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Home My WebLink About197-137Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/04/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# PBU 05-04A 50029201520100 196089 10/30/2025 BAKER RPM PBU F-18B 50029206360200 225099 11/4/2025 BAKER MRPM END 1-39A 50029218270100 206187 11/20/2025 READ PressTempSurvey END 1-55 50029217880000 188021 11/26/2025 READ PressTempSurvey END 1-57 50029218730000 188114 11/18/2025 READ CaliperSurvey END 1-63 50029219050000 189006 11/23/2025 READ PressTempSurvey END 1-65A 50029226270100 203212 11/29/2025 READ PressTempSurvey END 2-18 50029220320000 190043 11/19/2025 READ PressTempSurvey END 2-20 50029220480000 190060 11/24/2025 READ PressTempSurvey END 2-32 50029220840000 190119 11/30/2025 READ PressTempSurvey END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey NCI A-13 50883200870000 192106 11/27/2025 READ Caliper Survey NS-33A 50029233250100 208189 5/22/2025 READ EVCamera Please include current contact information if different from above. T41175 T41176 T41177 T41178 T41179 T41180 T41181 T41182 T41183 T41184 T41185 T41186 T41187 END 2-46B 50029219210200 197137 11/21/2025 READ PressTempSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.05 11:03:29 -09'00' STATE OF ALASKA • ALL OIL AND GAS CONSERVATION COMM SSION ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing LI Operations shutdown U Performed: Suspend ❑ Perforate ❑i Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool Li Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development {] Exploratory ❑ 197-137 3.Address: Stratigraphic El Service ❑ 6.API Number: ' 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-21921-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0034633 DUCK IS UNIT MPI 2-46B RECEIVED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ENDICOTT/ENDICOTTOIL JUN 14 2016 11.Present Well Condition Summary: ] Total Depth measured 14,430 feet Plugs measured 14,326 reeiG -` C true vertical 10,212 feet Junk measured N/A feet Effective Depth measured 14,326 feet Packer measured 11,446 feet true vertical 10,196 feet true vertical 9,306 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 30" 110' 110' N/A N/A Surface 2,499' 13-3/8" 2,499' 2,493' psi 2,260psi Production 7,157' 9-5/8" 7,157' 7,070' 6,870psi 4,760psi Liner 7,398' 7" 14,371' 10,203' 8,160psi 7,020psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED JAN 0l Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13Cr80/NSCT 11,502' 9,338' 1,505MD Packers and SSSV(type,measured and true vertical depth) Baker S-3 Pkr HES HXO SVLN See Above 1,488TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 84 0 675 1,800 279 Subsequent to operation: 55 613 311 1,800 271 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations {] Exploratory Development{] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil {] Gas ❑ WDSPL 7 Printed and Electronic Fracture Stimulation Data ❑ 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: 316-153 Contact Wyatt Rivard 'TredhR WC Email wrivard(a�hilcorp.com Printed Name Mike Dunn Title Operations Manager Signature - o 1 Phone 777-8382 Date 6/14/2016 Form 10-404 Revised 5/2015 Submit Original Only • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Slickline 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 3/9/2016-Wednesday RU SL UNIT AND PT SURFACE EQUIP 300 LP 2000 HP.TROUBLESHOOT RESTRICTION @ 2' SLM JUST BELOW TUBING HANGAR. UNALBE TO PASS RESTRICTION WITH 3.84" NOGO, 3.81" G-RING. BRUSHED W/2.81" G-RING AND 4-1/2" BLB, BRUSHED THRU RESTRICTION FROM SURFACE TO 50'. LARGEST DRIFT THRU RESTRICTION 3.40" G-RING. LDFN. 3/10/2016-Thursday No activity to report. 3/11/2016- Friday RU SLICKLINE AND PT SURFACE EQUIP 300 LP/2,000 HP. CONT TO TROUBLESHOOT RESTRICTION. RAN 3.43" BROACH WORKED THRU RESTRICTION. RAN 3.50" BROACH, WORK TOOLS UNABLE TO PASS THRU RESTRICTION. RAN 3.50" G-RING UNABLE TO PASS. RAN 3.70" LIB, LIB INCONCLUSIVE. LDFN. 3/12/2016-Saturday RU SLICKLINE AND PT SURFACE EQUIP 300 LP/2,000 HP. RAN 3.50" G-RING, UNABLE TO PASS 2' SLM RAN BARBELL SETUP WITH 3.70"TAPERED LIB, SHALLOW 360° MARK, POSSBILE SCALE, INCONCLUSIVE. RDMO 3/13/2016 -Sunday No activity to report. 3/14/2016- Monday No activity to report. 3/15/2016-Tuesday No activity to report. 1110 S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Slickline 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 3/16/2016-Wednesday No activity to report. 3/17/2016 -Thursday No activity to report. 3/18/2016- Friday No activity to report. 3/19/2016-Saturday No activity to report. 3/20/2016-Sunday No activity to report. 3/21/2016- Monday "PT 250/4,000 PSI (GOOD TESTS). RAN 3.43" BROACH AND PASSED THROUGH RESTRICTION FREELY. RAN 3.47" BROACH AND SAT DOWN @ 2', WORKED PAST RESTRICTION UNTIL TOOLS PASSED FREELY.. RAN 3.5" G-RING,SAT DOWN @ 2' AND IT TOOK HEAVY JARRING TO MAKE IT THROUGH. G-RING BOTTOM SCARED HEAVILY. RAN MULTIPLE RUNS WITH BROACHES AND WAS ABLE TO MAKE IT TO 7' WITH A 3.55"-3.57" TAPERED BROACH. 3/22/2016-Tuesday PT TO 320PS1/4000PSI (GOOD TESTS). RAN MULTIPLE BROACHES 3.55"-3.57"THROUGH RESTRICTION @ 2'-13' SLM. DRIFTED DOWN TO 500' SLM PROVIDED A SAMPLE FOR THE ENGINEER. RAN 3.60" G-RING, SAT DOWN @ 8' BROKE THROUGH @ 13', DRIFTED DOWN TO 500' SLM. GOT HUNG UP PRETTY GOOD COMING BACK UP THROUGH. • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Slickline 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 3/23/2016-Wednesday TREE NEEDS SERVICED BEFORE NEXT SLICKLINE JOB. PT 250/4,000 PSI (GOOD TESTS). RUN 3.62" BROACH, SIT DOWN @ 2', MAKE IT DOWN TO 8', HAND SPANG 25 MINUTES, UNABLE TO GET PAST 8' SLM. RDMO. 3/24/2016-Thursday No activity to report. 3/25/2016- Friday No activity to report. 3/26/2016 -Saturday No activity to report. 3/27/2016 -Sunday No activity to report. 3/28/2016 - Monday No activity to report. 3/29/2016 -Tuesday No activity to report. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Slick Line 50-029-21921-00-00 197-137 3/9/16 5/15/16 ,. Daily Operations. n, �= 4/13/2016-Wednesday Pumped 5 bbl acid treatment for scale build up at hanger. 4/14/2016-Thursday No activity to report. 4/15/2016 - Friday No activity to report. 4/16/2016-Saturday "PT 250/2,500 PSI (GOOD TESTS). RAN 3.805" G-RING AND CANNOT GET PAST RESTRICTION @ 2' SLM. RAN MULTIPLE G- RINGS FROM 3.71"-3.82"AND A 3.84" NO GO CENT, THROUGH RESTRICTIONS FROM 2'-11' SLM. RAN 4.5" GS (BRASS)56" BBE PRONG, PULLED 4.5" BBE SER# BB4-102 @ 1,470' SLM (1,505' MD). RAN 3.0" CENT, 3' 2-1/8" STEM, 15' 3" BAILER, OAL=20.1", DRIFT TO DEVIATION @ 12,533' SLM. 4/17/2016-Sunday No activity to report. 4/18/2016- Monday No activity to report. 4/19/2016-Tuesday No activity to report. • M Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Slick Line 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 4/20/2016-Wednesday No activity to report. 4/21/2016-Thursday No activity to report. 4/22/2016- Friday No activity to report. 4/23/2016-Saturday No activity to report. 4/24/2016-Sunday No activity to report. 4/25/2016- Monday Call in to PE for weather check before rolling to location. Winds are 16 mph, roll unit to Endicott, stop at gun shop and grab first gun.Arrive Endicott, Sign in at camp, spot unit, work with crews delivering pipe. Unit and support equipment spotted, PJSM. Exercise crane and check spot with test lift over well. Rig up needs to be very close to maintain lift capacity for down hole operations.Test lift is good, call to have well shut-in. DSO's are in middle of change-out, will be a little bit before they are available to shut-in well. DSO on location, shut-in well.Well shut-in, pop cap, stab rams on well, start making up lube. Make up tools and test at surface, tools check good, stab well, start PT. PT to 250psi/4000psi -good, call DSO to blow down flow line,flow line blown down, open well, rih with Tractor and gauge ring junk basket assembly, 3.5" GR.Tools stopped falling due to deviation, perform weight checks and line up to start tractoring. Made it to bottom, log up and make correlation pass, POOH at surface, shut in well, bleed down, unstab, lay down tools and lube, cap rams on tree. RDMO, DSO and PE notified. 4/26/2016-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Slickline 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 4/27/2016-Wednesday Morning meeting at SLB camp. Drive to gun shop to get explosives. Drive to Endicott. Arrive Endicott, check in with DSO, Sign In at security inspect location and equipment, PJSM. Start rig up, pick up lube. Pick up tools.Test tools at surface. Having an issue with tractor communication, lay down tools and investigate.;Tools check good, line checks good, head is good. Reboot entire truck and logging software second full reboot fixed locked up power module in EWAFE, tools check good, pick up and hot check for perf guns lost telemtry with tools again, lay down and reinvestigate.;Unable to get tractor telemetry system working consistently, decision was made to rig down and return to the shop for deeper investigation.Turn well over to DSO,tree cap on and tested. 4/28/2016-Thursday No activity to report. 4/29/2016- Friday WELL S/I UPON ARRIVAL. P/T TO 250psi LOW/2,050psi HIGH. SET 3.813" X-LOCK W/ BBE SCSSSV (ser# HNBB-50) 3 sets std pkg, sec lock do IN HXO @ 1,505' MD. PASSING CLOSURE TEST TO 400PSI DIFFERENTIAL.JOB COMPLETE -TURNED WELL OVER TO PAD OP TO POP. 4/30/2016-Saturday No activity to report. 5/1/2016-Sunday No activity to report. 5/2/2016- Monday No activity to report. 5/3/2016-Tuesday No activity to report. • S Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Eline 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 5/4/2016-Wednesday No activity to report. 5/5/2016-Thursday 24Hr Operations. WELL FLOWING UPON ARRIVAL. (ELINE TRACTOR PERF). PT TO 250PS1 LOW/4200PS1 HIGH. RIH WI ELINE TRACTOR & 20' OF PJ OMEGA GUNS.TRACTORED FROM DEVIATION @ 12,800'TO 14,050'. PERFORATED INTERVAL @ 13,840' - 13,860' (CONFIRMED SHOT AT SURFACE) . CORRELATED TO PDS DEPTH CORRELATION LOG DATED 18-AUG-13. BREAK DOWN GUN #1 AND GET READY FOR GUN #2. 5/6/2016- Friday 24Hr Operations. RUN #2- RIH W/ ELINE TRACTOR/ 15' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,816' - 13,831'. RUN #3 - RIH W/ ELINE TRACTOR/20' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,734' - 13,754'. RUN # 4- RIH W/ ELINE TRACTOR/20' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,714' - 13,734'. ALL PERFS TIED INTO PDS DEPTH CORRELATION LOG DATED 18-AUG-13. 5/7/2016-Saturday 24Hr Operations. RUN #5- RIH W/ ELINE TRACTOR/20' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,642' - 13,662'. RUN #6- RIH W/ELINE TRACTOR/20' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,508' - 13,528'.ALL PERFS TIED INTO PDS DEPTH CORRELATION LOG DATED 18-AUG-13. CURRENTLY RIH W/GUN #7. 5/8/2016-Sunday 24Hr Operations. RUN #7- RIH WI ELINE TRACTOR/20' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,488' - 13,508'. RUN #8- RIH W/ ELINE TRACTOR/ 10' 2-7/8" PJ OMEGA GUN - PERFORATE INTERVAL @ 13,478' - 13,488'. ALL PERFS TIED INTO PDS DEPTH CORRELATION LOG DATED 18-AUG-13.JOB COMPLETED-TURN WELL OVER TO DSO TO POP. 5/9/2016- Monday '0 No activity to report. 5/10/2016-Tuesday No activity to report. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date END 2-46B Eline 50-029-21921-00-00 197-137 3/9/16 5/15/16 Daily Operations: 5/11/2016 Wednesday No activity to report. 5/12/2016-Thursday No activity to report. 5/13/2016- Friday No activity to report. 5/14/2016-Saturday No activity to report. 5/15/2016-Sunday PRESSURE TEST 300/2,000 PSI (GOOD TESTS). RUN 4.5"" BBE W/STANDARD PKG. SER#HBB4-100 AND SET IT @ 1,471' SLM (1,505' MD). CLOSURE TEST A PASS. RDMO. " 5/16/2016- Monday No activity to report. 5/17/2016-Tuesday No activity to report. H 0 0 Endicott Unit Well: END 2-468 SCHEMATIC Last Completed: 9/28/1997 flacon)Alaska,LI.r. PTD: 197 137 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Initial KB Elev.:56.10' Tree Unknown 13-3/8" 2,772 cu/ft Permafrost in a 17-1/4"Hole Wellhead MCEVOY 9-5/8" 575 cu/ft Class"G"in a 12-1/4"Hole30 7" 448 cu/ft Class"G"in a 8-1/2"Hole 41 kkk CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 30" Conductor N/A N/A Surface 110' N/A 1 13-3/8" Surface 68/NT-80/Butt 12.415" Surface 2,499' 0.150 9-5/8" Production 47/NT-80/N/A 8.681" Surface 7,157' 0.0732 7" Liner 29/13CR80/Hyd511 6.184" 6,973' 14,371' 0.0372 TUBING DETAIL 13-3/8"/ ► 4-1/2" Tubing 12.6/13CR80 3.958" Surf 11,502' 0.0152 Ili 2 WELL INCLINATION DETAIL Max Angle is 83 deg.@ 12,998' Angle at Top Perf:82 deg.@ 13,132' 3 JEWELRY DETAIL No Depth Item 1 1,505' 4-1/2"OTIS HXO SVLN(3.813"ID) 40 4 GLM DETAIL:CAMCO 4.5" 9-5/8" la 5 2 3,563' STA 7:1.5"TB 9CR,Dev=1,VLV=Dome,Latch=RA,Port=16,ID=3.857",TVD=3,557',Date:1/27/1998 3 5,309' STA 6:1.5"TB 9CR,Dev=1,VLV=DMY,Latch=RA,Port=0,ID=3.857",TVD=5,303',Date:1/27/1998 a 6 4 6,378' STA 5:1.5"TB 9CR,Dev=15,VLV=Dome,Latch=RA,Port=16,ID=3.857",TVD=6,362',Date:1/27/1998 5 6,873' Liner Top Packer 6 7,134' STA 4:1"KGB-2-LS MOD 9CR,Dev=34,VLV=DMY,Latch=INT,Port=0,ID=3.909",TVD=7,050',Date:1/27/1998 IIII 7 7 8,325' STA 3:1"KGB-2-LS MOD 9CR,Dev=60,VLV=DOME,Latch=INT,Port=16,ID=3.909",TVD=7,746',Date:1/27/1998 8 9,909' STA 2:1"KGB-2-LS MOD 9CR,Dev=62,VLV=DMY,Latch=INT,Port=0,ID=3.909",TVD=8,458',Date:9/27/1997 8 9 11,369' STA 1:1"KGB-2-LS MOD 9CR,Dev=54,VLV=SO,Latch=INT,Port=22,ID=3.909",TVD=11,369',Date:12/9/2011 10 11,435' 4-1/2"HES'X'Nipple NSCT(3.813"ID) 9 11 11,446' 7"Baker S-3 Packer(3.875"ID) 12 11,469' 4-1/2"HES'X'Nipple 9CR(3.813"ID) 13 11,490' 4-1/2"HES'XN'Nipple 9CR(3.725"ID) _4 14 11,501' 4-1/2"WLEG(3.958"ID)/Bottom @ 11,502' 10 PERFORATION DETAIL 1 . ' 11 END Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Size 13,132' 13,192' 10,017' 10,025' 60 1/22/1998 Open 3-3/8" 12 13,172' 13,192' 10,022' 10,025' 20 1/21/1998 Open 3-3/8" 13,172' 13,192' 10,022' 10,025' 20 12/17/1997 Open 3-3/8" 1-:: 13 13,260' 13,280' 10,036' 10,039' 20 4/26/2002 Open 2-7/8" FV 13,424' 13,446' 10,060' 10,063' 22 4/23/2002 Open 2-7/8" 13,446' 13,478' 10,063' 10,068' 32 4/23/2002 Open 2-7/8" ' 13,478' 13,488' 10,068' 10,069' 10 5/8/2016 Open 2-7/8" 13,488' 13,508' 10,069' 10,072' 20 5/8/2016 Open 2-7/8" 13,508' 13,528' 10,072' 10,074' 20 5/7/2016 Open 2-7/8" 13,642' 13,662' 10,090' 10,092' 20 5/7/2016 Open 2-7/8" 13,674' 13,694' 10,094' 10,100' 20 2/16/1998 Open 3-3/8" 13,694' 13,714' 10,097' 10,097' 20 2/15/1998 Open 3-3/8" 13,714' 13,734' 10,100' 10,102' 20 5/6/2016 Open 2-7/8" FIV 13,734' 13,754' 10,102' 10,105' 20 5/6/2016 Open 2-7/8" Marker Jt 13,816' 13,831' 10,115' 10,117' 15 5/6/2016 Open 2-7/8" @12,997 13,840' 13,860' 10,118' 10,121' 20 5/5/2016 Open 2-7/8" 13,870' 13,890' 10,123' 10,126' 20 2/15/1998 Open 3-3/8" Caliper Restriction = 13,890' 13,910' 10,126' 10,130' 20 2/15/1998 Open 3-3/8" 5.13"ID@13,881':":= 8/18/2013\ =r, C Endicott Sands • FIll 14,210' 14,300' 10,178' 10,176' 90 9/25/1997 Open 4-1/2" �+►� = GENERAL WELL INFO SAFETY NOTE: API:50-029-21921-02-00 H2S Reading average 230 to 260 PPM on A/L& 7 I` • .'. Initial Completion by Doyon 15 -3/25/1989 Gas Injectors. Well requires a SSSV.Well Angle> TD=14,430(MD)/TD=10,212'(TVD) Sidetrack(END 2-46A)by Doyon 15 -1/28/1997 70 Deg.@ 12,777'-4-1/2"Chrome Tubing. PBTD=14,326'(MD)/PBTD=10,196'(TVD) Sidetrack(END 2-46B)by Doyon 15 -9/28/1997 See Perf Table for Add Dates GLV C/O-12/9/2011 Perf Add-5/5 to 5/8/2016 Revised By:TDF 6/14/2016 • • LOF Tb y*•\��\Iyy,, A THE STATE Alaska Oil and Gas 71 o e LASKA Conservation Commission ki th= 333 West Seventh Avenue ^ti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O m Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 SCANNED MAR 0 3 2016 Anchorage, AK 99503 Re: Endicott Field, Endicott Oil Pool, DIU MPI 2-46B Permit to Drill Number: 197-137 Sundry Number: 316-153 Dear Mr. Dunn: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P* 11--t,)(74- Cathy P. oerster ,�yl� Chair DATED this Z4*of February, 2016. RBDMSVV FEB L 6 2016 0 • RECEIVED • STATE OF ALASKA FEB 2 2 ?016 ALASKA OIL AND GAS CONSERVATION COMMISSION 073 Z(2 ¢// APPLICATION FOR SUNDRY APPROVALS AOGLta 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q . Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ . 197-137 . 3.Address. Stratigraphic ❑ Service El 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-21921-02-00 - 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 462 - Will planned perforations require a spacing exception? Yes ❑ No El DUCK IS UNIT MPI 2-463 - 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0034633 - ENDICOTT/ENDICOTT OIL- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,430'• 10,212' - 14,326' 10,196' 3,805 14,326' N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 30" 110' 110' N/A N/A Surface 2,499' 13-3/8" 2,499' 2,493' 5,020psi 2,260psi Production 7,157' 9-5/8" 7,157' 7,070' 6,870psi 4,760psi Liner 2,392' 7" 14,371' 10,203' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6#/13CR80/NSCT 11,502' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker S-3 Pkr and HES HXO SVLN 11,446 MD/9,306 TVD and 1,505 MD/1,488 TVD 12.Attachments: Proposal Summary El Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 3/7/2016 Commencing Operations: OIL ❑ ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Wyatt Rivard Email wrivard( hilcorp.corn Printed Name - e Dunn Title Operations Manager Signature -- Phone 777-8382 Date 2/22(2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. _ \6" Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes El No Q Subsequent Form Required: /0 —Lj Z `4 RBDMS 0, FEB 2 6 2016 '/ APPROVED BY Approved by: r �r�r� COMMISSIONER THE COMMISSION Date: 2-2_f--/C ,/eilet47 ) R Submit Form and Form 10-403 Revised 11/2015 Approved application is d 1i rYf6ntTls 1\ ASL a of approval. lachmze,[its in Duplicate 4 " .--`-sem 2. 2:2 •-/4, • • Add Perf Well: END 2-46B PTD: 1971370 IIilcorp Alaska,LL' API: 50-029-21921-02-00 Well Name: END 2-46B API Number: 50-029-21921-02-00 Current Status: Flowing w/Gas Lift Rig: SL+ EL Estimated Start Date: March 7, 2016 Estimated Duration: 5 Reg.Approval Req'std? YES Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 1971370 First Call Engineer: 1 Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8847 (0) (509) 670-8001 (M) Current Bottom Hole Pressure: 2,047psi @ 10,000' TVD (Based on SBHPS on 5/23/14) Maximum Expected BHP: 4,805psi @ 10,000' TVD (Based on UPSZFIV/FV Virgin Press Gradient) Max. Proposed Surface Pressure: 3,805psi (Based on: MPSP= Max BHP-(0.1 psi/ft x 10,000 TVD) Reference Log: PDS Depth Correlation dated 18-Aug-2013 Brief Well Summary: The well is currently flowing with the assistance of gas lift at 170bopd, 752bwpd,0 MCFD (81.6%WC).This well was sidetracked, completed and perforated via TCP and Eline tractor in the fall of 1997 in the FIII, FIV and FV UPSZs. Additional perforations were added with Coil Tubing in 1998 and 2002. The high deviation necessities coil or tractor intervention at the perf intervals. Most recently, an Eline tractor-conveyed caliper was run to top of fill at 14,210' MD.The caliper identified a 5.13" restriction at 13,881' MD. Current SSSV in well: 4-1/2" BBE-SSSV set in 4-1/2" HES HXO SVLN at 1,505' Objective: Using Eline and tractor conveyance, perforate following intervals for increased oil production: Gun Run# UPSZ Perf Top Perf Bottom Perf Length 1 4 ±13,844' ±13,864' 20 2 4 ±13,818' ±13,833' 15 3 4 ±13,734' ±13,754' 20 4 4 ±13,714' ±13,734' 20 5 4 ±13,646' ±13,666' 20 6 5 ±13,508' ±13,528' 20 7 5 ±13,488' ±13,508' 20 8 5 ±13,478' ±13,488' 10 Total 145 Table 1:END 2-46B Proposed Gun Runs Procedure: Slick Line 1. MIRU SL unit and pressure test to 250psi low and 2,000psi high. 2. RIH and pull 4-1/2" BBE SSSV, POOH. 3. Drift for 2-7/8" dummy gun to deviation. 4. RD slick line. Eline 5. RU EL unit and pressure test to 250psi low 4,000psi high. 6. MU tractor with junk catcher and gauge ring for 2-7/8" drift. • • Add Perf Well: END 2-46B • PTD: 1971370 Hilcorp Alaska,LL API: 50-029-21921-02-00 7. RIH to deviation and tractor as needed to reach TD, POOH. 8. MU perforating tool string with 2-7/8" guns and tractor. 9. RIH to deviation and tractor as needed to reach correlation & perf interval. a. Deviation increases rapidly from ^'70 deg at 12,800' to ^'83 deg at 13,000' then stays between 80-83 deg to TD. Max DLS is 13.9 deg at 12,870'. b. Eline caliper run on 8/18/13 required tractor below 12,830'. 10. Correlate 1st gun run to reference log PDS Depth Correlation dated 18-Aug-2013. Contact OE Taylor Wellman at 1(907) 947-9533 prior to perforating for final approval of tie in. Contact OE on future gun runs at OE's discretion. 11. Perforate 15t gun run (±13,844' to ±13,864'md) as per Table 1: END 2-46B Proposed Gun Runs. POOH. a. Note any tubing pressure change in WSR. 12. Repeat steps 8-11 for gun runs 2-8 as per Table 1: END 2-46B Proposed Gun Runs. 13. RD Eline. Slick Line 14. MIRU SL unit and pressure test to 250psi low and 4,000psi high. 15. MU 4-1/2" BBE SSSV and set in nipple @1,505'. POOH. 16. RD SL Attachments: As-built/ Proposed Well Schematic/AOR Map • � Endicott Unit Well: END 2-46B . II SCHEMATIC Last Completed: 9/28/1997 Hilcorp Alaska,LLC PTD: 197-137 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Initial KB Elev.:56.10' Tree Unknown 13-3/8" 2,772 cu/ft Permafrost in a 17-1/4"Hole Wellhead MCEVOY 9-5/8" 575 cu/ft Class"G"in a 12-1/4"Hole �,*� + 7" 448 cu/ft Class"G"in a 8-1/2"Hole 301 to . s i CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 4. a-" 14 30" Conductor N/A N/A Surface 110' N/A 41 13-3/8" Surface 68/NT-80/Butt 12.415" Surface 2,499' 0.150 * > 9-5/8" Production 47/NT-80/N/A 8.681" Surface 7,157' 0.0732 , 7" Liner 29/13CR80/Hyd511 6.184" 11,979' 14,371' 0.0372 P TUBING DETAIL 13-3/8"¶4 j le I 4-1/2" Tubing 12.6/13CR80 3.958" Surf 11,502' 0.0152 2 WELL INCLINATION DETAIL Max Angle is 83 deg.@ 12,998' Angle at Top Perf:82 deg.@ 13,132' 3 JEWELRY DETAIL No Depth Item 1 1,505' 4-1/2"OTIS HXO SVLN(3.813"ID) 4 GLM DETAIL:CAMCO 4.5" 9-5/8"f /1 5 2 3,563' STA 7:1.5"TB 9CR,Dev=1,VLV=Dome,Latch=RA,Port=16,ID=3.857",TVD=3,557',Date:1/27/1998 3 5,309' STA 6:1.5"TB 9CR,Dev=1,VLV=DMY,Latch=RA,Port=0,ID=3.857",TVD=5,303',Date:1/27/1998 6 4 6,378' STA 5:1.5"TB 9CR,Dev=15,VLV=Dome,Latch=RA,Port=16,ID=3.857",TVD=6,362',Date:1/27/1998 5 6,873' Liner Top Packer 6 7,134' STA 4:1"KGB-2-LS MOD 9CR,Dev=34,VLV=DMY,Latch=INT,Port=0,ID=3.909",TVD=7,050',Date:1/27/1998 7 7 8,325' STA 3:1"KGB-2-LS MOD 9CR,Dev=60,VLV=DOME,Latch=INT,Port=16,ID=3.909",TVD=7,746',Date:1/27/1998 8 9,299' STA 2:1"KGB-2-LS MOD 9CR,Dev=62,VLV=DMY,Latch=INT,Port=0,ID=3.909",TVD=8,458',Date:9/27/1997 8 9 11,369' STA 1:1"KGB-2-LS MOD 9CR,Dev=54,VLV=SO,Latch=INT,Port=22,ID=3.909",TVD=11,369',Date:12/9/2011 11 10 11,435' 4-1/2"HES'X'Nipple NSCT(3.813"ID) 9 11 11,446' 7"Baker S-3 Packer(3.875"ID) 12 11,469' 4-1/2"HES'X'Nipple 9CR(3.813"ID) _ 13 11,490' 4-1/2"HES'XN'Nipple 9CR(3.725"ID) 14 11,501' 4-1/2"WLEG(3.958"ID)/Bottom @ 11,502' it10 PERFORATION DETAIL 11 END Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Size 12 13,132' 13,192' 10,017' 10,025' 60 1/22/1998 Open 3-3/8" k 13,172' 13,192' 10,022' 10,025' 20 1/21/1998 Open 3-3/8" 13 FV 13,172' 13,192' 10,022' 10,025' 20 12/17/1997 Open 3-3/8" 13,260' 13,280' 10,036' 10,039' 20 4/26/2002 Open 2-7/8" 13,424' 13,446' 10,060' 10,063' 22 4/23/2002 Open 2-7/8" 13,446' 13,478' 10,063' 10,068' 32 4/23/2002 Open 2-7/8" 14 r 13,674' 13,694' 10,094' 10,100' 20 2/16/1998 Open 3-3/8" , ,,t,'4 13,694' 13,714' 10,097 10,097' 20 2/15/1998 Open 3-3/8" FIV 13,870' 13,890' 10,123' 10,126' 20 2/15/1998 Open 3-3/8" 13,890' 13,910' 10,126' 10,130' 20 2/15/1998 Open 3-3/8" V, Fill 14210 14,300' 10,178' 10,176' 90 9/25/1997 Open 4-1/2" to to , GENERAL WELL INFO API:50-029-21921-02-00 Marker Jt Initial Completion by Doyon 15 -3/25/1989 Fi @12992---44 Sidetrack(END 2-46A)by Doyon 15 -1/28/1997 Sidetrack(END 2-46B)by Doyon 15 -9/28/1997 Caliper Restriction See Perf Table for Add Dates 5.13"ID@13,881' GLVC/O-12/9/2011 8/18/2013a Endicott Sands SAFETY NOTE: II: H2S Reading average 230 to 260 PPM on A/L& °' Gas Injectors. Well requires a SSSV.Well Angle> 7'r ' 70 Deg.@ 12,777'-4-1/2"Chrome Tubing. TD=14,430(MD)/TD=10,212'(ND) PBTD=14,326'(MD)/PBTD=10,196'(ND) Created By:TDF 2/15/2016 ,11 • • Endicott Unit Well: END 2-46B PROPOSED Last Completed: 9/28/1997 Hilcorp Alaska,LLC PTD: 197-137 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Initial KB Elev.:56.10' Tree Unknown 13-3/8" 2,772 cu/ft Permafrost in a 17-1/4"Hole t - , Wellhead MCEVOY 9-5/8" 575 cu/ft Class"G"in a 12-1/4"Hole ;: " 7" 448 cu/ft Class"G"in a 8-1/2"Hole z' [,,t, CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm BPF 1 30" Conductor N/A N/A Surface 110' N/A 13-3/8" Surface 68/NT-80/Butt 12.415" Surface 2,499' 0.150 9-5/8" Production 47/NT-80/N/A 8.681" Surface 7,157 0.0732 7" Liner 29/13CR80/Hyd511 6.184" 11,979' 14,371' 0.0372 30" ;I ''':.1 < TUBING DETAIL 3/8' te I 4-1/2" Tubing 12.6/13CR80 3.958" Surf 11,502' 0.0152 2, WELL INCLINATION DETAIL Max Angle is 83 deg.@ 12,998' Angle at Top Perf:82 deg.@ 13,132' 3 JEWELRY DETAIL No Depth Item 1 1,505' 4-1/2"OTIS HXO SVLN(3.813"ID) 4 GLM DETAIL:CAMCO 4.5" 9-5/8"gi 5 2 3,563' STA 7:1.5"TB 9CR,Dev=1,VLV=Dome,Latch=RA,Port=16,ID=3.857",TVD=3,557',Date:1/27/1998 3 5,309' STA 6:1.5"TB 9CR,Dev=1,VLV=DMY,Latch=RA,Port=0,ID=3.857",TVD=5,303',Date:1/27/1998 6 4 6,378' STA 5:1.5"TB 9CR,Dev=15,VLV=Dome,Latch=RA,Port=16,ID=3.857",TVD=6,362',Date:1/27/1998 ' 5 6,873' Liner Top Packer 6 7,134' STA 4:1"KGB-2-LS MOD 9CR,Dev=34,VLV=DMY,Latch=INT,Port=0,ID=3.909",TVD=7,050',Date:1/27/1998 7 7 8,325' STA 3:1"KGB-2-LS MOD 9CR,Dev=60,VLV=DOME,Latch=INT,Port=16,ID=3.909",TVD=7,746',Date:1/27/1998 8 9,299' STA 2:1"KGB-2-LS MOD 9CR,Dev=62,VLV=DMY,Latch=INT,Port=0,ID=3.909",TVD=8,458',Date:9/27/1997 8 9 11,369' STA 1:1"KGB-2-LS MOD 9CR,Dev=54,VLV=SO,Latch=INT,Port=22,ID=3.909",TVD=11,369',Date:12/9/2011 10 11,435' 4-1/2"HES'X'Nipple NSCT(3.813"ID) 9 11 11,446' 7"Baker 5-3 Packer(3.875"ID) 12 11,469' 4-1/2"HES'X'Nipple 9CR(3.813"ID) , 13 11,490' 4-1/2"HES'XN'Nipple 9CR(3.725"ID) 14 11,501' 4-1/2"WLEG(3.958"ID)/Bottom @ 11,502' 10 PERFORATION DETAIL 11 END Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Size 1. 12 13,132' 13,192' 10,017' 10,025' 60 1/22/1998 Open 3-3/8" r 13,172' 13,192' 10,022' 10,025' 20 1/21/1998 Open 3-3/8" 13 13,172' 13,192' 10,022' 10,025' 20 12/17/1997 Open 3-3/8" t ii 13,260' 13,280' 10,036' 10,039' 20 4/26/2002 Open 2-7/8" FV 13,424' 13,446' 10,060' 10,063' 22 4/23/2002 Open 2-7/8" rk 13,446' 13,478' 10,063' 10,068' 32 4/23/2002 Open 2-7/8" s « ±13,478' ±13,488' ±10,068' ±10,069' 10 Future Future 2-7/8" 14 N ±13,488' ±13,508' ±10,069' ±10,072' 20 Future Future 2-7/8" ♦ ±13,508' ±13,528' ±10,072' ±10,074' 20 Future Future 2-7/8" ±13,646' ±13,666' ±10,090' ±10,093' 20 Future Future 2-7/8" ±13,714' ±13,734' ±10,100' ±10,102' 20 Future Future 2-7/8" , ±13,734' ±13,754' ±10,102' ±10,105' 20 Future Future 2-7/8" • ±13,818' ±13,833' ±10,055' ±10,117' 15 Future Future 2-7/8" FIV ±13,844' ±13,864' ±10,119' ±10,122' 20 Future Future 2-7/8" �Jt " 13,674' 13,694' 10,094' 10,100' 20 2/16/1998 Open 3-3/8" @12'992 ' aTi 13,694' 13,714' 10,097' 10,097' 20 2/15/1998 Open 3-3/8" _' 13,870' 13,890' 10,123' 10,126' 20 2/15/1998 Open 3-3/8" Caliper Restriction p 13,890' 13,910' 10,126' 10,130' 20 2/15/1998 Open 3-3/8" 5.13"ID @13,881' 8/18/2013 T., Endicott Sands FIll 14210 14,300' 10,178' 10,176' 90 9/25/1997 Open 4-1/2" GENERAL WELL INFO SAFETY NOTE: 7%s ,. t,'t API:50-029-21921-02-00 H2S Reading average 230 to 260 PPM on A/L& " Initial Completion by Doyon 15 -3/25/1989 Gas Injectors. Well requires a SSSV.Well Angle> TD=14,430(MD)/TD=10,212'(TVD) Sidetrack(END 2-46A)by Doyon 15 -1/28/1997 70 Deg.@ 12,777'-4-1/2"Chrome Tubing. PBTD=14,326'(MD)/PBTD=10,196'(TVD) Sidetrack(END 2-46B)by Doyon 15 -9/28/1997 See Perf Table for Add Dates GLV C/O-12/9/2011 Created By:TDF 2/22/2016 • 0 L. / 30 �� ,� 01 991 2,12/1/1'9, 4)> 2-22 3/25/1989 6 • ---______�\ 2,•0 2-16 6/11/1'\ o1.135 11/11/1988 , 41 2-4 -3 109997 2-50 19/1993 2-58 •""—— 1018/1986 �� 4/2 - / 2-48 // /�� —�{y .. A --. • 995 re / 1 2-4. �N 11/27/1997 111111111"111111.1111111111111111 — 11 i4111t• ,' 7/9/1990 ——.' 2-5 . r ' ''. /I 9/1.1987j 3/1/1 9/20/198 2-60 1/111994 - SAG DELTA 034_ 19 s 1123/1977 All 1-4 7/10/198 El HILCORP ALASKA LLC / . ALASKA NORTH SLOPE:ENDICOTT UPSZ FIV AOR MAP POSTED WELL DATA Well Number 1-67 WELL-SPUD_DATE 11/13/1989 2-66 ft 1-69 WELL SYMBOLS 7/25/199 3/311990 • Active 011 ' 2-40 Dan 1/4/1995 O Location • f Shmm On X P&A Oil SWO 1-51 1 Temporarily Abandoned 3/21/1993 1 /J)\ %ug Back U INJ Well(Water Flood) Shutinlnjector Wet•r • INJ Welleaslnjector) • Idea-BP REMARKS Well symbol el lop of UP.FIV Sana Red Dashes SZ F_1,W p mtlius from proposetl UPS•FN S FV pertorelions In MPI 2J6B gs(We/Open parts In Black Proposed pens m rad InaclrvelAbentloned Perla in pink 1 DDD z oOO FEET February 19.2016 • • RECE;V re. Post Office Box 244027 ry ft Anchorage,AK 99524-4027 Hilcorp Ajaska,LLC ,JUL 3 0 201' 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster -/51 rJ Alaska Oil & Gas Conservation Commission i // 333 West 7th Avenue, Suite 100 � Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request 'CANNED 4(U( 9 201p Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I"followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/134" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp I • I Orig • New API WeIlNo PermitNumber WeilName I WellNumber I WeliNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/011 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/513 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-17B 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: D Grayscale, halftones, pictures, graphs, charts- Pages: n Poor Quality Original'- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type -OVERSIZED n .Logs of various kinds Other Complete COMMENTS: [3 Scanned by: Bever~j Mitdred-Daretha ~oweli , TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: /s/ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 _ Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Q ,37 i s-r3 Mr. Jim Regg 1 ' n � Alaska Oil and Gas Conservation Commission 1 L `� 333 West 7 Avenue ,� - Anchorage, Alaska 99501 C� Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/28/2012 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 END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2-08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0 -16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0 -19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME -01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0-14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN-01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 ___--TEND2 -46B / 8-13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0 -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / 1.1-10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 50 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Point Mclntyre Unit 4. Location of well at surface 8. Well number 31' FNL, 4081' FEL, Sec. 14, T12N, R14E, UM (asp's 681435, 5998548) P2-17 At top of productive interval 9. Permit number / approval number 3486' FNL, 3450' FEL, Sec. 07, T12N, R15E, UM (asp's 692083, 6000641) 198-137 At effective depth 10. APl number 3560' FNL, 3469' FEL, Sec. 07, T12N, R15E, UM (asp's 692067, 6000566) 50-029-22902-00 At total depth 11. Field / Pool 3463' FNL, 3362' FEL, Sec. 07, T12N, R15E, UM (asp's 692170, 6000665) Point Mclntyre Oil Pool 12. Present well condition summary Total depth: measured 16086 feet Plugs (measured) Tagged PBTD @ 15923' (11/11/1999) true vertical 9200 feet Effective depth: measured 15923 feet Junk (measured) true vertical 9120 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 118' 20" Driven 118' 118' Surface 6599' 10-3/4" 1773 sx CS III, 820 sx 6637' 4824' Class 'G' Production 16003' 7-5/8" 350 sx Class 'G' 16053' 9184' RECEIVED Perforation depth: measured Open Peris 15700' - 15730', 15740' - 15775' true vertical Open Peris 9010'- 9025', 9030'- 9047' APR ~ :[ Z00 _ Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR TBG @ 15630'. ~ Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Perm Packer @ 15574'. 4-1/2" Camco Bal-O Nipple @ 2010'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/20/2002 Well Shut-In Subsequent to operation 03/05/2002 795 652 1172 668 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is tru,,,e and correct to the best of my knowledge. ~~~~~ Title: TechnicalAssistant Date March 28, 2002 DeWayne R. Schnorr ~.~ Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE P2-17 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/16/2002 PERFORATING: DRIFT/TAG 02/17/2002 PERFORATING: DRIFT/TAG 02/23/2002 PERFORATING: PERFORATING 02/16/02 EVENT SUMMARY DRIFT TBG W/10' 3-3/8" DUMMY GUN, TEL & SAMPLE BAILER TO 15820' WLM (STUCK IN HOLE) -- CONTINUED ON 02/17/02 WSR 02/17/02 CONTINUED FROM 02/16/02 WSR -- FLOW WELL IN ATTEMPT TO FREE UP TOOL -- POOH W/3-3/8 DG, SB, & TEL (SB EMPTY) ****LEFT WELL SHUT IN**** O2/23/O2 COMPLETED ADPERF. SHOT 15' INTERVAL (15,760'- 15,775') IN ZONES LC4/LC3 WITH 3-3/8" POWER JET, 6 SPF, RANDOM ORIENTED, 60 DEG. PHASED GUN. WELL WAS SHOT UNDER BALANCED (WH PRESS. @ 750 PSI). WELL WAS TURNED BACK TO DSO TO POP. FLUIDS PUMPED BBLS 1 DIESEL FOR PRESSURE TESTING SURFACE PRESSURE CONTROL EQUIP 1 TOTAL 02/23/2002 ADD PERFS THE FOLLOWING INTERVAL WAS PERFORATED USING THE 3-3/8" POWER JET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 15760'-15775' Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _× Plugging _ Perforate _X ADD P£RFS / ACIDIZI: Puli tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 56 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Duck Island Unit / Endicott 4. Location of well at surface 8. Well number 2045' FNL, 2306' FEL, Sec. 36, T12N, R16E, UM (asp's 258898, 5982375) 2-46B/S-13 At top of productive interval 9. Permit number / approval number 1416' FNL, 3348' FEL, Sec. 35, T12N, R16E, UM (asp's252599, 5983209) 197-137 At effective depth 10. APl number 1398' FNL, 3374' FEL, Sec. 35, T12N, R1 CE, UM (asp's 252570, 5983234) 50-029-21921-02 At total depth 11. Field / Pool 1209' FNL, 3492' FEL, Sec. 35, T12N, R16E, UM (asp's 252460, 5983338) Endicott Field/Endicott Oil Pool 12. Present well condition summary Total depth: measured 14372 feet Plugs (measured) Tagged TD @ 14218' (04/22/2001) true vertical 10202 feet Effective depth: measured 14218 feet Junk (measured) true vertical 10179 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 71' 30" Driven 110' 110' Surface 2459' 13-3/8" 2772 cf Permafrost 2498' 2492' Intermediate 7118' 9-5/8" 575 cf Class 'G' 7157' 7069' Liner 7398' 7" 448 cf Class 'G' 6973' - 14371' 6914' - 10202' Perforation depth: measured Open Perfs 13132'-13212', 13226'-13246', 13260' - 13280', 13424' - 13478', 13674'-13714', 13870'-13910', 14210'-14300' true vertical Open Perfs 10017'-10028', 10030'-10033', 10036'- 10039', 10060'- 10068', 10094'-10100', 10123'-10130', 10178'-10192' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, NSCT 13-CR-80 TBG @ 11501' MD. '.'"'-' ' ' ,'- ~'" ~ ~..~' '..'~- ~; "~ Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 11446'. 4-1/2" HES 'HXO' SSSV Landing Nipple @ 1505' MD. 13. Stimulation or cement squeeze summary . Intervals treated (measured) (see attached) ;~-~.~,'~f.~" ' I...~?~.. ~.~ Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 04/20/2002 188 2411 294 285 Subsequent to operation 04/28/2002 558 2390 1116 289 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~~~,~~~~ Title: Technical Assistant Date April 291 2002 DeWayne R. $chnorr Prepared by DeWar/ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 04/11/2002 O4/22/2OO2 04/23/2002 O4/24/2OO2 O4/25/2OO2 O4/26/2OO2 04/11/02 O4/22/O2 04/23/02 2-46B/S-13 Description of Work Completed NRWO OPERATIONS PERFORATING: DRIFT/TAG; SSSV C/O OR STROKE PERFORATING: PERFORATING; PRODUCTION PROFILE W/ DEFT PERFORATING: ACID TREATMENT; PERFORATING; PRODUCTION PROFILE W/DEFT PERFORATING: ACID TREATMENT; PERFORATING PERFORATING: ACID TREATMENT; PERFORATING PERFORATING: ACID TREATMENT; PERFORATING SUMMARY DRIFTED TUBING TO TOP OF SSSV @ 1467' WITH A 3.85" SWEDGE, PULLED BBE SSSV # BB 4-48, DRIFTED TUBING INTO LINER UNTIL STOPPED BY DEVIATION AT 12915' CORRECTED ELM. DRIFTED TUBING OUT OF TAIL WITH A 3.5" DUMMY GUN - ALL CLEAR. WELL POP. MIRU UNIT #3. MU AND RIH WITH PROD LOGS AND DEFT. LOG PASSES @ 30, 60, AND 80 FPM. TAGGED UP @ 14218 ON INITIAL 60 FPM PASS. LOG REMAINING PASSES FROM 13050 - 14218. MAKE STOP COUNTS. SI WELL. LOG FROM 13,500 TO 12,900' @ 30 FPM. FLAG PIPE @ 12900'. POOH. DOWN LOAD DATA. POOH W/P-PROF. DOWN LOAD DATA AND UNABLE TO MAKE GOOD CORRELATION. RE-RUN CCL/GR OVER LONGER INTERVAL (14000 - 11400). FLAG PIPE @ 12905 CTMD. POH. MU AND RIH WITH GUN 1 (26'). PERF 13446 - 13478 WITH 2-7/8" HSD GUNS WITH 29PJ06 HMX CHARGES AT 4 SPF WITH 60 DEGREE PHASING AND RANDOM ORIENTATION. POOH. MU GUN #2 (22'). PERF 13424 - 13446 WITH 2-7/8" HSD GUNS WITH 29PJ06 HMX CHARGES @ 4 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. POOH. FOUND CRACKS IN FLUID END/SWAP OUT PUMPS. <<< JOB IN PROGRESS>>> 04/24/02 04/25/02 04/26/02 PROBLEMS WITH PUMP WAITING ON CEMENT PUMP, PUMP ON LOCATION AT 0200. TCP HAND ON G-PAD BREAKING DOWN GUNS , WAITING ON HIM. MIRU DS CTU#3. PERFORM WEEKLY BOP TEST. RIH WITH 1-11/16" PDS MEM GR/CCL TOOLS. LOG FROM 12800'-14000' - PAINT FLAG AT 13200' CTDM. GOOD MEM DATA - CALL OUT PERFORATORS. RIH WITH GUN #3, SWS 2-7/8" HSD, 6 SPF. DEPTH CORRECT TO FLAG & SHOOT INTERVAL FROM 13260'-13280'. POOH. 3.5" JS NOZZLE. PUMP WELL KILL. PUMP 25 BBLS 90:10 DAD ACID 12%: TITRATION12.1%; IRON<50PPM. SOAK FOR 20 MINUTES. FLUSH W/SEAWATER. POOH. CHANGE PACKOFFS. RDMO. <<<PAD OPR NOTIFIED --WELL LEFT FLOWING>>> Page 1 2-46B/S-13 Description of Work Completed NRWO OPERATIONS Fluids Pumped 1 DIESEL FOR SURFACE EQUIP PRESSURE TEST (1 DIFFERENT TESTS) 121.3 METHANOL WATER 138 60/40 METHANOL WATER 474 SEAWATER 25 90:10 DAD ACID 12%: TITRATION12.1%; IRON<50PPM. 305 C - H20 1064.3 TOTAL 4/23 & 26/2002 ADD PERF SUMMARY THE FOLLOWING INTERVALS WERE PERFORATED USING 2-7/8" HSD 29PJ06 HMX CHARGES, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 13424'-13478' 13260'-13280' Page 2 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001. M P L E ATE IA L U N D W E R TH IS M ARK ER C:LORBMFILM.DOC AOGCC Geological Materials Inventory PERMIT 9 7- ! 3 7 BP EXPLORATION Log Data. Sent Recieved Box 8153 '~PE'RRY MPT/GRfEWR4/CNP/SLD 10/22/97 10/22/97 DGR/CNP/SLD-MD ~5-14366 11/5/97 11/5/97 DGR/CNP/SLD-TVD ~: 10202 11/5/97 11/5/97 JWL-GR/CCL /.Mff280-14320 It 12J> Jt'l ~ 11/2/1909 12/3/97 MWD SRVY ~Y 7100.30-14366. 11/7/97 11/20/97 NGP/DGR/EWR4-MD ,~-14366 11/5/97 11/5/97 NGP/DGR/EWR4-TVD gYt(fi~-10202 /.t ~.///~ 11/5/97 11/5/97 l PERF/GR/CCL ~..A-.t'2~0-14320 ill~tl I~vI 11/2/1909 12/3/97 t.k0~07 Completion Date q/'~ ~/~ ~' ~)¢ Daily well ops ,~-//'2~ ~,/~?.. ~/~ Are dry ditch samples required? yes jno And received?~,~.~.e., s..~_~_~ no Was the well cored? yes 7;'.'.'.'.'.'.'.'.~ no Analysis _description recieved?:.~..y.e&~, no Are tests required? yes ~,~ no Received? ~_.-.-J~-~s--,~--"~n° ./ Well is in compliance Initial Comments Thursday, September 23, 1999 Page I of 1 MEMORANDUM TO: THRU: Blair Wondzeti, P. I. Supervisor FROM: Chuck Scheve, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 29, 1998 FILE NO: aavkc3fe. DOC SUBJECT: BOPE Test Nordic 2 KRU 1D-117 PTD 97-237 Sunday March 29 1998: I traveled to ARCOs KRU 1D Pad to witness the initial BOPE Test on Well 117 being completed by Nordic Rig 2. As the attached AOGCC Test Report shows the test lasted 3.4 hours and there were no failures. The test went reasonably well considering the testris broken down. The Rig was clean and sporting a new paint job in several areas. All related equipment appeared to be in good condition. ~ SUMMARY: I witnessed the initial BOPE test on Nordic Rig 2 completing ARCOs KRU 1D-117 Well. Nordic 2, 3129/98, Test Time 4 hours, 0 Failures Attachments: aavkc3fe.xls X Unclassified Classified Unclassified with Document Removed STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report 3/29198 659-7115 OPERATION: Drlg: Workover: X DATE: Drlg Contractor: Nordic Rig No. 2 PTD # g7-237 Rig Ph.# Operator: ARCO Rep.: Mark Chambers Well Name: 1D-117 Rig Rep.: Lance Johnson Casing Size: Set @ Location: Sec.~ T. R. __Meridian Umiat Test: Initial X Weekly Other MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign NO Drl. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 P 250/2500 1 250/3,000 P N/A N/A N/A 1 250/3,000 P I 250/3,000 P I 250/3,000 P 2 250/3,000 P N/A N/A N/A MUD SYSTEM: V*~ual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP 1 Lower Kelly / IBOP 1 Ball Type 1 Inside BOP I Test Pressure P/F 250/3,000 P 250/3,000 P 250/3,000 P 250/3,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 250/3,000 P 30 250/3,000 P P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Cloe' ;~e 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 30o0I 2000 minutes 18 sec. 1 minutes 35 sec. Yes Remote: Yes 4 bottels at 2200 Psig. Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested '18 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper./Rig c - Database c - Tdp Rpt File c- Inspector Ft-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve ALASi~.. OIL AND CONSERVATION COMMIS,O~"W REPORT (, ;SUNDRY WELL OP,..,'iATIONS 1. Operations performed: Operation shutdown__ Pull tubing Stimulate.---- Plugging__ Perforate X Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 2045' SNL, 2306' WEL, SEC 36, T12N, R16E, UPM At top of productive interval 1416' SNL, 3348' WEL, SEC. 35, T12N, R16E, UPM At effective depth 1398' SNL, 3374' WEL, SEC. 35, T12N, R16E, UPM At total depth 1290' SNL, 3492' WEL, SEC. 35, T12N, R16E, UPM 5. Type of Well: Development .. Exploratory ~ Stratigraphic ~ Service 6. Datum elevation (DF or KB) KBE = 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-46B/S- 13 9. Permit number/approval number 97-137/not recluired 10. APl number 50- 029-21921-02 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14372' feet 10202' feet 14210' feet 10121' feet Plugs (measured) Junk (measured) feet Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 71' 30" Driven 110' 110' Surface 2459' 13 3/8" 2772 C.F. Permafrost 2498' 2492' Intermediate 7118' 9-5/8" 575 c.f. Class 'G' 7157' 7069' Production 7398' 7" 448 c.f. Class 'G' 6973'-14371' 7011'-10202' Liner Perforation depth: measured 13132'- 13192? 13192'- 13212? 13226'- 13246'; 13674'-13714'; 13870'-13910'; 14210'-14300' (afl open) true vertical Subsea 9960'-9969'; 9969'- 9972'; 9974'- 9977'; 10038'-100437 10067'-100737 10121'- 10135' (afl open) Tubing (size, grade, and measured depth) 4 1/2" 12.6# NSCT 13 CR 80 Tubing to 11502' Packers and SSSV (type and measured depth) 7" Baker S-3 Packer (3.875" I.D.) set to 11446' 13. Stimulation or cement squeeze summary Add perforations (1/21/98) CTU add perforations (2/16/98) Intervals treated (measured) Treatment description including volumes used and final pressure see attached 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 844 434 844 0 692 779 1129 0 Tubing Pressure 268 289 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations. 16. Status of well classification as: Oil X Gas Suspended Service 17. I here~_y..certify th~at/t~,f~oregoing,~is true and correct to the best of my_knowledge. Signed ~('-~ ' ~~/~~/~~-f/f~.~( ~ Title~eniorTechnin~14.~.~i.~t~nt IV lev 06/15/88 Form 10-4~4j: ' ! U/ Date 3/10/98 SUBMIT IN DUPLICATE WSA- Well Operations Telex To: From: Operation: Date: Cost Code: Anchorage Engineering Luecker Endicott 2-46 CT CONVEYED GR/CCL LOG and Perf Operation Jan. 21, 1998 727014 Summary RIH with PDS's GR/CCL memory tool. Did not tag TD. Logged from flag at 13200 to 12700. Log was within 1' of MWD log of 9-8-97. POOH and pick up SW 2 7/8" 6 spf HSD gun. 34j charges. Flag was placed at 13200 on CT counter while logging; this would place the hydraulic disconnect at 13190.6' Caught flag and pulled up to 13167 placing gun #1 at 13172-13192 interval. Gun deployed after ball on seat with 31 bbl and sheared at 2600 psi. Laid down for night and continued on next day. Perforated the remaining 40' of interval with same guns in two more runs. Total perf interval was 13132-13192 reference MWD logs of Sept, 97. Time Operation 1/21 08:00 Safety meeting. 09:30 Press lest 4000. 23:40 RIH. FWHP-250, FWHT-115, lAP-1300, OAP-0. 12:31 At 13386, start logging out @ 50 fpm, stop and flag pipe at 13200 and 12700. 15:04 OOH, have data from PDS. CCL to Hyd disconnect-9.4' SWS on location. 15:48 Safety meeting with SWS, pick up gun #1, a 20' 2 7/8", 6 spf, 60 degree phased, random oriented HSD gun loaded wth deep penetrating charges. Top shot to Hyd Dis.-5.1'. 16:28 Pressure test 2500, RIH 17:13 Received logs back from PDS, amazing PDS log is within 1' of MWD log of 9-8-97. Hyd disconnect is 13190.6' when at flag. 18:58 Catch flag @ 13222, reset depth to 13190.6'. Drop 5/8" ball. 19:12 Start pumping ball, pull up to 13167. 19:46 30 bbls away 2600 ps~ gun deployed, POOH. 22:03 OOH, swab leaking, s/I well. All shots fired, LDFN. 1122 07:00 Safety meeting. 7:42 FWHT-102, FWHP-300, lAP-1200, OAP-0, press test 2500. 8:17 RIH with gun #2, same as gun #1. 10:43 Catch flag, set depth to 13190.6, drop ball, pull to 13147 placing gun across 13152-13172interval 11:29 Gun deployed with 33 bbl @ 1400. POOH. 13:30 OOH, wait on crew changeout. 17:40 Safety meeting. 18:24 Pick up gun #3, sme as #1, PT 2500, RIH. 20:49 Catch flag, reset to 13190.6', pull to 13127 placing gun across 13132-13152 interval, drop ball. 21:37 31 bbl away, gun deployed, POOH. 23:32 OOH, RD, secure well. I B BLS- 100 BHA #1 Tool string Description Fishing Neck Check Valve Hydraulic Disconnect IFluid Summary Diesel J O.D. II IILength 2.125" 1.92" J 1.37' 2.125" .812 1.36' 2.125" .687 1.55 Comments Endicott 2-46B CT Conveyed Perf, 03/10/98 Crossover 2.125" .35' Crossover 2.125" .50' P DS Toolstring 1.875" 7.83 G R/CCL cci to disconnect 9.4' BHA #2,3 and 4 Tool string Description II O.D. II ~.D. II Length II Comments Fishing Neck 2.125" .92" 1.37' Check Valve 2.125" .812 1.36' Hydraulic Disconnect 2.125" .687 1.55 Baker crossover 2.125 .27' SWS x/o and firing head 2.125" 4.20 5/8" ball 2 718" gun 2.875" 20.59 Endicott 2-46B CT Conveyed Perf, 03/10/98 BPX Endicott Production Engineering Department WSA- Well Operations Telex To: From: Well: Operation: Date: Cost Code' Detail Code: Endicott Production Engineering Engler / Bundy End 2-46B / S-13 CT Add Perfs 02113-16/98 AFE No. 727014 9335-070-735 Summary Pebruary 13, 1998- MI DS CTU #2. Wind speed to high to raise mast (>35 mph). WO wind to die down. February 14, 1998- Raise mast. PT to 4000 psi. Function test BOP's- test OK. MU lubricator. Stab lubricator. Motor on block winch leaking hydraulic fluid. No spill occurred. Set down injector head and LD mast for repairs. Repairs made. MU lubricator- 33'. MU PDS logging string (BHA#1). RIH. Logged tie-in CCL/GR, flagged pipe. POH. Flag corrected to 13,877'. February 15, 1998 Made three gun runs. Perforated the following; Run #1 - 13,890' to 13,910' (20'), Run #2 - 13,870' to 13,890' (20'), Run #3 - 13,694' to 13,714' (20% MU Gun #4. PT lubricator. Triplex pump would not disengage- pressure on lubricator 5000 psi. SD pump w/emergency shut down. Bleed off pressure. Coil collapsed during PT. February 16, 1998 Cut 24' coil. Change flag depth by 24'. MU new Coil BHA and perf gun (BHA #6). RIH. Perforate interval from 13674- 13694'. POOH. Break down tools. RD. MO DS CTU #2. End 2-46B Add Perfs Page 2 Time Operation 02113 0100 MI DS CTU #2 w/15,070 ft. 1.75" CT (CT Vol. = 34.4 bbls). WJnd speed >35 mph- cannot raise mast. WO wind to die down. 02/14 0600 Raise mast. Stab BOP's. 0815 Finish RU. PT to 4000 psi- held ok. Prepare to test BOP's. 0900 Finish BOP test. Test OK. Break off lubricator. 0920 Start PU lubricator. Block winch on trolley leaking hydraulic fluid. SD & order manlift to look @ problem. 1100 Have to lay down mast to work on winch motor. Wrap motor to avoid spilling hydraulic fluid. Lay mast down. Call out mechanic to fix motor leak. 1500 Repairs made. Raise mast. MU lubricator. 1530 MU coil connector- Pull test to 20 k lbs. P-I connector- did not hold. Change O-rings in tool string. 1630 MU logging tools (103.5" from CCL sensor to top of tool string + 8" X-overs to btm of hydraulic disconnect). Stab lubricator. 1645 PT lubricator to 4000 psi. Held OK. Open swab (17 turns). Fusible installed. Initial Well Status FWHP lAP OAP FLP FLT GLP (psig) (psig) (psig) (psig) (deg F) (psig) Flowing 225 250 0 225 90 Time Depth Rate CTP WHP Stg Remarks BPM vol. 1646 0 0 100 220 10/0 RIHwithBHA#1. Diesel 1750 5000 0 0 245 Weight chk = 8.3 k lbs. 1800 5925 0 0 250 IA= 200 psi, OA= 0 psi. 1845 10007 0 0 270 Weight chk = 20 k lbs. 1915 12100 0 0 265 Weight chk = 22.4 k lbs. 1935 14050 0 0 255 Stopped at 14050'. Paused. PUH logging CCL/GR. 1940 13900 0 0 250 Flag pipe at 13,900'. Continue PUH logging to 13,700'. 1955 13700 0 0 250 POH 2215 surf 0 0 260 At surface 2245 surf Rig down logging toolstring. 2315 surf Safety Meeting to discuss gun handling. 2325 surf Rig up perforating assembly - BHA #2 (20' - 3 3/8" gun). 2355 surf 2 / 0 PT lubricator, via backside, to 4000 ps~g. Diesel 2/15/98 I Time Depth Rate CTP WHP Stg Remarks BPM vol. 0025 surf 0 - 280 Open swab. RIH with BHA #2 (Gun Run #1). 0215 12000 0 - 255 Weight Check - 19,500# 0240 13877 0 - 250 At flag (bottom of disconnect). Set counter depth @ 13,877' based on PDS tie-in log (Reft to Sperry Sun ROP/NGP/DGR/EWR - 9/21/97) 0300 13877 0 - 260 Launch ball 0307 13885 0 - 260 RI H to 13,910'. PUH to shoot depth - 13,885'. Disconnect to top shot = 5'. (Top Shot- 13,890' ... Bottom Shot- 13,910') 0308 13885 1.8 260 0 Start pumping ball 0320 13885 0.6 65 250 27 Slow pump rate 0337 13885 0.6 250 36 Ball on seat. 0339 13885 1400 250 38 / 0 Pressure up, fired gun. Diesel 0342 13885 0 - 250 POH, pulling 26.5k 0615 surf 0 - 260 At surface, Gun #1 - all shots fired. End 2-46B Add Perfs Page 3 0630 surf 0 Safety Meeting / Crew change. Break down Gun #1, MU Gun #2 0725 surf 0 2 / 0 PT lubricator to 4000 ps~g Diesel 0730 surf 0 - 280 Open swab. RIH with BHA #3 (Gun Run #2). 0825 5519 0 - 280 Weight chk = 11.0 k lbs. 0920 10511 0 - 280 Weight chk = 17.5 k lbs. 1000 13959 0 - 280 Weight chk = 21.0 k lbs. Ran past flag for stretch. PU to flag. 1010 13927 0 - 280 At flag. Reset depth to 13877'. 1012 13877 0 - 280 RIH to position reel to drop ball. 1014 13898 0 - 280 Drop ball. 1020 13898 0.92 0 280 0.77 Start displacing ball. Pull up to shooting depth. 1025 13865 1.3 90 280 5.65 At shooting depth. Up ball displacement rate to 1.5 bpm. 1035 13865 1.5 205 290 25.3 Circulating ball on seat. 1037 13865 0.65 20 300 28.8 Reduce rate for ball seat. 1045 13865 0.6 875 291 31.25 Ball on seat. Begin pressure up. 1046 13865 0.65 1100 290 31.5 Fired gun. 1048 13865 0 0 270 33 / 0 Come off pump. POOH. Pulling 24.5 k lbs. Diesel 1155 8411 0 - 270 Continue POOH. 1300 0 0 - 300 Tools @ surface. Close swab (17 turns). Bleed offwell pressure. 1301 Safety meeting prior to unstabbing lubricator. 1305 Unstab lubricator. Gun #2 - all shots fired. Break down gun. 1310 2 / 0 MU Gun #3. Stab lubricator. PT. Diesel 1345 0 265 Open swab. lAP = 1300 psi. OAP = 0 psi. RIH with BHA#4 (Gun #3). 1530 6200 0 270 Weight chk = 12.5 k lbs. 1610 0 - 270 Weight chk = 17.0 k lbs. 1645 13930 0 - 290 At flag. Reset depth to 13877'. Pulling 21.0 k lbs. 1646 13877 0 - 290 Pull up to position reel to drop ball. 1655 13848 0 - 265 Drop ball. Come online w/pump to displace ball @ 1.5 bpm until 28 bbls away- then slow rate to 0.6 bpm until ball seats. 1700 13763 1.4 130 250 4.8 PUH to shooting depth. 1702 13689 1.4 150 260 6.7 At shooting depth. Continue circ ball down. 1723 13689 0.65 30 265 31.8 Ball on seat. Begin pressure up. 1725 13689 0.65 1400 280 32.7 Fired gun. 1726 13689 0 - 270 33 / 0 Come off pump. POOH. Pulling 25.5 k lbs. Diesel 1925 surf At surface, Gun #3 - all shots fired. Break down gun. 2030 surf 2 bbl Make up Gun #-4. Stab lubricator. PT. ! riplex pump would not Diesel disengage during PT, pressured up to 5000+ psig before emergency shut down was hit to shut down pump. 2100 surf Break down gun to inspect for flooding prior to RIH. Gun is dry. Stab back on to well. Make up hydraulic line from DS pump to handle backside PT. 2200 surf PT lubricator. Pressure bled down rapidly when pump was shut down. Lubricator and accessories held pressure while pump was rolling, possibly swab not holding from top. No external leaks. 2205 surf 0 - 280 Open and close swab (17 turns -good). RIH with BHA#5 (Gun Run #-4). 2315 5000 0 - 260 After lengthy discussion on possible causes of pressure fall off during lubricator PT ..... 3 scenarios were developed ... 1. Swab leaking from top down (original theory), 2. Check valves leaking back to coil (coil is void of fluid so no pressure indications on coil), 3. Coil connector leaking due to damage during PT. Worse case scenario #3 is of most concern. Elect to POH. Will fully inspect, change out Baker tools, cut coil and re-head. 2355 surf 0 - 250 At surface. Close swab, master and w~ng. 2/16/98 End 2-46B Add Perfs Page 4 Time Depth Rate CTP WHP Stg Remarks BPM vol. 0010 surf 26 bbl Break down tools. Found collapsed coil immediately above connector Diesel (approx. 6"). Cut 24' coil. Made up complete new Baker hookup. Pull tested to 20k. PT Baker tools to 3500 psig. NEW FLAG DEPTH = 13,853' (13,877'-24') 0115 surf Make up gun (BHA #6). Grease swab and master. 0150 sud 2 bbl Stab on well. Thaw hoses. PT lubricator to 2000 psig. Diesel 0250 surf 0 - 260 Open master and wing. Well back on production. Open swab. RIH with BHA #6 (Gun Run #4). 0405 6300 0 - 270 Weight check - 15.0k 0445 10300 0 - 260 Weight check - 20.5k 0520 13853 0 - 260 At flag, set depth at 13,853' (new depth) 0530 13718 0 - 260 Position reel to launch ball, launch 0535 13669 0 - 260 PUH to shooting depth at 13,669' (Top Shot - 13,674'). Weight - 26k 0536 13669 1.5 250 260 0 Pump ball 0552 13669 0.5 30 260 28 Slow rate 0554 13669 0.5 60 260 30 Ball on seat 0555 13669 0.5 1730 260 32 Pressure up - fire gun 0557 13669 0 - 250 POOH. 0820 0 0 - 35 / 0 Tools @ surface. Unstab lubricator. Gun #.4- all shots fired. LD Diesel perf guns. 0900 Begin RD. 1130 MO location. Final Well Status FWHP I lAP OAP FLP FLT GLP (psig)I (psig) (psig) (psig) (deg F) (psig) Flowing 250 I 1300 0 250 95 Fluids Pumped BBLS. Description MeOH 185 Diesel 2% KCI water 185 Total Fluids Pumped End 2-46B Add Perfs Page 5 BHA Summary BHA #1: PDS Mem Log-GR/CCL Tool String Descriptions O.D. I.D. Length Comments Baker CT connector 2.25 1.0 1.38 Baker Dual check valves 2.25 1.0 1.37 Baker Hyd disconnect 2.25 1.1875 1.56 0.75" ball ×O sub 1.1/2" MT Box X 1" MT pin 2.125 0.625 0.71 Blank Ported Sub XO sub 1" MT pin X %" sucker rod 2.125 0.625 0.50 5.52 Baker Total PBS Coiled TBG connection 1.875 1.83 Battery Holder 1.875 1.54 Memory Section 1.875 1.90 Gamma Ray 1.875 2.21 CCL Tool 1.875 1.54 Bull Plug 1.875 0.50 9.52 PDS Total NOTE: 9.3 ft. from CCL sensor on PDS tool to btm of hydraulic disconnect. 15.04 Total Toolstring BHA #2: SWS 20' Perf Gun Assmbly Tool String Descriptions O.D. I.D. Length Comments Baker CT connector 2.25 1.0 1.38 Baker Dual check valves 2.25 1.0 1.37 Baker Hyd disconnect 2.25 1.1875 1.56 0.750" ball XO sub 1.112" MT Box X 1.75" 6 P p~n 2.125 0. 0.27 'CBF' Firing Head/×O 2.125 4.20 0.625" ball 3 3/8" HSD Deep Penetrating 3.375 21.27 Top Shot to Bottom of Baker Disconnect = 5.14' Total 30,05' BHA #3,4,5,6: SWS 20' Perf Gun Assmbly Tool String Descriptions O.D. I.D. Length Comments Baker CT connector 2.25 1.0 1.38 Baker Dual check valves 2.25 1.0 1.37 Baker Hyd disconnect 2.25 1.1875 1.56 0.750" ball XO sub 1.1/2" MT Box X 1.75"6 P pin 2.125 0. 0.27 'BCF' Firing Head / XO 2.125 - 3.63 0.625" ball 3 3/8" HSD Deep Penetrating 3.375 - 21.27 Top Shot to Bottom of Baker Disconnect = 4.57' Total 29.48' End 2-46B Add Perfs Page 6 Perforation Summary Gun Top Int. Bott Int. Size/Type SPF Orientation Phasing 1 13890 13910 3-3/8" 6 Random 60 deg 2 13870 13890 3-3/8" 6 Random 60 deg 3 13694 13714 3-3/8" 6 Random 60 deg 4 13674 13694 3-3/8" 6 Random 60 deg Interval Summary' Notes: IITD - NOT Tagged Charges' Ref. Log: 13,674'- 13,714' (40') 13,870' - 13,910' (40') 34B HSD Deep Penetrating Sperry Sun MWD- GR log dated 9121/97. STATE OF ALASKA ALASK~..,-O. IL AND GAS CONSERVATION COMMISSI'--- REPORT O. SUNDRY WELL OPE, ATIONS 1. Operations performed: Operation shutdown__ Stimulate X Plugging__ Pull tubing__ Alter casing __ Repair well Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.(Te, Alaska 99519-6612 4. Location of well at surface 2045' SNL, 2306' WEL, SEC 36, T12N, R16E, UPM At top of productive interval 1416' SNL, 3348' WEL, SEC. 35, T12N, R16E, UPM At effective depth 1398' SNL, 3374' WEL, SEC. 35, T12N, R16E, UPM At total depth 1290' SNL, 3492' WEL, SEC. 35, T12N, R16E, UPM 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14372' feet 10202' feet 14210' feet 10121' feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Structural BKB Conductor 71' 30" Driven 110' Surface 2459' 13 3/8" 2772 C.F. Permafrost 2498' Intermediate 7118' 9-5/8" 575 c.f. Class 'G' 7157' Production 7398' 7" 448 c.f. Class 'G' 6973'- 14371' Liner Perforation depth: measured 13192'- 13212'; 13226'- 13246'; 14210;14300' (afl open) 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-46B/S- 13 9. Permit number/approval number 97-137 10. APl number 50~ 029-21921-02 11. Field/Pool Endicott Field/Endicott Pool R CE V D Alaska 0ii & Gas Cans. Commissior~ AnchCrage True vedical depth BKB 110' 2492' 7069' 7011'-10202' true vertical Subsea 9969'- 9972'; 9974' - 9977'; 10121' - 10135' (all open) Tubing (size, grade, and measured depth) 4 1/2" 12.6# NSCT 13 CR 80 Tubing to 11502' Packers and SSSV (type and measured depth) 7" Baker S-3 Packer (3.875" I.D.) set to 11446' 13. Stimulation or cement squeeze summary Bullhead stimulation 12/7/97, add perforation 12/17/97. Intervals treated (measured) Treatment description including volumes used and final pressure see attached ORI61NAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3 396 252 0 939 218 346 0 Tubing Pressure 254 275 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil × Gas Suspended Service 17. I here~by~certify that/th~foregoing is. true and correct to the best of my knowledge. Form 10-4¢¢4 Rev 06/15/88 Date 1/23/98 SUBMIT N DUPLICAT,,~.~ Page 1 BPX Endicott Production Engineering Department DATE: 12/7197 Well 2-46b/S-13 Operation: Bullhead Stimulation BP Rep: McBride Service Company: DowelI-Schlumberger DATE/TIME OPERATIONS SUMMARY 1217197 The bullhead treatment did not seem deliver any major results. A slight increase in injectivity was noted while sqzing pill into formation. Formation was tight from the beginning and we were forced to pump the bulk of the job over frac gradient to push our t fluids into the reservoir. The clean sweep consisted of 9450 Gallons of: ~ 800 gpt A26 Xylene I I I 100 gpt U66 Mutual Solvent ! 100 gpt L401 Stabilizing agent I Total fluids pumped were: 20 BBLs diesel I 225 BBLs of Clean Sweep Pill ! 445 BBLs FSW i 10 BBLs Meoh TIME RATE BPM PUMPING SUMMARY PUMPi STAGE CUM PSIG BBL BBL COMMENTS WELLBORE DISPLACEMENT = 275 BBLS 0800 Hold Safety meeting with Atlas and Dowell 0815 Begin rigging up Dowell Surface equipment 0910 Pressure test to 4000 psig 0915 Come on line with FSW- establish rate 0935 3 1830 52 52 0947 3 1900 85 85 3 2100 133 133 Well beginning to pressure up. Bumped fluid likely 1013 1.4 2180 146 146 Still building pressure 1022 1.6 2180 155 155 Drop rate 1035 1.2 2130 175 175 1039 1.0 2130 179 179 1107 .5 2115 200 , 200 Tried to be nice and stay under frac grad. Time , to go to work. 2 1132 2.0 2.0 2('- 'j T-210 210 220 27001 T-10 2900 10 3450 30 3450 60 3750 100 3750 120 376O 150 3750 T-225 3780 T-10 3800 30 3280 3280 3280 3280 3600 35 3700 40 374O 70 3730 100 3800 110 3780 120 3740 130 3740 140 3780 150 3720 160 1137 2.0 230 1151 2.0 250 1203 1.3 Blow off rest of fi~. .,rage of loading tbg. Switch to Diesel spacer. Diesel away - switch to Clean Sweep solution 250 Back down rate 1226 1.7 290 Seawater is entering perfs 1238 1.4 310 1256 1.7 340 1349 1.4 415 Out of Pill - Switch to diesel 1356 1.4 425 Switch to FSW 1427 1.0 475 Leading diesel at perfs. Shut down and monitor WHP. 1429 1433 1437 1444 SIWHP steady. Come on line and sqz diesel into perfs, above frac gradient 1450 1.4 480 1500 1.6 485 Pill entering perfs 1513 1.6 515 1531 1.7 545 1536 2.0 555 1542 2.0 565 1547 2.0 575 Small decrease in injection pressure noted 1551 2.0 585 1556 2.2 595 1601 2.0 605 1605 2.0 3700 170 615 1610 2.0 3700 180 625 1615 2.0 3690 190 635 1620 2.0 3700 200 645 No sign of any increase in injectivity 1625 2.0 3700 210 655 1635 2.0 3700 230 675 1645 2,0 3700 T - 245 690 Shut down SW and switch to MEOH 1648 2.0 3650 T - 10 700 Shut down and monitor. Leading edge of final diesel 10 bbls from perfs. 1649 3420 1650 3122 1652 3100 Begin Rig down and move off location. Flag well to remain SI for 24 hours. 1815 2900 Final reading for the night. BPX Endicott Production Engineering Department DATE: 12/17-/97 WELL N°: 2-46b/S-13 BP EXPLORATION REP: SERVICE COMPANY: ADD-PERFORATION w/TRACTOR D. Varble ATLAS (L. Koenn) DATE/TIME 12117 . 0930 12/18 1040 1100 1200 1245 1335 1342 1344 1353 1500 1540 1730 1758 1800 1915 1945 1100 1200 1310 1340 1420 1453 1505 1630 1745 1830 OPERATIONS SUMMARY Miru AWS. FWHP= 300 psig. lAP= 1180 pslg. OAP= 0 psig. Safety meeting - - arm Gun #1. Running Guardian system - no need for radio silence. Shut in well & Rih wi Tractor/PFC/& Gun #1 (3-3/8"x 20' HSC, Alpha Jet, 21.0 gm charge, 6 spf). Distance from CCL to TS= 4'. Set down (~ 12500'. Tractor down to 13400' md. Log tie in pass. ¥ie into GR-CCL dated 11/20/97. +4'. Tractor down for confirmation pass. (flag line) Log confirmation pass. On depth. Log into place & hang CCL @ 13168' md. Shoot gun # 1 form 13172'-13192' md. No cap break or weight change. Re- shoot. No luck. POOH OOH. Fuses blown on EBW package (Guardian). Repair. RIH with same. Sat down (~ 12760' md. Tractor down hole. At flag. Short in line, lost all signal to tools. POOH. OOH. Short not in the line. Somewhere in tool string. RDFN. Will repair tools & try again tomorrow. Rig up AWS RIH with tractor tool I PFC / 3-3~8" gun. Lost tool signal (~ approx. 9500' md. Trouble shoot. Appears to be a short in line. POOH. Regained signal @ approx. 1800' md. All tools appear to be working. RIH. CCL quit working. Trouble shoot. Tractor down to 13000' md. Short in line. Best guess is somewhere around 3000' from cable head. POOH. OOH RDMO PERFORATION SUMMARY: Unable to successfully complete a perforating run due to problems with new line on truck. Rigged off well and will finish job'with coil tubing unit unless AWS can pinpoint the problem with the new line. State oT Alaska Alaska Oil & Gas Conservation Comm. Atten' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to' Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 17-Dec-97 :,iWell Name ~ NO-11 :12-46 B/S-13 Services Bluelines R/F Sepia Film GR/CCL PERF 1 1 GR/CCL PERF 1 1 0 "-' 'i~eEeived REC ,-, u DEC '! 9 '1997 Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. Stat~ of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 28-Nov-97 Well Name Services Bluelines R/F Sepia Film ~?-- o'~ [ 2-44 A/Q-11 GR/CCL PERF 1 1 0 STATIC SURVEY 1 1: 0 2-44 A/Q- 11 2-44 A/Q- 11 .2-46 B/S-13 2-46 B/S- 13 GR/CCL JEWELRY LOG 1 1 0 !~ GR/CCL PERF 1 1 0 i GR/CCL JEWELRY LOG 1 1 0 ' Receive~~ Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION NOV' 20 199 ' WELL COMPLETION OR REOOMPLETION REPORT AND LOG Alaska Oi is~..11 1, Status of Well Classification of Service W(J~I1CJI01'a~ ....... J~ Oil J--J Gas J--J Suspended [] Abandoned J--J Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-137 397-157 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21921-02 .... . 4. Location of well at surface i ; :... :~ ~ . 9. Unit or Lease Name 2045' SNL, 2306' WEL, SEC. 36, T12N, R16E, UPM: q/~'~"/;~..~O-lr:( ? i ! ~; ~.~:~ ] Duck Island Unit/Endicott At top of productive interval 1416' SNL, 3348' WEL, SEC. 35, T12N, R16E, UPM i~._ Vi,~i?~ !?j$~__~__~_ ~ '.,I "~;~ .~...;_~,~~.~ 10. Well Number 2-466/S-1 3 At total depth ! ' ' ;; ~. 11. Field and Pool 1290' SNL, 3492' WEL, SEC. 35, T12N, R16E, UPM Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) J c. Lease Designation and Serial No. KBE = 56.10'J ADL 034633 12. Date Spudded8/27/97 J 13' Date T'D' Reached j 14' Date C°mp" Susp" °r Aband'J15' Water depth' ? °fish°re 116' N°' °f c°mploti°ns9/20/97 9/28/97 6 - 12' MSLI One 17. Total Depth (MD+TVD) J18. Plug Back Depth (MD+TVD)J19. Directional Survey J20. Depth where SSSV set J21. Thickness of Permafrost 14372 10202 FTJ 14340 10198 FTJ J~Yes J--JNoJ 1505' MD J 1465' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 110' - Driven 13-3/8" 68# NTSOCYHE Surface 2498' 17-1/2" 2772 c.f. Permafrost 9-5/8" 47# NTSOS Surface 7157' 12-1/4" 575 c.f. Class 'G' 7" 29# L-80 6973' 14371' 8-1/2" 448 c.f. Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 5 spf 4-1/2", 12.6#, 130R80 11502' 11446' MD TVD MD TVD 14210'-14300' 10177'-10191' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH JNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 14 bbls diesel 27. PRODUCTION TEST ~'~ Date First Production I Method of Operation (Flowing, gas lift, etc.) U 1% t t~ I 1~1/'[ L September 30, 1997 J Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure '.CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. ~4-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 130. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Kekikt u k 13118' 10014' Fill 14178' 10172' FPDW 14299' 10191' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that th~..~_,~g ~,~,~~rect to the best of my knowledge ///,/,~//~ Signed ~. SteveShultz . Title Senior Drilling Engineer Date 2-46B/S-13 "" v 97-1'1'1~7 397-157 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27-' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 BPX Endicott Production Engineering Department CUT TBG FOR SIDETRACK DATE: 7/16/97 WELL N°: 2-46A/R-10 BP EXPLORATION REP: SERVICE COMPANY: R. Clump SWS (J. Pawluk) DATE/TIME OPERATIONS SUMMARY 1230 MIRU SWS. WHP= 250 psi, IAP= 0 psi, & OAP= 0 psi. GLM station #2 is open pocket. 1400 Safet~ meeting. Call for radio silence. Arm chemical cutter. 1450 Rih w/CCL & 3-5/8" Chemical Cutter. Distance from CCL to severing head= 9'. Overall tool string length= 23'. 1600 Log tie-in strip from coil fish to GLM g2. Tied into Tubing Summary from completion (+14'). 1620 Log confirmation strip. 1630 Tag fish @ 8344' drillers depth. Log into CCL firing position @ 8279' (8288' severing head depth). Fire cutter. Good indications at tree. Log off and POOH. Cut tbg at the middle ofjt above jt with coil fish top, which is seven full jts below GLM station #2. 1730 OOH. No problems w/anchors. Severing head shows chemical expelled from all holes. Half of head has %" gap. Release radio silence. RDMO SWS. SUMMARY: Cut tbg @ 8288' drillers depth. Middle of first full jt above jt w/coil tbg fish. Seven full jts below GLM Station #2. Will need to bleed WHP to 0 psi and set BPV to be ready for upcoming sidetrack. SSSV: OUT Facility End MPI Progress Report Well 2-46B/S-13 Rig Doyon 15 Page Date 1 28 October 97 Date/Time 17 Aug 97 18 Aug 97 19 Aug 97 20 Aug 97 01:30-06:00 06:00-06:30 06:30-07:00 07:00-09:30 09:30-10:30 10:30-13:30 13:30-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-20:00 20:00-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-14:00 14:00-14:30 14:30-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-23:30 23:30-00:00 00:00-02:00 02:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-11:30 11:30-14:00 14:00-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-01:00 01:00-02:30 02:30-03:00 03:00-04:00 04:00-05:30 Duration 4-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr liar 3hr lhr lhr 1/2 hr 2hr 1/2 hr 1-1/2 hr 4hr 1/2 hr 1/2 hr 1/2hr 1/2 hr 1/2 hr lhr 1/2 hr lhr lhr 1/2 hr 7-1/2 hr 1/2 hr 1/2 hr lhr 2hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr lhr 1/2 hr 2hr 2hr 1/2hr 1-1/2 hr 1/2hr lhr 1-1/2 hr 2-1/2 hr 2-1/2 hr lhr 1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr lhr 3hr 1-1/2 hr 1/2 hr lhr 1-1/2 hr Activity Rig moved 90.00 % Held safety meeting Skid rig Fill pits with Brine Retrieved Hanger plug Circulated at 8315.0 ft Installed Hanger plug Rigged down Surface tree Removed Adapter spool Rigged up All functions Held safety meeting Rigged up All functions Tested All functions Rigged up Lubricator Removed Hanger plug Rigged down Lubricator Flow check Retrieved Tubing hanger Circulated at 8315.0 ft Flow check Rigged up Tubing handling equipment Laid down 500.0 ft of Tubing Held safety meeting Laid down 8275.0 ft of Tubing Rigged down Tubing handling equipment Installed Wear bushing Rigged up Drillstring handling equipment Made up BHA no. 1 Held safety meeting Made up BHA no. 1 Serviced Block line R.I.H. to 8315.0 ft Fished at 8344.0 ft Flow check Pulled out of hole to 2698.0 ft Pulled BHA Serviced Top drive Made up BHA no. 2 Held safety meeting R.I.H. to 2697.0 ft R.I.H. to 8286.0 ft Fished at 8286.0 ft Pulled out of hole to 2698.0 ft Pulled BHA Serviced Drillfloor / Derrick Made up BHA no. 3 Held safety meeting R.I.H. to 8286.0 ft Fished at 8286.0 ft Pulled out of hole to 640.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 2246.0 ft R.I.H. to 8286.0 ft Facility End MPI Progress Report Well 2-46B/S-13 Rig Doyon 15 Page Date 2 28 October 97 Date/Time 21 Aug 97 22 Aug 97 23 Aug 97 05:30-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-12:30 12:30-14:00 14:00-15:00 15:00-15:30 15:30-17:00 17:00-18:00 18:00-18:30 18:30-21:00 21:00-22:30 22:30-00:00 00:00-00:30 00:30-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-10:30 10:30-12:00 12:00-14:30 14:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-21:30 21:30-23:00 23:00-01:00 01:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:30 09:30-11:30 11:30-13:00 13:00-14:30 14:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-22:30 22:30-01:30 01:30-06:00 06:00-06:30 06:30-10:00 10:00-11:00 Duration 1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 2hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr lhr 1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr lhr lhr 2hr 1-1/2 hr 2-1/2 hr 1-1/2 hr lhr lhr 1/2 hr lhr 1/2 hr 1-1/2 hr 1-1/2 hr 2hr 2hr lhr 2hr 1/2 hr 1/2 hr 1-1/2 hr lhr 2hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 3hr 4-1/2 hr 1/2 hr 3-1/2 hr lhr Activity Milled Tubing at 8286.0 ft Held safety meeting Pulled out of hole to 2245.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 7259.0 ft Serviced Block line R.I.H. to 8288.0 ft Fished at 8291.0 ft Circulated at 8291.0 ft Held safety meeting Pulled out of hole to 2727.0 ft Pulled BHA Made up BHA no. 6 Serviced Top drive R.I.H. to 8287.0 ft Fished at 8287.0 ft Pulled out of hole to 3500.0 ft Held safety meeting Pulled BHA Made up BHA no. 7 R.I.H. to 8290.0 ft Washed over string at 8307.0 ft Pulled out of hole to 2245.0 ft Pulled BHA Made up BHA no. 8 R.I.H. to 6042.0 ft Held safety meeting Serviced Block line R.I.H. to 8287.0 ft Fished at 8287.0 ft Circulated at 8287.0 ft Pulled out of hole to 2230.0 ft Pulled BHA Laid down fish Made up BHA no. 9 Held safety meeting Made up BHA no. 9 R.I.H. to 8344.0 ft Washed over string at 8378.0 ft Pulled out of hole to 2248.0 ft Pulled BHA Made up BHA no. 10 R.I.H. to 8377.0 ft Washed over string at 8405.0 ft Pulled out of hole to 7000.0 ft Held safety meeting Pulled out of hole to 2281.0 ft Pulled BHA Tested BOP stack Installed Cement retainer Held safety meeting Ran Drillpipe in stands to 7460.0 ft Circulated at 7460.0 ft Facility End MPI Progress Report Well 2-46B/S-13 Rig Doyon 15 Page Date 3 28 October 97 Date/Time 24 Aug 97 25 Aug 97 26 Aug 97 11:00-11:30 11:30-12:00 12:00-13:30 13:30-14:30 14:30-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-22:30 22:30-23:00 23:00-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-18:00 18:00-18:30 18:30-23:30 23:30-00:00 00:00-01:30 01:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-09:30 09:30-12:00 12:00-14:00 14:00-15:00 15:00-16:00 16:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-22:30 22:30-23:30 23:30-01:30 01:30-02:30 02:30-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-10:00 10:00-11:30 11:30-12:00 12:00-13:00 13:00-18:00 18:00-18:30 Duration 1/2 hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr lhr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 4hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2hr 10-1/2 hr 1/2 hr 5hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr lhr 1/2 hr 1/2 hr 2hr 1/2 hr 2-1/2 hr 2hr lhr lhr 1-1/2 hr 1/2 hr 1/2 hr lhr lhr 2hr lhr 2hr lhr lhr lhr 1/2 hr lhr 1/2 hr 1/2 hr 2hr lhr 1-1/2 hr 1/2 hr lhr 5hr 1/2 hr Activity Pulled out of hole to 6885.0 ft Circulated at 6685.0 ft Pulled out of hole to 2213.0 ft Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 6690.0 ft Serviced Block line Held safety meeting Ran Drillpipe in stands to 7360.0 ft Circulated at 7360.0 ft Circulated at 7360.0 ft Pulled out of hole to 0.0 ft Made up BHA no. 11 R.I.H. to 5000.0 ft Held safety meeting R.I.H. to 7256.0 ft Circulated at 7155.0 ft Milled Casing at 7197.0 ft Held safety meeting Milled Casing at 7205.0 ft Circulated at 9205.0 ft Circulated at 9155.0 ft Pulled out of hole to 741.0 ft Pulled BHA Circulated at 0.0 ft Held safety meeting Made up BHA no. 12 R.I.H. to 7200.0 ft Circulated at 9200.0 ft Circulated at 9155.0 ft Pulled out of hole to 733.0 ft Pulled BHA Made up BHA no. 13 R.I.H. to 7131.0 ft 'No Milled Casing at 7205.0 ft Held safety meeting Milled Casing at 7253.0 ft Circulated at 7253.0 ft Pulled out of hole to 733.0 ft Pulled BHA Ran Drillpipe in stands to 7253.0 ft Circulated at 7253.0 ft Mixed and pumped slurry - 45.000 bbl Pulled Drillpipe in stands to 6293.0 ft Reverse circulated at 6293.0 ft Monitor pressures Held safety meeting Circulated at 6293.0 ft Pulled Drillpipe in stands to 0.0 ft Ran Drill collar in stands to 372.0 ft Pulled out of hole to 0.0 ft Serviced Draw works Serviced Block line Repaired Draw works Held safety meeting Progress Report Facility End MPI Well 2-46B/S- 13 Rig Doyon 15 Page 4 Date 28 October 97 Date/Time 27 Aug 97 28 Aug 97 29 Aug 97 30 Aug 97 31 Aug 97 01 Scp 97 18:30-00:00 00:00-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-10:30 10:30-12:00 12:00-16:30 16:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-02:00 02:00-03:00 03:00-06:00 06:00-06:30 06:30-11:00 11:00-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-14:00 14:00-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-22:00 22:00-00:00 00:00-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-13:00 13:00-13:30 13:30-15:30 15:30-18:00 18:00-18:30 18:30-20:30 Duration 5-1/2 hr 3hr 1-1/2 hr lhr 1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3hr lhr 3-1/2 hr lhr 3hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 5hr 1/2 hr 11-1/2 hr 1/2 hr 7-1/2 hr 1-1/2 hr lhr 1/2 hr lhr 1/2 hr 3-1/2 hr 2hr 1-1/2 hr 2hr lhr 1-1/2 hr 1/2 hr 3hr 3-1/2 hr 1/2 hr 2hr 2-1/2 hr 1/2 hr 2hr Activity Repaired Draw works Made up BHA no. 14 R.I.H. to 1142.0 ft Tested MWD - Via string Pulled BHA Held safety meeting R.I.H. to 2000.0 ft Tested MWD - Via string R.I.H. to 6226.0 ft Washed to 6760.0 ft Drilled cement to 7157.0 ft Drilled to 7159.0 ft Held safety meeting Drilled to 7279.0 ft Held safety meeting Drilled to 7480.0 ft Held safety meeting Drilled to 7774.0 ft Held safety meeting Drilled to 8200.0 ft Held safety meeting Drilled to 8290.0 ft Circulated at 8290.0 ft Pulled out of hole to 2519.0 ft Pulled BHA Tested BOP stack Held safety meeting Made up BHA no. 15 R.I.H. to 8206.0 ft Washed to 8290.0 ft Drilled to 8380.0 ft Held safety meeting Drilled to 8820.0 ft Held safety meeting Drilled to 9189.0 ft Circulated at 9189.0 ft Pulled out of hole to 7157.0 ft R.I.H. to 9189.0 ft Drilled to 9200.0 ft Held safety meeting Drilled to 9285.0 ft Rig waited · Assessed situation Rig waited · Equipment Circulated at 9285.0 ft Pulled out of hole to 7110.0 ft Repaired Main engine Held safety meeting Repaired Main engine Rig waited · Orders R.I.H. to 8200.0 ft Circulated at 8200.0 ft Pulled out of hole to 4428.0 ft Held safety meeting Pulled BHA RECEIVED Na~ka Oil & Gas Cons. ~{)' Anchorage Facility End MP! Progress Report Well 2-46B/S- 13 Rig Doyon 15 Page Date 5 28 October 97 Date/Time 02 Sep 97 03 Sep 97 04 Sep 97 05 Sep 97 06 Sep 97 07 Sep 97 08 Sep 97 09 Sep 97 20:30-21:30 21:30-01:30 01:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-12:00 12:00-12:30 12:30-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-22:30 22:30-23:30 23:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-12:30 12:30-14:00 14:00-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-01:00 01:00-06:00 06:00-06:30 06:30-18:00 Duration lhr 4hr 4-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr 1/2 hr 10hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 2hr 3hr 1/2 hr 4hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 2hr lhr lhr 6-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 6hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1/2 hr lhr lhr 4-1/2 hr 5hr 1/2 hr 11-1/2 hr Activity Made up BHA no. 16 R.I.H. to 9285.0 ft Drilled to 9375.0 ft Held safety meeting Drilled to 9670.0 ft Held safety meeting Drilled to 10172.0 ft Held safety meeting Pulled out of hole to 9090.0 ft R.I.H. to 10172.0 ft Drilled to 10715.0 ft Held safety meeting Drilled to 10895.0 ft Held safety meeting Drilled to 11065.0 ft Held safety meeting Pulled out of hole to 10142.0 ft R.I.H. to 11065.0 ft Drilled to 11192.0 ft Held safety meeting Drilled to 11310.0 ft Held safety meeting Drilled to 11435.0 ft Held safety meeting Flow check Pulled out of hole to 6057.0 ft Pulled BHA Retrieved Wear bushing Tested All functions Installed Wear bushing Repaired SCR Made up BHA no. 17 Held safety meeting Made up BHA no. 17 R.I.H. to 7100.0 ft Serviced Block line R.I.H. to 11435.0 ft Drilled to 11545.0 ft Held safety meeting Drilled to 11745.0 ft Held safety meeting Drilled to 11858.0 ft Held safety meeting Drilled to 11943.0 ft Circulated at 11943.0 ft Pulled out of hole to 7278.0 ft Pulled BHA Held safety meeting Made up BHA no. 18 Held safety meeting R.I.H. to 11943.0 ft Drilled to 11975.0 ft Held safety meeting Drilled to 12121.0 ft Progress Report Facility End MPI Well 2-46B/S- 13 Rig Doyon 15 Page 6 Date 28 October 97 Date/Time 18:00-18:30 18:30-06:00 10Sep 97 06:00-06:30 06:30-18:00 18:00-18:30 18:30-22:30 22:30-23:00 23:00-01:30 11 Sep 97 01:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-11:30 11:30-12:30 12:30-18:00 18:00-18:30 18:30-06:00 12 Sep 97 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 13 Sep 97 06:00-06:30 06:30-07:30 07:30-09:00 09:00-11:00 11:00-14:30 14:30-15:00 15:00-17:45 17:45-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-22:30 22:30-23:30 23:30-02:30 14 Sep 97 02:30-03:00 03:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 15 Sep 97 06:00-06:30 06:30-14:30 14:30-16:30 16:30-18:00 18:00-18:30 18:30-21:00 21:00-22:30 22:30-23:30 23:30-00:00 16 Sep 97 00:00-04:00 04:00-04:30 Duration 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 4hr 1/2 hr 2-1/2 hr 2-1/2 hr lhr lhr 1/2hr lhr 1/2 hr 3-1/2 hr lhr 5-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr lhr 1-1/2 hr 2hr 3-1/2 hr 1/2 hr 2-3/4 hr 1/4 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr lhr 3hr 1/2 hr 3hr 1/2 hr 11-1/2 hr 1/2hr 11-1/2 hr 1/2 hr 8hr 2hr 1-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr lhr 1/2 hr 4hr 1/2 hr Activity Held safety meeting Drilled to 12290.0 ft Held safety meeting Drilled to 12410.0 ft Held safety meeting Drilled to 12450.0 ft Circulated at 12450.0 ft Pulled out of hole to 7278.0 ft Pulled BHA Made up BHA no. 19 R.I.H. to 4000.0 ft Held safety meeting Serviced Block line Serviced Draw works R.I.H. to 12244.0 ft Reamed to 12450.0 ft Drilled to 12504.0 ft Held safety meeting Drilled to 12595.0 ft Held safety meeting Drilled to 12690.0 ft Held safety meeting Drilled to 12795.0 ft Held safety meeting Drilled to 12805.0 ft Circulated at 12805.0 ft Pulled out of hole to 5710.0 ft Pulled BHA Removed Wear bushing Tested All functions Installed Wear bushing Held safety meeting Made up BHA no. 20 Held safety meeting R.I.H. to 5949.0 ft Serviced Block line R.I.H. to 12706.0 ft Reamed to 12805.0 ft Drilled to 12833.0 ft Held safety meeting Drilled to 12894.0 ft Held safety meeting Drilled to 12972.0 ft Held safety meeting Drilled to 13028.0 ft Circulated at 13028.0 ft Pulled out of hole to 10000.0 ft Held safety meeting Pulled out of hole to 1600.0 ft Pulled BHA Made up BHA no. 21 Serviced Top drive R.I.H. to 12965.0 ft Reamed to 13028.0 ft REi EIV NOV Naska Oil & Gas Cons. Anchorage D Facility End MPI Progress Report Well 2-46B/S- 13 Rig Doyon 15 Page Date 7 28 October 97 Date/Time 17 Scp 97 18 Sep 97 19 Scp 97 20 Sep 97 21 Sep 97 22 Scp 97 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-01:30 01:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-09:00 09:00-18:00 18:00-18:30 18:30-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-11:00 11:00-14:00 14:00-16:00 16:00-18:00 18:00-18:30 18:30-23:30 23:30-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-11:00 11:00-12:00 12:00-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-21:00 21:00-22:00 22:00-00:30 00:30-01:00 Duration 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr lhr 2hr 4hr 2-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 8-1/2 hr 1/2hr 11-1/2 hr 1/2 hr 1/2hr 1/2 hr 1-1/2 hr 9hr 1/2 hr 7-1/2 hr 2hr 2hr 1/2 hr 1-1/2 hr 2hr lhr 3hr 2hr 2hr 1/2 hr 5hr 6-1/2 hr 1/2 hr 2-1/2 hr lhr lhr lhr 3hr 3hr 1/2 hr 1/2hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 1/2hr Activity Drilled to 13058.0 ft Held safety meeting Drilled to 13346.0 ft Held safety meeting Drilled to 13550.0 ft Held safety meeting Drilled to 13732.0 ft Held safety meeting Circulated at 13732.0 ft Pulled out of hole to 9511.0 ft Pulled BHA Made up BHA no. 2526 Serviced Block line Serviced Top drive R.I.H. to 5000.0 ft Held safety meeting R.I.H. to 13637.0 ft Washed to 13732.0 ft Drilled to 13870.0 ft Held safety meeting Drilled to 14075.0 ft Held safety meeting Drilled to 14082.0 ft Serviced Top drive Repaired Main engine Drilled to 14208.0 ft Held safety meeting Drilled to 14366.0 ft Circulated at 14366.0 ft Pulled out of hole to 10247.0 ft Held safety meeting Pulled out of hole to 7150.0 ft R.I.H. to 1688.0 ft Washed to 14366.0 ft Circulated at 14366.0 ft Pulled out of hole to 9513.0 ft Pulled BHA Held safety meeting Pulled BHA Ran Casing to 5077.0 ft (7in OD) Held safety meeting Ran Liner to 7122.0 ft (7in OD) Singled in drill pipe to 7122.0 ft Ran Liner to 7393.0 ft (7in OD) Circulated at 7393.0 ft Ran Drillpipe in stands to 14372.0 ft Circulated at 14372.0 ft Held safety meeting Circulated at 14372.0 ft Mixed and pumped slurry - 80.000 bbl Displaced slurry - 80.000 bbl Reverse circulated at 6988.0 ft Pulled Drillpipe in stands to 0.0 ft Retrieved Wear bushing Facility End MPI Progress Report Well 2-46B/S- 13 Rig Doyon 15 Page Date 8 28 October 97 Date/Time 23 Sep 97 24 Sep 97 25 Sep 97 01:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-13:00 13:00-15:30 15:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-02:00 02:00-03:30 03:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-16:00 16:00-18:00 18:00-18:30 18:30-22:30 22:30-01:30 01:30-02:30 02:30-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-12:00 12:00-13:30 13:30-14:30 14:30-15:00 15:00-15:30 15:30-17:00 17:00-18:00 18:00-18:30 18:30-01:30 01:30-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-10:30 10:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 Duration 3hr 1/2 hr 1-1/2 hr 1/2 hr 3hr lhr 2-1/2 hr 2-1/2 hr 1/2 hr lhr lhr 1/2 hr lhr lhr 5-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 2hr 2hr 1/2 hr 1/2 hr 1/2hr 2hr 2hr 1/2hr 4hr 3hr lhr 3hr 1/2 hr 1/2 hr lhr 4-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 7hr 4-1/2 hr 1/2 hr 2hr lhr lhr 7hr 1/2 hr 1/2hr 1/2 hr Activity Tested BOP stack Installed Wear bushing Ran Drillpipe in stands to 5235.0 fi Held safety meeting Laid down 5235.0 fi of 5in OD drill pipe Serviced Block line Ran Drillpipe in stands to 6988.0 ft Functioned Tie back packer Tested Tie back packer - Via annulus Reverse circulated at 6972.0 ft Pulled Drillpipe in stands to 3500.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 23 Singled in drill pipe to 7471.0 ft R.I.H. to 14171.0 fi Washed to 14266.0 fi Tested Liner Drilled to 14430.0 ft Held safety meeting Circulated at 14430.0 ft Pulled out of hole to 7470.0 ft Pulled out of hole to 302.0 ft Pulled BHA Serviced Drillfloor / Derrick Made up BHA no. 24 R.I.H. to 7465.0 ft R.I.H. to 14430.0 fi Held safety meeting Circulated at 14430.0 fi Circulated at 14340.0 ft Cleared Flowline Reverse circulated at 14340.0 fi Cleared Trip tank Held safety meeting Cleared Trip tank Pulled out of hole to 308.0 ft Pulled BHA Serviced Block line Serviced Draw works Held safety meeting Rigged up sub-surface equipment - TCP Ran Drillpipe in stands to 4450.0 fi Held safety meeting Ran Drillpipe in stands to 14311.0 ft Pulled Drillpipe in stands to 5000.0 fi Held safety meeting Pulled Drillpipe in stands to 440.0 fi Retrieved TCP Installed TCP Ran Drillpipe in stands to 14340.0 ft Functioned Retrievable packer Held safety meeting Perforated from 14210.0 ft to 14300.0 ft Facility End MPI Progress Report Well 2-46B/S-13 Page 9 Rig Doyon 15 Date 28 October 97 Date/Time 26 Sep 97 27 Sep 97 28 Sep 97 19:00-20:00 20:00-21:00 21:00-23:00 23:00-03:30 03:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-18:00 18:00-18:30 18:30-00:00 00:00-01:00 01:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-11:00 11:00-16:00 16:00-18:30 18:30-19:30 19:30-22:00 22:00-01:00 01:00-02:00 02:00-04:00 04:00-05:00 05:00-06:00 Duration lhr lhr 2hr 4-1/2 hr lhr lhr 1/2 hr 1/2 hr 1-1/2 hr 10hr 1/2 hr 5-1/2 hr lhr 2hr lhr 2hr 1/2 hr lhr lhr 2-1/2 hr 5hr 2-1/2 hr lhr 2-1/2 hr 3hr lhr 2hr lhr lhr Activity Reverse circulated at 14300.0 ft Monitor wellbore pressures Pulled Drillpipe in stands to 7419.0 ft Laid down 7262.0 ft of Drillpipe Retrieved Retrievable packer Retrieved TCP Rigged down Wear bushing Held safety meeting Rigged up Tubing handling equipment Ran Tubing to 5500.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 9995.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 11500.0 ft (4-1/2in OD) Installed Tubing hanger Circulated at 11500.0 ft Held safety meeting Reverse circulated at 11500.0 ft Ran Tubing to 11502.0 ft (4-1/2in OD) Circulated at 11502.0 ft Conducted slickline operations on Slickline equipment - Tool run Set packer at 11446.0 ft with 4000.0 psi Rigged down Hanger plug Removed BOP stack Installed Xmas tree Removed Hanger plug Freeze protect well - 14.000 bbl of Diesel Installed Hanger plug Skid rig SHARED SERVICES DRILLING ENDICOTT / 2-465/S-13 500292192102 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 SPEP~V-SUN DRILLING SERVICES PAGE DATE OF SURVEY: 092097 MWD SURVEY JOB NUMBER: AK-MM-70222 KELLY BUSHING ELEV. = 56.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7100.30 7022.59 6966.5 7160.00 7071.92 7015.9 7194.26 7099.90 7043.9 7223.79 7123.98 7067.9 7255.93 7149.85 7093.8 9 33 28 S 62.90 W .00 139.23S 477.23W 457.52 2 35 4 S 62.97 W 2.68 154.52S 507.16W 485.45 0 35 27 S 68.47 W 9.34 162.65S 525.18W 502.38 8 35 19 S 72.99 W 8.88 168.29S 541.31W 517.74 5 37 28 S 77.39 W 10.52 173.14S 559.74W 535.47 7284.44 7172.22 7116.2 7317.10 7197.16 7141.1 7349.23 7221.01 7165.0 7381.60 7244.24 7188.2 7414.01 7266.58 7210.5 2 39 12 S 81.57 W 10.95 176.36S 577.12W 552.35 6 41 13 S 85.79 W 10.36 178.66S 598.07W 572.89 1 42 58 S 89.67 W 9.76 179.50S 619.59W 594.15 4 45 17 N 87.35 W 9.61 179.03S 642.11W 616.58 8 47 34 N 85.55 W 8.10 177.57S 665.55W 640.02 7446.19 7287.88 7231.8 7478.75 7308.54 7252.5 7508.59 7326.56 7270.5 7603.84 7378.91 7322.9 7698.66 7427.05 7371.0 8 49 31 N 87.70 W 7.86 176.16S 689.62W 664.09 4 51 43 S 89.86 W 8.90 175.69S 714.77W 689.12 6 53 57 S 89.47 W 7.55 175.83S 738.55W 712.72 1 59 20 N 89.39 W 5.75 175.75S 818.08W 791.70 5 59 39 S 88.94 W 1.55 176.08S 899.76W 872.78 7795.94 7476.27 7420.2 7892.35 7525.16 7469.1 7986.58 7573.18 7517.1 8082.71 7622.25 7566.2 8177.83 7670.68 7614.6 7 59 33 S 88.48 W .42 177.97S 983.65W 955.86 6 59 29 S 88.54 W .09 180.13S 1066.71W 1038.10 8 59 13 S 87.91 W .64 182.64S 1147.75W 1118.27 5 59 23 S 87.16 W .69 186.19S 1230.34W 1199.87 8 59 23 S 86.78 W .34 190.52S 1312.09W 1280.54 8262.70 7714.04 7658.0 8359.60 7762.53 7706.5 8456.54 7809.28 7753.2 8551.53 7854.10 7798.1 8647.97 7898.74 7842.7 4 59 9 S 84.55 W 2.27 196.03S 1384.82W 1352.12 3 60 46 S 84.65 W 1.67 203.92S 1468.33W 1434.12 8 61 33 S 85.37 W 1.03 211.31S 1552.93W 1517.26 0 62 7 S 87.42 W 2.00 216.57S 1636.50W 1599.63 4 62 43 S 88.21 W .95 219.83S 1721.92W 1684.07 8742.64 7941.71 7885.7 8840.25 7985.46 7929.4 8935.22 8027.56 7971.5 9032.20 8071.23 8015.2 9127.84 8114.86 8058.8 1 63 17 S 87.50 W .91 222.99S 1806.22W 1767.41 6 63 26 S 87.27 W .26 226.97S 1893.38W 1853.50 6 63 55 S 86.66 W .77 231.48S 1978.39W 1937.39 3 62 32 S 87.63 W 1.69 235.79S 2064.86W 2022.75 6 63 10 S 85.98 W 1.67 240.54S 2149.83W 2106.57 9221.01 8156.20 8100.2 9308.44 8193.93 8137.9 9405.45 8235.49 8179.4 9500.26 8275.42 8219.4 9596.24 8316.33 8260.3 0 64 9 S 86.15 W 1.06 246.27S 2233.12W 2188.61 3 64 43 S 83.59 W 2.72 253.32S 2311.66W 2265.77 9 64 33 S 83.76 W .24 262.98S 2398.78W 2351.15 2 65 37 S 85.90 W 2.34 270.72S 2484.40W 2435.26 3 63 54 S 87.37 W 2.27 275.82S 2571.06W 2520.71 ORIGINAL SPEP~¥-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 2-46B/S-13 500292192102 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 MWD SURVEY JOB NUMBER: AK-MM-70222 KELLY BUSHING ELEV. = 56.00 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9692.04 8358.88 8302.88 9787.35 8402.07 8346.07 9883.21 8446.24 8390.24 9978.45 8491.03 8435.03 10075.30 8537.44 8481.44 63 21 S 88.70 W 1.37 278.77S 2656.83W 62 45 S 88.37 W .71 280.94S 2741.76W 62 22 S 88.84 W .59 283.01S 2826.81W 61 31 S 87.92 W 1.23 285.39S 2910.83W 61 12 S 87.79 W .36 288.57S 2995.77W 2605.54 2689.63 2773.85 2857.00 2940.98 10170.70 8583.74 8527.74 10268.54 8632.14 8576.14 10362.32 8679.49 8623.49 10457.07 8728.18 8672.18 10550.44 8777.37 8721.37 60 44 S 87.52 W .54 291.98S 3079.11W 59 57 S 87.53 W .81 295.65S 3164.06W 59 24 S 88.97 W 1.45 298.13S 3244.97W 58 44 S 88.15 W 1.03 300.17S 3326.22W 57 40 S 87.27 W 1.40 303.33S 3405.51W 3023.34 3107.26 3187.31 3267.76 3346.13 10647.44 8830.58 8774.58 10741.18 8883.20 8827.20 10837.30 8937.87 8881.87 10934.26 8995.13 8939.13 11028.94 9052.15 8996.15 55 46 S 86.03 W 2.22 308.06S 3486.45W 55 57 S 89.53 W 3.10 311.06S 3563.96W 54 42 S 89.29 W 1.31 311.88S 3643.01W 52 53 S 87.51 W 2.39 314.05S 3721.20W 53 2 N 89.50 W 2.53 315.36S 3796.75W 3425.95 3502.57 3580.97 3658.36 3733.23 11125.08 9111.08 9055.08 11220.23 9170.65 9114.65 11316.27 9229.96 9173.96 11417.91 9290.24 9234.24 11512.11 9343.97 9287.97 51 19 N 89.37 W 1.79 314.61S 3872.69W 51 9 N 88.76 W .53 313.40S 3946.87W 52 33 N 87.40 W 1.84 310.86S 4022.35W 54 40 N 87.28 W 2.09 307.06S 4104.08W 55 45 N 87.34 W 1.15 303.43S 4181.36W 3808.73 3882.55 3957.80 4039.40 4116.58 11607.75 9398.50 9342.50 11705.98 9453.67 9397.67 11802.11 9504.69 9448.69 11897.43 9551.91 9495.91 11991.90 9597.13 9541.13 54 43 S 89.79 W 2.69 301.74S 4259.91W 56 55 S 88.85 W 2.37 302.71S 4341.15W 58 58 S 86.41 W 3.03 306.10S 4422.54W 61 37 S 87.15 W 2.87 310.74S 4505.20W 61 10 S 85.83 W 1.32 315.82S 4587.99W 4194.77 4275.34 4355.76 4437.30 4518.91 12089.15 9644.43 9588.43 12185.75 9692.13 9636.13 12281.36 9739.64 9683.64 12378.04 9787.71 9731.71 12445.81 9819.85 9763.85 12473.98 9832.33 9776.33 12504.56 9845.37 9789.37 12537.51 9858.80 9802.80 12567.31 9870.40 9814.40 12601.25 9883.43 9827.43 60 36 S 86.78 W 1.04 321.30S 4672.78W 60 12 S 87.20 W .56 325.71S 4756.66W 60 12 S 86.49 W .64 330.28S 4839.50W 60 10 S 86.08 W .37 335.71S 4923.21W 63 12 S 89.76 W 6.55 337.85S 4982.81W 64 12 N 87.47 W 9.50 337.34S 5008.06W 65 20 N 84.69 W 9.02 335.45S 5035.66W 66 31 N 82.80 W 6.34 332.17S 5065.56W 67 41 N 81.07 W 6.63 328.31S 5092.73W 67 10 N 77.68 W 9.35 322.54S 5123.53W 4602.47 4685.25 4766.98 4849.47 4908.40 4933.54 4961.16 4991.24 5018.68 5049.94 SPE?~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING ENDICOTT / 2-46B/S-13 500292192102 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 MWD SURVEY JOB NUMBER: AK-MM-70222 KELLY BUSHING ELEV. = 56.00 OPER3ATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12634.07 9896.58 9840.58 12663.70 9908.56 9852.56 12696.30 9921.06 9865.06 12729.08 9933.07 9877.07 12776.90 9949.94 9893.94 65 34 N 75.66 W 7.45 315.61S 5152.78W 66 45 N 72.68 W 10.04 308.22S 5178.85W 68 8 N 70.16 W 8.30 298.62S 5207.38W 68 53 N 68.82 W 4.44 287.93S 5235.95W 69 47 N 66.51 W 4.90 270.93S 5277.33W 5079.81 5106.57 5136.03 5165.66 5208.75 12805.96 9959.54 9903.54 12839.72 9969.54 9913.54 12870.39 9977.34 9921.34 12901.87 9983.86 9927.86 12934.90 9989.47 9933.47 71 37 N 63.75 W 10.95 259.40S 5302.21W 73 55 N 61.32 W 9.68 244.52S 5330.81W 76 38 N 57.93 W 13.89 229.52S 5356.39W 79 26· N 56.86 W 9.53 212.93S 5382.33W 80 59 N 55.21 W 6.78 194.74S 5409.32W 5234.81 5264.97 5292.14 5319.85 5348.79 12968.88 9994.68 9938.68 12998.25 9998.76 9942.76 13032.46 10003.14 9947.14 13065.22 10007.36 9951.36 13094.99 10011.20 9955.20 81 22 N 51.72 W 10.21 174.76S 5436.30W 82 39 N 48.65 W 11.24 156.14S 5458.63W 82 37 N 45.96 W 7.80 133.13S 5483.57W 82 35 N 45.96 W .06 110.55S 5506.92W 82 35 N 46.34 W 1.26 90.10S 5528.21W 5377.93 5402.31 5429.78 5455.63 5479.17 13191.25 13286.99 13381.88 13477.49 13575.25 10024.61 9968.61 10039.69 9983.69 10054.26 9998.26 10067.42 10011.42 10080.23 10024.23 81 22 N 46.92 W 1.40 24.64S 5597.50W 80 29 N 47.64 W 1.19 39.49N 5666.95W 81 50 N 47.28 W 1.48 102.89N 5736.04W 82 19 N 48.22 W 1.10 166.56N 5806.13W 82 36 N 48.47 W .38 230.97N 5878.54W 5555.68 5632.21 5708.27 5785.37 5864.86 13671.62 13764.75 13860.71 13957.43 14051.43 10093.30 10037.30 10106.45 10050.45 10121.18 10065.18 10137.32 10081.32 10152.62 10096.62 81 47 N 48.24 W .88 294.42N 5949.89W 81 58 N 47.88 W .43 356.04N 6018.47W 80 21 N 47.97 W 1.69 419.57N 6088.85W 80 25 N 47.87 W .13 483.48N 6159.63W 80 49 N 48.20 W .55 545.50N 6228.59W 5943.18 6018.54 6095.91 6173.72 6249.50 14147.45 14242.05 14306.20 14366.00 10167.61 10111.61 81 12 10182.29 10126.29 80 55 10192.29 10136.29 81 7 10201.52 10145.52 81 7 N 48.40 W .45 608.59N 6299.40W N 48.73 W .45 670.43N 6369.46W N 48.79 W .32 712.20N 6417.11W N 48.79 W .00 751.13N 6461.56W 6327.25 6404.10 6456.33 6505.06 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6505.07 FEET AT NORTH 83 DEG. 22 MIN. WEST AT MD = 14366 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 276.76 DEG. TIE-IN SURVEY AT 7,100.30' MD WINDOW POINT AT 7,160.00' MD PROJECTED SURVEY AT 14,366.00' MD SPER~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING ENDICOTT / 2-46B/S-13 500292192102 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 JOB NUMBER: AK-MM-70222 KELLY BUSHING ELEV. = 56.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 7100.30 7022.59 6966.59 139.23 S 477.23 W 77.7 8100.30 7631.20 7575.20 186.94 S 1245.46 W 469.1 9100.30 8102.43 8046.43 238.82 S 2125.31 W 997.8 10100.30 8549.49 8493.49 289.41 S 3017.66 W 1550.8 11100.30 9095.60 9039.60 314.82 S 3853.34 W 2004.7 391.39 528.77 552.94 453.89 12100.30 9649.90 9593.90 321.84 S 4682.47 W 2450.4 13100.30 10011.88' 9955.88 86.46 S 5532.02 W 3088.4 14100.30 10160.40 10104.40 577.65 N 6264.56 W 3939.9 14366.00 10201.52 10145.52 751.13 N 6461.56 W 4164.4 445.69 638.02 851.48 224.59 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPEF~<¥-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING ENDICOTT / 2-46B/S-13 500292192102 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 4/97 DATE OF SURVEY: 092097 JOB NUMBER: AK-MM-70222 KELLY BUSHING ELEV. = 56.00 FT. 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 NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7100.30 7022.59 6966.59 139.23 S 477.23 W 77.71 7140.55 7056.00 7000.00 149.44 S 497.21 W 84.55 6.84 7263.72 7156.00 7100.00 174.09 S 564.44 W 107.72 23.17 7398.51 7256.00 7200.00 178.36 S 654.25 W 142.51 34.79 7560.46 7356.00 7300.00 175.99 S 781.25 W 204.46 61.95 7755.94 7456.00 7400.00 177.06 S 949.17 W 299.94 95.47 7952.99 7556.00 7500.00 181.58 S 1118.91 W 396.99 97.05 8149.00 7656.00 7600.00 189.13 S 1287.31 W 493.00 96.00 8346.22 7756.00 7700.00 202.84 S 1456.70 W 590.22 97.22 8555.60 7856.00 7800.00 216.73 S 1640.09 W 699.60 109.38 8774.46 7956.00 7900.00 224.23 S 1834.61 W 818.46 118.86 8999.17 8056.00 8000.00 234.58 S 2035.58 W 943.17 124.71 9220.55 8156.00 8100.00 246.24 S 2232.71 W 1064.55 121.38 9453.38 8256.00 8200.00 267.52 S 2441.86 W 1197.38 132.83 9685.61 8356.00 8300.00 278.64 S 2651.08 W 1329.61 '132.23 9904.25 8456.00 8400.00 283.39 S 2845.45 W 1448.25 118.63 10113.82 8556.00 8500.00 289.87 S 3029.50 W 1557.82 109.58 10316.12 8656.00 8600.00 297.34 S 3205.19 W 1660.12 102.30 10510.43 8756.00 8700.00 301.74 S 3371.72 W 1754.43 94.31 10692.68 8856.00 8800.00 310.08 S 3523.81 W 1836.68 82.25 10868.68 8956.00 8900.00 312.19 S 3668.62 W 1912.68 76.00 11035.35 9056.00 9000.00 315.31 S 3801.87 W 1979.35 66.67 11196.88 9156.00 9100.00 313.79 S 3928.69 W 2040.88 61.53 11359.10 9256.00 9200.00 309.32 S 4056.32 W 2103.10 62.22 11533.41 9356.00 9300.00 302.73 S 4198.93 W 2177.41 74.31 11710.28 9456.00 9400.00 302.80 S 4344.76 W 2254.28 76.87 11906.03 9556.00 9500.00 311.12 S 4512.76 W 2350.03 95.75 12112.72 9656.00 9600.00 322.45 S 4693.28 W 2456.72 106.69 12314.28 9756.00 9700.00 332.02 S 4868.02 W 2558.28 101.56 12530.49 9856.00 9800.00 332.96 S 5059.17 W 2674.49 116.21 12795.06 9956.00 9900.00 263.82 S 5292.89 W 2839.06 164.57 13394.15 10056.00 10000.00 111.13 N 5744.96 W 3338.15 499.09 14072.63 10156.00 10100.00 559.44 N 6244.19 W 3916.63 578.48 14366.00 10201.52 10145.52 751.13 N 6461.56 W 4164.48 247.85 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS WELL LOG TRANSMITTAL To: State of Alaska November 5, 1997 Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor I r2~1 3001 Porcupine Drive q q. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2-46B/S-13, AK-MM-70171 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention off Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2-46B/S-13: 2" x 5" ~MD Resistivity & Gamma Ray Logs: 50-029-21921-02 2"x 5" TVD Resistivity & Cramrna Ray Logs: 50-029-21921-02 2"x 5" MD Neutron & Density Logs: 50-029-21921-02 2"x 5" TVD Neutron & Density Logs: 50-029-21921-02 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline ~ _ 1 Rev Fo~~ l',OV '~ '1997 Gas Cons. Comfier,, 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11520 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Greater Point Mclntyre Area 1 1/3/97 Floppy Well Job # Log Description Date BL RF Sepia Disk P1-01 bkt C--.- INJECTION PROFILE 970925 1 1 P1-01 ~ INJECTION PROFILE 97091 3 I 1 ,, , P 1-6 · ~ ~, I~"'1 PRODUCTION PROFILE 971 003 I 1 P 1 - 11 · PRODUCTION PROFILE W/DEFT 971 01 2 I 1 ,, P 1 - 12 ° PRODUCTION PROFILE W/DEFT 97 081 1 1 1 ! P 1 - 14 bi,. ~ (~. INJECTION PROFILE 97 0 92 6 1 I ,., P 1-21 ~ 1 C~ INJECTION PROFILE 97 0 92 6 1 1 P2-01 , C~'1, O~[~ PRODUCTION PROFILE 970914 I 1 P2-16 L~ i C_ INJECTION PROFILE 97 0 801 I 1 P 2-1 8, PRODUCTION PROFILE W/DEFT 97 0 927 I 1 P2-19. q-J · O~K~[ PRODUCTION PROFILE DEFT IMAGES 971004 I 1 P2-19 - ~ PRODUCTION PROFILE 971 004 1 1 P2-28 Ut(._ INJECTION PROFILE 971 01 0 I 1 P2-31 · PRODUCTION LOG 97 0 804 1 1 P2-50, DEFT IMAGES 971 005 I 1 P2-50. PRODUCTION PROFILE 971 005 I 1 P2-54. PRODUCTION PROFILE 97081 9 I 1 P 2- 57, PRODUCTION PROFILE 970911 1 1 P2-58, ( .~ PRODUCTION PROFILE W/DEFT 97101 0 I I 3'o5~J 1-0'/3 3'/2.3 ?.o"l'f o.oo~ SIGNED: ~O'~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ,. ^,, ~ lqq7 ~tUV u .... Alaska Oil & Gas Cons. Cornfr~o~ /~chomge 0 F:! I I--I-- I 1~] G S ~:: I:! ~J I r- ~:: S WELL LOG TRANSMITTAL To: State of Alaska October 22, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - 2-46B/S-13, AK-MM-70222 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Fan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21921-02 OCT 2 2 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company .... STATE OF ALASKA ALASKA .,~L AND GAS CONSERVATION CO,v,,vllSSlON APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2045' SNL, 2306' WEL, SEC. 36, T12N, R16E, UPM At top of productive interval N/A At effective depth 3070' NSL, 2833' WEL, SEC. 36, T12N, R16E, UPM At total depth 3879' NSL, 3337' WEL, SEC. 35, T12N, R16E, UPM 5. Type of well: [] Development [] Exploratory [--] Stratigraphic I-~ Service 6. Datum Elevation (DF or KB) KBE = 56.10' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-46B/S-13 9. Permit Number 97-137 10. APl Number 50-029-21921-02 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14420 feet Plugs (measured) 10209 feet 14395 feet Junk (measured) 10204 feet Baker Cast Iron MBP at 13990' (3/97); Baker Cast Iron MBP at 14240' (2/97); Cement Plug from 9296'-9562' (4/97); BP at 7360' (8/97); Cement plug from 7157- 7253' (8/97) Length Size Cemented M D TVD Structural Conductor 70' 30" Driven 110' 110' Surface 2459' 13-3/8" 2772 c.f. Permafrost 2498' 2492' Intermediate 8241' 9-5/8" 575 c.f. Class 'G' 8280' 7974' Production 6521' 7" 555 c.f. Class 'G' 7259'-13780' 7154'-10106' Liner 724' 4-1/2" 221 c.f. Class 'G' 13696'-14420' 10092'-10209' Perforation depth: measured 13290'-13440', 13600'-13630', 13800'-13840', 13875'-13950', 14010'-14090', 14110'-14150' (Open); 14310'-14390' (Closed) true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) 10025'-10052', 10077'-10082', 10109'-10115', 10120'-10132', 10142'-10154', 10157'-10163' (Open); 10186'-10203' (Closed) Alaska Oil & Gas Cn.o -17choral~. .,~,.mls~ 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketcl¢I Se 14. Estimated date for commencing operation August 27, 1997 16. If proposal was verbally approved~ Jack Hartz Name of approver 8/26/97 Date approved Contact Engineer Name/Number: Chris West, 564-5089 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the forego~g is true and correct to the best of my knowledge Signed ,_~----"7-)~ ~._~¢.¢-~ . ~ Dan Stone Title Senior Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness I Approval No., .¢'~ Plug integritYlntegrity %` BOP Test __ Location clearance __required ~ ~¢~q~.~¢OCO~~y'~ Mechanical Test Subsequent form 10- _.,,na~ Signed By Approved by order of the Commission )~v!d W. -Johnston Com Form 10-403 Rev. 06/15/88 Submit In Triplicate 2-46b/S-13 Summary Procedure o . . o . o 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. If not circ well w/brine or milling fluid until the well is dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Screw into the landing joint. Pull and LD the tubing. (1 day) Attempt to fish coil, tubing, packer etc. Run a EZSV 100 feet below the top of the 7"liner, spot an 17 ppg pill from the BP to 7358 to 7150. Displace brine with milling fluid. P/U section mill and TIH to cut section from 7150' - 7200' MD. (2 days) POOH w/mills. (1/2 day) RIH with OE DP and Spot 300 sx cement plug from 7000' to 7358' MD, and squeeze into section. (1/2 day) POOH with OEDP. (1/2 day) P/U and RIH with sidetrack BHA while WOC for 12 hours minimum. (1/2 day) Pick up Sperry 6.75" directional BHA to turn and build @ 8°/100 feet to 59° at appx 7570' MD. Hold tangent section, then build and turn to target #1 at 13,010. Ensure maximum flowrates are being implemented to negate cutting bed buildup. Drill ahead as specified by the rigsite geologist to TD at 14,194'MD. POOH. (15 days) If hole conditions dictate, run HO over hole interval and spot lubricant in OH section. POOH. Run 7" solid liner from 7,050' to 14,194' MD, rotate for as long as possible and cement as per plan. (2 days) Perforate with DCP charges at 1000 psi underbalanced with perforation intervals picked from logs. (3days) RIH w/7" x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 12,700 MD. Drift packer, tubing and all jewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). Turn the well over to Production. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Alter Casing [] Change Approved Program Name of Operator BP Exploration (Alaska) Inc. [] Suspend [] Repair Well [] Operation Shutdown Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Plugging [] Time Extension [] Pull Tubing [] Variance [] Re-Enter Suspended Well [] Stimulate 5. Type of well: [] Development [] Exploratory [] Stratigraphic r-]Service [] Perforate [] Other Location of well at surface 2045' SNL, 2306' WEL, SEC. 36, T12N, R16E, UPM At top of productive interval N/A At effective depth 3070' NSL, 2833' WEL, SEC. 36, T12N, R16E, UPM At total depth 3879' NSL, 3337' WEL, SEC. 35, T12N, R16E, UPM DUPLICATE 6. Datum Elevation (DF or KB) KBE - 56.10' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-46B/S-13 9. Permit Number 97-137 10. APl Number 50-029-21921-02 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 14420 true vertical 10209 Effective depth: measured 14395 true vertical 10204 Casing Length Structural Conductor 70' Surface 2459' Intermediate 8241' Production 6521' Liner 724' feet Plugs (measured) feet feet Junk (measured) feet Baker Cast Iron MBP at 13990' (3/97); Baker Cast Iron MBP at 14240' (2/97); Cement Plug from 9296'-9562' (4/97); BP at 7360' (8/97); Cement plug from 7157- 7253' (8/97) Size Cemented MD TVD 30" Driven 110' 110' 13-3/8" 2772 c.f. Permafrost 2498' 2492' 9-5/8" 575 c.f. Class 'G' 8280' 7974' 7" 555 c.f. Class 'G' 7259'-13780' 7154'-10106' 4-1/2" 221 c.f. Class 'G' 13696'-14420' 10092'-10209' Perforation depth: measured true vertical 13290'-13440', 13600'-13630', 13800'-13840', 13875'-13950', 14010'-14090', 14110'-14150' (Open); 14310'-14390' (Closed) 10025'-10052', 10077'-10082', 10109'-10115', 10120'-10132', 10142'-10154', 10157'-10163' (Open); 10186'-10203' (Closed) Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) Attachments I~ Description summary of proposal [] Detailed operations program I-I BOP sketch Estimated date for commencing operation . 115. Status of well classifications as: August 27, 1997 ! I~ Oil l~ Gas [-'J Suspended Service 16. If proposal was verbally approved Jack Hartz Name of approver Contact Engineer Name/Number: Chris West, 564-5089 8/26/97 Date approved Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~._-¢,~. ~ Dan Stone Title Senior Drilling Engineer Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date I Approval Plug integrity _.~_- BOP Test ~ Location clearance '-'~~~¢'J {i~ Mechanical Integrity Test Subsequent form required 10 j,-ig~nal Signed By order of the Commission '~Vid W_ .Inhnst0n Commis~ Form 10-403 Rev. 06/15/88 Submit In Triplicate . . , . . 6~ 7. . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. z-46b/S-13 Summary Procedure Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. if not circ well w/brine or milling fluid until the well is dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Screw into the landing joint. Pull and LD the tubing. (1 day) Attempt to fish coil, tubing, packer etc. Run a EZSV 100 feet below the top of the 7"liner, spot an 17 ppg pill from the BP to 7358 to 7150. Displace brine with milling fluid. P/U section mill and TIH to cut section from 7150' - 7200' MD. (2 days) POOH w/mills. (1/2 day) RIH with CE DP and Spot 300 sx cement plug from 7000' to 7358' MD, and squeeze into section. (1/2 day) POOH with OEDP. (1/2 day) P/U and RIH with sidetrack BHA while WOC for 12 hours minimum. (1/2 day) Pick up Sperry 6.75" directional BHA to turn and build @ 8°/100 feet to 59° at appx 7570' MD. Hold tangent section, then build and turn to target #1 at 13,010. Ensure maximum flowrates are being implemented to negate cutting bed buildup. Drill ahead as specified by the rigsite geologist to TD at 14,194'MD. POOH. (15 days) If hole conditions dictate, run HO over hole interval and spot lubricant in OH section. POOH. Run 7" solid liner from 7,050' to 14,194' MD, rotate for as long as possible and cement as per plan. (2 days) Perforate with DCP charges at 1000 psi underbalanced with perforation intervals picked from logs. (3days) RIH w/7"x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 12,700 MD. Drift packer, tubing and all jewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). Turn the well over to Production. TONY KNOWLE$, GOVEF~NOF~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 22, 1997 Chip Alvord Senior Drilling Engineer BP Exploration (Alaska) Inc,. P O Box 196612 Anchorage, AK 99519-6612 Duck Island 2-46B/S- 13 BP Exploration (Alaska) Inc. Permit No. 97-137 Sur. Loc. 2045'SNL, 2306'WEL, Sec. 36, T12N, R16E, UM Btmnhole Loc. 3873'NSL, 3332'WEL, Sec. 35, T12N, R16E, UM Dear Mr. Alvord: 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. 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. ~--. STATE OF ALASKA ..... ALASKA OIL~ ,ND GAS CONSERVATION COMMI,~.~ION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entr7 [] DeepenI []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE -- 56.10' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034633 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2045' SNL, 2306' WEL, SEC. 36, T12N, R16E Duck Island At top of productive interval 8. Well Number Number 25100302630-277 3071' NSL, 2480' WEL, SEC. 35, T12N, R16E 2-46B/S-13 At total depth 9. Approximate spud date Amount $200,000.00 3873' NSL, 3332' WEL, SEC. 35, T12N, R16E 07/20/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034634, 1948'I No Close Approach 2560 14446' MD / 10206' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10500' MD Maximum Hole Angle 71 ° Maximum surface 4058 psig, At total depth (TVD) 10000' / 5055 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 HYD 511 2094' 12352' 9686' 14446' 10206' 204 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. ORIGINAL. Present well condition summary Total depth: measured 14420 feet Plugs (measured) Baker Cast Iron MBP at 13990' (3/97); Baker Cast Iron MBP at 14240' true vertical 10209 feet (2/97); Cement Plug from 9296'-9562' (4/97) Effective depth: measured 14395 feet Junk (measured) true vertical 10204 feet Casing Length Size Cemented MD TVD Structural Conductor 70' 30" Driven o~ ~. C ~. I L 110' 110' Surface 2459' 13-3/8" 2772 c.f. Permafr ' 2498' 2492' Intermediate 8241' 9-5/8" 575 c.f. Class 'G' 8280' 7974' Production 6521' 7" 555 c.f. C~ass'G' ,,, '/~ ~997 72.5_..9~[~780', 7154'-10106' Liner 724' 4-1/2" 221 c.f. Class 'G' ' - "- . .0~_~4420 10092'-10209' Per~oration depth: measured 13290'-13440', 13600'-13630', 13800'-13840', 13875'-13950', 14010'-14090', 14110'-14150' (Open); 14310'-14390' (Closed) true ve~ical 10025'-10052', 10077'-10082', 10109'-10115', 10120'-10132', 10142'-10154', 10157'-10163' (open); 10186'-10203' (Closed) 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord ,~ ~ O~'~ Title Senior Drilling Engineer Date Commission Use Only Permit Number I APl Number App. roval Date I See cover letter .?~"/,~7I 50- O.2-~- .2./ ?~ /-- ~ ~ ~~-~'~[ for other requirements Conditions of Approval: Samples Required []Yes J~ No Mud Log Required []Yes '[] No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required .~Yes [] No Required Working Pressure for BOPE FI2M; FI3M; C~LSM; I-I10M; F]15M Other: o,',g~na! Signed By by order of Approved By ~avid W. Johnston Commissioner the commission Date "~ -~ -'¢' Form 10-401 Rev. 12-01-85 Productibn 4.5' ~ 12,352 to 14,445 with 4.5" x 9-5i8" liner hanger -C~m=b-nt from 12,352 to 14,445 -+_ 204 Sxs -ola§s~G-, - 0.5% CFR 2 0.7% Halad 344 0.1% HR-5 2 pps Super CBL Submit In Triplicate 2-46b/S-13 Drilling Program Directional Plan ~3 7/15/97 Page 3 Mud Program: Production Mud Properties: 16" hole section: LSND Depth Density Marsh Yield 10 sec LSR YP pH Fluid Flow (PPG) Viscosity Point 10 Min Loss Rate Gel Whipstock 10-10.2 150-180 60-80 8-16 8.5- <6 250 11 - 24 9.5 Drilling 10.2 - 45 - 60 14 - 25 6 - 9 8.5 - <6 300 10.4 9.5 Hazards/Concerns Pore pressure (_+4.3 - 9.7 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing at the wellsite. WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: McEvo¥ 13 3/8" X 13 5/8", 5M Flange McEvoy Mandrel Hanger McEvoy 13 5/8",5M X 13 5/8", 5M Cameron 4 1/16",5M DIRECTIONAL STATS FOR 7" CASING ON 2-46aJR-10ABOVE THE KOP Average Angle above KOP · Maximum Angle Maximum Dogleg Centralizers Top of Cement 70° 71° @ 14000' 10.166°/100@8350' 9.774°/100' @ 8384' Turbo Clamps from 13,780' to 11,566' 10,516 (Calc. assumin~l 30% washoutI Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS There are no drilling close approach wells after the sidetrack of the original 2-46a/R-10 wellbore. This closest points between these well is 395 feet away (wellbore to wellbore), and is minimum risk of collision. PORE PRESSURE / LOST CIRCULATION Production Interval (6"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset pore pressure (based on nearby 3C BHP of 2215 - 5055 psi at 10,000' TVDss) should range from _. 4.3 to 9.7 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Disposal Cuttings Handling: Fluid Handling' CC2A Annular injection is not available at Endicott for this well. 2-46b/S-13 Drilling Program Directional Plan #3 7/15/97 Page 4 Contacts Office Home Pa.qer Drilling Superintendent Adrian Clark 564-4720 345-9066 275-1779 Sr Drilling Engineer Steve Shultz 564-5405 373-1657 275-1789 Operations Drilling Engineer: Chris West 564-5089 345-4699 275-7530 Production Engineer Bob Metzger 564-4613 Geologist: Evvy Goebel 564-5367 276-1045 275-1337 Geophysicist: Tom Walsh 564-5309 563-7860 Sperry Sun Directional Gordon Hecht 563-3256 345-6125 242-8019 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 2-46b/S-13 Drilling Program Directional Plan #3 7/15/97 Page 5 D - ling Discussion General The 2-46b/S-13 well on MPI at Endicott will target the Kekiktuk in the MPI 3A3 in accordance with the 1997 development plan. We will have to abandon the existing perforation in the 2-46A/r-10 well by cutting the tubing, fishing the coil tubing, cleaning out the 7" liner, placing cement down drill pipe with the rig, set a whipstock, cut a window, and kick off through the 7" casing to the new S-13 BHL utilizing the 4.5" rotating liner design. The liner length will be __ 2094 feet, with the top of the liner hanger back into the 7" casing. There have been problems with sidetrack wells especially keeping the metal cuttings from sticking the BHA. The milling fluid is designed to clean the hole if flow rates are kept high and the ditch magnets are closely monitored for recovery. A standard 6 valve slimhole (4.5" x 1.5" for 9-5/8" casing) GLM design will be run for the completion on a 4.5" L-80 tubing design with a X/X/XN nipple profile. Directional Plan: The directional plan for the 2-46b/S-13 well consists of kicking off via whipstock mills, and conventional BHA's for the Kekiktuk Flow sands. Current plans call for 8 to 12 °/100' doglegs below the whipstock, but this may be adjusted pending results during the drilling process. After sidetracking, and steering directionally back into the Sands with 66° of inclination, the well will be drilled to _+14,446 MD (10,150' TVD). THE DIRECTIONAL TARGET CAN BE INTERSECTED ANYWHERE WITHIN THE TARGET BOUNDRY. THUS UNNECESSARY AND VERY EXPENSIVE SLIDING SHOULD BE AVOIDED TO KEEP THE WELL EXACTLY ON THE WELLPATH. THERE IS NOT ANY GEOSTEERING APPLICATION FOR THIS WELL. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted unless flow rates exceed the motor operating parameters. If high performance drilling is desired, the motor should be jetted, and maximum flow rates used for maximum ROP. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized in the 6" hole sections to minimize potential differential sticking. We will be using bent housing motors with either 7/8 or 5/6 rotor/stator configurations. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics should be discussed at the daily wellsite meeting. Survey Program The survey program for 2-46b/S-13 calls for use of Sperry's DWD MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. 2-46b/S-13 Drilling Program Directional Plan #3 7/15/97 Page 6 Bit Program We will kick off the in the Seabee Shale with a conventional directional BHA and roller cone bit, which should make it to the Kekiktuk. After milling the section, a 6" drop/turn, tangent, then build/turn section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication of bit failure such as torque spikes, the bit should be pulled at the descretion of the rigsite team. It remains the Endicott Doyon 15 wellsite TEAM's resposibility to confirm these bits are the best choice before running based on actual drilling conditions and bit performance. Recommended Jet Sizes Expected Interval Bit Type Flowrate H SI Casing Whipstock Standard Whipstock Mills 500 - 550 gpm 6" Kickoff - only GTPS11 250 - 300 gpm 3 x 12 2.9 - 4.8 6" Tangent and Hycalog DS 111 or BBL 880 250 - 300 gpm 3 x 15 or 2.9 - 4.8 Reservoir section 4 x 12 NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. PDC bits will be run in the 6" hole section only if Sperry 4-3/4" performance motors are available, and ONLY WHERE ECONOMICAL. Mud Program: We will use LSND on this well. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biozan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Most of this well will be drilled at angles of greater than 60°, therefore frequent lo/hi vis sweeps should be implemented to ensure hole cleaning. In addition rotary speeds of 100 rpm should be used during the sweeps to aid in cutting bed removal. Rheology control can be maintained using Gel and Biozan polymer. At this time raise the LSR YP to the recommended range using Biozan. Frequent Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Additions of 3#/BBL each of Baranex and Barotrol should be maintained this well in 8.5' section. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. To prevent torque problems from developing, the standard ERD lubricant mix should be started after the window is cut. Lubricant additions should begin with mixing Lubtex up to the required concentration and then adding EP Mudlub. All lubricants should be added gradually to prevent foaming and shaker blinding. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping in the 6" hole interval should be undertaken with caution due to swabbing possibilities with high viscosity fluids. The bottom hole pressure varies from 2215 psi to 5055 psi (4.2 to 9.7 ppg ). It is recommended that mud weights be maintained in the 10.2 to 10.4 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends 2-46b/S-13 Drilling Program Directional Plan #3 7/15/97 Page 7 utilization of Iow viscosity sweep., to assist with hole cleaning ano to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 2-46b/S-13 well. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. Logging Program: ILogs: 6" Hole Tangent and Curve MWD-GR IRES Cased Hole: None The following summarizes logging evaluation needs: LWD Basic LWD will be run. Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This sidetrack well will require a single 4.5" 12.6# L-80 liner to be run across the entire interval. This will be hung off in the 7" casing at 12,352 feet. Make sure we have 5000 feet of 5" "S" drill pipe to allow fo the maximum overpull and torque. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Also, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges in the Tuffs, will require special care while running casing through. The liner will require 2 straight blade centralizers on every joint to the 200 feet above the top of the Kekituk at _+ 13,352', and then one straight blade centralizer on every other joint to the window. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program is designed place cement 1000 feet above the top of the Kekiktuk formation. The approximate volume will be 205 sacks of Class 'G' with additives as speficied in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. Drill Pipe Conveyed Perforating This well will require DPCP perforating across the pay as identified by MWD logs. It is therefore critical these FINAL Field Prints logs are sent to town after a QA/QC procedure insures the data is adequate to pick the perforated interval. 2-46b/S-13 Drilling Program Directional Plan #3 7/15/97 Page 8 SUMMARY PROL;EDURE , , , o , , o 7, , , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. COMMENTS 1. The 7" x 4-1/2" production packer is a Baker permanent packer with a tubing seal assembly. 2. The new 7"x 4.5" packer should be set at +/- 10,250 MD. PRE-RIG OPERATIONS 1. RU wireline, pull GLM's. 2. Cut tubing with chemical cutter just above coil tubing fish at 8315' MD. Circulate 10 ppg drilling fluid around in preparation for whipstock operations. Freeze protect annulus to 200' MD. Set BPV. Dig out the cellar and level the pad. Inspect the wellhead and tree. Test the packoff and function LDS. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check to see the well is dead. If not circulate with 10 ppg drilling fluid. ND tree and NU BOP. Test the tree and pull BPV. Screw into the tubing hanger and pull and LD 4.5" production tubing. Pick up fishing BHA for coil tubing and recover same. See attached Baker fishing program for BHA details. Pick up fishing BHA #2 and recover remaining production tubing and lowermost GLM #1. Pick up milling BHA #3 and burnover Baker S-3 Packer at 8719' MD. Pick up spear for packer and recover same. Pick up 6" bit and scraper to drill out cement from 9296 to 9562, and then to the 4.5" liner top at 13,696' MD. POOH. Run an USIT Icg from 4.5" liner top to at least 12,300 ir TOC. TIH with cement retainer to 12,500 place a 375 sx cement plug MD. Squeeze cement into perforations at up to 1500 psi. Unsting from retainer and reverse out. Drill out cement to KOP at 12,500' MD. P/U 7" Whipstock and milling BHA and TIH to cut window from 12,490 - 12,502 MD. (2 days). POOH w/mills. (1/2 day). Pick up Sperry 4.75" directional BHA for sidetrack at 10,500 to turn and drop @ 8°/100 feet to 26° and turn to 255° azimuth at appx. 11,282' MD, hold this attitude until second KOP and the build and turn to 66° and 223° Azimuth. Drill ahead as specified by the rig supervisor to CP at 13,189. POOH. (12 days) If there are hole problems, run a HO over whole interval and spot lubricant in OH section. POOH. Run a 4.5" solid liner from 12,350 to 14,446 MD, cement as per plan. (2 days). Make a clean out trip with bit and scraper and displace with KW Brine. Perforate with DPC perfs 2-7/8" guns at 6 spf. (2 days). RIH w/7" x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 10,350 MD. Drift packer, tubing and all jewlery before running. Stab tubing tail into liner top (1 day). Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day). Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 20. Turn the well over to Production. 2-46b/S-13 Drilling Program Directional Plan ~¢3 7/15/97 Page 9 T..ELEV = 55.1 16.3 BF. ELEV = 13-3/8 68#/FT F~'~ -Rn RI.~. Abandoned Q-15 Wellbore ( MP! WELL 2-46N Wellhead: 13-5/8' / 5000 psi / McEvoy 4-1/6 -5000 psi Cameron SSSV LANDING NIPPLE I 1500' Top of 7' ENDICOTI ~ 157 LOC;: NEW HARKER L ~ c XPI: ~8-95 ~5/¢6/97 1~:4D:¢6 DEP]H UNIT - FEET COHHENT: ~NE . _. ___-..._ ...... TUAL~~6 HD PERFS AC .................. ~ IA have 10.6 ppg Brine Tie-back, liner nlnnlnn lrml. Chemical Cut 8315' Top o! Cemer~t~' 113fl0' MD ~h~v~ KE,~I~I~.I09" wall CT ~ibly collaps~ from 8895'-8315') ~ N~ ~ 8895' Final Position Odg~ Stuck ~ ~ 93~' Cement from ~ 9296'-9562' SIZE SPF INTERVAL STATUS 4-5/8 6 13290'-13440' OPEN 4-5/8 6 13600'-13630' OPEN 2-3/4 4 13800'-13840' OPEN 2-3/4 4 13875'-13950' OPEN 2-3/4 4 14010'-14090' OPEN 12-3/44 14110'-14150' OPEN 2-3/4 4 14310'-14390' CLOSED DATE I REV. BY I COMMENI'S Coil Fish / CMT Plug 4-1/2' 12.6~/R, Cr13, GAS UFT MANDRELS NO. MD-BKB TVD-SS #6 3527' 3465' Note; All GLM's have bottom Intergal #5 5312' 5250' 4-1/2' 'X' NIPPLE I 8708' (9 Ct)I 7-5/8 x 4-1/2 16719' RAKFR 4-1/2" 'X' NIPPLE 18742, (9 Cr)l 4-1/2- 'x,~.,PP.~ 167~'(~col 18=4, Top ol 4-1/2" liner 12,6 ifil L-80 NSCT ..~.~BAKER CAST I1399o' I IRON MBP ..~.~.i BAKER CAST I 14240, I IRON MBP ~ PBTD- 14395' I ENDICO'rr WELL2-46A/R-10 APl NO. 029-21921-01 INITIAL COMPLETION, BP EXPLORATION, INC. ~01~0100 02106/97 WELL NAME LOG/DATE ZONE TOP M.D. BOTM.D. H TOPTVD BOTTVD 2-46A/R-10 DLL/GR FV 13290 13440 150 9969 9996 1/9/97 FV 13600 13630 30 10021 10026 FV 13800 13840 40 10053 10059 FV 13875 13950 75 10064 10076 FV 14010 14090 80 10085 10098 FV 14110 14150 40 10101 10107 Fill 14310 14390 80 10131 10144 Last Revised: 05/05/97 .: : . MPI WELL 2-46BIS-13(Wp3) SURFACE & DOWNHOLE LOCATIONS 7/15/97 ITEM NAME COMMENTS ALASKA STATE PLANE ZONE 3 (NAD 27) DECIMAL DEGREES (NAD 27) S & E SEC LINE OFFSET SECTION, TOWN., NEAREST SECTION LINE OFFSET~c NO. Y X LATITUDE (N°) LONGITUDE (VV*) FSL FEL RANGE, UMIAT, AK DIST. LINE DIST. LINE 1 MPI 2-46B/S-13 Surface @ MPI Surface Location 5,982,375.10' 258,898.11' 70.352479° 147.957951° 3235 2305 SEC 36 T12N R16E 2044 N 2306 E 2 MPI2-46B/S-13 MD:12512 KOP 5,982,015.54' 253,993.-52' --70.351061° 147.997654° 2716 1916- SEC-35 T12N R16E 2563 N 1916 E 3 MPI 2-46B/S-13 MD:13261 S-13 Target 1 5,982,395.00' 253,435.00' 70.352047° 148.002287° 3077 2486 SEC 35 T12N R16E 2202 N 2486 E 4 MPI 2-46B/S-13 MD:14445 S-13Target 2/TD/4 1/2" Liner 6,983,226.00' 252,610.00' 70.354239° 148.009204° 3879 3337 SEC 35 T12N R16E 3879 N 1942 W Notes: Coordinates shown are North American Datum 1927 (NAD 27). F. Robert Bell & Assoc. Jeff Cotton 564-4969 File Name: MPIBH715.xls 7/15/97 9200 9400 1 9600 - 9800 10000 10200 10400 - -- 10600 - -- 10800 - 11000 32O0 2-46B/S-13 Wp3 I Shared Services Drilling Sfrucfure · End MPI Field ' Endicoif .... Point .... ?~e on lleon KOP End of Build End of Hold Torget Target 14445 81.26 313.31 Well · 2-46B/S-1.3 Locafion · Alaska WELL PRO MD Inc Dir TVD 12512 66.68 268.61 9750 12512 66.68 268.61 9750 12529 67.85 269.35 9757 12862 68,44 312.61 9886 13154 68.44 312.61 9993 13261 81.26 513.31 10021 10201 I I I I I I I I I I I I I I I I I I I I I I I I I I I 5400 5600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 FILE DATA NoAh East DLS(deg/lOOft) -519 -4891 0.00 -519 -4891 0.17 -519 -4906 8.00 -411 -5186 12.00 -228 -5386 0.00 -157 -5461 12.00 645 -6313 0.00 ~cole I ' 200.00 V~rfficalSe¢lionon309.$Oazimufhwithrefer .... O.OON, O.OOEfromO2-46A/R-lO Shared~ Services Drilling Structure: End MPI Wetl' 2-46B/S-15 Field: Endicott Location · Alaska I 2-46B/S- 1 ,.3 Wp,3 A Ii ,C Scale 1 ' 200.00 East -> 1000 . -- 800 - -- 600 - -- 4OO - 200 - -- 0 - -- -200 - -- -400 - -- -600 - -- -8OO -7200 -7000 -6800 -6600 -6400 -6200 -6000 -5800 -5600 -5400 -5200 -5000 -4800 -4600 -4400 -4200 -4000 41/2' Liner S- 13 Target 2 14445 81.26 15261 81.26 TARGET DATA I I I North Eoat -- Name .... Position -- 3~3.3] ~020~ 6~5 -63~3 S-,3Torget2 252610. 5985225 ,~3.3~ ]OOZ~ -~? -54~] S-"3Tomct~ 253435,5982395 S-13Target 1 - 7200 - 7000 - 6800 - 6600 - 6400 - 6200 - 6000 - 58 O0 - 5600 -5400 -5200 - 5000 - 4800 - 4600 - 4400 - 4200 - 4000 1000 -- - 800 6OO - 400 -- - 200 -- - 0 -- - -200 - -4OO - -600 -- -800 A II 7 0 Scale 1 ' 200.00 East -> 2-46B/S-13 Wp3 Vertical Section 309.3° RKB 56.00' MD Inc. Azi, TVDss TVDrkb 12511.77 66.68 268.61 9694.00 9750.00 12528.67 67.85 269.35 9700.53 9756.53 12600.00 66.98 278.57 9727.97 9783.97 12700.00 66.67 291.63 9767.47 9823.47 12800.00 67.44 304.64 9806.60 9862.60 12862.11 68.44 312.61 9829,96 9885.96 12900.00 68.44 312.61 9843.88 9899.88 13000.00 68.44 312.61 9880.63 9936.63 13100.00 68.44 312.61 9917.37 9973.37 13153.69 68.44 312.61 9937.10 9993.10 13200.00 73.99 312.92 9952.01 10008.01 13260.64 81.26 313.31 9965.00 10021.00 13300.00 81.26 313.31 9970.98 10026.98 13392.19 81.26 313.31 9985.00 10041.00 13400.00 81.26 313.31 9986.19 10042.19 13500.00 81.26 313.31 10001.39 10057.39 13600.00 81.26 313.31 10016.59 10072.59 13622.42 81.26 313.31 10020.00 10076.00 13700.00 81.26 313.31 10031.79 10087.79 13800.00 81.26 313.31 10046.99 10102.99 13900.00 81.26 313.31 10062.20 10118,20 14000.00 81.26 313.31 10077.40 10133.40 14100.00 81.26 313.31 10092.60 10148.60 14200.00 81.26 313.31 10107.80 10163.80 14280.23 81.26 313.31 10120.00 10176.00 14300.00 81.26 313.31 10123.00 10179.00 14400.00 81.26 313.31 10138.21 10194.21 14444.68 81.26 313.31 10145.00 10201.00 Rect. Coordinates Northing 518.59S 518.86S 514.34S 490.47S 447.15S 411.24S 387.39S 324.43S 261.47S 227.66S 197.90S 157.44S 130.76S 68.25S 62.96S 4.85n 72.65n 87.85n 140.45n 208.25n 276.06n 343.86n 411.66n 479.46n 533.86n 547.27n 615.07n 645.37n Easting 4890.50w 4906.09W 4971.70w 5060.21W 5141.17w 5186.09W 5212.03W 5280.48w 5348.93w 5385.69W 5417.86W 5461.07w 5489.37w 5555.67W 5561.29W 5633.21w 5705.12w 5721.25W 5777.04w 5848.96W 5920.88W 5992.80W 6064.71w 6136.63W 6194.33W 6208.55w 6280.47W 6312.60W Grid Coordinates Easting 253993.52 253977.93 253912.51 253824.83 253745.31 253701.58 253676.43 253610.06 253543.69 253508.06 253476.87 253435.00 253407.58 253343.34 253337.90 253268.22 253198.55 253182.92 253128.87 253059.19 252989.52 252919.84 252850.16 252780.49 252724.59 252710.81 252641.1 3 252610.00 Northing 5982015.54 5982015.77 5982022.43 5982049.15 5982095.08 5982132.42 5982157.10 5982222.25 5982287.40 5982322.38 5982353.16 5982395.00 5982422.59 5982487.22 5982492.69 5982562.79 5982632.89 5982648.61 5982702.99 5982773.09 5982843.19 5982913.28 5982983.38 5983053.48 59831O9.72 5983123.58 5983193.68 5983225.00 DLS deg/100ft 0.17 8.00 12.00 12.00 12.00 12.00 0.00 0.00 0.00 0.00 12.00 12.00 0.00 0.00 0.00 0.00 '0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 3456.01 3467.89 3521.53 3605.14 3695.24 3752.74 3787.92 3880.77 3973.62 4023.47 4067.21 4126.27 4165.08 4255.98 4263.68 4362.28 4460.87 4482.98 4559.47 4658.07 4756.67 4855.26 4953.86 5052.46 5131.56 5151.06 5249.65 5293.71 KOP S-13 Target 1 TFU 5 TFU 4 TFU 3 Comment S-13 Target 2/TD/4 1/2" Liner 7/14/97 8:41 AM Page I of 1 STATE OF ALASKA ALASK :BOIL AND GAS CONSERVATION CL, ~IMISSION - APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2045' SNL, 2306' WEL, SEC. 36, T12N, R16E At top of productive interval 2450' SNL, 2606' WEL, SEC. 35, T12N, R16E At effective depth 1697' SNL, 3405' WEL, SEC. 35, T12N, R16E At total depth 1680' SNL, 3423' WEL, SEC. 35, T12N, R16E 5. Type of well: [~ Development [] Exploratory E~ Stratigraphic E~] Service 6. Datum Elevation (DF or KB) KBE = 56.10' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-46A/R-10 9. Permit Number 96-181 10. APl Number 50-029-21921-01 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 14420 feet Plugs (measured) 10209 feet 14395 feet Junk (measured) 10204 feet Baker Cast Iron MBP at 13990' (3/97); Baker Cast Iron MBP at 14240' (2/97); Cement Plug from 9296'-9562' (4/97) Length Size Cemented M D TVD 70' 30" Driven 110' 110' 2459' 13-3/8" 2772 c.f. Permafr(~F_,.~ F t~ i~J ~ ~ ~¢, !-~;; 2498' 2492' 8241' 9-5/8" 575 c.f. Class 'G' )"~ :~,, ~" ~ 8280' 7974' 6521' 7" 555 c.f. Class 'G' 7259'-13780' 7154'-10106' 724' 4-1/2" 221 c.f. Class 'G' ~; ~ ~ {~ !~q~ 13696'-14420' 10092'-10209' 13290'-13440', 13600'-13630', 13800'-13840', 13875'-13950', 14010'-14090', 14110'-14150' (Open); 14310'-14390' (Closed) 1~~25~~1~~52'~1~~77~~1~~82'~1~1~9'~1~115'~1~12~~-1~132~~1~142'-1~154~~1~157~-1~163~(~pen); 10186'-10203'(Closed) Tubing (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 set at 8776' Packers and SSSV (type and measured depth) 4-1/2" HXO SVLN set at 1503'; 7" Baker S-3 Packer set at 8719' 13. Attachments 6~ Description summary of proposal E~] Detailed operations program E~ BOP sketch 14. Estimated date for commencing operation July 25, 1997 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Chris West, 564-5089 Date approved 15. Status of well classifications as: [~ Oil I---I Gas I--I Suspended Service Prepared By Name/Number: Kathy Campoamor, 564-5122 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ,/,,.-_..J.~.,(__"~ ' ~ ~_,/_...¢... Title Senior Drilling Engineer Commission Use Only Date '7/'~ %(/) 7 Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test~ Subsequent form required 10- -- Original Signed By Approved by order of the Commission ~,-.,;,,4 W, I~1~,~^~ LICIV IM tJ',J111 IO L~JH Form 10-403 Rev. 06/15/88 Commissioner Submit In Triplicate Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Oct 16 15:19:17 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/10/16 Origin ................... STS Tape Name ................ UNKNOWN M C[OF LM[D continuation Number ...... Ol Date J J.'~ JO ! Previous Tape Name ....... UNKNOWN · Comments ................. STS LIS Writing Library. SCientific Technical Services Physical EOF Comment Record TAPE HEADER DUCK ISLAND UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-70222 E. CRIBBS E. VAUGHN RECEJVb? OCT 2 2 ]997 Oil & Gas Cons. 2-46B / S-13 500292192102 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 16-OCT-97 MWD RUN 3 AK-MM-70222 E. CRIBBS E. VAUGHN MWD RUN 4 AK-MM-70222 E. CRIBBS J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-PR4-7 0222 E. CRIBBS J. CARLILE MWD RUN 6 AK-MM-70222 G. GRIFFIN J. CARLILE MWD RUN 7 AK-MM-70222 G. GRIFFIN J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 8 AK-MM-7 0222 M. HANIK J. CARLILE MWD RUN 9 AK-MM-7 0222 M. HANIK J. CARLILE MWD RUN 10 AK-MM-70222 G. GRIFFIN E. VAUGHN SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 36 12N 16E 2045 2306 .00 56.00 14.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7160.0 8.500 14366.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 CONTAINS NO VALID DATA AND IS NOT PRESENTED. 3. MWD RUNS 2 THROUGH 7 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. MWD RUNS 8 THROUGH 10 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD) . 5. A CHANGE FROM SCINTILLATION TYPE GAMMA RAY (NGP) TO DUAL GAMMA RAY (DGR) OCCURRED AT 12745'MD, 9938'TVD. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE , CONVERSATION BETWEEN ALI TURKER OF'SPERRY-SUN DRILLING SERVICES AND BRENT VOORHEES OF BP EXPLORATION (ALASKA), INC. ON 13 OCTOBER, 1997. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14366'MD, 10202'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY - COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR/NEUTRON LOG PROCESSING: HOLE SIZE = MUD FILTRATE SALINITY = MUD WEIGHT = FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ 1800 - 1400 PPM. 10.2 - 10.5 PPG. 16000 PPM. 1.0 G/CC 2.65 G/CC SANDSTONE File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB $ .5000 START DEPTH 7100.0 7155.0 12693.5 12693.5 12693 5 12718 5 12718 5 12718 5 12718 5 12718 5 12728 0 12728 0 12728 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD STOP DEPTH 14299 0 14366 0 14253 5 14253 5 14253 5 14279 ~ ' 14279 5 14279 5 14279 5 14279 5 14288 5 14288 5 14288 5 EQUIVALENT UNSHIFTED DEPTM BIT RUN NO MERGE TOP MERGE BASE 2 7155.0 8292.0 3 8292.0 9286.0 4 9286.0 11439.0 5 11439.0 11944.0 MWD MWD MWD MWD MWD REMARKS: 6 11944 · 0 12451.0 7 12451 · 0 12807 · 0 8 12807.0 13030.0 9 13030.0 13732.0 10 13732 · 0 14366 · 0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OH~R~ 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 NPHI MWD P.U. 4 1 68 FET MWD HOUR 4 1 68 FCNTMWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 0 4 8 12 16 20 24 28 32 36 40 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 NaIne DEPT ROP GR RPX RPS RPM RPD NPHI FET FCNT NCNT RHOB DRHO PEF Min 7100 1 1336 16 1456 4 1954 4 8977 4 8111 5 0223 6 1015 1.349 486.702 2319 .9 2. 0639 -0.09 1.5142 Max 14366 625.781 296.224 240.323 220.995 232.075 185.631 63.1894 33.7543 1938.89 4732.1 2.8854 0.5577 7.6829 Mean Nsam 10733 14533 38 3288 14423 79 9153 14399 25 8592 3123 27 5186 3123 30 9934 3123 28 9541 3123 20 4384 3121 9.13742 3123 945.846 3121 3506.85 3121 2.49177 3122 0.0623067 3122 2.57485 3122 First Reading 7100 7155 7100 12718 5 12718 5 12718 5 12718 5 12693 5 12718 5 12693 5 12693 5 127~8 12728 12728 Last Reading 14366 14366 14299 14279 5 14279 5 14279 5 14279 5 14253 5 14279 5 14253 5 14253 5 14288 5 14288 5 14288 5 First Reading For Entire File .......... 7100 Last Reading For Entire File ........... 14366 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7100.0 8230 . 0 ROP 7155 . 0 8292 . 0 $ LOG HEADER DATA · DATE LOGGED: 29 -AUG- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 35 . 3 MAXIMLrM ANGLE: 59.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 8292.0 7155.0 8292.0 TOOL NUMBER NGP SPC 40 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record T!rpe .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.90 55.0 10.8 5700 5.7 .000 .000 .000 .000 .6 Name Service Order Units Size Nsam Rep Code Qffset Channel DEPT FT 4 1 68 ' 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 56.1 First Name Min Max Mean Nsam Reading DEPT 7100 8292 7696 2385 7100 GR 16.1456 83.6895 54.0532 2261 7100 ROP 1.3722 159.26 39.9496 2275 7155 Last Reading 8292 8230 8292 First Reading For Entire File .......... 7100 Last Reading For Entire File ........... 8292 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 3 DEPTH INCREMENT: .5000 FILE SU~MMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8224.5 9218.0 ROP 8293.0 9285.5 $ LOG HEADER DATA DATE LOGGED: 31-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.1 MAXIMUM ANGLE: 64.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 9286.0 8292.0 9286.0 TOOL NUMBER NGP SPC 223 8.5OO 8.5 LSND 10.00 58.0 9.9 4700 FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION ToOL STANDOFF (IN): EWR FREQUENCY (HZ) : (IN) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.5 .000 .000 .000 .000 ~6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 58.9 First Name Min Max Mean Nsa~ ' Reading DEPT 8224.5 9285.5 8755 2123 8224.5 GR 53.6527 90.8634 74.8713 1988 8224.5 ROP 2.6796 625.781 64.8216 1986 8293 Last Reading 9285.5 9218 9285.5 First Reading For Entire File .......... 8224.5 Last Reading For Entire File ........... 9285.5 File Trailer Service na/ne ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE N[TMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RLTNNUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9213.0 ROP 9287.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUMANGLE: STOP DEPTH 11366.0 11438.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (O~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 06-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 11439.0 9286.0 11439.0 51.2 65.6 TOOL NUMBER NGP SPC 40 8.500 8.5 LSND 10.20 53 .0 8.7 2800 3.9 .000 .000 .000 .000 63 .3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9213 11438.5 10325.8 4452 9213 GR 51.7909 208.897 96.9566 4307 9213 ROP 1.1336 370.547 48.2724 4304 9287 Last Reading 11438.5 11366 11438.5 First Reading For Entire File .......... 9213 Last Reading For Entire File ........... 11438.~ File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... 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BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMIqARY VENDOR TOOL CODE START DEPTH GR 11351.5 ROP 11414.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMI/M ANGLE: STOP DEPTH 11881.5 11943.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 08-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 11944.0 11439.0 11944.0 54.7 59.0 TOOL NUMBER NGP SPC 223 8.500 ' 8.5 LSND 10.20 57.0 8.7 2300 3.1 .000 .000 .000 .000 67 .8 .6 : HZ~I4fl~ zqI,~ %{ZG~ZH zqI~ p~oseH ~eumuo O S00'~IqSLs ....... am-e~ eIT~ snolAe~d Oq ................ act~L elTg S£SS9.-p~ooe~ I~OTSK~ urn~xm~ 0'0'~ ........... ~ec[0/~H uots~eA · -'eure~ IeAeq qns eo~A~es 900'~IqSLS ............. eureu eo!A~es ~epmeH eIT~ 900'~I%SLS ........... aure~ eIT~ ~xa~ Oq ................ ad_KL aIT~ S£559''p~ooa~ I~O!sX~ urn~Ix~ 9I/0I/L6 ....... uoi~m~auaD ~o ajm~ 0'0'I ........... xsqumN uo!s~aA '''allre~ I~ASq qns aOIA~S S'£P6II S'I88II S'£%6II PI%II 090I S88I'E~ £'0II £86S'~ dO~ S'IS£II I90I I8I'%~I ~E~'96~ 86ES'£~ HO S'I5£II 58II S'£~9II 5'£~6II ~'IS£II ~ZQ Du!p~~ ures~ u~aN x~ u!~ ~ure~ ~S~TZ £ 8 89 I % H/L~ S ~MI4 dOH I 0 89 I ~ ~ L~ZQ IaUUmqD Jasg~O apoD da~ uresN azTs sjTu~ ~aP~O a~TA~aS amen Curves and log header data for each bit run in separate files. BIT RUN NI3MBER: 6 DEPTH INCREMENT: .5000 FILE SLKVAMARY VENDOR TOOL CODE START DEPTH GR 11880.5 ROP 11943.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 12388.5 12451.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 10-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 12451.0 11944.0 12451.0 60.2 61.6 TOOL NUMBER NGP SPC 40 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 8.500 8.5 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 LSND 10.20 59 .0 8.9 2100 3.8 .000 .000 .000 .000 67.8 .6 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11880.5 12451 12165.8 1142 11880.5 GR 24.5033 245.533 58.7067 1017 11880.5 ROP 3.4621 91.0547 13.6955 1016 11943.5 Last Reading 12451 12388.5 12451 First Reading For Entire File .......... 11880.5 Last Reading For Entire File ........... 12451 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... 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BIT RUN NLrMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12385.5 12744.5 ROP $ LOG HEADER DATA 12448.5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12806.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 13-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 12807.0 12451.0 12807.0 64.2 69.1 TOOL NUMBER NGP SPC 223 8.500 8.5 LSND 10.20 58.0 9.2 1800 3.3 .000 .000 .000 .000 65.6 .6 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12385.5 12806.5 12596 843 12385.5 GR 24.369 132.518 62.4885 719 12385.5 ROP 1.5303 209.252 10.8744 717 12448.5 Last Reading 12806.5 12744.5 12806.5 First Reading For Entire File .......... 12385.5 Last Reading For Entire File ........... 12806.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUNiMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX 8 .5000 START DEPTH 12693.5 12693 5 12693 5 12718 5 12718 5 12718 5 12718 5 12718 5 STOP DEPTH 12916 5 12916 5 12916 5 12942 5 12942 5 12942 5 12942 5 12942 5 PEF 12728.0 DRHO 12728.0 RHOB 12728.0 GR 12739.0 R0P 12805.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12951.5 12951.5 12951.5 12962.5 13029.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 15-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 13030.0 12807.0 13030.0 73.9 81.0 TOOL NUMBER P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 8.500 8.5 LSND 10.20 58.0 9.2 1600 3.2 .34 .60 .80 0 2 81.6 0 0 600'~IqSLS ........... ~mM oITZ qxoM O~ ................ odAL OTTZ S£S~9''p~o~o~ Ie~TSAqd mn~Tx~ 9~/0~/L6 ....... ~oTqm~ouoO ~o oqe~ O'O'Z ........... ~oqurn~ ~OTSAOA · ''om-eM IOAO~ qns ooTA~oS 800'~I~SLS ............. oure~ o~TAAoS S'6~0£I ........... OT~Z o~uZ ~oz buTp~a~ S'£69~I .......... oIT~ o~T~uZ ~o~ b~Tp~o~ S'YS6[T S'~S6[~ S'~S6[I S'9T6[T S'9T6[T S'[~6[~ S 6[0£~ S 916[Z S ~6~ ~pma~ 8[L[~ 8[L[~ S £69[~ ~ £69[I . S 8IL[~ S S08[~ S £69~ S 8~L~ S 8ILE~ S 8IL~ S 8~L[~ 6£L[~ S'£69~I 8~ 9£~6'[ £S~I'% [L69'I 8~% 86S00I'0 LLSS'O 990'0- OHH~ 8%~ 8I£09'[ %S88'[ 6£90'[ ~OHH L~ 90'~I~£ I£'~L~ 6'6I£~ L~ ~6L'968 ~'LOLI ~0L'98~ 6~ £L80'II 808'~LI L~ L998'£~ ~68I'£9 ~59'9 IH~M 6fl 8LIO'LI £619'£9 699 699£'LI 89L8'£9 III8'9 699 SISS'LI 699 £~9I'9I 89~ SSC'IL I6I'~OI 609~'9£ £L9 5'I98EI S'6[0£I S'£69EI uresM treoM x~M uTM oure~ £I 89 II O~ OI 9£ 8 8~ 9 OE q 9I g 8 I 0 IOUUmqO qos~o opoo Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN IgI/MBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12917 5 12917 5 12917 5 12943 0 12943 0 12943 0 12943.0 12943 0 12952 5 12952 5 12952 5 12963 0 13031 0 SURFACE sOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): STOP DEPTH 13619.0 13619.0 13619.0 13645 0 13645 0 13645 0 13645 0 13645 0 13653 5 13653 5 13653 5 13664 5 13731 5 17-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 13732.0 13030.0 13732.0 80.5 82.7 TOOL NLTMBER P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 8.500 DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM). AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 9 AAPI 4 1 68 RPX MWD 9 OHMM 4 1 68 RPS MWD 9 OHMM 4 1 68 RPM MWD 9 OHlV~ 4 1 68 RPD MWD 9 OHMM 4 1 68 NPHI MWD 9 P.U. 4 1 68 ROP MWD 9 FT/H 4 1 68 FET MWD 9 HOUR 4 1 68 FCNT MWD 9 CNTS 4 1 68 NCNT MWD 9 CNTS 4 1 68 RHOB MWD 9 G/CC 4 1 68 DRHO MWD 9 G/CC 4 1 68 PEF MWD 9 BARN 4 1 68 8.5 LSND 10.40 53 .0 8.9 1400 3.0 .860 .362 .860 .880 Code 6ffDet Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 80.0 Name Min Max Mean DEPT 12917.5 13731.5 13324.5 GR 20.0637 106.266 65.0681 First Last Nsam Reading Reading 1629 12917.5 13731.5 1404 12963 13664.5 RPX 6.4303 240.323 29.6258 1405 RPS 6.8682 220.995 31.993 1405 RPM 6.7484 232.075 36.807 1405 RPD 7.3965 185.631 32.1363 1405 NPHI 10.1941 37.2237 20.2801 1404 ROP 4.2849 167.791 35.3338 1402 FET 1.349 26.2901 6.96617 1405 FCNT 639.231 1383.5 901.098 1404 NCNT 2767.06 4249.94 3456.78 1404 RHOB 2.1285 2.7897 2.43497 1403 DRHO -0.09 0.2748 0.0558426 1403 PEF 1.5142 5.5069 2.39693 1403 12943 12943 12943 12943 12917.5 13031 12943 12917.5 12917.5 12952.5 12952.5 12952.5 13645 13645 13645 13645 13619 13731.5 13645 13619 13619 13653.5 13653.5 13653.5 First Reading For Entire File .......... 12917.5 Last Reading For Entire File ........... 13731.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI FET RPD RPM RPS RPX PEF DRHO 10 .5000 START DEPTH 13617 5 13617 5 13617 5 13643 5 13643 5 13643 5 13643 5 13643 5 13652 5 13652 5 STOP DEPTH 14253 5 14253 5 14253 5 14279 5 14279 5 14279 5 14279 5 14279 5 14288 5 14288 5 RHOB 13652.5 GR 13663.0 ROP 13731.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 14288.5 14299.0 14366.0 TOOL STRING (TOP TO BOTTOM VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)' MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Tlrpe ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 20-SEP-97 ISC VERSION 5.07 DEP 2.042 / NGP 5.74 MEMORY 14366.0 13732.0 14366.0 80.4 82.0 TOOL NLrMBER P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 P0830CRDGP6 8.500 8.5 LSND 10.40 580.0 9.1 1400 3.0 .86 .36 .86 .88 0 2 85.0 0 0 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 10 AAPI 4 1 68 RPX MWD 10 OHI~M 4 1 68 RPS MWD 10 OHMM 4 1 68 RPM MWD 10 OHIO4 4 1 68 RPD MWD 10 OHMM 4 1 68 NPHI MWD 10 P.U. 4 1 68 ROP M~ 10 FT/H 4 1 68 FET MWD 10 HOUR 4 1 68 FCNT MWD 10 CNTS 4 1 68 NCNT MWD 10 CNTS 4 1 68 RHOB MWD 10 G/CC 4 1 68 DRHO MWD 10 G/CC 4 1 68 PEF MWD 10 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Na/ne DEPT GR RPX RPS RPM RPD NPHI ROP FET FCNT NCNT RHOB DRHO PEF Min 13617.5 22 9253 5 6032 6 0964 5 9399 6 1177 6 1015 4 1961 2 7118 646.794 2675.91 2.2693 -0.049 1.7314 Max Mean Nsam 14366 13991.8 1498 129.227 70.1151 1273 156.345 25.0752 1273 122.866 26.0509 1273 156.748 29.329 1273 148.848 29.3213 1273 41.6955 19.398 1273 154.98 23.857 1271 19.9881 7.48038 1273 1938.89 1012.47 1273 4732.1 3595.51 1273 2.8278 2.51495 1273' 0.1418 0.056081 1273 7.6829 2.64189 1273 First Reading 13617.5 13663 13643.5 13643 .5 13643.5 13643 . 5 13617.5 13731 13643 5 13617 5 13617 5 · 13652 5 13652 5 13652 5 Last Reading 14366 14299 14279.5 14279.5 14279.5 14279.5 14253.5 14366 14279 5 14253 5 14253 5 14288 5 14288 5 14288 5 First Reading For Entire File .......... 13617.5 Last Reading For Entire File ........... 14366 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/16 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/16 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/16 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File