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Home My WebLink About186-105Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 01-29 (PTD 186-105) EV Camera 4/09/2022 Please include current contact information if different from above. 186-105 T36484 Kayla Junke Digitally signed by Kayla Junke Date: 2022.04.27 10:47:36 -08'00' 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,610'None Casing Collapse Structural Conductor 470 Surface 1,950 / 2,670 Production 4,760 Scab Liner 5,410 / 7,500 Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Monty Myers Contact Email: Contact Phone: 223-6784 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 9,257'9,563'9,215'2,488 None 17.I hereby certify that the foregoin g is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Sean McLaughlin sean.mclaughlin@hilcorp.com Drilling Manager Tubing Grade: Tubing MD (ft): 8,251' / 8,042' 8,489' / 8,265' 8,650' / 8,413' Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 028329 186-105 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21604-00-00 Hilcorp North Slope, LLC PBU 01-29 Prudhoe Bay Field / Prudhoe Oil Pool Length Size 13Cr80 / L-80 TVD Burst 28' - 8,358' / 8,456' - 8,763' 7,240 / 8,430 MD 6,870 1490 3,450 / 4,930 32' - 112' 32' - 2,509' 30' - 9,253' 32' - 112' 32' - 2,509' 3,004' - 8,233'7" x 4-1/2" 9-5/8" 20" 13-3/8" 80' 9,576' 2,477' 3,004' - 8,455' Perforation Depth MD (ft): 30' - 9,606' 9,314' - 9,382' 5,451' 8,996' - 9,056' February 1, 2022 4-1/2" 12.6# 4-1/2" Baker S-3 Packer 4-1/2" Baker SB-3 Packer 5-1/2" Baker SB-3 Packer ory Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 11.9.2021 By Samantha Carlisle at 12:30 pm, Nov 09, 2021 321-573 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.11.09 12:25:48 -09'00' Monty M Myers Variance to 20 AAC 25.112(i) approved for alternate plug placement. DLB 11/09/2021 X BOPE test to 3500 psi. 10-407 MGR29NOV21 DSR-11/10/21 2,488 dts 11/30/2021 11/30/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.30 11:23:49 -09'00' RBDMS HEW 12/1/2021 To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin Drilling Engineer Date: November 9, 2021 Re: PBU 01-29 Sundry Request Sundry approval is requested to set a whipstock and plug the perforations as part of the drilling and completion of the proposed 01-29A CTD lateral. Proposed plan for 01-29A Producer: A ~2400’ MD coil tubing sidetrack will be drilled with Nabors CDR2 rig. A 4-1/2” x 9-5/8” High Expansion Wedge will be set pre-rig, in the 9-5/8” casing, and cemented with service coil. The rig will mill a 3.80” window off of the High Expansion Wedge. The well will kick off in the Sag and land in Zone 2. Then the well will then build up to Z4 before dropping to Z2 at TD (3 cross cuts between Z4 and Z2). The proposed sidetrack will be completed with a 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This Sundry covers plugging the existing perforations via the pre-rig cement down squeeze, liner cement job, or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start in February 2022): 1 Fullbore MIT-IA to 2500 psi 2 Eline Set HEW 8830’ 3 Service Coil Mill XN nipple with a LH motor/mill assembly 4 Service Coil Cement the whipstock in place, plug parent wellbore perfs 5 Fullbore MIT-T to 2500 psi 6 Valve Shop Bleed wellhead pressures down to zero. 7 Valve Shop Bleed production, flow and GL lines down to zero and blind flange. 8 Operations Remove wellhouse and level pad. Rig Work: x Reference PBU 01-29A PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,488 psi 2. Mill Window 3. Drill Build and Lateral 4. Run and Cement Liner* 5. Freeze Protect and RDMO 6. Set LTP* (if needed), RPM log and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) Sean McLaughlin CC: Well File Drilling Engineer Joseph Lastufka 907-223-6784 Sundry 321-573 Separate PTD 24 hour notice to AOGCC. BOPE test to 3500 psi. -00 DLB -00 DLB Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee k`(D -k05 • • 2-(0 WELL LOG TRANSMITTAL#902694153 DATA LOGGED /Ni/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. October 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 01-29 Run Date: 8/28/2015 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 01-29 Digital Log file, Interpretation Report 1 CD Rom 50-029-21604-00 Production Profile (Final Field Print) 1 Color Log 50-029-21604-00 scAtta r 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: MAizadzo„.11') kvo-k 05 • • 2 �Z1co PRINT DISTRIBUTION LIST BAKER t5-3( 05•0'L A Please sign and return one copy of this transmittal fc HUGHES oz.-au (mandatory) 0 14 � Petrotechnical Data Center, LR2-1 DATA LOGGED "4/2015 WELL NAME 5 DIFFERENT WELLS 900 E. Benson Blvd. ivl.K. BENDER (mandatory) Anchorage, Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE RPM-Wireline (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: September 3,2015 TODAYS DATE: 24-Sep-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: CANIZARES EMAIL: (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) A B C D L.I.S. FILM PERSON ATTENTION #OF PRINTS_#OF COPIES#OF COPIES#OF COPIES#OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 1 1 1 1 Attn:Ricky Elgaricio A= 05-02A_RPM_PNC3D_RAW_03SEP2015_BH I.meta ATO 3-344 700 G Street Anchorage,AK 99510 B= *(Folder 1 on cd/dvd) 05-02A RPM_PNC3D_RAW_O3SEI 2 ExxonMobil,Alaska RECEIVED' 1 1 1 Attn:Lynda M.Yaskell and/or G G Y Leonardo Elias SEP 2 8 2015 3700 Centerpointe Dr.Suite 600 Anchorage,AK 99503 AOGCC 3 State of Alaska-AOGCC ,,/ 1 1 1 1 !Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 SCANNED AUG 1 7 2016 4 DNR-Division of Oil&Gas 0 I 0 I I I I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5 I T I TOTALS FOR THIS PAGE: 2 1 1 1 0 0 TOTALS FOR ALL PAGES: 2 1 1 1 0 0 10/n t /n9 Schlumberger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2525 Samball Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503.2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job* Log Description Date BL Color CO K -11 AY1M -00033 SOUP SURVEY u j*( fEa 09/12/09 1 1 L4 -30 AWL8-00031 PRODUCTION PROFILE Q j /f1.C/ 08/06/09 1 1 P2 -31 AP30 -00045 LDL 19L/ 63 -34.1 07/11/09 1 1 01-29 B6JE -00009 PRODUCTION PROFILE /t 08/11/09 1 1 J -22A 1369K -00013 PRODUCTION PROFILE j 08/30/09 1 1 W-44 B149.00071 INJECTION PROFILE IJ-Se_ 1 r I 09/06/09 1 1 12-25 13581 -00010 INJECTION PROFILE L 08/22/09 1 1 L5-33 AYKP -00051 SBHP SURVEY 09/01/09 1 1 P2-48 069K -00015 SBHP SURVEY it, 09/01/09 1 1 Z -28 869K -00016 INJECTION PROFIL V 9 _1 a -4 Is 3 09/19/09 1 1 O-02A AP3Q -00054 IBP/LDL j L}''_ .'"t 07/24/09 1 1 N -10A AXBD-00040 MEM PROD PROFILE --el L• C 08/25/09 1 1 W -24 AWJ1 -00044 MEM INJECTION PROFILE U c{if(.- 0 Vq1D8/15/09 1 1 V -03 B2NJ -00021 MEM PROD PROFILE aS, (S' 1 09/03/09 1 1 H -148 B2WY-00026 MEM PROD PROFILE '4.-) 08/27/09 1 1 P1 -01 AY1M -00031 INJECTION PROFILE t"[(t 1 6 �7 08/20/09 1 1 P1 -05 B581-00009 PRODUCTION PROFIL €JG�� y/ NK -10 B2WY -00023 MEM INJECTION PROFILE D I J 08/22/09 1 1 13 -27A B2NJ -00019 MEMORY SCMT Hee 1 101 08/13/09 1 1 18.0213 B2WY -00021 MEMORY SCMT ry a --du -7-0- 08/19/09 1 1 a� y NK -38A AYKP -00049 USIT r'�f s I L 08/17/09 1 1 06-09 SWL8- 00028 USIT I d 5 07/30/09 1 1 13 -03A 09AKA0150 OH MWDILWD EDIT 441 a 17f 07/06/09 2 1 C -18B B2NJ -00017 MCNL 1Zligmag,Fs 08/09/09 1 1 1- 35/0 -25 869K -00011 RST 7' 7 08/26/09 1 1 04 -35A AXBD -00025 MCNL d 64 _Oa _T! 05/13/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. k leiNE t p 1 i 'L Z ;SI Anchorage. AK 09503 2838 f I�� l ~~~ ~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~"ti`' ~~ '.~;~ ,.~ „}~;t,f ..."~4,.~>~~~ -~ ~ ._ . ~og Description Date BL 08/28/09 NO. 5342 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color CD 07-14C 09AKA0145 OH MWD/lWD EDIT 08/01/09 2 1 01-10 ANHY-00104 RST - L 08/11/09 1 1 01-29 B6JE-00009 RST OS/12/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503-2838 ~ ~ ~ UNDER EVALUATION: O1-~TD #1861050) Sustained Casing Prue on the IA d... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] I Sent: Thursday, March 19, 2009 7:53 AM ~~ (~ ~`~~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Seltenright, Ana Maria; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 01-29 (PTD #1861050) Sustained Casing Pressure on the IA due to TxIA Comm Attachments: 01-29.pdf; 01-29 TIO Plot.doc Hi all, Well 01-29 (PTD #1861050) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 2360/2240/0 on 03/18/09 when a TIFL failed confirming TxIA commun' 'on. The well has been reclassified as Under Evaluation and may continue to be produced while efforts are made to mitigate the communication. The plan forward for the well is as follows: 1. Well Integrity Engineer: Evaluate gas lift valve change out 2. Slickline: Change out GLVs 3. DHD: Re-TIFL post GLV change out A wellbore schematic and TIO plot have been included for reference. «01-29.pdf» «01-29 TIO Plot.doc» Please call with any questions. Thank you, Anna ~u6e, ~ E. ' WeIE Integrity Coordinator . ~ 1 GPB Welis Group ~~~~~~ t~Q~ ~ ~,'v~ Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 3/24/2009 PBU 01-29 PTD 1861050 3/19/2009 TIO Pressures 4:GGi i , 3:000 • # Tbg --/- IA 2,000 -~- OA OOA ~~ OOOA 1AGU i -~ On ~ j I 121cUlOd 12127108 01103/03 01/10109 011171(19 011241u9 01/31109 02/07109 U211~'09 02121it19 02128109 63107/09 03/14109 ~ ~._.... __..__...._,__,._......d,.... .,.....~_ _ _...~. ,_._........,W.~....,.__....__ • TREE = CNV WELLHEAD = MCEVOY ACTUATOR BAKER C KB. ELEV..- 70' BF. ELEV..- .-...,_.m_. KOP = 5300' Max Angle = 30° @ 8900' ~. Datum MD = 9171' Datum ND = 8800' S5 20" CONDUCTOR, -1 110, 91.5#, H-40, O = 19.124" 01-29 SAFETY NOTES: *** 4-112" GMROME TUBING *** I9-5/8" CSG, 47#, L-80 HYD 563, O =8.681" I 1826' 9-518" BOWFIJ CSG PATCH 1912' 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 2509' {TOP JOINT IS 68#, L-55 BTRS, ID = 12.415") 9-5/8" X 7" BKR ZXP LTP, ID = 7.00" 3004' 9-518" X 7" BKR FLEXLOCK 3019' LNR HGR , ID = 6.190" Minimum ID = 3.725" @ 8753' 4-1 /2" OTIS XN NIPPLE 4-112" TBG, 12.6#, 13CR-80 VAM TOP, 835$' .0152 bpf, ID = 3.958" 4-112" SCAB WR, 12.6#, L-80 IBT-M, ID = 3.958" $455' 4-112" TBG STUB (12/06/D8} 8456' 1864' --~ 9-518" ES CEMBVTFR 1877' 13-3/8" X 9-518" ISOZONE ECP, ID = 8.619" 2140' 4-112" HES X NIP (9-CR}, O = 3.813" f1A S I_ ~T MANDRELS ST NID ND DEV TYPE VLV LATCH PORT DATE 5 3337 3337 1 MMG DO BK 16 01!22!09 4 5086 5086 3 MMG SO BK 20 01122!09 3 6411 6332 23 MMG DMY BK 0 01/10!09 2 7612 7442 21 MMG DMY BK 0 01110/09 1 8143 7940 19 MMG DMY ~ BK 0 01110/09 8221' --i4-112" HES X NIP (9-CR), ®= 3.813" 8251' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 8326' 4-112" HES X NIP {9-GR}, ID = 3.813" 8358' 4-1/2" WLEG (9-GR), O = 3.958" $4.24' 7" X 4-112" PORTED XO, ID = 3.958" $465' 4-112" UNIQUE OV ERSHOT 84$5' 9-518" X 4-112" BKR 56-3 PKR, ~ = 3.860" 8556' 4-112" HES X NIP, ID = 3.813" 4-1/2" TBG,12.6#, 13GR-80 VAMACE, ~ 8619' 8626' 4-112" UNIQUE OV ERSHOT, ID = 3.935" .0152 bpf, ID = 3.958" 8649' 4-112" X 5-1/2" XO, ~ = 3.958" " ' 4-112 TBG STUB {05-18-02) 8622 ' ID = 3 860" 1/2" BKR SB 3 PKR " $650 . , - X 5- 9-5/8 8665' 7-5/$" BKR MILLOUT EXTENSION,' ID = ? 4-112" TBG-IPC, 12.6#, L-80 BTG $764' 8671' --f 7-5(8" X 4-1 /2" XO, ~.? = 3.958" .0152 bpf, ID = 3.958" $752' 4-1(2" OTtS XN NIP, tD = 3.725" PERFORATION SUMMARY REF LOG: BRCS ON 06/08/86 ANGLE AT TOP PERF: 28° @ 9314' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19(93 4 9309 - 9314 S 07119193 4 9314 - 9329 O 07/27/93 4 9372 - 9382 O 07127/93 4 9382 - 9383 S 07/19/93 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" ~~ 9606' DATE REV BY COMMENTS DATE REV BY COMMENTS O6/10/8S PKR 141 ORIGINAL COMPLETION 05!21102 D16 RWO 01111!09 D16 RWO 02/24109 HB/JMD DRLG DRAFT C/O (02110109) 02124/09 ?/ PJC DRLG DRAFT CORRECTIONS 8763' -~4-112" BAKER SHEAROUT SUB 8764' 4-112" WLC-G, ID = 3.958" $778' ELMD TT LOG XXIXXIXX 8~8' ' i 9-5t8" MARKER JOINT 5563' H PBTD 9610' ( TD PRUDHOE 8AY UNIT WELL: 01-29 PERMIT No: 1861050 API No: 50-029-21604-00 SEC 8, T10N, R15E, 1017' FNL & 1511' FWL BP Exploration {Alaska) STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION p G~G1 Y E) REPOT OF SUNDRY WELL OPE~IONS 1~~G G ~~ i o r~ 2 9 2009 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate A(a~S~ ~l~f$H$~s0~3d11 ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ~ef1~~1Qf3~B ^ 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 188-105 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21604-00-00 . 7. KB Elevation (ft): 70, 9. Well Name and Number: PBU 01-29 - 8. Property Designation: 10. Field /Pool(s): ADL 028329 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9610' ' feet true vertical 9257' feet Plugs (measured) None Effective depth: measured 9563' feet Junk (measured) None true vertical 9215' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2509' 13-3/8" 2509' 2509' 3450 1950 Intermediate Production 9606' 9-5/8" 9606' 9253' 6870 4760 Liner Scab Liner 5461' 7" 3004' - 8465' 3004' - 8243' 7240 5410 f ~w F-. r~~.r, I~~aokr::;' ~~L-+ lh G~ t~~Fl cy Perforation Depth MD (ft): 9314' - 9382' Perforation Depth TVD (ft): 8996' - 9056' 4-1/2", 12.6# $ 13Cr80 8358'; Tubing Size (size, grade, and measured depth):. a-1/2" 1 R# I _Rn Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer $ 8251' $ (2) 9-5/8" x 4-1/2" Baker'SB-3' packers 8489' $ 8650' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut, pull $ dress off tbg to 8460'. Run 7" Scab Lnr (7", 26#, L-80 w/ crossover to 4-1/2"), cement w! 160 Bbls of Class 'G' (898 cu ft / 774 sx). Cut, pull $ dress off 9-5/8" casing to _1906'. Run 9-5/8" tieback to 1 913' $ cement w/ 131 Bbls Class 'G' (736 cu ft / 629 sx). Run new Chrome tubing. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®~Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 308-467 Printed Name Terrie Hubble Title Drilling Technologist Q~ ~ Prepared By Name/Number: 8 Signature Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~~ ~=t:!~ ~ Q t~0~ ~ J~ Submit Original Only nor • 01-29, Well History (Pre Rig Workover) Date Summary 11/25/2008 T/I/O=SSV/540/120, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0 psi). Functioned LDS, all moved freely. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (650 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 12/2/2008 T/I/O = SSV/620/120. Temp = SI. OA FL (OA FL campaign). No AL. OA FL Q 36' (2.25 bbls). SV, WV, SSV =closed. MV =open. IA, OA = OTG. NOVP. 12/5/2008 WELL S/I ON ARRIVAL. PULL P-PRONG & 4-1/2" PX PLUG BODY (intact) FROM 8 556' MD. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 12/5/2008 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 450/550/100 SET 4-1/2" HES FASDRIL PLUG C«~ 8520' MD AS PER PROGRAM. CORRELATED TO TBG TALLY DATED 19-MAY-02. 12/6/2008 LRS MIT-T TO 1000 PSI FOR 10 MINS PASSED LOST 20 PSI. LRS MIT-IA TO 1000 PSI FOR 10, MINS PASSED LOST 60 PSI. JET CUT 4-1/2" TBG C~ 8456' MD. IN 1ST FULL JOINT ABOVE PKR AS PER PROGRAM. TIED INTO TBG TALLY DATED 19-MAY-02. INFORMED DSO OF WELL & TREE VLV STATUS. FINAL T/I/0= 270/300/100. WELL LEFT S/I, JOB COMPLETE. 12/6/2008 T/I/0=300/560/120 Temp=Sl Assist E-line, MIT T PASSED to 1000 psi. MIT IA PASSED to 1000 psi,, Pumped 6.8 bbls crude down Tbg to achieve test pressure for MITT. Tbg lost 20 psi in 10 mins. Bled TP to 300 psi. RD from Tbg, RU to IA. Pumped 1 bbl of meth into IA to achieve test pressure for MITIA. IA lost 60 psi in 10 mins. Bled IAP. FWHP's = 280/0/120. E-line in control of well upon LRS departure. 12/7/2008 T/I/0=400/560/100 Temp = SI MIT OA PASSED to 2000 osi; Pumped 2.2 bbls 60°F crude into the OA to achieve test pressaure. OA lost 60 psi in 1st 15 mins and 20 psi in 2nd 15 mins for a total pressure loss of 80 psi in 30 mins. Bled back (-2 bbls). FWHP's = 400/560/140. DSO notified of following upon departure: SWV, WV, SSV = S/I. MV, IAV, OAV =Open. OA tagged. 12/15/2008 CMIT-TxIA to 1000psi. JOB POSTPONED DUE TO WEATHER. 12/16/2008 Road to location, RU to Tbg. 12/17/2008 T/I/0=580/580/80 MIT-T to 1000 psi PASSED, MIT-IA to 1000 psi FAILED, MIT IA to 500 psi FAILED. Pumped 8.6 bbls Crude down Tbg to reach test Pressure. IA did not track. Pumped 1.7 bbls of crude into the IA to reach test pressure, Tbg did not track. Rig back up to Tbg and pump an additional 5 bbls of crude to reach 1500 psi. IA started to track but did not climb above 1140 psi with 1500 psi on the Tbg. Tbg/IA lost 120/100 psi in 15 min. MIT-T to 1000 psi PASSED 2nd Attempt. Loss of 40 psi 1st 15 min. Loss of 0 psi 2nd 15 min. MIT-IA to 1000 PSI FAILED Pumped 1.1 bbls crude down IA to reach test pressure. Loss of 100 psi 1st 15 min, Loss of 100 psi 2nd min. ,MIT-IA to 500 FAI D att .mom Gained 30 psi 1st 15 min. Gained 30 psi 2nd 15 min, stabilized at 580 psi. Final WHP's = 300/560/80 Valve positions at the time of departure =Swab, Wing, SSV =Closed /Master, IA, OA =Open /Master & IA are tagged with MIT data. 12/18/2008 Load fluids, road to location. Job postponed due to inadequate space /Rig move. 12/19/2008 T/I/O = 620/620/0. Temp= S/I Circ out (RWO Prep). Page 1 of 2 01-29, Well History (Pre Rig Workover) Date Summary 12/20/2008 T/I/O = 300/620/0. Temp= S/I Circ out/ CMIT TxIA Failed to 2500 n:;, lJnable to establish LLR amt to small (RWO Prep. Pumped 5 bbls meth down tubing followed by 650 bbls crude, taking returns from IA to Flowline of well #28. CMIT TxIA -jumper line rigged up from T to IA to equalize pressure. First test - T/I pressured up to 2500 psi with 9 bbls crude. T/I lost 240/240 psi in 15 minutes. Second test - T/I pressured up to 2500/2500 psi with 1 bbl crude. T/I lost 240/240 psi in 15 minutes. Third test - T/I pressured up to 2500/2500 psi with 1.4 bbls crude. T/I lost 220 psi in first 15 minutes and 260 psi in second 15 minutes. For a total of 480/480 psi in 30 minutes. Fourth test - T/I pressured up to 2500/2500 psi with 1.9 bbls crude. T/I lost 280 psi in 15 minutes. Fifth test -Shut jumper line. T/I pressured up to 2360/2500 psi with .8 bbls crude. T/I lost 20/300 psi in first 15 minutes and 60/120 psi in 2nd 15 minutes. For a total of 80/420 psi in 30 minutes. Bled down pressure to 20/0/0. Monitored pressure for 30 min. pressures at T/I 20/220/0. IA pressure increased. FWHP's=20/0/0 AT DEPARTURE VALVES in followir 12/20/2008 T/I/O = 0/600/0 Circ-Out. (Pre RWO) Pumped 10 bbl methanol spear, 340 bbls 9.8# Brine down tbg taking returns up IA to 01-28 Flow Line. 12/21/2008 Circ-out. Pumped total of 867 bbls 9.8# Brine down Tbg taking returns up IA to 01-28 Flow Line. Freeze Protected w/ 40 bbls diesel, U-tube Freeze protect into IA. Freeze Protect 01-28 Flow line w/ 7 bbls neat methanol, 103 bbls crude. Final WHP's = 0/0/0 Valve positions at the time of departure: Swab, Wing, SSV =Closed /Master =Open / IA, OA =Open to gauges / Hardline valves closed /Swab, Wing, SSV on well 01-28 are closed. 12/22/2008 T/I/O -0/0/O,Set 5-1/8" Grav "K' BPV # 606 thru tree. tag C«~ 108". 1-2' ext. used, pre-rig, no problems. Page 2 of 2 BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To Hours Task Code NPT 12/28/200805:00 - 10:00 5.00 MOB Pi~ 10:00 - 22:00 12.00 MOB P 22:00 - 23:00 1.00 MOB P 23:00 - 00:00 1.00 ~ MOB ~ P 12/29/2008 00:00 - 00:30 0.50 MOB P 00:30 - 01:00 0.50 RIGU P 01:00 - 01:30 0.50 RIGU P 01:30 - 12:00 10.50 RIGU P 12:00 - 18:00 I 6.001 RIGU I P 18;00 - 22:30 4.50 RIGU P 22;30 - 00:00 1.50 RIGU P 12/30/2008 100:00 - 01:15 i 1.251 WHSUR ~ P 01:15 - 04:15 I 3.001 KILL I P 04:15 - 04:45 0.50 KILL P 04:45 - 06:00 1.25 WHSUR P 06:00 - 08:30 I 2.501 WHSUR ~ P 08:30 - 09:00 0.50 ~ WHSUR ~ P 09:00 - 11:00 ~ 2.00 ~ WHSUR ~ P 11:00 - 15:00 ~ 4.00 ~ BOPSUF(P 15:00 - 15:30 0.50 BOPSU P 15:30 - 22:00 6.50 BOPSU P Spud Date: 5/28/1986 Start: 12/16/2008 End: Rig Release: 1/11/2009 Rig Number: Phase ~~, Description of Operations __ ~ _ - - - PRE PJSM. Lower and secure Derrick. Pull off Well Slot and move to edge of Pad. Wait on Security. PRE Road Ri From M-16 to DS 01. PRE Stage Rig at Drill Site 01 entrance. Doyon and Nabors Tool Pushers discuss a plan forward for moving the Rig around Nabors Rig 2ES presently rigged up at DS 01-05B. PRE Rig move around completed with no problems. Stage Rig on side of Drill Site. PRE Remove Booster Tires. PRE PJSM. Raise and pin Derrick. PRE Move Rig over and pick-up BOP Stack. PRE BOP Stack work. Nipple down Single Gate Ram Preventer. Nipple up Double Gate Ram Preventer. Install 3 1/2" x 6" VBR in Sin le Gate Preventer. Install 4 1/2" x 7" Gate Ram Preventer. Work on Mud Pump #1 PRE Bridle down. Rig up Blocks to Top Drive. Hook up Compensators. Install torque pins. Install Blind Rams. Tighten all BOP bolts. Finish bolting up Mud Pump #1. Stand back BOP Stack on stump. PRE Spot Rig over 01-29 Well Slot. Check measurements . Had to double mat for Wellhead /BOP Stack cl .Shim Rig. PRE Rig up manifold and make up circulating lines. Install double IA Valves. OAP = 110 psi. IAP = 0 psi. DECOMP Plck u Lubricator. Attem t to ressure test. Trouble shoot Test Pump (ice in low section of the suction line, ok now). Test Lu ricator. Pull BPV. La w (spot Pump #2). DECOMP PJSM. Hook up line to Production Tree. Bleed pressure from OA to 0 psi. Take on 9.8 Brine in Pits. Pressure test lines and Mud Pump #1 at 1000/3700 psi. Good test. Bring Pump on line. Took 4.0 bbls to fill hole. Pump a 20 bbls Hi-Vis sweep. Circulate Well with hot 9.8 Ib/gal Brine at 7.0 bpm/680. Pumped a total of 625 bbls. DECOMP Monitor Well. Pick up Lubricator and BPV. No flow. DECOMP Blow down lines. Break circulating line off of Tree. Install Lubricator and test. Set Grey K BPV with lubricator, UD Lubricator. Set Test Dart with T Bar. DECOMP Test 8PV from below to 1000 si. Roll pump to maintian pressure above a 1000 psi. Leak very tight, bleed off is about 100 psi in a little over 5 mins. No fluid seen at tree during test. Test BPV and Dart from above to 3500 osi for 10 mins., Good Test all tests charted. DECOMP Blow down circulating lines. R/D lines and Rig up cement line to circ manifold then to IA valve. DECOMP PJSM with Crew. N/D Grey Tree and Adapter Flange. Clean Wellhead and inspect Lock Down Screws. Check hanger threads with 5-1/2" Rt Hand Acme XO, 18-1/4 turns. DECOMP Nipple Up BOP's with Upper and Lower Pipe Rams, Blind Rams and Annular Preventer. DECOMP Fill Stack and Rig Up to Test BOP's DECOMP Test BOPE er BP procedure and AOGCC regulations. Test all components to 250-psi low and 3500-psi high. Hold and chart all tests from 5-minutes. BP WSL and Doyon Toolpusher witness all tests. Test VBRs with 4", 4-1/2" and 7" Testjts as Printed: 1/19/2009 4:13:04 PM i BP EXPLORATION Operations Summary Report Legal Well Name: 01-29 Common Well Name: Oi-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 i Date From - To I Hours Task '! Code NPT 12/30/2008 15:30 - 22:00 6.50 BOPSU P 22:00 - 22:30 I 0.501 WHSUR I P 22:30 - 23:30 1.001 WHSUR I P Page 2 of 14 ~ Spud Date: 5/28/1986 Start: 12/16/2008 End: Rig Release: 1 /11 /2009 Rig Number: Phase ~ Description of Operations DECOMP appropriate. Test Annular preventer with 4" Test jt. Jeff Jones with AOGCC waived witness of BOP Test. DECOMP Blow down Choke manifold and Kill line. Vac out BOP stack. Cameron tech pull Test Dart using T-bar. DECOMP PU Dutch Riser System and MU. PU DSM lubricator. Pressure test Lubricator to 500-psi. Good Test. Pull Type K 23:30 - 00:00 0.50 WHSUR P DECOMP 12/31/2008 00:00 - 00:30 0.50 PULL P DECOMP 00:30 - 01:30 1.00 PULL P DECOMP 01:30 - 02:00 0.50 PULL P DECOMP 02:00 - 03:00 1.00 PULL P DECOMP 03:00 - 04:30 1.50 PULL P DECOMP 04:30 - 05:30 1.00 PULL P DECOMP 05:30 - 06:00 0.50 PULL P DECOMP 06:00 - 14:00 8.00 PULL P DECOMP 14:00 - 14:30 0.50 PULL P DECOMP 14:30 - 15:00 0.50 CLEAN P DECOMP RD DSM Lubricator. LD Lubricator arid Type K BPV. RD Dutch Riser System. PU Double Spear dressed with 3.947" Nominal catch grapples. RIH. Set down 20K-Ibs 5' higher than expected. Lower grapple engaged in Tbg hgr. Disengage grapple and POH. Lower grapple is flared out. Unable to break down grapple at Rig due to lack of tongs to ,handle spear. Baker fisherman take spear back to shop to replace bent lower grapple. While waiting, RU to LD 4-1/2" Tbg. Attem t to en a e 4-1/2" 12.6# 13cr80 Tb & Tb H r 'th Doubles ear dressed with 3.885" Nominal catch grapples. RIH and tag at same depth as before. First grapple tagging an obstruction 'ust below tubin han er. Discuss situation with day WSL and RWO superintendent. Decide to screw into tubing hanger threads with XO and landing jt. Hold PJSM and Risk assessment with Rig crew, BP WSL, Doyon Tourpusher, Cameron wellhead tech and Baker fisherman. Discuss hazards of tubing hanger parting and ensure that everyone is clear of the rig floor, mezzanine and cellar while pulling the tubing hanger free. Ensure everyone knows proper number of RH turns to MU to tubing hanger. Derate maximum allowable pull from 270K-Ibs to 200K-Ibs including blocks (expected string wt in 9.8-ppg brine is -131 K-Ibs) LD double spear. MU XO from DP to 4-1/2" IF and then XO from 4-1/2" IF to 5-7/8" RH Acme han er to threads). RIH and screw into tubing hanger with 18-3/4 RH turns. Ensure that IA is still on a vac. BOLDS. Pull on tubing hanger gradually increasing pull from 65K-Ibs up to 140K-Ibs. Hanger ulls free at 140K-Ibs. PU wt with han er free = 135K-Ibs. Pull hanger to floor. Back out landing jt and LD hanger.. ID of XO below tubin han er was cali eyed at 3-13/16". RU and CBU at 10.2-BPM with 1300-psi. Steady sand returns seen throw hout entire circulation. Monitor well -Static. Pump Dry Job. RD circulating equipment. Blow down circulating line. LD 4-1/2" 12.6# 13cr80 Vam Ace Tubin to i e shed. Pull to joint 51 (full joints) then Top X Nipple. Pull jts 52 to 77 then first GLM. Pull jts 78 to 118 to second GLM. Pull jts 119 to 149 to third GLM. Pull jts 150 to 177 to fourth GLM. Pull 178 to 196 to fifth GLM. One Cut Joint = 18.78 ft. Flare on Cut = 4-7/8" Rig Down Handling Equipment for Drill Pipe. Clean and Clear Rig Floor. Set Wear Ring and Bring BHA Components to Rig Floor. Printed: 1/19/2009 4:13:04 PM BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 01-29 01-29 WORKOVER DOYON DRILLING INC DOYON 16 Date I From - To I Hours I Task I Code', NPT 12/31/2008 115:00 - 16:00 16:00 - 00:00 1/1/2009 100:00 - 00:30 1.00 CLEAN P 8.001 CLEAN I P 0.501 CLEAN I P 00:30 - 01:30 1.00 CLEAN P 01:30 - 02:00 0.50 CLEAN P 02:00 - 05:00 3.00 CLEAN P 05:00 - 06:00 I 1.001 CLEAN 1 P 06:00 - 06:30 0.50 CLEAN P 06:30 - 07:30 1.00 EVAL P 07:30 - 10:30 3.00 EVAL P 10:30 - 11:00 0.50 EVAL P 11:00 - 12:00 12:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:30 15:30 - 20:30 20:30 - 00:00 1.001 EVAL I P Spud Date: 5/28/1986 Start: 12/16/2008 End: Rig Release: 1 /11 /2009 Rig Number: Phase II Description of Operations DECOMP M/U Dress Off BHA. BHA consists of Dress-off shoe, Wash pipe Extensions with Internal Dress-off Mill, Boot basket, 9-5/8" Csg Scraper, Bumper Sub and 9(ea) 4-3/4" Drill Collars. Total BHA length = 316.88' with -18' of washover capability. DECOMP RIH with Dress-off BHA on 4" DP from Pipe Shed. Break Circulation every 30-stds RIH. 180-stds RIH at 2140-hrs. DECOMP RIH with Dress-off Milling BHA to 8443'. Obtain Milling Parameters. PU wt = 165K, SO wt = 160K, Rot Wt = 165K. Turn pumps on at 5-BPM with 420-psi. Rotate at 50-RPM with 3K-Ibs-ft of free torque. Wash down and tag top of tubing Wash down to final shoe de th of 8478' 18' of swallow . PU and slide over stump while pumping three times. PU and slide over stump without pumping. Tag stump lightly, rotate and weight falls off, allowing shoe to slide down over stump to no go on internal mill without further issues. Repeat with identical results. DECOMP Pump 20-bbl High Visc sweep and chase at 10-BPM with 1700-psi. Seeing some oily sand returns throughout. circulation. Get globs of gray mushy material at bottoms up. Very fine dark sand seen after sweep came back. DECOMP Monitor well -Static. Pump 15-bbl dry job. LD single jt of DP. Blow down Top Drive. DECOMP POH with Dress-off BHA Stand back 4" DP in derrick. 45-stds out at 0345-hrs. 70-stds out at 0430-hrs. DECOMP Stand back 3-stds of 4-3/4" DCs in derrick. LD Dress-off BHA and Casing scraper. Boot Baskets contained a small amount of sand. DECOMP Clear and Clean Rig Floor, move subs from BHA outside. DECOMP P/U HES RTTS for 9-5/8" 47# Csg. M/U and RIH with 3 Stands of 4-3/4" HT 38 DC's. DECOMP RIH with RTTS on DP from Derrick to 8356 ft (85 Stands) DECOMP P/U Single and Set RTTS at 8381 ft COE. R/U up to pressure test Casing below RTTS DECOMP Pressure Up Below RTTS to 3500 psi. Pressure Test from 8381' to Fasdril Pluo at 8520 ft to 3500 psi for 30 mins. Good 2.00 EVAL P DECOMP R/D Test Equipment. POOH and Stand Back DP. POOH with RTTS to -4000 ft. 0.50 EVAL P DECOMP P/U Single and Set RTTS at 4014 ft COE. R/U to Pressure Test Casing. 0.50 EVAL P DECOMP Pressure Test casing from 4014' to surface. Test to 3500 psi 0.50 EVAL P DECOMP Release RTTS. RD all circulating lines. 5.00 EVAL P DECOMP Safet t nd down regarding injury to Roustabout in Pipe shed. Perform incident investigation. Hold meeting with Rig Crew, Doyon tool & tour pushers, BP WSLs, ADW HSE Advisor and Doyon Safety. Dicuss incident, Doyon and ADW safety expectations, ways to improve safety performance, PJSMs and task hazard analyses. 3.50 EVAL P DECOMP Drop 2-1/4" DP rabbit. POH with RTTS from 4014'. Stand back DP and 3-stds of 4-3/4" DCs in derrick. Recover 2-1/4" DP rabbit just above DCs. LD 9-5/8" HES RTTS. Printed: 1/19/2009 4:13:04 PM n BP EXPLORATION Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours I Task Code; NPT 1/2/2009 100:00 - 07:00 7.00 CASE P 07:00 - 07:30 I 0.501 CASE I P 07:30 - 17:00 9.501 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 19:30 1.50 CASE P 19:30 - 20:30 1.00 CASE P 20:30 - 21:30 1.00 CASE P 21:30 - 22:00 I 0.501 CEMT P 22:00 - 22:30 ~ 0.50 ~ CEMT ~ P 22:30 - 23:00 0.50 CEMT I P 23:00 - 00:00 ~ 1.00 ~ CEMT ~ P 1/3/2009 100:00 - 01:30 1.501 CEMT P Start: 12/16/2008 Rig Release: 1 /11 /2009 Rig Number: Page 4 of 14 ~ Spud Date: 5/28/1986 End: Phase Description of Operations TIEB1 Steam, Drift & Strap 7" 26# L-80 BTC casino in pipe shed; Steam thread protectors. Drift all casing by pulling a 6.151" drift on cable thru the joint. Strap all joints threads off (BTC threads). Strap all casing jewelry. RU on Rig Floor to run 7" 26# L-80 BTC Scab liner while finishing casing tally. TIEB1 PJSM with Rig Crew, Doyon Casing, Baker Completions. Discuss casing running operations on rig floor and pipe shed. TIEB1 P/U and run 4-1/2" x 9-5/8" Uni ue Overshot on 4-1/2" Tb Baker Type II Landing Collar with ball on seat and sand, 4-1/2" x 7" XO with holes, 7" Float Collar, 1 Jt of 7" Casing, 1 Jt of 7" Casing with Baker Insert Landing Collar, 131 joints of 7", 26# L-80 BTC Csg. Baker Flex Lock Liner Hanger and Baker ZXPN Liner Top Packer. 132 free floating straight vane centrilizers were run from the hanger down. TIEB1 Change out handling equipment and MU Liner Hanger and Liner Top Packer assembly. RU to circulate. TIEB1 Circulate 1-1/2 liner volumes at 4-BPM with 300-psi. RD circulating equipment. TIEB1 RIH with 7" 26# L80 BTC Scab liner on 4" DP to 8400'. Fill pipe every 5-stds. TIEB1 Obtain parameters: PU wt = 207K-Ibs, SO wt = 200K-Ibs. Did not observe assin over 4-1/2" tubin stum .Tag shear pins at 8463'. Observe shear pins shearing with 5K-Ibs over string weight. Continue in hole and no go at 8467', setting 20K-Ibs down on stump. PU 10' and RIH again. Verify no go at 8467'. PU 2' off of no go to park bottom of Unique Overshot at 8465'. TIEB1 PU Baker Cement head and MU to 4" DP. RU cement line to Cement head. TIEBi Pump 20-bbl Safe Surf O pill and spot on bottom. Pump at 5-BPM with 460-psi. While spotting pill, hold PJSM with Rig Crew, Doyon Tour pusher, BP WSL, Baker techs, Schlumberger cement crew and CH2MHill truck drivers. Discuss hazards associated with pressure, spills, extreme cold weather. Highlighted the importance of good communication. Reviewed all procedures for cementing. TIE61 Schlumberger finish RU and prepping equipment. Schlumberger pump 5-bbls of water to fill lines and prime pump. Pressure test all cementing lines and head to 4700-psi. Good test. TIEB1 Schlumber er batch u and um 156.5-bbls of 15.8- Class Gcement. Initial pump rate = 4.1-BPM with 467-psi. Stage pumps up to 5.3-BPM with 801-psi. Final pump rate = ~ 4-BPM with 462-psi. TIEBI Dro Drill i e wi er dart. Displace 156.5-bbls of 15.8-ppg Class G Cement. Begin displacement at 6-bpm with 50-psi. Slow pump to 1.5-BPM at 270-stks. Do not see DP wiper dart latch liner wiper plus. Bring pump back up to 5.5-BPM. Catch cement at 820-stks of displacement pumped. Pump at 4.5-BPM with 700-psi. Pump pressure climbs to 1690-psi at 3-BPM with 1500-stks pumped. Continue pumping and reducing rate to limit pressure below 2200-psi to keep Liner Top Pkr from setting prematurely. Pressure steadily increasing with decreasing pump rate. Pumping at 2-spm with 2489-psi at Pnntetl: 1/ly/"LUUS 4:1:i:U4 PM BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Spud Date: 5/28/i986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours i Task Code ~~~ NPT Phase ~ Description of Operations 1/3/2009 00:00 - 01:30 1.50 CEMT P TIEB1 1911-stks. Pump stalls at 1915-stks while pumping at 1-s with 2670-psi and when attempting to begin pumping agar pressure increases rapidly indicating Liner Top Pkr is set. Final pressure is 2790-psi. Continue to pressure up to 3800-psi to release from acker. Set 40K-Ibs down on packer to confirm set. 01:30 - 02:00 0.50 CEMT P TIE61 CIP at 0135-hrs. Check floats -holding. Pressure up to 500-psi, rotate and PU so that running tool is clear of Liner top. Bring pumps online and pump 20-bbl Biozan pill at 7-BPM with 420-psi. Chase pill at 12-BPM with 940-psi. See a minimal amount of cement returns ahead of BU. Circulate another bottoms up without seeing cement returns. 02:00 - 03:00 1.00 CEMT P TIEB1 RD Baker Cement head. 03:00 - 04:00 1.00 CEMT P TIEB1 Pump full wellbore volume at 12-BPM with 840-psi. No cement seen during entire circulation. Blow down Top Drive. 04:00 - 06:00 2.00 CEMT P TIEB1 POH with. Baker running tool. Stand back 4" DP in derrick. LD running tool. Dogs on running tool were sheared and packer is _ P/U Cement head and break down. 06:00 - 07:30 1.50 CEMT P TIEBi Vac out BOP Stack. MU BOP stack washing tool. Flush stack with Citric acid pill. LD stack washer. Clean drip pan, pull riser to clean, clean and inspect air boots, reinstall riser. 07:30 - 08:30 1.00 CEMT P TIE61 P/U and M/U drill out BHA with a 6-1/8" used tooth bit, 2 boot baskets, 7" csg scraper, bit sub, bumper sub, xo, and 3 stds of 4-3/4" drill collars. Total length = 299.72'. 08:30 - 12:00 3.50 CEMT P TIEB1 RIH with drill out BHQ,, Obtain Parameters orior to aoino_ throw h liner to at 3004': P/U wt = 85K-Ibs, S/O wt = 93K-Ibs. Did not see 7" liner to . 12:00 - 12:30 0.50 CEMT P TIEB1 Continue RIH from 7600'. Tagged wiper plug at 8188'. Obtained parameters prior to drilling out cement: P/U wt = 160K-Ibs, S/O wt = 155K-Ibs, Rot wt = 158K-Ibs. Rotate at 60-RPM w/ 4K-Ibs/ft free torque. 12:30 - 16:00 3.50 CEMT P TIEB1 Drilled out wi er lu with 15K-Ibs WOB and 3-5K-Ibs/ft of torque. Pumps on at 10-BPM with 2360-psi. Continue drilling cement from 8189' to landing collar at 8370'. 16:00 - 19:00 3.00 CEMT P TIEB1 Drilled float equipment from 8370' to 7" x 4-1/2" XO at 8420'. Maintained above parameters, but reduce WOB to 5K-Ibs. Did not see any indication of float collar. 19:00 - 20:30 1.50 CEMT P TIEB1 PJSM with rig crew and CH2MHILL for displacing well to clean 9.8-ppg brine. Ensure truck drivers and spill champion had radios and could stay in good communication with each other and the rig. Ensure that everyone working outside had proper foot wear and cold weather gear. Pumped 40-bbl hi-vis sweep followed by 437-bbls of 9.8-ppg brine at 10-BPM with 2200-PSI. 20:30 - 21:00 0.50 CEMT P TIEB1 Shut down pumps and monitor well -Static. Stand back 1-std and blow down the top drive. Rig up testing equipment and fill lines. Pressure test lines to 3500-psi. Good test. 21:00 - 23:30 2.50 CEMT P TIE61 Pressure test 7" liner to 3500- si for 30-charted min t Confer with RWO engineer and decide that 125-psi loss over test interval was acce table. 23:30 - 00:00 0.50 CEMT P TIE61 RD test equipment. 1/4/2009 00:00 - 01:30 1.50 CEMT P TIEB1 PJSM on Slipping and Cutting Drilling line. Assign positions to rig crew, review procedure and discuss hazards associated Printed: 1/19/2009 4:13:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: 01-29 Page 6 of 14 ~ Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 1/4/2009 00:00 - 01:30 1.50 CEMT P TIE61 with slipping and cutting line. Grease all equipment on Rig Floor. Adjust equalizer bar on drawworks. 01:30 - 04:00 2.50 CEMT P TIEB1 POH with Drill Out BHA from 8363'. Stand back 4" DP in derrick. 04:00 - 05:00 1.00 CEMT P TIE61 Stand back 3-stds of 4-3/4" DCs. LD Drill out BHA. Recover -1-1/2 cups of Cement and quarter size chunks of metal in boot baskets. 05:00 - 05:30 0.50 EVAL P TIEB2 Clean and Clear Rig floor. Send all un-needed Baker tools off of floor. Prepare Rig Floor for RU E-line. 05:30 - 06:00 0.50 EVAL P TIEB2 PJSM & RU E-line. 06:00 - 08:30 2.50 EVAL P TIEB2 RIH with USIT for 9-5/8" 47# casin to 3000 ft. Log Up in Corrosion and Cement Modes. Found Top of Cement at -1985' in 9-5/8" x 13-3/8" Annulus. Log showed very good cement bond below. 08:30 - 09:30 1.00 EVAL P TIEB2 R/D Eline Tools. E-Mail Logs to town and discuss with Town Engineer on cut depth. Decide on cut depth of 1905 ft., 09:30 - 11:00 1.50 EVAL P TIEB2 Pressure Test Casing to 3500 psi for 30mins, charted -good test. R/D Test Equipment and Blow Down Lines. 11:00 - 11:30 0.50 CASE P TIEB2 M/U HES 9-5/8" RBP on sin le 'oint of DP. 11:30 - 15:00 3.50 CASE P TIE62 RIH with RBP to 2026 ft. Attempt to set RBP. Unable to set RBP, make multiple attempts. RBP fell off during setting attem t. RIH to to of liner and find RBP. Latch RBP, P/U off bottom and set to confirm plug latched up. Pull up hole with RBP to 2026 ft. Set RBP and confirm, top of RBP at 2026 ft. 15:00 - 18:00 3.00 CASE P TIEB2 Pull up hole 1 stand. Pressure Test RBP to 1500 psi for 10 mins on chart. Good Test. R/U Sand Funnel and Dump 2200 Ibs of 20-40 river sand on top of RBP, 18:00 - 19:00 1.00 CASE P TIEB2 RIH with one stand of DP and Tag Top of Sand at 1991 ft. POOH with DP. L/D RBP Running Tool. 19:00 - 19:30 0.50 WHSUR P TIEB2 Blow Down lines to BOP Stack. Pull Wear Ring. Pull Flow Riser 19:30 - 20:00 0.50 WHSUR P TIEB2 PJSM on N/D BOP's and Removing Tubing Spool. Two tested barriers in place, Fasdril Plug in 4-1/2" Tbg Tail and RBP at 2026 ft. N/D BOP stack and spacer spool. 20:30 - 21:00 0.50 WHSUR P TIEB2 N/D tubing spool and remove from cellar. 21:00 - 21:30 0.50 WHSUR P TIEB2 Vac fluid off top of 9-5/8" emergency slips. Cameron Reps inspect emergency slips and function LDSs. Clean ring groove and install new API ring. 21:30 - 22:00 0.50 WHSUR P TIEB2 N/U Drilling Spool. 22:00 - 23:00 1.00 BOPSU P TIE62 Nipple Up BOP stack. Install riser. 23:00 - 23:30 0.50 BOPSU P TIEB2 Pressure test BOP and Wellhea break to 250-psi low and 3500-psi high. Hold and chart each test for 5-minutes. Test witnessed by BP WSL and Doyon Tourpusher. Good test. 23:30 - 00:00 0.50 BOPSU P TIEB2 RD test equipment. Blow down lines. Gather Casing Cutter BHA components. 1/5/2009 00:00 - 00:30 0.50 FISH P TIE62 MU 9-5/8" Casin Cutter BH .BHA consists of: 8-1/4" Multi-String Cutter, XO, Stabilizer, Pump Out Sub and XO. Total BHA length = 13.4'. 00:30 - 01:00 0.50 FISH P TIEB2 RIH with 9-5/8" Casing Cutter BHA on 4" DP from Derrick. Test Hardline to rental flowback tank to 2000-psi. Good Test. 01:00 - 01:30 0.50 FISH P TIEB2 Obtained parameters: P/U wt = 65K-Ibs, S/O wt = 70K-Ibs. Continue RIH and tag sand at 1971'. Stand back 1-std of 4" DP. Printed: 1/t 9/2009 4:13:04 PM • BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~, Task Code NPT Phase Description of Operations 1/5/2009 01:30 - 02:00 0.501 FISH P TIEB2 1 P/U single from pipeshed to work with while attempting to 02:00 - 03:00 1.00 FISH P ITIE62 03:00 - 03:15 I 0.251 FISH P (TIEB2 03:15 - 03:30 0.25 FISH P TIEB2 03:30 - 04:15 0.75 FISH P TIEB2 04:15 - 04:30 0.251 FISH P ITIE62 04:30 - 05:30 1.00 FISH P TIEB2 05:30 - 06:30 1.00 FISH P TIEB2 06:30 - 07:00 0.50 FISH P TIEB2 07:00 - 10:00 3.00 FISH P TIEB2 10:00 - 11:00 I 1.001 FISH I P I ITIE62 11:00 - 11:30 0.50 FISH P TIE62 11:30 - 12:00 0.50 FISH P TIE62 12:00 - 12:30 0.50 FISH P TIEB2 12:30 - 13:30 1.00 FISH P TIEB2 13:30 - 14:00 0.50 FISH P TIEB2 14:00 - 15:00 1.00 FISH P TIEB2 15:00 - 15:30 0.50 FISH P TIEB2 15:30 - 16:00 0.50 FISH P TIE62 16:00 - 20:30 4.50 FISH P TIEB2 20:30 - 21:30 I 1.001 FISH I P I ITIE62 locate collars of the 9-5/8" casing. While locating collars, pumps on at 5-BPM with 560-psi, to open casing cutter tool. Located collars at 1900' and 1939'. UD single. PJSM with rig crew, CH2MHILL, Little Red Services, and Baker Rep on cutting 9-5/8" csg, and circulation cycles that follow. Rig up Little Red to standpipe and pressure test lines to 3000-psi. Good test. Position cutter at 1905' and cut: ROT wt = 70K-Ibs, 3-5K-Ib/ft TO, pumps on at 8-BPM with 1140-psi. Saw pressure drop to 600-psi and torque increase of 7K-Ibs/ft. Confirm cut with Baker Rep. Monitor well and observe minimal amount of gas at surface asp fluid level slowly dropping. Little Red pump 20-bbls of 120-deg F Diesel at 2-BPM down drill pipe. Shut annular on drill pipe. OA showing 360-psi when open to Flow Back Tank. Little Red pump additional 80-bbls of 120-deg F Diesel at 2-BPM. Line up and pump 20-bbl High Visc Sweep at 4-BPM with 310-psi. Chased with 5-bbls of diesel to ensure lines do not freeze while allowing diesel in annulus to soak. OA pressure = 75-Ibs while circulating. Shut in OA and allow diesel to soak for 1-hr. OA pressure = 50-psi with no increase. R/D Little Red. Chase sweep out with 160-bbls 9.8-ppg brine at 7-BPM with ICP = 970-psi and FCP = 1200-psi Allow fluid to soak in OA and monitor pressure. OA pressure decreased from 30-psi to 15-psi. Pump 20-bbl Safe-Surf-O sweep followed by 20-bbl Hi Visc sweep. Chase with 140-bbls of 9.8-ppg brine at 7-BPM with 1200-psi. Monitor well -Static. Open annular and close OA. CBU x2 at 10-BPM with 1290-psi. Monitor well -Static. POH from 1905' standing back 4" DP in derrick. UD String cutter BHA. Clear and clean rig floor. M/U 9-5/8" csg spear. Engage 9-5/8" cso with spear. ,Overpull to ensure catch. Cameron tech BOLDS. Noticed minimal flow out of OA before pulling 9-5/8". Monitor well. Static. Wait for water to stop draining. Drain BOP stack. Water was from differential pressure of fluid column in stack. Pull 9-5/8" Emergency Slips off seat. Pull casing free with 120K-Ibs. String wt = 115K-Ibs. Safety Meeting on UD Casing. Circulate 1-1/2 wellbore volumes (423-bbls) at 6.5-BPM with 60-psi. B/D Top Drive. Remove Emergency Slips. UD Spear. C/O Handling Equipment and Rig Up to UD 9-5/8" 47# csg. UD 9-5/8" 47# csg from 1905' to surface. Avg Breakout torque = 35-40K-Ibs/ft. Recover 48-full jts of Csg, 2-cut jts and 12-centralizers. Cut jt from wellhead = 7'. Cut Jt from downhole = 6.05'. RD all 9-5/8" Csg handling equipment. Clean and Clear Rig Floor. PflfltBtl: 1/ly/"LUUy 4:1:1:U4 YM • BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: 01-29 Common W Event Name Contractor Rig Name: Date ~ ell Name: 0 : Name: From - To 1-29 WORKO DOYON DOYON Hours VER DRILLIN 16 Task G INC Code . NPT 1/5/2009 21:30 - 22:30 1.00 BOPSU P 22:30 - 00:00 1.50 BOPSU P 1/6/2009 00:00 - 02:00 2.00 BOPSU P 02:00 - 03:00 1.00 BOPSU P 03:00 - 03:30 0.50 FISH P 03:30 - 05:00 1.50 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 06:30 0.50 FISH P 06:30 - 07:00 0.50 FISH P 07:00 - 08:00 1.00 FISH P 08:00 - 08:30 0.50 FISH P 08:30 - 10:00 1.50 CASE P 10:00 - 12:00 2.00 CASE P 12:00 - 16:00 4.00 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 18:00 1.50 CEMT P Spud Date: 5/28/1986 Start: 12/16/2008 End: Rig Release: 1 /11 /2009 Rig Number: Phase ', Description of Operations TIEB2 RU all BOPE test equipment. Set test plug. Fill lines & BOP stack. TIE62 PJSM on testing BOPE with Rig Crew, Doyon Tourpusher, BP WSL &BP WSLf. Discuss positions of people, hazards associated with high pressures and review procedure. Test BOPE per AOGCC regulations and BP procedures. Test using 4" & 4-1/2" Test jts. Test to 250-psi low and 3500-psi high. Hold and chart all tests for 5-minutes. BP WSL and Doyon Tourpusher witness all tests. AOGCC rep Lou Grimaldi waived witness of test at 2155-hrs on 1/5/09. TIE62 Continue testing BOPE per BP procedures and AOGCC regs. Test with 4" & 4-1/2" Test jts. Test to 250-psi low and 3500-psi high. Hold and chart all tests for 5-minutes. All tests witnessed by BP WSL and Doyon Tourpusher. AOGCC rep Lou Grimaldi waived witness of test at 2155-hrs on 1/5/09. TIE62 RD BOP test equipment. Pull Test plug. TIE62 PU 9-5/8" Csg Spear. Release spear from 9-5/8" Csg cut jt from wellhead. LD Spear & Cut Jt. TIEB2 PJSM on MU Casin Dress off BHA,with Rig Crew, BP WSL and Baker Fishing rep. Discuss hazards, BHA components, and postions of people. MU Casing Dress off BHA. BHA consists of: Dress off shoe, Washpipe Extensions, Internal Dress off Mill, Junk Basket, PxP sub, 13-3/8" Csg Scraper, Bit Sub, Float Sub, Bumper Sub, XO and 3-stds of 4-3/4" DCs. Total BHA length = 310.2' with 6.95' washover capability. TIE62 RIH with Casing Dress off BHA on 4" DP from derrick. TIEB2 Dress off casing stub at 1905 ft to 1906 ft. Make multiple runs over top of casing stub to clean up, last run had torque very smooth as running over stub. Unable to get over stub without r t tion still required slight rotation to get shoe over. Pump 20-bbl high vise sweep and 6.5 bpm at 270 psi. Chase Sweep with 9.8-ppg brine at 12 bpm and 720 psi. TIE62 Monitor well -Static. B/D Top Drive. TIE62 POH from 1913' to 310'. Stand back 4" DP in derrick and L/D Dress Off BHA. TIEB2 Clear and Clean Rig Floor. TIEB2 R/U to run 9-5/8" cs . TIEB2 PJSM on running 9-5/8" tieback with rig crew, Baker Reps, HES Rep, Doyon csg rep, Doyon toolpusher,and BP WSL. Run 9-5/8" 47# L-80 H dril 563 casin tieback. Casing tieback consist of 9-5/8" casing patch, ECP, ES cementer, XO, and 47-jts of 9-5/8" 47# L-80, Hydril 563 casing. Use torque turn services on every connection. Optimum make up torque = 15,800 Ibs/ft with Jet Lube Seal Guard. Baker lock all connections below the ES cementer. TIE62 Continue to RIH with 9-5/8" 47# L-80 Hydrill 563 Casing from 86' to 1900'. TIE62 Obtain Parameters prior to engaging csg patch: P/U wt = 115K-Ibs, S/O wt = 120K-Ibs. RIH and tag 9-5/8" csg stuma at 1905'. Rotate slightly and slide over stump. Engage csg patch__ by setting down 35K-Ibs. P/U 50K-Ib to set grapple. Pull test 9-5/8" cs atch to 250K-Ibs. TIEB2 PJSM with rig crew, Doyon toolpusher, BP WSL, HES Rep, Printetl: 1/19/2009 4:13:04 PM J BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code', NPT Phase ~ Description of Operations 1/6/2009 16:30 - 18:00 1.50 CEMT P TIEB2 and BP WSLf to change out bails and rig up cement head. Hazards identified and task leaders assigned for each task. Change out bails and rig up cement head. 18:00 - 19:00 1.00 CEMT P TIEB2 Pressure test all surface lines to 3,500 psi. Good test. P/U 100K-Ibs on 9-5/8" string. Pressure Test csg to 1,000-psi_for 10-charted minutes. Good Test. Pressure up to 1550-psi. Observe acker settin b ressure bleed off to 1150- s'. Pressure up to 1550- si to close ECP Continue to pressure up to 2,000-psi. Pressure test csg to 2,000-psi for 10 charted minutes. Good test. Bleed pressure to 0-psi. Pressure u to open ES cementer. ES cementer o ened at 2700- si. 19:00 - 20:00 1.00 CEMT P TIEB2 Circulate throw h ES cementer at 5-BPM with 270-psi until 9.8-ppg brine returns are 80 degrees F. Held PJSM with rig crew,Schlumberger, CH2MHILL, Baker, and Halliburton. Discuss hand injuries, spill potential, good communication throughout job, high pressure lines, proper weather gear, and positioning of people for job. 20:00 - 20:30 0.50 CEMT P TIEB2 Test Schlumberger lines to 4,000-psi. Good test. 20:30 - 21:00 0.50 CEMT P TIEB2 Schlumber er um 131-bbls of 15.8# cement at 5-BPM with 850- si. 21:00 - 22:00 1.00 CEMT P TIEB2 Shut in cementers and drop plug. Schlumberger kick plug out with 5-bbls of fresh water. Displace cement at 5-BPM with 600-psi. See cement returns at surface with 110-bbls displacemen pumpe proximate) 20-bbls of cement return to surface. Bump plug with 129.2-bbls of 9.8-ppg brine pumped. Pressure up and close ES cementer with 1500-psi. CIP at 2152- hrs. 22:00 - 22:30 0.50 CEMT P TIE62 Check floats -holding. Flush BOP stack and OA valve with D-110 pill. L/D HES cement head. Blow down all lines. Vac out stack and 9-5/8" csg. 22:30 - 23:00 0.50 BOPSU P TIEB2 Split BOP stack in preparation for installing slips and making Wachs cut. 23:00 - 00:00 1.00 WHSUR P TIE62 Cameron re s lace emer enc sli s. Slack off 100K-Ibs on slips and set. Cameron RU Wachs cutter and cut 9-5/8" Csg. 1/7/2009 00:00 - 01:00 1.00 WHSUR P TIEB2 LD 16.17' Cut Jt of 9-5/8" Csg. Remove Drilling Spool from BOP stack. 01:00 - 03:00 2.00 WHSUR P TIEB2 NU new tubin s ool and BOP stack. Install double IA valve. VR plug installed behind blind flange in rig side valve. Record new RKB measurements. 03:00 - 03:30 0.50 WHSUR P TIEB2 Test 9-5/8" packoff to 3800-psi for 30-minutes. Good test. 03:30 - 05:00 1.50 BOPSU P TIEB2 Finish torquing all bolts on BOP stack and Tubing spool using Sweeney wrench. Set test plug in tubing spool and RILDSs. RU to test BOP and tubin s of breaks. Fill Stack. Test breaks to 250-psi low and 3500-psi high. Hold and chart each Pest for 5-minutes. RD BOP test equipment. Blow down all lines. BOLDS and pull test plug. 05:00 - 08:00 3.00 CEMT P TIEB2 Clean and Clear Rig Floor. Wait on cement to reach 1000-psi compressive strength per Schlumberger UCA. 08:00 - 09:30 1.50 CEMT P TIEB2 k Drill-out B : 8-1/2" milled tooth bit, 2-ea Boot Baskets, Lubricated Bumper Sub, 9-ea 4-3/4 Drill Collars. 09:30 - 10:30 1.00 CEMT P TIEB2 RIH with drill-out BHA on DP from Derrick to prepare to drill out the 9-5/8" Cement Track. 10:30 - 12:00 1.50 CEMT P TIE62 Circulate heated 9.8-ppg brine from Pits, 5-BPM at 150-psi to Printed: 1/19/2009 4:13:04 PM • BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To .Hours Task Code NPT Phase ', Description of Operations 1/7/2009 10:30 - 12:00 1.50 CEMT P TIEB2 enhance cement cure. 12:00 - 14:30 2.50 CEMT P TIEB2 PJSM for Day Tour Crew to drill out the 9-5/8" cement track. Get parameters: P/U wt 70K-Ibs, S/O wt 75K-Ibs, Rot wt 75K-Ibs, 80-RPM, Free Torque 2K-Ib-ft. RIH to tag at 1856', start milling with 5K-Ibs WOB, 6-BPM, 200-psi. The ES Cementer is located at 1859', D-16 RKB. See the Cementer at 1245-hours. Drill through at 1320-hours. Continue through to 1873'. P/U and pull through ES Cementer area at 1859' to 1856' with the bit to check for drag. No drag coming u~or RBIH. Continue in with pump on, reduced to 2-BPM at 20-psi, stop rotating, and tag something at 1877'. Expected sand to ' -100' dee er at 19T3'. , s art rotating, bang pump up to 7-1/2-BPM at 240-psi, 50-RPM. Mill down the full stand to 1902'. Saw lots of cement coming over the shakers while milling from 1877' to 1902', but seeing almost no resistance. 1400-hrs, P/U stand #17 and continue rotating and circulating down to cleanout depth of 1969'. POH slowly to back ream, seeing no drag for a full stand out. Stop rotating, S/D pump and let DP slowly drop through to a dry tag on top of sand at 1977'. POH 5' to circulate a HiVis sweep. 14:30 - 15:00 0.50 CEMT P TIEB2 Circulate a 20-Bbl HiVis sweep at 10-BPM, 600-psi and get cement across shakers with lots of chunks of rubber, bits of aluminum, and small mushy lumps of a gummy substance, but no traces of oil or diesel. The returns cleaned up after all the sweep came across the shakers. 15:00 - 15:45 0.75 CEMT P TIE62 Dry drill on top of sand at 1977'. Decide to start pump and bring up to 3-BPM to work on something hard sitting on top of the sand. Use 4K to 12K-Ibs WOB, 2-K-Ib-ft rotating torque. Stop pump and continue to dry drill with same WOB range. Fi- Wally see a breakthrou hand sto at 1978' to circulate. 15:45 - 16:15 0.50 CEMT P TIE62 Circulate 140-Bbls, 10-BPM at 580-psi, see some sand and cement across shakers. 16:15 - 17:00 0.75 CEMT P TIEB2 POH and S/B DP in Derrick. 10-stands POH at 1635-hours. 15-stands at 1645-hrs. All 17-stands of DP S/B in Derrick at 1650-hours. S/B 3-stands of 4-3/4" DCs in Derrick. 17:00 - 17:30 0.50 CEMT P TIEB2 B/O and L/D drill-out BHA. Empty Boot baskets and get 15-Ibs of cuttings and debris. 17:30 - 18:00 0.50 CEMT P TIEB2 Close Blinds and test casing to 3500-psi recorded on chart for 30-minutes. Hold PJSM on MU RCJB BHA with Rig Crew, BP WSLs and WSLf, and Baker fisherman. Discuss hazards associated with MU BHA and order of tools run. Also discuss cleaning pits and the hazards for individuals engaged in that task. Finally discussed what would be done if "man down in the pits" were called. As the pitwatcher and derrickman would both be engaged at the time, their duties were passed on to two of the floorhands. 18:00 - 18:30 0.50 CEMT P TIEB2 MU RCJB BHA. BHA consists of 7" RCJB, 2-Boot Baskets, 9-5/8" Csg scraper, Bit sub, Bumper sub, XO and 9 (ea) 4-3/4" DCs. Total BHA length = 305.94'. 18:30 - 19:00 0.50 CEMT P TIEB2 RIH with RCJB BHA on DCs and 4" DP from derrick. 19:00 - 19:30 0.50 CEMT P TIEB2 Obtain parameters: PU wt = 75K-Ibs, SO wt = 76K-Ibs, Rot Wt = 75K-Ibs. Rotate at 60-RPM with 3K-Ibs/ft of free torque. RIH to 1979'. Drop ball and pump down at 3-BPM with 150-psi' Printetl: 1/19/2009 4:13:04 PM • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase ~, Description of Operations CEMT P TIEB2 Ball seats and pressure rises to 500-psi. Bring pumps up to 1/7/2009 19:00 - 19:30 0.50 19:30 - 20:30 I 1.001 CEMT I P 20:30 - 21:00 0.50 CEMT P 21:00 - 22:00 1.00 CEMT P 22:00 - 22:30 I 0.501 CEMT I P 22:30 - 23:30 I 1.001 CEMT I P 23:30 - 00:00 I 0.50 I CEMT I P 1/8/2009 100:00 - 00:30 0.501 CEMT P 00:30 - 01:00 0.50 CEMT P 01:00 - 01:30 0.50 CEMT P 01:30 - 02:30 I 1.001 CEMT I P 02:30 - 03:30 I 1.001 CEMT I P 03:30 - 04:00 0.50 ~ CEMT ~ P 04:00 - 05:00 ~ 1.00 ~ CEMT ~ P 05:00 - 06:30 1.50 CEMT P 06:30 - 07:30 1.00 CEMT P 07:30 - 08:30 1.001 DHB ~ P 7-BPM with 2020-psi. Wash down 15' to 1994'. TIEB2 CBU x2 at 7-BPM with 2020-psi. Heavy sand returns from first bottoms u throu h second. Sand cleans up after second BU. Stand back 1-std and blow down Top Drive. TIEB2 POH w/ RCJB BHA. Stand back 4" DP in derrick. TIEB2 Stand back 3-stds of DCs. Break out RCJB and empty. Recover 3-large pieces of aluminum and a 4"-long piece of wire seal ring. Baker fisherman redress RCJB. LD 9-5/8" Csg Scraper. Empty Junk Baskets and recover -1 cup of sand and several small, thin pieces of metal. TIEB2 MU RCJB BHA #2 exce t DCs. RCJB BHA is the same as first run minus the 9-5/8" Csg scraper. Total BHA length = 302.57'. TIE62 Hole fill is not operational due to riser length._Change Out TIEB2 Safety Stand Down with Tower's Crew, Doyon Toolpusher, BP WSL and WSLf to discuss leak from riser and leak and spill potentials across the operation of Doyon 16. Each person pinpoints a spill potential related to their job throughout Rig during their tour and what they are going to do to eliminate the hazard while at work. TIE62 Safety Stand Down continues on rig while discussion is held with Pickworth crew (who had just come off tour), BP WSL and WSLf and Doyon Tourpusher about leaks that occured in the last 24-hrs and spill potentials across the operation of Doyon 16. Discussed leak and spill prevention and what every member of the crew will do to prevent spills in the future. TIEB2 Pull Riser. Install second air boot. Reinstall Riser. TIE62 RIH with RCJB BHA #2 on DCs and 4" DP from Derrick to 1911'. TIE62 Obtain parameters prior to washing down above RBP. P/U wt = 72K-Ibs, S/O wt = 77K-Ibs, ROT wt = 75K-Ibs. Rotate at 6-rpms at 6-BPM with 2240-psi. Drop ball and pump down at 3-BPM at 150-psi. Ball seats and pressure raises to 520-psi. Pump 5-bbls Hi-Visc Sweep at 6-BPM with 2200-psi to prevent flow back while making connection. M/U single and continue to wash down at 6-BPM with 2200-psi to 2010'. TIE62 Pump 15-bbl Hi-Visc Sweep and chase at 6-BPM with 2200-psi. Heave sand returns with fine rubber when sweep returns. Circulate another bottoms up until returns clean up. TIEB2 Monitor well. Static. L/D single. Blow down Top Drive. POH with RCJB BHA #2 from 2010' to 305', standing back 4" DP in derrick. TIEB2 Stand back 3-stds of 4-3/4" DCs in Derrick. LD RCJB BHA #2. Recover two small pieces of aluminum from RCJB. Recover -1-cup of sand and very small metal debris from boot baskets. TIE62 PU HES RBP Retrieval tool and RIH on 4" DP from derrick. TIEB2 Park above RBP and get parameters: P/U wt 72K-Ibs, S/O wt 77K-Ibs, bring pumps up to 11.5-BPM at 740-psi. Slowly work down throw h remainin -10' san on f th R P, with COE of RBP at 2030'. Get sand and other assorted small chunks of debris over the shakers. TIE62 Work RBP Run/Pull tool down onto RBP, taking 5K-Ibs, P/U NnntBtl: 1/15/LUUy 4:1;i:U4 YM • BP EXPLORATION Operations Summary Report Legal Well Name: 01-29 Page 12 of 14 Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours I Task Code , NPT I Phase Description of Operations 1/8/2009 07:30 - 08:30 1.00 DHB P TIEB2 and no RBP. Repeat twice without success. Rotate 1/2 turn and repeat stacking out 5K-Ibs on RBP, P/U and no success latchin onto RBP. P/U, rotate 1/2-turn and repeat stacking out 5K-Ibs on RBP, P/U and latched onto RBP, set back down and pump HiVis sweep and get lots of sand across shakers; drop pump rate to -9.5-BPM to keep from pumping all retums overboard into cuttings tank. P/U slowly with RBP while making a slow, right-hand rotation and RBP comes free, Drop back down past where RBP had been set and do not stack out. Prepare to POH. 08:30 - 11:00 2.50 CEMT P TIEB2 Monitor well, well dead. PJSM. POH and S/B DP in Derrick. PJSM. B/O and L/D 4-3/4" DCs. L/D RBP. 11:00 - 15:30 4.50 CLEAN P DECOMP Move 2-7/8" handling equipmerit to Rig Floor. Bring 2-7/8" BHA components to Rig Floor. Load and strap 2-7/8" PAC DP and 3-1/8" DCs in Plpe Shed. PJSM to M/U 2-7/8" BHA and to RIH with same. BHA: 3-5/8"Junk Mill, 9-ea 3-1/8" DCs, 6-ea 2-7/8" PAC DP, 7" Casing Scraper, Bumper Sub, Oil Jar, Pump-out Sub. 15:30 - 20:00 4.50 CLEAN P DECOMP RIH 2-7/8" PAC DP and 3-1/8" DCs on DP from Derrick. 20:00 - 20:30 0.50 CLEAN P DECOMP RIH to 8400'. Obtain parameters: PU wt = 156K-Ibs, SO wt 148K-Ibs. Taq 7" x 4-1/2" XO at 8420'. PJSM on displacing well to 8.5-ppg seawater with rig crew, CH2MHILL, Baker Tech, Doyon Tourpusher, and BP WSL. Discuss spill potential, displacement volume, proper line up, good communication, and proper ppe for weather conditions. i 20:30 - 22:00 1.50 CLEAN P DECOMP Pump 20-bbl Hi-Visc Sweep at 6-BPM with 2080-psi. Displace well to 8.5-ppg Seawater at 7-BPM with 2230-psi. 22:00 - 00:00 2.00 CLEAN P DECOMP Be in millin at 8420' with above parameters and 2-4KIbs WOB. Tag ball and seat at 8439'. Increase WOB to 6K-Ibs and pump pressure to 2260-psi. Mill through ball and seat at 8440' (Aluminun insert seat and Phenolic Resin Ball). Shut rotation off and PU above 7"x 4-1/2" XO. Run back through XO and Collar to ensure clean. Continue milling ahead. Taa somethin at 8480'. Mill through obstruction with 3K-Ibs WOB. Continue milling ahead. Tag FasDrill plug at 8518'. See cement and a few small pieces of rubber in returns. 1/9/2009 00:00 - 01:00 1.00 CLEAN P DECOMP Pump 20-bbl High Visc sweep and chase at 7-BPM with 2150-psi. See cement with metal shavings returns at volume pumped that corresponds to the depth of the ball and seat. See heavy cement returns at volume pumped that corresponds to the obstruction tagged at 8481'. Light cement returns just ahead of the sweep. 01:00 - 01:30 0.50 CLEAN P DECOMP Mill through FasDrill olua at 8518'. Mill at 50-RPM with 2-7K-Ibs-ft of torque and 5K-Ibs WOB. Pumping at 7-BPM with 2450-psi while milling. Mill -2' and then well goes on vac. All returns lost immediate) -. Blow down Top Drive and begin filling hole through Kill line at 110-BPH.. 01:30 - 02:30 1.00 CLEAN P DECOMP Continue to RIH, picking up single jts of DP from pipe shed. Push lu remnants out of tail '. Continue R final shoe de th of 8877'. Scrape 7" casing from 8181' to 8420', working each jt of DP top to bottom x3. 02:30 - 10:00 7.50 CLEAN P DECOMP POH from 8877'. LD 4" DP to pipe shed. All 2-7/8" PAC pipe out of 4-1/2" tubing tail at 0315-hrs. Maintain continuous hole Printetl: 1/19/2009 4:13:04 PM • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: 01-29 Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date ~, From - To ~ Hours Task Code NPT Phase Description of Operations 1/9/2009 02:30 - 10:00 7.50 CLEAN P DECOMP fill of 110-BPH while POH. DHD take 3 fluid level shots at 0430-hrs. Unable to pinpoint fluid level. During initial rig up of DHD tools, well was on a vac. By the time DHD rigged down (-10-minutes later), the well was no longer on a vac. Continue POH and LD DP to pipe shed. Maintain continuous hole fill of 110-BPH. 10:00 - 11:30 1.50 CLEAN P DECOMP POH and L/D PAC DP and DCs. Maintain continuous hole fill at 110-BPH. 11:30 - 12:00 0.50 BUNCO RUNCMP Clear and clean rig floor. Maintain continuous hole fill at 110-BPH. 12:00 - 12:30 0.50 BUNCO RUNCMP PJSM to bring Torque Turn equipment to rig floor and to R/U all handling equipment to RIH with the new 4-1/2", 12.6#, 13Cr80, Vam Top completion. Maintain continuous hole fill at 110-BPH. 12:30 - 15:30 3.00 BUNCO RUNCMP R/U and test Torque Turn equipment. R/U 4-1/2" handling equipment. Computer interface for Torque Turning equipment developed problems. Swap out computers and continue troubleshooting. Maintain continuous hole fill at 110-BPH. 15:30 - 00:00 8.50 BUNCO RUNCMP RIH with new 4-1/2" Vam Top tubing completion: WLEG, X-Nipple w/ RHC-M plug, 4-1/2" x 7" Baker S-3 packer, ', X-nipple, 5-ea 4-1/2" GLMs (#5 with DCK Shear Valve), X-nipple, all RIH on 191-joints of new 4-1/2", 12.6-Ib, 13Cr80, VamTop tubing. Utillize Torque Turn services and MU to 4440-Ib-ft of torque. Use Jet Lube Seal Guard on all connections. BakerLok all connections below packer. Full joint #15 RIH at 1700-hours. RIH with GLM #4 at 19:30-hours. 160-jts RIH at 2300-hrs. Maintain continuous hole fill of 110-BPH. ',1/10/2009 00:00 - 01:00 1.00 BUNCO RUNCMP Continue RIH with 4.5" 12.6# 13CR80 Vam Top Tbg. -Utillize Torque Turn services and MU all connections to 4440-Ib-ft of torque. Use Jet Lube Seal Guard thread compound. PU wt = 137K-Ibs, SO wt = 130K-Ibs. Maintain continuous hole fill of 110-BP and begin using 110-degree Seawater for hole fill. 01:00 - 02:00 1.00 BUNCO RUNCMP RD Compensator. PU Tubing hanger and MU using torque turn. PU & MU TCII landing jt. Maintain continuous hole fill of 110-BPH. 02:00 - 03:00 1.00 BUNCO RUNCMP RIH and Land Tubing hanger. Cameron wellhead tech RILDS. Be in fillin hole throu h IA instead of Kill line. RU equipment to reverse circulate packer fluid. Continue to fill hole at 110-BPH. 03:00 - 03:30 0.50 BUNCO RUNCMP RD 4-1/2" handling equipment and clear rig floor. Maintain continuous hole fill through IA at 110-BPH. 03:30 - 04:30 1.00 BUNCO RUNCMP Hold PJSM with Rig crew, Doyon tourpusher, BP WSL and CH2MHill truck driver. Review procedure for reverse circulating, discuss spill potential and appoint task safety managers. Pressure test all circulating lines. Reverse circulate 130-bbls of 110-degree Seawater at 3-BPM with 30-psi. 04:30 - 06:00 1.50 BUNCO RUNCMP Reverse in 290-bbls of of 110-degree seawater treated with Corrosion Inhibitor at 3-BPM with 30-psi. 06:00 - 09:30 3.50 BUNCO RUNCMP PJSM. Break off fill line and drop Ball-Rod. Fill tubing after 15-minutes and it takes 90-strokes to fill from #1 Mud Pump; fluid level in tubing was at -1046'. Build pressure to 3600-psi in PfI11tBtl: 7/19/LUUy 4:1:1:U4 PM a • BP EXPLORATION Legal Well Name: 01-29 Operations Summary Report Page 14 of 14 ~ Common Well Name: 01-29 Spud Date: 5/28/1986 Event Name: WORKOVER Start: 12/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/11/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours'. Task Code NPT i Phase ' Description of Operations 1/10/2009 06:00 - 09:30 3.50 BUNCO RUNCMP tubin and it levels out at 3550- si; recorded for 30-minutes on chart. Bleed down tubin to 1500-psi and S/I tubing. Fill_ annulus to PT the casin at 3500- si. Takes 400-strokes to_ build pressure; fluid level was at 730'. Build pressure to 3600-psi and S/I pump. Record PT on chart for 30-minutes_at 3500- si. Excellent tests. Release pressure from tubing and shear DCK valve. Pump both ways to ensure valve is open. 09:30 - 12:30 3.00 BOPSU P RUNCMP PJSM. Cameron install TWC in hanger. P/T from above to choke and kill lines, circulating manifold, and IA line to cuttings tank. Clean out Mud Pits. 12:30 - 16:00 3.50 BOPSU P RUNCMP Change out rams from double gates. Clean out ram cavities to prepare them for storage. The Double gate body will be removed after the rig has been backed off the well. Remove turnbuckles, riser clamp and drilling riser. N/D BOP stack. 16:00 - 18:00 2.00 WHSUR P RUNCMP Inspect and clean wellhead with supervision from Cameron Tech. N/U Adapter Flange and Tree. 18:00 - 19:00 1.00 WHSUR P RUNCMP Cameron Tech rig up test adapter flange. Test to 5,000-psi for 30-min. Good test. 18:30 - 20:30 2.00 W HSUR P RUNCMP Rig up to test tree. Test to 5,000-psi for charted 10-min. Good test. 20:30 - 22:00 1.50 WHSUR P RUNCMP DSM rig up lubricator to pull TWC from hanger. _Test.lubricator to 500- si. Good test. Pull TWC with 45- si underneath. Bleed off pressure. Verify 0-psi on IA and tbg. 22:00 - 22:30 0.50 WHSUR P RUNCMP RU to circulate diesel freeze protection. 22:30 - 23:00 0.50 WHSUR P RUNCMP PJSM with Rig Crew, Little Red Crew, Doyon Tourpusher and BP WSL. Discuss spill potential, hazards associated with working around high pressure, and assign people to positions. 23:00 - 23:30 0.50 WHSUR P RUNCMP LRS pressure test all lines with diesel to 3500-psi. Good test. 23:30 - 00:00 0.50 WHSUR P RUNCMP Reverse in 140-bbls of 65-degree diesel freeze protection at 2-BPM with 450-psi. 1/11/2009 00:00 - 00:30 0.50 WHSUR P RUNCMP Continue to reverse in 140-bbls of 65-degree diesel freeze protection at 2-BPM with 450-psi. 00:30 - 01:30 1.00 WHSUR P RUNCMP Line up valves and let Tubing and IA U-tube diesel freeze protection. 01:30 - 03:00 1.50 WHSUR P RUNCMP Check pressure on IA and Tbg. IA and Tbg pressure = 110-psi. Bleed 1/4-bbl back to Little Red and both pressures drop to 0-psi. Monitor gauges and pressure stays at 0-psi. Order out DSM lubricator to set BPV. RD rig floor equipment while waiting for lubricator to arrive. 03:00 - 04:00 1.00 WHSUR P RUNCMP Attempt to blow down lines in cellar. Unable to blow down. Cement line in cellar is frozen. Suck back lines to LRS and thaw cement line with steam. Drain tree through wing valve. 04:00 - 04:30 0.50 WHSUR P RUNCMP PU DSM lubricator and BPV. Stab onto tree. Hold PJSM with all rig hands involved in pressure testing the lubricator. r sure t st lubricat r to 500- si. Good test. 04:30 - 05:00 0.50 WHSUR P RUNCMP Set BPV with DSM lubricator. 05:00 - 07:00 2.00 WHSUR P RUNCMP Use LRS to test BPV with diesel to 1000-psi for 10-charted minutes. Secure Cellar and Tree Release riq at 0700-hrc Printed: insizooy aaa:ua rnn rELLHEAD = GRAY CTUATOFt = AXEL B. ELEV = 70' F. ELEV = ? OP= 5300' DRLG DRAFT ' ax Angle = 30 @ 8900 alum MD = 9171' alum TV D = 8800' SS 9 -5/8" 47#, L-80 from 1908' to surface 13-3/8" CSG, 68/ 72#, K-55/ L-80, ID = 12.347" ~~ 2509' 4.5" 12.6# 13Cr-80 tubing Minimum ID = 3.725" @ 8752' 4-1 /2" OTIS XN NIPPLE 4.5" x 7" ported XO--------8424` 4-1/2" Unique Machine Overshot 4-1/2" TBG-VAM ACE, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 1 /2" TBG-PC, 1 Z.6#, L-80, .0152 bpf, ID = 3.958" I $764' PERFORATION SUMMARY REF LOG: BHCS ON 06/08/86 ANGLE AT TOP PERF: 29 @ 9127' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/93 4 9309 - 9314 S 07/19/93 4 9314 - 9329 C 07/27/93 4 9372 - 9382 C 07/27/93 4 9382 - 9383 S 07/19/93 PBTD I~ 9563' 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9606' TD 9610' O 1 .2 ~ SAFETY NOTES: 4-1 /2" TBG 13-CR-80 2140' -~ 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATI 5 3337 3337 1 KBG2 DCR BEK 0 01/10/ 4 5086 5086 3 KBG2 DMY BK 0 01/10/ 3 6411 6332 23 KBG2 DMY BK 0 01/10% 2 7612 7442 21 KBG2 DMY BK 0 01 /10/ 1 8143 7940 19 KBG2 DMY BK 0 01/10/ 7" 26# L-80 scab liner cemented 3004`-842 $221' 4-1/2" HES X-Nipple, 9Cr, 3.813" Pkg Bore - 7" x 4.5" Baker S-3 packer @ 8251 ` 8326' 4-1/2" HES X-Nple, 9Cr, 3.813", RHGM Plug 8358' 4-1/2" WLEG, 3.958" ID 8489' 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860' 8556' 4-1/2" HES X NIP, ID = 3.813" 8622' UNIQUE OVERSHOT/TBG STUB, ID = 3.935" 8650' 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860' 8752' 4-1/2" OTIS XN NIP, ID = 3.725" 8763' 4-1/2" BAKER SHEAROUT SUB $764' 4-1/2" TUBING TAIL 'i $77$' ELMD TT LOG DATE NOT AVAILABLE DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/10/86 ORIGINAL COMPLETION 06/23/08 SWC/SV GLV C/O (06/15!08) WELL: 01-29 05/25/02 DAC/TL RWO 07/21/08 JRA/SV SET PX PLUG (07/14/08) PERMIT No: 1861050 02/04/01 KAK CORRECTIONS 01/11/09 PJC DRLG DRAFT CORRECTIONS API No: 50-029-21604-00 05/06!02 DDW/KK TBG PUNCH & CHEM CUT SEC 5, T10N, R15E, 2507.97' FEL & 5185.05' FNL 11/29/04 DFR/TLP 13-3/8" CSG CORRECTION D5/29/D6 DFRlPJC TBG CORRECTIONS (11/29/041 8P Exoloration fAlaskal 01 /23/09 wi~r~lUmllf~a~~~s~ Alaska Data & Consulting Services a(" 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Or ~ ATTN: Beth pj1J -p QG `L a~~~~ ` W/ ell l O .Inh S f ' 1 nn rlncnrrn4:nn NO.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 n..~., el n_I~- nn H-35 11970840 PRODUCTION PROFILE 08/12/08 1 1 -11 12111927 IBP & CROSS-FLOW STP ..- 1 11/24/08 1 MPS-41 11966291 SCMT - 5~0 11/24/08 1 1 K-05C AWJB-00016 MEM PROD PROFILE p _ ~ ~-5 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE r Q -Q(,) 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- (~!"- 12/30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - b 01/10/09 1 1 01-29 AP3O-00011 USIT '- 1 01/04/09 1 1 09-30 AY1M-00007 _ STATIC SPINNER &IBP ' ~-~ L,~ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - ~ 01/06/09 1 1 R-24 AY3J-00004 USIT 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILE/WFL .r (~'(~ 01/08/09 1 1 07-OVA AYOQ-00009 USIT '`/f - (/ 01/22/09 1 1 N-12 12014053 RST - 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) t)'S,t? 06/15/07 1 B-27A 11999059 RST ®QI ~ ~s + 11107!08 1 1 12-37 40018138 OHM D/LWD EDIT ~ '~ ~'`~-- 11/07/08 2 1 N-18A OSAKA0037 OH MWD/LWD EDIT ~0~ - -~ 12/24/08 2 1 H-38 OSAKA0031 OH MWD/LWD EDIT G 12/07/08 2 1 -1 ~ . rr.-.-.~.-,v,~,~v-•~~v~w~,ia-v~~ u~ V~V~~II~V MIYY IICI VIl1911YV VIYC IiVPi GNlifl IV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 98503 2133, ~ 8 -~ ° „ r' ATTN: Beth -~ Received by: ,,,-, kg, - ~a~l ,l f ~ b ( ~"'io b~l~'-~ 51 (,~it~ C~ • SARAH PALIN, GOVERNOR David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: u 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-29 Sundry Number: 308-467 Dear Mr. Reem: ~~ ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set -out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appear. a .Commission decision to Superior Court unless rehearing has bey.; requested. Sincerely, j> Daniel T. Seamount, Jr. Chair ~~ DATED this~~' day of December, 2008 Encl. ,~~ r1 ~ ~ STATE OF ALASKA , ,~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION - - •~, APPLICATION FOR SUNDRY APPROVAL ~ ~ti~ 20 AAC 25.280 1. Type Of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ®Alter Casing - ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing _ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development -^ Exploratory 186-105 / 308-413 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21604-00-00 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 01-29 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028329 ~ 70' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9610' - 9257 ~ 9563' 9215' 8556' None asin Len th iz MD TVD Burst II se Struct ral r 11 1 11 47 rf 2 0 ' 13-3/ " 2 9' 45 19 0 In rm iat Pr i n 7 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 9314' - 9382' 8996' - 9056' 4-1/2", 12.6# 13Cr80 I L-80 8764' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'SB-3' packer; Packers and SSSV MD (ft): 8489'; 9-5/8" x 4-1/2" Baker'SB-3' packer 8650' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 26, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name vi Re Title Engineering Team Leader Prepared By Name/Number: Signature ' ~~ Phone 564-5743 Date ~ LL Q~ Terrie Hubble, 56a-4628 Commission Use Onl Sundry Number: Conditions appro al: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance \\ __ ~ T~.S~ Other: ~SQ~ ~S ~ irts-~~ES'}' ~ a Q S ~ ~~ ~~ ~`1 ~- C1~nntl~ pp ~~~ G~p~ vc~ ~ Sv(~E~:SE~'~ ~~~' ~~~ S b t F R dd u sequen orm equ e : APPROVED BY 7 ~ L- A roved COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2 ~ f `~ ~ Submit In Duplicate ~~ SAL ~ ~v~ • by c,y, 01-29 Rig Workover (Repair IA x OA communication and PC leak) Scope of Work: Pull 4.5" 13Cr-80 completion. Run & cement 7" 26# L-80 scab liner from 8450-3000'. Run USIT log to find TOC, cut and pull 9.625" casing as deep as possible. Tie back 9.625" casing, and cement to surface. Replace 9.625" packoff and hanger. Run 4.5"13Cr-80 completion. Engineer: Hank Baca MASP: 2366 psi Well Type: Producer Estimated Start Date: January 1st, 2009 S 1 Recover PX lu C«~ 8556'. Drift tubin to 8600' for 4.5" Fasdril & 'et cutter. E 2 Set Fasdril @ 8520'. Reference tubin tall dated 5/19/02 F 3 MIT-T to 1000 psi for 10 minutes to verif lu is holdin .MIT-OA to 2000 psi E 4 Jet cut tubing at 8456' if plug holds. Reference tubing tally dated 5/19/02, cut desired to be'/2 wa down first full 'oint above acker F 5 CMIT TxIA to 1000 psi (with seawater) for 10 minutes. If it fails 1000, try 500 psi for 10 minutes. Ho in to avoid the need for sin le barrier dis ensation. Record LLR if test fails. F 6 Circulate well with 9.8 ppg brine (only if CMIT fails ~ 500 psi), diesel FP cap as needed. Bleed WHPs to 0 si. W 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured with Fasdril lu at this time. PPPOT-T & IC. V 8 Set a BPV in the tubin han er. O 9 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE (with 3.5" x 6" VBRs) to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate 9.8 ppg brine. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. PU 9.625" RTTS &RIH to 4000'. Test above RTTS to 3500 psi for 30 minutes to determine top of leak and scab liner top. Continue to RIH w/ RTTS to 8400' and test Fasdril plug/packer~tQ 3500 psi for 10 minutes to verify its holding ~'i r-G,~S o r- a-~ • `v~~C~Gh~1 ~c~ 5. Run 7", 26#, L-80 scab from 8450' - 3000'. 4.5" over hot on 4.5" tubing XO'd to 7". ,, 6. Cement 7" liner, set liner hanger and packer ~~ e~~vi K 7. Drill out 7" float equipment and 4.5" overshot & XO. 8. Test 7" scab liner to 3500 psi for 30 charted minutes. 9. RU wireline and run USIT from cut to surface. /~~ 10. Run 9-5/8" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. 11. Mechanically cut 9 s/$" casing in 1St full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/8" stub in pre aration of casing overshot. Note: VBR's will not be changed to 9-5/e" pipe rams as the well has tested barrier (RBP) to the reservoir. ~,'~ `~ • • 12. Run back in with condition B 9 s/e", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9 s/8" pack-off to 3500 psi. Cement new 9 5/e" casing to surface 13. Drill out 9.625" 14. Cleanout above 9-5/e" RBP. Pull 9-5/8" RBP. 15. Run 4-~/z" 13Cr-80 stacked packer completion 16. Displace the IA to packer fluid and set the packer. 17. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 18. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE _ GRAY WELLHEAD =. GRAY ~ ACTUATOR = AXEL O ~ ~ KB.' ELEV = 70' - BF. ELEV = ? KOP = 5300' Max Angle = 30 @ 8900' Datum MD = 9171' Datum TV D = 8800' SS 113-3/8" CSG, 68/ 72#, K-55/ L-80, ID = 12.347" I 4-1/2" HES X NIP, ID = 3.813" GAS LIFE MANDRELS Minimum ID = 3.725" @ 8752' 4-1 /2" OTIS XN NIPPLE 4-1/2" TBG-VAM ACE, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8622' I PERFORATION SUMMARY REF LOG: BHCS ON 06/08/86 ANGLE AT TOP PERF: 29 @ 9127' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/93 4 9309 - 9314 S 07/19/93 4 9314 - 9329 C 07/27/93 4 9372 - 9382 C 07/27/93 4 9382 - 9383 S 07/19/93 PBTD I~ 9563' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9606' TD 9610' SAFETY NOTES: 4-1 /2" TBG 13-CR-80 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3310 3310 0 MMG DMY RK 0 06/15/08 2 5060 5060 3 MMG DMY RK 0 06/15/08 3 6390 6313 0 MMG DMY RK 0 05/24/02 4 7594 7425 21 MMG DMY RK 0 05/24/02 5 8418 8199 21 MMG DMY RK 0 05/24/02 ~8489~ ~s-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" 8556' 4-1/2" HES X NIP, ID = 3.813" 8556' 4-1/2" PX PLUG (07/14/08) 8622' UNIQUE OV ERSHOT/TBG STUB, ID = 3.935" $650' 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" $752' 4-1 /2" OTIS XN NIP, ID = 3.725" 8763' 4-1/2"BAKERSHEA ROUT SUB $764' 4-1/2" TUBING TAIL 8778' ELMD TT LOG DATE NOT AVAILABLE DATE REV BY COMMENTS DATE REV BY COMMENTS 08/10186 ORIGINAL COMPLETION 06/23/08 SWGSV GLV GO (06/15/08) 05/25/02 DAC/TL RWO 07/21/08 JRA/SV SET PX PLUG (07/14/08) 02/04/01 KAK CORRECTIONS 05/06/02 DDW/KK TBG PUNCH 8~ CHEM CUT 11/29/04 DFR/TLP 13-3/8" CSG CORRECTION 05/29/06 DFR/PJC TBG CORRECTIONS (11 /29/04) PRUDHOE BAY UNff WELL: 01-29 PERMff No: 1861050 API No: 50-029-21604-00 SEC 5, T10N, R15E, 2507.97' FEL & 5185.05' FNL BP 6cploration (Alaska) . TREE _ GRAY WELLHEAD ~ GRAY ACTUATUR = AXEL KB: ELEV = 70' BF. ELEV = ? KOP = 5300' Max Angle = 30 @ 8900' Datum MD = 9171' Datum TV D = 8800' SS O ~ -~ ~ SAFETY NOTES: 4-1 /2" TBG 13-CR-80 • PROPOSED 9-5/8" 47#, L-80 from -2400' to surface 13-3/8" CSG, 68/ 72#, K-55/ L-80, ID = 12.347" ~ 2509' 4.5" 12.6# 13Cr-80 tubing Minimum ID = 3.725" @ 8752' 4-1 /2" OTIS XN NIPPLE 4.5" x 7" ported 10` XO/pup 4.5" overshot 4-1/2" TBG-VAM ACE, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ $764' PERFORATION SUMMARY REF LOG: BHCS ON 06/08/86 ANGLE AT TOP PERF: 29 @ 9127' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/93 4 9309 - 9314 S 07/19/93 4 9314 - 9329 C 07/27/93 4 9372 - 9382 C 07/27/93 4 9382 - 9383 S 07/19/93 PBTD I~ 9563' 9-5/8" CSG, 47#, L-80, ID = 8.681 " ~ 9606' TD 9610' 2000 ~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3310 3310 2 5060 5060 3 6390 6310 4 7595 7425 5 8420 8200 7" 26# L-80 scab liner cmt'd 3000`-8400' 7" x 4.5" Baker S-3 packer @ -8370` 8~ 622 I 8650' 8752' 8763' 8764' 8778' ~9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" I 4-1/2" HES X NIP, ID = 3.813" 1 UNIQUE OV ERSHOT/TBG STUB, ID = 3.935" 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" 4-1 /2" OTIS XN NIP, ID = 3.725" 4-1/2" BAKERSHEAROUTSUB 4-1/2" TUBING TAIL ELMD TT LOG DATE NOT AVAILABLE DATE REV BY COMMENTS DATE REV BY COMMENTS O6/10/86 ORIGINAL COMPLETION 06/23/08 SWGSV GLV GO (06/15/08) 05/25/02 DACITL RWO 07/21/08 JRA/SV SET PX PLUG (07/14/08) 02/04/01 KAK CORRECTIONS 05/06/02 DDW/KK TBG PUNCH & CHEM CUT 11/29/04 DFR/TLP 13-3/8" CSG CORRECTION 05/29/06 DFR/PJC TBG CORRECTIONS (11129/04) PRUDHOE BAY UNfr WELL: 01-29 PERMfr No: 1861050 API No: 50-029-21604-00 SEC 5, T10N, R15E, 2507.97' FF1 & 5185.05' FNL BP Exploration (Alaska) 01-29 sundry (308-413) Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Thursday, December 18, 2008 2:22 PM To: 'Baca, Hank' Cc: Hubble, Terrie L; Reem, David C; Saltmarsh, Arthur C (DOA); Regg, James B (DOA); Williamson, Mary J (DOA) Subject: RE: 01-29 (186-105) sundry (308-413) Hank, Sorry for not getting back to you sooner. I sort of expected that a new sundry would be submitted given the large number of changes. After reviewing what is now proposed, it is appropriate to send in that new sundry revising the intended plans. Sorry for the additional work, but this is a significant scope change. The revised procedure is similar to other workovers that have recently been accomplished at Prudhoe. One point of the plan 1 DO NOT agree with is not needing 7" rams. The Fasdrill/packer combination constitutes a single barrier and I believe, according to the workover reports I have examined, there have been a few occasions when a Fasdrill has failed. I agree with not needing 9-5/8" rams since there will be 2 tested barriers which is the more usual practice. Although 1 will be in the office after Friday, there should not be an issue with processing the sundry early next week. Call or message with any questions. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Wednesday, November 26, 2008 10:25 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Reem, David C Subject: 01-29 sundry (308-413) Tom, 01-29 was submitted with the plan to bring 7" casing from 8400 to surface . This was going to be cemented to about 3000' to repair a leak at 6500'. It would also repair IA x OA communication. We've decided it will be more cost effective to cut and pu119-5/8" casing as deep as possible, replace with gas-tight connections and cement to surface. A 7" scab liner will also be cemented from 8400 to 3000' to repair that leak. Attached are the new proposed diagram and scope of work. I apologize for the inconvenience. Thanks, «01-29 Scope of Work.ZlP» «1-29 proposed.pdf» Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 12/18/2008 by GP~~, ~ C~ 01-29 Rig Workover (Repair IA x OA communication and PC leak) Scope of Work: Pull 4.5" 13Cr-80 completion. Run 8~ cement 7" 26# L-80 scab liner from 8450-3000'. Run USIT log to find TOC, cut and pull 9.625" casing as deep as possible. Tie back 9.625" casing, and cement to surface. Replace 9.625" packoff and hanger. Run 4.5° 13Cr-80 completion. Engineer; Hank Baca MASP: 3300 psi Well Type: Producer Estimated Start Date: January 1st, 2009 S 1 Recover PX lu 8556'. Drift tubin to 8600' for 4.5" Fasdril 8~ 'et cutter. E 2 Set Fasdril 8520'. Reference tubin tall dated 5119/02 F 3 MIT-T to 1000 si for 10 minutes to veri lu is holdin .MIT-0A to 2000 si E 4 Jet cut tubing at 8456' if plug holds. Reference tubing tally dated 5/19102, cut desired to be '/Z wa down first full 'oint above acker F 5 CMIT TxIA to 1000 psi (with seawater) for 10 minutes. If it fails 1000, try 500 psi for 10 minutes. Ho in to avoid the need for sin le barrier dis ensation. Record LLR if test fails. F 6 Circulate well with 9.8 ppg brine (only if CMIT fails @ 500 psi), diesel FP cap as needed. Bleed WHPs to 0 si. W 7 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured with Fasdril lu at this time. PPPOT-T 8~ IC. V 8 Set a BPV in the tubin han er. O 9 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE (with 3.5" x 6" VBRs) to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate 9.8 ppg brine. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. PU 9.625" RTTS 8~ RIH to 4000'. Test above RTTS to 3500 psi for 30 minutes to determine top of leak and scab liner top. Continue to RIH w/ RTTS to 8400' and test Fasdril plug/packer to 3500 psi for 10 minutes to verify its holding 5. Run 7", 26#, L-80 scab from 8450' - 3000'. 4.5" overshot on 4.5" tubing XO'd to 7". Note: Pipe rams will not be changed to 7" as the well has a tested barrier (packer/Fasdril) to the reservoir. 6. Cement 7" liner, set liner hanger and packer 7. Drill out 7" float equipment and 4.5" overshot & XO. 8. Test 7" scab liner to 3500 psi for 30 charted minutes. 9. RU wireline and run USIT from cut to surface. 10. Run 9-5/e" RBP and set 100' below TOC determined from USIT. PT RBP to 1000 psi to prove plug is set. Dump ~50 ft of sand on RBP. • 11. Mechanically cut 9 5/g" casing in 1~` full joint above top of cement. Pull casing thru stack. Dress-off 9- 5/8n stub in preparation of casing overshot. Note: VBR'8 will not be changed to 9 5/$" pipe rams as the well has a tested barrier (RBP) to the reservoir. 12. Run back in with condition B 9-5/8", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9 5/g" pack-off to 3500 psi. Cement new 9 5/$" casing to surface 13. Drill out 9.625" 14. Cleanout above 9 5/s' RBP. Pull 9 $/e" RBP. 15. Run 4-'/z" 13Cr-80 stacked packer completion 16. Displace the IA to packer fluid and set the packer. 17. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 18. Set TWC. ND ROPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = GRAY WELLHEAD = GRAY ACTUATOR = AXEL KB. ELEV = 70' BF. ELEV = ? KOP = 5300' Max Angle = 30 @ 8900' Datum MD = 9171' Datum N D = 8800' SS 01-29 PROPOSED 9-5/8" 47#, L-80 from -2400' to surface 4.5" 12.6# 13Cr-80 tubing 4.5" x 7" ported 10` XO/pup 4.5" overshot PERFORATION SUMMARY REF LOG: BHCS ON 06/08/86 ANGLE AT TOP PERF: 29 @ 9127' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/93 4 9309 - 9314 S 07/19/93 4 9314 - 9329 C 07/27/93 4 9372 - 9382 C 07/27/93 4 9382 - 9383 S 07/19/93 SAFETY NOTES: 4-1 /2" TBG 13-CR-80 ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3310 3310 2 5060 5060 3 6390 6310 4 7595 7425 5 8420 8200 7" 26# L-80 scab liner cmt'd 3000`-8400' 7" x 4.5" Baker S-3 packer @ -8370` $77$' ELMD TT LOG DATE NOT AVA~ABLE DATE REV BY COMMENTS DATE REV BY COMMENTS O6/1G/Ei6 ORIGINAL COMPLETION 06/23/08 SWGSV GLV GO (06/15/08) f;j/25!02 DAC/TL RWO 07/21/08 JRA/SV SET PX PLUG (07/14/08) 0?i0~101 KAK CORRECTIONS - ~ ~ ~~ 0'~~/Ota •?_ DDW/KK TBG PUNCH & C;FiE1N CUT . . ..~ e 1 `.!?Q/0+ DFR/TLP 13-3/8" CSG CORK::^CTION .., _ ,a. _ .-.. ._ .,._ _ PRUDHOE BAY UNfr WELL: 01-29 PERMff No: 1861050 API No: 50 0?9-21604-OG SEC 5, T10N, R15E 250%.97 FEJ_ & 5185.05' FNi.. BP Exploration (Alaska) ~~ ~ f -.. _._,_ _ ....~..~._J AL1~5S-A OIL AI~TD G~,S CO1~T5ER'QA7'IO1Q CO1~iII~iI55IO1~T David Reem Engineering Team header BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~~~~ ~-~ ~~ ~~ zoa8 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, O 1-29 Sundry Number: 308-413 Dear Mr. Reem: cos `~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.0$0, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day ft the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 1 Cathy P. Foerster Corrunissianer r~~ / DATED this d y of November, 2008 • Encl. ~,~~~ ,,, STATE OF ALASKA `~~ ~8 ALl~4 OIL AND GAS CONSERVATION COIGN PLICATION F R SUNDRY APPROVAL~c` - AP O I~~, 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Exterrsion ^ After Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 186-105 3. Address: ^ Service ^ Stratigraphic 6. API Number: , P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21604-00-00 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: 01-29 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): d ~ \ ADL 028329 ~ 70' - Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (tt): Plugs (measured): Junk (measured): 9610' ~ 9257' ~ 9563' 9215' 8556' None in B r I rl 1 1 ' rf In /" 7 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (tt): Below Plug: 9314' - 9382' 8996' - 9056' 4-112", 12.6# 13Cr80 / L-80 8764' Packers and SSSV Type: 9-5/8" x 41/2" Baker'SB-3' packer; Packers and SSSV MD (ft): 8489 ; 9-5/8" x4-1/2" Baker'SB-3' packer 8650' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 1, 2009 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number Signature ~j Phone 564-5743 Date /~ ~~ ~pp~ Terris Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: '~~ ~} v ~`~ ~ ~~ ~ '~C ~~ Subsequent Form Required: "'~. ,' APPROVED BY J ~ ^ , ~ Og A roved B : COMMISSIONER THE COMMISSION Date / v7~ Form 10-403 Rimed 06/2 i~ '; ~_ y h ~ t y ~iM1.S ~~~-. Neu ~ 4 2006 Submit In Duplicate • • µ o d G a ¢~r, P~r~~ 1 n e Ba y 01-29 Rig Workover (Repair IA x OA communication) Scope of Work: Pull 4.5" 13Cr-80 completion. Run & cement 7" 26# L-80 scab liner to shut off 9.625" casing leak. Run 4.5" 13Cr-80 completion. Engineer: Hank Baca MASP: 3300 psi Well Type: Producer Estimated Start Date: January 1st, 2009 S 1 Dum 30' of slu its on PX lu 8556'. Drift tubin for 4.5" 'et cutter. F 2 MIT-T to 1000 si for 10 minutes to veri PX plu is holdin .MIT-0A to 2000 psi E 3 Jet cut tubing at 8456' if plug holds. Reference tubing tally dated 5/19/02, cut desired to be %Z wa down first full ~oint above acker F 4 CMIT TxIA to 1000 psi (with seawater) for 10 minutes to verify barrier. Hoping to avoid the need for sin le barrier dis ensation. Record LLR if test fails. F 5 Circulate well with 9.8 brine, diesel FP ca as needed. Bleed WHPs to 0 si. W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured with PX plug at this time. PPPOT-T & IC. V 7 Set a BPV in the tubin han er. O 8 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate 9.8 ppg brine. 2. Pull and LD tubing string to the cut. 3. Dress 4.5" tubing stub 4. PU 9.625" RTTS 8~ RIH to 4000'. Test above RTTS to 3500 psi for 10 minutes to determine top of leak and scab liner top. Continue to RIH w/ RTTS to 8400' and test PX plug/packer to 3500 psi for 10 minutes to verify its holding 5. Run 7", 26#, L-80 scab from 8350' - 3000'. 4.5" overshot on 4.5" tubing XO'd to 7". Note: Pipe rams will not be changed to 7" as the well has a tested barrier (packer/PX plug) to the reservoir. 6. Cement 7" liner. 7. Test 7" scab liner to 3500 psi for 30 charted minutes. 8. Run 7" TC-II liner from tie-back sleeve @ 3000' to surface. 9. Drill out 7" float equipment and 4.5" overshot & XO. 10. Clean out sand on top of PX plug 11. Run 4-%" 13Cr-80 stacked packer completion 12. Displace the IA to packer fluid and set the packer. 13. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. 14. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. • • by Bury 01-29 Rig Work~ver (Repair IA x OA communication) Scope of Work: Pull 4.5" Cr-80 completion. Run & cement 7" 26# L-80 scab liner to shut off 9.625" casing leak. Run 4.5" 13Cr- 0 completion. Engineer: Hank Baca MASP: 3300 psi < </ Well Type: Producer l l~~d~ ~ Estimated Start Date: January 1st, 09 "-- °- ~~'= S 1 Recover PX lu C«~ 8556'. D t tubin to 8600' for 4.5" Fasdril and 'et cutter. E 2 Set Fasdril C~ 8520'. Referenc ubin tall dated 5/19/2002. F 3 MIT-T to 1000 si for 10 minutes verif com osite bride lu is holdin . E 4 Jet cut tubing at 8456' if plug hold Reference tubing tally dated 5/19/02, cut desired to be'/z wa down first full 'oint above acker F 5 CMIT TxIA to 3500 si. Test ex ected fail, obtain LLR F 6 Circulate well with 9.8 brine, diesel ca as needed. Bleed WHPs to 0 si. W 7 Check the tubing hanger lock down screw for free movement. Completely back out and check each lock down screw for breakage (chec one at a time). Well should be secured with a Fasdril) lu at this time. PPPOT-T & IC. V 8 Set a BPV in the tubin han er. Proposed Procedure 2. 3. 4. 5. 6. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 ps high. and circulate 9.8 ppg brine. Pull and LD tubing string to the cut. Dress 4.5" tubing stub Run 9.625" RBP and set 8,420'. Dump -50' of sand on RBP. PU 9.625" RTTS & RIH to 4000'. Test above to determine top of I Run 7", 26#, L-80 scab from 8350' - 3000'. Note: Pipe rams will well has a tested barrier (RBP) to the reservoir. Cement 7" liner. Test 7" scab liner to 3500 psi for 30 charted minutes. Run 7" TC-II liner from tie-back sleeve C~ 3000' to surface. Drill out 7" shoe, and clean out above 9.625" RBP. Pull 9.625" RBP. Drill up 4.5" Fasdril C~ 8,520' and chase out tail pipe Run 4-~/z" 13Cr-80 stacked packer completion Displace the IA to packer fluid and set the packer. Test tubing and IA to 3500 psi. Freeze protect to 2,200' MD. Circulate out freeze protection 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. and scab liner top. be changed to 7" as the Set TWC. ND ROPE. NU and test tree. Pull TWC and set BPV. RDMO. rR~b ~Ra~ WELLHEAD = GRAY -ACTUATOR = AXEL • O ~ ~ KB. ELEV = 70' - BF. ELEV = KOP = 5300' Max Angle = 30 @ 8900' Datum MD = 9171' Datum TV D = 8800' SS ~ 13-3/8" CSG, 68/ 72#, K-55/ L-80, ID = 12.347" Minimum ID = 3.725" @ 8752' 4-1 /2" OTIS XN NIPPLE SAFETY NOTES: 4-1/2" TBG 13-CR-80 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3310 3310 0 MMG DMY RK 0 06/15/08 2 5060 5060 3 MMG DMY RK 0 06/15/08 3 6390 6313 0 MMG DMY RK 0 05/24/02 4 7594 7425 21 MMG DMY RK 0 05/24/02 5 8418 8199 21 MMG DMY RK 0 05/24/02 8489' -19-5/8" X 4-1/2" BAKER SB-3 PKR iD = 3.860" 8556' 4-1/2" HES X NIP, ID = 3.813" 85~~ 4-1/2" PX PLUG (07/14/08) 4-112" TBG-VAMACE, 12.6#, 13-CR-80, 86~' 8622' UNIQUE OV ERSHOT/TBG STUB, ID = 3.935" .0152 bpf, ID = 3.958" 8650' 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" 8752' 4-1 /2" OTIS XN NIP, ID = 3.725" 8763' 4-1/2" BAKERSHEAROUT SUB 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" $764' .8764' 4-112" TUBING TAIL 8778' ELMD TT LOG DATE NOT AVAILABLE PERFORATION SUMMARY ', REF LOG: BRCS ON 06/08/86 ANGLE AT TOP PERF: 29 @ 9127 '' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/93 4 9309 - 9314 S 07/19/93 4 9314 - 9329 C 07/27/93 4 9372 - 9382 C 07/27/93 4 9382 - 9383 S 07/19/93 PBTD I-~ 9563' 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9606' ~~ 9610' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/10/86 ORIGINAL COMPLETION 06/23/08 SWGSV GLV GO (06/15/08) 05/25/02 DAC/TL RWO 07/21/08 JRA/SV SET PX PLUG (07/14/08) 02/04/01 KAK CORRECTIONS 05/06/02 DDW/KK TBG PUNCH 8~ CHEM CUT 11/29/04 DFR/TLP 13-3/8" CSG CORRECTION 05/29/06 DFR/PJC TBG CORRECTIONS (11/29/04) PRUDHOE BAY UNff WELL: 01-29 PERMfi No: 1861050 API No: 50-029-21604-00 SEC 5, T10N, R15E, 2507.97' FEL & 5185.05' FNL BP Exploration (Alaska) TRFF = - GRAY WPLLHEAD = GRAY ACTUATOR = AXEL KB. ELEV = 70' BF. ELEV = ? KOP = 5300' Max Angle = 30 @ 8900' Datum MD = Datum TV D = 9171' 8800' SS 7" 26# L-80 TC-II 3000`-surfa 13-3/8" CSG, 68/ 72#, K-55/ L-80, D = 12.347' H 2509' 4.5" 12.6# 13Cr-80 tubing Minimum ID = 3.725" @ 8752' 4-1/2°° OTIS XN NIPPLE 4-1/2" TBG-VAM ACE, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, D = 3.958" I PERFORATION SUMMARY REF LOG: BHCS ON 06/08/86 ANGLE AT TOP PERF: 29 @ 9127' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/93 4 9309 - 9314 S 07/19/93 4 9314 - 9329 C 07/27/93 4 9372 - 9382 C 07/27/93 4 9382 - 9383 S 07/19/93 I PBTD I 9-5/8" CSG, 47#, L-80, D = 8.681" I-~ 9606, ~~ 9610' DATE REV BY COMMENTS DATE REV BY COMMEMS 06!10/86 ORIGINAL COMPLETION 06/23/08 SWGSV GLV GO (06/15/08) 05/25/02 DAC/TL RWO 07/21/08 JRA/SV SET PX RUG (07/14/08) 02/04/01 KAK CORRECTIONS 05/06/02 DDW/KK TBG PUNCH 8 CH9N CUT 11/29/04 DFR/TLP 13-3/8" CSG CORRECTION 05/29/06 DFR/PJC TBG CORRECTIONS (11 /29/04 ) 9 _ ~ SAFErY NOTES: 4-1 /2" TBG 13-CR-80 • _ - -:. ~~~~~ ^-2000 -14-1/2" HES X NIP, ID = 3.81 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 ~;lo ~~11i 2 5060 5000 3 6390 6310 4 7595 7425 5 - - - - 7" 26# L-80 scab liner cmt'd --3000'-8400' 7" x 4.5" Baker SB-3 packer @ -8300` 4.5" x 7" ported 10` XO/pup 4.5" overshot 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" I 4-1/2" HES XNIP, D = 3.813" $622' ~ UNIQUE OVERSHOTffBG STUB, D = 3.935" 8650' I-I9-5/8" X 4-1/2" BAKER SB-3 PKR, D = 3.86( $752' ~--~4-1/2" OTIS XN NIP, D = 3.725" I 876$' 4-112" BAKER SHEAROUT SUB $764' 4-1 /2" TUBING TAIL $77$' ELMD TT LOG DATE NOT AVAILABLE PRUDHOE BAY UNIT WELL: 01-29 PERMff No: 1861050 API No: 50-029-21604-00 SEC 5, T10N, R15E, 2507.97' FEL 8 5185.05' FNL BP 6cploration (Alaska) TREE =ti GRAY WEt_LHEAD= G Y ACTUATOR= AXEL KB. ELEV = 70' BF. ELEV = ? KOP = 5300' Max Angle = 30 @ 8900' Datum MD = 9171' Datum TV D = 8800' SS 7" 26# L-80 TC-II O ~ -~ ~ SAFETY NOTES: 4-1 /2" TBG 13-CR-80 • • PROPOSED ~ 13-3/8" CSG, 68/ 72#, K-55/ L-80, ID = 12.347" ~ Minimum ID = 3.725" @ 8752' 4-1 /2" OTIS XN NIPPLE 4.5" 12.6# 13Cr-80 tubing f 1 /2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TV DEV TYPE VLV LATCH PORT DATE 1 3310 3 0 2 5060 60 3 6390 6310 4 759 7425 5 8 0 8200 7" # L-80 scab liner cmt'd 3000`-8400' "'-8300 7" X 4-1/2" BAKER SB-3 PKR 8489' -19-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.860" 8556' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG-VAM ACE, 12.6#, 13-CR-80, I 8622' .0152 bpf, ID = 3.958" I~ 4-112" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I PERFORATION SUMMARY REF LOG: BHCS ON 06/08/86 ANGLEAT TOP PERF: 29 @ 9127' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4 9127 - 9137 S 07/19/ 3 4 9309 - 9314 S 0711 93 4 9314 - 9329 C 07/ /93 4 9372 - 9382 C 0 /27/93 4 9382 - 9383 S 7/19/93 I PBTD 1 ~ 9-5/8" CSG, 47#, L-80, ID = 8.681y ~ JIQUE OV ERSHOT/TBG STUB, ID = 3.935" 5/8" X 4-112" BAKER SB-3 PKR ID = 3.860" 1 /2" OTIS XN NIP, ID = 3.725" 1/2" BAKER SHEAROUT SUB 4-1/2" TUBING TAIL ELMD TT LOG DATE NOT AVAILABLE DATE REV BY COMMENTS DATE REV BY COMMENTS 06/10/86 ORIGINAL COMPLETION 06/23/08 SWGSV GLV GO (06/15/08) 05125/02 DAC/TL RWO 07/21/08 JRA/SV SET PX PLUG (07/14/08) 02/04/01 KAK CORRECTIONS 05/06/02 DDW/KK TBG PUNCH 8~ CHEM CUT 11/29/04 DFR/TLP 13-3/8" CSG CORRECTION 05/29/06 DFR/PJC TBG CORRECTIONS (11/29/04) PRUDHOE BAY UNIT WELL: 01-29 PERMfT No: 1861050 AR No: 50-029-21604-00 SEC 5, T10N, R15E, 2507.97' FEL 8~ 5185.05' FNL BP Exploration (Alaska) Page 1 of 3 Maunder, Thomas E (DOA) From: Baca, Hank [hank.baca@bp.com] Sent: Tuesday, November 18, 2008 2:11 PM To: Maunder, Thomas E (DOA) Subject: - Attachments: 01-29 Scope of Work.ZlP; 1-29 proposed.pdf • Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, November 18, 2008 10:17 AM To: Baca, Hank Subject: RE: D5 01-09A (194-033) Hank, 01-09A appears OK, but I think you missed some changes on 01-29. I don't think the 9-5/8" RBP will come through the 7" liner. Have a look and provide any needed revisions. Tom Maunder, PE APGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Tue 11/18J2008 6:52 AM To: Maunder, Thomas E (DOA) Subject: RE: DS Ol-09A (194-033) Tom, here are the updated documents. 1-29 We got a liquid Leak rate of 1.5 gallons/min in July 08, so I'm planning to skip getting one here. We'll test the 4.5" fasdrill to 1000 psi, cut the tubing, and try to get a CMIT to 1000 psi. With such a low LLR I'm hopeful it will pass and avoid a single barrier dispensation. We'll seta 9.625" RBP above all that and isolate the leak with an RTTS (and test the RBP). I'm planning to do those tests to 3500 psi just b/c the LLR is so low. 1-09A Testing 4.5" fasdril to 2500 psi, then getting LLRs @ 1000 & 2000 psi. Planning to set RBP & isolate leak w/ RTTS at 2500 psi. LLR in 2003 was 0.7bpm @ 20000 psi. Hopefully I got it right this time, holler If I missed something else. Thanks, and sorry about that. Hank Baca 11/20/2008 Page 2 of 3 • Drilling Engineer 907-564-5444 office 907-748-0997 cell • From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, November 17, 2008 3:15 PM To: Baca, Hank Cc: Reem, David C Subject: RE: DS 01-09A (194-033) Hank, Yes, please send updated sheets. Tom From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Monday, November 17, 2008 7:12 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: DS 01-09A (194-033) Hi Tom. Sorry about that. For both 1-09 & 1-29 I was just planning to establish a leak rate, but you're correct we'll likely exceed the 1000 psi test to verify the 4.5" Fasdril is set. I'll change that test pressure to reflect it, probably 2000 psi. I need to double check the file. As far as testing the 9.625" RBPs, I was planning to do it while the RTTS was in the hole to find the leak top, but did not have that in what I sent you. This would be part of step 4 for 1-09 and step 5 for 1-29. If that works for you, can I update them and email them to you? Thanks, Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: ,November 16, 2008 10:48 AM To: Baca, Han Cc: Reem, David C Subject: DS 01-09A (194-0 Hank and Dave, I am reviewing the sundry to workover this well. 6 having a tested RBP in place in the 7" liner. There s questions ... fated that 7" pipe rams will not be employed due to be a tested Fasdril in the tailpipe. A couple of 1. There seem to be several test press planned on the Fasdril. 000 psi MIT-T is planned when it is set, however after cutting the tubing psi OMIT TxIA is planned althoug not expected to pass. Is it expected that pressures > psi will be attained when attempting to establish mp in rate? If so, shouldn't the initial test on the ril be in excess of whatever pump in pressure is attained to a that the Fasdril is not leaking? 2. Re g not employing 7" rams, when will the RBP be tested? I do not find any mention of tes hat plug a setting. Since there is a casing leak, it would seem that the RTTS would need to be run deeper than 11 /20/2008 Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, Plovember 16, 2008 11:09 AM To: 'Baca, Hank' Cc: 'Reem, David C' Subject: RE: DS 01-29 (186-105) Hank and Dave, 1 am reviewing the sundry to workover this well. Similar questions to DS 01-09A. In step 6 it is stated that 7" pipe rams will not be employed due to having a tested RBP in place in the 7" liner. There should also be a tested Fasdril in the tailpipe. A couple of questions ... 1. There seem to be several test pressures planned on the Fasdril. A 1000 psi MIT-T is planned when it is set, however after cutting the tubing a 3500 psi CMIT TxIA is planned although it is nat expected to pass. Is it expected that pressures > 1000 psi will be attained when attempting to establish a pump in rate? If so, shouldn't the initial test on the Fasdril be in excess of whatever pump in pressure is attained to assure that the Fasdril is not leaking? 2. Regarding not employing 7" rams, when will the RBP be tested? I do not find any mention of testing that plug after setting. Since there is a casing leak, it would seem that the RTTS would need to be run deeper than that leak and then a test preformed to "prove" the RBP. 1 Look forward to your reply. Tom Maunder, PE AOGCC 11/16/2008 1. Operations performed: ( STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS [] Operation Shutdown [] Stimulate [] Pull Tubing [] Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1017' SNL, 1511' EWL, SEC. 08, T10N, R15E, UM At top of productive interval 66' SNL, 2484' EWL, SEC. 08, T10N, R15E, UM At effective depth 83' NSL, 2751' EWL, SEC. 08, T10N, R15E, UM At total depth 94' NSL, 2770' EWL, SEC. 05, T10N, R15E, UM [] Plugging [] Perforate [] Repair Well [] Other Casing 5. Type of well: I~! Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RKB = 70' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 01-29 9. Permit Number/ Approval No. 186-105 10. APl Number 50- 029-21604-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9610 feet Plugs (measured) true vertical9257 feet ORIGINAL Effective depth: measured 9563 feet Junk (measured) true vertical 9215 feet Length Size Cemented M D TVD Structural Conductor 110' 20" 10 Shots Poleset 110' 110' Surface 2509' 13-3/8" 2500 sx CS III, 400 sx CS II, 2509' 2509' Intermediate with Top Job of 150 sx CS II Production 9606' 9-5/8" 670 sx Class 'G', 300 sx AS I 9606' 9253' Liner RECEIVED Perforation depth: measured 9314' - 9329', 9372'- 9382' Squeezed: 9127'-9137', 9309'-9314', 9382'-9383' JUN 2 5 2002 true vertical 8996' - 9009', 9047' - 9056' Squeezed: 8832'- 8841', 8991' - 8996', 9056' - 9056' Alat~ Oil &/~a{t.(~t3~, i~Ul~.i.i,tJ~.$.~)' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to 8626'; 4-1/2", 12.6#, L-80 to 8764' Packers and SSSV (type and measured depth) 9-5/8" x 4-1/2" Baker 'SB-3' packer at 8650' and 8489'; 4-1/2" HES 'X' Nipple at 2198' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation: 1352 Subsequent to operation: 1351 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 27290 894 27131 1195 16. Status of well classifications as: [] Oil [] Gas [] Suspended 17. I hereby certify that the forgoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant ,, Form 10-404 Rev. 06/15/88 Casing Pressure Tubing Pressure Service Date (~°~-'("~ 0 ~,-, ~,~ Prepared By Name/Number: Terrie Hubble, 564-4628 ~,,~ Submit In Duplicate ~ Well: 01-29 (RWO) Rig Accept: 05/15/02 Field: Prudhoe Bay Unit Rig Spud: N/A APl: 50-029-21604-00 Rig Release: 05/21/02 Permit: 186-105 Drilling Rig: Doyon 16 PRE-RIG WORK 04/25/02 DUMPED 5# SLUGGETS ON TOP OF PLUG @ 8752' MD. 04/26/02 FINISH DUMPING SLUGGETS ON PLUG. ATTEMPT TO PULL ST # 7. @ 8425' WLM. UNABLE TO PULL. DIFFICULTY SHEARING OFF TWO RUNS. RUN SPLIT SKIRT, UNABLE TO PULL. SHEAR OFF EASILY. 04/28102 PPPOT-IC FAILED, MITOA PASSED TO 1000 PSI, LDS ALL TURNED FREELY. 05/06/02 PUNCHED TUBING A'F 8605'-8607'. CONDITIONED PIPE FOR CUT WITH A STRING SHOT. CUT TUBING AT 8620' (FIRST FULL JOINT ABOVE PACKER) WITH 3 3/8" CHEMICAL CUTTER. GOOD INDICATIONS OF CLEAN CUT. NOTIFY PAD OPERATOR OF WELL STATUS - LEFT SHUT IN. 05109/02 ClRC OUT IA X WELLBORE W/1477 BBLS SEAWATER TAKING RETURNS TO PRODUCTION / FREEZE PROTECT TUBING & IA W/175 BBLS DIESEL / FREEZE PROTECT FLOWLINE W/5 NEAT METH & 133 BBLS CRUDE. 05111/02 CMIT TXIA PASSED TO 3000 PSI. 06101/02 PULL B&R FROM RHC @ 8546'SLM. PULLED DGLV FROM STA#2 AND RP VALVE FROM STA#1. SET GENERIC DESIGN. PULLED RHC BODY. BAIL SLUGGITS FROM TOP OF PLUG @ 8741' WLMD. 06/04/02 BAIL SLUGGITS OFF XXN PLUG. PULL XXN PLUG. LEFT WELL SHUT IN AND NOTIFIED PAD OPERATOR. RECEIVED JUN 2 5 2002 Naska Oil & Gas Cons, Anchomge Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5/15~2002 06:00 - 08:00 08:00 - 10:00 10:00- 12:00 12:00 - 13:00 13:00 - 14:00 14:00- 15:30 15:30 - 20:30 20:30 - 23:00 5/16/2002 23:00 - 00:00 00:00 - 03:00 03:00 - 05:30 05:30 - 06:00 06:00 - 15:00 15:00- 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 21:00 21:00 - 00:00 BP EXPLORATION Operations Summary Report Page 1 of 4 01-29 01-29 WORKOVER DOYON DOYON 16 Hours Task Code NPT Start: Rig Release: Rig Number: Phase 5/8/2002 Spud Date: 5/28/1986 End: Description of Operations 2.00 RIGD P 2.00 MOB P 2.00 RIGU P 1.00 RIGU P 1.00 RIGU P 1.50 KILL 5.00 KILL P 2.5O WHSUR P 1.00 WHSUR P 3.00 WHSUR P 2.50 WHSUR P 0.50 WHSUR P 9.00 PULL P 1.00 PULL P 2.00 PULL P 0.50 PULL P 0.50 PULL P 2.00 WHSUR P 3.00 WHSUR P POST PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP PJSM. MOVE RIG OFF WELL. LAY OVER DERRICK. PRE MOVE SAFETY MEETING WITH ALL ASSOCIATED PARTIES. MOVE RIG FROM DS 05 TO DS 01. PJSM. RAISE DERRICK, RIG UP HOISTS, CLOSE WINDWALLLS, BRIDLE BACK. SPOT & LEVEL RIG OVER 01-29. TAKE ON SEAWATER & INSPECT DERRICK FOR POTENTIAL FALLING OBJECTS. RIG ACCEPTED @ 13:00 HRS, 05/1512002. RIG UP DSM & PULL BPV, RIG UP TO CIRCULATE & TEST LINES, OK. PJSM. INITIAL PRESSURES: O/A 80 PSI, I/A 500 PSI, TUBING 125 PSI. DISPLACE WELL W/SEAWATER, PUMPING DOWN TUBING @ 6 BPM / 780 PSI, TAKING RETURNS UP ANNULUS, DIESEL & GAS BACK, (1) COMPLETE CIRCULATION. MONITOR WELL, SLIGHT FLOW, (DIESEL), CIRCULATE 50 BBLS MORE & MONITOR, OK. DRY ROD BPV, BPV DID NOT SET PROPERLY, CALL OUT . DSM & PICK UP LUBRICATOR & SET BPV, OK. BLEED 80 PSI OFF O/A, DIESEL BACK. PJSM. N/D TREE & ADAPTER FLANGE. INSPECTED THREADS ON TUBING HANGER, LOOK GOOD. NU 13 5/8" x 5M BOPE. TUBING HANGER LEAKING, UNABLE TO GET FLAT LINE TEST ON BOPE. PERFORM BODY TEST & TEST ON BLIND RAMS, ANNULAR & UPPER PIPE RAMS, NO VISIBLE LEAKS. WILL PERFORM FULL CHARTED TEST AFTER HANGING OFF TUBING, PLAN FORWARD OK'd BY AOGCC REP JOHN CRISP. SET BPV. M/U LANDING JOINT, SCREW INTO HANGER. BOLDs. PULL TO 175K, HANGER NOT FREE. WRAP & HEAT TUBING SPOOL W/STEAM, PULL TO 220K, NO MOVEMENT. PULL LOCK DOWN SCREWS PUMP OIL AROUND HANGER, WRAP & HEAT W/STEAM. WORK @ 215K, STILL STUCK AT HANGER. M/U SPEAR & JAR ASSEMBLY, UNABLE TO SPEAR PIPE. I_/D SPEAR & M/U LANDING JOINT & JARS, JAR @ 125K, HANGER FREE. PULL TUBING HANGER TO FLOOR, 193K UP WT & TUBING PULLED FREE. 112K UP WT, 105K DOWN WT. L/D LANDING JOINT, JARS & TUBING HANGER. CIRCULATE BOTTOMS UP, MONITOR, OK. POOH W/4 1/2" BTC TBG, (4 JTS), & CONTROL LINE, SECURE CONTROL LINE. M/U RTTS & RIH, SET @ 57', RELEASE FROM RTTS & L/D (2) JTS DP. TEST RTTS @ 2000 PSI, OK. N/D BOPE. N/D TUBING SPOOL. PRESSURE BLED OFF ON O/A. BEGIN BACKING OUT LOCK DOWNS ON PACKOFF, NOTE GAS BUBBLING AROUND PACKOFF INDICATING SOME TRAPPED PRESSURE. ALLOW TO BLEED DOWN & DOUBLE CHECK FOR VR PLUG IN ANNULUS VALVE, VERIFY O/A TOTALLY Printed: 5/28/2002 11:40:22 AM BP EXPLORATION Operations Summary Report Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/16/2002 511712002 01-29 01-29 WORKOVER DOYON DOYON 16 From - To Hours Task 21:00 - 00:00 00:00 - 02:30 02:30 - 03:00 03:00 - 05:30 05:30 - 07:30 Code NPT 3.00 WHSUR P 2.5O WHSUR P 0.50 WHSUR P 2.50 WHSUR P 2.00 WHSUR P 07:30- 08:30 1.00 WHSUR P 08:30- 09:00 0.50 PULL P 09:00- 10:30 1.50 PULL P 10:30- 11:00 0.50 PULL P 11:00- 12:00 1.00 PULL P 12:00- 22:00 10.00 PULL P 22:00 - 23:00 1.00 PULL P 23:00 - 00:00 1.00 PULL P 5118~2002 00:00 - 01:30 1.50 REST P 01:30- 11:30 10.00 REST P 11:30- 12:00 0.50 REST P 12:00- 17:30 5.50 REST P 17:30-20:30 3.00 REST P 20:30- 22:30 2.00 REST N DPRB 5/19/2002 22:30 - 00:00 1.50 REST P 00:00- 07:00 7.00 REST P Start: Rig Release: Rig Number: 5/6~2002 Spud Date: 5/28/1986 End: Phase DECOMP DECOMP DECOMP DECOMP DECOMP Description of Operations DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP BLED OFF. PULL PACK OFF. INSTALL NEW PACKOFF & RILDs. PJSM. CUT 1" OFF OF 9 5/8" CASING STUB & DRESS OFF SAME. N/U TUBING SPOOL & DOUBLE I/A VALVE. PRESSURE TEST 9 5/8" PACKOFF @ 3700 PSI / 10 MINUTES, OK. N/U BOP, PRESSURE TEST CHOKE MANIFOLD & SURFACE SAFETY VALVES W/NIPPLING UP. CONDUCT INITIAL TEST ON BOPE. WITNESSING OF TEST WAIVED BY AOGCC STATE MAN JOHN CRISP. NO FAILURES. DRAWDOWN TEST ON ACCUMULATOR, OK. P/U KELLY, TORQUE & PRESSURE TEST KELLY VALVES, 250 / 3500 PSI, OK. INSTALL WEAR BUSHING. RIH W/(2) JTS 3 1/2" DP & SCREW INTO / RELEASE RTTS. CIRCULATE BO'I-rOMS UP, MONITOR WELL, OK. L/D DP & RTTS. PJSM. SLIP & CUT 57.5' OF DRILLING LINE, CHECK CROWN-O-MATIC, OK. PJSM. POOH & L/D 4 1/2" COMPLETION STRING & CONTROL LINE. (28) CONTROL LINE BANDS RETRIEVED. 204 JTS TOTAL LAID DOWN & 20.18' OF JT# 205, (8) GLMS & (16) PUP JTS. CHEMICAL CUT WAS 90% COMPLETE, (1") TAB ..... ACCOUNTS FOR 80K OVERPULL TO FREE TUBING. CLEAR & CLEAN RIG FLOOR. PJSM. O/A OPEN TO TANK, PRESSURE UP I/A AGAINST BLIND RAMS TO 3000 SPI / 30 MINUTES, CHARTED, OK. NO FLOW UP O/A DURING TEST. P/U BHA, (9) 4 3/4" DCs, MILL & 9 5/8" CASING SCRAPER. P/U 3 1/2" DP & RIH W/CLEANOUT BHA. ESTABLISH PARAMETERS, KELLY UP & WASH DOWN, TAG TUBING STUB @ 8626' DPM, MILL/DRESS TUBING STUB TO 8627'. MIX & PUMP HI VIS SWEEP & CIRCULATE TO CLEAN RETURNS, SLIP & CUT 115' OF DRILLING LINE W/ CIRCULATING. MONITOR WELL, OK. POOH & L/D 3 112" DP, PULLED HEAVY @ 6455', (SCRAPER @ 6446'). 102K UP WT, PULLED TO 130K, ABLE TO GO BACK DOWN. MIX & PUMP HI VIS SWEEP, (20 BBLS), CIRCULATE AROUND & PULL 5-10K OVER UP WT, SET SLIPS & ROTATE, SEEING TORQUE RELEASE. ABLE TO PULL THROUGH, GO BACK DOWN & REPEAT SEVERAL TIMES WHILE CIRCULATING SWEEP OUT UNTIL SMOOTH. QUICK TEST ON 9 5/8" CASING @ 3000 PSI / 5 MINUTES, CHARTED, TO VERIFY INTEGRITY INTACT, OK. CONTINUE TO POOH & L/D 3 1/2" DP. POOH & L/D 3 1/2" DP, (SLOWLY), AS ENCOUNTERING TIGHT SPOTS. HAVING TO OVERPULL 5-10K & SET ROTARY TABLE SLIPS, SEE TORQUE TO 6500 FT/LBS & POPPING FREE, WORKING EACH AREA. TIGHT SPOTS @ 4053', 3422', 3370' & 3232' DPM. (SCRAPER DEPTHS). SUSPECT OVERTORQUED CONNECTIONS ON 9 5/8" Printed: 5/2812002 11:40:22 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 5/19/2002 01-29 01-29 WORKOVER DOYON DOYON 16 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: Hours Task Code NPT Phase 00:00- 07:00 7.00 REST P 07:00 - 08:00 1.00 REST P 08:00 - 09:00 1.00 REST P 09:00- 19:00 10.00 RUNCOIVP 19:00- 19:30 19:30 - 00:00 0.50 RUNCOIVP 4.50 RUNCOIVP 5/20/2002 00:00 - 15:00 15.00 RUNCOIVP 15:00- 16:00 16:00- 19:00 19:00 - 22:30 22:30 - 00:00 Page 3 of 4 00:00 - 01:30 01:30 - 03:00 5/21/2002 03:00 - 05:00 05:00 - 06:30 5/6/2002 Spud Date: 5/28/1986 End: Description of Operations 06:30 - 07:30 07:30 - 08:30 08:30- 10:00 1.00 RUNCOIVP 3.00 RUNCOr~P 3.50 RUNCOIVP 1.50 RUNCOIVP 1.50 RUNCOIVP 1.50 RUNCOIVP 2.00 BOPSURP 1.50 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 1.50 WHSUR P DECOMP DECOMP DECOMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP CASING. L/D (9) 4 3/4" DCs. L/D BHA, INSPECT SCRAPER, NO IRREGULARITIES. CLEAR FLOOR. P/U & BREAK CONNECTIONS ON KELLY, PULL WEAR BUSHING. LOAD PIPESHED W/4 1/2" COMPLETION STRING, DRIFT, STRAP & CLEAN THREADS ON SAME. RIG UP FLOOR TO RUN TUBING. PJSM ON RUNNING TUBING WITH GATOR HAWK. EMPHASIS ON AWARENESS, BODY/HAND PLACEMENT. HAZARDS & RISKS IDENTIFIED. M/U JEWELRY & RIH W/4 1/2", 12.6#, YAM ACE 13cr TUBING & GLMs. TORQUE TURNING EACH CONNECTION TO 3620 FT/LBS & GATORHAWKING EACH CONNECTION TO 4500 PSI. CONTINUE TO RUN 4 1/2", 12.6#, VAM ACE, 13cr-80 COMPLETION STRING, TORQUE TURNING EACH CONNECTION TO 3620 PSI & GATORHAWK TESTING EACH CONNECTION TO 4500 PSI. M/U HEADPIN ON # 201 & WASH DOWN OVER TUBING STUB @ 3 BPM, 130 PSI. SEE PRESSURE INCREASE TO 460 PSI W/8' OF JT # 201 IN, SWALLOW 6' OF STUB & LOCATE OUT W/14.5' OF # 201 IN HOLE. PJSM. REVERSE CIRCULATE 140 DEG SEAWATER, 460 BBLS @ 3 BPM /230 PSI. AFTER PUMPING (1) TUBING VOLUME, TREAT SEAWATER W/CORRSION INHIBITOR & CONTINUE REVERSE CIRCULATING AROUND. LOCATE OUT W/14' OF # 201 IN HOLE. SPACE OUT: PULL # 201, #200 & #199, INSTALL (2) PUPS, 15.80' & 5.80', JT# 199 & M/U TUBING HANGER & LAND SAME. VERIFY LANDED & RILDs. PJSM. PRESSURE TUBING TO 3500 PSI TO SET PACKER & TEST TUBING @ 3500 PSI / 30 MINUTES, CHARTED, OK. BLEED TUBING TO 1500 PSI & PRESSURE TEST I/A & TOP OF PACKER @ 3000 PSI / 30 MINUTES. 100 PSI LOST IN 30 MINUTES, NO SURFACE LEAKS, CHARTED, OK. BLEED TUBING TO ZERO, SHEAR RP VALVE & BLEED ALL PRESSURE. HELD PJSM. BLEW DOWN AND RIGGED DOWN LINES AFTER PRESSURE TESTING. SET BPV. CIRCULATED FRESH WATER THROUGH MUD PUMP, BOP's, CHOKE MANIFOLD CHOKE LINES, AND TOTAL MUD SYSTEM. BLEW DOWN LINES AND DRAINED BOP STACK. HELD PJSM. N / D BOP's. SET BLANKING PLUG IN BPV. HELD PJSM. N / U ADAPTOR FLANGE AND PRODUCTION TREE. TESTED ADAPTOR FLANGE, NECK SEAL AND HANGER TO 5,000 PSI f/15 MINUTES, OK. HELD PJSM. R / U LINES TO TREE. PRESSURE TESTED TREE TO 5,000 PSI f/15 MINUTES w/DIESEL. OK. DRAINED AND R / D LINES. HELD PJSM. PULLED BLANKING PLUG. R / U DSM LUBRICATOR, PULLED BPV, R / D DSM. HELD PJSM. R / U LITTLE RED TO ANNULUS. PRESSURE Printed: 5/28/2002 11:40:22AM BP EXPLORATION Operations Summary Report Page 4 of 4 Legal Well Name: 01-29 Common Well Name: 01-29 Event Name: WORKOVER Contractor Name: DOYON Rig Name: DOYON 16 Date From - To Hours Task Code NPT Start: Rig Release: Rig Number: Phase 5/6/2002 Spud Date: 5/28/1986 End: Description of Operations 5/2112002 08:30-10:00 1.50 WHSUR P 10:00 - 13:00 3.00 WHSUR P 13:00-14:00 1.00 WHSUR P COMP COMP COMP TESTED LINES TO 3,000 PSI, OK. PUMPED 160 BBLS OF 100 deg DIESEL DOWN IA. PUMP RATE 2.5 BPM, 350 PSI. LINED UP VALVES AND LINES. U-TUBED IA AND TUBING. BLEW DOWN LINES AND R / D LITTLE RED. SET BPV. REMOVED 2ND ANNULUS VALVE, INSTALLED TREE CAP & GAUGES. INSTALL BLIND FLANGE ON ANNULUS VALVE. SECURED WELL. RELEASED RIG @ 14:00 HRS, 05 121 / 2002. Printed: 5/28/2002 11:40:22 AM GeoQuest 500 W. Infatuations! Airport Road Anchorage, AK 99518-1199 ATI'N: Sherrie NO. 9742 Company: 9/21/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant '3001 Porcupine Drive Anchorage, AK 99501 D.S. 7-16 D.S. 7-2 D.S. 7-16 D.S. 7-16 F.D. 14-15 D.S. 14-26 ~ ~.,,~ D.S. 15-05A ?/ Job # Well Log Description 9531 4 CNTG ~ PROD PROFILE ~ I~RFREI~RD ~,t~ PROD PROFILE ! PROD PROFILE d ~ U[ TBG PUNCHER/POGLM SET RECORD Field: Date BL 950910 950907 1 950909 1 950910 1 950914 1 950908 1 95O91O 1 950909 I Prudhoe Bay Floppy RF Sepia DIR MWD Disk SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: RECEIVED SEP 2, 1 1995 A/aska Oil & Gas Cons. Commission Anchorage Schlumber.cler I GeoQuest 51)0 W, Inlernational Airport Road Anchorage, AK 99518-1199 ATFN: Sherrle Well Job # ~.S. 1-3 -7~) ' I(o 94354 :~.. _.S. 3-12 -~- ~'o~ 94396 D.S. 1-4 ~ 2.~ 94399 D.S. 1-05 ST 7G~ ~0 94399 D.S. 1-06 '7 '~'~ /.~ 94399 D.S. 1-11 ? 7-- ~ 7 94399 D.S. 1-29 ~'(,,- I o3"" 94399 D.S. 1-7A c/~/.. ,~-z-- 94399 D.S. 14-20 ~'J'- 70 94399 D.S. 18-4 y 2.-:2. o¥ 94399 D.S. 4-44 ~ ¥--/O 94408 D.S. 15-8A ~ '~'-'1~ t~ 94364 Log Description DUAL BURST TDT-P (10-23-94) DUAL BURST TDT-P (11-24-94) - DUAL BURST TDT-P (4-20-94) DUAL BURST TDT-P (6-13-94) DUAL BURST TDT-P (6-13-94) DUAL BURST TDT-P/PRESSURE LOG (3-25-94) DUAL BURST TDT-P (6-14-94) DUAL BURST TDT-P (9-15-94) DUAL BURST TDT-P (3-11-94) DUAL BURST TDT-P (6-11-94) DUAL BURST TDT-P (12-13-94) PDC GR (10-1-94) PDC GR (10-02-94) NO. 9204 Company: Alaska 011 & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 ,eld: ~..-~udhoe Bay ~/~~R Sepia RF Sepia Ioqb"l Mylar 1/19/95 Floppy Disk · SIGNED: _ Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: June 21, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well ~ Log Date Numberi (M-D-Y) 1-05ST I 6-13-94 1-06 f 6-13-94 1-11 ~ 6-14-94 1-25 ! 6-10-94 1-29 f 6-14-94 1-30 16-08-94 3-02 ! 6-07-94 3-19 6-05-94 4-36 l6-11-94 4-41 l6-12-94 5-11 ~6-11-94 9-15 !6-13-94 9-18 i6-14-94 9-25 j6-i4-94 11-35 !6-11-94 11-36 i6-07-94 13-31 i6-09-94 13-35 i6-09-94 14-03 ~6-15-94 14-03 !6-15-94 16-23 ~, 6-13-94 16-23 {6-10-94 17-02 ~6-6-94 18-02 {6-12-94 18-04 l6-12-94 18-19 i6-10-94 Tool Type /" Dual Burst ,/ Dual Burst 1; Pen'Record Perf Record i'" Dual Burst CNL i/ Tubing Cutter i'/' Perf Record i"' Per[Record i ,-"Cutter Record "Dual Burst · ' Inj Pmf / Inj Pmf / inj Pmf -' Per[ Record · " Perf Record /' Per[ Record /' Per[ Record ~- Prod Log ,- Dual Burst -" Leak Detection ~' Alpha Tubing ~ Prod Prof / Per[ Record / Dual Burst ,-'Leak Detection P.O. Box 100360, '~....,~=horage, AK Transmittal #: I 1 5" 1 5" 1 5" I 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" I 5" 1 5" 1,5" 1, 5" 1,5" 1, 5" 1, 5" 1, 5" 1, 5" 1" & 5" 1, 5" 1, 5" 1" & 5" t Sch Sch Sch Sch Sch i Sch ! 1 Sch I . I Sch t Sch t Sch iSch Sch i Sch i Sch Sch i Sch t Sch ! Sch . ! i Sch Sch Sch Sch Sch i Sch i Sch * The correct APl # for 1-05ST is 50-029-20076-00 Number of Records: ~eG~rey~~~=~ Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska' ARCO Alas~m, Inc. Is a 5.b~idlar/o! AllanllcRIcMleldConlgmny .ARCO Al.,~b.-,. Inc. P.O.Box 10036O Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~ED HOL~FINALS 1-19 ~10-1-93 1-22 ~- I-~q /10-1-93 1-29 ~ 10-8-93 2-16A ~-~ ~ ~9-29-93 3-9 -'10-6-93 3-29 ~'~ /10-6-93 3-31 -~10-5-93 3-32 ~0'~ ~10-5-93 3-33 ~0-10-93 4-4 ~-~ ~0-9-93 4-12 ~ 10-2-93 4-24 ~- ~t ~10-10-93 .lc~..C~iZ~.:~/~ 9-30-93 - 10-1-93 6-12A ~2- ~ ~/9-29-93 6-13 10-1-93 7-5 7~-~ 10-6-93 -28 10-9-93 -28 x0-9-93 9-11 ~"~t~ /10-4-93 9-13 /10-3-93 9'20 '77-~ ~ ~ 10-7-93 ~10-1-93 12-22 ~(~0 /9-28-93 /13-20 ~0-2-93 ~-c~ ~, 13-20 /10-10-93 14-31~ y~-~ ~ ~ ~-25-~3 14-3~ ~-28-93 ~-~ 14-32 ~10-2-93 15-22 ~-~ ~9-30-93 ~- 2~ 16-17 ~ 10-8-93 16-22 ~ ~10-10-93 ~-~0 17-15 ~ 10-8-93 *** 17-16 ~'~ ~0-3-93 Perf Record Run Rerf R~m',] Run Prod Proflle l'~ l ' -':~ ~ ,~-~1~-~ Run Pe~ Record ~tt~-~ R~ Pe~ Record ~ ~ - ~ ~ R~ Completion R~ Pe~ Record R~ InJ Profile )~:~l~t~ Run Leak Detect]2P~J~-~l~-~/~ Run Prod Proflle{~m Perf Record ~ ~ ~oo .- ~ t~* 3~ Run Perf Depth Control/~/cc~- Completion Leak Detect / ~Prod Profile/~ /Completion 'Prod ~Dual Burst TDTP Leak Detect/~al~t~l~ InJ Profile Dual Burst TDTP Data Patch Setting InJ ~ome CNTG/GR/CCL HLDT/~[cc~ Completion Completion ~od ~o~e;~f InJ ~o~e~ Please sign and return thy attache? copy.u ~ceipt of data. RECEIVED BY Have A Nice Dayl Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON #BFX # STATE OF ALASKA The correct API# for 1-22 is 50-029-20848-00. The correct API# for ll-16ST is 50-029-21581-00. The correct API# for 17-16 is 50-029-22286-00. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, ,~1.~,_ 99510 DATE: 8-10-93 REFERENCE: '~-~f% 1-6 7-~--r~ 1-12 ~- loS: 1-29 /3-20A c1% ~q**'z ~3-20A ~,-.-~ 6-6 6-13 11-13A 12-26 13-7 14-22A 15-4 15-6 15-24 15-25 16-6 17-1 17-7 17-9 ARCO CAS~ HOLE FINALS 7-31-93 7-27-93 7-27-93 8-1-93 8-1-93 7-26-93 7-30-93 7-28-93 7-29-93 7-30-93 7-31-93 7-27-93 8-2-93 7-27-93 8-3-93 7-30-93 8-1-93 8-3-93 8-2-93 /~n-~e~- ~, 5" q too-. I t ~.~h Production ~og _ _~un 1, Px luctton Log '2- Run 1, 5" n ch PeriRecord~qz-q~ta Run 1.5" Sch Dual Burst TDTP Peri Record ,~-~5'? Run Peri Record ~zv ~ ~ Run Peri Record~ -~v0-~ ~ Run 1, 2"&5" Sch~-~°°o 1.5"~b-~t t~Sch 1, 5" Sch 1, 5" Sch 1.5" Sch Peri Record f ~-~o- jt !~..~ Il,,- 1, 5" Sch Peri Record ;~o~o- I~qO Run 1, 5" Sch Peri Record,x~o-~o R,,- 1, 5" Sch ~ B~t ~ R,,- 1, 5"~0' ~O~h ~-~ B~t ~ R~ 1, 5"~~7 ~h C~ ~-~9 R~ 1, 5" Sch ~ ~t ~ ~z~ ~R-n 1, 5" 6~ Sch ~ucflon 1, 2"&5" ~-~h ~O ~ucflon ~g" R~ ~ucflon ~g ' R-~ 1, l"&5"~-Sch ~~ ~~flon ~g ~' R-~ 1, 2'&5'~-~h ~ Please sign and' return the attached copy. as receipt of data. Have A Nice Day! Sonya W811qee AT0-1529 # CENTRAL F~ # CI~R. VRON # CLINT CHAPMAN # EXXON MARATHON # MOBIL The co,,¢~t API# f~r 11-13A is 50-029-212294)1 not 50-129.21229-01. The co,,c~--t AFl# for 14-22A is 504)29-20747-01. f~ STATE OF ALASKA ALASKA~ . AND GAS CONSERVATION CC~~ llSSION REPORT bF SUNDRY WELL OPEHATIONS 1 Operations performed: · operation shutdown Stimulate .. ;.; Plugging Perforate ~' Pull tubing ~ Alter casing Repair well .--- Other ~ 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB)~"'_.,~, Development X 70 RKB ARCO Alaska, Inc. Exploratory ,--'-- 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service -- Prudhoe Bay Unit 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical RECEIVED AUG 2 0 199 Alaska Oil & Gas Cons. Commission Anchorage 8. Well number 1-29 9. Permit number/approval number 86-105 10. APl number 50 - 029-21605 11. Field/Pool Prudhoe Bay Oil Pool 9610 feet 9256 feet Plugs(measured) PBTD Tag @ 9460' MD (7/24/93) Effective depth: measured 9460 feet true vertical 9124 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 10 shots Poleset 110' 110' Surface 2480' 13-3/8" 2900 sx CS II 2509' 2509' Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx CIG & 300 sx AS I 9606' 9253' Perforation depth: measured 9314-9329'; 9372-9382' true vertical 8996-9009'; 9047-9055' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 31' MD; 4-1/2", 12.6#, L-80, PCT @ 8764' MD Packers and SSSV (type and measured depth) Baker SB-3 @ 8650' MD; 4-1/2", Camco BaI-O SSSV @ 2190' 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1282 15239 1367 -- 1921 Subsequent to operation 2115/''''' 4124 1155 -- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations . Oil X~ Gas __. Suspended. , Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 346 Date SUBMIT IN DUPLICATE ",,. 1024/4 DEE cc: SW, JWP I -29 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 7/13/93: RIH & tagged bottom at 9415' MD. 7/19/93: An Acid Wash & CTU Cement Squeeze for Gas Shutoff, were performed as follows: MIRU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT & reciprocated an acid wash across the open perforations located at: 9127 - 9137' MD (Z4) Ref. Log: BHCS 6/8/86. 9309 - 9329' MD (Z2) 9373 - 9383' MD (Z2) Pumped 25 bbls 12% HCl w/10% Xylene, followed by 25 bbls 9% HCl - 1% HF @ 2.4 bpm, followed by 100 bbls 1% NH4Cl Water, followed by 227 bbls Seawater & 72 bbls Crude, then switched to pumping cement to squeeze the perforation intervals (listed above). Pumped a total of 48 bbls Latex Acid Resistive Cement & placed 11 bbls of cement behind pipe at 3500 psi max, held for I hour. Contaminated cement w/biozan & jetted cement from wellbore down to 9445' MD. POOH w/CT. Rigged down. 7/24/93: RIH & tagged bottom at 9460' MD. 7/27/93: Reperforated: 9314 - 9329' MD (Z2) 9373 - 9382' MD (Z2) Added perforations: 9372- 9373' MD (Z2) Ref. Log: BHCS 6/8/86. Ref. Log: BHCS 6/8/86. Returned well to production & obtained a valid production test. REEEIVED A US 0 199 ,alaska Oil & Gas Cons. Commission Anchorage ARCO .~1051,-, Inc. P.O.Box 100360 Anchorage, .~lss~- 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-0 s-2o-os 1-11 7'7-67 4-2-o3 1-1o s-22.os ~-22 ~-~ 4-6-93 ~~-~-20 4-6-03 1-3S ~1~ 4-4-0S s-27-0s 2-11 ~% 4-0-0s s-8 s-28-0s s-lo ~~ s-28-0s 4-2 s-20-0s 4-20 4-ss s-2s-os ~.~1 7U~O s-20-0s 6-0 =~ 7~ 4-S-os a-18 s-so-os a-22 ~~ s-2a-os -4A ' -~-4A S-22o0S4.0.0S '--O-SSA 4- X-OS O -1 x- XSA 4-0-OS x2-xx ~9~ s-sx-gs ~~ds-io s-ix-os x4-xs ~l~q s-so-os ~4-1~ 4-I-OS ~7-~0 4-S-OS /18-26 s-2s-9s. ~s-2a s-24-os ~.s-2v s-24-0s Leak Detect Production Production Peri Record Production Peri Record InJ Profile Peri Record Production Tubing Puncher CNL Static Pressure Press/Temp/Spin Static Pressure ProdUction/Gas Entry Peri Record Leak Detect 'Production Peri Record Peri Record Static Pressure Peri Record Production Peri Record Production PITS Peri Record Peri Record Peri Record Peri Record Static Pressure GR/CCL Static Pressure GR/CCL Run 1, Run 1, Run 1, Run 1, Run 1. Run 1. Run 1. Run 1. Run I, Run 1. Run 1. Run 1, f~' Run 1, Run 1, Run 1, Run 1. Run 1, l"&l~" Run 1, f~' Run 1. Run 1. Run 1, Run 1, Run 1. Run I. Run 1, Run 1, Run 1, Run 1. Run 1. Run 1, Run 1. Run 1. Run I. Run 1. Please sign and xetu,- the;attached copy as receipt~of dat~ Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch · Sch Sch Sch Sch Sch Sch Sch Sch Sch ARCO Ahska, Inc. P.O.Box 100360 Anchorage, ,~l~_qlr~ 99510 DATE: 12-18-92 REFERENCE: ARCO CA*qmD HOLE FINALS * 1-58T ~ 9-29-92 Perf Record 1-29~P~-t°~' 12-8-91 TMD 2-11 ?ff-~ 10-26-92 CCL (Pert] 2-22~2-~/~/ 10-26-92 ~- ~ ~/ 4-14~ 10-29-92 7-11/~- ~9 8-14-92 7-13 7~'-~°* 7-31-92 ~'~-~'¢ ** 12-6A 8-10-92 ~¢-~° 12-22 8-10-92 14.41F~2~ 10-25-92 Run 1, 5" ~iT_~ Run 1, 5" Run 1, 5" CCL (Perf) Run 1, 5" Atlas SBL/GR/CCL Run 1, 5" Peff Record R~ 1, 5" T~ (Bo~) R~ 1, 5" Peff Record R~ 1, 5" Peff Record R~ 1, 5" GR/CCL (P~~p~ R~m 1, 5" ~h RECEIVED BY Have A Nice Day! Sonya ~~ce ATO-1529 Please Sign and return the attached copy as receipt of dam. RECEIVED DEC ~ 0 1992 ... _ _AJ~ka_D.U & (~as Cons. Commission # ~iTX~U, FJ/,ff~chorage ' # CH v;VRON D&M # EXTENSION EXPLORATION # RYXON " MARATHON # MOBIL The correct APl# for 1-58T is 50-029-20076-00. The correct API# for 12-6A is 50-029-20401-01. ARCO Ahsk~ Inc. P. OJ3ox 1O0360 Anchorqe, ~p-*~ 99510 DAI~. 11-13-92 REFERENCE: ARCO MAGNETIC TAPE(Si wf~ti LISTINGS ~'~-¢~-~ 1-20~-~Z 9.3-92 ~ CNL/GR W ~/~? 1-29~-/o~' 12-8-91 ~/TMD ~/J~/~-~ * 2-3 ,~"-~z/ ~1.92 ~ ~l~ - ~~ 2-4 ~o-/~ ~1.92 ~ ~l~ ~ ~o 2-34 ~~ ~ 14-92~ ~K- 1~ ~ ~/ 7-13~-~~ 7-31.02 ~ ~~~7-29 ~g-~ 7-30-92 ~ ~/~ Run 1 Atlas Run 1 m-~ Run 1 Aths Run 1 Aths Run 1 Aths Run 1 m-~ Run 1 Aths l~e-~e Men and return the attached copy as receipt of data. RECEIVED BY /~V ~'~ Have A Nice DayJ SOil]ri Wqllq~_ ATO-1529 Trans# 9225 1 D&M BOB OC. J2t~ (OH/C,C~ # ~ON MARATHON MOBIL PB wp.T~ lm.l~S R&D # STATE OF ALA$~r& * The correct APl# for 2-3 is 50-029-20077-00. RECEIVED NOV 2 3 1992 Alaska Oil & Gas Cons. Commission Anchorage AR~ Alas~ Inc. P.O~ox 1OO36O Anchorage, Alaska 99510 DATE: 2-21-92 ARCO CA$~3~. HOLE FINAL~ 1-1B / 1-26-92 PDK-100/GR/CCL 1-29 ~// 2-7-92 CCL(Per~) ~4-34A ~ 2-6-92 PFC/GR (Per~ ~4-34A ~ 2-6-92 ~-:39 / 2-2-92 Pezf Record- -39 / 2-2-92 ~4-42 ~/ 12-28-91 C~ 12-25 / 2-3-92 C~ (~~ ~~) 12-25 / 2-~92 ~~ ~acker Reco~) R~ 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 2"&5' Run 1, 5" Rl!n 1, 5" R.n 1, 5" Run 1, 5" Run 1, 5" Have A Nice Day~ AT0-1529 Please ai~ and return the attached cogy as receipt of date. D&M EXTENSION EXPLORATION KxxON MARATHON MOBIL # I-H~,.T.Tps # STATE OF AL~$1r& RECEIVED FEB 2'5 1992 Alaska 0ii & Gas Cons. Commissior~ Anchorage 1. Operations performed: ALASI~" 31LAND GAS CONSERVATION C4~ IMISSION i'l REPOR' OF SUNDRY WELL OF'. RATION Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM At total depth 93' FSL, 2513', FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratoq Strafigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number feet 9. Permit number/approval .number 86-105 10. APl number 50 - 029-21604 11. Field/Pool Prudhoe Bay Oil Pool 9610 feet Plugs(measured) 9256 feet Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Caeing Length Size Cemented Measured depth Conductor 80' 20" 20 shOts Polecat 110' Surface 2480' 13-3/8" 2900 sx CS II 2509' Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx CI 'G'& 300 sx AS I 9606' True vertical depth 110' 2509' 9253' Perforation depth: measured 9127-9137'; 9309-9319'; 9319-9329'; 9373-9383' true verii¢~ 8762-8771 '; 8991-9000'; 9000-9009'; 9048-9056' Tubing (size, grade, and measure:t dep[h) Packers and SSSV (type and measured depth) Baker SB-3 @ 8650' MD; 4-1/2", Camco BaI-O SSSV @ 2190~MD 13. Stimulation or cement squeeze summary R [ C [IV ~ 14. Intervalstreated(measured) APR - it 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Representative nelly Average Production or Irljection nab] OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1649 17650 1227 - 1947 Subsequent to operation 16565 431 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certify that the fore/~ing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 ~.,/' CC: S. Wallace/DS Engr/~J.~/W. Peirce 2589 / - 1903 Oil x.~_ Gas ~.. Suspended ~. Service Date ~'/&/~ ,7...._ SUBMIT IN DUPLICATE DS 1-29 Description of Work Completed Subject well was adperfed on February 7, 1992. Total MD SS' SPF Feet 9127-9137 8762-8771 4 10 Ref. Log: BHCS 6/8/86 RECEIVED APR - 8 1992 .Alaska Oil & Gas Cons. Commissio'~ Anchorage STATE OF ALASKA ALASK~" '_ AND GAS CONSERVATION C~ ,'llSSION REPORT uF SUNDRY WELL OPERATIONS Stimulate Plugging Perforate X~ 1. Operations performed: Operation shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM At total depth 93' FSL, 2513, FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Repair well 5. Type of Well Development X~ Exploratory Stratigraphic RECEIVED JUN 1 1 199 Alaska 0il & Gas Cons. Commission Anchorage 9610 feet Plugs(measured) 9256 feet O~her 6, Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-29 .- 9. Permit number/approval number 86-105/90-186 10. APl number 50 - 029-21604 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 20 shots Poleset 110' 110' Su dace 2480' 13-3/8" ~ ,x cs, 2509' 2509' Top Job w1150 sx C$ II Production 9579' 9-5/8" 670 sx Cl 'G'& 300 sx AS I 9606' 9253' Perforation depth: measured 9133-9137'; 9309-9319'; 9319-9329'; 9373-9383' (isolated below sand/cement cap) true vertical 8767-8771 '; 8991-9000'; 9000-9009'; 9048-9056' (isolated below sand/cement cap) Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.6#, PCT @ 8764' MD Packers and SSSV (type and measured depth) Baker SB-3 @ 8650' MD; 4-1/2", Camco Bal-0 SSSV @ 2190' 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-Md Water-Bbl Casing Pressure Prior to well operation 3045 30218 0 -- Subsequent to operation 3430 '~ 31372 -" 0 -- 1572 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ...._ Oil x Gas __ Suspended __ Service 17, I hereby certify th.c~the foregoing is. true and correct to the best of my knowledge. Signed ~~ ~',...~_ _.-........ - -) Title Senior Area Engineer Form 10-404 Rev 06/15/88 ' Tubing Pressure 1429 t Date /~y (3~7'I~' SUBMIT IWDUPLICAT~,~ DS 1-29 Description of Work Completed Subject well was adperfed on April 10, 1991. M 13 S S' SPF 9133-9137 8767-8771 1 Total Feet 4 Ref. Log: BHCS 6/8/86 RECEIVED JUN 11 1991 Alaska Oil & Gas Cons. Commission Anchorage .' , "'. .... ;.PL O',".'E~OX 'i ~e36i~ ...... ' ........ . : .... ?'.,.:::.~r....~-.:',:..??:':~.~-~!: ........ :"... ..................... ... ': '.' .",...:~.....'...,.:.,..Z' ... '. ' . , :.. , .. : .. ',<~,. ,; ,. ' ..i ;... '"' ... ANCHORAGE, ALASKA .995i(~., ' '""'"~ ' ' ' ,"" ' 'i"'""': ""/"~ " ............. ,~ ............. i ........................... ' "' " ' "' ' ..... . ' ~. ' ' "' ' ' - ' - '., .'.. ' ".'"";.,'..~'.::. t'.'''~''' i"~'..' .~;.¢~j~,~-')2:..'.d,., .... .' . '. · · '. :" . ' . . ".. :.... ',-'."'..':':'(~:' i. '..: .,. :,.'. '~ ~..;'~'~'.!~':.:~.~- .: ' ' · · ' . '. ' ..... ,' ' . " . ' . .' , '...'. ,..",,%~,-~,,!,~' "~4," ,,.S.,'Y:,~.,',~.',~',,,'.,',',,', .... ', . · .. ':. ' -.' ' : "'Tq '? .'"" "". '.', '.' '~ "'~-' u',.~'%~'~SX.:Y:~','.~'~. . .: . ..... . ....... · .... . .......... . ,.. · .L..' ...... ',.' .-~':; ....... ' ::'-'4~,:'::'~':~-i'-'~,..~'.'"'~,":.~'",:,~,"~:~'. ................... . .... : ...... ~ ...... '-. ........ : ".'.-,.'.'.'~':"-~"~/ii:4f-~ ...... '~'~.'~,'.i~.~'~?,~!'<~;' .:', ..... ' · .... . .......... ~.' ' . .',~' .... : .'~. ~',"....:.,~.?~;'.'..?'. ' '. ...... ' ~. - .' . .. '.:,..,~;~":.',.~.; ".' ..... .d!-.~,~.';';~i;D ." :," ' . .... , . "' DATE: 5-i 6-?i . .., .... · ...... REFERENCE' ARCO CASED '":HOLE FINALS 3-i 8 ..... 3=29 3-2? ......... 3-.29 5-3 6-6 9'-'39 9-39 9-4~) ..... 'i.,.. ....... 9~'-4'3 ......,,. .,, · , . , . . . . . .," ,.,., RUN .1"':t'I ':'," :' ' 5 ' ' .' '" '" ~'"'.:': ."': : .... RUN"~ ;i,..5:"' '""";: .... A.TL.A~' ' .. RUN i, 5" ., CAMCO ..... RUN,'t", 5' 'HL$' RUN i.','" 5' - HL$ ".R'UNF".t','.' 5' ......... .',.'."":". ....... ATLAS' RUN "'i ;.':"2' &'S ":' .'..'4 .'"'""'"CAMCO RtJN f, 5 · CAMCO 5-5.-9i CBT. RUN i, 5 · 2CH 5--5'9t .."" ;.".CET'.:I~'I ~I ' . I Ill' I . 'I '" ' I: I'' ;I~I'' "':''I' I'' ' ' ' ' ' ' ' I .... RUN"' t Im'I ''II '5 ' ' ' ' ' ..... :~'']'I ' I ''$CFI ~-~ ~-~t' "':~".',"."'GAH'MA'"" ~;'L!:':?~jk:".'.'~JEWELRY 'PERF. RE(;ORD"RUN".. i.';r.'/"5 ": '" """ ']'".."'HL$" . . . ... t"-: ~':4'.~gi'v":'"L:'i'!'Y:F'E.R"F:."2~ECOP, I)'":'!".':'..'' '.':'.:;:". '.' ..................... 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"?P.'." ..................................... .. .... ............... , ........ _ ...................... . : ..... - ~ .... . .... - .... ~ ...... . h~: ..... .'~,.~-.-.-~,.~ ~..-~-, --. ..... :.~, , . ......: .~., _ ..~-:~,~.~ :' ~ ~ .~:.: ~ · · .. ~:, ,~,~ ~......~. ,~..~..:~ · ,.,~:~-~-~--~?~ ........~.-::~,, m-,- ~ ........ ~,. ~~-.-. ,~r-,:::.-~.~,.~ '~-t-, ~¢,..~.~,~-:~-~..~,::.~:~ ~. ~- ~,~,~;~ ~ ' ~ ~ ~..,~ .. .,-, _.-,.:. ,..: .. : ...... ,...., :.~,,:..,_~.:.,....-,:~:~,~.~.:.:~,~,,,~:, ,~,~-...-.. ?.-~..~....... :, ::~.-,,.,. ..... ,,. _..,~ ....... .. ,,.,~,:;~<~ ~,, ,~......,,.,. .............................................. . '.., -~ ' ~'-: ;; '.' - · · -~ ' · .~ ::' ~..;';~ :;.' ' ;:~'~.:~- '~: ~- ~-'~',~'~-,~: -'~ -~"~,~,,,~.... 7-' .~,-,z,; .. ':;.r'~}'~;~:' '-_" '7~.',~':f':~ :'-.~ ~ '"'~:.~'~ ~' ~"~ ~'"%'~.~" . · .:. ..... :~: ...... - -:., .: .... ... .... .~.:':~..~ ...~,..- ~?r~:..~.::,;. ~:. '-~:~:..";~c: ~..:-%,~,~z~y~:..~ ,~ ..... ~ _~¢--.,~,:-~:., 74:-~> ,~:~:=~:,~,~;TF:.A~:-T~.>~,:~-~ ~'~- .z'~:'.~ ....... . ...... :,:,...: ' --,-- -.%, , '- ~,'~ : ........ '; -': .~ --. , . - ~ ;.~ ~, --r=_ -:. ~: '.~'.- ~..-- ~..' ,~;'~- .= - - -- ~ : .-.~Z'~ b~.-~- :~ .... ~ ~ ~ - ;~,~:~ ~,~,.~-,~. ~ ',~-;z~ ..'~ -*; ~ --;;~- ~-= '~.~::.;~-; ~ r ~- . · .' ~- "- '~: -~::: .... :,', .... ~::".'-- '"-', .... ¢ ..... ~ .... , ....... ~ '~ - -~.~'.:.; ..... r~,~.,¢~¢~-'?- .... ~' ~:;~ ...... ~, ..... ~ ~ --'~ ' :,; ...-.-: ARCO ALA£KA, INC ..... F'.O. BOX 108368 ANCHORAGE, ALASKA DATE: i-2i-9i REFERENCE: ARCO CASED HOLE FINALS F'DK-i~,O/DIF'F.CORR. SIGMA & F'ORO RUN PRODUCTION PROFILE RUN l' EMF'ERA '['U R E RUN PRODUCTION PROFILE R'UN PRODUCTION PROFILE RUN TEMF'IFRATURE RUN INJ PROFILE RUN FLOWMETER/TEMP SURVEY RUN PITS RUN PITS RUN INd PROFILE .RUN INJ PROFILE RUN INJ F:'ROFILF RUN PRODtJCTION F'ROFILE RUN F'RODUCTION PROFILE RUN PRODUC'I'ION PROFILE RUN PLEASE SIGN RECEIVED BY HAVE A NICE DAY! SHARON WILSON AT0-i529 AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. AF'F'ROVEB~=~ 'rRANS~ 9t 82t · ATLAS dAmCO CAHCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CA~CO CAMCO CAMCO CAHCO CAMCO D I .s,'TR I.BUT I ON CENTRAl_ FILES ,- CHEVRON ,,~ EXTENSION.EXPLORATION EXXON MARATHON ~ MOBIL F'FIlLLIF'S F'B WEL,L FILES R&D BF'X $1'ATE 'OF AIZASKA' TEXACO "RECEIVED' JAN 2 9 1991. AJaska Oil & Gas Cons. CommJssion ....... Anchorage I' ...... · '-% .... ,..~ P 0 B 0'~ i ,,-,,,,~ ,", o u ANCHORAGE: ALASKA ~95i() DATE' i ()-i 8-9G PCFERENCE ',,_ ARCO. PASED.,. HOLE .i--'r*,iAL Z...., i _r.~_. 8-i ~-'5 8-'29-9G COLLAR RUN i , 5 i -i 2 8""3¢-9¢ FIERF RECORi) RUN '-, 5" i -29 8-t , ,~,...,,uK~ RUN 2-'7 5-i '7 9"-i 6--'i4 8 .... 5i'--9¢ PERF' RECORD Ri.iN i , 5" 6 .... 25 8-5t-9¢ F'ERF RECORD RUN "i , 5" i i --' ! 7 9-'7'-96, F'ERF' RUN i i ._,.~o~ i 2 .... i 8--6 .... 9¢ PERF RE:CORD RUN i , 5" f 4--i i6---2i 9--6'--9e F'ERF RECORI) RUN i , 5" F'L. li"AS!E SIGN AND RIETUIF,,'N THE ATTACHED COF'Y AS I;,'IECEIF"f' 01:-' DATA, I.,, I::.,_. i- I V E D B Y _ I'-iAVE: A NICE DAY! SAi..I... Y HO F'F" i_:-" CI< E R ATO'-t 52°. , I--iL.S HL$ 1.4 i ~': I HL.S HL_:£' i..I. ';' HL.S l..iL_;f H;L_S I..iL.'~' HL$ HI_S DISTRIBUTION · "- C;:NTRAL FILES .~i: C H Ii:' V R 0 N D & M · "',,. EEX'FEN£ION EXF'LORATION. ~~ EXXON MARATHON :~ MOBIL · ioi · "' F'HILL.[F $ PB WELL R & b :~ BPX STATE OF' ALAS'I<A TEXACO RECEIVED OCT I 9 1990 A/aska 0ii & Gas Cons. Commission Anchorage · : . STATE OF ALASKA U" ~"~ :! i'..:.'.~ ,~ ~'",; · . ALASK/¥ 'L AND GAS CONSERVATION C~' ,VlISSlON ~ ~'~' REPORT F SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate Plugging ~ Perforate X Pull tubing ~ Alter casing ~ Repair well .---. Olher X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM 5. Type of Well Development Exploratory Strafigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-29 9. Permit number/approval number 86-105/90-186 10. APl number 50 - 029-21604 feet At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9610 feet Plugs(measured) 9256 feet 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 80' 20" 20 shots Poleset 110' Sudace 2480' 13-3/8" 2900 sx CS II 2509' Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx Cl 'G' & 300 sx AS I 9606' True ve~icalde~h 110' 2509' 9253' Perforation depth: measured 9309-9319'; 9319-9329'; 9373-9383' (isolated below sand/cement cap) true vertical 8991-9000'; 9000-9009'; 9048-9056' (isolated below sand/cement cap) Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.6~, PCT @ 8764' MD Packers and SSSV (type and measured depth) Baker SB-3 @ 8650' MD; 4-1/2", Camco Bal-0 SSSV @ 2190' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached 14. Treatment description including volumes used and final pressure .~i~!.].!~:..~ ........... ,,~,.~.,~. f,~ ......... .~.,..., "~' .;~ '.7" Representative Daily Average Production or Injection Data · ;' v,',!~ .~.',~' ! ,'..';'~ "~. OiI-Bbl Gas-Mcf Water-Bbl Casing PressiJre" '~ Tubing Pressure Prior to well operation 2985 21542 787 -- 1120 Subsequent to operation 2962 5024 16 -- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 547 DCR c: J. Gruber, ATO-1478 SH 250 Date /0/11/~ SUBMIT IN DUPLICATE-~.~ DS 1-29 DESCRIPTION OF WORK COMPLETED SAND DUMP/CEMENT CAP FOR GAS SHUT-OFF 5/9/90: MIRU, & RIH w/CT. Fluid packed wellbore w/seawater, then pumped 90 bbls of Sand Slurry, to cover perforations at: 9373 - 9383' MD Ref. Log: BHCS 6/8/86. Pumped 20 bbls 12% HCL. Displaced CT w/Meth-Water. 5/10/90: RIH, & tagged top of sand at 9360' MD. POOH. RD. POOH. RD. 5/16/90: MIRU, & PT equipment to 4000 psi. RIH w/CT and pumped a 10' cement plug on top of sand, from 9350 - 9360' MD. Displaced CT w/Meth-Water. POOH. RD. 5/26/90: RIH, & replaced DGLV's w/LGLV's. RD. 7/3/90: MIRU, & PT equipment. RIH w/CT and pumped 0.7 bbls of cement on top of the previously pumped cement/sand. POOH. RD. 7/8/90: RIH, & tagged bottom at 8991' MD. POOH. RD. 8/15/90: RIH w/underreamer, and underreamed down to 9345' MD. Circulated fill out of the wellbore. POOH. RD. 8/18/90: Reperforated: 9309 - 9319' MD 9319 - 9329' MD Ref. Log: BHCS 6/8/86. Flowed well. Obtained a new capacity. STATE OF ALASKA 'L AND GAS CONSERVATION ALASK/~' ~MISSION REPOR'P',JF SUNDRY WELL OPERATIONS Operation shutdown Stimulate Pull tubing Alter casing 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FWL, Sec. 8, T10N, R15E, UM At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical ....... Plugging ~ Repair well 5. Type of Well Development Exploratory Stra~graphic Perforate X 9610' feet Plugs(measured) 9256' feet Other 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-29 9. Permit number/approval number 86-1 05,./~, ~,-~. ~j ~_ ~ ../,~,~, 10. APl number 50 - 029-21604 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 9353' feet true vertical 9030' feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 10 sx Poleset 110' 110' Surface 2480' 13-3/8" 2900 sx CS 1 2509' 2509' Top job w/150 sx CS 11 Production 9579' 9-5/8" 670 sx Class G & 300 sx AS 1 9606' 9253' Perforation depth: measured 9309-9319'; 9319-9329' true vertical 8991-9000'; 9000-9009' Tubing (size, grade, and measured depth) 4-1/2", L-80 tubing w/tail @ 8764' RECEIVED S E P - 6 1990 Alas .ka.0J~ & Gas (;0,s, , ~01zqr~. ~,---'"" ..... Packers and SSSV (type and measured depth) Baker SB=3 @ 8650' & BAL-O SSSV @ 2190' 13, Stimulation or cement squeeze summary Intervals treated(measured) Well was perforated Treatment description including volumes used and final pressure 14. Prior to well operation Representative I')aily Averaae Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 2194 13165 515 ..... Tubing Pressure 1691 Subsequent to operation 3406 2342 0 ..... 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil ~ Gas .__ Suspended ~ Service 17. I hereT~ t~/~he foregoing is t, rue and correct to the best of my knowledge. ~igned Z___~ '~'~;~. ,. "'~Title Senior Area Engineer rm10-40," Rev 06/15/88 ~S/Sun\ II 250 DESCRIPTION SUMMARY PRUDHOE BAY UNIT DS1-29 WELL APl # 50-029-21604 Permit # 86-105 ARCO Alaska, Inc. perforated DS 1-29 at selected intervals within the Sadlemchit Sand of Prudhoe Bay Unit as shown below. Ref: Schlumberger GR/BHCS, 6/8/86 Intervals perforated: Date 9309-931 9' M D Aperfs Zone 2B 4 SPF 8/1 6/90 931 9-9329' M D Reperfs Zone 2B 4 SPF 8/1 6/90 Subject well was also ,plugged back with sand and capped with cement to 9353' MD (9030' TVD), isolating lowest set of perforations @ 9373-9383' MD. RECEIVED S E P - 6 1990 Alaska 0il .& Gas cons. .... STATE OF ALASKA !,.',;. ALASK./( .... 'L AND GAS CONSERVATION C(" ,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown ~ Stimulate ---. Plugging ~ Perforate X Pull tubing Alter casing ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured 9610 feet true vertical 9256 feet Repair well 5. Type of Well Development X Exploral~y Stra§graphic Plugs(measured) Olfler X 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-29 9. Permit number/approval number 86-105/90-121 10. APl number 50 - 029-21604 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 20 shots Poleset 110' 110' Surface 2480' 13-3/8" 2900 sx CS II 2509' 2509' Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx Cl 'G' & 300 sx AS I 9606' 9253' Perforation depth: Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.64t, PCT @ 8764' MD RECEIVED measured 9319-9329'; 9373-9383' (isolated below sand/cement cap) ~ true vertical 9000-9009'; 9048-9056' (isolated below san~cement cal:~/~ Oil & Packers and SSSV (type and measured depth) Baker SB-3 @ 8650' MD; 4-1/2", Camco Bal-0 SSSV @ 2190' MD 13. Stimulation or cement squeeze summary The proposed CTU cement squeeze was cancelled; A sand dump/cement cap job was approved Intervals treated(measured) (#90-186) and was done in place of the C I'U squeeze. Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection 13at~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure .. Subsequent to operation ........ 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations m Oil~ Gas ..._ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 480 DCR c: J. Gruber, ATO-1478 SH ,SUBMIT IN DUPLIOATE F:' .. 0. B (3 X 4 ,:3 E:, ~'."~ c<.~ A iq C.: H J")I:;..' A 6 [-:., A L A DATE' 7-S-90 R.::.FE..~':. ..... ,_ ARCO MAGNETIC TAPE(S) WiTH I...]:STii"!,G($) - 'J i 6-2-90 -:28 6- i i -9,:3 · -"29 6--.3 - 9 ,...-.--26 6-9-9() 5--i 8 6-~ ".:.:'-9(3 6-"~'.'.":' 6-i i-o0 .¢.... .. ]""'2~ 6-- i j-90 DSN z./'~ ~,~.- JOB.~..,264242 'FDT.-F'/BURAX ( 7 F'A£'£') , RUN '; ~'"'~ ~l[:~"~"/,"-;9'J~:..'., T ::, T- F' ( :: PA ::' S '..~, ~::: U ;'.~. 'l r ~ ~' ~'Y" ,: u [~ :~';' .: ? 'i :" · -i .-! - · .[ I::' L E A ~¥ ["' .'":,' I ['~ N A N D F, E 1 J R N ]"I"iE A"f' T A C I'-I F D C 0 P Y A,~' R E C E I P'i" 0 F' D A i"A ,. HAVE: A N. ICE DAY! ;~ AL.L.Y HOFFECI<I::R A TO-.~ 5 2 9 ,.. JUL - 6 1990 Alaska Oil & Gas Cons. L;omm'tssWt~ A P F' R O V E ~chomga 'T'RAN,S:~ e.. A HL.,S' A i-LA;S HL Z ,.SCFi ;S C ;"i D I S' T R I B U T ]: 0 N CENTRAL. FILE;.~; (CH) CHIEVRON D & M ]"AMMA$ BROWN (OH) E X X 0 N MARA'rHON MO B I i_ !- I-I.[I_L l F'$ F'B WIEI_L FILES ..'"'BF'X :~ STATE 0i-'-' ~:~L~'~I,A T E X A C 0 1. Type of Request: 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 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM STATE OF ALASKA ALASIq" ~ILAND GAS CONSERVATION ~'~ ~MISSION APPLICh rlON FOR SUNDRY A¥,PROVAL Abandon Suspend ~ Operation shutdown ~ Re-enter suspended well ~ Plugging ~ Time extension~ Stimulate Pull tubing ~ Variance Perforate X Other 5. Type of Well 6. Datum of elevation(DF or KB) Development :X 70 RKB feet Exploratory 7. Unit or Property Stratigraphic ser~ce Prudhoe Bay Unit 8. Well number DS 1-29 At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM 9. Permit number 86-105 10. APl number 50 - 029-21604 At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9610 feet Plugs(measured) 9256 feet 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 10 sx Poleset 110' 110' Su dace 2480' 13-3/8" 2900 sx CS 11 2509' 2509' Top job w/150 sx CS 11 Production 9579' 9-5/8" 670 sx Class G & 300 sx AS 1 9606' 9253' Perforation depth: measured 9319'-9329'; 9373'-9383' true vertical 9000'-9009'; 9048'-9056' Tubing (size, grade, and measured depth) 4-1/2", L-80, tubing w/tail @ 8764' REEEiVED · 4~aska .Oil.&, ~as Co.$. ' ~chora~ Packers and SSSV (type and measured depth) Baker SB=3 ~ 8650' & BAL-O SSSV ~ 2190' 13. Attachments Description summary of proposal x~ 14. Estimated date for commencing operation June ,1990 16. If proposal was verbally approved Detailed operations program BOP sketch 15. Status of well classification as: Oil ~ Gas __ susPended X,, Name of approver Date approved Service 17. I hereby ce~fy that the foregoing is true and correct to the best of my knowledge. Signed ~~b~ ~(//~,,~ J~. ~ Title Sr. Area Engineer t3R ~.{3MMIRRIt3N I IRI= t3NI Y Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~ 4. I Approval No. Approved by order of the Commissioner Form 10-403 Rev 06/15/88 WHS/SUNVI ORIGINAL SIGNED BY I_rlNNIF C. SMITH Commissioner Approvecl Copy SUBMIT IN TRIPLICATE ARCO Alaska, Inc. proposes to perforate DS 1-29 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested at 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref: Schlumberger GR/BHCS, 6/8/86 Proposed Reperforation Intervals: 9309-9319' MD Aperfs Zone 2B 4..'~,PF 9319-9329' MD Reperfs Zone 2B 4 ;.~JPF 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE · 2. 5000 PSI WIRE:LINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI ¢ 1/6" FLOW TUBE PACK-OFF J 1 I,I 1 REL I NE BOP EGU I PIqENT ARC[) ALA.S'KA., ]]NC. F'. 0. BOX i ,S, ,:.") 3 6 ,3 ANCHORAGE, ALASKA 995i0 DATE' 6!7/9~ REFERENCE' ARCO CASED HOLE FINALS PWI)Wi-..-~. s-.~o-90_ ,_, . SQUEEZE: F'ERF RUN I, 5" F'WDWi.-2 5-29-9G BRIDGE F'LLJG SET'Fi[NC, REC RUN i, 5" i-ti 6-2-90 [;OMF' NEUTRC)N G/R RUN t, 5' i-2~,.) 6-2-90 COMP NEtJTRON G/R RUN t, 5" i-29 6-:5-'90 COMF' NELJTRON G/R RLJN i, 5" ~-2'? 5-24-90 COMP NEUTRON RUN t, 5' 4-3~ 5-i9-90 POST INJ TEMF' RUN i, 2" 6-2 5-25-9~ COMP NEUTRON RUN ~_., 5" 7-.i 6 5-24-90 COMF' NELJTRON RUN ,.,~-, 5" ~ 2-t 8 5-30-90 COLLAR RUN t , 5' i8-i7 5-23-90 COMF' NEUT. RON RUN i , 5' t 8-t 9 5-2L.'1-9(> COMP NIEU'I"I~:ON RUN t , 5' PLEASE SIGN .AND RETURN THE AI'I'ACHED COPY AS RECEIPT OF DATA, HAVE A NICE DAY! dUN SALLY HOFFECKER AJ~ OJJ & G~ A T O- i 5 2 9 ~nchomge I'RANS~- 9(~2t ='I C I--I 2CH A'[ LA2 l" I_A S ATL. A..:. ~''' $C!"t HRS SCH SCH TI_AS $'CH SCI'-I ,. DIS'TRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHQN MOBIL '~' F'HILLIF'S PB WELL FILES · ,-'"' BF'X · "'STATE OF ALASKA TEXACO ARCO Alaska, Inc~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 2, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-291 Permit No. 86-105 Dear Mr. Chatterton: Attached is a resubmitted Application for Sundry Approval in triplicate detailing work to be performed on the above-referenced well. Please void the earlier approval #90-121 of 2/28/90 for the cement squeeze which will not be performed. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 1-29)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany APR - ~ !990 Alaska Oil & Gas Cons. AR3B--6132-(3 1. Type of Request: , STATE OF ALASKA ALASK~ ~ IL AND GAS CONSERVATION~q' 1MISSION iili~ ;',"i "~ .'.:i]i ~., APPLlCA i'ION FOR SUNDRY AFPROVALS Abandon~ Suspend ~ Operation shutdown ~ Alter casing~ Repair well ~ Plugging ~ Change approved program ~ Pull tubing ~ Vadance 2. Name of Operator 5. Type of Well ARCO Alaska, Inc. Development X Exploratory 3. Address Stratigraphic P.O. Box 100360, Anchorage, AK 99510-0360 set, ce 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM Re-enter suspended well Time extension Stimulate Perforate X Other X 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number feet 1-29 At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9610 feet Plugs(measured) 9256 feet 9. Permit number 86-105 10. APl number 50 - 029-21604 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 20 shots Poleset Surface 2480' 13-3/8" 2900 sx CS II Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx Cl 'G' & 300 sx AS I Perforation depth: measured 9319-9329'; 9373-9383' true vertical 9000-9009'; 9048-9056' Tubing (size, grade, and measured depth) 4-1/2"' L-80, 12.6~, PCT @ 8764' MD Measured depth True vertical depth 110' 110' 2509' 2509' 9606' 9253' APR - } 1990 Alaska 0il ,& Gas C0us. G0mm~$st0-~ 'Anctiomg~ Packers and SSSV (type and measured depth) Baker $B-3 @ 8650' MD; 4-1/2", Camco Bal-0 SSSV @ 2190' MD 13. Attachments Description summary of proposal 14. Estimated date for commencing operation April1990 16. If proposal was verbally approved x Detailed operations program BOP sketch 15. Status of well classification as: Oil ~ Gas Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~..~~x~ ..~ ~,~, ~4¢,~ Title Operations Engineering Manager Date Ft3R ~(3MMIRRIt3N llRI= (3NI Y Conditions of approval: Notify Commission so representative may witness;I Approval No. ~..,.. Plug integrity BOP Test Location clearance / Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 311 D.C. Ream ,ORI61NAL SIGNED BY LONNIE C. SMITH Commissioner Date z~_/'~'Z ~ SUBMIT IN TRIPLICATE D.S. #1-29 CTU GSO/WSO Sand Dump PRELIMINARY PROCEDURE Objective: The purpose of this workover is to shut off excess gas and water production. 1. RU slickline. Tag bottom. 2. RU CTU and sand-dump equipment. RIH with open-ended nozzle. Mix and pump gelled sand slurry. Sand volume should be sufficient to bring sand top to 9360'MD. RD CTU. 3. RU E-Line unit. Tag top of sand. Dump bail -5 sx of cement on top of sand. RD E- Line unit. The perforations to be covered with sand are as follows: (Ref. BHCS dated 6/8/86): Perforation Interval Zone 9373'-9383' 2A 4. Shut well in for one week to allow cement cap to cure. RU Slickline unit. Tag top of cement cap. Should be at 9350'. 5. Return well to production. Current Status: Producing with a ~6500 GOR. Estimated Reservoir Temperature: 199°F Estimated Reservoir Pressure: 3580 psi APR - ~ 1990 Alaska .Oit ~, 6as Oons. {;o~a~lss~' 161 4 , , > ! I . 5 I I I I I ! i I 1990 APR ' 3 L~. Od & Gas Gons. 1 I COILED TUBINg UNIT BOP EGtU ! PHEN~" HIREL INE BOP EOU ! PMENT 5000 PSI 7" W[:LLHrjId) CONN£CI'OR FLAJ~G£' 1. 5000 PSI ?" W[LLHCAX) CONNECTOR FLANG! 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS S. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING; BOX 2. 5000 PSI WIRELIN£ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, In[( Prudhoe B,. c~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager February 23, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-29 Permit No. 86-105 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 1-29)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompa.ny AR3B--6132-C 1. Type of Request: STATE OF ALASKA .- '"'" '" ;j iii ,L~ ~ ALASKf' OIL AND GAS CONSERVATION {. MMISSION '~'"~ '" "-' '~ ' '~' APPLIC.. ION FOR SUNDRY APPROVALS Abandon Suspend ~ Operation shutdown ~ Re-enter suspended well ~ Alter casing Repair well Plugging --... Time extension Stimulate Change approved program ~ Pull tubing ~ Variance Perforate X 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) ARCO Alaska, Inc. Development ~ 70 RKB feet Exploratory 3. Address Stratigraphic -- 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 ser~ce __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM Other X 1-29 At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5, T10N, R15E, UM 9. Permit number 86-105 10. APl number 50 - 029-21604 At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 9610 feet Plugs(measured) 9256 feet 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 9663 feet true vertical 9215 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 20 shots Poleset Surface 2480' 13-3/8" 2900 sx CS II Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx Cl 'G' & 300 sx AS I Measured depth Truevedicaldepth 110' 110' 2509' 2509' 9606' 9253' ,ECE VED Perforation depth: measured 9319-9329'; 9373-9383' true vertical 9000-9009'; 9048-9056' Tubing (size, grade, and measured depth) 4-1/2', L-80, 12.6#, PCT @ 8764' MD Packers and SSSV (type and measured depth) Baker SB-3 @ 8650' MD; 4-1/2', Camco Bal-O SSSV @ 2190' MD 13. Attachments Description summary of proposal 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved Detailed operations program BOP sketch 15. Status of well classification as: Oil ~ Gas Suspended · x Name of approver Date approved Service 17. I hereby certify th_at the foregoing is true and correct to the best of my knowledge. Signed 4~'J/~'~~~~ Title Operations Engineering Manager F~R ~.~MMI~fiI~N I1.~1= ~NI Y Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ~,,/i.. Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Date tApproval No. Commissioner Date SUBMIT INTR IPLICATE 311 D.C. Ream D.S. #1-29 CTU GSO/WSO Cement Squeeze PRELIMINARY PROCEDURE Objective: The purpose of this workover is to shut off excess gas and water production. 1. RU slicklinc. Surge well and tag bottom. 2. RU CTU and acid equipment. Acid wash thc perforations. 3. Flowback acid load and production test thc well. 4. RU CTU and cementing company. Squeeze off perforations with a maximum squeeze pressure of 3000 psi. Thc perforations to bc squeezed arc as follows (Rcf BHCS dated 6/8/86): Perforation Interval Zone 9319'-9329' 2B 9373'-9383' 2A 5. Maintain 3000 psi squeeze pressure for one hour. 6. Reverse out cement remaining in wellbore with gel. 7. Cleanout wellbore to PBTD. 8. Shut well in for one week. 9. Perforate the well as follows (Ref BHCS dated 6/8/86): Pre-squeeze pcrfs Comments 9319'-9329' Sol'n GOR 9373'-9383' Gas/Water 10. Return well to production. Post-squeeze pcrfs Zone SPF Comments 9319'-9329' 2B FSD Rcperfs 9383'-9393' 2A LSD Addperfs Current Status: Producing with a -6500 GOR. Estimated Reservoir Temperature: 199°F Estimated Reservoir Pressure: 3580 psi 161 4 I i 2 I 1 ! 2 3 C01LED TUBING UNIT, BOP E0U ] PMEN~" 'NIRELINE BOP EOUIPHENT 1. 5000 PSi ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI' 41/16" STUFFING BOX 1. 5000 PSI ?" WELLHEAD CONNECTOR rLANOl 2. 5000 PSI WIRELIN£ RAI~IS (VARIABLE SIZE) 3. ~0O0 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orlr ARCO AI..ASK F'.O· BOX i ANCHORAGE, ALASKA 995i E) DATE: 'i2-5-89 REFERENCE: ARCO CASED HOLE FINALS i -26 i i -.t .5-89 F'II'~' '. RUN 2, t-29 t t-i 7-89 PITg RUN t, i-34 i i--i 7-89 F'II'~' RUN I, 5-2i t i-i 8-89 GR/CCL RUN t, -/-i 6 i i-i 6-.89 INJEC'TION F'ROFII. E RlJN i, 7-34 t t-i'.~....89 INJECTION PROFILE R~JN t, i i-~ i i-.i 9-89 PRODUCTION ~'ROF'ILE RUN i, tt-t8 ti-t8-89 TEHP RUN t, .ti-26 ti-t9-.89 INJECTION F'ROFILE RUN i, i2-22 ii-..i6-89 F'RODUC'FION PROFILE RUN t, i2-3i ii-.t7-89 INJECTION PROFILE/TEMF' RUN i, t4-2 it-t8--89 F'RODUCI'ION F'ROFILE RUN t, i 4-26 i i-.i 8-89 F'II'~ RuN t , t6-t6 tf-.t~-89 INJECTION F'ROFILE RUN t, i7-i4 it-2~-.89 PRODUCTION PROFII. E RUN i, i 8-8 i t z2~--89 PI'F$' RUN t, PI_EASE ,S'IGN RECEIVED HAVE A NI :~'AI. LY HOF:F.'ECKER"" ATO- i 529 AND REI'URN I'HE AI'TACHED COPY A;S' RECEIF'I' OF DATA, D I ~'TR I BUT I ON CENTRAL FILES . ~u~u~ D & H.';' ... EXTENSION. EXPLORATION EXX~N-~..,..' .... MOBIL F'HII_LIP$ F'B WELL FILES IR& D BF:'X $I'AI'E Of' ALASKA TEXACO 5;" 5" 5" 5" 5" 5" 5" 5' 5" 5" 5" 5" 5" 5' 5" 5" C;AHC:O C A M C 0 CAliCO CAMCO CAMCO CAHCO C A H C 0 · CAMCO CAHCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ARCO ALASKA, INC. P.O. BOX J8~S68 ANCHORAGE, ALASKA 99S t 8 DATE' t8-38-89 REFERENCE- ARCO CASED HOLE FINALS J -4 t (-)-t 3-89 J -6 J 8-2'2-89 ~-6. t 8-2~-8,o ~ -~ 6 ~ 8-~ 6-89 ~ -~ 7 ~ ~-~ 9-89 J -23 ~ ~-2~-89 t ~25 ~ ~-J 5-.89 ~ -2~ ~ 8-~ ~-2~ ~ 8-~ 4-8~ 2-5 ~ 8-~ 8-8~ 2-.~2 ~ 8.-~ 6-8~ ~_~- ~ ~5 ~8-25-89 4-J2 ~ ~-25-8~ ~7-~ ~ J 8-t 6-89 9-~6 tG-t t-89 ~ ~-~ 2 ~ 8-7-89 ~ 4-23 ~ 8-~ 4-89 ~ 6-~ ~ ~ 8-~ 3-89 ~ 6-2~ ~ 8-4-89 ~ 7-4 ~ 8-~ 4-89 ~8-~6 9-~ 8-89 PLEASE $'IGN PRODUCTION PROFILE CNL-GR F'DK-J eS/GR/CCL PRODUCTION F'ROFILE PERF RECORD CNL-GR PRODUCTION PROFILE PRODUCTION PROFILE F'RODUCTION PROFILE CNL TEMP SURVEY CNL-GR CNL-GR F'DK-:t 8 -8/GR/CCL PRODUCTION F'ROFILE PRODUCTION RROFILE INJECTION PROFILE PRODUCI'ION PF:OFILE TEMP COMPLETION RECORD LEAK DETECTION TEMP F'RODUCTION F'ROFILE PIT~ - RUN J, RUN J, RUN i, RUN J, RUN J, RUN ~, RUN 1, RUN J, RUN t, RUN 2, RUN t, RUN J, RUN t, RUN J, RUN t, RUN J, RUN t, RUN t, RUN J, RUN 1, RUN t, RUN t~ RUN t~ RUN t~ AND RETURN THE ATTACHED COF'Y AS RECEIPT OF' DATA. RECEIVED B.Y HAVE A NICE .DAY! SALLY HOFFECKER AT0-t529 ! 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 5' 5" 5" 2"&5" 5' , 5" 5" 5" CAMCO A ATLA.S' CAMCO Z,'Ci-I ATLA,? CAMCO L~.,MLO CAMCO ,~CH CAMCO ATLAS ATLA.? ATLAS CAMCO L~AMCO CAMCO CAMCO CAMCO $CH CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON . D'&M EXTENSION EXP&ORATION EXXON MARAI'HON MOBIL. PHILLIPS F'.B WELL F'iLE~' R & D, BF'X . .STATE OF' .ALASKA. TEXACO * filE CORRECTED AF'I~ FOR '~-"~ I~' 5{)'4)29-20766 · ..i m~..., · ** THE CORRECTED API~ FOR '***' THE CORRECTEI) AF'I~ FOR t6-t I$' 50-029-205J 6' ,\,.._./ Alaska Oil & Anchorage ARCO ALASKA, INC. F'.O. BOX i80360 ANCHORAGE, ALASKA 995 i ~ DATE' 2-i0-89 REFERENCE' ARCO CA£ED HOLE FINALS i - i 9 i -5-89 COLLAR/PERF RUN t -29 t -8-89 COLLAR/F'ERF Ir(UN 3-20 i 2-8-88 PDK/CNL OVERLAY RUN 3-22 i 2-8-88 PDK/CNI_ OVERLAY RUN ~;-27 i2-3i-88 PDK/CNL OVERLAY RUN ~-27 2-3-89 SPI NNER/TEMP RUNS 9-35 i 2-i 2-88 F'DK/CNL OVERLAY RUN ti-4 ti-27-88 PDI</CNL OVERLAY RUN ii-ii 2-3-89 LEAl< DETECTION RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. · GE-A{.~ HL~' A'CLAS ATLAS ATLA:=: OTIS A'i'L. A3' ATLAS 0 T I $ RECEIVED BY_ HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRAN$ ~89~ · AF'F'ROVED .... AlaS[;.= 01; & ~.~s Con:. Commission Anchorage · , DISTRIBUTION ~ CENTRAL FILE£ · ~ CHEVRON ,.. D&M EXTENSION EXPLORATION ~ EXXON MARATHON .~ MOBIL PHIl. LIPS PB WELL FILES R & D "' SAF'C STATE OF ALASKA TEXACO '. STATE OF ALASKA AI.A~KA OIL AND GAS CONSERVATION COMMI3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Alter casing Change approved program 2. Name of Operator 5. __ARCO Ala.~k~. Inc. 3. Address Suspend Operation shutdown Repair well Plugging P.O. BOX 100360 Anch, AK 99510 Pull tubing Type of Well: Development _x_ Exploratory Stratigraphic Service measured 9610 feet Plugs (meaf ~red) true vertical 9256 feet Variance 6. Re-enter suspended well Time extension Stimulate Perforate x Other Datum elevation (DF or KB) 70' RKP~ 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 1-P9 9. Permit number 86-105 10. APl number 50-029-21604 11. Field/Pool Prudhoe Bay Oil Pool. 4. Location of well at surface 1017'FNL, 1511'FWL, Sec. 8, T10N, R15E, UM At top ot proauct~ve interval 66'FNL, 2482'FWL, Sec. 8, T10N, R15E, UM Au eTTec,ve aep[n 83'FSL, 2532'FEL, Sec. 5, T10N, R15E, UM Au ~o~a~ aep~n 93'FS~. P513'Fr:~.. Sec. 5. T10N. R15F. UM 12. Present well condition summary: Total depth: feet Effective depth' measured 9663 feet Junk (measured) true vertical 9215 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' Surface 2480' Production 9579' 20" 10 sx Poleset 110' 110' 13-3/8" 2900 sx CS 11 2509' 2509" Top job w/150 sx CS 11 9-5/8" 670 sx Class G & 9606' 9253" 300 sx AS 1 Perforation depth: measured 9319'-9329', 9373'-9383' true vertical 9000'-9009', 9048'-9056' Tubing (size, grade, and measured depth) 4-1/2", L-80, tubing w/tail @ 8764' Packers and SSSV (type and measured depth) Baker SB-=3 @ 8650 & BAL-O SSSV @ 2190' RE'¢EiVED 13. Attachments: Description summary of proposal x DEC 2 7 '_.AJaska OJ!.& Gas.Cons. Commjssio~.. ""!.: ~chorage ' Detailed operations program BOP sketch x 14. Estimated date for commencing operation 13ecemher .~,t3. 1988 16. If proposal was verbally approved 15. Status of well classification as: Oil x Gas~ Suspended~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,. ~'~ ~ ~).,,e'. 5'~.~'~,,'~. Title Operations Engr. Manager FOR COBMISSION USE ONLY CONDITIONS OF APPROVAL: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Date I^pp,.ov., No. Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGIN.~L SIGNED BY I nNNIF C,. RMITH Commissioner Date &pproved Copy SUBMIT IN TRIPLICATE Retqrned ARCO Alaska, Inc. proposes to reperforate DS 1-29 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested at 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref: Schlumberger GR/BHCS, 6/8/86 Proposed Reperforation Intervals: 9373'-9383'MD RECEIYED DEC 2 7 Alaska Oil.& Gas Cons. .Commission ~' ~chorage 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE · 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 REE IVED DEC :2 7 ~.i~.~ ,Alaska Oil & Gas Cons. Commission Anchorage NIRELINE BOP EQUIPMENT ~I:~'C[! AI...I~..~'K/~: T Nr: ,. F'..n., ~f}~ ~ 99~0 I:~' F:' F' I:' R' F.: H .1:: F:': ~ R' ('; fi i'4 A f'; N I::: '1' T r;. T i.~ F' F:' .? b.I / I T .S' l' T N f. !;:! IH Fi'! li'4 4 I:i'111'4 I::;I lf'J '~, !:~'I IK! !:;.' ! lt, J ARCO AI.../~.,~I(A., T. NR.,, . ANP, HORAF.,E., AI..A..~KA 995~ (3 DAT~: 5-tG-BR RI IN ~ .. E'IIN i. {.~'lli'J -i . R'I I~.J i. !:?! !i,J -!. !-~'11b.J -~ !:;'1 IN .<~. i F:~ I.¥.!. I:,~ Ii I::' I I::' A.'"',' F' R' r F; J,J A H h I:;,' r. i:;.' I:: F': ,FF.. ]; V j.:." .9 .R Y 1.4 A ~.I E A N '.IT A'T'O-~ A P F'I:~'. ,f,) V ~,-. g F'.' f",' I::' Y A .',7 F.? 'IT: P. F 'r F"r Fl I::' r) A T A. {r' STATE OF ALASKA (' ALAg,,,-~ OIL AND GAS CONSERVATION COIV~...~SION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown ~ Alter Casing ~ Other [] 1. Operations performed: Stimulate [] Plugging r- Perforate .~. Pull tubing 2. Name of Operator ARCO A1 ~.-k~. ?hr. 3. Address P.O. Box 100360, Anchorage, AK. 99510 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, TION, RI5E, UM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, Rl5g, DM At effective depth 83' FSL, 2532' FEL, Sec. 5 T10N, RI5E, DM At total depth 93' FSL, 2513' PEL, Sec. 5, T10N, R15E, DM 11. Present well condition summary Total depth: measured 9610 feet true vertical 9256 feet 5. Datum elevation (DF or KB) 70t RI[R 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-29 8. Approval number 8-60 9. APl number 50-- 079-71604 10. Pool Plugs (measured) Feet Prudhoe Bay Oil Pool Effective depth: measured 9563 true vertical 9215 Casing Length Size Conductor 80 ' 20" Surface 2480' 13-3/8" Production 9579' 9-5/8" feet feet Junk (measured) Cemented Measured depth l0 shots Poleset Il0' 2500 + 400 sx CS II 2509' Top job w/150 sx CS II 670 sx C1 C & 9606' 300 sx AS I Rue Verticaldepth 110' 2509' 9253' Perforation depth: measured 9319-9329t; 9373-9383' true vertical 9000-9009'; 9048-9056' ' Tubing (size, grade and measured depth) 12.6# pct@ 8764' MD; 5%", 17#, L-80, pc tubing 4½", L-80, Packers and SSSV (type and measured depth) Baker SAB Packer @ 8650' & Bal-0 SSSV @ 2190' 12. Stimulation or cement squeeze summary Intervals treated (measured) At cached Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0m~.~issio~ 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water. Bbl Casing Pressure Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations [] 1900 1208 65 Tubing Pressure 418 2734 1744 263 369 Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10.404 Rev. 12-1-85 WELL S 2 / 53 Title Ooerations En?4n--.rtnf Man-gpr P. V. Lantero Submit in Duplicate DS 1-29 MUD ACID STIMULATION 2/24/88 MIRU pump trucks, N2 unit and transports. The following fluids were pumped fullbore: 500 gals 2% NI{zC1 water nitrified w/300 SCF/bbl N. 1000 gals 1~% H~I water nitrified w/300 SCF/bbl N9z 2000 gals 6% HCl-l.5% HF water nitrified w/300 SCP/bbl N2 2000 gals 2% NHAC1 water nitrified w/300 SCF/bbl N. 125 bbls dead ~rude water nitrified w/300 SCF/bblZN2 Returned well to production. WELLS2/53 ARCO AI._A,.~KA., T. NC,,. F'.,O, BOX tQSJ6Q. ANCHORAGE'.: AI._A,S'K A DATF..: F?F..".F'F..RF'.:NCF..: ARC.O F..;A,~ED I.-IOI...F..' F' 1' NAI.. 2-- ,..'2. 7- ~ 8 F'R.D 'i F'RF:'I....F../HF'F'M/WHI. IT RUN .'2-.'2(~-88 MI,~C., [,A,~-IN,JEC'I'ION F'RF! F.'!; RI. IN 5--i :.~--4-88 HF'FH/'I'F.-.EHF' ,S- i 8 2-6-88 cnL I.. AR., P .F. RFC1RAT ]1; ON RIJN ~ ..-~ ~.-. ,........ 88 P ]"1',~/I.;R/TE~F' RUN 2-~ ;'.~ ~.~--29-R8 [:OI...I..AR I...fll'.; RllN ?-...2.'..~ 2-i 9-...88 I N...I ,. F'RFI..,F./"FE~MF:'/FI,..OWMETEtR RI. IN "') ~3" ., . . ~:.-".,:. ? ;.T.--;~--SR .'[N,.I PI-'?FI...F.7/HF'FM/TF..NP RUN 4-26 '2-,'.). (-)- 88 F'RD ,. F'RF"I...E / F'I...F..)WME:TIE. R/WI-~U'T RI.IN ?'-t Z.~ 2-.,.'?4-88 COL [.. AR/F' .FI;:FORAT l ON RUN F'I..E;A,S'E ,S'IGN AND RF~Tt. IR.~.,,~T,?~I~'f~TAC.~COPY A,~.~.,F.'.~II::'T OF DA R .F': .C.I.-.-. :1: VF..D HAVE n N.T.C F'F.G£;Y RENNF.'. T'T ..~ ,;..9 AT (3.-. t '" '') I:;: ANA' ~.R~:.~ f A:3 ./. ~'j__ P F~,, .¢.l V El I) ......................... "'...~ .... Al::' . ................................................... .1). T ,~'T R' ]; BI, IT A .., (:AMC, F! CAMf':I'! CAMF.'.F1 ¢;FAR [: A M f; fi CAMf:f~ CAMC.O CAMCO .¢.;AMC.O F; F.'AF.' "" · 'l .... s Fm ~ (., E. N r R A I... F .11 I... I..., ,.~ ~-- 1.41 I,,. I,.. I F:' :.,"~ C. HF.-.VF~'ON F'R WF..I... I.. F:' T I 13 & M I;.'. & :~ E X'l' .F..:N,.~ T ON .F. xr-"I... ORAT T. ON :~ ,.~'A F' ~ · "~ E×XON ~.' ,S'I'ATF...'. OF AI...A,S'I<A HARATI..ION '~ · "' H 0 .R. I I · l~. .. ARCO AI..AXKA , ANCHORAF, E, AI..A.~K A 995 DATF: ~-4-BR REFERENCE: ARCO PRES~IIRE DATA ~2-7A 2-29-Bffi ~2-~3 2-29-BB ~2-~5 2-~4-~ffi 4-5 2-26-88 BHP-$TATIC GRADIENT BHP-$TATI~ CRAI)IENT BHP-FI_OWTNG GRADIENT BHP-$TATIC GRADTENT BHP-$TATIC GRADIENT ~HP-£TATIC GRADIENT CAMCO F'I.EA.~E XT. GN AND RETURN THE ATTACH.F.D COF'Y AE RECE.T.F'T OF DATA~ RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT ATO-t52~ Cons. Commissic~ TRANE ~88t~7 APPROVED DI2TRIBI, ITTAN CENTRAl... FIt...EE CHEVRON D & M EXTFN£I'ON EXPt..ORATION EXXON MARATHON MOBIl.. R & D SAPC STATE OF AI..A~KA , TEXACO ...... ARCO AI...A~KA: INC ~ I~'; P.,O., .BOX t00~60 ANCHORA.I..,E: al...A,~KA 9.95t 0 DATE: REFERENCE: ARCO CASED MOI..E F[NAII.. ~ 2-`) 0-88 FI...OWMF...TER/FI...iJT..D-T.D/HPFH RiiN `): 5" `) -~2 2-') 5-88 F'RD., F'RFL. E.../,~P.T.N/WHI. ll'/.DF..'N.~ RI. IN i . ..9" t-.~4 2-.~ 0-88 F'R D, F'l-i'. F I....F.. / H F:' F M / WHI.I'(' RUN i t~...'7' - ':.~ .5~.. ~...~- ~ ~- ~:~,..,... ,... ,., T E H F' .F; R A T I.I R'F/,~ F' .T. N NE R RI. IN HAVE A N I CE DAY A~ask~. Oi~ & Gas Con~, Commi$$ioT~ Anchorage F' E.: (.; [.; Y ~ENNETT ATO-- ~ ..929 TRAN,.~ ~88t ~S~ AF'PROVE)) ................. '.~ .................................. D T.,.~TR.? ~II. ITT F1N CAMCO I';AMF;FI ~P. 14 CENTRAl... F .T.I... E".,.~' [.'.HE'.. VR(]N l)& M EXTF..N,S' T ON EXP[..r. IRAT T (..'IN EXXON MARAI'HON ME)B.T.L. ARCO AI..A..~KA, INC,. (' P,O, ~ox see~6e ANCHORAGE.., ALASKA 995t e DATE: 2-4 B-SO REFERENCE: ARCO PRE$$1JRE DATA 2-4 ~)-88 5-7 4 5-4 2 4 46-46 2-2-88 ~ 6-~ 9 ~-28-88 t 6-2~ ~ -29-88 ' ~7-2 ~-3~-8R PWDW~-~ ~-~ t BHP-PRE$$URE BI.III...DI.IP ~HP-£TAT~ GRADIENT BHP-$TATIC GRADIENT ~HP-$TAT~ GRADIENT BHP-£TATIC GRADIENT BHP-FL. OWINC ~RAD~ENT BHP-F'I..OW[NG GRADIENT BHP-F[..OW~N~ GRADIENT BHP-$TAT~C G~AD[ENT PL. EASE SIGN AND RETURN THE'ATTACHED RECEIPT OF DATA, CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO RECEIVED BY HAVE A NICE DAY! PEGGY BENNETT ATO- 4 529 _~___~i~Oi TRAN2 ~88tt3 APPROVED DI$TRIBI.!TTON CF~NTRA[.. F I I...E$ CHEVRON ,, D&M EXTENSION EXPI.. ORAT.TON '"' EXXON MARATHON ~: MOB I I... '"' PHI I...I,...T. PS F'R. WELL F.TLE$ ~ SAPC ~~ STATE OF ~ TEXACO i~' STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION COMk~, 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 r~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Bo:< 100360, Anchorage, AK 99510 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, OM At top of productive interval 66' FNL, 2482' FWL, Sec. 8, T10N, R15E, UM At effective depth 83' FSL, 2532' FEL, Sec. 5 T10N, R15E, UM At total depth 93' FSL, 2513' FEL, Sec. 5, T10N, RlSE, UM Plugs (measured) 11. Present well condition summary Total depth: measured 9610 feet true vertical 9256 feet feet 5. Datum elevation (DF or KB) 70' I~B 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-29 8. Permit number 86-105 9. APl number 50-- 029-21604 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 9663 feet true vertical 9215 feet Casing Length Size Conductor 80' 20" Surface 2480' 13-3/8" Production · 9579' 9-5/8" Junk (measured) Cemented Measured depth 10 shots Poleset 110' '2500 + 400 sx CS II 2509' Top job w/150 sx CS II 670 sx C1 C & 9606' 300 sx AS I Wue Verticaldepth 110' 25.09' 9253' Perforation depth: measured 9319-9329'; 9373-9383' true vertical 9000-9009'; 9048-9056' Tubing (size, grade and measured depth) 4½", L-80, tbg w/tail @ 8764' Packers and SSSV (type and 'measured depth) Baker SAB Packer @ 9715' MD; Otis RQY SSSV @ 2184' MD 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 14. If proposal .was verbally approved February 1988 Name of aPprover Date approved 15. I hereb~ertify tha/~ the,foregoing is true and correct to the best of my knowledge Signedl/,X///~.~.~~//~/~.~...'"" Title Operations Engineering Manager Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. .~, Plug integrity ~ BOP Test ~ Location clearance I Approved Copy e~_turned Approved by Form 10-403 Rev 12-1-85 ORIGINAL SIGNED BY LONNIE C..SMITH WELLS2/53 P. V. Lantero Commissioner Date ~/~/~ ~ the commission Date Submit in triplicate Drill Site 1-29 Selective Stimulation Procedure I · Obtain a wellhead fluid sample from well 1-29 and perform emulsion and sludge tests with all stimulation fluids (tests should be performed with 7% HCI and 2.4% HF for the mud acid and 16% HCI for the hydrochloric acid). Add non- emulsifying and anti-sludging additives as necessary to ensure no downhole emulsions or sludges are formed. Send a copy of emulsion/ sludge tests to Paul Lantero at 263-4312. 2. MI and RU pump trucks, N2 unit, and transports. 3. Titrate acid and test for iron as follows: 15% HCL: 12%< HCI < 16%; Fe<300 ppm 6.5% HCI-1.5%HF: 5.5%<HC1<7%; 1.2%<HF<2.4%; Fe<300ppm NOTE: Additives should not be added to the acid system above 130°F to prevent precipitation of iron sequestering agents. Erythorbate additives should be added to the acid system just prior to pumping the acid (either at the warehouse or at location). 4. Roll all acid compartments before pumping fluids downhole. 5· Pump the following fluids fullbore: 1 NOTES: - All fluids except displacement crude and diverter carrier fluid should be filtered to 2 microns. A. B. D. I. 500 gals of 2% NH4Cl water nitrified with 300 SCF/BBL of N2 1000 gals of 15% HCl w/additives nitrified with 300 SCF/BBL of N2 2000 gals of 6% HC1-1.5% HF w/additives nitrified with 300 SCF/BBL of N2 2000 gals of 2% NH4CI water w/additives nitrified with 300 SCF/BBL of N2 170 bbl of dead crude nitrified with 300 SCF/BBL of N2 Return the well to production immediately and obtain a well test. If the well has difficulty in flowing by itself, the spent acid should be nitrogen lifted out of the wellbore. Volume of tubing/liner to top of perforations: Volume of tubing/liner to bottom of perforations: 174 177 bbls. bbls. ARCO Alaska, Inc. F'.O. Box i80368 . Anchorage, Alasl<a 995t DATE' Aucjus~ Si, i987 REFERENCE' ARCO Ca~e~ Ho~e F~;l'a ~ i -29 8--8-87 t -SC) 8-9-87 i '-'Si 8-'9-87 l-S2 8--i 8-87 t "-3S 8--9-87 S-'9 8--1 6-87 S-f2 8-8-87 3-. t 8 8-6-8'7 S..-. 2'? 8-i 6-87 3:....30 8-i (')-87 4-3 8--i 6-.8 4..-.6 '7/St '-'8/ 4'"'2'7 8""6'"'87 4-32 8- i 6-8 5'-"2 8/i .... 21 ?.-2S 8'-' t 2-8 9 .... i 8 .... i'7....8 9 .-- :'5 8-- t S ..- 8 9.-8 8--'7'--- 8"? 9 .... f 8 8'-7-87 9-3f '?-. ::~9-87 t '2.---20 8.-5--.'8'7 7 i/87 .? 87 '7 '7 ..?. Prod. F'rofi le Pr'od. Pr'ofi le Prod. F'¥'ofi le F'rod, F'rofi [e F'rod, F:'rofi Le Temp. Log In j, I::'rofi le In.j. F'rofi le Prod. Profi Le 6R/Temp/Prod. F:' r' o f i l e $ ii r' v e y Prod, F:'rofi le Leak I)e't~/'¥'emp/Flowmeter In j, l.':'rofi Le/Temp,/F'Lommeter F'rocl~ F'rofi le Lea k De'l'/Temp, L.og F I. owme f er X-.Y Ca I. i pe¥' F'rod, F'rofi le In.j, Profi Le/Temp,/l::'Lowmet'er In j, Pr'ofi Le/Temp,/FLowmet'er F'rod, F:'¥' o f i L e Inj, F'rofi le F:' !. e a s e .,.~ i g n a ¥1 d ¥' e T u r n ~ h e a 't i' a c h ecl c o p y a .s' HAVE A N CE: DAY! //-" R c):~' a n n e I~e i< ~~ 0'- ( AT 0 .... 5 ..... & eons. Conm ss 0,. Al.) I.)! .oved ............................ .L~ .......................................................... '.;N Run t, 5" Run t, 5" Run t, Run Run t, 5" Ru.l"it, 5" Run 1, 5" Run t , 5" Run i, 5" Run t, 5" ~un i, 2" R~n Run t, 5" R~n t, 2" R~n Run R~n t, 5" Run t , 5" Run !, 5" ¥'ec: e i p 't o 'f c! a 't a, & 5" & 5" C a m c o Camco Ca mc o Ca f~lC 0 Ca mc o C a m c o C a mc o Ca mc o C 8 m c: o Ca mc o C a m c o Camco C a m c o Camco C a m.C o C a ~ o Camco C a mc o Camco ?" , ~'~'.~ 0 · ,. C e n 't l- a l I:-" i l e s' · ,,.'"' C h e v r o n I) & M · ,."" ii'-' x 't' e r, ~; i o n Ii!: x p I. o r a i' i o n '"'... E x x 0 n Fi a r a 'i' h o n · "'.,,. M o b i I. ,il, · ,- l::'h i { lip .'.:,' I::'IF.', W e I. I. F:' i I. e .s' R ~., I) .Il. '~ 'i' · ,' ,.~] C h I 0 ""... ,.~ 't a 't e o t" A I.. a s' k a · ~'"'')" 69 × ~.~ C 0 ARCO A[a.ska, Inc~ P · O~ B'~'x' t 8'8~6(~ ,."' Anchorage, Ata~ka 9~ DATE' A~guz~ 3t, t987 REFERENCE: AR.CO ,.Pressure O. ai'a i-29 8--i7-87 $'~a~ic Gradiel'~ Camco t-30 8-i7-87 Sfafic Gradienf Camco t-.3i 8-t7-87 St'a~ic Gradie~ Camco L~-7 8-t 9-87 Memory F'r es.s/Temp, (I:'~ F-, 0, ) F-J--,~ch 3-27 8-i7--87 Flowing Gradien~ Camco 3-3e m-~ e-87 F low J ng Grad i eh1' Camco 4-t 8-t 6-87 Flowing Gradient Camco 4-3 8-.I &-87 F low il3g Grad i en~ Camco ?'-i 8-..i 3-87 I::' low ing Grad i e~n~ Camco da t' a ,, C e ~'i 't r a I. I::' i l e.s' '"' i::' · .- hi I. l ip.~ C h e v r o n P B. W.o [ !. F' i !. e ~' .il. · .. I) & M .". · .. I:;'. & I) I'-']..,,' .1: e n .s i o n .... I::' x p I. o r a i' i o n '"'.,. $ o h i (::. ,11, · ,- IE x x o n ..,,...... ' ....~;.' .I.. a "t' e o 'f" A I. a s' I,'. a H a r a '[' h o n ....". 'l"e x ,'..~ c o · ,.'"' M o !-) i l ALA '/~ OIL AND GAS CONSERVATION' ~,'OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL IX GAS ['-I SUSPENDED 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1017' FNL, 1511' FWL, Sec. 8, T10N, R15E, UM At Top Producing Interval 66' FNL, 2/+82' FWL, Sec. 8, T10N, R15E, UM At Total Depth 93' FSL, 2513' FEL, Sec. 5, T10N, R15E, UM ABANDONED [] SERVICE [] 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 70' I ADL 28329 ALK 2327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 05/28/86 06/09/86 05/1/+/87* 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 9610'ND, 9256'TVD 9563'MD, 9215'TVD YES ~] NO [] 2190' feet MD 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP, LDT/CNL/GR/Cal, Gyro, CBL/CCL/GR ' ' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SlZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE 20" 91.5# H-40 Surf 110' 30" 13-3/8" 68.0/72.0# ' K-55/L-80 Surf 2509' 17-1/2" 9-5/8" /+7.0# L-80 Surf 9606' 12-1/M' 7. Permit Number 86-105 8. APl Number 50- 029-21604 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 1-29 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 031 Pool 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL 1 21. Thickness of Permafrost 1900' (approx) CEMENTING RECORD AMOUNT PULLED 10 shots Poleset 2500 sx CS III & /+00 sx CS II Top job performed w/150 sx CS II 670 sx Class G & 300 sx AS I 24. Perforationsopento Production(MD+TVD of Topand Bottom and interval, sizeand number) 9319'-9329'ND w//+ spf 9373'-9383'ND w/2 spf 9000'-9009'TVD ? 90/+7'-9056'TVD' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 8764 ' 8650' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production ' 5/1/+/87 Date of Test 5/20/87 Flow Tubing Press. 391 28. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) F1 owi ng Hours Tested PRODUCTION FOR 01L-BBL GAS-MCF WATER-BBL 8.1 TEST PERIOD I~ 690 38/+ 0 Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL N/A 24-HOUR RATE ~P 20/+3 1138 0 CORE DATA I CHOKE SIZE. I GAS-OIL RATIO I 557 ' OIL GRAVITY-APl (corr) N/A Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. None *Note: Drilled RR 6/10/86. Form 10407 Rev. 7-1-80 TubJ ng run 1/10/87. Perforated we11 5/1/+/87. CONTINUED ON REVERSE S~D~C3/19:DANI JUL o ? ]g87 Oil & G~s Cons. ~ommission Anchor~e Submit in duplicate/ 29. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS include interval tested, pressure data, alt fluids recovered and gravity, GOR,and time of each phase. Top Sadlerochit 8929' 8659' GOC 9162' 8862' HOT 9416' 9085' OWC 9456' 9120' N/A 3~[. LIST OF ATTACHMENTS Perforati on Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 DS 1-29 PERFORATION SUMMARY Commenced perforation operations 5/14/87. Pressure tested lubricator to 3500 psi. RIH w/gun #1 and shot the following intervals: 9373'-9383' (w/2 spf) 9319'-9329' (w/4 spf) Shut-in well, POOH; all shots fired. RD and secured well. GRU1/77 7/1/87 July 8, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60035 Well: DS 1-29 Field: Prudhoe Bay Alaska Survey Date: June 13, 1986 Operator: E. Sellers Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co. and Exxon as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry. SunlNL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 Nasl~ 011 & Gas Cons. Commission Anchorage ARCO ALASKA, INC. DS 1-29(SEC08 TION R15E) PRUDHOE BAY ALASKA SPERRY-SUN_WELL-.SURVE¥ING. OOMPANY_._ ANCHORAGE ALASKA VERTICAL SECTION CALCULATED ALONG CI_OSURE COMPUTATION.DATE_ JUNE 16, 1986 ................................... PAGE 1 DATE OF SURVEY dUNE 13, 1986 .... BOSS.GYROSCORIC..SLEiVE¥ ........ dOB NUMBER AK-BO-60035 KELLY BUSHING ELEV. = 70.00 FT. OPERATOR=E. SELI FR~ ............ TRUE :3UB _-SEA COURSE MEASLiRED VERTICAL VERTICAL INCLINATION DEPTH DEF'TH DEPTH BEG M I N 0 0.00 :[00 100.00 200 200.00 300 299.99 400 399.99 500 499.99 600 599.99 700 699.99 800 799.99 900 899.98 1000 999.98 1100 1099.98 1200 1199.98 1300 1299.98 1400 1399.98 1500 1499.98 1600 1599.98 1700 1699.98 1800 1799.98 1900 1899.98 2000 1999.97 2100 2099.97 2200 2199.97 2300 2299.97 2400 2399.97 2500 2499.~7 2600 2599,97 2700 269~.97 2800 2799.96 2900 2899.96 [:OURSE DIRECTION DEGREES -70. O0 30. O0 130. O0 229.99 329.99 429.99 529.99 629.99 729.99 829.98 92'2.98 1029.98 1129.98 1229.98 1329.98 1429. 1529. 1A'-,o 9~ 1729.9 1829 9.9~ rn (i.r~24 1 ....- .-..-6 2329.97 2429 97 2529.97 2629.97 2729.96 2829.96 D. OGcLEO SEVERITY DEG/IO0 · . TOTAL_ RECTANGULAR COORDIN~'~' ...... VERTICAL NORTH/SOUTH EAST/WEST SECT I ON 0 0 N O. 0 E 0.00 0 27 S 6:4.69 E O. 45 0 .24 S 68..30 E . . 0.!3 0 18 S 46.10 E 0.17 0 19 S 60.69 E 0.08 0 21 ~' o 68.10 E 0.06 0 12 S 46. 0 E 0.18 0 17 S 70.69 E 0.13 0 20 S 53.89 E 0.11 0 25 S 61.50 E 0.10 0 8 S 77.10 E 0.28 0 11 ._N ~_._~9 E ....... 0.2~:_.._ . 0 3 N 27.60 E 0.15 0 11 S 43.69 E 0.23 0 1.7_._ .... 0 13 0 14 0 !~ 0 11 0 13 0 2! 0 28 0 31 O .4! 0.00 0. O0 0 04 S 0 '-'~ . ..:,~ E 0.20 :S ........... !....!__1_ .. E 0.51 S 1.62 E 0.83 S 2.05 E 1.08 S 2.58 E 1.32 S 2.99 E 1.53 S 3.36 E 1.~79 S 3.84 E 2.14 S 4.40 E 2.35 S 4.85 E 1.98 S 5.05 E . ~" m 2 06 ._q 5 1.'-7 E O. O0 0.27 O, 70 0.87 O. 99 1.22 1.37 1.51 1.6:-]' 1.88 2.08 2.29 2.47 2.52 S 38.10 E 0.21 2.55 S 15.60 W 0.21 2.91 S 22.10 E 0.17 3.33 o 6.50 W 0.20 3.89 S 12.19 E 0.13 4.58 S S_...4. 7_. !_O...'E. ..... 0_..~4 ............ 5. ! 0 S S 69.50 E 0.20 ) 5.32 S N 86.10 E 0.16 5.33 S N 82.10 'E .................. O. 16 .5, .3.1 ~ S 45. 0 W 0.28 5.42 S S 9.30 W 0.14 5.74 S . . I~ ............ 6. e. ~ '-~s~j. . ~ S 1 10 F.._ ...... O. !3 '~=' '-' S 17.89 W 0.18 6.94 S 'S 1.69 E O. 1'-'.:. 7.80 S -'::: .!4, !0 E 0.2! ..... o._84 $ .. 5:.27 E 5.34 E 5.41 E _~.44 E 5.49 E 5.53 E 5.80 E 6.08 E 6.39 E 6,68 E 6.64 E 6.48 E /-.-_., 4 ~ E 6.33 E 6.22 E 6, .3.8 E 2.31 2.13 ... !:87 1.54 1.11 0,, 96 . .. 1.03 1.25 1.49 I. 38 1.05 O, 70 0.15 -0.50 -1,07 ARCO ALASKA, INC. DS 1-29(SEC08 TION R15E) ........ PRUDHOE BAY ALASKA SPERRY,SUN WELL SURVEYINO._COMPANY ................................................ PAGE. ANCHORAGE ALASKA DATE OF SURVEY JUNE 13, 1:"]86 ......... COMPL!TATION. r_!~.TE .......................... BOSS _GYR.[~[~.' ~-I~....~l IRVFY_ JUNE 16~ 1:-]86 JOB NUMBER AK-BO-b0035 KELLY BUSHING ELEV. = 70.00 FT. VERTICAL SECTION CALCUL-~TE'~['ALONG 'c:EosuR~ ................................................... OPF_,~]].JlF~_-_E ..... SSi[L! FR::~ TRUE SUB-SEA MEA::;URED VERT I C:AL VERT I CAL ]EF'TH DEF'TH DEPTH .. C.'_O_L.!R~_E ............ .L-_:.C.!_U_R_'~._E ........... P.C_Q-L_E.G_ ............................ T_CJ !AL_ ................. INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES V~'T-~CAL DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 3000 2999.95 3100 3099.94 3200 3199.94 3300 3299.93 3400 3399.92 3500 3499.~2 3600 3599.91 3700 3699.~1 3800 3799.90 3900 3899.90 4000 3999.89 4100 4099.89 4200 4199.89 4300 4299.88 4400 4399.87 4500 4499.86 4600 4599.86 4700 4699.85 4800 4799.84 4900 4899.83 5000 4999,79 5100 5099.70 52O0 5199.36 5300 5298.34 5400 5396.28 5500 5492.77 5600 5587.21 5700 5679.77 5800 5771.64 5900 5863.37 292:"]~-95 0 '45. ' 8' IO'A~0 ............. E 0~0:3 .............. ~'0';'07--8- .................. ................ · ;'C)'~¢, 94 0 36 "'-; 1': 50 E O. 15 11 22. S J. 6 90 E -'?' 26 ._1. ~..~. . . .i- m 'q129 94 0 45 '-] 14.8:9 E O. 16 12 37 S 7.19 E ..... : ................................................................................................ - .................................................................. ?.:_2._.. ~! 3229.93 3329.92 3429.92 3529.91 3629.91 3729.90 . . 3829.90 3929.89 4029.89 4129.89 4229.88 4329.87 4429.86 4529.86 4629.85 4729.84 4829.83 4929,79 5029.70 5129.36 5228.34 5326.28 5422.77 5517.21 5609.77 5701.64 579~.37 0 37 0 . 37 . _.0 ._.4_! _ 0 28 0 27 0 31 0 30 0 35 0 31 __ 0 34 0 44 . C) __.4.7... 0 41 0 43 0 _ .33 .... 0 22 I '75 ....... 1 ...... 46 _._ .s_-: 0 6 15 .... 10. _0 13 15 17 7 ,$1_. 11 23 1= 23 17 · -., .~ ~...~ :2:7 S 29.60 E 0.23 13.48 S 7.63 E _o~..21 S 43.60 E 0.15 14.34 S 8.27 E -3.31 S 36, _! 9_ E ............ O, 1.1 .............. 1 ~,._22_ ~ ................ 9,._00 E ........ -'3 · 34 S 6. 0 W 0.46 16.12 S 9.31 E -:q.71 S 2.69 W 0.03 16.94 S 9.25 E -4.29 _._S . .!.2., .!_..9..._._E ............ ().,..!_5 ................ !.7._: 7_.9_ ...~ ............ '~_.._.'3.'2 .E ............ _-._4,.~0 . S 13.80 E 0.03 18.68 S 9.53 E -5.23 · ~3.80 E 0.13 19.62 S 9.67 E -5.75 $ ! !_:6.0_~.H ........_c]:.!_..6. ......... ~(..).,.~?_._.~ ............... ?.,_ _6_!_..E. ........... ..-....6,.4..4. S 1. 0 W 0.11 21.54 8 9.51 E -7.14 · '2. 9 W 0.29 9.25 E S 2' I 22.64 S ' -'=' 06 S 27.8'"] W o.09 23 :-]4 S 8.69 E ............ .._ .......................... -_. ..... .. ........................ m_. __.. ...................................................... S 44.80 W 0.24 24.88 S 7.94 E S 46.89 W 0.04 25.74 S 7.06 E $ 6,_3_(!__W_ ................. _O.,.....4._Z ............. 26_,_6.4_..gi ........... i..6_,_.55 _E.. S 0.30 W 0.19 27.44 S 6.49 E S 86.80 E 1.45 27.84 S 7.73 E _ N..8~,._67.. E ................. _Ct,_~Z ................... 2Z-. ~_0_.. ~ ........... 10., ~2 _E ....... N 79.30 E 1.30 N 65.69 E 3.41 N. 54,50 E ........ A.04 N 49. 0 E 3.43 N 45.69 E 3.96 N 42.69 .E ~.19. . N 40.19 E 2.27 N 3:"]. 89 E 0.12 N 3'2.69. E O. 35 27.40 S 14.65 E 24.67 S 22.20 E 17.38.S.. 34.24_.E 4~82 S 49.97 E 12.99 N 6~.16 E .36..56. N .... 91,96 E . 64.92 N 116.95 E 95.16 N 142.37 E 125.75.N .. 167.86 E... -10.53 -11.76 ....... ,1.2, Z4 -13.31 -12.65 ....... ,1D.60 -7.17 0.30 14.15 34.25 60.42 .. 93.11 130.62 169.70 209.05 ARCO ALASKA, INC. DS 1-29(SEC08 TION R15E.) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEY. lNG_ C:.OMSANY ............. ANCHORAGE ALASKA .. VERTICAL SECTION CALCLILATED ALONG CLOSURE COMPUTATION DATE dUNE 16, 1986 ............................... .PAGE 3 DATE OF SURVEY dUNE 13, 1986 .BOSS_OYROSCOPI¢.SUR~E¥ ...... dOB NUMBER AK-BO-60035 KELLY BUSHING ELEV. = 70.00 FT. OPERATOR~E ..... $~LLER~ ......... ]'RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL INCLINATION DEF'TH DEF'TH DEPTH DEG MIN 6000 5955.00 5885.00 6100 6046.64 5976.64 6200 6138.29 6068.29 6300 6230.01 6160.01 6400 6321.79 6251.79 6500 6413.58 6343.58 6600 6505.47 6435.47 6700 6597.52 6527.52 6800 6689.70 6619,70 6900 6782.06 6712.06 7000 6874.54 6804.54 7100 6966.99 68~6,~9 7200 7059.45 6989.45 7300 7151.94 7081.94 7400 7244.62 7174.62 7500 7337.68 7267.68 7600 7431.01 7361.01 7700 7524.59 745.4.59 7800 7618.34 7548.34 7~00 7712.04 7642.04 8000 7805.51 7735,51 8100 7899.29 7829.29 8200 7993.73 7923.73 8300 8088.09 8018.09 8400 8181.83 8111.83 8500 8274.7~ 8204.79 :~600 ~"~ ..... _ ,.c.~,.72 8296.72 8700 8457.42 8387~42 8800 8546.59 8476.59 8900 8633.98 8563.~8 COURSE.. DOG=LEG TOTAL ................................. DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 23 35 N 39.30 E 0.16 156.65 N 1.93.33 E 248.60 23 36 N 39.10 E 0.08 187.67 N 218.63 E 288.10 .23 .. .34. N_. :38, ~ .E ........ 0,08 .21.8,7.6 N ......... .2..43,.~1 ....E . 3~7, 56 23 23 N 39.39 E 0.27 249.66 N 268.96 E 366.87 23 23 N 39.89 E ' 0.20 280.23 N 294.30 E 406.10 2~ 2! N 3~.__60 E ......... 0,13 .... 3!0,74 _N. .31.9.68 .E . 445.32 23 6 N 39.30 E 0.2:9 341.20 N 344.74 E 484.27 22 53 N 5:9.10 E 0.21 371.4.8 N 369.43 E 522.82 22 ...43 . . _N :.~9...,.3_0__...E ........ O,__'_2Q ......... ..4_.Q1_..5~...._N_ ........ ~.'P.3,~4_ E .5.6._1__,08 22 21 N 39.50 E 0.37 431.14 N 418.27 E 598.'-'-' 22 21 N 3~.50. E 0.00 460.50 N 442.46 E 636.50 22 . _.27 ...N~ ~_ .. 6._9.__ _E .............. 0,1.3 ....... ~8.._9. ~7 ..N ......4_/:_:..6.,.76 .E_ ..... 674_. 16 22 19 N 40.80 E 0.44 518.95 N 491.:38 E 711.86 22 21 N 41.19 E 0.15 547.64 N 516.32 E 749.55 21 44 N 42.19 E 0.72 575.67 N 541.29 E 7¢.~ ~'- ........................................................................................................................................ 21 13 N 42.50 E 0.52 602.74 N 565.96.E 823.24 20 51 N 42. 0 E 0.42 62~.31N 590.10 E 858.93 .20. ~5 ....... ~_._~2~6~.~ ............... ~_,_~7 .............. ~,.~?._N .......... 6!.3,82.E .... 89~,97 20 18 N 43. 0 E 0.18' 680.93 N 637.47 E 928.60 20 34' N 42.69 E 0.28 706.53 N 661.22 E 963.35 ~! ...... 3 ..... N_.~2,6~..E ............ ~,4~ .........7~2,6.7.~ ......... 6.85,30. E ....... ~8,70 19 33 N 42.89 E 1.50. 758.15 N 708.86 E 1033.23 18 47 N 43.89 E 0.84 782.02 N 731.42 E 1065.94 19 52_._ N..46,30 E.._~ .......~=.1,84 8¢~,37.~ ..... 754.87 E ~098,98 20 53 N 49.60 E 1.54 828.66 N 780.74 E 1133.78 22 20 N 52 '*' '- ~,o E 1.76 851.84 N 809.~5 E 1170.._7 · 2~ .... ~8 _._N_~..~@_E--,--, 2~02 ...... 8Z~..~_..N ............ 84!,09 .................. E .1209.72 25 48 N 58.30 E 2.22 898.04 N 876.32 E 1251.35 27 57 N 60.80 E 2,43 920.91 N 915.31 E 1295.71 30. 10 .... N..6~..~O_.E ........ 2,3~ ..... ~4~..03.N ......... ?~8.02..E 1343,.02 ARCO ALASKA, INC:. DS 1-29 ( SECO:_=.. T 10N RI_~E.). ........... PRUDHOE BAY ALASKA VERTICAL. ::;ECTION CALCLILA~TEKi ALONG cLosuRE ............. ~,FERRY-~UN1 WELL. SIU,gVEYING._~._OMPANY ............................................. PAGE ANCHORAGE ALASKA DATE OF SURVEY JUNE 13, 1986 .C_OMPL!TA.T. ION [~E ............. BO~_.~Y~OSF:OP~. ~LIRV~. JUNE 16~ 1986 JOB NUMBER AK-BO-60035 KELLY BUSHING ELEV. = 70.00 FT. ............................... OP~AT~R~_E. .... SELLERS ....... 'I"RUE SUB-SEA COURSE.. ........L.-:._O_UR_ _S.'_E .............. P _Q__G_' _-_I___E G ............... TOTAL MEASI_IRED VERTICAL'" vIBR~'~CAL INCLINATION DIRECTION SEVERITY RECTANGULAR cooRDINATES DEPTH DEPTH '~, 9O00 8720.74 9100 8807.89 ~200 88~5.30 ~300 8983.07 9400 ~071.09 9500 ~159.29 9600 9247.61 ~610 9256.44 DEPTH DEG MIN DEGREES DEG/IO0 NORTH/SOUTH EAST/WEST vERTICAL SECT I ON 8650.74 29 -~8 ' 'N 6'i.80"-"E '- 0~-'~ .......... 9~7'.34 N ............ i~'~i]~'"'~ .............. ~"~-,37 8737.89 29 15 N 61.1~ E 0.37 ~90.74 N 1045.05 E 1439.16 '-"~'-'= :30 28 ~2 N 60.50 E 0.50 1014.40 N 1087,47 E 14:B6.~ ':'~. ................................................................................................................................................................ 8913.07 28 23 N .60.30 E 0.50 1038.07 N 1129.14 E 1533.51 ~001.09 28 16 N 60.1~ E 0.13 1061.62 N 1170.34 E 1579.~8 ~08~.29 27 58 N.60,3~_E ........ 0,81 ...... i~84.,~.7_.N .... ]21.1,~8 E. 16~6,12 9177.61 27 58 N 60.3~ E 0.00 1108.14 N 1252.06 E 1672.01 ~186.44 27 58 'N 60.3~ E 0.00 1110.45 N 1256.14 E 1676.60 HORIZONTAL DISPLACEMENT = 1676.6°. FEET A'T NoRTH"48"DE(}: -'-3i'-' MIN... EAST-AT. ~lD"--= ....... ~6'10 .................... THE CALCLILATION PROCEDURES ARE BASED ON _THE. U$_E' OF' TH_...R_E..E .D!.M._EI~.!ONA_~...R. AQ!_g!.S__OF_~U. RV_A_TL_!BE ._METH.OD.. ARCO ALASKA, INC. DS 1-29(SEC08 TION R15E) ._ PRUDHOE BAY ALASKA 9PERRY-gUN WELL .S ~URVEYI_NG COMPANY. ANCHORAGE ALASKA .... COMPUT~IT I ON .DAIE .......... JUNE 16, 1986 DATE OF :SURVEY ,.IUNE 13, 1986 JOB NUMBER AK-BO-60035 KELLY BUSHING ELEV. = 70.00 FT. _.. OPERAT~R~E .... SELI FRS .......... MEASURED '~'~DEF'TH INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA VERT I CAL VERT I CAL DEPTH DEPTH TOTAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL · NORTH/SOUTH _ EAST/WEST DIFFERENCE . __.C.'QRREC.T.I_O..N. .... 0 0.00 -70.00 1000 99~.~8 929.98 2000 1~99.97 1929.97 3000 2~9~.~5 2929.95 4000 3~99.89 3929.89 5000 49~9.79 492~.79 6000 5955.00 5885.00 7000 6874.54 6804.54 8000 7805.51 7735.51 ~000 8720.74 8650.74 9610 9256.44 9186.44 0.00 0.00 0.00 2.~5 S 4.85 E 0.02 5.10 S 5.80 E 0.03 10.07 S 6.65 E 0.05 19.62 ~ 9.67 E 0.11 27.90 S 10.52 E 0.21 156.65 N 193.33 E 45.00 460.50 N 442.46 E 125.46 732.67 N 685.30 E 194.49 967.34 N 1001.95 E 279.26 1110.45 N 1256.14 E 353.56 0.02 0.01 0.02 0.06 0.10 44.79 80.46 69.03 84.77 THE C:AL.C:L~LAI'ION F'ROCEDLIRES ARE BASED ON THE L. oE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA, INC. DS 1-29(SEC08 TION R15E). PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYINO COMPANY ANCHORAGE ALASKA . _ COMPU.TAT_I ON_DATE ..... dUNE 16, 1'286 PAGE. &, DATE OF SURVEY JUNE 13, 1986 dOB NUMBER AK-BO-60035 KELLY BUSHING ELEV. = 70.00 FT. ..... OPERATDR~E.._ SELLEES ............ ~EASURED ""'DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 'I"RUE SUB'SEA TOTAL ............ VERT I CAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOL. ITH EAST/W.EST _E.!!.FFERENCE . VERTICAL _C'_ :OR_RE'. C_: T ! ..ON ..... 0 70 17£) 270 370 470 570 670 770 870 970 1070 1170 1270 1370 1470 1570 16,70 1770 0. O0 -70. O0 O. O0 O. O0 70.00 o. oo o,0! s _ ..0., !.6 .E ...... 170.00 100.00 0.12 S 0.91 E ";' ') m ~..7~..00 200.00 0.40 S 1 51 E :370. O0 300. O0 O. 75. S !. 9 ! . .E. 470.00 400.00 1.01 S 2.41 E 570.00 500.00 1...-5 S :Z.91 E ,, · -.. .-- .":m .--.~ 670.00 /_-,00 00 1 48 F; :_-:.~-~ E 770.00 700.00 1.69 S 3.70 E 870. O0 8£)0.00 2.04 S 4.21 E 970 (')0 900 ¢')0 2 :'~ ...... o $ .. 4.,_78 E'. 1070.00 100¢'). O0 2. :31 S 4.99 E 1176),00 1100,00 2,01 S 5,03 E 1270.00 1200 O0 1. cY':~ S 5 12 ..E_ ....... ii . -.; .. ...... ~_ ..... 1370. AA 1:'::00. O0 2.23 S 5.29 E 1470.00 1400.00 2.4~ S 5.27 E 15'70. r,) 1500. O0 .. 2.7~_-'~ ..... .5_.._.4_._4.... E 1 ./-..70.00 1600. O0 3.20 S 5.39 E 1770. F,') 1700. O0 :"-:. 69 S 5.52 E 0.00 ..... 0..00 ........ 0.00 0.01 0.00 0..0~ ...... o..oo.. 0.01 0.00 0.01 0.00 0,~! .- ........ 0,00 0.01 0.00 0.01 0.00 0.02 0.00 .......... 0.._.. 0_0 ....................... O. O0 0.02 0.00 0.02 0.00 0.02 0.00 .... 0,0~ ...................... 0..00._ 0.02 0.00 0.02 0.00 ARCO ALASKA, INC. DS 1-29(SEC08 TiON R15E) . . PRUDHOE BAY ALASKA SPERRY-SUN. WELL ~c;URVEYIN~ O.O~JP~NY ...............................................................PA_GE '.7 ANCHORAOE ALASKA DATE OF SURVEY dLINE 13, 1¥o6 ..COMPUTATION.DATE_ JLINE 16, 1986 dOB NUMBER AK-BO-60035- KELLY BUSHING ELEV. = 70.00 FT. _. OPERATORr£ .... SELLER~ ...... INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH -~,.~ 1EASI_IRED · DEPTH ]'RUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH .... EAST/WEST D!FFER~NCE__ COR~~N... 1870 1970 2070 2170 2270 2370 2470 2570 2670 2770 2870 2970 3070 3170 3270 3370 3470 3570 3670 1870.00 1~70.00 2070.00 2:170.00 2270. O0 2370.00 2470.00 2570.00 2670.00 2770.00 2870.00 2970.00 3070.00 3:170.00 3270.00 3370.00 3470.00 3570.00 3670.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 4.37 S 5.48 E 0.02 0.00 5, O0 S 5, 68...E ..... O, 03 ..... 0_._..00 ............ 5.30 S 6.0:3 E 0.03 0.00 5.34 S 6.26 E 0.03 0.00 5.32 S 6.64 E .. 0,.0.3 ....... 0,00. .... 5.35 c, ~ 6.71 E 0.03 0.00 5.62 S 6.50 E 0.03 0.00 6.06 S 6.45 E O. Q3 ........... 0.._.00 ............... 6.71 S 6.41 E 0.03 0.00 7.52 S 6.21 E 0.04 0.00 8.49 $ ___ $_,_~. E .......... O_,_.Q4_ ............ O, 00... ............ 9.68 S 6.58 E 0.05 0.01 10.92 S 6.82 E 0.06 0.01 ! !, ,c<'.._9 .S.' ............... 7__. _O.._9._.._E:._ ............. _c.),.O~_ ...................... 0..,_0__1 13.20 S 7.47 E 0.07 0.01 14.11 S 8.04 E 0.08 0.01 1_4. ~73...$ ........... 8...Z8_. E ............... 0,0.8 ....... ~).01 ...... 1=~,.87 S 9.33 E 0.09 0.01 16.70 S :9.26 E 0.09 0.00 ARCO ALASKA, INC. DS 1-29(SEC08 TION RI~E) ........ PRUDHOE BAY ALASKA SPERRY-SUN WELL_SURVEYING_..CD~RANY ............................................ PABE. @ ANCHORAGE ALASKA DATE OF SURVEY dUNE 13, .... ~OMPU~TION.__ ~A~E .................................................................. JUNE 16, 1986 JOB NUMBER AK-BO-60035 'KELLY BUSHING ELEV. = .......................... OPEBATORcE~...~ELLERS 1986 70.00 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~EASURED '~"'"DEPTH TRUE VERT I CAL DEF"rH SUB-SEA VERTICAL DEPTH TOTAL ........................................................................ RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH./.~OUTH .... E..AST/WE$.T.. [!!FFE_R._E'.N_E:E ...... CO~.E'_E_._C_..TI_O_N_ ................... 3770 3870 3970 4070 4170 4270 4370 4470 4570 4670 4770 4870 4970 5070 5170 5271 5373 5476 5581 3770.00 3870.00 3970.00 4070.00 4170.00 4270.00 4370.00 4470.00 4570.00 4670.00 4770.00 4870.00 4970.00 5070.00 5170.00 5270.00 5370.00 5470.00 5570.00 3700.00 3800.00 ... 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 . . 4500.00 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 17.52 S .9.27 E 0.10 0.00 ..... .!. ~.: 4'_2_._.~: ................ ?, .4_~_..g ................ 0.._ _l.(~ ........................ _0_ :.__0_0. ..................................... 19.32 S .9.65 E 0.10 0.00 20.32 S .9.66 E 0.11 0.01 2 !.._, ~.4 .S ....... ~, 5_1__. _ _E_E .............. _0._,,.. 1_ 1._ ......................... .O_,OQ .................................... 22.28~.,'-' 9.40. E 0.12 0.00 23.48 S 8.88 E 0.13 0.01 24.63 .~ 8.19 E 0.14 ....................................................... ................ ~ ..................................................................... 0.01 .... 25.48 S 7.33 E 0.14 0.01 26.36 S 6.58 E 0.15 0.00 .27, 25 $ ..... t:.":, _4__.9._...E:_ ........ O, ._!6_. ........... ~,_g. 1 ................................. 27.79 S 6.9.9 E 0.16 0.01 27..90 S .9.5.9 E O. 20 O. 04 · ..2_7_. _6. ?_.._S. ............ _i.~,_._I_.~_._E ........................... O._~Z ............................ __0._.07 ........................................... 25.82 S 19.50 E 0.50 0.23 20.02 S 30.38 E 1.27 0.78 ....... _8.,.6 7_____S_ ............... 45_ ,__~4.'3._. E_ ....................... ~_....Q_5 .............................. 1 ,.78 ........................ '=' 27 N 64.27 E 6 24 3 18 ~,,,~ m , m 31.78 N 87.51 E 11.5.9 5.35 ARCO ALASKA, INC. DS 1-2.9(SEC08 TION R15E.I ..... PRUDHOE BAY ALASKA SPERRY-SUN_WELL.SURVEYING _COMPANY ANCHORAGE ALASKA .._COMPUTATION_DATE ............... JUNE 16, 1986 ............................. PAGE DATE OF SURVEY JUNE 13, 1.986 joB'NUM~£R--~KL~260035 -" KELLY BUSHING ELEV. = 70.00 FT. .OPER~IOR=E..SELLER~ ...... MEASURED '""'"'DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH · . TRLIE VERTICAL DEF'TH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST ..DIFFERENCE VERT I CAL CORRECT ! ON .. 568.9 57.98 5.907 6016 6125 6234 6343 6452 6561 6670 6778 6886 7103 7211 731.9 7427 7534 7641 5670.00 5770.00 5870.00 5970.00 6070.00 6170.00 6270.00 6370.00 6470.00 6570.00 6670.00 6770.00 6870.00 6~70.00 7070.00 7170.00 7270.00 7370.00 7470.00 5600.00 61.71 5700.00 ~4~62 5800.00 127..98 5~00.00 161.72 6000.00 1.95.5~ 6100.00 22.9.53 6200.00 263.02 6300.00 2.96.24 6400.00 32.9.4.9 6500.00 362.46 6600.00 3~5.14 . . 6700.00 427.31 6800.00 45~.05 6.900.00 4.90.83 7000.00 522.23 7100.00 553.23 7200.00 583.1~ 7300.00 612.00 7400.00 640.34 N 114.24 E 1';".36 N .... 1..4.! ......9~. E 2_'8,._2! .......... N 169.71 E 37.23 N 1.97.48 E 46.36 N . 225: 07_.E ' 55, 48 . N 252.50 E 64.59 N 27.9..95' E 73.57 N 307.67 E 82.53 N 335.15 E .91.44 N 362.10 E 100.12 N_ _. 388.71 E __ !0_8:64 _ N 415.11 E 116..96 N 441 28 E 125 0.9 8 1° . · . N .... _4_6Z_. 5.6._ E ........... _1.:~:~. ~5 ........... ~,,. ! ? .... N 4.94 21 E 141 41 8 1= . . . N 521.21 E 149.53 8.12 N 574.45 E 164.68 N 600.04 E 171.72 7.78 _. 8,..6.'~ ....... 9.02 9.13 9,!2 .9.11 8..97 8..96 _ . . 8..91 8.68 8..5..~ ..... 7.79 7.36 7.05 ARCO ALASKA, INC. DS 1-29(SEC08 TION R1.SE.} PRUDHOE BAY ALASKA I'~_. ii ~1 · =,PERRY-SUN WELL SL!RVEY.ING .COMP. ANY ...... ANCHORAGE ALASKA ¢OMPUTAT.ION..DATE. dUNE 16, 1986. DATE OF SURVEY dUNE 13, KELLY BUSHING ELEV. = ... OPERATOF/-_E.._ __SELl FRS ........ .. PAGE 10 1986 70. O0 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASURED VERT I CAL VERT I C:AL ~-q]EPTH DEPTH DEPTH ..... TOTAL ...................................................................... RECTANGULAR COORDINATES MD-TVD VERTICAL NOeTH/SOLITH_. . EAST/~,/EEiT. r-!I FFERENCE COR~ECT. I_ON .......... 7748 7570.00 7500.00 667.82 N 76:55 7670.00 7600, O0 .~:,94, 95 N. 7961 777(.'). O0 7700. O0 722.60 N 80/:,8 7870. O0 7800. O0 750.53 N 8174 7970. O0 7900. O0 77~. 20 .N.. 8280 8070.00 O000. O0 800.85 N 8387 8170. O0 8100. O0 825.74 N 8494 0270.00 8200. O0 . _ .8~0, 6.~. _N_ 8603 8370. O0 :~.~,0o. O0 875.86 N 871.=,'" 8470. O0 8400.00 901.24 N 8826 8570.00 8500~ O0 . _ ~26_._~8..N 8941 8~.70.00 8600. O0 ~53.76 N 'P056 8770.00 8700. O0 o,~,~ov. 52 N 'F/171 8870. O0 8800, O0 1007...~..._N_ _ ~o._, o ~7(.). ¢)¢) 8900. ¢)0 1034.57 N 9:398 9070.00 9000. O0 1061.33 N. 9512 9170. O0 9100, O0 1_08~,_78. N 9610 9256.44 f/186.44 1110. 45 N 625.27 E 178.45 6.73 650.~ E __. 105,_10 ......... 6,65 ............. 676.04 E 191.95 6.84 701.77 E 198.92 6.98 725,82 E 204_..~3 ........... ~.01 ...... 750.14 E 210.76 5.83 777.30 E 217.34 6.57 ~@Z. 7~...E .............. 22~,.~2 .................. 7.~ ....................................... 842.29 E 233.59 8.77 881.50 E 243.98 10.39 ....... 726..1~.E .............. 2~6._~0 ......................... 12,.52 ................ 976.54 E 271.65 15.15 1026.44 E 286.57 14.92 .... 107~._~ E .............. 301...1..1 .................... 1.~.._54 ....... 1123.01E '315.15 14.04 11~9.83 E 328.76 13.61 1.21.6~23.._E ........... 3_42,1~ ................ 13,37 ...... 1256.14 E 353.56 11.43' THE IZ:ALCUI_ATION PROCEDURES USE ~ LINEARi.I.NTE~OL~T_ION_BEINF,,E~ ........................................... THE NEAREST 20 FOOT ~[I (FRO~ RADIUS OF CURVATURE) POINTS ARCO ALASKA, INC. DS 1-29(SEC08 TION R15E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYII~].COMPANY. ............ PAGE.'ll ANCHORAGE ALASKA DATE OF SURVEY dUNE 13, 1986 .C:OMPUTATION. DA~E ................................................................. dUNE 16, 1986 dOB NUMBER AK-BO-60035 KELLY BUSHING ELEV. = 70.00 FT. .............. OPERATOR~E..E;EIIFRR __ MEASURED '~-~DEPTH INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS I'RUE VERTICAL DEPTH :,UB-._,EA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH . E~ST/WEST MARKER A12 8848 9156 9162 ~215 9416 9428 9456 ~=''~ 9610 8557.1~ 8588.99 8659.05 8856.77 8862.02 8908.43 9085.18 9(}95.75 ~120.43 9159.29 9214.93 $~256.44 8487.19 8518.~9 8589.05 8786.77 87~2.02 8838.43 9015.18 9025.75 9050.43 9089.29 9144.93 9186.44 923.66 N 931.89 N 950.81N 1003.93 N 1005.36 N 1017.97 N 1093.78 E 1065.~~ ._.~ N 1176.92 E 1068,21 N . ._118!,.85 E 1074.78 N 1193.34 E 1084.97 N 1211.28 E !099,56 N. . ~236,~7_E. 1110.45 N 1256.14 E 920.22 E TOP SAG RIVER ~34,~5 E._ TOP SHUBLIK ...... 970.92 E TOP SADLEROCHIT 1068.98 E TOP ZONE 3 . !o7!.5o~E ... GAS/OIL CONTACT TOP ZONE 2 HOT ._.ZONE ~B ..... ...... OIL/WATER CONTACT SURVEY DEPTH PL. UGBACK ~D TOTAL DEPTH DRILLER ARCO ALASKA, INC. DS 1-29(SEC08 T10N R15E) ..................... STRATI GRAPHiC_SUMMARY DERIVED USING DIL DEPTHS AND SPERRY SUN oil RVEY DATA .MARKER .......... MEASURED DEPTH TVD BKB BKB SUB-SEA ....................... EnnRnTNATE$.. THICKNE~ WITH REF. TO WELLHEAD VERTICAL (ORIGIN-IO1TFNL 1~ ._,llFWL) ............................... ~._~8 TION .... ~!~.. TOP SAG RIVER TOP SHUBLIK TOP SADLEROCHIT TOP ZONE 3 OAS/OIL CONI'ACT TOP ZONE 2 HOT ZONE lB OIL/WATER CONI'ACT 8812 8848 ._. 8:929 '.9156 91/_-,2 .. '.9215 7416 ~ 'P428 ~ F'LLIOBACK I"D '-?~" '-' TOTAL DEPI"H DRILLER 9610 ,'3557 19 ,_~487.19 923.66N 920.22E 8588,_ ;-,? ... 8518. ~ .................................. ~ !_.~. 8~M ..... ~4, 95E 8659.05 ~.,8 .~. 05 950.81N 970.92E 8856.77 8786.77 1003.93N 1068. t98E 8862.02 8792.02 1005. :=:AN 1 A71 5AE ........................................................................................................ ~.~ ............... ~ - -. ~ _ ~ _.. 8908.43 8838.43 1017.97N 1093.78E 9085.18 9015.18 1065.38N 1176. 9095,.~5 __.~025,75 .......... .~0~8,2!.~._ !!~!,85E 9120.43 9050.43 1074.78N 119:3.34E 9214.93 9144.93 i 099.56N 1236.97E 1> FROM LINEAR EXTRAPOLATInN BELOW DEEPEST"S~iATioN: ................................ ' .............. i .................................................................... 2) COMPI_ITER F'ROGRAM - SPERRY SLIN THREE DIMENSIONAL RADIUS OF CURVATURE. DAI'A CALC:UI_ATInN AND INTERPOLATION._BY .R_A._D.I.I_I~. !__q_F__ _CU_R__V.A__T.L]_R.E ..................................................................... COMPUTATION ['ATE ........... ._IUNE 16., 1986 .D. ATE._O_F_._S_%ISVEY JUNE .... 1...3__: ..... 1.~.86 ......... ,_lOB NUMBER AK-BO-600:35 KELI.Y BUSHING EL._E._V .... = 70, O0.F_T ............ 56ql..6 -'.- i. "f..1~£'1 "78 500. O0 / 500. 0 P.fdOhOE 8g'I qFiC..l~ ':::It q3Kq. L',S ;,-..29',5E[708 7'"ON BLSE~ ..IdNF: .:$. 1.986 qK -BO .60035 -50~.00 ~]. 000, ~JO ' "'"'~ ,,/... '¢ -5 O '3. 00 , ,A/',.~//- · O0 ~ 50,3. CO tOO0. CO 9610 FEB o 6 1987 Alashs Oil & Gas Cons. commission Ancboraejo 0.00 2000. C qRco .:IL RSKR. .IJNE :3. :988 2000.00 4000.00 t:', O0 O. O0 8000.00 RECEIYED '~;.~. ,~ ................. ~ 9S 1 F'E~3 o 6 1987 , o ~'..;,;. ,; :;,r ....................................... ~ ,., ,-; ,.; .' ;;,; Alasb Oil & Gas Co~. Commission ARCO A[azka, Inc. F'.O. Box t003&8 Anchorage, Alaska DATE: May 29, t987 REFERENCE: ARCO F'rezzure Da1:a t -29 .5-t 6-87 3-5 5-t 8-87 5:1: m 1: lc BHP .:'7..[ i.s' 9-t 3 5-t 8-87 t2-t2 5-t7-87 t 6-24 4..-30--87 Pr es.z~ir e F'l. eas'e .s-ign and ret:urn the a1:1:ached ¢::opy a.~ receipt: of da1:a, Received By ............................................. H AVF A NICE DAY! ~o~~~~ Ro.~a nne Peek '"?' .... Jt I'F(ANS ~87278 ~ alaska Oil & Gas Cons. Commiss'i~n Ap p roved .............................................................. ~..~ Anchor;~T9 DISTRIBUTION Cen1:l"a L F'i Les .,. F:'h i L L il.':,..'; C h e v r o n F' ~.: [.,~ ,:.:.' ~ ' '"~ I) & M '"' R & I) '11' , '"' Soh i o Ex'ten.s'ion Exptora1:ion ,,. ..-'"' Exxon ~ ~'t:a't'e Of · "' T e x a c o H a r a 1: h o n ... '"' Mob i t ALaska A~CO Alaska, Inc( Prudhoe Bay ,-'ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager May 8, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 1-29 Permit Number: 86-105 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/MRO:sd Enclosure cc: Standard Alaska Production Co. File P1(DSl-29)W1-3 RECEIVED · [VLAY '- 8 .Alaska 0il & Gas Cons. C0mmJssJon Anchorage, ARCO Alaska, inc. is a Subsidiary ol AtlanticRichlleldCompany STATE OF ALASKA ALASi(' OIL AND GAS CONSERVATION COMi{ SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend :. Operation Shutdown r- Re-enter suspended well '-; Alter casing m T,me extension "~ Change approved program '~ Plugging '- Stimulate- Pull tubing- Amend order- Perforate j~ Other 3. Ntdmaa P.O. Box 1003~0 Anchorsge~ AK 99510-0360 4. I.O~ltJOfl Of will at lUrflCl 1017' FNL,1511' niL, Sec. At top of praductive interval 66' FNL, 2482' ~L, Sec. 8, TION, R15r, Uld At effective depth 83' FSL, 2532' FEL, Sec. 5, TION, R15E, UH At tOtal ~pth 93' IrSL, 2513' FEL, Sec. 5, T10N, R15E, UM 11. Present will condition summary Total depth: measured true vertical 9610 'HD 9256 ' 1'VD Effective depth: meuumd 9563 'HD true vertical 9215 'TVD 5. Datum ellvation (DF or KB) RKB 70' 6. Unit or Property name Prudhoe Bey Unit 7. Well number 1-29 8. Permit number 86-105 g. APl numl~r 50-- n~-~l r.n~ 10. I=~ol Prudhee Bey 0tl Pool feet Plugs (measured) feet None feet Junk (measured) feet None Felt Caetng Length Size Comluetor 80 ' 20" Surface 2480' 1 Product1 on 9579' 9-5/8" I~rfomtion depth: measured .. 9 319 ' -9 32 9 ' true vertical 9000'-900~°' Cement~l 10 shots Poleset 2500 sx CS II & 400 sx CS II Top Job w/1SO sx CS II 6~0 sx Class G & 300 sx AS I , 9373'-9383' , 9048'-9056' Measured depth 1lO*MD 2509 'MD 'l~ue VlrtlCII depth 110'TVt) 2509'TVD 9606 'MD 9253 ' TVD Tubing (size, grade and millumd depth) 4-1/2", L-60, tbg w/tell e 8764' Peckerl and SSSV (type and measured depth) SB"3 pkr (I 8650' & Bel-O SSSV ~ 2190' 12.Attachments Description summary of proposal Alaska Oil & Gas Cons. Commissior Anchc:'a~e Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation May 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,~certify that,t~e fojegoing is true and correct to the best of my knowledge Operations Engineering Manager Commission Use Only Conditions of approval N~otify commission so representative may witness I Approval No. .., Plug integrity - BOP Test ~ Location clearancel - Commissioner Approved by Form 10-403 Rev 12-1-85 Date by order of the commission Date ARCO Alaska, Inc. proposed to perforate DS 1-29 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. 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. Ref' BHCS 6/8/86 Proposed Perforation Intervals' 9319'-9329'MD 9373'-9383'MD 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 W I REL I NE BOP EQU I PMENT . . SlOOeZlOO6 REV.[ i~ STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION COMI~.i &ION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] Other [~ COMPLETE 1. Operations performed: 2. Name of O~)erator ARCO A~l~ska· I nc. 3. Address P.0. Box 100360 Anchorage· AK 99510-0360 4. Location of well at surface 1017~ FNL·1511~ FWL~ Sec. 8~ T10N· R15E~ UN At top of productive interval 66' ENL· 2~82' FWL~ Sec. 8~ T10N~ R15E· UN At effective depth 83' FSL~ 2532' FEL~ Sec. 5~ T10N, R15E· UM At total depth 93' FSL· 2513' FEL· Sec. 5· TION· R15E, UM feet Plugs (measured) 96107MD feet 9256 ~ TVD 9563 'MD feet Junk (measured) 92157TVD feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Perforate [] Pull tubing 5. Datum elevation (DF or KB) RKB 70 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-29 8. Approval number 9. APl number 50-- o29-~1 10. Pool Prudhoe Bay 0il Pool N o ne None Casing Length Conductor 807 Surface 29807 Size 2077 13-3/8" Production 9579~ 9-5/8" Cemented 10 shots Poleset 2500 sx CS II & 400 sx CS II Top job w/150 sx CS II 670 sx Ciass G & 300 sx AS I Measured depth 1lO'ND 25097 ND True Vertical depth 1107~'VD 2509 ~ TVD 96067ND 9253~TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) ~-1/2"· L-80~ tbg w/tail ~ 8764~ Packers and SSSV (type and measured depth) SB-3 pkr ~ 86507 & Bal-0 SSSV ~ 2190~ 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Representative Daily Average Production or In[action Data OiI.Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments ( Comp1 eti on We11 Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run X~ that the foregoing is true and correct to the best of my knowledge ~-- 15. I hereby certify ~vRn Form 10-404 Rev. 12-1-85 Title Associate Engineer (DANI) SW0/166 Date )%.'~"~ Submit in Duplicate ~,,,:~, ~.,~~.~? ~ ,.,, .,. ,c ~,., ...... ~ . ' '~'"'," "::~ ' ;.? '''~' ...... ' ~RCO Oil and Gas Company~ Daily W , flisto~-Final Re~d In.t~gtlon.: Prepare and submit the "FInM Repo~" on the fi~i Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Rep=~" should be submitte~ also when operations am suspended for an indefinite or appreciable length of time, On workove~ when an official test is not required upon completion, mpo~ completion and representative test data in blocks provided. The "Final Repo~" form may be used for reposing the entire operation if space is available. Accounting cost center code District County or Perish Alaska North Slope Borough Field Lease or Unit Prudhoe Bay ADL 1128329 Auth. or W.O. no, Title AS0847 Completion State Alaska IWell no. 1-29 WWS #l AP1 50-029-21604 Operator A.R.Co. W.I. 'Total number of wells (active or inactive) on this, cost center prior to plugging and . I A~CO Alaska, Inc. 21.66% abandonment of this well Spudded or W.O, begun Date Hour I Prior status if a W.O. I Complete 1/08/87 0130 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m, 1/08/87 1/09/87 1/10/87 9-5/8" @ 9606' Accept rii @ 0130 hfs, 1/8/87. ND tree, NU BOP;-. 9-5/8" @ 9606' 9530' WLMPBTD, RIH w/4%" tbg Pull tbg hgr, cst BOPE. Tst 9-5/8" csg to 3000 psi; OK. Schl, make GR/JB rn, RD $chl. RIH w/4½" tbg. RU 9-5/8" @ 9606' 9530' WLMPBTD, RR Displ well w/diesel. Set pkr. Tst tbs to 2500 psi, ann to 2000 psi; OK. ND BOPE, NU & tst tree to 5000 psi. RR @ 0100 hrsa 1/10/87. (SSSV @ 2190', SB-3 Pkr @ 8650', Shear out Sub @ 8764'. Rn 270 its, ~", 12.6#, L-80 BTCABMod tbS) Old TD Released rig 0100 Hrs. Classifications (o11, gas, etc.) Oil Producing method Flowing Potential test data Well no. Date New TD Date Reservoir Producing Interval FEB N~l~ Oil & Gas Co~. Com~ss't0a PB Depth Kind of rig 1/10/87 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Sadlerochit OII or gas Test time Production OII on test Gas per day Pump size, 8PM X length Choke size T,P. C.P. Water GOR Gravity Allowable corrected Effective date The above ia correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and a7. IDate 1/30/87 Title Drilling Supervisor ARCO Alaska, Inc. P.O. Box t003&0 Anchorage, A~taska 99~t0 DATE: Aucj uzt 26, t986 REFERENCE: ARCO Cased HoLe Final t-29 6-t3-86 ACB Log VDL/$Ifl/GR Rur~ t, 5" 3-33 6-9-B6 F'DK-tO0 Run ~, 5" 6-4 6-t 5-86 PI)K-tO0 R~n t, 5" 6-9 6-26-86 PDK-~ Run ~, 5" 9-~4 6-~t-86 Gamma Ray Log Run t, 5" 9-35 6-8-86 PDK-t~O Run t, 5" ii-.J6 6-i5-86 ACB L.o~ VDL/~IN/GE Run i, 5" t6-2~ 6-t 3-86 PDK-t~8 Run t, 5' i6-2Q 6-25-86 DIFF ')'emp. Log Run t, 5' P Lease Rece i ved HAVE A Linda HuLce AT0-t529 TRAN$ t86532 Dress Dress Dress Dress Dress Dress Dress DI$1'RIBUI'ION Central Fi [es Chevron E:'xtens' ion I.'_!]xp Lorat ion Exxon Marathon Nob i L · '.,Phi [Lips F'B WeLL F'i Les R&D ~'-... $ohio ~ State of ALaska .a.... T e x a C 0 ARCO ALaska, Inc F' 0 ].o× 400360 Anchorage, ALm~ka 99.5.'i 0 DATE: ,Jul. y 2 4,4986 REFERENCE' ARCO Directional Data ~ 'l :78 .... ':':--"~"-"-86, ,..., MW][) D irec 'J i ona I. Te I. eco ~ 'i --29 6-'i 7-86 HWD 1) i rec'l' i ona [ l'e [eco ~t--3e '?-.t.-86 MWI) I)irec~'ionaL l'eLeco '"'t.-~ '7--22-86 HWD D i rec't i ona [ l'e I. eco ~ ~ .... i~4 7-9-..86 HWI) Ilirec~ional. l'eLeco t ~-.-4 ? 6--t 8--86 HWD Direct iona[ Te I. eco -~'1 ~ -48 '?-4 ..-86 HWI) I) i rec 't i ohm I. l'e I. eco ' ~-24 7-7-.86 HW1D Directional l'el. eco ~48-5 5.-.2~-..86 HWI) Directional. Te I. eco F'l. ea.~;e .s'ign and ret~Jtrn the a'J"Eac:hed copy a.s' receip'l' of clmta, Received By .................................................. HAYE A NICE DAY! I...inda Hulce' A'T'O- ~ 529 , 'T'RAN$ :,",'.8645"? D I $ 'l' R I B LJ T I C) N F:'hi I. Lip J; '"' F:'B We I.I. F: i I.e..s I:;: & l) · "' 3' o h i o l'exaco .~ ~" 8 8 1986¢ Aljdm 011 & Gas Gon~. Gomml~aion ~;'ELEEDI Teleco Oilfield 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 ss of Alaska Inc. June 17, 1986 JOB # 501TAK WELL: DS 1-29 PRUDHOE BAY 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 RECEIVED JUL 2 8 1986 Alaska Oil & Gas Cons. Commission Anchorage A SJJNAT COMPANY TELECO OILFIELD SERVICES JOB 501 SURVEY CALCULATIONS **************************************** Date 05/31/86 Page 1 Company: ARCO Well= DS 1-29 Location= PRUDHOE BAY Rig: PARKER 141 TELECO Job # 501 TAK Grid Correction: Magnetic Declination: Total Correction-. 'Proposed Direction: 0.00 degrees 31.25 degrees 31.25 degrees 50.70 degrees. N 50 42 E MINIMUM CURVATURE CALCULATION **************************************** MEAS DIRECTION TRUE VERTICAL cooRDINATES CLOSURE DOG LEG DEPTH 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 ' **************************************************************************************************** SINGLE SHOT 4984.00 2.4 88.6 N 88 36 E 4983.94 5.91 4.26N TELECO 5168.00 6.9 61.5 N 61 30 E 5167.30 19.81 9.63N 5356.00 13.9 Ss .00 0.s 46.8 N 46 48 E 47.3 N 47 18 E 5905.00 23.7 38.0 N 38 00 E 5865.85 243.72 169.26N 6251.00 23.5 38.3 N 38 18 E 6182.91 378.93 278.19N 4.15E 5.94 N 44.251E 0.000 2.656 17.72E 20.17 N 61.479E 5352.13 53.48 30.50N 44.14E 53.66 N 55.353E 3.953 5521.12 105.69 66.11N 82.46E 105.69 N 51.278E 3.730 176.41E 244.48 N 46.185E 261.98E 382.13 N 43.281E 1.272 0.068 TELECO Job # 501 TAK 05/31/86 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH 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' ***************************************************************************************************** 6720.00 22.7 36.9 N 36 54 E 6614.30 558.14 423.95N 374.27E 565.52 N 41.439E 0.207 7030.00 22.3 38.3 N 38 18 E 6900.71 673.68 517.94N 446.64E 683.92 N 40.773E 0.216 7341.00 21.8 40.4 N 40 24 E 7188.96 788.13 608.22N 7655.00 21.0 520.64E 800.62 N 40.564E 41.3 N 41 18 E 7481.31 901.00 694.89N 595.56E 915.19 N 40.598E 8030.00 19.8 41.1 N 41 06 E 7832~79 1029.92 793.24N 681.66E 1045.90 N 40.674E 0.321 0.300 0.275 8273.00 20.0 .45.4 N 45 24 E 8061.29 1111.89 853.43N 738.31E 1128.48 N 40.863E 0.608 8586.00 24.2 53.4 N 53 24 E 8351.30 1229.34 929.32N 827.99E 1244.67 N 41.700E 1.648 ., (.. TELECO O i 1F i el d Smrv i cms VERT I CAL PROJECT ION P-"'f' ..... ~ .......... ~--Si ..... S7' ' ....................... ~ ............ ~--I ......... ; ..................... ~-I-~'~' '-I - I ~ / ' t L ~ ~ -.L--~-.~ ........4 ......... ~---~ ....... l--~'--- ...... ~ .............. 1'- -- ' ~ ~ ~ ~ ! T -- ..... ~ ........ k../ ~..~Z~ ..... I .......... r.--,-- .17-"~7"t"-E' ..... ~ ] ~ n~ '..-~ , ~=~ ~'L ~ ~L_- ~ ! ...... ~~~-~.q-~ .......... 4---~ .... . ~' - ~-, ' ._..e~ ~ l~ ~.-~ ............. ~-.-'-- -~, t-t~ ..... ~ -~ .... ~ ~~,~_~:. ._:., _..~-.!- ~ ~,, , , ~-~- _ ........................... ~_.., 5500 ~ ~~; ~ ~ · ~ . [ J._. ~, , _J ........ ~ ..... ~ ......... ~ ................ _~.~:-~.-j ........ ~- , ~ ~...J,~...~,.~ ........ ~--"t - I ! ....... I ' i ' '~t_L ~l !-; ..... I ...... ' .......... ~ ........ --~ .......... ~h~~;~',~__~_ ~ :: .... ~ q .............. ~. ...... ~-~ ~ I ! I',, I ! , I I / J_ ~~-.L .................. r ....4 ...... · - ~ ~ ~ --~ ,L~~"'~--~ .........~---~"'4 .......... ' ........ ~ ...... F''~ .4--::1~---~ ..... ~~. ~ ...... + t' t . Y ,' ...... ~ .... i--P,.¢-, I !--~ ....... I' ........ I .... V'. -.~-.-.!..-~-~~~-~~: .... ~ . r .... F ..... -'7-~'~ I..~--~. x, ~ =~ ~ I~ ~., 1'-~ ' ~ --T ~' -~ ~ '~ ~ - I ~--'~'-' ~ ~ + ..... i ...... ~"- - ~'~ ...... ~---]~-', I -"~- ~_~ / i ~ ~ ....... m-~- ~ ~ i di ~ ~ ,~.~ ......... ~ ~- -~ .................... ~ .~...i..-.4.-. ~ ....... ~-~%~ .... !-..~-! I ~ ~-'-~~ ...... ~"i-I '~ .... I-'T'~'",- ~ ' ~ i ' i ] I ~ I~ ~ ~ '--' ...... ~.~ .... l ................ :~ ......... 4., , ~ . . ~', ~ ~ I : I l~' ~ ..... ~--"---~--i-" ......... .... ~ ..................... ,. ?,--.~ , --e .... ~ ...... . , , ~ , , . , ~ , ~ ~ , , l,, ~ ~. ~ ,_.., ..... ~ .... ~_.~ ......... ............. , ......... ~. _.- .-, .... . , , ~ ~V~ .~ ~ , ~ , >, ~,~~ r,-.r-~ , ,~ ~ ...... ~~...- ~.~.~--.~ ...... 4-.t ~ ~-,--~.~~--t~--~'T"T ........ S"-~'-! i iii; t , : ; ,~ ~- _~ ....... ,,. ........ ~._ ~ ....... ~-. _.._._.~_..L ...... ~..~ .... .--~--- -~ ........ , -- , ~, · , '. ', ~ '.'_i._' ................ ~ ---4 .... , ...... , ............ ~'~'', % ; ' ' 3 ~ ' . ' , , ,, , ~ , · ~ I ............... ~ ........... .... I ............ ~ .......... ..- , ,., , ...... , , . ~ ,, , : I ~ i I i I ' ~ : ', ~ ' ~ ~ , L,, ;.,, ~ !~.t..= ........... ,__.~ ..... ..... ,44...q ..... .... ...... , ....... l-.~ r"'~T"~'--~ ....... , ..... r'-~ .-'~r~ U : ..... '~ ' ! , ~l-4--i ...... ~ ....... 4-.-~---.; ..... ~--- ~ i--~ .... ~..-4--~ .... ~ ........ e--r"'$-~--~-l- ,-Ti ~_~....: ..... ! ......M .... ~--'~ ' ~ .......... ' .......... . . h. I , , ! , , ~ ~. : ~ ~ ,, __. .... =_, .... L ........ SL---k¢ ............. == --'f-FF'-,~~ ..~ ~r ~. VERTICAL SECTION (,-. TELECQ O i 1 ~ t ~ 1 d Smrv i cms PL^N VIEW EAST -1"-~- i -~..~ ..... L_.,_.L._~~ ~. T~L . i ~ ~.~ J ~ ~- i Ii [~L~ ~ .". -' ....... ' ..... ~- -~ ...... ~--t ............. ~ ....... ~.¢..-~-~ .... J__.~_~ .... ~ , ~__ l! / i _ / --k-~..~ . ,--, ! .... ~-& .... 1.--~-.~ , ~---~.-L.] I ~ ' ~ t / I ~ t ' ! ~ ' ~-, ~ _ _.L~_.. I._ .... ~ .... ~.. , . ,zl ,, . , .- ,~ ---P .............. , ' ~ ~ I ' , t ~ ' ! --~. ~%.--.~ -.~-.t__~.=._ l- ~ ~ ~ , , , . ~ ~, t ~ , . ~ ~ , ~oo ,', ~ ,,',, I~ ,,~!1 ,/ ,:., ..... ~ -'~ , -- ,-'~- .~ '---., ..... 1- I.~ ...... - , -,.--~ ' ~ 2 .... ' Lu ~ ' I [ I , ,' ; i'. ~-~'~"-:, , ...... f~'~ ......... ' I t I .--~ ....... , , ...... ~---~-~-.~.- ~i--'~-~-~%-ff--.~--~-~--F-~ ..... L4.~_ :! .... 1-~ .... k~ .... ! ..... ~..1-.-~._ ' .~.~ ! ! ~ I ' ! I ! I , I ' ·" II ~-', !~-t"-~ .... ?~--~- !. ~.~-,--~-~-.~--!--- .... ~...~-.~- ' ! ' , . ~ I ! ' I ~ ~ ~ I I --' i - ~ - 2z~o ' ~ ' i , . , , ~ ~ , ~, /!, . i .~ ~ I ~.L.L '.~ % l! ! ~~. !~ ~ , ' ~ i ~ ~ i I ~! "T~--F ..... %'I-'1 ~1 ~----~"-h--~?'- ...... 4' ~..-' ' ~ I ~ ~ --~~J ' ~ I ~ " ' -- ~ ~ '~-- ' ' ! ~ ' ~ I ~ U I I ' i- , ~~.-4~-~~-.-t.-. ~ ~'- ' ~'--~-----~~-~ ' !--~ ..... ]--.~ ...... - ii ; '. ' ' I I ' i ~ ~ ~ "i ' ~ ! ~ , / , 7, eoo, ! I ~ ~ · ~ ', ; ~-~, ..... ~.~ ....... ~._~4 ..... , _t . ~ , ,~ , ~ ~-~, .... ~.~.~.-.&.e,.. ..... ~..~ -. ? ' '- I--~'--"~-~"i- L-.t.-- '~ , , ~ H , , ,,~ ,, , , ,'-~ ..... ~-", ..... ~..~~- ... ~ ' ~- i ~ , ~- I ' , ~ ~ I , , I. .. t, ~, 1 .~/ ,, t ~. ............. . , , .... ,---,-. ,.,, -.,, .... ......... . .... ...... , ..,__L I I ~ ~--~ .... ,.~ L!Z] ~' ', ~ Fw-"~ .... . .... ~-'F'~ ...... ..~ ~ , .......... . --.-¢ .... ~ ......... ~-..q-.~ .... ~_.~_~_.~ I ' Ir Z ! T ~.,, , ~ ' I ; ; t, I, I ''T"-~--F+--'~~'''''j .... ~' ...... ~ff''''~ ....... ' '-' ................ I ~ l .......... ~ ........ ~'--& ....... ~'~ ....... , . ~..--~ , . ,, ,. ,, , , ~, .... ~-~4 .......... ~ ...... ~..-~ · , , , ~ , .~ ~ ~ , , . , 400 !. ~ ~ , ' ~, .4 , I I ;,. ; · ~ ~ : J ~ i I i . , ' ' ,,': ~ I I ; ~ ' ~ ~ ' . ~ ', ' : . ~ .~ ...... ~ ..... J ...... '.~ .... L.. ,~ I , I , ' ~ ' ~ .~ ' ' ~. ............. ' I ~-~--~, ' ..........· ~ ~ '~ ' , = , , ...., , . . ,,, , ,, ~..~-,-.-. ............ ~.~.~,~._~ .... L.~._: ..... t__=._.~ I , ..... ~ ' , . : i ~ : i i ' ' ' ~ ' '~ ~-~-~.-.~ ..... 4 ~ ~ , , , I ~ t ; ~ · : ~ . ,~ ...... ~ .............. ~ .... ~.~__~ ..... ~... , . , ,. . , ~ , , t . - ....... 4~- ., , .: , . , ., , , ' i ; ' /" ' ~'F ~ , , -t'-': ........ ~---~~ : . . . , , , ~ , -~ .. ~ ..... . ......... -~' ~ ...... ~"'~. ....... .~ ....... ~ .... i ............ ~ ...... ' ........... , ~ ...... " , ~ ,' ,~ ' ' - "~.-.-,. ' i .... ~ L i ~ ~, ~ ' ' i ' k:"='"=: .... +-...h--I .... 1--.4-~-'-~ ..... ~ .- i ...... "-..'-;-.-.k..' -" -~. 0 200 400 800 800 lpnn ARCO Alazka, Inc P.O. Box t00360 Anchorage, ALazka .- DATE: June t, REFERENCE' ARCO t-ta 4-25-87 t-28 t2-28-86 t-27 5-t4-87 2-8 5-2-87 3-? 5-9-8? J-tO t2-27-86 9-7 4-27-87 ii-1 t2-25-86 t4-32 5-t3-87 t8-9 ~2-29-86 995 t 0 t987 Cased HoLe Final FLowater/F Luid I.D,/GR Run Perf. Record Run Collar &Perf. Locj Run Collar Locj (PLi, cj) Run Collar & Perf. Lo~ Run EPL R~n ~oLLar & Perf. Log R~n Perf. Record Run CoLLar & Perf. Log R~n T~b lng Puncher .Run Casco $ch Gear Gear Gear $ch Gear $ch Gear £ch PLease sign and Received By HAVE A NICE DAY! Rozanne Peek A'rO-t529 TRAN$ ~87279 Approved _, DISTRIBUTION · ,~ Central Fi Les ~ Chevron · ,,."" Ex'l'en.zion Exploration T Exxorl Hara fhon '~., Hob i L ARCO A£aska, Inc. F'.O. Box JOOJ60 Anchorage, A£aska 995~0 DATE' Juty REFERENCE' t -29 986 ARCO Open HoLe Finats 6-'8-86 DIL/SF:'L Run t 2,5" Sch 6-8-86 LDT/CNL"-PORO Run ~ 2,5" $ch 6-8-86 LDT/CNL-RAW Run ~ 2·5" Sch 6-8-86 BHCSLog Run ~ 2,5" £'ch 6-..8-86 Cyber Look Run ~ 5" ,~'ch F'Lease .sign and re'tu -. . / 1"5 F(ec e ired ~y .... ~_..~_~__.. .................... ( / ~ka Ol! HAVE A NICE ~ ~ ~ Anchorao~ Linda HuLce ATO- ~ 529 1RAN$ ~:86427 DI£TRIBUTION Phi LLip~; PB WeLl. F:i i. es ~- R & D JI. .~. ,S'o h i o · .~ . ~S':~ate. o.f. ALaska.. · '..,. Texa co 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 r-; Pull tubing ~ Amend order r~ Perforate ~ Other 2. Name of Operator ARCO Alaska~ Inco 3. Address P. 0. Box 100360 Anchora(~e, AK 99510 4. Location of well at surface 1018'FNL~ 1506'FWL~ Sec.8~ T10N~ R15E~ UN At top of productive interval 0'FNL~ 2750'FWL~ Sec.8~ T10N~ R15E~ UN (approx.) At effective depth 1/+9' FSL~ 2565'FEL~ Sec.5~ T10N, ELSE= UN (approx.) At total depth 160'FS~.~ 25/~6'FEL= Sec.5~ T10N~ R15E~ UN (approx.) 11. Present well condition summary Total depth: measured 9610 feet Plugs (measured) true vertical 9260 feet 5. Datum elevation (DF or KB) 70'RKB 6. Unit or Property name Pr,Jdhoe Ray Unit. 7. Well number 1 -29 8. Permit number 86-105 9. APl number 50--029-21 60/~ 10. Pool Prudhoe Bay 0il Pool None feet feet Junk (measured) Effective depth: measured 9563 None true vertical feet 9219 Casing Length Size Cemented Measured depth Conductor 80' 20" 10 shots Poleset 110'MD Surface 2z~80' 13-3/8' 2500 sx CS II & 2509'HD ~00 sx CS II Top job w/150 sx CS II Production 9579' 9-5/8" 670 sx Class G 9606'ND True Vertical depth 110'TVD 2509 ' TVD 9257 ' TVD .. Perforation dePth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED JUL 1 0 1986 Naska 011 & Gas C~ns. coremissi°p Anchorage ' 12.Attachments Description summa_ry of proposal [] we]~ History & Addendum (dated 6/17/86) 13. Estimated date for commencing operation January~ 1987 14. If proposal was verbally approved Detailed operations program [] BOP sketch [] N~me of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~o~j ~./.~., Title Associate Engineer Commission Use Only ( DAM ) 5A/071 Date Conditions of approval [] Plug integrity Notify commission so representative may witness [] BOP Test [] Location clearance · ;..~,~,'.;~i; ,. ,.~, ~.~,;~,~ Approved by Form 10-403 Rev 12-1-85 Approval No. by order of the commission Date ~ ""~/~,,~., . 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 ~e form giving inclusive dates only. District County, parish or borough Alaska North Slope Borough Field Lease or Unit Prudhoe Bay ADL #28329 Auth. or W.O. no. Title APE AS0847 Drill State Alaska Parker #141 Operator ARCO Alaska, Inc. Spudded or W.O. begun Ioate I Spud Data end depth Complete record for each day reported aa of 8:00 a.m. AP1 50-029-21604 I Hour 5/28/86 2400 Hrs. ARCO w.I. 21.66% Prior status if a W.O. 5/28/86 thru 5129186 20" @ 110' 522', (413'), Trip f/bit Wt. 9.3, PV 10, YP 40, PH 8.5, WL --, Sol 7 Accept rig @ 2200 bra, 5/28/86. NO diverter sys. 5/28/86. Drl 17½" hole to 522'. Spud well @ 2400 hfs, 5/30/86 20" @ 110' 2515', (1993'), POOH to rn 13-3/8" Wt. 9.4, PV 21, YP 41, PH 7.5, WL --, Sol 9 Drl 17½" hole to 2515'. 5/31/86 thru 6/02/86 13-3/8"'@.2509' 4746', (2231'), TIH Wt. 9.4+, PV 5, YP 7, PH 8.5, WL --, Sol 9 Pun f/2050~,2175', TIH to 2505', rm to btm, CBU, POOH. RU A rn 58 ]ts, 13-3/8", 72#, L-80 Butt csg & 1 it, 13-3/8", 68#, K-55 Butt csg w/PS @ 2509', PC @ 2426'. Cat w/2500 s; CS III, followed by 400 sx CS II. Displ using rig paps, bump plug. ND diverter. Perform 150 sx CS II top Job. ND & tst BOPE. TIH w/12¼" BHA, DO cmt & fit equip + 15' new hole to 2530'. Conduct formation Cst to 13.3 ppg EM~. Drl 12k" hole to 4746'. 6/03/86 13-3/8" @ 2509' 5630', (884'), POOH.f/DD Wt. 9.4, PV 7, YP 7, PH 8, WL --, Sol 8 Navi-Drl, DD & surv 12¼" hole to 5630', POOH f/lock-up assy. 4984', 2.4°, N88.6E, 4983.94 TVD, 5.91VS, 4.26N, 4.15E 5533', 20.5°, N42.3E, 5521.31TVD, 105.56 VS, 65.33N, 82.95E 6/04/86 13-3/8" @ 2509' 6585', (955'), Drlg Wt. 9.7, PV 8, YP 7, PH 9.5, WL 9.4, S°l 10 Chg BHA, TIH tO 5109', wsh & rm to 5602', drl & surv 12k" hole to 6585'. 5905', 23.7°, .N38.0E, 5865.98 TVD,. 243.13 VS, 172.38N, 173.10~ 6251', 23.5°, N38.3E, 6183.04 TVD, 378.37 VS, 281.23N, 258.76~ 6/05/86 13-3/8" @ 2509' 7375', (790'), Drlg Wt. 9.8, PV 12, YP 8, PH 9, WL 5.9, So1 11 Drl & surv 12¼" hole to 7375'. 6720', 22.7°, N36.9E, 6614 TVD, 558 VS, 427N, 371E 70307, 22.3°, N38.3E, 6901TVDs 673 VSs 521N, 443E The above Is correct For ~orm preparation ~nd distribution, see Procedurea Manual, Section ~0, DrlHIng, Fages 811 and 8?. Date 6/20/86 Drilling Supervisor -, 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 se;iuentially. 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) Sobmit 'Interim" sheets when filled out but net less frequently than every 30 days. er (2) On Wednesday o! the week in which oil string is set. Submit weekly for workovers and Iollowing setting of oil string until completion. District Alaska Field Prudhoe Bay Date and depth as of 8:00 a.m. County or Parish North Slope Borough Lease or Unit ADL #28329 Complete record for each day while drilling or workover in progress IState Alaska IWell no. 1-29 6/06/86 6/07/86 thru 6/09/86 6/10/86 13-3/8" @ 2509' 8027', (652'), Drlg Wt. 9.8, PV 12, YP 10, PH 9, NL 5.8, Sol 11 Drl & surv 12¼" hole to 8027'. 7341', 21.8°, N40.4E, 7189 TVD, 788 VS, 611N, 518E 7655', 21°, N41.3E, 7481TVD, 901VS, 698N, 593E 13-3/8" @ 2509' 9571', (1544'), RIH Wt. 9.8, PV 9, YP 6, PH 9, NL 5.9, Sol 11 Drl & surv 12¼" hole to 9571', 10 std short trip, CBU, POOH. RU & rn DIL/BHCS/GR/SP f/9546' WLM-2500'. Rn LDT/CNL/GR/CAL f/9546' WLM-8745', cent w/CAL to 7880', RD Schl. Chg BFog, ~IH. 8030', 19.8°, N41.1E, 7833 TVD, 1030 rS, 796N, 679E 8586', 24.2°, N53.4E, 8351TVD, 1229 VS, 933N, 825E 8800', 27.6°, N58.3E, 8544 TVD, 1323 rS, 986N, 903E 9571', 28°, N60.3E, 9226 TVD, 1678 rS, 1169N, 1212E 13-3/8" @ 2509' 9610', (39'), Rn'g 9-5/8" Wt. 9.8, PV 8, YP 6, PH 9, WL 6, Sol 11 RIH, rm 9513'-9571', 4fl 12¼" hole to 9610', C&C, POOH, LD DP. tst. RD to rn 9-5/8" csg. Chg rams & The above is correct Signat~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate ]Title 6/20/86 ' Drilling SupervisOr ARCO Oil and Gas Company Daily Well History-Final Report · 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 operation if space is available. Accounting cost center code District County or Parish Alaska North Slope Borough Field Lease or Unit Prudhoe Bay ADL #28329 Auth. or W.O. no. Title AFE AS0847 Drill State Alaska Well no. 1-29 Parker #141 AP1 ~0-029-21604 Operator A.R.Co. W.L 'Total number of wells (active or inactive) on this cost center prior to plugging and I A~CO Alaska, Inc. 2].. 66% abandonment of this well I Spudded or W.O. begun Date Hour IPrlor status if a W.O. I Spud. 5/28/86 2400 Hrs. Date and depth Complete record for each day reported as of 8:00 a.m. 6/11/86 9-5/8" @ 9606' 9610', (0'), RR 9.4 ppg filtered brine Rn 241 its, + 2 mkr its, 9-5/8", 47#, L-80 BTC csg w/FC @ 9563', FS @ 9606'. Cmt w/400 sx C1 "G" w/8% gel, 3% KC1, 2.2% FL-28 & 1 gal/10Osx FP-gL, followed by 270 sx C1 "G" w/3% KC1, 1.1% FL-28, .3% CD-31, .2% A-2 & 1 gal/100 sx FP-gL. ND BOPE, NU & tst tree. RR @ 2400 hfs, 6/10/86. Old TD Released rig 2400 Hrs. Classifications (o11, gas, etc.) Oil Producing method Flowing Potential test data Well no. Date Reservoir New TD Date PB Depth 9610' Kind of rig 6/10/86 Type completion (single, dual, etc.) Single Official reservoir name(s) SadlerOchit Producing Interval Oil or gas Test time 9563' Rotary Production OII on test Gas per day Pump size, SPM X length Choke size T,P. C,P, Water CDR Gravity corrected Allowable Effective date The above Is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 6/20/86 ITItle Drilling Supervisor ADDENDUM WELL: 1-29 6/13/86 RU Sperry-Sun, rn gyro. RU DA, rn CBL/CCL/GR (with 1000 psi and with psi), RD DA. >1i~i s o r ARCO Alaska, Inc F'~O, Box Anchorage, Alaska DATE' June 24 , i986 REFERENCE: ARCO Magnetic Tapes w/Listing t-29 6-8-86 Open Hol. e .~ch Linda Hu[ce ATO-~ 529F TRAN$ ~86382 DI~'TRIBUTION Central Fi les Chevron D&M Extension Exploration Exxon Marathon Mob i [ Phi Ltips F:'B WeLL Fi Les R & D ~,r $ohio ,~tafe of A La~;ka 'Ir Texaco ARCO Alaska, Inc. (' Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 27, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor 'As-Built Location Plat - DS 1 (Wells 28 - 29) Dear Hr. Chatterton: Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JO/tv ORU1/].2 Enclosure RECEIVED J U N - 2 1986 Alaslm 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllantlcRIchfleldCompany I I CC)ND. C)ES. fi. d, Norton CHK, J.A.K. OXT! 5'10'86 01 II _ LEGEND/NOTES · EXIIIT. lIEU. Al' BUII.T CONDUCTOR - ALL COORDS, ARE &S.R ZONE 4. - BAIII OF LQCATIOfl Il MOll'S. 'I-A", AHD'I'B" PER' ~1.¥. LOUNIBURY. ' LOCATE D WITHIN P~IOTRACTEO SEC LOCATION , ,~ Y.S, tll, ltl~O LAT., 1'0" 14.~,.4.11~" I~O0'ir.W.L · ,611,111,1 LO#1,.141ofJ'll. IT" tSl' Ir.N.L. CE].LAR BOX ELEV. · $9.~ Y. I~IIt, IIO. S LAT.. 1,0el4' ~.I.811" ISII' F.W.L. X. etl,l~l.O LO#I.. Hie 13* 31,15" 1017' F.N.L. CELLAR BOX EL EV. · RECEIVED, JUN - 2 1986 ' Alaska Oil & Gas Cons. Commission Anchorage I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LANO SURVEYING IN THE STATE OF ALASKA ANO 'THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY REVIEWED BY'HEt AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: 5- 16-86 - · , (~ D.$.- I 'COND. Nc~t28,29 AS-BUILT ARCO Alaska, Inc. O 1~4eldlaf/ of AIIQiIll Rl~,.hfleld Company NOflTH 8LOPE DRIt. LINI~ PflU~OE BAY m May 23, 1986 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit DS 1-29 ARCO Alaska, Inc. Permit No. 86-105 Sur. Loc. 101$'FNL, 1506'FWL, Sec. 8, T10N, R15E, UM. Btmhole Loc. 72'FSL, 2838'FWL, Sec. 5, T10N, 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 commencing installation of the blowout prevention equipment so that a representative of the Com~_ission may be present to witness testing of the equipment before the surface casing shoe is drilled, Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so t~at the Commission may witness testing before drilling below the shoe of the conductor pipe. trul'~.yo~rs, Chairman of' Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO}9.IISSION jo Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ' STATE OF' ALASKA'' ALASKA( .iL AND GAS CONSERVATION CL,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill []1 lb. Type of well. Exploratory ,"-1 Stratigraphic Test ~ Development Oil Re-Entry i~. Deepen[]1 Service [2 Developement Gas ~ Single Zone .l~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510 4. Location of well at surface (Approximately) 1018'FNL, 1506'FWL, Sec.8, T10N, R15E, UN At top of productive interval 0'FNL, 2750'FWL, Sec.8, T10N, R15E, UN At total depth 72'FSL, 2838'FWL, Sec.~ T10N, R15E, UN 12. Distance to nearest 13. Distance to nearest well property~.;~3,1ine 1-8 and 1-28 are feet feet 16. To be completed for deviated wells ' Kickoff deptl~700 feet Maximum hole angle23 18. Casing program size Specifications Hole Casing Weight Grade Coupling Length 30" 20" 91.5# H-~O Weld 80' 17"1/2' 13'3/8" 68# K-55 BTC 2~70' 72# L-80 12-1/~" 9-5/8" ~/# L-80 BI'C .9535' RKB 70', PAD 39.5'feet 6. Property Designation ADL 28329/ALK2327 7. Unit or property Name Prudhoe Bay Unit; 8. Well nuqnber 1 -29 9. Approximate spud date 05/27/86 14. Number of acres in property Prudhoe Bay Field Prudhoe Bay Oil Pool 11. Type Bond (see 20 AAC 25.025) Stat;ewide Number #8088-26-27 Amount $500~000 15. Proposed depth (MD and TVD) 9227 ' TVD 9~' Nn feet 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) 0 Maximum surface 2785 pslg At total depth (TVD) Setting Depth Top Bottom MD TVD MD TVD 30' 30' 110' 110~ 30' 30' 2500' 2500' 29' 29' ~56~' 922/' 3800 Quantity of cement (include stage data) 2000# Poleset 1500 sx CS III & ~00 sx CS II 800 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: ' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat Length Size Cemented Measured depth True Vertical depth BOP Sketch Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that,~e foregoing is true and correct to the best of my knowledge Signed '7~',/~,/~//~~/ - CommissionTitle Regionaluse Only Drilling Engineer Date~/~/?/o=~ p~)/pn~7n Permit Number I APl number I Approval date ISee cover letter 86-105 [ 50- 029-21604 [ 05/23/86 /for other requirements Conditions of approval Samples required [] Yes '~ No Mud log required [] Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No Required workin~q,Fr~ssur~UF]=~[]2~ ~' 3M; [] 5M; [] 10M; []15M Other: f /~/'f ~.~~ . by order of Appr°ved bY~k'- ~, '"/, L _~-'~ Commissioner the commission Form 10-401 Rev. 12-1-85 Submit,,~l~ triplicate DS 1-29 DRILLING PROGRAM 1. Set 20" conductor and poleset in place. 2. MIRU drilling rig. NU 20" bell nipple and flow line. (NOTE: No shallow gas was encountered on surface interval of previous well.) 3. Drill 17-1/2" hole to 2500' MD. ~. Set 13-3/8" casing and cement. Perform cement top job if no cement returns. Test casing to 2000 psi. 5. Install 13-5/8", 5000 psis RSRRA BOP stack. Test BOP stack to 5000 psi. Test BOP stack weekly. Drill 10' new hole then perform leakoff test. 6. Drill to ~700' (KOP). Build 2.5°/100' oriented NSO°~2'E to 23°. Drill directional hole to 956~' MD (9227' TVD). 7· Run open hole logs. 8. Run and cement 9-5/8" casing. Displace cement with 9.~ ppg brine. 9. Test casing to 3000 psi. 10. Secure well and release rig. 11. Run cased hole logs. 12. MIRU completion rig. 13. Run 5-1/2", 17.0#s L-80s AB-HOD x ~-1/2"s 12.6#s L-80 BTC tubing string with packer and provisions for subsurface safety equipment. Set packer above Sadlerochit. 1~. NU tree and test to SO00 psi. 17. Secure well and release completion rig. 18. Perforate and stimulate well. Install. subsurface safety valve. NOTES: a · be C ~ 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· The drilling fluid program and fluid surface system will confor.m to the regulations set forth in 20 AAC 25.033. Maximum surface pressure is based upon recent BHP surveys and a full column gas to TD (0.11 psi/ft). Well 1-29 will pass 83' from well 1-7 at 3177' MD,(3177' TVD), The closest wells to 1-29 will be 1-8 and ,1-28, This will occur at the surface and will be 60'. PD/PD270a:sw 05/15/86 DS 1-29 DRILLING FLUID PROGRAM Depth (TVD) Surf to 13-3/8" Csg Poi nt --. Density #/gal Plas Yield Visc. Point Initial IOM (CP) #/100 ft2 Gel Gel 8.8 Funnel to 100- 9.2 250 ~0-60 30+ 50+ FL CC/30M 25 % Oil % Sol ids pH and Type of Mud Gel-Benex Spud Mud 13-3/8" Csg Shoe 8.8 Minimum 2 2 5 to to Possi bl e to to to K-lQ 9.~ ~ ~ 10 25 to 10 3.5 to 6.5 Low Sol ids Non-dj spersed K-lO 9.2 10 6 ~ 8 to to to to to to, TD(9-5/8" 9.8' 20 10 8 12 Csg.Pt.) 15 to 10 to 8 pH 9-10 Low Sol ids/ Non-dj spersed DS 1-29 EQUIPMENT - DRILLING FLUID SYSTEH 1. Degasser, 2. Shakers 3. Pit level indicator (with both visual and audio warning deviCes) Drilling fluid flow sensor 5. Trip tank' 6. Agitators 7. Mud cleaner (desilter) PD/PD270b=sw ."%.'p~cal Mu~'Pi=~."~hema=i¢ Trip Tanks Sand=rap (30 bbls) Shaker ODegasser (83 bbls) .(97 bbls) Shaker . (97 bbls) Pill. Pit (36 bbls) Desander (36 ]:)bls) Suction Pit (448 bbls) Drawing not to scale. .. Mix Pit (122 bbls) NOTE: System is equippe'4 with a dxilling fluid pit lewel indicator with both visual and audio warning devices and a fluid flow sensor located in the ~mmediate area of the ~riller'S console. ) 13-$/8" BOP StacJ~ Test 1. ~ill R~P stack and .nanifcld rich a non-freezing liquid. ,,Check chat. all hold dovn screws are ~ully retracted. ,'dark rmm~g jo~zl: vith predetermzued plug seac~.ug cbpch. ~ test pl~J~ or~ C~ll pipe ~ seat ] ( ) ( 1em 3 q~es. BI~ ~sm co :~. at leuc ~~~. BI~~~ M :e~. ) ( 9. ~n~seco~pA~ ~ c~cloM~msec o~ 3. Close ~r~,~ar pTevemer and ups~rem valves. 4. ~i~l? test chokes. . · ~. -.~u ~ of r. he ~ollovi~ tests, ~irsc hold a 250 psi AOW pTessIJre test for a m4~4nn O~ $ m4,u~es, che~ test ac,tho htSh pressure. 6. In~'~m presto to 3000 psi and hold ~rr a n4,n~n,. off 3 eizmces, Bleed pressure to zero, 13. 14. IS. 16. 17. 18. pipe rms. Ir~,.ae pressure co SO00 psi belov tho bottm sec of pipe rms iai hold ~r R less~ 3 n~- k~te~ o Test ree,~,~ ~cesced -q,4~old valves (if vich 5000 psi upscre~ of valve azd zero pressure dmmstrem. Bleed pressure co zero. Open boston sec of pipe l*l~s. Back off nmning join~ and pull ou~ of hole. Close blind res and ten to ~000 psi ~or at least minutes. Bleed pressure off all equi~m. Open blind ram. Make sure --~ ~old and lines .are full of non- freeziAf liquid and all valves are set iA drilliag position. Test standpipe valves ~o SO00 psi. .Test ~el!y Cocks and inside ~OP tO $000 psi Foaney punp. Clmck uvc.,&tion of gerasser. Bocord test irL~Cormation on bloMrd~ e,.~Aer tesl pe~£o,, crop,ere Bc~ test once a ~eek and f~nc* levised 1/:1/8~ o ooo f..ooo 3ooo 0 -.l' ' t':U' (jAblNfa T,:: 0 "110 , , ooo",'.'_ ooo I I , I 7000 t-0 1000 - . . . . . . . . . 2000- ' ' . i 3-a/o' CASING TVO -2600 i 3000 . I . 4000 ARCO A?, SKA, INC. I(OP TVD - 471)0 5000 ~' 12.5 .m '" 17 5 . II · ' ' 22.5 EOC TVO - ISBS4 MD - 6018 OEP "..16~_~ A VERA~ E ANOLE 6000 7000 K-IS TVO m 7160 MO ' 7308 DI"P ' 641 8000 9000 · $~AI I= I IN, = lnnn F' .. SHL: 1018' :NL, 1508' FWL, SEC 8, TION, R15E, Uld THL: O' FNL, 2750' FWL, · qPq EL T nM, FI16F, tl%t N 50 DEG 42 ~N E · 1607 :."""2(~'~ TARGET) ... . K-6 1'VD '" 7i106 MD m 8020 OEP -' 1118 LCU TVD mm 8400 MD m 1666 DEP -- 1370 SAG RIVER TVD m 8563, MD m 8834 C EP am 1438 SHUBLIII: TVD m 8590 IdS m 8872 DEl' "" 1451 TOP SADLEROCHIT TVD m 8660 MD-- 8948 DEP - 1480 mI ~ mbt d GlO CONTACT TVD 8836 MD 9138 DEP 166 J TAR.~iPT TVQ m_lA~) Mn · 'Jo74, [LEP-J 1007 OIW CONTACT TVD - esso MD - 0414 OEP - 1682 BASE SADLEROCHIT TVD - 8210 ViD "" 0646 DE.i) ." 1713 TO 1'VD "" 0227 Mi:, .- 06a4 DEP -, 1720 - 1000 - 2000 . . . . . . - 3000 -4000 · m~ · · · m. - 5000 · · · · . - 6000 · = -7000 - 8000 = . . = . -9000 I o_ U c-~ 10000 11000 ......... m 0 1000 I 2000 I I I ' I 3000 4000 5000 8000 VERT I CF:IL SECT I ON , . - 10000 . . - 11000 7000 o -2000 O ! ! ! ~ - . F. - ~ OOORO~NBT~S ~ 1000 2000 3000 4000 5000 i i i ~ i i i i i i i i i i i i i i SEC 8, TION. R15E, UlV -HL: O' FNL, 2.760' FWL, SEC 8, TIO#, R16E, UI~I z : DS1-~9 . TVD -- 8840' TMD ' 82"4' DEP -- 16C7' : N 1018 c~. - 0 E' 1244 I Illlmllll Illlmltlm flfllllJI Ilmllllml mllllllll IIIlllllllpmllmmlllllllll! -2000 -1000 0 1000 2000 ~o00 ' ~000 5000 E - ~ COOROINBTES o -~-000 - 1000 (~ ! ! ! m ~! ! ! ! ! ! ! ! ! ! ! ! ! (4) ' r'~ . n- . CD - CD - CD ' Z ' ;75 5O6 Fi. - N COORDINRTES 1000 2000 3000 ! ! ! ~ ! ! ! ! ! i ! ! ! ! ! ! ! ! ! ! ! m ! m ! ! ! 4000 5000 m ! ! ! m ! ! ~ i m DS1-~9 DS1 ~ ~927 -' b21U DS 1-8 _-, ' 6338 - , 6919 562~ 1-7: · mmmmm -2000 m m m m m ! m ! m ! ! ! m, - 1000 0 , ! m m ! m ! ! ! m ! ! ! ! ! ! m~ ! ! ! m ! I ! m ! ! 2000 '3000 4000 5000 COORDINRTES -:~oo" -200 -lo[ F.. - ~ i i ~ i I I i i i i i · i i i i I i i i i i I i i i i if')- . N COORDINATES 0 1 O0 ~,,d ~00 ~00 . ,= m . m . m . 3558 us'_-zu~' DS1-29 ,~531 '-~0 ~458 , OGiO 15 1--~- ' O. (%1 I ' I. IIIIIIIII IIIIIIIII IIIIIIIII -300 -200 -100 i i i i i i i I i i i i i i i i i i i i i i i i i i i i i i i i i i i ! 0 1 O0 200 300 400 N COORDINRT[S C~ECK LIST FOR NEW WELL PERMITS ITEM DATE Fee .'~' ,%:. ~..~; 1. APPROVE C.. <:".."..'¥ (2) Loc "~'"",'.,';f """ ' ,,, (2 tliru 8) Is the permit fee attached .............................. Lease & Well No. YES · NO (3) Admin (9 thru (10 and 13) ' (4) Cas~ _~,.~.~E (14 thru 22) (23 thru 28) . 10. 11. 12. 2. Is well to be located in a defined pool ...................... ~ 4. Is well located proper distance from other, wells ............... 5. Is sufficient undedicated acreage available in this pool .......... . .... st.. 6. Is well to be deviated and is wellbore plat included .............. ~ 8. Can permit be approved before ten-day wait .~...]~ .................. ~' Does operator have a bond in force .................................. ,,, Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~, 13. Does the well have a unique name and'number ......................... 14. Is conductor string provided ........................................ 15. Will surface casing protect fresh water zones ....................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is.this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure iacluded on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... ~ Is the drilling fluid program, schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached./~. Does BOPE have sufficient pressure rating - Test to ~OO psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. ~ (6) OTHER ~/, A. (29 thru 31) Geo logy: HWK/ Eng.ineering: LCS .?~:'~: ~Ew- ........... rev: 04/03/86 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. · INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,'..~'o ~ ,::'~.-,:/~',,'. l -..o, ( [r,~ o I I ~ E-O 0 h. 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. LiB.~A.RY T.~-~E CUKVE EPECi.--iCATiONS Company Well Field County, .~CO Alaska. !nc. D.S. 1-29 ?rudhoe Bay Noruh Slope, ECC$ DATE 3361 5/~/88 ~/17/88 (Ah~ rev. ) CCL C~ GX Scaudar~ Cu~,e Name · Casing Collar Comp eusa= ed Neuureu Shat: Space Long Gamma Lo~s Used CN - tiu!:is=ace I 't I0 - i00 .. 60 - 0 ~0 - $30 0 - 200 , !00 - 200 I .'! ** REEL HEADER ** REEL NAME : DATE : ORIGIN : FSYS SERVICE NAME: BiTLIS REEL CONTINUATION NUMBER: 01 FREVIGUS REEL NAME : COMMENTS: DRESS;~ ATLAS LIS CUSTOMER TAPE --- CRE~TED BY SCS PROGRAM R 2.0 LENGTh: 1~2 BYTES ~* TAPE TAPE NAME : D~TE : ...... ORIGIN : FSYS SERVICE NAME: mASS ! TA~E CONTINU~TZON NUMBER: 01 PREVIOUS TAPE NA~E : COMMENTS: LENGTH: 132 BYTES ,, FILE HEADER # I ** FILE NAME: PASS 1.001 SERVICE kAME: VERSION # : 1 OATE: $5/11/ZC MAX RECORO LENGTh.: 1C2z~ BYTES FILE TYPE: LC PREVIOUS FILE NA,VE: , ~* INFORMATION R~COROS ** MNEM CONTENTS APIN : 5002921~04 CN : ARCO ALASKA, INC. WN : D~ 1-2'9 · FN : PRUCMOE BAY COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 ** FORMAT ** UNITS ENTRY BLOCKS TYPE ENTRY DESCRIPTION ~ I DEPTHS DECReaSE 8 60..0 FRAME. SPACING ' 9 ,lIN FRAME SPACING U~ITS 11 19 MAXIMUM FRAMES/RECORO 0 TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE NAME REPR CODE SIZE SAMPLE UNITS mmmm mmmm mmmmmm, mmmmN · CURVE NAME REPR C¢OE SIZE S~MPLE UNITS ' ,SSN 68 4 1 GR 68 4 1 CCL1 68 4 1 TEN 68 4 1 CN 68 4 I ** FORMAT ** o"Va '"" ' ..... C'La'm Om CPS CSSN 68 API CCL 58 TTEN 58 LBF SPC 68 % CNC 68 4 4 4 4 ' 'l ....... I CPS I DIM 1 LBF I F/MN 1 ENTRY BLOCKS TYPE ENTRY DESCRIPTION mmmm mmmmm 4 I EEPTHS EECREASE 8 50.0 FRAME SPACING 9 .lIN FPA~E SPACING UNITS 11 19 ~AXiMUM mRAMES/RECORE. 0 TERFINATOR -0.500 LEVEL SPACING DATUM SPECImICATiCN BLOCKS CURVE REmR NAMm CODE SIZE S&MPLE ~NITS mmmm mmmm LSN 68 4 1 CPS SSN 68 4 1 CPS GR 68 4 1 ~PI CCL1 68 ~ 1 T~N 68 4 1 LBF CN 58 4 1 CURVE REPR NAME CC~ SIZE mmmm mmmm CLSN 68 4 CSSN ~8 4 CCL 58 4 TTEN ~ 4 SPD 68 4 CNC ~8 4 S~MPLE UNITS mmmmm 1 CPS cps 1 DI~ 1 LBF 1 F/MN 1 % ** DATA ** DEPTH 9534.C00 FT 2905.9690 M LSN 28.997 CLSN GR 49.472 CCL TEN -39.646 SPD 7.249 0.000 26.997 SSN 115.9~8 CCL1 0.0¢0 CN 15.000 CSSN 116.988 TTEN 744.126 CNC 19.000 DEPTH LSN GR TEN 9500.C~0 FT 2895.6050 M 33.493 CLSN 42.758 CCL 38.192 SPD 7.533 0.000 25.997 · SSN 134.225 CCL1 O.OOC CN 39.035 CSSN 122.803 TTEN 978.152 CNC 43.035 DEPTH 9400.000 FT 2865.126C M LSN 40,492 CLSN GR 25.703 CCL TEN' 28.471 SPD 9.178 ~.000 25.894 SSN 144.62d CCL1 C.OCC CN 32.272 CSSN 132.387 TTEN 999.604 CNC 36,272 DEPTH 9300.000 FT 2834.6460 M LSN 59.428 CLSN 14.945 GR 31.155 CCL O.OCO TEN 77.806 SPD 25.997 DEPTH 9200.000 FT 2804.1660 M SSN 197.69C CCL1 C.OCC CN 29.317 CSSN 202.164 TTEN 1078.132 CNC 33.317 ... LSN 80.163 CLSN 20.901 GR 23.071" CCL ...... O.O00 ' TEN -49.551 SPD 25.997 SSN 21 3.408 CSSN 222. 551 CCL1 '" '"' " C.OOO " TTEN "' 985.882 CN 20.416 CNC 24.416 DEPTH '~9100 CCO'FT '"2773 6860 M "..'"'"',.' .... ' ..' · i ..... ' ' "' ' ' Y'' ', ·" ..... ·, ·: ' : ' ." ' '.' '. ,~ -, ' ..'., ,', '.,.., ,. ' ,.. ,, "' .: ,... .' ..... , ... , .,... . ... ' . , . , .', ;. .;. : ';":'! ,., · ' T SN R EN DEPTH · m m.,mm LSN TEN 47.428 CLSN 32.887 CCL 34.964 SPD 12.042 SSN 173.571 CSSN 185.530 0.000 CCL1 O.OOC TTEN 1039.533 25.991 CN 35.738 CNC 39.738 .. 9CO0.C~C FT 2743.2060 M 53.895 CLSN 1~.726 26.574 CCL G.CCO -35.471 SPD 25.997 SSN CCL1 CN 180.8~C CSSN 197.203 C.OCC TTEN 960.204 24.05C CNC 2~.050 DEPTH 8900.CCC FT 2712.726C M LSN 100.24g CLSN 39.~32 GR 56.C9~ CCL O.C£O TEN 45.~76 SPD 25.871 SSN CCL1 CN 247.2~7 CSSN 297.034 C.OCC TTEN 1034.516 11.43~ CNC 15.438 DEPTH 8800.CC0 =T 26~2.245C M LSN 32.997 CLSN 8.249 GR 62.273 CCL O.COO TEN 27.447 SFD 24.998 SSN CCL1 CN 134.9~ 'CSSN 134.986 C.OCC TTEN 1012.499 39.35~ CNC 43.356 OEPTH 8782.5CC FT 2676.911C M mmmmmlmmmm LSN 32.gg? CLSN 8.2~9 GR 60.663 CCL C'.CO0 TEN 27.447 SP~ 24.99~ SSN CCL1 CN 134.9~ CSSN 134.g66 C'.OCC TTEN 1012.499 3g.35d CNC 43.355 STARTING DEPTH = 9534.000 FT ENOING DEPT~ = 8782.500 FT 2905.9690 M 2676.9110 M ** FILE TRAILER FILE NAME: P~SS SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: .,.i ..... FILE TYP:: LC ... NEXT FILE NAME: I .001 1024 ** FI. LE HEADER # 2 ** mILE NAME: PASS 2.002 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 MAX RECORD LENGTH: 1024 FILE TYPE: LC. PREVIOUS FILE NAFE: DYTES ** INFORMATION RECORDS ** MNEM CONTENTS APIN : 5002921~04 'CN : ARCC'ALASKA,'INC. WN : DS 1-29 FN : PRUEHOE BAY COUN : NORTH SLCPE "' """' ..... ·"STAT .... : ALASKA "" "'"' ...... '" ..... LCC : 150.00 · ~, .,. ..'.",'.'.~' ** FORMAT'** ' "'.:' ". ...... ": .' ," ·. ·UNITS ENTRY BLOCKS TYPE ENTRY DESCRIPTION ____ 4 I DEPTHS DECREASE $ 6C,0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 19 MAXIMUM FRAMES/RECORC 0 TERMINATOR -0.5G0 L~VEL SPACING DATUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS mmmm m--mm LSN 68 4 I CPS SSN 68 4 1 CPS CCL1 68 4 1 TEN 68 4 1 LBF CN 68 4 1 CURVE REPR NAME COrE SIZE S~FPLE UNITS m--mm mmmmm CLSN 68 ~ I CPS CSSN 68 4 1 CPS CCL 68 4 I DIM TTEN 68 4 I L~F SPD 68 4 I F/MN CNC 68 4 I " ** mORMAT ** ENTRY BLOCKS TYPE ENTRY DESCRIPTION mmmm mmmmm mmmmmmmmmmmmmmmmmmm 4 I DEPTHS DECREASE 8 60,0 FRAME SPACING 9 .1.IN FRANE SPACING UNITS 11 19 MAXIMUM FRAMES/RECORC 0 TERFINATOR -0.500 LEVEL SPACING gATUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS mmmmlm Immm mmlm mJmmm LSN 68 4 I CPS SSN 68 4 1 CPS GR 68 4 I API CCL1 68 4 1 TEN 68 4 1 LBF CN 68 4 I CURVE REPR NAME CODE SIZE S~MPLE UNITS mmmmmm mmmm mmmm mmmmm CLSN 68 4 I CPS CSSN 68 4 1 CPS CCL 68 4 I DIM TTEN 68 4 I LBF SPD 68 4 1 F/MN ChiC ** DATA ** DEPTH 9533 m mmmmmmmmmmmmm LSN 2 GR 5 TEN 10 DEPTH 9500 · CO'O FT 2905.664C M 8.997 CLSN 7,249 1.827 CCL O.O00 0.~40 .. SPD 24,998. · C~0 FT 2895.6060 M SSN CCL1 CN 116.988 15.0CC ., CSSN 116.98~ TTEN 817.318 CNC 19.000 , .... LSN 35,21 GR "': " ...... 48.00 TEN 130,67 2 CLSN 7.876 SSN 2 .... CCL 'mmlmmmm"'''OJCO0 .... ..... '''CCLI'' 5 SPD 26"555 CN 131 .941 CSSN 122.122 ........ C.OCO TTEN m I m ~m~ 1021.450 .,. 3~.145 CNC 40,145 LSN ... GR TEN 40.537 CLSN 9,565 SSN 145.622 CSSN 138.520 24.048 CCL 162.000 CCL1 162.00C TTEN 1104.999 88.172 SPD 25.997 CN 32.5~? CNC 36.~87 DEPTH 9300.C00 FT 2834.646C M mmmmmmmmmm LSN 62.284 CLSN 15.963 GR 28.379 CCL O.CCO TEN 15.435 SPD 26.168 SSN 199.914 C$SN 204.363 CCL1 C.OCC TTEN 1073.483 CN 27.23C CNC 31.230 OEPTH 9200.CC0 FT 2804.166C M LSN 82.511 CLSN GR 20.389 CCL TEN -8.237 SPO 20.951 O.CCO SSN 216.769 CSSN 218.~4 CCL1 C.OOC TTEN 1C35.753 -- CN 19.725 CNC 23.725 ---- LSN GR TEN 9100.CCC =T 2773.656C ~ 48.223 CLSN 31.857 CCL C, EPTH 9C00.0C~ mmmm LSN 5~. 2~8~ GR 2~..381 TEN -2.C37 FT 11.g'c2 ~6.28~ 27~3.206C M CLSN 16.C89 CCL 0.C03 SP; 26.997 SSN 174.737 CSS.N 188. 548 CCL1 C.OCC TTEN 1C. 47. 730 CN ~?.174 CNC 41 .174 SSN 178.49~ C$SN 193.346 CCL1 C.OCC TT~N 1030.700 CN 24.63~ CNC 2~.639 C=PTH 8gOO.CCC FT 2712.72dC M Immmmmmmmmmmml/mmmmmi LSN 110.408 CLSN 33.191 GR 61.117 CCL O.CO0 TEN 38.716 SPO 25.997 DEPTH 8800.C00 FT 26~2.245C M mmmmmmmmmmmmmmmmmmmm LSN 23.998 CLSN 5.999 GR 61,839' CCL 0.~00 TEN -39.646 SPO 2~.997 OEPTH 8781.500 FT 2676.607~ M mmmmmmmmmm LSN 23.998 CLSN 5.999 GR 63.864 CCL 0.000 TEN -39.646 SPD 26.997 SSN CCL1 CN SSN CCL1 CN SSN CCL1 CN 248.8~C CSSN 288.362 C.OCC TTEN 1064.852 14.5C3 CNC 18.503 131.987 CSSN 131.987 0.00C TTEN 1012.499 72.467 CNC 76.457 131.987 CSSN 131.987 C.O00 TTEN 1012.499' 72.467 CNC 76.467 STARTING DEPTH = 9533.000 FT 2905.6640 M ENDING DEPTH = 87~1.500 FT 2676.6C70 M ** FILE TRAILER ** FILE NAME: PASS 2.002 SERVICE N4ME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FILE N~NE: '* FILE DE.aDER # 3 FILE NAME: P~SS 3.003 .' SERVICE NAME: VERSION # : 1 'DATE:'85/11/20 ...... . -,'.:"'.'",,"?'.!. ' ...... :~':' .... ".',, .", .... ... .... ""':?""'"'". ' .':'.':,'-'" ,.' . '.:: i.: 7' ..", '",'. · , '," :,',, , ' . ' .: ;." , . , ., :'..'. '~.. ,, . ,. ', . ,. . . , . .... ,. ,. .. ,, "FILE TYPE: LO PREVIOUS FILE NAME: . ** INFORMATION RECORDS ** MNEM CONTENTS wmI-- APIN : 5002921604 CN : ARCO ALASKA, WN : DS 1-29 FN : PRUOHOE ~Y COUN : NORTH SLOPE ST~T : AL~SK~ : LOC : 150.00 INC. UNITS ~,* FORMAT ** ENTRY E TYPE ENTRY 4 1 8 6~.0 9 .lIN 11 19 0 -0.500 DATUM SPECIFI LOCKS DESCRIPTION DEPTHS DECREASE F~AFE SPACING FR~E SPACING UkITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING CATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS mmem mmmm LSN 68 4 I CPS SSN 68 4 I CPS GR 68 4 1 CCL1 68 4 1 TEN 6~ 4 I LBF CN 68 4 I % ** FORMAT ** CURVE REPR N~M~_ CC:DE S'ZE~ S~MPLE mmmm mmmm CLSN ~8 4 1 CSSN ~8 4 1 COL ~8 4 1 TTEN ~8 4 1 SPD 68 4 1 CNC 68 4 1 UNITS CPS CPS DIM F/MN % ENTRY BLOCKS TYPE ENTRY :ESCRiPTION --mm. 4 1 ~EPTHS~n:CRE~S~ 8 6C.0 .FR~FE SPACING 9 .lIN FRAFE SPACING UNITS 11 19 MAXIMUM FRAMES/RECORC 0 T~RMINATOR ., -0.500 LmVEL SPACING ~ATUM .SPECIFICATION BLOCKS · ~, CURVE REPR NAME CODE SIZE SAMPLE mmmmmm mmmm mmmm LSN 68 4 1 SSN 68 4 1 GR 68 4 1 ,, . CURVE N~ME REPR UNITS CCO: SIZE S~MPLE mi mm m mere CPS CLSN 68 4 1 CPS CSSN 68 .4 1 ~PI CCL 68 4 1 UNITS mmmmm Cps CPS DIM iLBF ,.. : '"" CN 68 4 1 .% CNC 68 ** DATA ** 4 1 % 7 DEPTH 9534.C00 FT 2905.9690 M LSN 30.997 DLSN 7.749 SSN 115.98~ GR 47.116 CCL 0.CCO CCL1 C.00C TEN 210.429 SPD 22.995 CN 15.000 ¢SSN 115.988 TTPN 829.517 CNC 19.O00 DEPTH 9500.CCG FT ;895.6060 M mmmmmmmmmmmmmmmmm------mm LSN 31.604 CLSN ~.010 GR 45.233 CCL O.~rC TEN 184.344 SPG 2c.233 SSN 122.95,~ CCL1 C .OCC CN - 35.50~ CSSN 122.158 TTEN 1015.094 CNC 3~.508 D=-°Th 9'"C CCC FT pS~ 12AC v LSN 40,. 2't6 CLSN ~ ,=x C'S~ I rr,. GR 3G.5,= ...... T~N 10.512 S~C 25.997 SSN 145 .B51 CCL1 1 .OC, C CN 35.995 C$SN 1/.5.014 TTEN 1027.787 CNC 39.995 DEPTH 9S00.CCG FT 283L.6460 M LSN ~3.291 CLSN ',qR 30 7n~ CrL ~ CCn TEN -50.599 SmD 26.997 SSN 2C5.7g~ CCL1 C.OCC CN 28.005 CSSN 201.245 TTEN 995.~93 CNC 32.005 DEPTH LSN TEN 920,S.000 FT 2804.166C' M 76,471 CLSN 20,1B0 28.736 CCL C.000 51,420 SPD 26.997 SSN 212.142 CCLI C.CCC CN 20.674 CSSN 216.743 TTEN 1104.820 CNC 24.674 DEPTh 9100.~00 FT 2773.6860 M mmmmmmmmmm/mmmmI LSN 53.297 CLSN 12,G57 SSN GR 32.720 CCL 0.000 CCL1 TEN 4.288 SPO 25.997 CN DEPTH 9C00.C00 PT 2743.206G M iml~mmmIImm~IilII~mmmmlImlIIII LSN 51.858 CLSN 1 5.276 'SSN GR 29.866 CCL O.C~O CCL1 TEN -54.536 SPD 25.997 CN 1B~.098 CSSN 182.708 C.O~C TTr-N 1057.398 34.497 CNC 3,~.497 176.478 CSSN 192.732 G.OCC TTEN 977.049 2~.529 CNC 30.529 DEPTH 8goo.co0 FT 2712.726C M m Imm m i, m m m ,m ~mmm m m m m m imm m m Im' m m m mm m IN Imm m m m LSN 1~_'C.300 CLSN 26.227 SSN GR 73.123 CCL C'. C, O0 CCL1 TEN 34.606 SP0 20.003 CN DEPTH LSN GR ,; TEN ,, ',, j"' DEPTH ;..' ,,, , , · .,. LSN .'."...:'::,.i.i,, ' ' T E N . ..:':.;;: :'.' 8800.000 FT 2~B2.2450 M mmmmmmimI, mmmmmmmmmmmlm 21.99~ 'CLSN 5.499 64.216 CCL C.CO0 4~.'795 S2D 25.997 , , ,,,. ,,, .,, . .... 8782.500 ~T '2676.9110 M SSN CCL1 CN 21.998 CLSN 5.499 SSN 63.765 CCL 0.000 CCL1 48.795 SPD 25.997 CN ': ¥'."'"':. ].i /':":;', " S T ART I NG' DEPTH .= ..'9534.000 ,,'.FT ..... '.,..2gc 5. 9690, M ":, ].,~. , ....,.-..~,,-,~> ... -..., -, ~. . , '",,",", ,..,.,,., -- "' :::T,,' ',"'?. . ...,' '" ' . . , ,. , ,' . · ., 2~C.0C9 CSSN 25,5.702 C.OgC TTEN 1034.845 17.533 CNg 2! . 533 . , 14C.9~ CSSN 140.986 C.OCC TTF-N 1061.294 114.614 CNC 11~.614 140.986 CSSN 140.986 C.OOC TTEN 1061.294 114.614 CNC 118.614 ** FILE TRAILER FILE NAME: PASS ].003 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LC NEXT FILE NAME: ** TAPE TRAILER ** TAPE NAME: SERVICE NAME: PASS 3 DATE: ORIGIN O~ CAT~: FSYS TAPE CDNTINU~T!Oh ~ : 01 NEXT TAPE NAME: COMMENTS: ** REEL TRAILER ** REEL NAME: SERVICE NAME: EITLIS DATE : ...... O~iGIN OF DATA: FSYS REEL CONTINUATION # : 01 NEXT REEL NAFE: COMMENTS: DRESSER ATLAS LIS CUSTCMER TAPE --- CREATED BY SDS PROGRAM REEL HEACER TAPE HEADmR FILE HEADER INFORMATION FORMAT DATA - TABLE DUMP - FILE TRAILER i,~'''.'''~: TAPE TRAILER REEL TRAILER 1 1 3 3 6 24O 3 1 1 ', TOTAL RECORDS: 262 COMPANY NA~E .' ARCO ALASKA, INC. WELL NAME : DS 01-29 FIELD NAME '. PRUDHOE BAY BOROUGH : NORTH SLOPE STATE ~ ALASKA API NUMBER ~ 500292160400 REFERENCE NO : 98519 RECEIVED ~'~.~ 26 1999 Alasla Oil & ¢ms'Cofls. Coa~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC REEL NAME : 98519 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA, DS 01-29, PRUDHOEBAY, API# 50-029-21604-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC TAPE NAME : 98519 CONTINUATION # : 1 PREVIOUS TAPE COF~4ENT : ARCO ALASKA, DS 01-29, PRUDHOE BAY, API# 50-029-21604-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 01-29 API NUMBER: 500292160400 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-MAR-99 JOB NUMBER: 98519 LOGGING ENGINEER: STEPHENSON OPERATOR WITNESS: MORGAN SURFACE LOCATION SECTION: 8 TOWNSHIP: iON RANGE: 1SE FNL: 1017 FSL: FEL: FWL: 1511 ELEVATION(FT FROM MSL O) KELLY BUSHING: 70.00 DERRICK FLOOR: 69.00 GROUND LEVEL: 39.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 9. 625 9579.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NL~BER: PASS NUMBER: DATE LOGGED: JUNE-86 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 9403.0 9395.5 9372.5 9371.5 9359.5 9348.5 9348.0 9345.0 9344.5 9339.5 9333.5 9331.5 9323.5 9304.5 9299.0 9296.5 9295.0 9290.5 9285.0 9282.5 9272.0 9271.0 9269.5 9261.5 9259.0 9258.0 9252.0 9248.0 9242.0 9237.5 9234,0 9233.5 9230.0 9229,5 9227.5 9226.5 9224.0 9222.0 9206, 5 9201.5 9197.5 9196.5 9189.5 9187.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.5 88888.0 9403.0 9396.0 9371.5 9371.5 9358.5 9348.5 9347.0 9344.0 9344,0 9338.0 9334.5 9332.0 9323.5 9323.5 9305.0 9298.5 9296,0 9295.0 9290.0 9285.0 9282.5 9273,0 9270.0 9270.0 9262.5 9260.0 9257.5 9252.0 9246.5 9240. 5 9238.5 9233.5 9233.0 9229.5 9229.5 9227.0 9227.5 9222.5 9221.0 9203.5 9200.0 9197.5 9194.0 9189.0 9186.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9185.5 9178.5 9176.0 9175.0 9165.0 9161.0 9157.0 9153.5 9145.5 9142.5 9132.5 9127.0 9122.0 9119 0 9117 0 9114 0 9110 5 9107 0 9091 5 9087 5 9086,5 9083,0 9072.5 9071.5 9070.0 9069.0 9066.5 9062.5 9061.5 9057.5 9044.0 9024.5 9023.5 9014.0 9000.0 8996.0 8992.5 8990.0 8982.5 8975,0 8961.0 8960.0 8953,0 8951.0 8949,5 8945.5 8936.0 8930.0 8929.5 8927.5 8922.0 8919, 0 8917.0 8914.0 8912.0 8911.0 9184.0 9175.5 9163.0 9160.5 9153.0 9146.0 9134.0 9126.5 9121.5 9118.5 9113.5 9110.0 9106.0 9087.0 9071.0 9067.5 9062.5 9056.5 9044.0 9024.5 8995.5 8993.0 8975.0 8960.5 8954.0 8950.5 8929.0 8910.5 9177.5 9173.0 9157.5 9143.5 9117.5 9113.0 9093.5 9087.0 9084.5 9073.5 9070.5 9066.5 9062.5 9044.0 9024.5 9015.0 9001.0 8991.0 8983.5 8960.5 8950.0 8946.5 8936.0 8932.0 8929.0 8922.0 8919.5 8918.0 8914.0 8912.5 22-MAR-1999 08:58 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 8906.5 8907.0 8905.0 8904.5 8902.0 8902.5 8897.0 8896.5 8896.0 8896.5 8889.0 8890.0 8883.5 8883.5 8879.0 8878.5 8875.0 8874.5 8873.0 8873.5 8871.5 8871.0 8866.5 8866.0 8863.5 8864.5 100.0 99.5 101.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCOALASKA'S DS 01-29 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE DIL GAF~4A RAY, ALSO BASE PASS #1 SIGMA AND THE DIL GAMMA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUFIVlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9400.5 8859.5 RST 9411.0 8861.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REM_a~KS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1242431 O0 000 O0 0 1 I 1 4 68 0000000000 BSALRST PPK 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PA GE: 6 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) SIBF RST CU 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1242431 00 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1242431 O0 000 00 0 1 1 1 4 68 0000000000 SFNC RST CU 1242431 00 000 00 0 1 1 1 4 68 0000000000 SIGM RST CU 1242431 00 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1242431 O0 000 00 0 1 1 1 4 68 0000000000 CRRA RST 1242431 O0 000 00 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1242431 O0 000 00 0 1 1 1 4 68 0000000000 TENS RST LB 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1242431 O0 000 00 0 1 1 1 4 68 0000000000 GR DIL , GAPI 1242431 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9515.000 NBAC. RST -999 250 FBAC.RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999 250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT. FIL -999.250 CIRN. FIL -999 250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF. RST -999.250 TPHI.RST -999 250 SFFC.RST -999.250 SFNC. RST -999.250 SIGM. RST -999.250 DSIG.RST -999 250 FBEF. RST -999.250 CRRA.RST -999.250 GRCH.RST -999.250 TENS.RST -999 250 CCL.RST -999.250 GR.DIL 49.949 DEPT. 2507 000 NBAC. RST -999.250 FBAC. RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999 250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT. FIL -999 250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF. RST -999 250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST -999.250 SIGM. RST -999 250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST -999.250 GRCH. RST -999 250 TENS.RST -999.250 CCL.RST -999.250 GR.DIL 36.668 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~M_ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9399.5 8859.5 RST 9411.0 8861.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888 0 9410 5 9408 5 9405 0 9403 5 9401 0 9396.5 9392.5 9388.0 9385.0 9383.5 9380.5 9379.5 9377.0 9372,0 9367.5 9361.5 9359.5 9357.0 9351.5 9347.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.5 88888.0 9410.5 9408.0 9405.0 9403.0 9400,5 9396.0 9392.0 9383.5 9380.0 9370.5 9359.5 9347.0 9391.5 9388.0 9384.5 9379.0 9377.5 9367.0 9359.0 9355.5 9351.0 LIS Tape Verification Listing Schlumberger Alaska Compu ting Center 22-MAR-1999 08:58 PAGE: 9345.0 9340.5 9332.0 9330 5 9324 0 9321 0 9315 5 9314 5 9304 5 9304 0 9302 0 9299 0 9296.0 9295.0 9292.0 9291.0 9289.0 9282.0 9279.5 9275.5 9273.5 9268, 0 9265.0 9264.5 9262,5 9259.5 9259.0 9251.5 9250.0 9249.0 9240. 5 9239.0 9234.0 9233.5 923 O. 0 9227.0 9221.5 9218.5 9215.0 9212,0 9208.5 9205.0 9196.5 9195.5 9193.0 9185.0 9179.0 9173,5 9172,0 9162.5 9161.5 9157.0 9153.5 9145.5 9145,0 9338.5 9332.5 9330.5 9320.5 9314.5 9303.0 9298.5 9296.0 9290.0 9289.0 9279.0 9265.5 9259.5 9250.5 9237.5 9233.5 9211.5 9194.0 9184.0 9170.0 9160.5 9153.0 9146.0 9344.5 9324.0 9315.0 9304.5 9301.5 9295.0 9290.5 9282.0 9277.0 9273.5 9269.0 9265.0 9263.5 9260.0 9252.5 9249.0 9241.5 9233.0 9230.0 9227.5 9220.5 9217.5 9213.5 9210.5 9205.5 9203.0 9195.0 9192.0 9177.5 9171.0 9162.5 9157.5 9145.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 9132.5 9128.0 9127.0 9120.5 9119.0 9117.0 9110.5 9107.5 9106.5 9101.0 9096.5 9091.5 9088.0 9087.0 9085.0 9083.5 9077.5 9074.0 9072.5 9072,0 9070.5 9066.0 9062.0 9053.5 9050.5 9043.5 9041.0 9038 5 9033 0 9028 0 9025 0 9024 0 9018 5 9014 0 9011 5 9002 0 9000 0 8994.5 8991.0 8988,0 8983.0 8980,5 8979.5 8972.0 8969.0 8962.0 8956.0 8954.0 8949.5 8945.5 8943.0 8937.5 8936.0 8934.0 8931.0 9126.5 9118.5 9106.5 9087.0 9084.5 9077.0 9074.0 9071.0 9041.0 9039.5 9028.5 9024.5 9011.0 8999.0 8994.0 8991.5 8978.5 8961.0 8954.0 893 6.5 8932.0 9133.5 9128.5 9121.0 9117.5 9113.0 9109.0 9103.5 9098.0 9093.5 9087.5 9084.5 9073.5 9070.5 9066.0 9062.5 9054.0 9050.5 9043.5 9033.5 9025.0 9019.5 9014.5 9003.0 8989.0 8983.5 8980.5 8972.0 8969.5 8956.5 8950.0 8946.5 8943.0 8936.0 8932.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 10 8930.0 8927.5 8926.5 8922.5 8918.0 8917.0 8912.0 8911.5 8907.5 8903.0 8902.5 8897.5 8894.0 8891.5 8888.0 8887.5 8887 0 8886 0 8884 5 8883 5 8879 5 8874 0 8873.0 8872.0 8869.0 8867.0 8864.5 8864.0 100.0 $ 8929.0 8926.0 8917.5 8910.5 8907.5 8902.5 8897.0 8890.5 8887.5 8886.0 8883.5 8879.0 8873.5 8871.0 8868.5 8866.0 8864.0 99.5 8929 8922.5 8918.0 8912.5 8902.5 8895.0 8888.0 8886.0 8883.5 8873.5 8865.0 101.0 REi~ARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 11 TYPE REPR CODE VALUE .............................. 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1242431 O0 000 O0 0 2 1 1 4 NBAC RST CPS 1242431 O0 000 O0 0 2 1 1 4 FBAC RST CPS 1242431 O0 000 O0 0 2 1 1 4 SBNA FIL CU 1242431 O0 000 O0 0 2 1 1 4 SFNA FIL CU 1242431 O0 000 O0 0 2 1 1 4 SBFA FIL CU 1242431 O0 000 O0 0 2 1 1 4 SFFA FIL CU 1242431 O0 000 O0 0 2 1 1 4 TRAT FIL 1242431 O0 000 O0 0 2 1 1 4 IRAT FIL 1242431 O0 000 O0 0 2 1 1 4 CIRNFIL 1242431 O0 000 O0 0 2 1 1 4 CIRF FIL 1242431 O0 000 O0 0 2 1 1 4 BSAL RST PPK 1242431 O0 000 O0 0 2 1 1 4 SIBF RST CU 1242431 O0 000 O0 0 2 1 1 4 TPHI RST PU-S 1242431 O0 000 O0 0 2 1 1 4 SFFC RST CU 1242431 O0 000 O0 0 2 1 1 4 SFNC RST CU 1242431 O0 000 O0 0 2 1 1 4 SIGM RST CU 1242431 O0 000 O0 0 2 1 1 4 DSIG RST CU 1242431 O0 000 O0 0 2 1 1 4 FBEF RST UA 1242431 O0 000 O0 0 2 1 1 4 CRRA RST 1242431 O0 000 O0 0 2 1 1 4 GRCH RST GAPI 1242431 O0 000 O0 0 2 1 1 4 TENS RST LB 1242431 O0 000 O0 0 2 1 1 4 CCL RST V 1242431 O0 000 O0 0 2 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. SFNA.FIL IRAT. FIL SIBF. RST SIGM. RST GRCH. RST 9411.000 NBAC. RST 2222 995 FBAC.RST 21.868 SBFA.FIL 43 908 SFFA.FIL 0.526 CIRN. FIL 1 107 CIRF. FIL 32.006 TPHI.RST 24 834 SFFC.RST 15.977 DSIG.RST 1 364 FBEF. RST -999.250 TENS.RST 1088 000 CCL.RST 3543.475 SBNA.FIL . 19.828 TRAT. FIL 2.167 BSAL.RST 15.855 SFNC.RST 64.846 CRRA.RST 0.049 52.464 O. 972 28.339 16. 677 1. 914 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 12 DEPT. 8859.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST 55.446 TENS.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC. RST -999.250 FBEF. RST -999.250 CCL.RST -999.250 SRNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST -999.250 CRRA.RST -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCR~ENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 1242431 O0 000 00 0 3 1 1 4 68 0000000000 SBFA RSAV CU 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 1242431 00 000 O0 0 3 1 1 4 68 0000000000 TRAT RSAV 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 1242431 O0 000 00 0 3 1 1 4 68 0000000000 CIRNRSAV 1242431 00 000 00 0 3 1 1 4 68 0000000000 CIRF RSAV 1242431 00 000 O0 0 3 1 1 4 68 0000000000 BSALRSAV PPK 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 1242431 O0 000 00 0 3 1 1 4 68 0000000000 SFFC RSAV CU 1242431 O0 000 00 0 3 1 1 4 68 0000000000 SFNC RSAV CU 1242431 O0 000 00 0 3 1 1 4 68 0000000000 SIGM RSAV CU 1242431 00 000 00 0 3 1 1 4 68 0000000000 DSIG RSAV CU 1242431 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 1242431 00 000 .00 0 3 1 1 4 68 0000000000 CRRA RSAV 1242431 O0 000 00 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1242431 00 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 14 ** DATA ** DEPT. 9411 . 000 NBAC.RST 2054. 431 FBAC. RST SFNA.RSAV 22. 047 SBFA.RSAV 41 . 753 SFFA.RSAV IRAT. RSAV 0.520 CIRN. RSAV 1.106 CIRF. RSAV SIBF. RSAV 32. 455 TPHI . RSAV 25. 709 SFFC. RSAV SIGM. RSAV 15.917 DSIG.RSAV 1.502 FBEF. RSAV GRCH. RST - 999 . 250 3512. 367 SBNA.RSAV 19. 796 TRAT. RSAV 2 . 145 BSAL. RSAV 15 . 803 SFNC. RSAV 63 . 760 CRRA. RSAV 53. 875 0.980 29. 606 16. 928 1. 929 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9447.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): STOP DEPTH 8806.0 28-JUN-98 8Cl-205 9450.0 9454.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 15 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8860.0 9411.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BORBHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 9. 625 9579.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCED FLUIDS 60.0 188.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN WITH SWS BHC OF JUNE 8, 1998 PUMPING 270 BBL OF CRUDE WERE PUMPED TO FLUID PACK THE WELL 20 BBL OF CRUDE WERE PUMPED WHILE LOGGING FIRST TWO PASSES 100 BBL OF BORAX WERE PUMPED AND THEN CHASED WITH 120 BBL OF CRUDE BEFORE BORAX PASSES WERE LOGGED WITH A TOTAL OF 30 BBLS OF CRUDE BEING PUMPED DURING LOGGING. ALL PASSES WERE MADE WITH A FLOWRATE OF 0.5 BPM. THIS FILE CONTAINS THE RAW DATA FOR PASS #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PA~E : 16 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SBT TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1 F/HR 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NPHV PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 1242431 O0 000 O0 0 4 1 I 4 68 0000000000 RCFR PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RCAK PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PS1 1242431 O0 000 O0 0 4 I 1 4 68 0000000000 FPHVPS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELD CODE (HEX) FPDE PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 BMCU PS1 UA 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 GDCU PS1 MA 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 EXCU PS1 UA 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 XHV PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 XPSV PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 X~2V PS1 V 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PSi 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 RXAKPS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PSl MA 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PS1 PPK 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNPS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PS1 CU 1242431 O0 000 O0 0 4 I 1 4 68 0000000000 SBFA PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 1242431 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) ....................................................................................... SIGM PS1 CU 1242431 SIBF SIG CU 1242431 SIGM SIG CU 1242431 TRAT PS1 1242431 TRAT SIG 1242431 TRAT FIL 1242431 GR PS1 GAPI 1242431 RDIX PS1 1242431 CRNI PS1 KHZ 1242431 CRFI PS1 KHZ 1242431 CTM PS1 DEGC 1242431 XTM PS1 DEGC 1242431 TAV PS1 1242431 FICU PS1 AMP 1242431 CACU PS1 AMP 1242431 BUST PS1 1242431 BUSP PS1 1242431 RSXS PS1 1242431 TPHI PS1 PU 1242431 TPHI SIG PU 1242431 CCLC PS1 V 1242431 RSCS PS1 1242431 00 000 O0 0 4 1 1 4 68 0000000000 O0 000 00 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 00 000 O0 0 4 1 1 4 68 0000000000 O0 000 00 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PS1 TPHI.PS1 9447.000 1468.393 0.441 -12 191 0 000 1 887 161 621 30 399 60 875 5 069 0 000 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 20.037 87.402 2.500 -999.250 CS.PS1 1642.336 TENS.PSi 783.000 NPHV. PS1 NSCE. PS1 2.261 CRRA.PS1 1.977 NSCR.PS1 CHV. PS1 201.339 CPSV. PS1 5.060 CP2V. PS1 RCFR.PS1 0.000 RCLC.PS1 0.000 RCRC. PS1 RTDF. PS1 0.000 FPHV. PS1 1535.646 FPDE. PS1 FSCR.PS1 -0.014 AQTF. PS1 0.441 SF6P. PS1 BMCU. PS1 33.984 GDCU. PS1 60.012 EXCU. PS1 FBEF. PS1 60.086 NPGF. PS1 1.009 FPGF. PS1 BSPR.PS1 1.156 MARC. PSi 0.000 XHV. PS1 XP2V. PS1 12.114 XI~2V. PS1 -12~368 RXFR.PS1 RXRC. PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRF. FIL -999.250 DSIG.PS1 -999.250 FBAC. PS1 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA.PS1 SBNA.PS1 -999.250 SBFA.PS1 -999.250 SFNA.SIG SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS1 SFFC. PS1 -999.250 SIGM. PS1 -999.250 SIBF. SIG TRAT. PS1 -999.250 TRAT. SIG -999.250 TRAT. FIL RDIX. PS1 157412.000 CRNI.PS1 448.187 CRFI.PS1 XTM. PS1 85.938 TAV. PS1 94.744 FICU. PS1 BUST. PSi 3.000 BUSP.PS1 3.000 RSXS.PS1 TPHI.SIG -999.250 CCLC.PS1 0.029 RSCS. PS1 1506.349 -0.232 12. 143 0.000 1499.177 145. 468 3. 945 1. 001 200.370 O. 000 26. 991 -999.250 - 999,250 - 999. 250 - 999,250 - 999. 250 -999.250 - 999. 250 -999.250 226. 746 2. 363 8878. 000 8459. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 19 DEPT. 8806.000 CS.PS1 NPDE. PS1 1471.444 NSCE.PS1 AQTM. PS1 0.441 CHV. PS1 CM2V. PS1 -12.231 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE.PS1 1.736 FSCR.PS1 HVPV. PS1 162.891 BMCU. PS1 NBEF. PS1 32.811 FBEF. PS1 BSTR.PS1 60.468 BSPR.PS1 XP5V. PS1 5.082 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL.PS1 11.798 BSAL.SIG CIRN. FIL 0.976 CIRF, FIL IRAT. PS1 0.540 IRAT. FIL SFFA,PS1 28.199 SBNA.PS1 SFFA.SIG 0.505 SBNA.SIG SFFA.FIL 27.918 SBNA,FIL SFNC. PS1 25.986 SFFC,PS1 SIGM. SIG 0.497 TRAT. PS1 GR.PS1 51.230 RDIX. PS1 CTM. PS1 83.008 XTM. PS1 CACU. PS1 2.485 BUST. PSi TPHI.PS1 31.997 TPHI.SIG 1814.482 TENS.PSi 2.273 CRRA.PS1 201.581 CPSV. PS1 0.000 RCLC. PS1 0.000 FPHV. PS1 0.055 AQTF. PS1 37.187 GDCU. PS1 60.698 NPGF. PS1 1.098 MARC. PS1 12.109 X~2V. PS1 0.000 RXAK. PS1 7.073 CIRN. PS1 1.603 DSIG.PS1 0.541 NBAC. PS1 48.854 SBFA.PS1 3.924 SBFA.SIG 48.273 SBFA.FIL 27.318 SIGM. PS1 1.123 TRAT. SIG 174919.000 CRNI.PS1 81.999 TAV. PS1 3.000 BUSP. PS1 1.228 CCLC. PS1 1011.000 NPHV. PS1 1.850 NSCR.PS1 5.040 CP2V. PS1 0.000 RCRC. PS1 1528.322 FPDE. PS1 0.441 SF6P. PS1 59.859 EXCU. PS1 1.007 FPGF. PS1 0.000 XHV. PS1 -12.383 RXFR.PS1 0.000 SHCU. PS1 0.973 CIRF. PS1 -1.286 FBAC. PS1 2161.625 SFNA.PS1 47.563 SFNA.SIG 3.780 SFNA.FIL 43.750 SIBF, PS1 26,905 SIBF. SIG 0.019 TRAT. FIL 457.011 CRFI.PS1 94.974 FICU. PS1 3.000 RSXS. PS1 -999.250 RSCS.PS1 1506.349 O. 474 12.129 0.000 1499. 559 145. 843 2.998 1. 001 200.45O 0.000 26.276 1.579 3486. 784 25.543 0. 573 26.226 26.214 2. 451 1.125 247,045 2.354 8878. 000 84 63. 000 ** END OF DATA ** **** . FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 20 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... RST $ LOG HEADER DATA DATE LOGGED: 9449.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH .......... 8803.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 28-JUN-98 8C1-205 9450.0 9454.0 8860.0 9411.0 TOOL NUMBER CGRS-A RST-A 9.625 9579.0 PRODUCED FLUIDS 60.0 188.0 THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 21 BLUELINE COUNT RATE SCALES SBT BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: TIED IN WITH SWS BHC OF JUNE 8, 1998 PUMPING SUMMARY: 270 BBL OF CRUDE WERE PUMPED TO FLUID PACK THE WELL 20 BBL OF CRUDE WERE PUMPED WHILE LOGGING FIRST TWO PASSES 100 BBL OF BORAX WERE PUMPED AND THEN CHASED WITH 120 BBL OF CRUDE BEFORE BORAX PASSES WERE LOGGED WITH A TOTAL OF 30 BBLS OF CRUDE BEING PUMPED DURING LOGGING. ALL PASSES WERE MADE WITH A FLOWRATE OF 0.5 BPM. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2 F/HR 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS2 LB 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NPHVPS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS2 V 1242431 00 000 00 0 5 1 1 4 68 0000000000 NSCE PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS2 S 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CP5V PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 1242431 O0 000 O0 0 5 1 I 4 68 0000000000 CM2V PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RCAK PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 1242431 00 000 00 0 5 1 1 4 68 0000000000 AQTF PS2 S 1242431 O0 000 00 0 5 1 1 4 68 0000000000 SF6P PS2 PSIG 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS2 MA 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS2 UA 1242431 O0 000 O0 0 5 I 1 4 68 0000000000 FBEF PS2 UA 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 1242431 00 000 O0 0 5 1 1 4 68 0000000000 FPGF PS2 1242431 00 000 O0 0 f 1 1 4 68 0000000000 BSTR PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 1242431 00 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 1242431 O0 000 O0 0 ~ 1 1 4 68 0000000000 XHV PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 1242431 O0 000 00 0 ~ 1 1 4 68 0000000000 X~f2V PS2 V 1242431 00 000 00 0 5 1 1 4 68 0000000000 RXFR PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS2 1242431 O0 000 00 0 5 1 1 4 68 0000000000 RXRC PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RXAK PS2 1242431 00 000 00 0 5 1 1 4 68 0000000000 SHCU PS2 MA 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1242431 00 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Compu=ing Center 22-MAR-1999 08:58 PAGE: 23 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) NBAC PS2 CPS 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1242431 O0 000 O0 0 5 I I 4 68 0000000000 SBFA SIG CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS2 CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS2 1242431 O0 000 00 0 5 1 1 4 68 0000000000 TRAT SIG 1242431 00 000 00 0 5 1 1 4 68 0000000000 TRAT FIL 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KHZ 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 KHZ 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 1242431 00 000 00 0 $ 1 1 4 68 0000000000 XTM PS2 DEGC 1242431 00 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 1242431 O0 000 O0 0 5 I 1 4 68 0000000000 CACU PS2 AMP 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS2 V 1242431 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS2 1242431 O0 000 00 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9449.000 CS. PS2 1982.379 TENS.PS2 928.000 NPHV. PS2 NPDE.PS2 1471.521 NSCE. PS2 2.315 CRRA.PS2 1.939 NSCR.PS2 AQTM. PS2 0.661 CHV. PS2 200.854 CP5V. PS2 5.050 CP2V. PS2 CM2V. PS2 -12.270 RCFR.PS2 0.000 RCLC.PS2 0.000 RCRC.PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 1535.646 FPDE.PS2 FSCE. PS2 1.774 FSCR.PS2 0.645 AQTF. PS2 0.661 SF6P. PS2 HVPV. PS2 162.842 BMCU. PS2 37.793 GDCU. PS2 60.668 EXCU. PS2 NBEF. PS2 33.449 FBEF. PS2 64.856 NPGF. PS2 1.002 FPGF. PS2 1501. 466 -0. 096 12.173 O. 000 1498. 796 145. 980 2. 762 O. 997 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 24 BSTR.PS2 52.193 BSPR.PS2 1.166 MARC. PS2 XPSV. PS2 5.069 XP2V. PS2 12.114 ~2V. PS2 RXLC. PS2 0.000 RXRC. PS2 0.000 RXAK. PS2 BSAL.PS2 -999.250 BSAL.SIG -999.250 CIRN. PS2 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS2 IRAT. PS2 -999.250 IRAT.FIL -999.250 NBAC. PS2 SFFA. PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS2 -999.250 SFFC.PS2 -999.250 SIGM. PS2 SIGM. SIG -999.250 TRAT. PS2 -999.250 TRAT. SIG GR.PS2 203.409 RDIX. PS2 177115.000 CRNI.PS2 CTM. PS2 83.984 XTM. PS2 82.031 TAV. PS2 CACU. PS2 2.480 BUST. PS2 3.000 BUSP.PS2 TPHI.PS2 -999.250 TPHI.SIG -999.250 CCLC. PS2 DEPT. 8803.500 CS.PS2 1876.840 TENS.PS2 NPDE. PS2 1470.987 NSCE. PS2 2.279 CRRA.PS2 AQTM. PS2 0.441 CHV. PS2 201.339 CPSV. PS2 CM2V. PS2 -12.231 RCFR.PS2 0.000 RCLC. PS2 RCAK. PS2 1.000 RTDF. PS2 0.000 FPHV, PS2 FSCE. PS2 1.766 FSCR.PS2 0.391 AQTF. PS2 HVPV, PS2 163,053 BMCU. PS2 38.203 GDCU. PS2 NBEF. PS2 34.120 FBEF, PS2 60,816 NPGF. PS2 BSTR.PS2 50.635 BSPR.PS2 1,082 MARC. PS2 XPSV. PS2 5.083 XP2V. PS2 12.108 X~2V. PS2 RXLC. PS2 0.000 RXRC.PS2 0.000 RXAK. PS2 BSAL.PS2 3.890 BSAL.SIG 8.208 CIRN. PS2 CIRN. FIL 1.269 CIRF. FIL 2.502 DSIG.PS2 IRAT. PS2 0.553 IRAT. FIL 0.553 NBAC. PS2 SFFA.PS2 19.118 SBNA.PS2 48.285 SBFA.PS2 SFFA.SIG 0.276 SBNA.SIG 3.870 SBFA.SIG SFFA.FIL 19.640 SBNA.FIL 49.383 SBFA.FIL SFNC. PS2 15.994 SFFC. PS2 16.474 SIGM. PS2 SIGM. SIG 0.351 TRAT. PS2 0.917 TRAT. SIG GR.PS2 36.567 RDIX. PS2 194603.000 CRNI.PS2 CTM. PS2 83.496 XTM. PS2 82.747 TAV. PS2 CACU. PS2 2.480 BUST. PS2 3.000 BUSP.PS2 TPHI.PS2 17.720 TPHI.SIG 0.951 CCLC. PS2 0.000 -12.328 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 456.280 95.031 3.000 0.029 1005.000 1.782 5.060 0.000 1535.646 0.441 60.318 0,997 0.000 -12.374 1.000 1.268 -0.361 2358.432 43.548 3.336 40. 964 16. 664 O. 013 453.113 94.955 3.000 -999.250 XI4V. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS. PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS. PS2 200.612 0.000 23.089 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 235.319 2.368 8878.000 8463.OO0 1506.349 0.410 12.173 0.000 1501.161 146. 901 2. 814 0.997 200.418 0.000 24.650 2.542 3437.778 20.461 0.418 20.731 23.488 2.814 0.924 254.214 2.369 8878.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 99/03/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-MAR-1999 08:58 PAGE: 25 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC TAPE NAME : 98519 CONTINUATION # .. 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, DS 01-29, PRUDHOE BAY, API# 50-029-21604-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/19 ORIGIN : FLIC REEL NAME : 98519 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA, DS 01-29, PRUDHOE BAY, API# 50-029-21604-00 aLRSKA CO~PU?ING CENTER ~m~mmmmmmmm~mmmmmmmmmmm~m~mm~ *--.-----.SCHbUMBERGER .j. . I8 ~a~e ver.t, ficatf, on [,lstino c lum - eroer co?, utin : Cemter S~RVtCE NA~t~ : ~DIT O~IC'[~ ! FL,~C RFEr. ~A~ : e4399 P~EVIOU$ ~E~L CO~"E~T : &~C~ ALASKA INC, DS 01-29, PRUDHOE S~ ,50-0~9-21~04-00 SERVICE N~'~ : EDIT O~I~I~ t ~LIC TAPF ~A~E : ~439q CONTINd~TION. # : 1 P~EVIO!J$ TAPE : CO~ES~T : ARCO T~PT ~EaDER · . ~ ". OP~R.ATO~.. .: LOGGING CO~P.AMY: · ':' TAPE CR~A.TION DAT~: JOB NII~I~ER~ ..'. ... ~ . · SURFACE 50C~TIO~ · '.' SFCTI. ON: 800 92 60 00 A.R¢O. ALASKA, N~ · 23-D~C,94 · 94~99 .'. . FSD{ ELEVAT.IONCFT.TROM...MSb.0)· KELGY'~USH~NG':' DERRICK rL'OOR: GROtI~D''LEV~'b'~ ..... '# W~bL CASING RECORD ~ND STR.I~G ~RD PRODUCTION ' 69,00 9, 7.0 OoE~'.~'OGE" CASING DRILLERS' CASING· BIT SIZZ'¢I~) 8I.ZE" {iN.) DEPTH (FT) wEt:GHT..iLB/rT) 1'3,375' "'248~ 0'. .7'2~'00 -9.,'625 '957 '~0 47'00 5'500 31.0 t7.'00 .# CURVE SM.IrT DAT~ -. ALL PASSE& TO STANDARD.('M£A. SU~ED D~PTH) . I'~ Ta~e ~erificat..ton T.,isti~ CblU~berger Alaska Computin~ Center 18-JA~{-1995 08~04 .:' · . BASELINE DEPTH· 94 94 94 94 93 93 93 93 93 9m 9~ 99_ 9~ 9m 9~ 91 9!. 91 91 91 9430,0 14,5 14.0 03, ~ 03, . 70,5 4~,5 33.5 3~,0 24,5 g6 0 8.9 5 71 0 34 0 28 O. 2? 5 62,0 60,0 53.5 4~ 0 44 0 .0 9118 9O8.8. 90?0 .~0.6'.3. 9062 9024. 9'00 ! 89'96 899:1' 80'4 892 8o.2 89.1 ~90 :.10 5 5 0 0 ~5 5 ' 0 '.,,.~ I'0 8'0 $,0 8, .5 0,5. 1.,0 0,0 0,.0. -- ..... ---EOUIVALENT UNSHIFTED GRCH TDTP 8888 88888 9430,9 9414,0 9413.5 9403,0 9371,~ 9.344,$ 933~,0 9323,0 9295,0 9288.0 9270'0 9227,0 91.60,0, 9152,5 914.7 0 9331,0 9323,5 9233.0 9227,5 9' o.o ..9062.:g...S.:..' 9024,5 8995'5 '8991.'0 8~76,5 892~,0 .. 8902.5. 98.5. 9062,5 9o'ol .o. 8990."5 8948,0 89'29,'0 89'2.0 8oo ,.. o. ..i0.1~0 DEPTH---------- PAGE~· 2 chlumberqer Alaska Co.'Pt)Limbo Center 18-JAN-1995 08:04 T~IE I.~-~FOR~ATIO}4 PERTAINING TO THE OPEN HOLE GR SUCH AS ~U~ f'~"i~4~E~, P.~SS ~.IU~BER LOGGING DATE AND LOGGING CO~tP~r,~'~' ,'~A6 ~nT P~OVIDE6 WITH T~E TAPE SUPPLIED BY TH~ C L I E r.~ ~r, TO OP~.~ ~iOLE GR.A~ID C~S~D HOb~ S~GM T~ OPeN HOLE ~R. ALb UTHFR TDTP CUgV~S W~RE CARRIED WITH THE 8IGM SHIFTS ,. F~b~ NA~E : ~DTT V~RSION : O0~COi M~X RFC STZ~ ~ ~0~4 FTLF TYPE : [.,O FIL~ HEADMR · ' FILM NUMBER~ 1 ..' EDITED CURVES .:.'..'.~ePth shifted .and cl~poed curves for each Pass .~n separate ~iles,~ : P~$~ N'UMBER~ . D~P,H' IMCR~MENT, 0.'5000 '"' G TOOL CoDE START DEPTH STOP DEPTH .... . . .. CRCH 94.31.0 ' .8900..0 ':" ~ .... :.;~i:,.~ .p~'~ :.,. ........... . ..... ~4S'.,o 8¢oo'oo ·. ~ ' ": .. · ",'. .' ."....".'.. :'.'~ '.' · '... : ..' · .... . · , ..'.u' · -'~. ': .: '.' .. · . . # ..:CUR~E $~I~T.'~..a'T~.'-..P~SS..'TO.¢~,SS..."¢','.~AS.~.~'~PI~) .... ..:.. BASE[,INE.C.URVE FOR.SHIFTS · .. # .. .. ' ----------.~aUIvAb~N? - U'N~F~gO .: ~E)tAPK.$~, THIS FILE CONTAIN8 PASS #·l OF THE'TDTP,. NO PASS.TO PASS $~)IFTS WEDE APPLIED TO THIS DATA. $ "LIS FORMAT· DATA IS ~a~e ver~.f.t, cat~on Listin~ Chlumherger AlasKa .~o~r3utin~ Center ].~-JAN-19q5 0B:04 PAGE: 4 TIF,..,[,k: TYP~ .' ............................................... ............ '"'"'"'ii' " ........ '""'"'"' ~' D.S. 01-29 Well Name API~' 50-029-91604-00 APl Serial ~umber FL 1017' f'~h & 1511' FWb Field ~ocation $~C~ 8 Section TOW~! ~0~ Township RANt l. Sf Ranoe COU~' NORTH SLOPE County S~A~' ALASKA State or Province NATT USA Nation $~ 4~8~41 Service Order Number pnA? ~s5 Permanent datum EVD ~T u, Elevation o~ Permanent Datum b~F ~K8 ~og Measured. From A~D ~T ?0, Above Permanent'Datum E~S ~I 7o, Elevat$on o~ Kelly Bushin~ EDF ~T 69. E'levatl'on o~ Derric~ Floor ECL ~T 39,7 'Elevation o~.~round ~evel T~D ~T 9563.. Total Depth'- Driller TDb FT 9452. 'TOtal Depth.- ~oqqer BtI FT 94~$, Bottom boq Interval TI.,I Fr $900, Top..Loq ~IfiterYal.. DFT S~AwATER/2ORAX Drilling Fluid :Type. .s?~ nsCF 40 Surface Temperature · . ~"T DEG[ .[~6.. Bottom.Hol. e.'.'~emper~ture'. DEF! $IG~ Sigma .(.Neutron Capture Cross Section) TPH~ T'DT Porosity S~HF B. orehole Si6ma - far detector 'S~H~' ~orehoIe 'Sigma '-'Near detector " STGC Siama Correction '..' $IB~ TPAT BlC~ FBAC .TCA~ 'TCFO 'TSC~ Corrected ~or'ehole Sigma ~ation Totei.~ear to Far counts Standard ~teviatiom of Sigma 8acK,round Count Rates -..Near' Detector' Bae~oround Count Rate - Far Detector Total counts'analyzed - near detector (TDT¢) Total. counts analyzed -'far detector (TDTP) Total. capture counts - Near detector ota] capture Counts - far dectector _oral Selected COunts -. ~ear Detector I8 Tan..e Vertti,¢at~.o~ Listi~o Chlumber~er AlasKa mom[~t~n'~. .~.,~ ~., Center 1. ~-J~N-~.gg5 0~:04 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 1SC? Total Selected Coont~ - Par Oetectos I))N~ Tnelastlc count rate - near ~etector I~)F9 Tnelastic count rate - far detector G~Cw Ca~{0a Ray in Casfn~ T~N~ Surface Tension CCL CCL ~ol!tude G~ ~PI-Corr~cte~ Gamma ~av PAGEI ~* nATA FORUAT SPRCIF~C~TTUN RECORD *~ TYPE REPR CODE VALUE 1 ~6 0 2 66 0 3 7] q2 4 &6 5 66 6 73 7 ~5 ~ 65 11 66 13 66 0 14 65 FT i5 66 68 i6 ~6 .... 9 ......... 66. . 0 . .... ** SE~ TYPE - CHAN *$ .. ' NRME $£RV UNIT SERVIC~ API ~P! API ~PI FI'BE NUMB ·NUMB SIZE. REPR. PROCES&'.. ID ~RD.E~ # LOG TYPE CLASS MOD NUmb SRMP E~EM CODE (HEX..) DF'pT " 'F~ 48~241 00' 000 00' 0 1 ~ .l 4 68 0000000000 SIG~ TOTP C~. 48~241 00 000 00 0 ~ 1 ! 4' 68 0000000000 TDH! TbTP PU-S 48824! 00 fi00 00 0 ! ! 1 4 68 .0000000000 SRHF TgrP CU 45P241 0o 000 00 0 1 ~. I 4 68 0000000000 8~ TOTP CT.~ 4892~ 00 000 00 0 1 ! ! 4 68 00'00000000 $~Gc 'T0~P CU 48~24,1 O0 000 O0 0 ! ~. 1 '4 68 .0000000000 818~ T~P CU 48~241 00 000 00 0 ~ 1. I 4 68 0000000000 ' .T~AT TDTP 48~2al 00 000 00 0 1 ! ! 4 ~8 0000000000 '~$I TOTP CU 489241 ~0 000 00 0 ~ ~ I 4 68 0000000000 BRCK TOTP CPS aB~2al 00 000 00 0 i ! 1 4 ~8 0000000000 F~AC ?[)TP CPS 4~2a! 00 000 00 0 ! I ~. 4 68 '0000000000 TCA~ TDTP CPS 4B7241 O0 000 00 0 1 .1 ! 4 68 '0000000000 · . IS Ta~e verlf1¢at~on ?.,istln~ ChlUmberqer A!as~a Comp,~t~n.~ ~emter 18-JA~!-1995 08:04 ..; N U"~!IT ~E~¥ ~ AP·X APl APl APT FILE NUmB NUMB SIZE REPR P TD Okn~ , DOG TYPE CL~$$ "OD NUMB SA~P E~EM CODE (HEX) '~;~ ......... ~[JTP ~ ........... 4.8,2~1 ~ ........000 ~ ............. 0 1 ~'' ..... 1 '' .... 4 '''''68 .......... 0000000000'''''' O0 000 O0 0 1 1 I 4 68 0000000000 TCND TDTP CPS aSf1241 TCF~ TDTP CPS 48~241 TSCN TDTP CPS ~8~2a3 T~C~ TPTP CPS 48~2~1 T~N~ TDTP LR 4.~824! CCL Tg~P V 45e241 90 0~0 UO 0 I 1 1 O0 000 O0 0 1 I 1 O0 000 O0 0 1 1 1 On 000 O0 0 1 1 O0 000 O0 0 I 1 oO 000 O0 0 1 1 un 000 O0 0 1 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 O000000000 4 68 0000000000 DFPW. °519.000 $ICM.TDTP $~' ' .TDTP ~909 250 BACK.,TDTP TCAF.TDTP 949~250 TC~D,TDTP TSCW,~DTP ~999.2~0 INgD.TDTP TEN~.TDTP -999.250 CCh,TDTP DEPT. 8744.0.00 SI~M:.TDTP SBH~.TDTP -999.250 SIGC.TOTP ~SDST.TQTP -999.2~0 BACK.TDTP TCAV.T~TP -999.250 TCND',TDTP TSCW.TDTP -999o25() INND:,.TDTP T~NS..TDTP -9qq.~50 CCb. TDTP -999 250 TPHI.TDTP -q99 250 $IBH,TDT~ -999 250 'FBAC,TDTP -99q 250 TCFD,TDTP -99.9 250 INFD.TDT~ -g99 ~50 GR,O" -99~o250 TpHI.,~D?p -999.250 SIBH,TDTP -999.~50 'FB~C.,TDTP -999.250 TCFD.,TDTP -999.250 INFD.TDTP -999..250 GR,OH 999,250 SBHW.'TDTP 999,250 TRAT.TDTP 999,250 TCAN..TDTP. 999,250 TSCN.'TDTP 999,250 .GRCH,TDTP 46,605 =999,.250 -999,'25'0 -999,'250 97.,~02 TRAT~?DT.P 'TCAN."TDTP .TSCN.,'TDTP.. GRCH..'.TDTP ** ...E~D OF DATA· ** ....... . ... '999,250 -~99,.250 "99.,'250 -999',250 "gg .; so ,g~9,2:$0 g~250 -99g.:.250 -999.,250 FIbE NA~E : EDIT SE~VIC£ : F51C VERSIOH : O'O1CO1 · ' · DATF : 94/12/23 MaX R~C SIZE· : 1024 F'IL~ TYOE : LO Z8 ~ane verificat~on [..ist.~.nq Chlu~herqer AlasKa C.o~putlr~¢] Center l~-JAN-~995 OS:n4 .PAGE= .7 EnI~ED ~U~V~S Depth shifted an~ cl~'pPed curves for each Pass ~ separate f~les~ FTLF $1JU~ARY LDWG TnOl, CODE TO .,. P START DEPTH .... 9445,0 STOP DEPTH 8900,0 8900,0 CURVE 8~4IFT D.~TA - PASS TO PASSCMEASURED DEPTH) RASELIME CURVE FOR SHIFTS 5DWC CU'PVE CODE: GRCH PASS NU~B~R: 1 AASELfhE D~PTH 5A,.,5... · 30,~ ~437,5 9434.5 9433,.5 9430,5 9a25.,5 9421.5 9418 5 9~17 ~ 9414 5 941~ 5 9406 5 9~02 5 9401 5 9~97 5 9394'~ 9393:~ ----------E~UIVALENT .UNS.HZFTED DEPTH'-'-'--.-' ~CH T. DTP 94S4,5 .... ' "' "" 944~.0 94.3~,5 943~o0 9433,5 94~5,5 9421.0 9417.0 9413,5. 9401.5 9397.0 9393.0 9434.5 9430.0 9418.0 9414.5 9406.~ 94.0~,0 9394.0 ~S ~a~e Verification chlUm.h, er,~,.r ^lasKa Co~:~utfn..q. Center l~-JAh~-~.9g5 OB:04 PAGEg g3go 5 9.3B?.5 9378 5 9~77:5 997~.5 9370.5 9~69.~ 9366.5 9~65.5 ggSg' .5 934g.~ 9~41.5 ~314.5 9~10 5 · 9~06.5 · 9~86.5 9282,5 9~7R.5 9~77.5 9~74 5 9773 5 9~70 5 9~69 5 9~66 5 9~65 5 926] 5 9~57 5 9250 5' 9246 5 9239 5 9~34 5 99295 9~25 g 9~21 5 9~I0 5 9705-5 9202 5 9201 5 9~9B 5 91.97 5' 1.94,5 93Bq.5 9385.n 938!.0 937&.5 9373.5 9365.o 9361.5 9353.5 9950.0 9349.0 9337.5 9~77.5 9~74.5 9270.0 9~66.0 .9~6~.,5 . . . 925~,0 9230.0 9225.5 9522.0 9390.5 9~86·5 9378.5 9370.~ 9~67.0 9323.0 9315,5 9312.0 9307.0 9302.5 9999.0 9286,5 9283,0 9~79.5 9270.0 9~66.5 ""g25f~ 9'255.0 24 ' '5 99~3 5 g235,0 9211.0 9206i5 92t)6.0 9202.5 9701..5 9199.0 9197.~ 919a.0 ~1~6.0 1'$ Tape Verification ~,ist~..n.~ :blumberc~er a.las.~a Co~:ut~.no Center 1B-JaN-1995 08:04 PAGE: 9174 ~ 9t7t~R 9!.5,*,5 0~50.5 9134.5 912~ 9~2~.5 9110.5 9109.5 9~.06 ~ 9102 gl. or ~ 0~93.5 9053~5 9~49,5 9o45,5 9~37,5 9034.5 9033,5 ~'030,5 9029.5 9026 5 9022 5 90~a 5 90~4. 5 90~0 5 9006.~5 899.3,5 8086.'~ 8982'.~ 8981 5 8978 8973 897~ 8q66 8962 895~ 8950 894R 8938 8934. 8922. 5 5 5 9174.0 gl. 71.0 9126.0 q~2! .5 91 9106.0 9102.0 9097.5 9094.0 905a,0 9050.5 9046,0 903~0 903~.0 9030.0 899.4,0 8990.5 8986,5 898~,o 8978.5" 8074.0 9173.5 9lb7.0 91.55.0 9151.5 9t46.5 9!34.K 9131.0 9111.0 9107.5 9103.0 9035.0 9031.5 9026.5 9022'5 90 9010.5 9007,0 '8":9 9'1. o' 89'86,5 8983.0 8978,5 8970'5 896'?i 8963 ~. 8959 0 895!,'0 8947,S 8939.5 8935,0 B927,0 8923,5 IS Tame Verif.l. cation List.ina Chlumberqer A].asKa Computlna Center 18-JaH-19g5 08:o4 PAGE~ 1.0 8giH.K 8919.5 8914.5 ~g14.5 10o.o $..)0.5 100.5 ~E~A,K$: THIS FI!,5 COi,!TA!~S PASS ~2 OF THE TDTP. THE DEPTH COR~ECTIO~.!S SHO~,, A~OVE REFLECI P~SS #2 GRCH TO PASS G~CH A~D P~SS ~9 SIGH TO PASS ~! SI~, AL[, OTHER TDTP' C~RVES WErE CAR~IED ~IT~ THE SIGM S~IFTS. SLTS F~R~T DA~A T~I,,E TYPF = CO~!S CN API~ FL SECT R~NC COUN W~TN '.SON ~D · ." ?DD ~LI D~? TLAB T~N! VALU DEF! : A~CO ~b~SK~, ~NC. Compan~ Name P,UDHOE BAY F[e"ld Name D.S. 01-29 Well Name 50'029-21604-00 AP1 Serial. Number 1017' F~b & 1511"FW~ Fteld Location 8 Section ION Township 1SE Range NORTH SLOPE County ALASKA State or ProVince USA Nation. D.. REEM Witness Name 4~B24! 'Service Order NUmber. MSL Perman nt datum- ~T 0 ~levat~on. manent . Oa u · Log. Measured From . .rT.. 70... .... FT 39.7 Elevation' o~..Greund.'Leve, l. rT. 95~. Total Depth~-'Drtller' FT 9452. Total DePth:- ~o~ae'r FT 9445. Bottom Lo~"lnterg&l ~T ~900. ~'boo'InterVal.. ~42 14-JU -94 Time ~oq~er.'at.,$ottom DEGF 40' · Surface Temperature.. ....-.............. .... ... ..... ......-....................-..........,,.....,.......,.,.,.....,.,.,,,.,, Is Tane V-,.r(.fication t, ist~..nc chlu,mber~:.r A!as~8 Co~vutlnc Center 18-JA~-1995 08:04 TABLE TYPF : CuPV DFFT ~m;mmmmmmmmm;mmmmmmmmmmmmmm~mm~m~mmmmmmmmmm~mmmm~mmmmm~m~m~ D..P? oe~t $Ig~ ~loma ¢;',eutron C~gture Cross section) TPH! TDT Porosity SBHW Borehole $~.g.:a - far detector $~H~ Borehole &Jgma - ~ar detector $1GC $1oma Correction S~B~ Corrected ~ore~ol.e Sioma TWAT ~ation Total ~ear to Far couDt$ SDS? Stan~'ard deviation of S~gma B~CW Race.round Count Rates - ;gear Detector F~AC Backoroun{~ Count Rate - Far Detector TCA~ Total counts analyzed - near detector (TDTP) TCAF Total cou~ts amalyzed - far 4erector (TDTP) TC~IO ~otal capture counts - ~ea~ detector TCFO Tota! capture Counts - far dectector TSC~ Total ~e]..ected Counts -.Near Detector T$Cw Total ~elected Counts - Fa~ Detector X~Nn Inelastic count rate - near detector 'I~FO Inelastic count rate - far detector G~C~ Gamma Ray t~ Casing T~NS S~faC~ Tension · ~CC5 CC5 Amplitude PAGEi I .' ~*.DATA FORe, AT SPECIFICATION RECORD ** SET TYPE -. 64.EB '..'? · .. TYPE ...... I 66 0 2 66 0 3. 7.3 88 4 .66 5 66 '6 73 7' '65 '' 8 68 0,5 9 65' rT 11 66 1~ 68 13 '66 0 14 65 FT 15 66 68 16 66 0 66 · . IS Tar~e verification T.,istl. nc~ chlumberoer AlasKa Computinq Center 1B-JAN-!go5 08:04 mmmmmmm mmmmmmm D~P? SIG~ ? TPH! T SRH~ T TRAT S~S! BAC~ FmAC TCA~ TCN~ TCF~ TSC~ TSCF INFD TE~S /~mm.m~m CU CPS CPS CPS CPS CPS CPS CPS CPS CPS' (;APT V mmmm~mm#mmmm · 459241 oo 4BR2~1 O0 48924·1 O0 48~2g! O0 48~241 O(") 48n241 oO 48~241 Oo 48~241 48R241 ~8~241 oO ~.241 O0 ¢B~24! O0 48~241 489241 O0 4B~241 O0 48~241 O0 48q241 nO 48R241 O0 48~2~! '00 Apl APl ~P'[ F DOG ,l'Yi)!~ CLASS MOD N 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 nO 0 ~ oho O0 0 2 oo0 O0 0 2 000 O0 0 ~ OOO O0 0 2 O00 o0 o 2 OhO nO 0 2 0o0 O0 0 ? 000 O0 0 2 OOO O0 0 2 000 O0 0 2 000 O0 0 2 000 O0 0 2 000 OO 0 2 000 O0 0 2 0o0 o0 0 .2 00o O0 0 2 o00 O0 0 2 mmmmmmJmmmmmmmmmmmmmmmmm! l ,g .u G ...... .... '"'"' ,t,.8 szzg' RE.., P,ocgss' .. ................. .,~ODE 1 1 ! ! 1 1 ! 1 1 1 .1 .1 I 4 {8 0000000000 I 4 i8 0000000000 1 4 ~8 0000000000 I 4 t8 oo0o00oo0o 1 4 t8 0000000000 I 4 ~8 0000000000 1 4 ,8 0000000000 I 4 ,8 0000000000 1 4 t8 0000000000 I 4 ,8 0000000000 1 4 ~8 0000000000 1 4 ~B 0000000000 1 4 ~8 0000000000 I 4 ,8 0000000000 I 4 ~B o00o000o00 1 4 ~8 0000000000 I 4 ~8 0000000000 I 4 ~8 0000000000 1 4 ~8 0000000000 1 4 ~8 0000000000 i 4 ~8 0000.000000 1.. 4 ...,O .0000000000 ** DATA DEPT., SBHN.TDTP 'SDST.TDTP TCAF,TOTP, 'T~NS.TD?P PgPT, $~H~,,TDTP' SDSI,,T~TP TCAF.TpTP "T~CF.TD?P TF~A,TD?P #, 0.519 BACK..,.T~TP ' 1.26 91 1257.227 CCb. TDT.P 0,000 ~900.000 ~IU~,TDTP 15,267 17440,539 TC~D'TDTP 25 I 02? 33n0;78.6 'IN~D'~TD'T,.." P 2095'.0'26 ' TPHIj.'TDTP SIBH,'TDTP FBAC.'TDT.P. ..TCFD.,TDTP .... ]:'iVFD~"TDTP " 'SIBH.'.~,'.TDTP. ·FBAC,·TDTP TCFD.,TDT~ )NFD",TDTP 50,~3 3.1.~,"~8 2'0,~4 45'.i{'30 '.29.i3B5 17 ? .~12 9441 .imG{~'~ ? 'SBHF~.TDTP TRAT.,TDTP TCAN,TDTP :TSCN,TDTP .$BHF'jTDTP' TRAT~'TDTP TCAN.'TDTP iT$~N..TDTP 40.;.81.8 3Oo4}-,sa6 4,000 4:193,:..000 · ,$-572 3685t,89! "6974,'56& 48,'000 ** E~D OF DATA *'* [8 ~a~e vertflcatt, on r,i. sttno :l~Xum~ero~r AlasKa ~o~.putino ~enter 18-JAN-1995 08:04 SERVICE ~ .rLIC VFR~IO;~ : O0tCni DAT~ : 94/1~/~3 Flbr TYPE : LO LAST rILE : FTLM MA~E : EDIT $FRVICE : rblC V~R$IO~ : 001C01 D. aTF : ~i/17/~3 M~X R~C SIZE t 1024 FTLm TY~E ~ bO FILE ,EADER FIb~ ~U~BgR: 3 EDITED CD,VMS ,, ~ePth Shifted and cllpPe~ curves'~or each pass in separate ~lles~. 3 0,5000 PASS NUmBeR: DEPTH INC~EMEMT! FILM SU~M.ARY LDWG.TOOB ~RCH TDTP STA'RT OEPTH 9431.0 9445,0 STOP DEPTH 8900.0 8900,0 '" ~URVE'"'SHi'F'T 'D~"T~ "'PASS TO'"PASS'(~ASU"~ED' 'DEPTI4')'' BASELINE CURVE; FOR SHIFTS [,D' m GR'C'H .~,,, CURVE ·CODE: P~SS N'U~SFR: 1 RASELINE D~PTH 8888~.0 9449.5 9451-5 9.~45,5 9447,0 9441,5 944~.0 9440,5 944~.0 9436 5 9438,0 9432!5 9433,5 9.428 5 942g,0 9424'5 9.425-5 9~20:5 9~21.0 9416,5 9417.5 . . : ---- ..... -EQUIVALENT UNSHIFTMD DEPTH.-=-=-==-. ~RCH TDTP 88889.5 88890.0 ~hlumber~er alamK~ Com~ut~n~ ?ente~ 9413.5 941~.5 9400.5 9409.5 9405,5 9401.5 9397 9393 9392 5 9389 938~ 5 9385.5 9~8a.5 9~65.5 9361,5 9360,5 9357.5 9356,5 9~53.S 934o.5 9345,5 9~41..5 933'7.5 932 932 5 931 5 930 ',5 .92.9?°5 '9296,5 9293,5 9289,5 92.85.,.5 9281.5 927? 5 9273 5 9269 9265 9261 5 9260 9257 9256 9253 9249 5 9245 9241,5 9~0g.5 9~97,5 9 .ss.s 9413.5 940o.n 9393.n 936~.n 9357.5 q~97.0 9~5~.0 9414.0 94i0.5 9406.0 9402.0 939~.5 9394.0 939~.5 9386.0 9374,0 9370,5 9366.5 9~63,0 9359.0 9354.5 9351.0 9346.5 9343.0 9338.5 9335"0 932? 0 9322,5 .9318.5 9315,5 9299,5 9295.0 9291. 92.83.0 928O 0 9~75 0 9~7X .5 9~67 5 926'2'5 9259,0 9255.5 925~..0 9246.5 9243.0 9207.0 9~04,0 91.99,5 9~.93.0 9~88.5 IR-JAN-1995 08:04 PAOE~ X4 X8 Ta~.e veri, ficatl, on ~.:istlnc, chlumberger ~a~a Com~)ut.lnc Center i 8-JA~.-1, 995 08:04 PAGE: 15 91.77 9173 9~69 9157 9~.2K 9t2! 9!.17 911] 95.09 9,~08 9.10a g,~.O~ 9100 9097 9~61 9057 905~ 9049 902~; 9025 90~7 90~6 9013 901~ 9009 9008 900~ 9004 8q89 8985 89.8'1' 8977 897'3 8969 8965 8961 8960 8957 8953 8952 8949 8~48 8o,.4~ 804~ 892l 8017 891~ 8gOg .5 5 5 5 o$ °5 °5 ,5 5 5 $ ~.. 5 5 9110,0 9!05.5 91 O2.0 9018,0 9014.,5 9010,0 90(;6,5 8966.5 8962-0 8054,0 8050',5 8946,0 9180.5 9!77,0 9171,5 9~67.0 9159,0 9154,5 9!51,0 9!39,o 9135o5 91.27.5 91.24°0 9~1 9~03,5 9090.0 9063.0 9059°5 905~ 5 9051" ,0 9031o0 9027.5 9023'5 9019.0 9015.5 9011..5 9007°0 8991,0 8984 8979' 8963,5 8959.0 8055,5 8951,0 8947.5 8923,5' 891~,0 8915,5 8911,0 ZS Tame Verlflcntton r..,lsttn~ ChlUmherqer AlasKa Core,uti. no Center 00:04 PAGE: ~ 00o0 .101 °5 lO1 °5 $ COR~EC'I.'~S SUOW;~ gnov~ REFLECT P~SS ~3 GRCH TO PASS G~C~.~ hr,i~ PASS ~3 SIC~I TO PASS ~ SIG~ ALI, OTHER TDTP TUr, I VALtJ DEFY . . C,~ ARCh AI.,ASKA, Fs! W~' Fl, TOW~! R~ 'COUN N~T! 'SON .PDAT .EPD APD .. EFB ' EDF TBD ~T ~T ~T. P~UDHDE 5.. 02..-21604-00 1017' Vub & 1511' fwb ION NORTM 8LOPE ALASKa D,..REEM 4~8241 0~.' ?0~. ~..? . ':" '~5~'3~ ' " 9452.. 9445° '$9.0O. SEAWA. TER/BO~AX 14~42 Z4'JUN-94 STE~' DEGF 40 DEGF 1~'0, ' ' Companx Name ~Field -ame · Well Name :API Serial Number i~ield Location ~$ection .Township :Range County Sta~e or Province ~ation Witness Name. ~Servlce. Order Numbe~ ~Permanent datum ~levatton o~ Permanent',Datum ~boq ~.easured '~rom ~.~bove Permanent,,Datum ~..Elevatlon"o~ Ke.lly.,Bushinq ::¢levatlon.o£-Ground'..~eve~. '!'?~"tal ~'Pth'""'~r'li"l'e'~"' · JTotal Depth '-.LO~qer ;Bott.om.boq I.n.~erval ~!Tlme. Log~er"at Bottom '"Surface'"?empefat~'~e ~;i~'ottom.~ole'?emperature.. ............... TgBT.,E TYPM : eO~V D~TFT D~p.T ... ne. t. · SIG~,~ Sioma (Neutron Capture Cross section) .TPH'T TDT POrosity '8~HF Rorehol. e S~.qrna - far detector Tame V.r.(.t.'tcat~on ~,lst.ir;q chlumber~er AlaSKa C¢)~ut.tr~o Center IR-JA~..!-1995 08:04 S~H~' mot _ r detector $IGC Sigma Correction $IBW Correcte8 ~orebole TPAT ~ation Total ~ear to Far counts $~$~ Standard deviatio~ of BaCK !~acKoround Count Rates - i'~ear Detector FRAC ~acKQround Count Rat~ - Far Detector TCA~ Tota~ Counts analyzed - near detector TCA? Total counts a.a!~e~ - far detector TCN~ motal capture counts - !~Jear detector TCFD ~otal capture Co~]nts - far detractor TSCN ~otal Selected Counts - Near Detector T$C~ Total Selected Counts - War Detector I~ND Inelastic count ~ate - near detector I~FD ~nelastic count rate - far detector GPC. Gam~a ~av ~n Casin~ T~N~ Surface Tension CC~ CCL A~91~tude PAGE~ ~* ~ATA FnR~AT SPECIFfCA~ION ~ECORD mmmmmmmm.mmmmmmmemmmmmmmmmmmmmm TYOE RMPR CODE VALUE .1 6~ 0 2 66 0 J 73 88 4 66 5. 66. 7 65. 8 68 '0,5' 9 65 FT 1! 66 ~? 6g 13 66 0 14 65 1.5 66 68 16 66 0 ~6 I$ Taoe Verification List~no Chlumbevqer Alaska Comp,.]tlnq Center 18-JAN-!995 08:04 PAGE:: N~H~ SFRV U~:!I· S~'VTC~ APl bpi APl hPT ~ILE NUmB NUMB SIZE' ~EPR PROCE~ ' ........... ' ..... X[ ........... ............ .......... ,'"'"'"'""'"'"'"""" D~PT FT 824t O0 . O0 0 1 4 {8 0000000000 Cl, 4~241 O0 000 O0 0 3 1 I 4 {8 0000000000 $IG~ TDTP $~HW TOTP C~.) 48~2~1 00 0gO 00 0 3 ! ! 4 SRH~ TDTp C!.l ~8924~ OD 000 00 n 3 ! ~ 4 STGC TDTP C~ 48~2~1 OD 0~O O0 0 3 I 1 4 SIB~ TDTP C'.! 48~241 00 gOO PO 0 ~ ! I 4 T~AT TOTP 4.8~24t ~{) 000 O0 0 ] 1 i 4 S~ST TDTp CL1 48~241 0O 00O O0 0 3 I I 4 B~C~ TDTP CmS 4fi924,1 nO 000 0O 0 3 1 I 4 FnAC TDTP CU$ 48~241 o0 Oo~ 00 0 3 ! 1 4 TCA~ ~DTP CPS 4Bn2al 0O OhO O0 0 ] i 1 4 TCA? TDTP CmS 4~R241 O0 t~00 00 0 3 ! ! 4 TCN~ TDmP CPS .¢8~2al OO 000 00 0 3 1 1 4 TCFO ~OWP CPS ~882aI no n0o O0 0 3 I 1 4 T$C~ TDTP CPS ~2~241 nO u00 O0 0 ] 1 I 4 INND .TDTP C~$ ~8~24! 00 O0O 00 0 ~ ~ 1 4 G~C~ TOTP G~PI 48~24~ O0 00O 00 0 3 1 1 4 T~NS TDTP b8 48R241 00 000 O0 0 3 I 1 4 ~CCL .TDTP V ¢88241 O0 o00 00. 0 3 1 1 4 0000000000 0000000000 0000000000 48 0000000000 0000000000 0000000000 (8 0000000000 0000000000 (8 0000000000 0000000000 0000000000 t8 0000000000 0000000000 (8 0000000000 (8 0000000000 t8 0000000000 t8 0000000000 '(8 0000000000 18 0000000000 (8 0000000000 .~mmmm~mmm~mm~mmmmmm~mmmmmm~mmmmmmmmmmmmmmm~mmmm~m~mmmmmmmmmmmmmmmmm.{{mm#~mms~m~s~! 18 · DEPT. ~445.000 ~ TDTP ..'SBHN,TDTP 47.8~7 $1GC..TDTP 2.565 SiBH.'TDTP SD$I..TDTP 0.543 BACK..I....2, ~39..~92 FBAC,TDTP ** E~D OF DATA **** FILE TRAILER '**** FILE NA~g : EDIT .0n3 SERVICE : FbTC VER8IO~ : OUICO! DAT~. ~ q4/i~/23 F?'L~ TYPE ~ LO LAST'FILE ~ Tame Veritt~cation Cblumherqer Alaska Co~r.,-,u't~no Center DRTF MAX F~b~ TYPE 18-JAW-1995 0~:04 1.9 TD~P 9~45.o $ ~URVE S~IFT D~TA - PASS TO PASS(~EASU~ED DEPTH.) ~ASE~IME C~RVE FOR SHIFTS LD~G CUR'VF CODE: ~RCH STOP DEPTH 8900,0 ,. 88~.0 8~ . 888B~.0 460,5 .... .. 9.4.61,.~... 449',"M" ' 9449, 9444,5 9445,0 9443 5 9445-5 9439:5 944~,5 943~.5 943.7,0 943..,5 943~o0 9427,5 9a27,~ 9'424' ~ '9425'.'0 9420}~ 94'20 .5 939~. 5 9388 ~ 9389.0 9~87!~ 9387.0 9384 5 9384.5 9380.5 9'380,5 9~76,'5' 9377,5 937~.5 9973,O 9~71.5 9]67,5 9367,5 , .. ------ .... EQUIVALENT UNSHIFTED DEPTH-'----",---! ~8 Tare v~r.t~(¢a:~.on :h~un~erq~r ~.!.'.~s~a C..c~p:.,~l.~o Center 9~5q,5 935~.5 9352,5 9~3~ 5 9335.5 9332.5 9331 ,r~ ~-~2~,~ 9~1.6.~ 9~o~.~ 9~o4,~ 9~9~,~ 928R ~ g283 9200.5 9276,5 9260.5 9255,~ 9252,~ 9~5~ ,5 924~ 5 9~47': 5 9.244,5. 9~2'4,'5 9223,~ 9220'"~ 92'19,5 9~0~, S 920 5 9~88 5 91.84:~ 9172,~ 91,88,5 9t67,5 9164,5 9~60 '5 9144,5 935-.'5_..5 934h.5 9336.0 9~32.5 9328.K 932a.~ 9704,5 9256,5 9252,0 9~48,5 ... 9224,5 2o.o 9216.5 9~69.5 g353.0 9349,5 9337,5 9333.0 9321.0 9316.5 9308.5 9305.5 929R.0 9~93.5 9~89o0 9285,5 9281.0 927~,0 9972,5 268,0 265,5 9261.0 9~56.5 9253.0 9'249.0 92.45..,.5 9225,5 9222.0 92.17o5 '9209,5 9~9! .5 91B8'0 91BO,O .9~.7'4.0 9169,5' 9165,5 91.61..0 9~.49.0 9t45,5 18-JAI~..'- t. 995 00:04 .. PAGE; '20 chll]m..b, erqer A].a~Ka Co.~'~Du~na ten%er 18-JAN-!.995 1.]~ 5 91.~7,~ 9120,5 9116,5 9111.5 9%04,5 910~o5 9~96.5 904.0,5 903~ ~ 0 9rtl? ~ 900a 5 900~,5 8~76 5 8975 5 8971 5 896~ 5 896~. 5 8~64 ~ 8963 5 8959 5 8951 5 8948 5 8947 5 8.9.4i. 5 $9'4, '5 8o4~ 5 8936 5 8~32 5 8e285 8~2~ 5 8~6 ~ ~0~ e 912q.o 9112.0 9¢)(..''~. . 5 8077.0 897~,5 8~6a.0 8q60.5 ~o52,5 8q4~.O '"Bq'44.'5 1 (.)1 ,0 9129.5 9~25.0 9~2~,5 9t1~.,5 9113.0 9101.5 9097.5 9094.0 9089.5 9041.5 9037,0 9033,5 9029,5 9025,0 9913,0 9009,5 8~81.5 8977,0 8969.0 8966.0 896i.5 89'49.5 8946,0. 8941,5 8937,5 8934,0 B929.5 8o21,5' 8917,0 .~.0'0,5 CORRECTIONS S~OWN ABUVE R.~FLECT BORAX PASS '~1 GRCH TO~ BIS~' PASS. ~! GRC},~ at~D BORAX PaSS ~1 6IGM TD BASE PA~S~' ~1 SiG~. ~LL OT!.tE~ ~DTP CURVES WERE CARRIED WITH THF STG~ SHTFTS, # LIS 'F..fik~iAT DATA PA'OE~ 21 I$ Tame v'ert, flcation chl~mberper l~].asKa Co~outir, o Center 18-JAM-1995 08104 PAGEt 22 · i'U ~ T VALO CN ARCO ab.ASKA'Ii~C' COmpany Name F~,' PRUDHOE BAY Field Name WN b.$.~01-29 A~I~] 5o-nz9-?1604-00 F{, 1017' ~'~b & 1511; Fwb SFCT 8 TO~W !0~ RaNt 15~ CDU~ ~ORTH 6LOPE STAT ALASKA NaT? USA WTTN D. REF~ PDA? EPD ~T ADD WT 70. E~B WT 70. EDF wT E~L WT 39.7 TnD rT 9563. Tnb FT 9452. BI,! VT 9445. TLI TT D~T :TLA~ Well Name REI Serial Number Field Location Section Township ~ance County State or Province Nation Witness Name Service Order Number Permanent datum Elevation o~ ~ermanent Datum Lo~ Measured From RbOVe Permanent Datum Elevation o~ Kelly Bushing Elevation pt Derrick Floor ~levation of Ground bevel Total De~th - Driller Total Depth - Logger Bottom bog Interval 8900. Too Log I~terval . SEAWATER/BORAX DrtlllBq Fluid Type 14142 14-JUN-P4 Time boqper.'at Bottom 40,. Surface Temperature · 180..,. ...... Bottom Ho?-:~em~eratu~e .....:;....TABLE TYPE t .CU~V DE'FI D~PT De.th $IG~ Sl~m. {Neutroa Cs~ture.Cross Section) TPH? TDT Porosity $~H~ 'Borehole Big'ma - ~ar. detector STGC 'TCA~ TCAF TC~ TCFD · T$C~ noreh'ole Sigma"- Near detector Sloma Correction Corrected Rorehol, e Sigma Patlo~'Total ~.~ear to ar counts Standard deviation of $ioma Rack~round Coumt Nates - Near Detector ~ac~round Cou~t Rate - Far Detector Total counts analyzed - near detector (TDTP) Tota~ co%~nts analyzed - ~ar detecgor (TDTP) Total capture counts - aear detector ~otal camture Counts - far dectector Total Selected Count~ - ~'~ear Detector IS ?ane 'veri~ic~tt.o, List,.no chlUmherqer Ala$~ Co~:.:,~t~,o ~e,t~r 1~-..~ a..'i- 1995 08:o4 .23 TSCF oral Se .... counts - . ? ..n...etector I~t~ Inelastic count rate - ~ear detector I~F.n ~nelastic count rate - far detector G~C~. Cam~,a Pay ~.n TFN~ Surface Tenslon CCL CCL A ~D 1 .t ** mATA F~R,',4AT SFF. CTFIC.~I'IOh: t~ECO.~D ** 2 66 0 4 66 ~ 5 66 ~ 73 7 65 8 68 0.5 9 65 FI 1.! 66 11 1~ 68 13 66 0 I4 65 PT 15 66 68 16 66 ! 0 66 1 ** SET ~YPE - C~AM ** .. . ,"'"'""'""'""" FILE NU.B .NUMB :SI~ R'EPR pROCESS' ' D~P? F? 48~241 00' 000 O0 O' 4 t 1 4 68 0000000000 TPH? 'rDTP $SH~ '!!o'rP · ' $IB~ TD~P .T~AT SOS'T ~O~P B~C~ TDTP TCA~ TCA? 'rDTP CU 48824'1 no PU-$ 488241 o0 CU 48~24I 00 C~ 488241 o0 C'U 48~24I 00 CU 4B8241 O0 ~8241 O0 CU 48~241 00 C~$ 488241 'o0 C~S ~882~.1 ~0 C~$ 48~241 00 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 0 4 000 O0 O' 4 0o0 O0 0 4 OOO O0 '0 4 0o0 O0 0 4 o00 00 0 4 000 O0 0 4 0 4 CPS 4892'41 nO '000 O0 ! 1 4 68' 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 I i 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1' '4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 1. '1 4 68 0000000000 I8 ~a~e Ver~.f~catton r,isttnu PAGE: '.24 . ..... ;; '"'"" ........... P~0C£$8 Oa~ ~ brig !r¥~ Cb~SS ~'0~ ~o~B S~MP ~b~ ~On~ fH~X) mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm mm mmmmmmmmmmmmm CPS 46n2al no ooo O0 0 4 1 I 4 68 0000000000 TCFt ~DTP CPS TSC~' TUTP CPS a8824t 00 T$Cr ~{3'T'p CP~ ~g241 oO G~C~ ~"C. TP G~P~ 48~241 OO0 oO 0 4 00u (.)O O 4 000 O0 0 4 9o0 O0 0 4 OOU O0 0 4 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 TFF~ 'r l]'~' p bP.., 4 BR2.'I l nO OhO O0 0 4 1 I 4 68 0000000000 SIGM.TOTP 21.430 TPHI,TDTP $IGC.TnTO 3.072 SIBH.TDTP PACK.T~To 149.g7g FBAC,TDTP TC~!{.).TDTP 91900.45~ TCFD,TDTP TN~D.TDTD 2300,340 INFD.T~TP CCD.TDTP 0,000 31.4241 SBHF TDTP 50;919 TRAT,'?DTP 33:680 TCAN.TD?P 6777,~606 T$C~,TDTP 434~69~ GRCHoTDTP 30858, 750 4436,896 "999.250 **** FTLE TRAILER FILM NA~.{E : EUTT ,004 SEXY'ICg : rblC V~RSI. OrJ : O.O1COl D~T~ ! g4/12/23 M~X R~C SIZE : 1024 """FILm TYPE '~ LG' b~$m FILE ... ****' FTbF HEADER **** $~RVlCE : WLTC V~RSlnN : O0~.COl' M~X R~C 8~Z~ : 1024 FILM TYPE ~ LO L~ST wILE FILE PE~D~R EDITED CURVrS chlu~er~er Al~s~:~ ¢.'o,.putln~ Center 18-JAN-1995 08:04 FTL~ SU~ aRY ~DWG TO0!, CODE ~nd clt.r..ned curves for eSch mass 5 0,50 ~ 0 944.9.0 8900.0 ~AqEt, Ih~E CURVE FOR P.~6$ ~SER~ - PASS TO mAS$(~KASU~ED DEPTH} I~E DKP?H 447 4.19 410 407 406 398 39! .......... E., Q [,' I VA [,g,~.WT 9440.0' 9414.5 gal0.0 9~,06.0 940~.'5 0 9'39. 9390.5 9]86.0 TOTP 88888.5 9a48.0 9423.5 9419:0' 9415,0 9407.5 9403..0 9391.0 9363,~ 9355. 935~.0 934~.0 9344,5 934~.0 .934a.0 9338.5 9336.0 9~34.0 933'1.0 9330.5 9326.0 932J.5 390,5 375,5 363 5 355 5 351'g 3q7 5 3~.3 5 342.~ 339,.., 338.5 335.5 33~ 5 330 5' 327 5 323.5 Oh!SHIFTED sevarate files. DEPTH .... ------ IS ~a~e Verification Cblumberger Alaska 93O? 9?99.5 929.~,5 9291 .~ 92@7,5 9283,5 9979.5 9975.5 9~74,5 997~ ,5 9~5~,5 9~55.5 9~51.5 9~47.~ 9~43.5 9223.5 9219 5 92"L 5 5 9! 99 9~95 5 9!9~ 5 9~ ~7 5 9~7~ 5 9~.67 9J. 54 9!5~ 9150,5 9~47,5 9~43 5. 9~42 9. ~ 3.9... 9~38 9135 91.31 '5 9!27 5 9126 9123 9!22 9~ ~5 5 9111.5 9~ 07 9109 5 9n99 5 9095.5 9090,5 9087.5 9086,'5 9274,.~ 9?6?.0 9155,0 9151.5 9!.47.0 91.43.0 9139'5 9.127,5 912],0 9103,0 90.99.5 9091,5 9087.0 Center 9310.0 9306.0 9304,0 9296,0 9292.0 9287,5 9283.0 9?80.5 9276.0 9260,5 9~56,0 9252,~ 924fl 5 9244'0 · 9224,0 9220,5 9216,0 9204,0 9200,5 9196.0 9!9~ ~ 918~' 9173,0 9168,0 9!.52.0 9'1.47,5 9~44,0 .. 91.40,.0. 9136,5 91:32,.5 9120,0 9124'0 9120.5' 9!16.0 9112.5 9109,0 9100,0 9096,5 9088,~ 08:04 PAGEI 26 IS Tape Verl~.tc,,3tlo~ [,lstino chlumberoer AlasKa Co~put~no Center 1 ~-JA~-1995 .. PAGEI 907~,5 90~7,5 9n59 9n50:5 9046.5 9039.5 9035,~ 9AIg,. ~011 9~07,5 8e9e.5 8n79.5 8~75,5 S974o5 896~,5 896~,5 8059 8955 8~5! ~00 90U~.5 9051.5 9011.0 e~75.5 101.0 9080.5 9068.5 9064,0 9060.5 9040.5 9036.0 9020,0 9017.o 901~.o 9008,$ 9000.5 8096,0 8988.0 8984.5 8970,5 8976.0 806~.0 8064.5 0060o$ 8956..0 8~5~'0 8948!5 10~ .0 TWIg rlL£ CONTAINS RORAX P~S~ #2 OF'THE IDTP°.::TNE.DEPTN CORPEeTIONS SHOWN ABOVE REFLEOT..BORAX #1, SIGh AL[., 0"~ SIG~ SHIFTS, · S" "'"" ' '' " '' ,b.T.S FO-R~,~AT DATA 'Y . U Ti~BI..~E ~ .DF. ,' CO S T~!,{? VALU 'DEF! N A~Co AbASKA, INC.. ·Company Name ~ PRUDHOE' B~Y ' Field Name API~ FL SP.C· COU~ SmA? .$. 01-29 ~0'029m21604-00 1017' F~;5'& 1511' 'FWL 8 15E NORTH SLOPE ALASK~ · Well Name APl-Serial. Number. 'Field 5ocatlon 'Section. 'Township Ranoe County .. · 'State'or ~rovinCe I8 ?a~-e ver, lftcatlon Cbluw~erger A.l.a~Ka Co~p~t]n~ Center 995 OB: 04 PAGE~ 28 $ kn :,: 488241 APD FT 7n. EK6 ~T 70. EOF ~I' 69, EOb ~]' 3~,7 TDD WT 956]. TDL ri 9452. Tt.I ml' 8900. D~T , S~AWATER/~ORAX TI, AB 14:42 14-JU~-94 STE~'~ DEaF ~0, Witness Name Service Order Number Permanent datum Elevation ot Fermanent Datum Log ~easured From Above Permanent Datum Elevation ot Kellg Bushing ~levatXon ot Oerric~ rioor Elevation ot Ground bevel Total DeDth - nr~ller Total DeDth - bogQer Bottom boq Interval 5o~ Interval T°tll. i~¢r Fluid Type Time ho~qer at Bottom Surface Temperature Bottom Hole Temperature .. ~-~-~-~-~~-~-~--~--~-~--m--~m~m-~-~--~~mm-~---~m-m~m-mmm~-~-m~m~~m~mm~m~~~ DFFI .. . nenth. 6IG~ $iqma C~eutron CaPture Cross Section) TPMT TDq' SB~m morehole 6~q~a - ~mr d~tector SmHN ~ore~o).e.$~Qma - ~ear detector STGC Sigma CorrectioD SIBH Corrected ~oreho]:e Slqma T~AT ~ation Total. ~,~ear to Far counts :.:.:...SDST stan~ard,..deviati.on.o.f.$1.gma 'B'~k' ~ack~round Count' cares'-"Near 'Detector '" : .... FBAC ~ac~round Count Rate , ~ar Detector TCA~ Total' counts a~alyzed - near detector (TOT?) TCAF 'fora! co~nts analyzed - ~ar 4etector'(TDTP. TCND Total ca~ture counts .- ~ear detector TCFn ~otat capture Cougars - ~ar ~ectector 'T~C~? ~ota! Se].ee[,~ Counts - Near Detector .TSCm ~otal Selee:e~ Counts'- War Dete'etor 'I~t~D Inelastic count rate - near ~etector I~F~ I[~elast. ic count rate - far ~etector 'TFN~ Surface q'e~s]On .CCL CCD IS Ta~e V.~rtficat~on 18-JAN-1995 (;8:04 PA~E~ X 60 0 2 66 3 73 88 5 6 73 7 ~ 68 0,5 ~ 65 FT ii 66 ~ 68 1~ 66 0 14 65 ~T 15 ~6 68 16 ~6 U 66 1 mmmmmmmmmmmmmmmNmmmmmmmmmmmmmm ** SEW TYPE - C~A~ ** N~hF SFRV iJ~J I~ SERVICW APl ~PI AP1 API' FILE NUMB NUMB SIZE REPR PROCESS ID ORDE~ # bOG TYPE CL~.SS MOD NUMB SAMP EbEM. CODE (HEX) DEPm F'T 488241 O0 000 O0 0 5 1 i 4 68 '0000000000 S~G~' TDTP Ct~ ~882~1 O0 000 O0 0 .5 1 TPH? TDTP PU-S 4.88241 O0 000 O0 0 5 1 SSH~ T.DTP CU a8~241 oO 000 O0 0 5 1 $~H~ TDTP CU 488241 oo 000 O0 0 STGC TDTP CU 4882~1 0.0 060 O0 0.. 5 $.IB~ TDTP. Cu 4.8..e2~1 oO ..O.O.O ..0.0. 0 $ .i . ......... 'T~.AT TD?P" '"'48~2d1' 00 .... 000 00 ..... .0'' 5'" ..... ~DSX TDTP CU 48~2aI 00 000 00 O' 5 I "'." BtCW TDTP FBAC TDTP TC'AN TD~P TCAV TDTP TCN~ TDTP T'CF~ TDTP T~C? ~mP 'INFD TDTP G~C~ TENS TDTP CPS 488241 O0 CPS a882~i O0 CPS 488241 00 CPS 488241 o0 CPS ~882dl 00 CPS ~'8~24'1 O0 CPS 4~82,41 oO CPS i8~241 O0 CPS 488241 o0 GAPI 48S24,1 00 L,B 48~2.41 nO 000 O0 0 5 1 000 O0 0 5 1 00'0 O0 0 5 .1 000 '00 0 5 1 000 O0 0 5 1 000 O0 0 5 :1 oO0 O0 0 ~ 1 000 0'0 0 5 1 000 00' o 5 1 00'o O0 0 5 1 000 OO 0 5 1 000 O0 0 5 i 1 1 1 1 1 1 1 1 1. 1 1 1 1 1 1 1 1 1 1 1 4 68 .0000000000 4. 68 0000000000. .4 6-8 000000'0000 4 68 0000000000 4 6.8 0000000000 4. 68 0.000.0000.00. 4' 6'8 "000'0'000000 4 68 0000000000 4 68 0000000000 4 68 00000'0000'0 4 68 0000000000 4 68 0000000000 .4 68 0000000000' 4 68 .0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 · ..COb ' wD'rp V 48e2m.!. oo 00o O0 0 5 I I 4 68 0000000000 I$ ~ave v'~r~.ftcat~.on t, ist]no Cblum~erqer AlasKa Co,~t:.',,~tfn~ Center 18-JAN-1995 0~:04 20.712 158 375 21~7~:000 TCWD.TDTP 2095.~27 0.000 29,553 SBHF,TDTP 53.445 TRAT.TDTP 33,930 TCA~,?D?P 6714,750 TSC~.,TDTP 415.925 GRC~.TD?P 45,199 t,66i 33032.000 4196,500 '-999,250 · *** FILE TRAiLE~ FTLE ~'!~"E : ~DT!' .005 SWRvIC.F..', t ~DTC FTLw TYPE L~S~' FILE **** FTLE WEADM~ *'*** FILE NA~E : EDT'~ ,006 SERVICE VERSION : 001. C01 DaTF M~X R~C SIZE : 10~4 Flb~ TYPE : L~$T FILE Compensated ~!eutron: Arithmetic average of. edited Passes.for all, curves. ., Pulsed Neutron~ Unaveraged edited. PasS.! Gamma Ray and backround, counts; arithmetic average. of edited statlc ba$oltne, passes for all other curves. ' DEPTH lgCRE~ENT 0.5000 ~ · . P~.SSES INCLUDED I~ AVERAGE LDWG T~OL CODE PASS NI!~BE~S ~DTD., 1, 2, 3, ~E~A~KS: T~E .A~iTH~E~IC ~VERAGE OF THE THREE PASSES WAS cOmPUTED AFTE~ ALL DEPTH C~RRECTIOM$ ~RE APPLIED* LIS FORMAT DA~A IS Va-e Vertf~..catl. o~ Chl,~ber,:;er 4!osKa Contd.:uti. no Center ~ ~-JAM-19 .°. 5 08:04 f ~ API~'? . 1604-00 Fl, 1017' FN~ & 151~' Fw5 S~CT 8 TO~ COUN }fORTH SLOPE N~T! USA P~AT E~D WT O. APD ~T 70. E~8 WT 70, EDF WT EGL ~T 39.7 T~D ~T 9563 · IDb FT .9452.~ BLI FT 9445. TbI DFT STE~ .DEAF .. B~T Tt'i~ ? VA [.,U DEF! .......................................C~'~ ;.~(~''~';~;;'~2.e.,' b ................ Company '' ........ Name ''''''''''''''''''' P~UDHP.,E BaY Field Name Well Name APl Serial Number Field bocation Section. ?ownsh~O Ranoe County State or Province Nation Witness Name Service Order Number Permanent datum Elevation o~ Permanent Datum bo~ ~easured From Above Permanent Datum Elevation of Kelly .Bush[n Elevat.on o~ De,ricK Floor E[evatton or.Ground 5evel. Total Pepth - Driller Total.De~th - 5oqqer Bottom bog interval 8900, 'ToD boq Interval... SEAWATER/BORAX" Orillinq Fluid TYpe'. t4:42 14-JUN-94 Time..boq~er.at Bottom 40. Suriace'Temp~rature · . 1~6,. . ........ Bottom..Hole.,wemperatu~e. .............. :..::.....T~BbE .TYPE...:CU{4. V. . ........ ... ...... D~FT . DEP~ $IGu T. PHT SIGC T~A~ 'SDS! rSA~ TCA~ TCAF TC~D TCFD TSC.W Si~ma CNeutron Capture Cross Section) TDm.Porosit¥ ~orehol. e Stoma - far detector ~ore. hOle St'~a - ~e'ar detector' CoTTeCted Boreho[e ~e~[or~ ~o[a[ Nea~ to. Far counts ~ac~ou~d ¢ount. Ea~es - ~ear Detector ~ac~ro~d ¢ou~t ~a[~ - ~a~'De~ec~or. ?o~e[ counts a~a[yzed - ~ear detector ?oral counts ana[y~ed.- ~a~ detector (TDTP) Total capture counts - ~ear detector Total capture Counts - far detractor Total Selected Counts - Near Detector IS Tame Verl. fic,~t~on [,i'$t.tn,~ ChlumherfJer alaska ComPutln~ Center T~C~ ~ .i oral ,qe].ect.. r ~etector ~,~J Cou~ts ' Fa I,~N.P' tnelaSt~c coun~ rate - near ~etector I~F~ Tnelastic count rate - far detector GPC~! ~amma ~av In Casing CCi an'~iJ, rude ~m~m~m~m~m~ ~m~m~m mm~m ~mm~mm mm~mm~mm~mm~m~m~ PAGE~ 32 Ty~ER~PP CODE ¥.~UE ~m~~m~m~mm~m~m~mmm i 66 0 2 66 0 5 66 6 73 ? 65 8 68 0,5 9 65 FT ~ 68 i3 66 0 14 65 FT !5 66 68 16 66 1 0 . 6b 1 . ~mm~mmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmm~mmmmm~mmmmmmmmmmmmmmmmmmmNmmmm~m~m~mmmN~mW~ " NAMF SMRV UNIT SEPVICE API ~.PI API APT FILE NUmB NUMB SiZE REPR PROCESS ID ~ROE~, ~ bOG TYPE CbAS'$ MOD NUMB. SAMP EbEM CODE' (HEX) . .... SIG~ pN~V Cti 48~24I O0 000 O0 0 6 1 I 4 .6g 00000'00000 TPHT PN'AV PU-S ,48~241 O0 000 O0 0 6 1 I 4 68 0000000000 ~BHF PNAV C~? 4-8~24.1 O0 000' O0 0 6 .1 i 4 68 0000000000 8RH~'Pi'~.~V CU 4,8~24'1 O0 000 O0 O 6 1 I 4 68 0000000000 ~IG¢ PNAV C!.} 4~9241 O0 000 O0 0 6 1 I 4 69 00000000.00 $IBU P~gAV 'C' .4~241' oO 000 oO 0 6 1 1 4 .6~ 0000000000 .T~AT P~AV ~ 8... 2~1 90 000 O0 0 6 I ! 4 6~ 0000000000 $~$!' PNAV CU 48~24t O0 000 O0 0 6 '1 I 4 6~ 0000000000 BAC~ PNAV C~ ¢~a241 O0 0o0 O0 ,0 6 i i 4 6.8 0000000000 F~AC PaAV CPa 4~9241 ~0 000 O0 0 6 1 1 4 6.8 0000000000 TOAd!' PaAV' C~$ agg'241 O0 ' 000 O0 0 6 1 1 4 6~ 0000000000 TCA~ PNA¥ CPS 48~2~1 Ou 000 O0 0 6 I .1 4 68 0000000000 IS fane Vertt~,catlon Liscj. n,: chlumberg~r A]asKa Co~,~p,3t~.D~ renter 18-,?AN-1995 OR:04 PAGEI 33 ......,rrN~ ~; .... v c~s' .....4 ;;~ ...... ........ 1 ~,::) ~'"go .................... 0 0 6 1 i ........ 4 ' ..... 68 ''"'""'=""0000000000 TCFr~ ~i~Av CPS ~m~2~i nC, 000 oO 0 6 1 1 4 68 0000000000 T$C~ o,.~A V CVS 48~241 ou 000 O0 0 6 1 1 4 68 0000000000 T$C? P;,~Av CPS 48~24i OO 000 O0 0 6 1 1 4 68 0000000000 I~NP P~AV CPS 48~241 O0 000 O0 O' 6 1 I 4 68 0000000000 GPCN ~iAV G~PT 45~241 O0 000 O0 0 6 1 1 4 68 0000000000 TF~ P.'<~V h~ 48~241 09 000 O0 0 6 1 1 4 68 0000000000 D~P?. q44,5.0nU S~HU.P~AV d. 7.549 SDSI.u~i~V 0.516 TCAr.~'V 10852.~.8 T$CW.P~V T~N$,ui~AV 12~3,947 SlG~.PNAV 21.088 TPHI..PNAV $I~C,PWAV 3.240 $IBtt.PNAV ~ACK.PNAV 8R,896 ~8~C.PNAV TCND,PNAV ~155g,109 TCFD,PNAV Ii~Q.PNAV 2441 595 INFD,P~AV CCL.P~AV O:OOO 29'.547 SBHF.PNRV 3~i062 52,890 T.~A?,PNAV 653 22.340 TCAN.PNAV 2799~i,.863 6787.067 T$CN,PNRV 4284,594 437.~89 GRCH,PNRV '-999,2~0 **** FILM TRAILER **** 'FIbF ~A~E : EDIT ,006 S~RVICE : FbTC V~R$IO~ : 00.1C01 DAT~ : 94/1~/~3 .~.~ .... M'AX.REC SIZE : .F{LF TYUE : LO b~S? FIbE : **** FILE MEADER **** F/L~ NA~E : EDIT .007 SERVICE ~ FbTC VMR$IO~ : 001,'C01 M~X R~C $~ZE : 1024 FTLM TYPE L~S~ FILE ChlUr~herr;~r A!.as~a Co.~'.p,,;tfnC Center DFPT~ I r'.'m C n E ;:~E r,~ T,· 0.5000 VEt.'L)mR TOOL f~,.'.3DE ,.q. TgRq' D£PTR $ LOG HEADER DATA DAq~ LOGGEP,': SOFTWARE VF..RSIOt~: "'P LOGGE~CFI): and lod DeaMer data for each oass in separate STOP D~PTH SPEED fFPl.in): TOOL VEND(.)~ TOOL CnDM TOOl., TYPE TDTP TDTP TDT~ TDTP T~TP TDTP COLLA~ LOCATO~ AUXILLI~RY CART~IDGF TDTP CARTRIOGE TDTP DETECTOR TDTm GENERATOR AUXTLhIaRY MODULE FORE~OLE AND CASINO DATA 0~ ~ob~ ~,T~ SIZE .DR.!b. LE. RS.C.A,.SIN.G ~.E.P.T.H..~F.T~.)~ LO~GERS 'CASI~G D~PT~ ('PT):" 80~EHOLE CONDITIONS FLUID DENSITY (LB/G~I SURFACE T~MPERATURE ~OTTO~ ~GLE T~MPE~ATU~E FLUID S~LI'~TTY FL~ID LEVEL (F~): FLUID RAT~ .AT WELLHEAD CBP.M): ~TER CUTS (PCT): GAS/OIL RATIO: C~OEE (DEC)! ~EUT~O~ TOOL TnOL ~YPE (EPITUE~L Om THeRmAL): M~TRI'~: ~ATRIX HOLE CO~RECTIO~i files; raw background Pass in last '.f~ t4-JUN-94 38.2 1442 9563.0 9452.0 8900,0 9445.0 1800o0 "0 14-JUN-94 TOO6 NUMBER HDW CAL-UB-1269 ArC-CB-Il99 TNC-Pol4! TND-P-?5 TNG-~-236 .2.48..0..0,.. SEAWATER/BORAX .40.0 180.0 THERMAL SANDSTONE 2.65 I~ ~a~e vertf,!¢~tJon ~hlvmberqer AlaSKQ ComPUt~nQ r.'e~ter 18-JAN-1995 08:04 .PAGE; 35 ..... o.,.LE (CP$)~ WA~ CGU~T ~ATE HTG~ SCALE ¢CP$)~ ,!~a~ COU~'I' RATF ~,!]W ~CaLE · .. ~ ~'E~ COU~T ~,.rw 1.4~H ~CALE (CPS TOOL TIED ~,~TO 5{4C (S~$) DATE0 08-JUN-S6, ~I~°EO 230 gSl.,S SFAWATER/IO0 ¢BI,S BORAX/170 BBbS SEAWATER, ~ATA T~BLE TYPE ~, CQ[',iS TUN! VALU DEr! P~UDHOE'.B~ARCO ~L~5~ ~NC, Compzn¥ Name FL :. $~C~ TOWN .. NATI .. pDAn' EPD " A~D EgS E~F 'TDD T~5 .TSI D~T "STE~ ?T ~T ~T ~T FT 10i7' FN~'& 1511' ION ...1.~.E ...... USA. 0~' 70, 945~'' SEAWA?ER/BO~AX · 14:42 '14'JUN-94 40, Field Name Well Name API..$e'rt~l Number' Field ~ocatlon Section.. Township Range.. 'state or Prov~nce ~atlon witness Name. Se~v~ce'Orde~ Pe'~man~nt datum. Z~evat~o~ of Pe~mane'nt'.Datum ~o'~ ~eas~ed. F~o'm " ~bove Permanent ~at~m ..,.. £1evation'o~ Kelly ~levation o~ De~cZ ~o0~ ~levatio~ o~ ToP.~oO ~'nte'~a~.... · $~ac.e ?empe~ato~e 18 ?aue veri~cat.ion Listin~ .'hlumberger ;,.1. as~a Computine Center 18-JAN-1995 08:04 PAGE.. 36 TABLE 'rYp~ ; Ct:~v' TPHT $~ HF STGC T~AT BACw F~AC TCA~ TCAF TCFD .T$CW T$C~ INN~ · ', G~ ...CCh DEFI ..... ........ :;22 ....... ";':"" ....... ""'"'""" SIG~ Sloma (~eu Capture r ss Section) mDT morosit¥ norehole Sigma - far detector norehole Sigma - ~ear detector $1oma Correction Corrected ~orehole Sigma mation Total igear to Far counts 8tanaard d~vlatien of Sigma gacKground Count Rates - Near Detector macK~round Count Rate - Far Detector Total counts analyzed Total counts analyzed - far detector (TDTP) Total camture counts - Near detector Total capture mounts - far dectector. Total Selected Coumts - .ear Detector Total Selecte~ Counts'- Far Detector Inelastic count rate - near detector Inelastic cot]nt rate - far detector Surface Tension APl-Corrected Camma CCL ~mplitude .. ** DATA FORi~AT ~PECIFTC .~ION ~EC0~D , . ** ,SET TYPE TYPE REPR CODE VA~UE 1 66 0 2 66. 0 4 66 1 5 66 6 73 7 6,5 ~.' ~ o.~. 9 65 ~T' 1~ 66 I?' 68 1') 66 0 Ia Ta~e Yertffc,~t!on [I~E~P,~ l~-JAN-.!995 0~:04 :Mlumberqer /~l, asKa cu~ut~,~,~i Center NA~? . T D~PT $IGv PS]. TDHT PS1 $~H~ P$!. $~H~' DS 1. TPAm SDST 'F~A¢ TCA~ TCA~ TCND TCF~ TSCr INND 'INFD P$1 G~ ~.....,.CCb.. PSi 15 6f~ 68 16 66 o 6,5 1 RV UWlT .' .... ICF APl PI APl APT O ~DnE~ ~ LnG TYPE CGASS F'r 4~241 O0 000 00 0 Ct! 480241 00 OO0 00 PU 4~241 o0 000 O0 0 C{? 4G~241 O0 OOO O0 0 CU 4.~241 nO 000 O0 0 CU 4G~241 O0 CO0 O0 0 CU 48A241 O0 000 O0 0 48~24.1 O0 000 O0 CU 488241 O0 OOO O0 0 CPS 48R241 oo 000 00 0 CPS 48~2~i OO 0o0 O0 0 CPS 48~24~ 00 0o0 O0 0 CPS 48~241. oo 00g 00 o CmS ~.8~241 o0 000 O0 0 C°S 4~82dl o0 o00 00 0 CPS 48P241 O0 000 O0 0 C~3 48~241 oO 000 O0 0 C~S 48~241 O0 000 O0 0 CPB 4@~241 OO 000 O0 0 h~ 4.8~241 O0 000 O0 0 GaP! 48~24i O0 000 O0 0 .. ~...V .... 4.88241...00 .... 0.00 , * D A T A * * DKPT. 946'9.000 SBH)~.D$1 42.088 SDST.P$I 0,759 · TCA~ ~$~ 0807.189 TSC~iD$1 1961.478 G~ PS1 46.594 '.D~PT. 8894.000 'SFH~.'PSI 45.9~3 SDST'.P$1 TCAW.US! 29193.65~ T$.CW.DS1 :)637.853 G~.DS1 35,9~9 FILE NUMB NUMB SIZE EPR PROCESS mm~mmm~~mm~mmmmmmmmm~m~mmmmm~m~mmmmm 7 1 i 4 68 0000000000 7 I 1 4 68 0000000000 U 1 1 4 68 0000000000 7 ! 1 4 68 0000000000 7 1 I 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 ? 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 ! 4 68 0000000000 7 1 I 4 68 0000000000 7 i 1 4 68 0000000000 7' I 1 4 68 0000000000 7 1 ! 4 68 0000000000 7 1 I 4 68 0000000000 7 1 .1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 ? I 1 4 68 0000000000 7 '1 1 4' 68 0.000000000 ? · 4 .6, oooooooooo · '. O0 0 . ..7.. 1.'. · 1.'..' . ."4 ...... . . 6,8. ..0000000000 · SIGC.PSl ~ 350 SiBH,PS1 42'088 TRAT.PSI ..~.',.'934 B'ACK','PSi 9 '1947 PBAC.,'P$1 45.-.120 'TCAN.PSI' TCNO.P$1 ~4742.613 ~CFD.P.Sl 7.654.778 .TSCN,P$1 '5883'..,442 I~;ND.P$I 2315.88~ INFD.P$1 428~724 TENS PS1 .'1135.000 o5 . ps, SIGN',PSI i '~569 1 48,932 TEAT P.S! -..".$.."534 $1G¢.P$1 "SIBH:~P$.... m.': T ~ 5~ .... ,. ' " -,,....O.PS& 30~..015 INFD.PB'I 444o160 TENS.PS1 .~150.~.000 CC5.P$I 0.000 ' I'$ 'ra.e Yer~.ftcation T,i'st.,Ino .~hlumberqer .~l. asKa Como,~ti.n~ Center 18-JAN-19g5 08:04 PAGE: SFRVICE V~RSIOq DaTF ~X RFC STZ~ FTLW TYPE FTb~ UU~BFR CUR Curves and log header data ~or each pass in separate P~$~ ~U~BERt 2 DFPTH INC~EgENT: 0.500{) ............ FIEF..$'U~MA~Y · · . ....... VE~DOR'TO'OL CODE .START DEPTH ?DTp 9467 0 L~G H~ADER' DATA DATE LOGGED: '$OFTWA~ V~RSIOt,~I TD D~ILU~R (WT)~ · 'D LOGGER (FT): ~OP ~O~ T'NT~R'VAb ROTTEN bOG I~T~RVA[~ LOGGTN~ SPEED (FPdR): lOu.., ST~ISG (TOP V~ND[)~ q'OC!5 ~.0£;~ TOOL TYPE 'STOP'D~PTH."' ~tles; 'raw bacK,orounc~ Pes. s'in 1ast"~tJ !4=JUN-94 38,2' 144 I~-JUN~g4 9~3.0 "' 9452.0 B900'o 94'45,0 1800',0 NO TOOL NUMBER IS ~a~e verifY_cation 18-JAN-~gg50P. J04 PAGE: 39 TOTP TOTP T..n.. TP TmTP T,..nTP I'OTP S HDw CAb=UB-l~69 &TC-CB=1199 TNC-P-14! TNO-P-75 TNG-P-236 ~T~-~B-283 ~[]PEHOLE AND OPEN ~OLE mRTbI,[.:~ C~6Tr.~O nEPl'~ (FT): bOGG~'. $ CA~I~}G ~0~ F;NOI.,E FLUTD i)E~'.~ ~ l ~ Y BOTTO~ HOLE FLUTD SAL!~:T'.rY (PPis:); ~.~I~ LEVEL FI, UID RAT~ AT ~Lt, M~D (BPM)~ '~ATER CUT~ (PCT) C~{OKE (DE~) ~?.E~T~ON TOOL TOO[., TYPE (EPI'rHE~MAL OR THER~AL)~ ~ATRIX DE~:~S XTY.; BLU~I,INE COU~?~T RATE NOR~Af, IZA~ION IM OIL ZONE BASE NOR~AbIMIMG WI[~DOW . . ~ '~ . ~ . TOoL ST.ANDOF? ~,PPRRS THAT ~'~i3T .A~',I.~ GAS' WAS FbUSHFD 'DURING PASS ~UMPED ~30 BB.[,S. SEAWA?~R/iO0 B'BLS BORAX/170 B'Bb8 "8'EAwATER, $ 2480.0 SEAWATER/BORAX 40,0 180.0 THERMA5 SANDSTONE TIED INTO BHC ('SWS) DATED 08-JUN-86, # LTS FOR ~;,Am Tape ¥~rt.f~cation l..ist,inq cblUmberoar Alaska Co..-,.~:~utln, Center iS-JA~-lgg5 08:04 PAGE; 40 C~ 0 Coem, p~n a~e F~ P~UD~OE ~¥ Fi ,1 , ama FI, 1~17' F~L & 15iX' FWL SgCW 8 C~U~ NORTH SLOPE STAT ALASKA N~TI bSA WTT~! D. $0~ 498241. E~D ~T 0 L~F APD FT 70. E~B ~T 70, EDF WT 69, TDD FT 9~63, TDL FT 9452. BLI FT 944~, T5I ~T 800.. DFT SEAWATER/BORAX TLA~ 14:42 14-JUN-94 .... Well Name ~PI Serial Number Field Location Section Township Range County State or Province Nation Witness .ama Service Order Number Permanent datum ~levation ot eermanent Oatum Log Measured From Above Permanent Oatum Elevation of Kell'¥ Bushing ~levat~on o~ DerricK. FlOor Elevation of.Ground Level Total ~ept~ - Driller Total. Depth - Log~r 8ottom LOg.Interval Top boo InterVal: .' Orill~ng Fluid'.Type.. Time.bogger.:'at .Bottom .Surtace.'Temperature. ..Bottom..Hole.Tem~erature ...... , ....... :,. .. :. TRB[,E. TYPE. ; C.UnV. . D~FI ~.emmmmmmmmeme'mmmmmmmmmemmmmmmmmemmmmmmmmmmmmm'mm'mmmm'mmemmmemlmm $IG~ S'TGC .TRAT SDS7 B.~C~' FnAC TCAN TCAr TCND TCF~ TSC~ neDth $1bma fheutron Capture Cross Section) TDT Porosity , Rorehole S~qma - far detector ~oreholeS.!gma - Near detector Sigma Correction Cor~ected'Forehole Slqm9 Ration Total 'Near to Far counts Standard deviation of Sigma ~ack~rouDd Count Rates - Near Detector ~ac~oround Count Rate - Far Detector Total, counts analy~e~ - near'detector CTDTP) Tote], counts analyzed -. far .detector CTDTP) · ota! capture counts - Near detector Total capture Counts - far d,erector' Total Selected Counts - Near Detector IS ?awe 'v',ri~-icatlon t,istino Chlumber~er A!asKa Comput.tno. Cemter 1B-,..IA~g-1995 08:04 mmmmmmmmm mm m . m mmmmmmmmmmmmmmmmmmmmm I~'~ Inelastic count rate - near detector I~FD Inelastic count rate - far detector TFN$ Surface ~ension G~ APl-Corrected Gamma Ray CCL CCI., A,nolltude ~mm~mmmmmmmm~mmm~mm~mmm~mmmmmmmmm~m~m~m~m~~mm~ 4% ** ~ATA FORe'AT SPFC?FICATTO~ PECORD ** 2 ~6 0 3 73 4 66 5 66 6 73 7 65 9 65 · 1.} 66 ~? 6.8 13 66 0 14 65 PT 15 66 6,8 16 66 0 66 **' SEw T'¥~E - CHAM ** NAHr SERV UNIT SgRVICE API AP.~ APl AP! FILE .NUMB NUMB 'SIZE' REPR 'PROCE.$& ID .ORDER # bOG TYPE CLASS MOD NUMB. SA'MP ELEM ..... CODE .,(HEX). ., mm~mmmm~mmM~mmm~mmm~mm~m~m~m~mmm~mmmmmmmmmm~m~mmmmmm~mmm~mmmmm~m~mm~mmm~m~m~ D~P~ ?? 48~41 0g 000 00 0 8 1 .~ 4 68 0000000000 "~. . . . 'SIG~ PS9 CU 4.8.241 00 000 00 0 8 · ! 1 4 68 0'000000000 TPH!' PS2 PU 48~241 O0 000 O0 0 ~ 1 1 4 68 SBHF P$~ CD 48~241 00 000 '00 · 0 8 I i 4 6.8 S~H~ PS2' CU .48'~241 OO 000 nO 0 8 1 1 4 68 $IGC P$2 CU 48R241 O0 uO0 O0 0 8 I I 4 68 SIB, PS? Ct! 48~241 O0 000 0'0 0 8' I 1 '4 6g · TRAT PS2' 48~2aI OO 000 O0 0 8 1 .1 4 68 SDST PS2 C!~ 48R241 O0 000 O0 ' 0 8 1 1 4 68' BAC~ P$~ CPS 48~241 00 000 O0 0 ~ ~ .I 4 68 · FBAC PS9 CPS 48R'241 00 000 O0 0 · 8 1 I 4' 68 TCAN P$~ CPS 4B~2~i 00 000 O0 0 8 1 1,. 4 '6g TCAF.P$~. CPS a8~241 00 000 oo 0 8 I I 4 '68 0000000000 0000000000 0000000000 0000000000 0000000000. 0000000000 0000000000 0000000000 0000000000 00.00000000 0000000000 IS Ta~e verlflcat.ion List~n~ 18-JA.~,-,-1995 08:04 ChlUrnbera.*r AlaSKa Co~,~.o~tlna Center PAGE: 42 TCN~ P$2 CP~ 48824.1 O0 TCF~ P62 CP~ 45~2~1 OU 000 OV O ~ 1 TSC~ P~ CPS 48P24! Ot~ OOO O0 0 8 ! T$CP P$2 CoS 488241 O0 uno O0 0 8 1 I~FO PS2 C~S 4~g24i T~N~ PS2 bP 488241 O0 000 OO O 8 1 GR u$2 GaP! 4.8q2a! ,~r) 000 oO O 8 1 mmmmmm mmmmmmmmm mmmmmmmmmm mmmmmmmmmmmm mm, mm ..... i;i ......... ;,m,m;~).)mm,.m ..... mmm;mmm,mmmmmm,mmmmm;m; ..... mmmmmmmm# R~:~VTC? ~'Pl AP I PILE Nij~ NUMB SIZE E R PROCESS U~B SAMP EbEM ~ODE (HEX) mmmmmmmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmm 1 4 68 0000000000 1 4 68 0000000000 1 4 68 O00O000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 00OO000000 1 4 68 0000000000 1 4 68 0000000000 DEPT. 0467.009 SiC~i,P$2 14.05~ SRH~'.DS2 45.9B3 .gIGC.P82 1.569 SDST.PS2 0.3]1 ~ACK.PS2 1i4.411 TCAF.PS? 10'1.93.652 TC~D,P$2 ~173 934 T~Cr.D$2 3637 8~.'~ INNO:.P$2 ~30~015 GP.PS2 4.7:469 CCh. PS2 0.0o0 D~PT, 8893.500 $IGM,,PS2 13.968 SRH)? P$2 40.162 ,>IGC,.PS2 1.540 SDST.PS2 0.316 '~.ACK'..PS2 145,193 . 'cc PS2 ~6385 648 TCAF,PS? 19859 3~2 · T$C~,PS2 3763.297 T,~i~ID.PS2 **** FTL~ TRa. ILER **** .'FIL~ NA~!E ~ EDI'T ,OnB. S~RVlCE : FLJC VERSION : 001. C01 D~TF ~ 9~/12/23 MiX R~C SIZE : 1024 LAST FILE TPHI.P$2 18.322 SBHF.PS2 8IBH.P$2 48.932 TRAT.P$2 BAC,PS2 25.~'33 TCAN,P$~ ~CFD,PS2 g806,934 T$CN.P$2 INFD,PS2 444..160 TENS,PS2 TPHI.,.PS2 18'099 SRHF.P$2 SIBH,P82 49..240 TEAT.PS2 FBAC,PS2 30,720 TCAN,PS2 TCFD.PS2 I01'08,338 T$CN,PS2 INFD,'P82 471,067 TENS.PS. 2 i56' 17433,938 1055'000 35-299 ':~',527 40388'~945 '.7653.~'61,2 1175.000 I$ Va~e 'Ver~.f~cat~on r,ist~no Chlt.'mher~.r AlaSKa CO~.PUt.lp.,U Center 18-JAN-1995 0~104 SFRVIC~ : ~LlC V~R~IC:~; : oO~CA1 DA~F : o4t1~/~3 F~LF TYPE : LO L~ST FI[,E FIb? ~Uk':B~ 9 RAW C[~RV~S Curves ano log header data for each pass in separate pA$~ ~U~BFRI 3 ' DFPTH .I~!C~E~ENT: n. FOo0 F?L~ ~O~ARY YES'Dna. .. .. TOOL CODE START D,~P~HF "' TD~P 9466.5 bOG HFADE~ DATA DATE bOGGED: SUFTWA~E. VERSION: TI~ LOGGE~ ON TD D~I'bLER (FT)S V'~NDOe TOOb CODE TOOl., TYPE TDTP TDTp TQ.TP COLLAR LOCATOR ~ ~.. TP AUXtLLI~RY CART~IDG~ T~TP TDTP CArTrIDGE TDTm' TOT~ DETECTOR TgTP Tr}TP ~EHE~ATOR T~TP AUXTLLI~RY ~ODULE ~OPE~OLE AND CASING DATA OPE~ HOLE BTT SIZF [$~): DRILLERS CASING DEPT~ LOGGERS CASING D~PTH ~OREMO!,,E CONDIWIO~$ .FLUTD TYPE: STOP DEPTH 8~gI.5 fXles; raw bacZoround pass in last'fi 38,2 ~442 9563.0 9452 8900.~. 944~60 i800 NO TOOb NUMBER emmmm'mm.mmm · . HOW 'CAb-UB-1269 'ATC-CB-II99 T.NC-P-141 'TND-P-?5' TNG'P-236 A.TM-AB-283 2480.0 SEAWATER/BORAX IS Tame Yeti fi. carlo, t,istino chlumheroer AlasKa Computina Ce.tar · .. i 8-jAW-.lgg5 08:04 PA(';,E ~ 44 SURFACE TF~P~,PA'_r.U~E (mE,F); ~b~I~ LEVEL (FT): FLUTD RATF ~T ~FI.,[,H~AD ~vAT~R C~T8 CPC'i): ~.A'rel~ DE~.~SXTY: ~LU~LXN~ COI!NT RATE ;~OR~ALIZATIO~ IN OIL ZONE · 0p NU~blZII',~G WINDOW CRT): BLIIE[..INE COU~aT RAT~ SCALES SET'BY FIELD ENGINEER ~AD COUNT PATE bO~ SCALE ~,~EAR C..-UNT R .,E ;~IGH 8CAbE (C TOOb $TA~OOFF (IM): TIED INTO BHC (SWS) D~TMD 08-JUN-86, 40.0 180.0 THERMAL SANDSTONE 2.65 APP.F..RS ..P~AI PlOT ALb"GAS WA$ F[,USHED DURING PASS '" ~'U~PEn ~3o ~'~[,S S~AWA?E./~00 B~t,S 80RAx/t?O 8BbS SEAWATER,:· ['T'S' ~o~r~A'~' ~A'?~' : ....'" '. .......... .. . . '. TRBI..,E TYPE ~ C0~]8 . TUN l VAbU DEFI, . ". ....... . .......,; . CN ' ' ARCO AbA:SKA, 'INC,'. ·Comp·any Name F~ P.RUDHOE BAY well Name. W~ Ol-2.g · FI., 1017' 'FNb.& 1511' FW'b · SFCT 8 TC~ 1ON R~N~ 1ME · COU~ NORTH ~OPE STAT ALASKa NRT~ USA WIT~ D, API Se'rEal Number 'Field.Location 'sect/on..' Township Range· County State or erovinee. ~ation ~itness Name IS ~a~e '~'er.if.i. catfon L~.~t..fnn ChlU.mher¢;~r AlasKa ?o~F~utln.~ Center 18-JA),!-lgg5 08:04 PAGE'~ 45 Ti~ ~i '? VALU DEF! $0'~ 4~8241 Service Order Number WI APD ~'T 70. EKB ~':~ 70, E~F FT 69, E~L WT 39,7 ?~D ~'~ 9563. T~L w'l' 945~. B~,I WT 9445. TX,! FT 8900. DWT $~AWATER/BO~AX T~A~ 14:42 14-J~N-94 B~T Permanent datum Elevation of Permanent Datum tog Neasured From AOove Permanent Datum Elevation.of KelX¥ B~sh~ng Elevation of Derrick Floor Elevation of Ground bevel Total Depth'- Driller Total DePth - hog,er ~ottom bog Interval Top bog Interval Drilling Fluid TYpe Time bogger at Bottom Surface'Temperature 4O ~EGF 18o. Bottom Hole 'Temperature . .. TaB[,E TYP~ : CU~V TPHT SIGC '$)B. TRAT SDS? .BACK ..F.BAC ..... · T~A~ TCAr TCNO TCFD ,T~C~ INN~ DEF! Depth.. $1oma (~eutron Capture Cross Section) TOT Porosity Bor.eho)e $iqma - ~ar det'ector Rorehole Sigma - Near detector Sigma Correction Corrected Borehole Slam. ~at~on ~otal ~ear to Far counts Sta.~ard deviation of Sigma BacK.rOund Count Rates -.Near DetectOr ~a.c.z~roun. d C.ount..Ra..~e - ra~.net.ector..' T'Ot:a~ count's' a6algzed"-;neat de't. eCtot C'TDTp) Total counts analyzed - tar detector..CTPTP) Total ea'~ture counts -'Near.de.tee. tot Total ca~ture Counts - far decteetor Total Selected Court.ts . Near Detector ?oral'Selected Counts - ~ar Detector Inelastic count rate - neat detector Inelastic count 'rate - far'detector Surface TenSion aP)-Correct.ed ~amm~ CCi a~Dl~tude memmmmmmmmmmmmmmemmmmmemmmememmmmmmmmmmmmmmemmmmmemmm.mmeem iS Tape Ver~.'ftcatton [,istt. nc :hlumberg~r AlasKa Com~ut~Dq Center 1R-JAN-19Q5 08:04 ** DAWA F~R!~AT SPFCIFTC~TION PECO~D ** 2 66 0 5 66 7 65 B 68 0.5 9 65 1~ 66 0 14 65 15 66 68 16 66 1 0 66 ** SET TYDE - C~AN ** ... NAM~ SER. V UNI? SERVTCE ADI hPI' API ~PI FILE' NUMB NUMB SIZE REPR 'PROCESS '. ID nRDER ~ LOG TYPE CLASS MOD NUMB SAMP.. ELaM ,CODE. '(HEX) D~PT FT 48R241 O0 000 O0 0 9 I I 4 68 .00.00000000 $IO. PS3 CU TPH? PS] SBHm PS] CU S;GC uS3 CU ] :<.,.SIBH .PS...I' 'SDS! P$3 CT.{ 488'241 O0 488241 O0 48~241 O0 488241 O0 48~241 O0 4,88,,2 O0 4882~I''00 48P241 O0 F~AC .TCA~ PS] TCAF PS3 · TCND PS3 TCF,~ PS] TSC~ · ,' TSCr 'INFD PS] TFN~ PS) G~ PS3 0o0 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 0.0.0.. O0 0 000' 00' 0 000 O0 0 CnS 48~241 0'0 000 O0 0 iP$ 48~241 oO 000 O0 0 PS 48,2,1 O0 000 O0 0 9 '1 1 9 '1 1 9 I 1 g .t 1 9 I 1 9 I 1 9 1 I 9 .I i 9 ! '9 I 1 O 1 't 9 I 1 9 1 '1 9 1 9 1 .1 q I .1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 '68 0000000000 4 68 0000000000 .4. 6.8. .000.0.0.00000. 4 6'8 0000000000 4 68 0000000000 4 .65 0000'000000 4 68 0000000000 4 68 0000000000 4 '68 0000000000 4 68 0000000000 4 .68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4' 68 0000000000 4 68 0000000000 4 68 0000000000 CCL. PS] V 4882'4I O0 000 O0 0 o - I 1 4 68 0000000000 mmmm~mm~Mmmmmmm~mmm~e~m~mmm~mm~mm~m~m~mmm~m~mmmm~m~mee~eem~emM~memeee~m~e~me PAGE: 46 :hlumheTger AlasKa Com?~tlno Center 18-JA~{-1995 08=04 DFPT, o466,50t, SRH~,P$3 4~,162 SIGC,PS3 TCAF,P$3 198~g.312 TC~U,FS3 T~C~.P$3 3763.297 GW.P$3 53.40~ CCL.PS~ 40 SIRH,PS3 ~45i. 93 FBgC.P$3 ;6385 48 TCFD,P$3 2!~og~4 INFD,P$] 0,000 DFPT. nSqi.500 SlGa. PS3 $~$T,PS~ 0.409 BACK.PS3 TCAF.~$3 14119.146 TCND PS3 T$CF,P$~ 2701,544 I:~ND[P$3 GW,P$~ ~6.969 CCh,PS3 1,770 SIBH,PS3 154.~65 FBAC'P$3 ~0810.67~ TCFD,PS3 2126,61~ INFD.P$] 17.344 SBHF.P$3 61.099 TRAT,P$3 30.791 TCAN,P$3 7863.604 TSC~.P$3 445.563 TEN$.PS$ 527 4038§,945 7653,612 42'832 1~449 2~604,695 5281,.857 ~245.000 FIb~ NA~E ! EDTT ,009 VERSION : 001C01 DaT~ ~ 94/1~/23 M~X R~C 5IZ~ : 10~4 F~L~ TYPE ~ 50 L~ST FILE = · FIbE NA~E : .EDIT .010 SERVICE : ~blC · .. VERS. ION : 001C01 ..~' ......... DAT~ ...... : q.~/12./23 .. FTb~ TYPE .: LO FIL'~ HEADER URVE$ ..... RA~C~rves and lo~ ~eaaer data t°r each Pass in separate .~i. les; ~raw.bac~arOund Pass'in last'"fi P~S~ NU~BER: 4 DFPTH IgC~E~E~T: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPT~ STOP DEPTH , :hlumherc.,er Alaska Computtno Center 18-JAN-1995 0~:04 TOOL ST~It~G (ToP TO ~30TTO.~,~) ¥.F. NDOR TOOi~ CODE ~OOL TYPE 3.'~TP T~TP TPTP T~TP TDT~ $ COL[,A~ LOCATO~ A~IXTI, I.,IARY CART~IDG~ TDTP CARTRIDGE TOTP DE?ECTOR T~TP GE,'~E~ATOR AUX.]:DT.,I ART ~ODULE 14-j1.1~-94 38.2 1442 9563.0 9452.0 8900.0 9445.6 1800.0 NO TOOL NUMBER 14-JUN-94 CAL-UB-1269 mTC-CB-1{99 THC-P-141 THO-P-75 TNG-P-236 AT~-~B-283 MO~EHOLE A~!D C~$ING DATA OPEN ~OI.,E 8TI SIZE (IN): DRILLE~6 CASING DEPTH LOGGERS CA~ING D~PTH FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TFMPERATURE (OEGF): BOTTO~ HOI~E TEMPERATURE (DEGF)~ ~.~T~ CHTS (~CT): G~S/O~'5 ~TXO~ CHO~E ~EUTROM ToOL TOOL TYPE {'EPITgERM~L OR THERMAL): ~AT.I× DE~r$ITY: HOLM CO~RFCTIO~; 8[,UELT~'E COHN~ RATE NORMALIZATION IN OIL ZONE TOP NOR'MabIZIN~ WIMDOW (FT)~ ~ASE. ~OR~ALIZI~G '~!~DOM (VT): 8LUEI.,I~E COU~iT RATE'SCALES SET 8Y 'FIELD ENGINEER FA~ COUNT RATE bO'!~ SCALE ,,,=. R COUNT R~T~ LU~ SC~l'.~ (CPS 2480.0 SEAWATF. R/BORAX 40.0 .~80.0 THERMAL 'SANDSTONE 2.65 4e IS Ta~e ver~.f{¢at~on l,,lstlng Chl~m~er{]er Alaska Computlna Center 18-JAN-1995 08:04. 49 A"F H . TOOL . .,u ) LIS F~R~ TaB~.,E TYP~ : CONS 1:.. VA t, U DEFI ,. FT FT WT FT FT C~ FI, R~NC, STAT N~T! WI, TN SON' POAT APD :' ...... E~B EOF ""'. .T~D .TPL D~T T[,A~ STE~ ARCO AGASKA, INC. PRUD~OE BAY '01-29 $ 1017' FNL & 1511' FW~ 8 NORTH SLOPE ALASKA ?.0~... ..... .. 7'0, .39.7. 945~, Company ~ame Weli .ame APl Seria Number Section Township Ranqe' Countv · .State. or. ProVince ~ation ~ltnes. s. uame... Servlce'.Order ~umber' Permanent,datum · , ~levatton. o~'~ermanent.:~atum ~o~ ~ea~u. red:...'F~o~ · .A~o.¥e..~e~mlne~'..~Dlt~ ..... .,~.... Total ~e~t'~":- ~rllt. er ' Total:Depth.'- ~ogge'r': 9445' 8Or'tom bO~ Interval 890'0; 'To~ bo~ 'Interval.. SEAWATER/BORAX O~ll"i'ng Fluld':~y~ 14:42 I4-JU~-~4 Time.bogge'r at .Bottom. DEGF 40 Surface'.Temperature .... .............. 1R-JA~-Igq5 08:04 DFFI DFPT DePth'.,. ''=''' $IG" Sioma (Neutron Capt~]~e Cross Sectior~) TPH? TDT SRHF ~orehole $1g~a - far detector $gHW morehole $iq~a - ~ear detector $!GC Sloma Correction $?Bw correcte~ ~orehole $1q~a T~AT Pat~on Total ~ear to Far counts $D8I Standard deviation of BaCK ;~acKoround Co{jnt Rates - ;=~ear Detector F~AC ~acK~round Count Rate - war Detector rCA~' Total counts a~alyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TOTP) TCND Total capture counts - Near detector TCFD ~otal capture Counts - far dectector T$C~ Total. Selected Counts - Near ~etector TSCW Total Selected Counts - Far Detector INN9 Inelastic count. ~ate - near detector INFD IDelastic count rate - far detector T~N$ Surface Tensi. on G~ ~Pl-Corrected Gamma ~ay CC~ CCI., AmPlitude PAGE~ 50 SET TYPE.- TYPE.. ....... R~P~ CODE 1 66 0 2 66 0 3 73 88 · 4' , 66 ~ 7 65 8 68 0~5 9 65 ~' I1 66 11 1~. 68 13 66 0 14 65 ~'T 1~ 66 68 16 6b ). 0 66 ~ Tape Yeriflcat~om Li$tlnn Chlumberqer AlasKa Computino Center l~-JAN-~995 08:04 D~PT FT 48~2 SIG~ PS4 C¥.! 4~82 TPH! PS~ PU 48P2 SFH~ P~4 CU STGC P$4 CU TRAT PS4 4BP2 SDS! P$4 CU ~882 B~CK PS4 CPS 48R2 TCA~ v$4 CPS 48~2 TCAF P$4 CPS 48~2 TCND P$4 CP~ 4882 TCFn P$4 CPS 4882 TSC~ eS~ CPS 48~2 INND PS4 CPS 4882 INF~ PS4 CPS 4882 CCD P$4 V 488 4.[ O0 41 O0 000 O0 0 41 nO 000 O0 0 1 41 o0 000 O0 n 1 ~.! O0 OoO O0 0 1 41 n() 000 O0 0 1 41 oo 000 oO 0 41 oO uno O0 0 1 41 O0 O00 O0 0 41 O0 000 oO 0 1 ~1 oO 0o0 O0 0 4! O0 000 O0 0 1 41 oO 000 O0 0 1 41 oO 0o0 O0 0 ~1 O0 000 O0 0 l 41 O0 000 O0 0 l 41. O0 000 O0 0 4i O0 000 O0 0 41 O0 000 O0 0 41 O0 000 O0 0 1. ~ ........... LE NUMB NU';;II;~I;;ll;;;;-IIIIIIIIIIIIIII|IIIPROCESs U~B SANP ~b~l CODE !HEX) 1 1 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 OOO0000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 241 OO 000 O0 0 lO ! 1. .4 68 0000000000 241 .00 000 O0 0 10 ! 1.' . 4 68 0000000000 SSH~.PS4 SU~.P$4 $BHN.PS4 .$DSI,uS4 .TC.AF.PS4 TSCF,P$4 G~,PS4 V469'.5o0 S~C,.VS.4 49.'1~0 112104ll3''068' TCND'PS. 4. 62'81'3 CCh'PS4 8891 000 Sing..PS.4 81:i~5 ~:IC~.pS4 25'55.',897' t~N'O~p~4 ~8.1~6 CCL,P$4 198 159.936 0,000 0,1~6 1.41'5114'66 2~15 654 04 365 0.000. $IBH:.PS4 rBA¢,PS4 .. ?P~I:.pS4 SXBH.P$'4 FBRC',P$4 TCFDll, PS4 lN'FD:iP.84 117l''l'492 54..6 P$4 TCAN..P84 27414,.907 '.3. t:.5.9'.'~...659 41.73..1759 '.ll'95',000 51 :hlumber.~er AlasKa Computlno Center 18-JA~4-~995 08:n4 FTLF ~'AU~ : EOT~ .010 SERVIC~ : FLTC VFR~ION : 09~COl M~X R~C SIZE ~ 1~4 L~$T FILE FTb; gE~OMR CIIRVES Curves and log header data for each pass in seoarate D~P?H I~C~E~E~T~ 'FILF VENDOR TOOl, CODE START.DEPT~ TDTP 9464.0 $ · STOP DEPTH .8893,0 :~:,....,...LOG HEADER'... DA:TA .. .# 'DATE. bOG'~ED: 80mTWA~g VERSION! 'TIME' LO.G~E~ O'N BOTTOm: TD D~ILLER' (WT): TD LOGGE~(FT)~ · OP'LO~ INTERVAL (FT): ROTTO~ b~G INTERVAL LO~GIM~ SPEED ~E~TN CONTROL !.!SMD (YES/MO): TOOL STPI~aG (TOP TO BOTTOM) V~NDOP ~OOb 'CDDF TOOL TYPE TDTP TDT TDT~ COLLAR LOCATO~ TDTP A!~XIbLIARY'CARTRIDGM TDT~ TDTP CART~IDG'M 'TDTP TDTP DE~ECTOR TDTP T~TP GEMEPATO~ ~lles~ raw.bacX~;round· 14."j'U.N~'94 38,2 1.442_ 9563,0 9452',.0 8900.0 9445 0 18oo',.6 ... 14-JUN'94 HDW 'CAI,-UB-1269 ATC=CB-I199' .TNC-P-~.41 TNG-P-~3,6 X8 Tape Verl~cstlom Listlnq ~hll]mber. c~er AlasKa momp~t~.['~q CeDter 1B-OAN-~9q5 08:04 '53 # ~DTP AUXIIJLIARY $ OPEN HOLE BT~ ~IZF DRTLT.,E~S C~ST~G DEPTH LOGGERS CASI~!G DFPTH FOREHOLE CONDITIOn, S FLUTD TY~E~ ~bUTD DENSITY SqI~ACE TFMPE~ATt~nE BOTTO~ HOLE T~PE~TU~E Ft, UID SALINITY FbUID LEVEL FI.OlD RATF IT ~LLHEAD ~AT~R CUTS (PCT)~ G~S/OIL RATIO: CWOKE (DEC): TOOl., TYPE (EPITWE~Ab {)R MATRIX: ~ATRIX DENSITY: 8LU~LINE CO!.~NT. ~ATE NORMALIZATION IN OIL ZONE TOP NORMALTZTN~ WINDOW BA$~ NOR~ALIZ!NG WTN))OW BLUELIME COUNT RATM $CAbF$ SET BY.FIEGD ENGINEER wAD COUNT RATE bO~ SCAL~ (CP$)~. ~AR COUNT DATE HIGH $C~hF NEaR COUNT RATE LOW '~N~r''''-'-''":'-'s?A DO~ (~), '"'" "" "'"' =' " AT)~-AO-2B3 2480.0 SEAWATER/BORAX 40.0 180.0 THERMAb SANDSTON~ 2,65 'TIED INTO. BHC (8~8) DA~RD 08-J'UN-R6. ~ · . APPERS T.HAT NOT A.I,L GAS WAS FLUSHED DURING. PASS , UgnMP 230 BOtS SEAWATER/100 EBbS BORAX/iTO B'BbS SEAWATER.,' $ ~T$ FORe, AT DATA TABLE TUN! VALU ..... m m m m I m m m m m · CN ARCO Ab'ASKA, INC. ComPeDV Name'. FN PRUDHOE BAY 'Fi:eld Na I$ ~ane V~r~flcatlon Llst~na chlumberg~r ~l.a~a ComputXn~ Center l~'JAN-1995 08:04 PAGE; ~54 TU~T VALU. DEF! ' W~J D.$. ol-2g Well Name A~IN 50-02g-~1604-00 ~! Serial Numbe~ F!. 1017' FN~ & 1511' FW~ Field Locatio~ iKCT 8 Section TO~ 10N Township R~N~ 1SE ~ange COU~ ~ORTM 6LOPE County S~AT ALASKA State or Province N~TT tJSA Nation WTT. D REE~ Witness Name SON 4~8~41' Service Order Number P~AT ~SL Permanent datum EPD FT O, Elevation.of Permanent Datum L~F RKB Log ~easured. From A~D rT 70. ~bove Permanent Datum EwB FT 70, Elevation of Kelly BuSh~nq E~F rT 69, Elevation of Derrick Floor E~L ~T 39,~ Elevation o~ 6round Level T~D ~T 9563, Total DePth'- Driller TDb mT 9452, Total Depth - ~ogger Bt, I ~T 9445. Bottom bo~ InterVal TtI FT 8900, Top bog 'X6terVal: . D~T iEA~ATfR/~O~AX Drilling FlUid TYpe · TLA8 14=42 14-JUN-g4 Tlme..L.o~qer.'at. Bottom STE~ DEGF 40 Surtace'Temperatu.re. BHT nEGF .1~o ...... Bottom Hole .Temperature' I ............... 'T~BLE TYPF = CU~V .D~F! .. · D. EP.T D~.Pth · · ":'"' ~IG" Slcma"'~'~eu"t"ron'C'aP~ur'e C"r'°ss'Sect'i'on) TPH! TDT. Porosi '6~H~ ~orehole $Xg~a'- ~ar detecto~ $~H~ 8orehole $1~a = ~ear'detector S~GC Stoma Correction S.~B" Corrected. Bore~ole sigma T~AT Ration TOtal Near to Far counts SDS! 'Standard deviation'of Sigma .B.~C~ BacK,round Count Rates - Near 'Detector FBAC BaCkcround Count Rate - Far Detector ~CA~ Total counts analyzed - near detector (TDTP] TCA? Tota! counts.analyzed.- far detector · TCN~. Total 'camt~.]r'e counts'- Near ~etector TCF~ Total. camture Counts - far .detractor' T$C~ Total Selected Counts - Near Detector TSC~ Total Selected Coumts - ~ar Detector "iNND ~nelastic count rate - nea~' der'actor · INF~ ~n~lastic count rate - far'detector T~NS Surface Tension IS Tap. e vertitc.tio~ I.,is~i, nq 19-JA~-'1995 0~:04 PA6E~ chlumbera~r alaska Co~r..~tlr~o Center '55 OEFT CCL Ar~,~litu~e IIIIIIII~IIIIIIIIIIIII$II ~IIIItI~IIIIIIiIIIIIIIIiiiIIIiiIiiii DATA 2 66 0 3 73 4 66 5 66 6 73 7 65 11 66 11 1~ 66 0 14 65 15 66 68 16 66 '! o 66 ImIIIIII$ItIII~$.IIIIIIIIIIIIII ** SET TYPE - CMAM ** ,. ........ ,'.,..,.:., .NI.M.~ · .$ERV...U.N.I.T. 8tlRVIC.~' APl AP1 . AP!. A.PI, ri.bE .. NU)B .NUM) mSI'[~.... e~Pa P'~.OmCm~SS. la ORDE~ ~ bOG TYPE' CblSS ~OO' NU~BSPAM · E'~M. ":...CODE ' ' (.H'~X) '.. DEPT TPHT P$5 .SIB~ P$5 'TEAT 'SDS! PS5 B~CK 'FRAC P$5 TCA~ PS5 TCA? .TCND 'TCF9 T$C~ T$CF F? 488241 0'0 CU 488241 O0 'PU 48~'24i. O0 CU 4,88241. O0 CU 488241 O0 Ct) 48~24'1 O0 CU 48~241 O0 4~241 O0 C!,) 488241 O0 CPS 488241 00. CPS a8~241 O0 CPS 48~241 oO CPS 48~2~1 O0 CmS 48~241 00 CPS 48~241 O0 CPS 48~241, O0 CPS 48~241 O0 000' 0'0 0 11 .1 1 .4 000 '00 0 1.1 1 I 4 000 O0 .0 11 .1 i 4 000 O0 0 11 1 1 4 000 O0. 0 11 1 I. 4 000 O0 O' 11 I 1 l 000 O0 0 11 1 I 4 O00' 00. 0 11 .1 1 4 o00 o0' 0 11 1 1 4 000 O0 0 11 I I 4 000 oO .'0 11. I 1' 4 000 O0 0 11 1 l' 4 000' O0 0 Ii ! i 4 000 O0 0 !1 1 I 4 000 O0 -0 li 1 1 4 000 O0 0 '11 1 1. 4 000 O0 0 11 t i 4' ' 8 .0000000000 68 ' 0000000000' .65 '0000.000000 68 0000000000 68 0000000000 68 0000000000 '68 0000000000 '68 0000000000 68 00,00000000 68 0000000000 0000000000 .68 0000000000 68 000000'0000 68 0000000000 68 '0000000000 68 '0000000000 68 0000000000 I8 ~aDe Verlflcation l..istina Cblumberqor AlasKa eomputino Center 1~-JA~-1995 PA. GE; ~56 !D n~DE~ ~ hOG TYP~ C~$5 ~00 ~U~B SANP E~EM CODE (HEX) ........ ;;; .......... ;; ...... . ....... ;.................. ..... . .... ..-..-.-;;...... ! N o$~ a8~241 . O~o oO li 1 1 4 6~ 0000 .0000 INFD PS5 CPS 459241 O0 000 O0 O 11 1 I 4 6~ 0000000000 TFN$ P$~ LR 4.8~2~1 O0 000 O0 0 1! 1 I 4 68 0000000000 SDS?.P$5 ~AUK.P$5 0'4n8 TC,O PS5 TCAF.PS5 13367, . T~CF.PS5 9555.8o7 IN~D.P$5 G~.PS5 62.750 CCL.P$5 D~P?. R$93.000 S~HN P$5 ~6.694 SIGC,P$5 SDS?:P$5 0.365 BACK,PS5 TCAW.PS5 1709~..56] TCNDoP$5 TSCF.P$5 3246.533 INND.PS5 ~S~ 66 750 CCL P$5 G~,. ~ · · 0.136 SIBH.PS5 151.466 FB~C,PS5 14215.654 TCFD,PS5 2204.365 INFD.PS5 0.000 14.168 TPHI,P85 1.495 SIBH.PS5 156.540 FBAC,PS5 24~6~.950 TCFD, PS5 1944,955 INFD.,P85 0.000 13.998 SBHF.P$5 I09.~25 TRAT.PS5 14.666 TCAN.P$5 302.3'11 TSC~.PS5 6426.755 T£NS.PS5 21.777 SBHF,PS5 50,I08 TRAT.PS5 · t2" 58 .TCA~,PS5 8950.746 TSC~.,PS5 432.47! .TENS,PS5 i,'292 18~6,667 241 3,759 880.000 :~9~625 .'1,,6.38 37356,383 ?092,921' .1150..,000 END Or DATA S~.RVI.C£ .. :..r.b~ . '"':' VERSION ', '00'" D'T~ : 9.4/17/23 ",~X'REC. S'IZ~ : 1024 FIL~ TYPE D~ST FILE **** ThPE'TR~ILEP **** S~RVICE NAM~ ~ EDTT D~TE O~I~IN T~PF ~A~E : 04]99 CONTINU~TTOM # PREVIOUS T~E ,. 18-JAN-1995 OBI04 O~I~IN ~ RFE[. ~A~E : 9439~ CON?I~II~TTO~ ~ : P~EVIOU$ ~EEL CO~E~T : ~RCO ~[.,~$K~ ~C, [)$ 01-29, PRUDHOE BAY PAGE: · PROGRAM: LIS REVISION: 4.1 PART NUMBER: W5550-MICRO Start of execution: Wed 27 JUN 90 3:50pm WELL DATA FILE: C:\WDSDATA\W04397.WDF ECC: 4397.00 COMPANY NAME: ARCO ALASKA, INC. WELL NAME: D.S. i - 29 FIELD- . LOCATION: Top of Well: Bottom of Well: Level Spacing: 8880.000 9340.000 0.500 NUMBER OF CURVES: 13 DEPTH CCL CLSN LSN SPD SSN CN TEN CNC TTEN CNRA CSSN GR COMPANY:ARCO ALASKA, INC. WELL:D.S. 1 - 29 FIELD:PRUDHOE BAY COUNTY:N.SLOPE STATE:ALASKA TAPE INFORMATION FILE:PASS 1.001 FILE INTERVAL: START= 9340.000 END= 8880.000 DEPT GR SPD TEN TTEN CLSN CSSN CN CNC CNRA LSN SSN CCL 9340.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9315.000 23.784 31.997 251.065 37.420 0.068 47.085 9290.000 18.934 31.997 136.703 35.020 0.071 48.601 9265.000 23.893 31.997 109.828 37.132 0.068 47.079 9240.000 15.636 31.997 44.198 28.331 0.084 62.183 9215.000 14.929 31.961 19.929 29.480 0.081 62.975 9190.000 14.327 30.997 33.440 28.853 0.083 62.143 9165.000 17.749 31.439 25.569 22.964 0.099 82.281 9140.000 23.199 31.997 7.185 38.508 0.067 45.029 9115.000 24.023 31.997 -8.047 34.667 0.072 47.688 9090.000 24.976 31.997 15.077 33.816 0.073 49.082 9065.000 21.421' 31.997 -8.568 27.744 0.085 67.669 9040.000 35.763 31.997 7.358 39.126 0.066 45.428 9015.000 25.582 31.997' 0.110 29.998 0.080 57.901 8990.000 25.591 31.997 -12.326 35.367 0.071 ..46.255 8965.000 25.577 31.794 8940.000 29.250 32.824 8915.000 59.852 32.163 8890.000 88.498 4.000 8880.000 -999.250 -999.250 WELL DATA FILE: ECC: COMPANY NAME: WELL NAME: FIELD: 31.997 -19.565 0.077 59.173 31.997 -33.001 0.075 54.152 31.997 -7.914 0.076 62.474 0.000 -100.000 0.000 0.000 -999.250 -999.250 -999.250 -999.250 C: \WDSDATA\W04398 4398.00 . WDF ARCO ALASKA, INC. D.S. 1-29 -999.250 1016.615 173.294 990.939 170.287 1082.773 172.292 1008.214 185.196 970.614 193.397 1082.598 187.705 1053.551 208.832 1035.029 169.210 1034.307 165.817 1144.548 167.485 1036.854 198.307 1105.667 172.673 1063.453 180.227 1010.547 163.268 968.388 192.624 961.948 180.641 1025.297 205.180 0.000 50.000 -999.250 -999.250 -999.250 11.771 0.000 12.150 0.000 11.770 0.000 15.546 0.000 15.744 0.000 15.536 0.000 20.570 0.000 11.257 0.000 11.922 0.000 12.271 0.000 16.917 0.000 11.357 0.000 14.475 0.000 11.564 0.000 14.793 61.'000 13.538 0.000 15.619 0.000 0.000 150.000 -999.250 -999.250 173.294 170.287 172.292 185.196 193.397 187.705 208.832 169.210 165.817 167.485 198.307 172.673 180.227 163.268 192.624 180.641 205.180 50.000 -999.250 33.420 31.020 33.132 24.331 25.480 24.853 18.964 34.508 30.667 29.816 23.744 35.126 25.998 31.367 27.794 28.824 28.163 0.000 -999.250 ., LOCATION: Top of Well: Bottom of Well= Level Spacing: NUMBER OF CURVES: 13 DEPTH CCL CLSN LSN SPD SSN 888O.00O 9340.000 0.500 CN TEN CNC TTEN CNRA CSSN GR FILE:PASS 2.002 FILE INTERVAL: START= 9340.000 END= 8880.000 DEPT GR SPD TEN TTEN CLSN CNC CNRA CCL LSN SSN 9340.000 -999.250 -999.250 9315.000 21.';06 36.034 9290.000 24.643 37.174 9265.000 26.660 35.040 9240.000 20.312 26.976 9215.000 17.461 27.874 9190.000 14.929 28.278 9165.000 14.940 23.497 9140.000 22.658 38.932 9115.000 23.564 38.570 9090.000 27.637 35.758 9065.000 19.'544 26.889 9040.000 39.141 36.720 -999.250 -999.250 29.033 0.070 28.997 0.068 28.997 0.071 28.997 0.087 28.997 0.085 28.997 0.084 28.997 0.097 28.997 0.066 28.997 0.066 28.997 0.070 28.997 0.087 28.997 0.069 28.997 0.080 -999.250 -999.250 293.256 0.000 188.568 0.000 89.667 0.000 43.914 0.000 40..548 0.000 27.518 0.000 6.946 0.000 18.684 35.000 0.097 0.000 -10.178 0.000 32.982 0.000 30.589 0.000 34.621 0.000 -999.250 -999.250 1077.048 46.659 1140.698 46.835 1085.101 48.867 1084.563 64.075 1162.240 64.956 1155.984 64.722 1103.349 79.467 1139.996 44.729 1142.617 44.227 1106.780 48.508 1201.257 71.478 1227.170 47.462 1256.714 57.606 9015.000 23.451 29.941 -999.250 -999.250 11.665 167.008 11.709 171.544 12.217 171.291 16.019 183.764 16.239 191.042 16.180 192.480 19.867 205.186 11.182 169.411 11.057 166.391 12.127 172.632 17.870 204.488 11.866 172.274 14.402 179. 046 CSSN -999.250 167.008 171.544 171.291 183.764 191.042 192.480 205.186 169.411 166.391 172.632 204.488 172.274 179.046 CN -999.250 32.034 33.174 31.040 22.976 23.874 24.278 19.497 34.932 34.570 31.758 22.889 32.720 25.941 8990·000 22.977 28.997 -9 35.124 0.071 0 8965.000 23.289 28.997 8 33.486 0.074 0 8940.000 32.864 28.997 -2 32.676 0.075 0 8915.000 63.057 28.997 -14 30.746 0.079 0 8890.000 71.474 0.000 .369 .000 .150 .000 ·046 .000 .560 .000 0.000 -100.000 0.000 150.000 8880.000 -999.250 -999.250 -999 -999.250 -999.250 -999 WELL DATA FILE: ECC: C: \WDSDATA\W04399 4399.00 ARCO ALASKA, INC. D.S. 1-29 8880·000 9340.000 0.500 13 CLSN SSN CN TEN COMPANY NAME: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: .. NUMBER OF CURVES DEPTH CCL LSN SPD .250 .250 · WDF CNC TTEN 1029 46 1152 59 1116 54 1131 63 -999 -999 .927 .584 .356 .401 .765 .949 .822 ·456 .000 .000 .250 .250 CNRA 11. 163. 14. 201. 13. 182. 15. 201. · -999. -999. 646 584 85O 192 737 666 864 304 000 000 250 250 CSSN 163.584 201.192 182.666 201.304 50·000 -999.250 GR 31.124 29.486 28.676 26.746 0.000 -999.250 FILE:PASS 3.003 FILE INTERVAL: START= 9340.000 END= 8880.000 DEPT GR SPD TEN TTEN CLSN CNC CNRA LSN SSN CCL 9340.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9315.000 22.535 28.997 315.867 1099.995 40.158 0.065 43.126 166.975 9290.000 23.389 28.997 157.870 1094.751 36.174 0.070 47.714 171.279 28.997 0·071 28.997 0.082 28.997 0.083 9265.000 25.195 34.945 56.595 49.262 46.272 58.765 -0.305 63.147 9240.000 23.476 29.299 996.634 172.322 1033.205 179.613 1027.224 191.245 9215.000 18.260 28.953 10.781 5.000 11.929 0.000 12.315 0.000 14.691 0.000 15.787 0.000 CSSN -999.250 166.975 171.279 172.322 179.613 191.245 CN -999.25O 36.158 32.174 30.945 25.299 24.953 9190.000 16.807 28.997 -11.611 987.658 16.240 189.373 23.556 27.556 0.086 64.960 189.373 0.000 9165.000 18.645 29.003 -5.079 994.672 19.718 214.611 21.183 25.183 0.092 78.874 214.611 0.000 9140.000 21.568 29.597 -9.316 1022.741 10.622 169.178 37.812 41.812 0.063 42.489 169.178 0.000 9115.000 23.747 28.997 7.412 1045.756 11.101 168.435 35.015 39.015 0.066 44.404 168.435 0.000 9090.000 31.070 29.039 2.547 1031.591 11.769 171.489 32.901 36.901 0.069 47.075 171.489 0.000 9065.000 24.041 29.555 -5.831 1037.738 16.294 196.256 24.737 28.737 0.083 65.176 196.256 0.000 9040.000 36.154 29.397 -14.822 1005.364 11.249 173.706 35.991 39.991 0.065 44.997 173.706 0.000 9015.000 24.091 29.003 6.404 1019.156 14.518 180.336 25.908 29.908 0.081 58.072 180.336 0.000 8990.000 28.208 29.955 -8.476 966.051 11.336 164.466 32.683 36.683 0.069 45.344 164.466 0.000 8965.000 26.368 28.997 5.633 1020.417 14.116 190.244 29.257 33.257 0.074 56.464 190.244 0.000 8940.000 33.583,. 29.033 -35.175 904.358 12.836, 184.567 32.244 36.244 0.070 51,.342 .184.567 0.000 8915.000 59.290 29.955 6.954 1058.797 17.880 205.734 23.082 27.082 0.087 71.521 ,205.734 0.000 8890.000 125.382 0.000 -100.000 0.000 0.000 50.000 0.000 0.000 0.000 0.000 50.000 150.000 8880.000 -999.250 -999.250 -999.250 -99,9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 End of execution: Wed 27 JUN 90 3:50pm Elapsed execution time = 10.00 seconds. SYSTEM RETURN CODE = 0 VP OlD.H02 VER'IFIC~?I3N LISTINS · ER¥ICE NAME :EDIT ,'ATE )RI$IN : 'EEL NAME' :.1492'91.1ii · ,'D~TINUATI'3N' # =01 ~'REVIO~S' REEL :O'M'MENTS =SCHLU~BERG.ER dELL SERi/.ICES CSU TAPE :'*' TAPE HEADER ;'ER~ICE NAME :EDIT lATE :86/06/13 I, RI SIN :FS1A ::APE NAME :'O.MT I N'.J~TI ON # 'R. EVIO.gS TAPE :, ;OMMENTS :SCHLUMBERGER dELL SERIICES CSg TAPE :. :L.E' NA~E '".ED..:]:T .DO:1- . ;,,E'~VIC'E NAME. ' : ' ~'.:'E.'".RSI:aN #' ..... ):.lit E . ":'. "R:: V'l'O U.S' F'I'L E · ' :' .,.. :..' ,.., ~:~' INFOtMAT'Z'DN' ~ECOR"DS .' ... '.'.. ~.'N'E ~, .... Ca N T. ~'N T.'S.<.' ... ~i~'hi,," . ,.....' · -~..-,..~,~ .~.~,.:~.'~. :.v'....:. · ..'..:... · ..~ ..<.. · ... ' · · ......~ · .' . .'....:" ;..".~ .' :'.:. . .. :":..: . :.~5,g "'" "' ~' '..'. ,~,..~.....,.... '.~.~.c.a..... ~.s.~.~..'. ~ ~:N.. ' ~ "'.~ $'" 1-2 ¢. "' '" ' ........"' .... ''~' .. ... ,.. :~. ~ ' · . .. . I.IN * · 15 E..' ' '. .' ~ . ~'.~N,. I:ON ..'... . 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V~ Oi3.HOZ VE~IFICATi]~ LI~TIN'$ :~' ~EEL TRAILER-,-"",- ,E.RVICE N~E :E~IT ,ATIE :85/05/13 '.E'.E L' NA~:E ~.1~92911~ :OtTINU~TIDN ~ ·:01 IEXT R:EL ~A~E : ;.O'MMENTS :SC.MLJMBER'GER dELL SERVICES CSU T~PE * HHHH HHHH * * I'IHHH I-IIDIH H H A LL LL II BBBB U U RRRR wwwww O N N * * HHHH HI-IHH H H AA LL LL II B B U U R R T O O NN N * * ~ HHHH A A LL LL ~I BBBB U U RRRR T O O N N N * * ~HHHHHHH H H AAAA LL LL II B B U U R R T O O N NN * * HHHH HHHH H H A ALL LL II BBBB U R R T O N N * * HHHH HHHH * *HHHH HHHH L O G G I N G S E R V I C E S , I N C . * . . . , . * . ******************************************************************************** ******************************************************************************** , . ' . '* LIS TAPE VERIFICATION LISTING * . · COMPANY: ' ARCO ALASKA INC. * · WELL: DS 1-29 * · AI~I ~: 50-029-21604-00 * · DATE: 12-08-91 * · FIELD: PRUDHOE BAY * · BOROUGH: NORTH SLOPE *, · STATE: ALASKA * * · LOGS = TMD * . · * ******************************************************************************** · RECEIVED NOV 2 1992 Alaska 0il & Gas Cons. Commission Anchorage Page i SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER PREVIOUS REEL NAME COMMENTS: --- COMCEN --- 92/10/30 --- 739618 ****************************************************************************** TAPE HEADER RECORD .............................. TYPE 130 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER PREVIOUS TAPE NAME COMMENTS: --- COMCEN --- 92/lO/3O ------ i ****************************************************************************** COMMENT RECORD .................................. TYPE 232 TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0 ) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 01-29 500292160400 ARCO ALASKA INC. HALLIBURTON LOGGING SERVICES 30-OCT-92 L73961-8 KILLINSWORTH K. MORRIS 08 10N 15E 1017 1511 70.00 69.00 42.00 NOV 2 b 992 Alaska 0il & Gas Cons. An~horag.e. cASING DRILLER'S CASING Page 2 BIT SIZE(IN) SIZE(IN) DEPTH(FT) WEIGHT (LB/FT) 1ST STRING 13.375 2480.0 72.00 2ND STRING 12.250 9.625 9579.0 47.00 3RD STRING 5.500 31.0 17.00 PRODUCTION STRING 12.250 4.500 8764.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: GR PBU CURVE CODE: BCS RUN NUMBER: PASS NUMBER= DATE LOGGED: LOGGING COMPANY: EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH TMD 8886.5 8929.0 8972.0 9005.0 9041.0 9087.5 9117.5 9160.0 9233.0 9332.0 9380.0 9423.0 9451.5 REMARKS: 8886.5 8929.0 8972.0 9005.0 9041.0 9087.5 9117.5 9160.0 9233.0 9332.0 9380.0 9422.0 9450.5 PASS ~1-2-3 ARE NON-BORAX BASELINE PASSES. PASS ~4-5-6 ARE BORAX INJECTION PASSES. CASING VOLUME TO TOP OF THE PERFORATIONS = 163 BBLS. PUMPING VOLUME AND FLUID TYPE: METHANOL= 10 BBLS SEAWATER= 350 BBLS BORAX= 171 BBLS CRUDE= 142 BBLS TOTAL= 673 BBLS SEAWATER $ ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.001' --- 92/10/30 --- 1024 --- LO ****************************************************************************** Page 3 COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 01 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER= 01 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TM]) 9451.0 8886.5 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE' FOR SHIFTS PBU CURVE CODE: GR PASS NUMBERs 01 BASELINE DEPTH TOTAL PUMPED; LIS FORMAT DATA ......... EQUIVALENT UNSHIFTED DEPTH ......... TMD PUMPING INFORMATION FOR NON-BORAX PASS $1: VOLUME & TYPE: 10 BBLS METHANOL 350 BBLS SEAWATER 171 BBLS BORAX 28 BBLS CRUDE 559 BBLS SEAWATER ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 I 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= Page 4 MNEM SERVID SERVICES UNITS API CODE FILES SIZE SSAMP REPR. DEPT F 00000000 0 4 i 68 SGFN TMD 739618 CU 00000000 0 4 i 68 SGFF TM]) 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 I 68 NSBF TMD 739618 CPS 00000000 0 4 1 68 FSBF TMD 739618 CPS 00000000 0 4 i 68 NTMD TMD 739618 CPS 00000000 0 4 i 68 FTMD TMD 739618 CPS 00000000 0 4 i 68 RTMD TM]3 739618 00000000 0 4 I 68 CRNF TMD 739618 00000000 0 4 i 68 PHIT TMD 739618 PU 00000000 0 4 i 68 SGFM TMD 739618 CU 00000000 0 4 i 68 SIGQ TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 i 68 GRCH TMD 739618 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9451.000 SGFN = 22.767 SGFF = 19.498 SGBH = 65.946 NSBF = 34.339 FSBF = 3.748 NTMD = '18333.360 FTMD = 2627.348 RTMD = 6.978 CRNF = 7.915 PHIT = 63.088 SGFM = 19.526 SIGQ = .985 RSBF = .416 SGIN = 15.764 SIGC = 1.315 GRCH = -1.000 DEPT = 9251.000 SGFN = 21.111 SGFF'= 17.973 SGBH = 68.149 NSBF = 46.167 FSBF = 4.558 NTMD = 15919.430 FTMD = 2988.865 RTMD = 5'.326 CRNF = 5.959 PHIT' = 29.588 SGFM = 17.778 SIGQ = .980 RSBF = .930 SGIN = 13.774 SIGC = 1.333 GRCH = 16.757 DEPT = 9051.000 SGFN = 23.401 SGFF = 20.987 SGBH = 66.282 NSBF = 69.034 FSBF = 6.044 NTMD = 14782.710 FTMD = 2828.259 RTMD = 5.227 CRNF = 5.821 PHIT = 27.584 SGFM = 20.191 SIGQ = .975 RSBF = .978 SGIN = 16.521 SIGC = 1.288 GRCH = 20.366 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.001 --m~ 0 --~m 5 --- 92/10/30 --- 1024 --- LO --- COMCEN.002 Page 5 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.002 m~e O me~ 5 --- 92/10/30 --- 1024 --- LO --- COMCEN.001 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER: 02 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER= ,02 DEPTH INCREMENT: 0.5000 ' FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9451.0 8900.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE= GR PASS NUMBER: 01 BASELINE DEPTH $ -" .... .--EQUIVALENT UNSHIFTED DEPTH ......... TMD PUMPING INFORMATION FOR NON-BORAX PASS VOLUME & TYPE: 28 BBLS CRUDE TOTAL PUMPED: 587 BBLS SEAWATER 'NO PASS TO PASS DEPTH SHIFTS WERE PERFORMED. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD -~ ............. TYPE 64 . ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 I 66 1 5 I 66 I RECEIVED NOV 2 3 1992 Alaska 011 & Gas Cons. Commission Anchorage Page 6 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 I 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE~ UNITS API CODE FILES SIZE SSAMP REPR. DEPT F 00000000 0 4 i 68 SGFN TMD 739618 CU 00000000 0 4 i 68 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CPS 00000000 0 4 I 68 FSBF TMD 739618 CPS 00000000 0 4 i 68 NTMD TMD 739618 CPS 00000000 0 4 i 68 FTMD TMD 739618 CPS 00000000 0 4 I 68 RTMD TMD 739618 00000000 0 4 i 68 CRNF TMD 739618 00000000 0 4 I 68 PHIT TMD 739618 PU 00000000 0 4 1 68 SGFM TMD 739618 CU 00000000 0 4 i 68 SIC~Q TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 i 68 S~IN TMD 739618 CU 00000000 0 4 1 68 SI~C TMD 739618 00000000 0 4 i 68 GRCH TMD 739618 ~API 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9451.000 SGFN = 21.593 SGFF = 18.250 SGBH = 64.292 NSBF = 101.623 FSBF = 13.377 NTMD = 19079.270 FTMD = 2680.288 RTMD = 7.118 CRNF = 8.080 PHIT = 66.348 S~FM = 18.287 SiGQ = .993 RSBF = .356 SGIN = 14.353 SIGC = 1.333 GRCH = -1.000 DEPT = 9251.000 S~FN = 20.852 S~FF = 18.386 SGBH = 66.538 NSBF = 90.084 FSBF = 8.750 NTMD = 15715.130 FTMD = 2950.749 RTMD = 5.326 CRNF = 5.932 PHIT = 29.198 SGFM = 17.505 SIGQ = .975 RSBF = .981 SGIN = 13.463 SIGC = 1.333 GRCH = 20.894 DEPT = 9051.000 SGFN = 24.035 S~FF = 20.859 SGBH = 69.072 NSBF = 101.155 FSBF = 9.835 NTMD = 14584.710 FTMD = 2767.771 RTMD = 5.269 CRNF = 5.912 PHIT = 28.910 S~FM = 20.871 SI~Q = .978 RSBF = .868 S~IN = 17.295 SIGC = 1.262 GRCH = 24.398 ****************************************************************************** Page 7 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.002 mm~ 0 t---- 5 --- 9'2/10/30 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.003 --- 92/10/30 --- 1024 --- LO --- COMCEN.002 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER: 03' EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 03 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9451.0 8900.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD 8900.0 8900.0 8929.0 8929.0 8972.0 8972.0 9005.0 9005.0 9041.0 9041.0 9087.5 9087.5 9117.5 9117.5 9160.0 9160.0 9233.0 9233.0 9332.0 9331.5 Page 8 9380.0 9422.0 9450.0 $ REMARKS: 9379.5 9422.0 9450.0 PUMPING INFORMATION FOR NON-BORAX PASS $3: VOLUME & TYPE: 29 BBLS CRUDE TOTAL PUMPED: 616 BBLS SEAWATER $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 I 66 1 5 i 66 1 8 4 73 60 9 4 65 .liN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICES UNITS API CODE FILE~ SIZE $SAMP REPR. DEPT F 00000000 0 4 I 68 SGFN TMD 739618 CU 00000000 0 4 I 68 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CPS 00000000 0 4 i 68 FSBF TMD 739618 CPS 00000000 0 4 i 68 NTMD TMD 739618 CPS 00000000 0 4 I 68 FTMD : TMD 739618 CPS 00000000 0 4 i 68 · RTMD TMD 739618 00000000 0 4 I 68 CRNF TMD 739618 00000000 0 4 i 68 'PHIT TMD 739618 PU 00000000 0 4 i 68 SGFM TMD 739618 CU 00000000 0 4 I 68 SIGQ TMD 739618 00000000 0 4 I 68 RSBF TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 1 68 SIGC TMD 739618 00000000 0 4 1 68 GRCH TMD 739618 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9451.000 SGFN = 21.677 SGFF = 20.813 Page 9 SGBH = 66.489 NSBF = 107.782 FSBF = 14.534 NTMD = 18719.120 FTMD = 2288.316 RTMD = 8.180 CRNF = 9.714 PHIT = 102.325 SGFM = 18.376 SIGQ = .991 RSBF = .394 SGIN = 14.454 SIGC = 1.333 GRCH = -1.000 DEPT = 9251.000 SGFN = 21.608 SGFF = 18.683 SGBH = 70.310 NSBF = 107.590 FSBF = 10.310 NTMD = 15945.910 FTMD = 3024.659 RTMD = 5.272 CRNF = 5.935 PHIT = 29.246 SGFM = 18.303 SIGQ = .980 RSBF = .870 SGIN = 14.371 SIGC = 1.333 GRCH = 27.529 DEPT = 9051.000 SGFN = 24.742 SGFF = 19.919 SGBH = 71.147 NSBF = 116.158 FSBF = 10.944 NTMD = 14574.700 FTMD = 2756.573 RTMD = 5.287 CRNF = 5.966 PHIT = 29.688 SGFM = 21.632 SIGQ = .981 RSBF = .789 SGIN = 18.161 SIGC = 1.237 GRCH = 29.368 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.003 ------ O --- 92/10/30 --- 1024 --- LO --- CO~CEN.004 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE, OPTIONAL PREVIOUS FILE NAME --- COMCEN.004 --- 92/10/30 --- 1024 --- LO --- COMCEN.003 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER= 04 EDITED CURVES Depth shifted and clipped curves 'for each pass in separate files. PASS NUMBER= 04 - DEPTH INCREMENT: 0.5000 FILE SUMMARY page 10 PBU TOOL CODE START DEPTH STOP DEPTH TMD 9451.0 8899.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01 ......... EQUIVALENT UNSHIFTED DEPTH' BASELINE DEPTH TMD 8899.5 8899.5 8929.0 8929.0 8972.0 8972.0 9005.0 9005.0 9041.0 9041.0 9087.5 9087.5 9117.5 9117.5 9160.0 9160.0 9233.0 9233.0 9332.0 9332.0 9380.0 9379.5 9422.0 9421.5 9450.0 9450.0 $ PUMPING INFORMATION FOR BORAX PASS #4: VOLUME & TYPE: 19 BBLS CRUDE TOTAL PUMPED: 635 BBLS SEAWATER $ LIS FORMAT DATA ******************************************************************************** DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i I 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 I 66 1 '8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE# SIZE #SAMP REPR. Page 11 DEPT F 00000000 0 4 I 68- SGFN TMD 739618 CU 00000000 0 4 i 68 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 I 68 NSBF TM]) 739618 CPS 00000000 0 4 i 68 FSBF TMD 739618 CPS 00000000 0 4 i 68 NTMD TMD 739618 CPS 00000000 0 4 i 68 FTMD TMD 739618 CPS 00000000 0 4 i 68 RTMD TM]) 739618 00000000 0 4 i 68 CRNF TMD 739618 00000000 0 4 I 68 PHIT TMD 739618 PU 00000000 0 4 I 68 SGFM TMD 739618 CU 00000000 0 4 i 68 SIGQ TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 i 68 GRCH TMD 739618 GAPI 00000000 0 4 i 68 ******************************************** DATA RECORD TYPE 0 *********************************** DEPT = 9451.000 SGFN = 26.657 SGFF = 23.622 SGBH = 71.878 NSBF = 74.231 FSBF = 12.705 NTMD = 12195.540 FTMD = 2209.404 RTMD = 5.520 CRNF = 6.231 PHIT = 33.671 SGFM = 23.671 SIGQ = .976 RSBF .852 SGIN = 20.483 SIGC = 1.181 GRCH = -1.000 DEPT = 9251.000 SGFN = 18.135 SGFF = 14.928 SGBH = '129.584 NSBF = 77.634 FSBF = 7.900 NTMD = 8280.707 FTMD = 1892.881 RTMD = 4.375 CRNF = 5.648 PHIT = 25.150 SGFM = 14.241 SIGQ = .992 RSBF = .656 SGIN = 14.447 SIGC = 1.333 GRCH = 30.373 DEPT = 9051.000 SGFN = 20.002 SGFF = 16.836 SGBH = 120.134 NSBF = 86.285 FSBF = 9.937 NTMD = 7515.777. FTMD = 1734.133 RTMD = 4.334 CRNF = 5.543 PHIT = 23.700 SGFM = 16.252 SIGQ = .993 RSBF = .760 SGIN = 16.558 SIGC = 1.276 GRCH = 38.474 ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.004 mmm 0 --- 92/10/30 --- 1024 --- LO --- COMCEN.,005 ****************************************************************************** · Page 12 FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.005 m--t O mm~ 5 --- 92/10/30 --- 1024 --- LO --- COMCEN.004 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER= 05 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER= 05 DEPTH INCREMENT= 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP 'DEPTH TMD .9451.5 8901.0.. $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE= GR PASS NUMBER= 01 ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH TMD 8901.0 8900.0 8929.0 8928.0 8972.0 8971.0 9005.0 9004.0 9041.0 9040.0 9087.5 9086.5 9117.5 9116.5 9160.0 9159.0 9233.0 9232.0 9332.0 9331.0 9380.0 9379.5 9422.0 9421.5 9450,'5 9450.0 $ PUMPING INFORMATION FOR BORAX PASS $5= VOLUME & TYPE= 19 BBLS CRUDE TOTAL PUMPED= 654 BBLS SEAWATER LIS FORMAT DATA Page 13 DATUM FORMAT SPECIFICATION RECORD TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 I 66 1 5 i 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 i 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE# UNITS API CODE FILE~ SIZE $SAMP REPR. DEPT F 00000000 0 ' 4 I 68 SGFN TMD 739618 CU 00000000 0 4 I 68 SGFF TMD 739618 CU 00000000 .0 4 I 68 SGBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CPS 00000000 0 4 i 68 FSBF TMD 739618 CPS 00000000 0 4 i 68 NTMD TMD 739618 CPS 00000000 0 4 i 68 FTMD TMD 739618 CPS 00000000 0 '4 I 68 RTMD TMD 739618 00000000 0 4 I 68 CRNF TMD 739618 00000000 0 4 i 68 PHIT TMD 739618 PU 00000000 0 4 i 68 SGFM TMD 739618 CU 00000000 0 4 I 68 SIGQ TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 I 68 SGIN TMD 739618 CU 00000000 0 4 i 68 .SIGC TMD 739618 00000000 0 4 i 68 GRCH TMD 739618 GAPI 00000000. 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9451.500 SGFN = 22.769 SGFF = 22.006 SGBH = 75.10,7 NSBF = 94.776 FSBF = 14.917 NTMD = 10921.390 FTMD = 1736.404 RTMD = 6.290 CRNF = 7.168 PHIT = 49.169 SGFM = 19.532 SIGQ = .980 RSBF = 1.160 SGIN = 17.911 SIgC = 1.315, GRCH = -1.000 DEPT = 9251.500 SGFN = 17.955 SGFF = 14.422 SGBH = 124.452 .NSBF = 97.844 FSBF = 10.518 NTMD = 8473.434 FTMD = 1916.276 RTMD = 4.422 CRNF = 5.656 PHIT = 25.252 SGFM = 13.846 SIGQ = .991 RSBF = .645 SGIN = 14.031 Page 14 SIGC = 1.333 GRCH = 41.765 DEPT = 9051.500 SGFN = 19.663 SGFF = 16.054 SGBH = 118.073 NSBF = 106.346 FSBF = 10.726 NTMD = 7974.449 FTMD = 1847.087 RTMD = 4.317 CRNF = 5.513 PHIT = 23.289 SGFM = 15.553 SIGQ = .995 RSBF = .735 SGIN = 15.824 SIGC = 1.296 GRCH = 45.357 FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME '--- COMCEN.005 --- 92/10/30 --- 1024 --- LO --- COMCEN.006 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.006 --im O --- 92/10/30 --- 1024 --- LO --- COMCEN.005 ****************************************************************************** COMMENT RECORD TYPE 232 FILE HEADER FILE NUMBER: 06 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 06 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH TMD 9443.0 8901.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: 01' -- .EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TMD Page 15 8901.5 8929.0 8972.0 9005.0 9041.0 9087.5 9117.5 9160.0 9233.0 9332.0 9380.0 9422.0 9442.0 REMARKS= 8901.5 8929.0 8972.5 9005.5 9041.5 9088.0 9118.0 9160.0 9233.0 9332.0 9380.0 9422.0 9442.0 PUMPING INFORMATION FOR BORAX PASS #6= VOLUME & TYPE= 19 BBLS CRUDE TOTAL PUMPED= 673 BBLS SEAWATER $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 68 4 i 66 1 5 i 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE# ,UNITS DEPT F SG N Tm ?39618 cu SGFF TMD 739618 CU SGB. THD 739618 CU NSBF TMD 739618 CPS ;SBT TY, D 739618 CPS TSn 739618 CPS FTMD TMD 739618 CPS RTMD TMD 739618 CRNF TMD 739618 PHIT TMD 739618 PU SGFM TMD 739618 CU API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 #SAMP, REPR. i 68 i 68 i 68 i 68 I 68 i 68 i 68 i 68 i 68 I 68 i 68 I 68 Page 16 SIGQ TMD 739618 00000000 0 4 I 68 RSBF TMD 739618 00000000 0 4 I 68 SGIN TMD 739618 CU 00000000 0 4 I 68 SIGC TMD 739618 00000000 0 4 i 68 GRCH TMD 739618 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9443.000 SGFN = 20.559 SGFF = 20.167 SGBH = 81.945 NSBF = 101.830 FSBF = 15.482 NTMD = 8978.438 FTMD = 1445.918 RTMD = 6.210 CRNF = 7.175 PHIT = 49.284 SGFM = 17.195 SIGQ = .990 RSBF = 1.333 SGIN = 17.549 SIGC = 1.333 GRCH = -1.000 DEPT = 9243.000 SGFN = 16.956 SGFF = 13.506 SGBH = 128.842 NSBF = 102.459 FSBF = 9.953 NTMD = 9140.020 FTMD = 2125.347 RTMD = 4.300 CRNF = 5.574 PHIT = 24.128 SGFM = 12.763 SIGQ = .995 RSBF = .607 SGIN = 12.894 SIGC = 1.333 GRCH = 47.884 DEPT = 9043.000 SGFN = 19.309 SGFF = 16.467 SGBH = 123.296 NSBF = 111.378 FSBF = 12.286 NTMD = 8078.910 FTMD = 1908.311 RTMD = 4.234 CRNF = 5.473 PHIT = 22.752 SGFM = 15.656 SIGQ = .992 RSBF = .784 SGIN = 15.932 SIGC = 1.293 GRCH = 50.626 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.006 --- 92/10/30 --- 1024 --- LO --- COMCEN.007 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.007 m~g O --- 92/lO/3O m__ 1024 --- LO --- COMCEN.006 ****************************************************************************** page 17 COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER: 07 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass i gamma ray and background counts~ arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS mmmmmmmmmmmmm mmmmmmmmmmmm TMD 01,02,03 $ REMARKS: AVERAGE OF NON-BORAX PASSES ~1-2-3. $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY I i 66 0 2 i 66 0 3 2 79 68 ' 4 i 66 1 5 I 66 1 8 4 73 60 9 4 65 .lIN 11 2 79 14 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 I 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE# UNITS API CODE FILE~ DEPT F 00000000 SGFN PNAV 739618 CU 00000000 SGFF PNAV 739618 CU 00000000 SGBH PNAV 739618 CU 00000000 NSBF PNAV 739618 CPS 00000000 FSBF PNAV 739618 CPS 00000000 NTMD PNAV 739618 CPS 00000000 FTMD PNAV 739618 CPS 00000000 RTMD PNAV 739618 00000000 CRNF PNAV 739618 00000000 PHIT PNAV 739618 PU 00000000 SIZE ~SAMP REPR. 4 i 68 4 i 68 4 i 68 4 i 68 4 i 68 4 i 68 4 I 68 4 I 68 4 i 68 4 1 68 4 i 68 Page 18 SGFM PNAV 739618 CU 00000000 0 4 I 68 SIGQ PNAV 739618 00000000 0 4 i 68 RSBF PNAV 739618 00000000 0 4 i 68 SGIN PNAV 739618 CU 00000000 0 4 i 68 SIGC PNAV 739618 00000000 0 4 I 68 GRCH PNAV 739618 GAPI 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9443.000 SGFN = 22.273 SGFF = 19.231 SGBH = 68.018 NSBF = 57.195 FSBF = 6.454 NTMD = 19098.520 FTMD = 2657.342 RTMD = 7.210 CRNF = 8.288 PHIT = 71.100 SGFM = 19.007 SIGQ = .991 RSBF = .361 SGIN = 15.173 SIGC = 1.321 GRCH = -1;000 DEPT = 9243.000 SGFN = 20.807 SGFF = 17.124 SGBH = 69.732 NSBF = 46.059 FSBF = 4.940 NTMD = 16879.470 FTMD'= 3259.823 RTMD = 5.178 CRNF = 5.826 PHIT = 27.656 SGFM = 17.457 SIGQ = .982 RSBF = .869 SGIN = 13.408 SIGC = · 1.333 GRCH = 17.893 DEPT = 9043.000 SGFN = 23.504 SGFF = 20.140 SGBH = 70.287 NSBF = 68.282 FSBF = 6.945 NTMD = 15619.340 FTMD = 3034.917 RTMD = 5.147 CRNF = 5.801 PHIT = 27.315 SGFM = 20.313 SIGQ = .979 RSBF = .880 SGIN = 16.659 SIGC = '1.283 GRCH = 21.511 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.007 --- 92/10/30 --- 1024 --- LO --- COMCEN.008 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF'GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.008 --- 92/10/30 --- 1024 --- COMCEN.007 Page 19 FILE HEADER FILE NUMBER: 08 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 01 ' DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH mmmmmQmmmmmmmmmm mmmmmmmmmmm TMD 9455.5 LOG HEADER DATA DATE LOGGED= SOFTWARE VERSION= TIME LO~GER ON BOTTOM= TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT)= BOTTOM LO~ INTERVAL (FT): STOP DEPTH 8886.5 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE m m emm em m m mm m m m m m em emm mm mmmemmmmmm mm mmmm GR GAMMA RAY TMD TMD $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRiLLER0S CASING DEPTH (FT): LOGGER'S'CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM),: FLUID LEVEL FLUID RATE AT WELLHEAD (BPM)= WATER CUTS (PCT)= GAS/OIL RATIO: CHOKE'(DEG): NEUTRON TOOL .,TOOL TYPE (EPITHERMAL OR THERMAL)= MATRIX= MATRIX DENSITY: HOLE CORRECTION (IN)= 08-DEC-91 DLS 4.01 0900 08-DEC-91 9571.0 9438.0 8886.5 9450.0 1200.0 NO TOOL NUMBER 106312 106315 12.250 9579.0 SEAWATER/BORAX 0.0 THERMAL SANDSTONE 2.65 12. 250 Page 20 BLUELINE COUNT I~ATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9310.0 BASE NORMALIZING WINDOW (FT): 9410.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS)= 0 FAR COUNT RATE HIGH SCALE (CPS)= 5300 NEAR COUNT RATE LOW SCALE (CPS)= 0 NEAR COUNT RATE HIGH SCALE (CPS)= 30000 TOOL STANDOFF (IN): REMARKS: 0.0 TOTAL PUMPED: $ LIS FORMAT DATA PUMPING INFORMATION FOR NON-BORAX PASS VOLUME.& TYPE: 10 BBLS METHANOL 350 BBLS SEAWATER 171 BBLS BORAX 28 BBLS CRUDE 559 BBLS SEAWATER ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS= TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 80 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM DEPT SGFN TMD SGFF TMD SGBH TMD NSBF TMD FSBF TMD NTMD TMD FTMD TMD RTMD TMD CRNF TMD PHIT TMD SGFM TMD SERVID SERVICE~ UNITS F 739618 ' CU 739618 CU 739618 CU 739618 CNTS 739618 CNTS 739618 CNTS 739618 CNTS 739618 739618 739618 DECI 739618 CU API CODE FILE# SIZE 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 00000000 0 4 $SAMP REPR. i 68 i 68 i 68 i 68 i 68 i 68 i 68 i 68 i 68 I 68 I 68 I 68 Page 21 SIgg TMD 739618 00000000 0 4 i 68 G4~R TDwlD 739618 00000000 0 4 i 68 ~B~ ~MD 739618 00000000 0 4 I 68 ~B~ ~MD 739618 00000000 0 4 I 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 i 68 GR TMD 739618 GAPI 00000000 0 4 i 68 CCL TMD 739618 MV 00000000 0 4 I 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9455.500 SGFN = 21.924 SGFF = 17.230 SGBH = 58.809 NSBF = 1.983 FSBF = .625 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = .958 PHIT = -999.000 SGFM = 17.765 SIC, Q = .977 G4ER = -.020 RSBF = .268 ABTN = 1489.324 SGIN = 13.736 SIGC = 1.333 GR = -1.000 CCL = 1.000 DEPT = 9355.500 SGFN = 21.266 SGFF = 18.334 SGBH = 67.817 NSBF = 33.446 FSBF = 3.924 NTMD = 16078.100 FTMD = 2844.494 RTMD = 5.652 CRNF = 6.314 PHIT = .350 SGFM = 17.941 SIGQ = .979 G4ER = .015 RSBF = .828 ABTN = 29468.760 SGIN = 13.960 SIGC = 1.333 GR = 13.888 CCL = 589.827 .DEPT = 9255.500 SGFN = 20.366 SGFF = 17.117 SGBH = 67.127 NSBF = 45.570 FSBF = 4.810 NTMD = 16382.51.0 FTMD = 3177.232 RTMD = 5.156 CRNF = 5.759 PHIT = .267 SGFM = 16.992 SIC, Q = .985 G4ER = .014~ RSBF.= .917 ABTN = 31995.620' SGIN = 12.878 SIGC = 1.333 GR = 16.152 CCL = 589.930 DEPT = 9155.500 SGFN = 21.836 SGFF = 18.037 SGBH = 69.877 NSBF = 57.650 FSBF = 5.137 NTMD = 16487.160 FTMD = 3339.199 RTMD = 4.937 CRNF = 5.577 PHIT = .242 SGFM = 18.436 SIC, Q = .983 G4ER = .008 RSBF = .882 ABTN = 31971.330 SGIN = 14.523 SIGC = 1.333 GR = 16.462 CCL = 589.385 DEPT = 9055.500 SGFN = 23.284 SGFF = 20.177 SGBH = 68.986 NSBF = 70.820 FSBF = 5.851 NTMD = 15350.380 FTMD = 2965.292 RTMD = 5.177 CRNF = 5.811 PHIT = .275 SGFM = 20.080 SIGQ = .979 G4ER = .015, RSBF = .895' ABTN = 31744.020 SGIN = 16.395 SIGC = 1.292 GR .= 15.497 CCL = 589.181 ., Page 22 DEPT = 8955.500 SGFN = 23.555 SGFF = 20.996 SGBH = 70.698 NSBF = 75.373 FSBF = 7.512 NTMD = 14740.470 FTMD = 2768.403 RTMD = 5.325 CRNF = 5.998 PHIT = .302 SGFM = 20.368 SIGQ = .982 G4ER = .014 RSBF = .905 ABTN = 32084.360 SGIN = 16.723 SIGC = 1.281 GR = 17.750 CCL = 588.912 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.008 mmm O m--m 5 --- 92/10/30 --- 1024 --- LO --- COMCEN.009 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 ----m O --- 92/10/30 --- 1024 --- LO --- COMCEN.008 COMMENT REcoRD .................................. TYPE 232 FILE HEADER FILE NUMBER: 09 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 02 DEPTH INCREMENT:. 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): mmmmmm~mmmm 9458.0 8900.0 08-DEC-91 DLS 4.01 0900 08-DEC-91 9571.0 9438.0 8886.5 9450.0 Page 23 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 1200.0 NO TOOL NUMBER GR GAMMA RAY TMD TMD $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G)~ SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF)= FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 106312 106315 12.250 9579.0 SEAWATER/BORAX 0.0 THERMAL SANDSTONE 2.65 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9310.0 BASE NORMALIZING WINDOW (FT)= 9410.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 REMARKS: PUMPING INFORMATION FOR NON-BORAX PASS VOLUME & TYPE: 28 BBLS CRUDE TOTAL PUMPED: 587 BBLS SEAWATER $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY. Page 24 i I 66 0 2 I 66 0 3 2 79 80 4 1 66 1 5 i 66 1 8 4 73 3O 9 4 65 .lin 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 I 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICES UNITS API CODE FILES SIZE SSAMP REPR. DEPT F 00000000 0 4 i 68 SOFN TMD 739618 CU 00000000 0 4 I 68 SOFF TMD 739618 CU 00000000 0 4 I 68 SOBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CNTS 00000000 0 4 1 68 FSBF TMD 739618 'CNTS 00000000 0 4 1 68 NTMD TMD 739618 CNTS 00000000 0 4 i 68 FTMD TMD 739618 CNTS 00000000 0 4 i 68 RTMD TMD 739618 00000000 0 4 i 68 CRNF TMD 739618 00000000 0 4 1 68 PHIT TMD 739618 DECI 00000000 0 4 i 68 SOFM TMD 739618 CU , 00000000 0 4 i 68 SIOQ TMD 739618 00000000 0 4 i 68 O4ER TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 i 68 ABTN TMD 739618 00000000 0 4 I 68 ., SOIN' TMD 7396,18 CU 00000000 0 4 i 68 SIOC TMD 739618 00000000 0 4 i 68 OR TMD 739618 OAPI 00000000 0 4 i 68 CCL TMD 739618 MV 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 ,DEPT = 9458.000 SGFN = 23.326 SOFF = 20.470 SOBH = 70.341 NSBF = 89.684 FSBF = 18.483 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.396 PHIT = -999.000 SOFM = 20.290 SIGQ = .985 O4ER = .012 RSBF = .771 ABTN = 23936.630 SGIN = 16.619 SIGC = 1.284 GR = -1.000 CCL = 1.000 DEPT = 9358.000 SOFN = 21.380 SOFF = 19.069 SGBH = 67.364 NSBF = 84.486 FSBF = 8.265 NTMD = 16064.800 FTMD = 2926.513 RTMD = 5.489 CRNF = 6.125 PHIT = .321 SOFM = 18.062 SIGQ = .975 G4ER = .018 RSBF = .891 ABTN = 30442.880 SGIN = 14.097 SIOC = 1.333 GR = 19.904 CCL = 589.924 .. Page 25 DEPT = 9258.000 SGFN = 20.422 SGFF = 17.976 SGBH = 66.963 NSBF = 89.819 FSBF = 8.324 NTMD ~ 16528.520 FTMD ~ 3194.478 RTMD = 5.174 CRNF = 5.775 PHIT = .269 SGFM = 17.051 SIGQ = .976 G4ER = .017 RSBF = .912 ABTN = 31402.890 SGIN = 12.946 SIGC = 1.333 GR = 20.861 CCL = 589.362 DEPT = 9158.000 SGFN = 21.730 SGFF = 18.260 SGBH = 70.582 NSBF = 98.949 FSBF = 9.945 NTMD = 15751.090 FTMD = 3135.966 RTMD = 5.023 CRNF = 5.678 PHIT = .256 SGFM = 18.375 SIGQ = .983 G4ER = .020 RSBF = .887 ABTN = 31735.120 SGIN = 14.453 SIGC = 1.333 GR = 25.733 CCL = 589.256 DEPT = 9058.000 SGFN = 25.676 SGFF = 22.352 SGBH = 73.400 NSBF = 102.8.88 FSBF = 10.123 NTMD = 14644.050 FTMD = 2631.060 RTMD = 5.566 CRNF = 6.306 PHIT = .348 SGFM = 22.624 SIGQ = .984 G4ER = .008 RSBF = .753 ABTN = 28092.560 SGIN = 19.291 SIGC = 1.208 GR = 25.171 CCL = 589.686 DEPT = 8958.000 ' SGFN = 23.322 SGFF = 19.632 SGBH = 70.579 NSBF = 106.925 FSBF = 9.753 NTMD = 15307.940 FTMD = 3015.147 RTMD = 5.077 CRNF = 5.732 PHIT = .263 SGFM = 20.119 SIGQ = .982 G4ER = .008 RSBF = .841 ABTN = 29642.480 SGIN = 16.439 SIGC = 1.291 GR = 24.135 CCL = 589.660 ' ' ****************************************************************************** FILE TRAILER RECORD TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.009 --t-- 0 --- 92/10/30 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE 'SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.010 m---- 0 --- 92/10/30 --- 1024 --- LO Page 26 OPTIONAL PREVIOUS FILE NAME --- COMCEN.009 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER= 10 RAW CURVES Curves and log header data for each pass in separate files~ raw background pass in last file. PASS NUMBER= 03 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9458.0 $ DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER .(FT): TD LOGGER (FT)= TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VEND~R TOOL CODE TOOL TYPE GR GAMMA RAY TMD TMD $ BOREHOLE AND "CASING DATA OPEN HOLE BIT SIZE (IN):.. DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT)= FLUID RATE AT WELLHEAD (BPM)~ WATER CUTS (PCT): GAS/OIL RATIO~ CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): 8900.0 08-DEC-91 DLS 4.01 0900 08-DEC-91 9571.0 9438.0 8886.5 9450.0 1200.0 NO TOOL NUMBER 106312 106315 12.250 9579.0 SEAWATER/BORAX 0.0 THER~tL Page 27 MATRIX: MATRIX DENSITY= HOLE CORRECTION (IN)= SANDSTONE 2.65 12.250 BLUELINE COUNT I~ATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9310.0 BASE NORMALIZING WINDOW (FT): 9410.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS)= 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 REHAR~S: PUMPING INFORMATION FOR NON-BORAX PASS #3: VOLUME & TYPE: 29 BBLS CRUDE TOTAL PUMPED: 616 BBLS SEAWATER $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS:' TYPE SIZE REPR. CODE ENTRY i i 66 0 2 i 66 0 3 2 79 8,0 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 ' 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE# UNITS API CODE DEPT F 00000000 SGFN TMD 739618 CU 00000000 SGFF TMD 739618 CU 00000000 SGBH TMD 739618 'CU 00000000 NSBF TMD 739618 CNTS 00000000 FSBF TMD 739618 CNTS 00000000 NTMD TMD 739618 CNTS 00000000 FTMD TMD 739618 CNTS 00000000 RTMD TMD 739618 00000000 CRNF TMD 739618 00000000 PHIT TMD 739618 DECI 00000000 SGFM TMD 739618 CU 00000000 FILES 0 0 0 0 0 0 0 0 0 0 0 0 size 4 4 4 4 4 4 4 4 4 4 4 4 #SAMP 1 1 1 '1 1 1 1 1 1 1 1 1 REPR. 68 68 68 68 68 68 68 68 68 68 68 68 Page 28 SIG~ TI. ID 739618 00000000 0 4 i 68 G4ER TMD 739618 00000000 0 4 I 68 RSBF TMD 739618 00000000 0 4 I 68 ABTN TMD 739618 00000000 0 4 1 68 SGIN TND 739618 CU 00000000 0 4 i 68 SIGC TI, ID 739618 00000000 0 4 I 68 GR TMD 739618 GA.PI 00000000 0 4 1 68 CCL TND 739618 MV 00000000 0 4 I 68 DATA RECORD TYPE 0 DEPT = 9458.000 SGFN = 24.170 SGFF = 24.054 S~BH = 65.772 NSBF = 111.390 FSBF = 27.183 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.222 PHIT = -999.000 S~FM = 24.019 SIGQ = .972 ~4ER = .011 RSBF = .934 ABTN = 19601.300 SGIN = 20.874 SIGC = 1.173 ~R = -1.000 CCL = 1.000 DEPT = 9358.000 SGFN = 21.576 SGFF = 18.953 SGBH = 68.348 NSBF = 103.744 FSBF = 10.241 NTMD = 16116.640 FTMD = 2916.438 RTMD = 5.526 CRNF = 6.181 PHIT = .329 S~FM = 18.269 SIGQ = .979 G4ER = .013 RSBF = .848 ABTN = 29808.960 SGIN = 14.333 SIGC = 1.333 ~R = 25.070 CCL = 588.632 DEPT = 9258.000 SGFN = 20.151 S~FF = 17.952 SGBH = 67.199 NSBF = 107.626 FSBF = 11.360 NTMD = 16616.620 FTMD = 3226.021 RTMD = 5.151 CRNF = 5.754 PHIT = .266 S~FM = 16.76.5 SIGQ = .981 ~4ER = .016 RSBF = .965 ABTN = 32633.420 SGIN = 12.621 ,SI~C = 1.333 OR = 26.771 CCL '= 588.647 DEPT = 9158.000 SGFN = 21.193 SGFF = 18.197 SGBH = 68.904 NSBF = 112.629 FSBF = 9.604 NTMD = 15913.960 FTMD = 3156.670 RTMD = 5.041 CRNF = 5.669 PHIT = .254 SGFM = 17.806 SI~Q = .978 O4ER = .025 RSBF = .983 ABTN = 33512.450 SOIN = 13.805 SI~C = 1.333 GR = 28.115 CCL = 588.563 DEPT = 9058.000' SGFN = 25.562 SGFF = 22.454 SGBH = 69.528 NSBF = 117.942 FSBF = 10.729 NTMD = 14595.520 FTMD = 2610.502 RTMD = 5.591 CRNF = 6.272 PHIT = .343 SGFM = 22.502 SIGQ = .982 G4ER = .007 RSBF = .799 ABTN = 29041.950 SGIN = 19.153 SIGC = 1.211 GR =. 31.517 CCL = 586.964 Page 29 DEPT = 8958.000 SGFN = 22.360 SGFF = 19.200 SGBH = 65.991 NSBF = 116.225 FSBF = 9.996 NTMD = 15542.360 FTMD = 3021.756 RTMI) = 5.143 CRNF = 5.726 PHIT = .262 SGFM = 19.099 SIGQ = .969 G4ER = .022 RSBF = .980 ABTN = 32133.710 SGIN = 15.277 SIGC = 1.329 GR = 30.157 CCL = 588.082 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.010 t---- 0 --- 92/10/30 --- 1024 --- LO --- COMCEN.011 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH" FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 ----m O --- 92/10/30 --- 1024 --- LO --- COMCEN.010 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER= 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER= 04 DEPTH INCREMENT= 0.2500 FILE SUMMARY VENDOR'TOOL CODE START DEPTH TMD 9457.0 $ LOG HEADER DATA DATE LOGGED= SOFTWARE VERSION= TIME LOGGER ON BOTTOM= TD DRILLER (FT): TD LOGGER (FT)= TOP,LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT)= '. STOP DEPTH 8899.5 08-DEC-91 DLS 4.01 0900 08-DEC-91 9571.0 9438.0 8886.5 9450.0 Page 30 LOGGING SPEED (FPHR)= DEPTH CONTROL USED (YES/NO): 1200.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TMD TMD $ TOOL NUMBER 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 12.250 9579.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER/BORAX 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9310.0 BASE NORMALIZING WINDOW (FT):' 9410.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS)~ 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS'): 30000 TOOL S~TANDOFF (IN):. · REMARKS= PUMPING INFORMATION FOR BORAX PASS ~4~ VOLUME & TYPE: 19.BBLS CRUDE TOTAL PUMPED: 635 BBLS SEAWATER LIS FORMAT DATA ******************************************************************************* DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: 'TYPE SIZE REPR. CODE ENTRY Page 31 i i 66 0 2 i 66 0 3 2 79 80 4 i 66 1 5 I 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 i 66 1 0 I 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICES UNITS AP1 CODE FILES SIZE SSAMP REPR. DEPT F 00000000 0 4 i 68 SGFN TMD 739618 CU 00000000 0 4 I 68 SGFF TMD 739618 CU 00000000 0 4 I 68 SGBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CNTS 00000000 0 4 i 68 FSBF TMD 739618 CNTS 00000000 0 4 i 68 NTMD TMD 739618 CNTS 00000000 0 4 i 68 FTMD TMD 739618 CNTS 00000000 0 4 i 68 RTMD TMD 739618 00000000 0 4 i 68 CRNF TMD 739618 00000000 0 4 I 68 PHIT TMD' 739618 DECI 00000000 0 4 i 68 SGFM TMD 739618 CU 00000000 0 4 i 68 SIGQ TMD 739618 00000000 0 4 I 68 G4ER TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 i 68 ABTN TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 i 68 GR TMD 739618 GAPI 00000000 0 4 I 68 CCL TMD 739618 MV 00000000 0 4 I 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9457.000 SGFN = 26.216 S~FF = 2.I.824 S~BH = 74.384 NSBF = 121.388 FSBF = 27.058 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 1.551 PHIT = -999.000 SGFM = 22.627 SIGQ = .984 G4ER = .004 RSBF = .671 ABTN = 16539.700 SGIN = 19.285 SIGC = 1.208 GR = -1.000 CCL = 1.000 ., DEPT = 9357.000 SGFN = 18.950 S~FP = 15.977 SGBH = 131.964 NSBF = 65.551 FSBF = 7.333 NTMD = 8500.469 FTMD = 1747.560 RTMD'= 4.864 CRNF = 6.133 PHIT = .322 SGFM = 15.343 SlGQ = .999 G4ER = .007 RSBF = .606 ABTN = 12539.330 SGIN = 15.604 SIGC = 1.303 GR = 32.590 CCL = ' 789.081 Page 32 DEPT = 9257.000 SGFN = 16.707 SGFF = 14.413 SGBH = 123.808 NSBF = 72.446 FSBF = 8.094 NTMD = 8904.633 FTMD = 2083.763 RTMD = 4.273 CRNF = 5.513 PHIT = .233 SGFM = 13.364 SIGQ = .990 G4ER = -.004 RSBF = .665 ABTN = 13396.700 SGIN = 13.525 SIGC = 1.333 GR = 37.084 CCL = 788.530 DEPT = 9157.000 SGFN = 17.035 SGFF = 13.566 SGBH = 123.793 NSBF = 80.183 FSBF = 7.291 NTMD = 8704.898 FTMD = 2162.875 RTMD = 4.025 CRNF = 5.288 PHIT = .203 SGFM = 12.490 SIGQ = .989 G4ER = .013 RSBF = .678 ABTN = 13689.900 SGIN = 12.608 SIGC = 1.333 GR = 33.573 CCL = 789.394 DEPT = 9057.000 SGFN = 21.480 SGFF = 19.205 SGBH = 127.652 NSBF = 85.792 FSBF = 9.063 NTMD = 7306.0'00 FTMD = 1652.874 RTMD = 4.420 CRNF = 5.677 PHIT = .255 SGFM = 18.199 SIGQ = .993 G4ER = -.007 RSBF = .721 ABTN = 13475.200 SGIN = 18.604 SIGC = 1.232 GR = 34.913 CCL = 789.016 DEPT = 8957.000 SGFN = 19.984 SGFF = 17.042 SGBH = li7.332 NSBF = 90.920 FSBF = 9.265 NTMD = 7914.902 FTMD = 1855.530 RTMD'= 4.26.6 CRNF = 5.460 PHIT = .226 SGFM = 16.393 SIGQ = .991 G4ER = .013 RSBF = .791 ABTN = 13803.530 SGIN'= 16.707 SIGC = 1.273 GR = 38.104 CCL = 789.002 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.011 t---- O --- 92/10/30 --- 1024 --- LO --- COMCEN.012 ****************************************************************************** FILE HEADER RECORD .............................. TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE --- COMCEN.012 m~-- 0 --- 92/loi3o --- 1024 --- LO Page 33 OPTIONAL PREVIOUS FILE NAME --- COMCEN.011 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER: 12 RAW CURVES Curves and log header data for each pass in separate files~ raw background pass in last file. PASS NUMBER: 05 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TMD 9457.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TMD TMD BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): 8900.0 08-DEC-91 DLS 4.01 0900 08-DEC-91 9571.0 9438.0 8886.5 9450.0 1200.0 NO TOOL NUMBER mmmmmmmmmmm 106315 12.250 9579.0 SEAWATER/BORAX THERMAL ,Page 34 MATRIX: MATRIX DENSITY= HOLE CORRECTION (IN): SANDSTONE 2.65 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9310.0 EASE NORMALIZING WINDOW (FT): 9410.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEARCOUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 0.0 REMARKS: PUMPING INFORMATION FOR BORAX PASS VOLUME & TYPE: 19 BBLS CRUDE TOTAL PUMPED: 654 BBLS SEAWATER $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY ' i i 66 0 2 i 66 0 3 2 79 80 4 i 66 1 5 i 66 1 8 4 73 30 9 4 65 .lIN 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 ' i 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS: MNEM SERVID SERVICE~ UNITS API CODE FILE~ DEPT F 00000000 SGFN TMD .739618 CU 00000000 SGFF TMD 739618 CU 00000000 SGBH TMD 739618 CU 00000000 NSBF TMD 739618 CNTS 00000000 FSEF TMD 739618 CNTS 00000000 NTMD TMD 739618 CNTS 00000000 FTMD TMD 739618 CNTS 00000000 RTMD TMD 739618 00000000 CRNF TMD 739618 00000000 PHIT TMD 739618 DECI 00000000 SGFM TMD 739618 CU 00000000 SIZE ~SAMP REPR. 4 i 68 4 I 68 4 i 68 4 i 68 4 i 68 4 I 68 4 i 68 4 i 68 4 i 68 4 i 68 4 i 68 4 I 68 Page 35 SIGQ TMD 739618 00000000 0 4 i 68 G4ER TMD 739618 00000000 0 4 i 68 RSBF TMD 739618 00000000 0 4 I 68 ABTN TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 i 68 SIGC TMD 739618 00000000 0 4 i 68 ~R TMD 739618 GAPI 00000000 0 4 i 68 CCL TMD 739618 MV 00000000 0 4 i 68 DATA RECORD TYPE 0 DEPT = 9457.000 SGFN = 21.905 SGFF = 20.518 SGBH = 114.823 NSBF = 103.268 FSBF = 28.313 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 2.617 PHIT = -999.000 SGFM = 20.714 SIGQ = .987 G4ER = .006 RSBF = .968 ABTN = 10905.240 SGIN = 19.153 SIGC = 1.189 ~R = -1.000 CCL = 1.000 DEPT = 9357.000 SGFN = 19.465 SGFF = 17.076 SGBH = 123.515 NSBF = 91.314 FSBF = 8.742 NTMD = 7680.172 FTMD = 1590.526 RTMD = 4.829 CRNF = 6.039 PHIT = .308 SGFM = 15.951 SIGQ = .993 G4ER = .005 RSBF = .625 ABTN = 12302.120 SGIN = 16.242 SIGC = 1.285 GR = 38.571 CCL = 788.236 DEPT = 9257.000 SGFN = 17.080 SGFF = 13.387 SGBH = 121.421 NSBF = 95.727 FSBF = 9.527 NTMD = 9021.328 FTMD = 2083.799 RTMD = 4.329 CRNF = 5.548 PHIT = .238 SGFM = 12.748 SIGQ = .995 G4ER = .000 RSBF = .651 ABTN = 13051.460 SGIN = 12.878 SIGC = 1.333 GR = 38.467 CCL = 774.563 DEPT = 9157.000 SGFN = 17.462 SGFF = 13.774 SGBH = 123.767 NSBF = 100.198 FSBF = 10.947 NTMD = 8309.609 FTMD = 2005.378 RTMD = 4.144 CRNF = 5.395 PHIT = .217 SGFM = 12.82,9 SIGQ = .996 G4ER = -.002 RSBF = .667 ABTN = 13333.660 SGIN = 12.963 SIGC = 1.333 ~R = 41.153 CCL = 786.608 DEPT = 905,7.000 SGFN = 21.273 SGFF = 17.987 SGBH = 123.262 NSBF = 104.311 FSBF = .9.766 NTMD .= 7440.594 FTMD = 1588.818 RTMD = 4.683 CRNF = 5.895 PHIT = .287 SGFM = 17.717 SIGQ = ~990 G4ER = .013 RSBF = .744 ABTN = 13715.730 SGIN = 18.098 SIGC = 1.241 GR = 41.942 CCL = 785.691 Page 36 DEPT = 8957.000 SGFN = 19.170 SGFF = 16.070 SGBH = 120.303 NSBF = 108.490 FSBF = 10.337 NTMD = 8156.727 FTMD = 1905.037 RTMD = 4.282 CRNF = 5.496 PHIT = .231 SGFM = 15.389 SIGQ = .995 G4ER = .010 RSBF = .758 ABTN = 13834.720 SGIN = 15.652 SIGC = 1.301 GR ~ 41.265 CCL = 785.040 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.012 --m~ 0 --- 92/10/30 --- 1024 --- LO --- COMCEN.013 ****************************************************************************** FILE HEADER RECORD TYPE 128 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL PREVIOUS FILE NAME --- COMCEN.013 ~ O ------ 5 --- 92/10/30 --- 1024 --- LO --- COMCEN.012 ****************************************************************************** COMMENT RECORD .................................. TYPE 232 FILE HEADER FILE NUMBER= 13 RAW CURVES Curves and log header data for each pass in separate files~ raw background pass in last file. PASS NUMBER: 06 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE TMD LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION:. TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) = BOTTOM LOG INTERVAL (FT): START DEPTH STOP DEPTH 9450.0 8901.5 08-DEC-91 DLS 4.01 0900 08-DEC-91 9571.0 9438.0 8886.5 9450.0 Page 37 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 1200.0 NO TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TMD TMD $ TOOL NUMBER 106312 106315 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 12.250 9579.0 BOREHOLE CONDITIONS FLUID TYPE= FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): SEAWATER/BORAX 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 12.250 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 9310.0 BASE NORMALIZING WINDOW (FT): 9410.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5300 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): O. 0 REMARKS: PUMPING INFORMATION FOR BOI~AX PASS ~6: VOLUME & TYPE: 19 BBLS CRUDE TOTAL PUMPED: 673 BBLS SEAWATER $ LIS FORMAT DATA ****************************************************************************** DATUM FORMAT SPECIFICATION RECORD ............... TYPE 64 ENTRY BLOCKS: TYPE SIZE REPR. CODE ENTRY Page 38 i I 66 0 2 i 66 0 3 2 79 8O 4 i 66 1 5 1 66 1 8 4 73 30 9 4 65 11 2 79 12 12 4 68 -999.000 14 4 65 F 15 i 66 68 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS= MNEM SERVID SERVICE~ UNITS API CODE FILES SIZE SSAMP REPR. DEPT F 00000000 0 4 i 68 SGFN TMD 739618 CU 00000000 0 4 I 68 SGFF TMD 739618 CU 00000000 0 4 i 68 SGBH TMD 739618 CU 00000000 0 4 i 68 NSBF TMD 739618 CNTS 00000000 0 4 i 68 FSBF TMD 739618 CNTS 00000000 0 4 i 68 NTMD TMD 739618 CNTS 00000000 0 4 i 68 FTMD TMD 739618 CNTS 00000000 0 4 I 68 RTMD TMD 739618 00000000 0 4 i 68 CRNF TMD 739618 00000000 0 4 i 68 PHIT TMD 739618 DECI 00000000 0 4 i 68 SGFM TMD 739618 CU 00000000 0 4 I 68 SIGQ TMD 739618 00000000 0 4 i 68 G4ER TMD 739618 00000000 0 4 I 68 RSBF TMD 739618 00000000 0 4 i 68 ABTN TMD 739618 00000000 0 4 i 68 SGIN TMD 739618 CU 00000000 0 4 I 68 SI~C TMD 739618 00000000 0 4 i 68 GR TMD 739618 GAPI 00000000 0 4 i 68 CCL TMD 739618 MV 00000000 0 4 i 68 ****************************************************************************** DATA RECORD TYPE 0 DEPT = 9450.000 SGFN = 20.570 SGFF = 21.414 SGBH = 112.661 NSBF = 119.246 FSBF = 33.959 NTMD = .000 FTMD = .000 RTMD = .000 CRNF = 2.599 PHIT = -999.000 SGFM = 21.846 SIGQ = .991 G4ER = .009 RSBF = .983 ABTN = 9809.371 SGIN = 22.434 SIGC = 1.174 GRi = -1.000 CCL = 1.000 DEPT = 93.50.000 SGFN = 17.651 SGFF = 14.994 SGBH = 129.510 'NSBF = 97.670 FSBF = 9.586 NTMD = 8683.113 FTMD = 1907.554 RTMD = 4.552 CRNF = 5.813 PHIT = .275 SGFM = 14.099 SIGQ = .993 G4ER = .012 RSBF = .623 ABTN = 12933.680 SGIN = 14.297 SIGC = 1.333 GR = 40.436 CCL = 782.707 Page 39 DEPT = 9250.000 SGFN = 17.598 SGFF = 14.529 SGBH = 120.800 NSBF = 103.661 FSBF = 10.283 NTMD = 8493.145 FTMD = 1908.992 RTMD = 4.449 CRNF = 5.656 PHIT = .253 SGFM = 13.771 SIGQ = .996 G4ER = .004 RSBF = .633 ABTN = 12500.270 SGIN = 13.953 SIGC = 1.333 GR = 42.910 CCL = 788.050 DEPT = 9150.000 SGFN = 18.575 SGFF = 15.544 SGBH = 126.656 NSBF = 107.441 FSBF = 10.268 NTMD = 8697.129 FTMD = 1791.866 RTMD = 4.854 CRNF = 6.085 PHIT = .315 SGFM = 15.003 SIGQ = .991 G4ER = .001 RSBF = .635 ABTN = 12722.030 SGIN = 15.247 SIGC = 1.314 GR = 42.085 CCL = 788.068 DEPT = 9050.000 SGFN = 20.898 SGFF = 17.794 SGBH = 126.514 NSBF = 109.701 FSBF = 11.793 NTMD = 7036.840 FTMD = 1598.007 RTMD = 4.404 CRNF = 5.653 PHIT = .252 SGFM = 17.149 SIGQ = .992 G4ER'= .003 RSBF = .683 ABTN = 12953.780 SGIN = 17.501 SIGC = 1.254 GR = 50.698 CCL = 787.327 DEPT = 8950.000 SGFN = 16.791 SGFF = 14.028 SGBH = 126.584 NSBF = 109.630 FSBF = 11.484 NTMD = 9085.395 FTMD = 2196.162 RTMD = 4.137 CRNF = 5.409 PHIT = .219 SGFM = 12.938 SIGQ = .989 G4ER = .006 RSBF = .719 ABTN = 14149.420 SGIN = 13.078 SIGC = 1.333 GR = 42.670 CCL = 787.667 ****************************************************************************** FILE TRAILER RECORD .............................. TYPE 129 FILE NAME SERVICE SUB LEVEL NAME VERSION NUMBER DATE OF GENERATION MAX. PHYSICAL RECORD LENGTH FILE TYPE OPTIONAL NEXT FILE NAME --- COMCEN.013 tm~ 0 ~m-- 5 --- 92/10/30 --- 1024 ! ****************************************************************************** TAPE TRAILER RECORD .............................. TYPE 131 SERVICE NAME DATE ORIGIN OF DATA TAPE NAME TAPE CONTINUATION NUMBER NEXT TAPE NAME --- COMCEN, --- 92/10/30 ~ 0 Page 40 COM16ENTS = REEL TRAILER RECORD .............................. TYPE 133 SERVICE NAME DATE ORIGIN OF DATA REEL NAME REEL CONTINUATION NUMBER NEXT REEL NAME COMMENTS~ --- COMCEN --- 9~/~o/~o --- ANCH --- 739618 ****************************************************************************** END OF TAPE ENCOUNTERED Page 41