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Home My WebLink About197-042 STATE OF ALASKA ALA. ,t OIL AND GAS CONSERVATION COMMIS_.JN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 11 Repair Well LJ Plug Perforations U Perforate LJ Other U R&R ESP Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 197-042 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-22748-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047437 Milne Pt Unit KR E-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,440' feet Plugs measured N/A RECEIVED true vertical 7,191' feet Junk measured N/A feet FE 102015 1 Effective Depth measured 9,332' feet Packer measured N/A feet true vertical 7,123' feet true vertical N/A feet AOG C Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' N/A N/A Surface 4,301' 9-5/8" 4,301' 3,561' 5,750psi 3,090psi Intermediate Production 9,419' 7" 9,419' 7,178' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic � - G r �� ,_�1f :.� SCANS C True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE8rd 9,090'MD 6,963'TVD Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 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: 0 0 0 0 0 Subsequent to operation: 169 22 622 180 188 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR El 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: 314-678 Contact Chris Kanyer Email ckanver(ahilcorg.com Printed Name Chris Kanyer Title Operations Engineer ISignature % , Phone 907-777-8377 Date 2/10/2015 IE� A -/z-is RBDM�l FEB 1 1 2015 Form 10-404 Revised 10/2012 e u<z/J Submit Original Only Milne Point Unit Well: MPE-18 SC EIVIATI C Last Completed: 1/25/2015 llilcorp Alaska,LLC PTD: 197-042 CASING DETAIL Orig.KB Elev.:33.55'/GL Elev.:24.7 Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 2a] 9-5/8" Surface 40/L-80/Btrc. 8.679 Surface 4,301' 7" Production 26/L-80/Btc Mod 6.151 Surface 9,419' 1 TUBING DETAIL 2-7/8" Tubing 6.4/L-80/N/A 2.347 Surface 9,090 3/8" Tubing Stainless Steel N/A Surface 9,090 JEWELRY DETAIL No Depth Item 9-5/8" • 1 1 137' GLM 2 8,763' GLM 3 9,020' 2-7/8"XN-Nipple(2.2005 No-go ID) 4 9,031' Discharge Head 5 9,032' Pump SXD 161 P11 6 9,054' Intake 7 9,059' Tandem Seal Section-Top 8 9,072' Motor 9 9,086' Pheonix Sensor w/6 Fin Centralizer—Bottom @ 9,090' PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kup.C Sands 9,133' 9,153' 6,987' 7,000' 20 4/25/1997 Open Kup.B Sands 9,156' 9,187' 7,002' 7,029' 31 4/25/1997 Open Perforation Charge Detail:"37 gm. Hyperjet II Charges(EHD=6",TTP=34.58")5 JSPF @ 60 deg.Phasing as°ssci,er cal FREEZE PROTECT Injection Line 70bbls Diesel WELL INCLINATION DETAIL KOP @ 300' Max Hole Angle=48.8 deg. @ 9,282' Hole Angle through perforations=47 deg. Only DLS>deg./100+4.7 @ 1,514' I 2 OPEN HOLE/CEMENT DETAIL 20" Cmt w/250 sks of Arcticset I in 24"Hole • 9-5/8" Cmt w/1,261 sks PF"E",865 sx Class"G"in 12-1/4"Hole 7" Cmt w/385 sks Class"6"in 8-1/2"Hole H; 3 TREE&WELLHEAD Tree 5M FMC 2-9/16" Eri, 4 Wellhead 11"x 7-1/16"5M FMC Gen 5A,w/2-7/8"FMC Tbg.Hngr.,3"LH ACME on top and 2-7/8"EU 8rd on bottom,2.5"CIW BPV Profile GENERAL WELL INFO 6 API:50-029-22748-00-00 Drilled and Cased by Nabors 4-ES -5/6/1997 Completed with ESP by Nabors 4ES—5/7/1997 • ESP Completion#2 w/Nabors 4-ES—2/26/2001 ESP Completion#3 w/Nabors 4-ES—7/22/2004 8 ESP Completion#4 w/Nabors 4-ES—8/4/2007 ESP Completion#4 w/Nordic 3—1/25/2015 ' 9 KUP C Sends Need Cementing Report to Establish Tops r KUP B Sands 7 j Il' TD=9,440'(MD)/TD=7,191'(TVD) PBTD=9,332'(MD)/PBTD=7,123'(TVD) Created By:TDF 2/10/2015 Hilcorp Alaska, LLC ,, ,,,., Weekly Operations Summary Well Name API Number _Well Permit Number Start Date End Date MPE-18 50-029-22748-020-00 197-042 1/17/2015 Future Daily Operations: 1/14/15-Wednesday No operations to report. 1/15/15-Thursday No operations to report. 1/16/15-Friday No operations to report. 1/17/15-Saturday No operations to report. 1/18/15-Sunday Moving in and rigging up. 1/19/15 Monday (? t Rig up lubricator install BPV.Spot Rig. Breakout all Hardline and fittings and move to cleanout. Rig up hot air to thaw 60 ? kill tank maifold and riser. BOP test Waived by AOGCC after 2200 and before 0500.Take on 500 bbls Heated Sea water. Take on Rig water for Boiler. Remove BPV. Rig up to circulate. Purge all lines and PT to 2,500psi. Reverse Circulate 1 tubing Volume 55 bbls swap over and circ conventional 316 bbls. Hot Sea Water 8.57 ppg holding 100psi back pressure.Total pumped 371bbls,total recovered 339bbls,total lost 32bbls. ISIP after kill 230psi. Bleed of to 190psi catch fluid.SI for 30 minutes 180psi, Bleed off to 150psi wait 30 minutes 140psi, Bleed to 100psi 30 min build to 120psi. EST BHP 3,239psi, use 100 psi safety factor equivelent 3,339psi.order 9.2 Brine and 151 sx NaCI for weight up to 9.4 ppg if needed. Load pipe racks with 30 jts tubing for trip swap of bad joints. Load 2-7/8"test joint.Offload and spot spooler,off load 438 bbls returns from Kill tank send to plant.Offload 90 bbls 8.5+Seawater.Continue to monitor well+- 100 psi.Will test BOP's next shift. 1/20/15-Tuesday Displace well with 9.2 sea water weighted with NaCI.Circ @ 3 BPM 340 bbls, losses 27 bbls.Well on light vacuum. Install BPV ND tree inspect and hang in cellar. NU 7-1/16"5 M DSA 11"5 M spacer spool with blinded outlets,11"5 M drilling spool with gate valves and external HCR both sides, 11"5M double BOP w/2-7/8" Rams top and CSO in bottom 11"5 M annular and install Bell nipple.Test waived by AOGCC again @ 1400 hrs. NU Choke and Kill lines install bell :Q nipple. Pull BPV Install TWC.Fill and purge system.Shell and Chart BOPE 250psi Low and 3,000psi high c/o anuular � \ hydraulis hose had hanger leaking problems on penetrators. Repeated pressure cycling Hanger packed off proceed ��' with testing BOPs 250psi low/3,000psi high test annular 250psi low/2,500psi high. Proceed and check all Choke maifold valves and chokes.Valve#4 on CM leaking tore down redress and lubricate valve yesyed OK. Perform Accumulator pressure and Draw down tests.All good. LD test Joint remove TWC well on very light vacuum,lnstal x-overs and landing joint tie on to top drive. Hook load blocks w top drive is 36K. PU and work String @ 105K hanger pulled free pipe moving with 5 K drag.SW is 69K actual. PU hanger above rotary and fill hole while Baker cutting off connector. Hole fill 20 BBIs in 18 hours w 9.2 ppg.Calling losses 1 BPH. b/o hanger and top 2 pup joints and LD same. Prepare to pull pipe. Pull first stand. Hand Derrick Sheave Thread ESP cable through top sheave, Pull 2nd stand to pull cable and tie to spooler. Install Herculite on Mats between spooler and rig beaver slide. Hilcorp Alaska, LLC HiIcor,,:„a„k:,.1.1,4: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPE-18 50-029-22748-020-00 197-042 1/17/2015 Future 'day Operations: 1/21/15-Wednesday PTSM.Complete spooler ESP line connection on 2nd stand continue POOH 43 stands and LD 32 Jts,observed bad joints due to wall loss,external corrosion and heavy slip damage. At approx 140 jts out LaSalle clamps can no longer be removed with wrench. Pneumatic chisel ESP clamps to remove.PTSM @ 1730.Continue POOH 1 more stand strap good pipe in derrick 4,110.30'(including jt#163 Internal pitting will be LD on clean out run.)Continue POOH, LD pipe, conditon improving around 250 jts out,continue LD pipe.Still chiseling ESP clamps for removal.POOH to ESP assy. _ POOH break out pump and LD same. Losses 24 hrs 97 bbls over normal 2-7/8 tbg displacement. PTSM @ 0530 1/22/15-Thursday PTSM.Continue LD of ESP assy. Rig up Dutch riser and Slickline.PU PDS caliper.JSA rig ops and vice versa. RIH to 1,000' and log 7"casing to surface with PDS caliper. LD Caliper and riser.Offload all tools. PU Scraper assembly with Mule shoe 7"29#csg scraper and Pup joint. Length 13.3'. RIH w/174 jts new 2-7/8"6.5#L-80 tubing ands 119 jts 2-7/8"of original production string. Run scraper to perfs @ 9,133'.RIH and wipe upper perfs w/4k down through lower perfs. 4K down continue to 9,200'. PU above perfs 2K drag. RU to circulate,circulating slow with 9.0 heavy NaCI.Work to 3 BPM. Mousehole break/LD last 5 stands in derrick while circulating work circ.rate to 5 BPM.Circ.until fluid density 9 heavy in/out light oil in returns,no solids. Total fluid lost 19 bbls. Cumulative total losses to date—181 bbls NaCI/seawater. RD circulating Iron and POOH, LD 117 jts remaining original production pipe.TOOH racking back new pipe. Dispatch packer/hand.Onload remainder of new pipe,to set packer @—8,600',50 jts left to pull. 1/23/15-Friday POOH LD Scraper. PU 7"Test Packer. RIH w test packer to 8,634'. PU 84K SO 70K Set packer. Pressure Test casing and ze Chart to 1,500 PSI/15 Min,no pressure loss.Test good.Release Packer. POOH and LD test Packer.Trip Losses 20 bbls. ,s+ Total cumulative losses 201 bbls.Offload tools.Onload tubing and prepare for ESP run. PU MU ESP Assy Service motor f1� and seals. Hang double sheave and thread 3/8"cap string and ESP cable. Pressure test capillary check valve to 5,000 D psi. No good.Change check and cycle 3,400psi check 6 times,OK. Install between stabilizer fins approx 30'below pump intake.Attempt to pressure test cap string after hook up.Pressures up to 5,000psi and bleeds off to 2,000psi repeat several times cannot test.Assume capillary frozen. Move in heater and hose under cap spool,cut off cap string to ESP from spooler.Thaw cap string. Run new cap string to floor and hook up to check on ESP. Pressure test cap string to 5,000psi.Cap string test to pump through check valve OK. Hook up ESP cable and test same. RIH with 2-7/8"6.5#L-80 8RD EUE production string and cannon clamps every other joint and Cap line through the cannon clamps. 1/24/15-Saturday PTSM Continue RIH with ESP and 3/8"capillary cannon clamps every other joint and safety band every 4 clamps on 3/8" cap string. Backlash on ESP Spool.Work on spool backlash. RIH with 2 stands to—3,014',cannot solve backlash decision made to cut and splice and then swap spools.Swapping spools and splicing ESP cable. PJSM.RIH with ESP and capstring 60 stands apprx 6,000' in,35 stands to go. 1/25/15-Sunday PTSM continue RIH w/ESP and cap string with 287 Jts 2-7/8" L-80 EUE. Install hanger with 5'pup below hanger,install penetrator.Install landing joint. Space out capillary for cut off and install capillary in bottom of hanger with pigtail above thru bore.Cut ESP cable and install connector and epoxy same. Install ESP cable and align penetrator.Drain BOP stack and blow down all suface lines. RIH and land hanger, pump depth is 9,090'. PU 105K S/O 60K Run in all lockdown screws. Install TWC.Offload all fluids,.ND BOPE NU Tree test to 500psi/5,000psi with Diesel/Test Void to 5,000psi. Good test.Test ESP Cable/Good Test Remove TWC. INFO ESP Bottom 9,090.05', 10'pup,XN Top 9,019.9',8 jts tbg,6' pup,Top of GLM 8,762.66'.6'pup,275 jts 2-7/8" L-80 6.5 EUE tbg.6'pup,Top of GLM 137.46',6'pup,64 jts 2-7/8" tbg,5'pup,and hanger. HARDWARE 159 ea cannon clamps,81 ea.steel bands,4ea.flat bar. Dress tree and capstring. Secure Cellar. PJSM. RDMO.Turn well over to production. Freeze protect well, begin rig move. 1/26/15-Monday No operations to report. 1/27/15-Tuesday No operations to report. 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. /~ 7- ~ 9'.z File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Odginal- Pages: [] Other- Pages: DIGITAL DATA D Diskettes, No. B Other, No/Type 'OVERSIZED [] .Logs of vadous kinds o Other Complete COMMENT~: Scanned by: Beverb, Miidred-D'are~~___~Lowell TO RE-SCAN Date.: ,, Is/ Notes: D,--,_C~t-~nnarl hi, l" ~.,~,.,,~ lJil~t~l ~.-nath~ Natl-mn Lowell Dale: /si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 5 NNE FEB S 21)2 ‘I , : Mr. Tom Maunder Alaska Oil and Gas Conservation Commission r ,r 1$3111] 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad I 9 r 7 — Dear Mr. Maunder, al p Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad 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 r, a.+ < u ,.. x .... _. .. �> ,. ..., w.mr� . ;.a ;^!:a �°t °:, .a�.._ u'cA'r•P _ a�s7� w: • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPE -Pad 10/10/2011 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 MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE-04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE-06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job ----". MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 8.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE-33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 · STATE OF ALASKA _ ,~~ ALA1rA Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission RECEIVED AUG 2 7 2007 1. Operations Performed: .... o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-042 ./ 3. Address; o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22748-00-00 ,,- 7. KB Elevation (ft): KBE = 58.25' 9. Well Name and Number: MPE-18 - 8. Property Designation: 10. Field / Pool(s): ADL 047437 < Milne Point Unit / Kuparuk River Sands t' 11. Present well condition summary Total depth: measured 9440 " feet true vertical 7191 " feet Plugs (measured) None Effective depth: measured 9332 feet Junk (measured) None true vertical 7124 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 112' 112' 1490 470 Surface 4266' 9-518" 4301' 3561' 5750 3090 Intermediate Production 9419' 7" 9419' 7178' 7240 5410 Liner Perforation Depth MD (ft): 9133' - 9187' / Perforation Depth TVD (ft): 6993' - 7029' 2-7/8" 6.5#, L-80 9112' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after work; o Exploratory 181 Development o Service 181 Daily Report of Well Operations 16. Well Status after work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 Printed Name Sondra Stewman Title Technical Assistant ..-""') . ~ Prepared By Name/Number: Sign'iUre ~ (f) "'1\:-v", Phone 564-4750 DateŒ ~7Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 R1G/NAL RBDMS 8ft. SEP 1 () 2007 Þ. ~\ l Submit Original Only ~~ Tree: 2-9/16" - 5M FMC Wellhead' 11"x7-1/16"5M FMC Gen 5A, w 2-7/8" FMC Tbg. Hgr., 3" LH Acme on top and 2-7/8" EU 8rd on bottom, 2.5" CIW BPV Profile 20" 91.1 ppf, H-40 ~ KOP @ 300' Max Hole Angle = 48.8 deg, @ 9282' (TO). Hole angle through perfs. = 47 deg. Only DLS >4 deg.l100 = 4.7 @ 1514' 9-5/8" 40#/ft., L-80 BTRC. 14301' I 2-7/8" 6.4 ppf, L-80 EU 8rd tbg ( drift id = 2.347" cap = .00592 bpf) 7" 26 ppf, L-80, BTRC production casing (drift ID = 6.151", cap = 0.02758 bpf with tubing) Stimulation Summary None performed Perforation Summary Ref. Log GR/CCL 04/15/97 Size SPF Interval TVD Kup"C" 4.5" 5 9133'-9153' (6987'-7000') Kup "B" 4.5" 5 9156'-9187' (7002'-7022') "37 gm. HyperJet II Charges (EHD = ¡" TTP = 34.58") 5 JSPF @ 60 deg phsg. DATE REV. BY MPU E-18 COMMENTS 2/26/01 GMH 7/22/04 Lee Hulme RWO Nabors 4ES RWO Nabors 4ES RWO Nabors 3S 8/4/07 Lee Hulme . RT Elev. = 58.25' (N27E) Orig. GL Elev. = 24.7' RT to Csg Spool = 33.4' (N27E) Camco 1" KBMM GLM I 140' Camco 1" KBMM GLM 8800' HES 2-7/8 "XN" Profile Nipple (NO-GO ID 2.205"). 9036' Pump, 160P11, Model SXD I 9052' Gas Separator Model - GRSFTXAR 19069' 16949' 19074' Intake @ (TVD) Tandem Seal Section GSB3DB UT/L T AB/HSN PFSNFSA CL5 Motor, 228 HP, 2305 volt, I 9088' 60 amp, Model KMHG . PumpMate XTO w/6 fin I 9108' Centralizer PumpMate TVD = 6976' 7" float collar (PBTD) 9332' 7" float shoe 9419' MILNE POINT UNIT WELL E-18 API NO. 50-029-22748 BP EXPLORATION (AK) . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-18 MPE-18 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 7/29/2007 8/5/2007 Spud Date: 3/22/1997 End: 8/5/2007 - To Hours 7/29/2007 18:00 - 00:00 6.00 I MOB N WAIT PRE Wait on trucks. Move rig carrier off K-38 @ 2300 - 0000 hrs I 07/29/07 wlo trucks. Rig on standby wI crews @ 0000 hrs 07/29/07. 713012007 00:00 - 00:00 24.00 MOB N WAIT PRE Moved carrier from K-37 to E-18 and RU on well. Wait on trucks to move pipe shed, tool shed, mud pits, Tiger tank and camp. 7/31/2007 00:00 - 10:00 10.00 MOB N WAIT PRE Wait on rig move trucks due to Doyon 14 rig move. 10:00 - 11 :00 1.00 MOB P PRE Move camp, shop, generator skid, mud pits, pipe shed from K Pad to E Pad. 11 :00 - 13:00 2.00 MOB P PRE Finish MIRU on E-18. RU mud lines. 13:00 - 18:00 5.00 BOPSU P PRE Reconfigure BOPE from 2 rams to 3 rams wI crane. Spot pipe shed. Continue RU BOPE. Accepted rig @ 1400 hrs 07/31/07. 18:00 - 20:30 2.50 BOPsu1 P PRE RU kill lines to tree. RU hard lines to Tiger tank. T = 500 psi, IA = 1050 psi, OA = 0 psi. 20:30 - 21 :30 1.00 DHB P DECOMP Pull BPV wI lubricator. T = 980 psi, IA = 1020 psi, OA = 0 psi 21 :30 - 22:00 0.50 KILL jP DECOMP Take on hot seawater to pits. Pressure test surface lines to I 3500 psi and hard lines to Tiger tank to 500 psi. 22:00 - 00:00 2.00 KILL IP DECOMP Circulate 55 bbls hot seawater down tubing to Tiger tank. I Bullhead 15 bbls hot seawater @ 2 bpm wi T = 1580 psi & IA = I I 1460 psi. 8/1/2007 00:00 - 02:00 2.00 KILL ip DECOMP Circulate 275 bbl hot seawater down tubing to Tiger tank @ 3 I bpm wi T = 1260 psi & IA = 660 psi. 02:00 - 02:30 0.50 KILL P DECOMP Shut well in and monitor pressures. Initial TSIP = 700 psi, 15-min TSIP = 730 psi. Calculated KWM = 10.6 ppg. 02:30 - 07:00 4.50 KILL P DECOMP Take on hot seawater and 11.0 ppg NaBr. Mix KWM to 10.6 ppg. Monitor pressures: 3-hr TSIP = 740/750 psi. Increase KWM to 10.7 ppg. Prepare to kill well wI 10.7 brine. 07:00 - 09:00 2.00 KILL P DECOMP Circulate 55 Bbls of 10.7 ppg NaBr at 3 BPM with T=1200 psi and IA=600 psi while taking returns out the IA and to the Tiger Tank. Bullhead 15 Bbls of 10.7 ppg NaBr at 3 BPM and 1250 psi. Circulate 170 Bbls of 10.7 ppg NaBr while taking returns out the IA and to the Tiger Tank at 3 BPM and T =900 psi, IA= 500 psi. 09:00 - 12:00 3.00 KILL P DECOMP Mix additional 10.7 ppg NaBr in Pits. 12:00 - 13:00 1.00 KILL P DECOMP Circulate 120 Bbls of 10.7 ppg NaBr at 3 BPM, T =1100 psi and IA=200 psi. Circulated while taking returns to the Tiger Tank until 10.7 ppg returns were seen. Lost a total of 10 Bbls during well kill. T/IAlOA=vac/20/0 psi. 13:00 - 13:30 0.50 KILL Ip DECOMP Monitor well for 30 minutes. T/IAlOA=vac/1010 psi. 13:30 - 17:30 4.00 KILL P DECOMP Circulate 300 Bbls of 10.7 ppg brine at 3.5 BPM and 1100 psi while taking returns to the Pits. T/I/O = 2/510 psi. Found NaBr/Salt in the bottom of pit #2. Discovered Gun Lines not working which could have caused the NaBrlSalt to settle to bottom of Pit. Fixed Gun Lines. T/I/O=vac/vac/O. 17:30 - 18:00 0.50 KILL P DECOMP Mix additional 1 0.7 ppg brine into pit #2. Blow down surface lines & choke. 18:00 - 19:00 1.00 DHB P DECOMP Set TWC. 19:00 - 20:00 1.00 DHB P DECOMP Test TWC from above to 3500 psi fl 10 charted minutes. I Attempt to pressure test to 1000 psi from below. Established I injection rate wI 3 bpm @ 600 psi. Pumped 6 bbls into formation. 20:00 - 22:00 2.00 WHSUR P DECOMP NO tree. Check 3" Acme threads wI 9 turns on hanger. Printed: 8114/2007 4:24:43 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name; Rig Name: MPE-18 MPE-18 WORKOVER NABORS ALASKA DRILLING I NABORS 3S 'ras(·JOode 2.00 B~p~:r 8/1/2007 22:00 - 00:00 8/2/2007 00:00 - 10:00 10:00 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 18:30 18:30 - 22:00 22:00 - 23:00 23:00 - 00:00 8/3/2007 00:00 - 01 :00 01 :00 - 09:30 09:30 - 11 :30 11 :30 - 15:00 15:00 - 18:00 18:00 - 20:00 20:00 - 00:00 8/4/2007 00:00 - 09:30 09:30 - 10:00 Start: Rig Release: Rig Number: Spud Date: 3/22/1997 End: 8/5/2007 7/29/2007 8/5/2007 DECOMP i 10.001 BOPSU~P I I i 5.00 BOPSU9 P i DECOMP DECOMP i BOPSUR P DHB Ip DHB ip I I i 3.50 I PULL i P 1.00 1.00 1.50 DECOMP DECOMP DECOMP DECOMP i 1.00 PULL Ip 1.00 PULL Ip I I 1.00 PULL P 8.50 PULL P 2.00 PULL P 3.50 PULL N 3.00 RUNCO 2.00 RUNCO P 4.00 AUNcot i DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP 9.50 RUNCO P RUNCMP 0.50 RUNCO P RUNCMP NU BOPE. Break stack to install new API ring on Hydril. Install DSA & mud cross. Remove spacer spool. BOPE reconfigured wI lower 2-7/8" x 5-1/2" single-gate VBRs, and upper double-gate wI blinds and 2-7/8" fixed rams. Torque studs. Continue to NU BOPE. Install Koomey hoses, kill and choke lines, flow riser. Install ram blocks. Shoot fluid level in well - 160'. Pressure Test BOPE to 250 psi low and 3500 psi high. Test witnessed by Bob Noble of the AOGCC. Ram Configuration: 2-7/8" x 5-1/2" VBRs, Blind Rams, 2-7/8" Fixed Rams, Annular Preventer. Drain Stack and test gas alarms. Changeout Cement Line. M/U Opso Lopso and Lubricator. PIT Lubricator to 500 psi. Pull TWC. T/INOA= vaclOIO psi. Break and UD Lubricator and Opso Lopso. Circulate 320 Bbls of 10.7 ppg brine at 2.5 BPM and 750 psi while taking returns to the pits. Shut down and monitor well. T/INOA= 01010 psi. Open Blind rams. R/U and drain stack P/U landing joint and RIH. M/U to TBG HGR. Check for gas and BOLDS. POOH wI TBG HGR to rig floor. HGR pulled free @ 65,000 Ibs and TBG string broke over at 70,000 Ibs. Up weight was 67,000 Ibs. Disassemble HGR and UD. UD landing joint. Fill hole and monitor well. l.osses around 4 BPH. Tie ESP cable into Centrilift Spooler. R/U to pull ESP completion. POOH wI 2-7/8", 6.5 ppf EUE 8rd TBG. Rack TBG in derrick. Recovered 149 LaSalle clamps, 5 Protectolizers, 3 Flatgaurds. All tubing was inspected and found to be in good condition. Conduct checks on ESP. Break and UD ESP per Centrilift recommendations. Keeping hole full with continuous fill. Wait on crew to arrive on location. Flight delays have delayed their arrival by 3-hrs. PUMU & service ESP. Pull Cable over sheave. Plug into ESP & meg Cable connection. R/U rig floor to RIH wI ESP completion. Remove La Salle Cable clamps from rig floor and rig. Replace with rebuilt clamps. Check conductivity of electric cable and RIH wI ESP completion on 2-7/8" EUE 8rd TBG. Clamp cable to first 9 joints and then every other joint. Use Best-O-Life dope. Make up each joint to an average make up torque of 2300 ft-Ibs. Ran bottom "XN" Nipple wI plug in profile and lower GLM wI open pocket. Check conductivity of electric cable each 2000' while RIH wI ESP completion on 2-7/8" EUE 8rd TBG. Clamp cable to first 9 joints and then every other joint. Use Best-O-Life dope. Make up each joint to an average make up torque of 2300 ft-Ibs. Ran 151 LaSalle Clamps, 5 Protectolizers, and 3 Flatgaurds. PU Landing Joint. PUMU to Tubing Hanger. Printed: 8/14/2007 4:24:43 PM . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-18 MPE-18 WORKOVER NABORS ALASKA DRilLING I NABORS 3S .S~~I:~~jriìpf;'ltøo 3.00 RUNCOt I \ RUNCMP 0.50 RUNCorr [ RUNCMP 1.00 RUNCOtp i RUNCMP 1.00 BOPSU~ P POST 2.00 BOPSU P . POST 2.00 BOPSU ,P [i POST 2.50 BOPSU1 P i POST 2.00 BOPSUI1 P POST 1.50 WHSUR P POST 1.50 WHSUR P , POST 0.50 DHB P POST 0.50 WHSUR P I POST 2.00 RIGD P , POST , , 8/4/2007 10:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 15:30 15:30 - 17:30 17:30 - 19:30 19:30 - 22:00 22:00 - 00:00 8/5/2007 00:00 - 01 :30 01 :30 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 06:00 Start: Rig Release; Rig Number: Spud Date: 3/22/1997 End: 8/5/2007 7/29/2007 8/5/2007 Space out and Centrilift makes final surface splice of ESP Cable. Make final cable test. Land Tubing Hanger. P/U weight = 68k-lbs. SIO weight = 45k-lbs. RILDS. Set and test TWC to 1000 psi from above. Test TWC to 250 psi from below by pumping at 3 BPM. Chart both tests. Wash Stack and choke manifold with fresh water. Blow down circulating lines. N/D choke and kill lines. Open ram doors and remove rams. Close and torque ram doors. N/D double gate ram bodies. Pick off stack with Annular and set aside. Break out Annular and reconfigure BOPE for K-17. N/D mud cross from Double Stud Adapter flange and set on cradle. N/D DSA flange from TBG Spool and set aside. P/U, orient, and set Adaptor Flange and tree on TBG spool. Perform Centrilift's final conductivity test on ESP penitrator. N/U Tree and Adaptor Flange. Test Adapter Flange void to 5000 psi and hold for 30 minutes. Pressure up and test Tree body to 5000 psi and hold for 10 charted minutes. Tests witnessed by BPX WSL. P/U DSM lubricator. R/U and pull TWC. Install BPV. RID DSM and UD DSM lubricator. Secure Tree and Cellar. Release Rig at 04:00 hrs. RDMO MPU E-18. Printed: 8/14/2007 4:24:43 PM STATE OF ALASKA ALASKA vlL AND GAS CONSERVATION COh,..JlISSION REce'VED REPORT OF SUNDRY WELL OPERATIONS AUG 161004 ~ ~ - t'._- 1. Operations Performed: Alas !!S~ 0 Abandon II Repair Well 0 Plug Perforations 0 Stimulate II ~orage 0 Alter Casing II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. permit r 0 Drill Number: BP Exploration (Alaska) Inc. II Development 0 Exploratory 197-042 3. Address: 0 Stratigraphic 0 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22748-00-00 7. KB Elevation (ft): KBE = 58.25' 9. Well Name and Number: MPE-18 8. Property Designation: 10. Field / Pool(s): ADL 047437 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 9440 feet true vertical 7191 feet Plugs (measured) Effective depth: measured 9332 feet Junk (measured) true vertical 7124 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 112' 112' 1490 470 Surface 4266' 9-5/8" 4301' 3561' 5750 3090 Intermediate Production 9419' 7" 9419' 7178' 7240 5410 Liner Perforation Depth MD (ft): 9133' - 9187' Perforation Depth TVD (ft): 693' - 7029' 2-7/8" 6.5#, L-80 9013' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RIIIIS BF L AU6 1 7 10°' 13. ReDresentative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: II Daily Report of Well Operations 0 Exploratory II Development 0 Service II Well Schematic Diagram 16. Well Status after proposed work: II Oil 0 Gas DWAG DGINJ DWINJ 0 WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knOWledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sandra Stewman Title Technical Assistant ~ ~ i 5 . ll-d-\': Prepared By Name/Number: Phone 564-4750 Date -'l' Sondra Stewman, 564-4750 A..I' Form 10-404 Revised 04/2004 Submit Ori inal Onl sian OQlGlNAI 9 y ~ ~ 2-9/16" - 5M FMC Wellhead: 11" x 7-1/16" 5M FIVIC Gen 5A, w 2-7/8" FMC Tbg. Hgr., 3" LH Acme on top and 2-7/8" EU 8rd on bottom, 2.5" CIW BPV Profile 20" 91.1 ppf, H-40 ~ KOP @ 300' Max Hole Angle = 48.8 deg, @ 9282' (TD). Hole angle through perfs. = 47 deg. Only DLS >4 deg.l100 = 4.7 @ 1514' 9-5/8" 40#/ft., L-80 BTRC. 14301' I 2-7/8" 6.4 ppf, L-80 EU 8rd tbg ( drift id = 2.347" cap = .00592 bpf ) 7" 26 ppf, L-80, BTRC production casing ( drift 10 = 6.151", cap. = 0.02758 bpf with tubing) Stimulation Summary None performed Perforation Summary Ref. Log GRlCCL 04/15/97 Size SPF Interval (TVD) Kup"C" 4.5" 5 9133'-9153' (6987'-7000') Kup "B" 4.5" 5 9156'-9187' (7002'-7022') "37 gm. HyperJet II Charges (EHD = 0.46", TTP = 34.58") 5 JSPF @ 60 deg phsg. DATE REV. BY COMMENTS 2/26/01 7/22/04 GMH Lee Hulme RWO Nabors 4ES RWO Nabors 4ES MPU E-18 ,..~ J. RT Elev. = 58.25' (N27E) ling. GL Elev. = 24.7' RT to Csg Spool = 33.4' (N27E) Cameo 1" KBMM GLM I 136' Cameo 1" KBMM GLM 1 8796' HES 2-7/8 "XN" Profile 18938' Nipple (NO-GO ID 2.205"). Pump, 159 stg. GC1150, I 8954' Model - GPMTARM 1:2 Tandem Gas Separator 18972' Model - GRSTXNARH6 Intake @ (TVD) 16882' Tandem Seal Section 18977' GSB3DB L T H6 FER FSA HSN Motor, 171 HP, 2290 volt, I 8991' 44 amp, Model KMH PumpMate w/6 fin 19008' Centralizer 7" float collar (PBTD) 9332' 7" float shoe 9419' MILNE PINT NIT ~ BP EXPL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date _.- 7/20/2004 7/21/2004 7/22/2004 7/23/2004 ~, . . ~ BP EXPLORATION Operations Summary Report MPE-18 MPE-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To I Hours I Task I Code NPT! Phase ! ---. 18:00 - 00:00 00:00 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 12:30 12:30 - 18:00 18:00 - 20:00 20:00 - 22:30 22:30 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 05:30 05:30 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 14:30 14:30 - 16:00 16:00 -17:30 17:30 - 19:30 19:30 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 03:30 03:30 - 05:30 05:30 - 06:00 06:00 - 07:30 07:30 - 09:00 ---.-- 6.00 MOB 8.00 MOB PRE PRE P P 1.50 KILL P DECOMP 0.50 KILL 2.50 KILL DECOMP DECOMP P P 5.50 KILL DECOMP P 2.00 KILL P DECOMP 2.50 KILL P DECOMP 0.50 WHSUR P 1.00 WHSUR P 2.00 BOPSUF P 3.50 BOPSUF P DECOMP DECOMP DECOMP DECOMP 1.00 WHSUR P 1.00 PULL P DECOMP DECOMP 1.00 PULL P DECOMP 6.00 PULL P 1.50 PULL P 1.50 RUNCor p 2.00 RUNCor p 4.50 RUNCor,p DECOMP DECOMP RUNCMP RUNCMP RUNCMP 0.50 RUNCor,p 2.50 RUNCor,p 0.50 RUNCor P 2.00 RUNCor P 0.50 RUNCor P 1.50 BOPSUF P 1.50 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Page 1 of 1 Start: 7/20/2004 Rig Release: 7/23/2004 Rig Number: Spud Date: 3/22/1997 End: 7/23/2004 Description of Operations 0.0. - -- ....-----..-.---- PJSM. Rig down & move rig from L-101 to Milne Point E-18. Continue moving rig & rig components from L-101 to Milne Point E-18. Rig up. Rig accepted @ 08:00 hrs, 07/21/2004. Held ATP wi Mark O'Malley, Milne pt Safety Coordinator Bob Cardon, Drill Site Operator & rig crew. Take on heated seawater to pits. Rig up lines to wellhead & tiger tank & PT same, OK. Pre Well Kill wi rig crew. SITP = 900 psi, SICP = 1070 psi. Open tubing to pump, open 27/8" x 7" annulus to choke & commence displacing well to heated seawater taking returns to tiger tank. Pump 1 00 bbls @ 4 bpm 11100 psi. Shut in & bullhead 25 bbls @ 2 bpm, 1525 psi final pressure. Continue displacing well, seeing seawater returns wi 350 bbls pumped. Shut in & observe. SICP & SITP = 600 psi. Order out 10.5 ppg sodium bromide. Wait on weighted fluid. Spot spooling unit. RlU tubing tools. Hang ESP sheave. Take on 10.5 ppg NaBr kill fluid. Check lines. Hold PJSM to kill well. SITP 610 psi, SICP 610 psi. Open well & Kill well wi 10.5 ppg fluid. Pumped 350 Bbls of fluid @ 4 BBPM , 1200 psi. SID & check return wt, 10.5 ppg. Swap lines to circulate to pits & check losses. Less than 2 bbls in 10 min. SID & monitor well. Hole stayed full. Well static. Set & test TWC.. Blow & RID lines to tree. Bleed void. N/D X-mas tree. N/U BOPE. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by John Spaulding wi AOGCC. M/U lubricator & pull TWC. UD lubricator. PJSM. P/U landing joint, screw into hanger, BOLDs. Pull hanger to floor, 77K to break free, 75K up wt. 8 bbls to fill hole. PJSM. Circulate (2) tbg volumes & rig up spooling unit. Monitor well, well stable. PJSM. POOH wi 2 7/8" ESP completion. Inspect drain & UD pump & motor. Clear & clean rig floor. Swap out cable spools. RID elephant trunk. P/U & M/U ESP. Service & plug in cable. RIH wi ESP on 2 7/8' tbg. Check cable every 2000'. Ran in hole wi 75 stands. (7000') Con't to RIH wi ESP. Ran 82 stands. (8736') Splice ESP cable. Finish RIH w/2 7/8" Tbg & ESP. Ran total 284 its. M/U hanger & landing jt. Install penetrator. Make connector splice. Land ESP completion. Bottom of string @ 9013'. RILDS. Set TWC PJSM. N/D BOPE. PJSM. N/U & test tree. Set BPV. Secure well. Rig released @ 09:00, 07/23/2004. Printed: 7/27/2004 10:43:52 AM STATE OF ALASKA ALASKA t)lL AND GAS CONSERVATION COMMI~,.,iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator i5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 58.25' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service ~ Location of well at surface 8. Well Number 3661' NSL, 1974' WEL, SEC. 25, T13N, R10E, UM MPE-18 At top of productive interval 9. Permit Number / Approval No. 197-042 1433' NSL, 1173' WEL, SEC. 23, T13N, R10E, UM 10. APl Number At effective depth 50-029-22748 1518' NSL, 1305' WEL, SEC. 23, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 1566' NSL, 1375' WEL, SEC. 23, T13N, R10E, UM Sands 12. Present well condition summary Total depth: measured 9440 feet Plugs (measured) true vertical 7191 feet Effective depth: measured 9332 feet Junk (measured) true vertical 7124 feet Casing Length Size Cemented MD TVD Structural Conductor 75' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 4266' 9-5/8" 1261 sx PF 'E', 865 sx Class 'G' 4301' 3561' Intermediate Production 9386' 7" 385 sx Class 'G' 9419' 7178' Liner Perforation depth: measured 9133' - 9153'; 9156' - 9187' true vertical 6993' - 7006'; 7008' - 7029' APR ! Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 9006'. Alaska Oil & Gas Cons. (;omrr~issio',~ Packers and SSSV (type and measured depth) None Anchoraae 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gne~~--~.. Title Techni. cal Assistant Date Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 QDtQIk!AI Submit In Duplicate,., ..~ !~ee: 2-9¢16" - 5M FMC Wellhead: 11" x 7-1/16" 5M FMC Gen 5A, w 2-7/8" FMC Tbg. Hng., 3" LH Acme on top and 2-7/8" EUE 8 rd on bottom, 2.5" CIW BPV Profile ,VIPU E-18 Orig. RT Bev.: Z5' (N27E) Orig. GL Elev. = 24.7' RT to Csg Spool = 33.4' (N27E) 20" 91.1 ppf, H-40 1112' IKOP @ 300' Max Hole Angle - 48.8 deg, @ 9282' (TD). Hole angle through perfs. -- 47 deg. Only DLS >4 deg./100 = 4.7 @ 1514' 9-5/8" 40#/ft., L-80 BTRC. 14301'1 Stimulation Summary_ None performed Perforation Summary_ Ref. Log GR/CCL 04/15/97 I size I SPFI Interval ('I-VD) 4.5" 5 9133'-9153' (6987'-7000') Kup "B" 14.5" I 5 19156'-9187' 7002'-7022') "37 gm. HyperJet II Charges (EHD = 0.46", TTP = 34.58") 5 JSPF @ 60 deg phsg. DATE REV. BY 2/26/01 GMH COMMENTS RWO Nabors 4ES Camco 2-7/8" x 1" I KBMM GLM I 136' Camco 2-7/8" x 1" I KBMM GLM J 8795' HES 2-7~8" 8rd. "XN" Profile 18937' I Nipple (ID 2.205"). Pump, 151 stg. GC1700, Model - GPMTAR 1'1 Standard Bolt-On Intake Model- GPINTHP3 Intake @ (TVD) Tandem Seal Section Model GST34BILPFS Motor, 171 HP, 2390 volt, 44 amp, Model KMH PumpMate w/6 fin Centralizer 8953' I6983' 7" float collar (PBTD) I 9332' 7" float shoe I 9419' MILNE POINT UNIT WELL E-18 APl NO. 50-029-22748 BP EXPLORATION fAK) : 0pe a ionssummary Report Legal Well Name: MPE-18 Common Well Name: MPE-18 Spud Date: 3/22/1997 Event Name: REPAIR Start: 2/25/2001 End: Contractor Name: NABORS Rig Release: 2/27/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: : ~at~ ~ro~! ~ I ~rs ~ ~i~ ~: ~ Description of Operations 2/25/2001 00:00 - 06:00 6.00 MOB PRE MOVE FROM MPH-05 TO MPE-18. SET RIG MATS & BERM. RAISE & SCOPE DERRICK. ACCEPTED RIG @ 0600 HRS 2-23-01. 06:00 - 08:00 2.00 RIGU PRE SPOT & BERM TIGER TANK. HOOK UP HARD LINES TO X-MAS TREE. 08:00 - 09:00 1.00 WHSUR DECOMP P/U LUBRICATOR & PULL BPV. L/D SAME. 09:00 - 10:00 1.00 PULL DECOMP PRESSURE TEST HARD LINES TO 3000 PSI, OK. TAKE ON 10.6 PPG BRINE. 10:00 - 13:00 3.00 KILL DECOMP HOLD SAFETY MTG. OPEN WELL. SITP 800 PSI, SICP 800 PSI. KILL WELL @ 3 BPM. 1100 PSI. KILLED W/360 BBLS. S/D & OBSERVE WELL. WELL DEAD. 13:00 - 13:30 0.50 WHSUR DECOMP INSTALL TWO VALVE. 13:30 - 14:30 1.00 WHSUR DECOMP N/D X-MAS TREE. 14:30- 16:30 2.00 BOPSUF DECOMP N/U BOPE. 16:30 - 17:30 1.00 BOPSUF DECOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI. WITNESSING WAIVED BY JOHN CRISP W/AOGCC. 17:30- 18:30 1.00 WHSUR DECOMP PULL TWC VALVE. 18:30 - 19:30 1.00 WHSUR DECOMP P/U LANDING JT. BOLDS. PULL HANGR. P/U 76K. CHECK PENETRATOR. 19:30 - 20:00 0.50 PULL DECOMP FILL HOLE W/9 BBLS BRINE. OBSERVE WELL. WELL DEAD. 20:00 - 00:00 4.00 PULL DECOMP PULL 2 7~8" COMPLETION STRING. 2/26/2001 00:00 - 02:00 2.00 PULL DECOMP POOH W/2 7~8" COMPLETION STRING TO 8700'. 02:00 - 03:00 1.00 PULL DECOMP OBSERVE WELL. WELL DEAD. FINISH POH W/TBG STRING. 03:00 - 04:30 1.50 PULL DECOMP INSPECT & L/D ESP. 04:30 - 05:00 0.50 PULL DECOMP RIH & L/D 3 JTS OF BAD 2 7~8" TBG. 05:00 - 05:30 0.50 PULL DECOMP CLEAN RIG FLOOR.& SERVICE RIG. 05:30 - 08:00 2.50 RUNCOI~ COMP P/U & SERVICE NEW ESP. 08:00 - 09:00 1.00 RUNCOI~ COMP PLUG IN & TEST ESP/PUMP MATE. 09:00 - 12:00 3.00 RUNCOI~ COMP RIH W/2 7~8" COMPLETION STRING. PUMP THRU PUMP @ 1000', 3000' & 4500'. 12:00 - 15:30 3.50 RUNCOr i COMP MAKE MID-RUN CABLE SPLICE & TEST SAME. 15:30 - 18:30 3.00 RUNCOr COMP CON'T TO RIH W/2 7~8" COMPLETION STRING. 18:30 - 19:00 0.50 RUNCO~ COMP M/U HANGER & SPACE OUT SAME. 19:00 - 21:30 2.50 RUNCOt COMP MAKE UP CABLE SPLICE. FLUSH PUMP & TEST CONNECTION. 21:30-22:00 0.50 RUNCO~4 COMP LAND HANGER. RILDS. P/U WT 75K, SIC WT43K. 22:00 - 22:30 0.50 RUNCO~I COMP SET TWO VALVE. TEST TO 2500 PSI. DRAIN DOWN BOP STACK. 22:30 - 00:00 1.50 BOPSUF COMP N/D BOPE. 2/27/2001 00:00 - 01:00 1.00 WHSUR COMP N/U X- MAS REE. 01:00 - 01:30 0.50 WHSUR COMP PRESSURE TEST ADAPTER FLANGE & TREE. TO 5000 PSI, OK. CHECK PENETRATOR. 01:30 - 02:30 1.00 WHSUR COMP PULL TWO VALVE & INSTALL BPV. 02:30 - 04:00 1.50 WHSUR COMP FREEZE PROTECT WELL WI 65 BBLS DEAD CRUDE DOWN ANNULUS & 15 BBLS DIESEL DOWN TBG. CLEAN CELLAR & SECURE WELL. RELEASE RIG @ 0400 HRS, 2-27-01. Printed: 3/5/2001 2:14:31 PM THE MATER/AL UNDER THIS COVER HAS BEEN ON OR BEFORE PL M ATE E C:LO~M. DOC W IA L UNDER T H -------------~-----~----____._ IS M ARK ER ---- PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 97-042 PERF 97-042 GR/CCL 97-042 7676 97-042 DGR/EWR4-MD ~.~8900-9270 · 5/4320-9940 97-042 DGR/CNP/SLD-MD 97-042 DGR/CNP/SLD-TVD 97-042 DGR/EWR4-TVD -~3:575-7191 · 97-042 MWD SRVY ~C~ERRY 0-9440. 97-042 MMS SRVY 10-407 DAILY WELL OPS '~R~'~S PERRY 4463.5-9242.7 · '7' .'>-" ' " ".~ ' -. ~/'COMPLETION DATE @ ~ @ 31~'!1~??1 TO .fl ! /??/ Are dry ditch samples required? yes L'n~ And received? Was the well cored? yes no~.Analysis & description received? · .~: .... Are well tests required?~s ~_~Received? *~ Well is in compliance Initial COMMENTS FINAL 04/25/97 FINAL 05/09/97 i o~io9/97 FINAL 05/28/97 FINAL 05/28/97 FINAL 05/28/97 FINAL 05/28/97 01/09/98 01/09/98 @ t/~/?~/ ~ I/~/~/ yes: no T D BOX -- STATE OF ALASKA ~. F C E IV E D ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG. JAN ---9 1998 1. Status of Well Classification o~q~lV~as Cons. Comm~ [] Oil [] Gas [] Suspended [] Abandoned [~ Service Annhnmn~. 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-42 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22748 4. Location of we,, at surface ~ '~%~? 9. Unit or Lease Name 3661' NSL, 1974' WEL, SEC. 25, T13N, R10E, UM , .::_. :i.. ':~.?~"~~--m'Jm'~i Milne Point Unit 1434' NSL, 1174' WEL, SEC. 23, T13N, R10E, UM .?.._j ~ MPE-18 At total depth~ ~ .....~.~.~ 11 . Field and Pool 1567' NSL, 1375' WEL, SEC. 23, T13N, R10E, UM - . _ - ....... Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 58.25'I ADL 047437 12. Date Spudded3/22/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' water depth' if OffshOre 116' NO' °f c°mpleti°ns3/29/97 5/6/97 N/A MSLI One 17. Total Depth (MD+TVD)9440 7191 FTIjl 8' Plug Back Depth (MD+TVD)J19' Directi°nal SurveY 120' Depth where SSSV set 121' Thickness °f Permafr°st9332 7123 FTI []Yes I-q No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR/CCL, LWD, ESS 23. CASING, LINER AND CEMENTING RECORD CASING SE'Fi-lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 37' 112' 24" ;'50 sx Arcticset I (Approx.) 9-5/8" 40# L-80 35' 4301' 12-1/4" 1261 sx PF 'E', 865 sx Class 'G' 7" 26# L-80 33' 9419' 8-1/2" 385 sx 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 2-7/8", 6.5#, L-80 8977' MD 'I-VD MD TVD 9133'-9153' 6992'-7006' 9156'-9187' 7008'-7029' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 70 bbls diesel ~7. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) May 23, 1997 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF iWATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure iCALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · - . ssl0~ Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Kuparuk 8879' 6818' KC1 9123' 6985' Top Kuparuk 'B' 9143' 6999' Top Kuparuk B6 9183' 7026' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .,,1 Chip Alvord ,./'~,~ Title Senior Drilling Engineer Date '(7(y~ MPE-18 97-42 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 0RIGINA RECEIVED blask~ 0il & G~s C0r~s. c0mmiss[0~ Anchorage SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPE-18 Rig Name: N-4ES AFE# 347065 Accept Date: 05/04/97 Spud Date: - Release Date: 05/06/97 May 5, 1997 MIRU. Rig accepted 05/04/97 @ 2300 hrs. Set berm TT, take on brine. ND frac tree. NU adapter flange, BOP. Pull BPV, set test plug. Test BOP. May 6, 1997 Test BOP. Load pipe shed with 2-7/8" tubing. MU RBP tool, RIH t/2256'. Circ out freeze protect w/brine. Cont RIH with 2-7/8" tubing RBP tool. Slip 42' drill line, adjust brakes. Cont RIH t/8947'. Circ out displace seawater w/brine. RIH tag RBP @ 9018', set down 5K. Monitor well static, release 5K over. RIH t/9042'. Circ around brine, recover 7 bbls crude, total fluid loss 8 bbls. Pump 20 bbls pill per program, monitor well static. TOH w/RBP, LD same. RU to run ESP, pull WR May 7, 1997 Lub rig. RIH with 2-7/8" ESP assy. MU ESP cable splice. Cont RIH, MU hanger & landing jt. MU ESP pigtail splice @ hanger. Land tubing, RILDS, LD landing jt, set 'I'VVC. ND BOP, NU tree, test tree & hanger t/5000#. Pull TWC, set BPV, RU HD lines. Freeze protect w/10 bbls diesel down tubing, 60 bbls bullhead down annulus. Blow down lines, RD secure well/cellar/check ESP, ok. Rig released 05/06/97 @ 1930 hrs. Page Performance Enquiry Report Operator BP Exploration Date 21:52, 12 Dec 97 Page 1 The analysis is from - 07:00, 27 Mar 97 - to - 07:00, 27 Mar 97 Programs in Result Table: MPE-18 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPE-18 Event 07:00, 27 Mar 97 07:00, 27 Mar 97 0 hr 0 min Obtained leak off 13.1 Hole Size MDR 8-1/2 Facility Date/Time 21 Mar 97 22 Mar 97 23 Mar 97 24 Mar 97 25 Mar 97 26 Mar 97 Progress Report M Pt E Pad Well MPE- 18 Rig Nabors 27E Page 1 Date 12 December 97 14:00-20:00 20:00-01:00 01:00-06:00 06:00-11:00 11:00-17:00 17:00-19:00 19:00-20:00 20:00-20:30 20:30-21:00 21:00-23:00 23:00-23:30 23:30-01:00 01:00-03:30 03:30-06:00 06:00-06:30 06:30-10:30 10:30-11:30 11:30-21:00 21:00-21:30 21:30-22:00 22:00-22:30 22:30-23:00 23:00-23:30 23:30-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-14:00 14:00-14:30 14:30-15:00 15:00-16:00 16:00-16:30 16:30-00:00 00:00-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-09:30 09:30-11:00 11:00-12:30 12:30-15:00 15:00-16:30 16:30-21:00 21:00-21:30 21:30-23:30 23:30-01:00 01:00-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-09:00 Duration 6hr 5hr 5hr 5hr 6hr 2hr lhr 1/2 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr 4hr lhr 9-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr lhr 2hr lhr 1/2 hr 1-1/2 hr 6hr 1/2 hr 1/2 hr lhr 1/2 hr 7-1/2 hr 5-1/2 hr 1/2 hr lhr lhr 1/2 hr lhr 1-1/2 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 2hr 1-1/2 hr 3hr 1-1/2 hr 1/2hr 1/2 hr 2-1/2 hr Activity Rigged down Handling equipment Removed Drillfloor / Derrick Rig moved 70.00 % Rig moved 100.00 % Rigged up Divertor Rigged up Drillfloor / Derrick Made up BHA no. 1 Held safety meeting Tested Divertor Tested Fluid system Cleared Bell nipple Drilled to 220.0 ft Made up BHA no. 1 Drilled to 534.0 ft Held safety meeting Drilled to 864.0 ft Circulated at 864.0 ft Drilled to 2130.0 ft Circulated at 2130.0 ft Pulled out of hole to 1012.0 ft R.I.H. to 2139.0 ft Drilled to 2223.0 ft Circulated at 2223.0 ft Pulled out of hole to 0.0 ft Pulled BHA Made up BHA no. 2 Serviced Top drive Serviced Top drive R.I.H. to 2223.0 ft Drilled to 3328.0 ft Circulated at 3328.0 ft Pulled out of hole to 1545.0 ft R.I.H. to 3328.0 ft Drilled to 3517.0 ft Repaired Mud pumps Drilled to 4320.0 ft Circulated at 4320.0 ft Circulated at 4320.0 ft Pulled out of hole to 1050.0 ft Serviced Top drive R.I.H. to 4320.0 ft Circulated at 4320.0 ft Pulled out of hole to 210.0 ft Pulled BHA Rigged up Casing handling equipment Ran Casing to 4301.0 ft (9-5/8in OD) Rigged up Cement head Circulated at 4301.0 ft Mixed and pumped slurry - 305.000 bbl Circulated at 1312.0 ft Mixed and pumped slurry - 382.000 bbl Serviced Casing handling equipment Serviced Divertor Serviced Top drive Facility Date/Time 27 Mar 97 28 Mar 97 29 Mar 97 30 Mar 97 31 Mar 97 M Pt E Pad Progress Report Well MPE-18 Rig Nabors 27E Page Date Duration 09:00-11:00 2hr 11:00-12:00 1 hr 12:00-16:00 4 hr 16:00-19:00 3 hr 19:00-20:00 1 hr 20:00-22:30 2-1/2 hr 22:30-23:30 1 hr 23:30-00:00 1/2 hr 00:00-01:00 1 hr 01:00-03:00 2 hr 03:00-04:00 1 hr 04:00-04:30 1/2 hr 04:30-06:00 1-1/2 hr 06:00-06:30 1/2 hr 06:30-07:00 1/2 hr 07:00-16:00 9 hr 16:00-16:30 1/2 hr 16:30-17:00 1/2 hr 17:00-17:30 1/2 hr 17:30-05:30 12 hr 05:30-06:00 1/2 hr 06:00-07:00 1 hr 07:00-08:00 1 hr 08:00-22:00 14 hr 22:00-22:30 1/2 hr 22:30-23:00 1/2 hr 23:00-23:30 1/2 hr 23:30-06:00 6-1/2 hr 06:00-11:00 5 hr 11:00-12:00 1 hr 12:00-12:30 1/2 hr 12:30-13:00 1/2 hr 13:00-14:30 1-1/2 hr 14:30-17:30 3 hr 17:30-19:00 1-1/2 hr 19:00-23:30 4-1/2 hr 23:30-00:00 1/2 hr 00:00-00:30 1/2 hr 00:30-03:00 2-1/2 hr 03:00-06:00 3 hr 06:00-08:00 2 hr 08:00-10:30 2-1/2 hr 10:30-11:00 1/2 hr 11:00-11:30 1/2 hr 11:30-13:00 1-1/2 hr 13:00-22:00 9 hr 22:00-01:00 3 hr 01:00-03:00 2 hr 03:00-04:00 1 hr 04:00-06:00 2 hr 06:00-07:00 1 hr 07:00-08:30 1-1/2 hr 08:30-11:00 2-1/2 hr 11:00-12:30 1-1/2 hr Activity Rigged down Divertor Installed Casing head Rigged up BOP stack Tested BOP stack Installed Wear bushing Made up BHA no. 3 Serviced Top drive R.I.H. to 1310.0 ft Drilled installed equipment - DV collar R.I.H. to 4200.0 ft Tested Casing Held drill (Stripping) Drilled installed equipment - Landing collar Circulated at 4340.0 ft Performed formation integrity test Drilled to 5816.0 ft Circulated at 5816.0 ft Pulled out of hole to 4300.0 ft R.I.H. to 5816.0 ft Drilled to 7317.0 ft Circulated at 7813.0 ft Pulled out of hole to 5000.0 ft R.I.H. to 7317.0 ft Drilled to 8531.0 ft Circulated at 8531.0 ft Pulled out of hole to 6800.0 ft R.I.H. to 8531.0 ft Drilled to 9031.0 ft Drilled to 9440.0 ft Circulated at 9440.0 ft Pulled out of hole to 8510.0 ft R.I.H. to 9440.0 ft Circulated at 9440.0 ft Pulled out of hole to 4301.0 ft R.I.H. to 9440.0 ft Circulated at 9440.0 ft Pulled out of hole to 8510.0 ft R.I.H. to 9440.0 ft Circulated at 9440.0 ft Pulled out of hole to 4300.0 fl Pulled out of hole to 215.0 ft Pulled BHA Rigged down Drillfloor / Derrick Retrieved Wear bushing Rigged up Casing handling equipment Ran Casing to 9418.0 ft (7in OD) Circulated at 9418.0 ft Mixed and pumped slurry - 140.000 bbl Tested Casing Serviced Drillfloor / Derrick Serviced Wellhead integral components Rigged down BOP stack Installed Xmas tree Serviced Block line 2 12 December 97 Facility M Pt E Pad Progress Report Well MPE- 18 Rig Nabors 27E Page Date 3 12 December 97 Date/Time 12:30-17:00 17:00-06:00 Duration 4-1/2 hr 13 hr Activity Laid out 5in drill pipe from derrick Rig moved 65.00 % SPE' .... '-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOR3~TION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 MWD SURVEY JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 OPERATOR: 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. .00 .00 -58.25 210.74 210.74 152.49 299.21 299.19 240.94 389.81 389.75 331.50 480.35 480.21 421.96 0 0 N .00 E .00 .00N .00E 0 30 N 58.00 W .24 .49N .78W 1 30 S 82.99 W 1.32 .55N 2.26W 1 59 S 87.60 W .55 .34N 5.02W 2 44 N 85.44 W .89 .44N 8.75W .00 .92 2.16 4.28 7.38 568.72 568.44 510.19 658.61 658.05 599.80 749.47 748.35 690.10 778.01 776.66 718.41 870.16 867.88 809.63 3 32 S 76.90 W 1.42 .01S 13.52W 5 22 S 79.52 W 2.05 1.41S 20.37W 7 10 S 71.39 W 2.20 3.99S 29.94W 7 32 S 72.06 W 1.29 5.14S 33.41W 8 42 S 76.91 W 1.47 8.58S 45.96W 11.00 15.77 22.06 24.22 32.44 957.22 953.89 895.64 1050.88 1046.23 987.98 1144.01 1137.33 1079.08 1235.70 1225.86 1167.61 1329.87 1315.85 1257.60 9 3 S 82.96 W 1.15 10.91S 59.19W 10 18 N 83.00 W 2.84 10.80S 74.82W 13 36 N 74.52 W 4.00 6.86S 93.64W 16 34 N 67.14 W 3.86 1.10N 116.09W 17 40 N 63.50 W 1.62 12.70N 141.26W 41.85 54.65 72.26 95.16 122.39 1421.29 1402.47 1344.22 1514.32 1489.01 1430.76 1608.22 1573.49 1515.24 1699.11 1651.73 1593.48 1793.17 1731.46 1673.21 19 34 N 58.38 W 2.74 26.92N 166.72W 23 28 N 52.98 W 4.70 46.25N 194.79W 28 14 N 50.00 W 5.26 71.80N 226.76W 32 53 N 47.57 W 5.29 102.29N 261.46W 31 11 N 46.19 W 1.97 136.39N 297.89W 151.37 185.45 226.32 272.28 321.73 1887.56 1811.51 1753.26 1979.06 1887.71 1829.46 2072.50 1963.61 1905.36 2166.76 2037.46 1979.21 2237.37 2091.08 2032.83 32 46 N 46.89 W 1.73 170.77N 334.18W 34 26 N 50.05 W 2.63 204.31N 372.10W 36 54 N 53.48 W 3.40 237.98N 414.92W 39 55 N 55.74 W 3.52 271.86N 462.67W 41 15 N 55.98 W 1.91 297.64N 500.70W 371.24 421.58 475.99 534.55 580.47 2331.98 2161.60 2103.35 2425.46 2229.78 2171.53 2519.55 2297.66 2239.41 2611.45 2363.74 2305.49 2704.44 2430.63 2372.38 42 21 N 55.65 W 1.19 333.08N 552.87W 43 57 N 56.15 W 1.75 368.92N 605.81W 43 40 N 55.53 W .54 405.50N 659.72W 44 22 N 55.74 W .78 441.55N 712.44W 43 36 N 56.14 W .88 477.73N 765.95W 643.53 707.44 772.57 836.43 901.00 2799.52 2498.27 2440.02 2894.15 2564.55 2506.30 2987.42 2630.23 2571.98 3081.60 2696.78 2638.53 3176.25 2763.83 2705.58 45 40 N 56.20 W 2.18 514.92N 821.45W 45 23 N 56.15 W .31 552.51N 877.55W 45 4 N 56.28 W .35 589.34N 932.59W 45 0 N 55.92 W .28 626.51N 987.91W 44 46 N 55.45 W .43 664.17N 1043.08W 967.78 1035.28 1101.48 1168.10 1234.88 SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 MWD SURVEY JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 FT. OPERATOR: BP EXPLORATION 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. 3269.23 2829.84 2771.59 3363.52 2896.89 2838.64 3458.51 2964.64 2906.39 3552.73 3031.67 2973.42 3646.99 3098.73 3040.48 44 46 N 55.49 W .04 701.28N 1097.03W 44 34 N 55.75 W .28 738.72N 1151.74W 44 25 N 55.64 W .18 776.25N 1206.74W 44 52 N 55.62 W .47 813.63N 1261.39W 44 25 N 55.69 W .48 851.00N 1316.08W 1300.35 1366.64 1433.21 1499.41 1565.63 3741.00 3165.99 3107.74 3834.35 3232.96 3174.71 3925.68 3297.56 3239.31 4018.52 3362.43 3304.18 4112.04 3428.04 3369.79 44 13 N 56.95 W .96 887.42N 1370.74W 44 4 N 56.39 W .45 923.15N 1425.07W 45 52 N 54.70 W 2.36 959.68N 1478.28W 45 28 N 56.23 W 1.25 997.33N 1532.99W 45 25 N 56.41 W .15 1034.29N 1588.45W 1631.28 1696.26 1760.79 1827.19 1893.80 4204.89 3493.35 3435.10 4261.39 3533.20 3474.95 4370.97 3610.72 3552.47 4463.50 3676.82 3618.57 4557.06 3744.40 3686.15 45 10 N 58.47 W 1.60 1069.80N 1644.05W 45 8 N 59.57 W 1.38 1090.42N 1678.40W 44 49 N 55.64 W 2.55 1131.90N 1743.79W 43 58 N 55.92 W .95 1168.30N 1797.31W 43 32 N 57.15 W 1.02 1203.98N 1851.29W 1959.70 1999.63 2076.95 2141.68 2206.34 4650.59 3812.47 3754.22 4742.98 3879.45 3821.20 4834.74 3945.52 3887.27 4928.76 4013.41 3955.16 5019.67 4079.30 4021.05 43 3 N 56.57 W .67 1239.05N 1905.00W 44 0 N 55.62 W 1.25 1274.55N 1957.81W 43 52 N 55.60 W .15 1310.51N 2010.35W 43 40 N 55.90 W .30 1347.12N 2064.12W 43 25 N 56.80 W .74 1381.83N 2116.26W 2270.42 2334.03 2397.69 2462.72 2525.33 5113.37 4146.58 4088.33 5206.08 4212.24 4153.99 5301.38 4279.84 4221.59 5393.51 4345.41 4287.16 5486.67 4411.28 4353.03 44 47 N 55.63 W 1.70 1418.09N 2170.45W 45 1 N 55.94 W .34 1454.89N 2224.57W 44 37 N 55.67 W .46 1492.65N 2280.13W 44 37 N 57.12 W 1.11 1528.46N 2334.03W 45 22 N 54.88 W 1.88 1565.30N 2388.63W 2590.50 2655.93 2723.09 2787.77 2853.61 5580.09 4476.99 4418.74 5673.47 4542.94 4484.69 5764.42 .4607.47 4549.22 5861.06 4676.33 4618.08 5954.53 4743.02 4684.77 45 13 N 55.30 W .36 1603.30N 2443.08W 44 54 N 56.63 W 1.06 1640.30N 2497.85W 44 42 N 57.28 W .55 1675.25N 2551.58W 44 24 N 54.80 W 1.83 1713.11N 2607.80W 44 33 N 56.90 W 1.58 1749.87N 2662.00W 2920.01 2986.09 3050.12 3117.88 3183.35 6048.54 4810.10 4751.85 6141.12 4876.32 4818.07 6235.15 4943.28 4885.03 6328.50 5009.38 4951.13 6422.06 5075.58 5017.33 44 23 N 54.05 W 2.13 1787.19N 2716.25W 44 16 N 54.11 W .13 1825.14N 2768.64W 44 54 N 55.33 W 1.12 1863.26N 2822.53W 44 57 N 53.49 W 1.39 1901.63N 2876.13W 44 58 N 52.71 W .59 1941.32N 2929.00W 3249.18 3313.88 3379.89 3445.80 3511.89 · PAGE 3 SPEI -SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLOP~ATION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 MWD SURVEY JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 OPERATOR: 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. 6516.63 5142.41 5084.16 45 5 N 53.48 W .59 1981.50N 2982.50W 6609.16 5207.83 5149.58 44 54 N 54.63 W .90 2019.91N 3035.47W 6702.73 5274.19 5215.94 44 45 N 54.36 W .27 2058.22N 3089.17W 6794.78 5339.43 5281.18 44 59 N 56.62 W 1.75 2095.00N 3142.68W 6889.46 5406.81 5348.56 44 16 N 53.90 W 2.16 2132.89N 3197.33W 3578.78 3644.21 3710.18 3775.10 3841.59 6984.32 5474.57 5416.32 44 33 N 54.81 W .74 2171.57N 3251.27W 7077.23 5541.38 5483.13 43 28 N 53.33 W 1.61 2209.44N 3303.55W 7171.73 5609.72 5551.47 43 53 N 54.40 W .90 2247.92N 3356.26W 7265.28 5677.65 5619.40 42 58 N 55.22 W 1.14 2284.99N 3408.81W 7360.03 5746.74 5688.49 43 23 N 55.00 W .46 2322.08N 3462.00W 3907.97 3972.52 4037.78 4102.09 4166.93 7455.00 5815.61 5757.36 43 38 N 54.20 W .64 2359.96N 3515.30W 7547.54 5882.40 5824.15 43 57 N 53.87 W .42 2397.58N 3567.14W 7642.50 5950.57 5892.32 44 17 N 55.37 W 1.15 2435.85N 3621.04W 7735.62 6017.40 5959.15 44 0 N 51.07 W 3.23 2474.66N 3672.97W 7830.78 6085.59 6027.34 44 27 N 51.55 W .60 2516.15N 3724.78W 4232.32 4296.37 4362.47 4427.28 4493.56 7923.46 6151.36 6093.11 45 7 N 51.06 W .80 2556.97N 3775.74W 8015.93 6216.15 6157.90 45 55 N 50.68 W .91 2598.61N 3826.91W 8106.76 6279.84 6221.59 45 1 N 53.06 W 2.11 2638.59N 3877.83W 8199.43 6345.11 6286.86 45 25 N 53.80 W .72 2677.78N 3930.66W 8291.85 6410.27 6352.02 44 54 N 55.40 W 1.35 2715.75N 3984.08W 4558.75 4624.59 4689.25 4755.02 4820.56 8385.87 6476.25 6418.00 45 57 N 56.08 W 1.22 2753.45N 4039.44W 8477.94 6540.56 6482.31 45 26 N 55.88 W .58 2790.31N 4094.05W 8571.48 6605.63 6547.38 46 23 N 55.03 W 1.21 2828.41N 4149.39W 8664.38 6670.08 6611.83 45 45 N 55.38 W .74 2866.59N 4204.33W 8760.27 6736.74 6678.49 46 10 N 55.20 W .47 2905.85N 4260.99W 4887.52 4953.39 5020.57 5087.46 5156.39 8856.21 6802.56 6744.31 47 10 N 55.08 W 1.04 2945.74N 4318.26W 8949.96 6866.82 6808.57 46 17 N 55.42 W .98 2984.65N 4374.35W 9043.13 6930.98 6872.73 46 40 N 57.84 W 1.93 3021.80N 4430.76W 9137.98 6995.72 6937.47 47 14 N 57.21 W .77 3059.02N 4489.24W 9230.88 7057.87 6999.62 48 45 N 57.37 W 1.64 3096.32N 4547.32W 5226.18 5294.44 5361.93 5431.16 5500.11 9325.31 7119.03 7060.78 50 30 N 56.31 W 2.03 3135.67N 4607.53W 9389.49 7159.42 7101.17 51 30 N 55.18 W 2.07 3163.75N 4648.75W 9440.00 7190.86 7132.61 51 30 N 55.18 W .00 3186.32N 4681.21W 5571.98 5621.84 5661.37 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5662.71 FEET AT NORTH 55 DEG. 45 MIN. WEST AT MD = 9440 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 305.49 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 9,40.00' MD SPERP~Y-S~ DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 BP EXPLORATION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.25 1000.00 996.11 937.86 2000.00 1904.92 1846.67 3000.00 2639.12 2580.87 4000.00 3349.44 3291.19 .00 N .00 E .00 11.34 S 66.08 W 3.89 3.89 211.90 N 381.30 W 95.08 91.19 594.28 N 940.00 W 360.88 265.80 989.99 N 1522.01 W 650.56 289.67 5000.00 4065.01 4006.76 6000.00 4775.42 4717.17 7000.00 5485.74 5427.49 8000.00 6205.07 6146.82 9000.00 6901.38 6843.13 1374.42 N 2104.94 W 1767.29 N 2688.73 W 2177.91 N 3260.27 W 2591.36 N 3818.06 W 3005.10 N 4404.20 W 934.99 284.43 1224.58 289.59 1514.26 289.68 1794.93 280.67 2098.62 303.69 9440.00 7190.86 7132.61 3186.32 N 4681.21 W 2249.14 150.52 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE :-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 OPERATOR: BP EXPLORATION FT. 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 .00 .00 -58.25 58.25 58.25 .00 158.25 158.25 100.00 258.26 258.25 200.00 358.30 358.25 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .24 N .39 W .00 .00 .67 N 1.22 W .01 .00 .38 N 3.93 W .05 .04 458.37 458.25 400.00 558.51 558.25 500.00 658.81 658.25 600.00 759.45 758.25 700.00 860.42 858.25 800.00 .36 N 7.70 W .13 N 12.90 W 1.41 S 20.39 W 4.39 S 31.12 W 8.25 S 44.53 W .12 .07 .26 .14 .56 .30 1.20 .63 2.17 .97 961.64 958.25 900.00 1063.11 1058.25 1000.00 1165.57 1158.25 1100.00 1269.49 1258.25 1200.00 1374.40 1358.25 1300.00 10.99 S 59.88 W 10.49 S 77.04 W 5.36 S 98.64 W 4.85 N 124.98 W 18.86 N 153.40 W 3.39 1.21 4.86 1.47 7.32 2.46 11.24 3.93 16.15 4.91 1480.96 1458.25 1400.00 1591.01 1558.25 1500.00 1706.87 1658.25 1600.00 1824.49 1758.25 1700.00 1943.34 1858.25 1800.00 38.64 N 184.38 W 66.70 N 220.61 W 105.14 N 264.57 W 147.61 N 309.60 W 191.34 N 356.62 W 22.71 6.56 32.76 10.05 48.62 15.86 66.24 17.62 85.09 18.85 2065.82 1958.25 1900.00 2193.86 2058.25 2000.00 2327.45 2158.25 2100.00 2465.01 2258.25 2200.00 2603.77 2358.25 2300.00 '235.59 N 411.72 W 281.65 N 477.05 W 331.36 N 550.35 W 384.22 N 628.60 W 438.53 N 708.01 W 107.57 22.47 135.61 28.05 169.20 33.59 206.76 37.55 245.52 38.77 2742.62 2458.25 2400.00 2885.17 2558.25 2500.00 3027.09 2658.25 2600.00 3168.39 2758.25 2700.00 3309.24 2858.25 2800.00 492.42 N 787.84 W 548.95 N 872.24 W 604.94 N 955.95 W 661.02 N 1038.52 W 717.24 N 1120.24 W 284.37 38.85 326.92 42.55 368.84 41.92 410.14 41.29 450.99 40.85 3449.56 2958.25 2900.00 3590.24 3058.25 3000.00 3730.20 3158.25 3100.00 3869.56 3258.25 3200.00 4012.56 3358.25 3300.00 772.71 N 1201.57 W 828.57 N 1283.23 W 883.32 N 1364.43 W 936.71 N 1445.47 W 994.96 N 1529.45 W 491.31 40.33 531.99 40.67 571.95 39.97 611.31 39.35 654.31 43.00 SPE7 ' SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 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 4155.08 3458.25 3400.00 4296.87 3558.25 3500.00 4437.69 3658.25 3600.00 4576.16 3758.25 3700.00 4713.51 3858.25 3800.00 1051.22 N 1613.99 W 1103.39 N 1699.91 W 1158.26 N 1782.47 W 1211.12 N 1862.34 W 1262.99 N 1940.91 W 696.83 42.52 738.62 41.79 779.44 40.82 817.91 38.47 855.26 37.35 4852.40 3958.25 3900.00 4990.69 4058.25 4000.00 5129.82 4158.25 4100.00 5271.05 4258.25 4200.00 5411.55 4358.25 4300.00 1317.43 N 2020.45 W 1370.92 N 2099.59 W 1424.64 N 2180.01 W 1480.63 N 2262.54 W 1535.34 N 2344.67 W 894.15 38.89 932.44 38.29 971.57 39.13 1012.80 41.23 1053.30 40.50 5553.49 4458.25 4400.00 5695.08 4558.25 45-00.00 5835.74 4658.25 4600.00 5975.91 4758.25 4700.00 6115.88 4858.25 4800.00 1592.55 N 2427.56 W 1648.69 N 2510.60 W 1702.90 N 2593.33 W 1758.06 N 2674.56 W 1814.81 N 2754.37 W 1095.24 41.94 1136.83 41.60 1177.49 40.66 1217.66 40.16 1257.63 39.97 6256.28 4958.25 4900.00 6397.56 5058.25 5000.00 6539.07 5158.25 5100.00 6680.28 5258.25 5200.00 6821.39 5358.25 5300.00 1871.75 N 2834.80 W 1930.83 N 2915.22 W 1990.96 N 2995.27 W 2049.01 N 3076.33 W 2105.35 N 3158.39 W 1298.03 40.40 1339.31 41.28 1380.82 41.51 1422.03 41.21 1463.14 41.11 6961.42 5458.25 5400.00 7100.48 5558.25 5500.00 7238.76 5658.25 5600.00 7375.87 5758.25 5700.00 7513.99 5858.25 5800.00 2162.31 N 3238.14 W 2218.99 N 3316.38 W 2274.68 N 3393.96 W 2328.32 N 3470.92 W 2383.85 N 3548.33 W 1503.17 40.03 1542.23 39.06 1580.51 38.28 1617.62 37.11 1655.74 38.12 7653.23 5958.25 5900.00 7792.49 6058.25 6000.00 7933.22 6158.25 6100.00 8076.21 6258.25 6200.00 8218.15 6358.25 6300.00 2440.15 N 3627.17 W 2499.47 N 3703.78 W 2561.32 N 3781.12 W 2625.59 N 3860.56 W 2685.66 N 3941.42 W 1694.98 39.24 1734.24 39.26 1774.97 40.74 1817.96 42.98 1859.90 41.94 8359.98 6458.25 6400.00 8503.16 6558.25 6500.00 8647.42 6658.25 6600.00 8791.34 6758.25 6700.00 8937.56 6858.25 6800.00 2743.07 N 4024.00 2800.39 N 4108.92 2859.69 N 4194.33 2918.64 N 4279.40 2979.56 N 4366.97 W 1901.73 41.84 W 1944.91 43.17 W 1989.17 44.27 W 2033.09 43.92 W 2079.31 46.22 SPE7 -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 BP EXPLORATION MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/25/97 DATE OF SURVEY: 032997 JOB NUMBER: AK-MM-70076 KELLY BUSHING ELEV. = 58.25 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 MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9082.89 9231.45 9387.61 9420.00 6958.25 6900.00 7058.25 7000.00 7158.25 7100.00 7178.41 7120.16 3037.20 N 4455.24 W 2124.64 45.33 3096.55 N 4547.68 W 2173.20 48.56 3162.91 N 4647.55 W 2229.36 56.16 3177.38 N 4668.36 W 2241.59 12.23 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPErRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 033097 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70086 KELLY BUSHING ELEV. = 58.25 OPERATOR: BP EXPLORATION PAGE FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 4463.50 3676.93 3618.68 4472.40 3683.36 3625.11 4565.90 3751.42 3693.17 4658.40 3818.53 3760.28 4750.11 3884.60 3826.35 COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 43 58 N 55.20 W .00 1168.33N 1797.36W 43 31 N 55.00 W 5.18 1171.85N 1802.41W 43 2 N 55.72 W .73 1208.30N 1855.15W 43 55 N 54.75 W 1.18 1244.60N 1907.44W 43 53 N 54.37 W .29 1281.47N 1959.25W VERT. SECT. 2141.73 2147.88 2211.98 2275.63 2339.23 4844.00 3952.39 3894.14 4934.80 4018.22 3959.97 5028.60 4085.56 4027.31 5121.50 4151.33 4093.08 5216.60 4218.85 4160.60 43 40 N 54.89 W .45 1319.08N 2012.23W 43 22 N 54.97 W .34 1355.01N 2063.41W 44 50 N 54.78 W 1.57 1392.57N 2116.81W 45 0 N 55.15 W .33 1430.23N 2170.53W 44 31 N 53.90 W 1.05 1469.09N 2225.07W 2404.19 2466.73 2532.02 2597.62 2664.58 5308.70 4284.50 4226.25 5401.50 4350.28 4292.03 5493.70 4415.27 4357.02 5587.20 4481.40 4423.15 5680.90 4548.02 4489.77 44 32 N 56.44 W 1.93 1505.98N 2278.08W 45 10 N 54.24 W 1.80 1543.21N 2331.91W 45 10 N 54.75 W .39 1581.19N 2385.14W 44 47 N 55.64 W .79 1618.91N 2439.41W 44 34 N 56.62 W .77 1655.63N 2494.12W 2729.16 2794.60 2860.00 2926.09 2991.95 5775.20 4615.35 4557.10 5868.30 4681.82 4623.57 5962.90 4749.34 4691.09 6055.80 4815.78 4757.53 6150.80 4883.57 4825.32 44 18 N 55.31 W 1.01 1692.58N 2548.84W 44 33 N 55.04 W .34 1729.80N 2602.35W 44 21 N 53.92 W .86 1768.29N 2656.27W 44 19 N 52.63 W .97 1807.12N 2708.32W 44 37 N 53.43 W .66 1847.14N 2761.49W 3057.95 3123.13 3189.38 3254.30 3320.83 6243.90 4949.75 4891.50 6336.30 5015.23 4956.98 6430.80 5082.05 5023.80 6523.50 5147.65 5089.40 6617.70 5214.57 5156.32 44 45 N 52.58 W .66 1886.54N 2813.78W 44 59 N 52.40 W .28 1926.24N 2865.49W 45 1 N 53.24 W .63 1966.63N 2918.74W 44 52 N 54.48 W .96 2005.25N 2971.63W 44 35 N 55.10 W .55 2043.48N 3025.80W 3386.28 3451.44 3518.23 3583.72 3650.02 6671.70 5252.96 5194.71 6711.10 5280.88 5222.63 6805.80 5348.31 5290.06 6900.40 5415.94 5357.69 6994.20 5483.38 5425.13 44 46 N 55.23 W .36 2065.17N 3056.97W 44 58 N 55.47 W .68 2080.97N 3079.84W 44 12 N 54.87 W .93 2118.94N 3134.41W 44 31 N 54.70 W .36 2157.09N 3188.46W 43 31 N 53.69 W 1.31 2195.21N 3241.33W 3687.99 3715.79 3782.27 3848.42 3913.60 7088.30 5551.48 5493.23 7183.50 5620.65 5562.40 7277.50 5689.24 5630.99 7371.40 5757.57 5699.32 7466.00 5826.08 5767.83 43 45 N 54.10 W .39 2233.48N 3293.80W 43 1 N 52.63 W 1.31 2272.50N 3346.28W 43 15 N 53.04 W .38 2311.33N 3397.50W 43 22 N 53.50 W .36 2349.85N 3449.12W 43 49 N 52.53 W .86 2389.10N 3501.23W 3978.54 4043.92 4108.17 4172.57 4237.78 {-'% SP~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 033097 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70086 KELLY BUSHING ELEV. = 58.25 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 7560.10 5893.71 5835.46 44 16 N 53.16 W .66 2428.62N 3553.37W 4303.18 7653.00 5960.31 5902.06 44 7 N 51.89 W .97 2468.02N 3604.76W 4367.89 7747.20 6027.76 5969.51 44 25 N 50.88 W .82 2509.06N 3656.14W 4433.55 7840.60 6094.20 6035.95 44 52 N 50.87 W .48 2550.48N 3707.07W 4499.07 7933.20 6159.29 6101.04 45 47 N 50.98 W 1.00 2592.00N 3758.20W 4564.80 8023.60 6222.63 6164.38 45 13 N 53.08 W 1.78 2631.67N 3809.03W 4629.22 8115.80 6287.48 6229.23 45 22 N 53.57 W .41 2670.82N 3861.59W 4694.74 8208.90 6353.21 6294.96 44 48 N 55.10 W 1.31 2709.26N 3915.15W 4760.67 8303.20 6419.60 6361.35 45 40 N 55.67 W 1.02 2747.29N 3970.27W 4827.63 8396.90 6485.27 6427.02 45 19 N 55.39 W .43 2785.12N 4025.37W 4894.45 8488.60 6549.22 6490.97 46 13 N 55.09 W 1.01 2822.58N 4079.36W 4960.16 8581.70 6613.91 6555.66 45 45 N 54.83 W .56 2861.02N 4134.18W 5027.12 8676.90 6680.21 6621.96 45 57 N 54.70 W .24 2900.44N 4189.98W 5095.43 8729.30 6716.39 6658.14 46 42 N 54.48 W 1.46 2922.40N 4220.87W 5133.34 8772.40 6745.86 6687.61 47 0 N 54.67 W .75 2940.63N 4246.50W 5164.78 8867.30 6811.04 6752.79 46 15 N 54.56 W .79 2980.57N 4302.73W 5233.76 8960.10 6875.05 6816.80 46 31 N 54.79 W .34 3019.42N 4357.55W 5300.95 9054.00 6939.23 6880.98 47 14 N 55.45 W .93 3058.62N 4413.77W 5369.48 9147.90 7002.36 6944.11 48 16 N 56.32 W 1.29 3097.60N 4471.32W 5438.97 9199.80 7036.51 6978.26 49 26 N 56.25 W 2.26 3119.29N 4503.83W 5478.03 9242.70 7064.25 7006.00 49 59 N 56.39 W 1.30 3137.44N 4531.06W 5510.74 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5511.26 FEET AT NORTH 55 DEG. 18 MIN. WEST AT MD = 9242 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 305.49 DEG. TIE-IN SURVEY AT 4,463.50' MD LAST SURVEY STATION AT 9,242.70' MD SP~'RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 033097 JOB NUMBER: AK-EI-70086 KELLY BUSHING ELEV. = 58.25 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4463.50 3676.93 3618.68 5463.50 4393.98 4335.73 6463.50 5105.16 5046.91 7463.50 5824.27 5766.02 8463.50 6531.86 6473.61 1168.33 N 1568.82 N 1980.47 N 2388.05 N 2812.21 N 1797.36 W 786.57 2367.65 W 1069.52 282.95 2937.27 W 1358.34 288.82 3499.85 W 1639.23 280.89 4064.49 W 1931.64 292.41 9242.70 7064.25 7006.00 3137.44 N 4531.06 W 2178.45 246.81 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPF~-,RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPE-18 500292274800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 033097 JOB NUMBER: AK-EI-70086 KELLY BUSHING ELEV. = 58.25 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 4463.50 3676.93 3618.68 1168.33 N 1797.36 W 786.57 4575.25 3758.25 3700.00 1211.89 N 1860.43 W 817.00 4713.54 3858.25 3800.00 1266.70 N 1938.64 W 855.29 4852.11 3958.25 3900.00 1322.29 N 2016.81 W 893.86 30.43 38.29 38.57 4990.08 4058.25 4000.00 1376.91 N 2094.62 W 931.83 5131.28 4158.25 4100.00 1434.18 N 2176.21 W 973.03 5271.87 4258.25 4200.00 1491.69 N 2256.55 W 1013.62 5412.81 4358.25 4300.00 1547.89 N 2338.42 W 1054.56 5554.58 4458.25 4400.00 1605.94 N 2420.44 W 1096.33 37.98 41.20 40.58 40.94 41.77 5695.26 4558.25 4500.00 1661.17 N 2502.54 W 1137.01 5835.22 4658.25 4600.00 1716.50 N 2583.32 W 1176.97 5975.36 4758.25 4700.00 1773.42 N 2663.32 W 1217.11 6115.23 4858.25 4800.00 1832.25 N 2741.43 W 1256.98 6255.87 4958.25 4900.00 1891.66 N 2820.47 W 1297.62 40.68 39.96 40.14 39.87 40.63 6397.13 5058.25 5000.00 1952.37 N 2899.66 W 1338.88 6538.45 5158.25 5100.00 2011.38 N 2980.21 W 1380.20 6679.15 5258.25 5200.00 2068.16 N 3061.28 W 1420.90 6819.66 5358.25 5300.00 2124.51 N 3142.32 W 1461.41 6959.53 5458.25 5400.00 2181.08 N 3222.08 W 1501.28 41.27 41.32 40.70 40.51 39.87 7097.68 5558.25 5500.00 2237.28 N 3299.05 W 1539.43 7234.96 5658.25 5600.00 2293.80 N 3374.23 W 1576.71 7372.34 5758.25 5700.00 2350.24 N 3449.64 W 1614.09 7510.63 5858.25 5800.00 2407.90 N 3525.79 W 1652.38 7650.12 5958.25 5900.00 2466.78 N 3603.19 W 1691.87 38.14 37.28 37.38 38.29 39.50 7789.92 6058.25 6000.00 2527.94 N 3679.36 W 1731.67 7931.71 6158.25 6100.00 2591.32 N 3757.37 W 1773.46 8074.19 6258.25 6200.00 2653.22 N 3837.78 W 1815.94 8216.00 6358.25 6300.00 2712.12 N 3919.26 W 1857.75 8358.45 6458.25 6400.00 2769.59 N 4002.86 W 1900.20 39.79 41.79 42.48 41.81 42.45 8501.65 6558.25 6500.00 2827.97 N 4087.09 W 1943.40 8645.31 6658.25 6600.00 2887.32 N 4171.44 W 1987.06 8790.56 6758.25 6700.00 2948.31 N 4257.33 W 2032.31 8935.68 6858.25 6800.00 3009.21 N 4343.07 W 2077.43 9082.01 6958.25 6900.00 3070.28 N 4430.71 W 2123.76 43.20 43.66 45.25 45.12 46.33 9242.70 7064.25 7006.00 3137.44 N 4531.06 W 2178.45 54.70 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS r'l I::I I I_1_ I IM G , WEI,I, LOG TRANSNHTTAL To: State of Alaska June 25, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPE-18 AK-MM-70076 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.' Yah Galvin, Sperry-Sun Drilling Services,. 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22748-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska May 28, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPE-18, AK-MM-70076 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.' Yah Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPE-18: 2" x 5" MD Resistivity and Gamma Ray Logs: 50-029-22748-00 1 Blueline 1 Rev. Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22748-00 1 Blueline 1 Rev. Folded Sepia 2" x 5" MD Neutron and Density Logs: 50-029-22748-00 1 Blueline 1 Rev. Folded Sepia 2"x 5" TVD Neutron and Density Logs: 50-029-22748-00 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 Schlumberger- GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) May 7, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. ~'~ Anchorage, Alaska 99519-6612~t Lcd~" 0 (..¢''~ ~ The following data of the PDC GR for wells MPK-43A & MPE'-18, Job # 97193 & 97183, was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 CH LIS Tape each 1 Film (MPE-18) 3 Bluelines State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 CH LIS Tape each 1 Blueline 1 RFolded Sepia OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 1 CH LIS Tape each 1 Blueline 1 RFolded Sepia Sent Certified Mail Z 777 937 565 PLEASE ACKNOWLEDGE RECE lNG AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska ...99519-6612.7 Date Delivered: "' ~-'; ~ 'i} !!}c}~ Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10967 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) 4/24/97 Well Job # Log Description Date BL RF Sepia LIS Tape MPU E-14 PERFORATION RECORD 97041 6 I 1 MPU E-18 PERFORATION RECORD 97041 5 I 1 MPU E-19 PERFORATION RECORD 97041 4 I 1 MPU F-701 L,x,~ C~-. CHEMICAL CUTTER 970320 I 1 MPU F-73 GPJCCL 97031 3 I 1 MPU F-73 PERFORATING RECORD 97031 3 I 1 M P U J-09 kJ,..,~, (~ CHEMICAL CUTTER RECORD 97041 7 I 1 MPU J-09 . ~_. CBL 970418 I 1 MPU J-09~ PERF RECORD 97041 8 I 1 K-21 PERF RECORD W/GR 97031 6 I 1 MPK-21 CBL 97031 6 I 1 MPK-43A H.P.G. GUNS SHOOTING RECORD 97031 9 I 1 MPK-43A STATIC PRESSURE SURVEY W/CPLT 97031 9 I 1 MPK-43A CBL 970319 I 1 MPK-43A H.P.G. GUNS PERFORATION RECORD 9703 21 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received TONY KNOWL£$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 20, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPE-I8 BP Exploration (Alaska) Inc. 97-42 3661'NSL, 1974'WEL, Sec 25, TI3N, RIOE, UM 1504'NSL, 1242'WEL, Sec 23, TI3N, R10E, UM Dear Mr. Thomas: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated March 12, 1997 are in effect ibr this revision. · Chailm~..,~ ~ BY ORDER OF MISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COM~v, ISSION PERMIT TO DRILL REVISED 03/17/97 2O AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type ofwork []Re-Entry []Deepen~ []Service I-IDevelopment Gas r-]Single Zone I'-]Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 57.7' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3661' NSL, 1974' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1392' NSL, 1085' WEL, SEC. 23, T13N, R10E MPE-18 Attotal depth 9. Approximate spud date Amount $200,000.00 1504' NSL, 1242' WEL, SEC. 23, T13N, FI10E 03/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 1504'I No Close Approach 2560 9292' MD / 7168' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 200' Maximum Hole Angle 43.85° Maximum surface 2885 psig, At total depth (TVD) 7045' / 3590 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement ....... Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 4255' 31' 31' 4286' 3558' 988 sx PF'E', 865 sx'G' 8-1/2" 7" 26# L-80 Btrc 9262' 30' 30' 9292' 7168' 233 sx Class 'G' ....... 119. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ....~: .;.... ~ Liner ORIGINAL ;. i '-:', \ ';:i-~-'::i;;,-: !..':'ii !'~ : ::i:":~:;i;.;. ~'' Perforation depth: measured -,. , .., true vertical " ........ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the !.oCr. c,.goi~s tr~e an.d (~or~'ect to the best of my knowledge Signed , _.fl? · Title Senior Drilling Engineer Date Tim Schofie[d // Commission Use Only Permit Number I APl Number I Approval Date See cover letter ,,,9,,7-42 50-029-22748 03/12/97 for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures []Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 10M; [] 15M Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared I Type of Well Services Drilling Contact: I Well Name: Well Lance Spencer IMP E-18 I Plan Summary (producer or injector): I Kuparuk Producer 564-5042 ISurface Location: Kuparuk Target Location: Bottom Hole Location' 3661 NSL 1974 WEL Sec 25 T13N R10E UM., AK 1392' NSL, 1085' WEL , Sec. 23, T13N, R10E, UM., AK 1504' NSL, 1242' WEL, Sec. 23, T13N, R10E, UM., AK IAFE Number: 1337065 I Estimated Start Date: 121 Mar 97I I MD' 19,292' I ITVD' I Rig: I Nabors 27-E I Operating days to complete' I10 17,168' Bkb I I KBE' 157.7 Well Design (conventional, slimhole, I Milne Point Ultra Slimh,,ole Longstring 9- etc.)' 15/8", 40# Surface X 7, 26# Longstring Formation Markers- Formation Tops MD TVD (bkb) Base Permafrost 1 95 6 1 800 8.3 ppg, 777 psi NA 5291 4283 8.3 ppg, 1849 psi CA 5464 4408 8.3 ppg, 1902 psi OB 5554 4473 8.3 ppg, 1931 psi BaseOB 5603 4508 8.3 ppg, 1946 psi Top HRZ 8154 6348 8.6 ppg, 2839 psi Base HRZ 8 45 2 65 63 8.6 ppg, 2935 psi TKLB 8 5 91 66 63 9.6 ppg, 3326 psi TKUP/UD 8771 6793 9.6 ppg, 3391 psi TKC1 9014 6968 9.8 ppg, 3551 psi TKUC/TARGET 9 01 4 6 968 9.8 ppg, 3551 psi TKUB/B8 9028 6978 9.8 ppg, 3556 psi TKB7 9042 6988 9.8 ppg, 3561 psi Total Depth 92 92 + 71 68 + 9.8 ppg, 3653 psi Casing/Tubing Pro! ram' Hol~, (~sg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 4255 31/31 4286/3558 8-1/2" 7" 26# L-80 btrc 9262 30/30 9292/7168 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at _+ 7045 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7045 TVDSS. The maximum anticipated surface pressure in--this¢. ~c~.,seassum!_n_g a · -- . :'~ '.~,~ .,'.~,.. '.!,~ reservoir pressure of 3590 psi ~s 2885 psi using a 0.1 psi/ft gas grad~'etit;' well; ~ei*~N~-'~the internal yield pressure rating of the 7" casing· . ,.~ .~ ;..,.,,_~ !'.,~ ;.'.,! ~ · ','~ ~..~._, i MP E-18 (O) Drilling Permit 3/17/97 Logging Program: Open Hole Logs' Surface Intermediate Final Cased Hole Logs: Mud Logging MWD Directional: GR: EWR4: CNP: SLD: ROP: Mud Program' MWD Directional from surface to TD. N/A MWD Directional from 9-5/8 shoe and LWD GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time N/A Mud Loggers and samples are NOT required. Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Special design considerations Special attention should be given to gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on E-Pad. Prior to spudding a complete review of the E-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate )roblems and lost time in the surface hole. HYDRATES Hydrates are present on E-Pad and must be managed safely. It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will be encountered while drilling on E-Pad. Surface Mud Properties' I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 10.2 50 35 15 30 10 15 Production Mud Properties' I LSNDfreshwatermud Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 10 3 7 8.5 6-8 to to to to to to to 10.2 50 15 10 20 9.5 4-5 MP E-18 (O) Drilling Permit 2 3/17/97 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP:200' Maximum Hole Angle: 43.85° Close Approach Well: (No Shut In Wells) Disposal: No "Drilling Wastes" will be injected or disposed into E-18 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A or other approved site for disposal. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564- 4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations. GENERAL DISCUSSION Well Objective: MP E-18 will be drilled to a TD of 9292' md with a horizontal displacement of 5,51 8'. The surface casing will be shallow set above the Schrader Bluff at 4,286'md (3558' bkb) . This well is planned to intersect two targets in the Kuparuk: the C1, and B7 sands. MP E-1 8 will be completed as Kuparuk River C1 and B7 Sand producer. Geology The anticipated reservoir pressure for the MPE-18, (O) fault block is 3600 psi, based on the initial reservoir pressure encountered in exlporation wells MPA-01 and MPA-02. Pressures surrounding the fault are substantially lower due to production. The fualt to the northwest pf the target appears to be a reverse fault, so the C abd B sand could be duplicated in the well bore. A drilling drsk exits if the wellbore and fault angle are to close; the wellbore should be about 45 degree theu the target, and the target should eb restricted to the SE quadrant. The Kuparuk C abd B sands should be 100% oil bearing. The OWC in the MPE-18, (O) fault block is expected at 7045' TVDss which is in the Kuparuk B shale. DRILLING HAZARDS AND RISKS SUMMARY: Hydrates may be encountered on E-pad in the surface hole but are most often seen when drilling southeasterly and are not expected to be a major factor while drilling this well. Formation pressures are expected to be normal in the Kuparuk and not be adversely effected by depletion o r injection. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this. Lost circulation and stuck pipe have occurred but not recently and are not expected. GAS HYDRATES Hydrate sections may be encountered on E-Pad while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on E-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate to potential risks and minimize the nonproductive time involved in managing hydrates. Some measures which are necessary to lessen to effects of gas hydrates include: 1. Increased mud weights; 2. Low drilling fluid temperatures; 3. Reduced ROP's for control drill rates; 4. Controlled circulating and drilling fluid rates; 5. Utilization of Lecithin MP E-18 (O) Drilling Permit 3 3/17/97 Close Approaches There are no close approaches associated with the drilling of MP E-18, however, tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized. Water Injection The water injection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazard or risk. Annular Injection Currently annular injection is not permitted on E-Pad, Gas Injection No gas injection wells are present on E-Pad. The gasinjection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazzard or risk. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occured while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. The losses normally occur in the Ugnu and Schrader Bluff with the shallow set surface casing design especially while cementing the 7" csg. Stuck Pipe Potential: Running gravels, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occured while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9- 5/8" casing has been stuck. While drilling the surface hole additional time has beeen spent reaming and conditioning the hole prior to cementing because of tight hole. These problems in some instances were greatly exaggerated because of measures taken to manage the gas hydrate problems. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurance has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher muds weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK SAND 7044' TVDss 3600 PSI 9.8 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKB7 at +_ 7044 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +7044 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3589 psi is 2885 psi. The maximum expected pore pressure for this well is 9.8 ppg EMW (3,600 psi @ 7,044' TVDss). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point E-Pad Data Sheet prepared by Pete Van Dusen for information on E pad and review recent wells drilled on E Pad. MP E-18 (O) Drilling Permit 4 3/17/97 MP E-18 Kuparuk Producer Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. . Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. , Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 1300'. . Perform Two Stage cement. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SDL). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 150' of production rat hole between the base of the Kuparuk B sand and PBTD before running the 7" casing. 11. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source waterand enough diesel to cover from the base of permafrost to surface (+-21 00' MD). 1 2. Test casing to 3500 psig. 13. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 1 4. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP E-18 (O) Drilling Permit 5 3/17/97 MP E-18 Kuparuk Producer 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON Casing Size: 9-5/8" 40# L-80 Circ. Temp 60 deg F at 2840' TVDSS. TWO STAGE CEMENT PROGRAM' Refer to the Two Stage Cementing Procedure The objective of the Surface Cement is to insure that cement is circulated to surface. Second stage lead cement shall be pumped until such time as cement is circulated to surface before switching to displacement. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface, This volume may exceed the annular capacity and the 250% estimated excess. 1. The ES Cementer is located at 1300' md. 2. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. 3. Lead and Tail slurries are pumped in the first stage. 4. Only a Lead slurry is pumped in the second stage. 5. Dye shall be introduced into the inital part of the first stage and into the water before the second stage in order to obtain an estimate of annular capacity so that additional cement can supplied and adequate excess can be pumped if required. 6. Once an adequate volume of cement has been circulated to surface immediately begin displacement. 7. The WELLHEAD STABILITY CEMENT will be pumped only if the cement top falls below surface after the pumps are shut down. 8. Utilize a large flow area float shoe. 9. Use weighted spacer before first stage lead slurry:(1 ppg higher than current mud weight). 1 0. Add dye in the water spacer before the second stage to assist in determining the annular volume. 1 1. Incorporate "Celloflakes" into ONLY the First Stage cement LEAD and TAIL slurries. Caution' 1. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPINGDISPLACEMENT. 2. Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurries. 3. Make preparations to handle cement to surface on the first stage circulation. 4. Make preparations to handle cement to surface on the second stage circulatie.,n., ,,; -,.~"~ MP E-18 (O) Drilling Permit 6 ~'"~::~;!~!:"'"~'~;;:;:'~ :3/iw97": ,.. Note: First Stage. SPACER' 70 bbls NSCI weight 1 ppg higher than current mud weight. 1st LEAD CEMENT TYPE: Permafrost E ADDITIVES: 0.15#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 331 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 1st TAIL CEMENT TYPE' Premium G ADDITIVES: 2.0% CaCI2 +.15#/sk Floceles WEIGHT: APPROX NO. SACKS: 865 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 4.9 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREEWATER:0 Second Stage. SPACER: 75 bbls Water 2nd LEAD CEMENT TYPE:' Permafrost E ADDITIVES: None WEIGHT: APPROX NO SACKS: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk 6 5 7 THICKENING TIME' Greater than 4 hrs at 50° F. Wellhead Stability Cement CEMENT TYPE: Permafrost E ADDITIVES: None WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk Centralizer Placement: . Install one(l) Straight Blade Rigid Centralizers per joint of 9-5/8" bottom 10 joints of casing (required). . Install one(l) Straight Blade Rigid Centralizers per joint on the 9-5/8" from 2200-2700 feet to cover the top hydrate intervals (required). centralizers in middle of joints using stop collars. casing on casing on Place all MP E-18 (O) Drilling Permit 7 3/17/97 Surface Cement Volumes: I . First Stage LEAD Cement Volume = Interval from1300-1956' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer at 1300' md to the Base of the Permafrost at 1956' md (1858 TVDbkb) + 250% EXCESS. 2. First StageTAIL Cement Volume = Interval from 1956-4292' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the Base of the Permafrost at 1956' md to surface TD at 4292' md (3558' TVDbkb) plus 30% Excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. Sc Second Stage LEAD Cement Volume = Interval from 0-1300 md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 1300' MD (1281' TVDbkb) to surface plus 250% excess. . The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Other Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 1 2 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. 2. After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well to improve the chances of getting cement to the surface. If the cement falls back, do a wellhead stability cement job. MP E-18 (O) Drilling Permit 8 3/17/97 MP E-18 Kuparuk Producer 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON This cement program is proposed only if the Schrader Bluff formations are NOT hydrocarbon bearing. In the event the Schrader Bluff formations proves to be hydrocarbon bearing a revised cement program will be submitted. Casing Size: 7" 26# L-80 CIRC. TEMP' 140° F BHST 170° F at 7040' TVDSS. SINGLE STAGE CEMENT JOB' Cement from TD to 1000' above KUPARUK TKUP/UD. SPACERs: 20 bbls fresh water and 70 bbls NSCI mixed per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 233 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME' Interval 7771-9292' md . Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: . Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. MP E-18 (O) Drilling Permit 9 3/17/97 Anadrill Schlumberger Alaska District illl East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-1622 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPE-18 (P6) Field ........ : Milne Point, E-Pad Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.45461295 N Surface Long.: 149,43553070 W LOCATIONS - ALASKA Zone: Legal Description X-Coord Surface ...... : 3660 FSL 1974 FEL S25 T13N RIOE UM 56917'1.36 Target ....... : 1392 FSL 1085 FEL S23 T13N R10E UM 564752.00 BHL .......... : 1504 FSL.1242 FEL S23 T13N R10E UM 564594.33 4 Y-Coord 6016198.16 6019170.00 6019280.23 Prepared ..... : 14 Mar 1997 Vert sect az.: 305.49 KB elevation.: 57.70 ft Magnetic Dcln: +26.171 (E) Scale Factor.: 0.99990544 Convergence..: +0.53194469 ANADRILL AKA-DPC APPROVED IVI/%R 1 ? 1697 m~.lmmmlmmlmmllmmm! mm~mmmmm mmmmmm mmmmm~l:= PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS IDENTIFICATION DEPTH ANGLE AZIMUTH TVD SUB-SEA KB 0.00 0.00 0.00 0.00 KOP / 1/100 BUILD 200.00 0.00 270.00 200.00 300.00 1.00 270.00 299.99 BUII~D 1.5/100 375.00 1.75 270.00 374.97 400.00 2.13 270.00 399.96 -57.70 142.30 242.29 317.27 342.26 SECTION DEPART COORDINATES-FROM ALASKA Zone 4 WELLHEAD X Y 0.00 -0.00 0.71 2.18 TOOL DL/ FACE 100 500.00 3.63 270.00 499.83 442.13 BUILD 2/100 575.00 4.75 270.00 574.63 516.93 600.00 5.25 270.00 599.53 541.83 700.00 7.25 270.00 698.93 641.23 . CURVE 2.5/100 800.00 9.25 270.00 797.89 740.19 6.95 11.41 13.18 22.04 33.73 0.00 N 0.00 E 569171.36 6016198,16 90L 0.00 0.00 N 0.00 E 569171.36 6016198.16 90L 0.00 0,00 N 0.87 W 569170.49 6016198.15 90L 1.00 0.00 N 2.67 W 569168.69 6016198.14 90L 1.00 0.00 N 3.52 W 569167.84 6016198.13 90L 1.50 900.00 11.22 278.69 696.30 838.60 1000.00 13.37 284.72 994.01 936.31 48.96 68.4.6 0.00 N 8.53 W 569162.83 6016198.08 90L 1.50 0.00 N 14.01 W 569157.35 6016198.03 90L 1.50 0.00 N 16.19 W S69155.17 6016198.01 HS 2.00 0.00 N 27.07 W 569144.29 6016197.91 HS 2.00 0.00 N 41.42 W 569129.94 6016197.78 42R 2.00 (Anadrill (c)97 MPE18P06 3.0C 3:49 PM P) 1.47 N 59.08 W 569112.27 6016199.08 34R 2.50 5.88 N 79.89 W 569091.43 6016203.30 28R 2.50 STATION IDENTIFICATION MEASURED DEPTH INCLN ANGLE 15.62 17.94 20.30 22.69 25.09 ~,NADRILL AKA-DPC APPROVED 1997 END 2.5/100 CURVE 1100,00 1200.00 1300.00 1400.00 1500,00 1600.00 27.52 1700.00 29.95 1800.00 32.40 1900.00 34.85 1919.64 35.33 BASE PERMAFROST CURVE 2.5/100 1956.41 35.33 1993.18 35.33 2000.00 35.50 2100.00 37,96 2200.00 40.42 2300.00 42.89 END 2.5/100 CURVE 2338,92 43.85 9-5/8" CASING POINT 4285,48 43.85 NA 5290.79 43,85 OA 5464.12 43.85 OB 5554.25 43.85 BASE OB 5602.78 43.85 THRZ 8154.19 43.85 BHRZ 8452.32 43,85 TKLB (MARKER 19) 8590.98 43,85 TKUP/(D SHALE) 8771.25 43,85 KC1 9013.91 43.85 TARGET ************* 9013.91 43.85 PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA ~==~=== ........ =====~ 289.07 1090.82 1033.12 29~.'33 1186.56 1128.86 294.87 1281.04 1223,34 296.89 1374.08 1316.38 298.55 1465.50 1407.80 299.93 1555.14 1497.44 301.10 1642.82 1585.12 302.12 1728.37 1670.67 303.00 1811.63 1753.93 303.16 1827.70 1770.00 303.16 1857.70 1800.00 303.16 1887.70 1830,00 303.22 1893.26 1835.56 303.97 1973.40 1915,70 304.65 2050.90 1993.20 14 Mar 1997 PaTe 2 SECTION COORDINATES-FROM ALASKA Zone 4 TOOL DL/ DEPART WELLHEAD X Y FACE 100 92.19 13.22 N 103.80 W 569067.45 6016210.41 24R 2.50 120.11 23.47 N 130.78 W 569040.38 6016220.41 21R 2.50 152.16 36.62 N 160.77 W 569010.27 6016233.28 18R 2,50 188.28 52.64 N 193,71 W 568977.19 6016248.99 16R 2.50 228.40 71.49 N 229.54 W 568941.19 6016267.51 15R 2.50 272.45 93.16 N 268.20 W 568902.34 6016288.82 14R 2.50 320.35 117.59 N 309.60 W 568860.71 6016312.86 13R 2.50 371.99 144.73 N 353.67 W 568816-39 6016339.59 12R 2.50 427,29 174.54 N 400.33 W 568769.46 6016368.96 llR 2.50 438.57 180.70 N 409.79 W 568759.95 6016375.03 HS 2.50 459.81 192.33 N 427..59 W 568742.04 6016386.50 HS 0.00 481.06 203.96 N 445.40 W 568724.13 6016397.96 llR 0.00 485,01 206.13 N 448.70 W 568720.80 6016400,09 llR 2.50 544.28 239.22 N 498.51 W 568670.70 6016432,72 IOR 2,50 607.95 274.85 N 550.69 W 568618.19 6016467.86 10R 2.50 305.27 2125.61 2067.91 674,40 305.49 2153.90 2096.20 701.13 305,49 3557.70 3500.00 2049.62 305.49 4282.70 4225,00 2746.06 305.49 4407.70 4350.00 2866.14 305.49 4472,70 4415.00 2928.58 305.49 4507.70 4450.00 2962.20 305.49 6347,70 6290.00 4729.71 305.49 6562.70 6505.00 4936.24 305.49 6662.70 6605.00 5032.30 305.49 6792.70 6735,00 5157.18 305.49 6967.70 6910.00 5325,28 305.49 6967.70 6910.00 5325.28 312.94 N 605.15 W 568563.39 6016505.44 9R 2.50 328.41 N 626.94 W 568541,45 6016520.71 HS 2.50 1111,30 N 1724.91 W 567436.38 6017293.29 HS 0.00 1515.63 N 2291.96 W 566865.65 6017692.30 HS 0.00 1585.34 N 2389.72 W 566767.25 6017761,09 HS 0.00 1621.59 N 2440.56 W 566716.08 6017796.87 HS 0.00 1641.11 N 2467.94 W 566688.53 6017816.13 HS 0.00 2667,26 N 3907.07 W 565240.07 6018828,78 HS 0.00 2787.16 N 4075.23 W 565070.82 6018947.11 HS 0.00 2842.93 N 4153.44 W 564992.10 6019002.14 HS 0.00 2915.43 N 4255.12 W 564889.76 6019073.69 MS 0.00 3013.03 N 4391.99 W 564752.00 6019170.00 HS 0.00 3013.03 N 4391.99 W 564752,00 6019170,00 MS 0.00 {Anadrill (c)97 MPE18P06 3.0C 3:49 PM P) PROPOSED WELL PROFILE STATION MEASURED VERTICAL-DEPTHS IDENTIFICATION DEPTH TVD SUB-SEA TKUB/B8 9027.77 6977.70 6920.00 TKUBV 9041.64 6987.70 6930,00 TKB6 9069.3~ 7007.70 6950.00 TKB5 9104.04 7032.70 6975.00 TKB4 9152.57 7067.70 7010.00 INCLN DIRECTION ANGLE AZIMUTH 43.85 305.49 43.85 305.49 43.85 305.49 43.85 305.49 43.85 305.49 SECTION DEPART TKB3 9194.17 43,85 305.49 7097.70 7040.00 EXPECTED OWC 9201.10 43.85 305.49 7102,70 7045.00 TZB2 9228.84 43.85 305.49 7122.70 7065.00 7" CASING POINT 9291.64 43.85 305.49 7167.99 $110.29 TD 9291.64 43.85 305.49 7167.99 ?110.29 COORDINATES-FROM ALASKA Zone 4 TOOL WELLHEAD X Y FACE 5334.89 3018.61 N 4399.82 W 564744.13 6019175.50 HS , 5344.49 3024.18 N 4407.64 W 564736.26 6019181.01 HS 5363.71 3035.34 N 4423.28 W 564720.5'1 6019192.01 HS 5387.72 3049.28 N 4442.83 W 564700,83 6019205.77 HS 5421.~4 3068.80 N 4470.21 W 564673.28 6019225.04 HS 5450.1'6 3085.53 N 5454.96 3088.32 N 5474.18 3099.47 N 5517.68 . 3'124.73 N 5517.68 3124.73 N DL/ 4493.67 W 564649.66 6019241.55 HS 0.00 4497.58 W 564645.73 6019244.30 ~S 0.00 4513.23 W 564629.98 6019255.30 MS 0.00 4548.65 W 56'4594.33 6019280.23 0.00 45~8.65 W 564594.33 6019280.23 0,00 AN/.. DRILL AKA-DPC · APPROVED MAR 1 7 1997 INITIAL/,/~' ~ O O (Anadrill (c)97 MPE18P06 3.0C 3:49 PM Mar-17-97 10:02A ~'~adY-~-ll DPC . .907~344 2160 P.06 m SHARED SERV ICES DR ILL ING l, I I I I · I II i ANADRILL AKA-DPC MPE-18 (P6) APPROVED VERTICAL SECTION VIEW i J MAR i ? 1997 Section at: 305.49 TVD Scale.' I inch : 1000 feet ,,, ..... ./~ Oep Scale.' I inch : ~000 feet <KB> o A ,,'-,,~,-.,.~.z.¢ _ : Drawn · ~4 Mar ~997 500 .................. ~ .......................... ~ ' ~ - = Scn]umaerger ' Marker Identification MD BKB SECTN INCLN 1000 ~ ' '~ . A) KB 0 0 0 .0,00 B) KOP / 1/~00 BUILD 200 200 -0 0,00 C) BUILD 1.5/J00 375 375 2 (,75 )500 ..... i ...... D) BUILD 2/~00 575 575 ~1 4,75 : E) CURVE 2.5/~00 800 798 34 9,25 F) END 2,5/100 CURVE ~920 ~828 439 35,33.- ~ ~ ........ ~~,'~-~ G) CURVE 2.5/~00 1993 ~888 48~ 35,33 2000 ~ ~ ' ~~ ~~l,. .... H] END 2.5/t00 CURVE 2339 2i54 70, 43,85 ' I) 9-5/8" 'CASING POINT 4285 3558 2050 43.85 'I ~ d) TARGET.~~*~ 90~4 6968 5325 43.85 K) 7" CASING POINT 9292 7168 5518 43.85 T e5oo ................. f ....... . L) TD 9292 7~68 5518 43.85 )V D' 3000, ~ ., . a5oo- = .............. .... ; 5000- F~ ;o i ; .. ~ ~ ~t~on Hold Z~ 0.00o, on ~ 0.00· ~ 0, ~ 2o 200' ~ : , ~0~" 200, 375, KOP/Bu~2d ~o/~00-, ....................... rz~ rnc 0.00o ~o ~.75O,on Az 270.000 F~ 200' ~ ~o 375' ~ 375' 57S' ~ld ~.So/~0O· D~r 80~0-- Fr~ Znc 2.75o ~o 4.75°,on Az 270.00o FF~ 37S' ~ 2o 575' I i i.i ~ i I t . i i F~ 575 ~ ~ to 798 ~ ~ F~ ~no 9.25~ ~o 35.33~,F~ Az 270.00 7000-- ~Z~ Z~ 35.3~o,~o1~ &= 303.16~ ;:~~,~ .......... ~ 1828' ~ ~o 1888' ~ 2993' 2339~ Cu~o 2.5o/~00, D~ .... Znc 35.33° to (3.85°,F~ Az 303.16o , . .-. ~ ,7 ,~/~.],j~ : · o ~ 305.~9, ~ 1888' ~ ~o 215~~ 7500--- 333~' 9393' ~11 ~~ ~o _ -- ........................... F~ 3254~ ~ ~o 7&~8~ ~ ., , eooo ; ; I I I I t ..... J o 5o0 ;ooo ~5oo eooo esoo 3ooo 3~oo 4ooo ~5oo ~ooo 5500 6ooo 65oo Section Departure m~ i ~ ~,~ ; ,, -- .. . (Anaar)]) (c)97 i~PE~BP06 3.0C 3:50 PM Pi Mar-17-97 10:02A ../!~.ad~j.11 DPC _ 907~:.~44 2160 P.07 SHARED SERVICES BRILLTNG I )- ,-.'22'2l"-'L-'_- -"'L--'L' '.",-'"2'-] ISection at: 305.49 JTVD Scale.: 1 inch : 100 feet ) . ,% '.~ , ].,i Marker Identification HO 8KB 5ECTN INCLN A) TARGET ',w,www,w~w,~ 90~4 696B 5325 43.85 B) 7'! CASING POINT 9292 716B 551B 43.85 I ..... ' ....~ ~.~: .]. ..:.__ ~_ C) TO 92927168551843.85 : } ~ ................. _ ....... '~- -~¢~' ' .~ Tar~e£ _(~ad.tu~. £Qg.feet ) ~- ~¢ ............ ~ - ~ ..... ) 'T~'~ ........... "' ........ i ---4 ......... ~ ...... '~m - ~ ........ ~ ..... ~ .....5 - ' .~- - g~ ........................ ..... ...... .....___:___._._. -~ - r~ .............. ~ ........ _. - _ b ....... ] · ~ ~ ~ ............ ~ .... _.~ ............. . ...... ~ ~ ] : A f, .' DRILL 'AK~,-DPC i O ' Ap[~RC,Vb~ ' ............. r~, ~' 1 ? 199/ ......... ; ............................. , ..... OD 4~o qnnn ~n~n ~ ~ nn ~' 50 5200 5250 5300 5350 5400 5450 5500 5550 5600 Section Departure (6)91 ~!8P06 3.06 4:01 PH PI SHARED SERVICES II ii DRILLING ,4nadr.i ]] S£h]umberger II MPE-18 (PC) PLAN VIEW CLOSURE · 5519 feet at Azimuth 304.49 ..................... D~CLINATION.: +28.:1:~/ {E) feet} i SCALE ....... : :1 inch = 600 feet I , '~ DRAWN. 14 Mar ~997 , ' Marker Ident ~ f icat~on MD N/S E/~ B) KOP / ~/~00 BUZLD eO0 0 N 0 ~ ~ ~ · C) BUILD ~.5/100 375 0 N 3 ' D) BUILD 2/I00 575 0 N 14 ~ ~" ' i E) CURVE ~ ' , i F} END 2,5/100 CURVE 1920 ~ ~ G} CURVE 2.5/100 i993 204 N 445 i J) TARGET ' ' K)'7" CASZN6 PO[Nf 9292 3125 N 4549 .,.. I ~ L) TD '9292 3~25 N 4549 '' i ~ 1997 ~ i ~ ' .. ' _ i__.. ._ i ................. , ~ . 5100 4800 4500 4200 3900 3600 3300 3000 2700 2400 2100 1800 ~500 ~200 900 600 300 0 300 <- WEST · EAST -> (Ana~il] [c)97 I~:~JBPO$ 3.06 4:02 P14 P) N Mar'14-g7 03:27P hadril'~-~Dpc' . , ,_gO7 )~ .... 2160 .p.07 - SHA..RED 'SERVICES" DRI'".LLING ' I i m m i ' MPE-J. 8 (P6) APPROVED VERTICAL, SECTION, VIEW FOR PERMiTTiNG se.t~o, at' 305.49 TVD Scale' I inch- 1000 feet O~LY ~ Dep Scale.' I inch = {000 feet ~oo- ~ '~.- Ana~rjY] Sc~]umberger ~ ........... ~.-.-.-] ............ , , , ~ , Narker Identification HD BKB SECIN INCLN ~000 ~ A) KB 0 0 0 O. O0 I B) K~ / t/tO0 BUILD 200 200 -0 0,00 C) BUILD 1.5/~00 375 375 2 t,75 1500 .... O) BUILD 2/100 575 575 t~ 4.75 E) C~VE 2.5/t00 800 798 34 g.25 . F) END 2.5/[00 CURVE 1920 ~828 439 35.33 ' ~ .... ~~r'~ G) CURVE 2.5/t00 1993 ~88B 4Bt 35.33 2000 ~.~ H) ENO 2,5/t00 CURVE 2339 2~54 70[ 43.85 I) 9-5/8' CASI~ POINT 42B5 355B 2050 ~3,B5 T J) ~ARGET **~***~ ~14 6968 5325 43.85 , 2500~- K) 7' CASING POIN[ 9292 7~68 5518 43.85 ~ '" L] TD 9292 7~68 55~8 43.85 ~V D 3ODD 3500-- I ~ ...... ~000 -, . 500Or- " , 5500 ..... 6000 ~ -~ -~ ..... . .... ~ ..... 6500- ~; ~ ...... ~ ~ r~)- -~ ~---] ...... 7ooo ........................................... J ................ ma,Jmlmm JlmmlmmjG~'' G''~ ..... . .... GG m~m ~m~m ~~m~ , 7~00~ ~' , ..... 0 500 ~000. ~500 ~000 esoo 3000 3500 4000 4500 5000 5500 6000 6500 ...................... Section Departure go7 3~ 2160 P.08 MAY--14-97 03.:.27P...A-qadr~--'i~'~''-DPc · - 8 (P6) iN I~r ~mmmmmm~ -- ~mm~ VERTICAL SECTION VIEW __~ , ..~~. Sect~o~ at: 305.49 ..... [ ...... ' .... ~ ..... ~'~, TVD Scale · ~ inc~ ~ go feet i ~ Oep Scale' I inch = go feet '~ _i5-~ m~ '~'Drawn, · ~4 Mar 1997 'tEE'~I~I)-'~ Marker Identification ~ BKB SECTN INCLN : ~ ~ A) TARGET tllltWttlfltl gOl4 6968 5325 43.85 ' B) 7' CASING POINT g~9~ 7168 55t8 43.85 , ~ ~ C) TO 9292 7168 5518 43.85 i-~: ~. ................~~ . ~ , , ~ ......... I ~,~-~--'--~-'-: :--'- ....... [: .., ....,.. _ .... [ " ~ APl ROVED ~ :,._ ~..~ rz_~,,',' . :' ..... F .... [ I t 4900 4945 4990 503,5 5080 5t;35 5170 5~15 5260 530,5 5350 5395 5440 5485 5530 SeCt ion Departure __ SHARED 150 ' 301 5100 4800 4500 4200 ~a~r~l! (c)97 HPE18P06'3.OC 3: ]5~P# PI 'SERVICES" i _ i ir l i ii__. i 3900 3600 3300 _ DRILLI'NG i iiiJll iiii i iii i i _ Ill J I · Anadr ]] $ch/u l)erger i iii i i i i iiii ~lll ii HPE-18 (PG) PLAN VIEW i i1~ u i_ II CLOSURE ' 5519 feet at Azimuth 304,49 DECLINATION.' +28.155 (E) SCALE ' ~ inch = BOO feet DRAWN · 14 Mar' 1997 Narker Identification MD N/S E/W Al KB 0 0 N 0 E B) KOP / 1/100 BUILD 200 0 N 0 E C) BUILD 1.5/100 375 0 N 3 W D) BUILD 2/100 575 0 N 14 W E) CURVE 2,5/]00 800 0 N 41W F} ENO 2.5/i00 CURVE 1920 18i N 4i0 W G} CURVE 2.5/100 t993 204 N 445 W H) ENO 2.5/100 CURVE 2339 328 N 627 W I) 9-5/8' CASING POINT 4285 1111N 1725 W J) TARGET ~t~x~ 9014 3013 N 4392W KI 7" CASING POINT 9292 3i25 N 4549 W L) TD 9292 3125 N 4549 W 3000 2700 2400 2100 1800 1500 1200 900 600 300 0 300 <- WEST' EAST -> 0 '0 K) 0 0 HAY'- 14-97 02: 07P A~_.ad),"i~_l ~DPC .~ 907~.3'°r~ 2160 P- 02 MPE-18 PO6 MPE-Pad Milne Point NABORS 27E Anadrlll MPE. I 3JkST2 Ma'r'-14-g7 02 07P ~ad'r-,~_~'OPC ~907. 3z~'. 2160 P,03 w,- MPE-18 , ~ MPE-Pad j ~ Milne Point . J _ ~ .~ NABORS 27E J ~ I~-ISA$T2 I BP EXPLORATION March 17, 1997 David W. Johnston, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: Before Spud Changes to Approved Application for Permit to Drill #97-42 Dear Mr. Johnston, in order to improve the positioning of the bottom hole location away from faults in the Kuparuk is it necessary to modify the well profile from the one submitted and approved in the Permit to Drill #97-42 on March 12, 1997. This correspondence is submitted in order to be in compliance with AOGCC Regulation 20 ACC 25.015, Changes to Drilling Permit, (a) For a proposed change in a drilling permit ...... before the start of actual drilling operations. After reevaluating seismic, it has been determined by the BPX Milne Point Geosciences Group that a more optimal wellbore trajectory for stimulation and well productivity will be achieved if the well profile is changed through the Kuparuk interval in the well E-18, as proposed in the Before Spud Changes to the Approved Permit. The revised well profile for E-18, incorporating this modification to the well trajectory is included in this request for change. As a result of the proposed wellbore trajectory modification the following changes are requested: 1. The well profile be modified. 2. The location At top of productive interval be changed to: 1392' NSL, 1085' WEL, Sec. 23, T13N, R10E, UM. from: 1622' NSL, 1035' WEL, Sec. 23, T13N, R10E, UM. 3. The location At Total Depth be changed to: 1504' NSL, 1242' WEL, Sec. 23, T13N, R10E, UM. from: 1697' NSL, 1132' WEL, Sec. 23, T13N, R10E, UM. Thank-you for your consideration in this mater and if you have any questions or need additional information concerning this request for Before Spud Changes to Approved Appfication for Permit to Drill #97-42 please contact me in Anchorage at 564-5042. Lance J. Spencer Ddlling Operations Engineer Shared Services Drilling BPX ALASKA OIL AND GAS CONSERVATION COMMISSION .. TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 12, 1997 Randy Thomas Drilling Superintendent BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Mitne Point Unit MPE-18 BP Exploration (Alaska) Inc. Permit No 97-42 Sur. Loc.: _~661~SL, 19/. WEL, Sec. 25, TI.~N, R10E, UN[ Btmhole Loc: 1697~SL, l132'WEL, Sec. 23, T13N, R10E, UM Dear Mr. Thomas' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dltYenclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION CO~vI,'vllSSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill !1b. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] 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. Plan RTE = 57.7' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3661' NSL, 1974' WEL, SEC. 25, T13N, R10E Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 1622' NSL, 1035' WEL, SEC. 23, T13N, R10E MPE-18 At total depth 9. Approximate spud date Amount $200,000.00 1697' NSL, 1132' WEL, SEC. 23, T13N, R10E 03/14/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025518, 1697'I No Close Approach 2560 9258' MD / 7095' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 200' Maximum Hole Angle 44.46° Maximum surface 2885 psig, Attotal depth (TVD) 7044' / 3589 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) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 4271' 31' 31' 4302' 3558' 988 sx PF'E', 861 sx'G' 8-1/2" 7" 26# L-80 Btrc 9228' 30' 30' 9258' 7095' 242 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Sudace Intermediate Production "_~~ ~ ~ V Liner 0R IGINAL Perforation depth: measured .,~.~ Gl & Gas Cons. true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Lance Spencer, 564-5042 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 ~~.._~~ Rand/Thomas ~ Title Drilling Superintendent Date Commission Use Only Perm~mb~[/? I APl Number Approval Date I See cover letter -- ~ 50- CD 2.- ~' --- ~ ~ ~ ~ F ,-~'-"/c'~ -- J 7 for other requirements Conditions of Approval: Samples Required [] Yes ,¢~ No Mud Log Required [] Yes ]~ No Hydrogen Sulfide Measures ?E~Yes ,,~No Directional Survey Required ~Yes [] No Required Working Pressure for 8OPE [] 2M; []3M; J~ 5M; [] 1OM; [] 15M Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared J Type of Well Services Drilling Contact: Lance Spencer I Well Name: IMP E-18 Well Plan Summary (producer or injector): I Kuparuk Producer 564-5042 ISurface Location: Kuparuk Target Location: I Bottom Hole Location' 3661 NSL 1974 WEL Sec 25 T13N R10E UM., AK 1622 NSL 1035 WEL Sec 23 T13N R10E UM., AK 1697 NSL 1132 WEL Sec 23 T13N R10E UM., AK I AFE Number: 1337065 I Estimated Start Date: I MD' 19,258' I ITvD: IWell Design (conventional, slimhole, etc .)' I Rig: INabors 27-E I Operating days to complete: I10 17,095' Bkb I I KBE' 157.7 IMilne Point Ultra Slimhole Longstring 9- 5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) Base Permafrost 1 953 1 800 8.3 ppg, 777 psi NA 5421 4283 8.3 ppg, 1849 psi CA 5 4 9 3 4 4 0 8 8.3 ppg, 1902 psi CB 5584 4473 8.3 ppg, 1931 psi Base OB 5 6 3 3 45 0 8 8.3 ppg, 1946 psi Top HRZ 8 21 1 6 3 48 8.6 ppg, 2839 psi Base HRZ 8 51 3 6 5 6 3 8.6 ppg, 2935 psi TKLB 8 6 5 3 6 6 6 3 9.6 ppg, 3326 psi TKUP/UD 8835 6793 9.6 ppg, 3391 psi TKC1 9080 6968 9.8 ppg, 3551 psi TKUC/TARGET 9083 6970 9.8 ppg, 3914 psi TKUB/B8 9094 6978 9.8 ppg, 3919 psi TKB7 91 0 8 6 9 8 8 9.8 ppg, 3924 psi Total Depth 9258_+ 7095 9.8 ppg, 3984 psi Casinq/Tubing Pro!lram' Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1 # H-40 Weld 80 32/32 11 2/11 2 12 1/4" 9-5/8" 40# L-80 btrc 4271 31/31 4302/3558 8- 1/2" 7" 2 6 # L-80 btrc 9228 30/30 9258/7095 The internal yield pressure of the 7" 26# casing is 7240 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKC1 at _+ 7044 TVDSS In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7044 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3589 psi is 2885 psi, well below the internal yield pressure rating of the 7" casing. MP E-18 (O) Drilling Permit ORIGINAL 1 3/5/97 Logging Program: Open Hole Logs: Surface MWD Directional from surface to TD. Intermediate N/A Fi n al MWD Directional from 9-5/8 shoe and LWD (GR/EWR4/CNP/SLD/ROP) from surface shoe to TD. Real Time Cased Hole Logs: N/A Mud Logging Mud Loggers and samples are NOT required. MWD GR: EWR4: CNP: SLD: ROP: Directional: Inclination and Azimuth Gamma Ray Electromagnetic Wave Resistivity 4 (Four Depths of Investigation) Compensated Neutron Porosity Stabilized Litho Density Rate of penetration Mud Pro~lram: Special design considerations Special attention should be given to gravel, clay, hydrate, and coal intervals in the surface hole. Running gravel, sticky clays below the permafrost, gas gut mud due to hydrate formation, excessive fill on connections, tight coal sections and stuck pipe have been encountered in previous surface holes on E-Pad. Prior to spudding a complete review of the E-Pad drilling hazards is required. Preventative measures such as more frequent short trips, viscosity and mud weight control, Iow mud temperatures, controlled drilling rates, and lower flow rates should be employed to mitigate )roblems and lost time in the surface hole. HYDRATES Hydrates are present on E-Pad and must be managed safely. It is necessary to be knowledgable of the safeguards and measures required to safely handle the hydrates that will be encountered while drilling on E-Pad. Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 10.2 50 35 15 30 1 0 15 Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 10 3 7 8.5 6 - 8 to to to to to to to 10.2 50 15 10 20 9.5 4-5 MP E-18 (O) Drilling Permit 2 3/5/97 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP:200' Maximum Hole Angle: 44.46° Close Approach Well: (No Shut In Wells) Disposal: No "Drilling Wastes" will be injected or disposed into E-18 while drilling this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A or other approved site for disposal. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564- 4305) with request. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with Pertinent rules and regulations. GENERAL DISCUSSION Well Objective: MP E-18 will be drilled to aTD of 9258' md with a horizontal displacement of 5,541' The surface casing will be shallow set above the Schrader Bluff at 4,302'md (3558' bkb) . This well is planned to intersect two targets in the Kuparuk: the C1, and B7 sands. MP E-18 will be completed as Kuparuk River C1 and B7 Sand producer. Geology The anticipated reservoir pressure for the MPE-18, (O) fault block is 3600 psi, based on the initial reservoir pressure encountered in exlporation wells MP^-01 and MPA-02. Pressures surrounding the fault are substantially lower due to production. The fualt to the northwest pf the target appears to be a reverse fault, so the Cabd B sand could be duplicated in the well bore. ^ drilling drsk exits if the wellbore and fault angle are to close; the wellbore should be about 45 degree theu the target, and the target should eb restricted to the SE quadrant. The Kuparuk C abd B sands should be 100% oil bearing. The OWC in the MPE-18, (O) fault block is expected at 7045' TVDss which is in the Kuparuk B shale. DRILLING HAZARDS AND RISKS: GAS HYDRATES Hydrate sections may be encountered on E-Pad while drilling the surface hole. Mud treatments with Lecithin have minimized the adverse effects of hydrates but it's use is still not proven so its use should be carefully monitored. In spite of the apparent success's of the Lecithin treatments extreme caution is still advised. Severely gas cut mud, excessive connection gas, flow on connections and other problems can occur while during the surface hole on E-Pad and are directly attributed to gas hydrates. In addition problems can develop as a result of measures designed to lessen to effects gas. It is important to recognize what problems might develop while fighting gas hydrates and have plans in place to minimize them. Plans should be made in advance prior to spudding the surface hole to mitigate to potential risks and minimize the nonproductive time involved in managing hydrates. Some measures which are necessary to lessen to effects of gas hydrates include: 1. Increased mud weights; 2. Low drilling fluid temperatures; 3. Reduced ROP's for control drill rates; 4. Controlled circulating and drilling fluid rates; 5. Utilization of Lecithin MP E-18 (O) Drilling Permit 3 3/5/97 Close Approaches There are no close approaches associated with the drilling of MP E-19, however, tolerance lines should be carefully monitored and deviations from the proposed wellpath minimized. Water Injection The water injection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazard or risk. Annular Injection Currently annular injection is not permitted on E-Pad. Gas Injection No gas injection wells are present on E-Pad. The gasinjection wells on E-Pad do not abonormally pressurize the Kuparuk, Ugnu or Schrader Bluff formations causing a drilling hazzard or risk. Lost Circulation: Lost circulation has been most prevalent while running casing and cementing in the surface as well as production hole. Losses are extremely probable while cementing the long string in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing. Major losses have also occured while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. The losses normally occur in the Ugnu and Schrader Bluff with the shallow set surface casing design especially while cementing the 7" csg. Stuck Pipe Potential: Running gravels, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occured while drilling the 12 1-4" surface holes on E-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing after drilling the surface hole. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole and bridging, and the 9- 5/8" casing has been stuck. While drilling the surface hole additional time has beeen spent reaming and conditioning the hole prior to cementing because of tight hole. These problems in some instances were greatly exaggerated because of measures taken to manage the gas hydrate problems. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk. This is a common occurance has often causes difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8 1/2" production interval. Attention should be given to The Ugnu and Schrader Bluff formations to reduce the chances of differential sticking in these formations with higher muds weights needed to keep the HRZ and Kuparuk formations in balance. Differential sticking is most likely while running the production string. Formation Pressure: KUPARUK SAND 7044' TVDss 3600 PSI 9.8 PPG EMW The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKB7 at _+ 7044 TVDSS. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _+7044 TVDSS. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3589 psi is 2885 psi. The maximum expected pore pressure for this well is 9.8 ppg EMW (3,600 psi @ 7,044' TVDss). There has been injection in this region, however the reservoir pressure is not expected to exceed this estimate. See the updated Milne Point E-Pad Data Sheet prepared by Pete Van Dusen for information on E pad and review recent wells drilled on E Pad. MP E-18 (O) Drilling Permit 4 3/5/97 MP E-18 Kuparuk Producer Proposed Summary of Operations Review Pre-Spud Checklist RP-Surface Hole VI.0 pages 1-3. prior to spud. , Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5A Wellhead on conductor as well as a nipple to aid in performing potential wellhead stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. , , . , Drill a 12-1/4" surface hole as per directional plan. Advise Rig Team to proceed with Extreme Caution prior to and while drilling the hydrate interval. Run Directional MWD from surface to 12-1/4" TD. . .... Run 9-5/8" casing. Space out ES Type H Cementer to 1300'. ~. Perform Two Stage cement. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP . MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/EWR4/CNP/SDL). RIH, Drill out Float Equipment and 20' of new formation. Perform Leak Off Test as per Revised Recommended Practices Manual. Record pressure versus cumulative volume for LOT test for the well file. 10. Drill 8.5" hole to TD as per directional plan. Make sure sufficient footage is drilled to provide 150' of production rat hole between the base of the Kuparuk B sand and PBTD before running the 7" casing. 11. Run and Cement 7" Casing. Insure that a short joint is run in the 7" casing approximately three joints above the top of the Kuparuk. Displace cement with 8.4 ppg source waterand enough diesel to cover from the base of permafrost to surface (+- 2 1 0 0' MD). 1 2. Test casing to 3500 psig. 13. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 1 4. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. MP E-18 (O) Drilling Permit 5 3/5/97 MP E-18 Kuparuk Producer 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON Casing Size: 9-5/8" 40# L-80 Circ. Temp 60 deg F at 2840' TVDSS. TWO STAGE CEMENT PROGRAM: Refer to the Two Stage Cementing Procedure The objective of the Surface Cement is to insure that cement is circulated to surface. Second stage lead cement shall be pumped until such time as cement is circulated to surface before switching to displacement. Arrangements should be made to insure that sufficient cement is available so that continuous cementing can occur uninterrupted until cement is circulated to surface. This volume may exceed the annular capacity and the 250% estimated excess. Note: 1. The ES Cementer is located at 1300' md. 2. RECIPROCATION of the CASING STRING is required WHILE CEMENTING. 3. Lead and Tail slurries are pumped in the first stage. 4. Only a Lead slurry is pumped in the second stage. 5. Dye shall be introduced into the inital part of the first stage and into the water before the second stage in order to obtain an estimate of annular capacity so that additional cement can supplied and adequate excess can be pumped if required. 6. Once an adequate volume of cement has been circulated to surface immediately begin displacement. 7. The WELLHEAD STABILITY CEMENT will be pumped only if the cement top falls below surface after the pumps are shut down. 8. Utilize a large flow area float shoe. 9. Use weighted spacer before first stage lead slurry:(1 ppg higher than current mud weight). 1 0. Add dye in the water spacer before the second stage to assist in determining the annular volume. 1 1. Incorporate "Celloflakes" into ONLY the First Stage cement LEAD and TAIL slurries. Caution: 1. MAKE SURE THAT THE SECOND STAGE LEAD CEMENT IS CIRCULATED TO SURFACE BEFORE PUMPINGDISPLACEMENT. 2. Do not incorporate FLOCELE "Cello-Flakes" in the Second stage cement slurries. 3. Make preparations to handle cement to surface on the first stage circulation. 4. Make preparations to handle cement to surface on the second stage circulation. MP E-18 (O) Drilling Permit 6 3/5/97 First Stage: SPACER: 70 bbls NSCI weight 1 ppg higher than current mud weight. 1st LEAD CEMENT TYPE: Permafrost E ADDITIVES' 0.15#/sk Flocele WEIGHT: 12.0 ppg APPROX NO SACKS: 331 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. 1st TAIL CEMENT TYPE: Premium G ADDITIVES: 2.0% CaCI2 +.15#/sk Floceles WEIGHT: APPROX NO. SACKS: 861 15.8 ppg YIELD:l.15 ft3/sx MIX WATER: 4.9 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 Second Stage: SPACER: 75 bbls Water 2nd LEAD CEMENT TYPE:: Permafrost E ADDITIVES: None WEIGHT: APPROX NO SACKS: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk 6 5 7 THICKENING TIME: Greater than 4 hrs at 50° F. Wellhead Stability Cement CEMENT TYPE: Permafrost E ADDITIVES: None WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk Centralizer Placement= , Install one(l) Straight Blade Rigid Centralizers per joint of 9-5/8" bottom 10 joints of casing (required). , Install one(l) Straight Blade Rigid Centralizers per joint on the 9-5/8" from 2200-2700 feet to cover the top hydrate intervals (required). centralizers in middle of joints using stop collars. casing on casing on Place all MP E-18 (O) Drilling Permit 7 3/5/97 Surface Cement Volumes: . First Stage LEAD Cement Volume = Interval from1300-1955' md The estimated first stage lead cement volume is equivalent to the annular volume calculated from the ES Cementer at 1300' md to the Base of the Permafrost at 1955' md (1858 TVDbkb) + 250% EXCESS. 2~ First StageTAtL Cement Volume = Interval from 1955-4302' md The estimated first stage tail cement volume is equivalent to the annular volume calculated from the Base of the Permafrost at 1955' md to surface TD at 4302' md (3558' TVDbkb) plus 30% Excess and the shoe joint volume. The estimated shoe joint volume is equivalent to the capacity of 80'md of 9-5/8", 40# casing. 3. Second Stage LEAD Cement Volume = Interval from 0-1300 md The estimated second stage lead cement volume is equivalent to the annular volume calculated from the ES cementer located at 1300' MD (1281' TVDbkb) to surface plus 250% excess. . The estimated Wellhead stability Cement Volume is 150 sacks. It will be pumped if necessary to provide support to the wellhead. Other Considerations: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 1 2 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. . After MPK-25 was suspended following problems with the surface casing job. The importance of getting a sucessful cement job on the suface job cannot be stressed enough. There are changes to the spacer, cement volumes and centralizer program on this well to improve the chances of getting cement to the surface. If the cement falls back, do a wellhead stability cement job. MP E-18 (O) Drilling Permit 8 3/5/97 MP E-18 Kuparuk Producer 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON This cement program is proposed only if the Schrader Bluff formations are NOT hydrocarbon bearing. In the event the Schrader Bluff formations proves to be hydrocarbon bearing a revised cement program will be submitted. Casing Size: 7" 26# L-80 CIRC. TEMP: 140°F BHST 170° F at 7040' TVDSS. SINGLE STAGE CEMENT JOB' Cement from TD to 1000' above KUPARUK TKUP/UD. SPACERs: 20 bbls fresh water and 70 bbls NSCI mixed per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE' Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.45% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 242 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: , . 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the from 120' below to 1 20' above any potential hydrocarbon bearing sands. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. CEMENT VOLUME' Interval 7835-9258' md , Single stage cement volume is calculated to cover 1000 FT MD above the highest potential KUPARUK(TKUPD) production sand + 30% excess. OTHER CONSIDERATIONS: , Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. MP E-18 (O) Drilling Permit 9 3/5/97 Anadr£11 Schlumberger Alaska DistrAct 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPE-18(O) (P05) Field ........ : Milne Point, E-Pad Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.45461295 N Surface Long.: 149.43553070 W Legal Description Surface ...... : 3660 FSL 1974 FEL S25 T13N R10E UM Tie-in survey: 3660 FSL 1974 FEL S25 T13N R10E UM Target ....... : 1622 FSL 1035 FEL S23 T13N R10E UM BHL .......... : 1697 FSL 1132 FEL S23 T13N R10E UM LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 569171.36 6016198.16 569171.36 6016198'.16 564800.00 6019400.00 564702.41 6019474.40 PROPOSED WELL PROFILE Prepared ..... : 04 Mar 1997 Vert sect az.: 307.87 KB elevation.: 57.70 ft Magnetic Dcln: +28.154 (E) Scale Factor.: Convergence..: +0.53] 0.99990544 ~4-469 ANADR~[L AKA-OPC APP OV£D FOR PERMITTING ONLY PLAN # 5' STATION IDENTIFICATION Tie-in KOP BUILD 1/100 BUILD 1.5/100 MEASURED INCLN DEPTH ANGLE 33.00 0.00 200.00 0.00 300.00 1.00' 375.00 1.75 400.00 2.13 DIRECTION AZIMUTH VERTICAL-DEPTHS SECTION TVD SUB-SEA DEPART 0.00 270.00 270.00 270.00 270.00 33.00 -24.70 200.00 142.30 299.99 .242.29 374.97 317.27 399.96 342.26 0 - 00 -0.00 0.69 2.11 2.78 COORDI NATES' F ROM WELLHEAD ALASKA Zone 4 TOOL DL/ X Y FACE 100 0.00 N 0.00 N 0.00 N 0.00 N 0.00 N 0.00 E 569171.36 6016198.16 90L <TIE 0.00 E 569171.36 6016198.16 90L 0.00 0.87W 569170.49 6016198.15 90L 1.00 2.67 W 569168.69 6016198.14 90L 1.00 3.52 W 569167.84 6016198.13 90L 1.50 BUILD 2/100 CURVE 2.5/100 500~00 3.63 575.00 4.75 600.00 5.25 700.00 7.25 800.00 9~25 270.00 499.83 .442.13 270.00 574.63 516.93 270.00 599.53 5141.83 270.00 698.93 641.23 270.00 797.89 740.19 6.74 0.00 N 11.06 0.00 N 12.78 0.00 N 21.37 0.00 N 32.70 0.00 N 8.53 W 569162.83 6016198.08 90L 1.50 14.01 W 569157.35 6016198.03 90L 1.50 16.19 W 569155.17 6016198.01 HS 2.00 27.07 W 569144.29 6016197.91 HS 2.00 41.42 W 569129.94 6016197.78 45R 2.00 900.00 11.16 279.16 896.31 838.61 47.53 1.54 N 59.02 W 569112.34 6016199.15 36R 2.50 O (Anadrill (c)97 MPE18P5 3.0C 9:16 AM P) STATION MEASURED INCLN IDENTIFICATION DEPT}{ ANGLE 1000.00 13.26 1100.00 15.49 1200.00 17.78 1300.00 20.12 1400.00 22.50 1500.00 24.89 1600.00 27.31 1700.00 29.74 1800.00 32.18 1900.00 34.62 END 2.5/100 CURVE BASE PERMAFROST CURVE 2.5/100 1918.03 35.06 1954.68 35.06 1991.33 35.06 2000.00 35.28 2100.00 37.73 s~ ~.S/lOO co~vs 9-5/8''~ CASING NA 2200.00 40,19 2300.00 42.65 2373.40 44.46 4302.21 44.46 5318.03 44.46 OA OB BASE OB TOP MRZ BASE HRZ 5493.17 44.46 5584.24 44.46 5633.28 44.46 8211,36 44.46 8512.60 44.46 TKLBiMARKER 19) TKUP/(D S~ALE) 8652.71 44.46 8682.86 44.46 8834.86 44.46 PROPOSED WELL PROFILE ====~=m== ---== DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 285.56 994.05 936.35 290.19 1090.92 1033.22 293.67 1186.73 1129.03 296.37 1281.30 1223.60 298.53 1374.46 1316.76 SECTION DEPART 66.63 89.97 117.50 149.16 184.90 300.29 1466.02 1408.32 301.76 1555.82 1498.12 303.00 1643.68 1585.98 304.08 1729.43 1671.73 305.02 1812.90 1755.20 Mar i.~97 COORDI NATES- FROM WELLHEAD 6.16 N 79.63 13.84 N 103 . 21 24.58 N 129.73 38.36 N 159.13 55.14 N 191 . 35 224.65 74.89 N 226.34 W 268.32 97,58 N 264.03 W 315.85 123.17 N 304.34 W 367.14 151.60 N 347.20 W 422.09 182,83 N 392.53 W 305.17 1827.70 1770.00 432.38 188.75 N 305.17 1857,70 1800.00 453.41 200,88 N 305.17 1887.70 1830.00 474.44 213.01 N 305.25 1894.79 1837.09 479.43 215.89 N 306.05 1975,16 1917.46 538.87 250.56 N 306.77 2052.92 1995.22 601.72 307.42 2127.90 2070.20 667.87 307.85 2181.08 2123.38 718.44 307.85 ]557.70 3500.00 2069.46 307.85 4282.70 4225.00 2780.98 307.85 4407.70 4350,00 2903.66 307.85 4472.70 4415.00 2967.45 307.85 4507.70 4450.00 3001.80 307.85 6347.70 6290.00 4807.58 307.85 6562.70 6505.00 5018.59 307.85 6662.70 6605.00 5116.73 307.85 668~.22 6626.52 5137.84 307.85 6792.70 6735.00 5244.31 ALASKA Zone 4 TOOL DL/ X Y FACE 100 ~===~s=== ~=== ~=~ 569091.69 6016203.58 30R 2.50 569068.03 6016211.04 25R 2.50 5~9Q~1~.92 ~016221_ 54 __ 22R 2.50_ _ AKA-DPC 400.96 W 568768.71 6016383.16 HS 2.50 418.17 W 568751.39 6016395.13 BS 0.00 435.38 W 568734.06 6016407.10 llR 0.00 439.46 W 568729.96 6016409.94 11R 2.50 487.79 W 568681.31 6016444.16 llR 2.50 287.89 N 538.38 W 568630.38 6016481.01 10R 2.50 327.79 N 591.15 W 568577.25 6016520.{2 10R 2.50 358~68 N 631.19 W 568536.92 6016550.93 HS 2.50 1187.74 N 1697.92 W 567462.64 6017369.97 HS 0.00 1624.36 N 2259.72 W 566896.87 6017801.32 ~S 0.00 1699.64 N 2356.58 W 566799..32 6017875.69 HS 0,00 1738.79 N 2406.95 W 566748.60 6017914.37 HS 0.00 1759.87 N 2434.07 W 566721.29 6017935.19 HS 0.00 2868.00 N 3859.87 W 565285.39 6019029.93 HS 0.00 2997.48 N 4026.48 W ~65117.61 6019157,85 HS 0.00 3057.71 N 4103.96 W 565039.58 6019217.35 ~S 0.00 3070.66 N 4120.64 W 565022.79 6019230.15 ~S 0.00 3136,00 N 4204.70 W 564938.13 601929~,69 HS 0.00 (Anadrill (c)97 MPE18P5 3.0C 9:16 AM P) STAT ION IDENTI FICAT ION KC1 **~ TARGET TKB7 TKB6 TKB5 TKB4 TD TKB3 EXPECTED OWC MEASURED INCLN DEPTH ANGLE 9080.05 44.46 9082.86 44,46 9094.07 44.46 9108.08 44.46 9136.10 44,46 9171.13 44,46 9220.17 44.46 9258.08 44.46 TKB2 PROPOSED WELL PROFILE DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 307.85 6967.70 6910.00 307.85 6969.70 6912.00 307.85 6977.70 6920.00 307.85 6987.70 6938.00 307,85 7007,70 6950.00 307.85 307.85 307,85 7032.70 6975,00 7067.70 7010.00 7094.76 7037.06 7097.70 7040.00 7102.70 7045.00 7122.70 7065.00 SECTION DEPART 5416.05 5418.02 54~5,87 5435.68 5455.31 5479.85 5514.20 5540,75 · D4 Mar i997 Page ===================== ~====~=====~====== ==== ~=== COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X Y FACE 100 3241,39 N 4340.31 W 564801.56 6019398.81 ~S 0.00 3242.59 N 4341.86 W 564800.0~ 6019400.00 ~S 0.00 3247,41 N 4348.06 W 564793.76 6019404,76 HS 0,00 3253.44 N 4355.80 W 564785.95 6019410.71 ~S 0,00 3265.48 N 4371.30 W 564770,35 6019422.61 ~S 0,00 3280.54 N 4390.68 W 564750.84 6019437.48 ~S 0.00 3301.61 N 4417.80 W 564723.52 6019458.31 ~S 0.00 3317.91 N 4438.76 W 564702.41 6019474.40 0.~0 O ANADRILL AKA~DPC APPROVED FOR PERMITTING ONLY O (Anadrill (c)97 MPE18.P5 3.0C 9:16 AM P) Ma~-04-97 Og=48A AnadPill DPC 907 344 2160 P.O.~ SHARED SERVICES DRILLING MPE- 8 (0)(PO5) VERTICAL SECTION VIEW ' A-- ! i ) Section at: 307.87 B-- Ii I TVD Scale.' ~ ~ncn-- lO00 feet C---~ m m m ~ m __ .'! Oep Scale' ~ inch 1000 feet )--- D-:--- ! ..... i' DPawn .... ' 04 HaP ]997 E' I ' ........... Marker Identification MD BKB SECTN INCLN >................ A ) Tie-tn33 :]3 0 0.00 i I B) KOP BUILD ~/lO0 200 200 -0 0.00 '''--~ ....... ' .... ~J~sf-Ke~ C) BUILD 1.5/lO0 375 375 2 ~.75 )m D) BUILD 2/~00 575 575 ~ 4.75 , E) CURVE 2.5/100 BOO 7gB 33 9.25 m F) END 2.5/t00 CURVE 19lB ~B2B 432 35.06 ', G) CURVE 2.5/~00 1991 1888 474 35.06 )m ..... ' H) END 2.5/100 CURVE 2373 21B~ 718 44.46 I) 9-5/8" CASING 4302 355B 2069 44.46 J) ~ TARGET ~ 9083 6970 54~B 44.46 ) ' m K) TO 9258 7095 5541 44.46 . i . ~:~ ~ ........... ~ ...... m .... ... . , I -T~Z- ~ fie ................. ~ ....... I ..................... ...... ' .... ~ ~ ,~tJ ..... ~-~2; .......... ~. .i ii iiill ,llml _ iiii ii iiiiii' ii lljm Illllllml i::' mm IIIII . ...................... ._1 , , 0 500 looo t500 2000 ;~500 3000 3500 4000 4500 5000 5500 6000 6500 Section Departure (Anadril) (c]97 N~tGP53.069:J7 AM P] Ma~-04-97 09:49A Anad~ill DPc 907 344 2160 P.06 ~ . A) ~ TARGET ~** 9083 6970 54~8 44.46 . Section at: 307.87 - TVD Sca]e.' ~ ~nch = 200 feet . Dep Scale.' J inch = 200 feet 6ooo ~ ' Draun .... · 04 Mar ~997 . , ' AnadrJ ]] SchJu~berger ~oo .... 6gO0-~ - ) ............................ . 720O ,. ~ m 73oo ) ANAG RILL AKA-D~ -- ~ ........ ; ........................ - ...... · ..... ~ ...... ~ ...... m. ; ~ A ~P~OVED · F. OR I'ERMITTING ........... { ] ...................... ; ............... m m m .. , ~.oo - .uoo ~soo ~700 4800 Zsoo sooo o{oo u~oo 5300 5~00 55oo 5600 5700 5800 Sect ~on DepactuCe Ma~-O4-97 Og:4gA Anadrill Dpc 9O7 344 2160 ~ . P.O7 SHARED Marker Identificalion A) Tie-in B) KOP BUILD 1/100 C) BUILD 1.5/~00 D) BUILD 2/100 E) CURVE 2.5/~00 F) END 2.5/100 CURVE G) CURVE 2.5/100 H) ENO 2.5/i00 CURVE I) g-5/8" CASING J) ~ TARGET w~ K) TD ~D N/S 33 0 N 200 0 N 375 0 N 575 0 N 800 0 N 1918 · 189 N 1991 213 N 2373 359 N 4302 1188 N §063 3243 N 9258 33t8 N SERVICES E/W 41 401 435 631 1698 4342 4439 DRILLING MPE-18 (0)(PO5) PLAN VIEW CLOSURE ..... : 5542 feet at Azimuth 306.78 DECLINATION.: +28. 154 (E) SCALE ....... ; 1 knch : BOO feet DRAWN ....... : 04 Mar 1997 AnadrJ ] ] Schlumberger i ANADRILL AKA-DPC i APPROVED i FOR PERMITTING] ONLY , I PLAN # _~ j l~rget (Rild~U-':; J0C feet ) -. .......... I vt: ra 5200 4800 4400 4000 3600 3200 2800 2400 2000 1BO0 1200 800 400 0 400 <- WEST' EASI -> (~.nadrill [cig7 NPE~BP5 3.0C ~. tg AM P) WELL PERMIT CHECKLISTco. WELL NAME INIT CLASS a~c~9/ /- z~,~4 GEOL AREA , PROGRAM: expD dev~redrlD servO wellbore seg~ ann disp para reqD miT# ///6~ ON/OFF SHO~,.. ~J~ ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Y Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well lOcated proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... I Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait.' ...... N N N N N N N N N N N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... .~ N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............ ~Y~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.-~Y----N 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip lis% adequate . N 25. BOPEs adequate ............. ~J--2~ .... ~ N 26. BOPE press rating adequate; test to ~'~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... .~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ......... 34. Contact name/phone for weekly progress reports .... [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH.~ mcm~ Comments/Instructions: HOWldlf - A:\FORMS\cheklist rev 01/97 WELL PERMIT CHECKLISToo Y FIELD & POOL ~ ..~- ~-/~-~ INIT CLASS PROGRAM: expo dev~redrl[1 serv[q wellbore seg~ ann disp para req~ UNiT ON,OFF /~/~ ADMINISTRATION 1. Permit fee attached .................. . ~ 2. Lease number appropriate ............... ' 3. Unique well name and number ............... Y 4. Well located in a defined pool .............. Y 5. Well located proper distance from drlg unit boundary. . .Y 6. Well located proper distance from other wells ...... Y 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. . .~.Y 13. Can permit be approved before 15-day wait ....... ENGINEERING DA E 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf cng. .y~ 17. CMT vol adequate to tie-in long string to surf cng . . . 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..-~~ 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ............ Z-~ ....... ~ N 26. BOPE press rating adequate; test to ~J~ psig~/ N 27. Chokemanifoldcompliesw/2LPIRP-53(May84) ...... 28. Work will occur without operation shutdown ....... N 29. Is presence of H2S gas probable ............ ~ N Permit can be issued w/o hydrogen sulfide measures .... Y N/ Data presented on potential overpressure zones ..... ~/N 32. Seismic analysis of shallow gas zones ......... Seabed condition survey (if off-shore) ...... ~ . Y N Contact name/phone for weekly progress reports .,/ . . . Y N [exploratory only] ~ GEOLOGY R 30. 31. 33. 34. REMARKS GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions: HOW/dlf- A:\FORMS\cheklist rev 01197 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 Wed Jun 18 10:23:36 1997 Reel Header Service name ............. LISTPE Date ..................... 97/06/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Tape Header Service name ............. LISTPE Date ..................... 97/06/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Physical EOF Comment Record TAPE HFJADER MILNE POINT UNIT MWD/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MWD RUN 3 AK-MM-70076 G. TOBIAS P. WILSON OPEN HOLE BIT SIZE (IN) Scientific Technical MPE-18 500292274800 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 18-JUN-97 , ECE VED 25 13N JUN 2 0 1997 10E Gas . ~],.,s;,~a 0il & Cons. Comrni.~ion 3661 Anchorage 1974 .00 58.20 24.70 CASING DRILLERS SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 20. 000 112.0 12. 250 9. 625 4301.0 8.500 9440.0 1. ALL DEPTHS ARE MEASURED DEPTHS(MD) UNLESS OTHERWISE NOTED. 2. MPE-18 IS REPRESENTED BY RUNS 1, 2, AND 3. 3. RUNS 1 AND 2 7kRE DIRECTIONAL ONLY AND DATA IS NOT PRESENTED. 4. RUN 3 IS DIRECTION~LL WITH GAMMA RAY (SGRC), 4-PHASE ELECTROMAGNETIC WAVE RESISTIVITY(EWR4), COMPENSATED NEUTRON POROSITY(CNP/SPSF), AND STABILIZED LITHO-DENSITY(SLD/SBDC). 5. RUN 3 DRILLING STARTED AT 4320' MD (3574' TVD) BUT DEPTH MONITORING AND LOGGING DID NOT START UNTIL 4324' MD(3578' TVD). 6. ALL GAMMA RAY DATA IS ACQUIRED WITH DUAL GAMMA RAY / GEIGER MUELLER TYPE DETECTORS, AND IS DENOTED DGR / SGRC. 7. MPE-18 IS DRILLED TO TOTAL DEPTH (TD) AT 9440' MD(7191' TVD). SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(SHALLOW SPACING) SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY(DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME(RESISTIVITY SENSOR) 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 STAND OFF CORRECTION. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING: HOLE SIZE: 8.5" MUD FILTRATE SALINITY : 800 ppm MUD WEIGHT: 8.6 - 10.2 ppm FORMATION WATER SALINITY: 14545 ppm FLUID DENSITY: 1.0 g/cc MATRIX DENSITY: 2.65 g/cc LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FI LE SUMMARY PBU TOOL CODE STTkRT DEPTH FCNT 4223.5 NCNT 4223.5 NPHI 4223.5 FET 4246.5 RPM 4246.5 RPS 4246.5 RPX 4246.5 RPD 4247.0 GR 4269.5 DRHO 4300.0 RHOB 4300.0 PEF 4304.0 ROP 4321.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 4224.0 4270 4279 4303 4321 4332 4348 4362 4368 4386 4395 4398 4405 4412 4443 4474 4491 4512 4527 4568 4635 4660 4686 4708 4731 4779 4798 4815 4881 4915 4942 4968 4987 5040 5066 5096 5112 5191 5212 .5 .5 .0 .0 .5 .5 .0 .5 .5 .0 .5 .0 .5 .0 .5 .0 .0 .5 .0 .5 .5 .0 .5 .0 .0 .5 .0 .5 .5 .0 0 0 0 0 5 0 5 0 GR 4223.0 4269.5 4281.5 4306.0 4323.5 4332.5 4350.0 4362.5 4370.0 4389.5 4396.0 4399.5 4406.0 4414.0 4445.0 4476.0 4495.5 4513.5 4528 5 4572 0 4636 5 4660 5 4689 5 4712 0 4731 0 4780 0 4799 5 4817 0 4881 5 4915 5 4940 0 4968 0 4987 0 5040 5 5066 5 5097 5 5113 5 5193 0 5212 0 all bit runs merged. STOP DEPTH 9343 5 9343 5 9343 5 9369 5 9369 5 9369 5 9369 5 9369 5 9389 5 9378 0 9378 0 9378 5 9447.5 EQUIVALENT UNSHIFTED DEPTH 5224.5 5295.0 5311.0 5348.0 5366.0 5374.5 5384.5 5408.0 5417.5 5477 5 5502 0 5515 5 5527 0 5547 0 5562 0 5603 0 5612 0 5617 5 5630 5 5641 0 5673.5 5690.5 5706.5 5736 5 5811 5 5820 5 5865 5 5891 5 5971 0 6309 0 6350.5 6842.0 6908.0 7128.5 7410 5 7530 0 7664 5 7672 0 7750 5 7778 5 7804 5 7835 0 7851 0 7900.0 7919.5 7950.0 8139.5 8152.5 8167.0 8224.0 8237.0 8280.0 8287.5 8314.0 8427.0 8441.5 8450.0 8467.5 8492.5 8510.0 8528.0 8537.0 8551.5 8565.5 5224 5 5295 5 5311 0 5348 0 5365 0 5375 5 5385 0 5408 5 5416 0 5477 0 5498 0 5515 0 5527 0 5547 5 5563 0 5601 5 5612 0 5617 5 5629 0 5636 0 5670 0 5689 5 5706 0 5736 0 5809 5 5819 5 5864 5 5892.0 5970.5 6307.0 6349.0 6839.5 6907.0 7126.0 7405.5 7526.0 7658.5 7668.0 7749.5 7772.5 7798.5 7829.5 7846.0 7898.0 7918.0 7944.0 8132.5 8145.5 8158.0 8217.5 8229.5 8273.0 8280.5 8307.0 8420.0 8432 0 8441 5 8460 0 8484 0 8501 5 8521 0 8529 0 8543 5 8558 5 8573 0 8595 0 8615 5 8634 5 8654 0 8671 5 8844 5 8886 5 8895 0 8925 5 8933 0 8952.5 8966 0 8982 0 8994 5 9015 5 9058 0 9088 0 9100 5 9123 5 9130 5 9133 5 9154 0 9158 0 9169 5 9179 0 9215 5 9272 5 9281.0 9300.5 9310.0 9316.5 9448.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: 8566 0 8584 5 8608 0 8626 5 8647 5 8663 5 8835 5 8878 5 8887 5 8919 5 8924 0 8943 0 8957 0 8973 0 8986 0 9007 0 9049 0 9079 0 9091 5 9113.5 9120.0 9125.0 9145.5 9148.0 9159.5 9169 5 9205 5 9266 5 9273 0 9291 5 9303 0 9308 5 9440 0 BIT RUN NO MERGE TOP MERGE BASE 3 4320.0 9940.0 DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Order Units Size Nsam Rep Code Offset Channel 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 MERGED MAIN PASS. $ NPHI MWD NCNT MWD FCNT MWD RHOB MWD DRHO MWD PEF MWD P.U. 4 1 CNTS 4 1 CNTS 4 1 G/CC 4 1 G/CC 4 1 BARN 4 1 68 68 68 68 68 68 32 36 4O 44 48 52 9 10 11 12 13 14 Name DEPT GR ROP RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF Min 4223.5 12 6985 4 7781 0 6394 0 0691 0 4308 0 6391 0 1672 16 4794 2040 402 1.42 -0. 635 1. 811 Max 9447.5 6 276.15 91 1005.16 21 2000 5. 184.985 4 107.994 4. 2000 16 50.0804 1 81. 7622 43 3728 26 1056.6 63 2.9222 2. 0.3097 0.03 11.2598 2. Mean Nsam 835.5 10449 .6211 10241 1.801 10254 35617 10247 .1758 10247 12318 10247 .8833 10246 .5223 10247 .2978 10216 45.18 10241 4.182 10213 30343 10157 48987 10157 46749 10150 First Reading 4223.5 4269.5 4321 4246.5 4246.5 4246.5 4247 4246.5 4223.5 4223.5 4223.5 4300 4300 4304 Last Reading 9447.5 9389.5 9447.5 9369.5 9369.5 9369.5 9369.5 9369.5 9343.5 9343.5 9343.5 9378 9378 9378.5 First Reading For Entire File .......... 4223.5 Last Reading For Entire File ........... 9447.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/18 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 ....... 97/06/18 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: 3 DEPTH INCREMENT: .5000 FILE SUI~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 4223.0 9336.0 NCNT 4223.0 9336.0 NPHI 4223.0 9336.0 FET 4246.0 9362.0 RPM 4246.0 9362.0 RPS 4246.0 9362.0 RPX 4246.0 9362 . 0 RPD 4246.5 9362.0 GR 4269.0 9382.0 DRHO 4303.5 9370.5 RHOB 4303.5 9370.5 PEF 4307.5 9371.0 ROP 4324.0 9440.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (Top TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 CNP SLD $ ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABI. LITHO DENSITY 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: 29-MAR-97 ISC 4.96 CIM 5.46 MEMORY 9940.0 4320.0 9940.0 43.0 51.5 TOOL NUMBER P0687CRDGP6 P0687CRDGP6 P0687CRDGP6 P0687CRDGP6 8.500 8.5 PAC GEL 10.20 56.0 9.8 8O0 4.0 3.200 1.800 2. 600 3.400 64.4 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 3 AAPI 4 1 68 RPX MWD 3 OHMS4 4 1 68 RPS MWD 3 OHMM 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHMS4 4 1 68 NPHI MWD 3 P.U. 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 HOUR 4 1 68 RHOB MWD 3 G/CC 4 1 68 PEF MWD 3 BARN 4 1 68 DRHO MWD 3 G/CC 4 1 68 FCNT MWD 3 CNTS 4 1 68 NCNT MWD 3 CNTS 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 Name DEPT GR RPX RPS RPM RPD NPHI ROP FET RHOB PEF DRHO FCNT NCNT Min 4223 12 6985 0 6394 0 0691 0 4308 0 6391 16 4794 4 7781 0 1672 1.42 1.811 -0.635 402 2040 Max 9440 276.15 2000 184.985 107.994 2000 81.7622 1005.16 50.0804 2.9222 11.2598 0.3097 1056.6 3728 Mean Nsam 6831.5 10435 91.5128 10227 5.37414 10233 4.19274 10233 4.14316 10233 17.7501 10232 43.3138 10198 211.996 10233 1.55504 10233 2.30353 10135 2.46659 10128 0.0349111 10135 633.86 10195 2644.94 10227 First Reading 4223 4269 4246 4246 4246 4246.5 4223 4324 4246 4303.5 4307.5 4303.5 4223 4223 Last Reading 9440 9382 9362 9362 9362 9362 9336 9440 9362 9370.5 9371 9370.5 9336 9336 First Reading For Entire File .......... 4223 Last Reading For Entire File ........... 9440 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/06/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Traile~ Service name ............. LISTPE Date ..................... 97/06/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 97/06/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File Date_O(--o'~- OI * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... . ............................ COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : MPE-18 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22748-00 REFERENCE NO : 97183 LIS Tape Verification Listing Schlumberger A~aska Computing Center 6-MAY-1997 09:13 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 97/05/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/ 6 ORIGIN : FLIC TAPE NAi~E : 97183 CONTINUATION # : 1 PREVIOUS TAPE COM~IENT : B.P. EXPLORATION, MILNE POINT MPE-18, API #50-029-22748-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 97/05/ 6 ORIGIN : FLIC REEL NAME : 97183 CONTINUATION # : PREVIOUS REEL : COF~F=NT : B.P. EXPLORATION, MILNE POINT MPE-18, API #50-029-22748-00