBLS OF 8.5 -PPG SEAWATER AT 7 -BPM WITH 1800 -PSI INITIALLY. - PRESSURE DROPS OFF VERY SHORTLY AFTER BEGINNING BULLHEAD AND BULLHEAD PRESSURE DROPS TO 1380 -PSI. -BLEED PRESSURE OFF. —15 -BBLS BLED BACK. -OPEN ANNULAR AND MONITOR WELL. - FLUID LEVEL DROPPING SLOWLY. 07:00 - 07:30 0.50 CLEAN P DECOMP CONTINUE RIH AND TAG CBP AT 10104'. - CONTINUE TO MILL PLUG WITH 10K -LBS WOB. -PUSH PLUG OUT OF TUBING TAIL TO FINAL MILL DEPTH OF 10160'. -POH TO 10145'. 07:30 - 09:30 2.00 CLEAN P DECOMP CLOSE ANNULAR AND CBU THROUGH CHOKE. -PUMP AT 4 -BPM WITH 600 -PSI. - FINELY GROUND CEMENT SEEN THROUGH CIRCULATION. - MONITOR WELL - FLUID LEVEL DROPPING. - OBTAIN STATIC LOSS RATE OF 40 -BPH. - OBTAIN DYNAMIC LOSS RATE AT 4.5 -BPM OF 75 -BPH. 09:30 - 10:30 1.00 CLEAN P DECOMP POH AND LD DP FROM 10145' TO 9991' TO GET ABOVE 7" X 5 -1/2" XO. - MAINTAIN CONTINUOUS HOLE FILL. - STATIC LOSS RATE = 48 -BPH. - DYNAMIC LOSS RATE AT 4.5 -BPM OF 60 -BPH. -PUMP 15 -BBL DRY JOB. -BLOW DOWN TOP DRIVE, CHOKE MANIFOLD AND LINE, AND KILL LINE. Printed 2/22/2011 2:02:20PM �1 • ` AI'erlce ALASKA BP ®1 '� r � � per S wary • r Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:00 0.50 CLEAN P DECOMP HOLD AARON DRILLING OUT PLUG AND CIRCULATING. -HOLD PJSM ON POH, LD DP. IDENTIFY HAZARDS OF REPETITIVE TASKS, PINCH POINTS ON RIG FLOOR AND PIPE SHED AND THE IMPORTANCE OF MAINTAINING CONTINUOUS HOLE FILL. 11:00 - 14:30 3.50 CLEAN P DECOMP POH, LAYING DOWN 4" DP TO PIPE SHED FROM 9991' TO 8175'. -MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF 30 -BPH. 14:30 - 15:00 0.50 CLEAN P DECOMP REMOVE 6 -1/4" DC HANDLING EQUIPMENT FROM RIG FLOOR. -HOLD AAR ON CHANGE OUT AND BEGINNING TO POH, LD DP. 15:00 - 16:30 1.50 CLEAN P DECOMP RIH WITH LAST STAND OF DP IN DERRICK. -CONTINUE TO POH, LD DP TO PIPE SHED ✓ FROM 8175 TO 6835. -MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF 30 -BPH. 16:30 - 17:30 1.00 CLEAN P. DECOMP HOLD UNANNOUNCED KICK WHILE TRIPPING DRILL WITH 2 -MIN RESPONSE TIME. - MONITOR WELL AND CONFIRM STATIC LOSS RATE OF 30 -BPH. -HOLD AAR WITH RIG CREW AND DISCUSS THE IMPORTANCE OF MONITORING KICK INDICATORS USING THE TOTCO PVT. ALSO DISCUSS CREW MEMBER RESPONSES. - IDENTIFIED THAT A DIFFERENT LIFTING EYE COULD BE USED FOR THE TIW VALVE THAT WOULD HAVE ALLOWED THE ELEVATORS TO BE LATCHED UP IF NEEDED. 17:30 - 23:30 6.00 CLEAN P DECOMP CONTINUE TO POH, LD DP FROM 6838' to 500'. - MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF 30 -BPH. - MONITOR WELL. 23:30 - 00:00 0.50 CLEAN P DECOMP MU XO TO TIW VALVE, WHILE MONITORING WELL. 12/1/2010 00:00 - 01:00 1.00 CLEAN P DECOMP L/D D.C. & DRILL OUT BHA. 01:00 - 01:30 0.50 CLEAN P DECOMP CLEAR AND CLEAN RIG FLOOR. 01:30 - 02:00 0.50 WHSUR P DECOMP PULL WEAR RING. 02:00 - 03:30 1.50 RUNCOM P RUNCMP THA. R/U TO RUN 4 1/2 ", 12.6 #, L -80, TCII TBG. 03:30 - 20:00 16.50 RUNCOM P RUNCMP HOLD PJSM ON RUNNING 4 -1/2" 12.6# L -80 TCII TUBING. -RUN 4 1/2" TBG. USE COMPENSATOR. ✓ - TORQUE TURN ALL CONNECTIONS TO TCII OPTIMUM TQ OF 3820 FT /LBS. -BAKER LOCK ALL CONNECTIONS BELOW PKR. - UTILIZE "JET LUBE SEAL GUARD" THREAD COMPOUND ON ALL TCII CONNECTIONS. -DID NOT "SEE" 7" LINER TOP AT 4807'. -MU 230 JOINTS OF 4 -1/2" TUBING. PUW- 152K, SOW- 117K. 20:00 - 22:00 2.00 RUNCOM P RUNCMP PU & MU TUBING HANGER. PU LANDING JOINT LAND TUBING. RILDS. Printed 2/22/2011 2:02:20PM or, ,' ��ll America - ALiE1SKA - BF' `S:� � � Pay ,14 • � Ope tion Summary Report T -1 4, =. . Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -00QNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: 11/12/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:00 1.00 RUNCOM P RUNCMP PJSM. FILL AND PRESSURE TEST LINES. REVERSE IN 150 BBLS OF 120 DEGREE 8.5 -PPG SEA WATER AT 4 BPM / 220 PSI . 23:00 - 00:00 1.00 RUNCOM P RUNCMP REVERSE IN 120 - DEGREE 8.5 -PPG SEA WATER WITH CORROSION INHIBITOR AT 4 BPM / 260 PSI. 12/2/2010 00:00 - 03:30 3.50 RUNCOM P RUNCMP CONTINUE TO REVERSE CIRCULATE IN 120 DEGREE SEA WATER W/ CORROSION INHIBITOR. -PUMP 350 BBLS TOTAL INHIBITED SEA WATER @'4 BPM / 240 PSI. -TOTAL SEA WATER PUMPED IS 500 BBLS. - REVERSE IN 120 BBLS OF 80 DEGREE DIESEL @ 2.2 BPM / 450 PSI. -RU TO TBG, BULLHEAD 30 BBLS OF DIESEL DOWN TUBING © 1.5 BPM / 750 PSI. 03:30 - 06:00 2.50 RUNCOM P RUNCMP DROP BALL & ROD, ALLOW TO FALL FOR 10 MINUTES. - PRESSURE UP ON TBG, PKR SET @ 2200 PSI. - CONTINUE TO PRESSURE UP TO 4000 PSI. -TEST TUBING TO 4000 PSI FOR 30 CHARTED MINUTES. -BLEED DOWN TUBING PRESSURE TO 1500 PSI. - PRESSURE TEST IA TO 4000 PSI FOR 30 CHARTED MINUTES.__ -RIG DOWN LRS. 06:00 - 07:00 1.00 RUNCOM P RUNCMP THA. CAMERON T -BAR IN TWC. -USE LRS TO TEST TWC TO 250 -PSI FOR 5- MINUTES AND 4000 -PSI FOR 10- MINUTES. -CHART BOTH TESTS. -BOTH TESTS GOOD. -RD LRS 07:00 - 08:00 1.00 RUNCOM P RUNCMP BLOW DOWN AND RIG DOWN CIRCULATING LINES. -DRAIN BOP STACK. - PREPARE TO ND BOPE. 08:00 - 11:00 3.00 BOPSUR P RUNCMP HOLD PJSM WITH RIG CREW, BP WSL, BP SUPERINTENDENT AND DOYON TOOLPUSHER. - DISCUSS DROPPED OBJECT POTENTIALS, PROPER PERMITTING AND POSITIONS OF PEOPLE. -ND BOP STACK. -2- BARRIERS FOR ND BOP STACK ARE 1) BALL & ROD ON SEAT WITH KWF ABOVE AND 2) TESTED TWC IN TUBING HANGER. -BEGIN TO RD RIG FLOOR EQUIPMENT. 11:00 - 13:15 2.25 WHSUR P RUNCMP NU ADAPTER FLANGE AND PRESSURE TEST TO 250 -PSI LOW FOR 5- MINUTES AND 5000 -PSI FOR 30- MINUTES. - RECORD BOTH TESTS USING CRYSTAL DATA RECORDER. -RD #4 GENERATOR AND #2 MUD PUMP. - CONTINUE TO RD RIG FLOOR EQUIPMENT. - FINISH CLEANING PITS. Printed 2/22/2011 2:02:20PM p __„„:, ,,,$:!,-.1y*---------:---,---- , -, 3 € rte- , - � s " _ - E` ° ° € , er EI]I11 • . _ . Common Well Name: 11 -26 AFE No Event Type: WORKOVER (WO) Start Date: 11/20/2010 End Date: 12/2/2010 X4 -OOQNV (2,708,000.00 ) Project: Prudhoe Bay Site: PB DS 11 Rig Name /No.: DOYON 16 Spud Date/Time: R Rig Contractor: DOYON DRILLING INC. UWI Rig elease: : Active Datum: 41 : 26 1/15/1987 00:00 @58.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description 11/12/2010 of Operations (hr) (ft) 13:15 15:15 2.00 WHSUR P RUNCMP NU NEW 4 -1/1B PROflL1CTLON_TREE._. TEST TREE W DIESEL TO 250 PSI FOR 5 MINUTES AND 5000 -PSI FOR 5- MINUTES. -CHART BOTH TESTS. -GOOD TESTS. -BLOW DOWN LINES USED TESTING AND SAME. 15:15 16:00 0.75 RUNCMP " WHSUR P SECURE WELL. INSTALL ALL TREE AND WELLHEAD JEWELRY. ND ORE = SI. TREE. TBG = TWC. - HANG IA "TWC IN HOLE" SIGN ON -RIG A RELEASED A PRESSU AT 16:00 HRS 0 -P Printed 2/22/2011 2:02:20PM • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 KAMM JAN 4 ZO1 December 21, 2010 Mr. Tom Maunder ?1�1 Alaska Oil and Gas Conservation Commission 0;1 ±' , `'a Sion 333 West 7 Avenue , ,r Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 11 18 — O c t Dear Mr. Maunder, I l Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 11 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, API and PTD numbers, 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, Gerald Murphy, at 659 -5102. Sincerely, 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) DS -11 Date: 12/21/10 ' a Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement _ date inhibitor sealant date ft bbls ft na gal 11 -01A 1921120 50029206440100 NA Sealed NA NA 6/25/2010 11 -02 1811280 50029206490000 NA Sealed NA NA 6/25/2010 11 -03A 1911520 50029206660100 NA Sealed NA NA 6/25/2010 11 -04A 1940230 50029204800100 NA Sealed NA NA 6/25/2010 11 -05A 1961570 50029206700100 NA Sealed NA NA 6/25/2010 11 -06A 2042250 50029206740100 NA Sealed NA NA 6/25/2010 11 -07 ` 1811770 50029206877000 NA Sealed NA NA 6/25/2010 11 -08 1842290 50029212450000 NA Sealed NA NA 6/27/2010 11 -09A 1 961 280 50029214020100 NA 25 NA 42.50 6/29/2010 11 -10 1851590 50029213940000 NA 5 NA 28.90 6/30/2010 11 -11 1851410 50029213820000 NA Sealed NA NA 6/27/2010 11 -12 1841950 50029212120000 NA Sealed NA NA 9/12/2010 11 -13A 1921100 50029212290100 NA Sealed NA NA 9/12/2010 11 -16 1860780 50029215817000 NA Sealed NA NA 6/27/2010 11 -17A 2020320 50029215980100 NA Sealed NA NA 6/27/2010 11 -18 1861120 50029216070000 NA Sealed NA NA a 6/27/2010 11 -22A 1950870 50029220356000 NA 1 NA 9.35 7/1/2010 11 -23A 1940810 50029216100100 NA Sealed NA _ NA 7/1/2010 11 -24A 1932040 50029216230100 NA Sealed NA NA 6/26/2010 11 -25A 1990820 50029204880200 NA Sealed NA NA 6/26/2010 11 -26 1 1861340 50029216280000 NA 1.9 NA 5.10 6/28/2010 11 -27 1861480 50029216380000 NA 3.5 NA 11.90 6/28/2010 11 -28A 2000950 50029219580100 NA Sealed NA NA 6/28/2010 - 11 -29 1940250 50029224660000 NA 0.2 NA 1.70 6/28/2010 11 -31A 1961830 50029225090100 NA 1.4 NA 6.80 6/28/2010 11 -32 1941310 50029225120000 NA 6.7 NA 59.50 6/30/2010 11 -33 1940900 50029224900000 NA 0.5 NA 2.55 6/30/2010 11 -34 1941380 50029225160000 NA 0.5 NA 3.40 11/27/2009 11 -35 1940650 50029224760000 NA 0.6 NA 5.10 6/30/2010 11 -37 1961740 50029227160000 NA 4 NA 42.50 7/1/2010 11 -38A 1982160 50029227230100 NA 2.1 NA 22.10 6/28/2010 • I OT ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSER`QA'nON COMMSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. NOV P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 11 -26i 1 Sundry Number: 310 -368 Y Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, Qp Daniel T. Seamount, Jr. Chair QQ DATED this - day of November, 2010. Encl. STATE OF ALASKA ALASK)OL AND GAS CONSERVATION COMMISON i ' ro APPLICATION FOR SUNDRY APPROVAL I A 20 AAC 25.280 ( O N , 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ® Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 186-134- 3. Address: ® Service - ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 21628 -00 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 11 -26i Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028325 ° I Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10945' - 8968' 10891' 8920' 10135' None Casino Length Size MD TVD Burst Colla Structural Conductor 110 20" 110 110 1490 47 Surface 2 13 -3/8" 2 2492' 4930 267 Intermediate Production 10936' 1 9-5/8" 10936' 8960' 6870 47 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10733'- 10779' 8777' - 8819' S -1/2 ", 17# L -80 10151' Packers and SSSV Type: 9-5/8" x 5-1/2" BKR SB -3 packer K Dnd and SSSV 10031'/ 8147' TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑Exploratory ❑Development 19 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 10, 2010 ❑ Oil ® WINJ - ° ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564 -5444 Printed Name David Reem Title Engineering Team Leader Signature � <�i� � � Phone 564 -5743 Date /0 /p Elizabeth Bar 564 - 4628 Commission Use Onl Conditions of approval�N tify Commission that a representative may witness Sundry Number: ❑ Plug Integrity El BOP Test El Mechanical Integrity Test ❑ Location Clearance I , ,� yDoo y Other: 'iAMCEIVED OCT 2 9 2010 RR oil & GPIs Cons COW.1, Subsequent Form Required: � Q _ � 8 Y �?xt� . �l;4I011 Anchorage APPROVED BY � Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Rev n � Submit In Duplicate ORIGINAL /7-& V b p G% dr - fm&rxv 11 -26i Rig Workover (Repair production casing leak) Scope of Work: Pull 5 -1/2" L -80 completion, change out 9 -5/8" casing packoffs & tubing spool, run and cement 7" scab. Run new 4 -1/2" L -80 completion. MASP: 2520 psi I Well Type: Water Injector Estimated Start Date: November 10, 2010 Intervention Engineer: Hank Baca Pre -rig prep work: S 1 Pull 5.5" PXN @ 10,135'. E 2 Set 5 -1/2" composite bridge plug @ - 10,115'. Jet cut tubing @ - 9,996' Cut desired to be 10' down i full joint above the packer. Reference tubing tall 1/3/87). F 3 Circulate out the well with seawater. Diesel freeze protect to 2000'. Ensure IA is dead with seawater. CMIT to 500'si for 10 min to verify a barrier. Last LLR was 1.3 gpm @ 2500 psi. — W 4 Check the tubing hanger and casing 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. O 1 5 11 Set a BPV in the tubing hanger. 1 01 6 1 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU Rig. ND tree. NU 4 Preventer BOPE with annular, 7" fixed, blind /shear, mudcross and 3 -1/2 x 6" VBRs. Pressure test pipe and blind rams to 250psi low /4 high (annular to 3.. 500 psi) 2. Pull and LD 5 -1/2" tubing string. - 3. Dress 5 -1/2" stub. C� 4. Run and cement 7" scab (with overshot) from 4000 -9996' <<gf &461 f- 1# 5. 5. ND BOPE and tubing spool. Change 9 -5/8" packoffs & replace tubing spool. ' 6. NU BOPE and test breaks to 250 /4000psi . 7. Drill up 7" float equipment and composite bridge plug. LDDP 8. Run 4 -1/2" L -80 TC -II tubing completion with packer at 9,850' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test Tubing & IA to 4000 psi. Freeze protect to 2000' MD. 11. Set TWC. ND BOPE. NU and test tree. RDMO. I I MCEVOY GEN 4 F*AFETY NOTES IDatum iEAD = MCEVOY IATOR = AXE -SON 1 1 =2 6 ELEV = 58' ELEV = P = 1 900' x Angle = 48 @ 3900' tum MD = 10823' 2216' 5 -1/2" CAM BAL -O SSSV NIP, I TV D = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2502' Minimum ID = 4.445" @ 10135' 5 1/2 " OTIS XN NIPPLE 10031' 9 5/8" X 5 1 /2" BKR SB -3 PKR 10135' 5 -1/2" OTIS XN NIP, ID = 4.455" 10135' 5 -1/2" PXN PLUG (09/08/09) 10150' 5 -1/2" BAKER SHEAROUT SUB 5 -1/2" TBG -PC, 17 #, L -80, 0.0232 bpf, ID = 4.892" 10151' 10151' 5 -1/2" TUBING TAIL 10148 ELMD TT LOGGED 07/31 /87 PERFORATION SUMMARY REF LOG: BHCS on 01/28/87 ANGLE AT TOPPERF: 26 @ 10733' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10733 -10754 S 08/25/89 3 -3/8" 6 10760 -10780 C 04/25/96 3 -3/8" 4 10763 -10779 C 09/21/89 PBTD 10891' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 10910' TD 10945' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION WELL: 11 -26 01/15/01 SIS-MWH CONVERTED TO CANVAS PERMIT No: 86 -134 01/18/01 SIS -MD FINAL API No: 50- 029 - 21628 -00 10/10/01 RN/KAK CORRECTIONS Sec. 28, T11N, R15E, 4200.07 FEL 1205.45 FNL 10/01/09 CJN/SV 1 SET PXN PLUG (09/08/09) BP Exploration (Alaska) TREE = MCEVOY GEN 4 11-26 AFETY NOTES WELLHEAD = MCEVOY J _- _- _ ACTUATOR = AXELSO ELSON *PROPOSED KB. ELEV = 58' BF. ELEV = KOP= 1900' 2000` 4 -1/2" HES X NIP, ID = 3.813" Max Angle = 48 @ 3900' Datum MD = 10823' Datum TV D = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2502' Minimum ID = 4.445" @ 10135' 5 1/2 " OTIS XN NIPPLE 7" x 9 -5/8" liner hanger &liner top packer 7" 26# L -80 scab liner cmt'd from 4000- 10,000` 4 -1/2" x 7" HES TNT L -80 packer 4 -1/2" 12.6 # /ft, TC -II L -80 tubing 5 -1/2" UMI overshot 10031' 9 5/8" X 5 1 /2" BKR SB -3 PKR 10135' 5 -1/2" OTIS XN NIP, ID = 4.455" 5 -1/2" TBG -PC, 17 #, L -80, 0.0232 bpf, ID = 4.892" 10151' 10151' S 1/2" TUBING TAIL 10148" ELMD TT LOGGED 07/31 /87 PERFORATION SUMMARY REF LOG: BHCS on 01/28/87 ANGLE AT TOP PERF: 26 @ 10733' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 4 10733 -10754 S 08/25/89 3 -3/8" 6 10760 -10780 04/25/96 3 -3/8" 4 10763 -10779 09/21/89 PBTD 10891' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 10910' TD 10945' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/87 ORIGINAL COMPLETION WELL: 11 -26 01/15/01 SIS-MWH CONVERTED TO CANVAS PERMIT No: 86 -134 01/18/01 SIS -MD FINAL API No: 50- 029 - 21628 -00 10/10101 RN/KAK CORRECTIONS Sec. 28, T11 N, R15E, 4200.07 FEL 1205.45 FNL 1 10/01/091 CJN/SV I SET PXN PLUG (09/08/09) BP Exploration (Alaska) 1~`1f~~~ L~~.? ~~~~~~~~ gl: PeoAcrive DiAgNOSric SeevicES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and Jr~a~~~~ r ~ is ~ ~ ~~~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 /3C~ ) g01~9 Fax: (907) 245-8952 (~-t-C /~~0~ 1) Leak Detection - WLD 06-Nov 09 11-26 2J Signed Print Name: 1 BL / EDE 50-029-2 1 62 8-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL . 5~ _~ __ ___, _ WEB$ITE ~_~ _ W_ ":`~Dociunents'and Settings`,LRane WCtliams+Desk:op\Tcansrtut_BP.docs .~=. ¡h: f~ i ~j f:: Ù Schlumberger ~J=B 2 è'"t, ",. ~ ... ~. . 'J .~ .r;.;~-" ö ~' L ¿iJUÜ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth A~~~~~~~ '_'oJ, ¡:: ¡ ];~:;,sJaJ Well Job# Log Description Date BL 13-31A .,)05- ¡/.DO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B -:905 -Of'.(/, 11057071 SBHP SURVEY 12102/05 1 NK-43 ¿¡61-CO I 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /CN - C'S7 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A Iq,~~C57 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 I €-d.c·- I 3 4- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 J 9~·· /51- 11098756 PROD PROFILE WIDEFT & GHOST 01/30/06 1 L5-05 )~7-C(cC¡' 11058541 RST 11/11/05 1 Z-29 iM -C("r.C;- 11051081 RST 08/10/05 1 L5-09 fC¡C -/~ 11090725 RST 11/11/05 1 15-44 ,qú - I f () 11194155 RST 01/15/06 1 C-20B ";¿O{- I 14- 11075913 MCNL 08/29/05 1 02-14A Q03 4/~5 11075901 MCNL 07/29/05 1 Z-21A ';;01- iO 1 11076449 RST 06/30/05 1 F-27 A c905-1é(4- 10928641 MCNL 09/01/05 1 MPH-15 .!)c15 - /59 11076486 USIT 12/15/05 13-31A 'QC5-IIßÖ 11133211 SCMT 12/23/05 WGI-04 17'1 - e5C- 11183461 USIT 01/26/06 WGI-04 1"7 q - C' st'. 11211566 USIT 02/03/06 WGI-08 I'iC'" o4q 10987559 USIT 01/02/06 WGI-08 ¡ero - C4'1 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNEÇ FES Z 8 2008 Date Delivered: ...... I ---........... { 0 . :..;/ r~ /" . (-/' 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK99501 Field: Prudhoe Bay Color CD 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by 6[ßQoö.) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS-11 06/08/03 John Cubbon Chuck Scheve P.T.D.I1861340 Type test Notes: 4 year AOGCC witnessed MITIA WellI Type Inj. i P.T.D.I Notes: WellI Type Inj P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: Packer Depths (ft.) I Pretest Initial 15 Min. 30 Min. ~'~Wl ~0'0~'1 ~'~'1 Tubingl 1650l 16501 16501 16501 Interva'~4 Test psiI 20371 I Casin~l 2001 2490l 24501 24501 P/FI P I Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0608_MIT_PBU_I 1-26.xls CANNED AUG 0 ! 2003 -26 (PTD #1861340) 4 year MIT1A Subject: 11-26 (PTD #1861340) 4 year MITIA Date: Tue, 10 Jun 2003 13:39:44 -0500 From: "Cubbon, John R" <CubbonlR@BP.com> To: "Jim Regg (E-mail)" <Jim Regg~admin.state.ak.us>, "Win-~on Aubert (E-mail)" <Winton Aubert~admin.state.ak.us>, "Bob Fleckenstein (E-mail)" <Bob ~leckenstein~admin.state.ak.us> CC: "NSU, ADW Well Integrity Engine-er" <NSUADWWelllntegrityEngineer~BP.com>, "Cubbon, John R" <CubbonJR~BP.com>, "Anders, Joe L" <anders22~BP.com> Gentlemen, Please see the attached MITIA form for the 4-year AOGCC witnessed MITIA at the 11-26 injection well. Thanks, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 <<MIT PBU 11-26 06-08-03.xls>> MIT PBU 11-26 06-08-03.xlsl Type: Microsoft Excel Worksheet (application/vnd.ms-excel) ]Encoding: base64 1 o fl 6/25/2003 11:37 AM ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Randy Ruedrich DATE: June 8, 2003 Commissioner Jim Regg r/~¢1 61¢_.~'t(3~UBJECT:BPxMechanical Integrity Test P.I. Supervisor ~'"~' I ~ DS 11 11-26 Chuck Scheve PBU Petroleum Inspector NON- CONFIDENTIAL Welll 11-26 I P.T.D.I 186-134 I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI , P.T.D. I Notes: P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I'"t rv 'l TypetestI P I Testpsil 2037 I CasingI 200 I 24901 24501 24501 P/F I P Type Inj. Type test IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. 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 I traveled to BPXs DS 11 and witnessed the routine 4 year MIT on well 11-26. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed with the well demonstrating good mechanical integrity. M.I.T.'s performed: 1_ Number of Failures: 0 Attachments: Total Time during tests: 1 hour cc: MIT report form 5/12/00 L.G. 2003-0608 MIT PBU 11-26 cs.xls 6/24/2003 SCANNED JUL 0 9 2.803 ALASKA ..... · AND GAS CONSERVATION CO ~" ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing -~. Repair well Other 2. Name of Operator ~,RCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 334' FSL, 205' FEL, Sec 28, T11 N, R15E, UM At top of productive interval 1445' FNL, 1225' FWL, Sec 28, T11N, R15E, UM At effective depth 1225' FNL, 1081' FWL, Sec 28, T11N, R15E, UM. At total depth 1205' FNL, 1069' FWL, Sec 28, T11N, R15E, UM. 5. Type of Well Development Exploratory Stratigraphlc Service ORIGINAL 6. Datum of elevation(DF or KB) 58 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-26i 9. Permit "number/approval number 86-134 10. APl number 50 - 029-21628 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10945 feet 8967 feet Plugs(measured) PBTD Tagged @ 10849' MD (4/20/96). Effective depth: measured 10849 feet true vertical 8881 feet Junk(measured) Casing Length Size Conductor 80' 20" Surface 2502' 13-3/8" Production 1091 O' 9-5/8" Cemented Conductor Rpt not received 2500 Sx CS III & 400 Sx CS II 600 Sx Class G Measured depth Trueve~icaldepth 110' 110' 2530' 2491' 10936' 8959' RECEIVED Perforation depth: measured 10760 - 10780' true vertical 8800 - 8818' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10151' MD. MAY 2 8 1996 Naska Oil & Gas Cons. Commis$io~ Anchorage Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 10031' MD; 5-1/2" Camco BaI-O SSSV @ 2216' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation - 5482 Tubing Pressure 773 Subsequent to operation - 6635 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run . Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 865 Service I W Injector :orm 10-404 Rev 06/15/88 Title Sr. Area Operations Engineer Date ~ -/~' -~'~ SUBMIT IN DUPLICATE 11-26i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 4/20/96: RIH & tagged PBTD at 10849' MD. 4/25/96: MIRU & PT equipment. Added Perforations: Reperforated: RIH w/perforating gun & shot 20' of perforations as follows: 10760- 10763' MD (Z1B) 10779- 10780' MD (Z1B) Ref. Log: BHCS 1/28/87. 10763 - 10779' MD (Z1B) Ref. Log: BHCS 1/28/87. Used a 3-3/8" carrier & shot 6 spf at 60 degree phasing at balanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to Seawater injection & obtained a valid injection rate. ]996 GeoQuest 500 W. Interl~ational Airport Road Anchorage, AK 99518-1199 ATTN: 5herri~ NO. 10223 Company: Alaska Oil & Gas Cons Comm Attn: Howard Oakland 3001 Porcupine Drive Anchorage, Al( 99501 6/4/96 Field: Prudhoe Bay Job # Log Description Date BL RF Sepia . Anadrili Anadrill Anadrill Survey Program Performance _ Calculation Letter TEMPERATHRE OVERLAY PUMP-IN TE~VIPERATURE SURVEY · ! PUMP-IN TEMPERATURE SURVEY , PRODUCTION PROFILE LOG :DUAL BIJRST TDT-P · I PERFORATIhlG RECORD .... PERFORATIHG DEPTH CONTROL :INFLATABLI~ BRIDGE PLUG . ,.TUBING PATCH RECORD PERFORATli,.JG RECORD TIJBING PATCH RECORD .. TDT-P BORAX LOG PERFORATIOH RECORD PERFORATIOH RECORD 960429 960430 96O43O 960503 960504 960425 951108 951108 951120 951123 951117 960429 951111 951112 TDT-P BORAX LOG 9 6 0 4 2 8 I I ~':~i! '::SIGNED:; _ ,~,~ '-:i; iia '!li i!!i-!:Please~ sign and return one copy of this transmittal to Sher'rle at the above address. Thank you. DATE: DATE' t ~;,.- 2_5.... ? i F,.:EFEF.:ENL':E' AF:,'CO [.'.ASE:D H[)L.E FINALS 'I N._t P R []1:: i L.. E PROD F'R[]F:ZLE I N. i F:'F.:[)F/(.i.F.:/-'rE:N,"~. :[NJ F'F..'OF Z LE :1: N d F' R 0 F' i L..E PROD F'ROF ILii" I...EAK i;, E: :i': ~-~G-T .... LEAK DiE1'E(]T F' I:;.: 0 i:." F' F.: C!I:: ]: L E: F' i':.'. [) D F' F.: O F I L Ii.'-. iL i-'i: A I< i) E:'i" E C T F'R 0 ~)P F.: O F: i L E C. t:;.: / [:.' C i... (.-i.A;~: LEP, K Di:_-TECT L E A i< i) E T E: [:: T F'i...E~qSE SiGN AND F;.:ETURN TI'~E AT"I"ACHE:D COF:'Y AS t-;..'ECE:I:F'F [.if:' )}A'i'A,. i'-iAV!i:_' A N SONYA WALLACE A 'F [1.. .... i ~..,-._ .", c, :01 S T F..' ]: B Ij T I 0 N '~' CENTRAL F'rLES '"' CI-I~::",," F:O N · i.i·~._ ,~ · L"'., & N '"- t~!:Xi"E:NS -I r~N E ×i::'LOF..'A'i- 1t' ~ EXXON i'iARAi'HON ~ HOE:IL F:' F! il I... 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' . ~-~:~'.-' ·..... ?..-_ ....-..~ _~-. ~,,.,,,~ ..:~.~.~?-.~?~...~.,~??...~.. . ,....~ . ~ ... ~..:. ~.~.: .~. , ....-:.~,-~ ...~' ..:?-,'-.. · ~. CHEVRON ... ..: .... .....,.:...,: ......... ~EEE.~~- ... ' .-' .' "-.~ ~':" EXTENSION EXPEORAT~ON--.,...-'~.~ '. ~PX ',. '.."' : ..'.' ~ .,;~' ~.~,-... '..'.~,~...?,.~.:,~. - · ~-' ' .' '":~.': -'"- ~ _-'- EXXON ~'./' ~- .":?'?-" ;..~..~,.' ';~'-.~.~; .::-_, ,; ~ ./.~TATE OF ALASKA '. ~-"~ ~ ' '.' ...... ~ ;'. ;L:. _.' ;;. ;~.. % .... :z'~. ~:-_~.;~' . - ':, - ', .: ~LL .'~..:_~.~;~.,:'~..¢,,~L.;~,A~..:~;~. ..... -..T~X~CO' ~: ' - ' "~""~'~" ~'~:',' '~' .... '~' ~''"';''~'~'~' ' ~~'~'~ ' .... . .. , '.. ",,..~ .... , ....... '..4~ ': ......... '..... · ......... ; ~ -.. .'~~-~-.~.' . .., .,. :......~.,.: .,.. ..... .,..........,..,. ,.... :.....::. :~..~. ~:.. ¢;.~...:?.~:~?~..(.....,........:,.. ¢...~ ....:. :, .....? ,?:y;..:~.,...,.....~:,;:...F,.~ 3' .,2" . .: .... ....:...... .... ,......~ :.....': ..... ~. ~.?..:_ .,' .~ ......... ~..... .: :.. ~ g~..._~;,-~. ~:,~..;. (~ ,.~..~~. · -. ..................... '- .~:::-;~r:~'-,"~-~: ':-.:.'~g'~,~'~'. ....... ?.?' :,n~r~,~:r,'~g~ ~',~.~"¢~ ~: ...... ?":: ;~:&-~ ...... : .... ~.%~4 ":'*' ~,-'"'r '~ ~'~2'"~:~"?':~ '" ' '~'?:""'""'-"~ '. ' ' · ~ ...~ ·· .... · ..... ,. · · ~ ..... ~ ..... ~' ~ - '. · . · · ~ . - , · ~..} ~ ,-.. r~ .......... , , ~ .......... . ......... . ...... ~ .................. ~ ...... ~ ..... ' '.' ' ..~ ..".' -~.'. 2 ," :..' . ....... :.."'"~;',~;.?...~'.;" · ".. '...'-. '.' -~ ,' " 2? ,'' :.. ' . ~..~"..',..- ~o~ "'.'.'2..." .-'' ~"~ ?' '.-'~"~-~ ~'~K-' '.:~?~W?:-~'A~"~?~~''~'' '~-?-~'~,.-!...".:,' ? ~,?,. ?-?%, '~'~.~..,~'~-',;'.~',,~'.<'~ '?'-.. ~-~-'--~-~.'. ~. -~' ~. - · ', . · . ' ,~ ,{~ :~.~'~ '~ ~- . · /. ',.. ~,' ,. . ~-:. . ., .. , ,, . .. , ~ . . .. ,, . ..... ~ . . . . ~., .. .... ~ ,. ~ .. .... . ., . , .... ~. . ~, ~.~-.., ,:.. ;~~,.~. ~-~ ...... . ...... ..... ............ , ...... .... ...... ..... ..... ..... . ........ , ........ . ....... ................ t ' · ' ,- '. ,:".., z . ;' , ~' : .' '" _ -. -- ' -:..? ?.~'~' ~,,-, .~?.,-??:'~ :'.-:- ,, ,,, "- ; .... ',- · .... , ' · :.' .... ' ' ' ARCO ALASKA, INC F'~ 0 · BOX i ANCHORAGE, ALASKA -- DATE' 9-28-90 995i0 REFERENCE' ARCO CASED HOLE FINALS i-i6, 9-5-90 STATIC TEMF' RUN i, i-26 9-5-9¢, STATIC TEMF' RUN i, '2-2 9-5-9,3, INJECTION F'R. OFILE RUN i, '~-~ 9-9-9~, iNJECTION PROFILE RUN 2-i3 9-6-90 PRODUCTION PR. OFILE RUN i, 2-'2i 9-6-9~ INJECTION PROFILE RUN i, 2-28 9-5-90 PRODUCTION F'ROFILE RUN i, 5-2 9-7-90 PRODUCTION PROFILE RUN i, 5--i5 9-7-90 PRODUCTION PROFILE RUN t 6-o-~_~ ~-4-~-~, , ~ F'RODUCTION PROFILE RUN i F't_E~SE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. RECEIVED BY HAVE A NICE DAY~ SALLY HOFFECKER ATO-i529 5' 5' 5' [;ANCO C A M C 0 L; i::.i f~ U U "",... A f'i C C CAMCO CA~'~CO CA~-qCO C A r',, C 0 CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL _~-.~:." PHZLL~'F'S F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO PF("FIVED O(:l' o I 1990 ~nchorage ARCO Alaska, Ir~~ Prudhoe r~_. Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 8, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 11-26i, Approval No. 86-134/9-667 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/BJN/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 11-26i)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA _.. ALASK~'"'hlL AND GAS CONSERVATION (' '/IMISSION ~ REPOR'i JF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 334' FSL, 205' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1445' FNL, 1225' FWL, Sec. 28, T11N, R15E, UM At effective depth 1225' FNL, 1081' FWL, Sec. 28, T11 N, R15E, UM At total depth 1205' FNL, 1069' FWL, Sec. 28, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 58 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-26i 9. Permit number/approval number 86-134/9-667 10. APl number 50 - 029-21628 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10945 feet Plugs(measured) true vertical 8967 feet Effective depth: measured 10891 feet true vertical 8919 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" Not received Surface 2502' 13-3/8" 2500 sx CS III & 400 sx CS II Production 10910' 9-5/8" 600 sx CI 'G' Measured depth Trueverticaldepth 110' 110' 2530' 2491' 10936' 8959' Perforation depth: measured 10763-10779' true vertical 8803-8817' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10151' MD Packers and SSSV (type and measured depth) Baker SB-3 packer @ 10031' MD; 5-1/2" Camco Bal-0 SSSV @ 2216' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 9715 5299 Tubing Pressure 693 1394 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~..~ ~//~ ~o¢' ~,, _,<"¢~. Title Operations Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DS 11-26i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE · INJECTION PROFILE MODIFICATION 8/21/89 · MI RU CT and Stimulation Equipment. PT CT to 4000 psi. RIH w/CT, and washed perforations at · 10733- 10754' MD Ref. Log:-BHCS 1/28/87. 10763 - 10779' MD Pumped the following treatment: 70 bbls 15% HCI, followed by, 50 bbls 12% HCL - 3% HF, followed by, 45 bbls 12% HCL. Displaced acid from CT w/ 300 bbls of filtered seawater. POOH. RD. 8/25/89 : A CTU Squeeze was performed as follows: MI RU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/340 bbls of seawater. Pumped 66 bbls cement, squeezing perforations : 10733 - 10754' MD Ref. Log: BHCS 1/28/87. 10763 - 10779' MD Put 38 bbls of cement behind pipe, at 1700 psi max squeeze pressure. Contaminated cement with 135 bbls of contaminant. Displaced CT with 40 bbls of Meth - Water. POOH. Rigged down. 8/26/89' Cleaned out contaminated cement from wellbore. 8/27/89' MIRU and RIH to tag bottom at 10879' MD. POOH. Rigged down. 9/21/89' Reperforated' 10763 - 10779' MD Ref. Log' BHCS 1/28/87. Returned well to injection, and obtained a valid injection test,' '~ ~.. ¢-: ..3,.,I,~c. ;':,': i'i". ~_~ :, !~L:;[ ; ,CO ALASKA, INC· P·O· BOX i(-}OS6(:~ ANCHORAGE, ALA~"K A 995 t 0 DATE' ~ 2-5-89 REFERENCE' ARCO CASED HOLE FINALS - ~' I1'5' ' RUN '2 " t 26 tt-t5-89 F' t-29 tt-i-?-89 F'IT.~ RUN t, 5" t-34 t i-t ?-89 PITS RLJN t , 5-2t tt-.t8-89 GR/CCL RUN t, 5" 7-i 6 t t -i 6-89 INdECTION PROFILE RUN 7-~4 tt-t5--89 INJECTION PROFILE RUN ti-g it-t9--89 PRODUCTION ~'ROF'ILE RUN t, 5' t t-t 8 t t-t 8-89 TEHF' RON t · tt-26 it-t9-89 INJECTION F'ROFILE RIJN t, t2-22 it-t6-8~ PRODUCTION PROFILE RUN t, 5' i2-3t ii-.i?-8~ INJECI'ION PROFILE/TEMF' RlJN i t4-2 tt-t8-8~ PRODUCTION F'ROFILE RUN t4-26 ii-i8-8~ PIl'~ RuN t, t6-t6 tt-t9-8~ INJECTION F'ROFILE RUN t, 5" iT-J4 ii-2~-8~ PRODUCTION F'R. OFILE RUN i, 5' t8-8 t t '~ ' -~-8~ PIT~ RUN t , 5 PLEASE SIGN AND RETORN THE-ATTACHED COF'Y A~ RECEIF'T OF DATA· RECEIVED BY~__~__.....,,~;I.i.~ HAVE A NICE DAY',' ~.~,~,~_~.~ :~AI..LY HOFrF'ECKE:R I~~'-----~ APPROVED ATO-t 52~ DEC~ ~ 1~ ,_~RANS~ 8~- DISTRIBUTION CEN'rRAL FILES CHEYRO~. D & H'"' , EXTENSION EXPLORATION EXXON~: HARATHO~ ' - MOBIL CAMCO C A M C 0 C A M C 0 CAMCO [;AHCO C A H C t] CAHCO CAMCO - CAMCO C A i,t C O C A M C O CAMCO CAMCO CAMCO CAMCO CAMCO ARCO ALASKA, INC. P.O~ BOX i~0360 ANCHORAGE, ALASKA 995J0 DATE' '9-29-89 REFERENCE' ARCO CASED HOLE FINALS 5-t8 9-5-89 INJECTION PROFILE RUN 4-S 9-t8-89 CET RUN 4-20 9-i-89 INJECTION PROFILE RUN 5-t9 9-t3-89 CET RUN 6-5 9-t~-89 LEAK DETECTION RUN 6-9 9-9-89 PRODUCTION PROFILE RUN 7-28 9-7-89 PRODUCTION PROFILE RUN t t-23 9-24--89 COLLAR/PERF RIJN tt-24 9-6-89 PRODUCTION PROFILE RUN ~ t-'>6_ 9-~-89 COLLAR/PERF RUN t4-S2 9-t~-89 LEAK DETECTION RUN t4-S2 9-2'2-89 PERF RECORD -RUN t6-4 9-t-89 LEAl( DETECTION RUN ~?-t 9-4-89 PRODUCTION PROFILE RUN t7-~ 9-8-89 PITS RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ RECEIVED BY HAVE A NICE DAY~ SALLY HOFFECKER AT0-t529 ,,Olll~l_q.~O[I A F' PR 0 V E D,,~- TRANS:~ 89~04 Anctmrage DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON PB WELL FILES D & M R & D EXTEN£ION EXPLORATION ~ BF'X EXXON ~ STATE OF ALASKA MARATHON _ ~ TEXACO MOBIL CAMCO $CH CA,nCO ~(]:1"i CAMCO CAMCO A'¥LASJ C~MCO ATLA~~ CAMCO ~'CH CAMCO CAMCO CAMCO ARCO Alaska, Inc. Prudhoe Bay ,_ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager ORIGINAL August 2, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 11-26, Permit No. 86-134 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. $cheve DF$/JMV/jp Attachment cc: T.B. Gray, BP d. Gruber, ATO-1478 PI(DS 11-26)W1-3 RECEIVED AUG o 1989 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKI~'%L AND GAS CONSERVATION Cr~--'MISSION APPLICA ,'ION FOR SUNDRY AF,-,ROVALS T. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 334' FSL, 205' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1445' FNL, 1225' FWL, Sec. 28, T11N, R15E, UM At effective depth 1225' FNL, 1081' FWL, Sec. 28, T11N, R15E, UM At total depth 1205' FNL, 1069' FWL, Sec. 28, T11N, R15E, UM Operation shutdown Plugging Pull tubing Vadance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other X 6. Datum of elevation(DF or KB) 58 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 11-26 9. Permit number 86-134 10. APl number 50 - 029-21628 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10945 feet 8967 feet Effective depth: measured 10891 feet true vertical 8919 feet Casing Length Size Conductor 80' 20" Su trace 2502' 13-3/8" Production 10910' 9-5/8" Plugs(measured) Junk(measured) Cemented Conductor Report Not Received 2500 sx CS III & 400 sx CS II 600 sx CI 'G' Measured depth True vertical depth 110' 110' 2530' 2491' 10936' 8959' Perforation depth: measured 10733-10754'; 10763-10779' true vertical 8776-8795'; 8803-8817' RECEIVED Alaska Oil & 6as Cons. CorrlrnissJorl Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10151' MD Packers and SSSV (type and measured depth) Baker SB-3 packer @ 10031' MD; 5-1/2" Camco Bal-0 SSSV @ 2216' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation August 1989 16. If proposal was verbally approved Name of approver Date approved Service Injector 17. I hereby/~ertify that the foregoing is true and correct to the best of my knowledge. Signed ~/~'~//Z~,~_~ Title Operations Engineering Manager FOR COMMISSION H~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance ~ ~ Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Commissioner 15. Status of well classification as: Oil Gas Suspended I Approval No. ~ ...- & ~ '~ Approved Copy Returned Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 11-26 CT Cement Squeeze Application For Sundry Approvals ARCO Alaska Inc. proposes the following workover on DS 11-26: 1. Perform a slickline tag run to verify PBTD and ensure wellbore is free of obstructions. 2. Perform a fill cleanout to a PBTD of 10891' MD. 3. Perform a fullbore mud acid treatment to acidize the intervals 10733-10754' and 10763-10779' MD. Place well on injection to flush near wellbore region of acid. 4. MIRU cementing equipment. RIH with CT and fluid pack wellbore with filtered seawater. 5. Pump 85 bbls of cement followed by a 2 bbl water spacer and 170 bbls of contaminant. Hold a surface squeeze pressure of 1500-3000 psi for at least 60 minutes to squeeze the following perforations: Interval Zone SPF 10733-10754' MD lB FSD 10763-10779' MD lB FSD Reference: SWS BHCS (1/28/87) 6. WOC 18 hrs. Jet or reverse out contaminated cement. 7. WOC 2 weeks. MIRU perforating company. Reperforate the following intervals: o Interval Zone SPF 10733-10754' MD Reperf 10763-10779' MD Reperf Reference: SWS BHCS (1/28/87) Return well to injection and test. lB LSD lB FSD Other Well Information Current Status: On seawater injection (100%) Expected Static Bottomhole Pressure: 3810 psi @ 8800' SS Expected Static Bottomhole Temperature: 185 °F (Rathole) Expected Fluid in wellbore at time of workover completion: RECEIVED Alaska Oil & Gas Cons. Comn]issior~ seawater Anchorage 6 5 4 3 2 COILED TUBINi3 UNIT BOP EOM 1 PMEN7 1. 5000 PSI 7" WELLHEAD CONNECTOR FLAN0£ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYD~L~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX N]RELINE BOP EOUIPHEN'I' _ 1. 5000 PSI ?" WELLHEAD CONN£C:1OR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" IrLOW TUBE PACK-OFF ,,.:...tJ AI...A~'~K A I NC I::',. 0,. BOX i 0(.)..'360 ANCHORA[~F:i, AI...A3:K A D A T E ' 5 - 2 6 - 8 9 RliLI::'EI:::ENCE' ARCO CAS'ED HOLE FINAL,.? J-'2Ef '5-6-89 PROD,, PROFIL. li£/L.E. AK DEI"EC1 ION RUN t, 2-'t I .~'--4-8'.: 'FIF. i"tF'/FrI..U.[D DEN~'-'[TY I',,'UN t ..'.~ -' .,-.. "':' 't ':" ..> -- ,,:. ":' "::~ ..: - .:8 "c' ./ C 0 [.. !.. A R / I::' lie f;: f:' R U N i , 3-9 5-~8-89 CNL_-'GAHHA RUN t , ....."z_c.~ .,':";.-. ~ 8--8~. , DIFF TEHF' RUN ~ , "Y · .:.~-.J e ..,,-,~....89 INJECT:r-ON I:"RUFII_E I¢,'!Jdf , 3 .... ~ ':~ 5"'-3-89 IN,..IECTION PROI::'I'L.E/Tri. HP RUN f , · 1-2 5-.-20-89 CNI_-GAHHA RUN J , 4-5' 5 .... ~9-89 CNL-"GAHHA RUN ~, 4-'? 5-t 9-89 CNI_-~AHMA RUN ~ , 4- f ~' ~' ~" . .,. ..,-..>-..89 INJECI'ION I::'ROF'J:LE F.--tLIN t , 4-.2~ 4-i-89 COI_.I_AR/PERF RUN ~ , 4-26 ..,':~'-t 8-8~;', CNI.-GAMHA RLIN t , 5-!5 3-2'?-89 COI_I_AF:/PEI;tF RUN t , '5- J ? :~--29-89 COL. LAR/PIERF F~tUN ~ , 7-.30 '3-~ 7--89 DUAL BUR$'r 'l"D'r-I:' RUN ~ , '7-:30 5-i 7-89 CNL. RLJN t , 9-28 3"-3~-89 COLI_~R TO ::~E'I' F'~TCH RUN t, i t "'i 0 .5-i (')'"El'? LEAK DEIECI"ION RLIN i , tt-26 '."5-5-89 T-NJECTION PROFTLE/TEMF' RUN t, ~8-1 5-8-89 FLUID DEN,.?TTY/I"EMF' RUN i, t8-9 5-8-89 F'I_[JID DE:NS"[TY/TIEMF' ' ..... RUN t, t 8-23 S-26""89 COI. I. AR/F'ERF RUN t, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF"r [)1::' DATA, C A i"i C 0 C A H C 0 I I... H ,.~. AI'I...AS: A '~' L.A 5' C A f,l C 0 C A t,~ C 0 A FL_A;~' A l" I... A ;~;' A i' L A ;S' C A t,i L; 0 HL.Z n 'I'L.A,S' 5' C F'I HL~ CAMCO C~MCO C A M C 0 CAHCO I-IL3' REECE]:VED BY HAVE A NICE DAY! .S;A LI... Y HOFFECKER ATO- t 529 DISTRIBUTION CENTRAL FILE? ~ F'H i LI.. I-' F'$ CHEVRON F:'B WELl_ FILE.$' D & ii R & D EXTE~'ION, EXF:'LORAT I ON ... ~' BPX EXXON ~ ~ ~ ,~'I'A"I'E OF ALAS'KA MARAI'HON ~' l EXACO HOBIL ; ALASKA., INC.. .L1. BOX tO0~GO ANCHORAGE, ALASKA 9951 DATE' t - t 9-89 REFERENCE' ARCO CASED HOLE FINALS -~._o] i-ii-89 RIC$/RATO F'DK/CNL OVERLAY*5' RUN i 2-213 I -t t -89 PDK-t ¢,¢~/CCL/GAMMA RUN S-6 i~-~-8~ MULTIRATE INJECTION F'ROFILE RUN i S-i2 t-i2-89 VERTILOG RUN i, 5' S-i'~ i -t (:)-8o. , I'UB IN6 CUTTER RIIN_ , 4-5 i~-'~i~ -88 F'RODUCTION PROFILE RUN ~-~ i i-28-88 EPILOG RUN ') q" 7-~5 i~°-')2-88~ LEAK DETECTION RUN i, 5' 9-!¢ i~ 26-88 INJECTION PROFILE TEMP ~URvEY RUN i, ii-26 i-tS-89 COLLAR/F'ERF RUN i, 5' i.-~-i ~. i ._~-22-88 F'RODUCT I ON F'ROF I LE RIJN_ i PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 TRANS ~:89 ~:' :'-" AI-"F'I;,'O V E ~ ]~.._ DISTRIBUTION · ,,-CENTRAL FILES · .-'"' CHEVRON D & M · ~ EXTENSION EXPLORATION · ,,-'" EXXON MARATHON ~ MOBIL F'HI LL IF',S' F'B WELL FILES R & D SAF'C STATE OF ALASKA T. EXACO A 'T'L A S' ATLAS CAMCO A 'T'L AS" ATLAS CAME:t] ATLAS CAMCO CAMCO ATI_A.? CAMCO i--i r:':', ",,/!::' ,".'.'-, ?g '.:." [-: !::' T:.-' ;;':; Y: !::" F:' f'(..- f'-; Y f:; F:' i'.J i"-J F!' "~:" "i" . . : ,.:-:,..r c, ..... ~ ,::...- :.,,,-:..;- r::-, i::, !::'. !::-., c~ ',,' ii' ¥'.', ................................................. JtJ'~l I 198B 'r.--, 'r ::-:."¥' !:;, ~ ,,..; ~ ~:: r"..., i,...~ _A_l~.ska .Oil & Gas Cons. Commission ----~-,-<-_Anchorage .. Telecopy No. (907) 276-7542 February 4, 1988 ADMINISTRATIVE APPROVAL NO. 213.13 Re: Injection profile waiver, Rule lla, Conservation Order No. 165 D F Scheve Operations Engineering Manager ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Mr Scheve: By letter dated January 29, 1988, you requested a waiver to Rule lla of Conservation Order (CO) No. 165 for Prudhoe Bay Unit (PBU) well DS 11-26. DS 11-26 is producing from 37' of perforations in. Zone lB of the Sadlerochit Formation. Since all production would necessarily enter the well from this zone, a productivity profile as required by Rule lla of C0165 is not needed.' Therefore, the Commission approves your request to waive the_~prod~ction profile required by Rule lla of CO165 in PBU well~~When additional zones are perforated in the well and produced concurrently with the lB zone then a productivity profile will-be required. Lonnie C Smith Commis s loner BY ORDER OF THE COMMISSION jo/3 .AA213 ARCO Alaska, Inc. Prudhoe Ba~ .gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager January 29 , 1988 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re- DS 11-26 Permit Number- 86-134 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours',. D. F. Scheve DFS/BLS'sd Enclosures cc' Standard Alaska Production Co. File Pl(DS11-26)W1-3 " ARCO. Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ""-'-, ALASK~ ,.)IL AND GAS CONSERVATION COMM;__,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate I~. Pull tubing [] Amend order ~ Perforate~ m Other [Z] 2. Name of Operator ARCO Alaska~ Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 334' FSL, 205' FEL, Sec. 28, T11N, R15E, UM At top of productive interval 1445' FNL, 1225' FWL, Sec. 28, T11N, R15E, UM At effective depth. 1225' FNL, 1081' FWL, Sec. 28, T11N, R15E, UM At total depth 1205' FNL, 1069' FWL, Sec. 28~ T11N, R15E, UN 11.Total Present depth: well condition measured summary 10945 feet Plugs (measured) true vertical 8967 feet 5. Datum elevation(DF or KB) 58' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 11-26 8. Permit number 86-134 9. APl number 50-- 029-21628 10. Pool Prudhoe Bay Oil Poo' Effective depth: measured 10891 feet true vertical 8919 feet Junk (measured) Casing Length Size Conductor 80' 20" Surface 2502' 13-3/8" Producti on 10910' 9-5/8" Cemented Measured depth Conductor Report 110' Not Received 2500 sx CS 111 & 2530' 400 sx CS 11 Top job w/150 sx CS 11 600 sx Class G 10936' True Vertical depth 110' 2491' 8959' Perforation depth: measured 10733'-10754' 10763' 10779' true vertical 8776'-8795' 8803'-8817' Tubing (size, grade and measured depth) 5½", L-80, tbg w/tail @ 10151' Packers and SSSV (type and measured depth) SB-3 pkr @ 10031' & Ba.l-O SSSV @ 221~' 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation N/A 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~ertify that the foregoing is true and .correct to the best of my knowledge Signed Title Operations Engineerinq Manage~Date ~/'¢7 ?z/~'t' Commission Use Only Conditions of approval Notify commission so representative may witness ~ Plug integrity ~ BOP Test © Location clearance ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned~, Approved by Commissioner [Approval No. ~/~ ._.,,~'"'-~ the commission Date~:~-J ~ Form 10-403 Rev 12-1-85 11-26/STAT17 B.L. Surritt (263-4217) Submit in triplicate In accordance with Conservation Order No. 213, ARCO Alaska, Inc. requests the fol 1 owing: Permission to waive the injection profile prescribed in Conservation Order 165, Rule 11a. Only 37' of perforations were shot in 11-26. All of the perforations were shot in Zone lB thereby eliminating the need for a spinner survey. Additional perforations in Zone lB and 2 are planned. However, the timing of the perforations is after the initial six month time period has passed. An injection profile will be run subsequent to the additional Zone 2 perforations. ARCO ALASKA, INC, P.,O, BOX 400360 ANCHORAGE, AI...A,?KA 99..54 0 DA'rE: 4 2-28.-87 REFERENCE: ARCO PRE~SllRE DATA .__ t 2-t 7-87 4 2--;4 7-87 42-t7-87 4 .:.-47-87 BHF' REPORT BHP REPORT BHP REPORT BHP REPORT F'I..EA,.~E ,.~IGN AND RETURN THE AI'TACHED COPY A,.~ RECEIPT OF' DATA, RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT ATO-~527 Gas Cons. TRAN~ ~877G6 APPROVED DI$'FRIBUT.1;ON CAMCO CAMCO CAMCO CAMCO CENTRAl., FII..E~ CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIl_ F'H I I...I... I F'$ PB WEI...I... FII..E,~ .. ~APC STATE OF ALASKA TEXACO 99~t~ DATE: tt-9-B7 REFERENCE: ARCO Cased Hole Final. t-3 9-5-87 Collar t-7 8-22-87 Collar t-tt 7-t1-B7 Collar t-20 7-~i-B7 Collar 2-t2 7-22-B7 Col. tar 4-22 7-24-87 Cotter 5-4 8-2t-87 Col. l. ar 5-$ 3 7-2~-87 Co I let 5-t 7 9-23-87. Verf i I. 6-7 7-t 2-B7 Co I let 7-t t 7-t ~-87 Co [ I. ar 9-2 t ~-t5-87 Co I I~r 9-34 8-2i-87 Collar tt-27 6-22-87 Collar 1i-27 7-~t~87 Collar t2-8B 9-~-87 Cotl. ar t2-t5 9-~-87 t3-t B-3i-B7 Collar t3-t~ 9-3-87 t3-t4 8-t7-87 Collar (Perforefion lo9) (Perforafion Log) (Perforefton Log) (Perforaflon Log). (Per rorer ion l..o9 ) (Perforation Log) (Perforafion Log) (Perforafion I. o9) og (Perforafion I..o9) (Perforafion Log)- (Perforafion Log) (Perforation [.og) (Perforafion Log) (Perforafton Log) (Perforafion Log)- (Perforat i o~ 'Log) (Perforafion [.o9) CPerforalion Log) (P~..rforaf ion Log) Run Rub R~.~D R~D R~D Rub se $19n end return ~be~_~.is~/-.bed copy es receipt Received By .... HAVE A NICE DAY(I /-' · Oil'& Ga~ Cons. C0m~ssl0 ~Alas~ '- ~ch0rage Peggy ~enn~ff RTO-t 529 TR~N$ ~87606 ~ Approved DISTRIBUTION t, t, t, t, t, t, t, t, t, t, t, t, t, t, of da 11 5' 5' 5' 5' ..5' 5' 5' 5' 5' 5' Af I.a~ Af la.~ Af I.a.~ Afla~ Af ta.~ Af la..~ Af I.a.~ A~ I.a.~ Afl. ag ~ I. ag ~t I. as ~t I. as Centra I. F i Chevron Exfension Exp [oral ion Ex xor~ Marathon Hob i I. STATE OF ALASKA ' ALASKA~OIL AND GAS CONSERVATION t, OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-134 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21628 4. Location of well at surface 9. Unit or Lease Name 334' FSL, 205' FEL, 5ec.28, T11N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1504' FNL, 1236' FWL, Sec.28, TllN, R15E, UM 11-26 At Total Depth 11. Field and Pool 1264' FNL, 1080' FWL, Sec.28, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 58'I ADL 28325 ALK 2323 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 01/15/87 01/:30/87 07/:31/87'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD} 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10945'MD, 8967'TVD 10891 'MD, 8919'TVD YES]~] NO []I 2216 feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/BHCS/GR/SP, FDC/CNL/Cal/GR, FMS/GR, EWR/CNP/GR, Gyro 23, CASING, LINER AND CEMENTING RECORD , . SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Z0~ ~l.b# H-40 Surf ' 110' :30" Conductor Report not av,,ilable 13-:3/8" 68.0/72.0# K-55/J-55 Surf 2530, 17-1/2" 2500 sx CS Ill & 400 sx CS II Performed top job w/150.sx CS II 9-5/8" 47.0# L-80 Surf 10936' 12-1/4" 600 sx 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) 10734'-10755'MD 8778'-8797'TVD 5-1/2'' 10151 ' 10031 ' 10764 ' -10780 'MD 8805 ' -8819 'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF~ MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO iTEST PERIOD I~ . Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 10 psi 24-HOUR RATE I~ . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. **Note: Well would not flow. Currently scheduled to be a future injector; no injection to be attempted for approx. 6 months. OC"i'',~r'" 9 '~"sb... 7 *Note: Drilled RR 2/1/87. Tubing was run 2/4/87. Well was perforated 7/31/87. Al~sk~0ii&6asc;0~s'f~°mmissi( Form 10-407 WC:3/76:Dani Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FOR'MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochit 10285' 8373 ~ N/A G0C 10590'-10596' 8648'-8653' Base Sadl erochit 10779' 8818' 31. LIST OF ATTACHMENTS Addendum (dated 7/21/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge : (),,?~.')'.' .. .(.L~/.>/JL .~ Title Associate Engineer //0-~:~-~_'~7 Signed H~,: 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. Item 28' If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ALAS,.A OIL AND GAS CONSERVATION CON. ,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. '. 3. Address Post Office Box 100360, Anchora~ie, AK 99510 4. Location of well at surface 334' FSL, 205' FEL, Sec. 28, T11N, R15E, UN At top of productive interval 1445' FNL, 1225' FWL, Sec. 28, T11N, R15E, UN At effective depth 1225' FNL, 1081' FWL, Sec. 28, T11N, R15E, UM At total depth 1205' FNL, 1069' FWL, Sec. 28, T11N, R15E, UM 5. Datum elevation(DF or KB) 58' RKB Feet 6. Unit or P~'~[~'~lYO~,a~c~y Ullit 7. Well number DS 11-26 8. Approval number 7-454 9. APl num(~L~)_21628 50-- 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10945 8967 feet feet Effective depth: measured 10891 true vertical 8919 feet feet Plugs (measured) Junk (measured) Casing Length Size Conductor 80' 20" Surface 2502' 13-3/8" Production 10910' 9-5/8" Cemented Measured depth Conductor Report 110' Not Received 2500 sx CS 111 & 2530' 400 sx CS 11 Top job w/150 sx CS 11 600 sx Class G 10936' ~ue Vertical depth 110' 2491' 8959' Perforation depth: measured 10733'-10754', 10763'-10779' true vertical 8776'-8795' 8803'-8817' Tubing (size, grade and measured depth) 5½", L-80, tbg w/tail @ 10151' Packers and SSSV (type and measured depth) SB-3 pkr @ 10031' & Bal-0 SSSV @ 2216' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-BblGas-Mcf 0 0 Well died; would not flow current!~shut-i n Water-Bbl Casing Pressure 0 0 10 Tubing Pressure 0 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run © 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~ ~)~.~~'~--~ Form 10-404 Rev. 12-1-85 Title Operations Engineering Manager Date SN ll-26/STAT16 B.L. Surritt (263-4217) Submit in Duplicate(~ Summary of Operations Began perforating operations on 7/31/87. RU perforating unit, pressure test equipment. RIH w/gun #1, shot interval 10763'-10779' (4 spf). Well open, slight positive pressure. POOH, all shots fired. RIH w/gun #2, shot interval 10733'-10754' (4 spf). Wellhead pressure 0 psi. POOH, all shots fired. Well open, no liquid flow to surface. RD. Shut-in and secure well. Ref: BHCS 1/28/87 ADDENDUM WELL: 6/12/87 thrU 7/16/87 11-26 Inject reserve pits w/cumulative total of 89,483 bbls dn well. Drilling Supervisor Date ~ALa_~ka, Inc. · Box .~chormge, Alaska DATE: August ii, i~787 REFERENCE: ARCO F're~.i~lre l>a+.a i t -i 6 ?-25-8? i t-25 8-2-87 i i -26 F.)-2-87 i t-27 8-2-87 ' i2-26 7-25-87 Static Gradi HP Pressure Survey Log HP Pressure Survey Log HP Pre~sure ;~urvey Log Static Gradient Run t Run t Run t Otis Sch Sch Sch Oti~ F'kem_~e sign and return the mifmched copy a.s receipt of data. Rece i red By HAVE A NICE DAY) Rosanne Peek ATO-t 52~) I'RANS ~874iZ5 ~ Approved~ DISTRIBUTION Central Fi les Chevron I) & M Extension ExpLoration Ex xoll Marathon Hob i ~ F'hi ttip~ F'B W~il FFle$ R & D Sohio State of ALaska Texaco ARCO Alaska, In(/'-```. Prudhoe Bar Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 20, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 11-26 Permit Number: 7-159 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve Fo~l),~5~eu[ DFS/BLS-sd Enclosures cc' Standard Alaska Production Co. File P1(DSll-26)Wl-3 .IUL 2 1 1987 Alaska Oil & Gas CODS. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~-~ STATE OF ALASKA AL/,. A OIL AND GAS CONSERVATION-CO, ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown D Re-enter suspended well ~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 334' FSL, 205' FEL, Sec. 28, TI[N, R15E, UM At top of productive interval 1445' FNL, 1225' FWL, Sec. 28, T11N, R15E, UM At effective depth 1225' FNL, 1081' FWL, Sec. 28, T11N, R15E, UN At total depth 1205' FNL, 1069' FWL, Sec. 28, T11N, R15E, UM 5. Datum elevation (DF or KB) 58' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 11-26 8. Permit number 9. APl number 50-- 029-21628 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical 10945 feet 8967 feet Plugs (measured) Effective depth: measured 10891 feet true vertical 8919 feet Casing Length Size Conductor 80' 20" Surface 2502' 13-3/8" Production 10910' 9-5/8" Junk (measured) Cemented Measured depth Conductor Report 110' Not Received 2500 sx CS 111 & 2530' 400 sx CS 11 Top job w/150 sx CS 11 600 sx Class G 10936' ~ue Vertical depth 110' 2491' 8959' Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 5½", L-80, tbg w/tail @ 10151' Packers and SSSV (type and measured depth) SB-3 pkr @ 10031' & Bal-0 SSSV @ 2216' Oq,' . Ata.~a Oil & Gas Cons, Commission 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation July 24, 1987 14. If proposal Was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed2~r~ 2, !~~~_ '~,~,.<~k6o~ Title 0peration~ Fng'inmpr'ing Manager Date 7/2~/'~7 Commission Use Only Conditions of apProval Notify commission so representative may witness I Approval No. [] Plug integrity © BOP Test [] Location clearanceI '/ Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Rig (?~-4717~ Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 11-26 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. Upon perforating, the well will be fl owed for cleanup. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10733'-10754'MD 10763'-10779'MD Ref: BHCS 1/28/87 ~RCO ALaska P~O. Box i O(~,S6(~ Anchorage, I)AI'E' JuLy i6, t987 REFERENCE' ARCO Ca~ed Hole Fina~ '~- S-9 7--i 2-'87 CET ' '-~ 5- i 7 5-22-8'7 Vet ~ i I_ og ' '- i i-'i 0 7-i 2-87 CEI' '- -'tS-2i 7-tS-87 Spinner F'rofi ~e R~n i, Run Run Run Dress S c h Pi_ease sign and return the attached copy am' receipt of daSa. Received By HAVE A NICE DAY! Rosanne Peek AT0-i529 TRAN$ ~-87369 Approved ............ = ................................ ~YS~' DISTRIBUTION Alaska Oil & Gas Cons. Commission Anchorage '"' CenTraL F'i Les 'r · .-'"' Chevron D ,_*.,. M ~-'"'Exi'en.sion Exptorai-ion ~: Exxon H a r a i- h o n · "'~,- M o b i. L -..~ F'hi LLips F'B Wel. I Fi Les R & D -.-~ Sob i o '"',.$*ate of ALaska · .-'"' lexsco '~-- STATE OF ALASKA -~ ALAS .... OIL AND GAS CONSERVATION COM~ .,5SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate FI, Plugging ~ Perforate [] Pull tubing GYRO Alter Casing ~.' Other 2. Name of Operator ARCO Alaska~ Inc 3. Address P,0, Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 334' FSL, 205' FEL, Sec.28, T11N, ELSE, UM At top of productive interval 1445' FNL, 1225' FWL, Sec.28, T11N, R15E, UM At effective depth 1225' FNL, 1081' FWL, Sec.28, T11N, R15E, UM At total depth 1205' FNL, 1069' FWL, Sec.28~ T11N~, R15E~ UM 11. Present well condition summary Total depth: measured 10,945 'MD true vertical 8967'TVD 5. Datum elevation (DF or KB) RKB 58 ' 6. Unit or Property name Prudhoe Ba), Unit. 7. Well number 11-26 8. Approval number 7-159 9. APl number 50-- 029-21628 10. Pool Prudhoe Bay Oil Pool feet Plugs (measured) None feet Effective depth: measured 10,891 'MD true vertical 8919 ' TVD feet Junk (measured) None feet Casing Length Size Conductor 80' 20" Surface 2502' 13-3/8" Production 10,910' 9-5/8" Cemented Measured depth Conductor Report 110'MD Not Received 2500 sx CS III & 2530 'MD 400 sx CS II Top job w/150 sx CS II 600 sx Class G 10,936'MD' True Vertical depth 110'TVD 2491 'TVD 8959 'TVD Perforation depth: measured None 12. true vertical None Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail @ 10,151' Packers and SSSV (type and measured depth) SB-3 pkr ~ 10,031' & Bal-O SSSV ~ 2216' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inj, ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments ~ Daily Report of Well Operations ,.~ Copies of Logs and Surveys Run ro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~.~ --' /~- ~)7 Signed Form 10-404 Rev. 12-1-8 Title Associate Engineer (Dani) SW02/8 Date ~'~ 87 Submit in Duplicate March 3, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70013 Well: DS 11-26 Field: Prudhoe Bay Survey Date: February 03, 1987 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-$un/N L Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 AR C 0 A L A'.S K A :, i N E:. l:::'RU].'iHOtii:; B/.'>~ ¥ F::fi.. A'.!ii: KA VERT I _..HL. SEC:]" I ON ('::AI'i.C.LI[i~:~4~:T~F-7~LCtNG '! ........ ' .v ' M E A :!:&. Ri.E I) DI:i:'F TH ANC:HCIF;:A(.':~E A L..i'-:~',SI.::iA I]ATE C'!F '.:7-.;LIRVEY FEBRUARY 9'-' t., .;,, 1987 ...................... LI.. (:i!;:?II:7:'.!:::FT'ATZ I;).!:,! EIA.!7..E ............................................ : B__L]_'!i.:,;~__~; i~ ¥ RLtoL, U.P I _. cURVE¥ . t:::[ii:Ji:..::F:::UAR'f ()4.: :t.'!;)E:7 ,..lOB ,") i<F[LL, Y BUSHING E:]_.[i'_'V = '=',"', C;r; I:::'"i" ............................................ TRUE ~;I tB' SE:A L.J_tUb,.::,[: C OI::.tF;,' S E R ]:..:r r:: At._ VE.;RTI C'i~i[[ .... "ii-i~i~ii'[['i[:~;:'7:J:::i[:i!!i:i(F' .':'i'i[]' [~i:ii:'C.'f::f' [Oh:i-' Bt:i:'F 'T].,i DEI"-':'I"H DEG ; MI Iq . O I',.t ~:'i~: 0" E O, 00' ! 0(), (')'F~ ":', O0 ,.~: ,... -.,,...,. -.,,.~ ~,t L), :~,(..~ 200,, O0 i 4-2, 0() () 1.4 S 81, F3'ii;' W. 0 ,: 32 0, ,,.:, :l. ::, · ::o,:::: ,,',:",o 2.,::i..::?';:~ 'i';:B ...................... ii:; .... ? ..... s "T"i;;,':'il;i:? '~ [:~: ............. '::; ':' !:?-~[ ........................... 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E' ~. 54 8.6.1. :F: 'P. 06 [iL d` [~} 1. d,'P 4 2 N 2'9. :5:(") W 16':'.:' 1 4 '.'-." 5 ~= · _,._, N J.'P W '741. 1.5 7 -T.,-:, -'.- N 37.60 '%::.-,,--~,/:4 ..... ............. .:> ........... '5 ........... F,~ '-4 .'-.~,E''' o' :3 .I ()C:, C' '1 :}:: :I. ,", c :3:2:(30 :2 ::i: ,,".'- ,:' , :340 0 3600 :3".-::' 0 (.: .. 4-0 c:, 0 41 4200 4300 4400 4 5 0 ( .~ 4800 5000 5 ]. ,."~ (5 5:1i'0.', -..J C) - . , _ :7::7. ~::: !'~. !::'.,. ? :';:::;;:...=!..'! .,~. ~.:'~J::: k:.,,.~ ANE.:HCff:~AGE ALASKA DATE OF. SURVEY, FEBRU~RY 03, 1987 CC~MPLJTA]:'IOI'4 DATE . i:::'Ii.:.':BRIJAF;:Y C)-":I-:, :['3':i!i:7 ...1(')[:.4 Nt.J. MBI:ER Af'.-"BC)'::iXC.!.(i!.:;!..i;~! ....................... ......... KI!i:'L..I....Y BL.I:!.:.';H]:NG ti:l....F.'i3.?, :-':: f.":a!:::,(':C~ t:':'"i",, ............................. 0 P E R A T 0 R-"1" ,, M (.': I.:ii I...I ]: I:;,' E · ., UB ..... 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"x20,::) .. ()0 :2'i775.72 N .3:'.:;'65. :26 W 16'?,:':,, 9 :L 2'::;' ,, OC, 7::.:.:('.~0,, 00 302'4,'20 N" ' :.~4::-:0, O(i '~4 .......... 'i ?~!5', 5::~: ....................... ~i',~ 6'.'--": ......................... 7;,I-00, 00 307."2,114 N 34'.:'.,'2, 80 N 1753. O0 27.4.7 r-:~RC:O AL. ASI<A,, D'.'T:; t ].,-:;;it 6 ..... .~. .:.... .................................................................................................................. t:::'A ]: NC:., DATE: ............." (IF F:;I IRVE'Y 'F'EDRI IAR Y ()~, :1 ,'",c','-~:;,o., C:(]MF'LI TAT I OF.I DA TE t:::'i~:::EJl..;:t...t~)~t::<~'' o/t. :, :t. '?:F;7 .. ("fB iqL.iHk)[~::F;: Ai<'-'.BO-:'7001:3 : ' ' ';~ :'.,: :.:'; :::~ .::':~':: k. ::' -j 1'". I~- ~ t ~ ~ i" . . ',~,,:, t'NTERF'OLAT'ED ' VALL!E:3 Fl]IR EVEN 100 . ..... 'T' 1::,:: ~.,.I i:~: S LIB--SE ~:'~ "1" 0 T' A I.,. {~[::~ :" r-," ....... J. · ~'~ ' { I ';' ~', ''" ...... ' "~ -~ ....... '"" z~ , ' '"- ~'~ '",'"" ............. '"' :'. '... 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"= 1 ':' 7© ................... :,.., W 188,S, ~5'2 :::::.'::~ F:; ::..: .. ,:') () 'B 2, O,:) ,, C~ 0 :2, 494. ,. 9 ::::; N :':}',',g 4 Y~5~ A :2 (.,J 19 l ,.'). e, l :[ I. 4- ',B,:':!-~YC~ ,. :::~0',~?, ,':!. ,:) C:, .. 00 :B~5::~/i-'.. ~5:B N :3:~:'72. :3Y[ !.,,1 I '~':::-: 1 ,~ 4:B :10, :32 ......................................................................... :.BA.~;~:5, O0 8600 ,, O0 ':B614, ~::.=: N :3926 ,, 0:3 W 1. 94:3 ,, ~5.4 11.06 '""7 =;'::'. C) (') :q'Y () O , O () .'-':, (:,' ,.,. ~= '=., ~ ~50 f~..~ "" '" :' 49 W 1 ':) =[ 4 ,, 6, 9 11 1 E; '::":"::;':::' ("~c~ :::F:~O000 :'~:F.,S;'F-,. 44- N .Bt4"/'d:, :32 W I '~F =; 7~:' 11. 10 ]:'? :~:J, ~3 ~ 00 '? ? O,:'::,., ,:'} 0 :B 7 ?, 7~ 4:3 Fi ~:l. ()O :'3, '7 :B ~,.~ 1 '? 7 d:,. :~: :2 11.. 0 'B F:','76'7 ~ 17 'C:'70'? .. '!. '?' :B';'41. :1. 9' FI 4006, O~, kl :t. ',q'Y'Z. 8:3 I. O 1 'I'HE C:AL.C:LtLg:~TION PROCE:DLIF,'ES U:Z;E A LINE. F, '( INTERF, OLATiON BE:TWEEN THE NEAREST 20 F'CK.'.iT MD (FROM RiqDIi ':' _. _ I.:, OF F:!.IRVATIIF,'E) F'O/NT.'_--; A L.., A S 'K A ANCHORAGE~ A L.A::]-;KA ............................................................................ DATE OF' :3IIRVEY FEBRU(4RY [....:,, 'I; o7 ;,.., .,. , , ,]..) ,::,~,-., ........................... ~ ~ E!:?!f::.!?.]':o:r.;[ !:;!,i';-! 5:),!~.Tg F::'E:'f'3F:;:UAF:;,'Y' ()4., :t. 5;'07 ,..iCIB NUMBER AI<"'"BO-¢'O()_1:3 . "'./:Iii-"..i... ":,;' 'E','i..li~.~ ILi'i'NG [!!LE:i./"~' ........ i';; ........... !!j'i~i'","i]','":, 'i:::'::1:' ,, .................................................... o F::' F:: R F:'~ "t: (] F:;,'- T ,, M C (:.:i I...I I Fi E D.=, :I.' 1.=- 2,:?:, Di.:i:l::,,':i v t':.t t...t"ii i:t'qi::i[ ]:::i'll .... !'3E~t'::"Tt I:iJi; ;:'~N~']! :!.:.'; F:' fS: F:;; F:~ "/ :i.:.;Libl i-~LiF:;::,,'E:Y ~......,..:,: .,. /-, =:::.. 7.: ¢.:; ., . ,.. i. o::ii3,:-, ' ::ii: .:;!: ¢:ii= ,,' ,,.!:, 4 s:::?!7o ,, " ...... : x3'i ................... Jiiiiiii::ii':;', '" i': :". 73 ;::;"" : .... . ..... ,:,-=,::':,.-':', "i,-: . '-::.:., .' 3' ;:,.' .................... ........ "' ................................ :::;',~7"::' ;; '" :':=;;:.:7': ..................... ::;.;:.:-ti-... -.~:'.,/:..,.,:¢..,~i~ 1 () :,::: U !:::, ' E: :.:: '7 ::.~ , ','30 8:31 q-, Eft') :3500, 79N :38zi.?, 55W TOI=" Z 0 I',.IE 4 ....... rf~E~-P!?,,~ TL-.~F' Z F N t:'{ 2 GA'.3/O I L CONI'ACT GA:.:i;/0 :[ I.... C:ONTAC:T GAS/OIl .... CONT'(-:,C:'T GAt:ii}" i:.)] l... C:Oi'~I"f"A(." ]" "f'(.]P ZONE i i':i~ ilia :~i;tJ:!7 :iii, [:'-'~ .[.il... E![ F:;: I[.) t.'..: i..-t :[ ']' F'LUG BACI< 'f'B TOTAL DEPTH DR:[LLER .... ::,._,, ,= .... :,UN ::_=:'.:.'~0 :!.......?_?J:,l. (3 Aifi:/; il) ]:' ji.i'. ' Ci3 N"[: ?ii:".'T:' ........... 'f i':i !:i:; ':;? i'::, .................................................................. 'i!!!i'/:., z~. '7 ,.:":, :1 --,:" ..... ;'''~ 7:,;.., ;'::;;.',, ,:::,;'":;.. ........................................................................ :?,:.!:, .1. 0 ,, ,{:, :3 F,I ".'!:'.;;':2:? ,. :i. 0 'f!.;'i;:." .~. r!..?, ,,.'.,:, 4-',i~:, 5 :t :E, !..;'i;',' (), 51. ::ii:,'.':, :1. O ,, '? 9 N 3'?;' :2:2.5 ,:'.I~ W .1 ':') '::"; '? :;i: :3,:¢:, 4 '.:.;' ,, .q ]. :;i::5'? :i. ~ zi. 1 ::.:.:,'.?:, ]. 1 ,, :3,St",i :::: 'i;:' :;:.' ::i!: , "7 Z;"t4 :1. ;")....'=; .......... ,=/-'::: :z: ,:., .~ c.~ ::ii: :[ '"',::, ....,':' "'::/.~:'-. :3 i :361:1., 7:2 N :3924,0:t W ~... , ~:::~. ~;~ ,'"~ ~:.~-. :l. 0594 ,::,c .... 1,, ..:1 ,=,._, ;~..:,, 21 :3612, ()';Tdq :3924.2.5W i (') F;':? F:; ':::' ,'.. F-] "::, ], :[ -', ~'- · ."', ¢: . ........... :: ..... ;~ 4, 11 c, .:, 1 .;. ,.',1. !SN :39:24- 4,=,""W ............................................................................................................... ] .... ,=.,-... , .......... :'., ':'-," :!ii', ,:::', ':';i :? , ;".'.... J ;]i:', ':'". ,:.""' ' =,,, 0 ]. :3 ,:!:, ]. 2 ,, ',? 5.!: r,,l :3 '~.:, 2 .,:] ,, '1. 0 '72 ,':1:, :.::: ';;:' d:, 9 .. 9,'.::. ~i}i: Z :1, :I. ,, '.:.?/.-:, :3 ;b ~.'-, 0 ,, :2: E:'N .'5i, !;; 5,5 ,, ] ,"~'7";?,:..' ........ ;~.'i::~f::l.',";' ,:.:.,,'.!', ;!!i'. '"" ':::' ""'; .... ::.', ,'!:,/:, :': /- ":~ '::;' '::;'('q',~ :;f::'::'":":" ............ ,:'*,":,1.,,I .............. ' '_.~' . ................... ' ........... ::.....= :;. ': "..:; ..2'.. '~ .............. " .:;'.:': 1,3 ::q':.? :[ '-'":~ ,54 ':,' 7'=' 1. '2 &, N 5: 9' 95:70 W ........ =, :: 1 :.'7.: :':: 860,54 ........... I (')'_-='4'.=i F:: qv':, 7" I '7 """- - '-. . ....... ,z, ;,'(_) :..' 17 3741. 19N 4006., ()6W ]. ) F:'ROH i... ]; ' '""' '" _. . - i',IE:.~4R Ex'r'RAF'OL:.A"I"ZnN BF.."[ Ol,,,J FE=.':E:I::'EST sT~;'t' i: oN ,, ' ............................................................................................................... '-') COI'IPLITER t='ROGRAM :.'-sPERRY SUN THREE i' .e_. " i "- ,:. -- E l HEN,.., l ONAL RA~ I LIo OF CURVATURE, [)A'TA- CAL. r::LILATION AND INTERF:'OLATI'ON BY RADfI_IS OF CURVATURE . . COMPI._ITATION DATE FE:E~Rt. IARY 04, 1 ;,,~ 7 dOB NUH. BEI~ . AK----BO--- 7 O01 '.2: .K'ELL¥ BUSHINA EL EV :'= .=;E:.O(3 FT. I SPERR7 -SUN .. $C~ILE _ _ 1894~ '-% . -. _ . . : LOOO. O qRCO RLRSKq. !NC, =68Rdq~ 03, :987 ~3C'S. OO -..% SPFP, Rv --S ;.J N SCALE : - ~ INCh TO 2COO. CC / 20130. C _ _ =g=8dq~': 0= -:996;.. ! . _ 10945 "NC .987 STATE OF ALASKA '"'"' ALAS,,., OIL AND GAS CONSERVATION COMI,. .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown ~' Re-enter suspended well ~ Alter casing ~ Time extension © Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc, 5. Datum elevation (DF or KB) 3. A~dre~s. . Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 334' FSL, 205' FEL,' 5ec.28, At top of productive interval 1070' FNL, 1240' FWL, Sec.28, At effective depth 1102' FNL, 1102' FWL, 5ec.28, At total depth 1081' FNL, 1086' FWL, 5ec.28, 11. Present well condition summary Total depth: T11N, R15E, UM T11N, R15E, UM (approx.) T11N, R15E, UM (approx.) T11N~ R15E~ UM (approx.) measured 10,945 'MD feet Plugs (measured) true vertical 8948'TVD feet RKB 58' 6. UnitorProperty name Prudhoe Bay Unit 7. Well number 11 -26 8. Permit number 86-134 9. APl number 50_029-21628 10. Pool P'rudhoe Bay 0il Pool None Effective depth: measured 10,891 ' ND true vertical 8901 ' TVD Casing Length Size Conductor 80' 20" Surface 2502' 13-3/8" Production 10,910' 9-5/8" feet Junk (measured) None feet Cemented Measured depth ~ueVerticaldepth Conductor Report 110'HD 110'TVD not received 2500 sx CS III & 2530'MD 2491'TVD 400 sx CS II Top job w/150 sx CS II 600 sx Class G 10,936'MD 8940'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail ~ 10,151' Packers and SSSV (type and measured depth) SB-3 pkr ~ 10,031 ', Bal-O SSSV @ 2216' 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation February, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge // ~ ' Title A,~-*r~¢.~ ~-,, F,,¢,~ .... Signed ~,~~L.~ ~ . Commission Use Only . ) $A2/07 Conditions of approval Notify commission so representative may witness( [~AI~III Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date ~-12-~7 Approved by ._ Commissioner the commission Date :..~" Form 10-403 Rev 12-1-85 Submit in triplicate - ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first WednesdaY' after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or b gh .... [State Alaska Alaska North Slope Borough Prudhoe Bay ADL #28325 - I Title Drill & Complete Auth. or W.O. no. AS1029 Parker #141 50-029-21628 Operator IARCO W.I. ARCO Alaska, Inc. 21.66% Spudded or W.O. begUnSpUdIDate 1/15/87 [Hour 1500 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 1/16/87 1/17/87 thru 1/19/87 1/20/87 1/21/87 1/22/87 20" @ 110' 1350', (1240'), Drlg Wt. 8.8, PV 12, YP 46, PH 8.0, WL --, Sol 4 Accept rig @ 0800 hfs, 1/15/87. NU diverter sys. 1/15/87. Drl 17½" hole to 1350'. Spud well @ 1500 hrs, 13-5/8" @ 2530' 3173', (1823'), TIH Wt. 8.7, PV 4, YP 3, PH 9.5, WL --, Sol 3 Drl & surv to 2545', 10 std short trip, C&C, POH. RU & rn 1 jr, 13-3/8", 68#, K-55 csg & 63 its, 13-3/8", 72#, L-80 BTC csg w/FS @ 2528', FC @ 2448'. Cmt w/2500 sx CS III & 400 sx CS II. Displ using rig pmps, bump plug. ND diverter. Perform 150 sx CS II top job. NU & tst BOPE. TIH, DO cmt & flt equip + 10' new formation. Conduct formation tst to 13.5 ppg EMW. Drl & surv'12¼" hole to 3173'. 1719', 5°, N35.9W, 1718.79 TVD, 9.44 VS, 7.73N, 5.60W 2096', 16.7e, N50.7W, 2088.95 TVD, 80.70 VS, 57.43N, 56.70W 2469', 24.0°, N53.9W, 2436.09 TVD, 215.55 VS, 141.27N, 163.68W 2795', 29.1°, N47.2W, 2727.58 TVD, 360.77 VS, 233.92N, 276.47W 3111', 41.1°, N49.7W, 2986.11TVD, 542.07 VS, 354.32N, 412.56W 13-3/8" @ 2530' 4865', (1692'), DD Wt. 9.2, PV 4, YP 3, PH 8.0, WL NC, Sol 7 Drl, DD & surv to 4865'. 3390', 44.5°, N47.9W, 3190.82 TVD, 731.15VS, 3705', 45.9°, N47.9W, 3412.78 TVD, 954.32VS, 4049', 47.0°, N46.1W, 3649.57 TVD, 1203.63VS, 4583' · 40.8° N49W, , 479.18N, 555.19W 629.03N, 721.03W 798.89N, 903.82W 4045.08 TVD, 1562.09VS, 1055.87N, 1153.75W 13-3/8" @ 2530' 6414', (1549'), TIH Wt. 9.3· PV 3, YP 3, PH 8.5, WL 31.2, Sol 8 DD & surv to 6414'. 4897', 39.6°, N49.3W, 4284.91TVD, 1764.17VS, 1188.57N, 1306.94W 5536', 39.1°, N47.2W, 4777.28TVD, 2170.70VS, 1460.38N, 1610.22W 6331', 43.9°, N39.8W, 5374.05TVD, 2695.25VS, 1842.13N, 1969.88W 13-3/8" @ 2530' 7290', (876'), Drlg Wt. 9.2, PV 7, YP 4, PH 9.0, WL 15, Sol 8 DD & surv to 7290'. 6801', 44°, N45.SW, 5712.14 TVD, 3021.56 VS, 2081.98N, 2191.71W 7149', 45.2°, N48.3W, 5960 64 TVD, 3265.71VS, 2248 62N, 2370.41W Date I Title 3110187 Drilling Supervisor see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporfed on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequenlly than every 30 days, or (2) on Wednesday of the week in wtiich oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field I County or Parish Lease or Unit Prudhoe Bay ADL #28325 Date and deptll Complete record lor each day while drilling or workover in progress as of 8:00 a.m. Alaska 1/23/87 1/24/87 thru 1/26/87 3527.34W 1/27/87 1/28/87 1/29/87 1/30/87 North Slope Borough IState Alaska no. 1-26 13-3/8" @ 2530' 8290', (1000'), Drlg Wt. 9.6, PV 14, YP 7, PH --, WL 10.4, Sol 10 Drl & surv 12¼" hole to 7892', POOH & chg BHA to drop angle. 8290'. 7459', 45.7°, N49.3W, 6178.31TVD, 3485.90 VS, 2394.01N, 2536.49W 7801', 46.2°, N49.0W, 6415.88 TVD, 3731.19 VS, 2555.08N, 2722.44W 8146', 46.2°, N49.7W, 6654.67 TVD, 3979.40 VS, 2717.45N, 2911.22W TIH, drl to 13-3/8" @ 2530' 9615', (845'), Drlg Wt. 9.8, PV 22, YP 14, PH 9.5, WL 6.6, Sol 11 Drl & surv 12¼" hole to 9348', POOH. RIH, rm f/9100'-9348', drl to 9615' 8429', 41.0°, N49.7W, 6859.61TVD, 4173.82 VS, 2843.68N, 3000.06W 8742', 39.2°, N49.7W, 7099.91TVD, 4373.61VS, 2973.40N, 3213.03W 9264', 37°, N43.3W, 7507.50 TVD, 4698.36 VS, 3184.47N, 3461.42W 9433''-34.8°, N40.2W, 7644 40 TVD, 4797.32 VS' 3258 46N, 13-3/8" @ 2530' 10,169', (554'), Drlg Wt. 9.7, PV 21, YP 14, PH 10.0, WL 4.0, Sol 11 Drl & surv 12¼" hole to 10,169'. 9,746', 31.1°, N38.4W, 7906.90 TVD, 4967.03 VS, 3390.38N, 3635,31W 10,064', 28.1°, N35.2W, 8183.40 TVD, 5122.61VS, 3516.15N, 3729.40W 13-3/8" @ 2530' 10,925' TD, (756'), Circ Wt. 9.8, PV 15, YP 10, PH 10.0, WL 4.0, Sol 10 Drl & surv 12¼" hole to 10,925' TD. 10,064', 28.1°, N35.2W, 8183.40 TVD, 5122.61VS, 3516.15N, 3729.40W 13-3/8" @ 2530' 10,925' TD, (0'), Logging Wt. 9.8, PV 18, YP 12, PH 10, WL 4.2, Sol 10 Circ, 25 std short trip, C&C, POH. RU Schl, log DIL/BHCS/GR/SP f/10,921'-10,200', FDC/CNL/CAL/GR f/10,800'-10,200', FMS/GR f/10,800'-9700'; cont w/GR to 2530'. 13-3/8" @ 2530' 10,945', (20'), Rm'g ¥ Wt. 9.9, PV 21, YP 11, PH 9,0, WL 4.4, Sol 10 Fin logging GR to 2530' RD Schl. RIH, rm, drl f/10,925'-10,945",~20 std , short trip. Rm rathole. .- - ~r The.a~ve is correct S~nature Fo~' form preparq,ti~and distribution see Procedures Ma~al Section 10, Drilling, Pages 86 and 87 IOate ITitle ~J~':: (~ 3/10/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Instructiolls: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish I State Alaska North Slope Borough Field JLeaee or Unit I #28325 Complete record for each day while drilling or workover in progress Alaska ]We~ no. 1-26 Prudhoe Ba~ 1/31/87 thru 2/01/87 Date and depth as of 8:00 a,m, 2/03/87 2/04/87 9-5/8" @ 10,936' 10,945' TD, 10,891' PBTD, Standby w/crews 9.4 ppg NaC1 Rm to 10,945', CBU, POOH, LD DP. Chg & tst rams. RU & rn 251 its, 9-5/8", 47#, L-80 BTC csg w/FC @ 10,891', FS @ 10,936'. Cmt w/150 sx C1 "G w/3% KCl, 2.2% FL-28 & 1GHS FP-6L & 450 sx C1 "G" w/3% KC1, .3% CD-31, .2% A-2 & 1GHS FP-6L. Displ w/brine, bump plug. ND BOPE, NU tbg spool & lower master vlv. Freeze protect well. RR @ 0300 hrs, 2/1/87. Rig on standby w/crews. 9-5/8" @ 10,936' 10,891' PBTD, Logging 9.4 ppg NaC1 HgO Acce?t rig f/c~mpleti.on @ 1030 hfs, 2/2/87. RU DA, rn CBL/GR/CCL; irratic tl readings, POOH. ND master vlv, NU & tst BOPE to 5000 psi. RU DA, rn CBL/GR/CCL f/10,865'-9684' @ 0 psi & f/10,865'-9688' @ 1000 psi. POOH w/CBL. 9-5/8" @ 10,936' 10,891' PBTD, Lnd'g 5½" tbg 9.4 ppg NaC1 H30 POOH w/CBL/GR/CCL. Make 8.45" GR/JB rn to 10,865', POH. Rn gyro/CCL f/surf - 10,800', POOH, RD DA. RU & rn 254 jts, 5½", 17#, L-80 AB-Mod 8RD tbg & lnd w/SSSV @ 2216', SB-3 pkr @ 10,031' & TT @ 10,151'. The above is correct · . For form preparatiorl..a4~Ldistribution ~ see Procedures M~r~3ua~Section 10, ~ 3/10/87 ITitle Drilling Supervisor Drilling, Pages 86 and 87 .ARCO Oil and Gas Company Daily Well History-Final Report operation if space is available. Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire District ICounty or Parish I Alaska Field ~Lease or Unit I Prudhoe Bay Auth. or W.O. no. ]Title I AS1029 North Slope Borough ADL #28325 IAccounting cost center code State Alaska Well no. 11-26 Drill & Complete Operator Spudded or W.O. begun Spud Date and depth as of 8.'00 a.m_ Parker #141 50-029-21628 A.R.Co. W.I. ~otal number of wells (active or inactive) on this i Icost center prior to plugging and I ARCO Alaska, Inc. 21.66% labandonment of this well i Date JHour I Prior status if a W.O. 1/15/87 ~ 1500 Hrs. I Complete record for each day reported 2/05/87 9-5/8" @ 10,936' 10,891' PBTD, RR 9.4 ppg NaC1 H_O z Pmp diesel f/freeze protection. Tst tbg to 2500 psi & ann to 2000 psi. ND BOPE, NU & tst tree to 5000 psi. RR @ 1700 hrs, 2/4/87. Moving to DS 11-25. Old TD Released rig 1700 Hrs. Classifications (oil, gas, etc.) O±l Producing method Flowing Potential test data INew TO Date I PB Depth 10,945 ' IKind of rig 2/04/87 I IType completion (single, dual, etc.) S±ngle Official reservoir name(s) Sadlerochit 10,891' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The a,~b~ is correct _ Date Tithe s~ ature '~ ~)~ 3/10/87 Drillin~ Supervisor For form preparatid~d~distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO A[a!<ka, Inc. P.,O~ Box i0036(~/ .... ' Anchorage, ALaska DATE' March ~, t987 REFERENCE' ARCO Open HoLe F t t -26 t -29-87 Stra t i graph tt-26 i -~ o~ Elan Dipmet:er Run i Run i , 5' $ch $ch F'Lea~e ~ign and Received By. HAVE A NICE DAY! Rosmnne Peek AT0-i529 ,~ska 0ii &' Gas Cons, commissio-~ TRANS $87i4i Ap p roved ........... !~ DI2TRIBUTION of da ta ~ TT-F£B-8? 11114;42 PRO~RAH~ EbAN * $CHbUMB£RGER · EE&N CUSTOH£R blSTING COMPANY FIELD COUNTY STATg COUNTRY ~OGGgD AHCO AbASKA~ D6 11'26 PRUDHOE BAY AbASKA USA 72182 28'dAN'87 INC, COHPAIVy ; ARCfl At, ASKA, l~iC. I~£LL .* DS 11-26 PAGE ~NPANY A[.ASKA, .]NC. WELL : DS 11-26 PAG~ , * PU , , * 44,0 * 47.2 * 3b,1 * 32,7 * 27,b * 26.5 * 34.0 , 24.H * 28.B * 18.6 * 32.2 * 32.4 * 29.5 * 32,6 * 32.1 * 25,9 * 24.5 * 25.0 , 25.1 * 30,9 * 40,3 * 40,9 * 3§,0 * 2 * * * 25.0 * 29.1 * 14,9 * 3,1 * 30,0 8, 25.4 * * ~9.b * 0.4 * 21,2 * 1B.9 * 17 I ******************* * POR i CUM * * PDR * PU , * , * , * 1b.4 * 92,9 * 15.4 * 92.7 * 17,5 * 92,5 * 20.3 * 'q2e4 * 21.2 * 92,1 * 21.7 * gl.9 * 23.8 * 91,7 * 23.9 * 91,5 * 18.8 * 91,2 * lb.4 * 91.1 * 21,0 * 90.9 * 20,3 * 90,7 * 23.1 * 90,5 * 24,0 * 90,2 * 21,8 * 90,0 * 20,4 * n9.8 * 21.7 * 89.6 * 23,2 * H9,4 * 24,2 * 89,1 * 23.2 * 88,q * 23.2 * 88,'1 20.9 * 88.4 19.5 * 88,2 21,3 * 88.0 25.1 * 87,8 25.3 * 87.6 24,5 * 87,3 24.1 * 87,1 21,7 * 80,8 19.7 * B6,6 19,0 * 8b.4 18.8 * 86,2 23,0 * 86,0 25.9 * 85,8 25,5 * 85,5 24,7 * 85,3 24,0 * 85,0 22,9 * 84,8 22.7 * 84,6 23,7 * 84,3 23,2 * 84,1 22.5 * 83,9 23,6 * 83,6 24.9 * 83,4 25 2 , 83 2 ,****{*********{*** ******************************************** , CUM * PERM * CUM · HC-F? ~, INTRIN * PERu * &H~bE · F, , MD ' F, , PU ,***************~*************************** . · ~.~ ,~,~:~4~o~,~ , t~'~ 67, * 1 . 84148, * , 66 6 * , 83 0,6 66 5 * 2.~ 66 3 * 3, 66 ~ * 25.1 * 85918,9 66 * 17.5 * 83915.7 65 9 * 54,7 e5 ? * 118.3 * 81829.9 65 b * I12.5 65 4 * 00.6 * 8359U.b , 10.2 ~ J . ,o.~ ,~o~.~ , ,~., 6 *74.4 *B]461.1 * 6~ 0 * 170,1 * 8535~4 $ B.3 6 8 * 130,3 * 83158,8 * 11.0 64,4 * 3 ,3 * 82852.8 * , 64,2 * ,6 * 82814, * , 63,5 * 1 ,6 * .1 * 11.4 63. * 14.7 6 , ,* 81 ,1 8 * 4 * 8177 * .12,~ 62,2 * 403, * 80 4 * , , · tt.o ~,. . ~i:o · ~,~, ., 61e~ ~ 79200,~ * 8,0 5 * 789924 * 8.9 60 . I , · 78577.~ , 5.3 ~o: , ,~ ~ * ~" * ~" · **~, ~******* ************************* NY g ANCO ALA,C;KA~ /NC'. PAG£ T CC)MF'AN¥ : ARCO Al ASI.;,A, iNC. DEPTH * FT * PU 10380 * 15.7 10382 {0383 10384 10385 10386 10387 10388 10390 10391 10392 10393 10394 {0395 10396 10398 10399 lO400 10402 10403 10404 $04O5 {0406 10408 ~0410 {0411 10412 10416 14. 14. lb.~ 16. 16.92 20. 19. 17. 13, 11,~ 12.~ 1~.~ 10. i~:] 22. 23.1 ********** * P U R s PU , $ 25.9 * 2b,7 * 2b.2 ~.~ ~*.~ 25.3 25,~ ~*.~ 25.1 25.~ * 25,3 * 25.4 * 25.4 26.5 2b,8 25,4 2b,3 2b,7 25,9 25,~ 26,5 2U.4 26.3 ~.~ ~., 25.9 : ~.~ 25,7 22.8 22,5 ~.~ 22,5 ~o.~ 20,2 * I ,2 · 18 2 CU~ , CUM * PERI{ EI,'F , HC-F? · ~N'rRIN PUR q~ * FT , FT · · ************************ ~··· 72,0 * 51,{ ~ 208.2 ~'.~: ~t: : iii' 50 ,0 ~ 49, , 315.~ ,~. : 50 , · 46. 369: 45, 394. 537. : ,,. : 44,~ , 6 ~i:~ , 42, , 60 9 * 42 3 * "7 ,,,,,,i,,,,,,,,,l,,,,,,,,j~{,, 11-26 * CUI{ * VOb * · PER~ · *HkbE · · · F~ · PO *********************** , · 66612,2 * ,3 64656 63763 63254 61979 :,3 61179 6o~ :~: 575?0 : : ~o6,~ : ~ : 500~2 48948 ~ 48648 48287:~ : ~i:~: : 47819, * 47 4 * 47642,2 * 10 2 * *********************** m.."~ t"[ I mlii/*I: l,it [: I m PAGE '~)MPAN¥ : ,~RCu A[.A,.SKA, INC. ~. . WELL : DS 11-26 DEPTH, w AT · PUR * CUM * Ct. IM * P[RM * CUM * VOb * SAT * ~FF * EFF * HC F~': '~ ~N~RIN e ~ENM ******************************************************************************** 10426 t 20.7 * 17.2 * 60.7 * 42,~ ~9;0 t 4761~,4 ~v:"T 04 7 * 22,2 * 17,8 * 60,5 ~ · ' e $ B8 t {0430 , 21.2 * 22.6 * ,59,~ * 41,~ * 165,3 * 47439.8 : 10432 * 17.o * 21.9 * 59.5 * 41,2 * %39,8 * 47079,0 * 7,1 ~{0433 * lb.4 * 19.5 * 59,J * 4{~0 $' li1,4 * 469e~,~ ' 10434 * 18.5 * 1'1.9 * 59.1 * 40.~ · 93.6 e 46869.3 ~ {0435 * 19.2 * 19.1 * 58.~ * 40e.7 $ 70,7 * 46817,7 : 10436 * 21,6 m 19,2 , 58,7 * 40,B * 97,7 * 467B~,7 * 1,8 ~.' {0437 * 23.7 , 18.~ , . 58~5 * 40,4 * 24.8 , 4~725,8 , 5.7 ~ 10438 * 24.H * 18.3 * 58.3 * 40,3 * 24.8 * 46700.0 * ~.I ~ 10439 * 2b,9 * 1'1,1 * 58,1 * 40,'1 ~ i7,3 * 46669,4 -- J0440 , 24.3 * 15.9 * 58,0 , 40,0 * ~2.7 * 46657,6 ~* {0441 * 21,9 * lb.2 * 57.8 * Jg,~ ~ 20,{ * 46645,J r-'- i0442 * 20,9 * 16.2 * 57.7 * 39,8 * I8,9 * 46624,7 * ~:'10443 * 2o,2 , 10.8 * 57,5 * {gib ~ {5,.9 * 466020S ~ 10444 * 19.0 * ih.8 , 57.3 * 39,5 * 32.9 * 46580,1 * 3.8 ~.'10445 * 24.5 * lb,i * 57.2 * 39e4 * 14o8 * 46949,~ ~" 1044~ * 22.9 * 15.2 * 57.0 * 39,2 * 20.4 * 46529,4 ~" 10447 * 19,4 * 14,3 , 5b,9 , 39ol * {O,e * 46499,M ~'- J0448 * 21., * 14.3 * 56.7 * 39.0 * 22.4 * 46457.J ' 0449 * 22.1 * lb,9 , 56,6 * 38e9 * , * ~ ~ 10450 ' 21.0 * 20.1 * 5b., * 38,8 * t~.~ ' l{l{t,1 ' 5.} -- 0 51 * lb,l * 20,9 * 56,2 * , * I {e * 6 e ~.{0453 * 23,b * 17.9 * 55.8 * 3~,3 $ 40.5 $ 4~lS{eO ~ * 10454 * 23.5 * 15,0 * 55.6 * 38,1 * 22.3 * 48112,4 ,. 0 5 * 9,1 * 14,2 * 5 ,5 * , 4,2 * 0 , :'~ 0 57 * 7.6 * .2 * 55.2 * , * e' * b e * ,7 .= 9 * 22,3 * 17, * 4, * e * 9,0 * 94 e * ~ 6 * ~,5 * 17,8 * 54,5 * , e * ~50, · 9,4 * 5, * 5' e5 * e2 * 4 b , I I 6. 5 9' 5 , · 4 · *********************************** PAGE ~DMPAN¥ : ~RCO ALASKA~ INC. wgbb I DS 11-26 DEPTH ~ wA'[ * PUR $ CUM * CUM ~ : $A~ . F:FF : ~'F . H~UN ' P£R~ ZNTHIN PER# PUR $ i *, # FI FT * ,.~.~. ~ ~· ~ · ' ~:, ***,,,,,, ,, , . 51.6 * ~5070~$ -- ~o,,i.~~o.,,~.~, ~,.~, : · ..., o,~ : I~. : ~.4: ~.o , ~, , 44760,3 ~,, o4,1: I~ 25.6 50.4 *3~e9 *32b.5 ~, o4~: II'~:~.~: ~o.~ ,~,, , 0.6 0488 19. 49. , 10 · ,o,~, ,,~.~: ,~. ~. ,~ ~: ~ ,o4,,: i,.~',~.' ~: ~' : ii1 "~0499 : 12.2 47 31, 10500 , . . · 183, 41781, ".': 41359, 434. 35944. 1. . 43.7 771. ~47~. · *****,{~*****,,i*********{****,,,** ,,,,,,,,*******,,,**** ARCO ,' .. ALASKA, INC. WELb ' I D8 11-26 £PTH ,I, WA'I' * P{.)R * CUM { CUM V I}{~R PI C~ulq ~ VOL ~ ~' ~, ~ .:.~ ,~ ~., ~ :~..,~.,~,~,,,.:....,,*.....,... . ,,.,., .,.... ,,,....:,,....,,, .,,, ' . ,~. 10524 18.0 23,9 41.~ 29862,4 * ~,2 17.3 * 24.1 40,3 * y · 20352,5 * : 16.2 I 23,4 39,8 :8 ,2 t 3 ,o~, ,~.o, ~. : : {~,~.~: ~.o · 10538 { 13, 37,8 6,5 11, ~,o,~, ~: ]2:] ~,, , ~?,.6 , 9 ~. 5,1 o * 26. 36.2 21,6 $ 309,3 $ 10550 * 15,1 v 24, 34,8 ~,0 ~"t81}t: t~:~ ' ~.~: . ' . ' ~ . , 9 ~ 25, - 34,3 ,.~.....,.,~ ARCO AI,ASKA, iNC. WEbb I DS 11-26 ! . rT r , *****[~***** *******: IWW,**** ,,, , **~**** :, 10,1 $ 16,4 $ 13241, 4,7 10564 66 0568 0569 05 ? 0 72 O5'/ 058 060 060 POR ~.,,: ~. ,~.~: ~:~:~,.~ 22.7 23 * 29, 2~.~ $ I .8 2b,'l * 1~09 26.0 $ 18.6 27,2 * 19,9 26.0 * 20,0 47,0 * 18,7 84.6 * 14.6 100.0 * 12.3 79.0 * 19.? 58.6 * 23,1 40,0 * 2J,5 31,9 * 22,1 45.6 * 17.b 80.2 * 19.5 54.8 * 22,6 * 25.6 45.0 * l~,b * 25,4 41.3 * 18,5 ~.~ , ~.~ , ~.o .7 * 22.1 * 24.8 .5 * I ,2 Jb.7 * Ii,6 34,1 * 16.9 I~.5 .* 22.3 ,~..* 2e.l , 2~,4 , . * 26,7 ]~.' , ~., ,]~... .2 *24.3 :,, ~.o, .=, 26.2 * 23.9 · 2554, 2~.~: ~o. ~: . ~,o~.~: .1 : 12502. : 41.? ??,8 224U3o~ 36.9 ~3,0 15.4 '. ?7.6 I2012. : PAG~ ~£LL ~ DS 11-26 PAG~ Im.~; H&bE FT :, FT * ND .~ ! F · ,,,,t,,,,, ~u ~0620 : ~ ~ ll.l * 417.4 10621 ~ 32. 22, ~.0 ~o~2 ~ ~oo.o , 2o.5 ~ ~x. x,.? ~o.? , 40.6: ?~e~.~ ~. ~osv~: ~9. ]8,5 ]0., , ~?.~ ??~s.~: ~?.6 ?2. 18,3 10.5 * 80.7 ~0684 21. ~'~.' * 2~.~ 17.0 : 9,9 * 216.6 7&91,9 ~0686 9.5 * 671,0 '" 15.5 10687 ~ 23, 16.3 9~3 * 121.2 10688 10689 ~ 21, ~.~:~. : *~.~ 15.8 9.0 * 92.2 ~0690 ~ 19, ~o~9~: ,,.~:~.~: ~.~: .~ , ~.,: s~,~.,: ~.~ 10699 45. 14.7 804 * 34,8 5 9 25,0 lo700 : 32, 14.~ · ~o7o~ ~.~ : 2~. a.~ · ~o~.9 10703 ~ 14. 1~,0 7,9 * 112.4 ]o?o5 ~e.~ : 20. ~3.~ ?.4 , 127.o ~ ,8 a~.~ 21.4 4810,6 16,3 ~o?o~ ~. ,~., ~.6 , ~.~: 't~:~::~: ~' *~'~:~" *~'~: ,t,~.~: ~.~ ~.~: x~.4 ~.~: ~66.~: : 3596,6 3106,4 16,0 t{: Ii:~' ~ ' ' 3 * 26.~ * 10, 4 ~ · 15.R _ <*~r~MPANg : ARCO AI, ASKA W£LL I D5 11-26 PTH , ~A'l' * POR , CUM , CUM * PERM * CUM * ¥Ob · SAT 1, EFF , EFF' , HC,,FT $. INTRJN * P£R# · * * POR , * e ******************************************************************************** , , , , e , 10719 , 17.1 , 24.7 * 10.0 , 4,5 * 3]5;2 * 16'39,8 O? 0 * lb.4 * 22,6 * 9, * ~ e * 40 !g;!i: . ,.t: Io~ 3 , ~. , .~ ~.2 ,o , [ * 4 . , ~,s 10725 , 21,5 * 23,0 , , 8,5 , 3,4 * 135,7 * 450,5 ~"')~t]~: ~:~: 1~:~: ~.~: ~,~: 40.2 , ~,o.6 , ~.~ e,l J, 2,3 * 302,0 {o~e · 2~.~ * ~o.v , ~.o , ~,~ ' {2,m · {a4, · ~ e 10729 * 3~.1 * 22.1 * 7.7 * 2.8 * 32.1 · 244.~ , 16:4 10730 * 58,~ * 20,2 * 7,5 * 2eD $ 13,6 * 219 3 {0734 14,7 * 19,1 * 7,0 * 2eD $ ~,7 * 1 40 * 2 * , 7.0 177.0 0 3 ,7 20.0 * 6.0 * ,9 ~ I ,7 * 6 IU/4O ~ 1],4 ~ 12.1 * 5.3 * 1.6 * .l * 1~4.6 ~!gg~]: ~['~: ~.~: ~.~ ~ ~.~, ., · ~,,.,, ~,.= 0749 * 51.0 * 13,5 * 4- * , e · 42.6 * lb,O * 4,7 * ~ * · ~ lb ,. 10763 * 100,0 * 14,1 * 3,2 * .9 * ,1 * 111.7 ' 0 6 * ,4 .* 20,8 * 3,0 * e * 9,0 * 108 0 ~ ,. .J.. * l~, * 2.6 * ,7 * 17,4 * b $ 4608 * lb,8 * .J * , $ 3 7 $ 1 10771 * 60.7 * 12.6 * 1-8 * 3 * ' * - [0~73 * 72.1 * 12,4 * 1.6 * ,2 * .2 * 7.9 . 4 * 64 9 * 15' * I 4 * , , PAGE: 10 0799 * ARCO A[,ASKA~ INC, ~AI * 5A * EFF , PU * PU ***************** 62.5 * 14,~ 57,5 68,3 i00.o * 13.4 CUM J ,**,,~t,,~l,,.~l ,, , ~ ~:;-;" ';~,, ,****,,*i~ . i,' ~ .,, , ARCO ALaska, Inc, P,.O~ Box t0036(~ : Anchormge, ALaska 995J 0 DATE' Febru. ary 2. 4, ~oo~,o, REFERENCE' ARCO Direc~ionat Da°~a ~ ~.-26 ~ -.~ 6-8'? MWD Direc:t i o'na L ~"ur vey Te Leco Please ~ign and re~urn ~he a~ached copy @..~ receip~ of da'~a~ Ro.sanne Peek ATO'-~ 529 . I 2 1987 'I'RAN$ -~87,2~ (~ ~..~OJi & Cas Cons. Comm,ssJon Ap p r eyed ~chorage D I E T R I B U T I 0 h~ Ce¥~kra[ Fi Les' F'hi LLip.s Chevron '".,,. F'B We 1. 1. F i Les' D & M R & D Ex '~en~ i on Exp I. ora '~' i on ~ .'.';'oh i o Exxon ~- $'ta~:e of ALaska Marafhon Texaco Hob i [ Telm:o Oilflald Sa,~""'-~es of Alaska Inc. [ TELECOI to way Anchorage, AK 99502 (907) 562-2646 January 30, 1987 JOB #558 ARCO ALASKA WELL: DS-11 #26 PRUDHOE BAY 0 © . RIG: PARKER 141 - Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to ARCO. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard, Field Service Supervisor PH/el Enclosures TELECO OILFIELD SERVICES JOB 558 SURVEY CALCULATIONS Date Page 01/16/87 npany: ARCO ALASKA Li: D.S. 11-26 ~ation: P.B.U. PARKER 141 '~Er ) Job # 558 TAK .d ~orrection: lnetic Declination: ~al Correction: ~posed Direction: 31.20 degrees 31.20 degrees 0.00 degrees 315.30 degrees RADIUS OF CURVATURE CALCULATION lEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG :PTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY ~eet deg deg deg/min feet feet feet feet feet deg deg/100' ASSUME VERTICAL TO 1500 FEET ~88.00 4.2 328.3 N 31 42 W 1687.87 5.50 4.21N 3.57W 5.52 N 40.290W 3.181 82.00 6.9 323.0 N 37 00 W 1781.42 14.44 ll.71N 8.69W 14.58 N 36.594W 2.921 .42.00 8.8 316.0 N 44 00 W 1840.86 22.61 17.94N 14.01W 22.76 N 37.998W 3.539 .38.00 12.3 312.8 N 47 12 W 1935.22 40.18 30.23N 26.57W 40.25 N 41.309W 3.695 ~95.00 1.3 313.9 N 46 06 W 1594.99 1.07 0.74N 0.77W 1.07 N 46.043W 1.369 TELECO MWD SURVEYS ,0t .~0 0.0 313.9 N 46 06 W 1500.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 ELECO Job # 558 TAK 01/16/87 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' !032.00 15.5 313.5 N 46 30 W 2026.45 62.74 45.67N 43.04W 62.76 N 43.300W 3.409 !127.00 18.2 309.3 N 50 42 W 2117.37 90.20 63.88N 63.69W 90.20 N 44.915W 3.116 12' }00 20.3 309.6 N 50 24 W 2207.05 121.36 83.78N 87.87W 121.41 N 46.366W 2.213 1375.00 24.4 306.5 N 53 30 W 2348.53 179.05 119.62N 133.67W 179.38 N 48.174W 2.787 1469.00 24.0 306.1 N 53 54 W 2434.27 217.11 142.44N 164.73W 217.77 N 49.150W 0.459 795.00 29.1 313.2 N 46 48 W 2725.79 361.98 235.33N 276.81W 363.32 N 49.631W 1.840 971.00 33.3 308.2 N 51 48 W 2876.30 452.81 294.75N 345.89W 454.45 N 49.565W 2.802 111.00 41.2 310.3 N 49 42 W 2987.65 537.01 348.32N 411.46W 539.10 N 49.751W 5.715 390.00 44.7 312.8 N 47 12 W 3191.84 726.65 474.38N 553.69W 729.12 N 49.412W 1.395 705.00 45.9 312.1 N 47 54 W 3413.40 950.27 625.49N 718.90W 952.92 N 48.974W 0.412 86~)00 47.3 312.8 N 47 12 W 3521.27 1064.20 702.48N 049.00 47.0 313.9 N 46 06 W 3648.45 1201.21 796.59N 803.07W 1066.96 902.76W 1203.97 N 48.822W 0.949 N 48.575W 0.460 254.00 41.2 319.5 N 40 30 W 3795.60 1343.72 900.33N 1000.52W 1345.97 N 48.017W 3.407 426.00 42.6 312.1 N 47 54 W 3923.62 1458.50 982.62N 1080.54W 1460.52 N 47.717W 2.985 583.00 40.8 310.3 N 49 42 W 4040.84 1562.66 1051.41N 1159.12W 1564.94 N 47.789W 1.377 741.00 39.4 311.0 N 49 00 W 4161.69 1664.10 1117.71N 1236.33W 1666.67 N 47.885W 0.931 89?.00 39.6 310.7 N 49 18 W 4282.07 1763.03 1182.61N 1311.39W 1765.88 N 47.956W 0.178 LECO Job # 558 TAK 01/16/87 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG ,EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' ************************************************************************************************** 052.00 39.6 311.7 N 48 18 W 4401.50 1861.57 1247.69N 1385.73W 1864.67 N 48.001W 0.412 207.00 39.9 312.8 N 47 12 W 4520.67 1960.54 3' ~00 39.6 312.8 N 47 12 W 4652.91 2070.42 536.00 39.1 313.5 N 46 30 W 4774.31 2169.90 705.00 38.9 313.5 N 46 30 W 4905'.65 2276.20 020.00 41.7 317.7 N 42 18 W 5145.87 2479.87 175.00 41.6 318.8 N 41 12 W 5261.69 2582.73 331.00 43.9 320.2 N 39 48 W 5376.24 2688.33 424.00 44.2 321.2 N 38 48 W 5443.08 2752.71 612.00 46.0 314.9 N 45 06 W 5575.78 2885.65 8CP %00 44.2 314.6 N 45 24 W 5709.18 3019.51 J, 005.00 44.7 312.1 N 47 54 W 5854.81 3162.28 149.00 45.2 311.7 N 48 18 W 5956.72 3263.83 459.00 45.7 310.7 N 49 18 W 6174.19 3484.18 801.00 46.3 311.0 N 49 00 W 6411.77 3729.45 146.00 46.3 310.3 N 49 42 W 6650.12 3978.05 ~63.00 46.3 310.3 N 49 42 W 6730.96 4062.32 1314.33N 1459.09W 1963.78 1389.10N 1539.74W 2073.74 1457.18N 1612.37W 2173.27 1530.43N 1689.48W 2279.59 1675.95N 1752.79N 1831.98W 2482.93 1900.56W 2585.43 1833.31N 1969.33W 2690.59 1883.34N 2010.28W 2754.68 1982.33N 2099.26W 2887.30 2076.58N 2174.64N 2242.58N 2388.09N 2549.00N 2711.49N 2194.33W 3021.14 2298.20W 3163.98 2373.92W 3265.68 2540.14W 3486.45 2726.23W 3732.26 2915.47W 3981.47 2766.23N ' 2979.95W 4065.97 N 47.988W 0.494 N 47.944W 0.177 N 47.894W 0.426 N 47.828W 0.122 N 47.547W 1.238 N 47.316W 0.476 N 47.049W 1.595 N 46.867W 0.815 N 46.641W 2.559 N 46.579W 0.959 N 46.582W 0.892 N 46.630W 0.399 N 46.767W 0.281 N 46.924W 0.187 N 47.076W 0.147 N 47.130W 0.034 ~LECO Job # 558 TAK 01/16/87 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' ~429.00 41.0 310.3 N 49 42 W 6851.03 4176.42 2840.36N 3067.26W 4180.40 N 47.200W 3.193 7~ }00 39.2 310.3 N 49 42 W 7092.87 4374.28 2968.45N 899.00 39.2 310.7 N 49 18 W 7214.54 4473.16 3032.90N 056.00 39.0 307.9 N 52 06 W 7336.38 4571.63 3095.61N 3371.18W 4576.86 N 47.440W 1.132 200.00 37.7 311.4 N 48 36 W 7449.30 4660.53 3152.61N 433.00 34.8 319.8 N 40 12 W 7637.19 4798.16 3250.95N 3536.26W 4803.52 746.00 31.1 321.6 N 38 24 W 7899.79 4967.61 3382.66N 3644.07W 4972.08 N 47.131W 1.223 064.00 27.9 324.8 N 35 12 W 8176.53 5122.68 3508.01N 3737.84W 5126.17 N 46.817W 1.121 3219.11W 4378.86 3294.56W 4478.02 3439.96W 4666.08 N 47.320W 0.342 N 47.368W 0.161 N 47.496W 1.757 N 47.407W 2.466 586.00 38.7 310.0 N 50 00 W 6971.55 4276.61 2905.22N 3144.15W 4280.89 N 47.262W 1.470 0 i000 2000 3000 4000 5000 6000 7000 8O0O 10000 TELECO Oil?ield S~rvices VER ~ ~ ~ ~ , ir,~L. PROJ=C, ~ 1000 2000 3000 4000 5000 6000 ~i O.S. 11-26 ! - . ' .| ; -;--./ P.B.pU. ; .I. : -k- a~?s ·; a[~.4 o~.~ i PARKER -i4!_i - . , x: ' . . '. - i i ~ : . I I .'., '· / i ' ,"':' : ..... ~' I ':"x '-; / ................ , ....... _...: , .. : ..... ' 'NL ~ . ~ .... . 1 ? . ~ .... :.._~...:.:._~.~..,_-~,~,. ~-~-~ ---; .... ~... ~ -. ,_. ~. ~... ~--~ '~ 5705 .r 38. 9 'DE(:; · . · .~. -'r ..... ~ ..... ; .....~ - - ' ~ 58o~ '- 44. i ,_ . .Alaska '~-, ~- 78 . - t-E-CEtVE pil & Gas ,Cons. _~mmis.sion. I A'nCh°-rage- I --. TELECO 0 i I'F' i e 1 d S,~r"'v i c,~ PLAN VIEW WEST (Ft) i.!' _L~__i_'L !. ~I "_L_LI,! ~ I "[ , T--T-m---Ill l-- I il, I I ] : --' ,~, '---~ --l--f--., -i- .... I : :-!' , l _, ~ ~ , , ~ ~, . AR LIASK,~ . __J. ........ , _~. ~_N .... ,., , ,, i. _,_,,,.''" , ,-t--~ ! ,, ~ - : i--I-'~-' ~'?, ' ~! .I-~ i -,.-7-!--., . , I , . S~A.. I , ,, , . I , .-? ..... '=' ' ' 1 · · ' ,,'-~,-~ .... ~ i 'i I ~ I ! --t-= ', ---~--m, -' ,'ii i-"r"., : - -i i ; i , . i ' i T- i illi !',I, ii1 il i~ , = i '-ff' ~I-- i- -Ill-- __L i_, , , , ~ ~ ~ _,_~, ,___.,__,_, ~ , _ ,. ; I i I_I l-li! i ! i. l ~, 'T---,'~'~--~_ , --i---.--', ~ ~ I -'. -1- ' i, ..... ~ "i ~ l, t-~ ~"' I ~ .-'~ , , , , , , , 11 ~ F;ri i I , ~ · · ' f I ' ~iI I ! I I ' I / ~ I ~ ' ' ' i t .L__L , ~,.__L_J ! ~ ~ , '. i ~ ! _L_J¥,L ~ i I i 1 ,, ! ,,i,, F--~---,L-T---t-----J,---i----~J---i---~-~_i-_-'N_~.'--;---' i ' i k ' ' --i L_L.j_.~ ,t ! !_ ! ~j_..L_J__;__~..~ ,,~_EL,~_L_%._'_L_I_i. .u__~ I i i--.:':' i i --e--e--.--+----F-.'- --+--L-.+---i---t----i .... .i---~. -r ...... ,,---r~.-~-,-f---- .,-fi--"t-~, '- iFFy- · ~ . : , , . . i . , ~x,j , i 1 ----,----M--4---i - I __+.._j__j_____.i__.~ ~ ' : ~M. t : t I L I : ' . L_L_.! .... L.L___LJL_L._~ ~ i : ~---.-I i"~.?~'x"L!--I I ' ~ '" ~i-..~__ 4._-_i . i . / , I , ........ _,_ ,-T, ~ ~ T--i ,. , =' , I , ! ,¼---'t I i · ~ , I / Ii!!' ' · i i '-'-*'-r" .-r-~l _~..._. ....,,, : ~ ! i i I i i L_$_?:.__~_ l-i__j_i-!-~4__~....m..~.j_ ,~ ~~-'~r r ,'X'~ '.'-- '----r---- '+--4, _.z._~ ! ! i~ -'-F-r ~ -', ,-- ii''' F-I-,-Fii ii,,,-'i-¥:-:~ 7200 6400 5600 4800 : 4000'"' 5200 2400 1600 800 ARCO ALa.skm, Inc. - P~O. Box i00S68 Anchorage, ALaska' 99~ J ~3 DATE' F'ebr,_,ary 2 4, J987 REFERENCE · ARCO Open HoLe Fin~l.~ -26 J-~,"~°--°'"',_., I::'M$ Compo.~ i 'l:.e F'ar +. J of J J ( J C~80¢..) -26 J--29-.87 FM$ Compos'J Ce F'ar¢ 2 of J J (J(~>7(~(~ -26 J-.29-87 F'M$ Compos'J'~e Par!' S of JJ (~G68~ -26 J-29-87 FM$ Composite F'~r~ 4 of JJ (J~5~)O -26 J-.:29-87 FMS Compo~iCe ParC '5 of 1t (t~4~ -26 1-29-87 FM~ Compo~iCe ParC 6 of -26 t-29-87 FMS Composite ParC 7 of tt (t~28~ -26 1-29-87 FM~ Compo.s'tie F'ar¢ 8 of -26 t-29-87 FM~ Compo~JCe Par¢ 9 of -26 t-29-87 FMS Compo~iCe ParC -26 t-29-87 FM~ Compo~J'~e ParC -'! e600 -.i OiO0 -t 0(~00 (99~0'-98~') (9808'-.97~0') $ch $ch S c h S c h $ch S c h $ch Sch Sch Sc h $ch ~:. F'Lea~'e .sign and reCurn Che a¢¢mched copy as receip¢ of da¢a. Received By HAVE A NICE DAY! Ro~anne Peek ATO-i5°°.~, 'FRANS ~87i ~.~'~.... App¥'oved DISTRIBUTION ~ Centra !. t::'J I. es: ~- Chevron ¢: D & M $ !:: x 't e n...¢ i o n E x p L o r a i' J o n · "~ Exxon ~ MaraChon · "' Mob i L · ,. Phi L L i p.s' PB WeLL F'i Los' -,.'"' R & I) · ~' $oh i o '15' '"'-.- S~ate of ALaska -,-'"' Texaco ARCO Al.a.s'ka, Inc, P~.O, Box 'i~¥6~ Anchorage, Alaska "l' E: ' F'e b r ti_ a r y i o:., i c :,., : .,o -z, REF'ERENCE' ARCO Magnet it'_' Tapes' w/I. is'ting t-26 2--'?--87 Magtape ()1.-i (I:;.'.LL.:EWR,fS:R:ROP) HI., PLea.s:e sign anci return 't'he a'!."l:ached copy a.s rec-eip'.l: of d a 'l: ,.':l ., t:;.:ecei vecl By E HAVE A N:I:CIE DAY~ ~ · Ro.sanne F'eek ,Alaska Oil & Gas Cons. O0mmissi0n AT fl- ~ 529 Anch0ra~e 'fRANS ~:87tE>2 ~ Approved ....................................................... '- D I Z'I'R I B U T I 0 N "" ( "> ) C e n t r a L t::' i I, e ~ :~ · ,,- .-. I::'h i t. Lip s' Chevron F'B Wel. t. F'i l.e..s' D & M I:;: & D · "'.,,- ~', 'i ,', P ., M ;:. F' h e e 't- e r ~: .'~ ,..,~" o h i o .11, ~ Exxon ~ State of A La.,~ka M a r a 't' h o n "F e x a c o Mc, bi I. ARC. O ALa.s,'ka, :rnc. P,.O, Box t00S60 Anchorage, A [ca~ka 99510 P i. ea.'~e s'i g'n and Received By__ HAVE A NICE DAY! Rosanne Peek A T 0-- ~ ~' o o ret,am the a~:!'achecl copy a~ receip+, of daSa, ' - ~!~sk~~'' Oi~ ~ Gas Cons. Gummissi0~ - Anchorage f R~-.~N,s .,-,.., ,' i ..;._, ('~ Ap p r eyed .................... ~ .......................................... DI~"TRT''; I ' .,..bU 1 ION ~ Cen+.raL F:'i Les ~ Phi LI. ip.s · ".,- Chevror~ PB W~-.I.I. F:i · '".,. D & M ~ F;.: & i:) · .-'"- E x 't' e n ::-': i o n E x p L o r a .t.. i c, r., :~ ,.;'" c,l~-" i o · ,,-Fxxon ~. ,?.."ia're of ALaska · ,. M a r ca 't' h o n .,. T e × a c e ..If Hob i [ ARCO Al.a'.-:ka, Inc · I-'"~0, Bc, x i00.560 Anchorage, ALaska 99.5i0 · c-,/,,-ra.. F'ebr u.a'cv t c2 i 9 :.z r'l i E.. . .. . ~ u i' ARC. O Ope'r'~ Hol. e Fi'ha l..s ii-26 t .... 28-8'? F'NS'/IEL. AN Comp,(l~"~'~ervaL i o'f 2) 10" i t ~..,~/_.~.,, i --28-,°7.-, ...,F:'M£'/ELAN Coffil:)., ':. I r~'t'er,,,'a I. t t -.26 t -29-87 F"M.S'/EL. AN/DIF:' Cc, rap it-26 t--.29-.8'7 F~'f$/ELAN/DIF' Cimp,(In'ferval. 2 c, 1'" 2) PLease ~'ign and return the attached copy a.s receil.-,+, o1"' data, Recei red By H. AYE A NICE DAY! Ros'a'nne Peek ATO- 1 529 'T'I:,:AN,t? :Il:8'7 '~ 08 ~ Ap pro v ed ..'..j ............... !~ ......................................... D I ,f.,' T R i B U T I 0 N · ,- l::'hl L L ir.)5 F'B W e I. L I:: i L e -:'.,' ~: Re,.' D ~ ;.?oh i o ~ S'tate c:,f' A I.a.,;t,'.a -~ T e x a c o ARC;O ALa.s'ka, Inc, I::' ,. 0 ,, Bo x '! 00:360 Anchorage, A I.a.ska DATE' F'ebruary t 9, 'i91i!7 REt'-"ERENCE AI-.,'CL C.a.:'..."ed Ho I_e F ina L ~.'5-32 .¥..-.tt-86 C,.,'r"l' I) irectionat Survey Run t ~'cl'l "" ' 5" ,~c h ~4-..27 4-.~.~-.-86 CBI.. VariabLe Densi¢y Run ~, ~5--.5 4--- i 3.--86 CH CNL. Run i, 5' ,?ch ~tt-t 4--i4 86 CH CNL Run 1, 5 ~.,. o ..-" 5'c h ~-26 ~'*--°-..87~ A.,E.L.,C' /~TDt .... /~",IGN/GR Run ~, %.." I)re~ ~ ~4-72 ~2..-'2'2-..86 F'DK-.~99 Run ~, 5" Dre~ F:'Lease .s'i gn arid Received By HAVE A NICE DAY! Re_sa nne F:'ee k ATO..- t 529 TRAN$ ~.o~.~,7j~)7 ~ Approved ............ D I ~' T R I B U T I 0 N tel:urn the a1:1:ac:~! copy as' receipt: of da1:a, · ~laska Oil & Gas Cons. Gommi~si0n ....................... ~.~ Anchorage · ,-'"' C en t: r a lI::'i l e ~ Chevron PB Well I:'i D & M R & l) ~ Ex ten.:; i on Expl. ora't'ion ~'.,-Exxon '- ~ 2ta1:e Of'ALaska M a r a t- h o n :,~ T e x 8 c o · "'.,. Mob i I. 995: i (!:: ~;i .... 2. 6 i .... 2. 8 .... i!!~'7 ~i .... 26 i .... 29----87 ';: i .... 26 i .... 2 S-' ..... ~-.'i~'7 · ") it 2:::: "i II I:;' ~! A'¥' 0 .... i ~:..'-' 2 9 : C) ( .........................................................................!..~. Z(.':." i .S' ')" F--'..' ;i; B [..[ T i (;} i'--4 July 7, 1986 Telecopy: (907) 276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ~nchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 11-26 ARCO Alaska, Inc-. Permit No. 86-134 Sur. Loc. 334'FSL, 205'FEL, Sec. 28, T!IN, R15E, UM. Btmhole Loc. 953'F~, 1124'F%~, Sec. 28, TllN, R15E, UM. Dear Mr. Oostermeyer: EnClosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to co~encing installation of the blowout prevention equipment so that a representative of the Co~ission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of 'the conductor pipe. Cha iman o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COmmISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower7 --"-..~ STATE OF ALASKA ALASKA t..,_ AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill FII lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 58', PAD 28' feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL28325 ALK 2323 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 334'FSL, 205'FEL, Sec.28, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval ((¢, -~'O.f'~¢'~r) 8. Well number Number 1070'FNL, 1240'FWL, Sec.28, T11N, R15E, UN 11-26 #8088-26-27 At total depth 9. Approximate spud date Amount 953'FNL, 1124'FWL, Sec.28, T11N, R15E, UM 07/08/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 1 0,908 'MD 1070' ~ Tarqet feet 11-24 120'(~ surfacefeet 2560 (8901 'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth1500 feet Maximum hole angle40½°~ Maximum surface. 2910 psig At total depth (TVD) 3800 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" i9! .Sff H- ~'. O We~.d 89' 28' 28' !08' !08' ! 8~'. 9 ff Po~. esot 17-1/?"1'q-'q/R" '~R.O#/ ~-55! RTE' $.1 ' ??,~ 77, :C..R, ;qR' ?~QQ ~ ¢'~ I! I 72.0# L-80 BTC 2~,67' 68' 68' '25:~5' 2500' 400 sx CS II 12-1/4"9-5/8" 47.0# L-80 NS-CC 50'~' 25' 25' 5100' 4500' 500 ~x Class G 47.0# L-80 BTC 5800' 5108' 4500' 8901 '.710908' .:8-1/2" ;:7-;! ' 29.0# L-8_0 BTC -:~ 1036' 9872' 8115' 8901 '¢'~ 10908' 300 sx Class G (Continc3~ncy' Li~er-) . ' Total depth: measureo 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 Conductor Surface ~ ~ C ~!~''/F D Intermediate Production !'!i. 0 '~ 1986 Liner '-' '"' Perforation depth: measured Alaska 0il & Gss Cons. C0mmissi0p true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [~ Drilling fluid program I~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge '~7~', ~ ~~ Title R egi on al D rilli ng E ngi neet Date Signed Commission Use Only (GSW) PD/PD291 i,,. number I ,~,r~v¢~ ISle cover letter Permit Number ~-I.Z¢'t' 50-- o%'~..-~t~'Z,~ 86 for other requirements Conditions of approval Samples required [] Yes I~ No Mud Icg required [] Yes ~ No Hydrogen sulfide measu~r,~s [] Yes [] No Dir~.ctional survey required ,12L, Yes [] No Required working p,,r, eS~ur¢ for/l~O,~.~ ~_,,2~M; ,,1~3~; ,~ 5M; [] 10M; [] 15M Other: / /~-////~ / ~ by order of Approved by L "/ .-/~ ~,~.._~,//~~ Commissioner the commission Date . . . Fnrm 10-401 RRv_ Sub~ r~ triplicate DS 11-26 DRILLING PROGRAM 1. Set 20" conductor and cement. A 20", 2000 psi annular diverter might not be used for the well. A waiver of the surface hole diverter system for Drill Site 11 has been received from the AOGCC. 2. MIRU Nabors Rig 22E. 3. Drill 17-1/2" hole to 1500'MD(1500'TVD). Build 2.5°/100' N44°42'W to 40°35,. 4. Set 13-3/8" casing and cement to surface. Test casing to 2000 psi. Perform leakoff test. 5. Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi. Test BOP stack weekly. 6. Finish build and drill 12-1/4" hole to 10,908'MD (8901'TVD). 7. Run open hole logs. 8. Set 9-5/8" casing and cement. Displace cement with 9.4 ppg brine. Test casing to 3000 psi. Spot 400' diesel cap. 9. Secure well and release rig. 10. Run cased hole logs. 11. MIRU completion rig. 12. Run 5-1/2" 17.0#, L-80, AB-MOD tubing string with packer, gas lift mandrels and provisions for subsurface safety equipment. Set packer above Sadlerochit. 13. NU tree and test to 5000 psi. 14. Secure well and release completion rig. 15. Perforate and stimulate well. Install subsurface safety valve. NOTE: a. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. If hole conditions warrant, 9-5/8" casing will be set IO'TVD above the Sadlerochit and a 7" contingency liner set at TD. c. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. d. Maximum surface pressure is based upon recent BHP surveys and a full column of gas to TD (0.10 psi/ft). Existing well within 200' of the proposed well is DS 11-24 120' at the surface. PD/PD291a:tw 07/03/86 Plas Density Vi sc. Depth (TVD) #/gal (CP) Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Point Yield Point #/100 ft2 40-60 DS 11-26 MUD PROGRAM Initial 1OM FL % % Gel Gel CC/30M Oi 1 Sol i ds 30+ 50+ 25 0 8 pH and Type of Mud Gel-Benex Spud Mud 13-3/8" Csg Shoe 8.8 to to K-lO 9.4 Mi ni mum Possible 2 to 4 2 5 25 3.5 to to to 0 to 4 10 10 6.5 Low Sol i ds Non-dispersed K-lO 9.2 10 6 to to to to 9-5/8"Csg. Pt. 9.8 20 10 (Contingency) 9-5/8" Csg. Shoe 8.8 to to TD 9.2 10 to 20 4 8 8 2 4 to to to to to 8 12 4 5 8 6 4 8 10 2 4 to to to to to to 10 8 12 4 5 8 pH 9-10 Low Solids/ Non-dispersed Low Solids/ Non-Dispersed 1. Degasser 2. Shakers 4. 6. 7, PD/PD291b:tw EQUIPMENT - DRILLING FLUID SYSTEM Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) Trip tank Agitators Mud cleaners and centrifuges 0 0 1000 2000 3000 4OOO 5000 6000 7000 8OOO 90O0 10000 1)00 2000 3000 4000 5000 6000 ,. kO' CASING T~ 'D == 120 <:OP TVD = 151}0 ARC 3 AL,a,SKA, INC. 7.5 t 17.5 I~I~ALI= I IN = 1000 P'r. 17.5 SHL: 33~'FSL, 205'FE1., 22 ') 27L5 13-3/8' CASING TVD -2~00 MD--2531! Sec. 28, TllN :R15E, UN DEP=2 30' / ' ,:12.5 THL: 1070'FNL, 1240'FYIL, 37.5 Eoc T~/D -- 2991 MD -- 3124 DEP -- i~2 N44 DI G42MINW 5453 F' '(TO TARGET) A VERAr. E ANGLE 40 DEG 16 MIN K-lO TVI) = 7178 MD = 8638 DEP == 4 140 .. ~,.' ~. K-5 TVD -- 7733 MD -- 9369 DEP -- 4615 ~,'.' SAG RIVER TVD = 8288 MD = 10100 DEP = I;091 SHUBLIK TV[ =8333 MD='10169 DEP=ii129 LCU TV[ - 8333 MD ' 10158 DEP - ~ 129 TOP SA[ILEROCHIT TVi ) == 8343 MD = 10172 DEP = i ~138 GlO CONTACT ? VD = 8633 Mr = 10654 DEP = 6387 _ TARGE1 TVD -8710 kid -10666 DEa -8463'"-.,. = ~ BA~E SADLEROCH r TVD -- 8788 MD -- 10768 C EP - 6619 ~ u~-~/u- (;A~ U [VD -- USO1 MO = ~OeUU £ ~-~ -- 5616 7000 0 lO00 2000 3000 4000 5OOO 6000 7000 8OOO 9OOO 0 1000 2000 3000 4000 SO00 6000 VERT I SECT I ON 10000 7000 o -6000 o o o E - N COORDINRTES -5000 -4000 -3000 -2000 -tO00 0 1000 c~ I z 0 I -6000 I I I I I R~41 · .~ SEC.28 THL: 107 SEC.28 OSll-21; TVD ~ 871 TMD ~ 106;5' DEP = 545: 3835 I I i I I -5000 -4000 -3000 -2000 -1000 0 1000 E - N COOROINR'I"ES ". ~' E - kl- COD~'~,-,ui.NBTES 0 -6000 -5000 -4000 -3000 -2000 - ! 000 0 1000 -c:N~ ·~.'=,. 4'FSI ~n6'Fl:~ ..- . . SEC.28 TllN, R15E. JM . ~ ' . . THL: 107 0'FNL, 1240' =WL, . . - SEC.28 TllN, R15E~ JM · .. · II I ! I . OS 11-2~ . - ..... ...... ,~~11 .... TARGET ( _ . - TVD '" 871~ TMD = lOft.5.,5' DEP '= 545; r , ,, -- ; W 3835- '-' " . . - . . _ .- . ' .' I I I I II . . . · -. i , ,~, r,~ ,-F~, ' i c-,v-'.';'.i',.,J ~' ' _ i i i i i i I i i I I i i i i i · Iii Iii Ii iII i Ii i i i i i I I. 1 i i .I i I i I II i i I . i I i i~ i i i i i i I i i i 1 i i i Ii i i C:) (iD C~ CD LI') -6000 -5000 -tO00 -3000' -2000 - 1000' 0 1000 .. E -'~N C'OOROINRTES o -6000 -5000 -4~-~ -3000 -2000 ~-~,1000 0 lO00 · . . . · I I I I I I I I .il, , _ 1. ~ ........ ! --__ , .... i . l . i _ , , i i , · i :... ...... . ~ - --' <' :~:,;.:3 :~': i i ~ i i i t i i j ~l i i i i i i i i i ! i i i i i i i i i i i i' i i Il ~'iI~ i i i i i i i i i i iI i i i i i '1 i i i 1 i i i I Z 0 I I -6000 -5000 -4000 -5000 -2000 - 1000 0 1000 E - N' COORDINATES E - N OOORDINB~ES -500 -900 -300 -200 -100 0 tOO 200 (JO w zCD CD CD o Z o o I I -500 -900 -300 -200 -100 0 tOO 200 E - H COOROINBTES DRILL SITE 1 1 TYPICAL HUD PIT SCHEMATIC (DRAWIN6 IS NOT TO SCALE) CUTTINGS CONVEYOR SHAKERS CENTRIFUGE ICENTRIFUGE J TRIP TANK ii ,i AGITATOR CUTTINGS AUGER t: , 'AGITATOR AGITATOR ._ HUD CLEANER AGITATOR HUD CLEANER: WATER TANK PILL PIT AGITATOR JG $/16/86 4,, BLIND 10. 11. 12. 1~. 1~. 1~. 1. Fill 30P sr~k ang mani~ld wir. h a non-~ree.-ing ~ ~ all ~1~ ~ ~ ~ ~ly ~~e~. ~k ~g jo~ ~ ~e~ pl~ seabag ~. ~ :es: plug ~ ~1 pi~ ~ sea: ~. ~ose ~~ p~~r ~ ~~ vales. A. ~i~ly test -S. -~ ea~ of ~ ~11~ :e~, fir~ ~ld a 2S0 psi 7, ~ ~ ~~er ~ ~ ~t ~ pi~ 1~ ~ ~. ~ ~~ ze~. ~s.. ~ ~s~ ~ 50~ psi g. ~ :~ set of pi~ ~ ~ clo~ ~ set of p~ ~. ~~e ~s~ to 5000 ps~ Te~ ~g~es~ ~ld valves ~ SO~ psi ~~ of v~ ~ ze~ ~ o~ ~ jo~ ~~ ~ off.lc. Te~ s~i~ v~ves :o 5000 psi. Tes: ~lly ~ ~ ~i~ ~ :o 5000 psi ~y ~. 9 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE -- (1) Fee (2) Loc_(~(T.t//h,,ru~8-) ...... Me 3. 4. 5. 6. ,~:.,;' ": ,," ' "::' 8. (8). (3)~Admim ,, <',,~ ........ "'? ..... : ,'"" :~ 9. (9/thru 13) 10. (10 and 1§) 12. 13. (14 Ehru 22) (5) BOPE (23 thru 28) (6) OTHER /V, (29 thru 31) Geology: Engipe~ering: LCS -~ B~W ' ' ~ HJH ~ WVA ~ MTM .... rev: 04/03/86 6.011 Company YES Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells ................ ,... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Lease'& Well No. NO REMARKS ' 14. 15. 16 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Does operator have a bond in force ................ ~ ................. Is a conservation order needed ......... ............................. Is.administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ' Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate//~ Are necessary diagrams and descriptions of ~~-BOPE attached. Does BOPE have sufficient pressure rating - Test to ~'OOO psig .. Does the choke manifold comply w/API RP-53 (May 84).' ................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 0 ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . FMS Composite Sepia's 186-134 1 - 11 Are in special storage due to . overSIze. Please ask the Liberian to retrieve them for you in the storage upstairs. l (~/t (~/86-- t 5 , 39-I)EDDGW ~ PETROS ~ LOAD2 MOI)LILE=CSULOG ENTER INF'UT CSU FILE NAME DSt ~ 26,DATA READING I_IS FII_E COPIED l'O I)ISK ON t0:(~3:~7 ENTER: SCAN99 SCAN99 SCAN ONLY .... ENTER: DOlT DOll' DOIT -- I FILES~ SCAN [INLY --- ~ F'IL..ES. NO INFORMATION RECORDS PRINTED START LOGICAl_ FILE '1 ' ,.x.**.~ kEEl_ HEADER ***** ( ~ ) RLL--B 87/~)2/(~? REEL-~)t 58 HRS. AFTER BEING DRIL. L. ED;i0645-t08~O ~ (~21 5-"t ~)83(~ ' LOGGED ( ( ( ( ( ( ( ( *~**~ COMMENTS *~ COMPANY NAME :.ARCO ~ALASKA, INC ~ WELL NAME ~~ ~/¢: , F I Ei_~ :;P~Ug~O-E:~AY:: :: 5) 6) 7) 8) COUNTY :NORTH SLOPE STATE :ALASKA COUNTRY RIG :PARKER 14~ COMPANY REP :MR~ RALL ***** TAPE HEADER ~'~.*** ( t ~)) RLL-B 8'7/02/(~? TAF'E-.~)~)5 58 HRS. AFl'ER BEING DRII_I_ED;t(~645-t(~850 1 02~ 5--t (~8S(~'LOGGED ***** FILE HEADER ~**~ ( ti) RL.L-B .O(~i t024 PHYSICAl_ EOF NUMBER ~W*** COMMENTS t2) MAIN LOG'FET=58 HRS~ ( ~3) **~** DATA FORMAl' SPECIFICATION ***** ENTRY BLOCKS UP/DOWN FLAG ................................................ 255,~ DEPTH RECORDING MODE ............................. e.eeeeeeE+ee UNITS OF DEPTH IN DATA RECORDS ..... FT REPR~ CODE FOR OUTPUT DEPTH ................ ~8~8~ DATUM BLOCKS ID ORDER ~ ,---. LOG TYPE CLASS MOD NO, _.. LEVEL CODE DEF'T RL.L-B FT ~ ~ ~ ~ ~ 4 ~ ~ 68 GPA RLL.-B 8 8 8 8 t 4 8 I 68 GRB RL.L-B 8 8 8 O t 4 8 I 68 RATE RLL-B 8 8 8 8 I 4 8 t 68 EWR RLL-B 8 8 ~ 8 t 4 8 1 68 CNF'S RLL-B 8 8 8 ~ I 4 9 f 68 CNFO RLL-B 0 0 0 0 t 4 0 t 68 CNF~ RL.L-B 0 O 0 0 t 4 0 t 68 CNNO RLL-B O 0 0 0 ~ 4 0 I 68 CNN1 RL.L-B O ~ O 0 I 4 0 t 68 DEPTH ERROR~ PREVIOUS== i(~t8.5~0000 THIS= REC t 4 ( ~ ) tO DATA FRAMES FROM 18t80.50 THROUGH t8t85~00 RECORDS t4 THROUGH ~4 DEF'I'H ERROR~ PREVIOUS= O,O00OOOO00E+OO THIS: i0185.5000 DINC= 0~5000000~0 REC t 5 ( ~ ) t DATA FRAMES FROM O,OO THROUGH O,O0 RECORDS 14 THROIJGH t4 2 SEQUENTIAL DEPTH ERRORS FROM RECORD t4 I'HROUGH iS DEF'TH ERROR~ PREVIOUS= 18i~(')~,~)888 THIS: REC t S ( f ) tO DATA FRAMES FROM 10t85~50 THROUGH DEPTH ERROR~ PREVIOUS= O.OOOO0000OE+O~ THIS= tOl9~500O DINC= O,500OOOOO0 REC 16 ( 1 ) i DATA FRAMES FROM 8,~ THROUGH 2 SEQUENTIAl_ DEF'I'iq ERRORS FROM RECORD i5 'FFIROUGH i6 DEPI'H ERROR~ PREVIOUS= lOl~S,.O00~) THIS= REC f 6 ( i ) t~ DATA FRAMES FROM 18l~SG THROUGH I~t~5,08 RECORDS t6 THROUGH DEF'I'H ERROR~ PREVIOUS= O,OOO00OOOOE+OO THIS= t~I95,5000 DINC= ~,5000OO0~ REC t 7 ( t ) I DATA FRAMES FROM ~88 THROLIGH '~) i" · · '1 ,~ SEqUENTIAl_ DEF'TH ERF(ORS FROM RECORD 16 THF(OIJGH 17 DEPI'H ERROR~ PREVIOUS= t028(-)~0008 THIS= 0~88808(')88{)E+8(') DINC= 8~5888888~8 REC i 7 ( t ) t~ DATA FRAMES FROM ~8t95~58 THROUGH ~8288~88 RECORDS 17 THROUGH ~7 DEPTH ERROR~ PREVIOUS= ~,~8~8~88~E+~8 THIS= t82~8,5~8 DINC= ~.58~88~ REC ~ 8 ( ~ ) i DATA FRAMES FROM O.OO THROUGH 0.00 RE:CORDS 1 '7THROUGH 17 2 SEQUENTIAL DEPTH ERRORS FROM RECORD t7 THROUGH t8 DEF'I'H ERROR,. PREVIOUS= t0285~{)8~)(') THIS= REC i 8 ( 1 ) t0 DATA FRAMES FROM t~28~5~ THROUGH t82~5~8~ RECORI)S t8 THROUGH DEF'TH ERROR~ PREVIOUS= 8.8~8888~8E+8~ THIS= REC ~ ~ ( ~ ) t DATA FRAMES FROM 8,~8 THROUGH 8,89 RECORDS i8 THROUGH 2 SEQ, UENI'IAL. DEPTH ERRORS FROM RE:CORD 18 THROUGH DEPTH ERROF(, PREVIOUS== I02I(~0808 THIS= REC l ~ ( t ) t8 DATA FRAMES FROM 18285.5(~ THROUGH DEPTH ERROR, F'REVIOU~= 8,88888888~E+~ THIS= i~21~5~ee DINC= REC 28 ( I ) **-~***~* 2 SE~.ENTIAI_ DEF'TH ERRORS FROM R]~.CORD t? THROUGH 28 DEPTH ERROR~ PREVIOUS: 40215~(~0(~0 THIS= ~)~0(~0~)~)~800E4,0(~ DINC= 0~500088000 REC 2~ ( I ) t~ DATA FRAMES FROM t~2~58 THROUGH t~2t5~ RECORDS 2~ THROUGH 28 REC 2 ~ ( f ) t DATA FRAME~ FROM 8,8e THROUGH e,ee RECORD~ 2e THROUGH 2~ 2 SEQUENTIAL DEPTH ERRORS FROM RECORD 20 THROUGH 24 I)EPTH ERROR~ PREVIOUS= t022~)~00~)0 THIS= REC 2t ( I ) ~e DATA FRAMES FROM ~e2~5~58 THROUGH REC 22 ( i ) i DATA FRAMES FROM 8,8e THROUGH 8,e8 RECORDS 21 THROUGH 2i SEQUENTIAL. DEPTH ERRORS FROM RECORD 24 THROUGH 22 DEPTH ERROR~ PREVIOUS=: t~)225~)0~)0 THIS= REC 22 ( t ) t e DATA FRAMES FROM l e228,se THROUGH ~8225~ee RECORDS 22 THROUGH 22 1 DATA FRAMES FROM e,ee THROUGH e,e8 RECORDS 22 THROUGH 22 2 SEQUENTIAL DEPTH ERRORS FROM RECORD 22 THROUGH 23 DEF'TH ERROR~ PREVIOUS= 48238~888 THIS= 8~88~~E4.~ DINC= REC 2~( 4~ DAI'A FRAMES FROM 4~225~58 THROUGH 482S8~8~ RECORDS 2S THROLIGH 2S DEPTH ERROR~ PREVIOUS= 8,8888~888E+~ THIS: i8258,5~8~ DINC= REC 24( t DATA FRAMES FROM 8,8~ THROUGH 8,~8 RECORDS 2~ THROUGH 2 SEQUENTIAL. DEFTH ERRORS FROM RECORD ~.~ THROUGH 24 2 SEQUENTIAL DEPI'H ERRORS FROM RECORD 24 THROIlGH 25 2 SEQUENTIAL. DEPTH ERRORS FROM RECORD 25 THROUGH 26 2 SEQLIENI'IAL DEPTH ERRORS FROM RECORD 26 THROLIGH 27 SEQUENTIAL DEPTH ERRORS FROM RECORD 27 THROUGH 28 2 SEQUENI'IAL DEpI'H ERRORS FROM RECORD 28 THROUGH 29 2 SEQUENTIAl.. DEF'TH ERRORS FROM RECORD 2? THROUGH 2 SEQUENTIAL DEPTH ERRORS FROM RECORD ~50 I'FIROLIGH ~l **~***~* 2 SEQUENTIAL DEPI'H ERRORS F'ROM RECORD 3i I'HROLIGH 32 2 SEQLIENI'IAL DEPTH ERRORS FROM R~iCORD SS I"HROIlGH S4 *~**~ FILE TRAILER **~** t44) RLL-B ,08~ **~** END LOGICAL FILE 260 DEPTH ERRORS 2 SEQUENTIAl. DEPTH ERRORS FROM RECORD t44 I_OGICAL RECORDS ~4S THROUGH ~43~ FRAMES READ FROM CH 2&] NON--CONI'IGLIOUS DATA SEGMENTS I DATA FRAMES FROM 0,(~0 'rHROUgH,_. 0,00 RECORDS .14~ 'FI..IROLIGH t 47 HNEM ~ID CLIRVE MINIMUM MAXIMUM MEAN STD."'DEV SAMPLES GRA RLL.- 0 0 ~ 000000E+00 S04~ I55 46~989~ 4E), 27S2 tS62 GRB RLi..- 8 ~, ~8~E+~ ~2~, 77~ 45,6~9 ~9,5994 i S62 GRC RLL- ~ ~ ~888E+~ 3~2~463 46~2965 ~9.759~ t~62 RATE RLL.- 8 8 ~ 888~88E+8~ 345. ~ 7~ ~52~774 59.4~3 EWR RLL- ~ ~88~88E+88 33~3~3 ?~288~ 73.~663 1364 CNF'S RL.L.- ~ -632,822 71,749i 32,7632 36,2387 i349 CNFO RLL- 0 O.O00000E+O0 ti07.00 578.t67 20S.78S CNNO RLL,,- O 0. OO0000E+O~ 2984 ~ OO 2769.22 784,727 CNNt RI_L- O o,oooOOOE+OO zeee,oe 2aa2.51 772,0s6 1760 END LOGICAL FILE ENTER' 0 .... SCHLUMBERGER ..... ~= LIS TAPE VERIFICATION LiSTiNG FEB 1 o 198.7 Oil & ~as Cons. Commission LVP 010.H02 VERiFICATICN LISTING PAGE i -.~- REEL H-ADER SERVICE NAME :EDIT DATE :87/02/ 2 ORiGiN : REEL NAME :S CONTiNUATiON ~ :01 PREVIOUS R:EL COMMENTS :LIBRARY TAPE ..~'$. TAPE HEAOER ~$ SERVICE NAME :EOIT DATE :87/02/ 2 ORIGIN :FS1A TAPE NAME : CONTiNUATiON ~ :01 PREVIOUS TAP~ : COMMENTS :LIBRARY TAPE -,--,~ FiL~- HEADER ...... FILE NAME :EDIT .00t SERVICE NAME : VF-RS~'ON # · DATE : MAXIMUM LENGTH : 1024 FiL~ TYPE : PREVIOUS FILE : "'""-,--,. iNFORMATiON RECORDS-,-""~'-,. MNEM CONTENTS UNIT TYPE CATE SIZE CODE CN : ARCO ALASKA, INC. 000 000 O1B 065 WN : DS 11-26 000 000 008 065 FN : PRUDHOE BAY 000 000 012 065 RANG: 1SE 000 000 004 065 TOWN: I1N 000 000 004 065 SECT: 28 OOO 000 OOZ 085 COUN: NORTH SLOPE 000 000 012 06~ STAT: ~LASKA 000 000 006 065 MNEM CONTENTS UNiT TYPE CATE SIZE COOE LYP OlO.H02 VERIFICATION ~LISTiNG PAGE 2 -,-'" SCHLUMB F-R GE R ;;~ '"-,- ALASKA COMPUTTNG~. _ CENTER_ ~'- ~,,~,; ~NY = ARCC ALASKA INC WELL = OS 11-26 Fir-LO = PRUDHOE B~Y COUNTY = NORTH SLOF~ ~OROUGH STATE = 4LASK~ JOB NUMBER AT ACC: 72179 RUN #ON~, DATE LOGG;O: 28 JAN 87 LOP: T H~LSTSAg CASING = 13.375" @ 2530' - BIT SIZE = 12.25" TO 2541' TYPE FLUID = LiGNO DENSITY = 9.80 LS/G RM = 3.150 ~ 66 DF VISCOSITY : 13.0 S RMF : 2.570 @ 66 PH = 10.0 RMC = 3.450 ~ 66 OF FLUID LOSS = ~.0 C3 RM AT BHT : 1.484 ~ 148 DF MATRIX SANDSTONE ~~ THiS DATA HAS NOT ~EEN DEPTH SHIFTEO - OVERLAYS FIELD PRINTS LVP OtO.H02 VERIFICATION LISTING PAGE 3 SCHLUMBERGER L~GS TNCLUD~D -'- DUAL *NDUCTION SPH'~RICALLY FOCUSED LOG (DIL) ~- DATA AVAILABLE: 10913' TO 10144' ~:~ BOREHOLE COMPENSATED SONIC LOG (BHC) ~- OATA AVAILABLE: 10877' TO lO14q' -,- LITHO DENSITY COMPENSAT=~ LOG (LDT) ~ C~MPENSATED NEUTRON LOG (LDT) ~- DATA AVAILABLE: 10833' TO 10150' -~- GAMMA RAY IN CASING (GR.CNL) '"-,. DATA AVAILABL=: 10156' TO 2541' DATA FORMAT RECORD 6NTRY BLOCKS TYPE SiZ~ REPR CODE ENTRY 2 I 66 0 4 t 66 8 ~ 73 60 9 4 65 .liN 16 1 66 1 0 t 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API AP1 APi AP1 FILE SIZE SPL REPR PROCESS iD ORDER # LOG TYPE CLASS MOD NO. CODE (OCTAL) DEPT FT O0 000 O0 0 0 4 I 68 00000000000000 SFLU OiL OHMM O0 220 O1 0 0 4 1 68 00000000000000 LVP OlO.H02 YER!FICATiON LISTING PAGE 4 ILO DiL OHMM O0 iLM OIL OHMM O0 SP OIL MV O0 GR OiL GAPI O0 TENS DIL LB O0 DT BHC US/F O0 GR BHC GAFI O0 TENS BHC LB O0 GR LOT GAPI O0 CALI LOT IN RH08 LOT G/C3 O0 DRHO LOT G/C3 O0 NRAT LDT O0 RNRA LOT NPHi LOT PU O0 DPHI LOT PU O0 PEF LDT O0 NCNL LOT CPS O0 FCNL LDT CPS O0 LSHV LDT V O0 SSHV LDT V O0 QSS LDT O0 QLS LDT O0 TENS LOT LB O0 LL LDT CPS O0 LU LDT CPS O0 LS LOT CPS O0 LITH LDT CPS O0 SSI LDT CPS O0 SS2 LDT CPS O0 GR CNL GAPI O0 120 46 0 0 120 44 0 0 010 Ol 0 0 310 O1 0 0 63: 21 0 0 520 80 0 0 310 Ol 0 0 635 21 0 O 310 O1 0 0 280 O1 0 0 350 02 0 0 356 O1 0 0 420 Ol 0 0 000 O0 0 0 890 O0 0 0 89O O0 0 0 358 Ol 0 0 q30 3t 0 0 330 30 0 0 000 O0 0 0 000 O0 0 0 000 O0 0 0 000 O0 0 635 21 0 0 354 Ol 0 0 354 Ol 0 0 354 01 0 0 354 O1 0 0 000 O0 0 0 000 O0 0 0 310 O1 0 0 DEPT 10934.5000 SFLU SP 0.3750 GR GR 94.9375 TENS RHOB -999.2500 DRHO NPHI -999,2500 DPHI FCNL -999.2500 LSHV QLS -999,2500 TENS LS -999.2500 Li'TH GR -999.2500 DEPT t0900.0000 SFLU SP -14.5703 GR GR 93.3750 TENS RHOE -999.2500 DRHO NPHI -999.2500 OPHl FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR -999.2500 3.8915 ILO 94.9375 TENS 1570.0000 GR -999.2500 NR~T -999.2500 PEF -999.2500 SSHV: -999.2500 LL -999.2500 SS! 6.0879 iLD 93.3750 TENS 5064.0000 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi 4 4 i 4 1 4 1 4 1 4 1 4 ! 4 i 4 1 4 i 4 i 4 1 4 4 4 1 4 t 4 1 4 1 4 1 4 1 4 4 4 4 t 4 i 4 1 4 1 4 1 4 t 4 1 3.4220 ILM 1570.0000 DT -999.2500 C~LI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999,2500 LU -999.2500 SS2 4.6350 iLM 5064.0000 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 $52 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 00000000000000 68 OOO00000000000 68 00000000000000 68 00000000000000 68 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TENS 2.3438 DRHO 27.0508 OPHI 921.5000 LSHV -0.0137 TENS 355.2500 LITH -999.2500 10500.0000 SFLU -94.1250 GR 31.3438 TENS 2.t699 DRHO 18.5547 OoHi 1174.0000 LSH? -0.0161 TENS 47!.0000 LiTH -999.2500 10400.0000 SFLU -85.1875 GR 37.2500 TENS 2.1934 DRHO 22.6563 OPHI 951.0000 LSHV -0.0229 TENS 450.0000 LITH -999.2500 10300.0000 SFLU -41.8750 GR 55.9375 TENS 30.$674 ILO 69.7500 TENS 5092.0000 GR 0.1470 NRAT 7.9164 PEF 1139.0000 SSHV 5540.0000 LL 86.0000 SSi Ill.0274 ~ n 35.7813 TENS 5108.0000 GR -0.0088 NRAT 27.6824 P~F i138.0000 SSH¥ 5472.0000 LL 134.5000 SSi 122.5592 iLD 43.1250 TENS 4984.0000 GR 0.0078 ~RAT i8.5687 PEF 1159.0000 SSHV 5348.0000 LL 96. 87=0~ SS1 960.9092 iLO 31.3438 TENS 4960.0000 GR -0.0!07 NRAT 29.1027 PEF 1159.0000 SSHV 5272.0000 LL 148.5000 SSI 389.6957 ILO 37.2500 TENS 4992.0000 GR -0.006~ NRAT 27.6824 PEF 1159. 0000 SSHV 526~.0000 LL ii5. t$75 SSi 217.3912 ILO 55.9375 TENS 4984.0000 ~R 8.0005 !LM 5092.0000 DT 108.1250 CALI 3.2910 RNRA 2.8418 NCNL 1122.0000 QSS 174.7500 LU ZTT.0000 SSZ 58.~234 ILM 5108.0000 DT 37.2187 CALI 2.9277 RNRA 2.1934 NCNL 112~. 0000 QSS 24:~. 7500 LU ~32.3750 SS2 44.4512 ILM 4984.0000 DT 44.5938 CALl 2.7715 RNRA 2.5410 NCNL 1122.0000 QSS 187.1~50 LU 234.8750 SS2 ~85 6587 ILM ~960.0000 DT 31.0000 CALl 2.2031 RNRA 2.1973 NCNL 1122.0000 QSS 251.6250 LU 232.6250 SS2 218.9565 ILM 4992.0000 DT 33.1250 CALl 2.4863 RNRA 3.29i0 NCNL 1123.0000 QSS 239.0000 LU 234.5000 SS2 65.6033 iLM 4984.0000 DT 57.3125 CALl 9.8000 79.6875 13.6875 3.5234 1770.0000 0.0786 314.2500 349.0000 48.2164 t00. 687~ 12.3203 3.0430 2516.0000 0.0103 414.5000 338.0000 42.0018 91.5000 12.4844 2.8242 2464.0000 0.0342 336.0000 322.0000 95.5988 91.3750 12.4844 2.3320 2888.0000 0.0347 438.5000 328.7300 95.5988 102.5000 12.8047 2.4570 2554.0000 0.0410 &22.2500 327.5000 53.8371 94.9375 12,8047 LVP OIO.H02 VERIFICATION LISTING PAGE 6 RHOB NPHi FCNL QLS LS GR DEPT SP GR RHO8 NPHI FCNL QLS LS GR DEPT SP GR RHDB NPHI FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL ~LS LS GR 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2.3312 96.8125 14.1484 3.3262 1871.0000 0.0645 263.7500 306.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 LVP~ OlO.H02 VERIfICATiON. ~' ~STiNG PAGm. 7 LS GR DEPT SP GR RHO5 NPHZ FCNL QLS LS GR OEPT SP GR RHO8 NPHI FCNL w~.S LS GR DEPT SP GR RHO8 NPHi FCNL QLS LS GR DEPT SP GR RHOB NPHi FCNL QLS LS GR DEPT GR RH05 NPHI FCNL QLS LS GR -999.2500 L!TH 137.5000 9700.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 167.1250 9600.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 -999.2500 DPHi -999.2500 LSH'V -999.2500 TENS -999.2500 LITH i59.7500 9500.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 ORHO -999.2500 DPHZ -999.2500 LSHV -999.2500 TENS -999.2500 [ITH ti3.9375 9400.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 LSH¥ -999.2500 TENS -999.2500 LITH 94.9375 9300.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LZTH 86.1875 -999.2500 SS1 -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSt -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2~00 NR~T -999.2500 PEF -999.2500 SSHV -99'9.2500 LL -999.2500 SSi -999.2500 iLD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSH'V -999.2500 LL -999.2500 SSi -999.2500 iLD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 S32 -999.2500 iLM -999.2500 DT 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QLS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP GR NPHi FCNL QLS LS DEPT SP GR RHO5 NPHi FCNL QLS LS GR D:PT SP GR RHOB NPHI -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 74.3125 9100.0000 SFLU -999.2500 GR -999.2.500 TENS -999.2500 DRHO -999.2300 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 97.9375 9000.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 83.4375 8900.0000 .SFLU -999.2500 GR -999.2500 TENS -999.2500 ORHD -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 91.8125 8800.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS --999.2500 LITH 120.0000 8700.0000 SFLU -999.2300 GR -999.2500 TENS -999.2500 ORHO -999.2500 DPHI -999.2500 TENS -999.2500 GR -999.2300 NRAT -999.2300 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 ILD -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 P~F -999.2500 SSHV -999.2500 LL -999.2300 SSI -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF --999.2500 SSHV -999.2300 LL -999.2500 SSt 999.2500 iLD -999. 2500 T:NS~ -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 ILO -999.2500 T~NS -999.2500 GR -999.2500 NRAT -999,2500 P~F -999.2300 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL :-999.2500 QSS -999.2500 LO -999.2500 SS2 -999.2300 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALZ -999.2300 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2300 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALl · -999.2500 RNR~ -999.2500 NCNL -999.2500 QSS -999.2300 LU -999.2500 SSi -999.2500 iLM -999.2500 DT -999.2300 CALl -999.2500 RNRA --999,2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2300 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.H02 VERIFiCATiON LISTING PAGE 9 FCNL QLS LS GR DEPT SP GR RHOB NPHi FCNL ~LS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP GR RH05 NPHi FCNL QLS LS GR DEPT SP GR RHO5 NPHi FCNL qLS LS GR DEPT SP GR RHOS NPHI FCNL ~LS LS GR -999.2500 LSHV -999.2500 TENS -999.2500 LITH 105.0000 8600.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 71.0000 8500.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSMV -999.2500 'TENS -999.2500 LITH 91.9375 8400.0000 S~LU -999.2500 GR -999.2500 TENS -999.2500 ORH'O -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 82.3125 8300.0000 S~LU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 73.8750 8200.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRH'O -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LiTH 74.1250 -999.2500 SSHV -999.2500 LL -999.2500 SS! -999.2500 -999.2500 -999.2500 -999.2500 -999..2500 -999.2300 -999.2500 -999.2500 ILD TE NS GR NRAT PEF SSHV LL SSI -999.2500 ILO -9'99.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2500 SS~V -999. 2500 LL -999.2500 SSt -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILD TENS GR NRAT PEF SSHV LL SS1 -999.2500 iLO -999.2500 TENS -9'99.230-0 GR -999.2300 NRAT -999.2300 PEF -999.2500 $SHV -999.2500 LL -999.2500 SSl -999.2500 ILD -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2300 PEF -999.2500 SS~V -999.2500 -999.2500 SSI -999.2500 ~SS -999.2500 LU -999.2500 SS2 -999.2300 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999,2500 SS2 -999.2500 ILM -999.2500 OT -999.2500 CALl -999.2500 RNRA -999.2300 NCNL -999.2300 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2300 OT -999.2500 C~Li -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 · ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2300 LU -999.2500 SS2 -999.2500 ILM -999.2300 DT -999.2500 CALI -999.2500 RNRA -999.2300 NCNL -999.2500 QSS -999.2500 LU -999.2500 SSZ -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 --999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 LVP OIO.H02 VERIFICATION LISTING PAGE 10 DEPT GR RHOB NPHI FCNL QLS LS GR OEPT SP GR RHOB NPHI FCNL ~LS LS GR DEPT S? GR RH08 NPHi FCNL wLS LS GR DEPT SP GR RHOB NPHI FCNL qL$ L$ GR DEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP 8100.0000 SFLU -999.2500 GR -999.2500 TENS -999.Z500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 47.9375 8000.0000 SFLU -999.2500 GR -999.Z500 TENS -999.2500 ORHO -999.2500 OPHi -999.2500 LSHV' -999.2300 TENS -999.2500 LZTH 84°0625 7900.0000 SFLU -999.2500 GR -999.2500 T~NS~ -999.2500 ORMO -999.2500 OPHl -999.2500 LSHV -999.2500 TENS -999.2500 tITH 95.5625 7800.0000 SFLU -999.2~00 GR -999.2500 TENS 999.2500 DRHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.Z500 LITH 56.6563 7700.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 78.1250 7600.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 P~F -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 iLO -999.2500 TEN~ -999.2500 GR -999.2500 NRAT -999.2500 P~F -999.2500 SSH¥ -999.2500 LL -999.2500 SSi -999.2500 iLO 999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2~00 SS1 -999.2500 iLO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSt -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 ILM -999.2500 OT -999.2500 C~Li -999.2500 RNRA -999.2500 NCNL -999.2500 OSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2300 DT -999.2500 C~I -999.2500 RN~A -999.2500 NCNL -999.2500 qSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 ~SS -999.2500 LU -999.2300 SS2 -999.2500 ILM -999.2500 DT -999.2500 C4Li -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999:.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 LVP OlO.H02 VERIFICATION LISTING PAGE 11 RHOB NPHI FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR OEPT SP GR RHOB NPHi FCNL QLS LS GR DEPT SP GR RHOB NPHi FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP GR RHO~ NPHI FCNL QLS -999.2500 ORHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 43.2500 7500.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 46.3750 7400.0000 SFLU -999.2500 GR -999.2500 TENS 999 2500 DR'~ -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 56.5313 7300.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHD -999.2500 DPH'I -999 2500 ~ · ~HV -999.2500 TENS -999.2500 LITH 67.6875 7200.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2300 LiTH 62.8437 7100.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 ORHG -999.2500 ~PHI -999.2500 LSHV -999.2300 TENS -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSl -999.z~v'~-'~O ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999. 2500 SS1 -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRA'T -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 ILD -999 ~ · ~500 TENS 999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999,2500 SS1 -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEE -999.2500 SSHV -999,2500 LL -999.2500 SSI -999.2500 -999.2500 TENS -999.2500 GR -999· 2500 NRAT -999.2500 PEF ~-999.2500 SSHV -999.2500 LL -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 OT -999.2500 CALl -999.2500 RNRA ~99.2500 NCNL -999,2500 QSS -999·2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LO -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999·2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 LVP OiO.H02 VERiFiCATION LISTING PAGE 12 LS GR DEPT GR RH8~ NPHI FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR DEP'T SP GR RHOB NPH! FCNL QLS LS GR OEPT SP GR RHOB NPH! FCNL QLS LS GR OEPT SP GR RHOB NPHI FCNL QLS LS GR -999.2500 LITH 58.6563 7000.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 51.7500 6900.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV' -999,2500 TENS -999.2500 LITH 49.9375 6800.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 46.7813 6700.0000 SFLU -999.2500 GR -999.2300 TENS -999.2500 DRHO -999.2500 OPHI -999.2300 LSHV -999.2500 TENS -999.2500 LITH 73.8750 6600.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 LSHV -999.2300 TENS -999.2500 LiTH 61.3428 -999.2500 SSI -999.2500 -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999°2500 SSI -999.2500 iLD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 ILO -999. 2500 TENS -9'99. 2500 GR -999.2500 NRAT -999. 2500 PEF -999.2500 SS'HV -999.2500 LL -999.2500 SSt -999.2500 ILD -9'99.2500 TENS -999.2300 GR -999.2300 NRAT -999.2500 PEF -999.2500 SSHV -999.2~00 LL -999.2500 SSi -999.2500 SS2 -999.2500 iLM -999.2300 DT -999.2500 CALl -999.2300 RNR~ -999.2500 NCNL -999.2300 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2300 ~SS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 OT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2300 SS2 -999,2500 ILM -999.2300 -999.2500 CALI -999.2300 RNR~ -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2300 ILM -999°2500 DT -999.2300 CALi -999.2300 RNRA -999.2300 NCNL -999.2500 LU -999.2500 SS2 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2~00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -'999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6500.0000 SFLU -999.2500 ILO -999.2500 ILM -999.2500 LVP OiO.HO2 VERiFiCATiON LISTING P~aGE i3 SP RHOB NPHI FCNL QLS LS GR OEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP GR RH06 NPHI FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR OEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP RHO8 NP~I -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS i999,2500 LITH 54.0625 6400.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 ORHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 59.3125 6300.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999,2500 LITH 70.5625 6200.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHi -999.2500 LSHV -999.2500 TENS -999.2500 LiTH 53.7813 6100.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRH8 -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 87.6250 6000.0000 SPLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2~00 DPHI -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PfF -999.2500 SSHV -999. 2500 LL -999.2500 SSl -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV --q99.25~ . vv LL -999.2500 SS1 -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 tt -999.2500 SSi -999.2500 ILD -999. 2500 TcNS~ -999.2500 GR -999.2500 NRAT -999.2500 PEP -999.2500 SSHV -999.2500 LL -999.2500 SSI -999.2500 iLO -999.2500 TfNS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS! -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEP -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2300 DT -999.2300 CALi -999.2300 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2300 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2300 NCNL -999. 2500 ~C~ -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALl -999.2300 RNRA -999.2300 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.N02 VERiFICATiON LISTING P~GE 14 FCNL L$ GR DEPT SP NPHi FCNL QL$ LS DEPT SP GR RHOB NPHZ FCNL QLS kS GR DEPT GR RHOB NPHZ FCNL QLS LS GR OEPT SP GR RHO8 NPHI FCNL QLS LS OEPT SP GR NPHI FCNL ~LS LS -999.2500 LSHV -999.2500 TENS -999.2500 LITH 50.7188 5900.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 T~NS -999.2500 LITH 90.0625 5800.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 ORHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 36.4375 5700.0000 SFLU -999.2500 GR -999.2500 TENS -999.2:00~ DRHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 86.5000 5600.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 66.9375 5500.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LiTH YZ,.BTSO -999.2500 SSHV -999.2500 LL -999,2300 SS1 -999.2500 iLD -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 iLD -999.2500 TENS -999.2900 GR -999.2500 NRAT -999,2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 iLD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 -999.2300 iLD -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999,2500 LL -999.2500 SSi -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRdT -999.2500 PEP -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALi -999.2500 RNR.~ -999. 2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 OT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LO -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999. 2:00~ SS2 -999.2300 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 LVP OIO.H02 VERIFICATION LISTTNG P~GE 1~ DEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP GR NPHI FCNL QLS LS GR DEPT SP GR RHOB NPHi FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL QLS LS GR DEPT SP GR RH05 NPHI FCNL QLS LS GR DEPT SP 5400.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 ORHO -999.2500 DPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH 81.7500 5300.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 69.5625 5200.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRH~O -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 76.8125 5100.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 57.2500 5000.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 -999.2500 DPHi -999.2500 LSHV -999.Z500 TENS -999.2500 LiTH 42.4688 4900.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSI -999.2500 iLD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 iLO -999.25.00 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 iLO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSI -999.2500 iLO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 iLO -9'99.2500 TENS -999.2500 GR -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 OT -999.2500 CALI -999.2500 RNRA -999. 2500 NrNL~ -999.2500 QSS -999.2500 LO -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999 2500 N~ ~L -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALZ -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 C~LI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.H02 VERIFICATION LISTING PAGE !6 RHOB NPHI FCNL QLS LS GR OEPT SP GR NPHi FCNL QLS LS GR DEPT SP GR RHOB NPHI FCNL ~LS LS GR OEPT SP GR RH05 NPHI FCNL ~LS LS GR DEPT S? SR RH08 NPHI FCNL LS DEPT SP GR NPHI PCNL ~LS -999.2500 ORHO -999.2500 DPHI -999.2500 LSHV --999.2500 TENS -999.2500 LITH 73.1250 4800.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 OPHi -999.2500 LSHV -999.2500 TENS -999.2500 LITH T0.3750 ~700.0000 SFLU -999.2500 -999.2500 TENS -999.2500 DRHO -999.2500 DPHi -999.2300 LSHV -999.2500 TENS -999.2500 LITH 56.1875 4600.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 60.5313 4500.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2500 DPHI -999.2500 LSHV -999.2500 TENS -999.2500 LITH 49.6250 4400.0000 SFLU -999.2500 GR -999.2500 TENS -999.2500 DRHO -999.2300 DPHi -999.2500 LSHV -999.2500 'TENS -999.2500 NRAT -999.2300 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 ILD -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSI -999.2500 iLO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999.2500 -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2300 SSHV -999.2500 LL -999.2500 SSI -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2300 SSHV -999.2500 LL -999.2500 SSi -999.2500 ILD -999.2500 T:NS -999.2500 GR -999.2500 NR~T -999.2500 PEF -999.2500 SSHV -999.2~00 LL -999.2500 RNRA -999.2~00 N -999.2500 QSS -999.2500 -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2300 ~SS -999.2500 LU -999.2500 SS2 -999.2300 ILM -999.2300 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999,2500 -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNL -999.2500 ~SS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2300 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ibM -999.2500 DT -999.2500 CALl -999.2500 RNRA -999.2500 NCNb -999.2300 ~SS -999.2300 LU -999.2300 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.HO2 VERIFICATION LISTING PAGE 17 LS -999.2500 LiTH GR 81.5625 OEPT ~300.0000 SPLU SP -999.2500 GR GR -999.2500 TENS RHO6 -999.2300 DRHO NPHi -999.2500 DPHi FCNL -999.2500 LSHV QLS -999.2S00 TENS LS -999.2500 LITH GR 82.0625 DEPT 4200.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHI -999.2500 DPHI FCNL -999.2500 LSHV' QLS -999.2500 TENS LS -999.2500 LiTH GR 53.4688 DEPT 4100.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 ORHO NPHI -999.2500 OPHi PCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 78.8125 DEPT 4000.0000 SPLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHI -999.2500 DPHi FCNL -99'9.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 63.3750 DEPT 3900.0000 SPLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHi -999.2500 DPHi FCNL -999.2500 LSHV QLS -999.2300 TENS LS -999.2500 LiTH GR 72.8750 -999.2500 SS1 -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSt -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 S$1 -999.2500 -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSt -999.2500 iLO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEP -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SSZ -999.2500 ILM -999.2500 OT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999.2500 ~SS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2500 RNRA -999.2500 NCNL -999,2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LO -999.2500 SSZ -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500' -999.2500 -999.2500 -999.2500 -999.2500 OEPT 3800.0000 SFLU -999.2500 !LD -999.2500 iLM -999.2500 LVP OlO.H02 VERIFICATION LISTING PAGE SP -999.2300 GR GR -999.2500 TENS RH08 -999.2500 DRHO NPHI -999.2500 OPHI FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 68.5625 DEPT 3700.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHO8 -999.2500 DRHO NPHi -999.2500 ~PHl FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 55.6875 DEPT 3600.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHO8 -999.2500 DRHO NPHI -999.2500 DPHi FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 48.9375 DEPT 3500.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHI -999.2500 DPHI FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LZTH GR 43.6250 D:PT 3400.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHI -999.2300 DPHi FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LZTH GR 62.4375 DEPT 3300.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHI -999.2500 DPHi -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2300 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSI -999.2500 iLD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2300 iLO -999.2500 TENS -9'99.2500 GR' -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 -999.2300 ILO -999.2500 TENS -999.2300 GR -999.2300 NRAT -999.2300 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSI -999.2500 iLO -999.2500 TENS -999.2300 GR -999. 2300 NRAT -999.2300 PEF -9'99.2500 SSHV -999.2500 LL -999.2500 SSl -999.2500 ILD -999.2500 TENS -999.2300 GR -999.2500 NRAT -999.2500 PEF -999.2500 DT -999.2300 CALi -999.2300 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 -999.2500 SSZ -999.2300 ILM -999.2300 OT -999.2500 CALl -999.2300 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2300 DT -999.2500 CA~Li -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 L'U -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALi -999.2300 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2300 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LO -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2300 CALi -999.2500 RNRA -999,2500 NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP 010,H02 VERIFICATION LISTING PAGE 19 FCNL -999.2500 LSMV QLS -999.2500 TENS LS --999,2500 LITH GR 77o7~00 OEPT 3200,0000 SFLU SM -999,2500 GR GR -999,2500 TENS RHO5 -999.2300 DRHO NPHI -999,2500 DPHZ FCNL -999,2500 LSHV OLS -999.2500 TENS LS -999,2500 LITH GR ~4.8750 OEPT 3100,0000 SFLU SP -999,2500 GR GR -999,2500 T=NS~ RHOB -999,2500 DRHO NPHI -999.2500 OPHI FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 36.5000 OEPT 3000.0000 SFLU SP -999,2500 GR GR -999,2500 TENS ~HO~ -999,2500 ORHO NPHi -999.2500 DPHI FCNL -999,2500 LSHV QLS -999,2500 TENS LS -999,2500 LITH GR 59°0938 DEPT 2900.,0000 SFLU SP -999,2500 GR GR -999.2500 TENS RHO6 -999,2500 ORHO NPHI -999,2500 DPmI ~CNL -999,2500 LSHV QLS -999.2500 TENS LS -999,2500 LiTH GR 60.0625 OEPT 2800,0000 SFLU SP -999.2500 GR GR -999,2500 TENS RHOB -999,2500 NPHI -999.2500 DPHI FCNL -999,2500 LSHV QLS -999,2500 TENS LS -999.2300 LZTH GR 57.2500 -999,2500 SSHV -999.2500 LL -999.2500 SSI -999,2500 iLD -999,2500 TENS -999,2500 GR -999.2500 NRAT -999.2500 PEF -999,2500 SSHV -999,2500 LL -999.2500 SSI -999.2500 ILO -999.2500 TENS -999,2500 GR -999,2500 NRAT -999,2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SSi -999,2500 ILO -999.2500 TENS -999,2500 GR -999,2500 NRAT -999.2500 PCF -999.2500 SSHV -999,2500 LL -999,2500 SS1 -999,2500 ILD -999,2500 TENS -999.2500 GR -999,2500 NRAT -999.2500 PEF -999,2500 SSHV -999,2500 LL -999,2500 SS1 -999.2500 iLO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999,2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 -999.2500 ~SS -999.2500 LU -999.2500 SS2 -999,2500 ILM -999,2500 DT -999,2500 CALl -999.2500 RNR4 -999.2500 NCNL -999,2500 QSS -999,2500 LU -999.2500 SS2 -999,2500 ILM -999,2500 OT -999,2500 CALl -999,2500 RNRA -999,2500 NCNL -999.2500 QSS -999.2500 LU -999,2500 SS2 -999,2500 !LM -999,2500 DT -999,2500 CALI -999,2500 RNRA -999,2500 NCNL -999,2500 QSS -999,2300 LU -999,2500 SS2 -999,2500 !LM -999,2500 OT -999.2500 CALl -999,2500 RNRA -999,2500 NCNL --999.2500 QSS -999,2500 LU -999,2500 SS2 -999.2500 iLM -999.2500 DT -999.2500 CALl -999.2500 RNR4 -999.2500 NCNL -999.2500 QSS -999,2500 LU -999,2500 SS2 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.25~0u -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OIO.H02 VERiFICATiON LISTING PAGE 20 OEPT 2700.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RHO~ -999.2500 DRHO NPHi -999.2500 OPHi FCNL -999.2500 LSHV QLS -999,2500 TENS LS -999.2500 LITH GR 68.6875 DEFT 2600.0000 SFLU SP -999.2500 GR GR -999.2500 TENS RH08 -999.2500 DRHD NPHi -999.2500 DPHI FCNL -999.2500 LSHV' ~LS -999.2500 TENS LS -999.2500 L!TH GR 64.3125 DfPT 2529.5000 SFLU SP -999.2500 GR GR -999.2500 TENS RHOB -999.2500 DRHO NPHI -999.2500 DPHI FCNL -999.2500 LSHV QLS -999.2500 TENS LS -999.2500 LITH GR 32.0313 ~ FILE TRAIL~ ~,-- :IL ~ NAM~ :EDIT SERVIC~ NAME : VERSION # : DATE : MAXIMUM L:NGTH : FiLE TYRE : NEXT FiLE NAME : -999.2500 ILD -999.2~00 TENS -999.2500 GR -:999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 'LL -999.2500 SSi -999.2500 ILD -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF --999.2500 SSHV -999.2500 LL -999.2~00 SS1 -999.2500 ILO -999.2500 TENS -999.2500 GR -999.2500 NRAT -999.2500 PEF -999.2500 SSHV -999.2500 LL -999.2500 SS1 .00t 1024 e~: TAPE TRAILER ~ SERVICE NAME :EDIT DATE :87/02/ 2 ORIGIN :FSiA TAPE NAME : CONTINUATION ~ :OI NEXT TAPE NAME : COMMENTS :LiERARY TAPE -999.2500 !LM -999.2500 DT -999.2500 CALI -999.2500 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2500 SS2 -999.2500 ILM -999.2500 DT -999.2500 CALI -999.2300 RNRA -999.2500 NCNL -999.2500 QSS -999.2500 LU -999.2300 SSZ -999.2500 ILM -999.2500 OT -999.2500 CALi -999.2500 RNRA -999,2500 NCNL -999.2500 QSS -999.2300 LU -999.2500 SS2 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP 010.H02 VERiPICATiON LiSTiNG PAGE 21 ~:~ R~EL. TRAiL=R~ ~$ SERVIC=~ NA~q~. ::DIT DATE :87/02/ 2 ORiGiN : REEL NAME :S ~~ CONTINU4TION ~ :O! NEXT REEL N4ME : COMMENTS :LIBRARY TAPE