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190-051
STATE OF ALASKA „ t t .1,y„ AL A OIL AND GAS CONSERVATION COMM' )N 1 a ; e- . REPORT OF SUNDRY WELL OPERATIONS :; 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U ¢ ti Performed: Alter Casing ❑ Pull Tubing❑ t Stimulate-Frac ❑ Waiver ❑ Time Extensions '" Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Others Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Developments Exploratory ❑ ` 190-051-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22040-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: • ADL0028346 ' PBU 16-22 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 14238 feet Plugs measured None feet true vertical 9204.75 feet Junk measured See Attachment feet Effective Depth measured ` 14148 feet Packer measured See Attachment feet true vertical 9135.75 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 32-112 32-112 1490 470 Surface 4319 13-3/8"68#L-80 32-4351 32-3495.76 5020 2260 Intermediate None None None None None None Production 13914 9-5/8"47#L-80 30-13944 30-8978.99 6870 4760 Liner 641 7"29#L-80 13598-14239 8724.06-9205.52 8160 7020 Perforation depth Measured depth 13992-13993 feet 13993-14002 feet 14002-14007 feet 14007-14012 feet 14016-14024 feet 14028-14030 feet 14030-14040 feet 14050-14060 feet 14060-14068 feet True Vertical depth 9015.88-9016.65 feet 9016.65-9023.59 feet 9023.59-9027.45 feet 9027.45-9031.3 feet 9034.38-9040.55 feet 9043.63-9045.17 feet 9045.17-9052.86 feet 9060.55-9068.24 feet 9068.24-9074.39 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): 13992'-14012',14016'-14024', 14028'-14040', 14050'-14068'. SCANNED JUN 201 RBDM MAY 16 2014 Treatment descriptions including volumes used and final pressure: 77 Bbls 12%HCL Acid,0 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 739 146 4017 1854 350 Subsequent to operation: 442 12 4015 1882 355 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator$U Development s. Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil •Q Gas U WDSPIU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 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 Garry Catron Email Garry.Catrona.BP.Com Printed Name Garry Catron Title PDC PE Signatureyli Phone 564-4424 Date 4/17/2014 A VLp .J h211ei-- Form 10-404 Revised 10/2012 Submit Original Only 16-22 190-051-0 Junk Attachment SW Name MD _ Date Description 16-22 14060 2/21/2009 FASDRILL Plug 16-22 14088 3/17/1993 MC-VR STD RK GLV cc N W c m o a Sa Qpm Q Q.a M 4) U) Y Y 03 mm r r V V' CD (1) '0 N cn O Cl) J a M 0 '- ') -be 2 M V r r a O. Y �U Q Q as as 15 zCO (0 WI 1 en• 00000.0 • 0 N g-). CD 0 0 O N LO LO V 4g OO) CO O- NM s m — 03 CO LL) CO CO N 0) CD 0) N LO O) I-- O) O) • iocoLr) MI.C) N O0) CD r-- O) CO M co co 0 CD U) O O) N O N O) p Cr) N CO M NCO N- CDC O) '-M .4- - CD N M �f to CV N- • N O) M LC) CD CO M M t.) M co N- 0) (NI MMMMNM C o F Q 0oO 0 00 . 0 C 100 J Cl) N• o4# NCCDCO � d) - CO ZO � r M N 6 C7 1:3)0 r ° 0))0) .4- • co c O M CD J CDM � M '— Z. 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E E E E co N o 0 0 0 C E o a) a) a) a) O 747.747. c c c cc "- ca . — — — a) L c c c c 7 C) O 0 0 0 C o M N- r N- r * a) CD Cil CJ CV CO * CO * CO CO r * CI N- V 1- N 4- O J a) a) N 2 O O 4, � o < O c O A O 0 .1- 0 � Q.CD N Et N N N cr 1 N w> re CO j (O co CO (. t Cfl > >1 _ * = 0) o o a) a) CO ) RS C N c a) E C C O O C O .E O .0 ' .0 = .0 E D 0 D 0 D c D c D a) V) * t/) * to M V) c (n a) EL ra) mH � HcH0H E v) * 08 c) oU) Cl)oCu) (1) u) o < a- < o < o < < v v v v v O O CD O o N N N N N 0) 6) O N- N N CO CO CO CO M 5 V' TREE= r ow WELLE-EAD= MCEVOY SAV NOTES:"'4-1/2'CHROME TBG"' ACTJJATOR= BAKER C KB.ELEV= 70' BF.ELP1/= 1.1] KOP= 1000' ' ' LII 2109' H 4-1/2"HES X NP,D=3.813" Max Angle= 63"@12300' Datum MD= 12090' Datum ND= 8800'SS 13-3/8"CSG,68#,L-80 BTC,D=12.415" H 4351' GAS LFT MANDRELS ST PA) TVD DEV TYPE VLV LATCH FORT DATE IA 1 4609 3647 55 MMG DOME RK 12 04/20/09 2 8827 6000 55 MMG DOME RK 16 04/20/09 3 11205 7361 56 MC SO RK 28 12/09/12 4 12690 8161 52 M*A3 DMY RK 0 02/23/09 Minimum ID = 3.725" @ 13658' 5 13295 8523 53 MMG DMY FM 0 02/23/09 4-1/2" OTIS XN NIPPLE 1 1 13376' —14-1/7 I-ES X NP,D=3.813" >< x 1340T —19-5/8"X 4-1/2"BKR S-3 F R.D=3.870" I I 13441' H4-1/2"HES X NP,D=3.813" 4-12"TBG,12.6#,13CR-80 VAM TOP, — 13504' .0125 bpf,D=3.958" 1,-4-7-13 519' —19-5/8"X 4-1/2'UNIQt.E OVERSHOT 4-12'TBG STUB(02/19/09) 1— 13500' 13553' SB-3A 13569' —7"MLLO&JT EXTH'ISION,D=6.00" 13_676' —7"X 4-12"XO,D=3.90" 13606' —16.32'BKR TACK,D=7.383 TOP OF 7'LNR H 13605' J L13611' _--19-5/8'X 7"BKR LTP&LNR HGR,D=6.167' ¢L 13658' H4-12"OTIS XN NP.D=3.725' — 13670' H4-12"BKR S/O SUB 4-1/2"TBG-FC,TBPC,12.6#,L-80 BTC-114H 13670' 0152 bpf,D=3.958' 13671' H4-12WD " LEG, =3.958' 9-5/8'CSG,47#,L80 BTC,13=8.681" —1 13944' 13664' —{ELM TT LOGO 07/04/90 PERFORATION SURN AR' FEF LOG:OH CM_ON 05/27/90 ANGLE AT TOP PERF:49"©13993' 1 Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE SQZ 3-3/8'• 6 •13992-13993 0 09/11/94 I 3-3/8" 1 13993-14002 0 10/22/90 I 3-3/8" 6 13993-14002 0 09/11/94 I 3-3/8" 4 14002- 14012 0 07/06/90 I 3-3/8" 4 14016- 14024 0 07/06/90 3-3/8" 2 14028- 14040 0 10/22/90 3-3/8" 6 14030-14040 0 09/11/94I -14060 -14-12"FASDRLL PLUG PUSHED BELOW WLEG 3-3/8" 2 14050- 14068 0 10/22/90 @ 13670'(ON BTM OR GONE 01/09/14 TAG) 3-3/8" 6 14050-14060 0 09/11/94 14088' _HMC-VR-STD-RK(STA#4 FND.EMP(3/17/93) PBTD H 14149' 1 1111111111111114 7"LN,29#,L-80 BTC,.0371 bpf,D=6.184" —I 14253' 1111111111111114 1111111111111114 DATE REV BY COMA TS DATE REV BY (X) i NTS PRUDHOE BAY INT 07/06/90 INT1AL COMPLETION 01/12/14 LER/PJC FASDRLL DEPTH CORRECTION WELL: 16-22 02/24/09 D16 RWO 01/13/14 PJC DRAWING CORRECTION PERMIT No:'1900510 08/13/09 AW/JM D DRLG DRAFT CORRECTIONS AR No: 50-029-22040-00 11/19/12 JCMJMD SET Ito(PLUG(11/17/12) Sec.24,T1ON,R15E, 1741'FNL&1271'FWL 12/14/12 BSHJMD GLV C/O(12/09/12) 01/12/14 LEF/PJC PULL I-EX PLUG(01/09/14) BP Exploration(Alaska) RECEIVED STATE OF ALASKA A OIL AND GAS CONSERVATION COMMIDON DEC 18 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon [J Repair Well [] Plug Perforations L( Perforate Li Other L 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 Q Exploratory ❑ 190 -051 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22040 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028346 PBU 16 -22 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 14238 feet Plugs measured 14007 feet true vertical 9204.75 feet Junk measured 14002, 14088 feet Effective Depth measured 14007 feet Packer measured See Attachment feet true vertical 9027.45 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 32 - 112 32 - 112 1490 470 Surface 4320 13 -3/8" 68# L -80 31 - 4351 31 - 3495.76 5020 2260 Intermediate None None None None None None Production 13914 9 -5/8" 47# L -80 30 - 13944 30 - 8978.99 6870 4760 Liner 628 7" 29# L -80 13605 - 14233 8728.99 - 9200.92 MAR 8160 7020 Perforation depth Measured depth See Attachment feet SCANNED MAC 8 �" 2013 True Vertical depth See Attachment 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): 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: 287 672 4520 368 Subsequent to operation: 237 967 5471 425 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development el -. Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG El 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 Prepared by Nita Summerhays 564 -4035 E -mail Nita.Summerhays(a.bp.com Printed Name Nita Summerhay Title Petrotechnical Data Technician w � / Sig atur /1��� i� - -i Phone 564 -4035 Date 12/18/2012 - ----_ 1 D r? Iry / / l2'2-a Z--- Form 10 -404 Revised 11/2011 A /7/20z Submit Original Only • • Daily Report of Well Operations ADL0028346 TY AT6 ** WvE" 1- L• ..;. ING CAN A - R VAL ** RAN 3.5 CENT,T.E.L.,S.BAILER,TAGGE T.T @ 13,621'SLM/ 13,664'ELM.43' CORRECTION. TAGGED T.D.@ 14,064 ELMD. CURRENTLY RUNNING PDS 40 ARM CALIPER FROM 14000' SLM /1443' ELMD * ** NEEDED TO USE ROLLER STEM TO GET OUT TT W/ DRIFT & CALIPER DUE TO DEV. & CHROME TUBING * ** 7/19/2012 * * *CONT WSR FROM 7- 20 -12 * ** * * *CONT WSR FROM 7- 19 -12 * ** (caliper) RAN PDS 40 ARM CALIPER FROM 14000' SLM/1443' ELMD (good data) * ** 7/20/2012 ** *WELL LEFT S /I, PAD OP NOTIFIED * ** 11/13/2012 Freeze Protect Flowline and Tubing for E -line - Job postponed due to weather. 171 /0= 500(FTP) /1700 /450 Freeze Protect tbg & flowline (profile mod) Pump 5 bbls neat meth, 103 bbls crude down flowline. DSO S ?I IGV pump add! 7 bbls crude to pressure up to 1500 psi. Pump 3 bbls neat meth & 38 bbls crude down tbg. FWHP's= 1200/1980/290 SV, WV =S /I SSV, MV =O 11/14/2012 IA(AL), OA =OTG Tags hung DSO notified ** *WELL SHU f -IN ON ARRIVAL* (cline HEX plug) INITIAL T/I/O = 1950/1950/100 SSV OPEN SET INTERWELL 350 -700 HEX PLUG AT 14011' MID - ELEMENT (TOP @ 14007') (OAL = 8.46' , MAX OD = 3.50 ", HAS ONE SEALING ELEMENT, 3.5" GS FISHING NECK) DEPTH CORRECTED TO CAMCO GR /CCL LOG DATED 7 -4 -90 WELL SHUT IN UPON DEPARTURE - NOTIFIED PAD OP OF WELL STATUS FINAL T /I /O = 1950/1950/100 11/16/2012 ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 3 DIESEL 8 METH 148 CRUDE 159 TOTAL Perforation Attachment ADL0028346 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base 16 -22 2/6/09 BPS 13600 13602 8725.47 8726.88 16 -22 2/21/09 BPP 13600 13602 8655.47 8656.88 16 -22 9/11/94 APF 13992 13993 8945.88 8946.65 16 -22 10/22/90 APF 13993 14002 8946.65 8953.59 16 -22 9/11/94 RPF 13993 14002 8946.65 8953.59 16 -22 7/6/90 PER 14002 14012 8953.59 8961.3 16 -22 11/16/12 BPS 14007 14148 8957.45 9065.75 16 -22 7/6/90 PER 14016 14024 8964.38 8970.55 16 -22 10/22/90 APF 14028 14040 8973.63 8982.86 16 -22 9/11/94 RPF 14030 14040 8975.17 8982.86 16 -22 10/22/90 APF 14050 14068 8990.55 9004.39 16 -22 9/11/94 RPF 14050 14060 8990.55 8998.24 16 -22 3/20/01 FIL 14061 14068 8999.01 9004.39 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET OH HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028346 SW Name Type MD TVD Depscription 16 -22 PACKER 13407 _ 8523.84 4 -1/2" Baker S -3 Perm Packer 1 16 -22 PACKER 13553 8622.65 4 -1/2" Baker SB -3A HYD PERM PN 1 t Casing / Tubing Attachment ADL0028346 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 32 - 112 32 - 112 1490 470 LINER 628 7" 29# L -80 13605 - 14233 8728.99 - 9200.92 8160 7020 PRODUCTION 13914 9 -5/8" 47# L -80 30 - 13944 30 - 8978.99 6870 4760 SURFACE 4320 13 -3/8" 68# L -80 31 - 4351 31 - 3495.76 5020 2260 TUBING 13490 4 -1/2" 12.6# 13Cr80 29 - 13519 29 - 8669.18 8430 7500 TUBING 170 4 -1/2" 12.6# L -80 13500 - 13670 8656.17 - 8775.2 8430 7500 • • TREE= CIW 9 1 W .LHEAD = MCEVOY SA NOTES: "`4 -1/2" CHROME TUBING & t'8 EES"' A ACTUATOR = BAKER C KB. ELEV = 70' BF ELEV = 1 1 I I KOP= 1000' I 2109' H4 -1/2" HES X NP, D = 3.813" Max Angle = 63° Datum PAD= 12090' D ) L atum TV D = 8800' SS GAS LIFT MANDRELS 13-3/8" CSG, 68#, L -80 BTC, D= 12.415" H 4351' ST MD TVl7 DEV TYPE VLV LATCH FORT DATE 1 4609 3647 55 MMG DOME FE 12 04/20/09 2 8827 6000 55 M43 DOME RK 16 04/20109 3 11205 7361 56 MMG SO RK 28 12/09/12 4 12690 8161 52 MNG DMY RK 0 02/23/09 Minimum ID = 3.725" @ 13658' 5 13295 8523 53 MMG DMY RK 0 02/23/09 4 -112" OTIS XN NIPPLE I 13376' H4 -1/2" I-ES X NP, D = 3.813" 1 •171 13407' . H9-5/8" X 4 -112" BKR S-3 PKR, D = 3.870" I I 13441' H4- 112" HES X NP, ID= 3.813" 1 4-1/2" TBG, 12.6#, 13CR 80 VAM TOP, 13504' .0125 bpf, D= 3.958" 13519' — 19 -5/8" X 4-1/2" UNDUE OVERSHOT 1 4-1 / 2 " TBG STUB (02/19/09) I 13500' , M I 13553' — I 9 -5/8" X 4 -1/2' BKR SB-3A PKR I TOP OF 7" LNR 13605' I I 13658' IH4 -1/2' OM XN MP, D 3.725" 13669' H4 -1/2" BKR S/O SUB 4-1/2' TBG PC, 12.6#, L -80 BTC-M —I 13670' I 13670' H4 -1/2" WLEG, D= 3.958" I .0152 bpf, 13= 3.958" I 13664' I°-I ELM TT LOGGED 07/04/90 9-5/8" CSG, 47 #, L80 BTC, D = 8.681" H 13944' ■ ,, I I ^-? I- 4-1/2" FASDFI LL FLUG PUSHED BELOW PERFORATION SUH+SAARY I VI/LEG CO 13670' (02/21/09) REF LOG: OH CPL ON 05/27/90 ANGLE AT TOP PERF: 49° © 13993' Note. Refer to Production DB for historical pert data _y ~ SEE SPF NTERYAL Opn/Sqz DATE SOZ ' 1 I 14007' 1 NTERWH.L 350 -700 NIX PL , 3-3/8" 6 13992 - 13993 0 09/11/94 ME @ 14011' (11/17/12) 3-3/8" 1 13993 - 14002 O 10/22/90 3-3/8" 6 13993 - 14002 O 09/11/94 3-3/8' 4 14002 - 14012 O 07/06/90 3-3/8" 4 14016 - 14024 C 07/06/90 3-3/8" 2 14028 - 14040 C 10/22/90 3-3/8" 6 14030- 14040 C 09/11/94 ' 3-3/8" 2 14050 - 14068 C 10/22/90 3-3/8" 6 14050 - 14060 _ C 09/11/94 I I 14088' IH MC-VR- STD- RK(STA#4 FPD. EMP (3/17/93) I PBTD 14148' Pe'W6V0 1•••••••1 I r LW( 29#, L -80 BTC, .0371 bpf, D = 6.184" H 14253' *4..4*** 4444�� 1 1 DATE REV BY COMNBYTS DATE REV BY COMENTS PRtDHOEBAY UNIT 07/06/90 ORIGINAL COMPLETION WELL: 16-22 01/08/01 SIS -QAA CONVERTED TO CAMAS PEWIT Na: F 1900510 02/24/09 D16 RWO _ AR No: 50- 029 - 22040 -00 08/13/09 AW /JMD DRLG DRAFT CORRECTIONS Sec. 24, T1ON, R15E, 1741' FT& &1271' P M. 11/19/12 JC MJMD SET HEX PLUG (11/17/12) 12/14/12 BSE/JMD GLV C/O (12/09/12) BP Exploration (Alaska) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 40400 AILS 07 2011 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 190 - 08/ Anchorage, Alaska 99501 6, a -- Subject: Corrosion Inhibitor Treatments of GPB DS -16 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 16 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional inforrnation, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, )&") Mehreen Vazir BPXA, Well Integrity Coordinator • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-16 Date: 03/06/2012 Corrosion 1 Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD if API ft cement . pumped cement off date inhibitor sealant date ft bbls ft na gal 16-01 1801360 50029205330000 Sealed conductor NA NA NA NA NA 16-02 1801500 50029205440000 Sealed conductor NA NA NA NA NA 16-03 _ 1810110 50029205540000 Sealed conductor NA NA NA NA NA 16-04A 1921510 50029205610100 Sealed conductor NA NA NA NA NA 16-05A 2010100 50029205740100 Sealed conductor NA NA NA NA NA 16.06B 2060110 50029205840200 Sealed conductor NA NA NA NA NA 16-07 1852040 50029214300000 Dust Cover NA NA NA NA NA 16-08A 1991260 50029205490100 Sealed conductor NA NA NA NA NA 16-09A 1910380 50029205580100 Sealed conductor NA NA NA NA NA 16-10A 1991230 50029205060100 Sealed conductor NA NA NA NA NA 16-11 1801180 50029205160000 Sealed conductor NA NA NA NA NA 16-12A 1990190 50029205650100 Sealed conductor NA NA NA NA NA 16-13 1810270 50029205680000 Sealed conductor NA NA NA NA NA 16-148 2060030 50029205700200 Sealed conductor NA NA NA NA NA 16-15 1852640 50029214740000 6.0 NA 6.0 NA 39.10 10/25/2011 16-16 1801270 50029205250000 Sealed conductor NA NA NA NA NA 16-17 1852200 50029214410000 72.0 17.0 1.5 9/312011 8.60 _ 3/6/2012 16-18 1852430 50029214610000 34.0 13.0 0.7 9/3/2011 8.50 10/25/2011 16-19 1852650 50029214750000 16.0 10.0 0.3 , 9/3/2011 2.60 3/6/2012 16-20 1852850 50029214930000 8.0 NA 8.0 NA 40.80 8/18/2010 16-21 1853120 50029215180000 29.0 10.0 0.3 9/3/2011 7.65 10/25/2011 �.-51 16-22 1900510 50029220400000 8.0 NA 8.0 NA 51.00 8/23/2010 16-23A 2010540 50029220500100 5.3 NA 5.3 NA 32.70 8/23/2010 16-24 1880240 50029215360000 0.8 NA 0.8 NA 8.50 10/25/2011 16-25 1920510 50029222700000 0.3 NA 0.3 NA 10.20 10/25/2011 16-26A 1991270 50029222670100 1.0 NA 1.0 NA 8.50 8/18/2010 16-27A 2000040 50029222600100 1.3 NA 1.3 NA 10.20 8/18/2010 16-28 1920620 50029222760000 0.0 NA 0.0 NA 7.65 10/25/2011 16-29A 1920660 50029222720000 Sealed conductor NA NA NA NA NA 16-30 1920760 50029222810000 0.8 NA 0.8 NA 6.80 8/18/2010 16-31 1920750 50029222800000 0.5 NA 0.5 NA 5.10 8/18/2010 DATE: 17- May -12 Stephanie Pacillo TRANS #: 5955 ".. Data Delivery Services Technician "1,, 4r. iVlakana K Bender Scblumberger Oilfield Services - IA : Natural Resources Technician 11 Data & Consulting Services r° ' Alaska Oii & Gas Conservation Commission ' i , ; Ave. ` ,13' t-, c, _ i 2525GambellSt,Ste.400 �� - �� °� --° - . Anchorage, AK 99503 I': Office: (907) 273 -1770 WELL SERVICE OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR ELECTRONIC NAME ORDER # DIST DIST DIST DIST LOGGED PRINTS PRINTS CD MPB -20 C4W7 -00008 X WATERFLOW RST LOG 30- Apr -12 1 1 G -09B BD88 -00204 X MEMORY PPROF W GHOST 20- Mar -12 1 1 • G -09B BD88 -00204 X _ MEMORY CNL BORAX (PROF 22- Mar -12 1 - 1 16 -22 BX69 -00028 X PPROF W GHOST DEFT 22- Feb -12 1 1 P2 -39 BYS4 -00024 X USIT 26- Mar -12 1 1 OWDW -C C2JC -00013 X USIT W CBL 23- Apr -12 1 1 J -26 C2JC -00015 X LEAK DETECT LOG 7- May -12 1 1 III X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 S trifttED NOV 0 6 2012 -1) 0' O STATE OF ALASKA A~~ OIL AND GAS CONSERVATION CO SION 'f'~as'~ REPZ7RT OF SUNDRY WELL OPETIONS ~~R ~ ~ X009 ;~`tac~a fit ~ Gas Cons. Commission 1. Operations Performed: At1ChOfegB ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4: Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 190-051, 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22040-00-00 - 7. KB Elevation (ft): 70, 9. Well Name and Number: PBU 16-22- 8. Property Designation: 10. Field /Pool(s): ADL 028332 & 028346 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 14238' ~ feet true vertical 9205' - feet Plugs (measured) None Effective depth: measured 14148' feet Junk (measured) 14088' true vertical 9136' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' "° --~ 1490 470 Surface 4351' 13-3/8" 4351' 3496' 4930 2270 Intermediate 13944' 9-5/8" 13944' 8979' 6870 4760 Production Liner 628' 7" 13605' - 14233' 8729' - 9201' 8160 7020 Perforation Depth MD (ft): 13992' - 14060' Perforation Depth TVD (ft): 9016' - 9068' 4-1/2", 12.6# 13Cr80 / L-80 13671' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 13407 ; 9-5/8" x 4-1/2" Baker'SB-3A' packer 13553' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~`~ ~"~ ~ ~.~ -~ ~~~ Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 290 208 5,506 Subsequent to operation: 552 977 4,256 1,620 415 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®~Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Arcs Worthington, 564-4102 N/q Printed Name Terrie Hubble Title Drilling Technologist ~ / Prepared By Name/Number: Signature Phone 564-4628 Date (~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 Submit Original Only 1~~~~~ • u 16-22, Well History (Pre Rig Workover) Date Summary 01/13/09 WELL S/I ON ARRIVAL. DRIFT OUT TT W/ 3.70" CENT, SAMPLE BAILER TO 13770' SLM. (SAMPLE BAILER EMPTY). WELL LEFT S/I ON DEPARTURE. DSO NOTIFIED OF ALL VALVE POSITIONS. 02/05/09 T/I/0=190/0+/210. Temp=S1. TBG & IA FL's (for FB). IA has integral installed. AL spool dropped. TBG FL Q 740' (11.25 bbl). IA FL C surface. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 02/05/09 WELL SHUT IN ON ARRIVAL. INITIAL T/ I/ O = 190/ 0/ 75 PSI. HES 4-1/2" FASDRILL PLUG SET WITH TOP AT 13600'. CMIT PASSED TO 3500 PSI. CUT 4.5" TBG AT 13518' USING 3.65" SLB POW ERCUTTER. 02/05/09 T/I/O = 0/0/150. Temp = S/I. Assist E-line with CMIT TxIA "'*PASS"~" to 3500 psi (RWO). Speared in with 3 bbls meth. Pressured up TBG with 22 bbls of diesel. MIT TxIA lost 20 psi in 1st 15 minutes and 0 psi in 2nd 15 minutes for a total of 20 psi during 30 minute test. Bleed TBG & IA down to 300 psi, threw the flowline. FWP = 300/300/150. E-line on well at time of departure. 02/06/09 INITIAL T/ I/ O = 190/ 0/ 75 PSI. HES 4-1/2" FASDRILL PLUG SET W ITH TOP AT 13600'. CMIT PASSED TO 3500 PSI. CUT 4.5" TBG AT 13520' USING 3.65" SLB POW ERCUTTER. WELL LEFT SHUT IN. ALL GAUGES OPEN TO PRESSURE. SSV CLOSED. WELL TURNED OVER DO DSO. FINAL T/I/O = 400/0/75. JOB COMPLETE. 02/07/09 T/I/O = 420/420/150 Temp = S/I Circ-out well bore fluids. (Pre- RWO) Pumped 10 bbl Neat meth spear followed by 1422 bbls 1 % KCL down Tbg up IA through jumper loop and casasco and down Flowline to Circ- out well bore fluids. Started pumping 90° diesel down TBG for FP. 02/08/09 Temp = SI Circ-Out, Freeze Protect FL, CMIT TxIA to 2000 psi PASSED 2nd attempt. MIT OA to 2000 psi PASSED. Pumped a total of 140 bbls 90° diesel down TBG taking returns up IA through jumper loop and casasco to FL. U-tube for 1 hr to put FP in place. Pumped 1 bbls neat methanol followed by 2 bbls 30° diesel through jumper loop to FP loop and casasco valve. CMIT TxIA- Pumped 5.5 bbls 30° diesel down TBG to reach test pressure. T/IA lost 0/0 psi in 1st 15 min and 0/0 psi in 2nd 15 min for a total loss of 0/0 psi in 30 min test. Bleed T/IA pressures, Bled back -- 5 bbls, Pumped 5 bbls neat methanol followed by 85 bbls crude capped with 15 bbls 30° diesel up FL for FP. MIT OA- (2nd attempt), Pumped 2 bbls 60° crude, and 13 bbls 30° Diesel down OA to reach test pressure. OA lost 40 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 60 psi in 30 min test. Bleed WHP's, Bled back 3 bbls. Final WHP's 20/20/280. Swab shut, Wing shut, SSV shut, Master open, IA,OA open to gauges. 02/08/09 T/I/O = SSV/Vac/290. Temp = SI. Bleed OAP for Cameron. AL spool dropped. OAP increased 215 psi since 2-6-09. OA FL @ 36' (2 bbls). Bled OAP from 290 psi to 72 psi in 2 hrs (gas/fluid). SI and monitor for 30 min. OAP increased to 78 psi. FWHPs =SSV/Vac/78. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 02/10/09 T/IA/OA= 0/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T Remove 1/2" NPT plug, RU BT onto void 50 psi to 0 psi. RD bled tool, remove internal check, install Alemite and HP BT onto tubing spool. Pressure test void to 5000 psi for 30 min test, 5000/ 15 min, 5000/ 30 min. Bled void to 0 psi, RD test equipment, cycle and torque LDS "N style" all were in good working and visual condition. PPPOT-IC Remove 1/2" NPT plug, RU BT onto void 170 psi to 0 psi. RD bled tool, remove internal check, install Alemite and HP BT onto inner casing spool. Pressure test void to 3500 psi for 30 min test, 3500/ 15 min, 3500/ 30 min. Bled void to 0 psi, RD test equipment, cycle and torque LDS "N style" all were in good working and visual condition. Internal checks removed. 02/10/09 T/I/0=O/VAC/70. Temp=S1. Bleed IA & OA to 0 Assist CAM. No AL. IA & OA unchanged since 02/08/09. IA FL near surface. Bled IAP from 80 psi to 0 psi in 150 mins (gas/fluid). Monitored for 30 mins, OAP increased to 10 psi. Held open bleed for 2 hours while Cameron preformed PPPOT. Final WHPs=O/VAC/0+. SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. Page 1 of 1 BP EXPLORATION Page 1 of 5 Operations Summary Report • Legal Well Name: 16-22 Common Well Name: 16-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To ', Hours Task Code NPT 2/14/2009 18:00 - 21:00 3.00 RIGD P 21:00 - 22:00 1.00 RIGD P 22:00 - 00:00 2.00 RIGD P 2/15/2009 00:00 - 16:00 16.00 RIGD N 16:00 - 00:00 I 8.00 I MOB I P 2/16/2009 100:00 - 14:00 I 14.00 I MOB I P 14:00 - 18:00 I 4.001 MOB I P Spud Date: 4/28/1990 Start:. 2/7/2009 End: 2/24/2009 Rig Release: 2/24/2009 Rig Number: Phase Description of Operations Prepare rig for move off of well. Bridle up. Clean cuttings tank. PJSM -Move rig off well H-16 and set down on edge of pad. (Notified H pad operator). PRE Clean and secure rig for move. PRE Wait on booster wheels and BOP craddle from Endicott to move to DS-16-22. Clean and service rig. Booster Wheels arrived on H-pad at 1300-hours. Remove BOP from cellar stump and place on moving cradle. Install Booster wheels. PRE Begin rig move from H-pad to DS 16. Pass GC2 at 1700-hrs. Pass BOC C~ 2130-hrs. Pass DS-14 C~ 2330-hrs. PRE Continue moving rig from H-16 to DS 16-22. Rig at Sag river C~ 0400-hrs. Rig crossing under powerlines near DS16/17 access road junction C~3 0815-hours. Snow berms need to be removed from DS 16 pad, but no snow removal equipment onsite as of 0815-hrs. On DS 16 pad at 0945-hrs. Disconnect Boosters, install BOP stack on pedestal, raise Derrick, Lay down Herculite, lay out rig mats. PRE Move rig onto rig mats and center over tree. R/U cellar and manifold. Remove bridle lines from blocks and re-hang in Derrick. Line up #2 pump module, line up auxilliary power module, and line up cuttings/slop tank. Check IA and OA and no pressure on either one. Take on seawater into pits. (Rig PRE PRE 18:00 - 19:00 1.001 KILL P DECOMP 19:00 - 19:30 0.50 KILL P DECOMP Pressure test circulating lines to 3500 psi. (Good test). 19:30 - 00:00 4.50 KILL P DECOMP Hold PJSM with Rig crew, Truck drivers, WSL, and Tour pusher. Reverse circulate 50 bbls diesel from tubing. Realign valves and pump down tubing C~3 6 BPM with 300 PSI. Pump 20 BBL Hi-vis sweep followed by 825 BBLS of 120 Degree seawater taking returns to slop tank. Still seeing signs of diesel strung out, circulate until clean. 2/17/2009 00:00 - 00:30 0.50 KILL P DECOMP Monitor well for 30 min' ~+~~ I~yeIJ is ~+a+ic) 00:30 - 01:00 0.50 KILL P DECOMP R/D circulating lines to set TWC. 01:00 - 02:00 1.00 KILL P DECOMP Cameron Tech. set TWC and test from above to 3500 osi and below to 1000~si for 10 charted minutes each. (Good 02:00 - 05:00 3.00 WHSUR P DECOMP PJSM-N/D Tree and Adapter flange. 2) Barriers for N/D are tested TWC and Fasdrill set @ 13600'. Function X-O 11-1/2 turns, hanger threads looked good. 05:00 - 10:00 5.00 BOPSU P DECOMP N/U BOPE. Fill lines and install and fill test joint with water. Start rig camp move from Price Pad to Tarmac Pad. 10:00 - 12:00 2.00 BOPSU P DECOMP PJSM to discuss the BOP testing procedures. Assign crew members to their tasks and working areas; talk about leak prevention as well as watching for leaks. Calibrate gas detection sensors and alarms. Find leak in the ring gasket area between the BOP stack and the adaptor spool. Hold a THA and decide to use Sweeney wrench to check all bolts. Find loose bolts and re-torque them with Sweeney. 12:00 - 18:00 6.00 BOPSU P DECOMP Initial BOPE test. Test er BP rocedure and AOGCC Re s. 250-psi low, 3,500-psi high holdi and chart all tets for 5 minutes. Use 4" and 4-1/2" test joints on VBR's. Test Hydrill WAIT Printed: 3/6/2009 1:42:42 PM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: 16-22 Common Well Name: 16-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 Start: 2/7/2009 Rig Release: 2/24/2009 Rig Number: I Spud Date: 4/28/1990 End: 2/24/2009 Date From - To Hours ' Task 2/17/2009 12:00 - 18:00 6.00 BOPSU P 18:00 - 18:30 0.50 BOPSU P 18:30 - 20:00 1.50 WHSUR P 20:00 - 20:30 I 0.501 WHSUR I P 20:30 - 00:00 I 3.501 PULL I P 2/18/2009 00:00 - 01:30 1.50 PULL P 01:30 - 02:00 0.50 PULL P 02:00 - 03:00 1.00 PULL P 03:00 - 10:30 7.50 PULL P 10:30 - 12:30 2.00 PULL N 12:30 - 13:00 0.50 PULL P 13:00 - 13:30 0.50 PULL N 13:30 - 20:30 7.00 PULL P 20:30 - 21:00 0.50 PULL P 21:00 - 21:30 0.50 FISH P 21:30 - 00:00 2.50 FISH P 2/19/2009 ~ 00:00 - 04:00 04:00 - 05:00 4.00 FISH P 1.00 FISH P NPT Phase I Description of Operations DECOMP with only the 4" test joint. Record all tests on Chart. BP WSL witness all tests. AOGCC rep. (Chuck Scheve waived witness of test). DECOMP R/D test equipment, Blow down choke, kill, and Top drive. DECOMP Rig up Dutch riser. R/U DSM lubricator and test with diesel to 500 psi. Pull TWC. DECOMP Make up landing joint with 12 turns. BOLDS. Pull hanger free at 140 K. Pull up 5' and Circulate. DECOMP Circulate @ 12 BPM with 700 psi. 6800 strokes into circulation Bottoms up ~ 7800 strokes H2~rm went off. Driller and lead floorhand closed annular. No pressure on DP. All personell evacuated to up wind safe breifing area and notifications were made. ERT notified ~ 2155 hrs, Fire Chief on location at 2240 hrs. 2300 hrs Fire Chief Driller, and WSL readin s were at 0 PPM. Called all clear at 2315 hrs. Rig crew broke circulation thru gas buster staged pumps up to 5.5 BPM-180 psi. DECOMP Continue circulating thru choke ~ 5.5 BPM-180 psi. DECOMP Monitor well for 30 minutes. Well static. DECOMP UD hanger and UJ. Blow down choke, kill line and Top drive. DECOMP Lay down 4-1/2" L-80 12.6# tubin .155 jts, SSSV, 49 SS Bands, and dual Control Line. RREP DECOMP Loader Broke Down. Unable to off load pipe from shed. M/U Safety Valve and Clean Rig while loader is being repaired. DECOMP Service Rig RREP DECOMP Continue to wait on loader repair. Continue to clean the rig. DECOMP Loader Up and Running. PJSM on UD Tubing. UD 4-1/2" L-80 12.6# tubing from joint #155 to joint #341. Recovered 341 full joints, 1 cut off joint 10.52', 9 GLM's, 1 SSSV. Cut off joint OD 4-7/8" ,length =10.72 ft. DECOMP Clear and clean rig floor of tubing handling equipment. DECOMP Install 8.75" ID wear bushing. DECOMP PUM/U BHA #1 Tubing Dressoff assembly. 8-1/2" x 4-9/16" Dress-off Shoe, 3-ea Extensions, 4-1/2" Tubing Dress-off Mill, Boot Basket, 9-5/8" Casing Scraper, Bumper sub, Oil Jars, Pump-out sub, and (9) 4-3/4" DC's. DECOMP Continue RIH with dressoff BHA picking up 4" DP from pipe shed 1x1 to 4796'. Parameters-Up Wt.-104K Dn Wt.-95K. Apply steam to wellhead at 0300 hrs. DECOMP Set RTTS 35' below RKB. Test to 1000 psi for 10 charted 05:00 - 06:00 1.00 BOPSUF~ P DECOMP Blow down lines and drain stack to change packoff and tubing s ool. Barriers are tested RTTS and Fasdrill plug set at 13600'. 06:00 - 08:00 2.00 BOPSU P DECOMP PJSM - N/D BOP's and set back on pedestal. 08:00 - 10:30 2.50 WHSUR P DECOMP N/D 11" x 13-5/8" Tbg Spool. Clean Up top of Casing Spool and Pack Off. Pull 3" Valve from New Tbg Spool and Install VR Plug and Blanking Flange. M/U Pulling Tool for Pack Off and Pull from Casing Spool with 6,000 lbs. 10:30 - 12:00 1.50 WHSUR P DECOMP PJSM -Dress new packoff and install on top of casing stub. Install new packoff, required -25,000 Ibs down force to set at Printed: 3/6/2009 1:42:42 PM BP EXPLORATION Operations Summary Report Legal Well Name: 16-22 Common Well Name: 16-22 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT '~ ___ _- -- 2/19/2009 l __._ _ - l __ 12:00 - 13:30 I 1.50 WHSUR P 13:30 - 15:30 I 2.001 BOPSUR P 15:30 - 17:00 I 1.501 BOPSUR P 17:00 - 18:00 I 1.001 BOPSUR P 18:00 - 00:00 6.00 CLEAN P 2/20/2009 00:00 - 03:00 3.00 CLEAN P 03:00 - 04:30 I 1.501 CLEAN I P 04:30 - 07:00 I 2.50 I CLEAN I P 07:00 - 13:00 6.00 CLEAN i P 13:00 - 14:00 1.001 CLEAN P 14:00 - 15:00 I 1.001 CLEAN I P 15:00 - 16:30 ~ 1.50 ~ CLEAN ~ P 16:30 - 21:00 4.50 CLEAN P 21:00 - 22:00 1.00 CLEAN P 22:00 - 00:00 2.00 CLEAN N 2/21/2009 00:00 - 13:00 13.00 CLEAN N 13:00 - 13:30 I 0.501 CLEAN I P 13:30 - 14:30 1.00 CLEAN P 14:30 - 15:30 1.00 CLEAN P 15:30 - 16:00 0.501 CLEAN P DECOMP I Manage fluid losses ~ 360 BPH. 15 BPM with 2600 DECOMP Chase Fasdrill plug out of Tbg. tail ~ 13670'. Drop ball & rod and Dull 2 stands. Start: 2/7/2009 Rig Release: 2/24/2009 Rig Number: Page 3 of 5 Spud Date: 4/28/1990 End: 2/24/2009 Phase Description of Operations DECOMP proper depth. Confirm groove in proper placement and RILDS. DECOMP N/U New McEvoy 13-5/8" x 13-5/8" Tbg Spool and Torque up with Sweeny Wrench. Test Mandrel Pack Off to 5000 psi for 30mins. DECOMP N/U BOP's with 13-5/8" x 13-5/8" Spacer Spool and Torque up with Sweeny Wrench. Set Bell Nipple and Riser, Fill Stack. DECOMP PJSM -Set Test McEvoy Test Plug in Tba Soool. Test BOP Body, Choke HCR, and Annular with 4" Test Joint. Pressure Test 250 psi low and 3500 psi high for 5 mins each, all Tests Charted. Good Test. Pull Test Plug. DECOMP PJSM - P/U Running Tool for HES RTTS STorm Packer and Engage RTTS. Make 21 Rt Hand Turns and No Pressure Under RTTS. Unseat RTTS and POOH. L/D RTTS. DECOMP Continue RIH from 4796' to 9817' with 4" DP from pipe shed. DECOMP Continue RIH from 9817' to 13486'. Reciprocate scraper from 13359' to 13486' 4 times (Packer setting depth 13430') DECOMP Parameters= Up wt.-210K Dn wt.-142K Rot wt.-168K RPM-70 Tq-8K. Tagged up C~? 13496' Drillers measurement, Rotate and ream down over stub 6 BPM 650 PSI seeing 2-3K torque increase (Debris around stub) wash down 17' over stub mill 6" off of stub. Set down 6K (Top of Stub @ 13500' Drillers measurement) DECOMP Circulate sweep ~ 11 BPM with 2400 PSI. Nothing much seen at shakers from bottoms up or sweeps. Monitor well 15 mins. DECOMP Pump Dry Job, Break Off and Blow Down Top Drive. POOH and Stand Back DP. DECOMP Stand Back DC's and Break Out BHA. Upper Dress off mill showed good indication of being on top of tubing. Wash Over Boot Basket filled with material. DECOMP Clear and Clean Rig Floor. PJSM with rig crew on building new BHA and RIH. DECOMP I M/U 3-5/8" Mill with 6 ioints_gf PAC DP Shear Pin Guide Shoe, 4-3/4" Bumper Sub, Jars, Circ Sub, and DC's. Total Length = 496.47 ft. DECOMP RIH with BHA #2 on 4" DP from 496' to 13487', Break circulation each 30 stands. DECOMP Load 4-1/2" 12.6# 13 Cr 80 Vam Top tubing in pipe shed. Cut and slip drilling line. (Found small crack in Dog nut guard, Toolpusher brought to welder and fixed) DECOMP Continue to Load, strap, and drift 4-1/2" 12.6# 13 Cr 80 Vam Top tubing in pipe shed. WAIT DECOMP Continue to Load, strap, and drift 4-1/2" 12.6# 13 Cr 80 Vam Top tubing in pipe shed. DECOMP PJSM-Obtain Parameters- Up wt. 215K, Dn wt. 135K, Rot. wt. 165K, Tq. 8K, 5 BPM ~ 1000 PSI. Tag 4.5" Tub. stub ~ 13500',. Sheared guide with 20K. DECOMP Continue washing down, tapped funk @ 13522', Milled Fasdrill Printed: 3/6/2009 1:42:42 PM BP EXPLORATION Page 4 of 5 Operations Summary Report Legal Well Name: 16-22 Common W Event Nam Contractor Rig Name: Date ell Name: 1 e: Name: From - To 6-22 WORKO DOYON DOYON Hours VER DRILLIN 16 Task G INC Code . NPT 2/21/2009 16:00 - 18:00 2.00 CLEAN P 18:00 - 00:00 6.00 CLEAN P 2/22/2009 00:00 - 05:30 5.50 CLEAN P 05:30 - 07:00 1.50 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 08:30 0.50 CLEAN P 08:30 - 09:00 0.50 CLEAN N RREP 09:00 - 10:30 1.50 BUNCO P 10:30 - 11:00 0.50 BUNCO SFAL 11:00 - 11:30 0.50 BUNCO P 11:30 - 00:00 12.50 BUNCO P 2/23/2009 00:00 - 02:30 2.50 BUNCO P 02:30 - 04:00 1.50 BUNCO P 04:00 - 05:00 1.00 BUNCO P 05:00 - 07:30 2.50 BUNCO P 07:30 - 08:00 0.50 BUNCO P 08:00 - 12:00 4.00 BUNCO P 12:00 - 12:30 0.50 BUNCO P 12:30 - 13:00 0.50 BUNCO P Spud Date: 4/28/1990 Start: 2/7/2009 End: 2/24/2009 Rig Release: 2/24/2009 Rig Number: Phase Description of Operations DECOMP Open pumpout sub and establish loss rate 260 BPH, pumping down kill line and DP @ 2.3 BPM with 25 PSI wiat on fluids. DECOMP POOH with BHA #2 UD DP to pipe shed. Fill hole C~1 90 BPH No returns). Take fluid shot Fluid ~ 1100' POOH from 13577 to 7672'. DECOMP Continue to UD DP from 7672' to 496'. Fill hole ~ 90 BPH. DECOMP UD BHA #2 Milling Assembly. DECOMP Clean and Clear Rig Floor. L/D Power Tongs for PAC DP and Handling Tools. DECOMP Rig Service DECOMP Address possible hydrualic leak on top drive. RUNCMP PJSM Rig Up for Running completion. Organize completion jewelry and bring tbg hanger to rig floor. R/U double stack power tongs, torque turn, pick up sling and stabbing guide. RUNCMP Found small leak at hydrualic fitting on power tongs. Lay down tongs and pick up different set. RUNCMP PJSM on picking up and running tbg. RUNCMP P/U and RIH with 4-1/2" 12.6# 13Cr80 Vam Top Tbg form pipe shed. Filling hole C«? 90 BPH. RUNCMP Continue to RIH with 4-1/2" 12.6# 13Cr80 Vam Top Tbg form pipe shed. Filling hole C~ 90 BPH with 120 deg F SW .Used Jet tube seal guard dope, M/U Tq. 4440 ft. lbs. RUNCMP PU Jt #314, and 315. PU wt = 198K-Ibs, SO wt = 110K-Ibs. RIH and tag 4-1/2" tbg stub at 13508' No indication. Continue RIH and tag first set of shear pins at 13512'. Set down 8K-Ibs and observe first shear. Continue RIH and tag second set of shear pins at 13520'. Set down 10K-Ibs and observe second shear. Continue RIH and No Go with Unique Overshot at 13522'. P/U and set back down to confirm. L/D Jt.#315 and #314 and P/U 9.85' Spaceout Pup and P/U Jt.#314 and M/U hanger. Run in and land RILDS. Overshot 2.8' off tag. RUNCMP Rig up circulating lines to reverse circ. seawater and corrosion inhibitor, test lines to 3800 psi. Hold PJSM with WSL, Truck drivers, Rig crew, Tour pusher on reverse circ. seawater and corrosion inhibitor. RUNCMP Reverse circulate at 3 bpm. Well starting to pressure up in IA due to packing off down hole. RUNCMP Bleed Down IA. Back Out Lock Down Screws and Pull Hanger back to Rig Floor. RUNCMP Close bag and Reverse Circ at 3 bpm with no pressure on the well and no returns. RUNCMP Make up new hanger seal. RIH with completion and re-land hanger. RILDS. RUNCMP Break off circ head, drop ball and rod and back out landing 13:00 - 14:30 ~ 1.50 ~ RUNCOf~1P ~ RUNCMP ~ Rig up to pressure test tbg. Fill tubing with -17 bbls. Close 14:30 - 15:30 1.00 BUNCO P RUNCMP Swap valves and pump down IA, fill with 27 bbls. Pressure up on IA and pressure testt to 3500 si for 30 mins. Good Test. Bleed off pressure on tbg, witness shear valve release at 2500 psi differential pressure. Pump both was through shear valve. Printed: 3/6/2009 1:42:42 PM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: 16-22 Common Well Name: 16-22 Spud Date: 4/28/1990 Event Name: WORKOVER Start: 2/7/2009 End: 2/24/2009 ,Contractor Name: DOYON DRILLING INC. Rig Release: 2/24/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours ~ Task Code NPT ~ Phase Description of Operations 2/23/2009 15:30 - 16:30 1.00 BUNCO P RUNCMP Cameron Rep set TWC in tbg hanger. Pressure test TWC from 1000 psi below for 10 mins and 3500 psi above for 10 16:30 - 18:00 1.50 BOPSUF~ P 18:00 - 22:30 4.50 WHSUR P 22:30 - 23:30 1.001 WHSUR P 23:30 - 00:00 0.50 WHSUR P 2/24/2009 00:00 - 01:00 1.00 WHSUR P 01:00-03:30 I 2.501 WHSURIP 03:30 - 04:30 I 1.001 WHSUR I P mins. Good Test. RUNCMP Nipple down BOPE. RUNCMP Nipple up adapter and tree, test adapter to 5000 psi for 30 min (good test). Test tree to 5000 psi for 10 charted minutes (good test). RUNCMP Rig up DSM lubricator and test to 500 psi with diesel, pull TWC valve an $1Gf uricator. RUNCMP Rig up circulating lines to freeze protect. RUNCMP Change bails and prepare to move. Wait on Little Red Services. RUNCMP Hold PJSM - R/U LRS and pressure test lines to 3500 psi, Reverse circulate 150 bbls of diesel @ 2.5 BPM with 300 psi. U-Tube freeze protect for 1 hour. RUNCMP Cameron rep. set BPV and test from below to 1000 psi for 10 R/D circulating lines. 04:30 - 08:00 3.50 WHSUR P RUNCMP Remove secondary annulus valve. Install jewelry on tree. Secure Cellar. Finish cleaning pits and suck out slop tank. Ready Rig to back off well. Release rig at 0800 hrs 2/24/09. Printed: 3/6/2009 1:42:42 PM WELLHEAD= _ CAMERON ACTUATOR ~ AXELSON ~ KB. ELE~/ _ _ 70~ ~°~ __ BF. ELEV = ..._- ~ - KOP = 1000' Max Angle = 63 @ 12300' Datum MD = 12090' _ _ . Datum TVD = 8800' SS 13-3/8" CSG, 68#, N-80, ID = 12.415" 4351' Minimum ID = 3.725" @ 13658' 4-1 /2" OTIS XN NIPPLE' 4-1?2°' TBG, 12.6#, 13CR-80, .0152 bpf: ID = 3.958" 135(1$' TOP OF 7" LNR I-) 13604' -1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" (-~ 13670' 9-5/8" CSG, 47#, N-80, ID = 8.681" ~-{ 13944' PERFORATION SUMMARY REF LOG: OH CNL ON 05/27/90 ANGLE AT TOP PE:RF: 49 @ 13993' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 13992 - 13993 O 09/11/94 3-3/8" 1 13993 - 14002 O 10/22/90 3-3/8" 6 13993 - 14002 O 09/11/94 3-3/8" 4 14002 - 14012 O 07/06190 3-3/8" 4 14016 - 14024 O 07/06/90 3-3/8" 2 14028 - 14040 O 10/22/90 3-3/8" 6 14030 - 14040 O 09/11/94 3-3/8" 2 14050 - 14068 O 10/22/90 3-3/8" 6 14050 - 14060 O 09/11/94 PBTD -~ 14148, r7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 14230' 16-22 SAFETY NOTES---H2S = 25-PPM I 2109' I-~4-112" HES X N(P, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 4009 3847 55 MMG DOME F2K 16 02/27/ 2 8827 600 55 MMG SO RK 20 02127/i 3 11205 7361 56 MMG DMY RK 0 02/23/ 4 12690 8161 52 fvfMG DMY RK 0 02/23/ 5 .13295 8523 53 MMG DMY RK 0 02/23/i 13376` 4-112" HES X N[P, 1D = 3.813 13$07' S-3 BAKER PACKER E 41 ` 4-112" HES X NIP, ID = 3.813" 13504' 4-1/2" UNIOUEOVERSHOT 13553' 9-5/8" X 4-1/2" BKR SB-3A PKR 13658' ~4-1/2" OTIS XN NIP, ID = 3.725" 13669' 4-1/2" BKR S/O SUB 13670' 4-1/2" TUBING TAIL 13664' ELM TT LOGGED 07/04/90 14088' ~-~ MGVR-STD-RK(STA#4 FND. E3v1P (3/17/93) DATE REV BY COMMENTS DATE REV BY COMMENTS 07/06!90 ORIGINAL COMPLETION 02/24/09 D16 RWO 02/27/09 /TLH CORRECTIONS 03/03/09 TFA/SV GLV C/O (02/27/09) PRUDHOE BAY UNIT WELL: 16-22 PERMIT No: 90-051 API No: 50-029-22040-00 Sec. 24, T10N, R15E, 4901.74 FEL 3340.52 FNL BP Exploration (Alaska) R' ìr'\ C· .."'" E""-..":.-. a \/1 F.~.·:= «,,...(1 ,>,,,,,,",!1 'Ii' ,,~ Schlumbepger APR 2 U Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i~ Oil & Gas Cons. CQfnm~ Ançñoraga /C]D-05( Well Job# Log Description Date BL 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2·40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. S~^~'NED APR 2 5 2007 Petrotechnical Data Center LR2-1 \1".11 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: <9( 04/16/07 NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ( Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. SUpervisor DATE: May 1, 2001 FROM' John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field DS-16 MaY. 1, 2001: I traveled to BP's Prudhoe Bay Field to witness the semi-annual SVS tests on DS-16. I witnessed SVS tests on BP's DS-16. Testing went very well. No failures were witnessed. We had more than adequate manpower to test this Pad in a timely manner. Flow 2 Supervisor Roy Wells checked in w/the Pad Operators & Leads on DS-16 that were performing tests to make sure operations were being performed in a safe & efficient manner. Preventive maintenance had been performed on SVS for this Pad two weeks before State testin~ was conducted. SUMMARY: I witnessed SVS tests on BP's PBU DS-16. 2.0 .w,.e!,!,~. 40 ,c0m~onen, ts, tested, Nq fail,utes ..witnessed,., 0,~ ,..failuye r~,t~. Attachments: SVS PBU DS-16 5-01-01jc CC; · NON-CONFIDENTIAL SVS PBU DS-16 5-01-01jc Ala~..~ Oil and Gas Conservation Commis ~a Safety Valve System Test Report Operator: BPX Operator Rep: W. Williams AOGCC Rep: John Crisp ...... Submitted By: John Crisp Date: Field/Uni~ad: Pmdhoe Bay Field DS-16 Separator psi: LPS 171 HPS 5/1/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number,,, Number ,, PS! PSI ,,T~p Code Code Code ~assed GAS or ~¥~LE 16-0i 1801360 16-02 1801500 ......... 16-03 1810110 16-04A 1921510 171 150 110 P P oIL 16-05 18103~0 171 1'50 i'25'" p" p ........ I OIL 16.06 181o5'io ......... 16-07' 1852040 ....... 1 ........ 16-08A 1991260 171 '150 " 120 P ..... P ' OIL 16,09A" 1910380 171. '"150 120' e .... P ........... OiL 16-106 1991230 ................ 16-11 1801180 1,6-12A ,,1990190,, 171, [59' i'20 P ..... P~ .... , oiL 16-13 1810270 171 150 140 P P OIL 16-14A 1980360 3000 1800 1800 P P G1NJ J6-15 ' 1'852640 171 150 .... i20'' P ' 'p ' 'OiL 16-16 1801270' t. ~1'7 1852200" 171 156 '125:" 'P .... P ..... OIL 16-18 1852430 171 150 100 P P OIL 16-19 1852650 171 150! 120 P P OIL 16-20 1852850 171 150!" 110 P P .... oIL 16-21 1853120 '' 171 156 90 P P ....... OiL 16-22 '19005101 '171 150 ' i20" P' 'P .......... oIL 16-23 .... 1900620 .... ' .............. 16-24 1860240 16-25' '~920510' "17i "150 90'" P ' P ..... oIL i6'-26A 1991270 "'i7i ~50 120'" P '-' P .......... OIL 16-27A ' 2000040 ' 1~1 150 .... 110' P P ...... OIL i6-28 '1920620 '17i ....... 150 115 ~ P ...... OiL, 16-29A 1920660 171 150 120 P P OIL 16-30 1920760 ...... 17i 150 " 120 P P ...... oIL 16-31 1920750 Wells: 20 Components: 40 Failures: 0 Failure Rate: 0.00% I"190 var Remarks: RJF 1/16/01 w,o ~ ,,~ qxrq ~)m)r~q_~n 5-01-0!jc~ ,, .... , , ,,, ..., :i~, .... ,' ii" , ii~: :':i "~ : :: " " ~ .... ' · Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI ,Trip Code Code Code. , Pas.s.e,d .,GAS or, RJF 1/16/01 Page 2 of 2 SVS PBU DS-16 5-01-01jcl THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE ,OCTOBER 27, 2000 E P M C:LO~LM.DOC L E W A T E R IA L U N D E TH IS M A R K E R R ,~--"- STATE OF ALASKA ALASI~ .)ILAND GAS CONSERVATION L MMISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1742' FNL, 1271' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 1907' FSL, 213' FWL, Sec. 17, T10N, R16E, UM At effective depth At total depth 1942' FSL, 374' FWL, Sec. 17, T10N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-22 9. Permit number/approval number 90-51 10. APl number 50 - 029-22040 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Sudace 4281' Production 13874' Liner 626' 14238 feet 9207 feet 14062 feet 9069 feet Plugs(measured) PBTD Tagged @ 14062' MD (9/11/94) Junk(measured, Size Cemented Measured depth True vertical depth 20" 275 sx CS II 112' 112' 13-3/8" 2500 sc CS III & 600 sx Gl 'G' 4351' 3496' 9~5/8" 450 sx CI 'G' 13944' 8978' 7" 220 sx CI °G' 14230' 9202' Perforation depth: measured 13992-14012'; 14016-14024'; 14028-14040'; 14050-14068' true vertical 9015-9031 '; 9034-9040'; 9043-9052'; 9060-9074' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, IPCT @ 13670' MD Packers and SSSV (type and measured depth) Baker SB-3A packer @ 13553' MD; Otis HRQ SSSV @ 2207' MD 13. Stimulation or cement squeeze summary R E C E ~V E D Intervals treated(measured) See attached. Treatment description including_volumes used and final pressure NOV ] 4 1994, '14. Representative Daily Average Production or Injection Data~'° .... 0!! 4..; ~2S r,~,., n,~ .,;..in OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure AflCh°lJ't~bing Pressure Prior to well operation 1405 907 3436 -- 288 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 1468 650 3397 -- 284 16. Status of well classification as: Oil x Gas, Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢~.. ~ - ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 1251 cc: KZ, JWP Date SUBMIT IN DUPLICATE,,,,.~, 16-22 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 9/1 I/94: MIRU & PT equipment. 30' of perforations as follows: Added perforations: 13992 - 13993' MD (Z3) Reperforated' RIH w/perforating gun & tagged PBTD at 14062' MD, then PU & shot 13993 - 14002' MD (Z3) 14030 - 14040' MD (Z2) 14050 - 14060' MD (Z2) Ref. Log: OH CNL 5/27/90. Ref. Log: OH CNL 5/27/90. Used 3-3/8" carriers & shot 6 spf at 60 degree phasing, at underbalanced pressures. POOH w/perf guns; noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED m~ska. ~.~ii & 6as Cons. C0r~missi0n GeoQuest IS[X] W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 8975 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 10/7/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 1-6 ~ .~%--- I. ~.~ PERF RECORD (9-20,94) 1 1 D.S. 2-lA ~ (~ ~ I I ~J~ STATIC PRESSURE SURVEY (9-19-94) 1 1 D.S. 3.31~~~~. - ~ BRIDGE PLUG RECORD (9-13-94) 1 1 D.S. ~-~6 ~~ ~ PERF RE~ORD (9-14-94) .1 ... 1 D.S. 4-2'~-~ ~~~ ~ TUBG ~U~ER RE~ORD (9-1~-94)~ 1 1 D.S. 5-4 STATIO PRE~URE SURVEY (9-19-94) 1 1 D.5. 5-19 STATIC PRE~URE SURVEY (9-20-94) 1 1 D.S. 7-24 ~, ~ ~ ~ STATIC BHP SURVEY (9-19-94) 1 1 D.S. 9-26 ~ ~/~ ~ ~ POGLM SE~ING RECORD (9-11.94) 1 1 D.S. 13-13 ~-I~ ~ LEAK DETECTION (9-20-94) 1 1 D.S. 15.37 ~ ~ ~ ~ STATIo BHP SURVEY/PERF RECORD ~9-15-94) 1 1 D.S. 16-5 ~ J - ~ STATiO BHP SURVEY/INJEO PROFILE ~9-16-94) 1 1 D.S. 16-14 ~ l ~ ~ ~ PROD PROFILE (9-8-94) 1 1 D.S. 16-22 ~ ~ PERF REOORD (9-11-94) 1 1 , I SIGNED: ~~ Plea~, ~ign and retu one copy of this transmittal to Sherrle at the above address. Thank you.- ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, ,horage, AK Transmittal #: 94023 99510,~ ~, Subject: ARCO Case.___C_d ~ From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution l Well !L°g DatelNumber (M-D-Y) T°°l Type ! RUn'scale C°ntract°r f 1-24A ~ 12-24-92 PFC/GR I 1, 5" Atlas ~ i PWDW I01-24-94 Staticpre~emp 1,5" Sch .~32:1 i 1-30-94 Parr Record 1, Cch P%3-1 I 2-5-94 CNL 1, 5" Sch I 3-20A I 2-2-94 i Perf Record 1, 5" Sch f 3-21 I 2-4-94 I Compi Record 1, 5" Sch i 3-25A I 2-4-94 CompIRecord ~ 1, 5" Sch i 3-27 f 2-3-94 t Prod Profile f 1, 1"&5" Cch i 3-32 i 1-25-94 ~1 Bridge Plug E~.i 1, 5" Sch ! 4-5 i 1-26-94 Tubing Cutter ~ 1, 5" Sch i 4-;~2 ~ 2-2-94 CompiRecord ~ 1,5" Sch F' 4-46 l 2-6-94 USIT/Cement 1, 5" Sch I",~ 4-46 i 2-6-94 PDC & Jewerly 1, 5" Sch I '5-35 ! 2-7o94I Leak Detec 1,2" Sch j//9-9 ! 2-7-94 LeakDetec 1, 2"&5" Sch ~'% 99.~ i 1-26-94 Leak Detec 1, 1"&5" Cch i 1-24-94 Bridge Plug%t~l ?.~..1, 5"('(5~j?'~ Cch 9-13 I 1-29-94 ~ Bridge Plug ~ 1, 5" Cch 9-20 1-24-94 Mi Inj Profile 1, 5" Cch 9-34 i 1-25-94 ¢;;)1 Bridge Plug ¢J~c. 1, 5" Sch I 11- 2-3-94 b~ Bridge Plug 1, 5" Cch 16ST1 , &<-: 1 t%~[0~--- ! 11-17 2-5-94 Leak Detec 1, 1"&5" Sch f 12-16A 2-2-94 Perf Record 1, 5" Sch /'14-2B 2-3-94 USlT/Cement 1, 5" Cch k, 14-2B f 2-4-94 Perf Record 1, 5" Sch 14-31I 2-4'94 Prod Profile 1, 5" Sch 15-9A 2-6-94 Perf Record 1, 5" Sch 15-22 2-6-94 Perf Record 1, 5" Sch 16-7 6-16-92 CasingCollar(~ 1, 5" Atlas 16-22 l 2-3-94 Gas lift survey' 1, 1" Sch 16-29A j 1-31-94 Prod Log 1, 1"&5" I Cch DS# 1-24ST the correct well name is 1-24A ** DS# 11-16ST1 the correct APl# is 50-029-21581-00 Number of Records:32 John E. DeGrey ARCO Alaska, Inc. Is a Sub~ldl~ of AtlantlcRIchfleldComcemy ARCO Alaska, inc. P.O. Box 100360, , ;orage, AK Date: Feb 25, 1994 Transmittal #: 94024 Subject: ARCO Static Pressure Surveys From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Well iLog Date Nurrber! (M-D-Y) 2-3 i 6-5-93 2-5 ! 7-21-93 3-8 i 11-22-93 3-19 I 1-3-94 3-34A i 11-22-93 3-35 i 12-7-93 l ! 3-36 i 7-24-93 4-12 i 11-17-93 ! !4-31!1-3-94 i 4-32 ! 9-8-93 q~,-i~'~ ! 4-41 ! 11-21-93 '~dlq* I 5-12 ! 7-21-93 ! 6-19 ! 11-28-93t I 7~A I 7-2:1'-93'' 11- ~ 9-5-93 16ST1 11-17 i 11-26-93 12-16A i 11-8-93 13-14f 7-2-93 13-14 ~ 7-2-93 t14-01 11-25-93 14-6 11-25-93 14-18 f 11-26-93 14-38 12-4-93 14-39 12-4-93 15-6 ~ 5-28-92 15-15 7-5-93 15-16 8-26-93 15-18 10-26-93 15-23 9-23-93 16-12 ! 7-21-93 16-17 12-29-93 16-18 7-18-93 16-22 ~ 7-18-93 17-1 ! 11-23-93 17-13 i 8-27-93 1S-29A t 5-19-93 Tool Type Static Press Surv. Run, Scale 1,5" Contractor Sch Static Press Surv. " Sch II Sch Static Press Surv. Static Press Surv. Static Press Surv. Sch ,, t Sch " Sch Static Press Surv. Static Press Surv. " Sch Static Press Surv. " Sch " Sch Static Press Surv.. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. " Sch " Sch " Sch ' ~ Sch II Sch " Sch " Sch " Sch " Sch " Sch " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. " Sch Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. Static Press Surv. II II Sch Sch Sch Sch Sch O.c.~ ARCO Alaska, Inc. Is m Sui3ddlary of AtianlicRIr. llfl~dCompany ARCO Alaska, Inc. P.O,Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~FINALS 1-19 ~10-1-93 1-22 ~- I-/~ /10-1-63 1-29 / 10-8-93 2-16A c~ ~-II~ -/9-29-93 3-9 ~10-6-93 3-29 ~ ~10-6-93 ~ 3-31 ~10-5-93 3-32 ~-~0~ ~0-5-93 3-33 ~0-10-93 4-4 ~[-~ ~0-9-93 4-12~ 10-2-93 - 10-1-93 6-12A ~- ~ ~9-29-93 6-13 10-1-93 7-5 ~-15 10-6-93 -28 10-0-03 .~ ~ o-~-,a 9-13 ~10-3-93 9-20 97-~ l ~ 10-7-93 ~11-168T ~10-1-93 12-22 ~-~0 /9-28-93 /~3-2o ~o-2-o3 ~13'20 /10-10-93 14-3~ ?~.~ ~ ~-25-93 14-3~ ~-28-93 14-32 ~10-2-93 15-22 ~-~ ~9-30-93 ~%-~O16-17 ~10-8-93 16-22 ~ ~10-10-93 17-15 ~ 10-8-93 17-16 ~Z-~ 40-3-93 17-21~. ~5~10-4-93 Perf Record Run 1. P_e~._Rr~d Run 1. Prod Profile/1~lx-~el ,~ta~ Run 1, USIT~t~ t ~~r R~ 1, Perf Record lttq~-~;7 R~ 1, Perf Record ~ ~ - ~ ~ R~ 1, Completion R~ 1, Pe~ Record R~ 1, lnJ ~offie }~7c~/~l~ R~ 1. ~ak ~tect]S~a]~t~/~ R~ 1, Perf Record ~ ~ 0~ - ~ I ~ ~ R~ 1, Peri ~pth Con~ol/~/~ R~ 1, Completion R~ 1, /Completion R~ 1, ~D~ B~t T~P R~ 1, ~ ~tect/~all~ ~$/6 a R~ 1, InJ ~offie I~,~[~?l&e$[~ R~ 1, D~ B~t T~P R~ 1, Inj ~o~e]sf~N~}*~)~ R~ 1, CNTG/GR/CCL R~ 1, HLDT/~[~ R~ 1, Completion Completion R~ 1, ~ 5~-~ R~ 1, ~oduction~m}~~/~ R~ 1, l"&5" ~ -~CSch ~, ~- io~oO Sch Please sign and return tho attached copy as re_ceipt of data. RECEIVED BY ~ Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON #BPX # STATE OF ALASKA The correct APl# for 1-22 is 50-029-20848-O0. The correct API# for 11-168T is 50-029-21581-00. The correct API# for 17-16 is 50-O29-22286-00. Trans# 93123 # LILLIAN # EXXON # MOBIL // ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS ?~'/ 14-2 3-3-92 PITS ?~-r~- 14-3 2-10-92 Leak Detect 72~? 14-4 2-11-92 Prod Prof ~-/ ~14-5A 2-29-92 Prod Prof * ~14-5A 3-17-92 PITS ? ~.~14-6 2-13-92 Jewelry ** ~16-9A 3-12-92 PITS ~/~g ( 16-9A 2-24-92 Jewelry ~/-~ ? 16-13 3-16-92 Prod Prof ~c-~/16-15 2-25-92 Prod Prof ~1'~ ~/~ 16-21 2-24-92 Prod Prof ?~ ~-/16-22 3-8-92 PITS ~/- ~)/ 17-8 2-26-92 InJ Profile ~f- ?/ 18-16 2-20-92 PITS R~_!n 1, 5" Camco R~_m 1, 5" Camco Rim 1, 5" Camco Rl~n 1, 5" Calnco Run 1, 5" Camco R~_m 1, 5" Camco Rnn 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco R!m 1, 5" C~_mco Rim 1, 5" Camco R!!n 1, 5" Ca/nco Rnn 1, 5" Camco Please sign and return the ,ECElV, Have A Nice Day! Sonya Wallace ATO-1529 attached copy as receipt of data. ~ ~ C ~IV ~ D APR 5 0 1992 Alaska Oil/& ~as Cons. Commission Trans# 92080 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF AI2~KA TEXACO The cOrrect well name for this log is 14-5A. The correct well name for this log is 16-92L STATE OF ALASKA --. ALASK~ '"LAND GAS CONSERVATION C~ ,vllSSION REPORT uF SUNDRY WELL OPERATIONS 1. '~perations performed: Operation shutdown Stimulate X Plugging Perforate 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 1742' FNL, 1271' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 3506' FNL, 5111' FEL, Sec. 17, T10N, R16E, UM At effective depth 1928' FSL, 309' FWL, Sec. 17, T1 ON, R16E, UM At total depth 1906' FSL, 518' FWL, Sec. 17, T10N, R16E, UM 5. Type of Well Development X Exploratory ,, Stratigraphic Service 6. Datum of elevation(DF or KB) 70 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-22 9. Permit number/approval number 90-51/90-535 10. APl number 50 - 029-22040 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 14238 feet Plugs(measured) 9207 feet Effective depth: measured 14148 feet true vertical 9136 feet Junk(measured) Casing Length Size Cemented Measured depth Conductor 80' 20" 280 sx CS II 112' Surface 4281' 13-3/8" 2500 sx CS III & 600 sx CI 'G' 4351' Production 13874' 9-5/8" 450 sx Cl 'G' 13944' Liner 626' 7" 220 sx Cl 'G' 14230' True vertical depth 112' 3496' 8978' 9202' Perforation depth: measured 13993-14002'; 14002-14012'; 14016-14024'; 14028-14040'; 14050-14068' true vertical 9016-9023'; 9023-9031'; 9034-9040'; 9043-9052'; 9060-9074' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, IPCT @ 13670' MD Packers and SSSV (type and measured depth) Baker SB-3A packer @ 13553' MD; Otis HRQ SSSV_('~,2207' MD 13. Stimulation or cement squeeze summary ~~,C ~ ~1 t,- '"- Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Representative Daily Average Brodu~ion or Inie'c~'~D~t¢~, OiI-Bbl Gas-M~ Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3943 2158 83 -- 341 Subsequent to operation 4703 2859 417 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run .... I Daily Report of Well Operations __ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-~'04 Rev 06/15/88 / Service, Title Sr. Area Operations Engineer 303 Date 2./~.Z..,/~ ./ SUBMIT IN DUPLICATE 672 DRR c: J. Gruber, ATO-1478 DS 16-22 DESCRIPTION OF WORK COMPLETED MUD ACID STIMULATION TREATMENT 10/7/90: A Mud Acid Stimulation was performed as follows: MIRU CT & PT equipment to 4000 psi. Loaded wellbore w/390 bbls of Crude. RIH w/CT & treated open perforation intervals at: 14002 - 14012' MD (Z2) Ref. Log: OH CNL 5/27/90. 14016 - 14024' MD (Z2) Pumped: a) 11.9 bbls Xylene, followed by b) 11.9 bbls 2% NH4CI Water, followed by c) 23.8 bbls 12% HCl w/10% Xylene, followed by d) 47.6 bbls 6% HCl - 1.5% HF, followed by e) 47.6 bbls 3% HCl w/5% mutual solvent, followed by f) 210 bbls Dead Crude, followed by g) 5 bbls Diesel. Rigged down. Flowed well. 10/22/90: Added perforations: 13993 - 14002' MD (Z3) 14028 - 14040' MD (Z2) 14050 - 14068' MD (Z2) Ref. Log: OH CNL 5/27/90. Obtained a valid production welltest. ARCO ALA,.?KA~ INC, P,O, BOX JOOL~60 ANCHOF,'A(.i['[~ AL.A,~K A 995~0 DAI'E' J'2 .... tt--.90 4 .... 24 · ~ J '"' 3- 9'.':) !::' E R F F;,' E C 0 FL: D 4 .... 3 2 · ~ ~ .... 9 .... 9':') F:' R 0 D F:' !:;: 0 F:' I !... E / F:' I T' 3." 6 .... t 4. J () .... 26'"' 9 C) P Ii:. R F:' I:~'. E C 0 I:;:. D ~i .... 4- ~'l .... i'i-9() F'IT'5' 'i t .... 6 ~ 9-t 9 .... 9(') 'I'HD-B(~I'?AX t I '- 1 t ~ t t '- t 2'"' 9 (') P I 'f',~ t t-i t' t t .... t 2-9(') 'I'BG COL. I..AR t 2-'2. ' t I .... 2 6 - ? 6' I=' E R F t 2- t "~' t ''~ " ,.. '"' g - 9 r.', C 0 L I... A R / P E R F' 'i4 .... ~(), 'it .... 9"-'9() I...EAK DETECTION i 4 .... 'i C:'. i t .... 9 .... 9(') 'l"B6 COL. I...AI::~ t 4 .... 13 S, ~ 'i .... 'i 4 -9 C:' C 0 i...I... A R /6 I'? / C C I... "i I::' s : ·..,'- .... 'i (."., · i i .... 1 .a .... c;, r.',F:' E F;.:F: I:;.: E C: 0 R D t5-'"' 2. 'i · t 'i -5: .... 9 (:;' F:' E R I::' t5:"- 2 i' i i .... '?- 9 (') P :i: T :5' / T I:'i: H F" 'i 6-'"6' 'i 'i/t cF' .... 2,."~:'/9(=':, I...EAI'-':'. DETli:CTION "i 6 .... 2 2' i i .... t 8 .... 9'::} I::' R 0 D F:' R 0 F: I !... E F:' I... iii: A S IE :!i: I (:.; N A N D F~: li:':"f' L.J R i".J. T I"1 Iii: A"f' T A C !"I Ii"_' D C 0 F:' Y A S !..I A V I.:.': A i,J, I C': Iii: D A Y ! RLJN t, RUN t, RLJN t , F:tJN t, RUN t , RUN t, RLJN t , RLJN t, F;,'LIf,I 't, F;:L.IN '1, RLIN t, RLJN t, RUN t , I::.:UN t , I:;:UNJ, Rt...I N t , I~I..JN 2, f;.' U N 2, RIECE:ILI::'T OF DA"f'A, 5" 5" 5" 5' 5" 5' '5 ' 5' 5" 5" 5" .5" 2"&5" 5" I..ll...,S' C A I,~ C.: 0 I..I I... ,S' C A fl C 0 I-IL.,.? CAMCO C A H C 0 HL.S A TL..A:.~' t.-IL.,S C A M C 0 C A Pt C 0 C A t'i C 0 C A H C 0 H !...,.? !..i !... :.~;' C A H C 0 C A H C O C A H C 0 D I $ T R I B U '1" i 0 N · ..'"' C E i",l 'F R A L F I L E $ ~,. C I--! [:.:' 'V' F;..' 0 N D & M -.- EXTEN,.?ZON EXPL. ORA'i" I ON 31. · .- E X X 0 N f't A F;: A T I"10 N -~ HOBII_ F'H I I..L I F:',.? F:'B WELl_ F'ILES R & D :,": BF'X '"' STALE OF ALASKA 1' TEXACO RECEIVED DEC 1 1990 Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INC. F'..O,, BOX t00360 ANCHORAGE, ALAS'KA 995. _ DATE' t 0-3t REFERENCE' AF,'CO CASED HOLE FINAL'J,' t -7 t 0--t S-90 COLLAR 4-5 9-t 3-90 F'ERF RECORD 5-t 4 i ~-,, t ...°-9~.') CC[. PERF RECORD 7-2.5 i 0',"-2 t -9£) COLLAR/PERF' 9-44 t ¢-':2¢-9(~ CBT 9-44 t O-2e-'-?e CET i i -9 i ¢-8-90 F'ERF t 4- i 9-2-9,'-5 COLLAR i 5-6 t ¢'--i 9-96' COL/..AR/PERF t .5 6 t ;.-}-i 9--9'3 6R/..,UL t 5-t 6 i ¢-2(-}-9¢ COI...LAR/TBC- CUTTER t '=:-t A t ;:; -- '-' "~ - q:' O C..CL/TB6 CUTTIER t 5-2t t ,:.-}-i 5:-9() F'ERF RE:COF;.:D i 6-22 i ¢--22-9G COLL_AR/F'EF;,'F: i,_,c:' .. i i c;,, - .~.":' :5 - ':;', '":'~,, P E R F' F.: E: C 0 F;:. D F'I_EA.'?E ;~I(;N AND i:;.:FTURN THE A'T"i'ACHf:'£:, F.:ECEIvE.~ Be ........ FiAVE A N!C'E DAY! ::i! A L L Y H 0 F F:' E: C K E R ATO- '~. 52°,- RUN t , RUN t , RUN i, RUN t , RUN i , RUN i , RUi'~.i, RUN i , RUN i , RUN t , F;,' U N t , KUN i, F<UN ~ , RUN i., F;:.UNi , COF'Y' A~ F;I::'CE:LPf' OF DATA.,. APF'ROVFI) ~ 'i'F;.iAN:':::~ 9¢q i 8 · 5" 5" 5" 5" ._, 5." 5:" 5" HLS' HL~ H'L£' A FLA~: 5'CH &' C 14 I-!l.~' HL~2 ATLAS ATLAS A ATI_A,? I.iL ~? A f'l_A:? FIL.~; D t 5'TR I BIJTI ON '~ CENTRA~ F:[I..E$ -,.""CHEVRF]N. . D & M '"' EXTEN.'£I ON E:XF'L. ORAT I ON ~-- EXYON, MARATHON · ~" MOBIL * THE AF'I~: FOR t-7 I5' 5C~-~29-':2C~i57. ** THE AF'I~ FOR t5-2t I$ 5C)-~29-2'.~50.5, PHILLIPS PB WELL FILE2. l;: D BF'X .'~TATE OF ALASKA TEXACO RECEIVED NOV 0 1 1990 Alaska 0il & Gas Cons. Commission Anchorage ARCO ALAZKA: J'NC~ P~, O, BOX i 00,¥,66,' ANCHORAGE., ALA;~KA DATE' 9-t :5-90. REFERENCE' ARCO CASED HOLE F!NAL:-'~,' i ~ '-':'" 8- 'i 5- 9 0 F' E RF R,:. C 0 R D R U N i , 4-4 '?-i i .-iF',:-], F'EF'.F RECORD RUN i , 4--i,:;:, 7-2i-9¢ (.'-;AMM/4 CORt:;.~.. W~ F'EF;:.F: RECORD F.:L!r'4 i, · 4- i ':.:;'8-5-9'.':.:' F'ERF RECORD 14.'UNi , 5:-- i i 8- i 8 - 90 P Z T £ R. U i"4 i , 6-.i '"~ 7-22-90 PERF RECORD RUb! i., '7'-'5 7---Si-9':") r"ERF RUN i, ,'-..: ,.'-..~i .-o,-:; PERF RECORD ,;' ~t,.~ -, 7 .-- i .'.f 8 -.. i 9 '--9,:.],P ]: T£ F..' U N ! , 7 - S 4 '7.- 22 .- 9 (.-~ ?' ..':'_ R F R E C 0 R O R U N 'i , 9-4i 8-'i 5-9¢ C;-F;:./COLLAR RUN t , if-4 8-8-90 F'RODUCTION F'ROF:tLE RUN i., i 'i ...,,:.'-" c,,..., 8 .... i 8 - o,. ,2. C': 0 L L ¢4 R R U N. i , i 2---i i , ~_..--'~0 PEp~' RECORD I;:UN i , i 3;- 7 8-- i 5- - 9 ¢ P l T ':.: R tJ Ni: t 5-'7 8--i "7-9¢ PZT£ RIJN t., i S-i 2 8-i 6-':;;'¢ PRE-FRAC -['EMP I:;.:UN t , f 4--5 8-2¢-9¢ COLLAR RUN t , i6-7 8-i7-9,:.} PRODUCTION PROFILE RUN t, t 6'-'.-"":',. ,....., ,S-i ,:..,'.~.-c~6, .. PRODUCTION r"ROFILE RUN t , i 6-22 7-6-9(::, GAMMA COLLAF:./PEF;¢F RECORD F:.UN -, Ft_,:.,-~r-_' "'""'"' :~T!GN AND RETUF;,'N THE ATTACHED COF'Y A,~" RECEIF"F OF DATA. ,?AI..LY HOF'FECK ER ATO-'i "~'-" ¢ SEP 1 9 1990 Alaska Oil & Gas Cons. Comm~ss'tot~ Anchorag~ AI::'F'ROVED · DI£TRIBUTION '"' CENTRAL FILE'J '~,~ CHEYRON D & M · ,~'* EXTEN,?, I ON. EXPLRRAT I ON. _ -,,-'~ EXXON MARATHON :~ MOBIL. · ,-'"' F'HILLIF'$ PB WELL F]:LEZ c~ D ~' BF'X ~' ZTATE OF ALAZI<A TEXACO HL. 3' H L ,'ii: i.! i... ,? iL.: ~':'."~ i"i (i: E: H L.. l,.t t ':," i.4, t... C A f'i C 0 H L.,'~: C A M C 0 C A i'fi C O C A M C 0 I.-t L;;" CAHCO CAMCO C A M C 0 Ii]: A Fi C 0 C A H C': 0 C A H C 0 H 1...,?;.' THE CORRECTED AF']:.~ F'OR i-i0 I5' 5'0-'::;'29-20169, ARCO Alaska, Inc. Post Office B,. i00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 15, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 16-22 corrections Dear Mr. Chatterton: Please replace the existing DS 16-22 Well Completion Report (10-407) dated 8/10/90 with the attached revised report, dated 8/15/90. If you have any questions please feel free to call me at 263-4618. Danielle Warner Engineering Aide DW cc: File W1-1 ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,RECEIVED .. r £V '- STATE OF ALASKA '-' AL/:,.. .A OIL AND GAS CONSERVATION COt' ...... SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG l Statu~ ,,'Well Classification ofS~ic~/el~ G OIL ~--~ GAS r"-] SUSPENDED r'~ ABANDONED [--'1 SERVICE ,,, 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-51 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22040 4 Location of v~ell at surface 9 Unit or Lease Name At Top Producing Interval 1907' FSL, 213' FWL, SEC 17, T10N, R16E UM ~t;~~,~__ 16-22 At Total Depth ~,~ ~,~ 11 Field and Pool 1942'FSL, 374'FWL, SEC 17, T10N, R16E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 70' ADL 28346 ALK 2330 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 04/28/90. 05/25/90. 07/06/90* N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 14238' MD/9204' TVD 14148' MD/9135' TVD YES [~1 NO ['--] 2207' feet MD 1900' (approx) 22 Type Electric or Other Logs Run GR/DIL/Z-DEN/CNL, GR/DIL, CBT/CET/GR/CCL, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 SURF 112' 30" 275 SX CS II 13-3/8" 68.0# L-80 SURF 4351' 17-1/2" 2000 SX CS III & 600 SX CLASS G TOP JOB W/300 SX CS II 9-5/8" 47.0# L-80 SURF 13944' 12-1/4" 450 SX CLASS G 7" 29.0# L-80 13605' 14233' 8-1/2" 220 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) - SIZE DEPTH SET (MD) PACKER SET IMD/ 4-1/2" 13671' 13553' 14002'-14012'MD/9023'-9030'TVD W/4 SPF, 180° PHASING 14016'-14024'MD/9033'-9040'TVD W/4 SPF, 180° PHASING 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. [CEIVED Ancl~ora[:,e, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS .... ., NNV~ Include interval tested, pressure data, all fluids recoverd and gra'/ity, ME. AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 13993' 9016' HOT 14068' 9074' OWC 14122' 9115' NONE i OWC 14136' 9126' I I 31. LIST OF ATTACHMENTS GYROSCOPIC SURVEY (2 COPIES)~ ADDENDUM (SIGNED 8/6/90) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~, ~/'~.~/ ~ ~/£~'~-J[~ Title DRILLING ANALYST Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA ~" AL., ,CA OIL AND GAS CONSERVATION C(.,,..,vllSSION WELL COMPLETION OR RECOMPLETION REPORT i,, I Status of Well ClassifiCatio~f ~victe v~e~l ~ ~ '~ OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE ~ 2 Name of O~ator 7 Pe~it Numar ARCO Al~ka, Inc ~-51 3 Addre~ 8 APl Numar P.O. ~x 1003~, Anch0ra~e~,AK ~51~0 ,_ .... ~-0~-22040 4 Loca~on of well at surface /~..~ ~- C-~~ ~~..~ .... 9 Unit or Lease Name 17~ 1271' ~L, SEC~T10N R15E UM --~[E~ PRUDHOE BAY UNIT ~o )~ At Top Producing ~ ~ ~ Well Numar ~ ~-~ F; ' 16-22 '_~t To~ '----~ , ................. . 11 Field a~ Pool '~ 5 Elevation in f~t (indi~te KB, DF, etc.) ~ 6 L~ Designa~on ~d ~Hal ~. PRUDHOE BAY OIL POOL RKB 70'~ ADL 28346 ALK 2~0 12 Date Spud~ 13 ~m T.D. R~ch~ 14 Date Comp., Susp. or A~nd. 15 Water Dep~, if offshore ~16 No. of Completions ~/28/~. 05/25~. 07/06~0' N/A f~t MSL~ 1 ...... 17 To~l Dep~ (MD+~D) 18 Plug ~ck ~p~ (MD+TVD) 19 Dir~tional Suwey ~ ~p~ ~ere SSSV ~t 21 Thick,ss of ~r~frost 14238' MD/9~4' ~D 14148' MD~I~' ~D YES ~ ~ ~ 2207 f~t MD 1~0' (approx) ~ Ty~ El~c ~ O~er Logs Run GR/DI~Z-DEN/CNL, G~DIL, CBT/CET/GR/CCL, GCT -- , , 2~ CASING, UNER AND CEME~N~ RECORD SE~NG DEPTH aO ' C*S~ S~Z~ ~. PER ~. ~RAO~ TOP m~ ~LE S~ZE C~ME~ .ECORO *UOUNT PU~LEO ~" 91.5~ H-40 SURF 112' 30" 275 SX CS II 13-3/8" 68.0~ L-80 SURF 4~ 1' 17-1/2" 2~ SX CS III & 6~ SX C~SS G TOP JOB W/3~ SX CS II ~5/8" 47.0~ L-80 SURF 13944' 12-1/4" 4~ SX C~SS G , ~ 29.0~ L-80 13605' 14233' 8-1/2' 2~ SX C~SS G , , ~ , 24 Pedorafio~ o~n to Production (MD+~D of Top a~ ~om and 25 TUBI~ RECORD intew~, size and numar) SIZE DEPTH SET [MD) PACKER SET 4-1/2' 1~71' 13553' ,14002'-14012'MD/~23'-9030~D W/4 SPF, 1~° PHASING , ,, 14016'-14024'MD/~33'-9~0~D W/4 SPF, 1~° PHASING ~ ACID, FRACTURE, CEME~ SQUEEZE, FTC DE~ I~ERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A , , , , 27 N/A P~DUCT~N TEST Date First Production ~Me~od of O~a~n (FIo~, gas li~ etc.) I , Date of T~t Ho~s Test~ ~T~N FOR OIL-BBL GA~MCF WA~R-BBL CHOKE SI~ ~ GA~OIL ~TIO I ~ST ~RIOD ~ Flow Tubing Ca~ Pm~e CALC~D OIL-BBL GAs-MCF WA~R-BBL OIL GRAVEY-API (co~) Pre~. 24-~ ~TE ~ 28 CORE DATA Brief de~ription of li~ology, ~rosi~, Eac~ms, ap~ent di~ ~d pres~ce of oil, gas or wat~. Sub~t co~ chi~. NONE *NOTE: DRILLED & TUBING RUN ~0. PERFORATED WELL 7/6~. ~..~,~ ..... Form 10-407 Submit in duplicate Rev. 7-1-80 ~NUED ON REVERSE SIDE WELL HISTORY ADDENDUM WELL WORK LOG Well # 16-22 Work performed: INITIAL PERFORATIONS Cost: $2JZ,.5..Q.0_,.0~ AFE: AS3595 Date' 07/06/90 Time Summary O83O 1200 2220 0155 O33O MIRU HLS. PT bop & lub RIH w/gun #1, @ 180° phasing, orient. Shoot gun #1 f/ 14016'-14024'. ASF. Shoot gun #2 f/ 14002'-14012'. ASF. RD. RIH w/ gun #2. DRILLING SUPERINTENDENT I ' Teleco'Oilfield ~"'"'~ces of Alaska Inc. 6116 Nietson V% Anchorage, AK 99502 (907) 562-2646 OJ{i&iNA/ June 21, 1990 JOB #758 WET,T,; DS-[6-22 PRUDHOE BAY RIG: NABORS 28-E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveYs or any of our other services. Sincerely, Jonathan G. Mapes Field Operations Supervisor JGM/el Enclosures A J,~lllJlJ'l' COMPANY TELECO OILFIELD SERVICES SURVEY CALCULATIONS May 23, 1990 2ompany: ARCO ALASKA INC. Sell: DRILL SITE #16 WELL #22 Location: PRUDHOE BAY ~ig: NABORS 28E PELECO Job # ]rid Correction: ~agnetic Declination: Potal grid correction: Proposed Direction: 758 TAK 0.0° 30.8' 30.8' 69.2' MINIMUM CURVATURE CALCULATION 4eas Course True Vertical Coordinates Closure Dog Leg )epth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' INITIAL TIE-IN COORDINATES 428 0 0.6 266.3 427.99 -0.99 ].53N 1.64W 2.24 N 46.99W 0.00 TELECO MWD SURVEYS 633 205 2.5 79.0 632.94 2.39 2.31N 1.68E 2.86 N 35.96E 1.51 817 184 7.4 70.2 816.20 18.20 7.10N ]6.78E ]8.22 N 67.07E 2.69 LO08 191 11.3 62.1 1004.63 49.08 20.02N 44.90E 49.].6 N 65.96E 2.15 L197 189 16.5 72.6 1188.06 94.29 36.'/3N 86.9]E 94.35 N 67.09E 3.05 PAGE Company: ARCO ALASKA INC,, Well: DRILL SITE #16 WEI,I, #2_2_, l,ocation: PR[IDHOE BAY, .R._i~q: NABORS 28E ~eas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100' 1388 191 19.1 67.7 1369.91 152.62 56.70N ].41.72E 152~64 N 68.19E 1.57 1579 191 23.1 69.2 1548.07 221.35 81.88N 205.68E 221.38 N 68.29E 2.11 ~769 190 26.7 67.4 1720.38 301.32 111.53N 279.96E 301.35 N 68.28E 1.94 1957 188 28.9 68.8 1886.68 388.97 144.19N 361.32E 389.02 N 68.24E 1.22 2141 184 30.0 74.0 2046.93 479.29 172.95N 447.00E 479.30 N 68.85E 1.51 2333 192 32.4 71.2 2211.15 578.55 202.77N 54].86E 578.55 N 69.48E 1.46 2525 192 36.6 69.1 2369.36 687.24 239.78N 644.07E 687.26 N 69.58E 2.27 2714 189 41.9 67.0 2515.67 806.74 284.57N 754.89E 806.74 N 69.34E 2.89 2902 188 48.3 66.3 2648.31 939.71 337.37N 877.07E 939.71 N 68.96E 3.41 3096 194 54.4 65.6 2769.41 1090.90 399.12N 1015.34E 1090.97 N 68.54E 3.16 3317 221 55.5 65.3 2896.33 1271.43 474.29N ].].79.90E 1271.66 N 68.10E 0.51 3541 224 54.2 66.3 3025.29 1454.25 549.38N ].346.95E 1454.68 N 67.81E 0.69 3764 223 53.9 69.5 3156.23 1634.69 617.29N ]514.17E 1635.16 N 67.82E 1.17 3987 223 55.1 65.6 3285.76 1816.10 686.64N 1681.88E 1816.64 N 67.79E 1.52 PAGE 2 Company: ARCO ALASKA INC., Well: DRILL SITE #16 WELL ~, Locati. oo: PRUDHOE BAY, R~g: NABORS 28E ~eas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0' ~303 316 53.8 69.5 3469.53 2073.00 784.85N 1919.39E 2073,65 N 67.76E 1.09 t621 318 55.0 68.0 3654.65 2331.54 878.58N 2160.35E 2332.17 N 67.87E 0.54 %937 316 56.1 71.9 3833.45 2592.01 967.83N 2405.07E 2592.51 N 68.08E 1.08 ~253 316 58.4 70.2 4004.39 2857.61 1054.18N 2656.39E 2857.92 N 68.35E 0.86 5602 349 57.0 65.3 4190.96 3152.36 1165.73N 2929.32E 3152.75 N 68.30E 1.25 ~906 304 55.8 66.3 4359.19 3405.12 1269.54N 3160.26E 3405.73 N 68.11E 0.48 ~223 317 57.0 67.0 4534.61 3668.88 1374.17N 3402.67E 3669.68 N 68.01E 0.42 5534 311 56.0 68.1 4706.27 3928.10 1473.22N 3642.34E 3929.00 N 67.98E 0.44 ~863 329 56.3 69.5 4889.53 4201.32 1572.02N 3897.07E 4202.19 N 68.03E 0.37 7175 312 55.7 71.2 5064.01 4459.91 1659.01N 4140.65E 4460.64 N 68.17E 0.49 ~490 315 56.0 70.0 5240.84 4720.51 1745.60N 4386.53E 4721.09 N 68.30E 0.33 ~803 313 56.1 68.1 5415.66 4980.13 1838.43N 4628.98E 4980.69 N 68.34E 0.50 3118 315 53.6 69.8 5597.00 5237.65 1930.98N 4869.30E 5238.20 N 68.37E 0.91 PAGE 3 ~ompan¥: ARCO ALASKA INC., Well: DRILL SITE #16 WEL!, ~a Loc~tjop; PRUDHOg BAY, Rig: NABORS 28E Ieas Course True ~Vertical Coordinates Closure Dog Leg )epth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity ~eet feet deg deg feet feet feet feet feet deg deg/100° 1430 312 54.2 72.3 5780.85 5489.58 2012.81N 5107.70E 5490,00 N 68.49E 0.68 [746 316 55.1 71.9 5963.68 5746.98 2092.04N 5352.96E 5747.25 N 68.65E 0.30 ;072 326 54.4 70.5 6151.83 6013.03 2177.81N 5604.98E 6013.21 N 68.77E 0.41 ;384 312 55.4 67.0 6331.27 6268.22 2270.35N 5842.80E 6268.40 N 68.77E 0.97 ;690 306 56.0 64.0 6503.73 6520.43 2375.18N 6072.77E 6520.74 N 68.64E 0.83 )001 311 55.1 66.0 6679.67 6776.17 2483.58N 6305.17E 6776.68 N 68.50E 0.60 )347 346 55.5 65.6 6876.64 7060.13 2600.18N 6564.63E 7060.83 N 68.39E 0.15 )664 317 54.2 68.1 7059.16 7319.07 2702.11N 6802.90E 7319.90 N 68.34E 0.76 )978 314 55.4 67.0 7240.16 7575.53 2800.].1N 7040.02E 7576.44 N 68.31E 0.48 [325 347 55.4 70.5 7437.24 7861.08 2903.60N 7306.16E 7861.99 N 68.33E 0.83 [639 314 56.7 72.3 7612.61 8121.33 2986.65N 7553.02E 8122.08 N 68.42E 0.63 [795 156 57.6 72.3 7697.23 8252.19 3026.49N 7677.87E 8252.83 N 68.49E 0.58 k968 173 58.7 71.6 7788.52 8398.97 3072.03N 7817.58E 8399.52 N 68.55E 0.72 PAGE 4 ,"ompan. v: ARCO ALASKA INC,, Well: DRILL SITE #16 WELL ~.2..2, Location: PRUDHOE BAY, Rig: NABORS 28E 4eas Course True Vertical Coordinates Closure Dog Leg )epth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0° ~288 320 62.5 72.3 7945.58 8677.39 3158.36N 8082.61E 8677,78 N 68.66E 1.20 2501. 213 54.9 72.6 8056.16 8858.96 3213.22N 8256.00E 8859.25 N 68.73E 3.57 2645 144 51.8 74.0 8142.11 8974.18 3246.44N 8366.63E 8974.40 N 68.79E 2.29 2811 166 52.2 75.4 8244.31 9104.38 3280.95N 8492.80E 9104.52 N 68.88E 0.71 2972 161 53.3 71.2 8341.79 9232.16 3317.80N 8615.50E 9232.25 N 68.94E 2.19 3093 121 53.7 71.2 8413.76 9329.36 3349.14N 8707.57E 9329.44 N 68.96E 0.33 3195 102 54.1 71.9 8473.86 9411.71 3375.22N 8785.75E 9411.78 N 68.98E 0.68 3361 166 50.1 70.5 8575.82 9542.59 3417.38N 8909.73E 9542.63 N 69.02E 2.50 3613 252 45.2 71.6 8745.53 9728.67 3477.91N 9085.80E 9728.70 N 69.05E 1.97 3925 312 40.0 75.4 8975.15 9939.13 3538.]_8N 9288.04E 9939.14 N 69.15E 1.86 PAGE 5 TEL,_.CO Oi 1 fie ld PLAN VIEW Service~ ~.600 ARCO ALASKA INC. DRILL SITE #16 WELL #22 PRUDHOE BAY NABORS 28E JOB# 758 TAK/O0 SCALE: 1 inch = 1600 feet +~6534 ' +J5253 ' +/3987 ' 12800 11200 9500 8000 ,~.-. .__. 6400 4800 + 639 ' 1600 1600 3200 . 4800 6400 EAST (ft) 8000 TELL~O 0 ~ 1 f i e 1 d Se r v ~ c e s VERTICAL PROJECTION -lO00 lO00 3000 5000 7000 9000 11000 2000 ,~000 -5000 4--, -BO00 >~0000 12000 14000 15000 18000 l~oos ' ~.~ -1~141 ' 30 deg :~4 ' 4l.~ oeg "4.~4i ' 54.~ deg 3 ' 53.8 aeg . 57 oeg ,~W. x7,75 ' 55.7 deg 8 ' 53.6 978 ' ~5.4 Oeg 95 ' 57'6 ~g ceg ARCO ALASKA INC. DRILL SITE #16 NELL PRUDHOE BAY NABORS 28E JOB# 758 TAK/O0 SCALE: 1 inch = 2000 feet #22 deg VERTICAL SECTION (ft) ORIGINAL ~UB'~URFACE DIREcI'IONAL ~URVEy ~UIDANcF. I~ONTINUOU$ ~./OOL do~b ~eference No. 73950 ~ g-JUN-90 S A R B £ R C__omputecl 8~ KRUN£LL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. D.S. 16- 2Z PRUDHOE BAY NORTH SLOPEr ALASK* SURVEY DATE: g-JUNE-gO ENGINEER: G. SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 59 DEG 11 MIN EAST COMPUTATION DATE: 9-JUL-90 PAGE I ARCO ALASKA INC. D.S. 16 - 22 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 9-JUNE-90 KELLY BUSHING ELEVATION:. 70.00 FT ENGINEER: G. SARBE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL OOGLEG RECTANGULAR COORD[NATES HDRIZ. OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -70.00 0 0 N 0 0 E 100.00 100.00 30.00 0 14 S 71 42 W 200.00 200.00 130.00 0 8 S 4 15 E 300.00 300.00 230.00 0 12 N 83 0 W 400.00 400.00 330.00 0 16 N 45 45 E 500.00 499.99 429.99 ! 5 N 66 25 E 600.00 599.93 529.93 2 45 N 74 35 E 700.00 699.68 629.68 5 26 N 69 3'7 E 800.00 798.98 728.98 8 ZO N 67 57 E 900.00 897.71 827.71 10 5 N 65 39 E 0.00 0.00 0.00 N 0.00 E -0.25 0.13 0.05 S 0.25 W -0.44 0.61 0.26 S 0.38 W -0.67 0.00 0.29 S 0.60 W -0.79 0.93 0.18 S 0.78 W 0.38 1.19 0.35 N 0.27 E 3.61 2.45 1.27 N 3.38 E 10.57 3.66 3.43 N 10.01 E 22.35 1.98 7.64 N 21.01 E 38.16 2.51 13.92 N 35.54 E 0.00 N 0 0 E 0.25 S 79 ZO W 0.46 S 55 45 W 0.67 S 64 2 W 0.80 S 77 22 W \ 0.45 N 3? 40 E 3.61 N 69 28 E 10.58 N 71 6 E 22.35 N 70 2 E 38.16 N 68 37 E 1000.00 995.94 925.94 11 27 1100.00 1093.44 1023.44 13 57 1200.00 1190.04 1120.04 15 56 1300.00 1285.70 1215.70 18 1 1400.00 1380.34 1310.34 19 38 1500.00 1473.91 1403.91 21 44 1600.00 1566.11 1496.11 23 42 1700.00 1657.22 1587.22 24 59 1800.00 1747.32 1677.32 26 24 1900.00 1836.15 1766.15 28 6 N 65 41 E 56.86 2.58 N 70 2 E 79.01 2.28 N 70 21 E 104.83 2.14 N 68 29 E 133.96 2.26 N 68 20 E 166.25 1.75 N 68 13 E 201.49 2.49 N 65 42 E 240.18 1.88 N 65 17 E 281.27 1.94 N 67 6 E 324.60 1.72 N 68 10 E 370.50 0.82 21.78 N 52.55 E 56.89 N 67 .30 E 30.02 N 73.12 E 79.04 N 67 40 E 38.54 N 97.49 E 104.84 N 68 26 E 48.88 N 124.73 E 133.96 N 68 36 E 60.79 N 154.75 E 166.26 N 68 33 E 73.72 N 187.54 E 201.51 N 68 32 E 88.85 N 223.17 E 240.21 N 68 17 E 106.14 N 260.56 E 281.35 N 67 50 E 123.64 N 300.26 E 324.72 N 67 37 E 141.03 N 342.76 E 370.64 N 67 38 E ZO00.O0 1924.11 1854.11 28 36 2100.00 2011.76 1941.76 29 6 ZZO0.O0 2098.84 2028.84 29 57 2300.00 2184.80 2114.80 31 21 2400.00 2269.79 2199.79 32 18 2500.00 2353.24 2283.24 34 52 2600.00 2433.46 2363.46 38 21 2700.00 2509.85 2439.85 41 56 2800.00 2582.40 2512.40 45 18 2900.00 2650.59 2580.59 48 17 N 70 3 E N 74 18 E N 74 33 E N 71 59 E N 70 12 E N 69 55 E N 68 45 E N 67 16 E N 67 32 E N 66 43 E 418.06 2.51 466.10 0.97 515.05 1.42 565.99 Z.1Z 618.65 1.64 673.74 3.63 733.40 3.51 797.90 3.04 866.65 4.39 939.74 2.07 158.31 N 387.06 E 418.19 N 67 45 E 172.76 N 432.97 E 466.16 N 69 15 E 185.86 N 480.35 E 515.06 N 68 51 E 200.34 N 529.35 E 566.00 N 69 16 E 217.68 N 579.09 E 618.66 N 69 24 E 236.37 N 630.92 E 673.7~ N 69 28 E 257.47 N 686.73 E 733.41 N 69 27 E 281.66 N 746.53 E 797.90 N 69 20 E 308.25 N 809.98 E 866.65 N 69 10 E 336.46 N 877.45 E 939.74 N 69 I E 3000.00 2716.09 2646.09 49 58 3100.00 2777.41 2707.41 54 44 3200.00 2833.50 2763.50 56 18 3300.00 2889.43 2819.43 55 39 3400.00 2946.15 2876.15 55 17 3500.00 3003.65 2933.65 54 28 3600.00 3062.33 2992.33 53 59 3700.00 3120.57 3050.57 54 32 3800.00 3178.90 3108.90 54 32 3900.00 3235.78 3165.78 56 3 N 65 34 E 1015.18 N 64 22 E 1093.92 N 63 48 E 1176.36 N 63 47 E 1258.89 N 64 3 E 1340.90 N 64 39 E 1422.42 N 65 42 E 1503.19 N 67 8 E 1584.38 N 68 39 E 1665.59 N 68 2 E 1747.82 2.45 4.91 0.63 1.06 0.60 0.85 1.06 1.92 1.54 1.13 367.15 N 9%6.48 E 1015.20 N 68 48 E 400.49 N 1018.05 E 1093.99 N 69 32 E 436.81 N 1092.44 E 1176.53 N 68 12 E 473.44 N 1166.80 E 1259.19 N 67 55 E 509.69 N 1240.76 E 1341.37 N 67 40 E 545.08 N 1314.52 E 1423.05 N 67 29 E 579.10 N 1387.99 E 1503.96 N 67 21 E 611.74 N 1462.44 E 1585.23 N 67 18 E 642.02 N 1537.81 E 1666.45 N 67 20 E 672.28 N 1614.28 E 1748.68 N 67 23 E COMPUTATION DATE: 9-JUL-90 PAGE ARCO ALASKA INC. D.S. 16 - 22 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 9-JUNE-90 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: G. S~RBE~ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTUR~ MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG )liN 4000.00 3291.77 3221.77 55 33 4100.00 3348.88 3278.88 54 56 4200.00 3406.77 3336.77 54 22 4300.00 3465.44 3395.44 53 50 4400.00 3524.64 3454.64 53 39 4500.00 3583.52 3513.52 54 18 4600.00 3641.64 3571.64 54 33 4700.00 3699.36 3629.36 55 0 4800.00 3756.46 3686.46 55 20 4900.00 3813.09 3743.09 55 41 5000.00 3868.99 3798.99 56 34 5100.00 3923.14 3853.14 57 46 5200.00 3976.06 3906.06 58 14 5300.00 4028.37 3958.37 58 48 5400.00 4079.80 4009.80 59 18 5500.00 4130.87 4060.87 59 0 5600.00 4183.90 4113.90 56 58 5700.00 4238.96 4168.96 56 11 5800.00 4294.95 4224.95 56 7 5900.00 4350.39 4280.39 56 6 6000.00 4406.07 4336.07 56 27 6100.00 4461.06 4391.06 56 41 6200.00 4515.94 4445.94 56 49 6300.00 4570.33 4500.33 57 16 6400.00 4624.60 4554.60 57 4 6500.00 4679.61 4609.61 56 6600.00 4735.58 4665.58 55 59 6700.00 4791.32 4721.32 56 19 6800.00 4847.0'7 4777.07 55 59 6900.00 4902.87 4832.87 56 23 7000.00 4958.59 4888.59 56 0 7100.00 5014.62 4944.62 55 45 7200.00 5071.00 5001.00 55 36 7300.00 5127.43 5057.43 55 55 7400.00 5183.13 5113.13 56 9 7500.00 5238.84 5168.84 56 7 7600.00 5294.49 5224.49 56 18 7700.00 5350.01 5280.01 56 13 7800.00 5¢05.72 5335.72 56 5 7900.00 5462.34 5392.34 54 55 DEG MIN FEET OEG/IO0 FEET FEET FEET DEG N 68 I E 1830.66 N 68 24 E 1912.74 N 68 39 E 1994.27 N 68 51 E 2075.25 N 69 56 E 2155.84 N 70 23 E 2236.65 N 70 39 E 2318.01 N 70 58 E 2399.63 N 71 14 E 2481.68 N 71 26 E 2564.04 N 71 9 E 2646.90 N 69 35 E 2730.95 N 69 24 E 2815.79 N 69 17 E 2901.02 N 66 57 E 2986.76 N 66 16 E 3072.64 N 64 51 E 3157.24 N 65 Z E 3240.48 N 65 31 E 3323.15 N 65 52 E 3406.21 N 66 10 E 3489.15 N 66 37 E 3572.57 N 67 21 E 3656.11 N 67 54 E 3739.99 N 68 28 E 3823.97 N 67 59 E 3907.47 N 68 20 E 3990.32 N 68 59 E 4073.34 N 69 21 E 4156.36 N 69 52 E 4239.34 N 70 27 E 4322.36 N ?0 38 E 4405.17 N 70 54 E 4487.73 N 69 55 E 4570.27 N 69 30 E 4653.31 N 69 51 E 4736.35 N 68 37 E 4819.43 N 68 8 E 4902.60 N 68 28 E 4985.63 N 68 26 E 5068.05 1.16 0,,52 0.51 0.54 1.14 0.76 0.34 0.60 0.40 0.22 I .58 1.13 0.25 1.22 1.54 1.73 I .48 1.42 1.18 1.05 0.69 0.58 0.54 0.72 0.45 0.70 0.56 0.55 0.69 1.15 0.83 0.19 0.38 1.97 0.03 0.42 1.63 0.43 0.58 1.36 703.38 N 1691.08 E 1831.53 N 67 25 E 733.85 N 1767.31 E 1913.61 N 67 27 E 763.67 N 1843.20 E 1995.14 N 6'7 30 E 793.03 N 1918.67 E 2076.10 N 67 33 E 821.47 N 1994.08 E 2156.65 N 67 37 E 848.85 N 2070.12 E 2237.40 N 67 42 E i) 876.01 N 2146.83 E 2318.68 N 67 48 E 902.84 N 2223.96 E 2400.23 N 6'7 54 E 929.41 N 2301.63 E 2482.ZO N 68 I E 955.78 N 2379.72 E 2564.49 N 68 7 E 982.34 N 2458.27 E 2647.28 N 68 13 E 1010.58 N 2537.45 E 2731.28 N 68 17 E 1040.33 N 2616.91 E 2816.11 N 68 19 E 1070.31 N 2696.69 E 2901.33 N 68 Z1 E 1102.22 N 2776.28 E 2987.08 N 68 21 E 1136.43 N 2855.16 E 3073.01 N 68 18 E 1171.53 N 2932.32 E 3157.69 N 68 13 E 1207.01 N 3007.88 E 3241.02 N 68 8 E 1241.62 N 3083.16 E 3323.78 N 68 4 E 1275.91 N 3158.99 E 3406.93 N 68 0 E 1309.66 N 3234.90 E 3489.95 N 67 58 E 1343.15 N 3311.41 E 3573.44 N 67 55 E 1375.84 N 3388.35 E 3657.02 N 67 54 E 1407.78 N 3465.94 E 3740.94 N 67 54 E 1438.94 N 3543.94 E 3824.93 N 67 54 E 1469.84 N 3621.52 E 3908.43 N 67 55 E 1500.75 N 3698.41 E 3991.30 N 67 55 E 1530.92 N 3775.76 E 4074.32 N 67 56 E 1560.48 N 3853.33 E 4157.32 N 67 57 E 1589.39 N 3931.12 E 4240.27 N 67 59 E 1617.56 N 4009.23 E 4323.24 N 68 Z E 1645.14 N 4087.34 E 4405.99 N 68 5 E 1672.35 N 4165.32 E 4488.50 N 68 7 E 1699.81 N 4243.17 E 4570.98 N 68 10 E 1728.78 N 4321.01 E 4654.01 N 68 12 E 1757.65 N 4398.87 E 4737.02 N 68 13 E 1786.81 N 4476.67 E 4820.09 N 68 14 E 1817.67 N 4553.90 E 4903.26 N 68 14 E 1848.35 N 4631.07 E 4986.31 N 68 15 E 1878.62 N 4707.74 E 5068.73 N 68 15 E COMPUTATION DATE: 9-JUL-90 PAGE ARCO ALASKA INC. D.S. 16 - 22 PRUOHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 9-JUNE-g0 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: G. SAR BE'R INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 8000.00 5520.43 5450.43 54 11 8100.00 5579.19 5509.19 53 57 8200.00 5638.15 5568.15 53 53 8300.00 5696.76 5626.76 54 31 8400.00 5754.79 5684.79 54 23 8500.00 5812.84 5742.84 54 38 8600.00 5870.29 5800.29 55 6 8700.00 5927.51 5857.51 54 58 8800.00 5984.90 5914.90 54 47 8900.00 6042.75 5972.75 54 24 N 68 51 E 5149.44 N 69 29 E 5230.36 N 69 56 E 5311.12 N 70 27 E 5392.13 N 70 59 E 5473.54 N 70 56 E 5554.92 N 70 7 E 5636.75 N 70 53 E 5718.75 N 71 0 E 5800.59 N 69 22 E 5882.14 1.51 0.67 0.61 1 0.67 1.11 0.37 0.61 1.19 0.57 1908.32 N 4783.52 E 5150.12 N 68 15 E 1937.10 N 4859.15 E 5231.03 N 68 16 E 1965.10 N 4934.90 E 5311.77 N 68 17 E 1992.53 N 5011.14 E 5392.75 N 68 19 E 2019.40 N 5088.02 E 5474.11 N 68 21 E 2045.83 N 5165.04 E 5555.45 N 68 24 E i) 2073.24 N 5242.16 E 5637.25 N 68 25 E ' 2100.75 N 5319.43 E 5719.22 N 68 27 E 2127.31 N 5396.88 E 5801.02 N 68 29 E 2154.88 N 5473.65 E 5882.55 N 68 31 E 9000.00 6100.93 6030.93 54 25 9100.00 6159.02 6089.02 54 48 9200.00 6216.28 6146.28 55 12 9300.00 6273.26 6203.26 55 9 9400.00 6330.20 6260.20 55 24 9500.00 6387.11 6317.11 55 19 9600.00 6443.83 6373.83 55 33 9700.00 6500.10 6430.10 55 57 9800.00 6556.53 6486.53 54 58 9900.00 6614.60 6544.60 54 30 N 69 23 E 5963.48 N 68 55 E 6044.87 N 66 9 E 6126.81 N 65 28 E 6208.84 N 65 16 E 6290.86 N 65 0 E 6372.89 N 64 42 E 6455.01 N 64 24 E 6537.40 N 65 I E 6619.69 N 65 35 E 6700.93 0.20 1.71 1.34 0.07 0.39 0.43 0.56 0.38 2.06 0.86 2183.56 N 5549.76 E 5963.87 N 68 31 E 2212.39 N 5625.88 E 6045.26 N 68 32 E 2243.73 N 5701.62 E 6127.22 N 68 31 E 2277.52 N 5776.54 E 6209.31 N 68 29 E 2311.TT N 5851.27 E 6291.39 N 68 26 E 2346.35 N 5925.87 E 6373.48 N 68 24 E 2381.34 N 6000.42 E 6455.68 N 68 21 E 2416.86 N 6075.06 E 6538.17 N 68 18 E 2452.32 N 6149.62 E 6620.55 N 68 16 E 2486.18 N 6223.66 E 6701.86 N 68 13 E 10000.00 5672.20 6602.20 54 57 10100.00 6729.61 6659.61 55 1 10200.00 6786.85 6716.35 54 55 10300.00 6844.21 6774.21 55 14 10400.00 6900.66 6830.66 55 48 10500.00 6957.00 6887.00 55 48 10600.00 7014.10 6944.10 54 30 10700.00 7072.50 7002.50 54 17 10800.00 7130.56 7060.56 54 36 10900.00 7188.20 7118.20 54 53 N 65 17 E 6782.49 N 65 7 E 6864.17 N 64 53 E 6945.95 N 64 47 5 7027.63 N 64 52 E 7109.93 N 64 52 E 7192.32 N 66 35 E 7274.23 N 67 3 E 7355.35 N 66 53 E 7436.71 N 66 36 E 7518.35 0.42 0.64 0.72 0.54 I .37 0.68 I .84 0.73 0.13 0.25 2520.23 N 6297.97 E 6783.51 N 68 11 E 2554.59 N 6372.29 E 6865.28 N 68 9 E 2589.25 N 6446.60 E 6947.15 N 68 7 E 2624.03 N 6520.76 5 7028.93 N 68 5 E 2659.16 N 6595.46 E 7111.34 N 68 2 E 2694.29 N 6670.24 E 7193.84 N 68 0 E 2728.29 N 6744.95 E 7275.84 N 67 59 E ~ 2760.06 N 6819.65 E 7357.01 N 67 58 E 2791.93 N 6894.57 E 7438.41 N 67 57 E 2824.19 N 6969.65 E 7520.11 N 67 56 5 11000.00 7245.46 7175.46 55 19 11100.00 7302.09 7232.09 55 44 11200.00 7358.16 7288.16 55 58 11300.00 7414.35 7344.35 55 34 11400.00 7471.07 7401.07 55 26 11500.00 7527.53 7457.53 55 57 11600.00 7583.33 7513.33 56 17 11700.00 7638.43 7568.43 56 48 11800.00 7692.73 7622.73 57 29 11900.00 7746.05 7676.05 58 12 N 66 20 E 7600.24 N 66 21 E 7682.55 N 66 54 E 7765.27 N 69 7 E 7847.96 N 70 10 E 7930.32 N 70 41 E 8012.83 N 71 8 E 8095.78 N 71 5 5 8179.18 N 70 57 E 8263.11 N 70 48 E 8347.67 0.35 0.37 1.21 2.71 0.22 0.67 0.69 0.35 0.87 0.96 2856.94 N 7044.81 E 7602.07 N 67 56 E 2890.06 N 7120.28 E 7684.46 N 67 54 E 2922.99 N 7196.26 E 7767.24 N 67 54 E 2954.10 N 7272.90 E 7849.95 N 67 54 E 2982.46 N 7350.22 E 7932.26 N 67 55 E 3010.11 N 7427.98 5 8014.72 N 67 56 E 3037.22 N 7506.41 5 8097.59 N 67 58 E 3064.21 N 7585.37 E 8180.91 N 68 0 E 3091.53 N 7664.78 5 8264.77 N 68 Z E 3119.19 N 7744.73 E 8349.26 N 68 4 E COMPUTATION DATE: 9-JUL-90 PAGE 4 ARCO ALASKA INC. DATE OF SURVEY: 9-JUNE-90 D.S. 16 - 22 KELLY BUSHING ELEVATION: 70.00 FT PRUDHDE BaY NORTH SLOPEr ALASKA ENGINEER: G. SARBEh INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTUR~ MEaSUREO VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 12000.00 7798.26 7728.26 58 51 12100.00 7849.43 7779.43 59 47 12200.00 7898.72 7828.72 61 10 12300.00 7945.9¢ 7875°94 62 36 12400.00 7992.01 7922.0! 61 20 12500.00 8044.63 7974.63 55 5 12600.00 8105.01 8035.01 51 41 12700.00 8166.52 8096.52 52 19 12800.00 8227.47 8157.47 52 37 12900.00 8287.88 8217.88 53 3 13000.00 8347.88 8277.88 53 10 13100.00 8407.33 8337.33 53 44 13200.00 8466.19 8396.19 54 6 13300.00 8525.39 8455.39 52 45 13400.00 8588.37 8518.37 49 ! 13500.00 8655.70 8585.70 46 56 13600.00 8724.87 8654.87 45 19 13700.00 8796.13 8726.13 43 38 13800.00 8869.45 8799.45 42 5 13900°00 8944.63 8874.63 40 20 14000.00 9021.43 8951.43 39 32 14100.00 9098.53 9028.53 39 56 14200.00 9175.20 9105.20 39 56 14238.00 9204.34 9134.34 39 56 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG N 70 39 E 8432.92 N 70 3~ E 8518.81 N 70 38 E 8605.79 N 70 35 E 8693.91 N 70 40 E 8782.62 N 71 12 E 8867.56 N 71 32 E 8947.18 N 71 29 E 9025.96 N 71 21 E 9105.19 N 71 19 E 9184.82 N 71 5 E 9264.77 N 70 56 E 9345.14 N 70 52 E 9425.94 N 70 43 E 9506.50 N 70 33 E 9584.13 N 70 59 E 9658.03 N 70 50 E 9730.'21 N 71 7 E 9800.34 N 73 16 E 9868.23 N 74 20 E 9933.95 N 77 20 E 9997.56 N 76 49 E 10060.58 N 76 49 E 10124.21 N 76 49 E 10148.39 0.74 1.56 1.20 I .92 4.94 6.00 0.33 0.36 0.32 0.72 0.20 0.36 0.36 3.30 3.91 1.58 0.40 2.34 I .72 2.04 1.34 0.00 0.00 0.00 3147.32 N 7825.24 E 8434.46 N 68 5 E 3175.80 N 7906.30 E 8520.29 N 68 7 E 3204.67 N 7988.38 E 8607.21 N 68 8 E 3233.94 N 8071.52 E 8695.28 N 68 10 E 3263.35 N 8155.25 E 8783.94 N 68 ll E 3291.20 N 8235.53 E 8868.82 N 68 13 E ~~ 3316.58 N 8311.07 E 8948.38 N 68 15 E 3341.57 N 83'85.85 E 9027.10 N 68 I6 E 3366.84 N 8461.00 E 9106.26 N 68 18 E 3392.38 N 8536.48 E 9185.84 N 68 20 E 3418.29 N 8612.17 E 9265.75 N 68 21 E 3444.44 N 8688.20 E 9346.07 N 68 ?-2 E 3470.86 N 8764.60 E 9426.83 N 68 24 E 3497.39 N 8840.71 E 9507.35 N 63 25 E 3523.21 N 8913.93 E 9584.95 N 68 26 E 3547.60 N 8983.73 E 9658.82 N 68 27 E 3571.23 N 9051.97 E 9730.97 N 68 28 E 3594.27 N 9118.23 E 9801.06 N 68 29 E 3614.98 N 9182.98 E 9868.90 N 68 31 E 3633.4~_ N 9246.28 E 9934.56 N 68 33 E 3649.15 N 9308.36 E 9998.09 N 68 36 E 3663.11 N 9370.47 510061.01 N 68 39 E 3677.75 N 9432.97 510124.57 N 68 42 E 3683.32 N 9456.73 510148.72 N 68 43 E COMPUTATION DATE: 9-JUL-gO PAGE ARCO ALASKA INC. D.S. 16 - ZZ PRUDHOE BAY NORTH SLOPE~ ALASKA DATE OF SURVEY: g-JUNE-gO KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: G. SARBE~ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -70.00 0 0 1000.00 995.94 925.94 11 27 ZO00.O0 1924.11 1854.11 28 36 3000.00 2716.09 2646.09 49 58 4000.00 3291.77 3221.77 55 33 5000.00 3868.99 3798.99 56 34 6000.00 4406.07 4336.07 56 27 7000.00 4958.59 4888.59 56 0 8000.00 5520.43 5450.43 54 11 9000.00 6100.93 6030.93 54 25 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 10000.00 6672.Z0 6602.20 54 57 11000.00 7245.46 7175.46 55 19 12000.00 7798.26 7728.26 58 51 13000.00 8347.88 8277.88 53 10 14000.00 9021.43 8951.43 39 32 14238.00 9204.34 9134.34 39 56 N 0 0 E 0.00 N 65 41 E 56.86 N 70 3 E 418.06 N 65 34 E 1015.18 N 68 I E 1830.66 N 71 g E 2646.90 N 66 10 E 3489.15 N 70 27 E 4322.36 N 68 51 E 5149.44 N 69 23 E 5963.48 N 65 17 E 6782.49 N 66 20 E 7600.24 N 70 39 E 8432.92 N 71 5 E 9264.77 N 77 20 E 9997.56 N 76 49 E 10148.39 0.00 2.58 2.51 2.45 1.16 1.58 0.69 0.83 1.51 0.20 0.00 N 0.00 E 0.00 N 0 0 E 21.78 N 52.55 E 56.89 N 67 30 E 158.31 N 387.06 E 418.19 N 67 45 E 367.15 N 946.48 E 1015.20 N 68 48 E 703.38 N 1691.08 E 1831.53 N 67 25 E 982.34 N 2458.27 E 2647.28 N 68 13 E 1309.66 N 3234.90 E 3489.95 N 6T 58 E 1617.56 N 4009.23 E 4323.24 N 68 2 E 1908.32 N 4783.52 E 5150.12 N 68 15 E 2183.56 N 5549.76 E 5963.8T N 68 31 E 0.42 0.35 0.74 0.20 I .34 0.00 2520.23 N 6297.97 E 6783.51 N 68 11 E 2856.94 N 7044.81 E 7602.07 N 67 56 E 3147.32 N 7825.24 E 8434.46 N 68 5 E 3418.29 N 8612.17 E 9265.75 N 68 21 E 3649.15 N 9308.36 E 9998.09 N 68 36 E 3683.32 N 9456.73 E10148.72 N 68 43 E COMPUTATION DATE: g-JUL-gO PAGE 6 ARCO ALASKA INC. D.S. 16 - 22 PRUDHOE BAY NORTH SLOPE9 ALASKA DATE OF SURVEY: 9-JUNE-90 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SER DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -70.00 0 0 N 0 0 E 70.00 70.00 0.00 0 16 S 83 13 W 170.00 170.00 lO0oO0 0 9 S 23 26 E 270.00 270.00 ZO0.O0 0 10 N 84 2 W 370.00 370.00 300.00 0 7 N 26 52 W 470o01 470.00 400.00 0 50 N 66 34 E 570.04 570.00 500.00 2 10 N 75 20 E 670.21 670.00 600.00 4 28 N 71 20 .E 770.76 770.00 700.00 7 17 N 68 50 E 871.88 870.00 800.00 9 30 N 66 7 E 973.56 970.00 900.00 11 4 1075.87 1070.00 1000.00 13 26 1179.18 1170.00 1100.00 15 34 1283.50 1270.00 1200.00 17 39 1389.04 1370.00 1300.00 19 27 1495.79 1470.00 1400.00 21 37 1604.25 1570.00 1500.00 23 46 1714.11 1670.00 1600.00 25 14 1825.38 1770.00 1700.00 26 54 1938.43 1870.00 1800.00 28 22 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN Z05Z.Z9 1970.00 1900.00 28 45 2166.80 Z070.00 2000.00 29 32 228Z.68 2170.00 2100.00 31 11 1400.24 ZZ70.O0 2200.00 32 19 2520.55 2370.00 2300.00 35 35 2647.15 2470.00 2400.00 40 6 2782.43 1570.00 2500.00 44 32 2929.31 1670.00 2600.00 48 44 3087.39 2770.00 2700.00 54 5 3265.45 2870.00 2800.00 55 55 0.00 0.00 0.00 N 0.00 E -0.12 0.00 0.02 S 0.12 W -0.45 0.28 0.19 S 0.41 W -0.58 0.00 0.30 S 0.51 W -0.85 0.81 0.24 S 0.82 W -0.12 0.78 0.15 N 0.19 W 2.33 1.53 0.93 N 2.14 E 8.01 2.92 2.56 N 7.59 E 18.41 3.44 6-19 N 17.35 E 33.39 1.71 11.96 N 31.18 E N 64 57 E 51.72 0.89 N 69 14 E 73.30 2.30 N 70 52 E 99.20 1.77 N 68 37 E 128.89 2.69 N 68 18 E 162.60 1.64 N 68 18 E 199.92 Z.47 N 65 36 E 241.88 1.87 N 65 30 E 287.25 1.85 N 67 29 E 335.98 2.25 N 68 16 E 388.69 0.73 3441.71 2970.00 2900.00 54 59 3613.09 3070.00 3000.00 54 6 3784.72 3170.00 3100.00 54 22 3961.32 3270.00 3200.00 55 58 4136.65 3370.00 3300.00 54 42 4307.72 3470.00 3400.00 53 48 4476.88 3570.00 3500.00 54 8 4648.98 3670.00 3600.00 54 43 4823.83 3770.00 3700.00 55 25 5001.83 3870.00 3800.00 56 36 N 72 55 E 443.11 N 74 37 E 498.67 N 72 36 E 557.01 N 70 11 E 618.78 N 69 39 E 685.62 N 68 2 E 763.20 N 67 24 E 854.Z0 N 66 13 E 961.67 N 64 33 E 1083.75 N 63 46 E 1230.44 N 64 20 E 1374.98 N 65 50 E 1513.78 N 68 35 E 1653.16 N 67 55 E 1798.69 N 68 32 E 1942.69 N 68 54 E 2081.48 N 70 18 E 2217.90 N 70 49 E 2357.92 N 71 17 E 2501.27 N 71 9 E 2648.42 0.00 N 0 0 E 0.12 S 79 28 W 0.45 S 65 2 W 0.59 S 59 8 W 0.85 S 73 27 W ,~ 0.24 N 50 35 W 2.34 N 66 26 E 8.02 N 71 21 E 18.41 N 70 23 E 33.39 N 69 0 E 19.62 N 47.87 E 51.74 N 67 43 E 28.04 N 67.75 E 73.33 N 67 31 E 36.68 N 92.18 E 99.22 N 68 18 E 47.03 N 1ZO.Ol E 128.90 N 68 36 E 59.44 N 151.35 E 162.61 N 68 33 E 73.13 N 186,08 E 199.94 N 68 33 E 89.55 N 224.72 E 241.91 N 68 16 E 108.64 N 266.00 5 287.33 N 67 47 E 128.03 N 310.76 E 336.11 N 67 37 E 147.78 N 359.65 E 388.83 N 67 40 E 2.41 0.69 1.89 1.64 3.60 4.11 4.44 1.93 5.40 0.51 166.27 N 410.84 E 443.21 N 67 58 E 181.48 N 464.49 E 498.69 N 68 40 E 197.58 N 520.79 E 557.01 N 69 13 E 217.73 N 579.21 E 618.79 N 69 24 E 240.49 N 642.07 E 685.63 N 69 28 E 268.44 N 714.44 E 763.21 N 69 24 E 303.48 N 798.48 E 854.20 N 69 11 E 345.23 N 897.57 E 961.68 N 68 58 E 396.11 N 1008.83 E 1083.81 N 68 34 E 460.82 N 1141.17 E 1230.70 N 68 I E I .10 1.25 1.27 0.99 0.79 0.65 0.98 0.65 0.44 1.59 524.58 N 1271.56 E 1375.52 N 67 35 E 583.44 N 1397.67 E 1514.56 N 67 Z1 E 637.49 N 1526.24 E 1654.03 N 67 ZO E 691.39 N 1661.44 E 1799.56 N 67 24 E 744.85 N 1795.17 E 1943.56 N 67 28 E 795.27 N 1924.48 E 2082.33 N 67 33 E 842.54 N 2052.45 E 2218.66 N 67 41 E 889.19 N 2184.52 E 2358.56 N 67 51 E 935.71 N 2320.20 E 2501.78 N 68 2 E 982.83 N 2459.71 5 2648.79 N 68 13 E COMPUTATION DATE: g-JUL-90 PAGE 7 ARCO ALASKA INC. DATE OF SURVEY: g-JUNE-90 D.S. 16 - 22 KELLY BUSHING ELEV,ATION: 70.00 FT PRUDHOE BAY NORTH SLOPEr ALASKA ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG REC'TANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 5188.49 3970.00 3900.00 58 12 5380.83 4070.00 4000.00 59 14 5574.38 4170.00 4100.00 57 23 5755.44 4270.00 4200.00 55 50 5935oll 4370.00 4300.00 56 6116.28 4470.00 4400.00 56 40 6299.39 4570.00 4500.00 57 16 6482.79 4670.00 4600.00 56 9 6661.61 ¢770.00 4700.00 56 11 6840.94 4870.00 4800.00 55 56 7020.41 4970.00 4900.00 56 3 7198.23 5070.00 5000.00 55 36 7376.42 5170.00 5100.00 56 11 7555.92 5270.00 5200.00 56 11 7735.92 5370.00 5300.00 56 9 7913.30 5470.00 5400.00 54 46 8084.39 5570.00 5500.00 54 0 8254.14 5670.00 5600.00 54 5 8426.15 5770.00 5700.00 54 29 8599.49 5870.00 5800.00 55 6 8774.10 5970.00 5900.00 54 56 8946.83 6070.00 6000.00 54 26 9119.10 6170.00 6100.00 54 58 9294.29 6270.00 6200.00 55 11 9469.96 6370.00 6300.00 55 15 9646.38 6470.00 6400.00 55 45 9823.35 6570.00 6500.00 54 36 9996.17 6670.00 6600.00 54 58 10170.61 6770.00 6700.00 55 6 10345.43 6870.00 6800.00 55 38 10523-06 6970.00 6900.00 55 35 10695.71 7070.00 7000.00 54 16 10868.35 7170.00 7100.00 54 54 11043.19 7270.00 7200.00 55 28 11221.14 7370.00 7300.00 55 54 11398.12 T470.00 7400.00 55 26 11576.03 7570.00 7500.00 56 9 11757.92 7670.00 7600.00 57 10 11945.66 7770.00 7700.00 58 29 12141.19 7870.00 7800.00 60 22 DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN N 69 24 E 2806.02 N 67 20 E 2970.29 N 65 6 5 3135.78 N 65 21 5 3286.31 N 65 59 5 3435.29 N 66 44 E 3586.16 N 67 54 E 3739.47 N 68 3 E 3893.20 N 68 47 E 4041.42 N 69 34 E 4190.28 N 70 30 E 4339.29 N 70 54 E 4486.28 N 69 29 E 4633.73 N 69 31 E 4782.79 N 68 17 E 4932.43 N 68 2'7 E 5078.91 N 69 22 E 5217.73 N 70 13 E 5354.89 N 71 5 E 5494.80 N 70 7 E 5636.33 N 71 9 E 5779.42 N 69 20 E 5920.23 N 68 30 E 6060.50 N 65 29 E 6204.17 N 65 4 E 6348.26 N 64 34 E 6493.17 N 65 17 E 6638.72 N 65 18 E 6779.36 N 64 56 E 6921.93 N 64 48 E 7064.92 N 64 59 E 7211.31 N 67 3 E 7351.87 N 66 42 E 7492.48 N 66 17 E 7635.73 N 67 15 E 7782.77 N 70 10 E 7928.77 N 71 5 E 8075.86 N 71 1 E 8227.71 N 70 46 E 8386.52 N 70 36 E 8554.49 0.30 2.22 2.50 0.6! 0.58 0.60 0.72 1.3q 0.90 0.86 0.63 0.37 0.27 1.41 0.45 1.39 0.53 0.75 0.52 0.37 0.96 0.27 2.33 0.27 0.20 0.35 I .62 0.37 0.63 1.50 1.51 0.65 0.28 0.61 1.73 0.20 0.76 0.75 0.56 1.31 1036.90 N 2607.75 E 2806.34 N 68 19 E 1095.82 N 2761.10 E 2970.60 N 68 21 E 1162.43 N 2912.B2 E 3136.21 N 68 15 E 1226.27 N 304.9.59 E 3286.90 N 68 6 E 1287.79 N 3185.59 E 3436.04 N 67 59 E 1348.54 N 3323.90 E 3587.04 N 67 55 E ) 1407.59 N 3465.46 E 3740.42 N 67 54 E 1464.49 N 3608.29 E 3894.16 N 67 55 E 1519.42 N 3745.98 E 4042.40 N 67 55 E 1572.39 N 3885.10 E 4191.23 N 67 58 E 1623.2t N 4025.19 E 4340.16 N 68 2 E 1671.87 N 4163.94 E 4487.04 N 63 7 E 1721.92 N 4302.66 E 4634.43 N 68 11 E 1773.73 N 4442.43 E 4783.44 N 68 14 E 1828.75 N 4581.61 E 4933.10 N 68 14 E 1882.61 N 4717.84 E 5079.59 N 68 15 E 1932.67 N 4847.32 E 5218.41 N 68 16 E 1980.00 N 4976.07 E 5355.53 N 68 18 E 2026.31 N 5108.14 E 5495.36 N 68 22 E 2073.10 N 5241.77 E 5636.83 N 68 25 E 2120.44 N 5376.85 E 5779.86 N 68 29 E 2168.32 N 5509.29 E 5920.63 N 68 31 E 2218.09 N 5640.43 E 6060.89 N 68 32 E 2275.58 N 5772.27 E 6204.63 N 68 29 E 2335.93 N 5903.49 E 6348.84 N 68 25 E 2397.74 N 6035.02 E 6493.89 N 68 20 E ) 2460.33 N 6166.93 E 6639.60 N 68 15 E , 2518.92 N 6295.12 E 6780.37 N 68 12 E 2579.04 N 6424.79 E 6923.10 N 68 8 E 2639.96 N 6554.60 E 7066.27 N 68 4 E 2702.36 N 6687.49 E 7212.86 N 68 0 E 2758.70 N 6816.45 E 7353.53 N 67 58 E 2813.92 N 6945.89 E 7494.23 N 67 57 E 2871.22 N 7077.36 E 7637.60 N 67 55 E 2929.80 N 7212.39 E 7784.75 N 67 54 E 2981.93 N 7368.76 E 7930.71 N 67 55 E 3030.77 N 7487.56 E 8077.69 N 67 58 E 3079.99 N 7631.30 E 8229.40 N 68 1 E 3131.99 N 7781.43 E 8388.09 N 68 5 E 3187.64. N 7939.97 E 8555.94 N 68 8 E COMPUTATION DATE: 9-JUL-90 PAGE 8 ARCO ALASKA INC. O.S. 16 - 22 PRUDHOE BAY NORTH SLOPEr ALASKA DATE OF SURVEY= 9-JUNE-90 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER= G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 12352.77 7970.00 7900.00 62 58 12542.98 8070.00 8000.00 52 51 12705.69 $170.00 8100.00 52 20 12870.29 8270.00 8ZO0.O0 52 55 13037.03 8370.00 8300.00 53 28 13206.49 8470.00 8400.00 54 5 13371.69 8570.00 8500.00 50 8 13520.91 8670.00 8600.00 46 47 13663.73 8770.00 8700.00 44 15 13800.74 8870.00 8800.00 42 4 N 70 40 E 8740.86 N 71 27 E 8902.21 N 71 28 E 9030.46 N 71 16 E 9161.11 N 71 3 E 9294.45 N 70 51 E 9431.Z0 N 70 27 E 9562.60 N 70 56 E 9673.28 N 70 43 E 9775.19 N 73 15 E 9868.72 I .39 4.38 0.36 0.11 I .16 0.2.7 3.97 I .52 2.48 I .73 3249.53 N 8115.83 E 8742.20 N 68 11 E 3302.30 N 8268.39 E 8903.45 N 68 14 E 3343.00 N 8390.12 E 9031.59 N 68 17 E 3384.78 N 8514.01 E 9162.15 N 68 19 E 3427.92 N 8640.26 E 9295.41 N 68 22 E 3472.59 N 8769.57 5 9432.08 N 68 24 E ,) 3516.02 N 8893.63 E 9563.43 N 68 26 E 3552.58 N 8998.15 E 9674.06 N 68 27 E 3586.03 N 9094.45 E 9775.92 N 68 29 E 3615.12 N 9183.46 E 9869.40 N 68 31 E 13933.16 8970.00 8900.00 39 53 14062.88 9070.00 9000.00 39 33 14193.21 9170.00 9100.00 39 56 14238.00 ~9204.34 ~'9134.34 39 56 N 75 9 E 9955.20 N 77 19 E 10037.09 N 76 49 E 10119.B9 N 76 49 E 10148.39 2.26 I .46 0.00 0.00 3639.04 N 9266.88 E 9955.78 N 68 34 E 3657.84 N 9347.34 E10037.56 N 68 38 E 3676.76 N 9428.73 E10120.25 N 68 42 E 3683.32 N 9456.73 E10148.72 N 68 43 E COMPUTATION DATE: 9-JUL-90 PAGE 9 ARCO ALASKA INC. D.S. 16 - 22 PRUOHOE BAY NORTH SLOPEr ALASKA MARKER 13 9/8" CASING 7" CASING TOP 9 5/8" CASING TOP SAD ZONE 3 ZONE Z HOT LAST GCT READING OWC OWC PBTD 7" CASING BOTTOM TO DATE DF SURVEY: 9-JUNE-g0 KELLY BUSHING ELEVATION: 70.00 FT ENGINEER: G. SARBE~ INTERPOLATED VALUES FOR CHOSEN HORIZONS · SURFACE LOCATION = 1741' FNLt E 1271' FWL, SEC24 TION R15E~UM MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4351.00 3495.60 3425.60 807.74 N 13605.00 8728.38 8658.38 3572.39 N 13944.00 8978.32 8908.32 3640.82 N [3993.00 9016.03 8946.03 3648.17 N 13993.00 9016.03 8946.03 3648.17 N 14002.00 9022.97 8952.97 3649.43 N 14068.00 9073.94 9003.94 3658.56 N 14100.00 9098.53 9028.53 3663.11 N 14122.00 9115.40 9045.40 3666.33 N 14136.00 9126.14 9056.14 3668.38 N 14148.00 9135.34 9065.34 3670.14 N 1¢233.00 9200.50 9130.50 3682.59 N 14238.00 9204.34 9134.34 3683.32 N 1957.07 E 9055.32 E 9273.60 E 9304.01 E 9304.01 E 9309.60 E 9350.53 E 9370.47 E 9384.22 E 9392.97 E 9¢00.47 E 9453.60 E 9456.73 E COMPUTATION DATE: 9-JUL-90 PAGE 10 ARCO ALASKA D.S. 16 - 2Z PRUDHOE BAY NORTH SLOPE, INC. ALASKA MARKER 13 3/8" CASING 7" CASING TOP 9 5/8" CASING TOP SAD ZONE 3 ZONE Z HOT LAST GCT READING OWC OWC PBTD 7" CASING TO BOTTOM ~~~ STR~TIGRAPHIC SUMMARY SURFACE LOCATION MEASURED DEPTH BELOW KB FROM KB TVD SUB-SEA DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: g-JUNE-gO 70.00 FT G. SARBE~ 4351.00 3495.60 3425.60 13605.00 8728.38 8658.38 13944.00 8978.32 8908.32 13993.00 9016.03 8946.03 13993.00 9016.03 8946.03 14002.00 9022.97 8952.97 14068.00 9073.94 9003.94 14100.00 9098.53 9028.53 14122.00 9115.40 9045.40 14136.00 9126.14 9056.14 14148.00 9135.34 9065.34 14233.00 9200.50 9130.50 14238.00 9Z04.34 9134.34 1271' FWL, SEC24 T RECTANGULAR CO NORTH/SOUTH ION R ORDIN EAST/ 15E,UM ATES WEST 807.74 N 3572.39 N 3640.82 N 3648.17 N 3648.17 N 3649.43 N 3658.56 N 3663.11N 3666.33 N 3668.38 N 3670.14 N 3682.59 N 3683.32 N 1957. 9055. 9273. 9304. 9304. 9309. 9350. 9370. 938¢. 9392. 9400. 9453. 9456. 07 32 60 01 01 60 53 47 22 97 47 6O 73 FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 14238°00 9204.34 9134.34 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10148.72 N 68 43 E SCHLUMBEROER O [ RECT [ ONAL SURVEY COMPANY ARCO ALASKA INC. NELL O.S. 18 - 22 F I ELD PRUOHOE BAY COUNTRY USA RUN ONE DATE LOOOEO 09 - JUN - 90 REFERENCE ?@0S0 WELL' D.S. 16-22 '~-"~ HORIZONTAL PROJECTION (174t' FN~L, 1271' FWL, SEC 24, TION, R15E,UM) NOR?H 10000 REF 73950 8OOO 4OOO 2000 -2OOO -4000 ~I. ITH -SO00 blEST SCALE = 1/2000 IN/FT -4000 -~000 0 2000 4000 6000 8000 10000 12000 EP~T WELL' D.S. 16-22 VERTICAL PROJECTION (174q' FNL, 1271' FWL, SEC 24, TION, R15E,UM) -~000 0 O ~000 4000 I~000 801 .. J, · ~ ~ ] ! ~,. ~ i ! [ i ~ ~ ..... .~-.-, . , , - ~.,~, :uw l uuuu I ZUUU 14000 ,.~...~.4--~ ....... ~.-.~...~..~ ~Z~.] L.i..~ ~ ~ ': ~ ~ ~ ~ ~ ~ ~ , ~ '. ~ J t ~ ~ ~ ~t ~ ~ :~ ; '- ; ~ ~ : ~ : ; .... : ~ . ~ , ' · ' · ' ; : · ::::::::::::::::::::::::::::::::: '~ ~:Z:::::: :::2:~]:~::~] ~ ~ 2:'"f"+'+'?"~'+'f"H ....... f"?-r-'t ....... ~'+',-+--'..+4-.-~-..;-+.+.--:-..~-.-~ ...... ~...:..:...;...I. ,..,...;..., ..... ::::::::::::::::::::::::::::::::: --L.L..i..; ~ ~ ~ ~ W T:~]}~]_ ~. ~ ~ ; ~ * ; T'T"-'T"?'~ ..... ~"T'T'T": ....... 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"~'"r"t .......... *'"t'"t'"t ...... t'--t"?-~ ..... ?..r.~..*..- ..... ~.-.~-f -~-~ ~ ~-, 4.-'...; : : ---~-~-~-.. %4~ ~-~4-~ 4 : 4 + ~ : ~ ~ : ~ :~ ~ : 4 ~ ~ ~ .... t t ~ r"t"'t'"t ...... t"'r"t'"t ....... t..?..t...t ...... t...t...t...t... ~ I , ' ~ : , ; ; : ~'*'-$.--~.-~ ..... ~..4--~ ....... ~ '- ~ ~ - -~ ~ 4- :- : ~ . ~ : : : : ' : ~ : . t' t'"t'"~'" '"~*?*' -~ .... t*"~'*'t ..... . i ! , ~ ,,, ~ ~ '"T"'T'"T'"~ ....... T'"T"'T-'T ...... TT'~"T'"T'-T ...... `...t..~-.t...t".?...t..T..t...:-.t.~...t...t...t...f*.f..f..f..~+.~...f..f..t..f..~..~...~ ...... F'+"'~'-'~"'t'"~---~--'f-'f ...... ~...~...~...-~.~...?:...~...~ ..... PROJECTION ON VERTICAL PLANE 69. - 249. SCALED IN VERTICRLDEPTI~ HORIZ SCALE = 1/2000 IN/FT PERMIT # , ~: - ,~"/ ~.,IL~i'iitl]"'l_~C*. ! [Ui%I I..~$.3t ~ [:. ~!__ WELL NAME /_~,_? / --,,, ,, t., ;..$. IL,, U 1'4 I AOGCC GEOLOGICAL MATEnlALS "i'NVENTOR-Y LIST ~0red iflterva,s i · [ check off or Ii drilling histor~ ~t data as it is received j , ' surveY ! "';I' well tests ! ~J'! core desription d~ ditch intervals j ',,, digital data I ! , LOG TYPE RUN 'iNTERVAL'S ..... SCALE NO. 11] /.~$ ~o / _ /~'/o / ' /! /~oo~/- /~Z/o~'" ,., /- ' ,,/", '¢ ,,,q. " ARCO ALr:-'~i:KA, ]]NC.~ P~O. BOX i0({)360 ANCHORAGE: ALA:?KA 995~0 F;:. lie F' FL F;.' E i',! C E ' A F;: C 0 ri: A ,5-; E D i..i 0 L E:.: F' ! N A L.. 2 , ..: ;-i-9:? ,q.-'i :$ "? .... '?-.-90 '7 ..... i :i-~', 7 -6-- 9,:!';, 9-.}~2 7-i i-9(i:, 9--- 2; 8 7 - i 2 '-9 ,?> i2-i2 7--i'2 .... 9 i 2 "- i 6 7 -,:ii, - ':.:,:' 0 i 6 - 22 '7 - 4 -':20 i & "- 2 ?':; 7 .... 7;-- c,:,,q iS-ii 7 .... 8--90 F' i:~ 0 D !.J C 'T' I 0 N F:' F;..' 0 F' I !... P R 0 £:, U C 'i" I 0 f:i F' R 0 F' .[ L. E · :Z .;: L." i ....... ~-,~-.. i) iii. ]" E C:'T' i 3 i'-! I N .J E C T ! ('-i i"'.i F:' iN.'. 0 F' .i.: t.. i.:] I i'-.! .. ..... ii::' ,_..r' -;-, ]: 0 N F:' F;: .... r'i F:' I ,...,...I ]::' F' R i.'j D U C 'f' ;il 0 H F:' R 0 F' .[ i.. ii:_ i iq J E C T i 0 i'-i P R 0 F: i L.. E F:' F;:. 0 D U C '!" ]] 0 N F:' F;.: 0 F:' Z L L. r..:-. A K T.) E'f E C "f' ]] [] i".! [.i-1';: COL. L. AR ,..;-;" F;..' .F;OL..L..AR... L.. E A K D F- T E C T I 0 N /F' Z '¥' £ F' !_ E A.~i; E ."~' .i: G N A iq D F;:. E "[' LJ R N T H FZ A T T A C H iii. D C f-:~ Y A ;~; R E C E I F:' 'T' 0 F:' i) A 'i" r::',., F;:FC:E I VET:, BY ............. ~"_~_ ..% .'~/_ _ _ _ ...... ........ H A V E A i'-.-!. ]: C Ii"' D A Y ! D I ;5'T F.: I B U 'T' ]: 0 N :.":- C'EN T F;.:AL FILES ~.i: C: H E V iR 0 N D & M · I~: EXTEN$1'ON EXF:'L. OF:'.A T I ON :~ l!-" X X 0 N HARATHON :~: H O B I t_ :i~ F:' I-'i .[ I.. L :[ !::'B WEL. L. F'Ii...E::'7 R ,:!-,. 'lC:, ,tl, · ,,-. B P'X · ~l: ,.~v'f'A'i"l£ 0¢:', AI..A."fI-(A ]" E X A [": (] _ 4 UG - 3 19 0 '--" STATE OF ALASKA ---. ALASF )ILAND GAS CONSERVATION APPLICATION FOR SUNDRY A PROVAES ''. 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1742' FNL, 1271' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 3506' FNL, 5111' FEL, Sec. 17, T10N, R16E, UM At effective depth 1928' FSL, 309' FWL, Sec. 17, T10N, R16E, UM At total depth 1906' FSL, 518' FWL, Sec. 17, T10N, R16E, UM 5. Type of Well Development Exploratory ,, Stratigraphic , Service 6. Datum of elevation(DF or KB) 70 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-22 9. Permit number 90-51 10. APl number 50 - 029-22040 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 14238 feet Plugs(measured) true vertical 9207 feet Effective depth: measured 14148 feet true vertical 9136 feet Junk(measured) Casing Length Size Cemented Conductor 80' 20" 280 sx CS II Surface 4281' 13-3/8" 2500 sx CS III & 600 sx CI 'G' Production 13874' 9-5/8" 450 sx CI 'G' Liner 626' 7" 220 sx CI 'G' Measured depth True ve~icaldepth 112' 112' 4351' 3496' 13944' 8978' 14230' 9202' Perforation depth: measured 14002-14012'; 14016-14024' true vertical 9023-9031'; 9034-9040' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, IPCT @ 13670' MD R[CEIVED LIUL 1 a 19 0 A~s/~ 0il & Sas C0~s. ~mmis~i,;;, ~, ~chom~ Packers and SSSV (type and measured depth) Baker SB-3A packer ~ 13553' MD; Otis HRQ SSSV ~ 2207' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x ,,,, , 14. Estimated date for commencing operation July 1990 16. If proposal was verbally approved Oil X Name of approver Date approved; Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer FOR COMMISSION LISI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test __ Subsequent form required 10- ~-/~ ~ ORIGINAL SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Date ""~// I/ ¢)'~ Form 10-403 Rev 06/15/88 420 DRR cc: J. Gruber, ATO-1478 JApproval No. 15. Status of well classification as: Gas Suspended .. SUBMIT IN TRIPLICATE Commissioner Approved Copy Drill Hydraulic Site 16-22 Zone 2 Fracture Treatment PRELIMINARY PROCEDURE Arco Alaska intends to pump a hydraulic fracture treatment on well 16-22 as outlined below: o . . . . . Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Rig up fracturing service company. Pump propped fracture treatment at 45 BPM using a cross linked water system with approximately 106,000 lbs of 16-20 proppant. The interval to be fracture stimulated is Zone 2from 14,002 to 14,024'. The pump schedule is outlined as follows: A. B. C. D. E. F. G 1350 Bbl cross linked water pad 60 Bbl 2 PPG proppant 65 Bbl 4 PPG " 70 Bbl 6 PPG " 74 Bbl 8 PPG " 94 Bbl 10 PPG " 99 Bbl 12 PPG " If necessary rig up CTU and cleanout to PBTD. Install gas lift valves. Open well to flow gradually increasing the drawdown to allow proper fracture healing. RECEIVED 6 5 4 3 2 COILED TUBING UNIT BOP EOU 1. 5000 PSI 7" WELLHEAD CONNECTOR 2. 5000 PSi 4 1/16" PIPE RAMS 3. 5000 PSI4 1/6" HYDRAULIC SLIPS 4. 5000 PSI4 1/6" SHEAR RAMS 5. 5000 PSI4 1/6" BLIND RAMS 6. 5000 PSI4 1/16" STUFFING BOX 3 H]RELINE BOP EOUIPMENT _ 1. 5000 PSI 7" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr ARCO Alaska, In Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 30, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 16-22, L5-18, L5-19, L5-26 & PWDW1-2 As-builts _ Dear Mr. Chatterton: Enclosed are copies of the subject As-builts for your information. If you have any questions, please call me at 263-4618. Danielle Warner Engineering Aide DW cc: File W1-1 ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AP3[~-¢C';02-(~ NOTE~ Jd ~~ ~ L~~ P~ D.S. MON. 16-A a AS-BUILT OF WELL 16- 24. Rd ALA~A ~T~ TE PLA~ C~ T~ ARE . W~LL A.~.P. CO0~DINA T~5 PLANT ~,, ~ODETIC POSITION ELEV. LOCATION ........ , .... Cellar NO. NORTHIN~ EA~TIN~ COORD~, LA T. LONG, · cox tN SECTION ~ ~ ~ ~ ~ ~Y ~cr F,R, BELL & ASSOCIA TES A~ OT~R ~TA[$ A~ COR~CT ARCO~Iaeke,_~. ~ __ ........... CONDUCTOR A3-BUIL T D.S. 16~ WELL 2~ !0 ";' ~ E ' ~':t'~ F..' C: C) ", J:;,' iii: F:' iii: i::.: E.,', Z: 'i: H f:'-'~ Cf iq iii: 'i" :J: C i" fr:'~ F:' E: ( ,S' ) t,.J ]: i" I..I t... ]: ~"i" ]: N C.; ( ,? ~ .i~:,--.'-", ':~ .... "'.... ~~ ... '"'"' .... ,::. ,= .. 2 ~ ? '3 )]' :I: F:' I.../' Z )]' t... . tL'j 1:{¢ :[: 4 ,:) ,' 'i6 .... 2¥ 4 .... i8 .... 9'3 O]:F'L./Z:Ot... ~~ F:'t...E:r~:~;~:I]~ ;~';;:I:(;.N Ai'q):) t:;~!F~T'LJF;~N THE: rr:~'TTr:~C:HE:D COF'Y r:~;k; t:;~I~:C:E:~I:F:'T' OF:' .()r:t~'i"r:':~ ........................... 3' rr:~ L. L. Y H 0 F' F:' E; C: K E~ R Alask~ Oit & G~s Cons. Gol'fl~JssJo~f:~ f:' F' tR 0 V E; D ..~ ,- ~.. ;" Anchorage T R ~::~ N S :,. 9,:~ 6 2 :0 ]: 5:! 'T' R ]: E; U '¥' ]: O N C: !ii: N '1" !:~: r:~.~ !... K .'[ L.. i.:.': ..'.? ,:'. C.; I"t ';, C: J..l E: V B'. C) N i"AHHA,?? E: i::,' Ct ~4 H (()H) E: X X O N i"i r:':~ F~:. ~ T H 0 N i'i 0 }3 :I.' 1... STATE OF ALASKA ' L~ ALASKA OIL AND GAS CONSERVATION COMM~odlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown X Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate_ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1742' FNL, 1271' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 6. Datum elevation (DF or KB) RKB 70' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 16-;~2 9. Permit number 3506' FNL, 5111' FEL, Sec. 17, T10N, R16E, UM (APPROX) At effective depth 1928' FSL, 309' FWL, Sec. 17, T10N, R16E, UM (APPROX) At total depth 1940' FSL, 365' FWL, Sec. 17, T10N, R16E, UM (APPROX) 12. Present well condition summary Total Depth: measured 14238' feet Plugs (measured) true vertical 9207' feet .90-51 10. APl number 50-029-22040 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool None Effective depth: measured 14148' feet Junk (measured) None true vertical 91 36' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 2 0" 275 sx CS II 1 1 2' 11 2' Surface 431 9' 1 3-3/8" 2000 sx CS III & 4351' 3496' Intermediate 600 sx Class G - Top job w/300 sx CS II Production 1 391 3' 9-5/8" 450 sx Class G 1 3944' 8978' Liner 628' 7" 220 sx Class G 1 3605'-1 4233' 8728'-9204' Perforation depth: measured None ~ !i'~' :~'~ .~-; I~:''~;'' i.. true vertical N o n e 13. Tubing (size, grade, and measured depth 4-1/2", t-80 tbg w/ tail @ 13671' Packers and SSSV (type and measured depth) Anch0ra~a Otis 'HRQ' sssv @ 2207' & Baker 'SB-3A' pkr @ 13553' Description summary of proposal ~ Detailed operation program ~ BOP sketch _ Attachments Well History 14. Estimated date for commencing operation 115. Status of well classification as: Julv 15, 1990 I Oil X Gas ~ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended Signed C,~ ~0~ (~~ Title Drilling Analyst oI FOR COMMISSION USE ONLY Conditions approval: Notify Commission so representative may witness Date Plug integrity ~ Mechanical Integrity Test BOP Test Location clearance ~ Subsequent form require 10- //r;~? ORIGINAL SIGNED BY LONNIE C. SM!TH Approved by the order of the Commission IIAppr°val No.¢~ Commissioner Date (~, /~/WO Form 10-403 Rev 06/15/88 SUBMIT IN 'I:RIPLIC~ATE Approved Copy . Rpturnef:i ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the ',~_RiI~I" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sPU~!~::b, summarized on the form giving inclusive dates only. NORTH SLOPE ·. ~*~ PR~HOE ~Y ~IT ]t~ or u.~t ~L: 28346 Auth. Or W.O. "~S3595 T~fle DRILL & CO~LETE ~I: 50-029-22040 IState AK W;II no. 16-22 Operator A~CO iA.cow.I. 21.0 0 0 0 Spudded or W.O, begun IDate IHour ]Prior status if a W.O, SPUD I 04/28/90I 07: 30 Date and depth as of 8:00 a.m. 04/28/90 ( TD: 0' ( SUPV: MRC 04/29/90 ( TD: 970' ( SUPV: MRC 04/30/90 ( TD: 1466' ( SUPV: MRC 05/01/90 ( TD: 1920' ( SUPV: MRC 05/02/90 ( 05/05/90 ( TD: 4365' ( SUPV: TJ Complete record for each daf rejoQrted NABORS 28E 1) 0) 2) 970) 3) 496) 4) 454) 5) MU BHA 91, MIX MUD. 20"@ 112' MW: 8.5 VIS: 75 ACCEPT RIG @ 2200 HRS, 4/27/90.MIX MUD, NU ~SER AND FLOWLINE, MU BHA#i. a ~' DAILY:S119,189 CUM:$119,189 'ETD:S150,000 EFC:$3,154,189 see Procedures Manual, Section 10. Drilling, Pages 86 and 87. DRILLING AT 970' 20"@ 112' MW: 9.0 VIS:300 COMPLETE BHA#I. FUNCTION TEST DIVERTER. RIH. SPUDDED WELL @ 0730 HRS, 4/28/90. DRLD F/ 100-500'. TRIP FOR BHA DRLD TO 970'. DAILY:S60,987 CUM:$180,176 ETD:S180,000 EFC:$3,185,176 DRILLING AT 1466 20"6 11~' MW: 9.2 VIS:295 DRILLED F/ 970-1206'. TRIP FOR BIT. DRILLED TO 1445'. SHAKERS BLINDING W/ SAND CHANGED SHAKER SCREENS. DRILLED TO 1466'. DAILY:S51,914 CUM:$232,090 ETD:S235,300 EFC:$3,181,790 DRILLING 20"@ 11~' MW: 9.2 VIS:297 DRILL F/ 1466'-1847' CBU, DROP SURVEY, PUMP SLUG. POOH, C/O MWD TOOL, RIH. DRILL F/ 1847'-1920' DAILY:S56,307 CUM:$288,397 ETD:S175,000 EFC:$3,298,397 DRILLING 20"@ 11~' MW: 9.2 VIS:280 TD: 2427' (/507~)~{~= :DYNA__ DRILL TO 1950', MOTOR FAILED. CIRC, POOH, CHANGE SUPV:MRC/GL~:?~.__~: ':'~TOR,..~ .' RIH. DYNA DRILL TO 2163', WOULD NOT SLIDE DUE TO -l:i; :i:~:'.MOTO~, P/U 1 DEG BENT HOUSING DYNA DRILL. RIH, NO FILL. . [~:~?~"~:?~:' :' 'DYNA DRILL F/ 2163'-2427'. 05/03/90 (/6) : DRILLING 20 @ 117- MW: 9.3 VIS:200 TD: 3675'([248) DRILL TO 3530'. CHANGE SHAKER SCREENS. DRILL TO 3570'. SUPV:TJ CHANGE SHAKER SCREENS. CIRC & COND. DRILL TO 3675'. DAILY: $46,578 CUM: $389,668 ETD: $385,000 EFC: $3,189,668 05/04/90 ( 7) RNG 13-3/8" CSG 13-3/8"@ 4351' MW: 9.4 VIS:120 TD: 4365'( 690) DRILL TO 4365'. CBU. DROP SURVEY, PUMP SLUG, POOH. CHANGE SUPV:TJ RISER TO 21-1/4". RIH, CBU, POOH, L/D BHA. RU CSG TOOLS & RUN 13-3/8" CSG. DAILY:S43,975 ' CUM:~433,643 ETD:S400,000 EFC:$3,218,643 8) TSTG BOP. 13-3/8"6 4351' MW: 9.4 VIS: 59 0) RIH W/ 110. JTS 13-3/8", 68#, L-80, BTC CSG. C&C. PUMP 100 BBL$ ~'~<ESF. ;';AT,R, ,'-:iX ~ PUMP 2000 SX CS III @ 12.2 PPG, TAILED IN W/ 600 SX CL G @ 15.8 PPG. DISPLACE CMT & BUMPED PLUG W/ 2000 PSI. PERFORM TOP JOB W/ 300 SX CS II. CLEAR FLOOR. N/D RISER & HYDRIL, M/U CAMERON SCREW ON CSG HEAD. N/U BOP. CLEAN PITS & TSTG BOP. DAILY: $39%52~ ..... I.D~[e~ \ I Title · ~.":; ©i.~ .~':~aS ~J0~'~ !.:',i ::..i ~ ;i~..~;',; INumber all d.lly wall history forms consecutively .~,cI~.r'~,~'~ ~as th.y are p,.pe,.d for ..ch w.,. I AR3B-459-1-D iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "FInol" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. I iState District ARCO ALAS[(,A TNC. County or Parish NORTH SLOPE AK Field PRUDHOE BAY UN'[' IL ...... unit DS 16-22 Iwe''n°~ I I Date and depth Complete record 05/06/90 ( TD: 4871'( SUPV:TJ 05/07/90 ( TD: 6418'( SUPV:TJ 05/08/90 ( TD: 7582'( SUPV:TJ 05/09/90 ( TD: 8677'( SUPV:TJ 05/10/90 ( TD: 9462'( SUPV:MC 05/11/90 ( TD:10265' (~ SUPV:MC as of 8:00 a.m. 05/12/90 ( TD:10760' ( SUPV:MC 9) 506) 10) 1547) 11) 1164) 12) 1095) 13) 785) 14) 803) 15) 495) The above is ~,orrect Signatu ''~ ', '.,, ~ For form pr~oa~'tior~ and"b~stributio' n see Procedures Manual Section 10, for ea%j~(~ d~l~r~ ..... k .... in p rog .... DRLG 13-3/8"@ 4351' MW: 8.9 VIS: 35 FIN TSTG BOP. M/U BHA & RIH, TAG FC @ 4262' TEST CSG TO 2500 PSI FOR 30 MIN DRILL FLOAT COLLAR & CMT TO 4375'. TEST CSG TO 2500 PSI. DRILL SHOE & 10'. PERFORM LOT TO 12.3 PPG EMW. DRILL TO 4640' FLOWLINE PLUGGING UP W/ CLAY. C&C, CLEAR FLOWLINE. DRILL TO 4680', MWD FAILED. CBU, POOH, CHANGE OUT TOOL. RIH. DRILL TO 4871'. DAILY:S47,388 CUM:$873,558 ETD:S1,400,000 EFC:$2,658,558 DRLG AHEAD 13-3/8"@ 4351' MW: 9.3 VIS: 43 DRILL F/ 4871' - 6418'. DAILY:S54,983 CUM:$928,541 ETD:S1,400,000 EFC:$2,713,541 DRILLING 13-3/8"@ 4351' MW: 9.3 VIS: 36 DRILL TO 6922'. CBU, DROP SURVEY, PUMP SLUG. POOH, HOLE TRIED TO SWAB F~ 5000'-4351' CHANGE BIT, RIH, SLIP & CUT, RIH. DRILL F/ 6922'-7582'. DAILY:S62,710 CUM:$991,251 ETD:S1,450,000 EFC:$2,726,251 DRILLING 13-3/8"@ 4351' MW: 9.4 VIS: 41 DRILL TO 8275'. CHANGE SWAB OUT ON PUMP #2. DRILL TO 8488'. CIRC HIGH VIS SWEEP, CBU. SHORT TRIP TO 6827'. DRILL TO 8677'. DAILY:S56,527 CUM:$1,047,778 ETD:S1,560,000 EFC:$2,672,778 DRILLING 13-3/8"@ 4351' MW: 9.6 VIS: 39 DRILL TO 9005'. CBU, PUMP HIGH VIS SWEEP, DROP SURVEY, PUMP SLUG. POOH. CHANGE BITS. RIH. DRILL TO 9462'. DAILY:S57,079 CUM:$1,104,857 ETD:S1,620,000 EFC:$2,669,857 DRILLING 13-3/8"@ 4351' MW: 9.7 VIS: 48 DRILL TO 9936', CIRC 20 BBL LOW VIS / 50 BBL HIGH VIS SWEEPS WHILE DRLG. SERVICE MUD PUMP #2. DRILL TO 10029', STUCK PIPE. WORK PIPE FREE, DRILL TO 10218'. PLUGGED JET, CIRC LOW VIS / HIGH VIS SWEEPS, CBU, SHORT TRIP TO 8996'. DRILL TO 10265'. DAILY:S52,832 CUM:$1,157,689 ETD:S1,700,000 EFC:$2,642,689 DRILLING 13-3/8"@ 4351' MW: 9.7 VIS: 45 DRILL TO 10280' CBU. POOH. CHANGE OUT MOTOR & BIT. SERVICE WEAR BUSHING. SLIP & CUT DRILL LINE. RIH, 3' OF FILL. DRILL TO 10760' DAILY:S67,016 CUM:$1,224,705 ETD:S1,800,000 EFC:$2,609,705 Drilling, Pages 86 and 87 Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively Page no. as hey are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District ARCO ALASKA INC. ICounty or Parish NORTH SLOPE lState AK Field PRUDHOE BAY UNIT Lease or Unit DS 16-22 JweH no. Date and depth as of 8:00 a.m, 05/13/90 TD:ll130' SUPV:MC 05/14/90 TD:l1515' SUPV:MC 05/15/90 TD:11893' SUPV:MC 05/16/90 TD:12065' SUPV:MC 05/17/90 TD:12438' SUPV:RJB 05/18/90 TD:12786' SUPV:RJB 05/19/90 ( TD:13263' ( SUPV:RJB 05/20/90 ( TD:13473' ( SUPV:RJB Complete record for ea~A~j~e d~iSi]~g or workover in progress (16) (370) (17) ( 385) (18) ( 378) (19) (172) (20) ( 373) (21) (348) 22) 477) 23) 210) The above is correct :'~. Signature ~ L~ ~ '!\!,q.~ For form prepar~tio~ ar{d dis'tribE ion see Procedures Manual Section 10, Drilling, Pages 86 and 87 DRILLING 13-3/8"@ 4351' MW: 9.7 VIS: 46 DRILL TO 11047'. CBU, PUMP LOW VIS / HIGH VIS SWEEPS. DROP SURVEY, PUMP SLUG. POOH, CHANGE BHA & BIT. RIH. DRILL TO 11130'. DAILY:S55,584 CUM:$1,280,289 ETD:S1,800,000 EFC:$2,665,289 DRILLING 13-3/8"@ 4351' MW: 9.7 VIS: 46 DRILL F/ 11130'-11515'. DAILY:S49,744 CUM:$1,330,033 ETD:S1,840,000 EFC:$2,675,033 CIRC BOTTOMS UP 13-3/8"@ 4351' MW: 9.7 VIS: 46 DRILL TO 11588' DROP SURVEY, PUMP SLUG. POOH. SERVICE WWEAR BUSHING. TEST BOP. MU PDC BIT, PU GR/RES MWD. RIH. REPLACE O-RING IN STAND PIPE. DRILL TO 11893', NOZZLE PLUGGED. CBU. DAILY:S63,302 CUM:$1,393,335 ETD:S1,900,000 EFC:$2,678,335 RIH 13-3/8"@ 4351' MW: 9.8 VIS: 49 CBU. DROP SURVEY, P~ SLUG, POOH. UNPLUG (2) BIT NOZZLES, CHA/gGE BHA. RIH, SLIP & CUT DRILL LINE, FIN RIH. DRILL TO 12065', COULD NOT SLIDE. POOH. CHANGE OUT MOTOR. RIH. DAILY:S48,330 CUM:$1,441,665 ETD:S1,900,000 EFC:$2,726,665 DRILLING 13-3/8"@ 4351' MW: 9.9 VIS: 48 FIN RIH. DRILL TO 12364'., ANGLE BUILT TO 62 DEG. CBU. POOH. P/U 2 DEG BENT SUB & SLICK MOTOR. RIH. DYNA DRILL TO 12438'. DAILY:S48,590 CUM:$1,490,255 ETD:S1,950,000 EFC:$2,725,255 DRILLING 13-3/8"@ 4351' MW: 9.8 VIS: 43 DYNA DRILL TO 12562' DROP SURVEY, PUMP SLUG, POOH. L/D BENT SUB & SLICK MOTOR. P/U 3/4 DEG BH STEERABLE MOTOR & PDC BIT. RIH, SLIP & CUT, RIH. REAM F/ 12335'-12562'. DRILL TO 12786'. DAILY:S47,034 CUM:$1,537,289 ETD:S1,965,000 EFC:$2,757,289 RIH 13-3/8"@ 4351' MW: 9.8 VIS: 48 DRILL TO 13162' CIRC. DRILL TO 13263', BUILDING ANGLE. CBU. POOH. CHANGE BHA. RIH. DAILY:S50,202 CUM:$1,587,491 ETD:S1,983,000 EFC:$2,789,491 CIRC 13-3/8"@ 4351' MW:10.2 VIS: 47 ~ F/ 13225'-13327' FOR LOGGING DATA, INCREASE MUD WT. TO 10.0 PPG. DRILL TO 13473', ANGLE DROPPING TOO FAST. POOH, HOLE TIGHT, RIH. INCREASE MUD WT TO 10.2 PPG. PUMP LOW & HIGH VIS SWEEPS. POOH, HOLE STILL TIGHT, RIH. CIRC & WORK ~T~; Th;C'-P~?. :.;[~,'J ~;i~ qb') i ;': % ?~."' ate ' ~Title ...... ' -~ AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. JPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesd. ay of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ARCO ALASKA INC. Icounty or Parish NORTH SLOPS [sta,. AK Fie,d PRUDHOE BAY UNIT Ite un,t DS 16_22 ..... Iwe,, no. Date and depth as of 8:00 a.m. 05/21/90 TD:13684' SUPV:RJB 05/22/90 TD:13966' SUPV:RJB 05/23/90 TD:13966' SUPV:RJB 05/24/90 TD:13967' SUPV:MC 05/25/90 TD:14206' SUPV:MC 05/26/90 TD:14238' SUPV:MC templet ...... df ..... ~;~,~(~ d~ ..... k .... in prog .... 24) 211) 25) 282) DRILLING 13-3/8"@ 4351' MW:10.5 VIS: 47 POOH, WORK PIPE THRU TIGHT SPOT F/ 12984'-12671', FIN POOH. CHANGE BHA & RIH. REAM F/ 13015'-13473'. DRILL TO 13521' CHANGE SWAB ON PUMP #1. DRILL TO 13684'. DAILY:S67,856 CUM:$1,709,159 ETD:S2,027,000 EFC:$2,867,159 26) 27) o) 1) 28) ( (29) ( The above is correct Signature ~~~ ~ For form preparatio~ and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 269) POOH TO RUN 9-5/8" CSG 9-5/8"@13944' MW:10.5 VIS: 49 DRILL TO 13966'. CBU. SHORT TRIP. WASH & REAM F/ 13954'-13966'. CBU, PLTMP LOW &*'HIGH VIS SWEEP. POOH TO RUN CSG. DAILY:S57,110 CUM:$1,766,269 ETD:S2,042,000 EFC:$2,909,269 CIRC WHILE BATCH MIX CMT 9-5/8"@13944' MW:10.4 VIS: 43 POOH. CUT & SLIP DRLG LINE. POOH. CHNG TOP RAMS. R/U AND RUN 9-5/8" CSG. TOP F.S @ 13943'. TOP F.C @ 13860'. CIRC & COND MUD FOR CMT. DAILY:S469,110 CUM:$2,235,379 ETD:S2,275,000 EFC:$3,145,379 CBU 9-5/8"@13944' MW: 9.1 VIS: 39 FIN CMTG 9-5/8" CSG W/ 450 SX 'G', DISPLACE CMT, BUMP PLUG, FLOATS HELD. SET PACKOFFS. ND FLOWLINE, BOP & DRLG SPOOL. NU TBG SPOOL & TEST TO 5000 PSI. NU BOP & TEST. SET WEAR BUSHING. PU 8-1/2" BHA. RIH, TAG FLOAT COLLAR @ 13852'. TEST CSG TO 3000 PSI. DRILL FC & CMT TO 13932'. RETEST CSG TO 3000 PSI. DRILL OUT CMT, SHOE & 10' NEW HOLE. CBU. DAILY:S86,905 CUM:$2,322,284 ETD:S2,575,000 EFC:$2,932,284 REAMING BACK TO TD 9-5/8"@13944' MW: 9.8 VIS: 43 CBU. PERFORM FIT TO 12.5 PPG EMW. DRILL TO 14088'. REPLACE ROTARY CHAIN. DRILL TO 14206' CBU. ATTEMPT TO SHORT TRIP, PULLED 475K. INCREASE MUD WT TO 9.3 PPG. ATTEMPT TO POOH, INCREASE MUD WT TO 9.6 PPG. POOH TO CSG ONLY WITH PUMPS ON. WASH & REAM TO TD. PUMP LOW / HIGH VIS SWEEPS. PUI~P STRING OUT OF HOLE. REAM BACK TO BOTTOM. CBU & RAISE MUD WT TO 9.8 PPG. POOH 8 JTS TO CSG W/O PUMPING. DAILY:S64,272 CUM:$2,386,556 ETD:S2,600,000 EFC:$2,971,556 RIH FOR WIPER TRIP 9-5/8"@13944' MW:10.0 VIS: 43 REAM & DRL TO 14238'TD. RAISE MUD WT TO 10.0 PPG. SHORT TRIP, TIGHT HOLE. REAM TO TD. POOH. RU ATLAS W/L. RIH W/ GR/DIL/Z-DEN/CNL, COULD NOT GET PAST 13990'. POOH. RUN GR/DIL, COULD NOT GET PAST 13995'. POOH, R/D ATLAS W/L. CHANGE OUT ROLLER REAMER & BOTTOM STAB. RIH. SLIP & CUT DRILL LINE. RIH. DAILY:S65,735 CUM:$2,452,291 ETD:S2,750,000 EFC:$2,887,291 Dte JTitle Drilling Supt. AR3B-459-2-B Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company {~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnteriltl" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ARCO ALASKA INC. iCounty or Parish NORTH SLOPE Is`ate I Field PRfJ"DHOE BAY UNIT It. ease or unit DS 16-22 I complet ...... df .... c~j~(~ d~_l§r~ ..... k .... in progress Date and deptl~ as of 8:00 a.m. 05/27/90 TD:14238' SUPV:MC 05/28/90 TD:14238' SUPV:MC 05/29/90 ( TD:14238 PB:I414~ SUPV:MC 05/30/90 ( TD:14238 SUPV:MC 05/31/90 ( TD:14238 PB: 14148 SUPV:RJB 06/01/90 ( TD:14238 SUPV:RJB (30) ( 0) (31) ( 0) 32) 33) 34) 35) AK IWell no. RIH TO C & C FOR LINER 9-5/8"@13944' MW:10.2 VIS: 44 FIN RIH. WASH & REAM F/ 13944'-14236'. RAISE MUD WT TO 10.2 PPG. PUMP LOW & HIGH VIS SWEEPS. SHORT TRIP. SPOT POLYMER PILL ACROSS OPEN HOLE. POOH. R/U ATLAS W/L. RUN GR/DIL/Z-DEN/CNL. LOG OPEN HOLE. R/D ATLAS W/L. RIH TO CONDITION BEFORE RUNNING LINER. DAILY:S48,169 CUM:$2,500,460 ETD:S2,800,000 EFC:$2,885,460 CIRC. & COND. 7~@14233' MW:10.2 VIS: 44 FIN RIH. REAM F/ 13944'-14236'. CIRC, SHORT TRIP, CBU. SPOT POLYMER PILL. DROP SURVEY & POOH. R/U TO RUN LINER. M/U 7", 29#, L-80, BTC LINER. RIH W/ LINER. BREAK CIRC @ 9-5/8" SHOE. FIN RIH W/ LINER & SET F/13605-14233. CIRC & COND MUD. DAILY:S50,844 CUM:$2,551,304 ETD:S2,975,000 EFC:$2,761,304 TSTG LINER & CSG 7"@14233' MW: 9.2 NaC1 CIRC & COND MUD. BATCH MIX 220 SX CLASS G "ARC" CMT @ 15.7 PPG. PUMP 50 BBLS ARCO PRE FLUSH, 65 BBLS CMT, 38 BBLS FRESH WATER. DISPLACE CMT, BUMP PLUG. PRESSURE UP TO 3000 PSI, SET LINER HGR. RELEASE F/ HGR, SET LINER TOP PACKER. REVERSE OUT CMT ABOVE TOL. POOH & L/D RNG TOOLS. L/D 8-1/2" BHA. RIH W/ 6" BIT & BHA. RIH, TAG CMT @ 14096', CLEAN OUT LINER TO 14148'. CBU. TEST LINER & CSG TO 3500 PSI. R/U TO REVERSE. REVERSE IN 9.2 PPG NACL, PRECEDED NACL W/ 300 BBLS WATER & 20 BBL HIGH VIS SWEEP. DAILY:S170,281 CUM:$2,721,585 ETD:S3,000,000 EFC:$2,906,585 RIH W/ 4-1/2" COMPLETION 7"@14233' MW: 9.2 NaC1 FIN DISPLACING WELL TO 9.2 PPG NACL. TEST LINER LAP TO 3500 PSI. LDDP. ND FLOWLINE, NU SHOOTING NIPPLE & LUBRICATOR. RUN CBT/CET/GR/CCL. ND SHOOTING NIPPLE, NU FLOWLINE. RU TBG TOOLS. PU BAKER SB-3A PACKER ASSEMBLY. DAILY:S102,993 CUM:$2,824,578 ETD:S3,005,000 EFC:$3,004,578 POOH W/ COMPLETION STRING 7"@14233' MW: 9.2 NaCl RU TO RUN TBG. RIH W/ 4-1/2", 12.6#, L-80, BTC MOD, IPC TBG, SB-3A PKR, CHEM INJ MANDREL & LINE, GLMS AND SSSV. DROPPED DOPE BRUSH IN TBG, POOH 7 JTS & REVERSE OUT BRUSH. CONT TO RIH W/ COMPLETION. LOST PRESSURE ON CHEM INJ LINE 10 JTS FROM BOTTOM. POOH W/ COMPLETION STRING. DAILY:S41,098 CUM:$2,865,676 ETD:S3,100,000 EFC:$2,950,676 SLIP & CUT DRILL LINE 7"@14233' MW: 9.2 NaCl FIN POOH W/ COMPLETION STRING, WHILE WORKING PACKER THRU BOP PACKER SHEARED FREE. RD TBG TOOLS. MU TRI-STATE SPEAR ASSEMBLY. PU DRILL PIPE & RIH. SLIP & CUT DRILL LINE. DAILY:S96,945 CUM:$2,962,621 ETD:S3,100,000 EFC:$3,047,621 The above is correct Signature . ~ -~ ~, For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each welt. JPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. State County or Parish NORTH SLOPE AK no. DS 16-22 ILease or Unit ]Well PRUDHOE BAY UNIT Date and depth as of 8:00 a.m. 06/02/90 ( TD:14238 PB:I4~4~ SUPV:RJ~ 06/03/90 ( TD:14238 PB:f414~ SUPV:RJB Complet ...... df .... c~,~(~ d~l~n~ ..... k .... in progress 36) 37) LDDP 7"@14233' MW: 9.2 NaCl FIN PU DRILL PIPE & RIH W/ SPEAR. SPEAR PACKER @ 13593'. POOH. REPAIR TIE BACK RAIL IN DERRICK. FIN POOH & LD PACKER & SPEAR. STAND BACK TAIL PIPE ASSEMBLY. RIH W/ DP. POOH & LAY DOWN DRILL PIPE. DAILY:S3.8,475 CUM:$3,001,096 ETD:S3,100,000 EFC:$3,086,096 N/D BOP 7"@14233' MW~' 9.2 NaC1 FIN LDDP. RU TO RUN TBG. RUN ~-1/2", 12.6#, L-80 COMPL ASSY W/ PKR, GLMS & SSSV. MU TBG HGR FREEZE PROTECT TBG & ANNULUS W/ DIESEL TREATED W/ C-190. LAND HGR. DROP PKR SETTING BALL. SET PKR @ 13553' CONFIRM TBG SEAL ARE FREE. RELAND TBG. TEST TBG TO 3500 PSI. HOLD 950 PSI ON ANNULUS & SHEAR OUT THE SHEAR OUT SUB W/ 3700 PSI. LD LDG JT. SET BPV. N/D FLOWLINE & BOP. (OTIS 'HRQ' SSSV @ 2207', BAKER 'SB-3A' PKR @ 13553', & TT @ 13671'.) DAILY:S304,675 CUM:$3,305,771 ETD:S3,185,000 EFC:$3,305,771 The above is correct '~ ~ S~gnatu For form prel~aration and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ]Title _ Drillina Supt. AR3B-459-2-B Number all daily well history forms consecutively las hey are prepared for each well. IPage no. ARCO el| and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" should be completion, '~~~~llPre~ent ative~-t est required upOsPacan is available~i. District ~County or Parish NORTH S~PE I Field PR~HOE ~Y ~ZT ILease or Unit ~L= 28346 I Auth. or W.O. noAs3595 JTltle D~ILL ~ CO~L~E I ~[: 50-029-22040 the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. suspended for an indefinite or appreciable length of time. On workovers when an official test is not data in blocks provided. The "Final Report" form may be used for reporting the entire JAccountlng cost center code State AK Operator ~:~,CO IA.R.Co. W.~. 23.,0000 I Spudded or w. OsI[;~:~ I Date 0 4 / 2 8 / 9 0 I Complete record f[l~l~;~:l~ I'~l~d Date and depth as of 8:00 a.m. Old TD Released rig 06/04/90 ( TD:3.4238 PS: 1414~ SUPV:RJB Classifications (oil, gas, etc.) Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well I our 07: 30 IPrlor status If a W.O. I 38) RIG RELEASED @ 0900 HRS 6/3/90 7"@14233't MW: 9.2 NaC1 N/U TREE & TEST TO 5000 PSI. T~ST CONTROL LINES TO 5000 PSI. SECURE WELL & RELEASE RIG AT 0900 HRS 6/3/90. DAILY:S61,000 INew TD Date Producing method Potential test data CUM:$3,366,771 ETD:S3,185,000 EFC:$3,366,771 PB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date i Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day ,. Pump size, SPM X length Choke size T.P. C.P. i Water % GOR Gravity Allowable Effective date corrected Signature ~,.~~ Title S~jpt. For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, AR3B-459-3-C Number all daily well history forms consecutively ae they are prepared for each well. iPage no. Division of AllsntlcRIchlleldCo~pa~y ARCO ALA~?K P~ O~ BOX ANCHORAGE~ ALAS'KA 995~(.) D A T E · 6 - 2 (3 - 9 R Iii: F:' iii: R E N C Iii; ~.-~ I-, L...J i'"i A ~; N ii!;'T' I C: 'T'A P ii: ( ~':,' ) W 1 i' I"1 t... I ,.S' 1' I N (:; ( ,?;' ) F:'I... E A S Ei: ,?? I C. N A N D R E I"LJ R N T H Iii: A 'T' T A C t"1 E D C: O F:' Y A S R E C Iii: I P T O F:' i.:' A '¥ A .: I~I~~ II I~ I..IAVE: A NICE DAY~ JUN 2 2 1990 .~~ ;~:AL.L.Y I--IOF'F'ECK tER A P P R O V E D . ,'-,, .- -, -~ ~... Alaska 0il & Bas Cons. ~o$$issio. T ~ AN S':~ 9 <~ ~ (.)' Anchorage D I S' 'T' R I B U T I O N C E N'T' R A I.. I:: I I...E,S' ( C I"1 ) C i"1E V R 0 N D & M TAi"'iMA,S; BF;,.'OWN (OFI) li.] X X 0 N M A R A T I"t 0 N M 0 B I I... A R E:(3 A I... A S K A, :[ N E: ,. F:',.O~ BOX 'i ¢'~NCI-tOF,'.(:'~F..'-,E:, r:~L~,S'K(~ c,;'95'i (.) '" I1 ~ · . .. 0 F:: iii: H 0 L. Iii: F: ]: N A t...,? t:;.i Iii: F' Iii: F;,' i~:. N ::: ii: ~'-~ R C ['i i'-.! I..I¢,VtE ¢, N :1: CIE D(:~Y ! ,'!;; A 1... t... Y i"10 F' F:' E (": t( E R A 'f' 0 -" i '5 2 ? R Ii!: ~"' E T V ~=" :() B Y ...................... /....:;:'....~=/c. >.: ................................... RECEIVED JUN 2 0 1990 nPF'ROVEi:~:.~ ............... · .3-1~' ~'.~ N ~' :~ ':? (:;,"2'2 4 Alaska Oil & Gas Oons. ~;o~rOtssl.oJ ' '~ ~chorage ARCO ALA3~KA, INC. P.O. BOX i(~0S60 ANCI"tORA(~F, ALAS'KA 995t0 DATE ' 6/t 2/90 REFERENCE' ARCO CASED HOLE FINALS' t -9 6-6-90 COLLAR 2-S 6-6-90 COMP. NEUTRON G/R 2-t0 6-6-90 COMP. NEL}TRON G/R 2-t S 6-9-90 COLLAR 2-'23 6-8-90 COLLAR 3-20 6-7-90 COMP. NEUTRON G/R 3-'~'~.-.-- 6-7-°0, COMP ~ NEUTRON G/R 4-i6 6-7-90 COMP. NEUTRON G/R 4-23 6-8-90 COMP. NEUTRON G/R 4-24 6-8-9~ COMP. NEUTRON G/R 5-6 6-~8-90 COMF'~ NEUTRON G/R 7-9 6-9-90 COMF'~ NEUTRON G/R 7-9 6-9-9(~ DIFF. TEMPERATURE 7-34 6-9-90 COMP~ NEUTRON G/R t 2-t 8 6--4-90 CET t2-t8 6-4-9~ CBT t6-22 5-29-90 CBT t 6-~'~.~. 5-29-90 G/R t6-22 5-29-9(~ CET WGI-5 6-3-94> F'ERF RECORD WGI-6 5-3~3--9.~ PERF RECORD WGI-7 6-t -90 PERF RECORD WGI-8 6-2-90 PERF RECORD RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN i 5" 5" 5" 5' 5" 5' 5" 5" 5" 5' 5 · 5" 5" 5" 2" 5" 5" 5" 5" 5" ATLAS' ATLAS A'I'LA~' ATLAS' A'I'LA3' ATLA~ A'l' LA ~,' ATLAS A'FLA3~ ATI_A~~ A'fL. A3~ AI'LA~ ATLA~ ATLA~ ~'CH ~'CH $CH $CH $CH $CH .~CH $CH $CH PLEA~'E SIGN AND RETURN THE A~'~A~W~ED COF'Y AS RECEIF'T OF RECEIVEI) BY __ HAVE A NICE DAY' ' . ~ALLY HOFFECKER ~F'F'ROVE AT0-t529 T~AN~ ~218 DATA~ DISTRIBUTION CENTRAL FILES ~ PHILLIF'£ CHEVRON PB WELL FILES D & M R & D EXTENSION EXF'LORATION ~' BPX EXXON ~ ~ STATE OF ALASKA MARATHON TEXACO MOBIL D A '¥' E · '.5 / :;~ J / 9 ~') R Iii: F:' E I::..' E N C E ' A F:. C: 0 O F' Iii: N t"t O I... E'.' F' ]: N A 1... 5; 'T' V D ,S' U B .... ;? E A Z'-'i)I:_"iN,!~' I1...OC-/F;:AW DATA D U A L.. I N D L.I C: T I 0 N (ii. / R Z .... D E"-' N ,? I t... O (; / I=' O R O ;g' I "1" Y F:'I... iii: A S' E ,?; 1 6; N A N D I:;.: E 'T' U R N T H E A ]" 'T'A C t'-Iiii: i) C 0 F:' Y A,? R Iii: C: E I F:"i" 0 F:' L" A "l' A., R Ii!: C E :i: V E D B Y .................................... ~..~,..":;vlii: ,::., i.~. ]: (::: ,ii: .~)~,y! dUN 1 4 1990 :~: ~.":~ L. L Y H 0 F F' E C K E R Alaska Oil .& Gas Gons. Gommt~o-, 4.......~.. Anchorage ~:~ F, F' ~: 0 V r.-;: ~ D I S T R I B LJ 1' I 0 N · 'J,': C: E N T R,.~ L.. F' I L.. E,? · ,,.'"' C I-.I Ii!: V R 0 N · "' D & }'-'i 'IF · 'il: E X T F.i: N ,S' I 0 N E X F' I... O R ~.':', 1" I O i'J. :~ IE X X C1 t'..J. · ,.'"' i"iAF:.'A T HON . · "' H 0 B I L. ~' F:' H I 1_ I.. I !' ,., '11' F:' I'}: W E t... !... F:' I L.. E · ~ F..' ,~,, D '"' B F'X ~11' STATE OF AL_AS'I<A TEXACO April 16, 1990 Telecopy No. (907) 276-7542 J D Gillespie Regional Drilling Engr ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit DS 16-22 ARCO Alaska, Inc .... Permit # 90-51 Surf Loc 1742'FNL, i271'FWL, Sec 24, T10N, R15E, LR~ Btmhole Loc 1906'FSL, 518'FWL, Sec 17, T10N, R16E, UM Dear Mr Giilespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C V Chatterton Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION jo Enclosure Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl la. Type of work Drill Re-Entry - 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK ~ ~-'", STATE OF ALASKA ALAS . ,. _ AND GAS CONSERVATION Cf, MISSION PERMIT TO DRILL 20 AAC 25.005 ~.;,__ Redri,,--1 lb. Type of we,,. Exp,oratory ,~. Stratigraphic Test ~ Deve,opment Oi, ~ -- Deepen~-i Service - Developement Gas Z Single Zone/~ Multiple Zo__n_e_.?______~ 5. Datum Elevation (DF or KB) 10. Field and Pool RKB 70 ' 38 ' GL feet Prudhoe Bay Field 6ADP{.op2esrt3Y41~esignation Prudhoe Bay Oil Pool 99510-0360 4. Location of well at surface 1742'FNL, 1271'FWL, Sec.24, T10N, R15E, UM At top of productive interval 3506'FNL, 5111'FEL, Sec.17, TiON, R16E, UM At total depth 1906'FSL, 518'FWL, Sec.17, TiON, R16E, UM feet 13. Distance to nearest well DS 16-24 60 ' at surface feet 12. Distance to nearest property line 5798 ' (~ TD 16. To be completed for deviated wells Kickoff depth 5oo feet 18. Casing program size Hole Casing 30" 20" 17-1/2" 13-3/8" 13-3/8" 9-5/8" 54°20' Maximum hole angle Specifications Weight I Grade 1 Coupling ]Length 91.5#IH-40 I Weld I 80' ! I 29# 1~'-8o I BTC 1880' MD 30' 30' 50' 13506' 12-1/4" 8-1/2" 7" ALK 2530 7. Unit or property Name Prudhoe Bay Unit 8. Well number PBU DS 16 -22 9. Approximate spud date 04/20/90 14. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2920 psig At total depth (TVD) 3800 psig Setting Depth Top Bottom Quantity of cement TVD ! MD I TVD (include stage data) ! ! 30'I 1101 110' 280 sx CS II 30'I 501 50' 2500 sx CS III & I 30' 113806~ 9000' 11. Type Bond Iseo 20 AAC 25.025) Statewide Number No. U-630610 Amount $200,000 15. Proposed depth(MDandTVD) 14386'MD feet . 93_37'TVD 800 sx C1 G _ 140 ax 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: feet feet measured feet true vertical feet Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Junk (measured) Length Size Cemented Measured depth True Vertical depth RECEIVED APR ! O 1990 Alaska Oil .& Gas Cons. commlsslq~ 'J~ nrhnmn~i 20. Attachments Filing fee ~ Property plat [] BOP Sketch I~ Diverter Sketch ~" Dril'l[E~"6;'~am ~' Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge//~ ..,,.~ ?'] / ./~..? ../.,,... ~ ~-L~? · Date .-.~ ,~ Commission Use ~nly - - ~ ~) ~ ~~ / z ~~~ ' Permit Number .~ ~API number ~Approval date ~ See ~ver letter Conditions of approval Samples required ~ Yes ~No Mud log required ~ Yes ~No Hydrogen sulfide~measures .U Ye~ No Directional survey required ~Yes U N O R~q~ir~d w~rking p~r~ ~r ~] ~;%~2M; ~ 5M; ~ ~0M; ~ ~5M Other: //~ / ~~~/~~ _ cOmmissioner order o, Approved by ( ~ ./. ( ' the commission Date Form 10-401 Rev.12-1-85- ' ~ ' / / Sub'it ~triplica~ . . PBU DS 16-22 OPERATIONS SUMMARY MIRU drilling rig. NU diverter and function test same. Ddll 17-1/2" hole to 500 ' TVD/MD and kickoff. Build angle at 2.0 degrees/100 ft. to 54° 20' at 2827' TVD / 3217' MD. Drill 17-1/2" hole to 3500' TVD / 4369' MD maintaining the 54° 20' hole angle in a N 69 degrees 11' E direction. Set 13-3/8" casing and cement same. Nipple up BOPE and test to 5000 psi. Test casing to 2500 psi for 30 minutes. 4. Pick up 12-1/4" BHA and GIH. Drill 10 ft of new hole and perform leakoff test. . Drill 12-1/4" hole to 9000' 'I'VD / 13806' MD maintaining the 54° 20' hole angle in a N 69 o 11'W direction. 6. Set 9-5/8" casing and cement same. 7. Pick up 8-1/2" BHA and GIH. Test casing to 3000 psi. 8. Drill 10 ft of new hole and perform EMW test. 9. Drill 8-1/2" hole to 9337' 'I-VD / 14386' MD maintaining the hole angle at 54o 20'. 10. Run wireline logs as programmed. 11. Set 7" liner and cement same. 12. Clean out the 7" liner and test liner to 3000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 13. Release drilling rig. Run cased hole logs 7 days after rig release. 14. MI and RU completion rig. Run tubing and packer assembly. N/U tree and test to 3000 psi. Release completion rig. 15. Rig up wireline unit and perforate. RECEIVED APR ][ 0 1990 .0il & Gas Cons. Commissio~ Anch0rag~ NOTE; PBU DS 11-22 OPERATIONS SUMMARY CONT. a. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid dudng any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Well within 200 ft. of the proposed well is: DS16-24 60 ft @ DS16-5 175 ft @ SURFACE TO 500' TVD / MD SURFACE TO 600' TVD / MD c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). e. Based on previous logs on DS 11, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. RECEIVED APR 1 0 1990 Alaska 0JJ & Gas Corl8. C0mmissi0[? AnchOrage i i i i i i i i i i i i i i i I i i i i i i i T I I I I r r i I I I I I I I I I I I r I I i .................. RKR 1/~T.EVATION 70' ?~" '~'--'. 20" Casing TVD=I 10 TMD=ll0 --0 AR(20 ALASKA, II C. :2.0 ..o DS1(5-22 8.0 ~}t ~4.o SHL: U 1 DN 15E 24 1742' ~tL 1271' FWL }~ ~a.o THL: U 1ON 16E 17 3506' 1~ IL 5111' FEL ~2~.Ozo BHL: U 10N 16E 17 1906' FilL 518' FWL It 24.o N 69 11' 26.0 \% ~o \% ~o -~6,0 18.0 ~4.o EOC ~=2~27 ~3217 D~=I ~ - ' ' ~=35~ ~369 DE~2130 ~85 D~=35~ A~GE ~ NG~ = ~ 20' RECEIVED APR 10 !990 ~~:~,7o ~,~,,: ~:,~, A!aS~ 0il .a Gas Cons. Gom~tSslol~. An,:horage ~70 F~=128~ DE~ ~ ~D~010 T~=1382 D~=9813 ~ ~ Top Sadl~t ~:=~10 ~=138~ D[ ~9813 T~GE r ~70 T~=12 )27 D~=98~ HOE ~=~80 ~=13 ~2 D~=~ O~ Contact ~=91~ ~13~ ~ D~=9937 B~e Sadl~ochit ~=9~0 ~142: 4 D~=101~ ~ ~=9337 ~ ~14386 D~=10270 ................................................................ 2000 3000 4000 5000 6000 7000 8000 9000 10000 7000 8000 9000 10000 11000 12000 13000 VERTICAL SECTION 14000 ARCO ALASKA, INC. DS16-22 N69 ll'E E - W COORDINATES 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11 ( RECEIVED APR 10 1990 Alas.l~a .Oil & Gas Cons. Ar~chorag~ 50 0 50 1 O0 1 50 200 250 300 :~50 200 150 1:00 5O oo 1 ~oo 110o 900 500 .., ~'t :~oo .,. -.-'~ 1 O0 .- 900 · ' 500 o ~ - _ 50 ~oo I _ '= D5 I(,-Z ~_ ~ oo 50 0 50 1 O0 1 50 200 250 300 :350 PBU DS 11-22 MUD PROGRAM DEPTH (TVD) DENSITY ViS (PPG) YP INT 10 MIN FL OIL SOLIDS MUD GELS GELS CC/30MIN (%) (%) TYPE SPUD to 13-3/8 csg pt. DEPTH (TVD) 8.8 300 to to 9.2 100 DENSITY (PPG) 70 30+ 50+ 25 0 2 GEL-BENEX to to SPUD MUD 40 6 SET 13-3/8" CASING PV YP INT 10 min FL OIL SOLIDS MUD (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 13.3/8" to 5400 9 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 9.6 15 10 4 10 15 6 POLYMER 5400 9.6 10 6 2 4 15 0 2 LIGHTLY to to to to to to to to to TREATED K-10 9.7 15 10 4 10 10 6 POLYMER K-10 9.8 10 6 2 4 10 2 4 LIGHTLY to to to to to to to to to TREATED 9-5/8" 10.3 15 10 4 10 6 5 9 POLYMER SET 9-5/8" CASING DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 9-5/8" 8.7 10 6 2 8 8 2 4 LIGHTLY to to to to to to to to to TREATED 7" Liner 9.1 15 10 4 10 6 5 6 POLYMER SET 7" LINER . THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. ANY MAJOR CHANGES SHOULD BE DISCUSSED WITH THE ANCHORAGE OFFICE. R ¢ lVrr. g APR ], 0 1990 ~iasl~a 0il & 6as Cons. Co~mtss~0:~---"" Anchoraq~ NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP LINE RISER FLOWUNE I 20" 21:X)0 PSI DIVERTER RECEIVED I 10" BALL VALVE I I APR ! O ~_990 I Alaska 0il & Gas Cons. I~ AnchOrage 10" BALL VALVE i CONDUCTORI NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT 10" VENT LINE 10" VENT UNE DIVERTER UNES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEES. 13-5/8" 5000 psi BOP STACK DIAGRAM I IPE RAMS L~LIND RAMSj[~ SPOOL ~ I .CASING ~ SPOOL BRADEN ~ HEAD ~ ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES . 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. NABORS 28E MI3) SYSTEM PIT #1 130 BBLS PIT #2 81 BBLS PIT #5 117 BBLS PILL PIT 20 BBLS PIT #6 135 BBLS TRIP TANK 170 BBLS PIT #3 137 BBLS PIT $4 179 BBLS EQUIPMENT - DRILLING FLUID SYSTEM (3) DERRICK FLO-LINE CLEANER (1) DERRICK MUD C?.~.~NER (1) BRANDT CF-2 CENTRIFUGE (1) PIONEER MARK I CENTRIFUGE (1) RIG BUILT GAS BUSTER (1) DRILCO DEGASSER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRILLING FLOW SHOW SENSOR W/ readout convenient to the driller's console R ¢EIVED APR ! 0 1990 :Oil & ~as Cons. Com~'~s~i~.~ AnchOrag~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc /('~-~}~fhru 8) (8) (3) Admin (~91 9~z5/~z'~ 9. hru 13) ' '-- 10. (10 and 13) 1:2. , I3. (14 thru 22) 14. 15. (5) BOPE ,~f. ~", ~'.~' (23 thru 28) Company Lease & Well No. ~ YES NO _ Is the permit fee attached .......................................... 2. Is well td be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO~P psig".. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. 23. 24. 25. 26. 27. 28. (6) Add: ~',~',~. 4/-t~-~ Geology: Engi~ee~i~fig: ~- Dwi ,vv scs rev: 01/30/89 6.011 For 29. 30. 31. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. ~ Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXi ., No special 'effort has been made to chronologically organize this category of information. -; · .. PROGRAM: LIS REVISION: 4.1 Start of execution: Mon 2 JLY 90 ll:02am PART NUMBER: W5550-MICRO WELL DATA FILE: C:\WDSDATA\W04370.WDF ECC: 4370.00~ COMPANY NAME: ARCO ALASKA INCORPORATED WELL NAME: D.S. 16 - 22 FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 13780.000 14230.000 0.500 NUMBER OF CURVES: 21 DEPTH CAL CHT CNC GR PE RFOC RILD RILM SFT2 SSD SSN TTEN ZCOR ZDEN HRD1 HRD2 LSN SHR SP SPD COMPANY:ARCO ALASKA INCORPORATED WELL:D.S. 16 - 22 FIELD:PRUDHOE BAY COUNTY:NORTH SLOPE STATE:ALASKA TAPE INFORMATION FILE:MAIN .001 FILE INTERVAL: START= 14230.000 END= 13780.000 DEPT GR SPD SP CHT CAL TTEN RILD RILM SSD SHR SFT2 HRD1 LSN SSN CNC ZDEN ZCOR PE RFOC HRD2 14230.000 14205.000 14180.000 14155.000 14130.000 14105.000 14080.000 14055.000 14030.000 14005.000 13980.000 13955.000 13930.000 13905.000 13880.000 13855.000 -999. -999. -999. · 53. 3. O. 90. 3. 119. 97. 9. 48. 39. 21. 108. 59. 18. 81. 33. 14. 73. 49. 22. 88. 48. 21. 94. 84. 5. 24. 99. 5. 19. 137. 8. 29. 111. 14. 28. 100. 11. 30. 72. 31. 30. 250 250 250 000 225 000 885 714 0O0 402 836 8O8 041 578 139 358 317 012 811 005 190 000 235 962 204 447 547 559 132 809 276 603 993 714 477 578 531 785 819 506 089 878 202 647 669 403 399 204 -999. -999. -999. 26. 3. O. 26. 4. 0. 26. 4. 320. 26. 9. 176. 26. 19. 290. 26. 17. 246. 26. 13. 233. 26. 17. 250. 26. 19. 267. 26. 4. 134. 26. 4. 124. 26. 10000. 145. 27. 10000. 141. 27. 10000. 144. 27. 10000. 154. 250 250 250 342 246 00O 342 262 O00 997 339 594 107 288 327 997 773 603 997 112 674 762 158 309 342 833 615 997 144 163 997 672 827 997 398 076 997 000 228 652 000 635 997 000 014 888 000 120 -999.250 -999.250 -999.250 -81. 150 0.000 0.000 -52.349 0.000 0.000 -34.022 8698.859 24.636 19.781 8632.199 37.177 -49.385 9106.418 24.813 -34.238 9075.199 29.073 -68.350 8939.355 30.521 -47.537 8881.312 26.516 -105.714 8549.848 26.364 -28.739 12767.789 73.391 3.362 10455.121 115.341 -58.336 2632.373 58.700 -79.073 2756.181 59.524 -78.826 2583.968 54.737 -69.831 1091.181 64.636 -999.250 -999.250 -999.250 1250. 312 0.000 2.000 1187.864 0.478 2.000 1156.260 0.677 2.397 1291.753 0.473 2. 626 1171. 143 0.574 2.346 1168.844 0.447 2.263 1267.696 0.401 2.307 1166.105 0.386 2.359 1125.233 0.424 2.310 1250.181 0. 183 1.698 1067.837 0.218 1.858 1039.953 0.196 2.396 1039.968 0. 175 2.149 1039.093 0.162 2.151 1051.869 0.166 2.227 -999.250 -999.250 -999.250 6.000 0.000 -0.250 6.000 0.000 -0.250 9.022 997.548 0.033 9.984 721.960 0.120 9.040 1280.792 0.039 9.034 1256.995 0.004 9.211 1124. 129 0.013 9.029 1052.727 0.030 9.780 1133.706 -0.012 18.759 2485.229 -0.017 20.805 1666.664 -0.070 8.933 137.284 -0.646 8.933 195.627 -0.714 8.933 182.938 -0.750 9.041 49.484 -1.205 -999.250 -999.250 -999.250 5351.996 0.000 0.000 5218.352 0.000 0.000 5155.684 1314.936 2.249 5495.988 953.559 4.512 5216.746 1564.405 3.187 5261.000 1710.562 4.954 5481.578 1556.649 5.879 5325.234 1430.684 6.255 5248.555 1471.781 5.400 5475.473 4586.941 21.322 5117.242 3012.533 18.439 5092.844 253.559 19.234 5088.625 383.521 20.724 5057.352 362.215 19.401 5044.879 92.012 28.596 -999.250 -999.250 12.444 0.000 13.200 0.000 11.276 1774.338 11.332 1308.252 36.986 1951.432 25.773 2197.539 20.447 2062.816 28.303 1917.447 25.532 1931.383 6.215 8197.437 5.224 5084.770 0.309 428.444 0.310 635.498 0.309 573.594 0.323 190.416 D.S. 16 - 22 DEPT GR SPD SP CHT CAL TTEN RILD RILM SSD SHR SFT2 HRD1 LSN SSN CNC ZDEN ZCOR PE 13830.000 80.904 0.000 -999.250 0.200 0.200 2938.992 26.557 134.579 63.687 500.000 0.190 2.056 13805.000 0.000 0.000 -999.250 0.200 0.200 3149.822 28.373 141.427 61.516 500.000 0.172 2.050 13780.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 13780.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 WELL DATA FILE: C:\WDSDATA\W04371.WDF ECC: 4371.00 COMPANY NAME: WELL NAME: FIELD: LOCATION: ARCO ALASKA INCORPORATED D.S. 16 - 22 Top of Well: Bottom of Well: Level Spacing: 13770.000 14240.000 0.500 9.038 256.016 -0.714 9.038 286.070 -0.677 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4000.000 467.745 18.754 4000.000 505.151 18.676 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 RFOC HRD2 0.200 788.229 0.200 878.779 -999.250 -999.250 -999.250 -999.250 NUMBER OF CURVES: 21 DEPTH CAL CHT CNC GR PE RFOC RILD RILM SFT2 SSD SSN TTEN ZCOR ZDEN HRD1 HRD2 LSN SHR SP SPD FILE:REPEAT.002 FILE INTERVAL: START= 14240.000 END= 13770.000 DEPT 14240.000 14215.000 14190.000 GR SPD SP CHT CAL TTEN RILD RILM SSD SHR SFT2 HRD1 LSN SSN CNC ZDEN ZCOR PE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 27.997 -64.064 0.200 3.927 0.000 0.000 0.000 0.000 30.946 27.997 -74.885 2.045 2.944 0.000 0.000 0.000 0.000 -999.250 -999.250 -999.250 1208.075 0.000 2.000 1121.726 0.000 2.000 -999.250 -999.250 -999.250 6.000 0.000 -0.250 6.000 0.000 -0.250 -999.250 -999.250 -999.250 5232.434 0.000 0.000 5140.500 0.000 0.000 RFOC HRD2 -999.250 -999.250 12.130 0.000 10.500 0.000 14165. 000 86.375 27. 7.419 6. 52.359 186. 997 22.309 1234.880 11.261 5348.602 527 8575.480 0.306 634.429 890.895 006 35.672 2.639 0.121 8.846 6.807 1313.186 14140.000 29.636 27. 3.325 4. 97.116 271. 997 -52.657 1216.509 9.012 5400.516 120 9053.004 0.615 1303.078 1587.047 967 26.151 2.327 0.028 2.780 13.406 1984.654 14115.000 29.259 27. 18.262 17. 112.719 304. 997 -52.042 1307.707 9.144 5565.766 222 8841.387 0.495 1156.432 1496.764 533 24.949 2.327 0.014 4.176 41.366 1973.374 14090.000 49.857 27. 14.150 13. 79.356 229. 997 -20.052 1218.780 10.022 5457.582 258 9399.699 0.491 1528.157 1952.546 585 27.284 2.204 0.001 4.232 13.875 2470.135 14065.000 29.170 27. 14.075 12. 78.323 252. 997 -80.403 1175.108 8.982 5341.559 486 9011.773 0.407 1296.444 1745.266 370 31.374 2.247 -0.006 5.752 18.762 2213.324 14040.000 38.022 27. 16.862 12. 90.169 257. 997 -71.087 1154.371 9.045 5300.285 020 8607.223 0.442 1054.631 1428.803 574 26.837 2.349 0.007 5.039 23.461 1827.906 14015.000 54.503 28. 25.595 20. 74.366 218. 652 -52.770 1277.573 9.225 5529.980 799 8739.586 0.471 1285.135 1617.779 961 27.914 2.274 -0.014 4.542 32.528 2053.525 13990.000 85.188 28. 6.665 4. 22.258 123. 997 -2.841 1174.146 17.548 5363.402 708 12708.535 0.206 2441.891 4199.633 758 79.108 1.790 0.016 16.711 5.644 7067.520 13965.000 76.632 28. 6.127 4. 21.097 124. 997 2.951 1062.564 23.319 5140.012 801 12107.891 0.213 1634.531 2953.374 726 93.391 2.035 0.086 17.014 5.433 4776.484 13940.000 88.677 28. 4.786 175. 24.281 106. 761 6.869 1055.514 20.469 5125.520 889 12797.445 0.189 822.014 1442.064 489 48.571 2.625 0.355 16.948 1.381 2397.138 13915.000 104.885 28.106 11.191 10000.000 29.639 152.648 -50.596 1047.761 8.943 5146.746 2427.219 0.159 133.754 248.747 65.961 2.279 -0.736 24.525 0.305 475.281 13890.000 105.126 28.997 10.797 10000.000 28.368 140.810 -49.372 1049.413 8.933 5118.793 2618.100 0.162 164.540 344.190 60.988 2.186 -0.729 22.796 0.309 562.460 13865.000 130.814 28.997 11.102 10000.000 27.647 142.173 -39.118 1048.594 8.933 5110.215 2672.823 0.172 200.307 379.358 65.739 2.133 -0.738 19.033 0.309 621.622 D.S. 16 - 22 DEPT GR SPD SP CHT CAL TTEN RILD RILM SSD SHR SFT2 HRD1 LSN SSN CNC ZDEN ZCOR PE RFOC HRD2 13840.000 94.288 0.000 -27.394 500.000 9.038 4000.000 0.200 0.200 3049.674 0.169 190.507 429.828 27.101 142.158 68.725 2.197 -0.639 22.931 0.200 653.278 13815.000 0.000 0.200 0.000 -999.250 0.200 1194.877 500.000 0.139 9.038 4000.000 73.825 152.134 0.200 273.833 29.634 143.756 58.242 2.015 -1.235 26.623 13790.000 0.000 0.000 -999.250 500.000 6.000 4000.000 0.200 0.200 0.000 0.000 0.000 0.000 27.554 134.150 58.657 2.000 -0.250 0.000 0.200 0.000 13770.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 End of execution: Mon 2 JLY 90 ll:02am Elapsed execution time = 10.43 seconds. SYSTEM RETURN CODE = 0 LIs VERIFICATION LISTING FOR: ARCO ALASKA INC. DRILL SITE 16 WELL 22 PRUDHOE BAY R ¢EJVED JUN 2 2 1990 ,OJJ & Gas Cons. Commission Anchorage ! t J i i J i I J i i I I I t i i J ** reel header ** service name :RGD date :90/06/14 origin :2200 reel name :758TAK continuation # :01 previous reel : comment :TELECO OILFIELD SERVICES PROPRIETARY FIELD TAPE ** tape header ** service name :RGD date :90/06/14 origin :2200 tape name :758TAK continuation # :01 previous tape : comments :RIG NABORS ALASKA #28 E ** file header ** file name :758TAK. 001 service name :RGD version # : 1.31 date :90/06/14 maximum length :1024 file type :LO previous file : ** information records ** table type :TOOL MNEM STAT LENG WEIG HEIG GR ALLO 0.000 0.000 0.000 RSN ALLO 72.000 0.000 0.000 DCDS ALLO 360.000 0.000 0.000 ** information records ** STAT PUNI TUNI table type :CONS MNEM VALU J J J J i J J J J J J J J ,~ J J J J J BS UNAL IN IN 12.250 CSIZ UNAL IN IN 13.375 SD UNAL F F 11600.000 WMUD UNAL LB/G LB/G 10.500 SHT UNAL DEGF DEGF 0.000 BHT UNAL DEGF DEGF 0.000 TD UNAL F F 13965.000 YEAR UNAL 90.000 MONT UNAL 6.000 DAY UNAL 14.000 ** information records ** table type :CONS MNEM STAT PUNI ~NI VALU SON UNAL R~ UNAL R2 UNAL R3 UNAL R4 UNAL R5 UNAL R6 UNAL R7 UNAL R8 UNAL HIDE UNAL WN UNAL CN UNAL FN UNAL FL UNAL FL1 UNAL LUL UNAL ENGI UNAL WITN UNAL DFT UNAL LONG UNAL LATI UNAL STAT UNAL COUN UNAL DMF UNAL LMF UNAL PDAT UNAL APIN UNAL RESISTIVITY/GAMMA/DIRECTIONAL DRILL SITE 16 WELL #22 ARCO ALASKA INC. PRUDHOE BAY ANCHORAGE ST. PIERRE/BROCKWAY JOHNSON ALASKA NORTH SLOPE RKB RKB I i . I I I i I i I t I I I I I I I I I OS1 OS2 OS3 OS4 OS5 OS6 TLAB TCS TN1 TN2 TN3 TN4 TN5 TN6 TN7 TN8 TN9 TN10 TNll TN12 SECT TOWN RANG NATI CONT MSS . MFSS MCSS SLAB CLAB CS1 CS2 CS3 BSl BS2 BS3 HLD RUN LUN OPER LLUN LCC BLI TLI EPD UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL F F F USA NAM STATE COUNTY 13.375 17.50 12.25 INCL 0.000 2300.000 0.000 0.000 O.000 0.000 0.000 0.000 APD UNAL EKB UNAL EDF UNAL EGL UNAL TDD UNAL TDL UNAL CW1 UNAL BSD1 UNAL CBD1 UNAL CBL1 UNAL CW2 UNAL BSD2 UNAL CBD2 ~q~AL CBL2 UNAL CW3 UNAL BSD3 UNAL CBD3 ~q~AL CBL3 UNAL sTEM UNAL MRT UNAL DFD UNAL DFV UNAL DFPH UNAL DFL UNAL RMFS UNAL RMS UNAL RMCS UNAL MST UNAL MFST UNAL MCST UNAL ** information records ** i F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF t i I i i F 0.000 F 31.550 F 30.550 F 0.000 F 13965.000 F 13965.000 LB/F 0.000 F 0.000 F 0.000 F 0.000 LB/F 0. 000 F 0.000 F 0.000 F 0.000 LB/F 0. 000 F 0.000 F 0.000 F 0.000 DEGF 0.000 DEGF 0-00!0 LB/G 0'000 S 0.000 0.000 C3 0.000 OHMM 0.000 OHMM 0.000 OHMM 0.000 DEGF 0.000 DEGF 0.000 DEGF 0.000 table type MNEM OUTP STAT TRAC CODI ALLO Ti LLIN ALLO T2 MLIN ALLO T3 LSPO ALLO T3 LLIN DISA T3 LLIN DISA T2 LDAS DISA T2 MDAS GRCX GRCX RSAX RSAX ROPS ROPS WBCS WBCS DT DT ILD0 ILD ILD1 ILD i I I i DEST 1 1 1 1 1 1 1 MODE NB GRAD NB NB SHIF GRAD GRAD J J J J J i J J J J . ! J i .J ! i t i i TT1 TT1 DISA T3 LLIN TT2 TT2 DISA T3 LSPO TT3 TT3 DISA T3 LDAS TT4 TT4 DISA T3 LGAP TENS TENS DISA T3 LSPO 12 DUMM DISA Ti LLIN 13 DUMM DISA T1 LLIN 14 DUMM DISA Ti LLIN 15 DUMM DISA T1 LLIN 16 DUMM DISA Ti LLIN 17 DUMM DISA Ti LLIN 18 DUMM DISA Ti LLIN 19 DUMM DISA T1 LLIN ** information records ** 1 1 1 1 1 NEIT NEIT NEIT NEIT NEIT NEIT NEIT NEIT SHIF SHIF SHIF SHIF NB NB NB NB NB NB NB NB NB table type :FILM MNEM GCOD GDEC iDEST DS CA 1 E2E -2- PFI S2 2 EEE -2- PF2 D500 ** information records ** table type :AREA MNEM STAT BEGI END PATT DEST 1 DISA Z1 Z1 BLAN NEIT 2 DISA Z1 Z1 BLAN NEIT 3 DISA Z1 Z1 BLAN NEIT 4 DISA Z1 Z1 BLAN NEIT 5 DISA Z1 Z1 BLAN NEIT 6 DISA Z1 Z1 BLAN NEIT 7 DISA Z1 Z1 BLAN NEIT 8 DISA Z1 Z1 BLAN NEIT ** data-format record ** entry blocks type 4 8 size repr code entry 1 66 255 4 68 60.000 9 4 65 .liN 12 4 68 -9999.000 0 2 79 0 datum specification blocks WARNING the following table is in LIS Datum Specification Block Sub-Type 0 and the API Type Codes may be Unreliable!!! mnem service service unit api api api api file size spl repr id order # log type class mod no. code DEPT FT 00 000 00 00 0 4 1 68 ROPS 00 000 00 00 0 4 1 68 WBCS 00 000 00 00 0 4 1 68 RPMS 00 000 00 00 0 4 1 68 TCDX 00 000 00 00 0 4 1 68 GRBX 00 000 00 00 0 4 1 68 GRAX 00 000 00 00 0 4 1 68 GRCX 00 000 00 00 0 4 1 68 SNBX 00 000 00 00 0 4 1 68 RSAX 00 000 00 00 0 4 1 68 RSCX 00 000 00 00 0 4 1 68 CSAX 00 000 00 00 0 4 1 68 CSCX 00 000 00 00 0 4 1 68 INC 00 000 00 00 0 4 1 68 AZM 00 000 00 00 0 4 1 68 TVD 00 000 00 00 0 4 1 68 process level depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX 11600.0000 feet .... 1.0000 WBCS 1.0000 GRAX 1.0000 RSCX 1.0000 AZM 3535.6800 meters 1.0000 RPMS 1.0000 TCDX 1.0000 GRCX 1.0000 SNBX 1.0000 CSAX 1.0000 CSCX 1.0000 TVD 1.0000 11650.0000 feet .... 3550.9200 meters 71.7500 WBCS 13.2200 RPMS 95.7000 TCDX 168.8700 GRAX 140.8700 GRCX 200.7300 SNBX 2.9900 RSCX 2.9900 CSAX 334.8700 CSCX -9999.0000 AZM -9999.0000 TVD -9999.0000 11700.0000 feet 53.7300 WBCS 153.1300 GRAX 3566.1600 meters 15.8600 RPMS 0.0000 TCDX 125.9900 GRCX 179.5300 SNBX 1.0000 1.0000 1.0000 132.8000 0.4300 334.8700 136.4000 0.4400 kSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC 3.0900 RSCX 3.0900 CSAX 323.2000 -9999.0000 AZM -9999.0000 TVD -9999.0000 11750.0000 feet .... 3581.4000 meters 87.2200 WBCS 13.1600 RPMS 450.0000 183.2000 GRAX 154.4300 GRCX 220.0400 3.3600 RSCX 3.3600 CSAX 297.1900 -9999.0000 AZM -9999.0000 TVD -9999.0000 11800.0000 feet .... 3596.6400 meters 92.5300 WBCS 10.1200 RPMS 286.3600 202.5800 GRAX 172.7600 GRCX 246.1600 3.1600 RSCX 3.1600 CSAX 316.8900 -9999.0000 AZM -9999.0000 TVD -9999.0000 11850.0000 feet .... 3611.8800 meters 87.7500 WBCS 13.6600 RPMS 173.3600 172'5800 GRAX 144.3900 GRCX 205.7300 3.6000 RSCX 3.6000 CSAX 277.5400 -9999.0000 AZM -9999.0000 TVD -9999.0000 11900.0000 feet .... 3627.1200 meters 39.4000 WBCS 9.9900 RPMS 317.6500 166.4700 GRAX 138.6100 GRCX 197.5000 3.0600 RSCX 3.0600 CSAX 326.4500 -9999.0000 AZM -9999.0000 TVD -9999.0000 11950.0000 feet .... 3642.3600 meters 63.8900 WBCS 8.2000 RPMS 102.5900 179.0000 GRAX 150.4600 GRCX 214.3800 3.7600 RSCX 3.7600 CSAX 265.7700 -9999.0000 AZM -9999.0000 TVD -9999.0000 12000.0000 feet .... 3657.6000 meters 43.3300 WBCS 12.0100 RPMS 125.0000 171.2900 GRAX 143.1600 GRCX 203.9900 3.9500 RSCX 3.9500 CSAX 253.3800 -9999.0000 AZM -9999.0000 TVD -9999.0000 12050.0000 feet .... 3672.8400 meters 42.0900 WBCS 9.7400 RPMS 125.0000 168.5000 GRAX 140.5300 GRCX 200.2300 3.6000 RSCX 3.6000 CSAX 277.5400 -9999.0000 AZM -9999.0000 TVD -9999.0000 CSCX TCDX SNBX CSCX TCDX SNBX CScx TCDX SNBX cscX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX 323.2000 136.4000 0.4800 297.1900 135. 1400 0'4500 316.890© 138. 2000 0.5.100 277' 5400 138.2000 0.4400 326.4500 129.2000 0.5400 265.7700 132.8000 0.5600 253.3800 132.8000 0.5100 277.5400 depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX 12100.0000 feet .... 3688.0800 meters 96.1400 WBCS 12.5900 RPMS 132.3000 177.1900 GRAX 148.7500 GRCX 211.9400 2.9600 RSCX 2.9600 CSAX 337.8800 -9999.0000 AZM -9999.0000 TVD -9999.0000 12150.0000 feet .... 3703.3200 meters 70.6300 WBCS 8.2600 RPMS' 144.7600 172.72,00 GRAX 144.5200 GRCX 205.9200 4.4400 RSCX 4.4700 CSAX 225.0100 -9999.0000 AZM -9999.0000 TVD -9999.0000 12200.0000 feet .... 3718.5600 meters 88.7300 WBCS i6..4400 RPMS 125.0000 179.8500 GRAX 151.2600 GRCX 215.5300 3.5300 RSCX 3.5300 CSAX 283.1500 -9999.0000 AZM -9999.10000 ~D -9999.0000 12250.0000 feet .... 3733.8000 meters 88.0800 WBCS 10.1200 RPMS 125.0000 172.9600 GRAX 144.7400 GRCX 206.2400 4.1200 RSCX 4.1300 CSAX 242.6100 -9999.0000 AZM -9999.0000 TVD -9999.0000 12300.0000 feet .... 3749.0400 meters 128.3700 WBCS 16.2200 RPMS 125.0000 164.2400 GRAX 136.5000 GRCX 194.4900 3.4100 RSCX 3.4100 CSAX 292.9300 -9999.0000 AZM -9999.0000 TVD -9999.0000 12350.0000 feet .... 3764.2800 meters 51.2700 WBCS 9.7300 RPMS 125.0000 160.2700 GRAX 132.7400 GRCX 189.1400 4.0800 RSCX 4.0800 CSAX 245.1100 -9999.0000 AZM -9999.0000 TVD -9999.0000 12400.0000 feet .... 3779.5200 meters 19.9000 WBCS 102.7300 RPMS 125.0000 181.1300 GRAX 152.4700 GRCX 217.2500 4.4100 RSCX 4.4400 CSAX 226.7900 -9999.0000 AZM -9999.0000 TVD -9999.0000 12450.0000 feet .... 3794.7600 meters 18.7800 WBCS 110.9200 RPMS 125.0000 171.5200 GRAX 143.3800 GRCX 204.3000 TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX 129.2000 0.4200 337.8800 129.2000 0.6300 223.5200 132-8000 0.5000 283.1500 134'0200 0.5900 242.1700 134.6000 0.4900 292.9300 136.4000 0.5800 244.8200 120.2000 0.6300 225.4100 125.6000 0.5600 J J J J . ! ! J J I I | ! J I J J J ~ J RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX iNC depth = ROPS GRBX RSAX lINC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC 3.9000 RSCX 3.9000 CSAX 256.1100 -9999.0000 AZM -9999.0000 TVD -9999.0000 12500.0000 feet .... 3810.0000 meters 39.5400 WBCS 106.7600 RPMS -9999.0000 170.5000 GRAX 142.4200 GRCX 202.9300 4.2600 RSCX 4.2800 CSAX 234.6300 -9999.0000 AZM -9999.0000 TVD -9999.0000 12550.0000 feet .... 3825.2400 meters 29.2800 WBCS 113.2800 RPMS -9999.0000 186.4700 GRAX 157.5200 GRCX 224.4400 3.3400 RSCX 3.3400 CSAX 299.3900 -9999.0000 AZM -9999.0000 TVD -9999.0000 12600.0000 feet .... 3840.4800 meters 61. 7300 WBCS 17. 2100 RPMS -9999. 0000 185.9300 GRAX 157.0100 GRCX 223. 7300 4. 0900 RSCx 4. 1000 csAX 244.2200 -9999 · 0000 AZM -9999. 0000 TVD -9999- 0000 12650.0000 feet .... 3855.7200 meters 34.8000 WBCS 16.3200 RPMS 125.0000 241.6100 GRAX 209.6700 GRCX 298.7600 4.2100 RSCX 4.2200 CSAX 237.7600 -9999.0000 AZM -9999.0000 TVD -9999.0000 12700.0000 feet .... 3870.9600 meters 110.7500 WBCS 17.0700 RPMS 125.0000 271.2800 GRAX 237.7200 GRCX 338.7300 2.9000 RSCX 2.9000 CSAX 345.4400 -9999.0000 AZM -9999.0000 TVD -9999.0000 12750.0000 feet .... 3886.2000 meters 81.4900 WBCS 16.4600 RPMS 125.0000 194.5100 GRAX 165.1300 GRCX 235.2900 2.7300 RSCX 2.7300 CSAX 366.5700 -9999.0000 AZM -9999.0000 TVD -9999.0000 12800.0000 feet .... 3901.4400 meters 144.1600 WBCS 20.0800 RPMS 125.0000 211.9700 GRAX 181.6300 GRCX 258.8000 2.7500 RSCX 2.7500 CSAX 363.9000 -9999.0000 AZM -9999.0000 TVD -9999.0000 CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBx cscx TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX 256.1100 127.4000 0.6100 233.7100 129.2000 0.4800 299.390O 129 · 2000 0'~5800 243. 8800 134.6000 0.6000 237.0200 136.4000 0.4100 345.4400 136.4000 0.3900 366.5700 138.2000 0.3900 363.9000 depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX 12850.0000 feet .... 3916.6800 meters 113.0100 WBCS 10.5200 RPMS 125.0000 154.5300 GRAX 127.3100 GRCX 181.4000 3.2800 RSCX 3.2800 CSAX 305.1200 -9999.0000 AZM -9999.0000 TVD -9999.0000 12900.0000 feet .... 3931.9200 meters 67.7900 WBCS 14.2000 RPMS 125.0000 147.4600 GRAX 120.6300 GRCX 171.8900 3.0800 RSCX 3.0800 CSAX 324.2400 -9999.0000 AZM -9999.0000 TVD -9'999.0000 12950.0000 feet .... 3947.1600 meters 109.3500 WBCS 15.0100 RPMS I25.0000 168.0000 GRAX 140.0500 GRCX 199.5600 3.6200 RSCX 3.6200 CSAX 276.8400 -9999.'0000 AZM -9999.0000 TVD -9999.0000 13000.0000 feet .... 3962.4000 meters 102.7300 WBCS 14.7400 RPMS 125.0000 187.2100 GRAX 158.2200 GRCX 225.4500 3.1000 RSCX 3.1000 CSAX 322.4900 -9999.0000 AZM -9999.0000 TVD -9999.0000 13050.0000 feet .... 3977.6400 meters 52.2200 WBCS 87.4000 RPMS 125.0000 179.5000 GRAX 150.9300 GRCX 215.0600 2.5400 RSCX 2.5400 CSAX 392.9900 -9999.0000 AZM -9999.0000 TVD -9999.0000 13100.0000 feet .... 3992.8800 meters 53.1300 WBCS 9.3200 RPMS 125.0000 200.3100 GRAX 170.6100 GRCX 243.0900 3.3200 RSCX 3.3200 CSAX 300.9600 -9999.0000 AZM -9999.0000 TVD -9999.0000 13150.0000 feet .... 4008.1200 meters 35.3300 WBCS 10.1400 RPMS 125.0000 298.0000 GRAX 263.0000 GRCX 374.7400 3.9600 RSCX 3.9600 CSAX 252.4800 -9999.0000 AZM -9999.0000 TVD -9999.0000 13200.0000 feet .... 4023.3600 meters 64.6300 WBCS 10.6800 RPMS 125.0000 332.4900 GRAX 295.6200 GRCX 421.2200 TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX 138.2000 0.4700 305.1200 140.0000 0.4400 324.2400 140.0000 0.5200 276.8400 141.8000 0.4400 322.4900 134.6000 0.3600 392.9900 141.8000 0.4700 300.9600 144.4300 0.5600 252.4800 141.8000 0.9800 t I t I J I i ! i J ! J i i I t I I J RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC 6.8400 RSCX 7.1900 CSAX 146.1600 CSCX -9999.0000 AZM -9999.0000 TVD -9999.0000 13250.0000 feet .... 4038.6000 meters 58.2400 WBCS 11.3300 RPMS 125.0000 250.5500 GRAX 218.1200 GRCX 311.4800 4.7700 RSCX 4.7700 CSAX 209.7900 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 13300.0000 feet .... 4053.8400 meters 34.8700 WBCS 44.6200 RPMS 130.0000 241.1800 GRAX 209.2600 GRCX 305.5200 4.5600 RSCX 4.5600 CSAX 219.5500 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 13350.0000 feet .... 4069.0800 meters 37.7300 WBCS 49.7600 RPMS 130.0000 227.7700 GRAX 196.5800 GRCX 287.0000 5.9100 RSCX 5.9500 CSAX 169.1100 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 13400.0000 feet .... 4084.3200 meters 28.7400 WBCS 48.3000 RPMS 130.0000 243.6700 GRAX 211.6100 GRCX 308.9500 4.1600 RSCX 4.1600 CSAX 240.1800 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 13450.0000 feet .... 4099.5600 meters 52.3800 WBCS 58.0100 RPMS 130.0000 215.7100 GRAX 185.1700 GRCX 281.5400 4.6900 RSCX 4.6900 CSAX 213.4000 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 13500.0000 feet .... 4114.8000 meters 32.8700 WBCS 53.0200 RPMS 125.0000 224.7300 GRAX 193.7100 GRCX 294.5100 6.9300 RSCX 7.0500 CSAX 144.2400 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 13550.0000 feet .... 4130.0400 meters 45.4500 WBCS 53.4300 RPMS 130.0000 199.0900 GRAX 169.4600 GRCX 257.6400 6.7800 RSCX 6.8400 CSAX 147.4900 -9999.0000 AZM -9999.0000 TVD -9999.0000 TCDX SNBX CSCX 139.0600 145.4000 0.6800 209.7900 139.78010 0.6500 219.5500 143.6000 0.8400 i68.2300 152.6000 0.5900 240.1800 152.6000 0.6700 213.4000 140.0000 0.9900 141.9000 143.6000 0.9700 146.2800 i t ! I ~ i J t I t I . ~t i i I J i J I depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX tNC dePth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX RSAX INC depth = ROPS GRBX 13600.0000 feet 4145.2800 meters 25.6900 WBCS 55.8600 RPMS 130.0000 210.6300 GRAX 180.3700 GRCX 274.2300 8.3100 RSCX 8.5100 CSAX 120.3000 -9999.0000 AZM -9999.0000 TVD -9999.0000 13650.0000 feet .... 4160.5200 meters 21.7300 WBCS 55.8100 RPMS 130.0000 155.8900 GRAX 128.6000 GRCX 195.5300 14.5600 RSCX 16.5000 CSAX 68.6800 -9999.0000 AZM -9999.0000 TVD -9999.0000 13700.0000 feet .... 4175.7600 meters 20.0600 WBCS 55.2700 RPMS 130.0000 240.8300 GRAX 208.9300 GRCX 317.6600 3.9900 RSCX 3.9900 CSAX 250.7200 -9999.0000 AZM -9999.0000 TVD -9999.0000 13750.0000 feet .... 4191.0000 meters 27.3300 WBCS 57.5500 RPMs 130.0000 288.5900 GRAX 254.1000 GRCX 386.3300 6.2200 RSCX '6.2400 CSAX 160.6500 -9999.0000 AZM -9999.0000 TVD -9999.0000 13800.0000 feet .... 4206.2400 meters 18.3500 WBCS 56.7900 RPMS 130.0000 261.3400 GRAX 228.3300 GRCX 347.1600 5.9200 RSCX 5.9300 CSAX 168.8700 -9999.0000 AZM -9999.0000 TVD -9999.0000 13850.0000 feet .... 4221.4800 meters 27.6200 WBCS 57.5400 RPMS 130.0000 275.2700 GRAX 241.5100 GRCX 367.1900 8.1100 RSCX 8.2800 CSAX 123.3500 -9999.0000 AZM -9999.0000 TVD -9999.0000 13900.0000 feet .... 4236.7200 meters 16.1000 WBCS 58.7000 RPMS 130.0000 233.2400 GRAX 201.7500 GRCX 306.7400 4.3000 RSCX 4.3000 CSAX 232.7100 -9999.0000 AZM -9999.0000 TVD -9999.0000 13950.0000 feet 4251.9600 meters 21.0900 WBCS 54.5500 RPMS 130.0000 -9999.0000 GRAX -9999.0000 GRCX -9999.0000 TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX csCx TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX CSCX TCDX SNBX 147.2000 1.1900 117.5200 150.8000 2.0800 60.6100 154.3300 0.5700 250.7200 154.4000 ~0.8900 160.2200 152.6000 0.8500 168.8100 156.2000 1.1600 120.7400 158.0000 0.6100 232.7100 159.8000 -9999.0000 ! ! ! I t J J ! ! t i I J J J J J J J RSAX INC -9999.0000 RSCX -9999.0000 AZM -9999.0000 CSAX -9999.0000 TVD -9999.0000 CSCX -9999.0000 -9999.0000 ** file trailer ** file name :758TAK. 001 service name :RGD version ~ : 1.31 date :90/06/14 maximum length :1024 file tYpe :LO next file name :
