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193-075
• • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg �.. 1 `LO Alaska Oil and Gas Conservation Commission y !) AUG 2 333 West 7 Avenue Anchorage, Alaska 99501 3 - 0 7c Subject: Corrosion Inhibitor Treatments of GPB M -Pad jf4 °.1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, \_p(firi----f Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M-07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -198 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 \ - o 75 25-JAN -2012 Bm I r A, ' T -,-, 5873 Alaska Data & Consulting Services Company: State of Alaska l 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Ail 4 : `' _ Me Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 400 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD G -11B BINC -00051 RESERVOIR SATURATION TOOL LOG 7- Jul -11 1 1 K-05D BUTT -00010 MEMORY COMPENSATED NEUTRON LOG 26 -Au • -11 1 1 04 -22AL1 BAUJ-00054 MEMORY COMPENSATED NEUTRON LOG 19- Nov -10 1 1 J -22A BJGT -00049 RESERVOIR SATURATION TOOL LOG 6-Jul-11 1 1 F -01A BINC -00049 RESERVOIR SATURATION TOOL LOG 5-Jul-11 1 1 III 11 -28A BRRJ -00017 RESERVOIR SATURATION TOOL LOG 27- Oct -11 1 1 H -26 BJGT-00062 RESERVOIR SATURATION TOOL LOG 22- Aug -11 1 1 07 -13C BD88 -00148 MEMORY COMPENSATED NEUTRON LOG 7- Aug -11 1 1 F -30 BINC -00048 RESERVOIR SATURATION TOOL LOG 4-Jul-11 1 1 H-04B BUTT -00033 MEMORY COMPENSATED NEUTRON LOG 6- Oct -11 1 1 J -19 BINC-00057 RESERVOIR SATURATION TOOL LOG 13 -Aug -11 1 1 , 15 -17 BVYC -00006 RESERVOIR SATURATION TOOL LOG 29- Sep -11 1 1 M -24A BBSK -00074 RESERVOIR SATURATION TOOL LOG 6-Jun-11 1 1 E -19C BD88 -00132 MEMORY COMPENSATED NEUTRON LOG 6-Jul-11 1 1 1 2- 04/M -19 AV1P -00100 RESERVOIR SATURATION TOOL LOG — 9 -Au �. -11 1 1 G -21 BG4H -00070 RESERVOIR SATURATION TOOL LOG 6- Aug -11 1 1 1 04 -23A BBSK -00091 RST SIGMA WI BORAX 26- Aug -11 1 1 Z-87 U$I 19416. 1 OWDW -SW E1.. AVIP- 091 RESERVOIR SATURATION TOOL LOG 16- J 1 !� 1 !� 1 1 ' *ik :.,.-..a..'vw 77 .. r ��.S " +2 4 . .'.- 1�. .J.S,.. r..3XA.a,5i�..:.!-7i # 1.. ! c i::!`.uiill 1 3 Ili MU _ 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.d Anchorage, AK 99503 -2838 Vii, , 5 1 4 .._ STATE OF ALASKA ., ALASKA 1PAND GAS CONSERVATION COMMISSIO10 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate 0 5 Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Ti e ' i:� in ' VE Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspeeir le117 n 9 N, 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development gg Explorato r 193 -0750 . 1. T : alil� y Pains �I 3. Address: P.O. Box 196612 Stratigraphic Service w 6. AP u e . $Sj Anchorage, AK 99519 -6612 ' AnC 0923 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028282 o , PBU M -21A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9550 feet Plugs (measured) 8955 (TOC) feet true vertical 9223.75 feet Junk (measured) None feet Effective Depth measured 9493 feet Packer (measured) 2580 7493 feet true vertical 9172.75 feet (true vertical) 2580 7355 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 35 - 145 35 - 145 Surface 2660' 13- 3/8 "72# L -80 34 - 2694 34 - 2694 4930 2670 Production 7512' 9 -5/8" 47# L -80 33 - 7545 33 - 7404 6870 4760 Liner 2161' 7" 29# 13CR80 7389 - 9550 7256 - 9224 8160 7020 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 32 - 7589 32 - 7446 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV Packer 2580 2580 4 -1/2" Baker SAB Hvdro -set Packer 7493 7355 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: i ?3 €*i ? F ?� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 268 320 1413 195 Subsequent to operation: 234 277 1137 199 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development. 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: - Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam- oe Lastufk.a Title Petrotechnical Data Technologist Signat tinai Phone 564 -4091 Date 10/14/2011 pp OCT q e V RB Form 10-404 Revised 10/2010 DAAS O 1 &► ! ded • /T. LI Sub riginal O ly /'7'9(,/ M -21A 193 -075 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base M -21A 6/14/93 PER 8,997. 9,056. 8,735.22 8,786.76 M -21A 7/31/93 APF 9,066. 9,144. 8,795.51 8,863.91 M -21A 6/21/11 SPS 8,967. 8,989. 8,709.09 8,728.25 M -21A 6/21/11 SPS 8,989. 9,493. 8,728.25 9,172.75 M -21A 8/10/11 APF 8,962. 8,963. 8,704.75 8,705.61 M -21A 8/18/11 APF 8,930. 8,931. 8,676.98 8,677.84 M -21A 8/31/11 APF 8,870. 8,890. 8,625.19 8,642.42 M -21A 9/16/11 SPS 8,955. 8,997. 8,698.66 8,735.22 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 • • M -21A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY . l ... .5 „ fix -$ 6/20/2011':. Continued from WSR of 06/19/11. CT -8 1 3/4" SCOPE OF WORK: Depth control I ; log, Sand plug w /Cmt Cap. f Cont RU, shoot fluid level in IA, 7339'. Load IA with 423 bbl diesel. Kill well with 180 bbl KCL. RIH with Pig cementing nozzle BHA. Displace tubing with 150 bbl diesel. ;Tag bottom at 9168'. 61' deeper than slickline. Scale in 7" liner. Bullhead slick KCL. POH. Cut 50' coil. M/U CTC, DBPV and Disco. Pull and press test. M/U PDS =memory GR/CCL. RIH and tag bottom at 9065' up depth. Flag coil at 9040'. Log up at 40 fpm to 7400'. POH while pump slick KCL at min rate. Download data. -8.5' correction. MU Pig shear noz, RIH, 9032.5' corrected @ flag. a « «JOB IN PROGRESS » »> 's 6/21/2011 ** **Continued from WSR 6-20-11**** 1CT -8 1 3/4" SCOPE OF WORK: Set sand plug w /cmt cap. Set first sand plug, tagged at 9060'ELMD set 1400# 20/40 sand plug Tagged sand plug after 1 hr @ 9000' ELMD. Set second sand plug, 500# 20/40. Tag twice at 8989'. PJSM. Pump 1.1 bbl cement. Displace cement with nozzle at 8979'. Shear pig nozzle at 800 psi.. Pull to 8941'. Let cement settle. Squeeze cement to 2200 '; psi, good squeeze. Reverse circ at 8941', 70 bbl. No cement seen at surface. Top of Cement cap calculated at 8951'. Hold 2270 psi WHP squeeze pressure, good ;squeeze. POH while holding 1000 psi WHP. Freeze protect tubing at 2500'. POH. `Lay out BHA. ;Perform Weekly BOPE Pressure / Function testing. « «<JOB COMPLETE »» 6/23/2011 ` ** *WELL S/I ON ARRIVAL * ** RAN 2.25" DRIFT, LOCATED TT @ 7574' SLM/7577' ELM ;TAGGED TOC @ 8964' SLM/8967' ELM, RECOVERED —1 /2cup OF CEMENT :RAN 3 -3/8" x 10' DUMMY GUN, LOCATED TT @ 7570' SLM/7577' ELM ;TAGGED TOC @ 8963' SLM /8970' ELM, RECOVERED —1 /2cup OF CEMENT ** *WELL LEFT S /I, PAD OP NOTIFIED * ** 6/26/2011 `T /I /0= 1050/1300/0 Temp =S /I, MIT -T PASSED to 3500 psi; pMIT -TxIA PASSED to ;3500 psi (Pre Frac) Bled gas off Tbg and IA. Pressured up tubing with 2.4 bbls crude to reach 3500 psi. MIT -T lost 96 psi in 1st 15 minutes and 33 psi in 2nd 15 minutes for a total of 129 psi in a 30 minute test. Bled tubing to 2500 psi. Pressured up IA and 'tubing with 45 bbls of crude to reach 4000/3970 psi. CMIT -TxIA lost 50/50 psi in 1st 15 minutes and 20/20 psi in 2nd 15 minutes for a total of 70/70 psi in a 30 minute ?test. Bled Tbg and IAP. SVWV,AL,Pitt= Closed/ SSV /MV,IA,OA =Open. i FW HP's= 450/450/0. 8/10/20111T/1/0= 760/460/0 High Pressure Breakdown /Inj. Test (Pre Frac) Rig to E -Line ;lubricator. PT Lubricator to 500 psi. Standby for E -Line to RIH. Pressure up Tbg to 14500 psi pumping diesel @ 0.4 bpm. Bleed Tbg to 700 psi. RDMO. FWHP= 1700/460/0 E -Line on well @ departure. IA and OA open to gauges. Operator notified. • • 8/10/2011 ***WELL SHUT IN ON ARRIVAL * * *(ELINE PERF, INJECTIVITY TEST, DUMP I BAILER) INITIAL T /1 /0= 350/450/0 PSI :INITIAL VALVE POSITIONS: MASTER/VALVES TO CASING= OPEN, ;SWAB /SSV/WING= CLOSED RUN 1: SHOT INTERVAL= 8962'- 8963', CCL TO TOP SHOT= 8.0', CCL STOP 'DEPTH= 8954', 1' BOTTOM LOADED 5' X 3 -3/8" PJ 3406 HMX HSD (4 SPF, 60 ',DEG PHASE)(4 SHOTS LOADED) :RUN 2: BOTTOM HOLE PRESSURE SURVEY FOR INJECTION BREAKDOWN ;TEST. PRESSURE SENSOR DEPTH = 8952'. PUMPED DIESEL AT A STEADY :RATE OF 0.42 BBLS /MIN UP TO 4500 PSI SURFACE PRESSURE AND 7800 PSI DOWNHOLE. PRESSURE HELD SOLID DOWN HOLE. NO INDICATION OF INITIAL BREAKDOWN. HOLD PRESSURE FOR 15 MINUTES. STILL NO '.INDICATION OF INITIAL BREAKDOWN. BLEED OFF PRESSURE AND LRS RIG DOWN. SLB POOH AND RIG DOWN. ;LAY DOWN LUBE AND LEAVE EQUIPMENT OVERNIGHT. SWAB = C, SSV = C, MASTER = 0, WING = C FINAL TWO = 700/450/0 PSI ** *JOB IN PROGRESS AND CONTINUED ON 11 -AUG- 2011 * ** 8/18/2011 1 ** *WELL SHUT -IN ON ARRIVAL * ** ! INITAL T /I /O 400/450/0 PERFORATED 8930' -8931' WITH 3.38" PJ3406 HMX, 4SPF. DEPTH CORRECTED TO SLB JEWELRY LOG DATED 6- JUNE -11. RAN INJECTIVITY TEST TO 4500 PSI SURFACE PRESSURE. WELL WOULD NOT: TAKE FLUID. HELD PRESSURE FOR 5 MINUTES. CONFERED WITH TOWN PE BEFORE BLEEDING PRESSURE. BLEED WELL BACK TO 500 PSI. ;LAY UNIT DOWN FOR NIGHT &, RETURN IN MORNING TO RUN 20' OF 3.38" GUN. HAND OVER WITH DSO PRIOR TO DEPARTURE, WELL SECURE FOR NIGHT. ** *JOB CONTINUED NEXT DAY * ** 8/18/20117/I/O= 500 /440Nac, Temp =S /I, Assist E -line Post Perf (Pre Frac) Pumped 3 bbls of diesel to reach 4500 psi monitor psi for 2 min tbg lost 30 psi. Final WHP's 500/440/0 E -line on well at departure 8/26/2011: T/I/O= ?/370/0 +. Temp =S1. Assist PT tree saver (Micro - frac). ALP =1990 psi, SI @ 'casing valve. Assisted SLB PT tree saver to 4000 psi. Final T/I/O= ?/370/0 +. ** Job is Complete ** } ** SLB in control of well upon departure ** 8/28/2011 IT /1 /0= 450/440/0 Assist SLB w/ a HPBD (pre - frac). Pumped 18.1 bbls crude down the IA to pressure up to and maintain 3000 psi while SLB performed the high I pressure break down on the TBG. * *Tag hung, IA & OA valves left open to the gauges. ** FWP's= 1200/530/0 8/28/2011 Micro Frac Stress Test RU/ Set treesaver Pump at min. rate to breakdown perfs. 1st ;breakdown pressure 4350 psi ISIP 3950 psi. 2nd test 4165 psi ISIP 3900 psi. 3rd test 4070 psi ISIP 3860 psi. R/D Contact DSO close permit. Job Complete • • 8/31/2011;* **WELL SHUT -IN ON ARRIVAL * ** (E -LINE ADD PERF, SBHPS) INITIAL T /I /O 700/620/0 ;PERFORATED 8870' -8890' WITH 3.38" HSD 6SPF 60 DEGREE PHASED PJ3406 :GUN. DEPTH CORRECTED TO SLB JEWELRY LOG DATED 6- JUNE -11. ;RAN STATIC BHPS AFTER PERFORATING. PERFORMED STOPS AT 8900, 8785,; ;8668. MASTER =O, SSV =C, WING =C, GLT =C, SWAB =C TREE CAP ON AND TESTED FINAL TWO 350/420/0 !***JOB COMPLETE WELL LEFT SI UPON DEPARTURE * ** 9/3/2011 ;ASRC Test Unit #4 Cont flowing well, S/I to stack out and try get liquid to surface. RDMO. ** *Job Complete * ** Outlet well M -23 9/14/2011: ** *WELL S/I ON ARRIVAL * ** (frac) :TAGGED TOP OF CEMENT AT 8965' ELM W/ 2.55" CENT, TEL, S.BAILER. SAMPLE OF WHAT APPEARS TO BE ASPHALTINES MIXED W/ REMANTS OF 'CTU FOAM PIG. RAN SLB SBHPS GAUGES (SAG FORMATION), OBTAIN GOOD DATA * * *CONT ON 09/15/11 WSR * ** 9/15/2011; * * *CONT FROM 09/14/11 WSR * * *(frac) ,SET 4 -1/2" WHIDDON C -SUB IN SWN NIP @ 7652' SLM/7577' MD PULL ST #1 RK -OGLV @ 7333' SLM/7339' MD, PULL ST #3 RK -LGLV @ 5189' `SLM/5196' MD, PULL ST# 4 RK -LGLV @ 3072' SLM /3081' MD SET ST# 4 RK -DGLV @ 3081' MD, 'ST# 3 RK- DGLV @ 5196' MD LRS LOADS IA W/ 475 bbls CRUDE, SET RK -DGLV IN ST# 1 @ 7333' SLM/7339' ;MD LRS CONDUCTS PASSING MIT -IA TO 4000 psi, LRS FREEZE PROTECTS 1 FLOWLINE * * *CONT ON 09/16/11 WSR * ** 9/16/2011: * * *CONT FROM 9/15/11 WSR * * *(frac) PULL EMPTY 4 -1/2" WHIDDON C -SUB FROM SWN NIP © 7652' SLM / 7577' MD RAN 3.5" x 10' D.BAILER, DUMP BAILED 15 GAL CEMENT ( -10' IN 7" LNR), TOC @ 8950' SLM/ 8955' ELM (CORRECTED) . ** *WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED * ** 9/17/2011;T/I/0=1600/40/0 Temp =Sl Step rate Injectivity test ( Pre Frac) Pumeped 5 bbls `meth, 20 bbls crude, 17 bbls 1% KCL tbg locked up, pumped 5 bbls meth, 3.5 crude for freeze protect * ** CONTINUED TO 09 -18 -11 WSR * ** ( 9/18 /2011; ** *CONTINUED FROM 09 -17 -11 WSR * ** Continued to squeeze crude down tbg for `Freeze protect. pumped a total of 5 bbls meth, 39 bbls crude. bled back — 4 bbls Final WHP's 2000/0/0 SV,WV,SSV,AL= shut MV,IA,OA =open Pit valve = closed Pad op notified on departure 9/22/2011' T/I/O= 1350/0/0. (High pressure breakdown/ Pre- Frac). Pressure up on IA to 1500 . psi. Pump 35 bbls diesel down tbg to establish injectivity. Pump 188 bbls 2% KCI ;down tbg @ 5 bpm to establish pump rate & pressure. Pressure @ 5 bpm started at ;3030 psi and dropped to 2290 psi at end of pumping. Freeze protect tbg w/ 36 bbls ;diesel. Bleed IA pressure down to 500 psi. FWHP= 1600/500/0. Swab, SSV, & wing valve shut. Master, IA, & OA open. • 9/27/20111** *SLB Frac Crew * ** Job Scope: Fracture Targeting Sag « <InterAct Publishing »> Rig up frac equipment, LRS and Stinger tree saver. Pump break down /step down ;test, Scour Stage, Data Frac twice. Datafrac analysis showed FG = 0.51, leak -off 'coef = 0.001, Pc 680 and final estimated net pressure build of — 1500 psi. Pump 'Frac at 20 bpm using 40# x -link gel. Pad stage of 75 bbls. 1 PPA Flat stage 20/40 ceramic proppant in 50 bbls, Ramp 1 PPA - 4 PPA in 75bbls. Ramp 4 PPA - 8 PPA in 100 bbls. 8 PPA Flat in 293 bbls. Flush vols of 51 bbls 40# XL Gel, 51 bbls of non -XL Gel 46 bbls LVT -200 (Mineral Oil) placing freeze protect at —2566' 97,628 ,Ibs of 20/40 C -Lite proppant behind pipe and 7,135 lbs in Liner. Est top of sand; ;once gel breaks out, —8867' = 3' above top perf. ** *Job Complete * ** 9/27/2011 T/l/O= 72/600/20 ( Assist Frac Crew / Heat Frac tanks / Hold backside Pressure ) WSR continued from 09- 26 -11. Continue heating Frac Tanks to 100 *. Pumped a ;total of 9.8 bbls DSL down the IA to maintain 3500 psi on the IA while SLB performed a frac. Bled IAP (6.4 bbls fluid). * *Tags hung, IA & OA valves left open to gauges .upon departure ** FWP's= 1670/500/20 FLUIDS PUMPED BBLS 636 1% XS KCL W/ SAFELUBE 395 DIESEL 21 FRESH WATER 81 50/50 METH 25 NEAT METH 638 CRUDE 17 1 %KCL 188 2% KCL 1128 YF14OLG X -LINK GEL 611 20# LINEAR GEL 46 LVT -200 (MINERAL OIL) 1.1 CEMENT 3787.1 TOTAL FLUIDS PUMPED GALS 58 L65 SCALE INHIBITOR 73 F103 SURFACTANT 138 L64 CLAY STABILIZER 445 J877 GUAR POLYMER 32078 J922 WIDEFRAC 100 ST 15 CEMENT 32807 TOTAL • FLUIDS PUMPED LBS 15 ENZYME BREAKER 24 MICROBIOCIDE 55 J475 BREAKER 104763 20/40 C -LITE PROPANT 1900 20/40 SAND 106757 TOTAL TREE = 4" CW • . " WBLLHE:`AD = McEVOY SAFETY NO•HROME TBG & LNR ACTUATOR = BAKER M -21 A KB. ELEV = 62.55' - BF. ELEV = 27.25' KOP = 4900' ( 2090' 1 - 4 OTIS HXO SSSV NIP, ID = 3.813" I Max Angle = 32 @ 8598' Datum MD = 9130' Datum 'ND = 8800' SS 2580' H 9 -5/8" DV PKR I i r ^T- 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I—I 2694' I ' MERLA GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3081 3081 0 TGPD DOME RK 16 10/05/11 �� 3 5196 5186 17 TGPD SO RK 20 10/05/11 Minimum ID = 3.725 @ 7577 2 7191 7068 18 TGPD DMY RK 0 06/12/93 4 -1/2" XN NIPPLE 1 7339 7209 18 TGPD DMY RK 0 09/15/11 TOP OF 7" LNR H 7389' I I 7437' H4 -1/2" PARKER SWS NIP, ID = 3.813" I E ►,< 7493' I — 7" X 4 -1/2" HYDRO SET, LATCHED PERM PKR, ID = 3.950" I I 7523' H4 -1/2" PARKER SWS NIP, ID = 3.813" I 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 7545' I I 7577' I — I4 - 1/2" PARKER SWN NIP, ID = 3.725" I TOP OF CEMENT I 7550' + 7589' — 14 - 1/2" WLEG, ID = 3.958" I v I 7577' I--I ELMD TT LOGGER 06/14/93 I Nip 8908' —14-1/2" MARKER JOINT I 7 1 1 PERFORATION SUMMARY 1 — 8955' ELM I — 15 GAL CEMENT 111111 (09/16/11) REF LOG: BRCS ON 06/04/93 1 ♦111111111111.1. ANGLE AT TOP PERF: 31° @ 8870' 11'1Y'1'1"111'1'1 , 11111111111 — 8951' CTM — CMT PLUG Note: Refer to Production DB for historical erf data 1111111111 P 11111111111 ± : o (06/21/11 SIZE SPF INTERVAL OPNISQZ DATE 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1+ ...vow. ) 3-3/8" 6 8870 - 8890 0 08/31/11 1 +�► 7.14. 111 3 -3/8" 4 8930 - 8931 5 06/21/11 1 4 1 A 1 A1A1A 1 A1A 1 �1�11 •�� �wwwww��% .�i i�ww 3 -3/8" 4 8962 - 8963 S 06/21111 ` 3 -3/8" 6 8997 - 9056 C 06/14/93 3 -3/8" 6 9066 - 9144 C 07/31/93 • ..............******4 vve*v•V�•t '' `,AM. 1 11 1 1 1 1 1 11 4 1 _ �w www .,......... 11111 11 11 1 1 1 1 1 1 �• `I ww. 14 -1/2" TBG, 12.6 #, NT13CR -80 NSCT, .0152 bpf, ID = 3.958" H 7589' I Awmviivr AIMIIIMY ■ww• 120/40 SAND PLUG (06/20/11) r 8989' - 9060' CTM \ ," 1 PBTD H 9493' 1 7" LNR, 29 #, 13CR -80, .0371 bpf, ID = 6.184'1 —I 9550' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/14/93 SIDETRACK COMPLETION 09/21/11 SRD/ PJC PERF (08/31/11) WELL: M -21A 02/27/01 SIS -Isl CONVERTED TO CANVAS 09/21/11 CJN/ PJC GLV C/O (09/15/11) PERMIT No: 1930750 03/14/01 SIS -MD FINAL 09/22/11 RRW/ PJC DRAWING CORRECTIONS API No: 50- 029 - 20923 -01 07/19/01 RN/TP CORRECTIONS 10/22/11 CJN/ PJC GLV C/O (10/5/11) SEC 6, T11 N, R13E, 1939' FNL & 195' FWL 06/25/11 RRW/ PJC CMT CAP/ SAND PLUG (06/21/1 )11/11/11 CJN/ PJC GLV /O (10/05/11) 08/15/11 SRD/ PJC PERF - PRE FRAC (8/10 & 8/19/11) BP Exploration (Alaska) 1 15 -SEP -2011 1)3 .0 �5 hberger 2104'7 No. 5791 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I Well Job # Log Description Date BL Color CD F-45B BUTT -00013 PPROF W/ GHOST 29- Aug -11 1 1 M -21A BBSK -00093 SBHPS 31- Aug -11 1 1 MPC -19 BD88 -00155 IPROF 27- Aug -11 1 1 MPC -39 BUTT -00011 IPROF 26- Aug -11 1 1 MPC -36 BD88 -00154 IPROF 26- Aug -11 1 1 • V -216 BD88 -00153 (PROF 25- Aug -11 1 1 S -125 BD88 -00156 PPROF W /DEFT & GHOST 29- Aug -11 1 1 04 -08 BD88 -00159 (PROF 1- Sep -11 1 1 04 -23A BBSK -00091 PPROF W/ DEFT 25- Aug -11 1 1 A-43 BG4H -00086 PPROF W /DEFT & GHOST 9- Sep -11 1 1 12 -04A BINC -00064 PPROF W/ DEFT 31- Aug -11 1 1 MPS -04 BCRC -00121 IPROF 8- Sep -11 1 1 P2 -10 AV1P -00105 PPROF W /DEFT & GHOST 10- Sep -11 1 1 a 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 e� 4- I *1-1 .1, ,t. L) ': � e OPERABLE: Producer M -21A (PTD 30750) OA pressure manageable by beds Page 1 oj2' Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com]ef, Z (7I )( Sent: Monday, February 07, 2011 4:40 AM To: Regg, James B (DOA); AK, RES GPB West Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; Cismoski, Doug A; Engel, Harry R; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Sayed, Mohamed; AK, D &C Well Integrity Coordinator; King, Whitney Subject: OPERABLE: Producer M -21A (PTD #1930750) OA pressure manageable by bleeds All, An OA repressurization test was conducted on Producer M -21A (PTD #1930750) between 2/1 -2/5. The OA pressure increased —20 psi /day making it manageable by bleeds. Therefore, the well has been reclassified as Operable and may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 ' N FEB 2 8 ZUV Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, January 31, 2011 8:52 PM To: 'Regg, James B (DOA)'; AK, RES GPB West Wells Opt Engr; AK, D &C Wireline Operations T-am Lead; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, OPS P •d Controllers; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; Cisroski, Doug A; Engel, Harry R; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)! Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Sayed, Mohamed Subject: UNDER EVALUATION: Producer M -21A (PTD #1930750) Sustained C- ing Pressure on the OA - POP to eval IAxOA comm All, Producer M -21A (PTD # 1930750) was classified as Not Oper. • e during the shut down due to sustained casing pressure on the OA. The wellhead pressures were , •ing /IA/OA equal to SSV/1960/1440 psi on 01/14/2011. The well has been reclassified as Under Ev uation so that it may be placed on production to perform diagnostics. Please notify Well Integrity after e well has thermally stabilized so DHD can begin monitoring for OA repressurization. The plan forward is as follows: 1. W: PPPOT -IC 2. DHD: OART A TIO plot and wellbore schematic have been included for reference. 2/7/2011 UNDER EVALUATION: Producer MIA (PTD #1930750) Sustained Casingessure on the 0... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Monday, January 31, 2011 8:52 PM G t To: Regg, James B (DOA); AK, RES GPB West Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; Cismoski, Doug A; Engel, Harry R; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Sayed, Mohamed Subject: UNDER EVALUATION: Producer M -21A (PTD #1930750) Sustained Casing Pressure on the OA - POP to eval IAxOA comm Attachments: M -21A TIO Plot 01- 31- 11.doc; M- 21A.pdf All, Producer M -21A (PTD # 1930750) was classified as Not Operable during the shut down due to sustained casing pressure on the OA. The wellhead pressures were tubing /IA/OA equal to SSV/1960/1440 psi on 01/14/2011. The well has been reclassified as Under Evaluation so that it may be placed on production to perform diagnostics. Please notify Well Integrity after the well has thermally stabilized so DHD can begin monitoring for OA repressurization. The plan forward is as follows: MIMED FEB k) 7 2O1 1. W: PPPOT -IC r 2. DHD: OART A TIO plot and wellbore schematic have been included for reference. «M -21A TIO Plot 01- 31- 11.doc» «M- 21A.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 2/1/2011 PBU M-21A PTD 1930750 1/31/2011 TIO Pressures Plot Well: M-21 4,000 • 3,000 - -0— Tbg - -II— IA 2,000 --A— OA 00A 000A • • I 1.000 ,„.• • • el •■•• On • • • 11 • • • • • 12/04/10 12/11/10 12118110 12/25/10 01 /di /11 01 /08/11 01/15/11 01122/11 01/29/11 • 1 • • TREE= 4" CIW WELLHEAD = McEVOY M -21 A RK LATCHET : MERLA GAS LIFT MANDRELS WITH ACTUATOR = BAKER KB. ELEV = 62.55' BF. ELEV = 27.25' KOP= 4900' I 2090' H 4 -1/2" SSSV OTIS LAND. NIP, ID= 3.813" I Max An • le = 32 • 8598' Datum MD= 9130' Datum TVD = 8800' SS 2580' H 9 -5/8" DV PKR I I 13 -3/8" CSG, 72#, L -80, ID= 12.347" H 2694' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3325" @ 7577 4 3081 3000 0 TGPT RK 3 5196 5100 7 TGPT RK 4 -1/2" XN NIPPLE 2 7191 7000 10 TGPT RK 1 7339 7120 11 TGPT RK I TOPOF7 "LNR H 7389' I I I 7437' H 4-1/2" X NIP, ID= 3.813" I S E I 7493' 7" X 4-1/2" HYDRO SET, LATCHED PERM FKR, ID= 3.950" I I I 7523' H 4 -1/2" X NIP, ID= 3.813" I I 9 -5/8" CSG, 47 #, L -80, ID= 8.681" H 7545' I I TOP OF CEMENT H 7550' • r: PERFORATION SUMMARY REF LOG: BHCS ON 06/04/93 7589' H 4 -1/2" TTL WLEG I ANGLEAT TOP PERF: 30 @ 8997' ftf ♦ ����1� , . , I 7577' H ELM) TT LOGGED 06/14/93 I � Note: Refer to Production DB for historical perf data At VA SIZE SPF INTERVAL OPWSQZ DATE . .V. 1V11'� ♦ 3 -3/8' 6 8997 - 9056 0 06/14/93 • ••• •• *1 � W. 3 -3/8" 6 9066- 9144 0 07/31/93 �� W. • 4 9-5/8" BRIDGE PLUG 7900' ... .ice a. TOP OF CEMENT 8742' .b.. ...■■■•■■ 1 � 1 iv � 1 � 1 • I 4 -1/2" TBG, 12.6 #, 13 -CR .0152 bpf, ID= 3.958" H 7589' I PBTD H 9493' I 7" LNR 26#, L -80, .0383 bpf, ID= 6.276" H 9550' I DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 06/14/93 SIDETRACKCOMFLETION WELL: M-21A 02/27/01 SIS - IsI CONVERTED TO CANVAS PERMIT No: 1930750 03/14/01 SIS-MD FINAL AR No: 50 -029- 20923 -01 07/19/01 RNITP CORRECTIONS SEC 1, T11 N, R12 E, 1939' FNL & 195' FWL BP Exploration (Alaska) • • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, January 14, 2011 10:34 PM r.qq �f 2 Ili To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570) C -15A (PTD #2090520) E -17A (PTD #2042040) E -27A (PTD #1990590) F -04B (PTD #2100870) ,, , f FFB 7 201' W -01A (PTD #2031760) W -16A (PTD #2031000) W -21A (PTD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. (PTD #1932010) M -21A (PTD #193075Q1'� N -22B (PT #D 2061610) All the wells listed above will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start-up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 PL M ATE THIS IA L U M A R W N D K E R E R !3, 93 .... 0 7 $ B H C 93--075 PERF' c/--L. 7300-"9200 q3-075 PER~ L~L ~.~ 850 .... 9200 .. .........q3 .... 075 pRp, n ~Ri ~8800 .... 9300 93,,,075 SE, T ~ 7700'--96Sa. g3---075 ':3ST'VD ~/L 7538 .... 94.76 Ai-'"e (.clr'y d'~t(3h sansp'J e:3 r"eqLJ~ r"sd a:s 't:he wel J cor'ec!? yes ~ Aha Ar'e wel'l tests r'equ'ifed? yes We'l'l '~s -in comp'i'iance C C, iq l'-'i E N 'T S I ys'¥s & descr"¥pJ:'¥on Rece'i STATE OF ALASKA ALAS-'--'~OIL AND GAS CONSERVATION COMMISSIC'-' REPORT SUNDRY WELL OPERATIONS _ ..,perations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1939'SNL, 195' EWL, SEC. 06, T11N, R13E, UPM At top of productive interval 1629' SNL, 659' EWL, SEC. 06, T11N, R13E, UPM At effective depth 1853' SNL, 4298' EWL, SEC. 06, T11N, R13E, UPM At total depth 1877' SNL, 586'EWL, SEC. 06, T11N, R13E, UPM Repair well Other 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 51.75' AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-21A (12-06-11-13) PBU 9. Permit number/approval number 10. APl number 50- 029-20923-01 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 9550 feet BKB 9224 feet Effective depth: measured 9493 feet true vertical BKB 9173 feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 x 30 8 c.y. concrete 135 Surface 2659 13 3/8 3720 c.f. Permafrost II 2694 Intermediate 8796 9 5/8 1925 c.f. "G'Y130 c.f. PF 8821 Production -- Liner 947 7 800 c.f. Class "G" 7389 - 9550 Perforation depth: measured 8997'- 9056' true vertical subsea 8736'- 8787' Tubing (size, grade, and measured depth) 4 1/2" 13 CR @ 7589' Packers and SSSV (type and measured depth) 9 5/8" Baker packer at 7493~ 5 1/2" SSSV at 2090' True vertical depth BKB 135 2694 8602 8363-9260 RECEIVE! 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation Subsequent to operation Representative Dailv Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1410 ~ 436 42 635 4050 4754 710 1533 Tubing Pressure 296 249 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service oing is true and correct to the best of my knowledge. 17. I hereby certify that the fore~g Si~lned ~a~,~ ~ ~j[ ~' r~/-~,~ ' Title SeniorTechnicalAssistantl Form 10-40,{ Rev 06/15/88 / - Date SUBMIT IN DL~PLIOATE ssion 7/31/93 WELL M-21A(12-06-11-13) ADDPERF/FRAC The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9066' - 9144' MD 8/25/93 Performed a Hydraulic Fracture using the following fluids: FLUIDS PUMPED DOWNHOLE INJ TEST: DATA FRAC: FRAC: 11 5 1 1 2 3 3 4 74 159 350 BBLS 20# GEL 20 BBLS 40# GEL PREPAD TO ESTABLISH RATE 75 BBLS 40# X-LINK GEL PAD 157 BBLS 20# GEL DATA FRAC FLUSH 25 BBLS 40# GEL PREPAD TO ESTABLISH RATE BBLS 40# X-LINK GEL PAD Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 20# LINEAR GEL FLUSH fjh 6/10/94 RECEIVED dt. Ji'q 1 4 1994 A!~.o,,a"-"~" (.)ii & Gas Corls. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/10/93 T# 84863 BPX/PBU ~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-09~1-O7 PRODUCTION LOG 08/02/93 #1 B-0270-zo PRODUCTION LOG 08/01/93 ~1 B-06U~'7~ PRODUCTION LOG 08/06/93 #1 B-071~'~ PRODUCTION LOG 08/02/93 #1 B-20%%'{~ PRODUCTION LOG 08/06/93 #! G-031~-~q DTL 08/04/93 %1 M-21A~7~ PRODUCTION LOG 08/01/93 #1 Z-12 ~-~L PFCI6~I~ 08/06/93 #1 Z-14~-~ PFC~O~CC~ 08/06/93 %1 Z-32 ~9.~ CCL (~ 08/07/93 #1 9250.00- 9750.00 ATLAS 5 " 10250.00-10562.00 ATLAS 5 " 8950.00- 9200.00 ATLAS 5 " 11500.00-11716.00 ATLAS 5 " 9500.00- 9830.00 ATLAS 5 " 8800.00- 9200.00 ATLAS 5 " 8800.00- 9300.00 ATLAS 5 " 10300.00-11330.00 ATLAS 5 " 9600.00-10192.00 ATLAS 5 " 9800.00-10110.00 ATLAS 5 " Information Control Well Records t ECEIVED AUG 1 ? 199 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 BPX/PBU~LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at A-33 PDK-100 A-37 ~w~)7 PDK-100 M-21A ~-TS PERF s-04 ~-79 PRODUCTION LOG X-19A PDK-100 07/30/93 #1 07/29/93 ~1 07/31/93 ~1 07/31/93 ~1 07/30/93 %1 DATE: 08/05/93 T~ 84852 below. If you have any (907) 564-4004. 11000.00-11380.00 ATLAS 5 " 10400.00-10686.00 ATLAS 5 " 8850.00- 9200.00 ATLAS 5 " 8900.00- 9287.00 ATLAS " 9775.00-10117.00 ATLAS 5 " Information Control Well Records STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RI=COMP Li=TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-I SIJSPEiXE)ED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 93-75 3. Address B. APl Number iq ~ /~'~'~/,LCV~,I4~ 9.50'029'20923'01Unit or Lease Name P. O. Box 196612, Anchorage, Alaska 99519-6612 ~' r''~ '- - -"~-:--.-: 4. Location of well at surlace '~ ,/t~l~d3 Prudhoe Bay Unit At Top Producing Interval i z),~-r~ ! ~ sur~~ O.M.21AWell Number(12_6.11.13) Prudhoe Bay Field/Prudhoe Bay Pool 1877' SNL, 586' EWL, SEC 6, T11N, R13E i5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. KBE = 51.75' I ADL 28282 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. ~ Aband. 115. Water Depth, if offshore ]16. No. of Completions 5/29/93 673/93 6/14/93I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey ~0. Depth where SSSV set ~21. Thickness of Permafrost / 9550' MD/9224' TVD 9493' MD/9173' TVD YES [] N:~ [] 2090' feet MD ! 1900' (Approx.) 22. Type Electric or Other Logs Run DLL/GR/A C-4/CAL, MWD 23. CASING, LINER AND CEMENTING RECORD SETrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BoTroM HOLE SIZE CEM~ RECORD AMOUNT PULLED 20" X 30" Insulated conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2694' 17-1/2"' 3720 cuft Permafrost II 9-5/8" 47# L-80 Surface 8821' 12-1/4" 1925 cuft "G"/130 cuft PF 7" 29# 130R80 7389' 9550' 8-1/2" 800 cuft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun DiameterMD 3-3/8" 6~ 4-1/2", 13CR 7589' 7493' 8997'-9056' 8736;8787' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAl. USED 27. PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) 6/14/93 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (curt) Press. 24-HOUR RATE 28. CORE DATA Briel description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Anchor;.qe Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -'9. 30. GEOLOG~ 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. BKB Subsea Sag River 8853' 8558' Shublik 8896' 8595' Sadlerochit 8997' 8682' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ Title Drillino Engineer Supervisor 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 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: M-21A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: APl: 50- PERMIT: APPROVAL: ACCEPT: 05/25/93 03:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 05/25/93(1) TD: 9515 PB: 8742 RU TO KILL WELL MW: 9.8 NaCI TURN KEY MOVE FROM M-18B, CHGD 2 TIRES IN CELLAR, BERM SLOP TANKS, R/U TREE, FILL WATER TANKS 05/26/93 ( 2) RIG DOWN TBG EQUIP MW: 0.0 KCI TD: 9515 ClRC OUT DIESEL & CRUDE, INSTALL 2-WAY CK, N/D TREE, N/U PB: 8742 BOPE & TEST, P/U LUB PULL 2-WAY CK, PULL BTG HGR TO FLOOR & CBU, R/U OTIS, L/D 5-1/1" L-80 TBG, CLEAN FLOOR & R/D TBG EQUIP 05/27/93 (3) CUT SECTION. MW:10.0 KCI TD: 7548 RIH W/9-5/8" BP. SET @ 7900'. DISP W/MILL FLUID. SPOT PB: 7548 18 PPG PILL ON BP. TEST CSG. OK. POOH. RIH W/SECTION MILL/ START CUT @ 7545'. MILL CSG. 05/28/93 ( 4) RIH. MW:10.2 KCI TD: 7548 MILL SECTION F/7548'-7569'. CIRC. MILL F/7569'-7576'. PB: 7548 REAM & CIRC. MILL F/7576'-7595'. CIRC. POOH. L/D BHA. RIH TO 7695'. CIRC. REV CIRC. 05/29/93 ( 5) DRILL OUT OF WINDOW MW:10.0 VIS: 61 TD: 7563'( 0) CONT CIRC. TEST LINES, PUMP CMT, DISPL W/MUD. SQZ CMT. CIRC, POH. CLEAN BOP'S, TEST PKOFF. TEST BOP & RUN WEAR RING. TEST MTR. RIH, CIRC. C/O CMT. ORIENT MTR & SLIDING OUT TO 7563. 05/30/93 ( 6) DIRECTIONAL DRILL MW: 9.9 VIS: 56 TD: 8013'( 450) DIRECTIONAL DRILLING TO 8013. 05/31/93 ( 7) TRIP FOR BIT MW: 9.9 VIS:350 TD: 8396'( 383) CONT DRILLING TO 8067. CBU. SHORT TRIP TO CSG SHOE. CONT DRILLING TO 8396. PUMP DRY JOB & DROP SURVEY. POH. 06/01/93 (8) DRILL 8.5 HOLE MW: 9.9 ViS: 62 TD: 8659'(263) CONT POH, PU BIT, RIH. TEST MWD. RIH. POH TO RECVR DP SCREEN. RIH. WASH & REAM. DRILL TO 8659. WELL · M-21A OPERATION: RIG · DOYON 16 PAGE' 2 06/02/93 ( 9) DRILLING MW: 9.9 VIS: 68 TD: 8877'( 218) DRLD F/8659' TO 8847', PUMPED SWEEP, CIRC HOLE CLEAN, DROPPED SINGLE SHOT, POH 15 STDS TO INSIDE 9-5/8", L/D SINGLES, CONTD TO POH, RIH W/BHA #3, FILLED PIPE @ 4100' & 7545', RIH TO 8773', REAMED F/8773'-8847', TIGHT AROUND 8800' & 8816', DRLD F/8847'-8877' 06/03/93 (10) DRLG MW: 9.9 VIS: 55 TD: 9342'( 465) DRLG TO 9158. REPLC SHKR MTR. WORK PIPE. DRLD TO 9342. 06/04/93 (11) RU WIRELINE TO LOG MW: 9.9 VIS: 56 TD: 9550'( 208) DRLD TO 9550. CIRC. POH, RIH W/OVERSHOT ON W/L. RETRV SURV TOOL. RIH. REAM TO 9550. CIRC. POH, RU TO LOG. 06/05/93 (12) RIH W/7" LINER MW: 9.9 ViS: 55 TD: 9550'(0) COMP LOGGING. RIH W/PK ASSY. REAM TO 9550. CIRC HI-VIS SWEEP. POH. RU & RIH W/7" LINER. 06/06/93 (13) DRILLING CMT MW:10.0 VIS: 58 TD' 9550'( 0) MU LINER HGR & CIRC VOL. CONT RIH. CIRC DP. PUMPED CMT & SET LNR HGR. POH. PU BHA & RIH. WOC. CIRC. RIH, TAG CMT @ 7229. DRLD CMT TO 7386. CBU. 06/07/93 (14) POH FOR POLISH MILL MW: 8.6 VIS: 0 TD: 9493'( 0) CIRC HOLE CLEAN, POH. REPLC HYD HOSE. PU DC & DP, RIH. DRLD CMT TO 9493. CBU, & DISPL W/SW. TEST LINER LAP, POH & PU POLISH MILL. 06/08/93 (15) TD: 9493 PB' 0 RIH W/4-1/2" COMP MW: 8.6 Seawater POOH. L/D BHA. RIH. POOH. L/D DP. RIH W/4-1/2" 13 CR COMP ASS'Y. 06/09/93 (16) RELEASE RIG MW: 8.6 Seawater TD: 9493 CONT RIH W/TBG. LAND TBG & SET CONTR LINES. ND BOP, NU PB: 9184 FLANGE & TEST LINES. SET PKR. TEST ANNULUS. PUMP CELLAR & SET BPV. RELEASE RIG 6-8-93 16:30. ********* ****.***** ANADRIi£ ********* *************************************************** WELL HEAD ~TION,: LAT(~-S) 0,00 AZIMUTH ~ ROTARY TABI~ 11} TAR-]~ IS TIE IN POINT(TIP) ~ED DEPTH TRUE VERT DEPTH INCLINATION AZIMUTH LATITUD£(R/-S) DEPARTUBE(E/-W) 7409.00 18.70 30,40 724.,~ 482,00 DEP(E/-W) 187.89 0,00 MIC OFILME L. ~ ',J' ,,-' Alaska Oi! L& Gas Cons. Commission Anchoraga PAGI~ NO. M-21~ ~EAg_~D IHT~UAL ~TICAL DEFTH DEPTH ft ft ft 7550,00 0,0 ~91,~ 241,9 78H,05 92,2 7~78.31 ~4,3 78Z7,~ 8071,97 ~,7 7919,12 ************* ANAl)RILL *********~+**** SURUEY CALCULA~] DNS ******** MINIMUM CURVAT~ ~ETHOD TAF~ET STATIO~ AZIFIKI~ LATITUDE SECTIO~ I~CLH, ~-S ft d~ de~ ft -7~,3I 1~,70 30.40 724,~ -824,14 9,17 -823,~ 9,75 11~.~7 ~,24 -813,69 12.12 1~,2~ 745.52 -794.~ 14,66 175.~4 7~.48 DEPARTURE DISPLACt~IEHT at A~]IUTH £/-W ft ft ~2,00 869,77 3~,65 521,00 921,~ 5'-,44 5~,34 ~7,~.~, ~,26 ~,15 912,91 37,37 DLS deg/ lOOft 0,00 6,22 5.72 6,51 7,92 81~,50 82~,75 8-.~3,94 8446,19 85~, 19 94.6 8009.85 94.I 80~7,83 ~,2 8181,91 92,2 8262,24 ~,0 8341,~, -767,~' 18,39 1~o65 698.76 -734,56 23,22 18B.47 665,70 -694,42 2.7,82 188~73 626.02 -649,11 31,04 18~.16 581,2~ -600,:75 31.65 189,95 533,54 ~2,52 890,81 56,33 5,33 ~7,49 86t.~ ~.43 5,12 541,49 827,72 40,86 4,94 534,45 789.61 4~,60 3,50 526,41 749,52 4~,61 0,79 8,632,55 8726,8? 87~,60 93,4 6421,~8 94,3 8501,71 63,7 8556,33 -55!,89 31,56 191-46 485.47 -502,94 31,23 194,35 437,57 -470,40 30,76 195.11 405,92 517,32 709,43 ~.82 0,85 506,37 ~?,24 49,17 1,60 497.77 ~2,30 ~;.80 1,64 55,4 ~03,94 -442,~ 30.76 195.11 378.70 489,?1 619.22 5~.30 PRUDHOE BAY DRZLLZNG PBU/M-21A 500292092301 NORTH SLOPE COHPUTATTON DATE: 6/17 SPERRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PAGE /93 DATE OF SURVEY: 06/03/93 ELECTRONZC NULTZ-SHOT SURVEY JOB NUHBER: AK-EI-30034 KELLY BUSHZNG ELEV. = 51.75 OPERATOR: BP EXPLORATZON FT. TRUE SUB-SEA COURS COURSE D HEASD- VERTZCAL VERTZCAL ZNCLN DZRECTZON DEPTH DEPTH DEPTH DG NN DEGREES DG/ LS TOTAL RECTANGULAR COORDZNATES 100 NORTH/SOUTH EAST/WEST VERT. SECT. 7550 7409.00 7357.25 18 39 N 30,43 E ,00 7572 7430.-53 7378,78 16 51 N 31,19 E 8,07 7663 7517.90 7466,15 14 16 N 45,36 E 5,05 77'55. 7607,76 7556,01 10 33 N 72,92 E 7,50 7849 7700.19 7648,44 9 19 S 75,97 E 5,80 724.00N 482.00E 589.42 729,92N 485,53E 593.83 749.03N 500.30E 611,41 759.48N 516.43E 628,98 760.16N 532.03E 644.49 7942 7792,59 7740,84 10 53 S 43,95 E 6.13 8035 7882,88- 7831,13 13 34 S'13,10 E 7,54 8129 7973,74 7921,99 16 33 S 8,74 W 6,77 8223 8062,87 8011,12 20 56 S 9.51 W 4.66 8317 8148,85 8097,10 26 8 S 9,14 ~ 5.54 751.93N 545.57E 656,57 735,08N 554.09E 662.35 711.07N 554,55E 659,05 681.19N 549,73E 649.61 644.22N 543.67E 637.84 8411 8231.87 8180,12 29 38 S 10.55 ~ 3.79 8504 8312.61 8260.86 31 36 S 10.25 ~ 2.11 8597 8391.71 8339,96 31 37 S 11.66 W .80 8692 8472.25 8420.50 31 5 S 13.20 W 1.02 8785 8552.18 8500.43 30 33 S 16.03 W 1.66 8878 8632,30 8580,55 30 36 S 17.98 W 1,07 8970 8712.41 8660,66 29 30 S 17.73 W 1,18 9064 8794.39 8742,64 28 51 S 17.31 W .72 9095 8821.33 8769,58 28 46 S 16,59 ~ 1,16 9188 8902,75 8851,00 28 22 S 16.35 ~ ..46 600.93N 536.13E 623.61 553.92N 527.50E 607.73 506.12N 518.25E 591.10 458.20N 507.69E 573.18 412.07N 495,67E 554.08 366.80N 481.83E 533.32 322,68N 467.61E 512.37 279.00N 453.83E 491,91 264.82N 449,50E 485.42 222.29N 436.93E 466,34 9277 8981.33 8929,58 28 1 S 16,65 W ,42 181 9370 9063,73 9011,98 27 36 S 15,89 W ,59 140 9465 9147,84 9096,09 26 52 S 15,64 W .77 98 9499 9't78,21 9126.46 26 30 S 15.93 W 1,14 83 9550 9223,78 9172,03 26 31 S 15,93 W ,00 61 ,89N 424.96E 448,20 ,16N 412,78E 429.63 .49N 401.01E 411.49 ,79N 396.86E 405.08 .93N 390.62E 395.50 THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF THREE-DZHENSZON HZNZHUN CURVATURE HETHOD. HORZZONTAL DZSPLACEHENT = 395.50 FEET AT NORTH 80 DEG. 59 HZN, EAST AT HD = 9550 VERT:[CAL SECTZON RELAT]:VE TO WELL9HEAD VERTZCAL SECT]:ON COHPUTED ALONG 80. 9 DEG. SPERRY-SUN DRZLLZNG SERVZCES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRTLLE'NG PBU/I',4-21A 500292092301 NORTH SLOPE COI'4PUTAT]'ON DATE: 6/17/93 DATE OF SURVEY: 06/03/93 JOB NUHBER: AK-EZ-30034 KELLY BUSHZNG ELEV. = 51,75 OPERATOR: BP EXPLORATZON ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH TRUE SUB-SEA TOTAL NEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES ND-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DZFFERENCE VERTZCAL CORRECTZON 7550 7409.00 7357.25 724.00 N 482.00 E 141.00 8550 8351,04 8299.29 530.64 N 523.29 E 198.96 9550 9223.78 9172.03 61,93 N 390,62 E 326,22 57.96 127.26 THE CALCULATZON PROCEDURES THREE-DZHENSZON NZNZNUH ARE BASED ON THE CURVATURE NETHOD. USE OF FT. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/M-21A 500292092301 NORTH SLOPE COMPUTATION DATE: 6/17/93 DATE OF SURVEY: 06/03/93 JOB NUMBER: AK-EI-30034 KELLY BUSHING ELEV. = 51.75 OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES HD-T NORTH/SOUTH EAST/WEST DIFFEREN VD VERTICAL CE CORRECTION 7550 7409.00 7357,25 724.00 N 482.00 E 141. 7594 7451.75 7400.00 735.18 N 488.93 E 142. 7698 7551.75 7500.00 754.21 N 506.40 E 146. 7799 7651.75 7600.00 760,84 N 524.06 E 148. O0 98 1 .98 32 3.33 15 1 ,83 7901 7751.75 7700.00 756.64 N 539.86 E 149. 8003 7851.75 7800.00 741.83 N 551.92 E 151. 8106 7951.75 7900.00 717.35 N 555.24 E 154. 8211 8051.75 8000.00 685.32 N 550.42 E 159. 8320 8151.75 8100.00 642.77 N 543.43 E 168. 53 1 ,38 41 1 ,88 49 3,08 64 5,15 59 -3.95 8433 8251.75 8200.00 589.81 N 534.06 E 182. 8550 8351.75 8300.00 530.21 N 523.21 E 199. 8668 8451.75 8400.00 470.23 N 510.52 E 216. 8784 8551.75 8500.00 412.31 N 495.74 E 232. 8900 8651.75 8600.00 355,86 N 478.28 E 249. 16 13.57 09 16.93 39 17.30 90 16.52 06 16.16 9015 8751,75 8700,00 301.51 N 460.86 E 264, 9130 8851.75 8800.00 248.81 N 444.73 E 278, 9243 8951.75 8900.00 196,98 N 429,47 E 292, 9356 9051,75 9000.00 146.18 N 414.50 E 305, 9469 9151.75 9100.00 96,58 N 400,'48 E 317. 21 15.15 39 14. 18 05 13.66 21 13.16 72 12.51 9550 9223.78 9172.03 61.93 N 390.62 E 326.22 8.51 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT ND (FROM MINIMUM CURVATURE) POINTS FT. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/28/93 T# 84698 BPX/PBU ~GNETIC TAPE W/LISTING Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. M-21A OH/DLL FIN 06/04/93 #1 7538.00- 9520.00 1600BPI API#500292092301 9396->TP# ATLAS REF#5968 Information Control Well Records BP EXPLORATION BPX/PBU~LOGS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/25/93 T# 84689 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. M-21A M-21A M-21A M-21A DLL 06/04/93 #1 BOREHOLE PROFILE 06/04/93 ~1 BHC 06/04/93 #1 SS TVD 06/04/93 #1 7538.00- 9476.00 ATLAS 2/5" 7538.00- 9520.00 ATLAS 2/5" 7538.00- 9505.00 ATLAS 2/5" 7538.00- 9476.00 ATLAS 1/2" Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/24/93 T# 84688 BPX/PBU ~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. B-07 _\ PFC D_13~[~ 7~ PRODUCTION D-28~ ,~i~PRODUCTION LOGLoG E-24 ~ i CCL/PERF F-05 ~O% PRODUCTION LOG H-02 UI-~ PDK-100 H-15 ~ CCL M-2 lA'/ SBL N-I~[~ PRODUCTION LOG N-131 CCL N-14 5~'~q CNL P-04 ~%~7~ PRODUCTION LOG T-01~-~6 PRODUCTION LOG T-07~~ PRODUCTION LOG 06/12/93 ~1 11400.00-11650.00 ATLAS 5 " 06/03/93 ~1 11100.00-11347.00 ATLAS 5 " 06/03/93 #1 10800.00-11032.00 ATLAS 5 " 06/16/93 #1 10300.00-10618.00 ATLAS 5 " 06/15/93 #1 11050.00-11392.00 ATLAS 5 " 06/01/93 #1 8500.00- 9056.00 ATLAS 5 " 06/05/93 #! 1].300.00-11527.00 ATLAS 5 " 06/14/93 #1 7300.00- 9200.00 ATLAS 5 " 06/13/93 #1 7700.00- 9434.00 ATLAS 5 " 06/12/93 91 8500.00- 9592.00 ATLAS 5 " 06/12/93 91 8500.00- 9592.00 ATLAS 5 " 06/15/93 ~1 9300.00- 9708.00 ATLAS 5 " 06/14/93 91 40.00-11793.00 ATLAS 5 " 06/04/93 91 9750.00-10885.00 ATLAS 5 " 06/04/93 #1 9100.00- 9448.00 ATLAS 5 " 06/13/93 91 9312.00- 9645.00 ATLAS 5 " 06/08/93 #1 9665.00-10146.00 ATLAS 5 " Information Control Well Records ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 18, 1993 Bill Kirton Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-21A BP Exploration Permit No. 93-75 Sur. Loc. 3341'NSL, 4697'WEL, Sec. 6, TllN, R13E, UM Btmnhole Loc. 3378'NSL, 4256'WEL, Sec. 6, TllN, R13E, UM Dear Mr. Kirton: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. D_av .id W~ohnst~n~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,,o~5 r~rh'~fed on tec'vcfocl paI~er h y C ., :.,,? , , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=50.25'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P, O. Box 196612. Anchorar~e. Alaska 99519-6612 ADL 28282 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3341'NSL, 4697' WEL, SEC~ 6, T11N, R13E, UM Prudhoe Ba)/ Unit At top of productive interval 8. Well number Number 3622' NSL, 4222' WEL, SEC. 6, T11N, R13E, UM M-21A (12-6-11-13) 2S100302630-277 At total depth 9. Approximate spud date Amount 3378' NSL, 4256' WEL, SEC. 6, T11N, R13E, UM 5/22/93 $200,000.00 .. 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Prop,~$ed depth (MD and TVD) property line ADL 28260-627' feet No close apProach feet 2560 9547' MD/9218' TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (se,, 20 AAC 25.o35 (e)(2)) Kickoff depth 7ssofeet Maximum hole angle29. Tz° Max,mum surlace 3330psig At total depth (TVD) 8~'00',/4390psic~ 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity el cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (inc;ude stage data) 8-1/2" 7" 29¢ 13CR80 NSCC 2147' 7400' 7263' 9547' 9218' 300 cuft Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary ^v 1~ ~ Total depth' measured 9515feet Plugs (measured) i~;'''.~ true vertical 9260 feet Aiaska i.)il & Gas Cons. Co~.~xniss~O~'~ Effective depth: measured 9378feet Junk (measured) Anchorage true vertical 9215feet Casing Length Size Cemented Ivleasured depth True Vertical depth Structural Conductor 80' 30' x 20" 8 cu yds 110' 110' S u rf ace 2664' 13-3/8" 3720 cuft 2694' 2694' Intermediate P rod ucti on 947' 7" 390 cuft 8566'-9513' 8363'-8369' Lin e r 946' 5" 127 cuft 8509'-9455' Perforation depth: measured 9762'-9797', 9803'-9809', 9813'-9819', 9823'-9834' true vertical 8884'-8953'ss (.four intervals) 20. Attachments Filing fee [] Property plat [] BO~ Sketch [] Diverter Sketch [] Drilling program [] Drillin~ fluid pro,ram [] Time vs depth plot [] Refraction aralysisF3 Seabed reportr~ 20 AAC 25.050 requirements[] 21. ! hereby ce/r~fy~h%the~foregoing is true and correct to the best of my knowledge Si~ned ~ ,~~ Title Dr#ling Engineer Supervisor Date Commission Use Only Pen.'nit Number IAPI number IApprov. a.~l date ISee cover letter '~'¢- ,~ .,¢ 150-o~ ~,- ,2_,. o ¢..2, .~-~ / I ,~ -" / ~" ~/..~ J!o_r other requ,remer,~ Conditions of approval Samples requi'red [] Yes ~ No Mud log required [] Yes ~ I'.'.. Hydrogen sulfide measures [] Yes [] No Directional survey required J~ Yes [] No Required working pressure for BOPE []2M' 1-13M; ~5M; I-I10M; 1-115M' Other: Original Signed By by order of Approved by David W. Johnston Commissioner zne commission Date,~ -,~/~.,, ..... Form 10-401 Rev. 12-1-85 Submit in triplicate _ ZlA Permit to Drill Informatio,. M-21A PRELIMINARY WELL PLAN WELL: M.21A SIDETRACK PBU J[ELN_.0~ 50-029-20923-00 (on the original M-21 well) LOCATION: Surface: 3341' FSL, 4697' FEL, Sec. 6, T11N, R13E, UM Target: 3622' FSL, 4222' FEL, Sec. 6, T11 N, R13E @ 8685' ssTVD BHL: 3378' FSL, 4256' FEL, Sec. 6, T11N, R13E @ 9155' ssTVD .ESTIMATED ST.~RT..: 22 May, 1993 O.P..R ...... DAYS TO COMPLE,T.E: 14 CONTRACTOR' Doyon Rig #16 DIRECTIONAL' Kickoff at 7550' MD. the south.) (11 degree angle build and 158 degree turn to WELLBORE: Item TVD(BKB) 20" CONDUCTOR 110' 13-3/8" SHOE 2694' KOP 7409' TOP SAG RIVER 8608' TOP SHUBLIK 8648' TOP SADLEROCHIT 8738' TOTAL DEPTH 921 8' MD(BKB) Mud Wt. 11 0' N/A 2694' N/A 7550' 9.7 8844' 9.7 8890' 9.7 8993' 9.7 9547' 9.7 LOGGING PROGRAM: 8-1/2" Hole: DLL/GR/BHCS/S P NOTE: Open hole CNL sonde will not be picked up. MUD PROGRAM.: The milling/drilling fluid program will consist of a 9.7 - 9.8 ppg XCD polymer / KCI water based mud. DEPTH DENSITY PV YP INT 10 MIN FL OIL (TVD). (PP..G) (CP) (#/FT) GEL GEL c¢/30min f%~ 7550' 9.7 10 10 5 7 5 0 to to to to to to to to 9547' 9.8 16 18 10 15 8 0 SOLIDS MUD f%~ TYPE 5 Water to Base 7 Mud MAY 1 3 ~,99~ Alaska Oil & Gas Cons, Cornrnissiof'.' Anchorage ,v,-21A Permit to Drill Information MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.7 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 3550 psi/8545' ss TVD. 3500 psi/8800' ss TVD. Overbalance Sag River: Overbalance Top Sadlerochit: 760 psi. 940 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4200 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3320 psi based upon a gas column to surface from 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING 7" 29# 13CR-80 NSCC DEPTH BIJRST/OOLLAPSE TENSILE 7400'-9547' MD 8160 psi/7020 psi 676 klbs CEMENT CALCULATIONS: 7" LINER: Measured Depth: Basis: Total Cement Vol: 7400'MD (Hanger)- 9547'MD (Shoe) 60% open hole excess, 40' shoe joints, and 500 MD above top oil bearing sand (Sag River @ 8844 MD) 300 cu ft or 250 sxs of Class G blend @ 1.18 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR-80 NSCT (0'- 7500' MD) ~IA Permit tO Drill Information, MUD DOYON RIG #16 & SOLIDS CONTROL EQUIPMENT _ _ _ _ w m _ m _ _ _ Continental Emsco FA1300 mud pump Brandt shale shaker Alfa-Laval centrifuge Triflow mud cleaner Gas buster Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console Gas ,,..,ons. C.~iiu-nissio~ Anchorage __ .21A Permit to Drill Inf0rmati.o,, . 6b. 6C. 7. 10. 11. 12. 13. 14. 15. 16. 17. 18. M-21A SUMMARY PROCEDURE 1. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 5-1/2" tubing at 8430' MD. Freeze protect. 2. MIRU workover rig. Test intermediate packoff to 5000 psi. 3. Pull BPV. Circulate out freeze protection fluid. 4. Set BPV. ND tree. 5. NU 11" 5M x 13-5/8" 5M DSA if required and BOP's. Install tree test plug. Test BOP's to 5000 psi. Pull tree test plug and BPV. Pull and lay down .5-1/2" tubing. Run casing inspection Icg from 100' below the planned section cut to surface if casing integrity is suspect. At this point there are no known problems with the casing. RIH w/9-5/8" bridge plug and set at 7900' MD. Replace intermediate packoff if necessary. RIH with a 9-5/8" section mill and cut a 50' section in the 9-5/8" casing starting at +/- 7550' MD. Prior to starting section cut, spot an 18 ppg pill from PBTD to the base of the proposed section. 8. RIH with open-ended DP. Mix and pump a minimum of 180 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. 9. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" packed hole assembly to total depth of 9547" MD / 9218' TVD or 150' MD below the OOWC at -9025' ss TVD. RU Atlas wireline and Icg with the .D..LL / Microlog / GR / Sonic. Make wiper trip depending on hole conditions and logging time. Run 7" 29# 13CR NSCC x 7" 29# L80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. Crossover from 13CR to L-80 at 7460 MD. Cement liner with a minimum of 250 sacks. (Ensure that cement covers up to 500' above all oil bearing sands) Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. Change over to clean inhibited seawater. RIH with 4-1/2" 12.6# 13Cr completion string w/Z" packer. Space out, land completion, and place packer at 7500 MD based on 100' below the 7" liner top.. Drop ball. Set BPV. ND BOP's. NU the adapter flange and 6" 5M tree. Install tree test plug and test to 5000 psi with diesel. Pull tree test plug and BPV. Pressure down tubing and set packer. Test down tubing to 4000 psi. Bleed tubing pressure down to 1000 psi and hold. Test tubing x casing annulus to 3500 psi. Shear RP valve and freeze protect. Set BPV. Release rig. Gas Cons. Ar!chor~ge 21A Permit to Drill Informatio,, OBJECTIVES The primary objective of this sidetrack is to increase oil production and reduce water production. The well has a very high watercut due to production from Zone 3. The route to the water is via two mechanisms. First, the well has a confirmed channel behind the 5" scab liner to squeeze perforations in the 7" liner adjacent Zone 3. The well was fraced with the channel present. Secondly, the fracture design was pumped at 40 bpm with a pad volume of 17 mgals; easily big enough to frac into Zone 3. RFT data taken in M-32 implies a 150 psi differential between the top of Zone 4 and Zone 3. This would lower the oil PI and make the watercut increase. · Well status: Producer · Qo = 500 BOPD WC = 80+% · Current Well Problems: GOR = 1500 scf/stb 1. High Water Production 2. Channel behind scab liner- to squeeze perfs in Zone 3 3. Fracced with Channel 4. Fracture Treatment too Large - Pad 17 mgals @ 40 bpm 5. Gas Lift Design not very stable 6. A Fault cut in Zone 2 could indicate water problems due to fault location The work is tentatively scheduled to begin May 22, 1993 with rig Doyon 16. Total time required to perform the work should be approximately 14 days. MECHANICAL CONDITION · Tubing' · Liner: · IA: · OA: No Known Problems No Known Problems No Known Problems No Known Problems ~cope' 1. Squeeze perforations and lay cement plug 2. Cut tubing above the packer 3. Move rig on location, pull tubing 4. Mill window 5. Lay kick off cement plug 6. Drill 8.5" hole to proposed Location 7. Run open hole logs. 8. Run and cement 7" 13 chrome liner. Pressure test to 3000 psi. Alask~:~ 0il & Gas Cons. Anchora.qe ~ 21A Permit tO Drill Information,, 9. Run 4.5" 13 chrome production tubing with gas lift mandrels, 7" packer, and a 4.5" tailpipe with X and XN nipples. 10. Perforate when rig is off location. Produce for 4 weeks and review stimulation 11. Anticipated initial rate: Qo = 3000 BOPD wc = 0% GOR -- 1000 scf/stb 12. Anticipated ad-rec: 0 MSTB, with an IOR of 2500 bpd. IMPACT ON FUTURE DEVELOPMENT M-21's current location is midway between a line of injectors and a line of producers. The location for the M-21 sidetrack is along the line of HVGR phase 1 producers. The key objective of the sidetrack is to accelerate oil production from the HVGR phase 1 project area. This sidetrack precludes the use of the M-21 production slot for HVGR phase 2. WELL HISTORY M-21 was drilled in March 1983 and put on production May 1984. A RWO was performed in June 1990 to run a 5"scab liner. The objective of the scab liner was to cover holes in the 7" liner, prevent rock/sand production and reduce water production. A PITs in February 1991 confirms a channel behind the scab liner to the squeeze perforations in Zone 3. The well was fraced in April 1991 with the channel still open. The pad volume for the fracture treatment was 17 mgals pumped at 40 bpm; enough to frac into Zone 3. No acid jobs were performed on this well. :~aska Oil & Gas Cons. Com~-~issiO~': Anchorage i '1 A) TIE-TN ~) END OF SUP, VE C) TARGET 5'/ lO <KB> .... =PRUDH'OE ,~200- 4800 5400- 6000/ ; 56oo'-h- -- 7200 BA-?'--DR Z LL T NCZ" ~,IO BKB 5ECTN iNCLN -=~" 740g /.,_O -77D 18.64 B341 6171 -694 29.77 c-OO5 87~ -364 29.77 ~54t 98~8 -95 29,77 11 I M-21A ~ VERTICAL SECTION n,_~.tion at' ~87.C,6 !TVD Sca]~.' ] ]nnh = ~200 fee( ~¢ ' '1 i~ f200 feet u~p Scale ch = IDcswn - 05/u~,/~B- j20¢1 1BO0 2400 Sect,,on Oeosrtur. e 3000 360( V I E W i 4200 4503 PRUQHOE BAY DRILLING 'dent ! f ica t ~ on t4D :'~.,'S E/k' T i E- .~,',1 7550 7~ .., ~G~T ~005 30~ N 477 M-2 JA PLAN V JEW rh r",'"'I ~ T · , i~,=~_IrlA, ION.. 29.79 E ISCALE ....... : i ~nch = 200 tDRAWN ....... : 04/15/93 ! i Shear Land OJnection~7 2^0 !O0J 90C.-z 8O0 ,SOO 400 3OC .... ' ....... _20'0 I KB · .{ , .- lO0 i0,3 EAST -> =ii - 40O 5OO 1 i 7OO .. JC,0O :2,7'0 . , ~.300 TC;TF, L F'. 05 ---.'. ........... , ........ ' PRUDHOf~ BAY D~_T_-LI---i-N'~' -' ! ~i ,.:~o o.~ ~. ,_, ~. ,, .-: sz~,. s~,~ -~.~ ~.._~.~ VERTTCAL SECTION VI-~'~ SecL]on aE: ~87.66 ~TVD Scale.' ~ inch = 300 fee~ . ~Bep Scale.: ~ ~r~ch = 300 feel 6900 ........ ~ ....... i i "~~Dna~,n ..... : 05/05/03 ' i / 7~00 ....... , ~ ~380- ~ ~ ~ ~ ', * .......................~ ' ...... i i 7~00' ~ .,.,. , I I .. 1 .i " ~ / ~ i' i ' ....... ...... 7S03 ' I --~ .. , ', ti ; 7~ .................. i ' ' .... ' I,:',' I i , . , ~ ~ , ~.~ . : e4oo ! --' ,' f. ~ . ' .... ~ ,' ; [ : I .~. 2-: -~500 -~350 -~800 -1050 -900 -750 -600 -450 -300 -i50 0 ]50 300 4~0 ~00 iu,A- F'. E',~ FR._-II'i G~'.E~ i LaND GR'2_AT h.~2~mD DiRECTiONA-L DRiLLiNG -~'~ Corporate Office 1111 East 80nh Avenue K = }~nchorage, AK 99518 (907) 34%-4511, Fe.X 349-~48~, y = -' T - "r'~'l" DIRECTIONA. L W~.LL pL.~/,~ for PRL~,HOE EAY D.-._~,L~, ~ ~.;eil ......... : M-2!A (P2) ?ield ........ : PRUDHOE BAY M-PA~ Units ........ : FEET LEGAL DESCRIPTION }urface ...... ; 3}41 FSL 4697 Tie-in. ........ , ~0G~ FgL ~21~_ FEL E0g T~it~ Ri2~ ?arget ....... : 3622 FSL 4222 FEL S06 TilN Ri~E A~L .......... : 3378.~SL 4256 FEL $06 Ti~''~ . ~,.J'~. '~ Prepared ..... ; 0,1./!~/9~ Section at...: 197.d6 PtB elevasion. : 62.60 ASP ZOi,~=~ ¥ 62947~.27 629451.43 5975150.24 5974720.00 5974475.60 ;~ia$I~a Oil .& ~as Oons. ~orar, qis ~r~chorago PROPOSED WELL PROFILE STATION M~S iNC~ VERT-mm_~no ID~IFiCATION DEDTM ~I.~GLE =}lB 7550 7600 7700 7800 7900 TiE-iN ___ ~ OF Cb-RVE ~, ~ I, TA~.GET IONR 4A/X-~tA¥ DOWC ZONE ~ zoz.rs ~/2c TOP HOT · _opwc .... ~o ~ _ ZONE i/'I~ TD 1~'~' BSAD SECT DIST DiRECTiON AZ i >UJT P: !8.6% 7~09 7347 -779 30.39 15.76 7457 7394 -792 33,27 10.21 755~ 74~2 -~12 5.66 76~3_ 7591 -82i 73,=~=~' ~ ~ 775~ 7690 -520 ~,7 8000 10.14 7852 7790 -8,Sg $i00 15.69 79~0 7887 -757 8200 21. 47 ~044 798~ - 755 8300 ~ ~5 8~ - ~oq 80/3 -714 834! 29,77 ~171 9109 -~94 SSg0 29.77 g64g 9585 ~422 8993 29.77 $738 8675 ~7C, 8993 29.77 - ~738 8675 -370 9005 29.77 8748 86~5 -364 9051 ~ ~ 77 ~7°8 8725 -3%~ 9068 29.77 8803 8740 -333 9109 29.U~ ~8~8 8775 -~I~ =~78 ~9 .77 $8Q$~ 8R~5._ - 279 9270 29.77 8978 89i5 -233 9345 29.77 RO~$ 8}80 -i96 9397 29.7? 9068 9025 -270 9-'~ ..... ~ 4~" 4ff'~~ = ............. ~ -i36 9547 29 77 Q9i8 9!5= · ~ ~ _, !78.75 183.79 !86.76 187.66 187,66 !B7.66 I~7,66 187.66 I87.66 iS7.66 187.66 i8?,g6 187.66 i~7.66. 187,66 i67.66 RE L - CO©P~ I i'L:,T F. 5 FP.C,M- ;'TELLHEf-12 745 N 69! 650 N 620 }{ 521 E 360 N '~z ': 3O9 N 'if. i 309 N 478 £ 304 N -~7.-' i 2El N 474 '.v 272 N 473 E 053 1,I 'i~' ~ 219 I,T 4g6 E 111 N 45! E 37 ~? 441 E DL/ :.SO <TiE 6.0 6.0 6.0 6,0 6.0 6.0 6.0 ,3. O 5. O C..3 O.0 .:2,. O 0,0 0,O 0.0 O,O 3.0 -3. ?. 0, ,3 O,O 3LDD (c)~.2 .~IA Ri.46 ~:~1 PM 2) DOYON 16 13 5/8" 5,000 psi Stack t 10.15 4.5 I/ RKB I I HYDRIL I I 5.02 Variable 3.5" x 6" Pipe Ram Variable 4.5" x 7L" Pipe Ram ,, 1.02 1.80 2.35 0.25 MUD CROSS GROUND LEVEL Blind Ram , ETBG SPOOL ETBG SPOOL I 1. BASE i FLO 12.40 15.40 17.60 20.70 24.85 25.10 Oil & Gas Cons. Commissioii M-21ACMT.XLS Well: Field~ State Permit M-21A Prudhoe Bay 93-75 Ei'I~I'leeK Work Sheet: Date: /~f. kf/nde[ Cemen! l/ok~rne £dcu/alion~ 5/!7/.93 Cas',"~ T Casing Size -Inches Cuing Length - Fee~ Hole Di~eter -!~ Ce~nt - Sa~ C~e~- Y~d C~e~- C~ fl C~-C~ f[ C~e~-S~k~ 82 C~nt- Y~ ~2 Ce~- C~ fl ~2 C~- ~c fl ~2 Ce~- Sa~ ~3 Ceme~ - Y~ ~3 C~- ~ ft Ce~- ~ fl / Vol Cement- Fill F~tor Conducto~ 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 11:DIV/O! Suface 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 ttDIV/O! Liner 7.000 2,147.000 8.500 0.000 1.180 0.000 300.000 0.000 0.000 0.000 0.000 300.000 1.102 Casing T~e Ca~ing Size -Inches Ca~g DepIh - Feet Hole Diameter-Inches Cernen~ - Sacks ti1 Cement- Yield111 Cemenl - Cubic it 1:I1 Cement- Cubic it 111 Cement- Sacks112 Cement-Yield :11:2 Cement- Cubic fl: 1:12 Cement- Cubic fl: :112 Cement-Sacks :113 Cement- Yield:113 Cement- Cubic ft t:I3 Cement- Cubic fl: :1:t3 Cement- Cubic it /Vol Cement-Interval fl: Top of Cement- Feet Intermediate II1 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O! t1~IV/O! Intermediate 112 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.013 0.00 0.00 0.00 0.00 11DIV/O!. I~DIV/O! Production 0.000 0.000 0.000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 lION/O! I~DIV/O! Nleasured Depth Pdnted 5/17/93 Sta~e: Alaska Borough: Well: M-21A Field: Prudhoe Bay St. Perm ~g3-75 Date Engr: M-21ACSG.XLS 5/17/93 M. Minder Casing Interval Interval Size Bottom Top Length 1A 7 9218 7263 2147 2A 0 0 0 0 3A 0 0 0 0 4A 0 0 0 0 SA 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 D~,~ D~,=,~o,, o,,~=i~o, Tension Lbs Grade Thread Lbs 29 13CR-80 N$CC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 10t9 Mud Hydraulic Collapse Weight Gradient Gradient ppg psi/ft psi/It 9.8 0.510 0.410 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -43.100 0.0 0.000 -0.100 0.0 0.000 -0.1 O0 0.0 0.000 -O. 1 O0 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure psi 333O 0 0 0 0 0 0 0 0 0 Yield psi BDF 8160 2.5 0 #DIV/O! 0 #DIV/O! 0 #DiVK)! 0 #DR//O! 0 #DIV/O! 0 #DIVK)! 0 #DIVK)! 0 #DIVK)! 0 #DIVK)! 1C 2C 3C 4C 5C 6C 7C 8C 9C 10C Tension Strength K/Lbs 62.26,3 0 0 0 0 0 0 0 0 0 K/Lbs 'rDF 676 10.88 0 #DiV/O! 0 #DIV/O! 0 #DIV/O! 0 #DIVK)! 0 #DiV/O! 0 #DIV/O! 0 #DiV/O! 0 #DIV/O! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi 3776 0 0 0 0 0 0 0 0 0 Resist. CBF 7020 1.859 0 #DR//0! 0 #DR/10! 0 #DIVK)! 0 #DR//0! 0 #DIRK)! 0 #DR/K)! 0 #DIVK)! 0 #DIV/O! 0 #DIVK)! P cje 1 STATE OF ALASKA ALA ~ OIL AND GAS CONSERVATION COMMIS5, :~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon xx Suspend__ Alter casing __ Repair well ~ Change approved program ~ Operation Shutdown ~ Re-enter suspended well~ Plugging xx Time extension__ Stimulate~ Pull tubing~ Variance__ Perforate~ Other xx Plugback for redrlll 2. Name of Operator 5. Type of Well: 6. BP Exploration Development X Exploratory 3. Address Stratigraphic__ 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 service__ 4. Location of well at surface 8. 1939'SNL, 195'EWL, SEC. 06, T11N, R13E At top of productive interval 9. 867'SNL, 948' EWL, SEC. 06, T11N, R13E At effective depth 10. 721' SNL, 1081' EWL, SEC. 06, T11N, R13E At total depth 11. 710' SNL, 1091' EWL, SEC. 06, T11N, R13E Datum elevation (DF or KB) KBE = 62.55' feet Unit or Property name Prudhoe Bay Unit Well number M-21 (11-06-11-13) Permit number 83-37 APl number 50- 029-20923 Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical 9515' feet Plugs (measured) 9260' feet BKB Effective depth: measured true vertical 9378 feet Junk (measured) 9215' feet BKB Casing Length Size Structural Conductor 80' 20" x 30" Surface 2664' 13-3/8" Intermediate 8791' 9-5/8" Production 947' 7" Liner 946 5" Perforation depth: measured 8975'-9078', 9088'-9131', (open) 9142-9154, 9164-9174' (squeezed) Cemented 8 cu yds 3720 cu ft 1925 cu ft 390 cu ft 127 cu ft true vertical subsea 8684'-8873', (four open intervals) Tubing (size, grade, and measured depth) 5-1/2" AB/BTC L-80 @ 8506' Measured depth 110' 2694' 8821' 8566'-9513' 8509-9455' True vertical depth BKB 110' 2694' 8602' 8363'-9 RECEIVED MAY 1 1 199 Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 9-5/8" Baker SAR-3 Packer @ 8451', SSS V @ 1998' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation 5/14/93 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. Signed ~/t/' ?/~_~'~- Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY ~/~2/~,~ Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Intd'grity Test Subsequent form required 10- ~09' / Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnctnn J ADp roval N o. (_.9.,-~,,.~ /,/,/ , ,:o ,'~ ed C~issioner Date ~/~ ~ ~ SUBMIT IN TRIPLICATE CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE Loc [2 thru 8] [10 g 13] (4) Casg [14 thru 22] (5) BOPE ,~:,,~:'-~f' ~-/7-,¢/~ [23 thru 28] Company YES 1. Is 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 ..................... ~ Lease S Well ~ ./¢~z:¢Z ~_~~;2_' /9~(~ NO REMARKS 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ . 10. 11. 12. 13. 14. 15. Does operator have a bond in force ................................... ~ Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease ntrnber appropriate .......................................... ~ Does well have a unique name $ ncrnber ................................ Is conductor string provided ..................................... ,... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ............................. a diverter system required ........................................ Will cement tie in surface g intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is Is Is 16. 17. 18. !.9. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of ~ BOPE attached .... ~ Does BOPE have sufficient pressure rating -- test to ~¢~ psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... ~ (6) Other 4¢/~_ .~<~ ~,,/~ ~ [29 thru 31] (7) Contact . ~32 ] (8) Addl -~.,,~,.~z/,5"o??'-~3- geo 1 og~' eng i nee r i nq: DWJ ,~ MTM~ RAD_.~-I ~> RPC/t¢/" cD BEW JDH ¢/t~ J-k LG rev 12/92 jo/6.011 29. 30. 31. 32. 33. FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone ntrnber of contact to supply weekly progress data ...... Additional requirements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE remarks' MERIDIAN' UM ,,~' TYPE' Exp/~X Redril 1 2< Rev Inj -rE 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, informati;3n 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. M - 2lA PRUDHOE BAY RECEIVED JUL 0 6 1993 Oil & Gas Cctv, Commf~im Anchorage MICitOFIL Run 1' 04 - June - 1993 DLL/ACI4CAL/GR 7538 9520 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN1 5968.00 J. DAHL SEE REMARKS REMARKS: OPEN HOLE M - 2lA (12-6-11-13) 500292092301 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 17-JUN-93 RUN 2 RUN 3 6 liN 13E 1938 4096 52.80 51.60 25.70 DLL/AC/4CAL/GR LOGS WITNESSED BY: H. HAYWOOD, Z. RUNJE, D. ROBERTSON CIRCULATION STOPPED: 00:30 04-JUNE-93. SOME ACOUSTIC CYCLE SKIPPING BELOW CASING SHOE. $ 9.625 7545.0 8.500 9550.0 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 7538.0 9485.0 7538.0 9505.0 7538.0 9474.0 GR (MEASURED DEPTH) BASELINE DEPTH LL3 7538.0 7538.0 7607.5 7672.5 7688.5 7689.0 7688.5 7750.5 7750.5 7759.0 7759.5 7773.0 7772.5 7795.0 7795.0 7894.0 7893.5 7930.0 7930.0 7930.5 7933.5 7933.0 7962.0 7961.5 7962.5 7980.5 7981.0 7981.0 8007.5 8007.5 8008.0 8008.0 8050.0 8050.0 8070.0 8070.0 8114.5 8114.0 8125.0 8125.0 8125.5 8150.5 8150.5 8150.0 8180.5 8180.5 8187.0 8187.0 8187.0 8192.0 8191.5 8192.0 8222.0 8222.0 8223.0 8223.0 8245.5 8245.5 8250.5 8250.5 8254.0 8253.5 8260.0 8259.5 8272.0 8272.5 8272.5 8275.0 8275.0 8279.0 8279.5 8282.0 8282.0 8285.5 8285.5 8287.5 8287.5 8318.0 8318.0 8323.5 8323.5 8336.5 8336.5 8372.0 8372.0 8372.0 8389.5 8389.5 all EQUIVALENT UNSHIFTED DEPTH DT 7538.0 7608.0 7673.0 7688.5 runs merged; no case 8390.0 8398.0 8408.0 8415.0 8438.0 8471.5 8488.0 8488.5 8510.0 8516.5 8545.0 8550.0 8662.0 8725.5 8758.0 8814.5 8830.0 8896.5 8899.0 8899.5 8910.0 8915.0 8915.5 8919.5 8922.0 8938.5 8939.0 8952.0 8963.0 9002.0 9004.5 9022.0 9029.5 9049.5 9140.0 9146.0 9148.5 9151.5 9193.0 9249.0 9296.0 9296.5 9307.0 9308.0 9407.5 9408.0 9431.5 9444.5 9445.0 9540.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS DLL $ REMARKS: 8389.5 8397.5 8489.0 8544.5 8550.0 8661.5 8899.0 8909.0 8915.0 8918.0 8921.5 8939.0 8952.0 8963.5 9002.0 9004.0 9048.5 9146.5 9149.0 9193.0 9249.5 9297.5 8398.0 8408.0 8416.0 8438.0 8472.0 8488.0 8510.0 8516.0 8662.5 8725.5 8758.0 8814.0 8830.5 8895.0 8898.5 8915.0 8938.5 8963.0 9022.0 9029.5 9140.0 9152.0 9297.0 9306.5 9308.0 9408.0 9409.0 9432.0 9444.0 9444.5 9540.0 9540.0 RUN NO. PASS NO. 1 6 1 6 1 6 OPEN HOLE PORTION MAIN PASS. MERGE TOP 7538.0 7538.0 7538.0 MERGE BASE 9485.0 9505.0 9474.0 LLD, SP, C13, C24, MTEM, TEND, & TENS WERE SHIFTED WITH LL3 · $ CN : BP EXPLORATION WN : M - 2lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 C13 BCS 68 1 IN 4 4 C24 BCS 68 1 IN 4 5 TEND BCS 68 1 LB 4 6 TENS BCS 68 1 LB 4 7 LL3 DLL 68 1 OHMM 4 8 LLD DLL 68 1 OHMM 4 9 SP DLL 68 1 MV 4 10 MTEM DLL 68 1 DEGF 4 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 175 Tape File Start Depth = 9540.000000 Tape File End Depth = 7538.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44056 datums Tape Subfile: 2 344 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 7349.0 7538.0 BCS 7478.0 7538.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE PORTION MAIN PASS. $ CN : BP EXPLORATION WN : M - 2lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH BCS 68 1 GAPI 4 2 DT BCS 68 1 US/F 4 3 TEND BCS 68 1 LB 4 4 TENS BCS 68 1 LB 4 4 67 465 06 6 4 84 653 71 5 4 56 053 87 1 4 56 053 87 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 8 Tape File Start Depth = 7538.000000 Tape File End Depth = 7348.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1906 datums Tape Subfile: 3 34 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7349.0 AC DLL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 7349.0 7533.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG 4-ARM CALIPER CENTRALI Z ER CHT TEMP PCM MIS DLL GR MIS AC 4 CAL CENT $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMTJM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) STOP DEPTH 9501.0 9521.0 9490.0 04-JUN-93 FSYS REV. J001 VER. 1.1 30 04-JUN-93 748 04-JUN-93 9550.0 9526.0 7538.0 9520.0 1800.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 3967XA 1609EB/1603MA 4203XA 8.500 7545.0 7538.0 KCL POLYMER 9.90 56.0 10.0 5.8 193.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : M - 2lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.150 73.0 0.060 193.0 0.113 69.0 0.000 0.0 0.230 68.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 C13 AC 68 1 IN 4 5 C24 AC 68 1 IN 4 6 CAL AC 68 1 IN 4 7 CHT AC 68 1 LB 4 8 TTEN AC 68 1 LB 4 9 RS DLL 68 1 OHMM 4 10 RD DLL 68 1 OHMM 4 11 SP DLL 68 1 MV 4 12 TEMP DLL 68 1 DEGF 4 13 SPD DLL 68 1 F/MN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 51 246 18 5 4 44 037 22 5 4 94 885 22 5 4 95 558 30 1 4 95 558 30 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 488 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 9540.000000 7348.000000 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 166823 datums Tape Subfile: 4 567 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 5 0.2500 VENDOR TOOL CODE START DEPTH GR 8824.0 AC 8824.0 DLL 8824.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRC~TION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 9507.5 9527.5 9496.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC 4CAL CENT $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC-ACOUSTILOG 4-ARM CALIPER CENTRALIZER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): 04-JUN-93 FSYS REV. J001 VER. 1.1 30 04-JUN-93 717 04-JUN-93 9550.0 9526.0 7538.0 9520.0 1800.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 3967XA 1609EB/1603MA 4203XA 8.500 7545.0 7538.0 KCL POLYMER 9.90 56.0 10.0 5.8 193.0 0.150 0.060 73.0 193.0 MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : M - 2lA FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA 0.113 ~69.0 0.000 0.0 0.230 68.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 2 AC AC 68 3 ACQ AC 68 4 C13 AC 68 5 C24 AC 68 6 CAL AC 68 7 CHT AC 68 8 TTEN AC 68 9 RS DLL 68 10 RD DLL 68 11 SP DLL 68 12 TEMP DLL 68 13 SPD DLL 68 1 GAPI 4 1 US/F 4 1 4 1 IN 4 1 IN 4 1 IN 4 1 LB 4 1 LB 4 1 OHMM 4 1 OHM/~ 4 1 MV 4 1 DEGF 4 1 F/MN 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 51 246 18 5 4 44 037 22 5 4 94 885 22 5 4 95 558 30 1 4 95 558 30 1 4 40 514 81 0 4 39 859 45 0 4 23 415 80 5 4 84 503 82 1 4 11 639 82 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 162 Tape File Start Depth = 9546.000000 Tape File End Depth = 8818.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42689 datums Tape Subfile: 5 239 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LIS 93/ 6/17 01 **** REEL TRAILER **** 93/ 6/18 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 18 JUN 93 8:41a Elapsed execution time = 53.39 seconds. SYSTEM RETURN CODE = 0
