Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
196-010
Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE : 10/29/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL GPB 18-01A (PTD 196-010) PNC3D 09/15/2020 Please include current contact information if different from above. PTD: 1960100 E-Set: 34142 Received by the AOGCC 10/29/2020 Abby Bell 10/30/2020 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI•N q. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate B Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 196-010 3. Address: P.O.Box 196612 Anchorage, Development 8 Exploratory ID AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20752-01-00 7. Property Designation(Lease Number): ADL 0028326 8. Well Name and Number: PBU 18-01A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: AtC IVED Total Depth: measured 11242 feet Plugs measured feet • - true vertical 8855 feet Junk measured 11117/11234 feet N O V 2`t A 2015 Effective Depth: measured 11234 feet Packer measured See Attachment feet tJ true vertical 8852 feet Packer true vertical See Attachment feet ,A0G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 29-108 29-108 1490 470 Surface 2570 13-3/8"72#L-80 28-2598 28-2597 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10831 -10836 feet 10890-10950 feet 11058-11078 feet 11080-11100 feet 11134-11186 feet 11206-11218 True vertical depth: 8760-8762 feet 8782-8794 feet 8799-8802 feet 8803-8806 feet 8814-8832 feet 8840-8845 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 115 4922 769 1150 499 Subsequent to operation: Shut-In 1040 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil m Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature4Phone +1 907 564 4424 Date 11/23/15 Form 10-404 Revised 5/201_ ..145 VT(- / 2-/23/ /S t ,z,zf/., RBDMs Ukl. 01 Y015 Submit Original Only • • 0 E a) L f/) Q LU a) O Y d a) p Q- , 00 d W o a Q H ch ) p d u) Cn U X a) a) CL N N CO m 3 = - 0 �+ m N N J ct d I� 4Li) w E cts L V Q O — M (O 00 N 4 aD N O O) N CO CO C) N- CO 00 a0 C 13 a co ca Lo v L CD aO) � wCO -C 2O) rnrnO (� M a rX Y Y >Uaa0 m m F- F- a) E < < < < R � r z 0 0 0 0 CO CO aS OO r r � U) • • m .p 0 0 0 0 0 0 0 0 0 co N- Cfl 0O - N O 00 O N- O (c:;.1 N Lf) • N V LO l!) N- N- CO I.- U y 0 0 0 0 0 0 N.00 0 0 - C) CO I- LC) (.0 Lo CO cr CO • V O CO - CN I� CO V CC) 00 I- CO CO I- CO C° (3) O CO CO LC) CO O O CA CO CO O) CO LC) I,- LO C) 00 CO CO CO O CA N CO CO 00 r-- CS) O7 CO LC) CO r- N O) CO I- CO CO LC) CA CA N N CO') CO CA O N CO CO a) CO 00 N I- LC) '- N N- CO CO � cocC) i p ("Ni LSC) copCO N CO CA 0) O) O) (A V 4-1 Q 2 4-0 c (N O CD CD CO CO O C7) 00 N- I- O O V LC) Ca CO N N N CO O CO CO N LC) L!) CO CO •cr CA O) CA (S) • W ~_ p (� 00 O O a , coco op O 00 00 Q OJO J = d *k N *k U) J J *k * •N N LC) I� V # *k *k CO U - - C0 N \- CA t LO LO O N N- CO O N N- C co co 00 O LC) O CO co (N () N CO - LC) CA W _Q Q C WD W W U o u_ cttxccccZ_ Z_ Z Z W W W W W E m m O D ~ H Z_ Z_ _Z J J D O U) Z Z J J J H H H 6-3/8"CNV ! SA NOTES:WELL ANGLE>70 @ 10900"`• " LIT`°= FMC 18 01 A 4-1/2"CHROME TBG*** Q.CTUATOR= BAKER C OKB.ELEV= 46.0' /I I 29' -15-1/2"X 4-1/2"XO,D=3.958" BF.ELEV= KOP_ 2800' 20" CONDUCTORH 110' Max Angle= 91°@ 10992' ' I 2062' -14-1/2"CAMCO SSSV NP(DB PROFLE),D=3.813" Datum AM= 11220' 91.5#,H 40, Datum TVD= 8800'SS D=19.124" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 13-3/8"CSG,72#,L-80 BT&C,D=12.347" H 2598' 3 3511 3472 28 MMG DOME RK 16 08/22/06 I 'I 2 6855 5992 43 KBG2 SO BK 20 08/04/06 9-5/8"X 7"ZXP LTP&FLD(LOCK HGR,D=6.31" 4003' 4 IULI 1 9018 7494 44 KBG2 DMY BK 0 07/13/06 Minimum ID = 2.372" @ 9643' c.' ' 4 9459' 14-1/2"HES X NP,D=3.813" 3-112" X 2-7/8" XO 0' +R } 9480' 7"X 4-1/2"BKR S3 PKR D=3.875" °',ate c.' J ►. ' ' i4 9504' I4-1/2'HES X NP,D=3.813' 4-1/2"TBG, 12.6#, 13CR-80 VA TOP, - 9551' 4. 9551' J-14-1/2'MULE SHOE ASSY,ID=3.958" .0152 bpi,D=3.958" >' 9566' H5-1/2"BKR PBR ASSY,D=?" 5-1/2"TBG-PC, 17#,L-80 LTC AB-M. -1 9566' :. 4. .0232 bpf,D=4.892' ' 9570' D= 7'SCAB LNR,26#,L-80 BTC-M, - 9570' .'* 9672' -16"BKR PROD SEAL ASSY,D=4.878" .0383 bpf,D=6.276" 9582' -19-5/8"X 5-1/2"BKR SAB R(R D=4.750" L 9593' --I5-1/2'x 4-1/2"TBG XO,D=3,958" TOP OF r LNR -1 9600' - -I 9600' H 9-5/8"X 7'BKR LNR HGR/TIEBACK,D=? 9640' -3.70"BKR G DEPLOY SLG,D=2.992" DAMAGED BY CTU(08/08/14)-SEE WELL FILE 9643' -13-1/2"X 2-7/8"XO,ID=2.372"- I 9653' -14-1/2'CAMCO DB NP MLLEI)D=3.80" 4-1/2"TBG-FC, 12.6#,N-80 BTC, -1 9664' / --I 9665' -14-112"WLEG,0=3.958" BEHIND .0152 bpf,D=3.958' CT LINER 9-5/8"CSG,47#,L-80 1 S0095 BT&C,D=8.681" -1 9917' , 10167' --I 7"MARKER JOT 7'LNR,29#,L-80 BT&C,.0371 bpf,0=6.184" 10905' • rJ MLLOUT WNDOW(18-01A) 10631 -10363 10984'-10995' -2-7/8"WFD ER PKR,D=1.370"(10/12/14) PERFORATION SUMMARY r. 4' (ORFICE PULLED 01/25/15) REF LOG: BHCS ON 06/23/82 - '1.4; 11117'CTM FISH-SL FISH ATTACHED TO ER PKR ANGLE AT TOP PERF: 67° 10831' @ y , PUSHED DOWN HOLE TO TD(9/25/14) Note:Refer to Production DB for historical pert data ^am• ••i► SIZE SPF INTERVALOpn/Sqz SHOT SQZ A 4 `� CTD HO NOTE(2/10/96)- 2" 6 10831 -10836 0 10/25/15 ti.',. . we ` 2-7/8"FC @ 11234'LEAKED 2" 6 10890- 10950 0 07/22/13 *4--4.7:, ` 2-118" 4 11058-11078 0 05/01/96 ► %i;v' . 2-1/8" 4 11080-11100 0 05/01/96 FISH-CBP MILLED&PUSHED DH(7/30/14) -1 11234' /'.' 2-1/8" 4 11134-11186 0 02/09/96 2-1/8" 4 11206-11218 0 02/09/96 PBTD -I 11234' 2-7/8"LNR,6.5#,L-80,.0058 bpi,D=2.372" -1 11240' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY LST 06/27)82 ORIGINAL COMPLETION 10/03/14 JTG/JMD SET FISH(09/25/14) WELL: 18-01A 02/10/96 CTD SIDETRACK 10/13/14 TA/PJC RUSH ER PKR OH(10/11/14) PERWIT No: 1960100 07/14/06 D14 IMO 10/13/14 TA/PJC SET ER FKR w/ORFICE(10/11/14) AF1 No: 50-029-20752-01 09/03/14 JDM/PJC SET ER PRK(08/01/14) 01/25/15 JCP/PJC RLL ORF10E FROM WFD Fi(R SEC 24,T11 N,R14E, 1416'F 1.&101'FEL 09(03/14 JDM'PJC PA-L CIBP&PUSH OH(7/30/12) 11/16/15 F V/JML'ADF132FS(10/25/15) 09/08/14 PJC GLV FORT SIZE STA#2 BP Exploration(Alaska) , STATE OF ALASKA AlIKA OIL AND GAS CONSERVATION COM ON c" `-, . REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U , Perforate U • Other U f - f 11"` Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 196-010-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20752-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028326 PBU 18-01A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL . 11.Present Well Condition Summary: Total Depth measured 11242 feet Plugs measured 11020 feet true vertical 8855.2 feet Junk measured None feet Effective Depth measured 11020 feet Packer measured See Attachment feet true vertical 8794.62 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2569 13-3/8"72#L-80 29-2598 29-2597.92 4930 2670 Intermediate None None None None None None Production 9889 9-5/8"47#L-80 28-9917 28-8130.68 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10890-10950 feet 11058-11078 feet 11080-11100 feet 11134-11186 feet 11206-11218 feet True Vertical depth 8782.46-8794.16 feet 8798.77-8802.4 feet 8802.77-8806.33 feet 8813.54-8831.8 feet 8840.12-8845.2 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED NOV 0 82013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 6 28950 0 0 1969 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorC❑ Development El Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U ' Gas U WDSPLI1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays( BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Ar,Signature ���� iii/�_• Phone 564-4035 Date 8/16/2013• 171,E RBDMS AUG 2 0 20 (,; tv-/ 11 ,. ; .� Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028326 ACTIVITY DATE. SUMMARY ® col, o• cope: .•-• on ingen - an. MCNL MIRU, RIH W/2.3" drift run before PPROF. Tag down on 7" scab liner top at 9560' CTM, below 4.5"tubing tail. Work past after several attempts. RIH. Sat down at 11100'. Circ to jet thru possible fill. No progress. Shut in well, RIH and set down at 11,102'. Hard bottom in horizontal hole. Can only log top set of perfs at 11058-11078'. Talk to pad engineer about plan forward. Cancel PPROF logging, since only 1 set of perfs are open. 7/20/2013 ****Continued on WSR of 07/21/13***** Continued from WSR of 07/20/13. CTU#3, 1.5" coil. Job scope: MCNL/GR/CCL, set CIBP, add perf. Continue POH with 2.3"drift BHA. Test barriers. Swab leaking. Grease swab, SSV and wing valves. Test barriers. Good test. Lay out BHA. M/U MHA. PT MHA. PJSM. M/U SWS MCNL/GR/CCL, RIH w/ MCNL, passed smoothly through the TOL, gentle tag @ 11110 ft, recorded two up passes and went back down for a flag. Painted an orange flag @ 11000.4' (electronic counter). POOH. L/D the MCNL assy, sent the data to town. P/U the CIBP assy, greased the ssv and the swab valves. RIH w/CIBP (BHA AOL = 26.82'). stopped at the flag depth and corrected the flag depth to 10991.3'. set the plug @ 11020' (mid element), sat down 2klb on the plug and PT same to 1000 psi for 5 min, POOH. Check barriers. Lay out BHA. Cut 125' coil. PJSM. M/U SWS 30' perf BHA. PT Lube. RIH with 30' perf guns. 7/21/2013 ******Continued on WSR of 07/22/13***** Continued from WSR of 07/21/13. CTU #3, 1.5" coil, Job Scope: Gas shut off and add perf. RIH with 30' SWS perf guns. Tag CIBP and correct depth to 11020". PJSM. Launch 1/2"AL ball. Position bottom perf charge at 10950'. Perforate 10920-10950'. POH. Test barriers. Lay out fired perf guns. P/U the 2nd perf guns (30 ft), RIH and tagged the CIBP, corrected the depth to 11020'. dropped the 1/2" ball, positioned the bottom perf @ 10920'. perforated 10890'-10920'. POOH. Freeze protect tubing with 39 bbl 50/50 meth. L/D the fired gun. cut CTC and changed the pack-offs. RDMO. Total perforated interval = 10890-10950', 2" PJ, 6 SPF. 7/22/2013 ******Job Complete**** FLUIDS PUMPED BBLS 141 1% KCL WITH SAFELUBE 425 1% KCL 39 50/50 METH 605 TOTAL Casing / Tubing Attachment ADL0028326 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5#H-40 30 - 110 30 - 110 1490 470 LINER 5567 7"26# L-80 4003 - 9570 3888.87 - 7893.99 7240 5410 LINER 1036 7"29#L-80 9600 - 10636 7914.95 - 8666.83 8160 7020 LINER 1602 2-7/8"6.5#L-80 9640 - 11242 7942.72 - 8855.2 10570 11160 PRODUCTION 9889 9-5/8"47# L-80 28 - 9917 28 - 8130.68 6870 4760 SURFACE 2569 13-3/8" 72# L-80 29 - 2598 29 - 2597.92 4930 2670 TUBING 9524 4-1/2" 12.6# 13Cr80 27 - 9551 27 - 7880.66 8430 7500 • TUBING 27 5-1/2" 17#L-80 9566 - 9593 7891.19 - 7910.07 7740 6280 TUBING 71 4-1/2" 12.6# L-80 9593 - 9664 7910.07 - 7959.3 8430 7500 • 0 • Packers and SSV's Attachment ADL0028326 SW Name Type MD TVD Depscription 18-01A PACKER 4003 3842.87 7" Baker ZXP Top Packer 18-01A PACKER 9480 7784.44 4-1/2" Baker S-3 Perm Packer 18-01A PACKER 9582 7856.39 5-1/2" Baker SAB Packer ! _ FRAC • SAFESTE5: WFI.L ANGLE>70°6 10900'&>90°4a ACTUATOR= =A'®-SON 1 8-01 A ��1n"�HRORWO r AB LNR REPAIRED PC LEAK. NT1AL KB.E.E 46.0' BF.ELEV -K-OP:--- 2800' Max A _ u_ 91° � � �� 29' f--j5-1/2"X 4-1/2"XO,D=3.958" Angle or coNDUCTOR H 110' I Datum WD= 11220' 2062' — 4-1/2"CAMCO SSSV NP(DB FROFLE),D=3.813" I 91.5#,H40 -Da-tun 1VD= 8800'SS 206r Hw/DRAY BALL VALVE,D=2.25"(07/13106) I GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" H 2598' A ST ND 1VD DEV TYPE VLV LATCH PORT DATE -3 3511 3472 28 194 DOPE RC 16 08/22106 2 6855 5992 43 KBG2 SO BK 20 08/04/06 1 9018 7494 44 KBG2 MN BK 0 07/13/06 Minimum ID =2.372" @ 9643' 4003' I-9-5/8"X r ZXP LNR TOP PKR& 3-1/2" X 2-718"XO 1 44 .i FLEXLOCK LNR MGR,D=6.31" i4 ,• 14 4 8459' H4-1/2"FESX( D=3.813' I 14 I' 1 1 -•� ►��r 9480' I—17'X 4-1/2'BKR S3 PKR D=3.875" I 1� IA/ ( 9504' H4-1/2'hESXNP,D=3.813' I 4-1/2"18G.12.6#,13CR-80 VAM TOP, —j 9551' 4. 0152 bpf,D=3_958" 9551' H4-1/2"MUL.E SHOE ASSY,ID=3.958" I 17"SCAB LIB 26#,L-80 BTC-M,D=6.276" H 9570' �4�` y`1. 9566' J-15-1/2"BAKB2 PBR Asst I //4' 4444 1 9570' H7"X 5-1/7 XO,D=4.89' e 1 9572' —I6"BKR PROD SEAL ASSY,0=4.878" I .t ►� 9582' I—I9-5/r X 5-1/2"BKR SAB PKR,D=4.750" I 5-1/2"113G-PC,17#,L-80,.0232 bpf,0=4.897 H 9593• ? I 9593' H 5-1/2"X 4-1/2'TBG XO,D=3.958' I 9600• H 9-5/8"X r LNR HGR I 9640' H 3.70"BKR G DEPLOYMENT SUB,D=2.992' I HI _.------I 9643' H3-1/2"X 2-7/8"XO,D=2.372" I ill I I 9653' I—4-1/7 CAMCO I B NP,kILLED D=3.60" tBE 1 4-1/2"TBG-PC,12.6#,L-80,.0152 bpf,0=3.958° H 9664' I `� ' 1iND EG( PIP 1 9-5/8"CSG,47#,L-80,13=8.681" H 991 r I� • III ��f PERFORATION SUMMARY P111t 1f t r MILLOUT WINDOW REF LOG: BHCS ON 06/23/82 1111v, 1111, 10630'-10636'(OFF CMT PLUG) ANGLEAT TOP PERF: 71° 10890 11114 11111 / Note:Refer to Roduction DB for historical pert data 1••• ••` SIZE SFF NBN TAL Opn/Sqz SHOT SQZ 1•�••. 1••••■ 1N44* NOTE ON 02/10/96 CID HO,NO1E 7 6 10890-10950 0 07/22/13 111111♦ 11111111. STATED 2-718"FC,_, 11234'LEAKED. 2-1/8" 4 11058-11078 C 05/01/96 11•1•4•1•1•1•1•! // ` 2-1/8" ••••••••' 4 11080-11100 C 05/01!96 1••••••• •••••••• I 2-1/8" 4 11134-11186 C 02/09/96 11111111 •••••••• 2-1/8" 4 11206-11218 C 02/09/96 11111114 4 ` FWD —I 11234'/ •••••••• 1••••••• •••••••• 11111111 I ►111111111/1111• 2-7/8"CUP 11020' 1. r....... ...1� 1� (07/21/13) 4•1• 17"LN2,298,L-80,0=6.184' H 10906' ►••••••• 1217/8'LNR,6.5#,L-80,.0058 bpf,D=2.372" I-i 11240' I DATE REV BY COMMENTS I DATE REV BY OORMAEN1S PR.JDHOE BAY UNIT 06/27/82 ORIGINAL COMPLETION 08/22/06 DAV/PAG GLV 0'0 WELL: 18-01A 02/10/98 +CTD SIDETRACK 01/05107 fTLH ORLG DRAFT FINALIZED PAT No: 1960100 07/14/06 D14 RWO 11/18110 CSRIPJC PERF CORRECTIONS API No: 50-029-20752-01 07/17/06 PCITLH DRLG DRAFT CORRECTIONS 08/13/13 I2RNJM)SET CBRADP82FS(07/21-22113) SEC 24,T11N,R14E,1416'FNL&101'FE- 08/04/06 KSB/PJC GLV C/0 08/10/06 DAV/PJC SSSV NPCORRE+CTION 1 8P Exploration(Alaska) ~ -- ~ I ~ e3~~~~~~~~~~~ NO. 5289 Alaska Data Ft Consultin Services ,-t:~ t= ?_525 Gambell Stree4, Suite 400 A.;~;~ j~„~~~ ~1 ~! ^~ r> ~~~~ Company: State of AlaskB Alaska Oil & Gas Cons Comm Anchorage, AK: 99503-2838 Attn: Christine Mahnken l1TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 06/26/09 A-44 09AKA0048 OH MWD/LWD EDIT ""~' ~'Q OM26/09 2 1 4-04A/T-30 09AKA0040 OH MWD/LWD EDIT 03/28/09 2 1 18-O1A 62WY-00003 MCNL 04/30l09 1 1 15-296 09AKA0143 OH MWD/LWD EDIT 05/30/09 2 1 05-35A 40017778 OH MWD/LWD EDIT ~V~ ~ ~ 09M0/08 2 1 V-115L2 11962618 OH WIRELINE ~- 08/22/OS 1 1 MPS-41 11966289 OH WIRELINE iSc-l.~j /'~ac~ 11/19/08 6 1 G-01.4 BOOR-00006 MCNL ~y~~ ~_~`~~ ~ 04/01/09 1 1 4-04AJT-30 BOCV-00014 _ ~ CH EDI i r~+~,~-GR (SCMT) (REVISE DATA) - ~ /27/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORRELATION) ,/ 12/03/08 1 07-148 AYQQ-00029 CH EDIT PDCL-GR (LDL) -~. 05/26/09 1 I_3-08 AWL9-00028 RST / O6/11/09 1 1 a..a~MJG Filif~ItlVtlYLGVIaC IIGIiCIrI ~i JIUltllltl~.1 NIVU 11C1 UI'fIVI1VU VIVC l.VY1 CNVI'1 ~ V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Alaska Data & Consulting Services 2525 Gambeli Street, Suite 400 Anchorage,AK 99503-2838 05/14/09 h I @ I" Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth o \' fi. i, a ~~ ~ . Well Job # Lea Descriotian N0.5235 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date 6L Color CD Z-06 AP3O-00035 STATIC PRESS/TEMP SURVEY 04/25/09 1 1 E-07A AYOO-00022 SCMT 04/24/09 1 1 V-04 AWJB-00031 MEM GLS -( 03/24/09 1 1 Y-16 AZ4D-00015 USIT / ~' .-p O Q 05/06/09 1 1 07-16A B2WY-00002 MEM CBL p 04/29/09 1 1 J-06 ANHY-00009 PRODUCTION PROFILE i3U 05/08/09 1 1 R-21 AVY5-00038 LDL / -( / / v 05/02/09 1 1 18-01A 62WY-00003 MEM CBL ~9~ -(~ 05/01/09 1 1 13-03 AYKP-00018 SCMT ~~~~®(c~ 1 o/a1 05/01/09 1 1 4-04A/T-30 BOCV-00014 SCMT a 04/27/09 1 1 03-09 AXOY-00007 MCNL / . pa 605 12/13/08 1 1 K-16AL2 AXIA-00009 MCNL 01/10/09 1 1 02-13B AWL9-00028 RST 03/26/09 1 1 C-03B AVY5-00040 RST 05/05/09 1 1 PLtASt AGKNUWLtUGt HtGtIY 1 t3T SIGNING ANU Ht I UHNING UNt GUYT tAGH 1 U: ro BP Exploration (Alaska) Inc. ~" ~~ Petrotechnical Data Center LR2-1 - ~ , -~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~/ ~QG9 Date Delivered: g I~ Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 50 - 838 ATTN: Beth ~1 Received by 1. Operations Performed: Anchorage o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 196-010 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20752-01-00 7. KB Elevation (ft): 46' 9. Well Name and Number: PBU 18-01A 8. Property Designation: 10. Field / Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11242 feet true vertical 8855 feet Plugs (measured) None Effective depth: measured 11234 feet Junk (measured) None true vertical 8852 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2598' 13-3/8" 2598' 2598' 4930 2670 Intermediate 9917 9-5/8" 9917' 8131' 6870 4760 Production Liner 1036' 7" 9600' - 1 0636' 7915' - 8667' 8160 7020 Liner 1502' 2-7/8" 9640' - 11242' 7943' - 8855' 10570 11160 Scab Liner 5576' 7" 4002 \Þ.è( )8~'j '@al 7240 5410 Perforation Depth MD (ft): 11058' - 11218' Perforation Depth TVD (ft): 8799' - 8845' Tubing Size (size, grade, and measured depth): 4-1/2",12.6# x 13Cr80 / L-80 9665' 5-1/'" 17# x 4-1/'" l' R# Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer 9480' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~. ", f" A I\~ 1\1 ,... '''' . ! ' .~, ·~V,-t.:;';-':t;,t:t) "Jt.JL._. ;:~ Treatment description including volumes used and final pressure: Cut and pulled 5-1/2" tubing from about 9500'. Run 7" Scab Liner. Cement w/81 Bbls (455 cu ft /166 sx) LiteCrete and 87 Bbls (488 cu ft /417 sx) Class 'G'. Run new chrome tubinQ. 13. Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service 16. Well Status after proposed work: o Well Schematic Diagram 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ìSUndry Number or N/A if C.O. Exempt: Contact Doug Cismoski, 564-4303 306-202 Printed Name Terrie Hubble Title Technical Assistant Signature ~ /In I~' M I ~ Phone 564-4628 ð 7! ' I~ Prepared By Name/Number: Date 2Jø O(P Terrie Hubble, 564-4628 , STATE OF ALASKA!f¿ Y2.7/c6 RECEIVED ALA&OILANDGASCONSERVATIONCOMII~ION JUL 262006 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission Form 10-404 Revised 04/2006 ORIGINAL RBDMS 8Fl JUt 2 7 1006 Submit Original Only TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP- Max Angle = Datum MD = Datum "TV 0 = FMC FMC e TlH n~ A 46.0' 2800' 91 @ 10992' 11220' 8800' SS 20" CONDUCTOR, H 91.5#, H-40 I 113-3/8" CSG, 72#, L-80, 10 =12.347" I 2598' Minimum ID = 2.372" @ 9643' 3-1/2" X 2-7/8" XO 14-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 1.0152 bpf, 10 = 3.958" 17" SCAB LNR, 26#, L-80 BTC-M, 10 = 6.276" I 9551' 9570' 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" I 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 9917'1----<11I ÆRFORA TION SUMMARY REF LOG: BHCS ON 06/23/82 ANGLEATTOPÆRF: 81 @ 11058' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 4 11058 - 11078 0 03/23/00 2-1/8" 4 11080 - 11100 0 03/23/00 2-118" 4 11134 - 11186 0 03/23/00 2-1/8" 4 11206-11218 0 03/23/00 I 7" LNR, 29#, L-80, 10 = 6.184" I 10905' 18-01 A '" --l; /1 110' 9593' 9664' I- - " I }-J . ..__ I I .. ....J . I- 5< " ~ . I.- ~ l - 8: I ""'"" I I .H I I - -1 - 29' 2062' 2062' ST MD 3 3511 2 6855 1 9018 4003' I 9459' 9480' 9504' 9551' 9566' 9570' 9572' 9582' 9593' 9600' 9640' 9643' 9653' ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06/27/82 ORIGINAL COM PLETION 02/10/96 CTD SIDETRACK 07/14/06 D14 RWO 07/17/06 PCITLH DRLG DRAFT CORRECTIONS .J" 5 SAFAoTES: WELL ANGLE> 70° @ 10900' & > 90° @ 1097~EAK FOUND IN 9-5/8" CSG @ 6146' ON 04/01/00. 2006 RWO 7" SCAB LNR FIX 9-5/8" CSG LEAK??? ***4-1/2" CHROM E TBG*** 1-15-1/2" X 4-1/2" XO, 10= 3.958" I 4-1/2" CAMCO HXO SSSV NIP (DB PROFILE), 10 -fw /DMY BALL VALVE, 10 = 2.25" (07/13/06) I GAS LIFT MANDRELS 1VD DEV TYÆ VLV LATCH 3472 28 MMG OCR RKP 5992 43 KBG2 DMY BK 7494 44 KBG2 DMY BK 3.813" PORT DA TE o 07/13/06 o 07/13/06 o 07/13/06 9-5/8" X 7" ZXP LNR TOP PKR & I FLEXLOCK LNR HNGR, 10 = 6.31" -14-1/2" HES X NIP, 10 = 3.813" I -17" X 4-1/2" BKR S3 PKR, 10 = 3.875" I -14-1/2" HES X NIP, 10 = 3.813" I -14-1/2" MULE SHOE ASSY, 10- 3.958" I -15-1/2" BAKERPBRASSY I -17" X 5-1/2" XO, 10 = 4.89" I -16" BKR PROD SEAL ASSY, 10 - 4.878" I -19-5/8" X 5-1/2" BKR SAB PKR, 10 - 4.750" I -15-1/2" X 4-1/2" TBG XO, 10 - 3.958" I -1 9-5/8" X 7" LNR HGR I -13.70" BKR G DEPLOYMENT SUB, 10 = 2.992" I -13-1/2" X 2-718" XO, 10=2.372" I 4-1/2" CAMCO DB NIP, MILLED 10 = 3.80" (BEHIND PIPE) I 9665' -14-1/2" WLEG (BEHIND PIPE) I / 7" M ILLOUT WINDOW 10630' -10636' (OFF CMT PLUG) NOTE: ON 02/10/96 CTD HO, NOTE STA TED 2-7/8" FC @ 11234' LEAKED. I PBTD H 11234' I ~ I 12-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.372" H 11240' 1 PRUDHOE BA Y UNrr WELL: 18-01A ÆRMrr No: "1960100 API No: 50-029-20752-01 SEC24, T11N, R14E, 1416' FNL & 101' FEL BP Exploration (Alaska) e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-01 18-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/2/2006 Rig Release: Rig Number: 14 Spud Date: 6/8/1982 End: 7/2/2006 04:00 - 06:00 2.00 MOB P DECOMP Skid rig floor from drilling position to move position 06:00 - 07:00 1.00 MOB P DECOMP Move rig off H-01A 07:00 - 11 :00 4.00 MOB P DECOMP UD BOP stack - Install booster tires 11 :00 - 00:00 13.00 MOB P DECOMP Moving rig to DS-18 7/3/2006 00:00 - 04:00 4.00 MOB P PRE Continue moving rig from H pad to Drill site 18 04:00 - 09:00 5.00 MOB P PRE Remove rear boosters - Move over and pick up BOP stack - Stuck rig temporarily on soft pad 09:00 - 10:00 1.00 MOB P PRE Spot rig over well 10:00 - 11 :00 1.00 MOB P PRE PJSM - Skid rig floor over well 11 :00 - 13:00 2.00 RIGU P PRE Mobilize rig floor - Rig accepted @ 1300 hours 13:00 - 15:00 2.00 DEMOB P DECOMP RlU cir lines to tiger tank - Fill pits w/ 9.8 brine - (Annulus and tree pressure = 0 psi) 15:00 - 16:00 1.00 DEMOB P DECOMP RlU lubricator - Pull BPV - RID lubricator 16:00 - 18:30 2.50 KILL P DECOMP PJSM - Pump 50 bbls 9.8 brine down annulus taking returns to tiger tank (203 gpm @ 790 psi) - Blowdown and swap lines - Pump 160 bbls 9.8 brine down tubing taking returns to tiger tank (325 gpm @ 1750 psi) - Verify well is dead - Blowdown and RID cir lines 18:30 - 19:00 0.50 WHSUR P DECOMP Install BPV - Test to 300 psi from back side 19:00 - 20:00 1.00 WHSUR P DECOMP PJSM - N/D tree - Dry test XO - Install blanking plug 20:00 - 23:30 3.50 BOPSU P DECOMP N/U BOP stack - C/O choke line spool - Install double valve on annulus 23:30 - 00:00 0.50 BOPSU DECOMP RlU 5.5" test joint and test equipment 7/4/2006 00:00 - 03:30 3.50 BOPSU DECOMP PJSM- RU test equipment- Attempt to close bottom rams on 5 1/2" test joint borrowed from Doyon 16- no success. 03:30 - 04:30 1.00 BOPSU DECOMP Test BOPE-FMC blanking plug- Blind rams, HCR kill, choke valves # 3,4 & 6 to 250 low- 3500 psi high. 04:30 - 06:00 1.50 BOPSU DECOMP PU 5" test joint- Test bottom rams to 250 low- 3500 high on chart 06:00 - 08:00 2.00 BOPSU DECOMP Change top rams to 4 1/2" x 7" variables. 08:00 - 10:00 2.00 BOPSU DECaMP PU 5 1/2" test joint- Attempt to screw in L.H. ACME onto FMC blank plug- Crossed threads- Pull out to inspect- Blank plug came out- Threads damaged. 10:00 - 11 :00 1.00 BOPSU DECaMP RU & test IBOP & Floor safety valve to 250 low- 3500 high while waiting on new blank plug & crossover. 11 :00 - 15:00 4.00 BOPSU DECOMP Install new blank plug into hanger- Continue to test BOPE- Annular,valves # 1,12,13,14- Top rams, valves # 4 through 11- valve # 2- Floor safety valve & choke # 3- HCR choke, IBOP- Manual Choke & kill, Top drive IBOP all to 250 psi low- 3500 psi high- Record all tests on chart- Perform accumulator test- All tests witnessed by W.S.L.- Witness of test waived by AOGCC Rep. John Crisp 15:00 - 15:30 0.50 BOPSU DECOMP Lubricate rig 15:30 - 17:00 1.50 BOPSU DECOMP RD test equipment, test joint & crossovers- Install bales, elevators, etc. 17:00 - 19:00 2.00 BOPSU DECOMP RU Extension / Lubricator- Pull BPV- RD lubricator. 19:00 - 20:30 1.50 PULL DECOMP Moblize fishing tools - MU spear assy - RIH - Spear hanger - Pull tubing 215K PU - 180K to pull hanger to floor 20:30 - 21 :30 1.00 PULL P DECOMP CBU 1 X - 329 GPM - @ 850 psi - 22 bbls to fill hole -lost 15 bbls circulating btms up 21 :30 - 22:30 1.00 PULL P DECOMP Break out spear - LD same - C/O handling equipment - RU power tongs - LD hanger - RU control line spool 22:30 - 00:00 1.50 PULL P DECOMP POH - LD 51/2" L-80 AB-Mod 17# tubing from 9500' to 8460' Printed: 7/17/2006 1:49:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-01 1 8-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/2/2006 Rig Release: Rig Number: 14 Spud Date: 6/8/1982 End: 7/5/2006 00:00 - 01 :30 1.50 PULL P DECOMP LD 5 1/2" Tubing from 8460' to 7280' 01 :30 - 02:00 0.50 PULL P DECOMP RD Schlumberger spool - Recovered 25 clamps - 4 SS bands 02:00 - 08:30 6.50 PULL P DECOMP Con't LD 5 1/2" tubing from 7280' to surface- Recovered 238 jts.+ cut joint (19.70'). 08:30 - 09:00 0.50 PULL DECOMP RD casing equipment- Clear rig floor 09:00 - 13:30 4.50 BOPSU DECOMP PU test joint & packoff tool- Pull 9 5/8' packoff w/ 20k overpull- Run in new packoff- Trouble getting packoff to seat- Pull out & inspect- Change seals- Rinse out casing head-Re-run- RILDS- Test packoff to 5000 psi f/ 10 min. 13:30 - 16:00 2.50 BOPSU P DECOMP PJSM- RU & change top rams to 2 7/8" X 5"- Change door seals on ram door-Test rams w/ 4" to 250 psi low-3500 high. - Pull test plug - Set wear ring 16:00 - 19:30 3.50 CLEAN P DECOMP PJSM - Moblize Clean out assy to rig floor - MU assy 19:30 - 00:00 4.50 CLEAN P DECOMP RIH with assy - PU 4" DP from pipe shed 1 X 1 from 318' to 5824' - (Total losses 182 bbls in last 24 hours - Total losses 480 bbls) 7/6/2006 00:00 - 02:30 2.50 CLEAN P DECOMP Cont. PU 4" DP - 1X1 from 5824' to 9462' 02:30 - 04:30 2.00 CLEAN P DECOMP Screw in T.D.- Obtain parameters- Wash down to 9494'- Work pipe 90' strokes while CBU- 50k over pull at 9483',9438' and 9395'. Rotate w/ 40 rpm on down stroke- Work through 4 times wI same overpull- Work through 2 times w/ no rotary, no overpull at 9483' & 9438'- 20k over at 9395'. 04:30 - 08:00 3.50 CLEAN P DECOMP POH F/9395' (10k over at 9290') to 318' 08:00 - 09:30 1.50 CLEAN P DECOMP Stand back DC's - LD BHA 09:30 - 10:00 0.50 CLEAN P DECOMP Clear rig floor - Moblize BHA #3 10:00 - 10:30 0.50 FISH P DECOMP Make up BHA #3 - 9.625" RTIS 10:30 - 14:00 3.50 FISH P DECOMP RIH to 6475 with RTIS - PUW 134 - SOW 125 14:00 - 15:00 1.00 EVAL P DECOMP Set RTIS 6478' - Up WT 135K - Down Wt 125K R/U Circulating Head - Pressure up below RTIS to 2500 Psi - Held F/10 min. on Chart - No Losses - Bled off - Close Rams- Establish injection Rate @ 3 BPM - 780 Psi - Shut down pumps for 10 mins. - Bled down to 330 Psi - Bleed off Press. - Open Rams. 15:00 - 17:00 2.00 EV AL P DECOMP POH to 4100' - Up Wt 105K - ON Wt 105K - Set RTIS @ 4095' - Close Rams - Press. up to 3500 PSI above RTIS - Held F/30 Mins. on chart, Good Test - Bled off Press. - Open Rams. 17:00 - 18:30 1.50 FISH P DECOMP POOH - Make Ser. Break - UD RTIS - Clear Rig Floor 18:30 - 20:00 1.50 FISH P DECOMP PJSM - M/U-BHA-Spear-Jar-Pump out sub-Drill collars 20:00 - 21 :00 1.00 FISH P DECOMP RIH F/305' to 2678' 21 :00 - 22:30 1.50 FISH P DECOMP Cut and Slip Drill Line-Service Top Drive 22:30 - 00:00 1.50 FISH P DECOMP Cont. TIH. 7/7/2006 00:00 - 01 :00 1.00 FISH P DECOMP Con't RIH to 9417' 01 :00 - 01 :30 0.50 FISH P DECOMP Wash down to 9500' - PU 190 - SO 157 - ROT 170 - TQ 3K- SPM 30 - PP 260 - SPM 40 - PP 510 01 :30 - 03:00 1.50 FISH P DECOMP Tag fish @ 9505' - Spear fish - Pull 60 over - Jar on fish - Max over pull 140K (String pull weight 330) - 80 hits - 5 bpm @ 390 psi 03:00 - 06:00 3.00 FISH P DECOMP Fish free - Lost complete returns - Pumping down Annulus / DP attempting to regain returns - Circulate w/ 2 BPM dropping mud wt to 9.4 ppg while waiting on DHD to arrive to shoot fluid levels. 06:00 - 08:30 2.50 FISH P DECOMP RU DHD and shoot fluid level- First shot level at 1170'- Wait 30 min.- Second shot level at 1590'-wait 15 min.- Third shot level Printed: 7/17/2006 1:49:43 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-01 18-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/2/2006 Rig Release: Rig Number: 14 Spud Date: 6/8/1982 End: 7/7/2006 06:00 - 08:30 2.50 FISH P DECOMP at 1698'- Fourth shot level at 1698'- 08:30 - 10:00 1.50 FISH P DECOMP Pump 290 bbls of 8.6 ppg seawater down backside- Let stabilize fl 30 min. 10:00 - 12:00 2.00 FISH P DECOMP Shoot fluid levels- First shot level at 1268'- Wait 30 min.- Second shot level at 1320'- Wait 30 min- Third shot level at 1360'- Wait 30 min. Fourth shot level at 1350'. 12:00 - 16:00 4.00 FISH P DECOMP Blow down lines- POH fl 9446' to 305' using double fluid displacement 16:00 - 18:00 2.00 FISH P DECOMP LD Spear BHA - LD Fish - (Recovered Cut joint 19.57 - 1 Joint 41.90 - Seal Assy 18.34) 18:00 - 18:30 0.50 FISH P DECOMP Clear rig floor of all fishing equipment - Associated tools 18:30 - 21:30 3.00 BOPSU P DECOMP Pull Wear ring - Install test plug with 7" Test joint - Change top VBR's to 7" Casg rams - RU test equipment - Test to 250 low I 3500 high 5 mins each test - Pull test plug I LD test joint - RD test equipment - Install wear ring 21 :30 - 22:30 1.00 CASE P DECOMP PJSM - RU 7" casing equipment - 22:30 - 00:00 1.50 CASE P DECOMP PJSM - PU 7" Liner - 7" 26# L-80 BTC-M - 7/8/2006 00:00 - 04:30 4.50 CASE P DECOMP Con't PU I Run 7" L-80 26# BTC-M casing to -5500' 04:30 - 05:00 0.50 CASE P DECOMP MU Baker FlexLock Hanger - ZXP Liner top packer - PU wt 182k- SO wt 165k 05:00 - 07:30 2.50 CASE P DECOMP RIH with Liner on 4" DP to -9569'- Obtain parameters- PU 225k- SO 160k 07:30 - 08:00 0.50 CASE P DECOMP PU Baker cement head- RU lines- Screw in Top Drive- Sting into PBR (Top at 9573')- SO to 15k down- PU to 10k over- Sit back down wI 15k 08:00 - 11 :00 3.00 CASE P DECOMP Pump down DP to fill void in annulus- Obtained returns wI 100 bbls pumped- 7.5 bpm 950 psi- Gas cut on returns- Increase rate to 8.5 bpm 1240 psi- Circulate surface to surface 2x while waiting on Schlumberger. 11 :00 - 12:00 1.00 REMCM P DECOMP Pump cement- 5 bbls H20- Test lines to 4500 psi- 5 bbls H20- 81 bbls 11.5 ppg LiteCrete- Yield 2.74 wi 1/4 #1 bbl each celoflake & cemnet LCM 5 bpm 280 psi- Pump 87 bbls 15.8 ppg class "G" cement wI GASBLOK- Yield 1.17 wI 1/4 #1 bbl each celoflake & cemnet LCM 4.8 bpm 270 psi. 12:00 - 12:30 0.50 CASE P DECOMP Displace to seawater wI rig pump 9.5 bpm 250 psi to catch cement- 230 bbls away lost partial returns- Bump plug at 239 bbls away (2390 stks)- Bump wI 1000 psi over (2750 psi) and set hanger- Switch to Schlumberger- Pressure to 3000 psi and observe packer shear- Continue pressure to 4300 psi- Bleed pressure- Check floats- OK- CIP @ 1230 hrs. 12:30 - 13:30 1.00 CASE P DECOMP Rotate 20 turns to right to release from hanger- Pressure to 1000 psi- PU and observe press. drop- Circ. BU wI 10 bpm 1390 psi- 18 bbls cement returned to surface- Set down wI 60k to ensure packer set- LD cement head. 13:30 - 14:30 1.00 CASE P DECOMP Pull out of liner top- Pump H.V. sweep wI nutplug- Reciprocate pipe 90' strokes- 10 bpm 800 psi- Flow check, dry job- Blow down 14:30 - 16:00 1.50 CASE P DECOMP POH fl 3904'- LD running tool & inspect same- OK 16:00 - 18:30 2.50 EVAL P DECOMP PJSM - Pull wear ring - Install test plug - Change 7" rams to 2 7/8" x 5" VBR's - RU testing equipment - Test to 250 low to 3500 high - 5 mins each test - RD testing equipment - Pull test plug - Install wear ring 18:30 - 20:00 1.50 CLEAN P DECOMP MU Clean out assy - 6 1/8" Bit - 2 Boot baskets - Bumper sub - Printed: 7/17/2006 1:49:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-01 18-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/2/2006 Rig Release: Rig Number: 14 Spud Date: 6/8/1982 End: 7/8/2006 18:30 - 20:00 1.50 CLEAN P DECOMP Jars - 9 4 3/4" DC's 20:00 - 22:30 2.50 CLEAN P DECOMP RIH - from 309' to 9139'- PU wt 192k SO 140k 22:30 - 00:00 1.50 CLEAN P DECOMP Cut Drlg line - Rig service - Top Drive service 7/9/2006 00:00 - 00:30 0.50 CLEAN P DECOMP Con't rig service 00:30 - 01 :00 0.50 CLEAN P DECOMP Con't RIH to 9420' 01 :00 - 02:00 1.00 CLEAN P DECOMP CBU 9.4 bpm - @ 2600 psi - PU 198 - SO 138 -70 RPM - 5K TO 02:00 - 03:00 1.00 CLEAN P DECOMP RU test equipment - Test casing to 3500 psi for 30 mins - Record on chart - RD test equipment - Blow down choke - Kill line 03:00 - 07:30 4.50 CLEAN P DECOMP Wash to 9445' - Tag firm cement - 10 to 12K WOB - Drill cement from 9445 to LC 9505' - Drill cement to 9546' (Upper float collar) - Drill upper float collar @ 9546' - Drill cement from 9548' to 9556' (lower float collar) - Drill lower float collar from 9556 to 9558' - Drill cement to 9569'- Tag Baker Ball Seat Insert. 07:30 - 09:30 2.00 CLEAN P DECOMP Displace well with clean seawater - Circulate Hi-vis sweep - Followed with clean 8.5 ppg seawater 09:30 - 10:30 1.00 CLEAN P DECOMP Drill ball and seat fl 9569' to 9571 '- Lost returns when drilled through. 10:30 - 14:00 3.50 CLEAN P DECOMP POH to 309' filling hole wI double displacement. 14:00 - 14:30 0.50 CLEAN P DECOMP Stand back DC's- LD BHA 14:30 - 15:00 0.50 CLEAN P DECOMP Clear rig floor of all equipment not needed- Mobilize Reverse basket BHA - RU tongs elevators for 2 7/8" PAC pipe. 15:00 - 17:00 2.00 CLEAN P DECOMP MU Clean out assy - Reverse circ basket - Junk baskets - 3 joints 2 7/8" PAC - Boot basket - 7" scraper - Boot basket- Jars - Pump out sub - 4 3/4" DC's 17:00 - 21 :00 4.00 CLEAN P DECOMP RIH from 420' to 9570' - Taking weight 5K 21 :00 - 23:00 2.00 CLEAN P DECOMP Work through top of 7" X 51/2" Seal assy XO - Pump 254 GPM @ 1700 psi - 30 RPM - TO 7K - Con't Wash to top of 2 7/8" Liner @ 9653' MD 23:00 - 00:00 1.00 CLEAN P DECOMP CBU - 267 GPM @ 1650 PSI 7/10/2006 00:00 - 03:00 3.00 CLEAN P DECOMP Cont. POH to 420' 03:00 - 04:30 1.50 CLEAN P DECOMP Stand back 4.75" Drill Collars - LD BHA 04:30 - 07:00 2.50 DHB P DECOMP MU 95/8" RBP - RIH to 2466 - Set - Fill void in annulus (45 bbls) - Test to 1000 Psi - POH 2 Stds.- 07:00 - 08:00 1.00 DHB P DECOMP MU 9.625" Storm PKR - RIH 1 Std - Set and Release off - POH 1 Std back. 08:00 - 09:30 DECOMP ND BOPE 09:30 - 10:30 DECOMP Change out Tubing spool - Test pack off to 5000 psi fl 15 min 10:30 - 12:00 DECOMP NU BOPE 12:00 - 17:30 DECOMP Install Test Plug - RU Test Equip - Test - Annular - 250 Low - 3500 High - Top rams - Bttm rams - Choke Manifold - Upper I Lower IBOP - Blind rams - HCR Choke I Kill Valves - Manual Choke / Kill Valves - Floor Safety Valves - 250 Low I 3500 High - Accumulator test performed - All test witness by WSL - Jeff Jones with AOGCC waived witness of test - RD testing equip - Pull test plug - Install wear ring 17:30 - 20:00 2.50 DHB P DECOMP PU 1 stand - RIH - Retrieve Storm PKR - RIH 2 stands - Retrieve RBP - POOH - LD Plug and Running Tools 20:00 - 21 :30 1.50 CLEAN P DECOMP MU - Reverse circulating basket Assy - 21 :30 - 00:00 2.50 CLEAN P DECOMP RIH from 420' to 7257' 7/11/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP RIH from 7257' to 9653' Printed: 7/17/2006 1:49:43 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-01 18-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/2/2006 Rig Release: Rig Number: 14 Spud Date: 6/8/1982 End: 7/11/2006 01 :00 - 01 :30 0.50 CLEAN P DECOMP Break circulation - Circulate on top of liner to clean any debris off liner top - 6 bpm @ 1600 psi - PU 205 - SO 140 01 :30 - 03:30 2.00 CLEAN P DECOMP Pump 35 bbl Hi-Vis polymer spacer - Followed by clean SW back to surface -7 bpm @ 1900 psi - Monitor well 03:30 - 07:00 3.50 CLEAN P DECOMP PJSM - POH Laying down 4" DP from 9653' to 4800' 07:00 - 08:30 1.50 CLEAN P DECOMP Cut drlg line - Top Drive service - Rig service 08:30 - 11 :00 2.50 CLEAN P DECOMP Continue POH LDDP - From 4800' to 420' 12:00 - 12:30 0.50 CLEAN P DECOMP LD BHA - Clear rig floor 12:30 - 15:00 2.50 RUNCO RUNCMP PJSM - Pull wear bushing - C/O bales - Moblize tongs, elevators, slips, compensator - RU Tubing equipment - 15:00 - 00:00 9.00 RUNCO RUNCMP PJSM - PU I Run - (41/2" 12.6# 13 Cr Vam Top tubing) - Depth 7285' 7/12/2006 00:00 - 01 :00 1.00 RUNCO RUNCMP PJSM - Moblize control line spool to rig floor - RU spool I sheave 01 :00 - 05:30 4.50 RUNCO RUNCMP Con't RIH with 41/2" Completion from 7285 to 9849' - With dual control line 05:30 - 08:00 2.50 RUNCO RUNCMP PU landing joint - XO - Make up Hanger - Tie in control lines to hanger - Pump 316 bbls inhibited seawater in annulus 08:00 - 10:00 2.00 RUNCO RUNCMP Attempt to land tubing - Could not pass 9566' - Work string 5 to 6 times - No Go 10:00 - 14:00 4.00 RUNCO RUNCMP Wait on slick line unit 14:00 - 00:00 10.00 RUNCO RUNCMP PJSM - RU full well control for slick line - BOP's - Lubricator - RIH pull dummy sleeve on SSSV - RIH pull ball I rod - RIH pull RHC plug - RIH with 3.6 drift - Hit obstruction @ 9573 WLD - PU overpull - Slack off - Hit jar one time string free - Work 3 to 5 times across XO on seal assy from 9500 to 9600 - RIH tag up on 2 7/8" Liner top @ 9662 WLM - POH to 9480 - Slight bobble down and up across 9570 to 9573 - No over pull seen coming up through XO top @ 9573 WLD - POH - RIH to set RHC plug 7/13/2006 00:00 - 05:30 RUNCMP Con't RIH with RHC plug - Could not pass X Nipple - POH - RIH retrieve RHC plug - Redress RHC - RIH - Set plug - POH 05:30 - 06:30 1.00 RUNCMP RIH Set Dummy valve SSSV - Test control line - POH 06:30 - 07:30 1.00 RUNCMP PJSM - RD Slick line BOP's - Lubricator 07:30 - 08:00 0.50 RUNCMP Pick up landing joint - Make up hanger to LJ I Control lines - Attempt to land tubing hanging up at 9566' 08:00 - 11 :00 3.00 RUNCMP LD landing joint - Hanger - 2 joints 4 1/2" tubing - MU 1 pup 1 joint 4 1/2" tubing - PU hanger - Landing joint - Make up control line to hanger - Test - RIH land tubing @ 9550.53' - RILDS on hanger - (Total stainless steel bands 54 ran) 11 :00 - 12:30 1.50 RUNCMP RU circulating lines for setting packer - Testing tubing and annulus 12:30 - 15:00 2.50 RUNCMP Pressure up to 3500 psi - Set packer - Hold for 30 mins - Record on chart - Bleed off tubing to 1500 psi - Pressure up on annulus to 3500 psi - Hold for 30 mins - Record on chart - Bleed down tubing pressure - Shear out DCK valve - Bleed off all pressure tubing I annulus 15:00 - 15:30 0.50 RUNCMP RD circulating line to tubing - Back out landing joint - Install TWC - Test from bottom 1000 psi 15:30 - 17:30 2.00 BOPSU P RUNCMP NO BOP's 17:30 - 22:00 4.50 WHSUR P RUNCMP NU FMC Adapter flange - Tree - FMC test adapter flange to 5000 psi 10 mins - Test good 22:00 - 23:00 1.00 WHSUR P RUNCMP RU test equipment - Test tree to 5000 psi for 30 mins with rig Printed: 7/17/2006 1 :49:43 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-01 18-01 WORKOVER DOYON DRILLING INC. DOYON 14 Start: 7/2/2006 Rig Release: Rig Number: 14 Spud Date: 6/8/1982 End: 7/14/2006 1.00 WHSUR P 1.00 RUNCO 0.50 WHSUR P 1.00 WHSUR P 01 :30 - 03:00 03:00 - 04:00 1.50 WHSUR P 1.00 WHSUR P test pump - Record on chart - Test good Change out saver sub RU lubricator - Pull TWC - RD lubricator RU Little Red Hot oil service - Freeze protect with 140 bbls diesel - BPM 3 @ 500 psi RUNCMP U-Tube annulus I tubing RUNCMP RU lubricator - Install BPV - Test from below to 1000 psi - RD lubricator RUNCMP Suck out all lines - RD Little Red - Secure well - Install blind flange on wing valve - Install valve handles - Install gauges on annulus valves - Close all valves on tree - Release rig @ 05:30 hrs 04:00 - 05:30 1.50 WHSUR P Printed: 7/17/2006 1 :49:43 PM Legal Well Name: 2-18 Common Well Name: 2-18 Event Name: WORKOVER Assembly Name: PACKER WITH TAIL Suspended From:SURFAcE EQUIPMENT @ (ft) TMD Correction: (ft) Landed TMD: 13,118.51 (ft) Report #: Start: 1 7/6/2006 Spud Date: 9/8/1989 Report Date: 7/13/2006 End: Install Date: 7/13/2006 Pull Date: Final String Weight: (Ib) Landed Weight: (Ib) 25.0 TUBING HANGER 3.90 0.7 FMG TGII TUBING PUPJOINT 3.95 2.4 SUMITOMO TGII TUBING JOINTS 3.95 41.9 SUMITOMO TGII TUBING PUPJOINT 3.95 9.7 SUMITOMO TGII TUBING JOINTS 3.95 1,999.01 SUMITOMO TGII TUBING PUPJOINT 3.95 9.7 SUMITOMO TGII X NIPPLE 3.81 1.2 HALLIBURTON TGII TUBING PUPJOINT 3.95 9.7 SUMITOMO TGII TUBING JOINTS 3.95 10,891.9 SUMITOMO TGII TUBING PUPJOINT 3.95 9.7 SUMITOMO TGII X NIPPLE 381 1.2 HALLIBURTON TGII TUBING PUPJOINT 3.95 19.7 SUMITOMO TGII PAGKER (PERMAN 3.87 4.8 BAKER TGII TUBING PUPJOINT 3.95 19.7 SUMITOMO TGII X NIPPLE 3.81 1.21 HALLIBURTON TGII TUBING PUPJOINT 3.95 9.8 SUMITOMO TGII TUBING JOINTS 3.95 41.0 SUMITOMO TGII TUBING PUPJOINT 3.95 9.7 SUMITOMO TGII MULE SHOE GOLL 3.95 9.6 TGII Printed: 7/17/2006 1 :49:56 PM e e ~ U ~ u Œ lID ~ 1% ~ ~ ~ æ ~ / FRANK H. MURKOWSKI, GOVERNOR AltASIiA OILAIQ) GAS / 333W.7'"AVENUE,SUITE100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~/i) Î 0 \q Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-01A Sundry Number: 306-202 . . ,." "_.c',, . 't' '\ " ¿nmo' ·.·'Iη..· '<.Mi<I..¡iio-" L p, I .\1 ; ,If. VV ~~~~ ,¡;;;p~~~ t¿> tr,J j ....... -- Dear Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fIle with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisLJ day of June, 2006 EncL , f. ~ ,l/Jc.. 6/;2/ó¿ C(/J- t// J(í6 ¡,../óA-- t,[lz.I'Loo£, A~.. [' '1'\0 I STATE OF ALASKA I e RECEIVED /J¡AI b I ALASKA 0 AND GAS CONSERVATION COMMISSION JUN 0 9 2006 ¡ l APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Commission Anchoraoe 1. Type of Request: 0 Abandon a Repair Well o Plug Perforations o Stimulate o Alter Casing a Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended W 2. Operator Name: 4. Well Class Before Work: ( 5. Permit To Drill Number BP Exploration (Alaska) Inc. g Development 0 Explorato 196-010 ./ 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20752-01-00 ./ 7. KB Elevation (ft): 46' 9. Well Name and Number: PBU 18-01A"'/ 8. Property Designation: 10. Field / Pool(s): ADL 028326 Prudhoe Bay Field / Prudhoe Bay Pool l1;i '>< · ..... ,.,..",......' is \iVELI...'\;VI'\!L./l » .,.... i. .<. ·sr'(......;<· < ,'.. .... .". .. > Total Depth MD (ft): Total Depth TVD (ft)lEffective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 11242 8855 11234 / 8852 None None Casina Lenç¡th Size MD / TVD Burst Collapse Structural Cnnductor 80' 20" 80' 80' 1490 470 Surface 2598' 13-3/8" 2598' 2598' 4930 2670 Intermediate 9917 9-5/8" 9917' 8131' 6870 4760 Production Liner 1036' 7" 9600' - 1 0636' 7915' - 8667' 8160 7020 Liner 1502' 2-7/8" 9640' - 11242' 7943' - 8855' 10570 11160 Perforation Depth MD J): I Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft): 11058'-11218' 8799'-8845' 4-1/2" x 5-1/2" 13Cr80 / L-80 9665' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer; I Packers and SSSV MD (ft): ~ ,/ 9-5/8" x 4-1/2" Baker 'S-3' packer 12. Attachments: 13. Well Class after proposed work: g Description Summary of Proposal 0 BOP Sketch o Exploratory g Development 0 Service o Detailed Operations Program 14. Estimated Date for JUna06 15. Well Status after proposed work: / Commencing Operations: g Oil o Gas o Plugged o Abandoned 16. Verbal Approval: Dafé: o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Na~e Doug Cismoski Title Drilling Engineer l"'\b../___ ~Æ1... h - ds>Æ. V. Prepared By Name/Number: Sianature Phone 564-4303 Date 'ð't 0(, Terrie Hubble, 564-4628 ~ ¿? Commission Use Only I l~ --- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: <.. . :'X R.. o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: T e-s t- ßOPf -to 3Soo p~,' . RBDMS 8Ft JUN 1 3 2006 Subsequent Form Required: tv - 40 rìj t, 1-/3,t;6 .....--1 ~ ~OMMISSIONER APPROVED BY Approved By: THE COMMISSION Date Form 10-403 Revised 07/2005 o RIG 1 N1\L "- Submit In Duplicate e e G PBU 18-01 A Rig Workover Scope of Work: Pull 5-1/2" completion, run 7" scab liner, run 4-1/2" 13Cr80 stacker packer completion. MASP: QpSi Well Ty~roducer Estimated Start Date: June 25, 2006 Pre-rig prep work: 0 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well is secured at this time with a TTP. PPPOT-T & IC. S 2 Drift thru 5-W' tubinq for Power-jet cutter and FasDril1. DONE 5/28/06 E 3 Set FasDrill in the middle of the first full joint above the packer, 9540' MD. Power-jet cut the 5- W' L-80 tubing in the middle of the second full joint above the Baker SAB packer. 9500' MD. Reference tubinQ tally dated 06/26/82. F 4 Circulate well with seawater and diesel thru the cut. CMIT TxlA to 3500 psi. M ITOA to 2000 psi. 0 5 Set a BPV in the tubing hanqer. 0 6 Remove the wellhouse & flow line. Level the pad as needed for the riq. Proposed Procedure / 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-1/2" tubing string to the cut. 3. Pressure test 9-5/8" casing to confirm Cretaceous leak. 4. If casing does not pressure test, run and cement 7" scab liner from top of 5-1/2" tubing stub to 4000' /' MD. 5. Run 4-1/2" 13Cr80 stacker packer completion with Baker S-3 packer. Set packer at -9350' MD. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. ./ 8. Set BPV. NO BOPE. NU and test tree. RDMO. TREE = ELLHEAé> = ACTUATOR = KB, ELEV = BF. ELEV = KOP= Max Angle = Datum MO = Datum1VO= FMC FMC e 46,0' 2800' 91 @ 10992' 11220' 8800' SS 113-3/8" CSG, 72#, L-80, 10=12,347" I Minimum ID = 2.372" @ 9643' 3-1/2" FL4S X 2-7/8" FL4S XO 15-1/2" TBG-PC. 17#, L-80, ,0232 bpf, 10 = 4,892" I 9593' 13-1/2" FL4S X 2-7/8" FL4S LNRXO, 10 = 2.372" I 9643' 14-1/2" TBG-PC, 12,6#, L-80, ,0152 bpf, 10 = 3,958" I DATE 06/27/82 02/10/96 09/13/03 05/19/06 OS/21/06 OS/21/06 9664' 19-5/8" CSG, 47#, L-80, 10 = 8,681" H 9917' PERFORA TION SUMMARY REF LOG: BHCS ON 06/23/82 ANGLEATTOPPERF: 81 @ 11058' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2-1/8" 4 11058 - 11078 C 03/23/00 2-1/8" 4 11 080 - 11100 C 03/23/00 2-1/8" 4 11134 - 11186 C 03/23/00 2-1/8" 4 11206-11218 C 03/23/00 I 7" LNR, 29#, L-80. 10 = 6.184" I 10905' REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CMO/TLP DATUM MO &ÆRF ANGLE JNA/PJC PULL IBP @ 9556' 1 FISH DTRlPJC FISH IBP ELEMENTS JRP/PJC PULL POGLM (12/21/99) SAfE1a:>TES: WELL ANGLE> 70° @ 10900' & > 90° @.78'. LEAK FOUND IN 9-5/8" CSG@ 6146' ON 04/01100. RSH @ 9582'SLM (LOWER POGLM). SEE TELEX OF 12/21/99. ONE TBG PUNCH HOLE FOR POGLM @ 3914'. 18-01A . -15-1/2" CAMCO BAL-O SSSVN, 10 = 4,562" 9566' -15-1/2" BAKER PBR ASSY I -19-5/8" X 5-1/2" BKR SAB PKR, 10 = 4.750" -15-1/2" X 4-112" TBG XO, 10 = 3,958" I 9640' -13.70" BKR G DEPLOYMENT SUB, 10 = 2,992" 9653' -14-1/2" CAMCO DB NIP, MILLED TO 3.80" 10 I 9665' -14-1/2" WLEG I 7" MILLOUT WINDOW 10630' - 10636' ( OFF CMT PLUG) NOTE ON 02/10/96 CTD HO, NOTE STATED 2-7/8" FC@ 11234' LEAKED. 11234' I 11240' I PRUDHOE BA Y UNIT WELL: 18-01A PERMIT No: "1960100 API No: 50-029-20752-01 SEC 24, T11 N, R14E, 1416' FNL & 101' FEL DA TE REV BY COMMENTS 05/27/06 RCT/PJC PULLED FISH (POGLM@ 9582') BP Exploration (Alaska) TREE = 8..LHEAV = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MO = DatumlVO= FMC FMC 18-~A Proposed Wor~ver 46.0' 2800' 91 @ 10992' 11220' 8800' SS 113-318" CSG, 72#, L-80, 10=12.347" I 17" CSG, 26#, L-80, 10=6.276", FULLY CEMENTED H -4000' I 14-1/2" TBG, 12.6#, 13Cr80, ,0152 bpf, 10=3.958" H -9580 I 15-1/2" TBG-PC, 17#, L-80, ,0232 bpf, 10 = 4,892" I 9593' 13-1/2" FL4S X 2-7/8" FL4S LNRXO, 10 = 2.372" 9643' 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9664' 9-5/8" CSG, 47#, L-80, 10 = 8.681" I PERFORATION SUMMARY REF LOG: BHCS ON 06/23/82 ANGLE AT TOP PERF: 81 @ 11058' Note: Refer to Production OB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2-1/8" 4 11 058 - 11078 C 03/23/00 2-1/8" 4 11080 - 11100 C 03/23/00 2-1/8" 4 11134 - 11186 C 03/23/00 2-1/8" 4 11206-11218 C 03/23/00 7" LNR, 29#, L-80,10=6.184" I 1 0905' OATE 06/27/82 02/10/96 10/10/01 09/13/03 REV BY COMMENTS ORIGINAL COMPLETION CTD SIDETRACK CH/KA K CORRECTIONS CMOITLP OA TUM MO &PERF ANGLE OATE REV BY - 4-1/2" HES HXO SSSV NIP, 10 = 3.813" GAS LIFT MANORELS MO lVD OEV TYÆ VLV LATCH PORT OATE 4-1/2" HES X NIP, 10 = 3,813" I 9-5/8" X 4-1/2" BAKER S-3 PKR, 10 =" I 4-1/2" HES X NIP, 10 = 3,813" I UNIQUE MACHINE OVERSHOT I 5-1/2" BAKER PBR ASSY I 9-5/8" X 5-1/2" BKR SAB PKR, 10 = 4.750" 5-1/2" X 4-1/2" TBG XO, 10 = 3,958" I -i 9-5/8" X 7" LNR HGR I 9640' -f 3.70" BKR G OEA..OYMENT SUB, 10 = 2.992" I 9653' 4-1/2" CAMCO DB NIP, MILLED TO 3.80" ID I 9665' 4-1/2" WLEG I 7" MILLOUT WINDOW 10630' - 10636' ( OFF CMT PLUG) NOTE: ON 02/10/96 CTO HO, NOTE STATED 2-7/8" FC@ 11234' LEAKED. 11234' I 11240' I COMMENTS PRUOHOE BA Y UNIT WELL: 18-01A PERMIT No: 1960100 API No: 50-029-20752-01 SEC24, T11N, R14E, 1416' FNL & 101' FEL BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED · ON :OR BEFORE JANUARY O3 2001 M PL A T-E E T W IA L UNDER H IS M A R K E R C :LOtCIXMFILM.DOC PERMIT 96-010 96-010 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS PERF RCD ~SEPIA I0©~- [Oq~O GAS LIFT MANDRELS/SEPIA 3700-4040 96-010 GR/ROP-MD 96-010 GR-TVD 96-010 7401 105905-11242 ~/8589-8809 ~~/~,2~ 4-7,9 10572-11215 Page: 1 Date: 02/25/98 RUN RECVD 1 06/07/96 1 07/12/96 FINAL 07/25/96 FINAL 07/25/96 09/03/96 10-407 ~R~-COMPLET I ON DATE DAILY WELL OPS R /13OP& I TO A1 q /¢~/ ~'/~olc~l ~ ©,,~_~ ~ (~ ~-00- /~ ~ 3/~/~ Are dry Gitch samples required? yes ~_ And received? y~--n~- Was the well cored? yes n~_~Analysis & description received? ~._D~ Are well tests required? yes Well is in compliance Inmtial COMMENTS ri I::! I I_1_ I IM G S I::: FIL/I C E S WEI,L LOG TRANSMIT'FAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - DS 18-0lA AK-MW-60019 September 03, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:! I L_I_I N G WELL LOG TRANSMITTAL To: State of Alaska July 25, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 18-0lA, AK-MW-60019 '- The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 18-0lA: 2" x 5" MD Gamma Ray Logs: 50-029-20752-01 2"x 5" TVD Gamma Ray Logs: 50-029-20752-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Schluml)?r_~er GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Shen'ie NO. 1O228 Company: Alaska Oil & Gas Cons Comm Attn: Howard Oakland 3001 Porcupine Drive Anchorage, AK 99501 6/6/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log l')escription Date BL RF sepia Survey Program Performance Disk Calculation Letter i'i.~'::. SIGNED: _ , ~.'I. DATE: ~!,,~ please sign and r~c~f this transmittal to Sherrle at the aboVe address. Thank you. . ,, · D'.s. 11-13A ~ ~1,~ 9614"-~- CNT-D - 960506 1 D,S. 3-33 # 7/~ 96,056 CNT-D _ 960214 1 D.S. 1~15A ----- PROD PROFILE 960515 I 1 .... D.S. 1-17A ~-'-'" TEMPERATURE 960505 I 1 , , D.S. 1-19 '-~ PROD PROFILE 960425 I 1 D.S. 2-2 ---~' PERFRECORD =960511 I 1 D~S. 2-4 ~ PERF RECORD 960507 I 1 D.S. 2-10 ~---~" PERF RECORD 960507 I 1 , , , __ D,S. 2-25 ~ PROD PROFILE 960427 I 1 D.S. 3-12 '""~ INJEC PR(')FILE 960501 I 1 , , D.S. 3-17 ~ INJECPROFILE 960501 I 1 , , D;S. 4-30 ST ~ CNT-D 96051 0 I 1 D'.S. 5-16A ~ TBG PATCH & POGLM 960426 I 1 D.S. 5-25 ~ DUAL BURSTTDT-P 960425 I 1 ,- D,S. 6-08A ",-~ PROD PROFILE 960424 1 1 D,S, 6-23 ~ PROD PROFILE 960424 I 1 D.S. 11-13A '-'"' CNT-D 960506 1 1 D.S. 11-23A ~ LEAK DE'rECTION 960506 I 1 D.S. 11-30 .-" PERF RECORD 96051 0 I 1 D,S. 15-39 ~ PROD PROFILE 960430 1 1 D.S. 16-5 ~ PERFRECORD 960504 1 1 D;S. 18-01 A ,--"'" PERF RECORD 960501 I 1 D.S. 18-34 ~ PROD pROFILE 960427 1 1 · ...'~ ~' ~ ,., I 1' ,'/ ..., :"~ ":, -__. STATE OF ALASKA _ --, ALASKA' .ND GAS CONSERVATION CC _SION REPORT ,JF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1416' FNL, 101' FEL, Sec 24, T11N, R14E, UM. At top of productive interval 743' FNL, 1117' FWL, Sec 30, T11N, R15E, UM. At effective depth At total depth 1529' FNL, 4049' FEL, Sec 30, T11N, R15E, UM. 5. Type of Well Development X Exploratory St ratigraphic Service 6. Datum of elevation(DF or KB) 46' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 18-01A 9. Permit number/approval number 96-10 10. APl number 50 - 029-20752-01 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11242 feet 8855 feet Effective depth: measured 11234 feet true vertical 8852 feet Casing Length Size Conductor 79.5' 20" Surface 2552' 13-3/8" Production 9871' 9-5/8" Liner 1036' 7" Liner 1602' 2-7/8" Plugs(measured) RECEIVED MAY 1 $ 199G Junk(measured) Alat~a~,~,~.o.C°mmi~'si°-n- - Cemented .~r~'~ '! rue vertical depth 2443 Sx Poleset 79.5 79.5' 1900 Sx Fondu & 400 Sx PFC 2598' 2598' 500 Sx Class G & 300 S× PFC 9917' 8131' 350 Sx Class G 10636' 8667 10.5 bbls Class G 11242' 8855' Perforation depth: measured 11058 - 11078'; 11080 - 11100'; 11134- 11186'; 11206 - 11218' true vertical 8799 - 8801'; 8802 - 8806'; 8813 - 8832'; 8840 - 8845' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9593' MD; 4-1/2", 12.6#, L-80, PCT @ 9665' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9582' MD; Camco Bal-O SSSV @ 2213' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 3202 0 577 1309 5 Tubing Pressure 477 5O4 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Servic.e 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~,x(/¢-~, ")V~. ~ Title Engineering Supervisor Date ,~5"'-- ¢- ~::2 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 18-01A CT PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 5/1/96' MIRU CTU & PT equipment. as follows: RIH w/CT mounted perforating guns & shot 40' of add perforations Added perforations: 11058 - 11078' MD (Zl) 11080 - 11100' MD (Zl) Ref. Log' BHCS 6/23/82. Used 2-1/8" carriers & shot 4 spf. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED Alaska Oil & Gas Cons. Oommis~ion Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F~ GAS E~ SUSPENDED E~] ABANDONED ~' 5--RVIOE 2 Name o! Operator 7 Permit Number ARCO Alaska. Inc 96-10 3 Address 8 APl Number P.O. Box 100360. Anchorage, AK 99510-0360 50-029-20752-01 4 Location et well at surface r_ : ........... .~ 9 Unit or Lease Name 1416' FNL, 101' FEL, Sec 24, T11N, R14E UM ; ~;~¢:,~i': ~. ', · : PRUDHOE BAY UNIT At Top Producing Inter~l i' ~/-~/~ ~ '"' .... ' ;i~,~.,~ ..... .. ~-. ,. 10 Well Number 743'FNL, 1117'~VL, Sec30, T11N, R15E UM : · ? -':- -- '.'-:'," 18-01A Depth .:~'__'~ ._ . . 11 Field and Pool At Total · 1529' FNL 4049' FEL Sec 30, T11N. R15E UM ..... : PRUDHOE BAY FIELD 5 Elevation m feet (mdic~.'e KB, DF, etc.) I 6 Lease Designabon and Serial N0~ ....... ' ' ' ...... PRUDHOE BAY OIL POOL 46' RKBI ADL 28326 12 Date Spudded 13 Date T.D. Reachea 14 Date Comp., Susc_ or Aband. I 15 Water Depth, if offshore 116 No. of Comp~e~ons 1/31/96. 2/6/96. 2/9/96.I N/A feet MSLI 1 17 Total Depth (MD+TVD~ 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 11242' MD/8855'TVD 11234' MD/8852"FVD YES ~ bO UI 2213' feetMD 1900' (approx) 22 Type Electric or Other Logs Run MWD Survey, GR. 23 CASING, LINER AND C~'MENTING RECORD SE-FrING DEPTH MD CASING SIZE vcr. PER FT. GRADE TOP BOTTOM J HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20" 91.5 # H-40 Surf 79.5' ; 30" 2443 sx Poleset 13-3/8' 72 # L-80 Surf 2598' i 17-1/2" 1900 sx Fondu & 400 sx PFC 9-5/8' 47.0 # L-80/S00-95 Surf 9917' !2-1/4" 500 sx G & ,.'.'.'.'.'.'.'.'.'~ sx PFC 7" 2'9.0 # L-80 9600' 10636' i 8-1/2" 350 sx Class G 2-7/8' 6.5# L-80 9640' 11242' i 3-3/4" 10.5 bbls Class G 24 Pedorattons open to P,-c~duction (MD+TVD of ToD and Bottom and !25 TUBING RECORD interval, s:ze eno numar) !SIZE DEPTH SET (MD) PACKER SET (MD) i 5-1/2" Tbg 9593' 9582' 11134-11186'MD(Z1); 8813- 8832' TVD; at4spf, i, ..¢-l/2"Tbcj 9665' 11206- 11218'MD(Z1); 8840-8845'7'VD; at4spf. 126 ACID, FRACTURE, OEMENTSQUEE. ZE, ETC iDEP'~- iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Product]on Method of Operation (Flowing. gas lift. e~.c.) 2__/26/96. Flowing. PRODUCTION Date of Test N~urs Tested FOR OIL-DEL i GAS-~¢CF WATER-DEL CHOKE SIZE GAS-OIL RATIO i , 2__/27/96. 4.4 iTEST PERIOD ¢ i 1868 FlowTubina c~smg Pressure i CALCULATED OIL-DEL iGAS~MCF WATER-DEL OIL GRAVITY-APl (corr) , Press 387 i24-HOUR RATE I~ 2 01 I 376 5 28 CORE DATA Bdet descnpuon of I~tholo¢'~_.. porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. "NOTE: see Coil Tu~'~ng Sidetrack Ddlling Operations Summary attached. = R~'6~iV~D MAR 2 0 1996 'NOTE: This CompeD:on Repodsubmitted as requffed per 10-401 (Permit # 96-10; LSSuea :'22/96) for CT Sidetrack. Form 10-407 Submit in duphce~e Rev. 7-1-80 CONTINUED ON I::IEVE]::~SE S~DE ~9, 30. I GEC~ N{~RI~,,_S FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, I~EAS. DEPTH TRLE VERT. DEPTH GOR, and time of each phase. ! I Top Sadlerochit 10173' 8314' N/A I I I I I ! t i31. UST OF A'I-rACHMENTS Summa~ of 18-01A Coil Tubin? Side~'ack Drilling 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ '~. ~ Title Engineering Super~4sor Date I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB. etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection. Shut-in, Other-explain. i~ E C E iV E D Item 28: If no cores taken, indicate "none". Form 10-407 MAR 2 0 1996 18-01A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 1/30/96: Milled a pilot hole through the cement plug to 10630' MD. POOH w/milling BHA. milling BHA. Milled a window through 7" liner from 10631' to 10635.8' MD. formation to 10640' MD. Backreamed window. MU & RIH w/window Continued drilling 1/31/96: Backreamed window & circulated 30 bbl biozan pill. POOH w/window mill. MU & RIH w/drilling BHA. Couldn't pass BHA through window; POOH w/BHA. MU & RIH w/BHA. Drilled 3.75" sidetrack hole to 10654' MD. Backreamed & POOH w/BHA. MU & RIH w/drilling BHA. Tagged bottom at 10654' MD & swapped openhole to FIo-Pro. PU above window & pressured to 450 psi for leakoff test (SW in annulus above window); no leakoff. 2/1/9 RIH to w/BHA. 6.' resume drilling & circulated well to FIo-Pro. Drilled build to 10812' MD. MU & RIH w/drilling BHA. Drilled to 10884' MD. CBU & POOH w/BHA. Circulated OOH 2/2/96: MU & RIH w/drilling BHA. Drilled to 11098' MD & crossed fault. PU into liner & circulated. Pumped 25 bbls liquid casing pill to slow 30-40 bph LC to 15-20 bph. Pumped another 25 bbls liquid casing pill; got loss to 0 - 6 bph. Squeezed LCM w/400 psi ECD & RIH to drill. 2/3/96: Continued drilling to 11200' MD with 10 bhp loss. Pumped 15 bbl LCM pill & squeezed at 475 WHP. No mud loss; resumed drilling to 11228' MD. PU above window & pumped 17 bbls liquid casing pill. POOH w/BHA. RD CTU for reel changeout. 2/4/96: Standby for reel changeout. 2/5/96: Changed out CT. Wait on weather. 11235' MD. POOH w/BHA. MIRU CTU. MU & RIH w/drilling BHA. Resumed drilling to 2/6/96: MU & RIH w/drilling BHA. Drilled to TD at 11242' MD. Circulated Hi-Vis sweep. POOH w/BHA. MU & RIH w/2-7/8" liner assembly. Landed liner at 11242' MD. Released from liner & POOH. 2~7~96: RIH w/cement stinger & stung into liner top at 9640' MD. POOH displacing well to Seawater. RIH w/nozzle. Pumped 10.5 bbls Class G cement to set liner. 2/8/96: Jetted cement from liner w/biozan. POOH & displaced well to Seawater. WOC. MU & RIH w/perforation guns to ',"ag float collar. PU to 11219' & PT TOL/cement to 1000 psi; had 0.6 bpm/1000 psi leak. POOH w,:-Derf guns. RIH w/stinger & stung in TOE PT at 1000 psi to verify liner leak; backside PT at 1000 psi held solid. 2/9/96: POOH w/seal assembly to perforate. perforations at: MU& RIH w/perforation guns to tag float coll~ E CI~ ~¢~_ i~tial 11134 - 11186' MD (Z1) MAR 2_0 199~, 11206 o 11218' MD (Zl) Alaska 011 & ~s C~n~. C0mrnis~ion Used 2-1 8" carriers & shot all perfs at 4 spf at 0 degree phasing. POOH & LDperf gun~ncll(~ w/nozzle & displaced well to Crude while POOH from TOL. Set BPV. RD & MO CTU. ~._.~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/18-!A 500292075201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/96 DATE OF SURVEY: 020696 MWD SURVEY JOB NUMBER: AK-MW-60019 KELLY BUSHING ELEV. = 46.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB - SEA MEASD VERTICAL VERTICAL DEPT~ DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREF. S DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10500.00 8562.50 8516.50 39 54 S 8.80 E .00 4817.90S 1244.60E 10630.00 8662.23 8616.23 39 54 S 8.80 E .00 4900.315 1257.36E 10636.00 8666.77 8620.77 41 47 S 8.80 E 31.67 4904.185 1257.96E 10647.92 8675.39 8629.39 45 34 S 8.80 E 31.63 4912.325 1259.22E 10660.84 8684.04 8638.04 50 16 S 8.80 E 36.38 4921.795 1260.68E 4965.27 5048.61 5052.53 5060.76 5070.34 10675.47 8693.04 8647.04 53 52 S 7.31 E 25.95 4933.225 1262.30E 10689.44 8700.99 8654.99 56 46 S 2.21 E 36.49 4944.665 1263.24E 10705.97 8709.80 8663.80 58 47 S 1.48 W 22.49 4958.645 1263.32E 10720.44 8716.93 8670.93 62 8 S 4.64 W 29.89 4971.215 1262.65E 10736.72 8724.05 8678.05 66 0 S 8.68 W 32.56 4985.745 1260.94E 5081.87 5093.29 5107.04 5119.26 5133.22 10749.47 8729.06 8683.06 67 45 S 9.39 W 14.72 4997.325 1259.10E 10768.99 8736.45 8690.45 67 45 S 14.66 W 24.99 5014.995 1255.34E 10800.94 8748.57 8702.57 67 45 S 24.33 W 28.01 5042.825 1245.48E 10825.24 8757.98 8711.98 66 42 S 30.83 W 25.04 5062.675 1235.12E 10854.34 8769.17 8723.17 68 1 S 31.54 W 5.06 5085.655 1221.21E 5144.26 5160.92 5186.44 5204.01 5224.00 10879.27 8778.57 8732.57 67 40 S 28.90 W 9.91 5105.595 1209.59E 10912.24 8788.69 8742.69 76 32 S 29.26 W 26.89 5132.995 1194.36E 10945.67 8793.79 8747.79 85 52 S 29.43 W 27.91 5161.755 1178.18E 10978.14 8794.77 8748.77 90 41 S 37.16 W 28.06 5188.855 1160.38E 10991.82 8794.49 8748.49 91 34 S 41.73 W 34.01 5199.415 1151.70E 5241.44 5265.53 5290.79 5314.10 5322.87 11011.82 8794.33 8748.33 89 22 S 49.11 W 38.50 5213.44S 1137.46E 11035.12 8795.65 8749.65 84 6 S 54.74 W 33.06 5227.775 1119.17E 11067.74 8800.41 8754.41 79 5 S 49.47 W 22.16 5247.57S 1093.71E 11100.09 8806.28 8760.28 80 4 S 38.39 W 33.82 5270.455 1071.68E 11129.79 8812.42 8766.42 76 6 S 28.55 W 35.04 5294.655 1055.66E 5334.00 5344.69 5359.41 5377.80 5398.60 11160.57 8821.84 8775.84 68 17 S 19.76 W 37.19 5321.315 1043.65E 11191.67 8834.06 8788.06 65 28 S 12.73 W 22.66 5348.755 1035.63E 11221.54 8846.63 8800.63 64 46 S 6.75 W 18.31 5375.44S 1031.05E 11228.27 8849.48 8803.48 65 12 S 7.98 W 17.76 5381.495 1030.27E 11242.00 8855.14 8809.14 66 4 S 10.40 W 17.23 5393.835 1028.27E 5422.57 5448.03 5473.41 5479.20 5490.96 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVA~ METHOD. HORIZONTAL DISPLACEMENT = 5490.97 FEET AT SOUTH 10 DEG. 47 MIN. EAST AT MD = 11242 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 169.29 DEG. TIE IN POINT 10,500' WINDOW POINT 10,636' INTERPOLATED DEPTH 11,242' RECEIVED' MAR 2~ 0 1996 oPERRY-SUN DRILLING SERVIL~ ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING PBU/18-1A 500292075201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/96 DATE OF SURVEY: 020696 JOB NUMBER: AK-MW-60019 KELLY BUSHING ELEV. = 46.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10500.00 8562.50 8516.50 11242.00 8855.14 8809.14 4817.90 S 1244.60 E 1937.50 5393.83 S 1028.27 E 2386.86 449.36 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ERRY- SUN DRILLING SERVICL ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING PBU/18-1A 500292075201 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/26/96 DATE OF SURVEY: 020696 JOB NUMBER: AK-MW-60019 KELLY BUSHING ELEV. = 46.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTAN~ COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10500.00 8562.50 8516.50 10608.84 8646.00 8600.00 10794.17 8746.00 8700.00 11220.05 8846.00 8800.00 4817.90 S 1244.60 E 1937.50 4886.90 S 1255.28 E 1962.84 25.34 5037.00 S 1247.77 E 2048.17 85.33 5374.10 S 1031.21 E 2374.05 325.88 11242.00 8855.14 8809.14 5393.83 S 1028.27 E 2386.86 12.81 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN TltE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D !::! I I--I_ I IM G c: ~:: I::1 L/I r' E S February 22, 1996 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: Survey Data 1-17A, 7-6A, 15-42, 18-lA Dear Mr. Grant, Enclosed are two hard copies of the above mentioned file(s). Well 1-17A Well 7-6A MWD survey, tie in point 9400', window point 9416', interpolated depth 10345' MWD survey, tie in point 9200', window point 9253', interpolated depth 10123' MWD survey, surface to 10048' MWD sm~ey, tie in point 9542.86' kickoff point 9550', interpolated depth 9851' MWD survey, tie in point 9737.1', window point 9769.59', interpolated depth 9884' Well 15-42 MWD survey, tie in point 9737.1, kickoff point 9755', interpolated depth 11590' Well 18-lA MWD survey, tie in point 10500' window point 10636', interpolated depth q ~ ~' {0 11242' Please call me at 563-3256 if you have any questions or concerns. n Dept. Specialist Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company OIL AND GAS CONSERVATION CO IISSIO TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 22, 1996 Jim C. Abel, Engineering Supe,misor ARCO Alaska. !nc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 18-01A ARCO Alaska, Inc. Permit No 96-10 surf Loc ' 1416'FNL, 101'FEL, Sec. 24, T11N, R14E, UM Btmhole Loc 1511'FNL, 913'FWL, Sec. 30, T11N, R15E, UM Dear Mr. Abel: Enclosed is the approved application for permit to re-ddil the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must 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 a new hole. Notice may be given ~ ~leum field inspector on the North Slope pager at 659-3607. David W. Jbh~nston ~ ~ Chairman ~ BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o end STATE OF ALASKA ALAbKA OIL AND GAS CONSERVATION COMMI,b,.,~ON PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill _ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test . Development Oil .~_ Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone x__ Multiple Zone. 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 46' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28326 Prudhoe Bay/Prudhoe Bay Oil 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1416' FNL, 101' FEL, Sec 24, TllN, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 743' FNL, 1117' FWL, Sec 30, T11N, R15E, UM. 18-01A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 1511' FNL, 913' FWL, Sec 30, T11N, R15E, UM. January, 1996 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line No Close Approach 11240' MD / 8926' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 10630' MD Maximum hole angle 68° Maximum surface 2800 psig At total depth ITVD) 3500 psi~l 18. Casing program Setting Depth size Specification Top Bottom Quantily of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta(~e data) 3-3/4" 2-7/8" 6.4 LB0 FL4S 1640' 9600' 7915' 11240' 8926' 10 bbls '~'9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10905 feet Plugs(measured) PBTD tagged at 10853' MD (5/16/94). true vedical 8879 feet Effective depth: measured 10853 feet Junk (measured) true vertical 8838 feet r.~ Casing Length Size Cemented Measured depth True Vedical depth Conductor 79' 20" 2443 # Poleset 79' 79' -~r Surface 2552' 1 3-3/8" 1900 Sx Fondu & 400 Sx PFC 2598' 2598' o...~ ©~'b' -'---~ ~.~. Production 98 71 ' 9- 5/8" 500 Sx CIG & 300 Sx PFC 9 91 7' 81 3 0' ~:~'~ ~-~ r-,o Liner 1305' 7" 350 Sx CIG 1 0905' 8879' ~ ¢.~ ,?' Perforation depth: measured 10765 - 10814' , , true vertical 8768 - 8807' ::~ 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~x Diverter Sketch_ Drilling program ~ Drilling fluid program ~ Time vs depth plot _ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21 . I hereby certify that the foregoing is t~-a~d~ correct to the best of my knowledge :igned ~~'~ ~''~' Titlle Engineering Supervisor Date/ ~ r.~ ~;5~ I Commission~Use Only APl number Approval date See cover letter for ermit '"/O 50- O2_.-~'"' ~..4:~ ~',.~.~.-<:::3 /----' '~,'"~..,.----~'(_~ other re(~uirements Conditions o~f approval Samples required ~Y e s~ N o Mud log required ~ 'Y e s ~ N o Hydrogen sulfide measures ~ Y e s ~ N o Directional survey required /~'Yes __ N o Required working pressure for BOPE __2M; ~ 3 M · ~ 5 M ' ~ 1 OM' ~ 1 5 M T_~ 3500 psi for CTU Other:drigina! Signed 8y David W. Johnston by order of Approved by Commissioner the commission Date / -- 'Z,,,'7....-~7 (7' Form 10-401 Rev. 7-24-89 Submit in triplica DS 18-lA CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a high angle twin well from the existing wellbore. Complete with 2-7/8" cemented liner. Intended Procedure: Cement squeeze the current perforations and plugback the existing completion to -- 10590' md. Mill window in 7" casing at ~10630' md. Drill 10' of formation and perform a formation test to an equivalent mud weight of at least .5 ppg over the highest anticipated mud weight. Build angle to 68° at 31°/100' to TD. Directionally drill twin well to access Zone lB reserves. Run and cement 2-7/8" liner to TD. Perforate selected intervals. Return well to production. January 9, 1996 18-01 Well Plan revision I Jan. 9, 1995 18-01RI~V MD INC DIR SS Depth NI{-S) E/(-W) VS D'LEG BUILD TURN ASP Y It deg deg fl fl It ft ell00 e/100 ell00 10500.0 39.9 171.2 8516.5 -4817.9 1244.6 4965.3 0.0 0.0 0.0 5955665.5 10600.0 39.9 171,2 8593.3 -4881.2 1254,5 5029,3 0.0 0.0 0.0 5955~02.5 10630.0 39.9 171.2 6616.3 -4900.2 1257,4 5048.6 0.0 0.0 0.0 5955583.5 10700.0 56.7 189.7 8862.9 -4951.9 1255,9 5099.0 31,0 24.1 26,5 5955532.0 10742.8 68.0 197.6 8882.7 -4988.6 1246.8 5133.4 31.0 26.4 18.4 5955495.0 10800,0 68.0 197,6 8704.2 .-5039,1 1230.8 5180,1 0.0 0,0 0.0 5955444.0 10815.0 68.0 197,6 8710.0 -5052.9 1226.4 5192.8 0,0 0.0 0,0 5956430.0 10900.0 67.0 204.8 8742.3 -5125 8 1198.2 5259,0 8,0 -1.2 8.6 5955356.5 11000.0 66.2 213.5 8782.1 -5205.6 1153.6 5329,3 8.0 -0.8 8.7 5955275.5 11081.2 66.0 220.6 8815.0 -5264,8 1108,9 5379.2 8.0 -0,3 8.7 5955215.0 ASP X Comments ft 693037.9 Tie in Point Actual 693049.4 6930529 KOP, Start Build 693052.7 693044.6 093029.9 603025.9 Clear Fault 692999.6 (Berlin orient to TO) 692957.1 692913.9 Highest Parrs. 11100.0 66.0 220.6 8822.7 -527'7,9 'lOg?,7 5389.9 0.0 0.0 0 0 5955202,0 692903,1 11200 0 00,0 2.20.0 8863,4 -5347,2 1038,3 5441.0 0,0 00 0.0 5955131 0 602845 6 11240,8 68.0 220.8 8880.0 -5375.5 1014.0 5470.3 0.0 0.0 0.0 5~)55102,0 692821,9~D IIJ _J H Lt_ Notes: 1. Magnetic Declination to b~ applied is 29.75 deg. lo Irue North/Grid convergence is 1.46 (leg. 2 ASP coordinates are relative off Grid North, wellplan is designed to meet target objectives based off of Grid norlh 3. Vertical section plan used is 169,29 rotated lo True Nodh. Drilex Pagers and Phone Numbers Slope 907-659-3649 pager ~ u:~ '~_ Anchorage 907-562-3312 Off 800-569-3363 Toll Free ",,~ Brian Blngham Bimo Hedtputro L·) DRILE . ARCO ALASKA INC. lB-lA SIOEIRACK O0 HORIH StOlE ~ BAY NORTH REL. TO TRUE N. ZI lDue ( ,y~ Mag (+29,75) Plan In TN 16-0100 , Or, igt~l veil in IN 8000 ..i. 8400 - 8516.5 SS -- 8616.3 SS 8710.D SE; -- 880O---:- 8615.0 (]S 92O 4~5.3 5m8.6 VS 5379.2 Vi; /ne ie In Point 10500 MD 39.9' 31'/100 TI' 46. l' KOP 10630 MO 39.9' ~ld 10742 MO GS' 4 01 8'/100 If 100' 10815 MI) BI)' Hold 11~1 Im 66' ,'NT0. :) V$ 11740 Ill} Vel,!ical Sec| ion , Scale I inch: 400 ft PLANE OF VERT SECTH 169.79" Rotat. ed to l'Pue E/W Scale I Inch : 4DO fi ~-4800 -- ',,---4 = Nor, th Shop Fuel Water Boilers Mu( 60/40 J Pump Room Pipe rack Preferred Major Equipment Layout for CT Drilling in DS 18-1A Dowell Drilling Equipment Trailer C T Drilling Wellhead Detail ~ CT Injector Head 5-1/8' ID CT BOP Stack Flanged Rna 1R~0'~30ant~' Working Pressure~' Keay Hose To Dual \ ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure co.,~-~ II II 2' Pump-In ~= Cutters or Combination Cutter/Blinds / Driang spool 7-1/16', 5M by 5-1/8', 1 OM Annuba' BOP (H~dl),7-1/16' ID 5,000 psi worldng pressure Allgnmont Guido Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams o.4sa' ($.s') ]1[ Manual Ma~ter Val~e ManuaJ Valves (3-1/2' Valve~) from GL to top of MV ~.Tubing Hanger 9-5/8' Annulus ~Fire Resistant Kelly Hose to Flange Dy Hammer Up 1/4 Turn VaNe on DS Hard,ne 10' from Tree 13-3/8' Annulus DS 18-1A PROPOSED CTD COMPLETION 2213' 5-1/2" Tubing 5-1/2" Camco Bal-O SSSV Nipple (4.562" ID) 5-1/2" PBR 9-5/8" SAB Pkr. 7" liner top @ 4-1/2" DB-6 nipple 3.687" ID 4-1/2" Tubing tail 9-5/8" Casing Shoe @ 9~66' 9582' 9600' 9653' 9665' 9917' 4-1/2" GS FN on top of liner @ _+9600' Window Cut in 9-5/8" casing with CT, ~ 10630 - 10635' 3-3/4" Open hole 2-7/8" FL4S liner Original perforations cement sqz'd. TD @ _.+ 11240' 7" Liner Shoe @ 10905' STATE OF ALASKA · ALASKA £ AND GAS CONSERVATION COk 'SSION APPLICATION FOR SUNDRY APPr{OVALS 1. -Type of Request: Abandon X Suspend OperalJon shutdown Alter casing Repair well Plugging X Change approved program Pull tubing Re-enter suspended well Time extension SlJmulate Vadance Pedorate 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1416' FNL, 101' FEL, Sec 24, T11 N, R14E, UM. At top of productive interval 743' FNL, 1117' FWL, Sec 30, T11N, R15E, UM. At effective depth At total depth 1202' FNL, 1192' FWL, Sec 30, T11N, R15E, UM. Other 6. Datum of elevation(DF or KB) 46' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 18-01 9. Permit number 82-80 10. APl number 50 - 029-20752 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10905 feet 8879 feet Plugs(measured) PBTD Tagged @ 10853' M D (5/16/94) Effective depth: measured 10853 feet true vertical 8838 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 24434¢ Poleset 79' 79' Surface 2552' 13-3/8" 1900 Sx Fondu & 400 Sx PFC 2598' 2598' Production 9871' 9-5/8" 500 Sx CIG & 300 Sx PFC 9917' 8130' Liner 1305' 7" 350 Sx CIG ~,. _ __. ____._,1.Q905' 8879' Perforation depth: measured 10765- 10814' JAN 0 4 true vertical 8768 - 8807' /~,,o:~a ~! & C--a-~ Cons. Tubing (size, grade, and measured depth) 5-1/2", 17~, L-80, PCT ~ 9593' MD; 4-1/2", 12.~, L-80, PCT ~ 9665' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9582' MD; Camco BaI-O 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, 1996 16. If proposal was verbally approved Oil X Gas Suspended Name of al)prover Date approved Service 17. I here~y~ify thole for~d correct to the best of my knowledge. Sig~,,_/~'~/'''-'' - Title Engineering Supervisor Date FOR COMMISSION U~l= ONLY Co~i~ns of approval: Notify~Commission so repr.~esentative may witness Plug integrity /,," BOP Test ~ Location clearance Mechanical Integrity Test Subsequent form required 10- Original Signed ~:~, David W. J0hnst0~ Approved by order of the Commissioner I Approval No. ~, ... ~ O~ fi2pro~ved Copy _./'//~7~ u~ed Commissioner Date ///~0//~~'~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SLW cc: KZ. JWP. PERMIT CHECKLIST co~m~Y INI~ CLASS PROGRAM: exp [] dev [], redr~/~ aery [] w uNI~# //~p~ ON/OFF SHO~ ~ ADMINISTRATION ENGINEERING 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............ N 5. Well located proper distance from drlg unit boundary. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ...... ] i ] i ~ ] ] N 10. Operator has appropriate bond in force. N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. -I N 13. Can permit be approved before 15-day wait ....... N REMARKS 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 abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~ pstg.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~ 31. Data presented on potential overpressure zones ..... Y/N /~,w' ~~j~ 32. Seismic analysis of shallow gas zones ......... / N ~ 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . .~.. Y N [exploratory only] cheklist GEOLOGY: rev 11195 ENGINEERING: COMMISSION: Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. HIdSQ HHI SI DO~ SIHi S~ HNO~ S~M ~NII~IHS HidH~ ON 0'E~EII 0~t'£ 0'0590I 008'£ 0'I£90I 000'£ 0'£I66 SE9'6 (ma) Hma~ (~) SZZS (~Z) SZ~S iIS SH~qqIH~ ONIS~D ~qOH N~O 00'99 I0I 9IPI bIII. xa~oo~/ss~s NO,L~MIHJ. HOM :SHHk~4~H ©MI~S MOI~DQ~O~d ONI~IS QME DNI~iS ~MODMM DMIS~D :q~AM~ ~N/iOHD :HOOqM MDIHH~ :OMIHS~ (0 qS~ ~OH~ ~)NOI£~A~ :qM~ :~S~ :dIHSNMO~ :NOIID~S NOIi~DOq ~D¥~%LrlS :SS~NIIM :M~MION~ OMI~OOq 6 NIIM (/MN anH/SSW NI-l%f D ' E anH/sS~fS NHlf£ ' ~ 9 N/1H aanH/ssvs S N/IH :SSMNIIM HO£k~H~aO :HMMMIONM ONIOOOq aanH/SS~ NI-r~D ' ii aana/ss~ g bLrl~{ (/MN 96-On~-LE SMDIAMMS ONIqqIMG N/IS-AEHMdS 'DMI krHSlf~l~f OOR-~f IOES£0E6E00S ~I0-8I 'S'~ aanH/SS~ 61009 M~ A~f I N/IH (IM/4 :SSMM£IM HO£k~t~60 :H~MMIOM~ ONI©OO% :A_N-tfdNOD OMIOOOq :MMMWIIM Id~ s~o~ ~¢~/z~ liN/1X~ ~OH~/1Hd REFeREncE FOR THIS WELL (PER DICK OWENS, ARCO). ~mE 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 GR 10572.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 11215.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 10595.0 10630.0 10630.0 10639.0 10639.0 10650.0 10650.0 10814.0 10814.0 10884.0 10884.0 11224.0 11224.0 11242.0 MERGED MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 16 s~Aq 5IOI s~Aq ~9 :q~6usI p~ooe~ mnmTxeM :q~BusI p~ooe~ mnmTuiM smn~p PgOP 89 :spoo :Xz~mmns 6uipoosp spoo uoi~ussszds~ SI% O0000S'O = 5u!o~dS I~AS% sII~ ~d~i O00000'E£SOI = q~de~ pu~ eIT~ ede~ O00000'~PEII = q~d@~ ~2S ~TT~ : (MI) .~.~Og/~f£S '-ZOO.T, 000 ' 00' :(MI) MOIIOZHHOO ZqOH :XIML~f~ ~OOL NO~iOZM 0' 000' 0' 000' I'0SI 000' 0' 000' . 0 O' O' 00' N~fZOI~/~I~M~S 0'I590I 008'5 : (i.~) HidH~ ~NIS%fD S,%tZTII%t~I :(MI) ZZIS .l.I~t Z~IOH MZdO ~fi~f~ ~MIS~fD fIN-~ Z~IOHZHO~ ZdX.l, ~IO0.1, .~(~OD ~IO0,L %t0~MZA (MOiiOS Om dOll,) DMI%tIS ~IO0.L O'OP 6'65 0 0'0590I 0'S6~0I 0'0590I IS0'E 96 -N'¢'£- 05 0'9090I HIdZG dOIS 'SeIT~ eqe~edes uT un~ qlq qoee ~o~ eqep ~epeeq BoI pue se~no GMI4 MlfH SI~ :scL4~ sT 5 eIl~qns ed'- CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-01A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 2 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4. 90 810 01 1 Tape File Start Depth = 10635.000000 Tape File End Depth = 10572.000000 Tape Fil~e Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 382 datums 65 records... 62 bytes 1014 bytes 0 0' :(ZH) xsM,~n0,~,~ ~4,~ : (MI) .~.40gNlfJ. S 000 ' 00' : (MI) MOI£OH~OO H~OH :XIISM~ ~OOi NO~J~'l~M ' 000 ' ' 000 ' 'LEI 000' ' 000 ' . 0 0' 0' 00' N~fZOI~/~I~M~S 0'I£90I 008'£ : (3..~) H.I. dHG OMISIfD S,%{.~IqlHG : (MI) HZIS IlS .~IOH MHdO tf.l.tf~ ONI SIfD ~N-lf ,~iOH~{%:IO~t 8£ ~8WflN ~OOi ~dX.l. qOOJ. .~GOD qOOJ. (NO£10S 0£ dO£) DMI~IS ~OOi 6'6£ 6'6£ 0 0'6£90I 0'0£90I 0'6£90I I~0'E 96-N~fD-I£ 0'91901 'Sall~ a~dss uT un~ ~Iq qo~s ~o~ ~p ~sp~aq 5oi pu~ ssA~no GMH M~ £ :HH~Hf]_M HqI~ SI~ :~ctX~ sT ~ Sll~qns ad~ CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-0lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 978 BYTES * Tape File Start Depth = 10640.000000 Tape File End Depth = 10600.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4268 datums Tape Subfile: 4 64 records... Minimum record length: 62 bytes Maximum record length: 978 bytes ape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10614.0 $ 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 10633.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 01-FEB-96 1.32 2.041 MEMORY 10650.0 10639.0 10650.0 0 39.9 42.1 TOOL NUMBER NGP 110 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.800 10631.0 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 CIRC~TING TEMPERATURE: MUD FILTRATE AT MT: MI/D CAKE AT MT: SEAWATER/BIOZAN .00 .0 .0 0 .0 .000 .0 .000 150.1 .000 .0 -. .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 4. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-0lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES Total Data Records: 2 API API API API Lo9 Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 10660.000000 Tape File End Depth = 10610.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 686 datums Tape Subfile: 5 65 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes 000 ' 00' : (~) NOTiO.~OO ,~qOH : XIISN,~G : XIII,TAfI4 ~O0.T, , O' 5 'L£I O' 000 ' 000 ' 000 ' 000 ' ~,-c3 000£~ S'6 O' 06'8 O%tcI - Oq,~ 0 'I£90I 0SA' £ : (i,~) HLdZ~ ONIS~fD S : (NI) ZZIS iI~ Z~IOH NZdO ~fi~f~ ~NIS~fD ~ Z~IOHZ~O~ 0II d~N ~ZSWi1N ~00~ ZdX,I. qOOJ, ZGOD ~IO0,1. (NOLLO~ OJ. dOi) DNI~LS 0'89 9'S~' 0 0'~I80I 0'0S90I 0'~I80I I~0'E 96-~Z~-I0 0'I6LOI HLdZ~ dO£S SI% :aclKq sT 9 ~IT~qns adP' s~Aq 9IOI s~Aq ~9 :q~6usI p~oDs~ mnm~x~ :q~6usI p~oDs~ mnm~u~ · ''sp~oos~ 89 9 :~T~qns smn~p E~ 89 :~poD d~ :A~mmns Buipoo~p spoo uoy~uss~ds~ SI% O0000S'O = Bu!oeds I~A~% ~IY~ sdeL O00000'SE90I = q~d~ puz sII~ ~d~L 000000'0~80T = q~d~G ~S ~II~ ~d~ I0 018 06 ~ I0 0I£ 06 ~ 5 ~Hd~ I 89 ~ dOH E 5 Idlftf I 89 ~MI4 HD I pOM sIO clK£ clXL q~6ua% szIs Id~ IdW Id~ Id~ s~Iu~ ssIdm~s spoo IOOL :s~A~no E ~ :~I q~dsp sdei ZW~-~ ~Zd H£dZ~ ZNO tf~S~ : ZdO%S HLHON : X~ ZOH~flHd : ~I0-SI 'S'~ : 'OMI 'lf){S~ OOYtf : .¢ NIiOD N~ NM ND ,ape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10791.0 $ 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 10857.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 02-FEB-96 1.32 2.041 MEMORY 10884.0 10814.0 10884.0 0 66.7 68.0 TOOL NUMBER NGP 38 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.750 10631.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MIID VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 8.90 .0 9.4 43000 5.4 .000 .000 .000 ,000 .0 133.2 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 REMARKS: MWD RUN 6. ss~Aq ~IOI :q~6usI p~oosx mnm~x~M ss~Aq E9 :q~BusI p~ou~ · ''sp~oo$~ 99 L :sI~gqns smn~p 08£I 89 :~poD :A~mmns 6u~poo~p ~poo uo~u~s@~dsx 00000~'0 = 6u~o~dS I~AS~ sIT~ 000000'~8£0I = q2ds~ pu~ ~I~ 000000'0060I = q~d~ ~S ~I~ I0 018 06 ~ I0 0I£ 06 ~ 9 HHd~ I 89 GMI4 dOH ~ Id~f%f I 89 GMAI ~ po~ SlO dXi cL~i q~Su~q sz!s A~D A~D s~u~ s~Idm~S spoo IOO£ sm~M :s@A~nD ~ ~ :GI q~dap sd~i ~Z S~-q~f : ZdO~IS H,I,~ON : X~f~ ZOHg//Hd : ~fI0-8I 'S'G : · 0MI '~S~I~f OOkKf : NDOD NM ND ~ape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10858.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 11204.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 04-FEB-96 1.32 2.041 MEMORY 11224.0 10884.0 11224.0 0 65.5 91.6 TOOL NUMBER NGP 38 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.750 10631.0 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.1 42000 5.6 .000 .000 .000 .000 .0 137.5 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 REMARKS: MWD RUN 7. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-0lA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 10 Tape File Start Depth = 11230.000000 Tape File End Depth = 10850.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7726 datums Tape Subfile: 8 73 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~ape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11204.0 $ 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 11215.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 06-FEB-96 1.32 2.041 MEMORY 11242.0 11224.0 11242.0 0 65.0 65.2 TOOL NUMBER NGP 38 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 10631.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OH.MM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 9.0 39000 .0 .000 .000 .000 .000 .0 137.5 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 REMARKS: MWD RUN 9. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 18-0lA : PRIIDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 11242.000000 Tape File End Depth = 11200.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1636 datums Tape Subfile: 9 Minimum record length: Maximum record length: 65 records... 18 bytes 1014 bytes -£ape Subfile 10 is type: LIS 96/ 8/27 01 **** REEL TRAILER **** 96/ 8/27 01 Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 27 AUG 96 5:10p Elapsed execution time = 1.15 seconds. SYSTEM RETURN CODE = 0
