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Home My WebLink About183-173MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-22 PRUDHOE BAY UNIT 09-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 09-22 50-029-21049-00-00 183-173-0 W SPT 8606 1831730 2400 1757 1755 1756 1757 69 273 277 275 REQVAR P Sully Sullivan 9/6/2025 2 year MIT to MAIP (2400 psi) Per AIO 4E.041 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-22 Inspection Date: Tubing OA Packer Depth 183 2607 2557 2544IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250910143011 BBL Pumped:5.2 BBL Returned:5.2 Wednesday, October 22, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-22 PRUDHOE BAY UNIT 09-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 09-22 50-029-21049-00-00 183-173-0 W SPT 8606 1831730 2400 1247 1249 1248 1249 341 572 571 567 REQVAR P Josh Hunt 9/9/2023 2 year MIT-IA per AIO 4E.041 Max A/I 2400 psi. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 09-22 Inspection Date: Tubing OA Packer Depth 289 2555 2517 2503IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH230909123544 BBL Pumped:5.9 BBL Returned:5.2 Tuesday, October 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 9 AIO 4E.041 James B. Regg Digitally signed by James B. Regg Date: 2023.10.17 14:39:51 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector l NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 11, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 09-22 PRUDHOE BAY UNIT 09-22 Src: Inspector Reviewed B P.I. Supry Comm Well Name PRUDHOE BAY UNIT 09-22 API Well Number 50-029-21049-00-00 Inspector Name: Bob Noble Permit Number: 183-173-0 Inspection Date: 9/12/2021 IRsp Num: mitRCN210912155645 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F 09-22 Type Inj w . TVD 8606 - Tubing 1779 - 1785 1773- 1749, - PTD 1831730 Type Test SPT Test psi 2200 - IA 351 2506 - 2486 2476 ' BBL Pumped: 5.8 - IBBL Returned: 5.3 I OA 336 - 508 - 516 523 Interval REQV AR PAF P ✓I Notes: 2 year to max anticipated injection pressure of 2200 psi as per AA A10 4E.041 i✓' Monday, October 11, 2021 Page i of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg n DATE: Thursday, October 3, 2019 pp� P.I. Supervisor �� /L� tU x(15 SUBJECT: Mechanical Integrity Tests [[ / BP Exploration (Alaska) Inc. 09-22 FROM: Bob Noble PRUDHOE BAY UNIT 09-22 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Z�52— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-22 API Well Number 50-029-21049-00-00 Inspector Name: Bob Noble Permit Number: 183-173-0 - Inspection Date: 9/26/2019 Insp Num: mitRCN190928093535 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We11 09-22 Type Inj w ` TVD 8606 Tubing 1366 1367 - 1349 - 1372 " PTD 1831730 Type Test SPT Test psi 2500 - IA 96 2502 - 24 2483 BBL Pumped: BBL Returned: 5 — O 401 628 - ]62838622 InQvAR P/F P ., Notes: AA AIO 4E.041, Every 2 years to max injection psi of 2500. Thursday, October 3, 2019 Page 1 of 1 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 13,2017 TO: Jim Regg I SUBJECT: Mechanical Integrity Tests W� 9� P.I.Supervisor ,4( 1111 BP EXPLORATION(ALASKA)INC. 09-22 FROM: Jeff Jones PRUDHOE BAY UNIT 09-22 Petroleum Inspector Src: Inspector Reviewed Bye,, P.I.Supry LI NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-22 API Well Number 50-029-21049-00-00 Inspector Name: Jeff Jones Permit Number: 183-173-0 Inspection Date: 9/12/2017 Insp Num: mitJJ170912194940 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-22 ' Type Inj W TVD 8606 ' Tubing 1345 1346 - 1350 1353 ' PTD 1831730 ' Type Test SPT Test psi 2152 - IA 453 2447 • 2431 2424 " BBL Pumped: 4.5 BBL Returned: 4 OA 599 793 - 797 " 788 , Interval REQVAR P/F P Notes: 1 well inspected,no exceptions noted. SCANNED -E$ .t 'wJ Wednesday,September 13,2017 Page 1 of 1 • STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate m Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 183-173 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-21049-00-00 7. Property Designation(Lease Number): ADL 0028345 8. Well Name and Number: PBU 09-22 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13125 feet Plugs measured feet true vertical 9134 feet Junk measured 12978 feet JUL 13 2017 Effective Depth: measured 13084 feet Packer measured 12495 feet true vertical 9099 feet Packer true vertical 8609 feet AOGC,/C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface 2790 13-3/8"72#L-80 34-2825 34-2553 4930 2670 Intermediate 12831 9-5/8"47#L-80 32-12863 32-8912 6870 4760 Production Liner 585 7"29#L-80 12541-13127 8646-9136 8160 7020 Perforation Depth: Measured depth: 12840-12841 feet 12852-12853 feet 12863-12868 feet 12868-12869 feet 12869-12877 feet 12890-12892 feet 12892-12905 feet 12905-1 2917 feet 12922-12937 feet 12944-12949 feet True vertical depth: 8892-8893 feet feet 8903-8903 feet 8912-8916 feet 8916-8917 feet 8917-8924 feet 8935-8936 feet 8936-8947 feet 8947-8957 feet 8962-8974 feet 8980-8985 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"Baker FHL Packer 12495 8609 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): AUG0 (} Treatment descriptions including volumes used and final pressure: SCANNED G 1 241+- 7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -7322 180 1640 Subsequent to operation: -9403 420 1503 14.Attachments:(required per 20 AAC 25.070.25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work:J/ Oil 0 Gas El WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ �e WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Ohms,Danielle H Contact Name: Ohms,Danielle H Authorized Title: Petr Engineering Discipl• Lead Alaska Contact Email: Danielle.Ohms@bp.com e Authorized Signature: d � �- Date: 7_42 _1 7 Contact Phone: +1 907 564 5759 Form 10-404 Revised 04/2017 v--n. WI 3 //1 ,77/07 Ir7t" Y, "i 1,1 4 2"I.7 Submit Original Only • • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED RE: BP Exploration (Alaska), Inc. JUL. 13 2017 Report of Sundry Well Operations Summary AOGCC June 29, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well 09-22, PTD # 183-173. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • • 0) • 00000 la ti CON 00 O CO N- O N ►n O N Tr ti CO Ns V L OO) M O- COO Tr C) • d' C) 00 '— N cf Tr CO 00 Ns 00 in M (NJ (0c- T CC) e- C) O N- LCI CD v- UD N 00 O) 00 CO 0 iPI— (D tC) N c- O 00 M M CO(0 C') CO c') I- LOO CnCO N 00 Is N 00 - Tr U') r- ON M N N N r �- r V Co T- CI I I II � N v-- Q lnTrN � � � 01 M 01 N Ch N • � • MM • W a O O OOD O O OD co ODOD 1. r - (I) N N CV U) I— N VD 011 US '7 bhh N W � Q c0 ' U W W V 0u_ Ce ce00 Z ccW W m 00 OF Z U !n Z J F- I- • • 0 . w "?w o ti p o Co o * Z CO N CO Li o 0 d II d II cc E >- m = m = I- sg Z m a CO a~ cc ci I-1-1 w < .� Q (1) 0 cn 0 w o p =a. = a Ex 2 M - o IA 0 O N CC _4 - Z CO p * co w U w U _ j U-IyCVv0 p RI LL CL - d F =m � ci) � QO CL = m1- CL y- . 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Z EL O * � NZ nLL = m0 � J < 0 < m 0 JQQIJt-iCOi 4C ~ I" II C' _0 > U_ > J Q 9+ Q � � E > ZofY LU�' LTJ 0 0 EtHHwWaw ~ ooin z cn z i_ 0, Q ~ I- CCLL00 + 0ZLID Nw LU p W LU p inw OmmO � co0o > > II p I- p I- w II 0- >- } u- = Ncn = OQ ¢ < < I- 2 T - Zzc0cncncw ft w Ce c QC) JZ - J J = 0 = O ZF- o- - ZOJ ,_ JJ - wLL --- LLi Lc1 = � � � = 00 �° < QO0c 03 ° 0 � IL = Z co N • HH * « « iZa .- - 4,YCOCDCC CL 0 w I- Q f- N- N- N- p 0 0 0 0 w CI H iii co a) O co N > N N N co m I- in ir) (n U Q Mil= FMC GEN 3 I SA Fll ;,10TE_S.142S REA C1NGS AVERAGE 125 ppm WEEN Mall-VA D= FMC I • ON ELL REQUIRES A SSSV WHEN ON MI — A:ACTUATOR= AXELSON 09-22 CONPOSITE liMRAP REPAIR SH LEAK-DO NOT MT-0A OKB ELEV= 55 OVER 1200 PSI DUE TO DESIGNED PRESSURE RA TING OF BF.ELEV= I REPAIR&DO NO T R.MD Ii.,ETH OR I.C.I1-1 BLEND INTO OA I KOP= 1000'1 (XE TO CHEM INCX)AtI3A TIBILITY w/EPDXY RESIN— 2200 Pi,fax Angle= 58°@ 97001 psi(ZERO SAFETY FACTOR)PATCF-FLEX COLLAPSE Datum MD= 12795RATING R-L/TIWI-EIBPPKRS HAVE RECUCED TEST PRESS I Datum TVD= 8800'SSI LIMITS El SORE CASES CONTACT ACE(X5102)FRIOR TO PRESSURE I e_blING D _ 2378' 15-1/2"SSSV NIP,1".:i=4.562"1 —1 1 13-3/8"CSG, 72#,L-80 BTC,ID=12_347" I-- 2824' Minimum ID = 3.725" © 12562' :4-1/2" OTIS XN NIPPLE , i 12469' H 5-1/2"BKR FBR ASSY --, 5-1/2'TBG-PC, 17#,L-80, 0232 bpf,C=4_892" H 12483' 1 ! 12483' 1 I--;L___5-1/2"X4-1/2"X0-.ID=3.958" *MEI 11,217-11 , 12493' _I It 9-518"X 4-1/2"BKR FM RKR TOP Of 7"LM R I--I 12539' i li I 12562' H 4-1/2'OTIS XN NV 13=3.725" 12573' Ji—I4-1/2"BKR SHEAROUT SUB i I 4-1/2"TBG-FC, 126# L-80, —j' 12574' I 12574' I—I4-1/2"WLEG,I)=3.958 .0152 bpf,10=3 958" " 9 12545' I-Haw-IT LOGGED 05/13/85 , 12840' h 7'CRILLFLEA FTG-ra-i(SET 03/17/98) 1 I COLLAPSE RATING 2200 PSI(ZERO L .17. ii.:_-.... I 9-5/8"CSC,47#,L-80 BUTT,i0=8.681 I-1 12862' ;—A SAFETY FACTOR),ID=5 280" I ! PERFORATION SUMMARY I REF LOG: 131-CS ON 02/05/84 ANGLE AT TOP FERE 33'@ 12852 Note.Refer to Production 06 for historical perf data SIZE SPE INTERVAL Opn/Sqz 1 DATE I I i 3-318" 1 12840- 12841 ' S 11/22/89 3-3/8" 1 12852- 12853 0 11/22/89'I I 3-3/8" 6 12863-12877 0 05/30/17 ; I 3-3/8" 1 12868 12869 0 11/22/89' 3-3/8" 6 12890- 12905 0 05/30/17 3-3/8" 4 12892- 12917 S I 05/10/85 I 3-3/8" 4 12922- 12937 0 05/14/88 ; I 1 3-3/8" 4 12944. 12949 0 05/14/88 I I ! I1 411kr 12978' ,—RSH-DRLLFLEX PATCH(LOST 01/01/98) _ P4317-1D I—I 13084' ' / 4 WAIVAWA•AvAiva 7"LNR,29#,L-80 BUTT, .0371 bpf,ID=6.184" IH 13125' ' DATE I REV BY — COmMENTs I DATE REV BY I COMMENTS I PRUDHOE BAY UNIT i ,02112/84i ORIGINAL COMPLETION 05/31/17 MIRDUMD ADPERFS(05/30/17) tA/13,L, 09-22 I 09/26/01 I RN(TP CORRECTIONS 1 ' PERMIT No 1831730 ;02/26/11 ' TQ/PJC SFT'( NOTE_(COMPOSITE WRAP) I AF1No 50-029-21049-00 I 01/11/12 '17",(WID ADDED I-I2S SAFETY NOTE II I SEC 1 FU (R15E, 172'FSL&324'FWL I I —, 07/30/12 CLAD 'ADDED PATCH OD(07/25/12) 11 , i I 04/22/16 3M) 'ABS CLEAN UP PER TALLIES •!II i BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,September 10,2015 P.I.Supervisor (I ��I� C� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-22 FROM: Jeff Jones PRUDHOE BAY UNIT 09-22 Petroleum Inspector Src: Inspector Reviewed By:p P.I.Supry Jib, — NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-22 API Well Number 50-029-21049-00-00 Inspector Name: Jeff Jones Permit Number: 183-173-0 Inspection Date: 9/6/2015 Insp Num: mitJJ150906112215 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-22 - Type Inj W TVD 8606 - Tubing 1557 r - 1554. 1549 1545 • PTD 1831730 Type TestLSPT Test psi 2152 ' IA 597 2503 ' 2485 - 2474 - - Interval REQVAR !P/Ii P -11 OA381 529 533 535 Notes: AIO 4E.041:2 yr.MIT to max.injection pressure.4 BBLS diesel pumped. 1 well inspected,no exceptions noted. SCANNED Thursday,September 10,2015 Page 1 of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,October 07,2013 TO: Jim Regg P.I.Supervisor /0!1/(3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-22 FROM: Jeff Jones PRUDHOE BAY UNIT 09-22 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv( L-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-22 API Well Number 50-029-21049-00-00 Inspector Name: JeffJones Permit Number: 183-173-0 Inspection Date: 9/20/2013 Insp Num: mitJJ130924211149 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WP_--T--eD—ll _ 09-22 i T YP e I_-n J w TVD 8606--- IA 1_31 319 { —zso s, 2490 za_8s + 1831730 i Type Test SPT psi OA 212 233 - 236 . 239 Inter val QvAR , -_-- 11P/F P vTubing 121a4 1218 -I 1223 r 1230 - Notes: AA IA x OA communication. I well inspected,no exceptions noted. - SCANNED DEC 10 2013 Monday,October 07,2013 Page 1 of 1 S bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 StANNED FEB 2, 4 Z012 Mr. Tom Maunder 1 1 3 Alaska Oil and Gas Conservation Commission S 333 West 7 Avenue g,a— Anchorage, Alaska 99501 o 9' Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -004) DS-09 10/20111 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09 -01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09-02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A , 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09-11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09 -13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09-16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09 -18 1770390 50029202590000 Tandco conductor NA NA NA NA NA 09 -19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09-20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 - 09-22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/82010 09 -24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09 -26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 1020/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09-29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/202011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09 -36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 1020/2011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10202011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 1.2 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 102 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09.48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/182010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 1 ro s `L � / / SEANPARNELL GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMDIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.041 Mr. Doug Cismoski Wells Intervention Manager FEB 1 7 2042 BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 RE: Request for Administrative Approval Prudhoe Bay Unit 09 -22 (PTD 1831730) Prudhoe Bay Oil Pool Dear Mr. Cismoski: In accordance with Rule 9 of Area Injection Order (AIO) 04E.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. Wellhead pressure trend plots confirm that Prudhoe Bay Unit 09 -22 (PBU 09 -22) exhibits slow inner annulus by outer annulus communication. The rate of pressure build -up in the outer annulus is manageable with periodic pressure bleeds. Previous repairs to correct a starting head leak have resulted in BPXA imposing pressure and fluid restrictions for the outer annulus. The AOGCC finds that BPXA does not intend to perform repairs at this time. Reported results of BPXA's diagnostic mechanical integrity tests indicate that PBU 09 -22 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. It is appropriate to address the pressure and fluid restrictions as part of this administrative approval. AOGCC's approval to continue water injection only in PBU 09 -22 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. BPXA shall perform a mechanical integrity test of the inner annulus every 2 years to the maximum anticipated injection pressure; 4. BPXA shall restrict the outer annulus pressure to a maximum of 1000 psi. Fluids pumped into the outer annulus shall not include methanol as a component; • AIO 4E.041 February 16, 2012 Page 2 of 2 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is September 25, 2011. "OIL M DONE at Anchorage, Alaska and dated February 16, 2012. „JJ w Y LA' lad I It/ AN 12 71111 : • 4 PION CO' Daniel T. Seamount, Jr. Cathy ' . oerster J. " 7'. o an Chair, Commissioner Com issioner Com _' ener RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for Septem... Page 1 of 1 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Tuesday, October 18, 2011 11:17 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for September 2011 Attachments: AOGCC Inj Report 10- 11.zip t 1 Tom, Jim, Phoebe, and Guy, Attached is the September 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. « AOGCC Inj Report 10- 11.zip» Notes on wells: Added to Report: 09 TD 831730): Under Evaluation for slow IAxOA repressurization. (PTD #1930020): Under Evaluation for slow IA repressurization Taken off Report: NS -27 (PTD #2010270): Removed after monitoring for 2 months for IA repressurization. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 10/18/2011 Well 09 -22 Injection Plot TIO Plot Well: 09 -22 ° o Pressure vs. Rate o PTD #: 1831730 o O 0 -•�•++ i N Tbg Last MIT -IA - 09/17/09 o • ` • I 1 �� _ B • to Well Under Evaluation for • • • - IAxOA communication • • rn 0. 0 o • a o o DART performed 09/21 till _ _ 09/28/2011 •• 1 0 • • 0 0 J • Last 90 days • Last Month k__( Li \-n li • 0 � o 0 2,000 4,000 6,000 8,000 10,000 12,000 5/12/11 8/2/11 10/23/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) • 1 0 /0/ 1 11 8,297 1,635 10/01/11 1,635 1,200 250 09/30/11 8,284 1,636 09/30/11 1,636 1,550 200 09/29/11 8,363 1,667 09/29/11 1,667 1,550 100 09/28/11 8,682 1,673 09/28/11 1,673 550 200 09/27/11 8,821 1,677 09/27/11 1,677 550 200 09/26/11 8,682 1,660 09/26/11 1,660 550 200 09/25/11 8,468 1,659 09/25/11 1,659 550 200 09/24/11 8,934 1,675 09/24/11 1,675 350 150 09/23/11 8,868 1,666 09/23/11 1,666 350 150 09/22/11 8,632 1,642 09/22/11 1,642 1,500 750 09/21/11 9,245 1,686 09/21/11 1,686 1,500 750 09/20/11 9,739 1,727 09/20/11 1,727 1,500 660 09/19/11 9,529 1,703 09/19/11 1,703 1,540 500 09/18/11 9,294 1,690 09/18/11 1,690 1,540 380 09/17/11 8,986 1,671 09/16/11 1,705 880 560 09/16/11 9,501 1,705 09/15/11 1,687 880 560 09/15/11 9,407 1,687 09/14/11 1,710 880 560 09/14/11 9,618 1,710 09/13/11 1,705 880 560 09/13/11 9,437 1,705 09/12/11 1,754 880 560 09/12/11 10,114 1,754 09/11 /11 1,774 860 520 • 09/11/11 10,471 1,774 09/10/11 1,486 840 500 09/10/11 7,114 1,486 09/09/11 1,719 840 500 09/09/11 9,340 1,719 09/08/11 1,718 900 500 09/08/11 9,271 1,718 09/06/11 1,768 900 450 09/07/11 9,588 1,756 09/05/11 1,778 900 450 09/06/11 9,686 1,768 09/04/11 1,745 950 450 09/05/11 9,771 1,778 09/03/11 1,751 950 450 09/04/11 9,316 1,745 09/02/11 1,790 1,000 400 09/03/11 9,319 1,751 09/01/11 1,794 1,000 400 09/02/11 9,715 1,790 08/31 /11 1,786 1,000 400 09/01/11 9,685 1,794 08/30/11 1,776 1,000 400 OPERABLE: Injector 09 -22 (PTD #18317.S1ow IAxOA Communication Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, October 11, 2011 3:43 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; GPB, FS2 DS Operators; Igbokwe, Chidiebere Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Olson, Andrew; Reynolds, Charles (Alaska) Subject: OPERABLE: Injector 09 -22 (PTD #1831730) Slow IAxOA Communication Attachments: 09 -22 TIO 10- 11- 11.doc; MIT PBU 09 -22 09- 25- 11.xls All, Injector 09 -22 (PTD #1831730) continues to show slow IAxOA communication. During an OA Repressurization Test performed 09/29 - 10/03/2011 the OA build up rate was —72 psi /day. A Pack Off test on the IC Hanger passed indicating that the communication is not through the wellhead. An MIT -IA passed on 09/25/2011 confirming two competent barriers. The well is reclassified as Operable and may remain on water injection only while an Administrative Approval is pursued for continued injection. An updated TIO Plot and MIT -IA form are attached for reference. «09 -22 TIO 10- 11- 11.doc» «MIT PBU 09 -22 09- 25- 11.xls» Please call if you have any questions. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Tuesday, September 20, 2011 7:51 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; GPB, FS2 DS Operators; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Vazir, Mehreen Subject: UNDER EVALUATION: Injector 09 -22 (PTD #1831730) Slow OA Repressurization During OART All, 11/2/2011 OPERABLE: Injector 09 -22 (PTD #1831731ow IAxOA Communication Page 2 of 2 of slow IA x OA communication during injector 09-22 (PTD #1831730) has shown signs o g an OART J performed from 09/17- 20/2011. The well had over the last 2 months while on water injection exhibited slow OA pressurization that was thought to be thermally induced. During the OART, the OA pressure increased 580 psi with a 1500 psi differential pressure between the IA and OA. The well is reclassified as Under Evaluation. Plan forward: 1. Wellhead: Positive pressure pack off test (PPPOT -IC) 2. Fullbore: MIT -IA 3. WIE: Pending results of steps 1 and 2, re -OART 4. WIC: If the communication is through the wellhead, evaluate for a Seal -Tite treatment 5. WIC: If the communication is down hole, evaluate the well for an AA on produced water only A copy of the TIO, Injection plot and wellbore schematic are included for reference. « File: Injector 09 -22 (PTD #1831730) TIO and Injection Plot.doc » Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/2/2011 • • Injector 09 -22 (PTD #1831730) TIO Plot 10-11-11 Wet 0922 IOm • 3AW. 144 2m3_ 00 000 0004 04 I ' � 1300 • 0916/11 072911 I.. 07/31211 09446 00/711 089011 00/27111 09440111 0914411 091111 09/2441 10001J11 tOrVO m Injector 09 -22 (PTD # 1831730) Injection Plot Welk 0322 7:9IUCC 000 1.700 1,600 00 1.900 1100 1,330 0a0 1200 900 1.000 -6000 -WIIW 900 _ Pw • 64 000 — �00 100 - 41410 66 11 50 - 3103 403 - 2 900 300 200 -1 220 100 0716/11 0723711 07/30/11 03/36111 08/1311 00+2001 082711 0/0071 09/ 0771711 09/2441 10/01/11 10/07111 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa a( alaska.gov: doa .aogcc.prudhoe.bavnalaska.gov phoebe.brooks(aalaska.aov; tom.maunderaaalaska.00v OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT 1 PAD: Prudhoe Bay / PBU / DS09 DATE: 09/25/11 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09 -22 Type Inj. W TVD 8,606' Tubing 1600 1600 1600 1600 Interval ID P.T.D. 1831730 Type test P Test psi 2151.5 Casing 295 2500 2494 2494 P/F P Notes: OA 160 320 330 330 MIT -IA for Under Evaluation for slow OA pressurization Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU 09 - 22 09 25 As UNDER EVALUATION: Injector 09 -22 (PTD #1831730) Slow OA Repressurization Du... Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, September 20, 2011 7:51 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Operators; AK, OPS PCC EOC TL; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; GPB, FS2 DS Operators; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Vazir, Mehreen Subject: UNDER EVALUATION: Injector 09 -22 (PTD #1831730) Slow OA Repressurization During OART Attachments: Injector 09 -22 (PTD #1831730) TIO and Injection Plot.doc; Injector 09 -22 (PTD #1831730) wellbore schematic.pdf All, WAG injector 09 -22 (PTD #1831730) has shown signs of slow IA x OA communication during an OART performed from 09/17- 20/2011. The well had over the last 2 months while on water injection exhibited slow OA pressurization that was thought to be thermally induced. During the OART, the OA pressure increased 580 psi with a 1500 psi differential pressure between the IA and OA. The well is reclassified as Under Evaluation. Plan forward: 1. Wellhead: Positive pressure pack off test (PPPOT -IC) 2. Fulibore: MIT -IA 3. WIE: Pending results of steps 1 and 2, re -OART 4. WIC: If the communication is through the wellhead, evaluate for a Seal -Tite treatment 5. WIC: If the communication is down hole, evaluate the well for an AA on produced water only A copy of the TIO, Injection plot and wellbore schematic are included for reference. «injector 09 -22 (PTD #1831730) TIO and Injection Plot.doc» «Injector 09 -22 (PTD #1831730) wellbore schematic.pdf» Please call if you have questions or concerns. - `,. f o �? is r ; Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 9/21/2011 • • Injector 09 -22 (PTD #1831730) TIO Plot 09 -21 -2011 W� og22 4.000 3.000 �- Tbg -0 -- W 2.000 00A �- 000A 1 193) 06/25/11 07/02/11 07/09/11 07/1641 0723/11 07/30/11 08/06/11 08/13/11 — 00/20/71 00: 05/03/11 0911 /11 09J1711 Injector 09 -22 (PTD #1831730) Injection Plot w� 09-22 1,800 • 1.700 10.000 • 600 1.500 9.000 • 1,400 1.300 1200 Y - 7000 1,100 n 1.000 6.000 SW j -5.000 900 — GI — on. 600 500 400 300 2W0 200 800 100 06/25/11 07/02/11 07/09/11 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 09/20/11 08/27/11 09/03/11 09/1 09/17/11 MEMORANDUM TO: Jim Regg e P.I. Supervisor ~ E'~lC~ I L` I Z-~(,) hROM: Jeff Jones Petroleum L~spector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, September 21, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-22 PRUDHOE BAY UNIT 09-22 Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv l~ ~'-- Comm Well Name: PRUDHOE BAY UNIT 09-22 API Well Number: 50-029-21049-00-00 Inspector Name: Jeff Jones Insp Num: mit.11090919202446 Permit Number: 183-173-0 Inspection Date: 9/17/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCII I 09'22 Type Inj. I ~/ TVD ~ 8606 ~IA 1 s40 ~ 4000 ~ 3960 3930 P.T.D~ 1ss1~3o 'TypeTest sI'T Test psi zlsl.s OA s3° s7o sso sso INITAL P Tubing 1360 1360 1360 1360 Interval P/F Notes: 7.7 BBLS methanol pumped. 1 well inspected; no exceptions noted. NN ~~i; ~ 2009 Monday, September 21, 2009 Page 1 of 1 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • Email to: Winton_Aubert~admin.state.ak.us; Bob_Fteckenstein~lmm.state.ak.us; Jem Regg~admin.state.ak.us; Tom_M~under~adminstate.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhce Bay! PBU / DS ~ DATE: 09/17/09 OPERATOR REP: Torin Roschinger AOGCC REP: Jeff Jones Paeker [9eph1~ P~est kwS~ai 45 Ad4is~. 34 iJlin. Weit 09-22 Type Inj. W TVQ 8.607° Tubiru~ 1360 136d 1360 1360 Interval 4 P.T.D. 1831730 Type test P Test psi 2152 Casi 540 4000 396Q 3930 P/F P Notes: AOGCC MITIA to 40~ psi dA 530 870 85d 850 Weil Type Inj. TVD Tubirng lnterval P.T.D. Type test Test psi ~asing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi C~a~ P/F Notes: d.A Well Type Inj. TVD Tutrir~g Interval P.T.D. Type test T~t psi C~Sing P/F Notes: OA Well Type Inj. NQ Tca~ Interval P.T.D. T test Test~si Casi P/F Notes: OA TYPE INJ C~es D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Cades M = Annul~ A~MOni~ng P = Standard Przssa,re Test R= Intema! Rad~ Txacer 5urvey A =Temperature knana}y Survey D = Dilferential Tempera0ure FesF ' y~~,~,~G.~r-x::r ; ~ ~~ ~.' i ;J L~i-:.:i ~~ ~i~ t Ge INTERYAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T =Test during W of~cover O = Other (describe in notes) MIT Report Form BFL 9/1/OS ~IT ~U [i9-22 ~-17-09.~ds OPEREIBLE: 09-22 (PTD #1831730) Furmanite Treatment of Starting Head Successful Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, December 29, 2008 7:29 AM ~, ~~ l Z~Z~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; GPB, FS2 DS Operators Cc: Phillips, Patti J; Dahlem, Jason E; Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 09-22 (PTD #1831730) Furmanite Treatment of Starting Head Successful All, After almost a week of monitoring the starting head of 09-22 pos#-Furmanite treatment, no leaking has been observed. in addition, the well passed an MIT-OA on 12/i8/08. Therefore, the well has been reclassified as Operable. Please notify Well Integrity if any bubbles in the composite wrap or leaking is observed. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~` From: NSU, ADW Well Integrity Engineer Sent: Thursday, December 18, 2008 1:04 PM To: GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; GPB, FS2 DS Operators Cc: Phillips, Patti J; NSU, ADW Well Integrity Engineer; Dahlem, Jason E; Quy, Tiffany Subject: UNDER EVALUATION: 09-22 (PTD #1831730) Monitor on production post Furmanite Treatment of Starting Head Hi all, Well 09-22 {PTD #1831730) has been treated with Furmanite composite wrap around the starting head to mitigate a small thread leak. The Weii has been reclassified as Under Evaluation so that the well may be placed on production and monitored. DHD will apply pressure to the OA, ask that Operations pop the walk, and will remain on location to manage the OA pressure. Please contact me an Harmony 2376 with any questions. Thank you, Anna ~u6e, ~'. E. Weft Integrity Coordinator GPB Wells Group 12/29/2008 OPERABLE: 09-22 (PTD #18317) Furmanite Treatment of Starting Head Successful Page 2 of 2 • Phone: {907) 659-5102 Pager: {907) 659-5'100 x9154 12/29/2008 _ _ ~~~~ DEC 2 9 2008 STATE OF ALASKA ~~ "~~~1J8 ALA OIL AND GAS CONSERVATION CO ~~ ~' N& Gas Cons. Commissic~r~ REPORT OF SUNDRY WELL OP I~N~nchorage 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ Other ~ Startinghead repair, Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ Furmanite App , Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 183-1730 ' 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~' . 6. API Number: Anchorage, AK 99519-6612 50-029-21049-00-00 7. KB Elevation (ft): 9. Well Name and Number. 55 KB ~ PBU 09-22 " 8. Property Designation: 10. Field/Pool(s): ADLO-028345 - Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: • -~ -- Total Depth measured 13125 ~ feet Plugs (measured) None true vertical 9134.35 - feet Junk (measured) 12978' 1/1/98 Effective Depth measured 12933 feet ;~, , ' ~ ~~~~ true vertical 8971 feet ~~ ~~ ? ~ ~~~~ Casing Length Size MD TVD Burst Collapse Conductor 80' 20" Surface - 80' Surface - 80' Surface 2767 13-3/8" 72# L-80 Surface - 2822' Surface - 2549' 5380 2670 Production 12807' 9-5/8" 47# L-80 Surface - 12862' Surface - 8870' 6870 4760 Liner 586' 7" 29# L-80 12539' - 13125' 8644' - 9133' 8160 7020 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 Surface - 12483' 4-1 /2" 12.6# I-80 12483' - 12574' Packers and SSSV (type and measured depth) 9-5/8"x4-1/2" BAKER FHL PKR 12493' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 3875 240 1475 Subsequent to operation: 3875 1267 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Dev~elOpment ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~' WAG ~,~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~' Phone 564-4944 Date 12/29/2008 r Form 10-404 Revised 04/2006 ~~ i ~ Submit Original Only 09-22 183-173 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-22 5/10/85 PER 12,892. 12,917. 8,936.33 8,957.48 09-22 5/10/85 PER 12,922. 12,937. 8,961.71 8,974.43 09-22 5/10/85 PER 12,944. 12,949. 8,980.36 8,984.6 09-22 4/24/88 SQZ 12,892. 12,949. 8,936.33 8,984.6 09-22 5/14/88 RPF 12,922. 12,937. 8,961.71 8,974.43 09-22 5/14/88 RPF 12,944. 12,949. 8,980.36 8,984.6 09-22 11/22/89 APF 12,840. 12,841. 8,892.44 8,893.29 09-22 11/22/89 APF 12,852. 12,853. 8,902.56 8,903.4 09-22 11/22/89 APF 12,868. 12,869. 8,916.05 8,916.9 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • s 09-22 DESCRIPTION OF WORK COMPLF}~E/~/ NRWO OPERATIONS E(~ EVENT SUMMARY w rte,- «~r ~ ~:t• ii. ~., ~ tY "E ,+ ~ :I ~ .t:' 12/11/2008 T'I/O =SSV/0+/0+. Temp = SI. Position heater & check to see if cellar needs gravel removal. Heater installed in W/H. No visible circ ports, flutes packed with rocks and dirt. SV, WV, SSV shut. MV open. IA & OA otg. NOVP. _. _._ --- ~ _ ._ _._.... _.___ , __~_.__. __._.__________ ___ ._._._.~____4. 12/12/2008 T/I/O=Vac/10/0+. Temp=S1. Prep for Furmanite (Vac-out cellar). Bled IAP from 10 psi to 0 psi in 15 mins (all gas). Bled OAP from 0+ psi to 0 psi in 2 reins (all gas). Pulled grating, Vac'ed 2 yds cellar gravel to make room for Furmanite a lication, cleaned startin head. Final T/I/O=Vac/0/0. SV. WV= _ A. OA=OTG. NOVP. 12/13/2008 T/I/O=Vac/10/0+. Temp=S1. Prep for Furmanite (N2 purge). IAP increased 10 psi overnight. Bled IAP from 10 psi to 0 psi in 15 mins (all gas). Bled OAP from 0+ psi to 0 psi in 2 mins (all gas). Apply 20 psi nitrogen to Tubing, IA & OA. Final T/I/0=20/20/20. SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 12/14/2008ET/I/0=14/20/26. Temp=S1. Assist Furmanite wrap (Startinghead repair). Maintain required wellhead conditions during Compositech and Furmanite ;;,operations. Maintain an open OA bleed, pre &post-Furmanite wrap. ""Note: 'Job continued on next days entry. Final T/I/0=14/20/0. SV, W V=C. SSV, MV=O. IA, OA=OTG. NOVP. 12/15/2008'T/I/0=14/20/0. Temp=S1. Maintain open OAP bleed (Furmanite application). 12/16/2008T/I/0=14/19/2. Temp=S1. Maintain open OAP bleed (Startinghead repair). *" Continued from previous days work. "" Assist Furmanite as needed. Maintain an open OA bleed. Bleed N2 from Tubing & IA. Final T/I/0=0/0/0. ":SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 12/17/2008;T/I/0= 0/0/0. Temp= SI. Maintain open bleed (SH repair). Changed out w/ night crew. Continued to monitor open bleed. Assist Furmanite as required. SW,WV=C. SSV,MV=O. IA=OTG. OA=Open to bleed. 12/18/2008T/I/0=0/0/0. SI. Maintain open bleed (SH repair). Changed out with day crew. ;Continued to monitor open OA bleed for Furmanite job. SW,WV=C. SSV,MV=O. IA=OTG. OA=Open to bleed. Day crew in control of `well. i 2/18/2008 T/I/0= 0/0/0. Temp= Sl. Maintain open OAP bleed, MIT-OA *"PASS""* to 1000 psi (Tree WH Repair). Changed out w/ night crew. Continued open OA bleed. Furmanite installed heating blanket_around SH. Heated SH to 176" for 4 hrs. MIT-OA to 1000 psi using 1 bbl of diesel. 1st 15 mins, OAP decreased I 30 psi to 970 psi. 2nd 15 mins, OAP unchanged @ 970 psi for a total loss of 30 psi in 30 mins. SI, monitored for 30 mins. OAP unchanged. Tagged OA w/ f caution tag "Watch for thermal expansion". FWHP's= 0/0/970. SV, WV= C SSV, MV= O IA, OA= OTG NOVP. \J 12/19/2008aT/I/0=0/0/830. Temp=S1. Monitor WHP. OAP decreased 140 pi overnight. No leaks detected on SH. SV,W V=closed.SSV, MV=open.lA,OA=OTG. NOVP. ~. _ _______ . __ ~_..._-- -_ ~. _ _ ~.._~..___ _ N_ _. _._. __ __..__ ___ _~ _ ____ .. _ _. m.~ ~ __ 12/20/2008""*WELL S/I ON ARRIVAL*'"' (post furmanite repair) ;PULLED 4-1/2" PXN PLUG FROM 12544'SLM __ j""`LEFT_W_ELL_SI,_TURNED O_F_ER TODSO*"" _ _ _ __ 12/20/2008 T/I/0= 0/10/750. Temp= SI Monitor WHP. TP unchanged, IAP increased 10 ;psi, OAP decreased 80 psi overnight. No visible SH leaks, no fluid in flutes. SV,WV,CV=C. SSV,MV=O. IA,OA=OTG. NOVP. 12/23/2008T/I/0=0/10/650. Temp=S1. Monitor during POP (Startinghead repair). OA FL @ surface. OAP decreased 100 psi overnight. Well put on infection @ 1330, hr. Bleed as needed to maintain OAP between 950 psi and 1000 psi during :.startup. Change out with night crew. Continue to monitor and bleed OAP as 'needed. ""Note: No Startinghead leaks currently visible. Final WHPs= ;1350/30/990. 'SV=Closed. WV, SSV, MV= Open. IA & OA= OTG. NOVP. 12/23/2008~T/I/0=1300/40/990. Temp=Hot. Monitor OAP (POP post-Furmanite repair). *" 'Continued from previous days entry ** Continue bleed when necessary to ;maintain 1000 psi during well POP (all fluid, 5.5 bbls total). Bled OAP back to 300 psi (fluid, 6.3 bbls total for job). Monitored 30 mins (during RD), OAP ':increased 5 psi. '"` Note: No Startinghead leaks visible. Final T/I/0=1250/40/300. SV=C. WV, SSV, MV=O. IA, OA=OTG. NOVP. ~Nw. _~_.____ ~______.. ~_. _.a__. _.__..~ ..-_,~_._.___ _~._~_~~___ ~__.___~._n. 12/24/2008,T/I/0=1230/30/460. Temp=Hot. Monitor WHPs (eval OAP). OAP increased ;160 psi in < 6 hrs. No visible leak on Startinghead. 'WV=C. WV,SSV,MV=O. IA&OA=OTG. NOVP. ___.__ 12/24/2008,T/I/O = 1160/30/540. Temp=Hot. Monitor WHPs post POP, bleed OAP as needed (post SH repair w/furmanite). AL connected, SI & blinded @ casing 'valve. Pressures read @ 1100 hrs, previous readings taken in early morning -:hrs. TP decreased 70 psi, OAP increased 80 psi since last readings. OA has 'fluid to surface (diesel). No leaking around SH. SV=C. WV,SSV,MV=O`IA,OA=OTG. NOVP. 12/26/2008T/I/O = 1100/60/660. Temp =Hot. Monitor WHP's post POP, bleed OA as needed (post SH repair w. furmanite). (09:13 am) OAP increased 120 psi since ;12/24/08. No leaking detected around SH. WV, SSV & MV =Open. SV = Closed. IA & OA = OTG. NOVP. __a w _._____. ___ _. _ _.__.....____n_ _ ._. ~_ _~n... .~__ ~_ _ _a,., e.a_~.~~_.___,~__..~. ~__. 12/27/2008 T/I/O = 1040/30/570. Temp -Hot. Monitor W HP's post POI, bleed OAP as needed (post SH repair w/ Furmanite). (09:00 am). OAP decreased 90 psi to `570 psi overnight. No visible SH leaks @ this time. ?SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. __ .._ __ _ _.~ .._..______ . __. ~.~_._~. _ _..._ . _ _. ~. _._ ~ ~,__._ __._ _. __~w .. ~ _.._~ ~_ .. _ ,_____ .~_ ~ _,.~.._ 12/28/2008,T/I/O = 1000/401520. Temp -Hot. Monitor WHPs post POP, bleed OA as ;needed. (post SH repair w. furmanite). (13:20 hrs). TP decreased 40 psi, IAP 'increased 10 psi & OAP decreased 50 psi overnight. No SH leak detected. 'sSV =Closed. WV, SSV, MV =Open. IA & OA = OTG. NOVP. FLUIDS PUMPED BBLS 1 diesel 1 Total NOT OPERABLE - 09-22 (PTD #1831730) Repair attempt unsuccessful Page l,yf~ ~ ~ b~~~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] `~~~ (~/~~ Sent: Monday, June 02, 2008 7:49 AM I\ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: Dahlem, Jason E; Roschinger, Torin T.; Oman, Taylor T; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE - 09-22 (PTD #1831730) Repair attempt unsuccessful AEI, The repair attempt on the starting head of 09-22 proved to be unsuccessful after several days of monitaring. The well has been shut-in and reclassified as Not Operable. Please call with any questions or concerns. Thank you, ~~~~ ~UN ~. ~. 2~~~ Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Saturday, May 24, 2008 3:50 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSi/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC); Dahlem, Jason E; Townsend, S. Eliot; Wellman, Taylor T Subject: UNDER EVALUATION - 09-22 (PTD #1831730) Seal-Tite repair of starting head All, A Seal-tite repair of the starting head is complete on well 09-22 (PTD #1831730). In order to determine the success of the job, the well will need to be put on water injection and the starting head monitored for several days. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. WIE: Seal-tite starting head -DONE 2. WOE: POI 3. D: Monitor well 4. WIC: Send 10-404 to AOGCC for wellhead repair Please notify the Well Integrity Engineer if any seepage is seen from the starting head. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator 6/4/2008 09-22 (PTD #1831730) Wellhead Leak Page 1 of 1 Regg, James B (DOA) From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Saturday, August 25,2007 12:58 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADWWelllntegrity Engineer; Lau, John, Jack; Winslow, Jack L. !<é',¿¡1' c:¡ /S)ò] Subject: 09-22 (PTD #1831730) Wellhead Leak ( Jim and Tom, v-/ A leak on the starting head of well 09-22 (PTD #1831730) was discovered on 08/24/07. The well has been shut-in and will be secured until the starting head leak has been repaired. The well has been reclassified as Not Operable. t/ Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~çMNED SEP 1 1 2007 9/5/2007 ,) MEMORANDUM TO: Jim Regg T c:7:(.J'- P.I. Supervisor ' ",q i Î %, ÐS FROM: Jeff Jones Petroleum Inspector ) Alaska Oil and Gas Conservation Commission State of Alaska DATE: Wednesday, September 21,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-22 PRUDHOE BAY UNIT 09-22 ·/3 ''0/ \ \'1 Src: Inspector Reviewed By: P.I. Suprv ...:::J'DL- Comm NON-CONFIDENTIAL Depth IA OA Tubing ---.--..--.,---....-.".....-- Notes Pre MI swap MIT. 1 well house inspected, no exceptions noted. Well Name: PRUDHOE BAY UNIT 09-22 Insp Num: mitJJ050920070843 Rei Insp N urn API Well Number 50-029-21049-00-00 Permit Number: 183-173-0 Inspector Name: Jeff Jones Inspection Date: 9/19/2005 Packer Well i 09-22 Type Inj. I TVD I 8608 -p~T~11.~_~_I~_3.~j!I_~'!._~_~!. I SPT Test psi l----- 2152 Interval OTHER P/F P Wednesday, September 21,2005 Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ::~_~_:~~_+_:: j_-_3i.~__---- I __ ____~ 1800 I 1800__L____I~_0 : 1800 ~{;~NEL NOV 0 B 20D5 Page 1 of I ) TREE = WB..LHEAD = ACTUATOR = KËfELËV = ' ì3i=. ELEv ",; KOþ; ,~~,~~~~..::: Datum MO = Datum TVD = Frvc GEN 3 Frvc AXELSON .."- . "55' 09-22 '1 öÖ"Qi , ",?,~,~~!O~: 12795' 8800' SS / 2822' I e 13-3/8" CSG, 72#, L-80, 10 = 12.347" H \ } 15-1/2" TBG-FC, 17#, L-80, 0.0232 bpf, 10 = 4.892" H 12483' ITOPOF 4-1/2" TBG H 12483' Minimum 10 = 3.725" @ 12562' 4-1/2" OTIS XN NIPPLE :8: ~ I TOP OF 7" LNR H 12539' I Ë I§ I . 4-1/2" TBG-FC, 12.6#, L-80, -t 12574' I 0,0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 12862' t---.4 PERFORATION SUMVlARY REF LOG: BHCS ON 02/05/84 A NGLE AT TOP ÆRF: 33 @ 12840' Note: Refer to Production DB for historcal perf data SIZE SPF INTERV AL Opn/Sqz DA. TE 3-3/8" 1 12840-12841 S 11/22/89 3-3/8" 1 12852-12853 0 11/22/89' 3-3/8" 1 12868-12869 0 11/22/89' 3-3/8" 4 12892-12917 S 05/10/85 3-3/8" 4 12922-12937 0 05/14/88 3-3/8" 4 12944-12949 0 05/14/88 I PSTO H 13084' 7" LNR, 29#. L-80, 0.0371 bpf, 10=6.184" l-t 13125' , ~ DA. TE 02/12/84 11/15/00' 01/02/01 02/19/01 09/26/01 10/16/02 RBI BY SIS-Is I SIS-LG SIS-rvD RN/TP B HC/KK COMrvENTS ORlGINC\L COMFlETlON CONVERTED TO CANV AS RBlISION FINC\ L CORRECllONS PERF CORRECTION DATE REV BY COMrvENTS ,I, SAFETY NOTES: 2200 psi (ZERO SAFErY FACTOR) PA TCHFLEX COLLAPSE RA llNG FHUTIW HBBP PKRS HA VE REDUCBJ TEST PRESSURELlMTS IN SOrvE CA.SES. CONTACTACE(X5102) PRIOR TO PRESSURE TESTING ~I 2378' Ii 5-1/2" SSSV NIP, 10 = 4.562" I 12469' 1-1 5-1/2" BAKER FBRASSY I 12483' 1-1 5-1/2" X4-1/2" XO I I 12493' 1-1 9-5/8" X 4-1/2" BAKER FHL PKR I I 12562' 1-1 4-1/2" OTISXNNIP, 10=3.725" I 12573' 4-1/2" BAKER SHEAROUT SUB 12574' 4-1/2" TUBING TAIL I 12545' 1-1 ELMO TT LOGGBJ 05/13/85 I .. 12840' r- 7" ORlLLFLEX PA TŒ-I (SET 03/17/98) COLLAPSERA llNG 2200 PSI (ZERO SAFETY FACTOR) , , I 12978' 1-1 RSH- ORlLLFLEX PATCH (LOST01/01/98) I PRUDHOE BAY UNIT WELL: 09-22 PERMT I\b: 1831730 AA I\b: 50-029-21049-00 SEC 1, TON, R15E. 172' FSL & 324' FWL BP Exploration (Alaska) ,', "', " .. ,.!-'~,. > ¡......l.. #",; \ j., t- ~. '" -rû 'f-lLE 1 'M~,t.jj o$'oOjcl-cGr,oö'i3 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test t' I jßl2- I", (3(04 Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / OS 09 12/04/04 Joe Anders ;{ \10 ~~. Packer Depth Pretest Initial 15Min. 30 Min. Well 09-22 Type Inj. PWI TVD 8,607' Tubing 1,720 1,720 1,720 1,720 Interval 4 /' P.T.D. 1831730 Type test P Test psi 2,500 Casing 200 2,500 2,500 2,500 P/F P Notes: MITIA to 2500 psi. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: AOGCC inspector Chuck Scheve declined witness. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. c.:: e--'A' h.'~.. n=:.: {'" 0 '~. p 2 "':i 12' [1 ('I LI ~\;? B".'\j~~.) ,,- 1"ß 1. "',' MIT Report Form Revised: 06/19/02 MIT PBU 09-22 12-04-04.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) ~' ~2 cj ~%~ ~--- STATE OF ALASKA ~--.. ~.~ .... '"' __.,,,,~ .$KA OIL AND GAS CONSERVATION COMMISSI, · OF SUNDRY WELL OPERATIONS 1. Operat~t~rformed: , Operation Shutdown _ 5'timulate__ Plugging _ Perforate _ Puli tubing Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_ 55' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_X Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 182' FSL, 324' FWL, Sec 1, TION, R15E, UM. 9-22 At top of productive interval: 9. Permit number/approval number: 1278' FSL, 1479' FEL, Sec 6, T10N, R16E, UM. 84-173 At effective depth: 10. APl number: 50-029-21049 At total depth: 11. Field/Pool: 1265' FSL, 1326' FEL, Sec 6, T10N, R16E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary I I~J ~ L Total Depth: measured 13125 feet Plugs (measured) true vertical 9133 feet Effective Depth: measured 12933 feet Junk (measured) true vedical 8971 feet Casing Length Size Cemented · Measured depth True vertical depth Conductor 80' 20" 1955~ Poleset 80' 80' Surface 2767' 13-3/8" 3500 Sx CS III & 2822' 2549' 400 Sx CS II Production 12807' 9-5/8" 500 Sx Class G & 12862' 8870' 300 Sx PFC Liner 586' 7" 300 Sx Class G 13125' 9133' Perforation Depth measured 12852 - 12852'; 12868- 12868'; 12922- 12937'; 12944- 12949' true vertical 8903 - 8903'; 8916- 8916'; 8962 - 8974'; 8980 - 8985' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC Tbg @ 12483' MD; 4-1/2", 12.6#, L-80, PC Tbg @ 12574' MD Packers and SSSV (type and measured depth) Baker FHL Packer @ 12493' MD; Otis RQM SSSV @ 2378' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Dally Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation - 1718 1805 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _ Gas_ Suspended_ Service_X ~A (~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~'.~ '~, ~ T~tle: Engineering Supervisor Date "~"-' 2, ~'- ~ ~/ Form 10-4( ay 06/15/88 SUBMIT IN DUPLICATE 9-22 DESCRIPTION OF WORK COMPLETED LINER PATCH INSTALLATION FOR INJECTION PROFILE MODIFICATION 3/17/98: Tagged PBTD at 12933' MD, then RIH & set a 3.66" ID Drill Flex Casing Patch from 12837' to 12843' MD to cover a hole located at 12840' MD. Inflated & warmed resins to cure patch to 7" liner. POOH. RD. 5/29/98: Video logged the casing patch; it appeared in good condition. 7/3/98: Performed an Injection Profile which showed the casing patch appeared to be sealing. Returned the well to PWI & obtained a valid injection rate. GeoQuest ~ W. International AIu~ort Road An~horacje, AK 99618-1199 ATTN: Shertle NO. 8966 Company: Alaska OII & Gas Cons Oomm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/30194 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar , ,, iD.$. 1-7A /'l / / ^ (-/-..~ DUAL BUR~T TDT-P (9-15-94) 1 1 D.S. 1-7A v/,v/.. U ~ ~RF RE.RD ~9-17-94) 1 1 D.'.7-25 : -- PERF RE'RD (9'12'94) 1 1 ,, D.S. 17-16 ~ ~ / ~PERF RE~ORD (9-19-94) 1 I SIGNED: .--~' PI return one copy ~f this transmittal to Sherrle at the above address. Thank you.' DATE: P~O. BOX i ANCHORAGE ~'~ ALASKA . ........ ....... ~ ............ ~_,. ...... . ..... ;~.~.; ...................... )(EF'ERENCE' ARCO CA~ED HOLE FINAL~ 2-~6 4-28-~ ~ F'RO~ F'ROF~' RUN ~, 5" CAHCO ~-~ ~ ~ ' RUN ~ 5" C~MCO 6-~S 5-5-~~ F'ROQ~ F'ROF~ RUN ~, 5' CAHCO ~-4 ' 5-5-~ '~"~'~LEAK' QETECT~ ' RUN ~, 2'& 5~ CAMCO ~-8 4-~e-~ - ~ GR ..... RUN ~, 5' CAMCO ........ ~ ~ .... 5-6-~ ~'~i;?~INJ~';"'PROF'~ .... ~;~ ...................................... :".' RUN '~'~ ~' ..... CAMCO ~-'~Y 4-25-~ ':' INJ. F'ROF". ' .... RUN ~'; 5' CAMCO ~ ~ ~-S 4-~ Y-~ '-;:..'~.,~, ,~; LEAK~ 'QETECT-~:~,~'7' ............. . RUN ~, 5' CAMCO ~2-~6 5-2'"~ -~; ~'~ F'ROQ~ F'ROF'~-GA~ LIE'T RUN ~, 2'&5' CAHCO ~-7 5-4-~' ..... ." .... LEAK ~ETEC, T. ......... RUN ~, "~'~ &5' CA~CO ~'-28 4-~Y-~. ~ GA~-ENTRY. -.. RUN ~, 2'&5' CAHCO ........... ; .~ .... J~ ~ ...................................... PLEASE ~IGN AND RETURN THE ATTACHEQ COPY A~ RECEIPT OF DATA. . . . '. · . I ........ ~:~ .~'. ~ :;~;':.~-~;.~-.. ' ...... ~.- ............... ;~ ....... ~. ~ ....................... -.:.~..~.;~,.~_~ .......... ~ ........ ' QI~TRiBUTION - ~ CENTRAL FILE~ ' ~ ~ F'HILLIF'~ ............ ~ CHEVRON ........... ~ .... ~---~"~ ...... ~ ..... ~; ..... F'B 'WELL F'ILE~ ................. --~ ~ ~ EXTENTION- EXF'LORATI oN-.?~-~ ~ ~ BF'X ........ ~ EXXON · HARATHON ......... : ................ TEXACO ~ ~OBIL .' ARCO ALASKA ~ P~O~ BOX ~(=)GS6A ANCHORAGE~ ALASKA 995 i () DATE' 8-i 7-9,'3, REFERENCE· AF.'CO CASED HOLE FINALS ,4--2 4-i 8-i S-9 ¢., 5-i 'i '7-i i -9I('~ %:': i4 c.~ i i-°~3 /... =6-,' ,_,-ii · 6-24 8--9-9¢' --'?-SS 8- i i -9¢' 9-')') 7-28-9¢, · :~ ,,--. --=9-42 8- 5-- 9 :::..~ --9-42 · i i-4 8-9-9'3' i i-2¥ 8-i ';"'-9(Z) ~-~i 2-¥2 7-25-- 9('} o-i'S'-7 8-5-9'3 i S- i~. '~ 7-2.6-9,2, j¥-i°,~ 8-,',..-,~,n, , . --' '" -~' -- "') Z. ~ . .....-4=' W D W i-·~ 8'- 7-9(::' F'ERF' RECORD DUAL BUiRST TDT-F' C 0 L I.. A R /P E R F DIAGNOSTIC FH PERF RECOR_O COLLAR/F'ERF CN.L-GR/CCL INUF-.'CTI ON PROFILE CO/.I_AR/PERF INJECTION PROFILE CBT CE'F CNL.-GR/CCL COL_I_AIR/F'EF:.F PRODLJCTZON PRC.iFILE rEt~.F RECORD _ DiAGNO~,-:T iC FH PERF" RECORD PROi)UCT! ON PROFILE CC!_ PLEASE SIGN AND RFTURN TI4E ATTAC'HED COPY AUG 2 2 1990 SALLY HOF'FECKER A T 0_- i 5 29 /~.]l~]~8.01! & Gas'Cons. uomm't~ion ncl omge RUN i, 5 RUN RUN i ,_, RUN i; i ",'2' RUN i, RUN i, 5' RUN i, RUN RUN i ,~' RUN i , RIIN.. i , ~'" RUN ~, '2"&5' '~- RUN RUN i RUN i, 5 ' RUN. i i:;: ij h.! RUN, i , ~-~' RUN AS RECEZF'T OF' DA'FA AF'F'ROVED ~ 'i'RANS:~ 9,~ ,5" $CH SCH ATLAS CAliCO SCH A TLA:<£ A'[ LAS CAMCO ATLAS CAMCO SCH SCH ATLAS.' A'I'I_A;~' CAMCO ~CH CAMCO C A H C 0 ATLAS DISTRIBUTION CENTRAL FILES CHEVRON DaM EXTENSION. EXPLORATION. EXXON MARATHON MOBIL · .-'"' F'HILLZF'S F'B WELL. FILES R & D ~ BF'X STATE OF ALASKA TEXACO * THE AF'I$ FOR tt-22; IS 5,9-G29--2i6ie.. ** THE CORRECTED AF'I~ FOR tS-7 IS i) A T E ' S - 2 - 90 i -- ! ":2 2-27 :5-22 4--3 5-ii --_ :.~; .; 9-i 8 ':-:---2,'3 ', 2.-i i:i ~;6-9 ',6-i 9 2 -- ~, 2 - 9 f:;~.. 2'-! 9-9;;:' 2 ..... i '5- 9':'::' Z-'/-9(:,' '-:'-'~ :5 .... 9-":; .;'.. ! -... "':' .._ "".' ':-'f .... -'S:: 2 .... i i .... 9 0 '-"'-i ;.-',..- ,:.:, A "...2-- i i '- 9 (') 2- i -'"'4 --9('> - '--2--i 8--':2 0 '2 - ! ".:-' -':-';" ;'-; ~-- J .... ,' :"-r..UL' t..,,., , T F' i:: C 'T'C:.,"' F.']I i '; ~ h.: ! &.~ t.? ..... ,F' .~' F ,'<:/P.q' 0a!.. , ,., :;i;"._. '¥', ~.r ,_~;'~a, ~. F' R 0 F' .~T LF F' F' (_-: "-C C i.. :_.'-' 0 L. i_. A ~:;':, ,," P ii'7. R F T'' ~ 'i" T g N F:','.. L.,, I i .z 11 -_. E "" c', "'..' i:' 'ii N ,J E F-: "..'.- I '..'3 N P R 0 i-' i L E :[NJEL-;T iON F'ROF i L.E COi_!_AR F' E F:.F RE C 0 F;.: i::' TB6 PATCH; F:.ECORD F,~ .... c ., -,-' ~.:~.: ,:. ,_ SiGN ANi) RETURN THE ATTACHED COPY r:~5" r-;:.ECr:.:.IF'T OF' RECEiVF'D BY _~. HAVE A.HiF'''--. .....,_ DA'Y! £ALLY ~-i ,"; .=' u- ¢.:' F- ~,' A'¥O-! 529 MAR - 8 !990 Alaska Oil & Gas Cons. Commission Anchorage T ir'.'. A N S' :~ ':2 'S~, 9 6 D A T A, i) I .'-i: T R I BUTI ON -.- CE~"~ iF.:AL F'rLES' 4.l: C H E V F;-: L') N D & M "'-,- -..,~:'""TFN;S:I ON .... EXPLORATION ~-'"' EXXON MARATHON ~ HOBIL PH ILL i F'~';' .- ,.~ . ""i iS ¢ F'F.' WEL{ F'~.,_~_~ R & D f,: ' Bi:;'X · ':~ $"f'A'i-E FiF Ai..AZKA · -- ]--ti:. :,." A F': F! .~1' ...., ~-. STATE OF ALASKA .- ALASK/~ .AND GAS CONSERVATION C ~ISSION REPORT OF SUNDRY WELL OPI:riATIONS 1. Operations performed: Operation shutdown . Stimulate Plugging .---- Perforate X Pull tubing ---- Alter casing ...-. Repair well . Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 182' FSL, 324' FWL, Sect. 1, T10N, R15E, UM At top of productive interval 1278' FSL, 1479' FEL, Sect. 6, T10N, R16E, UM At effective depth At total depth 1265' FSL, 1326' FEL, Sect. 6, T10N, R16E, UM 5. Type of Well Development .--. Exploratory Stral~graphic Servk:e X 6. Datum of elevation(DF or KB) 55 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-22 9. Permit number/approval number 84-173 / 9-994 10. APl number 50 - 029-21049 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor Surface Production Liner 13,125 feet Plugs(measured) 9,133 feet 13,084 feet 9,098 feet Junk(measured) Size Cemented 20' 105,54t PS 13 3/8" 3500 + 400 Sx 9 5/8" 500 + 300 Sx 7" 300 Sx Measured depth 'Tide ve~ical depth 80' 80' 2822' 2549' 12,862' 8870' 13,125' 9133' Perforation depth: measured 12,892-12,917'; 12,922-12,937'; 12,944-12,949'; 12,840-12,875' true vertical 8890-8921'; 8936-8958'; 8962-8975'; 8980-8985' Tubing (size, grade, and measured depth) 5 1/2", 17#, L-80, PC tbg ! 12,483'; 4 1/2", 12.6#, L-80, PC tbg @ 12,574' MD Packers and SSSV (type and measured depth) 5 1/2" Otis RQM SSSV @ 2378' MDk; Baker FHL packer @ 12,493' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) NONE Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Averaae ~ or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 4500 65O0 Tubing Pre~ure 1300psi 1200psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service WAG injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~j~~.,~~ T~le Operations Engineering Manager Form 10-404 Rev 06/15/88 DS 9-221 PERFORATING SUMMARY OF OPERATIONS Began perforating operation on 11/22/89. SI well, RU perforating unit, pressure tested equipment. RIH with 3 3/8" gun #1, opened up well and shot holes at 12868, 12840, 12852. SI well, POOH, no shots fa'ed. RIH with 3 3/8" gun #2, opened up well and shot holes at 12868, 12840, 12852. Flowed well to cleanup. SI well, POOH, all shots fired. Secured well, RD, returned well to injection. Intervals perforated: Ref. BHCS Footage Flow (2/5/84~ ('MD) SPF Unit Peri Depths ('MD) Ref. BHCS(2/5/84) 12840-12875 35 1/12 T5 12840,12852, 12868 ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 99~i0 DATE' i2-5-89 REFERENCE' ARCO CASED HOLE FINALS 2-2i ti-i~-87 PERF RECORD 2-2t tt-24-89 COLLAR/PERF 4-4 tt-t6-87 COLLAR/F'ERF 5-i9 ti-t4-89 COLI_AR (PKR SET REC) 9-22 ii-22-89 COLLAR/PERF ti-28 ti-ii.-89 COMPLETION RECORD t2-29 ti-i7-87 COLLAR/F'ERF ~3-4 ii-~°3-89 COLLAR/PERF t5-i ii-i9-89 METI' t5-i3 ii-i6-89 COLLAR i5-i3 ii-22-89 VERTILOG i8-24 ii-iS-89 COLLAR/F'ERF RUN i, 5" RUN i, 5" RUN i, 5' RUN t, 5' RUN i, RUN t, RUN t, RUN i, RUN i, RUN t, 5' RUN i, 5" RUN i, 5' PI_EASE SIGN~RETURN I~TTACHED COPY AS RECEIPT RECEIVED BY ' SAL. LY' HOFFECKER -OEC~'tt-~'~ , w A T 0 - t 529 ~8~ BB & Gm ~OB~- ~l~l~lSSl~- TRAN£~A P FIR 0 V E 89,~D i -- OF DATA~ DISTRIBUTION ' CENTRAL FILES ~ ~ PHILLIPS f,- CHEVRON F'B WELL FILES D & M R .& D ~- EXTENSION EXPLORATION ~ BPX $ EXXON ~-~ STATE OF ALASKA MARATHON - ~ TEXACO ~' MOBIL' $CFI ATLAS A'¥LA.~ ~'' AILAS ATLAS SCH A'FLAS ATLAS $CH ATLAS' A 'i-LA3' ATLAS * THE CORRECTED AF'I$ FOR 2-2t -IS 5~-029-2~781. ARCO Alaska, Inc. ' Prudhoe Bay ~...=~ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 14, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Well No. 9-22, Permit No. 84-173 Dear Mr. Chatterton: Attached, in triplicate, is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/GS S/sbm Attachment cc: J.S. Dietz, BP Exploration J. Gruber- ATO 1478 Pl(DS9-22)W1-3 ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany AR3B--6132-C .~. STATE OF ALASKA ALASKA"' AND GAS CONSERVATION APPLICA, iON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ~ Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 55' RKB 7. Unit or Properly Prudhoe Bay Unit 4. Location of well at surface 172' FSL, 324' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1278' FSL, 1479' FEL, Sec 6, T10N, R16E, UM At effective depth At total depth 1265' FSL, 1326' FEL, Sec. 6, T10N, R16E, UM 8. Well number 9-22 9. Permit number 84-173 10. APl number 50 - 029-21049 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 13,125 feet Plugs(measured) 9,133 feet Effective depth: measured 13,084 feet true vertical 9,098 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 20' 1055# PS 80' 80' Sudace 13 3/8" 3500 + 400 Sx 2822' 2549' Production 9 5/8" 500 + 300 Sx 12,862' 8870' Liner 7" 300 Sx 13,125' 9133' Perforation depth: measured 12892- 12917'; 12922-12937'; 12944-12949' true vertical 8936-8958'; 8962-8975'; 8980-8985' Tubing (size, grade, and measured depth) 5 1/2". 17#, L-80, PC tbg ! 12483'; 4 1/2", 12.6~, L-80, PC tbg @12574' MD Packers and SSSV (type and measured depth) 5 1/2" Otis RQM SSSV @ 2378' MDk; Baker FHL packer @ 12493' MD 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation November 198~ 16. If proposal was verbally approved Detailed operations program BOP sketch X I15. Status of well classification as: Oil. _ Gas Suspended Name of approver Date approved Service 17. I hereb/yi certify that the foregoing is true and correct to the best of my knowledge. Signed ~1~'~', j~~t'f"~''/ Title Operations Engineering Manager Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ,'~r),4-- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SM!TH Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 9-22i PROPOSED ADD PERFORATIONS APl # 50-029-21049 PERMIT # 84-173 ARCO Alaska, Inc. proposes to add perforations in DS 9-22 within the Sadlerochit Sand from the Prudhoe Bay Unit. The proposed perforation interval is as follows: Ref. BHCS Footage Flow (2/5/84) ('MD) SPF Unit Perf Depths ('MD) Ref. BHCS(2/5/84) 12840-12875 35 1/12 T5 12840,12852, 12868 Reference Log: BHCS (2/5/84) Well 9-22 is a WAG injector that is currently injecting SWI. The wellbore fluid present when the perforations will be shot is water. The expected bottom hole pressure is 3700 psi. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure (diagram attached). 3 J , 1. 5000 PS1 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PS1 WlRELINE RAMS (VARIABLE ,SIZE) 5. ,5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 ! ! iI ! 1 i HIRELINE BOP EQUIPMENT ! ARC[) ~,LA,',kA., INC, F' · 0, BOX i ("'.":'}360 ANCHORAGE, ALASKA 995' DATE' 1t-4-88 REFERENCE: ARCO CASED HOLE FINALS '~ !,-2 t 0/1 -2/88 "x'" '..-5,: '~"z- i,.., ..,.~ i 0-i 9-88 ~S-i 7 i 0/i -:.5/88 '~"-:3- t 9 i 0-24-88 ..~,..~_.~"',S- t 9 i 0-27-88 ~ 3 t9 i 0-27-88 ~ t 9-28-88 ~ 7-34 9-1 6-88 ""~ 9- ~ i 0-~-88 "~ 9-20 t 0-3-88 o ..... 9-22'-88 '~' 9-,55 9-26--'..:::8 '--"" i i -i i -'..'9-i -88 ~ i 2-'2 i 0-'~'z-°''~ i 2-9 9-i 9-88 ~ i 4-i 8 i 0-7-88 *~'"~' 'J D-i OA i 0-9-88 ~,'i 5-i 9 i 0-8-88 "'"-J i 5-2 i 9-30-88 "~i '7-6 9- i 4'-:]8 ,,~/i 8-i i8-ti F' AXE X I FLUID DENSITY CNL-GAMMA VERT i LOG TEMP SURVEY COLLAR CCL-F'LUG SETTING CET COLLAR/PFRF 9-i 6/t 7-88 COLLAR/F'ERF COLLAR/PFRF PROD!JCTION F'ROF'I I_E INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE F'RODUCTION PROFILE CNL-GAMMA COI_LAR/F'ERF GAMMA-COLLAR GAMMA-CCL COLLAR F'RODUCTION PROFILE COL. LAR/F'ERF 0-2-88 PITS 0-2'?-88 COLLAR/PERF GN AN[) RETURN i"H'E ATT~,CHED COF'Y AS' REC~-'-iPT RUN "> <" RUN i , 5" RUN t, 5" R~JN I, 5 · RUN t, 5" RUN i, S' RUN t, 5" Ir..'.tJN I, 5" RUN t, 5' F:tJN I , 5 · RUN i , 5" RtJN 1, 5 · RUN t , 5" RIJN 3, RUN ~, 5" RUN t , 5' RUN i, D' RUN t, 5" RUN t , 5" RUN t , 5" RUN t , 5 ' RUN I , 5 ° RUN t, 5" RUN I, 5" OF DATA, RECEIVED BY_ HAVE A NICE DAY! ~ALLY HOFFECKER AT0-i529 T,~.HN~ 8669 CENTRAL FILES CHEVRON. EXTENZION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES SAF'C STATE OF AI_ASKA TEXACO CAIdCO Al'LA:-:: A'FLAS CAMCO A"FLA:_:; SCI4 ~ _,1-t G E: A F;.: C A M C C A H C 0 C A id C 0 CAMCO CAMCO GEAR CAMCO CAi'iCO CAHCO CAHCO ~]. k" r4 F;.: C A id C A'i I_AZ THE2E LOGS' HAVE 'FHE WRONG APl NOS' ON 'f'HEM. 7-53 ~n.-n-:.,~-'~ 1 8~.~9 · ~'" ",./ "w" ~ · ~'~ ~ i 5-i OA 50-029--2050 t -0i THE CORREC'i' NOS' ARE' ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 20,~ 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 9-22 Approval No. 7-930 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMH/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 9-22)W1-3 RECEIVED WELLS3/40 AR3B--6132-C ~"-~-'~ STATE OF ALASKA .... . AL, . OIL AND GAS CONSERVATION COMMI,. 4 REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pull tubing __ Alter casing __ Repair well __ Purl tubing __ Other 2. Name o! Operator ARCO Aiaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Location of well at sudace 172' FSL, 324' ~J.,, Sec. 1, At top of productive interval 1278' FSL, 1479' FEL, Sec. At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service At total depth 1265' FSL~ 1326' FEL~ 12. Present well condition summary Total depth: measured true vertical T10N, R15E, UM 6, T10N, R16E, UM Sec. 6, T10N, R16E, UM 6. Datum elevation(DForKB) 55' RKB M UnitorPropertyname Prudhoe Bay Unit 8. Well number 9-22 9. Permit number/approval number 7-930 10. APl number 50-- 029-21049 11. Field/Pool Prudhoe 13125 feet 9133 feet Plugs(measured) feet Bay Oil Pool Effective depth: measured true vertical Casing Length feet 13084 feet 9098 Size Junk (measured) Cemented Measured depth · True vertical depth 13. 14. Conductor 80' Surface 2767' Production 12807' Liner 586' Pedorationdepth: measured 12922-12937'; 12944-12949' truevertical 8962-8975'; 8981-8985' 20" 13-3/8" 9-5/8" 7" Tubing (size, grade, and measured depth) 5½", 17#, L-80, PC tbg @ 12483' Packers and SSSV (type and measured depth) 5~", Otis RQM SSSV (~ 2378' ND; Stimulation or cement squeeze summary Baker FHL 1955# PS 80' 80' 3500 sx CS III & 2822' 2549' 400 sx CS II 500 sx C1 'G' & 12862' 8870' 300 sx PF 'C' 300 sx C1 'G' 13125' 9133' 12.6#, L-80, PC tail packer @ 12493' MD Intervals treated (measured) Attached Treatment description including volumes used and final pressure Representative Daily Average Prod:;c.':z~, or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation 0 3238 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations @ 12574' ND OCT :,.L':::L::~. 0i} &, 0~ ~i,, Tubing Pressure -- 807 0 3908 1392 16. Status of well classification as: Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~')//~~~ Title Form 10-404 Rev 06/15/88 Service Date SUBMITIN DUPLICATE Objective: Drill Site 9-22 COILED TUBING CEMENT SQUEEZE PROFILE MODIFICATION To modify the injection profile to reduce injectivity into the lower Romeo sand. 4/22/88 4/24/88 4/25/88 5/14/88 Performed coiled tubing acid wash across the following intervals: 12892 - 12949' MD. with the following treatment' 1) 2) 3) 20 bbls 12% HC1 dispersed with xylene 20 bbls 12-3% HC1- HF 23 bbls 12% HC1 RU coiled tubing. Fluid packed wellbore. Cement squeezed the following intervals with 40 bbls of cement: 12892 - 12917' MD 12922 - 12937'MD 12944 - 12949'MD Reference: BHCS 2/5/84 ,! tt ,! Contaminated cement. Reversed out contaminated cement. Reperforated the following intervals: Reference: BHCS 2/5/84 12922- 12937'MD 12944- 12949'MD Reperf 4 spf Reperf 4 spf Returned the well to injection and obtained new well test. JMH 10/6/88 ARCI] AI.A.?K ANCI.~rI[~.'A(~[.."., AI..A..q'KA ~95~ f) · Oil & ................................... P, uchom~ ...... · ~,: F' M T I. I. '[ I::' .? F' F~ la F7 !. I... F:' T I I::.c,' t:;.' ,% · ,?~ ,.?Tt~T.F'.. ('iF tql..~..q,'KO, ~ TF',v, A(]i'I ARCO AI...A..gKA. P., 0., BOX PLEASE ~ RECEIVED HAVE A N F'!.-.-. G G Y ~E ATO-~ 5°o PDODI.IC, TTON PF<F:IFTI..F-./.¢PTN/TF-HP I;.'IIH i. PI.!MP-TKI TFMPEF,.'AT! !RF/F,K" I.i.~tlHi . ~" F, 1CT .~/TFMp 171 li'J~ ~' PRF'IDIIFt. TTI]KI F'R'F1FTI. F/HPFM/F~R R'!IH t . ~.' F-'I~;F.ID!!CTTF1N. PR'I]FTI..F./DEN~TTY/TFMP R'I!N i . F'Rf]I'~Ili]TTf]h.I PF::f]FT.i. F/I--IF'FH/TF'MF' I;.'IIKIi . TN..IF{]TInKI F'F;.'f]FTI_.F/,?',F'T. NNF'R' R'IIN i : ':".3" F"RF1T)!itR. TTF1N PRtqFT. I F'/HPFH-I,JHIIT RIIN i . P!:;.'F.!1)i.lF:TTF1N PR"i]FTI.F/?.PTHNF. F,; R"lli'-J i. PI:;.'FIDIlC. TTFli"-.~ PI-'::F1FT! I--/.'-'C..I:'TNNI--I;." l-7"llhl ~ ':"" .... . .... i · · .*" f~AMMA 17AY/TTF-Tig I I]F; RI!N i ; F~i"'tMA R."AY/TTE-TN. LnG R"IIH TRAM.? '""-" A'E -,,.o80 ..... AF'F'RO"JED .... bl:2TRTR!.ITTRM P. AMRn f'I. A M i-: F1 P.AMC. O RAMP.n P..AMfZf] f':AMP.F] I":AMP. FI P.;.~ MCI'~ F'.AMCf'I RAMP. f] ~ CENTRAl.. F' I I...!'7.2 ~ PH'[ !..t...'[ P2 ~ CHEVRON F'tR I,JFI. i F'TI ..f) ,*. M · ~ EXTFH."~TF~N E.XF'!.. F!RA'TTFIN :.":. .~AF'f': - "- l:--¥¥f]N ~ :;.'I'A'TF f'lF Al A.~.~KA · .~o . .... .. . MARATHON ~ 'T F"( A I'":. f't $ Mr)'R T I. ARCO Alaska, In~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November. 25,' 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 9-22 Permit No. 84-173 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DAR/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 9-22)W1-3 WELLS2/32 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA "--' '--'-'. ALA,_.,A oiL AND GAS CONSERVATION CO,, .,.~,.,~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown '~. Re-enter suspended well ~ Alter casing 22 Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate rq, Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 55' RKB feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 172' FSL, 324' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1278' FSL, 1479' FEL, Sec. 6, T10N, R16E, UM At effective depth At total depth 1265' FSL, 1326' FEL, Sec. 6, T10N, R16E, UM 7. Well number 9-22 8. Permit number 84-173 9. APl number 50-- 029-21049 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Liner Length 13125 feet 9133 feet 13084 9098 Size 20" 13-3/8" 9-5/8" 7" Plugs (measured) feet feet Junk (measured) Cemented Measured depth ~ueVerticaldepth 1955# PS 80' 80' 3500 + 400 Sx 2822' 2549' 500 + 300 Sx 12,862' 8870' 300 Sx 13,125' 9133' Perforation depth: measured 12892-12917'; 12922-12937' true vertical ; 12944-12949' 8936-8958'; 8962-8975'; 8980-8985' Tubing (size, grade and measured depth) 5~"~ , 17#, L-80, PC tbg ~. 12483'; 4~", 12.6#, L-80, PC tbg @ 12574' MD Packers and SSSV (type and measured depth) .. 5~" Otis RQM SSSV @ 2378' MDk; Baker FHL packer @ 12493' MD 12.Attachments Description summary of proposal ~ Detailed operations program ~J I ECEIYED Oil & Gas Cons. Anchorage BOP sketch 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,certify that the foregoing is true and correct to the best of my knowledge Signed ~/~¢'~~~j~~ Title Operations Engineering Manager Date '/~'/'~",~ Commission Use Only Conditions of approval Notify commission so representative may witness I ~pproval~o. 7 ?~ ~ Plug integrity ~ BOP Test ~ Location clearance ~ Approved Copy eturn~ed ORIGINAL SIGNED BY Approved by Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triplicate WELLS/32 D. A. Rich, 263-4351 · · Be · DS 9-22 COILED TUBING UNIT CEMENT SQUEEZE WORKOVER PROCEDURE RIH with CTU. Clean fill and perform pre-squeeze perforation wash. Note any injectivity change. Continue water injection. Perform cement squeeze on all intervals through coiled tubing. Contaminate cement in wellbore. Clean out contaminated cement. 5. WOC at least 2 weeks. 6. Perforate: Ye 12922-12937' 12944-12949' Stimulate with acid. 8. Perforate: 12892-12917' Ref: BHCS 2/5/84 6 SPF 6 SPF Ref: BHCS 2/5/84 5 1. 5000 PSI '7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4. `1/`16" PIPE RAMS 3. 5000 PSI 4. '1/6" HYDRAULIC SLIPS 4.. 5000 PSI 4. '1/6" SHEAR RAMS 5. 5000 PSI 4. '1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 3 2 I 1 I COILED TUBING UNIT BOP EQUIPMENT 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EG)U I PMENI i ARCO Alaska, Inc. P.O. Box t08360 Anchorage, A[aska 995t~ DATE: March ~t, t986 REFERENCE' ARCO Cased HoLe Final DS 9-20 ~-22-86 spinner DS 9-22 i-23-86 Sp inner/Inj ~D$ 9-24 t i-i-85 ACBL/VDL/Si g/GR ~DS 9-27 ~ ~-3-85 ' Prod ~ DS 9-27 ~-5-86 GR/Sp inner ~ DS 9-28 J-3-86 GR/Sp inner ~ DS 9-29 ~2-~3-85 F'DK ~D$ 9-36 ~ ~-2-85 ACBL/VDL/Si g/GR ~DS J ~-J 2 ~-9-86 ~D$ J2-29 ~J-38-84 CCL/F'erf Record ! · Run t 5 ' Run t 5 ' · 5m Run ~ 5 ' Run t 5' Run t 5' Run t 5' Otis Otis DA DA Otis Otis DA DA $ch Please sign and return the attached copy as receipt of data. HAVE A NICE DAY' ATO-t 429F TRANS ~86t 97 DISTRIBUTION '-,,- Central Fi les -"--,,- Ch ew- on D&H · ,-'" Extension Exploration =·. · , Ex xon Marathon $ Mob i [ -,-- Phi llips F'B Well Fi Les R&D -'- $oh i o ,~- '"'-~---£tate'-Of Alaska ~~ Texaco ARCO Alaska, Inc. Prudhoe Bay ,veering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer May 2, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-21 DS 9-22 DS 9-23 DS 9-25 Permit No. 83-160 Permit No. 83-173 Permit No. 84-3 Permit No. 84-28 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/dh Attachments CC: Sohio Alaska Petroleum ...Company File Pi(DS 9-21)W1-3 .. File P1 (DS 9-22)W1-3 File Pi(DS 9-23)W1-3 File Pi(DS 9-25)Wl-3 RECEIVED 0ii & Gas Cons. Commisslo. Anchorage ARCO Alaska, Inc. Is · Subsidiary ol AllanllcRIchlleldCompany STATE OFALASKA " " ALASKA ulL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL×I-1 OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-173 3. Address 8. APINumber P.O. Box 100360, Anchorage, Alaska 99510 50- 029-21049 4. Location of Well 173 FSL, 330' FWL, Sec. 1, T10N, R15E, DM 1320' FSL, 1320' FEL, Sec. 6, T10N, R16E, UM 1340' FSL, 1167' FEL, Sec. 6, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 55' RKB I ADL 28345 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 9-22 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate X[] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate well 9-22 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating ~nd clean-up operation. Proposed perforation intervals: 12840'-12875 MD (35') 12892-12917 '~D (25') 12922-12937' ~D (15') 12944-12949' MD (5') 12988-13013' MD (25') Ref: BHCS 2-5-84 R CEIYED 0 2 1985 Alaska Oil & Oas Co,s. Commission 14. I hereby c~,~ify that the foregoing is true and correct to the best of my knowledge. ~.~, ~~.~~ Regional Engineer Signed Title The space below for Commission use Date Conditions of Approval, if any: Approved by. COMMISSIONER Approved Copy ~turned By Order of the Commission Form 10-403 Rp.v_ 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay r_.,glneering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 10, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-22 Permit No. 83-173 Enclosed is the "Subsequent" Sundry Notice detailing work done on the above-mentioned well. Very truly yours, D. F. Scheve DFS/JEB/dh Attachments cc: SOHIO Alaska Petroleum Co. File PI(DS 9-22)W1-3 ARCO Alaska, Inc. Is a Subsidiary ol AtlantlcRIchfieldCompany RECEIVED JUN ! 71 5 :,:::,.,,..-~ .j~ ,:, G~s Cons. Commission .:, ,~.chorage STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address p.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 173 FSL, 330' FWL, Sec. 1, T10N, R15E, OM 7. Permit No. 83-173 8. APl Number 50- 029-21049 9. Unit or Lease Name Prudhoe Bay Unit 1320' FSL, 1320' FEL, Sec. 6, T10N, R16E, UM 1340' FSL, 1167' FEL, Sec. 6, T10N, R16E, UM 5. Elevation in feet (indicate KB, DF, etc.) 55' RKB 6. Lease Designation and Serial No. ADL 28345 10. WellNumber D.S. 9-22 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Perforate Stimulate Repair Well Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' Pull Tubing (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] [] -Abandon [] Stimulation [] Abandonment [] [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 5-10-85. RU perforating unit and pressure tested equipment. RIH w/gun #1, shot interval 12892'-12917' MD (4 SPF). Shut-in well, POOH, all shots fired. RIH w/gun #2, shot select-fire interval 12944'-12949' MD (4 SPF); pulled up and shot select-fire interval 12922'-12937' MD (4 SPF). Shut-in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 2-5-84 RECEIVED J U N ! ? 1985 0,~ ;~ u~s Cons. Commission ,'-' ;~ch,~;age 14. I hereby ~,eftify that the f/gregoing is true and correct to the best of my knowledge. Signed ~._)~,~/. ~~. ~ _,-~~~--~'~~ TitleRegional Operations Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 ~o,, 7_~_~d and "Subsequent Reports" in Duplicate ARCO Alaska, Inc.. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 10, 1985 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-22 Permit No. 84-173 Enclosed is the Completion Report for work done on the above- mentioned well. Very truly yours, D. F. S cheve DFS/JEB/dh Enclosures cc: SOHIO Alaska Petroleum Co. File Pi(DS 9-22)W4-3 RECEIVED J u N ! ~ ]~085 Oi~ & ~as Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchflaldCompany --- STATE OF ALASKA .... ~. ALASKA~ ..AND GAS CONSERVATION CO, ,llSSlON WELL COMI LETIOII OR RECOMPLETIO# REPORT A#D LOG 1. Status of Well Classification of Service Well OIL I~[X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~ ~-173 3. Address 8. APl Number P. O. Box 100360, Anchorage, At( 99510 50- 029-21049 4. Location of well at surface 9. Unit or Lease Name 172' FSL, 324' FWL, Sec.1, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Weli Number 1278' FSL, 1479' FEL, Sec.6, TION,' R16E, UM 9-22 At Total Depth 11. Field and Pool 1265' FSL, 1326' FEL, Sec.6, TiON, R16E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 55' RKBI ADL 28345 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 01/15/84 02/05/84 02/15/84I N/A feet MS LI 1 17. Total Depth (MD+TVO) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 13125'MD,9133,TVD 13084'MD, 9098'TVD YES~ NO []I 2378 feet MD 1900' (Approx) 22. Type Electric or Other' Logs Run DIL/BHCS/OR/SP, LDT/CNL/OR/Cal, GR/CCL/CBL/CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Instld w/] 955~ Pm1 13-3/8" 72.05~ L-80 Surf 2822' 17-1/2" Cmtd w/3500 sx CS III + 400 sxs CS II 9-5/8" 47.0# L-80 Surf 12.862' 12-1/4" Cmtd w/500 sxs "G" nmi + 3~0 sx.~ PF "C" 7" 29.0# L-80 12539' 13,125' 8-1/2" Cmtd w/300 ~xs Ci~ "G' cm¢ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 12892'-12917' MD (25') 5-1/2,, ]?;574, 12922'-12937' MD (15') 12944'-12949' MD ( 5') 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Perf'd on 5-10-85 w/4 SPF N/~ TVD of perfs: 8937 ' -8985' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 5-10-85I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None J U N i ~ 1885 ~',~.~s~.a 0~ & G:~s Cons, Commission Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 8TA~g8 ' GEoLoGIc MARKERS " ' ~'" · ~- FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Zone 2 12,835' 8887' NONE Top Zone lB 12,915' 8954' Base Sadlerochit 12,998' 9025' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed . _ _ Title- Regional Oper. Engr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". STATE OF ALASKA ALASKA~'~ AND GAS CONSERVATION CCI ,ISSION /'~. WELL COMPLETION OR RECOMPLETION Fi"=PORT AND LOG 1. Status of Well Classification of Service Well OIL~~A~ GAS [] SUSPENDED [] ABANDONED [] SERVICE~ ~'~". . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 8/~173 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21049 4. Location of well at surface 9. Unit or Lease Name 172' FSL, 324' FWL, Sec.1, T10N, R15E, UM 'L~TIONs]'L ~ Prudhoe Bay Unit At Top Producing Interval 1 VERiFiED ~ 10. Well Number 1278' FSL, 1479' FEL, Sec.6, T10N, R16E, UM ~$ur£ ~- I 9-22 At Total Depth ]B.H. ~- ~J ~ 11. Field and Pool 1265' FSL, 1326' FEL, Sec.6, T10N, R16E, UM~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 55' RKB ADL 28345 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/15/84 02/05/84 02/15/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ] 20. Depth where SSSV set I 21. Thickness of Permafrost 13125'MD,9133'TVD 13084'MD, 9098'TVD YES [] NO [] 2378 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run DI L/BHCS/GR/SP, LDT/CNL/GR/Cal , GR/CCL/CBL/CET, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 80' 30" Instld w/1955# Poleset 13-3/8" 72.0# L-80 Surf 2822' 17-1/2" Cmtd w/3500 sx CS Ill + 400 sxs CS II 9-5/8" 47.0# L-80 Surf 12,862' 12-1/4" Cmtd w/500 sxs "G" cmt + 300 sxs PF "C" 7" 29.0# L-80 12539' 13,125' 8-1/2" Cmtd w/300 sxs Class "G' cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ... interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE 5-1/2" 1 2~574' 12~493' .. 26. ACID, FRAcTuRE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A .. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVI'TY-API (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Naska 0ii & Ga~ Cons. commission Form 10-407 Submit in duplicate Rev. 7-1-80 JMM/WC07 CONTINUED ON REVERSE SIDE :GEOLOGIC M-ARKE-RS .... '" , '~'' - ' ' '-' ' -" ' "' Fo~MATIbN :I-ES'I:S ' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Zone 2 12,835' 8887' NONE Top Zone lB 12,915' 8954' Base Sadlerochit 12,998' 9025' 31. LIST OF ATTACHMENTS Drilling Hi.~t-.ory; Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing,~ true and correct to the best of my knowledge ,~-~, ~~//' Area Drilling E ngr. Signed Title Date ~ ,~,- ~ -/ -/ I INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached. supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njection,,Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 9-22 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 0200 hrs, 01/15/84. Drld 17-1/2" hole to 2850'. Ran 70 jts 13-3/8" 72#/ft, L-80 w/FS @ 2822' Cmtd 13-3/8" csg w/3500 sxs CS III + 400 sxs CS II. ND 20" hydril & diverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld I II I 12-1/4" hole to 12,877 ~,, Ran 319 jts 9-5/8 47#, L-80 w/FS @ 12,862 . Cmtd 9-5/8" csg w/500 sxs" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 13,125' ('02/05/84). Ran DIL/BHCS/GR/SP f/13,100' - 12,837'. LDT/CNL/GR/Cal f/13,100' - 12,837'. Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs Coldset I + 125 bbl A.P. Ran 14 jts 7" 29#/ft, L-80 f/13,125' - 12,539'. Cmtd 7" lnr w/300 sxs "G" cmt. Drld cmt to 13,084' (PBTD). Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Run GR/CCL/CBL/CET f/12,994' - 12,368', GR f/12,861' - 2822'. Ran 5-1/2" completion assy w/tail @ 12,574' & pkr @ 12,493' &~SSSV @ 2378'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 1900 hrs, 02/12/84. DRN/DH61:tw RECEIVED JUN 2 Alaska Oil & Gas Cons. Gommission Anchorage Eastman/ Whipstock A PETROLANE COMFY REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY D.S. 9, Well Number: 22 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER A0284R0406-MZ TYPE OF SURVEY SIGMA-Gyro DATE 15-FEB-84 SURVEY BY CORAM/JAHN JUN2 119I~ Alaska,0~ & Gas Cons, nuomm[ssion Anchorage OFFICE Anchor age, Alaska Eastman DATE: 26-MAR-84 (907) 563-3650 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 ARCO ALASKA, INC.. P.O. Box 360 Anchorage~ Alaska 99510 Well Number: D.S. 9, Well No: 22 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: SIGMA-Gyro Date: 15-FEB-84 Method of Computation Radius of Curvature Surveyor/Driller: CORAM/JA~N Job Number: A0284R0406-MZ Attn: Mr. BILL CONGDON Dear Mr. Congdon, We are enclosing the original and eight copy/copies of the SIGMA-GYRO surVey run on the above mentioned well. : To dater the following distribution has been accomplished' A. 8 copy/copies delivered to drilling for in-house distribution. B. 0 copy/copies for noted oil company representatives. ~ 3 copies for E/W permanent w~tl files. We wish to take this opportunity to thank you for using Eastman %-~ipstock and look forward to being of service in the future. ~rel~ ~ f~ ~OM jON~~ Distri~echnical Coordinator cc/file RECEIVED JUN 2 1 Alaska 0il & 6as Cons. Commission Anchorage Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide . , ............ .O'.S '-".~., W ["::1_ I_ I',ll-I: .... '"" '::' : .... ::.,: .... . I GI'IA-E;YRCI ...lOB NFl AC.~2:E:4RO4-O/_-,-MZ I:'F;,'I_IDHC~E Bf...~Y~ NORI"H :i.:;I...CI:'IS~ AI..ASKA .............. %,.]LG£'f.b'A=~E!..,._JQ~_/:iEL~B]2E¥C~R: f":OR~ffl/,...IAl,lhl., ...DATE~ [(!.IN: 1 ... -,F EB..--,:,4. S I F[i PIP~ 3 (')(:) hi 0: '7 7 q.., F:'IR 0 B F I,,IC.I: (:)/::. 4 F::' f"~Rl'Z'.!ii; :[ (':iH T '::'/' '::' :':: 5 WhipstOck A PETROLANE COMPANY. , RE, t~IC4F<D .OF SI_IRVEY RADII..IS I]IF C:I_IRVATURE METHOD ..] l::;: C: ("l AL.A:i::;I<A, I NC. ]:=; ':)., WI:=L..I_ NO: :;;'.2 S_!~I¥1A.-r]iYF~CI ,Jl::lf'4 hll:':f: AO284F~C)4C.)6..-1'4Z C 0 I'"11=' I. T A T I 0 N "1" I M E l:) A T lie F'AGE NO. , 1' ::'RI I['d'..IC E BAY NOF<I'H '"' .... · , .=4 .,L F' E AI._A'.=;I<A (')6: 5/.'.'. ,, :3/=, ..' :.-.MAR- 84. 'I"I-~I_IE flEA'.SI IF. tED DR I FT [iR I FT COI_IRF:E VER'F I C:AL VERT I CAL ,-'11o''''~'/', · =._-,.=,~,-~ R E E: T A N G II L. A R E: L 0 c. I.I R E D 0 (-4 L E G DEF'TI-4 ANGLE D I REC:T I ON LEI',IGTH. [. EP ¥1--I F'4EF':.T InN TVD' FLEE]" D M D M FEET FEET FEET FEET C' Ci 0 R D I N A "1' IF. S DISTANCIE DIRECTION :_=;EVERI'I'Y FEET ~ FEET f) M DG / 10C~FT 0. 0 0 0 () 0. 10.00 0.00. .- '9 =i.,,. ._ . 00 100. ("} 18 S 78 4.2 W 1()0. 100.00 20.26 4...5.00 :20 O.. () 1 ..-.'=' N 82 24 H' 100 . 200 ,00 - 0 .69 14.._,. O. 0 :30 (~.. 0 6 S 41 4. 8 W 1 (] O, :300,0(] - 0, "~]o'" ':",.. 45 ,00 4. (] 0 ,, 0 1 :=: F-; 7 A 42 W ' 1 (] (]. 4 ('~¢~, ~'~ 0 - 1. :! 6, :'~ 4 ~. 00 ,', ....................... :,': ........... ,',:~ ........................................ :,-T--: ..... ,, .... 2...,: ...... :,, = ,~ ' ....L.-~ - ' 100. 500.00 -1.45 -1.52 0. O0 0. 0 · 05 S 0.26 W 0.07 S 0. S"~.~F-I;;;I 0.16 '.=: 0.92 W 0.44 S 1.12 W 4.45 00 0 67 c- .=;n.~ 00 "" 0. "-' =' S · -- "T '-- ~ 0.,.! 10C). 600.00 100. ~'- ' 6.~ Y, 96 O. 88 644,96 100 797'.¢. 77 /_' ..... 5 744.77 1 ("~0. ,-,o,_:, .-,.=, . ,:,._, 844 o~ ,:,;'.~' .,:.- 16 """- · 0.00 0 0 O. 00 0.26 '.=: 78 42 W 0.30 0.94 :3 :=:0 18' W 0. 1/"'. 1.20 S 68 2(:) W 0.2]. 1.37 W 1.49 W 1. ~'-'._, .' ¢',., 63 59 W . .-.=, o 76:3/=, W (') ' ' ..... 1 0, (:... 0 .' 73 N 0. '-'(' ,:, .) E :3.49 N .6.14 E 7 '"'-' ._.:, EE .,'.o N 15. r-;"" 1. ¢.)'"'o N 4:7 ? 9 E ......... J:. '.-.~ .......... ~ 7.06 N 60 22 E '::.",, 11 17. 15 hi 6,4 5:7': E 2.71 !..:; zI. · '% · 1 . 4'.:-:' · I. 8:3 1700. '2r-'; :31 N 86 14 E 1800. 2'2 2 N :=:!5 41 E 1900. :31 27 N 8:-=: 7 E 240 43 1 :,0,:,..'_-:7 · -:, ,:, - .,.,.,6.17 16'F'Y7. '..':3 336..=, 61 ~ 0 1783. 25.1~'o N 2:3.40 N 33. :31 N :2:84.91 E ,2:=:6. :3'2 N 84 1:=: E ':'._, ._, ._':" ~ , 0 :=: E 336 .68 N E: 4 19. EE '2, 00('). . :3:3 1:3 N :=:.1 ._5.=,'"' E '2100. :34 56, N 81 1.2: E 100. 192':3.10 100 · '", ' F, · . ~0(.)._ 'Fy3 40.28 N 48.51 N :2::3:3.06 E 4-4.2:. 4'F.* E :390.14 N :34. 4 E 446. 15:: N '-":' ~ 1 . :::":' ' 1.76 '220 (] '-' =' '='2 .... : ...... N 7:3 24 E · ';:Z :::_ 0(').. · ':'..,.~._ 46 N 74 .:,'-' ":¢.. E '_2..._.' ¢: C_) !_'?_ . , _ ___:_-_4.7. _4-0 _N_ 74 48 E 100. 20:E:7. 68 100. 216,9. 01 100 · 2249. 15 ._ 0.:,, 5::: 6:3 561.40 2114.01 620.6.=i_ '.='~. 194 .1 ._, =' · ~,'-' 69 N 72.24 N 88. C) O N 50C). 16 E .... ,o.7:3 E /_-.14.42 E 1./_-.9 -.'..22 .1.. 9o 2:5C) 0. 4(:) 51 N 75 4-1 E 260D. 44 0 N 74 7 E 1 CLO. 2:2:26.56, 100. 2400. :36 270(')._ 47 2 N 7:-_": 1° E,_, '2 -= (:)0. 49 '2:3 N 72 41~, E 2....''F.,C) 0. 5(') :=:4 N 72 14 E 1 Or). 2470.42 1 (') (') ..... ,:, 6 '7'-} 1 (')0. 26. 01.2.2: P.~. 227 . /= .... 44 I 56, 750f 32 234.5· :36 820.83 2415.42 8'24.44 14._~ 1. ':.-¢'~ 'Tt/-.¢y 93 '-,=',,! o.:, 104. 1':' N~. 121.6:3 N 675.62 E 740.75 E 683.60 N 81 14 E '750.6:3 N :=:0 40 E 141.68 N 16:3.44 N 1':'/- 47 N ~_m _, · 809.2.2: E :38r). 60 E 95.2:. 69 E 821.54 N 80 4 E ':'~5 64 N 79 '29 E ~_. ,.._ · . . 771.75 N 78 56 E :'::. 2:2: 3.:31 · q R C 0 A LA:'_-.'; KA, I NC. :'RL.IDHOE BAY, NERTH. F3L. OF'I?, AI_ASKA . ,!oF-J Nr3 :_ ~.!:~84R(')4.06-M Z C.:L]MI"-"U'T'A]' I I:)N P(..~l.'.:;IF' I\1(:). :;ii:' 'T' I M E D A ]" [--' MEASI...IRED ::RIFT [IRIF"F C:O!JR::;E VER"FIF:AL. VERTICAl._ '.:;I.JBSEA R E C 1" A I\1 G U L A R E: L. 0 '.::; U R E I:)O(:.iI_ECi~ DIEF'TH ANGLE DIRECTION LENGI"H DEPTH SECTION TVD C 0 0 R D I N'A T E S DISTANCE DIREC]"IOI',I L::;E.VI::RI]"Y ............ E.E,E]i I;! ........ _b..l ................ ~! .... ~_ FEET FEET FEET __FEET F'EEI" 'FEET D M DO / 1C.)OF'T' :3000 '=, 1.1 '--' N '71 ....:, E 100. 2664 ~'': .,:. ) 1046 27 2/-,(')9 2q) .... ' '" '= '-'= '-' '-' ( .... ' '-'~ z:.3,'"" ,_ .7:,71" J ' . 66 ,.7._ ...~ 56 :320C) t=i, 1-'=':=' N 7:2 .1. 4 E 1 (:)0. 278::::. 5/-, 1200 40 "" 'q" · . . ..I..I . . . ...... -'o4:,97 1278 14 · ::,'-':300,, ':'~'., ..' 1:---: N 72 46 E;. 100 '-"-' m . z.'-,'~m,~, ....,, .97 ............ 7!q:Q.!J:!., ............ ~J4.' ............ 1_._.N.,....Z:_~! ................. _CL E 1 C~O,, 2'F~09. '-L) ! 1 ..... ,7, 06 .-,:,....,4,91 ":' 10:37 Iq 1 (. ,:. 7, 5:3 E 1 C) 4::: 85 .~ , ')'"~ , Iq 7:3 26 IE '""' .~' . N 7'7 59 E ..'._-,4 ..7 N 11C) 1 86 E 1126.55 (') ,, :'::7 0 ':""/' . ._1 1,74. :':!:50(.".). 54 1 N 74 6 E 100. 2968.66 1437.01 2':) 13.6,6 :-~2::' '-"-' N 76, .'::;(') E · -, - ' ,-- '-,,'", .... , ..... , '-, ' '= "-: '-,o '~ ~.~ _,. o,:, N 1405, 'F/'F/ E 144:3, .9:3 .... · -, t-, ( )( ). ., .' ,-, · ..' ¢ )(.). ,4., C) -' 1 ( ) 1., 17 · A , -' :: 7 · C) ':':,.: C). 64 N 14-84, 1 .'-i E 1 ~' '-' ''= C) .1. 4...c E ........................................... ~ ................ N_.Z.~..,._.....z} ..... E .............. ,1, ................ ,,.,Z, ............ _,_ ....... _.~,-= .,_, 1 ... ._,....' .., , N 76 '-' 3'700 'q = "" ' ~'' ,:,Lx,,4 /:,2: ='~"'-' "'.':'.~ '-' (" '"' -':~ 63 ./ .37~ ':,9 1.=i/-,::: ~]:2 E 1606.75 :'-"':6 .... , t/_-, N 7q :'::A E 100 1._,.--o ._-, ., ~: .-. . N N 76 _ E . --. . . ~ .:.m :. # .,.,.. .... ., _ -- ' " ,m-- ,-- "'"ir :3800. !5:~1_ 4:3 N 7!5 b2 E lC)C). :3141 .27 1/.:, l:: (') .. _. 1.5 ._,Q (') ,:, A. ,_, _., :27 :2,.:~.3.28 N 1/:,4.~. .72 E 1/.,:::':'~.. 14 N 76:32 IF :~:'[~ C.)Q ,, ~LQ(~ ~ ,.:, ! ;~ 7, .,., :.:~ . 176, 2.29 ~: 142 .~ 3 4.1 '" ':'.' 722 · :, i N 1 9:':: E 1'771 79 N 76:3 .1. E: (")./,::,c. ...... 6 '7 N 76:38 E .4 C.) C)C) "": ............... ~,, *..,,.....,,--,, ............ ,'~ mr .-, t(. ' - - ,-' zL 1 c)(").. .~,,,.:L:,::~;..__b!,..._ZZ__.-.L4_ E 4. :20C.). 56 12 N 79 12 E 4:'::00.. 56 56 N 80 17 E .... 4:.4.!79 ............ ):)._6 .......................................................... 46 N ',311:3E Zl.~;(')(') 54 (") N o.":, ..... ,..,,. 21 E ...... 4:6!:)!:! ......... [j~ ..... 19 N :3:_:: 26 E 47 (')_ (')., 48 24 N ._,o._..':, 51 E 4-::::(')(') 48 3(') N '-'-' '= ...... =,._, i E ':~(-)("). _4'-' '-"-' hJ, '"~ 4 9 ..... _-'1:,. ............. c,_ -:.-:'';'....~F.- ! 50C)C). 47 46 N :35 44 E 5100. 47 :'-:7 N 85 4'.--.~ E 100 '-'/. ='5. · .:, :.._,.. 97 2416, O'F/ 3600 .' 97 10C), 3722.29 2490.89 :3667.29 '-- mm ,mi _ -"*"1 --i ~.." 5L-'5 78 N 2367 .=;:3 E ,:.4....... 2:1 N 77 '2'? E ~.-:, ._.=;._,...'--"~ · 03 N 2442 .0 ...... :::E 2'4 q'~':) · ._ ,:. N 7'7 41 E ~.,:.:c/._ _.. 0(] N2516 ./-':'_,._. E 2573, 7(')_ N 77 ~':q._ ._ E: 100, .':"='.=,.=, .............. 42 2/',::::~ '.-.-~2 380C). 4-2 '~._44, 47 N ':.'590, :::4 E 2647.4:3 N 7:3 8 E 100. :3922, 72 271:3.76 3867.72 549..'FYI N 26/:',4.60 E 2720, 76 N 78 20 E: ?., '.:.z Zl. (). :38 0. 6'::.:' 0.61 0.17 52 C) C). 48 7 N ,_,._':'.:, :--: 4 E 5 :'::_ 0 (').. 4 :E: 2 N c:._'- .~ 16 E 4(')(') 4.:--: 6 N '::'.':-] 2:1 E . . . 1 r)(-) :398 ? iD(') 2787. o- 39:34.8C) 1 (") C) ;, 41C)56. 60 2862. I 2 4001 · 60 i C)0. 4 I 2:3..4 I '2 S/ :E: /:, . 4 I 4C)68.41 555.46 N 27:2:8,56, E 2794·:2::3 N 78:32 E . ,'.z, 6o N 7::: 4:3 E 561.40 N 2817 74 E '"~' "".22 567.:36 N :2886·'?C) E 2'742.12 N 78 53 E C), 54 0.2.5 (1), 21 550C). 4:E: 1 N 85 .3F: E 56C) C). 4-8 20 N :35 24 E' · -'" 573.09 N 2961,C) 7 E :3016.02 hi 7'? :3 E: 100 4190.23 3010.70 41G5.23' 10C). 4";.:56. 'F~I :3085.11 42(,)1 · ':.-/1 578. ?/2 N :3C):35. :"::/:. E 3C)'F/0.0:3 N 79 1:2 E (::), 1:2 C), :_::7 5700. zl.::_': :36 N 85 28 E 5:3C) C). 4'? 22 N 85 15 E 5'.:./0C). 4 F-: 45 N :'-:5 7 E ~'" . 87 .9:--: ~ ,:, 4 N 310 9 E 31/_-, 4.50 N 7'P 21 E .'=; 9 (') '97 N '-' '-' .~. ::: 2 :::'~ 7'? 29 .... · -,1.-',._ 1'.'.-/ E ...... 55 hi E 5'.-:/7.2:0 N :326, 0.47 E 2:.2:14.7 :--: N 79:37 E O. 2?-- 0. :.:.:0 0.6,.'t T 3S 'P-, WEL_L NO: 22 SIGMA-GYIRO ,JOB NCI: A()284. R(')4.0/.:,-.MZ C: 0 M F'IJ l"A"l" I A N '1" I M E D A l' E :'RL.IDHOIE BAY,, NOIR'T'H SL. OF:'E.., AI_.A'.31<A (:T6: 5/:,: 36 2./:,-"MAR-84 TRUE -'l- I "-' C'll '-' qE ASI_IR E D BR I F'T DR I FT f ..... I1_ R.=,E VERT I C:AL VFRT I C:AL .:, - B.:,EA R E C: T A N G ]_l L A R, C: L 0 ..,':' i_l R E [) 0 G L E G I]EF:'TH ANGI_E D I F~EC:TIIDIq I..EiqGl'l.4 . DEF'TH RECT I ON. TVEf FE:EI' KI M D M F'EET FEET FEET FEE:'r C 0 0 R [f~I N A 'TIE S DI.=,IAIIL, E DII-2EC"I'ION SEVE:RI"I'Y FEET FEEl' D M D 73 / 10CTF"I' 6. 0 (30 . 4, :3 :_36 N . ...... ':' ~ =_, E /-, .... 1 (] 0 ,, 49 0 N ,_,':'=';._ 27 E 6 ()3.. 71 N..,._,'""':'..,._"::'"'-; , .:, _)'"'(' E.-,.-,,.','-"-' ''-'~''':~ . L=;O Iq 79 44. E 609.91 N :341 (.). :2:CT E :3464.4.1 N 79 5'2". [.':: 0. 14. C), 4.':? 6. 20 ("T . 4.'F..' 7 N ,_,':'...~ !56 F' 6:30 C) 4.:=: '"] 9 N ~'/- ...... :,., 16 E 6400, 4'.:'.-' :':: N :'=:6 10 E CT....:. ,::, 0. 1 () /-., .=; ('T (") 47:9:2 N 86 7 E lC)CT ~'*¢~ (')~/ .>7/.-,1 75 47?4 -,,:,.., .-. ....~' . .... (..T._ E .2:7 64. :2 7 N 8 0 :.'.it .1. E .......... /-,/-,('T('), 4:::: 1/-, N ::),,7 27 E lA('). 4915, ,:':-_:::: :::::::::A C)C) "'/' '-"-~ ''~ R:a .... Zl. ,:, ,_-, (.) , ,= ._ '/-',.::,4. N 37G.:5 4C) IF :.::::c:::_~ 27 N,:,(.T""' 29 E ......... =,.::,,.=L .', ........................ :r____'_'__-- .............. ,.--_ ........................... ~ .............. _'t...,,_' .........' -- ',' --- '"- _ ' ' -,.- · - - · " -' ./:,-7('TCT. 48 ' 0 N :5:7 11 E 100. 4982 56 3910 22 4':]27 =~ / ~ ':-,o '"l .-,m=o ...... . ..... :, 7 E ........ ,: .......... :, :, N ..-,,:,.:, ~ :::('T E '::':~ 12 .,' 4 N ::::0 '-'" """ (' . ...... '"" 6,:,(..T .) · 4:E: 1 N :E:7 47 F' 100 5('T4"), 45 :'~9R4,27 4'P'P 4, 45 ' 641,61 N :3'P:-":4 · () 7 E 3'78& 05 N ,::,(. 4. 4 E /..,9 ("T(') ,, 48 :3 N :B:3 17 E 100, 5116 .2:0 ' =''' - ' 4.(.),.,,=, ........... 27 5('TA 1 3:0 644 16 N 4,('T08:4ts: E 4 CTF, 9 o 1 N "":,(.'T '=i":' E: . 1 ().,:. () :,~: CT, 4.5 0, 2:7 70C)C). 48 ~.'~. N :3:3 2::: E 71 ('T("), 4:'-': 12 N F:9 4. E' 7200. 4:::::24 N :"-~'P 6 E 7F:00_ , 48 1':-'.., N 89 ~:..'-' E '74.(T('T, 4:~ :::4 N :::9 1:~ E ................ :....~ ................ ~2. ........ '~~ ..................... _"',_'. .................. ...~_. 7 F; ('T('T Z "' :=.:'-7/ ':' },:, .'::C) N i E '7600. 48 :=:6 N :F::'P :36 E 77 ('T. ('). ,, 4':). 4 o._, :::. '-?. 42 E '7:3C)CT. 4.'.-? 29 N :=:'F/ 55 E 7 ':'..' C) CT , 4'F' 25 N 8'.~~ 21 E 1 ()0. 5647.5C) 4652.29 5592.50 10C). 5712.7:3 4727.41 5657.7:_--: 100. 5777.72 4802. :--:0 5722.72 · _,6 N 26 C) 0 46_,..., E 4.727, N :E-:7: 4 E' ._, -- .1..· .- 4:. · /._,.=,....,c,. 04 N 4. 75:3. ,.._ E 4-:E: CT 2 ' ,:,.-, ~' ~' hi :E: 2 11 E (').. 44 :E:000. 4. 8 :':::3 N 81 10 E F:100. 49 36 N 7:--: lC) E 10 C) .... ~ 4..:..,. 487 8 10 5788 '-' = · _, ._! . · ._',._1 10C) ~,9(')R ~ .~ ~ =-'-' ...... 4 rye,..,, 56 ='~'=~' · :: ..... :'.J.=' · El5 /'='~ 26 N '-"-"-' ' 4,:,.:,.:, :=::E: E 4:=~7:3, 1:3 N 8:2 14. E L,"~ ._1 :;., · 672·;_4C) N 4'PCT7.71 E 495:3.61 N 82 12 E: 6.2'.';:: 2.51 :3200. 51 4 N 7:..3 22 E 8:2:00. 51 41 N 79 1. E :::4('T(3. .~l'2 F:/-, N 78 4:3 E ....... ~ .... ~ .-_ ....... ~-~_- .... ~-_~ 10C). 5':~72.66 5C):30. :_'-:5 5917.66 1 CT(:). 6035 · 07 5108..2:2 5980 .. 07 100. 6096 4:3 5187 1 ':' 6041 4-:~ · · ~ · - 6:BR 46 N 4'¢Z~-7:(-)9 E ~('T:'~(-T 4.2 N ':"-' ........ .................. :. :3 E 1.48 70:_--:.77 N 5059.71 E 5108.42 N :::2 5 E O.:=:CT 71'.~ 00 N .'"] :37 19 q' ' '-~::' · _ 1 E 51 .26 0, .... 7 N :::2 2 E .'.~ ..... ::.'::500, 5:3 12 N 78 4.9 E · _36i')('T. 54 :lC) hi 7'? 27 E 10 0 6156.74 ~'-' . · ~6~..72 6101 74 1 OCT. / '-' = . 96 · :,,' 1 .:, 5:347· 16 6160 ':76 0,6C) i · 0'? :E:7CW). 54:2:4 hi 7'=? :2:2 E 8:E:00. 55 7 N 79 29 E ::3 '=? CT CT . '=F,._,._ 4.2 ...................... N 7'-? :3 E 1 c)0 6274. '$,? ~,~,-:.,o 33 6219 s,'-., . · · .~.,a.. .... -'3",'1.=1 · . · ,~...~.. l (3 (') 6:331.7'P 550 9 ':~'- .... ; :~ /.:,276.7'F~ 10 ('). 638:=:, 55 55':? 2.20 6.2::3:3. 55 764 51 N 5.2:74 4.7 E ~ '-"-' ':' ._,4,'o 57 N 1 .=;4 E · · . i,..o -. 779. :3'~ N 5454., :=::=: E 551 C). 28 N :::: 1 5':.-' E 794,71 N 5535,77 E 55'?'-.-.'. 5:3 N 81 50 E 0,41 0.56 (') L ,=, ~RCO AI....~SI<A~ I NC ,, F:Cfl"IF:'L.IT~T I Ffl',l I::'Af':;liE Iqf], ::1-' ~;~r ~E~ ==' I s~I'R'' ~ EiLLr--s bl!]L~ __22. ......... ~i.I.~I.XI~:::~i.~E~£! .......... ~ N 0: A ..) = ,:, 4. I..~ (_) 4. ~.) 6- M Z T I PI E D A T E :'RL. IDHOiF. BAY., NOR]"I..4 '.BL. OPEE., AI....ASKA 06,: 56,: :]:6 2./.-.,-MAR-F:4 TRL!E ....... "l El A S I..IR E El EiR I F T [I.. R ! F'T C O I_1R'.E;E V E R"r'. 1' C A i_ V F' R 1' l C A L,-'.=,I_IB,'"..:,E A R E i-: T A N G I..I L A R -- F: L_ r'l_ L=; i..I R E ~ l]ll.'_l C41 E:' f': I]IEF:"I"H RIqGLIE DIRECTION L. IENGTH DEPI'H SECT!OI',I TVD C n FI R D T N ~ T E '.:3 DTS'TAI',ICIF. DIRECT! f"N SEVERI"I' .~.E.E~,I~.T ....[i! ....... ..PI ......... i3.....~_P] .............. F:rEET FEET FEEl' ' FEET FEET FEET [I M ~..11'"~/10OFT 9 C) C) C) 56 12 N 79 '='''- E 10 ("). /.':, 4- 4 ~ ._ ~. ~ A 74 ~ .,., o.:,,z,; ._ ~. :::,' 09 8.3 N .~5/-, ,1. '7 ":' .-,.-, -~'~' ':~ ' '-'""'"-'~ ~'~' .56' '- "::'"':' N ::: .1. q8 E 0" .... '""~, , ._,._,: ...... ,..-:.N F:::L 4.7 E 1 12 o, ,')(") =W. -'" "' ~'' ' "'- '-' . .... .~ ,= ...... o. _1, 644.4 '- "' ,, ...... ~s, ,~ .... :,;~.',.,,,=:~LL~,L..:;~..~. ~LD~i. .t(')O 6499 c/~", ~..]~.~,", ~., , ;~,=, ,'-,..."..:.: 4:3 N5/:,'.~'.:.~ 2:4 El =:;-z~,-, -'-.-, 1 (z) 0. 666, 4.4. 9 6 (")O,S:. 9 !5 66 (';~':."~. 49 0, r-. z ..'., ,.:;, 0 ,, 4:1. '.:.)5C)0. 57 11 N 7?' 24 E 100. 6.719.05 6092.'6,8 6664.05 i~76.04, 'N 6.029.85 E 6,093.15 hi 81 ........ ;~.?,Y:,.QO ............. 57.._..2D__1~_..~0 ............ D_E Z6LCL ........ 67Z;~..._1:3 _ 61.76, ZI_.__/~Z.!.~'_j_;~.. ,~:'.T~I. 06 N 6112, 62 E." 617'7.2.'.-.-,' N 81 4.2 E.:' '~.~700. 5'7 2:3 N 80 30 E 100. 6.826...94 62L-,0.S/3 6771.94 ,,' 905.32 N 6.1'.'"/5.6.'? E 6261.4F.: N 81 41 E '9:i::C)0. 57 10 N ::::0 24 E" 100. 6880.87 6345.09 6,825.87 919.28 N ~278.74 IF. 6:345.68 N :31 46.]) E ....... .t~.'~!)C!,.. ............ -.'5~_-4O,_,,I~L_.;E!!~LI~JZ ....... J._~!£! 6?;35. ,.,43, 6428.83 '6880.43 933.36 N 6.:361.35 E /_".42'?~. 4~:] N 81:39 E C) ,, 5:.::: 0.4'7 O, :38 0,52 , 6')(~ ,'- ~ ' ='-. ~ .-~ ,- ,~---~t.--. ~._'~ ~ ,--, .=,,-- .'-, 1 c) 6].)o6.'.)?,',/-, 2 7 Iq 7'P C) E 1..~,~- -.=, -~.~. -._ .-._-- -- --.._ __.l'~mm~"' :,, ,. 0.._,.."~m~.,.., 1 .,:.. 1 :~, 6, ...... :-, .;.:,.:, .. 4,_~...-, y N 6 4 4..:, · 4:--: E 6.51 ":'.,:.. ,:,...,'-' =' N :.]:1:3:i:: Ii!.' 1.07 :'-':4 :1020o !:'W-, ~=;:'>, N 7:'.-': 46, E 1 ,')~ 7100, U',~m~~J ~(~ J ,~~11~~. ":'9 IF. 6,679 " ........ . .4., · ......... ~7-=, '~I~i~II~C~ ~ 4E 6. 76,:3.4-4 N .1. :3 ! E (")..'.ii: 1 10:3C)C) .57 c',-, N 7 :":: c:.:,' E ! 0 1 ~._,. 0:1 67 ~-~'"~7~4~ I~L ~, =i ':' :=.../;~ .~.../2 N ~7,:, 1,:, E 10C~6,8 ~'l ::, N 81 E 6'.') 7:3 · -, ) E 6,846 r ~~ 10.~0c) 56 1~ N 77 54 E 100 7'-'~ = :19 ~9o9 · .. :,._, ..... .... c)'2 16 N , 27 ...... · · ... ,_- ........ .... . ~/6 E ~:, .... 9 F: 6') .09 N ,_,'::' .l E 0 .37 .-.! 1 (')/-, 63 (') f.i 5 ~ 4 i',1 7'7 2 2 E ! 6.')6.') 7:32 ('). 9 9 76') 1 1 ~...~'~- 7 ... 6._,. 9'? 10 4 8:3:3 N 6'.-.-, :34 0'2E 7 (319 96] N 81 2 4 I:::' (') 'q .; ....... ~: .,~-.v....:~..w ........... - - "- id · · · · # ra .... ,.# · .... 100. 7377 . '-"-'._-,..:, 7094'. 07.. 7:322 . '-:.::3 lCl6,6,.. .1~._ N 7014 . :z:O E 7C)9::'~ ...... · 36 N ,..,C:'l 21 E 10 0. 7 4:35.7.3 717 5.17 7:3 :--: O. 7:3 ' 1 f') 76,, c, - ,- ,=- . _. ,-,6 N 7 u Y._,. 1 '-} E 71 '7/-, 4 4 I',1 :.71 7 2 E" 100. 7497. 14 ' '-~=" '~.=.. 7~,.:..74 7442.14 1080'.00 N 7174.04 E 7z._4 87 N 8:1 26 E; 6,. '.-74 2.7:>' 1167) 00. 50:3 :.2 N :39 15 E 1 110c). .50 10 hi :::':' ':-":' E ............................... _.. .... .. ......... -- .. ._1, 16') 0 7 56, ('). 2 6 ~'--, ':: r, -' ~-' C' =' _ .. '-,-'~ .......... 7 :--: 26, 1081. 15 N 7251..=,':) E 7.z,._ 1.74 N :31:31 E a ! .,I .! ._1 ~ 100. 76.24.05 74C)7.22 756,9 J~ .95 :328 . .C.., 1081 N 7 .59 E 740:--: 03 N 81 :3/--, E 0.6.7 0.42 11:200. 4-9:36, N 89 :]:4 E 1 1:3o0. 49 4 N :_--:'F., 17 E 114o0. 4.8:32 N :39 4 E - · /' '-'"' J,_, ..' · .....~ N7 4.6.').~ c) 7 E 7 4,_~ .... 7:3 N :--: 1 41 EE 16] 0. 76, 8:3 48 74:3:3. 11 7 :,.:,.:,. 48 16' o.-, .=,,.-, _ · _ ,-, o 100. 775~:. 6.4 7558.40 767,8.6,4 1082:. 28 N 74:E:b. 9:3 E 755:_--:. '.-}5 N :-': 1 4.6 E lc'~O 7:319 49 763:3. 1:3 776.4 49 1084 ':'Y.i N -'=~' ~:-' - =c ,, ..... ,_-,. 17 E 7/-.:'~:7.._ :, N a: 1 .:, ) E . M , · · · ._1._ ~ -- -- 0.58 6:). 56,'_-. 0.56 11500. 4.7 57' N :--:8 3:3 E 116.00. 47 1 :'--: N :'-"::3 6. E 100. 7886.14 7707.23 7:-::2:1.14 1085.90 N 7630.70 E 7707.5:--: N 81 54 E 100. 7'753.~9 7780.6,7 7898.59 1088.05 N 7704.50 E 7780.'~5 N 81 58 E 0.7F: c). 66 1.176:)0. 4. 6. 15 N :--:7 52 E 11:30(:). 4!5:37 N 87 4:3 E ].l'T.,ClO· 44:3 8 hi 87 6, E 00. 8022 · 07 785.'_-:. 20 796,7.07 1090.6.2 N 7777.2::]: E 7:_::5.'_-:. 42 N 8'7.' 1 E 00 .............. 80 ~ 1 61 7924 75 8 o:.] A 6,1 1 o'-.-~:7 :~: 8 N 7849.14 E 7924.9'~: N ~.~':"-' 4 E 00. 816, 2. 16, 79 ?/5.36 8107.16, 10.96,. 58 N 7'.;; 19. '.--./4 E 7995.49 hi 82 7 E i 07S--' 0.65 1.07 q R C E A I_. A'.!!i; I< A, I N C. .JOB NO: AO2F.:4RO4OT-MZ E 0 M F' I_1T A'l" I 0 I',1 T I M E / D A'F E :'F~UDHOIE BAY., I',IORTH ::'~:LOF'E-, ALASI.:::A f:)&,: 56." :33:6 2/_-,.-MAR.-84 TRUE ' '""1 :('~' _ MEAE;I_IRED DR IF'T DRIFT F:L]I_IRF:E VERTICAL VERTICAL o_IE.:,EA R E C: T A N G IJ L A R C L 0 S II R EE Ii 0 G L E Fi; DEF'"I'H ANGI_E D I RECT I ON I_E:'NG'¥H DEF'TH SECT I ONi TVD F' E E: 'l" D M £.1 M F' E E T F E E T F E E T F E E T C 0 0 R D I N A T E S D ISTANCIE DIRECTION F:;EVERI'I"," FEET FEET D I'1 DG/10C)F"I' 1:2(')c)0,, 4. :3 54 N 86 4. :3 E 1 210. 0 . 4. 2: 4. 6 N 8,'2, ._"s,::,'"' E 1220('). 4.1 .48 hi 87 16 E 1 2:".~:(),r)..4.0 1. 7 N ,::,7 ._.,.. E 1:2400. :3::: 4.5 N 8:=: 4:9 E 1'2500. :]:7 '.--/ S F-:9 59 E 1 '2/., ('S (')'-'"=' ':' '" ......... · ',._, :3'7 S,..,,::, 4C) E 100 8774 2&, ~'"'"='"=, . '"' ' ':' ':":' 7:33: "'"=0~ 4.'.--.,' 7-,.-~_,---~--,--=' ............. .,,' .... . . o._,0._, 49 8719... 6, /I 110. 10 N ,.,4..,~., E o..,., .... N ,:::Z :.:,(..) E. 1. ~lt '-' '"" ~ .% ".' '.~ ~ ~'~' ,-., ~ ':'.' ':' "l '-' ~ ~' " "" = ='- ".~ 00 ,:,,:,.- 7 '-" 1106 97 '-' ':"-' ,=, o,. ~ N 0 3 '? 0 N 3 4 E 1 6'7 ,=,4 ...... =, E F::'.'.' ~'",. I. I ,': · CiO '-'~' c'~. '- '-'.=; "":' ,::, ;~ ~ 1 81 1 :Z · 57 '-' ~' ~' z - . ,_,_, ,:,o,:,o.~.:l 1102.9'.'-/.. N ,: .... 41 70 E 8612 67.-': N :"'":~ E ('~ 74 1 (");ii,mmg026.6~:664.2/,, E:971. &,&, 109:'334, .5'.::.'.~ Iq '""'=" 4 E 8664. '"'""' .... .:,._, N :.--.'::2.' 4:1:: =as man Wh pstook B' o L:.,7 c, 4 E"_ 8707 44 N '"'-' 47 , L') .." A PETF?OLANE COMPANY · C). 1 :':: 12. P';_,, :31 ...":: 9. o._, :::_ 5 .:,'" E 4.1 q 1 :'::.'::. 07 E:728 .':-:c) '- ,', ,-, '",,"', ....... .~07,:,. 07 1092.93 I',1 86,59.77 E / ,:,7 .-. ,:,. 47 N :3:2 4-8 E F I N A L C L. 0 ::;l_l R E - [I I R E C l' I 0 N: N 82 DEGS 4:--: MINS 25 SEC:S E C). O0 D I STANC:E: 8728.47 FEET f.:~:~; '.:.~ ~ WELL 19(3: ':.2:2'. '.:; I GMA--;3YRC~ ,..IC.~B NO: A('~2:E:4RO40/:,-FIZ F'F(I.JDHOE BAY ~ NORTH f:-i;I....L':;F'IE, AI_A'.:;I-.'::(-~ .............. SI.[:.t2LY.[!;: Il., C~:~_P2LE! ~..: Si L! F,: V E ~C! FEFC20 R A I1'! / ,_1A H N, [Lt~T E. F,JlJI~I_-__:1. >, ~ E E B ,,, 4 C.; ]: C~ I"I h :30 O N J. 7'2' 4 F'IR O F.-~ E. N O .' O &, q. F' O F:( E: '..:_; I GHT 2/..'.,:~:, :'::$ Eastman ,:, WhipstOek A PETROIANE COMPANY · .]l~C:f~l .F:~I....(.~SF:::(.'~, ]: I',IC, 3'.E '.:.), 1,4 [.:: L.. L -" . N J. :::' 2 '.E; I G M ¢1.--(3 Y R CI ,_1Ci B N 0: A O 2 :i.':: 4-R O 4-O 6-. I't Z C O I~i F' I..1"1' A'I' I O N T 1 I't E f.) A-I" E :'RUEd-.4OIE BPi",", FIOR]'H '.E;I_.OF'E, '(.~L. ASI--'::A ....................... M A RI-.'.'. F." R .............. T R I._1E 'S I_1B '.:5 E (..l C:ODE I'tI~:.A.:.L.IRE][ VEERTIC:AI_ MD-TVD VERTICAL R E C: T A N G I.I L A R L R E V[.:'RTIC:AL.. ........................... Ixl(.~ME ................... [:lEl:"l"l-I DEF'I'H D IFF DEPTH C O O R D I N A T E '.S D I STANCE D I REC'I' I ON 'TI,--I I CI<:IxlFZSS FEET FEET FEET FEET FEET FEET D M '1' 01:::' Z Olxl E :2 '1" 01::' Z OhlE ]. [~ B A !""; E :::; A D I_.I'Z R O C H I T Eastman Whtpstoc I, A PETROLANE COMPANY ' Suggested form to be inserted in each "Active" well folder to d~cck for tin~ly con~liance with our' regulations. ' ' Operator, We l"Name and Number Reports and Materials to be received by: ~ ~-/~- ~'/-/ Date Required Date Received Remarks Ccmpletion Report Yes . Registered Survey Plat ye-S ~ -e~ 7-'~ /~/~ . Drill Stun Test Reports /~6~/~/.~:_ Logs Run. Yes ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date: June 11,~1985 Reference~ ARCO Pressure Data 9-22 Static Gradient 5-11-85. Camco Please sign as reciept of data. Received by Pam Lambert ATO 1429C Trans 145 Gas Cons. Commiss[ort Anchorage Chevron ~"~: & M Expl., Services Ext. 'Exploration E-X~on- Marathon '~il P~r~-I I ip s PB Well Files Sohio ' ~.~~f Alaska ARCO Alaska, Inc. Post Office~--'' 3 Anchorage, .,a~a 99510 Telephone 907 277 5637 April 13, 1984 Reference' ARCO Cased Hole Finals D.S. 9-22 2-11-84 CBL/VD D.S. 6-10 1-11-84 EPL RUn 1 5" Sch Run 1 5" Sch sign and return the attached copy as receipt of data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFar land A?.O-1429F T~:ans.. ~A136 ,. :. _ DISTRIBUTION Chevron D & M Dallas Drilling Ext. Exploration Exxon Getty MarathOn Mob i 1 · SCo~~ Mobil E a P AI;c/;o-~ · CO~ ,~_, Phillips Prudhoe Bay Well Files R-&,D Carolyn Smith Sohio State of Alaska ARCO Alaska, inc. Post O ffic~3 ' 60 Anchora~, .-~,__,<a 99510 Telephone 907 277 5637 April 13~ 1984 Reference: ARCO Cased Hole Finals D.S. i-iA 2-3-84 D.S. 9-21 2-6-84 D.S. 9-22 j 2-1-84 D.S. 12-25f 1-29-84 D.S. 12-25/ 1-29-84 D.S. 14-14~ 1-12-84 D.S. 17-6/' 3-24-84 CBL/VD Gyro Continuous Tool CBL/VD CET EPL Collar/Perf Ran 1 5" Sch Run 1 Sch Run 1 5" Sch Run 1. 5" Sch Run 1 5" Sch Run 1 5" Sch Run 1 5" GO f P~lea'se sign and return the attached copy as receipt o'f data. . FRIDAY THE 13th is upon us -Have a Nice One! Kelly McFar land ATO'-1429F Trans. #144 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mob i 1 Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Sm~ th~. _ State of Alaska ,'~::~s~a ¢;I & O~s Cons, Commissio~ Artchorage ARCO Alaska, Inc. Post O ffi~-.~ ~'-'~",60 Anchora~_ A._.~,(a 99510 Telephone 907 277 5637 April 2, 1984 Reference: ARCO Open Hole Finals D.S. I-iA _1-30-84 ~1-30-84 ~1-30-84 .-1-30-84 .-1-30-84 .~1-30-84 D.S. 9-22 ~-2-6-84 ~2-5-84 .~2-5-84 ~-2-5-84 .--2-5 -84 D.S. 12-25 -'1-26-84 Jl-26-84 ./1-26-84 --1-26-84 ..1-26-84 ..1-26-84 CPL / Cyb er 1 ook BHCS/GR DIL/SFL/GR CDL / CNL / Ge (Raw) CDL/CNL/GR (Poro) CNL/GR/CCL CPL/Cyberlook BHCS/GR DIL/SFL/GR LDT/CNL/GR (Raw) LDT/CNL/GR (Poro) CPL/Cyberlook BHCS/GR DIL/SFL/GR LDT / CNL (Raw) LDT/CNL (Poro) GR in casing _-Run 1 5" Sch Run 1-2" & 5"--- Run 1 .2" & 5"~ Run 1 5" Run 1 5" Run 1 5" Run 1 5" Sch Run 1 ~2" & 5"-- Run 1-'2" & 5''~- Run 1 5" Run 1 5" Run 1 5" Sch Run 1 "2" & 5''~' Run 1 ~-2" & 5"--- Run 1 5" Run 1 5" Run 1 5" ~~Please sign and return the attached copy as receipt of data. HAVE A HAPPY EASTER! Kelly McFarland ATO-1429F DISTRIBUTION Trans. f/ 126 Chevron D &M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith Sohio State of Alaska ARCO Alaska, Inc. Post Office Br~'"-'~60 Anchorar~-~'% .a 99510 · Telephone :~07 277 5637 April 2, 1984 Reference' ARCO Magnetic Tapes / · /D.S. 14-31 3-5-84 CH CNL #69048 w/listing .S. 9-22 2-5-84 OH ~68980 w/listing Run 1 Run 1 Sch Sch Please sign and return the attached copy as receipt of data. HAVE A HAPPY EASTER! Kelly McFarland ATO- 1429F Trans. # 111 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon~ Getty Mobil Mobil E & P Phillips Prudhoe Bay Well Files R& D Carolyn Smith '- °-~v~'~ C'/~'~ Sohio Marathon State of Alaska STATE OF ALASKA /%/~ / N ~ ALASK/ . _AND GAS CONSERVATION £ ilSSlON MO THLY REPORT OF DRILLING AND WORKOVER OPERATIO 1. Drilling well)~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 173' FSL, 330' FWL, Sec.1, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 55' RKB, 21' Pad ADL 28345 For the Month of. February ,1984 ', Pe_r~jJ No. '3 ~-173 8. APl Number 50- 029-21049 9. Unit or Lease Name Prudoe Bay Unit 10. Well No. 9-22 11. Field and Pool 'Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 0200 hrs, 01/15/84. Drld 17-1/2" hole to 2850'. Ran, cmted & tested 13-3/8" csg. Drld 12-1/4" hole to 12,877'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 13,125'. OH logged. Arctic packed 13-3/8" x 9-5/8" annulus. Ran, cmtd & tstd 7" lnr. Ran CBL. Ran 5-1/2" comp assy. Secured well + RR ~ 1900 hrs, 02/12/84. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set @ 79'. 13-3/8", 72.0#/ft, L-80, BTC csg w/FS @ 2822'. 9-5/8" 47.0#/ft, L-80, BTC csg w/FS @ 12,862'. 7", 29.0#/ft, L-80 BTC csg f/12,539' - 13,125'. SEE DRILLING HISTORY Instld w/1955# Poleset. Cmtd w/3500 sxs CS III + 400 sxs CS Cmtd w/500 sxs "G" cmt + 300 sxs CS Cmtd w/300 sxs "G" cmt. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/BHCS/GR/SP f/13,100' - 12,837' LDT/CNL/GR/Cal f/13,100' - 12,837' GR/CCL/CBL/CET f/12,994' - 12,368', GR f/12,861' - 2822'. 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ' TITLE Ar-~m Dr-~ 11 { nn Fnn~ ~,' DATE . NOT~E.~ER~ort on th'_..~/orm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska O/H~nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 DRN/MR69 Submit in duplicate V 9-22 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 0200 hrs, 01/15/84. Drld 17-1/2" hole to 2850'. Ran 70 jts 13-3/8" 72#/ft, L-80 w/FS @ 2822' Cmtd 13-3/8" csg w/3500 sxs CS III + 400 sxs CS II. ND 20" hydril & diverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 12,877'. Ran 319 jts 9-5/8" 47#, L-80 w/FS @ 12,862'. Cmtd 9-5/8" csg w/500 sxs "G" cmt. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW- ok. Drld 8-1/2" hole to 13,125' (02/05/84). Ran DIL/BHCS/GR/SP f/13,100' - 12,837' LDT/CNL/GR/Cal f/13,100' - 12,837'. Arctic packed 9-5/8" x 13-3/8" annulus 300 sxs Coldset I + 125 bbl A.P. Ran 14 jts 7" 29#/ft, L-80 f/13,125' - 12,539'. Cmtd 7" lnr w/300 sxs "G" cmt. Drld cmt to 13,084' (PBTD). Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Run GR/CCL/CBL/CET f/12,994' - 12,368', GR f/12,861' - 2822'. Ran 5-1/2" completion assy w/tail @ 12,574' & pkr @ 12,493' & SSSV @ 2378'. Tested hanger and packoffs to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr. Secured well & released rig @ 1900 hrs, 02/12/84. DRN/DH61 'tw ARCO Alaska, Post Offi,.. Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 20, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - DS 9 Wells 21-22 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG6/L40' tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany VI Ci~,IITy ,MAP i~ =. 4~~ AFICO Oil ~nd Gss Company Division of Atlantic Richfield Company NORTH ALASKA DISTRICT-PRUDHOE BAY DW6 No~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION · Drilling wellX~[ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-173 3. Address 8. APl Number P. O. Box 100360, Anchorage-, AK 99510 50- 029-21049 9. Unit or Lease Name FWL, Sec. 1, TION, R15E, UM Frudhoe Bay Unit 4. Location of Well 173' FSL, 330' at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 55', Pad 21' I ADL 28345 10. Well No. 9-22 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool For the Month of. January ,1984 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0200 hrs, 01/15/84. Drld 17-1/2" hole to 2850'. 13-3/8" csg. Drld 12-1/4" hole to 12,200', as of 01/31/84. SEE DRILLING HISTORY Ran, cmted & tested 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40 weld conductor set ~ 79' Instld w/1955# Poleset 13-3/8" 72 0#/ft, L-80 BTC csg w/FS @ 2822' Cmtd w/3500 sxs CS Ill + 400 sxs CS II. 14. Coring resume and brief description NONE 15. Logs run and depth where run N/A 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that thefo~,[egoing is true and correct to the best of my knowledge. SIGNED , , .... TITLE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 D R N / M R 62 Submit in duplicate DS 9-22 DRILLING HISTORY NU 20" hydril & diverter system. Spudded well @ 0200 hrs, 01/15/84. Drld 17-1/2" hole to 2850'. Ran 70 jts 13-3/8" 72#/ft,_.w/FS @ 2822'. Cmtd 13-3/8" csg w/3500 sxs CS III + 400 sxs CS II. ND 20" hydril & diverter system. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Frld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 12,200', as of 01/31/84. DRN/DH54'tw TO: ' MEMORANDUM THRU: State of Alaska FROM: 1984 Edgar W. Sipple, Jrt..--~uBJEcT: Witness BOPE Test on Petroleum Inspector ARCO's Prudhoe Bay DS 9-22, Sec. 1, T10N,R15E,UM, Permit No. 83-173, Rowan Rig 35. Thursday, January 19, 1984: I traveled this date from Doyon 9 (-Subject of another r~po~) to ARCO's Prudhoe Bay DS 9-22, Rowan Drilling Rig NO. 35. The drilling contractor was in process of nippling up. The BOPE test commenced at 12:00 pm and was concluded at 3:15 pm. There was one failure. The inside BOP valve failed. I informed Mr. Steve Cameron, when the valve was repaired and tested to 5000 psi, to call the A.O.G.C.C. office. I filled out the A.O.G.C.C. BOPE inspection report which is attached to this report. · in summary, I witnessed the BOPE test on ARCO's Prudhoe Bay DS 9-22, Rowan Rig 35. Attactunent Mr. Steve Cameron-called the A.O.G.C.C. office January 20, 1984 at 11:50 am, the inside BOP valve had been repaired and tested satis- factorily. .02-00IA(Rev. 10i79) O~G.. #4 4/80 STATE OF AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator ~~.- p/~~~ well ~p q~ % ~ . Location:. Sec / T/~b7 R;g6OL~! Drilling Contractor FO~&~/ Rig # ~r Representative...~o_ ~~ ~,~/ Permit ~ ~- / 7~ /3 V~asing Set @ ~_~. ~ ft. _ Representative O: 6~Pv Location, General Well Sign ~/4~, General Housekeeping Reserve pit Rig ' BOPE Stack annu~., a r P~reven~r Pipe Rams ~ . Blind R~ Cho~e Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ~00 o . o~ ACCUMULATOR S'YS T Et.l Full Charge Pressure 3(9~ psig Pressure After Closure /~0~5- psig 200 psig Above Precharge Attained: O min~__sec Full, Charge ~.. N2 2.~.oo .~01 ~A,~o,/fL~,,..~$oo_~,~3~a ps iq Cqntrols: Master ~< Remot_e ~65 Blinds switch cover ._ Kelly and Floor Safety Valves Upper Kelly. ~"~Test Pressure Lower Kelly. 6'"~t~ Test Pressure Ball Typo ~~< Test Pressure :rnside eOP~.,]~l Test Pressure Choke Manifold '"a9/4 Test Pressure NO. Valves /5 NO. 'flanges ~ '' Adjustable chokes ~-~4~- }~ydrauically operated choke I;~.~- Test Results: Failures~ / ~esi--G~n~ ..... ~--h-rsflS-~'~,," ---- . - ~_ ]RePair or Replacement of failed equipment to be made within' ' ~s a~ ~ ~ Ins~ctor/Com~ssion office notified. / Distribution orig.' - AO&GCC cc - Operator cc - Supervisor November 2 5, 1983 Mr. D. S. Smiley Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 ' ' ~ Alaska 99510 Re: Prudhoe ~ oay Unit DS 9-22 ARC~ Alaska, Inc. Permit No. 83-173 Sur. Loc. 173'FSL, 330'FWL, Sec. 1, T10~, R15E, ~. Bt~mho!e Loc. 1340'FSL, i167'FEL, Sec. 6, T10N, R16E, UM. Dear l~k. Smi!ey: Enclosed is the approved application for permit to drill the above referenced well. If corin~'~ is conducted, a one cubic inch chip from each foot of recovered core is required. Sam. plea of well cuttings and a nvad log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~any rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 amd the regulations promulgated thereunder (Title~, ~ Atas~= Administrative. Code) . Prior to co,nmencing. operations you may be contacted by the Habitat Coordinator's Office, DePartment of Fish and Came. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations pro~.~.ulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal %~ater Pollution Control Act, as amended. Prior to c~mencing operations you may be contacted by a represeDtative of ~e Department of ~ ' ~=nv~ronmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to com~encing installation of the blowout Mr.~ D. ~.~ Smitey Frudhoe Bay Unit DS 9-22 -2- Nove~ber 25, 1983 prevention equipn%ent s° that a representative of the Co,~%~is~ion may be present to witness testing of the equipment before the surface casing shoe is drilled. %~ere a diverter system is required, please also notify this office 24 hours prior to c~mencing equipment instal!etlon so that the Commission may ~itnes.~ testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advanc~ notification so that we may have a ~ness present. Very truly yours, · ~. ~. Chatterton Chairman of Alask~ Oil and Gas Conservation Commission be~ 6: ;{tA EnclOsure Department of Fish & Game, Habitat Section w/o encl. Department of Environn~ntal Conservation w/o encl. ARCO Alaska, Inc. Post Office B~,~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 9-22, Permit to Drill Dear Mr. Chatterton- Enclosed is our application for Permit to Drill DS 9-22 and the required $100 filing fee. Attachments to the application include plats detailing the section and plan views of the proposed wellbore; a proximity plat; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we anticipate spudding this well on DecemberS, 1983, your earliest approval will be appreciated. Sincerely, D. S. Smiley ~/' Area Drilling Engineer DSS/JG'tw GRU5/L20 Enclosures AlasKa. Oil & Gas Cons, Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION III:lIMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name SERVICE ][~ STRATIGRAPHIC [] SINGLE ZON lO,Water MULTIPLE ZONE [] Prudhoe Bay Unit % ~. .,. 10. Well number '~ ,'~ 9-~2 173' FSL, 330' FWL, Sec.1, TION, R15E, UM At top of proposed producing interval 1320' FSL, 1.~.20' FEL, Sec. 6, TiON, R16E, Uivl. - At total depth 1340' FSL, 1167' FEL, Sec.6, T10N, R16E, UM 11.Fieldandpool i;' Prudhoe Bay Field ~ ~_, Prudhoe Bay Oil,Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 55', PAD 21' ADL 28345 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town: 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 4 mi. E. of Deadhorse miles 173 feet 9-20 well 237'@ 700'TVD feet 16. Pro-posed depth (MD & TVD) 13121' MD, 9109'TVD feet 17. Number of acres in lease 2501 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 50 Proposed Casinq, 18. Approximate spud d~te 20. Anticipated pressures 3466 . psiS@__ Surface o (see 20 AAC 25.035 (c) (2) 4076 psig@ 9109 ft. TD (TVD) Liner and Cementing Program SIZE . Hole i17-1/2" ~ 2-1/4" I-1/2" Casing Weight 20" 91.5# 13-3/8" 72.0# 9-5/8" 47.0# 7" 29. O# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 Weld L-80 BTC I 2792' L-80 BTC I 12779' L-80 BTC I 610 SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 80' 33' 33' I 33' I 33' 32' ~ 32' 12511 ' 8717' MD BOTTOM TVD 113'1 113' I 2825' 2500' I 12811'1 8910' 13121 ' 19109' I (include stage data) 2000# Poleset ~300sx CSIII & 400sx CS II ;OOsx Class G & 300sx CS I 400 sx Class G ARCO Alaska, Inc., proposes to drill this well to 13121' MD (9109' TVD) for injection of source water into the Sadlerochit zone. Logs will be run across selected intervals. A surface diverter will be installed and operationally tested prior to spud. A 13-5/8", 5000 psi, RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17#, L-80 tubing, and packer will be run. The packer will be set above the Sadlerochit. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A Sundry Notice will be submitted when the well is to be perforated. DS 9-22 will be 237' away from DS 9-20 ~ 700' TVD. There are no other close wellbores anywhere downhole. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~.~. / .,~ Area Drilling Engineer SIGNED , -~ TITLE The space below for CONDITIONS OF APPROVAL Samples required []YES Permit number APPROVED BY Form 10~01 Mud log required I Directional Survey required I APl number I-lYES ,J~O ,~¥ES []NO J 50- O ~-~ -"~ OZ/~ Approval date ~~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~ovembez 25, Z983 ~ ¢/"~'~~ by order of the Commission Submit in triplicate D$9-22 1200 2400 3600 4800 .6000 7200 0 1200 2400 3600 4800 6000 7200 8400 9600 2.5 KOP TVD ' 81 I0 !"'~'" ~7.5 · i~ ALAS8 INC. 37.5 . SHL' 173~FSL, 330~F~L, SEC 1, ~ T10N, R15E, UM ~[ :~ ITHL' 1320'FSL,, 1320'FEL', SEC 6 T10N R16E UM ...... I 13 N ~ ~E~ ~7 MIN ! 9-5/8' :ASING TVD = 8910 TMD = 12811 DEP -- 8848 ~ TOP SADLEIIOCHIT ~D ' 8920 ~D - 12826 DEP -- ~660 LCU ~O - 8S20 ~0 -- 12826 DEP -- ·ARGET ~D -aeeO TMD, ~ae=o DEP · aT.a BASE SAD[EROCHIT TVD -- 8045 ~D - 13021 DEP "8808 .................................... { ......... , ....... , .......... , , , , , , , , , , , , .... , 10800 0 8400 9600 10800 1200 2400 36O0 4800 6000 7200 8400 9600 0 1200 2400 3600 4800 6000 7200 8400 VERT I CFiL SECT I ON 10800 9600 10800 Ala. s~a Oil & (3as Cons. Anchorage D S 9- 2. 2 ooo o 0 -' 1000 0 I000 2000 3000 4.000 5000 6000 7000 §000 9000 10000 ! ! 0£ W 0 0 0 Z ! i i i i i i il i : i i i i i i i i i , i i i i J i i i i i i i J i i ~ i i i i i ~ i i i i ! i i i i i I i~ i i i i I i i i i i i i i i i i i i i I i i i i i i J i i i i i i i' i i I i i i i i i i i i i i i i i i i i i i I ii i ii i I I I L , . ., SHL: 173~FSL, 550'F~L, SEG 1, " T10N, THL:1520~FSL, 1320~FEL, 'SEG 6 T10N~ R16E~ . . , , · .' ~ ~2 '. . :5~ [ ...... . ;~;' TARGET 8980 S ~' " ND' 12920' ~'.'':' L'~ i"' NORTH 1147 ' _ ,, ~ '..-.. ...~:.~,./¢~ ~ EAST 8 6 S 6 ' C~ , ,'. ....... -:. ................... !,.,' ...... I ............................ 11000 -1000 0 1000 2000 3000 4.000 5000 §000 7000 8000 9000 10000 o - 1000 0 1000 2000 3000 ~t000 5000 6000 7000 0000 9000 1000O 11000 i i i I i i i i i i i i i i i i i i i i i i i i i i i i i i I i i i I i i I I I I I I I I I , I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I C~ · CD ~ ~170 36 3 ~~ 20 os 9-12 ,~ o ~ :.:0 ".~-~ 05 i I I I I I I I I , , ] , [ I , I I I [ [ I I I [ ~ [ ~ [ I I I I [' f I I I I I ' I [ ' ] [ I [ [ [ [ ' ' ' ' ' ' ' I [ I [ ' ' ' ' ] I I ] I ' ] ] ' ' ~ ' [ [ ' [ [ ~ V I [ I ' [ ] ' ] [ ' ' ' I ' I ' ' ' ' [ ] - 1000 0 1000 2000 3~ ~000 5000 6000 7000 8000 9000 10000 11000 E - ~ COORDINflTES DS 9- 22 ~. - ~ - lO0 0 1 O0 200 300 ~00 500 600 Z CD CZ) CD CD CD I - ~oo o ~oo aoo ' soo NOTE' 1~/ELL PATHS EXTEND E] - 14 COOROINFtTES B~.¥om) VIF. XINC 500 6O0 1 O0 1200 ~00 1 ~00 1500 1600 1700 1800 CD c~'n~ n NOTE'YoND WELL PATHS CONTINUE BE- ~'~'~'~ VIEWING WINDOW. · , .................. I ......... I ......................................... 0 o o I I i 100 t 200 1300 1400 ! 500 1500 1700 1800 £ - ~ COORDINatES 1500 1600 1700 1800 1900 2000 21 O0 2200 2300 2400 2500 i i ! i i i i i f i i ~ i i i i i i f i f ~ i t i i i i i i i i i i i i I i i i i i I i , tl i , i , i , i i , , , i , i , i i I , , ! , , , i i i i i i i i it i i iI , i i , , ~~.Q8 3512 3544 3351 ~ ---'-~"'--~- ~ 3255 ~~ 3158 ~~ 99 ............................. .......................... ............................... 500 1600 1700 1800 1900 2000 21 O0 ~ ~ 2300 2~00 25[ 0 o o i..-.-q ! I NOTE: WELL PATHS EXTEND BEYOND VIEW- E - W COORDINATES ING WINDOW. ANNULAR PREVENTER BLIND 13-5/B" BOP STACK Accumulator Caoacit¥ Test · Check and fill accumulator reservoir to proper level with hydraulic fluid· 5. Assure that accumulator pressure is 3000 psi with 1S00 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with charging prep Off. 4. Record on IAO¢ report. (The acceptable lower limit is 4S seconds closing time and 1200 psi remaining pressure. 13-S/8' BOP Stack Test PIPE RAMS SPOOL PIPE RAMS 1. Fill BOP stack and manifold with a non-freezing liquid. 5. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock dmen screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a. gSO psi low pressure test for a minimum of 3, minutes, then test at the high pressure. $. Increase presure t~and hold for a minimum of 3 minutes~1~ressure to zero. $. Open annular preventer and close pipe rams. Increase pressure and hold for at least 3 minutes. Bleeder--eS: ~s-u~e-'to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. g. Test remaining untested manifold valves Ii? any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. Ig. Bleed pressure off all equipment. Open blind rams. Make sure man~fold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and ~nside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16.- Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate 8OPE daily. Rev. 5/13/81 SURFACE HOLE D 'f VERTER ARCO ALASKA SYSTEM INC'. SCHEMATIC b I0" HYD. OPR. BALL VALVE WELL BORE (SEE DETAIL) I0" HYD. OPR. BALL VALVE I ALL 90" TURNS ARE "TEE" WELL QBORE , RESERVE PIT AREA NOTE' ~ . FLOWL INE ~~~u" O%VERTER LINE Valves on diverter lines open automati- cally when the annular preventer is closed. DRILLING RISER 20" 2000 PSI WP ANNULAR PREVENTOR IO" HYDRAULIC OPERATED BALL VALVES DR ILL lNG SPOOL CONDUCTOR PIPE "DETAIL" 20260102 CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE ('2 thru 8) (.,9' thru 11) (4) Casg ~.~, //-~r-~7 (12 thru 20) (21 thru 24) (6) Ada 2 //,- 2a"--O ® 10. 11. 1. Is the permit fee attached ......................................... 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 well bore plat included ... 7. Is operator the only affected party ....................... 8. Can permit be approved before ten-day wait .............. Does operator have a bond in force ..................... ............ Is a conservation order needed ..................................... Is administrative approval needed .................................. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO / ,,, REMARKS Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings .o. Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... /fi,g, Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached..:... '~ Does BOPE have sufficient pressure rating- Test to .~~D pslg''- Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. z~, Geology: Engineering: LC S BEW HWK~WVA JKT~ ~.~~ JH JAL (//.'~_._~..MTM rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE o Well History File APPENDIX Information of detailed nature that is not padiculady germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. -: o oo LIS TAPE vE~IFIC~TIO~ L/STING ,f:VP (;1F$,F!CP VVm.lr~lc.L~,l'!O.'4 I.TS?It<G PAGE ** TAPE .HEADEi; ** SEPVlCF a~ ~ ~-~E :EDIT DATE OR IgI ~,t :00~0 CO~TXNUATI~N ~ :01 PR~V ~'OllS T~PF CO~,{MFNYS :f,IBRIRY TAPE EOF' ********** ,SERVI CF NA~E VER8 I0~,', ~ PATE : }'I T,E TYPE ** INFORMATION RECORDS ** ~N ~ ~: ~ C 0 N T F N T S CN : ARCO ALASKA INC wI~ : g-22 P~ : DRUDHClE BAY RANG: 15~ TO~N: 10N SECT: 1. COUN: N.SLOPE CTOY~ USA !:INIT TYIDE CATE SIZE CODE 000 o00 016 0:65 o00 000 004 065 000 000 0S2 065 o00 o0o 004 065 000 000 004 065 000 000 002 065 000 000 008 '055 000 000 006 065 000 000 004 065 LvP 010 HO2 VKPI. FI.¢;'ATIf'~N L, TSTi~C PAGE * SCHLIJ~BERC, ER * , A[,~S~A CBt~PUTIMG CEt~TEP * ************************************************************************************* WELL = D,S, ~-~2 COUNTY = ~ORT~ SLOPE ~OR[~B'GH ,..lOB ~U~bER AT ACC; 6m9~0 RUN ~,1, DATE LOGGED: 5 Fw.P. 1984 !.DP: $, ',:AR,SHAT,b CA$I~;G CASING DEMSITY VISCOSITY Pi, t.~ 1. D t, OS$ 1.19 M 66 DF ,85 ¢ 66 DF 1,96 M 65 DF ,49 9 170 DF' ******************************************************************************** ( * ~tJ~[, I~D~CTIOI~ SPHERIC~LL~ FOCU,SED bOG (PI[,) * * [,ITHC DF~SITY CO~PFN~ATED LOG * CO~'PF~,SATED ~E~JT~(3~J [,[)G fL, PT) ** D/~TA F'OP, N/~T RFCORI) E~'r N. ¥ ~LOCWS TYPF, SIZE R ~] P i~ CODE ENTRY 4 ! 66 t)~TI~ ~P'EC?F~C~TION BLOCK8 TLD ~IL gR ~Ib CAPI G~ PHC GAPI ~PwI LDT PU ~CMI, I:BT CPS ~CK~[, I,DT CPS CALl LOT MR~T BDT ~NRA Pg~ GR [,bT ~API API APl bOG TYPE CbASS 0 0 0 7 0 0 7 1.2 46 7 0 O 7 t n 60 52 32 60 31 32 0 6B 2 0 44 0 35 I 0 34 g2 0 34 ~3 0 2~ 3 0 42 1 0 0 0 0 o 0 0 3~ 32 73 65 API FIFE'. ~OP }I0. 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 81 60 ZE PROCESS LE¥'F.L 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4' 0 4 0 4 0 4 0 4 0 4 0 4: 0 4 0 SAMPLE 1 1 1 ! 1 1 1 1 ! 1 1 1 ! REPR CODE 68 68 68 68 68 66 66 68 68 68 68 ** DATA ** DEPT Sp NP}tl Sp NPHI FCNb DEPT NPH I FCNL pg~ D g p SP NPHI ~CNL DFiPT SP 1313g -999 39 966 13.~00 341 069 3~ 13~00 17 32 879 0000 SFLU 2500 GR 3555 DR~O 5000 CALl 6484 G~ 0000 SFI.,O 0156 GR 5215 DR};u 5000 CALl Ji~75 GR 0 o 0 o S F L D n469 GR g ~Ol DRHO . oo.o CALl o3.~ 3 GR 29,931,6 DR~O ~g, 0000 CALl 3,5605 ~a 0 00 t .... S F I.., U 3,4. (') 000 ,, R ~q9q,2500 TLD 099,25O0 DT 0,()444 2,7305 NRAT ~,01.7500 7 0859 117 3125 0 011,7 6 ~.211 100 8750 4 7500 ~10 6250 o 0269 9 (I03 64 0625 TLD DT RHOB ILD DT 7813 .T L D '5156 5547 NR.~T 27,6563 2000,0000 l 123,~125 DT -q99 2500 -g99 2500 GR 2 3301 NCNb 2 9102 ~NRA I [.,~ 3105 NCNb 8437 RNRA 5,941.4 l[.,~ 86,1250: GR , 5840 NCNB ,9258 RNRA 46,9062 lb~ 94,1250 GR ~:3105 NCNb 74:02 RNRA 42,9375 6P., ~.875 GR -999,2500 -999,2500 3008,0000 3,1113 6,632B 1. 17,31:25 293],0000 ,0234 5,570,3 11~,62:50 27 ,0000 3,I660 ,5! 6 33 ,00 0 2,8750 2000,0000 1,23,8125 -999.25,r:0 DR~iL) -o99,7500 CA!I -09c~, 9. bO0 ~iR -999.2.50(.1 WILE ~,1 ~, .~! F' :EDT? .CO1 UAXI~I.I~ I,E~GTH : 1024 FI~,E TYPF -999.2500 -999.2500 -999,2500 ** TA. PF TRAIb[~TR SERVICE NA~,E r) AT ~:: :84/03/13 ORIGIN :0000 T,APE N A,~E :~9~0 C[]NT~NIIATION ~ :01 COJ~MhTNT8 :i,I. BRARY TAP'~ BATK :~4/03/13 ORIGIN : REEL, NA~K :135478~.~ CONTINUATION NEXT REEL NA~E COMMENTS :LIBRARY TAPE EOF EOF