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Home My WebLink About188-071MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, February 21, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-29 PRUDHOE BAY UNIT W-29 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/21/2023 W-29 50-029-21834-00-00 188-071-0 W SPT 8501 1880710 2125 1095 1098 1093 1094 4 4 4 4 4YRTST P Brian Bixby 1/7/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT W-29 Inspection Date: Tubing OA Packer Depth 355 2504 2439 2425IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230108032733 BBL Pumped:2.9 BBL Returned:3 Tuesday, February 21, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, January 14, 2019 P.I. Supervisor ��', %�' 1/1 j lint SUBJECT: Mechanical Integrity Tests 2162 BP EXPLORATION (ALASKA) INC. 2tss- W-29 FROM: Adam Earl PRUDHOE BAY UNIT W-29 Petroleum Inspector 2125 ]A Ste: Inspector F21� - Reviewed B�y� 283 P.I. Suprv:l NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-29 API Well Number 50-029-21834-00-00 Inspector Name: Adam Earl Permit Number: 188-071-0 Inspection Date: 1/5/2019 lnsp Num: mi[AGE190106115032 Rel lnsp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type Inj TVD 8501 Tubing 2162 2tss- 215TCST SPI TCSt psi 2125 ]A 5362900 F21� - 2844 - 283 Pumped: 5.4 13BL Returned: 33 - OA 4 3 1 - I val 4YRTST P/F P Notes: MIT IA Monday, January 14, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Friday,February 06,2015 ee'e, Z-' 6/1 5 SUBJECT:Mechanical Integrity Tests P.I.Supervisor (( g y BP EXPLORATION(ALASKA)INC W-29 FROM: Jeff Jones PRUDHOE BAY UNIT W-29 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv`r - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT W-29 API Well Number 50-029-21834-00-00 Inspector Name: Jeff Jones Permit Number: 188-071-0 Inspection Date: 1/18/2015 Insp Num: m10J150206100032 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WeII W-29 Type lnj w f VD 8501 Tubing 1346 1347 ' 1344 ' 1339 - rt 1880710 SPT 2125 343 i 2505 2464 2460 PTD I IType Test Test psi HIA Interval 4'RTST 1P/F P ' [ OA 1 4 . 6 4 � 3 Notes: 3 4 BBLS methanol pumped. I well inspected,no exceptions noted Friday,February 06,2015 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 12, 2011 TO: Jim Regg � 4 . 4113, P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W -29 FROM: Lou Grimaldi PRUDHOE BAY UNIT W -29 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT W - 29 API Well Number: 50 029 - 21834 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG110303144258 Permit Number: 188 - 071 - Inspection Date: 3/3/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-29 " 1Type Inj. G TVD 8501 ' IA 280 3290 3190 3160 P.T.D 1880710 ' TypeTest j SPT Test psi 2125 OA 10 20 20 20 Interval 4YRTST P/F P '" Tubing 2110 2110 2120 2120 Notes: MIT to 3300, good results. 4.1 barrels up and 4.0 back. Reported as variance required but no paperwork in wellhouse. L. . .b record of Jekt - ,.. e C- A /a\ £ �F S wrsisrs Tuesday, April 12, 2011 Page 1 of 1 • ~~Q~~ Oo ~ ada~~(Q /~....~..~~o~,~a Jack Lau O ~ l Petroleum Engineer ~~ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-29 Sundry Number: 310-210 Dear Mr. Lau: .:~..~3i~~i~ ,ii,l ~ %0~ 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 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. DATED this ~ day of July, 2010. Encl. STATE OF ALASKA ~~~ ALASK~L AND GAS CONSERVATION COMMISSI~ ~ ~q. ~'~ APPLICATION FOR SUNDRY APPROVALS ,l 20 AAC 25.280 ~r~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Chang Approved Program ^ Suspend ^ Plug Perforations ^ Perforate^ a Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^~ ~~ Alter Casing ^ ^ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 188-0710 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ _ ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21834-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU W 29 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028263 ~ PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10950 _ 9166.21 10908 9135.41 NONE 108031/21/07 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30 110 30 110 Surface 2651 13-3/8" 68# L-80 29 2680 29 2680 5020 2270 Production 10358 9-5/8" 47# L-80 28 10386 28 8752 6870 4760 Liner 796 7"26# L-80 10154 10950 8683 9166 7240 5410 Liner Pertoration Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 34 10182 Packers and SSSV Tvoe: 7" X 4-1/2" BKR PACKER Packers and SSSV MD and ND (ftl: 10041 8501 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/15/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^~ _ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jack Lau Printed Name Jacl au Title P E Signature Phone Date 564-5102 7/8/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY ~~ o ^~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: cc C ~~CjG~V1~D JUL 0 ~' 2010 Subsequent Form Required: / Q - ~ ~ `- Alaska Oii & Gu GORAz Cotnrrnsslon AOGPIQ~~~N APPROVED BY y' ~^ / Approved by: COMMISSIONER THE COMMISSION Date: S naunn~ ,fit,. ,, a ~r ~~ ~ _ ~~ _~ ~ 7~ ~~ QL ~y/a Form 10-403 Revised 1/2010 0 ~ I N Submit in Duplicate W-29 188-071 PERF ATTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base W-29 8/14/88 PER 10,700. 10,714. 8,982.69 8,993. W-29 8/14/88 PER 10,725. 10,742. 9,001.1 9,013.61 W-29 10/14/88 APF 10,652. 10,690. 8,947.27 8,975.32 W-29 10/14/88 APF 10,758. 10,773. 9,025.37 9,036.39 W-29 7/17/04 APF 10,610. 10,640. 8,916.19 8,938.39 W-29 7/14105 BPS 10,132. 10,773. 8,567.05 9,036.39 W-29 2/10/06 BPP 10,132. 10,773. 8,567.05 9,036.39 W-29 10/19/06 BPS 10,037. 10,773. 8,497.82 9,036.39 W-29 12/28/06 APF 5,480. 5,482. 5,074.17 5,075.65 W-29 12/30/06 BPS 5,661. 5,670. 5,207.29 5,213.84 W-29 12/30/06 SPS 5,622. 5,661. 5,178.86 5,207.29 W-29 1/1/07 APF 5,167. 5,172. 4,838.52 4,842.31 W-29 1/2/07 SQZ 5,150. 5,661. 4,825.63 5,207.29 W-29 1/3/07 OH 5,150. 5,670. 4,825.63 5,213.84 W-29 2/16/07 BPP 10,037. 10,773. 8,497.82 9,036.39 W-29 5/26/08 APF 10,560. 10,585. 8,879.15 8,897.66 W-29 5/26/08 APF 10,595. 10,610. 8,905.07 8,916.19 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ No Accidents, N~arm to People, and No damage To: Tyler Norene/Clark Olsen Wells Services Operation Team Lead From: Ben Geyer, Engineering Intern Jack Lau, Wells Engineer Subject: W-29 Bullhead HCI treatment $50M AFE: APBWPDWL29 100 Environment Date: June 16, 2010 (w:564-4928 c:740-704-6888) (w: 564-5102 c: 227-2760) Cost: IOR: Please perform a Bullhead Mud Acid treatment on W-29 following the procedure below. 1 F Bullhead HCI treatment Current Status: Operable Miscible Injector Last Test: 07/05/10: 4,929 bbls Inj.; 2,174 psi WHIP Max Inclination: 46° at 6,200'MD; Top Perf-42° @ 10,560' MD Max Dog Leg: 3.3 at 4,200'MD Minimum ID: 3.725" at the 4'/Z" XN Nip @ 10,168' MD Last TD tag: 9/20/09: Ran 2.2" Drift, Sample Bailer, Tagged TD @10,736'SLM/10,746 MD(27'of fill, recovered sample of schmoo) Last Downhole Op: 9/21/09: IPROF Latest H2S value: N/A, Injector Pad Avg - 20ppm BHP/BHT: No data is available for this location. ~ Objective 1~`~ The following are the objectives of this well intervention design: 1) Improve infectivity as a result of removing damage and improving skin by pumping an HCI acid stimulation. . Well History W-29 was originally completed as a producer in 1998. A RWO was performed in 2007 to install premium tubing for WAG injection. In May 2008, perfs were added at the intervals of 10,595'-10,610 and 10,560'-10,585' at 6 shots per foot. In April 2009, a Schmoo-B-Gone treatment was pumped down the tubing to try and remove schmoo. ~1V-29 Bullhead Acid Treatment Page 1 of 6 • No Accidents, N~arm to People, and No damage td~le Environment It is suspected that there is an increase in schmoo in the well again. A bullhead HCI treatment has been proposed to increase infectivity by removing schmoo and any additional damage. Target injection rate while on MI is 8 MMSCFD. Previous injection rate while on water is 2600 bwpd at 800 psi. ~~ The option of a horizontal sidetrack to improve pattern sweep is being considered in the future. Well Integrity Notes: > 01/20/07: Rig MIT-T &MITIA Passed to 4000 psi ` > 01/21/07: RWO fixed Slow TxIA Comm > 03/06/07: AOGCC MITIA Passed to 2700 psi ~`" > 07/29/09: Conductor treated w/ 1.7 gal RG2401 Please contact Jack Lau 564-5102 (W), 227-2760 (C) with any questions, comments, or concerns. cc: w/a: Well File Please review the following sections of the PE manual. <htt~://alaska.b~web.b~.com/sst drilling wells ~emanual/> Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash Section: Acid Safety & General Rig Up Section: Acid Flow Back Stimulation Target. . Perforatio n Status Zone MDT MDB H Status Z4Bu 10,560 10,585 25 O en Z4Bu/Z4B1 10,595 10,640 45 O en Z4B1 10,652 10,690 38 O en Z4A 10,700 10,714 14 O en Z4A 10,725 10,742 17 O en Z4A 10,758 10,773 15 Open W-29 13ullhead Acid Treatment Page 2 of 6 No Accidents, I~l~arm to People, and No damage tea Environment Design Details Total Perf Footage 154' # of Perforations 756 Wellbore Volume 169 bbl (to top perf) Acid Design 12% HCI - 50 gal/ft 2% KCI Over flush - 50 al/ft Acid Volume 12% HCI - 180 bbls Diversion Design Rock Salt Diversion Volume 568#s @ 3/4 Ibs/ pert Reservoir Pressure No Data is available for this location Pre-Acid Stimulation Pre-job planning. is essential to the successful delivery of this procedure. Cleanliness of trucks, tanks, pumps, etc. is critical to avoid possible formation damage. • Please review: Alaska Wells Group Rigless Operations Manual: Acidizing Section: Tubing Acid Wash 1. Mobilize pumps, tanks, and acid transport. 2. Order out fluids per the attached volumes table. • 2% KCI • 12% HCI 3. Ensure that the well is ready to be POI immediately after acid treatment is pumped away. Bullhead Acid Treatment • Filter all fluids that will enter the perforations to 3 microns absolute. • Do Not exceed .maximum pump pressure of 1750 psi to prevent fracturing the formation. Stay below 0.65 psi/ft frac gradient while pumping acid treatment if possible. ~JV-29 Bullhead Acid Treatment Page 3 of 6 No Accidents, N1~arm to People, and No damage tom Environment Do Not exceed WHP of 3000 psi during Rock Salt Diversion stages • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • Send an electronic copy of the treatment report including digital, ASCII or an EXCEL copy of pumping rates and pressures to Jack.Lau(a~bp.com, Benjamin.Geyer~bp.com, and Carolyn. Kirchner(c~bp.com. 4. Hold PJSM. • Ensure that current MSDS sheets are onsite and that safe handling procedures are followed. 5. PT surface lines to 5000 psi. 6. Mix/Circulate acid to ensure homogeneous solution at pump time. Ensure acid is pumped within 24 hours of mixing. 7. Bullhead the 3 stage acid treatment down the tubing per the treatment schedule below. Pump initial bbls at 3-5 bpm if possible, adjust rate to correspond with a maximum surface treating pressure of 1750 psi (to remain below 0.65 psi/ft frac gradient). WHP can be increased to 3000 psi during Rock Salt Diversion stages. Once acid reaches the perfs decrease pump rate to 1-2 bpm to increase acid contact time. Maintain this pump rate for the remainder of the job. Record pump rates, tubing, IA and OA pressures throughout the job. NOTE: If unable to immediately return to water injection then after the acid treatment freeze rotect tubin with 40 bbls of 60/40 meth water (2500'). Total Fluid Requirements 12% HCI 180 bbls 2% KCI 390 bbls W-29 bullhead Acid Treatment Page 4 of 6 No Accidents, N~arm to People, and No damage to~~ Environment W-29 Acid Treatment Desi n Schedule Stage Stage Description Fluid Type Fluid Vol. (bbl) 1 Sear 60/40 Methanol 5 2 Conditionin 2%KCI + 3%U67 20 3 Acid 12% HCI 60 Stage 1 4 Acid Over-Flush 2% KCI 60 5 30# HEC w/o Rock Salt 2 6 Diversion 30#HEC + 284 Ibs Rock Salt 5 7 30# HEC w/o Rock Salt 2 8 S acer 2% KCI + 3%U67 10 9 Acid 12% HCI 60 10 Acid Over-Flush 2% KCI 60 Stage 2 11 30# HEC w/o Rock Salt 2 12 Diversion 30#HEC + 284 Ibs Rock Salt 5 13 30# HEC w/o Rock Salt 2 14 S acer 2%KCI + 3%U67 10 Stage 3 15 Acid 12% HCI 60 16 Acid Over-Flush 2% KCI 230 Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. 8. POI immediately after acid treatment is complete. If unable to immediately return to injection then freeze protect with 40 bbls of 60/40 meth water. Procedure Contacts: Please contact Jack Lau 564-5102 (w); 227-2760 (c) with any questions, comments, or concerns W-29 Bullhead Acid Treatment Page 5 of 6 •~ ~ No Accidents, N rm to People, an d No damage to Environment iR~= 4-1l1$" tAC~J4ri /ICT-uAIUR- i0'CS~ rr SAFETYNOT~: KH. 4LEV ,- 92 60' BF. EIN ^ 5675 kfl1~- 310(i' Alm An{~e „*48~ 6200:: 41Plld~%Wi~,D~98t9' Gram AQ- 10577" ^n'wm TJQ •..,__--'8800' SS t9-91B' CS4a, t>B~AI L 84 D = t2it8 26BQ' 29T0I' s.be^ x T* G2 27T LP wa w.~avrx ttYt ~ se~so~ ~rxrm ~ 3.725" 70168' 4-712"' HES7LN NIPPLE 10D;t1' a.trrr~%~,o=98t9° 100 T•xa.trl-ems wcw.~~~eaa 1006 +6•td71^~%H~,D~39t9" T" SC7~B [lIR 29/, L.80, gTG#l. 0197• A~96pf, D ~ 6276' 4t12 -~ DdJ !~, ~~ 9.728' .k W? 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CpNSe¢ ~R.T'E ~tPI 12 btt2.5t t7 S Ot A2XiT 4t/I t2 5tB7-St72 S Ot.~Fl'dAT 4tfl Y1 butt=5482 S U1 Rk2AT 995' 8 TF1860 . tO8B5 4 fGl22Ri8 3.95' 8 105 - tOBtQ O ~r12A8 2Ptd@' 6 1084@-tf18lfl Q OTlt7XN 2~t5• A it1852 - 1f1872 Q tOdt+i58 2.t5° • tOSJ2 -108€!0 O #ifM58 5' i 10704-HF7t1 fl 06/t558 5' 4 t0725. - 10742 O OBFt656 2.18x' # M17'S8 - ~TT9 O tflltt58 104' 7' p1~RLL (Qtf2tdOTRrY~D) pe'rn 10908' rLrR ~s5: t,aq r~a9 epr.n~6 are° 10930" F6ttt1Ri0E BAY tM L- w,2s r~ ~4eearrta AP1Nrg SQA~-2td9+bOfl S~2 f, T! iNv R12E, 899' RAC b 144~f°Ai ~' BkpSoration (A4mka) W-29 Bullhead Acid Treatment Page 6 of 6 iXT€ Re! eY ooAwetTS aeElE ~ ew' no~rr's t~t~ae avR ~tAULr~a~1 81!21187 i~L186 #dY0 02ftT/tfJ .L4VFHr.G PR~1 05!3 V08 >idlliP.C 710N8 (n5rzalnej 1 O /OR/09 pp thIY111 t,+1�b{�e pr 11 r�;YSd'1w�iY� - NO. 5410 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambetl street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Both 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job S Log Description Date BL Color CD MPC -05A 11661124 MEMORY PROD PROFILE 01/25/07 1 L4 -03 AYIM -00032 PRODUCTION PROFILE 09/09/09 RODUC FILE 1 1-5.05 AP30 -00061 PTION PRO 09/15/09 1 03 -24A AZCM-00042 LDL 09/14/09 1 07 -328 BOCV -00027 J /15/09 1 W -214 AYS4 -00095 INJECTION PROFILE 09/12/09 1 1 04 -26 05JN -00014 PRODUCTION PROFILE / 09/25/09 1 07 -21 AYS4 -00098 PRODUCTION PROFILE 09/17/09 1 W -04 08K5 -00003 PRODUCTION PROFILE 09/24/09 1 P2 -53 AP30.00060 PRODUCTION PROFILE 09/13/09 1 943 AWLS -00037 PRODUCTION PROFILE 09/25/09 1 12 -23 AWLS -00035 INJECTION PROFILE 09/19109 1 05 -38 AYTO -00029 LDL 1 1 9WAAW 09/18/09 1 W -29 AWJI -00050 WE—MIN—IF"—n— PROFILE 08/20/09 1 W -30 AY1M -00034 PLUGBACK W/X -FLOW CHECK — 09/12/09 1 3.3711. -35 03SO -00024 PRODUCTION PROFILE V 09/16/09 1 NK -09 AP30.00057 USIT 09/07/09 1 W -07A AWJI -00047 M CEMENT EVAL OAT 09/07/09 1 11 -10 AYTU -00054 USIT 08128/09 1 02 -06B ANHY -00111 USIT 09/21/09 1 G -18A AWJI -00048 MEM CEMENT BOND LOG 09/17/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 I v V ~~i~~~~~G~~Gi~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: N0.5020 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 12/29/08 Well Job # 4-20/M-35 12014059 STATIC SURVEY/PERFo Descri lion Date BL Color CD W-18 11968978 PRODUCTION PROFILE 12/11/08 1 1 Y-07A 12103704 INJECTION PROFILE ~ 12/20/08 1 1 P2-35 12031533 SCMT .. 12/18/08 1 1 M-16 12111931 SCMT _ I L~ 12/18/08 1 1 P2-15A 40015006 OH MWD/LWD EDIT 12/19/08 1 1 P2-15AP63 40015006 OH MWD/LWD EDIT ~ _ ~`~ 04/01/07 2 1 P2-15APB2 40015006 OH MWD/LWD EDIT ~~ a ~ 03/27/07 2 1 P2-15AP61 40015006 OH MWD/LWD EDIT _ ~ ~ 03/24/07 2 1 W-31A 40017846 OH MWD/LWD EDIT I 03/22/07 2 1 W-29 11549353 CH EDIT (USIT) _ t ~ 09/27/08 2 1 H-05A AXBD-00002 MCNL 12/18/06 1 11/20/08 1 1 L g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T0: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 i u 05/30/08 ~c~Cumaerg+ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wrall .Inh S ~~.+>1~~I~ JUN ~. ~: 2008 1 nn nn nf:.. NO.4727 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n...., n~ n_~_- Z-03 11975773 SFRT 1- (~ 05/20/08 1 1 P2-32 12066522 MEM TEM SURVEY 05/19/08 1 1 18-13B 12021159 MEM PROD PROFILE '~- ~ ~ 05/18/08 1 1 Z-03 11975773 USIT C~ 3 05/19/08 1 1 W-29 11999017 INJECTION PROFILE (,( 05/26/08 1 1 15-39A 11999018 PRODUCTION PROFILE - 05/28/08 1 1 07-30A 11963095 SCMT - ~ 05!27/08 1 1 14-09B 11982432 PROD PROFILE W/FSI - Q, v 05/27/08 1 1 A-34A 12057614 USIT - p '' / G(jj~- 05/26/08 1 1 GNI-04 11824353 OH LDWG EDIT (DSI) -C _I t 4 11/07/07 1 1 r~~e+.a~ na.nrvvvv ccv~ac ncVCir~ vi JI171Y11VU li1VU rSCI Vr11V11VU VIVC I.VYT CAGr1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ , . ~ ;,`1~,. Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2 38 / ATTN: Beth ~ .// Received by: • STATE OF ALASKA ~~ ALA~OIL AND GAS CONSERVATION COMt~ION ~~'~~ REPORT OF SUNDRY WELL OPERATIONS MAY 2 9 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ h e r Ot ( ~ ,+ aS~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Tim~e'Ezt~n~ftl 85 Of1S. (;Qm(ni$$j Change Approved Program ~ Operat. Shutdown ~ Perforate Q ~ Re-enter Suspended Well [~(1C;~C~Qr ~, 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' Exploratory 188-0710 3. Address: P.O. Box 196612 Stratigraphic Service - 6. API Number: Anchorage, AK 99519-6612 50-029-21834-00-00" 7. KB Elevation (ft): 9. Well Name and Number: 92 KB ' PBU W-29 8. Property Designation: 10. Field/Pool(s): ADLO-028263 - Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10950 - feet Plugs (measured) None true vertical 9166.21 feet Junk (measured) 10804' Effective Depth measured 10908 feet true vertical 9135.41 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 30 - 110 30 - 110 Surface 2651 13-3/8" 68# L-80 29 - 2680 29 - 2680 5020 2270 Production 10358 9-5/8" 47# L-80 28 - 10386 28 - 8752 6870 4760 Liner 796 7" 26# L-80 10154 - 10950 8583 - 9166 7240 5410 Perforation depth: Measured depth: SEE ATTACHMENT - ~'~,y,~,~~~~ ~U~ ~ ~~ 208 = _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 34 - 10181' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR PERM PKR 10041' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 11 10 Subsequent to operation: 3335 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory fm`' Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: 0iI 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: 308-156 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/29/2008 ~.4 t3, Form 10-404 Re iv sed 04/2006 0 ~ ~ ~ I N ~ ~ ~ ~~„ .I~~ ~ ~ 7Q~~ Submit Original Only )il W-29 1880710 PERF ~TT~rHMFNT CJ Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 8/14/88 PER 10,700. 10,714. 8,982.69 8,993. 8/14/88 PER ~ 10,725. _ 10,742. _ 9,001.1 9,013.61 10/14/88 APF _ 10,652. 10,690. 8,947.27 _ 8,975.32 10/14/88 APF 10,758. 10,773. 9,025.37 9,036.39 7/17/04 ___ A_PF 10,610. 10,640. 8,916.19 8,938.39 7/14/05 BPS 10,132. 10,773. 8,567.05 _ 9,036.39 2/10/06 BPP 10,132. 10,773. 8,567.05 9,036.3 9 10/19/06 ____ BPS 10,037. __ 10,773. _ 8,497.82 _ 9,036.39 12/28/06 APF _ 5,480. 5,482. 5,074.17 __ 5,075.65 12/30/06 SPS 5,622. 5,661. 5,178.86 5,207.29 12/30/06 BPS 5,661. 5,670. _ 5,207.29 5,213.84 1/1/07 APF 5,167. 5,172. 4,838.52 4,842.31 1/2/07 SQZ 5,150. 5,661. 4,825.63 5,207.29 1/3/07 OH 5,150. 5,670. 4,825.63 __ 5,213.84 2/16/07 BPP 10,037. 10,773. 7.82 8,49 9,036.39 5/26/08 _APF _ 10,560. ~ 10,585. _ 8,879.15 8,897.66 5/26/08 APF 10,595. 10,610. 8,905.07 8,916.19 AB ABANDONED PER PERF , APF _ ADD PERF RPF REPERF __ BPP BRIDGE PLUG PULLED _ SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT _ SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • W-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY -_- _ ___ 5/26/2008 "***WELL ON INJECTION ON ARRIVAL'~~* (E-LINE (PROF &PERFS). INITIAL T/IA/OA: 1400/180/50 'LOG P~ ROF FROM 10500' - 10750'. FIELD SPLITS: PERFS AT 10610' - ', 10640' TAKING 13%, PERFS AT 10652'-10690' TAKING 9%, PERFS AT ', 10700' - 10714' TAKING 27%, PERFS FROM 10725' - 10742' AND 10758' - ' 10773' COMBINED TAKING 52%. (SPINNER GUMMED UP WITH SCHMOO AT BOTTOM OF WELL) PERFORATED USING 3-3/8" HSD GUNS LOADED WITH 3406 POWERJET ', CHARGES, LOADED 6 SPF, 60 DEG PHASED. API DATA: PENETRATION = ', ', 36.5", ENTRANCE HOLE = 0.37" 'INTERVAL #1:10595' - 10610' FINAL T/I/O = 50/0/0. WELL LEFT SHUT IN AS PER PAD OP. "*"*JOB COMPLETE**** FLUIDS PUMPED BBLS 1 diesel 1 Total 4 ~ ~ { ~ ~ a ~ ~ ~ r ~' 3 E _ ~ y ,, ~` SARAH PAUN, GOVERNOR Lsitcs-7i>•L1 OI~ ~ ~ 1 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOIIT COl-lIl-II55IO1~T /(! ANCHORf+GE,AtASwa 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Daniel Robertson Sr. Petroleum Engineer BP Exploration Alaska Inc. PO Box 196612 S~`~:~~~~~ ~~~ ~ ~ 200 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-29 Sundry Number: 308-156 , d ~~ Dear Mr. Robertson: ~- 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 ~ day of April, 2008 Daniel T. Seamount, Jr. Chair Encl. ~' REC~I\/E ~ ,c~, ~;~ ' V' ~ STATE OF ALASKA A `` ' ' ~ ALASKA OIL AND GAS CONSERVATION COMMISSION Ian APR 2 4 2 ~~' `°~~ APPLICATION FOR SUNDRY APPROVAL p,iaska Oil & Gas Cons. Com~ssion 20 AAC 25.280 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 188-0710 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-21834-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU W-29 . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028263 92 KB - PRUDHOE BAY Field / PRUDHOE BAY OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10950 - 9166.21 10908 9135.41 NONE 10804 Casing Length Size MD TVD Burst Collapse. CONDUCTOR 80 20" 30 110 30 110 SURFACE 2651 13-3/8" 68# L-80 29 2680 29 2680 5020 2270 PRODUCTION 10358 9-5/8" 47# L-80 28 10386 28 8752 6870 4760 LINER 796 7" 26# L-80 10154 10950 8583 9166 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHMENT - - 4-1/2" 12.6# L-80 SURFACE - 10181' Packers and SSSV Type: 7"x4-1/2" BKR PERM PKR Packers and SSSV MD (ft): 10041' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5!7/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Robertson Printed Nam Dani Ro ertson Title Sr. Petroleum Engineer Signature Phone 564-5546 Date 4/23/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,~~ ' ~ ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~\C~t~TCC~\ ~v'~ pt`nrC~~ ~« ~~ ~ 1-'s~.~ ~ . ~--~5'~ , Subsequent For quired: APPROVED BY Approved b COMMISSIONER THE COMMISSION Date: Q Form -403 s 06/2006 ~ F~j ~ ~ ~ ~ /~ ` ~~ ~~E~ `, ~ ~~~~ Submit in Duplicate W-29 188-0710 PERF ATTACHMENT Welibore: W-29 Zone MDT MDB TVDT TVDB 8/14/1988 10/14/1988 7/17/2004 7/14/2005 2/10/2006 10/19/2006 12/28/2006 12/30/2006 1/1/2007 1/2/2007 1/3/2007 5,150 5,167 4826 4839 OH 5,167 5,172 4839 4842 APF SQZ OH 5,172 5,480 4842 5074 OH 5,480 5,482 5074 5078 APF SQZ OH 5,482 5,622 5076 5179 OH 5,622 5,661 5179 5207 OH 5,661 5,670 5207 5214 OH Z46u/Z4BI 10,610 10,640 8916 8938 APF BPS BPP BPS BPS .2481 10,652 10,690 8947 8975 APF BPS BPP BPS BPS Z4A 10,700 10,714 8983 8993 PER BPS BPP BPS BPS Z4A 10,725 10,742 9001 9014 PER BPS BPP BPS BPS Z4A 10,758 10,773 9025 9036 APF BPS BPP BPS BPS AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • ~~_ ;~~ ~Z~ :~~ i~~:~1,~ To: Clark Olsen/Jerry Bixby, GPB Well Ops TL From: Dan Robertson, Area PE Tiffany Quy, Wells PE Subject: W-29 (PROF, add perfs PBWPDWL29-R This procedure includes the following steps: Date: April 22, 2008 Est. Cost: $60 M IOR: 200 BOPD Type Operation 1. S Drift and tag 3-3/8" w/dummy gun and TEL. Run smaller OD toolstrings as needed. 2. E (PROF, add perfs. Possible selective reperf of any intervals not taking injection if feasible. Current Status: Operable WAG injector Last test: 04/02/2007 Inj Press, psi: 1,357 Type: PW Vol: 5,628 Max Deviation: 46° @ 6200' MD Min. ID: 3.725" XN nipple @ 10168' Last TD tags: 2/16/2007 tagged soft bottom @ 10773' while pulling TTP Last DH Operation: 2/16/2007 pulled TTP from 10175' Latest H2S level: NA (injector) -typically 20 ppm for W pad producers Tie in Log: 08/20/1988 Schlumberger BHCS log OBJECTIVE: W-29 was originally completed as a producer in 1998. A RWO was performed in 2007 to install premium tubing for WAG injection. The objective of this work is to determine the relative injection into each open interval and add uphole perforations to the top of the reservoir. These uphole add perfs are part of an overall strategy for the pattern to add perfs to the top of the reservoir in both the injector and offset producer. Additional perforations to the top of the reservoir have already been added in offset producer W-25 with little gas rate increase. Uphole add perfs are pending for offset producer W-26a. If you have any questions or comments regarding this procedure, please call Dan Robertson at 564-5546 (W), 346-3714 (H), 529-5818 (C) or Tiffany Quy 564-5322 (o) or 253-576-6153 (c) cc: w/a: Well File • • PROCEDURE: (PROF and add Perforations Slickline: 1. RU slickline. 2. Drift to TD with 3-3/8" dummy gun and TEL. a. If shallow tag, run smaller OD toolstring as needed with sample bailer. b. Expect soft tag at ~ 10770' (from last attached SL WSR). This should be at or near the bottom of lowest perfs. Last sample bailer came back with Schmoo. 3. RDMO Eline• 4. Ensure well is on stable, normal injection rate at least 24 hours prior to logging. Typical rate is around 6000 bwpd 5. RU STP (full-bore spinner, continuous spinner, temp, pressure, x-y caliper, GR, CCL) and RIH. 6. Tie in with 08/20/1988 Schlumberger BHCS log 7. With well on steady injection, make the following log passes as seen in the spreadsheet below: a. Log 40, 80, 120 and 160 fpm up/down dynamic passes over the interval 10500' - 10820' (or as deep as possible below perfs without tagging TD with spinner. Depth will depend on SL pre job drift run to TD). b. Obtain stop counts above, between, and below ail perforation intervals. C. Record on log remarks -injection rate, choke, WH injection T&P, manifold T&P, IBHP, and IBHT. 8. Shut in well. Obtain temp log warm back passes from 10500' - TD (reference SL tag) @ 1 hr, 2hr, and 3hr intervals. a. Warm back passes may be deleted depending on PBTD. If tag is above bottom perfs, confirm with APE. • • W-29 (PROF Spreadsheet: Pass Direction Speed (fpm) Depth (Ft MDj Notes Flowing STP Up/Down 40 10500'-10820' MD Injection Flowing STP Up/Down 80 10500'-10820' MD Injection Flowing STP Up/Down 120 10500'-10820' MD Injection Flowing STP Up/Down 160 10500'-10820' MD Injection 10500' M D 10645' M D 10695' MD Stop Counts Up/Down 10720' M D Stop Counts 10750' MD 10900' M D Static Temp warm back 1 hour Pass Down ass 10500' -PBTD increment Static Temp warm back 2 hour Pass Down ass 10500' -PBTD increment Static Temp warm back 3 hour Pass Down ass 10500' -PBTD increment 9. POOH. 10. MU perf guns and RIH. 11. Perforate interval as seen in attached perf spreadsheet. If injection profile indicated any intervals not taking injection may be desireable to reperforate selectively. Consult with Dan Robertson. 12. RDMO. Return well to injection. Log Presentation: The following information should be presented on the field print. 1. Job Comments -operating steps in sequence, logging passes made, injection splits, basic field interpretation. 2. Present all down pass data in overlays. 3. Present up/down overlay from speed with best data. 4. Stop counts. 5. Warm back passes. • • 'fU'B11•JG 51.11v~F1AR~( RIG Nabars Date '1.1512007 `~ tNELL ?? GPB U+~-29i ~_ TtJBIt~G 4.~'" L-~#~ TC1l ~~ EG Y`~IT. 12.x# ktas~t a ~nE~KS a ~r~us :~~~ JT~ RAN 22.C1~1 GESB Tfl F d3u7,'r$ FTQ9d RACK `1~1,~t=~' FT RA~d lTEN9 D~~:crip#i>an i~rc9usl~s. 61ZE, T1fRE,, C(~N!`aE'GTI+Q1~ (JTS #-#y ID GD i.E~1GTFt TAP' Bt}TTOh~~ ?~.~`" LEG, L-SQ, Teti 13{~X ~ ~#LEG 4.:4010 4.9E0 1'.36 14179.61 141$0.3'r' >'~~ ~t--~1.~"', '9~., 'L-t~~, Ti:,.[[ t~~5~ ~: i~~ ~.J~ x.020 ~.EO 10165.; 1 14179.51 X1~-Nippy--+~.:~" x 3.813", ~l R1.9D-9UI, 3..725"-NQ-G,o 3,72a 5.0:;0 1.;0 14168.41 14169.71 1~~p ~t--~.`,", '~~_6#, L-~~}, T{~[1 ~~5; ~' t,i~i 3.93 ~,p20 S.E~': 1 d 153.60 '1~116E.-t1 .9aint~ ~1 end #2---4.6", 12.6#, L-8r], TCII bax x in 3.943 4.930 82,61 14075,93 14163.64 9='u~ It--d :,~', 1 L F~~, L'~~E, T4>II'f~x ~ F>G3~ 3,953 5.024 9.7'7 10066.22 14075.99 X-1`Ji ie--4.5" x 3.313.., TCII bQx x in 3.313 5,030 1.2d 10484.9$ 14468.22 pi_I , III--1 •_,". lz ~:~. L-~;1, Ti~,ii',~F ii;;ir~ 3.95E 5.02.0 5.79 10055.1) 14064.93 PU ~ .lt--d ;,'. 1 ?. ~~, LSO, Tt~l[ L~~~e a; r;'i~l 3 ~~~° 5.024 ~9.7~5 10445.44 14066.19' I~+ackeC---Baker S-3. 7"' x 4-112" 9~errnane~t 3,87 5.910 4.02 10441.42 '[404x.44 PU ?t--4.=,", '1.~~, L-801, -1'~IC L~ ,,~, r. ~i?~ 3.9'58 5.02.4 9.77 10401.65 14041.42 F'U , ~~t_4..~,", 1_~~, 'L-~Q, TisIE L,: r f ~I?l 3,9~$ 5.024 9.~ 7 10421.$8 14031.6b ->~9. ~~-~.~'~ ~ 3-813". TCi1 bax x in 3.913 5.034 1.23 10424.65 14027.$3 1~u ~It--4.~'", 12.6?, L-B~t, Tt1~Ei ;,~,~ :; ;.iii 3,958 a~.02{t 9.79 10014.86 '14020.85 ,14ins ~~;_#190-~-~,5", "1~.6f~, L-Ed, TGI( box x ire 3,9~iu ~4:93t1 7801.6' 22.09.'13 iQ010.E6 Fug, ~It--4_~", '92.6#, L-~~, Tf t[ ~~v:~. ~, pig-t 3.95E 5.4219' 9.7J 2195.40 2209.19 X-1~11ppte~--4.5'• x 3.613'", TGII box x ~ir~ 3,;81 u 6.430 1.24 :19$,16 2199,40 1='~Ip ~1t--4.5"'x 1L.~#, L-~~~, Ti~ii b~.d x ~irX 3,95E 6.024 9.7E 213$.03 215$.76 Jo[nt~ #197-#~42---~."', 1~.:E3#, L-8t], TC11 bax ~ pin 3,943 4,934 2160.09- 25.9 213$.08 McEvray Tbg Hgr--4-112", 12'.6~a L-8t9, TC11 pint x pin 3.29 22.0't3 25.29 hlabars a3 RFCB 22.04 22.t1 PfU-14351c, S1Ct=82k P~~clt setting ~iepth~ of 10,054' appr~av~d !'y' T+,m Maunder,; ~c?GDG, 1-1 r'-2047 ~ WELL SERVICE PORT WELL JOB SCOPE UNIT W-29 RWO EXPENSE SWCP 4515 DATE DAILY WORK DAY SUPV 2/16/2007 PULL MECHANICAL PLUG; DRIFTlTAG VARBLE COST CODE PLUS KEY PERSON NIGHT SUPV PBD4P9243-D SWCP-WEGLIN NARDINI MIN ID DEPTH TTL SIZE 3.725 " 10168 FT 4.5 " DAILY SUMMARY "' CONT FROM 2-15-07 WSR'~ PULLED 4 1/2" HES RHC TT PLUG FROM 10175' SLM. TAGGED SOFT BTM @ 10773' MD W/3.50" DRIFT. (BTM PERF C~ 10773' MD). "TURNED WELL OVER TO PAD OP, TO POI"* LOG ENTRIES Init Tb , IA, OA -> 0 0 0 TIME COMMENT 00:01- CONT FROM 2-15-07 WSR. 00:20 SAT DOWN @ 10175' SLM, JAR UP, CAME FREE, POOH. 01:10 HAVE RHC 01:20 RIH W/2' STEM, 3.50" CENT, TT LOC, SAMPLE BAILER. 01:50 LOC TT C~ 10179' SLM+ 1' = 10180' MD. 01:56 TAGGED SOFT BTM C~3 10772' SLM + 1' = 10773' MD. 02:24 SAMPLE BAILER CAME BACK W/ SCHMOO. BEGIN TO RIG DOWN. 02:45 NORMAL UP SSV, PT TREE CAP W/ NEW O-RING. 03:00 COMPLETE RIG DOWN, TRANCE TO Z-PAD. Fi nal Tb , IA, OA -> 300 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST _._ ___ . CUMUL TOTAL ..........-_.-..-o__..r_mm,.,-....,,._e,....~ ORBIS ..e.e ......................... . $4,800 $14,197 SCHLUMBERGER $1,151 $50,396 VECO $0 $2,176 MI FLUIDS $0 $7,305 AES $0 $1,000 CAMERON $0 $1,216 WEATHERFORD $0 $250 WAREHOUSE $0 $5,321 GBR $0 $750 I TOTAL FIELD ESTIMATE: I $5,951 I $97,173 FLUID SUMMARY NONE ~~ ~D$$~ ~~~I~~II~I ~~ DT a SP i ~ I ;~~ I Ia84~ 10600 d5P ~5 10700 t 8900 42P 37 ... _ .. 1873 d-7.I}r-P -* - a4 - --t- , 10800 ssR I ~ I--- !- ~ - - - ~ 9000 ~ osoo W-29: Injection Profile and Add Perfs 1. Obtain injection profile to determine current injection allocation. 2. Consider reperfs real time of any zones not taking sufficient injection 3. Add perfs in the 46P as follows: Zone Top MD Base MD Length MD 46P 10560 10585 25 46P 10595 10610 15 TOTAL ADD PERF LENGTH 35 Current Estimated Fluid Contacts GOC: N/A Believe gas has retreated from this area, based on low gas rate in pattern wells. If gas does remain in vicinity of 46P add perfs, it will help with in situ gas lift for offset producers which are being considered for 46P add perfs. OWC: Water to top of injection perfs. Regional OWC is 8870' sstvd based on W-19AL1 2003 LWD Pattern Overview W-29i supports offset producers W-26A, W-19A, W-32A and W-25. W-19A is currently shut in as a high WC, non- competitive producer. It is currently being evaluated for a multi-lateral sidetrack. W-32A remains competitive. W-26A has uphole add perfs pending. W-25 had 30-40' add perfs in the 46P 01 /08 which added 200 bopd. TQ / DBR / JNF 04/07/2008 • PERFORATING PROCEDURE V 1 2 R 1 /21/ 1 er . , ev 0 0 Well: W-29 API #: 50-029-2183400 Date: 04/22/2008 Prod Engr Dan Robertson Office Ph: 5845545 H2S Level: Niti'~inj)'~f3..PPm.... Home Ph: 346-3714 typical . .... Cost Est : ........ ................$60M........................ . .................. Cell/Pager: ................... ..................................................... 529-5818 .................................................... . . ....... CC or AFE: ........ PBWPDWL29-R ...................................................... . WBL Entries IOR Type Work Desciption . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . : . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . s ................S :Drift as deep. as possible, with 3-3/8" DummX.Gun.and.TEL E =(PROF, Add Perfs s ............................. i..............................................................................................................................................,............................................................................ € 2/16/2007 pulled TTP from 10175' and tagged soft bottom ~ 10773' This program will evaluate injection contributions and add uphole perfs for conformance with offset producers. If injection profile indicates any intervals not taking injection, may be desirable to reperforate selectively in same rig up if feasible. Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Add 0 feet Log: BHCS ............................. CET ............................ .............................................. to the tie-in log to be on ... Date: 8/10/1988 ............................. 8/13/1988 ....................... depth with the reference log. Company: SLB ............................. SLB .............................. Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/ReAperf 10,560' - .10,585' 10,560' - 10,585' 25 6 random 60° 46P Add 10,595' 10,610' 10,595' 10,610' 15 6 random 60 46P Add Requested Gun Size: 3-3/8" Cherge: Power Jet -deep penetrating charges Is Drawdown Necessary/Desired/Unnecessary During Pertorating Desired but not readilX feasible. while on water infection Preferred Amount of Drawdown/Suggestions to Achieve Drawdown none Last TD tag: 10;773 ff MD on 2/16/2007,.. Est Res. Pres. ~ .10,565, MD is .3600, psi Perforation Summary Summary Dist Well: W-29 Town: Date: API #: 50-029-2183400 Prod Engr: Anch Prod Engr ........................................................... P.D. Center PBTD ...................................................................... General Comments: T ... {.1r1r ~h;='~r~~Y `s~ ~C;wl ~~~~~ E ~~- ~ . , , ._ ~ Y 'K',I nn~ri date ~-91~" 32 5<1">.5-117 ~ ~ i;;'07 4.1f~"" 32 5 r ; ,~ ""r S Q1 u:~;i;? 2-`i,t~' 6 1- - q ~ '~17Cn 2-1#8'° 4 1~t~73 - i C%T73 C7 . i_=°i ~'~ ~ ~/~~~I'Y Nt~TES E,=~ ~: 3~~. E;'~` Cyr ,. _. CkAT~ ~" ~3' CC~R~Fi"*I7a 1 6 1'~i N .3 G'.~ __ __ CR1 GIhA~? .. r<~ -~:" T(:~;`d. /.^^ . -y { l ' ~J~If61 ~~~ - i4f'.YV ~~yy r::'JD~ `~~'.i-Y E1P~~TF .~__ ., SEG 21, T1" 1 12~ NL. ~ 144~t' FF1. BP Explor~lr,u.~ (Ar~sk;~j lVIE1\10RA.NDUM . TO: Jim Reg"./(/ 1 ( P.I. Sup;r~isor f\~11 "3!? ~Î FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE BAY UNIT W-29 Insp Num: ITIltCSOì0307073357 Rei Insp N urn Packer State of Alaska -\Iaska Oil and Gas Consenation Commission DATE: :Vlollda\. 'vlarch 12,2007 SL BJECT: 'v!cchanlcal lntcgrtl) Tests 8? EX?LDR^Ä. -CION \),/ -2() PRUDHOE BAY UNfT W-29 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-21834-00-00 Permit Number: 188-071-0 . Reviewed Bv: P I - ~~" - . . Suprv ~ Comm Inspector Name: Chuck Scheve Inspection Date: 3/6/2007 Well ------- P.T. 1880710 2710 15 Min. 30 Min. 45 Min. 60 Min. W-29 Type Inj. TypeTest SPT Test psi . __...__·___n__ _n ._--.n'-__"-~--'~7-- Inte_r:~.aL ViRKOVR_ __n.Pj£______.f'_nn Pretest Initial 450 -- ------------ --- Tubing 1250 1250 Notes Pretest pressures observed and found stable. Well demonstrated good mechanicalll1tegrity. - -----~--~._._--~--- Monday. March 12, 2007 4 in 450 ~--~-_.._----~---_.__.~-_..._- ---.-----_.~-- 2670 2670 -.---~-_..._._------------ - -------._._-_._._--_.._-~._- .-. .... ------- 1250 1250 / v' -----_._.._------_._---~--- ~NED MAR 2 r¡ 2007 ,. :"". . . ~ " ~,. _._,'_..,_,',_'" ,,'.-, .., _......¡.I> Page I of 1 .. '. . STATE OF ALASKA ..J~;7 RECEIVED ALA Oil AND GAS CONSERVATION COM.ION 1..>;-, REPORT OF SUNDRY WELL OPERATIONSY"?f~ FEB 2 0 2007 ,l\laska Oil & Ga~ r.nn~ ^ . I 1. Operations Performed: Anchoraa,8 D Abandon ~ Repair Well D Plug Perforations D Stimulate D Re-Enter Suspen ed Well D Alter Casing ~ Pull Tubing D Perforate New Pool D Waiver D Other D Change Approved Program D Operation Shutdown D Perforate D Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. D Development D Exploratory 188-071 j 3. Address: D Stratigraphic ~ Service ,; 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21834-00-00 J 7. KB Elevation (ft): 92' / 9. Well Name and Number: PBU W-29 ¡ 8. Property Designation: 10. Field 1 Pool(s): ADL 028263 ; Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10950, feet true vertical 9166 feet Plugs (measured) None Effective depth: measured 10908 feet Junk (measured) 10804 true vertical 9135 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2681' 13-318" 2681' 2681' 4930 2270 Intermediate 1 0386' 9-5/8" 10386' 8752' 6870 4760 Production Liner 796' 7" 10154' - 10950' 8583' - 9166' 7240 5410 Scab Liner 7167' 7 2970' - 10137' 2970' - 8571' 7240 5410 ~[~E1) FES 2 (5 2007 Perforation Depth MD (ft): 10610' - 10773' Perforation Depth TVD (ft): 8916' - 9036' 4-1/2", 12.6# L-80 10181' Tubing Size (size, grade, and measured depth): 7" x 4-1/2" Baker 'S-3' packer 4' ~.-, . . _........ ..,.....;...... A..>:...-J~""""'" 10041' Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pulled the 3-1/2" Tubing. Perf 5112' - 5482' for remedial cement job of the 9-5/8" casing. Cement w/15 Bbls Class 'G' (1.16 Yield). Run and cement 7" scab liner wI 210 Bbls Class 'G' (1.16 Yield). Run new 4-1/2" Tubinq. 13. Representative Daily Averaqe Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations o Exploratory o Development ~ Service 16. Well Status after proposed work: ~ Well Schematic Diagram DOil DGas ~WAG DGINJ DWINJ o 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 David Reem, 564-5743 306-304 Printed Name Terrie Hubble Title Technical Assistant Signature ./(Ó lIf\t: 0 ~ 564-~u ~i'~ .""pfite 0 Z1l6/07 Prepared By Name/Number: Phone Terrie Hubble, 564-4628 y! ~c n t'{¿ .:t; luu i . . 'on Form 10-404 Revised 04/2006 nR\G\\~J\L Submit Onglnal Only Digital Wellfi1e . '" k. Well Events for SurfaceWell - W-29 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> W -> W-29 Date Range: 10/Sep/2006 to 22/0ct/2006 Data Source(s): DIMS, AWGRS Events Source Well Date AWGRS W-29 10/22/2006 AWGRS W-29 10/21/2006 AWGRS W-29 10/20/2006 AWGRS W-29 10/20/2006 . Page 1 of 2 Description SET BPV /PRE RIG (continued from 10-20-06) Pump 2% kcl 1088 bbls and 154 bbls dsl u-tubed to freee protect to circ out well for pre RWO pump 10 bbls neat meoh to freeze protect flowline on well 30 FWHP=O/O/O T/I/O=O/O/O Circ-out for pre-rwo (continued on 10-21-06) CONTINUATION OF PREVIOUS JOB. CHEM CUT TUBING AT 10037. AFTER CUT THE TOOLSTRING HUNG UP AND HAD TO WORK TOOL. PUT LRS ON STBY. WORKED TOOL TO MAXIMUM PULL AND TOOL CAME FREE. POOH. RELEASED LRS. INSPECTION OF CUTTER INDICATED GOOD CUT. RDMO AND CLEAN LOCATION. NOTIFIED DSO OF DEPARTURE. *****JOB COMPLETE***** AWGRS W-29 10/19/2006 T/I/O = Vac/40/0 Assist E-Line Test Plug to 1000 psi. (PASSED) Pumped 4.2 bbls of neat methanol down Tubing to reach test pressure. Tubing lost 50 psi in the 1st 15 min and 0 psi in the 2nd 15 min for a total loss of 50 psi in the 30 min test. Final Whp's = 0/40/vac AWGRS W-29 10/19/2006 2.70" WEATHERFORFD CIBP SET MID-ELEMENT AT 10,134 FT, PLUG TOP AT 10,133.5 FT. DEVIATION 43 DEGREES AT PLUG SET. PLUG FAILED MIT TO 1000 LBS. lX12' STRING SHOT OVER INTERVAL 10,026-10,038 FT. SET HES 3-1/2" FASDRILL @ 10,051 FT. LRS RIGGED UP AND PRESSURED UP FOR MIT TEST ON PLUG. PLUG PASSED MIT TO 1,000# PSI. GIH WITH 1- 11/16" TUBING PUNCHER LOADED WITH SMALL CHARGES TO PUNCH 2 FT. @ 4 JSPF. TIED IN TO TUBING TALLEY DATED 14 AUG 1988. SHOT TUBING PUNCHER FROM 9,980' TO 9,982 FT. AFTER OOH WITH TUBING PUNCHER GUN SHOWED GUN FIRED OK. START RIGGING UP 2- 3/8" CHEMICAL CUTTER. ***JOB CONTINUED ON 10/20/06 WSR*** AWGRS W-29 10/19/2006 Continued froml0-18-06 T/I/0=VAC/20/VAC Assist E-line.. MIT TBG 1000 psi FAILED (RWO to return to MI) (Shut in) Pumped 7.1 bbls of 60/40 meth water down TBG to reach 1000 psi for MIT TBG 1st test 1st 15 min lost 950 psi. Blocked in choke on S-Riser. Attempted 2nd MIT TBG Pumped 3.2 bbls of 60/40 meth water to reach 1000 psi 1st 15 min lost 900 psi pumped 10.3 bbls total Final Whp's=0/20/VAC *** SOME S-RISER TO WING STUDS NOT FULL NUT 2 IA HANGER STUDS NOT FULL NUT SEVERAL TBG HANGER STUDS NOT FULL NUT********** MIRU MIT TBG 1000 psi (RWO to return to MI) job in progress 2.70" WEATHERFORD CIBP SET MID-ELEMENT AT 10,134 FT, PLUG TOP AT 10,133.5 FT. DEVIATION 43 DEGREES AT PLUG SET. LRS RIG UP TO TEST PLUG. **CONTlNUED 19-0CT- 2006** T/I/O = Vac/20/Vac. SI. TBG FL (for E-Line). TBG FL @ 432'. T/I/0=VAC/30/VAC. Temp=SI. WHP's (post-bleed). TBGP went from 0 psi to a VAC. No change in lAP. OAP went from 0 psi to a VAC. T/I/0=0/30/10 Temp=SI No A/L Bleed OAP to establish differential between IAxOA (UIC report). OA FL near surface. Bled OAP from 10 psi to 0 psi in 2 minutes. Monitor for 15 minutes. No change in pressure. Final WHPs=0/30/0 T/IA/OA= Pre rig well head MIT PPPOT-T Passed PPPOT-IC Passed Cycle all LDS on both tubing and casing spool. All moved very easy. Pressure up tubing hanger void to 5000 for 30 minutes. Test IC hanger to 3500 for 30 minutes. Had gland nut leaks, tighten and re-test. T/I/0=300/900/700 Load OA w. 9.8# Brine (Pre RWO) Pumped 289 bbls 9.8# Brine and 5 bbls DSL down OA. Final WHP's=100/0/520 T/IA/OA= 1700/1050/600 { Well head inspection} LLR rigging up on well McEvoy SSH well head 5 seal PIN 614522 3-1/8 adapter and tree/ tubing spool has 2 2" SSO Well head had external checks. Don't know if internal were pulled. AWGRS W-29 09/15/2006 T/I/O= 1730/200/75 Temp=Injecting PW MIT-IA 4000 psi ***PASSED*** (Pre-RWO) - Pressured up IA w/ 11.2 bbls 60/40 meth water to reach 4000 psi. 1st 15 min lost 70 psi, 2nd 15 min lost 30 psi with a total of 100 psi loss in 30 min test. Bled back 10 bbls. RU on OA to perform Injectivity test. Final WHP's= 1700/600/100 OA Injectivity Test - Pumped as per procedure - Pumped 100 bbls crude 5 bpm @ 1400 psi. AWGBS W-29 09/14/2006 ***WELL INJECTING ON ARRIVAL ***(pre rwo) DRIFTED TUBING W/ 2.5" CENT, TEL, 2.5" LIB LOCATED TT @ 10,152' SLM = 18' CORRECTION TO ELM SD @ 10,765' ELM = 8' OF FILL. BOTTOM OPEN PERFS @ 10,773' GOT IMPRESSION OF WHAT COULD BE A 3.5 G FN *** WELL LEFT S/I AS PER DSO*** AWGBS W-29 09/13/2006 (Identify Wellhead and Tree for Workover) Inspected System Records showed well to have 4 1/16" Tree, it was verified to be a 3 1/8" Cameron tree on a McEvoy SSH wellhead system. AWGBS W-29 10/18/2006 AWGRS W-29 10/18/2006 AWGRS W-29 10/17/2006 AWGRS W-29 10/03/2006 AYVGRS W-29 10/02/2006 AWGRS W-29 09/28/2006 AWGRS W-29 09/25/2006 AWGR5 W-29 09/25/2006 http:// digitalwellfile. bpweb. bp.comfW ellEvents/HomelDefault.aspx 2/13/2007 AWGRS W-29 09/10/2006 . . Page 2 of 2 ***WELL INJECTING ON ARRIVAL *** (pre-cibp) DRI. TUBING W/ 2.70" CENTRALIZER AND SAMPLE BAILER TO 10200' SLM (10018' MD TARGET) ( OUT OF TUBING TAIL) ***WELL INJECTING ON DEPARTURE*** Digital Wellfile , http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default. aspx 2/1312007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/8/2006 00:00 - 00:00 24.00 MOB N WAIT PRE Prepare rig for move from MPJ-06 to W-29. Unable to lower Derrick due to winds +30-MPH and side loading on Derrick. Rig maintenance and painting. 2200-hrs.: Wind speed +30-MPH. MPU Ops called Phase 1 weather condition. 12/9/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Pre-tour all crew meeting - Discuss phase weather conditions. Wait on weather. Wind speed @ 0100-hrs. - 33-MPH. 06:00 - 15:00 9.00 MOB N WAIT PRE Rig Maintenance and prep for Rig move. Waiting on weather to abate 15:00 - 00:00 9.00 MOB N WAIT PRE Lower mast on derrick. Prepare for arrival of PEAK trucks to commence with rig move. Wait on PEAK to finish rig move on 2 ES and Doyon 14. 12/10/2006 00:00 - 06:00 6.00 MOB N WAIT PRE Wait on PEAK to finish rig move on 2 ES and Doyon 14. Cleaning and painting rig components and performing planned maintenance. 06:00 - 22:00 16.00 MOB P PRE RDMO MPJ-06. 22:00 - 00:00 2.00 MOB P PRE Move rig from MPJ-06 to Milne Point Y intersection by MPU main camp. 12/11/2006 00:00 - 12:00 12.00 MOB N WAIT PRE Waiting at Milne Point Y intersection in front of MPU main camp for Doyon Rig #14 to pass. 12:00 - 00:00 12.00 MOB P PRE Move Camp, Carrier, Pits, and Pipe Shed from Milne Point Y intersection to W-29. 12/12/2006 00:00 - 03:00 3.00 RIGU P PRE Spot BOPs, Tree, and Adapter Flange behind Well. Set Mats and line up Carrier with Well. 03:00 - 04:00 1.00 RIGU N PRE Wait on Herculite to arrive. 04:00 - 12:00 8.00 RIGU P PRE Spot Herculite, spot and set Carrier and Pits. 12:00 - 16:00 4.00 RIGU P PRE Raise and Scope Derrick. Clear Floor and Pipe Shed. 16:00 - 19:00 3.00 RIGU P PRE Remove Stabbing Board from Roof and place in Pipe Shed. Install Windwalls on Stabbing Board and inspect hydraulic fittings. 19:00 - 21:00 2.00 RIGU P PRE PJSM. R/U Stabbing Board. 21 :00 - 23:00 2.00 RIGU P PRE R/U Berm and spot Tiger Tank. R/U Hardline. Load Pipe Shed with Kelly Swivel and Bushings. Remove Kelly from Shuck. 23:00 - 00:00 1.00 RIGU N PRE Manually adjust Upper Pipe Skate to line up properly as designed. 12/13/2006 00:00 - 02:30 2.50 RIGU N RREP PRE Remove Hydraulic Rams from Upper Pipe Skate section, manual adjust them to the proper length, and re-install. 02:30 - 04:00 1.50 RIGU P PRE PIU and R/U Kelly. 04:00 - 05:00 1.00 RIGU P PRE Install Double Valve on IA. R/U Line from IA to Tiger Tank and test. Accept rig at 0400-hours. 05:00 - 05:30 0.50 DHB P DECOMP Pull BPV with Lubricator. TIIIO = vac/O/O. 05:30 - 08:30 3.00 KILL P DECaMP R/U LRS to Circulate down Tubing. Install Fusible Cap on SSV and give LRS control of SSV. Test LRS lines and re-test line to Tiger Tank. R/U 1st Vac truck of 120-F seawater to suction of LRS pumping truck. Hold PJSM with all truck drivers, LRS crew, rig crew, Tool Pusher and Wellsite Leader. 08:30 - 12:00 3.50 KILL P DECaMP Circulate 290-Bbls of 120-F seawater through wellbore, taking returns to Tiger Tank; 5-BPM @1200-psi. SID after 290-Bbls pumped to strap TT and HIU second vac truck. TT has 248-Bbls; 42-Bbls lost to wellbore and lines fill up. Well was on slight vacuum when the BPV was pulled. Pump 2nd truckload at 5-BPM and 1200-psi, taking returns to TT. Send 290-Bbls to Pad 3 and strap 240-Bbls in TT. Pump 3rd truckload at 5-BPM, 1200-psi. Send 290-Bbls to Pad 3 for disposal. Well cleaned up Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Releasø: Rig Numbe!r: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/13/2006 08:30 - 12:00 3.50 KILL P DECOMP with 75Q-Bbls circulated through the well bore. Continue pumpin4 until 3rd truckload is emptied. HIU 3rd empty truck to TT and recover 271-Bbls for a total recovered volume of 851-Bbl~ versus 870-Bbls pumped. 12:00 - 13:00 1.00 KILL P DECOMP Check vVell and have slight vacuum on tubing and IA. RID LRS and blo~down line to Tiger Tank. 13:00 - 17:00 4.00 WHSUR P DECOMP P/U TWC and install in hanger and test both sides. Use Test Pump tq test from bottom. Test held solid @ 1 ,OOO-psi for 10-minu~es. Test TWC from above at 4,000-psi for 10-minutes. Find and replace three leaking Whitey valves in the Test pump lines. 17:00 - 19:00 2.00 WHSUR P DECOMP Nipple dpwn Tree. 19:00 - 20:00 1.00 WHSUR P DECOMP Cameror inspected Hanger threads (8-rd EUE), found to be in good sh~pe. Count 10 turns to fully screw in XO for Landing Joint. FLjnction LDS and visibly watch LDS turn. All LDS are functioning. 20:00 - 00:00 4.00 BOPSU P DECOMP PJSM. N/U BOPE. 12/14/2006 00:00 - 06:00 6.00 BOPSU P DECOMP NIU BO~E. 06:00 - 08:15 2.25 BOPSU P DECOMP Pressur~ test BOPE to 250 psi low and 4000 psi high and chart results. Pressure test Annular Preventer to 250 psi low and 3500 psil high. Find leaks in valves on Choke and Kill Manifold and use bew Valve saver AW grease to lube all valves. Find Valve with stem separated from paddle; breakout and repair. 08:15 - 10:00 1.75 BOPSU P DECOMP Repair v~lve in Choke/Kill Manifold. 10:00 - 20:00 10.00 BOPSU P DECOMP ResumelBOPE testing. Replace 1/2" choke valve in Test Pump bleed linè. Valves in Choke/Kill Manifold continue to leak. Retest Blinds and TWC and they are okay. Start over again with the Çhoke/Kill manifold; valves 1, 2, and 3 and HCRs on Choke a~d Kill lines test good. Continue on with second test: valves 4,j 5, and 6 and will not hold so decide to re-grease all valves inlthe manifold. Resume BOPE testing. 20:00 - 21 :30 1.50 PULL P DECOMP RlU SLBjSpooler and await arrival of DSM wI Lubricator and Lubricator extension. 21 :30 - 22:30 1.00 DHB P DECOMP RlU Lubricator and Lubricator extension. Pull TWC. T/I/O=OIOIO psi. RID ,nd UD Lubricator and Lubricator extension. 22:30 - 00:00 1.50 PULL P DECOMP BOLDS. RIH with 3-1/2" landing joint M/U and MIU to Hanger. Verify IA þressure is 0 psi. PJSM. PIU and break hanger free @ -90K 11- blocks, continue to P/U and see 75K + blocks. 12/15/2006 00:00 - 01 :00 1.00 PULL P DECOMP Tie sash þord onto Control Line and cut Control Line Umbilical and MIU pontrol Line to Spooler. Break off Landing Joint from Hanger ahd UD same. 01 :00 - 10:00 9.00 PULL P DECOMP POH UDj3-1/2" completion Tubing and control line (-2100'). Number jþints as POH. Stuff Tubing joint ends wlabsorb to prevent drips to pad. Transfer Tubing from Pipe Shed to bermed aJrea on well pad. 40-joints POH and UD at 0500-hours. SSSV reJched at 0630-hrs (65-jts UD). 10:00 - 10:30 0.50 PULL P DECOMP Hold Safety "Moment" on Rig Floor for night crew's long day. Discuss durrent operations to reinforce Safety focus for crew. 10:30 - 22:00 11.50 PULL P DECOMP Resume fOH with 3-1/2" tubing. 100-jts @ 1030-hrs; 130-jts @ 1145-hrs.jTool Pusher, WSL, ADW Field Drilling Engineer, Supersuc~er truck driver, GC2 Area Manager hold ACWR meeting i~ Pad Operator's building and in Rig Cellar, and agree to go ahetd with Mouse Hole construction. Build Mouse Hole in Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING J NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/15/2006 10:30 - 22:00 11.50 PULL P DECOMP Cellar with Steam Wand and Supersucker Snorkle line. SID POH at 1350-hrs wI 150-jts POH and UD. Insert Mouse Hole Casing; release Supersucker truck. Resume POH and UD 3-1/2 tubing. 190-jts @ 1615-hrs. 232-jts @ 1745-hrs. POH wI joint # 308 (cut joint) 16.00' in length. Cut is uniform with no flare. Picture taken and sent to town. Recovered 33 rubber Control Line Protectors and 4 SS-bands, vs 33 protectors and 2 SS-bands shown on original tally. 22:00 - 00:00 2.00 CLEAN P DECOMP RJU to MIU BHA. Load Pipe Shed with Drill Collars and 3-1/2" 13.3# HT38 Drill Pipe. Strap DP as it is being loaded into the Shed. P/U BHA components and bring to Rig Floor. 12/16/2006 00:00 - 02:30 2.50 CLEAN P DECOMP RJU to M/U BHA. Load Pipe Shed with Drill Collars and 3-1/2" 13.3# HT38 Drill Pipe. Strap DP as its being loaded into the Shed. PIU BHA components and bring to Rig Floor. 02:30 - 05:00 2.50 CLEAN P DECOMP PJSM wI Baker Fishing Hand. M/U BHA #1 consisting of 8-1/2" Bit, 9-5/8" Scraper, Bit Sub, Bumper Sub, Oil Jar, and 6 Drill Collars. 05:00 - 10:00 5.00 CLEAN P DECOMP RIH wI BHA#1 on 3-1/2" DP down to 2055' MD. 10:00 - 12:00 2.00 CLEAN P DECOMP PIU Kelly, M/U to DP, and circulate hot seawater through Kelly and string before torquing up the Kelly connections. 12:00 - 16:00 4.00 CLEAN P DECOMP Torque and PIT Kelly to 250 psi low and 4000 psi high. 15:00 - 21 :30 6.50 CLEAN P DECOMP RIH wI BHA#1 on 3-1/2" DP down to 5130' MD while picking up and strapping DP from Pipe Shed. 21 :30 - 22:30 1.00 CLEAN N DECOMP Repair leaking Hydraulic Ram Fitting on Upper Pipe Skate section. Approximately 1 gallon of hydraulic fluid leaked from Fitting and fell into containment. Hydraulic fluid was cleaned up and Fitting was repaired. 22:30 - 00:00 1.50 CLEAN P DECOMP RIH wI BHA#1 on 3-1/2" DP down to 10,037' MD while picking up singles from Pipe Shed. Joint # 210 @ 00:00. 12/17/2006 00:00 - 05:00 5.00 CLEAN P DECOMP RIH wI BHA#1 on 3-1/2" DP while picking up singles from Pipe Shed. Joint # 235 @ 02:00. RIH wI joint # 310. Lightly tag stub @ 10,023' MD. POH wI 1 joint of DP and secure well. 05:00 - 12:00 7.00 CLEAN P DECOMP Safety Stand down. 12:00 - 13:00 1.00 CLEAN P DECOMP Rig up to Reverse Circulate to cleanout wellbore and displace fluid with clean seawater, taking returns to Pits and to Tiger Tank. 13:00 - 14:00 1.00 CLEAN P DECOMP Ship fluid from Pits to allow returns through Shakers from Reverse Circulation. 14:00 - 18:00 4.00 CLEAN P DECOMP Reverse Circulate HiVis Sweep through wellbore and follow with clean seawater displacement. 18:00 - 18:30 0.50 CLEAN P DECOMP Pressure test Fasdrill Plug @ 10,051' MD to 1000 psi and chart. PIT passed. 18:30 - 19:00 0.50 CLEAN P DECOMP P/U and M/U joint #310. POH wI joint #310 and #309 and SIB. POH wI 3-1/2" DP and BHA #1 while SIB DP. 155 total stands to SIB. 19:00 - 00:00 5.00 CLEAN P DECOMP POH wI 3-1/2" DP and BHA #1 while SIB DP. 155 total stands to SIB. Filling hole wlseawater every 10 stands. 12/ 18/2006 00:00 - 03:00 3.00 CLEAN P DECOMP POH wI 3-1/2" DP and BHA #1 while SIB DP. 155 total stands to SIB. Filling hole wlseawater every 10 stands. 03:00 - 06:00 3.00 CLEAN P DECOMP POH and SIB 3-stands of Drill Collars. Break and UD BHA #1. Clear and clean Rig Floor. 06:00 - 08:00 2.00 EVAL P DECOMP PJSM. RJU E-Line for US IT log. 08:00 - 15:30 7.50 EVAL P DECOMP Log wI US IT in corrosion and CBL mode from 10,000' MD to Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: Spud Date: 7/24/1988 End: 12/8/2006 1/21/2007 12/18/2006 08:00 - 15:30 7.50 EVAL P DECOMP 15:30 - 17:00 1.50 EVAL P DECOMP 17:00 - 19:00 2.00 PULL P DECOMP 19:00 - 19:30 0.50 PULL P DECOMP 19:30 - 21 :30 2.00 WHSUR P DECOMP 21 :30 - 00:00 2.50 PULL P DECOMP 12/19/2006 00:00 - 02:30 2.50 PULL P DECOMP 02:30 - 10:00 7.50 PULL P DECOMP 10:00 - 11 :30 1.50 WHSUR P DECOMP 11 :30 - 12:00 0.50 WHSUR P DECOMP 12:00 - 15:30 3.50 WHSUR P DECOMP 15:30 - 16:00 0.50 WHSUR P DECOMP 16:00 - 18:30 2.50 WHSUR P DECOMP 18:30 - 19:30 1.00 WHSUR P DECOMP 19:30 - 21 :00 1.50 WHSUR P DECOMP 21 :00 - 23:00 2.00 FISH P DECOMP 3,000' MD. Area of primary interest 4,945' MD - 5,240' MD. Make repeat pass over area of interest. Transmit data to town. Top of quality cement -2,634'. RID Schlumberger E-line equipment. Slip and cut drilling line. Pull Wear Ring and RlU to changout Packoffs. Heat Tubing Spool to assist in pulling existing Packoffs. Attempt to changeout 9-5/8" Mandrel Casing Packoffs. Cameron onsite. Unable to get all LDS out. On every attempt 1-LDS would stick indicating that the 9-5/8" Casing might grow. Consult town. Change of scope. RILDS. Install Wear Ring. PJSM. PIU and MIU BHA #2 : Double Overshot Bowl, Jars, 10-Drill Collars, and Pump Out Sub. P/U and M/U BHA #2: Double Overshot Bowl, Jars, 10-Drill Collars, and Pump Out Sub. RIH wI BHA #2 on 3-1/2" DP from the Derrick to - 9,850' MD. 0600-hrs 83-stands. 0730-hrs, stand #100. 0835-hrs, #125. 0920-hrs, stand #140. PIU and M/U Halco RTTS packer and RIH one stand and set to use the weight of DP string to hold casing in place in order to withdraw LDS to remove the 9-5/8' packoff. P/U packoff running/pulling tool and engage packoff, backout LDS, and pull packoff to the floor. PIU new packoff on running tool and RIH. Can't get the packoff to drop over mandrel. Discuss with town and decide to remove BOP stack to gain access to the Casing Head. Remove Pitcher Nipple and NID Casing Head. Hold PJSM to discuss picking up the BOP stack with the Bridge Crane winches. BOP Stack picked up and moved 2' toward back of rig with no problem. Installed packoff over the top of the mandrel and it dropped into place with little effort. Run in two LDS and move BOP stack back over Casing Head and slowly lower into place. N/U BOP Stack to Casing Head flange and install Pitcher Nipple. Inject plastic sealant into packoff void and pressure test to 5,000-psi. Conduct BOPE Body test to 250 psi low and 4000 psi high. Passed. P/U 1-stand and RIH to engage RTTS. Rotate 19 revolutions, unseat RTTS and POH standing back 1-stand in Derrick. Monitor well T/I/O=OIOIO psi. Break and UD HES RTTS. RIH wI stand #152 and PIU single joint #311. Kelly up and RIH while pumping @ 3BPM and 280 psi. P/U weight = 142k SIO = 124k. Free spinning torque = 4,500 ft-Ibs with 134k hanging weight while rotating. RIH and tag stub at 10,023' MD. Swallow 9' (saw 300 psi pressure increase in pump pressure) and engage Grapple. P/U 180k then SIO to 145k (1 Ok over rotating weight). Rotate 19 revolutions (Max Torque experienced was 6,000 ft-Ibs) then P/U to 180k. Fish is not free. S/O and rotate 9 revolutions (no noticeable torque) then P/U to 200k. Do not have fish. P/U to 225k and allow jars to function. Set back down then P/U to 225k and allow jars to function. Repeat 3 more times. PIU to 250k and allow jars to function. S/O and repeat 2 more times. Fish comes free. Attempt to circulate but Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/19/2006 21 :00 - 23:00 2.00 FISH P DECOMP cannot. POH 20' with fish. PIU weight with fish is now 152k (7k over original P/U weight prior to latching fish). Due to the inability to circulate it is thought that the fish might be the SBR, Anchor Latch, and Fasdrill plug. Drop ball and Rod. Shear Pump out Sub at 2350 psi. 23:00 - 00:00 1.00 FISH P DECOMP Circulate 620 Bbls of seawater at 4 BPM and 400 psi. No gains or losses experienced. 12/20/2006 00:00 - 02:00 2.00 FISH P DECOMP Continue to circulate 620 Bbls of seawater at 4 BPM and 400 psi. No gains or losses experienced. 02:00 - 03:00 1.00 FISH P DECOMP Break and SIB Kelly. 03:00 - 11 :00 8.00 FISH P DECOMP POH wI BHA #2 and fish while SIB DP in Derrick. Filling hole with seawater every 10 stands. 0715-hrs, Std #68. 0845-hrs, Std #100. 1020-hrs, Std #138. Install repaired access stairs on Pipe Shed. 11:00 -17:00 6.00 FISH P DECOMP Break out and UD BHA. Will have to UD 4 of the 6 DCs. Recovered the SBR (15.43') and its pup joint (4.07'). Can't get the 3-1/2" cutoff out of the top Grapple in order to breakoff the Overshot Bowl, Bumper Sub and Oil Jars. Call Tool Services to round up 3-1/2" Ridgid Tubing Cutter. Cut tubing, break out and UD Overshot Bowls, Top Sub, XO Sub, Bumper Sub, and Oil Jars. Recovered 14.53' cut-off 3-1/2" joint. 17:00 - 18:30 1.50 FISH P DECOMP Install new Overshot Bowls dressed with smaller ID grapples and M/U remainder of BHA #3. 18:30 - 00:00 5.50 FISH P DECOMP RIH BHA #3 on DCs and DP from Derrick. Experience no gains or losses as RIH. Well is static. 12/21/2006 00:00 - 02:00 2.00 FISH P DECOMP RIH BHA #3 on DCs and DP from Derrick. 02:00 - 05:00 3.00 FISH P DECOMP RIH wI stand #152. P/U single joint #311 and 11.06' pup. Kelly up and RIH while pumping @ 3 BPM and 320 psi. PIU weight = 150k S/O = 130k. Free spinning torque = 1,300 ft-Ibs with 140k hanging weight while rotating. RIH and tag @ 10,045' MD. Swallow 9' (saw 20 psi pressure increase in pump pressure) and engage Grapple. PIU 200k then SIO to 150k (10k over rotating weight). Rotate 19 revolutions (none stayed in string) then P/U to 200k. Fish is not free. S/O and rotate 9 revolutions (none stayed in string) then PIU to 200k. Do not have fish. PIU to 225k and allow jars to function. Set back down then PIU to 225k and allow jars to function. Repeat 3 more times. PIU to 250k and allow jars to function. S/O and repeat 30 more times. PIU 275k and allow jars to function. Fish comes free. POH 20' with fish. PIU weight with fish is now 155k (5k over original PIU weight prior to latching fish). 05:00 - 06:30 1.50 FISH P DECOMP Reverse Circulate 135 Bbls of seawater @ 4 BPM and 500 psi, until returns cleaned up. Recovered bits of rubber and some sand. 06:30 - 15:00 8.50 FISH P DECOMP POH with BHA #3 and SIB DP in Derrick. 0800-hrs, Std #20. 0850-hrs, Std #40. 1100-hrs, Std #80. 1420-hrs, Std #145. 15:00 - 18:30 3.50 FISH P DECOMP Breaking out and UD BHA #3. Did not get all of Fish as expected. Send off for Burn Shoe from Baker Shop for next run. Consult town: plan forawrd is to burn through Packer. 18:30 - 20:30 2.00 FISH N DECOMP Wait on BHA components from Baker Shop. 20:30 - 22:00 1.50 FISH P DECOMP MIU BHA #4: Shoe, Washpipe, Boot Baskets, Jars, 6- Drill Collars, and Pump Out Sub. 22:00 - 00:00 2.00 FISH P DECOMP RIH wI BHA on 3-1/2" DP from the Derrick to 1,848' MD Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 1 2/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/21/2006 22:00 - 00:00 2.00 FISH P DECOMP (25-Stands). 12/22/2006 00:00 - 01 :00 1.00 FISH P DECOMP RIH wI BHA on 3-1/2" DP from the Derrick to 1,848' MD (25-Stands). 01 :00 - 02:00 1.00 FISH P DECOMP PIU and MIU Halco RTTS packer and RIH one stand and set (-65'). POH and SIB stand. PIU weight prior to setting RTTS was 50k-lbs. 02:00 - 03:30 1.50 DHB DECOMP Pull Wear Ring and install Test Plug. 03:30 - 11 :30 8.00 BOPSU P DECOMP Test BOPE to 250 psi low and 4000 psi high. Test Annular Preventer to 250 psi low and 3500 psi High. Test with 3-1/2" and 4-1/2" test joints. PIU and test Kelly. 11 :30 - 13:00 1.50 BOPSU P DECOMP PIU Kelly and set back into Kelly Shuck. 13:00 - 14:00 1.00 FISH P DECOMP RIH, engage the Storm Packer and POH, Break Off and UD same. 14:00 - 22:00 8.00 FISH P DECOMP Resume RIH with BHA #4 on DP from Derrick. 1630-hrs, Std #63. Pump dry job to improve cycle time between connections while RIH. 22:00 - 00:00 2.00 FISH N DECOMP Oiler which lubricates the bearings on the Drawworks is down. Oil in system is cold and too viscous to pump. Put Tioga under oil pan and attempt to circulate out the cold oil in the system. Cannot proceed until oiler is functioning. 12/23/2006 00:00 - 01 :00 1.00 FISH N RREP DECOMP Oiler which lubricates the bearings on the Drawworks is down. Oil in system is cold and too viscous to pump. Put Tioga under oil pan and attempt to circulate out the cold oil in the system. Cannot proceed until oiler is functioning. 01 :00 - 02:30 1.50 FISH P DECOMP Resume RIH with BHA #4 on DP from Derrick. 02:30 - 03:00 0.50 FISH P DECOMP Clear Rig Floor. PJSM for picking up Kelly. 03:00 - 04:00 1.00 FISH P DECOMP PIU and MIU Kelly. 04:00 - 08:00 4.00 FISH P DECOMP RIH and Tag at 10,058' MD. P/U weight'" 143k-lbs. S/O weight '" 127-lbs. Pump @ 3 BPM and 300 psi. Rotating weight = 134k-lbs. Set down 5k-lbs while rotating at 70 RPM with 3,500- 5,000 ft-Ibs of torque. Pump pressure increased to 380 psi. Milled down to 10,061' MD as of 0600-hrs. Milled to 10,063 at 0800-hrs. 08:00 - 00:00 16.00 FISH N RREP DECOMP While attempting to release locked-up torque in the drill string, the rotary brake failed to quickly stop the string. It is probable that excessive centrifugal force in the Rotary Clutch caused the pneumatic Quick Release housing bolted to the clutch assembly to disengage from the clutch. The pneumatic Quick Release housing, braided airline and connections were destroyed. The parts are available onsite, but the drive line to the clutch housing will be removed and the clutch housing and assembly will have to be dismantled to make repairs. Picked up to first tool joint and parked the string. No fluid loss to formation as of 1200-hrs. 12/24/2006 00:00 - 06:00 6.00 FISH P DECOMP RIH and Tag at 10,059.5' MD. PIU weight = 143k-lbs. SIO weight = 127-lbs. Pump @ 3 BPM and 380 psi. Rotating weight = 142k-lbs. Set down 5k-lbs while rotating at 70 RPM with 2,800 ft-Ibs of torque and made 0.5'. Set down 15k-lbs while rotating at 70 RPM and 3,000 ft-Ibs. Made no progress. Packer appears to be spinning as of 0430 hrs. Continue setting 15k-lbs on Packer and see torque increase to 3,500-5,500 ft-Ibs. Start losing fluid. PIU 10' and then RBIH and tag Packer @ '10,063'. Packer gives way. Push Packer down 20'. POH 10' and Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/24/2006 00:00 - 06:00 6.00 FISH P DECOMP circulate. 06:00 - 09:30 3.50 FISH P DECOMP Pump 30-Bbl HiVis sweep, circulate Bottoms Up volume of 620 Bbls @ 4 BPM and 500 psi. Get some oil and small chunks of rubber across shaker. Lose 45-Bbls during the 3-1/2 hour circulation, or 13-BPH. 09:30 - 10:30 1.00 FISH P DECOMP PJSM to P/U and set back Kelly. P/U Kelly and break off string to blowdown and set back Kelly in Shuck. P/U Bales and Elevators. R/U equipment to start POH with DP. 10:30 - 11 :00 0.50 FISH P DECOMP PIU single joint of DP from Pipe Shed and RIH. PIU stand from Derrick, RIH and tag fish, pushing it to a light tag at 10,097'. P/U, then slowly put 15,000-lbs on fish. Call that good; SIB double, UD single joint, and get ready to POH. 11:00 -12:30 1.50 FISH P DECOMP Clear and clean Rig Floor. Start hole fill pump to fill wellbore and the stand pipe valve had not been closed, allowing the Kelly and the Kelly Shuck to be filled with seawater. SID and suck out Shuck from the drain hole in the bottom. 5-gallons of seawater leaked out into secondary containment when the suction line was disconnected from the bottom of the Shuck. Spill was reported to BP Environmental, and was cleaned up by Floorhands immediately. 12:30 - 22:00 9.50 FISH P DECOMP POH with 3-1/2" DP and SIB in Derrick. 1400-hrs, 24-stds, 12-Bblloss. 1330-hrs, 4-gal spill of steamed seawater from cuttings tank thawing process. Spilled into containment and cleaned up immediately by roustabout. Reported to BP Environmental. 1500-hours, 40-stands. 1545-hrs, 60-stds. 1630-hours, 75-stds. 1700-hrs, 90-stds. 1900-hrs, 105 stds. 22:00 - 00:00 2.00 FISH P DECOMP Break and UD Burn Shoe and Washpipe BHA. 12/25/2006 00:00 - 03:30 3.50 FISH P DECOMP Break and UD Burn Shoe and Washpipe BHA. 03:30 - 07:00 3.50 FISH P DECOMP PIU and MIU BHA #5: Spear, Jars, 6-Drill Collars, and Pump Out Sub. 07:00 - 13:30 6.50 FISH P DECOMP RIH BHA #5 on DP from Derrick. 0845-hrs, Std 25. 1100-hrs, Std 75. 1200-hrs, Std 105. 13:30 - 00:00 10.50 FISH P DECOMP Stand down. 12/26/2006 00:00 - 05:00 5.00 FISH P DECOMP RIH BHA #5 on DP from Derrick. Kelly Up @ 10062' MD. PIU weight prior to spearing fish is 145k-lbs. SIO weight is 125k-lbs. Circulate Seawater @ 3 BPM and 480 psi. Tag top of Packer assembly at 10,097' MD. Set down 10k-lbs. PIU weight after spearing fish is 155k-lbs. Shear Pump Out Sub @ 1800 psi. 05:00 - 21 :30 16.50 FISH P DECOMP POH wI BHA #5 and Packer/Tubing Tail Assembly. SIB DP and Drill Collars. String increased in drag when POH with Stand #9, but pulled free with 5K overpull. 1000-hrs, 45-stds. Fluid losses @ -10 bbls/hr. 16:30 - 130 stands OOH. 21 :30 - 00:00 2.50 FISH P DECOMP POH wI BHA #5 and Packer. Bottom slips of Packer getting caught downhole and unable to POH. Packer might be caught on Wear Ring. BOLDS on Wear Ring. Attempt to pull Packer to surface again. Use tugger to center Packer in hole. No success. Packer caught on Packoff. RILDS on Wear Ring. Rotate 1/4 turn to the left. POH, no success. Rotate 1/2 turn to the left. Packer slides past Packoff and through Stack. As POH, lost a 2" x 4" portion of the bottom slips. Break and UD Packer. Change Elevators. Break and UD 3-joints of 3-1/2" Tubing. Tubing was full of water and foul smelling solid mud. 12/27/2006 00:00 - 04:30 4.50 FISH P DECOMP Break and UD BHA. RIH wI 6" Drill Collars. Break and UD Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/27/2006 00:00 - 04:30 4.50 FISH P DECOMP Collars into Pipe Shed. 04:30 - 06:00 1.50 FISH P DECOMP P/U and MIU BHA #6: Reverse Circulating Junk Basket, 2-Boot Baskets, Bumper Sub, Jars, 6-Drill Collars (4-3/4"). 06:00 - 15:00 9.00 FISH P DECOMP RIH wI BHA #6 on 3-1/2" DP from the Derrick. Losses = - 10 Bbls/hr. 155 stands in hole. P 15:00 - 17:00 2.00 FISH P DECOMP PUMU single 31/2" DP, MU Kelly and wash down to 10165'. Pumping 4 BPM, 650 psi. Wash 11' into 7" liner. Clean entry, no sign of TOL. Break out, blow down and lay down Kelly. 17:00 - 19:00 2.00 FISH P DECOMP PUMU singles of 3 1/2" DP as RIH to tag fill. 19:00 - 23:00 4.00 FISH P DECOMP PUMU 10' and 5' pup joints and RIH. Kelly Up and start circulating at 4 BPM and 730 psi. RIH while washing down and tag @ 10,755' MD. Set down 5k-lbs and rotate at 60 RPM. Free spinning torque = 2,000 ft-Ibs. Continue washing down with torque increasing as high as 2,500 ft-Ibs. Break through at 10,760' MD. Continue RIH and tag again at 10,763' MD. Set down 7k-lbs with torque increasing as high as 2,500 ft-Ibs. Reach 10,778' MD. POH, break Kelly, UD 5' and 10' pups, PIU a single joint and RIH. Kelly Up and wash down with same parameters.Tag again at 10,795'. Torque increasing as high as 3,100 ft-Ibs. Work from 10,795' - 10,804' MD over 30 minutes. POH 10' and RBIH to confirm 10,804' tag depth. Final depth reached during cleanout = 10,804' MD. Nothing seen across Shakers during circulation. 23:00 - 00:00 1.00 FISH P DECOMP Circulate 60 Bbls at 4 BPM and 700 psi. Break and set back Kelly. 12/28/2006 00:00 - 06:00 6.00 FISH P DECOMP POH wI BHA #6 and Fish while SIB 3-1/2" DP in Derrick. Losses at -6-10 bbls/hr. A total 75 of 167 stands are OOH as of 0430-hrs. 06:00 - 10:00 4.00 FISH P DECOMP POH 167 Stds total. Losses @ -10 BbI/Hr. At surface with RCJB BHA. 10:00 - 12:00 2.00 FISH P DECOMP BOLD Baker RCJB Fishing Assy. Recovered numerous slickline artifacts. Unable to determine if XX plug recovered in mass of braided line, metal pieces, and twisted metal rods. 12:00 - 12:30 0.50 FISH P DECOMP Clear and Clean rig floor. Schmoo. 12:30 - 16:00 3.50 FISH P DECOMP Remove pitcher nipple and boot basket from top of Hydril. Nipple up shooting flange for E-Line operations. 16:00 - 20:00 4.00 FISH P DECOMP RU SLB E-line lubricator and pressure control equipment to pipe shed and then to floor. Give AOGCC 24 hour notice for weekly BOPE testing. Talked to Chuck Scheve. Will utilize an RTTS with storm valve and Chuck insists we utilize a test plug for pressuring against. 20:00 - 00:00 4.00 FISH P DECOMP RIH wI E-Line to 10,400' MD and perform tie in pass. Found Liner top at 10,138'. Stop depth = 10,166.6'. CCL to top of plug = 11.4'. Fasdrill set at 10,178' (40' below Liner). Slacked off and tagged plug to confirm setting depth. POH wI Eline. 12/29/2006 00:00 - 01 :00 1.00 DHB P DECOMP Pressure Test Fasdrill at 10,178' wlmd to 2500 psi for 10 minutes and chart. Passed. Blow down lines. 01 :00 - 02:00 1.00 PERF P DECOMP MIU 2' Perf gun and bring to Rig Floor. 02:00 - 03:30 1.50 PERF P DECOMP RIH wI E-Line and perforate from 5,480' - 5,482' w/12 spf 4.5" guns. Tied into US IT log dated 12/18/2006. Good indication % 03:30 - 04:30 1.00 PERF P DECOMP detonation. POH wI E-Line. pt UD spent gun and M/U 5' Perf gun and bring to Rig Floor. 04:30 - 07:00 2.50 PERF P DECOMP RIH wI E-Line and perforate from 5,112' - 5,117' w/12 spf 4.5" Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/29/2006 04:30 - 07:00 2.50 PERF P DECOMP guns. Tied into USIT log dated 12/18/2006. Good indication of detonation. POH wI E-Line. 07:00 - 09:00 2.00 PERF P DECOMP Break out perf gun. All shots fired. Rig down SLB Lubricator, BOP and equipment. 09:00 - 11 :00 2.00 PERF P DECOMP Nipple down shooting flange. NU pitcher nipple and air boot on riser. 11 :00 - 17:30 6.50 PERF N RREP DECOMP PJSM for PUMU HES RBP. Boiler #1 and #2 go down on rig. Firebox door blown off of boiler. New crew starting shift arrive on location. Safety meeting with new crew. All hands blowdown and work to restore 1 boiler to operational condiditon. 17:30 - 00:00 6.50 REMCM P DECOMP 1 Boiler operational. PJSM with crew. PUMU HES RBP and RIH to 5670' MD. 12/30/2006 00:00 - 04:00 4.00 REMCM P DECOMP Set RBP @ 5,670' MD (top of plug @ 5,661 '). POH w/2-stands and stand them back in Derrick. Losses to the Formation have stopped. R/U Sand Hopper and dump 13' of sand through 3-1/2" DP and onto RBP. Started dumping sand at 01 :15 and stopped at 03:15. Circulate 27 Bbls down DP to clear sand. 04:00 - 04:15 0.25 REMCM P DECOMP POH wI 3-1/2" DP while SIB in Derrick to 4,956' MD. 04:15 - 06:00 1.75 REMCM P DECOMP M/U RTTS wI Storm Valve and RIH 1-stand. Set RTTS (Top @ 65', Rubbers @ 71') and POH wI 1-stand and SIB in Derrick. 06:00 - 08:30 2.50 REMCM N RREP DECOMP Pull wear ring. RIH wI test plug, RILDS. Changing out valves in choke manifold. 08:30 - 11 :30 3.00 REMCM N HMAN DECOMP Begin BOPE testing. Testing of choke manifold against closed manual choke. Consequently, 3 hours of testing against 1 closed valve. 11:30 - 21:30 10.00 REMCM P DECOMP BOPE Test to 250 psi low and 4000 psi high. Test Annular to 250 psi low and 3500 psi high. Test wI 3-1/2" and 4-1/2" Test joints. Test all gas monitors and alarms. Test witnessed by Chuck Schieve of AOGCC. Pull test plug. Run wear ring. PU Kelly and pressure test. 21 :30 - 23:00 1.50 REMCM P DECOMP PUMU Stinger and RIH wI 1-stand of DP. Sting into and unseat RTTS. Took two attempts as junk was found on threads of stinger tool after first attempt. POH, break and UD RTTS. 23:00 - 00:00 1.00 REMCM P DECOMP RIH wI 3-1/2" DP and tag sand top @ 5650' MD. POH wI 2-stands of DP and SIB in Derrick. R/U Sand Hopper and dump 25 more bags of sand downhole. 12/31/2006 00:00 - 03:00 3.00 REMCM P DECOMP RIH wI 3-1/2" DP and tag sand top @ 5,650' MD. POH wI 2-stands of DP and SIB in Derrick. R/U Sand Hopper and dump 25 more bags of sand downhole. Circulate 30 Bbls @ 1 -BPM and 200 psi. RIH and tag top of sand @ 5,620' MD. - 50' of sand on top of RBP. 03:00 - 07:30 4.50 REMCM P DECOMP POH and SIB 3-1/2" DP in Derrick. Break and UD RBP running tool. 60 stands OOH @ 05:30. 07:30 - 08:30 1.00 REMCM P DECOMP Lay down RBP retrieving head, PUMU HES 9 5/8" RTTS 08:30 - 14:30 6.00 REMCM P DECOMP RIH wI RTTS on 3 1/2" DP. 36 Stds in hole @ 11 :00 a.m. 14:30 - 16:00 1.50 REMCM P DECOMP With RTTS @ 5465' establish circulation parameters. 1 BPM I 50 psi, 2 BPM 1120 psi, 3 BPM I 250 psi, 4 BPM I 380 psi. Set RTTS @ 5465' and attempt to circulate through perforations. Pump 1/4 Bbl volume @ 1/4 BPM and pressure to 800 psi. Hold tight. Unseat RTTS and POH setting and retesting @ depths of 5444' 15425'1 and 5410'. Each attempt resulted in 1/4 Bbl pumped, pressure to 800 psi with no leak off. Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 12/31/2006 16:00 - 17:30 1.50 REMCM P DECOMP POOH and stand back 2 stands. MU test lines. Circulate with packer @ 5350'. Set packer and establish circulaton @ 2 BPM 1120 psi. Set RTTS attempt to inject. Pump 1/4 Bbl volume @ 1/4 BPM and pressure to 800 psi. Hold tight. Bleed DP to 0 psi, isolate annulus and pump1 1/2 Bbls @ 1/4 BPM, pressure to 800 psi. Bleed to 550 psi after 10 minutes. Pressure to 800 psi wI 1/4 BPM with bleed to 550 psi in 10 minutes. Repeat 3 times with pressure decline decreasing (bleeding slower) each time. 17:30 - 19:30 2.00 REMCM P DECOMP POOH to set packer @ 5020'. Set Packer at 5020' MD and attempt to pump into perforations. Pressured up to 800 psi immediately. Lost 200 psi in 5 minutes. 19:30 - 23:00 3.50 REMCM P DECOMP POH and SIB 3-1/2" DP in Derrick. Break and UD RTTS. 23:00 - 00:00 1.00 PERF P DECOMP Remove pitcher nipple and boot basket from top of Hydril. Nipple up shooting flange for E-Line operations. 1/1/2007 00:00 - 01 :30 1.50 PERF P DECOMP Remove pitcher nipple and boot basket from top of Hydril. Nipple up shooting flange for E-Line operations. 01 :30 - 05:00 3.50 PERF P DECOMP PJSM. RU SLB E-line lubricator and pressure control equipment (10' Lubricator pup, BOPs, Packott) to pipe shed and then to floor. 05:00 - 08:30 3.50 PERF P DECOMP RIH wI E-Line (5' of 4.5" 12 spf Perf Guns) to 5,620' MD and tag sand top. Perform tie in pass and correlate to USIT log dated 12/18/2006. Perforate from 5,167' - 5,172'. Well on slight vacuum for a couple minutes then stable. 08:30 - 10:00 1.50 PERF P DECOMP Rig down SLB. All shots fired. Break out and lay down pressure control equipment. Clean and clear rig floor. 10:00 - 13:00 3.00 PERF P DECOMP Nipple down shooting flange and nipple up air boot and pitcher nipple. Test air boots. Clean and clear rig floor. 13:00 - 21 :30 8.50 EVAL P DECOMP M/U and RIH wI RTTS on 31/2" DP. Tag top of sand at 5622' MD, compared to 5622' elmd. POH to 5460' MD. 21 :30 - 00:00 2.50 EVAL P DECOMP With RTTS @ 5460' establish circulation parameters. 1.5 BPM 160 psi, 2 BPM 1100 psi, 3 BPM I 210 psi, 4 BPM 1 370 psi. Set RTTS @ 5460' and attempt to circulate through perforations. Pump 1/4 Bbl volume @ 1/4 BPM and pressure to 800 psi. Hold tight. Unseat RTTS and POH setting and retesting at a depth of 5150' MD. Pump 1/4 Bbl volume and pressure rose to 550 psi then broke down to 100 psi. Able to circulate at 1 BPM/100 psi, 2 BPM/130 psi, 3 BPM/240 psi. Close Bag and pump down backside pressuring up to 500 psi. 450 psi seen on DP. RIH and set RTTS at 5215' and attempt again to circulate through bottom perfs. Pump 1/4 Bbl and pressure up to 500 psi, holding steady. Increase pump pressure to 800 psi, no circulation. Increase pump pressure to 1000 psi, still no circulation. POH above the perfs at 4961' 1/2/2007 00:00 - 04:30 4.50 EVAL P DECOMP Cut and Slip Drill Line. 04:30 - 09:00 4.50 EVAL P DECOMP POH wI RTTS while standing back 3-1/2" DP in Derrick. 09:00 - 10:00 1.00 EVAL P DECOMP Break out and laydown RTTS. PUMU HES Fasdril squeeze packer on mechanical setting tool and RIH. 10:00 - 16:00 6.00 EVAL P DECOMP RIH wI HES 9 5/8" FasDrill composite squeeze packer. 12:30 I 25 stands in hole. 16:00 - 17:30 1.50 EVAL P DECOMP MU head pin and TIW valve, circulate @ 3 BPM 240 psi, recicprocating pipe across 5150'. Break ott hose, set Fasdrill wI 53K#'s overpull, set 20K on retainer establish circulation wI Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/2/2007 16:00 - 17:30 1.50 EVAL P DECOMP returns through choke @ 3 BPM 500 psi, 160 psi annulus pressure. 17:30 - 19:15 1.75 EVAL N WAIT DECOMP PJSM, SLB unable to start motors in cement van. Circulate @ 1 BPM, 150 psi while waiting on SLB. 19:15-19:35 0.33 REMCM P DECOMP PJSM. SID rig pump. Switch to SLB. Pump 5.0 Bbls. to fill lines. Shut in TIW valve, 2" Lo-Torq valve on cement line and Rig pump valve. PIT cement line to 3000-PSI. 19:35 - 20:05 0.50 REMCM P DECOMP 1935-hrs. -- Pump 10-Bbls. chemical water spacer @ 2.5-BPM @ 50-PSI. SID SLB. Batch mix cement slurry to 15.8-ppg. 1940-hrs. -- Pumping cement @ 2.5-BPM @ 400-PSI DPP, lAP - 70-PSI. 1942-hrs. -- 8.0-Bbls. cement away - DPP = 160-PSI, lAP - 120-PSI. 1949-hrs. - 15.0-Bbls. cement away. Density steady @ 15.8-PPG. Switch to fresh water chaser. Pumped 23-Bbls. @ 2.5-BPM with DPP from 20-30-PSI, lAP from 190-PSI to 680-PSI. At 23-Bbls. away, cement entered perforations and pressures began stabilizing. Final pressure at 36-Bbls. water away DPP - 500-PSI and lAP - 360-PSI. Reciprocated pipe while circulating. 20:05 - 22:00 1.92 REMCM P DECOMP Unsting from cement retainer with no overpull required to clear retainer. Picked up 25' and cleared cement lines. Picked an additional 15' and began circulating residual cement out of wellbore. Reciprocated pipe while circulating. Circulated surface to surface volume - 316-bbls. @ 4.0-BPM @ 450-PSI. Recovered approximately 2.0-Bbls. green cement to vac truck containing 60-Bbl. cement retarder pill. SLB allowed -2.5-Bbls. cement rinsate to escape into herculite berm under rig carrier and 1-gallon of rinsate to escape to gravel pad while washing up cement van and lines. IR-2107815. 22:00 - 00:00 2.00 REMCM P DECOMP PJSM. POH wlcement retainer stinger standing DP in derrick. 1/3/2007 00:00 - 04:00 4.00 REMCM P DECOMP POH wlcement retainer stinger standing DP in derrick. BOLD cement stinger assembly. Clear and clean rig floor. 04:00 - 07:30 3.50 REMCM P DECOMP PUMU 8-1/2" bit, 2 x boot baskets, jars, bumper sub and 6 x 4-3/4" drill collars. 07:30 - 12:00 4.50 REMCM P DECOMP RIH wI drill out BHA on 3 1/2" DP 12:00 - 13:00 1.00 REMCM P DECOMP Tag TOC @ 5132'. Stand back one stand, PUMU 10' pup joint. Rig down elevator and bales. PU Kelly 13:00 - 15:30 2.50 REMCM P DECOMP Circulate above TOC @ 3 BPM, 340 psi while waiting for 1000 psi compressive strength on cement. 15:30 - 16:30 1.00 REMCM P DECOMP Drilling on Cmt @ 60 rpm, 800 ftJLbs torque. 4 BPM, 400 psi. Drill out cement to top of retainer at 5150'. 16:30 - 18:00 1.50 REMCM P DECOMP Drill out retainer @ 5150'. Drilling parameters - PUW = 75K, SOW = 70K, 5K-8k WOB, 60-RPM, 2K-4K-ftJlbs. torque, circulating @ 4.0-BPM @ 250-PSI. 18:00 - 18:30 0.50 REMCM P DECOMP Ream through cemented interval from 5132' to 5157'. Apparently no cement below retainer. Set kelly back and UD single jt. DP. 18:30 - 19:15 0.75 REMCM P DECOMP Run stand #78 from derrick to 5161' and tag up w/5K WOB. Set rotary slips and dry drill with footage achieved. Pick up DP and set 10K WOB. Set rotary slips and dry drill. Pick up DP and tag in same place at 5161'. 19:15 - 20:45 1.50 REMCM P DECOMP Kelly up. Tag up @ 5161'. Drilling parameters - PUW = 75K, SOW = 70K, 2K-4K WOB, 60-RPM, 2K-Ft./lbs. torque, circulating @ 4.0-BPM @ 250-300-PSI. Drill to 5167' and Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING J NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/3/2007 19:15 - 20:45 1.50 REMCM P DECOMP break through. 20:45 - 22:00 1.25 REMCM P DECOMP Set kelly back in rathole. RIH wlDP from derrick and tag up @ 5361' w/5K WOB. Set rotary slips and dry drill with footage achieved. Pick up DP and set 10K WOB. Set rotary slips and dry drill. Pick up DP and tag in same place at 5361'. 22:00 - 00:00 2.00 REMCM P DECOMP Kelly up. Tag up @ 5361'. Drilling parameters - PUW == 75K, SOW == 70K, 2K-4K WOB, 60-RPM, 2K-Ft./lbs. torque, circulating @ 4.0-BPM @ 250-300-PSI. Make connections and circulate down to 5550' with no further cement stringers encountered at OO:OO-hrs. 1/4/2007 00:00 - 03:30 3.50 REMCM P DECOMP Make connections and circulate down each connection with no further cement stringers encountered. Tag up at 5622' which should be top of sand on plug at 5661'. 03:30 - 04:45 1.25 REMCM P DECOMP Attempt to circulate down @ 4.0-BPM without rotating. No-Go. Establish drilling parameters - PUW == 90K, Pump Rate == 4.0-BPM, RPM == 60, WOB == 5-9K, Torque == 2-7K-ft./lbs. Discontinue drilling. Plan forward. 04:45 - 07:30 2.75 REMCM P DECOMP Close annular preventer. PIT casing to 21 OopS!. Pressure bled off 20-PSI in 15 minutes. Swap fluid in hole to clean seawater. Stand back Kelly, RU to POOH. 07:30 - 10:00 2.50 REMCM P DECOMP POOH w/ Drilling BHA. 10:00 - 11 :00 1.00 REMCM N DECOMP Repair heater in Derrick. 11 :00 - 17:00 6.00 REMCM P DECOMP Resume POH wI Drilling BHA. 17:00 - 18:00 1.00 REMCM P DECOMP BOLD Drilling BHA. Boot Baskets contained cement, small pieces of composite cement retainer and small amount of metal debris. The 8-1/2" mill tooth bit showed no wear on teeth and bearings are tight, but bit showed moderate gouge marks on bit shanks. 18:00 - 19:00 1.00 REMCM P DECOMP PJSM. PUMU 9-5/8" HES RBP and set and released RBP @ 60' below rotary table to verify tool in proper working order. 19:00 - 23:00 4.00 P DECOMP RIH w/RBP on 3-1/2" DP and DC's to set @ 5450'. 23:00 - 00:00 1.00 REMCM P DECOMP Attempt to set 9-5/8" RSP @ 5450'. 1/5/2007 00:00 - 00:45 0.75 REMCM P DECOMP Successfully set 9-5/8" RBP on 5th attempt. 00:45 - 04:45 4.00 REMCM P DECOMP POH UD RBP retreiving head standing back 3-1/2" DP in derrick. Notified SLB E-Line to be on well pad @ 04:00-hrs. SLB E-line arrived @ 04:00-hrs. 04:45 - 07:00 2.25 REMCM P DECOMP PJSM - E-line rig up and operations. Rigging up E-Line tools for US IT log. 07:00 - 07:30 0.50 REMCM P DECOMP SLB @ Depth of 5400', attempt to start logging run for US IT I CBL. Tool malfunction. Not getting voltage to tool and motor. Troubleshoot. 07:30 - 09:00 1.50 REMCM N DFAL DECOMP POOH wI US IT / CBL tool. Repair tools with spare parts available on unit. Call for spare tools and WFAD panel wI ET from the shop. Found short in cable head on wireline. Repaired and tested. 09:00 - 10:00 1.00 REMCM N DECOMP RIH wI US IT / CBL and log interval 5400' - 4000'. log shows some cement behind pipe, however, still questionable quality. 10:00 - 11 :30 1.50 REMCM P DECOMP Rig down SLB e-line tools and equipment from rig floor. 11 :30 - 15:00 3.50 REMCM P DECOMP PUMU HES retrieving head for RBP and RIH on 3 1/2" DP. 60 Stands in hole @ 15:00-hrs 15:00 - 16:00 1.00 REMCM P DECOMP Give 24 hours notice to AOGCC, (Lou Grimaldi) for BOPE testing. Continue RIH w/3 1/2" DP and RBP retrieving head. 16:00 - 16:30 0.50 REMCM P DECOMP Tag HES RBP @ 5450' and unseat. Swap lines and RU floor Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/512007 16:00 - 16:30 0.50 REMCM P DECOMP for POOH while letting elements relax. 16:30 - 21 :15 4.75 REMCM P DECOMP POOH wI RBP standing DP and DC's in Derrick. Pre-tour HSE meeting @ 17:30-hrs. 45 Stands OOH @ 19:30-hrs. 21:15 - 21:45 0.50 REMCM P DECOMP BOLD 9-5/8" Halco RBP. Clear & clean rig floor. 21 :45 - 22:00 0.25 REMCM P DECOMP All crew PJSM - PUMU RCJB BHA. 22:00 - 23:00 1.00 REMCM P DECOMP PUMU RCJB BHA - 7-7/8" RCJB, two 7" Boot Baskets, 1 x 4-3/4" Bumper Jar, 1 x 4-3/4" Oil Jar and 6 x 4-3/4" DC's. 23:00 - 00:00 1.00 REMCM P DECOMP RIH w/RCJB BHA on 3-1/2" DP. 1/6/2007 00:00 - 03:30 3.50 REMCM P DECOMP RIH w/RCJB BHA on 3-1/2" DP. 8 Stands RIH @ 00:30-hrs. 25 Stands RIH @ 01 :OO-hrs. Dry tag top of sand @ 5619' 03:30 - 04:30 1.00 REMCM P DECOMP Kelly up. Establish circulation rate @ 4.0-BPM @ 390-PSI. 04:30 - 06:00 1.50 REMCM P DECOMP Break off Kelly, drop ball, make up kelly and resume circulation @ 3.0-BPM to pump ball on seat. Mix 30-Bbl. Flo-vis pill in pill pit. Ball on seat @ 04:45-hrs. Circulating @ 4.0-BPM @ 830-PSI. Tag top of junk wlo rotating. Wash down 2'. Pick up and establish milling parameters. 60-RPM, 4.0-BPM, Free Torque = 3K-ft./lbs., PUW = 90K, SOW = 80K. Tag top of junk, WOM = 1-4K. Torque varying from 3K-ft.lbs. to 10K-ft.lbs 06:00 - 08:00 2.00 REMCM P DECOMP Mill 1 Wash down from 5624' to 5629' MD. WOM = 1-4K, 60 RPM, 3.5K - 10K ft.lbs. of Torque. Shut down pumping and dry mill. PU bring pump back on line, DP plugged pressure to 2100 psi. Work pipe, establish circulation @ 1/3 BPM, 550 psi. Pull 30K over, pipe free slowly. Rotate freely. 08:00 - 09:00 1.00 REMCM P DECOMP Break out, blow down, and stand back Kelly. RU to POOH 09:00 - 14:30 5.50 REMCM P DECOMP POOH wI RCJB BHA. Strapping DP in derrick as POOH. 29 stands OOH, DP pulling wet. Observe well and check trip tank volumes. Well static. Continue POOH. 14:30 - 15:00 0.50 REMCM P DECOMP At collars. Contact Lou Grimaldi wI AOGCC. Witness of BOPE testing waived. Break out collars and BHA. Drain stack and watch as pull 9.50 OD BHA into stack. No "hitch-hikers". Break out BHA. RCJB packed with remnants of 9 5/8" Fasdrill plug (above the finger baskets to jet ports). Mill face of RCJB grooved to OD of 8.118" @ 4.5" above the 8.50" OD mill face. Very little wear on bottom of mill face. Mark corresponds with what was seen on the Bit after drilling out plug and cement. 15:00 - 16:30 1.50 REMCM P DECOMP Break out jars and bumper sub, clean out boot baskets (about half full of drilling debris, sand) Pieces of composite pkr packed up into RCJB, above the fingers. Strap of DP in Derrick resulting in 8' difference over 170 jts (longer measurement due to slack in tape when measuring from stabbing board to rig foor). Prep for BOPE testing. 16:30 - 20:00 3.50 REMCM P DECOMP Pull wear ring and run test plug. Run in 4 x LDS on hanger. Prepare for BOPE testing. 20:00 - 00:00 4.00 BOPSU P DECOMP Weekly BOPE testing. Test annular preventer to 250-PSI Low, 3500-PSI High. Tested remaining BOPE to 250-PSI Low, 4000-PSI High. Tested 2-7/8" x 5-1/2" VBR's with both 3-1/2" and 4-1/2" test joints. 1/7/2007 00:00 - 02:30 2.50 BOPSU P DECOMP Weekly BOPE testing. Test annular preventer to 250-PSI Low, 3500-PSI High. Annular preventer failed high pressure test with 3-1/2" test joint. Replacing annular preventer element. Tested remaining BOPE to 250-PSI Low, 4000-PSI High. Valve #12 on choke manifold failed repeatedly despite greasing and manipulating valve stem. Replacing valve #12 and #13. Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: Valves #12 and #13 were previously scheduled to be replaced. Tested 2-718" x 5-1/2" VBR's with both 3-1/2" and 4-1/2" test joints. 02:30 - 02:45 0.25 RREP DECOMP All crew PJSM - changing out annular preventer element and #12 and #13 valves in choke manifold. 02:45 - 10:30 RREP DECOMP Changing out annular preventer element and #12 and #13 valves in choke manifold. Pitcher nipple cemented and sanded into top of Hydril. Work to free and remove. 10:30 - 11 :00 RREP DECOMP Near Miss: While breaking the bonnet on Hydril, utilizing 2" x 10' piece of pipe, pipe slipped and struck employee in ribs. Stand down ALL CREW MEMBERS. Discuss incident. Get "potatoe masher" from 7 ES and utilize it as proper tool for loosening bonnet on top of annular preventer. Traction report to be generated. 11 :00 - 19:00 8.00 BOPSU RREP DECOMP Continue changeing out bag and choke valves. 19:00 - 00:00 5.00 BOPSU DECOMP Resume weekly BOPE testing. Test #12 & #13 choke manifold valves and upper and lower Kelly cock valves to 250-PSJ low/4000-PSI high. Test annular preventer to 250-PSI 10/3500-PSI high with 3-1/2" and 4-1/2" test joints. 1/8/2007 00:00 - 04:00 4.00 BOPSU P DECOMP Continue weekly BOPE testing. Test #12 & #13 choke manifold valves to 250-PSllow/4000-PSI high and upper and lower Kelly cock valves to 250-PSllow/3500-PSI high. Test annular preventer to 250-PSllo/3500-PSI high with 3-1/2" and 4-1/2" test joints. 04:00 - 05:00 1.00 CLEAN P DECOMP Clear and clean rig floor. Prepare to PUMU BHA. 05:00 - 06:00 1.00 CLEAN P DECOMP PUMU Halco RBP Retrieving O/S to 2 x 7" Baker Boot Baskets, 1 x 4-3/4" Oil Jar, 1 x 4-3/4" Bumper Jar and 6 x 4-3/4" DC's. 06:00 - 07:30 1.50 CLEAN N DECOMP Thaw frozen choke and mud line. 07:30 - 11 :30 4.00 CLEAN P DECOMP RIH wI BHA on 3 1/2" DP. 11 :30 - 13:00 1.50 CLEAN P DECOMP Tag @ 5622'. Establish parameters of 86K #'s PU, 76K 3's SO weight. Pumping 5 BPM I 530 psi. Attempt to jet down through sand I junk. Jet to 5624', setting down hard. Short trip working retrieving tool, rotating, spudding and jetting. Unable to get deeper than 5624' 13:00 - 15:00 2.00 CLEAN P DECOMP Rig up to reverse circulate. Max WHP of 200 psi, 3.5 BPM. Strip through annular preventer trying to reverse down. Strip OOH and repeat. Reverse circulate until returns clean. Get clean sand back, no sign of composite or any other kind of Debris. 15:00 - 15:30 0.50 CLEAN P DECOMP Lay down circ head, single of DP, rig down reverse circulation lines, clean floor. RU Spinnerhawks and prepare to POOH 15:30 - 19:30 4.00 CLEAN P DECOMP POOH to lay down RBP Overshot and PUMH 6 bladed, 8.5" OD Junk Mill BHA. 19:30 - 21:15 1.75 DECOMP B/O and inspect BHA. UD RBP Overshot. Boot baskets retrieved approximately 1/2-gallon of mill shavings, cement, sand and remnants of the composite cement retainer. RBP Overshot showed no significant scarring or wear. 21:15 - 22:00 0.75 CLEAN P DECOMP PUMU Junk Mill BHA - 8-1/2" 6-blade Junk Mill, Bumper Jar, Oil Jar, 6 x 4-3/4" DC's. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH wlJunk Mill BHA on 3-1/2" DP. 1/9/2007 00:00 - 03:00 3.00 CLEAN P DECOMP RIH wlJunk Mill BHA on 3-1/2" DP. 03:00 - 03:45 0.75 CLEAN P DECOMP Kelly up. Dry tag @ 5625'. Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: Spud Date: 7/24/1988 End: 12/8/2006 1/21/2007 DECOMP Establish milling parameters - PUW = 90K, SOW = 80K, Pump Rate = 4.0-BPM @ 310-PSI, RPM = 60, Free Torque = 3500-ft.llbs., WOM = 4K-5K. Mill through junk to 5638'. Rotating through sand from 5638' to 5647. Pick up 5617' and ream to 5647' wIno drag. Pick up to 5617' and run down to 5647' wlo rotating. No drag encountered. DECOMP Make connection wI 10' pup. During connection, noted that piece of rotary slip die 1" x 3/4" missing and assuming it fell down hole during trip in hole. Establish milling parameters - PUW = 90K, SOW = 80K, Pump Rate = 4.0-BPM @ 310-PSI, RPM = 60, Free Torque = 3500-ft.llbs. Pump 30-Bbl. Flo-Vis sweep away. Rotate down to 5650'. Attempt to wash sand down to 5657' wlo rotating. Circulate Sweep surface to surface @ 4 BPM, 350 psi. Sand in returns. Circulate 30,000 strokes. (700 Bbls) POOH wI milling BHA. 25 stand OOH @ 11 :00 a.m. 45-stands @ 1200-hrs. POH and SIB DCs. M/U Lift Sub to BHA and break out, clean out, and UD Boot Baskets. Did not recover chunk of rotary slip die. Clear and clean Rig floor. M/U RBP retrieving tool. RIH RBP retrieving tool on DCs and DP from Derrick. 10-stds of DP in hole @ 1745-hrs. Calibrate Epoch rig monitoring system. RIH RBP retrieving head on DC's and DP from Derrick. RIH RBP retrieving head on DC's and DP from Derrick. Tagged sand @ 5629' which is 28' higher than where well was cleaned out to with junk mill. Rig up lines to reverse circulate. Reverse circulating @ 4.0-BPM @ 310-PSI. Washed down to 5645' and lost pump pressure. Troubleshoot surface equipment to determine reason for lost pump pressure. No anomalies found. Attempt to reverse circulate and lost pump pressure down to 90-PSI while pumping @ 4.0-BPM @ 310-PSI. SID pump and swap lines over to circulate long way. DECOMP Circulating long way @ 4.0-BPM @ 350-PSI. Wash down to 5655'. Pump 30-Bbl Flo-Vis sweep #1 and overdisplace sweep by 40-Bbls to outside of DP. SID pump and make connection. Tagged sand @ 5646'. UD Joint of DP. Pick up joint in mousehole and wash down again to 5655'. Pump 30-Bbl Flo-Vis sweep #2 and over-displace to outside DP by 80-Bbls and reciprocate DP while pumping with sweep outside DP. Recover sweep #1 with small amount of sand. When sweep #2 came to surface, a small amount of sand was recovered across the shakers. DECOMP Discuss options for continuing cleanout with engineering and decide to Reverse circulate at a reduced rate. Realign valves, heavily dope drill pipe to slide through Hydril, then bring rate up to 2-BPM, 170-psi; see no losses. Increase rate to 4-BPM and 320-psi and continue circulating for one DP volume (36-Bbls = 1480-strokes) when heavy sand came across shakers and pump pressure increased to 370-psi. Continue reverse circulating until returns are clean while working pipe down for 1/9/2007 03:45 - 04:30 0.75 CLEAN P 04:30 - 06:00 1.50 CLEAN P 06:00 - 09:00 3.00 CLEAN P DECOMP 09:00 - 13:30 4.50 CLEAN P DECOMP 13:30 - 14:00 0.50 CLEAN P DECOMP 14:00 - 16:00 2.00 CLEAN P DECOMP 16:00 - 17:00 1.00 CLEAN P DECOMP 17:00 - 21 :00 4.00 CLEAN P DECOMP 21 :00 - 23:30 2.50 CLEAN N RREP DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 1/10/2007 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 02:00 1.50 CLEAN P DECOMP 02:00 - 07:00 5.00 CLEAN P 07:00 - 09:00 2.00 CLEAN P Printed: 1/3012007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/10/2007 07:00 - 09:00 2.00 CLEAN P DECOMP next connection. Depth = -5,640'. P/U single and RIH while reverse circulating and continue to see very heavy sand returns across Shaker. Slowly stack out on RBP @ 5,667', P/U and continue rev circ for a total of 170-Bbls when returns clean up. 09:00 - 11 :00 2.00 CLEAN P DECOMP Realign valves to circulate long way and work down to engage RBP. Make numerous attempts to latch onto RBP, but cannot latch and pull, although see the pressure increase and decrease while setting down on and pulling off of the RBP fishing neck. 11 :00 - 13:30 2.50 CLEAN P DECOMP Realign valves to reverse circulate to attempt to further clean off the RBP. Rev circ 4-BPM, 350-psi for surface to surface circ. Small amount of sand recovered across shaker. 13:30 - 15:30 2.00 CLEAN P DECOMP Work retrieving tool over RBP fishing neck numerous times and cannot get latched. Also try rotating 1/4 and up to 1-1/2 turns to engage, but with no success. Break out TIW valve and UD single joint. 15:30 - 20:30 5.00 CLEAN P DECOMP POH and SIB DP and DCs in Derrick. 20-stands out at 1615-hrs. 20:30 - 21 :30 1.00 CLEAN P DECOMP BOLD RBP O/S BHA. No visible damage or foreign material lodged in RBP O/S. Recovered approximately 1/2-gallon of sand, pipe dope and -1-cup of mill cuttings in Boot Baskets. 21 :30 - 22:30 1.00 CLEAN P DECOMP PUMU Baker JRCJB BHA - 7-7/8" JRCJB, 2 x 7" Boot Basket, Bumper Jar, Oil Jar and 6 x 4-3/4 DC's. 22:30 - 00:00 1.50 CLEAN P DECOMP RIH w/JRCJB BHA on 3-1/2" DP from derrick. 1/11/2007 00:00 - 03:00 3.00 CLEAN P DECOMP RIH w/JRCJB BHA on 3-1/2" DP from derrick. 73 Stands RIH @ 0215 03:00 - 05:00 2.00 CLEAN P DECOMP Tag @ 5664' on Stand #86. UD top Joint on Stand #86. Kelly up. Circulate @ 4.0-BPM @ 390-PSI. Break off Kelly, drop ball, MU Kelly. Circulate ball down @ 2.0-BPM @ 110-PSI. Ball on seat 0440-hrs. Increase pump rate to 4.0-BPM, 1390-PSI. Ease down and tag @ 5664', jet down to 5666'. Wash up and down between 5660' and 5666' three times. Engage rotary and establish milling parameters - PUW = 85K, SOW+ 78K, 25 RPM, Torque = 2200-ftJlbs., Pump rate 4.0-BPM @ 1460-PSI. Rotate down to 5666' torque increased to 2400-ft.lbs. Pump 25-Bbl. Flo-Vis "L" sweep. 05:00 - 07:00 2.00 CLEAN P DECOMP Circulating 25-Bbl. sweep around @ 4.0-BPM @ 1490-PSI. 07:00 - 11 :00 4.00 CLEAN P DECOMP Break off TIW valve and UD single joint. POH and SIB DP and DCs in Derrick. 35-stands out at 0945-hrs. 70-stands at 1000-hrs. 85-stands at 1035-hrs. 11 :00 - 12:30 1.50 CLEAN P DECOMP Break out, empty, and UD Boot Baskets. Find in the JRCJB the nose of the cementing plug from the bottom of the Perf cement job shoe track. This would have been too big to pass the top of the fishing neck, which prevented the RBP retrieving tool from latching the fishing neck. 12:30 - 15:00 2.50 CLEAN P DECOMP RIH with Halliburton RBP Retrieving Tool on DCs and DP from Derrick. 15:00 - 15:30 0.50 CLEAN P DECOMP Safety Moment on Rig Floor for Daylight Tour's long day. 15:30 - 20:00 4.50 CLEAN P DECOMP Continue RIH with RBP Retrieving Tool. Hook up circulating lines. Start circulating @ 4.0-BPM @ 110-PSI and tag top of RBP @ 5665'. SID circulating and release RBP. Resume circulating @ previous rate and pressure. 20:00 - 20:45 0.75 CLEAN P DECOMP Rigging up lines to swap well over to clean seawater taking Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/11/2007 20:00 - 20:45 0.75 CLEAN P DECOMP returns from well to Tiger Tank. Ordered out dirty vac truck to haul away dirty returns from well out of Tiger Tank. 20:45 - 00:00 3.25 CLEAN P DECOMP Wait on dirty vac truck and two truck loads of clean seawater to arrive. Dirty truck arrived at 2330-hrs. Thawed hardline to Tiger Tank. Cleaning rig pits. 1/12/2007 00:00 - 10:00 10.00 CLEAN P DECOMP Circulate 160-Bbls clean 90F seawater @ 3.0-BPM @ 140-PSI into wellbore taking returns to Tiger Tank. 1st truckload w/290-Bbls. 90F seawater arrived at 0345-hrs. Waited 9.75-Hrs. for 1st load to arrive. Second 290-Bbls truckload due to arrive at 0700-Hrs, arrived 10:00 - 10:30 0.50 CLEAN DECOMP Safety Moment for Night Tour's long tour. Discussed placement of Elevator Hobble with respect to SIB DP and DCs. Also asked each of the crew for safety comments, most of which were associated with the hazards of the weather outside the rig. Derrickman and Driller discussed past incident (several years ago) that occurred to the Driller when he hit his head on the Hobble clamp attached to the elevator bail. 10:30 - 18:00 7.50 CLEAN P DECOMP POH and SIB DP and DCs. Break off and UD BHA and RBP. 18:00 - 21 :00 3.00 TIEBAC P OTHCMP Clear and clean Rig Floor. R/U Nabors Casing Service equipment and fill up line on floor. 21 :00 - 21 :45 0.75 TIEBAC P OTHCMP Pre-tour HSE meeting. PJSM - PUMU RIH 7" Liner. 21 :45 - 23:30 1.75 TIEBAC P OTHCMP PUMU 7" Liner BHA. Baker-Lok'd required connections and made up to the diamond mark as required for BTC-M connections. Applying Best-O-Life pipe dope to all other connections per program. Atter discussion wlBaker Completions expert and Baker Completions slope supervisor, re-pinned hydraulic setting tool for liner top packer from 3972-PSI to 3641-PSI. 23:30 - 00:00 0.50 TIEBAC P OTHCMP RIH wn" Liner 1 x 1 through pipe shed. 1/13/2007 00:00 - 12:30 12.50 TIEBAC P OTHCMP RIH with 7" Liner 1 x 1 through pipe shed. 0200-hrs, 5-joints RIH. 0300-hrs, jt #15. 0400-hrs, jt #20. 0500-hrs, jt #25. 1000-hrs, jt #80. 1230-hrs, jt #126. 12:30 - 15:00 2.50 TIEBAC P OTHCMP Load into the Pipe Shed and re-tally Joints #127 through #178. 15:00 - 19:00 4.00 TIEBAC P OTHCMP Resume RIH with 7" Liner. 1630-hrs jt #145 RIH, 1800-hrs. jt. #165 RIH. 19:00 - 19:45 0.75 TIEBAC P OTHCMP PUMU 7" Baker Liner Hanger and Packer. 19:45 - 20:30 0.75 TIEBAC P OTHCMP Clear and clean rig floor. Rig down 7" casing handling tools. Rig up floor with 3-1/2" DP handling tools. RU drift hatch on bails. Drift 3-1/2" DP w/2"-Drift while RIH to ensure DP dart will pass while cementing 7" Liner. RIH with 2-stds DP and set in slips. 20:30 - 00:00 3.50 TIEBAC N RREP OTHCMP Thaw out rig cement standpipe and hardline to Tiger Tank. 1/14/2007 00:00 - 01 :00 1.00 TIEBAC N RREP OTHCMP Thaw out rig cement standpipe and hardline to Tiger Tank. 01 :00 - 01 :30 0.50 TIEBAC P OTHCMP Circulate 10-Bbls. through 7" Liner taking returns from IA to pits to establish clear fluid flow path. 01 :30 - 07:30 6.00 TIEBAC P OTHCMP RIH with 45-stds 3-1/2" DP from derrick to locate Liner on depth. 22-stds RIH @ 0330-hrs. 26-stds RIH @ 0430-hrs. Drift stuck in stand #26. Flagged and set stand #26 aside and continued RIH. P/U stand #47 get Up Wt 193K and S/O Wt 159K. Slowly RIH and see slight bobble on weight indicator at 10,136', then stack out within 3'. P/U and POH to 20' and slowly RIH; see stack out at same spot, but do not see bobble on weight indicator. Bottom of Mule Shoe at 10,317', about 4-5' Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/14/2007 01 :30 - 07:30 6.00 TIEBAC P OTHCMP inside the Tieback Receptacle. TOL at 2,970'. 07:30 - 10:30 3.00 TIEBAC P OTHCMP Space-out DP and POH to M/U two pup joints to be placed below stack. RIH and install Baker Cementing Head. RlU additional circulating lines to enable quick valve re-alignment for reverse circulation to cleanout DP after cementing operations. Re-rig open topped tank to a "T" in the hardline to the Tiger Tank. Blow air and 10:30 - 11 :00 0.50 TIEBAC P OTHCMP PJSM with Rig Crew, Tool Pusher, Wellsite Leader, Schlumberger Cementers, Baker Completions Reps, and Veco Truck Drivers. Discuss Plan Forward and reporting requirements for incidents, spills and injuries. ¡¡.. 11 :00 - 14:30 3.50 TIEBAC P OTHCMP Begin cementing operations: 5-Bbls of freshwater, 15-Bbls of Chemical Wash CW-100, 210-Bbls 15.8-ppg Class G cement, and 294-Bbls of seawater displacement. Dropped Liner Wiper Plug Dart at tail end of cement slurry. Saw the Wiper Plug bump bottom at 294-Bbls displacement, then pressured up to 4,200-psi to set the Flex-Lock Hanger. Bleed off pressure, checked floats and they were holding. Relaxed string, re-set slips, and rotated to the right and released from Hanger after 3-turns. 14:30 - 16:30 2.00 TIEBAC P OTHCMP Blow down and clean out cementing lines. Rig down Schlumberger cementers. Reverse circulate cement out of drill pipe; took 102-Bbls to clean up returns to Open Topped Tank treated with Retarder. 16:30 - 18:30 2.00 TIEBAC P OTHCMP Clear and clean Rig Floor. RID circulating lines, break off Baker Cementing Head, and prepare to POH and SIB DP in Derrick 18:30 - 21 :00 2.50 TIEBAC P OTHCMP POH UD Baker C-2 Liner pusher tool. 1900-hrs. UCA analysis of cement compressive strength indicates cement at > 1000-psi. 21 :00 - 00:00 3.00 TIEBAC P OTHCMP Clear and clean rig floor. Prepare for weekly BOPE test. 1/15/2007 00:00 - 01 :30 1.50 BOPSU N RREP TIEB1 Repair BOPE test pump. 01 :30 - 10:30 9.00 BOPSU P TIEB1 Weekly BOPE test. AOGCC - John Crisp waived witness test. 10:30 - 16:30 6.00 CASE P TIEB1 M/U 6-1/8" bit with Boot Baskets, String Mill, and oil jars and RIH on DCs and DP from Derrick. Std #45 @ 1545-hrs. 16:30 - 21 :30 5.00 CASE N RREP TIEB1 SID operations to change-out Drive Shaft from Engine #2 to Compound and thaw out cement standpipe. 21 :30 - 22:30 1.00 CASE TIEB1 Pressure test 9-5/8" Casing and 7" Liner to 4,000-psi and record on chart for 30-minutes. Rock-solid test. 22:30 - 23:00 0.50 CASE P TIEB1 Blow down cement standpipe and prepare to RIH with drilling BHA and DP from derrick. 23:30 - 00:00 0.50 DRILL P TIEB1 RIH with drilling BHA and DP from derrick to landing collar @ 10,048'. 1/16/2007 00:00 - 04:30 4.50 DRILL P TIEB1 RIH with drilling BHA and DP from derrick to landing collar @ 10,048'. 110-stds. RIH @ 0330-hrs. 150-stds. RIH @ 0430-hrs. 04:30 - 05:00 0.50 DRILL P TIEB1 PUMU headpin and break circulation. Pump 25-Bbls. @ 3.0-BPM @ 530-psi. 05:00 - 06:00 1.00 DRILL P TIEB1 RIH with drilling BHA and DP from derrick. Get "mushy" Tag @ 9988', 14' in on stand #155. POH and SIB stand #155. PIU Kelly and 10' drilling pup joint and RIH and tag at same spot. 06:00 - 09:45 3.75 DRILL P TIEB1 Establish parameters: Up Wt 159K, Dn Wt 115K. Break circulation, start rotary and torque rapidly climbed. Bit was off bottom 10', so decide to pump a 30-Bbl Flo-Vis-L sweep to Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/16/2007 06:00 - 09:45 3.75 DRILL P TIEB1 clean the hole. Try again after DP volume, - 66-Bbls pumped, but have same quick build up of torque. 09:45 - 10:15 0.50 DRILL P TIEB1 Try drilling again after pumping another 100-Bbls and able to bring RPM up to 50-RPM and hold torque in the string. Drilled the 10' pup jt and the last 12' of the 26' of usable Kelly in 15-minutes to 10,010'. 10:15-19:00 8.75 DRILL P TIEB1 Break Kelly at bottom of TIW valve, B/O and UD 10' pup, P/U M/U single DP joint and resume drilling. Drill down usable Kelly to 10,036'. Returns across shaker contain enough cement that the circulating rate has to be reduced to 3-BPM, 350-psi, 50-RPM, WOB -4-5K. Call for Super Sucker to empty cuttings tank. Reciprocate full Kelly while circulating. Break off Kelly and P/U and M/U the 10' pup jt and RIH to resume drilling to 10, 046'. Reciprocate and circulate. Continue to see cement across the Shaker. Break off 10' pup and PIU single joint of DP and drill ahead to hard spot (at 1400-hrs) which appears to be the Landing Collar. Continue to drill on hard spot and pump MI Steel Lube EP pill. Returns across shaker clean up after drilling on "hard spot" for 1-hour. 19:00 - 20:30 1.50 DRILL P TIEB1 Continue drilling on Landing Collar. Set 12-15k Ibs WOB. Torque at 6k ft-Ibs. Over a 15 minute interval the torque rose to 11k ft-Ibs. Pump 30-Bbl High Vis Sweep. Torque decreases from 11 k ft-Ibs. to 6k ft-Ibs. Break through Landing Collar. Make an additional 2' of hole in 15 minutes with 2k Ibs. WOB and 6k ft-Ibs. of torque. 20:30 - 00:00 3.50 DRILL P TIEB1 Resume drilling with 10k Ibs. WOB, 8-11 k ft-Ibs of torque at 4 BPM and 570 psi. Continue to drill down to 10,151' MD and see breakthrough. RIH to 10,157' MD without seeing any cement. Seeing a lot of fine cement in returns over Shakers. Screens are packing off. 1/17/2007 00:00 - 02:00 2.00 DRILL P TIEB1 Circulate 30 Bbl High Vis Sweep surface to surface @ 3 BPM and 570 psi. Huge amounts of cement particles coming across Shaker. Decrease pump rate in order to keep Screens clean. Circulate @ 2 BPM and 280 psi. High Vis Sweep at surface. See pebble sized rubber chunks, some aluminium, and cement particles. 03:00 - 03:30 0.50 DRILL P TIEB1 PJSM with Crew and VECO truck drivers. Line up trucks according to plan. Re-arrange items on location as a result of PJSM. 03:30 - 08:00 4.50 DRILL P TIEB1 Attempt to Reverse Circulate. Line from VECO Tanker frozen. C/O lines. Attempt to Reverse Circulate. Line somewhere on the Rig is frozen. Hunt for frozen line. 08:00 - 11 :00 3.00 DRILL P TIEB1 Break Circulation and reverse circulate 4-BPM @ 680-psi with bit at 10,157'. Did not proceed further to tag Fasdrill plug. 11 :00 - 17:30 6.50 DRILL P TIEB1 Clean out and replace fluid in Mud Pits to prepare for drilling Fasdrill plug @ 10,178'. Get 8-yards of sand, cement, and debris out of the pits. 17:30 - 20:30 3.00 DRILL P TIEB1 Establish reverse circulation and pump thinly viscosified (one 5-gal pail Flo-Vis-L with 30-Bbls seawater) surface-to-surface. Pump at 4 BPM and 580 psi. 20:30 - 22:00 1.50 DRILL P TIEB1 RIH and tag plug at 10,171' MD. Rotate at 60 RPM, pump at 4 BPM and 560 psi, and set 12k-lbs WOB. Drill through Fasdrill plug to 10,173' MD and plug drops. RIH to 10,189' MD and shut Printed: 1/30/2007 11 :44:06 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 12/8/2006 1/21/2007 Spud Date: 7/24/1988 End: 1/17/2007 20:30 - 22:00 1.50 DRILL P TIEB1 down pumps. Monitor well for 20 minutes. Well is static. R/U to RIH with stands from Derrick to push plug to 10,804' MD. 22:00 - 00:00 2.00 DRILL P TIEB1 RIH wI stands from the Derrick while chasing Fasdrill plug to 10,804' MD. Tag at 10,790' MD. Set 7k-lbs WOB and push plug to 10,804' MD. Tag solid at 10,804' MD. Losses at -5 Bbl/hr. 1/18/2007 00:00 - 01 :30 1.50 DRILL P TIEB1 POH to 10,020' MD while UD singles into the Pipe Shed. 25 jts OOH. 01 :30 - 02:30 1.00 DRILL P TIEB1 Reverse Circulate 100 Bbls of seawater at 2.5 BPM and 270 psi. Nothing seen coming across the Shaker. 02:30 - 14:00 11.50 DRILL P TIEB1 Continue POH with DP while UD singles into the Pipe Shed. 50 jts OOH at 0330-hrs. 75 jts OOH at 0445-hrs. 135-jts @ 0900-hrs. 180-jts @ 1100-hrs. 230-jts @ 1300-hrs. 250-jts @ 1335-hrs. 14:00 - 15:45 1.75 DRILL P TIEB1 P/U Kelly, make up to DP, and break connections below Kelly. Break off Kelly and set back into shuck. 15:45 - 19:30 3.75 DRILL P TIEB1 Continue POH and UD DP through Pipe Shed. 260-jts @ 1550-hrs. 19:30 - 21 :30 2.00 DRILL P TIEB1 UD Drill Collars. Break and UD BHA #10. 21 :30 - 00:00 2.50 RUNCO RUNCMP R/U to run completion with Stabbing Guide and Compensator. Nabors Casing Hands onsite to assist. 1/19/2007 00:00 - 02:00 2.00 RUNCMP R/U to run completion with Stabbing Guide and Compensator. Nabors Casing Hands onsite to assist. 225-jts in at 0030-hrs. 02:00 - 00:00 22.00 RUNCO RUNCMP RIH wI 4-1/2" TCII L-80 completion using Jet Lube Seal Guard thread compound. Making connections up to the optimum torque of 3,500 - 4,200 ft-Ibs. BakerLok all connections below the Packer. 10-jts in at 0400-hrs. 28-jts @ 0645-hrs. 59-jts @ 0900-hrs. 80-jts @ 1040-hrs. Hold Safety Moment on Rig Floor at 1045-hrs. Crew change at 11 OO-hrs. 100-jts @ 1150-hrs. 130-jts @ 1440-hrs. 145-jts @ 1545-hrs. 170-jts @ 1830-hrs. 183-jts @ 1930-hrs. 200-jts @ 2100-hrs. Crew change at 2100-hrs. Rearrange air hose to prevent it from tangling in the Elevators as the wind has picked up. 205-jts @ 2230-hrs. Bring man on stabbing board down in order to warm up @ 0000 hrs. 1/20/2007 00:00 - 02:30 RUNCMP RIH wI 4-1/2" TCII L-80 completion using Jet Lube Seal Guard thread compound. Making connections up to the optimum torque of 3,500 - 4,200 ft-Ibs. BakerLok all connections below the Packer. 02:30 - 04:00 1.50 RUNCO P RUNCMP PUMU landing joint and Tubing Hanger and lower Hanger to Rig Floor. PIU = 105 k-Ibs. SIO = 82 k-Ibs. Land Hanger and RILDS. 04:00 - 06:00 2.00 RUNCO RUNCMP Clear Rig Floor. R/U to Reverse Circulate. 06:00 - 11 :00 5.00 RUNCO RUNCMP Reverse Circulate 175-Bbls of 140-degree F seawater while taking returns to the Tiger Tank at 3-BPM and 340-psi. Reverse Circulate 450-Bbls of 140-degree F seawater with Corexit EC1124A corrosion inhibitor at 3-BPM and 340-psi while taking returns to the Tiger Tank. 11 :00 - 12:00 1.00 RUNCO RUNCMP Wait on Lil Red Hot Oilers. 12:00 - 13:30 1.50 RUNCO RUNCMP R/U Lil Red. PIT lines. Use steam whip to warm circulating manifold due to Roughneck heater being pulled out of service for repairs. 13:30 - 15:00 1.50 RUNCO RUNCMP PJSM for freeze protecting the annulus. Reverse circulate 120-Bbls of diesel, 3-BPM, 400-450-psi, 65-F. 15:00 - 16:30 1.50 RUNCO RUNCMP Realign valves to bullhead 35-Bbls of diesel freeze protect Printed: 1/30/2007 11 :44:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-29 W-29 WORKOVER NABORS ALASKA DRILLING I NABORS 38 Start: Rig Release: Rig Number: Spud Date: 7/24/1988 End: 12/8/2006 1/21/2007 fluids. Pump at 1.5-BPM, 910-psi. PJSM. Realign valves on tubing and annulus for UI Red to set and test packer and PIT tubing and annulus to 4,000-psi. RlU chart recorder. RUNCMP Pressure up to 4000 psi and set Packer. PIT Tubing to 4000 psi and chart. Lost 0 psi in 30 minutes. Bleed Tubing from 4000 psi to 1500 psi. PIT IA to 4000 psi and chart. Lost 50 psi in 30 minutes. Bleed IA from 4000 psi to 0 psi. Bleed Tubing from 1500 psi to 0 psi. RID LRS. Set TWC with dry rod from Rig Floor per Cameron recommendations. PfT TWC from above to 1000 psi with diesel. PJSM. Clear cellar. N/D BOPE. N/D BOPE. N/U Adapter Flange and Tree. PfT Hanger and Seal to 5000-psi. PfT Adapter Flange and Tree to 5000-psi and chart. RlU Lubricator with VECO Wells Support and pull TWC. Install BPV. Install Tree Cap and break off double annulus valve. Install tapped blind flanges with gages and Whitey valves. Secure well and Cellar and prepare to RID Rig Floor to release rig from W-29 RWO. The Rig will remain on location to allow the R & R of the Allison transmission on the number 2 Cat engine. POST Begin to remove overhead electrical wiring and piping from motor room directly above number 2 Cat engine. Remove Stabbing Board from Derrick and UD same through Pipe Shed. PIU Kelly, breakout and UD through Pipe Shed. Release rig at 1800-hrs. POST Pull roof cover above Transmission. Pull Transmission. Load new Transmission. Replace roof cover. POST Install new Transmission. 19:30 - 22:30 22:30 - 23:00 0.50 DHB P POST 23:00 - 00:00 1.00 BOPSU P POST 1/21/2007 00:00 - 04:30 4.50 BOPSU P POST 04:30 - 06:30 2.00 WHSUR P POST 06:30 - 08:30 2.00 WHSUR P POST 08:30 - 12:00 3.50 WHSUR P POST 12:00 - 13:00 1.00 WHSUR P POST 13:00 - 18:00 5.00 WHSUR P 18:00 - 00:00 6.00 WHSUR P 1/22/2007 00:00 - 06:00 6.00 REST P Printed: 1/30/2007 11 :44:06 AM i TREE: 4-1/16" MCEVOY WELLHfAD = MCEVOY ACTUA TOR: OTIS KB. ELEV : 92.40' BF. ELEV = 54.75 KOp: 3100' Max Angle = 46 @ 6200' Datum MD: 10577' Datum TVD = 8800' SS W-29 PJC DRAFT 113-3/8" CSG, 68#. L-80, ID: 12.415" H 2680' Minimum ID = 3.725" @ 10168' 4-1/2" HES XN NIPPLE 17" LNR, 26#, L-80. BTG-M .0383 bpf, ID: 6.276" H 10154' I 4-1/2" TBG. 12.6#, L-80, TC-II, --! 10181' I .0152 bpf, ID: 3.958" 19-5/8" CSG. 47#, L-80, ID: 8.681" I ÆRFORA TION SUMMARY REF LOG: SHCS ANGLEAT TOP ÆRF: 42 @ 10610' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" 12 5112 - 5117 S 01/02/07 4-1/2" 12 5167 - 5172 S 01/02/07 4-1/2" 12 5480 - 5482 S 01/02/07 2-1/4" 6 10610 - 10640 0 07/17/04 2-1/8" 4 10652 - 10672 0 10/14/88 2-1/8" 4 10672 - 10690 0 10/14/88 5" 4 10700 - 10714 0 08/15/88 5" 4 10725 - 10742 0 08/15/88 2-1/8" 4 10758 - 10773 0 10/14/88 PBTD 10908' 17" LNR, 26#, L-80, .0383 bpf, ID: 6.276" 10950' DATE 10/15/88 01/21/07 02/12/07 REV BY GVR N3ES ?/PJC COMMENTS ORIGINAL COM PLETION RWO DRLG DRAFT CORRECTIONS DATE REV BY COMMENTS 2198' 14.1/2" HES X NIP, ID: 3.813" I 2970' 9-5/8" X T' G-2 ZXP L TP wI FLEXLOCK LNR HGR, ID = 6.290" 14-1/2" HES X NIP, ID: 3.813" I --i 7" X 4-1/2" BKR ÆRMANENT A<R, ID: 3.870 14-1/2" HES X NIP, ID = 3.813" I 10168' 14-1/2" HES XN NIP, ID: 3.725" I 10181 ' 14-1/2" WLEG, ID: 4.00'" 10595' -i MARKER JOINT I 10804' --iT' FASDRILL DEBRIS (010/21/07 RWO) PRUDHOE BAY UNIT WELL: W-29 ÆRMIT No: "1880710 API No: 50-029-21834-00 SEC 21, T11 N, R12E, 839' FNL & 1444' FEL BP Exploration (Alaska) 02/12/2007 Schlumberger NO. 4131 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ():L~ 1~~-ó7f Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD L5-25 11538589 LDL 12/28/06 1 Y-16 11626467 LDL 01/19/07 1 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01/24/07 1 1-33 11631645 USIT 01/09/07 1 A-05A 11533393 USIT 01/04/07 1 DS 05-10B 11626469 SCMT 01/22/07 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 USIT (CEMENT EVALUATION) 01/11/07 1 R-15A 11626266 USIT (CORROSION) 01/11/07 1 MPF-99 11637306 CEMENT EVALUATION/CBL 01/14/07 1 R-12 11414757 RST 09/01/06 1 1 NK-38A 40011271 OH EDIT MWD/LWD 03/11/05 3 1 NK-38A PB1 40011271 OH EDIT MWD/LWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01/05/07 1 DS 07 -04A 11533394 LDL 01/05/07 1 F-23A 11626066 LDL 01/08/07 1 P2-19 11630449 LDL 01/14/07 1 Y-09A 11630450 LDL 01/16/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 5(;ANNED FEB 2 1 2007 900 E. Benson Blvd. Anchorage, Alaska 99508 eEIVE: Alaska Data & Cons 2525 Gambell Street, Anchorage, AK 99503-2838 ATTN: Beth FEB 2 0 20m Date Delivered: Received by: Oil &. {3¡:¡s Cons. Cnmmis~ion Anchorage ICJ . . Re: FW: W-29i RWO (Sundry # 306-304) e e Bryan and Dave, Thanks for the information. Setting the packer as you propose should not be a problem. Your reasoning is valid. Cementing the new scab in place should provide the necessary deep isolation. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED JAN 1 7 2007 McLellan, Bryan J wrote, On 1/17/2007 8:58 AM: Tom, I've attached the existing schematic and an updated, proposed well bore schematic for W-29i (Sundry #306-304). As mentioned in the note to Winton below, the scope of work changed to include a remedial 9-518" cement job and a 7" scab liner. The original Sundry application had a stacker packer configuration, with the new production packer being set at 9890' md. Now that the old packer has been milled and removed, we would like to set the packer in the new 7" scab liner at -10050' md, just above the drilled out float equipment. This is roughly the same depth as the old production packer had been set (-10,073' md). I wanted to get your approval for our proposed packer setting depth, which would be a variance to regulation 412(b). With your approval, the packer on this injection well will be set at -10,050' md, which is >200' above the existing perforations at 10,610' md. The reason for this request is that we do not want to set the new production packer in the old 7" liner. We plan to run the completion some time tomorrow, January 18th. «W-29.pdt» «W-29 Proposed scab liner.pdt» Please feel free to give me a call to discuss or if you need more information. Thank you, Bryan McLellan 564-5516 440-7964 (cel!) From: Reem, David C Sent: Thursday, December 21, 2006 8:53 AM To: 'Winton Aubert' Cc: McLellan, Bryan J Subject: W-29i RWO (Sundry # 306-304) and 12-14ALl RWO (Sundry # 306-281 and 306-289) Winton, as you requested, here is a synapsis of the reason for scope changes on the two subject 10f2 1/17/200710:33 AM Re: FW: W-29i RWO (Sundry # 306-304) e e wells: W-29i: This wellbore passes within -200' of a planned Schrader Bluff injector. As such we ran a bond log across the Schrader Bluff interval and the cement bond looked to be poor to absent across the Schrader. The asset folks for the Schrader development have requested that we repair the 9-5/8" casing primary cement job across the Schrader bluff boundaries in W-29. Thus we are planning on a circulation squeeze thru perfs shot in the 9-5/8" at 5112'-5114'md and 5480'-5482'md. After the cement job, a second bond log will be run to confirm adequate bonding across the Schrader. Following this activity, a 7" 26#/ft, L-80 scab liner will be fully cemented in place from -3000' md down to the top of the existing 7" production liner. 12-14AL 1: This wellbore was logged in the 9-5/8" with a USIT and a 40-arm caliper. These diagnostic tools indicated severe drill-pipe wear on the 10 of the 9-5/8" casing in several areas just above the existing 7" production liner. Therefore we have elected to install a fully cemented 7", 26#/ft, L-80 scab liner in this well with the top at -3000'md and the bottom tied into the existing 7" production liner. This operation will follow the planned 9-5/8" casing repair work as outlined in the original Sundry applications. Do not hesitate to call with any questions. Thanks. Dave Reem Wells/Workover Engineer 564-5743 (w) 632-2128 (c) 20f2 1/17/2007 10:33 AM MCEV OY OTIS 92.40' 54.75 3100' 46 @_~200' Datum MD = 10577' ,~..~~¥.~.,.._,~~~<- Datum TVD = 8800' SS ¡ 13-3/8" CSG, 68#, L-80, ID = 12.415" H 2680' Minimum 10 = 2.750" @ 2100' 3·1/2" OTIS SSSV NIPPLE I TOP OF 7" LNR 13-1/2" T8G, 9.2#, L-80, .0087 bpf, ID = 2.992" 19-5/8" CSG, 47#, L-80, ID = 8.681" 10154' 10182' 10386' ÆRFORA TION SUMMARY REF LOG: SHCS ANGLE AT TOP ÆRF: 42 @ 10610' Note: Refer to Production D8 for hìstorical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/4" 6 10610 - 10640 C 07/17/04 2-118" 4 10652 - 10672 C 10/14/88 2-118" 4 10672 - 10690 C 10/14/88 5" 4 10700 - 10714 C 08/15/88 5" 4 10725 - 10742 C 08/15/88 2-1/8" 4 10758 - 10773 C 10/14/88 1 PBTD I I 7" LNR, 26#, L-80, .0383 bpf. 10'" 6.276" DA TE REV 8Y COMMENTS 10115/88 GVR ORIGINAL COMPLETION 08/28/03 JLJ/KK GL V ClO 106 JMlKK X NIP CORRECTION 07/17/04 LDK/KA FS 09/24/05 KDC/PJC SET HES 8B RBP (7/14/05) 02/10/06 KS8/PAG LOST FISH & DROP SB PLUG 10908' 10950' DATE 04/03/06 04/03/06 10/20/06 10/20106 W-29 2100' 3-1/2" OTIS SSSV LAND NIP, ID - 2.75" . GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH SIZE DATE 7 2989 2897 5 DMY RA 0 08/21/03 6 6026 5375 45 0 DMY RA 0 08/21/03 5 7636 6565 37 OTIS DMY RA 0 4 8237 7034 41 OTIS DMY RA 0 08/21/03 3 8838 7497 38 OTIS DMY RA 0 2 9408 7938 41 OTIS DMY RA 0 1 9913 8313 43 OTIS DMY RM 0 08/28/03 9980-9982' -1TBG PUNCH, 4 SPF (10/19/06) , 3-1/2" OTIS SLIDING SLEEVE, 10'" 2.750" J 2-3/8" CHEM CUT (10120/06) I J3-1/2" HES FASDRILL (10/19/06) I J3-1/2" TBG SEAL ASSY I 10073' -j 9-5/8" X 3-1/2" OTIS HCM PKR, 10 - 3.850" -j 3-1/2" OTIS X NIP, 10 - 2.750" I -13-1/2" WFD CIBP SET (10118/06) --i 3-1/2" OTIS X NIP, 10 = 2.750" I -13-1/2" TIWTBG TAIL H ELMD TT LOGGED 07/16190 10595' -j MA RKER JOINT , 110762' SLMI FISH- 2 B8 PLUG ELEMENTS & POSSIBLE BRAIDED LINE FROM PREVIOUS FISH (1990) 10908' -j3-1I2" xx PLUG ON BOTTOM 24" LONG I REV BY COMMENTS JCrvVPAG PULL FISH 88 PLUG (04/08/06) JRP/PJC FISH @ 10762 (ISP ELEMENTS) RRD/PAG SETCI8P@ 10134' (10/18/06) RRD/PAG FASDRILL, CHEM CUT, PUNCH PRUDHOE BAY UNIT WELL: W-29 ÆRMIT No: '1880710 API No: 50-029-21834-00 SEC 21. T11 N, R12E, 839' FNL & 1444' FEl. BP Exploration (Alaska) TREE = 4-1/16" MCEVOY WELLHEAD = MCEVOY ACTUA TOR = OTIS KB. ELEV := 92.40' BF. ELEV = 54.75 KOP= 3100' Max Angle = 46 @ 6200' Datum MD = 10577' Datum TVD = 8800' SS W-29 PROPOSED 2200' 4-1/2" HES'X' NIP, 10 = 3.813" 113-3/8" CSG, 68#, L-80, ID = 12.415" I 3000' 17" Baker ZXP Liner-Top A<r Minimum 10 = 3.725" @ 10160' 4-1/2" HES XN NIPPLE 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" , I TOP OF 7" LNR I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"H 1 0200' 10030' H4-1/2" HES 'X' NIP, ID - 3.813" 10050' 4-1/2" X 9-5/8" BAKER S3 A<R 10080' H4-1/2" HES 'X' NIP, ID- 3.813" 10140' 4-1/2" HES 'Xn' NIP, ID = 3.725" J4-1/2" WLEG 19-518" CSG, 47#, L-80, ID = 8.681" I 10386' ÆRFORA TION SUMMARY REF LOG: BHCS ANGLEATTOPÆRF: 42 @ 10610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/4" 6 10610 - 10640 0 07/17/04 2-1/8" 4 10652 - 10672 0 10/14/88 2-1/8" 4 10672 - 10690 0 10/14/88 5" 4 10700 - 10714 0 08/15/88 5" 4 10725 - 10742 0 08/15/88 2-1/8" 4 10758 - 10773 0 10/14/88 10595' -i MARKER JOINT , I PBTD I 10950' 10908' 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" DATE 10/15/88 08/21/03 08/28/03 09/06/03 07/17/04 09/24/05 REV BY COMMENTS GVR ORIGINAL COMPLETION RWLlKK GL V C/O JLJ/KK GL V C/O JIINKK X NIP CORRECTION LDKlKAK ADÆRFS KDClPJC SET HES BB RBP(7/14/05) DATE 02/10/06 04/03/06 04/03/06 08/31/06 REV BY COMMENTS KSB/PAG LOST FISH & DROP BB A...UG JCIINPAG PULL FISH BB A...UG (04/08/06) JRP/PJC FISH @ 10762 (IBP ELEMENTS) BJM PROPOSED RWO COMA...ETION PRUDHOE BA Y UNIT WELL: W-29 ÆRMIT No: "1880710 API No: 50-029-21834-00 SEC 21, T11 N, R12E, 839' FNL & 1444' FEL BP Exploration (Alaska) 01105/2007 Schlumberger SCANNED JAN 1 0 2007 NO. 4101 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth UTC--t~ .::.07 ( Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Welf Job# Log Description Date BL Color CD 17-20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PROFILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 USIT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 USIT 11/27/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Date Delivered: Received by: . . W-29i RWO (Sundry # 306-304) and 12-14.WO (Sundry... ¡.e ~ . (} -r I . Subject: W-29i RWO (Sundry # 306-304) and 12-14AL 1 RWO (Sundry # 306-281 and 306-289) From: "Reem, David C" <ReemDC@BP.eom> Date: Thu, 21 Dee 2006 08:52:40 -0900 To: ,Winton Aubert<winton...J;iubert@admin..state.ak.u.s> Cc: "McLéllan, BryanJ" <Bryal1.McLellan@BP.com> Winton, as you requested, here is a synapsis of the reason for scope changes on the two subject wells: W-29i: This well bore passes within -200' of a planned Schrader Bluff injector. As such we ran a bond log across the Schrader Bluff interval and the cement bond looked to be poor to absent across the Schrader. The asset folks for the Schrader development have requested that we repair the 9-5/8" casing primary cement job across the Schrader bluff boundaries in W-29. Thus we are planning on a circulation squeeze thru perfs shot in the 9..5/8" at 5112'-5114'md and 5480'-5482'md. After the cement job, a second bond log will be run to confirm adequate bonding across the Schrader. Following this activity, a 7" 26#/ft, L-80 scab liner will be fully cemented in place from -3000' md down to the top of the existing 7" production liner. 12-14AL 1: This wellbore was logged in the 9-5/8" with a USIT and a 40-arm caliper. These diagnostic tools indicated severe drill-pipe wear on the ID of the 9-5/8" casing in several areas just above the existing 7" production liner. Therefore we have elected to install a fully cemented 7", 26#/ft, L-80 scab liner in this well with the top at -30QQ'md and the bottom tied into the existing 7" production liner. This operation will follow the planned 9-5/8" casing repair work as outlined in the original Sundry applications. Do not hesitate to call with any questions. Thanks. Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) ;·''''''iJ.í't.U.,,~'I.:::. "ìI""i.. DE- C ç" c; 'Jo O'IR .)vd'\Z1jij=\jr...J' )', Z 1. L I -ü 1 of 1 12/21/20068:55 AM . , -""""-"1 . '¡ --,IE""'" ! j FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AlO) GAS CONSERVATION COMMISSION 333 W. 7'H 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 PJ.a. ,01 \ """\'-0 ]J Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU W-29 Sundry Number: 306-304 $CANNEl); SEP 1 3 2005 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. K. Chai DATED this <{ day of September, 2006 Encl. \, lQ ~fc 117/e>t; I REt'Ë1V~fjZ'Oo(P ~ \~\Ü . STATE OF ALASKA 073~/g/,b ~\ ALA~ OIL AND GAS CONSERVATION COM_ION S E P 0 6 2006 APPLICATION FOR SUNDRY APPROVAL AI k 0'1 & G C' . 20 MC 25.280 as a I as Cons. ommlsslon 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extensi~ncnorage o Alter Casing ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program ~ Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To ,9Till Number BP Exploration (Alaska) Inc. o Development o Exploratory 188-071 3. Address: o Stratigraphic 181 Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21834-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU W-29 /' Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028263 92' Prudhoe Bay Field / Prudhoe Bay Pool 12[TT< .. .. .....T ·.·.;·i-i<-·· ·.....·-.<.<....i<.1i;;1·).; ··xiXi <6.·..·..... .... ...; .1 ··/<1-/' · -iT.··· >X -i.-TiTXX ·X)i;-iiii;i·);x; _...._/ Total Depth MD (ft): Total Depth TVD (ft):IEffective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10950 9166 10908 / 9135 None 10762 & 10908 Casino Lennth Size MD / TVD Burst CollaDse Structural Conductor 110' 20" 110' 110' Surface 2681' 13-3/8" 2681' 2681' 4930 2270 Intermediate 10386' 9-5/8" 1 0386' 8752' 6870 4760 Production Liner 796' 7" 10154'-10950' 8583' - 9166' 7240 5410 Perforation Depth MD (ft): 1 Perforation Depth TVD (ft): 14- '/2 " Tubing Size: W6l\- Tubing Grade: Tubing MD (ft/ 10610' - 10773' / 8916' - 9036' -' z. )( 3-1/2",9.2# L-80 10182' Packers and SSSVType: 9-5/8" x 3-1/2" Otis 'HCM' packer / I Packers and SSSV MD (ft): 10073' / 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program /\ 15. Estimated Date for septembi 15.1006 16. Well Status after proposed work: Commencing Operations: o Oil o Gas o Plugged o Abandoned 17. Verbal Approval: DateV 181 WAG OGINJ OWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem. 564-5743 Printed Na'12ld Reem Title Drilling Engineer Bryan McLellan. 564-5516 Prepared By Name/Number: Signature (~ Phone 564-5743 Date 'ì - ~ - Ob Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: ?f1.J) - ~ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance Other;\'~Ç \ ßO{)f- to 4--000 f~· MLt VD~~d. Subsequent Form Required: yc.9 ~ 4-0 4¡-. -Lr¡ ~/øþ APPROVED BY Approved Bv: THE COMMISSION Date Form 10-403 Revised 06/2006 \...,./ V "-e>¡/y(of ~ÞIl1) u~it In Duplicate I ORIGINAL ð~, . . I f ~ 0 11 ~ ~~ G W-29 Rig Workover (Revision 1) This revision was written to include removal of the existing production packer and cleaning out fill to below the bottom perforation. Scope of Work: Pull 3-%" L-80 completion, replace 9-5/8" casing packoffs, run 4-W Premium-threaded L- 80 completion for gas and water injection service. MASP: 2570 Well Type: WAG Injector Estimated Start Date: September 15th, 2006 'It' ¡" ~~f·\ít..:lr) tl-vMt"d I;l\!...t\,j ')¡ n ~)f:f!f-: cJ \) t..~'v~ Pre-ria prep work: 0 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. S 2 Tag TD w/ TEL for corrected TD tag. If TD is above bottom perf at 10773' md, make an attempt to recover the remainder of the braided line fish. Drift tubing for 3-1/2" CIBP and Chem cutter. Done. F 3 MITIA to 4000 psi. Establish OA injectivity and attempt to load the OA with 9.8 ppg brine to the surface casing shoe. Top off with 5 bbls of diesel. Done. E 4 Set CIBP in the 3-1/2" tubing tail at 10,133' md (in the middle of the full jt between X-Nipples). MIT-T to 1000 psi to prove CIBP is a barrier. Chem-cut the tubing at 10,037' md (in the middle of the first full joint above the packer). Depths referenced to tubing tally dated 8/14/88. NOTE: The riq will mill and remove the packer and tubinq tail. F 5 Circulate well with seawater and diesel thru the cut. 0 6 Set a BPV in the tubing hanger. 0 7 Remove the wellhouse & flow line. Level the pad as needed for the riq. Proposed Procedure: 1. MIRU. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. ND tree. NU and test BOPE to 4000 psi. 2. Pull and LD 3-1/2" tubing string to the jet cut. 3. Change out 9-5/8" casing packoffs. 4. Mill and remove 9-5/8" x 3-1/2" production packer. / 5. Clean out fill to below bottom perforation. 6. Run new 4-1/2" premium threaded L-80 tubing completion with packer at -9,890' md. 7. Displace the IA to packer fluid and freeze protection. Set the packer. 8. Test tubing and IA to 4000 psi. Freeze protect tubing to 2200' MD. / 9. Set TWC. ND BOPE. NU and test tree. Set BPV. RDMO. TREE = 4-1/16" MCEVOY WELLHEAD = MCEVOY ACTUA TOR = OTIS KB. ELEV = 92.40' BF. ELEV = 54.75 KOP = 3100' Max Angle = 46 @ 6200' Datum MD = 10577' Datum TVD = 8800' SS 113-3/8" CSG, 68#, L-80, ID = 12.415" H 2680' Minimum ID = 3.725" @ 10160' 4-1/2" HES XN NIPPLE W-29 PROPOSED 2200' 14-1/2" HES 'X' NIP, ID = 3.813" 10030' 1-14-1/2" HES 'X' NIP, ID = 3.813" I 10050' H4-1/2" X 9-5/8" BAKER S3 PKR 1 10080' H4-1/2" HES 'X' NIP, ID = 3.813" , I TOP OF 7" LNR I 10180' 14-1/2" HES 'Xn' NIP, ID = 3.725" 1 10154' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958"1 10200' 19-5/8" CSG, 47#, L-80, ID = 8.681" I 10386' 10595' -i MARKER JOINT 1 PERFORA TION SUMMARY REF LOG: BHCS ANGLEAT TOP PERF: 42@ 10610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/4" 6 10610 -10640 0 07/17/04 2-1/8" 4 10652 - 10672 0 10/14/88 2-1/8" 4 1 0672 - 1 0690 0 10/14/88 5" 4 10700 - 10714 0 08/15/88 5" 4 10725 - 10742 0 08/15/88 2-1/8" 4 1 0758 - 1 0773 0 10/14/88 1 PBTD 1 1 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" DATE 10/15/88 08/21/03 08/28/03 09/06/03 07/17/04 09/24/05 REV BY COMMENTS GVR ORIGINAL COM PLETION RWLlKK GL V C/O JLJ/KK GLV C/O JMlKK X NIP CORRECTION LDKlKAK ADPERFS KDC/PJC SET HES BB RBP(7/14/05) 10908' 10950' DATE 02/10/06 04/03/06 04/03/06 08/31/06 REV BY COMMENTS KSB/PAG LOST FISH & DROP BB PLUG JCMlPAG PULL FISH BB PLUG (04/08/06) JRP/PJC FISH @ 10762 (IBP ELEMENTS) BJM PROPOSED RWO COMPLETION PRUDHOE BA Y UNrT WELL: W-29 PERMrT No: 'í 88071 0 API No: 50-029-21834-00 SEC21, T11N, R12E, 839' FNL & 1444' FEL BP Exploration (Alaska) . . W-29 Rig Workover Scope of Work: Pull 3-%" L-80 completion, run 4-%" Premium-threaded L-80 completion for gas and water injection service. MASP: 2570 / Well Type: WAG Injector Estimated Start Date: September 15th, 2006 Pre-riQ prep work: 0 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC, S 2 Tag TD wI TEL for corrected TD tag. If TD is above bottom perf at 10773' md, make an attempt to recover the remainder of the braided line fish. Drift tubing for 3-1/2" CIBP. and Power Jet cutter./ F 3 MITIA to 4000 psi. / E 4 Set CIBP in the 3-1/2" tubing at 10,018' md (3' up from the bottom of the pup joint directly below the sliding sleeve). MIT-T to 1000 psi to prove CIBP is a barrier. Power Jet-cut the tubing at 10,014' md (3' below the sliding sleeve). Depths referenced to tubing tally dated 8/14/88. NOTE: The rig will make an outside cut on the tubing to recover the CIBP. F 5 Circulate well with seawater and diesel thru the cut. 0 6 Set a BPV in the tubing hanger. / 0 7 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1, MIRU. Circulate out freeze otection fluid and circulate well to clean seawater through the cut. ND tree. NU and test BOPE to 000 si. 2. Pull and LD 3-1/2" tubing stri to the jet cut. 3. Change out 9-5/8" casing packoffs. 4, RIH with an outside cutter and cut tubing below the CIBP. POOH with cutter and section of 3-1/2" /' tubing with CIBP inside. & 5. Run new 4-1/2" premiu hreaded L-80 tubing completion with packer at -.. ,..89 'md. 6. Displace the IA to pac er fl 'd and freeze protection. Set the packer. 7. Test tubing and IA to 00 si. Freeze protect tubing to 2200' MD, ,. 8. Set TWC. ND BOPE. and test tree. Set BPV. RDMO. TREE = 4-1/16" MCEVOY W8.LHEAO == MCEVOY ACTUATOR = OTIS KB. ELEV = 92.40' BF. ELEV = 54.75 KOP= 3100' Max Angle = 46 @ 6200' Datum MO = 10577' Datum lVO = 8800' SS . 113-3/8" CSG. 68#, L-80, 10 = 12.415" H 2680' Minimum ID = 2.750" @ 2100' 3-1/2" OTIS SSSV NIPPLE 14-1/2" TBG. 12.6#, L-80. .0152 bpf, 10 = 3.958"1-1 10020' I I TOP OF 7" LNR 13-1/2" TBG. 9.2#. L-80. .0087 bpf. 10 = 2.992" 19-5/8" CSG. 47#. L-80. 10 = 8.681" I 10154' 10182' 10386' ÆRFORA TION SUMMARY REF LOG: BHCS ANGLEATTOPÆRF: 42@ 10610' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OA TE 2-1/4" 6 10610 - 10640 0 07/17/04 2-1/8" 4 10652 - 10672 0 10/14/88 2-118" 4 10672 - 10690 0 10/14/88 5" 4 10700 - 10714 0 08/15/88 5" 4 10725 - 10742 0 08/15/88 2-1/8" 4 10758 - 10773 0 10/14/88 1 PBTD I 17" LNR. 26#. L-80, .0383 bpf. 10 = 6.276" I OATE 10/15188 08/21/03 08/28/03 09/06/03 07/17/04 09/24/05 REV BY COMMENTS GVR ORIGINAL COMPLETION RWLlKK GL V C/O JLJ/KK GL V C/O JMlKK X NIP CORRECTION LOKlKAK AOÆRFS KDClPJC SET HES BB RBP (7/14/05) 10908' 10950' OATE 02/10/06 04/03/06 04/03/06 08/31/06 W-29 PROPOSED / ~OTES: 2200' 4-1/2" HES 'X' NIP. 10 = 3.813" 9880' H4-1/2" HES 'X' NIP, 10 = 3.813" 9890' 4-1/2" X 9-5/8" BAKER S3 A<R 4-1/2" HES 'XN' NIP. 10 = 3.725" 4-1/2" X 3-1/2" XO UNIQUE MACHINE OVERSHOT ~3-1/2" TBG SEAL ASSY I 10073' -19-5/8" X 3-1/2" OTIS HCM A<R. 10 = 3.850" 10116' -13,1/2" OTIS X NIP. 10 = 2.750" I -13-1/2" OTIS X NIP. 10 = 2.750" I -13-1/2" TIW TBG TAIL I 1-1 ELMO TI LOGGED 07116/90 10595' -1 MARKER JOINT I 10762' SLM FISH- 2 BB PLUG ELEMENTS & POSSIBLE BRAIOED LINE FROM PREVIOUS FISH (1990) 10908' -13-1/2" XX PLUG ON BOTIOM 24" LONG I REV BY COMMENTS KSB/PAG LOST FISH & OROP BB PLUG JCMlPAG PULL FISH BB PLUG (04/08/06) JRP/PJC FISH @ 10762 (IBP ELEMENTS) BJM PROPOSED RWO COMPLETION PRUOHOE BA Y UNIT WELL: W-29 ÆRMIT No: "1880710 API No: 50-029-21834-00 SEC21. T11N. R12E. 839' FNL & 1444' FEL BP Exploration (Alaska) TREE = 4-1/16" MCEVOY WELLHEAD ~ MCEVOY ACTUA TOR = OTIS KB. ELEV = 92.40' BF. ELEV = 54.75 KOP= 3100' Max Angle = 46 @ 6200' Datum MD = 10577' Datum lVD = 8800' SS 113-3/8" CSG. 68#. L-80. ID = 12.415" H Minimum ID = 2.750" @ 2100' 3-1/2" OTIS SSSV NIPPLE I TOP OF 7" LNR 13.1/2" TBG. 9.2#. L-80. .0087 bpf, ID = 2.992" 19-5/8" CSG, 47#. L-80. ID = 8.681" I . 2680' 10154' 10182' 10386' ÆRFORA TION SUMMARY REF LOG: BHCS ANGLE AT TOP ÆRF: 42 @ 10610' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/4" 6 10610 - 10640 0 07/17/04 2-1/8" 4 10652 - 10672 0 10/14/88 2-1/8" 4 10672 - 10690 0 10/14/88 5" 4 10700 - 10714 0 08/15/88 5" 4 10725 - 10742 0 08/15/88 2-1/8" 4 10758·10773 0 10/14/88 I PBTD I 17" LNR, 26#. L-80. .0383 bpf, ID = 6.276" DATE 10/15188 08/21/03 08/28/03 09/06/03 07/17/04 09/24/05 REV BY COMMENTS GVR ORIGINAL COMPLETION RWLlKK GL V ClO JLJ/KK GL V ClO JrwKK X NIP CORRECTION LDKlKAK ADÆRFS KDClPJC SET HES BB RBP (7/14/05) 10908' 10950' DATE 02/10/06 04/03/06 04/03/06 W-29 / ~OTES: EXISTING 2100' 3-1/2" OTIS SSSV LAND NIP, ID = 2.75" . GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LATCH SIZE DATE 7 2989 2897 5 OTIS DMY RA 0 08/21/03 6 6026 5375 45 OTIS DMY RA 0 08/21/03 5 7636 6565 37 OTIS DMY RA 0 4 8237 7034 41 OTIS DMY RA 0 08/21/03 3 8838 7497 38 OTIS DMY RA 0 2 9408 7938 41 OTIS DMY RA 0 1 9913 8313 43 OTIS DMY RM 0 08/28/03 I I 10007' 3-1/2" OTIS SLIDING SLEEVE, ID = 2.750" 10057' J3-1/2" TBG SEAL ASSY I 10073' -19-5/8" X 3-1/2" OTIS HCM PKR. ID = 3.850" 10116' "3-1/2" OTIS X NIP. ID = 2.750" I ., 3-1/2" OTIS X NIP. ID = 2.750" I ., 3-1/2" TIVV TBG TAIL I H ELMO TT LOGGED 07/16/90 10595' .,MARKERJOINT I 10762' SLM FISH- 2 BB A..UG EL8v1ENTS & POSSIBLE BRAIDED LINE FROM PREVIOUS FISH (1990) 10908' "3-1/2" XX A..UG ON BOTTOM 24" LONG I REV BY COMMENTS KSB/PAG LOST FISH & DROP BB A..UG JCfvVPAG PULL FISH BB A..UG (04/08/06) JRP/PJC FISH @ 10762 (IBP EL8v1ENTS) PRUDHOE BA Y UNIT WELL: W-29 ÆRMIT No: "1880710 API No: 50-029-21834-00 SEC21. T11N. R12E. 839' FNL & 1444' FEL BP Exploration (Alaska) . STATE OF ALASKA . AlÞ1 Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 3. Address: P.O. Box 196612 Anchorage, Alaska 99519- 6612 7. KB Elevation (ft): 92 Plug Perforations Perforate New Pool 0 Perforate 0 4. Well Class Before Work: Development 0 Stratigraphic 0 1. Operations Abandon Repair Well Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Other..t Pull Plug Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number~;_ 188-071 ;), 6. API Number: 50-029-21834-00-00; 9. Well Name and Number: W-29 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool Exploratory 0 Service [] 8. Property Designation: ADL-028263 11. Present Well Condition Summary: Total Depth measured 10950 true vertical 9166.21 feet feet Plugs (measured) Junk (measured) 10762,10908 Effective Depth measured 10908 true vertical 9135.41 feet feet Casing Conductor Surface Production Liner Length 80 2651 10358 796 Size 20" Conductor 13-3/8" 68# L-80 9-5/8" 47# L-80 7" 26# L-80 MD 30 - 110 29 - 2680 28-10386 10154 - 10950 TVD Burst Collapse 30 - 110 29 - 2679.93 5020 2270 28 - 8751.81 6870 4760 8583.10 - 9166.21 7240 5410 Perforation depth: Measured depth: 10610 - 10773 True Vertical depth: 8916.19 - 9036.39 Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 10182 Packers and SSSV (type and measured depth) 3-1/2" Otis HCM Packer 10073 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBOMS 8Ft MAY 3 0 2006 Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN SHUT-IN Tubing Pressure 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 15. Well Class after work: Exploratory 0 16. Well Status after work: OilO Gas 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Development 0 Service [] x WAG 0 GINJ 0 WINJ [] WDSPL Sundry Number or N/A if C.O. Exempt: N/A o Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatur~~ Title Data Mgmt Engr Phone 564-4424 Date 5/24/2006 Form 10-404 Revised 04/2006 OR\Gtf~AL Submit Original Only . . W-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SVI'iIIM~RY 3/21/2006 HES BB BP MONTHLY RENTAL FOR 03/12/06 - 04/12/06, MO 9. NOTE BP SET 07/14/0S NOTE: BB PLUG PUSHED TO BTM ON 02/10/06. WE RETRIEVE AT A LATER DATE 4/2/2006 ***WELL S/I ON ARRIVAL ***(post emit) GREASE CREW SERVICED MASTER, SSV & SWAB VALVES. PULLED 3.S HES BB PLUG @ 10,741' SLM. MISSING THE RUBBER ELEMENT. DRIFT TUBING W/3.S BLB AND 2.2S" 3 PRONG WIRE GRAB TO 10,748' SLM. RETRIEVED 1/2 PIECE OF RUBBER AND 2S' OF BRAIDED LINE. BRAIDED LINE WAS ACROSS TREE, CUT WIRE W/ MASTER VALVE. RAN 2.8S" G-RING THRU TREE - CLEAR THRU TREE. ***WILL RETURN WHEN BRAIDED LINE RAMS AVAILABLE TO FISH*** ***WELL LEFT S/I*** NOTE: 2 - BB PLUG ELEMENTS STILL IN HOLE & POSSIBLY UP TO SO' BRAIDED LINE. FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 FW: W-29 (PTD# 1880710) Slow IA pressurien on MI e Ç) \ IIÙ/C<P ~-/11q Subject: FW: W-29 (PTD# 1880710) Slow IA Pressurization on MI From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Mon, 09 Jan 2006 20:59:02 -0900 To: jim _ regg@admin.state.ak.us, winton _ aubert@admin.state.ak.us, bob _ fleckenstein@admin.state.ak.us CC: "Engel, Harry R" <Harry.Engel@BP.com>, "Robertson, Daniel B (Alaska)" <Danie1.B.Robertson@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@BP.com>, "GPB, GC2 Wellpad Lead" <GPBGC2WellpadLead@BP.com>, GPBWellPadsWZL V@BP.com, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "Anders, Joe L" <anders22@BP.com>, "Austin, Paul A" <Paul.A.Austin@BP.com>, "Dube, Anna T" <Anna.Dube@BP.com>, "Frazier, Nicholas B" <Nicholas.Frazier@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "Johnson, Roland D (VECO)" <JohnsRD2@BP.com>, "Luckett, Ely Z. (VECO)" <luckez@BP.com>, "MCCOLLUM, CODY 0 (VECO)" <Cody.McCollum@BP.com>, "Morse, Kenny (VECO)" <MorseK1@BP.com>, "Parks, Kevin D (VECO)" <ParksKD@BP.com>, "Pinkston, Bruce M (Veco)" <PinkstBM@BP.com>, "Winslow, Jack L." <Lyonsw@BP.com> lof3 1/10/2006 9:36 AM FW: W-29 (PTD# 1880710) Slow IA pressurem on MI e Hi Jim, Winton and Bob. This is an update on the status and plans for injection well W-29. Slow IA repressurization was observed 06/05 while the well was on MI injection. The well was SI and a series of pressure tests conducted. Final test results are the MIT- T fails (possible leaking tubing plug) and MITIA's to 3000 psi pass. The passing MITIA demonstrates competent tubing and production casing. Recent events: > 06/04/05: lAP BUR post bleed indicates slow TxlA comm to MI > 06/06/05: Swapped to PWI > 06/07/05: Notified AOGCC of slow TxlA comm while injecting MI > 06/10105: MITIA to 3000 psi Passed > 06/11/05: Notified state of passing MIT & plans to keep on PWI to monitor IA re-pressure > 07/14105: SetWRP @ 10132' > 07/28/05: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3500 psi, IC LOS cycled OK > 01/05/06: MITT FAILED, LLR > 0.2 bpm at 2450 psi; CMIT FAILED, never reached test pressure > 01/07/05: CMIT-TxIA FAILED to 2500 psi; MITIA Passed to 2500 psi Current plans are to return the well to produced water injection and monitor for indications of TxlA comm. If there are no indications of TxlA comm, we will attempt MI injection. Attached is a TIO plot and MIT form for the 1n/05 MITIA. The well is on the monthly UIC report. «W-29 TIO Plot.jpg» «MIT PBU W-29 01-07-06.xls» Please call if you have any questions or prefer some other action plan. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom From: NSU, ADW Well Integrity Engineer Sent: Saturday, June 11, 2005 10:56 AM To: 'jim_regg@admin.state.ak.us'; 'winton_aubert@admin.state.ak.us'; bob_fleckenstein@admin.state.ak.us Cc: NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); NSU, ADW Well Integrity Engineer Subject: RE: W-29 (PTD# 1880710) Slow IA Pressurization on MI Hi Jim & Winton, W-29 passed an MITIA to 3000 psi yesterday while on PWI, please find the MIT form attached: With a passing MITIA our current plan is to leave the well on PWI and continue to closely monitor for TxlA comm. The well has been added to the monthly AOGCC Injection report. Please call if you have any questions. Thanks, 20f3 1/10/20069:36 AM FW: W-29 (PTD# 1880710) Slow IA press.on on MI e Donald Reeves - Filling in for Anna Dube Well Integrity Engineer (907) 659-5102 (907) 659-5100,1154 pgr From: NSU, ADW Well Integrity Engineer Sent: Tuesday, June 07,20051:13 PM To: jim_regg@admin.state.ak.us; winton_aubert@admin.state.ak.us Cc: Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; GPB, GC2 Area Mgr; GPB, GC2 Ops Lead; Holt, Ryan P (VECO); Robertson, Daniel B (Alaska) Subject: W-29 (PTD# 1880710) Slow IA Pressurization on MI Hello Jim and Winton. Well W-29 (PTD# 1880710) is exhibiting indications of slow TxlA communication while on MI. TIO's on 6/4/05 were 325011300/260. We bled the IA to 850 psi and it re-pressured to 1300 psi in 6 days. The well has been swapped to PWI and the current plan is to conduct an MITIA. Attached is a wellbore schematic. Please call if you have any questions. « File: W-29.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer (907) 659-5102 (907) 659-5100, 1154 pgr Content-Description: W-29 no Plot.jpg W-29 TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: MIT PBU W-29 01-07-06.xls MIT PBU W-29 Ol-07-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 30f3 1/10/20069:36 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / W Pad 01/07/06 Cody Applehans 'Kft HO", Packer Depth Pretest Initial 15 Min. 30 Min. We1l1W-29 I Type Inj. I N TVD I 8,524' Tubing 1,025 1,025 1,020 920 Intervall 0 P.T.D.11880710 I Type test I P Test psil 2500 Casing 2,460 2,500 2,500 2,500 P/FI P Notes: Eval for possible TxlA comm, not witnessed OA 100 100 100 100 Weill I Type Inj. I I TVD I Tubing Intervall P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D. I Type test I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 -~ .(-¡U,bt"'j f~S5~ 'vl-e¿i,l.Jf Cð¿d â I~ kb.¡~ ~ . -- (J Q ¡ 0 CWRf) @ ID/l~ZI) TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlvey A = Temperature Anomaly SUlvey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V::; Required by Variance T::; Test during Workover o = Other (describe in notes) MIT PBU W-29 01-07-06-1.xls no 926x290 lofl +Tbg 1,11. 0,11. OO.iI. OOO,iI. 1/10/20069:35 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I W Pad 06/10105 Donald Reeves l fð9J- °7J Packer Depth Pretest Initial 15 Min. 30 Min. Well W-29 Type Inj. S TVD 8,524' Tubing 1,825 1,825 1,825 1,825 Interval 0 P.T.D. 1880710 Type test P Test psi 3,000 Casing 1,650 3,000 2,920 2,920 P/F P Notes: MITIA to 3000 psi to eval for TxlA communication Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.I.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.I.D. Type test Test psi Casing P/F Notes: Test Details: SCANNED JUl 0 7 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 2005-061 O_MIT _PBU_W-29.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission FROM: Lou Grimaldi Petroleum Inspector DATE: Wednesday, October 06, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-29 PRUDHOE BAY UNIT W-29 TO: JimRegg rV IO/'/(/'\A-- P.I. supervisorKq1 I \ V1 Src: Inspector Reviewed By: ,,-sf]I:Z-- P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT W-29 API Well Number: 50-029-21834-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLGO41005103827 Permit Number: 188-071-0 Inspection Date: 10/5/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-29 Type Inj. S TVD 8524 IA 520 2700 2650 2640 P.T. 1880710 TypeTest SPT Test psi 2131 OA 800 1000 1000 1000 Interval 4YRTST PIF P Tubing 2150 2150 2150 2150 Notes: Wednesday, October 06, 2004 Page 1 of 1 ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS "" 1. Operations Performed: RepairWeliD PluQ PerforationsD Stimulate 0 OtherD Abandon 0 Alter CasingD Pull TubingO Perforate New Pool D WaiverD Time ExtensionO Change Approved Program D Operation Shutdown 0 Perforate IKJ Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 188-0710 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ 50-029-21834-00-00 7. KB Elevation (ft): 9. Well Name and Number: 92.00 W-29 8. Property Designation: 10. Field/Pool(s): ADL-o028263 Prudhoe Bay Field / Prudhoe 011 Pool 11. Present Well Condition Summary: Total Depth measured 10950 feet true vertical 9166.2 feet Plugs (measured) None Effective Depth measured 10908 feet Junk (measured) 10906,10803 true vertical 9135.4 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 38 - 118 38.0 - 118.0 1490 470 Liner 796 7" 26# L-80 10154 - 10950 8583.1 - 9166.2 7240 5410 Production 10350 9-5/8" 47# L-80 36 - 10386 36.0 - 8751.8 6870 4760 Surface 2643 13-3/8" 68# L-80 37 - 2680 37.0 - 2679.9 4930 2270 Perforation depth: Measured depth: 10610 -10640,10652 -10690,10700 -10714,10725 -10742,10758 -10773 True vertical depth: 8916.19 - 8938.39,8947.27 - 8975.32,8982.69 - 8993,9001.1 - 9013.61,9025.37 - 9036.39 RECEIVED Tubing ( size, grade, and measured depth): 3-112" 9.3# L-80 @ 34 - 10182 SEP 1 6 2004 Packers & SSSV (type & measured depth): 3-112" Otis HCM Packer @ 10073 Alaska Oil & Gas Cons. ^ 12. Stimulation or cement squeeze summary: Anchorage Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: 0 0 -1732 Subsequent to operation: 0 0 -1600 0 1295 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ! OilD Gas 0 WAGD GINJD WINJI!] WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-245 Printed Name Garry Catron Title Production Technical Assistant Signature 9-1n~ ~A r_Þ- Phone 564-4657 Date 9/14/04 .I v ()OIr,IMAL RBDMS BFL SEP 1 6 7004 Form 10-404 Revised 4/2004 ~ "" W-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/14/04 ***WELL SHUT IN ON ARRIVAL *** (PRE-ADPERFS). DRIFT W /2.50 CENT, 12" EXT,& 3.5 X EO PRONG TO SSSVN,. PULLED 3.5 MCX(SER # 1090097-2,1.185" BEAN), DRIFTED W/2.5 DUMMY GUN,TEL,& S.B.-. LOCATE TT @ 10,158' SLM + 12' CORR= 10,170' ELMD - TAG TD @ 10771' CORR DEPTH. (ALL PERFS OPEN, BOTTOM OPEN INTERVAL HAS 3' OF FILL). 07/17/04 Perforate 10610'-10640' 6 SPF FLUIDS PUMPED BBLS I No Fluids Pumped 0 I TOTAL Page 1 "" .---..., TREE = 4-1/16" WCEVOY WELLHEAD = WCEVOY ACTU6. TOR - 0115 KB. ELEV - 92.40' BF. ELEV - 54.75 KOP= 3100' Max Angle = 46 @ 6200' CÐtum tvÐ = 10577' CÐtumTVD= 8800' SS W-29 . 13-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 2.750" @ 2100' 3-112" OTIS SSSV NIPPLE I I TOP OF T' Lf\R 3-1/2' TBG. 9.2#, L-80, .0087 bpf. ID = 2.992' 10154' 10182' 9-518" CSG, 47#. L-80, ID= 8.681" 10386' PERFORA 1l0N SlJ\.1Mð. RY REF LOG: BHCS ANGLE AT TOP PERF: 42 @ 10610' Note: Refer t> Produetion œ tor historieaJ perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/4" 6 10610-10640 0 07/17/04 2-1/8" 4 10652 - 10672 0 10/14/88 2-1/8" 4 10672 - 10690 0 10/14/88 5" 4 10700-10714 0 08/15/88 5" 4 10725-10742 0 08/15/88 2-1/8" 4 10758 - 10773 0 10/14/88 10908' 7" Lf\R, 26#, L-BO, .0383 bpf, D = 6.276" 10950' I SAFETY NOTES: 2100' ST MD TVD 7 2989 2897 6 6026 5375 5 7636 6565 4 8237 7034 3 8838 7497 2 9408 7938 1 9913 8313 10007' 10057' 10073' 10116' 10149' 10182' I 10170' 10595' 10803' 10725' 10908' DATE REV BY COWMENTS [)ð..TE REV BY COMMONTS 10/15/88 GVR ORIGINAL COMPLETION 11/03/01 Rt-VTP CORRB:;TIONS 08/21/03 RWL/KK GLV C/O 08/28/03 JLJ/KK GLV C/O 09/06/03 JM'KK X NP CORRECTION 07/17/04 LDKlKAK ADF£RFS 3-112" OTIS SSSV LAND NIP, ID = 2.75" GAS LIFT MANCRELS ŒV TYPE VLV LATCH SIZE DATE 5 OTIS D\1Y RA 0 08/21/03 45 OTIS D\1Y RA 0 08/21/03 37 OTIS D\1Y RA 0 41 OTIS D\1Y RA 0 08/21/03 38 OTIS D\1Y RA 0 41 OTIS D\1Y RA 0 43 OTIS D\1Y RM 0 08/28/03 3-112" OTIS SLIDING SLæve. ID = 2.750" 3-112"1BG SEAL ASSY 9-518" X 3-1/2" 0115 HCM PKR, D = 3.850" 3-1/2' OTIS X NP, D = 2.750" 3-1/2' OTIS X NP, D = 2.750" MAR<ER JOINT 3-112" FN & WIRE SPEA R, 3/16" BRAIDED LlNE+-150', WL ASHNGTOOL STRING, INTERNAL GRAPR.EHOOK BAKERINFL A<RFISH 3-112" XX FLlX3 ON BOTTOM 24" LONG FRLDHOE BA Y UNIT WELL: W-29 PERMrrNo: 1880710 API No: 50-029-21834-00 SEC21 , T11N, R12E, 839'FNL & 1444' FEL BPExploration (Alaska) ~J-G I'\- (p / L (1/ LOD4- ( STATE OF ALASKA ( - €ç::f, f:J.;. =¡ / 4- ALASKA OIL AND GAS CONSERVATION COMMISSION(-<.k=to:,E, !)'\:./ t'~;!.,)1 APPLICATION FOR SUNDRY APPROV~ 2. Ð 2004 20 MC 25.280 1. Type of Request: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Name: Suspend 0 RepairWell D Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: "! I'. O;~ 1O,"),: ,.~;U;d~i"':'::':;~:;: ~~~3~ ,\3 d ~.)~ ~..~''". PerforateŒ] ? ..' vy.1~\V~rQ:;Ef\nnUlar DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 188-0710 /' BP Exploration (Alaska), Inc. Development D Exploratory D StratigraphicD Service Œ1 /' 9. Well Name and Number: W-29 ~ 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): I Effective Depth TVD (ft): 10908 9043.4 S~ MD WD 6. API Number / 50-029-21834-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 92.00 KB 8. Property Designation: ADL-028263 11. Total Depth MD (ft): I Total Depth TVD (ft): 10950 9166.2 Casing Length Plugs (md): Junk (md): None See Attachment Burst Collapse Conductor 80 Liner 796 Production 10350 Surface 2643 Perforation Depth MD (ft): 10652 - 10690 10700 - 10714 10725 - 10742 10758 - 10773 Packers and SSSV Type: 3-1/2" Otis HCM Packer 12. Attachments: Description Summary of Proposal 0 20" 91.5# H-40 7" 26# L-80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 8947.27 - 8975.3 8982.69 - 8993.0 9001.1 - 9013.6 9025.37 - 9036.4 top bottom top bottom 38 - 118 38.0 - 118.0 1490 470 10154 - 10950 8583.1 - 9166.2 7240 5410 36 - 10386 36.0 - 8751.8 6870 4760 37 - 2680 37.0 - 2679.9 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 " 9.3 # L-80 34 - 10182 Packers and SSSV MD (ft): 10073 Detailed Operations Program Œ1 BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI 14. Estimated Date for Commencing °l?eration: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasO WAG ~ / GINJD Plugged 0 Abandoned 0 WINJIi) WDSPLD Prepared by Garry Catron 564-4657. July 8, 2004 Contact Dan Robertson Printed Name Signature ~an ROberts~ ^ ~ ~{1¥~~--"" Title Phone Senior Petroleum Engineer 564-5546 6/24/04 Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: / -- 3o"r-)... L/ ~ Plug Integrity 0 BOP TestO Mechanciallntegrity Test I8J Location Clearance 0 Form 10-403 Revised 06/2004 RBDMS BFl OR\GiNAL JUL 0 6 1ßn~ 6($01'1/ BY ORDER OF THE COMMISSION Date: ~. SUBMIT IN DUPLICATE bp .,. ,\If.'II, -.....~ ~...- ~..- ~...-- ..~ ~...... .'~'~~I\. ". (I ( To: Doug Cismoski/John Smart, GPB Well Ops TL From: Dan Robertson Area PE Date: June 3, 2004 Subject: W-29i Additional Perforations and Step Rate Test Est. Cost: $40 M 4P1930.0 lOR: 500 bopd Please perform the attached work as part of the EWE Injection Project. The scope is as follows: Step Type 1 S 2 E 3 F 4 S 5 0 P roced u re Drift wI 2.5" DG bailer and TEL Add 30' perforations Step ratel injectivity test Install SSSV AOGCC witnessed MITIA once well is POI. ./' Current Status: SI, waiting for injection Max Deviation: 46 deg at 6200' Min. ID: multiple 2.75" ID restrictions Last TD tag: 10,755 BKB wI RST toolstring 7/29/02 Last Downhole Ops: 12/07/03: Pull TTP from 100781 Latest H2S level: generally 10-20 ppm on W pad ,r- Note small school of fis~~.l(t.-well. ~ "./ ) Well W-29i currentl~eenJS-'1~ have mechanical integrity adequate to allow MI injection. /~ It is planned to add pêrtõiations in the 45P interval for conformance with offset producers W-25, W-19, W-26, and W-32. A step rate test is then planned to establish injectivity, frac gradient and flush any remaining loose plastic tubing coating from the tubing. Multiple days were spent bailing plastic coating from the top of a tailpipe plug. A successful MITIA at 4000 psi was obtained 11/16/03.~he tubing hanger seals and 9 518" packoff were successfully pressure tested 12/2/03. ~/ The deepest set of perfs (41 P interval) is covered with fill as indicated by the 7/02 TO tag. It is not planned to clean out this fill as only one of the offset producers in the pattern has perforations in this interval. If the step rate test indicates at least 2 bpm at 2000 psi injectivity, the well can be placed on MI injection following the completion of the work. ( f If injectivity is less than 2 bpm at 2000 psi, a mud acid stimulation will follow prior to injection. Injectivity on 7/29/02 with dead crude bullheaded down the tubing was 2 bpm at 1650 psi, 4 bpm at 2450 psi, so a reasonably high injection rate is anticipated. Comments or questions can be directed to Dan Robertson at 564-5546 (W), 346-3714 (H), 529-5818 (C). cc: w/a: Well File w/o: SHckHne: 1. Drift to TO with a 2.5" DG, sample bailer and TEL ; 2. Shoot fluid level down IA to confirm that fluid level is within 500' of surface. Top off I :-s~it:iesel or =If F:~e~~an":o~'~o:::(priO~ :~~ 1. Perforate 10,610-10640 MDBKB (zone 45P) ref 8/10/88 SWS BHCS with 2.25" // powerjet guns at 6 spf, 60 deg phasing, random orientation. 1. RU pump truck and vac truck or tanks with 2% KCL water. Apply 1500 psi to inner annulus with diesel. Pump 150 bbls 2 % KCL water down the tubing at maximum rate at 3000 psi maximum pressure. Tubing volume to the top perfs is 107 bbls. Do not shut down or slow the rate during this step. The objective is to push any remaining loose plastic coating through the perforations as opposed to just plugging them up. / 150 bbls 2% KCI at max rate, 3000 psi max pressure 10 bbls 1.5 ppb Biozan or Flo pro (viscous sweep) max rate, 3000 psi 150 bbls 2% KCI at max rate, 3000 psi max pressure Shut down 30 minutes, note ISIP Perform step rate test at 0.5, 1, 1.5,2,3,4,5 BPM (or maximum rate at 3000 psi maximum wellhead pressure) with 2 % KCI. Hold the first rate for 10 minutes and the remaining rates for 3 minutes each. Note the rate and pressure at the end of each step on the WSR. (The pressure does not have to be completely stable). Determine frac gradient. Freeze protect well. Filter all fluids to 3 microns. 2 ( (" . ." II 2. Well can be placed on MI injection assuming adequate injectivity was obtained. Perform AOGCC witnessed MIT and install SSSV. ".--' ',. 3 lREE= 4-1/16" WCBlOY WELLHEA D = WCBl OY ACTU<\ TOR;" OllS KB. B..EV = 92.40' BF. B..EV = 54.75 KOP= 3100' tllax A n~le = 46 @ 6200' Datum tv[) = 10577' Datum TVD = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" H 2680' Minimum ID = 2.750" @ 2100' 3-112" OTIS SSSV NIPP LE I TOP OF 7" LNR l-i 10154' 1 13-1/2" TBG, 9.2#, L-80, .0087 bpf, ID= 2.992" H 10182' I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1--1 10386' 1 PERF ORA 1l0N SUMfv\A.RY RS= LOG: BreS ANGLEA T TOP PERF: 42 @ 10652' Note: Refer to Production œ for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/8" 4 10652 - 10672 0 10/14/88 2-1/8" 4 10672 - 10690 0 10/14/88 5" 4 10700-10714 0 08/15/88 5" 4 10725 - 10742 0 08/15/88 2-1/8" 4 10758 - 10773 0 10/14/88 1 PBlD 1-1 10908' 1 7" LNR, 26#, L-80, .0383 bpf, D = 6.276" H 10950' 1 DATE 10/15/88 11/03/01 08/21/03 08/28/03 09/06/03 REV BY COMMENTS GVR ORIGINAL COMPLETION Rf\VTP CORRECTIONS RWUKK GLV C/O JLJ/KK GL V C/O JMA<K X NIPCORRECllON DA TE RBI BY W-29 8 ~ L I I i ::g If 'I .. , ." I" .~ j ~ COMMENTS (' I SAFETY NOTES: 2100' H3-112" OTIS SSSV LAND NIP, ID = 2.75" 1 ~ ST MD TVD 7 2989 2897 6 6026 5375 5 7636 6565 4 8237 7034 3 8838 7497 2 9408 7938 1 9913 8313 GAS LIFT MANDRELS DEV TYPE VL V LA TŒ! SIZE DATE 5 OTIS DMY RA 0 08/21/03 45 OTIS DMY RA 0 08/21/03 37 OTIS DMY RA 0 41 OTIS DMY RA 0 08/21/03 38 OTIS DMY RA 0 41 OTIS DMY RA 0 43 OTIS DMY RM 0 08/28/03 I 1000T H3-112"OTISSLlDINGSLIBIEID=2.750" 1 1 1005T IJ3-112" 1BGSEALASSY 1 I 10073' 1-19-5/8" X 3-1/2" OllS reM PKR, [) = 3.850" 1 I 10116' 1-1 3-1/2" OTIS X NIP, D =2.750" 1 1 10149' 1--1 3-1/2" OTIS X NIP, D =2.750" 1 1 10182' 1-13-112" llW TBG TAIL 1 1 10170' I-IEUvD TT LOGGED 07/16/90 I .. I 10595' I-IMARKER JOINT 1 I 10803' 1- 3-112" FN & WIRE SPEAR, 3/16" BRAIDS) LINE +-150', WL ASHNG TOOL STRING, INTERNAL GRAPREHOOK I 10725' HBAKERINFL R<RFISH 1 10908' H3-112" XX RLK3 ON BOTTOM 24" LONG 1 ffiUDHOE BA Y UNIT WB..L: W-29 ÆRMIT No: 1880710 API No: 50-029-21834-00 SEC 21, T11 N, R12E 839' FNL & 1444' FB.. 8P Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak. us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / W-29 11/16/03 Bruce Pinkston Packer Depth Pretest Initial 15 Min. 30 Min. WelIIW-29 I T)/pelnj. I S TVD I 8,524' Tubin~l 3501 3501 3501 3501 IntervalI O P.T'D.I1880710I ITypetest P Test psiI 2131 Casingl 501 4,0001 4,oooI 4,0001 P/FI P Notes: Pressure test was performed prior to the initiation of injection. An AOGCC witnessed MITIA will be performed once the well is POI. WellI Ini. TVDI Interval p.T.D.I ITyPe Notes: We,,I Type ,nj.I TVD I Intervall I I ITM Notes: P.T'D.IWe"IITypeType'nj'ltestlITestTVDpsill ICasin~lITUbinglI I IIntervaIp/FI Notes: WellI Type Inj.I TVD Tubin~l Type testI Test Casing I P/F I Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MiT Report Form Revised: 06/19/02 2003-1116_MIT_PBU_W-29_pre-inj,xls L STATE OF ALASKA O~' ALAS OIL AND GAS CONSERVATION C ,..alSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abanonr-] Suspend[~ Operation ShutdownS] Perforate[--] VadanceE] Annuar Disposalr-] After Casin~lE] Repair WellD Plucl PerforationsC-! stimulate[-] Time Extension[-] Other[] Change Approved Program[~ Pull Tubing["] Perforate New Pool~] Re-enter Suspended Well[~ WAG CONVERSION 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development r-~ Exploratory[~ 188-071 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic[-'] Service[] 50-029-21834-00-00 7. KB Elevation (ft): 9. Well Name and Number: 92,40 W-29 ~8. Property Designation: 10. Field/Pool(s): ADL 028263 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 10950 feet true vertical 9164 feet Plugs (measured) TD Tagged @ 9024 (07/26/2002) Effective Depth measured 10756 feet Junk (measured) true vertical 9024 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 148' 148' 40K 520 Surface 2642' 13-3/8" 2680' 2680' 80K 2670 Intermediate 10348' 9-5/8" 10386' 8752' 80K 4760 Liner 796' 7" 10154'-10950' 8583'-9166' 80K 7020 Perforation depth: Measured depth: Open Perfs 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773'. True vertical depth: Open Perfs 8911'-8922', 8930'-8948', 8950'-8959', 8962'-8966', 8975'-8980', Tubing: ( size, grade, and measured depth) 3-1/2" 9.2# L-80 TBG @ 10182'. Packers & SSSV (type & measured depth) 9-5/8" x 3-1/2" Otis HCM PKR @ 10073'. 3-1/2" Otis SSSV Landing Nipple @ 2100'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr 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: Exploratory[--] DevelopmentE~ Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: O"1--1 Gasl--I WAG[ GINJI'q W~NJI--I WDSPLr"I Daily Report of Well Operations _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: Contact DeWayne R. Schnorr I 303-229 Printed Name DeWayne R. Schnorr Title Techical Assistant Form 10-404 Revised 2/2003 ORIGINA L OCT 1 20[}3 08/24/2003 W-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FIRST INJECTOIN TEST FOR WELL W-29 THAT WAS REPORTED IN OMAR AS AN INJECTION WELL. 09/22/2003 UPDATE AS OF 09/22/2003. 08/24/03 EVENT SUMMARY FIRST WATER INJECTOIN TEST FOR WELL W-29 THAT WAS REPORTED IN OMAR AS AN INJECTION WELL. O9/22/O3 NO WATER OR MI HAS BEEN INJECTED INTO THIS WELL SINCE THE FIRST INJECTION TEST. ITOTAL FLUIDS PUMPED BBLS Page 1 ALASKA OIL AND GAS CONSERVATION cOMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ll. Type of Request: Abandon [--I :Suspencl r-I Operation Shutdown I-I PerforateD"] VarianceD Annuar DisposalD AIter Oasin~ [--! Repair Well I'-I Plu(l Perforations [-I Stimulater-I Time Extensionl-'] Other[] Chan~le Approved Pro, ram I-'] Pull Tubin~ D Perforate New Pool D Re-enter Suspended Wellr-I CONVERSION-WAG 2. Operator 4. Current Well Class: 5. Permit to Ddll Number: Name: BP Exploration (Alaska), Inc. Development · Exploratoryl--I 188-071 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic I-I service D 50-029-21834-00-00 7. KB Elevation (fi): 9. Well Name and Number: RKB 92.40 W-29 8. Property Designation: 10. Field/Pool(s): ADL 028263 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):10950 ITotal Depth TVD (ft): IEffective Depth MD '(ft): IEffective Depth TVD (ft): IPlugs (measured): IJunk (measured):9164 I 10756 (07/26~2002) I 9024 None 10803 Casing Length Size MD TVD Burst Collapse top bottom top bottom, Conductor 110' 20" 148' 148' 40K 520 Surface 2656' 13-3/8" 38' - 2680' 38' - 2680' 80K 2670 Intermediate 9120' 9-5/8" 38' - 10386' 38' - 8752' 80k 4760 Production 719' 7" 10154' - 10950' 8583' - 9166' 80K 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: I Tubing Grade: Tubing MD (ft): 10652' - 10773' 8947' - 9036' 3/1/2", 9.2# L-80 10182 Packers and SSSV Type: Packers and SSSV MD (fi): 9-5/8"x3-1/2" Packer; 3-1/2" Otis SSSVLN Packer @ 10073', SSSVLN @ 2100' 12. Attachments: Description Summary of Proposal· 13. Well Class after proposed work: Detailed Operations Program r-I BOP Sketch [--I Exploratoryl--I Developmentr-! Servicel~l 14. Estimated Date for September, 2003 //' 15. Well Status after proposed work: Commencin,q Operation: OilD /, GasD Pluggedr-I Abandonedr-I 16. Verbal Approval: Date: WAG~ GINJD-I WINJl-'! WDSPLI--~ Commission Representative: Perpared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact AmY Frankenburg Printed Name Amy Frankenbur~ Title Senior En~lineer ~ O..__ ~....-------~....~.~----'-"~ Phone 907/564-4503 Date Jun 19:2003 Signature d-~Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sund~'~q~r:'~~._. · Plug Integrity D BOP Testl'-! Mechancial Integrity TestiS' Location ClearanceD I~'?Ll2!' I :'' .......... ~'I r'l~ ...... __ ~jj~~~~., BY ORDER OF Approved by: COMMISIONER THE COMMISSION Date: ,. SEP 0 2003 Form 10-403 Revised 2/2003 ORI(. INAi_ SUBMIT iN DUPLICATE ACTUATOR = OTiS~I~V ~---~ ~m ,,, KB. REV = ~.~' BF2 ~ = ~.75 KOP = 3~ ~' ~xAn~e= 46~62~' ~ ] 2100' H3-1~"OT~SS~VLANDN~P,~D=2.75"l ~tum~ = 105~' ~ . ~tum WD = 88~' ~ ~ GAS LI~ ~N~S , ~~~ ~~~~ I 6~ 6026 5375 45 OTIS DOME ~ 16 10/1~94~ 5 76~ 65~ 37 OTIS 4 8237 70~ 41 OTIS D~E ~ 16 10/1~94 3 88~ 7497 38 OTIS Minimum ID = 2.750" ~ 2100' ~ 2 9408 79~ 41 OTIS 1 9913 83131 43 OTIS SO ~ 20 ,10/1~94 3-1~" OTIS SSSV NIPPLE I I ' I 10~ H3-1~"OTISSLiD~SL~D=2.7~" J I I I lo~16' i~/?'OT'SXN'P'~=2'?S0"I I ~o,~'~,, H ~0~4' ~ I I I ~°~4~' H ~'°~'SXNN'""~:~'~°"l I~-~,~"~,~.~,~-~o,o.oo~,,,~=~.~" H ~o~. I ~ '--~1 ~o~ H~-~,,~,~,~i I ~o~7o' H.~ ~OS~EDOZ/~o I 9-5/8" ~G, 47~, L-80, ID= 8.681" H 10386' ~ ",, ~ ~os9s' HMA~~ ~ ~ ~ ~0~3' ~13-1~" ~ &WIRESP~ 3/16" B~ID~ P~TION SUGARY LINE +-150', ~ RSHNG TO~ ST~NG, REF L~: BH~ ~ IN~R~ L G~P~E H~K A~LE AT T~ ~: 42 ~ 10652' No~: ~fer to Pr~uction DB for historbal peri data S~E~ SPF IN~RVA L ~n~Sqz 2-1/8" 4 10652-10672 O 10/14~8 2-1/8" ~ 4 10672-106~ O 10/14~8 ~ 5" 4 10700-10714 O 0~15~8 5" 4 10725-10742 0 0~15~8 ' 2-~/s" 4 ~07~-~0773 ~ 0 ~ ~0n4~8I , I ~' I lo72s' BA~RIN~ ~R FISH ~ ~ t ~o~' H,-,~"~ ~ o,.o~o~" ~o,~ I I""~ H ~o~. I I ~ R~ BY I COM~N~ DATE ~ BY ~M~S P~D~EBAY 10/15/88 GVR ORGI~L COM~ON WELL: W-29 0~1~01 SIS-~A CONVER~D TO CANVAS P~ ~: 18~0710 0~05/01 SIS-LG FIlL APl ~: 50-02~2183~00 11/0~01 ~/~ COR~C~O~ , S~ 21, Tll N, R12E ~ ~loration (Alaska) SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 10652-10672 O 10/14/88 2-1/8" 4 10672-10690 O 10/14/88 5" 4 10700-10714 O 08/15/88 5" 4 10725-10742 O 08/15/88 2-1/8" 4 10758-10773 O 10/14/88 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/15/88 GV R ORIGINAL COMPLETION 02/13/01 SIS-QAA CONVERTED TO CANVAS 03/05/01 SIS-LG FINAL 11/03/01 RN/TP CORRECTIONS bp BP Exploration (Alaska), Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 12August 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry notice for W-29 swap from producer to WAG injection BP Exploration Alaska, Inc proposes the following wellwork to prepare to swap W-29 from production to WAG (water alternating gas) injection with MI start-up estimated to occur in September, 2003 (TIFL test passed on 7/14/03) 1 S 2 O dummy off gas lift valves M1TIA to 4000 lbs. (witnessed by AOGCC) ~/ W-29 is shut in now due to construction activities associated with the tie-in of the surface injection facilities. Facility tie-in as a WAG injector will be complete in September 2003. W-29 will be put on injection beginning with a slug of MI. A copy of the wellbore diagram is attached. Please contact Amy Frankenburg at 564-4503 with any questions Sincerely, Amy Frankenburg EWE Production Engineer ACF (8/12/2003) 1 of 1 P~CHANICAL iNTEGRiTY ~R_E?ORT ' go: ~o9~o..~.. Ctla, q'TVD; ?~ZD: 107x6, ~ .... ?aZ.,/TVD shoe: TVD; Se[ at 1007~ · " ;. Parrs ~O~% to 1077Y iNTEGRITY - P.~T t! Annulus Press Test: ; 15 min ; 30 rain Theoretical TOC Cement Bond Log (%as or No) ~ ; In AOGCC File CBL Evaluation, zone above perfs , , ~ Production Log: Type : Evaluation STATE OF ALASKA , ALAS~'"~'.31L AND GAS CONSERVATION COMMISSI¢''-~ REPORT OF SUNDRY WELL OPEnATIONS 1. Operations performed: Operation shutdown Stimulate × Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311' SNL, 1273' EWL, SEC. 16, T11N, R12E, UPM At effective depth 2145' SNL, 1216' EWL, SEC. 16, T11N, R12E, UPM At total depth 2057' SNL, 1186' EWL, SEC. 16, T11N, R12E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Sewice 6. Datum elevation (DF or KB) KBE= 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU 9. Permit number/approval number 88-71 / 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10950 feet BKB 9164 feet 10814 feet BKB 9065 feet Plugs (measured) Junk (measured) Fish (3 1/2" XX plug on bottom); fill at 10814'MD (01/90) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth .. 110 20 8 c.y. 148 2643 13 3/8 3840 c.f. 2681 10346 9 5/8 2195 c.f. measured .. 796 7 280 c.f. 10154-10950 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773' True vertical depth BKB 148 2681 8581-9164 true vertical subsea 8855' - 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 10073' with 3 1/2" tailpipe to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCM packer at 10073'; 3 1/2" SSSV at 2100' RECEIVE 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure · ',)ii & O2s Cons. Anchora.~e 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 620 1847 488 1259 281 Subsequentto operation 690 2070 598 1374 297 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ! Daily Report of Well Operations Oil ,,X Gas Suspended 17. I hereby %ertify that the forego~.g is true and correct to the best of my knowledge. Si~n ed ~'-/3o./~(~ ~ (/ R o.,-~.~.'~ Title Senior Technical Assistantl Form 10-404~ Rev 06/15/88 Service Date SUBMIT IN DOPLI~:ATE ~mission 4/01/93 4/04/93 WELL W-29(12-16-11-12) Stimulation Operation A CTU HCL Acid Wash Treatment was performed using the following fluids: SUMMARY 1. RIH WITH BAKER 2.5" INFLATABLE PKR BHA. 2. UNABLE TO TIE-IN WITH TEL ~ NO OVERPULL THRU "X" NIPPLES OR SLIDING SLEEVE PROFILES, MADE SEVERAL PASSES, NO LUCK. RIH TO TD AND CORRECT TO E-LINE TD OF 10,798 FF BKB. PULL TO 10695 FT BKB FOR CENTER OF PACKER ELEMENT, LOAD WELL WITH SEAWATER, PUMP BALL, NO INDICATION OF BALL ON SEAT, SURGE PUMP, WORK CT, NO LUCK, 4. POOH, SWABBING FLUID IN 3.5" TBG UNTIL FLUID WEIGHT CAUSED PKR TO SHEAR RELEASE AT 8840 FT, WHERE WE SAW A 4000 LB LOSS OF WT. CONT. POOH. 5. RECOVERED TOOLS AT SURFACE, OUTER SEAL RUBBERS WERE LEFT IN HOLE AT 8840 FT. WILL FISH WITH WIRELINE FOR OUTER RUBBERS TOMORROW. ELEMENT HAD PARTIALLY INFLATED AT SOME POINT, DID NOT SEE OVERPULL WHILE PULLING UP THRU TAILPIPE, BUT DID SEE SWABBING SOON AFTER, WHILE POOH. NO PERF MARKS ON ELEMENT. 6. POP WITH GAS LIFT AT 2130 HRS. FLUIDS PUMPED BBLS. DESCRIFrION 92 SEAWATER, FILTERED 37 MF_.DH 129 TOTAL A PKR/CTU HCL Acid Wash Treatment was performed using the following fluids: SUMMARY 1. BY-PASS CRACKED NIPPLE TO DENSIOMETER, RE-PRESS TEST, OK 2. RIH WITH BAKER 2.5" INFLATABLE PKR BHA. SET DOWN IN TOP GLM (AT 3000'), POOH TO CHECK PETREDAT GAUGES FOR DAMAGE. FOUND PACKER HAD WT SET, REPLACE PACKER AND RIH. SET DWN AGAIN IN SSSV MANDREL, POOH, L/O PRESS GAUGES, RIH OK. 3. TIE-IN WITH TEL, GOOD TIE-IN, SET PKR ELEMENT AT 10695 FT BKB, INFLATE PACKER, SET DOWN WT ON PKR AND PERFORM INJECTIVITY TEST. PACKER SET OK. 4. ORDER OUT ACID FROM BJS. RIG UP BJS, PRESS TEST. ~-,, ,...,h taoe fjh 6/22/94 PAGE 2 WELL W-29(12-16-11-12) 5. PUMP ACID STIM AS PER PROGRAM, 73 BBL 15% HCL ACID TOTAL IN 3 STAGES WITH 2 DIVERTER STAGES OF N2 75 QUALITY FOAM. DISPLACE WITH SW. RELEASE PKR & POOH. 6. LEFT PACKER FISH IN HOLE, "BW" CONNECTOR BELOW TEL HAD BACKED OFF. THE PACKER PULL RELEASE LOOKED NORMAL, SO THE PACKER APPARENTLY FELL OFF WHILE POOH WTIH CT. THE BW THREAD SHOULD HAVE BEEN THREAD LOCKED WHEN IT WAS MADE UP IN THE BAKER SHOP. 7. "BW" CONNECTION ABOVE PACKER MAY HAVE BEEN LEAKING AT APPROX. 0.2 BPM DURING THE ACID STIM. WHICH WOULD HAVE PLACED APPROX. 10% OF THE ACID VOLUME ABOVE THE PACKER. A 0.2 BPM LEAK WAS SEEN WHILE INFLATING THE PACKER, BUT WAS THOUGHT TO HAVE BEEN AT THE BALL SEAT, SINCE THE PACKER SET OK. BBLS. 364 73 48 45 530 FLUIDS PUMPED DESCRIPTION SEAWATER, FILTERED W/3 MIRCRON 15% HCL ACID 75 QUALITY N2 FOAM DIVERTER MEOH FOR FRFtF2F~ PROTECT TOTAL RECEIVED Cons. A:~chor'a.je BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/10/92 T# 83785 BP MAGNETIC LIS TAPE Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. CH/4 PASS CNTD FIN 07/20/92 #1 SCH 10325.00-10789.00 1600BPI API#500292183400 9052->TP# REF#92444 information Control Well Records Adrian J. Martin / RECEIVED AUG 2 5 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXpLoRATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/24/92 T# 83755 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~ COMP LET ION W~- 2 0 CNL ..~--~ ~'Ir-'ll CNL 07/21/92 #1 07/19/92 #1 07/20/92 #1 9500.00- 9876.00 SCH 5 " 9350.00- 9806.00 SCH 5 " 10328.00-10787.00 SCH 5 " Information Control Well Records Adrian J. Martin RECEIVED 1 2 199~ Alas~ 0ii & Gas Cons. Anchorage Oommi~oion BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO DATE:08/13/91 EXXON T#: 82709 PHILLIPS STATE OF ALASKA ARCHIVES SYSTEM Ta~.e & Transmittal On_ly ,BP MA(~NETI~ LI~ TAPE & LISTING Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. W-20 CH/CNL/FIN 06/30/91 #1 9330-9805 SC H#74671 1600BPI AP 1#50-029-21808 W-29 CH/CNL/FIN 06/30/91 #1 10330-10793 SC H#74669 1600B PI AP 1#50-029-21834 W-30 CH/CNL/FIN 07/01/91 #1 9394-9940 SCH#74672 1600BPI AP1#50-029-21887 TAPE POS.#07883 TAPE POS.#07884 TAPE POS.#07885 Information Control Well Records LR 2-1 J. Dietz "%//' % BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date :07/0591 TO: DISTRIBUTION \ T#:82555 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. W-04 CNL 06/29/91 #1 11550-12107 Sch 5" W-10 CNL 06/29/91 #1 13990-14595 Sch 5" W-20 CNL 06/30/91 #1 9330-9805 Sch 5" W-29 CNL 06/30/91 #1 10330-10793 Sch 5" W-30 CNL 07/01/91 #1 9394-9940 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED JUL 9 1991 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO DATE: 09/07/90 EXXON T#: 81564 PHILLIPS STATE OF ALASKA ARCHIVES SYSTEM Tape & Transmittal Only BP MAGNETI~ LI~ TAPE & LISTING Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. W-29 DSN 07/16/90 #1 9948-10816 HLS#37817X 800BPI AP!#50-029-21834 TAPE POS.#07296 Information Control Well Records LR 2-1 J. Dietz/S. McCurry RECEIVED S E P 1 ~ 1990 Alaska 0il & Gas GoDs. Gommissio~ Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 09/07/90 T#:81563 FROM: SUBJECT: Information Control Well Records LR2-1 BP ~.A~ED HOLE FINAL~i Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. W-29 DSN 07/16/90 #1 1 0400-10820 HLS Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED S E P 1 ~ 1990 Alaska 0il & Gas (;OHS. (Jommissio~ Anchorage BP EXPLORATION BP ExDIorat~on (Alas~(a) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. AlasKa 99519-6612 (907) 561-5111 TO' DISTRIBUTION Date:07/31/90 T#:81450 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedai listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. v~,4-07 Ped 07/02/90 #1 9500-9850 HLS 5" ,~' S- 18 Perf 07/09/90 #1 11150-11965 HLS 5" v.S-18 Peal 07/10/90 #1 11600-11820 HLS 5" v' S-21 Perf 06/30/90 #1 9600-10358 HLS 5" v" W-29 Tubing Jewerly 07/16/90 #1 10400-10820 HLS 5" v"' Y-27 Perf 06/29/90 #1 13000-13415 HLS 5" V' Z-08 Perf 06/27/90 #1 10585-11576 HLS 5" Distribution: ,.oo CHEVRON MOBILPHILLIPS ~~A~SkA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 9, 1990 Alaska 0il & Gas Conservation Commi[sion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton well 'w-29 ' (12-16-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing remedial/capacity sustainment work on the well. Yours very truly, C. J. A. Lewis Supervisor Peripheral & EOA CJAL:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File f~--, STATE OF ALASKA ~SKA OIL AND GAS CONSERVATION COMI~.,_~ION REPORT OF SUNDRY WELL OPERATION ' 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate. Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3.Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at sudace 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311'SNL, 1273'EWL, SEC. 16, T11N, R12E, UPM At effective depth 2145'SNL, 1216' EWL, SEC. 16, T11N, R12E, UPM At total depth 2057' SNL, 1186' EWL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 10950feet true vertical BKB 9164feet Repair well 5. Type of Well: Development ~ Exploratory Stratigraphlc Service Other 6. Datum elevation (DF or KB) KBE ,, 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU 9. Permit number/approval number 88-71 / 90-022 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 10814feet true vertical BKB 9065feet Junk (measured) Fish (3 1/2" XX plug on bottom); fill at 10814' MD (01/90) Casing Length Size Structural -- Conductor 110 20 Surface 2643 13 3/8 Intermediate 10346 9 5/8 Production -- Liner 796 Perforation depth: measured Cemented Measured depth 148 2681 8 c.y. 3840 c.f. 2195 c.f. 7 280 c.f. 10154-10950 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773' True vertical depth BKB 148 2681 8581-9164 true vertical subsea 8855' - 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2"L-80 to 10073' with 3 1/2" tailpipe to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCM packer at 10073'; 3 1/2" SSSV at 2100' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure ,Reoresentative Daily Aver~,ge Productior~ or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1140 2006 249 0 256 Subsequent to operation 950 1388 428 1728 i5. Attachments 16. Status of well classification as: Copies of Logs and Surveys run. Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 245 Title Supervisor Peripheral & EOA Service WELL W-29 (12-16-11-12~ PBU STIMULATION OPERATIONS A scale inhibition treatment was performed January 27, 1990, on the following perforated intervals in Well W-29. 10652' - 10690' MD BKB 10700' - 10714' MD BKB 10725' - 10742' MD BKB 10758' - 10773' MD BKB The treatment was preceded by a 17-bbl. 15% HC1 tubing wash and 10-bbl. 15% perf wash. The scale inhibition treatment was pumped via coiled tubing as follows: a) b) c) d) e) f) 21 bbls. diesel preflush 24 bbls. methanol 46 bbls. EDTA w/OSR 94 bbls. scale inhibitor w/OSR 407 bbls. seawater overflush Displaced from coiled tubing w/diesel The well was left shut in for two hours, then returned to production slowly and tested. jam 219190 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 15, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-29 (12'16-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAM: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File . ' STATE OF ALASKA j i, ~ ,. .;KA OIL AND GAS CONSERVATION COMMI,._,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing ~ Repair well Change approved program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311' SNL, 1273' EWL, SEC. 16, T11N, R12E, UPM At effective depth 2084' SNL, 1195' EWL, SEC. 16, T1 IN, R12E, UPM At total depth 2057'SNL, 1186'EWL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: Operation Shutdown ~ Plugging .... Pull tubing ~ Variance ~ J5. Type of Well: Development X Exploratory ~ Stratigraphic ~ Service measured true vertical Re-enter suspended well~ Time extension Stimulate X Perforate, Other ~ 6. Datum elevation (DF or KB) KBE =92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU 9. Permit number 88-71 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool 10950 feet Plugs (measured) BKB 9164 feet Effective depth: measured true vertical 10908 feet BKB 9134 feet Junk (measured) Fish (3 1/2" XX plug on bottom) Casing Length Structural -- Conductor 110 Surface 2643 Intermediate 10346 Production -- Liner 796 Perforation depth: measured Size Cemented Measured depth 20 8 c.y. 148 13 3/8 3840 c.f. 2681 9 5/8 2195 c.f. 10384 7 280 c.f. 10154-10950 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773' true vertical subsea 8855'. 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2"L-80 to 10073'with 3 1/2"tailp~3e to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCMpacker at 10073~ 3 1/2" SSSV at 2100' True vertical depth BKB 148 2681 8581-9164 13. Attachments Description summary of proposal × Detailed operations program BOP sketch x 14. Estimated date for commencing operation January 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas~ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~/4~~ Title Manager Production En~lineerin~l Date [' 1~,C''~ ?~ fl C°nd~ns ofapproval: Notify Commission so representative may w~ness I ~rovaJ No... ~~ Plug int~r~y BOP Test L~ation clearance ~ *PP~°~ ~°V-ned M~hani~l Integrity Test Subsequent form r~uired 10- ~ ~ Retu~ ~ ORIGINAL SIGNED BY ~ / / Approved by order of the Commission LONN,E C. SMITH ~mmissioner Date - %~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL W-29 (12-16-11-12~ PI~U STIMULATION PROPOSAL A scale inhibition treatment is proposed for the following perforated intervals in Well W-29. 10652' - 10690' MD BKB 10700' - 10714' MD BKB 10725' - 10742' MD BKB 10758' - 10773' MD BKB The treatment will be pumped via coiled tubing as follows: a) b) c) d) e) 24 bbls. diesel preflush 24 bbls. methanol 48 bbls. EDTA w/OSR 95 bbls. scale inhibitor w/OSR Displace from coiled tubing w/diesel The well will be left shut in for two hours, then returned to production slowly, then tested. jam 1/11/90 Coiled Tubing~ Blow-Out-Preventers Coiled Tubing Pack-Off Blind Rams Cutter Rams Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (Circulate/Re turns) W ell Head Swab Valve BP EXPLORATION November 10, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-29 (12-16-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, 'MJ~naA~eBr pgrgoductlon Engineering JAB:JAM Enclosures (4) oc: L. Burke (MB12-1) Well Records (LR2-I) w/10 Well File RECEIVED Nov 1 ~ 1~9 Alaska Oil & (~as Cons. CommissiO~ Anchorage STATE OF ALASKA AL, ,~ OIL AND GAS CONSERVATION COMMIE)._ ~N REPORT OF SUNDRY WELL OPERATI( i 6! 1. OP~rati0ns performed: Operation shutdown .... Stimulate X Plugging Perforate Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of Well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311' SNL, 1273' EWL, SEC. 16, T11N, R12E, UPM At effective depth 2084' SNL, 1195' EWL, SEC. 16, TI 1N, R12E, UPM At total depth 2057'SNL, 1186'EWL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 10950feet true vertical BKB 9164feet Repair well 5. Type of Well: Development X Exploratory, Stratigraphic ~ Service Plugs (measured) Other. 6. Datum elevation (DF or KB) KBE = 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12.16.11-12) PBU 9. Permit number/approval number 88-71 / 9-889 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10908feet true vertical BKB 9134feet Junk (measured) Fish (3 l/2" XX plug on bottom) Casing Length Size Structural -- Conductor 110 20 Surface 2643 13 3/8 Intermediate 10346 9 5/8 Production -- Liner 796 Perforation depth: measured Cemented Measured depth True vertical depth BKB 148 148 2681 2681 8 c.y. 3840 c.f. 2195 c.f. 7 280 c.f. 10154-10950 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773' 8581-9164 true vertical subsea 8855' - 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 10073' with 3 1/2" tallpipe to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCM packer at 10073'; 3 1/2" SSSV at 2100' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) NOV 1 Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons, Commlssl0c ~ r_hn ,, Re~)resentative Daily Averacm Production or Iniection Data - OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 300 436 70 0 214 Subsequent to operation 1300 1900 290 1782 266 '"i5. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'~~ Title Manager Production Engineering Date l~" [0 '/~'~ Form 107~4 Rev 06/15/88 L/~// SUBMIT IN DUPLICATE V WELL W.29 (12.16-11.12~ PBU STIMULATION OPERATIONS A mud acid treatment was performed October 21, 1989, on the following perforated intervals in Well W-29. 10652' - 10690' MD BKB 10700' - 10714' MD BKB 10725' - 10742' MD BKB 10758' - 10773' MD BKB The treatment was pumped via coiled tubing as follows' a) b) c) d) e) f) g) h) i) j) k) l) m) 24 bbls. Arctic diesel preflush 10 bbls. 10% HCI 6 bbls. diverter 20 bbls. 10% HCI 6 bbls. diverter 20 bbls. 10% HCI 6 bbls. diverter 45 bbls. 10% HCI 241 bbls. 6% HCI - 1.5% HF 214 bbls. 2% NH4CI 20 bbls. Arctic diesel post-flush 50 bbls. xylene Displaced from coiled tubing w/26 bbls. diesel The well was returned to production slowly, then tested. jam 11/8/89 RECEIVED Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 2, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-29 (12-16-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, Manager Production Engineering JAM: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File RECEIVED ,4~.as,~a Oil & (Jas Cons~ Anchorage 1. Type of Request: '~'-" STATE OF ALASKA iSKA OIL AND GAS CONSERVATION COMb, ,ON APPLICATION FOR SUNDRY APPROVALS Abandon Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing ~ Repair well Plugging ~ Time extension ~ Stimulate X Change approved program __ Pull tubing __ Variance __ Perforate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311' SNL, 1273' EWL, SEC. 16, T11N, R12E, UPM At effective depth 2084' SNL, 1195' EWL, SEC. 16, TI 1N, R12E, UPM At total depth 2057'SNL, 1186°EWL, SEC. 16, T11N, R12E, UPM 10950 feet BKB 9164 feet 10908 feet BKB 9134 feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development X Exploratory __ Stratigraphic ~ Service 6. Datum elevation (DF or KB) KBE = 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU 9. Permit number 88-71 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) Fish (3 1/2"XX plug on bottom) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 8 c.y. 148 Surface 2643 13 3/8 3840 c.f. 2681 Intermediate 10346 9 5/8 2195 c.f. 10364 Production -- Liner 796 7 280 c.f. 10154-10950 Perforation depth: measured 10652'-I0690', 10700'-10714', 10725'-10742', 10758'-10773' true vertical subsea 8855'- 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2"L-80 to 10073' with 3 1/2" tailpipe to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCM packer at 10073'; 3 1/2" SSSV at 2100' True vertical depth BKB 148 2681 8581-9164 RECEIVED 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch X 14. Estimated date for commencing operation October 1989 16. If proposal was verbally approved Oil X Gas ~ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic, lned ~ ,~'~~ Title Mana~lerProductionEn~lineerin~l n< FOR COMMISSION USE ONLY Conditi of approval: Notify Commission so representative may witness 15. Status of well classification as: Plug integrity __ BOP Test__ Location'clearance __ Mechanical Integrity Test__ Subsequent form required 10- ~'o g Suspended __ IAppr°va' N°' 9 Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SE,gTH Commissioner Approved Copy Returned .io_--/o .-¢9 Date /0'"~- ~9/~ SUBMIT IN TRIPLICATE ,WELL W-2~ (12-16-11-12) PBU ~TIMULATION PROPOSAL A mud acid treatment is proposed for the following perforated intervals in Well W-29. 10652' - 10690' MD BKB 10700' - 10714' MD BKB 10725' - 10742' MD BKB 10758' - 10773' MD BKB The treatment will be pumped via coiled tubing as follows: a) b) c) d) e) f) g) h) i) j) k) l) m) 24 bbls. Arctic diesel preflush 10 bbls. 10% HC1 6 bbls. diverter 20 bbls. 10% HC1 6 bbls. diverter 20 bbls. 10% HC1 6 bbls. diverter 45 bbls. 10% HC1 238 bbls. 6% HCI - 1.5% HF 200 bbls. 2% NH4CI 24 bbls. Arctic diesel post-flush 50 bbls. xylene Displace from coiled tubing w/diesel The well will be returned to production slowly, then tested. jam 9/28/89 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off Blind Rams Cutter Rams 2" Chicksan (Kill Line) Slips Pipe Rams ,;.i,r..~,.,. - .. Pump-In Sub (Circula te/R e turns) W ell Head Swab Valve BP E~PLORATION HOUSTON ARCO '- CHEVRON E~TXON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES i NOEXED BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907} 561-5111 Date: 04-19-89 79983 REFERENCE: BP FI~NAL DATA - PRESSURE SURVEY DATA The following material Is being submifted herewith. Please acknowledge receipt by signing a copy of this.legal'er and returning It to fhls office: ~E-25 Static Gradient 03-31-89 'G-23 Static Gradient 03-31-89 H-29 Static Gradient 04-06-89 R-08 Flowing Gradient 03-10-89 R-10 Flowing Gradient 03-10-89 W-O1 Static Gradient 04-10-89 "W-06 Static Gradient 04-02-89 -W-17 Static Gradient 04-10-89 W-25 : Static Gradient 03-31-89 W-29 Static Gradient 04-01-89 · ~ W-31 Static Gradient 03-31-89 -W-37 Static Gradient 04-01-89 W-38 Static Gradient 03-30-89. W-40 Static Gradient 04-02-89 Y-14 Static Gradient 04-01-89 Y-19 Static Gradient 04-02-89 Z-01 Static Gradient 04-06-89 Z-08 Static Gradient 04-03-89 5-14 Static Gradient 04-03-89 Z-28 Static Gradient 04-04-89 Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco C~mco amco £ ~_ , ,' ~~ · - c~o ~ lpn 2 1 1~'~''~ Camc~ mFN - - " , ~' ~ :~.,;: ~"~;'~. ~O~,il[5o'~U Rece I ved Date Shirley R, McCurry I NFORMAT i ON CONTROL Wel I Records LR2-I BP EXPLORATION March 15, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-29 (12-16-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, !~er Production Engineering JAB: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File '~r~cJ~0ra,ge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311'SN!., 1273' EWL, SEC. 16, T11N, R12E, UPM At effective depth 2084'SNL, 1195' EWL, SEC. 16, T11N, R12E, UPM At total depth 2057' SNL, 1186' EWL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 10950feet true vertical BKB 9164feet Stimulate X Plugging Repair well 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) Perforate Other., 6. Datum elevation (DF or KB) KBE = 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU 9. Permit number/approval number 88-71 / 8-979 10. APl number 50- 029.21834 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10908feet true vertical BKB 9134feet Junk(measured) Casing Length Size Structural -- Conductor 110 20 Surface 2643 13 3/8 Intermediate 10346 9 5/8 Production -- Liner 796 Perforation depth: measured Cemented Measured depth True vertical depth BKB 148 148 2681 2681 8 c.y. 3840 c.f. 2195 c.f. 7 280 c.f. 10154-10950 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773' 8581-9164 true vertical subsea 8855'- 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2"L-80 to 10073' with 3 1/2" tallpipe to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCM packer at 10073'; 3 1/2" SSSV at 2100' 13. Stimulation or cement squeeze summary see attachment J\ 14. Intervals treated (measured) Treatment description including volumes used and final pressure Fleoresentative Daily Average Production or In!ectioq Data OiI-Bbl gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 950 465 0 1370 1786 26 16. Status of well classification as: Oil X Gas Suspended 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~c'~~vl~ ,/~~ Title orm ' 1627 323 0 249 Service Manager Production Engineering Date SUBMIT IN DUPLICATE WELL W-29 (12-16-11-12~ PBU STIMULATION OPERATIONS A mud acid breakdown treatment was performed February 4, 1989, on the following perforated intervals in Well W-29. 10652' - 10690' MD BKB 10700' - 10714' MD BKB 10725' - 10742' MD BKB 10758' - 10773' MD BKB Prior to the breakdown job a bullheaded HCl/xylene tubing wash was performed. The breakdown was performed as follows: a) c) d) 1000 gal. 12% HCI 2000 gal. 8%HCI - 2% HF 1000 gal. 12% HC1 1000 gal. 12% HC1 (dropped 250 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Steps a-d were repeated three more times, leaving balls out of the final stage, then the treatment fluids were displaced to within 10 bbls. of the top perforation with 84 bbls. dead crude. The well was surged three times to knock the balls off the perforations, then the well was returned to production and tested. jm 3/7/89 BP EXPLORATION HOUSTON ARCO CHEVRON BP ExDloration (Alaska) lng 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES Date: 03-1 3-89 T~: 79875 RESERVOIR REFERENCE: ARCHIVES : BP'CASED HOLE FINAL LOGS The following material is being submlt-~ed herewith. Please acknowledge receipt by signing a copy of this let~rer and returning It to this office: C-29 PITS 02-18-89 #1 11400-11880 Camco C-30 PROD-F 02-22-89 #1 9300-9620 Camco C-31 PITS 02-20-89 #1 11400-11635 Camco F-15 PITS 02-17-89 #1 9100-9650 Camco F-18 INJ 02-23-89 #1 11850-12350 Camco H-29 GLS 02-19-89 #1 SURFACE.8700 ' Camco M-06 PROD-F 02-18-89 #1 11000-11650 Camco S-09 INJ 02-19-89 #1 9850-10245 Camco W-27 PROD-F 02-16-89 #1 11250-11450 Camco W-29 PRO. D-F 02-15-89 #1 10500-10850 Camco Y-06 INJ 02'-17-89 #1 10600-11350 Camco Y-08 GLS 02-16-89 ~ #1 3100-8847 Camco 5" 5" 5': 5" 5" 5" 5" 5" 5" 5" · 51! Rece i ved Date Anchorage Shirley R. McCurry I NFORMAT I ON CONTROL .. Wel I Records LR2-1 Standard Alaska ~ Production Company . 900 East Benson Boulevarct P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION November 30, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well W-29 (12-16-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subseqUent report of perforating the well. Yours very truly, SLB:JAM Attachment (2) cc: L. Burke, MB12-1 Well RecOrds, LR2-1 W-29 Well File (w/10) Peripheral & Minor Reservoirs RECEIVED .~ ' ~!~,aska. 011 & Gas Cons, ,..,,~.. Anchorage-. A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI351ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .... Stimulate . Plugging. Perforate X Pull tubing... Alter casing 2. Name of Operator Standard Alaska Production Company 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311'SNL, 1273'EWL, SEC. 16, T11N, R12Eo UPM At effective depth 2084'SNL, 1195'EWL, SEC. 16, T11N, R12E, UPM At total depth 2057'SNL, 1186'EWL, SEC. 16, T11N, R12E, UPM Repair well Other ..... 5. Type of Well: Development X Exploratory Stratigraphic Service ..... 6. Datum elevation (DF or KB) KBE =, 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU 9. Permit number/approval number 88-71 / 8-785 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 10950feet BKB 9164 feet Plugs (measured) Effective depth: measured true vertical 10908feet BKB 9134feet Junk (measured) Casing Length Structural -- Conductor 110 Surface 2643 Intermediate 10346 Production -- Liner 796 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 148 148 2681 2681 20 8 c.y. 13 3/8 3840 c.f. 9 5/8 2195 c.f. 7 280 c.f. 10154-10950 10652;10690; 10700;10714; 10725'-10742; 10758;10773' 8581-9164 true vertical subsea 8855' - 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 10073' with 3 1/2" tailpipe to 10181' Packers and SSSV (type and measured depth) 9 5,8' Otis HCM packer at10073';3 1/2" SSSVat 210.~, ~ C ~ ~ V ~ ~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 190 229 0 1335 194 Subsequent to operation 1040 693 0 1175 237 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ ! Daily Report of Well Operations X Oil Gas Suspended .... Service 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. J./~, .~'- ~ ~' '-- <F"'~"~- ' ' Form 10-404 R~v 0~'15i88 SUBMIT IN DI~PLI(~ATE WELL W-29 (12-16-11-12) PBU ADD'L, PERFORATION OPERATIONS The following additional intervals were perforated October 14, 1988 using Dresser Atlas 2 I/8" Jumbo Jet Slimkone carrier guns at 4 spf: 10652' - 10690' MD BKB (8855' - 8883' TVDss) 10758' - 10773' MD BKB (8933' - 8944' TVDss) A lubricator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations, then tested. jm 1 1/14/88 Standard Alaskc~ Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5421 STANDARD December 20, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-29 (12-16-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (6) cc: L. Burke (MB12-1) W-29 Well File A. Bragg nager Production Engineering A unit of the ori9inal Standard Oil Company Founded i~ Cleveland, Ohio h~ 1870 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well__ Plugging __ Time extension ~ Stimulate X Change approved program __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840' SNL, 1444' WEL, SEC. 21, T11N, R12E, UPM At top of productive interval 2311'SNL, 1273'EWL, SEC. 16, T11N, R12E, UPM At effective depth 2084' SNL, 1195' EWL, SEC. 16, T11N, R12E, UPM At total depth 2057' SNL, 1186' EWL, SEC. 16, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 10950 feet true vertical BKB 9164 feet 5. Type of Well: Development x Exploratory ~ Stratigraphic__ Service 6. Datum elevation (DF or KB) KBE = 92.40 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-29 (12-16-11-12) PBU Plugs (measured) 9. Permit number 88-71 10. APl number 50- 029-21834 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10908 feet true vertical BKB 9134 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth .. 110 20 8 c.y. 148 2643 13 3/8 3840 c.f. 2681 10346 9 5/8 2195 c.f. 10384 .. 796 7 280 c.f. 10154-10950 measured 10652'-10690', 10700'-10714', 10725'-10742', 10758'-10773' True vertical depth BKB 148 2681 8581-9164 true vertical subsea 8855' - 8944' (four intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 to 10073' with 3 1/2" tailpipe to 10181' Packers and SSSV (type and measured depth) 9 5/8" Otis HCM pack~r at 10073'; 3 1/2" SSSV at 2100' 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended.__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Slgn.ed~. ~4,,~ ~'~~¢~.~ Title ManagerProductionEngineering FOR COMMISSION USE ONLY Con~i~ns of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test__ Subsequent form required 10- ~RIGINAL SIGNED Approved by order of the Commission BY LONNIE C. SMITH I Approval No. ~:~--,. ,~,~ ~ / Commissioner Date /,=2 ..-~..2 ~-~;;~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL W-29 (12-t~.-11-12} PBU STIMULATION , .~).RQPOSAL A mud acid breakdown treatment is proposed ,~'or the following perforated intervals in Well W-29. 10652' - 10690' MD BKB 10700' - 10714' MD BKB 10725' - 10742' MD BKB 10758' - 10773' MD BKB Prior to the breakdown job a bullheaded HC1/xylene tubing wash will be performed. The breakdown will be performed as follows: a) b) c) d) 1000 gal. 15% HC1 2000 gal. 12%HC1 - 3% HF 1000 gal. 15% HC1 1000 gal. 15% HC1 (drop 250 7/8"OD 1.1 SG ballsealers evenly thoughout the fluid Repeat steps a-d three more times, leaving balls out of the final stage, then displace the treatment to within 10 bbls. of the top perforation with dead crude. The well will be surged three times to knock the balls off ti~e perforations, then the well will be returned to production and tested. jm 12/16/88 Production Compo,~ y 900 EQ~ Befl~ofl P.O. ~ 196612 Anchoroge, AIo~Lo 99519-6612 (9071 HOUSTON INDEXED ARCO CHEVRON E,YZON TEXACO STANDARD /'-~,.I_ASK.,A PRODUC TtON Date: 11-04-88 TO: MOBIL r#: 79495 PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signlng a copy of this letter and returning It to this office: A-20 H-14 W-29 TEMP 10-22-88 #1 11100-11400 CAMCO 5" LEAK DET 10-22-88 #1 9000-9650 CAMCO 5" PROD-F 10-22-88 #1 10500-10805 CAMCO 5" '~ ~ ......... Lois Arnold ,-,,~..,~ 0~f'~ Gas Cons. Date ; : ~ChOFaO{~ INFORMATION CONTROL ~ Wel I Records LR2-1 Auml ot Ihe o~'~g~nol $lando,d 0~1 Co.npony Founded in Cle-eland. 0~;o. ,n 1870 Standa,d Alad~a P,od,.,¢t;o,,, Anchorage. Alaska ~519.66 TO: I-iO U S TO ARCO CHEVRON E~XON TEXACO MO B I L PHILLIPS STATE OF ALASKA GEOSC IENCES RES ERVO I R REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS STANDARD ' /.,~..--~ P..._.;t]~.~,_,,Cbt. Date: 10-31-88 r~: 79483 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: B-09 "~ c-i5 ~'~ C-30 ~F-02 -"G-02 '"'" H-08 "~ W-29 ~ W-42 --7 Z-20 ~ ZZ20 FBS/INJ 10-25-88 #3 9550-9923 Sch 5" CNL/GR (2.5" Tool) 10-24-88 #4 9000-9757 Sch 5" CNL 10-22-88 #1 8750-970i Sch 5" PROD i0-23-88 #1 10150-10600 Sch 5" CCL/PERF 10-24-88 #1 8820-9400 Sch 5" CNL 10-23-88 #5 8868-9423 Sch 5" PROD i0-24-88 #1 10550-10895 Sch 5" HP-PRESS Fall-off 10-21-88 #1 9600-9600 Sch CBT 10-22-88 #I 10265-11518 Sch 5" CET 10-22-88 #1 10265-11540 Sch 5" R~:e i ved O~te Oil .& ~as Cons. Commission Founded ,. Cle.elond. 06,o. ,. 1870 Shirley R. McCurry ~ NfORMA% ~ ON CONYROL We( I Records LR2-I Slandatd Alaska Ptoduc tlon Company 9~0 EO~I ~n~.on Boule,,ord P 0 ~. 196612 A,~cho,age. A~&o ~S 19-6612 HOUSTOn,~ ARCO CHEVRON ' E.YXON TEL\CO To: biO B I L REFERENCE: PHI!.I. iPS STATE OF ALASKA GEOSC IENCES R ES ERVO I R ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED _ STANDARD - c :,.;- :~-~[~)1 j(- Fi,~' ,F' ' AL /'..', ........ TI: 79431 The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-11 H-05 K-10 W-29 X-14 Collar 10-14-88 # 1 9600-10 350 Atlas 5" Collar 10-15-88 # 1 11180-11460 Atlas 5" Collar 10-12-88 #1 9400-9960 Atlas 5" Collar 10-14-88 #1 10500-10705 Atlas 5" Collar 10-12-88 #2 11250-11540 Atlas 5" ;~!aska 011 & Gas Cons. Commission Anchorage Received Date Shirley R. McCurry I NFORI~T I ON CONTROL We I I Records LR2- I Standard Alaska ~ Production Company 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 17, 1988 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well W-29 (12-16-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. Yours very truly, SLB:JAM Enclosures (9) cc: L. Burke (MB12-1) W-29 Well File S. L. Bryant, Supervisor Peripheral & Minor Reservoirs 0il & Gas Cons. Commi,~sion Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging !-1 Stimulate [] Pull tubing [] Amend order [] Perforate [] Other I"1 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 840'SN!_, 1444' WE/_, SEC. 21, T11N, R12E, UPM At top of productive interval 2311'SNL, 1273'EWL, SEC. 16, T11N, R12E, UPM At effective depth 2084' SNI_, 1195' EWL, SEC. 16, T11N, R12E, UPM At total depth 2057' SNL, 1186' EWL, SEC. 16, T11N, R12E, UPM 1. Present well condition summary Total depth: measured true vertical 10950 feet BKB 9164 feet Plugs (measured) 5. Datum elevation (DF or KB) KBE . 92.40 AMSL fee t 6. Unit or Property name Prudhoe Bay Unit 7. Well number W-29 (12-16-11-12) PBU 8. Permit number 88-71 9. APl number 5 0 - 029-21834 10. Pool Prudhoe Oil Pool Effective depth: measured 10908 feet true vertical BKB 9134 feet Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 8 c.y. 148 S u rface 2643 13 3/8 = 3840 c.f. 2681 Intermediate 10346 9 5/8 2195 c.f. 10384 True Vertical depth BKB 148 2681 8749 Production -- Liner 796 7 280 c.f. 10154-10950 8581-9164 Perforation depth: measured 10700'-10714', 10725'-10742' true vertical subsea 8890' - 8921'(two intervals) Tubing (size, grade and measured depth) 3 1/2"L-80to 10073'with3 1/2"tailpipe to 10181' Packers and SSSV (type and measured depth) Auchorage 9 5/8" Otis HCM packer at 10073'; 3 1/2" SSS V at 2100' 12. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 3. Estimated date for commencing operation October 1988 14. If proposal was verbally approved Name of approver / / ~? ~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,.~j,.~.~~r~ ~ ~ T itlecommissionSUpervisor, Periphera/&MinorReservoirSuse Only Notify commission so representative may witness [] Plug integrity [] BOP Test Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH --orm 10-403 Rev 12-1-85 Date [] Location clearanceJjAppr°val No. App:'oved Copy Returned /0 "~"~ -~ 2_ by order of Commissioner the commission Date /0~/~/-~ Submit in triplicate WELL W-29 (12-16-11-12~ PBU ADD'L, PERFORATION PROPOSAL We propose to perforate the following additional intervals during October, 1988: 10652' - 10690' MD BKB (8855' - 8883' TVDss) 10758' - 10773' MD BKB (8933' - 8944' TVDss) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to production immediately following perforating operations, then tested. jm 9/27/88 FLOW TUBES & PACKOFF BOWEN PACKOFF ~ J-~-HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE FLOWLINE VALVE GREASE LINE GREASE ,, / MANIFOLD GREASE PUMP RISER -.-GREASE RESERVOIR BOP SCHLUMBERGER WELL SERVICES 500 w. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY LOCATION A'n'ENTION · t,-,,,J,,-,..,;., AL.,-,SKA PR{)[.) CO ..-. 900 · . " ,...,. · i'dAR¥ ,~:,;N WILLIAMS · COMPUTING CENTER PRINT CENTER WELL NAME · SERVICES · NO. OF BOXES: ~.,~" it2.-16-1'1-12) WELL. NAME · 1 GCT FL''~':~ I GCT LIS TAPE SERVICES ' ] GCT' F["L'E~" ii TAPE ] OR[G~NAL + ]6 PHOTOCO;-~S~ OF .[. NO. OF BOXES: JOBNO. · 72889(REDO) JOB NO. ' $;~c;,', ~' :. - ,: ' .... "~''': ADD'L TAPES · -" ADD'L TAPES · 'FTC, .ff~.[....W., ,.S" ' "" '::":'" ':~'' '"'"::: A.[~. ~..~~ N"' :"?"' ''''?: ...; c~,~."..~..:THE ''~:''': "t ~.'. P.R.~ I .J U S '";;"" ' '~/':'":;:'~' ~" ' '"ON~: S. · '..' .'.,c..'"'"'"'"' ........... '"'. WELL NAME · WELL NAME · SERVICES . SERVICES · S U P, V ':: :/ NO. OF BOXES JOB 'NO. ADD'L TAPES NO. OF BOXES: JOB NO. : ADD'L TAPES ' WELL NAME · SERVICES · NO. OF BOXES' WELL NAME · SERVICES · NO. OF BOXES: JOB N'O. · JOB NO. - ADD,L TAPES · SCHLUMBERGER COURIER: ADD'L TAPES ' Slonda~d Ala$~,a "' '~ Production Company 900 EosI Ben,on ~<)uJevo~d P.O ~ 196612 An(ho~oGe, AlonZo ~ 19-66 INDEXED HOUSTON A~CO STANDARD CHEVRON ALASKA PRODUCTION EX]EON Date: 09/06/88 TEXACO 10: Il: 79280 MOBIL PHILLIPS STATE OF ALASKA ARCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following materiel Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of -rhls lel-~er and returning It to -rhis office: B-07 C-06 H-23 H-30 W-24 W-29 W-40 Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient 08/25/88 Camco 08/15/88 Camco 08/25/88 Camco 08/21/88 Camco 08/31/88 Camco 08/26/88 Camco 08/30/88 Camco Race I ved Da're A ue~;! oi the or~g;.o| $londord O,I Compon,f Founded in Cleveland, C~k). ,. 1870 Jennifer Dietz I NFORMAY ~ ON CONYR0[ Wel I Records LR2-1 Standard Alaska Production Compan~ 900 East Benson Boulevard P.O. Bo~ 196612 Anchorage, Alaska 99519-6612 (907) 564-5 ! I 1 INDEXED HOUSTON ARCO CHEVRON EXXON Sl'ANDARD ALASKA PRODUCTION o8/~8/8s Date: TO: TEXACO MARATHON TI: 79219 MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: ARCHIVES SAPC OPEN HOLE FINAL LOGS The following m~terlal Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: DAL/ffNIT/ST.&TE: W-24 W-24 ' "~ W-29 /'~ W-29 W-29 DIL/SFL 08/13/88 BHCS 08/13/88 LDT/CNL poro raw 08/13/88 ~DIL/SFL, 08/10/88 ~BHCS 08/10/88 ~LDT/CNL poro raw 08/10/88 #1 9137-9608 Sch #1 9137-9578 Sch #1 6858-9613 Sch #1 10370-10920 Sch #1 10371-10897 Sch #1 7694-10934 Sch 2 "/5" 2"/5" _~" 2"/5" 2 "/5' 5" ARCO/EXXON/SAPC ONLY: W-24 SSTVD 08/13/88 #1 9137-9616 Sch 1"/2" W-29 SSTVD 08/10/88 #1 10371-10937 Sch 1"/2" STATE ONLY: DIRECTIONAL SURV~YS~9 Di/~cti "l,:~h~, S~r~ - -88 . ,,, AL788-D24 Magnetic Single Shot ey ~, ,~Date: .... 8 OODtf: GyrOscopic Directional ~ate: ~-u JO ~: ~D 8 ~: 6~ I NF~T I 0N C~/R~ Dmte ?~?i~:~--'~ :" ': : ( :~ L:.~ .i Well Rec~ds tR2-1 founded ,n C~*elond. ~,o ~n 1870 '""-"" STATE OF ALASKA ,., · ALASK~ OIL AND GAS CONSERVATION C~,,/IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 88-71 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 so- 029.21834 .... 4. Location ct well at surface 9." Unit or LeaSe Name 840'SNL, 1444'WEL, SEC21, T11N, R12E _ .. _.._ :....1._.._~-LO~AT °I"151 trudhoeBayUnit At Top Producing Interval VERI"'""' I 10. Well Number W-29 (12-16-11-12) 2311'SNL, 4007' WEL, SEC 16, T11N, R12E ~$urf. ir 11. Field and Pool At Total Depth I! B. H. ~ Prudhoe Bay Field/Prudhoe Bay Pool 2057' SNL, 4094' WEL, SEC 16, T11N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE= 92.40' I ADL 28263 12. Date Spudded 13. Date'T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water D'epth, il offshore 116. No. of Completions 7-24-88 8-11-88 8-15-88I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10950'MD 9164' TVD 10908'MD 9134' TVD YES [] NO []I 2100 feet MD I 1942 22. Type Electric or Other Logs Run DIL/SFL, BHCS, LDT/CNL~ Poro Raw 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 8 cu yds Concrete 13-3/8" 68# L-80 Surface 2681' 17-1/2" 3840 cu ft Cold Set III & II 9-5/8" 47# L-80 NSCC Surface 4492' 12-1/4" 9-5/8" 47# L-80 Butt 4492' 10384' 12-1/4" 2195 cu ft Class G 7" 26# IJ4S 10154' 10950' 8-1/2" 280 cu ft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE i DEPTH SET (MD) PACKER SET (MD) S.O.S. 5"@4spf 3-1/2"9.3#L-80 [-' ~0181'MD 10075'MD MD TVDss with Tailpipe 10700;10714' 8890;8900' 26. ACID. FRACTURE, CEMENT SQUEEZE, ETC. 10725;10742' 8909;8921' DEPTH INTERVAL (MD) AMOUNT 8, KIND OF MATERIAL USED ,, 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8-14-88 I Flowing Date gl Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD ~ Flow Tubing CaSing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL'GRAVITY-API (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or w~'d~r. £;uf~mil core chips. . Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. SAG 10352' 8 726' Shublik A 10392' 8754' Zone 4 10554' 88 73' 31. LIST OF ATTACHMENTS 32. I hereby certify that lhe foregoing is true and correct to the best of my knowledge ; .... Signed Title PBU Drillin(~ En~ineerino Suoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 25, 1988 at 0600 hrs · Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 940' Day: 1 48- Hour Ftg: 940' Water Used: 1100 Current Operation: Drill & survey 12-1/4" hole. Accepted rig @ 0600 hours on 7/24/88; spud @ 1530 hours on 7/24/88. Drill & survey 12-1/4" hole to 940'. Mud Type: Spud WT: 9.3 VIS: 180 PV: 29 YP: 50 FL: 9.6 Solids: 11 Temp: 70 ~F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-29 (12-16-11-12) Daily Drilling Report-- PRUDHOE BAY July 26, 1988 at 0600 hrs AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 2430' Day: 2 24- Hour Ftg: 1490 Water Used: 1000 Current Operation: Drilling 17-1/2" hole. Drill and survey 17-1/2" hole to 2430'. Mud Type: Spud WT: 9.6 VIS: 84 PV:22 YP:32 FL: 10.8 Solids: 10 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 27, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 2700' Day: 3 24- Hour Ftg: 270' Water Used: Current Operation: Perform top job. Drill & survey 17-1/2" hole to 2700'. Run & cement 13-3/8" casing. Mud Type: Spud WT: VIS: PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 28, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 2800' Day: 4 24- Hour Ftg: 100' Water Used: 200 Current Operation: Rill to kickoff. NU and test BOP's. Test casing. Drill out and perform FIT. Drill 12-1/4" hole to 2800'. PU mud motor. Mud Type: LSND WT: 9.4 VIS: 38 PV: 14 YP: 7 FL: 18.2 Solids: 6 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 29, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 1206~6 AFE Amount: Current Amount: 0600 Depth: 4111' Day: 5 24- Hour Ftg: 1311' Water Used: 500 Current Operation: Drilling @ 4111'. Mud Type: LSND WT: 9.5 VIS: 34 PV: 9 YP: 5 FL: 13.2 Solids: 7 Temp: CF STANDARD ALASKA PRODUCTION . Rig: AUDI #3 Well: W-29 (12-16-11-12) Daily Drilling Report-- PRUDHOE BAY August 1, 1988 at 0600 hfs AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 7155' Day: 8 72- Hour Ftg: 2544' Water Used: 1200 Current Operation: Wash & ream to bottom. Drill & survey 12-1/4" hole to 7155'. Mud Type: Ligno. WT: 10+ VIS: 36 PV: 13 YP: 7 FL: 5.8 Solids: 12 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 2, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 7870' Day: 9 24- Hour Ftg: 715' Water Used: 1400 Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 7870'. Mud Type: Ligno WT: 10.1 VIS:36 PV: 14 YP: 8 FL: 4.6 Solids: 12 Temp: 76 °F STANDARD ALASKA PRODUCTION Rig: AUDI//3 Well: W-29 (12-16-11-12) Daily Drilling Report -- PRUDHOE BAY August 3, 1988 at 0600 hrs AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 8375' Day: 10 24- Hour Ftg: 505' Water Used: Current Operation: Drilling 12-1/4" hole. Drill & survey 12-1/4" hole to 8375'. Mud Type: Ligno. WT: 10.1 VIS:39 PV: 16 YP: 10 FL:4.6 Solids: 11 Temp: 80°F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 4, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 8854' Day: 11 24- Hour Ftg: 479' Water Used: 1100 Current Operation: Test BOPE. Drill and survey 12-1/4" hole to 8854'. Mud Type: Ligno WT: 10.1 VIS:38 PV: 14 YP: 10 FL: 4.3 Solids: 11 Temp: 106 °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 5, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 9390' Day: 12 24- Hour Ftg: 536' Water Used: 800 Current Operation: Trip for bit. Drill & survey 12-1/4" hole to 9390'. Mud Type: Ligno. WT:10.1 VIS:39 PV:14 YP:ll FL:4.0 Solids:Il Temp: 105CF STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY August 8, 1988 at 0600 hours Rig: AUDI //3 Nell: N-29 (12-16-11-12) AFE// 120646 AFE Amount: Current Amount: 0600 Depth: 10,390' Day: 15 72-Hour Ftg: 1,000' Hater Used: 2411 Current Operation: Cementing 9-5/8" casing. Drill and survey 12-1/4" hole to 10,390'. Run 9-5/8" casing. Mud Type: Ligno NT: 10.2+ VIS' 43 PV: 16 YP' 13 FL: 4.6 SOL' 12 Temp' 75 °F STANDARD ALASKA PRODUCTION . Da~ly Drilling Report -- PRUDHOE BAY August 9, 1988 at 0600 hours Rig: AUDI //3 Hell: N-29 (12-16-11-12) AFE// 120646 AFE Amount: Current Amount: 0600 Depth: 10,530' Day: 16 24-Hour Ftg: 140' Hater Used: 400 Current Operation: Drilling 8-1/2" hole. Cement 9-5/8'" casing. Test casing. Drill 8-1/2" hole to 10,530'. Mud Type' Ligno HT' 9.4+ VIS' 36 PV' ...9 YP 7 FL' 7.8 SOL' 7 Temp' 87°F STANDARD ALASKA PRODUCTION Daily Drilling Report .- PRUDHOE BAY August 10, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 10,950' Day: 17 24- Hour Ftg: 420' Water Used: 300 Current Operation: Logging 8-1/2" hole. · Drill 8-1/2" hole to 10,950'. POH for logs. Mud Type: Ligno WT: 9.5 VIS: 37 PV: 13 YP: 9 FL: 5.2 Solids: 7 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-29 (12-16-11-12) Daily Drilling Report -- PRUDHOE August I1, 1988 at 0600 hfs BAY AFE # 120646 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: 10,950' 18 200 Current Operation: Running liner. Log. Make wiper trip. Run 7" liner. Mud Type: Ligno WT: 9.5 VIS: 36 PV: 13 YP: 8 FL: 5.8 Solids: 8 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-29 (12-16-11-12) Daily Drilling Report-- PRUDHOE BAY August 12, 1988 at 0600 hrs AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 10,950' Day: 19 24- Hour Ftg: Water Used: 100 Current Operation: Pickup BHA. Run and cement 7" liner. Dress off TOL. Pickup tools to clean out liner. Mud Type: Ligno WT:9.5 VIS:38 PV: 11 YP: 10 FL: 12.6 Solids: 1 Temp: STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 15, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 10,950' PBTD Day: 22 72- Hour Ftg: Water Used: 4604 Current Operation: Retrieve dummy valve. Clean out and test 7" liner. Displace to brine. Test casing. Run cased hole logs. Perforate from 10,700'-10,714', 10,725'-10,742'. Run 3-1/2" tubing. ND BOPE, NU and test tree. Mud Type: NaC1 Brine WT: 9.5 VIS: PV: YP: FL: Solids: Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY August 16, 1988 at 0600 hrs Rig: AUDI #3 Well: W-29 (12-16-11-12) AFE # 120646 AFE Amount: Current Amount: 0600 Depth: 10,950' Day: 23 24- Hour Ftg: Water Used: 100 Current Operation: Lay down dummy valve. Set plug in X Nipple. Set and test packer. Test annulus. Displace annulus to 9.6 brine, displace tubing to diesel. Test tubing and annulus. Release rig @ 1800 hrs on 8-15-88. Mud Type: Ligno WT:9.5 VIS:38 PV: 11 YP: 10 FL: 12.6 Solids: 1 Temp: °F GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMPANY COMPANY WEST EILEEN WFJJ~ # W-29 WELL NAME PRUDHOE BAY LOCATION AL788-D24 JOB NUMBER DON LEJEUNE MULTI SHOT SURVEYS 8/09/88 TYPE SURVEY DATE DIRECTIONAL SUPERVISOR ~~~ NAME T I TLE SIGNATURE 400 FT 10320 FT DEPTH INTERVAL FROM TO 7/23/88 8/07/88 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR W~.r. WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ~-f. COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIC~IAL DRILLING, INC 8/9188 Client ............... : STANDARD ALASKA PRC~IUCTION CO. We]] ................ : WEST EIL.EEN g W-29 Ve~tlcol Section at.: N 33.63 W Magnetic Declination: 30 deg 8 min E Data file name ...... : B:WW29D.DAT RECORD OF SURVEY (Well assumed vertical to MD of Computation: RADIUS OF CURVATURE Survey date: 7/28/88 Method ..... : SINGLE SHOT & MWD RKB Height.: 92.4 ft O.O! MEAS DRIFT TRUVERT SUBSEA SECTIL-~ DIRECTION RELATIVE COORDINATES DIST ANGLE 0.00 N 0.00 E 0.19 N SO.O0 E -0.15 N 75.00 E -1.01 N 60.00 E -4.25 S ,1.1.00 W 3EPTH DG MN DEPTH DEPTH 0 0 0 0.00 -92.40 400 0 30 399.99 307.59 900 0 15 899.98 807.58 1410 0 45 1409.96 1317.S6 1910 0 15 ,1.909.94 1817.54 FROM WELL-HEAD 0.00 N 0.00 E 1.12 N 1.34 E 2.62 N 4.22 E 4.32 N 8.32 E 2.30 N 11.14 E CLOSURE DISTANCE E~3 MN S 0.00 N 0 0 0 E 1.75 N 50 0 0 E 4.96 N 58 8 11 E 9.37 N 62 33 19 E 1,1..38 N 78 19 37 E DOG LE( deg/`1.0( 0.00( O. I25 0.05( 0.09~ 0.10( 2410 2735 2873 2966 3058 0 15 2409.94 23~.7.54 0 30 2734.93 2642.53 2 6 2872.89 2780.49 4 24 2965.73 2873.33 6 54 3057.28 296~.88 -6.26 S 69.00 E -8.26 S 0.20 W -7.66 N 38.80 W -2.41 N 36.70 W 6:61 N 41.60 W O.SS N 12.12 E 1. _1.0 S 13.25 E 1.90 S ,1.0.98 E ,_°.27 N 7.76 E 9.29 N 2.04 E ,1.2. ,1.3N 87 25 20 E 13.29 S 85 ].3 S9 E 11.15 S 80 ,1.1 57 E 8.08 N 73 40 S8 E 9.,51 N 12 23 I0 E 0.00( 0. 071 1. '1.6~ 2.47: 2.71~ 3149 9 24 3147.35 3054.95 3246 12 0 3242.66 3150.26 3339 14 36 3333.16 3240.76 3431 17 6 3421.65 3329.25 3524 19 18 3509.99 34:1.7.59 19.35 N 43.70 W 37. ,1.0 N 42.70 W 58.21 N 43.40 W 82.91 N 44.80 W 111.59 N 40.60 W 18.78 N 6.70 W 31.91N ,1.9.03 W 47.54 N 33.63 W 65.58 N Sl.ll W 86.92 N 70.81 W 19.94 N 19 37 S2 W 37..1.5 N 30 48 27 W S8.23 N 35 16 32 W 83.15 N 37 55 56 W ,1.,1.2.11 N 39 9 S7 W 2. 2.68: 2. 2.72: 2.#1~ 3615 21 42 3595.23 3502.83 3678 23 30 3653.38 3560.98 3816 26 30 3778.44 3686.04 3908 28 42 3859.97 3767.57 4006 31 18 3944.83 3852.43 143.22 N 40.60 W 167.20 N 42.30 W 224.80 N 43.00 W 266.93 N 41.60 W 315.43 N 42.00 W 111.12 N 91.54 W 129.26 N 107.57 W 172.15 N 147.08 W 203.68 N 175.76 W 240.20 N 208.42 W 143.97 N 39 28 60 W 168.17 N 39 45 59 W 226.43 N 40 30 3]. W 269.03 N 40 47 33 W 318.02 N 40 56 52 W 2.63' 2.88! 2.17, 2.41' 2.65! 4092 33 42 4017.36 3924.96 4189 36 54 4096.S1 4004.11 4283 39 36 4170.32 4077.92 4563 40 24 4384.82 4292.42 4932 41 0 4664.57 4572.17 361.20 N 40.90 W 416.75 N 41.60 W 474.45 N 40.60 W 653.04 N 40.90 W 892.29 N 38.S0 W 274.83 N 239.00 W 316.97 N 275.96 W 360.82 N 314.21 W 497.16 N 431.69 W 682.29 N 585.38 W 364.22 N 41 0 41 W 420.26 N 41 2 36 W 478.45 N 41 3 0 W 658.43 N 40 58 S W 898.99 N 40 37 43 W 2.81t 3.30~ 2.90! 0.28, 0.32 WEST EILEEN N W-29 8/9/88 RECORD OF SURVEY NEAS DRIFT TRUVERT SUBSEA SECI'ION DIRECTION RELATIVE C~DRDINATES DEPTH DG MN DEPTH DEPTH DIST ANGLE FRL"~t WELL-HEAD 5207 40 18 4873.21 4780.81 1071.04 N 36.30 W 824.59 N 694.18 W SS84 43 0 S154.88 S062.48 1321.1]. N 37.80 W 1024.53 N 845.12 W S957 44 30 S425.76 S333.36 1579.84 N 37.10 W 1230.39 N 1002.80 W 6148 45 42 SSSg. 17 S466 ..... 77 1713 S4 N 36 O0 W 1337 94 N 1082 S2 W 6606 43 48 S884.42 S7~2.02 2035.60 N 36.70 W 15~7.62 N 1273.63 W 7088 41 42 6238.34 6145.94 2362.35 N 36.30 W 1860.61N 1468.23 W 7554 37 6 6598.34 6505.94 2657.81 N 35.60 W 2099.99 N 1641.83 W 7925 38 6 6892.28 6799.88 2884.]0 N 34.60 W 2285.19 N 1771.99 W 8209 40 54 7113..39 7018.99 3064.71 N 32.10 W 2436.06 N 1B71.28 W 8686 38 42 7477.84 7385.44 3369.75 N 30.40 W 2697.06 N 2029.67 W 9066 38 12 7775.44 7683.04 3605.17 N 27.20 W 2904.10 N 2143.49 W 9442 41 18 8064.49 7972.09 3843.51 N 25.10 W 313.9.89 N 2249.43 W 9811 42 42 8338.70 8246.30 4086.69 N 22.30 W 3345.94..N 2348.66 W ]0].40 43 ].8 8579.32 8486.92 4305.66 N 19.80 W 3555.33 N 2429.25 W 10320 43 30 8710.10 8617.70 4425.10 N 17.40 W 3672.54 N 2468.69 W CLOSURE DISTANCE DG 1'41'4 S 1077.89 N 40 S 33. W ].328.12 N 39 31 8 W 1587.28 N 39 10 S1W 1721.03 N 38 58 35 W 2043.16 N 38 33 43 W 2370.14 N 38 ].6 39 W 2665.63 N 38 I 10 W 2891.72 N 37 47 27 W 3071.82 N 37 31 48 W 3375.46 N 36 S7 47 W 3609.48 N 36 25 SO W 3846.25 N 35 47 30 W 4087.98 N 35 4 0 W 4306.00 N 34 20 37 W 4425.15 N 33 54 33 W DOG LE/.[ deg/lO( O. 42( O. 74( 0.41( 0.70: 0.42: O. 43; O. 98.c. O. 28[ 1. OSt O. 48~ 0.34[ O. 86t 0 .SI~ 0.40: 0.64: WEST EILEEN ~ W-29 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 8/9/88 MEAS. TRU VERT SUB SEA ND-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 9o 92 0 0 0 192 192 100 0 0 292 292 200 0 0 392 392 300 0 0 492 492 400 0 0 592 592 500 0 0 692 692 600 0 0 792 792 700 0 0 892 892 800 0 0 992 992 900 0 0 1092 1092 1000 0 0 1192 1192 1100 0 0 1292 1292 1200 0 0 1392 1392 1300 0 0 1492 1492 1400 0 0 1592 1592 ].SOO 0 0 1692 ld92 ].600 0 0 1792 1792 1700 0 0 1892 1892 ].800 0 0 ].992 1992 1900 0 0 2092 2092 2000 0 0 2192 2192 2100 0 0 2292 2292 2200 0 0 2392 2392 2300 0 0 2492 2492 2400 0 0 2592 2592 2500 0 0 2692 2692 2600 0 0 2792 2792 2700 0 0 2893 2892 2800 1 1 2993 2992 2900 I 0 RELATIVE COORDINATES FROM WELL-HEAD 0.09 N ' 0.02 W 0.37 N O. 16 W 0.75 N 0.58 W 1.10 N 1.27 W 1.64 N 1.91 E 2.19 N 2.41 E 2.72 N 2.81 E 3.21 N 3.10 E 3.67 N 3.30 E 2.76 N 4.67 E 2.97 N S.32 E 3.28 N 6.11 E 3.69 N 7'.04 E 4.22 N 8.12 E 4.98 N 9.08 E S.97 N 9.52 E 6.89 N 9.41 E 7. S4 N 8.88 E 7.78 N 8.12 E 1.94 N 11.12 E 1.52 N 11.19 E 1.13 N 11.39 E 0.80 N 11.68 E 0.57 N 12.05 E 0.46 N 12.S1 E 0.52 N ].3.12 E 0.81 N 13.78 E 1.80 S 13.64 E 1.28 S 10.48 E 4.04 N 6.40 E WEST EILEEN ~ W-29 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 8/9/88 MEAS. TRU VERT SUB SEA ND-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3093 3092 3000 1 0 319S 3192 3100 3 2 3297 3292 3200 S 2 3401 3392 3300 9 4 3SOS 3492 3400 13 4 3612 3S92 3S00 20 7 3721 3692 3600 3832 3792 3700 40 11 394S 3892 3800 S3 13 4062 3992 3900 70 4184 4092 4000 92 22 4312 4192 4100 120 28 4442 4292 4200 1SO 30 4573 4392 4300 181 3]. 470S 4492 4400 213 32 4837 4S92 4S00 24S 32 4969 4692 4600 277 32 SIO0 4792 4700 308 31 S233 4892 4800 341 33 S367 4992 490Q 37S 34 SSO0 S092 SOOO 408 33 S636 S192 S100 444 36 S774 S292 S200 482 38 S913 S392 S300 S21 39 6053 S492 S400 S61 40 619S SS92 SSO0 603 42 6336 S692 S600 644 41 6476 S792 S700 684 40 6617 S8.~ S800 72S 41 67S3 S992 S900 76]. 36 RELATIVE C~DRDINATES FRC~ WELL-HEAD 12.68 N ' 1. O1 24.S2 N 12.23 40.1S N 26.68 S9.36 N 44.99 81.41 N 67.78 110.27 N 90.82 142.18 N 1].9.36 177.32 N 151.91 2].7.32 N 187.91 262_34 N 228.61 314.71 N 273.95 W 374.77 N 326.18 W 438.22 N 380.75 W S02.06 N 43S.94 W S66.36 N 492.61W 630.08 N SS0.49 W 701.07 N 600.40 W 767.61 N 6S4.91 W 838.00 N 704.0S W 908.38 N 7S6.4S W 979.6]. N 1052.56 N 1127.60 N 1203.].4 N 1283.26 N 810. SI. W 866.90 W 92S. S9 W 98S.21 W · . 1043.18 W ].364.97 N 144S.64 N 1S2S.27 N 1603.6S N 1678.68 N 1102.19 1161.19 1219.89 1278.12 1334. ].9 WEST EILEEN ff W-29 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 8/9/88 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF_ CORRECT 6889 6092 6000 797 36 702S 6192 6100 833 36 71S8 6292 6200 866 33 7287 6392 6300 89S 2~ 74].7 6492 6400 92S 30 7S46 6S92 6S00 9S4 29 7673 6692 6600 98]. 27 7799 6792 6700 1007 26 792S 6892 6800 1033 26 80SS 6992 6900 1063 30 8184 7092 7000 1092 29 8314 7192 7100 1122 30 844 S 7292 7200 1153 31 8S7S 7392 7300 1183 30 870S 7492 7400 1213 30 8832 7S92 7S00 1240 27 8960 7692 7600 1268 28 9088 7792 7700 1296 28 92].8 7892 7800 ].326 30 9348 7992 7900 13S6 30 9480 8092 8000 1388 32 9614 8].92 8].00 1422 34 9749 8292 8200 14S7 3S 9884 8392 8300 1492 3S 10021 8492 8400 1S29 37 101S8 8S92 8S00 1S66 37 10296 8692 8600 1604 38 RELATIVE COORDINATES FROM WELL-HEAD 17S2.79 N 182S. 9S N 1897.8S N 1965.24 N 2030.68 N ' 1389.78 W 1444.90 W 149S. 64 W 1S4S. S1 W 1S94.30 W 2094.1S N 2].S8.32 N 2220.S4 N 228S.27 N 23S1.S7 N 1641.9S W 1683.84 W 1729.19 W 1772. OS W 1818.77 W 2418.73 N 2494.13 N 2S64.70 N 2634.02 N 2707.08 N 1868.10 W 1907.98 W 19S3.30 W 1998.63 W 203S.S6 W 277S.28 N 2842.4S N 2916.26 N 2988.62 N 3062.1S N 2076.69 W 21].8.9S W 2149.7S W 2187.72 W 2227.48 W 3142.34 N 3222.86 N 3303.48 N 3391.98 N 3477. S1 N 2280.02 W 2299.11 W 2340.02 W 2367.81 W 2404.78 W 3S66.94 N 36SS.24 N 2433.46 W 2467.28 W WEST EILEEN ~ W-29 DATA INTERPOLATED FOR EVEN 1000 FEET OF NEASURED DEPTH 8/9/88 NEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE C~3RD]NATES FRON WELL-HEAD 6000 S4SS S363 12S3.33 N 1020.22 7000 6173 608]. 1812.36 N 143~.6S 8000 69SI 68S9 2323.44 N 1798.71'W 9000 7724 7632 2863.29 N 2132.42 10000 8477 838S 3464.29 N 2398.94 1000 1000 908 2.77 N 4.72 E 2000 2000 1908 1.91N 11.12 E 3000 3000 2908 4.55 N 6.00 E 4000 3940 3848 237.89 N 206.34 W SO00 471& 4124 717.01 N 613.27 W 500 t§O0 2000 VERTZCAL SECTION STANDARD ALASKA PRODUCTION CO. NEST EILEEN # N-29 SECTION AT N 33.63 N TVD SCALE: 1 inch = lO00 feet DEP SCALE: t Inch = lO00 feet DRANN : 819/88 14arker Identtftcatton HD TVD DEPRT 4} KOP 0 0 0 B) TO t0320 B7iO 4425 2500 30OO 3500 T 4000 4500 D 5000 5500 6000 6500 700O 7500 8500 9000 -500 0 500 t000 i500 2000 2500 3OOO Departure 3500 4000 4500 5000 5500 Rarker Identification HD TYD DEPRT A) KOP 0 0 0 B) TD i0320 BTiO 4425 HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. NEST EILEEN # W-29 CLOSURE: 4425 fL N 33.9 N DECLINATION: 30.i3 dec E SCALE: I inch = ~000 feel BRAWN: 8/9/88 6500 6000 5~00 5000 4500 4000 35OO 3000 2500 2000 1500 iO00 500 500 §500 5000 4500 4000 3500 3000 2500 2000 i500 tO00 500 ~00 ~1 TELE£D 1 Teleco Oiifield Se, ; of Alaska Inc. / 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 August 12, 1988 JOB #642 STANDARD ALASKA PRODUCTION CO. WELL: W.- 29 EILEEN WEST END RIG: AUD #3 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportUnity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures A ,~lil,'l' COMPANY Date 08/07/88 Company: Well: Location: Rig: TELECO OILFIELD SERVICES JOB# 642 SURVEY CALCULATIONS STANDARD ALASKA PRODUCTION W - 29 WEST EILEEN ALASKA UNITED DRILLING INC. Page 1 TELECO Job # 642 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 326.37 degrees N 33 38 W RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE INTO GREATLAND SINGLE SHOT 2735.00 0.5 180.2 S 00 12 W 2734.93 -7.61 0.73S 12.64E 12.66 S 86.680E 0.146 2873.00 2.1 321.2 N 38 48 W 2872.89 -7.01 1.52S 10.37E 10.49 S 81.635E 1.818 2966.00 4.4 323.3 N 36 42 W 2965.73 -1.76 2.64N 7.15E 7.62 N 69.721E 2.476 3058.00 6.9 318.4 N 41 36 W 3057.28 7.25 9.66N 1.43E 9.77 N 8.444E 2.765 3149.00 9.4 316.3 N 43 42 W 3147.35 19.99 19.15N 7.30W 20.49 N 20.878W 2.766 2410.00 0.2 111.0 S 69 00 E 2409.94 -5.61 0.92N ll.51E 11.54 N 85.430E 0.000 TELECO MWD SURVEYS TELECO Job # 642 TAK 08/07/88 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 3246.00 12.0 317.3 N 42 42 W 3242.66 37.74 32.27N 19.63W 37.77 N 31.308W 2.687 3339.00 14.6 316.6 N 43 24 W 3333.15 58.85 47.91N 34.23W 58.88 N 35.548W 2.801 3431.00 17.1 315.2 N 44 48 W 3421.65 83.55 65.95N 51.72W 83.81 N 38.103W 2.749 3524.00 19.3 319.4 N 40 36 W 3509.99 112.23 87.29N 71.41W 112.78 N 39.285W 2.753 3615.00 21.7 319.4 N 40 36 W 3595.22 143.86 lll.50N 92.13W 144.64 N 39.569W 2.637 3678.00 23.5 317.7 N 42 18 W 3653.38 167.85 129.64N 108.16W 168.84 N 39.838W 3.039 3816.00 26.5 317.0 N 43 00 W 3778.44 225.44 172.53N 147.67W 227.10 N 40.560W 2.184 3908.00 28.7 318.4 N 41 36 W 3859.96 267.57 204.05N 176.35W 269.70 N 40.835W 2.493 4006.00 31.3 318.0 N 42 00 W 3944.83 316.07 240.58N 209.01W 318.69 N 40.983W 2.661 4092.00 33.7 319.1 N 40 54 W 4017.35 361.84 275.21N 239.59W 364.89 N 41.042W 2.874 4189.00 36.9 318.4 N 41 36 W 4096.51 417.39 317.35N 276.55W 420.94 N 41.070W 3.325 4283.00 39.6 319.4 N 40 36 W 4170.32 475.09 361.20N 314.80W 479.13 N 41.074W 2.947 4563.00 40.4 319.1 N 40 54 W 4384.81 653.68 497.54N 432.28W 659.10 N 40.985W 0.294 4932.00 41.0 321.5 N 38 30 W 4664.57 892.94 682.66N 585.97W 899.67 N 40.642W 0.454 5207.00 40.3 323.3 N 36 42 W 4873.21 1071.64 824.59N 695.27W 1078.59 N 40.137W 0.496 5584.00 43.0 322.2 N 37 48 W 5154.88 1321,66 1024.01N 846.91W 1328.85 N 39.593W 0.742 5959.00 44.8 322.9 N 37 06 W 5425.08 1581.10 1230.42N 1005.01W 1588.71 N 39.242W 0.497 ,' TELECO Job # 642 TAK 08/07/88 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 6148.00 45.7 324.0 N 36 00 W 5558.14 1715.14 1338.25N 6606.00 43.8 323.3 N 36 42 W 5883.39 2037.20 1597.93N 7088.00 41.7 323.7 N 36 18 W 6237.31 2363.95 1860.92N 7554.00 37.1 324.4 N 35 36 W 6597.31 2659.41 2100.30N 7925.00 38.1 325.4 N 34 36 W 6891.24 2885.69 2285.50N 8209.00 40.9 327.9 N 32 06 W 7110.36 3066.30 2436.37N 8686.00 38.7 329.6 N 30 24 W 7476.81 3371.34 2697.37N 9066.00 38.2 332.8 N 27 12 W 7774.41 3606.77 2904.41N 9442.00 41.3 334.9 N 25 06 W 8063.46 3845.11 3120.19N 9811.00 42.7 337.7 N 22 18 W 8337.67 4088.29 3346.25N 10140.00 43.3 340.2 N 19 48 W 8578.29 4307.26 3555.64N 10320.00 43.5 342.6 N 17 24 W 8709.07 4426.69 3672.84N 1084.95W 1722.80 1276.05W 2044.92 1470.65W 2371.89 1644.25W 2667.36 1774.41W 2893.44 1873.70W 3073.54 2032.08W 3377.16 2145.90W 3611.17 2251.85W 3847.91 2351.08W 4089.62 2431.66W 4307.62 2471.11W 4426.75 N 39.032W 0.631 N 38.610W 0.429 N 38.319W 0.439 N 38.056W 0.992 N 37.825W 0.316 N 37.562W 1.134 N 36.993W 0.515 N 36.459W 0.540 N 35.818W 0.898 N 35.092W 0.634 N 34.368W 0.549 N 33.933W 0.923 TELECD Q i 1 ~ i ~ id S~rv i c~s PLAN ViEW ~/E~T (~) 6400 ' i 4800 2400 4000 1600 8OO 4000 -.r- i- 2400z 1600 8O0 BO0 800 VERTi Ct~,L PROJECTION -I000 2000 5000 4O0O 5000 W 6000 > 7000 0 !OOO 2000 5000 4000 5000 i I 8000 ,~7 VERTICAL SECTION (~t) ~UB. SURFACE DIRECTIONAl. SURVEY [~UIDANCE [~ONTINUOU$ [~]OOL 'C, omp~y STANDARD ALASKA PRODUCTION COMPANY II m mi i W~J N~mo w~,2,9 !12-16-11-12) (840' SNLI1444' WELrSEC 21tTllN,R12E) FIeIJI/LOJJatIorIPRUDHOE...B.AY, NORTH SLOPEm ALASKA , Job Reference No. Date. 72889 14-AUG-88 ~ Comeuted SCHWARTZ STEVENS * $CHLUM6ERGgR * GCT DIRECTIC)NAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUCTION CO. W-29 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 14-AUG-B8 ENGINEERS SCHWARTZ METHODS OF C~.]MPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAl, SECTIO~: H[]RIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH STANDARD ALASKA PRODUCTION CO. W°29 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE~ 07-0CT-88 ~PAGE 1 DATE OF SURVE¥I' t4-AUG*Sa KELLY BUSHING EbEVATXONI 92,40 :rT ENGINEER l SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET Of' ~4EASURED DEPTH TRUE SUB-SEA COURSE: ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0 O0 100 O0 2OO O0 300 O0 4OO O0 500 O0 600 O0 700 Oo 800 O0 900 O0 0,00 100 O0 200 O0 3O0 O0 399 99 499 99 599 99 699 98 799i98 899 97 -92.40 0 0 N 0 0 g 7.60 0 18 $ 12 }~ W 1.07.60 0 8 S 5352 E 507,59 0 32 a 77 29 F 607,58 0 31 N 80 41E 707,58 0 30 N 83 42 E 807.57 0 31 N 84 11E 1000 O0 1100 O0 1099 200 300 oo oo ° O0 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1699 O0 1799 999 97 907,57 96 1007,56 95 1107,55 95 1207.55 94 1307,54 94 1407,54 94 1507 54 94 1607i54 94 1707 54 O0 1899,94 1807,54 o 34 N 70 27 E 0 44 N 73 33 E 0 41 N 64 52 E 0 36 N 52 46 E 0 31 N 44 4 E 0 24 N 41 56 E 015 N 35 5 E o 11 N 40 46 E 0 1 N 83 46 w 0 14 S 66 27 E 2000 O0 1999 93 19o7,53 21 2300 2400 2500 2600 2700 2000 2900 O0 2099 O0 2199 O0 2299 O0 2399 Oo 2499 O0 2599 O0 2699 O0 2799 VERTICAL DOGLEG RECTANGULAR COORDINATES HORXZ,, SECTION SEVERITY NORTH/SOUTH EAST/WEST DI~T FEET DEG/IO0 FEET FEET FEET O0 2899,88 2807,48 30OO 3100 3~00 3300 3400 3500 3600 3700 3800 3900 0 O0 0,00 0,00 N -0~16 0,00 0,25 S -0i48 0,31 0 61S -0 75 0.74 0:73 S '1,05 0 26 0,52 S -1 31 0:23 0.25 S -1:65 0.14 0.06 S '2 O1 0,00 0,12 N '2~41 0,00 0,24 N -2;83 0.10 0,35 N 0 29 0~16 0 O0 0 23 0 O0 0 05 0 O0 0 32 0 12 0,00 DEPARTURE ' ,DEG 'l 50 , B 64 N 6,50 N ~,90 lO,O0 10.83 ti,99 12,34 12,40 12,53 N 58 12,87 14.79 15~36 15,8{ ~ 54 16,18 57 15,52 9o 9e -3 13 -3 77 -3 85 -3 72 -3 53 6 :I -3. 7 0 17 S 69 41E -3.75 93 2007,53 0 25 S 78 29 E -4,22 93 2107,53 0 25 S 77 12 E -4,76 93 2207,53 0 25 S 81 44 E -5,29 92 2307,52 0 17 S 80 48 E '5.69 92 2407,52 0 18 S 70 52 E '6,06 92 2507,52 0 14 $ 52 8 E '6,48 92 2607,52 0 6 S 29 I E '6 80 92 2707,52 0 7 S 84 58 E '7:05 2 57 N 36 39 W -4.95 0,00 0,01 0,04 0,15 0,07 0,05 0,00 0,45 0,58 2, 0,55 N 0,88 N 1,32 N 1,90 N 2 54 N 3:14 N 3,58 N 3.89 N 4.01 N 3.88 N oo . . , , 13 38 43 51.25 76 44 O0 3851,78 3759,38 28 51 42 26 W 77 0.00 g 0,08 W 0,05 W 0,25 E I,~3 E 1. 9 E 2 90 E 3 8O E 4 72 E 5 63 E 6,48 7,58 8,80 10, 11,10 11 44 11:71 11,74 11,91 3,70 N 3,52 N 3,36 N 3,25 N 3.16 N 3,04 N 2,82 N 2,55 N 2,37 N 48 4,03 N 93 ~,88 1~ 88 4 ,47 . 2 O1 65,22 N 40 83 87,25 N 62 86 113,18 N 85 53 141,84 N 111 50 172,82 N 140 44 206,88 N 172 12.33 E 66 E 14 43 E 15 03 E 15 52 E i5 94 E 16 10 E 16 29 E 14,99 E STANDARD ALASKA PRODUCTION CO, PRUDHOE BAY NORTH SLOP£~ ALASKA COHPUTATION DATE~ 07-0CT-88 INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB-SEA COURSE NEASURED YERTICAb VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH PEG MZN D~G NIH VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 4000 oo 3938.32 3845,92 31 21 4100 oo 4022 32 3929,92 34 18 4103:43 4011,03 37 35 420O 43OO 44O0 4500 4600 47O0 48OO 4900 O0 O0 4181 20 4088,80 39 57 O0 4257:14 4164'74 40 51 O0 4333.12 4240.72 40 21 O0 4409.22 431.6.82 40 .42 O0 4485 O0 4392,b0 40 42 O0 4560:78 4468,38 40 43 O0 463604! 4544,01 40 54 317,29 2,93 370 98 3,10 429:01 3,13 491,14 2,20 555.59 0.50 620,02 0,13 &84.35 1.09 749,14 0 60 814,02 0:33 879,09 0.46 5200 53 5500 5600 5700 5800 59OO O0 4711 8b 4619,46 41 0 O0 4787 31 4694.91 40 56 O0 4863 17 4770,77 40 30 O0 4939 04 4846.64 40 54 5014 14 4921 74 41 41 ~ 5088 28 4995:88 42 0 O0 5161,65 5069,25 42 58 O0 5234,46 5142,06 43 31 O0 5306,66 5214,26 43 58 O0 5378,28 5285,88 44 35 N 39 8 W 944 41 N 38 50 W 1009 76 N 38 16 W 1074 67 N 38 17 W 1139 61 N 38 17 W 1205 41 N 38 9 W 1272 30 N 38 6 w 1340 04 N 37 56 W 1408 38 N 37 41W 1477,38 N 37 27 W 1547,01 0 47 0:52 0,59 1.16 1,01 0,29 0.41 0,75 0.41 0.71 6000 O0 5449 18 5356,78 45 7 6t00 O0 5519 43 5427.03 45 35 6200 O0 5589 22 5496,82 45 42 630O 6400 , o§ 68O 6900 O0 5659 O0 5730 O0 5801 O0 5873 O0 5946 O0 6019 O0 6092 55 5567.15 45 0 41 5638,01 44 42 78 5709,38 44 12 70 5781,30 43 47 13 5853.73 43 21 15 5926,75 42 55 57 6000.17 42 35 N 37 5 W 1617.39 N 36 31 W 1688,45 N 36 9 ~ 1759,99 N 36 29 W 1831 O0 N 36 53 W 1901 45 N 37 9 W 1971 37 N 37 32 w 2040 70 N 37 59 W 2109 47 N 38 11 W 2177 60 N 38 6 W 2 45 28 0.72 0,63 0,63 0,42 0,35 0,44 0,56 0,27 0,28 0,35 7000 O0 6166,40 6074.00 42 11 7100 O0 6240,88 6148,48 41 32 O0 6316. .24 6299.84 39 53 7200 7300 7400 7500 7600 77OO 7800 7900 03 6223.63 40 55 O0 6392 O0 6469,50 6377.10 38 46 O0 6548.21 6455.81 37 29 O0 6627 93 6535.53 36 48 O0 6707:86 6615.46 37 6 O0 6787.43 6695.03 37 31 00 6866.46 6774.06 38 6 N 37 7 W 2444 N 36 58 w 2509,60 N 36 25 W 2573,00 N 36 18 W 2634.61 N 35 52 w 2694,92 N 35 21 W 2754.98 N 34 59 W 2815.52 N 34 51W 2876.78 0 95 0i69 0 90 0.66 1,64 0,94 0.50 0.36 0.66 0.88 RECTANGULAR COORDINATES HORIZ', DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET FEET FEET D~G MIN 243,99 N 206,08 W 319,38 84 4 N 24 ! N ]7 ,59 13 ~ 43 ,18 4l 44 375,22 ~ 322 71 ~ 494,90 423.95 N 365 81 ~ 559,~ ~ 4¢ 4½ W 472.78 N 408 74 W 624, 521 51 N 535,42 W 672 O0 N 577 01 W 885 , , 3 39W 773.86 659.80 1016, 824.80 700.44 . . oe2.o. . 20 w 875,98 740,73~ 1~470~8 N 40 13 927079 1087,95 907,35 1416,66 1142,6! 949,77 ~ 1485,~1 1197,92 N 992,34 . 1555.55 1311.00 1077,72 1538,49 - 1246,56 1980,t2 N 125".69 2049.56 8 57 1330,93 21%8,50 1702,02 1373,07 2186,82 1808,61 1456 46 2322,15 8 1496 96 ~914 20N 1536 76W 2454.75N 38 84 52 2016 81N 1613 75 "2582 96 38 2066 48 1650 32 2644 60 N38 W 2164 13 1720 86 . 2764 92 STANDARD AbASKA PRODUCTION CO, W-29 PRUDHOE BAY NOR?H SLOPE~ AbA~KA COMPUTATION DATEI 07-0CT-88 DATE OF SURVEY1 14-AU~-8~ KEbb¥ BUSHING EbEVATXONI 92,40 FT ENGINEERI $,CHgAR~Z 8000 O0 6944,72 6852,32 38 57 8100 O0 7021 84 6929 44 40 4 7005:41 8200 830O 8400 8500 8600 700 80O 8900 O0 7097.81 40 57 O0 7173,07 7080.67 41 17 O0 7248.59 7156.19 40 40 O0 7324 83 72]2,43 39 55 O0 7401:91 7309,51 39 13 O0 7479175 7]87,35 ]8 34 O0 7558,31 7465,91 37 54 O0 7637,17 7544,77 38 3 N 34 35 W 2939,01 N 34 18 W 3002'66 N 33 3 W 3067~69 N 32 6 W 3133,52 N 31 bO w 3199,04 N 31 40 W 3263.72 N 31 34 W 3327,39 N 31 0 w ~390 1! N 30 12 W ~451:89 N 29 30 W 3513,26 9000 O0 7715,90 7623,50 38 4 9100 oo 7794,51 7702,11 38 27 O0 .26 7779,86 39 33 7872~74 7856,34 40 26 92 9400 9500 9600 9700 9800 9900 O0 7948 O0 8024 50 7932 10 41 5 O0 8099 68 8007:28 41 23 O0 8174 65 8082,25 41 30 O0 8249 32 8156,92 41 54 O0 8323 34 8230,94 42 36 O0 8396 51 8304,11 43 13 N 29 3 w 3574 73 N 27 30 W 3636:28 N 26 46 W 3698,76 N 26 28 W 3762.69 N 25 57 w 3827.42 N 25 26 W 3892,73 N 24 41W 3958,17 N 23 28 W 4023.75 N 22 54 W 4089 88 N 22 26 W 4156:80 10000 10100 10200 10900 O0 8469 28 8376.8U 4] 20 O0 8542:08 8449,68 4:3 12 O0 8614 96 8522.56 43 6 O0 8687 84 8595,44 43 24 O0 8760 16 8667,76 43 49 O0 8832 93 8740 5] 42 3! O0 8907 03 3814:63 42 9 O0 8980 83 8888,43 42 32 O0 9054 36 R061,96 42 50 O0 9127,76 9035,36 42 50 N 21 39 W 4224.03 N 20 43 W 4291.03 N 20 1W 4357,62 N 18 26 W 4424,02 N 17 23 W 4490,39 N 17 43 W 4556,28 N 18 33 W 4621,00 N 18 54 W 4686,21 N 19 6 W 4751,79 N 19 5 W 4817.53 10950,00 g164,42 g072,02 42 50 N 19 5 W 4850,45 DEPARTURE AZIMUTH DEG NXN 1,25 1,30 1,25 O,b7 0,57 0,99 0,97 0,65 0,94 0,21 FEET FEET ~315.04 ! 1826.26 ~ 2948.6 i421.59 1890,42 ~ 3077.0, 3272 13 641.97 2036 02 ~ 3335 4? 0,65 1,41 1,69 0,61 0.55 0,56 O,q3 0,94 0,70 0,91 2855,90 N 2361 O0 W 3581 2910,32 N 2190 30 ~ 364 2 2966 32 N 2218 93 W 3704 3023,90 N 2247 81 W 3767 3082,48 N 2276 61 ~ 3832 3141.88 N 2305 23 W 3896 , 241 , 44 N W 42 N 36 ~ 84 N 36 W ~6 16 W 86 N 35 28 0,72 1.05 3514,72 N 2463 1,08 3578,86N 2487 1,56 3643,57 N 2510 1,21 3709,26N 2531 1,64 3774 66 N 2552 0,75 3838:46 N 2572 0,34 3902,37 N 2594 0.87 3966.44 N 26~ 0,00 4030,63 N 26 38 03 w 4556 97 W 4621 63 W 4686 70 W 4751 92 W 4817 82 N 24 W 66 N 12 W 0,00 4062,76 N 2650,04 W 4850,65 N 33 6 W STANDARD ALASKA PRODUCTION CO, DHOE BAY NORTH SEOPE, ALASKA COMPUTATION DATE: O?-OCT-88 DATE OF SURVE¥I 14-AUG-88 K£LL¥ BUSHZNG EbEVATIONI 92,40 ~T ENGINEERI SCHWARTZ INTERPOLATED VAEUES FOR EVEN 1000 FEET OF' MEASURED DEPTH TRUE SUB-SEA COURSE ~EASUR~D VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG 0 O0 tO00 20OO 3OO0 4000 5000 6000 7000 8000 9000 0,00 '92,40 0 0 O0 999.97 907,57 0 34 O0 1999.93 1907.53 0 17 O0 2999,61 29()7,~1 5 25 O0 3938,32 3R45,92 31 21 O0 4731,86 4619,4b 41 0 O0 5449.18 5356.78 45 7 O0 6166,40 0074.00 42 I1 O0 6944,72 6852,32 38 57 O0 7715,90 7623,50 38 4 10000,00 8469 28 8376.88 43 20 10950.00 9164:42 9072.02 42 50 VERTICAL DOGhEG RECTANGULAR COORDINATES HORIZ, SECTION SEVERITY NO~TH/SOUTH EAST/~ES~ DIST, FEET DEG/IO0 FEET FEET FEET N 0 0 E 0.00 n 70 27 E '3.13 $ 69 41E '3.75 N 37 52 W 2 26 N 41 56 W 317:29 N 39 8 W 944.41 N 37 5 N 1617,39 N 37 ~5 W 2312,54 h 34 35 W 2939.01 N 29 3 w 3574.73 N 21 39 W 4224 03 N 19 5 N 4850:45 DEPARTURE AZ:TMUTH DEG 0.00 0.29 0 O0 2,9] 0.47 0.72 0.95 1,25 O,b5 0,00 0,55 N 6.48 E 6 3,70 ~ 12.33 E 12 9 88 N 10,78 E 14 243:99 N 206,08 ~ 319 722 82 N b18,55 W 95! 1254:01N 1035.08 W 1626 ~808:61N 1456'46 W 2322 2315 04 N 1826,26 W 2948 ~855,90 N 2{61,00 W 358{ 0,00 E 0 O0 N 0 0 E N7 l?6E N 38 32 ~8 16 W 35 N 3? 6 W 0.72 0,00 STANDARD ALASKA PROPUCTION CO, PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE= 07-0CT-88 INTERPObATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATfON AZIHUTH DEPTH DEPTH DEPTH DEG HIN DEG 0 00 40 292 40 392 41 49? 41 597 41 692 42 792 42 892 4.3 0 00 -92,40 0 0 N 0 0 g 92:40 0,00 0 18 S 15 12 w 192,40 !00,00 0 8 S 43 39 E 92,40 200,00 0 17 S 72 5 F: 92.4(.) 300,00 0 35 N 69 7 E 492.40 400,00 0 30 N 75 53 E 592 40 500.00 0 31 N 77 31 g 692~40 600'00 0 31 N 80 2 E 792;40 700.00 0 30 N 83 14 E 892,40 800.00 0 31 N 84 4 E 992 43 992 40 900,00 1092 44 1092 40 1000,00 45 1192 40 1100,00 1200.00 692 792 1892 45 1292 46 14 46 1592 46 1692 46 1792 46 1892 0 33 N 69 27 E 0 43 N 73 41 E 0 42 N 65 26 E 40 0 37 N 54 6 E 40 1300,00 0 31 N 43 55 E 40 1400,00 0 25 N 42 34 E 40 1500,00 0 15 N 33 46 E 40 1600,00 0 12 N 43 50 E 40 !700,00 0 1 N 64 26 W 40 1800,00 0 14 S 66 52 E 1992 2092 2192 292 392 2492 2592 2892 47 1992 40 1000,00 47 2092 40 2000,00 47 2192 40 2100,00 47 2292 40 2200,00 48 2392 40 2300,00 48 2492 40 2400,00 48 2592.40 2500.00 48 2692 40 26U0.00 48 2792i40 2700.00 51 2892 40 2HO0.O0 VERTICAL DOGbEG SECTION SEVERITY FEET DEG/IO0 2992 3093 42 3194 3297 3400 3505 3612 3721 3832 3946 0,00 0,00 '0,t3 0,07 -0.47 0,29 '0,71 0,56 '1.04 0,22 -1.29 0,13 '1,62 0,06 -1,98 0,00 '2,38 0,04 '2,80 0,06 -3 4 -3 '76 -3 86 -3 73 =3 55 -3 37 -3 26 -3,16 -3.34 0 16 S 68 52 E '3,72 0 24 S 77 3 E '4,18 0 25 S 76 50 E '4,72 0 25 S 81 36 E -5,25 0 17 $ 81 42 E -5 66 0 18 S 72 14 E '6' ,03 0 13 S 54 I E '6,45 0 7 S 19 14 E -6 79 0 6 S 64 0 E -7' ,04 2 46 N 37 54 W -5.33 76 2992 40 2900,00 5 12 3092:40 3000.00 7 54 78 3192.40 3100.00 10 44 10 3292.40 3200.00 13 ]2 69 3392.40 3300.00 16 39 86 3492,40 3400,00 19 12 62 3592 40 3500.00 21 51 50 3692:40 3000.00 24 40 71 ]792.40 3700.00 27 13 64 3892.40 3800.00 29 59 N 37 16 w 1.57 N 42 7 w 12.96 N 43 3 W 29,27 N 43 19 W 50.57 N 44 41 W 77.12 N 42 22 ~ 109,11 N 41 30 ~' 146,10 N 43 35 W 188,58 N 42 58 W 236,52 N 42 10 W 290,42 0 31 0,02 0,27 0,00 0,15 0,00 0,22 0,18 0,O0 0 oO 0i08 0 15 0 O6 0,16 0,11 0,00 0,69 0,62 2,68 ,76 ,25 2,87 2,68 4,07 2 71 2 91 2 43 2 50 2 42 RECTANGULAR COORDINATES HORIZ, DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET FEET FEET DEG 0,00 0,21 0,60 0.72 0,54 0,27 0,07 0,11 0,24 0,34 0,00 E 0,07 W 0,06 W 0,21 E 1,06 E 1 93 E 2 83 E 3 73 E 4 65 E 5 56 g 0,53 N 0,86 N 1,28 N 1,85 N 2,49 N 3,10 N 3,55 N 3,87 N 6 40 E 7 49 E 9 E 10 48 E 1! 06 E 11 42 E 11 70 E 11,74 E 11,88 E 3,71 N ,53 N ,38 N 3,25 N 3,17 N 3,06 N 2,84 N 2,56 N 2,37 N 3,72 N 12 29 g 12 86 E 13 60 E 14 38 E 14 99 E 15 48 E 15 91E 16 10 E 16 28 E 15 22 E O0 .N 0 0 E 1~ 26 W 4 ) 74 18 E 66 N 87 6 g $? g 86 3O t 11'32 N 71 42 E ~ '4 N 7 52 g 13 34 N 7438 E 14 02 N 76 3 g ";1 "" 5 N 78 49~ 16 16 N 79 53 1630 N 80 58 ~ 16 45 N 81 43 E 15 67 N76 15 E 1~,34 I 20 08 ~ . ~ 14 , t8 , 77 30,15 ,52 ~ 31 45,97 ~ ~ .21- 51 65,3b 98 77 88 69 ~ ' , 109 , ,39 ~ 14 116 67 ~ .68 48.24 ~ 11 .63- 18~ 183,63 N 151,01W 237 223,83 N 187,88 W 292 50 1 58 0 E 07 ~ 4 N 35 4 38 25 W 74 N 39 25 W 22 N 40 0 W STANDARD ALASKA PRODUCTION CO, W'29 PRUDHOE BAY NORTH SLOPE, ALASKA COPPUTATION DATEr 07-0CT-88 INTERPOLATED VALUES FOR EVEN I00 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION AZf~UTH DEPTH DEPTH DEPTH DEG NIN DEG MIN 4064 O1 3992,40 3900,00 33 13 24 4092 40 4000,00 37 7 4186 4314 4446 4577 4709 484i 49 5238 61 4192 50 4292 86 4392 76 4492 78 4592 21 4692 74 4792 47 4892 40 4100.00 40 26 40 4200.00 40 40 4500:00 40 43 40 4~00.00 41 2 40 4700,00 40 54 40 4800.00 40 36 620~ 634 93 4992 40 4900,00 41 28 58 5092:40 5000,00 42 0 15 5192 40 5100.00 43 14 19 5292 40 5200.00 43 54 85 5392 40 5300.00 44 41 44 5492 40 5400.00 45 26 56 5592 40 5500.00 45 40 43 5692 40 5600,00 44 53 6486 90 5792 40 5700.00 44 15 6625 89 5892 40 5800.00 43 41 6763 6899 7035 429 555 i933 45 5992 40 5900.00 43 1 77 6092:40 6000.00 42 35 02 6192~40 6100.00 41 56 62 6292.40 6200,00 41 8 21 6392,40 6300.00 39 53 28 6492.40 6400.00 38 20 54 6592,40 6500,00 37 4 62 6692,40 6600.00 37 4 27 6792.40 6700.00 37 33 O1 6892,40 6800.00 38 20 8061 8i92 8325 8457 8587 8716 8843 8970 9099 9226 64 6992,40 6900,00 39 ]9 83 7092.40 7000 O0 40 54 68 7192 40 7100:00 41 6 61 7292 40 7200.00 40 16 73 7392 40 7300.00 39 19 15 7492 40 7400.00 38 28 21 7592 40 7500.00 37 55 i5 7692 40 7600.00 38 4 31 7792 40 7700,00 38 25 21 7892.40 7800.00 39 54 VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ,' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, FEET DEG/IO0 FEET FEET FEET N 41 43 W 351 17 2.98 N 41 33 ~ 420:81 3.29 g 41 33 W 500144 2.00 N 41 19 W 585 63 0,'73 N .40 57 W 670:07 0.~6 N 39 55 W 755~47 0,53 N 39 30 W 841 17 0,23 N 39 13 W 927.57 0'26 N 38 49 W 1014,16 0:SR N 38 8 W 1099,60 0 10 N 38 17 W 1186 18 N 38 9 W 1276 05 N 38 1W 1368 77 N 37 43 W 1463 66 N 37 24 W 1560 93 N 36 44 ~ 1660 98 N 36 9 W 1763 24 N 36 42 W 1863 76 N 37 7 W 1962 25 N 37 39 W 2058.56 76 12 95 36 73 22 22 0 19 N 38 6 W 2152 N 38 6 w 2245 N 37 24 W2335 N 37 7 W 2424 N 36 58 W 2509 N 36 22 W 259 N 36 5 W 2668 N 35 24 w 2743 N 34 57 W 28 N 34 47 W 28 7 N 34 30 W 2978,07 N 3 34 W 319,64 ~ 30 55 ~ 400,15 N 29 44 ~ 3478,39 N 29 18 N 3556,38 N 27 32 ~ 3634,61 N 26 41 ~ 3715,41 DEPARTURE AZIMUTH DEG 269.51 ~ 228.90 353 ,N 423 .25 328.93 504 510i70 N~ 441.96 ~ 675 576 24 497 76 76 552 80 84½ 709 70 607 85 777 31N 662 57 W 1021 844,45 N 735 90 W 1107 0.82 0.11 0,50 0.44 0,47 0,57 0,68 0,46 0,48 0,36 0.43 0.35 0.60 0,53 0,67 1.44 0,80 0.60 0,61 0,61 N 40 8 W 912 65 N 769 69 ~ 11~9~ ~ 983 47 N 825:51 W 12o,, vv N 40 0 52 04 !970 98 ) 2093,63 N 1670 20 W 21 N 2280~65 N 1802 6 93 N 1.06 1,24 0,75 0,89 ,0~ 0,61 0,41 1,42 1.20 234 ,41 ~ 2907,66 241~,22 1848 64 249 '46 ,74 3159,37 56 256~' ~ 1942 46 1988,3i , 3244,97 263 35 2031,96 3327,76 2073 3407, W 20 ,84 277 78 2113,50 3485,64 ,03 3563.i2 290 84 2226,48 , 3720, STANDARD AbASKA PRODUCTION CO, W'29 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATES 07-0CT-88 PAGE KELLY BUSHING INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-BRA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGbEG RECTANGULAR COORDINATES HORZZ'::D~PAR?URE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DEPTH DEPTH DEPTH DEG MIN DEG MIR FEET DEG/IO0 FEET FEET FEET 9357 51 7992 40 7900,00 40 47 9490 9623 9756 9894 100 1O580 30 8092 40 8000,00 41 21 ?l 8192 40 8100,00 4135 05 8292 40 8200.00 42 19 36 8392 40 8300,00 43 !~ 75 ~492 40 ~400.00 43 20 04 8592 40 8500,00 43 7 ~8 8692.40 8600,00 43 26 56 8792,40 R700,O0 4326 27 8892,40 8800,00 42 3 ,00 9164:42 8900,00 42 32 9072,02 42 50 ~ 26 7 W 3799.82 0,97 N 25 29 W 3~86 39 0,56 N 24 23 W 3.73:70 1,01 N 23 6 W 4062,04 0,80 N 22 27 W 4153.0! 0.94 N 21 26 W 4245.37 0.30 N 20 19 ~ 4337,09 0.85 N 18 18 W ~428,19 1,59 N 17 29 W 4519,93 1,73 N 18 28 W 4608,22 0,63 N 18 58 W 4696,51 0.31 N 19 5 W 4850.45 0,00 3057,46 N 2264.39 W 3804 67 3136.10 N 2302 47 W 3890 321b,12 N 2339 83 W 397 7 3298 29 N 2375 80 W 4064 3383:68 N 2411 67 W 4155 347!;10 N 2447 O0 W 4246 ~559.04 N 2480 41 W 433 8 647, 67 442 , 540 59 452 3825,91N 2568 75 ~ 4608 3912 44 N 2598,09 ~ 469 ,5, ]] 365 SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY STANDARD ALASKA PROOUCT ION WELL W-29 FI ELD PRUDHOE BAY COUNTRY USA RUN 0 1 DATE LOOOED 14 - AUO - 88 REFERENCE ?2889 WELL: -(840' W-29 SNL, (12-16-11,-~l_~) 1444' WEL, 'C 21, TllN, R12E) HORIZONTAL PROJECTION 4000 9O0O 2000 ! 000 ~OUTH -2000 RE:F '72889 SCI:II.E = ] / 1 ~ I N/FT -BO00 -4000 -3000 -2000 - 1000 0 1000 2000 3000 E:I:~T WELL: W-29 (12-16-11c~-L2) (840' SNL, 1444' WEL,~ ZC 21 TllN, R12E) ~. VERTICAL PROJECTION 146. 3:) r' n :D r- II CD PROJECTION ON VERTICAL PLANE 326. - 1.46. ~CI:ILED IN VERTI£nL DEPTHS HORIZ SCALE = l; 1000 Ir.!,/FT SUB.$URFACE DIRECTIONAL ~URVEY r'~IUIDANCE ~ONTINUOUS r~OOL -Company STANDAR, D ALASKA PRODUCTION COMPANY Well Name W-29 (12-16-1-1--12) (840' SN,,Lz1444' WEL,,SEC 21,TllNzR12E_) FJ~ldJLocatloI1PRUDHOE BAY,~ NORTH SLOPE; ALASKA, Job Reference No. 72889 SCHWARTZ Date,, 14-AUG-88 Computed STEVENS SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FaR STANDARD ALASKA PRODUCT'[ON CO. W-29 PRUDHOE BAY NORTH SLOPEr ALASKA SURVEY DATE: 14-AUG-88 ENGINE ER: SCHWARTZ METHODS OF COMOUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 33 DEG 38 MIN WEST COMPUTATION DATE: 23-AUG-88 PAGE: I STANDARD ALASKA PRODUCTION CO. W-29 PRUDHOE BAY NORTH SLOPE g ALASKA DATE OF SURVEY: 14-AUG-88 KELLY BUSHING ELEVATION:: 92.40 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 -92.40 0 0 N 0 0 E 100.00 100.00 7.60 0 18 S 12 35 g 200.00 200.00 107.60 0 8 S 53 52 E 300.00 300.00 207.60 0 20 S 78 43 E 400.00 399.99 307.59 0 34 N 68 59 E 500.00 499.99 407.59 0 31 N 76 8 E 600.00 599.99 507.59 0 32 N 77 29 E 700.00 699.98 607.58 0 31 N 80 41 5 800.00 799.98 707.58 0 30 N 83 42 E 900.00 899.97 807.57 0 31 N 84. 11 E 0.00 0.00 0.00 N 0.00 E -0.16 0.00 O.Z5 S 0.08 W -0.48 0.31 0.61 S 0.05 {,4 -0.75 0.74 0.73 S 0.25 E -1.05 0.26 0.52 S 1.13 E -1.31 0.23 0.25 S 1.99 E -1.65 0.14 0.06 S 2.90 E -2.01 0.00 0.12 N 3.80 E -Z.41 0.00 0.24 N 4.72 E -Z.83 0.10 0.35 N 5.63 E 0.00 N 0 0 E 0.26. S 18 8 W 0.62 S 4 21 W 0.77 S 18 54 E 1.24 S 65 24 E 2.. O0 S 82 48 2.90 S 88 50 . 4.73 N 87 2 E 5.64 N 86 27 E 1000.00 999.97 907.57 1100.00 1099.96 1007.56 1200.00 1199.95 1107.55 1300.00 1299.95 1207.55 1400.00 1399.94 1307.54 1500.00 1499.94 1407.54 1600.00 1599.94 1507.54 1700.00 1699.94 1607.54 1800.00 1799.94. 1707.54 1900.00 1899.94 1!{07.54 0 34 N 70 27 E 0 44 N 73 33 E 041 N 64 52 E 0 36 N 52 46 E 0 31 N 44 ~, E 0 24 N 41 56 E 015 N 35 5 E 0 11 N 40 46 E 0 1 N 83 46 W 0 14 S 66 27 E -3.13 0.29 0.55 N -3.46 0.16 0.88 N -3.77 0.00 1.32 N -3.85 0.23 1.90 N -3.72 0.00 2.54 N -3.53 0.05 3.14 N -3.36 0.00 3.58 N -3.25 0.32 3.89 N -3.16 0.12 4.01 N -3.37 0.00 3.88 N 6.48 E 6.50 N 85 6 E 7.5~ E 7.63 N 83 21 E 8.80 E 8.90 N 81 27 E 9.81 E 10.00 N 79 2 E 10.53 E 10.83 N 76 26 E 11.10 E 11.54 N 74 12 E 11.44 E. 11.99 N 72 38 E 11.71 E 12.34 N 71 38 E 11.74 E 12.40 N 71 8 E 11.91 E 12.53 N 71 58 E 2000.00 1999.93 1907.53 2100.00 2099.93 2007.53 2200.00 2199.93 2107.53 2300.00 2299.93 2207.53 2400.00 2399.92 2307.52 2500.00 2499.92 2407.52 2600.00 2599.92 2507.52 2700.00 2699.92 2607.52 2800.00 2799.92 Z707.52 2900.00 2899.88 2807.48 0 17 S 69 41 E 0 25 S 78 29 E 0 25 S 77 12 E 0 25 S 81 44 E 0 17 S ~)0 48 E 0 18 S 70 52 E 0 14 S 52 8 E 0 6 S 29 1E 0 7 S 84 58 E 2 57 N 36 39 W -3.75 0.00 3.70 N -4.22 0.01 3.52 N -4.76 0.04 3.36 N -5.29 0.15 3.25 N -5.69 0.07 3.16 ii -6.06 0.05 3.04 N -6.¢8 0.00 2.82 N -6.80 0.45 2.55 N -7.05 0.58 2.37 N -4.95 2.48 4.03 N 12.33 E 12.92 E 13.66 E 14.43 E 15.03 E 15.52 E 15.94 E 16.10 E 16.29 E 14.99 E 12.87 N 73 17 E 13.39 N 74 44 E 14.07 N 76 9 E 14.79 N 77 19 E 15.36 N 78 8 E 15.81 N 78 54 F 16.18 N 79 57 16.30 N 81 I C 16.47 N 81 43 E 15.52 N 74 56 E 3000.00 2999.61 2907.21 5 25 3100.00 3098.91 3006.51 8 6 3200.00 3197.52 3105.12 10 53 3300.00 3295.21 3202.81 13 38 3400.00 3391.73 3299.33 16 37 3500.00 3486.87 3394.47 19 4 3600.00 3580.67 3488.27 21 31 3700.00 3672.80 3580.40 24 8 3800.00 3763.22 3670.92 26 25 3900.00 3851.78 3759.38 28 51 N 37 52 W 2.26 2.93 N 42 12 W 13.89 3.07 N 43 1 W 30.25 2.87 N 43 21 W 51.25 2.88 N 44 41 W 76.92 4.01 N 42 36 W 107.19 2.83 N 41 18 W 141.48 2.86 N 43 27 W 179.87 2.53 N 43 14 W 221.93 2.50 N 42 26 W 267.77 2.44 9.88 N 10.78 E 14.62 N 47 29 E 18.77 N 3.14 E 19.03 N 9 30 E 30.88 N 8.19 W 31.95 N 14 51 W 46.47 N 22.68 W 51.71 N 26 0 W 65.22 N 40.8~ W 76.95 N 32 3 W 87.25 N 62.38 W 107.25 N 35 33 W 113.18 N 85.30 W 141.73 N 37 0 W 141.84 M 111.55 W 180.44 N 38 11 W 172.8Z N 140.90 W 222.98 N 39 11 W 206.88 N 172.46 W 269.33 N 39 48 W COMPUTATION D~TE: 23-AUG-88 PAGE 2 S'TANDARO ALASKA PROOUCTION CO. W-29 PRUDHDE BAY NORTH SLOPE,ALASK~ DATE OF SURVEY: 14-AUG-B8 KELLY BUSHING ELEVATZON: 92.40 FT ENGINEER: SCHWARTZ ZNTERPOLATED VALUES FOR EVEN 100 FEET OF ,MEASURED DEPTH TRUE SUB-SEA COURSE ,MEASURED VERTZCAL VERTICAL DEVIATION AZTMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDZNATES HOR[Z. DEPARTURE SECTZON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3938.32 3845.92 31 21 4100.00 4022.32 3929.92 34 18 4200°00 4103.43 4011.03 37 35 4300.00 4276.15 4183.75 39 57 ¢400.00 4257.14 4164.74 40 51 4500.00 4333.12 4240.72 40 21 4600.00 4409.22 4316.82 40 42 4700.00 4485.00 4392.60 40 42 4800.00 4560.78 4468.38 40 43 4900.00 4636.41 4544.01 40 54 N 41 56 W N 41 41 W N 41 32 W N 41 32 W N 41 22 W N 41 16 W N 40 47 W N 40 OW N 39 36 W N 39 21 W 317.29 2.93 370.98 3.10 429.0! 3.13 491.14 2.20 555.59 0.50 520.02 0.13 684.35 1.09 749.14 0.60 814.02 0.33 879.09 0.46 243.99 N 206.08 W 319.38 N 40 I1 W 284.44 N 242.21 W 373.59 N 40 24 W 328.25 N 281.13 W 432.18 N 40 34 W 375-22 N 322.71 W 494.90 N 40 41 W 423.95 N 365.81 W 559.96 N 40 47 W 472.78 N 408.74 W 624.97 N 4.0 50 ' 521.67 N 451.40 W 689.85 N 40 52 571.36 N 493.67 W 755.09 N 40 49 WI 621.51 N 535.42 W 820.34 N 40 44 W 672.00 N 577.01 W 885.73 N 40 39 W 5000°00 4711.86 4~19.46 41 0 5100.00 4787.3t 4694.91 40 56 5200.00 4863.17 4770.77 40 30 5300.00 4939.04 4846.64 40 54 5400.00 5014.14 4921.74 41 41 5500.00 5088.28 4995.88 42 0 5600.00 5161.65 5069.25 42 58 5700.00 5234.46 514Z.06 43 31 5800.00 5306.66 5214.26 43 58 5900°00 5378.28 5285.88 44 35 N 39 8 W 944.41 N 38 50 W 1009.76 N 38 16 W 1074.67 N 38 17 W 1139.61 N 38 17 W 1205.41 N 38 9 W 1272.30 N 38 6 W 1340.04 N 37 56 W 1408.38 N 37 41 W 1477.38 N 37 27 W 1547.01 0.47 0.52 0.59 1.16 1.01 0.29 0.41 0.75 0.41 0.71 722.82 N 618.55 W 951.35 N 40 33 W 773.86 N 659.80 W 1016.96 N 40 27 W 824.80 N 700.44 W 1082.08 N 40 20 W 875.98 N 740.73 W 1147.18 N 40 13 W 927.79 N 781.65 W 1213.17 N 40 6 W 980.50 N 823.18 W 1280.24 N 40 0 W 1033.96 N 865.13 W 1348.16 N 39 55 W 1087.95 N 907.35 W 1416.66 N 39 49 W 1142.61 N 949.77 W 1485.81 N 39 44 W 1197.92 N 992.34 W 1555.55 N 39 38 W 6000.00 5449.18 5356.78 45 7 6100.00 5519.43 5427.03 45 35 6200.00 5589.22 5496.82 45 42 6300.00 5659.55 5567.15 45 0 6400.00 5730.41 5538.01 44 42 6500.00 5801.7~ 5709.38 44 12 6600.00 5873.70 5781.30 43 47 6700.00 5946.13 5853.73 43 21 6800.00 6019.15 5926.75 42 55 6900.00 6092.57 6000.17 42 35 N 37 ~ W 1617.39 N 36 31 W 1688.45 N 36 9 W 1759.99 N 36 29 W 1831.00 N 36 53 W 1901.45 N 37 9 W 1971.37 N 37 32 W 2040.70 N 37 59 W 2109.47 N 38 It W 2177.60 N 38 6 W 2245.28 0.72 0.63 0.63 0.42 0.35 0.44 0.56 0.27 0.28 0.35 1254.01 N 1035.08 W 1626.02 N 39 32 W 1311.00 N 1077.72 W 1697.11 N 39 25 W 1368.72 N 1120.12 W 1768.63 N 39 17 W 1426.01 N 1162.20 W 1839.63 N 39 10 W 1482.58 N 1204.37 W 1910.12 N 39 5 W 1538.49 N 1246.56 W 1980.12 N 39 0 ~ 1593.73 N 1288.69 W 2049.56 N 38 57 1648.23 N 1330.93 W 2118.50 N 38 55 ~ 1702.02 N 1373.07 W 2186.82 N 38 53 W 1755.39 N 1415.04 W 2254.7! N 38 52 W 7000.00 6166.40 6074.00 42 11 7100.00 6240.88 6148.48 41 32 7200.00 6316.03 6223.63 40 55 7300.00 6392.24 6299.84 39 53 7400.00 6469.50 6377.10 38 46 7500.00 6548.21 645~.81 37 29 7600.00 6627.93 6535.53 36 48 7700.00 6707.86 6615.46 37 6 7800.00 6787.43 6695.03 37 31 7900.00 6866.46 6774.06 38 6 N 37 35 W 2312.54 N 37 lO W 2379.12 N 37 7 W 2444.92 N 36 58 W 2509.60 N 36 25 W 2573.00 N 36 18 W 2634.61 N 35 52 W 2694.92 N 35 21 W 2754.98 N 34 59 W 2815-52 N 34 51 W 2876.78 0.95 0.69 0.90 0.66 1.64 0.94 0.50 0.36 0.66 0.88 1808.61 N 1456.46 W 2322.15 N 38 50 W 1861.64 N 1496.96 W 2388.85 N 38 48 W 1914.20 N 1536.76 W 2454.75 N 38 45 W 1965.88 N 1575.84 W 2519.52 N 38 42 W 2016.81 N 1613.75 W 2582.96 N 38 39 W 2066.48 N 1650.32 W 2644.60 N 38 36 W 2115.25 N 1685.90 W 2704.91 N 38 33 W 2164.13 N 1720.86 W 2764.92 N 38 29 W 2213.64 N 1755.74 W 2825.39 N 38 25 W 2263.89 N 1790.80 W 2886.54 N 38 20 W ! ,ar STANDARD ALASKA PRODUCTION CO. W-29 PRUDHO5 8AY NORTH SLOPE,ALASKA COMPUTATION DATE: 23-~UG-88 PAGE 3 DATE OF SURVEY: 14-AUG-88 KELLY BUSHING ELEVATZDN: 92.40 ET ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASUREO DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG HIN 8000.00 6944.72 6852.32 38 57 8100.00 7021.84 6929.44 40 4 8200.00 7097.81 7005.41 40 57 8300.00 7173.07 7080.67 41 17 8400.00 72¢8.59 7156.19 40 40 8500.00 7324.83 7232.43 39 55 8600.00 7451.84 7359.44 39 13 8700.00 7479.75 7387.35 38 34 8800.00 7558.3! 7465.91 37 54 8900.00 7637.17 7544.77 38 3 9000.00 7715.90 7623.50 38 4 9100.00 7794.51 7702.11 38 27 9200.00 7872.26 7779.86 39 33 9300.00 7948.74 7856.34 40 26 9400.00 8024.50 7932.10 41 5 9500.00 8099.68 8007.28 41 23 9600.00 8174.65 8082.25 41 30 9700.00 8269.32 8156.32 41 54 9800.00 8323.34 8230.94 42 36 9900.00 8396.51 8304.11 43 13 10000.00 8469.28 8376.~8 43 20 10100.00 8542.08 8449.68 43 12 10200.00 8614.96 8522.56 43 6 10300.00 8687.84 8595.44 43 24 10400.00 8760.16 8667.76 43 49 10500.00 8832.93 8740.53 42 31 10600.00 8907.03 8~14.63 42 9 10700.00 8980.83 8888.43 42 32 10800.00 9054.36 8961.96 42 50 10900.00 9127.76 9035.36 42 50 N 34 35 W 2939.01 N 34 18 W 3002.66 N 33 3 W 3067.69 N 32 6 W 3133.52 N 31 58 W 3199.04 N 31 40 W 3263.72 N 31 34 W 3327.39 N 31 0 W 3390.11 N 30 12 W 3451.89 N 29 30 W 3513.26 N 29 3 W 3574.73 N 27 30 W 3636.Z8 N 26 46 W 3698.76 N 26 28 W 3762.69 N 25 57 W 3827.42 N 25 26 W 3892.73 N 24 41 W 3958.17 N 23 29 W 4023.75 N 22 54 W 4089.88 N 22 26 W 4156.80 N 21 39 W 4224.03 N 20 43 W 4291.03 N 20 I W 4357.62 N 18 26 W 4424.02 N 17 23 W 4490.39 N 17 43 W 4556.28 N 18 33 W 4621.00 N 18 54 W 4686.21 N 19 6 W 4751.79 N 19 5 W 4817.53 1.25 1.30 1.25 0.67 0.57 0.99 0.97 0.65 0.94 0.21 0.65 1.41 1.69 0.61 0.55 0.56 0.93 0.94 0.70 0.91 0 1.05 1.08 1.56 1.21 1.64 0.75 0.34 0.87 0.00 2315.04 N 1826.26 W 2948.67 N 38 16 W 2367.51 N 1862.31 W 3012.19 N 38 11 W 2421.59 N 1898.42 W 3077.03 N 38 5 W 2477.14 N 1933.77 W 3142.56 N 37 58 W 2532.71 N 1968.54 W 3207.76 N 37 51 W 2587.67 N 2002.70 W 3272.13 N 37 44 2641.97 N 2036.02 W 3335.47 N 37 37 L 2695.58 N 2068.67 W 3397.87 N 3T 30 2748.78 N 2100.23 W 3459.30 N 37 22 W 2802.17 N 2130.78 W 3520.28 N 37 14 W 2855.90 N 2161.00 W 3581.35 N 37 6 W 2910.32 N 2190.30 W 3642.44 N 36 57 W 2966.32 N 2218.93 W 3704.42 N 36 47 W 3023.90 N 2247.81 W 3767.84 N 36 37 W 3082.48 N 22T6.61 W 3832.06 N 36 26 W 3141.88 N 2305.23 W 3896.86 N 36 16 W 3201.81 N 2333.30 W 3961.80 N 36 4 W 3262.54 N 2360.41 W 4026.87 N 35 53 W 3324.36 N 2386.88 W 4092.50 N 35 40 W 3387.25 N 2413.14 W 4158.93 N 35 28 W 3450.81 N 2438.99 W 4225.73 N 35 15 W 3514.72 N 2463.88 W 4292.31 N 35 1 W 3578.86 N 2487.69 W 4358.54 N 34 48 W 3643.57 N 2510.30 W 4424.61 N 34 33 W 3709.26 N 2531.37 W 4490.71 N 34 18 W 3774.66 N 2552.03 W 4556.41 N 34 3 W 3838.46 N 2572.97 W 4621.03 N 33 50 ' 3902.37 N 2594.63 W 4686.21 N 33 37 ~. 3966.44 N 2616.70 W 4751.82 N 33 24 W 4030.63 N 2638.92 W 4817.66 N 33 12 W 10950.00 9164.42 9072.02 42 50 N 19 5 W 4850.45 0.00 4062.76 N 2650.04 W 4850.65 N 33 6 W COMPUTATION DATE: 23-AUG-88 PAGE 4 STANDARD ALASKA PRODUCTION CO. W-29 PRUOHOE BAY NORTH SLOPE~ALASKA DATE OF SURVEY: 14-AUG-88 KELLY BUSHING ELEVATION: 91.40 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASUREO DEPTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION flZIqUTH DEPTH DC~PTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 ~EET FEET FEET DEG MIN 0.00 0.00 -92.40 0 0 1000.00 999.97 907.57 0 34 2000.00 1999.93 t907.53 0 17 3000.00 Z999.6! 2907.11 5 25 4000.00 3938.32 3845.92 31 21 5000.00 4711.86 4~19.46 41 0 6000.00 5449.18 5356.78 45 7 7000.00 6166.40 6074.00 42 11 8000.00 6944.72 6852.32 38 57 9000.00 7715.90 7623.50 38 4 N 0 0 E 0.00 N 70 27 E -3.13 S 69 41 E -3.75 N 37 52 N 2.;'6 N 41 5~ W 317.29 N 39 8 W 944.41 N 37 5 W 1617.39 N 37 35 W 2312.54 N 34 35 W 2939.01 N 29 3 W 3574.73 0.00 0.00 2.93 2.93 0.47 0.7;~ 0.95 1 0.65 0.00 N 0.00 E 0.00 N 0 0 E 0.55 N 6.48 E 6.50 N 85 6 E 3.70 N 12.33 E 12.87 N 73 17 E 9.88 N 10.78 E 14.62 N 47 29 E 243.99 N 206.08 W 319.38 N 40 11 W 722.82 N 618.55 W 951.35 N 40 33 ' ?~ 1254.01 N 1035.08 W 1626.02 N 39 32 ~, · 1808.61 N 1456.46 W 2322.15 N 38 50 W 2315.04 N 1826.26 W 2948.67 N 38 16 W 2855.90 N 2161.00 {,,I3581.35 N 37 6 W 10000.00 8469.28 8376.88 43 20 10950.00 9164.42 9072.02 42 50 N 21 39 W 4Z24.03 N 19 5 W 4850.45 0.71 0.00 3450.81 N 2438.99 W 4225.73 N 35 15 W 4062.76 N 2650.04 W 4850.65 N 33 6 W COMPUTATION DATE: 23-AUG-98 PaGE 5 STANDARD ALASKA PROOUCT[ON CO. W-29 PRUDHDE BAY NORTH SLOPE~ALASKA OATE OF SURVEY: 14-AUG-88 KELLY BUSHING ELEVATION: 92.40 FT ENGINEER: SCrHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/ZO0 FEET FEET FEET DEG 0.00 0.00 -92.40 0 0 N 0 0 E 92.40 92.40 0.00 0 18 S 15 12 W 192.40 192.40 100.00 0 8 S 43 39 E 292.40 292.40 200.00 0 17 S 72 5 E 392.41 392.40 300.00 0 35 N 69 7 E 492.61 492.40 400.00 0 30 N 75 53 E 592.41 59Z.40 500.00 0 31 N 77 31 E 692.42 692.40 600.00 0 31 N 80 2 E 792.42 792.40 700.00 0 30 N 83 14 E 892.43 892.40 800.00 0 31 N 84 4 E 0.00 0.00 0.00 N 0.00 -0.13 0.07 0.21 S 0.07 -0.47 0.29 0.60 S 0.06 -0.71 0.56 0.72 S 0.21 -1.04 0.22 0.54 S 1.06 -1.29 0.13 0.27 S 1.93 -1.62 0.06 0.07 $ 2.83 -1.98 0.00 0.11 N 3.73 -2.38 0.04 0.24 N 4.65 -2.80 0.06 0.34 N 5.56 0.00 N 0 0 E 0.22 S 18 26 W 0.60 S 5 41 W 0.75 S 15 58 E 1.19 S 62 43 E 1.95 s az 4 2.83 S 88 33 ',. ~ 3.74 N 88 I8 E 4.66 N 87 6 F 5.57 N 86 30 E 992.43 992.40 900.00 1092.44 1092.40 1000.00 1192.45 1192.40 1100.00 1292.45 1292.40 1200.00 1392.46 1392.40 1300.00 1492.46 1492.40 1400.00 1592.46 1592.40 1500.00 1692.46 1692.40 1600.00 1792.46 1792.40 1700.30 1892.46 1892.40 1800.00 0 33 N 69 27 E 0 43 N 73 41 E 0 42 N 65 26 6. 0 37 N 54 6 E 0 31 N 43 55 E 0 25 It 42 34 E 0 15 N 33 46 E 0 12 N 43 50 E 0 ! N 64 2~ W 0 14 S 66 52 E -3.11 0.31 0.53 N 6.40 E -3.44 0.16 0.85 N 7.49 E -3.76 O.OZ 1.28 N 8.72 E -3.86 0.27 1.85 N 9.75 E -3.73 0.00 2.49 N 10.48 E -3.55 0.15 3.10 N 11.06 E -3.37 0.00 3.55 N 11.42 E -3.26 0.22 3.87 N 11.70 E -3.16 0.18 4.01 N 11.74 E -3.34 0.00 3.89 N 11.88 E 6.43 N 85 17 E 7.54 N 83 28 E 8.81 N 81 37 E 9.93 N 79 14 E 10.77 N 76 37 E 11.49 N 74 22 E 11.96 N 72 43 E 12.32 N 71 42 E 12.41 N 71 8 E 12.50 N 71 52 E 1992.47 199Zo40 1900.00 2092.47 2092.40 2000.00 2192.47 2192.40 2100.00 2292.47 2292.40 2200.00 2392.48 2392.40 2300.00 2492.48 2492.40 2400.00 2592.48 2592.40 2500.00 2692.48 2692.40 2600.00 2792.48 2792.40 2700.00 2892.51 2892.40 2800. O0 0 16 S 68 52 E 0 24 S 77 3 E 0 25 S 76 50 E 0 25 S 81 36 E 0 17 S 81 42 E 0 18 S 72 14 E 0 13 554 0 7 S 19 14 E 0 6 S 64 0 E Z 46 N 37 54 W -3.72 0.00 3.71 N 12.29 E -~,.18 0.08 3.53 N 12.86 E -4.72 0.15 3.38 N 13.60 E -5.25 0.06 3.25 N 14.38 E -5.66 0.16 3.17 N 14.99 E -6.03 0.11 3.06 N 15.48 E -6.45 0.00 2.84 N 15.91 E -6.79 0.69 2.56 N 16.10 E -7.04 0.62 2.37 N 16.28 E -5.33 2.68 3.72 N 15.22 E 12.84 N 73 11 E 13.34 N 74 38 E 14.02 N 76 3 E 14.74 N 77 14 E 15.32 N 78 4 E 15.78 N 78 49 F 16.16 N 79 53 16.30 N 80 58 t. · 16.45 N 81 43 E 15.67 N 76 15 E 2992.76 2992.40 2900.00 5 12 3093.42 3092.40 3000.00 7 54 3194.78 3192.40 3100.00 10 44 3297.10 3292.40 3200.00 13 32 3400.69 3392.40 3300.00 16 39 3505.86 3492.40 3400.00 19 12 3612.62 3592.40 3500.00 Z1 51 3721.50 3692.40 3600.00 24 40 3832.71 3792.40 3700.00 27 13 3946.64 3892.40 3800.00 29 59 N 37 16 W 1.57 2.76 bi 42 7 W 12.96 3.25 N 43 3 W 29.27 2.87 N 43 19 W 50.57 2.68 N 44 41 W 77.12 4.07 N 42 22 W 109.11 2.71 N 41 30 W 146.10 2.91 N 43 35 W 188.58 2.43 N 42 58 W 236.52 2.50 N 42 10 W 290.42 2.42 9.34 N 11.20 E 14.58 N 50 10 E 18.08 N 3.77 E 18.47 N 11 47 E 30.15 N 7.52 W 31.07 N 13 59 W 45.97 N 22.21 W 51.05 N 25 46 W 65.36 N 40.98 W 77.14 N 32 5 W 88.69 N 63.68 W 109.18 N 35 40 W 116.67 N 88.39 W 146.37 N 37 8 W 148.24 N 117.63 W 189.24 N 38 25 W 183.63 N 151.01 W 237.74 N 39 25 W 223.83 N 187.88 W 292.22 N 40 0 W STANDARD ALASKA PRODUCTION CD. W-29 PRUOHOE BAY NORTH SLOPE,ALASKA COMPUTATION DATE: 23-AUG-88 PAGE 6 DATE OF SURVEY: 14-AUG-88 KELLY BUSHING ELEVATION: 92.40 FT ENGINEER: SCHNARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SU~-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTAhiGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FE6T FEET DEG 4064.01 3992.40 3900.00 33 13 4186.24 4092.40 4000.00 37 7 4285.60 4192.40 4100.00 39 38 4302.79 4292.40 4200.00 40 1 4319.98 4392.40 4300.00 40 23 4709.76 4492.40 4400.00 40 43 4841.78 4592.40 4500.00 40 43 4974.21 4692°40 4600.00 41 Z 5106.74 4792.40 4700.00 40 54 5238.47 4892.40 4800.00 40 36 N 41 43 W N 41 33 W N 41 31W N 41 32 W N 41 33 W N 39 55 W N 39 30 W N 39 13 W 351.17 2.9F) 420.81 3.29 481.98 2.40 492.92 2.17 503.86 1.93 755.47 0.53 841.17 0.23 927.57 0.26 0.58 0.10 N 38 49 W 1014.16 N 38 8 W 1099.60 5370.93 4992.40 4900.00 41 28 5505.58 5092.40 5000.00 42 0 5642.15 5192.40 5100.00 43 14 5780.19 5292.40 5200.00 43 54 5919.85 5392.40 5300.00 44 41 6061.44 5492.40 5400.00 45 26 6204.56 5592.40 5$OO.O0 45 40 6346.43 5692.40 5600.00 44 53 6486.90 5792.40 5700.00 4~ 15 6625.89 5892.40 5800.90 43 41 N 38 17 W 1185.18 N 38 9 W 1276.05 N 38 1 W 1368.77 N 37 43 W 1463.66 N 37 24 W 1560.93 N 36 44 W 1660.98 N 36 g W 1763.24 N 36 42 W 1863.76 N 37 7 W 1962.25 N 37 39 W 2058.56 0.82 0.11 0.50 0.44 0.47 0.57 0 0.46 0.48 0.36 6763.45 5992.49 5900.00 43 1 6899.77 6092.40 6000.90 42 35 7035.02 6192.40 6100.00 41 56 7168.62 6292.40 62-00.00 41 8 7300.21 6392.40 6300.00 39 53 7429.28 6492.40 6400.00 38 20 7555.54 6592.40 6500.00 37 4 7680.62 6692.40 6600.00 37 4 7806.27 6792.40 6700.00 37 33 7933.01 6892.40 6800.00 38 20 N 38 6 W 2152.76 N 38 6 W 2245.12 N 37 24 W 2335.95 hi 37 7 W 2424.36 N 36 58 W 2509.73 N 36 22 W 2591.22 N 36 5 W 2668.22 N 35 24 W 2743.30 N 34 5'7 W 2819.34 N 34 47 W 2897.19 0.43 0.35 0.60 0.53 0.67 1.44 0.80 0.60 0.61 0.61 8061.64 6992.40 6900.00 39 39 8192.83 7092.40 7000.00 40 54 8325.68 7192.40 7100.00 41 6 8457.61 7292.40 7200.00 40 16 8587.73 7392.40 7300.00 39 19 8606.45 7492.40 7400.00 39 10 8622.34 7592.40 7500.00 39 2 8970.15 7692.40 7600.00 38 4 9097.31 7792.40 7700.00 38 25 9226.21 7892.40 7800.00 39 54 N 34 30 W 2978.07 N 33 10 W 3062.98 N 32 3 W 3150.41 N 31 52 W 3Z36.43 N 31 34 W 3319.64 N 31 33 W 3331.46 N 31 32 W 3341.48 N 29 18 W 3556.38 N 2-7 32 W 3634.61 N 26 41 W 3715.41 1.06 1.24 0.75 0.89 1.03 0.90 0.71 0.41 1.42 1.20 269.51 N 228.90 W 353.60 N 40 20 W 322.05 N 275.64 W 423.90 N 40 33 W 368.30 N 316.57 W 485.66 N 40 40 W 376.56 hi 323.90 W 496.70 N 40 42 W 384.83 N 331.22 W 507.74 N 40 43 W 576.24 N 497.76 W 761.45 N 40 49 ' 642.56 N 552.80 W 847.62 N 40 42 709.70 N 607.85 W 934.43 N 40 34 W 777.31 N 662.57 W 1021.37 N 40 26 W 844.45 N 715.90 W 1107.07 N 40 17 W 912.65 N 769.69 W 1193.88 N 40 8 W 983.47 N 825.51 W 1284.00 N 40 0 W 1056.64 N 882.91 W 1376.96 N 39 52 W 1131.73 N 941.35 W 1472.06 N 39 45 W 1208.99 N 1000.82. W 1569..49 N 39 37 W 1288.92 N 1061.31 W 1669.64 N 39 28 W 137'1.35 N 1122.D~. W 1771.8~3 N 39 17 W 1452.35 N 1181.76 W 1872.40 N 39 8 W 1531.21 N 1241.04 W 1970.98 N 39 1 W 1607.92 N 1299.61 W 2057.46 N 38 56 W 1682.42 bi 1357.68 W 2161.91 N 38 54 W 1755.26 N 1414.94 W 2254.56 N 38 52 W 1827.23 N 1470.75 W 2345.60 N 38 49 W 1897.77 N 1524.33 W 2434.16 N 38 46 W 1965.99 N 1575.92 W 2519.65 N 38 42 W 2031.49 N 1624.58 W 2601.20 N 39 38 W 2093.63 N 1670.20 W 2678.21 N 39 34 ~ 2154.60 hi 1714.10 W 2753.26 N 38 30 ,~ '~ 2216.77 N 1757.93 W 2829.20 N 38 24 W 2280.65 N 1802.46 W 2906.93 N 38 19 W 2347.2Z N 1848.41 W 2987.66 N 38 13 W 2417.64 N 1895.86 W 3072.34 N 38 6 W 2491.46 N 1942.74 W 3159.37 N 37 56 W 2564.46 N 1988.31 W 3244.97 N 37 47 W 2635.35 N 2031.96 W 3327.76 N 37 38 W 2645.44 N 2038.15 W 3339.52 N 37 36 W 2653.98 N 2043.40 W 3349.50 N 37 35 W 2839.82 N 2152.03 W 3563.12 N 37 9 W 2908.84 N 2189.53 W 3640.79 N 36 58 W 2981.30 N 2226.48 W 3720.93 N 36 45 W COMPUTATION DATE: 23-AUG-88 PAGE 7 STANDARD ALASKA PRODUCTION CO. W-29 PRUOHOE BAY NORTH SLOPE~ALASKA DATE OF SURVEY:: 14-AUG-88 KELL? BUSHING ELEVATION: 92.40 FT ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN 9357.51 7992.40 7900.00 40 47 9490.30 8092.¢0 8000.00 41 21 9623.71 8192.40 8100.00 41 35 9758.05 8292.40 8200.00 42 19 9894.36 B392.40 8300.00 43 12 10031.75 8492.40 8~00.00 43 20 10169.04 8592.40 8500.00 43 7 10306.28 8692.40 8600.00 ~3 26 10444.56 8792.40 8700.00 43 26 10580.27 8892.40 8~00.00 42 3 N 26 7 W 3799.82 N 25 29 W 3886.39 N 24 23 W 3973.70 N 23 6 d 4062.04 N 22 27 W 4153.01 N 21 26 W 4245.37 N 20 19 W 4337.09 N 18 18 W 4428.19 N 17 29 W 4519.93 N 18 28 W 4608.22 0.97 0.56 1.01 0.80 0.94 0.30 0.85 1.59 1.73 0.63 3057.46 N 2264.39 W 3804.67 N 36 3I W 3136.10 N ?.302.47 W 3890.56 N 36 17 W 3216.12 N 2339.83 W 3977.21 N 36 2 W 3298.29 N 2375.80 ~1 4064.86 N 35 45 W 3383.68 N 24.1.1.67 W 4155.17 N 35 28 W 3471.10 N 2447.00 W 4246.92 N 35 10 t~ h 3559.04 N 24~0.41 W 4338.11 N 34 52 3647.66 N 2511.67 W 4428.76 N 3~ 33 W ' 3738.60 N 2540.59 W 45Z0.15 N 34 11 W 3825.9t N ~568.T5 W 4608.26 N 33 52 W 10715.73 8992.40 8900.00 ~2 32 10950.00 916&.42 9072.02 42 50 N 18 58 W 4696.51 N 19 5 W 4850.45 0.31 0.00 3912.44 N 2598.09 W 4696.51 N 33 35 W 4062.76 N 2650.0~ W 4850.65 N 33 6 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY STANDARD ALASKA PRODUCTION WELL W-29 FIELD PRUDHOE BAY COUNTRY USA RUN 01 DATE LOOOED 14 - AUO - 88 REFERENCE ?2889 WELL'~ W-29 (12-16-Il-)--=-) ~-. HORIZONTAL PROJECTION (840' SNL, 1444' WEL, , 21, TllN, R12E) 6000 BO00 4000 ~00 ~000 1000 - 1000 -2000 -S000 WEST RI~F ?2889 SCALE = 1/1000 IN/FT -..,...'-.-;-.~.- .4--;..4...~....-.4..4-J,.-4......4....~-..~.m..L.. ,.4..4.-J-4--~--.b.-k.-~-- .4 .~ .;-.L~ .~.4..4.~. ; i ~_~ -.L..~ .T.4 .;, ~ ~ .~ ..... ~ ~-.~.~ ....... ~ ~ ;. ~... ~ ~. ~: ~-~ : ! ' . : ! ::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: `.H....b.H"H~.H`~"¢.6H."H"H".H~"H..H..4..+..H"~...`.`.H..H..H~..H.`~".H-H..~H..H`"H".~.H".H..H.~6H ....... H-4..H ....... ~.4..: ....... ~.,L~ ........ 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' .... t''~ .... :''? ........... [ l'll'l 'lb*'''H'lLH''--¢l--+ ...... ¢l'll*lll¢''.¢''']''l'~ ...... ¢'''~ ....... H'''H''I~4'''¢'''H--'''H4''*''' ''';'''H'''*'l' '''H''l¢lll¢'''''''~ ........ ~'''* ....... ¢'ll;'ll~ ...... ~'l* ........... : .......... ~ .............. ~ .............. ~ .... : .... ~ ': ......... .................. ~ ........ , ........ [ I , . 1 ..¢: : : : ¢...¢...~...~ ll¢l.l.~...~...; .. I .¢..1.~.. ~lll;: ~ : ~ ~ ~ : ~ ........ ~ :~ ...... ; e : :;--1;'' ¢ I ~ll4' : : :¢ ¢'4: : : :~ ~ I '¢--~:' ¢''4''1, ~ : : : : ~' ¢''4' ~ 14''' ~ :' : ~' ~ll4'l'l~ ~' : 1;l'l~'''~:: ...... ~; ....... ; ...... ; ' ;~l'll; .... ;--', ............ ;''';. .......... 1 l*'~ .................. ' ~ '; ..... '+''t--'t'''t'''~''l?l+'l'tl'l*l'' '''Ht'''Sll+''~'''S--ll~ll'H+'''''''t'l't''+'+''~l--H+'''S''+'I''''H+'''s''+'']'''sl'+''s ........... ¥';'l+''?~''l+''H+'''s ....... ~ ......... ~ ....... *'S ..... * ........ S'' r''~ll *'4 .... ~l'%t ....... S'~ll ~ .... * '*l Is ..... _.?...f..f_[1.f..f?~ ...... t''?llltl'l?lll['''? 1--~'lltlllt ...... f'lt'''f''f--['l'f''f--f''f--~'''t'''f''?f'l[''ll~-'f'''}llll~ ....... ~ I ~ } ll I '~ l~'"[''ll}ll't'''l~ '? ...... ~lll~' ~ [ I l~ I l~ ..... : 1 '~"' ~ ~ I ...... }l: ~ ~ } l~li. : .... -4000 -3000 -2000 - 1000 0 1000 2000 3000 EAST · WELL' W-29 (12-16-11-~l--~.) VERTICAL PROJECTION (840' SNL, 1444' WEL, . 21, TllN, R12E) -2000 - ,000 0 0 !OOO ZOO0 3000 4000 5000 6OOO 326. PROJECTION ON VERTICAL PLANE 326. - 14IS. SCALED IN VERTICAL DEPTHS HORIZ SCALE = l/1000 IH/FT ARCO EXXON PHII.I. IPS TO: STANDARD ,'~! ,.~.,,?.... , , i.. Date: 08/16/88 T~: 79210 SYSTEMS ARCH IVES REF~CE: SAPC N,\(;NETLC I. IS TAPES & LISTIN(;S The follc~ing material is t>?ing sut~n~ttC~J signing a cc~.! of mis letter arg] returning it to tt~s office: W-24 OH/DIL/BHC/LDT/CNL 08/13/88 #1 6858-9636 Tape Pos. #06030 Sch #72886 1600bpi API#50-029-21833 OH/DIL/MSFL/BHC/LDT/CNL 08/10/88 #1 7694-10956 Tape Pos.#06032 Sch#72885 1600bpi API#50-029-21834 ARCHVIES ONLY: W-24 OH/field 08/14/88 #1 Tape Pos.#06031 Sch#72886 1600bpi W-29 OH/BHC/LDT/CNL #1 Tape Pos.#06033 Sch#72885 1600bpi W-29 OH/DIL/MSFL #1 Tape Pos. #06034 Sch#72885 800bpi * E~XON: An Asterisk (*) next to a listing above means you shc)ulct have received the Tape(s) and I. isting(s) directly from the respective service company. Please confirm thi~ C ' ~ '7'~~,~ ,t: i(.!2).~, Jennifer Dietz Slanda,d Alasl~¢ P~oducllon Comp. 900 Eos! Benson Boulevard P.O. Bo, 196612 Anchorage, Alaska 99519.6612 (907) 564-51 I 1 HOUSTON ARCO CHEVRON EXXON TEXACO TO: MOBIL REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD A,L ASY£-~ PRODUCTION Date: 08/17/88 TI: 79218 The following materlal Is being submitted herewith. Please acknowledge recelpt by slgnlng a copy of this letter and returning it to this office: ~ W-29 ~ W-29 ~'~ W-29 ~Z-14 ~ Z-14 ~ Z-14 Perf Record 08/14/88 #1 10050-10850 Sch CBT 08/13/88 #1 10050-10556 Sch 5" CET 08/13/88 #1 10050-10880 Sch 5" Completion Record 08/13/88 #1 9520-10232 Sch 5" CBT 08/13/88 #1 9032-10249 Sch 5" CET 08/13/88 #1 9032-10268 Sch 5" Alaska Oil & (]as Cons.. Commission Anchorage Rece I ved Date A u,',,! of th~. o,,9,nol S,ondo,d C~l Fo,.,,,d~,'d ,n Cl~'.~,lond C~,o ,~ 1870 Jennifer Dietz ~ NFORMAT ~ ON CON TR0~ Wel I Records LR2-1 M'EMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COM}~'II SS ION TO: Lonnie C. Smith Commissioner DATE: August 5, 1988 FILENO: D.ADA. 003 THRU: ~.zchael T Minder Sr. Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test SAPC PBU W- 29 Pemit No. 88-71 Prudhoe Oil Pool FROM: Doug Amos~ Petroleum Inspector Tuesday, July 26, 1988: I traveled this date from Anchorage to i~r~dh6~ ~Bay~° st~'h'd bY for the BOP Test at SA_PC PBU W-29 Well. Wednesday, July 27, 1988: The testing did not commence until 4:45 p.m. because a top cement job had to be performed 'on the 13 3/8" casing. The test was concluded at 6:45 p.m., there were no failures and I filled out an AOGCC BOP Inspection Report which is attached. In summary, I witnessed the successful BOP Test at SAPC PBU W-29 Well on AUDI Rig No. 3. Attachment 02-001A (Rev. 8~85) STATE OF ALAS~ ALASKA OIL & GAS CONSERVATION CO~IIS$ION B.O,P,E, Inspection Report' 'Inspector ~~ ~~ Operator ~ ~:U'~ Lo~ation: Sec_~l Tiif~ R'lg.~~ LA~ Drillin~ Contractor . ~~ Location, General ~ell Sign General Housekeepin~ ~ aiS ~ Reserve Fi~. ~ ,. Hud Systems Trip Tank Pit Cause Flop Honitor Gas Detectors Visual Audio II !est Pr,,ess,uze %:000 ,, ,,, , J~ i BOPE Stack Annular Preventer_ ii ACCUHULATOR Full Charge Pressure Pressure After Closure t~r~C) .psig ~ . Pump incr, clos. pres, 200 psi~ min ~-sec, Full Charge Pressure_A~t~ined: P~pe Rams Blind Rams .~ Choke Line Valves~ H.C.R. Valve Fill Line Valves Check Valve , Upper Kelly ~ ~/Te~t Pressure , Lower Kelly J, '?TeSt Pressure,,, Ball Type I, '.~.est Pressure Inside BOP j ~/Test Pressure · Choke Hanif01d [ Test Pressure ti No, Valves J~ No. flanges ~Td,rauSeall~ operated choke Teat Results: Failures .. ~o0~ Repair or Replacement of failed, equipment to be made within days and Inspector.f'" Commission office notified. " Remarks: :' i i ii i i i · Ill II I ' 1' · I I I I · . Distribution oriE, - AO&GCC cc - Operator cc - Supervisor Inspector mL M EM OR~~Po~,~?~ Lonnie C. Smith TO: Commissioner c o~ s ~VA$,t~tg, MP~f~ Al aska July 28, 1988 DATE: D. ADA. 001 FILE NO: TELEPHONE NO: Michael T. Minder~Z~x~,~· THRU: SUBJECT.' Sr. Petroleum Engineer Doug Amos~ Petroleum Inspector FROM: BOP Test SAPC PBU W-29 Permit No. 88-71 Prudhoe Oil Pool Tuesd..ay, July 26, 1988: I Traveled this date from Anchorage to Prudhoe Bay to stand by for the BOP Test on SAPC PBU W-29. ~ed~s.d~y, July 27, 1988: The testing did not commence until 4:45 p.m. because a top cement job had to be performed on the 13 3/8" casing. The test was concluded at 6:45 p.m., there were no failures and I filled out an AOGCC BOP Inspection Report which is attached. In summary, I witnessed the successful BOP Test at SAPC PBU W-29 Wel. 1 on AUDI Rig No. 3. Attachment 02.001A fRev. 8/85') JUL ~8 ~88 06:0~ RIG 2 4:34 P03 STATE OF ALASKA ALASKA OIL & GAS COHSERVATIOH COH~flSSIOH B.O.P.E. Inspection Report . eepresentative Operator -%_~"i~ ........ --'--- ._~ Ri I ~ Re'~resenta~ive Drill, Contractor Location, General Vel1 Si Ceneral aousekeeptn~kig.,/ Reserve Fit tlud S' ~te~ Visual Zrtp Tank I./' Flov Honicor m_ Gas Detectors ;oPE .Stac_k. Annul. ar Preventer Pipe Rams i~ ~ L,/~ Blind Rams t~ . [ Choke Line Valves_ '~ II.C.R. Valve //~ -- E.tli Line Valves ~'~_ Check Valve .... 0 Te.s.c Pre,s, sure Full Charge Fressur.e ..... _~ ~~__. psig~ ~---'/' ,._ Pressure A~cer Closure=. i~_~., pst~. ~ .. =. F~p incr. clue. pres. 200 psis mia Z~ec. Full Charse Fressur~AVceined~ ~.. min~sec. / ', ~ntrolsz Heater ....... .. R~,0~e /Blin~s svicCh ?yet ~~ ._ .m it Kell~ and Floor~.Safecy. Valves Upper Kell est Pressure Lover Eell? ,~ ~/Test Fressure..__~ - Ball Type~. !,/Test Pressure_.._ Inside BOP ,{ .~fesc Pressure_.. ._ · Choke Hantfold ~ Teac Pressure,, . Valves Ho. flang-s ..... Adjustable Chokes __ ~erated choke Test ResulCs~ Failures M~'%~ - - - 'Repair or Replacement of failed equipment co be made vichin Comnission of£tce no~ifted. days and Inspector! · ~isccibution ariS. - AOt~CC ce - Operator r~ lnspect~ ~;~ cc - Supervisor .... ~.~ ~ June 30, 1988 R H Reiiey PBU ~lvision Drilling Mgr Standard Alaska Production Company P O Box ]96612 Anchorage, ~ 99519-6612 Telecopy No. (907) 276-7542 Prudhoe Bay Unit W-29 Standard Alaska Production Company' Pertain # 88-71 Surf Loc 840'SNL, 1444'WEL, Sec 21, TllN, R12E, UM Btm~ole Loc 2106'SNL, 4113'WEL, Sec 16, TllN, R12E, UM Dear Mr Reiiey: Enclosed is the approved apPlication for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the.conductor pipe. Very truly yours, ~ / ¥'7 ~arnwe 1~,___ ' W W Com~is s ioner Alaska Oil and Gas Conservation Co~ission BY O~ER OF THE COMMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o enci Department of Environmental Conservation - w/o eucl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratoryl-] Stratigraphic Testl-I Development Oill[] Re-Entry [] Deepenr-II Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Comoanv 92 feet Prudhoe Bay Field/Prudhoe 3. Address ' 6. Property Designation Bay Pool P. O. Box 196~12. Anch~r~e. Alaska ~951g-6612 ADL 2R265 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s,,e 2o ^^c 25.02s) 840' SNL, 1444' WEL, SEC 21, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2252' SNL, 4016' WEL, SEC 16, T11N, R12E W-29 (12-16-11-12) KOO683449-G-14 At total depth 9. Approximate spud date Amount 2106' SNL, 4113' WEL, SEC 16, T11N, R12E July 5, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandmVD) property line ADL28262 1264 feet W-35 411 feet 2560 10901'MD 9162' TVD feet 16. To be completed for deviated wells 1 7. Anticipated pressure (see 20 ^AC 25.03,5 (e)(2)) Kickoff depth 2800 feet Maximum hole angle41.2 o Maximum surface 3330 pslg At total depth (TVO) ? pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 20" Cond. ~0 ~ Surface 110' 110' 8 cu yds concrete 17-1/2" 13-3/8" 68# L-80 Butt 2650' Surface 2680' 2680' 3723 cu ft Permafrost 12-1/4" 9-5/8" 47# L-80 NSCC 4671' Surface 4701' 4500' 12-1/4" 9-5/8" 47# L-80 Butt 5583' 4701' 4500' 10284' 8697' 2195 cuft Class G 8-1/2" ~ ~ -E-8~ ~ 868' 10033' 8509' 10901' 9162' 267 cu ft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth ~ ,~True ~Ver_tJc~ depth Structural ~' ii!~' ~ :~';ii? i"'~ L.,~ Conductor SurfaceJUN 2 4 Intermediate ~ Prod uction ~j~?~ CJi .~ [~,~ ' ....... Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat E] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ~s true,and correct to the best of my knowledge , Signed~ ~/ Title p~u Drilling Engineering Supervisor Date (o/7-,] / ~ou Commission Use Only ~ Permit Number IAPI number IApproval date ISee cover letter ~8-'~7 15o- o~"~--Z~-~ I 06/30/88 Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required FI Yes [] No Hydrogen sulfide measures [] Yes [] No D~rectional survey required [] Yes [] No Other: ~,~' ~-~~~-~'~~s'"'/~~ by order of ~/ Approved by t, ioner tne commission_ .Da. te. . .~' Form 10-401 Rev. 1~1-85 Submit in tri)licate PROPOSED DRILLING AND COMPLETION PROGRAM WELL W-29 [ 12-16-11-12 ] PBU Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-10.0 ppg water base mud in the 12-1/4" hole and a 9.4 ppg water base mud in the 8-1/2" hole. Drill 17 1/2" hole to 2700' and cement 13 3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 47# L-80 Butt/NSCC casing to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by nonfreezing fluid. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.6 ppg. NaCl completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production packer on internal plastic coated tubing with a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Shut down rig operations for perforating subsequent to rig release. The well will be perforated in accordance with normal practices. Tubing Size: Tailpipe Size: 3 1/2", 9.3#, L-80, EUE 8RD JLW:20-JUN-88 3 1/2", 9.3#, L-80, A/B Mod, EUE 8RD, IPC with 8 GLM's PROPOSED DQWNHOLE DIAGRAM WELL W-29 [!2-16-11-12] PBU/EWE PROPOSED DEPTH BKB 20" Conductor Ball Valve 110' 2000' 13-3/8" Casing Shoe 17-1/2" Open Hole 2680' 2700' 3-1/2" 9.3# L-80 AdB Mod. EUE tubing with 8 GLM's 9-5/8" Packer 9983' 7" Tieback Assembly 10033' %5/8" Shoe 12-1/4" Open Hole 10284' 10289' 7" 26# L~80 IJ4S Liner 7" PBTD 7" Liner Shoe 8-I/2" Open Hole 10781' 10901' 10901' B.O.P. STACK CONFIGURATION 13-S/8' IN. TRIPLE RAM STACK SO00 PSI WP DRILLING ANNULAR PREVENTER z IN. KILL LINE l GATE GATE ! I I PIPE RAMS 1 BLIND RAILS DRILLING SPOOL PIPE RAMS I I 4 IN. CHOKE LINE GATE GATE NORTH T. IZN. I ~: I1 N. WELL N" W-29 _ ~RJRFACE LOCAT I~ LAT. · 70° 17' 53. 057" LONG. · 149° 05" 40. 891" y · 5, 959, 41:~.07 A.S.P. X · 61 I , 789.06 ZONE: 4 840' FROM N. LINE SECT. 21 444' FROM E. LiNE SECT.?i liN. SPINE : _~ o · ~ .~ SCALE. L Z6 ILE. N.W. $4 I MILES Z5 CERTIFICATE OF SURVEYOR: SURVEYOR DATE: i WELL PAD W WELL N° W- 29 AS-BUILT LOCATED Iq PROTRACTED SECT. I'1, T. II N. , R. I~' E., U.M. SURVEYED FOR : ~l'/I.~l:~tUl~ ALASK-,.A P~ODUETIOr,, 2.0 P~EPARED IY ; KUUKPIK - TECHNICAL BERV. INC. PR UDHO£ lAY OFFICE tDATE , NOV. 15, 86 ~.AWN BY: S.T. CHKD. BY; SUMP SUklP NORTH LIN[ OF SECTI0k tt em IlL · · w · · W-21 · W-2D · W-lg · W-18 · W-15 · w-14 · · W-I · W-2 · · · · W-(~ · W-7 · W-8 · W-9 · W-lO · ~-iI · W-t2 14 4 4' t WELL PAD'W' IL WELL Ne W-29 Al-BUILT LOCATED I~ P~OTI~kCT[D B~CT. el , T. ~t II. , R. IZ F... FOR : Iq~EPARED. BY ~ KUUKPIK - TECHNICAL BERY. I1~. N Ij l')i,d ~lr I&V d~r Ir ICE BAT[ , NOV. I~, I~ $1$DUAIO:' £I)RANO2a]W29"C'~OsAP SHORT, · Search Radius= 3000 COURSE LINE For ~r'oposed ~ell: W-2~ [12-I6-11212] Location = W-E S-N TVD(SBS) Top &11789.00 5959413.00 -92.00 Bottom 609116.86 5563307.33 8558.00 Note: All depths' in ,Feet Below Kellg Bushing (BKB) Page 1 Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE A029-2052400 MP1511 7300.6 3189.4 7597.5 4894.3 2530.0 A029-2103300 W-T 4454.1 694.1 3924.2 1302.8 2360.2 A029-~177600 W-40 199.8 0.0 200.0 O. 5 586.'0 AOag-2178400 W-39 . 0.9 0.0 0.0 0.0 551.0 W-35 1401.2 0.0 1400.0 4. 8 407.4 A0~?-~180700 W-38 1.3 0.0 0.0 0.0 516.0 A0~9-~180800 W-20 510.0 0.0 500.0 O. 6 317. 5 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE SUMMARY The well which comes closest to the proposed well is: A029-2180800 W-20 Closest approach distance = KICK OFF for this run = 317.5 feet 2800.0 feet _$1$DUAIO: [DRANO23]W29_CLOSAP_SHORT7. LIS; 1 search Radius= 3000 7 DEQREE LEAD LINE For proposed well' W-29 [12-16-11-12] Location = W-E S-N TVD(SBS) Top 611789.00 5~59413.00 -~2.00 Bottom 608662. 18 5962~5~.65 8958.00 Note: All depths in Feet Below Kellq Bushing (BKB) Closest Approach WELL IDENT /PROPOSED% /NEARBY% TVD DEPART TVD DEPART CLOSEST DISTANCE A029-2052400 MP1511 7140.2 3048.8 7597.5 4894.3 2901.9 A02~-2103300 W-T 461~.9 836.8 4017.1 135~.& 2273.3 AO~-~177&O0 W,40 199.8 0.0 200.0 0.5 ~S&.O A0~9-2178400 W-39 0.9 0.0 0.0 0.0 ~I.0 ^029-2177~00 W-35 1401.2 0.0 I400.0 4.8 407.4 A029-2180700 W-38 1.3 0.0 0.0 0.0 51~. 0 A02~-~180800 W-~O 510.0 0.0 500.0 O.b 317. 5 SUMMARY The ~ell ~hich comes closest to the proposed well is: AO29-21BO800 W-20 Closest approach distance = 317. 5 ~eet KICK OFF For this run = 2800.0 ~eet Vertical Intersec*tion /PROPOSED% /NEARBY% TVD DEPART TVD DEPART VERTICAL DISTANCE ALASKA UNITED RIG NO. 3 MUD SOLIDS CONTROL EQUIPMENT 1 - Brandt Dual Tandem-Shale Shaker 1 - Demco 6-12" Cone Shale Desander 1 - Demco 416H w/16 cones & (1) Demco 48H w/16 cones (Desilter) 1- Tri-FIo Horizontal Vacuum Atmospheric Mud Degasser I- 200 gpm Operating Capacity Centrifuge 19- Brandt MA5 Mud Mix Agitators 1- 125 bbl. Trip Tank 1- Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console I- Drilling fluid flow sensor with readout at driller's console 1- Cavium Dewatering screen assembly RIG 3 MUD SYSTEM EXISTING /14UD~ PiTs HOPPEE ALASKA UNITED DRILLING INC. RIG 3 MUD SYSTEM D~WN. BY DATE October 1987 SCALE: NT$ APP~;)VED FILE NO CHECK LIST FOR NEW WELL PERMITS ITEM ~ APPROVE DATE 1, (2) Loc (2 thru (8) (3) (~ thru 13) 10. 'f~.~..~< ~ -mf-~,,~ 11. (10 a~ 13) 12. 13. (4) Casg (14 th~ 22) ($) BOPE ~~.~ (23 thru 28) Company ~/3CO Lease & Well No. /P)~ YES NO Is the permit fee attached .......................................... ~ -- 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... ~_ Does operator have a bond in force .................................. ~ Is .a conservation order needed ...................................... ,, Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... /~ Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............. . .................... ozHm /z /ea (29 thru 31) (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... .,,,_...~ 31. If an offshore loc., are survey results of seabed conditions prese~z~d 32. Additional requirements ............................................. Geology: ,En~ineerin~: WWB~ LCS~ BEW,?~ BEW MTM, RAD / rev: 02/17/88 6.011 / INITIAL GEO. UNIT ON / OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 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. 'o71 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAME : W- 29 FIELD NAME : PRUDHOE BAY BOROUGH · NORTH SLOPE STATE · ALASKA API N-JMBER : 500292183400 REFERENCE NO : 96345 R[CEIVED JAN 0 3 1997' Alaska Oil & Gas Cons. Commission Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN : FLIC REEL NAME : 96345 CONTINUATION # : PREVIOUS REEL : CO~4~ENT · B.P. EXPLORATION, W-29, PRUDHOE BAY, 50-029-21834-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN : FLIC TAPE NAME : 96345 CONTINUATION # : 1 PREVIOUS TAPE : COf4~ENT : B.P. EXPLORATION, W-29, PRUDHOE BAY, 50-029-21834-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: W~29 API NUMBER: 500292183400 OPERATOR: BP EXPLORATION (ALASKA) INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 28-DEC-96 JOB NUMBER: 96345 LOGGING ENGINEER: DECKERT OPERATOR WITNESS: D. BODNAR SURFACE LOCATION SECTION: 21 TOWNSHIP: liN RANGE: 12E FNL: 840 FSL: FEL: 1444 FWL : ELEVATION(FT FROM MSL O) KELLY BUSHING: 92.40 DERRICK FLOOR: 92.40 GROUND LEVEL: 47.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9.625 10386.0 47.00 2ArDSTRING 7.000 10950.0 26.00 3RD STRING 3.500 10182.0 9.30 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11..10 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CNT LDWG CURVE CODE: GRCH RUN NUMBER: PASS NUMBER: DATE LOGGED: 20-JUL-92 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10751.0 10744.5 10729.0 10719.5 10716.5 10701.0 10691.0 10684.0 10675.0 10647.5 10640.0 10633.0 10614.5 10604.5 10599.5 10589.0 10587.0 10568.0 10564.5 10562.0 10549.0 10547.0 10539.5 10528.0 10523.5 10514.5 10499.5 10484.5 10469.0 10468.5 10462.5 10456.0 10455.5 10446.0 10440.0 10429.5 10411.0 10410.0 10371.0 10369.5 10362.0 10357.0 10355.5 10354.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH SIGM 88890.5 88889.5 10752.5 10745.5 10731.5 10721.5 10717.5 10702.0 10692.0 10692.0 10685.0 10676.5 10648.0 10640.5 10634.0 10614.5 10606.5 10601.0 10588.5 10588.5 10568.5 10565.5 10562.5 10550.5 10548.0 10540.0 10528.5 10524.5 10514.5 10500.0 10484.0 10469.5 10469.5 10464.0 10456.5 10456.0 10447.0 10439.0 10429.0 10429.5 10410.5 10410.0 10371.5 10369.5 10364.5 10360.5 10355.5 10355.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 10346.5 10346.5 10346.0 10341.0 10342.5 10337.0 10339.0 100.0 102.0 $ REMARKS: 10348.5 102.5 The depth adjustments shown above reflect cased hole GR to cased hole CNT GR and cased hole SIGM to cased hole GR. Ail other TDTP curves were carried with the SIGM shifts. The cased hole CNT GR was depth shifted to open hole GR. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVU~BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~VA~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10748.0 10298.0 TDTP 10764.0 10298.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINB DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP REMARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. LIS FORMAT DATA No LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 553661 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 553661 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 553661 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 553661 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TP~T TDTP 553661 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 553661 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 553661 O0 000 O0 0 1 I 1 4 68 0000000000 INFD TDTP CPS 553661 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 553661 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 553661 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 553661 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI 553661 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: ** DATA ** DEPT. 10770.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TClFD. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 GRCH. CNT 20. 125 -999.250 -999.250 -999.250 -999.250 -999.250 DEPT. 10300.000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP -999. 250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999. 250 IArArD. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP 27. 672 TENS.TDTP -999.250 CCL.TDTP -999.250 GRCH. CNT -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: TDTP 10760.0 10299.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10739.5 10735.5 10731.5 10726.5 10719.5 10715.5 10711 5 10707 5 10703 5 10699 5 10691 5 10687 5 10683 5 10679.5 10675.5 10671.5 10667.5 10666.5 10663.5 10662.5 10659.5 10655.5 10651.5 10647.5 10639.5 10635.5 10630.5 10627.5 10626.5 10623.5 10622 5 10619 5 10618 5 10615 5 10614 5 10611 5 10610.5 10606.5 10603.5 10602.5 10599.5 10598.5 .......... EQUIVALENT UNSHIFTED DEPTH TDTP 88889.5 88891 . 0 10728.0 10668.0 10663.5 10631.5 10627.0 10624.5 10620.5 10617.0 10612.5 10609.0 10604.5 10601.0 10742.5 10737.0 10732.5 10720.5 10717.0 10713.0 10708.5 10704.5 10701.0 10693.0 10688.5 10685.0 10681.0 10676.5 10672.5 10669.0 10664.5 10660.5 10656.0 10651.5 10648.5 10640.5 10636.0 10628.0 10624.5 10620.0 10615.5 1 0612.0 10604.0 10599.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 10595.5 10594.5 10591.5 10590.5 10587.5 10583.5 10582.5 10579.5 10578.5 10575.5 10574.5 10570.5 10566.5 10563.5 10559.5 10555.5 10551.5 10547.5 10546.5 10543.5 10542.5 10539.5 10538.5 10534.5 10531.5 10530.5 10527.5 10526 5 10519 5 10515 5 10511 5 10507 5 10506 5 10503 5 10502 5 10499 5 10498 5 10494 5 10487 5 10483 5 10482.5 10479.5 10478.5 10475.5 10471.5 10462.5 10459.5 10458.5 10455.5 10454.5 10451.5 10450.5 10446.5 10442.5 10434.5 10597.0 10592.5 10584.5 10580.0 10576.0 10572.5 10568.0 10548.0 10543.5 10539.0 10536.0 10532.0 10527.5 10507.5 10503.0 10499.5 10496.0 10484.0 10479.5 10463.5 10460.0 10456.0 10451.5 10447.5 10442.5 10434.5 10595.5 10591.5 10587.0 10584.0 10580.0 10576.5 10564.5 10561.0 10557.5 10554.0 10549.5 10545.5 10541.0 10533.0 10529.5 10521.5 10517.0 10512.5 10508.0 10504.5 10500.0 10488.0 10484.5 10480.5 10476.0 10473.5 10461.5 10457.0 10452.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 10430.5 10431.0 10427.5 10428.5 10423.5 10424.0 10422.5 10423.0 10419.5 10419.5 10418.5 10419.5 10415.5 10416.5 10411.5 10412.0 10410.5 10411.5 10407.5 10407.5 10406.5 10407.0 10403.5 10403.0 10402.5 10403.0 10399.5 10400.5 10398.5 10399.5 10379.5 10380.5 10375.5 10375.0 10371.5 10370.5 10367.5 10365.5 10363.5 10363.0 10350.5 10351.5 10346.5 10347.0 10339.5 10340.0 10335.5 10335.5 10319.5 10320.5 100.0 100.5 101.0 $ REMARKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 ~o GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 553661 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 553661 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 553661 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 553661 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 553661 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 553661 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 IArND TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 553661 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 553661 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 553661 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 553661 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10763.000 SIGM. TDTP 14.337 TPHI.TDTP 18.197 SBHF. TDTP 39.946 SBHN. TDTP 43 . 811 SIGC. TDTP 1 . 195 SIBH. TDTP 44 . 982 TRAT. TDTP 1 . 544 SDSI. TDTP O. 411 BACK. TDTP 190. 871 FBAC. TDTP 1 O0. 420 TCAN. TDTP 32324.316 TCAF. TDTP 15834. 713 TCND. TDTP 24842. 711 TCFD. TDTP 8911 . 660 TSCN. TDTP 6925. 188 TSCF. TDTP 3392. 442 INND. TDTP 1941 . 135 INFD. TDTP 378. 966 GRCH. TDTP -999. 250 TENS. TDTP 1365. 000 CCL. TDTP O. 000 DEPT. 10299. 500 SIGM. TDTP SBHN. TDTP -999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDTP -999. 250 TCND. TDTP TSCF. TDTP - 999. 250 INND. TDTP TENS. TDTP - 999. 250 CCL. TDTP -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCFD. TDTP -999. 250 TSCN. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP 33. 688 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 10 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10752.0 10299.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TDTP 88888.0 88888.0 88888.5 10739.5 10740.0 10735.5 10736.0 10731.5 10730.5 10727.5 10727.5 10723.5 10723.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 11 10719.5 10719.5 10715.5 10715.0 10711.5 10711.5 10707.5 10707.0 10703.5 10703.0 10702.5 10702.5 10699.5 10699.5 10698.5 10698.0 10694.5 10694.0 10690.5 10690.5 10683.5 10683.5 10679.5 10679.0 10678.5 10678.5 10671.5 10671.0 10667.5 10668.0 10663.5 10663.0 10658.5 10659.0 10655.5 10655.0 10654.5 10655.0 10651.5 10651.5 10650.5 10650.5 10647.5 10648.0 10646.5 10647.0 10643.5 10643.5 10639.5 10639.5 10635.5 10635.0 10631.5 10630.5 10626.5 10627.0 10622.5 10623.5 10615.5 10614.5 10611.5 10611.0 10603.5 10603.0 10602.5 10603.5 10599.5 10598.0 10598.5 10599.0 10595.5 10594.5 10591.5 10590.5 10587.5 10586.0 10583.5 10583.0 10575.5 10575.0 10574.5 10575.0 10571.5 10571.5 10570.5 10571.5 10566.5 10567.0 10559.5 10559.5 10555.5 10555.0 10551.5 10552.5 10546.5 10547.0 10543.5 10544.5 10542.5 10542.5 10539.5 10540.0 10538.5 10538.0 10534.5 10534.5 10522.5 10522.5 10519.5 10520.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 12 10518.5 10515.5 10511.5 10502.5 10498.5 10491.5 10487.5 10483.5 10479.5 10475.5 10471.5 10467.5 10463.5 10455.5 10451.5 10450.5 10447.5 10446.5 10443.5 10439 5 10423 5 10419 5 10418 5 10415 5 10414 5 10411 5 10407 5 10403 5 10402 5 10399 5 10398 5 10383 5 10379 5 10375 5 10371 5 10367 5 10363 5 10362 5 10359 5 10358 5 10355 5 10351 5 10347 5 10343 5 10319 5 100 0 $ 10518.0 10502.0 10498.5 10450.5 10446.0 10418.0 10413.5 10401.5 10398.0 10362.0 10358.5 100.0 10515.5 10511.0 10491.0 10486.5 10482.5 10479.0 10475.5 10472.0 10468.5 10464.0 10456.0 10451.5 10448.0 10443.5 10439.0 10423.0 10418.5 10415.0 10410.5 10406.5 10401.5 10399.0 10383.0 10380.0 10376.5 10374.0 10369.5 10366.0 10362.0 10357.0 10352.5 10348.5 10342.5 10320.5 101.0 REMARKS: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 553661 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 553661 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 553661 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 553661 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 553661 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 553661 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 553661 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 553661 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 553661 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 553661 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 14 * * DA TA * * DEPT. 10752.500 SIGM. TDTP 14.308 TPHI. TDTP 24.267 SBHF. TDTP 38.614 SBHN. TDTP 48. 271 SIGC. TDTP 1 . 007 SIBH. TDTP 54 . 614 TRAT. TDTP 1 . 693 SDSI.TDTP 0.498 BACK. TDTP 178.142 FBAC. TDTP 47.309 TCAN. TDTP 31456.578 TCAF. TDTP 13973. 279 TCND. TDTP 24889. 699 TCFD. TDTP 8536. 609 TSCN. TDTP 7004 . 688 TSCF. TDTP 3111.542 IN1VD. TDTP 2056.084 INFD. TDTP 392.994 GRCH. TDTP -999.250 TENS. TDTP 1395. 000 CCL. TDTP O. 000 DEPT. 10299. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 - 999. 250 SBHF. TDTP - 999. 250 TRAT. TDTP - 999. 250 TCAN. TDTP -999.250 TSCN. TDTP - 999. 250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 34.969 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE~BER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS iVUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUNk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10741 . 0 10300.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 15 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10732.5 10728.5 10724 5 10720 5 10716 5 10712 5 10708 5 10704 5 10700.5 10699.5 10695.5 10692.5 10691.5 10688.5 10687.5 10684.5 10683.5 10680.5 10679.5 10676.5 10675.5 10672.5 10671.5 10660.5 10659.5 10656.5 10655 5 10652 5 10648 5 10644 5 10640 5 10639 5 10636.5 10635.5 10624.5 10620.5 10616.5 10612.5 10608.5 10607.5 10604.5 10603.5 10600.5 10596.5 10592.5 .......... EQUIVALENT UNSHIFTEDDEPTH TDTP 88889.5 10701.0 10697.0 10692.5 10688.5 10685.0 10681.0 10676.5 10673.0 10661.0 10656.5 10640.5 10637.0 10609.0 10605.5 88890.0 10734.5 10729.0 10725.5 10721.5 10717.0 10713.5 10710.0 10705.5 10702.0 10694.0 10689.5 10686.0 10681.0 10677.0 10674.0 10662.0 10657.5 10652.5 10649.5 10646.0 10641.5 10637.0 10625.0 10620.5 10617.0 10613.5 10609.0 10605.0 10600.0 10596.5 10593.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 16 10588.5 10584.5 10580.5 10576.5 10575.5 10571.5 10564.5 10560.5 10556.5 10555.5 10552.5 10551.5 10547.5 10543.5 10540.5 10539.5 10536.5 10535.5 10519.5 10516.5 10515.5 10512.5 10511.5 1O5O8.5 10507.5 10504.5 10503.5 10499.5 10492.5 10488.5 10484.5 10480.5 10476.5 10472.5 10468.5 10463.5 10459.5 10456.5 10455.5 10452.5 t 0451.5 10448.5 10447.5 10444.5 10443.5 10440.5 10439.5 10435.5 10431.5 10427.5 10424.5 10423.5 10420.5 10419.5 10416.5 10577.5 10573.0 10557.0 10552.5 10549.0 10544.5 10540.0 10536.5 10520.5 10516.0 10512.5 10508.0 10504.0 10500.5 10464.5 10461 0 10457 0 10452 5 10448 0 10443 5 10439 5 10435.0 10431.5 10427.0 10423.0 10419.5 10588.5 10585.0 10580.5 10577.0 10565.0 10561.5 10557.5 10554.0 10542.5 10538.0 10518.0 10513.5 10509.5 10505.0 10493 0 10488 5 10485 0 10481 0 10477 5 10473 5 10470 0 10458.0 10453.5 10449.0 10445.0 10441.5 10425.5 10421.0 10417.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 17 10415.5 10416.0 10412.5 10404.5 10403.5 10404 . 0 10400.5 10399.5 10400.5 10396.5 10392.5 10387.5 10388.5 10384.5 10383 . 5 10384.0 10380.5 10379.5 10380.5 10376.5 10375.5 10376.0 10372.5 10371 . 5 10372.5 10368.5 10360.5 10356.5 10352.5 10348.5 10344.5 10339.5 10340.5 10335.5 10335.5 10332.5 10328.5 10320.5 10316.5 100.0 100.0 $ 10412.5 10404.5 10401.0 10397.0 10393.5 10385.5 10382.5 10378.5 10375.5 10372 0 10364 0 10359 0 10354 5 10350 5 10347 5 10335.5 10332.0 10324.0 10321.5 105.0 REMARKS: This file contains TDTP Pass #4 (Base Pass #4). The depth shifts shown above relect GRCH Pass #4 to GRCH Pass #1 and SIGM Pass #4 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 18 TYPE REPR CODE VALUE 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TPtqI TDTP PU-S 553661 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 553661 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 553661 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 553661 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 553661 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 553661 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 553661 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 553661 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 553661 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 553661 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10743. 000 SIGM. TDTP 18. 108 TPHI. TDTP 31 . 538 SBHF. TDTP 48. 318 SBHN. TDTP 51 . 397 SIGC. TDTP O. 750 SIBH. TDTP 62. 784 TRAT. TDTP 1 . 742 SDSI. TDTP O. 627 BACK. TDTP 227. 875 FBAC. TDTP 57. 803 TCAN. 'FDTP 25729. 730 TCAF. TDTP 10485. 643 TCND. TDTP 23264 . 547 TCFD. TDTP 7502. 399 TSCN. TDTP 5627. 260 TSCF. TDTP 2293. 278 INND. TDTP 1928. 521 INFD. TDTP 370. 256 GRCH. TDTP ~ 999. 250 TENS. TDTP 1360. 000 CCL. TDTP O. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 19 DEPT. 10300. 000 SIGM. TDTP SBHN. TDTP -999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDTP -999. 250 TCND . TDTP TSCF. TDTP -999. 250 INND. TDTP TENS. TDTP - 999. 250 CCL. TDTP -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TPHI. TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 SBHF. TDTP TRA T. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP -999.250 -999.250 -999.250 -999.250 40.438 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: O. 5000 FILE SU~gC&RY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10752.0 10300.0 $ CURVE SHIFT DATA ~ PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 20 88888.0 10743.5 10739.5 10735.5 10731.5 10727.5 10723.5 10719.5 10718 5 10715 5 10711 5 10707 5 10706 5 10703 5 10702 5 10699 5 10698 5 10694 5 10690 5 10683 5 10679 5 10675 5 10671 5 10670 5 10667.5 10663.5 10659.5 10655.5 10651.5 10646.5 10643.5 10642.5 10639.5 10638.5 10635.5 10634.5 10630.5 10626.5 10622.5 10618.5 10607.5 10603.5 10602.5 10599.5 10598.5 10594.5 10591.5 10590.5 10587.5 10586.5 10583.5 10582.5 10579.5 10575.5 10571.5 88889.0 10719.5 10707.5 10703.0 10699.5 10695.0 10691.5 10671.5 10647.0 10643.0 10639.5 10635.5 10631.0 10627.5 10623.5 10620.0 10604.0 10600.5 10596.0 10592.5 10588.5 10584.0 88891.0 10746.5 10742.0 10737.0 10732.5 10728.0 10724.5 10720.0 10716.0 10712.5 10708.5 10704.0 10700.5 10684.5 10680.0 10676.0 10672.5 10668.5 10663.5 10660.0 10656.0 10652.5 10644.5 10640.0 10635.5 10607.5 10603.0 10599.5 10591.5 10587.0 10583.5 10580.0 10576.0 10571.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 21 10570.5 10567.5 10566.5 10563.5 10559.5 10555.5 10550.5 10546.5 10543.5 10542.5 10539.5 10538.5 10535.5 10534.5 10530.5 10522.5 10519.5 10518.5 10515.5 10514.5 10511.5 10510.5 10507.5 10503.5 10499.5 10498.5 10494.5 10482.5 10479.5 10478.5 10475.5 10471.5 10470.5 10466.5 10455.5 10454.5 10451.5 10450.5 10446.5 10442.5 10431.5 10430 5 10427 5 10426 5 10423 5 10422 5 10419 5 10418 5 10415 5 10411 5 10410 5 10407 5 10406 5 10403 5 10402 5 10572.0 10567.5 10551.5 10548.0 10543.0 10539.0 10535.5 10531.0 10523.0 10518.5 10514.5 10511.0 10499.0 10495.5 10483.5 10479.0 10471.0 10467.5 10455.5 10451.0 10447.0 10442.5 10430.5 10426. 0 10422. 0 10418.5 10410.5 10407.0 10402.5 10568. 0 10564.0 10560.5 10557. 0 10545.0 10540.5 10537.0 10521. 0 10516.5 10512. 0 10507.5 10504.0 10499.5 10479.5 10476. 0 10472.5 10456.5 10452.0 10432.0 10427.5 10423.5 10419.0 10415.5 10411.5 10407.0 10403.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28~DEC-1996 11:10 PAGE 22 10399.5 10400.0 10398.5 10399.0 10383.5 10384.0 10379.5 10379.5 10375.5 10377.0 10371.5 10374.5 10359.5 10362.5 10355.5 10358.0 10351.5 10354.0 10347.5 10349.5 10327.5 10330.0 100.0 100.5 102.5 $ REMARKS: This file contains TDTP Pass #5 (Base Pass #5). The depth shifts shown above relect GRCH Pass #5 to GRCH Pass #1 and SIGM Pass #5 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 553661 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 23 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TPHI TDTP PU-S 553661 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 553661 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 553661 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 553661 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 553661 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 553661 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS' 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 553661 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 553661 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 553661 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 553661 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10755. 000 SIGM. TDTP 13. 769 TPHI. TDTP 17. 249 SBHF. TDTP SBHN. TDTP 47. 347 SIGC. TDTP 1 . 859 SIBH. TDTP 51 . 078 TRAT. TDTP SDSI. TDTP 0 . 467 BACK. TDTP 218. 100 FBAC. TDTP 65. 681 TCAN. TDTP TCAF. TDTP 14170. 645 TCND. TDTP 24890. 762 TCFD. TDTP 8969. 465 TSCN. TDTP TSCF. TDTP 3189.371 INND. TDTP 2045.116 INFD. TDTP 397.905 GRCH. TDTP TENS. TDTP 1360. 000 CCL. TDTP O. 000 DEPT. 10300. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP - 999. 250 SIBH. TDTP M 999. 250 TRAT. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP -999. 250 TCAN. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP -999. 250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 31.971 1.493 28337.105 6377.800 -999.250 -999.250 -999.250 -999.250 -999.250 49.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 24 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, 4, 5, TDTP $ REM_ARKS: The arithmetic average of passes 1 to 5 was computed after all depth shifts and clipping was applied. $ LIS FORM_AT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 25 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PNAV CU 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PNAV PU-S 553661 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PNAV CU 553661 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN PNAV CU 553661 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PNAV CU 553661 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PNAV CU 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PNAV 553661 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PNAV CU 553661 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 INND PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PNAV CPS 553661 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 553661 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10765.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 110.636 FBAC. TDTP 31.930 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 10300.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 26 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 27. 672 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O0tCO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10764.0 10298.0 TDTP $ LOG HEADER DATA DATE LOGGED: 14 -NOV- 96 SOFTWARE VERSION: 42.2 TIME LOGGER ON BOTTOM: 1215 14-NOV- 96 TD DRILLER (FT) : 10784.0 TD LOGGER (FT) : O. 0 TOP LOG INTERVAL (FT) : 10300.0 BOTTOM LOG INTERVAL (FT) : 10750.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 27 TDTP TDT CARTRIDGE TDTP TDT SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : TNC 50 TND-P 10386.0 BRINE 201.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS NEUTRON DATED 20-JUL-92. PASS ONE BEFORE FLUID PACK-2, 3, 4 & 5 AFTER FLUID PACKED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 28 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS1 CU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS1 PU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS1 CU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS1 CU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 SICC PS1 CU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS1 CU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS1 553661 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS1 CU 553661 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 INND PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS1 CPS 553661 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS1 LB 553661 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS1 GAPI 553661 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS1 V 553661 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 29 ** DATA ** DEPT. 10770.000 SIGM. PS1 SBHN. PS1 232.538 SIGC. PS1 SDSI.PS1 5.519 BACK. PSi TCAF. PS1 9492.605 TCND.PS1 TSCF. PS1 2207.378 IN1VD.PS1 GR.PS1 7.914 CCL.PS1 DEPT. 10296.500 SIGM. PS1 SBHN. PS1 58.820 SIGC. PS1 SDSI.PS1 1.646 BACK. PSi TCAF. PS1 3826.540 TCND.PS1 TSCF. PS1 242.985 INND. PS1 GR.PS1 27.000 CCL.PS1 21.877 TPHI.PS1 0.000 SIBH. PS1 114.523 FBAC. PS1 22674.563 TCFD.PS1 2410.619 INFD. PS1 0.000 46.147 TPHI.PS1 0.196 SIBH. PS1 77.022 FBAC. PS1 12826.889 TCFD. PS1 1928.713 INFD. PS1 0.000 44.209 SBHF. PS1 305.730 TRAT. PS1 29.759 TCAN. PS1 7254.322 TSCN. PS1 440.579 TENS.PSi 76.212 SBHF. PS1 79.625 TRAT. PS1 18.933 TCAN. PS1 2929.257 TSCN. PS1 297.425 TENS.PSi 133.940 1.827 24031.250 5588.145 1130.000 55.805 1.884 16060.570 1029.076 1470.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 R~W CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SOW~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 10760.0 10299.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 30 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 14-NOV-96 42.2 1215 14-NOV-96 10784.0 0.0 10300.0 10750.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDT CARTRIDGE TDTP TDT SONDE $ TOOL NUMBER TNC 50 TND-P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10386.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 201.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS NEUTRON DATED 20-JUL-92. PASS ONE BEFORE FLUID PACK-2,3,4 & 5 AFTER FLUID PACKED. LIS Tape Verification Listing Schlumberger Alaska Computing Center 28~DEC-1996 11:10 PAGE: 31 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS2 CU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS2 PU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS2 CU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 SBHN PS2 CU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS2 CU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS2 CU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TROT PS2 553661 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS2 CU 553661 O0 000 O0 0 8 1 1 4 68 0000000000 BACK PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 INND PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS2 CPS 553661 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 32 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS PS2 LB 553661 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS2 GAPI 553661 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS2 V 553661 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10770.000 SIGM. PS2 15.749 TPHI.PS2 17.333 SBHF. PS2 SBHN. PS2 50.430 SIGC. PS2 2.882 SIBH. PS2 57.508 TRAT. PS2 SDSI.PS2 0.513 BACK. PS2 177.281 FBAC.PS2 75.917 TCAN. PS2 TCAF. PS2 11895.986 TCND.PS2 21257.262 TCFD.PS2 7682.124 TSCN. PS2 TSCF. PS2 2379.348 INND.PS2 1874.750 INFD. PS2 355.679 TENS.PS2 GR.PS2 134.500 CCL.PS2 0.000 DEPT. 10290.000 SIGM. PS2 43.123 TPHI.PS2 80.571 SBHF. PS2 SBHN. PS2 56.133 SIGC. PS2 0.000 SIBH. PS2 73.528 TRAT. PS2 SDSI.PS2 1.250 BACK. PS2 159.891 FBAC. PS2 34.081 TCAN. PS2 TCAF. PS2 3793.839 TCND.PS2 13464.020 TCFD.PS2 3067.174 TSCN. PS2 TSCF. PS2 285.182 INND.PS2 1769.612 INFD.PS2 275.143 TENS.PS2 GR.PS2 27.375 CCL.PS2 0.000 43.363 1.416 23608.402 4721.979 1050.000 55.174 2.056 16038.484 1271.188 1305.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE · 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE ' FLIC VERSION · O01CO1 DATE ' 96/12/28 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 33 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 10752.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10299.0 14-NOV-96 42.2 1215 14-NOV-96 10784.0 0.0 10300.0 10750.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDT CARTRIDGE TDTP TDT SONDE $ TOOL NUMBER TNC 50 TND-P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10386.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 201 . 0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX '. MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 34 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS) '. 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS NEUTRON DATED 20-JULy92. PASS ONE BEFORE FLUID PACK-2,3, 4 & 5 AFTER FLUID PACKED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS3 CU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS3 PU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS3 CU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN PS3 CU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS3 CU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS3 CU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS3 553661 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS3 CU 553661 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 35 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) BACK PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TCAN PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 INND PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS3 CPS 553661 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS3 LB 553661 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS3 GAPI 553661 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS3 V 553661 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10770.000 SIGM. PS3 43.824 TPHI.PS3 70.579 SBHF. PS3 SBHN. PS3 58.431 SIGC. PS3 0.000 SIBH. PS3 78.741 TRAT. PS3 SDSI.PS3 1.201 BACK. PS3 245.798 FBAC. PS3 235.762 TCAN. PS3 TCAF. PS3 9769.814 TCND. PS3 16948.340 TCFD.PS3 5072.221 TSCN. PS3 TSCF. PS3 1104.716 INND. PS3 2038.075 INFD.PS3 299.148 TENS. PS3 GR.PS3 416.000 CCL.PS3 0.000 DEPT. 10297.500 SIGM. PS3 44.014 TPHI.PS3 73.754 SBHF. PS3 SBHN. PS3 55.804 SIGC. PS3 0.000 SIBH. PS3 72.782 TRAT. PS3 SDSI.PS3 1.466 BACK.PS3 178.031 FBAC. PS3 32.917 TCAN. PS3 TCAF.PS3 3867.975 TCND.PS3 13753.064 TCFD.PS3 3149.073 TSCN. PS3 TSCF. PS3 309.801 INND. PS3 1785.100 INFD. PS3 274.539 TENS.PS3 GR.PS3 40.875 CCL.PS3 0.000 55.859 1.807 29414.383 3011.142 1220.000 48.042 1.902 16116.225 1212.820 1285.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 001 CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 36 **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 10741.0 10300.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDT CARTRIDGE TDTP TDT SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 14-NOV-96 42.2 1215 14-NOV-96 10784.0 0.0 10300.0 10750.0 1800.0 NO TOOL NUMBER TNC 50 TND-P 10386.0 BRINE 201.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 37 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL).. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS NEUTRON DATED 20-JUL-92. PASS ONE BEFORE FLUID PACK-2,3,4 & 5 AFTER FLUID PACKED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 38 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS4 CU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS4 PU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS4 CU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 SBHNPS4 CU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS4 CU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS4 CU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS4 553661 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS4 CU 553661 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS4 CPS 553661 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS4 LB 553661 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS4 GAPI 553661 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS4 V 553661 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 10770.000 SIGM. PS4 42.697 TPHI.PS4 74.017 SBHF. PS4 SBHN. PS4 57.104 SIGC. PS4 0.696 SIBH. PS4 75.731 TRAT. PS4 SDSI.PS4 1.153 BACK. PS4 214.334 FBAC. PS4 76.105 TCAN. PS4 TCAF. PS4 17938.824 TCND.PS4 24265.305 TCFD.PS4 7521.946 TSCN. PS4 TSCF. PS4 2234.647 INND. PS4 2061.969 INFD.PS4 372.001 TENS.PS4 GR.PS4 162.250 CCL.PS4 0.000 DEPT. SBHN. PS4 SDSI. PS4 TCAF. PS4 TSCF. PS4 GR. PS4 10290 000 60 406 1 257 4071 441 285 136 44 469 SIGM. PS4 43.497 TPHI.PS4 78.050 SBHF. PS4 SIGC. PS4 0.000 SIBH. PS4 83.222 TRAT. PS4 BACK. PS4 176.695 FBAC. PS4 37.854 TCAN. PS4 TCND.PS4 13314.203 TCFD.PS4 3030.717 TSCN. PS4 INND. PS4 1749.105 INFD.PS4 286.793 TENS.PS4 CCL.PS4 0.000 ~1.639 1.911 52290.398 6090.683 1105.000 49.011 1.947 17017.707 1189.236 1270.000 ** END OF DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 39 **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE · FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 10752.0 10300.0 TDTP $ LOG HEADER DATA DATE LOGGED: 14 -NOV- 96 SOFTWARE VERSION: 42.2 TIME LOGGER ON BOTTOM: 1215 14-NOV-96 TD DRILLER (FT) : 10784.0 TD LOGGER (FT) : O. 0 TOP LOG INTERVAL (FT): 10300.0 BOTTOM LOG INTERVAL (FT) : 10750.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDT CARTRIDGE TDTP TDT SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... TNC 50 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 4O DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10386.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE 201.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NO~IZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS NEUTRON DATED 20-JUL-92. PASS ONE BEFORE FLUID PACK-2,3,4 & 5 AFTER FLUID PACKED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 41 TYPE REPR CODE VALUE 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553661 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS5 CU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI PS5 PU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF PS5 CU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 SBHN PS5 CU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS5 CU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS5 CU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS5 553661 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS5 CU 553661 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TCANPS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TCND PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 INND PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 INFD PS5 CPS 553661 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS5 LB 553661 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS5 GAPI 553661 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS5 V 553661 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 10770.000 SIGM. PS5 44.609 TPHI.PS5 37.085 SBHF. PS5 SBHN. PS5 55.566 SIGC. PS5 0.000 SIBH. PS5 72.243 TRAT. PS5 SDSI.PS5 1.245 BACK. PS5 264.979 FBAC.PS5 126.697 TCAN. PS5 TCAF. PS5 20561.629 TCND. PS5 23063.734 TCFD.PS5 8256.848 TSCN. PS5 TSCF. PS5 2761.730 INND. PS5 2037.423 INFD.PS5 378.072 TENS. PS5 GR.PS5 144.500 CCL.PS5 0.000 49.977 1.253 45380.594 4758.291 1140.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 28-DEC-1996 11:10 PAGE: 42 **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE · ?LIC VERSION : O01CO1 DATE : 96/12/28 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN : FLIC TAPE NAME : 96345 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : B.P. EXPLORATION, W~29, PRUDHOE BAY, 50-029-21834-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/12/28 ORIGIN · FLIC REEL NAME : 96345 CONTINUATION # : PREVIOUS REEL : COf4~ENT · B.P. EXPLORATION, W-29, PRUDHOE BAY, 50-029-21834-00 * Ab.ASEA COMPUTING CENTER * ****************************** ****************************** COMPANY NAME : BP EXPbORATION WELL NAME I w-2g FIELD NAME I PRUDNOE BAY BOROUGH : NORTM SbOPg STATE I ALASKA API NUMBER = 50-029-21834-00 REFERENCE NO : 92444 RECEIVED AUG 2 5 1992 Alaska Oil & Gas Cans. C, ommls$ion Anchorage Tame Veri. flcat:lon bisti, no cblumberger Alaska Computing Center 7-AUG-1992 05:50 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 921081 6 ORIGIN : FLiC REEL NAME ~ 92444 CONTINUATION # P~EVIOU$ REEL : COMMENT : BP ~XPLORATION,PRUDHOE BAY,W-29,500292183400 **** TAPE HEADER **** SERVICE NAME ~ EDIT DATE : 92/08/ 6 ORIGIN : FLIC TAPE NAME : 92444 CONTINUATION # : ~. PRE¥IOU$ TAPE : ~ '~ P ' PRUDNOE BAY,~-29,500292:~83400 COMMENT BP f,X: LORATION, . TAPE HEADER PPUDHOE BAY UNIT CASED HOLE W!RELINE hOGS WELl., NA~E: API NU~RER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGCING ENGINEER~ OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: ~ANGE: WNL: FSL: ~ELt FWL: FLEVATION(FT FRO~ ~$L O) KELLY BUSHING: DERRICK FLOOR: G~OUND LEVEL: WELL CA$I~(; RECORD SURFACE LOCATION 1ST STRING 2ND STRING 3RD STRING PRODUCTION STR!~G W'29 500292~83400 BP EXPLORATION SCHLUMBERGER WELL SERVICES 6-AUG-92 92444 FORMIC~ RICK CRAWFOR 2! 84O 1444 92 40 92i40 47 80 OPEN HOLE CASING ORILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (ET) WEIGHT (LB/FT) 9'625 !0386.0 4~.00 8.500 7.000 10950.0 26.00 PAGEI :hlumberger .las o tlnq Center 7~AUG-1992 05:50 CURVE SHIFT DATA - ALL PA, SuES TO STANDARD(MEASURED DEPTH) BASELINE CURVE FOR SMIFT$ PBU TOOL CODE: PBU CURVE CODE: RUN NUMB. ER: PASS NUMBER: LOGGING COMPANY: BASELINE DEPTH 888~8,0 10774,5 ~0754,0 10744,5 10720,5 10713,5 10690 10685 10683 10633 10606 3.0605 10596 10567 10562 10548 10527 10524 !0524'0 10517,0 1~500'5 ~0485.5 10470 0 ~.0461:0 10457~0 10440.5 10417 0 10407 0 ~039310 10371 5 10369 5 ~0161,0 ~0356,0 R~MARKS~ GRCH 88889,5 10721,5 10715'0 10692,0 !.0685,0 10634,0 10606,5 10560.5 10524.5 10500.0 10469.5 10439.5 10417,0 10406,5 10369.5 10360,5 99.5 1'077 CNTD . 1078 8888g,5 10776 '0 0721 . 5 o 7 ~ 5 ' o !0685,,0 10609.0 I0598,0 10562,5 10547;5 10528'5 10524 0 10517:0 10484,5 10459,5 10456,0 10410,5 10392,0 ~o371.5 10355 5 99~5 THE OPEN HOLE IMFORMATIOD~ SUCH AS LOGGING COMPANY, RUN NIJ~BER AND PASS NUMBER WAS NOT PROVIDED WIT~ THE TAPE SUPPLIED BY T~E CLIENT, T~E DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT CASED HOLE GRC}{ TO OPEN HOLE GR AND CASED HOLE NPH! TO OPEN HOLE MPHI. $ $ PAGEt Ch.lu..m erqer aska COmPut nO Center **** FILE HEADER FIL~ NAME : EDIT ,001 SERVICE ~ FLIC VERSION : O01A07 DAT~ : 92108/ 6 MAX REC $!ZE : 1024 FiLF TYPE ~ FILM HELPER FIL~ NU~BE~:' EDITED CURVES Depth shifted and clipped curves for each pass ~n separate ~tles, P~SS NU~BER~ DSDTM INCREMENT 0,5000 FILF SUmmARY PBU TOOL CODE START DEPTH STOP DEPT~ GRCH 10776.0 10330,0 CNTD 10789,0 I0330,0 CURVE SHIFT DATA - PASS TO PASS(~EASURED DEPTH) BASELINE CURVE FOR SHIFTS PRU CURVE CODE: PASS NUMBER~ ----------EOUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH $ ~aRKS: TMI" FIbE CONT_~INS THE FIRST PASS OF T~E CNTD, NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATP~, LIS FORMAT DATA ** DaTA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ..--.--~.~..............--.~.~. TYPE RMP~ COO~ V~LUE ....~..~......~.......~--..... ! 66 0 2 66 0 3 73 4O 4 66 IS Ta~e Yerili¢ttlon bistino ¢hlumberC~er AlasKa Computin~ Center 7-AUG-1992 05:50 TYPE REPR CODE YALUE 5 66 6 73 7 65 8 68 0,5 13 66 0 !4 65 FT 15 66 68 16 66 0 66 0 ** SET ~ PE CHAN ** NAME SFRV UNIT SERVIC~ AP1 API ID ORDER # bOG TYPE FP T FT 440534 O0 000 P~I CNTD PU-$ 440534 O0 000 NRAT CNTD 4405~4 00 000 CRAT CNTD. 440534 O0 000 NCNT CNTD CPS 440534 O0 000 FCNT CNTD CPS 440534 O0 000 CNTC CNTD CPS 440534. O0 000 CFTC CNTQ CPS 440534 00 000 G~C~ CMTD GAPI ~40534 O0 000 TENS CNTD LB 440534 O0 000 AP1 AP! FII~E NUmB NUMB SIZE REPR PROCESS CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 0 1 i 1 4 68 0000000000 O0 0 1. 1 1 4 68 0000000000 O0 0 ! 1 I 4 68 0000000000 O0 0 1 ! ! 4 68 0000000000 O0 0 ! I ! 4 68 0000000000 O0 0 I 1 1 4 68 0000000000 O0 0 1 ! 1 4 68 0000000000 O0 0 I I I 4 68 0000000000 O0 0 1 1 ~ 4 68 0000000000 O0 0 I 1. ~ 4 68 0000000000, ** DATA ** DMPT. 10789,000 NPHI.CNTD NCNT,CNTD 2836,565 FCNT,CNTD GRCH,CNTD -999,250 TENS~.CNTD DEPT. 10500,000 NPHI,CNTD NCNT,CNTD 6338.000 FCNT.CNTD G~CH.CNTD 54.8~4 TENS.CNTD DEPT, 10330,000 NPHI.CNTD NCNT,CMTD '1873,0~6 FCNT,CNTD GRCH.CNTD 37.688 TENS,CNTD 22,062 NRAT,CNTD 3.901 CRAT.CNTD 710,137 CNTC,CMTD 2951.300 CFTC,CNTD 1540,000 8.974 NRAT,CNTD 2,057 CRAT.CNTD 2999 000 CNTC,CNTD 6647.000 CFTC,CNTO 1458:813 4~,091 NRAT,CNTD 7,688 CRAT.CNTO ~56,385 CNTC,CNTD 1999.055 CFTC,CNTD 1445.000 4.030 726,389 2,252 2820,000 7,~06 287. 50 ** END OF DATA ** IS Ta~e Verification blsti, nq .-hlum erqer A.!aska ComPtltlnc~ Center 7-AUG-199~ 05:50 PAGEs 5 SERVICE : FblC V~SION ! 001A07 DAT~ : 92/08/ 6 ~AX REC SIZE : FIL~ TYPE : LO LAST FILE ~*** FILE ~EADER **** FILM NA~E : EDIT ,002 SERVICE : FL!C VERSIUN : OOl. A07 DATE : 92/08/ 6 ~AX REC SIZE : ~0~4 FIL~ TYPE : LO LAST FILE ~ FILM MEADER FILM NU,BER: 2 EDITED CURVES Depth shifted add clipped curves ~or each Pass ~n separate files, 0,500o p.ASS NUMBER: DEPTH INCREMENT FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH CRC~ 107 6 0 I0330,0 CNTD 10789,0 .~.0330,0 ~URVE SMIFT DATA - PASS TO PASS(MEASURED DEPTM) 'BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS NUMBER: .... ------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DFPTH GRCM CNTD ...... .-;.:; ~8888,0 888 7 888 ~0779,0 107 9. 10770,5 10770,5 ~0754,5 10754.0 ~0744 0 10744,0 10713:5 ~0713.5 ~0694,0 10694.0 ~0691,0 ~0690,5 ~0685,0 10685,0 ~0684.0 10683.5 10654,0 10653,5 chlumberger Alaska Computin~ Center 7-AUG-i992 05:50 ]0640,5 .0633,0 1.05 .5 10587.0 10561.5 10554 0 lossl o 1.0525.0 . 05 ! 7,0 0500.0 10470,0 ~ 04:57.0 ~ 037 J.. 0 ~ 0369,5 .10350,5 100,0 10640.0 ~.0633.0 10587.0 10551.0 ~0528.5 10524'5 105~6.5 10500.5 10470.0 10440.0 I0~69.5 100.0 0625 0 1.0554.0 10457.0 10371,5 10351,0 100,5 THIS FILE CONTAINS THE SECOND PASS OF THE CNTD. TME DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS,:2 GRCH TO PaSS 1 GRCH AND PASS 2 NPHI TO PASS 1 NPHI $ LiS FORMAT DATA DATA FORMAT SP[:CIFICATION ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 9 11 66 25 12 68 13 66 0 14 65 FI 15 66 68 16 66 RECORD ** Tape Verification Listino ~-hlumberoer AlasKa ComPutino Cent. er 7-AUG-1992 05:50 PAGE: ** SET TYPE - CHAN NAMF SERV [INIT SERV!CR API API APl API FILE NUMB NUMB SIZE RKPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEM CODE DEPT FT 440534O0 000 00 0 2 I ! 4 68 0000000000 NPM~ CNTD PU-$440534O0 000 O0 0 2 I I 4 68. 0000000000 ~T C~Z~ 440534O0 000 O0 0 2 1 ! 4 68 0000000000 c~, c~T~ ~oLa~ oo 000 oo o ~ ~ ~ 4 ~ 0000000000 ~c~ C~T~ C~S ~O~a~ oo 000 O0 0 ~ ~ ~ 4 ~8 0000000000 FCNT CNTD CPS 440534O0 000 O0 0 2 ! I 4 68 0000000000 ~,c~ c~ ~.~ ~o~ oo ooo oo o ~ ~ ~ ~ ~ oooooooooo c~,c c~,= c~s ~o~ oo ooo oo o ~ 1 ~ ~ ~, oooooooooo c~,c c~,~ c~s ~4o~ oo ooo oo o ~ ~ i ~ ~. oooooooooo .,~s c~ t,~ ~o5~ o~ ooo o~ o ~ ~ i 4 ~. o~oo~ooooo. DEPT 107849 000 NPHI.CNTD 23.079 NCNT:CNTD 2SS :289 FCN'T.CNTD 636.855 CFTC,CNTD 645,339 TENS,CNTD 1465.000 D~PT NCNT'CNTD CFTC:CNTD 10500,000 NPHI,CNTD 9,923 6514.000 FCNT,CNTD 2686.000 2706,500 TENS,CNTD 1357.375 DEPT 103 ,000 NPH .CNTD 54 ~C~T:C~.T~ ~ o ~oo FC~, C~T~ ~4.7 o CFTCeCNTD 272:903 TEN$,CNTD 1355,000 END OF DATA ** NPAT CNTD N~AT CNTD GRCH:CNTD NPAT,CNTD GRCH.CNTD 250 CNTC;CNTD 2:.2~,~ CEAT,CNTD 57.0 CNTC.CNTD RAT CNTD , 2058, **** FILE TRAILE~ FILE NAME : EDIT ,002 SFRVICE. : FLIC VFRSION : 00lA07 DATF : 92/08/ 6 MAX REC SIZE : 1024 FILF TYPE LAST FILE IS TaDe Veri, flcation List~nq chlumberger Alaska Compt].tlno Center 7'AUG-1992 05:50 **** FILE HEADER **** FILE NANE : EDIT ,003 SERVICE : FL!C VERSIOM : O01A07 DATE : 92/08/ 6 MAX REC:SIZE : FILE TYPE : LO LAST FILE FILF NEADER F!L~ NUMBER: 3 EDITED CURVES Depth shifted and cl~pped curves for each pass ~ separate ~lles, PASS Nt.I~BER: 3 DEPTH INCREMENT 0,50o0 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10776,0 10330,0 ¢~TD 10789.0 10330,0 $ CURVE SHIFT DAT~ - PASS TI) PASS(~EASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODF: PASS NUMBER: GRCH ----'-----EOUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH GRCH CNTD ----.-- ...... 0 8~888.0 88888 5 !0776i5 10777~0 ~0770 5 10770,5 ~0756 0 ~0756.0 ~753,5 lo754.o !0732,0 10732,0 ~o719.5 !o7~o.5 lo7~o.o ~07~2.0 10713.5 1.0698,0 10699,5 .0693,0 10693,0 10690,5 ~0690,5 ~0657,0 {.0657,5 10654,5 10655.0 10605,0 10605,5 ~0601,0 1,0601.5 10584,5 105~5,0 !0551.0 10551.5 ~0527,0 10527.5 ].0514 0 10514.0 .0469:5 10470,0 ~o451.o lo45~.$ IS TaPe Vertflcatlon Listing :~lumberger ~,l. as~a ¢:omr~utinO Center 7-AUG-1992 05:50 10439 10406 ~0396 10392 !0360 !0355 100 SREMARKS~ 5 I0440,0 0 10406,5 5 10396,5 5 5 10361.0 0 0 100.5 10393,0 10356.0 lOl,O THIS FILE CONTAINS THE THIRD PASS OF THE CNTD.. THE DEPTH ADJUSTMENTS SHOWN ABOVE; REFLECT PASS 3 GRCH TO PASS 1 GRCH AND PASS 3 NPHI TO PASS I NPH!, $ bis FORMAT DATA · PAGEI ** DATA. FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** '''"~''''''~'''''''TYP R R CODE .... ~;[~' 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0 5 11 66 1~ 68 13 66 0 14 65 FT i5 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** .... .... ..... ........ ...-........,,..........,,................... N~M SEE U IT SE~V CE AP1 ! iPI APl FILE Nil NUMB SI REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD Nt!~B SAMP EDEN CODE (HEX) DFPT FT 440534 O0 000 O0 0 3 1 1 4 68 0000000000 NPH! CNTD PI]-S 440534 O0 000 O0 0 3 1 1 4 68 0000000000 NRA? CNTD 440534 00 000 00 0 3 1 1 4 68 0000000000 CWAT CNTD 440534 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CHTD CPS 440534 O0 OOO O0 0 3 1 ! 4 68 0000000000 FCNT CNTD CPS 44053~ O0 000 O0 0 3 1 ! 4 68 0000000000 GRC~ CMTD GAPI 440534 O0 000 O0 0 3 1 1 4 68 0000000000 IS Tape verification Llstinq shlumberger Alaska Computing Center 7-AUG-!992 05:50 PAGB:I ·, · NAMF SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CNTC CNTD CPS 440534 O0 000 O0 0 3 ! ! 4 68 0000000000 CFTC CMTD CPS 4405)4 O0 000 O0 0 3 I I 4 68 0000000000 TENS CNTD LB 440534 00~ 000 O0 0 3 ! I 4 68 0000000000 DATA DEPT I0330.000 NPHI,CNTD 58 200 ~CNT~C~TD ~946.392 FCNT.CNTD 255~802 CFTC.C~TD 257.199 TENS.,CNTD 1375.000 END OF DATA NRAT'CNTD GRCH,C'NTD NRAT.CNTD GRCH,CNTD NRAT,CMTD GRCN,CNTD , 4, t37 CRAT.CN?D -999.250 CNTC'CNTD ~C,CNTD 8 CN'TO C. T. · 671~ ''458 .500 2076 **** FILE TRAILER **** FILF NA~E ~ EDIT ,003 SERVICE : FLIC VERSION : O0~A07 DATE : 92/0R/ 6 MAX REC SIZE ~ 1024 FILE TYPE LAST FILE **** FILM HEADER **** FILE NA~ : EDIT ,004 SERVICE : FLIC VERSION : O01A07 DATF : 92/08/ 6 M~X REC SIZE : 1024 F!bE TYPE : bO bAST FILE FILF ~EADER FILE NUMBER: 4 EDITED CURVES Depth shifted and cl].pved curves for each pass in separate ~tles, IS Tame Ver~ficatlon Li$tino ~-hlumDergerAlaska Computing Center 05:50 PASS NUMBER: 4 D~PTH INCREMENT 0,5000 FILE SUmmARY PBU TOOL CODE START DEPTH G~CH 10776.0 CNTD 10789.0 $ STOP DEPTH 10330,0 BASELINE DEPTH GRCH CNTD 88888,0 88888.0 88888,5 ~0778,~ !0779,0 ~.077~, !0771,0 ~0753,5 10753,5 10743,5 10744,0 !07~9.0 10729,0 ~070~,0 10702,5 '069 .0 '0699,5 I067~ 0 t067~.5 o6~ :o ~,o~3~.~ ' Io I:o o6 s.o -060 5 1.0605.0 10595,5 I0596,5 10574.5 10575,0 ~o55~ o ~oss~.o ~o55o:5 ~o551.o ~i0527 0 10527,5 .o523:5 ~o524.5 ~.0516,0 105~6 5 ~0497.5 1049~:5 ~0493 5 10494.5 .0467:5 10468,0 10450.5 10451.5 ~0446.0 10447.5 ~0441o5 !0442,5 10410.5 10410.5 10411.0 ~0406.0 ~0406,5 ~o~7~'5 1o~73.5 ~o555 o toa55.5 loo~o !oo.5 ~o~.o $ - -------EQUIV.ALE. 3f UNSHIFTED DEPTH------- - THIS FILE CONTAI~S THE FOURTH PASS OF THE CNTD. THE DEPTH ADOI!ST~E~TS SHOWN ABOVE REFLECT PASS 4 GRCH TO PASS ~ GRC~ AND PASS 4 NPHI TO PASS I NPHI. S CURVE SHIFT DATA - PA. SS TO PAS$(~EASURED DEPTH) BASELINE CURVE FOR S~IFTS PBU CURVE CODE: GRCH P~SS NUMBER! cblU~berger .Alaska Computing CeD. ret LIS FORMAT DATA 7-AUG-1992 05~50 PAGEs ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REP~:CODE VALUE: I 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 ~5 12 68 13 66 0 14 65 FT 15 66 68 !6 66 1 0 66 1 ** SET TYPE - CHAM ** N~MF SERV UNIT SERV!CR API API API AP! FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE {HEX) ~m~mmmmmmmmmmm~mmmmmmmmmm~mmmmmm~m~mmm~mm~mmmm~mm~mmm~mmmm~m~m~m~m~Mm~m~~`~ DEPT FT 440534 O0 000 O0 0 4 1 I 4 68 NPHI CNTD PU-$ 440534 O0 000 O0 0 4 t 1 4 68 N~A~ C~TD 440534 O0 000 O0 0 4 1 1 4 68 CRAT CNTD 440534 O0 000 O0 0 4 ! t 4 68 NCMT CNTD CPS 440534 O0 000 O0 0 4 I 1 4 68 FCNT CNTD CPS 440534 O0 000 O0 0 4 ~ 1 4 68 G~CH C~TD GAPI 440534 O0 000 O0 0 4 ! 1 4 68 CNTC C~TD CPS 440534 O0 000 O0 0 4 1 1 4 68 CFTC CNTD CPS 440534 O0 000 O0 0 4 ! i 4 68 TENS CNTD LB 440534 O0 000 O0 0 4 ! 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 10789,000 MPP,.I.CNTD 26.736 NCNT,CNTD 2736 ~8 FCNT CNTD 597 543 CFTC,CNTD 636:176 TEN$:CNTD 15~0:000 NRAT,CNTD GRCH.CNTD 4.553 CRAT.CNTD -999,250 CNTC.CNTD 4.640 2897.193 D~PT, NCMT .CNTD CFTC, CN'TD ,, 0500,000 NPMI.CNTD 16689,000 FCN.~, . CNTD 2773,250 TE~S.CNTD 10 N'PH .~30.000~ ! C~TD 86.978 FCN'T:CNTD 277.257 TENS-CNTD DEPT NCNT: CNTD CFTC.CNTD ** EMD OF DATA ** 7-AUG-!992 05:50 9 13902375 52,324 293,505 1360,000 MRAT'CNTD GRCH,CNTD NRAT,CNTD GRCH.CNTD 6~' 19~ CRAT-CNTD .61, CMTC.CNTD CNTC' CMTD **** FILE TRAILE~ **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSiOM : 001A07 DATE ~ 92/08/ 6 ~AX REC SIZE I ~024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FIL~ HAME I EDI'T .005 SERVICE : FLIC VERSION I 001A07 DATE : 92/08/ 6 MAX REC SIZE : 1024 FILM TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic avegage o~ edited Dasses ~or all curves ~ulsed Meutron% Unavera~ed edited~ass ! Oamma ray and bac~round counts] arithmetic oi edited static baseline passes for all other curves. DEPT~ !MCRE~ENT 0.5000 P~SSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS CN D ~, ~, 3, 4, ~E~ARKS: THE ARITHMETIC AVERAGE OF PASSES 1 THRU 4 WAS COMPUTED AFTER ALL DEPTH ADJUSTMENTS ~ERE APPLIED. $ LIS FORMAT DATA ]CS ?a~-e Verificatlo~ blstinq chlumberqerAlask:a ¢,,omPut~n~ Center 7-AUG-lg92 05:50 ** DATA FOR'~IAT ePE(.IFICATION RECORD ** ** SET T m~ 1 66 2 66 3 73 5 66 6 73 7 65 8 68 9 65 ~! 66 13 66 1.4 65 15 66 !6 66 0 66 TYPE - 64EB.** PE REPR CODE VALUE 0 0 40 0,5 FT 25 0 FT 6B ! I ~T ~ ** Sf.~.' TYPE CMAN ** NAMF SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S.AMP ELEM CODE (HEX) DEPT FT 440534 O0 000 O0 0 5 I I 4 68 0000000000 NPHI CNAV PU-S 440534 O0 000 O0 0 5 1 1 4 68 0000000000 N~AT CMAV 440534 O0 000 O0 0 5 I 1 4 68 0000000000 C~Aw CNAV 440534 O0 000 00 0 5 i ~ 4 68 0000000000 NCNT CNAV CPS 440534 oo 000 oo 0 5 I I 4 68 0000000000 FCNT CN~V CPS 440534 O0 000 O0 0 5 ! 1 4 68 0000000000 CNTC CNAV CPS 440534 O0 000 O0 0 5 ~ 1 4 68 0000000000 CFTC CN~V CPS 440534 O0 000 O0 0 5 ~ 1 4 68 0000000000 G~CH CNAV GAP! 440534 O0 000 O0 0 5 1 I 4 68 0000000000 T~NS CNAV LB 440534 O0 000 O0 0 5 1 I 4 68 0000000000 mm~mmmmmmmmmmmmm~m~mmm~m~mmm~mmm~mmm~mmmmmm~mm~mmm~m~mmm~m~mmm~mm~mm~m~mm~~m~m ** DATA ** DEPT. 10789.000 NPHI.CNAV 24,165 NRAT,CMAV 4,166 NCN~.CNAV 2648.668 FCNT,CNAV 633,758 CMTC,CNAV 2800,41~ G~CM,CNAV 64.8,571 TEN$,CNAV 1501,250 D~PT 10500 000 NPHI CNAV 9,792 NRAT.CNAV 2.216 NCNT.'CMAV 65~6:250 FCNT;CNAV 2751,688 CNTC,CNAV 6714.625 G~C~.CNAV 61,382 TENS.CNAV 1 ~98.484 CFTC NAV CRAT.CNAV CFTC.CNAV 4.)07 648,57! 2,365 2731.938 TaPe verification Llst~Ing chlumberger AlasKa CompUtlng Center 7-AUG,199~ 05:50 EPT.: 10330,000 NPNI'C~}AV 53,209 NRAT,CNAV D NCNT,CNAV 1909,.322 FCNT,CNAV 267,603 CNTC,CNAV GRC~,CNAV 41,242 TEN$.CNAV !383,750 7.65I CRAT.CNAV 2043.543 CFTC.CNAV 69 ? 5 2 273, ** END OF DATA **** FIb~ TRAILER **~* FILE NAME : EDIT ,005 SERVICE : FLIC VERSION : 00IA07 DAT~ : 92!0g/ 6 MAX R~C SIZE : 1024 FILE TYPE : L0 LAST FiLE : **** FILE HEADER **** FILE NA~E { EDIT .006 SERVICE { FLIC VERSION ~ 001A07 DATE : 92/08/ 6 MA× REC SIZE : 1024 FILE TYPE ~ LO LAST FILE : FIL~ ~EADER FILE NUMBER 6 R~w CURVES Curves and log Leader data ~or each pass in separate files; raw bacK,round Pass in last file PASS NUMBER{ DEPTH INCREgEMT: -.5000 # VENDOR TOOL CODE START DEPTH $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E bOG~ER ON B.T7 TD DRILLE~ (FT): TD LOGGER(FT): TOP LOG INTERVAL BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FP~R): DEPTH CONTROL USED (YES/NO): STOP OEPTH i0325.0 ~0-J~h-92 CP 3 .6 830 20-JUL-92 10908.0 10792.0 10328.0 {0787.0 900.0 NO chlumberger Alasl<a Computing Center 7-AUG-199~ 05:50 ¸16 TOO[, STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CNTD COLLAR LOCATOR CAL-UB-I~69 CN'TD AUXlbLIARY MEAS.~ MOD.~ $ BOREHOLE AMD CASING DATA OPEN HOt, E BIT SIZE (IN): DRILLERS CASING DEPTH (FT)~ 10386.0 LOGGERS CASING DEPTH BORENObE CONDITIONS FLUID TYPE: PRODUCED FLUID FLUID DENSITY SURFACE TEMPERATURE (DEGF): 48.0 BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SAbI"ITY FLUID L~VEL FT) FLUID RATE AT ~ELLHEAD ~ATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG)t NEUTRON TOOL TOOL TYPE (EPITHERNAL OR THERMAL): MATRIX: SANDSTONE MATRIX DENSITY: ~,65 HOLE CORRECTION (IN): BI~UEL~NE COUNT RATE NORMALIZATION IN OIL ZONE TOD NOR~ALIZI~!G WINDOW SASE NORMALIZING WINDOW (FT): ~LUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COU~T RATE LOW SCALE (CPS)~ 0 FAR COUNT RATE }4IGH SCALE (CPS): 5000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS)~ 2~000 TOOL STANDOFF {IN): ~E~ARKS: TIED INTO SWS BHCS 10-AUG-88 WELL SHUT-IN 23:00 7-19-92 TO CONDITION WELL P~IOR TO LOGGIN~ Gqc KEY ~ELL; LOG~ED~ 4 PASSE~ 8 900 FPH. EXPERIE~CEb GAS BI~BBLE ON SECOND PASS ~ )o715' DELETED THIS & RE-R~N IT. $ LIS FORMAT DATA IS TaPe Verification Listt. ng :hlumberger AlasKa ComPuting Center 05:50 DATA FORMAT SPECIFICATION ~ECO~D ** SET TYPE - 64ES ** TYPE REPR.CODE VALUE ! 66 0 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FI i~ 68 13 66 0 t4 65 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAMF SERV UNIT SERVICE API AP! API AP1 FILE NUM'B NUMB SIZE REPR PROCESS ID CIRDER # LOG TY,.E CLASS MOD NUMB SAMP ELEM CODE' DEPT FT 440534 00 000 00 0 6 I 1 4 68 0000000000 NP~! PS1 PU 440534 00 000 00 0 6 1 ! 4 68 0000000000 RTN~ PS1 440534 00 000 00 0 6 1 1 4 68 0000000000 TNRA PSi 440534 O0 000 00 0 6 I 1 4 68 0000000000 RCNT PS1 CPS 440534 00 000 00 0 6 1 1 4 68 0000000000 RCFT PSi. CPS 440534 00 000 00 0 6 1 ! 4 68 0000000000 CNTC PS1 CPS 440534 00 000 00 0 6 1 1 4 68 0000000000 CFTC PS~ CPS 4405~4 00 000 00 0 6 1 1 4 68 0000000000 GR PSi GIPI 440534 O0 000 O0 0 6 1 1 4 68 0000000000 TENS ~S1 LB 440534 00 000 00 0 6 1 I 4 68 0000000000 CCh PSi V 440534 00 000 0O 0 6 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmNm~mmmmm#mm~#~M~#mm~mm~N# DMPT. 10789,000 NPNI.PSl 20.672 RTNR,PSl 3,783 TNRA,PSl RCN~.PS! ~B{~,836 ~CFT,PSl 743,978 CNTC,PS! 2935,782 CFTC,PS1 GP,P$! 63,625 TENS,PS1 1540,000 CCh,PSI 0,000 DEPT 10500.000 NPHI.PS1 8 231 RTNR,PS1 !,995 TNRA.PS! RCNT]PS1 6571,573 RCFT,PS1 31803771 CNTC,PSI 6779 635 CFTC,PS{ G~,P$1 56,313 TENS.PSI 1450' 000 CCh,PSi 0:000 763,878 2.149 3100'973 tS Tame Verification LlstinO :hlumberoer AlasKa Computlnq Center 7-AUG-1992 05:50 !8 DEPT, 10325.000 NPMI.PS! ~CNT,PS! 1666.830 RCFT.PS1 GR,PS! 35,031 TENs'PSi 48.131 RTNR.PSI 256.934 CNTC,PS1 1.435.000 CCL,P$! 6.727 T~RA.P$! 1776.406 CFTC.PSi '0.000 7,110 249 '490 ** END OF DATA ** **** FILE FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001A07 DAT~ : 92/08/ 6 ~AX RFC SIZE : 1024 FILE TYPE : LO LAST FiLE **** FILE HEADER **** FIL~ NA~E : EDIT .007 SERVICE : FLIC VERSION : 001A07 DATE : 92/08/ 6 MAX AEC SIZE ~ I024 FILE TYPE : LO LAST FILE : FILF HEADER FILM NUMBER 7 RAW CURVES Curves amd 1oo header data for each pass in separate files; raw bacKoround oass in last i~le PASS NUUBER: 2 DEPT~ INCREMENT: -.5000 # FILE SUMMARY YENDOR TOOL COrsE START DEPTH CNTD {0789.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGE~(FT): TOP LOG INTERVAL (MT): ~OTTO~ bOG INTER~AL LOGGING SPEED {FPHR): DEPTH CONTROL USED (YES/NO): STOP OEPTH 10325.0 20-dUb-92 CP 32.6 830 20-JUL-92 1090~.0 10792.0 10328,0 lO787,0 900,0 ~,blumberger Alaska Computing Center 7-AUG'1992 05:50 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD COMPENSATED NEUTRON CNTD AUXILLiARY SEAS, CART, C~TD COLLAR LOCATOR CNTD AUXILLIARY MEA$,: ~£iD, $ BOREHOLE AND CASING DATA OPEN MOLE BIT SIZE (IN): DRILLERS CASINGD~ EPTH LOGGERS CASING DEPTH ('T):F BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE'TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT 'WELLHEAD WATER CUTS GAS/OIL RATIO~ CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): EATRiX: ~ATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORgAb!ZI~G WI~DOW BASE NORMALIZING WINDOW BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE {CPS)! FAR COUNT RATE HIGH SCALE {CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL NUMBER CNC-DA 10~ ATC-CB 0538 CAL-UB-1269 ATM'AA"374 !0386,0 PRODUCED FLUID 48,0 201.,0 SANDSTONE 2.65 0 Soo0 0 ~2o00 TOOL STANDOFF ~E~ARKS: TIED IHTO SWS BH¢S ~0-AUG-88 WELL S}~UT-IN 23:00 7-19-92 TO CONDITION WEb[, PRIOR T~ LOGGING. AP~[)×I~ATE GCC O 106~0' KEY WELl,; [OGGED'4 PASSE~ @ 900 FPH. EXPERIENCED GAS BUBBLE ON SECOND PASS 0 10715' DELETED THIS g RE-RAN IT, $ LIS FORMAT DATA :blumberger AlasKa Computt gn~ Center 7-AUG-lEg2 05:50 PAGE~ ¸2o ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 11 66 2] !2 68 t3 66 0 14 65 FT' 15 66 68 16 66 1 0 66 1 m~m~m~mmm~mmm~mm~mmm~mm~m ** SET TYPE - CHAN ** MAME SERV UNIT SERVICE API APl API APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB BA~P EbEM CODE (HEX) DFPT FT 440534 O0 000 O0 0 7 1 1 4 68 NPHI PS2 PU 440534 O0 000 O0 0 7 1 1 4 68 RTN~ PS2 440534 O0 000 O0 0 7 1 1 4 68 TN~ PS2 440534 O0 000 O0 0 7 1 1 4 68 RCNT PS~ CPS 440534 O0 000 O0 0 7 1 1 4 68 RCFT PS2 CPS 440534 O0 000 O0 0 7 I 1 4 68 CNTC PS~ CPS 440534 O0 000 O0 0 7 1 1 4 68 CFTC PS2 CPS 4405~4 O0 000 O0 0 7 1 I 4 68 GR PS2 GAPI 440534 O0 000 O0 0 7 1 1 4 68 T~NS PS~ LB 440534 O0 000 O0 0 7 1 1 4 68 CCL PS2 V 440534 O0 000 O0 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmm~mmmmmmmmmmm~mmmmmmmm#~mmmmmmmmmmMmmmmmmmmmmmmmmmmmm~mmmmmmmmm~m~mmmmm~~m~mm ** DATA ** DFPT. 10789,000 NPHI,PS2 22.870 RTNR,PS2 RCMT PS2 2547,822 RCFT.PS2 663.~96 CNTC,PS2 GP:PS2 62,125 TENS,PS2 1485.000 CCL.P$2 DFPT 10500 0~0 UPHI.PS2 8.703 RTNR,PS2 ~CN~'PS2 6553~8 o ~CFT.PS2 3236.855 CUTC.P$2 G~:PS2 57.063 TENS.bS2 1370.000 CCL,PS2 3.878 TNRA.PS2 2677.282 CFTC,PS2 0.000 2.020 TNRA.PS2 6885.664 CFTC.PS2 0.000 4,138 647,7!7 2,214 'o o.vo KS Tape verlflcat~o~ Listing. ~blumberger'Alaska CompUtin.,.O Center 7-AUG-1992 05:50 DEPT'. 10325,000 NPHI.PS2 RCMT,PS2 1697.0~5 RCFT.PS2 GR,PS2 43,531 TENS,PS2 END OF DATA 50. 560 RTNR.PS2 254.58! CNTC.PS2 1350.000 CCL.P$2 6 848 TNRA.PS2 1819 367 CFTC.PS2 0 000 244.! 57 **** FILE TRAILER FILE NAME : EDIT ,007 SERVICE ~ FbIC VERSION : 001407 DATE : 9~/08/ 6 ~AX REC SIZE : 1024 FILF TYPE { LO I,,AST FILE **** FILE ~EADER FIL~ NA~E : EDIT ,008 SERVICE { FLIC V~SiON : 00iA07 DATE % 92/08/ 6 ~A× REC SIZE J 1024 FIL~ TYPE : LO bAST FILE FIbF HEADER FILE NU~[;E~ ~ RAW CURVES Curves and log header data for each pass in separate files; raw background Pass in last file P~SS NUmBeR: 3 DFPTH INCREMENT: -.5000 # FIL~ SUmmARY VENDOR TOOL CODE START DEPTH '"'"'"'" .... i;';'"'"' CNTD 7 9.0 LOG HEADER DATA DATE bOGGED: SOFTWARE VERSIONS: TI~E LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTO~ LOG INTERVAL (FT): LOGGING. SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 20-JUL-92 CP 32.6 830 20-JUL-92 10908.0 10792.0 10787.0 900,0 NO :blumberqer ~laska Computlnq Center 7-AUG-1992 05:50 TOOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE CNTD CO,PENSATED NEUTRON CNTD AUX!LLIARY ~EAS, CART, CNTD COLLAR LOCATOR CNTD AUXILLIARY NEAS. NOD. $ TOOL CNC-DA ATC-CB CAL-UB-1269 AT~'AA'374 BOREHOLE AND CASING DATA (]PEN MOLE BIT SIZE DP!LLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10386.0 B~REHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIO: CHOKE PRODUCED FLUID 48, '0 20!.0 NEUTRON TOOL TOOL TYPE (EPITHER~<Ab MATRIX: ~ATRIX DENSITY: HOLE CORRECTION SANDSTON~ 2.65 B!.,UELINE COUNT RATE NOR~ALIZATION IN OIL ZONE TOP ~![3P~ALIZING WINDOW (FT): BASE NOR~,ALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR CO{!NT PATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5000 NEaR COUNT RATE LOW SCALE (CPS): 0 NEAR CO[~UT RATE HIGH SCALE (CPS): ~2000 TOOL STANDOFF (IN): PEMARKS: TIED INTO SWS BHCS 10-AUG-88 W~LL SHUT-IN 23500 7-19-92 TO CONDITION WELL PRIOR TO bUGGING. APPROXIMATE GOC M ~06~0' KEY WELl.,; LOGGED 4 PASSE~ @ 900 FPH. EXPERIENCED GAS BUBBLE ON SECOND PASS 0 10715' DELETED TMIS g RE-R~M IT, $ LIS FORMAT ~ATA ~ lUmberger Alaska Computln Center 05:50 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE YgLUE 1 66 0 2 66 0 3 73 44 4 66 ? 65 8 6~ 9 65 1~ 66 12 68 !3 66 0 14 65 FT 15 66 68 16 66 0 66 3. ** SET TYPE - CHAN ** N~MF S~RV UNliT SERVICE API AP! APl AP! FILE NUMB ~UMB SIZE R~PR PROCESS ID ORDER # bOG TYPE CI..,ASS MOD NUMB SAMP ELEM CODE (NEX) DEPT FT 440534 00 000 00 0 8 3. 3. 4 68 NDHI P$3 PU 440534 00 000 00 0 8 1 I 4 68 RTN~ PS3 440534 00 000 00 0 8 1 1 4 68 TNR~ P$3 4~0534 00 000 O0 0 8 1 I 4 68 RCNT P$3 CPS 440534 00 000 00 0 8 1 1 4 68 RCFT PS3 CPS 440534 00 o0o 00 0 8 1 ! 4 68 CNTC PS] CPS 440534 O0 000 O0 0 8 1 1 4 68 CFTC PS3 CPS 440534 00 000 00 0 8 3. I 4 68 GR PS3 GAPI 440534 00 000 O0 0 8 I 1 4 68 TENS PS3 LB 440534 00 000 00 0 8 1 I 4 68 CCI~ PS3 V 440534 O0 000 00 0 8 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mm~m~mmmmm~mmmmmm~mmmm~mm~mmmmmmm~mmm~#mm~m~m~m~#~m~#m~m~m~m~m~mm~mm~ ** DAT~ ** DEPT 10789,000 NPHI,PS3 23.458 RTNR,PS3 4,000 TNRA,P$3 RCNT~PS3 ~435,653 RCFT,PS3 614,762 CNTC,PS3 2573.604 CFTC,PS3 GE,PS] 76,438 TENS,PS3 1480,000 CCh. PS3 0.000 DFPT, 10500.000 NPHI PS3 10,437 RTNR,PS3 RCNT.PS3 6551,830 RCFT:PS3 2515.569 CNTC,PS3 GP,PS3 6§.625 TENS,PS3 1385.000 CCL,PS3 2.370 TNR~.PS3 6729 344 CFTC.PS3 · 0[000 4 216 63.0:368 2 453 2637:473 [S Tare Verification Listinq :hlum~er~er Alaska Com~uting Cent, er 7~AUG-1992 05:50 7,:t03 TNRA.PS3 1.80~,992 CFTC,PS3 .000 END OF DATA **** FILE TRAILER FILE NAME : EDIT ,008 SERVICE : Fb!C VERSION : O0!A07 DATE : 92/08/ 6 ~AX REC SIZE ~ 1024 FiI, E TYPE : I..,0 bAST FILE : **** FILE HEADER **** FILE NAME = EDIT ,009 SERVICE : FL!C VERSION : 001A07 D~TE : 92/08/ 6 ~AX RFC SIZE = 1024 FILE TYPE : LO LAST FILE : F!LF HEADER FILF NU~BER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last t~le PASS NUMBER: 4 DEPTH INCREMENT: -.5000 # FII, F SUMMARY VENDO~ TOOL CODE START DEPTH C~TD. 10789.0 bOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI"E LOGGER OM BOTTOm: TD DRILLER (FT): TD LOGGER(ET): TOP LOG INTERVAL ~OTTO~ LOG INTERVAL (FT): I,OGGING SPEED CFPHR)! DEPTH CONTROL USED (YES/NO): STOP DEPTH 10325,0 20-JUL-9~ CP 32,6 830 20-JUL-92 10900.0 10792 0 10328:0 10787.0 900.0 =hlUmberger aska Comput nOj Center 05:50 ToOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTD COMPE~SATE. D NEPTRON CNTD AU×ILL!ARY ME~$, ~ART, CNTD COLLAR LOCATOR C~!TD AUX~LI, IARY SEAS, ~OD, $ BOREHOLE aMD CASING DATA OPEN ~OLE BlT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH ~OREHOLE CONDITIONS FI, UID TYPE~ SURFACE.{~g~PERATURET~DEGF): BOTTOM r. ubf TEMPERA {.iRE (DEGF): FLUID SALINITY FLUID bEVEL FT) FLUID RATE ~T WELLHEAD WATE~ CUTS GAS/OIL RATIO{ C,,OKE NEUTRON TOO!, TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: ~ATRIX DENSITY: ~OLE C~RRECTION (IN): FLUMLINE COUNT RATE NORMALIZATION IM OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW BLUEbINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS) NEAR COUNT ~ATE bOW SCALE (CPS): NEAR COl.!MT RATE HIGH SCALE (CPS): TOO[,, NUMBER CNC:-DA 10:[ ATC CB 0538 CALmUB-! 69 AT~.AA,3724 PRODUCED FLUID 48.0 201.0 SANDSTONE 2.65 0 5000 0 22000 TOO[, STANDOFF fiN): RE~ARKS: TIED TMTO SWS BHCS lO-AUG-88 WELL SHUT-IN 23:00 7-19-92 TO CONDITION WELL PRIOR TO LOGGING. APPROXIMATE GOC M 10620'. KEY wELL; LOGGED 4 PASSES ~ 900 FPH, EXPERIENCED GAS BUBBLE ON SECOND PASS ~ ~07~5' DEDETFD TMIS g RE-RAN IT, $ FORMAT DATA IS TaDe vertfl..catt-on bist'inq :hlumberger Alaska Computing Center 7-AUG-!99?. 05:50 ¸26 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64ED ** TYPE REPR. CODE VALUE ~ 66 0 2 66 0 3 73 44 4 66 5 66 6 7 65 8 68 'I1 66 12 68 !3 66 0 14 65 FT !5 66 68 ~6 66 0 66 ** SMT TYPE ,- CMAN ** Nn~E SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUmB SIZE REPR PROCE$8 ID ORDER # b..G TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 440534 O0 000 O0 0 9 1 1 4 68 NPHI PS4 Pt! 440534 O0 o00 O0 0 9 I I 4 68 RTNR PS4 440534 O0 000 O0 0 9 1 ! 4 68 TN~A PS4 440534 O0 000 O0 0 9 ! 1 4 68 RCNT PS4 CPS 440534 O0 000 O0 0 9 ! 1 4 68 RCFT PS4 CPS 440534 O0 000 O0 0 9 1 1 4 68 CNTC P$4 CPS 440534 O0 000 O0 0 9 1 ! 4 68 CFTC PS4 CPS 440534 O0 000 O0 0 9 I 1 4 68 G~ P$4 GAP! 440534 O0 000 O0 0 9 1 I 4 68 TFN8 P$4 LB 440534 O0 000 O0 0 9 1 1 4 68 CCL P$4 V 440534 O0 000 O0 0 9 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ~m~m~mm~mmmm~mmm~mmmmmmmmm~m~mmmmm~mmmm~mm~mmmmmmm~mm~mmm~mmmmmmm~m~m~m~mmm~~mm ** DATA ** DEPT. 10789 000 ~P"I.P$4 22.810 RTNR.PS4 RCNT,PS4 2932i947 RCFT,PS4 62~,879 CNTC,PS4 G~,P$4 48 844 TENS,PS4 150 ,000 CCL,PS4 DFPT 105(!0 000 NP~I.PS4 9 99~ RTNR,PS4 RCNT:P$4 b217:326 RCFT,PS4 2555:556 CNTC,PS4 ¢;P.P$4 64,750 TENS,PS4 1410' 000 CCh,PS4 4.025 TNRA.P$4 2926,776 CFTC.PS4 0.000 2.323 TNRA,PS4 6620,022 CFTC,PS4 0.000 4,130 658,242 2.392 2645,726 Tame Verification bist,lnq :hlumberqer Alaska ComputiDg Center 05:50 DiEPT. !0325,000 MPMI.PS4 RC~!T,PS4 !7~8,8~0 RCFT.P$4 GR.PS4 42.3~3 TENS'PS4 53.422 RTNR,PS4 241,480 CNTC,PS4 1360,000 CCh,PS4 7.226 TNRA.'PS4 ~'078 CFTC.PS4 t81 .000 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT ,009 S~RVICE : FLIC VERSION I 00lA07 DATE : 92/08/ 6 ~X REC SIZE : !024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE : 92/08/ 6 ORIGIN : FLIC TAPE NAME : g~444 CONTINUATION # : ~. P~EV!OUS TAPE : CO~ENT : BP ExPLORATION,PRUDHOE BAY,W-29,50029~8~400 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 92/08/ 6 ORIGIN : FLIC REEt NA~E : 92444 CONTINUATION # : P~EvIOUS REEL : CO~ENT : BP EXPLORATION,PRUDMOE BAY,M-29,500292183400 COMPANY NAME : BP ExpbORATION WEbb NAME : W-29 FIELD NAME ~ PRUDHOE BAY BOROUGH ~ NORTH SLOPZ STATE : ALASKA API NUMBER ) 50-029-218)4-00 ~EFERENCE NO : 74669 :hlum~erg~r laska Computing Center **** REEL HEADER SERVICE NAME : EDIT DATF : 91/08/ ORIGIN : FL!C REEL NAME : 74669 CON'TINt)ATION # : PREVIOUS REEL COM)4'ENT : BP EXPLORATIOM,PRUDHOE 8AY,W-29,50-029-21834-00 **** TAPE HEADER **** SEPVICE NAME : EDIT DAT~ : 91/08/ 8 ORIGIN ~ FLIC TAPE NAME : 74669 CONTINUATION # : ~ P~MVIOUS TAPE : ~ ~'~ PRUDMOE BAY,W-29,50-O~9-21834-O0 COMMENT : BP EXP.:..~ORATION, .. TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NIIMBER~ OPERATOR: LOGGING COMPANY: TAPE CREATION DATE~ dOB LO~GIMG EMGIMEER~ OPERATOR SUPFACE LOCATION SECTIONS TOW~SHIP~ RANGE: FNL: FSL: FEL: FWL: EbEVATI~N{FT FROM MSL O) KELLY BUSH~NG: DERRICK GROUMD LEVEL: WELL CASING RECORD SU~FACF LOCATION W-29 50-029-21834 BP EXPLORATION SCHLUNBERGER WELL SERVICES 8-AUG-91 74669 '~ JOHNSON : TRAV S 21 12E 840 1444 92,40 47,80 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - AL!, PASSES TO STANDARD(MEASURED DEPTH) BASELINE CURVM FOR SHIFTS PBU TOOL CODE: 8CS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH [FT) WEIGHT CLB/FT) ''~'''''''''12 50 ''';~'''9 5 ..... 1038 ~T''''O '''~'''''''''47. 8,500 7:000 10950.0 26.00 3.500 10~8~.0 9.30 PAGe: ~BU CURYE CODE: DATE LOGGED: LOGGING 88888, I07~7~ 10763. 10759, 10755, 10751. 10747, 10743, ~0735, 1071!. 10707' 10703, 10699~ 10695' 10679' I0675~ 10651 10647 5 10643 5 10619 5 1.0615 5 10603 5 10599 5 10579 5 10575 5 10571 5 10559:5 · 10555 5 10551 5 10543 5 10539,5 10535,5 10531.5 10519.5 10515 5 1o5oa15 lO499.5 lO495"5 lO479,5 lo475,5 10471.5 10459'5 lO455.5 10451.5 10419°5 1o415.5 10411,5 10403.5 10399.5 10371,5 10367.5 10363,5 100.0 NE DEPTH 0 5 5 5 5 5 ,5 5 5 5 5 5 5 5 5 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 GR 1 I !O-AUG-88 8CHLUMBERG~]R ----------EQUIVALENT CNTD 88887,0 I0766.5 10762'5 10758 0 10753 5 10 0 10~50 45 5 10740 5 10732 5 1071!,0 10707,5 10703 5 0699 0 0695 ,5 0679 5 0675'0 0651 0 0646 5 0643 0 0619 0 0615.5 0604.0 0599,5 057 5 o57 :o 0570,5 0558'5 10555.~0 10550.5 10542,5 10538,0 10534.0 105~9.5 10517.5 10513'0 10501,0 10496.0 10492,5 10476.5 10472.0 10468.5 10456.5 10453.0 10448.5 10416.5 10413,0 1040g.5 10401.5 10397.0 10369,0 10364.5 10361.0 g7.5 UNS~!FTED DEPTH---------,- $ BASELINE DEPTH 10771.5 10767 · 5 10763.5 ~0759~5 10755~5 10751,5 10747' 5 10739, 5 ~ o 7 3 5 ,; 5 10731'5 1071 ! ' 5 1.0707; 5 1.0679.5 10663 ~ 5 1. 0647' 5 10643 5 0639 5 0603 5 0599 5 O595 5 0591 5 0583 5 0579 5 0575 5 0567 5 0563 5 0559'5 0555.5 0539.5 0535.5 0531.5 05275 0503!5 0499 5 0495.5 0483.5 0479'5 0475.5 0471.5 0467.5 0463,5 0459,5 0455.5 10451,5 10443.5 I0439,5 10435.5 10431,5 10427.5 10423.5 10419,5 10403 5 10399:5 10395.5 10391,5 GRCH 88887,5 10771,0 10767.~ 10763. 10759,5 10756,0 10752'i~ 10747. 10739.0 10735,5 10732 :~ 10720 10712'0 !0708,5 10699'~ 10679'ii 10662, 10646' 10642.~ 1,0639, 10603.~ 1,0599"0 0595'~ }0591. 10583'5 10579,0 10575 10563,§ 10560, 10555.~ I0539, 10536,0 10531 10526 ~ 10502 10498 ~ 10494 10482 ~ 10478,0 10474.0 10470.5 10466,5 ~0462.0 10458,5 10454,5 10450 10437,~ 10434, 10430,~ 10426, 10422,0 10418.5 10402.~ 10398, 10394.~ 10390, 10375.5 10371 5 10367 5 10363 5 10359 5 10355,5 lo~si '5 103 5 loo,o $ RE,ARKS: 10386,0 !03@2,0 10374,5 10370,5 10366'0 t0362'5 10358,5 10355,5 10351'5 10347,0 99,5 **** FILE HEADER *~** FILE NAME : EDIT ,001 SERVICE FLIC VERSION : 001A06 DATE : 91/08/ 8 ~AX REC SIZE : !0~4 FILE TYPE : LO LAST FILE : FILE HEADER ~ILE NUMBER: 1 ED%TED CURVES Depth shifted and climPed curves for each Pass In separate files. 1 ',5000 PASS NUMBER: DEPTH INCREMENT FILE SUMMARY PBU TOOL CODE CNTD GRCH $ START DEPTH 10780'0 STOP DEPTH 10330 0 10330:0 CURVE SHIFT DATA - PASS TO PASSCMEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GR PASS NUMBER: --- ....... EOUIVALENT UNS~IFTED DEPTH---~------ $ ~E~ARKS: PASS ONE DATA HAS BEEN DEPTH ADJUSTED TO THE OPEN HOLE 1S Ta~e Verification Listing ¢hlumberger Alaska Computing Center 8-AUG-1991 11:25 PAGE{ DA. IA, G~ ...0 G9 AND NPHI TO NPHI:, TgESE SHIFTS ARE INDICATED IN THE.. TAPE HEADER COM'MENTS, ' # LIS FORMAT DATA TABLE TYPE : CONS TUN! VALU DEF! TYPE BP EXP oR ¢ O Company ame P..UDHOE BAY Field Name WM W-29 Well Name APIN 50-029-21834-00 API Serlal Number FL 840 FNL & 1444 FEb Field Location SECT 2! Section TOWN llN Township RAN~ 12E Range COUN NORTH SLOPE Coont¥ STAT ALASKA State or Province NATI USA Nation LATI Latitude LONG Longitude SON 42585 g Service Order Number PDA~ MSL Permanent datum EPD FT 0. ElevatiOn of Perm. Da L~F DF Lo~ Measured From APD FT 92.40001 ABOVE PERMANENT DATUM EKB FT -999.25 Elevation of Kelly Bu EDF FT 92.40001 Elevation of Derrick EGL FT 47 8 Elevation of Ground L TDD FT 10~75. Total DePth - Driller TDb FT 10796~ Total DePth - Logger BLI FT 10793, Bottom Lo~ Interval T~,I FT 10330. Top Lo Interval DFT PRODUCED FLUIDS Drtlli~ Fluid T~Pe. DFD G/C3 Drilling Fluid Denslt ZONE DFPM Drilling Fluid Ph ZONE DFv CP Drilling Fluld Viscos ZOME DFL F3 O, Drilling Fluid boss RES OHMS ReslstlVltY of Mud Sa ZONE MST DEGF Mud~Sample Temperatur ZONE R.FS OHMS Resistivity of mud fi ZONE MFST DEGF Mud Filtrate Sample T ZONE R~CS OHM~ Resistivity of Mud Ca ZONE ~CST DEGF Mud Cake Sample Tempe ZONE STEM DEGF 50. Surface Temperature B~T DEGF Bottom Hole Temperatu ZONE IS Tape Ver~.iiCation Listing :hlu~berger !.asRa Comput~nd Center 8-AUG-199~ I1:~5 PAGE: 3 TABLE TYPE : ZONE TUNI BDEP TDEP DFD DFPH DFV RMS MST RMFS MFST RMCS MCST I FT O. O' 0 , O. O. O. O. O, O, O. O, O, TABLE TYPE : CURV DEFI D nn 1EpT DePth Cha e Name NPH] Compensated Neutron Poroslt¥, 85 Matrix, cal!& dead time corr, N~AT Neutron Ration Non-Dead time Corrected(N/F) CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate TE~S Surface Tension CRAT Neutron Ratio, Dead Time Corrected (RN/RF) FCNT Raw Far Detector Count rate, Dead Time Corrected NCNT Raw Near Detector Count ~ate, Dead Time Corrected G~CH Gamma Ray in Casln~ ** mATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VAbUE I 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0 5 9 65 F~ 1! 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 IS Ta~e verification Listing chlum~erger AlasKa Computlnq Center ** SET TYPE.- CHAN ** · . . ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ESE.i..' M CODE (HEX) DEPT FT 425589 00 NPHI CNTD PU-S 425589 00 N~AT CMTD 425589 00 CNTC CMTD CPS 425589 00 CFTC CNTD CPS 425589 00 TENS CNTD LB 425589 00 CRAT CNTD 425589 00 FCNT C~TD CPS 425589 00 NCNT CNTD CPS 4255~9 O0 GRCH CNTD GAPI 425589 O0 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 I 1 ! 4 68 0000000000 000 O0 0 I ! ! 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 ! 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 1 I ! 4 68 0000000000 DATA DFc. PT, CFTC.CMTD N C ~' C N T O 10792.000 NPHI.CNTD 30 ~06 709'221 TE~S.CNTD 1510~ 00 714,134 GRCH.CNTD -999'~50 iO330.000 NPHI C~'~D 48 263 270,393 TENS.CNTD 1,390:000 260.304 GRCH.CNTD 37,031 DEPT. CFT._ CNTD NC~ ...~,.~T CNTD END OF DATA NRAT.CNTD CRAT,CMTD NRAT,CNTD CRAT,CNTD 4.905 CNTC.CNTD 5.045 FCNT.CNTD 7.200 CNTC.CNTD 7.125 FCNT,CNTD 3421,365 357 ,837 2003. 997 1986"696 **** FILE TRAILER **** FILE NA~E : EDIT .001 SFRVICE : FLIC V~iRSION : O01A06 D~TF : 91/08/ 8 MAX REC SIZE : 1024 F!LF TYPE : LO LAS· FILE : **** FILE HEADER **** FILF NA~E : EDIT .002 SFRVICE : FLIC VERSION ~ 00lA06 DATF : 91/08/ 8 ~AX REC SIZE : 1024 FIb~ TYPE : LO L~ST FILE : [$ Tape Verification Listing 2hlum~erger Alaska ComP..~tlng Center 8-AUG-1991 :25 FILE HEADER FILE NUMBER: EDITED CURVES Depth ~bifted PASS NUMBER: DEPTH INCREMENT FILE SUMMARY PBU TOOL CODE CNTD GRC~ $ and cl~Pped curves for eac~ pass -,5000 START DEPTH STOP DEPTH 10793,0 10~0,0 10780,0 10 30'0 CURVE SHIFT DATA - PASS TO PASS(~EASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE~ GRCH PASS NUMBER: 88888 10775 10771 10767 10731 107~7 10715 10711 10707 10703 10699 10695 10691 10683 10679 10675 10667 10663 10659 10655 10651 10647 10643 10631 10627 10623 10619 10615 10611 10607 10603 10575 10571 !NE DEPTH CNTD 0 88888.0 5 10775.5 5 10771'0 5 10767,5 5 10731,5 5 10727,0 5 10715.,0 5 10710,5 5 10707,5 5 10704.,5 5 10701,0 5 10696,0 5 10692,5 5 10684,5 5 10680,0 :5, 10676,0 ,5 10668.5 .5 10665,0 ,5 10661,0 ,5 10656,5 ,5 10652.5 :5 10648,0 5 10643,5 ~5 10631.5 5 10627.0 .5 10623.0 .5 10618.5 .5 10614.0 .5 10611.5 ,5 I0607,5 .5 10604.0 .5 10576,0 ,5 10571.5 in separate f~les. ---'EOUIVALENT UNSHIFTED DEPTH""--''-'-' PAGE; ~. lu~berger hlas~a ComPutlno Center 10555,5 10539 ;5 ! O535 ~ 5 I0531;5 10523 .~ 5 1. 0519' 5 105115 5 1051, :5 1O5O7,5 10503,5 10491 , 5 10487,5 10475,5 1..0471 · 5 046~ 5 1,04 5 10423 5 10419 5 10415 5 10411 5 10375 5 10371 5 1036.3 5 I0359 5 10355 5 100 0 $ BASEl. 88888,0 10771,5 10763.5 1,0759,5 10755,5 10751.5 10747,5 10743,5 10739.5 10735.5 10731.5 10715,5 10711.5 10707,5 1068'7,5 10683 5 10679~5 10675 5 10671~5 1O659.5 10655,5 10651 o5 10647.5 10~4~o5 106~1,5 INE DEPTN 10556,0 10540,0 10536,5 10532.,0 10524,0 10519'5 10515,0 1051,1,5 !0508,0 10503 ~ 10491~ 10488'0 10476,0 10471,5 1046~ 0 1043 ~0 10427,5 10423'5 10420i0 10415'5 I0412'0 10376,0 !0372,~5 10364,5 10360,0 10355,5 100,0 GRCH 88888,5 10772,0 10763,5 10759,5 10755,0 10750.5 10747.5 10744.0 10739.0 10734,5 10731.5 10715.5 10712,0 10707.5 10687,5 10684.5 10680,0 10675.5 10672.0 10660.0 10655.5 10651.5 10647,0 10644,0 10632.0 8-AUG-t991 1t:25 PAGE{ lumberqer AlasKa (.om utin6 Center 10627,5 10623,5 !0595,5 10591,5 10583,5 10579,5 10567,5 10563,5 10559,5 10555,5 10551.5 10547,5 10543,5 10539,5 10535,5 10531,5 10519,5 10515,5 10511 5 10507 5 10503 5 10499 5 10495 5 10491 5 10479 5 10475 5 10451. 5 I0447 5 10431 5 10427.5 23 J. 0415,5 10411,5 10407.5 10403.5 10399 5 1o391:5 10387,5 103B3,5 10379.5 10375 5 10359,5 10355.5 100,0 S # REdA LIS FORMAT DATA 10627,5 10624'0 10596,0 10591.,5 10583~5 10580,0 10568,0 10564 5 10560 0 10556 0 10552,5 10548,0 1054],5 10540,0 10535,5 10532'0 10520,0 10515.5 10512.5 10508,0 10504,5 10500'5 10496,0 10491'5 10479,5 10476,0 10452.0 10448,5 10432,5 !0428.0 10424.0 10419.5 10416.0 10412.5 10408,0 10403,5 1040O 0 10388.5 10384.5 10380,0 10375.5 10372,0 10360.0 10355.5 100.0 8-AUG-i991 11:25 [$ Ta~e VerSfication Listing 8-AUG-199! 11:25 pAGE: :hlum~eroer Alaska Computing Center TABLE TYP.~ : CONS TUNI .... VALU. DEFI T'YPE CN BP EXP:LO~ATION Compan~ Name PRUDHOE BAY Field 50-029-21834~00 840 FNL & t444 FEB 2! NORTH SLOPE ALASKA USA 589 FT 0 FT 92.40001 FT -999,25 FT 92,40001 ~T 47,8' FT 10175, FT 10796, FT 10793, - FT 10330~ PRODUCED fLUIDS ~/C3 F~ APIN SECT TOWN RANG STAT NATI LATT LON~ W!TN SON PDAT EPD EKB EDF EGL TDD TDL DFT DFD DFPN DFV DFL RMFS MFST R~CS ~CST STE~ C? F3 DHMN D~GF OH~ DEGF DEGF 0~ Well Name API Serial Number Field Location Section Township Ranoe County State or Prov~nce Nation Latitude Lon.ltude Witness' Name Service Order Number Permanent datum Elevation of Perm, Da 500 Measured From ABOVE PERMANENT DATU~ ~levat~on of Kelly Bu Elevation of Derrick. Elevation of Ground L Total Depth - Driller Total Depth - Logqer Bottom LOQ I~terval TOp Log Interval Drillino Fluid TyPe Drilling Fluid Denslt 'ZONE Drliiin~ Fluid eh ZONE Drl ..ln~ll Fluid ¥1scos ZONE Drillino Fluid Loss ResistiVity of Mud Sa ZONE Mud. Sample Temperatur ZONE Resistivltv of mud fi ZONE ~ud Filtrate Sample T ZONE Resistivity of Mud Ca ZONE Mud Cake Sample Tempe ZONE B~T OEGF 50, Surface Temperature Bottom Hole ~emperatu ZONE mm~mmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmm'mmm~mmm~mmmm~m'~mmmm~m mmmmmmmmmmm~mm~mm~m.mm.mm~m~ [$ Ta~e Ver. lflcatlon Listinq 2blUmb'erger Al. asKa Computing Center B-AUG-1991 11:~5 TYPE : ZONE TUN! BDEP TDEP DFD DFPH DFV RES MST RMFS MFST RMCS MCST I FT 0, 0. O, O, O. O. 0,. O, O, O, O, TYPE : CUR'V DEFI DEPT Depth Channel Name MPHI ComDensated Neutron Porosity, SS Matrix call & dead time corr, NRAT Neutron ~ation Non-Dead time Corrected iN/F) C~TC Corrected Near Det.ctor COunt Rate CFTC Corrected Far Detector Count Rate TENS Surface Tension CRAT Neutron Ratio, Dead T~me Corrected (RN/RF) FCNT Raw Far Detector Count rate, Dead Time Corrected NCNT Raw ~ear Detector Count Rate, Dead Time Corrected GRCN Gamma Rav In Casing ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALU 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 11 66 25 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 £S Tape Verification LiDsting 8-A~G-i. 99!. 11:25 PAGE: 10 ~ lu~beroer AlasKa Com utlnO Center ** SET TYPE - CHAN ** -.-....--~ .... ..-....-.-....,.....,...---....,-,.... .... ---.......~------ ..... .......-.. NAME SE UNIT SERVICE API A 'I API AP :ILE NUMB NUMB ZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX) · DEPT O0 O0 O0 0 2 I 1 4 68 000000000 NPHI CMTD PU-S 425589 O0 000 O0 0 2 ! 1 4 68 NRAT CMTD 425589 O0 000 O0 0 2 ! 1 4 68 CNTC CNTD CPS 425589 O0 000 O0 0 2 I I 4 68 CFTC CNTD CPS 425589 O0 000 O0 0 2 1 I 4 68 T~NS CNTD LB 425589 O0 000 O0 0 2 1 1 4 68 C~AT CNTD 425589 O0 000 O0 0 2 1 1 4 68 FCNT CMTD CPS 425589 O0 000 O0 0 2 I 1 4 68 NCNT CNTD CPS 425589 O0 000 O0 0 2 I 1 4 68 GRCH CNTD GAPI 425589 O0 000 O0 0 2 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** :DEPT. CFTC,CNTD NCNT.CNTD 10792,000 758 270 798 226 ** END O? DATA ** NPH~ CNTD 27,049 NRAT,CNTD 4 489 TEN i:C~TD 1480.000 CRAT.CNTD 4:679 GRCH,CMTD 999,250 CNTC,CNTD FCNT,CNTD 3465,956 3401.993 **** FILE TRAILER **** FILE NAME : EDIT ,002 SERVICE : FLIC VERSION : O01A06 DATE : 91/08/ 8 MAX REC SIZE : ~024 FIL~ TYPE : bO LAST FILE **** FILE HEADER **** FILE NAME ~ EDIT ,003 SERVlCE ~ FLIC VERSION : O0~A06 DATF ~ 91/08/ 8 MAX ~EC SIZE : 10~4 FIbF TYPE : LO LAST FILE FILE HEADER FILE NI}MBER: IS Tape Ver.!flcat~or~ l. ist~.ng :hlumb'erger Al. asK computing Center 11:25 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 3 DEPTH INCREMENT -,5000 FILE SUMMARY PBU TOOL CODE START DEPTH CMTD 10793,0 GRCH 10780,0 $ CURVE SH~FT DATA - PASS TO P~SS(MEASURED DEPTH) BASELINE CURVEi FOR SHIFTS PBU CURVE CODE~ GRCM PASS NUMBER: 1 for each Pass STOP DEPTH 330,0 BASEL 10775 107~2 107~7 10699 10651 ~06~7 10643 10639 ~0619 106~5 10611 10607 10575 10571 10559 1O555 10547 10543 1.0539 10535 10523 1O519 10515 10511 ln5O7 10479 10475 10467 10463 10455 10451 1O447 10423 10419 XN~ DEPTM 0 5 10775.5 0 10722'0 5 I0716,0 5 10700,0 5 10652,0 5 10647.5 5 i0644,0 5 10639,5 5 10619,5 5 10615 0 5 10611 5 5 10608 0 5 10576,0 ,5 10571,5 ~5 10559,5 5 10556,0 ,5 10548 0 .5 10544:5 .5 10540.0 ,5 10536,5 ,5 10524.5 ,5 10520,0 .5 10515,5 ,5 10511,5 ,5 10508,0 .5 10480.0 .5 10475,5 ~5 10467.5 5 10464.0 ,5 10456,0 ,5 10451,5 '5 10448.0 ,5 10424.0 .5 10419,5 In seDarate files. ----------EQUIVALENT UNSMIFTED DEPTH---------" CNTD 88888.0 PAGE: 11 Tape verification !,ist~nq :hlUmberger Alaska CompUting Center 8-AUG-!ggl 11:25 PAGE~ 12 10415.5 10415.5 10411'5 10412,0 10383.5 10384~0 i0379.5 !0380,5 I0371,5 10372.5 10367,5 10368'0 100.0 100.5 BASELINE DEPTH GRCH 8888~.. 88888,0 0776'5 10776,5 10720 10719,5 10692'5 la692,5 10583-5 I0584'5 10554 0 10554.5 10492 5 10492.0 10480 5 10481,0 10361 0 !0361,5 !00,0 !00'5 $ # $ # LIS FOR~AT DATA CN F~ APIN SECT COUN STAT' NATI PDAT EPD APD ~DF FT FT FT FT FT BP EXPLORATION PRUDHOE BAY ~-29 50-029-21834-00 840 FN[., & 1444 FEI, 21 12E NORTH SLOPE ALASKA USA 5589 O. DF 92.4000! -999.25 92o4000~ 47.8 Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness' Name Service Order Number Permanent datum Elevation of Perm. Da Lo Measured From ABOVE .... PERMANENT DATUM Elevation of Kelly Su ~levation of Derrick Elevat~on of Ground b IS Tape Ve.riflcation Listing :hlumberqer' AlasKa computln~ Center 8-AUG-Ig91. 11:25 PAGg: TONI VALU DEFI TYPE TOD FT 10175. Total Depth - Driller TDL FT 10796, Tota! Depth - Loo~er BLI FT 10793. Bottom hOq Interval TL! FT 10330~, To Lo~ Interval D% PRODUCED FLUIDS Dr~l lnq Fluid TYpe DFD G/C3 Drtl lnQ Fluid Densit ZONE DFV CP Dr i,~ lSCOS ZONE DFL F3 0. Drllli~ Fluid Loss R~$ 0H~M Resistivity of Mud Sa ZONE MST DEGF ~ud Sample Temperatur ZONE R .~S OHMM ResistiVitY of mud fi ZONE MFST DEGF ~ud Filtrate Sample T ZONE R~CS OHMM Resistivity of MUd Ca ZONE MCST DEGF Mud Ca~e Sample Tempe ZOME ST.E~ DEGF 50. Surface Temperature ,BMT DEGF Bottom Nole Temperatu ZONE TABbE TYPE : ZONE TUN! BDEP TDEP DFD DFPH DFV RM$ ~ST RMFS MFST R~CS ~CST BHT FT 0. 0. 0. 0. O, 0. 0. O, O, O. O, Oe T~BLE TYPE :CURV DEFI '''';'D~P .... De ;'th ....C~annel'''''''';;''Na .... ''''''''''''''''''''''''''' NPH7 Compensated. Neutro~ Porosity, SS ~atrix, call & dead time corr. N~AT Neutron Ration Non-Dead time Corrected (N/F) CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate TMNS Surface Tension CRAT ~eutron Ratio, Dead T~me Corrected (RN/RF) FCNT Raw Far Detector Count rate, Dead Time Corrected NCNT ~aw Near Detector Count Rate, Dead Time Corrected GRC~ ~amma Ray in Caslmg luMberger. Ala$.~ ComputlnQ Center 8-~UG-1991 11~25 ** DATA FORMAT $,. ~' . ~PECIFICATION RECORD ** ** SET TYPE - 64EM ** TYPE REPR CODE 'VAbUf; ! 66 0 2 66 0 3 73 4O 4 66 5 66 6 73 7 65 8 68 0 5 !! 66 25 13 66 I4 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB NtJ~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUmB SAMP ELEM CODE (HEX) DEPT FT 425589 00 000 O0 0 3 ! I 4 68 NPH! CNTD PU-S 425589 00 000 O0 0 3 I ! 4 68 N~AT CNTD 425589 O0 000 00 0 3 ! 1 4 68 CNTC CNTD CPS 425589 O0 000 00 0 3 ! I 4 68 CFTC CNTD CPS 425589 00 000 00 0 3 1. 1 4 68 TENS CNTD LB 425589 00 000 00 0 3 1 1 4 68 CRAT CNTD 425589 00 000 O0 0 3 1 ! 4 68 FCNT CNTD CPS 425589 00 000 00 0 3 ! 1 4 68 NCNT CNTD CPS 425589 00 000 00 0 3 ! 1 4 68 GRCH C~TD GAPI 425589 O0 000 00 0 3 ~ I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 !4 ** DATA ** DFPT. 10792,000 NPHi.CNTD 32.075 NRAT,CNTD 5 375 CFTC.CNTD 547.773 TEN$.CNTD 1510.000 CRAT,CNTD 5:29) NCNT.CNTD 544,102 GRCH.CNTD -999.250 CMTC CNTD FCNT:CNTD 2786.236 2800'000 ** END OF DATA Tape Ve~l~Ication Listing :hlumb~rger !asEa Comput~,n~ Center 8-AUG-!991 11:25 **** FILE TRAILER **** FILE NAME : EDIT ,003 SERVICE : FLIC VERSION : O01A06 DATE t 91/08/ 8 MAX REC SIZE : !0~4 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT ,004 SERVICE : FLIC VERSION : O01A06 DATE : 91/08/ 8 MAX REC SIZE : 1024 FILE TYPE : bO LAST FILE : PAGES 15 FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and cl~.pPe, d curves for each Pass lm separate files. PASS NUMBER: 4 ' ' DEPTH INCREMENT -,5000 FILE S~!~MARY PBU TOOL CODE START DEPTH STOP DEPTH CNTD 10793 0 10330,0 GRCH 10780:0 10330.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: GRCH PASS BASELINE DEPTH 10775,5 10771.5 10767,5 10759.5 10755.5 10739.5 10735,5 10731.5 10727,5 10723,5 -- ..... ---EQUIVALENT UNSHIFTED DEPTH---------- CNTD 88888.5 10776.0 I0771,5 IO768.0 10760.0 ~0756,5 10740.5 10737.0 !0733.0 10728,5 10724,0 chlUmBerger A aska Comput ng Center 10719.5 10715'5 10711.5 10707.5 1060 5 lO6, ,5 10671.5 10651.5 10647.5 10635.5 10631,5 }0627,5 0623.5 10615 5 I0611 5 10607 5 10603 5 10539.5 10535:~ 051051,~ .0483 10479,5 10475.5 10471.5 J0467.5 10463.5 10459.5 10455.5 10451,5 10447,5 10443.5 10439 5 1043515 10431'5 10427.5 10423 5 1o4 515 10411.5 10403.5 10399.5 J0383.5 10379.5 10375.5 J0371.5 10367.5 10363.5 lO359 5 100:0 BASELINE DEPTH ''';~888 ....... 0720,0 ~0715,5 10711,5 10708,0 10704.0 10700'5 1067 0 10653'0 10648'5 10636,5 I06.33.,0 106219.0 10624'5 10616'5 !0612.,0 10608,0 10604,5 10540.5 I0537,0 10521,0 10516,5 I0488,5 10485,0 I0480,5 10476,0 10472'0 10468,5 10464,5 10461,0 10457,0 10452.5 10449.0 10444.5 10440.5 10437.0 10432.5 10429.0 10424.5 10416.5 10413,0 10405,0 10400,5 10384,5 10381,0 10377,0 10373,5 10369,0 10365,0 10360,5 i01,0 GRCH 8"AUG'lggl 11:25 PAGE{ 1¸6 Tape ve~ ~hlumb%rger i. ficatlon Listing Alaska Comput ng Center 0771.5 0767'5 0763.5 0759 5 0755 5 075! 5 0747.5 0739'5 0735.5 o731 5 0727 5 07!5 5 0711 5 0707 5 07O3 5 0699 5 0695 5 0687 5 0653 5 0679.5 0675,5 067!.5 0667 5 0643 5 0639 5 0635'5 0631.5 0627.5 0623.5 0619.5 0615 5 0611 5 0607 5 0603 5 O595 5 0591'5 0583,5 0579.5 O575 5 o571:5 0563.5 0559.5 0555.5 0551.5 0547.5 0543'5 0539.5 0535,5 0527'5 05~3,5 0519.5 0515.5 0511.5 0507.5 0503.5 10772.0 10768.0 10764,5 10760,5 !075~'0 1075 ~5 10748'5 10740.5 !0735'5 10731,5 10728,0 10716;0 107!2,5 10708,5 10706.0 10701'0 10696.0 10688'0 10685,0 10681'0 10676,5 10672,5 10669 0 10645 '0 10640 5 10636 5 10632.0 10628.0 10624,5 I0620.5 10615'0 I0611,5 10608,0 10605.0 10597.0 10592,5 10584.5 10581.0 10576,5 10573.0 10565.0 10560'0 10556.5 10552.5 10548.0 10543,0 10539,5 10536.5 10528,5 10525.0 10520.5 10516,5 10513.5 10508.5 10504.5 8-AUG-1991 1I:25 PAGE: !7 IS Te~e Verif,i, catfo..n Listing :hlumberoer Alaska Comput ng Center 8-AUG-lggl I1:25 PAGE= 104995 10495 5 10479 5 10475 5 10467.5 10463,5 104159,5 10455,5 10447'5 10443,5 10427,5 10423,5 10419'5 10403,5 10399,5 10395.5 10391 5 1O387 5 1,0383 5 1.0375 5 10363 5 10359 5 10355 5 i00 0 $ # [,IS FORe, AT DATA 10501,0 10496,5 10480'5 10477,.0 10469'0 10464.5 10460'0 10456,0 10449'0 1 10426,0 } 0,5 10401'5 1039:6.5 10392'5 ,0388'0 0383;5 i0377'0 0365,0 10360~5 10356.5 10351'5 10348,0 !00,5 TABLE TYPE ; CONS TUN! VALU DEF! TYPE CN BP EXPLORATION Company Name FN PRUDHOE BAY Field Name WN ~-29 Well Name APIN 50-029-21~34-00 API Serial Number FL 840 FNL & 1444 FEL Field Location SECT 21 Section TOWN lin Township RANG 12E Range COU~ NORTH SLOPE Count~ STAT ALASKA State or prov~nce NATI USA Nation LATI Latitude LONG Longitude WITN E. TRAVIS Witness' Name SoN 425589 Service Order NumDer PLAT ~SL Permanent datum EPD FT 0. Elevation of Perm. Da Tape Ver. ification bisting :hlumb'erger AlasKa Computing Center 8-~UG"1991 1!|25 TUMI VALU DEFI~ TYPE .LMF DF hog Measured From APD .FT 92,40001 ABOVE PERMANENT DATUM EKB FT '999,25 Elevation of Kel!V Bu EDF FT 92,40001 Elevation of DerriCk EGL FT 47,8 Elevation of Ground 5 TDD FT 10i75. Total Depth - Driller TDL FT 10796, Total DePth - Logger BLI FT 10793, Bottom Log Interval DFTTLI WT PRODU~ED10330 ~ To FLUIDS Drp1 Log InterVal lllng Fluid TYpe DFD C/C3 Drilling FlUld Densit ZONE DFPH Drilling Fluid Ph ZONE DF¥ CP Drilling Fluid ¥1scos ZONE DFL F3 0, Drilling. Flu~d Loss RMS OH~ ResistiVitY of Mud Sa ZONE MST DEGF Mud..:Sample~Temperatur ZONE R~F$ OHM~ Resistivity of mud fi ZONE ~FST DEGF Nud.,.~Flltrate Sample T ZONE R~CS OH~ Resistivity of Mud Ca ZONE MCST DEGF MudlCake Sample Tempe ZONE STE~ DEGF 50. Surface Temperature BHT DEGF Bottom Hole Temperatu ZONE T.~BLE TYPE : ZONE TUNI BDEP TDEP DFD DFP~ DFV RMS MST RMFS MFST R~CS MCST 1 FT O. O. O. O. O. O. O. 0, 0, 0. 0, 0, TABLE TYPE I CURV D~PT NPHT CMTC CFTC C~AT FCNT G~C" Depth Channel Name Compensated Neutron Porosity, $$ Matrix caIi& dead time corr, ~eutron Ration Non-Dead time Corrected ~N/F) ~orrected Near Detector Count Rate Corrected Far Detector Count Rate Surface Tension Neutron Ratio, Dead T~me Corrected (RN/RF) ~aw Far Detector Count rate, Dead Time Corrected ~aw Near Detector Count Rate, Dead Time Corrected Gamma Ray in Casin~ Verification Ltstlnq 8-AUG"!99! {{:25 PAGE{ 20 hlum~erger AlasKa Computing Center ' ** DATA FORMAT SPECIFICATIOM RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VAbUE I 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 9 65 11 66 25 ~2 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl APl APl AP1 FILE NUMB NUMB SIZE REPR PROCESS ID 'ORDER # LOG TYPE.CLASS MOD NUMB SAMP EL£M. CODE (HEX) DMPT FT 425589 O0 000 O0 0 4 ! 1 4 68 NPHI CNTD PU-S 425589 O0 000 O0 0 4 ! 1 4 68 NRAT CNTD 425589 O0 000 O0 0 4 ! 1 4 68 CNTC CNTD CPS 425589 O0 000 O0 0 4 1 1 4 68 CFTC CNTD CPS 425589 O0 000 O0 0 4 1 I 4 68 TENS CNTD bB 425589 O0 000 O0 0 4 1 1 4 68 C~AT CNTD 425589 O0 000 O0 0 4 1 1 4 68 FCNT CNTD CPS 425589 O0 000 O0 0 4 1 I 4 68 NCNT CNTD CPS 425589 O0 000 O0 0 4 1 1 4 68 GRCN CNTD GAPI 425589 O0 000 O0 0 4 1 ! 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 m#~mm~mm~mmmmmm~mmmmmmmm#mmmmm#mmmmmmmm~mmmm#mm~mm#~mm~mmmmmm~m~mm#m~mmmm~m~m~mm#~ ** DAT~ ** DEPT. 10792.000 NPHI. CNTD 30.187 CFTC.CNTD 558.907 TEN$~CNTD 1490.000 NCNT.CNTD 555.3!4 GRCH.CNTD -999,250 NRAT,CNTD CRAT,CNTD 5.125 CNTC.CNTD 5.067 FCNT.CNTD 2791,732 2822.529 , lumb'erger glaska Computing Center 991 11.: 25 FILE NA~E ~ EDIT ,004 SERVICE : FbIC VERSION : 00lA06 DATE : 91/08/ 8 MAX REC SIZE : 1024 FILF TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT ,005 SERVICE : FLIC VERSION : 001A06 DAT~ : 91/05/ 8 MAX REC SIZE : 1024 FIL~ TYPE : LO LAST FILE : FILE HEADER FILE NUMOER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average 0~ edited Passes ~or all curves, Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and backround counts; arithmetic avera~ of edited static baseline passes for all other curves. DEPTH INCREMENT -,5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS CNTD , 2, 3, $ REMARKS: $ LIS FORMAT DATA TABLE TYPE ~ CONS TUN! VALU DEFI TYPE CN BP EXPLORATION Company Name FN PRUDHOE BAY Field Name WN w-2g Well ~ame £S TaPe Verification Listi, ng 8-AUG-199! 11:25 PAGE~ 22 :hlUmber~er alaska Comput n~ Center TUNI VALU DEFI TYPE APIN 50.029.21834-00 API Serial Number FL 840 FNL & 1444 FEb Field Location SECT 21 Section TOwN llN Township RANG 12E Range COUN NORTH SLOPE County STAT ALASKA State or Province NATI USA Nation LAT! Latitude LONG Longitude WIT~ ~ TRAVI$ Witness' Name SON ~5589 Service Order Number PDAT MSL Permanent datum EPD FT O. Elevation of Perm. Da L~F DF Leo Measured From APD FT 92 40001 ABOVE PERMANENT DATUM EKB FT -9~q 25 Elevation of Kelly Bu EDF PT 92,4~001 Elevation of Derrick ECL FT 47,8' Elevation of Ground L TDD FT 10i75 Total. Dept'h - Driller TDL FT 10796, Total Depth - Logger BLI FT 10793, Bottom LOq Interval TLI FT 10.330 Top bo~ Interval DFT PRODUCED FLUIDS Drllli.q Fluid Type DFD G/C3 Drll.lin~ Fluid Denslt DFPM Drilling Fluid Ph DFV CP Drilling Fluid Viscos DFL F3 o. Drill. lng Fluid Loss R~$ OHMM ResistiPitY of Mud Sa ~ST ~EGF ~ud Sample Temperatur R~FS OH~M ResistiVitY Of mUd fi .... EG~ Mud Flltr te SamPle T a RMCS OH~ Resistivity of ~ud Ca ~CST DEGF Mud~Ca~e Sample Tempe STE~ DEGF 50, Surface Temperature BHT DEGF Bottom Hole Temperatu ZONE ZONE ZONE ZONE ZONE ZONE ZONE ZONE ZONE ZONE TABLE TYPE : ZONE T D R O 1 FT O. 0, O, UN! BDEP ' TDEP DFD FPH DFV RMS MST MFS ~FST R~CS ~CST O, O, O, O, O. ' O, O. O. O, [$ TaDe Ver. l.~lcation 5istin~ ;hlumb'er~er lasKa Computing Center 8-AUG'Iggl 1~:25 TAB...,.~, T'tPM : CURV DEFI DEFT Depth C a h nnel Name PaI Comoensated Neutron PorositY, SS Matrix call & dead time corr, RAT Neu~roD Ration Non-Dead time corrected ~N/F) CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate TENS Surface Tension CRAT Neutron Ratio, Dead Time Corrected FCNT Raw Far Detector Count rate, Dead Time Corrected NCNT Raw Near Detector Count Rate, Dead Time Corrected GRCH Gamma Ray in Cas. nql ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** T ~ ',,,YDE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 I1 66 25 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ** ....... m ......... A~K SMRV UNIT SERVICE ApIIUZPAP1 AP1 AP FILE N MB NUMB SI E REPR ROCESS ID ORDER # LOG TYPE CLASS ~OD NUmB SAMP ELEM CODE (HEX) '~'''''EPT ...... ''''''''''''''''''''''''''''''''''''''''''''''''''''55 9 00 0 0 00 0 ! 1 4 .... ;~'''''''~'''''''000 00000 NDHI CNAV PU-S 425589 00 000 00 0 5 1 1 4 68 0000000000 NRAT CNAV 425589 00 000 00 0 5 1 1 4 68 0000000000 CNTC CNAV CPS 425589 00 000 00 0 5 1 1 4 68 0000000000 CFTC CN~V CPS 425589 00 000 00 0 5 1 1 4 68 00000O0000 TENS CNAV LB 425589 00 000 00 0 5 1 1 4 68 0000000000 CRAT CNAV 425589 00 000 O0 0 5 1 1 4 68 0000000000 [8 Tape vertflcation Llstl, nq 8-AUG-199! 11:25 PAGE: :hlumberger Alaska ComputlnQ Center .24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FCNT CNAV CPS 425589 O0 000 O0 0 5 I 1 4 68 0000000000 NCNT CN~V CPS 425589 O0 000 O0 0 5 1 1 4 68 0000000000 GRC~ CNAV GAPI 425589 O0 000 O0 0 5 i 1 4 68 0000000000 ** D~TA ** DE.P~,. 10792.000 MPHI CNAV 29.829 NRAT,CNAV 4,973 CFTC,CNAV 643,543 TENS:CNAV 1497.500 CRAT.CNAV 5.021 NCNT.CNAV 652,944 GRCH.CNAV 1497.500 END OF OATA ** CNTC,CNAV FCNT.CNAV 311~,822 314 .840 **** FILE TRAILER **** FTL~ NAME : EDIT ,.005 $~RVICE : FLIC VERSION : 00lA06 DATE : 91/08/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT ,006 SERVICE : FLIC VERSION : 00lA06 DATE : 91/08/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FI[,E HEADER FILE NUMBER 6 ~AW CURVES Curves and lo0 header data for each pass In separate files; raw bac~round pass in last file PASS NUMBER: 1 DE~TH INCREMENT: -.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTD I0793.0 10330,0 $ 2hlumberger AlasKa ComPUtl. ng Center 8-~U~-1991 t1:.25 ,25 # LOG HEADER DAT~ DATE bOGGED: SOFTWARE VERSION: TIME 5OGGER ON BOTTOM: TD DRILLER TD LOGGER(FT): TOP LOG INTERVAL (FTC: BOTT0~ LOG INTERVAL~FT.)~ LOGGING SPEED (FPHR): DEPTH CONTROL USED TOO5 STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOO5 TYPE CNTD CO~PE~'~ SATED NEUTRON CNTD COMPENSATED NE[JTRON CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON DRILLERS CASING DEPTH (FT): BOR~HOL~ CONDITIONS FLUID TYPE~ FLUID DENSITY (LB/G): SURFACE TEmPERaTUrE (DEGF): BOTTOg HOLE TE~PERATIIRE (DEGF): FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIO: CHOKE (DEG): NMUTRON TOOT, TOOL TYPE (EPITHERMAb OR THERMAL): ~ATRIX: ~ATRIX DENSITY: HOLE CORRECTIOM (IN): NORMALIZATION ~!NDOW START DEPT~ (FT): STOP DEPTH (FT): ANOUNT: GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: ~ULTIPLIER: TOOL STaNdOFF (IN): 30-JUN-91 CP ~2,4 0175,0 079 ,0 {0,33~,0 I079~ 0 6 TOOL NUMBER CNC-DA-146 ATC~CB-!152 CAb-UB-299 AT~-AAw374 PRODUCED FLUIDS 50.0 THERMAL SANDSTONE 2,65 tS ToD. e Ver. ification Listing 2hlumberger AlasKa Computlnq Center # LIS FORMAT DATA 8,-.~UG-Iggl I~ :25 TAHLE TYPE : CONS TUNi VALU DEFI TYPE CN BP EXPLOrAtION ~ompany Name FN PRUDHOE BAY ~leld Name WN w-29 Well Name APiN 50-029-21834-00 API Serial Number FL 840 FNL & 1444 FEL Field Location SECT 21 Section TOWN !IN Township RANG 12E Range COtJN NORTH SLOPE County STAT ALASKA State or Prov~nce NATI USA Nation LATI Latitude LONe Longltude WIT~ E, TRAVI$ witness'. Name SON 425589 Service Order Number PDAT MS5 Permanent datum EPD FT O. ~levation of Perm, Da L~F DF I,og Measured From APb FT 92,40001 ABOVE PERMANENT DATUM EKB FT -999,25 Elevation of Kelly ~F ~'T 9~i~0001 Elevation of Derrl L WT 47 Elevation of Ground L TDD FT 10 ~5, Total Depth - Driller TDL FT 10796. Total DePth - Logger BLI FT 10793, Bottom Lo~ Interval TLI FT 10330. TOP Log Interval DFT PRODUCED FLUIDS Drllling Fluid Type_ DF[') G/C3 Drl. llin~ Fluid Denslt ZONE DFPU ~ Drilling Fluid Ph ZONE DFV CP Drilling Fluid Viscos ZONE DFL F3 O, Drlllin~ Fluid Loss R~S DHMM ResistiVitY of MUd Sa ZONE MST DEGF Mud Sample Temperatur ZONE RMFS OH~ Resistivity of mud fi ZONE MFST DEGF Mud_Filtrate SamleP T ZONE RMCS OHMM Resistivity o~ Mud Ca ZONE MCST DEGF Nud Cake Sample Tempe ZONE STE~ DEGF 50, Surface Temperature BHT DEGF Bottom Hole Temperatu ZONE ES Tape verification Listing :hlUmberger Alaska ComPuting Center TgBLE TY,~E ZONE TUN! BDEP TDEP DFD DFPH DFV RMS MST %B.. R~FS MFST RMCS MCST BHT ~T 0 0 0 ~ O. O. O, 0. O, O. O, O, TABLE TYPE : CURV DEFI DEPT Depth channel Name NPH~ Compensated Neutron Porosity, SS Matrix, calt& dead time corr, RTNR Raw Thermal Neutron Ratio TNRA Calibrated Thermal Neutron Ratio RCNT RC~T RCFT RCFT CMTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate G~ ~PI-Corrected Gamma T~N$ Surface Tension CCL CCL Amplitude ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE R~PR CODE ~ALUE 1 66 0 2 66 0 ~ 73 44 4 66 1 5 66 6 73 7 65 9 65 11 66 12 68 13 66 0 ~4 65 FT ~5 66 68 16 66 IS Taue verification Listing .-blUe, berber lasKa Computin~ Center 8-AU~-199! 11:25 28 p,~ ** SET TY..E - CHAN ** NA~ S..,RV SERVICE AP1 AP1 A AP1 . ILE NUMB NUMB SI REPR ROCESS ID ORDER ~ GOG TYPE CBASS ~OD NUMB SAMP ~LEM CODE (H~X) ......... ,.................... ....... ...............,................. PT F 425589 0 000 O0 0 6 I ~ 4 8 0000000000 NPHT PS1 PU 425589 O0 000 O0 0 6 ~ I 4 68 RTNR PS1 425589 O0 000 O0 0 6 I I 4 68 TN~RA PS1 425589 O0 000 O0 0 6 1 I 4 68 RCNT PS1 CPS 425589 O0 000 O0 0 6 ! 1 4 68 RCFT PS1 CPS 425589 O0 000 O0 0 6 ! I 4 68 CNTC PS1 CPS 425589 O0 000 O0 0 6 I I 4 68 CFTC PSi CPS 425589 O0 000 O0 0 6 I 1 4 68 GR P$~ GAPI 425589 00 000 O0 0 6 1 I 4 68 TENS PS1 LB 425589 O0 000 O0 0 6 1 I 4 68 CCL PS1 V 425589 O0 000 O0 0 6 I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 OO00OO000O 0000000000 0000000000 0000000000 DATA DEPT 10703]~00 NPHI.P$I RCNT.*PS1 3574 37 RCFT.PS! GR,DS1 54.406 TENS,PS1 END OF DATA 30,1006 (~TNR,PS1 714, 34 NTC,PS1 1510,000 CCh,PS1 4.905 TNRA.PS1 3427.365 CFTC.PSI 0.000 5,'045 709.221 **** FILE TRAILER **** FIL~ NAME : EDIT .006 SERVICE : FLIC VERSION : 00lA06 DATE : 91/08/ 8 MAX REC SIZ~ : 1024 FILE TYPE : LO L~ST FILE **** FILE HEADER **** F~LF NAME : EDIT .007 SERVICE : FLIC VERSION : 001A06 DATE : 91/08/ 8 MAX REC SIZE : 1024 FILE TYPE : LO LASW FILE · [S Ta~.e verification List~nn 2hlumberger AlasKa ComPuting Center 8-AUG'~991 11:~§ P~GE~ 29 FILE HEADER FILE NUMBER 7 RAW CURVES Curves and !oB header data for each pass in.seParate files; raw backround ~ass in last file DEPTH INCREMENT: -,5000 FILE $~!MMARY VENDOR TOOL CODE START DEPTH CNTD 10793,0 $ LOG HEADER DATA STOP DEPTH 10330,0 DATE bOGGED:. SOFT~ARE VERsIOn: TI. E LOGGER ON BOTTOM' T'D DRIbl..,ER (FT): TD LOGGER(FT): TOP bOG INTERVAL . BOTTO~ LOG INTERVAL LOGGING SPEED (FPHR): DEPTH CONTROL USE~ lYES/N0 TOOL STRING (TOP TO BOTTOM) VEgDOR TOOL CODE TOOL TYPE CNTD COMPENSATED NEUTRON CNTD CO~PKNSATED NEUTRON C~TD CO~PENSATE~ NEUTRON C~'TD COMPENSATED NEUTRON BOR~HOLE AND CASING DATA OPEN HObF BIT SIZE ' ' {C ) DRILLERS CASING DEP.r~ LOGGERS CASING DEPTH (FFTT) BOREHOLM CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEmPERaTURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) FLUID SALINITY (PP~) FLUID I, EVEb (FT)~ FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHnKM (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR TRERMAL): ~ATRIX~ ~ATRIX DENSITY: ~OI, E CORRECTI0~ (IN)~ 30-JUN-g1 CP 0 ].0175,0 10796.~0 ~0330~0 I0793~0 1800,0 NO NUMBER CNC~DA'146 ATC-CB~1152 CAL-UB-~99 ATM-AA~374 86,0 pRODUCED FLUIDS 50,0 THERMAL SANDSTONE 2,65 TaPe Verifl,.catl, on Listing 8-AUG-!ggl 11:25 PAGE~ 30 hlumberger Alaska Computing Center NORNALIZATION WINDOW 8TART DEPTH (FT): STOP DEPTH (FT): AMOUNT: GAS SCALING FAC~,:O. FOR NEAR AND FAR COUNTS: ~ULTIPLIER: TOOL STANDOFF (IN): LIS FORMAT DATA TABLE TYPE : CONS TUNI VALU DEF! TYPE CN BP EXPLORATION Company Name PRUDHOE BAY Field Name F~ WN APIN SECT TOWN RANG COU~ STAT NATI LATI LONO WIT~ PDAT EPD APD EDF EGL TDD TDL DFT DFD DFpH DFV DFL ~ST RMFS W-29 50-029-21834~00 840 FNL & 1444 FEL NORTH SLOPE ALASKA USA E TRAVIS FT 92.40001 FT -999 25 FT 92.46001 FT 47.8 FT 10175, FT I0796, FT 10793, CP OH~ D£GF O~M O, Well !Name API Serial Number Field Location Section Township Ranqe Count~ State or Prov~nce Nat~on Latitude 5on~itude Witness' Name Service Order Number Permanent datum Elevation of Perm, Da Lo~ Measured From ABOVE PERMANENT DATUM Elevation ot Kelly Bu Elevation of Derrick Elevation of Ground L Total Depth - Driller Total DePth - Logger Bottom 5og Interval Top Log Interval Drilling Fluid TyPe.. Drilling Fluid Densit ZONE Drilling Fluid Ph ZONE Drilling Fluid Viscos ZOSE Drillin~ Fluid Loss ResistiVitY of ~ud Sa ZONE ~ud. Sample Temperatur' ZONE Resistivity of mud fi ZONE ES Tape Verification 5ist~nq ShlUmb'erger Alaska Computln~ Center TUNI VALU DEFI TYPE . · ~FST DEGF Mud:..Filtrate Sample T ZONE R~CS OH~ Resistivity of ~%]d Ca ZONE MCST DEGF ~ud. CaKe Sample TemPe ZONE STE~ DEGF 50, Surface Temperature ~BHT DEGF Bottom Hole Temperatu ZONE ~ .... T~BLE TYPE : ZONE . TUNI B. DEP TDEP DFD DFPiH DFV RM$ MST R~FS MFST R~CS MCST BHT 1 FT O, O, O, O. O, O. O, O. O, O, O, TABLE TYPE : CURV DEFI DEPT DePth Channel Name NPH! Compensated Neutron Porosity, SS Matrix, cal1 & dead time corr, RTNR Raw Thermal Neutron Ratio TNRA Calibrated Thermal Neutron Ratio RCNT RCNT RCFT RCFT CNTC Corrected Near Detector Count Rate CFTC Corrected Far ~etector Count Rate GR APl-Corrected Gamma Ray TF~S Surface Tension CCL CCL Amplitude DATA FOR,AT SPECIFICATION RECORD SET TYPE - 64E0 TYPE REPR E VALUE I 66 0 2 66 0 3 73 44 4 66 5 66 chlumberger asea ComPutlnq Center 8-AUG-199! 1i:25 PAGE { ~32 TYPE REPR,CODE VALUE 6 73 7 65 9 65 ii 66 23 !2 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAN ''''''''''''''''''''''i''N.~ME SE UNIT SER .CE ....... API ''''''''''';;'''''"'''''AP1 A FILE NUMB .... NUMB''''''SIZE .... ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 425589 00 000 00 0 7 I ! 4 68 NPHI PS2 PU 425589 O0 000 00 0 7 1 1 4 68 RTN~ PS2 425589 O0 000 O0 0 7 1 I 4 68 TNRA PS2 425589 O0 000 O0 0 7 I i 4 68 RCNT PS2 CPS 425589 O0 000 O0 0 7 1 I 4 68 RCFT PS2 CPS 425589 O0 000 O0 0 7 1 1 4 68 CNTC PS2 CPS 425589 O0 000 O0 0 7 1 1 4 68 CFTC PS2 CPS 425589 O0 000 O0 0 7 i I 4 68 G~ PS2 GAPI 425589 O0 000 O0 0 7 I I 4 68 TENS PS2 LB 425589 O0 000 O0 0 7 1 1 4 68 CCL PS2 V 425589 00 000 00 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA DEPT, 10793,000 NPHI,PS2 27 049 RTNR,PS2 RCNT,PS2 3401,993 RCFT,P$2 798:226 CNTC,PS2 GR,PS2 54,813 TENS,PS2 1480,000 CCL,PS2 4.489 TNRA P$2 CFTC:PS2 3465.956 0,000 754~: 679 270 END OF DATA **** FILE TRAIt, ER FILE NAME ~ EDIT .007 SFRVICE : FLIC VERSION : O01A06 DATE : 91/08/ 8 NAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : TaPe Veriflcatio~ Listing 2hlumb~eroer Alaska Computmg Center 8"AUG-!g91 11:25 33 **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : O0!A06 DATE : 91/08/ 8 MAX REC SIZE : ~.0~4 FILE TYPE : LO L~ST FILE : FILE HEADER FILE HUMBER 8 RAW CURVES .. Curves and lo~ header data for each PaSs in separate files; raw backround ~ass in last file P~SS NUMBER: DEPTH INCREMENT~ -,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 1()793,0 LOG ~EADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTO~ TD DRILLER (FT)~ TD LOGGER(FT): TOP LOG INTERVAl, (FT)~ BOTTO~ LOG INTERVAL (FT): LOGGING SPEED (FPHR): D~PTH CONTROL USED (YES/NO): STOP DEPTH 10330,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOI, CODE TOOL TYPE CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH (FT): BO~EHObE CONDITIONS FLUID TYPE: WbUID DENSITY SURFACE TE.PERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): BO-JUN-gl CP 32,4 0 10175,0 10796'0 103B0,0 10793~0 1800.0 NO TOOL NUMBER CN -DA-146 ATC-CB-1152 CAL-UB-299 ATM-AA-374 12.250 10386,0 PRODUCED FLUIDS 50,0 ;'hlumberqer lasKa Comput no Center' .34 FLUID SALINITY FLUID LEVEL FLUID RATE AT WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION NORNALIZATION WINDOW START DEPTH STOP DEPTH (FT): AMOUNT: GAS SCALING F,ACTOR FOR NEAR AND FAR'COUNTS: MULTIPLIER: TOO5 STANDOFF (IN): $ # LIS FORMAT DATA THERMAL TABLE TYP~ : CONS TUNI VALU DEFI TYPE CN FN WN APlN FL SKCT TOWN RANG COUN STAT NATI LATI LONG PDAT L~F APD EDF EGL FT FT FT FT FT BP EXPLORATION PRUDHOE BAY 50-029-~1834-00 840 FNL & 1444 FEL 2! NORTH SLOPE ALASKA USA E TRAVIS 4~558g 92 4 00! 47.8 Company Name Field Name Well Name API Serial Number Field Location Section Township Range County State or Province Nation Latitude Longitude Witness' Name Service Order Number Permanent datum Elevation of Perm, Da I, og Measured From ABOVE PERMANENT DATU~ Elevation of Kelly Bu Elevation of Derrick Elevation o~ Ground L IS Tap. e Verification Llst],ng :hlumSeroer .Alaska Computing Center TUNI VALU DEFI TYPE . · TOD FT 101~§, Total Depth m Dr~ller TDL FT 107~6. Total Depth - ho~er ELI FT 10793, Bottom bO~ Interval '~. I FT 10330 To Log Interval DFT PRODUCED FbUIDS Drilling Flul. d TYpe DFD G/C3 Drillin~ Fluid Denslt ZONE DFV CP Drill~n~ Fluid Viscos ZONE DFL F3 0, Drilling Fluid boss R~S OMgM Resistl%itY of Mud Sa ZONE MST DEGF Mud Sample Temperatur ZONE R~FS OHMS Resistivity of mud fi ZONE MFS? DEGF Mud.,~.Filtrate Sample T ZONE R~CS OHMS Resistivity of ~ud Ca ZOnE MCST DEGF Mud.,CaMe Sample Tempe ZONE STE~ DEGF 50, Surface Temperature B~T DEGF Botto~ Hole Temperatu ZONE - TABLE TYPE : ZONE TUMI BDEP TDEP DFD DFPH DFV RMS MST R~FS MFST RMCS MCST ! FT O, 0, 0, 0, 0, O, 0, O, O, O, O, O, TABLE TYPE : CURV DEFI D~PT Depth Channel Name NPHI Compensated Neutron Porosity, $8 Matrix, call & dead time corr, RTNP Raw Therma]. Neutron Ratio TNRA Calibrated Thermal Neutron Ratio RCNT RCMT RCFT RCFT CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate GR APl=Corrected Gamma Rav TFNS Surface Tension CCL CCL Amplitude lis TaDe veri~lcatton bistinq 8-AUG-Iggl 11:25 PAGE: :hlumberqer las~a CompUting Center ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE YAbUE ! 66 0 2 66 0 ] 73 44 4 66 5 66 6 7 65 8 68 0 5 11 66 23 12 68 13 66 0 I4 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CMAN ** NA~E SERV UNIT SERVICE ED ORDER # DFPT FT 425589 NPHI PS3 PU 425589 RTN~ PS3 425589 TNRA PS3 425589 RCNT PS3 CPS 425589 RCFT PS~ CPS 425589 CNTC PS3 CPS 425589 CFTC PS3 CPS 425589 GR PS3 GAPI 425589 TENS PS] LB 425589 CCL PS3 V 425589, mmmmmmmmmmmmmmmmmm APl API API API FILE NUMB NUMB SIZE REPR PROCESS LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 8 ! 1 4 68 0000000000 O0 000 O0 0 8 1 I 4 68 0000000000 O0 000 O0 0 8 1 1 4 68 0000000000 00 000 O0 0 8 1 1 4 68 0000000000 O0 000 O0 0 8 ! 1 4 68 0000000000 O0 000 O0 0 8 1 1 4 68 0000000000 O0 000 O0 0 8 1 1 4 68 0000000000 O0 000 O0 0 8 1 1 4 68 0000000000 O0 000 O0 0 8 I 1 4 68 0000000000 O0 000 O0 0 8 1 1 4 68 0000000000 O0 000 O0 0 8 1 I 4 68 0000000000 mmsmmmmmmmmmmmmmmmm~#m~mm~mmmmmmmmmm~#mm~m~m~mmmmmmmmmm#mmmmmmsm~m~mm ** DATA ** D~PT. I0703.000 RCNT.PS] 2800.000 GR.PS3 62.688 NPHI.PS3 32.075 RTNR.PS] 5.375 TNRA.PS3 RCFT.PS3 544.102 CMTC,PS3 2786.236 CFTC.PS3 TENS.PS3 1510.000 CCh. PS3 0.000 5,293 547,773 ** EMD OF DATA ** £S TaF%e Verificatio~ Llstin~ 2hlumberger AlasKa Computing Center FILE NA~E : EDIT ,008 S~RVICE : FLIC VERSION : 00iA06 DATE : 91/08/ 8 MAX REC SIZE : !024 FILE TYPE : LO LAST FILE : **** FILE NEADER **** FiLE NA~E : EDIT ,009 SERVICE. ~ FLIC VFRSION : O0!A06 DATE : 91/08/ 8 MAX REC SIZE ~ 1024 FILM TYPE : LO LAST FILE : 8"AUG-Ig91 I1:25 PAGE: 37 FI, LE HEADER FILE M..tMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw bac~round pass In last file PASS NUMBER: 4 DEPTH INCRE~ENT~ -,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD ~.0793,0 $ bOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(MT): TOP LOG INTERVAL (FT): BOTTO~ LOG INTERVAL LOGGING SPEED (FPHR): DEPTH CONTROL USED (YE$/NO)~ STOP DEPTH 10330,0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOt, CODE TOOL TYPE CNTD COMpEN~;~ED NEUTRON CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRON $ 30-JUN-91 CP 32,4 0 10175.0 107960 lO3 O2O 180 TOOL NUMBER c c-32:i; ' ATC-CB-1152 CAL-UB-299 ATM-AA-374 iS Ta~e Verification Listin~ :hlumberger Alaska Computln, Center PAGE{ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEE,, (FT): FLUID RATE AT WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX{ MATRIX DENSITY: HOLE CORRECTION (IN): NORgALIZATIOM WINDOW START DEPTH (FT){ STOP DEPTH AMOUNT: GAS SCALING FACTOR FOR NEAR AND FAR COUNTS MULTIPLIER: TOOL STANDOFF (IN): REMARKS: $ LIS FO~AT DATA {0386,0 pRODUCED FLUIDs 50,0 THERMAL SANDSTONE 2,65 TABLE TYPE : CONS CN BP EXPLORATION Company Name FN PRUDHOE BAY Field Name WN W-29 Well Name APIN 50-029-~1834-00 APl Serial Number FI, 840 FNL & 1444 FEL Field Location SFC? 2! Section TOw~ llN Town$5tP RANG 12E Range COU~ NORTH SLOPE County STAT ALASKA State or prov~nce NaTI USA Nation LAT! Latitude Tape ve-rfflcatlon Llstinq 3hl, umberger AlasKa Computlnq Center 8-AUG-tg91 11:25 PAGE{ 39 TUNI VALU DEF! TYPE . . LON~ Loggltude 'WITN E. TR~V'IS Wit6ess' Na~e SON 425589 Service Order Number PDAT MSL Permanent datum EPD FT ~ Elevation of Perm, Da L~F ' ~ 5o~ Measured From APD FT 92.40001 ABOVE PERMANENT DATU~ EKB FT -999.25 Elevation of Kelly Bu EDF FT 92.40001 EleVatiOn of Derrick EGL FT 47'8.' Elevation of,Ground b TDD FT !0i75, TOtal Depth Driller TDL FT 10796, Total DePth - Logger BLI FT I0793.. Bottom Loq Inte'rval TLI FT 10330, Top Log Interval DFT PRODUCED FLUIDS . Drilling Fluid Type.~ DFD G/C3 Drilling Fluid Densit ZONE DFPH Drilling Fluid Ph ZONE DF¥ CP Drilling Fluid ~lscos ZONE DF'L F3 O, Drilling<Fluid Loss R~S OH~M ReslStiv!ty of Mud Sa ZONE .S~ DEGF Mud,.Sample Temperatur ZONE RMFS OHM~ ResistiVity o~'mud fi ZONE MFST DEGF Mud. Flltrafe Sample T ZONE RMCS OH,~ Resistivity of Mud Ca ZONE MCST DEGF Mud Ca~e Sample Tempe ZONE STE~ DEGF 50. Surface Temperature BHT DEGF Bottom Hole Temperatu ZONE T~BLE TYPE : ZONE TUNI BDEP TDEP DFD DFPH DFV R~$ MST R~FS ~FST RMCS ~CST BHT ! FT O. O. O. 0. O, O. 0, 0. O, O. 0, O, y~ TABLE T_PE : CURV DEFI DEPT Depth C~annel Name NPNT Compensated Neutron Porosity, SS Matrix, cal!& dead time corr. RTNP Raw. Thermal Neutron Ratio TNR~ Calibrated Thermal Neutron Ratio RCNT RCNT IS Ta~e Verification ListinQ chtumberoer AlasKa COmPutlno Center 8-AUG-199! 11:25 PAGE: 40 RCFT RCFT CNTC Corrected Near Detector CoUnt Rate CFTC Corrected Far Detector Count Rate GR APl.Corrected Gamma RaY TENS Surface Tension CCL CCh AmPlitUde ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VAbUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 9 65 ' 11. 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** ..... ..... ........-.-.,,........-.-----.---.--,---..--.-----------,------------,,-- .... NAME SERV UNIT SERV E API API API AP1 ILE NUMB NUMB SI E REPR PR ESS ID ORDER # LOG TYPE CbA$S MOD NUMB $AMP ELEM CODE (HEX) ~~~-~~~~.~~~~.~.~~~~.~~.~~~~.D~T FT 4255 00 000 00 0 9 I I 4 8 0000000 00 PU 425589 O0 000 O0 0 9 1 1 4 68 0000000000 NPHT PS4 RTNR PS4 TNRA P$4 RCNT PS4 RCFT PS4 CNTC PS4 CFTC PS4 G~ PS4 425589 00 000 00 425589 00 000 00 CPS 425589 00 000 00 CPS 425589 00 000 00 CPS 425589 00 000 00 CPS 425589 00 000 00 GAPI 425589 0o 000 00 0 9 0 9 0 9 0 9 0 9 0 9 0 9 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ~s ~s4 ~ ~ss~9 oo 000 oo 0 9 ~ ~ ~ ~ o00000000o cc,~ ,,s~ I ~ss~ o.o. ooo oo o 9 i ' ! ~ o. oooooo, ooo :hlumberger Alas~ Computln. Center ** DATA ** DF...PT GR.PS4 5 469 NPH I, PS4 F RC ~, PS4 TENS, PS4 ** END OF DATA. ** 8-AUG'IR91 11:25 PAGE: 41 30.!16 RTNR.,P$4 41.824 TNRA'.PS4 5,058 578.108 CNTC,PS4 2830.;581 CFTC'PS4 568,680 1500,000 CCh,PS4 0,000 **** FXLE TRAILER **** FILE NAME ~ EDIT ,009 SERVICE : FLIC VERSION : O01A06 DATE : 91/08/ 8 M~.X REC SIZE : 1.024 FILE TYPE : LO LAST FILE ~ **** TAPE TRAIt, ER **** SERVICE NAME : EDIT D~TM : 91/08/ 8 O~I~IN : FbIC TAPE NAME. : 74669 CONTINUATION ~ : 1 PREVIOUS TAPE ~ COMMENT : BP EXpL:ORATION,PRUDHOE BAY,W-29,50-O~9-21834-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 91/08/ 8 ORIGIN ~ FLIC REEL NA~E ~ 74669 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION,PRUDH~E BAY,W-29,50-029-21834-O0 ~H~ ~.£1MMi~ TON DIRECT DIGITAL LOGGING ~,COMPUTER RECEIVED ~" AnChorage" PROCESSED ANALYSIS · ,~ IIIIIIIIII SSSSSSSS DDDDDDDDD UU UU NH MN PPPPPPPPPi.: IIIIIIIIII SSSSSSSSSS DDDDDDDDDD UU UU NNN NHN PPPPPPPPPF' ~, II SS SS DD DD UU UU MMMM MMMM PP Ii SS DD DD UU UU MM MM MM MM PP II SS DD DD UU UU MM MMMM MM PP II SSSSSSSSS DD DD UU UU MM MM MM PPPPPPPPP~ Ii SSSSSSSSS DD DD UU UU MM MM PPPPPPPPPF II SS DD DD UU UU MM MM PP Ii SS DD DD UU UU NM MM PP Ii S~ SS DD DD UU UU MM MM PP LLLLLLLLLL iIIIIIIIIi SSSSSS$SSS DDDDDDDDDD UUUUUUUUUUUU MM MM PP LLLLLLLLLL IIIIIIIIII SSSSSSSS DDDDDDDDD UUUUUUUUUU NM MM PP 444 4444 44 44 : :: 44 44 44 44 44444444444 444444444444 44 44 44 44 44 222222222 444 2222222222 4444 22 44 44 22 44 44 AA AA 22 44 44 AA AA 22 44444444444 AA AA 22 444444444444 22 44 AA AR :2 44 :2222222222 44 :2222222222 44 AA AA 3333333333 00000000 PPPPPPPPPPP MM 333333333333 0000000000 PPPPPPPPPPPP blMM 33 33 '00 O0 PP PP NMMM Hi 33 '00 O0 PP PP Hbl MM HH 33 O0 O0 PP PP MM MMMH 3333 O0 O0 PPPPPPPPPPPP btm MH 3333 O0 O0 PPPPPPPPPPPP 33 O0 O0 PP MM 33 O0 O0 PP MM 33 33 '0'0 O0 PP HH 333333333333 0000000000 PP MM 3333333333 OOOOOO00 PP HH UU UU GGGGGGGGGG 9999999999 0000000 UU UU GGGGGGGGGGG6 999999999999 OOOOOO00 UU UU GG GG 99 99 O0 UU UU GG 99 99 O0 UU UU GG 99 99 O0 UU UU GG 999999999999 O0 UU UU GG 999999999999 O0 UU UU GG GGGGG 99 O0 UU UU GG GGGGG 99 O0 UU UU GG GG 99 99 O0 UUUUUUUUUUUU GGGGGGGGGGG6 .,. 999999999999 00000000 UUUUUUUUUU GGGGGGGGG6 ... 9999999999 OOOO000 . ~" .'HEADER REEL HEADER **** Service name: ~G5F01 Date: 90/08724 Origin: RECORDS Reel name: 37817X Page Cont. inuation #: O1 Previous reel: Comments: ~** TAPE-HEADER **** Service name: &GSF01 Previous ~ape: Date: 90/08/24 Origin Comments: Tape name: 37817X Continuation #: O1 I i ********************** *** FILE:HEADER **** ********************** File name: ,001 Service name: Version Date: Maximum length: 1024 File type: LO Previous {'ile: INFORMAT ION RECORDS Page MHEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR CH WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DD DL CBLI TLI TCS TLA8 BHT MRT MT MSS DFD MVIS DFPH DFL RH RMF HFST HFSS RMC 8P EXPLORATION W-29 APl NUM: PRUDHOE BAY NORTH SLOPE ALASKA USA .......... 21834,000 ..................... 0 Omg. 0 Min. 0 0 Sec 0 Omg. 0 Min. 0 0 Smc 11N .... 12E ..... 92,40.0, , 92..400, . 47,80'0, , 1100.000 ... 1G? 7790 30 ......... 51301 WORTH SLOP ' iIORTH SLOPE YARBRO LUECKER 10908,000,., 1.0820.000.., 0.000 ....... 0.000 ....... 1'0400. 000. . . 10820..000. . , 0.000 ....... 1100,000 .... 0,000 ....... 0,000 ....... PRODUCED $ · I telllli iileIll IWilil! iiIiiii IaIiIii ilIlIli iliilIi IllIill [)ATE LOGGED N · · iii iii.il Ilill IIill ilIii m 50-029.-21834 07-.16-90, II I · i m I i · · m i i m i l i · · i, · · · mm · i 6'666'": ................................. · I · · i i I i i i i I i I i I · · i I i · · · i i m I I m I I i i i 0.000 ..................................... O.O00 ....................................... 0,000 .................................... 0.000 .................................... O..000 ...... 0.000 ...... 6'666 ...... m m m · m m ~l ImllmlllmlIlllmIlllmlll IeIlllIIlIllltlIllllIlI IIllIIIlIIIIlIIlIIlllII Ilillllllllllllllllllll i IIIIlIl"l IlllIllll IIllllIil IlllmmIII I · i · · iI i ii i ii i ! · I I I , i · ! i · · I m i I m I I 0 0 40 6.5 0 0 40 65 0 0 40 65 0 0 20 G5 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 .0 34 65 0 0 2 65 0 O 3 65 0 0 3 65 FT 0 3 4 G8 FT 0 3 4 68 FT 0 ~ 4 68 0 ~ 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 .0 1 0 65 Ct 0 1 0 65 0 0 20 65 0 0 2 0 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT O J 4 68 FT 0 ~ 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 ~ 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 LB,.'G 0 2 4 68 CF' 0 2 4 68 0 2 4 68 0 2 4 68 OHHM 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHMH 0 2 4 68 ,~ ',. T_HFORM~T_TOH RECORDS ., NHEM COHTEN.TS UHIT TYPE C~TG SIZE CODE ERROR .CST 0.000 ................................................... ~F 0 2 '4 ~e .ess ................................................... o ~ ~2 ~5 cs ~. 666 ......... i .............................. o ~ 4 ~e ~s s.soo ...................................................o ~ 4 es CO.MMENT RECORDS Location Comment Location Comment Location Comment Location Comment File Comment 1: Film Comment 2: Film Comment 3: Il Film Comment 4: Well 'Well Wel 1 Well Well Well Well We 1: SURFACE: 840' FNL & i444' FEL 2: TIED INTO PASSES 1-4 oCHLUMBERGER CEMENT BOND LOG DATED 08-13-88~ (WELL SHUT-IN), PASS 5 (WELL FLOWING), PASS 6 (WELL SHUT-IN / l0 MIN. AFTER FLOWING.) HODGES & LEHMAN AVERAGE OF PASSES 1-4 ONLY, mm LIS tape written by: ANCHORAGE COMPUTING CENTER mm mm All curve and tool mnemonics usmd are .those which most closely match mm mm Halliburton curve and tool mnemonics, mm HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE .UNIT Mt{EM SERVICE UNIT DEPTH DEPTH IIitll liII DEPTH FT DEPT FT 9935,00 10835,00 CS DSN F/MI CS DSN F/MI 9948,00 18816,25 TENS DSN LB TENS DSN LB 9948,08 10e16,25 CCL DSN CCL DSN 9948.00 10816.25 GE DSN AP1 GR DSN APl 9948,00 108i6.25 FDSN DSN CNTS FDSN DSN CNTS 9948.00 10816.25 NDSN DSN CNTS NDSN OSN CNTS 9948.00 10816.25 HRAT DSH NRAT DSH 9948,00 10816.25 NPHI OSN Z NPHI DSN % 9948.00 10816.25 DATA FORMA ENTRY BLOCKS ENTRY TYPE T SPEC I F I CAT IONS SIZE CODE Pag~ ~' · 1 G 1 6G 0 1 GG · ~ ENTRY BLOCK LEGEND TYPE DESCRIPTION Datum speci~i.cation block sub-type Term~na[or ( no more entri~ ) DATA FORMAT DATUM,SPECIFICATION BLOCKS SPEC I F I CAT IONS SER¥I~OE SERVICE AP1 MNEM ID ORDER # UNIT LOQ AP1 AP1 AP1 FILE TYPE CLASS MOD # PRC ~ SIZE LVL SMPL RC PROCESS INDICATORS DEPT 37817X FT 0 CS DSN 37817X F/HI 94 TENS DSN 37817X LB 94 CCL DSN 37817X 94 GE DSN 37817X AP1 94 FDSN DSN. 37817X CNTS 94 NDSN DSN 37@17X CNTS 94 NRRT bSN 37~17X 94 NPN! ,bSH 37S17X ~ 94 0 0 0 I 4 0 · 0 0 1 0 4 0 0 0 i 0 4 0 i ,0 0 1 0 4 0 0 0 1 0 4 0 1 0 0 1 0 4 0 '1 0 0 'I 0 4 0 'I 0 0 1 0 4 0 1 0 0 '1 0 4 0 I 68 68 68 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 '000000 000000 ATA DEPT CS TENS NPHI ~_ _ . ~ .... , , · : ................_.~ .. .,. ~ ....... ~.. _. . .. _. ~.~ 1 ~08!G, 250 18,750 837,000 9,094 RECORDS CCL GR FDSN NDSN NR~T -i,O00 0.000 729.195 20248.949 12.587 Page 7 0800,000 3'1 .480 I312,200 19,930 8, Ot 7 38,065 708. 580 20446. 895 32,655 1 0700. 000 22,656 1 41 I . 363 :30,02.7 7,954 18,973 538,461 21584,$31 45.596 l'OGOO, 000 31 , 020 1366,20.0 t8 ,e49 '8.145 15..490 855.919 22972,828 31 .321 ! 0500o.000 31 .:327 ! 366. 200 6.77O .. 8,:0~07 62,8'02 1788.622 25712,629 16.323 10400,0'00 28,621 1356,600 5,255 7,949 36,264 2042,919 25493,258 14.372 1.0300,'.'000 27,988 1 355,400 63,699 837 33,'!42 231 ,545 19!40,043 91 ,251 '1 0200.'000 27,422 1312. 200 65.57.4 1 O1 00,000 2.6. 818 131.0.'039 4. 884 7.8:09 46,831 234,933 19417,5'08 7,8.00 54,156 1469,609 18057,516 93,226 13.891 10000.000 28.846 1356.47.9 73,,894-. 7,783 43,949 144,712 13691.348 593 ~** FILE TRAILER **~* File name: &GSF01.001 Service name: TRAILER RECORDS Version #: Date: Page Maximum lmngth: 1024 File type: LO Next f'ile: **********.**** *** FILE HE~DE~ **** ************************** File name: .002 Maximum length: 1024 File type: LO Version Previous ~ile: Date: [ HFORM IT ]: OH RECORDS HHEH CONTENTS UN I T TYPE CH WH FH COUN STAT CTRY APIN LATI LONG SECT TOWN R~NG EKEI EDF E~L PD LHF DHF RUN TIHE DRTE LCC LUN FL LUL ENG! WITH DD DL · CBD 1 CBLI TL[ BL! TCS TLAB BHT HT HSS DFD H¥IS DFPH DFL RH RHF HFST HFSS RHC BP EXPLORATION t~1-29 PRUDHOE BAY DATE LOGGED: t40RTH SLOPE ............ ALASKA ............ USA ............ 21834 '000 m I I t il e I I I I I I I ! I I I I t I I t t I 0 .b.~g, 0 ~lin, O. 0 Se:c, N 0~u~g. 0 Min, O, 0 S~-c. '1 'i fl ......................... t2E ......................... 92 40.0 47 8 O0 . NS ..................... DF ilO0 000 : I ' I I I I I ! I I I I I I I I I I I I 16/ ?/90 ................... 36 ........................ OP~ ............... NORTH SL ...... NORTH SLOPE ......... YARBRO LUECKER ............ i.0~08. 000 ..................... 10820..000 ..................... 0.~00 ......................... 0 000 10400 000 10820 ~00 0.000 .............. 1100.000 ........... 0.000 .............. 0.000 .............. PRODUCED NUN: 50-029-21834 ........ 07-16-90 ........ IlfImllllllllll lIIItllllllllll llllIlllllllmll IilIiIImliliIii tIIIlIIIII llll etllllllll fill IllIllltII IIII W I I i I i ! I I I I i I I I I I I m t · 0.000 ....... 0.000 ....... 0.000 ....... 0.000 ....... O.-000 ....... 0.000 ....... Itl .elm III III mill mllI II I II t II I I1 1 IlIIIi lllIlI IIIIll ellllt Illlll iIIlte IIlIiI IIiiii Ilelll Iiiii IIlIm IIIll llIII IIIlIIIm IIlIIIII Illl IlII ~llt tile I·ll IIII Illl IIII gill IIII IIIIlI IIIlII lltlll IIIlIlIlI Ii·lliIlI IIIlltlII IIIItlllm IlllillII mille Itttl Illll IIIII IIIlt II·ll It II It mi ii mi II It II II i! mt ii Iii,lltlmllllllIilifllii imlllmllllllmmliillItlllIliiillttlll lIIiimllillllllIllliI IllllleIttlIltllllll IltlllllIIIlllIIItml iiiimiiiimllllllllll Illllllllllillllllll IlIImIIllIItllIllmII ItllmlllmlItllllllll IIIIIlIIIl·llllllllllIIIlll lllllllIIIIIIIIIIIIIlllllll Itl·lel IiIltilllmlllll·lll IIIIIII IIIIllIiIiIiilmllll · llllll IIiiIIiIiiiiIiIliii Illllli iIiIliiiIiIIiiiIiii IiiIiiI iIIl,lliIIiiiiIllli IIiilll I111111111111111111 · · 1 I · I I m · · mI I.II · ·i · ·· illllliiiiIlIi illl··ielIilIi iilIIIliiIil·l ilitllllllllll illlillIlIillllIIIlilllllll··llllii iiliIlelllliiiiliiiliill,llliiliiii 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 .'0 4 68 0 0 34 65 0 0 34 65 0 .O 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4. 68 0 3 2 65 0 3 2 65 0 3 2 65 0 ..0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHHH 0 2 4 68 OHHH 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHH 0 2 4 68 CATG SIZE CODE ERROR I NFORMAT I ON RECORDS NHEN CONTENTS UNIT TYPE CATG SIZE CODE ERROR MCST 0 ~00 DEaF 0 2 4 68 BS 8 500 0 3 4 68 . " COHHENT RECORDS We Wel Wel Wel 11 Location Comment 11 Location Comment II Location Comment I Loca%ion Comment 1 File Comment 1: I File Comment a: I File Comment 3: SURFACE: 840~ FNL & 1444' FEL 4~ TIED INTO SCHLUMBERGER CEMENT BOND LOG DATED 08-13-88. PASSES 1-4 (WELL SHUT-IN). PASS 5 (WELL FLOWING>, PASS.6 (WELL SHUT-IH ? 10 .MIN, AFTER FLOWING,) I File Comment 4: HODGES & LEHMAN AVERAGE OF PASSES I-4 ONLY, LIS tape written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most closely match Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9935, O0 I 0835, O0 CS1 DSM F/MI CS DSN F/MI 10391 ,50 1 0814,75 TENSI DSN LB TENS DSN LB 10391 ,50 1 0814,75 CCL1 DSN CCL bSN !0391 , 50 I 0814.75 GEl DSN AP1 GE DSN API i0391 , 50 1 0814 , 75 FDSNI DSN CNTS FDSN DSN CNTS 10391 ,50 1.0814.75 NDSN I DSM CNTS NDSN DSM CNTS 10391 . 50 1 0814 , 75 NRATI DSN NEAT DSM 10391 .50 I 0814.75 NPHI 1 DSN ~, NPHI DSN ~, 10391 ,50 1 0814 Page ii . ~ DATA FORMAT SPEC I F I CAT IONS ENTRY BLOCKS **** ENTRY TYPE SIZE CODE 16 0 66 Page ENTRY BLOCK LEGEND ***************************** TYPE DESCRIPTION 16 Datum specification block z.ub-t~pe 0 Terminator ( no more entriez > ' ,, DATA FORMAT ~** DATUM SPECIFICATION BLOCKS SPEC I F I CAT I'ONS Page SERVICE SERVICE MNEM ID ORDER # AP1 API AP1 AP1 FILE UNIT LOG TYPE CLASS MOD # PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT 37817X CS DSN" 37817X TENS DSN 37817X CCL DSN 37817X GE DSN 37817X FDSN DBN 37817X NDSN DSN 37817X NRAT DSN 37817X NPHI DSfl 3,7817X FT 0 '0 0 0 2 4 0 1 F/MI 94 0 0 3 1 4 0 LB 94 .0 0 3 1 4 0 94 0 0 3 API 94 ~0 0 3 i 4 0 CNTS 94 .0 0 3 CNTS 94 iO 0 3 1 4 0 .i 94 '0 0 3 ~ 94 0 .0 3 i 4 0 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 00.0000 000000 000000 000000 000000 DATA RECORDS DEPT CS T£NS CCL GR FD SN NPHI : ~--_::: : - . .__: ..... . : _. ...~ .., ............. : .... · .. · .., .. !...... ....... : .... .-: ........ _:: ' _ _ . . · 0814. 750 23,670 869,400 -1 . 000 O. 000 ~94,623 g ,'184 NDSN NP. RT Page 1.~i 19580,855 12.697 I0800,'000 31,174 1312,200 7.927 38,065 677,087 19,546 19574.086 32,179 1 0700,000 29. 071 1463,400 7,6'59 19,333 522,.003 31.510 1 0600,000 2.8,395 '1463,400 7,827 11 . 047 839.843 18,866 21556,922 22770,816 47.609 31 ,340 I 0500,000 28,671 1420,?..00 7.767 60, 160 1832. 118 6;210 24977,156 15,605 10400,000 27,719 1410.942 7.769 35,304 1940,212 5,592 24995,988 14,809 FILE TRAILER File n~me: &GSFO~.O0~ TRAILER RECORDS Version fi: Date~ Page 15 Maximum length:. 1024 File type: LO Hex: ~ile: ,*~ FILE HEADER ***m File name.: .:0.03 Maximum length: '1'024 Version File type: LO Previous Date: I NFORMAT I ON RECORDS Page HNEM mmm CN FN COUN STAT CTRY A. PtN LATI LONG SECT TOWN RANG EDF EGL PD LHF DHF RUH TIHE DATE LCC SON LUN FL LUL ENGI WITH DD DL CBDI CBLt TLI BLI TCS TLAB BHT NRT NT HSS DFD MVlS DFPH DFL RH RHF HFST HFSS CONTENTS UNIT TYPE CRTG SIZE CODE ERROR BP EXPLORATION W'29 PRUDHOE BAY NORTH SLOPE ....... ALRSKA ....... USA ....... 21834,000 .................. O.Deg, 0 Min. O, 0 Sec :O..Deg, 0 Min. O. 0 Sec 11H ................... 12E ................... 92,400 ................ 92,400 ................ 47,800 ................ DF ................... DF ................... Iiiiii1,1 iiiiii I1~1 I I 1100,000 .............. 167 7/90 ............. 3?GI?X ......... 51301 ............. NORTH SLOPE NORTH SLOPE ,, . YARBRO ,.. LUECKER 10908..000 .............. 10820.00'0 .............. 0.000 .................. 0.000 .................. 1040'0.000 .............. 10820. 000 .............. 0.000 .................. 11.00.000...' ............. 0.000 ................... 0.000 ................... PRODUCED .... API HUM: 50-029--21S34 DATE LOGGED: :07-16-90 , · , , , , , · , , , , , · ! , , l.., I I . I · iifl i m m m i m , 6'666:":'" 0,000 ....... O,O00 ....... O,-000 ....... 0.000 ....... 0.000 ....... 0.000 ....... · i m , it Imlllmmlmlll.lllll Illlmmlllmlllllll! Ilmllmll,lllllllll mill I m m i , Imlll mmmlm m ,Iii · , mi m i ma , i ,I · , gl I1 1 i il i IIii1 i I [llll I I IIIII I Illil I !1111 IIt[I I IIIIIII IIIIII111 IIIIIIlll Ilillllll ,,illlllllllllllll I,Illl,llll,lllllllllllllllll . .m , I l i I l , I , it . . . 1 · , . · , · l, mill maim mill I,ii I1,1 Iiii iiIiiii Iiiiiii Illllll IIIIIII Illmlllll lllllllll mtllll.l, .Imllllll IIl,l,llllllllllllllltll]llllllllllllli lllllllllllilllllllllllllllllllllllllll llllllllltlllllllllllllllllllllllltllll mil m mi! mil m mm. · , m , m · m m · , · , m m I m , , iiiii illl, ,1111 lmlllllltllll 0 0 40 65 0 0 40 65 0 0 40 ~5 0 I0 20 ~5 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4. 68 0 3 2 65 O 3 2 65 0 3 2 65 0 8 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I. 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP O 2 4 68 0 2 4 68 0 2 4 68 OHHH 0 2 4 68 OHMH 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHH 0 2 4 68 INFORMATION RECORDS Pag~ 17 NHEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR HCST 0 ~.00 DEGF 0 2 4 68 · I$IIeIlIIIIIIIIlIIIIIIIIlIliIIIeIIllIIIIIIIlIlIlIII ~C~ 0 2 i~ 65 I IlllllllIllllllIlIIlIItlltilllllllIItlIIllllIIIlIII BS 8 5.00 0 3 4 68 I SllIIIlIlIIlIlIllIeIIIll.lIIelIllltllIIIIIIIIIIIIII COMMENT RECORDS · Wel I Locat 'Well Locat Wel 1 Locat Wel 1 Loca~ Well File Well File Well File W~II File ion Comment ion Comment ion Comment ion Comment Comment 1: Comment 2: Comment 3: Comment 4: SURFACE: 840' FNL & 144'4' FEL TIED INTO SCHLUMBERGER CEMENT BOND LOG DATED 08-13-88, PASSES 1-4 (WELL SHUT-IN), PASS 5 <WELL FLOWING). PASS 6 (WELL SHUT-IN / I0 MIN. AFTER FLOWING.) HODGEs & LEHMAN AVERAGE OF PASSES 1-4 ONLY. LIS tape written by:ANCHORAGE COMPUTING CENTER All curve and tool mnemonicz used are those which most clozelp match Halliburton curve and tool mnemonicz. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEN SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9935,00 10835,00 CS2 DSM F/MI CS DSN F/MI 10397.00 10814.75 TENS2 DSM LB TENS DSM LB 10397.00 10814.75 CCL2 DSM CCL OSN 10397.00 10814.75 GR2 DSH API GR DSN API 10397.00 10814.75 FDSN2 DSM CNTS FDSN DSM CNTS 10397.00 10814.75 NDSN2 DSN CHTS NDSN OSN CNTS 10397.00 10814.75 NRAT2 DSN NRAT DSN 10397.00 108i4,75 NPHI2 DSM ~ NPHI DSN ~ 10397.00 10814.75 Page , ~' DATA FOR.MAT SPEC I F I CAT IONS ~ ENTRY'BLOCKS ENTRY TYPE SIZE CODE Page ... '16 1 66 ENTRY' BLOCK LEGEND TYPE DESCRIPTION Datum specification block sub type Terminator ( no more entries ~ DATA FORMAT ~** DATUH SPECIFICATION BLOCKS SPEC I f I CAT IONS P m g ¢ 20 HNEM SERVICE SERVICE AP1 AP1 AP1 APl FILE ID ORDER # UNIT LOQ TYPE CLASS MOD # PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT CS DSN TENS DSN CCL DSN GR DSN FDSN NDSN DSN HRAT NPHI DSN 37817X FT 0 0 0 0 3 37817X F/MI 94 0 0 4 2 378i7X LB 94 0 0 4 2 37817X 94 0 0 4 2 37817X AP1 94 .0 0 4 2 378178 CNTS 94 O 0 4 2 37817X CNTS 94 0 O 4 2 37817X 94 0 0 4 2 37817X g 94 0 0 4 2 4 0 ! 68 4 0 I 68 4 0 t 68 4 0 't 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 RECORDS DEPT C.$ TENS, CCL GR FDSN NDS,H HPHI ?,50 25. 547 891 . 000 -1 , 000 O, 000 293 'I 080'0..000 28.49;3 1366.200 7.857 4;3. 109 22.839 0700. 000 27.:306 14?4. 200 7,:877 21 .494 30. 149 1 06,00,000 29,642 1463,.400 7.891 12,008 19.552 1 0500,'000 :30,469 1420.200 6.189 0400.'000 :3'1 ,4-06 1380. 085 ?,778 5.876 NRRT 581,670 19752.629 15,340 612.63:8 19705.406 36.287 536.250 21567.270 45.761 834,'092 22946.062 32. 191 69.646 1831.880 25208.918' 15,578 29,660 1915,468 25346,043 15.176 Page '21 TRAILER RECORDS FILE TRAILER File name,~ &GSFO!.003 Service name: Version Maximum length: I024 File type: LO Next ~ile: Date: Page 22 ********************** FILE' HEADER **** ******************* File name: ,004 Maximum length:. '1024 Service name: Version File type: LO Previous ?ile: Date: INFORMATION RECORDS Page HNEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR CN WN FN COUN STAT CTRY AP{N LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF DMF RUN TIME DATE LUN FL LUL ENGI WtTN DD DL CBD! CBLI TLI BLI TCS TLAB BHT MRT MT DFD NVIS DFPH DFL RHF MFST MFSS BP EXPLORATION W-29 API PRUDHOE BAY DATE LOGGED: NORTH SLOPE ............ ALASKA ............ USA ............ 21:834,900 ....................... ~0 Deg. 0 Hin. O. 0 Sec. N ,o . , SeC. 11H ..... ,, , ..................... 12E ............................. 92,4:00 ...... , ................... 92,400 .......................... HUM: 5.0- 029-2!834 ......... 07-'I6 90 i ilmlmllll~ IItll ·1111 omltl ilmll~ll·lm lllll Ilmll mllll iiiIIltll·l 4? 1800 ..... ° · ° s ~ · m m 1'1' ~0, '0'00 ............. 1{S? 7/'9,0 .......................................... 0 m o m ! i m · m m 37817X ........................................ 5130'1. · SLOP~: NORTH NORTH SLOPE itmll i~111 11111 IIlil iiiii 11tll iiii1 I·111 t11tl IIIlt iltll YARBRO LUECKER 09 O 8..O 0 O ......... , 0820.000 .......... '0. 000 .............. 0.000 .............. 0400· ,000 .......... 0820. 000 .......... 0.000 .............. 1.00.00.0 ........... 0.000 .............. 0.000 .............. PRODUC:ED FT FT FT .,.,.,,,,.,.,.,,.,.,,,...,,,,,,,.,,. FT FT ,.,..,....,,....,...,,.....,,,..,... HR .,,....,..,..........,...........,.. HR .................................... DEaF .................................... DEGF mmlllm··lml·mmlllelllm·lmlllllm··mll · I · m i m I m m m ! s I I I I · · ii m m m I I 41 · I m e 0.000 ................................................... 0.000 ................................................... 0.000 ................................................... 0.000 ................................................... 0.000,' .................................................. 0,000 ................................................... LB/G cP OHHM OHHN DEGF OHMM 0 0 40 0 0 40 0 0 40 0 0 20 0 0 20 0 '0 20 0 :0 4 0 0 34 0 :0 34 0 0 2 0 0 3 0 0 3 O 3 4 0 3 4 0 3 4. 0 3 2 0 3 2 O 3 2 0 0 2 0 0 4 0 .0 8 0 0 ~ 0 0 10 0 0 10 · 0 0 20 0 0 20 0 "0 20 0 '0 20 0 3 4 0 3 4 0 3 4 0 3 4 0 3 4 0 3. 4 0 2 4 0 4 4 0 ! 4 0 ! 4 O 2 20 0 2 20 0 2 4 0 2 4 0 2 4 0 2 4 0 2 4 0 2 4 0 2 4 O 2 12 0 2 4 65 65 65 65 65 68 65 65 65 65 65 68 68 68 65 65 65 79 68 65 79 65 65 65 6.5 65 6,9 68 68 68 68 68 68 68 68 65 65 68 68 68 68 68 68 68 65 6:8 INFORMA T ION RECORDS Pagm 2,~ MHEM CONTENT9 UNIT TYPE CATG SIZE CODE ERROR HCST 0.000 ................................................... DEGF 0 2 4 68 ness ................................................... o ~ ~2 ~5 · I IIllll IIIIlIIIIIIIlIllIlI I II I I · II IIII · BS 8 500 0 3 4 68 'l IlIIlIlIIfIeIlIlIIIlIIIIIIIlIIdllIdIIlIIIIIlIIlIIII COMMENT RECORDS Page 25 Well Location Comment 1: 'Well Location Comment 2: Well Location Comment 35 Yell Location Comment 4: Yell File Comment I: TIED Well File Comment 2: Well File Comment 3: Yell File Comment 4: .SURFACE: 840' FNL & 1444' FEL INTO SCHLUMBERGER CEMENT BOND LOG DATED 08-13-88, PASSES 1-4 (WELL SHUT-IN), PASS 5 (WELL FLOWING), PASS 6 (WELL SHUT-IN / 10 MIN, AFTER FLOWING,) HODGES & LEHMAN AVERAGE OF PASSES 1-4 ONLY, ** LIS tape wri%ten by: ANCHORAGE COMPUTING CENTER ** ** All curve and tool mnemonics used ar~ those which most closel~ match ** ** Halliburton curve and .tool mnemonics, ** HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9935, O0 1 0835, O0 CS3 DSM F/MI CS DSH F?MI 10397, O0 1 0814,75 TENS3 DSN LB TENS DSN LB 1 0397, O0 1 0814.75 CCL3 DSN CCL DSN 1 0397, OO 1 0814,75 GE3 DSN API GR DSM API 1 0397, O0 1 0814,75 FDSN3 DSM CNTS FDSN DSN CNTS 1 0397, O0 ! 01914 . 75 NDSN:3 DSN CNTS NDSN DSN CNTS 1 0:397. O0 10814,75 NRAT3 DSN NRAT DSM 1 0397, O0 10814.75 NPHI3 DSH ~, HPHI DSH ;~, I 0397, O0 10814,75 DATA .F.ORMAT SPEC I F I CAT IONS ENTRY BLOCKS *********************** ENTRY TYPE SIZE CODE '1 16 1 66 0 I 66 ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 'Datum sBeci?ication block sub,type .0 Terminator ( no more entries Page 26 D 'TA FORMAT DATUM SPECIFICATION BLOOKS e*ee ************************************* SPEC I F I CAT I.ONS SERVI.OE SERVICE MN'EM ID ORDER # API API API API UNIT LOG TYPE CLASS MOD FILE PRO # # SIZE LYL SMPL RC PROCESS INDICATORS DEPT 37817X FT 0 0 0 0 CS DSN 378i7X F/Mi 94 0 0 5 TENS DSN 378i7X LB 94 0 0 5 COL D~N 378i7X 94 0 0 5 GR DSt4 378i?X API 94 ~0 0 5 FDBN DSN ~?Si?X CNTS 94 0 0 5 NDSN DSN ~?Si?X CNTS 94 0 0 5 NRAT DSN 37817X 94 0 0 5 NPHI .DSN 378'I?X X 94 :0 0 5 4 4 0 3 4 0 3 4 0 3 4 0 3 4 0 3 4 0 3 4 0 3 4 0 3 4 0 1 68 1 G8 1 68 1 68 1 68 000000 000000 00000'0 000000 000000 000000 000000 000000 000000 0000'00 000000 000000 000000 000000 000000 000000 000000 00000.0 000000 000000 000000 000000 000000 000000 000000 000000 000000 ' " DATA RECORDS DEPT C~ TENS CCL GR FDSN NDSN NPHI 1'0814.750 ~l.lO0 89i.000 -1.OOO O,OOO 558.668 18654,809 '10800.'000 27.150 '1311.119 7,848 39.746 560.991 18603,?73 · 24. 226 0700,.000 31 .406 I420.200 8..075 22.215 SOl .833 2'1774.883 32, '022 10600,000 26,884 1416.959 7',967 14,890 868.955 22629.457 18,33S I 0500,0.00 28,828 '142,0,200 7,872 57,999 1953,547' 25611 . 039 5. 819 0400,000 30,9'47 1.366,20.0 7,863 42,7'48 1860,554 25509,055 .277 NRAT Pag~ 044 38.040 48,312 30.686 15.102 15,692 TRAILER RECORDS ,** FILE TRAILER **** *********************** File name: &G5FOI,O04 Service name: Vmr~ion #: Date: Maximum length: '1 '02.4 File type: LO Next ¢ile: Page 2 ? ~** FILE HEADER **** File name: .005 Maximum length: .10~4 Version #: File type: LO Previous ~ile: Date: I NFORMAT I ON RECORDS Page NHEN CONTENTS UHIT TYPE CATG .SIZE CODE ERROR CH WN FN COUN STAT CTRY APtN LATI LONG SECT TOWN RANG EDF EGL PD LNF DNF RUN TINE DATE LCC SON LUH FL LUL EHGI WITH DL CBLI TLI BLI TLAB BNT NAT MT DFD N¥IS DFPH DFL RMF NFST NFSS BP EXPLORATION .............. W-29 API NUN: 50-029-21834 .............. PRUDHOE BAY DATE LOGGED: 07-1'6-90 .............. NORTH SLOPE .................................. ALASKA · . ................................. USA .................................. 2.! 834,0.00 ...... , ...................................... · 0 beg, '0 Hin. O. 0 Sec, N ...................... oo. ? ? ? : : . H.in Sec · · I I IIIIIlllIlIIlI II IIlI .............. .,,: ................................. 12E .................................................; 92 4.09 I IIlIIllllll 41$lIlllllltIltll$1111tlIttllllllll$ 9~t400 ...................... 47,800 ...................... fl Iii IIl*IIIIIIItI I I I I I I I I I I I t I I I I I I 16/ 7/90 .................... 37elTX .................. 51301 · SLOP~ ................. NORTH ........ NORTH SLOPE YARBRO LUECKER 10908.00:0.., l'082.0,000, , , .0.,000 ....... O. 000 ....... 10400,.000,,, t0820,~000,.. O.OOO ....... 1100,000 .... 0.000 ....... O,OOO ....... PRODUCED | I I I I m I ! · i I I i i i I I i · i i ! i i I m ~i m i m · i w i I m i I 41 i i O.OOO ........................... O, 000 ........................... O. O.O0 ........................... O.OOO ........................... 0.000 ........................... O. O0 0 ........................... Illmtllltlll ml.lmlllillll mmlmllmlllll Illllllllill iIIllllltlll iiiiiitliiii IlIIIItIIlII IIlIIIIIIIlt IlIIIlIIllII IllIIIIIlIlI llllllll mill·mill ................. : ..... : .... : IIlllIllllllllll IIIII IlllllllltIllltlflllllllllll IIIIIIlIItllllllllllllllllll II11111111111111111111111111 IilllllllIIIIIIIItl IIllllll IIIIIII11111 IIIlIttll IlIlIIII llllltIt IIIIIIit IIIIIIII !1111111 iIIlllil IIIIlIII IlllIIlI mlIllllltllt IlllllllIIll 111111111111 iIIItllllIII Illllltlllll IIIIIIIlllll IIItlfllllII llllllIIllll 11tll41elItl · · · I m I · & m m I m I I m i I · m Iiiii iiiil IIiil iiiii iiiii iiii1 tllll IIIll IIIII IIlII I IlIII IIIII I IIIlI IIllI · m m m m m m * m i · · · I I I I I · i · · · I m i e · I e · · · i m I · iiiii iiiiiii 11114 IiII! !1t1111 IIIIIIIIIIIIII Iiit1111111111 IIilllllllllll 6:666 .... :': ............................................ · II I · I · · · I I I I · · I m i · · I · I I m ! m i i m m · i · . I I I I m m · II m e t I S I 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 .0 3 2 65 0 O 2 79 0 '0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 10 ,65 0 O 20 65 0 0 20 65 0 ,0 20 65 0 '0 20 65 FT 0 3 4 6.8 FT 0 3 4 68 FT 0 3 '4 68 FT 0 3 4 68 FT 0 3 4 68 FT O 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF O 1 4 68 DEGF 0 1 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP O 2 4 68 0 2 4 68 O 2 4 68 OHHN 0 2 4 68 OHHN 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHNH 0 2 4 68 I HFORMAT I OH RECORDS NNEN CONTEHTS UHIT NCST NCSS BS allllllllllllllllllllllllllllllmtlllllllllllllllllt '1 lllllllllllillitllllllJllllllllll#lll I iiiiiii 8 } 500 ................................................... DEGF Page 31 0 2 4 68 0 2 12 65 0 3 4 68 0 3 4 68 TYPE CATG SIZE CODE ERROR ' ' COMMENT RECORDS Well Location Comment 1: 'Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: Well File Comment 13 Well File Comment 2: Well File Comment 3: SURFACE: 840~ FNL & 1444' FEL TIED INTO SCHLUMBERGER CEMENT BOND LOG DATED 08-13-88, PASSES I-4 (WELL SHUT-IN), PASS 5 (WELL FLOWING). PASS 6 (.WELL SHUT-IN / 1.0 HIM, AFTER FLOWING,) HODGES & LEHMAN AVERAGE OF PASSES 1-4 ONLY. Well File Comment 4: ********************************************************************************* ******************************************************************************** · ~ LIS tape wpitten by: ANCHORAGE COMPUTING CENTER m* · * All curve and tool mnemonic~ u~ed are tho~e which most closely match ** · ~ Hallibup.ton curve'and tool mnemonics, 4. ******************************************************************************** ******************************************************************************** HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT HNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9935. O0 1 0835. O0 CS4 DSN F/MI CS DSN F/MI ! 0447.50 I OBi 4.75 TENS4 DSN LB TENS DSN LB I 0447,50 1 0814,75 CCL4 DSN CCL ~)SN 10447,50 ! 0814,75 GA4 DSN API GR DSN API ! 0447,50 1 oel 4,75 FDSN4 DSM CNTS FDSN DSM CNTS 10447.50 ! 0814,75 NDSN4 DSM CNTS NDSN DSN CNTS 1 0447.50 I 0814.75 NRAT4 DSN NRAT DSM 1 0447,50 I 0814,75 NPHI4 DSN ~{ NPHI DSN ~. 10447.50 10814.75 Pag~ 3; DATA FORMAT SPECIFICATIONS ENTRY BLOCKS ENTRY TYPE SIZE CODE 16 0 66 66 Page ~mm ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum specification block sub-type 0 Terminator ( no more en%ries ) ~ ~ DATA FORMA ~** DATUH SPECIFICATION BLOCKS ******************************************* T SPEC I F I CAT IONS Page 34 SERVICE SERVICE AP1 APl AP1 AP1 FILE MHEH ID ORDER # UNIT LOG TYPE CLASS MOD ~ PRC # SIZE LVL SMPL RC PROCESS INDICATOES DEPT 37817X FT 0 0 0 0 5 Cg DSS: 37817X F/MI 94 0 0 6 4 TENS DSH" 378'17X LB 94 O O 6 4 CCL DSH 37817X 94 '0 0 6 4 GR DSHi 37817g AP{ 94 0 0 6 4 FDSN DSN 37817~ CNTS 94 0 0 6 4 NbSN DSN; 37817X CNTS ~4 0 0 6 4 NEAT DSN 37817X 94 0 O 6 4 NPHI DSN 37817X ~ 94 0 O 6 4 4 0 1 68 4 0 '! 68 4 0 1 68 4 0 1 68. 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 I &8 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00'OOO 000000 000000 000000 000000 000000 000000 000000 000000 00000,0 000000 000000 000000 000000 DATA DEPT CS ' TENS CCL NPHI _ - : - ~:__: _ - . . ~ .~:,_. ...., ._ .... __: -: _. _~: ~-- _ ....... _., .. .... : :..._ 1.0814,750 5;6, 115 e91,'OOO -1 ,O.OO 10,252 RECORDS GR FDSN NDSN NEAT 0.000 598,026 18670.652 14,026 1.0800. 000 28,31 i 13t2,200 7,924 22,783 I 0700.:000 31 ,095 1420,200 ?.917 2.6.501 48,873 586.459 18647.488 18.732 626,202 22.076.656 36.2i7 40,964 '1.0600.'000 30,469 t420,200 7.962 1'3,746 19.453 li13,990 24782,449 25. 035 10500;000 26,454 1409.400 7,888 5.320 1 09.873 2114. 127 27406,645 14.457 FILE TRAILER *********************** File name.: &~SF'OloOO5 TRAILER RECORDS Servic~ name: Vcrzion #: Date: Page Maximum length: File type: LO Next ~ile: ~,~ FILE HEADER ********************** File name: ,::006 Service name: Maximum length.: 1'024 Version #: File type: LO .Previous ~ilm: Date: I NFORMAT I Obi RECORDS. HHEH COHTEN.TS UNIT TYPE CATG SIZE CODE CH WN FN COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF EGL PD LHF DNF RUN TINE DATE LCC SON LUN FL LUL ENGI WITH DL CBD! CBL! TLI BLI TCS TLAB BHT NRT NT NSS DFD N¥IS DFPN DFL RN RHF NFST RNC BP EXPLORATION W-29 PRUDHOE BAY NORTH SLOPE ....... ALASKA ....... USA ....... ~1834.000 ................ 0 _Deg, 0 Nih, 0 ~1 Sec 0 ueg. 0 Min, 0 ~0 Sec 11N .................... 12E .................... 92. 400 ................. 92.4.00 ................. 47.8'0.0 ................. HS ...................... DF ..................... I S I m m i i e I ! m e ~ I m I m m m ~ I i ~ 1100.000 ................. '! 6/ 7/90 ................. 37~17X ............... NORTH SLOPE ...... NORTH SLOPE .: .... YARBRO LUECKER 109'08,000 ................ 1 0820.000 ................ O. 000 ..................... O. ~000 ..................... i 0400· 000 ................. 10820.~000 ................. 0.000 ..................... 11 0~0. 000 .................. O. 000 ..................... 0.000 ..................... PRODUCED ....... API HUN: 50-029-21834, DATE LOGGED: 07-1'6-90. ll~IIl immml I·lII IIlIl. lllmlll lItIIIf IIIItll IIIIiii tlt1111 Iiim! fttlf mmlll IIIII IlilI IItlI It111 IIIII I~11111 IIIIII1 tll·lll IIIllII IlIIlII IIIl·II IlIllII I I m · I m I · I ii S I I m i I I · al I m m · e . I · I · i · · mmlllll~ml i IIl·lmlmmm iIIimmllll ilmllllmml I1~1111111 · Illttlll·l I IIIIIIIitl I Illlllllll t I IIIIIIIIII IlllIIllllll I I I i mmmmellm lllllmIt mlmmlll· lmmmltll ii!11111 111111ti iiiiiiii iii11111 iiiit111 iiit1111 iiiiiiii iiiiii11 iiiit111 iii11111 iiii1111 IIi11111 iii11111 Iiiiiii1 ~: ~:. ........ : : I I i I: .............. I · · · a m I I i, I ii a · I I · · I m I · · I i ! 0 · '000 .............................. 0 . 000 .............................. 0,000 ............................... 0.000 ............................... 0.000 .................................................. 0.000 ................................................... mllllmmllmliIlllllllllll·l · mliIllllllil.llll I IIiiiiiiiiiiiiiii!1 t11111111tlltliiiii IiIIillllllllllllll iIIiiiiilllllllllll Illlllllt·lllllllll 0 0 40 65 0 0 40 65 0 .0 40 65 0 0 20 45 0 0 2O 65 0 0 20 65 0 .0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3' 2 65 0 0 2 79 0 0 4 68 0 0 8 65 0 0 2 79 0 '0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 i 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHHN 0 2 4 68 OHNN 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHHH 0 2 4 6'8 Page 37 ERROR I NFORMAT I ON RECORDS CONTENTS UNIT B~ 0 0 0 "~6~ ........ i .......................................... 500 ' DEGF TYPE CATG 4 12 4 4 CODE 68 65 68 ERROR · - COMMENT RECORDS Page 39 Well Location Comment i: SURFACE: 840' FNL & i444' FEL 'Wel! Location Comment ~: Welt Location Comment 3: ~e]l Location'Comment 4: Wel! ~ile ~ommen% 1~ TIED INTO SCHLUMBERGER CEMENT BOND LOG D~TED 08-13-88, Well File Comment 2: PASSES '1-4 (WELL SHUT-IH), PNSS 5 (WELL FLOWING), Well File Comment 3: PASS 6 (WELL SHUT-IN ? 10 MIN. AFTER FLOWING.) Well File Comment 4: HODGES ~ LEHMAN AVERAGE OF PNSSES 1-40HL¥, clo~elw match LIS tape written by: ANCHORAGE COMPUTING CEHTER All curve and tool mnemonics used are those which most Halliburton curve and ~ool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT 9935,00 10835.00 CS5 DSN F/MI CS DSN F/MI 10447.50 10814.75 TENS5 DSH LB TENS DSH LB 10447.50 10814.75 CCL5 DSM CCL DSN 10447.50 10814.75 GR5 DSH API GR DSM API 10447.50 10~14.75 FDSN5 DSH CNTS FDSN DSM CNTS 10447.50 10814.75 NDSN5 DSM CNTS NDSN DSM CNTS 10447.50 10814.75 NRAT5 DSM HRAT DSM 10447.50 10814.75 NPHI5 OSH ~ HPHI DSM ~ 10447,50 10814,75 ENTRY BLOCKS 'ENTRY D A T A F 0 R H A T SPECIFICATIOHS Page 40 TYPE SIZE CODE ,0 1 66 ~** ENTRY BLOCK LEGEND **** TYPE DESCRIPTION · 16 Datum speci~ica:ti.on 'block ~ub-t~pa :0 Termi. natoP ( no mope entpies ) - - DATA FORMATSPECIF ICATIOHS ~** DATUI'! SPECIFICATION BLOCKS ************************************** Page 41 SERVICE SERVICE API API API API FILE HNEM ID ORDER # UNIT LOG TYPE CLASS MOD # PRC # SIZE LVL SNPL RC PROCESS INDICATORS DEPT 37817~ FT .0 0 0 0 6 CS DSN' ~7@17~ F/HI 94 0 0 7 5 TENS DSN 37817X LB 94 0 0 7 5 CCL DSN 37817X 94 '0 0 7 5 GR DSN 37817X API 94 0 0 7 5 FDSN DSN ~7817X CNTS 94 0 0 7 5 NDSN DSN 37817X CNTS 94 0 0 7 5 NRAT DSN 378'17X 94 0 .0 7 5 NPHI .DSN 378i7X ~ 94 0 0 ? 5 4 0 1 68 4 0 I 68 4 0 1 ~58 4 0 1 68 4 0 1 68 4 0 1 6'8 4 0 1 68 000000 .000'0'00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 'DEPT HPH! 0814. 750 10.312 ! 0800,000 22,6;28 1 07 00. 0 00 28,779 1 0600. O00 '.17,035 1 05.0'0, ,000 5 .E~O5 D R T R RECORDS CS TENS CCL GE FDSN NDSN NRAT 19.30! 934.200 -1 , 000 O. 000 597.208 18608. 980 14. I O1 3'0.234 :1463.400 8.064 103.989 188'9.738 28.594 1463,400 7,983 16.33! 927.186 231:04,68'0 29.082 Page 27.902 1463.400 8,089 17.652 561.347 21596.465 43.932 28.216 '1409.400 7.863 43.349 580.386 18477.531 36.021 · ~ ' TRAILER RECORDS FILE TRAILER ************************ name: &GSF01,006 Service name: Version #: Date: Maximum length,:. !'024 File type: LO Next ~ile: ~,** F I LE. HEADER ********************** File name.: ..007 Service name: Version #: Date: Maximum length: 1024 File type: LO Previous ~ile: I NFORMAT I ON RECORDS ,, Page 44 MNEM CONTENTS UNIT TYPE CATG SIZE CODE ERROR CH WN FH COUN STAT CTRY APIN LATI LONG SECT TOWN RANG EKB EDF EGL' PD LMF RUN TI~E DATE SON LUN FL LUL ENGI WITN DL C~L! TLI TCS TLAB BHT HRT MT DFD H¥IS DFPH DFL RH RMF NFSS RMC BP EXPLORATION U-29 API PRUDHOE BAY DATE LOGGED: NORTH SLOPE .................. ALASKA .................. .USA 2'18~4 .000 ' O Deg, 0 Nin.~ O, 0 Sec, H ...... , NJn , $~c ....... 11N · Itdlltlltlllllillllllltllllll 12E,.. ............................... 2, oo ............... : ................ 92 400 t It111111~111t1111111111111 47 800 I llllllllllllllllllla$11lll ~S,, ,,, ,,,,,, . ,.,,,,,,,,,,, ,,,,,, ii'ii lllllllll.lllll&llllllllll IIIitl 1'10~ 000 I Itlllltltllllllltlllllll Illtll I 16/ 7/90 ' · ; IIIIlIIIIIIIIIItIlIIlIlI IIIIlt 37~l?X ............ , .....,, , ........ 513 01 scoP ................. ................ NORTH ............. ? .......... · NORTH SLOPE YAR~RO ........................ LUECKER ...... :: .... ::..: ........ I:0900.000 .............................. 'IOe~O 000 · IllflllllililtIIIIIlIlIIIllllllllll 0 OOO · 11411lllllllllllllIIllIIIImllllllllllli 0 O0 0 · · 10400 ~OO I IlllllllllltllllleIl.llIllIllIllll. 10820. 000 ................................... O.O00 ....................................... 1100.000 .................................... 0 '000 I IllIllIlllllalllIIlIllIllIIlllllIllllll 0,000 ............................... ........ PRODUCED ........................ NUN: 50-029-21834, 07-1'6-90, I I · · I . I I | · I . · I . I i I · I · * I I 0.000 ............................. O. 000 ............................. 0.000 ............................. 0.000 ............................. 0.000 ............................. O. 000 ............................. · · 6:55b': .... :':": .... :":": ...... t I I · I · · I · I I I I I · I I I I I I · · I 41 I I I I· I I II I I II lIIIIlllllllll Illl,llIitIIll tlllllllllllll IIIlllIIIIIlll tlIIIIIItllIll IIIIIIIIIII!11 IlillIIIIIIItl IIIlIIIIIIIIll IlIIlllllttlll I tllIllllllltll ttIIIIIlllllll llIIltllllllll IIIII111t11111 lllIIlll*lllll ltllIIIIIIIlll IIIII111111111 1t111111111 llllltlllll III11111111 IIit1111111 Iltlllllfll I!111111111 IltillllIII !111 Illllllllll !!11 IIII IIIII!11111 IIII IIIlIIIllll IIII IIIIIIIIIII IIII IIIIIIIlIII Illl IIII IIIIIIIIIII IIII IIII IIIIIIIIIII 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 .0 20 65 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT O 3 4 68 FT 0 3 4 68 FT 0 3 4. 68 0 3 2 ~S 0 3 2 65 0 3 2 65 0 '0 2 79 0 0 4 68 -0 0 8 65 0 0 2 79 0 0 10 65 0 '0 10 65 0 0 20 65 · O 0 20 65 0 0 20 65 0 0 20 65 FT O 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT .O 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF O 1 4 6e 0 2 20 65 0 2 20 65 LB/G O 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHNH 0 2 4 68 OHMN 0 2 4 68 DEGF 0 2 4 68 O 2 12 65 OHNN 0 2 4 68 I NFORMAT I ON RECORDS Page MNEM CONTENTS UHIT TYPE CATG SIZE CODE ERROR MCST 0 000 DEGF 0 2 4 68 MCSS 0 ~ 1~ ~5 ~'666 ....i ....i .......................................... o ~ 4 ~e BS 8.500 ............. , ..................................... 0 3 4 ~8 COMMENT RECORDS Page 46 Wel 'Wel Wel I Location Comment 1: SURFACE I Loca.~ion Comment 2: I Loca%ion Comment 3: 1 Location Comment 4: I File Comment 1: TIED INTO I File Comment 2: PASSES 1-4 840' FNL & 1444' FEL SCHLUMBERGER CEMENT BOND LOG DATED (WELL SHUT-IN), PASS 5 (WELL FLOWING). I File Comment 3: PASS 6 (WELL 8HUT-IN / 10 MIN, AFTER FLOWING,) 1 File Comment 4: HODGES & LEHMAH AVERAGE OF'PASSES 1-40HLY, LIS tape wrilt~en bp: ANCHORAGE COMPUTING CENTER ~11 curve and tool mnemonics us.ed are those which moz.t closely match Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMB£ROER TOP BOTTOM 'MNEM SERVICE UNIT MNEM SERVICE UNIT IIIi~I IlI~ IIiImml mI~I DEPTH FT DEPT FT AVG COMPUT ~ AVG COMPUT ~ SDD COMPUT SDD COHPUT DEPTH DEPTH 9935.'00 1 0835,.00 '!'0397. O0 1 0~I 4 , 75 1 0397, O0 ! 08! 4. ?'5 DATA FORMAT SPEC I F I CAT IONS Page ENTRY TYPE SIZE CODE 1 6 1 66 ,*~ ENTRY.BLOCK LEGEt4D TYPE DESCRIPTION 16 Datum speci'~ication block sub-type 0 Termi, nator ( no more entries ) DATA FOR.MAT SPEC I F I CAT IONS page ************************************* DATUM SPECIFICATION BLOCKS HNEM SER¥{OE SERVICE API API API API FILE ID ORDER # UNIT LOG TYPE CLASS HOD # PRO # SIZE LVL SHPL RC PROCESS INDICATORS DEPT SDD 378]?~ FT '0 0 0 9 ? COHPUT 37817~ ~ 94 0 .0 1 6 COMPUT 37817~ 94 ~0 0 t 6 4 0 1 68 4 0 ! 68 4 0 1 68 00000'0 00000'0 000000 000000 000000 000000 000000 000000 000000 DA TA REC ORDS Page DEPT -- L -- ~ ~ . . ~ , .~' L~'. ~__' . - - .... 'I' 0814.75.0 '1 'OE:O 0,000 1 '0 ? 0.0,0'00 1.0600,000 I ~0500,000 SDD ! , 235 3,753 21 .635 2, O14 3:0.92? ,948 8..862 .4 07 6,204 ,319 1 04.00,000 5,750 ,36'1 FILE TRAILER *********************** File name.: &GSF.'O'I,O0? Maximum lang.:hr. 1~024 TRAILER RECORDS Service name: Version #: Date: File type: LO Next ~ile: Page 50 ************************ REEL TRA[LER Service name..: &GSF01 Date: 90/'08/24 Origin: Reel name: 37817X Next reel: Continuation #: 01 Comments: *********************** *** TAPE' TRAILER *********************** Sap. vice name: &GSF'O'~ Next tape: Date: 90/08/24 O~igin: Tape name: 3.781.7A Comment~: Continuation #: 01 ********************** bis T~PE VERIFICATION I,,ISTING ,V~ 010,~'02 VE~I. FICATION LISTING PAGE ! ~* REEL NEADER ** ~ERVICF NAME ;EDIT )ATE :98108/15 JR?GIN :FLIC ~ONTINUATION ~ ~RFV~O~6 RREb ~O~MFNTS :EDIT L~S,STANDARD PRUDHOE BAY w . 29,API 50-029-21834 TAPE HEADER ** ~ER¥ICF NAME :EDIT 5RIGIN :FhlC ~APE NAME :72~85 ONTINUATION # ~RE¥?O~*S TAPE : ~TO"MENTS :EDIT LI$,STAMDARD PR'UDMOE B~Y ~* FIL~ HEADER ?ILE N~ME ~EDIT 001 SE~v~c~ ~A~£ :Fb{C VERS~O~ # :001A02 'I[E TYPE PR'EV ~Ol,]S FILE . ** CO~4~ENT8 ** ************************************************************************************** * SCHLUMBERGER * * AbASKA COMPUTING CENTER * COMPANY : STANDARD ALASKA PRODUCTION CO, ELL' ' ~ - 29 API~ = 50-029-21834 ~iEbP ,= PRUDHOE BAY COUNTY = NORTH SbO:PE BOROUGH ST,~TE = ALASKA .~VP 010.H0~ VEPIF'ICATION hISTI~G PAGE 2 lOB NU,B~R AT AKCC: 72885 SUN #1, DATE LnGGED: lO-AUG-88 -~DP: RICK KRUWELL ]ASING : 9 625" ~ 1038~' - BlT SiZE : 8.5" TO 10950'(DRILLERS DEPTH) FYPE FI~UID : L~GNO SUbFANATE >ENSITY : ~5SbB/G R~ : 3.05 ~ 68 DF /ISCOS?TY : R~F : 2.64 ~ 68 DF ~H = 9.5 ~,C = 2.~I @ 68 DF ~L~.'ID LOSS = 5,2 C3 R~ AT BHT = 1, 8 e 194 DF ~ATRIX SANDSTONE ~IFL~ "E~ARKS: 1,)SIX RUBBER FIN STANDOFFS AND 2' HOLE FINDER USED ON TOOL ~SFL TOO[. STICKING FRO~ 10850' TO 10650' CNL MATRIX = SAND. CORRECTION : CALIPER, ~ATRIXs6ENSIT¥ = 2.65 G/CC, FbUID DENSITY G/CC. CNL BOWSP~ING USED. FIR T PASS USED AS ~AIN PASS DUE TO TOOL STICKING ~ORE ON SECOND PASS. FLIC COMENTS.' 1,)FILE EDIT.O01 CONTAINS DITA OF DUA5 INDUCTION (.DIL). RICRO SPhERICAl, bY FOCUSSED bOG (.DJ, T). BOREHOLE CONPENSATED SONIC (.BHC). LITHO DENSITY (.LOT)~ CO~IPENSATED NEUTRON' LOG (.CN5), CONPENSATED NEUTRON ~,)FILE EDIT,O02 CONTAINS HI RES ~I.C~{] SPHERICALLY" FOCUSSED LOG (,DLT) ;VP O10,H02 V~RiFIC. ATIf)~ hISTING PAGE SAPPLED 9 .1~667' 3.~C~ANNEL HSFL.DLT aND CALS.DLT HA'YE BEEN DEPTH CORRECTED TO DUAL INDUCTION LOG. ******************************************************************************** * SCHLUMBERGER LOGS INCLI..IDEI) WITH THIS MAGNETIC * DUAL INDUCTION SPHERICALI~Y ~'OCUSED LOG (IDIL) * DATA AVAILABLE: 10929' TO 10371 * MICRO SPHERICALLY FOCUSSED LOG (DLT) * DATA AVAILABLE: 1091~' ~0 10371' * BUREHOLE COMPENSATED SONIC 50G (BNC) * D~TA'AVAILABLEJ 10897' * LITHO DENSITY LOG (,LOT) * DATA ~VAILABhE: 10934' TO 10371' * COMPENSATED NEUTRON LOG * ' DAT.A AVAILABLE: * COMPENSATED NEUTRON.LOG/GAmMA RAY THRU CASING * DATA A¥~ILABbE: 10388' TO 7694' , , , , , , , , , , , , , * , '~Vp OlO,M02 VERIFICATION LISTING PAGE 4 INFORMATION RECORDS ** ~ARbF TYPE :COMS MWE~ TUN I V~LU DEF I ......................... ........ CN ST RD ALAS~ omPanV Name FN PRUDHOE BAY Field Name ~N W - 24 ~ell Name NAT! LISA Nation STAT ALASKA State or Provi* COUN NORTH SLOPE County SFCT 21 Section TO~N 11~ To~nsbi~ RANG I~E Ra~e b~T! ba rude LONG Longitude OPER WARNER Operator's Cod* 0'548377 Service Order * sob APIN 50-02g-~1834 API Serial Num* Fb 840' FNb & 144. Field Location* TA.~LE TYPE M,,EM DEF! DEPT DEPTH CHANNEL * SFLU SFL Unaveraged* IbD IL-Deep ReSist* II,R Ih-Medium Resi* P $~ont, aneous Po* R (~amma Ray T~NS Tension CAbS SONIC CALIPER T~NS Tension T M~ES ~UD RESISTI¥'I * MTEM ~U'D TEMPERATUR* HTEN HEAD TENSION DT Delta-T G~ Gamma Ray T~NS Ten C~b! Cad'per LL ~onq Lower win* ~U uon~ upper L.$ Lon~ Sp~einq C* Ls~T~ Llt:,,holbg Wt6do* 1 ~hort Spacing * SS2 snort Sba¢ind * LS O~ALITY CONTRO* SS QUAbITY CONT~O* ,VP OlO.H02 VERIFICATION LISTING PAGE 5 LSHV Long Spacing N, SSHV Short Spacin~ * PEF Photo-Electric* RHOB Bulk DensltF DRHO Delta rho DP[t! Density Porosi* MPES .Un RE$ISTIVIT* ~TE~ ~UD TE~PER~TUR* TFNS Tension HTEN MEAD TENSION GR Gamma Ray T~R~ CAI,,I~RATED THE* RTNR RAW T~ERMAL NE* NPHI NEUTRON POROSI* RCNT RCNT RCFT RCFT CFTC CFTC CNTC CNTC TENS Tension HTEN HEAD TENSION M~ES MUD RESISTIVIT* MTE~ ~UD TEMPERATUR* G~ Gamma Ra TNRA CALIBRATE~ THE8 RTNR RAW THERMAL NE$ NPHI NEUTRON POROSI* RCNT RCNT RCFT RCFT CFTC CFTC CNTC CNTC T~N,$ Tension HTEN HEAD TENSIOM M~ES MUD RESISTIVIT* MTE~ ~UD TE~PER~TUR* G~ Gamma Ray ** [)ATR WORMAT R,~CORD"E ' ** ENTRY BbOCK8 TYPE SIZE REPR CODE ENTRY 1 1 66 0 2 1 66 0 3 4 73 236 4 1 66 9 4 65 FT 11 I 66 4 13 1 66 0 14 4 65 15 ! 66 68 16 1 66 1 0 1 6.6 0 0,5000 ~DATU~! SPECIFICA, TION BbOCKS ~:NEM SERVICE SERVICE UNIT APl APl' API API FIbE SIZE SPb REPR PROCESS ',VD OlO,H02 VERIFICATION LISTING PAGE 6 ID LD D ~R DIL TENS ~ALS DLT ENS bLT HTFN DLT DT BHC GR TEM$ CALl LDT Lb LDT LU LDT LS LDT LIT~ t, DT SSI LDT bDT t, OT ,SMV LDT LDT tRHO LDT !PM I I~DT RES I, DT MT~M LDT TENS LDT HTEN LDT GR LDT TNRA CNL NpH~ CNL RCMT CNL RCF? CNL CFTC CNL MT~N CNL ~R. ES CNL ~TE~ CNL. GR' CNL TNRA NPHI RC~T CSG C~TC ORDER # LOG TYPE CbASS MOD FT O0 000 O0 0 OHMM O0 000 OHMM O0 000 Ohm~ O0 000 MV O0 000 GAPI O0 000 LB O0 000 IN O0 000 [,B no 000 OHmm O0 000 DEGF O0 000 1,8 no ooo U$/F O0 000 GAP! O0 000 LB O0 000 IN O0 000 CPS O0 000 CPS O0 000 CPS O0 000 CPS O0 000 CPS O0 o00 CPS O0 000 O0 000 O0 000 V O0 000 V ~0 000 0 000 G/C3 O0 000 G/C3 O0 000 PU O0 000 OH~ O0 000 DEGF O0 000 LB O0 000 LB O0 000 GAPI O0 000 O0 000 O0 000 PU O0 000 CPS O0 000 CPS O0 000 CPS O0 000 CPS O0 000 LB O0 000 LB O0 000 OH~M O0 0~0 DEGF O0 0 0 GAPI O0 000 O0 000 O0 000 PU O0 O0 CPS O0 0~0 CPS O0 000 CPS O0 000 O0 0 oo o 00 0 0 o o O0 0 O0 0 oo 0 O0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 O0 0 O0 O0 0 O0 0 O0 0 O0 0 O0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 00 0 O0 0 oo 0 NO, 1 J 1 1 1 1 1 1 1 1 1 1 1 1 ! 1 ! 1 1 1 1 1 1 1 1 1 ! 1 1 1 1 1 I 1 1 1 1 ! 1 1 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 ,4 4 4 4 4 4 4 4. 4 CODE (OCTAL} 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 I 68 000000000~0000 I 68 000000000 0000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 i 68 00000000000000 68 00000000000000 ~ 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000,000 ! 68 000000 0000000 1 68 000000~0000000 1 68 00000000000000 1 68 00000000000000 00000 1 68 0000000~0 1 68 0000000 0000 68 00000000 '00000 i 68 00000000~00000 68 000000000000~ I 68 000000000000 1 68 00000000000000 I 68 00000000000000 .,VP OIO.H02 VERiFIC,~TION LISTING PAGE 7 ~NTC CSG CPS O0 000 O0 0 I 4 ~E~$ CS~ I.,B O0 000 O0 0 1 4 4TEN CSG LB O0 000 O0 0 I 4 tRES CSG OHMS, O0 000 O0 0 ~. ,4 ~TEM CSG DEGF oo 000 O0 0 1 4 JR CSG GAPI O0 000 O0 0 I 4 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 6~ 00000000000000 1 68 00000000000000 ~* D~T~ FORMAT RFCORD ~NTRY gLOCKS TYPE SIZE REPR CODE ENTRY 1 1 66 0 2 1 66 0 ] 4 73 236 4 ~ 66 8 4 68 9 4 65 FT 1~ 1 66 4 13 ~ 66 0 ~4 4 65 FT 15 I 66 68 16 1 66 1 0 I 66 i 0.5000 DATU~ SPECIFICATION BbOCKS MNEM $FRVlCE SERVICE 'UNIT APl API API APl FILE SIZE SPb REPR PROCESS bOG TYPE CLASS 'MOD NO CODE O~DER # FT O0000 O0 0 1 4 1 680000000 O0 o oi° o.~. oo ooo ooo ~ ~ ~~ oooooooooooo o.~oo ooo oo o ~ ~ ~~ oooooooooo o ~.~. ~o ooo oo o ~ ~ ~~ oooooo~oooooo o ~ oo ooo oo o ~. ~ ,. ~ ooooooooooooo aa~oo ooo oo o ~ ~ ~,~ oooooooooooooo [u oo ooo oo o ~. ~ ~~ oooooooooooo.oo t~ oo ooo oo o ~ ~ t,0 oooo~ooooooooo ,,~oo ooo oo o ~. ~ ~~8 oooo~ooooooooo oH~oo ooo oo o ~ ~ ~~ oo0oo0ooo0oo00 o~a~ oo ooo oo o ~ ~ ~,~ oo0ooo0oo0oo00 t,.oo ooo oo o ~ ~ ~68 oooooooooooooo us/r oo ooo oo o , ~ ~~ oooooooooooooo ~:~oo ooo oo o ~ ~ ~68 oooooooooooooo ~,~oo ooo oo o ~ ~ ~~ oooooooooooooo ~.~oo ooo oo o ~ ~ ~6~ oooooooooooooo c~soo ooo oo o ~ . ,~ oooooooooooooo c~soo ooo oo o ~ ~ ~~ oooooooooooooo c~soo ooo oo o ~ ~ ~~ 90000000000000 c~soo ooo oo o ~ ~ 1~8oooooooooooooo c~soo ooo oo o 1 4 ~~8 oooooooooooooo cpsoo ooo oo o 1 4 16~ oooooooooooooo oo ooo oo o ~ ~ ~~8 oooooooooooooo 0 O0000 O0 0 il. 4 16800000000000000000 V O0 000 O0 0 4 1 68 0 0 00000000 V O0000 O0 0 I 4 16800000000000000 O0000 O0 0 1. 4 I 6800000000000000 G/C3 O0000 O0 0 1 4 16800000000000000 .,VP 010,H02 VERIFICATION I..,'[STI~.!G PAGE 8 )RgO I,DT G/C3 O0 000 )PMI LDT PU O0 o00 ~RFS LDT OH.M O0 000 ~T~[{ [,DT DEGF O0 000 CEOS LDT LB O0 000 ~TEN LDT LB O0 000 iR I,DT GAPI O0 000 NRA CNL O0 000 T NR CNL O0 000 PHI CNL PU O0 000 ~CNT CNL CPS O0 000 ~CFT Ci~L CPS O0 000 7F TC CN5 CPS O0 000 ~NTC Ch[., CPS O0 000 ~ENS CNL [,~B O0 000 ~T~N CNL LB O0 000 "RES CNL OHMM 00 000 ~T~ CNL DEGF O0 000 GR CNL GAPI O0 000 TN~A CSG O0 000 RTNR CSG O0 000 NpHI CSG PU O0 000 C NT CSG CPS O0 000 C~T CS~ CP~ O0 000 ~FTC CSG CPS O0 000 CNTC CSG CPS O0 000 TE~$ CS~ LB O0 000 HTEN CSG LB O0 000 ~'R~$ C$~ OHM~ 00 000 ~T~M CSG DEGF O0 000 UR CSG GAPI O0 000 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 oo oo oo oo oo oo oo oo oo oo oo oo oo o0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DEPT SP TENS TENS RTNR CFTC .T~R CFtC ~'R 5 1.0956 0000 SFLU -999 -999 -,99 -999 -999 .999 -999 -999 .-999 -999 -999 -99'9 -999 2500 GR 2500 ~RES 5625 ~R 2500 bU ~500 $82 ~500 SS,V 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 ~TEM 2500 NP~I ~500 CNTC .~500 MTEM '9gg 2500 -gg9 -999 2O -099 -999 -999 -999 -999 -999 "999 -999 -999 -999 -999 2500 TENS 2500 531 500 2500 2500 PEF 50~ GR 00 RCNT ~00 TENS 2500 ~CNT 5 DEPT TENS 10900 0000 SFLO ,8437 GR 53 4,0000 ~RES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 ! 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00~00000000000 1 68 00 00000000000 I 68 00~000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000~00000 1 68 00000000 00000 1 68 00000000000000 i 68 00000000000000 -g~g 2500 -99 2794 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 2500 CALS 2500 MTEN 00 blTH ° 0 TNRA 2500 RCFT 2500 HTEN RCFT 2500 2500 8,5762 IhD 3'0988 21,7656 TEM~ 5324,,0000 0 .8.330 MTEh ~04,7500 HTEN -999 2500 -999 ~500 -999 500 -999 2500 · -999 2500 -999 0 -999 2500 '999 2500 -999 2500 -999 2500 -999 2500 ] ' 3894 8 ,. 2578 1115,7500 r!VP OIO,HOP VERIFICATION LISTING PAGE 9 74 6250 GR 1.59 2500 LU 211 0000 582 1473 0000 SSHV 0 0116 DPMI 5968 0000 N'~EN 2 1259 NPMI 2251 9360 CNTC 0.~30 '999, O0 NPHI -999,2500 CNTC -999,~500 ~TEM 2!.7656 TENS ~77'7500 298 7500 OhS 134q 14 1133 19 4460 204 -999 -999 -999 0000 PEF 7032 ~RES 0000 GR 0456 RCNT 9453 TENS 8000 GR 2500 RCNT 2500 TENS 2500 GR 10800 0000 SFLO -14 5308 71 91 195 1476 0 6004 2 1922 0 -999 -999 -999 2813 GR 0000 NRES 9375 ~k 6250 LU 3750 852 0000 SSHV 0291 DPHI 0000 HTEN 1583 NPMI 9656 CNTC 8335 STEM 2500 NPH! 2500 CNTC 2500 ~TEM !0 1562 66i2500 0 8345 66 2500 TEN6 173 264 1350 -6 1241 20 4194 206 -999 -999 -999 5000 7500 0000 PEr 1574 MRES 0000 GR 4506 RCNT 5537 TENS 7125 2500 RCNT 2500 TEN8 · 2500 GR DEPT SP TENS T ?ENS ~FTC ~TNR 10700 0000 SFLO -47 5264, 81 132 147 0 5704 159~ -999. -999 -999 0313 GR 0000 ERE$ 2500 GR 1250 hU 8750 852 0000 SSHV 0003 DPHI 0000 HTEN 4078 NPHI 6233 CNTC 8345 ~TEM 2500 NP~I 2500 CNTC 2500 ~TE~ 14 8394 I, LD 28 t~188 TEN8 345 0 23 282 1350 9 1095 ~687 ~06 -999 ~188 TENS 750 0000 QLS 0000 PEF 5515 2500 GR 5421 RCNT .1665 TENS 6000 ~500 RC~ 2:500 TENS 2500 GR DEPT TEN'~ DT ORHO 10~00,'0000 SFI,,O 5.4,1875 GR 5240;0000 ~RE8 ' 86,0625 GR. 185'7500 LU 204,0000 S82 1478,0000 SSHV 60~0,0092 DPHi 4,0000 NTEN 21 8984 ILD 29 1094 TENS 0 29 314 299 135t 20 1276 8477 MTE~ 1,094 TENS 5000 58 7500 OLS 0000 PEF ~3200 GR 5324.0000 CALl 298.0000 LITH 0.0166 OSS 2.6914 RHOB 0,8330 MTEM 35,2187 TNRA 471~.7490 RCFT 5968.0000 HTEN 35.2187 TNRA -9992500 RCFT -999~2500 HTEN ~999.2500 4,8040 !bM 5308.0000 CAbS 206,8750 HTEN 5308,0000 CALl ~78.3750 LITH 0,0459 085 3,5996 RHDB 0,8335 MTEM 75,5000 TNRA 412161~ RCFT 6004:00 NTEN 75,5000 TNRA -999 2:500 RCFT -999!2500 HTEN -999 2500 10.7057 IbP 206,50 HTEN 52640000 CALl. 251 1250 LITH 0 0166 OSS 4 5547 RHOB 0~8345 ~TEM 38~ 0000 TNRA 0063 RCFT 5704 0000 HTEN 29 0000 TNRA -999 2500 RCFT -999,2500 HiTEN -999'2500 5240 CAbS 5] o.oooo CA ,I 3.0000 LIT}'{ 0.0234 OSS 2,4746 RHOB 0,8496 28'6094 TN~A 8,2187 94,2500 0 0239 2 4074 204 8000 1 9863 2274 2739 13~ 0000 ~99 2500 -999 2500 -999 2500 4 7714 8 7344 1299 0000 8 6406 54 4688 0 0049 2 7516 206 7125 2 1146 1 0000 -999 2500 -9992500 -9992500 9 3275 111t00 8 5078 64 0625 0:0093 2.4924 2066000 157~ 3094 569 25 0 -99 2500 -99~ 2500 -999 2~00 I~0635 7656 1186 0000 9 ~5 206 ~500 2 188 ,VP ~lO,H02 YEnIP'iC.ATION LISTING PAGE 10 NR ~FTC ~RES 9 5714 1716}5'605 CNTC 0 8496 -999 2500 NPHI -999.2500 CNTC -999.2500 MT~M 23 55J. 4 RCNtC 3984:0894 TENS 206,1500 GR -q99.2500 RCNT -999.2500 TENS -999.2500 GR J_0500 fi000 -4 4375 5484 0000 55 9375 98 9375 193 75OO 1480 0000 0 0081 6304 1 4589 0 -999 -999 -999 SFLU SSHv DPHI 0000 HTEN 3321 NPHI 0605 CNTC 8770 MTEM 2500 MPHI 2500 CNTC ~500 ~TEM 1739 5000 105 0 105 195 263 1352 0 1471 7 6003 204 -999 -999 -999 7500 TENS 8765 MTEM 7500 TENS 2500 LS 2500 OhS 0000 PEF 9972 ~CMT 0967 TE~S 2375 UR 2500 RCNT 2500 TE~S 2500 UR DEPT SPN ~- LL LS.V DRHO TE'~,S RTNR CFTC R T ~ R CFTC ~RES !04.00 0000 SF[,}J 11 2109 5308 0000 58 3750 98 6250 bU 193 0000 148! 0000 SSHV 0 00§~ DPHI 6124 00 HTEN 1:1947 ~PHI 1 77 7 NPHI 309~ ~24 CNTC 04 295 5000 ILD 6O 0 60 190 263 1351 '0 1430 5 6680 20O 9 5~76 5000 TEN6 8955 ~TK~ 5000 TENS 3750 LS 7500 ObS ~000 PEF 0~56 ~RES O0 GR 8898 RCNT 1357 TENS 6250 GR DEPT TENS DT ss~. LSHV DRHO TE~S cFTC ~RES RTNR CFTC ~RKS 10300 0000 '999 '999 74 '999 '999 '999 '999 '999 '999 '999 '999 4 378 0 SFLU 2500 GR 2500 ~RES 2500 CE 2500 LU 2500 8$2 2500 SS~V 2500 DPHI 2,500 HTEN 2500 NPHI 2500 CNTC ~500 ~TE~ 5128 NPHI 1275 CNTC 9512 ~TE~ -999 2500 -999 -g99 67 -999 -999 -999 -999 -999 -999 -g99 -999 5! 150~ 18 2500 TENS 2500 8125 ~500 I.,S 50O OhS ~500 PEF 2500 ~RE'S 2500 2500 ~CNT 2500 TE~S ~CNT ~,~GRTENS 4267 8291 RCFT ~o~4:oooo ~ 28,6094 TNRA -99g,2500 RCFT -999.2500 [~TEN -999o2500 123,0368 5484,0000 CALS 204,1250 HTEN 5484,0000 CALl 196,6250 LITH -0,0181 OSS 4,9258 RHOB 0,8770 ~TEM 107,8750 TNRA 6343,7500 RCFT 6304 0000 HTEN 107i8750 TN~A '999 2500 RCFT '999.2500 HTEN 'g99'2500 72,7971 5308,0000 CAbS 200,5000 HTEN 5308,0000 CAb! 193,8750 [,ITH 0,0049 4,0273 RHOB 0'89!I ~TEM 53,6875 TN~A 7!70,'.1006 RCFT 6'124,0000 HTEN 53,6875 TNRA 5415,3.320 RCFT 8,0000 }{TEN 58~6,81.~5 -999 2500 IbM '999 '999 5232 -999 -9 9 -999 -999 -999 -999 -999 1,559 2500 CAbS 2500 HTEN 0000 CALI 2500 I.,ITH 5O0 OSS .500 RHOB 2500 ~TE~ 2500 TNRA 2500 RCFT 2500 HTEN 2500 TNRA 0894 RCFT o000 H'rEN 0625 1688 73~1 1276 5000 -999 2500 -999 2500 -999 2500 83.3758 9 0938 1424 0000 9 0.469 39 3750 204 1375 1 174 4335 9404 1471 ~437 -999 500 -999 2500 -999 2500 59 ,6614 9 0625 147~ 0000 9297 43 8750 0 0112 2 6626 ~00 7500 1 1670 577~ 8086 0000 1431 6904 , 000 1 0 -999 2500 -999 2500 -999 0 -999 2500 ~999 2500 -999 12500 -999 2500 -9994 i0 1~* o00o ,VP 010,H02 VERIFICATION 5ISmlNG PAGE )EPT ~L 0 ~RE5 ~TNR 2FTC )T ~S~4V 'RI~O ~rNR FTC CFTC 'EPT ,SHV ~R~O TC 9TN~ CFTC "P T SP~ TE S DT Lb o0oo -999 2500 5825000 -999,2500 LO -999 2500 SS2 -999 2500 -999 2500 DP~I -999 2500 ~TFN -999 2500 NPHI -999 2500 4,0889 389,2579 ~NTC ,962~ 10100 0000 SFLU -999 -999 6~ -999 -999 -999 -999 -999 -9gg -999 4 2500 GR 2500 1875 2500 BO 2500 SS2 2500 2500 2500 ~TEN 2~00 ~P.! 2500 CNTC 2500 ~TE~ .3023 NPHI 9009 9756 ~T~,qM 10000 0000 SFY.,U -999 -'999 ~999 -999 -999 -999 -999 -999 -999i -999 -999 ,4 2500 GR 2500 2500 OR ]5 00 5'0:0 SS2 2500 SBHV 2500 DPHi 2500 HTEN 2500 NPHI ~500 CNTC 500 783 NP~I 1100 CNTC 9834 MTEM 9900,0000 SFLU -999.2500 GR. ,999,~500 l~Rg$ .,999,2500 GR -O 99,2500 L U -Egg 2500 -999 7500 -999 2500 67 1250 -999 2500 -999 2500 -999 ~500 -999 2500 -999 2500 -999 2500 -999 2500 -999 43 1512 186 TENS TENS L6 PEF GR ~C~T TENS 2500 GR 9368 RCNT 8958 TENS 1250 -999.2500 -999.~500 -999.2500 65 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 -999 -999 -999 47 1498 1.84 TENS MTEM TENS LS OhS PEF MRES 2500 OR 2500 RCNT ~500 TENS 2500 GR 2435 RCNT 0032 TENS 8750 OR -999 2500 -999 2500 TENS -999 2500 -999 2500 TEN5 -999 2500 -999 2500 -999 2500 PEF -999 ~ 00 MRES '999 ~00 -999 2500 TENS -999 ~500 GR 46 RCNT TEN~, 183 2500 -999,2500 ISD -999,~500 TENS -999o2500 ~'TEM '999.2500 TENS -999.2500 LS -999.2500 -999.2500 CALS -999.~500 HTEN 5204.0000 CALX -999.2500 -999.2500 -999.~500 RHOB -999"2500 ~TEM -999.2500 TNRA -999.~500 RCFT '999.2500 HTEN -999,2500 T~A 1531.3884 RCFT 5728,0000 HTEN 71.6875 -999,2500 -999.2~00 CAt,$ -999.2 00 HTEN 51.28,0000 CALl '999,2500 hiT/'{ -999.2500 OSS '999.2500 RHOB '999.2500 MTE~ -999,~500 TNRA '999,2500 RCFT -999.2500 HTEN '999 2500 TNRA 1624 0383 RCFT 5688 0000 HTEN 67 4375 -999.2500 IBM ~500 CAt, S -999, -999, 500 MTE~ -999,...~ I~ITH '999.:~ O0 OSS -999 500 RHOB '999 -999 -999 "999 1598 5'584 7] ~500 MTEM 2500 TNRA O0 RCFT ~00 HTEN 2500 TNRA ]140 RCFT ~00 HTEN 75 -999,2500 lh~ -999.2500 CALS -999.2500 HTEN -999,2500 CALl -999o~500 LITH -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -099 2500 -999 2500 -999 2500 3 8128 383 4728 1205 1250 ~999.2500 999'2500 -999.2500 '999.2500 ~999,2500 999i2500 '999 2500 -999 -999 2500 '999 2500 '999 2500 35~ 9942 2111 1234 0000 -999~500 -999 500 ~999 0 -99? 2,500 -999 2500 -Egg ~00 -999 -999 2500 -999 2500 5564 1236 0000 ,999,2500 -999 ~ 2500 -999,2500 -999 ~ 25 O0 -999,~500 i '.,VP O'lO,H02 VEPlFiCATIf~N L, IST.ING PAGE 1.2 R~O -FTC aRES ~RES DEPT TENS SS1. t,S~V DRHO TE~S RTWR CFYC ~RES CFTC ~RES DEPT SP TENS DT LSHV CFTC ~RF, S EPI, RTNR CFTC -999 2500 SS2 -999 2500 SSHV -999 2500 DPHI -999 2500 HTFN -999 2500 NPH! -999 2500 CNTC -999 2500 MTEM 422, ]4 CNTC 0,9927 ~TFM 9800 0000 SFbU -999 2500 GR -999 2500 ~RES -999 2500 GR -999 2500 LU -999.2500 862 -999,2500 SSH¥ -999,~500 DPHI :999,2500 ~TEN 999,2500 NPHI -999,2500 CNTC 500 MTEM '999'~647 NPHI 44~i9955 CNTC 9966 ~TEM 9700 0000 SFLU 99 -999 -999 -999 -999 -999 :999, 999, -999 3 60~ 2500 GR 2500 MRES 2500 GR 2500 l,,U 2500 $52 2500 SSHV 2500 DPHI 2500 MTEN 2500 NPMI 2500 CNTC ~500 MTE~ 2083 NPHI 03 NTC 9600 0000 -999 -999 -999 -999 ~999 -999 -999 -999 -999 -999 :~500 G~ 2500 NRES 2500 GR ~500 bU ~00 SS~IV 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC -99~ 2500 Ok.$ -999 2500 PEF -999 2500 M~ES -999 -999 -99~ -999 1521 181 2500 2500 RENT 2500 TENS 2500 2452 6284 TENS 6250 GR -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 41 1614 ~80 2500 TENS 2500 PTEh 2500 TENS 2500 l,S 2500 OhS 2500 PEF 2500 ~RES 2500 GR 2500 RENT 2500 TENS 2500 GR 4564 RCN~t 3298 TENS 6250 GR -999 2500 I. hD -999 ~500 TENS 5OO -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 31 1832 2500 TENS 2500 bS 500 ohs 500 PEF 2500 PRES 2500 GR 2500 RENT 2500 TENS 2500 UR 2466 RCMT 1948 TENS 3750 GR. -999,2500 -999 2500 TENS "9.99:2500 .999. 500 LS "999,2500 -999.2500 PEF '999,2500 ~RE'$ '999,2500 GR ' 99,'2500 RCNT -999 2500 QSS -999:25o0 RHOB -q99.2500 HTE~ -999.2500 TNRA -999 2500 REFT -999:2500 HTEN -999.~500 TNRA 1600.0054 REFT 553~,0000 HTEN 56.0938 -999.2500 IbW :999,2500 CABS 999.2500 HTEN -999.2500 CALl -999.2500 LITH '999,2500 '999,2500 RHOB '999,2500 MTEM -999,2500 TNRA -999,2500 REFT -999,2500 HTEN -999,~500 TNRA 1673.7505 REFT 5448,0000 HTEN 56,7188 -999 2500 '999 "999 '999 '999 '999 '999 '999 -999 '999 "999 2500 CAbS 2500 HTEN 2500 CALl 2500 I, ITH 2500 OSS 2500 RHOB 500 PTEM ~500 TNRA 2500 REFT 2500 HTEN -999 2500 T'NRA 5448 0000 HTEN -999.2500 IbM -999,~500 CAbS '999, 500 HT~N -999,2500 CALl -999"2500 LITH -999,~500 OSS 999'2500 RBOB 99,2500 MTEM 99.2500 TNRA -999,~500 REFT -999,:~500 HTEN -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 7200 410 3694 1214 0000 -99q 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 -999 2500 -999 2500 ~ 6767 421 5239 1183 5000 -999 2500 -999 2500 -999 2500 -999 '2500 -999 2500 -999 ~500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 11,44 0000 -999,2500 -999~.2500 -999,2500 -999,2500 -999,2500 -999~2500 -999.2500 -9 ~2500 -999,2500 -999;2500 .,,VP 010,H02 YERIFICATION LISTING PAGE 13 ~RF.S !_TNR )EPT ~p ~E~,S )T 5SHV )RHO ~TNR 7FTC RES FTC 'EPT 'ENS ~T SHV ~ TNR CFTC RTI~IR CFTC ~.EPT ~ ~T c~c DgPT -999 2500 ~TEN 4,3617 SPH1 373,8441 CNTC 1,02~5 MTEM 9500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4 0000 SFLU 250O GR 2500 MRES 2500 GR 2500 bU 2500 SS2 2500 8SHV 2500 DPHI ~500 H'r~N 2500 NPHI 2500 CNTC 2500 ~TEM 0909 NPMI 8600 CNTC 0303 MTEM 9400 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -'999 40~ 0000 SFLU 2500 GR 2500 MRE8 2500 GR 2500 bU 2500 882 2500 SS~'V 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 ~TE'M 71,43 'NPHI 5801 CNTC 0410 9300 -999 -999 -997 ~999 -999 -999 '999 '999 '999 '999 '999 3 5~0 0000 SFL~ 25OO GR 2500 2500 bU ] oo O0 SSHV 2500 DPHi 2500 HTEN 2500 ~PHI ~500 CNTC 2500 3385 NPHI 7924 CNTC 0459 9200,0000 SFbU -999 49, 1556, 177, =999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 46 1465 176 -999 -999 -999 -999 -999 -999 -999 -999 -999 1484 174 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 1695 172 -999. ~500 6682 0833 8750 2500 2500 ~500 2500 2500 2500 2500 500 5OO 2500 2500 25OO 742 ~996 0000 2500 2500 2500 2500 2500 2500 2500 2'500 2500 2500 2500 2500 075 O~ 42 O0 2500 2 oo 2~00 2500 2500 2500 2500 2500 2500 2500 2500 2500 3092 0239 7500 2500 GR RCMT TENS I LD MTEM TENS PEW RCNT TENS GR RCMT TENS TENS MTEM TENS LS PEF GR RCNT TENS GR RCNT T~iNS GR TENS LS UR RCNT TENS RC~T TENS OR -999,2500 1727,0483 5348,0000 58,3438 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999'2500 ;999,2500 .557.1~04 5324.0000 64.6250 -999.2500 -999 ~500 -999:500 -999,2500 -999,2500 -999,2500 -999.2500 -999,2'500 -999,2500 -999,2500 -999.2500 } oo 1630 14 5328 0000 66 8750 TNRA RCFT HTEN IbM CAbS HTEN CALl blTH OSS MTEM TNRA RCFT HTEN TNRA RCFT HTEN CAbS HTEN CALI blTH RHOB MTEM TNRA RCFT HTEN TNRA RCFT HTEN -999, 500 :999, 500 CAbS .999' 500 HTEN .999,2500 CAb{ .999,~500 .999,~500 999,~500 RHOB -999'~500 MTEM -999,2500 TNRA -999'2500 RCFT ,5059 'RCFT 5248,0000 HTE,N 46,0938 -999,2500 4 1272 36~i~469 1186 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 ~410 393 564 1192 0000 =999 2500 999 2500 999 2500 -999 2500 -999 O0 ,.999 25o0 ,999 2500 .-999 25 ~999 2500 3 7289 398 4051 1171 0000 · -999 2500 -9992500 -999 ~500 -999 !500 -999 !500 ~999 1500 -999 ~500 -999 2500 '999 2500 -999~2500 -999,2500 3,)395 486,0952 1168,3750 .999,2500 ~¥P OlO,H02 VERIFICATION L].BTING PAGE 14 ;P CENS -999 -999 ~S1 -999 ',SHV -999 )RHO -999 rENS -999 ~T~R -999 2FTC -999 ~RES -999 .FTC 549 ~RES -999 2500 2500 ~aES 2500 GR 2500 [.,U 2500 SS2 2500 SSHV 2500 DPRI 2500 H~EN 2500 NPHI 2500 CNTC 2500 MTEM 4677 NPMI 2000 CNTC 05]7 MTEM -999 2500 TENS -999 -999 -999 -999 -999 -999 -999 -999 -999 34 1743 17! 2500 ~TE~ 2500 TENS 2500 L$ 2500 OLS 2500 PEF 2500 NRES 2500 GR 2500 ~CNT 2500 TENS 2500 GR 6819 RCNT 2849 TENS 6250 GR bSHV DR I40 ~_TNR CFTC ~T~ CFTC ~RES 9100 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 4 336 1 ]5OO GE 5OO 2500 CR 2500 La ]500 5OO $SHV 0 HTEN 2500 NPHI 2500 CN?C 2500 7568 NPHI 280'1 CNTC 0752 ~TE~ -999 2500 -999 -999 -999 -999 =999 -999 -999 -999 -999 -999 -999 57 1473 !'70 2500 TENS 2500 MTEM 2500 TENS 2500 LS 2500 OhS 2500 PEF 2500 MRES 2500 GR 0 TENS oo G~ SPN. DT TENS M:R~S RTNR CFTC 9000. '999, -999; -999' -g9g -'999. -999 -999 -999 -999 -999 -999 4 ~4~ oo0o SFLU 2500 GR 2500 2500 GR 2500 bU 2500 2500 $$HV 25~0 DPHI 25 0 2500 NPHI 2500 CNTC !500 [359 NPHI L999 CNTC 0850 ~T'EM -999 ~500 I, LD -999 -999 -999 -999 -999 -999 "999 -999 -999 ~9 1,]96 168 2,500 TENS 2500 ~TEM 500 TENS 500 2'500 2500 PEF 250 250§ 500 RCNT 500 2500 2001 RCNT 0349 TE;NS 0000 GR DEPT TE~S SS ~900,0000 SFLU .999.,2500 GR .999~2500 MRES 500 Ga. 999'~1500 LU -999~ '999,2500 SS2 -999,2500 SS~V '999.2500 IbD :999~2500 TENS 999,2500 MTE~ -999,2500 T~NS -999,~500 -999.'~ . PEF '999.2500 CAI, S -q99 2500 HTEN -999i2500 CALl -999 2500 L1TH -999 2500 OSS -999 2500 RHOB -999 2500 MTEM -999 2500 TNRA -999 ~500 RCFT -999 2500 HTEN -999:2500 TNRA 19t6,3682 RCFT 5168,0000 HTEN 43,7813 -999 2500 -999 -999 -999 -999 -999 -999 =999 -999 2500 CAbS 2500 HTEN 2500 CALl 2500 bITH 2500 OSS 2500 RHOB 2500 MTEM 2500 TNRA -999,2500 ECFT -999,2500 HTEN -999,2500 TNRA 1486,9712 RCFT 519'2,0000 HTEN 60'6250 -999 -999 -999 999 999 999 -999,2500 IbM 2500 CAbS 2500 ~TEN 2500 CALl 500 LXTH 0 RHOB 2500 ~TEM 2500 TNRA "999 ~500 R, CFT -999' 500 HTEN "'999,~500 TNRA 1468,3098 RCFT 514.0,0000 HTEN 61.,12:50 -999'i500 IbM 500 CAbS "999, H'T~N '999' 5100 ",999,500 CA£I -999'~500 LXTH -999~2500 QSS -999.2500 RHOB -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 25O0 -999 2500 -999 2500 -999 25OO -999 2500 3 3051 516 1637 1183 1250 -999 2500 -999 2500 -q99 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 -999 2500 -'999 2500 4 5762 301 4964 1212 5000 -999 2500 -999 2500 -99i 2500 '99 2500 -99 2500 -99 "999. 0 -999 '00 4 1015 3 4 7532 1i~5 7500 999,2500 :999,2500 -999;2500 -999,2500 -999,2500 -999,2500 -999,2500 .,VP 010,H02 VEPlFICATION I..,ISTING PAGE 1.5 -999 2500 DPHI -999!2500 WTEN -999 2500 -999 2500 CNTC -099!2500 ~ 81~2 374,0682 CNTC 1,1006 ~TF~ -999,2500 URES -999.2500 GR :999.2500 RCNT 999,2500 TENS -999.2500 GR 4],728! RCN'I' 1443.0320 TENS 166,2500 Gk ~EWS ~T $$1 [,,S~ V DRHO TENS ~RKS 8800 0000 SFLU -999 -999 -999 -999 =999 -999 999 -999 -999 -999 4 2500 ~R 2500 ~RE$ 2500 GR 2500 GU 2500 852 2500 $$HV 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 MTE~ 5946 NP~I 19 CNTC ~I04 MTEM -999 2500 -999 -999 -999 -999 -999 -~99 -999 -999 -999 -999 -999 48 1392 164 -999.2500 ~TEM -999,2500 TNRA ~999 2500 RCFT 999:2500 HTEN -999.2500 TNRA 1581.1707 RCFT 5000,0000 HTEN 49.4375 DEPT SP SS t, l,.,$~V C~Tc CFTC ~S 8700 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 '991 2500 GR 2500 2500 GR 2500 2500 S82 2500 SS~V 2:500 DPMI 2500 MTEN 2500 NPHI 2500 CNTC 500 409 NPHI 4555 CNTC -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 45 149~ ~6 -999,2500 TENS -999.~500 CAL$ 500 [.,5 -999, 500 LITH 2500 QLS -999.2500 2500 PEF -999.~500 RHOB 2500 ~RE$ -999;2500 2500 GE -999.2500 TNRA 5 00 RCNT -999,2500 RCFT 500 TENS -999.2500 HTEN 2500 GR -999.2500 TNRA 5250 RCNT 1428.612] RCFT 0273 TENS 5008,0000 HTEN 5000 GR 59..6250 DEPT DT Lb DRMO CFTC RFS .TNR 8600 0000 SFLU -999 -999 -999 -999 -999 -9'99 -999 -999 -999 -999 -999 4 2500 GR 2500 '~RES 2500 ~R 2500 LU 500 SS2 500 SS~V 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 ~TEM 0426 NP'HI 500 TEN8 2500 ~o0 TENS O0 2500 2500 PEF 2500 MRES 2500 GR ~500 RCNT 2500 TENS 2500 GR 6763 RCNT 95~4 TENS 0000 GR -999 2500 -999 2500 TENS 2500 ~00 TENS O0 ~ ~500 ohs 500 PEF 2500 ~RES 500 GR 500 RCNT 500 TENS ~500 ~R 70!6 RCNT -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 45 -999 O0 CAL$ -999.2500 HTEN -999.~500 CALI -999,~500 LITH -999, 500 088 -999.2500 RHOB -999,,:2500 ~TEM "999'2500 TNRA -999,2500 RCFT -999,2500 HTEN 999.2500 TNRA [~89.,7419 RCFT 68,0000 HTEN 64,0000 -999 '999 -999 "999 -999 -999 '999 "999 '999 "999 "999 '999 1579 .2500 Ib~ ,2500 CAbS ,2500 HTEN ,2.500 CALI ,2500 bITH 0 ,R,HOB 0 TNRA 2500 RCFT 2500 TNRA 50~2 RCFT -999 2500 999' - ,2500 '999.2500 -999,2500 368,3469 1238,0000 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 4 0645 359 9465 1228 0000 -999 2500 -999 20 -999 2~6°0 '999 2500 -999 2500 -999 2500 -999 2500 =999 2500 -999 2500 -999 2500 -999 2500 ~ 9082 ~77 ~434 1200 0000 -999,2500 :999;2500 999.~500 -999 O0 -999 25 -999 2500 -999 2500 .999 2500 -999 2500 ] 9096 342 7910 :V'P 0lC.F!02 VF, PIFICATIO~'q LISTING PAGE 16 :FTC ~RFS .]76.7169 CNTC !. 1279 UTEM 1501.9548 TENS 161 .7500 G~ 8500.0000 SFLU -999.2500 GR -999,~500 ~RFS -999,2500 GR -999"2500 LU -999.2500 $S2 -999 2500 SSHV -999 -999 -999 -999 -999 4 344 1 2500 DPHI 25O0 HTEN 2500 ~PHI 2500 CNTC 2500 ~TEM 3514 NPHI 4 24 CNTC ,367 ~TEM -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 54 2500 TEN6 2500 ~TEN 2500 25OO 250O OhS 2500 PEF 2500 2500 2500 RCNT 2500 TEN6 2500 GR 0563 PCNT 13767788 TENS 160.7500 GR )EPT batty ~RE~ RTNR CFTC 8400 0000 SFLU -999 -9gq -999 -999, -999 -999 -ggg -999 -9gg -9gg -999 4 2500 GR 2500 ~RE$ 2500 GR 2500 [,,U 2500 SS2 2500 SSHV HTEN 2500 NPHI 2500 CNTC ~500 ~TEM 5833 ~PHI 1578 CNTC 1455 ~T~ -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 52 1358 i59 .500 TENS 5OO 2500 TENS 2500 2500 OLS 2500 2500 2500 GR 2500 RC~T 2500 TENS 2500 GR 2497 RCNT 4448 TENS 2500 DEPT SP TE~:S DT DRHo TENS ~TN R CFTC 8300 0000 SFbU -~gg -999 -gg9 -g9g -999 -gg9 -'999 -ggg -999,2500 -~99'2500 -999,2500 4,6667 ~5414 2500 GR 2500 ~RES 2500 GR 2500 l.,U 2500 S52 2500 SSHV 2500 DPHI 2500 HTEN NPHi CNTC C~TC ~TE,M -999 2500 iLD -~gg -999 -999 -gg9 -999 -999 -999 -999 -999 -999 -999 56 1.407 1.57 2500 TENS 2500 ~TE~ ,2500 TENS 2500 LS 2500 ohs 2500 PEF 500 ~RES 500 GR 2500 RCNI 2500 TENS 5oo 538 RC~T 8545 TENS 8750 GR DEPT 200,0000 SFbU 999,2500 GR 999,2500 ~RES -999,2500 Ii,,,[:) -999,2500 TENS -999~2500 ~'TEN' 4888 0000 HTEN 53:1,250 -999.2500 -999.2500 CAbS -9992500 HTEh -999!2500 CALI -999 ~500 LITH -999,2500 OSS -999,2500 RHOB '999.2500 MTEM '999,2500 TNRA -999,2500 ECFT -999,2500 HTEN -999,2500 TNRA 1410,0107 RCFT 4788 0000 HTEN 51:8750 '999,2500 '999 2500 CAbS '999 2500 HTEN '999 2500 CALI '999 2500 bITM -g9g ~500 OSS -999 2500 RHOB -9992500 ~TEM '9992500 TNRA -'999,2500 RCFT '999,2500 HTEN '999,~500 TNRA 1434, 392 RCFT 4748,0000 HTEN 49,6875 -999 2500 Ih~ -99'9 -999 "999 -999 '999 '999 -999 -999 2500 CALS 2500 HTEN. 2500 CALl 2500 LITH 2500 2500 RHOB 2500 2500 TNRA -999,2500 RCFT -999~2500 HTEN -99~'2500 TNRA ISo : .CF 6775 46~4,00009687 HTEN -999.2500 I~ -999'2500 CAbS '999,2'500 HTEN 1180,0000 -egg 2500 - 9i25oo -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 4 3679 326 3582 1209 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 O0 -999 O0 -9992500 -999 2500 42688 318 2974 It7~ 7500 -999 2500 -999 2500 -999 2'500 ,9992500 -99§ 2500 "99~,2500 -99 2500 '-999 2500 -999 2500 -999 ~500 -999500 4 ~049 315 046 1175 0000 -999,2:500 ,-999,2500 ,-999'2500 .~VP 010,H02 VERIFICATION LISTING PAGE 17 ~T ;SI ,SHY )RHO ~RES 2FTC -999.2500 GR -99q,2500 LU -999,2500 SS2 -999,2500 $$NV -999,~500 DPHI -999.~500 HTFN -999 2500 NPHI -999 ~500 CNTC -999 2500 MTE~ 4 2500 NPH! 329 9583 CNTC i 1719 MTEM -999 2500 -999 2500 LS -999 2500 -999 2500 PEF -999 2500 -999 2500 -999 2500 RCNT -999 2500 TENS -999 ~500 GR 51! 389 RCNT 1358 7312 156.2500 GR 8100 0000 SFLU -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 4 ]44 2500 GR 2500 2500 GR 2500 LU 2500 2500 2500 OPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 5641 NPHI 29) CNTC 797 -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 .49 1420 154 2500 TENS 2500 NTEM 2500 TEN~ 2500 LS 2500 OhS 2500 PEF 2500 ~RES 2500 GR 2500 RCNT 2500 TENS 2500 GR 752 ~CNT 3 TENS DEPT LL Ssi LSHV TE~$ CFTC RTNR 8000 0000 SFbU -999 -999 -999 -999 -999 -999 -099 -999 -999 -999 -999 4 2500 GR 2500 ~RES 2500 GE 2500 I.U 2500 $$2 2500 SSHV 2500 DPHI 2500 HTEN 2500 NPHI 2500 CnTC 2500 ~TEM 1463 NPHI .~ 0,4 ~TE~ -999 2500 lbD TENS -999 -999 9gg -999 -999 ~999 -999 -999 -999 -999 45 1428 .153 2500 TEN6 2500 LS 2500 o~s 2500 PEF 2500 ~RES 2500 GR 2500 RCNT 2500 TENS 2500 GR 9325 RCNT GR ~EPT sp TE~S DT DE. HO TENS 7900 0000 -999 ~00 -999 2500 -999 2500 GR '999 2500 "999 2500 S$2 -999 2500 $SHV ~999,2500 DPHI -999,2500 HTEN -999 ~500 ILl) 0 -999 -999 -999 -999 -999 -999 -999 2500 TENS 2500 2500 QL$ ~500 PEF 2500 ~RRS 2500 '999.2500 CALl '999,2500 L, ITH '999,2500 QSS 'q99,2500 RHOB '999,2500 MTEM '999.2500 TNRA '999,2500 RCFT -999.2500 HTEN -999~2500 TNRA 1417,0613 ~CFT 4612,0000 HTEN 60,7188 -999,2500 -999,2500 CAbS -999,2500 HTEN -999.2500 CALl -999,2500 LITH -999 2500 -999:2500 RHOB -999,2500 MTEM -999,~500 TNRA -999.2500 RCFT -999,2500 HTEN -999,2500 TNRA 1493,9507 RCFT 4624,0000 HTEN 56,6563 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 1454 4588 48 -999,2500 I5~ -999..2500 CALS ,2500 HTEN ,2500 CALl ,2500 [;ITH RHOB ,2~00 M?KM 2.500 TNRA .2500 RCFT .2500 HT~N ,:2500 TNRA .5586 RCFT 0000 HTEN 46~8 -999.2500 '999,2500 '999'2500 -999, 0 -999 -999 -999 -999 CALS HTEN CALl i.,ITH 2500 Oss 2500 RHOB 2500 ~TEN ~500 TNRA -999.2500 -999 2500 -999 2500 -999 2500 .999 2500 ,999 2500 -999 2500 -999 2500 4,2243 309,5721 1166,3125 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 1166 351 3494 12t4 0000 '999, oo -999,2500 '999, O0 '999 o -999 00 -999,2500 -999,2500 -999.2.2500 -999 2500 -999 2500 ~99~ ~500 2500 -999 -999 ~DO0 500 LVP 010,H0~ VERIFICATION LTSTiNG PAGE 18 T N R FTC RFS I'I~R CFTC -999 2500 NPH1 -g9g 2500 CNTC -999 2500 MTEM 4 0526 NPHI 332 7906 CNTC ] 2041 MTEM -999 2500 RCNT -99912500 TENS -999,2500 GK 48,9168 RCNT 1332,4700 TENS 151,8750 GR .rJ, EPT Lh DR~O TENS RTNR CFTC RTNR CFTC ~RFS 800,0000 SFLU !999,2500 GR -999 2500 URES -999 -999 -999 -999 -999 -999 -999 -999 -999 4 292 2500 ~R 2500 t.U 2500 SSHV 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 MTEM 8846 CNTC 21,48 mTE~ -999 2500 IbD -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 54 1~69 150 2500 TENS 2500 2500 TENS 2500 2500 OhS 2500 PEF 2500 MRES 2500 2500 RCNT 2500 TENS 2500 GR 3993 RCNT 7874 TENS 5000 GR DEFT TENS CFTC P:TNR CFTC 7700 0000 SFLU -999 -999 -09 -999 -999 -999 -999 -999 -999 -999 4. 2500 GR 2500 MRE$ 2500 gR 2500 bU 2500 582 2500 SSHV 2500 DPHI 2500 ~'fEN 2500 NPHI 2500 CNTC ~00 MTEM 22 NPMI 0408 CNTC ~34 -999 2500 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 5] 1285 149 2500 TENS 2500 MTE~ 2500 TENS 2500 LS 2500 OhS 2500 PEF 2500 ~RES 2500 GR 2500 RCNT 2500 TENS 2500 GR .4~99 RCNT 3516 TENS 3750 GR EPT DR, HO ~TNR CFTC ~R£S RTNR CFTC MRE$ 7694 0000 SFbO -9992500 2500 MRES 2500 2500 bU 2500 882 2500 SS~V 2500 DPHI 2500 HTEN 2500 NPHI 2500 CNTC 2500 6061 NP~,I 090,6 CNTC 2344 -Egg -999 -999 -Egg -999 -999 -999 -999 -999 -999 4 285 '999 ~,500 ILl) -999 -999 -9 -999 -999 -999 -999 -999 -999 -999 54 1261 500 TENS 500 ~TEM 2500 TENS 2500 bS 2500 OhS 2500 PEF 2500 M~ES 2500 G~ 2500 RCNT 2500 TENS 500 GR ~510 RCNT 0339 TENS 8750 UR -999,2500 RCFT -999,2500 HTEN -999,2500 TNRA 1399,3562 RCFT 4544,0000 HTEN 56,0313 -999,2500 -999,2500 CAbS -999,2500 HTEN -999.2500 CALf -999,~500 LITH -999,2500 QSS '999,~500 R~OB '999,2500 M EM '999,~500 TNRA '999,2500 RCFT '999,2500 MTEN '999,2500 TNRA 1296,8145 RCFT 4520,0000 HTEN 92,4375 -999 2500 IbM -999 -Egg -999 -999 -ggg -Egg 99 -099 -999 -999 1344 4488 130 2500 CAbS 2500 HTEN 2500 CALX 2500 LITH 2500 eSS 2500 RHOB 2500 ~TEM, 2500 TNRA 2500 PCFT 2500 HTEN 500 TNRA 056 RCFT .0000 ~TEN 5O0O -999 2500 -Egg -999 -Egg -999 -999 -Egg ~999 -Egg -999 -999 -999 1399 4464 84 2500 CAbS 2500 HTEN 2500 CAb! 2.500 blTH 2500 ess 2500 RHOB 500 MTEM 500 TNRA 2500 RCFT 2500 HTEN 2500 TN~A 3562 RCFT 0000 MTEN 1.875 -999 2500 -g99 2500 4 0859 301 4964 1195 0000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 25O0 4 3867 ~76 -999 2500 -999 2500 -999 250O :,g g soo 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~,500 -999 2500 ~92 48 ''9992500 '99g ~500 -999 500 -999 m999 ~500 500 -999 2500 '"999~500 '999 500 -999 O0 -999 2500 '9992500 4 4115 292 1804 -999 2500 VERIFICATION LISTING PAGE 19 ~* F~LE ?RAIbERT** ~ILE ~AME :EDT ,001 ;EPVTCE NA~E :FLIC ~ATE :88/08t15 ~A~I~U~ LE~GTH :1024 ~ILE TYPE ~* FILE ME~DER ~ILE NAME :EDIT 002 ~E~V]CE NA~E :FLOC /ERS~ON # :O01A02 )ATE :88/08/15 ~AXI~IJ~ DE~GTH :1.024 ~ILE TYPE :bO ~R~VTOUS FILE INFORMATION RECORDS ** ~ABLE TYPE :CONS M~EM TUNi VRLU DEFI · CN N~T! 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