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Home My WebLink About199-126 P8 /6-06A Regg, James B (DOA) From: Jones,Jeffery B (DOA) Sent: Friday, November 18, 2016 6:08 PMe' c ilk(l(, To: Regg, James B (DOA) Subject: well deficiency re-inspection PBF 16-08 & 11-09A Attachments: Deficiency Report BPXA PBF 16-8 1-1-16 JJ.pdf; Deficiency Report BPXA PBF 11-09A 1-1-16 JJ.pdf Jim, , ✓ I inspected the repairs to BPXA PBF wells 16-08 and 11-09A today.The leaking VR plug and LDS on 16-08 have been repaired and the wellhead has been cleaned.The wellhouse on 11-09A was modified to allow more room for the flowline to exit the wellhouse and it looks good also. t :•• - •- . . •-• _ . - . . - Thanks, � Jeff B.Jones Petroleum Inspector Alaska Oil & Gas Conservation Commission N. Slope Ofc: 907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. SCANNED JUN 2 7 201? • p6t,t_ k p tggize0 Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Thursday, November 17, 2016 3:27 PM 11(r3Lt(, To: DOA AOGCC Prudhoe Bay Cc: Regg, James B (DOA);AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E Subject: FW: 16-08 deficiency fixed Attachments: 3606_001.pdf I see this in our in box and don't have record of it being forwarded to AOGCC. Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 %AIRED JUN 0 8 2.U1!, Harmony— 7187 (Alternate: Vince Pokryfki) 1 • c i l well Well: 08OK a a 6REATEI Well Events ip _ fir + Prod/Inj • WWI s '' ees ' } r � I Home User Settings Help OperNotes 16-08 16/Nov/2016 HWSP for Mike and Jarod to install well house OperNotes 16-08 16/Nov/2016 HWSP for Mike and Jarod to install well house OperNotes 16-08 ' 14/Nov/20161W0#543668 for DSM's to fix W/H backing. OperNotes 16-08 '09/Nov/2016 BOL from valve crew installing IA companior OperNotes 16-08 08/Nov/2016 BCP#71866 for Valve shop to install compan AWGRS 16-08A 108/Nov/2016 T/I/O=SSV/0/ 150. Install 2" Comp IA. Instal .., _. Comp IA VR plug, PT blind to 2500 psi. Pass AWGRS 16-08A ;08/Nov/2016 Cant from WSR 11/7/16. Bleed 1AP to 0 psi i 1300 psi to 0 psi in 18 hrs. Monitored for 30 SV, WV, SSV = C. MV = O. IA, OA = OTG. 0 WellOps 16-08A 08/Nov/2016 Feld Operations Relevant To Well Work [DS( WellOps 16-08A 08/Nov/2016 Annular Communication Work [ANN] OperNotes 1-16-08 07/Nov/2016 SI & F/P'd F/L &. TBG with PD pump for I/A ci OperNotes 16-08 07/Nov/2016 RAP#77885 for DHD to bleed I/A to 0 psi for AWGRS 16-08A 07/Nov/2016 'T/1/0 = 260/1300/640. Temp = 70°. Bleed I SO, 466 bbls). Grease Crew services AL LV. _ Cont on WSR 11/8/16, SQUIDServiceWork 16-08 07/Nov/2016•svc LAT. WellOps 16-08A 07/Nov/2016 Annular Communication Work [ANN] WellStatus 46-08A 05/Nov/2016 BOPD: 66 BWPD : 2188 MCFPD: 64 AL Rate: OperNotes 16-08 05/Nov/2016 grease crew tried to remove the needle valv plug but the VR plug was leaking by. well wil OperNotes ,116-08 04/Nov/2016 RAP#77830 to do WH POT (passed) & tighter AWGRS ; 16-08A 04/Nov/2016 T/I/0=300/1500/640, Temp=110*. Repair le 1Found 5 LDS assemblies on CSG head showi (500 psi), bled to 0 psi. Monitored void for li head to 3500 psi, leaks mitigated. Bled void From: AK, OPS FS2 DS Ops Lead Sent: Tuesday, November 08, 2016 2:50 PM To: AK, OPS FF Well Ops Comp Rep Subject: 16-08 deficiency fixed This deficiency has just be fixed also.Thanks Josh. From: FS2scannerObp.com [mailto:FS2scanner@ bp.com] Sent: Tuesday, November 08, 2016 2:47 PM To: AK, OPS FS2 DS Ops Lead Subject: Attached Image 2 • • 1,11 k,e)'Ito State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: PBF well 16-08A Date: 11/1/16 PTD: 1991260 Operator: BPXA Type Inspection: SVS test Operator Rep: Josh McQueen Inspector: Jeff Jones Position: Lead Operator Op. Phone: 659-5494 Correct by(date): 11/15/16 Op. Email: akopsfs2dsopslead@bp.com Follow Up Req'd: Detailed Description of Deficiencies Date Corrected The wellhead flange that contains the VR plug is leaking. I- 3- A lock down screw is leaking on the wellhead. !( ,9, 'C Attachments: [ Operator Rep Signatures: rC., ite44,.. AOGCC Inspector *After signing,a •py o this •rm is to b .eft with the operator, Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 • • „� ta iAtAt State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: PBF well 16-08A Date: 11/1/16 PTD: 1991260 Operator: BPXA Type Inspection: SVS test Operator Rep: Josh McQueen Inspector: Jeff Jones Position: Lead Operator Op. Phone: 659-5494 Correct by(date): 11/15/16 Op. Email: akopsfs2dsopslead@bp.com Follow Up Req'd: Detailed Description of Deficiencies Date Corrected The wellhead flange that contains the VR plug is leaking. A lock down screw is leaking on the wellhead. Attachments: Signatures: �. � Operator Rep crk G2, ,.,, 1444, AOGCC Inspector *After signing, 5lOPO ayo this ! rm is to b eft with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the Original file, may be scanned dudng the rescan activity or are viewable by direct inspection of the file. / ~ ~ /~ Well History File Identifier Organization (do.e~ D Two-Sided RESOA'N ~ior items: r Grayscale items: o Poor Quality Originals: Other: DIGITAL DATA o Diskettes, No. Other. No/Type OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) o Logs of various kinds TOTAL PAGES; NOTES: ORGANIZEO 8Y BEVERLY SHERYL MARIA LOWELL Project Proofing o Other PROOFED OAT E BEVERLY BREN ~~"~SHERYL MARIA LOWELL E)ATE¢,~ Staff Proof Scanned (do°e) P~-GES' ~,EvERL¥ BREt; VINCEI~S"'~E~Y[)MAP;A LOWELL F'~[ SCANrJ£O E','. BEvEI~L h 8P£N '~Sl"4ER'r't MX-~IA LOWELL Oeneral NOTES Or (.omments abOdl th~s lile PACES Oual~ty Checked 04/28/11 SchIumberger /10.5729 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE / 93 °- t' y? 03/14/11 1 O' o/ 1 17 -06 BBKA -00094 INJECTION PROFILE 0 y(t J ` 03/10/11 1 r > 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE Q «- ( 6 03/08/11 1 ♦" L( 1 G -23B BLPO-00079 MEM PRODUCTION PROFILE ni - 1444 03/09/11 1 ' 1 16 -08A BJGT -00022 GLS ^ 03/07/11 1 r " 1 A 02 -18B EHLPO -00087 `ld Iut=i _ • • (e --/ , 6 03/25/11 - . % 1 J -22A BJGT -00023 CBL •Ir — _ 03/10/11 :WAN L -210 BLPO -00086 MEM INJECTION PROFILE • - ~ 03/23/11 1 0' 1 V -105 BLPO.00091 MEM INJECTION PROFILE • r 03/29/11 1 •G 1 V -220 BBSK -00065 INJECTION PROFILEANFL f ♦ • `' ,� Yem 1 V -212 0D88.00096 ' ' ` I • ' • - • i 04/03/11 1 1 _ III L -214A BCRJ -00073 INJECTION PROFILE i i1! 03/18/11 1 ♦ 1 V.223 BAUJ -00071 MEM INJECTION PROFILE M. r ` � _ treg 1 V -217 BAUJ -00077 MEM INJECTI• PROFILE . _ F 04/17/11 1 7 1 1 a 3- 05/0 -29 BG4H -00043 Q Z f'g, 03/20/11 1 fit • s 1 1- 47A/M -20 BLPO -00092 MEM PRODUCTION PROFILE ♦igawrT•Y ireT,L Gi 1 1.25 -22 _ BBSK -00057 [II RWM fe -- T� S -Ot C BCUE -00113 MEM CBL ,-.3 p_ IL/ r 03/17/11 r "3o • f 1 1 11 -30 B088-00097 MEM INJECTION PROFILE j may' 4- U' - `4' 04/18/11 1 - 0 e 1 04 -11A AWJI -00134 INJECTION PROFILE 01,, 0 -�kJ /- 03/24/11 1 , (' "' = 1 P2 -41 BG4H -00044 PRODUCTION PROFILE - — _.. 03/22/11 1 _ ey. It 1 D -260 BMSA -00009 EETIMINIP1Z,. — . 03/24/11 f 0 •' J MIN 1 , 02 -18B BLPO -00087 MEM PRODUCTION PROFILE - ; t, 03/24/11 1 . 1 Z -20 BP5G -00010 GLS ill. Q _i n O 03/29/11 1 % 6'951 1 Y -29A BCUE -00122 MEM LDL j -7 eo CY; / 03120/11 1 Jo- 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 ti h 5 .. • STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO~OF SUNDRY WELL OPERA ONS R~~~'~® ~Ef3 ~ 2 2~1~ 1. Operations Performed: ~'s~~ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter ~15tl~tlY19N~~ ~+s~ I ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other Anchorage ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: .Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 199-126 3. Address: ^ Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20549-01-00 7. Property Designation: \ 8. Well Name and Number: ADL 028332 & 028333 ~ PBU 16-08A 9. Field /Pool(s): O Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured ~ 11148' feet true vertical ~ g08g' feet Plugs (measured) None Effective depth: measured 11112' feet Junk (measured) None true vertical g07g' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2717' 13-3/8" 2717' 2717' 4930 2670 Intermediate 9297' 9-5/8" 9297' 8861' 6870 4760 Production Liner 441' 7" 8982' - 9423' 8575' - 8975' 8160 7020 Liner 2194' 2-7/8" 8951' - 11145' 8547' - 9088' 10570 11160 Perforation Depth: Measured Depth: 9840' - 10821' True Vertical Depth: 9056' - 9044' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr80 / L-80 9016' 8606' Packers and SSSV (type, measured and true vertical depth): g_5/8" x 4-1/2" HES 'TNT' packer; 8777' 8390' 9-5/8" x 4-1/2" Baker'SB-3A' packer 8902' 8503' 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~ ~ aiy r`" ~ ~ Gam; ~ ~ ~ 1, °~ ~. ~'t3~~ ?' ~ ~ u 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ^ Copies of Logs and Surveys run 1 Well Class after work: ^ Exploratory ®Development ^ Service ort of Well O erations ® Dail Re y p p ® Well Schematic Diagram Well Status after work: ®Oil ^ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Hank Baca, 564-5444 N/A Printed Name Terris Hubble Title Drillin Technolo ist O Prepared By Name/Number: ,~ Si nature Phone 564-4628 Date Terris Hubble, 564-4628 g Form 10-404 Revised 07/2009 RBt3MS FEB 12 ZO~~-Z Z~~g% Submft Original Only r' ~3,/~7 16-08A, Well History (Pre Rig Workover) Date Summary 1/4/2010 WELL S/I ON ARRIVAL. TAG TRRSSV C~3 2185' SLM / 2212' MD W/ 3.84" NO-GO CENT. RAN FLAPPER CHECKER TO FUNCTION TEST AVA SC TRSSSV C~1 2185' SLM / 2212' MD (good test). 1/5/2010 TAG IBP C~? 8858' SLM W/ 3.65" CENT, 3.48" LIB (SLIGHT IMPRESSION OF FILL). CO. REP SAYS DUMP SLUGGIT. DUMP BAILED 12 GAL OF SLUGGITS C«~ 8858' SLM. TAG TOP OF SLUGGITS ~ 8838' SLM (20' of sluggits) WITH 3.75" DRIFT (no obstructions). PURGE CHEMICAL INJECTION LINE WITH 13 GAL HYDRAULIC FLUID. WELL LEFT S/I, DSO NOTIFIED. 1/12/2010 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 685/425/0 PSI. 3.65" JET CUT 4.5" TUBING AT 8864'. SET DOWN AT 8868', CORRELATED TO TUBING SUMMARY. FINAL T/I/0= 685/425/0 PSI. JOB COMPLETE. WELL LEFT SHUT-IN. 1/21/2010 T/I/0=800/50/0 temp=S1 Circ-out/ CMIT. TxIA Inconclusive to 3500 psi. OMIT. TxIA Passed to 500 osi. MIT OA Passed to 2000 psi. Freeze Protect flow line. Pumped 5 bbls neat methanol, followed by 893 bbls of 1 % kcl down TBG taking returns up IA and down FL. Rig up to IA and pump 1 bbl of neat to FP hardline jumper. Pumped 150 bbls of 110° diesel down IA, taking returns up TBG and down FL. Freeze protect flowline. Pumped 2 bbl neat, 36 bbls crude, 5 bbls neat, 45 bbls crude and 15 bbls diesel on the tail down FL. Bleed down pressures. CMIT TxIA to 500/460 psi lost 0. 0 psi in 30 minute test. MIT OA pressure up to 2000 psi with 1.9 bbls diesel. OA lost 60 psi in first 15 minutes and 20 psi in second 15 minutes. For a total of 80 psi. in 30 minutes. Bled all pressures to 0. FW HP's=0/0/0 Operator notified of valve positions and result of job. 1/22/2010 T/I/0= 200?/50/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS) (pre rig). Unable to open swab. PPPOT-T: Stung into test port (100 psi), bled to 0 psi. Function LDS (standard), 6 are stuck w/flats starting to twist off, the rest functioned normal (2.5"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (50 psi), bled to 0 psi. Function LDS (standard), 5 are stuck w/flats starting to twist off, the rest functioned normal (2.75"). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 1/23/2010 T/I/0= ?/0/0, Temp=Sl. LDS repair/drill out. DHD maintained open bleed on IA/OA. Casing head: Stung into IC test void to verify 0 psi. Broke free and removed 5 stuck LDS. Tapped threads in head and installed 5 new LDS assembly. Replaced 1 LDS that had damaged flats. Did not drill. PT IC test void to 3500 psi, no external leaks. 1/24/2010 T/I/0=0/0/0, Temp=S1. LDS repair/drill out (pre rig). DHD maintained open bleed on TBG & IA. 6 stuck LDS on tubing head. Stung into test void to verify 0 psi. Broke free and removed LDS. Tapped threads in head and installed 6 new LDS assembleys. Did not drill. PPPOT-T: Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 1/25/2010 WELL S/I ON ARRIVAL. RAN 3.84" CENT. TAGGED AVA TRSV NOGG C~ 2183' SLM. SET HOLD OPEN SLEEVE (dogless DB lock, 16' OAL, 2.23" MIN ID) IN AVA TRSV C~ 2183' SLM. JOB COMPLETE, WELL LEFT S/I ON DEPARTURE. T/I/O = 0/0/0 1/26/2010 T/I/0=20/100/0 Set 5-1/8" ISA BPV #537 thru tree for Doyon 16 pre-rig. 1-2' ext. used, tagged C«~ 96". Rolled Annulus Valve to backside of tree and PT'd to 5000 psi. No problems. Complete. 1/28/2010 Freeze Protect Flowline (RWO Expense) Pump 75 bbls crude down flowline and pressured up to 1000 psi. per DSO instructions. Page 1 of 2 n 16-08A, Well History (Pre Rig Workover) Date Summary 1/28/2010 T/I/O = BPV/1230/0. Temp = SI. Bleed WHP's to 0 psi (pre RWO). No AL, flowline, scaffold or wellhouse. 2" integral installed on IA. IA FL C~ surface. Bled IAP from 1230 psi to 10 psi (15.2 bbls fluid, filled 2 BT's) in 2.5 hours. Monitor for 30 min. IAP increased 10 psi to 20 psi. FW HP's BPV/20/0. 1/30/2010 T/I/O =BPV/60/0. Temp = SI. WHP's post bleed (RWO prep). No AL, flowline, scaffold or wellhouse. IAP increased 40 psi to 60 psi. OAP unchanged since 1/28/10. Page 2 of 2 • BP EXPLORATION Page 1 of 11 Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 1/29/2010 09:00 - 00:00 15.00 MOB N WAIT 1/30/2010 00:00 - 12:00 12.00 MOB N WAIT 12:00 - 00:00 12.00 MOB N WAIT Spud Date: 1/18/1981 Start: 1 /29/2010 End: 2/8/2010 Rig Release: 2/8/2010 Rig Number: 16 Phase Description of Operations PRE WAIT ON WEATHER TO CLEAR UP ENOUGH FOR PAD PREP TO BE COMPLETED. -STAY OVER WELL 16-03. -PERFORM LIGHT MAINTENANCE AND HOUSEKEEPING ON RIG. SERVICE DRAWWORKS, SERVICE CELLAR MANIFOLD -REMOVE SNOW BUILD UP FROM INSIDE RIG, CLEAR WALKWAYS AROUND THE OUTSIDE OF THE RIG. PRE WAIT FOR PAD PREP TO BE COMPLETED. -STAY OVER WELL 16-03. -PERFORM LIGHT MAINTENANCE AND HOUSEKEEPING ON RIG. -REMOVE SNOW BUILD UP FROM INSIDE RIG, CLEAR WALKWAYS AROUND THE OUTSIDE OF THE RIG. -TOOL SERVICE COORDINATED EQUIPMENT REMOVES SNOW FROM AROUND 16-03 AND THEN BEGINS PAD PREP. PRE CONTINUE TO WAIT FOR PAD PREP TO BE COMPLETED -RIG REMAINS OVER 16-03. -RIG WELDER REPAIRS DRIP PAN. -CONTINUE LIGHT MAINTENANCE AND HOUSEKEEPING THROUGHOUT RIG. -CLARIFY PAD PREP REQUIREMENTS WITH TOOL SERVICE AND DRILLING FIELD ENGINEER. -MOVE PUMP AND GEN MODULE. -PREPARE TO MOVE RIG OFF OF 16-03. 1/31/2010 100:00 - 02:00 2.00 ~ MOB ~ N ~ WAIT ~ 02:00 - 04:00 2.00 ~ MOB P PRE CONTINUE TO WAIT FOR PAD PREP TO BE COMPLETED. -RIG REMAINS OVER 16-03. -CONTINUE LIGHT MAINTENANCE AND HOUSEKEEPING THROUGHOUT RIG. -PREPARE TO MOVE RIG OFF OF 16-03. PRE PJSM FOR MOVING RIG. MOVE RIG OFF 16-03. -SPOT RIG OVER WELL 04:00 - 06:00 2.00 MOB P PRE MIRU -SPOT SLOP TANK, PUMP MODULE, GENERATOR MODULE. -INSTALL SECOND ANNULUS VALVE AND LINE FROM OA TO SLOP TANK. -PRESSURE ON OA = 0-PSI, IA = 50-PSI -RU CIRCULATING MANIFOLD AND LINES IN THE CELLAR. **ACCEPT RIG AT 0600-HRS ON 1/31/2010** 06:00 - 07:00 1.00 WHSUR P DECOMP PU DSM LUBRICATOR AND PRESSURE TEST TO 500-PSI. GOOD TEST. -PULL ISA BPV AND LD LUBRICATOR AND BPV. -50-PSI UNDER BPV. -BEGIN BRINGING ON SEAWATER WHILE PULLING BPV. 07:30 - 08:00 0.50 KILL P DECOMP FILL ALL LINES TO BE USED FOR CIRCULATING OUT FREEZE PROTECTION AND PRESSURE TEST SAME TO 3500-PSI. GOOD TEST. HOLD PJSM WITH RIG GREW, DOYON TOOLPUSHER, BP Nnntea: zn wzuiu SO/:4Z YM BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Spud Date: 1/18/1981 Event Name: WORKOVER Start: 1/29/2010 End: 2/8/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/8/2010 Rig Name: DOYON 16 Rig Number: 16 Date .From - To Hours Task Code NPT Phase Description of Operations 1/31/2010 07:30 - 08:00 0.50 KILL P DECOMP WSL, CH2MHILL TRUCK DRIVERS AND LEAD. DISCUSS SPILL POTENTIALS, POOR WEATHER CONDITIONS AND THE USAGE OF SPOTTERS TO GET LARGE TRUCKS AROUND THE END OF THE RIG. -FILL ALL LINES TO BE USED FOR CIRCULATING OUT FREEZE PROTECTION AND PRESSURE TEST SAME TO 3500-PSI. GOOD TEST. 08:00 - 12:30 4.50 KILL P DECOMP CIRCULATE THE LONG WAY AT 6-BPM WITH 550-PSI. -TOOK 8-BBLS TO GET RETURNS. -SEE CALCULATED VOLUME OF DIESEL ON THE BACKSIDE, FOLLOWED BY -30-BBLS OF CRUDE OIL AND THEN SEAWATER. -NEAR END OF CIRCULATION, SEE -30-BBLS OF CRUDE FOLLOWED BY CALCULATED VOLUME OF DIESEL. -SEAWATER FROM HOLE HAS CRUDE STRUNG THROUGHOUT. -GASSY RETURNS FROM BOTTOMS UP UNTIL CLEAN SEAWATER RETURNS. -CBU AGAIN AT 6-BPM WITH 500-PSI. -OA PRESSURE CLIMBS TO 150-PSI WHILE CIRCULATING. 12:30 - 13:00 0.50 KILL P DECOMP MONITOR WELL -STATIC. -BLOW DOWN ALL CIRCULATING LINES IN CELLAR -BLEED GAS OFF OF OA, LEAVING 50-PSI ON OA. 13:00 - 14:00 1.00 WHSUR P DECOMP REMOVE TREE CAP /CIRCULATING LINE AND OPEN MASTER VALVE. -PICK UP T-BAR. FMC SET ISA BPV. ,LD T-BAR. -REINSTALL TREE CAP & LINE. -PRESSURE TEST ISA BPV FROM BELOW TO 500-PSI FOR 10-CHARTED MINUTES. GOOD TEST. 14:00 - 15:00 1.00 WHSUR P DECOMP BLOW DOWN ALL CIRCULATING LINES IN CELLAR AND RD CIRCULATING MANIFOLD. -OA PRESSURE = 75-PSI. -DRAIN TREE. 15:00 - 17:00 2.00 WHSUR P DECOMP HOLD PJSM WITH RIG CREW ON ND TREE & ADAPTER FLANGE. -ND TREE AND ADAPTER FLANGE. -2 BARRIERS FOR ND ARE 1) IBP AT 8892' AND 2) TESTED ISA BPV IN TUBING HANGE°fi. '~ -CLEAN WELLHEAD. CHECK 5-3/4" RH ACME CROSSOVER WITH 10-RH TURNS. -LD MEASUREMENTS 3" IN, 4" OUT. -INSTALL BLANKING PLUG WITH 10-RH TURNS AND BLANKING PLUG XO WITH 7-LH TURNS. 17:00 - 20:00 3.00 BOPSU P DECOMP PJSM -NU BOP -INSTALL MOUSE HOLE. -RU TEST EQUIPMENT 20:00 - 00:00 I 4.00 P DECOMP TEST BOP TO 250-PSI LOW AND 3500-PSI HIGH. TEST THE VBRs (3-1/2" X 6") WITH 4" AND 4.5" TEST JOINTS. TEST ANNULAR WITH 4" TEST JOINT TO 250-PSI LOW AND 3500-PSI HIGH. CHART TESTS FOR 5-MIN EACH. -ON TEST #2 NOTICED CHOKE HOSE CLAMP WAS Printed: 2/10/2010 3:57:42 PM • BP EXPLORATION - Page 3 of 11 Operations-Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 1Date From - To Hours. Task Code' NPT 1/31/2010 120:00 - 00:00 I 4.001 BOPSUR P 2/1/2010 100:00 - 01:00 I 1.001 BOPSUR P 01:00-01:30 I 0.501 WHSURP 01:30 - 03:30 I 2.00 WHSUR P 03:30 - 05:30 I 2.001 PULL I P 05:30 - 07:00 I 1.501 PULL i P 07:00 - 17:00 10.00 PULL P 17:00 - 18:00 I 1.001 PULL I P 18:00 - 21:30 I 3.501 PULL I P 21:30 - 23:00 I 1.501 PULL I P 23:00 - 00:00 I 1.001 CLEAN I P Spud Date: 1 /18/1981 Start: 1 /29/2010 End: 2/8/2010 Rig Release: 2/8/2010 Rig Number: 16 Phase. Description of Operations DECOMP LEAKING, TIGHTENED AND RESUMED TESTING. -AOGCC REP BOB NOBLE WAIVED WITNESS. DECOMP TEST BOP TO 250-PSI LOW AND 3500-PSI HIGH. TEST THE VBRs (3-1/2" X 6") WITH 4" AND 4.5" TEST JOINTS. TEST ANNULAR WITH 4" TEST JOINT TO 250-PSI LOW AND 3500-PSI HIGH. CHART TESTS FOR 5-MIN EACH. -AOGCC REP BOB NOBLE WAIVED WITNESS. DECOMP LD BOP TEST JOINT -BLOW DOWN LINES. DECOMP -FMC PULL BLANKING PLUG FROM ISA BPV. -RU DUTCH RISER. -RU DSM LUBRICATOR AND TEST TO 500-PSI. -PULL BPV -IA = 0-PSI, OA = 70-PSI --- BLEED TO 0-PSI AND LEAVE OPEN. -BLEED DOWN CONTROL AND CHEMICAL INJECTION LINES -RD DSM AND DUTCH RISER DECOMP MU LANDING JOINT TO LH ACME XO. -RIH SCREW INTO HANGER. -FMC BOLDS. -PULL HANGER FREE WITH 140K-LBS -PULL HANGER TO RIG FLOOR -LD HANGER AND 10' 5-1/2" PUP JT UNDERNEATH TOGETHER. DECOMP RU CIRCULATING HEAD CIRCULATE BOTTOMS UP AT 7.5-BPM WITH 650-PSI. -MONITOR WELL -STATIC. -PUMP 15-BBL 9.8-PPG DRY JOB. -BLOW DOWN CIRCULATING LINE AND RD CIRCULATING HEAD. DECOMP POH & LD 4-1/2" 12.6# L80 BTC-MOD TUBING. LD TUBING FROM 8864' TO 1600' -TUBING APPEARS IN GOOD CONDITION WITH LIMITED VISIBLE DAMAGE TO CONNECTIONS. DECOMP CHANGE OUT CONTROL LINE SPOOL AND LD PALLET OF CLAMPS. DECOMP POH & LD 4-1/2" 12.6# L80 BTC-MOD TUBING. LD TUBING FROM 1600' TO SURFACE. -RECOVER 217-FULL JTS OF TUBING, 1-SSSV, 8-GEMS, 1-CHEMICAL INJECTION MANDREL, 225-RT CLAMPS, 24-SS BANDS AND 1-CUT JT. -REPORTED TO HAVE 215-RT CLAMPS, 28-SS BANDS -CUT JT IS 9.89' LONG AND CUT IS FLARED TO 5". CUT HAS JAGGED EDGES AND 1"SPLIT ON THE SIDE OF THE PIPE. -AT BOTTOM LAST GLM HAD A 1" HOLE IN IT. LAST FEW JOINTS SHOWED SIGNS OF ERROSION, LAST FULL JOINT HAD 2-HOLES 1" LONG. DECOMP LD SPOOLER AND TUBING EQUIPMENT. CLEAN RIG FLOOR. CHANGE OUT PIPE HANDLING EQUIPMENT. -PREPARE TO PU DRESS-OFF BHA. DECOMP PJSM ON MU BHA AND RIH WITH DP. ~~ ~~ Printed: 2/10/2010 3:57:42 PM BP EXPLORATION Page 4 of ~ Qperations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Spud Date: 1/18/1981 Event Name: WORKOVER Start: 1/29/2010 End: 2/8/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/8/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2010 23:00 - 00:00 1.00 CLEAN P DECOMP 2/2/2010 00:00 - 01:00 1.00 CLEAN P DECOMP 01:00 - 09:30 8.50 CLEAN P DECOMP 09:30 - 10:30 1.00 DHB P DECOMP 10:30 - 11:00 0.50 DHB P DECOMP 11:00 - 00:00 13.00 DHB N WAIT DECOMP 2/3/2010 00:00 - 08:00 8.00 DHB N WAIT DECOMP 08:00 - 10:00 2.00 BOPSU N DECOMP 10:00 - 11:30 1.50 BOPSU P DECOMP 11:30 - 12:30 1.00 BOPSU P DECOMP -MU 8-1/2" X 4-1/2" DRESS-OFF SHOE, 8-1/8" OD OVERSHOT DRESSED TO CATCH 4-1/2" TUBING, OIL JAR, PUMP OUT SUB, 6-EA 6-1/4" DC, ACCELERATOR. -TOTAL LENGTH 232.66' MU 8-1/2" X 4-1/2" DRESS-OFF SHOE, 8-1/8" OD OVERSHOT DRESSED TO CATCH 4-1/2" TUBING, OIL JAR, PUMP OUT SUB, 6-EA 6-1/4" DC, ACCELERATOR. RIH WITJ-1 BHA #1, PICKING UP 4" DP FROM PIPE SHED TO 7143'. / -RUNNING IN HOLE SLOWLY DUE TO SNOW IN THE DP AND HAVING TO THAW TO ENSURE PIPE WILL DRIFT. -PU WT = 146K-LBS, SO WT = 146K-LBS. PU 9-5/8" HES STORM PACKER AND RIH ON 3-JTS OF DP TO SET AT 99' BELOW THE ROTARY TABLE. -SET PER HES REP WITH 1/4-RH TURN. SET DOWN STRING WEIGHT AND RELEASE RUNNING TOOL. =POH & LD 3-JTS OF 4" DP AND STORM PACKER RUNNING TOOL. RU AND PRESSURE TEST STORM PACKER ABOVE TO 1000-PSI FOR 10-CHARTED MINUTES. -GOOD TEST. -RD TEST EQUIPMENT AND BLOW DOWN LINES. WAIT ON WEATHER (PHASE 2, LEVEL 2 WEATHER CONDITIONS WITH POTENTIAL TO GO TO PHASE 3) -CIRCULATE ACROSS THE TOP OF THE HOLE. -1600-HRS =PHASE 3 CONDITIONS ANNOUNCED. -2200-HRS CONTACTED IMT AND DUE TO WEATHER CREW WAS NOT ALLOWED TO CONVOY TO CHANGE OUT. WAITING ON WEATHER TO DIE DOWN A LITTLE BEFORE CREW WOULD BE ABLE TO CHANGEOUT. WAITING ON WEATHER. PHASE 3 CONDITIONS. -0200-HRS WEATHER CONDITIONS BEGAN TO CALM DOWN. CONTACTED IMT AND PERMISSION WAS GIVEN TO CHANGEOUT RIG CREW MEMBERS. -0400-HRS BLOWING SNOW STOPPED. RECEIVED PERMISSION TO PLOW SNOW FROM AROUND CAMP AND RIG. -0600-HRS, PHASE 3 LIFTED ON MAIN ROADS. CONTINUE TO PLOW SNOW AROUND CAMP AND RIG WAITING ON PHASE 2 FOR ALL ROADS AND PADS. PHASE 2, LEVEL THREE CONDITIONS ON ALL ROADS AND PADS. -CONTINUE TO CLEAR OUT SNOW FROM AROUND CAMP AND RIG BEFORE RESUMING OPERATIONS. -WATER AND WASTEWATER TRUCKS ARRIVE AND SERVICE CAMP AND RIG. BRING ALL WELLHEAD EQUIPMENT TO RIG FLOOR. -HOLD PJSM AND PREPARE TO ND BOP STACK. -GATHER ALL NECESSARY TOOLS AND EQUIPMENT IN CELLAR. -DRAIN STACK & BLOW DOWN CHOKE & KILL LINES. ND BOP STACK AND SET BACK ON TRAVELLING PEDESTAL. Printed: 2/10/2010 3:57:42 PM • a BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Spud Date: 1/18/1981 Event Name: WORKOVER Start: 1/29/2010 End: 2/8/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/8/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations. 2/3/2010 11:30 - 12:30 1.00 BOPSU P DECOMP -BLOW THROUGH OA TO ENSURE LINE IS CLEAR 12:30 - 17:30 I 5.001 WHSUR I P 17:30 - 18:00 0.501 WHSUR P 18:00 - 00:00 6.00 WHSUR P 12/4/2010 100:00 - 03:00 I 3.001 WHSUR I P SET AT 99' DECOMP ND TUBING SPOOL. REMOVE TUBING SPOOL AND PACKOFF. 1400-HRS PU ON TUBING ANS SPOOL WITH CABLES. PU TO 10K-LBS. WOULD NOT PULL FREE. 1430-HRS PU PACKOFF PULLING TOOL AND J INTO PACKOFF AND PU SPOOL AND PACKOFF TO 50K-LBS, WOULD NOT PULL FREE. FMC CALL TOWN TO DETERMINE LIMITS AND DECIDE TO STEAM THE CASING SPOOL, BUT KEEP THE MAXIMUM PULL TO 50K-Ibs. 1530-HRS PUT STEAM ON THE PACKOFF AND LET SIT FOR 1-HOUR. 1630-Hrs--P/U TO 90-K-Ibs SEVERAL TIMES AND PACKOFF DOES NOT COME FREE. STEAM FOR ANOTHER HOURS AND TRY P/U TO 90K-Ibs SEVERAL TIMES WITH NO SUCCESS. 1730-Hrs--POH WITH PACKOFF PULLING TOOL TO R/U TO PULL THE TUBING SPOOL WITH THE 4-PART SLING. DECOMP HOLD PJSM WITH FLOORHANDS, TOOLPUSHER, DRILLER, FMC TECHNICIAN, AND WSL TO DISCUSS THE OPERATION OF R/U AND PULLING THE TUBING SPOOL WITH FOUR PART SLING. CHECK ALL COMPONENTS ON THE SLING TO ENSURE THAT SHACKLES AND SLINGS ARE LOAD RATED AND CERTIFIED FOR THE JOB. WE LEARN THAT ONE OF THE SHACKLES HAS THE SAME LOAD RATING BUT DOES NOT HAVE THE SAME EXACT DIMENSIONS AS THE OTHER THREE. LOCATE AND INSTALL THE CORRECT SHACKLE. DECOMP BOLDSs ON THE BOTTOM FLANGE OF THE TUBING SPOOL. INSTALL 4-PART SLING RATED FOR 10K-Ibs PER SLING SECTION. 1500-HRS--PJSM. RU SLINGS AND PU TO 30K-LBS. NO CHANGE. 2000-HRS--PU TO 30K-LBS AND USE HYDRAULIC JACK ON TUBING SPOOL STUDS, JACK UP TO 8K. NOTICED THE SPOOL AND PACKOFF COME UP A LITTLE AND WEIGHT INDICATOR DROP SOME. MOVE JACK IN DIFFERENT PLACES AROUND FLANGE AND SLOWLY RAISE SPOOL UNTIL STUDS ARE INSIDE BOTTOM SPOOL. 2200-HRS--LD SLING AND PU PACKOFF RUNNING TOOL. PU 2K-LBS AND PACKOFF CAME OUT OF SPOOL. LD PACKOFF. RIH WITH PACKOFF RUNNING TOOL AND RILDS ON RUNNING TOOL TO PICK UP SPOOL. USE TUGGER TO ALSO BALANCE SPOOL BY SUPPORTING IA VALVE. WORK PIPE SEVERAL TIMES UP TO 25K THEN SPOOL CAME FREE. 2330-HRS-- LD SPOOL. CLEAN WELLHEAD FOR NEW PACKOFF AND SPOOL. DECOMP LD OLD TUBING SPOOL• , -CLEAN WELLHEAD. INSTALL NEW 9-5/8" MANDREL PACKOFF. Printed: 2/10/2010 3:57:42 PM • BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Spud Date: 1/18/1981 Event Name: WORKOVER Start: 1/29/2010 End: 2/8/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/8/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase' Description of Operations 2/4/2010 00:00 - 03:00 3.00 WHSUR P DECOMP -INSTALL NEW TUBING SPOOL. -FMC TEST PACKOFF TO 5000-PSI FOR 30-MIN. TEST GOOD 03:00 - 05:00 2.00 BOPSU P DECOMP NU BOP AND SET TEST PLUG. TEST BREAK TO 250-PSI 05:00 - 06:30 1.50 DHB P DECOMP 06:30 - 07:30 1.00 CLEAN P DECOMP 07:30 - 10:00 2.50 CLEAN P DECOMP 10:00 - 10:30 0.50 CLEAN P DECOMP LOW AND 3500-PSI HIGH. HOLD AND CHART EACH TEST FOR 5-MIN CHARTED. TEST GOOD -LD TEST JOINT -BLOW DOWN LINES -INSTALL 9"WEAR RING PU STORM PACKER RETRIEVAL TOOL. -RIH TO 99'. -ENGAGE AND RELEASE PACKER. -MONITOR WELL; SEE NO GAS WHEN PACKER WAS RELEASED. -POH AND LD STORM PACKER. INSTALL TIW VALVE. CIRCULATE ACROSS THE TOP WITH HOLE FILL PUMP AND MONITOR TRIP TANK. -LO/TO DRAW-WORKS TO ALLOW RIG ELECTRICIAN TO PERFORM AIR GAP CHECK AND CONTROL CIRCUIT RESISTANCE CHECKS ON DYNAMATIC BREAKING SYSTEM FOR RIG AUDIT REQUIREMENTS. RESUME P/U 4" DP FROM PIPE SHED TO RIH WITH THE 8-1/8" X 4-1/2" DRESS-OFF GUIDE AND 8-1/8" X 4-1/2" GRAPPLE TO DRESS-OFF THE TOP OF THE 4-1/2" TUBING CUT AT 8864' AND TO ENTER AND PULL THE BAKER LOC SEAL ASSEMBLY. THERE IS A PUMP-OUT SUB ABOVE THE BUMPER SUB AND OIL JARS THAT WILL BE UTILIZED TO BULLHEAD SEAWATER INTO THE 2-7/8" LINER. -0945-Hrs--P/U DP JOINT #274 AND M/U TO TOP-DRIVE TO GET PARAMETERS: --PUMP #1--30-SPM AT 120-psi; 40-SPM AT 240-psi. --PUMP #2 HAS SCR PROBLEM. BRING PUMP UP TO 48-SPM (4-BPM), 280-psi. START ROTATING AND BRING UP TO 60-RPM WITH 5-K-ft-Ibs FREE TORQUE. --STOP ROTATING, SLOWLY RIH AND TAG THE STUB AT 8848' D-16 RKB. --1015-Hrs--P/U AND START ROTATING AT 60-RPM, 5-K-ft-Ibs; SLOWLY RIH AND TAG STUB AT 8848', CONTINUE FOR 1' TO DRESS-OFF THE CUT. REDUCE ROTATING TO 20-RPM, 2.5K-ft-Ibs, CONTINUE RIH ANOTHER 2.5' AND THE TOP OF STUB ENTERS THE PACKOFF AND 4-1/2" BASKET GRAPPLES INSIDE THE HOLLOW MILL CONTAINER, CAUSING PRESSURE TO CLIMB TO 900-psi. STOP PUMP, BLEED OFF PRESSURE, AND CONTINUE RIH ANOTHER 3' TO THE NO-GO INSIDE THE HOLLOW MILL CONTAINER. --1020-Hrs--START JARRING ON SEAL ASSEMBLY W ITH FIRST JAR AT 210K-Ibs, THEN P/U TO 225K-Ibs. ---SET BACK DOWN TO 145K-Ibs TO RESET JARS. P/U TO 225K-Ibs, HOLD TO WATCH JARS GO OFF; P/U TO 225K-Ibs WITH NO RELEASE. ---REPEAT JAR RESET AND P/U TO 225K-Ibs TWICE, THEN ~,~Y Printed: 2/10/2010 3:57:42 PM BP EXPLORATION Page 7 of Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Spud Date: 1/18/1981 Event Name: WORKOVER Start: 1/29/2010 End: 2/8/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/8/2010 Rig Name: DOYON 16 Rig Number: 16 Date From.- To Hours Task Code NPT Phase Description of Operations 2/4/2010 10:00 - 10:30 0.50 CLEAN P DECOMP P/U TO 250K-Ibs AFTER SECOND RELEASE AND SEALS COME FREE. P/U ABOVE SEAL ASSEMBLY BORE AND FLUID LEVEL STARTS TO DROP SLOWLY IN IA. --SET BACK DOWN AND VERIFY THAT SEAL ASSEMBLY IS "FISH-ON". 10:30 - 13:00 2.50 CLEAN P DECOMP BREAK OFF DP JOINT #274 TO DROP PUMP-OUT SUB DART; WAIT 15-MINUTES FOR DART TO REACH PUMP-OUT SUB. PRESSURE UP TO OPEN SUB AND GET RETURNS WITHIN 10-STROKES. --1100-Hrs--P/U TO BRING DP JOINT #274 AND #273 ABOVE RIG FLOOR. LINE UP TO PUMP DOWN IA AND TUBING; CLOSE HYDRIL AND BULLHEAD 60-Bbls OF SEAWATER 5-BPM AT 170-psi INTO THE 2-7/8" LINER FROM 8951' TO 11,116'. --1130-Hrs--CBU 6-BPM AT 630-psi WITH A DYNAMIC LOSS RATE OF 72-BPH. --1250-Hrs--DYNAMIC LOSS RATE IS 60-BPH. --1300-Hrs--FINISH CBU. 13:00 - 19:00 6.00 CLEAN P DECOMP GET READY TO POH AND S/B DP, MAKE FIRST STAND BREAK, AND GRABBER ON TOP-DRIVE WON'T FUNCTION. MAKE SEVERAL ATTEMPTS TO SET GRABBER, THEN ROTATE TOP-DRIVE TO BREAK OUT STAND FROM SAVER-SUB, BUT GRABBER WON'T FUNCTION PROPERLY DUE TO BEING EXPOSED TOO LONG ABOVE THE WINDWALLS. --1400-Hrs--HOLD THA WITH DRILLER, FLOORHANDS, TOOLPUSHER, SITE SPOC, AND WSL TO DISCUSS THE OPTIONS FOR BREAKING OUT A SINGLE JOINT. --1415-Hrs--LOSS RATE WITH CONSTANT HOLE-FILL PUMP IS 60-BPH. --1430-Hrs--M/U STAND TO STRING AND TORQUE UP WITH IRON ROUGHNECK. RIH AND PARK SEAL ASSEMBLY AT THE TOP OF THE BAKER LOC SEAL BORE ASSEMBLY. BREAK OUT AND UD JOINT #274. --1450-Hrs--CONTINUE POH AND S/B DP IN DERRICK. --1620-Hrs--STAND #45 S/B IN DERRICK. (91-STANDS OF DP HAD BEEN RIH TO GRAB THE SEAL ASSEMBLY) --1900-Hrs-- POH WITH SEAL ASSEMBLY. -MAINTAIN HOLE FILL WITH 60-BPH LOSS RATE. 19:00 - 21:00 2.00 CLEAN P DECOMP HOLD PJSM ON PUNCHING TUBING TO RELEASE ANY TRAPPED GAS. -RU EQUIPMENT TO PUNCH TUBING. - PUNCH ABOVE AND BELOW CUT JOINT CONNECTION. TUBING FILLED WITH SAND. CLEAN OUT SLUG-ITS AND lD JOINT. -IN THE 6' PUP JOINT ABOVE THE SEAL ASSEMBLY COULD SEE THE IBP JUST BELOW WHERE THE TUBING WAS PUNCHED. ABOVE THE IBP THE PIPE WAS FILLED WITH SAND. CLEANED OUT SLUG-ITS. -UNABLE TO BREAK APART THE GRAPPLE AND TUBING, LD BOTH TOGETHER. -CUT JOINT WAS 29.40', PUP JOINT WITH NO GO SUB 7.10', MULE SHOE AND SEAL ASSEMBLY 13.63' OD = Printed: 2/10/2010 3:57:42 PM • BP EXPLORATION Page 8 of 11 Operations Surnrnary Report Legal Well Name: 16-08 Common Well Name: 16-08 Spud Date: 1/18/1981 Event Name: WORKOVER Start: 1/29/2010 End: 2/8/2010 Contractor Name: DOYON DRILLING INC. Rig Release: 2/8/2010 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 2/4/2010 19:00 - 21:00 2.00 CLEAN P DECOMP 4.687. -4.75" PBR AT 8884' MD 21:00 - 23:00 2.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. -CHANGE OUT GRABBER DIES ON TOP DRIVE AND INSPECT TOP DRIVE. -GATHER BHA FOR MULE SHOE AND SCRAPER ASSEMBLY 23:00 - 00:00 1.00 CLEAN P DECOMP PU AND MU BHA WITH 4.5" TUBING W/MULE SHOE, 9-5/8" SCRAPER, 2-EA 7" BOOT BASKETS -CONTINUE TO MAINTAIN HOLE FILL WITH 60-BPH LOSS RATE. 2/5/2010 00:00 - 00:30 0.50 CLEAN P DECOMP FINISH MU BHA CONSISTING OF 4.5" TUBING W/MULE SHOE, 9-5/8" SCRAPER, 2-EA 7" BOOT BASKETS 00:30 - 04:00 3.50 CLEAN P DECOMP RIH WITH MULE SHOE AND RAPER 7 ' SCRAPE FROM 8750' TO 8850'. MAKE AT LEAST 4 PASSES ACROSS THE AREA. -PU = 165K-LBS SO = 155K-LBS. CIRC AT 3.3-BPM WITH 150-PSI -CONTINUE TO RIH TO ENSURE THE MULE SHOE GOES INTO THE 4.75" ID RECEPTACLE AND NO GO ~ 8884'. -MAINTAIN CONSTANT HOLE FILL WITH 60-BPH LOSS RATE. 04:00 - 05:00 1.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP -8-BPM WITH 1010-PSI PUMP PRESSURE. -0430--Hrs--PJSM FOR POOH LD DP. -0450--Hrs--FLOW CHECK. NO FLOW. -0500--Hrs--PUMP 10-BBL SLUG. 05:00 - 14:00 9.00 CLEAN P DECOMP POH UD DP FROM 8884' TO SURFACE (280-Jts WERE UTILIZED FOR THIS RUN). LOAD, RABBIT, AND STRAP 4-1/2", 12.6#, 13Cr80 (Cond B) AND 13Cr85 (NEW) TUBING IN PIPE SHED, 1/2 LAYER AT A TIME. SHUT DOWN POH AND UD DP WHENEVER 1/2 LAYER NEEDS TO BE ROLLED TOWARD THE PIPE SKATE. --1015-Hrs--DP JOINT #160 UD. CURRENT DYNAMIC LOSS RATE USING CONSTANT HOLE FILL WHILE POH IS 36-BPH. --1145-Hrs--DP Jt #211 UD. --1235-Hrs--DP Jt #240 UD. DYNAMIC LOSS RATE IS 38-BPH. 14:00 - 16:30 2.50 CLEAN P DECOMP DRILLER HOLDS THA REVIEW FOR BREAKING OUT AND LAYING DOWN THE 9-5/8" SCRAPER BHA. EMPTY BOOT BASKETS AND GET 1/2 GALLON OF SCALE AND SANDY DEBRIS. UD 1/2-MULESHOE AND DO NOT SEE ANY DAMAGE OTHER THAN MINIMAL SCRATCHES ON THE SIDE OF THE MOUTH OF THE MULESHOE. --1500-Hrs--P/U THE GRAPPLE BHA TO REMOVE THE SEAL ASSEMBLY. FIND ANOTHER CORROSION HOLE IN THE FISH 9' BELOW THE CUT. LENGTH OF CUT JOINT IS 29.76'. 16:30 - 17:30 1.00 CLEAN P DECOMP PULL WEAR RING -BRING HANGER TO RIG FLOOR -REMOVE ELEVATORS AND SHORT BAILS. 17:30 - 00:00 6.50 BUNCO P RUNCMP CONTINUE TO LOAD, STRAP, AND DRIFT 4.5" TUBING Printed: 2/10/2010 3:57:42 PM • BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT Spud Date: 1 /18/1981 Start: 1 /29/2010 End: 2/8/2010 Rig Release: 2/8/2010 Rig Number: 16 Phase Description of°Operations 12/5/2010 ~ 17:30 - 00:00 ~ 6.50 12/6/2010 ~ 00:00 - 02:30 ~ 2.50 02:30 - 03:30 1.00 RUN 03:30 - 20:00 ~ 16.50 20:00 - 22:00 2.00 RUNCMP PJSM FOR RU TORQUE TURN AND COMPLETION EQUIPMENT. -RU 4.5" COMPLETION RUNNING EQUIPMENT. -CHECK ALL 4.5" COMPLETION JEWELRY FOR CORRECT DIMENTIONAL DATA -MAINTAIN HOLE FILL WITH 50-BPH LOSS RATE. RUNCMP CONTINUE TO LOAD, DRIFT, AND STRAP 4.5" TUBING. -RU TIW VALVE TO VAM TOP XO RUNCMP PJSM ON RUNNING TUBING, DISCUSS RUNNING ORDER WITH RIG CREW, DOYON CASING, HALLIBURTON, TOOL PUSHER, WSL. -FINISH RU TORQUE TOOLS. RUNCMP RUN 4-1/2", 12.6#, 13CR80 AND 13CR85 TUBING -MU ALL CONNECTIONS TO OPTIMUM TORQUE 4,440-LB-FT -BAKERLOK ALL CONNECTION BELOW PACKER. -USE JET LURE SEAL GUARD PIPE DOPE ON ALl CONNECTIONS ABOVE PACKER. -USE DOG COLLAR FOR THE FIRST 10-JOINTS OF TUBING RUNNING IN HOLE UNTIL SUFFICIENT WEIGHT HAS BEEN GAINED IN THE STRING. -MAINTAIN HOLE FILL WITH 50-BPH LOSS RATE. --0630-Hrs--TUBING JOINT #31 RIH. --0715-Hrs--#47 RIH; 0815-Hrs--#61 RIH; --0845-Hrs--DRILLER NOTICED THAT A HYDRAULIC FITTING WAS LEAKING ON IRON ROUGHNECK, ALTHOUGH IRON ROUGHNECK WAS NOT IN USE FOR THE CURRENT OPERATION. REPAIRED THE LEAK ON THE HOSE CONNECTION. --0915-Hrs--WITH TBG JOINT #71, RESUME RIH WITH NEW COMPLETION. --1130-Hrs--Jt #101 RIH; --1300-Hrs--Jt #120 RIH; --1615-Hrs--Jt #159 RIH; --1640-Hrs--Jt #164 RIH, WHICH IS THE LAST OF THE 'B' CONDITION 4-1/2", 12.6#, 13Cr80, VAM TOP JOINTS; SUBSEQUENT JOINTS ARE ALL NEW 4-1/2", 12.6#, 13Cr85, VAM TOP. --1700-Hrs--Jt #169 RIH; 50-BPH AVERAGE LOSS RATE WHILE RIH. -RIH AND TAG NO ~O .O AR ON TOP OF THE MULESHOE PUP JOINT, PLACING THE BOTTOM OF THE MULESHOE AT 8900.75', AND THE TOP OF THE SBR AT 8890', DOYON 16 RKB. -CALCULATE SPACE OUT PUPS NEEDED. -WHEN LANDED, THE TUBING MULE SHOE WILL BE AT -8896', NO GO COLLAR WILL BE -4.27' OUT OF SBR, WITH 5.53' INSIDE. -PU = 145K-LBS, SO = 135K-LBS RUNCMP RD TORQUE TURN EQUIPMENT. --2030-Hrs---MU HANGER AND LANDING JOINT. --2130-Hrs-- LAND HANGER AND FMC RILDS. Printed: 2/10/2070 3:57:42 PM ' ~ • BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: 16-08 Common Well Name: 16-08 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 2/6/2010 20:00 - 22:00 2.00 BUNCO 22:00 - 00:00 2.00 BUNCO 2/7/2010 00:00 - 02:30 2.50 BUNCO 02:30 - 04:30 2.00 BUNCO 04:30 - 07:00 2.50 WHSUR P RUNCMP 07:00 - 08:30 1.50 BOPSU P RUNCMP 08:30 - 10:30 2.00 WHSUR P RUNCMP 10:30 - 15:00 4.50 WHSUR P RUNCMP 15:00 - 18:00 3.00 WHSUR P RUNCMP Spud Date: 1 /18/1981 Start: 1 /29/2010 End: 2/8/2010 Rig Release: 2/8/2010 Rig Number: 16 Phase Description of Operations RUNCMP -RU CIRCULATING LINES TO REVERSE CIRC THROUGH IA. RUNCMP PJSM WITH CH2MHILL, RIG CREW, TOOL PUSHER, HALLIBURTON, WSL. -PUMP AT 3-BPM WITH 60-PSI PUMP PRESSURE. -REVERSE CIRCULATE 150-BBL OF 120-DEGREE SEAWATER. -FOLLOW WITH 480-BBL OF 120-DEGREE SEAWATER WITH CORROSION INHIBITOR. RUNCMP CONTINUE REVERSE CIRCULATING 480-BBL OF 120-DEGREE SEAWATER WITH CORROSION INHIBITOR. -PUMP AT 3-BPM WITH 60-PSI PUMP PRESSURE RUNCMP --0235-Hrs--DROP BALL N' ROD . --0240-Hrs--CHASE DOWN AT 1-BPM WITH 3.2-BBL OF SEAWATER DOWN THE TUBING. --0243-Hrs--BALL N' ROD ON SEAT, INCREASE TUBING PRESSURE TO 3500-PSI AND HOLD FOR 30-MIN CHARTED. TEST GOOD. --0316-Hrs--BLEED OFF PRESSURE TO 1500-PSI AND. LEAVE ON TUBING. --0336-Hrs-- LINE UP TO PRESSURE UP ON THE IA AND PRESSURE UP TO 3500-PSI AND HOLD FOR 30-MIN CHARTED. TEST GOOD. --0408-Hrs--BLEED OFF TUBING AND WITNESS DCR VALVE SHEAR. -PUMP DOWN TUBING AND THEN SWITCH TO IA TO VERIFY ABLE TO CIRCULATE. LD LANDING JOINT -FMC SET TWC IN TUBING HANGER. -TEST TWC TO 3500-PSI FROM ABOVE FOR 10-MIN AND TEST FROM BELOW TO 1000-PSI FOR 10-MIN CHARTED. PJSM TO N/D BOP STACK. N/D BOP STACK AND SET BACK ON STUMP. PJSM. N/U ADAPTOR SPOOL AND TREE. TEST ADAPTOR SPOOL TO 5000-psi FOR SOLID TEST FOR 30-MINUTES. PJSM TO TEST TREE TO 5000-psi. FILL TREE WITH DIESEL AND WORK VALVES TO ENSURE DIESEL IN VALVES. --1130-Hrs--MAKE CREW CHANGE. --PJSM WITH DAY CREW. RESUME 5000-psi TEST. FIND LEAK IN TEST PUMP POP-OFF. R/U ADDITIONAL TEST TEE TO TAKE TEST PUMP AND POP-OFF OUT OF THE SYSTEM AFTER PRESSURING UP. --1400-Hrs--MAKE SEVERAL ATTEMPTS TO BUMP UP PRESSURE, BUT LEAK OFF RATE IS 100-psi PER 5-MINUTES WITHOUT LEVELING OUT. -FIND NO VISIBLE LEAKS ANYWHERE ON THE TREE. NO PRESSURE IN THE IA OR OA DURING ANY OF THE TESTS.DECIDE TO CHANGE THE TWC. P/U DSM LUBRICATOR AND M/U TO THE TOP OF THE TREE AND TEST TO 500-psi. DSM TECHNICIANS PULL TWC AND REPLACE WITH THEIR SPARE. FIND NO PRESSURE UNDER THE TWC. --1645-Hrs--FILL TREE WITH DIESEL TO TEST FROM THE Printed: 2/10/2010 3:57:42 PM .~ ~ • BP EXPLORATION Page 11-of 11 Qperations Sumrnary Report Legal Well Name: 16-08 Common Well Name: 16-08 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours. Task Code NPT 2/7/2010 15:00 - 18:00 3.00 WHSUR P 18:00 - 18:30 0.50 WHSUR P 18:30 - 19:30 1.00 WHSUR P 19:30 - 21:00 1.50 WHSUR P 21:00 - 00:00 3.00 WHSUR P 2/8/2010 00:00 - 06:00 6.00 WHSUR P Spud Date: 1 /18/1981 Start: 1 /29/2010 End: 2/8/2010 Rig Release: 2/8/2010 Rig Number: 16 Phase Description of Operations RUNCMP TOP. --1715-Hrs--REPLACE PRESSURE SENSOR HEAD. --1745-Hrs--RESTART TEST AND GET A STEADY, PARALLEL LINE AT 5000-psi. RUNCMP RD TEST EQUIPMENT -RU DSM LUBRICATOR AND PULL TWC. RUNCMP RU CIRCULATING LINES TO TAKE RETURNS FROM TOP OF TREE. -PJSM AND RU LITTLE RED. -PRESSURE TEST LINES TO 3500-PSI RUNCMP REVERSE CIRCULATE 145-BBLS OF DIESEL THROUGH THE IA. -CIRCULATE AT 2-BPM WITH 250-PSI. RUNCMP WAIT 1-HR TO ALLOW FOR DIESEL TO U-TUBE INTO THE TUBING. --2215-Hrs BLED BEGAN TO BLEED DOWN LINES AND PRESSURE OFF WELL. -HAD 50-PSI ON TUBING. ATTEMPTED TO BLEED FOR 5-MIN WITH NO SIGN OF FLOW DECREASING. APPROXIMATELY 5-BBL DIESEL BACK. --2230-Hrs ALLOWED DIESEL TO CONTINUE TO U-TUBE. --2315-Hrs. TUBING AND IA HAD 50-PSI. BLEED OFF PRESSURE AND SHUT IN AT 30-PSI. PRESSURE SLOWLY INCREASED TO 45-PSI. --2330-Hrs SEPARATE THE TUBING FROM IA LINES AND ATTEMPT TO BLEED, WOULD NOT GO BELOW 30-PSI. SHUT IN. PLAN TO SET BPV AND TEST FROM BELOW. RUNCMP PJSM FOR RU DSM LUBRICATOR AND SET BPV. --0030-Hrs PU LUBRICATOR. RIH WITH BPV. --0100-Hrs UNABLE TO GO UP WITH LUBRICATOR. TROUBLESHOOT LUBRICATOR AND CHANGE OUT HYDRAULIC HOSE FITTINGS. --0230-Hrs UNABLE TO SCREW IN BPV. MAKE SEVERAL ATTEMPTS. PULL BPV AND INSPECT THREADS. GOOD THREADS. --0320-Hrs CHANGE OUT BPV. STILL HARD TO GET SCREWED IN. MAKE SEVERAL ATTEMPTS UNTIL BPV SET IN PROFILE. W w --0400-Hrs RD LUBRICATOR AND RU TREE CAP AND HOSE LINES TO PRESSURE TEST BPV. --0430-Hrs PRESSURE TEST BELOW BPV TO 1000-PSI FOR 5-MIN CHARTED. TEST GOOD --0500-Hrs RD TEST EQUIPMENT. BLOW DOWN LINES. --0600-Hrs RELEASE RIG AND PREPARE TO MOVE TO 16-01 i. Printed: 2/10/2010 3:57:42 PM TREE _ • FMC WELLHEAD - FMC ACT ATOR= AXELSON KB. ELEV..- 70' BF. ELEV.- KOP = 5350' Max Angle = 102 @ 9953' Datum MD = 9307 Datum TV D = 8800' SS 13-3/8" CSG 72#, L-80, ID =12.347" # 16-08A r4S-Burt 2-7-21~7~ FETY NOTES: WELL ANGLE> 70 DEG 9560' & > 90 DEG @ 9610'. 2022' HES X-NIPPLE, 4-1/2", 9Cr, 3.813" Pkg Bore GAS LIFT MANDRELS I 2717' I Minimum ID = 2.387" @ 8954' 3-1 /2" F L4S X 2-7/8" F L4S XO "Tubi n9 ~,b ~-~- ~L{< 4-1/2", 12.6#, 13cR80, Vam Top .0152 bpf, ID = 3.95 $$$7' Collar used for No-Go to Tag Top of SBR 4-1/2", 12.6#, 13Cr80, 3.958" ID--Muleshoed as WLE $$9$' 3-1/2" FL4S X 2-7/8" FL4S XO, ID = 2.387" i-~ $954' TOP OF 7" LNR I~ 8982` ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3492 410SS DCR RK 02/06/10 2 5520 410SS DGLV RK 02/06/10 3 6740 410SS DGLV RK 02/06/10 4 7786 410SS DGLV RK 02/06/10 5 8666 410SS DGLV RKP 02/06/10 8746' HES X-NIPPLE, 4-1/2", 9Cr, 3.813" Pkg Bore 8777' HES TNT Pkr, 9-5/8" x 4-1/2", 3.903" ID $$18' HES X-NIPPLE, 4-1/2", 9Cr, 3.813" Pkg Bore $$$5' HES X-NIPPLE, 4-1/2", 9Cr, 3.813" Pkg Bore $890` Top Baler SBR, 4.750" ID Dayon 16 RKB 02 9-5/8" X 4-1/2" BKR SB-3A PKR, ID = 4.750" 8951' 3-3/4" BKR DEPLOY SLV, ID = 3.00" 14-1/2" OTIS XN NIP, ID = 3.80" (BEHIND LNR) I 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" I-i 9015' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-i 9297' PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL of 03/01/00 ANGLE AT TOP PERF: 95 @ 9830' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9840 - 10170 C 03/03/00 2" 4 10552 - 10821 C 03/03/00 9016' ~4-1/2" WLEG (BEHIND LNR) 9000' ELMD TT LOGGED 12/13/91 7" LNR MILLOUT WINDOW 9423' - 9431' (OFF WHIPSTOCK ) TOP OF WHIPSTOCK @ 9425' \ RA TAG @ 9435' A PBTD 7" LNR, 29#, L-80, ID = 6.184" ~ 9423' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.387" 11145' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/11/81 ORIGINAL COMPLETION 01/15/07 TEL/PAG SET BKR IBP @ 8892' 03/14/91 RWO 07/21/07 SWGPJC GLV GO (07/11/07) 02/23/00 CTD SIDETRACK 10/04/09 RLM/SV GLV GO (09/10/09) 10/20/01 CH/KAK CORRECTIONS 10/04/09 JCM/SV TBG/GLV CORRECTIONS 08/15/06 TEL/TLH GLV GO 02/07/10 MR/JD 4.5" TBG SWAP 08/25/06 KSB/PA GLV GO PRUDHOE BAY UNff WELL: 16-08A PERMfT No: 199-1260 API No: 50-029-20549-01 2238' FNL & 4623' FEL, Sec. 24, T10N, R15E BP Exploration (Alaska) Schlumberger NO. 4290 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 Z007 Commission Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1¥J -l{)(o Field: Prudhoe Bay WI! CI CD J b L D D t 8L e o # og escrlptlon ae oor L5-23 11733320 PRODUCTION PROFILE 04/30/07 1 W-38A 11660532 MEM PROD PROFILE 05/02/07 1 Z-38 11660534 MEM PROD PROFILE 05/05/07 1 17-22 11745213 LDL 04/29/07 1 W-19A 11628772 MEM PROD PROFILE 05/07/07 1 Y-24 11630477 LDL 05/08/07 1 16-08A 11686747 LDL 05/20/07 1 G-05 11773110 LDL 05/13/07 1 16-03 11686743 LDL 05/11/07 1 14-07 11637334 PRODUCTION PROFILE 05/08/07 1 V-03 11628770 MEM LDL 04/30/07 1 MPF-91 11628759 MEM TEMP SURVEY 03/09/07 1 MPF-89 11628758 MEM TEMP SURVEY 03/08/07 1 MPS-10A 11638630 INJECTION PROFILE 05/07/07 1 8-34 11594500 INJECTION PROFILE 05/22/07 1 04-10 11594498 LDL 05/19/07 1 8-07 11657125 PRODUCTION PROFILE 05/11/07 1 H-24 11745216 PPROF/GLS 05/02/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 C-28A NIA LDL 05/09/07 1 M-07 11630476 LDL 05/07/07 1 P1-14 11745214 INJECTION PROFILE 04/30/07 1 P1-16 11594494 INJECTION PROFILE 05/01/07 1 PLEASE ACKNOWLEDGE RECEIPT 8Y SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: ~ ---- SCANNED JUN 2 1 Z007 Date Delivered: ()ßJ 06/07/07 . . DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Permit to DrilINo. 1991260 Well Name/No. PRUDHOE BAY UNIT 16-08A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20549-01-00 MD 11148 TVD 9089 Completion Date 3/3/2000 -~ Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N__9_o Samples No Directional Survey No -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format N a,,r~me ~ STAT BHP (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Dataset Scale Media No Start Stop CH Received Number Comments 5 FINAL 8850 9574 CH 8/4/2000 DOW SRVY CALC GR/EWR4-TVD ,,,L-/'' PDC/GR/CCL ,...L'"' ~/ICNL °~//DGR/EWR4-MD d~'~RVY LSTNG ~ SRVY RPT 25 FINAL 2 FINAL 2 FINAL 25 FINAL 9300 11148 OH 3/21/2000 8907 9018 OH 7/13/2000 8766 11107 CH 5/31/2000 9557 11106 CH 5/31/2000 9425 11147 OH 7/13/2000 9300 11148 OH 3/17/2000 O 7/13/2000 9300 11147 OH 312112000 C 5/31 ~2000 C 5/31 ~2000 BH. BH. 09574""' 9419-11099 SPERRY . 09609 9556-11096 09611 8778-11110 Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis Received? Daily History Received? (~/N Formation Tops Receuived? ~N Comments: Permit to Drill No. 1991260 DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. PRUDHOE BAY UNIT 16-08A Operator BP EXPLORATION (ALASKA) INC MD 11148 TVD 9089 Completion Date 3/3/2000 Completion Status 1-OIL Current Stares AP1 No. 50-029-20549-01-00 1-OIL UIC N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ REVISED PERF DEPTHS Pull tubing _ Alter casing _ Repair well _ Other_ Revised Perf Depths 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 70 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2238' FNL, 4623' FEL, Sec. 24, T10N, R15E, UM (asp's 719457, 5928693) 16-08A At top of productive interval 9. Permit number / approval number 4063' FNL, 4118' FEL, Sec. 24, T10N, R15E, UM (asp's 720017, 5926886) 199-126 At effective depth 10. APl number 356' FNL, 4243' FEL, Sec. 25, T10N, R15E, UM (asp's 719938, 5925311) 50-029-20549-01 At total depth 11. Field / Pool 386' FNL, 4245' FEL, Sec. 25, T10N, R15E, UM (asp's 719937, 5925280) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11148 feet Plugs (measured) true vertical 9089 feet Effective depth: measured 11116 feet Junk (measured) true vertical 9080 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 348 sx AS II 142' 142' Surface 2685' 13-3/8" 2850 sx Fondu, 400 sx PF 2717' 2717' Production 9265' 9-5/8" 500 sx Class 'G' 9297' 8861' Liner 441' 7" 350 sx Class 'G' 8982' - 9423' 8575' - 8975' Sidetrack Liner 2194' 2-7/8" 124 c.f. Class 'G' 8951' - 11145' 8547' - 9088' Perforation depth: measured Open Perfs 9840' - 10170', 10552' - 10821' true vertical Open Perfs 9056'- 9005', 9019'- 9044' ~. -: ~i~ = .~ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 8901'. 4-1/2" Tubing Tail @ 9000'. ,..~.:.!.' ~ ?. i!!i!- Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Baker SB-3A Packer @ 8901'. , ~. ~ ,,~ :)i~ '(,,~:¥:.' ~.~iii% ~:~:/,;~;¥~i~:J0i~ 4-1/2" AVA SC TRSSSV @ 2212'. ~, ¥ :i~,~i-?!q(~ 13. Stimulation or cement squeeze summary Intervals treated (measu red) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 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. ~~'~i,.~.~~~~ Title: Technical Assistant Date October 24, 2001 DeWayne R. Schnorr Prepared by DeWayne Fi. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE I O/24/2OO 1 10/24/01 16-08A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS REVISION OF PERFORATIONS DEPTHS EVENT SUMMARY THE INITIAL PERFORATIONS ON WELL 16-08A HAVE BEEN REVISED TO FIT THE CORRECT DEPTHS OF THE WELL. WHEN THE WELL WAS INITIALLY PERFORATED, THE END OF THE WELL WAS USED AS THE DEPTH CONTROL FOR THIS WELL. INITIAL PERFORATION DEPTHS 9830' - 10160' 10550' - 10818' REVISED PERFORATION DEPTHS 9840' - 10170' 10552' - 10821' Page 1 TREE = FMC ~ ~ WB_LHEAD = FMC SAFETY NOTES: WFIL ANGLE> 70 DEG / V VV~ KB. ELEV = 70' BF. ELEV = KOP = 5350' ' DatumMD= 9307' I 2212' 4-1/2"AVA SCTRSSSV, ID= :3.812' Datum'l'VD = 8800' SS GAS LIFT MANDRELS ST IVE) TVD DEV TYPE VLV LATCH PORT DATE 1 2991 2990 1 FMHC DorvE I:~ 16 03/09/00 k 3 6191 6148 24 FMHC DV RK 0 03/14,/91 4 7199 7008 32 FMHC DOME RK 20 03/09/00 L 5 7659 7399 31 FMHC DV RK 0 03/14/91 ~ Minimum ID: 2.387" @ 8954' 6 8002 7697 29 FMHC DV RK 0 03/14/91 3-1/2" FL4S X 2-7/8" FL4S XO 7 8346 8002 27 FMHC DV RK 0 03/14/91 8 8689 8311 26 FMHC S/O RK 28 03/10/00 CHEMICAL MANDRELS o · 8796 8407 26 MMG DV 0io3/14/911 r 8001' H O'51B"X4'll2"BKRSB-3AF~R'ID=4'750"I I I' 80S1' I~ 3-3/4"e~RD~'LOYUENTSLV,~D=3.00"I 13-1r2" ~4s x 2-7/8" FL4S XO, D = 2.387" I---~ 8054' [ I I I i II ~003' I'-~ 4'I/2"OTISXNNP'ID=3'80"(BEHINDLNR) I I 14-112"~,12.6#,L-80,.0152~p*,,D=3.958" H ~01S' , ~ ,' ~01~. i__~ 4'I~2"WLr~¢E~NDL~R>I I *000' I--i ~-mrr LO~GED12~13~l I I 7" LNR MI_LOUT WINDOW ! PERFORATION SUMMARY 9423'- 9431'( OFF WHPSTOCK ) , , REF LOG: SWS MBVIORY GR/CCL of 03/01/00 ~ TOP OF WHIPSTOCK @ 9425' ii ANGLEATTOP PERF: 95 @ 9830';I RA TAG @ 9435' Note: Refer to Production DB for historical perf data ' SIZE SPF INTERVAL Opn/Sqz! DATE i !2"4 9840-10170 O 03/03/00 I ~ 2" 4 10552. 10821 O .03/03/00 ~ ~ 11116' I I 7" LNR, 29#, L-80, ID = 6.184" I~ 9423' I I I 2-7/8"LNR, 6.16~, L-80, .00579 bpf, 19=2.387" H 11145" I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/11/81 ORIGINAL COIVPLETION 10/20/01 CH/KAK ICORRECTIONS WELL: 16-08A 03/14/91 RWO i PERMIT No: 199-1260 02/23/00 CTDSIDETRACK . APl No: 50-029-20549-01 01/03/01 SIS-OAA CONVERTED TO CANVAS i 2238' FNL & 4623' FEL, Sec. 24, T1 ON, R15E 02/21/01 SIS-LG REVISION BP Exploration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 9840 - 10170 O 03/03/00 2" 4 10552 - 10821 O 03/03/00 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/11/81 ORIGINAL COrvPLETION 10/20/01 CH/KA K I CORRECTIONS 03/14/91 RVVO 02/23/00 CTD SIDETRACK 01/03/01 SIS-QAA CONVERTED TO CANVAS 02/21/01 SIS-LG REVISION MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. i. Supervisor DATE: May 1, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field DS-16 May 1,~20,01; I traveled to BP's Prudhoe Bay Field to witness the semi-annual SVS tests on DS-161 I witnessed SVS tests on BP's DS-16. Testing went very well. No failures were witnessed. We had more than adequate manpower to test this Pad in a timely manner. Flow 2 Supervisor Roy Wells checked in w! the Pad Operators & Leads on DS-16 that were performing tests to make sure operations were being performed, inca safe & efficient manner. Preventive maintenance had been performed on SVS for this Pad two weeks before State testin~l was conducted. ~ SUMM.,A.,R .Y.: I witnessed SVS tests on BP's PBU DS-16. 20 we!Is' 40 components, tested. Nq..fail.ure. s,witnesse.d,, 0% fpilu,re rate. Attachments: SVS PBU DS-16 5-01-01jc cc; NON-C. ONF!,D, ENTIAL SVS PBU DS- 16 5-01-0 lj¢ Aia~..a Oil and Gas Conservation Commi, ,n Safety Valve System Test Report Operator: BPX Operator Rep: W. Williams AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Pmdhoe Bay Field DS-16 Separator psi: LPS 171 HPS 5/1/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI TAp Code Code Code Passed GAS or CYCLE 16-0i 1801360 16-02 1801500 16-03 1810110 16-64A 1921510 'i7i '15'0! ''110 P e 'oIL 16-05 18i037~ 171 '150! 125 P '" P OIL 16206 1810510 ' 16-07 1852040 16-08A' ~"1991260 171 '1501 ~120 P 'P ' OIL 16-09A 1910380 171 1501 120 P P OIL 16-10A 1991'230 .... 16-11 1801180 16-12A 1990190 171 150 120 P P OIL 16-13 18'~0270 171 150 "140 P P " OIL~ , , , , ,, ,, , 16-14A 1980360 3000 1800! 1800 P P GINJ 16-15 1852640 171 150! 1120 P P OIL! 16-16 1801270 ....... i !16-17 1852200 171 150! 125 P P OIL 16-18 1852430 171 1501 100 P P " oIL 16-19 1852650 171 '150 120 P P OIL 16-20 1852850 171 1'50 "110 .... P" ~ '' '0i~' ,, , ~16-21 1853120 171 150 90 P P ' OIL 16-22 '1900510 '"171' 150 120 P P '' OIL 16-23 1900620 ...... 16-24 1860240 16-25 1920510 171 150 90 e P OIL i6-26A' 1991270 17i 150 120 e P .... OIL 16-27A ' 2000040 1~1 150 110 e P. OIL 16-28 1920620 171 150 115 P P '' oIL 16-29A 1920660 ..... 171 150 120 P P " oil 16'30 1920760 "~i 150 120 '"P P " OIL - ,, 16-31 1920750 ,,,, Wells: 20 Components: 40 Failures: 0 Failure Rate: 0.00% 1-190 my Remarks: RJF 1/16/01 p,..~ 1 r~q9 .q,xzq pItTI nq_l~q q_nl_nlj,.1 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI ,PSI ,,T,rip Code Code Code ,,, Passed , ,GAS or, ,CY,C,,LE RJF 1/16/01 Page 2 of 2 SVS PBU DS-16 5-01-01jcl Schlmberger NO. 360 7/26/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'n'N: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 1-20 LEAK DETECTION LOG 000701 I 1 D.S. 3-02 STATIC B.H. PRESSURE LOG 000704 I 1 D.S. 3-03 STATIC B.H. PRESSURE LOG 000704 I 1 D.S. 7-06A LEAK DETECTION LOG 000702 I 1 D.S. 16-08A STATIC B.H. PRESSURE LOG 000703 I 1 D.S. 16-12A STATIC B.H. PRESSURE LOG 000704 I 1 D.S. 16-27A STATIC B.H. PRESSURE LOG 000703 I I , --, RECEIVED SIGNED: DATE: AIJG 04 2000 Alaska 0il & Gas bu,';~ ~mmissi0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~k~age EIRILLINB c; E Ri/I r' E c; WELL LOG TRANSMITTAL To.- State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 16-08A, ~qq' AK-MW-90247 July 13, 2000 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention ot2 /ran Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20549-01. E C E I VE D JUL 1 3 ~000 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company sper r, -sun CIRI LLI IM I~ C;ERL/I C E c; WELL LOG TRANSMITTAL To: State of Alaska July 13, 2000 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 \C~' \9-4 RE: MWD Formation Evaluation Logs: D.S. 16-08A, AK-MW-90247 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Gal~Sn, Sperry-Sun Ddllhng Ser~Sces, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 16-08A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50~029-20549-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20549-01 1 Blueline 1 Folded-Sepia 1 Blueline 1 Folded Sepia R£C JUL 1 3 2000 Alaska OiI & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company Schhlmberg NO. 179 5/23/0O Schlumberger Technology CorPoration, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 2-17A it ¢ibl~ 20070 MCNL 000126 I I 1 D.S. 16-08A~o4~LI 20109 MGR/CCL PERF DEPTH CONTROL (PDC) 000301 I I 1 D.S. 16-27A~ Io 20108 MGR/CCL (PDC) 000226 I I 1 D.S. 16-08A~d= 20107 MCNL 000221 I I I MAY 5 1 2000 DATE: Alaska 0ii & Gas Con~. Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 17-Mar-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 16-08A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 9,300.00' MD 9,425.00' MD 11,147.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. ~ RECEIVED MAR 2 1 2000 Kenneth W. Allen Survey Manager Alaska 0il & Gas C0r]s. Anchorage Attachment(s) STATE OF ALASKA ALASK/-~ OIL AND GAS CONSERVATION COMMI,.,,..ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~] Gas ri Suspended D Abandoned D Service D 2. Name of Operator ~~' 7. Permit Number ARCO Alaska, Inc. ~ 199-126 3. Address 1~1~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~'B.--~.'~,~ 50-029-20549-01 4. Location of well at surface ' ' ' --. .... 9. Unit or Lease Name 2238' FNL, 4623' FEL, Sec. 24, T10N, R15E, UM (asp's 719457, 5928693) / .... : :.! '~ Prudhoe Bay Unit At Top Producing Interval ! ~,~.~' 10. Well Number 4063' FNL, 4118' FEL, SEC 24, T10N, R15E, UM (asp's 720017, 5926886) 16-08A AtTotal Depth !..~!..~ ll. FieldandPool 386' FNL, 4245' FEL, SEC 25, T10N, R15E, UM (asp's 719937, 5925280) ...... . . Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 70 feetI ADL 28333 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions February 6, 2000 February 19, 2000 March 3, 2000I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11148' MD/9089' TVD 11112' MD/9079' TVD YES r~ No E]I 2212' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD/GR & Memory CNL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP DO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 94.0# H-40 Surface 110' 32" 348 Sx AS II 13-3/8" 72.0# L-80 Surface 2717' 17-1/2" 2850 Sx Fondu & 400 Sx PF II 9-5/8" 47.0# L-80/S00-95 Surface 9297' 12-1/4" 500 Sx Class G 7" 29.0# L-80 8982' 9423' 8-1/2" 350 Sx Class G 2-7/8" 6.40# L-80 8951' 11145' 3-3/4" 22 bbls 15.8 ppg Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING REC'O-F~- interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9016' 8901' 9830' - 10160' MD; 9057' - 9006' TVD; @ 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10550' - 10818' MD; 9019' - 9044' TVD; @ 4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 1... 27. PRODUCTION TEST~..~' Date First Production Method of Operation (Flowing, gas lift, etc.) t J March 13, 2000 Gas Lift Date of Test Hours Tested Production for OIL-BBL GAS-MCF !WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/14/2000 4.1 Test Period >I 378 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. -310 psi 24-Hour Rate > 3550 1340 690 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved December 28, 1999 (Permit #199-126) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ' 30. ' ~" GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Shublik 9340' 8900' Top o! Sadlerochit (Zone 4) 9418' 8971' 31. LIST OF A~ACHMENTS ,~]O;i0J'~'[~3 Summa~ of 16-08A CT Sidetrack Drilling Operations + Suwey. 32. I hereby ced~ that the following is tree and coffect to the best of my knowledge. Signed ~ Title ~lCoilTubin~Drillin~Supe~isor Date /~"~' ~~ Bruce E. Sm~h, P.E. INSTRUCTIONS Prepared by Paul Rauf 263-4990. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 16-08A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 2/06/2000: 2/07/2000: 2/13/2000: 2/14/2000: 2/15/2000: 2/16~2000: 2/17/2000: 2/18/2000: 2/19/2000: 2/20/2000: 2/21/2000: 2/22/2000: 2/23/2000: 2/29/2000: 3/01/20000: 3/02/20000: 3/03/20000: MIRU CTU. PT'd equip. PT'd Cement to 2000 psi - bled 245 psi in 30 minutes. RIH & milled XN nipple @ 8987' MD. RIH & tagged TOC @ 9403'. Milled Cement to the top of Whipstock @ 9423'. Milled window through the 7" Liner f/9423' - 9431'. Drilled FM to 9440'. Conditioned window interval. Layed in FIo Pro f/bottom while POOH. FP'd well. RD CTU. MIRU Nabors 3S Rig & CTU#4. 3S Rig accepted @ 0001 hrs. CTU on location 0200 hrs. PT'd BOPE. Performed maintenance on CTU. 3S on standby time. CTU#4 on location 2300 hrs. RU. PT'd BOPE. RIH & drilled to 9490'. Circ new mud. Performed LOT to EMW of 9.04 ppg. Drilled ahead to 9615' & POOH. RIH & drilled to 9759'. CT stuck - freed by puming Crude. Drilled to 10583' & became stuck. Called for Crude. Intersected Shublik Shale @ 10212'. Pumped Crude & CT pulled free. Drilled to TD @ 11148'. Conditioned OH for liner. RIH & logged OH. Conditioned OH for liner. POOH laying in new mud. Weather hold. RIH & landed 2-7/8" FL4S liner @ 11148'. TOL = 8953'. Pumped 22 bbls of 15.8 ppg Class G Cement to cement liner in place. Bumped plug. Contaminated Cement w/Biozan & jetted contaminated Cement from the wellbore. POOH. WOC. RIH w/CNL/GR/CCL logging tools & logged well f/11112' to 8700'. POOH w/logging tools. Left CNL, GR, CCL & ported sub in hole (-23.5' in length) as fish. Neutron source left in well. Decision to move off well. FP'd well. Begin RD. RDMOL. 3S released 1100 hrs. MIRU Klondike #1 workplatform & CTU#4. Continued RU. PT'd BOPE. RIH w/fishing BHA. POOH w/fish - full recovery. RIH w/GR/CCL logging tools & ran tie in log f/PBTD @ 11112' - 8750'. POOH. Performed liner lap test to 2100 psi. RIH w/2" perf guns. Shot 598' of Initial Perforations overbalanced f/: 9830' - 10160' MD (Zone 4B) 10550' - 10818' MD (Zone 4B) Shot all Perfs @ 4 SPF, 60° phasing,& random orientation. POOH w/guns. ASF. RD. Placed well 16-08A on initial production & obtained a valid well test. Sidetrack Summary Page I ARCO Plan.xlt 8400 8500 8600 8700 -- '~ 6800- >. 8900- I'-- ' I 9000- ¥ Field : Prudhoe Bay Location : North Slope, Alaska <- West (feet) Dote plotted : 14-Mar-2000 Plat Reference il 16-O~A. Coocdlnatee otl in feet reference 16-08, Vertical Depths ere reference RKB - MSL - 70 ft,i --- Baker Hughes IN?EQ --- ............................................................................................... 1400 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 i i i ~ /~i i i J ~ Tie-in Point ~-o~ W~I ~, Projected to TD -1600 - -1600 - -2000 '2200 · '2400 '2600 · -2800 3000 I ~6-o~ fi, ~o~'] ~ Projected to TD 1600 1700 1800 1900 2OOO 2100 22OO 2500 240O 2500 26OO 27OO 28OO 29OO 30aa 5100 3200 3300 5400 5500 3600 3700 Vertical Section (feet) -> Azimuth 188.00 with reference 0.00 N, 0.00 E from 1 6-08 Prepared by BHt 03/14/2000 End of Well Survey Calculations H~ Coordinates provided in: TRUE and GRID relative to Wellhead 1NTEQ and ALASKA STATE PLANE Company: ARCO Alaska, Inc. Rig: Nabors 3S Fldd: Prudhoe Bay, Alaska RKB H~ght: 70.000 Wall: 16-08A Verflc~ Sect. Plane: 188.000 Job No: 23582 Mag. Decflnation: 27.430 AFE No: AP-1498 G~d Correction: 1.660 API No: 50-029-20549-01 Job Start Date: 15-Feb-00 BHI Rep: P. Marwood Job End Date: 20-Feb-00 Survey Date: 19-Feb-00 Survey Type: MWD Meas. Ind. TRUE TRUE Subsea Coords. - True Coords. - ASP Dogleg Verflc~ Depth Angle Azi. V. Depth TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Seventy Section (deg) (deg) (~) (~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (3[) (°/100~) (Wellhead) 9300.00 25.07 176.40 8863.59 8793.59 -1772.70 504.43 5926935.34 720012.55i 0.61 1685.25 9425.00 24.42 176.73 8977.11 8907.11 -1824.92 507.56 5926883.23 720017.20 0.53 1736.53 9~44.84 26.43 176.73 8995.03 8925.03 -1833.43 508.05 5926874.74 720017.93 10.13 1744.88 9463.04 33.39 179.00 9010.80 8940.80 -1842.49 508.37 5926865.70 720018.51 38.74 1753.81 9506.24 50.48 187.00 9042.84 8972.84 -1871.15 506.53 5926837.00 720017.50 41.38 1782.44 9519.04 55.84 188.24 9050.51 8980.51 -1881.30 505.17 5926826.81 720016.43 42.59 1792.68 9549.04 67.84 184.94 9064.65 8994.65 -1907.52 502.18 5926800.51 720014.21 41.15 1819.07 9571.64 77.18 179.30 9071.44 9001.44 -1929.03 501.41 5926779.00 720014.06 47.67 1840.47 9604.17 89.07 174.19 9075.32 9005.32 -1961.20 503.26 5926746.89 720016.84 39.73 1872.08 9635.57 93.13 176.48 9074.72 9004.72 -1992.48 505.81 5926715.70 720020.30 14.84 1902.70 9661.57 94.98 180.89 9072.88 9002.88 -2018.41 506.41 5926689.81 720021.65 18.35 1928.28 9697.17 95.42 184.06 9069.66 8999.66 -2053.82 504.88 5926654.36 720021.14 8.95 1963.57 9723.17 96.12 187.59 9067.04 8997.04 -2079.55 502.25 5926628.57 720019.27 13.77 1989.41 9752.27 95.95 190.58 9063.98 8993.98 -2108.12 497.69 5926599.88 720015.53 10.23 2018.34 9786.87 95.42 193.93 9060.55 8990.55 -2141.76 490.38 5926566.04 720009.20 9.76 2052.67 9814.47 95.42 198.16 9057.94 8987.94 -2168.16 482.79 5926539.43 720002.37 15.26 2079.87 9863.07 94.45 207.50i 9053.75 8983.75 -2212.74 464.02 5926494.33 719984.91 19.25 2126.63 9896.07 96.92 203.80 9050.48 8980.48 -2242.33 449.80 5926464.34 719971.56 13.43 2157.91 9921.671 101.41 200.27 9046.41 8976.41 -2265.75 440.32 5926440.66 719962.76 22.20 2182.42 9952.87 101.59 201.86 9040.19 8970.19 -2294.28 429.33 5926411.83 719952.60 5.03 2212.20 9984.47 100.18 204.85 9034.22 8964.22 -2322.76 417.03 5926383.00 719941.13 10.31 2242.12 10015.27 99.30 208.03 9029.01 8959.01 -2349.94 403.52 5926355.45 719928.41 10.57 2270.91 10047.87 98.68 212.43 9023.91 8953.91 -2377.75 387.31 5926327.18 719913.01 13.47 2300.71 10076.87 98.50 209.79 9019.58 8949.58 -2402.30 372.49 5926302.21 719898.92 9.02 2327.08 10105.07 100.18 206.44 9015.00 8945.00 -2426.84 359.38 5926277.31 719886.52 13.15 2353.20 10156.07 98.41 205.03 9006.76 8936.76 -2472.17 337.53 5926231.36 719865.99 4.41 2401.14 10193.17 95.95 204.33 9002.12 8932.12 -2505.62 322.16 5926197.48 719851.60 6.89 2436.40 10229.37 93.22 202.92 8999.23 8929.23 -2538.67 307.70 5926164.02 719838.11 8.48 2471.14 10258.97 89.96 197.63 8998.41 8928.41i -2566.41 297.46 5926136.00 719828.67 20.98 2500.04 10287.57 87.22 196.40 8999.11 8929.11 -2593.75 289.09 5926108.43 719821.10 10.50 2528.27 10319.17 87.40 189.52 9000.60 8930.60 -2624.49 282.02 5926077.50 719814.92 21.76 2559.70 10354.97 85.11 184.94 9002.94 8932.94 -2659.92 277.52 5926041.96 719811.45 14.28 2595.41 10417.37 84.49 177.01 9008.60 8938.60 -2722.00 276.46 5925979.87 719812.19 12.69 2657.04 10457.17 85.73 170.85 9012.00 8942.00 -2761.42 280.65 5925940.60 719817.52 15.73 2695.48 10493.57 85.64 165.03 9014.74 8944.74 -2796.90 288.24 5925905.35 719826.13 15.95 2729.56 10537.17 85.90 161.68 9017.96 8947.96 -2838.55 300.69 5925864.08 719839.78 7.69 2769.08 10554.57 86.61 159.22 9019.09 8949.09 -2854.91 306.50 5925847.90 719846.06 14.69 2784.471 10585.57 87.14 155.52 9020.78 8950.78 -2883.48 318.41 5925819.69 719858.80 12.04 2811.101 10645.97 83.52; 154.46 9025.70 8955.70 -2938.02 343.85 5925765.91 719885.81 6.24 2861.57 10676.97 82.03 155.69 9029.60 8959.60 -2965.91 356.81 5925738.41 719899.57 6.21 2887.39 10703.97 81.15 158.34 9033.55 8963.55 -2990.50 367.24 5925714.13 719910.71 10.24 2910.28 10730.37 83.08 162.72 9037.17 8967.17 -3015.14 375.95 5925689.75 719920.13 17.99 2933.48 10754.97 85.46 165.38 9039.63 8969.63 -3038.68 382.68 5925666.42 719927.53 14.47 2955.85 10806.57 85.99 171.90 9043.48 8973.48 -3089.10 392.81 5925616.32 719939.12 12.64 3004.37 10835.57 86.87 174.72 9045.28 8975.28 -3117.84 396.18 5925587.69 719943.32 10.17 3032.36 10867.57 88.02 178.95 9046.71 8976.71 -3149.75 397.94 5925555.84 719946.01 13.69 3063.72 Meas. Incl. TRUE TRULY' Subsea Coords. - True ~rds. - ASP Dogleg Verflc~ Depth Angle Azi. V. Depth TVD N(+)/S(-) E(+)/W(-) N(+~t-) E(+)/W(-) Seventy Section (de~) (deg) (ft) (ft) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) (°/100~) (Wellhead) 10895.97 89.07i 182.83 9047.43i 8977.43 -3178.13 397.50 5925527.46 719946.391 14.15 3091.88 10943.77 86.96' 185.47 9049.09 8979.09 -3225.77 394.04 5925479.74 719944.31 7.07 3139.54 10977.97 83.79 185.30 9051.84 8981.84 -3259.71 390.85 5925445.73 719942.10 9.28 3173.59 11022.37 79.47 183.18 9058.31 8988.31 -3303.50 387.59 5925401.87 719940.12 10.82 3217.41 11040.57 78.06 182.65 9061.85 8991.85 -3321.33 386.69 5925384.02 719939.73 8.26 3235.19 11080.97 74.97 183.36 9071.27 9001.27 -3360.55 384.63 5925344.75; 719938.81 7.84 3274.32 11148.00 74.97 183.36 9088.66 9018.66 -3425.18 380.83 5925280.05! 719936.89 0.00 3338.84 North Slope Alaska Alaska State Plane 4 PB U_ EOA DS 16 16-08A Surveyed: 19 February, 2000 ORIGINAL SURVEY REPORT 17 March, 2000 RECEIVED MA~ 2 1 2000 ~laska Oil & G~xs Co~s. ~on~,m~ss~or Anchorage Your Ref: API-500292054901 Surface Coordinates: 5928692.41 N, 719456.98 E (70° 12' 27.6998" N, 148° 13' 49.3835" W) Kelly Bushing: 70.OOft above Mean Sea Level ~p~mm~j-~t.jm DRILL, INI3 SERVIC:ES SurveyRef:svy9690 A HAI..LIBURTQ~ COM~'AN'g Sperry-Sun Drilling Services Survey Report for 16-08A Your Ref: API.500292054901 Surveyed: 19 February, 2000 North Slope Alaska Alaska State Plane 4 PBU_EOA DS 16 Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 9300.00 25.070 176.400 8793.61 8863.61 9425.00 24.420 176.730 8907.13 8977.13 9444.84 26.430 176.730 8925.05 8995.05 9463.04 33.390 179.000 8940.82 9010.82 9506.24 50.480 187.000 8972.86 9042.86 9519.04 55.840 188.240 8980.53 9050.53 9549.04 67.840 184.940 8994.66 9064.66 9571.64 77.180 179.300 9001.45 9071.45 9604.17 89.070 174.190 9005.34 9075.34 9635.57 93.130 176.480 9004.74 9074.74 9661.57 94.980 180.890 9002.90 9072.90 9697.17 95.420 184.060 8999.67 9069.67 9723.17 96.120 187.590 8997.06 9067.06 9752.27 95.950 190.580 8994.00 9064.00 9786.87 95.240 193.930 8990.62 9060.62 9814.47 95.420 198.160 8988.06 9058.06 9863.07 94.450 207.500 8983.87 9053.87 9896.07 96.920 203.800 8980.60 9050.60 9921.67 101.410 200.270 8976.52 9046.52 9952.87 101.590 201.860 8970.30 9040.30 9984.47 100.180 204.850 8964.33 9034.33 10015.27 99.300 208.030 8959.12 9029.12 10047.87 98.680 212.430 8954.02 9024.02 10076.87 98.500 209.790 8949.69 9019.69 10105.07 100.180 206.440 8945.11 9015.11 Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/100fi) 1772.68 S 504.44E 5926935.14 N 720012.72 E 1824.90 S 507.58 E 5926883.03 N 720017.37 E 1833.41S 508.07 E 5926874.54 N 720018,10 E 1842.47 S 508.39 E 5926865.49 N 720018.69 E 1871.13 S 506.55 E 5926836,79 N 720017.68 E 1881.28 S 505.19 E 5926826.61 N 720016.62 E 1907.50 S 502.20 E 5926800.31 N 720014.39 E 1929,01 S 501,43 E 5926778.79 N 720014.25 E 1961.18 S 503,28 E 5926746.68 N 720017.03 E 1992.46 S 505.83 E 5926715,49 N 720020.49 E 2018.38 S 506.43E 5926689.59 N 720021.84 E 2053.80 S 504.90 E 5926654.15 N 720021.34 E 2079.53 S 502.27 E 5926628.35 N 720019.46 E 2108,10 S 497.70 E 5926599.66 N 720015.73 E 2141.75 S 490.39 E 5926565.82 N 720009.40 E 2168.15 S 482.80 E 5926539.20 N 720002.58 E 2212.73 S 464.03 E 5926494.10 N 719985.11E 2242.32 S 449.82 E 5926464.11N 719971.76 E 2265.74 S 440.34 E 5926440.43 N 719962.97 E 2294.27 S 429.35 E 5926411.59 N 719952.81 E 2322.75 S 417.05 E 5926382.76 N 719941.34 E 2349.93 S 403.53 E 5926355.20 N 719928.62 E 2377.74 S 387.32 E 5926326.93 N 719913.23 E 2402.29 S 372,51 E 5926301.96 N 719899.13 E 2426.82 S 359.40 E 5926277.05 N 719886.74 E 0.532 10.131 38.738 41.384 42.585 41.151 47.674 39.728 14.843 18.354 8.954 13.774 10.235 9.852 15.274 19.250 13.434 22.200 5.027 10.307 10.569 13.466 9.023 13.149 RECEIVED Vertical Section (ft) -1685.22 -1736.50 -1744.86 -1753.79 -1782.42 -1792.66 -1819.05 -1840.45 -1872.05 -1902.68 -1928.26 -1963.55 -1989.39 -2018.32 -2052.66 -2079.86 -2126.61 -2157.90 -2182.40 -2212.18 -2242.10 -2270.90 -2300.69 -2327.07 -2353.19 Comment Tie-on Survey Window Point MAR 21 2000 Continued... 17 March, 2000- 13:33 -2- Alaska Oil & Gas Cons {Somm~ss]o; Anchorage DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 16-08A Your Ref: API-500292054901 Surveyed: 19 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 10156.07 98,410 205.030 8936.88 9006.88 10193.17 95.950 204.330 8932.24 9002.24 10229.37 93.220 202.920 8929.35 8999.35 10258.97 89.960 197.630 8928.52 8998.52 10287.57 87.220 196.400 8929.23 8999.23 10319.17 87.400 189.520 8930,71 9000.71 10354.97 85.110 184.940 8933,05 9003.05 10417.37 84.490 177.010 8938.72 9008.72 10457.17 85.730 170.850 8942.11 9012.11 10493.57 85.640 165.030 8944.85 9014.85 10537.17 85.900 161.680 8948.07 9018.07 10554.57 86.610 159.220 8949.21 9019.21 10585.57 87.140 155,520 8950.90 9020.90 10645.97 83.520 154.460 8955.82 9025.82 10676.97 82.030 155.690 8959.71 9029.71 10703.97 81.150 158.340 8963.66 9033.66 10730.37 83.080 162.740 8967.29 9037.29 10754.97 85.460 165.380 8969.74 9039.74 10806.57 85.990 171.900 8973.59 9043.59 10835.57 86.870 174.720 8975.40 9045.40 10867.57 88.020 178.950 8976.83 9046.83 10895.97 89.070 182.830 8977.55 9047.55 10943.77 86.960 185.470 8979.20 9049.20 10977.97 83.790 185,300 8981.96 9051.96 11022.37 79.470 183.180 8988.42 9058.42 2472.16 S 337.55 E 2505.60 S 322.18 E 2538,66 S 307.72 E 2566.40 S 297.47 E 2593.74 S 289.11E 2624.48 S 282.03 E 2659.91S 277.54 E 2721.99 S 276.48 E 2761.41S 280.67 E 2796.89 S 288.25 E 2838.54 S 300.70 E 2854.90 S 306.51 E 2883.47 S 318.42 E 2938.01S 343.87 E 2965.90 S 356.83 E 2990.48 S 367.26 E 3015.13 S 375.96 E 3038.67 S 382.68 E 3089.09 S 392.81E 3117.83 S 396.18 E 3149.74 S 397.95 E 3178.12 S 397.51E 3225.76 S 394.05 E 3259.70 S 390.85 E 3303.49 S 387.60 E Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/100fi) 5926231.10 N 719866.22 E 4.415 5926197.23 N 719851.83 E 6.890 5926163.76 N 719838.34 E 8.482 5926135.74 N 719828.90 E 20.985 5926108.17 N 719821.33 E 10.501 5926077.23 N 719815.15 E 21.756 5926041.69 N 719811.69 E 14.278 5925979.60 N 719812.43 E 12.695 5925940.33 N 719817.77 E 15.732 5925905.08 N 719826.38 E 15.946 5925863.81N 719840.04 E 7.686 5925847.62 N 719846.32 E 14.686 5925819.42 N 719859.05 E 12.040 5925765.63 N 719886.07 E 6.243 5925738.13 N 719899.84 E 6.212 5925713.86 N 719910.98 E 10.242 5925689.47 N 719920.40 E 18.055 5925666.15 N 719927.80 E 14.409 5925616.04 N 719939.39 E 12.642 5925587.41 N 719943.59 E 10.168 5925555.56 N 719946.28 E 13.686 5925527.18 N 719946.67 E 14.149 5925479.46 N 719944.60 E 7.067 5925445.45 N 719942.39 E 9.282 5925401.58 N 719940.41 E 10.815 RECEIVED MAR 2 1 2000 Alaska State Plane 4 PBU_EOA DS 16 Vertical Section (ft) Comment -2401.12 -2436.38 -2471.13 -2500.03 -2528.26 -2559.69 -2595.40 -2657.02 -2695.47 -2729.55 -2769.06 -2784.46 -2811.09 -2861.56 -2887.37 -2910.27 -2933.47 -2955.84 -3004.36 -3032.35 -3063.71 -3091.87 -3139.53 -3173.58 -3217.4o Continued... 17 March, 2000- 13:33 -3- DrillQuest 1,05.04e Sperry-Sun Drilling Services Survey Report for 16-08A Your Ref: API-500292054901 Surveyed: 19 February, 2000 North Slope Alaska Alaska State Plane 4 PBU_EOA DS 16 Measured Sub-Sea Vertical Local Coordinates Depth Incl, Azim, Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°ll00ff) Vertical Section (ft) Comment 11040.57 78.060 182.650 8991.97 9061.97 3321.32 S 386.69 E 11080.97 74.800 183.360 9001.45 9071.45 3360.53 S 384.64 E 11147.00 74.800 183.360 9018.76 9088.76 3424.14 S 380.90 E 5925383.73 N 719940.02 E 5925344.47 N 719939.10 E 5925280.78 N 719937.22 E 8.257 8.248 0.000 -3235.18 -3274.30 -3337.81 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.411° (13-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 8.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11147.00ft., The Bottom Hole Displacement is 3445.26ft., in the Direction of 173.653° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9300.00 8863.61 1772.68 S 504.44 E Tie-on Survey 9425.00 8977.13 1824.90 S 507.58 E Window Point 11147.00 9088.76 3424.14 S 380.90 E Projected Survey 17 March, 2000 - 13:33 - 4 - DrillQuest 1.05.04e 8400 8500 (- 8600 8700 >. (D 8900 9000 9100 AI CO Alaska, Inc. Structure : D.S. 16 Held : Prudhoe Boy Well: 16-08A, 50-029-20549-01 Location : North Slope, Alosko <- West (fee'r) Creotad by potnla Dote plotted : 14-Mot-2000 Plot Reference is 16-08A. Coordlnotes ore in feet reference 16-0~. True Verticol Oeptha ere reference RKB - MSL = 70 ft, Brij Potnis 267-6613 --- B~ker Hughes INT[O 1400 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 I I I I I I I I I I I I I I I I I ORIG [WAL RECEIVED Tie-in Point MAR 17 2000 Alaska Oil & Gas Cons, Comm~ior~ Projected to ID _, Proiected to ID · 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 I I I I I t I i i 1600 1700 1800 1900 2000 2100 ' 2200 2,:300 2400 2500 2600 2700 2800 2900 3000 ,3100 3200 ,3300 ,3400 3500 ,3600 3700 Vertical Section (feet) -> Azimuth 188.00 with reference 0.00 N, 0.00 E from 16-08 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 ARCO Alaska, Inc. D.S. 16 16-08A 16-08 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker ~{ughes INTEQ Your ref : 16-08A Our ref : svy311 License : 50-029-20549-01 Date printed : 14-Mar-2000 Date created : 14-Mar-2000 Last revised : 14-Mar-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 718734.610,5930914.032,999.00000,N Slot location is n70 12 27.702,w148 13 49.383 Slot Grid coordinates are N 5928692.600, E 719457.000 Slot local coordinates are 2241.53 S 657.76 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED MAR 1 7 2000 ,Alaska Oii& Gas L;or~,s, Anchora..qe ARCO Alaska, Inc. SURVEY LISTING Page 1 D.S. 16,16-08A Your ref : 16-08A Prudhoe Bay,North Slope, Alaska Last revised : 14-Mar-2000 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing. 9300.00 25.07 176.40 8793.59 1772.70S 504.43E 0.61 1685.25 720012.55 5926935.34 9425.00 24.42 176.73 8907.11 1824.92S 507.56E 0.53 1736.53 720017.20 5926883.23 9444.84 26.43 176.73 8925.03 1833.43S 508.05E 10.13 1744.88 720017.93 5926874.74 9463.04 33.39 179.00 8940.80 1842.49S 508.37E 38.74 1753.81 720018.51 5926865.70 9506.24 50.48 187.00 8972.84 1871.15S 506.53E 41.38 1782.44 720017.50 5926837.00 9519.04 55.84 188.24 8980.51 1881.30S 505.17E 42.59 1792.68 720016.43 5926826.81 9549.04 67.84 184.94 8994.65 1907.52S 502.18E 41.15 1819.07 720014.21 5926800.51 9571.64 77.18 179.30 9001.44 1929.03S 501.41E 47.67 1840.47 720014.06 5926779.00 9604.17 89.07 174.19 9005.32 1961.20S 503.26E 39.73 1872.08 720016.84 5926746.89 9635.57 93.13 176.48 9004.72 1992.48S 505.81E 14.84 1902.70 720020.30 5926715.70 9661.57 94.98 180.89 9002.88 2018.41S 506.41E 18.35 1928.28 720021.65 5926689.81 9697.17 95.42 184.06 8999.66 2053.82S 504.88E 8.95 1963.57 720021.14 5926654.36 9723.17 96.12 187.59 8997.04 2079.55S 502.25E 13.77 1989.41 720019.27 5926628.57 9752.27 95.95 190.58 8993.98 2108.12S 497.69E 10.23 2018.34 720015.53 5926599.88 9786.87 95.42 193.93 8990.55 2141.76S 490.38E 9.76 2052.67 720009.20 5926566.04 9814.47 95.42 198.16 8987.94 2168.16S 482.79E 15.26 2079.87 720002.37 5926539.43 9863.07 94.45 207.50 8983.75 2212.74S 464.02E 19.25 2126.63 719984.91 5926494.33 9896.07 96.92 203.80 8980.48 2242.33S 449.80E 13.43 2157.91 719971.56 5926464.34 9921.67 101.41 200.27 8976.41 2265.75S 440.32E 22.20 2182.42 719962.76 5926440.66 9952.87 101.59 201.86 8970.19 2294.28S 429.33E 5.03 2212.20 719952.60 5926411.83 9984.47 100.18 204.85 8964.22 2322.76S 417.03E 10.31 2242.12 719941.13 5926383.00 10015.27 99.30 208.03 8959.01 2349.94S 403.52E 10.57 2270.91 719928.41 5926355.45 10047.87 98.68 212.43 8953.91 2377.75S 387.31E 13.47 2300.71 719913.01 5926327.18 10076.87 98.50 209.79 8949.58 2402.30S 372.49E 9.02 2327.08 719898.92 5926302.21 10105.07 100.18 206.44 8945.00 2426.84S 359.38E 13.15 2353.20 719886.52 5926277.31 10156.07 98.41 205.03 8936.76 2472.17S 337.53E 4.41 2401.14 719865.99 5926231.36 10193.17 95.95 204.33 8932.12 2505.62S 322.16E 6.89 2436.40 719851.60 5926197.48 10229.37 93.22 202.92 8929.23 2538.67S 307.70E 8.48 2471.14 719838.11 5926164.02 10258.97 89.96 197.63 8928.41 2566.41S 297.46E 20.98 2500.04 719828.67 5926136.00 10287.57 87.22 196.40 8929.11 2593.75S 289.09E 10.50 2528.27 719821.10 5926108.43 10319.17 87.40 189.52 8930.60 2624.49S 282.02E 21.76 2559.70 719814.92 5926077.50 10354.97 85.11 184.94 8932.94 2659.92S 277.52E 14.28 2595.41 719811.45 5926041.96 10417.37 84.49 177.01 8938.60 2722.00S 276.46E 12.69 2657.04 719812.19 5925979.87 10457.17 85.73 170.85 8942.00 2761.42S 280.65E 15.73 2695.48 719817.52 5925940.60 10493.57 85.64 165.03 8944.74 2796.90S 288.24E 15.95 2729.56 719826.13 5925905.35 10537.17 85.90 161.68 8947.96 2838.55S 300.69E 7.69 2769.08 719839.78 5925864.08 10554.57 86.61 159.22 8949.09 2854.91S 306.50E 14.69 2784.47 719846.06 5925847.90 10585.57 87.14 155.52 8950.78 2883.48S 318.41E 12.04 2811.10 719858.80 5925819.69 10645.97 83.52 154.46 8955.70 2938.02S 343.85E 6.24 2861.57 719885.81 5925765.91 10676.97 82.03 155.69 8959.60 2965.91S 356.81E 6.21 2887.39 719899.57 5925738.41 10703.97 81.15 158.34 8963.55 2990.50S 367.24E 10.24 2910.28 719910.71 5925714.13 10730.37 83.08 162.72 8967.17 3015.14S 375.95E 17.99 2933.48 719920.13 5925689.75 10754.97 85.46 165.38 8969.63 3038.68S 38~.68E 14.47 2955.85 719927.53 5925666.42 10806.57 85.99 171.90 8973.48 3089.10S 392.81E 12.64 3004.37 719939.12 5925616.32 10835.57 86.87 174.72 8975.28 3117.84S 396.18E 10.17 ~032.36 719943.32 5925587.69 10867.57 88.02 178.95 8976.71 3149.75S 397.94E 13.69 3063.72 719946.01 5925555.84 10895.97 89.07 182.83 8977.43 3178.13S 397.50E 14.15 3091.88 719946.39 5925527.46 10943.77 86.96 185.47 8979.09 3225.77S 394.04E 7.07 3139.54 719944.31 5925479.74 10977.97 83.79 185.30 8981.84 3259.71S 390.85E 9.28 3173.59 719942.10 5925445.73 11022.37 79.47 183.18 8988.31 3303.50S 387.59E 10.82 3217.41 719940.12 5925401.87 RECEIVED 17 2000 ~ Oi! & 6as Co~s. ¢'ommissior~ All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 16-08 and SSTVD from RKB - MSL = 70 ft. Bottom hole distance is 3446.29 on azimuth 173.66 degrees from wellhead. Vertical section is from wellhead on azimuth 188.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 16,16-08A Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 16-08A Last revised : 14-Mar-2000 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing. 11040.57 78.06 182.65 8991.85 11080.97 74.97 183.36 9001.27 11148.00 74.97 183.36 9018.66 3321.33S 386.69E 8.26 3235.19 719939.73 5925384.02 3360.55S 384.63E 7.84 3274.32 719938.81 5925344.75 3425.18S 380.83E 0.00 3338.84 719936.89 5925280.05 RECEIVED Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from 16-08 and SSTVD from RKB - MSL = 70 ft. Bottom hole distance is 3446.29 on azimuth 173.66 degrees from wellhead. Vertical section is from wellhead on azimuth 188.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and cgmputed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. D.S. 16,16-08A Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 3 Your ref : 16-08A Last revised : 14-Mar-2000 Comments in wellpath ==================== MD SSTVD Rectangular Coords. Comment 9300.00 8793.59 1772.70S 504o43E Tie-in Point 11148.00 9018.66 3425.18S 380.83E Projected to TD NO Targets associated with this wellpath RECEIVED TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~I~IISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (~07) 279-1433 FAX: Iq>07) 276-7542 Bruce E. Smith, P.E. AAI Coil Tubing Drilling Supervisor ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit 16-08A ARCO Alaska, Inc. Permit No: 199-126 Sur Loc: 2238'FNL, 4623'FEL, Sec. 24, T10N, RI5E, UM Btmhole Loc. 233'FNL. 4333'FEL, Sec. 25, T10N, R15E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) ~nust be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new' hole. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P.E. Chair BY ORDER OF THE_t~0MMISSION DATED this ~ ~ day of December, 1999 dlf/Enclosurcs cc: Department of Fish & Game. Habitat Scction xv/o encl. Dcpartmcnl of Environmcntal Conscrvation xx'/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: DHII D Redrill E~] I lb. Type of well. Exploratory D Stratigraphic Test [~] Development Oil r~ Re-entry N Deepen r'~I Service D Development Gas D Single Zone r~ Multiple Zone D 2. Name o! Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 70 feet 3. Address 6. Property Designation ,~,(J~-~ Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28333 ;~'~ ~__..~ Prudhoe Bay Oil Pool 4. Location et well at surlace v~ ~" v~ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 2238' FNL, 4623' FEL, Sec. 24, T10N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1215' FSL, 1164' FWL, SEC. 24, T10N, R15E, UM 16-08A #U-630610 At total depth 9. Approximate spud date Amount 233' FNL, 4333' FEL, Sec 25, T10N, R15E, UM February 6, 2000 $200,000 12. Distance to nearest property line ~ 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) ADL 028332, 233' MD feetI No Close Approach feet 2560 10961' MD / 9087' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 9425' MD Maximum hole angle 98° Maximum surface 2300 psig At total depth (TVD1 3160 psi~ @ 8800' 18. Casing program Settin~l Depth size Specifications Top Bottom Quant~ of Cement Hole Casing Weight Grade Coupling Len~h MD TVD MD TVD /include sta~le data) 3-3/4" 2-7/8" 6.4 L-80 FL4S 2011' 8950' 8546' 10961' 9087' 14 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 10132 feet Plugs (measured) PBTD tagged @ 9746' MD (6/12/1999) tree vertical 9631 feet Effective Depth: measured 9746 feet Junk (measured) tree vertical 9271 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 348 Sx AS II 110' 110' Surface 2647' 13-3/8" 2850 Sx Fondu & 400 Sx PF II 2717' 2717' Production 9227' 9-5/8" 500 Sx Class G 9297' 8861' Liner 1150' 7" 350 Sx Class G 10132' 9631' RECEIVED Perforation depth: measured 9424' - 9448'; 9454' - 9472'; 9477' - 9487'; 9492' - 9502'. DEC true vertical 8976' - 8998'; 9003' - 9020'; 9024' - 9034'; 9038' - 9047'. alaska & Gas Cons. 20. Attachments Filing fee [~] Property Plat D BOP Sketch r~ Dive,er Sketch D Drilling program r~ Drilling fluid program Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. I hereby cattily that the foregoing is true and correct to the best of my k~owledge Questions? Call Dan Kara@ 263-4837. Signed E.S~I~P. ~'~.,~_.p__.~ TiUe: AAI Coil Tubing Drilling Supervisor Date B Prepared b~/Pau( Rauf 263-4990 Commission Use Only Permit Numbe~;:~.. /2~:~ API5~umbeb ~...V.~ ~-~ ~::)_C/(~..' (~/I Approval/.~.,date_ ~'~'~-'~ ~j If°rlsee°therc°ver le, errequirements Conditions Of approval Samples required D Yes ~ No Mud log required r-~ Yes ~r No Hydrogen sulfidemeasures ~ Yes D No Directional surveyrequired ~[ Yes D No Required working preessure for BOPE r'~2u; [~ 3M; r"] 5M; D lOU;[~ r~ 3500 psi for CTU Other:. ._~,~iGINAL SIGNED'BY Robert N. Chdstenson byorderof /..~ ~..~)..~~x'~/,,' Approved by Commissioner the commission Date . Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 16-08A CT Sidetrack Intended Procedure Objective: P&A well with 15.8 ppg cement. Mill window from mechanical whipstock. Directionally drill a horizontal well from the existing wellbore. Complete with 2-7/8" cemented liner. Perforate appropriate intervals. Intended Procedure: · Install mechanical whipstock, P&A existing interval. Mill window from whipstock in 7" liner at 9425' md. Drill 20' of formation and perform leak-off test to 9.0 ppg, 0.5 ppg above the highest anticipated mud weight (8.5 ppg polymer mud). Directionally drill a 3-3/4" (4-1/8" bi-center) well to access Zone 4 reserves. · Run 2-7/8" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into disposal wells at Pad 3 or G&I. December 15, 1999 DS 16-08A Potential Drilling Hazards POST ON RIG H2S production measured 11 ppm on 4/12/99. Ensure all H2S monitoring equipment is operational. BHP: 3160 psi @ 8800' ss (6.9 ppg EMW), BHT 200 °F (9/29/98 SBHPS). No over pressured zones are anticipated. Maximum anticipated WHP w/full column of gas: 2300 psi. High perm intervals are expected across the Sadlerochit. No major faults are anticipated. The well will be drilled with 8.5 ppg mud. December 15, 1999 Proposal Calculations i'~GH~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLAN Company: ARCO Alaska~ Inc. Vertical Sect. Plane: 188.000 TRUE Job No: 0 Fidd: Prudhoe Bay~ Alaska Mag. Declination: 27.470 AFE No: 0 Wall: 16-08A Version#1 Grid Correction: 1.660 AP1 No: 50-029-20549-01 Rig: Nabors 3S Total Correction: 25.810 BHI Rep: 0 Surface Location Dip: 80.710 Job Start Date: 00-Jan-00 X: 719457.0 RKB Height: 70.000 Job End Date: 00-Jan-00 Y: 5928692.6 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (deg) (de~) (ft) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 9300.001 25.07 176.40 8793.59 -1772.70 504.43 5926935.34 720012.55 0.00 1685.25 153.00 0.00 0.00 Tie-in Point 9325.00 24.96 176.52 8816.25 -1783.25 505.08 5926924.81 720013.51 0.47 1695.60 153.00 -0.44 0.48 9350.001 24.86 176.65 8838.92 -1793.76 505.71 5926914.32 720014.44 0.47 1705.92 153.00 -0.40 0.52 9375.00 24.75 176177 8861.61 -1804.23 506.31 5926903.87 720015.34 0.47 1716.21! 153.00 -0.44 0.48 9400.00 24.65 176.90 8884.33 -1814.66 506.88 5926893.46 720016.22 0.47: 1726.46 -163.00 -0.40 0.52 9425.00 24.42 176173 8907.07 -1825.03 507.46 5926883.12 720017.10 0.96 1736.64 19.00 -0.92 -0.68 Kick-off Point 9431.00 27.26 178.97 8912.47 -1827.64 507.56 5926880.51 720017.27 50.04! 1739.22 20.00 47.33 37.33 3 9450.00 33.58 183.08 8928.85 -1837.25 507.35 5926870.90 720017.341 35.01 1748.76 16.00 33.26 21.63 9475.00 42.04 186.77 8948.58 -1852.50 505.99 5926855.62 720016.42 35.01 1764.05 13.00 33.84 14.76 9500.00 50.58 189.41 8965.84 -1870.37 503.42 5926837.69 720014.37 35.01 1782.10 11.00 34.16 10.56 9525.00 59.17 191.47 8980.21 -1890.45 499.70 5926817.50 720011.24 35.01 1802.51 10.00 34.36 8.24 9550.00 67.78: '193.19 8991.36 -1912.28 494.92 5926795.54 720007.09 35.01 1824.79 9.00 34.44 6.88 9575.00 76.42 194.70 8999.04 -1935.35 489.18 5926772.32 720002.03 35.01 1848.43 9.00 34.56 6.04 9600.00 85.06 196.11 9003.'06 -1959.11 482.63' 5926748.38 719996.16 35.01 1872.88 9.00 3~.56: 5.64' 9614.30 90.00 196.90 9003.68 -1972.80 478.57 5926734.58 719992.50 35'.01 1887.00 60.00 34.55 5.521 4 9625.00 90.54 197.83 9003.63 -1983.02 475.38 5926724.28 719989.61 10.00 1897.56 60.00 5.05! 8.69' 9650.00 91.78 199.99 9003.12 -2006.66 467.28 5926700.41 719982.20 10.00 1922.10 60.00 4.96 8.64 9675.00 93.03 202.16 9002.07 -2029.97 458.30 5926676.86 719973.89 10.00 1946.43 60.00 5.00 8.68 9700.00 94.27 204.34 9000.48 -2052.89 448.45 5926653.66 719964.72 10.00 1970.50 60.00 4.96 8.72 9725.00 95.51 206.52 8998.35 -2075.38 437.76 5926630.87 719954.68 10.00 1994.26 60.00 4.96 8.72 9750.00 96.74 208.71 8995.68 -2097.41 426.24 5926608.52 719943.80 10.00 2017.67 60.00 4.92 8.76 9775.00 97.96 210.911 8992.48 -2118.92 413.91 5926586.66 719932.11 10.00 2040.69 60.00 4.88 8.80 9775.90 98.00 210.99 8992.36 -2119.68 413.45 5926585.88 ' 719931.67 10.00 2041.51 -89.00' 4.44 8.89 5 9800.00 97.99 208.56 8989.00 -2140.40 401.60 5926564.83 719920.43 10.00 2063.67 -90.00 -0.04 -10.08 9825.00 97.97 206.03 8985.53 -2162.40 390.25 5926542.52 719909.72 10.00 2087.04 -90.00 ~0.08 -10.12 9850.00 97.93 203.51 8982.07 -2184.88 379.88 5926519.75 719900.00 10.00 2110.74 -91.00 -0.16 -10.08 9875.00 97.88 200.98 8978.63 -2207.79 370.51 5926496.57 719891.30 10.00 2134.74 -91.00 -0.20 -10.12 9900.00 97.81 198.46 8975.22 -2231.10 362.15 5926473.03 719883.62 10.00 2158.99 -91.00 -0.28 -10.08 9925.00 97.73 195.94 8971.84 -2254.76 354.83 5926449.16 719876.98 10.00 2183.44 -92.00 -0.32 -10.08 9950.00 97.63 193.42 8968.50: -2278.73 348.55 5926425.03 719871.40 10.00 2208.05 -92.00 -0.40 -10.08 9975.00 97.52 190.90 8965.20 -2302.95 343.33 5926400.66 719866.89 10.00 2232.76 -92.00 -0.44 -10.08 10000.00 97.39 188.38 8961.96 -2327.39 339.18 5926376.12 719863.45 10.001 2257.54 -93.00 -0.52 -10.08 Meas. Incl. TRUE Subsea Coords.. True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (deR) (de~) (ft) LaL (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100ft) /Wellhead/ (°/100ft) (°/100ft) 10025.00 97.25 185.86 8958.77 -2351.99 336.11 5926351.44 719861.09 10.00 2282.33 -93.00 -0.56 -10.08 10050.00 97.10 183.351 8955.65 -2376.72 334.11 5926326.67 719859.81 10.00 2307.09 -93.00 -0.60 -10.04 10075.00 96.93 180.83! 8952.59 -2401.51 333.21 5926301.86 719859.63 10.00 2331.77 -94.00 -0.68 -10.08 10100.00 96.75 178.32 8949.62 -2426.33 333.39 5926277.06 719860.53 10.00 2356.32 -94.00 -0.72 -10.04 10125.00 96.55 175.81 8946.72 -24'51.13 334.66 5926252.31 719862.52 10.00 2380.70 -94.00 -0.80 -10.04 10150.00 96.35 173.31 8943.91 -2475.85 337.02 5926227.66 719865.59 10.00 2404.86 -94.00 -0.80 -10.00 10175.00 96.13 170.80 8941.20 -2500.47 340.45 5926203.16 719869.74 10.00 2428.75 -95.00 -0.88 -10.04 10175.90 96.12 170.71 8941.10 -2501.35 340.60 5926202.28 71'9869.90 10.00 2429.60 110.00 -1.11 -10.00' 6 10200.00 95.29 172198 8938.70 -252~.09 344.00 5926178.66 719873.99 10.00 2452.64 110.00 -3.4~ 9.42 10225'.00 94.42 175.34 8936.59 -2549.86 346.53 5926153.96 719877.24 10.00 2476.82 110.00 -3.48 9.44' 10250.00 93.55 177.68 8934.85 -2574.76 348.05 59261~29.13 719879.48 10.00 2501.26 110.00 -3.48 9.36 10275.00 92.66 180.03 8933.49 -2599.71 348.55 5926104.20 719880.70 10.00 2525.90 110.00 -3.56 9.40 10300.00 91.78 182.37 8932.53 -2624.69 348.03 5926079.22 719880.90 10.00 2550.71 110.00 -3.52 9.36 10325.00 90.89 184.70 8931.94 -2649.63 346.49 5926054.24 719880.09 10.00 2575.62 110.00 -3.56 9.32 10350.00 90.00 187.04 8931.75! -2674.50 343.93 5926029.31 719878.25 10.00 2600.60 110.00 -3.56 9.36 10375100 89.11 189.37 8931.94 -2699.24 340.36 5926004.48 719875.40 10.00 2625.60 110.00 -3.56 9.32 10400.00 88.22 191.71 8932.53 -2723.81 335.79 5925979.79 719871.54 10.00 2650.57 110.00 -3.56 9.36 10425.00 87.33 194.05 8933.513 -2748.16 330.22 5925955.29 719866.68 10.00 2675.45 110.00 -3.56 9.36 10434.40 87.00 194.93 8933.96 -2757.25 327.87 5925946.13 719864.60 10.00 2684.78 -119.00 -3.51 9.36 7 10450.00 86.61 194.25 8934.83 -2772.32 323.95 5925930.95 71986i.ll 5.00 2700.26 -119.00 -2.50 -4.36 10475.00 85.99 193.17 89~6.45 -2796.56 318.04 5925906.56 719855.91 5.00 2725.08 -119.00 -2.48 I' -4.32 10500.00 85.36 192.08 8938.33 -2820.88 312.59 5925882.09 719851.16 5.00 2749.93 -119.00 -2.52 -4.36 10525.00 84.74 190.99 8940.49 -2845.29 307.61 5925857.55 719846.89 5.00 2774.79 -119.00 -2.48 -4.36 10550.00 84.13 189.90 8942.91 -2869.75 303.09 5925832.96 719843.09 5.00 2799.64 -119.00 -2.44 -4.36 10575.00 83.51 188.81 8945.60 -2894.28 299.05 5925808.33 719839.77 5.00 2824.49 -119.00 -2.48 -4.36 10600.00 82.89 187.71 8948.56 -2918.84 295.49 5925783.67 719836.91 5.00 2849.31 -119.00 -2.48 4.40 10625.00 82.28! 186.61 8951.79 -2943.44 292.40 5925759.00 719834.54 5.00 2874.10 -119.00 -2.44 -4.40 10650.00 81.67: 185.51 8955.28 -2968.06 289.78 5925734.32 719832.64 5100 2898.84 -119.00 -2.44 -4.40 10675.00 81.07 184.40 8959.03 -2992.68 287.65 5925709.64 719831.22 5.00 2923.53 -118.00 -2.40 -4.44 10700.00 80.47 183.29 8963.04 -3017.30 285.99 5925684.99 719830.27 5.00 2948.14 -118.00 -2.40 -4.44 10725.00 79.87 182.18 8967.31 -3041.91 284.82 5925660.36 719829.81 5.00 2972.66 -118.00 -2.40! -4.44 10750.00 79.27 181.06 8971.83 -3066.48 284.12 5925635.77 719829.83 5.00 2997.10 -118.00 -2.40! -4.48! 10775.00 78.68 179.94 8976.'61 -3091.02 283.91 5925611.24 719830.32 5.00 3021.43 -118.00 -2.36 -4.48 10800.00 78.09 178.81 8981.65 -3115.51 284.17 5925586.78 719831.30 5.00 3045.64 -117.00 -2.36 4.52 10825.00 77.51 177.68 8986.93 -3139~93 284.92 5925562.38 719832.75 5.00 3069.72 -117.00 -2.32 -4.52 10850.00 76.93 176.55 8992.46 -3164.28 286.14 5925538.08 719834.68 5.00 3093.66 -117.00 -2.32 4.52 10861.10 76.68 176.04 8994.99 -3175.06 286.84 5925527.32' 719835.69 5.00 3104.24 0.00 -2.25 -4.59 8 10875.00 77.38 176.04 8998.11 -3188.58 287'.78 5925513.84 719837.02 5.00 3117.50, 0.00 5.04 0.00 10900.00 78.63 176.04 9003.31 -3212.97 289.47 5925489.51 719839.41 5.00 3141.42 0.00 5.00 0.00 10925.00 79.87 176.04: 9007.97 -3237.47 291.16 5925465.07 719841.82 5.00 3165.451 0.00 4.96 0.00 10927.50 80.00 176.04 9008.41 -3239.93 291.33 5925462.62 719842.06 5.00 3167.85 0.00 5.20 0.00 10950.00 81.12 176.04 9012.10i -3262.07 292.87 5925440.53 719844.23 5.00 3189.57 0.00 4.98 0.00 10961.10 81.68 17'6.04 9013.76 -3273.02 293.62 5925429.61 719845.31 5.00 3200.30 0.00 5.05 0.00 TD ARCO Plan.xlt i i: D~t¢ plotted Structure : D.S. 16 Well : 16-08A Plan, 50-029-20549-O1 Field : Prudhoe Bay Location : North Slope, Alaska East (feet) -> 400 200 0 200 4-00 6,00 800 1000 1200 1400 1600 1500 1400 i i ~ ~,1 ~ 6O0 800 2200 2400 - 2600- 2800 30O0- - 32O0 · - 3600 - _ 5800 - !Tie-in Point Kick-off Po}nt TF=19 4 TF=60 ~!3 IF=20 / ! / ? TF=-ll9I 8 TF=O --- Bok.r H.ghe. I,~[e --- .................................................................................. ,, ,, Tie-;n Point ¢' ,, ,; /' Kick-off Point TF= 19 ~,, 4000 i ' , 4200 i ~"' 9200 3700 5600 3~00 3400 35S0 32ZC~ 3tED 3C:00 2900 281E, 2700 2~'30 2~30 24:i0 2~00 2200 2~03 2C'C0 190C ;$00 1700 ~6C, 0 1500 8500 8600 o -- _ - 88O0 -0 -,,. 8900 9OOO I 'x/ 9100 Vertical Section (feet) -> Azimuth 8.00 with reference 0.00 N, 0.00 E from 16-08 Prepared by BHI 12/15/99 DS 16-08A Proposed CT Sidetrack Horizontal 4-1/2" Tubing Packer @ 8901' 4-1/2" Otis XN 9003' 3.725" ID 4-1/2" TT @ 9016' 2212' 4-1/2" AVA SC TRSV id = 3.812" 7" Liner Top 8982' 9-5/8" Shoe @ 9297' Top of 2-7/8" Liner in 4-1/2" Tbg Tail Initial Perfs ~ 750' 2-7/8" Liner .. ~...:' 3-3/4" - 4-1/8" Open Hole 7" Casing Shoe Current Perfs cement squeezed TD @ ~ 10961' C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect - Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I '--" 7" Riser I Man Annular BOP (Hydril),7-1/16" ID 5000 psi WP Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus TRSSSV Tubing-IPC Casing Gas Lift Mandrel/Valve 1 Gas Lift Mandrel/Valve 2 Gas Lift Mandrel/Dummy Valve 3 Gas Lift Mandrel/Valve 4 Gas Lift Mandrel/Dummy Valve 5 Gas Lift Mandrel/Dummy Valve 6 ............................. Gas Lift Mandrel/Dummy Valve 7 Gas Lift Mandrel/Valve 8 Chemical Mandrel/Valve 9 SEALASY ............................. PKR NOGO Liner SOSUB 'ITL Per ......... Perf'--"-"" 16-08 APl: 1500292054900 Well Type: H2S:I Spud: SSSV Type:I Orig Compltn: Annular Fluid: I Diesel/9.1 Brine Last W/O: Reference Log:I BHCS Ref Log Date: I Last Tag:I Last Tag Date: Rev Reason:l GLV C/O Sta~2,4 Last Update: Elevat!~S~ ; :~ KB Grd 70 ff Oft 70 ff PROD 1 / 19/81 2/7/81 3/15/91 2/3/81 4/16/98 Cas Flng Tub Head RKB: 70 ft KOP: I0.00 ftKB PBTD: 10132.00 ftKB TD: 10132.00 ftKB Max Hole Angle: 33 deg @ 6600 Angle (~ TS: 24 deg (~ 9418 Ang e (~ TD: 20 deg ~ 10132 kB-grd ~epth iD ITyp® Description ' 221213.812 ITRSSSV 14-1/2" AVA SC TRSV SSSV Nipple 8900 0.000 SEALASY 4-1/2" Baker Locator Seal Assembly 890110.000 PKR 9-5/8" x 4-1/2" Baker SB-3A Packer 900313.725 NOGO t 4-1/2" Otis XN Nipple 901510.000 8OSUB 4-1/2" Baker Shearout Sub ' 901610.000 'ITL 4-1/2' Tubing Tail Off Off Date Note FRAC 04/18/90 9003 Min ID = 3.725" (4-1/2" Otis XN Nipple) 'iTL ELM (~ 9000: ELM Tubing Tail (Logged 12/13/91 ) Daterun: 1981-02-07 Item Top I Btm I Wt (in) (ftKB~.00 (ftKB) 13.375 in Casing 2717.00 72.00 C~i~ Sfri~: ~ PRODUCTION : Item Top I Btm I Wt7.004 (in) (ftKB~.00 (ftKB) 9.625 in Casing 9297.00 Ca~ihg::StH~g LINER: : Item Top J Btm J Wt (in) (ftKB) (ftKB) 7.000 in Liner 8982.00 10132.00 29.00 Grd L-80 Grd L-80 Grd L-80 Item Top I Bottom I (in) (ftKB) I (ftKB) I L 4.500 in Tubing-IPC 0.00 9016.00 I J~emi~! M~,d~is/'v~i~ : : :. IStn MD /ManMfr/ManType VivMfrl VlvType I 91 8796B'MMG'7'L'] MC VRCH Len I Wt Grd I (ft) 9016 12.60 L-80 I Latch I Vlv I Viv TROI Port t RK 0.188 3614.0 Vlv Run Stn MD Man Mfr Man Type 1 I 2991 MC-FMHOI 2I 47871MC~FMHOI 3 6191 MC-FMHO 4 7199 MC-FMHO 5 I 7659]MC'FMHDI 6I 8002/MC-FMHOI 7I 8346/MC-FMHOI 8 I 8689/MC-FMHOI tVlv Mfr'! CA MC Vlv Type R-20 R-20 VR-D R-20 VR-D VR-D VR-D RDO-20 I Latch I V'iv I VI~'TRO'j' Port I RK 0.250 1778.0 } RK 10.2501 1807.0I I RE 10.0001 0.0I IRK 10.2501 1844.0I J RE J O.O00 J O.OJ IRK I O.O00t 0.0l IRK I0.000[ 0.0I IRK 10.375 / 0.01 8/5/91 Vlv Run 4/7/96 5/23/97 1/1/60 5/23~97 6~30~94 1/1/60 1/1/60 4~7/96 Interval Zone Statu~ Feet SPF Date Type 9424- 9448 ZONE 4 O | 241 418/30/84 I RPERF 9454 - 9472 ZONE 4 O J 18J 4J6/11/84 RPERF 9477 - 9487 ZONE 4 O J 10J 4 J 8/30/84 APERF 9492 - 9502 ZONE 4 O ! 10 4 [ 8~30~84 APERF 9510 - 9514 ZONE 4 O | 4 0 6/9/84 APERF S~i~i~hs: & ~reat~h~::: Interval Date J Type Comment 9424 - 9472 6~9/84 J SQZ Comment May be SQZd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development __X RKB 70 feet , , 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ ,Anchorage, AK 99510-0360 set, ce__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2238' FNL, 4623' FEL, Sec. 24, T10N, R15E, UM (asp's 719457, 5928693) 16-08 At top of productive interval 9. Permit number / approval number 1215' FSL, 1164' FWL, SEC. 24, T1 ON, R15E, UM (asp's 720019, 5926883.5) 1817 )02-0 At effective depth 10. A/~r~ ~ber ~-' ~ !9-2054,.9...-" 4330' FNL, 4089' FEL, Sec. 24, T10N, R15E, UM (asp's 7200527, 5926618) / ~J3~e Bay Oil Pool 12. Present well condition summary //~/,,~ Total depth: measured 10132 ~eet Plugs (measur, ed)/ J/~;~TD tagged @ 9746' MD (6/12/1999) ,., fl)l/ ~ue vertical 927d f~et d II/I Conductor 110' I I 2!)" I'{ ' 3,h~xhSt~/ ~1 110' 110 Surface 2647' [ ~f~,~../~.t 205o S~'~du & 400 Sx PF II 2717' 2717' Production 9227' / ' \~,~'/8' 500 Sx 0~s G 0297' 8861' Uner 1150' ~/7' 350 sx cit G 10132' 9631' Perforation depth: measured 9424' - 9448'; 9454' - 9472'; 9477' - 9487'; 9492' - 9502'. ~ue vertical 8976' - 8998'; 9003' - 9020'; 9024' - 9034'; 9038' - 9047'. iTubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 POT @ 9016' MD. Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" BAKER SB-3A PACKER @ 8902' MD. 4-1/2" AVA SC TRSV SSSV @ 2213' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X ,,, 14. Estimated date for commencing operation 15. Status of well classification as: January 31, 2000 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby cerUly that the foregoing is true and correct to the best o! my knowledge. Que'stions? Call Dan Kara@ 263-4837. Signed '"---" ~ ~.~.~tie: AAI Coil Tubing Drilling Supervisor Date ~ ~-/~ ~ ~ Btu ~ Prepay'ed b~/ Pau! Rau! 263-4990 FOR COMMmSSmON USE ONLY Conditions of approval: PlugN°tifY Commission so representative may witneSSintegriby __ BOP Test _ Location clearance __ Appr°va' n~-~ ~'~/'t~",.~'"~ Mechanical Integrity Test __ Subsequent form required lO- Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. AAI PAYABLES Date: :1.2, , 99 P.O. Box 102776 Pay Entity: Vendor #: Anchorage, AK 99510 O2Ol ~ooov,_o2o221 12/14/ t9 VR121499SJD02 y077P 1299 SJD 100 . 00 100.00 FILING FEE FOR PERMIT TO D~ILL 16-08~% SIDETRAC ~ ~oo.oo ~oo.oo Questions regarding this remittance can be made by calling or writing: FRT 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 MATLS 907/265-6904 P.O. BOX 103560, Anchorage, AK 99510-3560 SVCS 907/265-6080 P.O. BOX 103240, Anchorage, AK 99510-3240 DIAL 907/263-~22 Detach check before depositing '!;:'57;:::::.:.~;i;?;,:i?i..::.~::.::::::. ::i:.'~;:~ :,,~::::~:/ (*'Amount. Not To Exceed $25,000.00'*) 12-15-99 To the order of: STATE OF ALASKA Date ALASKA OIL & GAS CONSERVATION CO~I~ISSION 300I PORCUPINE DRIVE ANCI{ORAGE AK 9950.1 **************100.00' Amount Void after 90 days :. Two si&natures required for amounl$ over ,'000010077B,' ~:OSSqOqSB8~: Oq qOOOO,' WELL PERMIT CHECKLIST FIELD & POOL ~'~ COMPANY~ WELL NAME .... PROGRAM: exp dev ~/redrll ~/ serv wellbore seg ann. disposal para req INIT CLASS ~ ~"-~//-.- GEOL AREA ,~r~L"'~ UNIT# ~)//~:~ '~ ON/OFF SHORE ADMINISTRATION , 8. 9. 10. 11. DATE 12. Permit fee attached ....................... Lease number appropriate.~. ................. Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... Y Y 24. 25. A~_~ DATE 26. 28. Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ~ ~ r~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. IN N N N N GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. ,,,c/,A,~ N ~,) ~/ -- 34. Contact name/phone for weekly progress reports [exploratory only~.,) N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N APPR DATE G EOL.~,~.~... ENGINEERING: UIC/Annular COMMISSION: ~PJ~"]/'~t , BEW ~ WM '""'"-~ DWJ JDH., '"~ - RNC co TE~O .~"~ \ ~* ~-~.~ . ,, Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09/27/99) 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 APPENDIXl .. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jul 11 10:43:53 2000 Reel Header Service name ............. LISTPE Date ..................... 00/07/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/07/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW- 90247 B. JAHN G. GOODRICH 16-08A 500292054901 ARCO Alaska, Inc. Sperry Sun Il-JUL-00 MWD RUN 3 AK-MW- 90247 B. JAPIN G. GOODRICH 24 10N 15E 2238 4623 70.00 70.00 .00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 9425.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RECEIVED JUL 1 Alaska Oil & Gas Co,~s. Bom,mission ~REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 3. MWD RUNS 2 AND3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR)) UTILIZING GEIGER MUELLER TUBE DETECTORS, AND ELECTORMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. NO FOOTAGE DRILLLED ON MWD RUN 2 DUE TO ORIENTER FAILURE AND IS NOT PRESENTED. 5. A MADPASS WAS PERFORMED DURING MWD RUN 300 TO FILL IN THE RESISTIVITY DATA FROM CASING TO 9415' MD, 8898' SSTVD. THIS DATA IS PRESENTED AS DRILLING DATA. 6. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC GR LOG (OF 2/3/00) WITH KBE = 70.00' KICKOFF POINT FOR THIS WELLBORE IS 9425' MD, 8907' SSTVD (TOP OF WHIPSTOCK). 7. MWD RUN 1 AND 3 REPRESENT WELL 16-08A WITH API# 50-029-20549-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11147' MD, 9018' SSTVD. SGRC = SMOOTHED GAMMARAY COMBINED SROP = SMOOTHED RATE OF PENETRATION SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( sHALLow SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/11 Maximum Physical Record..65535 File Type.... ............. LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH SEDP 9417.0 SEMP 9417.0 SESP 9417.0 STOP DEPTH 11110.0 11110.0 11110.0 SEXP 9417.0 SFXE 9417.0 SGRC 9419.0 SROP 9449.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9417.5 9556 9566 9585 9597 9606 9612 9647 9653 9658 9672 9700 9716 9729 9744 9749 9757 9770 9783 9801 9804 9807 9808 9816 9826 9834 9840 9846 9872 9888 9891 9895 9907 9946 9950 9958 9969 9976 9984 9988 9993 10010 10034 10040 10046 10050 10055 10066 10082 10099 10114 10126 10134 10137 10142 10148 .5 .5 .5 .0 .5 .5 .0 .5 .0 .0 .0 .0 .0 .5 .5 .0 .0 .5 .5 .5 .0 .5 .5 .0 .0 .0 .0 .0 .5 .0 .0 .5 .5 .5 .0 .0 .5 .5 .5 .5 .0 .5 0 5 0 5 5 0 0 5 0 .0 .0 .5 .5 10155.5 10172.0 GR 9415.0 9554.0 9563.5 9584.0 9594.5 9602.5 9609.5 9643.5 9649.5 9653.5 9667.0 9698.5 9714.5 9728.0 9740 5 9746 0 9750 0 9761 0 9774 5 9797 0 9798 5 9801 5 9803 0 9807 0 9816.5 9824.5 9829.0 9834.5 9860.5 9876.5 9879.0 9881.5 9895.5 9933.5 9937.0 9947.0 9956.5 9963.5 9971.5 9976.5 9981.0 9999.5 10022.5 10028.0 10034.0 10036.5 10042.5 10054.5 10073.5 10087.0 10104.0 10117.5 10126.5 10130.0 10135.0 10139.5 10147.0 10163.5 11110.0 11110.0 11099.0 11144.0 EQUIVALENT UNSHIFTED DEPTH 10183.5 10212.5 10225.5 10232.0 10236.5 10244.0 10268.0 10291.5 10302.0 10308.5 10339.5 10349.5 10352.0 10359.5 10362.5 10365.5 10378.0 10383.0 10391.0 10395.5 10425.0 10430.5 10433 5 10440 0 10459 0 10464 0 10478 0 10500 5 10513 5 10517 0 10527 0 10551 0 10561.0 10564.5 10574.0 10611.5 10621.0 10628.5 10633.0 10637.5 10641.5 10676.0 10683.5 10686.5 10694.5 10697.0 10711.0 10726.5 10732.0 10740.0 10747.5 10759.0 10772.0 10784.0 10799.0 10811.0 10844.0 10850.0 10931.5 10945.0 10972.5 10982.5 10985.0 11001.5 11020.0 11034.5 11038.0 11060.0 10176 0 10205 5 10218 0 10224 5 10228 0 10234 5 10261.0 10286.0 10296.5 10304.0 10335.5 10344.5 10349.0 10355.5 10357.5 10360.5 10372.5 10379.0 10384.5 10391.0 10421.0 10427.5 10433.0 10439.5 10458.0 10462.0 10476.5 10499.0 10511.0 10515.0 10524.5 10550.0 10559.0 10563.5 10572.5 10610.5 10619.5 10630.0 10634.5 10638.0 10641.0 10674.5 10682.0 10685.5 10693.0 10697.0 10710.5 10726.0 10734 5 10742 0 10750 0 10760 0 10771 5 10787 0 10802 5 10814 5 10848 5 10855 5 10935 0 10947 5 10979 5 10988 0 10991 0 11007 5 11024 0 11040.5 11045.0 11067.0 11085.5 11091.0 11090.5 11094.0 11144.0 11147.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD MWD 3 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 9417.0 9615.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9615.0 11147.5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 9417 11144 ROP MWD FT/H 6.35 6361.31 GR MWD API 20.63 534.06 RPX MWD OHMM 0.46 2000 RPS MWD OHMM 0.17 2000 RPM MWD OHMM 0.13 2000 RPD MWD OHMM 0.14 2000 FET MWD HR 0.1563 77.6559 Mean 10280.5 162.115 65.0947 33.7239 37.9115 51.749 144.919 8.67387 Nsam 3455 3391 3361 3387 3387 3387 3387 3387 First Reading 9417 9449 9419 9417 9417 9417 9417 9417 Last Reading 11144 11144 11099 11110 11110 11110 11110 11110 First Reading For Entire File .......... 9417 Last Reading For Entire File ........... 11144 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3kW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9417.0 ROP 9447.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9585.0 9615.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MLrD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MI/D AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: 16-FEB-00 Insite 1.22 Memory 9615.0 33.4 77.2 TOOL NUMBER 74165 3.750 FLO-PRO 8.50 65.0 9.3 13600 8.6 .000 .000 .000 .000 .0 141.0 .0 .0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9417 9615 9516 397 ROP MWD010 FT/H 20.12 3418.96 121.3 337 GR MWD010 API 28.62 165.57 55.7663 337 First Reading 9417 9447 9417 Last Reading 9615 9615 9585 First Reading For Entire File .......... 9417 Last Reading For Entire File ........... 9615 File Trailer Service name ............. STSLIB.002 Service SUb Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 9415.0 RPM 9415.0 RPS 9415.0 RPX 9415.0 FET 9415.0 STOP DEPTH 1111~.5 11113.5 11113.5 11113.5 11113.5 GR 9585.5 ROP 9615.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 11102.5 11147.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 19-FEB-00 Insite 1.22 Memory 11147.0 74.8 101.6 TOOL NUMBER 74165 4 3.750 FLO-PRO 8.50 65.0 9.5 13600 .0 .205 .100 · 165 .222 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 68.0 148.0 68.0 68.0 · RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 12 16 20 24 28 Name Service Unit Min Max DEPT FT 9415 11147.5 ROP MWD030 FT/H 6.35 6361.31 GR MWD030 API 20.63 534.06 RPX MWD030 OHMM 0.46 2000 RPS MWD030 OHMM 0.17 2000 RPM MWD030 OHMM 0.13 2000 RPD MWD030 OHMM 0.14 2000 FET MWD030 HR 0.1563 77.6559 First Mean Nsam Reading 10281.3 3466 9415 168.209 3065 9615.5 65.7824 3035 9585.5 33.8948 3398 9415 38.7122 3398 9415 54.0559 3398 9415 148.022 3398 9415 8.64752 3398 9415 Last Reading 11147 5 11147 5 11102 5 11113 5 11113 5 11113 5 11113 5 11113 5 First Reading For Entire File .......... 9415 Last Reading For Entire File ........... 11147.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/07/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/07/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/07/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File