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Home My WebLink About187-029Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ] ~- _~ ~ Well History File Identifier Organization (done) X Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. Other, No/Type TOTAL PAGES: ~ ~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other /s/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanned (done) PAGES: SCANNED %~he time of scanning) REN VINCENT SHERYL MARIA LOWELL /st ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL~ MARIA) LOWELL DATE: /SI General Notes or Comments about this file: PAGES: Quality Checked (done) Rev 1 NOTScanned.wpd - --- __ 1I 7I~~-11 (+~ 1I~~1t 1I~U~ `^ ~/1 1 ,1! ---_.-_ `^.--1n-t-- A- ----- 1` J `` (v. ~Jf ~1.J~.+.~1 \t \~~~~~~~ ~f I ^~r~\`~~~l ~ri~l lull,. r.~,.~{J III ~.f All1.J ~~~~ C~~ ~ l:~ 1_L 1!~ ~~ V rr"'~.' f~ CV • "t ~cs ~.'-~l Siq, ~ {r 0.YJ_ ~~ --~--~__ -- \ / 'h~ rcclucst ,»ay/~~11 c~i' tl~c al~cwc iniorrns~tic-n, l~lcasc contact: ~11:~s1c;~ Oil etc (:sus C'r~~ascrvati~~~~ C~~u~a»issicr~i 1333 ~V. 7(li ~~vc., Stc. I O0 I ~1-~ci~~~ra~;c, Alaska 99S(l l Voicc (9()7) 279-:1433 - I~'ax (~)()7) 27G-7542 STATE OF ALASKA RECEIVED AL .�A OIL AND GAS CONSERVATION COMMISSION 4J REPORT OF SUNDRY WELL OPERATIONS MAR 0 3 2014 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other GCC After Casing r Pull Tubing r7 Stimulate-Frac r Waiver r Time Extension GCC Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J Exploratory r 187-029 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r • 50-029-21710-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25523 , ' 3M-09 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured , 6880 feet Plugs(measured) None true vertical 6630 feet Junk(measured) 6573', 6618' Effective Depth measured . 6780 feet Packer(measured) 6340,6448 true vertical 6529 feet (true vertical) 6093,6200 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3448 9.625 3485 3484' PRODUCTION 6842 7 6869 6619 Perforation depth: Measured depth: 6538-6550,6556-6588,6590-6620AUG 1 4 2014, lz. True Vertical Depth: 6289-6301,6307-6339,6341-6371RBDMS SCANNED MAY 13 2014 Tubing(size,grade,MD,and ND) 2.875, L-80,6415 MD,6167 TVD 2.875,J-55,6408-6479'MD 6231'TVD Packers&SSSV(type,MD,and ND) • PACKER-BAKER FH PACKER @ 6340 MD and 6093 TVD PACKER-CAMCO HRP-1-SP RETRIEVABLE PACKER @ 6448 MD and 6200 TVD NIPPLE-CAMCO LANDING NIPPLE @ 523 MD and 523 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze performed during this workover Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development I✓ " Service r Stratigraphic r 16.Well Status after work: . Oil P. Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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: none Contact Theresa Lee a,263-4837 Email Theresa.M.Lee(a�conocophillips.com Printed NameTheresa Le Title Wells Engineer Signature Vr. Phone:263-4837 Date #[/ S I i Li vt ‘, // / 1 q Form 10-404 Revised 10/2012 4 404 4f Submit Original Only $ KUP PROD 3M-09 ConocoPhillips �'; Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APEUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) y,Mpp, 500292171000 KUPARUK RIVER UNIT PROD 36.94 4,600.00 6,880.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3M-09,2/2520148:52:06 AM SSSV;NIPPLE 145 11/23/2013 Last WO: 1/21/2014 40.00 5/3/1987 Vertical schematic(actual) _. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ...._._......_ .._.__. .._...._. ....._._. Last Tag:SLM 6,564.0 9/28/2013 Rev Reason:WORKOVER,PULL BALLBROD, haggea 2/25/2014 GLV C/O . HANGER;33.0L, .� -)�ti.�� Casing Strings I Casing Description OO lin) ID lin) Top MB) Set Depth(BOB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED I Casing Description 0D lin) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I.. Grade Top Thread SURFACE95/8 8.921 37.0 3,485.1 3,484.1 36.00 J-55 BTC , ' ° Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ""' Y°0'PRODUCTION 7 6.276 27.5 6,869.0 6,618.6 26.00 J-55 BTC ""Tubing Strings Tubing Description `String Ma...I ID(in) I Top(ftKB) I Set Depth(ft..I Set Depth(TVD)(...I Wt(Mt) 'Grade I Top Connection TUBING WO I 27/81 2.441 330 6,414.9 6,166.6 6.501L-80 EUE CONDUCTOR;38.0-115.0 ' Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top!WV) Item Des Com (in) NIPPLE;522.9 33.0 33.0 0.14 HANGER FMC TUBING HANGER 2.441 1 522.9 522.9 0.47 NIPPLE CAMCO DS LANDING NIPPLE 2.312 1 6,310.7 6,063.3 7.92 LOCATOR BAKER LOCATOR 2.370 1 6,311.8 6,064.3 7.91 SEAL ASSY BAKER SEAL ASSY-SPACE OUT 2.370 GAS LIFT;2.631.3 a 6,317.4 6,069.9 7.86 PBR BAKER 80-32 PBR 2.370 6,340.4 6,092.7 7.65 PACKER BAKER FH PACKER 2.430 6,359.6 6,111.7 7.48 NIPPLE HES 2.313""X"NIPPLE 2.313 6,406.7 6,158.4 7.02 OVERSHOT BAKER POOR BOY OVERSHOT-Will swallow 6.90'. 3.300 Will leave 1'space out. SURFACE;37.03,485.1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING-orignial 27/8 2.441 6,4082 6,479.5 6,230.8 6.50 J-55 Completion Details GAS UFT;3,934.2 Nominal ID Top( B) Top(TVD)(ftKB) Top not(") Item Des Com lin) 6,431.7 6,183.2 6.68 SBR CAMCO OEJ-10 SEAL BORE RECEPTICLE 2.313 111 6,448.2 6,199.6 6.45 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.347 6,467.1 6,2185 6.19 NIPPLE CAMCO D NIPPLE 2.250 GAS LIFT;5,023.8III 6,478.8 6,230.1 6.03 SOS CAMCO PE-500 SHEAR OUT SUB,TTL ELMD 6474' 2.441 SWS 5/21/1987 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;5,796.5 . Top(ftKB) (ftKB) Ft Des Com Run Date ID(in) 6,573.0 6,323.8 5.43 FISH Finger f/Wire Recovered both Tool Strings 8 Wire; 8/3/1997 0.000 Finger Left in Hole(8/3/97) I 6,618.0 6,368.6 5.27 FISH F-Stop 8 Element from T.O.Tool Lost in Hole 10/16/1993 0.000 (10/16/93) GAS L'FT 62580 Perforations&Slots 1111 Dens Shot Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Elm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com LOCATOR;6310.7 6,538.0 6,550.0 6,289.0 6,300.9 C-4,3M-09 4/26/1991 ' 6.0 IPERF 2 1/8"EnerJet,0 deg.ph SEAL ASSY;8311.7 PBR;6,317.1. 6,556.0 6,586.0 6,306.9 6,336.8 A-3,A-2,3M- 9/3/1993 ' 12.0 RPERF Big Hole EnerJet, 09 180deg ph PACKER;6,340.4 - 6,586.0 6,588.0 6,336.8 6,338.7 A-2,3M-09 4/26/1991 6.0 IPERF 21/8"EnerJet,0 deg.ph NIPPLE;6,359.6 6,590.0 6,592.0 6,340.7 6,342.7 A-1,3M-09 9/3/1993 6.0 IPERF Big Hole EnerJet, 180deg ph 6,592.0 6,6180 6,342.7 6,368.6 A-1,3M-09 9/3/1993 7.0 IPERF Big Hole EnerJet, 180deg ph 6,618.0 6,620.0 6,368.6 6,370.6 A-1,3M-09 9/3/1993 6.0 IPERF Big Hole EnerJet, OVERSHOT;6,406.7 180deg ph Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Bite(TVD) SBR;6,431.6 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 6,590.0 6,620.0 6,340.7 6,370.6 FRAC 10/17/1987 FRAC A-1 SAND w/GELLED DIESEL,20/40 SAND PACKER;6,448.2 Mandrel Inserts St NIPPLE;6,467.1 ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Seen Type Type lint (psp Run Date Com f 2,631.3 2,630.8 CAMCO KBMG- 1'GAS LIFT DMY BK-5 0.000 0.0 1/31/2014 006:6.478.8 M , 2 3,9342 3,928.8 CAMCO KBMG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/31/2014 M 3 5,023.8 4,861.3 CAMCO KBMG- 1'GAS LIFT DMY BK-5 0.000 0.0 1/31/2014 IPERF;65380-8550.0 I M 4 5,796.5 5,561.8 CAMCO KBMG- 1 GAS LIFT DMY BK-5 0.000 0.0 1/31/2014 M 5 6,258.0 6,011.1 CAMCO KBMG- 1 GAS LIFT OPEN 0.000 0.0 1/31/2014 RPERF;6,556.0-6,586.0 M FISH;6,573.0 Notes:General&Safety End Date Annotation IPERF;6,506.0.6.508.0- 11/22/1993 NOTE:CORKSCREWED TBG from 6384'Down;Use SLINKY 1.5"TOOL STRING 6/20/2000 NOTE:WAIVERED WELL: IA x OA COMMUNICATION IPERF;6,590.06,592.0 11/30/2010 NOTE:View Schematic w/Alaska Schematic9.0-RKB PROD/TBG DIFFERENT RIGS IPERF;6,592.0-6,618.0 r FRAC;6,590.0 1/21/2014 NOTE:WORKOVER FISH;6618.0 IPERF;6,618.0-6,620.0 PRODUCTION;27.5-6,869.0 3M-09 PRE-RIG WELL WORK DATE SUMMARY 5/9/2013 RAN VARIOUS TOOL STRING CONFIGURATIONS IN AN ATTEMPT TO GET SECURE DRIFT WELL BELOW PACKER @ 6448' RKB ( HEAVY/ERRATIC PICKUP WEIGHTS ) ; DRIFT W/ 1.25 SLINKY TOOL STRING W/5' OF 1.5 STEM TAGGED BTM @ 6568' SLM ( EST. 21' OF FILL); UNABLE TO GET DMY CA-2 DRIFT DOWN W/SLINKY TOOL STRING; UNABLE TO DRIFT PAST 6372 &6398'SLM W/ 1.5 STIFF TOOLSTRING W/ 1.75"X 10' BAILER. AWAITING PLAN FORWARD. 6/28/2013 LOG GYRODATA GYRO FROM SURFACE TO BRIDGEOUT DEPTH OF 6418'AND BACK TO SURFACE LOGGING IN CONTINUOUS MODE. PULLING HIGH AND ERATIC TENSION UNTIL 2000'WHILE POOH. WELL LEFT SHUT IN AND TURNED OVER TO DSO. 9/28/2013 PUMPED 270 BBLS SLICK DIESEL, DRIFTED TBG. AND TAGGED FILL @ 6564' SLM WITH 10'x 1.75" BAILER; RAN VARIOUS DRIFTS IN AN ATTEMPT TO GET SECURE DRIFT(NONE WERE ABLE TO PASS 6394' SLM — PACKER IS @ 6448' RKB), HEAVY/ ERRATIC PU WT. IN PROGRESS. 9/29/2013 ATTEMPT TO DRIFT TBG.w/DMY OLGOONIK MAGNA RANGE PERM. PLUG (7'x 1.69"& 3'x 2.19") UNABLE TO PASS 6385' SLM. 10/9/2013 (PRE-RWO): TIFL (PASSED); MIT OA TO 1800 PSI. (PASSED); T POT(PASSED); T PPPOT(PASSED); IC POT(PASSED); IC PPPOT (PASSED); FUNCTION TEST LDS. TUBING GLAND NUTS WOULD NOT FUNCTION, T LDS FUNCTIONED PROPERLY. IC GLAND NUTS AND LDS FUNCTIONED PROPERLY. 10/10/2013 TAGGED @ 6568'SLM W/ 1.5"SOFT SET ON 1.25" SLINKY TOOLSTRING. MEASURED BHP @ 6500' RKB: 2422 PSI. COMPLETE. 10/20/2013 FUNCTION TESTED T PO LDS'S-ALL FUNCTIONED PROPERLY. 12/31/2013 DRIFTED TBG WITH 2.25" CENTRALIZER AND 5'x 1.75" BAILER TO 6375'SLM, 1900# PICK UP WEIGHT. SET F-STOP CATCHER @ 6074'SLM. PULLED GLVs @ 5362', 4572', 3590'AND 2319' RKB. IN PROGRESS. 1/4/2014 DELAYED START DUE TO PHASE CONDITIONS. SET DVs @ 2319', 3590', 4572'& 5362' RKB. BLED IA TO CONFIRM INTEGRITY. PULLED GLV @ 6054' RKB & LEFT POCKET OPEN. PULLED COLLAR STOP @ 6074' RKB. WITH FLAPPER CHECKER DETERMINED TRDP 1A-SSA @ 1792' RKB IS STUCK OPEN. JOB COMPLETE, WELL READY FOR BPV. Time Log & Summary ConocoPhillips WeNNew Web Reporting Report Well Name: 3M-09 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 1/26/2014 1:00:00 PM Rig Release: 2/1/2014 11:59:00 PM Time Logs Date From To Dur< S.Depth E. Depth Phase Code Subcode T Comment 31/21/2014 24 hr Summary Delay in RDMO from1J-120.Waiting on Trucks(Sows). Rig maintenance and cleaning. Lay over Derrick and prepare welds for and then perform Tuboscope inspection. Move smaller support equipment to 3M pad. 00:00 12:00 12.00 0 0 MIRU MOVE RGRP T Waiting on Trucks(Sows)to move the Rig to 3M-Pad. Performing Rig maintenance on 1J-120 Well Slot. Replace Kelly Hose. Wielding in the Pit Module. Clean the A-Leg pins in preparation for particle inspection. Service the Crown Block Sheaves. Inspect the Derrick from the crown to the ground. 12:00 00:00 12.00 0 0 MIRU MOVE RGRP T Prep to lay the Derrick over. Lay Derrick over. Perform Derrick Inspection.Continue with moving misc equipment.Tuboscope inspection completed. NORM and load out old 1J-120 completion. 01/22/2014 Delay in RDMO fromIJ-120.Waiting on Trucks(Sows)and Weather. 00:00 12:00 12.00 0 0 MIRU MOVE RGRP T Loading out smaller egpt loads to pad 3M. Performing Rig Maintenance. Rig down berming for rig and Pits complexes.Wait on Rig move trucks(Sows) 12:00 00:00 12.00 0 0 MIRU MOVE RGRP T Prep to Remove Drilling Line reel from the rig deck. However,the Crane broke down. Wait on mechanic from the Equipment Shop. Crane up and running. Remove empty Drilling Line reel from the rig deck. Install reel with new Drilling Line on the Rig deck. Prep DOwney Camp to move, rig down berming. 31/23/2014 Continue to ready equipment for rig move.Weather condition now phase 3, suspend operations. 00:00 09:00 9.00 0 0 MIRU MOVE RGRP T Prep pits module and sub systems for move.Work on rig maintenance. Load and move smaller loads to 3M pad. Trucks to move Pits, Camp and Shop now expected to be on location at 07:00 hrs. Page 1 of 10 Time Logs Date From . To Dur_. .. S.Death E«Death=Phase Code -Subcode T 'Comment 09:00 12:00 3.00 0 0 MIRU MOVE MOB T Weather has steadily been deteriorating(blowing and drifting snow). The Rig move has been shut down due to weather and a decision by the Kuparuk IMT. Most of the field is in Phase3 and it is expected that the entire are will be Phase 3 soon. All further work has stopped until the Phase 3 has been lifted and the Rig move can be re-evaluated. 12:00 23:15 11.25 0 0 MIRU MOVE MOB T Weather continued Phase3 until late afternoon.Weather moved to phase 2 on main roads and phase 3 on secondary roads and pads. Continued checks with Roads and pads confirms that road to CPF3 is phase 2 but all other roads are in phase 3 shape and roads and pads is having difficulty keeping up with snow drifts on roads. Rig continues to stand by for move. Rig Maintenance on SRL's in Derrick and Cellar. 23:15 00:00 0.75 0 0 MIRU MOVE SFTY T Crew meeting with Company Representative on safety processes and recent injuries in the field. 31/24/2014 Continue to wait on Weather. Weather improved. Now Phase 1. Mobilize Peak Trucks for the move. Move Camp, Truck Shop, and the Pit Module. 00:00 00:45 0.75 0 0 MIRU MOVE SFTY T Crew meeting with Company Representative on safety processes and recent injuries in the field. 00:45 13:30 12.75 0 0 MIRU MOVE MOB T Waiting on weather to clear enough to move rig. Weather restrictions lifted at 13:30 hrs. Notify Peak to mobilize trucks at their Deadhorse Camp and head to 1J-Pad. 13:30 16:00 2.50 0 0 MIRU MOVE MOB T Peck Truck arrive on location. PJSM. Prep to move Rig. 16:00 18:00 2.00 0 0 MIRU MOVE MOB P Remove Parts House and Cuttings Tank. Jack-up Pits and pull away from the Sub. Install Jeep. Move Sub off of Well(note: Pad Operator observed)and stage on Pad. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Move Downey Camp,Truck Shop, and Pit Module from 1J-Pad to 3M-Pad. 01/25/2014 Spot Downey Camp,Truck Shop, and the Pit Module out of way on 3M. begin moving sub. Sub departed 1J at 01:00 and arrives at 3M at 19:00.Work on pad prep for rig to spot over well. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Rig leaving 1J-Pad and move towards 3M-Pad at 01:00 hrs. Set Downey Camp.Truck Shop on 3M-Pad. Stage Pit Module on 3M-Pad. 12:00 19:00 7.00 0 0 MIRU MOVE MOB P Finish moving 7es Sub to 3M-Pad. Page 2 of 10 Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Stage Sub on Pad. Wait on Roads and Pads to finish building up foot print area behind the Well. Lay rig mats. 01/26/2014 Finish Pad prep. Spot sub over well with rig mats and herculite. SPot pits complex with rig mats and herculite. Connect interconnects and electrical lines.Take on 8.6 ppg seawater. Rig up tiger tank with berming, choke house, hardline. Remove BPV with lubricator. RU lines in cellar to kill well. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Lay rig mats and herculite. Spot Sub over well. Spot Pits complex,set mats, herculite. Set cuttings tank. 06:00 08:30 2.50 0 0 MIRU MOVE RURD P Berm around rig. Hook up interconnect lines, hook up electric lines, swao power in pits. 08:30 08:45 0.25 0 0 MIRU MOVE SFTY P PJSM raising Derrick and inspecting derrick. 08:45 09:30 0.75 0 0 MIRU MOVE RURD P Raise and pin derrick. 09:30 12:00 2.50 0 0 MIRU MOVE RURD P Continue berming rig, prep pits for taking on fluid,tighten kelly hose, raise and pin cattle chute. 12:00 16:30 4.50 0 0 MIRU MOVE RURD P Bridle down, pin blocks to top drive, install hydraulic service loop, C/O hydraulic hose on top drive. Begin taking on 8.6 ppg seawater. RIG ACCEPTED @ 13:00. 16:30 20:00 3.50 0 0 MIRU MOVE RURD P Berming and spotting of Tiger tank, spotting of Choke manifold shack. Hardline being rigged up to cellar. 20:00 22:00 2.00 0 0 MIRU MOVE RURD P Continue putting in hardline form cellar to choke shack and connecting to tiger tank. SIMOPS: PU FMC lubricator per FMC rep to pull BPV. 22:00 23:00 1.00 0 0 MIRU WHDBO PULD P Pressure test lubricator to 1800 psi. (GOOD). Pull BPV with lubricator per FMC Rep. LD Lubricator 23:00 00:00 1.00 0 0 MIRU WHDBO RURD P Rig up circulating lines in cellar. 01/27/2014 Take on 8.6 ppg seawater. RU lines in cellar to kill well. Kill well with 8.6 ppg seawater. Circulate 475 bbls, well not dead. Bullhead 20 bbls,well not dead. Circulate 225 bbls, observe well while formation heals,well continues to have pressure. Reverse circulate 43 bbls,well continues to show 25 psi. Decision made to weight up to 9.1 ppg. Load pipeshed with 2 7/8"tubing. 00:00 02:45 2.75 0 0 MIRU WHDBO RURD P Blow down lines, found ice blockage in hard line. Clear ice blockage in line. Check conncetions. Cont RU lines in cellar. 02:45 03:15 0.50 0 0 MIRU WELCTL SFTY P PJSM for killing well with rig crew, and all 3rd party hands. Page 3of10 7 Time Logs Date From To Dur< S.Depth E.Depth Phase Code Subcode 'T Comment 03:15 11:30 8.25 0 0 MIRU WELCTL KLWL P Tbg= 1,450 psi, IA= 1,250 psi, OA = 1,200 psi. Bleed gas to the Tiger Tank. Line up to pump down the Tubing with 8.6 lb/gal Sea Water, taking return from the IA through the choke to the Tiger Tank. Circulate out gas, oil,sludge,and produced water. Finally got decent returns. Continue to clean up Well at 3.0 bpm/480 psi. Total volume pumped =475 bbls. (Hole volume from the open GLM pocket at 6,054-ft=220 bbls). Returns clean(-)8.6 lb/gal Sea Water. Monitor Well. Bleed the OA down to 500 psi and shut in OA. Slight flow for both sides. Close in Choke. Bull head 8.6 lb/gal Sea Water down the tubing to contaminate the sump at 1.0 bpm/220 psi down to the perforations (20 bbls). Crack open the choke and begin circulating the Well again for final clean-up to the Pits. Rate=3.0 blm/505 psi. Holding 80-70 psi back pressure on the Choke. Final rate 3.0 bpm/490 psi, Choke=60 psi,8.6 lb/gal clean Sea Water returns. Total volume circulated 225 bbls. Shut down Pump. Shut in Well. ISIP=80 psi. Lost a total of 55 bbls to the formation since the start of the Well Kill. 11:30 17:00 5.50 0 0 MIRU WELCTL KLWL P Continue to monitor Well. Pressure slowly bleeds off. Pressure at 13:00 hrs 37 psi. Continue to allow formation to heal. Pressure at 16:00 hrs= 12 psi. Discuss results and the possibility of recent injection support from a near-by injection Well with Anchorage Engineer. Open Well to Gas Buster and allow fluid to flow back. Monitor the OA at 500 psi. Observe just a dribble. Discuss again with Anchorage Engineer. Discovered there is injection support. Decision made to reverse circulate a tubing volume plus just to verify no gas on bottom. Reverse circulate at 2.0 bpm/130 psi. Reversed a total of 43 bbls(Tbg vol=35 bbls). No gas observed. Clean 8.6 lb/gal sample weight. Allow well to flow back. Flow slowed but did not quit. Shut in Well to monitor pressure. Initial SIP =26 lbs. Lost 4 bbls to the formation during the reverse out. Page 4 of 10 Time Logs Date °-From To Dur S. Depth E. Depth Phase Code' Subcode T Comment 17:00 19:00 2.00 0 0 MIRU WELCTI KLWL P Continue to monitor Well.While talking to Anchorage engineer. Decision made to weight up to 9.1 ppg(kill weight plus 125 psi margin). 19:00 00:00 5.00 0 0 MIRU WELCTL KLWL Weight up seawater in pits to 9.1 ppg. SIMOPS: Load pipeshed with 2 7/8"tubing, rabbit and strap same. 31/28/2014 Kill well with 9.1 ppg seawater. Circulate 45 bbls down tubing, Bullhead 20 bbls down tubing,circulate 200 bbls.Well dead. Set BPV&blanking plug. Obtain pictures of tre. ND tree. NU BOPE.Test BOPE. Observed upper VBR's failed. Remove Upper VBR's and redress rams with new 2 7/8"x 5"elements. Install same and retest.All tests performed at 250/3000 PSI. Observed 5 nitrogen bottles with an avg of 1880 PSI. Performed Koomey test,with initial 200 PSI increase in 14 seconds, and a full 3000 PSI in 120 seconds.Witness of test waived by AOGCC rep John Crisp. RU to pull tbg. 00:00 02:30 2.50 0 0 MIRU WELCTI KLWL P Circulate 45bbls of 9.1 ppg seawater down tubing taking returns up IA @ 2.5 bpm. Shut in IA and bullhead 20 bbls 9.1 ppg @ 2.5 bpm. Open IA and circulate 200 bbls @ 2.5 bpm until mud system and well have uniform 9.1 ppg. SIMOPS: Cont. load pipeshed with 2-7/8"tubing, rabbit and strap same. 02:30 03:15 0.75 0 0 MIRU WELCTL OWFF P Observe well for flow. (STATIC) SIMOPS: Load pipeshed with completion jewelry. 03:15 04:00 0.75 0 0 MIRU WHDBO RURD P Install BPV per FMC Rep. 04:00 05:00 1.00 0 0 MIRU WHDBO NUND P Nipple down tree. Pictures taken and marks made for orientation. Decomplete control line, plug control line, install blanking plug per FMC rep. 05:00 09:30 4.50 0 0 MIRU WHDBO NUND P Nipple up 13-5/8"BOPE w/Upper and Lower 2-7/8"x 5"VBRs. 09:30 10:00 0.50 0 0 MIRU WHDBO RURD P Pick up test joint and fill BOPE with water. 10:00 17:30 7.50 0 0 MIRU WHDBO BOPE P Test BOPE: Test#1 -Blind Rams, Choke manifold valves 1,2,3, Rig floor kill, Dart valve, outer test spool; Test#2-Manifold valves 4, 5,6, HCR HCR Kill, Upper IBOP, Inner test spool; Test#3-Manifold 7,8, 9, Manual kill, lower IBOP;Test#4- Super choke, manual choke;Test#5 -Manifold 10, 11, 15;Test#6- Manifold 12, 13;Test#7-Lower 2 7/8"x 5"VBR TIW, HCR choke, HCR kill(fail then pass);Test#8- Upper 2 7/8"x 5", manifold 14(Upper VBR failed, retested later);Test#9- Annular;Test#10-Manifold 14;Test #11 -blinds, HCR choke, HCR kill; 17:30 23:00 5.50 0 0 MIRU WHDBO RURD Pull upper 2 7/8"x 5"VBRs. Replace elements with new. Replace upper 2 7/8"x 5"VBRs in BOPE. Page 5 of 10 Time Logs Date From To Dur S. Depth_E.Depth Phase Code Subcode T;' Comment 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P Continue to test BOPE:Test#12 (retest of Upper 2 7/8"x 5"VBRs)- Upper 2 7/8"x 5"VBRs, HCR Kill, HCR Choke. 01/29/2014 BOPE test continued: Observed 5 nitrogen bottles with an avg of 1880 PSI. Performed Koomey test,with initial 200 PSI increase in 14 seconds, and a full 3000 PSI in 120 seconds.Witness of test waived by AOGCC rep John Crisp. RD test eqpt,pull blanking plug and BPV, RU to pull tbg, BOLDS. Pull 2-7/8"tubing completion.Would not pull free with max overpull. Mobilize E-Line. Observed static losses at 26 BPH with 9.1 PPG. OA pressure starting at 500 PSI-Bleed to bleed tank. Bled to 0 PSI. Rig up E-Line. Run#1:2.25"drift to 6467'MD; Run#2: Set WRP at 6451'MD; Run#3: Chase Junk catcher to top of WRPw/2 1/4"Drift; Run #4: String shot at 6409'MD. 00:00 00:30 0.50 0 0 COMPZ RPCOM RURD P BOPE test continued: Observed 5 nitrogen bottles with an avg of 1880 PSI. Performed Koomey test,with initial 200PSI increase in 14 seconds, and a full 3000 PSI in 120 seconds.Witness of test waived by AOGCC rep John Crisp. 00:30 03:00 2.50 0 0 COMPZ RPCOM RURD P Rig down Test eqpt. Pull blanking plug and BPV. Rig up casing tongs. Make up pups for landing joint to unland tubing hanger. Back out lock down screws. 03:00 03:45 0.75 0 0 COMPZ RPCOM PULL P Pull on 2 7/8"with max pull at 110K, repeated attempts to pull tbg free without success. Fill hole, hole took 21 bbls to fill to flow line (approximately 14 bbl fill). HES E-Line mobilized. 03:45 06:30 2.75 0 0 COMPZ RPCOM PULD P Continue to work string to max pull of 110K. Mark landing joint at 95k pull for spacing with 25k in tension for space out with collar above rotary table to crossover to E-Line. Break off top pup joints and set in slips. Make up crossovers to have 4 1/2 IF looking up. 06:30 07:15 0.75 0 0 COMPZ RPCOM PULL P E-Line arrives on site. Meets with Co Rep. Continue working pipe 07:15 10:30 3.25 0 0 COMPZ RPCOM RURD P PJSM. Spot E-Line, Rig up E-Line eqpt. 10:30 12:30 2.00 0 0 COMPZ RPCOM ELNE P RIH with E-Line w/2.25"drift to nipple at 6467'MD. POOH. Rig crew change. 12:30 13:00 0.50 0 0 COMPZ RPCOM PULD P E-Line lays down drift assembly. 13:00 15:30 2.50 0 0 COMPZ RPCOM PULD T Wait on Weatherford Wireline Retrievable Plug, and HES Setting tools. 15:30 16:30 1.00 0 0 COMPZ RPCOM PULD P Pick up and Make up WRP assembly. 16:30 18:45 2.25 0 0 COMPZ RPCOM ELNE P RIH with E-Line w/WRP to 6451'MD, set WRP, set down to ensure set. POOH. E-Line crew change. Page 6 of 10 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 1 18:45 19:30 0.75 0 0 COMPZ RPCOM PRTS P Pressure test to 1000 PSI for 10 minutes. (Charted-GOOD). SIMOPS Pick up junk catcher assembly on top of plug. 19:30 21:15 1.75 0 0 COMPZ RPCOM ELNE P RIH with E-Line to chase junk catcher down to set ontop of WRP @ 6451'MD, set down on Junk catcher to ensure set. POOH. 21:15 21:30 0.25 0 0 COMPZ RPCOM PULD P Lay down chasing assembly. Pick up String shot. 21:30 23:30 2.00 0 0 COMPZ RPCOM ELNE RIH with E-Line w/string shot. Correlated,with joints and string shot @ 6409'MD. POOH. 23:30 00:00 0.50 0 0 COMPZ RPCOM PULD Lay down String shot assembly. 01/30/2014 HES E-Line run#5: Cut tubing @ 6409'MD. Rig Down E-Line. Pull 2 7/8"completion, observe break at 95K. Observe well for flow. Circulate hole celan. Lay down 2 7/8"completion with control line. 00:00 00:15 0.25 0 0 COMPZ RPCOM PULD P Pick Up 1 11/16"Radial Cutting Tool assembly. 00:15 02:00 1.75 0 6,409 COMPZ RPCOM ELNE P RIH with E-Line w/1 11/16"RCT. Correlated,with joints and cut @ 6409'MD. Good indication of cut from HES eqpt, Correlation of tool joints shows slight 6"-12"shift. POOH. 02:00 02:15 0.25 6,409 6,409 COMPZ RPCOM RURD P Rig Down HES E-Line. Lay Down 1 11/16"RTC assembly. Good indication of cut on tool. 02:15 02:30 0.25 6,409 6,405 COMPZ RPCOM PULL P Pull on landing joint, observed break at 95K and then settled at 65K-70K (approxiamte weight of blocks and string). 02:30 03:00 0.50 6,405 6,405 COMPZ RPCOM OWFF P Observe Well for flow.Very slight flow down to STATIC. SIMOPS: Rig down HES E-Line. 03:00 04:30 1.50 6,405 6,405 COMPZ RPCOM CIRC P Circulate 9.3 PPG clean sweep followed by 2 hole volumes of 9.1 PPG seawater @ 5 BPM,990 PSI. 04:30 12:00 7.50 6,405 0 COMPZ RPCOM PULL P POOH, breakout&lay down 2 7/8" tubing(190 joints, 8 GLMs, 1 SSSV) and 1790'control line. Recovered 30 SS Clamps. Crew Change 12:00 13:15 1.25 0 0 COMPZ RPCOM PULL P Continue POOH&Lay down 2 7/8" tubing(4 joints, 1 GLM, and cut joint 15.12') 13:15 13:45 0.50 0 0 COMPZ RPCOM RURD P Clean and clear rig floor. 13:45 19:45 6.00 0 0 COMPZ RPCOM RCST P Decision made to replace the planned 2.25" Nipple beneath the FH Packer with 2.313""X"Nipple due to 2.25 WRP in hole beneath original packer. New nipple and pups mobilized from CAMCO in Deadhorse. Delay lengthened due to transporting truck being blocked by rig move. 19:45 20:00 0.25 0 0 COMPZ RPCOM PULD P Pick up 2.313""X"nipple with pup joints. Page 7 of 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM with all crew and 3rd party representative to run 2 7/8" completion. 20:15 21:00 0.75 0 168 COMPZ RPCOM RCST P Run 27/8"completion. Crew change. 21:00 00:00 3.00 168 2,568 COMPZ RPCOM RCST P Continue to run 2 7/8"completion. Make up Tq on 2 7/8"tbg=2150 Ft/lbs. Observed proper displacement. 01/31/2014 Finish running 2 7/8"completion. Set Packer. Shear out Seal Asembly. Space out and land hanger.Attempt Pressure test on tubing„observe flow from IA and no pressure.Troubleshoot surface equipment. Mobilize slickline. Rig Up slickline. Retrieve Ball and rod. Retrieve SOV from GLM, inspect and verify it was sheared. Set Dummy valve in GLM. Stand back Slickline lubricator and rig up circulation eqpt. Pressure test tubing to 3000 PSI, and IA to 2500 PSI as per well plan. 00:00 01:45 1.75 2,568 4,603 COMPZ RPCOM RCST P Continue to run 2 7/8"completion. Make up Tq on 2 7/8"tbg=2150 Ft/lbs. Observed proper displacement. 01:45 02:30 0.75 4,603 4,603 COMPZ RPCOM RURD T Power Tong dies broken, rig down same. Pick up stand-by tongs and rig up. 02:30 05:00 2.50 4,603 6,409 COMPZ RPCOM RCST P Continue to run 2 7/8"completion to position Poorboy overshot just above the tubing stump at 6409'. 05:00 07:00 2.00 6,409 6,409 COMPZ RPCOM RCST P Locate&run Overshot over top of tubing stub with no clear initial indication of shear screws shearing. Repeat attempts to with max set down weight of 20K, and observed shear screws shear, and proper position of overshot with 6.90'of swallow. Observed 15-20K drag,as the ID of the OS is 3.0",and the 2 7/8"tbg top had swelled to 2.98"OD. After observing free movement in the string, pull OS above tubing stump 3'. UP WT-65K, SO WT-62K 07:00 08:30 1.50 6,409 6,409 COMPZ RPCOM CIRC P Close upper pipe rams and reverse circulate 171 BBLS of 9.1 PPG brine with corrosion inhibitor, chasing it with clean 9.1 PPG to spot inhibitor. Pumps at 3 BPM-580 PSI as per BOT rep. 08:30 09:30 1.00 6,409 6,409 COMPZ RPCOM PRTS P Slack off and locate Poorboy overshot and allow 1'of spaceout. Drop ball&rod,and allow to seat in RHC plug at 6359'. Pressure down tubing to observe packer set at 1400 PSI,continue pressure to 2800 PSI as per BOT rep. Hold pressure 5 minutes. Bleed pressure to 1300 PSI &hold. Pull tbg to 30K over observing seal assembly shear out and free movement. Pull 25'.With pumps at 100 PSI,slack off to observe seal engaged and tag up on locator to verify. Page 8 of 10, Time Logs r Date From To , ; Dur ! x TS.Depth Doth iPhase =Code Subcode T ! Comment 09:30 11:00 1.50 6,409 6,409 COMPZ RPCOM RCST P Pull and lay down 3p-its of tbg. Install space out pup, 10.32', and 1 jnt of tbg. Install pup and hanger. Make up landing joint, and headpin with hose assembly. RIH with pumps at 100 PSI to observe seals engage in PBR,shut down pump,continue to RIH to land tbg hanger. RILDS. 11:00 11:30 0.50 6,409 6,409 COMPZ RPCOM PRTS P Line up and attempt pressure test on tubing. Observed flow on the annulus. Check surface equipment. Lined up good, no issues on surface. 11:30 12:30 1.00 6,409 6,409 COMPZ RPCOM PRTS T Troubleshoot surface equipment line up. Repeat attempts to pressure test, no success. Pump down annulus verifying circulation to the tubing. Max pressure observed 200 PSI. Pump down tubing to a closed annulus, and observed pressure build to 500 PSI, indicating Ball&rod in place and holding, and communication verified form tubing to IA. Discuss options with town engineer, and Slickline supervisor. 12:30 14:30 2.00 6,409 6,409 COMPZ RPCOM SLKL T Call for and mobilize Slickline unit to location. 14:30 18:45 4.25 6,409 6,409 COMPZ RPCOM SLKL T Slickline unit on location. Held PJSM with crew and Slickline crew. Discuss safety and hazard recognitions. Discuss spotting and rigging up. Spot Unit,and pull tools to rig floor. Make up crossovers back to slickline BOP's and Lubricator. Prep tools for run to pull SOV. 18:45 19:45 1.00 6,409 6,409 COMPZ RPCOM SLKL T Slickline run#1: RIH with ball and rod retrieval assembly. Latch on to ball and rod in RHC plug. POOH with ball and rod. Lay down same. 19:45 21:00 1.25 6,409 6,409 COMPZ RPCOM SLKL T Slickline run#2: RIH with valve retrieval assembly. Latch on to SOV in GLM#5. POOH with SOV. Lay down same. Once retrieved visually confirmed SOV was sheared. 21:00 22:30 1.50 6,409 6,409 COMPZ RPCOM SLKL T Slickline run#3: PU and RIH with Dummy valve and setting assembly. Set Dummy valve in GLM#5. Pressure test to 1000 psi.(GOOD). Release off Dummy Valve and POOH. 22:30 00:00 1.50 6,409 6,409 COMPZIRPCOM PRTS Stand back HES lubricator. RU circulation eqpt. Drop ball and rod. Pressure test tubing to 3000 PSI for 15 min, charted(GOOD). Bleed tubing to 1500, pressure test IA to 2500 for 30 min,charted(GOOD). RD circulation eqpt. Page 9 of40 Time Logs Date,. !; From To Dur S, Depth E. Depth Phase- Code Subcode T Comment 02/01/2014 24 hr Summary Rig Down slickline. Set'ISA BPV. Nipple Down BOP, Nipple Up tree. Remove'ISA BPV. Set tree test plug. Pressure test tree.Observed trouble pressure testing tree due to failed tree test plugs. Good tree test. Pull tree test plug. Freeze Protect well. U-tube until dead and install BPV. RDMO. Release Rig @ 23:59. 00:00 01:45 1.75 6,409 6,409 COMPZ RPCOM SLKL T RU HES lubricator. Slickline run#4: RIH with ball and rod retrieval assembly. Latch on to ball and rod in packer. POOH with ball and rod. Lay down same. 01:45 03:15 1.50 6,409 6,409 COMPZ RPCOM SLKL T Slickline run#5: RIH with valve retrieval assembly. Latch on to Dummy in GLM#5. POOH with Dummy Valve, leavcing open pocket for circulation. 03:15 04:00 0.75 6,409 0 COMPZ RPCOM OWFF P Monitor well. (STATIC); SIMOPS: Rig Down slickline eqpt. Pull Landing joint. 04:00 04:30 0.50 0 0 COMPZ WHDBO RURD P Set'ISA BPV per FMC Rep.Test BPV to 1000 PSI from below. (GOOD) 04:30 07:00 2.50 0 0 COMPZ WHDBO NUND P Hold PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to nipple down BOP stack and nipple up tree with proper orientation. ND BOPE. 07:00 10:00 3.00 0 0 COMPZ WHDBO NUND P NU tree. Test packoff 250/5000 PSI for 10 min(GOOD).Turn swab valve 180 degrees as per Drill Site Operator. 10:00 10:30 0.50 0 0 COMPZ WHDBO RURD P Pull BPV. 10:30 11:30 1.00 0 0 COMPZ WHDBO RURD P Install tree test plug,fill tree with diesel. Diesel leaking by plug. 11:30 12:00 0.50 0 0 COMPZ WHDBO RURD T Pull tree test plug and redress. 12:00 13:00 1.00 0 0 COMPZ WHDBO RURD T Continue redress and set tree test plug. 13:00 16:00 3.00 0 0 COMPZ WHDBO PRTS T Attempt to test tree. Not good test. Troubleshoot.Tree test plug not seating verified by fluid from IA. Tighten flanges on tree. 16:00 16:30 0.50 0 0 COMPZ WHDBO RURD T Prepare cellar for change out of Tree test plug. 16:30 18:30 2.00 0 0 COMPZ WHDBO PRTS T Pressure test tree to 250/5000 PSI. (GOOD)on chart. 18:30 19:00 0.50 0 0 COMPZ WHDBO RURD P Pull tree test plug. PJSM, Rig Up Little Red Services to circulate freeze protect. 19:00 21:30 2.50 0 0 COMPZ WHDBO FRZP P Freeze protect well by pumping 70 bbls of diesel down IA taking returns out tubing. SIMOPS: Blow down rig and empty cuttings tank. 21:30 22:30 1.00 0 0 COMPZ WHDBO FRZP P Rig up eqpt to U-Tube well.Allow well to U-Tube diesel to tubing from IA, until dead. 22:30 23:00 0.50 0 0 COMPZ WHDBO RURD P Rig down Circulating eqpt. Install 'ISA'BPV. 23:00 00:00 1.00 0 0 COMPZ MOVE RURD P Secure tree. Final pressures:tubing =0 PSI; IA=0 PSI; OA=75 PSI. Page 10 of 10 3M-09 (PTD 1870290) Report~Failed TIFL . Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, January 16, 2009 12:58 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 3M-09 (PTD 1870290) Report of Failed TIFL Attachments: 3M-09. Schematic pdf.pdf; 3M-09 90 day TIO plot..jpg Tom and Jim ~~~ I Kuparuk gas lifted producer 3M-09 (PTD 1870290) failed a diagnostic TIFL on 01/15/09 and has been added to the weekly SCP report. The TIO prior to the test was 150/1250/1120. Baking GLV is suspected. Slickline will troubleshoot the gaslift valves and repair if possible. Attached is a schematic and 90 day TIO plot. «3M-09. Schematic pdf.pdf» «3M-09 90 day TIO plot..jpg» Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/23/2009 KRU 3M-09 PTD 1870290 1 / 16/2009 TIO Pressures • • KRU 3M-09 CarracoPhilli~s Alaska, inc. 3M-09 _ _ API: 500292171000 Well T e: PROD r An le a) TS: 6 d a) 6535 ' SSSV Type: TRDP Orig 5/3/1987 Angle @ TD: 5 deg @ 6880 sssv -.-j Com lesion: (nag-na3' OD:2.B75) J - Annular Fluid: Last W/O: Rev Reason: TTL ELMD Reference Lo Ref Lo Date: Last U date: 3/30/2008 Last Ta :6594' SLM TD: 6880 ftK6 Gas Lin ~,~ ~.. ( Last Tag Date: 12/6/2007 _ Max Hole Angle: 37 deg~a 4600 __ _ _____ ------ MandrelNalve ~~`! Casing Strip-ALL STRINGS 1 _ _ _ Descri lion ~Size~ To Bottom ~ T'VD Wt Grade Thread (z31s-z3zo, CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 3485 3484 36.00 J-55 PROD. CASING 7.000____ 0 686.9__ 6619 26.00 J-55 _ ' ~ Tubing Siring- TUBING Size To Bottom ND Wt Grade Thread 2.875 0 6479 6230 6.50 J-55 T EUE HRD AB_M_OD Gas un .Perforations Summa ~_ -~ MandrelNalve Comment Interval TVD Zone Status Ft SPF Date T e 3 ! ` 6538 - 6550 6289 - 6301 C-4 12 6 4/26/1991 IPERF 2 1/8" EnerJet 0 de h (a176~17s, ~ 6556 - 6586 6307 - 6337 A-3,A-2 30 12 9/3/1993 RPERF Big Hole EnerJet, 180deg h ~~y 6586 - 6588 6337 - 6339 A-2 2 6 4/26/1991 IPERF 2 1/8" EnerJet 0 de h 6590 - 6592 6341 - 6343 A-1 2 6 9/3/1993 IPERF Big Hole EnerJet, 180deg h 6592 - 6618 6343 - 6369 A-1 26 7 9/3/1993 IPERF Big Hole EnerJet, 180deg h ' 6618 - 6620 6369 - 6371 A-1 2 6 9/3/1993 IPERF Big Hole EnerJet, 180deg ~~ -- -- -- - Gas Lift MandrelsNalves _ __ _ __ _ _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Gas Lift Cmnt MandrelNalve ~". 2 1 2319 2319 CMurra FMHO GLV 1.0 BK-2 1.800 1306 6/1/2005 s (53625363, Z 3590 3589 cMurra FMHO DMY 1.0 BK-2 0.000 0 7/11/1987 3 4178 4156 cMurra FMHO GLV 1.0 BK-2 0.156 1338 6/4/2005 4 4572 4486 cMurra FMHO DMY 1.0 BK-2 0.000 0 7/11/1987 5 4967 4813 cMurra FMHO DMY 1.0 BK-2 0.000 0 7/11/1987 6 5362 5158 cMurra FMHO GLV 1.0 BK-2 0.188 1364 6/1/2005 7 5723 5492 cMurra FMHO DMY 1.0 BK-2 0.000 0 7/23/1997 8 6054 5811 cMurra FMHO GLV 1.0 BK-2 0.188 1351 6/1/2005 Gas Lift ' . 9 6384 6136 Otis LB OV 1.5 T-2 0.188 0 6/1/2005 --- MandrelNalve $ , ~ ~ - - - _ - - _ - - - Other. plu s e ui etc. _-_JEWELRY _ _ (605a-6055, De th ND T e Descri lion ID 1742 1742 SSSV Camco'TRDP-IA-SSA' 2.312 GasLlft 6432 6184 SBR Camco'OEJ' 2.313 MandrelNalve ~- 6448 6199 PKR Camco'HRP-I-SP' 2.347 s _ 6467 6218 NIP Camco'D' Ni le NO GO 2.250 (s3aa~365, 6479 6230 SOS Camco'PE-500' 2.441 6479 6230 TTL TTL ELMD 6474' SWS 5/21/1987 2.441 ----. _ __._. - -- SBR - -. - _.._-._ - . FISh -FISH (64325433, OD:2.875) - --- -- --- - - - De th Descri tlon Comment 6573 Fin er f/ Wire Recovered both Tool Strin s & Wire; Fin er Left in Hole 8/3/97 6618 F-Stop & Element from T.O. Tool Lost in Hole X10/16/93) _ __ PKR _ Genera] Notes ___ __ (saaa5aas, ~~ __ Date rNote oD:s.151) 1/22/199 NOTE: CORKSCREWED TBG from 6384' Down; Use SLINKY 1.5" TOOL STRING 6/20/2000 NOTE: WAIVERED WELL: IA x OA COMMUNICATION NIP (64675468, OD:2.675) TUBING (0-6479, OD:2.675, ID:2.441) ~ I ~ Perf (6538-6550) Part - _ (6556F586) _ ----- Fingerf/Wire _ - __.- (6573-6574, OD:1.000) Perf --....- - / -~ l~ = ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ Well Job # oaim~~ A~ ~ .! ~ ~DflB Log Description NO.4792 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/24/08 1 A-O6 12080402 INJECTION PROFILE ~ - ( 07/06/08 1 1 3C-17 11964626 SFRT p$- 07/12/08 1 1 1Y-04 12096505 INJECTION PROFILE - - b 07!13/08 1 1 1G-O6 12061729 INJECTION PROFILE a ~ 07/13/08 1 1 1 F-06 12096506 PRODUCTION PROFILE - ~ 07!14/08 1 1 3M-08 12096516 SBHP SURVEY 07/21/08 1 1 3M-09 12098515 SBHP SURVEY (o (p 07/21/08 1 1 3N-13 12096517 SBHP SURVEY C (o - 07/22/08 1 1 2W-01 12096508 PRODUCTION PROFILE ~ ~- 07/16/08 1 1 1F-O6 12096510 PRODUCTION PROFILE -/C( 07/17/08 1 1 2A-02 12096511 INJECTION PROFILE ~ 07/18/08 1 1 3J-17 12096514 SBHP SURVEY ' g !~~ ~- ~ ` 07!20/08 1 1 3J-07A 12097409 ®~~ ~(0 SBHP SURVEY Ol~~' L~`~j 07/20/08 1 1 3C-15A 12097406 _ . USIT / •~ 07/17/08 1 1 2A-05 12096512 SCMT ~(- 07/19/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 581-8317. Thank you. (;h ') ) (~7.. OS'?' {~'7-oZ'7 / ?!&-{~to ¡<¡fer .. o'-f ( (~rl - {(2. Page 1 of 2 Conoc~hillips Transnlittal #383 Detail Date: 9/29/2004 I' Fron1 (I' AI Contact): Email: Sandra.D.Lemke@conocophillips.com First Sandra Name: N Last Lemke ame: Phone 265-6947 Number: Company: ConocoPhillips Alaska Address: 700 G Street, ATO 1486 City: Anchorage Statc: Ak Zip Code: 99510 SCANNED JAN 062005 To (Externall'arty): Email: Howard_Okland@admin.state.ak.us First Namc: Howard Last Name: Oakland Phone Number: Company: Address: City: I State: Zip Code: Sent Via: hand delivery Translnittal Info: Tracking it: Justification: per 9/26/2004 request from Helen Warman, AOGCC Librarian Quantity 1 1 1 1 1 1 ' Data Detail: Description Core Analysis report-KRU 30-12; Core Labs CL BP-3-1281; 8/9/1988 Core Analysis KRU 3M-09; 7/21/1987; Core Labs Core Analysis Report; KRU 3H-09; 2/22/1988; Core Labs Core Analysis Report; KRU 3K-09; Core Labs; 1/19/1987 Core Analysis Report; KRU 3M-16; Core Labs 8/19/1987 Type paper / paper ./ paper / paper j paper / paper / Core Analysis Report- KRU 2T-09; Core Labs; 9/30/1988 http://www.ak.ppeo.comltransmi ttal/pri nLasp ?transno=383 9/29/2004 ) Attachments: Filename: None Received By~/: h j J /' sign~4~. ./tIM~ Approver: Signature: http://www .ak. ppco.eom/transm i ttaJ/pri n t. as p ?transno=3 83 Filesize: NI A ). Date: ¥~ cf Date: Page 2 of2 9/?,9I?OO4 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a short list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on August 24, 2003. Dowell-Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender for each well. The cement was pumped from the bottom of the void to the top of the conductor on each well via high pressure hose. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call Nina Woods or me at 907-659-7224, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Problem Well Supervisor Attachment [', :', ¢! SCANNED,' SEP 0 8 21103 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field WELLS PTD# TOC VOLUME TYPE SACKS ft BBLS Cement 1H-01 1930060 18.0 3.74 Prod 22.6 1 H-21 1930460 21.0 3.66 Prod 22.1 2K-08 1890830 6.0 1.8 Prod 10.9 4~ 3M-09 1870290 46.0 8.32 Prod 50.2 3M-10 1870350 52.0 10.1 Inj 61.0 3Q-03 1911260 14.5 3.44 Prod 20.8 OIL AND GAS CONSERVATION COMMI 'Y REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate . .X Pull tubing ~ Alter casing Repair well~ 2. Name of Operator 5. Type of Well: Development X . ARCO Alaska, Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1112' FNL, 1665' FEL, SEC.25, T13N, R8E, UM At-top of productive interval. 2023' FNL, 1158' FEL, SEC.25', T13N, R8E, UM At effective depth 2045' FNL, 1'156' FEL, SEC.25, T13N, R8E, UM At total depth 2054' FNL, 1155' FEL, SEC.25, T13N, R8E, UM 12. Present well condition summary Total DePth: measured 6 8 8 0' fe et true vertical 6 6 2 9' feet Plugs (measured) Plugging ' Perforate Other __ 6. Datum elevation (DF or KB) RKB {~4 i'7. Unit or Property name Kuparuk River Unit feet 8. Well number 3M-09 9. Permit number/approval number 87-29 10. APl number 50-02!~-2171000 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 6 78 0' feet Junk (measured) true vertiCal 6529' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' I 6" 198 SX CS II 115' 115' Surface 3448' 9-5/8" 1300 SX AS III & 3485' 3484' Intermediate 335 SX CLASS G Production 6869' 7" 300 SX CLASS G &6869' 661 8' Liner 175 SX AS I Perforation depth: measured 0~1 ~1 ~IAL 6538'-6550', 6556'-6588', 6592'-6618' , ~....~ r: true vertical 6289'-6301, 6307'-6339', 6343'-6369' 1031# IN WELLBORE. Tubing (size, grade, and measured depth) 2-7/8" 6.5# J-55 ABM@ 6479' Packers and SSSV (type and measured depth) PKRS: Camco HRP-1-SP @ 6448', SSSV: Camco TRDP-1A-SSA @ 1792' 13. Stimulation or cement squeeze summary A Sand REFRAC, 7/26/97 Intervals treated (measured) 6556'-6588', 6592'-6618' Treatment description including volumes used and final pressure PUMPED "A" SANDS REFRACWlTH 259,094#, PUMPED 258633# TO 13PPA 12/18 TO PERFS, LEAVING PUMPED 17,722# 20/40 AND 241~372#rOF 12/18. 14. Representative Daily Avera,qe Production or Inlection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation REEEIVED Gas Cons. 486 348 10 1109 153 1091 1078 82 1393 147 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I her,~rtify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Petroleum Engineer Form~~4 JR~',FO'~/~O- - '- SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT ~' K1(3M-09(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-09 FRAC, FRAC SUPPORT 0720971654.3 DATE DAILY WORK UNIT NUMBER 07'/26/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY'Ia, ERSON SUPERVISOR 3 (~) Yes O NoI ® Yes O No DS-GALLEGOS JOHNS FIELD AFC,~ ~ DAILY COST ACCUM COST ' ' ' ' Initial Tb.cl Press Final Tb.(i Press Initial Inner Ann Final Inner Ann I Initial Ou 0 PSI 1800 PSI 500 PSI 1000 PSII DAILY SUMMARY PUMPED 'A' SANDS REFRAC, WITH 259,094# PUMPED, 258,633# TO 13PPA 12/18 TO PERFS, LEAVING 1031# IN WELLBORE. I I PUMPED 17,722# 20/40 AND 241,372# OF 12/18. TIME LOG ENTRY 07:00 09:00 09:57 10:05 10:10 MIRU DOWELL EQUIP, HOT OIL PUMP AND APc V,AC TRUCK. HELD ON SITE SAFETY MEETING PRESSURE TEST SURFACE LINE TO 9750 PSI. INITIAL WHP 0 PSI, START PUMPING BREAKDOWN, 25 BPM AND 5230 PSI. PUMP 1 PPA, 20/40 PROPPANT SLURRY FOR SCOUR STAGE. 50 # XL-GEL. 10:12 PUMP 50 BBL FLUSH, 15 BPM AND 4280 PSI. 10:15 PUMP 2 PPA, 20/40 PROPPANT SLURRY FOR SCOUR STAGE. 50 # GEL. 10:16 PUMP 10 GEL FLUSH AND 71 BBLS STRAIGHT SEAWATER FLUSH, 15 BPM AND 4200 PSI. 10:23 SHUT DOWN ISIP 1606 PSI AND PUMP POLSES. 11:01 PUMP DATA' FRAC & DISPLACMENT, 5 TO 15 BPMAND 3523 PSI AND SHUT DOWN ISIP 1523 PSI. 12:12 PUMP 405 BBLS PAD, 15 BPM AND 4450 PSI. 12:59 PUMP 2 PPA 20/40 STAGE 15 BPM AND 4160. 13:09 RAMP FROM 2PPA TO 6 PPA W/12/18 PRopPANT SLURRY, 15 BPM AND 4145 PSI. 13:30 RAMPING TO 10 PPA W/12/18 PROPPANT ,15 BPM AND 4183 PSI. 13:44 PUMP 10 PPA 12/18 FLAT STAGE FOR 380 BBLS, 15 BPM AND 4150 PSI. 14:10 RAMP TO 11.5 PPA, 15 BPM AND 4000 PSI. 14:13 RAMP TO 13 PPA, FINAL ENDPOINT. 14:16 PUMP FLUSH OF 53 BBLS, 15 TO 10 TO 7 BPM. SHUT DOWN. 14:18 PUMPED 259, 094 TOTAL PROPPANT , 258, 033 # TO 13 PPA 12/18 BEHIND PIPE. LEFT 1031# IN WELLBORE. RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $730.00 , APC $7,000.00 $7,000.00 DOWELL $102,991.00 $102,991.00 , HALLIBURTON $0.00 $7,266.00 LITTLE RED $2,000.00 $6,770.00 TOTAL FIELD ESTIMATE $11 1,991.00 $124,757.00 £mco Alaska, Inc. Post Office,B&.'~ ~,'00360 - Anchorage,-Alaska 99510-0360 Telephone 907 276 1215 November 10, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ~5-:zz~, 3F-02 Stimulate ~7--2-'~ ~ 3M-09 Stimulate '3M-09 Perforate E,~-?:Z 3N-10 Stimulate ~,~,-q t 3N-16 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED ~10V 1 5 1993 ~,ska, Oi~ & ~as Cons. ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ~A~- ~ OIL AND ~ ~ERVA~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate ~ Plugging , ,, Perforate Pull tubing , Alter casing Repair well ..__ 2. Name of Operator ARCO Alaska. Inc. . 3. Address P. O. Box 100360 e, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _. Stratigraphic _ Sewice 1112' FNL, 1665' FEL, SEC.25, T13N, R8E, UM At top of productive interval 2023' FNL, 1158' FEL, SEC.25', T13N, R8E, UM At effective depth 2045' FNL, 1156' FEL, SEC.25, T13N, R8E, UM At total depth 2054' FNL 1155' FEL SEC.25 IM 12. Present well condition summary Total Depth: measured 6880' feet true vertical 6 6 2 9' feet Plugs (measured) Other _. 6. Datum elevation (DF or KB) RKB 64 ..feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-09 . 9. Permit number/approval number 87-2~t 10. APl number 50-029-2171000 11. Field/Pool Kuparuk River Field K,uparuk RiVer Oil Pool Effective depth: measured true vertical 6780' feet Junk (measured) 6529' feet Casing Length Structural Conductor 80' Surface 3 4 4 8' Intermediate Production ' 6 8 6 9' Liner Perforation depth: measured 6538'-6550', true vertical 6289'-6301, Size Cemented Measured depth True vertical depth 1 6" 198 SX CS II 115' 115' 9-5/8" 1300 SX AS III & 3485' 3484' 335 SX CLASS G 7" .. 300 SX CLASS G & 6 8 6 9' 6 61 8' 175 SX AS I 6556'-6588', 6307'-6339', 6592'-6618' 6343'-6369' Tubing (size, grade, and measured depth) 2-7/8" 6.5# J-55 ABM@ 6479' Packers and SSSV (type and measured depth) PKRS: Camco HRP-1-SP ~ 6448', sssv: Camco TRDP-1ATSSA @ 1792' 13...Stimulation or cement squeeze summary A Sand Data Frac Intervals treated (measured) 6556'-6588', 6592'-6618' Treatment description including volumes used and final pressure 14. RECEIVED Alaska 0il & ass Con& C0mmission Anr, l~rage Pumped 162 Mlbs @ perfs. Total Fluids: Water 1212 bbls~ Diesel 28 bbls~ Additiyes 13 bbls. (See WSR) Re.oresentative Daily Average Production or Irl~eetiorl Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 15. Attachments Copies of Logs and Surveys' run Daily Report of Well Operations X 486 348 10 1091. ~'"' 1078 82 16. Status of well classification as: Water Injector g Oil ~ , C.-.-.-.-.-.-.-.-.~s Suspended ,,, 1109 153 1393 147 Service 17. I here~/ that the fo~going is true and correct to the best of my knowledge. (~~~i ,'~ Title Sr. Petroleum En.(:lineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE A~CO Alaska, Inc/"~ Subsidiary of Atlantic Richfield Company '. ~ WELL CON¥~ACTOR REMARKS c,~. WELL SERVICE REPORT IDAY$ I DATE / l)3OD - I(~.D . ~D ' I I 3 ~&ls ~ t~l~ fl, [-] CHECK'THIS BLOCK IF suMMARY CONTINUED ON BACK J Sign~ ~,, knot,[ REMARKS CONTINUED: ,, DESCRIPTION DAILY ACCU M. TOTAL CAMCO . OTIS DOWELL .............. HALLIBURTON .~.~ ~,~,.~'- ' ARCTIC COIL TUBING 'FRACMASTER " B. J. HUGHES Roustabouts Diesel Methanol , , Supe~ision Pr~Job Safety Meeting AFE _ .=,, TOTAL FIELD ESTIMATE ST^TEOFALASK AI~oKA OIL AND GAS CONSERVATION C(:~MI~. REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns Performed: Operation Shutdown Stimulate Pull tubing Alter casing , Repair well , 2. Name of Operator 15. Type ~f Well: · Development X ARCO Alaska. Inc. Exploratory ._ 3. Address I Stratigraphic _ P. O. Box 100360, Anchora~le, AK 99510I Service , ._ 4. Location of well at surface 1112' FNL, 1665' FEL, SEC.25, T13N, R8E, UM At top of productive interval 2023' FNL, 1158' FEL, SEC.25', T13N, R8E, UM At effective depth 2045' FNL, 1156' FEL, SEC.25, T13N, R8E, UM At total depth 2054' FNL, 1155' .FEL, SEC.25,. T13N, R8E, UM . , 12. Present well condition summary Total Depth: measured 6 8 8 0' feet Plugs (measured) true vertical 6 629' feet Plugging ....... · Perforate X '// '~ "- 6. Datum elevation (DF or KB) ' '(I RKB 64 feet 7. Unit or Property name KuParuk River Unit 8. Well number 3M-09 9. Permit number/approval number 87-29 10. APl number , 50-029-2171000 11. Field/Pool Kuparuk River Field KU ,l~ruk River Oil P001 Effective depth: measured 6 780' feet Junk (measured) true vertical 6 5 2 9' feet 13. 14. Casing Length Size Cemented Structural Conductor 80' 1 6" 198 SX CS II surface 3448' 9-5/8" 1300 SX AS III & Intermediate 335 SX CLASS G Production 6 8 6 9' 7" 300 SX CLASS G & Liner 175 SX AS I Perforation depth: measured 6538'-6550', 6556'-6588', 6592'-6618' true vertical 6289'-6301, 6307'-6339', 6343'-6369' Tubing (size, grade, and measured depth) 2-7/8" 6.5# J-55 ABM@ 6479' Measured depth True vertical depth 115' 115' 3485' 3484' 6869' 6618' tlOV 1 5 1992, Packers and SSSV (type and measured depth) & PKRS: Camco HRP-I-SP @ 6448', SSSV: Camco TRDP-1A-SS/[, @ 179;3~3sk1~0[[ Stimulat~n or ~ment squeeze summary REPERFO~TE A3, ~, AND A1 ~NDS Intewals treated (me~ured) 6556'-6586' AND 6590'-6620' Treatment des~ip~on including volum~ u~d ~d fi~l pm~um REPERF A SANDS WI6 SPF, 180 deg. PHASING, ORIE~ED 90 d~. CCW FOR LOW SIDE. Reor{~sen~tive Di~ilv Average Prodvction or Inlection Data OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation , ~ 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X .. Gas , ,Suspended 17. I hereby ,e~tify that the ,foregoing is true and correct to the best of my knowledge. Signed "~{~~ {~' ~'~----~'~ Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 Service SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL I PBDT / $~-0~ I' 3NTRACTOR .~kh....ker3¢r - 3'ok.~o.,, # 3+41 WELL SERVICE REPORT tFIELD - DISTRICT-STATE ,l~,,,,~,~k g;,,-' Fi<l( OPEI~AT4ON..AT REPORT TIME I D~YS I DATE I ~1~1~ cc.' 2.~. D53(, mb 5c,. ~: gOZ23 , o1'~5 CHECK THis-BLOCK Iy SUMMARY CONTINUED ON BACK RWeel~e r J Temp. OF j Chill F%tOr, F J Vi.lbllity mile~ J Wind Vel. Anch.mne J$1gned ,.o,.I c.o. REMARKS CONTINUED: DESCRIPTION DAILY ACOU M. TOTAL c .co OTIS SCHLUMBERGER ARCTIC COlL TUBING FRACMASTER Rousta~uts Diesel Methanol · , Supe~ision Pr~Job Safety Meeting AFE TOTAL FIELD ESTIMATE 423/ 550 Sign~ ~ STATE OF ALASKA '/~' ~'~ ' ~ OIL AND GAS OONSERVATION OOMMI~C~ REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: pull tubing 2. Name of Operator Operation Shutdown Stimulate __ Plugging Perforate X ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. LoCation of well at surface 1112' FNL, 1665' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 2023' FNL, 1158' FEL, Sec. 25, T13N, R8E, UM At effective depth 2045' FNL, 1156' FEL, Sec. 25, T13N, R8E, UM At total depth 2054' FNL, 1155' FELt .Sec. 25, T13N, R8E~ UM 12. Present well condition summary Total Depth: measured 6 8 8 0' feet true vertical 6629' feet Alter casing .. Repair well '5' Type "of Well: Development X Exploratory _. Stratigraphic _ 99510 Service _ Other 6. Datum elevation (DF or KB)'- 64' RKB feet 7, Unit or Property name Kuparuk River Unit '8. Well nui~her 3M-09 9. Permit number/approval number 87-29 1'0, APl number so-029-21710 11. Field/Pcol Kuparuk River Field/ Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 6 7 8 0' true vertical 6529' Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3448' 9-5/8" 6869' 7" measured 6538'-6550', true vertical 6289'-6301', feet Junk (measured) None feet Cemented Measured depth 198 sx CS II 1 1 5' 1300 sx AS III & 3485' 335 sx Class G 300 sx Class G & 175 sx AS I 6592'-661 8' 6343'-6369' 6556'-6588', 6307'-6339', Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w tail @ 6479' Packers and SSSV (type and measured depth) HRP;1-SP pkr ~. 6448, & TRDp-I^-SSA. SSSV ~ 1792' 13. Stimulation or cement squeeze summary See attached well report True vertical depth 115' 3484' 6869' 6618' RECEIVED Intervals treated (measured) See attached well report Treatment description including volumes used and final pressure See attached well report 14, Reoresentative Daily Averaoe Production or 'lniecti°n Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure UL 2 6 tgg! a [~as Cons. Commission Anchorage Tubing Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 4 3 6 220 -0- 4 5 7 ~ 237 -0- 16. Status of well classification as: Water Injector Oil X Gas Suspended 17. I hereby certifY that the f~)regoing is true and correct to the best of m'y 'knoWledge. Si~ne,d , ~~ ~~)~ ~''~~ Tit~e Senior Operations Engineer Form 10-404 Rev 09/12/90 1250 150 1250 148 Service SUBMIT IN DUPLICATE . ARCO Alaska, Inc. ~ ; Sul~ldlary of Atlantic Richfield Com~ WELL~ BDT .EMARKS I FIELD. DISYHICT. STATE ' '-~ KuP,,~U K. KZ',d a.L IOPERATION AT REPORT TIME WELL SERVICE REPOI~ DAYS I DATE IkZo T:'"ft-I=oE.~ (,,,'~'S4,,' "r'o L.S: ,, JUL z Alaska Oil & Gas Cons. (;omm~ss'~on I-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. [ ! Post Office BOX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 CONFIDENTIAL XPc_. August 8, 1988 Mr. C. V. Chatterton Commi ss i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3M-9 Core Description Dear Mr. Chatterton: Enclosed is a copy of the 3M-9 Core Description to include with the Well Completion Report. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:hf Enclosures cc' 3M-9 Well File GRU14/O20a ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Gas C0~S. commission Anchorage ARCO ALASKA, INC. K~~- 3M-9 SIDE WALL CORE DESCRIPTIONS FOR SEC. 25, THE STATE T13N, R£.~.~U OF ALASKA .M. DEPTH(MD) DESCRIPTION 2566.9 SAND, POROUS, OIL 2567.6 SAND, POROUS, OIL 2568.1 SAND, POROUS, OIL 2568.4 SAND, POROUS, OIL 2676.9 SAND, POROUS, OIL 2677.9 SAND, POROUS, OIL 2679.9 SAND, POROUS, OIL 2683.1 SAND, POROUS, OIL 2684.2 SAND, POROUS, OIL 2919.4 SAND, POROUS, OIL 2920.0 SAND, POROUS, OIL 2920.7 SAND, 2925.0 SAND, 2925.5 SAND, 2926.1 SAND, 3073.0 SAND, 3074.0 SAND, 3075.0 SILT, 3117.0 SAND, 3117.5 SHALE, 3117.9 SHALE, 3135.9 SHALE, 3136.9 SAND, 3137.9 SAND, 3216.0 SILT, 3217.1 SILT, 3218.0 SILT, 3223.9 MISFIRE 3224.2 MISFIRE 3224.4 MISFIRE 3224.6 MISFIRE 3224.8 MISFIRE 3225.0 MISFIRE 3225.1 SILT, SOME POROSITY, 3225.2 MISFIRE 3224.2 MISFIRE 3225.5 SHALE, SILTY, NO 3226.0 SHALE, SILTY, NO 3259.5 SAND, POROUS, OIL 3259.9 SAND, POROUS, OIL 3260.0 MISFIRE 3261.0 SAND, POROUS, OIL 3268.5 SAND, POROUS, OIL 3269.1 SAND, POROUS, OIL 3269.5 SAND, POROUS, OIL 3279.0 SAND, POROUS, OIL 3280.9 SAND, POROUS, OIL 3281.0 MISFIRE STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN CONFIDENTIAL ARGILLACEOUS, POROUS, SOME OIL STAIN POROUS, OIL STAIN SILTY, POROUS, NO OIL STAIN POROUS, OIL STAIN SILTY, SOME POROSITY, NO OIL STAIN ' SILTY, SOME POROSITY, NO OIL STAIN ARGILLACEOUS, LITTLE POROSITY, NO OIL STAIN POROUS, OIL STAIN SILTY, NO OIL STAIN SILTY, SOME SILTY SAND, LITTLE POROSITY, SILTY, NO OIL STAIN CEMENTED, LITTLE POROSITY, NO OIL STAIN SILTY, CEMENTED, LITTLE POROSITY, NO OIL SHALE, CEMENTED, NO OIL STAIN SILTY CLAY, CEMENTED, LITTLE POROSITY, NO CEMENTED, LITTLE POROSITY, NO OIL STAIN NO OIL STAIN OIL NO OIL STAIN OIL STAIN OIL STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN STAIN 3281.8 3321.9 3323.1 3324.0 3460.0 3460.5 3461.0 SAND, SAND, SAND, SAND, SAND, SAND, SAND, POROUS, POROUS, SILTY, SILTY, POROUS, POROUS, POROUS, OIL STAIN OIL STAIN SOME POROSITY, SOME POROSITY, OIL STAIN OIL STAIN OIL STAIN OIL STAIN OIL STAIN ARCO Alaska, Inc.~'.. Post Office .. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 S~IP LE 't'R3%YS~!ITTAL · hand-carried SHIPPED TO: , State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle DATE- 5 - 12- 8 8 OPERATOR' ARCO' N;u\IE - see below S~'%xiP LE TYPE' , SkxiP LES SENT: Lisb L5-21:11 boxes 12088/89 - 12133/34 12123 - 12144 12145/46 - 12149/50 12151/52 - 12198/99 12151/52 - 12198/99 12200/01 - 12223/24 12230/31 - 12288/89 12290/91 - 12371/72 12373/74 - 12390/91 12396/93 - 12406/07 12422/23 - 12425/26 12435/36 - 12445/46 12449/50 - 12463/64 12467/68 - 12471/72 12473/74 -'12581/81.5 12482/83 - 12490/91 12492/93 - 12510/11 12520/21 - 12614/15 core chips, plug ..ends NUMBER OF BOXES- 63 KRU 2T-9; I box KRU 3J-9:12 boxes .t~J-a-. 05"* 2150.8 --~ '6320 - 6393 "(5250 & 2315 are 6395 - 6436 preserved - no 6438 - 6453 samples are available)6459.- 6503 6507 - 6545 KRU 3H-9.: 9 boxes 6548 -. 6570 '6868'- 6908 KRU'3K-9:16 boxes 6911 - 6958 6971 - 7058 3365.2 - 3501.3 6967 '7009 KRU 3H-11:2 boxes 7027 - 7060 7060 - 7099 3941 - 3954 7102 - 2174 , ,, 3970 3974 7199 - 7243. 3979 - 3983 3993 - 3994 4025 - 4035 4057 - 4059 , 4061 - 4081 6531 - 6577.0 6579 - 6618 6637 - 665O -KRU 3M-16:7 boxes 7580 - 7614 76.17 - 7690 ,, SHIPPED. BY: ~, .... BayView Facility Coordinator , , UPON RECEIPT OF THESE S;~IPLES, PLEASE~NOTE ANY DISCREPANCIES AND b£~lL A SIGNED COPY~OF THIS FORM TO' ARCO ALASka, INC. ANCHORAGE, ALASKA 99510' ATTN: Paleo Lab · .. RECEIVED BY: DAT~~.' ~/~~ · ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany . '-~ STATE OF ALASKA ,~'~' ;~' ALASK~IL AN D GAS CONSERVATION ~-~MISS1ON WELL CO-MPLETtO NOR RE(2OMP TION R ORT AND LO 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator.................. 7. Permit Number ARCO Alaska, Inc. ,; ....... ',.:~.:8~-29 , , , 3. Address : ~'~''' ~ '8'. ;~Pt Number P. 0. Box 100360, Anchorage, AK 99510-0360 ' ~. ~'-' '50~,. 029-21710 4. Location of well at surface ~ , {;'~L; 9. Unit or Lease Name 1112' FNL, 1665' FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit At Top Producing Interval "1'01 Well Number 2023' FNL, 1158' FEL, Sec.25, T13N, R8E, UN 3H-9 At Total Depth 11. Field and Pool 205~+~ FNL, 1155~ FEL, Sec.25, T13N, R8E, UN Kuparuk River Ffe~d 5. Eleva;ion i'n feet (indicate KB, D'F, etc.) I 6. Lease Designation ;'nd Serial No. ' ..... Kuparuk River 0~ 1 Pool RKB 6~,' J ADL 25523 ALK 2559 12. Da~; Spudded ' ' 13. Date T.'D.'Reached' ' 14. Date'c'omp.i susp. or Aba'nd.' '115.'W;ter 'Depth, if offs~lore 116. No. of Completions 0~/23/87 05/01/87 · 10/17/87' J N/A feet MSL I 1 17. To'tel ~epth (MD+~/D) l$.Pl~g B~(~k Depth (M~D+Tt'I~rD) 19. Directi(~nal Surv;~ I 20. D;pth where S~SV set '1 21. ~'hi~:kness of Permafrost 6880 ND, 6629 TVD 6780 ND, 6529 TVD YESI~ NOF'I ~ 1792' feetUD J 1600' (approx) 22 Type Elect'rig or Othe~ Logs Run UIL/31-L/GK/SP'/L55, I~DT/CNL/NGT/EPT/Ca~"~' 'SHDT,' EPT, SWC, .......... DIL/SP/GR/SFL, FDC/CNL, Cal, SHDT, CBT, Gyro, Temp. Survey 23.· .............................CASING,_~LINER.AND cEM. E'NT!.NG RECORD ........ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16GG ' 6Z.5#" H-z~O ' Surf " ........ i15;' '2M' ..... ~98 ~'x CS I1' ; ~ .... ~ 9-5/8" 36.0# ~1-55 Surf 3z~85' 12-1/~+" 1300 sx AS I!1 & 335 s.( Class 7" 26.0# J-55 Surf 6869' '8-1/2" 300 sx Class G & 175 s.~ AS I 24. Perforations open to Production {MD+TVD of Top and Bottom and 25. '~'UBING RECORD interval, size and number) SIZE DEPTH SET {MD) PACKER SET (MD) Perforated w/1 spf, 120° phasing 2-7/8'"' 6~79' 6~8' 6592'-6618'MD 6342i-6368'TVD ' 261............AcIDi'rFRACTUREi CEMENT sQuEEZE, ETC.' ' .DEPTH ! ,NT~'RVAL'.(M~i' iAM~U'i~' ~' ~. iND'~F"M'/~TERiA~. USED .. See attached Addendum~, dated...10./2..1./8...7,_ , ~ fo"~ frac~.ure data. . , , ~ , ,~ . ..., .r~, , ., . ~../A: .......... ~- - '~ P"~OUCT,O" TEST ' ' Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hou;s Tested.., PRODUCTION FOR OIL;BBL GAS-MCF WATER-BBL CHOKE SIZE "1 GAs.oiL RATIO ;~.. ' TEST PERIOD I~ ' '~I ' F'iov~ Tubi'ng' Casing Pressure CALCULATED I~ OiL-BBL GAs-MCF WATER-BBL OIL GRAVITY-APl {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. Core description to be submitted when received. RECEIIrED NOV ! ~ ~/ Alaska 0il& Gas Cons. Commission *Note: Drilled RR 5/3/87. Perforated well & ran tubing 7/11/87. Fractured well 10/17/87.Allch°rag8 Form iO-407 ~/C3/98 :[;/~J I . Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ".: GEOLOGIC MARKERS ' ; ,-' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS, DEPTH TRUE VERT, DEPTH GOR, and time of each phase. ,, Top Kupar'uk C -6535' 6285' N/A .' Base Kuparuk C 6550' 6300' Top Kuparuk A 6550' 6300' Base Kuparuk A 6652' : 6402' · . . · . 31. LIST OF ATTACHMENTS Addendum (dated 10/21/87) 32. I hereby certify that the foregoing is trUe and correct to the best of my knowledge , , Signed /~ ~ ~~¢.~ Title Associate Engineer Date II-IZ"g'7 INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item: 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas I njectipn, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM 5~07~87 5/26/87 10/17/87 10/18/87 3M-9 RU Schl. Rn JB/GR to 6777' PBTD. Rn CBT f/6772'-5200'. Rn gyro f/6726'-surf. Rn Check Shot log. RD Schl. Arctic Pak well w/175 sx ASI & 61 bbls Arctic Pak. Frac Kuparuk A-1 zOne perfs 6592'-6618' in nine stages per procedure dated 10/11/87 as follows: Stage 1: 100 bbls gelled diesel @ 20 BPM, 5000-3700 psi Stage 2: 450 bbls gelled diesel @ 20 BPM, 3650-3680 psi Stage 3: 30 bbls gelled diesel 2 ppg 20/40 sand @ 20 BPM, 3750-3780 psi Stage 4: 50 bbls gelled diesel 4 ppg 20/40 sand @ 20 BPM, 3780-3620 psi Stage 5: 50 bbls gelled diesel 6 ppg 20/40 sand @ 20 BPM, 3690-3600 psi Stage 6: 50 bbls gelled diesel 8 Ppg 20/40 sand @ 20 BPM, 3610-3680 psi Stage 7: 30 bbls gelled diesel 10 ppg'20/40 sand @ 20 BPM, 4010 psi Stage 8: 20 bbls gelled diesel 12 ppg 20/40 sand @ 20 BPM, 4010-5480 psi Stage 9: 40 bbls gelled diesel flush @ 20 BPM, 5480-4080 psi Underflush by 1 bbl Fluid to_Recover: 772 bbls Sand in Zone: 47,400# Sand in Casing: 760# Avg Pressure: 4035 psi ! RU Otis, rn 2 post frac temp surv's f/6700'-6440'. Secure well. -Drilling Supervisor RECEIPTED NOV 1 6 Alaska 011 & Gas Cons. Commission Anchorage ( D~te ARCO Alaska, In~k Post Otlice BOX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: August 11, 1987 Transmittal t 6020 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the £ollowtng items. Please acknowledge receipt and return one signed copy of this transmittal, 2Z-4 Dual-Zone PBU 'A'-Sand 7-14-87 2Z-4 Dual-Zone PBU 'C' Sand 7-14-87 2Z-12 Dual-Zone PBU 'C' Sand 7-2-87 2Z-12 Dual-Zone PBU 'A' Sand 7-2-87 2U-15 Pressure Buildup 5-28-87 2W-6 Dual-Zone PBU 'C' Sand 7-15-87 2W-6 Dual-Zone PBU 'A"Sand 7-15-87 ,,~:~ Static Well Pressure Report 7-26-87 3H'3 Static Well Pressure Report 7-17-87 3M-8 Static Well Pressure Report 7-28-87 2Z. 6 Static Well Pressure Report 7-21-87 2Z-8 Static Well Pressure Report 7-25-87 2U-6 Static Well Pressure Report 7-19-87 .3I-9 BHP Report 7-16-87 2W-7 Static Well Pressure Report 7-21-87 2X-lO Static Well-Pressure Report 7-17-87 2X-14 Static Well Pressure Report 7-17-87 2X-12 Static Well Pressure Report 7-17-87 2W-3 Pressure.Buildup Test 7-4-87 2Z-2 Static Well Pressure Report 7-17-87 2Z-6 Static Well Pressure Report 7-13-87 2Z-2 Static Well Pressure Report 7-9-87 2Z-8 Static Well Pressure Report 7-13-87' 3M-1 Static Well Pressure Report 7-13-87' 3M-2 Static Well Pressure Report 7-13-87 1Y-lO Static Well Pressure Report 4-23-87 1Y-4 Static Well Pressure Report 4-21-87 1¥-4 Static Well Pressure Report 3-3-87 Receipt AcknoWledged: AUG1 1987 Alaska 011 & Gas Cons. Commisslofl Anchorage Date: DISTRIBUTION: BP Chevron Mobil SAPC Unocal State of Alaska D&M ARCO Alaska, Inc. is a Subsidiary of AllanflcRichfleldCompany ARCO Alaska, Inc. Post Offi~'"'~ox 100360 A nchorag~-, ,~.laska 99510-0360 Telephone 907 276 1215 Date: July 29, 1987 Transmittal ~009 , RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ,.3M-19 ,, 3M-19 , , 3M-19 . , 3M~½9 ~ '3M-19 , s3M-19 .~3R-21 ' '3H-21 ~ .3~-21 · '3R-21 · ,3M-21 ', 3M-21 Cyberlook 7-17-87 2" Porosity FDC 7-17-87 5" Porosity FDC 7-17-87 2" Raw Data FDC 7-17-87 5" Raw Data FDC 7-17-87 2" Dual Induction 7-17-87 5" Dual Induction 7-17-87 5" Dual Induction 4-24-87 2" Porosity FDC 4-24-87 5" Porosity FDC 4-24-87 2" Raw Data FDC 4-24-87 5" Raw Data FDC 4-24-87 2" Dual Induction 4-24-87 5" Dual Induction 7-24-87 2" Dual Induction 7-24-87 5" Porosity FDC 7-24-87 2" Porosity FDC 7-24-87 Cyberlook 7-24-87 2" Raw Data FDC 7-24-87 5" Raw (+1.2") FDC 7-24-87 4482-8939 4482-8939 4482-8939 4482-8939 4482-8965 4482-8965 115-3480 114-3494 114-3494 114'3494 114-3494 115-3480 1000-10761 1000-10761 5400-10735 5400-10735 10150-10680 5400-10735 5400-10735 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Rathmell D & !~ L. Johnston (vendor PackageJi_ . 'Vault(fi]an) ~receIved 3M-9 a~ready ARCO Alaska, Inc. is a Subsidiary of illanlicRichfleldCompany L.=,.. STATE OF ALASKA SS~I I~ / OIL AND GAS CONSERVATION C(~.~' I REPO F SUNDRY WELL OPERA'TIONS 1. Operations performed: Operation shutdown [] Stimulate [~ Plugging [] Alter Casing [] Other ~ CONPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 AnchOrage, AK 99510-0360 4. Location of well at surface 1112' FNL, 1665~ FEL, 5ec.25~ 'TI'3N, R8E, UN At top of productive interval 2023~ FNL, 1158' FEL, 5ec.25, T13N, R8E, UM At effective depth 2045' FNLs 1156' .FELs 5ec.25, T13N, R8E, UN At total depth 2054' FNL~ 1155' FEL~ $ec.25~ T13N, R8E~ UN 11. Present well condition summary Total depth: measured 6880 'ND true vertical 6629'TVD Effective depth: measured 6780 'MD true vertical 6529'TVD feet feet feet feet Perforate ~ Pull tubing [] 5. Datum elevation (DF or KB) RKB 64 ~ Casing Length Size Conductor 80~ 16" Surface 3448' 9-5/8" Production 6869~ 7" 6. Unit or Property name Kuparuk River Unit Feet 12. Perforation depth: measured true vertical 6592'-6618'ND 6342'-6368'TVD Tubing (size, grade and measured depth) 2-7/8"~ J-55~ tubing w/~.ail (~ 6~79' Packers and SSSV (type and measured depth) HI~P-I-RP ,nEe r~ C-,/~/~R, X. T~rtD.1A.qc;A Stimulation or cement squeeze summary N/A Intervals treated (measured) 7. Well number 3H-9 8. Approval number 87-29 9. APl number 50-- 029-21710 10. Pool Kuparuk R~ver '0il Pool Treatment description including volumes used and final pressure 13. Plugs (measured) None Junk(measured) None Cemented Measured depth 198 sx CS'II 115~HD t300 sx AS III & 3~85'HD 335 sx Class G 300 sx Class G & 6869'HD 175 sx AS I True Vertical depth 115~TVD 3~8~ ' TVD 6618 ~ TVD RECEIVED JUL 2 8 1987 011 & Oa~ Cena. ~rl Representative Daily Average Production or InieCtion Data. N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Compl etion Wel 1 Hi st.ory) Daily Report of Well Operations J~ Copies of Logs and Surveys Run EX Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~'--/~- ~7. Title Associ ate Engi neet Date Signed Submit in Duplicate Form 10-404 Rev. 12-1-85 (Dani) $W02/58 ARCO Oil and Gas' Company Daily Well History -Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or 8old. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ACcounting District ]Coun{y or Parish IState Alaska North Slope Borough Field ~Lease or Unit Kuparuk Rive= [ ADL 25523 Auth. or W.O. no. [Title AFE AK2386 [ Completion COlt center code Alaska Well no. 3M-9 Nordic 1 Operator [ A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun IOate Complete Date and depth as of 8:00 a.m. Complete record for each day reported 7/10/87 AP1 50C029-21710 W.I. rrotal number of wells (active or inactive) on this [cost center prior to plugging and 56.24% labandonment of this well IHour "' I Prlor ststul If a W.O. 7/10/87 [ 2315 hrs. Old TD New TD Released rig Date 2300 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Po'tential test data 7" @ 6869' 6768' (Will) PBTD RR 6.9 ppg Diesel Accept rig @ 2315 hfs, 7/10/87. ND tree. NU & tat BOPE. RU Gearhart, peri 6592'-6618' w/1JSPF, 120° phasing. RDWL. RU a rn 195 its, 2-7/8", 6.51, J-55 RUE 8RD tbg w/S$SV @ 1792', flRP-I-SP Pkr @ 6448', TT @ 6479'. Set Pkr. Tst tbs & ann to 2500 psi. Tst SSSV. ND BOPE. NU & tit tree to 250/5000 psi. Displ well to diesel. RR @,2300 hrs. 7/11/87. RECEIVED JUL 2 8 1987 al & Gas ConS. commission Anchorage Pa Depth 6768' (~) PBTD Kind of rig 7 / 11/87 Rotary IType completion (single, dual, otc.) . Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production 011 on test Gas pe'r day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86'and 87. Date . -- ]Title Drilling Supervisor SUB.~URFACE DIRECTIONAL F'~ UIDANCE $URVEY MICROFILMEI F~ ONTINUOUS rTlooL Company Well Name ARCO ALASKA, INC. RECEIVED At. Ii 011 ~ _~ Gene _3M,9(1112'. , FNL~, ],665' FEL~SEC Field/Location KUPARUK, ,NORTH SLOPE, 25tT13N,R8E.UM) Job Reference No. ~2317 WARNER Date 6-MA¥-87 Commuted KOHRING * $CHbU#~ERG~R ~ GCT DZRECTIONAb SURVEY CUSTOMER blSTING ARCO AbA&KA, INC, KUPARUK NORTH SbOPE,AbA&KA SURVEY DA~EI 06-MA¥-87 ENGINEERI D, WARNER METHOD& OF COMPUTA?ION TOOb bOCATXONI TANGENTIAb- Averaged dev~ation and azimut~ VERT~CAb SECTXONI HDRIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 25 DEG 3 MIN EAST ARCO AbASKAF ZNC, 3N-9 KUPARUK NORTH SbOPE,AbAEKA CDHPUTATION DATEI 25-MA¥-87 INTERPObATED VAbUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE 6US-SEA COUR$£ NEAEURED VERTICA~ VER?ICA~ DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG NIN DEG NXN VEHTICAb DOGbEG RECTANGUbAR COORUZNATE$ HORIZt DEPARTURE SECTZON 6EVERITY NORTH/6OUTH EAST/NEST DZETi AZlNU?H FEET DEG/AO0 FEET FEET FEET DKG 0,00 200 0,00 300 0000 399 0,00 499 0,00 59:9 0.00 699 0,00 799 0.00 899 lO00 '0 1300 ~4:0'0 1500 1600 t?O0 ~900 0 999 .0 1099 .oo~6,oo ,4~ o.12 0.40 ~ 8.~ oo ,, ¥.,o ,55 02 10 3.49 2003 9~98 .635,985'3'5'98 ~ ~ ~1412~ ~ 80 09 4,09 ~ 2,58 935 98 1035 9-7 1135 97 97 11~597 9'7 1.5'97 97 143~ 97 97 153~ 97 97. 1635,97 96 1735 96 95 1835 95 ¸ 99 0 ~99 PO ~0 ~ 399 PO 1499 )0 1599 )0 1,699 )0, 1799 O0 1899 9'7 97 2615 31 27355.' 22 283 20'00 19990 2100: 2099.~ 20 99 t1,, 240~,00 2 99 7 35 .00 ,00 99 ,oo;oo 2900,00 99 o.oo . o o 0;42 $ 14 58 E $ 17 4E 0,91 1,53 $ 21 4 E 2'38 $ {~4714 EE 3024 S ]0 9 4,03 S E 5,55 E 6,17 S I E 00 2999 O0 99 oo O0 1299 O0 99 3698 O0 3798 O0 3895 15 2935 3135 03 3235 01 3335' O0 3435 99 3534 94 3634 3734 0 I ~ 54 E .91 0 0 1 S 41 11 E .24 0 8 55 24 E 0 9 ,54 0 0 I0 S 6'6 8 E 7.81 0 0 16 $83 3 E 8,05 0 0 6 iS 64 37 g 8.24 0 0 17 N 6044 g 8.02 0 0 48 N 55 50 El 7,95 O: I 24 N 36 55 E: 7,64 0 s 07 6,46 & 4,61 55 6,55 ~ 4,99 , 66 $ 8,06 88 I 26' N ,~ 0 E 4 4 I 30 N 27 1 E 9 214 N 29 19 E ~ 71 2:2? N 29.44 E 16 4O 0 :1 0 45 0 O8 0 44 0 63 0 50 0 56 0 48 2 40S 0 06 S 19 O0 N 0 N 956~ 10 89 E ~0 8 iG 15 1 57 h 6O 52 E 10 I 41 N 59 22 E 06 I 26 N 56 42 E 03 I 17 N 54 47 g O! i 4 N 56 16 E O0 0 48 h 52 54 E 99 0 42 N 45 7 E 94 3 47 $ 46 33 £ 14 9 55 $ 35 19 E 78 14 30 $ 35 17 £ .8 ~s -9 95 '10 ~3 -10 3 °9 08 2~ 85 9? 98 16' 10 2 04 ~ 4 89 N 41 13 g 42 85 £ 44 20 £ 45' 16 £ 67,08 4 48 50 52 5 79 N 543 E 89 N 546 E 84 N 5358 E ARCO ALASKAw XNC. KVPARUK NORTH SbOPE,ALASKA COHPUTATZON DATEI 25-MA¥-87 PAG~ 2 DATE OF SURV£¥1 06-MAYe87 KEbL¥ BUSHXNG EbEVATXONI 64eO0 PT - ~NGXN~ERI De ~AR#~R XNTERPObATED VALUE6 FOR EVEN 100 FEET Or ~EASURED DEPTH TRUE SUB-&ER COURSE VERTICAL DOGbEG RECTANGUbAR COORDiNATe& HUR~Z,. DEPAR?URE #EA&URED VERTZCAb VERTICAb DEV~ATZON AZIMUTH SECTZON SEVERZ~¥ NURTH/SOU~H EA&T/NE$~ D~&T. A~#UTH DEPTH DEPTH DEPTH DEG MXN DEG ~IN FEE~ DgG/IO0 FEET FEET FEET DSG MZN 34 115 65 25 105,,10 ,57 210,53 ~ 248 407 2,68 4800.00 4671 87 460787 ~8 380 280,65 473 , 20 529 627 ~$2'00 ~,oo oo ~o~ ~ ~o~?.2o 2? ~, ~ ~' ~ o,~ ~?~ ~ ~ ' 5 04 399,87 805 74 000.00 ~00,0 6~00,00 6400,0 ,,~q00.O§ (00,0 'lrtO0,O~ 6800.00 6~80.00 5757 OO 5693 8~4 ~o:~ 608 99 6250 3b 6186 36 6349 628 9 ~o 6628 A3 6564 i 6 E 957 S 28 59 E 997 8 1 S 27 19 E 1012 7 6 $ 21 58 E 1025 5 44 $ 10 59 E 1036 5 18 S 6 I0 E 1045 5 4 $ 6 18 E 1054 4 56 S 614 £ 1062 4 56 $ 61~ E 1068 60 60 1 67 0 Io~ o 0 92 0 87 937 03 856 41 ~07 O0 934 O0 941 28 ~ 497 $ 505 J8 $ 50? 1~ ~ 50~ ?6 $ 509 58 $ 509 .. 08 g 98 95 S 29 88 E lO010 09 11 E; 1015 30 S 2 23 E 1048 23 E !056 17 E 1064 92 Ig 1070 38 S 29 15 lg · S ~ 56E 45 42 $ E 42 $ 8 ,t4 lC 79 S 28 26 g ARCO AbASKA, :]:NC, 31q-9' KU_PARUK NORTH 8bOPEtAbASKA COHPUTATLON DATEI 25'NA¥'87 PAG~ DATE Or &URVB¥1 06-NA¥-t7 KEbb¥ BU&HXNG EbEVATAONi &4eO0 P~ ' &NGXN~gRI De #ARNKR XNTERPObATEO VAbUE$ FOR EVEN 1000 FEET OF MEA&URED DEPTH TRUE &UB-&EA COURSE #EA&URED VERTXCAb VERT%CAb DgVXATZON AZZNUTH DEPTH DEPTH DEPTH D~G NXN DEG VERTXCAb DOGbEG RECTANGUbAR COORDINATE& HORZZ.~ &ECTXON 5EVERXTY* NORTH/&OUTH gA&T/NEaT DX&To FEET DEG/IO0 FEET FEET FEZT EPARTURZ Z!P4UTH DI:G 0,00 99~ iO00.O0 2000.00 1999 3000,00 2999 ~000,00 3991 t~=O0,O0 4840 ~.~00,00 5757 6880,00 6628 OD ii O0 '64, 8 98 935,98 91 1935.i~ 15 2935. 1 53 3927. t~ t9 4776.~ ii i9 O0 5693, 83 b564, 56 N 0 0 E 0 O0 & ?t 51 g 6 53 N I~ g 6 22 a 60 5 £ -6 56 6 36 11 E 5~ 20 S 20 1E 57 04 i 6 14 E 1068 0 O0 0 22 0 5 51 0 56 ~00 0,00 ~,40 25,4~ 1'8,38 481,63 837,22 941,58 9,56 E ,,.,,, ,2::8 83.95 E 85: 470~88 E 960 509.92 ~ 1070 AR~O AbASKAf INC. KUPARUK NORTH SbOPEpAbA~KA COHPUTATZON DATE: KE~¥ BU&HXNG ELEVATXON~64~00 PT · XNTERPOHATED VALUES [~OR EVEN 100 FE6;I' OF SUB-SEA DEPTH TRUE SUB-6EA COURSE: VERTICAb DOGbEG RECTkNGUb&R COORDINA'rE6 HOR~m' DEPAR~UR~ ~EASUR~D VER~XCAb VER~CAb DEViATiON A~U~H* 6~CTXON 6EVERXT~ NORTH/6OU~H EA6T/NE6~ DE:PTH DEPTH DEPTH DiG. MXN DEG MXN FE:ET DEGtlO0 FEET FEE~ oo~:oo .~,.oo ~ o ~ ~g ,g [ o.oo oo goo.o oo ~ o.oo ~ o $ ~0O00~00 0 4 ~I~ oo ~,,.oo ~oo.oo ,,[ ~:I~ 'g~ ~ ~ o? oi 364. oo 300 oo o gl s~ ~.ot ~ ..gb 8 3,34 864 00 800 00 1064,00 1000,00 ~ 6,80 1164.00 1100,00 22 7,14 ~ 4,05 1464,00 1400,00 1664.00 i600.00 ~ ~ 43 i7 [ 8.i6 7 o' ,~,.oo ,~oo.oo ,~ E 04 ~0,50 2364 O0 2300.00 ~ 29 0.30 31 1~ 14,83 ~ 19,16 ' · '7,96 ~6 25,81 33.t~ ~8oa oo ~8oo;oo ~ ~ -8.3~ : 3264'96 3264 O0 3200.00 I X9 [ ~ 33 40 46 29 49 97 -9 44 ~,6~.oo ~,~, oo~,oo.oo o ~ . ~ ? ~ -~o ,, o ~ ,~ . ,~ 3565.01 3564 O03500.00 0 44 "45 30 E -10 47 0 .14 32 52 N ,4 85 E 55__ 40 N 3765 3764 O0 3700.00 8 7 S 36 b E -2 45 2 83 N 5X · 3867 3864 O0 3800,00 13 12 ~ 34 56 g 16 21 4 11 34 N b2 ~ 63 56 N ARCO AbASKAw INC, KUPARUK NORTH SLOPE,ALASKA PAGE DATE OF SURVEYI BU~HZNG ZIACVAT,1;ONI 64.00 ENGZNEERt De,: NARN~R XNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 108.~4 40?7.64 4064.00 4000 54 10,94 78.50 79,26 4~87.07 4164,00 4100, !i ~ 34 ~ i I 38 77,67 _4420. 4364.00 4300 ~ 33 [ 62 , 121057 1.54,67 [ . 375,52 278,81 . 467,71 302.~6 48 · 9 5464 6109 05 650. · 4 377.64 92 4964 79 5264 5664 5764 50 5864 O0 4900 O0 5000 ~ ~o 00 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 29 27 S 19 26 E 644 0028~ S 281115 E 698 O0 25 ~. $ E 51 749 O0 S 25 30 E 795 I E 834 00"00 I~18 I.~59 $6 ~ 33 E 871 O0 17 48 $ 26 16 E 904 ,0015 19 $ 27 0 g 934 ~,00 13 11 $28 18 E 959 O0 11 10 S 28 50 E 981 0 20 38 18 50 O6 6{11.14 5964,00 5900 O0 6312.27 6064.00 600 O0 641~.~1 6164,00 610~ O0 65130 I 6264,00 6200 O0 6614015 6364.00 6300 O0 6464'00 000 ~1~.~6 64 0 ~,~o~'o'o~ ,~6,.oo ~,oo OD 6628,83 6564 83 7 ,5 6 57 E 6 $ 0 44 E 5 38 8 9 35 E 516 8 6 3 E 5 0 $ 6 12 E 456 S 611£ 4 56 S 6 E ~o~? ~ 046 9! 1.60 1,09 0,28 0,78 0000 0,00 8 ,77 001, 89 017, ,,?. oo ~ . 506,20 · 040 . 049. ,~?;,~ I Io,.o,,°'?' i 't [ ,~,..oI ~ ~o,.~, i I '~'* i l, 509 92 £ 1070 941,5' . ARCO A[.,ASKA~, INC. 3H,-9 KI~PARUK NORTH SLOPEp. ALA6KA NARKER CONPUTATION PATti 25-HA¥-87 PAGE DATE Or SURYE¥I 06-NA1t'-87 KELLY GUSHING ELEVATIONI 64.00 ~NGIN~RI D, ~ARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS N£ASUR£D DEPTH ORIGIN= 1112 rna, 1665 F£[,. SIC. 5. TllN. ll)!;w U~ ~VU R~CTAflGUbAR CDORDZNA~K$ TOP KUPARUK C 6535,00 6285.19 6221.1~ 9 BASE KUPARUK C 6550.00 6300.13 6236. 9~ ?~P KUPARUK A 6550.00 6300.13 6236.t3 912 :::-BASE KUPARUK A 6652,00 6401.69 6337.69 9 PBTD 6780.00 6529. 6465. TD 6880.00 6628.~ 20 6564.83 9 ARCO AbASKA~ ZNC, 3#"9 KUPARUK NORTH 8bOPE~AbASKA CDMPUTATZON DAT£1 25-MA¥-87 MARKER PKUPARUK C A&E KUPARUK C TOP'KUPARUK A (:--BA~ KUPARUK A PBTD TO MEASURED DEPTH BELOW K8 653 O0 655~ O0 66 O0 6780 O0 6860 O0 SURFACE bOCAT:ZON ORIG~N- 1112 FNL, 1665 rE;L. SEC..-.~5 :~.~. ROE, U, ~VP R~CTANGUbAR.~ O~R~..A~8 O0 6300 6401 6529 6628 6337 20 6465 83 6564 92:90 ~ 506, 507, 20 93 ,03 508, 83 94 ,58 S 509. 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I , .... .......... .. , · """"~ ....... ~ ....... 1""?'?"'? ..... ? ?'"?"'?'"? ...... ?'?"'? ? ..... ~'*T *~ : : : PROJECTION ON VERTICGIL PLI~NE IS4. - ~4. SCALEO IN YERTICI~L DEPTHS HORIZ SCALE = 1/200 IN/FT 154. I! - 1 -:.., Littan Core Lab ..J ~ 1 ....J. , - - -.-.-.-"- /CJ7 - o~ c¡ 8005 Schoon Street Anchorage, Alaska 99518-3045 (907) 349- 3541 CORE ANALYSIS REPORT Arco Alaska, Inc. KRU :# 3M-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska 21-Ju1-87 \- i L J I. SECTION A - SUMMARY OF PROCEDURES TABLE OF CONTENTS 1.) Introduction 2. ) Methodology a. Core Gamma Surface Log b. Laboratory sampling : Plug Samples, Full Diameter Samples c. Laboratory Procedures : Hydrocarbon Extraction, Porosity, Permeability, Porosity and Permeability - Overburden Conditions, Porosity and Permeability - Full Diameter Analysis, Fluid Saturation Measurements, oil Gravity Analysis, Core Photography. , '"- j L L 1... 3.) Special Conditions L II. SECTION B - CORE ANALYSIS RESULTS - TABULAR DATA 1.) Conventional Analysis Results ~ - 2.) CMS-200 Overburden Pressure Analysis Results 3.) Full Diameter Analysis 4.) Detailed Lithological Descriptions -- III. SECTION C - CORE ANALYSIS RESULTS - GRAPHIC DATA 1.) Correlation Coregraph IV. SECTION D - APPENDICES 1.) J..,. 2. ) 3. ) 4. ) 5. ) 6.) -, Refractive Index vs. API Gravity Plot oil Correction Chart Technical Paper - Automated Core Measurement System for Enhanced Core Data at Overburden Conditions (Keelan) Wellsite Core Report Well site Handling Procedure Shipping and Receiving Transmittals ,..- .-J Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518- 3045 (907) 349-3541 ~ ~ -I SECTION A 1 ~ SUMMARY OF PROCEDURES ~ ~, Arco Alaska, Inc. KRU :#3M-9 Kuparuk Formation Kuparuk River Unit North Slope, Alaska ,...0- ,...., """" .;¡... .L> INTRODUCTION ..,i... Core Lab personal at the drill site supervised the proceeding and preservation of the KRU :#3M-9 core. Well site handling procedures are explained in the Appendix. Whole core samples from the KRU #3M-9 well were brought to the Core Laboratories Anchorage facility for core analysis. The following is an outline of the procedures used in analyzing the KRU :#3M-9 samples. ,:s... ..1- METHODOLOGY ...... Core Gamma Surface Log ,~ - Gamma radiation was measured on the entire core using the Core Lab Surface Gamma Logger instrument. The results are reported on the Core Analysis Correlation Coregraph. .,J. i Laboratorv Samplinq Plugged Samples .J. A one and a half inch length by one inch diameter plug was drilled from a lithologically representative section of each foot for helium porosity and air permeability measurements. Plugs were taken from the center of each section and parallel to the bedding strike, with water used as the bit coolant. Approximately 150 gram sample was removed adjacent to the plug for fluid saturation and API gravity measurements. To minimize invasion effects the sample was taken from the center of the core. ,...;.. - - Full Diameter Samples , ...... Full diameter samples were removed from selected intervals for helium porosity and directional air permeability measurements. C02 was used and saw coolant. ...... Laboratorv Procedures Hydrocarbon Extraction The plug samples were placed in a toluene centrifuge extractor for hydrocarbon removal a minimum of three days. Once cleaned, the samples were dried in a convection oven for a minimum of 24 hours at 220 deg. F., and then cooled in a desiccator to room temperature before porosity and permeability was measured. - ;l-;" Porosity .1... Grain volumes were determined by a Boyle's Law - Heise Gauge Helium Porosimeter. Bulk volumes were measured by mercury displacement. )-, Permeability .J- Horizontal permeability to air was measured using a steady state permeameter with a 400 psig. boot pressure. .J- Porosity and Permeability - Overburden Conditions ,J... In order to simulate reservoir stress conditions, plug samples were run at requested overburden pressures in the CMS-200 Automated Core Measurement System. For each sample, a measured Klinkenberg equivalent liquid permeability, and estimated air permeability, and a helium porosity is reported for overburden pressures of 1000 and 3000 psig. .... .L. Core Laboratories is pleased to provide the overburden porosity and permeability data performed on these plug samples at no additional charge. These values should prove most helpful in the evaluation of the KRU :#3M-9 well, they are more representative of porosity and permeability at formation depth. -- porosity and Permeability - Full Diameter Analysis ~ Samples were cleaned, dry weights were measured and grain volumes determined by Boyle's Law-Heise Gauge Helium porosimeter. Bulk volumes were measured by Archimedes technique. - vertical and Horizontal permeability parallel and perpendicular to bedding, and porosity were measured in a hydrostatic holder at 400,1500, and 2000 psi. net overburden. Horizontal measurements were made with screens attenuating 45 deg. of arc. Permeability to air was measured using a steady state permeameter. Core Laboratories is pleased to provide the overburden porosity and permeability data performed on these full diameter samples at no additional charge. These values should prove most helpful in the evaluation of the KRU #3M-9 well, they are more representative of porosity and permeability at formation depth. Fluid Saturation Measurements Of the 150 gram sample, 100 grams was broken pieces for the retort process. The 100 gram in a conventional retort oven at 400 deg. f. when an initial water reading was measured. into "peanut" size sample were retorted for 40 minutes , The temperature of 1->- 1- the oven was then increased to 1200 deg. F. An observed oil* and final water was then read after and additional 15 minutes at the temperature. The remaining piece is used for bulk and gas volume measurements. Bulk volume for each sample was measured by mercury displacement. Gas volume for each sample was determined by mercury injection at 750 psig. !-. ;1- * Observed oil readings were corrected for coking using the oil correction chart in section D. )... oil Gravity Analysis J- The refractive index of the recovered oil was measured every fifth foot and the API gravity (60 deg. F.) was determined using the appropriate correlation chart derived from previously analyzed Kuparuk crude samples. See Section D. J- Core Photography J... - The core was photographed in white and ultraviolet light with approximately 15 ft. of core per 8x10 in. print. As requested, two sets of white light and one set of UV core photographs are submitted. - Special Conditions 1 - Core 1 from 6531 to 6539 feet and Core 3 were not preserved in Core Seal. Core 1 from 6531 to 6555 and Core 3 have been slabbed and photographed. The un-sampled portion of each foot in the rest of the well remains preserved. , ...... During coring, 17.5 feet was lost in Core 2. Following standard procedure, the lost interval was assigned to the end of the core. However that maybe incorrect and Core 2 depths 6591.0 thru 6618.5 are possibly 6609.0 thru 6636.5 with the core loss occurring in the middle of core. It is recommended that the core depths be corrected by correlating the core analysis data with the down- hole log data. - -1 Littan Core Lab J. J J. 1 .-... J. ..l. 1 --- ~ -- ,..... .-- 8005 Schoon Street Anchorage, Alaska 99518-3045 (907) 349- 3541 SECTION B CORE ANALYSIS RESULTS - TABULAR DATA Arco Alaska, Inc. KRU :#3M-9 Kuparuk Formation Kuparuk River Unit North Slope, Alaska 1..-' I .I 1- i , ,~ j ,-- , Conventional Analysis Results j r 1 ,- ¡ J '- \- .--" --- ~ r- 1?7- ()2 ~ Kfu 3fY7- { 1 1 ) ì J ) L 1 ..1 1 ~ .1 ~ '; ~ COR E LAB 0 RAT 0 R I E S I N C Arco Alaska, Inc. Date : 21-JUL-87 e No : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts: TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % \'TR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCR I PTION .. - .... ........ ... ...... .. .. .. .. .. .. .. ......- ...... .. - - ..--- -- ....- --....................... ..-..............- .......... .-...- -... --- - -- CORE #1 6531.0 - 6578.0 101 6531.3 0.11 11.4 0.0 89.8 2.74 SLTST,MDGY,ARG,MNR SD,SL CALC,\'ELL CONS,TR MICA 102 6532.4 3.39 12.3 0.0 91.7 2.73 SLTST,MGY-MDKGY,ARG,ABNT VFGR SD,SL CALC,\'ELL CONS,TR MICA ** 103 6533.5 0.03 11.1 0.0 91.6 2.72 SLTST,MGY,ARG,ABNT VFGR SD,SL CALC,\'ELL CONS,MICA 104 6534.5 0.05 11.3 0.0 84.4 2.72 SLTST,DKGY,VARG,MNR SD,SL CALC,\'ELL CONS, MICA 105 6535.4 4.83 11.6 0.0 92.9 2.73 SLTST,MDKGY,ARG,MNR SD,SL CALC,\'ELL CONS,MICA 106 6536.3 0.13 7.9 0.0 83.6 2.91 SLTST,MDGY,ARG,ABNT VFGR SD,GRADES TO DNSE P~SS SID-ANK CMT MDST 107 6537.2 0.21 10.6 0.0 85.1 2.71 SLTST,MDKGY-DKGY,ARG,MNR VF-FGR SD,SL CALC,\'ELL CONS 108 6538.4 1.01 7.5 0.0 81.5 2.99 SLTST,MDGY,ARG, TR F-MGR SD,\'ELL CONS,POSS SID-ANK CMT ** 109 6539.3 0.21 10.7 1.2 8D.2 3.07 SS,LTOLV-OLVGY,VF-CGR,PREDF-MGR,P-MOD SRTD,SBANG-SBRD,\'ELL èONS, P~SS SID-ANK CMT 110 6540.3 0.02 9.2 20.3 70.5 25 3.18 SS,LT OLVGY,YELBRN,VF-CGR PRED F-MGR,MOD SRTD,SBANG,DNSE,V\'ELL CONS,POSS SID-ANK CMT,GLAUC 111 6541.4 0.25 15.5 6.4 81.0 2.89 SS,GRNGY,YELLBRN,VF-CGR,PRED M-CGR,P-MOD SRTD,SBANG-SBRD,\'ELL CONS,GLAUC 112 6542.5 <0.01 5.8 0.0 54.5 3.23 MDST,LT-MBRN,ABNT F-MGR SD,\.ELL CMTD,DNSE,POSS SID-ANK CMT,MNR GLAUC 113 6543.5 0.02 6.2 11.8 71.8 3.06 SS,DKGRN GY,MBRN,VF-CGR,PRED F-CGR,\'ELL CMTD,P-MOD SRTD,SBANG-SBRD,POSS SID-ANK CMT,GLAUC 114 6544.7 <0.01 5.3 0.0 79.9 3.09 SS,LT-MBRN,VF-CGR,PRED FGR,WELL CMTD,DNSE,MOD-WELL SRTD,SBRD,POSS SID-ANK CMT,GLAUC 115 6545.3 0.D1 9.3 21.6 62.6 27 3.02 SS,LT-MBRN,VF-CGR,PRED M-CGR,\'ELL CMTD,DNSE,P-MOD SRTD, SBANG-SBRD,POSS SID-ANK CMT,GLAUC 116 6546. 1 8.83 20.2 27.1 57.7 2.86 SS,DKGRN,LTBRN,VF-CGR,PRED M-CGR,MOD-\'ELL CONS,P-MOO SRTD,SBANG-RD,POSS SID-ANK CMT,ABNT GLAUC 117 6547.9 0.97 18.1 14.6 72.4 2.91 SS,DKGRN,LTBRN,VF-CGR,PRED M-CGR,SLFRI-MOD CONS,P-MOD SRTD,SBANG-RD,POSS SID-ANK CMT,GLAUC 118 6548.3 0.78 14.8 22.4 57.6 3.23 SS,LTBRN,GRN, VF-CGR,PRED F-MGR,MOO'WELL SRTD,SBANG-RD,WELL CONS,POSS SID-ANK CMT 119 6549.8 0.53 16.5 15.1 60.4 3.06 SS,DKGRN,MBRN,VF-CGR,PRED M-CGR,MOD SRTD,SBANG-RD,\'ELL CONS,POSS SID-ANK CMT,GLAUC 120 6550.3 0.22 19.3 22.3 57.2 27 2.84 SS,DKGRN,MBRN,VF-CGR,PRED F-MGR,MOD-\.ELLSRTD,SBANG-SBRD,\.ELL CONS,POSS SID-ANK CMT,GLAUC 121 6551.2 0.01 15.4 26.4 57.3 3.19 SS,GRNGY,VF-CGR"PRED F-MGR,MOO-WELL SRTD,SBANG-SBRD,\'ELL CONS,POSS SID-ANK,GLAUC 122 6552.5 0.87 22.7 22.2 54.8 2.93 SS,DKGRNGY, VF-CGR,PRED F-MGR,P-MOO SRTD,SBANG-SBRD,MOD-\'ELL CONS,POSS SID-ANK.GLAUC 123 6553.7 0.60 10.6 1.8 91.6 2.89 SLTST,LTOLV-OLVGY,SDY,DNSE,POSS SID"ANK,30-40%INTBD MDST,XLN PYR ** 124 6554.4 0.18 11.1 2.5 81.2 2.70 MDST,OLVBLK,SLTY,\'ELL CONS,30-40r~DD SDY SLTST,TR PYR,SDY BURS 1 1 1 1 t ), .J. 1 1 ) t ,) ) ì COR E LAB 0 RAT 0 R I E S I N C Arco Alaska, Inc. Date : 21-JUL-87 File No BP-3-1221 KRU #3M-9 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg F ld : Bland Mud Analysts: TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % \.ITR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION - -- ..oo......... .. ........... .. .... .... .. .... ........ .... ..... -- .. .. .. .. -.. ..............-....-.... ..---.............. ....... ........- - -- ..... ........... 125 6555.3 0.36 11.5 26.7 57.6 17 2.64 MDST,GYBLK,SLTY,ABNT VFGR SD,\.IELL CONS,20-25%VFGR SDY BURS 126 6556.7 0.13 10.6 27.8 57.6 2.63 MDST,DKGY-GYBLK,VSLTY,\.IELL CONS,15-20%VFGR SDY BURS 127 6557.9 0.04 10.0 24.1 67.4 2.64 MDST,DKGY-GYBLK,PRED ARG,SLTY,\.IELL CONS,15-20%VFGR SDY BURS,TR PYR 128 6558.2 0.11 10.5 23.5 66.7 2.64 MDST,DKGY,PRED ARG,SLTY,\.IELL CONS,20-25%VFGR SDY BURS 129 6559.3 0.39 12.9 35.0 46.2 2.66 SS,LTBRN,VFGR,VWELL SRTD,SBANG-RD,\.IELL CONS,30-40%GYBLK,SLTY,VMIC,INTBD MDST 130 6560.7 112.04 22.1 33.9 49.2 20 2.67 SLTST,LTBRN,VF-FGR,PRED VFGR,VWELL SRTD,SBANG-SBRD,WELL CONS, 131 6561.7 207.37 26.1 25.9 36.1 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO CONS 132 6562.3 174.18 26.5 20.9 30.1 2.66 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 133 6563.8 225.34 27.3 28.6 33.7 2.66 SS,LTBRN,VFGR,SLT~,VWELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 134 6564.3 323.07 27.7 29.4 31.4 2.65 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 135 6565.6 292.81 28.3 29.2 28.2 23 2.65 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 136 6566.4 333.86 26.9 22.9 34.1 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 137 6567.4 100.87 22.3 39.9 17.1 2.69 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,MOO-\.IELL CONS 138 6568.3 31.D9 19.7 49.9 24.1 2.66 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,10% GYBLK,PRED ARG,INTBD MDST 139 6569.3 1.00 14.9 38.6 36.8 2.64 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,10-15% PRED ARG,MIC,INTBD MDST 140 6570.6 8.70 11.4 27.1 58.8 23 2.73 MDST,DKGY,PRED ARG,TR SD,\.IELL CONS,SL CALC,25% VFGR,SLTY,INTBD ss ** 141 6571.4 17.79 18.7 37.8 36.4 2.67 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,MNR MDY LAMS,TR PYR 142 6572.6 4.70 15.5 32.1 43.6 2.65 SS LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS 143 6573.3 1.83 13.8 30.3 45.9 2.69 MDST,DKGY,PRED SLTY,SDY,\.IELL CONS,SL CALC,30% VSDY,INTBD SLTST,DISM PYR ** 144 6574.3 7.73 11.3 30.1 35.8 2.66 MDST,GYBLK,PRED ARG,WELL CONS,SL CALC,20-25% VFGR \.IELL SRTD,SBRD,INTBD SS ** 145 6575.2 3.81 13.6 31.2 36.0 20 2.67 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS, 15% PRED ARG,INTBD MDST,TR PYR 146 6576.2 28.98 18.0 53.1 25.9 2.67 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,10% INTBD MDST, TR PYR 147 6577.0 7.94 17.9 33.6 20.9 2.66 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,10-15% INTBD MDST CORE #2 6579.0 - 6618.5 201 6579.7 6.24 15.3 42.2 15.8 2.67 SS,LTBRN,VF-FGR.PRED VFGR.SLTY.\.IELL SRTD,SBANG-SBRD,\.IELL CONS,30% PRED ARG,SLTY,INTBD MDST 1 1 1 1 ) 1 ~ ~ } } ~ ) l' J f COR E LAB 0 RAT 0 R I E S I N C Arco Alaska, Inc. Date : 21-JUL-87 FIle No : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts: TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % \.ITR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION --- ....... ...... ... ..... ... ... ... ....---..... ..... ...... ... ..... ... -- ...... .. ...............-............... -.... _____ ..-...O'.. __............... - ,- -- - 202 6580.2 19.52 21.2 52.2 11.3 2.65 SS,LTBRN,VFGR,MNR SLT,V\.IELL SRTD,SBRD-RD,\.IELL CONS,TR MDY LAMS 203 6581.5 86.31 24.4 51.5 5.6 22 2.68 SS,LTBRN,VFGR,MNR SLT,V\.IELL SRTD,SBRD-RD,\.IELL CONS,TR MDY LAMS 204 6582.8 80.71 22.3 3D.5 35.3 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO-\.IELL CONS,MNR MDY LAMS,TR PYR 205 6583.3 134.11 24.4 47.5 15.5 2.65 SS,LTBRN,VFGR,V\.IELL SRTD,SBRD-RD,MOO CONS,MNR MDY LAM 206 6584.5 40.32 23.5 52.0 11.8 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO-\.IELL CONS 207 6585.9 10.16 20.7 39.7 25.7 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO-\.IELl CONS,MNR MDY lAMS 208 6586.2 52.99 14.8 43.3 32.1 22 2.65 SS,LTBRN,VFGR,SlTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,35-40% SLTY,ARG,SL CALC,INTBD MDST 209 6587.5 44.61 23.1 54.3 20.9 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELl CONS,MNR MDY LAM 210 6588.7 2.32 13.9 36.0 41.1 2.74 SLTST,LTBRN,VSDY,MOO-WELL CONS,Sl CALC,20-30% PRED ARG,SLTY,SL CLAC,INTBD MDST ** 211 6589.6 1.11 15.8 30.5 39.8 2.64 SLTST,LTBRN,VSDY,MOO-WELL CONS,SL CALC,20-30% PRED ARG,SLTY,INTBD MDST 212 6590.6 7.48 13.3 37.1 39.6 2.82 SLTST,OlVGY,PRED SLT,SL CALC,WElL CONS,POSS SID-ANK,15-20% PRED ARG BDD MDST ** 213 6591.5 88.94 24.6 37.4 19.3 25 2.66 SS LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS,TR PYR 214 6592.2 66.93 17.6 41.5 44.3 2.63 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS20-30% PRED ARG,SLTY,INTBD MDST ** 215 6593.0 63.91 24.8 48.5 13.7 2.66 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO CONS,TR MDY LAMS 216 6594. 1 11.89 19.4 49.1 17.0 2.66 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS,MNR LAM MDST,BIOTURB 217 6595.4 108.17 21.9 49.8 6.5 2.66 SS,LTBRN,VFGR,MNR SlT,V\.IELL SRTD,SBRD-RD,MOD CONS,10-20%PRED ARG,INTBD MDST ** 218 6596.5 53.22 23.1 53.7 6.4 24 2.70 SS,LTBRN,VFGR,SlTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,SL CALC 219 6597.8 101.36 25.8 52.2 7.5 2.66 SS,LTBRN,VFGR,SLTY,V\.IELl SRTD,SBRD-RD,MOO CONS,TR MDY lAMS 220 6598.5 15.45 18.2 44.8 32.9 2.67 SS,lTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO CONs,30rRRED ARG SL CALC MDST,MNR PYR 221 6599.6 0.64 13.4 53.1 10.7 2.67 MDST,GYBLK,PRED ARG,MNR SDY BURS,MNR INTBD SS 222 6600.4 18.52 16.3 48.6 34.3 2.64 SS,lTBRN,VFGR,SLTY,V\.IELl SRTD,SBRD-RD,\.IELL CONS,30-40%ARG,SLTY,SL CALC,INTBD MDST ** 223 6601.6 20.79 23.2 49.9 13.7 19 2.66 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO CONS,MNR MDY lAMS 224 6602.4 6.54 15.2 53.9 26.4 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,30·40% PRED ARG,SL CALC,INTBD MDST 225 6603.5 79.00 21.9 56.0 5.2 2.69 SS,LTBRN,VFGR,MNR SLT,V\.IELL SRTD,SBRD-RD,MOO-\.IELL CONS,SL CALC 226 6604.5 5.12 17.6 39.5 45.9 2.71 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,15-20%PRED ARG MDST,XLN PYR 227 6605.9 137.93 19.9 38.9 41.7 2.66 SS,LTBRN,VF-FGR,PRED VFGR,SLTY,\.IELL SRTD,SBRD-RD,MOD CONS,MNR BDD MDST ** 228 6606.6 5.29 14.0 52.1 14.0 21 2.63 SLTST,OLVGY,ARG.SDY.\.IELL CONS,25-30%PRED SLTY.MIC.SL CALC,INTBD MDST,MNR CARB FRAGS ~ 1 1 1 ~ L t L ). ~ J. 1- " COR E LAB 0 RAT 0 R I E S I N C Arco Alaska, Inc. Date : 21'JUL-87 File No : BP-3-1221 KRU #3M-9 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts: TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % \.ITR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION - -- .. ...... .. .. ............ .. .. .. .. .... .. .. .... ..-.... - - .. .. .... -..--....- _..___................oo.. ..oo_.. ............ ...... .............--- 229 6607.6 18.28 14.4 32.1 56.0 2.64 MDST,GYBLK,PRED ARG,MIC,TR SD,MNR SDY BURS,30-40%VFGR,SLTY,\.IELL CONS,INTBD SS 230 6608.4 7.05 20.4 40.1 29.1 2.67 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,TR CARB FRAGS 231 6609.5 19.64 16.0 35.9 47.8 2.70 SS,LT-MBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,50% ARG,SDY,SL CALC, LAM MDST,PYR 232 6610.5 10.24 16.2 36.0 35.1 2.67 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,50% ARG,SDY,SL CALC,BIOTURB MDST 233 6611.3 8.17 13.1 35.9 51.5 15 2.66 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,WELL CONS SS,PYR,HVY BIOTURB ** 234 6612.4 0.48 13.6 28.8 60.4 2.70 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,WELL CONS SS,PYR BUR,BIOTURB 235 6613.6 2.56 14.5 53.7 12.1 2.66 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,WELL CONS SS,PYR,HVY BIOTURB ** 236 6614.7 5.34 18.9 50.8 14.0 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,MNR BIOTURB MDST 237 6615.9 0.89 15.8 43.4 32.6 2.64 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,50%PRED ARG,SDY,SL CALC,BIOTURB MDST 238 6616.5 1.78 15.5 45.9 32.1 19 2.82 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,50rRRED ARG,SDY,SL CALC,BIOTURB MDST,MASS PYR 239 6617.6 0.19 12.9 36.4 35.4 2.63 MDST,GYBLK,ARG,SDY,SL CALC,HVY BIOTURB,30-40%VFGR,SLTY,LAM SS 240 6618.3 7.61 13.7 33.5 53.6 2.64 MDST,GYBLK,ARG,SDY,SL CALC,30-40%VFGR,SLTY,INTBD SS ** CORE #3 6637.0 . 6657.6 301 6637.6 2.06 14.4 26.1 66.1 2.70 MDST,GYBLK,PRED SLTY,ARG,SL CALC,\.IELL CONS,20%VFGR,SLTY,INTBD SS ** 302 6638.5 319.24 14.9 35.1 49.6 2.67 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD, SBRD-RD,\.IELL CONS,30-40%SLTY,SDY,BDD MDST 303 6639.5 0.08 12.5 32.5 57.4 13 2.63 MDST,GYBLK,PkED ARG,SLTY,SL CALC,\.IELL CONS,MNR SDY BURS 304 6640.5 14.81 15.3 32.0 58.4 2.64 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS ** 305 6641. 5 8.36 13.3 31.0 48.1 2.62 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,20-30%LTBRN,VFGR,SLTY,INTBD SS,BIOTURB ** 306 6642.8 34.47 13.9 27.5 64.5 2.65 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,20-30%LTBRN,VFGR,SLTY,INTBD SS,** 307 6643.7 0.06 13.5 27.6 56.8 2.65 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS 308 6644.6 321.40 0.0 31.6 56.6 12 0.00 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS,BIOTURB 309 6645.4 449.27 12.6 32.1 61.5 2.64 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS,BIOTURB 310 6646.3 20.79 13.4 30.1 58.0 2.64 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS ** 311 6647.7 0.53 13.7 34.7 46.7 2.67 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,10%LTBRN,VFGR,SDY LAMS,BIOTURB ** 312 6648.7 42.57 11.5 15.1 67.0 2.66 MDST,GYBLK,PRED ARG, SLTY.SL CALC,\.IELL CONS,5%LTBRN,VFGR,INTBD SS ** J 1 ._~ ~_.." ) ) 1 1 ----' '"-. COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc Date : 21-JUL-87 File No BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts: TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % \.ITR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION - -- -.. .... .... ............ ....-... .. .. .. .. ........ .. .... . ------------------------............--. 313 6649.7 321.34 11.6 11.6 82.8 8 2.63 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,10%WHT,VFGR,INTBD SS 314 6650.5 0.04 13.3 10.5 79.2 2.65 MDST,GYBlK,PRED ARG, SLTY.SL CALC,~ELL CONS,MNR SDY BD,BIOTURB 1_ ~- j ,- i .. r , ,,..- CMS-200 Overburden Pressure Analysis Results ~ ~ "..-- , ;-- ,..- - , ~ - ~ ,...- r r 1 - L 1 t ~ \.. ~ ~ 1- ~ Ì' r COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 21-JUL-87 Fi Ie No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCR I PTI ON .. ........ .. .. .. .. .. .. .... .. ....... .. .... ...... .... ... .. .. .. .. .. .. ...... ...... .. --....----........--------- .. --...... --............... ..--- --.. 101 6531.3 atm(1) 11.4 0.11 SLTST,MDGY,ARG,MNR SD,SL CALC,\.IELL CONS,TR MICA 1000 11.0 0.02 0.04 102 6532.4 atm 12.3 3.39 SLTST,MGY-MDKGY,ARG,ABNT VFGR SD,SL CALC,\.IELL CONS,TR MICA ** 1000 11.9 0.22 0.26 3000 11.3 O.DO 0.00 116 6546.1 atm 20.2 8.83 SS,DKGRN,LTBRN,VF-CGR,PRED M-CGR,MOO-YELL CONS,P-MOD SRTD,SBANG-RD,POSS SID-ANK CMT,ABNT GLAUC 1000 19.9 2.77 3.67 3000 19.4 0.94 1.23 117 6547.9 atm 18.1 0.97 SS,DKGRN,LTBRN,VF-CGR,PRED M-CGR,SLFRI-MOD CONS,P-MOD SRTD,SBANG-RD,POSS SID-ANK CMT,GLAUC 1000 17.9 0.18 0_31 3000 17.4 0.06 0.13 118 6548.3 atm 14.8 0.78 SS,LTBRN,GRN, VF-CGR,PRED F-MGR,MOD-\.IELL SRTD,SBANG-RD,\.IELL CONS,POSS SID-ANK CMT 1000 15.5 0.38 0.54 3000 15.1 0.20 0.32 119 6549.8 atm 16.5 0.53 SS,DKGRN,MBRN,VF-CGR,PRED M-CGR,MOO SRTD,SBANG-RD,\.IELL CONS,POSS SID-ANK CMT,GLAUC 1000 16_ 1 0.21 0.37 3000 15.7 0.12 0.23 120 6550.3 atm 19.3 0.22 SS,DKGRN,MBRN,VF-CGR,PRED F-MGR,MOO-YELLSRTD,SBANG-SBRD.\.IELL CONS,POSS SID-ANK CMT,GLAUC 1000 19.2 D.1D D.21 3000 18.7 0.06 0.14 atm(1) = measured Ka and Por taken from conventional core analysis results. 1 r r 1 I 1- r t [' t t COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 File No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION ........-..- ..---....- .............. .. .... .. .. .............. ....-........ .. .. .. .. .. ............ .. .. .. .. .... .. .. .. .... .. .... .. .. .. .. .. ...... .. .... .......... .. 121 6551.2 atm 15.4 0.01 SS,GRNGY,VF-CGR"PRED F-MGR,MOO-\.IELL SRTD,SBANG-SBRD,WELL CONS,POSS SID-ANK,GLAUC 1000 17.2 0.01 0.01 3DDO 16.3 0.00 0.00 122 6552.5 atm 22.7 0.87 SS,DKGRNGY, VF-CGR,PRED F-MGR,P-MOD SRTD,SBANG-SBRD,MOO-\.IELL CONS,POSS SID-ANK,GLAUC 10DO 22.0 0.33 D.55 3000 21.6 0.19 0.34 123 6553.7 atm 1D.6 D.60 SLTST,LTOLV-OLVGY,SDY,DNSE,POSS SID-ANK,3D-40%INTBD MDST,XLN PYR ** 1000 10.3 0.08 0.12 3000 9.9 0.01 0.03 124 6554.4 atm 11. 1 0.18 MDST,OLVBLK,SLTY,\.IELL CONS,30-40r~DD SDY SLTST,TR PYR,SDY BURS 1000 10.7 0.06 0.11 3000 10.2 0.01 0.03 125 6555_3 atm 11.5 0.36 MDST,GYBLK,SLTY,ABNT VFGR SD,\.IELL CONS,20-25%VFGR SDY BURS 1000 11.4 0.08 0.14 3000 11.0 0.01 0.03 126 6556.7 atm 10.6 0.13 MDST,DKGY-GYBLK,VSLTY,\.IELL CONS,15-20%VFGR SDY BURS 1000 10.6 0.03 0.06 3000 1D.2 0.00 0.02 128 6558.2 atm 10.5 0.11 MDST,DKGY,PRED ARG,SLTY.\.IELL CONS.20-25%VFGR SDY BURS atm(1) = measured Ka and por taken from conventional core analysis results. }.. 1- '" 1 t 1 L 1.. L L \. COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 Fi Ie No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TOT North Slope, Alaska Location : T14N'R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION -----.... ............... ... .... .... .. .. ...... ..... .. .... .. .. .. .. .............. --..---...........--.............. ........-....-...... --.......... ..--.. 1000 10.3 0.04 0.09 3000 9.8 0.01 0.03 129 6559.3 atm 12.9 0.39 SS,LTBRN,VFGR,V\.IELL SRTD,SBANG-RD,\.IELL CONS,30-40%GYBLK,SLTY,VMIC,INTBD MDST 1000 12.5 0.15 D.27 3000 12.1 0.08 0.16 130 6560.7 atm 22.1 112.04 SLTST,LTBRN,VF-FGR,PRED VFGR,V\.IELL SRTD,SBANG-SBRD,WELL CONS, 1000 22.0 100.94 108.63 3000 21.7 97.26 104.84 131 6561. 7 atm 26.1 207.37 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS 1000 26.0 181. 71 194.18 3000 25.7 175 . 04 187.08 132 6562.3 atm 26.5 174.18 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 1000 26.2 150.85 162.95 3000 25.8 144.63 156.26 133 6563.8 atm 27.3 225.34 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 1000 27.1 196.05 209.75 3000 26.7 187.81 201.02 134 6564.3 atm 27.7 323.07 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 1000 27_4 279.88 295.37 30DO 27.0 267.98 283.48 atm(1) measured Ka and Por taken from conventional core analysis results. r r r L"î .....--.-...... --- ----... 1 J 1 COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 File No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .. .... .... .. - .... .. .. .. .... ........ .. .. .. .. .. ...... .. .. .. .... .. .. .............. ....", --..........- --.... -"-"- - --..-..------------..-----. 135 6565.6 atm 28.3 292.81 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 1000 28.1 260.19 275.54 3000 27.7 249.84 265.04 136 6566.4 atm 26.9 333.86 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,SL FRI,TR CARB FRAGS 1000 26.7 30D.52 316.58 3000 26.4 291.43 306.13 137 6567.4 atm 22.3 100.87 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO-WELL CONS 1000 22_3 88_94 96.95 3000 22.0 86.09 93.84 138 6568.3 atm 19.7 31.09 SS,lTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,10% GYBLK,PRED ARG,INTBD MDST 1000 19.4 26.40 29.84 3000 19.0 25.41 28.72 139 6569.3 atm 14.9 1.00 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,10-15% PRED ARG,MIC,INTBD MDST 1000 14.9 0.57 0.92 3000 14.3 0.38 0.65 140 6570.6 atm 11.4 8.70 MDST,DKGY,PRED ARG,TR SD,\.IELL CONS,SL CALC,25% VFGR,SLTY,INTBD ss ** 1DOO 11.2 1.80 2.00 3000 10.7 0.29 0.37 141 6571.4 atm 18.7 17.79 SS,LTBRN,VFGR,SLTY.V\.IELL SRTD.SBRD-RD.\.IELL CONS.MNR MDY LAMS,TR PYR atm(1) = measured Ka and Por taken from conventional core analysis results. J ) L L t ). ~ ~ ~ COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 21-JUL-87 Fi Ie No. BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS, TOT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .... ...... .... .............. .... .. . .... .. ......-- ...... .... .. .. _....---- 00.. __.... _......._.......... ..--- .... .. .. .. .. ........ .. ... .. .. .. .... .. .. . 1000 18.6 13.97 16.49 3000 18.3 13.35 15.75 142 6572.6 atm 15.5 4.70 SS LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS 1000 15.2 2.13 2.80 30DO 14.8 1.39 1.89 143 6573.3 atm 13.8 1.83 MDST,DKGY,PRED SLTY,SDY,\.IELL CONS,SL CALC,30% VSDY,INTBD SLTST,DISM PYR ** 1000 13.4 0.56 0.75 3000 13.1 0.12 0.22 144 6574.3 atm 11.3 7.73 MDST,GYBLK,PRED ARG,\.IELL CONS,SL CALC,20-25% VFGR \.IELL SRTD,SBRD,INTBD SS ** 1000 11.0 1.82 1.97 3000 10.4 0.25 0.31 145 6575.2 atm 13.6 3.81 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,15% PRED ARG,INTBD MDST,TR PYR 1000 13.1 1.40 1.91 3000 12.7 0.84 1.20 147 6577 atm 17.9 7.94 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,10-15% INTBD MDST 1000 17.7 5.68 7.14 3000 17.2 5.24 6.61 CORE #2 6579.0 - 6618.5 201 6579.7 atm 15.3 6.24 SS,LTBRN,VF-FGR,PRED VFGR,SLTY.\.IELL SRTD.SBANG-SBRD.\.IELL CONS.30% PRED ARG,SLTY,INTBD MDST atm(1) = measured Ka and Por taken from conventional core analysis results. 1 J 1 J 1 J 1 ,~ ~ _. ~..-.......... ---.-.~ ~_.".__.-411111 ------- COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 File No. : BP-3-1221 KRU #3M-9 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .--......... ...... ........ ...... ...... .. ........- ............... ........--- ..............---......-..........- .. .. ...... .... .... .... ... .. .. .. .. .. .. .. ..... .. 1000 14.8 4.10 5.10 3000 14.4 3.47 4.32 202 6580.2 atm 21.2 19.52 SS,LTBRN,VfGR,MNR SlT,V\.IEll SRTD,SBRD-RD,WElL CONS,TR MDY LAMS 1000 20.9 15.61 18.36 3000 20.6 14.90 17.56 203 6581. 5 atm 24.4 86.31 SS,LTBRN,VfGR,MNR SlT,V\.IELL SRTD,SBRD-RD,WELL CONS,TR MDY LAMS 1000 24.1 75.89 83.20 3000 23.8 72.95 80.11 204 6582.8 atm 22.3 80.71 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD-UELL CONS,MNR MDY LAMS,TR PYR 1000 21.9 65.30 71.80 3000 21.6 62.71 69.06 205 6583.3 atm 24.4 134.11 SS,LTBRN,VFGR,V\.IELL SRTD,SBRD-RD,MOD CONS,MNR MDY LAM 1000 24_2 119.00 128.51 3000 23.8 114.85 124.03 206 6584.5 atm 23.5 40.32 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO-\.IELL CONS 1000 23.3 33.85 38.46 3000 22.9 32.43 36.91 207 6585.9 atm 2D.7 10.16 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOO-\.IELL CONS.MNR MDY LAMS 1000 20.4 7.98 9.89 3000 20.1 7.52 9.32 atm(1) = measured Ka and Par taken from conventional core analysis results. 1 r r t t 1- .. 1- 1- J- 1 L BP-3-1221 Anchorage TLS.TDT N C E S LAB 0 RAT 0 R COR E . File No Laboratory Analysts API No 21-JUL Kuparuk Bland Mud T14N-R8E 87 on ld on Date Format F Drlg Locat nc Kuparuk River Unit North Slope. Alaska Arco Alaska, KRU #3M-9 See 25 CMS-200 Overburden Pressure Analysis HOR Ka(est) (me!) HOR Kl (me!) POR % PRESSURE ovaD DEPTH (FT) SAMPLE NUMBER DESCRIPTION SS.LTBRN.VFGR,SLTY.V\.IELL SRTD.SBRO-RD,\.IELL CONS.35-40% SLTY,ARG.SL CALC.INTBD MDST 52.99 11.88 3.33 10.37 2.78 14.8 14.7 14. atm 1000 3000 6586.2 208 V\.IELL SRTD,SBRD-RD,\.IELL CONS,MNR MDY LAM SS.LTBRN,VFGR,SLTY 44.61 42.85 41. 14 23.1 22.7 22.4 atm 1000 300D 6587.5 209 38.01 36.47 INTBD MDST ** \.IELL CONS.SL CALC.20-30% PRED ARG.SLTY,SL CLAC SLTST,LTBRN.VSDY,MOD 2.32 0.84 0.22 13.9 13.4 13.1 atm 1000 3000 7 6588 210 66 13 O. o \.IELL CONS.SL CALC,20-30% PRED ARG.SLTY,INTBD MDST LTBRN.VSDY.MOD SLTST 11 0.92 0.64 0.58 0.39 15.8 16.0 15.5 atm 10DO 3000 6589.6 211 CONS,TR PYR V\.IELL SRTD,SBRD-RD,MOD SS LTBRN,VFGR.SLTY 88.94 86.37 83.02 24.6 24.6 24.2 atm 10DO 3000 6591.6 213 78.21 75.03 INTBD MDST ** V\.IELL SRTD,SBRD-RD.\.IELL CONS20-30% PRED ARG.SLTY SS.LTBRN,VFGR.SLTY 66.93 23.63 10.07 20.55 8.57 7.6 17.2 16.7 atm 1000 3000 6592.2 214 LAMS CONS.TR MDY SS,LTBRN,VFGR.SLTY.V\.IELL SRTD,SBRD-RD.MOD core analysis results 63.91 conventional from 24.8 Por taken atm Ka end 6593 measured 215 = atm( 1) r .~ r ------'" ~._---- 1 1 1 . 1 1 COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 File No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-2DO SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .. .. ........ .. ..-..--.... .... .... .... .. ..---- ............. .. .... .. .. .... .. ..-......- -............ ..-..-...... --.....----............ ---- --..... 1000 24.3 53.35 59.81 3000 24.D 50.87 57.09 216 6594. 1 atm 19.4 11. 89 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS,MNR LAM MDST,BIOTURB 1000 19.2 7.42 9.17 3000 18.8 5.77 7.23 217 6595.4 atm 21.9 108.17 SS,LTBRN,VFGR,MNR SLT,V\.IELL SRTD,SBRD-RD,MOD CONS,10-20%PRED ARG,INTBD MDST ** 1000 21.5 82.22 89.24 3000 21.1 73.06 79.50 218 6596.5 atm 23.1 53.22 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,SL CALC 1000 23.1 44.11 49.60 3000 22.7 42.10 47.45 219 6597.8 atm 25.8 101.36 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS,TR MDY LAMS 1000 25.5 85.35 93.99 3000 25.2 81.85 90.22 220 6598.5 atm 18.2 15.45 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS,30%PRED ARG SL CALC MDST,MNR PYR 1000 17.6 5.51 6.79 3000 17.1 2.34 3.08 221 6599.6 atm 13.4 0.64 MDST,GYBLK,PRED ARG,MNR SDY BURS.MNR INTBD SS 1000 12_9 0.39 0.58 3DOO 12.5 0.12 0.19 atm(1) measured Ka and por taken from conventional core analysis results. } l' ) 1 1 ~ L ~ . ~ COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 Fi Ie No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TOT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCRIPTION .. ........ .... .... .. ...... .. ....-..--- .. .... .. .. .. .. .... .. .. .. --....--- .... .... .. .. .. .. .. .. .. .. .. .. .. .. .. .. ..... ....-..-.... --.......... --.... ......... 222 6600.4 atm 16.3 18.52 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,WELL CONS,30-40r~RG,SLTY,SL CALC,INTBD MDST ** 1000 15.8 6.83 7.98 30DO 15.3 2.57 3.24 223 6601.6 atm 23.2 20.79 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,MOD CONS,MNR MDY LAMS 1000 22.8 13.79 16.68 3000 22.3 12.08 14.69 224 6602.4 atm 15.2 6.54 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RO,\.IELL CONS,30-40% PRED ARG,SL CALC,INTBO MDST 1000 14.6 3.01 3_68 3000 14.1 1.53 1.92 225 6603.5 atm 21.9 79.00 SS,LTBRN,VFGR,MNR SLT,V\.IELL SRTD,SBRD-RD,MOO-\.IELL CONS,SL CALC 1000 21.9 68.62 75.52 3000 21.6 66.16 72.80 226 6604.5 atm 17.6 5.12 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRO-RD,\.IELL CONS,15-20r~RED ARG MDST,XLN PYR 1000 17.4 3.29 4.23 3000 17.0 2.16 2.84 227 6605.9 atm 19.9 137.93 SS,LTBRN,VF-FGR,PRED VFGR,SLTY,\.IELL SRTD,SBRD-RD,MOD CONS,MNR BDD MDST ** 1000 19.9 44.41 54.53 3000 19.4 27.60 32.14 228 6606.6 atm 14.0 5.29 SLTST,OLVGY,ARG,SDY,\.IELL CONS,25-30%PRED SLTY.MIC.SL CALC,INTBD MDST,MNR CARB FRAGS atm(1) = measured Ka and Por taken from conventional core analysis results. í r _..J< ......__~--OIIII ----... ~_."..--II r 1 1 ] 1 COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21 - JUL - 87 File No. : BP-3-1221 KRU #3M-9 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (md) (md) DESCR I PTI ON ..... .. ..... ... ... ----.....- .. .. .......... .. -........ ......--.... .... ............ ....-... -- -- -- ---.. -......-.. ..-......-................. ....--- --.-......- 1000 13.2 1.48 1.99 3000 12.9 0.44 0.68 229 6607.6 atm 14.4 18.28 MDST,GYBLK,PRED ARG,MIC,TR SD,MNR SDY BURS,30-40%VFGR,SLTY,\.IELL CONS,INTBD SS 1DOO 13.9 4.55 4.9D 3000 13.6 0.66 0.80 230 6608.4 atm 20_4 7.05 SS,LTBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELl CONS,TR CARB FRAGS 1000 19.7 4.50 5.83 3000 19.5 3.90 5.12 231 6609.5 atm 16.0 19.64 SS,LT-MBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELL CONS,50% ARG,SDY,SL CALC, LAM MDST,PYR 1000 15.8 6.91 7.97 3000 15.3 2.63 3.23 232 6610.5 atm 16.2 10.24 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,50% ARG,SDY,SL CALC,BIOTURB MDST 1DOO 15.5 1.39 1.90 3000 14.9 0.34 0.51 233 6611.3 atm 13.1 8.17 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,\.IELL CONS SS,PYR,HVY BIOTURB ** 1000 12.6 2.11 2.36 3000 12.2 D.28 0.38 234 6612.4 atm 13.6 0.48 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR.SLTY.\.IELL CONS SS,PYR BUR,BIOTURB 1000 13_3 0.18 0.29 3000 13.0 D.05 0.09 atm(1) = measured Ka and Por taken from conventional core analysis results_ ] t t I I l - J' r 1- ~ ¡- COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 File No. : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS, TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-20D SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVaD % (md) (md) DESCRIPTION .. .. .... .. .. .. .............. .._-.--.. .. .. .. .. .. .. .... .. ...... .. .... .. ...... .. .. .. .. .... .. .. .. .... .. .. .. ..... ...... .... .. .. .. .. .. .... ...... .......... .... .. .. .... .... .... .. .. 235 6613.6 atm 14.5 2.56 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,\.IELL CONS SS,PYR,HVY BIOTURB ** 1000 14.2 1.09 1.42 3000 13.6 0.35 0.51 236 6614.7 atm 18.9 5.34 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,MNR BIOTURB MDST 1000 18.7 2.32 3.13 3000 18.2 1.41 2.D3 237 6615.9 atm 15.8 0.89 SS,LTBRN,VFGR,SLTY,V\.I~LL SRTD,SBRD-RD,50rRRED ARG,SDY,SL CALC,BIOTURB MDST 1000 15.5 0.45 0.66 3000 14.8 0.22 0.37 238 6616.5 atm 15.5 1.78 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,50%PRED ARG,SDY,SL CALC,BIOTURB MDST,MASS PYR 1000 15.3 0.69 1.01 3000 14.9 0.28 0.47 239 6617.6 atm 12.9 0.19 MDST,GYBLK,ARG,SDY,SL CALC,HVY BIOTURB,30-40%VFGR,SLTY,LAM SS 1000 12.7 0.05 0.10 3000 12.2 0.01 0.02 240 6618.3 atm 13.7 7.61 MDST,GYBLK,ARG,SDY,SL CALC,30-40%VFGR,SLTY,INTBD SS ** 1000 13_2 1. 74 2.01 3000 12.6 0.49 0.67 CORE #3 6637.0 . 6657.6 atm(1) = measured Ka and Por taken from conventional core analysis results. I t f -- _____'i ~.~.,_... I I r r l I 1 'I I COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 21-JUL-87 File No. BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVRD % (md) (md) DESCRIPTION .............. .. .... .. .. .... ...... .... .. .. .......... .............. ........ .. .. .. .. .. .. .. .. .. .......... ...... .. .. .. .. .. .. .. .. .... .. .. .. ...... .. .. .. ........ .... ... 301 6637.6 atm 14.4 2.06 MDST,GYBLK,PRED SLTY,ARG,SL CALC,\.IELL CONS,20%VFGR,SLTY,INTBD SS ** 1000 14_ 1 0.55 0.69 3000 13.8 0.14 0.22 303 6639.5 atm 12.5 0.D8 MDST,GYBLK,PRED ARG,SLTY,SL CALC,\.IELL CONS,MNR SDY BURS 1000 11.9 0.04 0.07 3000 11.5 0.00 0.02 304 6640.5 atm 15.3 14.81 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS ** 1000 14.5 2.98 3.35 3000 14.0 0.25 0.35 305 6641. 5 atm 13.3 8.36 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,20-30%LTBRN,VFGR,SLTY,INTBD SS,BIOTURB ** 1000 12.8 2.03 2.23 3000 12.3 0.26 0.33 306 6642.8 atm 13.9 34.47 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,20-30%LTBRN,VFGR,SLTY,INTBD SS,** 1000 13.6 5.77 6.17 3000 13.D 0.72 0.80 307 6643.7 atm 13.5 0.06 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS 1000 12.8 0.03 0.07 3000 12.4 0.01 0.02 311 6647.7 atm 13.7 0.53 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,10%LTBRN,VFGR,SDY LAMS.BIOTURB ** atm(1) = measured Ka and Por taken from conventional core analysis results. ---. ._~ I ~_.._~ J -r ... r , J t ~ 1 r r 1 COR E LAB 0 RAT 0 R E S N C Arco Alaska, Inc. Date : 21-JUL-87 File No. : BP-3-1221 KRU #3M-9 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No. : Overburden Pressure Analysis - CMS-200 SAMPLE DEPTH PRESSURE POR HOR Kl HOR Ka(est) NUMBER (FT) OVBD % (rnd) (00) DESCRIPTION -- - - - - .. - .. - .. -- - -- ........ ----- .. - .. .. - .. -.. - - .. - .. - - - .. - - .... -.. ---...... -..-.. -...... - -- - - -- 1000 12.9 0.19 0.34 3000 12.4 0.04 0.09 312 6648.7 atm 11.5 42.57 HDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELl CONS,5%LTBRN,VFGR,INTBD SS ** 1000 10.6 7.28 7.70 3000 9.9 0.66 0.71 314 6650.5 atm 13.3 0.04 MDST,GYBLK,PRED ARG, SLTY.SL CALC,\.IELL CONS.MNR SDY BD.BIOTURB 1000 12.6 0.02 0.04 3000 12 0.00 0.01 j- ~..... I i l_ I j '!""'" , '~ Full Diameter Core Analysis J ,~ ,_ J , :,- " 1 - - . )-:;. , - - -" r ,~ ........ ___.___h_.oi ,.A .....--.- } \ I } l } r t J I ) I I COR E LAB 0 RAT 0 R E S , N C Arco Alaska, Inc. Date : 21-JUL-87 Fi Ie No : BP-3-1221 KRU #3M-9 Formation: Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts : TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : Full Diameter Core Analysis SAMPLE DEPTH CONFINING HORIZ Ka - (MD) VERT He GRAIN NUMBER FEET PRESSURE MAX Ka 90 DEG Ka (MD) POR DEN M. DESCRIPTION --- .. .. .. .... ... .. ....- ....... .. ..- .. .. .. .... ----..- ---- - - - .... .. .......... .. .. .... .. .... .. .. .. .. .... .. .. .. -- 112 6542.5 400 0.716 D.510 0.010 7.6 2.97 Sltst,gygrn,abnt f-cgr sd,vdense,well cmtd,abnt poss sld-ank cmt,burrows,frac 1000 0.414 0.224 0.005 6.2 1500 0.139 0.075 0.004 5.9 2000 0.103 0.065 0.003 5_9 115 6545.45 400 0.492 0.477 0.230 17.2 2.92 SS,gy olvgrn,vf-cgr,pred f-mgr,mod-well srtd,well cons,poss sid-ank cmt,abnt glauc,burrows 1000 0.167 0.217 0.103 15.8 1500 0.135 0.156 0.094 15.5 2000 0.111 0.135 0.D84 15.2 118 6548.5 400 11. 167 2.810 40.430 16.4 3.07 SS,grn'gy,dusky yell,vf-cgr,pred f-cgr,p-mod srtd,w cons,poss sid-ank cmt,abnt glauc,fracs 1000 5.842 0.982 13.450 16.0 1500 4.585 0.487 7.943 15.9 2000 3.920 0.400 3.432 15.7 121 6551.3 400 2.715 1.524 0.510 19.1 3.06 SS,dusky yell grn,vf-cgr,pred f-mgr,mod-well srtd,w cons,poss sid-ank cmt,sl vuggy,abnt glauc,fracs 1000 1. 715 1. 030 0.440 18.6 1500 1. 333 0.921 0_390 17.8 2000 1.247 0.781 0.196 16.5 122 6552.1 400 1.559 1.309 1.150 22.8 2.99 SS,gy grn,vf-cgr,pred f-mgr,tr grnls.mod-well srtd,w cons,poss sid-ank cmt,vuggy,abnt glauc 1000 1.095 0.857 0.881 22.5 1500 0.976 0.703 0.742 22.4 2000 0.893 D.663 0.707 22.4 - l_ ¡" j 1- j ~- j ~- Detailed Lithological Sample Descriptions .~,..... ~ ,- "" - >- ;.... - - - ~ ~ Detailed Lithological Descriptions ~ i .... ~ Lithological descriptions were performed on plugs removed from KRU #3M-9 whole core samples submitted by Arco Alaska, Inc. These are conventional descriptions using a binocular microscope, hand lens, grain size scales, and a comparison chart for percentage estimation and roundness determination. The following format was used for describing these samples: -¡ Sandstones -, j -' j 1.) Color 2.) Grain size 3 .) Sorting 4.) Roundness 5.) Cementing and/or degree of consolidation 6.) Minerals present 7.) Percent (%) minor rock type 8.) Sedimentary structures or features 9.) Fracture descriptions 1 --i I Mudstones/Shales/siltstones 1.) Color 2.) Grain size modifiers 3.) cementing and/or degree of consolidation 4.) Accessory minerals 5.) Percen t (% ) minor rock type 6.) Sedimentary structures or features 7.) Fractures descriptions ,...- ~~ 1- J Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska ì~ 1~ 1 r 101 6531.3 102 6532.4 103 6533.5 104 6534.5 '.-- }..- 'r- J...-. 105 6535.4 106 6536.3 107 6537.2 '- 1.- 108 6538.4 '--- ;.... 109 6539.3 110 6540.3 111 6541.4 112 6542.5 Date : 21-Jul-87 Formation : Kuparuak Drlg F1d : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-122l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description siltstone - mdgy, arg, mnr sd, sl calc, well cons, tr mica. siltstone - mgy-mdgy, arg, abnt vfgr sd, sl calc, well cons, tr-1% mica, horz open frac. siltstone - mgy, arg, abnt vfgr sd, sl calc, well cons, 1-3% mica in places, some bioturb. siltstone - dkgy, varg, mnr sd, grades to a mdst, sl calc, well cons, 3-5% mica, tr glauc, mnr open to closed horz frac. siltstone - mdkgy, arg, mnr sd, sl calc, well cons, tr-1% mica, mnr carb foss, horz open frac. Siltstone - mdkgy, arg, abnt vfgr sd, grades to a It olvgy, vdnse, poss sid-ank cmt mdst. siltstone - mdkgy-dkgy, arg, mnr vf-fgr sd, sl calc, well cons, 1-3% scat mica, tr glauc, mnr horz hairline frac. siltstone - mdkgy, arg, tr f-mgr sd, well cons, tr mica, tr-1% glauc, abnt olvgy sid-ank cmtd burrows, horz hairline frac. Sandstone - It olvgy, vf-cgr, pred f-mgr, poorly- mod srtd, sbang-sbrd, well cons, poss sid-ank cmt, composed of 10-20% glauc, 10-15% qtz, 10% lith frags, 50-60% silt and cmtd mtrx, qtz ovgths. Sandstone - It olvgy, yell brn, vf-cgr, pred f- mgr, mod srtd, sbang, vwell cons, poss sid-ank cmt, composed of 30-40% glauc, 20-30% qtz, 5% silt, 40-50% cmt, qtz ovgths present. Sandstone - grngy, yell brn, vf-cgr, pred m-cgr, poorly-mod srtd, sbang-sbrd, well cons, composed of 50% glauc, 20-30% qtz, 20-30% slty mtrx, 10% dnse cmt, poss sid-ank cmt, qtz ovgths present. Mudstone - It-mbrn, abnt f-mgr sd, well cmtd, dnse, poss sid-ank cmt, 15% glauc, 5-10% qtz, qtz ovgths present. - '*' -. Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska .l. ,...:1.. 113 6543.5 ~ 114 6544.7 .-l .J. 115 6545.3 ~ 116 6546.0 ,.....l 117 6547.8 118 6548.3 ...-J 119 6549.8 120 6550.3 121 6551.2 Date : 21-Jul-87 Formation : Kuparuak Dr1g F1d : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-1221 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - dkgrn, mbrn, vf-cgr, pred f-cgr, well cmtd, dnse, poorly-mod srtd, sbang-sbrd, composed of 30-40%glauc, 20% qtz, 15-20% silt, 15-20% cmt, poss sid-ank cmt, qtz ovghts present. Sandstone - It-mbrn, grngy, vf-cgr, pred fgr, well cmtd, dnse, mod-well srtd, sbrd, composed of 30- 40% glauc, 15-20% qtz, 20-30% poss sid-ank cmt, mnr slt, qtz ovghts present. Sandstone - It-mbrn, grngy, vf-cgr, pred m-cgr, well cmtd, dnse, poorly-mod srtd, sbang-sbrd, composed of 30-40% glauc, 15-20% qtz, 30% poss sid-ank cmt, 5% slt, abnt qtz ovghts. Sandstone - dkgrn, 1tbrn, vf-cgr, pred m-cgr, mod- well cons, poorly-mod srtd, sbang-rd, composed of 40-50% glauc, 10-20% qtz, 30 % silt, 5-10% poss sid-ank cmt, qtz ovghts present. Sandstone - dkgrn, 1tbrn, vf-cgr, pred m-cgr, poorly-mod srtd, sbang-rd, sl fri-mod cons, composed of 50% glauc, 10-20% qtz, 10% poss sid- ank cmt, 5-10% silt, qtz ovghts present. Sandstone - 1tbrn, grn, vf-cgr, pred f-mgr, mod- well srtd, sbang-rd, well cons, composed of 30% glauc, 10-15% qtz, 30-40% poss sid-ank cmt, 3-5% silt, qtz ovghts present. Sandstone - dkgrn, mbrn, vf-cgr, pred m-cgr, mod srtd, sbang-rd, well cons, composed of 25-30% glauc, 15-20% qtz, 30% silt, 10% poss sid-ank cmt, abnt qtz ovgths. Sandstone - dkgrn, mbrn, vf-cgr, pred f-mgr, mod- well srtd, sbang-sbrd, well cons, poss sid-ank cmt, composed of 30-35% glauc, 15-20% qtz, 30-40% silt, qtz ovgths present. Sandstone - grngy, vf-cgr, pred f-mgr, mod-well srtd, sbang-rd, well cons, poss sid-ank cmt, composed of 20% glauc, 10-15% qtz, 60% mtx cmt, 5% silt, qtz ovghts present. -- ,..... ;-... Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska ,1-- ~ 122 6552.5 ,.3- 123 6553.7 ..... 124 6554.4 ~ 125 6555.3 ~ ,...l.. 1266556.7 ~ 127 6557.9 ....:>... 128 6558.2 ~ 129 6559.3 130 6560.7 131 6561.7 132 6562.3 Date : 2l-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-l22l Lab : Anchorage Geologist : G. crosky Detailed Lithological Description Sandstone - dkgrn gy, vf-cgr, pred f-mgr, poorly- mod srtd, sbang-sbrd, mod-well cons, poss sid-ank cmt, composed of 30-50% glauc, 10-20% qtz, 30-50% silt and cmt, qtz ovghts present. siltstone - It olvgy, 30-40% olvgy, sl calc, intbd mdst, sltst is sdy, vdnse, poss sid-ank cmtd, xln pyr blebs present, horz open frac. Mudstone - olv blk, 30-40% olvgy, sdy, bdd sltst, mdst is slty, well cons, tr mica, tr dism pyr, some sdy burrows. Mudstone - gyblk, 20-25% vfgr, sdy burrows, mdst is slty, well cons, with abnt vfgr sd, 1-3% mica, bioturb present. Mudstone - dkgy-gyb'lk, 15-20% vfgr sdy burrows, mdst is vslty, well cons, 3-5% mica, bioturb present. Mudstone - dkgy-gyblk, 15-20% vfgr sdy burrows, mdst is pred arg, slty, well cons, 3-5% mica, tr pyr, bioturb present. Mudstone - dkgy, 20-25% vfgr sdy burrows, mdst is pred arg, slty well cons, 3-5% mica. Sandstone - ltbrn, 30-40% gyblk, slty, sdy, vmic, intbd mdst, ss is vfgr, vwell srtd, sbang-rd, well cons, composed of 50-70% qtz, 30-40% silt, bioturb present. siltstone - ltbrn, vf-fgr, pred vfgr, vwell srtd, sbang-sbrd, well cons, composed of 85-90% qtz, 10- 15% silt, tr mica, tr mdy lam. Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, mod cons, composed of 80-90% qtz, 10-20% silt, tr-l% mica. Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20& silt, 1% mica, tr carb frags. - ;-- ;-- Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska r ~ 133 6563.8 ..->-- 134 6564.3 -'" 135 6565.6 136 6566.4 ,...L. 137 6567.4 .... 138 6568.3 - 139 6569.3 ~ 140 6570.6 141 6571.4 - 142 6572.6 Date : 2l-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-l22l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - ltbrn vfgr, vwell srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1% mica, tr carb frags. Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1% mica, tr carb frags. Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, sl fri, composed of 80-90% qtz, 10-20% silt, 1% mica, tr carb frags. Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, sl fri, composed of 80-90% qtz,10-20% silt, 1% mica, tr carb frags. Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, mod- well cons, composed of 70-80% qtz, 20-30% silt, 1% mica, tr carb frags. Sandstone - 1tbrn, 10% gyb1k, pred arg, thn1y intbd mdst, ss is vfgr, slty, vwel1 srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt. Sandstone - 1tbrn, 10-15% dkgy, pred arg, mic, thnly intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz,20-30% silt, grades to sltst in places, some bioturb. Mudstone - dkgy, 25% ltbrn, vfgr, slty, thn1y intbd ss, mdst is pred arg, tr sd, well cons, sl calc, horz open frac. Sandstone - 1tbrn, 3-5% gyb1k, pred arg, mdst lams, ss is vfr, slty, vwe11 srtd, sbrd-rd, well cons, composed of 60-80% qtz, 20-40% silt, 1% mica, tr pyr. Sandstone - 1tbrn, 40% dkgy, pred arg, slty, well cons, sl calc, intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 60-80% qtz, 20-40% silt, 1-3% mica, horz open frac present. 1,- Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska j J- " j 143 6573.3 ~ , 144 6574.3 ':-- 145 6575.2 }--- 146 6576.2 147 6577.0 - 201 6579.7 , - 202 6580.2 - 203 6581.5 - 204 6582.8 Date : 21-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-1221 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Mudstone - dkgy, 30% ltbrn, vsdy, intbd sltst, mdst is pred slty and sdy, well cons, sl calc, 3- 5% dism pyr, 1% mica, horz open frac present. Mudstone - gyblk, 20-25% ltbrn, vfgr, well srtd, well cons, intbd ss, composed pred of qtz, mdst is pred arg, well cons, sl calc, 1% mica, horz open frac present. Sandstone - ltbrn, 15% dkgy, pred arg, intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt, 1% mica, tr pyre Sandstone - Itbrn, 10% dkgy, pred arg, thnly intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt, tr mica, tr vthn lam pyr in mdst. Sandstone - ltbrn, 10-15% dkgy, pred arg, thnly intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt, tr mica. Sandstone - Itbrn, 30% gyblk, pred arg, slty, thnly intbd mdst, ss is vfgr, slty, well srtd, sbang-sbrd, well cons, composed of 60-80% qtz, 20- 40% silt, 1-3% mica near mdst, 1% carb frags in mdst. Sandstone - ltbrn, vfgr, mnr sIt, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt, 1-3% mica, tr mdy lams. Sandstone - ltbrn, vfgr, mnr sIt, vwell srtd, sbrd-rd, well cons, composed of 80-90% qtz, 10-20% silt, 1-3% mica, tr mdy lams. Sandstone - ltbrn, 5-10% gyblk, pred arg, bdd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, mod- well cons, composed of 70-90% qtz, 10-30% silt, 1% mica, tr pyr. ~ ,~ Arco Alaska, Inc. KRU #3M-9 Kuparuk River unit North Slope, Alaska ..1 ..L 205 6583.3 J 206 6584.5 - 207 6585.9 -1 208 6586.2 .......1 - 209 6587.5 - 210 6588.7 1 - ,...' 211 6589.6 !- 212 6590.6 - 213 6591.5 - 214 6592.2 Date : 2l-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-l22l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - ltbrn, vfgr, vwell srtd, sbrd-rd, mod- well cons, composed of 80-90% qtz, 10-20% silt, 1- 3% mica, mnr thn lam mdst. Sandstone - ltbrn, vfgr, slty, vwell srtd, sbrd- rd, mod-well cons, composed of 60-80% qtz, 20-40% silt, 1-3% mica. Sandstone - ltbrn, vfgr, slty, vwell srtd, sbrd- rd, mod-well cons, composed of 50-70% qtz, 30-50% silt, 1-3% mica, mnr mdy lams. Sandstone - ltbrn, 35-40% gyblk, slty, arg, sl calc, intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 40-60% qtz, 30-50% silt, 5-7% mica, 1-3% carb frags, bed parallel break. Sandstone - ltbrn, slty, vwell srtd, sbrd-rd, well cons, composed of 70-90% qtz, 10-30% silt, 3-5% mica, mnr mdy lam. siltstone - ltbrn, 20-30% gyblk, pred arg, slty, sl clac, thnly intbd mdst, sltst is vsdy, mod-well cons, sl calc, grades to a vfgr slty ss, 7-10% mica, tr pyr, mnr horz open frac. siltstone - ltbrn, 20-30% gyblk, pred arg, slty, sl calc, thnly intbd mdst, sltst is vsdy, mod-well cons, grades to a vfgr, slty ss, bioturb. siltstone - olvgy, 15-20% gyblk, pred arg, slty, well cons, sl calc, bdd mdst, 10% ltbrn, vfgr, slty , inbtd ss, sltst is pred sIt, mnr sd, sl calc, well cons, poss mnr sid-ank cmt, horz open frac. Sandstone - ltbrn, vfgr, slty, vwell srtd, sbrd- rd, mod cons, composed of 70-90% qtz, 10-30% silt, 3-5% mica, tr pyre Sandstone - ltbrn, 20-30% gyblk, pred arg, slty, sl calc, inbtd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 60-80% qtz, 20-40% silt, 1-3% mica, 1% pyr blebs, horz open frac. - 1-- ~ Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska 1-- :L- 215 6593.0 .:L- 216 6594.1 ~ 217 6595.4 .1- .L 218 6596.5 219 6597.8 220 6598.5 - 221 6599.6 222 6600.4 223 6601.6 224 6602.4 Date : 21-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-1221 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - ltbrn, vfgr, slty, vwell srtd, sbrd- rd, mod cons, composed of 70-90% qtz, 10-30% silt, 1-3% mica in places, tr mdy lams. Sandstone - ltbrn, vfgr, slty, vwel1 srtd, sbrd- rd, mos cons, composed of 70-90% qtz, 10-30% silt, 1-3% mica, 7% mica in places, tr pyr, mdst lams, bioturb in mdst. Sandstone - ltbrn, 10-20% gyblk, pred arg, sl calc, intbd mdst, ss is vfgr, mnr sIt, vwell srtd, sbrd-rd, mod cons, composed of 70-90% qtz, 10-30% silt, 3-5%mica, 1-3% pyr, horz open frac. Sandstone - ltbrn, vfgr, slty, vwel1 srtd, sbrd- rd, well cons, sl calc, composed of 60-80% qtz, 20-35% silt, 3-5% mica Sandstone - ltbrn, vfgr, slty, vwell srtd, sbrd- rd, mod cons, composed of 70-90% qtz, 10-30% silt, 7-10% mica in places, tr mdy lams. Sandstone - 1tbrn, 30% gyb1k, pred arg, sl calc, bdd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, mod cons, composed of 60-80% qtz, 20-40% silt, 1% mica, 1% pyr blebs in mdst, bioturb. Mudstone - gyblk, 5-10% ltbrn, vfgr, slty, thnly intbd ss, mdst is pred arg, 1-3% mica, tr pyr, mnr sdy burrows, horz hairline frac. Sandstone - 1tbrn, 30-40% gyblk, arg, slty, sl calc, mic, intbd mdst, ss is vfgr, slty, vwe1l srtd, sbrd-rd, well cons, composed of 60-80% qtz, 20-40% silt, tr mica, mnr pyr and carb frags in mdst, mnr horz frac. Sandstone - 1tbrn, vfgr, slty, vwe1l srtd, sbrd- rd, mod cons, composed of 70-90% qtz, 10-30% silt, 1% mica, mnr mdy lams. Sandstone - 1tbrn, 30-40% gyb1k, pred arg, well cons, sl calc, intbd mdst, ss is vfgr, slty, vwe1l srtd, sbrd-rd, well cons, composed of 60-80% qtz, 20-40% silt, tr pyr, bioturb. Arco Alaska, Inc. KRU #3M-9 Kuparuk River unit North Slope, Alaska "- ~ 225 6603.5 .0- 226 6604.5 ->- 227 6605.9 .L- -'- 228 6606.6 - 229 6607.6 - 230 6608.4 , 231 6609.5 232 6610.5 233 6611.3 Date : 2l-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-l22l Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - ltbrn, vfgr, mnr sIt, vwell srtd, sbrd-rd, mod-well cons, sl calc, composed of 80- 90% qtz, 10-20% silt, tr mica. Sandstone - ltbrn, 15-20% gyblk, pred arg, thnly intbd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt, 1- 3% mica, 1-3% xln pyr. Sandstone - ltbrn, 5-10% gyblk, pred arg, mic, bdd mdst, ss is vfgr, slty, well srtd, sbrd-rd, mod cons, composed of 60-80% qtz, 20-40% silt, 1-3% mica, 1-3% carb frags, bed parallel break. siltstone - olvgy, mbrn, 25-30% gyblk, pred slty, mic, sl calc, intbd mdst, sltst is arg, slty, well cons, containing 5-7% mica, 1-3% carb frags. Mudstone - gyblk, 30-40% ltbrn, vfgr, slty, vwell srtd, sbrd-rd, well cons, intbd ss, mdst is pred arg, mic, tr sd, 1% mica, 1-2% xln pyr, mnr sdy burrows, horz open frac. Sandstone - ltbrn, vfgr, slty, vwell srtd, sbrd- rd, well cons, composed of 70-90% qtz, 10-30% silt, tr mica, tr carb frags, mnr indistinct mdy lams. Sandstone - It-mbrn, 50% gyblk, pred arg, sdy, sl clac, wvy lam mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 80-90% qtz, 10-20% silt, tr carb frags, 1-3% mica in mdst, pyr bleb present, horz open frac. Sandstone - It-mbrn, 50% gyblk, pred arg, sdy, sl calc, bioturb, mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-90% qtz, 10-30% silt, 1% mica, 3-7% mica in places. Mudstone - gyblk, 40-50% ltbrn, vfgr, slty, well c~ns ss, composed pred of qtz, mdst is pred arg, sdy, sl calc, with 1-2% mica, mnr pyr bleb, mnr carb lam and abnt bioturb, horz open to closed frac. .... ..L. Arco Alaska, Inc. KRU #3M-9 Kuparuk River unit North Slope, Alaska ..l- ....:L 234 6612.4 - 235 6613.6 .J 236 6614.7 -- 237 6615.8 238 6616.5 239 6617.6 240 6618.3 301 6637.6 302 6638.5 303 6639.5 Date : 21-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : T14N-R8E-Sec 25 File : BP-3-1221 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Mudstone - gyblk, 40-50% ltbrn, vfgr, slty, well cons ss, composed pred of qtz, mdst is pred arg, sdy, sl calc, with 1-2% mica, pyr filled burrow, and abnt bioturb. Mudstone - 40-50% ltbrn vfgr, slty, well cons ss, composed pred of qtz, mdst is pred arg, sdy, sl calc, with 1-2% mica, 1% carb frags, abnt bioturb, xln pyr, horz open frac. Sandstone - ltbrn, 5-10% gyblk pred arg, sdy, bioturb mdst, ss is vfgr, slty, vwell srtd, sbrd- rd, well cons, composed of 70-80% qtz, 20-30% silt, 1% mica. Sandstone - ltbrn, 50% gyblk, pred arg, sdy Is calc, mic, bioturb mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, weli cons, composed of 70-80% qtz, 20-30% silt, 1% mica, some carb material. Sandstone - ltbrn, 50% gyblk, pred arg, sdy, sl calc, mic, bioturb mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-80% qtz, 20-30% silt, 1% mica, massive pyr, mnr carb lam. Mudstone - gyblk, 30-40% ltbrn, vfgr, slty, vwell srtd, sbrd-rd, well cons, lam ss, mdst is pred arg, sdy, sl calc, mic, bioturb. Mudstone - gyb1k, 10-20% ltbrn, vfgr, slty, vwe11 srtd, sbrd-rd, well cons, intbd ss, mdst is pred arg, sdy, sl calc, mic, horz open frac. Mudstone - gyblk, 20% ltbrn, vfgr, slty, well cons ss, mdst is pred slty, arg, sl calc, well cons, pyr bleb, mnr bioturb, horz open to closed frac. Sandstone - ltbrn, 30-40% gyblk, slty, sdy, sl calc, bdd mdst, ss is vfgr, slty, vwell srtd, sbrd-rd, well cons, composed of 70-90% qtz, 10-30% silt, 1% mica, bed parallel break. Mudstone - gyblk, pred arg, slty, sl calc, well cons, 5-7% vfgr sdy burrows. .... J... Arco Alaska, Inc. KRU #3M-9 Kuparuk River Unit North Slope, Alaska ...L ...I. 304 6640.5 , 305 6641.5 -1 306 6642.8 ...I. ~ 307 6643.7 308 6644.5 309 6645.3 310 6646.3 311 6647.7 -' 312 6648.7 313 6649.6 314 6650.5 Date : 21-Jul-87 Formation : Kuparuak Drlg Fld : Bland Mud Location : TI4N-R8E-Sec 25 File : BP-3-1221 Lab : Anchorage Geologist : G. Crosky Detailed Lithological Description Sandstone - ltbrn, 50% gyblk, pred arg, mic, abnt bioturb mdst, ss is vfgr, slty, vwell srtd, sbrd- rd, well cons, composed of 70-90% qtz, 10-30% silt, horz open frac. Mudstone - gyblk, 20-30% ltbrn, vfgr, slty, intbd ss, mdst is pred arg, slty, sl calc, well cons, bioturb, horz open frac. Mudstone - gyblk, 20-30% ltbrn, vfgr, slty, intbd ss, 'mdst is pred arg, slty, sl calc, well cons, bed parallel break. Mudstone - gyblk, pred arg, slty, sl cal c, well cons, 5% sdy lams. Mudstone - gyblk, pred arg, sl ty, sl calc, well cons, bioturb, 5% sdy lams. Mudstone - gyblk, pred arg, slty, sl cal c, well cons, bioturb, 5% sdt lams. Mudstone - gyblk, pred arg, slty, sl calc, well cons, 5% sdy lams, horz open frac. Mudstone - gyblk, 10% sdy lams, mdst is pred arg, slty, sl calc, well cons, bioturb, sub horz open frac. Mudstone - gyblk, pred arg, slty, sl calc, well cons, 5% bdd ss, horz open frac. Mudstone - gyblk, 10% wht, vfgr, bdd ss, mdst is pred arg, slty, sl calc, well cons. Mudstone - gyblk, pred arg, slty, sl calc, well cons, bioturb, mnr bdd sd. , - .l Littan Core Lab l ì ...l. ..l ..1. ì 8005 Schoon Street Anchorage, Alaska 99518· 3045 (907) 349- 3541 SECTION C Core Analysis Results - Graphic Data Arco Alaska, Inc. KRU :#3M-9 Kuparuk Formation Kuparuk River unit North Slope, Alaska ...1 Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518· 3045 (9071349·3541 J.. ..1 .-1 SECTION D ..1 APPENDICES .....l ..J. Arco Alaska, Inc. KRU :#3M-9 Kuparuk Formation Kuparuk River Unit North Slope, Alaska .-l i - Gravity API vs. Formation ndex Kuparuk I I Refractive E I ~. f. -~=--~'K~ i , ¡ ¡ ¡ - ¡ I I- i '" -I "- I "" -+- ~ I '1:.~ --t- ~ I - "-~ -I ~.. - t E -+ 30 29 28 27 26 25 24- 23 22 21 20 19 18 17 16 15 14 13 12 "" rz. . 1:11 G) Q o (0 '-' ~ +I or4 > \If H Ô Þ04 ~ 1.53 1.51 (Retorted Oil) Index 1.4-9 Refractive 1.47 - .L L Appendix B Prudhoe Bay oil Correction Table .l... oil Base and Water Base Cores ..L Observed Correction Tr- 0.05 Tr+ 0.10 .L 0.10 0.25 0.20 0.35 0.30 0.45 ...L 0.40 0.60 0.50 0.70 0.60 0.80 1- 0.70 0.90 0.80 1. 05 0.90 1.25 1. 00 1.40 , >1. 00 +0.4 , .......- - I, .t: !1~ '- , j L. SPE 15185 j '¡''',:'o,: ¡,: ....~ . ""','. '>;{3-~;.'~: ':',,;' "..~, . ·'~"'·('-.t',~ "¡',.". '.. . ;..';.:'~ S':''-'' ...". . .c/·'·······.p·:..'·'·'·"'·"·······E".".. ",' ..,~o/'. " . .. o' .. o ._ .. SocIetu or PetroIeLßI Et IQMIOOo 'G L Automated Core Measurement System for Enhanced Core Data at Overburden Conditions \- by O.K. Keelan, Core Laboratories Inc. SPE Member L Copyright 1986. Society ot Petroleum Engineers ThiS paper was prepared tor presentation at me Rocky Mountain Regional Meellng of I"" Society of Petroleum Engineers held on 8ill1ngs. MT, May 19-21. 1986, This paper was selected ior presentahon by an SPE Program Committee following rev.e. of In1orma1lon contamed in an abstract submitted by the author(s). Contents of the paper. as presented. have not been reviewed by the SocIety ct Petroleum Engineers and are subjeC1 10 correction by the author(s), The ma1eroal, as presented. does not necessarily reflect any position of the ~ of Petroleum Engineers, ils offICers. or members, Papers presented at SPE meetings are subject to publication ,eview by Editorial Committees Of _ Society of Petroleum EngIneers, Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be COpied. The abs!(3C1 should contain conspicuous acknowledgment 01 where and by whom the paper is presented. W,ite Publicatoons Manager. SPE. P,O, Box 833836, RocMroson. TX 75083-3836. Telex. 730989. SPEOAL. '- , ABSTRACT L A ne~ automated, computer-directed, core me;lS- urement system ,furnishes porosity, air permeability, equivalent non-reactive liquid,permeability (Klinken- berg), and Forcheimer (turbulence) factor at program- mable, sequential overburden pressures from 500 to 10,000 psi. The system is accurate, precise, and flexible and furnishes enhanced routine core data. Capabilities and limitations of the system are dis- cussed. Data are presented for selected rock types and a graphical technique is proposed to relate the system measured porosity and permeability values to uniaxial strain conditions. 1 INTRODUCTION - Formations deposited in ancient times were buried under successive layers of sediments, re'sulting in increasing depth of burial and subsequent compression of the rock pore spaces. Core cutting and retrieval relieves the reservoir formation pressure and removes the ~eight of the overburden deposits, allowing expan- sion of the core. Consequently, routinely measured porosity and permeability values are higher than those present in the reservoir. Adjustments to routine data have often been made by applying factors developed by simulating reservoir overburden stress conditions on representative but limited suites of cores from the formations of inter- est. Even then, air permeability data were often measured at low mean pressure in the core sample, resulting in gaB Blippage and air permeability values that were higher than at reservoir pressures. Cor- rections for this slippage effect were often applied by using published correlations for uniform sand- stones, and ignored in more heterogeneous carbonates where correlations were not valid. Low permeability References and il1u8tfå,t~.cm."tend of paper . formations have focused attention on the importance of both slippage correction and overburden effects.1,2 The new automated, core measurement system offers a first-time capability to routinely and economically measure porosity and permeability at simulated over- burden stress conditions, while simultaneously meas- uring the gas slippage corrected equivalent liquid permeability as well as the Forcheimer' turbulence factor required to predict flow in high-rate wells. W'hen placed in the calibration mode, the system is self-calibrating with self-diagnosis of valve leak problems if present. Core sequencing and movement into a hydrostatic core holder, application of up to eight selected sequential overburden pressure meas- urements, interim dat3 display while testing, calcu- lations and final data presentation are performed automatically while under IBM PC control. Pore volume is directly measured by helium injection into the pore space, while permeability and turbulence factor are determined during unstead)-state flow utilizing principles described by Jones. REVIEW OF FACTORS LIMITING ROUTINE CORE DATA Cas Slippage Effects Gas slippage eff~cts were documented by Klinken- berg4. and the effect he observed is illustrated on Fig. 1. Unlike non-reactive liquid flo~, where permeabi lity of a rock is a constant, gas perme- ability is seen to vary linearly with the reciprocal mean pressure in the core. Mean pressure is defined as the average of the up-stream and down-stream pressure of the rock sample during flow. It 1s analogous to the foraation pre8sure. At increasing mean pressures the gas molecules are forced closer together such that the gas becomes more dense, behaves more like a liquid, and has a lower measured perme- ability. At infinite mean preS8ure, the· reciprocal of Pmefn equal. zero and the gas,. is :visualized 88 hav ng condensed .nd as flowing like ané9uivalent inert liquid. . 155 . ,", ';:-';':;¿"'~:"; :.- "~')-~:\1.-:}..;;.~.- ,", ,. .,-, ,.' ,',: .~;, :_'.'7'. '.' ;~:.-.'." . -:'_:;:::-::" 2 SPE 15185 )t., .] "':2 1 J: >{ -{ .~ AUTOMATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS Reservoir Turbulence (Kinetic) Effects ..L ..L. Routine permeability data are measured using air at low mean pressure in the core sample. In contrast, gas reservoirs described as "low pressure" are at high enough mean pressure whereby the reservoir gas permeability approaches the equivalent liquid perme- ability from laboratory tests. Results of steady- state flow measurements seen in Fig. 1 require deter- minations at several mean pressures and then extrapo- lation of the data to infinite mean pressure. T,hese tests are time consuming and expensive and have not been routinely determined despite the more representa- tive reservoir permeability value resulting when the slip-corrected Klinkenberg value is used. .1... ..J.. ...J.. Klinkenberg also found that different gasses have different permeability at the same mean pressure bllt all extrapolate to the same equivalent liquid perm~- ability. This results in different slopes of the gas permeability versus reciprocal of mean pressure lines. This has importance in the autom.,~ted core measurement system which utilizes helium as the flow- ing gas, and which determines both the slip-corrected permeahility and a helium slippage factor (b) propor- tional to slope. The need exists to calculate an equivalent air permeabflity to serve as a common tie point to previously measured core data where nitrogen or air has been used as the flowing gas. This calcu- lation utilizes the helium determined (b) value, and adjusts it to arrive at a slippage factor of (b) for air. Air permeability at commonly used laboratory instrument mean pressure conditions is then calculated using the equation shown on Fig. 1. ....1. ...1.. Overburden Effects - Increasing depth of burial results in increasing weight of overburden sediments tending to compress the formation rock. An overburden gradient of I psi per foot of depth is commonly assumed, although a bulk. densit\' log can be integrated to compute this overburden ~alue.5,6 The difference between the over- burden pressure and the formation pressure increases with depth as illustrated on Fig. 2, and the dif- ference is commonly referred to as the effective or net overburden pressure (NOB). When formation pres- sure is unk.nown, it is often calculated by multiplying an assumed salt water gradient of approximately 0.5 psi per foot times the formation depth. The differ- ence of th€se gradients times depth yields the NOB. It is this NOB that primarily controls formation compaction stress, and it is this NOB that is relieved during the coring process and that is re-applied and simulated in the core measurement system. - - Re-application of net overburden pressures on core samples allows adjustment of routine non-stressed core porosity and permeability data to initial reser- voit net overburd€n conditions. It also allows both porosity and permeability reduction to be moni tared as reservoi r pressure declines with a resul t'1nt in- crease in net overburden. Normalized data illus- trating these changes in porosity and per;neabil1ty were generated from measurements on the core measure- ment system and are illustrated on Fig. 3. Great diversity is observed, and different formations exhib- it widely differing sensitivity to overburden stress. Estimates of reservoir flow can be aade using Darcy equations and core permeabilities corrected for slippage, overburden and relative peraeability effects. However, well test data and laboratory data show that above a critical rate Darcy's equation does not describe fluid or gas flow, but predicts higher flow rates than the wells can deliver. The lower flow rate of the well has been attributed to a:: effect referred to as turbulence, inertial, or kinetic energy losses. This effect has been studied h, Forcheimer and others7, anò it can be çuantifie: by core measurements. and includeò as an adtiit10na: term in the Darcy equation. '." The turbulence factor has been used to descri ~ pressure losses and to calculate maximum :'10....· ra:~ eJuring non-Darcy turbulent flow into a '-"¿II hor". I t has been combi ned wi th flowing well ar." 1"5 is t ~ predict the economic effects of perforating conditio~~ as well as the nur.¡ber and size of perfora:ions rE- quired to maximize production8. The effect of turbulence on flow is illustrate;: on Fig. 4 and the Darcy equation modified for tubü- lence is shown. The zero turbulence con¿ition . < illustrated by tòe straight line, where flow rat~ per unit cross-sectional area increases in a lineê~ fashion as the pressure drop per unit le:1gth i:-:- creases. Above a critical rate the relationship :'.s no longer linea r, and an increase in pressure di f- ferential results in less flow than predicted by Darcy flow. The excess pressure drop is òue tv turbulent, non-laminar flow, and can be calculateè by the product of the turbulence factor (Beta) times the density of the flowing fluid and the square 0:' the veloc1ty.9 j j I î ¡ Relative Permeability Effects Routine core analysis permeability data are ger.- erated with a single non-reactive fluid (gas) i:: the pores of a cleaned and dried core. In the reser- voir both hydrocarbons and interstitial vater are present. The water sometimes reacts with the rock. or occupies pore space such that it interferes with hydrocarbon flow, resulting in a lower reservoir permeability to the hydrocarbon than measured during routine core analysis on the clean and dry core. 1:: many reservoirs of moderate permeability with no rock-water reaction and sufficient height above water to be at a minimum irreducible water, the intersti- tial water does not mOV€ and has a negligible effect on hydrocarbon permeability reduction. Routine cor~ permeability data corrected for slippage will approxi- mate reservoir values in this case. In other situ- ations, water in the reservoir may reduce hy¿rocarb0~ permeability and dry core Klinkenberg data ·...ill ~ optimistically high. THE CORE MEASUREMENT SYSTEl1 i 1 ~ ~ The core measurement system routinely and rapidly overcomes all of the factors limiting conventiona: core data except for the relative permeability effects due to the presence of 1 rreduci ble water. This ca:. " } '¡ 156 ¡. !. \ ;:....- !:~ \- 1 ( ,- j SPE, 15185' "," , '~':,(>:,'r' 'DareJ{. Ke,elan .,.' ......,.....,.. 3 -.,~~-~..~.;.~'~. 'h... '. also beaddre.aed .in ,the .ystemwith acfdit10aal effort and.1sd1scussed under Core Saturation Cond1tionthÀt follows. Equipment Description The system is packaged in a compact desk top, front loading chassis approximately 28" wide by 30" high and IS" deep containing back plate connections for helium, nitrogen, vacuum, power and data communi- cations. Major components include (1) an eighteen- sample carousel core plug holder, (2) an automatic load and unload system, (3) hydrostatic core holder and pressure application assembly, (4) helium volume reference cells and pressure sensing devices, and (5) computer hardware and software. 1- ij 1- ,- Equipment Operation l- The system is self-calibrating when the calibra- tion mode is specified, and utilizes stainless steel center-bored cylindrical standards of known pore vol- ume. It is also self-diagnostic, checking for proper valve operation and system leaks if present. Samples are manually loaded into individually numbered posi- tions within the carousel, which is then positioned in the chassis. Sample identification, length and area, for example, are required input to the IBM PC, and grain volume, bulk volume and weight of the sample are optional. Up to eight overburden pres- sures can be designated, which may include both sequential increasing and then decreasing overburden values. ,- - At test ini tia tion, Posi tion 1 of the carousel is automatically rotated into position, a vacuum is pulled on the rubber boet within the core holder, and a vertically upward moving hydraulic ram advances and lifts the sample into the rubber boot. After sample insertion, the vacuum is released and the minimum programmed hydrostatic confining stress is applied to the core. A quick permeability approxima- tion measurement is then made for selection of both the upstream volume and pressure to be used during subsequent permeability measurements. , - Pore volume is then determined by expansion of helium into the core sample from a known volume source at approximately 240 psi. At pressure equili- brium, Boyle' s Law is used to compute pore volume. The difference between the confining stress and the equilibrium pore pressure is the net confining stress. During this operation the overburden and internal pore pressures are monitored with digital readout on the chassis, and by a real time visual display of the plot of pore pressure versus time. Permeability is then measured by flowing helium from the previously selec ted volume reference cell at the selected pressure through the core. The downstream end of the core is maintained at atmos- pheric pressure. The upstream pressure decline is monitored in real time, and is observed by digital readout and visually displayed in either graphical or tabular form. The difference between the confin- ing stre8S and the mean pore pressure during flow is the net confining stress. Unsteady-state equations developed by Jone8 are u8ed to calculate the Klinkenberg slip corrected pel"llleab 11ity" the hel1umal1p . factor. . and, the For- cheimer turbulence factor.3 Air permeability 18 then calculated as a base to be compared with other non- Klinkenberg measured' core information from the field. The next pre-programmed overburden pressure is then applied' to the sample and measurements are repeated. After the last permeability measurement is completed fòr Sample II, the final selected overburden pressure is released, vacuum is applied to the rubber boot releasing the sample, and the core rides downward as the ram retrieves. Data are printed and stored on both hard and floppy disks. The carousel then rotates into the next position and the sequence is repeated until all samples are tested. Data can then be transferred to a central computer for statistical manipulation, graphical dis- play, and core analysis final report generation. CAPABILITIES AND LIMITATIONS Sample Sizes The current carousel will hold a maximum of 18 one-inch diameter cylindrical plugs. 3/4 to 3 1/8 inches in length. Since pore volume is by direct helium injection, sample ends must be essentially parallel, and data indicate well maintained normally used preparation equipment can furnish adequate sam- ples. Core should have square, not rounded, corners and be free of surface vugs and chipped edges. By mid-year, sample-size capabilities will include 1 1/2 inch diameter cores, and a 100 sample holder for either diameter that can be substituted for the carousel. Stress Conditions The confining stress is applied hydrostatically (equal on all sides) and can vary from 500 to 10,000 psi. A maximum of eight stresses can be programmed, and increasing as well as decreasing stress can be simulated. The minimum confining stress to yield porosity and permeability data comparable to routine zero stress porosity and routine 400 psi stressed core for permeability measurements is apparently a function of the hardness of the rubber boot that surrounds the core. The boot should be soft enough to conform to sample sides at low confining stress, but hard enough so that it will not flow into pore space at high confining stress and fail to properly release the sample at test conclusion. The current boot material requires at least 800 psi confining stress to conform to the samples, but a new design currently under investigation appears pro~ising in allowing the minimum stress to be reduced to 500 psi. Accuracy and Repeatability The system was designed to yield accurate and reproducible permeability values over a range of 0.01 millidarcies to 2 darcies. Test data indicate pore volumes can be determined for a range of 0_02 cc to 10 cc. Table8 I, 2 and 3 and Figures 5, 6 and 7 furnish control data on both one inch diameter steel standards and core 8amples substantiating design specifications. Control data are commented on in Data and Discussion of Results. 157 ,- I j 4 AUTOHATED CORE MEASUREMENT SYSTEM FOR ENHANCED CORE DATA AT OVERBURDEN CONDITIONS SPE 15185 Sample Consolidation ~- ¡ j Host tests to date have been made on consolidated cores. Limited data indicate that unconsolidated rock mounted in shrinkable tub ing 10 can be run in the device. Investigation of applicability to these type cores as well as metal jacketed samples is yet to be completed. 1- j Core Saturation Condition ~- The system was designed to test clean, dry cores. Data indicate valid permeability at irreducible water (Swir) can be measured. Multiple cores should not be batch loaded as evaporation will occur while awaiting analysis, and immobile water is necessary to prevent water redistribution during gas flow and movement from the core. Total eva pora t ion during ana lys is should be monitored by sample weights. Indicated hydrocarbon pore volume O.O-Swir) reduction due to overburden will be invalid and masked if the volume seen hy injected helium increases due to evaporation. , :- j \... 1- DATA AND DISCUSSION OF RESULTS Accuracy and Repeatability of Steel Standards '- Each core measurement system is calibrated at 1500 psig confining stress utilizing stainless steel cylinders of known pore volume. Each is subsequently independently checked with a set of steel standards. - Typical resul ts of a pore volume accuracy and repeatability check are shown in Table 1. These tests were run overnight in a laboratory with no special temperature control. Maximum pore volume difference observed in the sequence was 0_035 cc, which yields a maximum porosity error of 0.27 porosity points (1.e. 10.0 to 10.27 percent) for a I-inch diameter plug 1 inch in length. This is well within the API RP 40 accepted accuracy of + 0.5 porosi ty point. 11 - ~ Table 2 illustrates pore volume accuracy and consistency between various systems checked with a set of common standards. These locations represent various elevations, barometric pressures and tempera- tures, and excellent agreement is seen in measured pore volumes. Permeability checks on steel standards are shown in Table 3. All fall within the + 5% industry stan- dard for plugs of moderate permeability and reproduci- bility is excellent. Accuracy and Repeatability of Core Plug Standards Suites of cores tested with steady-state perme- ability techniques were used as standards in this evaluation. Air permeability was selected for com- parison as most historical data are in this form and routinely used permeameters develop these data. Mul- tiple measurements were made on carefully calib ra ted equipment and cross-checked between various instru- ments to arrive at standard values. Figure 5 presents differences at 800 psi confin- ing stress between the system and steady-state air permeability measurements. The difference shown is expressed as a percentage of the steady-state value. Three measurements are presented for each sample to illustrate reproducibility. The data indicate three samples with a difference greater than 5% of the standard value. Two are lower permeability samples, of less than one millidarcy. The + 5% limit was set for higher permeab ility samples. ãnd the tolerance is normally expanded in the lower range because of the small values measured and sensitivity to mean pressures in the core as permeability becomes lower. For example, if the true air permeability value is 0.020 millidarcies and the tested value found is 0.025, an error of 25% is indicated, although the magni tude of the difference is inconsequent ial and the permeability in both cases is quite small. A much larger (100%) error results from the incorrect use of the air permeability value of 0.02 to repre- sent reservoi r permeab i li ty rather than the slippage corrected Kl1nkenberg value of 0.01 determined for this plug_ Figure 6 shows comparisons of zero stress meas- urements utilizing a small volume porosimeter (SVP) versus core measurement system porosity data at 800 psi confining stress. Porosity in the system has been calculated using various equations that require different basic data. The zero stress equation util- izes bulk volume determined by mercury displace- ment (BVHg) and grain volume (GV) measured in a D.S.B.M. modified Boyle's Law apparatus using helium as the gas. ø BVH -GV g x 100 BVHg ............(1) The core measurement system uses equations in decreas- ing order of preference as shown below. Pore volume (PV) is by direct injection, and bulk volume is determined by one of three techniques. ø = PV x 100 PV+GV ...............(2) ø PV x 100 BVHg ................(3) ø PV x 100 LxA ............... .(4) In the Fig. 6 data set all porosities agree well with mean porosity differences from the zero stress condi- tion of -0.2, -0.2 and -0.3 porosity points respec- tively. Figure 7 presents individual sample porosity differences comparing values from F.quations 2, 3 and 4 with Equation 1. Equation 2 allows for a decreasing bulk volume as confining stress increases. Equation 4 typically yie Ids porosi ty values too low, as rounded corners or broken edges are often not properly accounted for in length (L) and diameter measurements used to com- pute area (A). This resul ts in higher 'bulk volumes than true; hence, low porosities. Equations 3 and 4 can be modified as illustrated below to allow for decreasing bulk volume as confin- ing stress increases. 158 ~ l ~ -..- >- ~ L-- J- ~ - , - - ..J-. SPE 15185 Dare K. Keelan 5 ø . PV BVHg-(PVi-PVn) ............(5) the core may not have compressed at all. and the pore volume compressibility calculated from pore vol- ume reduction is erroneously high. When the boot material fills the' surface indentions, subsequent increase in confining stress does compress the rock and result in actual pore volume compressibility. Samples prepared for constant temperature. pre- cise compressibility measurements are normally jack- eted with a heat shrinkable tubing that fills surface indentions so that no conformance problem exists, and early applied confining stresses see only sample compression. Figure 9 illustrates pore volume de- cr~ase for a jacketed and non-jacketed core. The jacketed sample also contained water at tOe time of test, which someti.lT1es softens the rock and yields greater and more representative pore volume compres- sihility than a dry core. This sample was tested, while jacketed, in a hydrostatically stressed compres- sibility apparatus, and the jacket was removed prior to testing the sample in the system. Curve 1 is the first system compressive cycle, and greater pore volume reduction is seen at low net stress than observed on the jacketed core. This is bel ieved due to the boot conformance previ.ously discussed, even though this sample was relatively smooth_ Curve 2 is the hysteresis curve, and at the minimum net confining stress of 400 psi obtained after the hysteresis loop, a lesser pore volume than initial is determined. This may gradually recover to initial value as a function of time, or may remain permanently reduced depending upon properties of the core and whether the elastic limit was exceeded. Examination of other data from this reservoir indi- cated an elastic limit of slightly greater than 4500 psi, and for this reason this test was not taken above 4000 psi confining stress. Curve 3 represents the second compressive cycle and Curve 4 is the final hysteresis curve. Note that the slope of the pore volume curve is essentially the same for the jacketed and non-jacketed tests above a net stress of approximately 2000 psig. Although Cycle 3 is below Cycle 1, pore volume compressibil1 ties would be essentially the same at the higher pressures since the slope of the pore volume versus net confin- ing stress is similar. Figure 10 presents porosity as a function of net confining stress. Agreement is well within accepted tolerance for both tests over the range of stresses applied. Note that a net confining stress of approxi- mately 800 psi was required on the Curve 1 compres- sive cycle to yield the pore volume measured on the jacketed core at 200 psi net stress. These data indi- cate boot conformance was occurring in this sample until at least 1500 psi net stress, yet the conform- ance effect on porosity was negligible_ Figure II illustrates the sensitivity of calcu- lated pore volume compressibility to initial boot conformance. The early system values do not appear to represent true pore volume compressibility, but conformance. While differences in compressibility at low confining stresses are significant, compressibil- ity is an instantaneous value calculated at a selec- ted net confining stress, and there is no cumulative error. Values at net stresses above 2000 psi repre- sent reservoir conditions at the reservoir depth of burial and values are in reasonable agreement with Where PVi - Pore volume in cc at Minimum confining stress (800 psig) PVn - Pore volume in cc at any succeeding stress Overburden Effects Table 4 presents typical system data at various confining stresses on a low and moderate permeabilitv sample. Measurements were made at two location~ to evaluate consistency between instruments. Once again, repeatability is good, although Run 2 d;Ha indicate samples have not fully rebounded from stres- ses imposed several days earlier during Run 1. Po- rosity and permeability decrease as expected, find these data indicate values of (b) related to slip- page are essentially independent of confining stress, whereas turbulence factors (Beta) tend to incr.:>ase as confining stress increases. The Sample A Beta factor at 6000 psig stress decreased remarkably in Run I, and this anomalous behavior was seen again in a second instrument in Run 2. Reasons for this are unknown. Figure 8 presents a typical porosity comparison between system measured porosity at various confining stresses with (1) a porosity generated at zero confin- ing stress and (2) with a helium injection technique comMonly employed in Special Core Analysis laborator- ies. The zero confining stress measurement is des- cdbed previously as Eq. 1. The "Pore Volume by Helium Injection" was determined with the core con- fined in a hyd rosta tic boot of lesser hardness than used in the system. Some initial porosity differ- ences between the three techniques is to be expected because some finite stress is required for the direct pore volume measurement techniques to conform the boot to the core exterior. The data indicate that 250 psig yields conform- ance in the softer rubber, while approximately 750 psig confining stress was required for the system to match the zero stress porosity. All measurements agree within an acceptable tolerance of 0.5 porosity points at the initial values reported, and the system and commonly used helium injection technique agree within acceptable limits throughout the overburden stress range investigated. INVESTIGATIONS IN PROGRESS Pore Volume Compressibility Investigation is ongoing to evaluate core surface conformance effects as the rubber boot surrounding the core is subjected to increased confining stress. This has importance 1n evaluation of both porosity reduction observed in the system, and pore volume compressib ility calculated from system measured pore volumes. Initially the boot is held away frol1l the core surface by tops of grains and/or any high points present. As confining stress increases, the boot conforms more closely and flows into the indented spaces between adjacent sand grains. This translates into a differential pore volume reduction sensed by the system as subsequently injected helium sees a smaller volume. While the pore volume is 8Glaller, 159 J I! ,- j 6 AUTOMATED CORE MEASUREMENT· SYSTEM FOR ENHANCED CORE' DATA AT OVERBURDEN CONDITIONS .:. SPE 15185 .<.; .;:.~ .~-..~ j ,1 >, ~ the jacketed sample. (i.e. system value of 7.4 x 10-6 versus 9.3 x 10-6 at 4000 psig and much better agreement at 2000 psi.) ~- J The system can furnish large volumes of data rapidly which are likely to be much more representa- tive of a formation or its various rock types and lithologies than average correlations in the litera- ture. The data can and should be calibrated to more precise measurements by running a suite of water saturated jacketed cores in a compressibility appara- tus, and arriving at a confidence and adjustment factor to be applied to the system calculated pore volume compressibility values. ,~ j ,~ ~ ;- Irreducible Water (Relative Permeability Effects) j Table 5 is a subset of data to illustrate the effect of irreducible water (Swir) on the Klinkenberg permeability. The data are somewhat erratic due to the unusual relationship of porosity and permeability indicated, and Swir appears quite low for two of the three samples. These cores were reported to contain kaolinite and perhaps slight changes in loose particle location in the dry core contributed to these results. In any event, irreducible water saturation of. up to 22.9 percent pore volume had a negligible effect on gas flow in all core tested. This indicates the dry core Klinkenberg permeability would represent gas reservoir permeability in zones containing irreduci- ble water. '-- ,- The samples were then restored with oil and oil permeabilities were determined. Sample 3 yielded an oil permeability equal in value to the Klinkenberg values found both on the dry core and the core con- taining irreducible water. The total data set indi- cated that in 40% of the samples tested, Ko at Swir equaled the dry core Klinkenberg value; conversely, 60% of the samples gave poor comparison. The cónclu- sion here is that validation of the Klinkenberg value at Swir as equal to the Ko at Swir must be done on an individual formation basis with independent oil permeability measurements. Table 6 illustrates the effects of irreducible water on slippage factor and turbulence for the core identified as Sample 3 in Table 5. The b value decreased in this and other cores tested in the presence of Swir, while turbulence factor (Beta) remained essentially constant. Conversion of Hydrostatic to Uniaxial Strain Data The core measurement system employs a hydrostatic load to simulate stresses of the rock at net overbur- den conditions. However, numerous authors have indi- cated that reservoir stresses are not hydrostatic, and the reservoir is free to compact in a vertical direction only, with no deformation laterally. This is referred to as uniaxial strain. Teeuw showed that uniaxial pore volume compres- sibility was approximately 62% of hydrostatic val- ues12. Anderson presented data comparing hydrostatic loading to uniaxial, and equations to transform hydro- static pore volume compressibility to uniaxial strain conditions13. It follows that a hydrostatic pore volume compreesion that is too high will result in a laboratory porosity reduction that is too high. Similar results have bee~ reported for permeability 14. If reservoir compression is only 62% of the laboratory value, then the reduction in reservoir porosity should only be 62% of the measured hydrostatic laboratory value. Nelson concluded permeability could be derived from hydrostatic confining pressure tests by calcu- lating the mean stress in the reservoir and then reading the permeability value from the hydrostatic curve at the calculated mean subsurface stress15. ,~ :~ , Both porosity and permeability data from the core measurement system can be normalized by dividing e;¡ch overburden value by the initial value 'It the minimum confining pressure. This type of data is illustrated on Fig. 12, and the curves allow a quick approximation of uniaxial strain porosity and permea- bility. The approach illustrated employs the average correction factor of 0.62 proposed by Teeuw. The curves are entered at Point A, the calculated reservoir net overburden pressure computed as illus- trated in Fig. 2. The porosity -fraction of original" curve intercepted at Point B represents too grea t a reduction in porosity since porosity was measured under hydrostatic loading. This -fraction of origi- nal" value is adjusted upward using Teeuw's factor by multiplying 0.62 (1.0 - normalized porosity factor read at Point B) and subtracting this product from 1.0. This adjusted value is plotted as Point C, which is the porosity -fraction of original" more representative of reservoir conditions, and which approximates data that would have been measured had the core been tested in a uniaxial strain test. We then move from Point C horizontally to the left to intersect the hydrostatic curve. The net overburden pressure Point D corresponding to this intersection is the equivalent mean stress on the hydrostatic curve required to yield the reservoir uniaxial strain porosity. By moving vertically, we intersect the normalized permeability curve at Point E at the same mean stress. We can then move horizontally to the left to Point F which represents the factor for permeability adjustment. This factor times initial permeability yields the desired permeability value. Reliability of this approach for a particular formation would be improved by having uniaxial perme- ability and porosity measurements to compare with hydrostatic and to develop the actual correction factor for the formation. CONCLUSIONS 1. Kl inkenb erg corrected permeability, porosity, slippage factor (b) and turbulence factor (Beta) can be accurately and routinely determined in the core measurement system at overburden pres- sures. 2. Overburden pressure effects (including hystere- sis) can be easily studied by designating confin- ing stresses that are automatically applied from 500 to 10,000 psi, and differences in properties at overburden conditions fro. low stress measure- ments can be significant. 160 \..-. ¡.... . ~ '.' >.: ,',- ~':_"'.~ :,' " ;;L~~ïi\,::~· " ,.-,-', ,. ',' ,i..'. ~ ;¿~.~:~>))~~~~ic. . Keelan SP! 1:¡18S' ~.~~~:\-~~~.tJf!-~:' .",::. :1 \".'-",'."'w. #--_. 7 3. Kl1ukenberg slippage facton (b) were 'essentially the same or increased only slightly in,tbe.and- stones tested as overburden pressuré increased, and the presence of irreducible water resulted in a decrease in (b) value. t 4. The turbulence factor (Beta) increased moderately in the sand stones tested as overburdenpres8ure increased and the presence of irreducible water had little. effect on its value. ~ àL 5. A minimum confining stress of 800 psi is currently required for the system determined porosity and permeability to equal (1) porosity values at zero stress and (2) air permeability values at 400 psi confining stress now employed in routine core analysis. ....->t l .J- .; 1 .:L.. 6. Helium injection porosity measurement techniques routinely employed in Special Core Analysis labo- ratories yield porosity values in good agreement with those measured on the system. , t ;L 7. Conformance of the rubber boot to the core sur- face had little adverse effect on system poros- ity values at pressures above 800 psi confining stress, and the jacketed and non-jacketed core yielded similar values of porosity throughout the range of overburden pressures investigated. ; \, !: OJ.- " 8. Pore volume compressibility of the non-jack- eted core, was extremely sensitive to boot con- forœance at confining stress below 2000 psi. Above this stress compressibilities approxi- mated true values. Compressibilities determined on non-jacketed dry core should be calibrated to best technique values by comparative measure- ments on jacketed, water saturated samples tested in a compressibility apparatus. .~ ...l-. ; . .-L ¡ ....:L 9. Hydrostatically confined porosity and permeabil- ity determined at selected net overburden pres- sures and presented as a fraction of original values allows approximation of both porosity and permeability at uniaxial strain conditions. Note: This is likely to be restricted to well- cemented cores whose behavior follows elastic theory. I - I, I 10. The system can be used to measure Klinkenberg gas permeablity with irreducible water in the core. and thereby verify whether dry core slippage corrected permeability at confining stress is representative of gas flow with connate water present. i L 11. Applicability of the system Klinkenberg gas perme- ability (with or without irreducible water pre- sent) to represent oil permeability (Ko) with irreducible water present must be verified by independent measurements of Ko. NOMENCLATURE k . permeability. md KA . permeability to air, md Ko. . Kl1nkenberg "Liquid" permeab l1ity. md b . Klinkenberg slippage factor. psi . . . t. ..A,/._:"'~ ' l1l~~.it~\, .!~~~ P.ean · arithmetic average' pre88ure p . pres8ure ~ p818· . L . length of flow path, ft V . velocity. ft/sec 6 - Beta· turbulence factor. ft-l µ . gas viscosity, cp P - density of fluid. lb mass/cu ft ACKNOWLEDGMENTS The author gratefully acknowledges the contri- bution of Brian Davis and Lisa Curry and those who developed and implemented the theory resulting in the automated core measurement system. REERENCES I. Thomas, R. D. and Ward, D. C.: "Effect of Over- burden Pressure and Water on Gas Permeability of Tight Sandstone Cores," J. Pet. Tech. (Feb. 1972) 120-124. 2. Jones, F. O. and Owens, W. W.: "A Laboratory Study of Low Permeability Gas Sands.·' AIME-SPE 7551 (May, 1979) Denver Low Permeability Gas Reservoir Symposium. 3. Jones, S. C.: "A Rapid Accurate Unsteady-State Kl1nkenberg Permeameter," Soc. Pet. Eng. J. (Oct., 1972) 383-397. 4~ KHnkenberg, L. .J.: "The Permeability of Porous Media to Liquids and Gases," Drill. and Prod. Prac., API (1941) 200. 5. Christman. Stan A.: "Offshore Fracture Gradients," Soc. Pet. Eng. J. (Aug.. 1973) 910-914. 6. Breckels, J. M. and Van Eekelen. H. A. M.: "Rela- tionship Between Horizontal Stress and Depth in Sedimentary Basins." paper SPE 10336 presented at 56th Annual Fall Tech. Conf. and Exhibition. San Antonio. Texas. October 5-7. 1981. 7. Tek. M. R.. Coats. K. H. and Katz, D. L.: "The Effect of Turbulence on Flow of Natural Gas Through Porous Reservoirs." J. Pet. Tech. (July, 1962) 799-806. 8. McLeod. H. 0.: "The Effect of Perforating Condi- tions on Well Performance." J. Pet. Tech. (Jan., 1983) 31-39. 9. D. L.: "Flow of Gases Ind. Eng. Chern., (1953) Cornell, D. and Katz, Through Porous Media," 45, 2145. 10. Griffin, T. J. and Bush, D. C., "Core Analysis in Unconsolidated Reservoirs Using an Improved Consolidation Technique," 36th Annual Meeting of Petroleum Society of ClM. Edmonton, Alta., Paper No. 85-36-41, June 1985. 11. API-RP 40: Recommended Practice for Core Analysis Procedures. American Petroleum In8titute. Dallas. 12. Teeuw. D.: "Predictions of Foraation Compaction from Laboratory Compressibility Data," Soc. Pet. Eng. J. (1971) II, 263-271. .- .' 181 ,¡~i\:, : -';.\.;.' .,'.~. .:. -: '.....'......'."... '.... " 8 ,;r::.,'.:.~<, , 13. AUTOMATED CORE HEASURÐŒNT SYSTEM FOR Eh1lANCED CORE DATA AT OVERBURDEN CONDITIONS SPE 1S185 ,- I l Andersen,M~A.~ . ",Predicting R~servoirCondition Pore-Volume Compressibility. from Hydrostat1c- Stress.Labòratory Data" paper SPE 14213 presented at the 60th Annual Technical Conference and Exhi- bition, Las Vegas, September 22-25, 1985. ,- j 14. Gray, D. H., FaU, I. and Berganini, G.: "The Effect of Stress on Permeability of Sandstone Cores," Soc. Pet. Eng. J. (1963) 2, 203. ~- 15. Nelson, R. A.: "A Discussion of the Approximation of Subsurface (Burial) Stress Conditions in Lab- oratory Experiments," Geophysical Xonograph 24, American Geophysical Union (1981) 311-321. J ,- 1 1...... ,J. ·.:, ./ ~I A 'l"tPICAL (X)RE I1&\SURDIfNI' Sm'Ø! CALIBRATI~ NÐ REPEATABILITY ANo\LïSIS ~ STEt:L I'OR£ 'oQ.tJŒ S'I'ANIWtDS AT OJNFINIIG STRESS STANtWID \CJUJIIE . 0_195 cc Confinin;¡ Stress Psig ~I IbJn 2 ~3 IbJn4 IbJn5 1000 0.207 (+_012) 0.230 (+.035) 0.223 (+.0281 0.224 (+.029) 0.222 (+.027) 2000 0,193 (-.002) 0.222 (+.0271 0.215 (+.020) 0.215 (+.020) 0_213 (+.018) 3000 0.188 (-.007) 0.217 (+.022) 0.210 (+.015) 0.211 (+.016) 0_209 (+.014) 4000 0.184 (-.011) 0_213 (+.018) 0_206 (+.011) 0.207 (+.012) 0.206 (+.0111 5000 0.180 (-.015) 0.210 (+.015) 0.203 (+.008) 0.204 (+.009) 0.203 (+.008) 6000 0.175 (-.019) 0.207 (+.012) 0.201 (+.006) 0.202 ( +.0071 0.200 (+_005) STA.'IIY\RIJ \QUJI1E . I. 021 cc 1000 1.017 (-,0041 1.045 (+.024) 1.043 (+.0221 1.043 ( +.0221 1.043 (+.022) 2000 1. 008 (-.013) 1.035 (+.014 ) 1.034 (+.013) I. 034 (+.0131 1.034 (+.013) 3000 1. 002 (-.0191 1.03l (+.010) 1.030 (+.009) 1,029 ( +.OOBI 1.029 (+.OOB) 4000 0.99B (-.0231 1.027 (+.0061 1.025 (+.004) 1. 025 (+.004) 1.025 (+.004) 5000 0.994 (-.0271 1. 02 3 ( +.0231 1.022 (+.0011 1.023 (+.002) 1.022 (+.0011 6000 0.991 (-,0301 1. 020 (+.0201 1.020 (-.0011 1.020 (-.001) 1.019 (-.002) STAN!ì\RD \QU.t\E . 3.099 cc lOOO 3.101 (+.O02) 3.123 (+.034) 3_131 (+.032) 3.126 (+.029) 3.129 (+_0281 2000 3.089 (-.010) 3.121 (+.022) 3_119 (+.020) 3.119 (+.0201 3.117 (+.013) 3000 3.083 (-.016) 3.114 (+.0151 3.113 (+.014) 3.113 (+.014) 3.113 (+.014) 4000 3.077 (-.022) 3.109 (+.0101 3.108 (+.0091 3,108 (+.0091 3.109 (+.OlOl 5000 3.073 (-.0261 3.105 (+.006) 3.105 (+.006) 3.103 (+.004) 3.105 (+_006) 6000 3.069 (-.030) 3.102 (+.0031 3_101 (+.002) 3.102 (+.003) 3.102 (+.003) 1) OIS ran overnight in aut~tic rTO.1e in laooratory environment with variable tenperature. . ., .~ 2) Haxinum error of 0.035 cc wo.Jld result in 0.27 porœity percent point error in a 5an\'le of 1 inch di_ter and 1 inch length (i.e. 10.0 to 10.27 porosity percent). TABLE 2 STANQARŒ OiECK IllJ.JS'ffiATIIG CORE ~ SYSTEM PORE \QUJI1E N:.aJf1ICt AND <nISISTDK:Y BE:NEÐI LlXATI~S (AT 1000 PSIC CCtlFlNIIG S'mESS) Standard Volumes ---2L- Aberdeen loncIon . Calgary·· Dallas Denver 0.195 0.209 (+.014) 0.188 (-.007) 0.212 (+.017) 0.199 (+.004) 0.545 0.540 (-.005) 0.515 (-.030) 0.547 (+.002) 0.529 (-.016) 1. 021 1.026 (+.005) 0.999 (-.0221 1.016 (-.005) 1.014 (-.007) 1.025 (+.004) 3.099 3.104 (+.005) 3.085 (-.014) 3_092 (-.0071 3.097 (-.002) 3.105 (+.006) 5.109 5.118 (+.009) 5.101 (-.008) 5.086 (-.0231 5.108 (+.00l) 5.109 (0.000) *After I year field trial in Aberdeen -*Recalibration after field repair - TABLE 3 <DRE f'EASIJRf>IENI' SYSnJ1 AIR PERMEA8ILIT'i N::OJAAC'i AND R£P&.TABILITt' 0iEX:!< 0; STEEl. STI\N!:\\Rœ Steady Confining State Stress Salrple K Average Psig Number ~ Run 1 Run 2 Run 3 Error 500 A 1.09 1.05 1.05 1.05 -3,7\ 1000 A 1.04 1.05 1.04 -4,3\ 500 B 29.] 26.7 28.6 28.6 -2.3' 1000 B 28.8 28.7 28.6 -2.0t 500 C 48.5 46.5 46.5 46_4 -4.2t 1000 C 46.4 46.4 46.4 -4_1\ SOO D 73.7 70.7 70.5 70.4 -4.3' 1000 D 70.6 70.5 70.3 -4.3' 500 £ 1430 1480 1480 1470 +3.3' 1000 E 1490 1490 1480 +4.2' L -I I ¡ 1 TABLE 4 TYPICAL CXJRE ~ SYSTDI (X)RE DATA AT cmFINUC S'mESS IWJS1"RATII'G O::'HSISTENCY BE:nÐ>I INSI'RLI1fNI'S SAllPLE A (LOW PERP1£AB1 tITY) Confining Dallas (~ II Denver (~n 2)· Stre5S 'J K Ka(est) b(!I.» Beta ø K Ka(est) b(!I.» ~~ Psig --L. .!&.. ~ ..!:!L FCI , ..!!!1.. ~ ~ 500 10.7 .065 _141 56.6 2.75xI013 10.7 .055 .130 66.6 1.76xI013 800 10.6 .057 . .132 63.2 2.96x1013 10.6 .052 _126 61\.2 2. 44x1013 1000 10.6 .054 .129 6~.2 2. 74x10 13 10.5 .052 .124 67.7 2.81x1013 2000 10.4 .053 .122 63.0 4.52xlO13 10.4 .050 .118 65.7 3.68xI013 4000 10.2 .048 .114 H.B ~.05xI013 10.2 .047 .112 67.1 3.7lxI013 6000 10.1 .043 .109 -;~ 9 1. 51x1013 10.0 .043 .109 74.0 I. 77xl 013 SA."IPI£ B ( f'OOCRATE PERMf,AlH LITY) 500 19.6 33.9 37.3 ~, :38 3.46x108 19.3 33.4 36.7 4.80 3,55xl08 BOO 19,3 32.8 36.2 ~ . ';'f.. 3.65xlO8 19. I 32.4 35.6 4,84 3.81x108 1000 19.2 32.4 35.7 '. ,S 3.80x108 19.0 32.0 35,\ 4,80 3,93xl08 2000 18.9 31.1 34.2 ~. ~S ~.05xI08 IB.6 30,7 33,7 4.80 4,23xl08 4000 \B.5 29.6 32.6 S,J4 4.33x108 18.3 29.2 32.1 4,88 4,54xl08 6000 18,3 28.5 31.5 ó, as ~. 56xl08 18,1 28,3 31.1 4,91 4.77xl08 ~1 -1 I i 1 -, ¡ -, I J -1 "Data set indicated pore space at tire .::>, Run 2 had not fulJy retx)Jnòed fron 6000 psi COO'Ç>ressiw force i",>Œed several days earlier dJring """ 1, TA9L£ lRR£OOCIBŒ WATER (RErAT:\'¡: PER"I£A9ILITY EfITCT) o-¡ O)R£ MEASUREMENr SY"lEM KLINKG-IBERG PER"IF.AB::":-:ì' !\.''D OIL PERMEABILITY AT <:aJf1NING STRESS , c-.s Klinkenberg Oil F\emeabi1 ity:md Perme-abil ity;nd-· Sanp Ie Porosity Swit Drv Core Core @ 9wir Ko ~ Swir Nu1Iber ---..L- \PV ~ ~ 800" ~ 800' 4000' 1 15.5 5.0 545 520 543 517· 400 374 2 7.7 7.2 32.2 29.5 ]1.] 29_] 22_] 18_5 3 17.2 22.9 30.1 28.7 31.1 29.6 30.7 29.2 _1 ·Conf ining Stress * ·Steady-State Measurenent TA8l..E 6 lRREDJClBLE WATER EffÐ:T Cf4 SU PPAGE (b) FACroR AND 11JRBUl.f}ICE (BITA) fACTOR AT <:aJfINIto(; STRESS Confining Dry Core Irreó.1cible Sw a 22.9 , PV Stress 'J b(Ke ) Beta b(Ke) Beta Psig --L. ..!:!L ~ Psi ~ 500 17.4 4,90 2.84x108 4.11 2.81x108 800 17.2 5.03 2.81x108 4.10 2_89xl08 1000 17.2 5.06 2.8h108 4.13 2.9Ox108 2000 16.8 5.05 2.99x108 4_16 2.99x108 4000 16.6 5.!! 3.04xl08 4.27 3.06x108 6000 16.5 5.10 3,I9xl08 4.30 3.15x108 ... :~. KA = Ka:> - ~ I- -I eX) ~ L<J ;; :IE /....... a: /.... L<J ¡:.... NON - RE ACT IVE LIQUID 0.. ,~~.... .................... ....... SL IPPAGE CORRECTE D KLlNKENBERG PERMEABILITY °0 -L P mean - F!g. 1-PermeablUty II . function of mean pressur.. 1.0 ;t ,9 I a ,S ¡ ,7 ~ !: ! ,6 I ~ ! ~ I . 3 0 , 2 3 4 5 6 7 CúNfIHIHG Sffi[S5 ; THOuSAHDS Of PSI Fig, 3-Poroslty and permeability .s, conllnlng BIres'. - 1""---'" '- ,....-'--..., ....- ... I ----.¡ 10 SURFACE T OVERBURDEN PRESSURE 0.5 1m { ,~; 1;;,~ NET OVERBURDEN = (OVERBURDEN PRESSURE) - (RESERVOIR PRESSURE NOB ~ DEPTH (1.0 ~~ - 0,5 ~I; ) ~ DEPTH (0.5 ~ITi ) Fig. 2-Net overburden pressure YI. depth. ~, ~ a: :r: 0 ...J u.. 1-:~=V++ßpvzl PRESSURE DIFFERENTIAL .. Fig. 4-Effects of turbulence on flow. [ I I 16.0 15,0 14.0 CONFINING STRESS (800 p.ig) 1.:1.0 12.0 l- 11.0 Z &oJ 10,0 u Ik: &oJ 9,0 n. 8,0 l: 7.0 ;¡¡ 0 6.0 It: 0 5,0 n. 4,0 .3.0 2,0 1.0 0,0 J ]- 1- 20" &oJ U 1 Or. Z &oJ It: &oJ "- "- Õ Or. ... z &oJ U It: -10~ &oJ n. - ;10" -jO'= 1- 1- I j 1- j '- j ,- ~.- 1 0,9 0.8 0,7 <II 0,6 I- 0,5 Z ::> 0,4 l: 0,3 ;¡¡ 0,2 0 It: 0,1 0 n. 0 I -0,1 &oJ -0,2 u z -0,3 &oJ It: -0,4 &oJ "- -0.5 ... Õ -0,6 -0,7 -o.e -0.9 -1 - . ....... ..--......'11. I I T·--r~nT-·~1 ...¡-.....,.-----,--- ·r·--r·--!-~ I-~ --·"T- - ~- ·1~"'·1- ·T--,.J 336 262 216 .96 175 99,8 80,6 52,2 15.6 0,020 290 230 203 117 157 90,5 71. 1 22,0 0,73 INDIVIDUAL SAMPLE PERMEABILITY: MILlIOARCIES _ RlJU 1 _ RUN 7 _ RUt..:I fIg ~-O,1t('.nC.5 01 liyst.m ~nn.ab,jt'.1i and "Ianda,dl. I I I I I I I I I TTfIIi I I I I I I I I I IIIII I I I I I I I I I I I I I I I I I I I I I I .... I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I II III I I I I I I I I I SVP 2 10 11 9 18 14 16 19 7 5 12 20 6 1 J 1 7 4 15 8 SAMPLE NUMBER _ PV/8VHg _ PV/(PV+GV) _ PV/(LxA) F'g. ,-Core tnehUfeflW:'llt .yet", ~ w.. .~. CONFINING STRESS (800 palg) IT~~"--' 1 ° 1 8 14 16 11 2 9 7 17 12 6 20 1 J 5 15 4 8 19 SMlPLE NUII48ER PV/(PV+GV) _ PV/8VH~ _ PV/(L><A) ...' ,..-........ aI_........ iM........' J " j 1 1 t I ....;¡, J I, au au 22,4 !i i 22,2 l: S22,0 21.8 (11.1) 2000 3000 '000 100{} CONf INING STRESS: PSIG fig. 8-Compar.tlve porosthes va. confining .tress. 3.55 8 J 1.50 ~ ~ 3.<5 3<0 335 5000 1.1$ 1000 1000 SOOO N[T CON~IMHG STJI:£SS : P5'G '00{} 5000 Fig_ 9-Comper.'íve pof'e volumes Y$. net confining .tress. ~ 28 ~ " l' > 20 " - 16 ¡¡; ~ ~ 12 ! ~ f 0 5000 0 .000 5000 I I I I I I I I® NET OVERBURDEN PRESSURE ... 230 118 12.6 z ~ 22.4, ~ J.&.()tETEO SAntE SATURATED COA£ IN COUPRE5SæU..ITV APPARATUS - ,. ~ 22.2 ~ 12.0 t 2HI 21.6 o 3000 Nn CÒNfIN1t<G STR£SS : f'SIG '000 1000 t fig, 10-Q>mpllraUve porooJties vs. net confining stress. - 1 1.0 - >- .... --I -1< ~~1 W_ ::IE 0:: 0::0 Wu.. a.. 0 <Oz >-2 ........ -(J V)< 00:: g§u.. a.. ® °0 N£T CONF1MNG STllESS : OSIG fig, 11~rative pore volume compr...-.ee ..., net conflning etress. POROSITY ADJUSTED TO UNIAXIAL STRAIN Fig, 12_oroeIIy _ .........~ .....tment to u.....I.III'eln, , - i J Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518,3045 (907) 349,3541 ,- j WELLSITE CORE REPORT 1- j Company: Arco Alaska, Inc. Date: 4/30/87 Well: KRU #3M-9 Technicians TLS,TDT ,- County, state: North Slope. Alaska Formation: Kuparuk , Core :# 1 Top Bottom Total (Ft.) L Coring Interval (drillers depths) 6531. 0 6579.0 48.0 1- Retrieved Core (measured depths) 6531. 0 6578.0 47.0 Type Preservation - Core Seal Core Barrel on drill floor - 8:35 am End preservation - 12:05 pm Box To~ De-pth Bottom Depth Remarks 1.) 6531. 0 6534.0 2. ) 6534.0 6536.5 3. ) 6536.5 6539.2 4.) 6539.2 6541.8 5. ) 6541. 8 6543.8 6. ) 6543.8 6545.8 7.) 6545.8 6547.2 8.) 6547.2 6549.6 9. ) 6549.6 6551. 6 10. ) 6551.6 6554.2 11.) 6554.2 6556.6 12. ) 6556.6 6559.0 l Littan Core Lab 1. Top Depth Bottom Depth Remarks , --'- 13. ). 6559.0 6561. 0 14. ) 6561. 0 6563.0 15. ) 6563.0 6565.3 1 16. ) 6565.3 6567.2 - 17. ) 6567.2 6569.1 ..l 18. ) 6569.1 6571. 3 19.) 6571. 3 6573.3 l 20. ) 6573.3 6575.4 21.) 6575.4 6577.2 22. ) 6577.2 6578.0 End Core :#1 23. ) 24. ) 25. ) 26. ) 27. ) 28.) 29. ) 30. ) 31.) - 32. ) 33.) 34. ) 35. ) 8005 Schoon Street Anchorage, Alaska 99518- 3045 (907) 349,3541 L Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518· 3045 (907) 349· 3541 L WELLSITE CORE REPORT L Company: Arco Alaska, Inc. Date: 5/01/87 Well: KRU #3M-9 Technicians TLS,TDT \ County, state: North Slope, Alaska Formation: Kuparuk Core :# 2 Coring Interval (drillers depths) Top Bottom Total (Ft. ) 6579.0 6637.0 58.0 6579.0 6618.5 39.5 , , Retrieved Core (measured depths) Type Preservation - Core Seal Core Barrel on drill floor - 8:40 pm End preservation - 12:00 am Box Top Depth Bottom Depth Remarks 1.) 6579.0 6581. 4 2. ) 6581.4 6583.7 3. ) 6583.7 6585.7 4. ) 6585.7 6587.8 5. ) 6587.8 6589.8 6. ) 6589.8 6592.1 * Depth 6591.0-6618.5 possibly 6609.0 - 6636.5 due to loss of 7. ) 6592.1 6594.4 core at middle of core interval (lost recovery was assigned to 8. ) 6594.4 6596.8 the end of core). 9. ) 6596.8 6598.8 10. ) 6598.8 6600.6 11.) 6600.6 6602.7 12. ) 6602.7 6604.7 -'- Littan Core Lab ...... Box Top Depth Bottom Depth -J. 13. ) 6604.7 6606.8 14.) 6606.8 6610.7 ~ 15. ) 6610.7 6612.7 16. ) 6612.7 6615.0 .... 17. ) 6615.0 6617.4 --' 18. ) 6617.4 6618.5 19. ) -1. 20. ) 21.) .....l 22. ) 23. ) 24. ) 25. ) 26. ) 27. ) 28. ) 29. ) - 30. ) 31.) - 32. ) 33.) 34. ) 35. ) 8005 Schoon Street Anchorage, Alaska 99518- 3045 (907) 349· 3541 Remarks End Core :#2 L L L 1 - 1 ~ L 1 - - - Littan Core Lab WELLSITE CORE REPORT Company: Arco Alaska, Inc. Well: KRU #3M-9 County, state: North Slope, Alaska Core # 3 Coring Interval (drillers depths) Retrieved Core (measured depths) 8005 Schoon Street Anchorage, Alaska 99518·3045 (907\ 349,3541 Date: 5/02/87 Technicians TLS,TDT Formation: Kuparuk Top Bottom 6637.0 6660.0 6637.0 6657.6 Core Barrel on drill floor - 7:30 am Type Preservation - Core Seal/plastic tubinq Total eFt.) 23.0 20.6 End preservation - 9:17 am Box Top Depth Bottom Depth 1.) 6637.0 6639.8 2. ) 6639.8 6642.5 3. ) 6642.5 6645.5 4. ) 6645.5 6648.5 5. ) 6648.5 6651.6 6.) 6651. 6 6654.2 7. ) 6654.2 6656.9 8.) 6656.9 6657.6 9. ) 10. ) 11.) 12.) Remarks Core packaged in plastic tubing " " " " " " " End Core #3 " " " " " " " - Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518,3045 (907) 349·3541 ~- ¡ L Recommended Wellsite Handling Procedure Fiberglass Sleeved Cores L 1.) Fiberglass liner or inner barrel is laid down in work area. L 2.) Clean exterior of fiberglass tube and mark orientation lines down the entire length with a waterproof/non-erasable ink. Markette brand markers seem to be best suited for this. Orientation lines shall be marked with black on the left and red on the right. We have found that taping the red and black markers together allows this to be done in a minimum amount of time. L L 3.) Cut plastic tubes into three foot sections with an electric skill saw. In some cases it may be required to use a pneumatic saw available by special order thru our Anchorage supplier. We use a masonry blade for cutting, available at most hardware stores. Generally it is the responsibility of the coring company to provide an appropriate saw with blades. 4.) Number each tube from top dowri in consecutive order by depth or coded numbers. We prefer marking be by depth, but if confidentiality is required, mark each core section by core number and tube number, i.e. core I-tube 1 marked 1-1, core 1- tube 2 marked 1-2, etc. 5.) Chips may be taken from the ends of the three foot sections for field descriptions. Core should not be removed from the fiberglass tubes unless examination is required for decisions regarding further coring. 6.) Both ends of the three foot sections are sealed with caps and hose clamps provided by the coring company. 7.) Load the three foot sections on crates or pallets measuring 38 x 38". It is recommended that crates be used and no more than 60 feet per crate. 8.) Freezing of the cores from unconsolidated formations is recommended for transportation. We do not recommend freezing of the more non-friable cores , either for transportation or while waiting at the staging area for shipment. 1_ Littan Core Lab 8005 Schoon Street Anchorage, Alaska 99518· 3045 (907) 349· 3541 ,- i j WELLSITE CORE PRESERVATION PROCEDURE ì- L . The following procedures for preservation of core samples at the wellsite conform to the requirements established for Prudhoe Bay equity determination wells and have been tested on a majority of those wells cored. The preservation rate for these procedures should average 20 feet an hour, thus keeping the time for the preservation of 60 feet under 4 hours total. If the process does not average 20 feet per hour, it is recommended that the core be fully wrapped in Saran Wrap, placed in a brine if a water/bland mud core, or placed in oil base mUd/arctic diesel for oil base cores. These procedures recommend six personnel for routine preservation and seven personnel for special preservation (core plugging,wettability tests,etc), although it has been properly performed with five personnel. It would be possible to meet these established requirements with four personnel who are experienced in core preservation. Although the following procedures are well defined, they will not substitute for experienced personnel familiar with the proper handling and preservation of core samples at the wellsite. 1_ ,- Recommended Personnel 1.) Core Lab Representative - Fitting core together, marking depths, sample selection, overall supervision of preservation process. 2.) Core Lab Representative - cutting of plugs or full diameter samples for laboratory analysis, special tests if required, assist in the preservation process where needed. 3.) Client Coring Supervisor, Engineer, or Geologist - Records depths of each core piece or sample before preservation and assists in decisions that may be required by special conditions encountered. Also generally performs core descriptions or other tasks required by his organization. 4.) Client Rep., Mudlogger, or Rig Hand - Wraps core in Saran Wrap. 5.) Client Rep., Mudlogger, or Rig Hand - Wraps core in foil and marks each piece with depth and orientation lines. These duties may be performed by one of the above if there is insufficient personnel available. 6.) Client Rep., Mudlogger, or Rig Hand - Wraps core with wire and dips core in Core Seal. Wellsite Core Preservation Page 2 '-- L 7.) Client Rep., Mudlogger, or Rig Hand - Removes dipped core from rack, places Core Seal where wire was trimmed, and boxes preserved pieces. May be performed by the person who dips the core if there is insufficient personnel available. The preservation operation can be divided into three main phases: , '- 1.) Material and site Preparation 2.) Core Handling and Preservation 3.) Final Boxing and Quality Control 1 - 1.) Material and site Preparation 1- - Upon arrival at the wellsite the required preservation materials should be set up in the core trailer as listed in the attached diagram. The melting pot should be filled with Core Seal and turned on. The temperature should be adjusted for the length of time before the core in recovered, place on low (180 F.) if more than 48 hours is anticipated. It is recommended that the melting pot be checked at regular intervals when turned on and never exceed the recommended dipping temperature for Core Seal(320-330 F. ) Personnel need to familiarize themselves with the areas on the wellsite that they will be working in while retrieving the core such as the rig floor, pipe shed, and core trailer location. Also all personnel should be aware of their areas of responsibility for the preservation operation. If a brine or diesel solution is to be used for submerging the core while awaiting preservation it is important to have the solution ready well in advance. Generally the service company responsible for the drilling fluid can provide the required solution. A trough for placing the core and solution in is usually supplied with each core trailer. Upon completing the above preparations, the core boxes should be put together and marked with Client, well name, core no., and box no. L 1 - - 2.) Core Handlina and preservation The Core Lab rep. should be present on the rig floor when the core barrel is being disconnected from the drill collars. He should have all materials that will be needed to prepare the core for movement to the core trailer at the rig floor or in the pipe shed. Also he should have a rock hammer, marker, and plastic sample bags with him on the rig floor for the pieces of core that are generally hanging out of the end of the core barrel or the inner liner. It is also important that he insures that the core is maintained in the proper orientation until fully marked. The type of core barrel and inner barrel used will determine the - 1_ J Wellsite Core Preservation Page 3 ~- i 1 ,- ~ type of handling required to prepare the core for movement to the core trailer. Generally most cores taken at present use the fiberglass inner barrel and the procedures used for preparing this type of core can be found in the Wellsite Handling - Procedures for Fiberglass Sleeved Cores. Most other types of core barrels may vary somewhat but overall they will require core boxes or core trays on the rig floor to carry the core in once it is removed from the inner barrel (not necessary for fiberglass sleeved core). Once core is in the core trailer it should be placed in a solution or wrapped in plastic wrap to reduce fluid loss. The core should be laid out on the counter in five to ten foot intervals, the surface cleaned to allow marking, and marked with depths and orientation lines. Depths shall be marked below the corresponding foot line and orientation lines marked with white on the right and yellow on the left if using lumber crayons, or red on the right and black on the left if using waterproof markers. It is recommended that lumber crayons be used for marking core surface and markers for fiberglass barrels or foil wrapped core. After core is marked, chip samples and core descriptions may be performed providing the exposure of the core is kept to a minimum. The Core Lab representative shall preserve a minimum of four inches from each foot for laboratory analysis. A cut-off saw using an appropriate coolant should be used for cutting out these samples. This samples shall be marked with a CL on both the core surface and the foil wrapping. Once the laboratory samples are designated, the core is placed with the top facing "down the line" towards the dip tank. This will help insure that the proper core orientation is maintained. The core is then wrapped a minimum of 3 full wraps of Saran Wrap, then wrapped with a minimum of 3 full wraps of aluminum foil, and marked. Wrapped core should be marked with depth and orientation lines. Also laboratory samples should be marked with the CL designation. Once marked, the core is wrapped tightly around the center with wire to facilitate the dipping of the samples. The core should be completely submerged in the dip tank for 10 to 15 seconds and then hung on the cooling rack. After Core Seal has cooled (3 - 5 minutes) it should be redipped to insure a proper seal and to help protect the core from damage during shipment. After the second dip, the wire is cut at a point just above the preserved piece, and a small amount Core Seal should be placed over the exposed wire to eliminate the wick effect. The preserved core is then placed in core boxes and the boxes left open for final quality control inspection. ,- '- ,- I 1 1- - '-- Wellsite Core Preservation Page 4 1--. Final Boxinq and Oualitv Control 1-.. Once all the core has been preserved and placed in the open core boxes, it should be checked for proper preservation and markings. Occasionally the Core Seal will be too thick to read the markings and if possible a marker should be used to mark the appropriate designations on the outside of the sample. waterproof markers seem to be best suited for writing on Core Seal. The core depths are then placed on the core boxes and the boxes packed and sealed for shipment. A wellsite inventory shall be completed for each core, and the boxes then placed in shipping crates. The core trailer should be cleaned and prepared for the next core to be preserved. J. 1- 1- L Recommended Tools and Materials l.. Core Seal Preservative (estimate one pound per foot of core) Melting Pot ( supplied with core trailer in PBU & KRU ) Saran Wrap or Handiwrap brand plastic wrap Aluminum Foil Plastic Sample Bags Plastic Tubing for nonpreserved sections Tape Measure Waterproof Markers (black and red) Lumber Crayons (yellow and white) Wire or Twine for dipping Core Boxes Strapping Tape Stapler Rock Hammer Large Chisel Screwdrivers and Nutdrivers Wirecutters Rags for wiping down core Skill Saw for cutting fiberglass inner barrel ( usually supplied by Coring Co.) cut-Off Saw with pump and fluid tank Drill Press (if special sampling required) Rubber Gloves Hardhat Safety boots and glasses Coveralls Cold Weather clothing L , - - .... - a o o 11 ~ III '<: ¡- !-' cooling racks Dip Tank ¡-. ~~ I I~ ¡- ~... - - - - Core Lay-out and Marking Area - - - - - - - ::To-:! o 11 1-'0 - - - o,c:: ..... <Q =' ::T <Q - - - o 8' I o 11 , - - - 11 (1) (f) - - - - - Sáran Foil Wrap Wire Wrap & Wrap Station Marking Station Station '0 P, 11 11 (1) f-" (f) I-' (f) I-' o c:: (f) rt J;1J I ~ 0 H1 H1 () o 11 (1) 'U 11 (1) (f) (1) 11 <: J;1J rt ..... o =' 0-3 11 III ....' I-' (1) 11 a ....' J;1J <Q 11 III S ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 9072761215 SHIPP~P TO: -- OPERATOR: ARCO ~.""'.'.~""'. . ., ".- .'" . . . , ~~ SMIPLE TRANSMITTAL Core Hand Carried by Core Lab DATE: June 8, 1987 Core Lab 8005 Schoon St. Anchorage, AK 99518 NAME: Kuparuk River Unit 3M-9 SAMPLE TYPE: NUMBER OF BOXES: 2 Pallets 6569.l-657l.3 657l.3-6573.3 6573.3-6575.4 6575.4-6577.2 6577.2-6578.0 Core 2 6579.0-658l.4 658l.4-6583.7 6583.7-6585.7 6585.7-fj587.7 6587.8-6589.8 6589.8-6592.l 6592.1-6594.4 6594.4-6596.8 6563.0-6565.3 6596.8-6598.8 6565'3-6567'2~6598.'8-6600.6 6567.2-6569.l 6 00.6-66 ,2~ SHIPPED BY: G Paleo Lab Tech UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND ~~IL A SIGNED COpy OF THIS FORÞl TO: - RECEIVED BY: 6602.7-6604.7 6604.7-6606.8 6606.8-6610.7 66l0.7-66l2.7 66l2.7-66l5.0 66l.5. 0-6617.4 66l7.4-66l8.5 Core 3 6637.0-6639.8 6639.8-6642.5 6642.5-6645.5 6645.5-6648.5 6648.5-6651.6 6651. 6-6654.2 6654.2-6656.9 6656.9-6657.6 ARCO ALASKA, INC_ P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab ABV/lOO DATE: SAMPLES SENT: Core 1 6531-6534.0 6534.0-6536.5 6536.5-6539.2 6539.2-654l.8 6541.8-6543.8 6543.8-6545.8 6545.8-6547.2 6547.2-6549.6 6549.6-6551.6 6551.6-6554.2 6554.2-6556.6 6556.6-6559.0 6559.0-6561.0 656l.0-6563.0 - - ARCO Alolko, Inc, 110 Sublldlory of AllonllcRlchti!'!dCompony I I .......-....., ~ ~ COR E LAB 0 RAT 0 R E S [ N C Arco Alaska, Inc. Date : 21-JUL-87 e No : BP-3-1221 KRU #3M-9 Formation : Kuparuk Laboratory : Anchorage Kuparuk River Unit Drlg Fld : Bland Mud Analysts: TLS,TDT North Slope, Alaska Location : T14N-R8E-Sec 25 API No : CONVENTIONAL CORE ANALYSIS SAMPLE DEPTH PERM MD He OIL % \.ITR % API GRAIN NUMBER FEET HORZ Ka POR PORE PORE OIL DEN M. DESCRIPTION .-- .. .. .. .. .. .. .......--- .. ........ .._-- ........ - - .. .. .. .. ..-.. -......................-..-................-....-- 229 6607.6 18.28 14.4 32.1 56.0 2.64 MDST,GYBLK,PRED ARG,MIC,TR SD,MNR SDY BURS,30-40%VFGR,SLTY,\.IELL CONS,INTBD SS 230 6608.4 7.05 20.4 40.1 29.1 2.67 SS,LTBRN,VFGR,SLTY,VWELL SRTO,S8RO-RD,\.IElL CONS,TR CARB FRAGS 231 6609.5 19.64 16.0 35.9 47.8 2.70 SS,LT-MBRN,VFGR,SLTY,VWELL SRTD,SBRD-RD,\.IELl CONS,50% ARG,SDY,SL CALC, LAM MDST,PYR 232 6610.5 10.24 16.2 36.0 35.1 2.67 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,50% ARG,SDY,SL CALC,BIOTURB MDST 233 6611.3 8_17 13.1 35.9 51.5 15 2.66 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,\.IELL CONS SS,PYR,HVY BIOTURB ** 234 6612.4 0.48 13.6 28.8 60.4 2.70 MDST,GYBLK,PRED ARG,SDY,SL CALC,40-50%VFGR,SLTY,\.IELL CONS SS,PYR BUR,BIOTURB 235 6613.6 2.56 14.5 53.7 12.1 2.66 MDST,GYBLK,PRED'ARG,SDY,SL CALC,40-50%VFGR,SLTY,\.IELL CONS SS,PYR,HVY 810TURB ** 236 6614.7 5.34 18.9 50_8 14.0 2.65 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS,MNR BIOTURB MDST 237 6615.9 0.89 15.8 43.4 32.6 2.64 SS,LTBRN,VFGR,SLTY,V\.IElL SRTD,S8RD-RD,50%PRED ARG,SDY,SL CALC,BIOTURB MDST 238 6616.5 1.78 15.5 45.9 32.1 19 2.82 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,50rRRED ARG,SDY,SL CALC,BIOTURB MDST,MASS PYR 239 6617.6 0.19 12.9 36.4 35.4 2.63 MDST,GYBLK,ARG,SDY,SL CALC,HVY BIOTURB,30-40%VFGR,SLTY,LAM ss 240 6618.3 7.61 13.7 33.5 53.6 2.64 MDST,GYBLK,ARG,SDY,SL CALC,30-40%VFGR,SlTY,INTBD SS ** CORE #3 6637.0 6657.6 301 6637.6 2.06 14.4 26_1 66.1 2.70 MDST,GYBLK,PRED SLTY,ARG,SL CALC,\.IELL CONS,20%VFGR,SLTY,INTBD SS ** 302 6638.5 319.24 14.9 35.1 49.6 2.67 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD, SBRD-RD,\.IELL CONS,30-40%SLTY,SDY,BDD MDST 303 6639.5 0.08 12.5 32.5 57.4 13 2.63 MDST,GYBLK,PRED ARG,SLTY,SL CALC,\.IELL CONS,MNR SDY BURS 304 6640.5 14.81 15.3 32.0 58.4 2.64 SS,LTBRN,VFGR,SLTY,V\.IELL SRTD,SBRD-RD,\.IELL CONS ** 305 6641. 5 8.36 13.3 31.0 48.1 2.62 MDST,GYBLK,PRED ARG, SLTY,Sl CALC,\.IELL CONS,20-30%LTBRN,VFGR,SLTY,INTBD SS,BIOTURB ** 306 6642.8 34.47 13.9 27.5 64.5 2.65 MDST,GYBLK,PRED ARG, SLTY,Sl CAlC,\.IElL CONS,20-30%LT8RN,VFGR,SLTY,INTBD SS,** 307 6643.7 D.06 13.5 27.6 56.8 2.65 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS 308 6644.6 321. 40 12.3 31.6 56.6 12 2.62 MOST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS,BIOTURB 309 6645.4 449.27 12_6 32.1 61.5 2.64 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS,BIOTURB 310 6646.3 20.79 13.4 30.1 58.0 2.64 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,SDY LAMS ** 311 6647.7 0.53 13.7 34.7 46.7 2.67 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,10%LTBRN,VFGR,SDY LAMS,BIOTURB ** 312 6648.7 42.57 11.5 15 67_0 2.66 MDST,GYBLK,PRED ARG, SLTY,SL CALC,\.IELL CONS,5%LTBRN,VFGR,INTBD SS ** ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 june 29, 1987 Mr. C. V. Chatterton COmmissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. If Sincerely, Gruber Associate Engineer OG/pk GRU1/31 Enclosure ^laska 0il & Gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanlicRIchlleldCompanY ADDENDUM WELL: 5/07/87 5/26/87 3M-9 RU Schl. Rn JB/GR to 6777' PBTD. Rn CBT f/6772'-5200'. Rn gYro f/6726'.surf. Rn Check Shot log. RD Schl. Arctic Pak well w/175 sx ASI & 61 bbls Arctic Pak. Drilling Supervisor 24 ~ 19 v!¢mtTY ~ $~,&LE I' · 2.¥1LES' ' NOTES: I. ALL COORDINATES &RE A.SJ). , ZONE 4. Z.AI.L DISTANt:tS SHOWN ME TNUE. ALL WELLS LOCATED IN SEC. 25, TI3N, R8E, UMIAT MERIDIAN. ASPs 'X' LATITUDE 506,156.45 K)6,14S.g8 506,155. ST 506,165.01' 506,114.6_3 SO6,184.1~ 506,193.5Z 506 ,Z0$. 14 506 506 ,Z41 506,251.O7 506,260.73 506,270.30 506,2:79.7 T $06,29"J.O5 506,308.1'6 ~ ~,*,, ~;7.9Z ~;~,,//7. ~,~ lb4.,) SIMPSON LAGOON $.ELEVATIONS &RE' B.R M. S.L. 4.REF. FIELD BOOK LeT-$ , PgL T-1~4 Le?-I ~ R ?; L e?-$,P 51 - 53; $.O.G.ELEVATIONS FROM ,.R. BELL & ASSOCIATES. 6.HOR,ZONTAL POSiTiONS BASED ON BM CI~.R~ ~ ~ ~ ~) MONUMENTS PER LHD ell ASSOCIATES. LONGITUDE 49o5 "23.659 .7'.23.868 7'24.094 ,49056'54,647 7~'Z7'/~. ~5~ /~f'57'~,; 7~'~7' /9. ~3 /~ST'D~. ~& t I HE.RElY CERTIFY THAT I Aid PROPERLY REGIS'~ERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADi[ BY ME OR UNDER ~" MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF $/8/87 MI) Dist. F..N.L. DIsLKF_L. 12~Jt' IT41' 25.1' 26.6' ,~: ,7~'. -.!'. . ~' ,,.: ,.4, ~.~, I I ~5 1675, 23. I, 26.6 ,~, ,s~. =,.T. 996: ,6,7: ,,.4'. ~.4: gSO, ISge',il.t: Z6.4~ ~04, ISTe i !0.~: 8B I 1569 ~0.~' 858' 1659' ~0.~' ~6.6~ 635 ' I~' Z~.~' Z5.9' ~, /7~/~ Z~.~' Z&.Z ' ARCO Alaska .Inc. D.S. 3M WELL CONDUCTOR AS-BUILT DWN BY: GLL CHK BY: AJR ARCO Alaska, Inc. Post Office~_x 100360 Anchorag~ ~ska 99510-0360 Telephone 907 276 1215 Date: May 26, 1987 Transmittal #5984 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 ~ Anchorage, AK 99510-0360 Transmitted herewith are the following'items. and return one signed copy of this transmittal. Please acknowledge receipt ~ · OH LIS Tape 5-2-87 72291 ~ 3M-8 / Re-Formated Field Tape 4-15-87 ~3M-6 / OH LIS Tape 4-21-87 72283 72274 C ka 0ii & Gas Cons Commms~.n ~- Anchorage Receipt Acknowledged: DISTRIBUTION: M. Stanford Date: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office~. 100360 Anchorage~ ;ska 99510-0360 Telephone 907 276 1215 Date:May 26, 1987 Transmittal # 5981 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return, one signed copy of this transmittal. CBT 5-6-87 ~~8 c]~T 5-6-87 '"' 2Z-5 CET 5-5-87 ~'~ 2Z-5 Squeeze & Retainer Record 5200-6772 7890-10003 7900-8129 8000-8138 5-5-87 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Chevron Mobil IE ~,~'Naska 0il & as Cons. Commission Anchorage Date: SAPC Union BPAE Vault (film) ARCO AlaSka, Inc. is a Subsidiary o! AflanticRichfieldCompany ' ' .~ STATE OF ALASKA ~ ALA~ ~,, OIL AND GAS CONSERVATION COM!, ~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Requesti Abandon [] Suspend [] Operation Shutdown~[] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO AlasKa~ Inc, RKB 63' feet~ 3. Al~drenss _..... Box 100360 Anchorage~ AK 9951 0-0360 4. Location of well at surface 1112' FNL~ 1665' FEL~ Sec.25~ T13N~ R8Es UN At top of productive interval 2129' FNLs 1190' FEL~ $ec.25~ T13N~ R8E~ UN (approx.) At effective depth 2037' FNL~ 11~+8' FEL~ Sec.25, T13N~ R8E~ UN (approx.) At total depth 20~+7' FNL~ 11~+6' FEL~ Sec.25~ T13N~ R8E~ UN (approx.) 11. Present well condition summary Total depth: measured 6880 "ND feet Plugs (measured) true vertical 6631 'TVD feet 5. Datum elevation (DF or KB) Unit or P..rqperty name ' uparuk ~ver Unit 7. Well number 3N-9 8. Permit number 87-29 9. APl number 50JZ29- 21710 10. Pool KulSaruk Rfver 0il Pool None Effective depth: measured 6780,ND true vertical 6532'TVD Casing Length Size Conductor 80' 16" Surface 3~48' 9-5/8" ProductJon 6869' 7" feet Junk (measured) feet None Cemented 198 sx CS II 1300 sx AS Iil & 335 sx Class G 300 sx Class G Measured depth 115'HD 3~85'ND 6869'ND True Vertical depth 115'TVD 3~8~'TVD 6620'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None Packers and SSS¥ (type and measured depth) None 12.Attachments Description summary of proposal [] WELL HISTORY & Addendum (dated .5/16/87) 13. Estimated date for commencing operation July~ 1987 Detailed operations program [] BOP sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge J/{0J ~z~_~~ TitleASS°Ciate Engineer Signed .~ Commission Use Only (Dani) 5A2/56 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel Approved by Date .. · Commissioner by order of the commission Form 10-403 Rev 12-1-85 Submit in triplicate A~O Oil and Gas Company Well History - Initial Report - Dally Inatmctlone: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are stmled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Euparuk River Auth. or W.O. no. AF~. AK2386 Doyon ~9 ARCO Alaska, Inc. Operator Spudded er W,O. begun Spudded 4/24/87 4/25/87 thru 4/27/87 4/28/87 4/29/87 4/30/87 Date and depth aa of 8:00 a.m. ICounty. parish or borough . North Slope Borough Lease °r Unit ADL 2~5'~3.,.. Title Drill State Alaska Well no. 3M-9 50-029-21710 4/23/87 [Hour Complete record for each day reported 0730 hrs. ARCO W.I. Prio'r statua if a W.O. 56.24% 16" @ 115' 3413', (3298'), Drlg Wt. 9.3, PV 20, YP 23, PH 9.0, WL 5.6, Sol 7 Accepted ri; @ 0200 hfs, 4/23/87. Spud well @ 0730 hrs~ 4/23/87. Slip & cut drl line Check diverter, ok. Drl to 3413'. 980', Assumed vertical 2953', 2.1°, N59.6E, 2952.37 TVD, 13.38 VS, N76.58, 25.78E EEEIVED 9-5/8" @ 3485' 4221', (808'), Drlg ,v,,~y 2 ! 1987 Wt. 8.6, PV 1, YP 1, PH 9.0, ~TL 12.8, Sol 2 Drl to 3500', short trip, CBU, POOH. RU Schl, rn Alaska Oil& Gas Cons. D[L/SFL/GR/SP/LSS, LDT/CNL/NGT/EPT/CAL, SHDT. Re-r~ EPT. Anchorage Shoot 55 SWC; rec'd 45. Make cond'g rn. R~ & z~88 Jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 3404', PS @ 3485'. Cmt w/1300 sxAS III & 335 sx Cl "G" w/2% S-1 & .2% D-46. Dtspl using rig pmps, bump plug. TIH, tag FC, tst csg; bled to 850 psi. RIH w/RTTS, csg tst good above FC. Pmp in @ 1400 psi below FC, POOH. TIH w/BHA, DO flt-equip & cmt + 10' new formation. Conduct formation tst to 12.5 ppg EMW. DD 8%" hole to 4221'. 3518', 0.7°, N43.3E, 3517.19 TVD, -15.09 VS, N33.96, 37.04E 3867', 13.6°, S34.7E, 3863.98 TVD, 14.16 VS, S13.06, 61.43E 9-5/8" @ 3485' 5787', (1566'), Drlg Wt. 9.1+. PV 6, YP 4, PH 9.0, WL 8.4, Sol 6 Drl & surv 8½" hole to 5787'. 4054', 21.5°, S35.8E, 4042.28 TVD, 69.65 VS, 32.99S, 93.97E 4991', 31.0°, S31.OE, 4832.31TVD, 566.03 VS, 472.95S, 324.97E 5557', 20.5°, S27.2E, 5337.35 TVD, 819.13 VS, 709.90S, 415.77E 9-5/8" @ 3485' 6464', (677'), Drlg Wt. 9.9, PV 11, YP 7, PH 8.0, WL 4.0, Sol 10 POOH. ~rl to 6464'. 5757', 18.3°, S26.0E, 5525.99 TVD, 885.54 VS, 769.30S, 445.52B 6339', 7.7°, S27.9E, 6093.31TVD, 1011.75 VS, 881.46S, 503.63E 9-5/8" @ 3485' 6579', (163'), Coring Wt. 10.0, PV 16, YP 8, PH 8, WL 5.0, Sol 10 Drl to 6531', CBU, POH. MU core bbl, TIH, core 6531'-6579'; jammed, POH. 6503', 5.6°, S13.9E, 6256.21TVD, 1030.69 VS, 899.20S, 510.40g The ab~e is correct Drilling, Pages 86 and 87. Date Title Drilling Supervisor ARCO Oil and Gas ComPany Daily Well History-Final Report Instruotions: Prepare and submit the "Final Reporl" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or 8old. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovere when an official test ia not required upon completion, report completion and representative test date in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFB AK2386 Doyon ~9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 5/Ol/87 Date and depth as of 8:00 a.m. 5/o2/87 thru 5/04/87 lCounty or Parish Lease or Unit Title Complete record for each day reported North Slope Borough ADL 25523 I Accountlng State coat center code Alaska IWell no. 3M-9 Drill API 50-029-21710 W.I. [Total number of wells (aotive or inactive) on this, Icost center prior to plugging and / 56,24I labandonment of this Well IHour I Prior etatul If a W.O. 4/23/87 / 0730 hrs. 9-5/8" @ 3485' 6660', (8'), Coring Wt. 10.0, PV 20, YP 10, PH 8, WL 4.8, Sol 10 Rec'd 47' f/core ~1. Core #2, 6579'-6637', rec'd 39.5'. #3, 6637'-6660', POOH w/core ~3. Core 7" @ 6869' 6880' TD, (6780'), RR 10.0 ppg Brine POOH w/core ~3, rec'd 21'. Drl 8½" hole to 6880', short trip, CBU, POOH. RU Schl, rn DIL/GR/SP/SFL f/6876'-3485', FDC/CNL f/6876'-6250', CAL f/6876'-6250' & SHDT f/6876'-surf cs$. RD Schl. Make wiper trip, spot diesel pill, POOH. RU & rn 158 its, 7", 26#, J-55 BTC dsg w/PC @ 6780', PS @ 6869'. Cmt w/100 sx 50/50 Pozz w/4% 9-20, .5I 9-65 & .2% 9-46 & 200 sx C1 "G" w/3l KCl, .9I 9-127, .3% D-13 & .2% D-46. Displ w/brine, bump plug. ND BOPE, instl tbg head, cst to 3000 psi. RR @ 0400 hfs, 5/3/87. 6880', 5.6°, S13.gE, 6631.41TVD, 1066.79 VS, 934.91S, 519.24B Old TD New TD Released rig Date 0400 hrs. Classifications (o11, gas, etc.) Oil Producing method Official reservoir name(s) Plowing Kuparuk Sands Potential test data PB Depth 6880' TD IKind of rig 5/3/87 I Type completion (single, dual, etc,) S ins le 6780' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gal per day Pump size, gpM X length Choke size T.P. C.P. Water % GOR Gravity Allowable ~ffeotlve date corrected The~v~ la correct For form pr~ffa/ation and distribution, see Proced~.e~ Manual, Section 10, Drillin~ Supervisor Drilling, Pages 86 and 87. ADDENDUM WELL: 5/07/87 3M-9 RU Schl. Rn JB/GR to 6777' PBTD. Rn CBT f/6772'-5200'. Rn gyro f/6726'-surf. Rn Check Shot log. RD Schl. ~ril~~- SuPervi ' ate THRU: . Lom3ie C:. Smith / ~' FROM: E~r W,. Sfpple, Jr. pe~'rOieU InSpeCtor FI LE NO.: May 6, 1987 D. EWS. 38 TELEPHONE NO.: SUBJECT: BOP Teat ARCO K~U 3M-9 Permit Ho. 87-29 K~pa~ liver Field a. tu~day~ April 2t.: 1987: i tra~led this date from ARCO's CPF 1, a BOP t~s~. The ~ll~g c~rac~o~ ~$ in te process, of ~nning casing. ~ $~y, ..Ap~i!. 26,_ ~98~: The SOp test coanen~d at .6..00 a.m. and was C~lu~d' aa ~7':Ig a.m. ~bere ~re no failures. I filled out ~he AOGCC BOP inspection report which is attached. In S~ry, I wi~essed the BOP Cest on ARCO's-3M-6, Doyon RiS g. Attac~nt . #4 5/84 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator Well Location: Sec Drillin8 Contractor Location, General General Housekeeping Reserve Pit Mud Systems Visual Trip Tank Pit Gauge Flow-Monitor Gas Detectors Well Sign Audio ' BOPE (stack ~ II ~.~e.~ams (91<11 ChOke L~e Valves ~ I~ ~ - ' Test Pressure 3oo0 300o H.C.R. Valve Check Valve Date~ Well Representative. -~,~ Permit # ~ tO'~Casing Set @ .. Representative ~ ACC~ATOR SYST~ Full Charge Pressure ~{~C} psig ~ Pressure Af~ter Closure ./:.~-'.~d psig /~0 Pump incr. clos..pres. 200 psig - O ~in~Osec. Co.froZe: ~aster ~(~ ~,~* ~~ Remote ~' Blinds swttca cover ~$ Kelly and iFloor S. afe.ty Valves Upper Kelly {} K~Test Pressure. Lower Kelly, ~k/Test Pressure Ball Type ~/{L~est Pressure Inside BOP *~ ~Test Pressure Choke Manifold O~',Test Pressure No. flanges~ Adjustable Chokes I-~ ~ Hydrauically operated choke ---- O Test Time / hrs. Test Results: Failures ,~ of failed equipment to be made within ~/~ days and Inspector/ Repair Replacement or Commission office notified. Remarks: Fc 7,'/0 Distribution orig. - AO&GCC cc - Operator cc - Supervisor / Inspecto NEW PROJECTS ENGINEERING TRANSMITTAL 1110 TO: John Boyle State DATE: April 27, 1987 FROM: H. D. White/P. S. Baxter WELL NAME: ~ TRANSMITTED HEREWITH ARE THE FOLLOWING: One copy of a blueline and sepia for each: ~2" Dual Induction - SFL ~5" Dual Induction - SFL ~2" Natural Ga~ Ray Spect~.Qmetry ~5" NatUral Gamma Ray SpeCtrOmetry Log ~2" Compensated Neutronlitho Density (poro) ~5" Compensated Neutronlitho Density (poro) ~'~2" Compensated Neutronlitho Density (raw) ~-~5" Compensated Neutronlitho Density (raw) ~2" Long Spacing Sonic 5" Long Spacing SOnic ~EPT/GR ~Stratigraphic High Resolution Dipmeter ~5" LDT High Resolution Pass ~25" LDT High Resolution Pass 4/24/87 run 1 4/24/87 run 1 4/2,4/87 run 1 4/24/87 run 1 4/24/87 run 1 4/24/87 run 1 4/24/87 run 1 4/24/87 run 1 4/24/87 run 1 4/24/87 run 1 4/~5/87 run 1 4/25/87 run 1 4/25/87 run 1 4/25/87 run 1 RECEIPT ACKNOWLEDGED: Anchorap. PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATTN: P. Susanne Baxter, ATO-1269 P. O. Box 100360 Anchorage, Alaska 99510 April 14, 1987 ~. J. B. Kewim Regional Dr!l!~ ~i. eer .~choraBe, Alaska 99510~36~ .Telecopy: (907) 276-7542 K~a~ ~fv.er U~.~I.: 3M-9 Rev.. ARCO Alas~, Pe~t No. 87~ . Sur. ~c. ili2'~, I~5'FEL, Sec. 25, T13N, R8E, Bt~ole Loc. 2208'~ Dear M~. ~tn: Enclosed is ~ aPproved revis~ ion for permit to drill the above ed ~1I; ' The provisions of the .cover le~, dated March 10, 1987, accomp, any~g ~e original approved p-e~t ~:. in effect for this revision. . c. v.' cbate_eMt Chairman of' ~aska 0il and ~s Conservation BY O~ER OF THE COMMISSION dlf Enclosure cc: Department of Fish & ~, Habitat Section w/o encl. Department of Environmental Conserva:lon w/o encl. Mr. ~u&, L, L~ery , ",u~, STATE OF ALASKA O~vl ALASKA AND GAS CONSERVATION C ISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill~ Redrill~l lb. Type of welI. Exploratory [-1 Stratigraphic Test [--I DevelopmentOil,~ Re-Entry Deepen Service [] Developement Gas [] Single Zone j~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1'0. Field and Pool ARCO Alaska~ Inc. EKD 63' PAD 26' · feet Kuparuk River Field p3 Address 6. Property Designation Kuparuk River 0il Poo ;0. Box 100360 Anchorage~ AK 99510-0360 ADL 25523 -ALK 2559 4. Location of well at surface 7~ Unit or property Name 11. Type Bond (see 20AAC 25.025) 1112'FNL, 1665'FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit: St:at:ewide 9At, top of productive interval 8. Well nurpber Number 212 FNL, 1190'FEL, Sec.25, T13N, R8E, UN 3M-9 #8088-26-27 At total depth ~,, ,¢¢,(,~,~.9. Approximate spud date Amount 2208'FNL, 1153'FEL, Sec.25, T13N,R~'E, UM 04/1~1/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 3M-8 6733 'MD 1112'~ Surface feet 25' ~ Surface feet 2560 (6436'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth3600 feet Maximum hole angle 39 0 aaxirnumsurface 2072 psig At total depth (TVD) 3076 psig 18. Casing programl Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 11.~' 4-200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 3465' 35' 35' 3500' 3500' 1200 sx AS III & HF-EI'.W 335 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 6699' 34' 34' 6733' 6436' 200 sx Class G(min~mun HF-ElitW T0C 5~)0' above t:op .of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth · · The sU.b~Jei::.t~- wle]l was originally approved 03/10/87 (APl No. 50-029-21710~ Permit: No. 87-29 however~'..due'.~:o Geological dat:a obt:ained from surrounding wells t:he bot:t:om hole locat:ion Ha rOl:d ,En.g.e'i "'.at- ..263 -4882 , . :. . -' · /: "':~S~ 20. Attachments F~l~ng fee [] Property plat [] BOP Sketch'l~)' D~verter Sketch ]~ Drilling program~l~ _ Drilling fluid .pr, p~m ~ Time vs ,depth plot [] Refraction analysis [] Seabed repo~'l'-I 20 AAC 25.050 requlrements.~ 21. I hereby,.,J'ertify/that the fore..g.ding.js true and correct to the best of my knowledge S i g n e d / ,//~_.~,/.O~~~~.~/ Title Date/~iZ~ · Rea~ onal Dri 1 1 i no Enai n~r ~-~"'"' ' // - - Commission Use Only ,,,~,,,, - ' Permit [ APl number I Approval date ' ........ ' I Se& ~6*e~r'l~tter Nu~nber~7-~,q-~ 50-- 0 ¢-q -~-~ 7[0 04/14/87 for other requirements Conditions of approval Samples required [] Yes /l~No Mud log required ILl Yes l~i['No Hydrogen sulfide measures,, [] Yes '~No !~il;ectional survey required '~Yes [] No Required working~:l/'~sure~rJ~'l~ ',Ji;j2a;~'~3a; []5M; [] 10a; [] 15M Other: ( /9/( /~" ///,~ by order of Approved by ~,-'~/,. ~~~f~' Commissioner the commission Date Subn 'iDlicate ~ : : ~ ~ ..... ~ ..... , ........ _I-1t~-: ~': ....... :-~ ::':': ::--':'~: ...... :-':"'-;:-1-:-:-: :~ ....... ; ........ :-':"':-'~:'=:'-~";:'":":: :: ~ - . ............ -.;: :.-: :. ~~~~~:': ........ :~_~_._..:. :-:~:: ...... : ........ ~: : .~ ....................... ~ ......... ~ : : ~ ........ ~~~ .... , ~;,", ', ~, ;I .... ;' ~~_, :., , : ' ..................... 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[ ' : : ' : i - - ~ ........ . ~ . ~ ] ............ 1':~ %-': "-' ~ ...... :-: ....... : t ' - ': .... i ~ ~ ..... ~ ...... 1~ ' :: :-: -:::-: ....... t .... !" . ' : ~ ' ' . ' .... '.'. ~ I .... I · ' ........... ,-_.. ~ ~ f .. ..........., ~' '~ i '~ ......... '-' ...... ~~ ...... ~ ............ ~. ~ -'~ ... i -- , . ~ .- ::-:. ::::.' :: ' ~' ' '' ~ ; ~-- ~ ......... l'~n~ · ' [.' i ..... , ....... -. ,~ .~ . . . T i ) ' . ........ ~ ! ~ ~~~ ..... .......... ~ . . , - . . ........ .......... ' ........... f T i ................ ...... i , i [ i i j i i i ........ :-: ....... : ..... ' : ............ : .......................... : ~-:.~ 4- :~:~::':~:~~:L./:/-~~~:..: .:.: ~:~-~: :-.:: ~-~--:~oo:-~.--~'_~ .~ ~'~:..~-}-.-~:.. ~...~~~s:~:' :/-; ~~',.~ .:~-:'.:.:.~-' .. ::.~- KUPARUK RIVER UNIT 20' DIVERTER SCHEI'IATIC I II DESCRIPTION 1, 16" CONDUCTOR 2. FfflC SLIP-ON ~tELD STARTING HEAD :5. FPlC DIVERTER ASSEPIBLY WITH 1%90 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PS1 DRILLIN~ SPOOL W/10" OUTLETS 5. 10" MCR BALL VALVES W/t0" DIVERTER LINES, A SINGLE VALVE OPENS AUT01flATICALLY UPON CLOSURE OF ANNULAR PI~.VENTER. VALVES CAN BE REI~OTELY CONTROLLED TO ACHIEVE DOWN, IN0 DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., RE-GUESTS APPROVAL OF THIS DIVERTER SYSTEI'I AS A ~ARIANCE FROM 20AAC25.035(b) fflAINTENANCE & OPERATION _G.I k. 2 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS iS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. 00 NOT SHUT IN WELL UNDER ANY ClRCUI'ISTANCES JG TI-$-86 7 6 il' - ~ I:~! X 13,-.,~/$~ - ~ I:~l :~::~ACI~ SFK)CL. 4~ 13,-5/8" - 50(X~ IW3l PIPE, ~ 5. 13-5/8' KLM.. 6. 13.-S/8' - ~ PSI ~ RNa W/PIPE ~ CN TC~o aI..IN3 ~ CN BOTTQa, 7. 13.-S/8' 5000 ~! AN~t.~- AC(3-MLRT(3R CAPACITY TEST I. C~ N~D FILL ~T~R I:~;~OIR TO ~ lEVEL glTH ~lC FLUID. ~ ~IT~, ~ ~ ~ ~~T~. 3. ~ ~ ~~ ~ ~ 8~T~Y 5 4 2 I I 1~-5/8" B(~ STA~ TEST I. FILL aCla STACK ~ Cl43~ M~3FCLO WITH ARCTIC 2. C}.ECK THAT ALL LOCI( ~ aCRE~ ZN ~rA~_~..ao ARE FLLLY RETRACTS. ~F. AT '1~ PI.I.~ ZN ItdELLI-F.,~} 6oa4',:,:,," ,~v.; MAY 15, 1~85 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 15-30 5-15 9-13 20-40 8-12 8-12 Viscosity 50-100 35-40 Initial Gel 5-15 2-4 35-45 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate AP1 20 10-20 pR 9-10 % Solids 10± 9.5-10.5 4-7 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Desasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drillin$ fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated usin$ a surface casin$ leak-off of 13.5 ppg EMW (Kuparuk averase) and a sas gradient of .11 psi/ft. This showe that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, A/{CO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary ~o control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezin$ fluid durin$ any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point accordin$ to directional plan. 4. Run open hole logs. 5. Run and cement 9-5/8" casing. 6. Install and test blow out preventer. Test casing to 2000 psig. 7. Drill out cement and 10' new hole. Perform leakoff test. 8. Drill 8½" hole to Kuparuk core point according to directional plan. 9. Core Kuparuk with water base polymer mud. 10. Continue drilling 8½" hole to provide 100' between plug back coral depth and bottom of Kuparuk sands. 11. Run and cement 7" casing. Pressure test to 3500 psiS. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 13. Nipple down blow out preventer and install temporary Xmas tree. 14. Secure well and release rig. 15. Run cased hole logs. 16. Move in workover rig. Nipple up blow out preventer. 17. Pick up 7" casing scraper and tubing, trip in hole Co plug back CoCa1 depth. Circulate hole with clean brine and trip ouC of hole standing tubing back. 18. Perforate and run completion assembly, set and test packer. 19. Nipple down blow out preventer and install Xmas tree. 20. Change over to diesel. 21. Flow well to tanks. Shut in. 22. Secure well and release rig. 23. Fracture stimulate. DE~R I'IUO CLEANER SHALE STIR STIR STIR SHAKERS Hi~E/13 £h IIUD CENTRIFUeE ~I. EANER TYPICAL IIUD $YSTEI1 SCHEMATIC ARCO Alaska, Inc. ~/ ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 27, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 9-9501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-18) Dear Mr. Chatterton: Enclosed is an as-built location!plat for the subject wells. you have any questions, please cal.1 me' at 263-4944. Sincerely, Gruber Associate Engineer If JG/db GRU1/31 Enclosure RECEIVED MAR 3 1 1987 Alaska 011 & Gas Cons. Commission Anchorgge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfteldCompany 24 ~' OLIKTOK PT, 19 SIMPSON LAGOON VICINITY MA_P SCALE I" t 2 Id ILES ALL WELLS LOCATED IN SEC. 25, !, NOTES: I. ALL COORDINATES ARE A.S.P., ZONE 4. 2.ALL DISTANCES SHOMd ARE TRUE. 3.ELEVATIONS ARE B.P.M.$.L. 4.REF. FIELD BOOK L87-$, Pg~. ?. I~..; L81,-I, R'r; L87-$,PSI $.0.G. ELEVATIONS FROId F.R. BELL & ASSOCIATES. 6.HORIZONTAL POSITIONS BASED ON 3id CONTROL MONUMENTS PER LHD & ASSOCIATES. ASPs 'X' LATITUDE LONGITUDE 4,016,f'02.11, 506, lZ6.99 70°2?'tg.TK'' ~o~. 6,01G,225.10 50G,166.45 6,248.21 506,145.98 ,271.24 506,155.57 016,294.28 506,165.01 1" 20.685 016,317.42 506,174.6;5 .T' 20.91:5 6,016,;540.48 506,184.16 i6'56.$16 ,016,$66.49 $06,196.52 58 , 506,Z06.14 506,252.O2 6 506,241.52 6, 506,z5~.07 70 6, 506,260.7'5 6,016,548.6:) 506,270.3,0 70°2T, 6,016,571.45 $06,279.77 TO°27, 6,016,594.7;5 50~,289.40 70°Z7 55.217 6,016,61 7.99 $06,E99.05 70027,25.868 54.935' 6,016,641.02 506,;508.76 70OZ7'24.094 49056'54.647 Oist. F.N.L. 1296 Z1,3 · ES0, ~7 ~04', 181 I 112', 042, 019' 996', 975 ~ 950', 904' 881' 858' Dis t.F.E.L. 11'41' I?$;) 1722 11'15 11'03 1694 1684 1675 IB65 1636 16 26 1617~ 1607 1598', 1588, 151'8, 1569 1559' O.G.Elev. Pod Elev. 23.1' 26.6' 23.3, 26.9, 23.4 26.8, 23.4', 26.8, 23.2, 26.6' 23. t, 26.6* 23.0, 26.4* 2 1.7, 26.51 2 I.S 26.5 21.4: 26.4~ 21.2 26.;5 2 I. I' 26.4'. ..o'. 2o.o; ~0.9 26.5 20.8' 26.6' t HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE ~,'~ - STATE OF AL"K' AND TI'IAT THIS 'I' ~'C' '''*'°" ! DS3M . PLAT REPRESE,TS A LOCATION_/.~..' __J~.~",o.'.; Ej · · SURVEY MAD/ BY ME OR UNDER ~,c0 / ~.=~_~F- MY SUPERVISION, AND THAT ALL ~ /49th~ ' '" - ...... ,.~ COR.ECT ~S OF ~/S/6; ; ~~~~ e~ CRAIG L 5Av~ ~rch 10, 1987 Mr. J. B. Kewi_n R~ional Drilltmg Engineer ARCO Alaska, Inc. P. O. Box 100360 Awchor~e, Alaska 9-9510-0360 Re: Telecopy: (907) 276-7542 Kupa~ River 'Unit 3M-9 ARCO: Alaska, Inc. Permit No. 87-29 Sur. Loc. lll2'FNL, 1665'FEL, Sec. 25, T13N, RSE, ~M. Btmhole ~c. 1994'~, l154'FEL, Sec. 25, T13N, RSE, DM. Dear Mr. Kewin: ~closed is' the approved application for persttt to drill the above referenced well. The permit to d~ill does not indemnify you from the probable need to obtain additional 'Pe~ts rewired by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling, field work, please notify this office 24 hours prior to commencing installation of the blowout.prevention equipment so, 'that a representative of the Cor~n~ lis ion may be present to ~tness testing of the equipment before the surface casing shoe is drilled. Where a d~Verter system is required, please also notify this office 21 ~rs prior to commencing equipment installation so that th~ ~misslon may witness testing b~'fore drilling below the shoe of' the conductor pipe. C. V, Chatterton' C~irman of Alaska Oil and Gas Conservation ~tssion BY ORDER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of ~rOnmental Conser~a~ion w/o encl. Mr. Doug L. Lowe~ . ~ STATE OF ALASKA C~~SlON ALASKA OIr--' AND GAS CONSERVATION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill '~1~' Redrill I-II lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepeni--II Service [] Developement Gas [] Single Zone [~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska· Inco RKB 63' · PAD 26' feet Kuparuk River Field ' Kuparuk River 0il Poo ,3. ,~,dd r~ss 6'APDr~)p~r~Y52D~s igAnl~l~i°~1.55 9 ~.u. ~ox 10'0360 Anchorage~ AK 99510-0360 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see ~0 AAC 25,025) 1112'FNL~ 1665'FEL~ 5ec.25~ T13N~ R8E~ UN Kuparuk R~ver Unit Sta~ew~de 1 9~t,~O~L~f ~~interval 8. Well number At total depth 9. Approximate spud date Amount 19~,'FNL~ 115~'FEL~ Sec.25~ T13N~ R~E~ UN 0~/12/87 $500~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 3N-8 66~8 ' ND 1112'~ Surface feet 25' ~ Surface feet 2.560 (6~39'TVD) feet , 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 2S.035 (e)(2)) Kickoff dept~5~6 feet Maximum hole angle 350 Maximum surface 2002 pslg At total depth ~VD) 3121 pslg 18. Oasing program ... Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2~" 16" 62.5~ H-~0 Weld 80' 35' 35~ 115' 115~ ~200 cf 12-1/~ 9-5/8" 36.0~ J-55 BTC 33~8' 35' 35' 3383~ 3383' 875 sx AS III & , HF-E{W 260 sx Class G blend 8-1/2" 7" 26.0~ J-55 BTC 661~' 3~' 3~' 66~8~] 6~39~ 200 sx Class G(min~mu~ HF;E{W TOC ~00~ abo~e top of Kuparuk 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 Oasing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~..' Intermediate Production ~,~-- ]4 Liner Perforation depth: measured AlaSkA 0ti ~ Gas Cons, true vertical 20. Attachments Filing fee ~ Property Plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program~' . Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed repor~ ~ 20 AAC 25.050 ~quirements~ 21. I hereby certi~[ the foregoin~ is true and correct t° the best of my knowledge . ~ '~~~~~~~ · Reg,onal Dr,11,ng Eng,neer e~~~ S~gned T~tle Dar /~ ~ /~ Commission UseOnly (HARRY) PD2/016 / Permit 'Num~_f'J APl number I Approval date I See cover letter ~2-~ I 50- o~q~[ 7l~ I 03/10/87 . j for other requirements Conditions of approval Samples requir~d ~ Yes ~No Mud Icg require~ ~ Yes ~No Hydrogen sulfide measures Q Yes ~No Directibnal survey required ~Yes Q No Required working ~ure for B~E~2M; ~ 3M; ~ 5M; ~ 10M; ~ 15M Other: / ~ ~/~,~~ [ /- // [ ~'/~ .~ ' " by order of Approved by ~ ~ ,~. ~ ~~~ Commissioner the commission Date~/D/~~v- ' Sul~jrn ate .i ) i 800 750 , ~00 i ! goo taoo ./. 7'00 i 650 - -.~40oo ' - 600 ~ · 5'50~ KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC DESCRIPTION 1. t6" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD ;5. FHC DIVERTER ASSEMBLY WITH T9/O 2-1/16" 2000 PSI BALL VALVES ,4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/lO* DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REHOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6, 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC.,~,:~OUESTS APPROVAL OF THISDIVERTER SYSTEH AS A:VARIANCE FROH 20AAC25.035(b) MAINTENANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR 6AS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE D(N/NWIND DIVERSION, DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 6 2 i1> ~DIAGRAM #) )3-5/8" ~JO0 PSI RSRRA BOP iSTA(~ I. 16' - 2000 P~! TAI~ 8TARTINO HEAD 2. I1' - ~ P~X CASINO HEAD 3. Il' - ~F~I X 1~8= - ~ ~I ~A~ ~ 4. 1~8" - ~ ~Z PZ~ ~ 5. 1~8" - ~ ~l ~Z~Z~ ~ W/~ ~ KI~ LI~ 6. 1~8= - ~~I ~ ~W~I~ ~ ~ ?. 1~8= - ~~I ~ ACOJVU, ATOR CAPACZTY TEST I. CHECI( AI~ FILL ACCLMJ.ATCIR RESERVOIR TO ~ LEVEL WITH HY~RNI.IC FLUID. 2. A88.RE THAT ~TCIR PRE:SELI~ I8 3000 PSI WITH 1500 PSI D(~id&TI~IM CF THE REg.LATC]R. 3. OBSERVE TII~o THEN (fl.0OE ~ UNIT8 $It4JLTA~CIJSLY AN3 RECI:I~ THE TIME ~ ~ REI~INZM3 AFTER ALL UNITS ~ CI.O~ED WITH CHNa3II~3 PLM: CFF. 4. RE~ ON ~ REPORT°TIE AO::EPTA~LE L~ LZIVlZT I8 45 SE~ CLC~IM3 13-5/8" BOP STACK TEST I. FILL i~P STACt( AN) CHOKE MN~IIFOLD WITH ARCTIC DIESEL. 2. a. ECI< THAT N.L LOCI( ~ ~ IN ~ ARE FUO. Y RETP,~CTED. SEAT TE~'r PI.T~3 IN ~ WITH RIJM4IN6 JT ~N3 ~ IN LOQ<DQIId LIllE VN.VES ~~ TO 90P 8T~CK. N.I. OTHER 4. ~ UP TO 260 ~N~I3 HOLD ~(3~ I0 MIN. IN- ~ ~ TO3000 F"3I ~ HQ.D FQ~ I0 MIN. 9LEED ~ TO 0 F"3I. LZ~E VALVE~. (:LO8[ TOP PIPE RNa6 ~ H(~ VN. VES 6. TEST TO 250 PSI ~ ~3000 F~I AS IN STEP 4. ?. (~NTINJE TESTIN6 ALL VN.VE~o LI~o N~D Q-K](E~ WITH A ~ PSI LOW ~ 3000 1~3I HIGH. TEST ~ IN STEP 4. ~x3 NaT ~ TEar ~u~r/ a4a~ T~u~T ~ NOT A ~ CL(]~IM3 ~TIVE SEAL ~. (31~.¥ 8. CPEN TC~ PIPE RNa6 ~ CL06[ BOTT(]VI PZF~ TEST BOTT(]vl PIPE RNV~ TO 2.60 PSI ~ 3000 PSI. 9. (]PEN BOTTCM PIPE RNV~o t~A(]( OUT RUN~IN6 JT IO. CLOSE 9LZN3 P, Nv~ ~ TEST TO ~60 PSI ~D 3000 PSI. ~IF~LD ~ LIF~,S ~E FULL CF N~N-~REEZIN6 FLUID. SET N.L VALVE~ IN DRILLIN6 PC~ITICN. 12. TEST ST~3PIPE VN.VESo KELLY° KELLY C0C~$o DRILL PIPE ~ VALVE, ~ INSIBE ~ TO 250 PSI 3OOO PSI. 13. RE~:TEST IFEOI~AATZON CN BLQNOUT Pt~ TEST ~(3F~4o $IGI~ N~) SEN3 TO DRILLIN6 SUPERVIS(~. 14. PERF~ ~ B(]:E TE~T N:TER NIPPLIN6 UP WEEKLY TH~ FUNCTI(3dN. LY CPERATE BCPE BAILY. 2 MAY 15, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-.13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit'Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. Will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level 'in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with. a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack Upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run open hole logs. 5. Run and cement 9-5/8" casing. 6. Install and test blow out preventer. Test casing to 2000 psig. 7. Drill out cement'and 10' new hole. -Perform leakoff test. 8. Drill 8½" hole to Kuparuk core point according to directional plan. 9. Core Kuparuk with water base polymer mud. 10. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of KuparUk sands. 11. Run and cement 7" casing. Pressure test to 3500 psig. 12. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 13. Nipple down blow out preventer and install temporary Xmas tree. 14. Secure well and release rig. 15. Run cased hole logs.. 16. Move~in work0ver rig.. Nipple up blow out preventer. 17. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth, circulate hole with clean brine and trip out of hole standing tubing back. 18. Perforate and run completion assembly, set and test packer. 19. Nipple down blow out preventer and install Xmas tree. 20. Change over to diesel. 21. Flow well to tanks. Shut in. 22. Secure well and release rig. 23. Fracture stimulate. IIUD CLEANER SHALE STIR STIR STIR SHAKERS HRE/13 ih PIUD CENTRIFUOE CLEANER TYPICAL ttUD SYSTEt'I SCHEMATIC m-r ,/ ' ............. ,',' ~ ~- 1. Is the fee attached .......................................... . (2) ~ ~ ~.~T~ 2. ~11 robe lo,ted ~ a ~d~l ............................. '8) ~11, Is ~11 l~ted p~ ~~.ce ~ p~~ 1~ .......... ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~~ ' ..... ~ ~11 lo.ted p~ ~s~ce ~ o~ ~lls ............ ' ..... Is ~ci~t ~~~ted a~e ~~ble ~ ~s ~1 .... ' ' ~ ~11 to be ~ted ~d is ~l~ore p~t ~l~d ....... , . 7. Is op~ator ~ ~y ~fected ~ .................... ~ .... . . ..~ ~~ ~./$-~T 8. ~ ~t be a~~d before f~~-~y ~t ......... ~.... .. (3) ~~ 9 ~s ~ b~d ~ force ' ' 10 ~ c~~e~m o~ ~e~d ' (9 ~ . a ...................................... , , ~~ ~ - ~j-~ r 11. I~ a~s~a~m a~~ -n~d ............................. ...... , .... (10 ~d 13) . 12. ~ ~ l~e~~ a~r~t~ . (4) ~g ~ 4./~-s7 "' ~ 22) 19. W~l all ~~ ~ a~te s~e~ ~ ~ll~se, t~i~ ~ ~st.. ~ . 20. Is ~ ~11 ~ be ~~d off ~ ~ ~st~ ~1~ ............ ] ~ . . ~. ~ old ~~re ~~t p~ce~e ~cl~d ~ 10-403 ............ ~,~ ...... , , ~ ~ a~te ~~ore se~a~ pr~sed ' ............................. , , ' ) ~. ~ a ~~~ ~t~r~ed 26. ~s ~ ~ ~~t ~~ ra~ - Test to 27. ~ ~ ~~ ~old ~ly w/~I ~-53 ~ 84) .................. ~. ~ ~ pr~~ of ~S g~ p~le ................................. [ For ~1o~~ ~d S~~~c ~1~: (6) ~ ~ .~. 29. ~ ~m p~~~ ~ ~tm~ ~~ z~? ................. (29 ~ 31) 30. ~ s~c ~ys~ ~ ~~ted ~ s~l~ ~ ~ .... , ....... 31. ~ ~o~s~re ~. ~ ~ ~~ of s~ ~~~ p~s~t~ (6) ,~: ~~ ~/~.~ 32. ~~~ ~ts ............................................. ,,,, ~: 01/28/87 6.011 (2) Loc ,~ ~"(~ '7 (2th~ 8) (8) 3 i/.._~7 11. (10 and 13) 12. 13. (14 thru 22) (23 thru 28) (6) GIMER Is the permit fee attached · ~ --- 2. Is well to be located in a defined P°°l .................. : .......... ~, 3.. Is well located proper distance from proper~ limm .................. ~ 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ~" 7. Is operator the only affected party ............................. .~... ~ 8 Can peim~t be approved before fifteen-day wait ~ · ® e® ~ee · · e® · ee®. eee ee® · 14. 15. 16. 17. 18. 19. 20. 21. 22. 24. 25. 26. 27. 28. Does operator have a bond in force ........................ . ......... Is a conservation order needed ...................................... Is administrative appr~,al-needed ............................. ...... Is the lease r~wnber appropriate ............. Does the well have a unique name and number ::::::::::::::::::::::::: Is conductor string prodded ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings .. Will c~ cover all known productive horizons .................... Will all .casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an exist~ wellbore ............ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required - Is the drilling ~luid program ,ch·mar_lc and lis~ o£ e~,~~t adequate Does ~ ~ sufficient pres~ rating - Tes~ to 3Ooo' psig .. ~ Does the choke manifold cc~ply w/API RP-53 (May 84) ............ , ..... Is the presence o£ H25 gas probable ................................. · ,, For exploratory and Stratigraphic wells: ~hru3~'/'/'~1~1 29. Are data presented on potential overpressure zones? ................. 31.' If an offshore .loc., are survey results of seabed eomditiorm presented-7~/~.. .:~ ,,, rev: 01/28/87 , 6.011' 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 roadability 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. LIS TAPE VERIFICATION LISTING JUN- 1 .Oil ,& Gas Cons. .MICROFILMED .VP OiO.H02 VERIFICATION LISTING PAGE I ~* REEL HEADER '~ ;ERVICE NAME :EDIT )ATE :87/05/ 8 ]RIGIN : ~EEL NAME :72291 ~ONTINUATION # :Oi ~REVIOUS REEL : ~OMMENTS :LIS TAPE, ARCO ALASKA, INC. 3M-9 (RUN l&2), API 50-029-21710 ~ TAPE HEADER ..~ ~ERVICE NAME :EDIT )ATE :87/05/ 8 )RIGIN :FSIA rAPE NAME : ;ONTINUATION # :OI ~REVIOUS TAPE : ;OMMENTS :LIS TAPE, ARCO ALASKA, INC. 3M-9 (RUN l&2), API 50-029-21710 ~ FILE HEADER ~ =ILE NAME :EDIT .OO1 ~ERVICE NAME : ~ERSION # : )ATE : ~AXIMUM LENGTH : 1024 =iLE TYPE : ~REVIOUS FILE : ~- INFORMATION RECORDS '~..-~- ~NEM CONTENTS ONIT ~YPE CATE SIZE CODE ~N : ARCO ALASKA, INC. 000 000 018 065 aN : 3M-9 (KUPARUK) 000 000 014 065 FN : KUPARUK 000 000 014 065 RANG: RSE 000 000 003 065 TOWN: T13N 000 000 004 065 SECT: S25 000 0.00 003 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 065 MNEM CONTENTS mmmm m~ mmm~mm UNIT TYPE CATE SIZE CODE PRES: E 000 000 001 065 ~ COMMENTS ~ .... ,VP 010.H02 VERIFICATION LISTING PAGE 2 : SCHLUMBERGER : ALASKA COMPUTING CENTER -~- .,..,..,..,..,..,..,..,..,..~..,..,, .,..,. -,..,. ;OMPANY = ARCO ALASKA~ INC. IELL = 3M-9 :IELD = KUPARUK ~DUNTY = NORTH SLOPE BOROUGH ;TATE = ALASKA JOB NUMBER AT AKCC: 72285 tUN #1~ DATE LOGGED: 24 APR 87 .DP: JIM KOHRING ~ASING FYPE FLUID )ENSITY IISCOSITY )H :LUID LOSS = 16.0" @ 115' - BIT SIZE = 12.25" TO 3486' : GEL SPUD MOD = 9.3 LB/G RM = 5,54 @ 68 DF = 72,0 S RMF = 5,23 @ 74 DF = 9.0 RMC = 4.09 @ 70 DF = 5.2 C3 RM AT BHT = 5.067 @ 75 OF 4AXIMUM RECORDED TEMPERATURE = 75 D.F. ~ATRIX SANDSTONE .VP 010.HOZ VERIFICATION LISTING PAGE 3 ~.~.-,--,--,- THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS .,--,--,--,-~'"'"'"'"'" ,. ......... ,..,.., .......... .,..,.., ....... .,.., ........ .,. .... ~ .,..,..~. :,.=. ~ ......... ,., .... .,..,. ...... ., ...... ,....., ............ ,. .... ,..,..,~ ~.,.., ........ ,~.,. ~ ~-- '" " '~ '"' "' "' "' "" '" SCHLUMBERGER LOGS INCLUDED WITH THIS FILE <RUN #1> · ~-~"~-~ FILE NAME = EDIT.O01 = <6" SAMPLE RATE> ~--,-~- DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIL) DATA AVAILABLE: 3479' TO 115' RUN #1 DIL MERGED WITH RUN #2 OIL AS FOLLOWS: SFLU/ILD/ILM/SP/TENS MERGE @3479' GR.DIL MERGED @3452' LITHO DENSITY COMPENSATED LOG (LDT) DATA AVAILABLE: 3494' TO 115' COMPENSATED NEUTRON LOG (LDT) DATA AVAILABLE: 3494' TO 115' .VP OlO.H02 VERIFICATION LISTING PAGE 4 IDB NUMBER AT AKCC: 72291 ,~UN ~2~ DATE LOGGED: 2 MAY 87 .DP: JIM KDHRING ;ASING tYPE FLUID )ENSITY IISCOSITY )H :LUID LOSS : 9.625" @ 3487' - BIT SIZE = 8.5" TO 6866' : KCL = 10.0 LB/G RM : 0.89 @ 68 DF = 41.0 S RMF = 0.35 @ 68 DF : 8'5 RMC = 0.89 @ 68 DF = 5.2 C3 RM AT BHT : 0.467 @ 136 DE IAXIMUM RECORDED TEMPERATURE ~ATRIX SANDSTONE ~'~'~-'-~' THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS '~'~"" .VP 010.H02 VERIFICATION LISTING PAGE 5 SCHLUMBERGER LOGS INCLUDED WITH THIS FILE <RUN ~2> .,-'"'~'~'-,-o,- FILE NAME = EDIT.O0! = <6" SAMPLE RAIE> ~=l~g -'-; DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIL) --~ DATA AVAILABLE: 6866' TD 3479' ~- RUN #1 OIL MERGED WITH RUN #2 OIL AS FOLLOWS: -~ SFLU/ILD/ILM/SP/TENS MERGED @3479' -,-"- GR . OIL MERGED @3452' -.-"' ~ FORMATION DENSITY COMPENSATED LOG (FDN) "- COMPENSATED NE~JTRON LOG (FDN) "-.,. DATA AVAILABLE: 6866' TO 6250' -,-'" -,. ~. **.. * ~-. ~ ~ ~ -,¥ ~. -,- -'.. -*- -'- .~ ~. -'- -'- ~ -'- -'- ~: * ~ ~ * ~ ~ ~.,..,. .,. .,. .,. ..,. ,..,..,...,..,..,. DATA FORMAT RECORD ~NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 i 66 0 4 I 66 1 8 4 73 60 9 4 65 .lIN 16 i 66 1 0 I 6 6 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. CODE (OCTAL) 2EPT FT O0 000 O0 0 0 4 I 68 00000000000000 SFLU DIL OHMM O0 220 01 0 0 4 1 68 00000000000000 ILM OIL OHMM O0 120 44 0 0 4 I 68 00000000000000 ILD DIL OHMM O0 120 46 0 0 4 I 68 00000000000000 SP DIL MV O0 -010 O1 0 0 4 I 68 00000000000000 GR OIL GAPI O0 310 01 0 0 4 1 68 00000000000000 .VP 010.H02 VERIFICATION LISTING PAGE 6 FENS DIL LB O0 ;R LOT GAPI O0 ;ALI LDT IN O0 IPHI LOT PU O0 IRAT LDT O0 {NRA LDT O0 ~CNL LDT CPS O0 =CNL LDT CPS O0 ~HOB LDT G/C3 O0 )RHO LDT G/C3 O0 )PHI LDT PU O0 ~E F LOT 00 ~LS LOT O0 ~SS LDT O0 .L LDT CPS O0 .U LDT CPS O0 .S LDT CPS O0 .ITH LOT CPS O0 ~S1 LDT CPS O0 SS2 LOT CPS O0 SSHV LDT V O0 LSHV LDT V O0 tENS LDT LB O0 ~R FON GAPI O0 ~ALI FDN IN O0 ~PHI FDN PU O0 ~RAT FDN O0 RNRA FDN O0 NCNL FDN CPS O0 FCNL FDN CPS O0 RHOB FDN G/C3 O0 DRHO FON G/C3 O0 DPHI FDN PU O0 TENS FDN LB O0 310 280 890 420 000 330 330 350 356 890 358 000 000 354 354 354 354 000 000 000 000 635 310 280 890 420 000 330 330 350 356 890 635 21 01 01 O0 01 O0 31 30 02 01 O0 01 O0 O0 01 01 01 01 O0 O0 O0 O0 21 O1 01 O0 01 O0 31 30 02 01 O0 21 DEPT SP CALI NCNL DPHI LL SS1 TENS NRAT RHOB 6898.5000 SFLU -74.7500 GR -999.2500 NPHI -999.2500 FCNL -999.2500 PEF -999.2500 LU -999.2500 SS2 -999.2500 GR 3.0547 RNRA 2.5488 DRHO DEPT SP CALI NCNL DPHI 6800.0000 SFLU -32.2187 GR -999.2500 N'PHI -999.2500 · FCNL -999.2500 PEF 3.4940 124.6250 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 124.6250 3.1133 0.0400 3.7396 106.3750 -999.2500 -999.2500 -999.2500 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 ! 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 3.0396 ILD 1920.0000 GR -999'2500 RNRA -999.2500 DRHO -999.2500 QSS -999.2500 LITH -999.2500 LSHV 8.4141 NPHI 1932.0000 FCNL 6.1316 TENS 2.9759 ILD 4328.0000 GR -999.2500 RNRA -999.2500 DRHO -999.2500 QSS 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 0000000000,0000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 .00000000000000 00000000000000 00000000000000 2.2447 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 35.1562 620.5000 1920.0000 2.8243 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 7 .L ;S1 'ENS ~RAT ~HOB )EPT ~P ~ALI ~CNL )PHI ,L ~S1 FENS qRAT ~HOB )EPT 3ALI 4CNL )PHI ~L TENS ~RAT RHOB DE PT SP CALI NCNL DPHI LL SS1 TENS NRAT RHOB DE PT' SP CALI NCNL DPHI LL SS1 TENS NRAT RHOB DEPT SP CALI NCNL -999.2500 LU -999.2500 SS2 -999.2500 GR 3.1055 RNRA 2.4766 DRHO 6700.0000 SFLU -32.0000 GR -999.2500 NPHI -999.2500 FCNL -999.2500 PEF -999.2500 LU -999.2500 SS2 -999.2500 GR 3.2656 RNRA 2.4180 ORHO 6600.0000 SFLU -37.7500 GR '-999.2500 NPHI -999.2500 FCNL -999.2500 PEF -999.2500 LU -999.2500 SS2 -999.2500 GR 2.8965 RNRA 2.2500 DRHD 6500.0000 SFLU -36.6875 GR -999.2500 NPHI -999.2500 FCNL -999,2500 PEF -999,2500 LU -999.2500 SSZ -999.2500 GR 4.6445 RNRA 2.2598 DRHO -999.2500 tS -999.2500 LITH -999,2500 SSHV -999.2500 LSHV 106,3750 CALl 8.6016 NPHI 3,0820 NCNL 2064,0000 FCNL 0.0117 DPHI 10.5114 TENS 2.8015 ILM 2.3721 ILO 103.6875 TENS 4272.0000 GR -999.2500 NRAT -999.2500 RNRA -999.2500 RHOB -999.2500 DRHO -999.2500 QLS -999.2500 QSS -999.2500 tS -999.2500 LITH -999.2500 SSHV -999.2500 LSHV 103.6875 CALI 8.5078 NPHI 3.2832 NCNL 1907.0000 FCNL -0.0059 OPHI 14.0625 TENS 26.9696 ILM 16.7560 ILD 68.0625 TENS 4172.0000 GR -999.2500 NRAT -999.2500 RNRA -999.2500 RHOB -999.2500 DRHO -999.2500 QLS -999.2500 QSS -999.2500 LS -999.2500 LITH -999.2500 SSHV -999.2500 LSHV 68.0625 CALl 8.4531 NPHI 2.8418 NCNL 2296.0000 FCNL -0.0117 DPHI 24.2424 TENS 1.6588 ILM 1.2889 ILD 107.5000 TENS 4074.0000 GR -999.2500 NRAT -999.2500 RNRA -999.2500 RHOB -999.2500 DRHO -999,2500 QLS -999,2500 QSS -999.2500 LS -999,2500 LITH -999,.2500 SSHV -999,2500 LSHV 107.5000 CALI 10.7578 NPHI 4.7773 NCNL 1867.0000 FCNL 0.0049 DPHI 23.6506 TENS 6400.0000 SFLU 2.1936 ILM 1.9290 ILD -43.2500 GR 101.8125 TENS 4064.0000 'GR -999.2500 NPHI -999.2500 NRAT -999.2500 RNRA .-999.2500 FCNL -999.2500 RHOB -999.2500 DRHO -999.2500 PEF -999.2500 QLS -999.2500 QSS -999.2500 LO -999.2500 LS -999.2500 LITH -999,2500 SS2 -999,2500 SSHV -999,2500 LSHV -999.2500 GR 101.8125 CALI 9.6641 NPHI 3..8379 RNRA 3.8887 NCNL 1666.0000 FCNL 2.4063 DRHO -0.0200 DPHI 14.7727 TENS 6300.0000 SFLU 3.0012 ILM 2.3597 ILO -46.9687 GR 142.8750 TENS 4054.0000 GR -999.2500 NPHI -999.2500 NRAT -999.2500 RNRA -999.2500 FCNL -999.2500 RHOB -999.2500 DRHD -999.2500 -999.2500 35,7910 669,5000 4328.0000 2.3031 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 38.8672 580,5000 4272.0000 16.5686 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 32.4219 807.5000 4172.0000 1.2179 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 60..8887 390.5000 4074.0000 1.8962 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 47.6563 428.2500 4064.0000 2.3143 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 8 )PHI -999.2500 PEF .L -999.2500 LU ;Si -999.2500 SS2 'ENS -999.2500 GR IRAT 3.7617 RNRA ~HOB 2.3574 DRHO )EPT 6200.0000 SFLU ;P -51.2500 GR 3ALI -999.2500 NPHI ICNL -999.2500 FCNL )PHI -999.2500 PEF .L -999.2500 LU ;S1 -999.2500 SS2 FENS -999.2500 GR IRAT 3.7285 RNRA · ~H06 2.3711 ORHO )EPT 6100.0000 SFLU ;P -51.2813 GR :ALI -999.2500 NPHI ~CNL -999.2500 FCNL )PHI -999.2500, PEF ~L -999.2500 LO ~S1 -999.2500 SS2~ FENS -999.2500 GR ~i!RAT 3.2168 RNRA ~HOB 2.4375 DRHO )EPT 6000.0000 SFLU ~P -53.6875 GR ~ALI -999.2500 NPHI ~CNL -999.2500 FCNL )PHI -999.2500 PEF -L -999.2500 LU SSI -999,2500 SS2 FENS -999.2500 GR ~RAT 3.1641 RNRA ~HOB 2.4648 DRHO )EPT 5900.0000 SFLU SP -56.1562 GR :ALI -999.2500 NPHI ~CNL -999.2500 FCNL 2PHI -999.2500 PEF LL -999.2500 LU SS1 -999.2500 SS2 FENS -999.2500 GR gRAT 2.9316 RNRA RHOB 2.5078 DRHO 2EPT 5800.0000 SFLU SP -59.7188 GR CALI -999.2500 NPHI -999.2500 -999.2500 -999.2500 142.8750 3.8379 0.0088 3.5555 216.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 216.2500 3.9473 -0.0063 4.1893 105.6875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 105.6875 3.1660 0.0063 3.6900 95.6875 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 95.6875 3.0254 0.0215 ~.0962 89.3125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 89.3125 3.2617 0.0537 3.5773 114.8750 -999.2500 QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSH~' CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT -999.2500 QSS -999.2500 LITH -999.2500 LSHV 9.3203 NPHI 1723.0000 FCNL 17.7320 TENS 2.4854 ILD 4120.0000 GR -999.2500 RNRA -999.2500 DRHO -999.2500 QSS -999.2500 LITH -999.2500 LSHV 9.0313 NPHI 1846.0000 FCNL 16.9034 TENS 3.3317 ILO 3974.0000 GR -999.2500 RNRA -999.2500 DRHO -999.2500 QSS -999,2500 LITH -999.2500 LSHV 10.1953 NPHI 1781.0000 FCNL 12.8788 TENS 3.2347 ILD 3924.0000 GR -999.2500 RNRA -999.2500 DRHO -999.2500 ~SS -999.2500 LI'TH -999.2500 LSH~ 10.5'391 NPHI 1786.0000 FCNL 11.2216 TENS 5.3944 ILD 3824.0000 GR -999.2500 RNRA -999.2500 DRHO -999.2500 QSS -999,2500 LITH -999.2500 LSHV 9,3516 NPHI 2334.0000 FCNL 8.6174 TENS 3.2228 ILO 3740.0000 GR -999.2500 RNRA -999.2500 -999.2500 -999.2500 46.7285 448.7500 4054.0000 2.3285 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 46.5820 467.5000 4120.0000 3.2477 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 35.4980 562.5000 3974.0000 3.1351 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 33.9844 590.0000 3924.0000 5.6387 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 31.8359 715.5000 3824.0000 3.2629 -999.2500 -999.2500 .VP OiO.H02 VERIFICATION LISTING PAGE 9 4CNL )PHI .L ;S1 FENS ~RAT JHOB )EPT ~P :ALI 4CNL ]PHI ,L 5Sl TENS NRAT RHOB gEPT SP CALI NCNL DPHI LL SS1 TENS NRAT RHOB -999.2500 FCNL -999.2500 RHOB -999.2500 PEF -999.2500 QLS -999.2500 LU -999.2500 LS -999.2500 SS2 -999.2500 SSHV -999.2500 GR 114.8750 CALI 3.1875 RNRA 3.3223 NCNL 2.3965 DRHO 0.0205 DPHI 5700.0000 SFLU 3.0900 ILM -60.2187 GR 109.6250 TENS -999.2500 NPHI -999.2500 NRAT -999.2500 FCNL -999.2500 RHOB -999.2500 PEF -999.2500 QLS -999.2500 LU -999.2500 LS -999.2500 SS2 -999.2500 SSMV -999.2500 GR 109.6250 CALI 3.2402 RNR~ 3.1191 NCNL 2.4023 DRHO -0.0073 DPHI 5600.0000 SFLU 3.6854 ILM -61.6875 GR 93.3750 TENS -999.2500 NPHI -999.2500 NRAT -999.2500 FCNL -999.2500 RHO8 -999,2500 PEF -999,2500 QLS -999,2500 LU -999,2500 LS -999,2500 SS2 -999,2500 ·SSHV -999°2500 GR 93,3750 CALI 3,4297 RNRA 2.9727 NCNL 2,4395 DRHO 0,0264 OPHI DEPT 5500.0000 SFLU 3.6738 ILM SP -64,2500 GR 93.7500 TENS CALI -999.2500 NPHI -999.2500 NRAT, NCNL -999.2500 FCNL -999.2500 RHOB DPHI -999.2500 PEF -999.2500 QLS LL -999.2500 LU -999.2500 LS SS1 -999.2500 SS2 -999.2500 SSHV TENS -999.2500 GR 93.7500 CALI NRAT 3.1934 RNRA 3,Z129 NCNL RHOB 2,4316 DRHO 0.0654 DPHI DEPT 5400,0000 SFLU 2.9951 ILM SP -64.1875 GR 110.0625 TENS CALI -999,2500 NPHI -999.2500 NRAT NCNL -999.2500FCNL -999.2500 RHOB DPHI -999.2500 PEF -999.2500 QLS LL -999,2500 LO -999.2500 LS SS1 -999,2500 SS2 .-999,250'0 SSHV TENS -999.2500 GR 110,0625 CALI NRAT 3.3340 RNRA 3.1719 NCNL RHOB 2.3789 DRHO -0.0063 DPHI DEPT 5300.0000 SFLU 3.1431 ILM SP -66.9375 GR 99.9375 TENS -999.2500 DRHO -999.2500 QSS -999,2500 LITH -999.2500 LSHV 13,0000 NPHI 1933.0000 FCNL 15.3646 TENS 3,2033 ILO 3660,0000 GR -999,2500 RNRA -999.2500 DRHD -999,2500 QSS -999.2500 LITH -999.2500 LSH¥ 10.9922 NPHI 2054.0000 FCNL 15.0095 TENS 3,4048 ILD 3534,0000 GR -999,2500 RNRA -999,2500 DRHO -999;2500 QSS -999,2500 LITH -999,2500 LSHV 9.5703 NPHI 1725.0000 FCNL 12.7604 TENS 4.0686 ILD 3484,0000 GR -999,2500 RNRA -999,2500 .DRHO -999,2500 "QSS -999,2500 LITH -999,2500 LSHV 12,9687 NPHI 2092.0000 FCNL 13.2339 TENS 3.0308 ILD 3424.0000 GR -999.2500 RNRA -999.2500 DRHO -999.2500 QSS -999.2500 LITH -999.2500 LSHV 11.4688 NPHI 2019.0000 FCNL 16.4299 TENS 3.2567 ILD 3360.0000 GR -999,2500 -999,2500 -999,2500 -999,2500 33,1055 581,5000 3740.0000 3,0433 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 35,0098 658.5000 3660.0000 3,3752 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 40.2832 580.0000 3534.0000 4.1243 -999,2500 -999,2500 -999,2500 -999.2500 -999,2500 -999,2500 33.2031 651.0000 3484.0000 2.9465 -999,2500 -999,2500 -999.2500 -999.2500 -999,2500 -999,2500 36,4746 636,5000 3424,0000 3.1880 -999.2500 .¥P OlO.H02 VERIFICATION LISTING PAGE 10 ~ALI -999,2500 NPHI -999,2500 tCNL -999.2500 FCNL -999,2500 )PHI -999.2500 PEF -999,2500 .L -999,2500 LU -999.2500 ;S1 -999,2500 SS2 -999,2500 ~ENS -999.2500 GR 99.9375 ~RAT 3.1113 RNRA 3.0000 ~HOB 2.3906 DRHO 0.0381 )EPT 5200.0000 SFLU 2.4365 ~P -71.6250 GR 109.5625 3ALI -999.2500 NPHI -999.25'00 ~CNL -999,2500 FCNL -999,2500 )PHI -999,2500 PEF -999,2500 -L -999,2500 LU -999,2500 ~S1 -999,2500 SS2 -999,2500 rENS -999,2500 GR 109,5625 ~RAT 3.1621 RNRA 3.2305 ~HOB 2.3672 DRHO 0.0161 ]EPT 5100.0000 SFLU 2.4025 SP -70.7500 GR 108.8125 CALI -999.2500 NPHI -999.2500 ~:CNL -999.250,0 FCNL -999.2500 DPHI -999,2500 PEF -999,2500 LL -999,2500 LO -999,2500 S,S1 -999.2500 SS2 -999.2500 TENS -999.2500 GR 108.8125 NRAT 3.4961 RNRA 3.9648 RHOB 2.3555 DRHO 0.0132 DEPT 5000.0000 SFLU 3.1465 SP -72.0000 GR 118.7500 CALI -999.2500 NPHI -999.2500 NCNL -999,2500 FCNL -999,2500 DPHI -999.2500 PEF -999.2500 LL -999.2500 LU -999.2500 SSI -999,2500 SS2 -999,2500 TENS -999.2500 GR 118.7500 NRAT 3'4844 RNRA 3.7168 RHO8 2.3301 DRHO 0.0044 DEPT 4900.0000 SFLU 2.5335 SP -73.2500 GR , 117.4375 CALI -999.2500 NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 DPHI -999.2500 PEF -999.2500 LL -999.2500 LU -999.2500 SS1 -999.2500 SS2 -999.2500 TENS -999.2500 GR 117.4375 NRAT 4.1289 RNRA 4.5195 RHOB 2.2656 DRHO 0.0190 NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS. LS SSHV CALI NCNL OPHI TENS NRAT RHO8 QLS LS SSHV CALI NCNL DPHI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12.4297 1918.0000 15.7197 2.4089 3250.0000 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 10.6953 1953.0000 17,;1402 2.3879 3090.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.8047 1859.0000 17.8504 2.9844 3014.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11.0156 1859.0000 19.3892 2.1506 2994.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.4609 1618.0000 23,2955 RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILO GR RNRA DRHO qss LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPH'I FCNL TENS' ILD GR RNRA DRHO qSS LITH LSHY NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 32.1777 639.0000 3360.0000 2.3784 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 33.6914 604.5000 3250.0000 2.3403 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 39.7949 468.7500, 3090.0'000 ].o2ov -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 39.4531 500.0000 3014.0000 2.0001 -999.2500 -9gg.2500 -9gg.2500 -999.2500 -999.2500 -999.2500 51.8066 357.7500 299,4.0000 DEPT 4800.0000 SFLU 3.6947 ILM 3.7103 ILO 3.8061 .VP OIO.H02 VERIFICATION LISTING PAGE 11 ;P -73.6875 GR ;ALI -999.2500 NPHI ICNL -999.2500 FCNL )PHI -999,2500 PEF .L -999,2500 LU iS1 -999.2500 SS2 FENS -999.2500 GR tRAT 3,3145 RNRA ~HOB 2.3320 DRHO )EPT 4700,0000 SFLU ~P -78.2500 GR 3ALI -999.2500 NPHI ~CNL -999.2500 FCNL )PHI -999.2500 PEF .L -999.2500 LU ~S1 -999,2500 SS2 FENS -999,2500 GR qRAT 3.6523 RNRA ~HOB 2.3301 DRHO DEPT 4600.0000 SFLU SP -79,0000 GR CALI -999.2500 NPHI NCNL -999,2500 FCNL DPHI -999,2500 PEF kL -999.2500 LU SSi -999.2500 SS2 TENS -999.2500 GR NRAT 3.3535 RNRA R'HOB 2.3496 DRHO DEPT 4500,0000 SFLU SP -79,5625 GR gALI -999,2500 NPHI NCNL -999,2500 FCNL DPHI -999,2500 PEF LL -999.2500 LU SS1 -999,2500 SS2 TENS -999,2500 GR NRAT 3.6641 RNRA RHOB 2,2930 DRHO DEPT 4400,0000 SFLU SP -82,2500 GR CALI -999.2500 NPHI NCNL -999,2500 FCNL DPHI -999.2500 PEE LL -999.2500 LD SSl -999.2500 SS2 TENS -999.2500 GR NRAT 3.4'531 RNRA RHOB 2.3242 DRHO 138.8750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 138.8750 3.2930 0.0107 2.0820 97.-7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 97.7500 3.4063 0.0166 2.6022 104.9375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.9375 3.4980 0,0122 2.8232 104,1250 -999,2500 -999.25.00 -999.2500 -999.2500 -999.2500 104.1250 3.3867 0.0166 3.6970 109.8750 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 109.8750 3.4863 0.0073 TENS NRAT RHOB QLS LS SSHV CALl NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL OPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS. NRAT RHOB QLS SSHV CALI NCNL DPHI 2920.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11.5469 1756.0000 19,2708 2,0795 2814,0000 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 9.8594 1693.0000 19,3892 2.7512 2690.0000 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 9.8203 1972.0000 18.2055 2.8592 2694.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9.6016 1650,0000 21.6383 3.9215 2690.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 8.9141 1996.0000 19.7443 GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHY NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH L SHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LiTH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 36.0840 533.0000 2920.0000 2.0372 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 43.9453 49'7.0000 2814.0000 2.7173 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 38.52.54 563.5000 2690.0000 2.9546 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 44.5801 487.0000 2694.0000 3.8038 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 41.7480 572.5000 2690.0000 _VP OlO.H02 VERIFICATION LISTING PAGE 12 )EPT 4300.0000 SFLU ~P -84.0000 GR ]ALI -999,2500 NPHI ~CNL -999.2500 FCNL )PHI -999.2500 PEF .L -999,2500 LU ~S1 -999,2500 SS2 FENS -999,2500 GR ~RAT 3.1387 RNRA ~HOB 2.3281 DRHD 2.9204 97.0625 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 97.0625 3.2871 0.0405 )EPT 4200.0000 SFLU 5P -86.4375 GR CALI -999.2500 NPHI qCNL -999.2500 FCNL 2PHI -999.2500 PEF LL -999.2500 LU SS1 -999.2500 SS2 TENS -999.2500 GR NRAT 3,1289 RNRA RHOB. 2,2949 DRHO 5.8233 100.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 100,2500 3.1348 0.0151 DEPT 4100.0000 SFLU SP -88.1875 GR CALI -999.2500 NPHI NCNL -999.2500 FCNL DPHI -999.2500 PEF LL -999.2500 SSi -999.2500 SS2 TENS -999.2500 GR NRAT 3.5391 RNRA RHOB 2,2773 DRHO 3,8176 101,1250 -999,2500 -999,2500 -999,2500 -999,2500 -999,2500 101,1250 4.0000 0.0225 DEPT 4000,0000 SFLU SP -88,9375 GR CALI -999,2500 NPHI NCNL '-999,2500 FCNL DPHI -999,2500 PEF LL -999.2500 LU SS1 -999.2500 SS2 TENS -999,2500 GR NRAT 3,4316 RNRA RHOB 2,2480 DRHO 3.7855 94.6250 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 94.6250 3.2793 0.0~83 DEPT 3900.0000 SFLU SP -89.6875 GR CALI -999.2500 NPHI NCNL -999,2500 FCN[ DPHI -999.2500 PEF LL -999.2500 LU SS1 -999,2500 SS2 TENS .-999.2500 GR NRAT 3,4668 RNRA RHOB 2,3027 DRHO 3.1669 96.8125 -999.2500 -999.2500 -999.2500 -999.,2500 -999.2500 96.8125 3.1152 0.0732 ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS tS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALi NCNL DPHI 3.1216 2614.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10,4141 1772,0000 19.5076 5.1730 2580.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9.7031 2142,0000 21.5199 3.7818 2464,0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.1406 I915.0000 22.5852 3.6641 2384.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 I0.6016 1624.0000 24.3608 3.2892 2360.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.5391 1633.0000 21.0464 ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILO GR RNRA DRHD QSS LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILO GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS 3.1319 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 33.6914 539.0000 2614.0000 4.8446 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 34.6191 683.0000 2580.0000 3.8883 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 41.4551 47B.7500 2464.0000 3.8929 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 '-999.2500 38.8184 495.0000 2384.0000 3.3951 -999.2500 '-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 39.5508 524.0000 2360.0000 .VP OIO.H02 VERIFICATION LISTING PAGE 13 )EPT 3800,0000 SELU ;P -92,8750 GR ;ALI -999,2500 NPHI ~CNL -999,2500 FCNL )PHI -999.2500 PEF .L -999.2500 LD ~S1 -999.2500 SS2 FENS -999.2500 GR ~RAT 2.9863 RNRA ~HOB 2.3535 DRHO )EPT 3700.0000 SFLU SP -95.4375 GR 3ALI -999.2500 NPHI qCNL -999.2500 FCNL )PHI -999.2500 PEF ~L -999.2500 LU SS1 -999,2500 SS2 lENS -999,2500 GR ~RAT 3,5254 RNRA RHOB 2.2187 DRHO DEPT 3600.0000 SFLU SP -94.7500 GR CALI -999.2500 NPHI N.~NL -999.2500 FCNL DPHI -999.2500 PEF LL -999.2500 LU SS1 -999.2500 SS2 TENS -999.2500 GR NRAT 3.8398 RNRA RHOB 2.1016 DRHO DEPT 3500.0000 SFLU SP -91.5625 GR CALI -999.2500 NPHI NCNL -999.2500 FCNL DPHI -999.2500 PEF LL -999.2500 LU SS1 -999,2500 SS2 TENS -999.2500 GR NRAT 4,2930 RNRA RHOB 2,0859 DRHO DEPT 3400.0000 SFLU SP -37.0000 GR CALI 12.7578 NPHI NCNL 1674.0000 FCNL DPHI 25.6836 PEF LL 216.1250 LU SS1 219,0000 SS2 TENS 2060,0000 GR NRAT 4.4063 RNRA 4.3319 98.8125 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 98.8125 2,8828 0.0063 4.0642 104.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 104.2500 3.6875 0.0107 1.4511 92.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 92.5000 4.1875 0.0479 2,8204 93.9375 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 93.9375 4.7891 0.0210 4,4973 79.1875 48,2910 416,5000 2,6484 371.0000 321,5000 56.3T50 4.6211 ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHOB QLS LS SSHV CALI NCNL DPHI ILM TENS NRAT RHO8 QLS LS SSHV CALI NCNL 4.6409 2290.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.7266 1911.0000 17.9688 4.3125 2114.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.3281 1658.0000 26.1364 1.3316 2084.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12.0391 1383.0000 33.2386 3.1916 2150.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 15.4297 1433.0000 34.1856 4,4261 2060.0000 4.0117 2,2246 0,0000 401.7500 1211,0000 9.0547 1167.0000 ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILO GR DRHO QSS LITH LSH¥ NPHI FCNL TENS ILO GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS IlO GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LIT'H LSHV NPHI FCNL 4.3209 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 30.9570 662.5000 2Z90.0000 4.4586 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99,9.2500 40.9180 449.5000 2114,0000 1.3450 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 45.5078 330.0000 2084.0000 3.9432 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 52.1973 299.0000 2150.0000 4.3541 79.1875 4.0156 -0.0083 0.0132 121,4375 1141.0000 58.9844 252.3750 .VP 010.H02 VERIFICATION LISTING PAGE 14 :HOB 1.9707 DRHO -0.4048 DPHI 41.1695 TENS 2120.0000 IEPT 3300.0000 SFLU 3.5674 ILM 3.6386 ILD 3.7426 ;P -35.8125 GR 72.4375 TENS 2010.0000 GR 72.4375 ~ALI 13.1406 NPHI 49.6582 NRAT 4.0977 RNR~ 4.2148 ICNL 1649.0000 FCNL 391.0000 RHOB 2.2773 ORHO 0.0493 IPHI 22.5098 PEF 2.9727 QLS 0.0059 QSS 0.0830 .L 218.2500 LU 371.5000 LS 404.0000 LITH 115.2500 ;S1 243.3750 SS2 324.2500 SSHV 1211.0000 LSHV 1141.0000 'ENS 2010.0000 GR 55.4063 CALI 9.0781 NPHI 55.0293 IRAT 4.1914 RNRA 4.4961 NCNL 1270.0000 FCNL 282.2500 ~HOB 1.9463 DRHO -0.4546 OPHI 42.649.1 TENS 2074.00§'0 )EPT 3200.0000 SFLU 4.4142 ILM 3.8048 ILD 3.7870 ;P -36.6563 GR 71.9375 TENS 1990.0000 GR 71.9375 ~ALI 12.9922 NPHI 46.3867 NRAT 3.9160 RNRA 4.4531 ~CNL 1666.0000 FCNL 374.0000 RHOB 2.1328 DRHO -0.0063 )PHI 31.2988 PEF 2.5078 QLS -0.0298 QSS 0.0156 .L 253.6250 LU 444.5000 LS 476.0000 LITH 144.6250 iS1 225.5000 SS2 335.7500 SSHV 1211.0000 LSHV 1141.0000 FENS 1990.0000 GR -999.2500 CALI -999.2500 NPHI -999.2500 ~RAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNt -999.2500 ~HOB -999.2500 DRHO -999.2500 DPHI -999.2500 TENS -999.2500 )EPT 3100.0000 SFLU 3.7678 ILM 3.8681 ILO 3.9515 ;P -42.0000 GR 63,2500 TENS 1940.0000 GR 63,2500 ~ALI 12.9453 NPHI 47.9492 NRAT 4.0000 RNRA 4.1602 ~CNL 1730.0000 FCNL 415.5000 RHOB 2.1973 DRHO -0.0098 )PHI 27.2949 PEF 2.4902 QLS -0.0215 QSS -0.0020 ,L 223.5000 LO 392.5000 LS 419.7500 LITH 124.5000 ~S1 219.6250 SS2 331.0000 SSHV 1212.0000 LSHV 1142.0000 FENS 1940.0000 GR -999.2500 CALI -999.2500 NPHI -999.2500' ~RAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 ~HOB -999.2500 DRHO -999.2500 DPHI -999.2500 TENS' -999.2500 )EPT 3000.0000 SFLU 4.8166 ILM 5.0849 ILD 5.2261 ~P -44.0:313 GR 66.437'5 TENS 1910.0000 GR 66.4375 ~ALI 12.8516 ~ NPHI 45.5566 NRAT 3.8652 RNRA 4.3828 ~CNL 1749.0000 FCNL 39'9.0000 RHOB 2.2031 DRHO -0.0146 )PHI 27.0508 PEF 2.5332 QLS 0.0059 QSS -0.0015 ,L 223.3750 LU 379.2500 LS 413.0000 LITH 125.4375 5S1 216.0000 SS2 324.7500 SSHV 1212.0000 LSH~ 1142.0000 FENS 1910.0000 GR -999.2500 CALI -999,2500 NPHI -999.2500 ~RAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 ~HOB -999.2500 DRHO -999-2500 DPHI -999.2500 TENS -999.2500 ]EPT 2900.0000 SFLU 7.1718 ILM 6.3943 ILD 6.5162 SP -45.0000 GR 72.6250 TENS 1860.0000 GR 72.6250 2ALI 13.1562 NPHI 44,8730 NRAT 3.8359 RNRA 3.9180 ~CNL 1630.0000 FCNL 416.000'0 RHO~ 2.2363 DRHO -0,0073 DPHI 24.9512 PEF 2.7695 QLS -0.0083 QSS 0.0034 LL 210.2500 LU 365.7500 LS 393.0000 LITH 115.5000 SS1 219.0000 SS2 325.2500 SSHV 1212.0000 LSHV 1142.0000 TENS 1860,0000 GR -9~9.2500 CAiI -999,2500 NPHI -999,2500 _VP 010.H02 VERIFICATION LISTING PAGE 15 gRAT -999.2500 RNRA ~HOB -999.2500 DRHO )EPT 2800.0000 SELU iD -59.5000 GR 2ALI 12.8750 NPHI ~CNL 1659.0000 FCNL 2PHI 31.3965 PEF LL 254.5000 LU SS1 220.6250 SS2 TENS 1815.0000 GR NRAT -999.2500 RNRA RHOB -999.2500 DRHO DEPT 2700.0000 SFLU SP -50.5000 GR CALI 12.5469 NPHI NCNL 1812.0000 FCNL DPHI 28.4668 PEF LL 236.1250 LU SS1 223.5000 SS2 TENS 1755.0000 GR NRAT -999.2500 RNRA RHOB -999.2500 DRHO DEPT 2600.0000 SFLU SP -48.5000 GR CALI 13.3906 NPHI NCNL 1884.0000 FCNL DPHI 39.5020 PEF LL 335.7500 LU SS1 236.1250 SS2 TENS 1720.0000 GR NRAT -999.2500 RNRA RHOB -999.2500 DRHO DEPT 2500.0000 SFLU SP -62.5000 GR CALI 14.1797 NPHI NCNL 1713.0000 FCNL DPHI 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GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILD GR RNRA DRHO QSS LITH LSHV NPHI FCNL TENS ILO GR RNRA -0.0005 148.8750 1138.0000 -999.2500 -999.2500 -999.2500 4.3255 69.8750 4.8711 -0.0103 0.0303 148.8750 1138.0000 -999.2500 -999.2500 -999.2500 40.4631 30.9531 5.8398 0.0425 0.0303 493.7500 1135.0000 -999.2500 -999.2500 -999.2500 6.1342 63.1875 4.6563 -0.0083 0.0117 165.6250 1137.000,0 -999.2500 -999.2500 -999.2500 9.2935 53.3750 4.3945 -0.0127 0.0234 165.1250 1137.0000 -999.2500 -999.2500 -999.2500 28.6444 55.0000 4.4883 .VP OlO.H02 VERIFICATION LISTING PAGE 20 ~CNL 1494.0000 FCNL )PHI 37.7930 PEF .L 312.2500 LU ;S1 231.1250 SS2 FENS 805.0000 GR 4RAT -999.2500 RNRA ~HOB -999.2500 DRHO )EPT 300.0000 SFLU ~P -93.5625 GR :ALI 21.3906 NPHI ~CNL 1207.0000 FCNL )PHI 49.1211 PEF .L 451.0000 LU ~S1 254.6250 SS2 FENS 760.0000 GR ~RAT -999.2500 RNRA ~HOB -999.2500 DRHO )EPT 200.0000 SFLU ~P -119.8125 GR SALI 23.5781 NPHI 4CNL 1168.0000 FCNL 3PHI 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