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190-080
THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ,ON OR BEFORE OCTOBER 27, 2000 P M C:LORIXMFILM.DOC E E L E W A T.E R IA L UNDER TH IS M ARK ER ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 August 5, 1994 David Sutter, Land Mgr ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Final Location Clearance Two Cook Inlet Wells Dear Mr. Sutter: Two of ARCO's wells have been considered for location clearance; they are Sturgeon #1 and Sunfish #1. Sturgeon #1 (PTD 90-080) was drilled in Cook Inlet waters from the vessel Glomar Marine's Adriatic VIII. There were various plugs placed in the well with the surface plug being installed on 10/22/90. A site clearance survey was made by EBA Engineering in late October, 1990; the results were submitted in a report titled "Results of Side Scan Sonar Survey, Arco Alaska-Sturgeon Well Site Cook Inlet, Alaska". The sonar scans verified that no casing remained above the mud line and that the only visible items were the sand bags and blocks placed to stabilize the Inlet bottom around the rig spud cans (per LCS note, these were okayed by the USCG). Sunfish #1 (PTD 91-055) was drilled in Cook Inlet waters from the vessel Glomar Marine's Adriatic VIII. There were various plugs placed in the well bore with the surface plug being installed on 11/5/91. A site clearance survey was made by ENSR titled "Results of Sunfish No. 1 Salvage Operations, Upper Cook Inlet, Alaska". The report summary, in part: "The side scan sonar records indicate that the sea floor in the area of the Sunfish No. 1 location has been left neat and orderly. The only identifiable impact of the drilling.operation is the shallow imprints on the sea floor where the spud cans were located." Based on the above information, final location clearance is hereby approved for these ARCO wells: Sturgeon #1 (PTD 90-080) ______ Sunfish #3 (PTD 91-055) David W. J~nston Chairman c: Blair Wondzell Dew/11 arZakw ARCO Alaska, Inc Post Office ~. _ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RECEIVED JAN 2 2 1991 Alaska Oil & Gas Cons. Commission Anchorage January 18, 1991 Larry Grant Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Sturgeon #1 Dear Mr. Grant: As requested, this letter is to verify Tape Volser #100880 DIL/BHC/SP/GR/LDT/CNL/GR/CALI Run #1 is included in the library Tape Volser 100883. Sincerely, David J. Doherty Senior Geologist DJD/am , ARCO Alaska, Inc. is a Subsidiary o¢ At.anticRichfieldCompany /~,l!:',l; ~;¢1¢i:~ ~; r-~ ARCO Exploration Company'~' ~ ARCO Oil and Gas Company,~. ~] ARCO Alaska, Inc..~rJ' Record Of Shipment ..,~ Confidential Information Alaska Oil & Gas Conservation Commission Attn: Gwen Thompson IDistrict: Alaska 3001 Porcupine Anchorage, AK (X) Enclosed ( )Under separate cover Subiect: Stur~leon #1 Well Quantity From: ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attn: Mar7 Pryor ()va Map number & description O.H. Edit Verification Listing for Tape Vol. Ser. 100883 DTE/BHC/LDT/CNL Approval: / cc: M. McDermott Note - Plea~, verify and acknowledge receipt~ by signing and returning a copy of this transmittal. Signed by .///~j~w~. ' , .,,'"//~ /~/'7 '~.?, )' .~v._.y_~.,. Date 1/[~/(7( .,/ Received by '~J~)l ~¢;)A/~ J~~ Date Remarks "'-' - ' ~'" ARCO Exploration Company ARCO Oil and Gas Company ARCO Alaska, Inc. {) Record Of Shipment Ot Confidential Information To: Alaska Oil & Gas Conservation Commission Attn: Gwen Thompson 3001 Porcupine Anchorage~ AK From: ARCO Alaska, Inc. IDistrict: Alaska P. O. Box 100360 Anchorage~ Alaska 99510-0360 Attn: David J. Doherty (X) Enclosed ( )Under separate cover ()va Subject: Quantity See Attached List M~p num,,ber & descrlptior~ cc: M. McDermott NOte - Please verify and acknowledge receipt~ by signing and returning a copy of this transmittal. Signed by ' ~ Date Received by Date Remarks TRANSMITTAL A B C D E F G 3 0 100860 TAPE DITE/BHC/SP/LDT/CNL/GR/AMS 1 800BPI 656 TD 3 1 100880 TAPE DIL/BHC/SP/GR/LDT/CNL/GR/CALI 1 800BPI 656 TD 3 2 100881 TAPE DITE/BHC/GR/AMS 2 1600BPI 2679 7158 3 3 100882 TAPE GCT 1 800BPI 0 2502 34 100883 TAPE DTE/BHC/LDT/CNL 1,2 1600BPI 1119.5 7211.5 3 5 100884 TAPE RFT/SP/GR 2 1600BPI 2679 7150 3 6 100885 TAPE LDT/CNL/GR/AMS 2 1600BPI 2679 7156 3 7 REPORT MWD SURVEY ANALYSIS 3 8 REPOF:rr SUB-SURFACE DIRECTIONAL SURVEY RECEIVED JAN 1 0 1991 Alaska Oil & Gas Cons. Commission Anchorag~ Page 1 L_~ ARCO Exploration Company [--] ARCO Oil and Gas Company ~-] ARCO Alaska, Inc. Record Of Shipment ~f Confidential Information Alaska Oil & Gas Conservation Commission Attn' Gwen Thompson 3001 Porcupine Anchorage, AK (X) Enclosed ( )Under separate cover From' ARCO Alaska, Inc. P. O. Box 100360 IDistrict' Alaska Anchorage, Alaska 99510-0360 Attn: David J. Dohert¥ ( )Via Subiect: Stur~leon #1 Well Lo~ls and Core Analysis Report ,Quantity , Map number & description See attached list ..... r'.nns. C0~[ss[0~ cc: M. McDermott Note - Please verify and acknowledge receipt~ by signing and returning a copy of this transmittal. Signedby ~~,~,,~_~ I Date // ~6/Cl i Received by ~ ~ Date Remarks TRANSMITTAL B C D E F G 41 LOG ~ '¥ BOREHOLE COMPENSATED SONIC 1,2 5:100 1269 7152 42 L{:3~ / ~ LITHODENSITY/COMPNEUTRON 1,2 ~ 5:100 1269 7153 43 LOG'/ ~ ADJUSTED SONIC LOGW/GEOGRAM I 2:100 1110 7000 44 LOG~/ v MECHANICAL SIDEWALL CORING TOOL 2 5:100 4585 5876 4 5 LOG ~ ~ BOREHOLE COMPENSATED SONIC 11 2:100 1269 7152 4 6 LOG vx j PRESSURE TEMP GRADIO ! 1 .2:100 0 3020 47 LOG v' vCET (1500 PSI) 1 ~5:100 2600 6612 48 LCG ,/' ~/ CEMENT BOND TOOL 3 5:100 2679 6620 49 ICG -~ V' REPEAT FM TESTER 2 1:100 3557 6468 5 0 I_C~' ~ RAMARKER DEPTH DETERMINATION I 5:100 0 3020 5 1 LOG i ~ GCT GYRO WELLSURVEY 1 0 2502 5 2 ICG 7 j RETAINER DEPTH SET RECORD I 5:100 5200 5660 5 3 LOG v'~ j RA MARKER DEPTH RECORD 1 5:100 4000 4650 5 4 LCG 4/ .J HOLE PROFILE 2 1:100 2679 7153 5 5 LOG / v PHASOR DUAL INDUCTION 1 2:100 1269 7152 5 6 'l_C~ ~ ~ AMSTEMP LOG 2 1 '100 2679 7153 ~ 7 LOG~ j LITHODENSITY/COMP NEUTRON 1 1:100 1269 7153 5 8 LOG ~ J PHASOR DUAL INDUCTION 1,2 5:100 1269 7152 59 ILOG.-~/ ~ TEMPERATURE LOG 1 1:100 1269 2688 60 LOG/ j DIPMETERANALYSIS 1:100 2700 7150 61 LOG~ ~/ FORMATION MICROSCANNER/GR/AMS 2 5:100 2679 7153 62 ILCG ¥ ~/CBT (1500 PSI) I 5:100 2600 6612 6 3 iLGG.: J STRAT HIGH-RES DIPMETER 2 5:100 2679 7143 6 4 LOG ~ ~ EXLOG FM EVALUATION LOG 2:100 1280 7206 6 5 LOG, -~ EXLOG ENGINEERING PARAMETERS LOG 2:100 1280 7206. 66 LOG ~ .~ EXLOG PRESSURE DATA LOG 2:500 1280 7206i 6 7 REPORT ~/ CORE ANALYSIS REPORT Page 1 ARCO Alasks~:,:, ...... ?cst { ¥ .o× "i00360 Anchorage, Alaska 995'~0=0360 Ta~ephone 907 27~ t215 November 16, 1990 Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Completion Report ARCO Sturgeon #1 Dear Commissioner Smith, Attached find the Well Completion Report for the ARCO Sturgeon #1. The well is permanently plugged and abandoned and the rig released. In addition to the Well Completion Report (Form 10-407), enclosed are the following: Well History Well Schematic: Condition After Abandonment ;:--~:~'-Well Testing Summary (including charts) As-built survey plat of wellbore surface location If you have questions or require any additional information, please contact W. J. (Bill) Penrose at 263-4511 or myself at 263-4970 in our Anchorage office. Sincerely, Richard F. Morgan Regional Drilling Engineer , ORIGINAL " ~-~' STATE OF ALASKA '~-" ALAS.,A OIL AND GAS CONSERVATION ,JO ..... JISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Serv,ce Well OIL ~-' GAS .r-] SUSPENDED ~ ABANDONED "~ SERVICE [~] 2 Name of Operator ARCO ALASKa, INC. 3. Address P,O. BOX 100360, Anchorage, Ak. 99510 3130'FNL, 486'FEL, Sec 25, T5N, Ri~--~ At Top Produci,g I,,erva, (Straight Hole) ~t Total 5. Elevation in feet (indicate KB, DF. etc.) RKB 255' above mud line 12. Date Spudded 8/31/90 17. Total Depth (MD+TVD) 7206' 7. Permit Number 90-80 8. APl Number 50- 733-20418 9. Unit or Lease Name N/A. 10. Well Number Sturgeon # 1 11. Field and Pool Wi ldc at 6, Lease Designation and Sera No. ADL 359110 9/29/90 10/22/90 139' MLLW feet MSL I 1 18.Plug Back Depth (MD+TVD)/19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost mud line, 255' R~YES ~ NO [] N/A feet MD 0' 22. Type Electric or Other Logs Run DIL/SP/GR/Caliper/LDT/CNL/BHCS/RFT/Sidewall Cores/Checkshot Velocity Surv. 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 30" 13 3/8". 9 5/8 WT. PER FT. 457 91.6 68 47 GRADE X-52 SETTING DEPTH MD TOP 42' 42' BOTTOM 401' 1270' HOLE SIZE Driven 26" CEMENTING RECORD Driven Cmtd to surf w/184 AMOUNT PULLED 231' SX 243' L-80 42' 2684' 17½" Cmtd to surf w/205 sx 247' L-80 34' 6717' 12¼" Cmtd to 3580'w/140 sx 566' 3ottom and 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET IMD) N/A 24. Perforations open to Proctuction {MD+TVD of Top and interval, size and number) 5232'-5260' 5312'-5335' 5352'-5392' 5688'-5724' 5735'-5822' 5826'-5838' 5872'-5882' Ail perfs squeezed w/cement 26. ACID, FRACTURE, CEMENTSQUEEZEoETC. DEPTHINTERVAL(MDd AMOUNT& KIND OF MATERIALUSED All perforations squeezed w/total of listed24 in Sec,(.../137/ -- sx class G cememt 27. PRODUCTION TEST Date First Production 10-11-90 Date of Test /Hours Tested 10/10-14/~0 24hrs, 0Mil Flow Tubing lCasing Pressure Press. 35psSg 1500 psig 28. i Method of Operation (Flowing, gas lift, etc.) Flowinq PRODUCTION FOR[OIL-BBL~ GASoMCF .TEST PERIOD I~ 0 0 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE II~ 0 0 WATER-BBL ICHOKE SIZE I GAS-OILRATIO 443 I 12-36/64"1 N/A WATER-BBL /OIL GRAVITY-APl (corr) 875 (ma~) ~/A CORE DATA Brief description of lithology, porosity, fractures, apparent dips a~d presence of oil. gas or wat.e r. Submit core chips. Core 1 (7176 to 7203.1) cut 27. ~t, recovere~ 27.1 ft. Siltstone/ sandy siltstone. Dark gray to greenish gray, fractured, with traces of carbonize plant debris, occasional thin calcite-lined fractures. No shows.~~ RECE Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ,9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Tyonek Spud Spud Hemlock 5228 5228 West Fore land 5950 5 950 Jura s s i c 6894 6894 SEE ATTACHED WELL TESTING SUMMARY 31. LIST OF ATTACHMENTS , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge i INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt' water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state;in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 CORE ANALYSIS REPORT FOR ARCO AK INC STURGEON ~1 WILDCAT November lggo FILE 70083 Oate ~ RECEIVED dAN 8 1991 Oil & Gas Oons. Commission Anchorage 4450 WEST 50TH AVENUE ANCHORAGE, ALASKA 99502 Company: Arco AK, Inc Well: Sturgeon #1 Field: Wildcat Date: 5 Dec 90 File # 70083 · · SIDEWALL CORE ANALYSIS Trim sample to right cylinder. Package with pre-weighed aluminum, teflon tape, and fit with 200 mesh stainless steel end screens. 3. Seat package to sample in a Hassler-type sleeve using 275 psi as confining stress. 4. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volumes. 5. Vacuum dry at 150'F until stable and weigh to 0.01g. 6. Cool sample in dessicator to room temperature and measure sand grain volume using a Boyle's Law helium porosimeter. Calculate sand grain density. 7. Mount sample in Hassler-Type sleeve using a confining stress of 275 psi. 8. Measure pore volume using a Boyle's Law helium porosimeter, determine porosity and fluid saturations. 9. Measure permeability with nitrogen gas using a calibrated flow tube- type permeameter. COMPANY : ARCO AK INC CORE TYPE: 4 INCH HUD TYPE : HATER BASE FORHATION: PETROLEUM TESTZNG SERVZCE, HELL : STURGEON FTELD : HTLDCAT COUNTY: COOK ZNLET STATE : AK S ] DEHAL L CORE ANALYS Z S ZNC. RESULTS PAGE : I . FILE NO.: 70083 DATE : NOVEMBER 16, lggO I I I I I I I I I I I I I SAMPLEI DEPTH IPERMEABILITYI ~UMBER I ft I mci I . .I ... I I I I I SATURATION I I I GRAf. I ~.c.Es I POROSlTY I O/V I OIL I~ATER TOTAL I DENSlTYIRECOVERED RATIO I (PERCENT PO~E VOLLME)I g/cc I I COMMENTS L I THOLOGICAL DESCRIPTION Sl 4585.00 27.0 0.0 0.0 92.6 92.6 2.67 0.20 Sst, gry, lsd-md, mod cmt, n odr, n stn, n fLuc S2 4775.00 448 26.4 0.0 0.0 97.3 97.3 2.65 0.80 Set, gry, fsd-md, mod c mt, fl odr, n stn, n fitK S3 4885.00 433 S4 4905.00 385 27.9 0.0 0.0 97.7 97.7 2.65 0.85 26.2 0.0 0.0 96.2 96.2 2.67 1.0~ Sst, gry, fed-md, mod cm, n odr, n Itn, n ftuc Sst, gry, md, mod cmt, n odr, n stn, n fluor S5 5145.00 6~ 22.4 0.0 0.0 98.7 98.7 2.64 0.90 Sst, gry, fsd-md, ~[ cmt, n odr, n 8tn, n fluor S6 5240.00 40 ST# 5245.00 22.0 0.0 0.0 96.6 96.6 2.62 0.69 0.00 #Fatted Sst, gry, fsd, arty, vt cmt, nc)dr, n 8tn, n ftuor S8 5320.00 24 19.3 0.0 0.0 92.1 92.1 2.62 1.03 Sst, gry, fsd-msd, ~[ cat, n odr, n stn, n ftuor S9 5330.00 137 23.6 0.0 0.0 92.9 92.9 2.64 0.39 Sst, gry, fsd-md, t~t cmt, n odr, notn, n ftuor SlO# 5334.00 0.00 #Insufficient Sll 5355.00 432 S12 5360.00 155 22.0 22.5 0.0 0.0 0.0 0.0 2.61 2.62 Sst, gry, crssd-vcrssd, pt)ts, vt ant, n odr, n stn, n fluor Sst, gry, md-crssd, st 8tty, vt cmt, n odr, n 8tn, n fluor CONPAHY : ARCO AK ZNC CORE TYPE: 4 INCH HUD TYPE : HATER BASE FORHATTON: PETROLEUH TESTTNG SERVTCE, NELL : STURGEON ~1 F:IELD : WILDCAT COUNTY: COOK :INLET STATE : AK S ] DEWALL CORE ANALYS T S INC. RESULTS PAGE : 2 FILE NO.: 70083 DATE : NOVEHBER 15, 1990' ! I I I I I I I I I I I i SAMPLE IDEPTH IPERMEABILITYI I NUMBERI ft I md I ' I I I I I I I I SATU~T:ON I I I '1 ~P~I~ I I~CKS I PQeOSITYI O/V I OIL ~MTER TOTAL I DENSlTYIRECOVERED % I RATIO I (PERCENT PORE VOLUME)I O/cc I I I COI4HENT$ LITHOLOGICAL DESCRIPTION S13 5365.00 110 23.6 0.0 0.0 97.? 97.7 2.63 1.06 S14 5375.00 291 25.0 0.0 0.0 97.1 97.1 2.65 0.87 S15 5385.00 199 25.4 0.0 2.5 92.3 94.8 2.65 0.?0 S16 5425.00 16 19.3 0.0 0.0 9?.397.3 2.6/, 1.30 Sl? 5427.00 109, 22.7 0.0 0.0 99.5 99.5 2.69 0.82 *Fractured S18# 5430.00 0.00 #Insufficient S19 5435.00 81' 22.3 0.0 0.0 96.4 96.4 2.62 1.10 *Fractured Ka S20# 5438.00 0.00 #Insufficient S21 5450.00 10 21.1 0.0 0.0 97.6 97.6 2.61 1.50 S22 5453.00 8.3 21.0 0.0 0.0 96.6 96.6 2,60 '0.93 Sat, gl'y, md, arty, #[ Cmt, fl o dr, natn, n ftuor Sat, gry, fad-md, wL cmt, nodr, natn, n fluor Sat, gry, fad-md, wt cmt, n ed?, ev Lt atn, yL fluor Sst, gry, fad, arty, wi (:mt, n ed?, fl atn, n fluor Sst, gry, fsd, sity, w{ cmt, ne dr, n stn, n fluor Sst, gry, fsd, sity, wi cmt, nodr, natn, n fluor Sat, gry, md, ahly, wi ¢mt, n ed?, natn, fl fluor Sat, gry, md, ahly, w~ clK, n ed?, rt Itn, n fluor COHPANY : ARCO AK INC CORE TYPE: 4 TNCH HUD TYPE : 1dATER BASE. FORHATION: PETROLEUH TESTZNG SERVTCE, HELL : STURGEON FIELD : #ILDCAT COUNTY: COOK INLET STATE : AK S I DEl/ALL CORE ANALYS I S INC. RESULTS PAGE : 3 FILE NO.: 70083 DATE : NOVEHBER 1990 [ I I i I I I I I I I i I SAHPLE I DEPTH IPERMEABILITYI I .. I I I I ! IraAIH I I~c~Es I POROSlTY I O~ I OIL WATER TOTAL I DENSITY I RECOVEREDI RATIO I (PERCENT PORE VOL~HE)I g/cc I I I I I I COlldENTS I I I I I I I L tTHOLC)GICAL DESCRIPTICWI I I I S23 5494.00 192 21.8 0.0 0.0 99.5 99.5 2.59 0.87 5/,95.00 582 22.8 0.0 0.0 96.0 96.0 2.60 1.06 s25# 5495.00 0.00- , ~No S~mpte $26 5497.00 569 27.1 0.0 0.0 97.9 97.9 2.65 0.85 S27 5515.00 35 20.2 0.0 0.0 96.5 96.5 2.66 0.93 S28 5518.00 111 21.7 0.0 0.0 96.6 96.6 2.6,4, 1.04~ S29 5535.00 316 25.1 0.0 0.0 97.5 97.5 2.64 1.C~ S30 55/,0.00 20/, 23.0 0.0 0.0 95.5 95.5 2.64 1.09 S31 5545.00 67 21.1 0.0 0.0 99.6 99.6 2.64 1.08 S32 5548.00 706 23.7 0.0 0.0 9~.2 9/0.2 2.65 0.85 , Sst, gry, fsd-msd, shty, mod cst, cart), n odr, n' stn, n fluor Sot, gry. md-crssd. Iht¥, ~xl cst, cerb, fl odr. fl otfl, fl fluor Sst. gry, md, ut cmt, n odr, n mtn, n ftuor Sot, gry, fsd, ut cmt, n odr, n mtn, n fluor Sst, gry, fsd. wt cmt, n odr, n sin, n fluor Sst, it tn, fsd-msd, mod cmt, n Ddt, n stn, n ftuor sst, tt tn, fsd-msd, mod c~t, n cdr, n stn, n fluor Sst, tt tn, fsd-msd, ehty, vt cat, n odr, n sin, n fluor Sst, it tn, msd-crssd, shiy, mod cmt, n odr, n 8tn, n fluor COtlPANY : ARCO AK INC CORE TYPE: 4 INCH HUD TYPE : gATER BASE FORHATION: PETROLEUH TESTXNG SERV!CE, NELL : STURGEON #1 FZELD : #ILDCAT COUNTY: COOK INLET STATE : AK S I DENALL CORE ANALYS I S INC. RESULTS PAGE : 4 FILE NO.: 70083 DATE : NOVEHBER 16, 1990 I ! I I I SAMPLE I DEPTH IPERHEABILITYi ' qU~BERI ft I ,,d I I I I I I I I I SATURATION I I I I GRAIN I iNCHES I PmOStTYI O/V I OIL gATER TOTAL. I DENSITYIRECOVEREDI % I RATIO I (PERCENT PORE VOLW4E)I g/cc I I I CCX44ENTS I I I LITHOLOGXCAL DESCRIPTION I I I I I S33 5703.00 13.9 0.0 0.0 98.8 98.8 2.65 1.57 S34 5703.10 4.3 0.0 0.0 95.6 95.6 2.66 1.30 S35# 5714.00 0.00 q ~o Sempte $3~ 5?40.00 0.00 #Insufficient S37 5750.00 33 21.7 0.0 0.0 99.2 99.2 2.68 1.30 S38 5?60.00 260 23.0 0.0 0.0 99.6 99.6 2.65 1.4o S39 5?70.00 73 21.8 0.0 0.0 99.6 99.6 2.67 1.50 S40 5?75.00 22 19.? 0.0 0.0 99.6 99.6 2.68 1.60 S41 5797.00 587 22.6 0.0 0.0 100 100.0 2.64 1.40 S42 5800.00 <0.1 1.8 0.0 0.0 85.0 85.0 2.69 1.50 Pbty sst, gry, msd-pbt, ut cmt, n odr, n stn, n ftuor Sst, gl'y, fsd, v tel cmt, v CetC, n oclr, n stn, n fluor Sst, gry, fsd, shty, ~t cmt, n odr, n itn, n ftuor Sst, gry, fsd-msd, mod awl:, n odr, n stn, n ftuor Sst, gry, fsd-md, st ohty, fit ant, fnt odr, n stn, n ftuor Sst, gry, fsd-msd, st shty, vt cmt, fnt odr, n stn, n ftuor Sst, gry, fsd-mcI, mod mt, n odr, n 8tn, n fluor Sst, gry~ cr$scI, v #[ Cllt~ V ClflC~ n odr, n itn, n fluor COMPANY : ARCO AK INC CORE TYPE: 4 INCH MUD TYPE : I~ATER BASE FORMATION: PETROLEUM TESTING SERVICE, THC. #ELL : STURGEON FIELD : I~ILDCAT COUNTY: COOK TNLET STATE : AK S z D EI~ALL CORE ANALYS T S RESULTS PAGE : 5 ~ FILE NO.: 70083 DATE : NOVEMBER 16, 1990 I ' I I I I I I I I I I I I saturation I I I I I I I I ...... I ~i. I INCNES I SAHPLE I DEPTH IPERMEABILITYI POROSitY I O~ I OIL .ATER TOTAL I DENSITY I RECOVEREDI NUMBER I ft I md I X I RATIO I (PERCENT P~E VOLUME)I g/cc I I I I I I I I COIIqENTS LITHOLOGICAL DESCRIPTION Sa3# 5803.00 0.00 S44 5803.10 1.4 0.0 S45 5815.00 881 2~.6 0.0 S46 5872.00 67 20.8 0.0 0.0 100 100.0 2.80 0.60 0.0 98.7 98.7 2.69 1.00 0.0 98.8 98.8 2.6? 1.,~% mlo seepte S~t, gry, fed, v Ht cmt, n o dr, notn, n ftuor Sot, it tn, md, mod cmt, n odr, n 8tn, n ftuor Sot, gry, fed, ut cmt:, n o dr, n 8tn, n fluor ARCO 011 and Gas Company Well HIItory - Initial Report - Dally laell~otloel: Prlplr~ I~d Iobmit the "lalflM Re~ort" o~ the flrlt WudnIIdly Iftaf a Dilly work p~r ~ IP~ddlng IttOuld bi 14Jmmldzld O~ h Iorm elvl~O In¢lul~vt ~ Only. OI-trlot I¢oumy. p4d~ of Alaska i Kenai Borouoh Fitld ILLIN O~ Unit Redoubt Bay_ IlTM Auth. or W.O. no. AFE: ^[:) 6951 J Wildcat lat~ta ski Stur0oon #1 Operator Glomar Adriatic VIII ARCO Alaska, Ina Spudded or W.O. begun IDlll IHour ~ 8/31/90 I 0600 Hrs. Date and depth Complete record for each day reported ee of 8:00 a.m, 8/31/90 1 glc/wjp 9/1/90 2 glc/wjp 9/2/90 3 glc/wjp 9/3/90 4 glc/wjp 9/4/90 5 glc/wjp 300', (20'), Drlg Wt. 8.4, PV 12, YP 33, WL 48, PH 8.5, Sol 3 ADC: $977,171 NU & tst diverter system. Spud well ~ 0600 hrs. 8/31/90. hole to 300'. IARCO W I Prior atalul if I W.O. Drl 17-1/2" 930', (630'), Drlg 17-1/2" hole Wt. 9.4, PV 8, YP 38, WL 46, PH 8.5, Sol 6 ADC: $1,462,171 Drl to 345', CBU, POOH & chg bits to 26'. Wsh & rm to 325', drl to 406', circ hole cln, POOH. PU new bit, TIH, wsh & rm to 406'; pressure increase fr/1000 psi to 2700 psi. Attempt to surge bit, POOH & ck jets; no obstructions. RIH to 406', drl to 658', reaming several coal beds. CBU, short trip to 30" csg shoe. Drl to 930'. 399', 0° - SS 658', 0° 1279', (349'), Opening hole to 26" @ 703' Wt. 9.3, PV 6, YP 38, WL 46, PH 8, Sol 6, ADC: $1,566,295 Drl to 986' (coal fr/ 960'-980'). Short trip to 401', TIH to 986', circ while repairing prop. Drl 17-1/2' hole to 1279', CBU twice. MU 26" hole opener, RIH & open 17-1/2' hole to 26" from 401' to 703'. 986', 1/2° 1272', 1 ° 1279', (0'), Opening hole to 26" @ 1263' Wt. 9.3+, PV 5, YP 35, WL 46, PH 8.5, Sol 6 ADC: $1,624,728 Rm & wrk thru coal fr/ 658'-703', circ hole cln. Open hole fr/ 703' - 858', CBU, short trip to 30" shoe. Function tst diverter @ 30' shoe; OK. RIH, open hole to 1263'. 1279', (0'), Prep to cmt 20' Wt. 9.3+, PV 6, YP 35, WL 48, PH 8.5, Sol 6 ADC: $1,692,588 Fin opening hole to 26' fr/ 1263' - 1279', C&C, POH. Short trip to 30' shoe. RIH, wsh & rm fr/1140' - 1279', C&C, POOH. RU & rn 30 jts 20' to 1270'. RIH w/cmt stinger on 5' DP, stabbed FC @ 1203', C&C mud & prep to cmt. (20', 91.6#, X-56, S-60 csg w/btm of shoe @ 1270', top of FC @ 1203', landing ring @ 296') For fo~'~reparatlon and dlalrlbutl~ ~ P~eduml Manual, ~1~ 10, Drilling, Pagel ~ ~d 87. I Duta 11/13/90 i T~t~, New Ventures Drilling Superintendent AR3B-459-1-D INumberIII dally will hlltory forml conleCutlvlly Page no~. they am preputial for IlCh wall. J ARCO 011 and Gas Company Dally Well History--Interim Mltnieflonl: This Iorm Is used during drtllln0. O.r wo.rk.o,w*r o. po.r. otlons. I.f..te~.tln0,.corln~l,~Or_pod, or.lting~, Ih.ow Io...nn~iofl no~o. ~ in ,de._ic,_flb. ln~ work. Number fill drill stem tests 0oquentillly. AIIiCh aotcr~,p, Tlofl ,ct all corel, wom0.P~_rtor_m~.a, oy /'rooKing :5~CliOfl Will N re~ortea 0fl iltlrl~l ~ts until Wmll completion. Repofl offlclnl or reprelentetlve t.est off FMI.! fo .r~.. 1.) Subm. it kltorbl.. ?~.ts Mun flllo, d ..out..b?t M)(...MI4 ~..u~.nlly than ow*fy 3q) dlyl, or (~) On Wednesday o! the week Iff which oil Itring il Mt. Submit WeeKly mr weft(ow*ri MW lOJlOWlhO settlno Of MI ltrlhO I~nuI C~/BIMIIIOn. Olstrict Field Alaska I County or Plrish IStste Kenai Borough J Alaska Lease or Unit Sturgeon #1 Iwell no Redoubt Bay Wildcat Date end doptfl as of 8:00 a.m. 9/5/90 6 tbc/wjp 9/6/90 7 tbc/tj/ten 9/7/90 8 Ibc/t j/ten 9/8/90 9 tbc/tj/ten 9/9/90 10 tbc/tj/terT 9/10/90 11 tbc/tj/terr leo Procedures Manuel Section 10, Drilling, Pages ~6 and 87 Complete record for each day while drilling or workover in progress 1279', (0'), Welding on 20" Bradenhead Wt. 9.4, PV 6, YP 14, WL 47, PH 8.5, Sol 6 ADC: $1,771,515 Prop 50 bbls frsh wtr spacer, followed by 1340 sx 12.8 ppg lead slurry containing 2.5% pre-hydrated gel, 0.25% CFR-3 & 3% CaCI2, followed by 500 sx, 15.8 ppg tail slurry containing 3% CaCl2. ClP ~ 09:15 hrs. 9/4/90. POH w/stab-in sub. Rn 2 strings 1-1/4' wsh pipe between 20' & 30' csg to 290' RKB, wsh cra! Ir/20" x 30" csg annulus and diverter using sea wtr. ND diverter while wac. Make final cut on 20" & weld on 20' FMC Bradenhead. 1384', (105'), Drlg 17-1/2" hole Wt. 8.8, PV 6, YP 28, WL 44, PH 11, Sol 3 ADC: $2,046,121 Tst welds to 350 p§i; OK.. NU 30' diverter & tst; OK. (Tst witnessed by AOGCC rep.) MU BHA w/MWD ti, RIH, DO FC @ 1203', cmt & FS @ 1270'. Wsh dn to 1279'. Drl 17-1/2' hole to 1289', C&C mud. Conduct formation tst @ 1289' to 10.2 ppg EMW. Drl to 1322'; drlg break, CBU. Cant drlg to 1384'. 1819', (435'), RIH w/bit #4 Wt. 8.9+, PV 6, YP 23, WL 48, PH 9.5, Sol 4 ADC: $2,123,745 Drl & surv 17-1/2" hole to 1498'; drl break 1488'-1498', CBU. Drl to 1571', CBU, drop surv. Short trip to 20' shoe; hole good. RIH, drl & surv to 1819', CBU, POOH f/new bit. 1463', .75° 1764', .50° 2285', (497'), RIH w/bit #5 Wt. 9.1+, PV 8, YP 14, WL 30, PH 8.9, Sol 5 ADC: $2,303,371 RIH to 1819', drl & surv 17-1/2" hole to 2285', CBU, POOH. Chg bit & RIH. 1905', .3° 2216', .6° (Divers found scour occurring under the inboard side of spud can. Prep to sandbag scoured areas.) 2585', (300'), Drl 17-1/2' hole to 2585' Wt. 9.1+, PV 10, YP 22, WL 30, PH 8.4, Sol 6 ADC: $2,423,080 Drl & surv to 2585'. 2492', .90o 2695', (110'), Cond hole f/csg Wt. 9.1, PV 18, YP 12, WL 12.8, PH 8.4, Sol 6 ADC: $2,530,334 Drl & surv to 2695', C&C, POOH. RU Schl, rn DIL/BHC/Sonic/GR to 2686' WLM. Rn CNL/LDT/GR/CAL/Temp fr/surf to TD. Rn CNL/LDT/GR/CAL fr/ 258~'-~2~C'. POH, RD $chL R~H f/';,'~pcr 11/13/90 New Ventures Drilling Superintendent AR3B-459-2-B INumber Ill daily well history fermi conseculiw*ly IPsge no. al they are prepared for each well. 2 ARCO Oil and Gas Company Dally Well History--Interim IIIIIIIICI~IlI: Thll form il lind during drilling or worl(o~r N)lrltlonl. If tilting, coring, er perforetlng. I~ow fom~etlon nll~ in delcribl_r~ ~o~ PeHmmed. Number ell drill stem tilts tequentl&lly. Altech ~elcrlptl~ of iii corel. Wo~k performed bit P~od~cin~ ~l<:llon will be mpo~e4 ~ "leletlll Ilteets until completion. Report officlll or reprlllnlltlvI flit o~ _"F. II~..' form. 1.) ~Jbm. tt "ll~tlrlI' Iheetl srhlh Ililed o~l but hal Illl fre~nlly lhln iv~ 30 dlyl, or 0~1 Wtdnlldly of the Wtlk in which oll itrlng il I1~1. Suomll wHkl¥ lor-worl(ovlre I~d following letting of ell Itrlng until completl~l. District ICounty or Perish JStste Alaska IKenai Borough ~aska Field ILeese or Unit Redoubt Bay Wildcat I Sturgeon #1 Date ,,nd depln ss of 8:00 a.m. 9/1 1/90 12 tbc/tj/te 9/12/90 13 tbc/tj/ten 9/13/90 14 tbc/tj/ten 9/14/90 15 glc/dl/ten 9/15/90 16 glc/dl/ter~ 9/16/90 17 glc/dl/ter~ Complete record for each day while drilling or workover in progress 2604' PBTD, Flushing 13-3/8" x 20" ann w/sea wtr Wt. 9.1, PV 16, YP 15, WL 13.2, PH 8.3, Sol 6 ADC: $2,733,969 RIH lo 2695', CBU, C&C mud [/cs{], POH. RU to rn csg. PU mudline hgr jr, MU FS to shoe jr. Attempt to MU jt #2; would not MU. LD jt ~t2. Chg out collar. Rn 69 jts, 13-3/8', 68#, L-80 BTC R-3 csg (2684'). Cmt w/1556 sx 12.8 ppg lead slurry w/0.15% CFR-3, 2.5% PHB, 0.15% LWL, followed w/ 500 sx, 15.8 ppg tail slurry w/0.2% CFR-3 & 0.05% LWL. ClP ,'~ 0345 hrs w/good rtns. Unsting, POH, LD cmt stinger. Rn 2 x 1- 1/4' wsh strings to landing ring @ 295'. Flush 20" x 13-3/8" annulus. 2604' PB'I:D, NU choke & kill lines Wt. 8.6, PV 5, YP 10, WL 7.8, PH 9.0, Scl 2 ADC: $2,836,027 Fin flushing annulus. Spot 50 bbl concentrated retarder pill on btm, POH, LD wsh strings. ND diverter, set slips, make rough cut. ND & rack back 30' diverter. Make final cut. NU 13-5/8', 10M BOP stack. 2604' PBTD, Rn'g gyro Wt. 8.6, PV 14, YP 7, WL 8.0, PH 9.2, Scl 2 ADC: $2,967,431 Fin NU BOPE & tst to 250/5000 psi. (Tst witnessed by Doug Amos, AOGCC.) RU Schl & rn gyro per program. 2952', (257'), Drlg ahead Wt. 8.5, PV 14, YP 10, WL 8.8, PH 10.5, Sol 2 ADC: $3,073,700 Complete gyro rn to 2502', RD Schl WL. TIH, tag cmt @ 2601', C&C. Tst 13-3/8' cog to 1500 psi; OK. DO cmt, FC @ 2603', FS @ 2684' + 10' new formation to 2705'. C&C mud. Perform LOT to 12.7 ppg EMW. Displ hole w/8.6 ppg Polymer mud. Drl & surv fr/ 2705%2952'. 2786', 1.1 o 3429', (477'), Drlg ahead Wt. 8.7, PV 29, YP 15, WL 6.6, PH 9.0, SCl 3 ADC: $3,190,695 Drl & surv to 3429'. 2910', 1.2° 3221', .9° 3930', (501'), Drlg ahead Wt. 9.1, PV 19, YP 12, WL 6.0, PH 10.0, Sol 4 ADC: $3,284,284 Drl & surv to 3930'. 3439', 1.0° 3780', 1.0° Well no. Fei' form pre~i~'~ and distribution tee Procedures Manuel Section 10, Ddlllng, Pagee ~ ~d 87 IDate ITM 11/13/90 New Ventures Drilling Superintendent AR3B-459-2-B INumber sll dilly well hilton/ fermi they ire prepared for each well. contecutlv~ly IPage no. 3 ARCO Oil and Gas Company Dally Well History--Interim Inltn~llol~l: Thll form II uled during drtlll~g or .workover oplrltlonl. If letting, Coring, or IleHorltlng. IhOW form&tlo~ name In delcrlbln~ work plrformt~l. Number Ill drill Item tlltl Ilquentielly. Altech dol~rtptton of III corel. Work performed by I)~)~4:tng ~4~lioa will be rl~)octed Oe "ll~llrlll Ihe~tl Until tk~ll completion. Report official or reprllentltlvl Oil! Of 1 "Fklll" form. 1) 8ubmlt "lalerhl" Iheet~ when lllled eot bul m)( ~ ff~tnantl¥ thin every 34) diVe, er (~) Orl We(~llldly O! thl wllk in WhiCh oil erring II Ill. ~Jbmlt w~kly for workovlrl and followi~ Itlth~ O~ ~ll Ilriog ~.mtil c4)~lll~ltlo~. Diltrict Field Date and depth as of 6:00 a.m. Alaska Redoubt Bay Wildcat 9/1 7/90 18 glc/dl/ten' County Or Pertlh J-~tste Kenal Borough JAlaska Lease or Unit !Complete record for each day while drilling of workover in progrell Sturgeon #1 4264', (334'), RIH w/bit #8 Wt. 9.1, PV 15, YP 10, WL 6.2, PH 9.5, Sol 4 ADC: $3,624,894 Drl & surv to 4264', POOH Ik'g f/wsh out in bit. Chg bit, RIH. 9/18/90 19 glc/dl/terr 9/19/90 20 glc/dl/ten 9/20/90 21 glc/dl/wj 9/21/90 22 tbc/tj/wj 3872', 1.4° 4122', 1.7° 4804', (540'), Drlg ahead Wt. 9.1, PV 17, YP 15, WL 6.0, PH 10, Sol 5 ADC: $3,755,802 Fin TIH, drl & surv 12-1/4' hole to 4804'. 4368', 1.8° 4617', 2.1° 51(~9', (365'), CBU f/bit 'trip Wt. 9.3, PV 18, YP 14, WL 6.4, PH 10, Sol 6 ADC: $3,869,165 Drl & surv to 4909', CBU, short trip to 2684'. RIH, rm fr/ 4819%4909'. Drl & surv to 5169' w/drlg breaks @ 4972' & 5147" (no gas). CBU. 5051', 2.09o 5254', (85'), CBU f/samples Wt. 9.3, PV 18, YP 19, WL 6.0, PH 9.8, Sol 6 ADC: $3,869,165 Fin CBU, chg bits, RIH. POH & PU new MWD ti. RIH, rm 90' to btm; no fill. Drl to 5254' w/drlg break fr/ 5246'-5254'. CBU f/samples. 5113', 2.06° 5640', (386'), Drilling Wt. 9.3, PV 17, YP 14, WL 5.4, PH 9.2, Sol 6 ADC: $3,975,492 Complete CBU; trace of show & no gas. Dri 12-1/4' hole to 5265', CBU f/samples; no trace of show & no gas. Drl & surv 5324; drlg break. CBU f/samples; no show & no gas. Drl to 5337" (still in drlg break). CBU f/samples; no show & no gas. Drl & surv to 5364'; flow ck after 8' of drlg break; no mud gain/loss. Drl to 5367", still in drlg break, CBU f/samples; no show & no gas. Dri to 5528'; had 10' drlg break fr/5518'-5528'. CBU f/samples; no show & no gas. Drl & surv to 5549'; had 10' drlg break fr/ 5539'-5549'. CBU f/samples; no show & no gas. Drl & surv to 5632', w/ 10' drlg break fr/5622'-5632'. CBU f/samples; no show & no gas. Drl & surv to 5640'. 5238', 2.09° 5394', 2.10° 5518', 2.11° Well no. Th(~'~t~l~cor rect SI ature . ~ ~ For form prepara~111~end d~stribution ~ see Procedures Manual Section 10, ~ Ddlling, Pages 86 and 87 Dote 11/13/90 New Ventures Drilling Superintendent AR3B-459-2-B INumb~r III dally well hiltory fo~'ml consecutively IPagl I~,. al Ihey are prepared fo~ each well. 4 ARCO Oil and Gas Company Dally Well History--Interim Iltltltlollo#l: Thil IOn Il ulld during drilling or workover OlXrltlOnl. I! telttng, coring, or plltoretlng, Ihow formation nlme in describing work pollo/wind. Number Iii drill item teats sequentially. Altech dllCriplion of III corel. Wo~ I~rfermed by Producing Section will be repotted en '°ln#Hm" Inlets until hn&l completion. Repofl official or reprolentative tilt on "FII~II' form. 1) ~bmlt "IalIHII" IhHtl wttln I~lled out bul Mt Sill freguenlly then every 3~ dlyl, or (2) ~n Wldneldly of the week in which oil airing 11 let, Submll weekly for wotkov~rl and following letting of o~1 Ilring until completion. District lCounty or Parish Alaska I Kenai Borough Field ILe,e or Unit ! Redoubt Bay Wildcat Date end depth Complete record for each day while drilling or workover in progress ae of 8:00 a.m. lStltl Alaska Sturgeon #1 IWsll no. 9/22/90 23 tbc/tj/wj 9/23/90 24 tbc/tj/wjl 9/24/90 25 tbc/tj/wj 9/25/90 26 tbc/tj/wj 9/26/90 27 tbc/tj/wj 5978', (338'), Drlg 12-1/4" hole Wt, 9.3, PV 16, YP 15, WL 6.2, PH 9.1, Sol 7 ADC: $4,050,480 Drl & sun/to 5683'. CBU f/samples; no show & no gas. Drl to 5705' w/ 10' drl break. CBU f/samples; no show & no gas. (Formation consists of volcanic ash, clay & sandy shale.) Drl to 5766' w/drlg break fr/ 5754' - 5766'. CBU f/samples; no show & no gas. POH to shoe @2684' f/conditioning trip. RIH to 5704', wsh & rm to 5766'. Drl & surv to 5810' w/10' drlg break fr/5800'-5810'. CBU f/samples; no show & no gas. Drl & surv to 5932', CBU f/samples; no show. Drl to 5978'. 5611', 2.09° 5734', 2.13° 5860.5', 2.06° · 6148', (170'), Drlg 12-1/4' hole Wt. 9.3, PV 16, YP 15, WL 5.6, PH 8.6, Sol 7 ADC: $4,252,562 Drl & sun/ !ri 5978' - 6019', POH f/bit change. Tst BOP to 250/5000 psi & annular to 250/3500 psi. PU new bit, RIH to 5929', wsh & rm to 6019'. Drl & sun/ to 6148'. 5953.89', 2.08° 6048.66', 1.99° 6396', (248'), Drlg 12-1/4" hole Wt. 9.3, PV 17, YP 15, WL 5.9, PH 8.8, Sol 5 ADC: $4,343,638 Drl & sun/ fr/ 6323' - 6396'. 6141.69', 2.14° 6296.23', 2.43° 6572', (176'), Drlg 12-1/4" hole Wt. 9.3, PV 15, YP 14, WL 5.8, PH 8.8, Sol 5.5 ADC: $4,423,997 Drl fr/6396' - 6404', POH f/bit change. PU new bit, RIH to 6330', wsh & rm to 6404'. Drl & surv fr/ 6404' - 6552' w/20' drlg break fr/ 6532'- 6552'. CBU f/samples; no show & no gas. Drl fr/6552' - 6572'. 6484.76', 2.66° 6794', (222'), CBU @ 6794' Wt. 9.3, PV 18, YP 17, WL 5.8, PH 8.9, Sol 6 ADC: $4,520,942 Drl 12-1/4" hole fr/ 6572'-6601', CBU. POH to 5684'; hole condition good. RIH, drl & surv fr/ 6601'-6618' w/ 10' drlg break. CBU f/samples; no show & no gas. Drl fr/6618' - 6670' w/ 10' drlg break. CBU f/samples; no show & no gas. Drl & sun/ fr/ 6670' - 6758', 10 std short trip. Drl & surv fr/ 6758' - 6794'. 6704.69', 2.91 o The abo~rmct ~ 8es Procedures Manual Section 10, / Drilling, Pagan 86 and 87 AR3B-459-2-B IDete 11/13/90 l;i,la New Ventures Drilling Superintendent INumber all dally well hlltor/ forml consecutively Ipage no. they ere preplred for each well. 5 ARCO Oil and Gas Company Dally Well History--Interim Inetm~lioal: Thll form le uled during drllltno or' workover Ol)erlllo~l. If ~1~, coring, ore,orating, ~ lo~all~ ~m In ~rtbln~ wo~ ~O~d. Nu~r ~11 drill ~tem te~t~ ~quenllally. AH~ch ~rlption of all ~t. Wo~ ~rfo~d by Prooucl~ ~l~ will ~ ~d ~ "ln~ ~t~ unlll final co~eUon. RI~ offictll or mp~ntlll~ tilt ~ "F~" fo~. t) 8u~lt .~,, ~tl w~n filled ~ ~ ~ IIM f~ntly ~ln I~ ~ dl~, or [2) ~ W~ly OI the week In ~lch oil itrl~ Il ~t. Submit ~kly ~r wo~ ~d following Mttl~ of ~1 Itd~ unlll ~mMeli~. District Field Date end depth es of 8:00 a.m. Alaska Redoubt Bay Wildcat 9/27/90 28 tbc/tj/wj: 9/28/90 29 glc/fJ/wj 9/29/90 30 glc/fj/wjl 9/30/90 31 gl¢/fj 1 0/1/90 32 flc/fj 1 0/2/90 33 glc/fj/wjl County or Parilh I$111u Kenai Borough I Alaska Lease or Unit Sturgeon #1 Complete record for each day while drilling or workover in progres" 6995', (201'), Drlg 12-1/4' hole Wt. 9.3, PV 15, YP 12, WL 5.6, PH 8.6, Sol 6 ADC: $4,619,030 POH f/bit change. PU new bit & RIH to 6716'. Wsh & rm 6794'. Drl to 6817'; had 10' drl break. CBU f/sample; no show & no gas. Drl & surv fr/ 6817' - 6995'. 6766.57', 3.25° 6890.76', 3.39° 7160', (165'), Drlg 12-1/4' hole Wt. 9.9, PV 15, YP 11, WL 6, PH 8.3, Sol 9 ADC: $4,702,386 Cent drlg to 7039'; 10 std short trip. RIH, rm last 75' to btm. Raise MW to 9.5 ppg. Drl to 7101'. Circ hi-vis sweep to surf, make 20 std short trip. RIH, rm last 90' to btm. Drl fr/7101' - 7160'. Raise MW to 9.9 ppg. 6922.11', 3.63° 7046.72', 4.41° 7182', (22'), Coring @ 7182' Wt. 10.1, PV 18, YP 17, WL 5.8, PH 8.3, Sol 10 ADC: $4,783,106 Drl 12-1/4" hole to 7176', CBU, 15 std short trip. RIH, rm last 100' to btm. Raise MW 1o 10.1 ppg, C&C, POOH. MU 8-1/2" coring assy, RIH. Core fr/ 7176'-7182'. 7076.97', 4.52° 7206', (24°), POOH to rn logs Wt. 10.1, PV 15, YP 12, WL 5.6, PH 9.0, Sol 10 ADC: $4,948,963 Finish cutting Core #1 to7206', POOH; cut 30', rec°d 27-1/2'. RIH, rm 90' to btm. Pmp 50 bbls hi-vis pill, C&C mud, POOH. 7206', (0'), Logging Wt. 10.1, PV 16, YP 13, WL 5.5, PH 8.5, Sol 10 ADC: $5,114,820 RU Schl lubr. Rn DIL/BHC/GR/SP fr/ 7153°-2684'. Rn CNL/LDT/GR/AMS fr/7158' & log out. Rn FMS to 7156' & log out. RIH w/Velocity Survey ti. 7206', (0'), RIH w/Rotary Sidewall Core TI Wt. 10.0+, PV 17, YP 12, WL 5.6, PH 8.6, Sol 10 $5,235,909 Rn Velocity Survey ti to 7030'. RD Schl equip. Tst BOP to 250/5000 psi & annuluar to 250/3500 psi. RIH w/12-1/4' bit to 7105', wsh & rm to 7161', C&C mud, prop 180 bbls hi-vis slug. POOH. RU Schl lubr & RIH w/rotary SWC ti. IWell no. Tho Oute 11/13/90 ITIt'e New Ventures Drilling Superintendent AR3B-459-2-B INumber 111 dilly will hlltory fermi they are prepared for each well. coneecutlvely JPege no. 6 ARCO 011 and Gas Company Dally Well History--Interim Inltl'ucll~nl: Thll form Ii u#d during drilling or workover op~ratlonl. If telling, coring, or ~t~ti~ ~ fo~ltl~ nlml. In ~lc;lbln~ work ~rfo~ Numar Ill drill Item tlltl Mquentillly. Att~ ~KriFi~ of ill CO~l. Work ~rfo~ by P~l~ ~tlon will ~ M~Io ~ "ln~rM telll until completion. Rl~ O,ictll Or ~prlHnlllt~ II~ ~ "FM" form. t) Submit "IIIIM" t~l Wn filled ~t buI Mt IiII fmq~nlly ~ln I~ ~ dlyl. or ~ Wldneldly of the w~k in which oil Itrl~ II Nt. ~mtt wHkly lot wo~o~ Md followi~ NHi~ of ~1 itrl~ unlll ~mpllll~. Date and depth as of 8:00 a.m. Diltrtct ICouflty or Parilh I StltO Alaska I Kenai Borough ] Alaska Field JLeale or Unll I Redoubt Bay Wildcat Complete record for each day while drilling or workover in progress, I 0/3/90 34 g Ic/fj/wjl 10/4/90 35 tem/fj 10/5/90 36 tbc/tj/ter 10/6/90 37 tbc/tj/te 1 0/7/90 38 tbc/tj/ter Sturgeon #1 7206', (0'), RIH w/12-1/4" bit Wt. 10.1, PV 19, YP 11, WL 4.8, PH 8.5, Sol 10 ADC: $5,304,764 Rn MSCT rotary SWC ti. Attempted 14 cores fr/5876'-5518'; ti jammed, POOH -- rec'd 4 cores. Rn ti again; attempted 35 cores fr/ 5872'-5315'; ti jammed, POOH -- rec'd 26 cores. Rn ti again; attempted 12 cores fr/ 5447'-5245'; ti jammed, POOH -- rec'd 8 cores. Rn ti again; attempted 7 cores fr/ 5320'-4585', POOH -- rec'd 7 cores. RIH w/bit f/conditioning trip. (Total 68 attempts and 45 recoveries.) 7206'r (0'), RIH w/12-1/4' bit Wt. 10.1, PV 13, YP 12, WL 5.6, PH 8.5, Sol 10 ADC: $5,384,805 RIH w/bit to 7156', wsh & rm last 90', C&C mud, POOH. RU Schl lubr, RIH w/SP/GR lis to 4149' & log out. Rn RFT ti to 6468'; took 32 pressure points fr/ 6468'-3708'. Attempt to take fluid sample fr/ 5330', 5320' & 4885', POOH; rec'd 1700 cc dirty wtr w/no gas. RIH w/bit. 7206', (0'), RIH w/9-5/8" csg Wt. 10.1, PV 14, YP 12, WL 5.4, PH 9.0, Sol 10 ADC: $5,470,446 Finish RIH to 7150', C&C mud. Spot 150 bbls, 15.8 ppg mud on btm, POOH to rn cig. Chg top rams to 9-5/8". RIH w/profile wsh ti, cln mudline hgr profile @ 296'. Tst top ram bonnet seals; OK. RU & rn 9-5/8" csg. 7206', (0'), NU 13-5/8' BOPE Wt. 10.2, PV 18, YP 13, WL 5.8, PH 8.5, Sol 11 ADC: $5,866,280 Finish rn'g 156 jts, 9-5/8", 47#, L-80 BTC csg w/ FC @ 6627' & btm of FS @ 6717'. Cmt w/ 1400 sx, 15.8 ppg CI 'G' cmt w/0.2% CFR-3, 0.10% L/sx Halad 344, & 0.20% HR-7. Bumped plug w/3000 psi. CIP C~ 1656 hrs w/good rtns throughout. WOC. ND BOPE, set slips, make rough cut on csg. Set packoff. NU 13-5/8', 10K x 13-5/8', 10K spool. NU BOPE &tst packoff to 2500 psi; OK. 7206', (0'), Displ'g seawater Wt. 8.5 ppg sea wtr ADC: $$5,384,805 (AD6951 Drlg) $612,841 (AD 6960 Tstg) NU BOPE &tst to 250/5000 psi; OK. LD 12-1/4' BHA. MU 8-1/2" bit/scrpr, RIH, tag cmt @ 6612'. CO to FC @ 6619', CBU. Tst 9-5/8" csg to 3000 psi; OK. Displ hole to seawater. iWell no Drilling, Pages 86; and 87 i r , Dale 11/13/90 r. ille o New Ventures Drilling Superintendent AR3B-459-2-B I Number all daily well hiatoty torres conlecutlvely Is they Ire prepared for alch wall. IPageno. 7 ARCO Oil .;,..ad Gas COmpany Dally Well History--lnterirn InltmctJel~: Thll form I ulad during drilling or workover ope;&tlonl. If tilting coring, o; ~Ho;ating, ~w formitl~ name In ~dbln~ wo~ ~rfor~d. Numar I I dr Item tlltl ~quentlllty. Attlch ~Kfiptiofl of Ill corel. WOA ~rf0rmed by P~clflg ~h will ~ ~ded ~ "labf~ ~tl until f~ll C;~ltiofl. Rlpo~ offtclll or repm~ntlti~ tilt ~ "F~I" fo~. 1) Submit "~11~" ~tl ~fl filled NI ~t MI III f~q~fltly ~lfl I~ ~ dl~, Or (2) 0fl WldnlMly of the week Iff ~lch otl itri~ II .t. ~bmlt w~kly for wo~ ~d followl~ ~fli~ of ~1 Itrlflo until complltl~. Dlltrict ICounty or Perieh ISte,e Al~sk~ Kenai Borough I Alaska Field ILeese or Unit Redoubt E ~y Wildcat I Sturqeort #1 Date end depth Complete record for each day while drilling or workover ~n progress es of 8:00 a.m. 10/8/90 39 tbc/tj/ter 10/9/90 40 tbc/lj/tem 10/10/90 41 tbc/tj/tem 10/11/90 42 tbc/tj/wjp 10/12/90 43 glc/fj/wjp 10/13/90 44 glc/fj/wjp 10/14/90 45 glc/fj/wjp lWell no. 6619' PBTD, RIH w/3-1/2" tbg Wt. 8.5 ppg Seawater ADC: $728,278 (AD 6960 - Evaluation AFE) POH w/bit & scrpr. RU Schl, make gauge ring/JB rn to PBTD. RU lubr, rn CBT under 0 psi fr/6619'-5000'; poor cml indicated. Rn CBT under 1000 psi fr/ 6619'-2684'. RD Schl. TOC @ 3580'. RU & rn 102 its, 3-1/2", 12.95#, N-80 PH-6 R2 tbg. Tst tbg every 1000' while RIH to 3000 psi. 6619' PBTD, RU TCP guns 9.3 ppg filtered bdne ADC: $820,786 (AD 6960 Tstg) Attempt to tst tbg string after 117 its, 3-1/2' tbg picked up; could not get pressure build up. POOH 10 stds, Ik'g f/leak. POH &std back tbg; found TIW vlv partially open. RU Schl lubr. Rn CBT/CET under 1500 ps] fr/PBTD to 2600'. RD lubr. RIH w/189 its 3-1/2" tbg. Tst tbg to 3000 psi; OK. Chg over to 9.3 ppg filtered brine. RIH w/slickline & sinker bar, sheared drain sub. POH w/3-1/2" tbg. 6619' PBTD, Prep to tst surf equip 9.3 ppg filtered brine PU 7' cs{} guns loaded @ 12 spf & spaced per program. MU 9-5/8" tst pkr. MU DST #1 ti stdng. RIH on 3-1/2' lbg. RU Schl, m GR/CCL correlation log. Set tst pkr@ 5651'. RU surf ins. 6619' PBTD, Tst well 9.3 ppg filtered brine ADC: $970,855 (AD 6960 Tstg) Tst surf equipment. Pmp 1650 psi N2 cusion. Press ann to 2750 psi. Perf programmed intervals. Open well & flow to tst tanks. SI well f/PBU. 6619' PBTD, LD TCP guns 9.3 ppg filtered bdne ADC: $1,046,272 (AD 6960 Tstg) Finish well tst. 6619' PBTD, Tst BOPE 9.1 ppg filtered bdne ADC: $1,128,988 (AD 6960 Tstg) LD TCP guns. RU Schl, m & set EZSV cat retnr on WL @ 5658' (30' above top pad). Chg top rams to 5'. RIH w/crnt stinger, sting into retnr & tst to 1000 psi. Mx 116 sx cat w/.ZY, CFR-3, .2% HR-7 & .1T gal/sx Halad 344L. Cat sqz DST pads. POH. Displ hole w/filtered compl fluid. POOH, LD crnt stinger. Instl 3-1/2" pipe rams. Tst BOP to 250/5000 psi. Tst annular preventer to 3500 psi. 6619' PBTD, DST #2 9.1 ppg filtered brine ADC: $1,203,545 (AD 6960 Tstg) MU TCP guns & DST tls. RIH w/DST tls on 3-1/2" tbg. Set pkr @ 5189'. Pmp 1700 psi N2 cushion. Pressure annulus to 1500 psi. Perf per program. Open well & flow to tst tanks. AR3B-459-2-B IO,,e 11/13/90 ITalia Numar prepared for each well. they I~e daily well hllto~ forml conlecutively New Ventures. D.r~l~g~Superintendent IPage no. 8 ARCO Oil and Gas Company Dally Well History--Interim Inlll~cll~el: This form il uled during drllll~g Or workover oplrltlonl. If tilting, coring, ofJ~forlllng, IhO~ fO~ltl~ nlml tn ~Krlbln~ wo~ ~,o~d. Number III drill Item teltl ~uentlllly. Att~h ~t~tlon ,? III ~1. Wo~,~[fo~d.by ~ro~ucln~. ~11~ will ~ re~ed ~ "~n~rim" ~? until ~1 completion, h~ ofliclll or roprlMnllll~ tell on F~ ~. 1) Submit laIIM Klltl WMn milo ~t OUt W O. Wld~ldly of the Wllk in which oil Itrl~ II HI. 8ubmll weekly ~r wor~ ~d l~lowlng Mttl~ of ~1 MdnG ~nlll District Field Dite end depth as of 8:00 n.m. Alaska Redoubt Bay Wildcat County or Plrish III'ti Kenai Borough I Alaska Lease or Unit 10/15/90 46 glc/fj/wjp 10/16/90 47 g~c/fi/wip 10/17/90 48 gl~j/wj~ 10/18/90 49 g~jp 10/19/90 50 tbc/tj Complete record for each day while drilling or workovar in progresl Sturgeon #1 [we. no 6619' PBTD, Inj produced fluid into formation 9.1 ppg filtered brine ADC: $1,329,568 (AD 6960 Tstg) Cons flowing well. POOH, LD tst tls & TCP guns. RU Schl, m & set EZSV cms retnr on WL @ 5200' (32' above perfs). MU crnt stinger on 5' DP, RIH to 5200', sting into retnr & Sst. Stung out of retnr& inj produced wtr back into formation. 6619' PTBD, NU BOPE 9.1 ppg filtered brine ADC: $1,655,127 *AD 6969 Tstg) Fin injecting 240 bbls produced formation wtr into pads. Mx 104 sx cms w/.2% CFR-3, .2% HR-7 & .1% gal/sx Halad 344L. Cml sqz DST pads. POOH. Tst sqz job to 2000 psi; OK. LD 3-1/2' lbg. Chg btm rams to 5'. RIH w/9-5/8" csg cutter, cut csg@ 600'. POOH, LDcsg cutter. NU 13-5/8" 10M x 13-5/8' 10M 9-5/8" csg spool. NU BOPE on 13-3/8" csg spool. 300' POTD, LD 13-3/8" csg cutter 9.1 ppg brine ADC: $1,818,607 (AD 6960 Tstg) Fin NU BOPE. Rn 9-5/8" csg spear, latch 9-5/8' csg, pull & LD 11 jts. MU 13-3/8" EZSV cml retnr on DP, RIH & set @ 500'. Mx 146 sx cml w/.1% HR-7 & .25% CFR-3. Sqz 13-3/8' x 9-5/8' annulus w/73 sx crnt on top of 13-3/8' retnr. POH. Tst crntg plug to 2000 psi; OK. ND 13-5/8" BOP. Remove 13-5/8" 10M mud cross & set stack on stump. ND 13-3/8" csg spool. MU 13-3/8' csg cutting assy. RIH, cut 13-3/8" csg @ 289'. POH w/csg cutter. (Tst of P&A plug witnessed by AOGCC.) 400' PBTD, Cut & pull 20" csg 8.5 ppg seawater ADC: $1,887,145 (AD 6960 Tstg) LD csg cutter. Rn 13-3/8" csg spear, latch csg, pull 6 jts & 2 cutoff sections. CUt & remove 20' wellhead. RIH w/20' csg cutter, cut 20" csg@ 285' (30' below mudline). Rn 13-3/8' csg spear, attempt to pull csg w/o success. Rn 20' csg cutter, cut csg@ 200'. Rn spear & attempt to pull 20" csg w/o success. MU sud jars, attempt to jar 20" csg; no movement. Rn sinker bar on WL, tag cml @ 160'. Rn 20' csg cutter, cut csg @ 150'. Rn spear & attempt to pull 20' w/o success. MU sud jars & attempt lo jar 20" csg loose; no movement. Rn 20' csg cutter & cml csg@ 106'. Rn spear & surf jars; attempt to jar 20' csg loose. 400' PBTD, RU 30' cutler 8.5 ppg seawater ADC: $1,949,404 (AD 6960 Tstg) Cons wrk'g 20" csg; unable to free. Redress cutter. RIH & cons 20" fsh'g operations w/top of 20' @ 200'; cut @ 285'. Top of 30' @ _+38'; cut @ 285'. (NOTE: Took on 59,766 gal diesel.) The at~;~orrect ~ ~ For form prepar~on ~nd dtsthT~'-~on ~ lee Procedures Manual Section 10, ~ Drilling, Pages 86 and 87 ~, ITItle 11/13/90 New Ventures Drilling Superintendent AR3B-459-2-B I Number Iii daily' well history forms consecutively they ",re prepared for elCh well. ARCO Oil and Gas Company Dally Well History-Final Report In·tmcttene: Prepare Ind lubmit 1he "Flail Rel~fl" on the firlt Wedneldly lhlr iIIowebll hll hen i~llgned or well Il Plugged, Abandoned, or 8eld. "Flnll Reperl" should be lubmitted iiio ~n operetlofll Ire lUlbendld for I~ Indefinite or epp~llbtl lenglh of lime. Oft workowre when In official test II riot required upon completion, report completion Ind representative tilt detl In blecl~ provided. The "l~laM Rel~e~t" Iorm may be uled for repealing the entire OptrlllOn if IplCe tl available. District ]County or Plrilh Alaska I Kenai Borough Field ILea·e or Unit Redoubt Bay Wildcat IiTM Auth. or W.O. no. AFE: AD 6951 I Wildcat IAccountlng colt center code ~,tetl Alaska Sturgeon #! I w., no Glomar Adriatic VIII Operator ] A.R.Co. W.I. ARCO Alaska, Inc. I1 Dele Spudded Or W.O. begun Spud I 8/31/90 Date and depth Complete record for each day reported as of 8:00 a.m. 10/20/90 51 tbc/tj 10/21/90 51 tbc/tj 10/22/90 52 tbc 10/23/90 53 tbc Old TD Reteased rig Classifications (oil, gas, etc.) Producing method Potential test data Iotel number of wells (active or inactive) on this est center prior to plugging and ~ bandonmenl of this well I our IPrlor ItltUl If · W.O. 0600 Hrs. 400' PBTD, Dressing csg cutter w/20" blades 8.5 ppg seawater ADC: $2,010,152 (AD 6960 Tstg) Cent 20' fsh'g operations. 400' PBTD, MU 20" csg cutter 8.5 ppg seawater ADC: $2,070,109 (AD 6960 Tstg) Cent 20' fsh'g operations. 400' PBTD, Cent fsh'g operations ADC: $2,130,955 (AD 6960 Tstg) Cent 20' & 30' fsh'g operations. 400' PBTD, RR ADC: $2,457,319 (AD 6960 Tstg) Complete fsh'g operations. POH, LD 30" conductor pipe. RR ~ 1215 hrs. 10/22/90. Move rig to Seward. Rig to warm stack @ 0001 hrs. 10/28/90. INew TD J PB Deplh Date ]Kind of rig IType completron (single, dual, etc.) Official reservoir name(s) .. Well no. Date Reservoir Producing Interval Oil or gas Test time Production , Oil on teat Gal per dly P,','~p size, SPM X lengthChoke Ilze T.P. C,P, Water % GOR Gravity Allowable Effective date corrected AR3B.-459-3-C Number ell dilly well hlMory fermi conlecullvely · 1 they are prepared for each well. L ARCO Sturgeon #1 Condition After Abandonment (All Depths RKB) Mud Line @ 255'..~ 30" csg cut off @ 273' 20" csg cut off @ 285' 13-3/8" csg cut off @ 289' TOC @ 400' 30" shoe @ 401' BOC @ 600' Cmt retainer @ 500' 9-5/8" csg cut off @ 600' 20" shoe@ 1270' 13-3/8" shoe @ 2684' TOC @ 3580' TOC @ 5063' BOC @ 5392' TOC @ 5563' BOC @ 5882' Cmt retainer @ 5200' 5232'-5260' Perfs: 531 2'-5335' 5352'-5392' Cmt retainer @ 5658' Perfs: 5688'-5724' 5735'-5822' 5826'-5838' 5872'-5882' 9-5/8" shoe @ 6717' Well TD @ 7206' STURGEON #1 WELL TESTING SUMMARY DATE TIME DST gl 10/09/90 14:00 10/10/90 03:00 10/10/90 09:30 10/10/90 10:50 10/10/90 11:04 10/10/90 16:55 10/10/90 17:04 10/10/90 23:30 QPERATIQN RIH w/test string. Set packer. Load tubing w/N2. Pressure up annulus to fire perforating guns. Perforated 5232'- 5260', 5312'-5335', 5352'-5392'. Flow well for 10-minute cleanup period. S/I well to run Surface Readout gauge. Open well to flow on 12/64" choke. Fluid to surface just as well died. Tubing pressure = 0 psi. S/I well. No flow into tanks during test. Retrieve fluid sample w/ wireline. Reverse out produced fluids and prepare for second flow period. Total production from perforations for DST gl = 43 bbls water. DST #1-A 10/11/90 07:00 10/11/90 09:35 10/11/90 10:15 10/11/90 12:45 10/11/90 18:00 10/11/90 22:00 Load tubing w/N2. Open well on 12/64" choke. Fluid to surface. Open choke to 24/64". Average rate-650 bpd. FTP = 35 psig. S/I well. Total production from perforations for DST #1-A = 215 bbls water w/minor gas production. Release packer and POH w/test string. (Note: All existing perforations squeezed with cement after DST gl-A) DST #2 10/13/90 09:30 10/13/90 14:00 10/13/90 11:15 10/13/90 22:50 10/13/90 23:00 10/14/90 00:20 10/14/90 01:20 10/14/90 02:45 10/14/90 03:00 10/14/90 09:00 10/14/90 14:00 RIH w/test string. Set packer. Load tubing w/N2. Pressure up annulus to fire perforating guns. Perforated 5688'- 5724', 5735'-5822', 5826'-5838', 5872'-5882'. Flow well for 10-minute cleanup period. S/I well to run Surface Readout gauge. Open well to flow on 12/64" choke. Fluid to surface. Average rate -875 bpd. FTP = 50 psig. Open choke to 24/64". FTP = 23 psig. Open choke to 36/64". Average rate -550 bpd, FTP = 36 psig. S/I well. Total production from perforations for DST #2 = 185 bbls water w/no gas production. Release packer and POH to P&A well. IBOTTO~ HOLE PRESSURE - PSI 10:00 15:00 20:00 01:00 I 06:00 11:00 16:00 21:00 0 SI to Run SRO Probe Open LPRN Open LPRN ~ '''~/ .................................................. .__ SI for FL '. : : : Reverse Out Produced Fluids Cycle OMNI Valve . Open LPRN SI Well'll ,Reverse Out Produced Fluids jUnseat Packer , ~ ~_~uST~orNLinto Tubing: ! l~i~i ;~" ;;;' ' i ~i}h" 'C~ 0~; ............ on /64 e 02:00 ' 23:00 00:00 O1:00 02:00 03:00 04:00 05:00 06:00 07:00 08:00 09:00 10:00 11:00 RIH w/SRO Gauge ..... Bleed Tubing Press SI For Fluid Level SI Well with LPR-N Open Well Flow on 12/64 Choke Flow on 24/64 Choke Flow on 36/64 Choke SI Well at Wellhead NI II ii I I I ! I I ! ! I ! i. I I I I I I ! I I I ! I I I I ! I I T5N, R17W, SM 3130.' Sec. 25 486'~ Sec. 26 T5N, R16W, SM Sec. 19 Sec. 30 ADL 359110 Well ARCO Sltxeae~ N~. 1 Operator Arco Alaska Inc. Rig Glomar ~ VIII Heading 199 Degrees True Area Sec. 25, T5N, R17W, SM Redoubt Ba~, Alaska Lease A[ I I I I I I I I I I I I "'1 I I I I I I I I I I I I I I I I I Sc, aim: 1"= 112 ~ 1. Location of well site was a¢~ by using trian- Kalgin","Redoubt Bay N. Base" and "Harriet Point Lighl". 2. All dtmensioas and coordinates are in feet. ~ STATE PLANE CCX3RDII~T~ ZONE 5, IN FEET. RB=ERENCED TO NAD27. Y = 2,377,047 X = 830,176 GEODETIC POSITION UTM ZONE 5, Meters Lat. 60° 29' 38.09" N. N. 6,706,502 Long. 152° 10' 07.76." W. E. 545,669 Center of the derrick is located 486 feet west of the east line and 3,130 feet south of the north line of protracted section 25, T5N, R17W, SM, in lease ADL 359110. Location Survey For ARCO STURGEON No. 1 Section 25, T5N, R17W, SM REDOUBT BAY, ALASKA ADL 359110 I hereby certify that I am properly registered ~ ,~-, ,o ~ ~..~ .~.~,~r~ ~. ~. ARCO ALASKA INC. iState of Alaska and that this plat repre~nts a I~ Ioca~ suwey made by me and iii ~ I D~e;*i,~n,~ ~, ~.~ o,h.r ~,,i~_~,.,~,'r.c,. __ ,., ,'--~ .._C"".'"'"""" ."X . I ~-'-~c>-~,~.,~.~~/'~ _ _ NCS International I ORIGINAL P~E ~o # ............ X,..X~fl, N,N.~N,~N ............ #,X...)C~N-N~N ........ CO~P~ ~CO ~I.4~1~ Il,lC I~ELL N~d~ 51'URCEON # 1 ~TION i COOI( INLET LOCJ~TION 2 ~l.~I~ I~TE: 2~-$EP-~O I't~I,~IC DECLINATION 23.07 i, IELL NUMBER 0 RECEIVED dAN 1 0 1991 Alaska Oil & Gas Cons. COmlTIJ$$JOrl Anchorage 'P~E SL~ ANALYSIS ***** FO~DIUS OF CL~TUR~ ~OD*~*~ ft ~ INC CHG CUI~INC CHG I RATE AZM CHG CUI~AZIq CHG ft deg dee dee/lOOft dee dee TURN RATE CLOg. IRE TOOL FACE DLS DLSKT deg/lOOft fr dee dee/lOOfr dee/lOOft**2 0,0 0,00 0,00 0,00 0,00 0,00 0,00 1251,9 1251,92 0,40 0.40 0,03 207,26 207,26 1281,9 1281.92 -0,02 0,38 -0.06 16,33 223,59 1314.6 1314.62 -0.11 0,28 -0,33 15,~ 239,05 1343,9 !343.92 0.14 0,41 0,48 -11.4~ 227.59 0.00 0,00 0,00 0,00 0,00 16,56 3,10 0.00 0,03 0,00 54,44 3,22 106,51 0,37 1,14 47.29 3,36 149,40 0,42 0,14 -39,12 0,00 0.00 0,52 0.35 1375.9 1406.9 1498,3 1530,1 1561,9 1375,92 -0,20 0.21 -0.~ 17,54 245.13 1406,92 0.17 0,38 0,5~ -43,20 201,93 1498.24 -0.03 0,36 '0,03 29,63 231,56 1530,11 0,24 0,59 0,74 -5,22 226,34 1561.91 -0,22 0.37 -0,69 -14,18 212,16 54,82 3,65 165,01 0,69 0,52 -13~,37 3,76 74,18 0,87 0,58 32.45 4.11 112.18 0,21 0,72 -16,37 4,31 13,77 0,76 1,72 -44,59 3.51 30.45 0,78 0,08 1592.9 1623.9 1653,9 1685.9 1716.9 1592,91 -0,15 0,22 -0,50 12,01 224,17 1623,91 0,04 0,26 0,12 27,~3 252,11 1653,91 0.2~ 0.55 0,97 -32,96 219.15 1685,91 0,07 0,62 0,22 -27,6& 191,49 1716,91 -0,07 0,54 -0.24 -33,61 157,88 38,73 4,58 166,13 0,53 0,~3 90,15 4,69 84,80 0,38 0,46 -109.87 4.8& 56.08 1.20 2,73 -~.44 5.00 90,00 0,89 0,98 -108,41 4,48 158,61 1,10 0,68 1748.9 1778,9 1811,9 1843,6 1875.4 1748,85 0,13 0,67 0,41 7,41 165,30 1778,91 -0,21 0,47 -0,69 9,43 174,73 1811.90 -0,07 0,40 -0,21 -9,52 165,21 1843.56 -0,01 0,39 -0,03 6.92 172.13 1875.39 0.05 0,44 0,15 -11,45 160,68 23,21 4,8~ 31.88 0.47 1,98 31.38 4,81 160.08 0.75 0.~ -28,85 4,77 137.39 0.31 1.36 21,87 4,73 103,58 0.17 0.44 -35,98 4,97 118.59 0,29 0,40 1905.0 1934,9 1966.1 1~97.6 2028,0 1905,01 -0,11 0,33 -0,3& 44,03 204,71 1934,91 0,01 0,34 0,04 0,63 205,34 1966,10 0.10 0,44 0,32 23,13 228,47 I~7,62 0,16 O,&O 0,51 9,58 238,05 ~27,94 0,13 0,73 0,43 -1,40 236,65 148,&4 4,68 130,98 1,02 2,47 2,11 4,75 0,00 0,00 3,42 74,17 4,88 69,18 0,59 1,89 30,38 5,11 31,80 0.56 0,07 -4,61 4,67 64,98 0.43 0.45 2059.6 2090,4 2121.9 2151.8 2183.5 2059,54 0,03 0.76 0.10 0,59 237.24 _-7090,350,08 0.84 0,25 0,68 237,91 2121,87 -0,15 0.69 -0,47 13,48 251,39 2151.72 -0,01 0,68 -0,04 -34,11 217,29 2183,47 -0,09 0,5? -0,29 0,~5 218,24 1,87 5.75 0,00 0,09 1,07 2,19 6,11 0,00 0,24 0,49 42,76 6,49 136,18 0,73 1,57 -114.25 6,78 t08,58 1.35 2,0~ 3,01 5,41 0.00 0.28 3.37 2216.3 2244,0 2275,8 2305,7 2339.7 2216,28 0.03 0.62 0,09 25,25 243.49 2243.94 0,15 0.77 0.55 9.50 253.00 2275.71 -0.05 0.73 -0,15 -25,92 222.08 2305.6~ -0.03 0.69 -0,11 8.~ 235,94 2339,64 0,12 0,82 0,37 13.71 249.~ 76,94 7,26 95,?4 0,80 1,59 34.36 7.57 40.31 0,67 0,46 -81,58 7,92 110.48 1.06 1,23 29,60 8,21 110,43 0,38 2,29 40.35 6.~ 0.00 0.65 0.78 2370.7 2399.5 2427.6 2461,5 24?2.? 2370,67 0.22 1,03 0,69 8,43 258,09 ~99.48 -0.06 0,97 -0,21 -27.90 230,19 242.7.50 -0.15 0.82 -0.55 9.12 239.31 2461.38 -0.13 0,69 -0,38 -4.95 234,3~ 2492.86 0.24 0,93 0,75 15,05 249,41 27.18 ?,09 36,70 0.82 0.56 -96,85 9.54 110.89 1.69 3.02 32.54 9.90 141.17 0.75 3.37 -t4,61 10,27 !..=5,53 0.42 0,96 47,82 8,61 62,41 i.00 1.84 PAG£,NO. 3 . ,~-~' STURGB]N # 1 MD TUB INC CHG CL)IlNCCHG ft ft deq deg 2524,0 2523,95 -0.02 2553.? 2553.85 0.15 2584,6 2584,55 -0,49 2615.6 2615,46 0.52 2631.6 2631,49 -0.13 I RA~ AZH CHG O~ZM CHG TURN RATE deg/lOOft deg deq deg/lOOft 0,91 -0,07 -21.67 227.74 -69,69 1,06 0.50 18,01 245,75 60,23 0,5'/ -1,59 -9,~2 235,83 -32,31 1,08 1,67 8,26 244.08 26.71 O,g5 -0.81 -189.26 54,82 -1180.70 CLOSL~ TOOL FACE DIS DL~T f~ deq deq/lOOf~ 11,09 104,34 1.11 0.35 11,52 73,29 1.14 0,10 11,?0 168,83 1.65 1,67 12,28 17,17 1,71 0,18 10,67 49,58 12,64 68,23 26?3,4 2724,4 7.755,9 2786,9 2816,7 26?3,32 -0,01 2724,32 -0,10 2755,81 0,20 2.786,81 2816,56 0,00 0,94 -0.02 207.06 261,88 0.84 -0,31 0,42 262,30 1,04 0.63 0,94 263,24 1,10 0,18 -1,22 262,02 1,09 -0,01 -5,68 25)6,34 334.83 1,36 2,98 -3,94 -19,08 12,65 166,56 2,97 15,64 13,13 0,00 0,30 8,62 13,64 0,00 0,62 1,03 14,22 0,00 0,18 1,43 12,38 17~.66 0.35 0,58 2848,1 2910.4 2941.4 2971,3 3003,4 2847,94 0,02 2910,28 0.05 2941,28 0.08 2971.10 -0.07 3003,20 -0.11 1,12 0.08 -0.67 25"5.68 1.17 0.08 9.31 264,99 1.25 0,27 -4.38 260.61 1,18 -0.23 0,18 260.7? 1,07 -0,35 -4,82 25~,97 -2,12 14.93 -14,12 0,61 -15,03 15,39 0,00 0,06 0,92 16,60 80,45 0.31 0,39 17.25 48,68 0.40 0,30 17.88 169,37 0,24 0,53 14.79 94.49 0.46 0.69 3035.3 3035.14 -0.24 3065,9 3065.75 0.15 305'7.0 30?6,85 -0.19 3129,0 3128.78 0.13 3161,2 3160,99 -0,01 0,82 -0,76 5,24 261,21 0,97 0,47 5,23 266,44 0,78 -0,60 -3,49 262,94 0,91 0.41 2.40 265.34 0,?0 -0,04 -8,23 7..5'7,11 15,41 17.0~ -11,23 7,51 -25,55 19,01 163,39 0,81 1,08 19,49 30,74 0,54 0,88 19,96 168,47 0.62 0.27 20,43 7,00 0,42 0,64 18,49 142,23 0.41 0,03 3188,5 3221.2 3252,? 3282.4 3315.4 3188,34 0.15 3221,00 -0,19 3252,73 0,13 3282.23 -0,05 3315.22 -0,0~ 1.05 0,56 -5,69 251.42 0,86 -0,59 10,12 261,54 0.99 0,42 5,52 267,06 0.94 -0,18 -4.96 262,09 0.88 -0,19 1,66 263.75 -20.60 31,00 17,38 -16,83 5.03 21,~ 36.16 0.66 0,93 21,88 144,26 0,78 0,35 22.39 35.18 0,50 0,87 22,89 124,40 0.34 0.57 20.90 99.1I 0.19 0.44 3346.4 3378,1 3408.9 3439.4 3470,4 33z~.2~ 0,16 3377.91 0,02 3408,71 -0.09 3439.20 0.00 3470.20 0.09 1,05 0,53 8,83 272,59 1.07 0.07 -7,63 264,95 0,97 -0,31 3,09 268,05 0,?7 0,00 -0,64 267,41 1,06 0,28 -1.68 265,73 28.49 -24,08 10,05 -2.09 -5,41 23.93 46.11 0.71 1.69 24,51 85.15 0.45 0,82 25,06 150,15 0,36 0.31 7J.67 89.59 0.09 0.87 23,41 169,34 0.31 0,69 3532,4 3563,8 3594.4 3622,8 3654,9 3532,19 0.08 3563,59 0.00 3594,18 -0,30 3622,56 -0,11 3654,67 0,07 1.14 0,12 12,13 277,86 1,14 0,00 -10,13 267,73 0.84 -0.99 -3,85 263,88 0,72 -0.39 -3,26 260,62 0,79 0,21 11.50 272.12 19,~ -32,24 -12.59 -11,48 35.82 27,41 77.88 0.3~ 0.14 28.11 94,74 0.64 0.80 28.64 169,34 1,01 1.22 2?.02 161,95 0.42 2.10 26.22 23.13 0.52 0.30 3685,4 3718,2 3749,4 3780,4 3811.4 3685.17 0.19 3717.96 -0,I0 3749,16 0.31 3780.15 -0.14 3811,13 0.15 0,98 0.61 -9,76 262.36 0,88 -0,30 3.50 265.87 1,19 0.99 5.30 L71,16 1,05 -0,44 -7,44 263,73 1.20 0,49 1.54 265,27 -31.99 10.67 16,98 -23.~ 4,97 29,91 43,75 0.78 0.86 30,44 152,40 0,35 1.32 31,00 20,09 1.04 2.21 31,61 !37.38 0.64 1.27 29,44 71,42 0.49 0.4? , SLRUEY AJiALYSIS RADIUS OF DJf,'V~TURE ~rrHOD~x~MM~-~ ft ft CU)II~ C~ -- d~ dmo/lOOft deg deg deg/tOOft C~ TOOL FACE DI~ DLSRT ft deq deg/lOOft deg/jOOft~2 3842.5 3872,4 3903.4 3934,4 3~65,4 3842,22 3872.13 3903,12 3934,11 3965.10 0.10 0,14 -0.16 0,27 -0°06 1,30 0.32 -0.47 264.80 1.44 0.48 2,95 267.75 1,29 -0.51 2.84 270.59 1.56 0,88 -2.29 268.30 1.50 -0.19 -1,03 267.27 -1.50 9,85 9.16 -7,38-3.31 32.89 0.00 0.31 33.60 24.72 0,52 0.72 34.34 158.85 0,5'5 0.09 35.11 12,33 0,90 1.13 32,21 3.60 0,22 2.18 3997,4 4028.4 40~9.4 4091.5 4122.0 3997,09 0,14 1,63 0,42 5,90 273,17 4028,08 -0,13 1,50 -0,43 1,13 274,30 40~9.06 0,17 1.67 0,56 -6.68 267,62 4091.09 0.01 1,69 0.04 10.60 278.22 4121,62 0,04 1,73 0,15 -6,82 271,40 18.42 3.64 -21.56 33.08 -22,32 36.81 52.91 0.66 1.36 37.65 168.64 0.44 38.51 50.23 0,82 1.22 9~.46 73.13 0.97 0.47 35.93 150.75 0,69 0.93 4151.8 4183.4 4214.4 4244,4 427~.4 4151,40 4183.01 4213.99 4243.98 47.74,96 0.03 0.02 0.04 -0.02 0.00 1,76 0,10 1.60 273,00 1,78 0,05 0,06 273,06 1,82 0,14 2,15 275,21 1.80 -0,07 0,03 2.75,25 1,80 0,01 -0,45 2.74.80 5.37 0,19 6,95 0.11 -1.44 41.27 55.81 0.18 1.71 42.25 34.28 0,06 0.36 43.22 56.68 0.25 0.60 44,16 0.00 0,00 0,82 40.36 81.20 0,00 0,00 4306.4 4337,4 4368.4 4398.9 4429.4 4305.95 -0.01 1,80 -0.02 -2,94 271.86 4336,93 -0.01 1,79 -0.02 2.41 274.27 4367.92 0.00 1.79 0.01 0.28 274,55 4398,40 0,07 1,87 0,24 -I,77 272,78 4428.88 0.01 1.88 0.05 2.51 275.28 -9,50 7.78 0,90 -5,80 8.22 46.14 ~,91 0.29 0,92 47.08 95.91 0.24 0.15 48.05 83.02 0.06 0,56 49.02 40.41 0.32 0.83 45.16 0.00 0,28 0,14 4461,4 4492,4 4523.9 4554,4 4586.4 4460,87 4491,85 4523,33 4553.81 4585,79 0.05 0,06 0.01 0,03 0.03 1.93 2,00 2,01 2,04 2,06 0.16 -0,68 274.60 0.20 -0.26 274.34 0.03 -2.32 272.03 0.10 2.19 274.21 0.09 -1,77 272.45 -2.14 -0.82 -7.36 7.17 -5.52 51.07 12.JO 0.16 0.35 52,13 0.00 0.19 0.09 53.21 83,01 0.24 0.16 54,30 69.05 0,26 0,05 50,01 81,67 0,21 0,14 4617.4 46.48.4 4680,4 4711.4 4742.4 4616.77 0,01 2.07 0.03 0,55 273.00 4647,75 0,04 2.11 0,12 0.72 ~3.72 4679.73 -0.04 2.06 -0.14 1.05 274.77 4710,71 0.11 2,17 0.34 -1.61 273.16 4741.69 -0.08 2.09 -0.26 -1,40 271.76 1,77 2.33 3,28 -5.19 -4,50 56,57 66,56 0,06 0.48 57.69 35.96 0,14 0,25 58,85 139,09 0,19 0,13 59.~ 31.15 0.3~ 0.67 55,43 65.99 0,30 0,30 4773,4 4804.4 4835.4 4867.4 4897,4 4772,67 4803.64 4834,62 4866.60 4896,58 0.01 -0.01 -0.03 0,03 2,10 0,04 0,25 272,01 2,09 -0,02 -1,81 270,19 2,15 0,18 -0,64 269,55 2.I2 -0.10 0.23 269,78 2,15 0.11 -0.21 269.57 0.79 -5,85 -2,07 0,71 -0.69 62.27 0,00 0.00 0.97 63.40 96,22 0,19 0,62 64.55 14,80 0.19 0.00 65.75 0.00 0,09 0,33 6t.14 150.43 0.09 0.02 4927.4 49~.4 4989.4 5021,4 5051.4 4926.56 -0,03 2.12 -0,10 -0.41 269,16 4957,54 -0.04 2,08 -0.14 -0.54 268.62 4988.52 0,04 2,12 0.14 -1,48 267,14 5020,50 -0.08 2.04 -0.5 -1.B1 265.33 5050.48 0,05 2,0~ 0.15 -0,73 264,40 -1.38 - 1.74 -4,76 -5.66 -3,10 67.99 0,00 0,07 0,09 69.13 0,00 0,11 0.14 70.26 47,33 0,21 0.33 71.42 140.57 0.32 0,34 66.87 0.00 0,19 0.45 ~.~VL'Y AHAI. YSIS ~.~ F,:ADIUS OF CO~,~AT[~£ I'ETHOD~..~ MD ft TUD INC_CHG CUMINC_CHG I_RATE AZ{I_CHG CUMA~_CHG TURN_RATE CLOSL$~ TOOL_FACE DLS DLS~'T ft de§ deg deg/lOOft deg deg deg/.lOOft ft d~ deo/lOOft deo/lOOft~2 5082,1 5081,14 0,01 2,10 0,04 5113.1 5112,12 -0,04 2,06 -0,14 5144.1 5143,10 -0,02 2,04 -0,05 5175,6 5174,58 0,01 2,05 0,02 5207,1 5206,06 0,10 2,15 0,33 0,14 264,55 0,47 -2,09 262.46 -6,75 -4,92 257,53 -15,87 0,26 25'7,80 0,84 -0,05 257,75 -0,16 73,61 0,00 0,00 0,61 74,73 121,93 0,28 0,90 75,82 97,83 0,57 0,93 76,91 0,00 0,00 1,80 72,50 34,77 0,32 1,02 5238,1 5~J7,04 -0,06 2,09 -0,20 5269,1 5268,01 0,08 2,17 0,26 5297.I 5297.~ 0.00 2.17 -0.01 5332.1 5330.?7 -0.04 2.13 -0.11 5362,1 5360.96 0,00 2,13 0,00 2,63 260,38 8,49 -1,04 2.59,34 -3,35 -1,24 258,11 -4,12 -1,70 256,41 -5.15 -0,37 256,04 -1,23 79,17 123,83 0,37 0,17 80,30 22,45 0,2? 0,28 81,45 95,62 0,13 0,51 82.65 122.78 0.21 0.23 78,04 0,00 0,00 0,69 5394,1 5392,93 -0,01 2,12 -0,03 5424.1 5422,91 -0,01 2,11 -0.03 5456.1 5454,84 -0,18 1.93 -0.56 5487.6 54(~6.37 0.20 2,14 0,65 b'518,4 ~17.15 -0,02 2,11 -0,07 2,12 258,16 6,62 -1.61 256,55 -5,37 1,27 257,82 3,9? 0,66 258,48 2,08 1,54 260,01 4.~ 84,95 99,31 0,24 0,75 86,04 100,78 0,17 0,22 87,14 168,41 0,57 1,24 88.24 3.35 0.65 0.25 83,79 0,00 0,19 1,48 ~'~0,1 b'~,~ 0,04 2,16 0,13 5581,1 5579,81 -0,12 2,04 -0,37 .5611.1 .~:)?,79 -0,02 2,02 -0,05 .5643,1 .5641,77 0,06 2,09 0,20 5674,1 5672,75 -0,08 2,00 -0,27 -0,97 259,04 -3,06 -1,00 258,05 -3,22 2,66 260,70 8,86 3,49 264,17 10,89 -2,31 261,88 -7,44 90,53 42,73 0,18 0,05 91,64 161,29 0,39 0.70 92.68 100,78 0,32 0.26 93.82 64,59 0,44 0,3? 89,36 112,79 0,37 0,24 b"7(YJ,15703.73 0,03 2,04 0,11 5734,3 5732,91 0,09 2,13 0,30 5765,3 5763,89 -0,07 2,06 -0,22 5797.1 5795,67 0,02 2,08 0,07 5829,1 5827,65 -0,05 2,03 -0,15 -0,83 261.05 -2.67 2,66 263,71 9,12 2,83 266,54 ?.13 -4,93 261,61 -15.5I 1,68 263.28 5.23 96.00 14,34 0,11 0.83 97,06 48,55 0,44 1,14 98,18 12~,~ 0.40 0,15 99,32 85.34 0,56 0.50 94.92 139.25 0,23 1,02 58~3,5 5859,03 0.03 2,0& 0.11 5892.1 5870,61 -0.04 2,02 -0,12 5923.1 5921,57 -0,01- 2.01 -0,04 5953,9 5952,36 0,07 2,08 0,21 5984,9 5983,35 -0,13 1,95 -0,42 4.57 267,85 14.54 2,24 270,09 7.08 -5,80 264,29 -18,71 5,64 269.93 i8,31 -3,78 266,I5 -12,18 101,57 80.47 0,52 0,92 102,70 118.17 0,26 0,83 103,77 96,32 0,66 1,30 104.87 74,94 0,69 0.10 100,46 132,31 0.61 0.28 6016,? 6015,33 0,05 2,00 0,16 6048,7 6047.07 -0,01 1,99 -0,03 6078,8 6077,25 -0,03 1,96 -0,11 6110,2 6108,59 0,01 1,97 0.04 6141,7 6140,05 0,17 2,14 0,53 1,45 267,60 4,53 2,24 269,84 7,06 -1.80 268,04 -5,95 1,15 269,19 3,65 0.10 259.28 0.30 107.05 43,58 0,22 1.19 108,14 96,89 0.26 0,11 109.19 117.70 0.25 110,26 69,90 0.13 0.38 105.96 135.96 0.52 1.26 6173,3 6171,62 -0,03 2,10 -0,11 6204,6 6202,94 0.11 2,21 0,34 6234.0 6232,30 0,I0 2,31 0.35 6265,2 6263,46 -0.0~ 2,26 -0,19 6296,3 6294,52 0,18 2,43 0,57 -2,46 26&,82 -7,79 0.33 267,15 1,04 1,63 2~.78 5,56 -0,90 267,88 -2,88 -0,79 267,09 -2,54 112,55 111.05 0,31 0,68 113.73 13.~ 0.35 0.I4 114,87 32.14 0.41 0,20 116.13 O.O0 0.18 0,74 111.39 0.00 0.58 1.28 'PAG£ ~0. 6 ,J ~==~ ~II6J)RILL ************** SlRl~l~ ANALYSIS ***** RADIUS OF CURV~?URE ~1~OD******** III) l'v'D INC_CHG CUI'IINC_CI..I~ I_RATE AZI'I_CHG CUI",AZI'I_CI~ TURN_~TE CLOSLP, E TOOL_F~E DIS DLSE"r ft ft de§ d~ de~/lOOft deg deg deg/lOOft ft deg deg/lOOft deg/lOOft~2 6330.0 6328,11~ -0.06 6361.6 639.80 0.00 6392.7 63~,84 0.20 642~.9 6422,00 0,03 6455.0 ~53.09 -0.05 2.37 -0,18 5.23 272.32 15.51 2,37 '0.01 -1,?0 270,42 2,57 0,65 0,09 270.51 0.28 2.~ 0.09 4.15 274,66 13,32 2.~ -0.17 1.59 276,26 5.12 118.82 108.12 0.67 0.28 120.13 94,32 0.24 1.36 121.47 0.00 0.65 1.32 122.8~ 83.51 0.61 0,14 117.40 2,11 0,28 1.06 6484.8 6482.82 0.11 6516.1 6514,13 -0.01 6548.6 6546.61 0.12 6579.2 6577,16 -0.11 6610.2 6608.10 0.26 2,66 0,38 25,35 301.61 85,18 2,65 -0,03 -25,57 276.04 -81,57 2,77 0.38 '1.74 274,30 '5.35 2.66 -0.~ 0.48 274.78 1.~7 2.92 0.83 3,95 278.74 12,77 125.54 97.17 3,85 12,02 126.90 103.17 3.75 0.34 128,43 34.31 0.45 10.14 129,88 177,13 0.35 0.32 124,27 129,13 1,03 2,18 6641.7 6639.62 -0.0~ 6671.6 6669.44 -0,05 6704.7 5702.49 0.12 6734.6 6732.41 0.17 6766.6 6764.28 0.17 2.85 -0,24 0,92 279,65 2,91 2,79 -0,18 0,41 280,07 1,39 2.91 0,37 2,84 282,91 8,58 3.08 0,56 -3,18 279,72 -10,62 3,25 0,53 2,03 281,75 6,36 132,94 I51,80 0.27 2,40 134,39 166,58 0,19 0,29 136,00 49,54 0.~6 1,12 137,54 46,15 0,78 0.76 131,37 38,51 0,63 0,48 6796,2 6793,84 -0,02 6828,4 6826.01 0,12 6859.4 68.56.97 0,01 68~.8 6888,26 0.04 6~.1 6919.~ 0,23 3.23 -0,07 -4,75 277.00 -16,04 3,35 0,36 2.94 279.95 9.14 3.36 0,03 1,23 281,17 3,96 3,39 0,12 -1,43 279,75 -4,55 3,&'.'.']0,75 -2.00 227.75 -6,37 140,92 96,56 0,91 0,93 142,75 56,90 0,63 0.8.6 144,52 81,54 0,21 1,36 146.34 66.69 0,29 0,25 139,27 34,30 0.84 1,75 6954.4 6951.80 0.13 3.76 6985,6 6982.90 0.28 4,04 7016.4 7013,64 0,25 4,29 7046.7 7043,86 0.12 4,41 7077.0 7074.01 0.11 4,52 0,40 -0,30 277,46 -0,9I 0,91 -1,c/O 275,56 -6,09 0,80 3.50 279,06 11,36 0.40 -2.35 276.71 -7.77 0,35 0,45 .°.77,15 1.47 150,30 0.00 0.40 1,36 152,41 24.61 1.00 1.93 154,63 47,41 1.15 0.49 1.~.90 56.72 0,72 1,43 148.24 28.06 0.37 1.14 180. 150. 120. 90. 60. 30. ,, Displace Mud 0.0 400 0 800.0 1200,0 1600.0 2000.0 2400.0 2800.0 32 0.0 3600.0 4000.0 28-SEP-90 02'08:45 ANADRILL Schlumbe rge r STURGEON # 1 ARCO ALASKA, ZNC COOK TNLET, ALASKA HOLE DEPTH (Fl) 2695. TO H DEPTH FT Points out: z~9, la:H DEPTH FT · 2695,00 to 3556,00 ~ Y =ax +b ( 2P ) X :=' 814~ o: 0.00000 b: O.O00OO 4-000. 180. 150. 120. 30. B Bit Trip ..... 4000.0 4400.0 4800.l 5200.0 5600.0 6000.0 6400.0 6800.0 7200.0 7600.0 8000. 28-SEP-90 09' 42' 44- ANADRILL Sch lumbe rge r STURGEON // 1 ARCO ALASKA, INC COOK INLET, ALASKA HOLE DEPTH (FT) 4.265. TO 7176. H DEPTH FT Points out: 201 Y =aX +b ( 2P ) N ~ 2710 a: O.OOOO0 b: 0.00000 ORIGi~A~ SUB - S URFA CE DIRECTIONAL SURVEY U IDANCE [~J ONTINUOUS ~ OOL RECEIVED JAN 1 0 1991 Alaska' 0il & Gas Cons. Commission Anchorage Company ARCO A.I-ASKA~. INC. , ...................... Well Name STURGEON #1 (3130'.FNL,486' FEL,SEC 25,TSN,R17W} Field/Location WILDCAT, KENAI,,ALASKA _. Job Reference No. Date 74115 13-SEP-90 Logged By:~ Computed By: MILLER KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. STURGEON #1 WILDCAT KENAI, ALASKA SURVEY DATE= 13-SEP-90 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: MILLER Averaged deviation and azimuth PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 37 DEG 55 MZN WEST COMPUTATION DATE= 27-0CT-90 PAGE 1 ARCO ALASKA, INC. STURGEON #1 WILDCAT KENAZ, ALASKA DATE OF SURVEY= KELLY BUSHING ELEVATION: ENGINEER: 13-SEP-90 118.00 FT MILLER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIAT]ON AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL SECTION FEET DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -118.00 0 0 100.00 99.99 -18.01 1 8 200.00 199.98 81.98 0 47 300.00 299.97 181.97 0 21 400.00 399.97 281.97 0 33 500.00 499.96 381.96 0 27 600.00 599.96 481.96 0 12 700.00 699,96 581.96 0 18 800.00 799.96 681.96 0 22 900.00 899.96 781.96 0 19 N 0 0 E S 7 4 E S 8 31 E S 7 38 E S 12 S49 S 58 59 W N 79 44 W S 84 46 W S 68 O. O. 2. 2. 3. 4. 4. 5. 5. 5. O0 89 15 78 49 29 84 10 44 88 0.00 0.00 N 0.00 E 0.00 0.58 1.23 S 0.14 E 1.24 0.68 3.01 S 0.36 E 3.03 0.05 3.89 S 0.47 E 3.92 0.33 4.73 S 0.40 E 4.74 0.08 5.39 S 0.05 W 5.39 0.00 5.75 S 0.49 W 5.77 0.00 5.80 S 0.86 W 5.86 0.00 5.74 S, 1.48 W 5.93 0.25 5.89 S 2.01 W 6.22 N 0 0 E S 6 24 E S 6 54 E S 6 54 E S 4 47 E S 0 34W S 4 54W S 8 23W S 1430W S 18 52W 1000.00 999.96 881.96 0 25 1100.00 1099.95 ~ 981.95 0 33 1200.00 1199.95 [ 1081.95 0 36 1300.00 1299.94 1181.94 0 24 1400.00 1399.94 1281.94 0 25 1500.00 1499.94 1381.94 0 21 1600.00 1599.94 1481.94 0 18 1700.00 1699.93 1581.93 0 26 1800.00 1799.93 1681.93 0 22 1900.00 1899.93 1781.93 0 28 S 85 49 W S 79 59 W S 42 21 w S 21 23 W S 35 53 W S 5 9 E S 59 26 W S 48 28 W S 35 55 E S 26 13 E 6. 6. 7. 8. 9. 10. 10. 11. 11. 11. 35 92 91 85 46 18 51 37 47 84 0.15 6.00 S 2.63 W 6.55 0.17 6.10 S 3.44 W 7.00 0.21 6.61 S 4.38 W 7.93 0.16 7.40 S 4.90 W 8.87 0.63 7.87 S 5.28 W 9.48 0.56 8.64 S 5.48 W 10.23 0.41 8.92 S 5.65 W 10.56 2.09 9.46 S 6.36 W 11.40 0.36 9.83 S 6.05 W 11.54 0.40 10.44 S 5.87 W 11.98 S 23 39 W S 29 24 W S 33 33 W S 33 31W S 33 52 W S 32 24 W S 32 22 W S 33 56 W S31 37 W S 29 20 W 2000.00 1999.92 1881.92 0 46 2100.00 2099.91 1981.91 0 47 2200.00 2199.91 2081.91 0 46 2300.00 2299.90 2181.90 0 44 2400.00 2399.89 2281.89 0 58 2500.00 2499.87 2381.87 0 54 2600.00 2599.86 2481.86 0 54 2695.00 2694.85 2576.85 0 54 S 25 37 W S 54 31W S 57 30 W S 61 10 W S 55 38 W S 55 52 W S56 9W S56 9W 12. 14. 15. 16. 17. 19. 20. 22. 66 O5 12 21 60 19 67 09 0.64. 11.37 S 6.00 W 12.86 2.98 12.39 S 6.96 W 14.21 0.59 12.84 S 8.12 W 15.19 0.37 13.47 S 9.07 W 16.25 0.65 14.25 S 10.35 W 17.61 0.00 15.14 S 11.78 W 19.19 0.00 16.01 S 13.09 W 20.68 0.00 16.84 S 14.33 W 22.11 S 27 50 W S 29 21W S 32 17 W S 33 58 W S 35 59 W S 37 53 W S 39 16W S 40 23 W COMPUTATION DATE: 27-0CT-90 PAGE 2 ARCO ALASKA, INC. STURGEON #1 W[LDCAT KENAI, ALASKA DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: 13-SEP-90 118.00 FT MILLER 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 VERTICAL SECTION FEET DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -118.00 0 0 N 0 O'E 1000.00 999.96 881,96 0 25 S 85 49 W 2000.00 1999.92 1881.92 0 46 S 25 37 W 2695.00 2694.85 2576.85 0 54 S 56 9 W 0.00 6.35 12.66 22.09 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.15 6.00 S 2.63 W 6.55 S 23 39 W 0.64 11,37 S 6.00 W 12.86 S 27 50 W 0.00 16.84 S 14.33 W 22.11 S 40 23 W COMPUTATION DATE= 27-0CT-90 PAGE 3 ARCO ALASKA, INC. STURGEON #1 WILDCAT KENAI, ALASKA DATE OF SURVEY= KELLY BUSHING ELEVATION= ENGINEER= 13-SEP-90 118.00 FT MILLER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL SECT[ON FEET DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -118.00 0 0 118.01 118.00 0.00 1 9 218.03 218.00 100.00 0 40 318.03 318.00 200.00 0 23 418.03 418.00 300.00 0 28 518.04 518.00 400.00 0 25 618.04 618.00 500.00 0 12 718.04 718.00 600.00 0 20 818.04 818.00 700.00 0 22 918.04 918.00 800.00 0 20 N 0 0 E S 7 4 E S 7 38 E S 3 55 E S 22 9 W S 49 46 W S 61 28 W N 78 37 W S 79 36 W S 75 45 W 0.00 1.14 2.31 2.86 3.64 4.42 4.90 5.15 5.52 5.97 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.36 1.59 S 0.18 E 1.60 S 6 34 E 0.50 3.24 S 0.40 E 3.26 S 6 59 E 0.34 4.01 S 0.48 E 4.04 S 6 53 E 0.67 4.88 S 0.35 E 4.89 S 4 5 E 0.01 5.48 S 0.16 W 5.48 S 1 38 W 0.08 5.78 S 0.55 W 5.81 S 5 24 W 0.16 5.78 S 0.95 W 5.86 S 9 22 W 0.11 5.75 S 1.60 W 5.97 S 15 31 W 0.13 5.92 S 2.11 W 6.28 S 19 37 W 1018.04 1018.00 900.00 0 26 1118.05 1118.00 1000.00 0 36 1218.05 1218.00 1100.00 0 35 1318.06 1318.00 1200.00 0 20 1418.06 1418.00 1300.00 0 26 1518.06 1518.00 1400.00 0 13 1618.06 1618.00 1500.00 0 24 1718.07 1718.00 1600.00 0 15 1818.07 1818.00 1700.00 0 23 1918.07 1918.00 1800.00 0 31 S 83 55 W S 74 53 W S39 OW S 25 23 W S 24 37 W S 0 31 E S 57 19 W S 9 38 E S 21 15 E S 17 48 E 6.44 7.06 8.09 8.96 9.59 10.25 10.62 11.46 11.52 11.92 0.00 6.01 S 2.76 W 6.62 S 24 40 W 0.46 6.14 S 3.61 W 7.12 S 30 30 W 0.00 6.75 S 4.50 W 8.11 S 33 43 W 0.33 7.50 S 4.94 W 8.99 S 33 23 W 0.32 7.99 S 5.35 W 9.61 S 33 48 W 0.81 8.73 S 5.47 W 10.30 S 32 6 W 0.52 8.98 S 5.75 W 10.66 S 32 38 W 1.68 9.54 S 6.40 W 11.49 S 33 52 W 0.44 9.93 S 6.00 W 11.60 S 31 7 W 0.45 10.59 S 5.81 W 12.08 S 28 46 W 2018.08 2018.00 1900.00 0 47 2118.09 2118.00 2000.00 0 37 2218.10 2218.00 2100.00 0 45 2318.10 2318.00 2200.00 0 48 2418.11 2418.00 2300.00 1 0 2518.13 2518.00 2400.00 0 54 2618.14 2618.00 2500.00 0 54 2695.00 2694.85 2576.85 0 54 S 32 20 W S 74 39 W S 50 36 W S 57 49 W S 57 31W S 56 9 W S 56 9 W S 56 9 W 12.90 14.23 15.35 16.43 17.90 19.45 20.94 22.09 0.89 11.59 S 6.12 W 13.10 S 27 51 W 1,00 12.47 S 7.15 W 14.38 S 29 50 w 0.31 12.98 S 8.31 W 15.42 S 32 37 W 0.17 13.60 S 9.28 W 16.47 S 34 19 W 0.19 14.42 S 10.61 W 17.91 S 36 20 W 0.00 15.29 S 12.02 W 19.45 S 38 10 W 0.00 16.17 S 13.32 W 20.95 S 39 30 W 0.00 16.84 S 14.33 W 22.11 S 40 23 W ARCO ALASKA, INC. STURGEON #1 WILDCAT KENAI, ALASKA MARKER COMPUTATION DATE: 27-0CT-90 INTERPOLATED VALUES FOR CHOSEN HORIZONS PAGE 4 DATE OF SURVEY: 13-SEP-90 KELLY BUSHING ELEVATION: 118.00 FT ENGINEER: MILLER SURFACE LOCATION = 3130' FNL & 486' FEL, SEC25 TSN R17W MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA BOTTOM 20" CASING 1270.00 1269.94 GCT LAST READING 2502.00 2501.87 BOTTOM 13 3/8" CASING 2695.00 2694.85 TD 2695.00 2694.85 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1151.94 2383.87 2576.85 2576.85 7.17 S 4.80 W 15.15 S 11.81 W 16.84 S 14.33 W 16.84 S 14.33 W ARCO ALASKA, [NC. STURGEON #1 WILDCAT KENAI, ALASKA MARKER TD COMPUTATION DATE: 27-OCT-90 STRATIGRAPHIC SUMMARY MEASURED DEPTH BELOW KB 2695.00 PAGE 5 DATE OF SURVEY: 13-SEP-90 KELLY BUSHING ELEVATION: 118.00 FT ENGINEER: MILLER SURFACE LOCATION = 3130' FNL & 486' FEL, SEC25 T5N R17W TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 2694.85 2576.85 16.84 S 14.33 W FINAL WELL LOCATION AT TD= TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 2695.00 2694.85 2576.85 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 22.11 S 40 23 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA, INC. WELL STUROEON ~ 1 F I ELD W I LDCAT COUNTRY USA RUN ONE DATE LOOOED 13 - SEP - 90 REFERENCE '74 ! ] S .~.L: STURGEON #1 ,.~130' FNLo 486' FEL, SEC 25, ~, R17W) HORIZONTAL PROJECTION -lO -6 0 6 lO 16 20 2~ 98. PROJECT I OH ON VER? I Cf:i. 218. - 38. 6CRLED IN VERTICRL Drr.,PIH6 HORIZ 6Ct:LE" I/$ IN/FT STURGEON #1 FNLo 486' FEL, S,~C 25, VERTICAL PROJECTION - 10 -G 0 0 6 10 16 ~ 218. PROJECTION ON VERTICRL PLt:tNE 218. - 98. SO:it.ED IN VERT]CRL DE:PTH~ HORIZ SCRLE = 1/1~ IN/F*T ._ ARCO Alaska, Inc. Anchorage, Alaska OR IGI N ^ L Results of Well Site Surveys ARCO Sturgeon No. 1 (Lease Block ADL 359110) Redoubt Bay ENSR Consulting and Engineering August 1990 Document Number 0480-110-100 Date~ RESULTS OF WELL SITE SURVEYS ARCO ALASKA, INC. ARCO Sturgeon No. 1 (Lease Block ADL 359110) Redoubt Bay, Cook Inlet, Alaska operator ARCO Alaska, Inc. Anchorage, Alaska prepared by ENSR Consulting and Engineering Anchorage, Alaska August 1990 TABLE OF CONTENTS 1.0 INTRODUCTION .............................................. 2.0 HISTORY OF THE PROJECT ..................................... 3.0 EQUIPMENT AND METHODS .................................... 3.1 Survey Vessel ............................................ 3.2 Horizontal Control ......................................... 3.3 Geophysical Systems ....................................... 4.0 SURVEY RESULTS ............................................ 4.1 Bathymetry .............................................. 4.2 Side Scan Sonar .......................................... 4.3 Seismic/Subbottom ........................................ 5.0 CURRENT MEASUREMENTS AND PREDICTION ...................... 5.1 Method ................................................. 5.2 Results ................................................. 6.0 CONCLUSIONS ............................................... Page 8 8 9 10 11 11 11 21 UST OF ILLUSTRATIONS Figure 1 Project Location ....................................... Page Figure 2 Une Spacing for Site-Specific Shallow Hazard Survey and Well Location Relationships (after Alaska OCS specifications) ......................................... Figure 3 Current Profiles for ARCO Sturgeon No. 1 Location .............. 13 Figure 4 Current Versus Elapsed Time at ARCO Sturgeon No. 1 Location ............................................. 17 Figure 5 Observed Current at ARCO Sturgeon No. 1 Drillsite plotted against Seldovia Tide Range ......................... 20 Plate I Survey Coverage ................................ In Pocket Plate II Survey Trackline Map ............................ In Pocket Plate III Plate IV Plate V Bathymetric Map ................................ Surficiai Geology, Side Scan Sonar Interpretation ........ Seismic Unes 103 and 204 ........................ In Pocket In Pocket In Pocket ii 1.0 INTRODUCTION This report presents the results of a marine geophysical survey and current measurement survey undertaken for ARCO Alaska, Inc. in the vicinity of Section 25, T5N, R17W, Seward Meridian. The survey location is in Redoubt Bay, west of Kalgin Island, Cook Inlet (Figure 1). The purpose of the geophysical survey was to obtain surface and subsurface geologic information by high resolution seismic profiling and side scan sonar in order to determine the local thickness and character of surficial sediments and to define any shallow geologic hazards within the survey area. In addition, precision depth recording information was obtained and a bathymetric map of the area was produced. 2.0 HISTORY OF THE PROJECT The prospect covered by these well site surveys was originally operated by Union Pacific Resources Company (UPRC) and the initial test well was to be identified as No. 1 WECO-UPRC Cannery Creek 42-36. UPRC contracted with ENSR Consulting and Engineering (ENSR) to conduct the equivalent of an MMS-OCS Site-Specific Shallow Hazard Survey over the 42-36 location in December 1989. The field efforts for this survey were conducted between December 9 and December 30, 1989. Line spacing and survey grid for this survey are shown in Figure 2. During the time that data from this survey were being reduced, UPRC and partners concluded a deal with ARCO Alaska, Inc. which resulted in ARCO assuming operatorship of the prospect. At that time, ARCO changed the name and location of the first exploratory well. These changes are summarized below: Operator and Well Location Location Location Designation Latitude/Longitude ASPC Zone 5 Sec Line Ref. Union Pacific 152° 10' 08.04"W X = 830,276.89 500 ft WEL, 3300 ft Resources Company: 60° 28' 57.41"N Y = 2,372,917.55 NSL, SEC 36, T5N, No. 1 WECO-UPRC R17W, SM Cannery Creek 42-36 (original location) ARCO Alaska, Inc. 152° 10' 06.90'W X = 830,218.84 3121 ft SNL, 445 ft ARCO Sturgeon No. 1 60° 29' 38.20"N Y = 2,377,059.54 WEL, SEC 25, T5N, (new location) R 17W, SM Location Difference: ,tX = - 58.05 z~Y = +4141.99 -1- PROJECT LOCATION ARCO STURGEON No. 1' COOK INLET ALASKA ARCO ALASKA, INC. ,Scale: Given FIGURE i. Attached to and made a part of application to flare natural gas produced during well testing operations. Sec 25 TSN~RITW )¢~1151# FORELAND ,¥/A'/$A'I Drift River Terminol ARCO STURGEON NO.1 LOCATION 12.5 ;} 1~.5 ~5 )--.M I-'-t I i · MILES UPRC LINE 101 UPRC LINE 103 UPRC LINE 105 ARCO STURGEON NO.1 OF DETAILED BATHYMETRY AND SIDESCAN SONAR COVERAGE -NO, 1 WECO UPRC CANNERY CREEK 42-36 UPRC UNE 107 : UPRC LINE 109 UJ Z 4800m (:3 n- CC: [~ 1200m J --i 0 0.5 1.0 1.5 2.0 km I I I ; ; ; ; ; ; I I I I I I 0 0.5 1.0 mi 62.4 km C38.8 mi) Figure 2. Une Spacing for Site-Specific Shallow Hazard Survey and Well Location Relationship (after Alaska OCS specifications). -3- The relationship between these two locations and survey coverage is shown in Figure 2. After consultation with the Alaska Oil and Gas Conservation Commission (AOGCC), it was determined that the original UPRC survey (December 1989) would suffice for shallow hazard identification at the ARCO location, since two high resolution seismic lines passed through, or were adjacent to the site. However, both AOGCC and ARCO determined that additional detailed bathymetry and side scan sonar data were required at the new ARCO location in order to adequately assess site-specific conditions. ENSR conducted these supplemental surveys at the ARCO location in August 1990. This report contains a description of the methods employed and the results of both the December 1989 and August 1990 surveys. 3.0 EQUIPMENT AND METHODS 3.1 Survey Vessel Both the December 1989 and August 1990 surveys were conducted from the M/V Maritime Maid. This vessel is of steel construction, 86 ft long, 22.2 ft beam width, and draws 8.8 ft. The vessel has accommodations for 13, a full galley, and cruises at 10.5 knots. Survey speed is approximately 3 knots. The M/V Maritime Maid was ideally suited for these surveys. The December survey was carried out under adverse sea and weather conditions and during two eruptions of Mt. Redoubt volcano. The vessel performed as well as could be expected under these conditions, although survey operations had to be suspended several times due to sea state and volcanic activity. The vessel is based in Homer, Alaska and all mobilization/demobilization work for both surveys was done in that port. Transit time to and from the survey area and the port of Homer varied between 8 and 15 hours depending on weather, tides, and sea state. The vessel is equipped with a 20 ft x 20 ft helicopter deck. This proved invaluable during the August 1990 survey when project time constraints required immediate data reduction and interpretation. Data tapes were flown directly from the vessel to Kenai in order to meet project schedules. -4- 3.2 Horizontal Control Horizontal control was maintained during both surveys with a Motorola Mini Ranger IV range- range positioning system. This system has a positional accuracy of · 6 ft (2 m). System Specifications are as follows: Principle of Measurement: Frequency: Power (RT and receiver units): Operating Temperature: Range: Range Accuracy (nominal): Pulsed Radar Interrogation 5400 to 5900 mHz 16 watts -50° to 60°C 30 ft to 40 nautical miles -2m System Peripherals Data Processor: Plotter: Printer: Digital Recorder: Trackline Indicator: Motorola MRDP Houston Instrument EPE-111/37 Texas Instruments Silent 700 Textronics 4923 Motorola Transponders were set by helicopter on the following onshore control points: North Kalgin X = 870,230.73 Y = 2,383,794.54 Harley (offset) X-- 866,362.74 Y = 2,352,197.50 A Harriett Point Ught X = 819,173.26 Y = 2,341,200.80 Redoubt North Base (R.M.2) X = 809,442.92 Y- 2,388,443.74 -5- (X and Y coordinates are all in Alaska State Plane Coordinate System Zone 5) Plate I shows the location of these control points relative to the survey area. During the surveys, navigation fixes and record annotations were made every 3 seconds and recorded on magnetic tape. 3.3 Geophysical Systems The following geophysical systems were employed on the December 1989 survey: Fathometer Ross Model 601/801 Dual Frequency Beam Angle Output Maximum Depth Interface Depth Resolution Systems Spares 41 kH and 298 kHz 24° and 8° Digital and Analog 3,000 ft Motorola Positioning Systems 0.1 ft Klein Side scan Sonar Klein Digital Graphic Recorder Dual Frequency 100/500 kHz Model 595 Recorder Model 422S-101 EF Model 422S-101 AF Horizontal Beam Width Vertical Beam Width Pulse Length Tape Recorder System Spares 500 kHzFish 100 kHzFish 500 kHz 0.2° 100 kHz 1.0° 40° Tilted 10° Below Horizontal 500 kHz 0.02 millsec 100 kHz 0.1 millsec HP 3968 -6- 3.5 kHz High Resolution Subbottom Profiler Datasonics: Model SBP-5(X)0 Principal of Measurement Frequency Pulse Length Power Output Beam Angle (total) Resolution (vertical) · . Acoustic Reflection 3.5 kH Selectable 0.1, 0.2, 0.5, 1.0, 2.0, and 5.0 millsec 12kw 50° · 1 ff System Coml3onents Transceiver Transducer Two Cable Graphic Recorder Seismic Recorder System Spares Data Sonics SBT-220 Data Sonics TTV- 120 Data Sonics TWC-601 EPC 3200 Hewlett Packard 3968 16 Joule. 300 Hz Bubble Pulser Seismic Reflection Subbottom Profiler Lister Enterprises: Principle of Measurement Central Frequency Band Width Pulse Length Output Transducer Single Channel Streamer Seismic Amplifier Graphic Recorder Seismic Filter Tape Recorder System Spares Acoustic Travel Time 300 Hz 100-1500 Hz 4 millsec Analog Lister Benthos 15/10P Teledyne HR-300 EPC 3200 Krohn-Hite 3550 HP 3968 -7- High Resolution Seismi(~ A(~quisition System System addresses problems in high resolution seismic surveys for shallow objectives including: Direct Arrival Interference Source Overdrive of Near Trace Response Refraction Interference Receiver/Source Array Effects Wavelet Processing with Varying Signature NMO Stretch Coherency-Resolution Optimization Dual Recording System: High Resolution System: Source: Shot Interval Sampling: Recording Time: Magnetic Tape and Laser Disc Vertical Resolution = 1 to 2 m 16/32 ch, 2 m Gl, Xmin = 10 m, Xmax = 40/72 m = 1-2 m providing up to 32 fold with CDP interval of 1 m 0.25 ms (Nominal Alias High Cut = 1,00 Hz) 0.25 - 0.30 S During the August 1990 detailed survey of the ARCO Sturgeon location, only the Ross 601/801 digital fathometer and the Klein 505 side scan sonar were employed. Current measurements were also made during the August 1990 survey and are reported in Section 5.0 herein. During the December 1989 survey, a total of 16 high resolution seismic and hydrographic lines were run on a line spacing shown in Figure 2. Side scan sonar data were recorded on all lines. During the August 1990 survey, an additional 23 lines of hydrographic and side scan data were recorded. Plate II shows the survey tracklines of the August 1990 survey as well as two seismic lines from the December 1989 survey. 4.0 SURVEY RESULTS 4.1 Bathymetry Bathymetric data were digitally recorded at 3 second intervals along all hydrographic and geophysical survey lines. A sound velocity of 4800 feet per second was used to convert the time record into water depth. Tidal corrections were based on data from the 1989 and 1990 -8- National Ocean Survey tide tables of the West Coast of North and South America. The tidal data for the Drift River Terminal corrections applied to Seldovia were used as the reference datum for reduction of all bathymetric data. The bathymetric map (Plate III) shows that the seafloor in the vicinity of the ARCO Sturgeon No. 1 location is characterized by irregular topography which reflects resistant underlying ridges which are partly or completely blanketed by large sand waves. Maximum relief exhibited by these features is on the order of 10 ft. Water depths ranged from -129 ft to -147 ft MLLW. A major east-west feature lies approximately 250 ft south of the planned well location. This feature has moderate slopes on the north side which average 5 to 6 vertical ft/lO0 ft and steeper slopes on the south side showing relief up to 11 to 12 ft/lO0 ft. The area south of this feature is characterized by large sand waves with amplitudes up to 2-2.5 ft. Similar conditions are found north of the planned well location. 4.2 Side Scan Sonar The side scan sonar provides information on the surficial characteristic of the seafloor under and on either side of the survey vessel out to a range of approximately 100 m. Depending on the relief of the seafloor, the local sediment types, and biological features present, various amounts of reflected or back-scattered acoustic energy are received by the side scan transducer. This back-scattered acoustic information appears on the sonograph record as shades of varying intensity, coherent patterns, or sharp outlines depending on the seafloor features or "targets" present. Since side scan systems operate at high acoustic frequencies (100 kHz), they are very sensitive to subtle textural changes associated with the various types of sediments and materials that cover the seafloor. Such materials as gravel, sands, or bedrock produce very characteristic distinctively different sonographs or records, thus allowing rapid mapping of seafloor geology. In addition, the size of large discrete "targets' such as boulders or rocks can be calculated based on the size of the acoustic shadow they cast. Plate IV summarizes the interpretation of the side scan sonar data. No rocks or boulders were observed within the area surveyed around the ARCO Sturgeon No. 1 location. Several areas of hard bottom, which are interpreted as very coarse sand and gravel, conform in areal distribution to the features of significant relief described in Section 4.1 above. -9- 4.3 Seismic/Subbottom The identification and classification of subbottom geology was based on the concept of seismic facies analysis. This analysis technique considers various seismic or acoustic parameters on the reflection record in order to infer characteristics and depositional environments of bottom and subbottom sediments. Parameters that were considered in identifying the different seismic facies units were: 1) reflection amplitude; 2) reflection continuity; 3) reflection configuration; 4) reflection frequency; 5) geometry of the seismic facies unit; and 6) the presence of diffractions. Once the various seismic units are identified, their general lithology can be inferred based on the parameters discussed above or determined by subsurface sampling. Three distinct units were identified on the seismic and subbottom records: Unit 1: This unit is a relatively fiat lying continuous unit underlying most of the area. It is interpreted as being consolidated to over-consolidated glacial till. Low amplitude returns and Iow impedance contrast from Unit I on the subbottom record suggests that it is composed of mostly dense sands lacking any internal reflectors. Unit I is most likely underlain by Tyonek formation. Unit 1 appears to be the core material within those features of significant relief described in Section 4.1 above. Unit 1 varies in thickness between 50 and 400 ft across the area. It has been differentially eroded which accounts for the differences in thickness. Unit 2: This unit varies between 5 and 15 ft in thickness, is unconsolidated to poorly consolidated, and is composed of medium to coarse sand. This unit was acoustically transparent to the subbottom profiling system. This unit makes up the sand waves which occur across the survey area. Unit 3: This unit is composed of surficial sand with patchy distribution across the survey area. It is most likely highly mobile and subject to almost continuous redistribution by tidal currents. Where it does occur, this unit is thin (~ 1-4 ft) and except for certain areas where it can be identified on side scan records, appears acoustically similar to Unit No. 2. Plate V shows the two high resolution seismic lines which pass through or close to the ARCO Sturgeon location. These lines have been annotated to show the above lithologic units. No shallow gas was identified in the area of the ARCO Sturgeon No. 1 location. This is consistent with other shallow hazard surveys and drilling experience in the Redoubt Bay area. - 10- 5.0 CURRENT MEASUREMENTS AND PREDICTION 5.1 Method Upon completion of the bathymetry and side scan sonar surveys described above, the survey vessel M/V Maritime Maid was anchored near the ARCO Sturgeon No. 1 drill location to run current meter profiles. Once anchored, the vessel was not moved until the current profiling was complete. The vessel was allowed to swing on its anchor during the flood and ebb tides. During the current profile measurements, the vessel ranged between 100 and 310 m of the drill location. A clump weight of approximately 1500 lb was suspended from the boom and lowered to the bottom. The weight was then raised 3 to 4 ft to allow the boat to swing freely with the currents. This also allowed the boom to be positioned and secured in such a position that the cable always hung next to the boat, thus easing the deployment and retrieval of the current meter. It was observed that the weighted cable maintained a near vertical orientation even in the strongest of currents. Once the clump weight was secured in place, the current meter (Neil Brown Model DRCM-2) was shackled to the wire and deployed. Current speed and current direction were measured at 15 ft, 25 ft, and thereafter every 25 ft down to 125 ft with a final measurement taken at the top of the clump weight. The depth of this last measurement ranged between 135 ft and 150 ft depending on the tide level. At each depth, the instrument was allowed to stabilize. Once it had stabilized, the time, the current speed, and the current direction were recorded from the deck unit (Neil Brown Model CMDT-1). Also recorded for each series of readings were the operator, the date, the vessel heading, and the type of tide (flood, ebb, high slack, Iow slack). Upon completion of each run, the current meter was secured at the final station until the next hour. Thus every other set of readings was taken from bottom to top. The runs were approximately one hour apart (start to start) and usually took 20 to 40 minutes to complete, depending on current. This sequence of readings was repeated every hour for 25 hours. Data was collected for 3 flood and 2 ebb tides during this 25-hour period. 5.2 Results Current data was collected over a 25-hour period, during which 21 profiles were run. The maximum current recorded was 2.7 knots at the surface during the second ebb tide. It was found that the magnitude of the currents generally decreased with depth with a maximum bottom current of 1.3 knots. -11- It was also found that the currents near the bottom changed direction about a half an hour before the currents at the top. The average direction of the near surface flood currents greater than 1.0 knots was 4.4°. At mid-depth, the average direction of flood currents was 354.8° and at the bottom the average direction for the flood currents was 350.0. The average of the surface ebb currents with magnitudes greater than 1.0 knots, was 154.0°. At mid-depth and at the bottom, the average direction of these currents were 158.3 and 159.3°, respectively. Based on an analysis of measured currents at the drillsite, the time of slack water at the location occurred about two hours later than the predicted time of high and Iow tide (slack water) for the Drift River terminal. The individual current profiles are presented in Figure 3. Figure 4 shows the plots of current versus elapsed time for the individual depths. In these plots, elapsed time is the time in hours since the first current measurement was taken. The first measurement was taken at 13:15 hours on August 17, 1990. Thus "zero hour" would be 13:15 on 8/17/90 and data for the 18th of August would begin at 10.75 hours of elapsed time. The data is presented in this format to allow for the plotting of the time shift between the beginning of a run and the end. Plotting each depth at the same time would tend to hide the difference with depth in when slack tide occurs. Figure 5 shows a plot of currents at the drillsite as a function of the predicted tide at Seldovia. Two maximum flood and two maximum ebb for both surface and at mid-depth are plotted against the corresponding Seldovia tide. From this curve, a current at the drillsite can be estimated from the tide range at Seldovia. -12- 0 -10 -20 -30 -40 -50 -~0 -70 -90 -100 -110 -120 -130 -140 -150 0 -10 -20 -30 -40 -50 -50 -70 -80 -90 -100 -110 -120 -130 -140 -150 0 -lO -20 -30 -40 -50 -60 -70 -90 -100 -110 -120 -130 -140 -t50 18/17/90 i 1 1315-1325ADT 0 -10 -20 -30 -40 -50 -50 -70 -80 -90 -100 -110 -120 -1~0 -140 -150 Current (Knots) ....... ! ! [ 3 -3 -1 1 ,~ $/17/9o 1340-13M ADT Current (Knots) 8/17/90 14.,t0-1452 0 -10 -20 -30 -40 -50 -50 -70 -~0 -90 -100 -110 -120 -1,30 -140 -150 Current (Knots) 8/17/90 15.10-1552 AOT Current (Knots) -4O -50 -60 -70 -60 -go -100 -110 -120 -130 -140 -150 1830-1~ ~ 8/17/I0 Current (Knots) 1730-1754 Figure 3. Current Profiles for ARCO Sturgeon No. 1 Location. -13- Current (~-"~S) 0 -10 -20 -30 -40 -50 -?0 - 120 -140 -150 , ,, -3 -1 8/~7/9o i 1 lg22-1941 ADT -110 -120 -130 -140 -150 Current (Knots) i e/17/go 2016-2048 0 -10 -20 -30 -40 -50 -60 -70 -110 -120 -130 -150 0 -10 -20 -40 -50 -70 -100 -11o -120 -130 -t40 -150 Current (Knots) EBB Fl.000 8/17/90 2121-21,38 ADT 0 -10 -20 -40 -50 -60 -70 -80 -go -100 -110 -120 -1,,~ -140 -150 Current (Knots) E88 ~(X~ i ! -1 e/~7/go 1 2221-2,240 ADT Current (Knots) EBB 8/17/902321-233~ ADT 0 -10 -20 -30 -40 -50 -60 -70 -go -100 -110 -120 -I~0 -140 -150 Current (Knots) 1/11/l~ ~17-'0041 ~ Figure 3. Current Profiles for ARCO Sturgeon No. 1 Location (Cont'd). -14- 0 -10 -20 -30 -40 -50 -60 -70 -80 -90 -100 -110 -120 -130 -140 -150 Curre~"~,nota) -1 1 8/18/90 0120--014~ .N)T 0 -10 -20 -30 -40 -50 -50 -70 -100 -110 -120 -130 -140 -150 _ Current (Knots) -1 8/18/90 0516-054,1 N~T i 0 -10 -20 -40 -50 -60 -70 -100 -110 -120 -130 -140 -150 0 -10 -20 -30 -40 -50 -60 -70 -~0 -g0 -100 -110 -120 -130 -140 -150 Current (Knots) 1 061 t-0~35 ADT 0 -10 -20 -30 -40 -50 -~O -70 -80 -90 -100 -110 -120 -130 -140 -150 Current (Knots) ! 8/18/g00715-0751 Current (Knots) e/le/ee ,,i 1 oe,le-og I7 ~ , ! o -lO -20 -30 -40 -50 -60 -70 -8o -go -1oo -11o -120 -130 -140 -I~4 Current (Knots) Figure 3. Current Profiles for ARCO Sturgeon No. 1 Location (Cont'd). -15- 0 -10 -20 -30 -40 -50 -60 -70 -80 -<JO -100 -110 -120 -150 -140 -150 0 -10 -20 -30 -40 -50 -70 -80 -90 -100 -110 -120 -130 -140 -150 Current (Knots) [ e/le/9o 1 1122-11,TS N}T 0 -10 -20 -30 -40 -50 -60 -70 -80 -90 -100 -110 -120 -150 -140 -150 Current (Knots) i e/le/~o 1 3 1523-1344N)T Current (Knots) e/18/~o 1218-1510 Figure 3. Current Profiles for ARCO Sturgeon No. 1 Location (Cont'd). - 16- --1 --2 i ! ] ] ! i ] [ ! [ 4 8 12 16 20 24 Elapsed Time (Hfs) ~2 --2 --3 2.5 ft o _ 0 Figure 4. -I-- .4- I I ' I ' I I , I' ' ! I I [ 4, 8 I 2 I 6 20 24 Elapsed Time (Hfs) 50 ft o i i i i i ' ' i I i [ i i Current Versus Elapsed Time at ARCO Sturgeon No. 1 Location. -17- --1 --2 --3 i i i [ [ i i [ i , 8 12 16 20 24 1 O0 ft --1 --2 2 - x x x x x [ i i i [' i i ! i i i [ ' 4 8 I 2 I 6 20 24 --1 --3 Figure 4. 2 -- 135 ft '" · ! ! '[' ! i ! T ! ! ' T ,~ 8 12 I $ 20 2,~ EIoG)led Time (Hrl) Current Versus Elapsed Time at ARCO Sturgeon No. 1 Location (Cont'd). -18- 150 ft 2 ~ QC~ 4 8 12 16 20 ~4 Elopsed T~rne Figure 4. Current Versus Elapsed Time at ARCO Sturgeon No. 1 Location (Cont'd). - 19- Current Speeds (Peak Measured) 3.5 -- ~ 2.5 -- 1.5 -- I__ 0o5 -- 0 0 -t- Surface Mid 4 8 12 16 20 24 Seldovia Tide Range (Ft) Figure 5. Observed Current at ARCO Sturgeon No. 1 Drillsite plotted against Seldovia Tide Range. 6.0 CONCLUSIONS The seabed in the area of the ARCO Sturgeon No. 1 location is covered with coarse sand and fine sand (Units 2 and 3). These units are relatively thin (probably less than 15 ft in total maximum thickness). The underlying sediments (Unit 1) consist of dense sands and/or gravel and exhibits a thickness up to 400 ff. The high resolution seismic reflections records indicate no areas of signal attenuation indicative of acoustically turbed sediments having a high compressibility due to interstitial gas bubbles. No near surface expressions of faulting were detected. Water depths in the area of the ARCO drillsite ranged from -129 ft to -147 ft MLLW. Significant topographic ridges exhibiting up to 10 ft of relief occur in the vicinity of the drillsite. These ridges appear supported by resistant ledges of Unit No. 1. Maximum current observed in the drillsite area was 2.7 knots. During periods of maximum tidal excursions, the current could be expected to be slightly greater than 3 knots. Slack water at the ARCO Sturgeon No. 1 location typically occurs between 1.5 and 2.0 hours later than predicted slack water at Drift River Terminal. Seabed and sub-seabed conditions revealed by these surveys indicate the sediments will provide a stable foundation for a jack-up drilling vessel. Leg penetration is estimated to be minimal. Some scour of newly disturbed material may be expected during the first period of maximum tidal excursions after elevating the drilling platform. - 21 - ARCO Alaska, In( Post Office =ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 15, 1991 Mr. David W. Johnson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: After Drilling Site Clearance Report ARCO Sturgeon #1 ~'o- ~ Dear Commissioner Johnson: Enclosed, please find a report entitled "Results of Side Scan Sonar Survey, Arco Alaska-Sturgeon Well Site, Cook Inlet, Alaska" performed by EBA Engineering. The survey was performed in late October as final preparations were made to move the Glomar Adriatic VIII back to Seward. The purpose of the survey was to document the seafloor condition at the Sturgeon #1 exploration drill site as required by 20 ACC 25.172. (b). The final abandonment of the well was detailed in previous corrospondance. A portion of the abandonment activities were witnessed by Blair Wondzell of your office. The RKB to mudline measurement at the site was 255'. The casings were cut at the following RKB depths and recovered: 30"--273' 20"--285' 13-3/8"--289' 9-5/8"--600' The sonar scans verified no casing remained above the mud line. As expected, the only visable items were the sand bags and blocks placed to stabilize the Inlet bottom around the rig spud cans. If you have questions or require any additional information, please contact Tom Maunder at 263-4971, Mike Winfree at 263-4603 or myself at 263-4970. Sincerely, Richard F. Morgan Regional Drillin..: 71}991 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /',t~:~l; ~; ~:'. ~; Arco Alaska Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attn' Mr. Thomas E. Maunder IGINAL Results of Side Q;~rl Sonar Survey Arco Alaska- Sturgeon Well Site Cook Inlet, Alaska 0268-0174 f ~, o From: EBA Engineering Inc. 907 E. Dowling Road Suite 27 Anchorage, Alaska 99518-1427 December 21, 1990 Copyright © 1990 by EBA Engineering Inc. This document may not be reproduced in whole or in part by any means whatsoever, nor may it be quoted or excerpted for any reason, without the express written consent of EBA Engineering Inc. Results of Side Scan Sonar Survey Arco Alaska - Sturgeon Well Site Cook Inlet, Alaska 1.0 2.0 3.0 4.0 Table of Contents INTRODUCTION 1.2 Purpose and Scope of Services SITE INVESTIGATION 2.1 Operational Summary 2.2 Geophysical Survey 2.3 Positioning DISCUSSION 3.1 Observations of Seafloor Scour 3.2 Observations of Man Made Objects CLOSURE Page 1 1 RECEIVED JAN 17 1991 EBA Engineering Inc. Geotechnical and Materials Engineers Arco Alaska Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Attention: Mr. Thomas E. Maunder Senior Drilling Engineer December 18, 1990 0268-0174 Results of Side Scan Sonar Survey Arco Alaska- Sturgeon Well Site Cook Inlet, Alaska Gentlemen: This letter report transmits the results of EBA Engineering Inc.'s technical services at Arco Alaska's Sturgeon Well Site located in Cook Inlet, Alaska. EBA Engineering Inc. was retained by Arco Alaska Inc. to provide offshore technical services at the Sturgeon No. 1 Well prospect located in Redoubt Bay, Alaska, Figure 1. These services included and were limited to performing a side scan sonar survey at the Sturgeon location upon completion of Arco's onsite operations. Our services were verbally authorize~'~lr. Thomas E. Maunder of Arco, Alaska on October 17, 1990. During the performance of our study EBA Engineering Inc. subcontracted the services of Watson Company, LCMF, and Martech USA Inc. to provide operational support. EBA appreciated the guidance and input Mr. Maunder provided during our study. This report inCludes an operational summary, selected images from the side scan sonar survey, and observations and interpretations of the data collected by EBA. In addition we have prepared general comments and recommendations based on our observations for future sitings of Global Marine's jack-up drilling unit "Adriatic VIII" in Cook Inlet, Alaska. EBA Engineering Inc. performed this work in a manner consistent with the level of skill ordinarily exercised by members of the profession currently practicing under similar conditions. No warranty, express or implied, is made. This report is intended for use only in accordance with the purpose and scope of the study described below. 907-East Dowling Road, Suite 27, Anchorage, Alaska 99518 · Telephone (907) 561-4085 · FAX (907) 561-7071 · 0268-0174 Page 2 1.2 Purpose and Scope of Services EBA Engineering Inc, understands the purpose of our study was to: · Investigate the scour around the spud cans of the "Adriatic VIII", and · Investigate the seafloor at the Sturgeon Well Site for man-made objects that may have been left after drilling was completed and the "Adriatic VIII" was demobilized. To fulfill the purpose of this study, EBA's scope of services consisted of performing a side scan sonar survey while the jack-up drilling unit "Glomer Adriatic VIii" was on location, and a second survey immediately upon its departure to investigate seafloor conditions. 2.0 SITE INVESTIGATION 2.1 Operational Summary The side scan sonar survey of Arco's Sturgeon Well location in Redoubt Bay was performed in conjunction with a bathymetric and sonar survey in Seward, Alaska for winter storage of the "Glomar Adriatic VIII". Upon completion of the site survey in Seward on October 22, 1990, EBA mobilized its personnel and equipment to Homer, Alaska. Prior to mobilizing a vessel and equipment to the Sturgeon Well site, EBA and LCMF re- established the navigational net used during setdown of the "Adriatic VIII". EBA mobilized side scan sonar and navigational equipment onboard Martech USA Inc's vessel the "Glacier" in Homer. The vessel was ready to depart Homer at 23:30 hrs on October 22, 1990, however gale force winds and high sea states forced the vessel to standby in the Harbor until 0600 hrs on October 23, 1990. EBA arrived in Redoubt Bay at the Sturgeon Well location at approximately 1500 hrs on October 23, 1990, and proceeded with a side scan sonar survey of the well site while the "Adriatic VIII" was still on location. The "Adriatic VIII". was then demobilized and a final side scan sonar survey was performed over the rig footprint. The site survey was completed and the "Glacier" returned to Homer at 0200 hrs on October 24, 1990. The vessel arrived at the Homer dock and EBA's equipment and personnel were demobilized from the vessel by 1200 hrs on October 24, 1990. A time and event summary has been prepared and is presented in Attachment A of this report. 0268-0174 Page 3 2.2 Geophysical Survey The'high resolution geophysical survey performed at the Sturgeon Well location by EBA Engineering was limited to side scan sonar only. The side scan data was collected by Watson Company using a modified EGG 260 side,scan sonar system. The data was recorded for post processing off the vessel. 2.3 Positioning LCMF provided positioning services in support of the side scan sonar survey. LCMF reestablished the same survey net used during the setdown of the "Adriatic VIII" and utilized the same positioning specialist. Positioning during the side scan survey was performed by range-range techniques from three geodetic benchmarks on the west side of Cook Inlet in the Redoubt Bay area. The range- range system provided by LCMF was a Falcon Mini- Ranger IV (MRSIV). Accuracies of the MRS IV system are typically _+3 meters (+10 ft.). 3.0 DISCUSSION Arco Alaska Inc. requested the data be processed and presented to allow a performance review to assess the cause of the scour experienced around the spud cans and the resulting settlements of the legs while the "Adriatic VIII" was on location. In addition to the review of the scour, Arco also was concerned if any man-made objects that may have been left on the seafloor after the demobilization of the drilling unit were visible in the sonar records. We have presented our side scan sonar images, and our observations in the following subsections of this report. EBA did not receive any existing data from Arco Alaska that may have been collected during the site clearance programs. The discussion presented is based solely on the data collected during EBA's side scan sonar survey. 3.1 Observations of Seafloor Scour The sonar images prepared to investigate the scour at the Sturgeon location are presented as Figures 2 through 5. We have prepared a brief discussion of our observations for each figure. Figure 2, illustrates the orientation of the "Adriatic VIII" with respect to the seafloor conditions. Spud Can #1 would coincide to the stern starboard leg, and spud can #2 would represent the stern port leg. The principal bottom current direction is north to south. The area immediately behind the bow leg, not labeled, shows a significant change in the sand waves present on the seafloor. 0268-0174 Page 4 Figure 3, illustrates a zoom of the seafloor conditions behind the port leg from Figure 2. The spud can imprint and scour can be approximately scaled to be 11.8 meters (35 ft.) across. The sand waves are approximately 6 to 10 meters (18 to 30 ft.) from crest to crest and approximately 2 to 4 meters (5 to 12 ft.)in height. Figure 4, illustrates the effect on natural bottom sediments due to the acceleration of the seafloor currents associated with the vortex created down current behind the bow leg. The slumping area appears to coincide with the outer limits affected by current acceleration and scour. The area labeled "recent deposition" would be related to the slack current in the vortex behind the bow spud can. Figure 5, is a presentation of the data by shape through shading techniques. Figure 5 illustrates the area of the seafloor sediments down current of the jack up drilling unit affected by the scour. In summary, the scour appears to have been enhanced by the acceleration of seafloor current velocities in an area already experiencing a heavy and active bedload movement. The settlements reported by Arco of the spud cans could be attributed to the fact that as the sand was scoured from below and around the spud cans, the bearing capacity of the existing soil was altered allowing penetration of the spud can to settle into the underlying less erosive sediments. The continuing settlements reported by Arco during drilling operations could be associated with rig activities varying the deck loads. The settlements associated with active deck loads normally are minimized or eliminated during the set down pre-loading procedures, as the pre-load weight is typically greater than the anticipated working deck loads. 3.2 Observations of Man Made Objects Arco also requested that the side scan data within the footprint of the jack-up drilling unit be processed to determine if any man-made objects were left on the seafloor after the drilling unit was demobilized. Figure 6, provided to EBA by Arco Alaska is the final dive report from Underwater Construction of the sandbags and concrete blocks (4 ft. X 4 ft.) placed around the spud cans during the scour protection operations. The sonar images prepared to investigate the presence of man made objects at the Sturgeon location are presented as Figures 7 through 13. We have included a brief discussion of our observations. Figure 7 and 8 illustrate the seafloor and the location of the spud cans. The seafloor was "normalized" through the color pallet. This processing technique enhances sonar reflectors 0268-0174 Page 5 stronger than the "normal" seafloor by showing them as yellow, orange, or red in color on the image. The red pallet would represent the strongest return similar to what would be expected for metal. Figure 9 through 13 are representative zooms of the seafloor around the three spud cans. Depending on the accuracy of the as built survey of the bagging operations performed by Underwater Construction's divers, most of the objects appear related to the sand bags and blocks. The strong red returns appear to correlate with the location of the 4 ft. X 4 ft. concrete blocks placed on the seafloor. EBA understand the concrete blocks had metal pipe and wire rope leads protruding from the top of the blocks. There are some strong returns that may also relate to the bagging operations that were not included in the as built survey. A moderately strong reflector appearing as a white image on Figures 9 through 13 is present in front of the spud cans as well as in the general vicinity of the foot print of the drilling unit. This possibly could correspond to a hard clay layer or denser sediments resulting from altered seafloor conditions associated with the scouring. 4.0 CLOSURE EBA Engineering Inc. appreciated this opportunity and continues to remain available to assist Arco Alaska Inc. with their offshore operations in the Cook Inlet, Alaska. Should you have any questions or require any additional assistance please do not hesitate to contact the undersigned. Ku~~O ~Stang Presid~nStt~~g Sincerely, EBA Engineering Inc. Michael G. Schlegel Project Director Attachments: Figures 1 to 13 Attachment A- Time and Event Summary T5N, R17W, SM Sec. 19 3130' I I Sec. 25 I I I 486'' , I ! I I I I I ................. I' ................ -- I I I I I I I I I Sec. 26 I I I I I I I I ADL 359110 Well Operator Rig Heading Area ARCO Sturgeon No. 1 Arco Alaska Inc. Glomar Adriatic VIii 199 Degrees True Sec. 25, T5N, R17W, SM Redoubt Bay, Alaska ADL 359110 Scale: 1' = 1/2 mile 1. Location of well site was accomplished by using trian- gulation stations "North Kalgin","Redoubt Bay N. Base' and "Harriet Point Light". 2. All dimensions and coordinates are in feet. ALASKA STATE PLANE COORDI~~ ZONE 5, IN FEET. REFERENCED TO NAD27. Y = 2,377,047 X = 830,176 GEODETIC POSITION UTM ZONE 5, Meters Lat. 60° 29' 38.09" N. N. 6,706,502 Long. 152° 10' 07.76." W. E. 545,669 Center of the derrick is located 486 feet west of the east line and 3,130 feet south of the north line of protracted section 25, T5N, R17W, SM, in lease ADL 359110. ! hereby certify that I am properly registered and licensed to practice land surveying in the Sate of Alaska and that this plat represents a location survey made by me and all dimensions and other de~ails are correct. Date Lawrence M. Whiting, LS 7618 EBA Engineering Inc. ' ' Location Survey For ARCO STURGEON No. 1 Section 25, T5N, R17W, SM REDOUBT BAY, ALASKA ADL 359110 ii I I I i ARCO ALASKA INC. II Positioned By NCS International Anchorage, Alaska Houston, Texas FIGURE I EBA E~3g~'~3ee~-ing ~nc. ~ F~{~U~E 3 IU I ,ffalA al¥O 01 931 A0g I I I I dL I II I I I _ 11 I I I I IIIII I I I . 11 l~10d N~S ILLUON sm,,~ 91U GUVOgU¥1S NU31S .iII]A SLl, Vili;. ;166111gd 111g Ilia 31~V~ ' ' OltJ~lJr0t :13¥/H03 :HOLLY'O0't :3.LYO OUO:)3U NO IJ.YIlD'FV'3 ' NOIJ.~IU.L6'N03 tI[31YAt:J3(II~ I Ill Il I II . Ill '~!o '~J.~ IIOJJI011 i ii _ ~d .... . I II _ _ Il '11~ Illl II II _ I Ill II [] I I I Ill 10/18/90 1500-1700 10/19/90 0800-1000 1000-1400 1400-1800 0800-1400 1400-2000 past 2000 10/21/90 0800-0900 0900-1500 1600-1900 10/22/90 0700-0800 0800-1200 1200-1700 1700-21 O0 10/23/90 0600 TIME AND EVENT SUMMARY ARCO ADRIATIC VIII RIG MOVE Mobilization. Purchase and assemble materials for field operations. Mobilization. Get crew together, load gear and equipment. Travel, drive from Anchorage to Seward. Contact vessel operator, inspect vessel, demobilize gear, meet with Arco representative Tom Maunder. Set navigation land stations. Mobilize equipment onto vessel and rig gear for operations. Oceanographic surveying of the Seward site. Data reduction and evaluation. Service equipment, prepare for ocean surveying. Oceanographic surveying of Seward site. Demobilize vessel, take down navigation stations. Mike Schlegel flies to Anchorage to prepare bathymetry and side scan sonar data for presentation to ARCO on 10/22/90 in Anchorage. Loaded equipment, mobilized for trip to Homer. Travel; drove from Seward to Kenai. Standby for Schlegel to arrive at Kenai airport from Anchorage. Whiting and Benson took ARCO helicopter from Kenai to set navigation stations on west side of Cook Inlet, then drove to Homer. Schlegel and Watson drove to Homer aand met captain and inspected MARTECH vessel the "Glacier" Mobilized equipment onto vessel. Standby overnight in Homer due to storm conditions in Cook Inlet. Left Homer harbor for the Sturgeon site. 1500-1800 1800-2200 2200-0200 0200-1000 1000-1230 1330-1515 1515-1645 1645-1900 1900-2100 10/25/90 09O0-13O0 Performed side scan sonar oceaographic survey of Sturgeon site while the Adriatic VIII was still in on location. Reduced and interpreted side scan sonar data. Standby for Adriatic VIII to move off site. Performed side scan sonar survey over the location of the Sturgeon site after the Adriatic VIII had been moved. Vessel traveled back to dock at Homer harbor. Demobilized and packed equipment. Demobilized gear from vessel at Homer Dock. Drove form Homer to Kenai. Whiting and Benson took ARCO helicopter from Kenai to west Cook Inlet to pick up navigation stations. Schlegel and Watson drove to Seward. Schlegel and Watson met with Arco and Glomar representatives at New Seward Hotel and presented oceanographic survey results. Whiting and Benson drove to Seward. Arco decides job is complete. Demobilize project to Anchorage. Schlegel drives back to Anchorage to meet ARCO representitive on 10/25/90. Whiting, Watson, and Benson drive form Seward to Anchorage and demobilize equipment and gear. ...... ~ ............... ~~~MATIEIRIA!_.S INVENTORY LIST/x} '~~~ .._~chcck off ~r Iis~dat~ as'i~ is ~ccivcd ~ corcd inter, Is . dry.ditch ilitclvals ......... di_~ilpl data ":"-' ~ ............ ~LOG ly'~j,E .......... RUI',I ........ : ........ [I"iTE J/V"~LS .... SCALE NO. ......... ~-;1 , .. ,. J " ........................................... ............ 71 ~. ', " S" .................................... ........ ~ .................. ............................................... _'0]~~.-~.~~~, ~ ~~, _ ~,., ~- ~i~'}- st.~/,~F~ ~ 4-~,./. ~ , · '- ~,, ............ ~ r~ ~2 ~ ~ r~ ........... ~ ~,, ......... .~ ~.~ - ............ · , ..... COMPLETION DATE / o ! ~2 !~ CO. CONTACT AOGCC GEOLOGICAL MATEFIIAL$ INVENTOFI¥ UST LOG TYPE RUN INTERVALS SCALE NO. '~71 ARCO Alaska, I'~-'''~ Post Offi~. ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 31, 1990 Lonnie Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Request For Approval of Plug and Abandonment Procedure ARCO Sturgeon #1 Dear Commissioner Smith, ARCO Alaska, Inc. requests the AOGCC's approval of its plans to plug and abandon the Sturgeon #1 well in Cook Inlet. Attached find an Application for Sundry Approval (Form 403) for this work. In addition, the following are enclosed: Well Schematic: Condition Prior to Proposed Abandonment Plug and Abandonment Procedure Well Schematic: Condition After Proposed Abandonment ARCO's Mike Winfree discussed these abandonment plans with you on October 13 and you verbally approved them with the condition that the top abandonment plug's placement and testing be witnessed by an AOGCC representative. The top plug was set and tested on October 16 and was witnessed and approved by the AOGCC's Blair Wondzell. If you have questions or require any additional information, please contact W. J. (Bill) Penrose at 263-4511 or myself at 263-4970 in our Anchorage office. Sincerely, Richard F. Morga~ Regional Drilling Engineer RECEIVED oil & cons. :' ~chora~ '~ ARCO Alas~(a, inc. is a Subsidiary of Atlan/icRichfieldCompany /V, ;It i;;),:} t (; ,SKA OIL AND GAS CONSERVATION CO, SSION APPLICATION FOR SUNDRY APPROVALS 1. T~,pe of Request: Abandon X Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate B Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development _ ARCO Alaska. Inc. Exploratory ;~ RKB 255' AML feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. BOX 100360, Anchorage, AK 99510 Service _ N/A 4. Location of well at surface 8. Well number 3130' FNL, 486' FEL, SEC 25, T5N, R17W, SM Sturaeon #1 -- At top of productive interval 9. Permit number (Straight Hole) 90-80 At effective depth 10. APl number 50-733-2041 8 At total depth 11. Field/Pool Wildcat 12. Present well condition summary Total Depth: measured 7206' RKB feet Plugs (measured) true vertical 7206' RKB feet Cement retainer @5658' w/cmt above & below. Effective depth: measured 5563' RKB feet Junk (measured) true vertical 5563' RKB feet N/A Casing Length Size Cemented Measured depth True vertical depth Structural 359' 30" driven 401' RKB 401' RKB Conductor 1,228' 20" to surf. 1270' RKB 1270' RKB Surface 2,642' 1 3-3/8" to surf. 2684' RKB 2684' RKB Intermediate Production 6,683' 9-5/8" to 3580' 6717' RKB 6717' RKB Liner Perforation depth' measured 5688-5724, 5735-5822, 5826-5838, 5872-5882 (squeezed) 5232-5260, 5312-5335, 5352-5392 (Open) R~CEIVED true vertical Same as measured depth Tubing (size, grade, and measured depth N/A ~,j{~)!~ (j ,? Packers and SSSV (type and measured depth) N/A '~;~$~l_OjJ.~ GaS COILS. 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP ~{~'~a.._~~3 14. Estimated date for commencing operation 15. Status of well classification as: 10/14/90 Oil __ Gas _ Suspended X 16. If proposal was verbally approved Lonnie Smith 1 0/13/90 Name of approver Date approved Se rvice 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig ned~~ ~'~~ ~,.F. '~~{~.-,' TitleRec, lional Drillincj Encjineer Date ~ " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprov~J No. Plug integrity __ BOP Test _ Location clearance ~ I .~ 0 -~' ~ MechanicalInte~N~'~~i Itff~tE0 I~Y Subsequent form require 10- /''''~? c. Approved by the order of the Commission Commissioner Date [ I Apptc. vcd Copy Form 10-403 Rev 06/15/88 ~..~,,,.,,~.~ SUBMIT II~'TRIPLICATE ARCO Sturgeon #1 Condition Before Abandonment (All Depths RKB) Mud Line @ 255' TOC @ ~295' 30" shoe @ 401' 20" shoe @ 1270' 13-3/8" shoe @ 2684' TOC @ 3580' 5232'-5260' Perfs' 5312'~5335' 5352'-5392' TOC @ 5563' BOC @ 5882' Cmt retainer @ 5658' Perfs: 5688'-5724' 5735'-5822' 5826'-5838' 5872'-5882' 9-5/8" shoe @ 6717' Well TD @ 7206' PLUG AND ABANDONMENT PROCEDURE STURGEON #1 After completing the drill stem testing of the well, the perforated interval 5232'-5392' will be isolated and the well abandoned as follows: . RIH with 9-5/8" 47#/ft EZSV on Schlumberger wireline. Set the EZSV at 5200' (32' above the top perforation.) POH & R/D Schlumberger. 2. Change rams to 5" and test the bonnet seals. , RIH with Halliburton EZSV stinger on 5" drill pipe. Sting into the EZSV @ 5200'. Weight-test the EZSV w/20K# down weight. With weight still on the EZSV, pressure test the seals with 1000 psi. Release pressure. . Sting out of EZSV. Circulate produced formation fluid to the stinger using Halliburton cementing unit (approx. 92 bbl). Sting into the EZSV. Pressure up the 3 1/2"X 5/8" annulus to 500 PSI with the rig pumps and monitor. With the pressure trapped on the backside, inject the produced fluid into the perforations. Do not exceed 1400 psi. 5. Follow the formation fluid with a 20 BBL fresh water spacer. . Mix & pump cement based on the following calculations: volume of 9-5/8" csg 30' above the perfs; 160' of perfs; 100' below perfs = 290' =120 cuft of slurry. The cement blend is as follows: Class G + .20% CFR-3 + .10 gal/sk Halad 344L +.20% HR-7. The yield is 1.15 cu ft/sk. Slurry wt. is 15.8 PPG. The sack vol is 104 sacks. Pumping time is 4 hrs 44 min. Fluid loss is 85 mi @ 145 deg. F. NOTE: Do not exceed 870 psi while displacing and squeezing cement. 7. Follow the cement with a 20 BBL fresh water spacer. 8. Displace and squeeze cement with 72 bbl of 9.3 ppg brine. 9. Sting out of EZSV. Monitor check valve in EZSV. 10. Reverse out cement w/ 140 bbl. (1-1/2 DP capacity). 1 1. POH, laying down all but 700' of drill pipe. 12. Pressure test 9-5/8" abandonment plug by closing blind rams and pressuring up to 2000 psi for 10 minutes. Record pressure test on chart recorder and submit to AOGCC via fax. 13. RIH w/ all 3-1/2" tubing and 6-1/2" drill collars. POH, laying it all down. 14. M/U Tri-State 9-5/8" casing cutter and RIH to 600'. Cut 9-5/8" casing. POH. 1 5. Break BOP stack at top wellhead flange and P/U. 1 6. Remove top casing spool and 9-5/8" casing packoff and set aside. 17. Tack-weld 9-5/8" casing hanger slips to 9-5/8" casing. Ensure 9-5/8" X 13-3/8" annulus valve is open and back out lock-down screws. 19. 20. 21. 22. 23. ¸24. 25. 26. 27. 28. 29. N/U BOP stack to wellhead. RIH with 9-5/8" casing spear and pull casing stub. (DriI-Quip mudline hanger will require 30-50,000 lbs overpull to unseat.) RIH with 13-3/8" cement retainer on drill pipe. Set retainer at 500' RKB. Squeeze 15 bbls of cement slurry, (73 sacks Class G mixed w/ .10% HR-7, .25% CFR-3, 5.00 gal/sk mix water. Mixed at 15.8 ppg with a yield of 1.15 cu./ft, sk.), below retainer to isolate 9-5/8" casing and 9-5/8" X 13-3/8" annulus. Pull off of retainer and place 15 bbls of cement slurry, mixed as above, on top of it. This will place a cement plug of at least 150' in length just below where the casing will be cut and pulled (State Regs). POH to 300' RKB and reverse out. Continue reversing until returns are clean. Test plug integrity by pressuring up to 2000 psi for 10 minutes. POH. N/D BOPE and wellhead equipment down to the 20" starting head. Ensure 13-3/8" X 20" annulus valve is open before backing out 13-3/8" casing hanger lock-down screws. M/U Tri-State multi-string casing cutter with 13-3/8" cutters installed and RIH to 290'. Cut, spear and recover 13-3/8" casing stub. This will leave the 13-3/8" casing cut off at 35' BML. Change casing cutter knives to cut 20" casing and RIH to 285' RKB. Cut, spear and P/U on 20" casing stub. Cut off 20" SOW wellhead. Recover the 20" casing stub. This will leave the 20" casing cut off at 30' BML. Cut starting flange off of 30" structural casing. Change casing cutter knives to cut 30" casing and RIH to 280' RKB. Cut, spear and recover 30" casing stub with overshot. This will leave the 30" casing cut off at 25' BML. Rig down, stow conductor support platform and prepare rig for tow. 0 0 0 o i ! o n ,4--.* E '~ ~' '- o ~ ~ TO: THRU: FROM: ALAg?~!~' OIL AND GAS CONSERVATIOF :~, fISSION MEMORANDUM Commis sione~/ ~ St ,e of Alaska DATE: October 17, 1990 FILE NO: A.BEW. 162 TELEPHONE NO: SUBJECT: Plugging for abandonment ARCO Sturgeon #1 Cook Inlet Wildcat Blair E Wondz~i Sr Petr Engineer Tuesday, October 16, 1990: Le['t the office at 8:45am; went home to ~h-~-~e ~c~iOthes; depart-~'d" Anchorage for Kenai on ERA' s 9: 45am flight. Arrived Kenai about 10:20am and the Glomar VIII at ll:30am. Met ARCO's Bill Penrose, Sr Drlg Engr, and Gene Cooper, Sr Drlg Spvr. The 9 5/8" had been cut and recovered from 600', and a Halliburton ESV retainer (sliding sleeve type) had been set at 500.34'. After setting, the annulus was pressured to 500 psi and 10,000 lbs was sent on the ESV to ensure its integrity. After pumping away pit fluids, they pumped a 20-bbl water spacer, 15 bbls of cement below the retainer, pulled up 5' and circulated 15 bbls of cement on top. Pulled ~u~ about 200' and reversed out (the cement contained .25% CFR3 and 0.~Zo HR7 -- the formation temp was 140°F at 1300") CiP @ 3:30pm. They closed the pipe rams and started to pressure up. At about 1500 psi the d.p. jumped about 15'. The rams were opened, the pipe lowered, the rams closed and the pipe raised until the collar caught on the rams. The casing was pressured to 2000 psig @ 4:06pm; the pressure held for about two minutes, then started dropping. The casing was repressured to 2000 psig at 4:14pm and started dropping immediately. They found a leaking flange on the well head (had been removed that morning). The flange was tightened. The well was again pressured to 2000 psig @ 4:48pm; this time it held. (See attached chart.) We concluded the pressure test @ 5:00pm. I checked the cement samples; they were settling out. Summa_~: i witnessed the successful placement and testing of the cement plug across the 9 5/8" casing stub, the integrity of the ESV @ 500'~ the cement placed on top of it; and the successful pressure test of the 13 3/8" well bore plug. At tachmcnt / 02-001A (Rev. 6/89) 20/11/MEMO1.PM3 "500, op~i // ×/ / 0006- / 000 500 2000 / 10500 ,' -11500 O00Z // 00~8 0008. ARCO Alaska, Inc. Post Office Bo,, Telephone 907 278 t2'15 SAMPLE TRANSMITTAL TO: State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 DATE: 1 0-5-90 AIRBILL #: AL510126 AFT#: 0- 10-05-44 CHARGE CODE# AD 6943 OPERATOR: Arco NAME' Sturgeon SAMPLE TYPE: Core Chips & Dries SAMPLES SENT: NUMBER OF BOXES: CORE CHIP DEPTHS Eleven boxes of dries: 7176 7177 7178 7179 7180 7181 7182 7183 7184 7185 7186 7187 7188 7189 7190 7191 7192 7193 7194 7196 7197 7198 7198 .: 7199 7200 7201 7202 7203 Box 1 Box 2 Box 3 Box 4 (Duplicate) 1300-1960 1960-2695 2695-3930 3930-4610 ARCO Alaska, !nc. is a Subsidiary of AtlanticRichfieldCompany Att31l fi0(¥~ C Box 5 Box 6 Box 7 Box 8 Box 9 Box 10 Box 11 4~ .5140 5140-5630 5630-5930 5930-640O 640O-679O 6790-7150 7150-7200 SENT BY' Dan Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ArcoAlaska, Inc. P. O. Box 100360 Anchorage, AK. 99510 Attn: ABV-100 RECEIVED B '- DATE- RECEIVED 03T o 9 1990 ;,*~,.Ojl & 6as Cons. 6olllfllJsSli:'., ~ , Anchorac~a Consulting and Engineering 750 West Second Avenue, Suite 100 Anchorage, Alaska 99501 Telephone (907)276-4302 Letter of Transmittal Attention: ~'~',u/~' ~--~, ~/z-,~/' Date: We are sending you the following: Project: Copies Date No. Description Remarks: TO: THRU: FROM: MEMORANuUM Stale of Alaska ALASF~ OIL AND/~AS CONSERVATION COMMISSION Lonnie C. Smit~~/ DATE: September 18, Con, his sioner / c~ FILE NO: JT. DA. 918 1990 TELEPHONE NO: Doug Amos ~ Petroleum Inspector SUBJECT: BOPE Test AAI Sturgeon No. 1 Permit No. 90-80 Exploratory Sec. 25,T5N,R17W,S.M. Tuesda~ Sept. I1, 1990: I traveled this date from Anchorage to AAI' Sturgeon NO. w~ -~c-~ witness the BOP test on Glomar's Jack-up rig, the Adriatic VII. Due to rig. settling and casing head proBems, the testing was delayed. Wednesday Sept 12, 1990: The testing commenced at 2:00 p.m. and was h-~nc--~~d-~t--~~ight. The two choke manifold valves and the T.I.W. floor valve that failed this test were repaired and I witnessed their retests on 9/13/90. I inspected the BOP choke and kill lines for threaded connections and found the system to be in compliance. Attached is an AOGCC BOPE inspection Report. In summary: i witnessed the BOP test at AAi's Sturgeon No. 1 well on the Glomar Adriatic VIII jack-up rig. 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION cOMMIsSION BOPE Inspection Report OPERATION: Drlg ~// Wkvr~ Operator Well ~-~I~~Z~J /~J~ Location: Sec ~ T Drlg contrctr Location (general) Housekeeping (general) Reserve pit ~, Well sign Rig MUD SYSTEMS: Visual Trip tank ~,/ Pit gauge ~/ Flow monitor / Gas detectors j DATE TEST: Initial ~ Weekly.~ Representative Permit # ~/~) - /3 ~/~.../[ Casing set V/ll Rep ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Other BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve min ft psig psig sec sec Full charge press attained ? min Audio Controls: Master Remote ,~' B1 i nd switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly l Test pressure Lower Kelly f Test pressure Test Pressure ~~ Ball type / Test pressure / , ~~) Inside BOP / Test pressure !-' Choke manifold ] Test pressure ~' Number valves ~ Number flanges Adjustable chokes / Hydraulically operated choke TEST RESULTS: Failures ~_~ Test time /~ hfs Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) WITNESS. TO: THRU: FROM: MEMORANDUM state of Alaska Lonnie C. Sm~~/'~t// DATE: September 6, 1990 Commissioner / ~ FILE NO: JT. MM. 96 TELEPHONE NO: SUBJECT: Michael T. Minder Sr. Petroleum Engineer AAI Sturgeon #1 BOP Modifications / Diverter Test Permit No. 90-80 Exploratory Sec 25,T5N,R17W, SM Wed. Sept 5, 1990: I arrived on. Glomar Adriatic 8 at 10:45 a.m. and c--~e~d~d~through inspection of BOP systems with company man Bruce Campbell. The required modifications were properly fabricated and are shov~ on attached photbs. The targeting had been completed and the turns in the vent line replaced with targeted 90°s. Hand,er unions were replaced with flanged or welded connections and the nitrogen back-up system had also been installed. It consists of 8 bottles and may be seen on photos. The diverter was installed with 2-12" lines; one to port the other starboard each containing a 12" full opening hydraulically operated ball valve. The lines extended, to the sides of the jack up and are supported only by a telescoping pipe type of brace located about ¼ of the length back from the effluent which was attached to the vent line and suspended from the substructure. See photo. There was a considerable amount of movement fore and aft, induced by the currents on the surface casing. This was why the diverter system could not be anchored aft. The system was functionally tested and operated correctly. However, the toolpusher attempted to conduct this diverter test without a pipe for the annular to close on. This made me wonder whether previous testing had been correctly conducted. Both diverter lines opened automatically when the annular was closed and was capable of being diverted independantly either port or starboard as testing verified. There was one failure on the actuator control; the seals failed and were replaced before testing could be completed. In summary: I witnessed the diverter system being functionally tested successfully and was able to verify that modifications were made properly. Attachments 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~'~-"~-,~L ~NSPECTION REPORT DATE, Inspector Operator N 9,.c,_<2~ Location: Sec R e p r e Se n t a ti v e_ [~_~2o_q._q-_ _Q_o_ _w~_~h.~_~_ ~_ _ _ Permit # ~t~-- 00 "Casing Drilling Contractor (.o__ko~>~.,.\ ~,¢,ex,,e. bc~ Rig. K~~ Representative Location (general) t~.~-~ General Housekeeping Reserve Pit Well Sign Rig MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors BOPE STACK: Annular preventer Upper Pipe Blind/Shear Middle Pipe Lower pipe Choke line valves HCR valve Kill line valves Visual Audio Test Pressure ACCUMULATOR SYSTEM; Full charge pressure Pressure after closure .psig Pump incr close press 200 psig Full charge press attained Controls: Master v/ Remote / Blind Cover KELLY AND FLOOR SAFETY VALVES; psig m s m s Test pressure_ Test pressure_ Test pressure ..... Test pressure_ ___ Test pressure Check valve (._oc' TEST RESULTS: Failures J Upper Kelly ..... Lower Kelly .... Ball type Inside BOP Choke manifold Number of valves Number of flanges Adjustable chokes Hydraulic choke Test time ~.O~.~z._ hours Repair or replacement of failed equipment to be made within days and Inspector/Commission office notified. Distribution: original-AOGCC cc-operator cc-contractor Inspector: _~~ ~~ '{' Inspector STATE OF ALASKA ..¢J,:'A OiL AND GAS CONSERVATION CL ~llSSION BOPE INSPECTION REPORT Ope rato r_~~_.z~~_ w e .... Location: Sec~ T~ R~ Drilling Contractor_~--~__~. t~ ~~ . Location (general) ~ Well Sign General Housekeeping ,----~-' Rig Reserve Pit .kI!~ MUD SYSTEMS_; _..V. isual Test Pressl, l.l~.e_. Trip tank Pit gauge Flow monitor Gas detectors ____ BOPS. STACK: Annular preventer Upper Pipe Blind/Shear Middle Pipe Lower pipe Choke line valves HCR valve KIll line valves Check valve · · ?;'L..~,,,' ,, Casing set @ ~-~.(~'/ ..... Rig_z~ ~ Representative _,~'~~ ...ACC_ UMULATOR SYSTEM: Full oharge pressure. _..., ..5~ .... psig Pressure after closure .... /'~"~ psig Pump incr close press 200 pslg /. m_~_.~s Full charge press attained ~m?~,..s Controls: Master L-.- Remote__~_~ I~llnd Cover_._ KELLY AND FLOOR SAF.....E~ VALVES: TEST RESULTS: Upper Kelly .... Lower Kelly .... Ball type ...... l~side BOP .... · Choke manifold.. Number of valves. Number of flanges Adjustable chokes Hydraulic choke_ Failures__~~_C~_-''_ ..... Test time · Repair or replacemenl of failed equipment to be made within · 'and Inspc,:lor/Commissior~ office notified. Test pressure. Test pressure Test pressure_...___ Test pressure ..... Test pressure__..___ hours days Distribution. originaI-AOGCC cc-operator cc-conlraclor Inspector: Global Marine Drilling Company 600 WEST 41ST AVENUE, SUITE 101 ANCHORAGE, ALASKA 99503 17 August Mr. Lonnie C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 G~R E N__G___~ SR ENG ENG-ASST ~ SR '~-E('31_ ASST! I Reference: (907) 561-2421 FAX: (907) 568-4012 /2-,~ L.,,¢__.. Nitrogen Backup on the BOP Accumulator Unit - Glomar Adriatic VIII Dear Mr. Smith: The Alaska Oil & Gas Conservation Commission (AOGCC) regulations identify a nitrogen backup system requirement on the blow out preventer control system. We are requesting a review of the system on the jackup drilling rig, the Glomar Adriatic VIII, and determination of equivalence. The BOP control system on the Glomar Adriatic VIII is powered by the following sources: Triplex Pumps: Main generator system (five independent generators) Emergency generator D-379 Caterpillar Air Pumps: Two independent electrically driven air compressors powered by the main generator system The above two air compressors are powered by the emergency generator An independent diesel engine driven emergency air compressor We submit that the above redundancy meets the intent of the AOGCC requirement for a backup system for the BOP accumulator system. Yours sincerely, AI. tG221990 Gregory R. Navarre ~ Arctic Operations Manager Al~a0/l&Ga$~~m~~ Global Marine Drilling Company ~chom~ GRN: cd qaAD8AOGCC 'U'D'H )403HO I:ldq "IYFIN¥~ ~ '1VI'IN ¥ IN ~UdN ~ UYqNNNV 'I:I'O'H :a)IOHD '1'11)1 C96L'6 AI::IVI'IEI8::I:I IliA OIIVII::IOV 0Ct~-~6 -.. )IDYLS 'd'O';! O'IOdlN¥1N '111~1 ~ :z)IOHD NOI.LD3NNOD q'IlM/::I)IOHD A DN::aDU::IIN:a 3)40H0 olqn¥1dOAH l-IV Q1OdiN¥1N C)(~ Oi Q'IOdlNVIN HDflOU£ Ol 3MOHO qVrINVIN QBA~ ,~ OX .LINN IflOUd NMOUO U38SYD3CI AOIIUOOd '~ta IIIA ot~lapv ~q~ 7o s~u~m~uIodd~ ~u~mdtnb~ pu~ ~uoI~InN~a MuttIlap ~s ~q~ p~ssn~sip pu~ DM '~uta~M I~qoI9 ~o a~N~u~M suot~a~dO.'~axwA~N Kq p~o~uoo s~m I ~=!m.~d uoIsstmmoD uo~A~uo pu~ II0 ~Ms~IV u~ m~pun ~Ai~o~ u~q ~ou swq qo!qm ~ia Nu!titap ~u~ uo K~o~u~Au~ ~u~md~nb~ ~q~ ~noq~ s~ouoo ~o ~soau~ · a~ q~la suoI~snosIp ~uIaolto~ '066I '9I Ktn£ p~nss~ I# uo~Nan~s p~sodoad s,IW ao~ (08-06 'oN) 08-06 'oN ~Ima~a IiIA oI~Iapv ~,a~moto/IW uoi~o~dsuI ~{O~/~IM Xx~uIm~.I~a 066t 'gI ~n~nv Z~£-9LZ (LO6) : ON L~IODM'IM.T. }~lchael B. Winfree ~RCO Alaska, Inc. - 2 - August 13, 1990 The Commission has concluded that the rig's piping downstream of the buffer tank will require~odi.fication prior_ to .spudding of subject well, Please notify this office when the rig is on locatiOn and ready for a pre-spud inspection. dlf: 1.LCS. 1 cc: Gregory R. Navarre, Operations Manager Global Marine Global Marine Drilling Company To: From: Greg Navarre Ralph Linenberger Date: 7 August 1990 Su~ect: Glomar Adriatic VIII - Choke Manifold Piping. Attached is the information on surface installations of choke manifolds from API RP-53, Second Edition, May 25, 1984. The reference that the Alaskan State department is making can be found in paragraph 3.A.3e.1; where the recommended practice suggests that the choke line between the BOP stack and the choke manifold, and lines downstream of the choke should be as straight as practicable, and if turns are required they should be targeted. As you can see in the figures that are included in the above attachment to the section for surface installations, there are no turns or targeted fittings shown. Basically this is because the manifolds shown in the figures are generally found on land rigs. The figure in RP-53 that best'depicts the type of manifold that Global Marine has installed on all of it's jackup rigs i~ the manifold that is shown in Figure 3.B.1 (subsea installation). My reasons as to why I feel that the system that is installed on the Glomar Adriatic VIII is sufficient are as follows: 1. Every offshore drilling rig that Global Marine Drilling Company has built since 1979 has the same piping ~ystem between the choke manifold and the mud/gas separator. To the best of my knowledge, we have never had any problems or washouts in this piping system. 2. In paragraph 3.A.3e, the lines that are being referred tO are those that are downstream of the chok~, not the choke manifold. My interpretation of this is similar to what is shown in Figure 3.B.1; that is those that are directly in line with the outlet'of the choke(s), and those that are upstream of any high pressure valves on the discharge side of the manifold (e.g. valves between the manifold and the mud/gas separator, flare line, bleed line, etc.). As far as the design of the Global Marine manifolds, we have included extra-thick erosion area downstream of the choke(s) in the for~ of a buffer tank. 3. If you look at paragraphs 3.A.3h, and 3.A.3i, which dtscus~ the recommended requirements for the bleed line and lines downstream of the choke manifold, there is nothing in these paragraphs that recommend that these lines need to be targeted. For the lines_~ownstream of the choke manifold, the RP states that these normally are not required to contain pressure. Without pressure, there is no high velocity. Without high velocity, there is little or no erosion. Hence, there is no need for targeting turns in these lines. As I stated earlier, we have never had any problems with washout in the choke manifold downstream piping with the system the way that it was originally designed. We have never had any regulatory body or certifying agency (i.e. North Sea, Gulf Of Mexico, etc.), or Operator raise this question that has been raised by the Alaskan State department. I trus~ that the information that I have provided will be sufficient for your discussion with the Alaskan State department this afternoon. If I can assist you any further on this matter, please contact me. (~.C. B. Watson C. Keaton File .Recommended Practice .for Blowout Prevention Equipment Systems for Drilling Wells APl RECOMMENDED PRACTICE 53 (RP 53) SECOND EDITION, MAY 25, 1984 American Petroleum Institute 1220 L Street, Northwest Washington, DC 20005 .,~~~ 14 American Petroleum Institute SECTION 3-A CHOKE MANIFOLDS -- SURFACE INSTALLATIONS PURPOSE 3.A.1 If the hydrostatic head of the drilling fluid is insufficient to control subsurface pressure, formation fluids will flow into the well. To maintain well control, back pressure is applied by routing the returns through adjustable chokes until the well flow condition is cor- rected. The chokes are connected to the blowout preven- ter stack through an arrangement of valves, fittings, and lines which provide alternative flow routes or per- mit the flow to be halted entirely. This equipment assemblage is designated the "choke manifold." DESIGN CONSIDERATIONS 3.A.2 Choke manifold design should consider such factors as anticipated formation and surface pressures, method of well control to be employed, surrounding environment, corrosivity, volume, toxicity, and abra- siveness of fluids. INSTALLATION GUIDELINES 3.A.3 Recommended practices for planning and installation of choke manifolds for surface installations include: a. Manifold equipment subject to well and/or pump pressure (normally upstream of and including the chokes) should have a working pressure equal to the rated working pressure of the blowout preventers in use. This equipment should be tested when installed in accordance with provisions of Par. 7.A.6 and Table 7-A. b. Components should comply with applicable API specifications to accommodate anticipated pressure, temperature, and corrosivity of the formation fluids and drilling fluids. c. For working pressures of 3M and above, flanged, welded, or clamped connections should be employed on components subjected to well pressure. d. The choke manifold should be placed in a readily accessible location, preferably outside of the rig sub- structure. e. The choke line (which connects the blowout pre- venter stack to the choke manifold) and lines 'down- stream of the choke should: l) Be as straight as practicable; turns, if required, should be targeted. 2) Be firmly anchored to prevent excessive whip or vibration. 3) Have a bore of sufficient size to prevent exces- sive erosion or fluid friction: a) Minimum recommended size for choke lines is 3-in. nominal diameter (2-in. nominal diameter is acceptable for Class 2M installations). b) Minimum recommended size for vent lines downstream of the chokes is 2-in. nominal diameter. c) For high volumes and air or gas drilling oper- ations, minimum 4-in. nominal diameter lin.es are recommended. f. Alternate flow and flare routes downstream of the choke line should be provided so that eroded, plugged, or malfunctioning parts can be isolated for repair with- out interrupting flow control. g. Consideration should be given to the low tempera- ture properties of the materials used in installations to be exposed to unusually low temperatures. h. The bleed line (the vent line which by-passes the chokes) should be at least equal in diameter to the choke line. This line allows circulation of the well with the preventers closed while maintaining a minimum of back pressure. It also permits high volume bleedoff of well fluids to relieve casing pressure with the preven- ters closed. i. Lines downstream of the choke manifold are not normally required to contain pressure, but should be tested during the initial installation (refer to Par. 7.A.6 and Table 7-A). j. Although not shown in the example equipment illustrations, buffer tanks are sometimes installed downstream of the choke assemblies for the purpose of manifolding the bleed lines together. When buffer tanks are employed, provision should be made to isolate a failure or malfunction without interrupting flow control. k. Pressure gauges suitable for drilling fluid service should be installed so that drill pipe and annulus pres- sures may be accurately monitored and readily ob- served at the station where well control operations are to be conducted. I. All choke manifold valves subject to erosion from well flow should be full-opening and designed to oper- ate in high pressure gas and drilling fluid service. Double, full-opening valves between the blowout pre- venh~r stack and the choke llne are recommended for installations with rated working pressures of 5M and above. tn. For installations with rated working pressures of 5M and above the following are recommended: 1) One of the valves in Par. 3.A.3.1 should be re- motely actuated. RP 53: Blowout Prevention Equipment Systems 2) At least one remotely operated choke should be installed. n. Spare parts for equipment subject to wear or damage should be readily available. A recommended inventory of choke manifold spare parts is included in Section 3-B. o. Testing, inspection, and general maintenance of choke manifold components should be performed on the ,same schedule as employed for the blowout preventer stack in use (refer to Par. 7.A.7). p. All components of the choke manifold system should be protected from freezing by heating, draining, or filling with appropriate fluid. 3.A.4 Figs. 3.A.1 through 3.A.3 illustrate example choke manifolds for various working pressure service. Refinements or modifications such as additional hydraulic valves and choke runs, wear nipples down- stream of chokes, redundant pressure gauges, and/or manifolding of vent lines may be dictated by the condi- tions anticipated for a particular well and the degree of protection desired. The guidelines discussed and illus- trated represent examples of industry practice. 16 American Petroleum Institute ADJUSTABLE CHOKE--x m X~ mTO PIT AND/OR MUD/GAS SEPARATOR/OVERBOARD . ~-~=: :W .... ~,, ;o~,,~ / XSTACK OUTLET' u[~'~N~l~ ~ ~X~[~~~ ~ BLEED LINE ll9 PIT/OV~/~D /---OPTIOflAL ON 2M Y2~" TO PIT AND/OR MUD/~S SEPARATOR/OVERBOARD · AOJUSTABLE CHOKE---/. NOMINAL FIG. 3.A.1 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 2M AND 3M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION ADJUSTABLE CHOKE- TO PIT AND/OR SE~PAR ATO R//OVER~_.t,A RD L2" NOMINAL x PREVENTER STACK OUTLET z-SEQUENCE OPTIONAL OPERATED VALVE NOMINAL -- BLEED LINE ,, ~ ~ TO PIT/ '(xOVERBOARD TO PIT AND/OR MUD/GAS SEPARATORttO~BOARD ~ 2" NOMINAL REMOTELY OPERATED OR ADJUSTABLE CHOKE FIG. 3.A.2 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 5M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION RP 53: Blowout Prevention Equipment Systems ~ ,--.-- ADJUSTABLE CHOKE REMOTELY OPERATED VALVE 2 _,~_~ LINE 2" ~- ~v / 5NUMNUM ~ _ ~ ~ REMOTELY REUOTE LY ~~' ~ OPERA~D ~- (OPTI ONAL) OR . ~~ ADJU STABLE CHOKE ~~~ - FIG. 3.A.3 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 10M AND 15M RATED WORKING PRESSURE SERVICE -- SURFACE INSTALLATION (Isometric Illustration) ( ( DRILLING FLUID PUMP LINE FLARE LINE OR VENT L)NE TARGETED N C ADJUSTABLE CHOKES ~7 "'L'~cEMENT UNIT PUMP LI NE KILL LiNE.~'~' (FROM BLOWOUT PREVENTER STACK) CHOKE · w---.-.. LiNE (FROM BLOWOUT PREVENTER STACK) FIG. 3.B.1 EXAMPLE CHOKE MANIFOLD ASSEMBLY FOR 5M, 10M, AND 15M RATED WORKING PRESSURE SERVICE--SUBSEA INSTALLATION MUD/GAS SEPARATOR REMOTELY OPERATED CHOKE CONTROL I UNIT I RIG FLOOR I I ~o~;e:' 'C'c:~ ~mx,:'t,i<,n:~ MlL.,STD,.!63 Stee} Mit] Prod~c:,. 0.6,25 0.1.32 8 0.250 0.277 30 2.~ 2 ~,02 0-322 0.~ ~ ~.gt~ 4.{8i 0.593 I{~ 4..~ 4.573 0,~ i~7; 5 L~ 5 538 I0 7~ 0.250 ).~ 2615 2.g6,8 O.R)7 30 3.O'M, 3.333 0~5 ,~ ~{t.? 3 757 0 ~ O~ ~.2~ 4 592 059~ ~ a I~ 5.070 0.~3 ~2~; 5.747 ~.0~ i .~ ~.~ ~.2~ 6.~ 0_3 ],q ~ L566 3683 0.~2 ~:~, ~.392 5271 0.087 0.~3 !(~.~ ~,23 ~ 6627 1.125 the eurrem edifio~ of §pe~cification ^ $30 u~- 1~ othc~ provid~ h~,~.~ b~sic--oxygen, o~~ electric-furnace, The ~nda~ff melting, using el~g mmeh::mg or vacuum-am remelting. If ~ondary reciting is cmpk(fciL ~e heal s{~aH ~m defined as a~ ~¢ ingots rcmclted fi-o~:a ~ single primary heat. hot fiaish~ c)r ~ld drawn, and ovec shall ~ furnished hot f~fished.. agreed ~.~{~m }~tw~n the maaafi~cturer and pu~ch~:~', ~Ad~drawn pq~ may t~ furmsbed 5. Ordering [nformatim~ 5, i Orders for rnater~raJS nnder this cation ~h~}l include ~hc fotlowmg~ as requ~red~ to de,:fire the desired malcfial adequately: 5.!.2 Name of m~lcrial (~amle~s steel 5.13 Grade (Fable 1), 5.1.4 Manuhcture (hot-finhhed or drawn), 5.1.5 She (either NPS and weight cl~ or <hedule n~r, or ~th, or oumide diameter and nomm~ wall thickn~% ANSI B36. 5.1.6 Length (s~ffic or r~dom, ~ction 5.1.70ption~ requiremenu (~Uon 9 and SI to SOL 5.1.8 Trot m~n r~uir~ (~tion 20 of S~ca!ion A 530), 5.1.9 S~cffi~tion numar, 5.1. !0 End u~ ofmatcrml, 5.1.1 ! Hydrostatic lesl m a~r~ 6.3 of S~ificalion A 530 or 132 of thus ificafion, and 5. !. 12 S~ial requi~menm. 6. lteat Treatment 6.1 H(~t-finished p}pe treated. Cold-drawn pipe ~ali bc heat alter the final cold d~a~ of 12~'"[: (650°(7i or higher. ~tion 7. If thc ~ondary melting pr~s 4.1 ;~e employ~ the hea~ a~}e~ysm shall oct o~' one mmelt~ ingot of e~c~ pnma~ ~ha~ ,,le~ermined from a p~o&~c~ am~ys~s made ~fac:~ured lhe sz~l, sl~ail ~e ~{'~'~>rt:ed to the io~.m to the ~'emarcments g~'~ ,,.. t ~ Se,ction ~. Producer Analysts of two pilm fium each lot (Note 2) of ~eng~hs or f?acUon H~c. reo~ of e~cb size up but ~tot including, NPS 6~ and t'[mn each lot of 2~ lengths or fraction thereol of each s~ NFS 6 and over, shall ~ made by the manulacture~' f~om the fmBhed pi~. The re, nits of the~ aualy~s shMI ~ re,,ed to the purchaser or his repre~ntative and M{al{ ~n~0rm to r~uirements s~ified m S~tion 7 93 If the anaNsisofone of the. tesk~ s~ified m 9. { dc~s not mMom m the [equiremems s~/i~ in ~tion '1, analy~,q shall ~ made on additional piles of double ~e on, al nmn- t~r from the ~me lin, each of which shall remora m r~uirements s~fied NoY~ 2--A h~ shall ~ns~t of ~he numar of len~,s s~ifi~l in ~t~o~9 ~d )5 ~',~ thc ~me e~d w~ ~ckn~ I)om ~y one h~a~ ol c~ck~;. When o~'d<:~c~ ~0~ clc~' cx~m~, bend ~,es'~ sl~.cimeas :~l',alt [~ bern ~ d:'.~¢ om:~,ide of the ~nt ~:n'm)t~,. ~'he reside 5ubstituOon of the ~nd test for the fla';~cai.ng :~ ~,3 k'o~ pit~ who~ diameier excec,d:~ 2.5 ~6,35 m ~.,> and w{~c~e diameter to, waii raise is 7.0 or less:, ~he ~nd test de.~:6i'a~d m 11,2 shal~ ~ condt;cted matead of t~ flat,enmg 12.1 t-c:c pipe over NPS 2 a ~ctiou of pi~ no~ k~ ;~;.an 25'~ in. (63.5 mm) m, in length ,:hail N:' :]attcned co~d. ~iween para;lei plates untd l.h, ~p~)sile walls of the ,:~ },l!.? ~)~c'e{ [:lai.- tenmg tesLs shah N- m ac~rdauce wl~h S~ci.. ,,,~.:o~ :, 530. ¢.xc:pt fi'~at m :he Ibr:,~ata to calculate ~c "Lp' value, the fogowi~)g COllgf~{[5 shall ~ ~: 0.08 for Grade A 0.07 foe Gra~ B ~ L' ~, :Chert low ~to-t ratio tubo}a~ omr~ry , unrea~ma~iy h*gh on lite i,~ be i'umish~d Withea!l byd~'osa;~ti,:: it:sting and each ~ength m tUm.~sh~ shal~ include wi~ the mandateU mark ing. t~e {e~le~ "N 1t" and Ibc tenlgt~ markea wah ;he iette~s "NH", the certfficafion, winch r~uir~, shMI clearly state '='No~ }lydr~m:~cally Test~". the s~i- B~m~n numar ~m ~:na~enai grade, as shown t4, 'ii'est Sl~-eime~s ~ l'e~l Metl~ls i4, I On NPS 8 a:~d larger, s{'mcimens cut e~l:het longitudinatl~ 14,2 T'e=,. s~cimen~¢ iOr fi~e ~,nd test $~ci- fled ~ ~cnon i i ~:~d i%[ the flattening tests ~i~:~de on ct"op ends,. 14,J'~ Teat s[mcimea:~ iied m i i.2 and ! i.3 saali ~ cut Ii'mn one end of lhe p{~ and, unless other~'i~ s~cified, shall ~ mien m a t~ansvc~m direction. One test s~cimcn shall ~ taken ~ c}o~ to the outer surthce ~ po~ble and anothe~ flora ~ close m the tuner surh,m as ~ible. The s~imens shall [n~ el~' ~ by et m. (12.7 by 12.7 ~)m s<cuor~ or I by ~ b~. (254 by 12.7 mm) m ~ctiot~ with ~e con~e~ rounded to a radi~ ~.iot ow:r ¢~ m. (l.6 m~',} and n~d not ex,ed 6 in~ ~t52 mm) i~"~ i,,g~:: ~:be side of the ~am. pk:~ plac~ io te~':~.or .... ~,:g ~e ~nd shall be ,be 5~de cto~st to: h. :;: ~ nd outer surfa~ 34.4 Ag v. mtiae c5- all ~ m~e at ,'me pi~ . ~hereof permRte;d by' l {.2 or requked by 11.3, shall marie on. one ea~ of 5 % of ~e p~ t~om eac~ io ~h,¢ hydtostat/c te~/~.~ m ~tioa 13 m.achmmg o~ deve~ ~hws,. it ~.y )~ d c~rded ~d ~m~e~ s~:~en ~6. ~. Itl' the ~vcei~'tag¢ of ,ekmgatior~ of any thc %?craven ~fi~re re:sting,, a retest ~hail ~0,2 S~o'uh3 ~ crop end era fi~fishcd made ;Yom thc/~ed end, Pi~ may m~z~d ci~hcr ~efore or a~er the fu~ ~est, bm pi~ sh~ ~ subj<~ to oMy ~wo norm~g 37 ~ N,pples shall be cut from pipe of thc s,~ne dimemdons and quality desc. rqx:d in th:ts 18. i ~ig~t--~e wc~t tff ~y leng~ o~' pi~ s~U ae~ vaO' mo~ ~.n I0 % over and 3 ~ ~ a~dcc ~at s~fi~. Ual~s othe~ ~r~d a~m ~tween the ~ufa,:t~ite~ and under the nominal wail may ~ ~av'c ~:cn pro~rfy eval~ted wilh [esj~c~ to depth, ExploraUon o:~ a~J sudacc b; c~ot ~cqu/~eO ha( may ~ t~.e~.~ary' compkaf~ wi~ 20.2, 20.2 Surh~ nn~riections more than 12¢~ % of the nominal wall lh.~ckn&~s {n encroach oa the mmhnum walt ~hiciaess shall be considered det~t& ~5~ ~ith ~uch de~ects shall ~ Wen one of che dis~.~itWns: 202 ! The def<t ~y ~ m~oved by grind- mg provid~ thai ~e rem~g ~s within s~c~fied hmim 20.2.2 Repa/r~ i~ accordant, la_~ welding provksions of 20,6. 20 2x Igc ~no~ of pi~ coaching the dcf~ may ~ cut off' wt~m ~c ~iu of ~c- 20 ~ .4 R.ej~ted, 20; T,:) pr~,~v~dr a wor~anlike moved by g~'mding. ,a smc~.a: cuev'~ surface ~m'~ cfi grinding may n~;~d(: with ~ ~ncchamod vh:e o{ ~ppropctate a~u~acy lo ::a,~: of dispute, ::ZOo6 Weki ~cpair aha.a ~' p,:nnkt~ onJ~ ?0.7 The /}aished pi~w 5ha~ be ~'e~mabiy Not~: ~.---Ma~'~s aad abi~:;~m:; arc defin~ ~s ~-., dude ~h¢ hydrtx~laiic teal prckxt~m ~hen t~ted~ ,ar tl~e letter "NH" when not te.$le~, ~ to the supplement~ t~ui~'emen~ ~.~,::~ ~:5:~:~c-~, lhe *onto:mi wa: ordered: or othe~ a,vc~,::t',~ia:,,:c~~. wi~>: ~be ~"eq~.~iceme/~i~ ~'>f MiL 22,.k yns/.,ec~i~m Uafe~:; othcrw~ qairemen~s s[.~'iti~ i~erem, Ex.pt as other- · ;:,'~.~ s~:i/},ed i.r, thc c~,~t,~c~., the pr~u~r may u~ b.~ or,-~, of aay ,~!i~e~ suitable hciliti~ for .) TO: THRU: · . MEMORANDUM State of Alaska ~SKA OIL A_ND GAS CONSERVATION COMMISSION Lonnxe ?. Sm DATE: July 30, 1990 Commis sloner / FILE NO: JT. DA. 730 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI/Glomar Adriatic VIII Seward Alaska FROM: Petroleum Inspector Thursday July 26 1_~_~_990: I traveled this date from my residence to S~W~rd ~-0 ~nd'~--~ the inspection on AAI's Glomar Adriatic VIII j ackup rig. ~J~990: I was met at the rig by AAI rep Don McKelvy and G-~r~NA~arre. We conducted the inspection of the choke manifold, choke and kill lines, diverter and BOP stack, accumulate and control panel, for compliance with AOGCC regulation. Attached are photos 6f the items I found questionable and will require the Commnissions attention. Photos ~1 2, and 3 show the long radius heavy wall Al06 90° ell and hammer union at the gas buster. Photo #1 and 4 show the short radius heavy wall Al06 90° ell down, stream of the chokes and upstream of the riser to the gas buster, photos #5,6, and 7 show the vent line piping running over the crown. Photo #8 shows the BOP stack without the spool between the rams, this spool will be installed before drilling operation commence as per AAI rep, Don McKelvy. Photos 9 and 10 show the diverter and the control panel to control the two 12" ball valves, the two items are in compliance. In my opinion the items shown due to their 10,000 # rating, their heavy wall Al06 construction and the buffer zone of 4" ID shown in the photos ~11 & 12 piping immediately dow~ stream of the 2" chokes, do not pose a problem. In summary: I inspected the Glomar Adriatic VIII jack up rig BOP system for compliance with AOGCC regulations. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 July 16, 1990 Telecopy~ (907)276-7542 Mr. Michael B. Winfree Acting Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage; Alaska 99510-0360 Re: ~ Sturgeon #1 ARCO Alaska, Inc. Permit No. 90-80 Sur. Loc. 3121'FNL, 445'FEL, Sec. 25, T5N, R17W SM. Btmhole Loc. 3121'FNL, 445'FEL, Sec. 25, T5N, R17W SM. Dear Mr. Winfree: 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. Sufficient notice must be given to allow for a representative of the commission to witness the BOPE installed on the surface casing and a test of same prior to drilling out the surface casing shoe. Very trulM yours, Chaiman of Alaska Oil and Gas Conservation C~lss!on BY ORDER OF THE COI~,{ISS!ON dlf :~ Enclosure ~ CC: Department of Fish & Game, Mabitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re.. THE APPLICATION OF ARCO ) ALASKA, INC. for an order) granting an exception to ) spacing requirements of ) Title 20 AAC 25.055 to ) provide for the drilling ) of the Sturgeon #1 ) exploratory well. ) Conservation Order No. 256 Sturgeon #1 Well Exploratory, Section 25, T5N, R17W, Seward Meridian July 16, 1990 IT APPEARING THAT: · ARCO ALASKA, Inc (ARCO) submitted an application on June 18, 1990 requesting an exception to 20 AAC 25.055(a)(1) to permit the drilling of Sturgeon #1 exploratory well closer than 500' from a drilling unit boundary. · Notice of~hearing on this request was published in the Anchorage Daily News on June 28, 1990 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: · ARCO proposes to drill Sturgeon #1 from a surface location 3121' from the north line and 445' from the east line of Section 25, T5N, R17W, Seward Meridian, to the same bottom- hole location. · An exception is necessary to achieve compliance with 20 AAC 25. 055(a) (1). · Offset operator/owners Beard Oil Company, Union Pacific Resources Company and Rowan Petroleum, Inc. have been duly notified and have filed no objection. Conservation Order ~._. 256 July 16, 1990 Page 2 CONCLUSION: Granting a spacing exception to allow drilling of the ARCO Sturgeon #1 exploratory well as proposed will not result in waste nor jeopardize correlative rights. NOW, THEREFORE, IT IS ORDERED: ARCO Alaska, Inc's application for an exception to 20 AAC 25.055, for the purpose of drilling the Sturgeon #1 exploratory well is approved as proposed. DONE at Anchorage, Alaska and dated July 16, 1990. laska Oil and Gas Conservation Commission Lonni'e C. Smith~Co~issioner Alaska Oil and Gas Conservation Commission ARCO Alaska, Inc. Post Office B~,,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1990 Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Permit to Drill ARCO Sturgeon #1 Dear Commissioner Chatterton, ARCO Alaska, Inc. hereby applies for a Permit to Drill an offshore exploratory well, the ARCO Sturgeon #1, in State waters of Cook Inlet. ARCO will act as operator for itself, Beard Oil Company, Union Pacific Resources Company and Rowan Petroleum, Inc. in evaluating acreage previously leased in State of Alaska Lease Sales. The proposed well location is approximately seven miles west of the northern tip of Kalgin Island in 135' of water. ARCO proposes using the 'Glomar Adriatic VIII' jack-up drilling rig to drill this well during the Fall of 1990. Attached find the information required by 20 AAC 25.005(c) with the exception of the analysis of seabed conditions required by 20 AAC 25.005(c)(9). The seabed survey data is currently being reduced and a report assembled, but the final document is several weeks from completion. ARCO requests that the AOGCC issue a permit to drill this well contingent upon ARCO first submitting the required seabed conditions analysis and upon that analysis showing the soils conditions to be appropriate for the planned operations. Also, the AOGCC is requested to keep confidential the following attachments to this permit application which are drawn from research and data proprietary to ARCO Alaska, Inc.: Pressure Information Proposed Drilling Fluid Program Pressure Analysis Proposed Drilling Program If you have questions or require any additional information, please contact W. J. (Bill) Penrose at 263-4511 or myself at 263-4603 in our Anchorage office. Sincerely, Michael B. Winfree ¢/ Acting Regional Drilling Engineer ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany /~f~:;i'~ ,;(~ll:~ (; STATE OF ALASKA ~'~ OIL AND GAS CONSERVATION COMM. ,,iON PERMIT TO DRILL ORIGINAL 20 AAC 25.005 i la. Type of Work Drill ;X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test . Development Oil Re-Entry DeepenI Service Development Gas Single Zone Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, In(;, KB Heiahl above mudline: 243 feet Wildcat 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL 359110 41 Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.025) 3121' FNL, 445' FEL, Sec. 25, T5N, R17W, SM N//~ Statewide At top of productive interval 8. Well number Number Same Sturg~grl #1.. #U-63061 0 At total depth 9. Approximate spud date Amount Same 9/1/90 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed deplh (MD and TVD) property line 55 feet 2.8 miles 3840 lease acres 7700' RKB 16. To be completed lor deviated wells N/A 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth feet Maximum hole angle Maximum surfac~ 1346 psit~ At total depth (TVD! 21 93 psi~ 18. Casing program Setting Depth (RKB) size Specification Top Bottom 'Quantity of cement Hole Casinc~ Weic~ht Grade Couplinc, I Lenc, lth IVD TVD IVD ~ TvD (include stac~e dataI Driven 30" 1-1/2wall -- D-60 346' 47 47' 393' 393' N/A 26" 20" .438"WalIX-56 S-60 1153' 47' 47' 1200' 1200' Lead 1255sx, Tail 500s~ ' 17-1/2" 13-3/8 68#/ft L-80 BTC 2653' 47' 47' 2700' 2700' Lead t045sx, Tail 500sx 12-1/4" 9-5/8' 47#/ft L-80 BTC 7653' 47' 47 7700' 7700' 820sx 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured ' feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface !~' ~ C ~IV Intermediate ~"k, 2 ...... ;'" Production Perforation depth: measured true vertical ': :.:;:;i<~.0ii & Gas Cons. 20. Attachments Filing fee ~ Property plat ~X BOP Sketch X Diverter Sketch ~ Drilling program ~ Drilling fluid program X~ 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 Sign 'ed~t~'~ ~!,~] Ap number Commis,ionTit'e Actingu,eReCjionalon.y Drillin~ Encjineer . Date ,~//~Z~ Per~;:~Num~b-- I 50-7::~'~ ~'-- ~---~ ~7///~' I Appr°va' 01~ ~ 6 / 90 I otherSee coVerrequirementsletter for Con'ditions of approval Samples required ~ e s N o Mud log required ~ Y e s N o Hydrogen sulfide measures .~ Yes~ N o Directional survey required ~ Yes o Other;Required working pressure~~~3~' __ 10a. __ 15M~,. by order of 7_~,~~ Approved by ,¢ ~ Commissioner the commission Date _ Form 10-401 Rev. 7-24-89 ~it in triplicate PROPOSED DRILLING PROGRAM ARCO STURGEON #1 (Per 20 AAC 25.005(c)(10)) , WELL PLAN (All depths are measured from RKB unless otherwise noted) Tow rig from stack site at Seward, Alaska to well location and jack down legs. Using leg jacking mechanisms, maintain constant air gap through one complete tide cycle. When tide has returned to original height, establish permanent air gap of 44' and take on preload consisting of 5400 short tons of Inlet water. After 12 hours at pre-load conditions or after all discernable leg settling has ceased, whichever last occurs, discharge pre-load water and rig up to spud. Rig up drive hammer and drive 30" structural casing to refusal (approximately 150' BML). Install 30" MSP-1000 diverter on 30" structural casing and function test. Pick up drilling assembly and drill 17-1/2" hole to 1200' RKB, then open hole to 26". Run 20", 0.438" wall, X-52 conductor casing with $-60 connectors to 1200' RKB. Centralize in 30" structural casing. Cement 20" casing to surface. Nipple down 30" MSP-1000 diverter, cut off 20" casing and weld on 20" SOW x 21- 1/4", 5,000 psi starting head. Using double studded adapter, nipple up 30" diverter on 20" starting head. Function test. Drill 17-1/2" hole to 2700' RKB. At 2700', run the following open-hole logs from 2700' to the 20" casing shoe: DI L/SP/GR/BHC LDT/CNL/Caliper/GR Checkshot Velocity Survey Run 13-3/8", 68#, L-80, BTC intermediate casing to 2700' RKB. Hang off on buttweld sub in 20" conductor casing at approximately 40' BML. Cement 13-3/8" casing to surface. Nipple down diverter, cut off the 13-3/8" casing and install 21-1/4 ", 5,000 psi X 13-5/8", 10,000 psi casing head. Install 13-5/8", 10,000 psi WP BOP stack on 13-5/8" casing head. Pressure test BOPE. Run cased hole logs (casing caliper, CBT and gyro multishot) from the 13-3/8" casing shoe to surface. Pressure test 13-3/8" casing to 3500 psi. Drill out and perform leak-off test. Drill 12-1/4" hole to TD, approximately 7,700' RKB. At 7,700', run the following open-hole logs from 7,700' to the 13-3/8" casing shoe: DI L/SP/GR/BHC LDT/CN L/Caliper/GR FMS Checkshot Velocity Survey SWC (approximately 90) RFT (Optional) If the logs provide sufficient encouragement for testing the well, run 9-5/8", 47#, L- 80, BTC casing to 7,700' RKB and land in mudline hanger system. Cement 9-5/8" casing to 5700' RKB. Nipple down BOP stack, cut off the 9-5/8" casing and install 13-5/8", 10,000 psi X 13-5/8", 10,000 psi casing head. Nipple up BOP stack on casing head and test. Run cased-hole logs (casing caliper, CBT and gyro multishot) from TD to the 13-3/8" casing shoe. Pressure test 9-5/8" casing to 4800 psi. Set production packer in the 9-5/8" casing at top of interval of interest and sting in with tubing-conveyed perforating guns, test tools and 3-1/2" tubing to surface. Include appropriate downhole flow control devices in test string. With the tubing hanging in the blocks and the pipe rams closed around it, nipple up a 5,000 psi WP test tree and manifold. Pressure test the tree, manifold and test string. Test by perforating underbalanced and flowing up the tubing and through surface testing facilities. Test liquids are to be stored in tanks aboard the drilling unit and pumped back into the reservoir or down the 9-5/8" X 13-3/8" annulus after testing. Gas is to be flared. Testing will involve alternating flow periods and shut-in periods. Individual intervals may be tested separately or concurrently. After completion of testing, kill well and remove test string and packer. Using drill pipe as the work string, squeeze all open perforations and abandon well per 20 AAC 25.105. Cut off and recdver all casing at 20' BML. Jack up legs o1' drilling unit and tow to its stack site at Seward, Alaska. PRESSURE ANALYSIS ARCO STURGEON #1 (Per 20 AAC 25.005(c)(7), as required in 20 AAC 25.033(e)) PRESSURE ANALYSIS A pressure analysis was performed for this well using site-specific seismic data and offset well information from wells in close proximity to the planned drilling location. There are four nearby offset wells: ARCO Drift River State #1 Hunt Oil Oldmans Bay #1 Champlin Beard State #1-11 Hunt Oil Kalgin Island State #1 The locations of these wells relative to the Sturgeon wellsite are shown on the attached map (Attachment 1). The Drift River well, with a TD of 5410', is the shallowest, having been drilled on the structural crest but on the west side of a major fault. The other three wells, with TDs ranging from 11,350' to 14,509', are considerably deeper because of being Iow on the east flank of the structure. All of the offsets as well as the planned Sturgeon well have the Hemlock and West Foreland sands as the target interval. Basement is the Jurassic section directly underlying the West Foreland. The Sturgeon well is situated higher on the structure than the three eastern offsets but to the east of the fault which isolates the Drift River well from the structural crest. Mud weight and fracture gradient information for the two closest offsets, the Drift River and Beard State wells, was extrapolated to the Sturgeon site. Also, the drilling supervisor for the Beard State well has been interviewed several times about what that well encountered in terms of hole problems, formation pressures and mud properties. Attachment 2 contains the mud weight and fracture gradient information from the Drift River and Beard State wells. Attachment 3 indicates the anticipated hydrostatic, mud and fracture gradients for Sturgeon as inferred from those two offsets. The Sturgeon gradients are conservative, using the highest of the offset mud weights and treating formation integrity tests as actual leak-offs. As can be seen, high formation pressures are not a concern at Sturgeon. Mud weights are not expected to exceed 11 ppg and the fracture gradient should not exceed 0.68 psi/ft. Seismic data indicate that there are no faults or truncations isolating the proposed well location from the Beard State well. Since all of the offset wells, including the Beard State well, experienced normal Cook Inlet lithology and pressures, unexpected trapped geopressure should not be a problem at Sturgeon. This is verified by the Interval Transit Time vs Depth plot on the attached Formation Characteristics summary. This plot indicates no trend reversals characteristic of over-pressured intervals. Finally, the geologic hazard assessment indicates there are no shallow hazards (such as shallow gas) to drilling at the proposed well location. 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'-'-;2_._.._._.2lil~ll- i__~.~IL[:/i --: ......... ................ ......... i lllli : i [7] il i ] ,~"'x~ .................... :,o,~ .... ~ ....... ]-I'U"...'.' ........................... i ............................................... T ......................... !-'"l'-'l'"'! ............... '~ ........... · I11 -r Well Formation Characteristics I Well number Prepared by STURGEON ~ Reference W. ..)ENROSE 6/25/~0 VELOCITY ANALYSIS FOR STURGEON PROSPECT (ARCO SEISMIC DATA) WELL HISTORY: CHAMPLIN BEARD STATE #1-11 WELL HISTORY: RICHFIELD DRIFT RIVER #1 Interval Traniit Time SOO. 600 Tm 10r) ~10~0 150 700~ 9000 10,0~0 11,000 14,000 1S,000 ! I%1111~: ,,., 'Ii" i.i I il I 50O 0O0 70O 500 9{01500 150 Pore preslure gradient lb/gal Pore Prell Gradient 9 10 11 12 13 14 15 18 17 18 19 20 Pore pressure gradient lb/gal. Formation ne~ne BELUGA TY(~JEK HEMLOCK WEST FORELAND JURASSIC DIAGRAM AND DESCRIPTION OF DIVERTER SYSTEM TO BE USED ARCO STURGEON #1 (Per 20 AAC 25.005(c)(5)) fO, DIVERTER SCHEMATIC ARCO STURGEON #1 12", 2000 psi Hydraulic Valve MSP-1000, 30" Annular Preventer 30", 1000 psi Spool 12" Outlets Flowline 12", 2000 psi Hydraulic Valve 30" X 1-1/2" Wall Drive Pipe Per 20 AAC 25.005(c~(3}: DIAGRAM AND DESCRIPTION OF BOP EQUIPMENT TO BE USED (As required in 20 AAC 25.035(a)(1)) AND INFORMATION ON MAXIMUM PRESSURES (As required in 20 AAC 25.035(d)(2)) BOP SCHEMATIC ARCO STURGEON #1 13-5/8", 10,000 PSI, RRSRRA 4 I I I I I I I I I 3 I I I I I I IL1 I I I I I I See listing of individual components on following page. /3. ARCO STURGEON #1 13-5/8, 10,000 PSI, RRSRRA BOP COMPONENTS 1. 13-5/8", 5000 psi WP, Hydril annular preventer with companion flange to bell nipple. 2. Double 13-5/8", 10,000 psi WP type "U" Cameron blowout preventer fitted with pipe rams top and bottom. 3. Double 13-5/8", 10,000 psi WP type "U" Cameron blowout preventer. Top preventer fitted with blind rams, bottom preventer fitted with pipe rams. 4. 13-5/8", 10,000 psi WP drilling spool Choke Valves: 5. 3-1/16", 10,000 psi WP manual valve 6. 3-1/16", 10,000 psi WP hydraulic valve Kill Valve~: 7. 3-1/16", 10,000 psi WP hydraulic valve 8. 3-1/16", 10,000 psi WP manual valve PRESSURE INFORMATION ARCO STURGEON #1 The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Sturgeon well: Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling ~in.~ (ft. RKB) (lbs/gal) (lbs/gal) (psi) (psi) 30 393 8.8 8.7 134 137 20 1200 10.2 9.1 519 504 1 3-3/8 2700 11.7 9.8 131 8 1346 Procedure for Calculating Anticipated Surface Pressure ~'ASP) ASP is determined on the basis of breakdown of the formation at the casing seat with a gas gradient to the surface as follows: ASP = [(FG x 0.052) - 0.11]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture Gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = True vertical depth of casing seat in ft RKB ASP Calculations 1. Drilling below structural casing (30") ASP= [(FG x 0.052) - 0.11]D = [(8.8 x 0.052) - 0.11] 393 = 137 psi . Drilling below conductor casing (20") ASP = [(FG x 0.052) - 0.11]D = [(10.2 x 0.052) - 0.11] = 504 psi 12OO . Drilling below intermediate casing (13-3/8") ASP = [(FG x 0.052) - 0.11]D = [(11.7 x 0.052) - 0.11] x 2700 = 1346 psi Casing Performance Properties Size Weight Grade Cnxn (in) (Ib/ft) 30 I -1/2" B D-60 wall 20 0.438" X-52 S-60 wall 13-3/8" 68 L-80 BTC 9-5/8" 47 L-80 BTC Internal Collapse Tensil Strength Yield Resistance J o i n t Body (psi) (psi) (1000 lbs) 3150 3000 260O 2210 520 2500 5020 2260 1545 1556 6870 4760 1122 1086 Casina Settina Depth R~.tiona, le 30" 150' BML 20" 1200' RKB, 957' BML 13-3/8" 2700' RKB, 2457' BML 9-5/8" 7700' RKB, 7457' BML Structural casing. Depth as required by 20 AAC 25.030(b)(1). Conductor casing to provide sufficient anchor and fracture gradient for diverter system. Intermediate casing to provide good anchor for BOPE and sufficient fracture gradient and well control until reaching TD. Production casing to be set only if well is to be tested or the open hole below the 13-3/8" casing seat dictates an additional string of casing. PROPOSED CASING AND CEMENTING PROGRAM ARCO STURGEON #1 (Per 20 AAC 25.005(c)(4)) ARCO ,.,rURGEON #1 CASING SCHEMATIC (All Depths RKB) 30", 1-1/2" Wall, S-60D Drive Pipe @ 150' BML 20", 0.438" Wall, X-56, S-60 Conductor Casing @ 1200' 13-3/8", 68#, L-80, BTC Surface Casing @ 2700' 9-5/8" TOC @ 5700' 9-5/8", 47#, L-80, BTC Production Casing @ 7700' Cementinq Proqram 20" Conductor Casing Size: Hole Size: Depth: 20" 26" 1200' RKB Top of Cement: Surface Excess Calculated: 1 00% BHT (Static): 50°F BHT (Circ): 50°F Slurry Components and Properties: 1,255 sacks Class G with 2.5% prehydrated gel + 0.25% CFR-3 + 3.0% CaCI2 Slurry Weight Slurry Yield Thickening time 12.8 ppg 1.94 cu. ft./sk 4+ hours Tail: 500 sacks Class G with 3.0% CaCI2 Slurry Weight Slurry Yield Thickening Time 15.8 ppg 1.15 cu. ft./sk 3.5 - 4.0 hours 13-3/8" Surface Casinq Casing Size: 1 3 - 3 / 8" Hole Size: 1 7- 1 /2" Depth: 2700' RKB Top of Cement: Surface Excess Calculated: 5 0 % BHT (Static): 90°F BHT (Circ): 80°F Slurry Components and Properties: 1,045 sacks Class G with 2.5% prehydrated gel + 0.25% CFR-3 + 1.0% CaCI2 Slurry Weight Slurry Yield Thickening time 12.8 ppg 1.94 cu. ft./sk 4+ hours Tail: 500 sacks Class G with 1.0% CaCI2 Slurry Weight Slurry Yield Thickening Time 15.8 ppg 1.15 cu. ft./sk 3.5 - 4.0 hours 9-5/8" Production Casin_o Casing Size: 9 - 5 / 8" Hole Size: I 2- 1 /4" Depth: 7700' RKB Top of Cement: 5700' RKB Excess Calculated' 5 0 % BHT (Static)' 1 55°F BHT (Circ)' 130°F Slurry Components and Properties: Preflushes: 1. 20 bbls Dual Spacer (10.5 - 11.0 ppg) 2. 5 bbls Fresh water 3. 10 bbls Super Flush (10.5 - 11.0 ppg) 4. 12 bbls Fresh water Slurry' 820 sacks Class G with 0.3% Halad-344 + 0.1% HR-7 + 0.2% CFR-3 Slurry Weight Slurry Yield Thickening Time Fluid Loss Free Water 15.8 ppg 1.15 cu. ft./sk 3.5 - 4.0 hours 100 cc/30 min. 0 cc ((9)(o)g00'g;~ OVV 0;~ Jad) I.# NO::::ilDI::In.LS O:C)EIV NOI/dlldOS=l(] IN::I/SAS CIlFII-I IDNI'i'IIblCi pue INVMIDOt:Id aln-I:l IDNl'l'llbla a=lSOdOad MUD PROGRAM INTERVAL: HOLE SIZE: CASING SIZE: MUD TYPE: From Base of Drive Pipe to 1200' RKB 17-1/2" opened to 26" 20" Sea water with high-viscosity sweeps as necessary MUD PARAMETERS (SWEEPS) WEIGHT: 8.5 -8.8 ppg VISCOSITY: 200 - 300 sec./qt PV: 20 - 30 YP: 40 - 60 pH: 9.0 FILTRATE: No control MAX SOLIDS: 5 % Drill 17-1/2" pilot hole with sea water, using high-viscosity sweeps as necessary to periodically clean the hole. These sweeps will be formulated with floculated bentonite supplemented with salt gel as required. Hole opening to 26" will follow the same procedure using high viscosity sweeps for hole cleaning. The sweeps will be pre-mixed for immediate application when needed. The sweep volumes will be calculated to fill at least 50' in the annulus. Lost circulation may be a problem in this interval. A supply of LCM will be on board for use if needed. Controlled drilling will be practiced if required. If hole conditions are questionable for running 20" casing, the hole will be displaced with a gelled slurry prior to pulling out of the hole to run casing. The casing running slurry will have the following properties: WEIGHT: 8.5 - 9.0 ppg VISCOSITY: 60 - 60 sec./qt PV: 15 - 20 YP: 15 - 20 pH: 9.0 FILTRATE: No control MAX SOLIDS: 5 % INTERVAl.; HOLE SIZE: CASING SIZE: MUD TYPE: 1200' RKB to 2700' RKB 17-1/2" 13-3/8" Low Solids Non-Dispersed Polymer Mud MUD PARAMETERS WEIGHT: 8.8 -10.3 ppg VISCOSITY: 35 - 45 sec./qt PV: 10 ~ 15 YP: 5 - 10 pH: 8.5 - 9.0 FILTRATE: 8 - 10 cc/30 min. Initial, 6 - 8 cc/30 min. Final SOLIDS: <8% Drill the 20" casing shoe and rat hole with spud mud from the preceeding interval, routing returns for disposal. Displace hole and surface mud system with fresh water mud formulated as follows: 0.25 ppb Caustic or KOH 7.50 ppb Aquagel 0.25 ppb EZ Mud (PHPA) 0.25 ppb PAC-L Adjust YP with Barazan Drill ahead, keeping the pH 8.5 - 9.0 with caustic soda or potassium hydroxide and maintain EZ Mud and PAC (both are polymers) concentrations at initial levels until the system has stabilized in the 17-1/2" hole. Keep the bentonite content in the 7 - 10 ppb range for filtration control and desired wall cake characteristics. Additional PAC may be required for reduced fluid loss near the bottom of the 17-1/2" interval. EZ Mud may be added depending on needed wellbore stabilization with the basic 0.25 ppb level being gradually increased to 0.75 - 10.0 ppb by the 17-1/2" TD. A thinner (Therma-Thin) may be run on an as-needed basis for stabilization of fluid flow properties. Desco-CF may also be used at some point for additional rheological control. Specialty additives for this interval may include sulfonated asphalts (Barotrol) for coal stabilization, drilling soap (Con Det) for bailing problems and a biodegradable lubricant (Torq-Trim II) to control excessive torque and drag. Coal is expected to present some drilling problems in this interval but, except for addition of sulfonated asphalts to the mud system as referenced above, coal problems and their solutions will be mostly mechanical in nature. INTERVAL; HOLE SIZE: CASING SIZE: MI,ID TYPE: 2700' RKB to 7700' RKB (TD) 12-1/4" 9-5/8" Low Solids Non-Dispersed Polymer Mud MUD PARAMETERS WEIGHT: 10.2 - 11.0 ppg VISCOSITY: 40 - 45 sec./qt PV: 15 - 20 YP: 10- 15 pH: 9.0 - 9.5 FILTRATE: 6 cc/30 min. SOLIDS: < 13% Drill the 13-3/8" casing shoe and rat hole, routing returns for disposal. Circulate mud sys~e--m-to even out properties and treat out any remaining cement contamination. Drill to TD, maintaining mud system properties as in the previous section of hole and adjusting gradually to the specific properties listed above as well as those dictated by wellbore conditions. DRILLING FLUID SYSTEM DESCRIPTION MUD STORAGE CAPACITIES · Drill Water 13,060 bbls · Bulk Mud 5,600 cu. ft. · SurgeTanks 100 cu. ft. · Liquid Mud (Active System) 1925 bbls · Sack Storage (Approximate) 1,265 sq. ft. MUD FACILITIES AND EQUIPMENT · Shale Shakers: Brandt dual tandem screen shale shaker mounted on sand trap. Driven by two (2) 5-hp motors. · Desander: Brandt desander unit charged by 8X6R centrifugal pump driven by 100-hp explosion-proof motor. · Mud Cleaner: Brandt dual cleaner including two (2) 3-hp 1,800 rpm explosion- proof motors charged by Mission 8X6R centrifugal pump driven by 100-hp electric motor. · Degasser: Wellco model 6200. · Mud Agitators: 1. One (1) 5-hp explosion-proof electric mud mixer mounted on slugging pit. 2. Four (4) 25-hp explosion-proof electric mud mixers on main mud tanks. 3. Four (4) 2-hp explosion-proof electric mud mixers on sand trap tanks. · Mud-Gas Separator: Global Marine design. · Mud Testing Facilities: Basic kit for viscosity, filtration, weight and titration. · Mud Mixing Pumps: Two (2) Mission 8X6R centrifugal pumps driven by a 100- hp electric motor. · Pit level indicator on active tanks with totalizer at drilling position. · Manifolding to cement surge tank to permit mixing of barite plug at cementing unit. · Gas Detection System: 1. Control Instruments fixed combustible five-point monitor gas detection system with sensors strategically located on the rig. 2. Seigar fixed H2S five-point monitor gas detection system with sensors strategically located on the rig. 0¥ ZOZO~O 06NV dVIN J.O=ld$OHd / 103dSOUd NOgOI:IfllS llNrl U3AIU Dig 0 'OUl 'eqSelV OOl:lV ODOIN¥ NOI:IA3HO ODN~O O NVMOU U OIdlDYd NOINrl dn GUY:lB OOUV %;, u %o~. dn %~- dn %OS-IW %s- u ".,~ - dn . %;- u ~ - rfv %os- iw %s,u ,,/,s, u %~t dn '/,Oz~ an Iot.1.~ 0~-0~-I.~, 1¥Nll1~131 Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of ARCO Alaska, Inc for exception to 20 AAC 25.055 for the ARCO Sturgeon #1. ARCO Alaska, Inc by letter dated June 18, 1990, has re- quested an exception to the provisions of 20 AAC 25.055. The exception would allow drilling the ARCO Sturgeon #1 well from a location closer than 500 feet from the boundary of a 160 acre drilling unit required for a well to explore for oil. The well is located in Section 25, Township 5N, Range 17W of the Seward Meridian. A person who may be harmed if the requested order is issued, may file a written protest prior to 4:00 pm July 13, 1990 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed, and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am July 31, 1990 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after July 13, 1990. If no proper protest is filed, the Commission will consider the issuance of the order without a hearing. ~ Smith Commissioner Alaska Oil & Gas Conservation Commission Published June 28, 1990 ARCO Alaska, Inc. Post Office Bo. J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1990 Beard Oil Company Enterprise Plaza, Suite 200 5600 N. May Avenue Oklahoma City, OK 73112 Atto: Vice President-Land Re: Request for Spacing Exception Sturgeon/ti Dear Sir, Attached is an application from ARCO to the Alaska Oil and Gas Conservation Commission (AOGCC) for exception to Statute 20 AAC 25.055 which defines well spacing rules for exploratory wells. 20 AAC 25.055 states in part that if an exploratory well is located outside of an established unit and the intersection of the wellbore with the objective, potentially hydrocarbon-bearing horizon is within 500' of a quarter section line, an exception to the spacing rules must be obtained and the lease holders of all directly and diagonally offsetting quarter sections notified of the exception request. This letter is intended to satisfy the requirement that Beard Oil Company, as part holder of all directly and diagonally offsetting quarter sections, be so notified. If you have questions or require any additional information, please contact the undersigned. Sincerely, W - {~'infree''' ' - ~ Michael B. Acting Regional Drilling Engineer ARCO Alaska, Inc. is a Subsidiary of AtlanticRlchlieldCompany AR3B-6003-C ARCO Alaska, ~ Post Offic.. Jox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1990 Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Request for Spacing Exception ARCO Sturgeon #1 Dear Commissioner Chatterton, ARCO Alaska, Inc. hereby applies for an exception to the provisions of 20 AA C 25.055 for the drilling of the ARCO Sturgeon #1, for which the proposed location is: (1) Surface Location: 3121' FNL, 445 FEL, Section 25, Township 5N, Range 17W, Seward Meridian (2) Intersection with Top of Target Interval: Same (3) Total Depth: Same The owners of all govemmental quarter sections directly and diagonally offsetting the proposed location of the well are the same and consist of ARCO Alaska, Inc., Beard Oil Company, Union Pacific Resources Company and Rowan Petroleum, Inc. ARCO will act as operator in drilling this well at the proposed location. Attached as required are the following: · Location Plat · Required verification of the information presented here · Copy of notice of application for spacing exception sent to offsetting leaseholders This well is planned as a straight hole with a total depth of approximately 7500'. The nearest wellbore is Richfield Oil Company's Drift River # 1 approximately 2-3/4 miles to the northwest. If you have questions or require any additional information, please contact the undersigned. Sincerely, - Acting Regional Drilling Engineer RECEIVED ARCO Alaska, Inc. is a Subsidiary o! AtlanlicRichlieldCompany Jtlt, l ? 1990 Alaska u. ~ ~as Cons. c0mml... Anchora~ A[t3£~ 6003 C &~J. 50% up · 20% R · · UP -~% TERMINAL up .20% I-il-# AD~ ~ n AM. 31Ml# AOt NUP -5% I - n -5% I - uP LEGEND U ARCO BEARD UP UNION PAC~F~ R ROWAN D DANCO C CHEVRON A AMOCO ' ' //¢/Iora~ ,S/oft OVEBtA* ARCO Alaska, Inc. O ~., cook iNLU. ALASKA ~ BIG RIVER UNIT ~" STURGEON PROSPECT ,~ , ,, LEASE / PROSPECT MAP -" i ..... ~-', ,=--- I, AK90020702 A0 Drilling Equipment Drawworks: National Type. 1625 DE with Elmagco electric brake, driven by three GE 752 electric motors. Drill Line: 7,500 ft. reel capacity of 1-1/2 in. 6 x 19 IPS IWRC. Sandline: 20,000 ft. reel capacity of 9/16 in. 6 x 7 galvanized wire rope. Derrick: Derrick Services International 150 ft. × 30 ft. square galvanized with 1,300,000 lb. static hook Icad capacity. Crown Block: National Type 860-J with 743 ton capacity. Traveling Block and Hook: National 650 ton. Swivel: National P-650. Rotary Table: National Type C-375, independently driven by GE 752 electric motor. Weight Indicator: Martin Decker, Type E. Kelly Spinner: International Tool A-6C-2 with dual motOrs for right and left rotation. Drill Pipe: 10,000 ft., 5 in. Grade "E," 5,000 ft., 5 in. Grade "G." Drill Collars: Thirty 6-1/2 in. × 30 ft.; twenty:four 8 in. x 31 ft. Power Tongs: Joy hydraulically powered drillpipe tongs. Mud Pumps: Two National Type 12-P-160 Triplex single acting pumps each powered by two GE 752 DC electric motors. Mud Mixing: Two Mission 8 x 6R centrifugal pumps. Cementing Units: Halliburton HT-400 powered by two diesel engines. Degasser: Wellco model 6200, charged by 8 x 6R centrifugal pump, driven by 100-HP explosion proof motor. Desander: Brandt unit, charged by 8 x 6R centrifugal pump driven by 100-HP explosion proof motor. Mud Cleaner: Brandt Dual Tandem, including two 3 HP, 1800 RPM explosion proof motors with 8 x 6R centrifugal pump. Shale Shaker: Brandt Dual Tandem screen type mounted on sand trap. Air Compressors: Three 350 CFM 125 psi air compressors with after coolers and one Ingersol-Rand 650 CFM, 40 psi compressor. Blowout Preventer Equipment BOP System: Suitable for H2S service. Stack Size/Rating: 13-5/8 in. 10,000 psi W.P. Ram Preventers: Two double ram preventers. Annular Preventers: One 13-5/8 in. annular blowout preventer rated at 5,000 psi W.P. BOP Handling System: A 68 ton blowout preventer handling system, including air powered hoists and trollies. Choke and Kill Valves: Two 3-1/16 in. 10,000 psi W.P. hydraulically operated valves and, two 3-1/16 in. 10,000 psi manual valves. BOP Control System: One (1) 180 gal. accumulator unit with control manifold, air driven pumps, electric driven pumps and 360 gallon fluid reservoir. Choke and Kill Manifold: 3-1/16 in. 10,000 psi W.P. trimmed for H2S service with one 3 in. maximum orifice manual adjustable and two 3 in. maximum orifice hydraulic chokes with full opening 3 in. bypass line. Diverter System: Hydril 30 in. 2,000 psi system with one 30 in. 2,000 psi annular, drilling spool; one 12 in. 2,000 psi W.P. hydraulically-operated diverter ball valve, two 150 psi W.P. hydraulically-operated port and starboard overboard valves. Auxiliary Equipment Water Distillation Unit: Koomey reverse osmosis, rated at 10,000 GPD. Waste Treatment: Omnipure sewage treatment unit. Welding Equipment: Three 400 amp Lincoln electrically driven units. pRINCIPAI CHARACTERISTICS Barge Information Length Overall: Width: Depth of Hull: Diameter of SpUd Cans: Height of Spud Cans: Allowable Variable Load (Drilling): Substructure: Cantilever: Crew Quarters: Cranes: Elevating System: Drilling .Depth: Operating Water Depth: Maximum: Minimum: 243 ft. 20O ft. 26 ft. 46 ft. 24 ft. 2,679 s. tons (approx.) Cantilevered sub-base with the following capacity: Rotary Load 450 s. tons Setback Load 225 s. tons Center of rotary can be positioned a maximum of 12 ft. either side of hull centerline and a maximum of 45 ft. aft of the hull. Air conditioned bunking and galley facilities certified for 90 persons, plus 6 hospital berths. Three Marathon LeTourneau PCM-120 all electric, 2 with 120 ft. booms and one with a 100 ft. boom. Rated at 50 s. tons at 24 ft. radius. LeTourneau rack and pinion--90 ft. per hour continuous rate. (approx.) 25,000 ft. capability. 3O0 ft. 25 ft. Storage ,Capacities Sacked Materials: 1,265 sq. ft. Liquid Mud: 1,760 bbls. Bulk Cement: 4,200 cu. ft. Potable Water: 1,217 bbls. Dry Bulk Mud: 5,600 cu. ft. Drilling Water: 8,000 bbls. Surge Tanks: 100 cu. ft. Tubular Storage: 4,300 sq. ft. Fuel: 2,798 bbls. Power Generation Power Conversion Emergency Power Five diesel electric generating sets, each one consisting of a CAT D-399 TA supercharged after cooled diesel engine driving a KATO SCR duty generator rated 800 kw, 1334 KVA, 600 volts, 3 phase, 0.6 power factor at 1200 RPM. Ross-Hill SCR power conversion system. One KATO generator rated at 400 kw/480 volts; 3 phase driven by a CAT D-379 diesel engine rated at 600 HP at 1,200 RPM. Communications Equipment SSB transceiver Magnavox MX-211 satellite Communications system VHF-AM aircraft radio VHF FM marine transceiver Gaitronics intercom system Loading and Towing Data Average Towing Speed: Maximum Leg Length for locations tow: Maximum Leg Length for ocean tows: Preload Capacity: 4 knots with 9,000 HP tug. 410 ft. 310 ft. 5,974 s. tons (approx.) Lifeboats Two 50 men U.S.C.G. approved capsules. Sufficient life rafts and life jackets for all personnel. - (2" thru 8) (8) [3) Admin fp~- ~ (9 thru 13) (10 and 13) (14 thru 22.) (23 thru 28) [6) OTHER 01/30/89 Company ,.~.~2 Lease & Well No. ~~ YES NO Is the perm.it fee attached .......................................... e 10. 11. 12. 13. 2. Is well to' 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 wel!bore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 3ocs operator have a bond in £o~c~~. ................................. is a conservation order needed ~'. ................................... Is adm.i.~istrati*e approval needed ................................... Is the lease number appropriate ..................................... Does :he well have a unique name and number ......................... F . _ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Is cdnductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circuiate on conductor and surface ......... Will cement tie in surface and intermediate or produc=ion strings ... Will cement cover all known productive horizons ..................... Will ail casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old we!lbore 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 ~O~O psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UN IT 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. T° 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. .o P A (; E: chlur~'c, er:~er nla~ka Co:"'~;ut:Jnd. Celt, er' 23-oC."1'-!.990 Ii:30 Company Field t:ame a[:'X ~e r ia 1. Fie!.d I.,ocation Sect io~ Town s h I p Cot,~pty State or Province ?'.~ a t i o p Service.. Order ~'~um~er Permanent datum ~:levati. on of Perm. Datum Loq ~:east.2red From .~FOVE PER~,~A(,IE~T DATUM El. evation of Kell. V Bushino E!evation off Oerric¢. Fl. oor E!evation off Ground Level ~"otal Depth - Total, DePth - I,,oqqer ~ottom bo~] rnterval 'ror.~ bo~ Interval Or].ll. ir~ Flui~ Type 9ri].lin~ Fluid Density i}ri!line ['luid Ph brillipa F3. uiO Viscosit~ :)rtl].jD~, F'iuJO boss ~esfsti~itV of Mud Sample ','~d 5amp]e Temperature ~esJ. stiv~t.~ of mud filtrate s ~,u~ Filt~'ate Sample Temperatu ~'esistivity o~ ~.ud CaKe .~u~ Cake Sample Temperature 'rime Circulation Stopped 'rir,-,e f,ocaer ht aottom PAGE OSg'666- 0qg'666- 666- O~g'666- O~g'66b- 0.qg'666- O00'O~ O00'gOq .'F,/E ' ~ I [' Oqg'666- O~F~'OLg 000' 0~. 8~g'~ O~g'666- 0qg'666- 0~666- O~g'666- 0§g~666 o~ 6662 Ogg'666- O~g'666- O00'O~g O00'gO9 O00'g~Lgg O§[.~66- OSE.OLg ooo -999. 250 - 999,250 -~qq 250 -999. 250 6.293 6. (! 6 3 '?, o 7 sO ('~. 960 4:! 7.5o0 26,75O -43.813 I ~. 9 3 8 eib2 . 39i. O00 I, 6 23 3 05.0 0 0 2266,5]0 :! 28. 975 5.496 5.621 175.625 ! 71. 250 (}, 96 1 433. 000 2'7.78i 25.213 10.500 561.00 ~:) 370.5Pt') 3 ! 3.7 50 4S.2'71 3.553 3F. 2(.,3.50O 0.963 2:3, 6,053 .1. (~ {i C; 3(:7. 2,209 5.50 0 ~ 0 9 t) ,.,s ~ . TNP.q, R C F T, C ~:! L '999,250 -995), -999,2,,0 -o,:~' 250 5,973 2O 000 164 750 35 2!9 -43 813 56 0,000 3 03,00 61.655 '0,034 539,500 i. 358,000 1.659 1.28 975 32 600 613 o29 20,891 3 1 6,000 5,273 20,000 177,'750 37.594 25 813 577 000 301 750 3! 102 -0 061 30O 25O !360.000 1,990 129.031 44,64B 478,7~6 1,4,6B8 353.000 3.639 20,000 281,250 23.375 103,938 668.500 293.750 !6.434 -0.006 173,375 !361.000 2,]16 128.91~ 44.57b ' ], 6,4~"i 62'!. 5(>0 TT2, BHC 26,172 F; i,4 C 0 n I 7 P ¢6 '"" Li]i'T q37 [i',~,' ,., t ~ . 352.461 GR 21!4..355 25,78I I28.9!:.9 1.0 ? 9 744 5,,50 0,963 616,000 4C,, 094 J, 6 7, o <:~ () 4.229 540,156 .338,039 2 , 0 ('} 0 321,750 53,162 1740.688 46,969 128,847 7.426 8,375 i 10.000 !27,.125 O, 961 5 i 9.5 5'7,2iq 257. 4. 129 334. 250 322,75(! 327,5 ," ! 814, 61,500 ! 20. 26 (;, 24:4, C.959 42~. 25t.' 32(:. 250 ~' , 1 'l 2 449.75C /. 9 ~. 0 0 .. 33.2 o 7 ~39R,q18 ~'CFT, CALl'. PAGg: It 521,,749 16,031 423,500 i,,061 '20,000 953,000 62,219 I67,000 822,500 3t9,250 37,482 -0.019 302 ~9~ 1361 000 2 Or1 128 847 3,094 3 7,672 15'914 450,395 8 984 2O 0o0 119 375 61 031 257 250 795,500 305,000 I7,605 -0,014 183'875 1360.000 2.279 129,144 44.833 444,44! i3.805 516,500 3,648 20.000 256,000 60.938 320,250 626,500 320,000 26,t07 -0.038 246,125 13¢,0.000 2.111 129,538 3.3 6B9 659:46B 606'~g 800'~ O00'09[[ B£O'O- O00'OS~ 00~'§~ O00:Og 0£~ Ol 9~6"0L9 000'09£~ 9~0'0 0£0~0~ 000 000 OOS Eg§ L6 00§ 9L 000 OE O00'[E9 O00'09E'[ ~0~0- O§L'TOE 000'£E9 O00'OE q?~D ' 6 9 :V ' £'9 b =4 [ 'l s 'i u <.', '.t." ~ e o "[ '.$ ':/' .i a ~\ ;.~ J e ,i, S' 'i: 0,000 J. 23.9 640.50 o 439, 216,375 38.531 0.957 I 2 "7 . b i.'! 1 I. 5, I. 6,781. 6 ! . OOf O, 970 37C:, 250 47.625 479.25o 7,555 379,250 351,25'J 2, l. q7 291.750 18.920 31 '11, ~ 44 50.688 ~'" 3,0 ! 0 2. 984 273'75n 446,250 42.46":) 517, () 0 0 4,496 4! 1,75O 324,750 2,146 2~6.25o 34,523 ~4.68,7 ~ 5 3~¢.53I 126.950 '~. 492 .-.' ~ 5.477 56. ~ 75 ~7i.375 '3 ~, 750 ~)7. 500 't 6.25 t', 1. o ] 7 P 5.5 r'.) 0 33.222 90,61 .l 12b, 106 P AGE: I 3 662.000 i. 4,406 ~.000 , 563 55,531 4'19,250 537. 000 295,500 17, !.25 2~0,043 ..2,250 ! 360,000 2 207 127 175 lS 783 1.258 501 14,06] 7 0 1,00 () 3,152 20,000 334:,750 45,875 517,000 649,000 292,500 28,022 '0,009 233,500 1360.000 2 160 126:950 35,647 594.680 ~7.64! 599.000 5.582 20.000 !.82.500 30,188 571.000 604,500 284,250 37,850 '0.072 314,500 !358,000 1.948 126.106 33,539 652,491 18,32~ 687.000 ~0 0 000'96§ O00'O~L ~EL'~g 89§:OLL LLL,£C 8E6'§[I 000'09[[ 696 ~Io 0' 899 000 89g 000 000 SL9 90 b E O00'Og OOS 9£L 696 9} 986 i ()~g L6E ELO O- L9~ gE Ogg 96g OOg OOg 8~9 ooo o[ 6g~ L (} i:: I: ':[ :..J 6 6 T - .]1D O- C F: ~L~ ~J oog LO0 000~9~ 000'019 000 0£~ §@9 9~5~ t~ 000 8£0°0 000~09 .~ O00*Og Lg~'69B ~6~'~L~ §~0 L~£~ ~Io O- O00'OS~ O00~LL9 O00'~g8 O~L'O,~ 000~0~ O~L ~['~ 00~°8~[ 0'[0~0 00~'9C8 O00~OE LLL'E98 8E6'9[L 9LL'9£ 000 6§E't ~L8 8Li 010 0 8g~'Og OgL~£gg 000 06~ O00"Og Oge'6 9T . . : i 3 ::) ' :5 :::,/i 2,q L ~, "~. 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O3 '] 263,9 0 (~ 42,923 2115,250 3e.. 26O 2}i. !09 31., 000 3O, 297 1.0i.5 7 0 {'300 a 5.0 00 4,465 ! 0. 26!.000 2.555 76,750 13,452 a29[>, '3~6 38. 938 20.031 5.363 5.293 175.375 ! .01.9 4t!6.0'~') ~t4.53! 4.828 5(.~.125 330,212 ! ,96! 256.89! 39.441 42.glg 120. 594 PAG~i: t 7 12 984 2O 00o 80 500 41. 625 n6~3 500 743,750 38,22~ -0,0!2 2~7.~0~ I35~,000 ,045 121,588 41,293 575,938 12,714 874,000 28,828 20,000 32,219 34,469 885,000 509,750 233,750 4,440 0.012 110,938 I359,000 2.572 120,931: 15,469 2102.965 12.109 895.500 000 47.000 U96.000 684o500 241,250 40.544 -0,017 316,094 135~.000 1o9~4 120.5q4 38,345 ~62,000 13.58b a90.o76 2'~-0C:i'-1q9{~ !t 1730 6 0 1 'f Ei 6.43 . -1 16. ! 0 4 ,::', 4 222 ?. 5 0 5,4 ~ ~.~ 5. 531 17 }, 000 171,375 1,023 500.75 0 44,688 9 lli 6.500 7.594 5 30,0 00 347,750 1' 99t~ 2~8,750 44,2S2 947. 969 ~19.q75 17 . 58.9 :) 6 5 '7.6 , . ..": 0, I. 4,4:7 2 51 '2,5 235, 28.71.2 3102, lo2 4q.313 119,300 5.824 161.625 1.932 4 :i E. 0 {'; 39,250 5.621 350,2_50 ?, 1. n5 231,259 5 (}, (} ¢ 0 118.73U PAGE: 1 R ,598 2.,000 180,625 906'500 69~,000 245,625 36,329 '0,026 295,250 1357,.000 2,02t ~!9.975 552.660 12,922 ~88.500 t. 5,609 2(:}, 57,406 ..':i 5,500 920.500 5 '~ 9.5 (,? 0 3 9,44 2 -0,0 ! 5 2 ~;', 5.5OO 2.0]9 1i9.]00 31.!9.3 12.195 ~99 ' uO0 0,070 20,000 172.875 54,688 948,500 645.000 235.625 30,~97 '0,028 244,000 1356.000 2.123 118,738 ]5.776 679.097 12,57E 9{)7.0{)0 ].3. ()1 .3,148 75,625 72,8!3 ]' 034 449 · 000 948. 4,02'7 2 7 a, 2¢4, 2,381 236'8?5 ~5.682 ~5~5.37~ 4 3.06 3 i.'18,119 6,891. 6. 777 37,~2b I, O4O 5 17,5 {1)0 ~ (;, ' 5 '.~ .t., 97 .t.. ' 5 (.:' 0 1. C}79,000 359,~50 ! ,6!8 ,~ ,. - 55.783 38,313 1 i 7, I !., D, [: T E IE'RE.DTE H T 'E !:,i, b T ~.; D F N I', L D T QLS , I.. 9T bb , LDT L,U RH, LOT ~i T ~.' ~i, LOT T:NPH, CNL ~CF'];' CALl p A G E;: 10 12,406 20,000 76; oo0 45.68. 597 500 230 000 1.5 187 0'01.6 153,250 1.358,000 !18 119 :17 879 1805 629 12 297 908,500 7,016 2o,0oo I47 375 43 531 971 500 703 500 219 375 62,152 -0,023 557,000 1~57 000 1.~65i 1!7,500 51.640 427.541 16,063 926.50{) 5,207 20,000 !~8,750 55,813 <)79.{}00 'l I 3, %}t': U 2 ~ 3. 7 5 0 23, '2~:, ¢1 · . 36.636 64!,309 16,172 922.500 6.~37 6.770 I 44,250 5 1!53, r 51.53! 973,5,3O 6 . 590 ~,.2. 9 2'! 1 2275,627 93 50, . !~6.3!9 9. ~75 10,438 , 00. 0 !..051 4:3 () * 7 39. 979, 2.325 3261. 37,356 !!6.038 4,7C3 4. h l. 3 195,8't 5 49g. 34.625 327.7~() 2 , 't 6 a 21eF.~}r,t PAGE; 20 6,781. 20,00(.) 147,625 55 063 973 500 71.4 000 213 750 23 '0,011 200,!25 358,00 (} 2,238 1i6,319 35,064 t~40,651 14,117 933,50O 9,I..48 20,000 95,750 39'844 979,000 632,500 ~?0 000 2;56.9 '0,00! 166,645 ~]57,846 2 342 116 03@ 24 771 1074 O63 13 5OO 943.308 5.383 20,000 207,625 40,156 983,500 704,000 209,375 2~.'73b -0,017 222,O00 1357.000 2.180 115.306 35.~04 5g~,60b !5.969 94~.000 C h } 0 mi:: e T C e 'r 2 .,.,~ ~ ,:~,~ k ~ C o r-0 ~":;~ !'t t,. 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E~ 7 [., S R h, i.., i)T 0 b ] 3 .) i f.~4,93g 1.. 0 79 0 '7 5{) 100!.. 5OO 3,525 27 ~',, 5 0 0 28 (}. 2 50 2. ::389 1 r:: 7 5 {") .' ~., 26, S:16 2594:052 34.469 7,5 o 4 1,2~;.6767 I. 086 59,906 (')04. 500 3,51 ~} 317,59 (} 299. 009 2 .~iO 34,8i4 i :1 ii . 7 2 P A GE; i4,789 20,000 64.813 ~4,063 1001,500 6'/9,000 196,2~0 i5,061 -0,005 .1,5(:),]_,25 i. 357'000 2,395 · 1!,762 125,930 8'/!,427 18,109 945.500 '/,922 20,000 1.30,250 56.438 :1004,500 712,500 207,500 18.861 -0,040 ].6'7,125 1~56,000 2.311 111,762 34.358 b53.915 1~,~22 :~ 45, "ii: :, '/. '73 c 7 i.. ~i.~ '7 4 ~ ,"-', , ! ¢1c · ...~ ~ ! q. 38.b' 1356.000 2,3ig !09,906 ~6'895 t~53.~56 15,039 759,834 22., 5.727 i 5 ? ,, 6 2 5 1 . 10i 4.492 296.5o(; 295.250 2.340 223 125 30 788 25S7 992 4 b. ~ ! 3 t5.7~7 I7.?~ ~., (.'.. 3:1..3 .1,!2'7 362. 'It;."_) i()].5.(:C~' 20b.332 260. ~ 44 2I 7. 4 3. ! r, t 1 'f,i..') ['~ T E ill 1. F r:t ~:j, D i' r: <;f~, F '~ ~'''' ': 0 7"t 3. ~.:!,5. LOT j.,l,. I., 9T ," .:: ;r. C ", ,':'!':" ,C' r PAGE: 23 6,23~ 2{),000 174.500 ~3.063 1016,000 72t,500 1.98,125 17,130 0~000 164.000 !358'000 2.352 32.443 730.055 15,953 836,000 7.633 2{).000 132.~75 49.500 t017.500 761..500 ,. I79.375 25.923 0,01!. 2!3,625 1356,000 2 221 !09~906 32.018 761.431 1.5,063 g77.000 12,578 2O.O0O 56.313 46.281 1015.000 594.000 18~.875 2.7 4O -0.016 104,066 1357,000 2.586 t09,231 ::1..6,840 1966.250 ].4,q67 '-' n'7 00q"~£6 060'68L 000'90~ ~00'0 O§L"£L~ O00'~L 000'£[0I 90~"~ O00,O~ '~66'L0[ O00'qgEt ~00'0- 000~£ OOg,OtOt 889'q 23-(,'~{:T-!99<! l~ :3fl .!,!,.867 i ,I., q 44 42,563 79,81 3 () , 3 4 0 % 32.000 35.03! 2,299 312.5 () 2,162 !77.500 35, 2090. 657 122,250 9. 828 !4.71! 96,25O 0,33 '1 32.J. 88 359.32() 302. 2. 237 177.055 27.32~ '27 .I r~ 5.207 lC0.938 '! ;~, C. 50 (.~, 32.' 7 e:, .43 o 5 r, U 2 9.4 ~ 9 2.5~4 35 g. 25 ~, 2.]!I I 377, ~ ~'t 124,43~ P A G E; 25 22,609 20,000 84. 375 35 031 1.. 04S 000 757 000 57.500 27,813 0 000 233 ~25 .t.~357 000 2 t68 1oo' .... 3 5"13 ' 965 9]7 ~ 000 20.156 20. 000 67.938 32,188 1054,000 ao8. ooo . !.61, ,8~5 24,O 6 -0,006 201,484 1355,000 2,239 1..23.705 31,243 773,844 i8,904 947,500 9,820 2O.OOO 200,250 29,469 1080,000 ~06,500 171,875 24.125 -0.007 ~56.250 1356.000 2.1!3 124,43g 55.955 307'287 2~,047 102o.500 5 . 762 5.7!9 !. 33.875 :I63,3'75 0.333 5 (: 6.75 0 ~;2,3 ¢.4 .! 06. 9.00 () 5~4. 555 349,i64 I. 964 1'73, I 7 2 4,2 91 37.~75 1. 2 4,9 72 *,.'~ 5. 64 ! 7 (? 0 5 96 23, ~4..~ 1.07! 2 445 3 26 ! 71 51 I 49 ~ 3 r.:, PAG',.F2: 26 ?.414 20.©00 174.750 42 344 1069 000 724, 000 173 125 37 274 -0,0t3 332,'~73 1356.000 !,969 124,972 46,881 368,648 20,0~9 974,273 t5.1.17 20.000 t77,875 23,844 !071.000 7~3,500 168,750 3().272 0,000 257,250 1357.000 2 117 124~563 49.176 324.411 18.859 q57.000 . i S - ~ Q (h . 722 7,5 0 u ib9.375 580, o {) 0 4:0.500 1,g66 352. 750 ! 153.750 !~ 7~, 468 ~2,5OO 5,539 t OO, 063 !67.75o. 0,342 599. OC, O 42,688 l 0 '75. O () 0 2,092 823. 072 392.785 ~7~.6~5 5(:. 49 J 122.0O0 6.4!8 f:. 7'70 74.~75 146.,75 0,.337 (; 77. 2.855 444, 337. 2.1i7 162.222 ~3 7~2 ! 2 ~. 7. 898 20,,000 1,89.250 1099,000 a38'000 1 .66,87 5 54.110 0,006 4:87,250 i, 35'/,000 1,756. 122,875 45*626 36~..033 !9 266 o:0o 9,797 20.000 l~0,500 42.688 !075 000 834 000 161 250 47,271 445.395 1356,000 1,789 !22,000 55.967 297.422 . 20,094 966,570 12 906 20~o0o 147'625 50.656 lo77.000 ~70.500 lql,875 27.277 '0,020 249.250 1355.778 2,119 J21.076 52.608 289,289 19,205 967.556 ..... ,,: ~7 ,a -~ .s 4,199 !14.938 225. 000 0.3 ,:'~ 0 584°000 31,29'7 ! ! ! 0, C: (';, o 2,4q~ 397.0(; 0 3!3.0f)0 2. ] F; 0 !4.8.750 37 ' 1 ~7 2! 76, 41.313 !25. 125 5. 258 5 o ~ 3 ~ 1 o 9.0 63 178.875 0,34.4 5 4 4.5 0 0 32.1,25 . 0 ('! 0 1.~ 1.5o , 3,4i4 3?5. 311,5OO t 46. 37 , 436 ~()41 .6(')4 41 .53! 123.250 4.23~4 4.035 I 1 ~, 22'1.!25 I !2'3. C~Q<I 3.3t, 7 3 9 ~, 0 c'~ {., I, b7.SE3 I ~ 2'1,068 PAGE: 28 8,609 20'000 238.000 31,297 !110.000 133,750 27,095 -0,005 225,375 !.356,000 2,182 '125 ~ . 5~!.957 18,34:~ 964.500 9.055 20'000 190'~75 32,125 1115,000 79,000 53,750 18.519 0 00~ 183'750 1357.000 2'29'/ 123.250 39'544 504,021 la,9~4 969.500 8.586 20,000 247,625 44.8!3 1!23,000 agO.O00 127.500 42.486 -0.032 413.000 1355,000 1.~34 122.063 5~.335 306,959 20.969 997.500 7. :7 2.7 q {) :! ! 3. (,: <::' O. 3 3 7 32,531 1126. !,!95 35~, ! a 3 750 i43~,6a4 33.938 122.938 I [,D. DTE I F n P..:, C. l. i~., P. T T 3. P, H C !.::PF ! . T !.:, [., F' 'if' ! ,": P.~'. C'., 1., F:CF! .CLL PAGE: 29 !3,51° 20,000 i ,34, 32.531 1126 000 833 000 135 625 5..8,48O 5~0 009 3:500 1,356,000 1,690 122.938 74,023 281.911 1.8,531 973,000 1~50,000 20,000 -934,500 24.984 1i. 20,o00 484,750 123.750 -999,250 -999.250 -999,250 -999,250 -999,250 -999,~50 -99g,250 -999.250 -999.250 -999.250 1_ 95 0,0 0 0 ~95:'), O00 2,3 0,0 ('; ~) - 9 33,5 (} () 0, ,~ 39 519.0o0 -999.25O -999,250 - 99 9.250 -999.~50 -999.250 -999,250 .9c~9' 250 -999,250 -999.250 1950 000 20 000 -934 000 19 203 '1. 119,000 594,000 135,000 -999°250 . c 9' 250· 99:: ,, '999,25£. -999,25(:i) -999,250 '999~250 '999 , 250 -999 ~50 -999 250 '999 250 50-733-2U4 i q 0 5 10 LEGEND: Original Survey Area Bell Navigation Aid REDOUBT NORTH BASE DRIFT RIVER j~ TERMINAL AREA OF DETAILED /FINAL ARCO ALASKA BATHYMETRY. ~_ LOCATION 4,800 ~." .-' KA lin co. ::::::::::::::::!:j~ ::; LOCATION ~ (Summer ; ~" ! only) o· · · .. , · .' .' ,' oO o.o REFERENCE POINTS - ASPC ZONE 5 · NORTH KALGIN x ---- 870,230.73 y -- 2,383,794.54 · HARLEY (offset) × --- 866,362.74 y -- 2,352,197.50 · HARRIETT POINT LIGHT x ---819,173.26 y --- 2,341,200.80 · REDOUBT NORTH BASE (R.M.2) x--- 809,442.92 y -- 2,388,443.74 PLATE I NIKISHKA KENAI ENSR Consulting and Engineering SURVEY COVERAGE SHALLOW HAZARDS SURVEY ARCO STURGEON No. 1 REDOUBT BAY, ALASKA Lease Block ADL 359110 and surrounding area PREPARED FOR: ARCO ALASKA, INC. DATE: SEPT. 1990 SCALE: N.T.S. PROJECT NO: 0480-110
