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198-044
Kyle Wiseman Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 04/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230414 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPF-81 50029229590000 200066 3/29/2023 READ CaliperSurvey MPI-04A 50029220680100 201092 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 4/2/2023 READ CaliperSurvey MPI-27 50029236920000 221013 3/20/2023 READ CaliperSurvey MPL-12 50029223340000 193011 4/2/2023 READ CaliperSurvey MPU I-27 50029236920000 221013 3/23/2023 READ LeakPointSurvey PBU 09-23A 50029210660100 198044 3/28/2023 READ MultipleArrayProductionProfile PBU L-112A 50029231290100 222138 3/27/2023 READ MemoryRadialCementBondLog END 1-11 50029221070000 190157 3/19/2023 AK E-LINE Perf END 1-29 50029216690000 186181 2/9/2023 AK E-LINE Perf NCI A-08 50883200280000 169063 3/20/2023 AK E-LINE Perf BCU 19RD 50133205790100 219188 4/4/2023 AK E-LINE PPROF SRU 224-10 50133101380100 222124 3/31/2023 AK E-LINE CIBP_GPT_Perf SRU 224-10 50133101380100 222124 4/3/2023 AK E-LINE GPT_Perf SRU 231-33 50133101630100 223008 3/29/2023 AK E-LINE GPT Please include current contact information if different from above. T37595 T37596 T37599 T37599 T37597 T37599 T37598 T37601 T37603 T37600 T37602 T37594 T37604 T37604 T37605 PBU 09-23A 50029210660100 198044 3/28/2023 READ MultipleArrayProductionProfile Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.17 14:10:44 -08'00' •• OF T�� • • �w���\I%%i so THE STATE Alaska Oil and Gas °ALASKA Conservation Commission Witt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF wh= P Main: 907.279.1433 ALASFax: 907.276.7542 � z1_ www.aogcc.alaska.gov Jessica Sayers Well Integrity Engineer \:()\°2-BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-23A Sundry Number: 315-595 Dear Mr. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this 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. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this S day of October, 2015 Encl. RBDMSJC OCT 0 6 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N • • APPLICATION FOR SUNDRY APPRO 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 •Repair Well ®Re-enter Susp Well 0 Other Well Lock OA ® - 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-044. 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-21066-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? RECEIVED Will planned perforations require a spacing exception? Yes ❑ No ® PERI09-23A . 9. Properly Designation(Lease Number): 10. Field/Pools: SEP 203 �2O1 5 LI S ADL 0028345 • PRUDHOE BAY,PRUDHOE OIL' 11. PRESENT WELL CONDITION SUMMARY //y g2gC lc Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Jurfk(fh )'" 18000 • 9043 . 17913 9041 Casing Length Size MD ND Burst collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 2669 13-3/8"72#L-80 29-2698 29-2522 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 16265-17885 8992.49-9040.83 4-1/2"12.6#13Cr80 13Cr80 25-16065 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program I3 Exploratory 0 Stratigraphic 0 Development I I Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ® • Gas ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer Signature / Phone +1 907 564 4281 Date al 123 'i s- 10 COMMISSION USE ONLY Conditions of approv.I. otify Commission so that a representative may witness Sundry Number: 315-695 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No I/ Subsequent Form Required: /9 4 e)4" 5 Approved by: ale.7 IAPPROVED BYTHE ..2-0‘4„.2(4,....._ COMMISSIONER COMMISSION Date: 1p, 6-.l S' V7L !a/z//` - ORIGINAL RBDMSj, OCT O 1241§ Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • m 0, 0 0 0 0 0 0 0 CO N- CO CO N O O O — CO N- C` O O CC) CC) 0 N d' N- N- N U r-- .500000000 0 i O) M N- N- CO CO Cr) M 7 '� 0) CO CO CO d' CO CO CO 00 CO CO O N co N Cr) vcr ONO N CO Nt O N LOO CO O) O CO O) N CO 00 O) CO 00 i I i I i i i H LO O) O O I. co O O) N N NO O O NCO CO CO CO 4.0C Gn CO OCO — (O in 0) CO Cr) O ti CO O O O O N O O • N CO W CO CO CC) CO 4.0 QMCO O O CO CV N N CO C O N p�cy co m m u, C O � J \ 0 • co� oO ooCoCp Q o U U = JZOo -� ChCh 11) N * --I ,N V) ' V - N N N U _CD Mao bo NN 7 OLO O N 0 0) �' V- 4 4 L 0) O O) .- O)O CO ' N CO tO O 0) 00 COCOO) ti O) O Cr) J NOO •- tn W W 0)O — — a - w o o •yC) U W W Zwwwwmm 0 ZZ » • • • Date: • 09-22-15 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 09-23 WellLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This . well exhibits OA repressurization when on production and is not manageable by bleeds. • WellLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use a pneumatic pump to squeeze the WellLock into the micro-annulus with high pressure and low • volume. Once pressure fall off dissipates the WellLock will be squeezed with Nitrogen. Well Detail Current Status: Not Operable — PAL Previous Test: 11-29-10 MIT-T, CMIT-IA Pass to 3000psi 06-20-13 MIT-OA Shell test @ 2000 psi, LLR 0.048 gpm Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas) Well Operation Detail Fluid Density: WellLock: 9.1-9.3 ppg (keep WellLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 75°-80° F throughout the entire job Relevant History: > 09/07/09: LLR-OA of.294 gpm for 30 min with diesel at 2000 psi: LLR-OA of 0.05 gpm for 10 min with hydraulic oil > 11/29/10: MIT-T Passed to 3000 psi, CMIT-TxIA Passed to 3000 psi > 08/21/11: PPPOT-IC Passed > 09/01/11: OART = —29 psi/day > 06/20/13: Using diaphragm pump to MIT-OA for LLR of .048 gpm @ 2000 psi. MIT-OA to 2000 psi - Lost 756 psi in 30 mins. > 10/23/13: Using diaphragm pump to MIT-OA for LLR of .186 gpm @ 2500 psi. > 01/27/14: Pulled WRP from 15923' Well Program: 1 D Clean OA v, strap TOC • 2 V Install OA Companion valve 3 SPr Strap TOC and fill OA void to bottom of VR profile. Rig up pneumatic pump. Squeeze WellLock into OA with nitrogen. 4 D Bump to target squeeze pressure (not to exceed 3,000 psi)three times. 5 V Service valves. 6 D Leave nitrogen cap (approximately 200 psi) on OA. Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 7 D After seven days, POP well under evaluation 2 of 3 • • A TREE= 4-lelEr C1W yie19,4„READ= FMC 09-23A SAFETY NOTES: EX1131DED EACH Pf3INIERAL ACILIATORAKER C SAIETRACK-WL A$ GE TO*ED 16666%"""4-1/2"R=. 4:8—ti—FAI.— vs CEIRDNIE Tea" lik_[ler= _ 1 KOP=. 10641 LAW ANN:, 92* 173111 I I AA rciails ND- '-- 15853'. OAS LIFT SAAFIFFFIS rod.Ivo= MOP SS !ST I 114)IL ''1V1314:61‘11 T P111 11 VW 11 A TC1111 POR7- DATE 120 03NDUCTOR_H*2_j 1 3613 131171 51 ; 40.6 DOW RCT',' 18 -6301448 — 2 6714 15007 52 1 MC ' CAB F8 1 0 03121 11AZ -911*CS0 474, - MC - i 3 8 'L-40141 0 503,113-,11.561` i ll '781 8154 1 52 004r C 18 te 1 Kam B1ams i 1 .....--..... 4 10571 i fa 1 $33G2 1 DONE BK , 16 0921106 1 , ; 10962 1DOLE. a( ri V 03/21/00 1 '.1L= 1 411 SOT 0-12.34r 6 14927:W1I 61 -; K002 4 SOSK i 20 1W21A16 : = 8466° lw9-56r X r am ZXPLTP 4 14TEAK Ilkliihritsin 0 a 3.813w fa 2302' t Eta 1.001 ECK 0=6 3ir r "4-1/2"HES X NFPLE ,4 4 1 0 L0111 WOOD*108,21/A)WO 01-9450 I 1 i $1V41:'''-1 111'•,,,...,,,.,,,,,,,,,,,... 04«, WM.44, 44.0 44411* 4.4.4.11.411 4.4.4.1 .,,,.:::-,-• 41.4% . 464211 4-i,2•1 hes x AIP,0=31113' 1 f ,...., 144 4 . .....1.6.4.6.V. '4.--wrisvi-row , - low r x 4.07 ex0,..0-3.__10 .1104:0, .... 1 28 A 58' I 48 ID=1.966" ifielEk 1596c' -r x 4-tfr 44418.6c7vERSBOT tzt 2-‹ . loot -1X4-Il? S(RS-3 EXH,C=3 ow I ......,_ I 1 0,42. _ —X W40 1 1_1_411*1 1604r s a 1 of149' 4.*X V'SKR ZXP LTP 1 cter iraG,12611,acme 111181A v Au. ,31A,hpf m -I Am* 1 i 1 60461 1 11: 0,, 0 MC HOB 13=4.43r \ .-- 1f42-VA.153 V=3,955' r oft 2010.1.,-ai arc,'ix.Asa 191,C=02M --1 16235* 1, 1 i ; "1-4-5=ii-iii:k51671.158-1 CIEVE,C3RA TION%AWRY Rtf WO BiXS LAMP 0,403.,1/60 4/43LE ATTCP PEW:7V 016265 1 I , WA Ferfer ia Raduclen CE fo.historical pert data 1 I Safi SPF T 14TERVAL OpriScF1 "SHOT , ''S& ..- 274* 4 A it7•41660 A 637117 ii - - 2--mr 4 16440-BM 0 1 0,3111,199 2-?/011 4 *CV-Met, 0 I 03,1419 2-735` 4 Mao-17280 0 I 04116110 3-11W 4 17475-17550 0 1 03/16(99= 2-wr 4 17770-17865 0 03116/99 1•11 1-1811LD0 i 17111"7- I I , * 4-UT(AK 1181,1,60 si-m,0152 myr 0_39—e-iFL.H. isoor ...-.--4 ... - DAM 11 REVIEW C0141311S aft—wig-—— COMMENTS PRUDHOE f3AY 1641 03468114.41004IAN38 00100441.031opt..En01# 11/21/08,,1313EaLH MEP 56111(10(280) M..1. 0 -23A _ 11813618; RIM 10731008 D4451R1C DBLQ DRAFT COBREC11C88 MUT Nx-ri3e3440 03128109 0 ODETRI1CK"A" i ,01/27(14 14x0 RIC FULL ARP AMA/ 51 WS 210E6,01 031101$' 014 0800 1 SEC 1.TION,Ht5E.54 ESL&MP PAL -04.111x8 1807111-7—As&IL 174:620-10474-344) I 07161io3' ATOM ORAVMO CORRELTEN0 , ; 11P 0aptori600(Alas** 3 of 3 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 r i December 30, 2011r�EB 2 .4 1_ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 'Gig— ©� 333 West 7 Avenue Anchorage, Alaska 99501 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 -404) 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 oal 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 Tanko 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 A 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 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 7/82010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 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 10/20/2011 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 WA NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/182010 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 10202011 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 1020/2011 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 10.2 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 10.2 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 10202011 NOT OPERABLE - 09-23A (#1980440) OA Repressurization is unmanageable Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Page 1 0~ ~1~.~~~ Sent: Wednesday, July 16, 2008 12:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; NSU, ADW Well Operations Supervisor Cc: Winslow, Jack L.; Phillips, Patti J; N~ ADW Well Integrity Engineer Subject: NOT OPERABLE - 09-23A (#1980440) OA Repressurization is unmanageable =-~ All, After almost two weeks of bleeding the OA pressure on well 09-23A (PTD #1980440), the build up rate is still unmanageable. At this point we have no plans forward for the well, but are awaiting the outcome of a peer review scheduled for early August. In the interim, the well will be classified as Not Operable. A gas sample will be collected from the IA and OA to aid in the review. Operations: Please ensure the well is shut-in as soon as possible. ~ Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: U, ADW Well Integrity Engineer Sent: Wed day, July 02, 2008 7:58 PM To: 'Regg, ]am B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, S2 DS Ops Lead; NSU, ADW Well Operations Supervisor Cc: Roschinger, Torin T.; Ilips, Patti J; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATI - 09-23A (#1980440) Sustained casing pressure on the OA All, Well 09-23A (#1980440) has been c firmed to again have sustained casing pressure above 1000 psi. The wellhead pressures were tubing/IA(OA qua! to 210!1640/1440 on 06/30/08. The well has been reclassified as Under Evaluation to further evaluate the urce of the high OA pressure. Although initial gas samples were taken and showed two different gas campositions etween the IA and OA, gas samples will again be taken and the OA pressure allowed to increase up to 2000 psi t evaluate the potential for IAxOA communication. A TIO plot and wellbore schematic have been inclined far reference. Please call with any questions. Thank you, 8/29/2008 ~- Q ~ IV ~~ ~ ~_ • ~ ~ ~ ~ d 0 ~ J 0 1 o ~ i a 0 0 a ~ ~ cn N 0 o ~ ~- t7~ 9~L 0 0 u~ ~~ 0 a ~ I ~ ~ 0 a ti ~ ~ °o °a 0 0 ~ ~ i~ d a 0 0 ni ~ ~ ° i 0 0 0 0 0 o~ ' TREE = 4 118" 5M WELLHEAD= FMC ACTUATOR = BAKER C _...~ KB. ELEV = 49' BF. ELEV KOP - 1094' Max Angle = 94 (c~ 17379' Datum MD = 15853' Datum TV D = 8800' SS 19-5~8" C:SG. 40#. L-80. ID = 8.835" 13-318" GSG, 72#, L-80, ID = 12.347" FT 09-23A 694' 2128' --~4-1t2'° HES X N1P, ID = 3.813" 2700' GAS LIFT MANDRELS Minimum ID = 3.813" @ 2302' 4-1i2" HES X NIPPLE TOP OF 7" LNR 9465' 9-518" CSC, 47#, L-80, ID = 8.681" I~ 96QQ' 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I~ 15964' 9-518" EZSV I~ 9900` ITOP OF 4-112" LNR ~-i 1604$'' 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 16063' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 16233' PERFORATK7N SUMMARY REF LOG: SWS LWDIGR ON 03(17!99 ANGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 4 16265 - 16305 O 03/16!99 2-718" 4 16440 - 16665 O 03/16,99 2-718" 4 16830 - 16965 O 03/16(99 2-718" 4 17100 - 17280 O 03/16199 2-718" 4 17475 - 17550 O 03r'16i99 2-718" 4 17770 - 17885 O 03!16199 FISH: HES FASDRILL ft91LLED~-17892' CTM & PUSHED TO BTM {04103/08} PBTD 17913' 5" X 7" BKR HMC LNR HANGER & ZXP PKR 4-1l2" LNR, 12.6#, 13-CR-80:.0152 bpf; ID = 3.958" (-{ 18000' DATE REV BY COMMENTS DATE REV BY COMMENTS 1988 ORIGINAL COMPLETION 03!11108 D14 O 03!20199 RIG. SIDETRACK 03/16/08 ITLH CORRECTIONS 02106/02 RN1TP CORRECTIONS 03!29!08 KDClSV GLV C!O {03121107} 10!17/02 JRCIKK WANER SAFEfI' NOTE 04118/08 RKITLH FASDRILL MILLER {04/03/08} 9124/05 EZLITLH WANER SFTY NOTE DELETED 05/30!06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNIT WELL: 09-23A PERMCf No: 1980440 API No: 50-029-21066-01 SEG 1, T10N, R15E, 1443.76 FEL & 2874.49 FNL BP Exploration (Alaska) ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3613 3117 51 MMG DOME RK 16 03/21!08 5 6714 5007 52 MMG DMY RK 0 03108/O8 4 8761 6154 57 KBG2 DOME BK 16 03/21/08 3 10571 6999 69 KBG2 DOME BK 16 03!21108 2 12830 7750 70 KBG2 DOME BK 16 03!21108 1 14927 8507 69 KBG2 SO BK 24 03/21/08 9-5i8" WINDOW 9600' - 9650' 15871' 4-112" HES X NIP, iD = 3.813" 15892' 4-112" x 7" BAKER S-3 PKR iD 3.875" 15953' 4-1?2" NES X NIP, ID = 3.813" 15972' 4-112" x 7" UNEOUEMAGHINEOVEf2SHOT _.,,,,__ 16009' 7" BAKERSB-3 PKR 16043' 4-1l2" HES X NIP, ID = 3.813" 16063' 4-112" WLEG ELMD TT NOT LOGGED OPERABLE - 09-23A {#1980440) OA pressure manageable by bleeds Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWe111ntegrityEngineer@BP.comj 2 s1~1~ Sent:. Thursday, May 15, 2008 11:28 PM ~~ To: Regg, James B (DOA); Maunder, Thomas, E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/21COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2. DS Ops Lead;: NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Reem, David G Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Phillips, Patti J Subject: OPERABLE - 09-23A (#1980440) OA pressure manageable by bleeds ~dx.~-~ -lost-~ AEI, As a follow-up to the note below an well 09-23A (PTD #1980440}, the OA pressure was allowed to build until 05/r 10108 when the wellhead pressures were tubing/lA/ OA equal to 320/1700 7 00 An open bleed was conducted far two days beginning 05/12 and then the well was monitored orT- another #hree days to evaluate the build up rate. On 05/15108, the wellhead pressures were 230/16401660 with. a build up rate of -40 psi/day. The weN has been reclassified as Operable. It is permissible to maintain the 0A pressure under MAASP with occasional bleeding. Please notify the Well In#egrity Engineer if the OA pressure exceeds MAASP ar becomes unmanageable by bleeds: (~ Please let me know if you have any questions. Thank you, Anna ~Du6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: {S07} 659-5102 Pager. {907} 659-5100 x1154 SCANNED MAY 2 1 2008 ~/~- = t-7oo~s; 31 bra From: NSU, ADW Well Integrity Engineer Sent: Saturday, April 26, 2008 9:07 AM To: 'Regg, James B (DOA);'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engef, Harry R; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, FS2 DS Ops Lead; NSU, ADW Wel(Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot a Subject: 09-23 Planned Action -Under Evaluation with Sustained Casing Pressure on the OA J'rm and TOm, Well 09-23 (PTD #1980440) has been found with sustained casing pressure on the OA. The TIOs on 04!22107 were 36011720/1050 psi. As seen in the email below, our plan is to evaluate the source of OA repressurizatian by first allowing the pressure to stabilize, and then by maintaining an open bleed for several days. At #hat paint, it will be determined if an in#ernal dispensation will be needed for continued operation with an OA pressure greater than 1,000 psi. The OA of 09-23 was cemented to surface on 03/11/08 during a rig workaver. The surface casing is 13-3/8", 72#, L-80 with a burst value of 5,380 psi. The OA pressure will riot be allowed to build aver 45% of burst.\ A TIO plat and wellbare schematic have been included for reference. ~24z1 ~1 5/20/2008 OPERABLE - 09-23A (#1980440) OA pressure manageable by bleeds Page 2 of 2 • • Please call with any questions or concerns. Thanlr you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Wednesday, Aprit 23, 2008 12:53 PM To: GPB, Area Mgr East (FSS/2/COTU/Seawater); GPB, F52/COTU OTL; GPB, FS2 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW We110perations Supervisor; Phillips, Patti ) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject; 09-23 Planned Action -Under Evaluation All, Well 09-23 is currently classified as Under Evaluation to evaluate the source of the OA pressure. The plan forward for the well is as follows: 1. WIE: Monitor OAP until stabile with well online (this is likely a pressure above MAASP. Please DO NOT bleed the OAP). 2. DHD: Once the maximum obtainable pressure has been established, maintain an open bleed on the OA in an attempt to deplete the gas source. 3. WIC: Eval far dispensation for continued operation with OAP above currently set MAASP. Operations: Please do not bleed the OA pressure until all of the diagnostics are complete. I wiU fallow up with an additional email once this is the case. Please do not hesitate to call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 5/20/2008 ~( ~t- c~1 ~ N ~ ~ ~ ~~ . o~° • a~ d 0 co v a 0 u~ S4 ~~ a G tD ~'V r F~- O f~ t7 r I'*- C3 O OC1 ~~ d 4 ~C O ~ O O ~ a ~ o °o o c~ o 0 Ir- O a C ~~ C~ ~• .TREE = 4 1 J8" 5M WELLHEAD = FMC ACTUAT(7R = BAKER G ~ ~(~ F"'~" ~ ~ ~ ~~ KB. ELEV = 49' ~ BF. ELEV = KOP = 1094' Max Angle = 94 @ 17379' Datum MD = 15853' Datum TV D = 8800' SS 9-518" CSG, 40#. L-80. ID = 8:835" 894' 13-3t8" CSG, 72#, L-80, ~ = 12.347" --~ 2700' Minimum ID = 3.$13" @ 2302' 4-112" HES X NIPPLE TOP OF 7" LNR '-~ 9465' ~ 9-518" CSG, 47#, L-80, ~ = 8.681" ~ 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, tD = 3.958" (-{ 15964' s-518" Ezsv ~-~ 9900' TOP OF 4-112" LNR] 1604$' 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 18083' 7" LNR, 26#, 1-80, .0383bpf, Fd = 6.276" 16233' PERFORATION SUMMARY REF LOG: SWS LWDIGR ON 03!17/99 A NGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 4 16265 - 16305 O 03116199 2-718" 4 16440 - 16665 O 0311.6/99 2-7/8" 4 16830 - 16965 O 03!16/99 2-7t8" 4 17100 - 17280 O 03116!99 2-718" 4 17475 - 17550 O 03116199 2-718" 4 17770 - 17885 O 03116(99 FISH: HES FASDR~L M~LED - j 17892• & PUSHED TO BTM (04143/0$} PBT€? 179' 5" X 7" BKR HMC LNR HANGER & ZXP PKR 4-112" LNR, 12.6#, 13-CR-80, .0152 bpf, ~ = 3.958" ~--{ 18000' DATE REV BY COMMENTS DATE REV BY COMMENTS 1988 ORIGINAL COMPLETION 03111f08 D14 RWO 03!20199 RIG. SIDETRACK 03/16/08 ITCH CORRECTIONS 02/06!02 RNlTP GORRECTIONS 03129/08 KDC/5V GLV CIO (03121107) 10/17/02 JRCIKK WANER SAFETY NOTE 04118108 RKITLH FASDRILL MILLED (04103t08} 9/24!05 I~LITLH WANER SFTY NOTE DELETED 05/30106 DTM WELLHEAD CORRECTION PRUDHOE BAY UNCt' WELL: 09-23A PERMff No: 1980440 APl No: 50-029-21066-01 SEC 1, T10N, R15E; 1443.76 FEL 8~ 2874.49 FNL BP Exploration (Alaska} S Y NOTES: EXTENt)ED RE4CH PERIPHERAL SCK 70° @.10101` & 90° @ 1:6386'. ***4- 12" CHROM E TBG & tNR*** 2428' 4-1i2" HES X Nom, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3613 3117 51 MMG DOME RK 16 03/21!08 5 6714 5007 52 MMG DMY RK 0 03108!08 4 8764 6154 57 KBG2 DOME BK 16 03121!48 3 10571 6999 69 KBG2 DOME BK 16 43!21/08 2 12$30 7750 70 KBG2 DOME BK 16 03/21/08 1 14927 8507 69 KBG2 SO BK 24 43121108 9-518" WINDOW 9600' -9650' 15871' 4-112" HF~ X NfP, tD = 3:813" 15892' 4-1?2" x 7" BAKER S-3 taICR tD 3.875" 15953' 4-1 t2°° HES X NIP; ID = 3.813" 15972' 4-1i2" x 7" UNIQUEMACH~tEOVERSHOT 16009' 7" BAKER SB-3 PKR 16043' 4-112" HES X NIP: ID =.3.813" ...._.16063' 4-1/2_WLEG 1 ~-{ELMD TT NOT LOGGED. Page 1 ofd' • Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, May 13, 2008 1:39 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 09-23A (198-044) Attachments: 09-23A Post Summary.pdf Here you go... • ~~~R MAY 2 3 2008 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, May 12, 2008 3:16 PM To: Hubble, Terrie L Subject: RE: DS 09-23A (198-044) Terrie, Sorry I haven't gotten back to you sooner. If you would, could you provide the post-rig details. Email is fine. Thanks. Tom From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, May 07, 2008 1:28 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 09-23A (198-044) Hi Tom, Basically I started the report where I thought the data was pertinent. Yes they did start the previous day, but all that was on that report was that they moved in and rigged up. There had been a number of days prior to the 02/'10/08 operation where they were attempting to pull the WRP, but I started it where they actually did pull the WRP. As for the post-rig work, I don't usually include any of that work unless it seems pertinent (a listed task) to the approved 10-403. In this case the post-rig work involved setting up the GLV's, drilling up the FASdrill plug and testing the well. Do you want me to print all of these out for you? April 7th was the 30th day after the rig released... always aiming to get these in under the wire. :-) Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska,gov] Sent: Sunday, May 04, 2008 3:49 PM 5/13/2008 Page 1 of Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 05, 2008 4:27 PM To: 'Reem, David C' Subject: RE: DS 09-23A (198-044) Dave, Thanks much. My questions are answered. Thanks for your time. Tom From: Reem, David C [mailto:ReemDC@BP.com] Sent: Monday, May 05, 2008 4:25 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 09-23A (198-044) Tom, I'll try to address all three of your concerns/questions in order 1. NORM = "hot". Not a big surprise as this well has a history of scale build-up {scale appears "hot" on gamma- ray logs}. 2. See what happens when you're in San Diego on vacation?? I have no explanation for the over-abundance of RBPs on this well. I do not know what prompted the RBP set at 2734'md. 3. We fear getting too close on our test pressure to the ES-cementer opening pressure...shearplns might not be all they are rated for. The 2000 psi test gives us confidence that the "connection" between the old casing and the new is competent to hold a full column of cement on the backside of the new pipe. And 2000 psi is far enough away to avoid shearing open the ES cementer... Hope this helps somewhat... DCR From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, May 04, 2008 3:53 PM To: Roach, Frank Cc: Reem, David C Subject: DS 09-23A (198-044) Frank and Dave, I am reviewing the 404 submitted for the recent work on this well. 1. When the tubing was pulled, it is noted "NORM" = HOT on 3/1/08. Could you provide some further information on this? I have not seen HOT on many workover reports. 2. Interesting 2 9-5/8" RBPs and a fasdril? 3. When the 2"d casing patch was run, the casing was sequentially tested to 2000 psi. Then the casing was pressure tested to 2800 psi to shear the ES. It seems the test pressure might have been closer to the shear pressure, say 2500 psi. I do know you want to get a test prior to shearing out the ES. Thanks, I look forward to your reply. Tom Maunder, PE AOGCC 5/5/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Sunday, May 04, 2008 3:49 PM To: 'Hubble, Terrie L' Subject: DS 09-23A (198-044) Terrie, I am reviewing the 404 for the well. In the pre-rig report, it appears that work might have started prior to 2/10/08. Also, there is no post rig work summary. Thahks, Tom Maunder, PE AOGCC 5/4/2008 STATE OF ALASKA ~ %~~ A~ OIL AND GAS CONSERVATION COMIC}lSSION 1. Operations Performed: nChOfag@ ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 198-044 " 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21066-01-00 " 7. KB Elevation (ft): 49 42' 9. Well Name and Number: PBU 09-23A 8. Property Designation: 10. Field /Pool(s): ADL 028345 ' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 18000' feet true vertical 9043 ~ feet Plugs (measured) None Effective depth: measured 17913 feet Junk (measured) None true vertical 9041 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1490 470 Surface 2700' 13-3/8" 2700' 2523' 4930 2670 Intermediate 9600' 9-5/8" 9600' 6622' 6870 4760 Production Liner 6769' 7" 9466' - 16235' 6545' - 8983' 7240 5410 Liner 1951' 4-1/2" 16049' - 18000' 8919' - 9043' 8430 7500 Perforation Depth MD (ft): 16265' - 17885' Perforation Depth TVD (ft): 8992' - 9041' 4-1/2", 12.6# 13Cr80 16065' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer; 15892'; 7" x 4- 1/2" Baker'SB-3' packer 16009' 12. Stimulation or cement squeeze summary: ,. ~ ~ • ~ _- ~ ~~ ~~~~ Intervals treated (measured): ~g ~~g~,+ ~~~ ~~) ~ ~ 1~0~ Treatment description including volumes used and final p ressure: Set FasDrill Plug at 16028'. Cut and pull tubing from -15971'. Cut and pull 9-5/8" casing from 691'. Run 9-5/8" Tieback (47#, L-80) 694' and cement w/ 71 Bbls Class 'G', w/ GasBlok 399 cu ft / 341 sx . Run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 307-021 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number ~~ Signature Phone 564-4628 Date ~(~ Terrie Hubble, 564-4628 RECEIVIE REPORT OF SUNDRY WELL OPERATIONS~~ APR 0 4 2008 asks 01t & Gas Cons. Form 10-404 Revised 04/2006 ~ ~ ~ ~ ~ ~ ` ~ ` ~~~ I~ Submit Original Only j(\'~!{ It_. ~~ ~ x(.3`3 Digital Well File ~ ~ Page 1 of 1 Well: 09-23 Well History Well Date Summary 09-23A 2/10/2008 ***CONTINUED FROM 02-09-08*** (pre rwo) P L D " W ELEMENTS FROM 16 020' SLM DRIFTED W/ 3.79" WEATHERFORD WRP DUMMY DRI TOAL=45" TO 16,100' SLM ******(DRIFT SET DOWN IN SEVERAL SPOTS FROM 14,765' - 15,287' BUT ABLE TO WORK THRU & CLEAR UP -SEE LOG)******* **** WELL LEFT SHUT IN /DSO NOTIFIED **** 09-23A 2/13/2008 *** WELL SHUT-IN UPON ARRIVAL**** RIG PREP - FASDRILL /JET CUT. RIH W/HEAD, SWIVEL, ERS SUB, 1.69" WEIGHT, E-LINE JARS, 1.69" WEIGHT, CCL, OWEN 2.5" SHORTY SETTING TOOL, HALLIBURTON 3.66 FAS-DRILL PLUG, MAX OD = 3.66", LENGTH = 31'. CONTINUED ON 14 FEB 08 AWGRS ***JOB INCOMPLETE**** 09-23A 2/13/2008 T/I/0=1900/1840/240 Assist E-Line (RWO Prep) Pumped 107 bbls of crude down Tbg to assist E-line in setting plug. (continued on 2/14/08) 09-23A 2/14/2008 **** WELL SHUT-IN UPON ARRIVAL*** ~4FT FASf)RII I PI I1(, AT ~Rn~R' HAD PROBLEMS TO GET DOWN HOLE DUE TO DEVIATION AND 2000 PSI OF TUBING PRESSURE. LRS PUMPED DOWN CRUDE WITH 1 BBU MIN TO HELP TOOL GET DOWN HOLE. CONTINUED ON 15-FEB-2008 WITH POWER CUTTER REPORT. ***JOB INCOMPLETE*** 09-23A 2/14/2008 **Continued from 02/13/08 WSR** Assist E-line, Load, OMIT Tx IA PASSED to 3500 osi (RWO Prep) Pumped down Tbg with 570 bbls crude while E-line RIH with composite plug. Post composite plug set. Pumped 21 bbls crude to reach test pressure. T/IA lost 20/20 psi in 1st 15 mins, T/IA lost 0/0 psi in 2nd 15 mins for a total loss of 20/20 psi in 30 mins. Standby for E-line to run cutter..(Continued on 02/15/08 WSR) ---Job in progress--- 09-23A 2/15/2008 CONTINUED FROM 14-FEB-2008, INITIAL WHP: T/I/O = 150/100/260, RIH WITH 3.65" POWER CUTTER, CUT 4.5" TUBING AT 15970' IN FIRST FULL JOINT ABOVE THE PACKER. LEFT 30' STUB ABOVE PA L. FINA WHP: T I = 100/100/260. ***JOB COMPLETE*** 09-23A 2/15/2008 T/I/0=150/100/260 Assist E-line, Freeze Protect Flowline. Pumped 112 bbls of crude and 7 bbls meth down flowline for freeze protect. Annulus casing valves tagged and left open on departure. FWHP= 150/300/260 09-23A 2/15/2008 T/IA/OA= 100/300/300 temp=cold PPPOT-T (PASS) PPPOT-IC (seal-tite) Gauge in void reads 300 psi (Pre RIG) PPPOT-T RU 2 HP bleed tool onto THA void 1700 psi to 0 psi. Flushed void until clean returns achieved, pressured void to 5000 psi for 30 minute test, 5000/15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment and cycle all LDS "Standard" all moved with no problems. PPPOT-IC Pack off has been treated with Tru-Flo from Seal-Tite LDS on IC were cycled no problems all moved free. 09-23A 2/15/2008 ***WELL SHUT IN ON ARRIVAL*** (pre rwo) SET 4-1/2" SS C-SUB ~ 8,525' SLM. RUNNING IN HOLE TO PULL STA# 2 IN PROGRESS. ***CONTINUE JOB ON 2/16/08 WSR*** 09-23A 2/16/2008 ***CONTINUE JOB FROM 2/15/08 WSR*** (pre-rig) :PULLED FLOW SLEEVE FROM STA# 2 ~ 8083' SLM. SET DGLV IN STA# 2 C~ 8083' SLM. PULLED EMPTY SLIP STOP C-SUB ~ 8525' SLM. ***WELL LEFT S/I DSO NOTIFIED*** 09-23A 2/16/2008 T/I/0= 200/275/260 Temp= S/I Circ Out, CMIT TxIA PASSED to 3500 psi (PRE RWO) Pumped 5 bbls neat, 1340 bbls 1 % KCI and 150 bbls diesel down Tbg up the IA through a jumper line taking returns down the flowline. Allow 1 hr. to U-tube. OMIT TxIA PASSED to 3500 psi. Tbg and IA pressured up with 12.3 bbls diesel, T/IA lost 50/20 psi. in 1st 15 min and 0/0 psi in 2nd 15 min. for a total loss of 50/20 psi. Freeze Protect Flowline with 10 bbls meth followed by 90 bbls crude and capped with 20 bbls diesel, Bled WHP's, ***WSR Continued to 02-17-08*** 09-23A 2/17/2008 ***WSR Continued from 02-16-08*** Continue bleeding WHP's (Post Circ-Out), RDMO Final WHP's 0/0/0 "Annulus casing valves tagged & left open" 09-23A 2/18/2008 Set 4" ISA BPV for pre-rig.Tagged C~ 102",well was on a vac.....no problems. Print Date: 4/4/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 4/4/2008 • • $P"EXPLORATION Page 1 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: ~ Phase. ' .Description of Operations Date From - To Hours Task Code NPT 2/27/2008 11:00 - 12:00 1.00 MOB P PRE Rig released from END4-14A. Rig down. 12:00 - 00:00 12.00 MOB P PRE Move Rig from Endicott to DS #9 well 23A. 2/28/2008 00:00 - 01:00 1.00 MOB P PRE Continue move to DS #9 well 23A. 01:00 - 03:30 2.50 RIGU P PRE Arrive on location ~ 01:00 hrs. -Position Rig & move over well. -Begin rigging up. 03:30 - 04:30 1.00 RIGU P PRE Skid Rig floor into position. 04:30 - 06:00 1.50 RIGU P PRE Spot & berm Rock washer. -Install auger in Rock washer. -R/U service lines to floor. -Acce t Ri ~ 06:00 hrs on 02/28/2008 06:00 - 07:00 1.00 WHSUR P DECOMP Install 1502 flange on Tree valve. -Install double valve on IA. -Test Gas alarms. 07:00 - 08:30 1.50 WHSUR P DECOMP R/U DSM Lubricator & test to 500 psi - OK. -Pull BPV. R/D Lubricator. 08:30 - 10:00 1.50 WHSUR P DECOMP C/O Top Drive Saver Sub, Grabbers & Bell guide. -Take on Seawater. 10:00 - 12:00 2.00 WHSUR P DECOMP Hard Line crew spot & berm Bleed off tank. -Spot Choke skid & run Hard Line to Rig. -Steam Hard Line. -Test Hard line with air. Look for leaks. 12:00 - 13:00 1.00 WHSUR P DECOMP Continue to rig up on Tree. -Test lines from Tree to slop tank. -Test C~? 3,500 psi - OK. 13:00 - 16:00 3.00 KILL P DECOMP Cirulate out Freeze protect diesel w/ 8.5 ppg Seawater. -Pump: -40 bbls down annulus up Tbg ~ 340 gpm / 2,700 psi. -170 bbls down Tbg up annulus ~ 340 gpm / 3,100 psi. -Wait 30 minutes for diesel to migrate. -Pump an additional 30 bbls ~ 340 bpm / 3,100 psi. -Blow down lines to slop tank. 16:00 - 18:00 2.00 BOPSU P DECOMP Install BPV & test from bottom to 1,500 si / 30 minutes - OK. 18:00 - 19:00 1.00 BOPSU P DECOMP N/D Tree & Adaptor flange. -Inspect hanger threads -Install blanking plug per FMC rep 19:00 - 21:30 2.50 BOPSU P DECOMP N/U Stack & install extension on Choke line. 21:30 - 22:30 1.00 BOPSU P DECOMP R/U to test BOPs. 22:30 - 00:00 1.50 BOPSU P DECOMP Test BOPs Choke manifold & related valves. -Test pressures ~ 250 psi low & 3,500 psi high. -Test for 5 minutes each. -Tested upper and lower rams with 4", 4 1/2", and 5" test joints -Tested both 4" and 5" dart and full open safety valves -Witnessed by TP & WSL. -Witness of test waived by Lou Grimaldi, AOGCC. 2/29/2008 00:00 - 04:30 4.50 BOPSU P DECOMP Continue testing BOPs & related equipment. 04:30 - 05:00 0.50 BOPSU P DECOMP R/D test equipment. -Back out & pull blanking plug. 05:00 - 05:30 0.50 BOPSU DECOMP Install Lubricator extension. -R/U & test DSM Lubricator to 500 psi. 05:30 - 07:00 1.50 BOPSU N WAIT DECOMP Wait on DSM to get extensions and correct pulling tool. Printed: 3/27/2008 1:53:02 PM • • BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date I From - To Hours Task Code NPT Phase Description ofi Operations 2/29/2008 07:00 - 08:00 1.00 BOPSU P DECOMP P/U & R/U extesions to correct depth. -Pull BPV. R/D DSM. 08:00 - 09:00 1.00 PULL P DECOMP P/U & M/U Spear, XO, & 1 jt of D.P. -Engage Hanger. -Pull Hanger to floor. PUW= 185K. 09:00 - 11:30 2.50 PULL P DECOMP Pump: -40 bbl Safe Kleen pill. -50 bbl Safe Scav pill. -Circulate pills S/S ~ 378 gpm / 2,330 psi. 11:30 - 12:00 0.50 PULL P DECOMP Disengage & UD Spear, XO & 1 jt of D.P. -UD Hanger. 12:00 - 00:00 12.00 PULL P DECOMP Pull & UD 4.5", 12.6#, 13Cr-80 New Vam Tbg. 3/1/2008 100:00 - 03:00 3.001 PULL P 03:00 - 03:30 0.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 05:00 0.50 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 12:30 6.50 CLEAN P 12:30 - 22:00 9.501 CLEAN P 22:00 - 23:30 I 1.501 CLEAN I P 23:30 - 00:00 I 0.501 CLEAN I P 3/2/2008 100:00 - 01:00 I 1.00 I CLEAN I P 01:00 - 04:00 I 3.001 CLEAN I P 04:00 - 05:30 I 1.501 CLEAN I P 05:30 - 06:30 I 1.001 CLEAN I P 06:30 - 12:00 5.50 CLEAN P 12:00 - 13:00 1.00 CLEAN P -Pups= 3.80', 5.85', 7.81', 9.75', 9.80' DECOMP Complete UD 4 1/2" Tbg. -Total recovered: -374 jts of 4 1/2", 12.6#, 13Cr-80 New Vam Tbg. -6 GLMs & 5 pup jts. -Cut jt= 19.24 ft. -No apparent damage to Tbg detected. - Tb "NORM" =HOT. DECOMP Clean Rig Floor DECOMP Clear Rig floor of Tbg handling tools. DECOMP Install Wear ring. DECOMP Mob Dress off BHA to Rig floor. DECOMP M/U Dress off BHA. DECOMP RIH w! Dress off Assy. -Single in hole w/ 4" D.P. to 6,588' md. DECOMP Continue to RIH w/ Dress off Assy. -Single in hole w/ 5" D.P. f/ 6,588' to 15,946' md. DECOMP P/U & M/U 2 jts of 5" D. P. in mouse hole. -M/U Top Drive & establish circulation. -Obtain circulation ~ 126 gpm / 250 psi. -Obtain SPRs. PUW= 253K, SOW= 185K. -ROT wt= 215K, Tq= 10K. -Wash down over slum to 15 970' md. -RPM= 40, Tq increased to 12K. Pump psi= 710. -Polished 4 1/2" Tbg stump to 15,971' md. DECOMP Circulate Hi Vis Sweep Surface /Surface. -420 gpm / 2,400 psi, RPM= 30. DECOMP Continue circulating HV Sweep. -420 gpm / 2,550 psi. DECOMP R/U & reverse circulate HV Sweep S/S. -336 gpm / 1,770 psi. -Stand 1 stand back. DECOMP Cut drilling line. -Service Top Drive. DECOMP Pumpdryjob. POH. -Stand back 30 stds of 5" D.P. in Derrick. DECOMP UD 5" D.P. to 6,850' md. DECOMP Change dies in Iron Roughneck. -C/O elevators. Printed: 3/27/2008 1:53:02 PM • • BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ~~ Hours Task Code NPT 3/2/2008 12:00 - 13:00 1.00 CLEAN P 13:00 - 17:30 I 4.50 I CLEAN I P 17:30 - 19:00 1.50 CLEAN P 19:00 - 20:00 1.00 CLEAN P 20:00 - 00:00 4.00 DHB P 3/3/2008 00:00 - 01:30 1.50 DHB P 01:30 - 02:00 0.50 DHB P 02:00 - 03:00 I 1.001 DHB I P 03:00 - 03:30 0.50 DHB P 03:30 - 05:00 1.50 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 07:00 1.00 CASE P 07:00 - 08:00 1.00 CASE P 08:00 - 08:30 0.50 CASE P 08:30 - 09:30 1.00 CASE P 09:30 - 10:00 0.50 CASE P 10:00 - 10:30 0.50 CASE P 10:30 - 11:00 0.50 CASE P 11:00 - 11:30 0.50 CASE P 11:30 - 12:00 0.50 CASE P 12:00 - 13:00 1.00 CASE P Spud Date: 3/16/1984 Start: 2/27/2008 End: Rig Release: 3/11/2008 Rig Number: Phase Description of Operations DECOMP -Clear Floor of Baker tools & 5" pin protectors. -Bring 4" pin protectors to Floor. DECOMP PJSM: UD 4" D.P. & BHA. -UD 4" D.P. DECOMP UD BHA. DECOMP Clear Rig floor of unnecessary tools & equipment. DECOMP PJSM: E-line R/U & P/U USIT tools & sheaves. -R/U E-line. -RIH to 3,050' md. -Log up for USIT log. DECOMP Perform USIT log from 3,050' and to surface. DECOMP PJSM: R/D E-line. -R/D E-line. DECOMP R/U & test 9 5/8" Csg to 3,500 psi / 30 minutes -Pass., -Clean Rig. -R/D Csg test equipment. DECOMP Service Rig. DECOMP M/U HES RBP on running tool. -RIH ~ controlled rate to 2,734' md. DECOMP Set RBP. Set down 25K to confirm set ~ 2,734' md. DECOMP R/U & test RBP to 500 psi / 15 minutes - OK. DECOMP Displace to 9.8 ppg NaCI ~ 336 gpm / 320 psi. DECOMP POH. P/U RBP # 2. DECOMP RIH with RBP # 2 to 837' md. DECOMP Attempt to set RBP 3 2. Did not set. DECOMP POH with RBP # 2. DECOMP UD RBP. -M/U loose connection on running tool. -P/U RBP # 2. DECOMP RIH with RBP # 2 to 815' md. DECOMP Set RBP # 2 ~ 815' md. DECOMP POH with running tool. UD same. DECOMP Test RBP # 2 to 2,200 psi f/ 30 minutes - OK. 13:00 - 13:30 0.50 CASE P 13:30 - 15:30 2.00 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 17:30 1.00 CASE P 17:30 - 18:00 0.50 CASE P 18:00 - 18:30 0.50 CASE P 18:30 - 19:30 ~ 1.00 CASE P DECOMP RIH to 662' and w/ 5" D.P. open ended. DECOMP Dump 2,200 Ibs of 20/40 sand down drill string -Settling rate ~ +/- 12.6 ft/min. DECOMP POH w/ 5" D. P. DECOMP Test OA to 1,000 psi / 30 minutes - OK. , DECOMP M/U BHA Multi-String cutter, Rot sub & XO. -M/U (9)- 6 1/4" D.C's. & XO. DECOMP RIH w/ BHA on 5" D. P. f/ 285' to 769' and (tagged sand). -Pull up to 691' and to cut 9 5/8" Csg. DECOMP Cut 9 5/8" 47# Csg ~ 691' md. -Pump rate= 269 gpm / 650 psi. -RPM= 80, Tq= 2-4K. DECOMP Close top rams. Line up to outside Tiger Tank. -Circulate: -45 bbls Safe Kleen / 9.8 ppg NaCI. -45 bbls 9.8 ppg NaCI. -45 bbls Safe Kleen / 9.8 ppg NaCI. -45 bbls 9.8 ppg NaCI. -294 gpm / 150 psi. Printed: 3/27/2008 1:53:02 PM • • BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: ~ Date From - To Hours Task Code NPT Phase Description of Operations 3/3/2008 18:30 - 19:30 1.00 CASE P DECOMP -P/U BHA & equipment to Rig floor. 19:30 - 20:00 0.50 CASE P DECOMP Blow down OA line, blow down Top Drive. 20:00 - 20:30 0.50 CASE P DECOMP POH f/ 691 to 285' and w/ 5" D.P. 20:30 - 21:30 1.00 CASE P DECOMP Rack back D.C's. Service break & UD Baker tools. 21:30 - 22:00 0.50 CASE P DECOMP Clear Floor of tools. Pull Wear ring. 22:00 - 22:30 0.50 CASE P DECOMP P/U 1 std of 5" D. P.. UD 1 single. -M/U Spear Assy. 22:30 - 23:00 0.50 CASE P DECOMP Spear into 9 5/8" csg. -Pulled 105K to break over. -Final PUW= 75K. -Pull Packoff to Floor level. 23:00 - 00:00 1.00 CASE P DECOMP Circulate Safe Kleen sweep surface to surface. -294 gpm / 60 psi. -R/U to UD Csg. 3/4/2008 00:00 - 00:30 0.50 CASE P DECOMP UD Spear. 00:30 - 01:00 0.50 CASE P DECOMP Stand back 1 std. Blow down Top Drive. -C/O Elevators. 01:00 - 04:00 3.00 CASE P DECOMP UD 9 5/8" L-80 47# Cs . -Total recovered: - 15 jts, 1 cut jt C~ 19.70' (clean cut). - pup 2 .24'. -(4) -Centralizers. 04:00 - 04:30 0.50 CASE P DECOMP Clean & clear Rig floor. UD Csg tools. 04:30 - 05:30 1.00 CLEAN P DECOMP Mob Dress Off tools to floor. -P/U Spear, make service breaks, UD Spear. 05:30 - 07:00 1.50 CLEAN P DECOMP M/U Dress Off BHA. 07:00 - 08:00 1.00 CLEAN P DECOMP RIH w/ Dress Off BHA, tag stump ~ 691' md. 08:00 - 09:00 1.00 CLEAN P DECOMP Dress Off 9 5/8" Cs stum 6"). -PUW= 78K, SOW= 82K, ROT wt= 82K. -RPM= 100, W06= 10K, Tq= 1K. -210 gpm / 120 psi. 09:00 - 09:30 0.50 CLEAN P DECOMP Pump Hi Vis Sweep surface to surface. -210 gpm / 80 psi. 09:30 - 10:00 0.50 CLEAN P DECOMP POH w/ Dress Off BHA. 10:00 - 11:00 1.00 CLEAN P DECOMP Make service breaks. Empty Junk basket (+/-15 Ibs). -UD BHA. 11:00 - 11:30 0.50 CLEAN P DECOMP UD vendor tools. 11:30 - 13:00 1.50 CASE P DECOMP R/U to run 9 5/8" Csg w/ Torque Turn. -Swap out two jts of Csg in pipe shed. 13:00 - 16:30 3.50 CASE P DECOMP PJSM: Run 9 5/8". -P/U Baker Csg Patch / ES-Cementer Assy. -All connections below the ES-Cementer are Bakerloked. -Run 9 5/8" L-80, 47#, Condition "B" Csg. -Utilize "Jet Lube Seal Guard" on Hydril 563 connections. -Target torque is ""15,200 fUlbs.""' 16:30 - 17:00 0.50 CASE P DECOMP P/U XOs, M/U Top Drive. Obtain parameters. -PUW= 77K, SOW= 81 K, Csg depth 691' md. -En a e Stum .Set down 40K. -P/U100K to confirm 17:00 - 23:30 6.50 CASE P DECOMP C/O Bails to long Bails. -R/D & UD Csg Tongs. -R/U XO, Cmt head, Valves, "T" & Cmt hose. -P/U 250K /Slack off and hold 125K. Printed: 3/27/2008 1:53:02 PM • • BP EXPLORATION Page 5 of 13 Operations Summary Report iLegal Well Name: 09-23A ~~Common Well Name: 09-23A Spud Date: 3/16/1984 !Event Name: WORKOVER Start: 2/27/2008 End: ',Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date From - To !Hours Task Code NPT 'Phase Description of Operations-_ 3/4/2008 17:00 - 23:30 6.50 CASE P DECOMP -Attempt to test Csq to 1,000 psi - OK. ; -Attem t to test Cs to 2,000 psi - no success. -Blow down Cmt line, R/D Valves, "T" & Cmt hose. -Slack off all wt. Csg moved down 2-3". -R/U & test Csa to 1.000 psi - no success. -Screw in Top Drive. -Turn to right to release Grapple. 23:30 - 00:00 0.50 CASE N DFAL DECOMP R/U Csg Tongs. 3/5/2008 00:00 - 01:30 1.50 CASE N DFAL TIEB1 UD 9 5/8" Csq and Csg Patch Assy f/ 691' md. -Packoff rubber in Csg patch had two large holes. -Hole sizes 5" X 2" & 2" X 1 1/2". -Possible cause: -Cracking from freezing embrittlement (-40F). -Movement on truck & forklift while frozen. 01:30 - 02:00 0.50 CASE N DFAL TIE61 R/D Tongs. -P/U 8 1/2" Dress Off BHA. -Dress off 9 5/8" Csg stump. 02:00 - 03:00 1.00 CASE N DFAL TIEB1 M/U Dress Off BHA. 03:00 - 03:30 0.50 CASE N DFAL TIEB1 RIH w/ Dress Off BHA. -Tag up C«~ 691' md. 03:30 - 04:00 0.50 CASE N DFAL TIEB1 Dress Off Cs stum 3" . -PUW= 78K, SOW= 82K, ROT wt= 82K. -RPM= 40, Tq= 1 K. -210 gpm / 120 psi. 04:00 - 04:30 0.50 CASE N DFAL TIEB1 Circulate Hi Vis Sweep surface to surface. - (3 #/bbl Duo-vis in 40 bbls of Seawater). -Sand & metal shavings in returns. -210 gpm / 90 psi. 04:30 - 05:00 0.50 CASE N DFAL TIE61 POH w/ Dress Off BHA. 05:00 - 06:00 1.00 CASE N DFAL TIEB1 UD Dress Off Assy. -Make service breaks on tools. -Empty junk baskets (Trace of metal shavings). 06:00 - 06:30 0.50 CASE N DFAL TIE61 Clear Rig floor of Vendor tools. 06:30 - 07:30 1.00 CASE N TIEB1 R/U to run 9 5/8" Csg w/ Torque Turn 07:30 - 09:30 2.00 CASE N DFAL TIEB1 PJSM: Run 9 5/8". ~-P/U Baker Csg Patch / ES-Cementer Assy. connections below the ES-Cementer are Bakerloked. -Run 9 5/8" L-80, 47#, Condition "B" Csg to 691 " md. -Utilize "Jet Lube Seal Guard" on Hydril 563 connections. -Target torque is ""15,200 fUlbs.""' -1 centralizer per jt. Total Cents= 16 -Stab onto stump C~ 691' md. 09:30 - 11:00 1.50 CASE N DFAL TIEB1 Set down on Stump 25K -P/U to 100K. -Set back down on stump 27K. -Test Csg patch seal to 1,000 psi / 10 minutes - OK. -Test Csg patch seal to 1,500 spi / 5 minutes - OK. -Test Csg patch seal to 2,000 si / 30 minutes -Pass. 11:00 - 11:30 0.50 CASE P TIE61 C/O Bails, UD XO. -R/U cement head & lines. 11:30 - 12:00 0.50 CASE P TIEB1 P/U 100K. P/U 250K. Slack off to 125K. -Shear ES-Cementer C~3 2,800 psi. Printed: 3/27/2008 1:53:02 PM C7 • BP EXPLORATION Page 6 of 13 .Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code ~~ NPT Phase Description of Operations 3/5/2008 11:30 - 12:00 0.50 CASE P TIE61 -Establish circulation: -Pump 9.8 ppg NaCI ~ 110 F. -126 gpm / 50 psi, 168 gpm / 70 psi, 210 gpm / 100 psi. 12:00 - 13:30 1.50 CASE P TIEB1 Circulate 9.8 ppg NaCI until returns are 85 F. 13:30 - 15:00 1.50 CEMT P TIEB1 PJSM: Cmt 9 5/8" Csg. -Cement 9 5/8" Cs -Pump 3 bbls H2O & test lines to 3,500 psi. -Blow downlines. -Batch & pump 68 bbls cement. - 15.8 ppg class "G" w/ GasBlok. -Drop ES-Cementer closing Plug. -Kick out Plug w/ 5 bbls of cement. -15.8 ppg class "G" w/ GasBlok. -Displace w/ 9.8 ppg NaCI. -Bump plug ~ 438 stks / 44.2 bbls. -CIP C~3 14:10 hrs. -Pressure up to 1,200 psi. 1,000 psi over FCP. -FCP = 20 spm / 200 psi. -Check floats. Blow down hole fill. -25 bbls of cement returns to surface. -Bleed off Choke & kill lines. 15:00 - 00:00 9.00 CASE P TIEB1 N/D Stack,Riser, Flow line, Turn buckles & Choke line. -P/U Stack 2 ft. Center up stack to set E-slips. -Set E-slips w/ 135K. -FMC to cut Csg w/ WACHS cutter. -Cut off jt = 32.42'. -UD landing jt. Remove Tbg spool.. -Set back Stack. Install new Tbg spool. -Install new Packoff. -Test Packoff to 3,800 psi / 30 minutes -Pass. -N/U Stack & Choke line. Double valve annulus w/ plugs. -Hook up turn buckles, Riser & Flow line. 3/6/2008 00:00 - 00:30 0.50 CASE P TIE61 N/U BOP's. Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -2 7/8" X 5" Variables. 00:30 - 01:30 1.00 CASE P TIEB1 Install test plug. -R/U & Test Stacks lit & Choke Lines lit. -Test 250 low psi / 3,500 high psi. -Test each for 5 minutes & chart -Pass. 01:30 - 02:00 0.50 CASE P TIEB1 Pull test plug. Install Wear ring. 02:00 - 02:30 0.50 CLEAN P TIEB1 P/U 8 1/2" Bit & 6 3/4" D.C- Drill out BHA to Rig floor. 02:30 - 03:30 1.00 CLEAN P TIE61 M/U 8 1/2" Drill out BHA. -Bit, 2 Junk baskets, 6 3/4" D.C's. & Jars. 03:30 - 06:30 3.00 CLEAN P TIEB1 RIH, Wash down from 550' md. -254 gpm / 60 psi. -Ta cement C~3 595' md. -Drill hard Cement rom o 677' md. -Drill out ESCementer plug ~ 677' md. -Drill out stringers to top of sand ~ 771' md. -PUW= 75K, SOW= 80K, ROT wt= 80K. Printed: 3/27/2008 7:53:02 PM • • BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT I Phase ~ Description of Operations 3/6/2008 03:30 - 06:30 3.00 CLEAN P TIE61 -336 gpm / 220 psi, WOB= 5K. -RPM = 60, Tq = 1 K. 06:30 - 08:00 1.50 CLEAN P TIE61 Circulate hole clean. -Pump Hi Vis Sweeps (31bs/bbl Duo-Vis). -Pump surface to surface. -Rotate & reciprocate. -Sand, cement & Plug rubber in sweeps. -420 gpm / 410 psi. RPM= 65. 08:00 - 09:00 1.00 CLEAN P TIE61 POH. Break off Bit (in gage). -Clean out Junk baskets. Recovered: -1 hand full of sand/cement and a few small metal pieces. -Some small pieces of Plug rubber 09:00 - 10:00 1.00 CLEAN P TIEB1 R/U to test 9 5/8" 471b Csg. -Close Blind Rams. -Test Cs to 3,500 si / 30 minutes -Pass. -Test w/ 9.8 ppg NaCI. 10:00 - 11:00 1.00 CLEAN P TIEB1 P/U & M/U Reversing basket, & 2 Junk baskets. -RIH to top of sand. C~ 771' md. 11:00 - 12:00 1.00 CLEAN P TIEB1 Wash sand from 771' and to RBP ~ 820' md. -PUW= 78K, SOW= 80K. -210 gpm / 820 psi. 12:00 - 13:00 1.00 CLEAN P TIEB1 Circulate sand out. -Pump Hi Vis Sweep surface to surface. -(3 Ibs/bbl Duo-Vis). -Recovered sand & metal shavings. 13:00 - 13:30 0.50 CLEAN P TIE61 Blow down Top drive. -POH f/ 820' to 304' md. 13:30 - 15:00 1.50 CLEAN P TIE61 L/D (9) - 6 3/4" D.C's. Oil Jar. -L/D Bit sub, 2 Junk baskets & Reversing basket. -Sand and small metal cuttings recoverd in Junk baskets. -Metal shavings in reverse basket. 15:00 - 15:30 0.50 CLEAN P TIEB1 Clear Rig floor of Baker tools. -P/U HES Overshot /retrieval tool. 15:30 - 16:00 0.50 CLEAN P TIEB1 RIH f/ 8' to 820' and (Top of RBP) w/ 5" D. P. 16:00 - 17:00 1.00 CLEAN P TIEB1 Obtain parameters: PUW= 65K, SOW= 68K. -Circulate C~3 378 gpm / 110 psi. -Attempt to get into RBP Plug several times. - Increase pump to 504 gpm / 280 psi. -Attem is failed. 17:00 - 18:00 1.00 CLEAN P TIEBi Blow down Top Drive. -POH f/ 820' to 8' md. -Pull Overshot to floor. -C/O Overshot. RIH w/ Overshot f/ 8' to 820' md. 18:00 - 19:00 1.00 CLEAN P TIE61 Obtain parameters: PUW= 65K, SOW= 68K. -Work new Overshot /several times prior to Latch up. -Latch onto RBP. Release RBP. 19:00 - 22:00 3.00 CLEAN P TIEB1 POH f 820' to 694' md. -RBP hung up. Work pipe up to 683' md. -Pull 20K over & work down. -RBP hung up again. 22:00 - 23:30 1.50 CLEAN P TIEB1 Close Bag. Reverse circulate. Printed: 3/27/2008 1:53:02 PM n • BP EXPLORATION Page 8 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date From - To , Hours ~ Task Code NPT Phase ~ Description of Operations 3/6/2008 22:00 - 23:30 1.50 CLEAN P TIEB1 -378 gpm / 360 psi. -Work pipe down to 698' md. 23:30 - 00:00 0.50 CLEAN P TIE61 Open Bag. Work pipe. -Rotate 20 - 40 RPM. -RBP free ~ 65K. -Pipe stalled out when picked up to 80K. - Continue working pipe. 3/7/2008 00:00 - 01:00 1.00 FISH N DPRB TIEB1 Work RBP & pipe. Rotate 20 - 40 RPM. -PUW= 65 - 170 psi. -Work down from 698' to 771' md. 01:00 - 02:00 1.00 FISH N DPRB TIEB1 -Attempt to release from RBP C~ 771' md_. -Work pipe down w/ left hand 1/4 turns. -No success. 02:00 - 03:00 1.00 FISH N DPRB TIEB1 Rotate left 50 turns. -Rotate right 40 - 60 RPM. -Work pipe up & down 50 - 125K. -RBP broke free ~ 125K overoull.. -Pull up to 677' and -hanging up in ES cementer ~ 677' md. -Work pipe cautiously & rotate up to 50 RPM. -Turn 80 RPM & P/U to 75K. -Pulled through ES cementer. 03:00 - 03:30 0.50 FISH N DPRB TIEB1 POH slowly with drag noted. -25K instant resistance noted C~? 200' md. -Continue out of hole. 03:30 - 04:00 0.50 FISH N DPRB TIEB1 Work RBP parts through Stack. -Hanging up on Wear ring. BOLDS. -Pull RBP pieces to Rig floor -Retrieved Cap & Inner sleeve of RBP. 04:00 - 05:00 1.00 FISH N DPRB TIE61 Make service breaks on Vendor tools. -L/D RBP pieces & running tool. -Send RBP pieces to Baker machine shop. -Baker to use RBP arts to d i 05:00 - 05:30 0.50 FISH N DPRB TIEB1 Remove & inspect Wear ring. -Gouges noted on bottom of Wear ring. 05:30 - 06:00 0.50 FISH N DPRB TIEB1 Lubricate & service Rig. 06:00 - 07:00 1.00 FISH N DPRB TIEB1 Install test plug. -R/U to test BOP's. 07:00 - 13:00 6.00 FISH N DPRB TIEB1 Test BOP's, Choke & associated valves: ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind Rams. -2 7/8" X 5" Variables. -Test Valves: 1,2,3,4,5,6,7,8,9,10,11,12,13 &14. -Test Manual valve, Kill, Choke, HCR Kill, Upper & Lower IBOP. -TIW & Dart valves. -Pass -Test upper & lower Rams w/ 5" & 4 1/2" test jts. -Test 250 low psi & 3,500 psi High psi. -Pass. -Hold each test for 5 minutes. -Test witnessed by T. P. & WSL. -Test witness waived by John Crisp AOGCC. -Install Wear ring. Printed: 3/27/2008 1:53:02 PM • • BP EXPLORATION Page 9 of 13 .Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date ,From - To Hours Task Code NPT Phase II Description of Operations 3/7/2008 13:00 - 14:00 1.00 FISH N DPRB TIEB1 L/D test jt. Blow down Choke manifold, -Choke line & Kill line. Install Wear ring. 14:00 - 16:00 2.00 FISH N DPRB TIE61 P/U Baker Tools to Rig floor. 16:00 - 17:00 1.00 ~ CLEAN ~ N ~ DPRB ~ TIEB1 17:00 - 17:30 0.50 CLEAN N DPRB TIEB1 17:30 - 18:00 0.50 CLEAN N DPRB TIEB1 18:00 - 18:30 0.50 CLEAN N DPRB TIE61 18:30 - 19:00 I 0.501 CLEAN 1 N I DPRB ITIEBI 19:00 - 19:30 0.50 CLEAN N DPRB TIE61 19:30 - 20:00 0.50 CLEAN N DPRB TIEB1 20:00 - 20:30 0.50 CLEAN N DPRB TIEB1 20:30 - 21:00 0.50 CLEAN N DPRB TIEB1 21:00 - 23:00 I 2.001 CLEAN I N I DPRB I TIEB1 23:00 - 00:00 I 1.001 CLEAN I N I DPRB ITIE61 13/8/2008 100:00 - 00:30 I 0.501 CLEAN I N I DPRB ITIE61 00:30 - 01:30 I 1.001 CLEAN I N I DPRB ITIEBI -M/U tools: Jet basket, 2 Boot basket, -Bit sub, Bumper sub, Oil Jar, XO's, & (6) 6 3/4" D.C's. RIH -Slowly f/ 221 to 716' and w/ 5" D. P. -Watch for RBP body. Tag fish ~ 716' md. -P/U 90 ft. Wash down to Fish. -PUW= 76K, SOW= 80K. Circulate & pump Hi VisSweep (51YP). -Sweep recovered sand, cement & metal shavings. -210 gpm / 820 psi. -336 gpm / 1,930 psi. -168 gpm / 540 psi. Blow down Top Drive. -POH f/ 716' to 221' and w/ 5" D.P. Rack back 6 3/4" D.C's. -Break down Baker tools. -Empty Junk baskets & Jet basket. Recovered: -(4)- Very large pieces of Plug catcher (6" to 8").. -(+/- 13) large pieces of Plug catcher (3" to 5"). -Plug rubber & metal shavings. M/U &RIH with the Same BHA: -Jet basket, 2 Boot basket, -Bit sub, Bumper sub, Oil Jar, XO's, & (6) 6 3/4" D.C's. RIH from 221' to 700' and with 5" D.P. Cautiously wash down to Fish @ 716' md. -252 gpm / 1,100 psi. -PUW= 76K, SOW= 80K. -Circulate & stage pumps up to 336 gpm / 1,980 psi. Blow down Top Drive. -POH from 716' to 221' and with 5" D.P. Rack back 6 3/4" D.C's. -Break down Baker tools. -Empty Junk baskets & Jet basket. Recovered: -(1) large piece of Plug catcher (3" by 3"). -(5) metal slivers. M/U Bit & 9 5/8" Csg scraper BHA. -Bit, 9 5/8" Csg scraper, Bit sub, Bumper sub, -Bowen Oil jar, XO, 6 3/4" D.C's & XO. -PJSM -New crew -two new floor hands. -RIH w/ 5" D.P from 210' to 500' md. Wash down slowly from 500' to 700' md. -PUW= 73K, SOW= 75K. -420 gpm / 280 psi. Circulate Hi Vis Sweep (45YP) surface to surface. -Some sand & small, hard cement pieces. -PUW= 73K, SOW= 75K. -420 gpm / 280 psi. Blow down Top Drive. Printed: 3/27/2008 1:53:02 PM C7 • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 3/8/2008 00:30 - 01:30 1.00 CLEAN N DPRB TIE61 -POH f/ 700' to 210' md. -Stand back 6 3/4" D.C's. UD Bit & scraper. -Bit in gage. 01:30 - 02:30 1.00 CLEAN N DPRB TIEB1 M/U Jet basket BHA. -Jet basket, 2 Boot basket, -Bit sub, Bumper sub, Oil Jar, XO's, & (6) 6 3/4" D.C's. -RIH f/ 221' to 694' md. -Wash down & tag fish C~ 716' md. -210 gpm / 700 psi. 02:30 - 03:30 1.00 CLEAN N DPRB TIEB1 Circulate & pump Hi Vis Sweep (50 YP) surface to surface. -210 gpm / 700 psi, stage up pumps to 315 gpm / 1,640 psi. -Nothing of note in returns. 03:30 - 05:00 1.50 CLEAN N DPRB TIE61 Blow down Top Drive. -POH f/ 716' to 221' md. -Stand back 6 3/4" D.C's. -UD Jet basket Assy -empty. 05:00 - 06:00 1.00 CLEAN N DPRB TIEB1 M/U Fishin BHA. -Haliburton XO thread, Stabilizer, Bumper sub, -Bowen Oil Jar, XO, 6 3/4" D.C's & XO. -RIH with Fishing BHA from 210' to 685' md. -PUW= 73K, SOW= 75K. 06:00 - 06:30 0.50 CLEAN N DPRB TIEB1 Rotate down t/ Top of Fish @ 716' md. -En a e Fish. -RPM= 10, Tq= 0. 06:30 - 08:00 1.50 CLEAN N DPRB TIEB1 POH slowly f/ 716' to 221' md. 08:00 - 08:30 0.50 CLEAN N DPRB TIE61 Reset Wear Ring. -UD Fish. -Remainder of RBP recovered. -RBP inner mandrel plugged with debris. 08:30 - 09:00 0.50 CLEAN P TIE61 Clear Rig Floor. -PU Reverse Junk Basket Assembly. 09:00 - 10:00 1.00 CLEAN P TIEB1 M/U Reverse Junk Basket Assembly. -Reverse Junk Basket, Boot Baskets, Bumper Sub, Oil Jar, -XO, 6 3/4" DCs, XO. 10:00 - 11:30 1.50 CLEAN P TIEB1 RIH f/221'to 2,685' md. -PUW= 110K, SOW= 106K. 11:30 - 12:00 0.50 CLEAN P TIEB1 Wash down & Ta RBP ~ 2,735' md. -210 gpm / 820 psi. -Tag & Work Fish. -336 gpm / 1900 psi. -Circulate Hi Vis Sweep surface to surface. -210 gpm / 820 psi 12:00 - 13:30 1.50 CLEAN P TIE61 -Complete surface to surface circulation of Hi Vis Sweep (50 YP). -Nothing of note w/ sweep. -Displace well to 8.5 ppg Seawater. -PUW= 108K, SOW= 105K. 13:30 - 15:00 1.50 CLEAN P TIEB1 Flow Check. -Static. -Blow Down TD. -POH f/ 2,735' to 221' md. 15:00 - 16:00 1.00 CLEAN P TIEB1 Rack back 6 3/4" DCs. -Clean out Reverse Junk Basket. -Recovered 3 pieces of metal. Printed: 3!27/2008 1:53:02 PM • • BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date Frorn - To Hours Task I Code -NPT Rhase ~ Description of Operations 3/8/2008 15:00 - 16:00 1.00 CLEAN P TIEB1 -1 piece - 5.5" x 2.5". -1 piece - 2.5" x 2.5". '~'r -1 piece - 2" x 1 ". -Clean out Boot Baskets. -Recovered -10# of metal shavings and small pieces of metal. 16:00 - 16:30 0.50 CLEAN P TIEB1 MU Reverse Junk Basket BHA. 16:30 - 17:30 1.00 CLEAN P TIEB1 RIH f/ 221' to 2,681' md. -Screw in Top Drive. 17:30 - 18:00 0.50 CLEAN P TIEB1 Wash down to 2,735' md. -210 gpm / 730 psi. -336 gpm / 1830 psi. -PUW= 108K, SOW= 105K. 18:00 - 18:30 0.50 CLEAN P TIE61 Blow down Top Drive. -POH f/ 2,735' to 221' md. 18:30 - 19:30 1.00 CLEAN P TIE61 Service break Baker tools. -Clean out Reverse Junk Basket & Boot Baskets. -Recovered -3# of metal. 19:30 - 20:00 0.50 CLEAN P TIEB1 UD Baker tools. -Reverse Junk Basket, Boot Basket, Oil Jar, Bumper Sub. 20:00 - 21:00 1.00 CLEAN P TIEB1 Clear Rig Floor of all unneeded tools. _-PU HES RBP retrieval tools. (Overshot & Adapter) 21:00 - 22:00 1.00 CLEAN P TIEB1 RIH f/ 7' to 2,735' md. -Latch u on RBP. -Confirm w/ 185K overpull. 22:00 - 22:30 0.50 CLEAN P TIEB1 R/U & Reverse Circulate. -210 gpm / 220 psi. -378 gpm / 500 psi. -PUW= 100K, SOW= 100K. 22:30 - 00:00 1.50 CLEAN P TIEB1 Flow Check. -Static. -Blow down Top Drive and Kill line. -POH & UD Drill Pipe f/ 2,735' to 1,041' md. 3/9/2008 00:00 - 01:30 1.50 RIGU P TIEB1 POH w/ RBP f/ 1,041' and to Surface. -UD 5" DP. 01:30 - 02:00 0.50 CLEAN P TIEB1 UD HES RBP. -RBP intact and in good condition. -Clear Rig Floor. 02:00 - 03:30 1.50 BUNCO RUNCMP RIH w/ 1 std 5" DP from derrick & UD. -RIH w! 2 std DCs from derrick & UD. 03:30 - 04:00 0.50 BUNCO RUNCMP Clear Rig Floor. -P/U Test Jt. -Pull Wear Ring. -UD Test Jt. 04:00 - 06:30 2.50 BUNCO RUNCMP R/U to run 4.5" 12.6# 13cr80 Vam Top Tubing. -C/O Bales. -P/U Tubing handling equipment -slips, elevators, -single jt compensator & elevators, tongs. 06:30 - 12:00 5.50 BUNCO RUNCMP PJSM -Running Tubing. -Run 51 jts 4.5" 12.6# 13cr80 Vam Top Cond B Tubing w/ Unique Overshot. -Optimum Torque - 4440 ft-Ibs. -Utilize Torque Turn services. -Utilize Jet Lube Seal Guard Thread Compound. -Bakerlok all connections below packer. Printed: 3/27/2008 1:53:02 PM • • BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: 09-23A (Common Well Name: 09-23A Event Name: WORKOVER 'Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 3/9/2008 12:00 - 00:00 12.00 BUNCO 3/10/2008 00:00 - 05:00 5.00 BUNCO 05:00 - 06:30 1.50 BUNCO 06:30 - 08:00 1.50 BUNCO 08:00 - 09:00 1.00 BUNCO 09:00 - 12:00 3.00 BUNCO 12:00 - 16:30 4.50 BUNCO 16:30 - 18:30 2.00 BUNCO Spud Date: 3/16/1984 Start: 2/27/2008 End: Rig Release: 3/11/2008 Rig Number: Phase ' Description of Operations RUNCMP PJSM -Running Tubing. -Run 251 jts 4.5" 12.6# 13cr80 Vam Top Tubing per program. -PUW= 290K, SOW= 110K. -Total Jts run Today = 302. RUNCMP Run 4.5" 12.6# 13cr80 Vam Top Completion to 15,980' md. -Run f/ jt #302 to jt #405. -Utilize Torque Turn services. -Use Jet Lube Seal Guard Thread Compound. -Optimum torque = 4,440 ft-Ibs. -Total Jts Run= 405. RUNCMP PU jt #406 & MU Head pin, XO to Cement Line. -Wash down - 100 gpm / 140 psi. -PU jt #407 & MU Head pin, XO to Cement Line. -Wash down - 132 gpm / 240 psi. -Pressure increased to 320 psi C~? stump. -Ta Tubin Stum @ 15 97 ' -Tag 1st shear pin @ 15,976' md. Shear w/ 10K over. -Tag 2nd shear pin @ 15,984' md. Shear w/ 10K over. -No Go ~ 15,986' md. RUNCMP LD jts # 407, 406, 405. -PU pup jts (10.09' & 9.84') & jt # 405. -MU to Tubing Hanger. -Land Tubing C~3 15,980' and w/ TC-II landing jt. -RILDS. RUNCMP RU to Reverse Circulate. -MU Head pin, High Pressure Line & Injection Line. RUNCMP Reverse Circulate heated Seawater. -84 gpm / 500 psi. -Begin pumping Corrosion Inhibitor ~ 2400 stks. RUNCMP Continue to Reverse Circulate. -84 gpm / 480 psi. -All Corrosion Inhibitor pumped (~ 6000 stks. -Continue to Reverse Circulate heated Seawater to 8600 stks RUNCMP RD Reverse Circulating Equipment. -Drop Ball & Rod (with Rollers). -RU to pressure up. -Pressure u Tubing to 3500 psi & set Packer. -Hold ressure & Test Tbg for 30 min. Chart test. -Good Tes+ -Bleed Tubing pressure to 1500 psi -Pressure u on Annulus to 3500 si to test Packer & Tb . -Hold ressure for 30 min. Chart test. -Good test. -Bleed Tubing pressure. DCR valve sheared w/ 900 psi. -Pump down Tubing: 126 gpm / 170 psi. Annulus: 126 gpm / 350 psi. -LD TC-II Landing jt. -RD Test Equipment. 18:30 - 20:00 1.50 BUNCO RUNCMP Install TWC. -Test f/ below C~? 1500 psi. -Hold pressure for 30 min. Chart test. -Good Test. -Test f/ above C~ 1000 psi. -Hold pressure for 5 min. Chart test. -Good Test. 20:00 - 21:00 1.00 BUNCO RUNCMP CO bales. -RD compensator sub. Printed: 3/27/2008 1:53:02 PM • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: 09-23A Common Well Name: 09-23A Spud Date: 3/16/1984 Event Name: WORKOVER Start: 2/27/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 3/11/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours I Task Code NPT Phase ~ Description of Operations 3/10/2008 20:00 - 21:00 1.00 RUNCO RUNCMP -Blow down Choke, Kill, Hole Fill & Bleed Off Lines. -Suck out Stack. 21:00 - 00:00 3.00 WHSUR P RUNCMP PJSM on upcoming Sim Ops. -RD Flowline, Riser, Hole Fill & Bleed Off Line. -ND BOP stack. -CO Saver Sub. -NU Adapter Flange & Production Tree. -Test Adapter Flange /Tubing Packoff to 5000 psi for 30 min. - Good Test. 3/11/2008 00:00 - 01:30 1.50 WHSUR P RUNCMP -RU to test Tree. -Test Production Tree w/diesel to 5000 psi. -Hold & Chart test for 10 min. -Good Test. 01:30 - 02:00 0.50 WHSUR P RUNCMP RU & Test DSM Lubricator. -Pressure test to 500 psi for 5 min. -Good Test. -Pull TWC. -RD DSM Lubricator. 02:00 - 03:00 1.00 WHSUR P RUNCMP R/U Lines & Valves for Freeze Protection & U-tubing diesel. 03:00 - 05:00 2.00 WHSUR P RUNCMP PJSM -Freeze Protecting. -RU Little Red Services. -Test lines to 3500 psi. -Pump 160 bbls diesel down IA to freeze protect. -2 bpm C?~ 650 psi 05:00 - 06:00 1.00 WHSUR P RUNCMP Allow diesel to U-Tube. 06:00 - 07:00 1.00 WHSUR P RUNCMP -RU DSM lubricator -Install BPV -RD lubricator -Attempt to test BPV. BPV leaks. 07:00 - 10:00 3.00 WHSUR N WAIT RUNCMP Wait on DSM for pulling tool available to pull BPV 10:00 - 11:00 1.00 WHSUR N SFAL RUNCMP -RU lubricator -C/O BPV -RD lubricator 11:00 - 11:30 0.50 WHSUR P RUNCMP Test BPV to 1,000 psi x 30 min on chart 11:30 - 12:00 0.50 WHSUR P RUNCMP RD lines. Secure tree. Release rig ~ 12:00 3-11-08 Printed: 3/27/2008 1:53:02 PM Digital Well File • . Page 1 of 3 Well: 09-23 Wel! History Well Da#e Summary 09-23A 3/11/2008 set ciw 41!16" bpv h plug for post rig, had to pull and reset first plug poppet cut, set #145 ~ 96" T/l/0 010!0 09-23A 3/15/2048 Pulled 4" CiW "H" BPV, post rig. T=O. 1 -2' extension used. Tag at 102". No problems. 49-23A 3!16/2008 *""WELL SHUT IN ON ARRIVAL*** PULLED B&R FROM RHC @ 15911' SLM PULLED BK-DGLV'S FROM STA.#'S 1 (14927'MD) & 2 (12829' MD) ""«JOB CONT. ON 3!17/08"«« 09-23A 3/17/2008 ««*JOB CONT. FROM 3!16108««' PULLED DGLV'S FROM STA#3 ~ 14,556'SLM {10,570'MD), STA #4 @ 8749'SLM {8760'MD) &STA #6 ~ 3591'SLM (3612'MD} SET 1.5" LGLV {16164",1647#) W/RK €N STA #6. SET 1"LGLV (16/64", 1861#} W/BK IN STA #4. SET 1" LGLV (16/fi4",1839#) W/BK tN STA #3. SET 1" LGLV (16/64",1815#) WlBK IN STA #2 ~ 12,812'SLM {12,829'MD). RIH W/ 1.25" LiB TO TAG STA.#5 *""JOB CONT. ON 3/18/08*"' 09-23A 3/18/2008 "*JOB CONT. FROM 3117/08"* RAN L!B TO STA #2 ~ 12,812'SLM - UNABLE TO GET IMPRESSION RAN JK RUNNING TOOL WIBRAS5 PtN TO STA #2 -PIN SHEARED, fNDIGAT#NG SE? VALVE. SET 1" OGLV (24/64"} IN STA #1 ~ 14,910' SLM {14,927'MD) PULLED 41/2" RHC FROM X-NIPPLE ~ 15,953' MD BUMPED UP W/TOOLS AND SMUT DOWN DUE TO TEMP. "*"GOON WEATHER TICKET FOR 3/19/08*" 09-23A 3/19/2008 '*** RESUME JOB AFTER WEATHER HOLD FROM 3-18-OS WSR ~«« 924' SLM. 1"LGLV FROM STA #3 ~ 10,570' MD RECOVERED IN RHC PULLED 41/2" RHC FROM 15 , DRIFT W/ 3.625" CENT & SAMPLE BAILER TO 15,976' SLM (16,005' MD -CORRECTION FROM DEPTH RHC WAS PULLED FROM) *`« RIG DOWN AND GO TO MAINT. WILL RESUME JOB AFTER MAINT"* 09-23A 3/20/2008 `«« OFF OF WEATHER HOLD, CONT FROM 3-i9-0$ WSR *`* SET 4-112" X-CATCHER IN X-NIP ~ 15871' MD ONE A-rTEMPT TO SET BK-LGLV IN STA.#3, UNABLE TO SIT DOWN SHUT DOWN DUE TO COLD WEATHER -41,5 •«*JOB CONT. ON 3/21108*** 09-23A 3/21/2008 "«*JOB CONT. FROM 3!20/08*«* SET 1"LGLV (16/64, 1839#} W/BK TO STA #3 ~ 10,566'SLM (10574'MD} PULLED 4 1/2" X-LOCK CATCHER ~ 15,850'SLM. «""WELL SHUT IN ON DEPARTURE""` 09-23A 3!31/2008 CTU # 9 . Weld additional 3500'to the existing CT to string on unit. *«Job continued on 04/01/08 ** 09-23A 4/1/2008 CTU, Weld additional pipe to existing string. «Gontinued from 03/31/08" 09-23A 4/1/2008 *"CTU 9 Continue job from 3/31/2008*'*Job Scope: MIII HES FasDrili «InterAct Publishing» Drift coil w. 1 1/2" ball pumping 60/40 meth. ...Job in progress... 09-23A 4!1/2008 '"'CTU 9 Continue job from 3/3#1200$««" Job Scope: Mill HES Fasprill «InterAct Publishing» Drift coil w. 1 1/4" ball pumping. Did NOT hear ball in CT. Rig apart iron in reel, could not find ball. Rig up to reverse CT. «.«Gontinued on 04/02/08'** 49-23A 4!2/2008 CTU # 9, <Mill HES Fasdrill>, Job continued from 04/01/08. Finish rigging iron to reverse.. Found the ball, Drift the with 1.25° ball. MU 2 718 motor with 3.70" venturri shoe......Job in progress..,. 09-23A 412!2008 CTU # 9 w/ 1.75" OD CT. Mill HES Fasdrili, Job continued from 04/01/08 WSR. Finish rigging iron to reverse. Found the ball, Drift the with 1.25" ball. MU 2 718 motor with 3.70" venturri shoe. RIH with 3.70" venturi burn over shoe. Ta ~ 15972' ctmd. RIH past suspected overshot while pumping 0.7 bpm. pry to ~ 16020' cimd. Begin mi ing as n 1.7 - 2.0 bpm. Mill through FasDrill bridge plug and ~~rrUS p uo to bottom at 17892' ctmd. Continued on WSR 04/03/08. 09-23A 4(2!2008 CTU # 9, <MiII HES Fasdriil>, Job continued from 04101/48. Finish rigging iron to reverse.. Found tha http://digitalwellfile.bpweb.lap.GOm/Wlfnfo/Reports/ReportViewer.aspx 5/13/2008 Digital Well File • • Page 2 of 3 Dri#t the with 1.25" bail. MU 2 718 motor with 3.70" venturri shoe. RIH with 3.70' venturi burn over half , shoe. Tag ~ 15972' ctmd. R!H past suspected overshot white pumping .7 bpm. Dry tag ~ 16020' ctmd. Begin mining Fas Drill ~ 1.7 - 2.0 bpm. *`*Job In Progress*`" 09-23A 4/3/2008 CTU #9 w/ f,75" OD CT. Continued from WSR 04/02/08. Mill/push FasDrili bridge plug to bottom at 17892' ctmd. Pull to surface not turning motor For drift. Inspect venturi at surface, did not recover plug in bum-over shoe. f=reeze protect wall to 2500' TVD with 60/40 methanoUw.ater. RDMO CTU #9. Job complete. 09-23A 4/5/2008 TNO= 240/1220!0. Temp= Hot. Bleed lAP & OAP (eva! IAxOA carnet}. AIL Bhutan ~ skid. DSO was in OAP After 20 min'~AP BUR d t t l on a +h o c of htocrlinn inv & OAP on arrival Shut-in b ee o 4e unchanged. OAP increased 1 i00 osi. Bled IAP to production of (9-23) from 1220 psi io 550 psi in 1.5 hr. Durin to bleed OAP decreased 100 psi to 1000 psi. Bled OAP from 1000 psi to 0+ psi in 1 min. Shut-in bleed and monitored or i r AP increased 10 psi. OAP increased 180 osi. Fina3 WHP's= 24015601180. 09-23A 4/6/2008 T/U0=200/5601520. Tamp=51. Bleed IAP & OAP to 0 psi (oval IAxOA Comm, DSO cats-in). IA Fl. ~ 3510'. OA FL near surface. Bled OAP to bleed tank from 520 psi to 0 pss in 5 min. Bled IAP to production from 560 psi to 270 psi in 1.5 hr. During IAP bleed OAP increased 270 psi. Monitor for 10 min. Fine! WHps=20012701270. 09-23A 4/6/2008 T/1/0=250/2801240 Freeze Protect Flowline with 7 bbls neat meoh and 118 bbts crude. Freeze Protect Tbg with 5 bbls neat and 33 bbis crude. Pressured up flowline to 1500 psi, rig dawn, FWHP~O/280/240 09-23A 4/7/2008 T/I/0=30/270/270. Temp=St. Bleed !AP & OAP to 0 psi {eva! IAxOA Comm, D50 call-in). A/LP=270 psi. AIL SI ~ lateral valve. IA Fl ~ 3510'. Bled IAP to DHD up right lank #009 from 270 psi to 40 psi in 4.5 hr. Bled OAP to up right tank from 270 psi to 40 psi in 5 min. Monitor 30 min. Final WHPs=30/44140. 09-23A 4/9/2008 T/IAIOA=SSV/010 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (IA x OA ) PPPOT-T RU 2 HP bleed tools onto THA 100 psi #0 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000115 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re-installed Alemite caps. Cycle and torque LDS "ET style" all moved with no problems. PPPOT•IC RU 2 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, test port would bleed to 2800 psi in 15 minutes. Cycle and torque LDS "Standard" all moved with na problems. {2nd test) 3500! 15 minutes, 3500/ 30 minutes. Bleed 1C void to 0 psi, RD test equipment re installed Alemite caps. 09-23A 4/2012008 T/I/O = 250/1790/340. Temp =Hot. Monitor WHP's (Post POP). **NOTE*' Operator had bled OAP from 1000 psi to 0 psi in 2-3 minutes (11:30 AM today}. 09-23A 4/21/2008 T/l/0=400/1740/930.. Temp=Hot. Monitor post POP~eval IxOA comet). A/l. on. Ladder on scaffold dons not reach floor (unsecure), OAP increased 590 psi since yesterday. 09-23A 4122!200$ T/I/O = 28011 740/1 01 0. Temp =Hot. Monitor post POP (eva! IAxOA comet), A/L online ®1740 psi. TP decreased 120 psi & OAP increased 80 psi overnight. 09-23A 4!2212008 T/If0 = 360/1720/1050. Temp =Hot. Monitor post POP (eva! IAxOA comet}. A/L online ~ 1720 psi. OAP increased 40 psi #rom earlier monitor (~9 hours). 09-23A 4!23/2008 T/110=380/1720/1130. Temp=Hot. Monitor post POP (oval iA x OA comet}. IAP unchanged & OAP increased 80 psi overnight. 09-23A 4!24!2008 T/U0= 270/1690/1130. Temp= Hot. Monitor post POP {eva! IAxOA comet) H2S. TP decreased 110 psi, IAP decreased 30 psi, OAP unchanged overnight. 09-23A 4!25/2008 T/I/O = 2701171011250. Temp =Hot. Monitor post POP (suet tAxOA comet). A/(. online ~ t 710 psi. TP unchanged, IAP increased 20 psi & OAP increased 120 psi overnight. "Note: Operator said OAP was 1200 psi this morning, pressures taken ~ 3:30 pm.' 09-23A 4/26/2008 T/I/O = 300/i890/1290. Temp =Hot. Monitor post POP (eva! IAxOA comet). OAP increased 40 psi overnight. "Pressures taken ~ iOAM this moming. 09-23A 4127/2008 T/1/0= 30011690/1320. Tamp Hot. Monitor post POP {eva! IAxOA comet). OAP increased 30 psi overnight. 09-23A 4/28/2008 T/I/O= 250/1670/1380. Temp= Hot. Monitor post POP (eva# 1AxOA comet}H2S. TP decreased 50 psi, IAP decreased 20 psi, OAP increased 40 psi overnight. 09-23A 4/29/2008 T/t10 = 28011 650/1 420. Temp =Hot. Monitor post POP (suet IAxOA comet). OAP increased 60 psi overnight. 09-23A 4/30/2008 T/1/0= 340/1850/1480. Temp= Hot. Monitor post POP {Eva! IAxOA comet). TP increased fi0 psi, IAP unchanged, OAP increased 60 psi overnight. 09-23A 511/2008 T/I/0= 250/1650/1500. Temp Hot. Monitor post POP {eva! IAxOA comet). TP decreased 90 psi. iA unchanged. OAP increased 20 psi overnight. http://digitalwellfile.bpweb.bp.com/Wilnfo/Reports/ReportViewer.aspx 5!13/2008 Digital Well File • C7 Page3of3 09-23A 5/2/2008 T/110= 25011650/1500. Temp Hot. Monitor post POP (eval IAxOA comm. OAp unchanged overnight. 09-23A 5/10/2008 T/1/0=32011700/1700. Temp= Hnt. Moni#or post POP (eval IAxOA comm. A/L on. Rig up crew on location, they had to bleed OAP down as the casing valve will not hold. They read 1700 psi on the OA before bleeding. Final WWP's= 320/1700/?. 09-23A 5/1112008 T/I/0=320/1654/1500. Temp=Hot. Monitor post POP (Fuel IAxOA comm. OA rigged up to bleed tank w/2" hardline. 09-23A 5/12!2008 TII/0=32011650!1500. Temp=Hot. Ho{d open bleed on OA (evai tAxOA comm. A/l- on. OA rigged up to bleed tank with 2" hardline. 5tar# bleed ~ 09:30.5 bbl's fluid in bleed tank. Bled OAP from 1500 to 0 in 90 seconds. Open-bleed moni#or on OA. OA cont~ued gurgling ~ tank, some dripping throughout the day. No visible fluid level increase in bleed tank. 51 OA bleed ~ 16:2i {monitor 30 minutes). OAP increased 100 psi in 30 minutes. Final WHP's=320/1650/100. Print Date: 5/18/2008 Page 1 of 1 httpJ/digitafwelifile.bpweb.bp.com/WlInfo/Reports/RepartViewer.aspx 5/13/2008 = 4 1/8" 5M _HEAD = FMC JATOR= BAKERC DRLG DRAFT 09~23A 1EV = 49' LEV = ? = 1094' Angle = 94 @ 17379' n MD = 15853' n TV D = 8800' SS 9-5t8" CSG, 40#, L-80, ID = 8.835" 694' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2700' Minimum ID = 3.813" @ 2302' 4-1/2" HES X NIPPLE TOP OF 7" LNR 9465' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-{ 9600' 4-1'2" TBG. 12.6#, 13-CR-80; .0152 bpf, ID = 3.958" I~ 15964' 9-5/8" FZSV I-i 9900' TOP OF 4-1(2" LNR ~-i 16048' 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 16063' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 16233' PERFORATION SUMMARY REF LOG: SWS LWD/GR ON 03/17/99 ANGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 16265 - 16305 C 03/16/99 2-718" 4 16440 - 16665 C 03/16/99 2-7/8" 4 16830 - 16965 C 03/16/99 2-7/8" 4 17100 - 17280 C 03/16/99 2-7/8" 4 17475 - 17550 C 03/16!99 2-7/8" 4 17770 - 17885 C 03/16/99 SAFETY NOTES: EXTENDED REACH PERIPHERAL SIDETRACK. 70° @ 10101' & 90° @ 16366' *`*4-1/2" CHROMETBG &LNR*** 212~~4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3613 3117 51 MMG DOME RK 16 03/21/08 5 6714 5007 52 MMG DMY RK 0 03/08!08 4 8761 6154 57 KBG2 DOME BK 16 03/21/08 3 10571 6999 69 KBG2 DOME BK 16 03/21/08 2 12830 7750 70 KBG2 DOME BK 16 03/21/08 1 14927 8507 69 KBG2 SO BK 24 03/21/08 9-5/8" WINDOW 9600' - 9650' 15871' 4-112" HES X NIP, 1D = 3.813" 15892' 4-1/2" x 7" BAKER S-3 PKR ID 3.875" 15953' 4-112" HES X NIP, ID = 3.813" 15972' 4-1/2" x 7" UNIQUE MA CHINEOVERSHOT 16009' 7" BAKER SB-3 PKR 16028' STILL HES FASORILL ??? (02114/08) 16043' 4-1 /2" HES X NIP, ID = 3.813" 16063' 4-1/2" WLEG 1 s ~ ELI1l~ TT NOT LOGG® 5" X 7" BKR HMC LNR HANGER & ZXP PKR PBTDI~ 17913' 4-112" LNR, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I--j 18000' DATE REV BY COMMENTS DATE REV BY COMMENTS 1988 ORIGINAL COMPLETION 03/11/08 D14 RWO 03/20/99 RIG. SIDETRACK 03/16/08 /TLH CORRECTIONS 02/06!02 RN1TP CORRECTIONS 03!29/08 KDGSV GLV C!O 10/17/02 JRGKK WANER SAFETY NOTE 9/24105 EZUTLH WANERSFTY NOTEDELETEO 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNff WELL: 09-23A PERMfI' No: 1980440 API No: 50-029-21066-01 SEC 1, T10N, R15E, 1443.76 FEL & 2874.49 FNL BP Exploration (Alaska) 03/06/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~n~,.u r..h u i .,.. ner~ra~:er~~;' _~__ , N0.4621 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Pt.Mac,Milne Pt,Orion,Lisburne nafa RI r`nlnr rn C-41A 12021141 MEM LDL 02/25/08 1 1 MPS-01A 11970714 SCMT ~"} _ C 02/21/08 1 1 P1-06 11975757 PROD PROFILE ?- 03/02/08 1 1 Pi-05 11998992 PROD PROFILE ~ 02/29/08 1 1 P1-06 11975757 SCMT (~ ~- ~ 03/02/08 1 1 09-23A 12045070 USIT ~j - G ~ 03/02/08 1 1 LS-34 12057596 PROD PROFILE S ~ 02/28/08 1 1 W-40 11970816 PRODUCTION LOG -l 03/04/08 1 1 15-046 12005202 MCNL ~~ - t< G 12/28/07 1 1 C-35B 12021139 MCNL ¢ 01/26/08 1 1 X-20A 11661178 CH EDIT PDC GR (MEM CORRELATION) _I 10/26/07 a~ 1 L-219 12017479 CH EDIT PDC GR (IBC) - [ /(p 01/02/08 1 PLEASE ACKNOWLEDGE RECEIPT BY 51(aNIrIG AND Rfcl U'RNINCi'pNt COPY tACFi I U: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. p Anchorage, Alaska 99508 ~ (l~,1V ~~ ~S~)f~ Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • t3 • • d -.~ c .1 ~'a ~ ~,° '..,-.% p,T".r' y, L .'".~ ~~ # 1 F~ ~ d `l~~". i u~+7j/,r/(y ,. ' 6 a ~ I r t' .6 tt Y {~~ f § ( ~ ~ ! ~ , ~ 1 s ~, ~ f'"'1~ ~ t i ~ ~ ~~ I-~ ~~ SARAH PALIN, GOVERNOR ~,.'::; J . ~. ~...~ is ` ~ i --~ i_1 ~.~ ..3 ~ \ L1 1.] L ~~ OII< ~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ER~A'I`IOI1T COMDIIS5IOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader ~~~ FEB ~ ~ 2~d~ BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 a . _ ~r~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-23A ~ ~ ` Sundry Number: 308-030 Dear Mr. Reem: Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. Sundry application 307-021 for similar work was issued January 17, 2007. DATED this day of February, 2008 Encl. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~C~! R~ ~~N ~ ~QQ8 ~lasic~ glil ~ ~~ ~~n ~Qmmssi0r~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time•Extensio -- ® Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended ell ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To II Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 198-044 3. Address: ^ Service ^ Stratigraphic 6. API N ber: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 9-21066-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and N ber: property line where ownership or landownership changes: BU 09-23A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Po (s): ADL 028345 49.42' Pru oe Bay Field / Prudhoe Bay Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD Plugs (measured): Junk (measured): 18000 9043 17913 9041 None None sin Len h iz MD TV Burst Colla se Structural n ctor 80' 2 80' 8 1490 47 Surface 2700' 13-3/8" 2700' 4930 2670 Intermediate 9600' 9-5/8" 960 ' 6 6870 4760 Pro i n Liner 6769' 7" 9466' - 654 - 8 83' 7240 5410 Liner 1951' 4-1/2" 16049 0' 891 - 9043' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft ~ T i S'z ~ Tubing Grade: Tubing MD (ft): 16265' - 17885' 8992' - 9041' 4- / ", 13Cr80 16065' Packers and SSSV Type: 7" x 4-1/2" Baker'SB-3' p r ckers and SSSV MD (ft): 16009' 13. Attachments: 1 ell Class er proposed work: ® Description Summary of Propos I B etch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 0, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: te: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby ce hat the foregoing is rue and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Na a avid Re Title Engineering Team Leader ~ Prepared By Name/Number: Signature Phone 564-5743 Date /_ LS-0 Terrie Hubble, 564-4628 Commi ~sion Use Onl Sundry Number: Conditions of approval: No ' Commission so that a representati~ ~ may witness ^ Plug Integrity ^ OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent F rm Required: APPROVED BY A rove B COMMISSIONER THE COMMISSION Date Form 1~'-403 Revised 06/2006 O n I ^ I ~ A ~ Submit In Duplicate '1.~` (~~J, H F~ ~~ ~~-.~~ ~~ ~ zoos • by G ~~ • 09-23A Rig Workover (IA x OA communication while on gas lift) Scope of Work: Pull 4-~/z" 13Cr-80 completion, cut and pull 9 5/$" casing, tie-back w/new 9 s/$" casing (cemented to surface), replace 9 5/$" hanger with emergency slips and primary pack-off, and run 4-'h" 13Cr80 completion. MASP; 2257 psi Well Type: Producer Estimated Start Date: March 10, 2008 Pre-Rig: S 1 Drift to 16060' for 4-1 /2" com osite bride lu Power Jet cutter. E 2 Set 4-1/2" composite plug @ 16028' (Ref 3/17/1999 Tubing Summary). CMIT TxIA to 3500 psi to confirm mechanical barrier. Power Jet cut tubing C~ 15980' (Ref: 3/17/1999 tubing summa .Jet cut desired to be in the middle. of the 1 st full ~oint above the acker. F 3 Circulate well with seawater and FP w/ diesel thru the cut. CMIT TxIA to 3500 psi to confirm mechanical barrier and casin inte rit .Bleed WHP's to 0 si. O 4 PPPOT-T, -IC, check all LDS. O 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE with 3-'h" x 6" VBR's and blind rams to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 9 s/8" RBP and set at ~200'md below TOC determined from USIT. PT RBP to 2200 psi to prove plug is set. Stack ~50 ft of sand on RBP. 5. Mechanically cut 9 s/8" casing in 2"d full joint above top of cement. Circulate out Arctic Pack. Pull casing thru stack. dress-off 9-5/8' stub in preparation of casing overshot. Note: VBR's will not be changed to 9 5/8" pipe rams as the well has two tested barriers (composite bridge plug and RBP) to the reservoir. 6. Run back in with new 9 s/a", 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9-5/8° pack-off to 3500 psi. Cement new 9 s/a" casing to surface. Run 4-~/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 15875' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. ~Z~ = FMC GEN 3 WELLHEAD = . _FMC ACTUATOR = BAKER C KB. EL'EV = 49' BF. ELEV = ? KOP = 1094' Max Angle = 94 @ 17379' Datum MD = 15853' Datum TV D = 8800' SS • S~NOTES: EXTENDED REACH PERIPHERAL O ~ -2 3A S CK 70° @ 10101' ~ 90° @ 16366' "*"4-1/Z" CHROME TBG &LNR'*' 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2700' i Minimum ID = 3.813" @ 2302' 4-1/2" HES X NIPPLE TOP OF 7" LNR 9465' 9-5/8" CSG, 47#, L-80, iD = 8.681" 96QQ' 9-5/8" EZSV 2302' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4766 3804 53 MMG-M RK 2 8110 5813 58 MMG-M RK 3 10613 7014 69 KBG2LS INT 4 12405 7609 71 KBG2LS INT 5 13609 8022 69 KBG2LS INT 6 14939 8512 69 KBG2LS INT 9-5/8" WINDOW 9600' - 9650' 16009, (-~ 7" BAKER SB-3 PKR i 16043' 4-1/2" HES X NIP, ID = 3.813" 16063' 4-1/2" WLEG ELMD TT NOT LOGGED 5" X 7" BKR HMC LNR \ HANGER & ZXP PKR TOP OF 4-1 /2" LNR ~- j 16048' 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 16063' 7" LNR 26#, L-80, .0383 bpf, ID = 6.276" 16233' PERFORATION SUMMARY REF LOG: SWS LWD/GR ON 03/17/99 ANGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 16265 - 16305 O 03/16/99 2-7/8" 4 16440 - 16665 O 03!16/99 2-7/8" 4 16830 - 16965 O 03/16/99 2-7/8" 4 17100 - 17280 O 03/16/99 2-7/8" 4 17475 - 17550 O 03/16/99 2-7/8" 4 17770 - 17885 O 03/16/99 PBTDI~ 17913' 4-1/2" LNR, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~-~ 18000' DATE REV BY COMMENTS DATE REV BY COMMENTS 1988 ORIGINAL COMPLETION 03/20/99 RIG. SIDETRACK 02/06/02 RNITP CORRECTIONS 10/17/02 JRGKK WANERSAFETY NOTE 9/24/05 EZL(TLH WANERSFTY NOTE DELETED 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY l1Nff WELL: 09-23A PERMfT No: 1980440 API No: 50-029-21066-01 .SEC 1, T10N, R15E, 1443.76 FEL & 2874.49 FNL BP Exploration (Alaska) TREE = FMC GEN 3 WELLHEAD = , FMC ACTUATOR = BAKER C KB. EL1=1/ = 49' BF. ELEV = ? KOP = ~ 1094' Max Angle = 94 @ 17379' Datum MD ~ 15853' Datum TV D = 8800' SS 9-518" CSG, 40#, L-80, ID = 8.835" 13-3/8" CSG, 72#, L-80, ID = 12.347" 09-23A Proposed S Y NOTES: EXTENDED REACH PERIPHERAL SACK 70° @ 10101' & 90° @ 16366' '""'4-1/2" CHROM E TBG &LNR"*' 14-1l2" HES X NIP, ID = 3.813" 2700' GAS LIFT MANDRELS Minimum ID = 3.813" @ 2302' 4-1 /2" HES X NIPPLE TOP OF 7" LNR 9465' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-j 9600'. 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" s-5/a° ¢sv ~~ 9900' TOP OF 4-1 /2" LNR ~ 16048' 4-1/2" TBG, 12..6#, 13-CR-80, .0152 bpf, ID = 3.958" 16063' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 162 PERFORATION SUMMARY REF LOG: SWS LWD/GR ON 03/17/99 ANGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 4 16265 - 16305 O 03/16/99 2-7/8" 4 16440 - 16665 O 03/16/99 2-7/8" 4 16830 - 16965 O 03/16/99 2-7/8" 4 17100 - 17280 O 03/16/99 2-7/8" 4 17475 - 17550 O 03/16/99 2-7/8" 4 17770 - 17885 O 03/16!99 ST MD TYPE VLV 1 3586 4-1/2" 1-1/2" 2 6703 4-1/2" 1-1/2" 3 8754 4-1l2" 1" 4 10574 4-1/2" 1" 5 12830 4-1/2" 1" 6 15805 4-1/2" 1" 9-5/8" WINDOW 9600' - 9650' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" x 7" BAKER S-3 PKR ID 3.875" 4-1/2" HES X NIP, ID = 3.813" 4-1/2" x 7" UNIQUE MACHINEOVERSHOT 16009' 7" BAKER SB-3 PKR 16043' 4-1/2" HES X NIP, ID = 3.813" 16063' a-1/2" wLEG ELMD TT NOT LOGGED 5" X 7" BKR HMC LNR HANGER & ZXP PKR PBTD 4-1/2" LNR, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" H 18000' DATE REV BY COMMENTS GATE REV BY COMMENTS 1988 ORIGINAL COMPLETION 02/21/07 FVR RWO PROPOSAL 03/20/99 RIG. SIDETRACK 02!06/02 RN/TP CORRECTIONS 10/17/02 JRGKK WANER SAFETY NOTE 9!24/05 ¢L/TLH WAVER SFTY NOTE DELETED 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNIT WELL: 09-23A PERMfT No: X1980440 API No: 50-029-21066-01 SEC 1, T10N, R15E, 1443.76 FEL & 2874.49 FNL BP Exploration (Alaska) • ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 01, 2008 4:04 PM To: 'Reem, David C' Subject: RE: DS 09-23A (198-044) Page 1 of 2 Thanks Dave. Coil was the other alternative, but there was no indication 1 way or the other. With either choice, it is a long way to 16000'. Unless advised otherwise, I will use the information you have supplied to update the procedure for 307-021 and we will return your latest application. Call or message with any questions. Tom Maunder, PE AOGCC From: Reem, David C [mailto:ReemDC@BP.com] Sent: Friday, February 01, 2008 3:59 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 09-23A (198-044) Tom, per your request, have added the missing steps. Note that the plan for the 4.5" Fasdrill composite plug is for service coiled tubing to mill it up after the workover and push it to bottom. Call if add'I information is required. Thanks Proposed Procedurelp~l_ip~~.~ 1. M1RU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-'/2" tubing string #o the cu#. 3. RU wireline and run USIT from packer to surface. 4. Run 9-5/8" RBP and set at ~200'md below TOC determined from USIT. PT RBP to 1000 psi to prove up barrier. Stack ~50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 2"~ full joint above TOC. Circulate out dead made and diesel freeze protect. Pull casing thru stack. Note: VBR's will not be chhanged to 9-518" pipe rams as the well has two tested barriers {Fasdrill plug and RBP) to the reservoir. 6. Run back in with new 9-5/8°, 47#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9-518" pack-off to 3500 psi. Cement new 9-5J8" casing ito surface. 7. Drill out 9-5/8" shoetrack down to the RBP. Test casing to 3500 psi. Pull RBP. 8. Run 4-'/Z" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at 15885' MD. 9. Displace the IA to packer fluid and set the packer. 10. Test tubing and IA #0 3500 psi. Freeze protect to 2200' MD. 11. Set BPV. ND ROPE. NU and test tree. RDMO. From: Maunder, Thomas E {DOA) [mailtoaom.maunder@alaska.gov] Sent; Friday, February 01, 2008 3:26 PM To: Roach, Frank Cc: Reem, David C; Hubble, Terrie L Subject: DS 09-23A (198-044) Frank and Dave, I am reviewing the recent sundry for 09-23A. In looking at the tile, I find that sundry 307-021 issued 1/17107 is pretty similar. It only appears that the intended setting depth of the 9-518" RBP has changed. Is there any other reason for the new application? While you are checking your fifes, please look at the general procedure. I think there might be a 2/1/2008 • Page 2 of 2 couple of steps missing between cementing the new 9-5/8" casing and running the completion. Will the rig drill out the deep composite BP? Call or message with any comments. If you might like to revise the letterlprocedure page, email is fine. Tom Maunder, PE AOGCC [p~tlOutline of workover program 2/1/2008 2 ~~ STATE OF ALASKA ~ ~~~ ~ ~ ~~~~ ~L " I ALASKA OIL AND GAS CONSERVATION COMt~ION ~i" Alaska ~1 ~ Gas bona Cart~~nisso REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other PLU "SET Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension 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 1ss-o44o - 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21066-01-00 7. KB Elevation (ft): 9. Well Name and Number: 49.42 KB PBU 09-23A _ 8. Property Designation: 10. Field/Pool(s): - ADLO-028345 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 18000 feet Plugs (measured) 16055' ELMD 4-1/2" WRD true vertical 9043.45 , feet Junk (measured) None Effective Depth measured 17913 feet c~f~r.'~ "'t:!"G~6/ ~~~"~/ ~ ~ 20D7 . true vertical 9041 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" Surface - 80' Surface - 80' 1490 470 Surface 2700' 13-3/8" 72# L-80 Surface - 2700' Surface - 2523' 4930 2670 Intermediate 9600' 9-5/8" 47# L-80 Surface - 9600' Surface - 6622'_,,, ,., ,,,„ .,. 6870 4760 Liner 6769' 7"26# L-80 9466' - 16235' 6545' - 8983' 7240 5410 Liner 1951' 4-1/2" 12.6# L-80 16049' - 18000' 8919' - 9043' 8430 7500 Perforation depth: Measured depth: C 16265' - 16305' C 16440' - 16665' C 16830' - 16965' C 17100' - 17280' C 17475' - 17550' C 17770' - 17885' True Vertical depth: 8992' - 9004' 9011' - 9021' 9036' - 9049' 9047' - 9044' 9035' - 9035' 9038' - 9041' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 Surface - 16065' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER SB-3 PACKER 16009' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Wk`` S ~ S`1~C~ Intervals treated (measured): ~~- l~ttti` 20Di G (c 5-o S~ ~ 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: shut in Subsequent to operation: Shut in 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ~ 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 11/2/2007 f-Orm lU-4U4 FieVISeJ~'U4/ZUUFi ~ ~) j { ~ ~"~' /~ ~ L t` ~ ~ auornn vnyindi viuy • 09-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 10/19/2007,"** WELL S!I ON ARRIVAL *** (secure well} RIG UP TO DRIFT FOR TTP `** CONT.ON 10/20/07 *** 10/20/2007 '*'` CONT. FROM 10/19/07 *** 'DRIFT T.W! 3.50 GAUGE RING TO 16080' SLM. DRIFT T.W/ 3.805 GAUGE RING TO 15987' SLM, POSSIBLY SITTING DOWN IN PKR @ 16009' MD 'RIG UP LRS, START PUMPING. **" CONT. ON 10/21/07 **'' _....... 10/20/2007 T/I/0=150/1200/100 Temp=S1 Assist Slickline with Brush-n-Flush. Pumped 48 bbls .190*F crude down Tbg while slickline RIH with brush **"'`Job continued on 10-21-07 WSR**** 10/21 /2007' *** CONT. FROM 10/20/07 '"'* B&F TUBING W/3 .50" CENT, 4 1/2" BL BRUSH & 3.15 CENT.TO 16025' SLM. SIZED UP TO 3.75 CENT. 4 112" BL BRUSH & 3.805 GUAGE RING TO 16015' SLM, 'NOT ABLE TO WORK PAST 16015' SLM. 'MADE TWO ATTEMPTS TO LOCATE AND SIT DOWN ON STA # 6 W/4 1/2" KOT !''`**CONT. ON 10-22-07*'** _. - _ _. 10/21/2007 **** Job continued from 10-20-07 WSR*** Assist Slickline with Brush-n-Flush (RWO ', re Pumped 211 bbls 190*F crude down Tbg while SL RIH with brush. '***'' Job continued on 10-22-07 WSR*** 10/22/2007 ***CONT. FROM WSR 10-21-07**" '':ATTEMPT TO GET IMPRESSION OF STA #6 W/ 3.625 CENT., '~!4 1/2 BLB, 4 1/2 OK6, 1.25 LIB. ';DRIFT W/ 3.77 WRP DRIFT TO 16,025' SLM FOR E-LINE ***" WELL LEFT SHUT IN AND TURNED OVER TO DSO "** __. - .__ 10/22/2007 "** Job continued from 10-21-07 WSR*** Assist Slickline as directed-- Job cancelled. 'Final WHP's=0/1220/120 "Annulus casing valves left open on departure" 10/23/2007 T/I/0= 0/1220/120 Assist E-line as directed. Pumped 5 bbls neat and 37 bbls icrude down Tbg to assist E-line downhole. Final WHP's= 0/1220/120 "Annulus `casing valves left open on departure" 10/23/2007 '*''*WELL SHUT IN UPON ARRIVAL""** (E-LINE-SET RETRIEVABLE PLUG). !INITIAL T/I/O = 0/1200/125 PSI. SET WEATHERFORD WRP AT 16,055' (MID ELEMENT). REQUIRED PUMPING !AT 1!2 BPM DOWN TUBING TO AID DESCENDING. FINAL T/I/O = 0/i 200/125. !WELL LEFT SHUT-IN. '***JOB COMPLETE*** • FLUIDS PUMPED BBLS 1 Diesel 1 Total . . SARAH PALIN, GOVERNOR AI~ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNED JAN 1 9 2007 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-23A Sundry Number: 307-021 Ù(V( \o...~'O Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this Ihay of January, 2007 Encl. .or¡:> ~/6/2 OItfH7'Ol.·~ R' ECEIVED STATE OF ALASKA !) ALASKA OIL AND GAS CONSERVATION COMMISSION if, 20 7 APPLICATION FOR SUNDRY APPROVAlf1ÿl'f' j/\N 1 1 ' 0 20 MC 25.280 " ns. ission 1. Type of Request: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Time Exten_horage o Alter Casing ~ RepairWell 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Change Approved Program ~ Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation: 10. KB Elevation (ft): I ADL 028345 / 49.42' 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number 198-044 j 6. API Number: 50-029-21066-01-00 ,¡ 8. Well Name and Number: PBU 09-23A I 11. Field I Pool(s): / Prudhoe Bay Field I Prudhoe Bay Pool Effective Depth TVD (ft): Plugs (measured): 9041 None MD TVD Burst 20" 0' 8' 14 0 47 2700' 1 -3/8" 2700' 2523' 4930 2670 9600' 9-5/8" 9600' 6622' 6870 4760 6769' 7" 9466' - 16235' 6545' - 8983' 7240 5410 liner 1951' 4-1/2" 16049' - 18000' 8919' - 9043' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 16265' - 17885' 8992' - 9041' Packers and SSSV Type: 7" x 4-1/2" Baker 'SB-3' packer Tubing Size: 4-1/2", 12.6# Tubing Grade: 13Cr80 Packers and SSSV MD (ft): 16009' Tubing MD (ft): 16065' 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencin 0 erations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Nam avid Reem Title Drilling Engineer 14. Well Class after proposed work: o Exploratory 181 Development 0 Service March 10, 2007 Date: 16. Well Status after proposed work: 181 Oil 0 Gas o WAG 0 GINJ o Plugged DWINJ o Abandoned o WDSPL Contact Frank Roach, 564-4373 Signature Phone 564-5743 Date (-/(-0 r Prepared By Name/Number: Terrie Hubble, 564-4628 Commission Use Onl Sundry Number' Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ¡tJ.. BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 65\)0 ~', ~a V ~ 7-\ E3~t 8 2007 Subsequent Form Required: l-\,(j ~ APPROVED BY THE COMMISSION Date Submit In Duplicate . . G 09-23A Rig W orkover Scope of Work: Pull 4-%" 13Cr-80 completion, cut and pull 9-5/8" casing above TOC, tie-back w/new 9- 5/8" casing, replace 9-5/8" hanger with emergency slips and primary pack-off, and run 4-%" 13Cr80 completion. MASP: 2257 psi Well Type: Producer Estimated Start Date: March 10, 2007 P R" re- Ig: S 1 Drift to 16050' for 4-1/2" XX plug. Set 4-1/2" XX plug @ -16043 (Ref 3/17/1999 Tubing Summary). CMIT TxlA to 3500 psi to confirm mechanical barrier (if OA pressure rises with pressure test, drop test pressure to 2000 psi and test TxIAxOA). E 2 Chemcial cut @ -15980'. (Ref: 3/17/1999 tubing summary). Chemical cut desired to be in the middle of the 1 sl full joint above the packer. F 3 Circulate well with seawater and FP w/ diesel thru the cut. CMIT TxlA to 3500 psi to confirm mechanical barrier and casing integrity. Bleed WHP's to 0 psi. 0 4 PPPOT-T, -IC, check all LDS. 0 5 Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-%" tubing string to the cut. 3. RU wireline and run USIT from packer to surface. 4. Run 9-5/8" RBP and set at -1 OOO'md below TOC determined from USIT. PT RBP to 1000 psi to prove up barrier. Stack -50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 2nd full joint above TOC. Circulate out dead crude and diesel freeze protect. Pull casing thru stack. Back-off 9-5/8" stub and pull same. Note: VBR's will not be changed to 9-5/8" pipe rams as the well has two tested barriers (XX plug and RBP) to the reservoir. . 6. Screw back in with new 9-5/8",40#, L-80 casing and land on new emergency slips with new primary' pack-off. PT 9-5/8" pack-off to 2500 psi. Cement new 9-5/8" casing to surface. 7. Run 4-%" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -15885' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. TRæ=' waLHEAD = ACllJA TOR = KB. 8..EV = BF. 8..EV = KOP= Max Angle = Datum tJÐ = DatumlVD= DATE 1988 03/20199 02106/02 10117(02 9124105 05130106 FMC GEN 3 FMC BAKER C 49' ? 1094' 94 @ 17379' 15853' 8800' SS 113-318" CSG, 72#, L-80, D = 12.347" I Minimum ID = 3.813" @ 2302' 4-1/2" HES X NIPPLE 1 TOP OF 7" LNR I 19-518" CSG, 47#, L-80, D = 8.681" I 19-518" EZSV I 09-23A 1 TOP OF 4-112" LNR I 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PERFORA TION SUMMARY REF LOG: SWS LWDlGR ON 03117/99 ANGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpntSqz DATE 2-718" 4 16265 - 16305 0 03116199 2-718" 4 16440 - 16665 0 03116199 2-718" 4 16830 - 16965 0 03/16/99 2-718" 4 17100 - 17280 0 03/16/99 2-718" 4 17475 - 17550 0 03/16/99 2-718" 4 17770 - 17885 0 03116/99 REV BY COIItM:NTS ORIGINAL COM PLETION RIG. SIDETRACK RI'VT? CORRECTIONS JRClKK WAIVER SAFETY NOTE EZLI1tH WAIVER SFTY NOTE DB.ETED DTM waLHEAD CORRECTION SAFETY NOTES: EXTENDED R!ACH PERIPHERAL SIDETRACK. 70". 10101' & 90°. 16318' ***4-112- CHROME TBG & LNR*** 2302' 4-112" HES X NIP, D = 3.813" GAS LFT MANDRB.S ST tJÐ lVD DEV TYPE VLV LATCH PORT DATE 1 4766 3804 53 t.lM3-M RK 2 8110 5813 58 t.lM3-M RK 3 10613 7014 69 KBG2LS !NT 4 12405 7609 71 KBG2LS INT 5 13609 8022 69 KBG2LS !NT 6 14939 8512 69 KBG2LS INT 9-518" I/IINDOW 9600' - 9650' 16009' -17" BAKER SB-3 PKR I 16043' -14-112" HES X NIP, ID = 3.813" I 16063' - 4-112" WLEG I H 8..MD TT NOT LOGGID I 5" X 7" BKR HMC LNR HANGER & ZXP PKR IPBTD 17913' 14-112" LNR, 12.6#, 13-CR-80, .0152 bpf, I) = 3.958" I DATE REV BY CC»NeNTS PRUDHOE BA Y UNIT W8.L: 09-23A PERMIT No: '1980440 API No: 50-029-21066-01 SEC 1, T10N. R15E. 1443.76 Fa. & 2874.49 FNL BP exploration (Alaska) · TRŒ= IlVELLHEAD = ACTUA TOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum þJ[) = Datum lVD = FMC GEN 3 FMC BAKER C 49' ? 1094' 94 @ 17379' 15853' 8800' SS 9·5/8" CSG, 40#, L-80, 10 = 8.835" 113-318" CSG, 72#, L-80, Ð = 12.347" I 09-23A Proposed SA NOTES: EXTENDED Rl:ACH PERIPHERAL SIDETRACK. 70°. 10101' & 90° fa 18381' ***4-1/2" CHROMETBG & LNR*** 4-1/2" HES X NIP, 10 - 3,813" GAS LIFT MANOR8..S ST MO TYÆ VLV 1 3586 4-112" 1-1/2" 2 6703 4-1/2" 1-112" 3 8754 4-1/2" 1" 4 10574 4_1/2" 1" 5 12830 4-1/2" 1" 6 15805 4-1/2" 1" Minimum ID = 3.81311 @ 2302' 4·1/211 HES X NIPPLE TOPOF7" LNR I 9-518" VVNDOW 9600' - 9650' 19-518" EZSV I 19-518" CSG, 47#, L-80, Ð = 8.681" I 4-1/2" HES X NIP. 10 - 3.813" 4-1/2" x 7" BAKER S-3 PKR 103.875" -14-112"HESXNIP, 10=3.813" I 4-1/2" x 7" UNIQUE MACHINE OVERSHOT 7" BAKER SB-3 PKR 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, 10 = 3.958" I PERFORA IDN SUMMARY REF LOG: SWS LWDlGR ON 03117199 ANGLE AT TOP PERF: 71 @ 16265' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-7/8" 4 16265 - 16305 0 03/16199 2-718" 4 16440 - 16665 0 03116199 2-718" 4 16830 - 16965 0 03116/99 2-718" 4 17100 - 17280 0 03116199 2-7/8" 4 17475 - 17550 0 03116199 2-718" 4 17770 - 17885 0 03116199 DATE 1988 03/20/99 02106/02 10/17102 9124105 05/30106 16043' -14-1/2" HES X NIP, ID = 3.813" I 16063' -14-112" WLEG I H 8..MD TT NOT LOGGED , 5" X 7" BKR HMC LNR HANGER & ZXP PKR 4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" PBTDI 17913' (4-112" LNR, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" I REV BY COM'ÆNTS ORIGINAL COMPLETION RIG. SIDETRACK RNITP CORRECIDNS JRClKK WAWER SAFElY NOTE EZL/TlH WAWER SFTY NOTE DElETED DTM IlVELLHEAD CORRECIDN REV BY COt.!t.1ENTS FVR RWO PROPOSAL PRUDHOE BA Y UNIT IlVELL: 09-23A PERMIT No: ~ 980440 API No: 50-029-21066-01 SEe 1, T10N, R15E. 1443.76 FB. & 2874.49 FNL DATE 01/09107 BP exploration (Alaska) 198-044-0 PRUDHOE BAY UNIT 09-23A 50- 029-21066-01 BP EXPLORATION (ALASKA) INC Roll #1: Start: Stop Roll #2: Start Stop MD 18~0.0_0 .... TVD .09~.0_4__3_ Completion Date: ~__/9.9 Completed Status: _1_-_0~ ..... Current: T Name Interval D 8751 ~ 4-7 SPERRY MPT/GR D 8752~ 2 SPERRY MPT/GR PB1 D 9264 / 1-4 SPERRY MPT/GR/EWR4 L DGR/EWR4-MI~~'',~'FINAL 9600-18000 L DGR/EWR4-TVDL,,~FINAL 6622-9044 L DGR-MD ~ 2 12408-12630 PB1 L DGR-MDt-'/ 4-7 11320-16397 2 8578-8472 PBI. 4-7 .... 7786-8976 ' F~IN~L 15430-15933 SPERRY 12295.02-12630. PBI SPERRY 11195.02-16397. SPERRY 9594.42-18000. ., L DGR-TVD L DGR-TVD ~ L PDC-PRES/TEM/GR., R SRVY RPT ~ R SRVY RPT~/ R. SRVY RPT~''''/ Sent Received OH 10/21/98 10/28/98 OH 10/21/98 10/28/98 OH 7/22/99 7/29/99 OH 8/3/99 8/17/99 OH 8/3/99 8/17/99 OH 10/28/98 10/28/98 OH 10/28/98 10/28/98 OH 10/28/98 10/28/98 OH 10/28/98 10/28/98 CH 5 3/26/99 4/27/99- OH 6/23/98 6/25/98 OH 6/23/98 6/25/98 Oil 3/24/99 3/26/99 T/C/D Wednesday, March 28, 2001 Page I of 1 r"'! I~ I I_., I... I ~.1 ~ S E F:IL/I r" E S WELL LOG TRANSM1TYAL To: State of Alaska Aug 3, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs · 9-23A, AK-MM-90081 The technical data listed below is-being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 9-23A: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-21066-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21066-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska'99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska July 22, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - D.S. 9-23A, AK-MM-90081 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-21066-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 3/26/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al'tN: Sherrie NO. 12465 Compan~ Alaska Oil & Gas Cons Camm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape D.S. 4-31 PROD PROFTL~ PSP-DEFT 990323 1 1 D.S. 9-10 ~A.%~_. IN~ECTION PROFILE W/PSP 990318 1 1 D.S. 9-23A DEPTH CORR/P~ESS/TEMP/GR/CCL 990316 1 1 SIGNED: (~,~~/~-~ DATE: /"'P~ Oil & Gas O0.s. Please sign and return one copy o! this lronsmittol to Sherrie at the above address or fox to (907) 562-6521. \ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil ~] Gas E] Suspended [~] Abandoned E~ Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 98-44 399-002 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ..: 50-029-21066-01 4. Location of well at surface . ~ . 9. Unit or Lease Name At top of productive interval i'! t , ~. 10. Well Number 2884' SNL, 2200' EWL, SEC. 08, T10N, R16E, UM ~...~ "!I~ 09-23A At total depth ..... !~. 11. Field and Pool 2876' SNL, 3835' EWL, SEC. 08, T10N, R16E, UM ' " - ..... .. - Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) ]6. Lease Designation and Serial No. Pool KBE - 49.42' AMSLI ADL 028345 12. Date Spudded ' 113. Date T.D. Reached I 14. Date comP., SusP,, or AbandJI151Wate~ depth, if Offshore 116'. No. of Completions 4/8/98 I 3/12/99 I 3/19/99 I . N/A ..M.....SLI .. One 17. Tota'l'"Depth (MD+TVD) 118. Plug Back Dept~'"i'MD+TVD) ]19. Pirec~'i0nal su'rvey 125'. Depth where SSSV set 121. Thickness 0~ Permafrost 18000 9043 ET] 17913 9041 FTI [~Yes [~No ] (Nipple) 2302' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, LWD ... CASING"' SETTING DEPTH HOLE V I SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" Instld w/1860# Poleset. ~ ~., ~; .-. 1'i'3-3/8"" ' 72# ' L-80 Surface 2700' 17-1/2" 3600 sx CS III, 400 sx CS II i: '.'"" 9-5/8" .~7# ~ . L-80 Surfac.e. .......... 9600' 12-1/4" 500 sx Class 'G', 300 sx CS I ........... 7" 26# L-80 9466' 16235' 8-1/2" 185 sx Class 'G' ~" 4-1/2.'' 12.6# ......... L-80 16049' 18000' 6" 245 sx Class 'G' '" "' "- ' ......... ....... open'"to ............ 24. Perf~)'rations Production (MD+TVD of Top and 25. TUBING RECORD ..... ~': :': ~ .... ""'~ ...... ' Bottom and interval, size and number) .............. SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", i2.6#, 13Cr80 16065' 16009' MD TVD MD TVD 16265' - 16305' 8992' - 9004' , 16440' - 16665' 9011' - 9021' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 16830' - 16965' 9036' - 9049' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 17100'- 17280' 9047' - 9044' 17475'- 17550' 9035' - 9032' 9900' set EZSV (PB2), w/36 Bbls Class ,G, i~elow 17770' - 17885' 9038' - 9041' 9605' K/O Plug, 40 Bbis Class 'G', SqZd to 1725 ps~ Freeze Protect with 180 Bbls of Diesel _~7. PRODUCTION TEST Date FirSt Pr°d~ction" I Method of Operation (Flowi~g, gas lift, etc.) April 2, 1999 ] Gas Lift Date of Test HOurs Tested PRODUCTION FOR" OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO iTEST PERIOD I Flow Tubing 3,asing p~essure 0ALcUUATED OIL-eSL GAS-MCF WATER-eau OIL GRAVITY-APl (CORR) Press. 24-HouR RATE ..... 28. CORE DATA ~ ' Briei'des~ri'pti~'*0fiithol0gy, porosity, fractures' apparent dips and presence of oil, gas or water, sUbmit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sadlerochit 16235' 8982' Zone 1 16352' 9011' 31. List of Attachments Summary of Daily Drilling Reports, Surveys (PB1 & PB2 Surveys were sent with 10-404, 09/98) (09-23 P&A also sent 09/98) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~"~. · ~ 0(./..,~0 ? .(~ Terrie Hubble "~ ~/~ W ....................... Title Technical Ass.!.stant III ... Date ; 09-23A 98-44 399-002 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No, · INSTRUCTIONS GENERA': 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 Ii-' 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 cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB DS 09 Well 09-23A Rig Nabors 7ES Page 1 Date 14 April 99 Date/Time 27 Mar98 18:00-18:30 18:30-19:00 19:00-21:00 21:00-06:00 28 Mar 98 06:00-06:15 06:15-13:00 13:00-14:00 14:00-14:30 14:30-18:00 18:00-18:15 18:15-22:00 22:00-06:00 29 Mar 98 06:00-06:15 06:15-13:00 13:00-15:00 15:00-18:00 18:00-18:15 18:15-20:00 20:00-06:00 30 Mar 98 06:00-06:15 06:15-15:00 15:00-18:00 18:00-18:15 18:15-00:30 31 Mar 98 00:30-02:00 02:00-04:00 04:00-06:00 06:00-06:15 06:15-13:00 13:00-16:00 16:00-18:00 18:00-18:15 18:15-01:00 01 Apr98 01:00-05:00 05:00-06:00 06:00-07:00 07:00-18:00 18:00-18:30 18:30-02:00 02 Apr 98 02:00-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-15:00 15:00-15:30 15:30-23:00 23:00-02:00 03 Apr 98 02:00-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-16:00 16:00-18:00 18:00-18:30 Duration 1/2 hr 1/2 hr 2 hr 9 hr 1/4 hr 6-3/4 hr lhr 1/2 hr 3-1/2 hr 1/4 hr 3-3/4 hr 8 hr 1/4 hr 6-3/4 hr 2 hr 3 hr 1/4 hr 1-3/4 hr 10hr 1/4 hr 8-3/4 hr 3 hr 1/4 hr 6-1/4 hr 1-1/2 hr 2 hr 2 hr 1/4 hr 6-3/4 hr 3 hr 2 hr 1/4 hr 6-3/4 hr 4 hr 1 hr 1 hr 11 hr 1/2 hr 7-1/2 hr 4 hr 1/2 hr 5 hr 1 hr 2-1/2 hr 1/2 hr 7-1/2 hr 3 hr 2 hr 2 hr 1/2 hr 4-1/2 hr 5 hr 2 hr 1/2 hr Activity Held safety meeting Rigged down Drillfloor / Derrick Serviced Block line Rigged down Top drive Held safety meeting Rigged down Top drive Serviced Service lines Held safety meeting Rig moved 30.00 % Held safety meeting Rigged up Service lines Rigged down Drillfloor / Derrick Held safety meeting Rigged down Drillfloor / Derrick Rigged down Lines / Cables Removed Drillfloor / Derrick Held safety meeting Rigged down Drillfloor / Derrick Rig moved 50.00 % Held safety meeting Rig moved 75.00 % Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rig moved 80.00 % Held safety meeting Rig moved 100.00 % Rigged up Service lines Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Top drive Held safety meeting Held safety meeting Installed Top drive Held safety meeting Installed Top drive Singled in drill pipe to 0.0 ft Held safety meeting Singled in drill pipe to 0.0 ft Removed Accessories Installed Fluid system Held safety meeting Circulated at 12470.0 ft Flow check Removed Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Removed Additional services Held safety meeting Facility Date/Time 04 Apr 98 05 Apr 98 06 Apr 98 07 Apr 98 08 Apr 98 09 Apr 98 PB DS 09 Progress Report Well 09-23A Rig Nabors 7ES Page Date Duration Activity 18:30-20:00 20:00-01:00 01:00-06:00 06:00-06:30 06:30-17:00 17:00-18:00 18:00-18:30 18:30-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-15:00 15:00-21:30 21:30-23:00 23:00-04:00 04:00-06:00 06:00-06:30 06:30-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-12:00 12:00-13:30 13:30-14:30 14:30-18:00 18:00-18:15 18:15-21:00 21:00-01:30 01:30-06:00 06:00-06:30 06:30-16:30 16:30-18:00 18:00-23:30 23:30-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-11:00 11:00-11:30 11:30-13:00 13:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 1-1/2 hr 5 hr 5 hr 1/2 hr 10-1/2 hr 1 hr 1/2 hr 5-1/2 hr 5 hr 1 hr 1/2 hr 2-1/2 hr 2 hr 4 hr 6-1/2 hr 1-1/2 hr 5 hr 2 hr 1/2 hr 11-1/2 hr 1/4 hr 3/4 hr 1 hr 6-1/2 hr 2-1/2 hr 1 hr 1/2 hr 5-1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 1/4 hr 2-3/4 hr 4-1/2 hr 4-1/2 hr 1/2 hr 10hr 1-1/2 hr 5-1/2 hr 2 hr 1/2 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 1/2 hr 1-1/2 hr 3 hr 1/2 hr 1 hr 1/2 hr Worked toolstring at 30.0 ft Circulated at 12470.0 ft Laid down 1457.0 ft of Tubing Held safety meeting Laid down 12477.0 ft of Tubing Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Ran Drillpipe in stands to 0.0 ft Held safety meeting Tested Bottom ram Serviced Top drive Ran Drillpipe in stands to 6385.0 ft Singled in drill pipe to 9751.0 ft Circulated at 9564.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 0.0 ft Held safety meeting Ran Drillpipe in stands to 11500.0 ft Held safety meeting Ran Drillpipe in stands to 12403.0 ft Worked toolstring at 12370.0 ft Worked toolstring at 12408.0 ft Circulated at 12400.0 ft Pulled out of hole to 12000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Serviced BOP stack Serviced Top drive Made up BHA no. 1 Held safety meeting Singled in drill pipe to 4464.0 ft R.I.H. to 12408.0 ft Drilled to 12499.0 ft Held safety meeting Drilled to 12630.0 ft Circulated at 12630.0 ft Pulled out of hole to 267.0 ft Pulled BHA Serviced Top drive Ran Drillpipe to 5500.0 ft (5in OD) Held safety meeting Ran Drillpipe in stands to 12350.0 ft Installed Drillfloor / Derrick Ran Drillpipe in stands to 12630.0 ft Circulated at 12630.0 ft Batch mixed slurry - 55.000 bbl Pulled out of hole to 11770.0 ft Circulated at 11770.0 ft Pulled out of hole to 1500.0 ft Installed Drillstring handling equipment Pulled out of hole to 0.0 ft Held safety meeting 2 14 April 99 Facility Date/Time 10 Apr 98 11 Apr 98 12 Apr 98 13 Apr 98 14 Apr 98 15 Apr 98 PB DS 09 Progress Report Well 09-23A Rig Nabors 7ES Duration Activity 18:00-19:00 19:00-02:00 02:00-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-13:30 13:30-14:00 14:00-18:00 18:00-18:15 18:15-02:30 02:30-04:00 04:00-06:00 06:00-06:30 06:30-12:00 12:00-14:00 14:00-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-00:00 00:00-06:00 06:00-06:30 06:30-16:00 16:00-18:00 18:00-18:15 18:15-00:30 00:30-01:00 O1:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-09:30 09:30-18:00 18:00-18:15 18:15-04:00 04:00-06:00 06:00-11:00 11:00-13:00 13:00-16:00 16:00-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-22:00 22:00-23:30 23:30-06:00 06:00-06:15 06:15-18:00 18:00-18:15 18:15-20:00 20:00-21:30 21:30-22:00 22:00-22:30 1 hr 7 hr 4 hr 1/2 hr 5-1/2 hr 1 hr 1/2 hr 1/2 hr 4 hr 1/4 hr 8-1/4 hr 1-1/2 hr 2 hr 1/2 hr 5-1/2 hr 2 hr 4 hr 1/4 hr 3/4 hr 1 hr 4 hr 6 hr 1/2 hr 9-1/2 hr 2 hr 1/4 hr 6-1/4 hr 1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 3 hr 8-1/2 hr 1/4 hr 9-3/4 hr 2 hr 5 hr 2 hr 3 hr 1 hr 1 hr 1/4 hr 3/4 hr 3 hr 1-1/2 hr 6-1/2 hr 1/4 hr 11-3/4 hr 1/4 hr 1-3/4 hr 1-1/2 hr 1/2 hr 1/2 hr Serviced Block line Conducted electric cable operations Ran Drillpipe in stands to 1000.0 ft Held safety meeting Ran Drillpipe in stands to 10165.0 ft Circulated at 10165.0 ft Ran Drillpipe in stands to 11309.0 ft Worked toolstring at 11309.0 ft Worked toolstring at 11280.0 ft Held safety meeting Worked toolstring at 11347.0 ft Circulated at 11347.0 ft Pulled out of hole to 9000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Serviced BOP stack Tested BOP stack Held safety meeting Serviced Top drive Made up BHA no. 2 R.I.H. to 11211.0 ft Drilled to 11370.0 ft Held safety meeting Drilled to 11452.0 ft Circulated at 11452.0 ft Held safety meeting Pulled out of hole to 792.0 ft Pulled BHA Made up BHA no. 3 Serviced Top drive R.I.H. to 4500.0 ft Held safety meeting R.I.H. to 11125.0 ft Drilled to 11462.0 ft Held safety meeting Drilled to 11531.0 ft Circulated at 11531.0 ft Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 2300.0 ft Serviced Block line Held safety meeting Serviced Top drive R.I.H. to 11241.0 ft R.I.H. to 11531.0 ft Drilled to 11910.0 ft Held safety meeting Drilled to 12293.0 ft Held safety meeting Drilled to 12578.0 ft Circulated at 12578.0 ft Pulled out of hole to 11432.0 ft Serviced Top drive Page Date 3 14 April 99 Facility Date/Time 16 Apr 98 17 Apr 98 18 Apr 98 19 Apr 98 20 Apr 98 21 Apr 98 PB DS 09 Progress Report Well 09-23A Page 4 Rig Nabors 7ES Date 14 April 99 Duration Activity 22:30-23:00 23:00-06:00 06:00-06:15 06:15-09:00 09:00-21:00 21:00-23:00 23:00-01:00 01:00-06:00 06:00-06:15 06:15-08:00 08:00-08:30 08:30-11:00 11:00-11:30 11:30-12:30 12:30-13:30 13:30-20:30 20:30-06:00 06:00-06:15 06:15-10:00 10:00-12:00 12:00-13:00 13:00-14:00 14:00-18:30 18:30-21:00 21:00-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-12:30 12:30-14:00 14:00-16:00 16:00-17:30 17:30-22:00 22:00-01:30 01:30-06:00 06:00-06:15 06:15-12:00 12:00-14:30 14:30-16:00 16:00-01:00 01:00-02:30 02:30-03:00 03:00-03:30 03:30-06:00 06:00-07:00 07:00-09:00 09:00-10:30 10:30-15:00 15:00-15:30 15:30-19:30 19:30-20:00 20:00-20:30 20:30-23:00 23:00-23:30 1/2 hr 7hr 1/4hr 2-3/4 hr 12hr 2 hr 2 hr 5 hr 1/4 hr 1-3/4 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 1 hr 7 hr 9-1/2 hr 1/4 hr 3-3/4 hr 2 hr 1 hr 1 hr 4-1/2 hr 2-1/2 hr 9 hr 1 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 4-1/2 hr 3-1/2 hr 4-1/2 hr 1/4 hr 5-3/4 hr 2-1/2 hr 1-1/2 hr 9 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1 hr 2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 4 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr R.I.H. to 12578.0 ft Drilled to 13140.0 ft Held safety meeting Drilled to 13315.0 ft Repaired Fluid system Drilled to 13419.0 ft Circulated at 13419.0 ft Pulled out of hole to 81.0 ft Held safety meeting Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Serviced Top drive Made up BHA no. 5 R.I.H. to 13419.0 ft Drilled to 14445.0 ft Held safety meeting Drilled to 14818.0 ft Circulated at 14818.0 ft Pulled out of hole to 13233.0 ft R.I.H. to 14818.0 ft Drilled to 15412.0 ft Circulated at 15412.0 ft Drilled to 15.0 ft Circulated at 15697.0 ft Drilled to 15728.0 ft Circulated at 15728.0 ft Drilled to 15861.0 ft Circulated at 15861.0 ft Drilled to 15957.0 ft Circulated at 15957.0 ft Drilled to 16397.0 ft Circulated at 16397.0 ft Pulled out of hole to 11500.0 ft Held safety meeting Pulled out of hole to 215.0 ft Pulled BHA Rigged up Casing handling equipment Ran Liner to 7806.0 ft (7in OD) Rigged down Casing handling equipment Installed Liner hanger Circulated at 7806.0 ft Ran Drillpipe in stands to 9706.0 ft Pulled Drillpipe in stands to 7805.0 ft Ran Drillpipe in stands to 11281.0 ft Ran Drillpipe in stands to 12800.0 ft Worked stuck pipe at 12789.0 ft Functioned Liner hanger Laid down 4955.0 ft of 5in OD drill pipe Rigged down sub-surface equipment - Setting tools Installed Retrievable packer Ran Drillpipe in stands to 4765.0 ft Tested Casing Facility Date/Time 22 Apr 98 PB DS 09 Progress Report Well 09-23A Rig Nabors 7ES Page Date Duration Activity 23:30-03:30 03:30-05:00 05:00-06:00 06:00-06:15 06:15-08:00 08:00-08:30 08:30-09:30 09:30-13:00 13:00-15:00 15:00-20:00 4hr 1-1/2 hr lhr 1/4 hr 1-3/4 hr 1/2 hr 1 hr 3-1/2 hr 2 hr 5 hr Laid down 4781.0 ft of 5in OD drill pipe Ran Drillpipe in stands to 3734.0 ft Laid down 450.0 ft of 5in OD drill pipe Held safety meeting Laid down 3284.0 ft of 5in OD drill pipe Retrieved Wear bushing Ran Drillpipe in stands to 2065.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree 5 14 April 99 Facility Date/Time 11 Feb 99 12 Feb 99 13 Feb 99 14 Feb 99 15 Feb 99 16 Feb 99 17 Feb 99 Progress Report PB DS 09 Well 09-23A Page 1 Rig Nabors 7ES Date 14 April 99 09:01-00:00 00:00-06:00 06:00-16:00 16:00-22:00 22:00-05:00 05:00-06:00 06:00-12:00 12:00-22:30 22:30-00:00 00:00-01:00 01:00-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-21:00 21:00-22:00 22:00-23:30 23:30-00:00 00:00-05:30 05:30-06:00 06:00-08:30 08:30-09:30 09:30-11:00 11:00-14:30 14:30-15:30 15:30-22:30 22:30-03:00 03:00-03:30 03:30-06:00 06:00-07:00 07:00-07:30 07:30-09:30 09:30-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-18:30 18:30-23:30 23:30-23:45 23:45-00:00 00:00-03:00 03:00-04:00 04:00-06:00 06:00-10:30 10:30-12:30 12:30-13:30 13:30-14:00 14:00-16:00 16:00-20:00 Duration 14-3/4 hr 6 hr 10hr 6 hr 7 hr 1 hr 6 hr 10-1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 1/2 hr 3 hr 2 hr 9-1/2 hr 1 hr 1-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 2-1/2 hr 1 hr 1-1/2 hr 3-1/2 hr 1 hr 7 hr 4-1/2 hr 1/2 hr 2-1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 5 hr 1/4 hr 1/4 hr 3 hr 1 hr 2 hr 4-1/2 hr 2 hr 1 hr 1/2 hr 2 hr 4 hr Activity Rigged down Drillfloor / Derrick Rig moved 35.00 % Rig moved 75.00 % (cont...) Rig waited: Equipment Rig moved 100.00 % Commissioned Drillfloor / Derrick Commissioned Drillfloor / Derrick Rigged up Top drive Installed High pressure lines Removed Hanger plug Circulated at 2000.4 ft Installed Hanger plug Removed Xmas tree Installed BOP stack Repaired High pressure lines Tested BOP stack Held safety meeting Laid down 2000.0 ft of 5in OD drill pipe Installed Wear bushing Ran Drillpipe to 4758.0 ft (5in OD) Circulated at 4758.0 ft Circulated at 4758.0 ft (cont...) Functioned Bridge plug Circulated at 4765.0 ft Pulled out of hole to 0.0 ft Rigged up Wireline units Conducted slickline operations on Slickline equipment - Tool run Conducted electric cable operations Rigged down Wireline units Made up BHA no. 6 R.I.H. to 4993.0 ft Worked stuck pipe at 9970.0 ft Circulated at 9970.0 ft Pulled out of hole to 9598.0 ft Circulated at 9598.0 ft Circulated closed in well at 9598.0 ft Monitor wellbore pressures Bullhead well Bleed down well Monitor wellbore pressures Bleed down well Monitor wellbore pressures Circulated closed in well at 9598.0 ft Monitor wellbore pressures Held safety meeting Pulled out of hole to 4975.0 ft Rigged up Casing handling equipment Laid down 1230.0 ft of Casing Laid down 5012.9 ft of Casing Rigged down Casing handling equipment Serviced Top drive Installed Cement retainer Ran Drillpipe in stands to 4785.0 ft Singled in drill pipe to 9930.0 ft Facility Date/Time 18 Feb 99 19 Feb 99 20 Feb 99 21 Feb 99 Progress Report PB DS 09 Well 09-23A Rig Nabors 7ES Page 2 Date 14 April 99 20:00-20:30 20:30-21:00 21:00-21:15 21:15-21:30 21:30-22:00 22:00-00:00 00:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-12:00 12:00-12:30 12:30-14:00 14:00-00:00 00:00-06:00 06:00-07:00 07:00-15:00 15:00-17:30 17:30-18:30 18:30-19:00 19:00-22:00 22:00-23:00 23:00-01:00 01:00-02:00 02:00-02:30 02:30-03:30 03:30-04:30 04:30-04:45 04:45-06:00 06:00-07:30 07:30-08:30 08:30-08:45 08:45-09:30 09:30-10:30 10:30-11:00 11:00-11:30 11:30-13:30 13:30-14:00 14:00-17:30 17:30-18:00 18:00-18:15 18:15-19:00 19:00-21:30 21:30-21:45 21:45-22:30 22:30-01:00 01:00-04:00 04:00-04:15 04:15-04:30 04:30-06:00 06:00-08:00 08:00-09:00 09:00-10:30 Duration 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 2 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 1 hr 4-1/2 hr 1/2 hr 1-1/2 hr 10hr 6 hr 1 hr 8 hr 2-1/2 hr 1 hr 1/2 hr 3 hr 1 hr 2 hr 1 hr 1/2 hr 1 hr 1 hr 1/4 hr 1-1/4 hr 1-1/2 hr 1 hr 1/4 hr 3/4 hr 1 hr 1/2 hr 1/2 hr 2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/4 hr 3/4 hr 2-1/2 hr 1/4 hr 3/4 hr 2-1/2 hr 3 hr 1/4 hr 1/4 hr 1-1/2 hr 2 hr 1 hr 1-1/2 hr Activity Functioned Cement retainer Stung into Cement retainer Held safety meeting Tested High pressure lines Mixed and pumped slurry - 36.000 bbl Circulated at 9880.0 ft Pumped out of hole to 3600.0 ft Serviced Block line Pulled out of hole to 1700.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 7 R.I.H. to 7000.0 ft Serviced Top drive R.I.H. to 9600.0 ft Milled Casing at 9600.0 ft Repaired Top drive Repaired Top drive (cont...) ~ Milled Casing at 9650.0 ft Circulated at 9650.0 ft Pulled out of hole to 8700.0 ft Serviced Top drive Pulled out of hole to 2650.0 ft Circulated at 2650.0 ft Pulled out of hole to 300.0 ft Pulled BHA Functioned BOP stack Ran Drillpipe in stands to 2900.0 ft Serviced Block line Circulated at 2900.0 ft Ran Drillpipe in stands to 5400.0 ft Ran Drillpipe in stands to 9500.0 ft (cont...) Washed to 9689.0 ft Held safety meeting Batch mixed slurry - 40.000 bbl Displaced slurry - 144.000 bbl Pulled Drillpipe in stands to 8570.0 ft Circulated at 8570.0 ft Held 1725.0 psi pressure on 8.000 bbl squeezed cement Rigged down High pressure lines Pulled out of hole to 0.0 ft Functioned BOP stack Retrieved Wear bushing Installed BOP test plug assembly Tested All functions Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 8 Singled in drill pipe to 2520.0 ft R.I.H. to 3000.0 ft Tested M.W.D. tool - Via string R.I.H. to 5000.0 ft Singled in drill pipe to 9200.0 ft Tested Casing Rigged up Top drive Facility Date/Time 22 Feb 99 23 Feb 99 24 Feb 99 25 Feb 99 26 Feb 99 27 Feb 99 PB DS 09 Progress Report Well 09-23A Rig Nabors 7ES Page Date Duration Activity 10:30-11:30 11:30-14:30 14:30-15:30 15:30-19:30 19:30-06:00 06:00-12:00 12:00-13:30 13:30-14:30 14:30-16:30 16:30-18:30 18:30-19:30 19:30-20:00 20:00-20:15 20:15-21:00 21:00-21:30 21:30-02:30 02:30-03:00 03:00-06:00 06:00-07:00 07:00-08:00 08:00-11:30 11:30-13:00 13:00-14:00 14:00-17:30 17:30-18:00 18:00-22:30 22:30-23:00 23:00-06:00 06:00-07:00 07:00-07:30 07:30-09:00 09:00-09:30 09:30-14:30 14:30-15:00 15:00-06:00 06:00-08:00 08:00-10:00 10:00-11:00 11:00-13:00 13:00-21:30 21:30-23:00 23:00-06:00 06:00-16:30 16:30-18:00 18:00-19:00 19:00-20:30 20:30-21:30 21:30-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-13:00 13:00-15:00 15:00-01:30 1 hr 3 hr lhr 4 hr 10-1/2 hr 6 hr 1-1/2 hr 1 hr 2 hr 2 hr 1 hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 5 hr 1/2 hr 3 hr 1 hr 1 hr 3-1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 7 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 5 hr 1/2 hr 15hr 2 hr 2 hr 1 hr 2 hr 8-1/2 hr 1-1/2 hr 7 hr 10-1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 1 hr 8-1/2 hr 1/2 hr 3 hr 1/2 hr 3 hr 2 hr 10-1/2 hr Washed to 9598.0 ft Drilled cement to 9617.0 ft Repaired Top drive Drilled to 9670.0 ft Drilled to 10002.0 ft Drilled to 10383.0 ft (cont...) Pulled out of hole to 9550.0 ft R.I.H. to 10383.0 ft Drilled to 10540.0 ft Circulated at 10540.0 ft Drilled to 10644.0 ft Circulated at 10644.0 ft Flow check Pulled out of hole to 9500.0 ft Flow check Pulled out of hole to 0.0 ft Downloaded MWD tool Repaired Top drive Repaired Top drive (cont...) Made up BHA no. 9 Functioned M.W.D. tool Singled in drill pipe to 765.0 ft Serviced Block line R.I.H. to 10554.0 ft Reamed to 10644.0 ft Drilled to 11023.0 ft Serviced Mud pumps Drilled to 11591.0 ft Drilled to 11688.0 ft (cont...) Circulated at 11688.0 ft Pulled out of hole to 10547.0 ft R.I.H. to 11688.0 ft Drilled to 11985.0 ft Serviced Mud pumps Drilled to 12851.0 ft Drilled to 13003.0 ft (cont...) Circulated at 13003.0 ft Pulled out of hole to 11594.0 ft Singled in drill pipe to 13003.0 ft Drilled to 13468.0 ft Circulated at 13468.0 ft Drilled to 13830.0 ft Drilled to 14410.0 ft (cont...) Circulated at 14410.0 ft Pulled out of hole to 12995.0 ft Singled in drill pipe to 14410.0 ft Circulated at 14410.0 ft Drilled to 14803.0 ft Backreamed to 14788.0 ft Drilled to 14881.0 ft Serviced Mud pumps Drilled to 15071.0 ft Circulated at 15071.0 ft Drilled to 15559.0 ft 3 14 April 99 Facility Date/Time 28 Feb 99 01 Mar 99 02 Mar 99 03 Mar 99 04 Mar 99 05 Mar 99 PB DS 09 Progress Report Well 09-23A Rig Nabors 7ES Page Date Duration Activity 01:30-02:00 02:00-06:00 06:00-12:30 12:30-14:30 14:30-15:00 15:00-16:30 16:30-17:00 17:00-19:00 19:00-23:00 23:00-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-10:30 10:30-12:30 12:30-19:30 19:30-23:30 23:30-02:00 02:00-03:30 03:30-06:00 06:00-15:00 15:00-15:30 15:30-16:00 16:00-18:00 18:00-20:30 20:30-22:30 22:30-01:00 01:00-03:30 03:30-06:00 06:00-09:00 09:00-13:30 13:30-21:30 21:30-23:00 23:00-23:45 23:45-00:00 00:00-03:30 03:30-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-11:00 11:00-14:00 14:00-15:00 15:00-17:30 17:30-18:30 18:30-22:00 22:00-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-12:00 12:00-15:00 15:00-17:00 17:00-21:30 1/2 hr 4hr 6-1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 2 hr 4 hr 1 hr 1/2 hr 4 hr 1-1/2 hr 4-1/2 hr 2 hr 7 hr 4 hr 2-1/2 hr 1-1/2 hr 2-1/2 hr 9 hr 1/2 hr 1/2 hr 2 hr 2-1/2 hr 2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 3 hr 4-1/2 hr 8 hr 1-1/2 hr 3/4 hr 1/4 hr 3-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1 hr 4 hr 3 hr 1 hr 2-1/2 hr 1 hr 3-1/2 hr 8 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 3 hr 2 hr 4-1/2 hr Repaired High pressure lines Drilled to 15830.0 ft Drilled to 16185.0 ft (cont...) Circulated at 16185.0 ft Drilled to 16214.0 ft Circulated at 16214.0 ft Drilled to 16235.0 ft Circulated at 16235.0 ft Pulled out of hole to 9600.0 ft Serviced Block line Serviced Top drive R.I.H. to 16145.0 ft Circulated at 16235.0 ft Circulated at 16235.0 ft (cont...) Circulated at 16235.0 ft Pulled out of hole to 4375.0 ft Laid down 4170.0 ft of 5in OD drill pipe Pulled BHA Rigged up Casing handling equipment Ran Liner to 1500.0 ft (7in OD) Ran Liner to 6770.0 ft (7in OD) Rigged down Tubing handling equipment Circulated at 6770.0 ft Ran Liner in stands to 9600.0 ft Circulated at 9600.0 ft Ran Liner in stands to 12328.0 ft Circulated at 12433.0 ft Ran Liner to 14893.0 ft (7in OD) Circulated at 14893.0 ft Circulated at 15083.0 ft Ran Liner in stands to 16235.0 ft Circulated at 16235.0 ft Batch mixed slurry - 36.000 bbl Pumped Water spacers - volume 70.000 bbl Mixed and pumped slurry - 36.000 bbl Displaced slurry - 421.000 bbl Functioned Setting tools Circulated at 9466.0 ft Circulated at 9400.0 ft Circulated at 9400.0 ft Pulled Drillpipe in stands to 2340.0 ft Laid down 2340.0 ft of 5in OD drill pipe Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 10 R.I.H. to 9000.0 ft R.I.H. to 9540.0 ft Serviced Block line R.I.H. to 16152.0 ft Circulated at 16152.0 ft Drilled installed equipment - Landing collar Drilled to 16258.0 ft Circulated at 16273.0 ft 4 14 April 99 Facility Date/Time 06 Mar 99 07 Mar 99 08 Mar 99 09 Mar 99 10 Mar 99 11 Mar 99 12 Mar 99 13 Mar 99 14 Mar 99 Progress Report PB DS 09 Well 09-23A Page 5 Rig Nabors 7ES Date 14 April 99 21:30-22:30 22:30-03:00 03:00-04:00 04:00-05:30 06:00-18:30 18:30-06:00 06:00-06:00 06:00-10:00 10:00-13:30 13:30-18:00 18:00-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-06:00 06:00-06:30 06:30-14:30 14:30-17:00 17:00-19:30 19:30-00:30 00:30-06:00 06:00-07:00 07:00-08:00 08:00-09:30 09:30-03:30 03:30-05:30 05:30-06:00 06:00-06:00 06:00-10:00 10:00-14:00 14:00-15:30 15:30-16:30 16:30-17:00 17:00-18:30 18:30-19:30 19:30-23:30 23:30-00:30 00:30-02:00 02:00-06:00 06:00-07:30 07:30-08:00 08:00-12:00 12:00-13:30 13:30-14:30 14:30-16:00 16:00-17:00 17:00-20:30 20:30-21:00 21:00-21:30 21:30-06:00 06:00-07:00 07:00-09:30 09:30-10:30 10:30-16:30 Duration 1 hr 4-1/2 hr lhr 1-1/2 hr 12-1/2 hr 11-1/2 hr 24 hr 4 hr 3-1/2 hr 4-1/2 hr 3-1/2 hr 1 hr 1/2 hr 1 hr 6 hr 1/2 hr 8 hr 2-1/2 hr 2-1/2 hr 5 hr 5-1/2 hr 1 hr 1 hr 1-1/2 hr 18hr 2 hr 1/2 hr 24 hr 4 hr 4 hr 1-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1 hr 4 hr 1 hr 1-1/2 hr 4 hr 1-1/2 hr 1/2 hr 4 hr 1-1/2 hr 1 hr 1-1/2 hr 1 hr 3-1/2 hr 1/2 hr 1/2 hr 8-1/2 hr 1 hr 2-1/2 hr 1 hr 6 hr Activity Flow check Circulated at 16230.0 fl Investigated pressure change Flow check Circulated at 16230.0 ft Drilled to 16646.0 ft Drilled to 17407.0 ft Drilled to 17487.0 ft Circulated at 17487.0 ft Logged hole with LWD: DIR/FE from 17467.0 ft to 16204.0 ft Circulated at 17487.0 ft Pulled out of hole to 16131.0 ft Flow check Investigated pressure change Pulled out of hole to 9600.0 ft Flow check Laid down 5360.0 ft of 4in OD drill pipe Pulled BHA Made up BHA no. 11 R.I.H. to 5360.0 ft R.I.H. to 15500.0 ft Serviced Block line R.I.H. to 16900.0 ft Reamed to 17487.0 ft Drilled to 17688.0 ft Circulated at 17688.0 ft Drilled to 17698.0 ft Drilled to 17964.0 ft Drilled to 18000.0 ft Circulated at 18000.0 ft Logged hole with LWD: DIR/FE from 18000.0 ft to 17376.0 ft Pulled out of hole to 16141.0 ft Serviced Top drive Serviced Block line R.I.H. to 18000.0 ft Circulated at 18000.0 ft Circulated at 18000.0 ft Pulled out of hole to 12600.0 ft Laid down 2100.0 ft of 5in OD drill pipe Laid down 2700.0 ft of 5in OD drill pipe (cont...) Circulated at 9300.0 ft Pulled out of hole to 1230.0 ft Laid down 1023.0 ft of 4in OD drill pipe Downloaded MWD tool Pulled BHA Rigged up Casing handling equipment Ran Liner to 1925.0 ft (4-1/2in OD) Rigged down Casing handling equipment Circulated at 1925.0 ft Ran Liner on landing string to 14500.0 ft Ran Liner on landing string to 16150.0 ft (cont...) Circulated at 16150.0 ft Ran Liner on landing string to 18000.0 ft Circulated at 18000.0 ft Facility Date/Time 15 Mar 99 16 Mar 99 17 Mar 99 18 Mar 99 19 Mar 99 Progress Report PB DS 09 Well 09-23A Page 6 Rig Nabors 7ES Date 14 April 99 16:30-16:45 16:45-17:30 17:30-18:15 18:15-18:45 18:45-20:00 20:00-00:00 00:00-00:30 00:30-06:00 06:00-08:00 08:00-08:30 08:30-11:30 11:30-12:00 12:00-16:00 16:00-17:00 17:00-18:00 18:00-18:45 18:45-01:00 01:00-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-08:30 08:30-09:00 09:00-09:30 09:30-10:00 10:00-12:30 1,2:30-13:30 13:30-18:00 18:00-18:30 18:30-19:30 19:30-02:00 02:00-02:30 02:30-04:00 04:00-06:00 06:00-09:00 09:00-09:30 09:30-11:30 11:30-12:00 12:00-06:00 06:00-12:00 12:00-14:00 14:00-14:30 14:30-18:00 18:00-20:30 20:30-21:00 21:00-23:30 23:30-00:00 00:00-00:30 00:30-01:30 01:30-03:00 03:00-05:00 05:00-06:00 06:00-07:00 07:00-09:30 Duration 1/4 hr 3/4 hr 3/4 hr 1/2 hr 1-1/4 hr 4 hr 1/2 hr 5-1/2 hr 2 hr 1/2 hr 3 hr 1/2 hr 4 hr 1 hr 1 hr 3/4 hr 6-1/4 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1 hr 4-1/2 hr 1/2 hr 1 hr 6-1./2 hr 1/2 hr 1-1/2 hr 2 hr 3 hr 1/2 hr 2 hr 1/2 hr 18hr 6 hr 2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1 hr 1-1/2 hr 2 hr 1 hr 1 hr 2-1/2 hr Activity Held safety meeting Mixed and pumped slurry - 50.000 bbl Displaced slurry - 243.000 bbl Functioned Other sub-surface equipment Circulated at 16049.0 ft Circulated at 16049.0 ft Tested Liner Pulled Drillpipe in stands to 4000.0 ft Pulled Drillpipe in stands to 0.0 ft (cont...) Removed Wear bushing Tested BOP stack Installed Wear bushing Installed TCP guns Ran Drillpipe to 1640.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Retrievable packer Singled in drill pipe to 2663.0 ft Ran Drillpipe in stands to 15764.0 ft Functioned Other sub-surface equipment Ran Drillpipe in stands to 1.7900.0 ft Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations (cont...) Rigged down Wireline units Rigged up High pressure lines Perforated Reverse circulated at 15915.0 ft Functioned Perforating tools Laid down 6150.0 ft of 5in OD drill pipe Serviced Top drive Serviced Block line Laid down 9330.0 ft of 4in OD drill pipe Rigged down sub-surface equipment - Perforating tools Laid down 308.0 ft of 2-7/8in OD drill pipe Retrieved Gun assembly Retrieved Gun assembly Retrieved B ore protector Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 13000.0 ft (4-1/2in OD) Ran Tubing to 16064.0 ft (4-1/2in OD) Space out tubulars Ran Tubing on landing string to 16064.0 ft Reverse circulated at 16064.0 ft Set Production packer at 16009.0 ft with 0.0 psi Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Tested Tubing Tested Casing Installed Hanger plug Rigged down BOP stack Installed Xmas tree Retrieved Hanger plug Tested Xmas tree Rigged up High pressure lines Facility Date/Time Progress Report PB DS 09 Well 09-23A Rig Nabors 7ES Page Date 09:30-11:00 11:00-12:00 12:00-12:30 12:30-13:30 Duration 1-1/2 hr 1 hr 1/2 hr 1 hr Activity Reverse circulated at 4758.0 ft Displace treatment Installed Hanger plug Functioned All tree valves 7 14 April 99 Ill:IICI--lNG SEFI~/I I-- ~ S 24-Mar-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 9-23A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,594.42' MD 9,600.00' MD 18,000.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) REC ~,,¢!AR ?_ 6 1999 Alaska Oil & Gas Cons. Commission ~omge 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_EOA DS 09, Slot 09-23 09-23 (R)- 9-23A Job No. AKMM90081, Surveyed: 12 March, 1999 ORIGINAL SURVEY REPORT RECEIVED 23 March, 1999 Your Reft API-500292106601 Surface Coordinates: 5941533.36 N, 718768.22 E (70° 14' 34.1400" N, 148° 13' 58.5502" W) Kelly Bushing: 49.42ft above Mean Sea Level ~,AAR 2. 6 1999 Al~Oii&GasCons.~n 13RI L I~1N Eii SERVICES; SurveyRef:svy8423 Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Ref: AP1-$00292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 9594.42 9600.00 96o5.00 9623.03 9659.84 9688.40 9720.74 9755.12 9786.84 9815.32 9847.88 9879.03 9911.o7 10007.36 10100.83 10196.95 10291.76 10387.48 lO485.12 lO579.31 10668.77 10766.78 10860.02 10953.40 11046.73 53.620 53.541 53.470 53.840 56.11o 57.580 59.730 61.65o 63.350 65.61o 67.200 68.860 68.670 68.11o 70.660 70.880 69.820 69.860 69.450 69.270 69.320 69.090 69.11o 7o.11o 70.470 Azim. lO2.7oo lO2.7o5 lO2.71o lO3.34o lO4.6oo lO5.53o lO6.55o lO7.59o lO8.53o lO7.79o lO9.43o lO8.46o lO8.72o lO8.41o lO8.63o lO8.O5O lO6.62o lO6.95o lO6.65o lO6.44o lO4.O2O lO3.83o lO3.77o lO6.29o lO6.95o Sub-Sea Depth (ft) 6569.68 6572.99 6575.97 6586.65 6607.78 6623.40 6640.22 6657.05 6671.70 6683.97 6697.00 6708.65 6720.26 6755.72 6788.63 6820.28 6852.17 6885.16 6919.10 6952.31 6983.94 7018.73 7052.00 7084.54 7116.01 Vertical Depth (ft) 6619.10 6622.41 6625.39 6636.07 6657.20 6672.82 6689.64 6706.47 6721.12 6733.39 6746.42 6758.07 6769.68 6805.14 6838.05 6869.70 6901.59 6934.58 6968.52 7001.73 7033.36 7068.15 7101.42 7133.96 7165.43 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1040.22 S 6160.34E 5940672.37 N 724956.15 E 1041.21S 6164.72 E 5940671.51N 724960.56 E 1042.09 S 6168.64 E 5940670.74 N 724964.50 E 1045.36 $ 6182.79 E 5940667.88 N 724978.74 E 1052.64S 6212.03 E 5940661.45 N 725008.19 E 1058.86 S 6235.12 E 5940655.91N 725031.44E 1066.49 S 6261.66 E 5940649.04N 725058.20 E 1075.30 S 6290.32 E 5940641.08 N 725087.09 E 1084.02 S 6317.07 E 5940633.13 N 725114.08 E 1092.03 S 6341.49 E 5940625.84N 725138.73 E 1101.55 S 6369.76 E 5940617.14 N 725167.27 E 1110.93 S 6397.08 E 5940608.56 N 725194.85 E 1120.45 $ 6425.39 E 5940599.86 N 725223.42 E 1148.95 S 6510.25 E 5940573.84N 725309.07 E 1176.74 S 6593.20 E 5940548.47N 725392.79 E 1205.30 S 6679.35 E 5940522.42 N 725479.73 E 1231.90 S 6764.57E 5940498.30 N 725565.70 E 1257.85 S 6850.60 E 5940474.86 N 725652.44E 1284.31S 6938.24 E 5940450.96 N 725740.81 E 1309.41 $ 7022.74 E 5940428.32 N 725826.00 E 1331.39 S 7103.47E 5940408.69 N 725907.34 E 1353.44S 7192.41E 5940389.23 N 725996.87 E 1374.22 S 7277.00 E 5940370.92 N 726082.03 E 1396.92 S 7361.52 E 5940350.68N 726167.18 E 1422.05 S 7445.71 E 5940328.00 N 726252.06 E Alaska State Plane Zone 4 PBU_EOA DS O9 Dogleg Rate (°/100fi) Vertical Section (ft) Comment 1.42o 1.42o 3.483 6.774 5.824 7.173 6.176 5.969 8.275 6.719 6.061 o.961 0.854 2.737 o.614 1.808 0.326 0.509 0.283 2.531 0.297 0.064 2.747 0.769 6234.62 6239.11 6243.13 6257.65 6287.79 6311.69 6339.28 6369.19 6397.22 6422.83 6452.53 6481.28 6511.o2 66oo.15 6687.27 6777.67 6866.73 6956.41 7047.79 7135.79 7219.41 7311.03 7398.13 7485.61 7573.32 Tie-On Survey Window Point Continued... 23 March, 1999 - 9:45 - 2- DrillQuest Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Ref: API-500292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 11146.19 11240.72 11336.17 11431.66 11527.97 11620.44 11715.68 11808.72 11900.80 11993.54 12089.31 12182.74 12277.07 12372.25 12465.17 12559.46 12655.20 12748.39 12842.26 12937.28 13029.95 13124.08 13218.66 13310.30 13401.25 71.070 70.550 70.340 71.410 71.190 71.030 70.74O 70.270 69.960 70.840 71.800 71.500 71.430 71.240 71.010 70.770 70.570 70.390 69.990 69.510 69.270 69.170 70.070 69.780 69.440 Azim. lO6.79o lO6.95o lO7.55o lO8.35o lO8.79o lO8.27o lO8.1oo lO8.130 lO7.48o lO8.56o lO9.61o lO9.5oo lO8.33o lO8.11o lO7.92o lO7.78o lO7.91o lO7.O9O lO6.99o lO6.58o lO7.43o lO6.61o lO7.87o lO7.5oo lO7.16o Sub-Sea Depth (ft) 7148.77 7179.84 7211.79 7243.O8 7273.95 7303.89 7335.08 7366.13 7397.45 7428.56 7459.23 7488.65 7518.63 7549.09 7579.15 7610.02 7641.71 7672.85 7704.67 7737.55 7770.17 7803.57 7836.51 7867.96 7899.65 Vertical Depth (ft) 7198.19 7229.26 7261.21 7292.50 7323.37 7353.31 7384.50 7415.55 7446.87 7477.98 7508.65 7538.07 7568.05 7598.51 7628.57 7659.44 7691.13 7722.27 7754.09 7786.97 7819.59 7852.99 7885.93 7917.38 7949.07 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1449.31 $ 7535.58 E 5940303.37N 726342.68 E 1475.21S 7621.01 E 5940279.95 N 726428.84 E 1501.89 $ 7706.91 E 5940255.78 N 726515.47E 1529.69 S 7792.74 E 5940230.48N 726602.07 E 1558.74 S 7879.21 E 5940203.95 N 726689.35 E 1586.55 $ 7962.17 E 5940178.56 N 726773.08 E 1614.63 S 8047.66 E 5940152.97 N 726859.35 E 1641.90 S 8131.02 E 5940128.13 N 726943.46 E 1668.38 S 8213.46 E 5940104.06 N 727026.64E 1695.41S 8296.54E 5940079.45 N 727110.47 E 1725.07 S 8382.28 E 5940052.29 N 727197.03 E 1754.76 $ 8465.84 E 5940025.05 N 727281.42 E 1783.75 S 8550.44E 5939998.52 N 727366.83 E 1811.94 $ 8636.10 E 5939972.82 N 727453.26 E 1839.13 S 8719.71E 5939948.07 N 727537.63 E 1866.44S 8804.52 E 5939923.23 N 727623.19 E 1894.13 S 8890.51E 5939898.06 N 727709.96 E 1920.54 S 8974.28 E 5939874.09 N 727794.46 E 1946.42 S 9058.72 E 5939850.67 N 727879.61 E 1972.16 S 9144.07 E 5939827.41 N 727965.67 E 1997.53 S 9227.01E 5939804.46 N 728049.32 E 2023.29 $ 9311.16 E 5939781.16 N 728134.18 E 2049.57 S 9395.84E 5939757.35 N 728219.58 E 2075.72 S 9477.84 E 5939733.59 N 728302.31 E 2101.11 $ 9559.22 E 5939710.57 N 728384.39 E Alaska State Plane Zone 4 PBU_EOA DS 09 Dogleg Vertical Rate Section (°/lOOff) (ft) Comment 0.622 7667.05 0.573 7756.15 0.632 7845.87 1.372 7935.79 0.489 8026.63 0.559 8113.75 0.348 82o3.41 0.506 8290.80 0.744 8377.12 1.450 8464.18 1.443 8554.44 0.340 8642.58 1.178 8731.58 0.296 8821.42 o.314 8909.04 o.291 8997.85 0.245 9087.91 0.852 9175.5o 0.438 9263.62 0.647 9352.60 0.897 9439.16 0.821 9526.97 1.57o 9615.42 0.494 97Ol.23 0.512 9786.27 Continued... 23 March, 1999 - 9:45 - 3 - DrlllQueat Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Reft API-500292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 13498.67 13591.00 13682.74 13777.48 13870.42 13964.13 14060.76 14154.17 14250.30 14343.52 14451.76 14544.44 14640.91 14738.58 14825.42 14925.11 15018.63 15110.18 15205.30 15298.04 15390.20 15488.77 15577.20 15675.97 15770.33 69.350 69.290 68.940 68.800 69.010 68.790 68.480 67.990 67.710 67.630 67.460 67.720 69.300 68.880 68.310 68.740 68.270 68.160 69.040 68.840 68.150 67.500 67.630 68.820 68.390 Azim. 106.880 106.780 108.620 107.990 107.100 107.140 106.480 107.100 106.720 106.310 106.080 106.250 107.400 107.090 106.790 108.380 107.970 107.760 108.420 108.300 108.690 107.830 107.880 108.600 108.630 Sub-Sea Depth (ft) 7933.94 7966.54 7999.25 8033.40 8066.85 8100.59 8135.79 8170.43 8206.67 8242.09 8283.43 8318.77 8354.11 8388.97 8420.66 8457.16 8491.42 8525.40 8560.11 8593.43 8627.22 8664.42 8698.17 8734.81 8769.23 Vertical Depth (ft) 7983.36 8015.96 8048.67 8082.82 8116.27 8150.01 8185.21 8219.85 8256.09 8291.51 8332.85 8368.19 8403.53 8438.39 8470.08 8506.58 8540.84 8574.82 8609.53 8642.85 8676.64 8713.84 8747.59 8784.23 8818.65 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2127.8o s 9646.41 E 5939686.42N 728472.32 E 2152.81S 9729.10 E 5939663.82 N 728555.69 E 2178.87 S 9810.75 E 5939640.14 N 728638.07 E 2206.62 S 9894.64E 5939614.83 N 728722.74 E 2232.76 S 9977.32 E 5939591.11 N 728806.14 E 2258.50 S 10060.87 E 5939567.81N 728890.40 E 2284.52 $ 10147.02 E 5939544.29 N 728977.26 E 2309.58 S 10230.07 E 5939521.65 N 729061.01 E 2335.48 S 10315.26 E 5939498.24 N 729146.91E 2359.99 $ 10397.93 E 5939476.14 N 729230.26 E 2387.89 $ 10493.99 E 5939451.04 N 729327.09 E 2411.75 $ 10576.28 E 5939429.58 N 729410.04 E 2437.73 $ 10662.20 E 5939406.10 N 729496.67 E 2464.78 $ 10749.33 E 5939381.59 N 729584.56 E 2488.34 S 10826.68 E 5939360.29 N 729662.55 E 2516.37 S 10915.11E 5939334.84 N 729751.76 E 2543.51S 10997.78 E 5939310.11N 729835.18 E 2569.59 S 11078.69 E 5939286.39 N 729916.82 E 2597.09 S 11162.87 E 5939261.34 N 730001.76 E 2624.35 $ 11245.01 E 5939236.48N 730084.66 E 2651.55 S 11326.33 E 5939211.65 N 730166.73 E 2680.15 S 11413.01E 5939185.58 N 730254.21 E 2705.21S 11490.81 E 5939162.78 N 730332.70 E 2733.92 S 11577.92 E 5939136.61N 730420.61 E 2761.97 $ 11661.18 E 5939111.00 N 730504.65 E Alaska State Plane Zone 4 PBU_EOA DS 09 Dogleg Vertical Rate Section (°/lOOft) (fl:) Comment 0.284 9877.26 o.12o 9963.48 1.912 10048.93 0.638 10136.96 0.922 10223.43 0.238 10310.66 o.712 10400.47 0.809 10487.06 0.468 10575.92 o.416 lO662.Ol 0.251 lO761.91 0.328 10847.48 1.978 10937.07 0.522 11028.08 o.731 11108.77 1.546 11201.27 0.647 11287.97 0.245 11372.71 1.128 11460.95 0.247 11547.16 0.846 11632.54 1.o43 11723.48 o.156 11804.95 1.382 11896.33 0.457 11983.80 Continued... 23 March, 1999 - 9:45 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Reft API-500292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 15865.00 15960.44 16056.20 16144.27 16273.57 16302.08 16333.24 16366.28 16398.76 16429.77 16461.39 16497.13 16527.94 16557.36 16590.83 16623.00 16653.77 16683.26 16714.52 16746.31 16777.25 16806.99 16840.94 16874.55 16906.47 68.160 69.300 70.030 69.740 71.050 75.200 81.590 88.640 92.370 92.520 92.460 88.990 88.770 86.510 85.320 83.580 84.110 84.950 84.970 84.880 85.050 84.480 84.010 83.830 83.890 Azim. lO8.53o lO6.87o lO6.63o lO6.69o lO8.85o lO9.48o lO8.67o lO8.15o lO5.O2O lO4.24o lO2.96o lOO.81o lOO.OlO 97.440 90.690 87.530 81.53o '78.040 77.220 78.1oo 78.990 81.41o 82.900 84.080 85.030 Sub-Sea Depth (ft) 8804.27 8838.90 8872.17 8902.46 8945.85 8954.13 8960.39 8963.20 8962.92 8961.59 8960.22 8959.77 8960.37 8961.58 8963.97 8967.08 8970.38 8973.19 8975.94 8978.75 8981.47 8984.18 8987.59 8991.15 8994.56 Vertical Depth (ft) 8853.69 8888.32 8921.59 8951.88 8995.27 9003.55 9009.81 9012.62 9012.34 9011.01 9009.54 9009.19 9009.79 9011.00 9013.39 9016.50 9019.80 9022.61 9025.36 9028.17 9030.89 9033.60 9037.01 9040.57 9043.98 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2789.99 S 11744.54E 5939085.41N 730588.79 E 2817.02 $ 11829.27 E 5939060.84 N 730674.26 E 2842.90 S 11915.25 E 5939037.47 N 730760.96 E 2866.61 S 11994.48E 5939016.07 N 730840.84 E 2903.79 $ 12110.46 E 5938982.27 N 730957.85 E 2912.74 S 12136.22 E 5938974.07 N 730983.86 E 2922.71 $ 12165.05 E 5938964.94 N 731012.97 E 2933.10 S 12196.27 E 5938955.46 N 731044.47 E 2942.37 $ 12227.39 E 5938947.10 N 731075.85 E 2950.19 $ 12257.36 E 5938940.15 N 731106.04 E 2957.62 $ 12288.07 E 5938933.62 N 731136.95 E 2964.98 $ 12323.03 E 5938927.28 N 731172.11 E 2970.55 $ 12353.33 E 5938922.59 N 731202.55 E 2975.00 $ 12382.38 E 5938918.98 N 731231.72 E 2977.37 S 12415.66 E 5938917.58 N 731265.06 E 2976.87 S 12447.67 E 5938919.00 N 731297.04 E 2973.96 S 12478.11E 5938922.80 N 731327.38 E 2968.75 S 12506.99 E 5938928.84N 731356.10 E 2962.08 S 12537.41E 5938936.39 N 731386.31E 2955.32 S 12568.34E 5938944.06 N 731417.04 E 2949.19 S 12598.55 E 5938951.05 N 731447.05 E 2944.15 $ 12627.73 E 5938956.94 N 731476.08 E 2939.54 $ 12661.19 E 5938962.52 N 731509.39 E 2935.75 S 12694.40 E 5938967.27 N 731542.47 E 2932.74 S 12725.99 E 5938971.19 N 731573.96 E Alaska State Plane Zone 4 PBU_EOA DS 09 Dogleg Rate (°/100ft) Vertical Section (ft) Comment 0.262 2.o13 0.798 0.335 1.872 14.7o9 20.664 21.395 14.99o 2.559 4.048 11.421 2.693 11.627 20.427 11.173 19.454 12.12o 2.614 2.772 2.918 8.327 4.581 3.532 2.965 12071.37 12160.04 12249.66 12332.22 12453.63 12480.77 12511.12 12543.88 12576.30 12607.27 12638.86 12674.58 12705.34 12734.64 12767.58 12798.62 12827.58 12854.50 12882.57 12911.12 12939.12 12966.36 12997.87 13029.32 13059.38 Con#hued... 23 March, 1999 - 9:45 - 5- DrillQuest Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Ref: API-500292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 16940.86 16973.74 17oo4.2o 17035.75 17066.57 17096.43 17128.36 17160.67 17192.31 17223.79 17255.18 17286.67 17319.12 17351.8o 17378.58 17413.52 17442.58 17476.78 175o6.51 17536.15 17565.58 17594.46 17627.27 17662.12 17691.16 84.46o 87.14o 89.17o 92.71o 93.11o 93.330 91.o8o 9o.15o 9o.18o 91.o2o 91.57o 91.72o 92.310 93.200 93.630 91.94o 91.85o 92.220 92.530 92.19o 91.29o 90.920 9o.18o 89.230 87.540 Azim. 85.240 86.040 87.1oo 89.060 87.840 87.400 86.800 88.13o 89.31o 89.230 89.520 89.740 9o.11o 90.520 90.290 89.880 89.050 90.250 88.970 89.330 88.360 88.450 88.200 87.440 87.620 Sub-Sea Depth (ft) 8998.05 9000.46 9001.44 9000.92 8999.36 8997.68 8996.45 8996.10 8996.01 8995.68 8994.97 8994.07 8992.93 8991.36 8989.76 8988.07 8987.10 8985.89 8984.66 8983.44 8982.54 8981.99 8981.67 8981.85 8982.67 Vertical Depth (ft) 9047.47 9049.88 9050.86 9050.34 9048.78 9047.10 9045.87 9045.52 9045.43 9045.10 9044.39 9043.49 9042.35 9040.78 9039.18 9037.49 9036.52 9035.31 9034.08 9032.86 9031.96 9031.41 9031.09 9031.27 9032.09 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2929.84 S 12760.08 E 5938975.08 N 731607.95 E 2927.35 S 12792.77E 5938978.52 N 731640.56 E 2925.53 S 12823.16 E 5938981.23 N 731670.88 E 2924.47S 12854.68 E 5938983.20 N 731702.36 E 2923.64 S 12885.45 E 5938984.92 N 731733.09 E 2922.40 S 12915.24 E 5938987.03 N 731762.83 E 2920.79 S 12947.10 E 5938989.56 N 731794.63 E 2919.36 S 12979.38 E 5938991.93 N 731826.85 E 2918.65 S 13011.01E 5938993.55 N 731858.45 E 2918.25 $ 13042.48 E 5938994.87 N 731889.90 E 2917.91S 13073.86 E 5938996.12 N 731921.26 E 2917.70 S 13105.34E 5938997.24 N 731952.72 E 2917.66 S 13137.77E 5938998.22 N 731985.13 E 2917.84 $ 13170.41 E 5938998.99 N 732017.76 E 2918.03 S 13197.14 E 5938999.58 N 732044.49 E 2918.08 S 13232.04 E 5939000.54 N 732079.37 E 2917.81S 13261.08 E 5939001.65 N 732108.40 E 2917.60 S 13295.26 E 5939002.85 N 732142.55 E 2917.40 $ 13324.96 E 5939003.92 N 732172.24 E 2916.96 S 13354.57 E 5939005.21N 732201.82 E 2916.37 S 13383.98 E 5939006.66 N 732231.20 E 2915.56 $ 13412.85 E 5939008.30 N 732260.03 E 2914.60 S 13445.64 E 5939010.21N 732292.78 E 2913.28 S 13480.46 E 5939012.55 N 732327.55 E 2912.03 S 13509.47E 5939014.64 N 732356.51E Alaska State Plane Zone 4 PBU_EOA DS O9 Dogleg Vertical Rate Section (°/100fi) (fi) Comment 1.765 13091.89 8.504 13123.14 7.518 13152.30 12.824 13182.74 4.161 13212.49 1.645 13241.20 7.293 13271.84 5.023 13302.93 3.731 13333.55 2.681 13364.09 1.981 13394.56 0.845 13425.15 2.146 13456.70 2.998 13488.51 1.820 13514.57 4.977 13548.55 2.871 13576.76 3.670 13609.97 4.426 13638.84 1.670 13667.56 4.495 13696.04 1.318 13723.95 2.381 13755.65 3.491 13789.24 5.852 13817.18 Continued... 23 March, 1999 - 9:45 - 6- DrlllQuest Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Ref: AP1-500292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 17721.20 85.630 88.900 8984.46 9033.88 2911.12 S 13539.44 E 5939016.42 N 732386.44 E 17752.41 84.450 89.710 8987.16 9036.58 2910.74 $ 13570.53 E 5939017.70 N 732417.50 E 17786.59 85.690 91.340 8990.10 9039.52 2911.05 S 13604.58 E 5939018.38 N 732451.55 E 17820.92 89.420 91.810 8991.56 9040.98 2911.99 S 13638.86 E 5939018.43 N 732485.84 E 17851.54 90.370 92.420 8991.62 9041.04 2913.12 S 13669.45 E 5939018.19 N 732516.46 E 17879.58 90.400 92.520 8991.43 9040.85 2914.33 S 13697.47 E 5939017.79 N 732544.50 E 17912.95 88.950 92.030 8991.62 9041.04 2915.66 $ 13730.81 E 5939017.44 N 732577.86 E 17943.78 88.310 91.760 8992.35 9041.77 2916.68 S 13761.61 E 5939017.31 N 732608.68 E 18000.00 88.310 91.760 8994.01 9043.43 2918.40 S 13817.78 E 5939017.22 N 732664.88 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.980° (12-Mar-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 103.270° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 18000.00ft., The Bottom Hole Displacement is 14122.61ft., in the Direction of 101.926° (True). Alaska State Plane Zone 4 PBU_EOA DS 09 Dogleg Rate (°/lOOff) Vertical Section (ft) Comment 7.650 4.580 5.978 lO.951 3.687 0.372 4.587 2.253 0.00o 13846.14 13876.31 13909.53 13943.11 13973.15 14000.69 14033.45 14063.66 14118.73 Projected Survey Continued... 23 March, 1999 - 9:45 - 7- DrlllQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for 09-23 (R) - 9-23A Your Ref: AP1-$00292106601 Job No. AKMM90081, Surveyed: 12 March, 1999 Alaska State Plane Zone 4 PBU_EOA DS O9 Comments Measured Depth (fi) 9594.42 9600.00 18000.00 Station Coordinates TVD Nodhings Eastings (~) (~) (~) 6619.1o lO4O.22 s 616o.34 E 6622.41 1041.21S 6164.72 E 9043.43 2918.40 S 13817.78 E Comment Tie-On Survey Window Point Projected Survey 23 March, 1999 - 9:45 - 8 - DrillQuest TONY KNOWLE$, GOVEFINOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 3, 1999 Dan Stone Engineering Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudfhoe Bav Unit 09-23A ARCO Alaska Inc. Permit No: 98-44 Sur Loc: 55'NSL, 349'EWL, Sec. 01, T10N, R15E, UM Btmhole Loc. 2372'NSL, 1010'WEL, Sec. 08, T10N, R16E, UM Dear Mr. Stone: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in-bottem-bole location. The provisions of the original approved permit dated March 117 1999, are in effect for this r ' ' Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures CC; Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASK,&{..~ ,b AND GAS CONSERVATION COI{v..:IISSION PERMIT TO DRILL 20 AAC 25.005 Revised: 01/12/99 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entn/ [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RKB = 49.02' Prudhoe Bay Field / Prudhoe 3. 'Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028345 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 55' NSL, 349' EWL, SEC. 01, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2440' NSL, 3222' WEL, SEC. 08, T10N, R16E, UM 09-23A At total depth 9. Approximate spud date Amount $200,000.00 2372' NSL, 1010' WEL, SEC. 08, T1 ON, R1 CE, UM 02/14/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028344, 1010'I DS 09-46 is 391' at 9607' MD 2560 18416' MD / 9049' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9600' Maximum Hole Angle 89° Maximum surface 2331 psig, At total depth (TVD) 8937' / 3225 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quant..it¥ of Cement Hole Ca~'i'~g 'Weight Grade Coupling Length MD TVD MD TVD (include stage datai ' 8-1/2" 7" 26# L-80 BTC-M 6740' 9450' 6535' 16190' 8966' 156 sx Class 'G' "6" 4-1/2" 12.6# L-80 IB:T"-"M ......... 2376' 16040' 894'8';'' 18416' 9049' 105 sx Class 'G'" ......... . 19. To be completed for Redrill, Re-entry, and Deepen Operations. l\ I~'~ ~,. ~ ' "' - Present well condition summary Total depth: measured 16397 feet Plugs (measured)1999 true vertical 8976 feet Effective depth: measured feet Junk (measured) true vertical feet ~.$~8. Oi~ & GaS (~ons, Anchorage Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 1860# Poleset 80' 80' Surface 2669' 13-3/8" 3600 sx CS III, 400 sx CS II 2700' 2525' Intermediate Production 11250' 9-5/8" 500 sx Class 'G', 300 sx CS I 11281' 7759' Liner 7806' 7" Not Cemented (stuck) 4983' - 12789' 3941' - 8298' Perforation depth: measured NoneORIGINAL true vertical None 201"Aiiachments [] Filing Fee B prOPertY Plat [] BOP Sketch ..... 'r;q DiVerter Sketch [] 'Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ... Contact Engineer Name/Number: C. Michael Jackson, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed -,,~. ~.-.,~.~ Engineering Supervisor Date ....... Dan Stone Title Commission Use Only Permit Number APl Number I Approval Date ] See cover letter 98-44 / 39s-1 2 s0-029-210 -01I .3,-//-- ?¢I forother requirements Conditions of Approval: Samples Required [~Yes ,~No Mud Log Required []Yes'~No Hydrogen Sulfide Measures~Yes ' [] No Directional S_ur/~ey Required '"~Yes/[] No Required Working Pressure for BOPE 1--12K; []3K; []~rK;) F-15K; I--I10K~ I--115K Other: Original Signed 87 by order of Approved By iBavid W. Johnston Commissioner the commission Date ~" Form 10-401 Rev. 12-01-85 Submit In Triplicate DATE J I C,ECKNO. VENDOR ALASKAST 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 1111~8 CI41111~8 100. O0 100. O0 HANDLIN~ INST: s/hI terrie hubble x4&28 N~0it & Gas Cons. Co~ ~ssior, AnchomBe ~ o~.m~ ~. ~ t OO. OO ~ OO. OO THE A~AC~D CHECK IS IN PAYME~ 'FitaST NATI~i~L.BANK :bF ASHLAND ~)N~:~rr~.~*,hK :::i::~::i~:i ::~:'-'":'~: :C~ND, ~HIO .~.:: ':' :". :' ::"~: '~-' ' ':~:.;':56-389': .'" . .: 412 NO. ':H ,:-.:.!:4 5 7 8.2 I CONs~ID~:ED .c°MMERcIAL ^CCOUNT ] '00143782: "',. I~ PAY oNE!i!HU~DRED:: &:::i:::~0./1.***************************************: US DOLLAR :": :AMOUNT .T.°':' The . ::::"ALASKA STATE.i~:DEP:T.::::.'QF REVE~..-.E ::':~: ::;:: :": '~:::: ..... ~::' NQT::VALID A~ER 120 DAYS: ... : . '-: :':O~da~";:~:: .~::z::~OO,:?~PDRCUP,NE?:D,.' :~?. ::-.:..:::: "?':~:'"::::':"~: ::~:~: ~ ~ ~:~ j~~'~~'' ANCHORAOE AK 99501-3120 a 008 L, L, I, q,' a red l' rvices rilling Alaska ~ BP Exploration / ARCO Alaska Inc. To: Blair Wondzell - AOGCC Date: January 12, 1999 From: C. Michael Jackson Subject: Reference: DS 9-23A Sidetrack Operations Form 10-401 Attachment Permit to Drill #98-44, APl #50-029-21066-01 Nabors 7ES is expected to move on DS 9-23A in mid to late February following the completion of the V-200 appraisal well. This memo is written as an attachment to form 10-401 for the re-start of sidetrack operations on DS 9-23A(API #50-029-21066-01). Operations are expected to follow previously approved Permit to Drill #98-44 subsequent to revised directional plan Wp11. Original Sidetrack Well 9-23A was a side-track out of the 9-5/8" casing into the cretaceous shale interval. A whipstock side- track was conducted at 12,370' and a kick off assembly RIH to kick off high side. Attempts to kick off at 12,370' MD failed and subsequently the open hole was cemented back up to 500 ft above the window. A second whipstock side-track was conducted and the well kicked off successfully at 11,281 '. An 8-1/2" hole was directionally drilled with a 10.3 ppg LSND to a depth of 16,397' ( 8,975' TVD) into the top of the Sadlerochit Zone 2 formation. The 7" liner was run through the window at 11,281' and became stuck at 12,789'. Circulation was attempted and achieved 1.7 BPM @ 1260 psi. The casing was stuck and finally the hole packed off with the top of liner @ 4,983', shoe @ 12,789' MD. Wellbore Abandonment Operations A free point on the stuck 7" casing will be obtained and as much casing retrieved as possible. A cement retainer will be placed on top of the remaining 7" casing and cement equivalent to 500' of 8.5" open hole will attempted to be squeezed under the retainer. It is our desire to retrieve the 7" casing and expose the open wellbore but this may not be the case. The wellbore was drilled through the Coleville Marine shales and has probably collapsed making a cement squeeze unlikely. C. Michael Jackson Operations Drilling Engineer 564-5486 Wk 275-1544 Pgr 349-1383 H m I Well Name: IDS 9-23A Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location' 55 FSL, 4930 FEL, Sec 1, T10N, R15E Target Location: 2440 FSL, 3222 FEL, Sec 8, T10N, R16E Bottom Hole Location' 2372 FSL, 1010 FEL, Sec 8, T10N, R16E I AFENumber: 14J0374 I Estimated Start Date: 12/14/99 I TVD=19049'1 I Rig: I Nabors 7ES I Operating days to complete: 130 I BE/USE= 120.52' I IRKS' 149.02' I Well Design (conventional, slimhole, etc.): I Horizontal sidetrack Objective: An un-penetrated Tango / Romeo target interval bounded by the Lower Cretaceous Unconformity(LCU) truncation and by either the base of the Sadlerochit or the HOT. Mud Program: Intermediate Mud Properties: LSND 8.5" hole section I Density (ppg) Funnel vis Yield Point 10 sec gel 10 min gel pH Fluid Loss 10.5-11.0 45-50 12-15 4-8 8-12 9-10 6-9 Production Mud Properties: Quickdril-n 16" hole section Density (ppg)Funnel vis LSRV LSR YP pH 8.6 - 8.8 45-65 >45,000 cP 10-20 8.5-9.0 Directional: KOP: 19600' MD Maximum Hole Angle: Close Approach Well' 89 16,900' MD(9035' TVD) DS 9-46 is 391' well-to-well at 9607' Logging Program: Intermediate Production Hole(Horizontal) IDrilling: Open Hole: Drilling: Open Hole: MWD / G R None MWD / GR / Resistivity None DS 9-23A Permit to Drill Formation Markers: Formation Tops MD TVDss Comments Cretaceous 9600' 6573' Kickoff Point K 5 14,197' 8207' K 2 15,597' 8700' Zone 2B 16,190' 8917' 7" Shoe Zone 1 16816' 8985' Target Kavik 9025' Not Penetrated Casing/Tubing Program: Hole- Csg/- Wt/[=t Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 8.5" 7" 26# L-80 BTC-M 6740' 9450'/6535' 16,190'/8 966' 6" 4 1/2" 12.6# L-80 IBT-M 2376' 16,040'/8948' 18,416'/9049' Tubing 4 1/2" 12.6# 13Cr-80 NSCC 16,040' 0/0 16,040'/8948' Note: The 4.5" production liner will be a Bonzai style completion with the solid cemented liner covering Zone 2(Tango) and the un-cemented slotted liner covering Zone 1(Romeo). Cement Calculations: Abandonment Plug I Cased / Open hole I Basis: Based on 500' of 8.5" open hole volume below the whipstock window at 11,281' TOC: At 11,180' md(7687' TVD, 7637' TVDss) Total Cement Volume: Tail 32 bbl/180 f¢ / 181 sks of Halliburton Premium 'G' at 17 ppg and 0.99 cf/sk. Kickoff Plug I Cased/Open hole I Basis: Based on 200' of 9-5/8" casing volume above the section, 50' of 12-1/4" milled section and 100' of 9-5/8" casing below the section. TOC: At -3700' md(3580' TVD, 3513' TVDss) Total Cement Volume: Tail 32 bbl/180 ft~ / 181 sks of Halliburton Premium 'G' at 17 ppg and 0.99 cf/sk. Liner Size 17" Intermediate I Basis: Lead: None Tail: Based on 80' shoe track and 1000' of open hole with 30% excess. Tail TOC: At 15,190' md(8607' TVD, 8558' TVDss). I Total Cement Volume'I No,e I Tail [32bbl/179f¢/156skofHalliburtonPremium'G'at 15.8 ppg and 1.15 cf/sk. Liner Size 14 1/2" Production I Basis: I Tail: Based on a solid cemented section covering 650' of Zone 2 with 50% I excess, 150' of liner lap and 200' of drill pipe by casing annulus. T°talCementV°lume: ITail 122bbl/124f¢/105sk°fHalliburt°nPremium'G'at15.8ppgand1.18cf/sk. DS 9-23A Permit to Drill Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: 3225 psi @ 8937' TVDss - Zone 2 · Maximum surface pressure: 2331 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies HYDROGEN SULFIDE - H2S Drill Site 9 is designated as an H2S drill site. The highest level of H2S measured on Drill Site 9 has been 642 ppm from DS 9-05A on 3/12/97 and the most recent recording of 258 ppm on well DS 9-49 ON 1/14/98. Standard Operating Procedures for H2S precautions should be followed at all times. DRILLING CLOSE APPROACH: Well DS 9-46 is 391' center-to-center to the planned DS 9-23A for directional plan Wp11 at 9607'. INTERMEDIATE SECTION: · The Kingak shale is truncated on Drill Site 9 and will not be drilled. · The kick tolerance for the 8.5" open hole section would be 40 bbls assuming an influx at 16,190' TD. This is a worst case scenario based on a 7.9 ppg pore pressure gradient and a fracture gradient of 9.0 ppg with a 11.0 ppg mud in the hole. PRODUCTION SECTION: · Stuck pipe has not been recorded in the production interval but differential sticking will be a problem if loss circulation is occurring. With 8.5 ppg seawater the hydrostatic expected overbalance will be 725 psi. · The kick tolerance for the 7" shoe would be an infinite influx(annular volume) assuming an influx at the 18,416' TD. This is a worst case scenario based on a 7.2 ppg pore pressure and a minimum fracture gradient of 10.0 ppg with a 8.5 ppg mud in the hole. Disposal · No annular injection in this well. DS 9-23A Permit to Drill Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Rig Work: 1. Test 9-5/8" packoff. Cycle LDS. Report packoff test results to Cps Drlg Engineer. Ri.q Operations: 1. MIRU Nabors 7ES. ND tree, NU and test BOPE. Circulate freeze protection from well via the 5" drill pipe currently hanging in the well at ~2,065' MD. POOH with the 5" DP. Note: Ensure new RKB measurements are utilized in determining all MD's. DS 9- 23A ground elevation is 29' MSL; Nabors 22-E elevation was 21'; RKB to MSL was 50'. 2. RIH and retrieve the HES Model III Retrievable bridge plug from ,-.4,765' MD. , RIH and latch the top of the 7" liner (the liner hanger/packer assembly has not been set). RU free point, RIH and identify the deepest free point in the 7" liner. Cut the liner and recover as much as possible from the wellbore as possible. 4. Close the blind rams and establish an injection rate. RIH with an 8.5" cement retainer on drill pipe and set 100' above the whipstock window at 11,281' 6. Sting into the cement retainer and pump 32 barrels, equivalent to 500' of 8.5" hole, of 15.8# cement to plug the open wellbore. 7. RIH with a 8.5" bridge plug on e-line and set at 9900'. 8. Run in with a Baker section mill and spot an 18 ppg pill covering from 9900' to 9600'. Mill a 50' section from 9600' to 9650'. 9. RIH open ended to 9750' and cement the 50' section covering from 100' below the bottom cut to 200' above the top cut at 9600'. DS 9-23A Permit to Drill 10. Drill out of section and drill to 7" drilling liner depth at approximately 16,190' MD. Short trip and condition the hole for 7" liner. Pre-treat interval with lubricants to reduce drag. POOH. 11. Run and cement a 7" drilling liner. 7" liner top (inside 9-5/8" casing) planned for 9450' MD to cover previously identified Cretaceous leak. 12. Test casing, drill out, perform FIT, displace to DRILn mud system and directionally drill 6" horizontal target in Zone 2 and Zone 1 sands. Real time MWD resistivity is required (no open hole DPC logs). TD is planned for 18,416' MD. Note: Although no faults are anticipated in the target polygon, there is geologic structural risk of running out of pay sands (the LCU truncates the entire Ivishak formation near the east end of the wellbore). 13. Run and cement a 4-1/2" solid x slotted "Bonzai" production liner. 14. Run 4-1/2", 13Cr tubing completion. 4-1/2", 13Cr tubing should be stung into the top of the 4-1/2" production liner. 15. ND BOPE, NU and test tree. Freeze protect. RDMO. Estimated Pre-rig Start Date: 2/14/99 Estimated Spud Date: 2/14/99 * The spud date may be accelerated which will be dependent on the V-200 appraisal well status. C. Michael Jackson 564-5486 1/11/98 DS 9-23A Permit to Drill Well: 09-23 Spud Date:02-14-84 OriginalRKBE:55' Top of Formation: 12877' AnnularFluid:Diesel/8.5SW ReferenceLog:BHCS ARCO Alaska, Inc. - Prudhoe API #:50-029-21066-00 Completion 11-19-88 HangerType:FMC Gen III Max Hole Angle:59° G MD: 8300' Date:03-04-84 Tie In: Ann. Comm: Leak in 13-3/8" @ 780' (01/31/94); Sqz'd 13-3/8" Leak 06/04/94 ALL DEPTHS ARE RKB DRILLING MD TO TOP OF EQUIPMENT EXCEPT SSSV = CAT #2 ~e~e~rv (~) SSSV = CAT#2 ' Depth DescriDtion Csg leak @ 780'; Sqz'd O6/O4/94 J-1 1 2228 3 12506 4 12507 5 12529 6 12617 7 12629 8 12630 12616 10 13117 5-1/2" Camco BAL-O SSSV Nipple ID=4.562" 5-1/2" TIW Seal Assembly ID=4.875" 9-5/8" x 5-1/2" TIW HBBP-L Packer Crossover 5-1/2" x 4-1/2" 4-1/2" Otis XN Nipple ID=3.725" 4-1/2" TIW Shearout Sub 4-1/2" Tubing Tail ELM Tubing Tail (Logged 05/15/91) FISH: IBP Element (Lost 05/24/94) G-1 Min ID: 4-1/2" Otis XN NiDple ID=3.725" Type :PRODUCER Status :Workover Hanger :29 ' Angle G TS:44° Angle G TD:42° Date: 00-00-00 WHERE NOTED. 3-3,4 3-5 Casing and Tubing (C) Size Weight Grade 1 13-3/8" 725 L-80 Leak @ 780' Sqz 06/04/94 2 9-5/8" 47% L-80 3 7" 295 L-80 5-1/2" 17% L-80 4-1/2" 12.6% L-80 Top Bottom DescriDtion 0' 2700' BTC Casing 0' 12567' 0' 12529' 12858' BTC Casing 13270' BTC Liner 12529' BTC-MOD Tubing-PC 12630' BTC-MOD Tubing-PC MD J-6 3435 J-7,8 6874 8673 C-2 9373 9861 Sand Tagge¢ 10309 @ 12744' 10760 08/30/95 11168 11617 12024 12348 P-1 J-lO Gas Lift Information (G) TVD Stn Mandrel (3007 (5107 (6109 (6495 (6786 (7088 (7397 (7681 (7998 (8294 (8536 ) 1 CA-MMG ) 2 CA-MMG ) 3 CA-MMG ) 4 CA-MMG ) 5 CA-MMG ) 6 CA-MMG ) 7 CA-MMG ) 8 CA-MMG ) 9 CA-MMG ) 10 CA-MMG ) 11 CA-MMG Valve Type Latch CA R-20 RK CA RDO-20 RK CA RD RK CA RD RK CA RD RK CA RD RK CA RD RK CA RD RK CA RD RK CA RKED RKP Perforation Data (ELM DEPTHS) Interval Zone FT SPF 1 12827-12842 2 15 4 12858-12878 2 20 4 12891-12901 2 10 4 12909-12929 2 20 4 12943-12968 2 25 4 12982-13035 lB 53 4 (P) Date Comments 05-17-91 APERF 05-04-85 IPERF 05-04-85 IPERF 05-04-85 IPERF 05-04-85 IPERF 05-04-85 IPERF Port 1/4" 7/16" TRO Date 1795 01-17-95 ORIF 04-29-95 06-15-92 04-29-95 03-27-94 C-3 Datum 8700' SS=12646' MD 8800' SS=12784' MD PBTD=13141' TD=13270' Revision Date: 07-16-96 by ENH Reason: SSSV = CAT%2 Previous Reason: 09-11-95 DS 9-23 Adandonment 13-3/8", 72#, L-8O Top of 7" liner 12,5 ppg EMW Cast~ag teak Milled window @ 1'1~28i' md /'758' TVD) FormatioJ~JZt;~ K-5 K-2 / HRZ LCU / 2B 12,605' md(8257' TVD) 14,649' md(8700' TVD) 16,316' md(8967' TVD) 12,370' MD Base LCU Top Zone 2B Plugged & abandonded 8.5" wellbore Nabors 22E 4/9/98 -- 9-5/8" 47# L-80 ~ We[[bore Sqz'd Perforations: 12,827' - 13,035' 11,281' to 11,490' 45~ 1t,490' to 1t,943' Build 8°/100' to 76° 11,943' to 15,218' 15,218' to 16,397' Build 2° ll00'to 84° DATE ~ 1/12198 ! CMJ I PBTD ~ 7" 29# L-80 ~ COMMENTS Abandon Condition PRUDHOE BAY UNIT WELL: 9~23A APl NO: 50~029~21066-01 SEC 1; TION; R15E Arco Alaska ~nc DS 9-23A sed Completion Nipple @ 2200' 13-3/8", 72#, L-80 ~ -- ~ 7", 26# L-80 BTC-N~od Liner Top Bridge Plug DS 9-23A Horizontal SidetracJ~ AFE ~tJ0374 29 Days $5,383 APl #50-029-2t 066-0t Zone 1 & 2 Production Target 7" L-80 intermediate Casing to Zone 2 4-1/2" L-80 'Bonzai' Liner 4-t/2" t3Cr-80 NSCC Completion Designed for future CTU sidetrack -- 4-1/2", 12.6~, 13Cr-80 NSCC Tubing 7" x 4.5" Baker Packer ~ ~4.5" Bonzai Liner Top 4-1/2", t2,6# L-80 IBT-Mod 'Bonzai' Production Liner 7" 26# L-80 BTC-Mod Shoe (~ TSag PBTD ~ 7" 26# L-80 ~ DATE REV. BY ceremENTS PRUD} 1112198 ClVIJ Proposed Completion WEL APl NO: SEC 1 ARC(: IBAY UNIT DS 9-23A 50-029-21066-01 ; T10N; R15E A~aska Shared Services Drilling Well: 9-23A Wp11 I DrillQuestTM Proposal Data for 09-23A Wp11 Vertical Orig~n: Well Horizontal O~gi~: Well Measurement Units: Nort~ Reference: True Nort~ Dogleg severity: Degrees per 1001t Ver'~cal Seclkm Azimuth: 103_269° Vertical Se~ion De~c~ptJon,-Welt vertical Sec'lion O~jin: 0.00 N.0.00 ~zeasure~ I.~ ~ verticat No~h~n~ ~as~j.~ Ve~d Do~ 9600.00 53.537 102'/06 6622.25 1041.211 $ 6 t65.03 E 6239.44 9640.00 57_537 102.306 6644.88 1048.53 R 6t97.20 E 6272.41 10.000 97~.44 69._386107.493 6715.13 1085.44 S 6332.80 F_. 6412.87 8.000 16100.83 69.386 107.493 8966.112 2884.19 S 12040. t2 F_. 12380.68 O J)00 16230.83 0__386 107.493 8980.10 2~J5.45 $ 12075.83 E 12418.02 0.000 16462.97 8:8.51686.748 9024.86 2~22.05 S 12299.72 E12642.03 12000 16816.8~ 88.516 116.'/489034.02 290L98 $ 12652.87 E 12981.15 16902~1 89.489 91.7~8 9035.51 29~0~90 S IZ738.YZ E130~.26 6.000 18416.99 89.48I)91.'/98 9049.02 2<248.4:2 $ 14252.19 E 14.548_440.000 SURFACE LOCATION I PLOT DATE: 06-,JAN-g9 RKBElewafion: 28.5011 Rig(EST) I ' ~'- ~o,s~ a wea (CEE) I _ 4e. a21t l~[S-.Nv~LJC, heckedBy: C00~mate~: Zo~e4. USF~ lAPPn:~d Y: NAD27 ~laska Stale Ptanes I PROPOSAL TARGET SUMMARY Tm*gel Name: TVDSS T~DRK13:.We~hea6 Offsets: GJoba/C<~.r~ne~s: 9-23A ~.CU Peoa~a~ 8917.00 8966.02 2884.1g S, 12040.12 E 5939000.00 N, 730~7.00 E ~-23A I. ar~aag Pt 8~85J00 ~34.a2Zg01~ge S. 12652.8'/E 5~391X10.00 N, 731500.00 E !~3AID ~00.0091)49.02 2948.42 $. 14252.19 E DRAFT COPY FOR PLANNING PURPOSES . ONLY 7000 8000 I I I I I ! I I I I 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 Scale: I inch -- 1000ft Vertical Section Section Azimuth: 103.269° (True North) Shared Services Drilling I DrillQuest' Well: 9-23A Wp 11 Proposal Data for 09-23A Wp11 Verfica~ Orig~: We{I [ Hodzo~al Origin: Well / Measurement Units: It Nortfl Refereoce: True Norl~ Dogleg severity: Degrees ~ l(30ff VedJcal ~ Azimulh: 103269° Verljcal Seclh~ Descr~p~io~Ne~ VerUCa{ Sec~on Origin: 0.00 N,0.00 E Measured ~ Azim. Ve~JcaI Noahings Eastings Ve~dca~ Dogleg ~00.00 53.537 102.706 9610.1)0 .5'/.537 10L706 ~'97.44 6~..~6 107.4~ 6'/15.13 16190.83 69.386 107.493 8966.02 16~30.83 6~.386 102.493 8980.10 16462.97 88516 ~6.748 9ff24.86 16S16.81 88.516 86.748 9034.02 16902_51 89.489 91.798 9035.51 1~16.99 89.489 91.798 9049.02 1041.28 S 6165.03 E 6239.44 1048.53 S 6197,20 E (~,~2.41 10.000 1085.44 S 633230 E 6412.87 $-000 2S84.19 S 12040.12 EI2380.6~ 0.000 2895.45 S 12075.83 E12418.02 0.000 2922J)5 S 12299.72 E12642.03 12.000 2901.98 S 12652.~7 £12981.1~ 0.000 2900.90 S 12'/38.52 E 130~4-26 6.000 2948_42 S 14252, I9 E 14548.44 0.000 SURFACE LOCATION Horizonlal Coordinates: 5941533~54 N. 718768.24 E RKB FJevmio~: 28.50fl Rig (EST} 2o.52 fl Weft (CSE) 49_O2 ft RKB - AMS£ Coordinate Syste~: NAD27 Ateska State Pla~, Zone 4, US FoOt PLOT DATE: 06-JAN-9~ Checked By: Ii,. PROPOSAL TARGET SUMMARY rgel N~ne: TVDSS 'rVDF~ Welh ~ed O~sel= TVDSS '[r'VDi°~B: Welheed Ck~ets: 5939000.00 N, 730~7.00 E 8~5.00 9034.022~01J)8 S, 12652.87 E 593g000.00 N, TJ1500.00 E 9(X)0.00 904~.022948.42 S, 14252.19 E 5~90~0.00 N, 733100.00 E ~ -3000 -- 7038.17 ,, 00-23A we1 ~,~e2 MD · ~84,19 ~, 1.~.12 E 90~t.~2 FVD ~ ~D I I I I I I I I 6000 7000 8000 ~ 10000 11000 12000 13~0 14000 Reference is Tree North Sc~e: linch = 1000~ Eastings - -3000 .) Prudhoe Bay Unit Measured Sub-Sea Vertical Depth incl. Azim. Depth Deplh (It) (ft) (It) 9600.00 53.537' 102.706 65'/3.23 6622.25 9640.00 57.537 102,706 6595-86 6644.88 9700.00 62.033 104,651 6b'26.05 6675.07 9797.44 69.386 107.493 6~66.11 6715.13 9800.00 69.31~6 107.493 6667.01 6716.03 9900.00 69.366 107.403 6702.22. b"/51.24 '[0000.00 69.386 107,493 6737.43 6786.45 10100.00 69,386 107.493 6772.63 6821.65 10200.00 69.386 107.493 6807-84 6856.138 1030O.00 89.386 107.493 6843.05 8592.07 .[0400.00 69.386 107.493 6878.25 6827.27 10500.00 69.386 107.493 6913.46 68o'2.48 10800.00 69~'z86 107.493 6948.b"7 6997.69 10700.00 69.386 107.493 6983.87 70~2.89 10800.00 69.386 107,4 93 7019.08 7068.10 10900.00 69,386 107.493 7054.28 7103.30 11~J0.00 69.386 I07.493 7089.49 7138,.51 11100.00 09.3H6 107.403 7124.70 7173.72 1 '[200J30 69.306 107,493 7159-90 7208.92 11300.00 69.366 107.493 7195.11 '7244.13 11400,0{) 69~ 107.493 7230.32: 7279.34 11500.01) 69.386 107,493 7265.52 7314.54 1'[600.00 69.385 107.493 7300.73 7349.75 11700.00 69.386 107,493 7335.94 7384.95 11800.00 69.386 107.493 7371.14 7~20.16 Sperry-Sun Drilling Services Proposal Report for 09-23A N7ES Wps - 09-23A Wp11 Local Coordinates Global Coordinates Notthings Eastings Norlhirtgs Eastings (11) (ft) ~) (It) 1041.26 S 6165.03 E 5940671.62 N 724960.89 E 1048.53 S 6197.20 E 5940665.31 N 724993.26 E 1060.81 S 6247.55 E 5940654.50 N 725043.05 E 1085-4-4- S 6332.80 E 5940632.35 N 725129.88 £ 1086.16 S 6335.09 E 5940631.70 N 725132.19 E 1114.29 S 6424.36 E 59406rJ6.17 N 725222.24 E 1142.43 S &513.63 E 5940580.64 N 725312.28 E '[170.56 S 6602.90 E 5940555.10 N 725402.~3 E 1198.70 S 6692.17 E 5940529.b-'7 N 725492.38 E 127_6-83 S 6781.44 E 5940504.04 N 725582.43 E 1254.97 S 6870.71 I: 5040478.51 N 725§72`47 E 1283,10 S 6059.08 E 5940452.98 N 725762.52 E 1311~33S 7049~_4 E 5940427.4.5 N 725852.57 E 1339.37 S 7138.51 E 5940401~91 N 725042.62 E 1367.50 S 7227.78 E 5040376~38 N 726032.67 E 1305.64 S 7317.05 E 5940350.85 N 726122.71 E 1423.77 S 7405.32 E 5940325.32 N 728212-7§ E 1451.91 S 7495.59 E 5940299.79 N 726302.81 E 1460.04 S 7584.86 E 5940274.25 N 726392.86 E '[508.18 S 7674.13 E 5940248.72 N 726482-91 E 1536.31 S 7763.40 E 5940223.19 N 726572,95 E 1564.45 S 7852.67 E 5940197.66 N 7266133.00 E 1592..58 S 7941-93 E 5940172.13 N 72b'753.05 E f620.71 S 8031.20 E 5940146.59 N 726843.10 E 1648.85 S 8120.47 E 5940121.05 N 726933.15 E Dogleg Vertical Rate Section [°/~0~} (ft) b'239.44 10.000 6272`41 8.000 632/L24 8.000 6412.87 0.000 6415.26 O.00,3 6508.61 O-900 6601.95 0.00O 6695.29 O.OOD 68~1,98 0.000 6975.32 0.000 706~.67 O,ODD 7162.01 0-900 7255.35 0.000 7348.71) 0,000 7442,04 0.000 7535,38 0.000 7628.73 0.000 7722.07 0,000 7815.41 0.000 7908.76 0.000 8002.10 O,OOD 8095.44 0.000 8188.79 0.000 8282.13 Comment Alaska State Plane Zone 4 PBU_EOA DS 09 DRAFT COPY FOR PLANNIttG PURPOSES O I[Y Con#nuedo.. Dr/I/Quest 7 January, 1990 - 10'57 o 1 - Sperry-Sun Drilling Services Proposal Report for 09-23A N7ES Wps - 09-23A Wp11 Alaska State Plane Zone 4 PBU_EOA DS O9 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Deplh Northings Easlings Northings Eastings Rate Section Comment (fl) (ft) (fl) (ft) (ft) (fl) {fl) (o/lOOfl) (ft} 11900.00 69,386 107.493 7406.35 7455.37 1676.98 S 8209.74 E 5940095.53 Iq 727023.19 E 0.009 8375.47 12~.00 69.366 107.493 7441.56 74~0-58 1705.12 S 8299.01 £ 5940070.00 N 727-[13~.4 E 0,000 8468.62 12100.00 59.366 107.493 7476.76 7525,78 1733.25 S 8388.28 E 59413044.47 N 727203.29 E 0.000 8562.-[6 12200.00 69.386 ! 07.493 7511.97 7560.99 1761.39 S 6477-55 E 5940018.94 N 72~293.34 E 12300.00 69.386 107.493 7547.18 7596.20 1789.52 S 8566.82 E 5939993.40 N 727353.39 E 12400.00 69.31~ 107.493 756238 7631.40 1817.66 S 8656.09 E 5939967.87 N 727473.43 E 12500.00 69.38~ 107.4~ 7617.5~ 7556.61 1845.79 S 8745.35 E 5939942.34 N 72756~48 E 12600.00 69.386 107.493 7652.79 7701.81 -[873.93 S 81~34.62 E 5939916.81 N 7Z7653.53 E 12700.00 69.386 107.493 7688.00 7737.0Z 1902.06 S 8923.89 E 5939891.28 N 727743.56 E -[2800.00 69.386 107.493 7723,2.1 7772.23 1930.20 S 9013.16 F_ 5939865.74 N 727833.62 E 1290~).00 69.386 107.493 7758.41 7807.43 1958.3,3 S 910243 E 593.q840.2~ N 727923.67 E 13000.00 69.386 107.493 7793.62 7842.64 1986.46 S 9191.70 E 5939814.68 N 728013.72 E 0.000 ~402.25 13100.00 69.386 107.493 7828.83 7877.85 2014.60 S 9280.97 E 5939789.15 N 728103.77 E 0.0{30 9495.59 -[3200,00 69.386 107.493 7864.03 7913.05 2042.73 S 9370.?.4 E 5939763.62 N 7281~3.82 E 0.000 9588.94 13300,01) 69,386 107.493 7899.24 7948.26 2070,87 S 9459~51 E 5g39736.08 N 7:28283.86 E 0.000 968P-28 13400.00 69;385 107.493 7934.45 7963.47 20g9.00 S 9548.78 E 5939712,55 N 728373.91 E 0.000 9775.62 13500.00 69.,386 107.493 7969.65 8018.67 2127.14 S 9638J3¢ E 5939687,02 N 7284~3.~6 E 0.000 9868.97 f3600.00 69.386 107.493 8004.86 8053.88 215527 S 9727.31 E 5939661.49 N 728554.01 E 0.0DO 9962.31 13700,00 69.386 107.493 8040.07 8089,09 2183.41 S 9816.58 E 5939535.96 Iq 728644.08 E 0.O00 10055.65 13800.00 69.366 107.493 6075.27 6124.29 2211.54 S 9905.85 E 5939810.42 N 728734.10 E 0.1300 10149.00 13900.00 69J.'.'.'386 107.493 8110.48 8159-50 2239.68 S 9995.12 E 5939584.89 N 7281~24..15 E 0.000 '[0242.34 14000.00 69.386 107.493 8145.66 8194.70 2267.81 S 10084.39 E 5939559.36 N 7L~914~.0 E 0.000 10335.68 14100,00 69.386 107.493 8180.89 8229.91 2295.94 S 10173.66 E 5939533.83 N 729004.25 E 0.000 10429.03 14200.00 69.386 107.493 62~6.10 6265.12 2324.08 S 10282.93 E 5939508.30 N 72g094.~ E 0.00O 10522.37 14300.00 69.366 107.493 8251.30 8300.32 2352~1 S 10352.20 E 5939482.77 N 729184.34 £ 0,000 10615.71 14400.00 69.386 107.493 8286.5~ 8335.53 2380.35 S 10441.47 E 5939457.23 iq 729274.39 E 0.000 10709.06 14500,00 69.386 107.493 8321.72 8370.74 2408.48 S 10530.73 E 5939431.70 N 729364.44 E 0.000 10802.40 14600.00 69.385 107.4~r~3 8356.92 8405~4 2436.62 S 10620.00 E 5939406.17 N 729454.49 E 0.00O IO895.74 147130.00 69.365 1137.493 8392.13 8441.15 2464.75 S 10709.27 E 5939380.84 N 729544.54 E 0.0D0 10969.09 14800.00 59.366 ~07.493 8427.:34 8476.36 2492.89 S 10798.54 E 5939355.11 N 729634.56 EE 0.0013 11082.43 Continued,.. DriliQues! -2- 7January, 1959 - 10:57 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (.) (ft) 14900.00 69.386 107.493 8462__54 8511.56 15000.00 69.386 107.493 8497.75 8546.77 15100.00 69.386 107.493 8532.96 8581.98 15200.00 69.386 107.493 8568.16 8617.18 15300.00 69.386 107.493 8603.37 8652.39 15400.00 59.386 107.493 8638.58 8687.60 15500.00 69.386 107.493 8673.78 8722-80 15600.00 69.386 107.493 8708.99 8758.01 15700.00 69.386 107.493 8744.19 8793.21 15800.00 69.386 107.493 8779.40 8828.42 15900.00' 69.386 107.493 8814.61 8863.63 16000.00 69.386 107.493 8849.81 8898.83 16100.00 69.386 107.493 8885.02 8934.04 16190.83 69.386 107.493 8917.00 8966.02 16199,35 69.386 107.493 8920.00 8969.02 16200.00 69.386 107.493 8920.23 8969.25 16230~3 69.386 107.493 8931.08 8980.10 16291.38 74.217 101.778 8950.00 8999.02 16300.00 74.917 100.988 8952.29 9001.31 16400.00 83.205 92.140 8971.29 9020.31 16462.97 88.516 86.748 8975.84 9024.86 16500.00 88.516 86.748 8976.80 9025.82 16600.00 88.516 86.748 8979.39 9028.41 16700.00 88.516 86.748 8981.98 9031.00 16800.00 88.516 86.748 8984.56 9033.58- 15816.81 88.516 86.748 8985.00 9034.02 16900.00 89.460 91.650 8986.47 9035.49 16902.51 89.489 91.798 8986.49 9035.51 17000.00 89.489 91.798 8987.36 9036.38 17100.00 89.489 91.798 8988.25 9037_27 Sperry-Sun Drilling Services Proposal Report for 09-23A N7ES Wps - 09-23A Wp11 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings EasUngs Rate (~) (ft) (ft) (ft) (~OOft) 2521.02 S 10887~1 E 5939329.57 N 729724.63 E 0.000 2549.16 S 10977.08 E 5939304.04 N 729814.68 E 0.080 2577-29 S 11066.35 E 5939278.51 N 729904.73 E 0.000 2605.42 S 11155.62 E 5939252.98 N 729994.77 E 0.000 2633.56 S 11244.89 E 5939227.45 N 730084.82 E 0.000 Alaska State Plane Zone 4 PBU_EOA DS 09 2661.69 S 11334.16 E 5939201.91 N 730174.87 E 0.000 2689.83 S 11423.42 E 5939176.38 N 730254.92 E 0.O00 2717.96 S 11512.69 E 5939150.85 N 730354.97 E 0.000 2746.10 S 11601.96 E 5939125.32 N 730445.01 E 0.000 2774-23 S 11691 ~3 E 5939099.79 N 730535.06 E 0.000 11642.49 11735.83 11829.18 11922-52 12015.86 2802;37 S 11780.50 E 5939074-26 N 730625.11 E 0.000 2830-50 S 11869.77 E 593.9048.72 N 730715.16 E 0.000 2858.64 S 11959.04 E 5939023.19 N 730805.21 E 0.000 2884.19 S 12040.12 E 5939000.00 N 730887.00 E 0.000 2886.59 S 12047.73 E 5938997.82 N 730894.67 E 0.000 12109.21 12202_55 12295.89 12380.58 12388.63 BLCU/-17-2B Target: 9-23A BLCU Penetrate, Geological 7' Liner 2886.77 S 12048.31 E 5938997.66 N 730895~5 E 0.000 2895.45 S 12075.83 E 5938989.79 N 730923.02 E 0.000 2909.93 S 12131.45 E 5938976.92 N 730979,93 E 12.000 2911.57 S 12139.60 E 5938975.52 N 730997.22 E 12.000 2922.66 S 12236.96 E 5938967.26 N 731094.87 E 12.000 1238924 12418.02 12475.47 12483.78 12581.09 2922.05 S 12299.72 E 5938969.70 N 731147.59 E 12.000 2919.95 S 12336.67 E 5938972.87 N 731184.46 E 0.000 291428 S 12436.48 E 5938981.43 N 731294.06 E 0.000 2908.61 S 12536.28 E 5938990.00 N 731363.66 E 0.000 2902.94 S 12636.09 E 5938998.56 N 731483.26 E 0.000 12642-03 12677.52 12773.36 1286920 12965.04 2901.98 S 12652.87 E 5939000.00 N 731500.00 E 0.000 2900.82 S 12736.01 E 5939003.57 N 731583.07 E 6.000 2900.90 S 12738.52 E 5939003.57 N 731585.58 E 6.000 2<J03.96 S 12835.96 E 5939003.34 N 731683.07 E 0.000 2907.09 S 12935.90 E 5939003.11 N 731783.07 E 0.000 12981.15 13061.80 1306426 13159.80 13257.80 Target: 9-23A Landing Pt, GeologicaJ Continued... 7 January, 1999 - 10:57 - 3 - DrifIQuest Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) 17200.00 89.489 91.798 8989.15 9038.17 17300.00 89.489 91.798 8990.64 9039.06 17400.00 89.489 91.798 8990.93 9039.95 17500.00 89.489 91.798 8991.82 9040.84 17600.00 89.489 91.798 8992.71 9641.73 17700.00 89.489 91.798 8993.61 9042.63 17800.00 89.489 91.798 8994.50 9043.52 17900.00 89.489 91.798 8995.39 9044.41 18000.00 89.489 91.798 8996.28 9045.30 18100.00 89.489 91.798 8997.17 9046.19 18200.00 89.489 91.798 8998.06 9047.08 19300.00 89.489 91.796 8998.96 9047.98 18400.00 89.489 91.798 8999.85 9048.87 18416.99 89.489 91.798 ~;K}00.00 9049.02 Sperry-Sun Drilling Services Proposal Report for 09-23A N7ES Wps - L~o; ,=a,.l~Co 0 rd, _nat _e~. Global Coordinates Dog,~ Venice, 2910~ S 1~5.85 E 5~02.87 N ~18~.~ E 0.~ 1~.80 2913.37 S 13~.80 E 593~ N 7319~.~ E 0.000 1~.~ 2916.51 S 13235.74 E 5939002.40 N 732083.05 E 0.000 13551.80 2919.64 S 13335.69 E 593.9002.16 N 7:32183.05 E 0.000 13649.80 2922.78 S 13435.64 E 5939001.93 N 732283.64 E 0.000 13747.80 2925.92 S 13535.58 E 5939001.69 N 732383.64 E 0.000 13845.79 2929.06 S 13635.53 E 5939001.45 N 732483.04 E 0.000 13943.79 2932~.0 S 13735.48 E 5939001.22 N 732583.03 E 0.000 14041.79 2935~3 S 13835.42 E 59390{30.98 N 732683.03 E 0.{)00 14139.79 2938.47 S 13935.37 E 5939000.75 N 732783.02 E 0.000 14237.79 2941.61 S 14035.32 E 5939000.51 N 732883.02 E 0.000 14335.79 2944.75 S 14135.2.6 E 5939000.28 N 732983.01 E 0.000 14433.79 2947.89 S 14235.21 E 5939000.04 N 733083.01 E 0.000 14.531.78 2948.42 S 14252.19 E 5939000.00 N 733100.00 E 0.000 14548.44 4 1/2' Uner Target: 9-23A 'iD. Geological Ail data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 0.000° (07-Jan-99) The Dogleg Sevedty is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 103.269° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 18416.99ft., The Bottom Hole Displacement is 14553.97ft., in the Direction of 101.688° (True). Alaska State Plane Zone 4 PBU_EOA DS 09 .) Con#nued... DrillQuest 7 January, 1999 - 10:57 - 4 - Alaska hared erv,ces rilling WELL NAME DS 9-23A DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT [~ Permit Documentation Prepared: ODE: ~~~'-~~ Permit Applicatio~'Reviewed: SDEmS: Permit~plic(~on ~jtted: ['--I SUNDRY NOTICE ~'] Sundry Documentation Prepared: ODE: Date: -']Sundry Application Reviewed: SDE/ES: Date: D Sundry Application Submitted: TA: Date: NOTE: SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW D PRE-RIG WORK Reason for Sundry (Check all that apply) [~ Pre-Rig Memo Reviewed: Abandon SDE/ES: Date: Alter Casing ~'] Pre-Rig Memo Sent to Slope: Suspend ODE: Date:~ Repair Well ['~ Pre-Rig Sundry Documentation Prepared: Plugging ODE: Date:~ 'Pull Tubing [--'l Pre-Rig Sundry Application Reviewed: Variance SDE/ES' Date:~ Other(Explain): ~i Pre-Rig Sundry Application Submitted: TA: Date:~ Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate APPROVAL TO PROCEED I Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: '(~ STATE OF ALASKA 'b{' ALASKA ,~AND GAS CONSERVATION CO ~w~ISSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Re-Enter Ops S/D Well 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 55' NSL, 349' EWL, SEC. 01, T10N, R15E, UM At top of productive interval N/A At effective depth N/A At total depth 2931' SNL, 1998' EWL, SEC. 08, T10N, R16E, UM 5. Type of well: [~ Development I--I Exploratory [] Stratigraphic [--]Service (TD at Ops Shutdown) 6. Datum Elevation (DF or KB) KBE = 5O.O2' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 09-23A 9. Permit Number 98-44 / 398-112 10. APl Number 50-029-21066-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 16397 feet 8976 feet feet feet Length Structural Conductor 80' Surface 2669' Intermediate Production 11250' Liner 7806' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Plugs (measured) Junk (measured) Size Cemented MD TVD 20" 1860# Poleset 80' 80' 13-3/8" 3600 sx CS III, 400 sx CS II 2700' 2525' 9-5/8" 500 sx Class 'G', 300 sx CS I 11281' 7759' 7" Not Cemented (stuck) 4983' - 12789' 3941' - 8298' RECEIVED JAN 0'3 1999 5" Grade 'E' Drill Pipe Kill String from Sur~[e to 2065' 9-5/8" Bridge Plug at 4765' 13. Attachments [~ Description summary of proposal F-~ Detailed operations program E~ BOP sketch 14. Estimated date for commencing operation February 10, 1999 16. If proposal was verbally approved Name of approver Date approved contact Engineer Name/Number: C. Michael Jackson, 564-5480 15. Status of well classifications as: [~ Oil I--] Gas [--I Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed c::~,.. -,~. ~ Dan Stone Title Engineering Supervisor C o.~qli~b n~Pf _A P P roval: Commission Use Only Approved by order of the Commission Notify Commission so representative .rn,~.a.y witness Plug integrity BOP Test ¢," Location clearance Mechanical Integrity Test ..... Subsequent form required 10- ORIGINAL SIGNED.BY Robert N. Christenson Commissioner Date T APpre~aI N°~'-~,~2-, Form 10-403 Rev. 06/15/88 Submit In Triplic/ate . , a rilfing BP Exploration / ARCO Alaska Inc. To: Blair Wondzell - AOGCC Date: January 5, 1999 From: C. Michael Jackson Subject: Reference: DS 9-23A Resume Sidetrack Operations Form 10-403 Attachment Permit to Drill #98-44, APl #50-029-21066-01 Nabors 7ES is expected to move on DS 9-23A in mid to late February following the completion of the V-200 appraisal well. This memo is written as an attachment to form 10-403 for the re-start of sidetrack operations on DS 9-23A(API #50-029-21066-01). Operations are expected to follow previously approved Permit to Drill #98-44 subsequent to a revised directional plan. OVERVIEW Well 9-23A was a side-track out of the 9-5/8" casing into the cretaceous shale interval. The original completion tubing was recovered from 12,447' and the 9-5/8" casing leak established at 9,657'. A 12.5 ppg EMW FIT was achieved on the leak which met the Kick Tolerance restrictions for the 8-1/2" hole section. A whipstock side-track was conducted at 12,370' and a kick off assembly RIH to kick off high side. Attempts to kick off at 12,370' MD failed and subsequently the open hole was cemented back up to 500 ft above the window. A second whipstock side-track was conducted and the well kicked off successfully at 11,281 '. An 8- 1/2" hole was directionally drilled with a 10.3 ppg LSND to a depth of 16,397' ( 8,975' TVD) into the top of the Sadlerochit Zone 2 formation. Tight spots (30,000 lbs over normal drag) were noted at 15,191-15,563', 14,910-15,000' and 14,444' to 14,630' which were double wiped. The extended 7" liner (7,806') was made up and run in hole to 9,617' were it was noted by the Driller that incorrect torque was put into the hanger. The liner was pulled out and the correct torque applied. The 7" liner was run to the window at 11,281' and circulation broken with 5 bpm @ 800 psi. The liner was then run into open hole where it started taking weight at 12,485'. The pipe was worked down to 12,789' without circulating where movement was no longer possible. Circulation was attempted and achieved 1.7 BPM @ 1260 psi. The casing was stuck and finally the hole packed off with the top of liner @ 4,983', shoe @ 12,789' MD. The drill pipe running tool was released from the hanger leaving the 7" liner in place. Due to the warming weather trend affecting the ice road condition across the Sag river the well was suspended. The well was suspended with a Halliburton retrievable bridge plug set at 4765' and the casing tested to 1500 psi for 15 minutes. Also 2065' of 5" drill pipe was hung from the tubing hanger for freeze protecting. The tubing hanger was tested to 1500 psi and the adapter flange / tree were tested to 3000 psi and secured with a BPV in the tubing hanger. Should you need any more information or have any questions please feel free to give me a call. Sincerely, Operations Drilling Engineer 564-5486 Wk 275-1544 Pgr 349-1383 Hm CC Jennifer Watson Dan Stone _DS 9-23A nded Conditign 4/22 ~ 68 Jts(2065') of 5" 'E' drill pipe 13-3/8", 72#, L-80 Halliburton RBP @ 4765' Top of 7" liner 7, 26 # Liner Baker 7" x 9~5/8" 'HMC' HgdPkr 20,25' 65 Joints L-80 BTC-mod 2618.96' X-Over L-80 BTC-mod box x NSCC pin 35.37' X-Over L-g0 NSCC box x BTC pin 39.23' 109 Joints L-80 BTC-mod 4382.81" Halliburton Float Collar 1.03' 2 Joints L-80 BTC-mod 79.65' Halliburton Float Shoe 1 Total 7805.76' 12,5 ppg E~¢~W Casing ~eak Milled window @ 11,281' md 7758' TVD) FormatierL.Zg&~ K-2 / HRZ LCU / 2B 12,605' md(8257' TVD) 14,649' md(8700' TVD) 16,316' md(8967' TVD) Milled window Base LCU Top Zone 2B Plugged & a~andonded 8.5" wellbore Nabors 22E 4/9/98 -- 9-5/8"47# L-89 j12,858'j Wellbore Art¢~ tl,281' to 11,490' 45° 11,490' to 11,943' Butld 8° ll0O'to 76° Sqz'd Perforations: 11,943' to ~ 5,2~ 8' 76° 12,827' - 13,035' 15,218' to 16,397' Build 2°/lOO'to 84° 1/05198 ~J PBTD ~ 7" 29# L-80 ~ COMMENTS Suspended Condition PRUDHOE BAY UNIZ WE~ APl NO: 50~29-21~ ~C I; T1 Arco Alaska Inc WSSSV Tubing-PC Casing Gas Lift MandrelNalve 1 Gas Lift MandrelNalve 2 Gas Lift Mandrel/Dummy Valve 3 Gas Lift Mandrel/Dummy Valve 4 Gas Lift Mandrel/Dummy Valve 5 Gas Lift Mandrel/Dummy Valve 6 Gas Lift Mandrel/Dummy Valve 7 Gas Lift Mandrel/Dummy Valve 8 ........ Gas Lift Mandrel/Dummy Valve 9 Gas Lift Mandrel/Dummy Valve 10 Gas Lift Mandrel/Dummy Valve 11 SEALASY PKR Tubing-PC SQZ NOGO .... Liner SOSUB 'FrL Per[ Per[ .... FISH ( .... 09-23 APl: 500292106600 H2S:' SSSV Type:' 2 Annular Fluid: Diesel/8.5 SW Reference Log: BHCS Last Tag: Rev Reason: FCO; CUT TBG; SQZ KB :i': :;':: Grd KB-Grd Well Type: PROD RKB:155 ft Spud: 2/13/84 KOP:IO.00 ftKB Odg Compltn: 13/10/84 PBTD:113270.00 ftKB Last W/O:111/19/88 TD:113270.00 ftKB Ref LOg Date:13/4/84 Max Hole Angle:159 deg @ 8300 Last Tag Date:I Last Update:{4/16/98 Angle @ TS:J44 de,(] @ 12827 Angle @ TD:/42 deg @ 13270 I / ',!!i!!!i:~iiii:.~i:~i/ii:!~!:~:;ii~? i!i i::: ::~:!!:' :;:! '?': :? :i.:?.!~,.:i-: '.: ~ 55 ft I Cas Flng I 0 ft 0 ft {Tub Head I 0 ft 55 ft I Depth ID Type Description ........................................... J 222814.562 IWSSSV 5-1/2" Camco BAL- .0 sssv Nipple I 1250614'875 J SEALASY 5ol/2" TIW Seal Ass_e. mbly [ 1250710.000 I PKR 9,5/8" x 5-1/2" TIW .HBBP-L Packer : 12529' 0.000 I XO Crossovor' 5-1/2" x 4-1/2 "i_-'_;?i'~_i?[;.-:_:Z,qo.~o-'-.7' ";"~.~-,,2',-otiFx~hp.-E~_: ':-.-'; -.-_17.; .... i _: .... ' ..... ". .... . ~ 12629 0.000 ISOSUB 4-1/2" TIW Shoarout Sub -- --' 12630 0.000[¥'1'[' ............ ."._4..-.~/.2_;-_T.u.-~_~_'.~jl-'.~'...:'.'-_--.':_'~_ .- ........... -'~. '--i.' ...... '~ ~'r~ i"~--~t~S ............. ..... i ........................................................................................ I?(~17 :.'.'.~ 'D 3 72? '~..1 '2" Cli.~ XN ':'::::'..:'. I..,'....:k ,' i'4,-,~, ci ,, /::., "2' 31 9.1. ['i:;/.:: '.:': ;~c'- I :;.'.:;.,'",,'J 0.i ['),: · -' ,' · i i ,i ., ' I.'l '." ;'; '.:.i~% ::,...::,:,...:'.'j I:~ ., :'~;," .' ',."~ ':! :)'...).u:..,,. '.:;,'..+.; :;:: I~.: Fish - FISH Dopth Desc~'il~iion Commont 1311.71 FISH I FISH: IBP Element (Lost 05/24/94) ' ,, .' ..... '.. ' ' ",' ::::,i,::,?'." 'Ca~ing~.Strl~lg -' PRODUCTION'..;~ Item (In) 9.625 In Cas. in.g_ C~Sln'g:St'riffg - EINER ' ':.. Item ,{In) 7.000 in Liner Ci~slhg:..String -.SURFA'.CE Item !(in) 13,375 in Casing ... (ftKB)0.00 .,' .:, . :: '... ... (ftKB) 12567.00 Btm , ,(ftKB) 12858.00 : ':'. . Top (ftKB) ... o.0o ~Ubl. ng~Strln'g -.TUBING'. :..:' · :::'.': ": ':: ' · (In) ( 5.500 In Tubinq-PC 4.500 in Tubinq-PC 12529.00J Btm (ftKB).. 13270.00 Btm (ftKB) 27oo.0o Wt : I--Grd 47.00 L-80 Wt I Grd 29.00. L-80 Wt: 1 -- Grd 72.00 L-80 B~ttor~ ~1 "L;R' ' I Wt Grd (ftKB) / (ft) I ~7 oo 12529,00~ 125291 . · L-80 12630,00/ 1011 12.601 L-80 GaS.iL, Ift~..Mai~drels/Valves:' ...... :. · .... ·.. Stn} 'MD JManMfr!ManType } ~'vMfr I VIvType I"La'~ch ! VIv !VIvTRO: VlvRun Port ' 1 I 34351 CA-MMG ICA[ R-20 [RK ]0.25d ' 1795.0 1/17~95- .. _2..; . _6.,.8_7.4~, C__A-_M. LMG ..' .......... i _'..C_A..._ ' ..... .R_D.O-2_0 _; .... R_.K _. ' ,_0...4_.3.8.'..'.. ~.9_0_9.C_.' ..4.'27_.:9.3... · 3 P,673 CA-~MG ' CA RD : RK 0.000 0.0 6 15,'.q2 -4"- ! .... 9~-~3'-CK'.;J;~ ............................ d~, ........ Fil~ .... ~ R"~ ': 0~'~(~ ........ -0~0 "' ;','29.:~:5' :"- i§- ....... ,(J~--61';' c-~,-~"~-.',4G .......... : ...... 'dA- ............ -~D' .............. hE'-" d:'06(7 ...... b:o ...... f 1'.'~0 ..... '-¢'" '-id~:-'b'~:M'~-G .................... : ' b-A .... ; ....... Fi5 ......... ~k - :',"-:7:'~ ......... ~.'.7~ .... =: ~-'~i.:-" · 8 ~ 11168 CA-MMG CA RD . I'.'.K ;i ',',',' :) 7, :': ''.~'.'. j- ~)- 1'-'~I-~7.'~A:'M~G ....................... ~, ......... I~-~ FK ;.: :'r::> :: .' '' .",.:'. -'1'~' -"I'~"~'~'4-FC'~'-M~-I ........................ C~,- ........ -I~'D F{K ',: :'::::.: ": · · ,.'!: ," i-{'":,-':1'~-48'. CA:M~'~ '. ..................... ~, ......... -I:iF(-~l} nKp (: :.:;.:! ...... :'.' IJ~¥Ffb'~'ii~'~i~' ~jh~-~:a_-~ ................. : ............................... ." ........ '" ' ' 'Jr~-~'F~l- .............. _-F~.~'~ ............ I'§~-~'t~'~.' ....... -i~'~- ......... §PF Date' ' 'Typo , Comment' · l J~827 - 1'~-~ -,'~dh-~' ~ ...... :'- ........................ ................................................. 1.'_3 ...... :J. 3_/. .1_0.../ ~ .... i ....................... 12858- 12878 ZONE 2 20 0'3/10/98 , ,'i 2-~ ---~5 ~ ......... z-~,,~ F2 ..... I .................... i7) ............ C)'"37¥0)~h .......................... ¥~-9-'~{~: :1~'~'~ ..... ~-(~-~'~. .... , ................................................................ 20 0 3/10/98 , 1'2-'~',~t §"-' ~12:-9-~g ...... -Z-O ~-'~-'2 .......... I6- ........... ~)-5' ......... 4' ;'§?~'/~-~" ' 'TPi~'F .................... · !~§-~..::.1.m.o:::~_..-:'..':::::45~.-~"..::: .:..~ '.-::. :-[ ..:.:: .... ~3 ........ '.--::-'.~.';"~_:,~7~.:.-.-:..'.~:~_~...:. -."!-:.."". ...... :-'...--:: Stimulations & Tnmtme,ts I'~{eF~ ........... b&te .........Fi;~/-~'~- ....................... C-~'-m'~F ....................................... 12532- 129'40 3/10/98 I SQZ OF:III_I--lNG S I::: FI U'I I-- E S WEI J, LOG TRANSMITTAL To: State of Alaska October 28, 1998 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 q ~'-~O q 4 RE: MWD FormafionEvaluafionLogs D.S. 9-23A & 9-23APB1, AK-MM-80185 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS,%23A: 2" x 5" MD Gamma Ray Logs: 50-029-21066-01 2" x 5" TVD Gamma Ray Logs: 50-029-21066-01 DS 9-23A PBI: 2" x 5" MD Gamma Ray Logs: 50-029-21066-70 2"x 5" TVD Gamma Ray Logs: 50-029-21066-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia R, EGEiVF- D OCT ?_8 Ala,~a Oil & Gas O~n~. G~mmi~ion ~omge 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries, Inc. Company s,n_F,r r xd-sun WEI,L LOG TRANSMITTAL To,' State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 9-23A, AK-MM-80185 October 21, 1998 The technical data listed bdow is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21066-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries, Inc. Company 0 I:t I I--I.-I IM G S ~:: !:t ~J I r' Ec: WELL LOG TRANSMITTAL To: State of Alaska October 21, 1998 Alaska Oil and Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Alaska 99501 (~ % ' Od ~/ RE: MWD Formation Evaluation Logs - D.S. 9-23APB1, AK-MM-80185 The technical data listed bdow is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~g3, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21066-70. OCT 2 8 1998 ~iaska Oil & Gas Cons. Commission An~om~e 5631 $ilverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries, Inc. Company 1. Operations performed: STATE OF ALASKA CO.SS.VAT O. CO U SS O. REPORT OF SUNDRY WELL OPERATIONS RECEIVED OCT O 1 1998 ~] Operation Shutdown i-1 Stimulate [--I Plugging [-1 Perforate Alaska 0ii & Gas Cons. Comfllt$ Pull Tubing r--J Alter Casing E~ Repair Well E~ Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 55' NSL, 349' EWL, SEC. 01, T10N, R15E, UM At top of productive interval N/A At effective depth N/A At total depth 2931' SNL, 1998' EWL, SEC. 08, T10N, R16E, UM J5. Type of well: [~ Development I--~ Exploratory [--I Stratigraphic [--I Service (TD at Cps Shutdown) Anchorage 6. Datum Elevation (DF or KB) KBE - 50.02' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 09-23A 9. Permit Number / Approval No. 98-44 398-112 10. APl Number 50-029-21066-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 16397 feet true vertical 8976 feet Effective depth: measured feet true vertical feet Casing Length Size Structural Conductor 80' 20" Surface 2669' 13-3/8" Intermediate Production 11250' 9-5/8" Liner 7806' 7" Plugs (measured) Junk (measured) ORIGINAL Cemented 1860# Poleset 3600 sx CS Ill, 400 sx CS II 500 sx Class 'G', 300 sx CS I Not Cemented (stuck) MD 80' 2700' 11281' 4983' - 12789' TVD 80' 2525' 7759' 3941' - 8298' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 5" Grade 'E' Drill Pipe Kill String from Surface to 2065' Packers and SSSV (type and measured depth) 9-5/8" Bridge Plug at 4765' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [~ Copies of Logs and Surveys run [~j Daily Report of Well Operations 16. Status of well classifications as: [] Oil F-1 Gas [--1 Suspended Service 17. I hereby certir~that the foreg~nd correct to the best of my knowledge Signed Jam¢~,,~.~L"~~--,~~ Title Senior Drilling ..Engineer Prepared By Name/Number: Date ~//~//~9~'- Terrie Humble, 564-4628 Submit In Duplicate Form 10-404 Rev. 06/15/88 _ hare. d _ ery .ces l r ll ng AlasKa To: From: Date: Subject: Sir: Blair Wondzell, AOGCC Jim Smith, SSD Sept. 29, 1998 Operation Shutdown on Well DS 9-23A Approval was granted on Sundry Permit #398-112 for Operation Shutdown on the DS 9-23A well April 24, 1998. The shutdown was forced by the need to move rig Nabors 22E across the Sag river due to arrival of spring flooding at the ice bridge. It is anticipated that operations will resume on the DS 9-23A well in March of 1999. Proposed operations at that time are: 1. MIRU, Circulate the freeze protection from the wellbore through 5" DP that was hung off at 2065'. ND tree and NU BOP's, test BOP's. 2. POOH with 5" DP. RIH to recover retreivable packer set at 4765' in the 9-5/8" casing. Monitor carefully for trapped gas below the packer. 3. The liner hanger supporting the 7" liner at 4955' has not been set and liner is uncemented. Make a free point run to determine deepest possible cut point of the 7" liner in the open hole below whipstock KOP at 11297'MD and above the 7" liner shoe at 12789'MD. Cut the 7" at deepest free depth and remove liner from well. 4. RIH and plug open hole with class G cement. 5. If remaining 7" stub in open hole is at least 200' below the whipstock we will sidetrack off the cement plug in 8-1/2" hole size, if the 7" stub is less than 200' below the whipstock a new whipstock sidetrack will be made100' uphole from the original whipstock exit at 11297'. 6. Redrill the 8-1/2" interval to approximately 16,400'MD at the top of Zone 2B parallel to the original directional plan. Run and cement 7" drilling liner from 150' above whipstock to TD. 7. Drill out in 6" hole along original directional wellplan continuing to TD at 18,825'MD/9,000'TVD. If there are any questions please contact Jim Smith at 564-5026. Smith, SSD Facility Date/Time 27 Mar 98 28 Mar 98 29 Mar 98 30 Mar 98 31 Mar 98 01 Apr 98 02 Apr 98 03 Apr 98 PB DS 09 Progress Report Well 09-23A Rig ~ ~r$ gg~ Page Date Duration Activity 18:00-18:30 18:30-19:00 19:00-21:00 21:00-06:00 06:00-06:15 06:15-13:00 13:00-14:00 14:00-14:30 14:30-18:00 18:00-18:15 18:15-22:00 22:00-06:00 06:00-06:15 06:15-13:00 13:00-15:00 15:00-18:00 18:00-18:15 18:15-20:00 20:00-06:00 06:00-06:15 06:15-15:00 15:00-18:00 18:00-18:15 18:15-00:30 00:30-02:00 02:00-04:00 04:00-06:00 06:00-06:15 06:15-13:00 13:00-16:00 16:00-18:00 18:00-18:15 18:15-01:00 01:00-05:00 05:00-06:00 06:00-07:00 07:00-18:00 18:00-18:30 18:30-02:00 02:00-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-15:00 15:00-15:30 15:30-23:00 23:00-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-16:00 16:00-18:00 18:00-18:30 1/2 hr 1/2 hr 2hr 9 hr 1/4 hr 6-3/4 hr 1 hr 1/2 hr 3-1/2 hr 1/4 hr 3-3/4 hr 8 hr 1/4 hr 6-3/4 hr 2 hr 3 hr 1/4 hr 1-3/4 hr 10hr 1/4 hr 8-3/4 hr 3 hr 1/4 hr 6-1/4 hr 1-1/2 hr 2 hr 2 hr 1/4 hr 6-3/4 hr 3 hr 2 hr 1/4 hr 6-3/4 hr 4 hr 1 hr 1 hr llhr 1/2 hr 7-1/2 hr 4 hr 1/2 hr 5 hr lhr 2-1/2 hr 1/2 hr 7-1/2 hr 3 hr 2 hr 2 hr 1/2 hr 4-1/2 hr 5 hr 2 hr 1/2 hr Held safety meeting Rigged down Drillfloor / Derrick Serviced Block line Rigged down Top drive Held safety meeting Rigged down Top drive Serviced Service lines Held safety meeting Rig moved 30.00 % Held safety meeting Rigged up Service lines Rigged down Drillfloor / Derrick Held safety meeting Rigged down Drillfloor / Derrick Rigged down Lines / Cables Removed Drillfloor / Derrick Held safety meeting Rigged down Drillfloor / Derrick Rig moved 50.00 % Held safety meeting Rig moved 75.00 % Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rig moved 80.00 % Held safety meeting Rig moved 100.00 % Rigged up Service lines Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Top drive Held safety meeting Held safety meeting Installed Top drive Held safety meeting Installed Top drive Singled in drill pipe to 0.0 ft Held safety meeting Singled in drill pipe to 0.0 ft Removed Accessories Installed Fluid system Held safety meeting Circulated at 12470.0 ft Flow check Removed Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Removed Additional services Held safety meeting 1 29 September 98 Facility Date/Time 04 Apr 98 05 Apr 98 06 Apr 98 07 Apr 98 08 Apr 98 09 Apr 98 PB DS 09 Progress Report Well 09-23A Rig (null) Duration Activity 18:30-20:00 20:00-01:00 01:00-06:00 06:00-06:30 06:30-17:00 17:00-18:00 18:00-18:30 18:30-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-15:00 15:00-21:30 21:30-23:00 23:00-04:00 04:00-06:00 06:00-06:30 06:30-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-02:30 02:30-05:00 05:00-06:00 06:00-06:30 06:30-12:00 12:00-13:30 13:30-14:30 14:30-18:00 18:00-18:15 18:15-21:00 21:00-01:30 01:30-06:00 06:00-06:30 06:30-16:30 16:30-18:00 18:00-23:30 23:30-01:30 01:30-02:00 02:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-11:00 11:00-11:30 11:30-13:00 13:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 1-1/2 hr 5 hr 5hr 1/2 hr 10-1/2 hr 1 hr 1/2 hr 5-1/2 hr 5 hr 1 hr 1/2 hr 2-1/2 hr 2 hr 4 hr 6-1/2 hr 1-1/2 hr 5 hr 2 hr 1/2 hr 11-1/2 hr 1/4 hr 3/4 hr 1 hr 6-1/2 hr 2-1/2 hr 1 hr 1/2 hr 5-1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 1/4 hr 2-3/4 hr 4-1/2 hr 4-1/2 hr 1/2 hr 10hr 1-1/2 hr 5-1/2 hr 2 hr 1/2 hr 4 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 1/2 hr 1-1/2 hr 3 hr 1/2 hr 1 hr 1/2 hr Worked toolstring at 30.0 ft Circulated at 12470.0 ft Laid down 1457.0 ft of Tubing Held safety meeting Laid down 12477.0 ft of Tubing Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Ran Drillpipe in stands to 0.0 ft Held safety meeting Tested Bottom ram Serviced Top drive Ran Drillpipe in stands to 6385.0 ft Singled in drill pipe to 9751.0 ft Circulated at 9564.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 0.0 ft Held safety meeting Ran Drillpipe in stands to 11500.0 ft Held safety meeting Ran Drillpipe in stands to 12403.0 ft Worked toolstring at 12370.0 ft Worked toolstring at 12408.0 ft Circulated at 12400.0 ft Pulled out of hole to 12000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Serviced BOP stack Serviced Top drive Made up BHA no. 1 Held safety meeting Singled in drill pipe to 4464.0 ft R.I.H. to 12408.0 ft Drilled to 12499.0 ft Held safety meeting Drilled to 12630.0 ft Circulated at 12630.0 ft Pulled out of hole to 267.0 ft Pulled BHA Serviced Top drive Ran Drillpipe to 5500.0 ft (5in OD) Held safety meeting Ran Drillpipe in stands to 12350.0 ft Installed Drillfloor / Derrick Ran Drillpipe in stands to 12630.0 ft Circulated at 12630.0 ft Batch mixed slurry - 55.000 bbl Pulled out of hole to 11770.0 ft Circulated at 11770.0 ft Pulled out of hole to 1500.0 ft Installed Drillstring handling equipment Pulled out of hole to 0.0 ft Held safety meeting Page Date 2 29 September 98 Facility Date]Time 10 Apr 98 11 Apr 98 12 Apr 98 13 Apr 98 14 Apr 98 15 Apr 98 PB DS 09 Progress Report Well 09o23A Rig (null) Page Date Duration Activity 18:00-19:00 19:00-02:00 02:00-06:00 06:00-06:30 06:30-12:00 12:00-13:00 13:00-13:30 13:30-14:00 14:00-18:00 18:00-18:15 18:15-02:30 02:30-04:00 04:00-06:00 06:00-06:30 06:30-12:00 12:00-14:00 14:00-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-00:00 00:00-06:00 06:00-06:30 06:30-16:00 16:00-18:00 18:00-18:15 18:15-00:30 00:30-01:00 01:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-09:30 09:30-18:00 18:00-18:15 18:15-04:00 04:00-06:00 06:00-11:00 11:00-13:00 13:00-16:00 16:00-17:00 17:00-18:00 18:00-18:15 18:15-19:00 19:00-22:00 22:00-23:30 23:30-06:00 06:00-06:15 06:15-18:00 18:00-18:15 18:15-20:00 20:00-21:30 21:30-22:00 22:00-22:30 1 hr 7hr 4hr 1/2 hr 5-1/2 hr 1 hr 1/2 hr 1/2 hr 4 hr 1/4 hr 8-1/4 hr 1-1/2 hr 2 hr 1/2 hr 5-1/2 hr 2 hr 4hr 1/4 hr 3/4 hr 1 hr 4 hr 6 hr 1/2 hr 9-1/2 hr 2 hr 1/4 hr 6-1/4 hr 1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 3 hr 8-1/2 hr 1/4 hr 9-3/4 hr 2 hr 5 hr 2 hr 3 hr 1 hr 1 hr 1/4 hr 3/4 hr 3 hr 1-1/2 hr 6-1/2 hr 1/4 hr 11-3/4 hr 1/4 hr 1-3/4 hr 1-1/2 hr 1/2 hr 1/2 hr Serviced Block line Conducted electric cable operations Ran Drillpipe in stands to 1000.0 ft Held safety meeting Ran Drillpipe in stands to 10165.0 ft Circulated at 10165.0 ft Ran Drillpipe in stands to 11309.0 ft Worked toolstring at 11309.0 ft Worked toolstring at 11280.0 ft Held safety meeting Worked toolstring at 11347.0 ft Circulated at 11347.0 ft Pulled out of hole to 9000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Serviced BOP stack Tested BOP stack Held safety meeting Serviced Top drive Made up BHA no. 2 R.I.H. to 11211.0 ft Drilled to 11370.0 ft Held safety meeting Drilled to 11452.0 ft Circulated at 11452.0 ft Held safety meeting Pulled out of hole to 792.0 ft Pulled BHA Made up BHA no. 3 Serviced Top drive R.I.H. to 4500.0 ft Held safety meeting R.I.H. to 11125.0 ft Drilled to 11462.0 ft Held safety meeting Drilled to 11531.0 ft Circulated at 11531.0 ft Pulled out of hole to 200.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 2300.0 ft Serviced Block line Held safety meeting Serviced Top drive R.I.H. to 11241.0 ft R.I.H. to 11531.0 ft Drilled to 11910.0 ft Held safety meeting Drilled to 12293.0 ft Held safety meeting Drilled to 12578.0 ft Circulated at 12578.0 ft Pulled out of hole to 11432.0 ft Serviced Top drive 3 29 September 98 Facility Date]Time 16 Apr 98 17 Apr 98 18 Apr 98 19 Apr 98 20 Apr 98 21 Apr 98 PB DS 09 Progress Report Well 09-23A Page Rig (null) Date Duration Activity 22:30-23:00 23:00-06:00 06:00-06:15 06:15-09:00 09:00-21:00 21:00-23:00 23:00-01:00 01:00-06:00 06:00-06:15 06:15-08:00 08:00-08:30 08:30-11:00 11:00-11:30 11:30-12:30 12:30-13:30 13:30-20:30 20:30-06:00 06:00-06:15 06:15-10:00 10:00-12:00 12:00-13:00 13:00-14:00 14:00-18:30 18:30-21:00 21:00-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-12:30 12:30-14:00 14:00-16:00 16:00-17:30 17:30-22:00 22:00-01:30 01:30-06:00 06:00-06:15 06:15-12:00 12:00-14:30 14:30-16:00 16:00-01:00 01:00-02:30 02:30-03:00 03:00-03:30 03:30-06:00 06:00-07:00 07:00-09:00 09:00-10:30 10:30-15:00 15:00-15:30 15:30-19:30 19:30-20:00 20:00-20:30 20:30-23:00 23:00-23:30 1/2 hr 7hr 1/4 hr 2-3/4 hr 12hr 2 hr 2 hr 5hr 1/4 hr 1-3/4 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 1 hr 7 hr 9-1/2 hr 1/4 hr 3-3/4 hr 2 hr 1 hr lhr 4-1/2 hr 2-1/2 hr 9 hr 1 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 2 hr 1-1/2 hr 4-1/2 hr 3-1/2 hr 4-1/2 hr 1/4 hr 5-3/4 hr 2-1/2 hr 1-1/2 hr 9 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1 hr 2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 4 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr R.I.H. to 12578.0 ft Drilled to 13140.0 ft Held safety meeting Drilled to 13315.0 ft Repaired Fluid system Drilled to 13419.0 ft Circulated at 13419.0 ft Pulled out of hole to 81.0 ft Held safety meeting Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Serviced Top drive Made up BHA no. 5 R.I.H. to 13419.0 ft Drilled to 14445.0 ft Held safety meeting Drilled to 14818.0 ft Circulated at 14818.0 ft Pulled out of hole to 13233.0 ft R.I.H. to 14818.0 ft Drilled to 15412.0 ft Circulated at 15412.0 ft Drilled to 15.0 ft Circulated at 15697.0 ft Drilled to 15728.0 ft Circulated at 15728.0 ft Drilled to 15861.0 ft Circulated at 15861.0 ft Drilled to 15957.0 ft Circulated at 15957.0 ft Drilled to 16397.0 ft Circulated at 16397.0 ft Pulled out of hole to 11500.0 ft Held safety meeting Pulled out of hole to 215.0 ft Pulled BHA Rigged up Casing handling equipment Ran Liner to 7806.0 ft (7in OD) Rigged down Casing handling equipment Installed Liner hanger Circulated at 7806.0 ft Ran Drillpipe in stands to 9706.0 ft Pulled Drillpipe in stands to 7805.0 ft Ran Drillpipe in stands to 11281.0 ft Ran Drillpipe in stands to 12800.0 ft Worked stuck pipe at 12789.0 ft Functioned Liner hanger Laid down 4955.0 ft of 5in OD drill pipe Rigged down sub-surface equipment - Setting tools Installed Retrievable packer Ran Drillpipe in stands to 4765.0 ft Tested Casing 4 29 September 98 Facility Date/Time 22 Apr 98 PB DS 09 Progress Report Well 09-23A Rig (null) Page Date Duration Activity 23:30-03:30 03:30-05:00 05:00-06:00 06:00-06:15 06:15-08:00 08:00-08:30 08:30-09:30 09:30-13:00 13:00-15:00 15:00-20:00 4 hr 1-1/2 hr 1 hr 1/4 hr 1-3/4 hr 1/2 hr 1 hr 3-1/2 hr 2 hr 5 hr Laid down 4781.0 ft of 5in OD drill pipe Ran Drillpipe in stands to 3734.0 ft Laid down 450.0 ft of 5in OD drill pipe Held safety meeting Laid down 3284.0 ft of 5in OD drill pipe Retrieved Wear bushing Ran Drillpipe in stands to 2065.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree 5 29 September 98 r'l !:! I I_1_ I N G S I:: !:t ~,~ I C I:: S 23-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 9-23APB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,295.02' MD 12370' MD 12,630.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 09 09-23A- 9-23APB1 ORIGINAL S UR VEY REPORT 23 June, 1998 Your Reft API-500292106670 Last day of Surveys 08-APR-98 Job# AKMMSO185 KBE- 50.02' DRILLING SERVICES Am~t,,a 0'~:,% Gm Cons..C~mmiss[°r Survey Ref: $vy3498 Sperry-Sun Drilling Services Survey Report for 09-23A - 9-23APBf Your Ref: API-500292106670 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) 12295.02 42.600 110.200 8445.14 8495.16 1550.59 S 8028.33 E 12370.00 42.240 110.650 8500.49 8550.51 1568.24 S 8075.73 E 12387.28 43.230 110.650 8513.18 8563.20 1572.38 S 8086.70 E 12442.16 41.840 110.650 8553.62 8603.64 1585.46 S 8121.42 E 12487.50 42.260 110.650 8587.29 8637.31 1596.17 S 8149.84E 12530.67 42.760 110.650 8619.11 8669.13 1606.46 S 8177.13 E 12572.49 42.960 110.650 8649.76 8699.78 1616.49 S 8203.75 E 12630.00 43.230 110.650 8691.76 8741.78 1630.35 S 8240.52 E 5940216.43 N 726838.17 E 8176.62 5940200.16 N 726886.06 E 0.628 8226.54 5940196.34N 726897.15 E 5.729 8238.11 5940184.27 N 726932.23 E 2.533 8274.70 5940174.39 N 726960.95 E 0.926 8304.66 5940164.90 N 726988.53 E 1.158 8333.43 5940155.65 N 727015.43 E 0.478 8361.49 5940142.86 N 727052.58 E 0.469 8400.25 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 101.191° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12630.00ft., The Bottom Hole Displacement is 8400.25ft., in the Direction of 101.191 ° (True). Comment Tie-on Survey Window Point Projected Survey Alaska State Plane Zone 4 PBU EOA DS 09 Continued... 23 June, 1998 - 9:40 .2 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for 09-23A - 9-23APBf Your Ref: API-500292106670 Alaska State Plane Zone 4 PBU EOA DS 09 Comments Measured Depth (ft) 12295.02 12370.00 12630.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8495.16 1550.59 S 8028.33 E 8550.51 1568.24 S 8075.73 E 8741.78 1630.35 S 8240.52 E Comment Tie-on Survey Window Point Projected Survey 23 June, 1998 - 9:40 - 3 - DrillQuest 23-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 9-23A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,195.02' MD 11281' MD 16,397.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company Prudhoe Bay Unit Alaska State Plane Zone 4 PBU EOA DS 09 09-23A SURVEY REPORT 23 June, 1998 Your Ref: API-50029210660f Last Survey at 19.April-98 Job# AKMMSOf 85 KBE- $0.02' DRII..LING S E~ RV I t- r= ES A DIVZ,.qION Ot~ DRE~II~t. i I*,TZ)U ~T~ I~,~ ~C, RECEIVED JUN 2 5 1998 Alaska Oit & Gas Cmos. Commlssior~ Anchorage Survey Ref: svy3500 Prudhoe Bay Unit Measured Depth (ft) Incl. 11195.02 11281.00 11297.34 11321.32 11331.81 11357.94 11370.09 11389.80 11409.96 11451.60 11465.90 11490.17 11530.95 11557.32 11593.04 11625.24 11653.39 11688.17 11720.26 11751.44 11782.91 11814.02 11841.40 11848.6O 11880,06 11912.15 11943.92 11975.26 12033.53 12131,34 45.330 45.320 46.050 45.910 45.500 45.400 45.190 45.20O 45.100 44.030 43,490 45,600 49.830 51.670 53.670 55.330 57.120 59.950 62.300 64.86O 67.200 69.440 70.530 70.740 72.850 75.100 76.780 76.75O 76.67O 78.750 Azim. 106.310 106.390 106.390 106.390 106.390 106.390 106.390 106.390 106.390 106.390 106.390 106.390 105.640 105.190 104.630 104.150 103.750 103.290 105.500 106.510 106.140 106.620 108.080 108.390 109.950 110.910 111.370 111.260 111.460 112.340 Sub-Sea Depth (ft) 7648.39 7708.84 7720.26 7736.92 7744.25 7762.58 7771.13 7785.01 7799.23 7828.90 7839.23 7856.52 7883.95 7900.64 7922.30 7941.00 7956.65 7974.80 7990.29 8004.17 8016.95 8028.44 8037.81 8040.20 8050.03 8058.89 8066.61 8073.78 8087.18 8108.00 Vertical Depth (ft) 7698.41 7758.86 7770.28 7786.94 7794.27 7812.60 7821.15 7835.03 7849.25 7878.92 7889.25 7906.54 7933.97 7950.66 7972.32 7991.02 8006.67 8024.82 8040.31 8054.19 8066.97 8078.46 8087.83 8090.22 81 O0.05 8108.91 8116.63 8123.80 8137.20 8158.02 Sperry-Sun Drilling Services Survey Report for 09-23A Your Ref: A Pi-500292106601 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 1316.05 S 7307.74 E 5940429.96 N 726111.08 E 7409.09 1333.26 S 7366.41 E 5940414.46 N 726170.22 E 0.067 7470.18 1336.56 S 7377.63 E 5940411.48 N 726181.53 E 4.468 7481.86 1341.42 S 7394.17 E 5940407.10 N 726198.20 E 0.584 7499.09 1343.54S 7401.37 E 5940405.19 N 726205,46 E 3.908 7506.60 1348.80 S 7419.24 E 5940400.46 N 726223.47 E 0.383 7525.20 1351.23 S 7427.52 E 5940398.26 N 726231.83 E 1.728 7533.83 1355.18 $ 7440.94 E 5940394.71 N 726245.35 E 0.051 7547.80 1359.21S 7454.65 E 5940391.07 N 726259.17 E 0.496 7562.08 1367.46 $ 7482.68 E 5940383.65 N 726287.43 E 2.570 7591.27 1370.25 S 7492.17 E 5940381.13 N 726297.00 E 3.776 7601.16 1375.05 S 7508.50 E 5940376.80 N 726313.46 E 8.694 7618.16 1383.37 $ 7537.49 E 5940369.33 N 726342.69 E 10.461 7648.31 1388.79 S 7557.18 E 5940364.48 N 726362.52 E 7.102 7668.72 1396.10 S 7584.63 E 5940357.98 N 726390.17 E 5.736 7697.12 1402.61 S 7610.02 E 5940352.20 N 726415.74 E 5.296 7723.33 1408.25 $ 7632.73 E 5940347.22 N 726438.60 E 6.468 7746.73 1415.18 S 7661.57 E 5940341.13 N 726467.63 E 8.215 7776.39 1422.18 $ 7688.78 E 5940334.93 N 726495.03 E 9.486 7804.49 1429.88 S 7715.62 E 5940328.01N 726522.08 E 8.708 7832.39 1437.96 S 7743.21 E 5940320.74 N 726549.90 E 7.513 7861.12 1446.11S 7770.95 E 5940313.39 N 726577.86 E 7.342 7890.00 1453.78 S 7795.50 E 5940306.43 N 726602.63 E 6.399 7915.68 1455.91S 7801.95 E 5940304.50 N 726609.14 E 5.001 7922.46 1465.72 S 7830.18 E 5940295.51 N 726637.63 E 8.196 7952.22 1476.49 S 7859.08 E 5940285.58 N 726666.83 E 7.578 7982.86 1487.60 S 7887.82 E 5940275.31 N 726695.89 E 5.471 8013.44 1498.69 $ 7916.24 E 5940265.05 N 726724.62 E 0.355 8043.70 1519.35 S 7969.05 E 5940245.93 N 726778.01 E 0.361 8099.94 1555.00 S 8057.72 E 5940212.88 N 726867.67 E 2.301 8194.60 Comment Tie-in Survey Window Point Alaska State Plane Zone 4 PBU EOA DS 09 Continued... 23 June, 1998 - 9:27 - 2 - DrillQuest Prudhoe Bay Unit Measured Depth Incl. 12226.75 12321.89 12417.62 12511.99 12604.60 12700.40 12793.30 12885.35 12981.54 13073.13 13166.94 13266.O4 13352.05 13445.47 13539.13 13631.97 13725.88 13820.41 13914.50 14006.78 14101.42 14192.32 14285.76 14378.61 14472.37 14563.79 14658.41 14750.43 14843.72 14937.52 78.740 78.270 77.95O 77.480 77.470 76.760 75.980 75.380 77.290 79.200 79.210 78.890 79.370 78.740 78.390 77.490 77.280 77.980 77.580 77.310 76.720 75.700 76.400 76.120 77.280 77.200 77.680 77.580 77.190 76.350 112.340 112.230 111.690 111.490 112.010 111.530 111.120 110.680 111.490 110.710 109.630 108.850 109.920 109.690 107.960 108.980 106.790 109.630 111.230 110.900 110.240 109.510 109.320 107.530 110.610 109.510 114.060 113.760 111.980 112.870 Sub-Sea Depth (ft) 8126.62 8145.58 8165.30 8185.38 8205.47 8226.83 8248.72 8271.49 8294.21 8312.87 8330.44 8349.26 8365.49 8383.22 8401.79 8421.19 8441.70 8461.96 8481.87 8501.93 8523.20 8544.87 8567.39 8589.45 8611.02 8631.21 8651.80 8671.51 8691.89 8713.36 Vertical Depth (ft) 8176.64 8195.60 8215.32 8235.40 8255.49 8276.85 8298.74 8321.51 8344.23 8362.89 8380.46 8399.28 8415.51 8433.24 8451.81 8471.21 8491.72 8511.98 8531.89 8551.95 8573.22 8594.89 8617.41 8639.47 8661.04 8681.23 8701.82 8721.53 8741.91 8763.38 Sperry-Sun Drilling Services Survey Report for 09-23A Your Ref: AP1-500292106601 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Easfings Rate Section (ft) (ft) (ft) (ft) (o/looft) (ft) 1590.56 S 8144.27 E 5940179.83 N 726955.22 E 0.010 8287.18 1625.92 S 8230.54 E 5940147.00 N 727042.48 E 0.507 8379.44 1660.95 $ 8317.42 E 5940114.50 N 727130.34E 0.645 8472.21 1694.88 S 8403.16 E 5940083.08 N 727217.02 E 0.539 8563.61 1728.38 S 8487.13 E 5940052.03 N 727301.93 E 0.548 8653.19 1763.02 S 8573.85 E 5940019.92 N 727389.63 E 0.888 8745.72 1795.85 S 8657.95 E 5939989.55 N 727474.64 E 0.943 8835.26 1827.67 S 8741.27 E 5939960.16 N 727558.85 E 0.800 8923.80 1861.29 S 8828.48 E 5939929.08 N 727647.00 E 2.148 9016.55 1893.57 S 8912.13 E 5939899.24 N 727731.55 E 2.246 9105.53 1925.34 S 8998.63 E 5939869.99 N 727818.93 E 1.131 .9197.14 1957.40 S 9090.49 E 5939840.61 N 727911.69 E 0.838 9294.03 1985.44 S 9170.17 E 5939814.90 N 727992.14 E 1.343 9378.12 2016.52 S 9256.46 E 5939786.34 N 728079.30 E 0.716 9469.37 2046.14 S 9343.35 E 5939759.25 N 728167.01 E 1.849 9560.84 2074.90 S 9429.46 E 5939733.00 N 728253.92 E 1.447 9651.35 2103.04 S 9516.67 E 5939707.40 N 728341.91 E 2.287 9742.78 2131.90S 9604.37 E . 5939681.11N 728430.41 E 3.027 9834.85 2163.99 S 9690.54 E 5939651.52 N 728517.48 E 1.715 9926.23 2196.37 S 9774.59 E 5939621.60 N 728602.44 E 0.455 10015.62 2228.77 $ 9860.93 E 5939591.72 N 728689.68 E 0.922 10107.23 2258.78 S 9943.95 E 5939564.13 N 728773.54 E 1.367 10195.04 2288.93 S 10029.48 E 5939536.48 N 728859.90 E 0.775 10285.32 2317.43 S 10115.04 E 5939510.47 N 728946.26 E 1.897 10375.24 2347.25 S 10201.27 E 5939483.17 N 729033.31 E 3.428 10466.11 2377.83 S 10285.02 E 5939455.03 N 729117.91 E 1.177 10554.77 2412.10 S 10370.75 E 5939423.27 N 729204.61 E 4.721 10646.25 2448.53 S 10452.92 E 5939389.24 N 729287.80 E 0.336 10734.79 2483.91S 10536.80 E 5939356.30 N 729372.67 E 1.908 10824.73 2518.74 S 10621.20 E 5939323.94 N 729458.05 E 1.286 10915.06 Comment Alaska State Plane Zone 4 PBU EOA DS 09 Continued... 23 June, 1998 - 9:27 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 09-23A Your Ref: AP1-500292106601 Prudhoe Bay Unit Measured Sub-Sea VertiCal Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100fi) (ft) 15031.27 75.920 112.260 8735.82 8785.84 15125.00 75.040 113.520 8759.32 8809.34 15218.39 77.090 114.100 8781.81 8831.83 15312.04 79.480 113.550 8800.83 8850.85 15404.10 79.590 112.500 8817.55 8867.57 15497.23 80.080 110.070 8833.99 8884.01 15589.93 81.850 108.580 8848.54 8898.56 15683.46 84.120 106.680 8859.97 8909.99 15776.33 85.350 107.030 8868.49 8918.51 15870.23 85.290 106.000 8876.15 8926.17 15963.80 85.010 106.290 8884.06 8934.08 16057.59 84.730 106.370 8892.45 8942.47 16151.36 84.580 106.120 8901.18 8951.20 16245.02 84.440 104.770 8910.14 8960.16 16332.87 83.920 105.470 8919.05 8969.07 16397.00 83.540 105.980 8926.06 8976.08 2553.67 S 10705.25 E 5939291.47 N 729543.07 E 0.781 11005.06 2588.96 S 10788.84E 5939258.62 N 729627.65 E 1.605 11094.70 2625.55 S 10871.76 E 5939224.45 N 729711.60 E 2.276 11184.01 2662.58 S 10955.64E 5939189.86 N 729796.52 E 2.616 11274.36 2697.99 S 11038.96 E 5939156.88 N 729880.83 E 1.128 11363.76 2731.26 S 11124.37 E 5939126.10 N 729967.17 E 2.622 11454.68 2761.56 S 11210.75 E 5939098.33 N 730054.40 E 2.483 11545.83 2789.66 S 11299.21 E 5939072.80 N 730143.63 E 3.155 11638.46 2816.48 S 11387.72 E 5939048.57 N 730232.88 E 1.377 11730.82 2843.08 $ 11477.44 E 5939024.58 N 730323.34E 1.095 11824.32 2869.01S 11567.00 E 5939001.27 N 730413.61 E 0.430 11917.49 2895.27 S 11656.65 E 5938977.61 N 730503.98 E 0.310 12010.82 2921.39 S 11746.28 E 5938954.11 N 730594.34E 0.310 12104.11 2946.22 S 11836.14 E 5938931.90 N 730684.88 E 1.443 12197.31 2969.01S 11920.51E 5938911.56 N 730769.88 E 0.989 12284.69 2986.29 S 11981.87 E 5938896.07 N 730831.71 E 0.988 12348.41 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 103.995° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16397.00ft., The Bottom Hole Displacement is 12348.41ft., in the Direction of 103.995° (True). Comment Projected Survey Alaska State Plane Zone 4 PBU EOA DS 09 Continued... 23 June, 1998 - 9:27 - 4 - DriilQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for 09-23A Your Ref: API-500292106601 Alaska State Plane Zone 4 PBU EOA DS O9 Comments Measured Depth (ft) 11195.02 11281.00 16397.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 7698.41 1316.05 S 7307.74 E 7758.86 1333.26 S 7366.41 E 8976.08 2986.29 S 11981.87 E Comment Tie-in Survey Window Point Projected Survey 23 June, 1998 - 9:27 - 5 - DrillQuest ALASKA{"'.. STATE OF ALASKA 'O(¢'' ,L AND GAS CONSERVATION C ~,MISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [--ITime Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 55' NSL, 349' EWL, SEC. 01, T10N, R15E, UM At top of productive interval 2448' NSL, 3508' WEL, SEC. 08, T10N, R16E, UM At effective depth At total depth 2372' NSL, 1010' WEL, SEC. 08, T10N, R16E, UM Type of well: [] Development I--] Exploratory r--] Stratigraphic [-IService (Planned) (Planned) 6. Datum Elevation (DF or KB) Plan KBE = 50.02' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 09-23A 9. Permit Number 98-44 10. APl Number 50-029-21066-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 16397 feet 8967 feet feet feet Length Size Structural Conductor 80' 20" Surface 2669' 13-3/8" Intermediate Production 12827' 9-5/8" Liner Plugs (measured) Junk (measured) ORIGINAL Cemented MD TVD 1860# Poleset 80' 80' 3600 sx CS III, 400 sx CS II 2700' 2525' 500 sx Class 'G', 300 sx CS I 11281' 8155' Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Attachments [~ Description summary of proposal E~ Detailed operations program F-~ BOP sketch 14. Estimated date for commencing operation April 20, 1998 16. If proposal was verbally approved Blair Wondzell 4/21/98 15. Status of well classifications as: [~ Oil I--] Gas r--] Suspended Service Name of approver ..................... Date a. pproved contact Engineer Name/Number: Gavin Kidd, 564-5516 Prepared By Name/Number: 17. I hereby cert)~j~that the foregoing/~)rue and correct to the best of my knowledge Signed Jam Title Senior Drillin~l Engineer Commission Use Only Terrie Hubble, 564-4628 D at e ¢/~(-~/~"~ I Approval No.,.~ Conditions of Approval: Notify Commission so representative may witness .. 12,6 ~;¢o.¢f- Plug integrity BOP Test ~ Location clearance ..... Mechanical Integrity Test Subsequent for.n¥(.§~Jired 10-__/-~__o_Z Approved by order of the Commission navir~ W I~,,k,,,,,,,~, ~' ~,.~," ,,],,'1/ Commissioner Form 10-403 Rev. 06/15/88 .-- -- ...... ,,,o~u, ~ · Submit In Triplicate~ BP EXPLORMION Memorandum To: Nabors 22E, DS 9-23A From: Jim Smith Date: April 21, 1998 Subject: Shut Down Proqram for 9-23A The present status of the 9-23A well is that the 7" liner has become stuck with the liner shoe at 12,772' and the liner top at 4955'. Circulation is not possible due to packed off annulus. TD of the 8-1/2" hole interval is 16,397', sidetrack exit point from the 9-5/8" casing is at 11,300'. Weather conditions are such that is imperative to begin rig move operations back to the main PBU field prior to Sag River flooding of the ice bridge. Proposed Program: Make manual backoff off the running tool from the 7" liner at about 4955'. The liner hanger and liner top packer will not be set. Leave drilling mud in the hole. POOH laying down 5" DP and liner running tool. PU and RIH with the HOWCO retrievable bridge plug for 9-5/8" casing, set bridge plug at 4800'+/-. Test casing above the bridge plug to 1500 psi. POOH LD 5" DP. Continue to RIH and POOH to LD remaining DP in derrick except for the 2000' of 5" retained for the kill string. RIH with last 2000' of DP to hang off with XO's to the tubing hanger. Land tubing hanger and test down 5" DP to the interval from bridge plug to tubing hanger seals, test to 1500 psi. ND BOP's and NU tree, test tree to 1500 psi. During rig down operations, freeze protect the well to 2000' with diesel. ~ ~ove rig across the Sag River. SSD drilling intends to re-enter the 9-23A well either in July 1998 (pending available rig) or in February of 1999 to complete the well objectives. Gavin Kidd Ops.~fngr. Jim Smith r~ngineer Dave Nims Drlg. Su.~intendent DS 9-23A Proposed Shut Down of Ops Design Ultraslim Sidetrack 1'{" .~: Producer Hanger type: FMC Gen III KB Elev.: 21' GL: 29' Tubing Hanger w/ BPV installed and test- ed to 3,000 psi. Xtree installed & tested HRZ Whipstock / 5" DP hung off at 2000' 13 3/8" shoe @ 2,700' Ret. Packer set at 4800' 7" liner top @ 4955', ~hgr/packer not set 7", 26#, L-80, BTC.Mod liner stuck and uncemented Packed off above liner shoe 7" liner shoe @ 12,772' 2B Baker Prod. Packer open hole to 16397' Wellbore tested to 3,000 psi. Squeezed perfs from 12,827'. 13,035' Date 04-20-98 Revised by G. Kidd Prudhoe Bay Unit APl # 50-029-21066.01 Sec. 01; T10N; R15E 04/09/98 13'$0 FAX 907 $64 $193 {" BP EXPLORATION Date 9 April, 1998 To: Blair E. Wondzell, P.E.- AOGCC From: Dan M, Stone - Shared Services Drilling Subject: Operational Plugback of well 9-23A eare. d rvlceS rilling BP Exploration / Ar(x) Alaska OO2 As discussed with you last night, following is the scenario resulting in the requirement to plugback the first attempt at sidetracking this well and commencing a second sidetrack: WELL: Permit Number: AP1 #: Approval Number: 9-23A, Prudhoe Bay Field 84-3/96-107 50-029-21066 398-054 Well .Ste.t_u_s at start of rig operations: · Open perforations in well 9-23 squeezed with cement (coil tubing squeeze), cement top 12500' (bottom perforation 13035', top perforation 12827'). [] 5-1/2" tubing cut at 12477' Operat[o~s_u.o to decision t° plugback:. [] Circulated 10.3 ppg mud around through tubing cut, well stable [] Pulled 5-1/2" tubing completion [] Set 9-5/8" EZSV at 12421' [] Isolate leak in 9-5/8" at 9657' w/RTTS, sq2'd LCM into leak, achieved 12.5 ppg leakoff test [] Set whipstock at 12408' [] Milled window in 9-5/8" casing f/12370'-12408' · Ran directional kickoff assembly, drilled 8-1/2" hole f/12408'-12630'. Not achieving build as_~o_er pie, n, suspect are paralleling old wellbore (42 degree old weilbpre, had olanned 8 degree/100' build t0_$7 degrees). Had v_e. ry little TVD to achiev, e build (230' TVD), ran_o_ut _of room to achieve la~t.cJLed horizontal well w.i~hout excessive dogl_e_gs, · Decision to plugback this sidetrack wellbore and recommence operations further uphole. Ataska Oi~ & 8as Cogs. ,Oommissi~ A~cborage 04/09/98 13:$0 FAX 907 $64 $193 BP EXPLORATION Planned Operations to PlA ioJt[al ~ldetrack: ~003 P2-09/P2-59 Cost Est. Page 2 RIH 3-1/2' stinger and abandon sidetrack with cement from 12630' to 11870' (500' above top of window in 9-5/8" casing). Cement recipe: 17 ppg Class G Set EZSV at 11300' P_lanned Forward Operations: · Set new whipstock in 9-518" casing at 11300', mill window and sidetrack well to original BHL following revised directional program_ Current Operations_(1200 hr8 4/9/98): · Have run cement stinger to TD, preparing to lay cement plug. We will maintain the well name of 9-23A as we are going to the same BHL as permitted. Please let me know if you require any further information on this well. Sincerely, Dan M. Stone Drilling Engineering Supervisor - PBU Shared Services Drilling 04(09/98 13'50 FAX 907 564 5193 BP EXPLORATION BP EXPLORATION BP E~plorat~on (Alaska) In=, ~0 East BenSon ~}oulevard RO. BO~ 196612 Anchora90, Alaska 99519-65"12 (90'/} 5b'1-Slll ~ 001 ?'r.O qB- c~q¢ _ ,_ , ,,, · DATE:_ TO: TELECOPY Name: Company: Location: Fax N~ber: FROM: Department: Location: Fax Number: PAGES .TO FOLLOW) RECEIVED ~,- ,-, "l 0 !,9 9 8 :Alaska Oil & Gas Co~s. Commissm Anchorage TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 prORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: i~07) 279-1433 FAX: ,907) 276-7542 March 10. 1998 James Smith Engineering Supervisor ARCO Alaska Inc. POBox 196612 Anchorage, AK 99519-6612 Pmdhoc Bay Unit 9-23A ARCO Alaska Inc. Permit No. t)8-044 Sur. Loc. 55'NSL. 349'EWL. Sec. ()1. TION. Ri5E, UM Btmnhoic Loc. 2372'NSL. IOI0'WEL, Sec. 08. TI()N. RI6E. UM Dear Mr. Smith: Enclosed is the approved application for permit to rcdrill thc abovc rcfcrcnccd xvcll. Thc permit to rcdrili docs not cxcmpt you from obtaining additional permits required by law from othcr governmental agcncics, and does not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prcvcntion equipment (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficient notice (approximatcly 24 hours) must be given to alloxv a rcprcscntativc of thc Commission to v¢itncss a tcst of BOPE installed prior to drilling ncxv holc. Notice may bc givcn by contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. David W.']'oh~ton '~ Chaim~an ~ BY ORDER OF THE COMMISSION dlffEnclosurcs CC~ Dcpartmcnt of Fish & Gamc. Habitat Section ~v/o cncl. Dcpartmcnt of EnvirOnmcntal Conscrvation xv/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~,~':i i'; '5 *~%~'" PERMIT TO DRILL 20 AAC 25.005 ,,.I' la. Typeofwork [-IDrill [~R]Redrill lb. Typeofwell []Exploratory E]StratigraphicT~l~-DevelOpment'Oil [] Re-Entry [] Deepen []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 50.02' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028345 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 55' NSL, 349' EWL, SEC. 01, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 2448' NSL, 3508' WEL, SEC. 08, T10N, R16E, UM 09-23A At total depth 9. Approximate spud date Amount $200,000.00 2372' NSL, 1010' WEL, SEC. 08, T10N, R16E, UM 03/15/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028344, 110'I No Close Approach 2560 18825' MD / 900,0'. TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)) Kick Off Depth 12,200' Maximum Hole Angle 89° Maximum surface 2319 psig, At total depth (TVD) 8740' / 3200 psig 18. Casing Program Specifications Setting Depth Size .Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD' MD TVD (include stagedata) 8-1/2" 7" 26# L-80 Mod-BTC 10323' 6000' 4575' 16323' 8987' 1533 sx Class 'G' 6" 4-1/2" 12.6# 13Cr NSCT 2650' 16175' 8981' 18825' 9000' 162 sx Class 'G' 19. To be completed fOr R'edrill, Re-entry, and Deepen Operations. ' Present well condition summary Total depth: measured 13270 feet Plugs (measured) Sand Plug tagged at 12744' (08/30/95) true vertical 9209 feet Effective depth: measured 12744 feet Junk (measured) true vertical 8825 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 20" 1860# Poleset 80' 80' Surface 2669' 13-3/8" 3600 sx CS III, 400 sx CS II 2700' 2525' Intermediate Production 12827' 9-5/8" 500 sx Class 'G', 300 sx CS I 12858' 8906' Liner 703' 7" 300 sx Class 'G' 12567' - 13270' 8696' - 9209' Perforation depth: measured 12827' - 12842', 12858' - 12878', 12891' - 12901', 12909' - 12929', 12943' - 12968', 12982' - 13035' true vertical 8883' - 8894', 8906' - 8921 ', 8930' - 8936', 8943' - 8957', 8967' - 8985', 8995' - 9034' , , , 20. Attachments"l~ Filing'"F~'e [] Property Plat [] BOP Sketch i-I Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number: Terrie Hubble, 564-4628 , 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed h//,,~~.,.~.~ ~,,,~---------' , James Smit .~ ,' Title Engineering Supervisor Date Commission Use Only ~;~>'- ~ ~ 50-029-21066-01 %/~ \Ot¢'~ for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Requir~t ~' [] Yes ]~No Hydrogen Sulfide Measures .l~Yes [] No Directional Survey Required '~Yes [] No Required Working P01~'R~Jf(~~~"~' []2M; J~i~3M; []SM; [] 10M; [] 15M Other: [3F~v'd W, Johnston byorderof'~ "~"~' Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit riplicate I Well Name: 19-23A Well Plan Summary I Type of Well (producer or injector): I Producer I Surface Location: 55'FSL, 349'FWL, Sec. 1, T10N, R15E X = 718,768 Y = 5,941,534 Target Start: 2448' FSL, 3508' FEL, Sec. 8, T10N, R16E X = 730,600 Y = 5,939,000 Z = 8,937' TVDss Turn Point 2424' FSL, 2709' FEL, Sec. 8, T10N, R16E X = 731,400 Y = 5,939,000 Z = 8,990' TVDss Target End: 2372' FSL, 1010' FEL, Sec. 8, T10N, R16E X = 733,100 Y = 5,939,000 Z = 9,000 TVDss [AFE Number: 14J0374 I Estimated Start Date: I 03/15/98 I I Rig: I Nabors 22E IOperating days to complete: I MD 1~8,825' [ I TVD: 19,000' [ IWell Design (conventional, slim hole, etc.): 31 I KBE: 150.02' I Isidetrack USH Objective: Sidetrack out of existing 9 5/8" csg into the HRZ,, directionally drill 8 V2" hole to the top of Z2B, set 7" liner, dir. drill 6" hole horizontally in Z2A & Z1B to LCU truncation, complete with 4 V2" Banzai liner & 4 V2" chrome. Formation Markers Formation Tops MD TVD(RKB) Begin sidetrack 12,200' 8,425 Sidetrack from Whipstock out of 9 5/8" csg into HRZ formation. Z2B 16323' 8,987' Set 7" liner in the top of Z2B TD 18,825' 9,000 TD in Z1B at LCU truncation. Casing/Tubing Program: Hole Csg/ WUFt Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 8 ½" 7" 26# L-80 Mod 10,323' 6,000/4,575' 16,323'/8,987' BTC 6" 4 ½" 12.6# 13cr NSCT 2,650' 16,175/8,981' 18,825/9000' Banzai liner 4 V2" Cr 12.6# 13cr NSCT 8,000' 5,500/4,266' 16,175/8,981' 5 V2" Cr 17# 13cr NSCT 5,470' 30'/30' 5,500'/4,266' Logging Program: I Open Hole Logs: Drilling section: MWD/GR from KOP (12,200') to Z2B. Sample catchers and rig site geologist on site before the top of the Z2B to TD. MWD/GR/4 phase resistivity in the entire 6" section (+ 16,323' - 18,824'). Mud Program: Special design considerations Standard fresh water LSND for the intermediate section. Quikdrill for the production interval. Mud Program Attached Initial Kickoff Mud Properties: 9.5/8" Kickoff (HRZ) Density 10 sec gel Yield LSR-YP Filtrate ph (PPG) Point HTHP 9.8 8-20 15-25 5-9 10.0 API 9.0 Mud Properties after kickoff: Density 10 sec gel Yield LSR-YP Filtrate ph (PPG) Point HTHP 10.5 6-15 10-25 4-8 10.0 8.5 - 9.5 Horizontal Drilling Mud Properties: Displaced at Top Zone 2 Density LSYP LSRV Chlorides ph (PPG) 8.6- 8.8 12- 20 35- 55,000 30,000 8.5- 9.0 Directional: KOP: I) 12,200' MD, drill out of 9 5/8" csg via whipstock at 109° azimuth, 42° inclination, build angle to 89° inclination, 92° azimuth to Start target, drill straight horizontal tangent to TD at + 18,825. Maximum Hole Angle: Close Approach Well: Point to point separation 89° in horizontal section There are no close approach wells to this wellbore. Cement Data: Casing/Liner Lead: Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments P&A of original well 376/15.8/1.15 "G" at 15.8 ppg 7", 26#, L-80 liner 1533/15.8/1.15 Class "G", 50% excess OH 4 V2" Banzai liner 162/15.7/1.19 Class 'G', 50% OH Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. NO ANNULAR INJECTION IN THIS WELL. 9-23A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Bottom hole pressure is 3,200 psi at 8,740' TVDss (estimated) Maximum shut-in casing pressure is 2,319 psi (assumes 0.1 psi/ft gas gradient to surface). Drilling Discussion Well Objective The DS-9 Periphery Development seeks to exploit an oil bearing geological play in the Southwest section of FS-2. The target is an unpenetrated Tango/Romeo interval bounded by the lower Cretaceous Unconformity (LCU) truncation and by either the base of the Sadlerochit or the HOT. To date this area has remained unexploited due to the need for additional seismic work (now complete) and the need for extended reach drilling capability of +15,000 ft (now available) to access the target interval. Oil in place is estimated at 8-12 MMSTB, with a potential recovery factor of 45-55%. Additional reservoir study in the region via the Frontism Model indicates that the area is unswept. Well 9-23A will be the first well into this peripheral target and will provide significant insight into the Lower Romeo truncation and fluid distribution which will provide data for the proposed 9-48A location. The timing for the conversion to an injector will depend on the reservoir pressure encountered and the logs which will indicate oil saturation. In the event that regionally &pressured pressures are encountered with 9-23A pre-production will be foregone and water injection will commence immediately. Drilling Objective The objective is to cut and pull the existing 5 ½" completion tubing above the 9 5/8" x 5 1/2" completion packer @ 12,477 ft (_+ 30ft above packer), mill window via whipstock in the 9 5/8" casing @ 12,200' MD, directionally drill 8 1/2" hole to the top of Zone 2; run, cement and test 7" liner. Directionally drill thru Z2B-Z1B to TD at + 18,825 ft MD or until the LCU truncates Z1B. The well will be completed as a Zone 1 producer with 4 1/2" chrome Banzai liner below 4 ½" x 5 ½" chrome tubing. Five GLM's will be run with depths determined after log evaluation. DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There are no wells which need to be shut in during the rig move. Well spacing of the adjacent wells is 120'. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on Anadril directional well plans. The closest actual point to point separation is 703' at 14,800', Well 9-46. The minimum tolerable separation is 701' at 14,800', Well 9-46. H__~_S, DS 9 has had H_~S reported: The highest levels of H2S from currently producing wells is 987 ppm from 9-34 measured on 6-Oct-93. Five other wells on DS 9 have reported H2S of _< 80 ppm. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) · Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; · H2S monitors with both audible and visual alarms; · Access to 5-minute emergency escape air packs; · Personal H2S monitors; · Functional wind indicator; · Posted evacuation routes (minimum of two); · Muster points in designated safe areas;__H_2S_; · Functional communications between rig camp and rig floor. PORE PRESSURE: The pore pressure in the HRZ is expected to be near 9.6ppg EMW, due to shale instability problems mud weight of 10.5 ppg will be used to drill the HRZ interval. The expected reservoir pressure in the Sadlerochit is 3,200 psi at 8740'TVDss (7.0 ppg EMW).. The planned mud weight of 10.5 ppg drilling the HRZ Shale and 8.6 - 8.8 ppg drilling Zones 2 thru 1 Sadlerochit formation will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS Tight hole, bridging, shale sloughing problems can occur in the HRZ shale. The drilling fluid will be conditioned to counteract these types of hole problems through the HRZ formation. There has also been some hole problems prior to running casing through the HRZ. This well will not cross any known faults. Lost circulation, if it occurs, will be handled using a comprehensive lost circulation decision tree. No other hole problems are expected in the production zones. Casing Shoe Kick Tolerance The smallest kick tolerance for the kick off window is calculated as infinite of influx assuming a swabbed gas influx at the top of the Sadlerochit along the planned directional path. Based on 8.7 ppg MW (TSAD 16,323' MD & 8,987' TVD 7.0 ppg reservoir pore pressure), and min. frac at the window 10.0 ppg. Pre-Rig Work 1. RU CTU. FCO sand plug 13,135' MD. 2. RU slickline and drift 5 ½"x 4 ½"tubing, tag fill. Ensure annulus is fluid packed. Note: There is a known leak in the 9 5/8" casing at + 6,500'. 3. Notify the AOGCC 24 hours prior to commencing abandonment operations. 4. RU E-line perforate 4 ½" tubing tail + 30' below TIW HBBP-L packer ( pkr set at + 12,507' MD). o P & A open perforations. RU CTU, lay in cement plug from PBTD to 12,537' MD, squeeze up to 54 bbls cement behind pipe. Open perforations at 12,982'-13,055',12,943'-12,968,12,909- 12,929',12,891'-12,901',12,858'-12,878' and 12,827-12,842'. MD. Perform P & A to 100' below bottom perforation interval, 15.8 ppg, 1.15 ft3/sx, Class 'G' cement displaced by seawater. Cement top MUST NOT be above 12,507'ft MD. Tag and test cement plugback. o RU electric line and make a chemical tubing cut in the first full joint above production packer (cut at _+ 12,477' MD). Circulate well to seawater through the cut. Freeze protect to _+ 2,200' MD. Note: If the tubing is plastic coated, run a double anchor acid cylinder cutter. 7. Test the 9 5/8" packoff and carefully cycle the LDS. 8. Set a BPV in preparation of the rig sidetrack. Rig Sidetrack Procedure 1. MIRU. ND tree, NU and test BOPE. Circulate well clean. 2. Pull the 5 ½" tubing completion. 3. Replace 9 5/8" packoff if necessary. 4. Repair the 9 5/8" casing leak if necessary. 5. Set EZSV Bridgeplug on electric line at + 12,210' MD. Mill window via Whipstock in 9.5/8" casing. 6. Kick-off and directionally drill 8.1/2" hole to + 16,323' MD. (Top of Zone 2) 7. Run, cement and test 7" L-80 production liner. Note: liner top will be set above the 9 5/8" Cretaceous Leak + 6,500' MD. 8. Directionally drill 6"horizontal hole thru Z2B-Z1B to TD + 18,825 ft MD ( 9,050' TVD). 9. Run and cement 4 1/2" chrome Banzai liner (4 ½" chrome tbg & L-80 slotted). 10. Complete well with 5 ½"x 4 1/2" 13 Cr, tubing and (5) GLM's. 11. ND BOPE, NU and test tree, freeze protect. RDMO. Well: 09-23 Spud Date:02-14-84 OriginalRKBE:55' Top of Formation: 12877' AnnularFluid:Diesel/8.5SW ReferenceLog:BHCS ARCO Alaska, Inc. - Prudhoe API #:50-029-21066-00 Completion 11-19-88 HangerType:FMC Gen III Max Hole Angle:59° @ MD: 8300' Bay Date:03-04-84 Tie In: Ann. Comm: Leak in 13-3/8" @ 780' (01/31/94); Sqz'd 13-3/8" Leak 06/04/94 ALL DEPTHS ARE .ISSSV = CAT -/f2 RKB Csg leak @ 780'; Sqz'd 06/04/94 J-1 DRILLING MD TO TOP OF EQUIPMENT EXCEPT Jewelry (J) SSSV = CAT#2 Depth 1 2228' 3 12506' 4 12507 5 12529 6 12617 7 12629 8 12630 12616 10 13117 Description 5-1/2" Camco BAL-O SSSV Nipple ID=4.562" 5-1/2" TIW Seal Assembly ID=4.875" 9-5/8" x 5-1/2" TIW HBBP-L Packer Crossover 5-1/2" x 4-1/2" 4-1/2" Otis XN Nipple ID=3.725" 4-1/2" TIW Shearout Sub 4-1/2" Tubing Tail ELM Tubing Tail (Logged 05/15/91) FISH: IBP Element (Lost 05/24/94) G-1 Min ID: 4-1/2" Otis XN Nipple ID=3.725" Type:PRODUCER Status:Workover Hanger:29' Angle @ TS:44° Angle @ TD:42° Date: 00-00-00 WHERE NOTED. J-3,4 J-5 Casing and Tubing (C) Size Weight Grade 1 13-3/8" 72% L-80 Leak @ 780' Sqz 06/04/94 2 9-5/8" 47% L-80 3 7" 299 L-80 5-1/2" 17# L-80 4-1/2" 12.6# L-80 Top Bottom Description 0' 2700' BTC Casing 0' 12567' 0' 12529' 12858' BTC Casing 13270' BTC Liner 12529' BTC-MOD Tubing-PC 12630' BTC-MODTubing-PC Gas Lift Information (G) MD TVD Stn Mandrel J-6 3435 J-7,8 6874 8673 C-2 9373 9861 Ssnd Tsg§ec 10309 @ 12744' 10760 08/30/95 11168 11617 12024 12348 P-1 (3007') 1 CA-MMG (5107') 2 CA-MMG (6109') 3 CA-MMG (6495') 4 CA-MMG (6786') 5 CA-MMG (7088') 6 CA-MMG (7397') 7 CA-MMG (7681') 8 CA-MMG (7998') 9 CA-MMG (8294') 10 CA-MMG (8536') 11 CA-MMG J-lO Perforation Interval Zone 1 12827-12842 2 12858-12878 2 12891-12901 2 12909-12929 2 12943-12968 2 12982-13035 lB Data (ELM DEPTHS) FT 15 20 10 20 25 53 Valve Type Latch CA R-20 RK CA RD0-20 RK CA RD RK CA RD RK CA RD RK CA RD RK CA RD RK CA RKED RKP (P) SPF Date Comments 4 05-17-91 APERF 4 05-04-85 IPERF 4 05-04-85 IPERF 4 05-04-85 IPERF 4 05-04-85 IPERF 4 05-04-85 IPERF Port 1/4" 7/16" TRO Date 1795 01-17-95 ORIF 04-29-9-= 06-15-92 04-29-9_= 03-27-94 C-3 Datum 8700' SS=12646' MD 8800' SS=].2784' MD PBTD=13141' TD=13270' Revision Date: 07-16-96 by ENH Reason: SSST; = CAT#2 Previous Reason: 09-11-95 DS 9-23A Proposed Completion Design Ultraslim Sidetrack Type: Producer Hanger type: FMC Gen III KB Elev.: 21' GL: 29' 13 3/8" shoe @ 2,700' 5 GLM's 4 1/2" 13cr 12.6# tbg. c>7", 26#, L-80 liner set @ 6,000' jWindow @ 12,200' 4 1/2" Banzai liner set @ 12,600' Zone 1 B 7" liner shoe @ 16,323' csg pkr nipple TO @ 18,825' Squeezed perfs from 12,827' - 13,035' Date 02-26-98 Revised by R. Kaluza Prudhoe Bay Unit APl # 50-029-21066-00 Sec. 01; T10N; R15E Anada-i 11 ~chl u~xberg~r 1111 Rash 80th Avenue Anchorage, AK 99518 (907) 3{9-45L~ Fax 344-2160 <[ Z <I DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING ~el~ ......... : DS09-23A (p%) Field ........ : Prudl%oe Bay Computation..: Minimum Cuz-va~ure Units ........ : FEET S~rf~ce La~..: 70.24281716 Surface Long.: 148.2329B038 LOCATXON8 - ALASXA Zone: 4 Legal Descrip~ion X-Coord Y-Coord Surface ...... : 54 PS~ 4931 FEL SO/ TION R15E UM 718768.24 5941533.5~ Tie-in survey: ~$02 FSL 20~ FEL S07 T10N RLe~ U~ 726774.03 $940237,4~ BSL Target...: 2449 FSL 3509 F~L SOS TION R16~ UM 730600.00 S939000.00 BHL .......... : 2372 FSL 1010 FEL ~08 T~0N R16~ L~4 733100,00 5939D0~.00 PRO~O~ED ~ELL PROFIL~ STATrON MEASURED INCLN DIRECTION VERTXCAL-DEPT~S TIE-I~ ~VSY 12195.02 ~1.72 109.20 ~421.O3 837/.01 KOP/~VE 6.00/~00 12200.00 {1.76 109.25 8424.75 8374.7~ ~2300.00 47.76 109.48 8~95.72 84~5.70 12400.00 53.76 lO9,67 8558.94 8508.92 12500.00 59.76 109.83 86~3.7] 8563,71 6.00/100 CURVE CURVE 6.D0/100 12600.00 65.76 109,98 ' 8659.49 8~09,47 12700.00 71.76 110.~1 8695.71 86{5.69 12800.00 77.75 110.23 8721.99 8671.97 12900.00 63,75 510.35 8738,05 8688.03 12932.63 85.71 I10.39 B74L.05 869L,03 16008.63 8~ .71 SECTION D~PART 8006.13 ~009,29 8076.~ 8~S0.00 8402.28 8~93.73 B587.2~ B617.99 110.39 8971.12 B921.[0 11523.0{ Prepared ..... : 26 Feb 1998 Vert $e¢= az.: 9~.66 KB elevation.: 50.02 fh Magaetic D~ln: +29.375 {E} Sca~ Factor.: 0.99995437 Convergence..: +1.66310906 ANADRILL AKA-DPC APPROVED FOP, PEP, MITTJ NG ONLY COORDINATBS-FROM ~ Zone 4 ~~ X y 1527.97 S 7965.14 E 726774.03 5940237.&4 ~529.06 ~ 7968.27 ~ 726777.19 5940236.44 ~552.4~ ~ ~034.67 H 726844.23 /578.35 S 81D7.6~ E 726917.89 5940191.22 1686.61 S 8186.29 E 726~97.35 5940165.26 ~OL ~/ FACE 100 3BR <T[~ 1R 6.00 ~R 6.00 1R 6.00 1636.87 S B269.85 E 727081.75 5940L37.43 1R 6.00 1668.80 ~ 8357.37 E 727170.15 59~0108.06 1R 6.00 ~702.06 S 8447.89 E 727261.68 5940077,~4 1R 6.00 1736.27 S B5~0.42 E 727355.0~ 5940045.93 ZR 6.00 1747.58 S 8570.88 ~ 7273ES.B5 5940035.51 HS 6.00 (Ana~riL1 (c)98 0923AP4 3.2b.5 10:06 AM P) 2816.1~ ~ 1~446,13 ~ 730290.79 5939050.9~ 82L O.O0 DS09-23A (p~) 26 Feb 1998 Pi~ge 2 STAT I ON )4RASURED r DEHTI FI CATION DEPTH 16100.00 16200.00 16300.00 END 6.00/[00 CURVE 16323.85 LC~ 16323.85 TARGET B~L 16323.85 ZONE TB L6363.55 7" CASINO PT L6403.24 ZONE 2A 17235.87 TAPd]ET ESL 18824.74 ESAD/KAV[K INCL~ DIRECTION VERTICAL-DEPTHS SECTION COORDI~ATE$-FR0~ ALeIBKA Zone 4 TOOL DL/ AAX~LE AZIMUTH TVD SUB-EEA DEPART WELLHEAD X Y FACE ~00 ~6.50 ~0~,95 8977.33 fl927.3~ ~16~.63 28~3.76 S 1~552.96 ~ 73~375,38 5939025.79 S2L 6.D0 87.40 99.01 8982.65 8932.63 1[?fl8.83 2864.48 S 1~630.60 E 750¢~6,57 5939007.92 $~L 6,00 8~.33 9~.08 8986.37 ~936.35 1~08.~2 2874,99 S 11729.93 E 73fl576.16 5959000.29 81U 6,00 88.55 91.66 8987.02 8937.00 11832.26 2875.95 S 11753.75 E 730600.00 5939000.00 KS 6.00 88.56 9L.66 8987.02 8937.00 11832.26 2875.98 S 1~753.75 E 730600.00 S939000.00 HS 6.00 88,56 91.66 8987.02 8937.00 11832,26 ~$75.98 S L1753.75 ~ ~30600.00 5939000.00 H~ 6.00 88.56 91.66 898~.02 8938.00 11871.95 2877.13 S 1L793.42 ~ 730639.68 5939000.00 HS 0.00 88.56 91.66 8989,02 8939.00 1L911.63 2878,28 8 1L833.08 ~ 730679,37 5939000.00 HS 0,00 85.$$ 91.66 9010.02 8960.00 12745.00 2902,47 S 1~666.~0 R 73~5~2.70 593~000.00 ~S O,OD 88.56 91.66 9050.0~ 9880.00 14332.36 2948.53 S ~252.79 ~ 733100.00 5939000.00 0.00 1882~.74 88.56 91.66 9050.02 9000.00 9075.02 9025.00 14332.36 2948.53 S L4252.79 R 733100.00 5939000.00 0.00 ANADP-J LL A~ ~ ~O~Jr~ D A~'----~c~' FOR pERMiTTING ONLY PLAN (Anad~ill (c)98 0923AP4 3.2b.5:0:06 AM P) SHARED SERVICES DRILLING n ANADRILL AKA-DPC ~4nadri ] ] Schlumberger DS09-23A (P4) VERTICAL SECTION V EN · Section at: 9~.66 TVO Scale' ~ inch = 2000 feet Oep Scale' ! inch = 2000 feet Drawn ' 26 Feb ~998 z m ii Marker Identification MD BKB SECTN INCLN A) TIE-I~ SURVEY J2~95 8421 8006 4~.72 B) KOP/CURVE 6.00/~00 J2200 8425 8009 4t.76 O} END 6.00/~00 CURVE ~2933 8741 8618 85.7~ D] CURVE 6.00/100 26009 8971 J1523 85.7! E] END 6.OO/JO0 CURVE [6324 8987 11832 88.56 F) TARGET 8SL 16324 8987 t]832 BB.5B G) 7' CASING PT 18403 8989 11912 88.56 H) TARGET ESL 18825 9050 14332 88,56 I) T0/4-1/2" LINER PT 18825 90§0 14332 88,56 ~ t200C "- 0 (~adril] (c)~ 0923~4 3.~.05 lO:~ ~ PI iO00 2000 3000 4000 5000 6000 7000 8000 9000 10000 lJO00 12000 13000 14000 15000 16000 17000 Section Departure SHARED SERV];C ..... MD .... BYe" SECTR" ' ' rm.L'N' .................................................... ': :-:~ -~-' ................................................................... A} TIE-IN SURVEY t2:~95 842~ 8008 41.72 8] K~/CU~VE 6.00/tO0 ~2200 8425 8009 4 t. 76 0 E~D 6.00/100 C~VE ~2933 874[ 8618 85.7~ D) CURVE 6.00/t00 t6009 897t Jt523 85.7t E) END 6.00/100 CURVE 16324 8987 ii832 88.~ Fl TARBET BSL ~6324 8981 tt83a 88.56 6] 7" 6A8~6 Pf i6403 8989 t tgt8 88.56 H) T~OET ESL ~8825 9050 t43~2 88.56 [) 78/4-t/2" LINER PT ~88~5 9050 ~4332 ~.56 ANADRILL AKA~DPC APPROVED FOR PERMITTING ONLY PLAN :J:J: L~_ Dsog-23A (P4) VERTZCAL SEOTZON VZEN ~ect~on al: 91,66 'VD Scale - i inch = 800 feet lep Scale.' 1 inch = 800 Ceet )fawn ' 26 Feb 1998 7600 8000 8400 8800 [~n~dr~]] [clgB 0923~P4 3'.2b.05 ]o:34 .Al~ P} 9200 9600 10000 30400 30800 ii2oo 116oo i2ooo ~24oo Seclion Oeparture 12800 J3~O ~3600 14000 14400 ~4BO0 W 0_ Z iii ii i iiIll DSO'9"'23A'(P41 ............. PLAN V~E~ __ CLOSURE · 14555 feet at Azimuth ~01,69 OECLINAIION.' +29.375 (£) SCALE -' ~ inch = lBO0 feet DRAWN ' 26 Feb J998 SHARED A) TIE-II~ SURVEY 12195 B) KOP/CUFIVE 6.00/100 1P200 C) END 6.00/100 CURVE ]2.933 D) CURVE 6.00/tOO 16009 E) END 6.00/~00 CURVE ~6324 F) TARGET 8SL ~6324 G) 7" CASING PT 16403 FI] TARGEI ESL IB825 ~) TD/4-1/2" LINER PT ~8825 SERVICES DRI! L lNG N/S E/W t528 S 7965 E 1529 S 7968 E 1748 S 8571E 28J6 S t~44§ E 2876 S ]]754 E 2876 S ~1754 E 2878 S 11833 E 2949 S 14253 E 2949 S t4~53 E ANADRILL AICA-DPC APPROVED FOR PERMITTING ONLY PLAN ~___~ -- ~~,._ n E~ large' (PointJ _ , .., _ . _ · .. __ _ ll') ~ ~m,r~ ~ ann ,.~'-r n n .,~ ~.n 180O 2700 3600 4500 5400 6300 7200 8iOO 9000 9900 10800 It700 ]2600 }3500 14400 15300 <- WEST' EAST -> ~nmdnt[) (cl~ O~3.qP'4 3.2b.~ ~0:37 ~H ~) ........................... w o_ n/ z i _l· il J i ! i i i t ,,, SBA,nED ,S,FRVIC' S 'OBI[[ i"NG _~ . . __~ ..... ~ o . .... ...... USO "-2'3A ....... PLAN V Il I ' Il I I I CLOSURE ' 14555 teet at Azimuth lO~o6g )ECLINATION.' +29.375 [E) " '/ ' ;CALE ....... : ~ inch = 800 feet .. ..._ )RAWN. ' 26 Feb 1998 ¢ ;,,.,., .... - ........_____ , , , , ~rk8 r Identification NO N/S E/~ . I] K~/OURVE 6,0g/tO0 ~ao t529 s 7968 E )) CURVE 8.00/t00 16009 2816 S t~446 E _ ~) END 6.00/t00 CURVE 16324 2876 S ~754 E I. ..... "~" "~ ,~-i~;~ · :~ TAR~f B~ 16324 2876 S Jt754 E )} 7~ CASI~ PT ~6403 2878 S 11833 E ..... ~"~'~ '~'~ 0 IARGET ESL J8825 2949 S 14253 E '.) ~0/4-t/2" L]NER PT ~8825 2949 S 1425~ E ~~ '' " " I ........ _ ... ~ ~.. _ ~ , , 8O0 ~00 8400 BBO0 9200 9600 EAST -> 10000 10400 10800 ~200 Ii600 t2OOO ~2400 12800 13200 13600 i m ii i · il i m 3200 14000 14400 · O0 I DATE J CHECK NO H 13 4 516 o2,,'2o?,~/ VENDOR ALASKAST 14- OO DATE INVOICE CREDIT MEMO DESCRIPTION GRo~ DISCOUNT NET 0~1898 CKO~iS~SA lO0. O0 lOO. O0 HANDLIN~ INST: s/h terrie bubble x 4628 'HE A~ACHEO CHECK IS IN PAYMENT FOR ~EMS DE~RIBED ABOVE. mm~e)li1~l ! OO. OO ! OO. OO STATE OF ALASKA ,, ALASKA OIL AND GAS CONSERVATION COMMISSION Revised: 02/25198 APPLICATION FOR SUNDRY APPROVAL ~. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing l~ Repair Well [] Pull Tubing [] Variance [:~ Other [] Change Approved Program [-~ Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack '2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) ARCO Alaska Inc. [] Development 55' RKB E~ Exploratory 7. Unit or Property Name '3. Address ' ' E~ Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 I--]Service ... '4. Location of well at surface 8.' Well Number 09-23 55' NSL, 349' EWL, SEC. 01, T10N, R15E, UM 9. Permit Number At top of productive interval 84-3 / 96-107 1629' SNL, 1610' WEL, SEC:",,O.7, T10N, R16E, UM 10. APl Number At effective depth " 50~029-21066 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe Bay 1760' SNL, 1336' WEL, SEC. 07, T10N, R16E, UM Pool 12. Present well condition summary Total depth: measured 13270 feet Plugs (measured) Sand Plug tagged at 12744' (08/3~ true vertical 9209 ' feet~' "i .~____~~, Effective depth: 'measuredtrue vertical 127448825 feetfeet Junk (measured) ........ -''..,.~!~: i" 'i. ...... i:'.iiii'I ...i'i:.-'i ?'i, " Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 1860# Poleset 80' 80' Surface 2669' 13-3/8" 3600 sx CS III, 400 sx CS II 2700' 2525' Intermediate Production 12827' 9-5/8" 500 sx Class 'G', 300 sx CS I 12858' 8906' Liner 703' 7". 300 sx Class 'G' '12567' - 13270' 8696' - 9209' ,i , Perforation depth: measured 12827' - 12842', 12858' - 12878', 12891' - 12901', 12909' - 12929', 12943' - 12968', 12982' - 13035' true vertical 8883' - 8894', 8906' - 8921', 8930' - 8936', 8943' - 8957', 8967' - 8985', 8995' - 9034' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 12529'; 4-1/2", 12.6#, L-8012529' - 12630' Packers and SSSV (type and measured depth) Camco Bal-O SSSV at 2228'; TIW HBBP-L packer at 12507' 13' Attachments [~ Description summary of proposal ~-q Detailed operations program E~ BOP sketch i41 Estimated date fc~'~- commencing operation 15. Status of well Classifications as: ..... March 4, 1998 16. I'f' Proposal was verl~ally approved ..... ¢;~ Oil r--] Gas ['-] Suspended Service ..Name of app..rover.. Date app. roved ....... contact Engineer Name/Number: Bob Kaluza, 564-5344 Prepared By Name/Number:. Terrie Hubble, 564-4628 17' I hereby certifY th~'L)the f°re§°in'~J is tru 'e ~:tnd c°rrect t° the best °f my kn°wledgeSigned///,¢¢_¢.,Z r '' '~ ~/("~ James Smith k'-~¢,¢~'¢~,,~ ~-'.'7~/,.- ~';;'~' .Title EncjineeringSupervisor Date /~ Commission Use Only J Approval No.__,2~-~,_~'~ Conditions of Approval: Notify Commission so .representative may witness Plug integrity ~ BOP Test Location clearance_ ~ ,_- .,.~- ' Mechanical Integrity Test ___ Subsequent form required 10~ "~'. O'I ., O~-¢ Approved by order of the Commission -Fnrm 1N-4Ng; Rc_v NR/1 R/RR '~-~ L~.~¢'"'~'-'~ ~'~'"~ ¥'''~' ~A~nn~,, ......... Commissioner Datest~hm,itt~n.T~ioli~a~e · WELL PERMITCHECKLIST COMPANY//~,/", _,~_ FIELD&POOL _/~'~'~'~::~j~('~., INIT CLASS ~.'_~ /Z--,~.,,,~2 WELL NAME /'~,~,/ _~'- ,~_~ PROGRAM: exp [] dev/~redrll [] serv [] wellbore seg E. ann, disposal para req 13 GE-OL'AREA ~:;2~?' ~ ' UNIT#" ,///~--~'._'¢'~:) ON/OFF SHORE <::~'"~/ ADMINISTRATION 1 1 ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3 Unique well name and number .................. 4. Well located in a defined pool ................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............. 9. Operator only affected party ................. 0. Operator has appropriate bond in force ............. 1. Permit can be issued without conservation order ....... 2 Permit can be issued without administrative approval ..... 3. Can permit be approved before 15-day wait .......... 14. Conductor string provided ................... Y 15. Surface casing protects all known USDWs ........... Y ~ ~~' 16. CMT vol adequate to circulate on conductor & sud csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ Y 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... Y(~N 25. BOPEs, do they meet regulation ..... ~i N 26. BOPE press rating appropriate; test to 27. Choke manifold complies w/APl RP-53 (May 84) ........ J~.-~'"" 28. Work will occur without operation shutdown .......... 29. Is presence of H?S gas probable ................. , N REMARKS GEOLOGY 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. * 33. Seabed condition survey (if off-shore) ........... ~ Y N 34. Contact name/phone for weekly,progress repo, rts . . ..,~... Y N lexp~oratory on~yj GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ ~ JDH~ R N C_.,~___~_~) co L'z)~./~/~r Comments/Instructions' ItOW/l¢ - A \FflRMS~!*u,kh!q r,,v (,u,q WELL PERMIT CHECKLIST FIELD & POOL ADMINIST~It. TION I ENGINEERING %D~ATE qtrl Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... COMPANY 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~'~:~x~(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ PROGRAM: exp dev ,,,~ redrll ~ serv wellbore seg ann. disposal para req Y N Y N UNIT# .... ,/~.//.~_.~..-I ON/OFF SHORE Y N N N N (~N ~ N 28. 29. (~N Work will occur without operation shutdown ........... N Is presence of H2S gas probable. - N Permit can be issued w/o hydrogen sulfide measures ..... Y N ~' ,,,'/~,//~,~-~ . Data presented on potential overpressure zones ....... Y~N' ' '"' ' ' ° Seismic analysis of shallow gas zones ............. /N _ ............ ~~on/y] Y N Seabed condition survey (if off-shore) Y N Contact name/phone for weekly progress reports [explore Y N GEOLOGY ANNULAR DISPOSAL APPR DATE 30. 31. 32. 33. 34. 35. With proper ceme~ng records, this plan ~ (A) will contain wast~,,~ suitable receivi~.ng~one; ....... (B) will not cont~w~ause ddlling waste... to surface; ~ (C) will not impa'r m~nteg '~ the well used for disposal; (D) will not dama.~ge~roducing forrnation~p,.~air recovery from a pool; and~-"' ~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.4 GEOL~.,GY: Y N Y N Y N Y N ENGINEERING:, U I C~"'/'~r~7- JDH ~ Y N COMM~ DWJ ~ RNC , co co Comments/Instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Oct 19 14:01:36 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-80185 J. PANTER R. JAYE D.S. 9-23A PB1 500292106670 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 19-0CT-98 1 I0N 015 55 349 .00 OCT ?_8 1998 ._. ,~, r~, & Gas ~ns DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 49.60 20.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 80.0 13.375 2669.0 9.625 12386.0 8.500 12630.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GIEGER- MUELLER TUBE DETECTORS. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN B WATSON OF ARCO ALASKA, INC. AND A TURKER OF SPERRY- SUN DRILLING SERVICES ON 10/12/98. 5. MWD RUNS 1-2 REPRESENT WELL 9-23A PB1 WITH API# 50-021066-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12630'MD, 8742'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12365.5 12586.0 ROP 12409.5 12630.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 12408 . 0 12630 . 0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12365.5 12630 12497.8 530 12365.5 GR 71.9535 319.651 130.162 442 12365.5 ROP 6.5396 636.328 40.3855 442 12409.5 Last Reading 12630 12586 12630 First Reading For Entire File .......... 12365.5 Last Reading For Entire File ........... 12630 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12365.5 ROP 12409.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/M ANGLE: STOP DEPTH 12586.0 12630.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 08-APR-98 5.07 5.46 MEMORY 12630.0 12408.0 12630.0 41.8 43.0 TOOL NUMBER P0991CG6 8.500 8.5 LSND 10.30 54.0 10.5 1800 3.5 .000 .000 .000 .000 50.0 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12365.5 12630 12497.8 530 12365.5 GR 71.9535 319.651 130.162 442 12365.5 ROP 6.5396 636.328 40.3855 442 12409.5 Last Reading 12630 12586 12630 First Reading For Entire File .......... 12365.5 Last Reading For Entire File ........... 12630 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 21 10:19:26 1999 Reel Header Service name ............. LISTPE Date ..................... 99/07/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/07/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: 9-23A 500292106601 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 21-JUL-99 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-90081 AK-MM-90081 AK-MM-90081 K.FERGUSON R.KRELL R.KRELL M.JACKSON M.JACKSON T. ELGEN REC,E VED ,IUI ..... 29 1999 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 3 AK-MM-90081 R.KRELL T. ELGEN MWD RUN 4 AK-MM-90081 K. FERGUSON T. ELGEN 1 10N 15E 55 MWD RUN 4 AK-MM-90081 K. FERGUSON T. ELGEN FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 349 49.40 49.40 20.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 7.000 16235.0 6.000 18000.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. TWO MEASUREMENT AFTER DRILLING (MAD) PASSES WERE PERFORMED WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUNS 3 AND 4. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 5. MWD DATA HAS BEEN DEPTH SHIFTED/CORRECTED USING THE CNL GR FOR PARENT WELL 9-23. WL-GR DATA WAS LOGGED BY SCHLUMBERGER IN 1984. KBE= 55' 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18000'MD, 9044'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9400 0 17958.0 ROP 9600 5 18000.0 FET 16202 5 17965.0 RPD 16202 5 17965.0 RPM 16202 5 17965.0 RPS 16202 5 17965.0 RPX 16202.5 17965.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9400 0 9415 5 9422 5 9434 0 9437 0 9451 5 9453.5 9493.5 9496.5 9516.0 9526.0 9531.5 9545.5 9558.0 9561.5 18000.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: GR 9400 0 9415 5 9424 5 9433 5 9439 0 9454 0 9455 5 9495 5 9497 5 9515 5 9524 0 9529.5 9542.5 9557.0 9561.0 17999.5 EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record MERGED MAIN PASS. $ Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined BIT RUN NO MERGE TOP MERGE BASE 1 9600.0 10648.0 2 10648.0 16235.0 3 16235.0 17485.0 4 17485.0 18000.0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD FT/H 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max DEPT 9400 18000 ROP 0 1785 GR 13.34 333.74 RPX 0.12 1000.79 RPS 0.14 1070.48 RPM 0.67 2000 RPD 1 2000 FET 0.47 122.33 First Last Mean Nsam Reading Reading 13700 17201 9400 18000 99.1855 16800 9600.5 18000 110.027 17117 9400 17958 6.19534 3526 16202.5 17965 7.00971 3526 16202.5 17965 29.5791 3526 16202.5 17965 31.561 3526 16202.5 17965 5.77534 3526 16202.5 17965 First Reading For Entire File .......... 9400 Last Reading For Entire File ........... 18000 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ START DEPTH STOP DEPTH 16222.0 17977.5 16222.0 17977.5 16222.0 17977.5 16222.0 17977.5 16222.0 17977.5 16222.0 17961.0 MAD RUN NO. MAD PASS NO. 3 4 MERGE TOP 16235.0 17485.0 REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 17485.0 18000.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 Name Min Max Mean DEPT 16222 17977.5 17099.8 GR 9.82 140.53 42.5163 RPX 0.19 19.25 4.92104 RPS 1.22 19.94 5.97866 RPM 0.85 2000 7.60926 RPD 0.25 2000 27.6299 FET 5.17 193.92 36.0108 Ns am 3512 3479 3512 3512 3512 3512 3512 First Reading 16222 16222 16222 16222 16222 16222 16222 Last Reading 17977.5 17961 17977.5 17977.5 17977.5 17977.5 17977.5 First Reading For Entire File .......... 16222 Last Reading For Entire File ........... 17977.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9400.0 10605.5 ROP 9600.0 10648.0 $ LOG HEADER DATA DATE LOGGED: 21-FEB-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10648.0 TOP LOG INTERVAL (FT) : 9600.0 BOTTOM LOG INTERVAL (FT) : 10648.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 53.5 MAXIMUM ANGLE: 70.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P1260HWGV6 8.500 8.5 LSND 10.20 58.0 12.2 6000 8.1 .000 .000 .000 .000 119.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9400 10648 10024 2497 9400 GR 26.06 120.21 69.7195 2412 9400 ROP 2 1785 123.313 2097 9600 Last Reading 10648 10605.5 10648 First Reading For Entire File .......... 9400 Last Reading For Entire File ........... 10648 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10606.0 16189.0 ROP 10648.5 16235.0 $ LOG HEADER DATA DATE LOGGED: 28-FEB-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 16235.0 TOP LOG INTERVAL (FT) : 10648.0 BOTTOM LOG INTERVAL (FT) : 16235.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 67.5 MAXIMUM ANGLE: 71.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUkL GAMM~ R~Y $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P1260HWGV6 8.500 8.5 LSND 10.60 46.0 9.2 1000 3.3 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 147.0 First Name Min Max Mean Nsam Reading DEPT 10606 16235 13420.5 11259 10606 GR 31.58 333.74 140.005 11167 10606 ROP 0 537 106.449 11174 10648.5 Last Reading 16235 16189 16235 First Reading For Entire File .......... 10606 Last Reading For Entire File ........... 16235 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 16202.0 27449.5 RPD 16202.0 17449.5 RPM 16202.0 17449.5 RPS 16202.0 17449.5 RPX 16202.0 17449.5 GR 16202.0 17441.5 ROP 16235.5 17485.0 $ LOG HEADER DATA DATE LOGGED: 08-MAR-99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 17485.0 TOP LOG INTERVAL (FT) : 16235.0 BOTTOM LOG INTERVAL (FT) : 17485.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 71.1 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P1268GRV4 P1268GRV4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 8.80 50.0 9.0 26000 6.2 .120 .100 .100 .300 .5 Name Service Order Units Size Nsam Rep Code Offset ChanneI DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 135.0 Name Min Max Mean Nsam DEPT 16202 17485 16843.5 2567 GR 13.34 116.5 29.4898 2480 RPX 0.12 1000.79 5.63257 2496 RPS 0.14 1070.48 6.27841 2496 RPM 0.67 2000 37.7972 2496 RPD 1 2000 40.3501 2496 ROP 1 1784 73.2884 2500 FET 0.47 122.33 5.36753 2496 First Reading 16202 16202 16202 16202 16202 16202 16235.5 16202 Last Reading 17485 17441.5 17449.5 17449.5 17449.5 17449.5 17485 17449.5 First Reading For Entire File .......... 16202 Last Reading For Entire File ........... 17485 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX 17442 0 17450 0 17450 0 17450 0 17450 0 17450 0 STOP DEPTH 17957.5 17964.5 17964.5 17964.5 17964.5 17964.5 ROP 17485.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17999.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 12 -MAR-99 INSITE 3.2 MEMORY 18000.0 17485.0 18000.0 84.4 92.5 TOOL NUMBER P1257GRV4 P1257GRV4 6.000 6.0 LSND 8.80 54.0 9.1 27000 6.3 .120 .100 .110 .250 .5 141.0 Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR RPX RPS RPM RPD ROP FET Service Order Units Size Nsam Rep FT 4 1 68 MWD 4 API 4 1 68 MWD 4 OHMM 4 1 68 MWD 4 OHMM 4 1 68 MWD 4 OHMM 4 1 68 MWD 4 OHMM 4 1 68 MWD 4 FT/H 4 1 68 MWD 4 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 17442 17999.5 17720.8 1116 GR 17.45 123.99 73.5749 1032 RPX 2.22 19.16 7.55912 1030 RPS 2.98 23.45 8.78186 1030 RPM 3.5 30.13 9.66424 1030 RPD 3.9 92.98 10.2626 1030 ROP 1 1491 34.0544 1029 FET 0.75 50.21 6.7636 1030 First Reading 17442 17442 17450 17450 17450 17450 17485.5 17450 Last Reading 17999.5 17957.5 17964.5 17964.5 17964.5 17964.5 17999.5 17964.5 First Reading For Entire,File .......... 17442 Last Reading For Entire File ........... 17999.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RLTNNI/MBER: MAD PASS NUMBER: FILE SUMMARY .5000 3 VENDOR TOOL CODE START DEPTH STOP DEPTH FET 16221.5 17442.5 RPD 16221.5 17442.5 RPM 16221.5 17442.5 RPS 16221.5 17442.5 RPX 16221.5 17442.5 GR 16221.5 17425.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 08-MAR-99 INSITE 3.2 MEMORY 17485.0 16235.0 17485.0 71.1 93.6 TOOL NUMBER P1268GRV4 P1268GRV4 6.000 6.0 LSND 8.80 50.0 9.0 26000 6.2 .120 .100 .100 .300 135.0 MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 3 API 4 1 68 RPX MAD 3 OHMM 4 1 68 RPS MAD 3 OHMM ,4 1 68 RPM MAD 3 OHMM 4 1 68 RPD MAD 3 OHMM 4 1 68 FET MAD 3 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 Name Min Max Mean Nsam DEPT 16221.5 17442.5 16832 2443 GR 9.82 109.83 28.597 2409 RPX 0.19 8.31 4.13714 2443 RPS 1.22 10.38 4.98753 2443 RPM 0.85 2000 6.90923 2443 RPD 0.25 2000 35.4572 2443 FET 6.26 193.92 30.6948 2443 First Reading 16221.5 16221.5 16221.5 16221.5 16221.5 16221.5 16221.5 Last Reading 17442.5 17425.5 17442.5 17442.5 17442.5 17442.5 17442.5 First Reading For Entire File .......... 16221.5 Last Reading For Entire File ........... 17442.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Sperry-Sun Drilling Services LIS Scan Utility Mon Oct 19 23:16:59 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: D.S. 9-23A 500292106601 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 19-OCT-98 MWD RUN 4 MWD RUN 5 MWD RUN 6 AK-MM-80185 AK-MM-80185 AK-MM-80185 J. PANTER J. PANTER J. PANTER R. JAYE R. JAYE P. WILSON JOB NUMBER: LOGGING ENGINEER: OPER3~TOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 7 AK-MM-80185 J. PANTER P. WILSON 1 10N 015 FNL: FSL: 55 FEL: FWL: 349 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 49.60 GROUND LEVEL: 20.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 20.000 80.0 2ND STRING 13.375 2669.0 3RD STRING 9.625 11297.0 PRODUCTION STRING 8.500 16397.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 3 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 4-7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERS- ATION BETWEEN B WATSON OF ARCO ALASKA, INC., AND A TURKER OF SPERRY-SUN DRILLING SERVICES ON 10/12/98. THIS DATA IS CONSIDERED PDC. 5. MWD RUNS 4-7 REPRESENT WELL 9-23A WITH API#: 50-029-21066-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16397'MD, 8976'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11291.5 16345.5 ROP 11318.0 16397.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 4 11320.0 11450.0 5 11450.0 11531.0 6 11531.0 13417.0 7 13417.0 16397.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11291.5 16397 13844.2 10212 11291.5 GR 23.8672 463.451 181.944 10109 11291.5 ROP 0.6804 1021.29 154.107 10159 11318 Last Reading 16397 16345.5 16397 First Reading For Entire File .......... 11291.5 Last Reading For Entire File ........... 16397 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11291.5 ROP 11318.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : STOP DEPTH 11422.0 11449.5 12-APR-98 5.07 5.46 MEMORY 11450.0 11320.0 11450.0 45.1 46.0 TOOL NUMBER P0991CG6 8.500 8.5 LSND 10.30 60.0 10.0 1400 FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 48.3 First Name Min Max Mean Nsam Reading DEPT 11291.5 11449.5 11370.5 317 11291.5 GR 46.4894 113.631 81.0428 262 11291.5 ROP 2.1497 1021.29 118.038 264 11318 Last Readin9 11449.5 11422 11449.5 First Reading For Entire File .......... 11291.5 Last Reading For Entire File ........... 11449.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11423.0 ROP 11451.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : STOP DEPTH 11503.5 11531.0 14-APR-98 5.07 5.46 MEMORY 11531.0 11450.0 11531.0 43.5 44.0 TOOL NI/MBER P0991CG6 8.500 8.5 LSND 10.30 600.0 9.7 1400 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 48.9 First Name Min Max Mean Nsam Reading DEPT 11423 11531 11477 217 11423 GR 64.9159 124.592 101.546 162 11423 ROP 0.6804 987.891 82.3841 161 11451 Last Reading 11531 11503.5 11531 First Reading For Entire File .......... 11423 Last Reading For Entire File ........... 11531 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Sez-vice name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 17388.0 17977.0 RPD 17388.0 17977.0 RPM 17388.0 17977.0 RPS 17388 . 0 17977 . 0 RPX 17388.0 17977.0 GR 17388.0 17960.5 $ LOG HEADER DATA DATE LOGGED: 12 -MAR- 99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2 DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 18000.0 TOP LOG INTERVAL (FT) : 17485.0 BOTTOM LOG INTERVAL (FT) : 18000.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER P1257GRV4 P1257GRV4 6.000 6.0 LSND MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHM_M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.80 54.0 9.1 27000 6.3 .120 .100 .110 .250 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 4 API 4 1 68 4 2 RPX MAD 4 OHMM 4 1 68 8 3 RPS MAD 4 OHMM 4 1 68 12 4 RPM MAD 4 OHMM 4 1 68 16 5 RPD MAD 4 OHMM 4 1 68 20 6 FET MAD 4 HOUR 4 1 68 24 7 141.0 First Name Min Max Mean Nsam Reading DEPT 17388 17977 17682.5 1179 17388 GR 15.05 140.53 70.4127 1146 17388 RPX 2.09 19.25 6.39909 1179 17388 RPS 2.37 19.94 7.84142 1179 17388 RPM 2.67 20.72 8.74684 1179 17388 RPD 3.23 34.21 9.25342 1179 17388 FET 5.17 106.2 44.3501 1179 17388 Last Reading 17977 17960.5 17977 17977 17977 17977 17977 First Reading For Entire File .......... 17388 Last Reading For Entire File ........... 17977 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/07/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/07/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11504.0 ROP 11532.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13366.0 13417.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 16-APR-98 5.07 5.46 MEMORY 13417.0 11531.0 13417.0 49.8 79.2 TOOL NUMBER P0992CG6 8.500 8.5 LSND 10.30 600.0 9.0 1400 3.4 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 59.8 First Name Min Max Mean Nsam Reading DEPT 11504 13417 12460.5 3827 11504 GR 47.5487 299.005 162.416 3725 11504 ROP 4.7767 356.647 141.159 3771 11532 Last Reading 13417 13366 13417 First Reading For Entire File .......... 11504 Last Reading For Entire File ........... 13417 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NLTMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13367.0 ROP 13418.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 16345.5 16397.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 19-APR-98 5.07 5.46 MEMORY 16397.0 13417.0 16397.0 44.0 85.4 TOOL NUMBER P0991CG6 8.500 8.5 LSND 10.30 55.0 9.0 1100 10.0 .000 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 API 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 67.7 First Name Min Max Mean Nsam Reading DEPT 13367 16397 14882 6061 13367 GR 23.8672 463.451 200.786 5958 13367 ROP 6.5771 782.734 165.876 5959 13418 Last Reading 16397 16345.5 16397 First Reading For Entire File .......... 13367 Last Reading For Entire File ........... 16397 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/10/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
