Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
196-172
WELL LOG TRANSMITTAL #905591617 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: 1C-11 Run Date: 04/04/2019 and 04/05/2019 195172 30 92 4 June 26 2 CEIV 9 A The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-11 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22714-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: 0—/ p�� / Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FRECEIVED MAY a Q ^ ;� 1. Operations Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown D Performed: Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program -Q Plug for RednIIE1 erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CO261 B Whipstock 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number Development E] Stratigraphic ❑ Exploratory ❑ Service ❑ 196-172 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 4- 50-029-22714-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25638, ADL 25649 KRU IC -11 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A I Kuparuk River Field / Kuparuk River Oil Pool 17. Present Well Condition Summary: Total Depth measured 11,300 feet Plugs measured None feet true vertical 7,011 feet Junk measured 10266, 10780 feet Effective Depth measured 11,211 feet Packer measured 5203, 10141 feet true vertical 6,939 feet true vertical 3518, 6143 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 121' MD 121' TVD SURFACE 6,903 feet 95/8" 6,945' MD 4439' TVD .5" SCAB LINER 5,108 feet 31/2 " 10,271' MD 6231' TVD PRODUCTION 10,438 feet 7 10,466' MD 6372' TVD LINER 1,021 feet 5 11,300' MD 701 1'TVD Perforation depth: Measured depth: 10660-10716 feet True vertical depth: 6571-6559 feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 10,321' MD 6,266' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - FHL Retrievable Packer 5,203' MD 3,518' TVD PACKER - BAKER Premier 10,141' MD 6,143' TVD SSSV - TRMAXX w/2.813" x -Profile 2,297' MD 1,994' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 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: 1803!93 1481 1000 300 Subsequent to operation: 1880 3379 4135 1200 1300 14. Attachments (required per 20 MC 25.070, 25.071, E 25283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-125 Authorized Name: James Ohlinger Contact Name: William Long Authorized Title: Staff CTD Engineer Contact Email: William.R.Long@cop.com Authorized Signature: 5 �1 g Contact Phone: 263-11372 1 Date: d'(/ Form 10-404 Revised 4/2017 VTL`/4119 :3BDMS.�✓MAY 2 9 2019 Submit Original Only 0/ /[[[( / KUP PROD WELLNAME 1C-11 WELLBORE iC_11 Well Attributes Max Angle & MD TD CQIIOCOPII)��)PS eltlNam¢ W¢IIC reFPWW W¢^W reSblus a°I MD'XKB) AciDn^hXBI A85K3. (IC. -. IKI Ip4RIIN RIVFRIINIT ISMJCJJ]ldnn oo n n s nn nn .. inn ast WO' Ic-m.Scusers1:leea PN Last Tag VaNUI SNnnm Manan Annabticn O.;dhj BI End paM WaNWre lea1Mon .,, Last Tell SIM 1 ,900.0 411912009 1C-11 Jai HANOER SS.T Last Rev Reason ............................. .._................. ...... 7 _...... ..... ... Annotation End Gale WNIMre Last MW By Rev Reason: Replaced DV 9172019 1C-11 zembaej Casing Strings GSInB Deic,ipllOn OD(in) P last that calim MKS) SN De PM IND),., 1110... GIMe Top Thread CONDUCTOR 16 0 121.p 121.0 62.50 H40 WELDED COHWCTOR;tl 64L0 Casing De¢ripllon OD(In) p (XNa) SN DepK11a1(BI Sa10ep1A DVp)... WI(Len 1L..Glade Top T!°read SURFACE 998 .3 6,945.2 4739.9 40.00 L-80 BT&C CainOnescripWn OD piny pIKK01 Se[OepIX BIKBI Set Leon LNp)... WVLen (L_Grade TOp ramd PRODUCTION > 2 10,485.8 63726 2800 L-80 BTCM h Lasing 0escripNOn O011p pMKa) Set OepM (XKej del OepN IND)... WYlen I, Top Thread larade LINER 5 .D9d 11,300.0 7,0107 18.00 LSO LTC SApMTVe:2,s+4 Liner Details Top fees) To p(NDr IRKB) TOpincl rl Nommal l0 IRm Da corn tiro 10.279A 8,238.5 45.22 AN R BAKER 5"x]" LINER HANGER a PACKER 5.000 Gad LIFT; AIsl apPACKER 10,303.2 6,2514 44.42 PER BAKER PER 400 GACNFT,anz4 Gslrq Dearlplbn WINDOW LI -02 Op pp 5 10 (In) 400 Top (ryKB) 10,7500 SN GpN 111KB1 6, ..0 901 OepN INO)... 6589.4 WtlLen g... 26.00 Ond¢ L-80 TepThmtl Cain, Danptlon 3.5"SCAB LINER OD sins 3112 ID lInl 2.99 Topheaft 5,163.3 SNDepMIryKBI 10,2]1.0 SN DepM(ND)... 6,230.6 WOLen(I...Gmda 930 LS0 TOp Thmd EUESIMBM OD GAS uFTams Liner Details Nominal ID ,,I..) Topf1DI1NKa) Tophi Item pea cum (in) 5,163.3 3,496.3 57.33 SLEEVE HR Liner Semnq Sleave ARM 10w7oR, S17o2 5,177.7 3,5041 Ili XO BUSHING Xover Bushing 42M 5,178.9 3SO47 57.34 BE 8040 Seal Bore Exlenti0n LOW sax s ins 5,198.2 3,515.1 57,35 XO BUSHING XDYer Bushing 2.990 5,202.9 3,517.7 5J. 5 PACKER FHL Retrievable Packer 2.992 10,140.9 6,142.8 4 26 PACKER Baker Premier Pramuction Packer 2870 10.1890 6,1745 4.06 NIPPLE 275 D'Nipple - MILLED TO 280"4/42009 2800 10,262.0 6224.3 4580 NIPPLE Fliled lg G 3.000 Tubing Strings TUMng Oescripdon Stria, Me IDlln IT -1-81 SN DepXr IN del OepN(NO)I... WI IIMI Gnde Top Connection TUBING 3112 2.99 367 5,1930 3,5123 930 L-80 EUE81dABMOD Completion Details TuplNp) Top mat Nominal Top MKS) (i r Ire - Des Gm 10 (in) aVRFAce, azSA.2- 36.7 36] 0.00 HANGER Tubing Hanger "x3.5""ISA"BPVG 2.992 2,2974 TEN 54.61 1SAFETY VLV TRMAXXw281 "X-Profle 2.812 5,1702 35000 5)34 LOCATOR BAKER LOCATOR w/104'space out 3.999 5,172.5 3,5012 I b1JK SEAL BAKER 81 SEAL ASSEMBLY 3.999 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, aft.) LINER IC -11L3@: sidd0 Topffsaw T(liked Tof,nd Om Gm Run Date ID fin) 10,2320 6,2070 46.58 23/8" CTD CTD 2 M' Liner, lined back up into the parent iner. 428/2019 LINER Top @10,237 MO lo, 622].1 45.67 SEAL ASSY OSEALA EMB L 55'-Sealpa0e 5452008 3.000 where it was plugged into 5" mer (see attached drawing) 172710 6230.6 45.50 PBR Baker GBH -22 TI/T I --S-000- 6 SYSCFBUNER;5.1S3s %Sci. 10,3210 62662 4382 HOE MULE SH E -has 4A" ID, Causing lip al the by Of FISH 1Ti4.000 6 sent easy; "i 17684.0 6534.7 41.64 WHIPSTOCK t Ba an -aft ad. Cn ig ( DR-) 1. A . et 41WO19 0 segs (high side) 10.74T 0 6,581.9 41.45 WHIPSTOCK GEN 11 TTAW, ORIENTED 15 DEGREES LEFT 51112009 2.500 1BAKER OF HIGH SIDE, 1,.3DAL 1 10,7800 41.38 FISH Be12 VS"Bakers in6liner; rased 3600 pal; Is inti 4202008 0.000 zder CTD LINER:1D,MO PROWcnoN:mz10,4ss.e 1 neck 1.375" OD; MON release pull - anc ed to 107M CTMD6211p6 Perforations & Slots ams RPERF:1D.85D6f0,MO FRAC"StahB IPeppleffr.D10,as0 TOp( l an 1aKB1 Top-.' IryKB) etmlNO) gll(B) LmxMZOa Oetr pft= ) TypY Co. 10, 10,6]00 8,516.8 6,524.3 C-4, X-11 BI1920OB 6.0 RPERF 5 HJ, Deg eashe OCK', 1D<a.0 phase 10,670.0 17]16.0 6524.3 6,556, C-0,C-3,iG 1 1/14/199) 20 IPERF amaeg. hasing; 1 " Eel Frac Summary LINER IC 11L1Lz: 10,TY2.0- 13.Ob.0 WliP5T9CIC 10.74)0 WINDOW LI -02, legan0 10,75].0 $Mn DaR pNppam pBained die Pmppanl In Formation(IM 62012008 31,a dbn OaR To De p par glKa) BImIKKer LinFb Fluty dyahm Vol 6lean@N) Vol Slurrylbap 1 62WMkI 10,660.0 10716.0 Manures Inserts FISH', Tessa at aft H Top "Of We tetth PONS"TRO Run Toe (WO) mal Make ModN ODpn) Sere Tkpa Type (in) (ps9 Run Datr Com 1 3,193.9 2,47 .8 ami KBMG 1 Gas Lift GLV IBK 0.186 1.277.0 3/172 19 2 4,2124 2,992. Camco KBMG 1 Gas Lift OV BK 0250 0.0 Y9 19 3 5,11].5 3,47 .8 amco KBMG 1 Gas Lift DMY BK 0000 00 9112019 Exl pkg Notes: General & Safety Em Da@ Annotation 4/3/2008 NOTE: SWS LDL INDICATES IBP@ 10,385 LEAKING FROM BELOW I LINER; 10,Mg41 I.Sa 0 1w I COIIOCOPhillips AIBSNa. u,c. KUP PROD WELLNAME 1C-11 WELLBORE 1C-11 171, EESE019 I is FM Notes: General B Safety veM4 WwmOc loll Ena D. AnnobEan .............................................................. .._........ ._._.. 52612008 NOTE: HOLE IN )" CASING@ 5466MD HANGER. 307 6182008 I NOTE. NEW 35" TBG INSERTED INTO 3.5 SCAB LINER @102)2' """"'-""-'---"""""""..... - ------ 6/162008 NOTE VIEW SCHEMATIC wl Alaska Shcemalic9.0REV 11/512008 INOTE: Recovered seWrety eroced OV @ 5117', GLM likely OamageE 22&2009 NTE MULTI -LATERAL 1C-11, 1G1111,1C-111141,1C-11L142 (OFF MAIN WELLBORE) CONRICTOR: 4101210 SAFEw VLV: ZM.0 GPS LIFT: R1 W b EA3UFT',4,Ni4 GPS LIFT: 5,11]5 LOCATOR', 5,1702 SEAL. at]$.5 SURFACE; 4236.BIS2� LINER 111112-02'. 10.ST.a 15,1080 S.5' SCAB IINER', 10.2]00 SFAL ASSV:10.iai.0 2 W CTD LINER: 10.29.0 PROWCTIOK 20?10.4e5.B RPERF', t0,M0-I0M0 FRAC: 10.6600 IPERF: IOM 0-10,OR 0 R0 WHIPSTOCK10W4.o LINER 1C-11Lt@'EM.0. 0.7300 wHIPbTOCK Io.Hio WINDCALI..I0.Nv0,0 10]5]0 FISH: 10,7800 LINER. t0,ZR 611.i)].0 Operations Summary (with Timelog Depths) IC-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Our(hd Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth(ftKB) 3/26/2019 3/26/2019 1.50 MIRU MOVE MOB P Continue RD checklist, Trucks on 0.0 0.0 20:00 21:30 location, load shop, secure stairs and landings, secure BOP'S, Complete RD checklist 3/26/2019 3/27/2019 2.50 MIRU MOVE MOB P PJSM, Pull utility module away from 0.0 0.0 21:30 00:00 rig and line up for move, trouble getting up hill to get off pad, hook up cat/dozer, work over hill, pull drilling sub off well. 3/27/2019 3/27/2019 2.00 MIRU MOVE MOB P Install Jeeps, ready to move, PJSM 0.0 0.0 00:00 0200 3/27/2019 3/27/2019 3.50 MIRU MOVE MOB P Begin move from 3F-Pad to 1C-Pad 0.0 0.0 02:00 0530 3/27/2019 3/27/2019 1.00 MIRU MOVE MOB P Park at 14 for changeout, walkaround 0.0 0.0 05:30 0630 3/27/2019 3/27/2019 3.25 MIRU MOVE MOB P Continue move to 1C 0.0 0.0 06:30 0945 3/27/2019 3/27/2019 1.00 MIRU MOVE MOB P Arrive on location, remove jeeps, prep 0.0 0.0 09:45 10:45 well location for rig 3/27/2019 3/27/2019 2.25 MIRU MOVE MOB P Spot sub & pits over well, lay mats, 0.0 0.0 10:45 13:00 drop stairs 3/27/2019 3/27/2019 2.00 MIRU MOVE RURD P Begin RU checklist, get COMMS up, 0.0 0.0 13:00 15:00 set-down shop & lay mats, install scaffolding & platform around well 3/27/2019 3/27/2019 3.00 MIRU MOVE RURD P Continue RU checklist, spot tiger-tank 0.0 0.0 15:00 18:00 & MU hard-line, begin NU BOPE, MU PUTZ, grease tree valves & Tangos, complete NU BOP " Rig Accept: 18:00 3/27/2019 3/27/2019 2.50 MIRU WHDBOP RURD P Complete rig up check list, Air test TT 0.0 0.0 18:00 20:30 line, Obtain RKB Measurments, Service tree and stack, Valve crew here. Prep for BOPE test 3/27/2019 3/27/2019 1.00 MIRU WHDBOP BOPE P PJSM, Fill stack and bleed aire out of 0.0 0.0 20:30 21:30 system. Shell test BOPE, Swap out 0- Ring on riser 3/27/2019 3/28/2019 2.50 MIRU WHDBOP BOPE P Start full initial BOPE test, Test 0.0 0.0 21:30 00:00 witness waived by Adam Earl, AOGCC, No Fail pass through midnight test #9 3/28/2019 3/28/2019 2.50 MIRU WHDBOP BOPE P Continue full BOPE test, on test 9 0.0 0.0 00:00 0230 3/28/2019 3/28/2019 0.50 MIRU WHDBOP BOPE P Pull test joint, Makeup nozzle stab on 0.0 0.0 02:30 03:00 injector. Pressure test inner reel iron and pack offs, End BOPE test 3/28/2019 3/28/2i!T19 1.00 SLOT WELLPR RURD P PJSM, Rig down BOPE test 0.0 0.0 03:00 04:00 equipment. PT PDL's TT line 3/28/2019 3/28/2019 0.75 SLOT WELLPR RURD P Normal up rig, Blow down TT line, 0.0 0.0 04:00 04:45 Open Tango valves. WHP=175 PSI 3/28/2019 3/28/2019 2.75 SLOT WELLPR PULD P M/U PD, BHA #1, fishing assembly 0.0 68.5 04:45 07:30 3/28/2019 3/28/2019 0.50 SLOT WELLPR PULD P Surface test Coil (good-test), Tag up 68.5 68.5 07:30 08:00 reset counters 3/28/2019 3/28/2019 2.00 SLOT WELLPR TRIP P RIH 68.5 9,745.0 08:00 10:00 3/28/2019 3/28/2019 0.30 SLOT WELLPR DLOG P Log formation correction of plus 3.5' 9,745.0 9,779.0 10:00 1018 3/28/2019 3/28/2019 2.00 SLOT WELLPR CIRC P Continue RIF, park @ 10,200', obtain 9,779.0 10,200.0 10:18 12:18 static, 8.5-8.7 ppg, bring pump on-line circ bottoms up. PUW 40 k Page 1/35 Report Printed: 5/2812019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time our as Phe Op Cade Activity Code Time P -T -X Operation start Depth (n De End Depth (NKa) 3/28/2019 3/28/2019 0.75 SLOT WELLPR CIRC P Vac out tiger tank, 10,200.0 10,200.0 12:18 13:03 3/28/2019 3/28/2019 1.50 SLOT WELLPR JAR P RIH, pumping .46 bpm latch into fish 10,200.0 10,245.0 13:03 14:33 @ 10,245', hit jars x 25, jaring at 25k (57k), straight pull to 70 k, with no success 3/28/2019 3/28/2019 1.75 SLOT WELLPR CIRC P Pump off fish, circulate 8.8 ppg drilling 10,245.0 10,200.0 14:33 16:18 1 fluid around 3128/2019 3/28/2019 0.50 SLOT WELLPR CIRC P 8.8 ppg all the way around, shut down 10,200.0 10,200.0 16:18 16:48 pump, perform flow check, flow at the valve, shut back in and montior, slowly built up to 116 psi, 3/28/2019 3/28/2019 0.30 SLOT WELLPR TRIP P RBIH, pumping 0.46 bpm latch into 10,200.0 10,245.0 16:48 17:06 fish, pump 1.5 bpm at 3,451 psi, no returns 3/28/2019 3/28/2019 0.30 SLOT WELLPR JAR P Perform 5 jar hits @ 25 k PU over 10,245.0 10,245.0 17:06 17:24 PUW 30 k, straight pull to 70 k 3/2812019 3/28/2019 1.30 SLOT WELLPR OWFF P Unlach fish, PUH to 10240. Observe 10,240.0 10,240.0 17:24 18:42 1 well for flow, WHIP 40 PSI and slowly climbing3/28/2019 3/28/2019 0.10 SLOT WELLPR OTHR P Take static pressures. Annular @ 10,240.0 10,240.0 18:42 18:48 2934, Bore @ 2928 PSI. 3/28/2019 3/28/2019 0.10 SLOT WELLPR OTHR P Slowly stab on and latch fish, 3K 10,240.0 10,245.0 18:48 18:54 down, Annular 2925, Bore 2935, WHP=40 3128/2019 3/28/2019 0.40 SLOT WELLPR OTHR P Set down 6K, Annular 2932, Bore 10,245.0 10,245.0 18:54 19:18 2929, WHP=40 PSI. Annular down to 2896 after 20 min. Bore at 2925 3/28/2019 3/28/2019 0.10 SLOT WELLPR OTHR P Put fish in tension, DHWOB=-3K, 10,245.0 10,245.0 19:18 19:24 Annular 2864, Bore 2923, WHP=41 3128/2019 3/28/2019 0.20 SLOT WELLPR OTHR P Pull fish harder, DHWOB=-7K, Annualr 10,245.0 10,245-0- 19:24 19:36 1 2883, Bore 2924, WHP=41 3/28/2019 3/28/2019 0.30 SLOT WELLPR OTHR P Pull fish up to 60K, Annular 2858, 10,245.0 10,245.0 19:36 19:54 Bore 2945. 3/28/2019 3/28/2019 1.30 SLOT WELLPR OTHR P Bring on pumps 1.5 BPM, release 10,245.0 10,200.0 19:54 21:12 from fish PUW=35K, PUH, Open EDC. Wait on 9.0 PPG fluid 3/28/2019 3/28/2019 1.20 SLOT WELLPR KLWL P Start pumping 9.0 PPG down CT .9 10,200.0 10,200.0 21:12 2224 BPM with .15 BPM returns. Slow pump down to .6BPM. returns holding @ .15 -.2 BPM. Jog coil to help shear fluid up to 9595 @ 80 FPM them back down to 10,200. CT displaced to 9 PPG. 3/28/2019 3/28/2019 0.90 SLOT WELLPR KLWL P Consult town, Bull head 60 BBis 9.0 10,200.0 10,200.0 22:24 23:18 Fluid, 1.5 BPM @ 1400 PSI WHIP 3/28/2019 3/29/2019 0.70 SLOT WELLPR KLWL P Shut down and monitor well. Would 10,200.0 10,200.0 23:18 00:00 not go to no flow,2900 PSI 6045.6 TVD, @ 9.26 PPG 3/29/2019 3/29/2019 1.60 SLOT WELLPR TRIP P POOH pumping 9.0 down CT 10,200.0 90.0 00:00 01:36 3/29/2019 3/29/2019 0.90 SLOT WELLPR OWFF P Al surface, Flow check well. Fluid 90.0 90.0 01:36 02:30 coming out of whity valve. Open up choke and blow down to pits. No flow for 12 minutes then started. 3/29/2019 3/29/2019 1.00 SLOT WELLPR PULD P Tag up and space out. PUD BHA#1. 90.0 0.0 02:30 03:30 wHP up to 30 PSI. Bleed down came right back up. Lay down fishing BHA 3/29/2019 3/29/2019 1.50 SLOT WELLPR ELNE P Shift to running a -line with lubricator. 0.0 0.0 03:30 05:00 Rigging up e -line grease head 3/29/2019 3/29/2019 0.6o SLOT WELLPR ELNE P PJSM, with Pallard & Rig crew for e- 0.0 0.0 05:00 05:36 line ops, crew change Page 2/35 Report Printed: 5128/2019 e Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stall Time End Time Our (hd Phase Op Cade Activity Code Time P -T -X Operation Start Depth (XKB) End Depth (fiKB) 3/2912019 3/29/2019 3.00 SLOT WELLPR ELNE P RU e -line 0.0 0.0 05:36 08:36 3/29/2019 3/29/2019 0.45 SLOT WELLPR ELNE P Stab on lubricator, PT with rig pump, 0.0 0.0 08:36 09:03 4,000 psi, good test, bleed off pressure 3/29/2019 3/29/2019 1.10 SLOT WELLPR ELNE P RIH, with 5/8" string shot, weight bar, 0.0 0.0 09:03 10:09 firing head (16.03' BHA), WHP=312 3/29/2019 3/29/2019 0.50 SLOT WELLPR ELNE P Log CCL for depth control on the way 0.0 0.0 10:09 1039 in the hole, no-go on nipple at 10,725', obtain log of previous cut depth, looks to be clean. fire string shot 10,713'- 0,725'. 3/29/2019 3/29/2019 1.20 SLOT WELLPR ELNE P POOH, w/e-line 0.0 0.0 10:39 11:51 Note: Operator shut in well IC -17 MI Injection well. 3/29/2019 3/29/2019 0.50 SLOT WELLPR ELNE P MU Jet cutter to a -line, stab on 0.0 0.0 11:51 1221 lubricator PT, grease head small leak, add additional grease, re -PT 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P RIH, w/Spectra2 Jet Cutter 1.68" OD, 0.0 0.0 12:21 13:21 3/29/2019 3/29/2019 0.40 SLOT WELLPR ELNE P Tie into K1 10,427.5', Log CCL while 0.0 0.0 13:21 13:45 RIH, log across seal bore and 15 joints. fire cutter on depth 10,722'. PUH free, RBIH past cut depth, temporily detained, RBIH, PUH w/increased speed, Pull free 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P POOH 0.0 0.0 13:45 1445 3/29/2019 3/29/2019 1.00 SLOT WELLPR ELNE P PJSM, LD cutter and pressure 0.0 0.0 14:45 15:45 equipment, RD a -line unit and release 3/29/2019 3/29/2019 0.70 SLOT WELLPR CTOP P PJSM, move INJH cart forward, RIH 0.0 7-0- 15:45 1627 with coil into mouse hole inspecting coil, found flat spots at 10' and 15', Prep coil and cut 20 3/29/2019 3/29/2019 0.80 SLOT WELLPR CTOP P Prep CT, Install CT connector. Pull test 0.0 0.0 16:27 1715 1 35K 3/29/2019 3/29/2019 1.00 SLOT WELLPR CTOP P Head up BHI LOG / test wire - Good. 0.0 0.0 17:15 1815 Pressure test DOC CTC to 4400 PSI - Good 3/29/2019 3/29/2019 2.00 SLOT WELLPR PULD P M/U and PD BHA#2 Fishing BHA with 0.0 81.3 18:15 2015 Accelorator, weight bars, Up down jars, and sealed GS spear 3/29/2019 3/29/2019 1.80 SLOT WELLPR TRIP P Trip in hole BHA#2. Sputtering small 81.3 9,760.0 20:15 2203 gas bubbles on trip in 3/29/2019 3/29/2019 0.20 SLOT WELLPR DLOG P Log K1 for -2.5", Close EDC 9,760.0 9,798.0 22:03 2215 3/29/2019 3/29/2019 0.30 SLOT WELLPR TRIP P Continue in hole, Pull weight check @ 9,798.0 10,248.0 22:15 2233 10,200' PUW=36K 3/29/2019 3/29/2019 0.70 SLOT WELLPR JAR P Latch fish, Jar up - down X5. Jar up 10 10,248.0 10,248.0 22:33 23:15 times 25K over PUW. No movement. 3/29/2019 3129/2019 0.20 SLOT WELLPR CIRC P Start pumping to establish circulation. 10,248.0 10,248.0 23:15 23:27 Remain latched to fish. .5 BPM @ 3478, Annular 3096. Unable to move fluid to surface 3/29/2019 3/29/2019 0.45 SLOT WELLPR JAR P Go back to jarring upon fish X15. No 10,248.0 10,211.0 23:27 23:54 movement. Pump on to release from fish 3/29/2019 3/30/2019 0.10 SLOT WELLPR CIRC P Pump on to establish returns 10,211.0 10,211.0 23:54 00:00 3/30/2019 3/30/2019 0.30 SLOT WELLPR CIRC P Continue circulating with open EDC 10,211.0 10,211.0 00:00 00:18 Page 3135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur (ho Phase Op Code AcWity Ootle Time P-T-X Operation Sfert Depth Depth(WB) De Entl Depth (WS) 3/30/2019 3/30/2019 0.50 SLOT WELLPR PRTS P Get static pressure test. BHP=3193, 10,211.0 10,211.0 00:18 00:48 TVD=6154.5, EMW=9.97 3/30/2019 3/30/2019 1.30 SLOT WELLPR CIRC P Circulate bottoms up 1.6 BBUMin with 10,211.0 10,211.0 00:48 02:06 full returns. 3/30/2019 3/30/2019 1.80 SLOT WELLPR TRIP P Trip out of hole, lost 4 BBIs on trip out 10,211.0 72.0 02:06 03:54 3/30/2019 3/30/2019 1.50 SLOT WELLPR PULD P Tag up and space out, PJSM. PUD 72.0 0.0 03:54 05:24 1 BHA#2 3/30/2019 3/30/2019 1.50 SLOT WELLPR ELNE P Prep rig floor for eline ops, standby for 0.0 0.0 05:24 06:54 SLB aline travel to rig 3/30/2019 3/30/2019 0.75 SLOT WELLPR ELNE P SLB on location, PJSM, spot in unit 0.0 0.0 06:54 07:39 3/30/2019 3/30/2019 0.30 SLOT WELLPR ELNE P PJSM with rig crew and SLB 0.0 0.0 07:39 07:57 3/30/2019 3/30/2019 5.00 SLOT WELLPR ELNE P RU, SLB pressure equipment to the 0.0 0.0 07:57 12:57 dg floor 3/30/2019 3/30/2019 2.00 SLOT WELLPR ELNE P PT SLB a-line lubricator 0.0 0.0 12:57 14:57 3/30/2019 3/30/2019 5.80 SLOT WELLPR ELNE P RIH, w/Shammas Chem Cutter 0.0 0.0 14:57 20:45 1.8675" OD, 2 x centralizers, CCL, Gamma. Log K1. Run CCL. Appears liner has moved uphole -15'. Attemp to log R nipple. Set down @ 10725. right where nipple should be. CCL 13' from bottom of a-line tool string. Log K1 to ensure we are on depth. POOH 3/30/2019 3/30/2019 1.10 SLOT WELLPR ELNE P At surface with a-line. PJSM to lay 0.0 0.0 20:45 21:51 down chem cutter. Swap out to 13/8" toolstring for logging ops 3/30/2019 3/30/2019 0.50 SLOT WELLPR ELNE P P/U Next a-line run. Stab on well 0.0 0.0 21:51 22:21 3/30/2019 3/31/2019 1.65 SLOT WELLPR ELNE P Trip in hole with a-line unit with 1 3/8" 0.0 0.0 22:21 00:00 logging tools 3/31/2019 3/31/2019 1.30 SLOT WELLPR ELNE P Continue tripping out with a line 0.0 0.0 00:00 01:18 logging tools 3/31/2019 3/31/2019 3.25 SLOT WELLPR ELNE P E-line at surface. PJSM. Pull logging 0.0 0.0 01:18 04:33 tools from well. Rig down e-line unit 3/31/2019 3/31/2019 0.70 SLOT WELLPR CTOP P PJSM, Position injector on rig floor. cut 0.0 0.0 04:33 05:15 off UOC. Boot wire, 3/31/2019 3/31/2019 0.25 SLOT WELLPR CTOP P Install CT cutter, Trim 300' of coiled 0.0 0.0 05:15 05:30 tubing from reel 3/31/2019 3/31/2019 1.50 SLOT WELLPR CTOP P Trim 300' of coiled tubing, String 0.0 0.0 05:30 07:00 #52794, Reel #20709 3/31/2019 3/31/2019 0.30 SLOT WELLPR CTOP P RD, cutting equipment operation 0.0 0.0 07:00 07:18 3/31/2019 3/31/2019 0.75 SLOT WELLPR CTOP P Install CTC, and pull test 35 k 0.0 0.0 07:18 08:03 3/31/2019 3/31/2019 0.45 SLOT WELLPR CTOP P Re-head BHI upper quick(77.5 0.0 0.0 08:03 08:30 meg/ohms, >2000) 3/31/2019 3/31/2019 0.25 SLOT WELLPR CTOP P PT re-head 4,500 psi 0.0 0.0 08:30 08:45 3/31/2019 3/31/2019 0.50 SLOT WELLPR CTOP P Stab into stump and pump 1 coil 0.0 0.0 08:45 09:15 volume forward @ 1.83 bpm at 3,299 psi, IA=110, OA=26, unstab INJH, park cart out of the way. 3/31/2019 3/31/2019 1.00 SLOT WELLPR PULD P PD fishing assembly 0.0 0.0 09:15 10:15 3/31/2019 3/31/2019 0.30 SLOT WELLPR PULD P Stab INJH, surface test BHI CoilTrak 0.0 81.3 10:15 10:33 tools (good-test) 3/31/2019 3/31/2019 1.75 SLOT WELLPR TRIP P RIH 81.3 9,760.0 10:33 12:18 Page 4135 Report Printed: 5/28/2019 AL Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Terre our (hr) Phase op code Ad" Code Time P -T -x o start Depthperedon rt Ke) End Depth (flKB) 3/31/2019 3/31/2019 0.20 SLOT WELLPR DLOG P Log formation correction of minus 4.0' 9,760.0 9,781.0 12:18 12:30 3/31/2019 3/31/2019 0.30 SLOT WELLPR TRIP P Continue IH 9,781.0 10,200.0 12:30 12:48 3/31/2019 3/31/2019 0.50 SLOT WELLPR CIRC P Circulate bottoms up @ 1.5 bpm at 10,200.0 10,200.0 12:48 13:18 3,100 psi, Diff=16 psi, WHP=36, BHP 3,651, IA=114, OA=27 3/31/2019 3/31/2019 0.50 SLOT WELLPR PRTS P Shut down pump, obtain static bottom 10,200.0 10,200.0 13:18 13:48 hole pressure 30 min - 10.09 ppg/3226 AP/WHP=235/6148.28' TVD, PUW 37 k 3/31/2019 3131/2019 0.60 SLOT WELLPR JAR P RIH latch fish @ 10,235', jar down x1, 10,200.0 10,240.0 13:48 14:24 jar up on fish x 1, jar down on fish x2, jar up on fish x 4, Pull up to 64 It, pump 1.9 bpm -10 bbl, Could not establish returns 3/31/2019 3/31/2019 2.90 SLOT WELLPR JAR P Continue to jar on fish. Stop every 5 10,240.0 10,199.0 14:24 17:18 cycles and attempt to get circulation. Jar a total of 45 cycles, release fish 3/31/2019 3/31/2019 0.10 SLOT WELLPR TRIP P PUH to tie in 10,199.0 9,760.0 17:18 17:24 3/31/2019 3/31/2019 0.20 SLOT WELLPR DLOG P Log K1 for +7.5' 9,760.0 9,502.0 17:24 17:36 3/31/2019 3/31/2019 0.10 SLOT WELLPR TRIP P RIH to tag top of fish @ 10,225'. 9,502.0 10,225.0 17:36 17:42 Release off fist 3/31/2019 3/31/2019 1.80 SLOT WELLPR TRIP P POOH 10,225.0 76.0 17:42 19:30 3/31/2019 3/31/2019 1.10 SLOT WELLPR PULD P At surface, Tag up and space out. 76.0 0.0 19:30 20:36 PJSM. PUD BHA #3 and lay down 3/31/2019 3/31/2019 0.80 SLOT WELLPR CTOP P PJSM. Lock out E -line. Remove LOC. 0.0 0.0 20:36 21:24 Boot wire. Stab on well. Perform slack mgmt 3/31/2019 3/31/2019 1.10 SLOT WELLPR CTOP P Unstab injecor. P/U hydraulic tubing 0.0 0.0 21:24 22:30 cutter. Trim CT for fatigue mgmt. Find e -line @ 38'. Trim 100'total 3/31/2019 3/31/2019 1.40 SLOT WELLPR CTOP P Test wire - good. Prep CT and install 0.0 0.0 22:30 23:54 connector. Pull test to 35K 3/31/2019 4/1/2019 0.10 SLOT WELLPR CTOP P Head up UQC 0.0 0.0 23:54 00:00 4/1/2019 4/1/2019 0.90 SLOT WELLPR CTOP P Complete reheading UQC. PT 0.0 0.0 00:00 00:54 connector to 4300 PSI 4/1/2019 4/12019 1.00 SLOT WELLPR PULD P PJSM, M/U and PD BHA #4 fishing 0.0 81.0 00:54 01:54 BHA. Check packoffs. Surface test BHA 4112019 4/1/2019 2.00 SLOT WELLPR TRIP P RIH BHA#4, EDC open, pumping 1.5 81.0 9,760.0 01:54 03:54 BPM from surface 4/1/2019 4/1/2019 0.10 SLOT WELLPR DLOG P Log k1 for 4.5' correction, Close EDC 9,760.0 9,791.0 03:54 04:00 4/1/2019 4/1/2019 0.10 SLOT WELLPR TRIP P Continue in well 9,791.0 10,220.0 04:00 04:06 4/1/2019 4/1/2019 3.00 SLOT WELLPR JAR P Set down @ 10,220'. Did not latch up 10,220.0 10,220.0 04:06 07:06 first time. Bring pumps on. BPM and run in faster. Set down and latch. Jar up 3X. Paint red flag @ 51 K PUW. Line up to pump down backside. Go up to 1100 PSI WHIP. Pull up to fire jars and dump pressure. No good. Jar 5X. Stop and pump 5 BBIs down coil. No circulation. Jar 5X up and down 4/1/2019 4/1/2019 0.50 SLOT WELLPR PULL P Continue jadng total of 30 cycles @ 10,220.0 10,195.0 07:06 07:36 10,199', hold in tention 60 k, 10,195', notice weight fall off slightly Page 5135 ReportPrinted: 528/2019 r Operations Summary (with Timelog Depths) l , 0�r]q IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur (hr)Phase Op Cotle Activity Cotle Tme P -T -X Operation Stan Depth (ftKB) End Depit (ftKB) 4/1/2019 4/1/2019 0.50 SLOT WELLPR PULL P Continue working fsh towards surface 10,195.0 9,753.0 07:36 08:06 75 k @ 3-5 fpm, notice weight change @ 10,145', continue pulling up to 9,975', 15-30 fpm, fish is pulling free 4/1/2019 4/1/2019 3.75 SLOT WELLPR PULL P Park with fish, discuss with town team, 9,753.0 9,753.0 08:06 11:51 plan forward to kill well, call out 10.5 ppg completion fluid. 10.5 ppg on location load into pits 4/1/2019 4/1/2019 1.20 SLOT WELLPR PULL P Second brine truck headed to the rig, 9,753.0 9,729.0 11:51 1303 start displacing coil to 10.5 ppg kill fluid w/open EDC holding one for one 45 bbls, , shut dawn and close EDC, slowly PUH circulating 0.25 bpm 2 bbls, shutdown open EDC, bullhead 1.4 bbl, WHP increased to 1,500 psi, shutdown pump, bleed pressure off, pull up hole to confirm fish is free, fish is free, Close the EDC, 4/1/2019 4/1/2019 0.50 SLOT WELLPR PULL P PU slow, pumping down the coil 0.2 9,729.0 9,699.0 13:03 13:33 bpm at 48 psi, CTSW=36.5 k, DHWOB= -2.2 k, close choke WHP built to 1,000 psi shutdown pump, park and discuss with town team further. 4/1/2019 4/1/2019 0.20 SLOT WELLPR PULL P Attempt to RIH w/1000 psi WHP, stack 9,699.0 9,717.0 13:33 13:45 out 5k CTSW, bleed pressure off WH 4/1/2019 4/1/2019 0.15 SLOT WELLPR PULL P Open EDC, PUH @ 2 fpm, seems fish 9,717.0 9,693.0 13:45 1354 is still on. 4/1/2019 4/1/2019 1.00 SLOT WELLPR OWFF P Park, bleed pressure off, perform flow 9,693.0 - 9,693.0 13:54 1454 1check, well still flowing, 4/1/2019 4/1/2019 0.30 SLOT WELLPR PULL P RBIH to tag @ 9,713' (Fish 9,693.0 9,713.0 14:54 1512 depth=10,287') 4/1/2019 4/1/2019 1.50 SLOT WELLPR PULL P Circulate bottoms up, gas cut brine at 9,713.0 9,713.0 15:12 1642 surface, take returns to tiger tank, bring back inside, 4/1/2019 4/1/2019 1.30 SLOT WELLPR OWFF P Perform flow check (no -flow) 9,713.0 9,713.0 16:42 1800 4/1/2019 4/1/2019 2.00 SLOT WELLPR TRIP P Close EDC, pump 2 bbls down the 9,713.0 557.2 18:00 2000 coil, shutdown, open EDC, circlulate through the EDC, 1.19 bpm at 1,477 psi, 0.80 bpm returns, POOH 4/1/2019 4/1/2019 0.60 SLOT WELLPR OWFF P PJSM, Check well for floww(no-flow) 557.2 557.2 20:00 2036 4/1/2019 4/1/2019 1.25 SLOT WELLPR PULD P Brake down BOT fishing tools, check 557.2 444.9 20:36 21:51 the hole (good) 4/1/2019 4/1/2019 1.20 SLOT WELLPR PULD P LD, fish 2-3/8" solid liner no 444.9 0.0 21:51 23:03 1 Icentrilizers. 4/1/2019 4/2/2019 0.95 SLOT WELLPR PULD P PJSM, MU cleanout assembly, Stab 0.0 23:03 0000 on well, Surface test tool 4/2/2019 4/2/2019 0.10 SLOT WELLPR PULD P Complete surface test tool 51.3 51.3 00:00 0006 4/2/2019 4/2/2019 1.80 SLOT WELLPR TRIP P Trip in hole, BHA#5 Clean out BHA 51.3 9,730.0 00:06 01:54 with straight motor and D-331 4/2/2019 4/2/2019 0.20 SLOT WELLPR DLOG P Log gamma tie in for -2', Close EDC 9,730.0 9,769.0 01:54 0206 4/2/2019 4/2/2019 0.30 SLOT WELLPR TRIP P Continue in well 9,769.0 10,220.0 02:06 _4/2/20 0224 1-9 4/2/2019 1.30 SLOT WELLPR CIRC P 10220'. Displace to 8.8 PPG milling 10,220.0 10,210.0 02:24 03:42 1 fluid slowly recip up hole 4/2/2019 4/2/2019 0.20 SLOT WELLPR TRIP P 10210, Wt check @ 35K, RIH min 10,210.0 10,276.0 03:42 03:54 rate. Tag dill @ 10,276 Page 6135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) + „r . 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation htKB) End Depth(@KB) 4/2/2019 4/2/2019 1.80 SLOT WELLPR OTHR P Bring pumps on 1.85 BPM @ 3629 10,276.0 10,442.0 03:54 0542 PSI FS. Start clean out. Taking 25' bites. Parafn coming across shaker at first bottoms up 4/2/2019 4/2/2019 0.50 SLOT WELLPR OTHR P Washing down set down @ 10442. 10,442.0 10,442.0 05:42 06:12 PUH slowly to 10356. RBIH and tag up 10442. DHWOB=2K. 4/2/2019 4/2/2019 0.90 SLOT WELLPR OTHR P Pump sweeps, PUH slowly circ 10,442.0 10,442.6 06:12 07:06 1 bottoms up 4/2/2019 4/2/2019 0.50 SLOT WELLPR MILL P Hole circulated clear, Bring pumps on 10,442.6 10,443.0 07:06 07:36 1.88 BPM @ 3635 PSI FS, BHP=3540, DHWOB=2K 4/2/2019 4/2/2019 0.30 SLOT WELLPR MILL P Pick up off bottom to reset. to hard to 10,443.0 10,443.0 07:36 0754 be fill. Reset. Set back down 2.5K DHWOB, 1.88 BPM @ 3635 PSI FS. BHP=3540 4/2/2019 4/2/2019 0.50 SLOT WELLPR MILL P 10443, Metal on shaker, PUH consult 10,443.0 10,444.0 07:54 0824 town eng. RBIH dry. Set down @ 10444 attempt to move down. Set 8K. 4/2/2019 4/2/2019 2.80 SLOT WELLPR TRIP P Trip out of well 10,444.0 46.0 08:24 11:12 4/2/2019 4/2/2019 1.20 SLOT WELLPR PULD P At surface, PJSM, PUD BHA#5, Lay 46.0 0.0 11:12 12:24 down motor. Mill out 2.80 NO Go 4/2/2019 4/2/2019 1.30 SLOT WELLPR SLKL P Move in / spot up slickline unit 0.0 0.0 12:24 1342 4/2/2019 4/2/2019 2.40 SLOT WELLPR SLKL P PJSM, R/U slickline unit, full pressure 0.0 0.0 13:42 16:06 control equipment on rig floor 4/2/2019 4/2/2019 1.90 SLOT WELLPR SLKL P PT slick line lubricator to 2500 PSI - 0.0 0.0 16:06 18:00 RIH with 2.47 LIB, POOH after tagging @ 10,462' SL depth 4/2/2019 4/2/2019 0.50 SLOT WELLPR SLKL P PJSM, pop off lubricator, LD LIB, 0.0 0.0 18:00 18:30 Picutes on S: Drive, confer w/ SL supervisor & town, decision made to to run non -retrievable spear. 4/2/2019 4/2/2019 0.40 SLOT WELLPR SLKL P PU non -retrievable spear 0.0 0.0 18:30 18:54 4/2/2019 4/2/2019 2.10 SLOT WELLPR SLKL P RIH w/ spear, attempt to spear into 0.0 0.0 18:54 21:00 fish, spang down for -45 min, unable to latch into fish, POOH to inspect tool 4/2/2019 4/2/2019 0.60 SLOT WELLPR SLKL P LD tools, small scratches on face of 0.0 0.0 21:00 21:36 grapple, decision made to run 1-1/2" braided line brush " Test non -retrievable spear on 4' piece of liner at surface to ensure engagment is possible, engages as designed 4/2/2019 4/2/2019 0.70 SLOT WELLPR SLKL P MU braided line brush 0.0 0.0 21:36 22:18 4/2/2019 4/2/2019 0.20 SLOT WELLPR SLKL P PU braided line brush, stab on 0.0 0.0 22:18 22:30 lubricator, PT 4/2/2019 4/2/2019 1.20 SLOT WELLPR SLKL P RIH w/ braided line brush, run tool into 0.0 0.0 22:30 2342 fish, see overpull of brushes in PU's 4/2/2019 4/3/2019 0.30 SLOT WELLPR SLKL P Begin POOH (to PU non -retrievable 0.0 0.0 23:42 0000 spear) 4/3/2019 4/3/2019 0.10 SLOT WELLPR SLKL P Complete POOH 0.0 0.0 00:00 0006 4/3/2019 4/3/2019 0.20 SLOT WELLPR SLKL P Pop off lubicator & LD tools, tattle tails 0.0 0.0 00:06 00:18 bent back, marking on 2.20" swedge at -5' up tool, appear to have engaged fish, retrieved 2 small steal fish pieces Page 7135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) rte.. 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Time Dur (hr) Phase Op Code Ac mty Code Time P -T -X Operation (ftKB) End Depth (ftKB) 4/3/2019 4/3/2019 1.30 SLOT WELLPR SLKL P PU non -retrievable spear, PT, RIH, 0.0 0.0 00.18 Ot 36 latched into fish, jarred up -25 times, sheared off spear (GR), no movement of fish 4/3/2019 4/3/2019 0.60 SLOT WELLPR SLKL P POOH 0.0 0.0 01:36 0212 4/3/2019 4/3/2019 2.50 SLOT WELLPR SLKL P PU 3" GS, RIH, latch into fish, jar on 0.0 0.0 02:12 04:42 fish for 1.25 ms, unable to move fish, shear off fish "BOT on the way to fish on coil 4/3/2019 4/3/2019 0.60 SLOT WELLPR SLKL P POOH 0.0 0.0 04:42 05:18 4/3/2019 4/3/2019 1.10 SLOT WELLPR SLKL P At surface, Bleed off lubricator Lay 0.0 0.0 05:18 06:24 down slick line equipment. Put lubricator in pipe shed 4/3/2019 4/3/2019 1.40 SLOT WELLPR PULD P M/U BHA#6. Fishing BHA with weight 0.0 67.0 06:24 07:48 bars, accelorator, Jars, and GS spear. Pressure deploy. make up to coil and surface test. Tag up and set counters 4/3/2019 4/3/2019 1.80 SLOT WELLPR TRIP P Trip in hole, EDC open 67.0 9,745.0 07:48 09:36 4/3/2019 4/3/2019 0.10 SLOT WELLPR DLOG P Log Gamma tie in for -3' 9,745.0 9,770.0 09:36 09:42 4/3/2019 4/3/2019 0.10 SLOT WELLPR TRIP P Continue in well, Close EDC @ 10225 9,770.0 10,441.0 09:42 09:48 4/3/2019 4/3/2019 0.50 SLOT WELLPR JAR P Set down and lift off fish. Set back 10,441.0 10,050.0 09:48 10:18 down and latch. P/U to 50K and fire jars. Pull up to 59K and start moving fish uphole 4/3/2019 4/3/2019 2.00 SLOT WELLPR TRIP P 10,050 stop, open EDC. See slight 10,050.0 59.0 10:18 12:18 overpull @ 10,189 milled nipple. Hang up in SSSV @ 2308. Shut EDC. Work down out of SSSV. Bring control pressure up to 5K PSI. Work free down. PUH and hung up in SSSV Cock jars down. PUH jars fire @ 43K continue out of hole 4/3/2019 4/3/2019 2.30 SLOT WELLPR PULD P At surface tag up and space out. PUD 59.0 0.0 12:18 1436 BHA #6. Have fish. Length 20.38'. Jet cut end flared to 2.752. Overall fish recovered 465.28' 4/3/2019 4/3/2019 1.00 SLOT WELLPR PULD P PJSM, Complete HES slickline rig 0.0 0.0 14:36 15:36 down. Remove spear from fish 4/3/2019 4/3/2019 1 A SLOT WELLPR PULD P PJSM. P/U BHA#7 FCO with straight 0.0 51.3 15:36 1700 motor and D331 mill and PD. Chek pack offs - Good 4/3/2019 4/3/2019 1.70 SLOT WELLPR TRIP P RIH BHA#7 51.3 9,730.0 17:00 18:42 4/3/2019 4/3/2019 0.20 SLOT WELLPR DLOG P Log K1 for -2' correction, close EDC 9,730.0 9,760.0 18:42 1854 4/3/2019 4/3/2019 1.60 SLOT WELLPR TRIP P Continue FCO, PUW = 37 @ 10.200', 9,760.0 10,717.0 18:54 20:30 1.85 bpm, FS = 290 psi, circ = 3656 psi, WHP = 20 psi, significant asphaltenes over shaker, pump 5x5 sweeps, taking bites & picking up, drop in MW out, begin taking returns to tiger -tank (pinch in choke), cleans up, begin taking returns back inside Page 8136 ReportPrinted: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur (hr) Phase Op Code Ackvity Code Time P-T.X Cpembon Stan Depth (WB) End Depth (WB) 4/3/2019 4/3/2019 1.40 SLOT WELLPR CIRC P Continue FCO, clean down to 10,717' 10,717.0 10,425.0 20:30 21:54 & hard tag, PUW = 37K, pump 5x5 sweeps, recip WS setting area, circulate 2 bottoms up, asphaltenes dean-up over shakers PJSM w/ LRS for hot diesel flush 4/3/2019 4/3/2019 0.30 SLOT WELLPR DLOG P Log K1 for 0' correction, RIH to bottom 10,425.0 10,690.0 21:54 22:12 413/2019 4/4/2019 1.80 SLOT WELLPR CIRC P Begin circulating 100 bbl of 180° 10,690.0 10,690.0 22:12 00:00 diesel (1.5 bpm) 4/4/2019 4/4/2019 0.30 SLOT WELLPR CIRC P Complete diesel circulation, chased w/ 10,690.0 10,690.0 00:00 00:18 DuoVis, 4/4/2019 4/4/2019 2.00 SLOT WELLPR TRIP P POOH, tag up, open EDC failed, 10,690.0 51.0 00:18 02:18 PJSM undeploy w/ failed checks 4/4/2019 4/4/2019 1.40 SLOT WELLPR PULD P PUD BHA#7 & LD tools, mill came out 51.0 0.0 02:18 03:42 2.80" no-go, PJSM 4/4/2019 4/4/2019 0.70 SLOT WELLPR PULD P PU BHA #8 Caliper (HES real-time), 0.0 24.0 03:42 04:24 slide in cart, check pack-offs, MU to coil, tag up, set counters 4/4/2019 4/412019 2.20 SLOT WELLPR TRIP P RIH w/BHA#8 24.0 10,707.0 04:24 06:36 4/4/2019 4/4/2019 0.50 SLOT WELLPR DLOG P 10,707', Line up across the top, Open 10,707.0 10,130.0 06:36 07:06 caliper finger. Log up 25 FPM 4/4/2019 4/4/2019 0.10 SLOT WELLPR TRIP P Close finger. RBIH 10,130.0 10,350.0 07:06 07:12 4/4/2019 4/4/2019 0.20 SLOT WELLPR DLOG P Open fingers. relog 10,350 to 10,121 10,350.0 10,121.0 07:12 07:24 for comparison 4/4/2019 4/4/2019 1.70 SLOT WELLPR TRIP P Close caliper fingers. Trip out of hole 10,121.0 22.0 07:24 09:06 4/412019 4/4/2019 0.70 SLOT WELLPR PULD P At surface, PJSM, Shut swab. Unstab 22.0 0.0 09:06 09:48 injector. Lay down caliper and camera adapter 4/4/2019 4/4/2019 2.20 SLOT WELLPR CTOP P Pull floats from LOC. Stab injector on 0.0 0.0 09:48 12:00 well. Jet stack roll CT to water. Unstab injector. Fluid pack BOPE obtain shell test 4/4/2019 41412019 6.00 SLOT WELLPR BOPS P Start full BOPE lest, perform draw- 0.0 0.0 12:00 18:00 down test, test IRV. Test witness waived by Matt Herrara, AOGCC, '• 250 low / 3500 high 4/4/2019 414/2019 1.20 SLOT WELLPR CTOP P Roll coil to drilling fluid, pop off 0.0 0.0 18:00 19:12 injector, install checks in UQC, load BOT tools onto dg, bring tools to rig floor, PJSM 4/4/2019 4/412019 0.90 SLOT WELLPR PULD P PD BHA#9 Haily Under-Reamer 0.0 66.0 19:12 20:06 (4.10" &4.7" blades), slide in Cart, check pack-offs, MU to coil, tag up, set counters 4/4/2019 4/4/2019 1.90 SLOT WELLPR TRIP P RIH w/ BHA #9 66.0 10,435.0 20:06 22:00 4/4/2019 4/4/2019 0.10 SLOT WELLPR CLOG P Log Kt for 4' correction, close EDC, 10,435.0 10,474.0 22:00 22:06 PUW = 35K 4/4/2019 4/4/2019 0.20 SLOT WELLPR TRIP P Conflnue RIH, RIW = 12.2K 10,474.0 10,660.0 22:06 22:18 Page 9135 ReportPrinted: 512812019 -; - Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Depth Stag Time End Time our (hr) phase Cp Code Activity Cade Time P -T -X opemlmn (fiKB) End Deplh(eKB) 4/412019 4/412019 1.00 SLOT WELLPR UREM P Under -reaming, start at 1 fpm, 1.87 10,660.0 10,681.0 22:18 23:18 bpm, dp = 1420 psi, annular = 3658 psi, pump = 4610 psi, CWT = 11.5K, WOB = 0.61K, vibrations into red Stall at 10,679', PUW = 38K, out rate dropped (from 1,8 bpm to 1.64 bpm), rate out continues to drop to 1.36 bpm, stall at 10,681', PUW = 37K, annular increasing, packing off, significant cement over shakers 4/4/2019 4/5/2019 0.70 SLOT WELLPR UREM P Continue under -reaming, reduce 10,681.0 10,687.0 23:18 00:00 speed to .2 fpm, dp = 1313 psi, annular = 3973 psi, pump = 4781 psi, annular dropped & rate out increased back to 1.8 bpm 4/5/2019 4/5/2019 1.80 SLOT WELLPR UREM P Continue under -reaming from 10,687' 10,687.0 10,700.0 00:00 01:48 @ 0.2 fpm, cip = 1283 psi, 1.84 bpm in, 1.79 bpm out, annular = 3619 psi, pump = 4341 psi, CWT = 8.5K, WOB =1K Stall at 10,690', 10,694', 10,699', again at 10,698' getting to bottom, ream to 10,700' 4/5/2019 4/5/2019 0.40 SLOT WELLPR UREM P Back -ream up to 10,600'@ 5 fpm, 10,700.0 10,600.0 01:48 02:12 PUW = 39K 415/2019 4/5/2019 1.10 SLOT WELLPR UREM P Under -ream from 10,600', dip = 1275 10,600.0 10,660.0 02:12 03:18 psi, pump = 4387 psi, 98% returns, start at 0.2 fpm, walk up to 0.5 fpm, then 1 fpm, vibrations to 4, pump 5x5 sweeps 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream @ 5 fpm, PUW = 38K 10,660.0 10,600.0 03:18 03:36 4/5/2019 4/5/2019 2.30 SLOT WELLPR TRIP P Open EDC, POOH 10,600.0 66.0 03:36 05:54 4/512019 41512019 1.10 SLOT WELLPR PULD P PJSM, PUD SHA#9. All under reamer 66.0 0.0 05:54 07:00 blades intact 4/5/2019 4/5/2019 0.90 SLOT WELLPR PULD P MIN HES caliper, Stab on and surface 0.0 22.7 07:00 07:54 test. 4/5/2019 4/5/2019 2.10 SLOT WELLPR TRIP P RIH BHA#10 22.7 10,704.0 07:54 10:00 4/5/2019 4/5/2019 0.30 SLOT WELLPR DLOG P 10,704'. Open caliper anus. Log 10,704.0 10,148.0 10:00 10:18 uphole. Close caliper arms 4/5/2019 4/5/2019 1.70 SLOT WELLPR TRIP P Trip out of well 10,148.0 22.0 10:18 12:00 4/5/2019 4/5/2019 0.50 SLOT WELLPR PULD P PJSM. Pull BHA #10 from well 22.0 0.0 12:00 12:30 415/2019 4/5/2019 1.20 SLOT WELLPR PULD P M/U Whipstock in pipe shed/ Plan 0.0 0.0 12:30 13:42 change reset motor back to 0° and pick up under reamer 4/5/2019 4/5/2019 1.30 SLOT WELLPR PULD P PJSM, PD BHA#11 Under reamer on 0.0 66.0 13:42 15:00 straight motor, Make up injector and surface test. 415/2019 4/5/2019 1.70 SLOT WELLPR TRIP P RIH BHA#11, EDC open. Pumping 66.0 9,730.0 15:00 16:42 1 min rate 4/5/2019 415/2019 0.10 SLOT WELLPR DLOG P Log gamma tie in for -4.5 9,730.0 9,770.0 16:42 16:48 4/512019 4/5/2019 0.30 SLOT WELLPR TRIP P Continue RIH to 10,600' 9,770.0 10,660.0 16:48 17:06 Page 10/35 ReportPrinted: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Tme End Time Dur (hr) Phase Op Cotle ArAvity Cotle Time P -T4 Operaeon Stan Depth (eKB) Emi Depth(RKB) 4/5/2019 4/5/2019 1.50 SLOT WELLPR UREM P Under -reaming, dip = 1249 psi, annular 10,660.0 10,700.0 17:06 18:36 = 3610 psi, pump =4368 psi, 1 fpm from 10,660'to 10,700', back -ream to 10,680', under -ream down to 10,700' @ 0.5 fpm " Cement over shakers (trace asphaltenes, very little metal) 4/5/2019 4/5/2019 0.30 SLOT WELLPR UREM P Back -ream up to 10,600'(5 fpm) 10,700.0 10,600.0 18:36 18:54 4/5/2019 4/5/2019 1.80 SLOT WELLPR UREM P Under -ream from 10,600'to 10,660'(1 10,600.0 10,680.0 18:54 20:42 fpm), slow to 0.5 fpm from 10,660' to 10,680' " Stall @ 10,668', PUW = 37K 4/5/2019 415/2019 0.30 SLOT WELLPR UREM P Back -ream 10,680'to 10,600' (5 fpm), 10,680.0 10,600.0 20:42 21:00 PUW = 37K 4/5/2019 4/5/2019 1.60 SLOT WELLPR UREM P Under -ream from 10,600'to 10,700'(1 10,600.0 10,700.0 21:00 22:36 fpm), pump 5x5 sweeps, open EDC 4/5/2019 4/6/2019 1.40 SLOT WELLPR TRIP P Begin POOH, PUW = 36K 10,700.0 2,600.0 22:36 00:00 4/612019 4/612019 0.60 SLOT WELLPR TRIP P Complete POOH 2,600.0 66.0 00:00 00:36 4/6/2019 4/6/2019 1.20 SLOT WELLPR TRIP P PJSM, PUD BHA #11, LD tools 66.0 0.0 00:36 01:48 4/6/2019 4/6/2019 1.10 PRODt RPEQPT PULD P PD BHA#12 WS Assembly, slide in 0.0 75.0 01:48 02:54 cart, check pack -offs, MU to coil, lag up, set counters 4/6/2019 4/6/2019 1.80 PROD1 RPEQPT TRIP P RIH w/ BHA#12 75.0 10,420.0 02:54 04:42 41612019 4/6/2019 0.20 PROD1 RPEQPT DLOG P Log K1 for -3.5' correction 10,420.0 10,476.0 04:42 04:54 4/6/2019 4/6/2019 0.20 PROD1 RPEQPT TRIP P Continue RIH, arrive at setting depth, 10,476.0 10,697.0 04:54 05:06 PUW = 35K, close EDC, RBIH, bring up pump, shear off at 3700 psi, set - down 5K WOB, TOWS -10,684' 4/6/2019 4/6/2019 1.80 PROD1 RPEQPT TRIP P POOH w/ BHA #12, PUW = 35K 10,697.0 69.0 05:06 06:54 4/6/2019 4/6/2019 1.10 PROD1 RPEQPT PULD P Tag up and space out. PJSM PUD 69.0 0.0 06:54 08:00 1 BHA#12 Whipstock setting tools 4/6/2019 4/6/2019 1.30 PROD1 WHPST WPST P MIN BHA#13 with .6°AKO motor, 0.0 74.7 08:00 09:18 2.80 DSM, 2.79 String reamer, and 10' pup. Pressure deploy. Make up to coil and surface test 4/6/2019 4/612019 1.90 PROW WHPST WPST P RIH BHA#13 74.7 10,440.0 09:18 11:12 4/6/2019 4/6/2019 0.20 PRODi WHPST WPST P Log K1 for 4.5', Close EDC, 10,440.0 10,477.0 11:12 11:24 PUW=36K 4/6/2019 4/6/2019 0.20 PROD? WHPST WPST P Continue in well, Dry tag @ 10688. 10,477.0 10,688.0 11:24 11:36 1 PUH 4/6/2019 4/6/2019 4.20 PROD1 WHPST WPST P PUH bring pump on 1.9 BPM @ 4024 10,688.0 10,692.8 11:36 15:48 PSI FS, BHP=3668, Ease onto tray call pinch point 10,688.5. 4/6/2019 4/612019 2.20 PRODi WHPST WPST P DHWOB fall off. Call bottom of 10,692.8 10,695.8 15:48 18:00 window. Continue time milling for string reamer exit 4/6/2019 4/6/2019 0.90 PROD1 WHPST WPST P Begin pushing on it w/ string reamer 10,695.8 10,711.0 18:00 18:54 out, milling rat -hole, CWT = 11.81K, WOB = 1.31K, pump = 4114 psi, annular = 33722 psi, WHP = 18 psi Page 11/35 ReportPrinted: 5/2812019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Time End Time our (hr) Phew Op Cotle Aprvity Code Time P-T-X Operation sten Dept MKS) Entl Depth (WS) 4/6/2019 4/6/2019 1.80 PROD1 WHPST REAM P Dress window (HS, 30R, 30R, & 10,711.0 10,711.0 18:54 20:42 1800), 1 fpm, dry drift window up & down, clean, tag TD of rat-hole, pump sweeps, PUW = 36K 4/6/2019 4/6/2019 1.90 PROW WHPST TRIP P Open EDC, POOH w/ BHA #13, PJSM 10,711.0 75.0 20:42 22:36 4/6/2019 4/6/2019 1.00 PROD1 WHPST PULD P PUD BHA#13, mill came out 2.80" no- 75.0 0.0 22:36 23:36 go, string reamer came out 2.79" po- go 4/6/2019 4/7/2019 0.40 PROD1 DRILL PULD P Begin PD BHA#14 Build/Turn 0.0 72.0 23:36 00:00 Assembly (2.2° AKO motor, RB Dynamus bit) 4/7/2019 4/7/2019 0.70 PROD? DRILL PULD P Complete PD BHA#14 Build/Turn 0.0 72.0 00:00 00:42 Assembly (2.2° AKO motor, RB Dynamus bit), slide in cart, check pack -offs, MU to coil, tag up, set counters 4/7/2019 4!7/2019 2.20 PROD1 DRILL TRIP P RIH w/ BHA#14 72.0 10,425.0 00:42 02:54 4/7/2019 4/7/2019 0.20 PRODt DRILL DLOG P Log K1 for-4' correction, close EDC, 10,425.0 10,463.0 02:54 03:06 1 1 PUW = 35K 4/7/2019 4/7/2019 0.10 PROD1 DRILL TRIP P Continue RIH 10,463.0 10,711.0 03:06 03:12 4/7/2019 4/7/2019 1.20 PRODi DRILL DRLG P Drilling, FS = 535 psi @ 1.9 bpm, 10,711.0 10,805.0 03:12 04:24 CWT =10.5K, WOB=2.3K, annular= 3788 psi, WHP = 79 psi, pump = 4161 psi, 98% returns, pump 5x5 sweeps, begin losing -0.1 bpm @ 10,799', drill to called TO of 10,805' 4/7/2019 4/7/2019 0.20 PROD1 DRILL TRIP P PUH to log K1 & RA, PUW = 38K 10,805.0 10,425.0 04:24 04:36 4/7/2019 4/7/2019 0.40 PROD1 DRILL DLOG P Log K1 for 0' correction, log RA at 10,425.0 10,725.0 04:36 05:00 10,691' TOWS = 10,684', BOW = 10,692, RA = 10,691.5' 4/7/2019 4/7/2019 1.80 PROD1 DRILL TRIP P POOH, PUW=37K 10,725.0 67.0 05:00 06:48 4/7/2019 4/7/2019 1.30 PRODi DRILL TRIP P At surface, Tag up and space out. 67.0 0.0 06:48 08:06 PJSM. PUD BHA#14 Build section BHA 4/7/2019 4/7/2019 0.80 PROD1 DRILL OTHR P M/U Nozzle. Stab on well. Jet stack. 0.0 0.0 08:06 08:54 Flush micro motion. Pull off well. Change out floats in UQC 4/7/2019 4/7/2019 1.20 PROD1 DRILL PULD P PJSM. M/U Mill, Motor, and FVS and 0.0 78.2 08:54 10:06 scribe. PD BHA#15 lateral BHA with .5° AKO motor, agitator, and RB HYC A3 bicenter. Make up to coil and surface test 4/7/2019 4/7/2019 2.10 PROD1 DRILL TRIP P RIH, Shallow test agitator @ 300'. 78.2 10,445.0 10:06 12:12 1 1 Continue in well 4/7/2019 4/7/2019 0.10 PROD1 DRILL DLOG P Log K1 for 4.5', Close EDC, 10,445.0 10,464.0 12:12 12:18 PUW=36K 4/7/2019 4/7/2019 0.20 PROD1 DRILL TRIP P Continue in well, Clean pass through 10,464.0 10,803.0 12:18 12:30 window 4/7/2019 4/712019 0.80 PROD1 DRILL DRLG P 10803', Drill ahead, 1.9 BPM @ 5057 10,803.0 10,864.0 12:30 13:18 PSI FS, BHP=3833. New mud @ bit 10,844' 4/7/2019 4/7/2019 0.10 PROD_ DRILL WPRT P Pull BHA wiper, PUW=35K. 10,864.0 10,864.0 13:18 13:24 I 4/7/2019 4/7/2019 1.90 PROD1 DRILL DRLG P New mud around, 1.9 BPM @ 10,864.0 11,000.0 13:24 15:18 4634PSI FS, BHP=3807. RIW=10.5K, DHWOB=l.5K Page 12135 ReportPrinted: 512812019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time ?-T-X operation (flKB) End Dope (flKB) 4/7/2019 4/7/2019 2.40 FROM DRILL DRLG P Start continuous rotating drilling 11,000.0 11,205.0 15:18 17:42 11,000' - 11,155',1.9 BPM @ 4634 PSI FS, BHP=3840 4/7/2019 4/7/2019 0.20 PROM DRILL WPRT P Wiper up -hole, PUW =37K 11,205.0 10,813.0 17:42 17:54 4/7/2019 4/7/2019 0.20 PROD1 DRILL WPRT P Wiper in-hole, RIW = 13K 1 10,813.0 11,205.0 17:54 18:06 4/7/2019 4!7/2019 1.70 FROM DRILL DRLG P Drilling, FS = 1303 psi at 1.9 bpm, 11,205.0 11,290.0 18:06 19:48 CWT = 11.5K, WOB = 1.61K, annular = 3846 psi, WHP = 114 psi, pump = 4955, -100% returns, avg ROP = 50 fph Drilling a bit ratty, clays/sands in samples, 50K PUW from 11,241', increase to 6% KCI 4/7/2019 4/7/2019 1.50 PROM DRILL DRLG P Continue drilling from 11,290, CWT = 11,290.0 11,370.0 19:48 21:18 8.11 WOB = 2.85K, annular = 3855 psi, WHP = 119 psi, pumps 5x5 sweeps, 1 00'wiper from 11,357', PUW = 39K, PUW = 45K from 11,370', avg ROP = 53 fph Holding -87° Inc in attempt to acquire the C1 prior to Fault 1 crossing (per geology) 417/2019 4/7/2019 1.70 PRODt DRILL DRLG P PUW =45K from 11,370', pull heavy to 11,370.0 11,467.0 21:18 23:00 52K break -over Drilling, CWT = 10.81K, WOB = 1.9K, annular = 3851 psi, WHP = 78 psi, PU's as required, avg ROP = 71 fph 4/7/2019 4/8/2019 1.00 PRODi DRILL DRLG P Continuous rotation drilling, CWT= 11,467.0 11,511.0 23:00 00:00 10K, WOB = 1.7K, annular = 3875 psi, WHP = 69 psi, avg ROP = 44 fph 4/8/2019 4/8/2019 1.50 PROM DRILL DRLG P Continuous rotation drilling from 11,511.0 11,600.0 00:00 01:30 11,511', CWT = 7.41K, WOB = 2.51K, annular = 3877 psi, WHP = 66 psi, pump sweeps, avg ROP = 60 fph 4/8/2019 4/8/2019 0.30 PRODt DRILL WPRT P Wiper up -hole, PUW = 40K 11,600.0 10,800.0 01:30 01:48 4/8/2019 4/8/2019 0.60 PRODt DRILL WPRT P Wiper in-hole, coil stacked at 11,400', 10,800.0 11,600.0 01:48 02:24 no WOB, PUW = 50K, reduce rate to get through & bring back up quickly, RIW = 9.9K 4/8/2019 4/8/2019 1.60 PRODi DRILL DRLG P BOBD (non oscillating to acquire 11,600.0 11,697.0 02:24 04:00 targets) FS = 1190 psi @ 1.85 bpm, CWT = 10.2K, WOB = 1.31K, annular = 3892 psi, WHP = 20 psi Confer w/ town geology, decsion made drop to 84° Inc (target deeper in C1 prior to fault crossing) 4/8/2019 4/8/2019 0.60 PRODt DRILL WPRT T Rig Link crashed, PU off bottom, PUW 11,697.0 11,697.0 04:00 04:36 = 43K, pulled heavy to 63K at 11,620' (at 7 fpm), pump 5x5 sweeps, reboot, resolve issue, RIW = 8.7K 4/8/2019 4/8/2019 3.00 FROM DRILL DRLG P Drilling, FS = 1107 psi @ 1.9 bpm, 11,697.0 12,000.0 04:36 07:36 CWT = 8.61 WOB = 1.4K, annular = 3864 psi, pump = 4784 psi, drilling break at -11,699', PUW = 41 K from 11,756' Page 13135 ReportPrinted: 5/28/2019 Operations Summary (with Timelog Depths) IC -11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Depth Start Tom End Time our (hr) Phase Op Code Activity Code Time PJA Operation (ftKB) End Depth (ftKB) 4/8/2019 4/8/2019 1.20 PRODt DRILL WPRT P Wiper to window with tie into RA 12,000.0 12,006.0 07:36 08:48 marker for a +7' correction. Some slight overpulls coming up. RBIH stacking multiple times. Reduce rate to get throigh 11,450, 11496' 4/8/2019 4/8/2019 3.50 PROD1 DRILL DRLG P 12,006', Drill 1.9 BPM @ 4742 PSI 12,006.0 12,400.0 08:48 12:18 FS, BHP=3930, RIW=7.2K, DH WOB=2K. 12059' start working rotation 4/8/2019 4/8/2019 0.30 PROD1 DRILL WPRT P 12,400', 800 foot wiper with 5 X 5 12,400.0 11,592.0 12:18 12:36 sweeps, PUW=44K 4/8/2019 4/8/2019 1.80 PROD! DRILL WPRT P RBIH, Stack out @ 11,941. Unable to 11,592.0 12,400.0 12:36 14:24 get past at various rates and speeds. PIU heavy at 68K and dragging. -12K DHWOB. Pump more sweeps and circ bottoms up. Normal material on shakers at bottoms up Work through bad area 11940 to 12,070. Min rate, Continue to bottom at full rate 4/8/2019 4/8/2019 0.50 PROD1 DRILL DRLG P 12400 Drill, 1.84 BPM (414722 PSI 12,400.0 12,450.0 14:24 14:54 FS, BHP=3937, Goto rotation @ 10430'. 4/8/2019 4/8/2019 2.70 PROD1 DRILL DRLG P 12450'. Increase inclination to 100° 12,450.0 12,628.0 14:54 17:36 tum up to crass cut. 1.84 BPM @ 4722 PSI FS, BHP=3954, 4/8/2019 4/8/2019 0.70 PROD1 DRILL WPRT P Pull wiper to 12,400. Staking, 12,628.0 12,628.0 17:36 18:18 PUW=53K 4/8/2019 4/8/2019 3.20 PROD1 DRILL DRLG P 12628', Drill, 1.89 BPM @ 4918 PSI 12,628.0 12,796.0 18:18 21:30 FS, BHP=3970, RIW-.8K, DHWOB=I.8K. Hard to gel drilling 4/8/2019 4/8/2019 0.70 PROD1 DRILL WPRT P 12796', Wiper trip to 12,300'. 12,796.0 12,795.0 21:30 22:12 PUW=55K 4/8/2019 4/8/2019 0.60 PROD1 DRILL DRLG P 12795', Drill, 1.84 BPM @ 4810 PSI 12,795.0 12,822.0 22:12 22:48 FS, BHP=3978 4/8/2019 4/9/2019 1.20 PROD1 DRILL DRLG P 12822, Drill, 1.84 BPM @ 4810 PSI 12,822.0 12,660.0 22:48 00:00 FS, BHP=4025, New mud going down coil 4/9/2019 4/9/2019 0.60 PRODt DRILL DRLG P Difficulty starting drilling, WOB w/ no 12,860.0 12,880.0 00:00 00:36 motorwork, drilled to called TO of 12,880', pump 10x10 sweeps 4/92019 4/9/2019 2.90 PROD1 DRILL TRIP P POOH, PUW = 38K, open EDC in 12,880.0 78.0 00:36 03:30 cased hole, PJSM, pre -load DS PDL 4/9/2019 4/92019 1.00 PRODi DRILL PULD P PUD BHA#15, bit came out a 1-1 78.0 0.0 03:30 04:30 " UT coil (thinnest @ .165"), inspect injector 4/9/2019 4/9/2019 2.00 PROD2 STK PULD P PU/PD BHA#16 OH Anchored Billet, 0.0 72.0 04:30 06:30 failed checks, PUD, & redeploy, check pack -offs " Crew chage 4/9/2019 4/912019 2.10 PROD2 STK TRIP P RIH w/BHA #16 72.0 10,445.0 06:30 08:36 4/9/2019 4/9!2019 0.40 PROD2 STK DLOG P Log K1 for +15' correction, Clean 10,445.0 10,495.0 08:36 09:00 counter wheel, PUW = 371 Page 14135 ReportPrinted: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Dapfh De Start rime End Time our (hr) r) Phase Op Cotle Activity Code Time P -T -X Operation (ft End Depth (RKa) 4/9/2019 4/9/2019 0.80 PROD2 STK TRIP P Continue RIH, park at window, close 10,495.0 11,050.0 09:00 09:48 EDC, RIH & stack weight 10,744', PUW = 40K, dragging -3.7K WOB, RBIH, setdown at 10757'10760', 10762', continue working through 10,802' Arrive at setting depth, PU 36K, bring on pumps, shear off at 4200 psi, set down 4K WOB, TOB -11,050% oriented HIS 4/9/2019 4/9/2019 1.80 PROD2 STK TRIP P POOH, open EDC, PJSM 11,050.0 78.0 09:48 11:36 4/9/2019 4/9/2019 1.00 PROD2 STK PULD P PUD BHA #16, bit came out a ... 78.0 0.0 11:36 12:36 4/92019 4/9/2019 0.40 PROD2 STK BOPE P Suck out stack, PU test jnl, function 0.0 0.0 12:36 13:00 test BOP'S, LD test jnt 4/9/2019 4/9/2019 1.30 PROD2 STK PULD P PD BHA#17 KO/Drilling Assembly 0.0 78.0 13:00 14:18 (Agitator, 0.5° AKO motor, new HYC A3 bit), slide in cart, chaged out pack - offs, MU to coil, tag up, space out, set counters 4/9/2019 4/9/2019 2.20 PROD2 STK TRIP P RIH w/ BHA#17, test agitator, 1.9 78.0 10,435.0 14:18 16:30 bpm, pump = 4650, FS = 1203 psi (verity on transducer) 4/9/2019 4/9/2019 0.10 PROD2 STK DLOG P Log K1 for 4 correction 10,435.0 10,473.0 16:30 16:36 4/9/2019 4/9/2019 0.40 PROD2 STK TRIP P Continue RIH, PUW = 36K, clean 10,473.0 11,050.1 16:36 17:00 through window, dry tag TOB at 11,051', PUW = 39K, bring up pump & RBIH 4/9/2019 4/9/2019 1.20 PROD2 STK KOST P Milling off billet 330' ROHS, FS = 11,051.1 11,052.1 17:00 18:12 1 1 11242 psi @ 1.9 bpm, 1fph for 1 fl 4/9/2019 4/9/2019 0.40 PROD2 STK KOST P Milling off billet 330° ROHS, FS = 11,052.1 11,053.1 18:12 18:36 1242 psi @ 1.9 bpm, 2fph for 1 It 4/9/2019 4/92019 0.20 PROD2 STK KOST P Milling off billet 330° ROHS, FS = 11,053.1 11,054.1 18:36 18:48 1242 psi @ 1.9 bpm, 3fph for 1 ft 4/9/2019 4/9/2019 0.40 PROD2 DRILL DRLG P Off billet drilling ahead -10 ft/hr, WOB 11,054.1 11,058.0 18:48 19:12 c1 k lbs. 4/9/2019 4/9/2019 1.20 PROD2 DRILL DRLG P Past OH anchered billet slips, Drill 11,058.0 11,150.0 19:12 20:24 ahead with unresticted WOB. CT Wt 8.6 k lbs, WOB 2.5 k lbs, ROP 89 ft/hr 4/9/2019 4/92019 0.20 PROD2 DRILL WPRT P PU Wt 30 k bs, PUH to dry drift billet. - 11,150.0 11,003.0 20:24 20:36 1 k WOB tug as the bit pased the top of billet. 4/9/2019 4/9/2019 0.10 PROD2 DRILL WPRT P RBIH, CT Wt 10 k lbs, billet clean. 11,003.0 11,149.0 20:36 20:42 4/9/2019 4/10/2019 3.30 PROD2 DRILL DRLG P CT 5027 psi @ 1.87 by in and 1.86 11,149.0 11,422.0 20:42 00:00 bpm out, free spin diff 1248 psi, BHP 3808 psi holding 11.1 ppg EMW, BOBD, cT Wt 8.8 k lbs, WOB 2 k Ibs, 11,271' PU 40 k lbs - MM out acting up, bypass, flush/blowdown, drive gain back to normal. Average ROP over interval drilled - 83 ft/hr 4/10/2019 4/10/2019 0.30 PROD2 DRILL DRLG P OBD- 11,422.0 11,450.0 00:00 00:18 1 1 I 4/10/2019 4/10/2019 0.10 PROD2 DRILL WPRT P PU Wt 42 k lbs Wiper# 1 to just below 11,450.0 11,112.0 00:18 00:24 1 I I the billet Page 15135 ReportPrinted: 5128/2019 - Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime Ertl Time our (hr) Phase Op Code Ac" Code Time P -T -x Operation Start Depth (WB) End Depth (ftKB) 4/10/2019 4/10/2019 0.20 PROD2 DRILL WPRT P RBIH, RIH Wt 8.8 k lbs- Wellworc 11,112.0 11,450.0 00:24 00:36 estimates 0.2 bbls cuttings returned. 4/10/2019 4/10/2019 5.50 PROD2 DRILL DRLG P CT 4841 psi Q 1.88 bpm in and 1.87 11,450.0 11,850.0 00:36 06:06 bpm out, free spin diff 1300 psi, BHP 3880 psi holding 11.1 ppg @ the window. WH 87 psi, IA 122 psi, OA 34 psi. CT Wt 5.8 k lbs, WOB 2.7 k lbs, 11,545' PU - 45 k lbs 11,646' PU - 43 k lbs free spin 1313 psi 11,667' PU - 42 k lbs 11,720' PU - 43 k lbs Pump sweeps 4/10/2019 4/10/2019 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW = 43K, clean up 11,850.0 11,100.0 06:06 06:24 to 11,100' 4/10/2019 4/10/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, stack CWT at 11,267', 11,100.0 11,850.0 06:24 06:42 no WOB indication, PUW = 51 K, then got by, RIW = 10K 4/10/2019 4/10/2019 3.00 PROD2 DRILL DRLG P Drilling, FS = 1336 psi, CWT = T2K, 11,850.0 12,043.0 06:42 09:42 WOB = 2K, annular = 3860 psi, WHIP = 46 psi, pump = 5292 psi, pump 5x5 sweeps, avg ROP = 64 fph 4/10/2019 4110/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT = 5.5K, WOB = 2K, 12,043.0 12,138.0 09:42 11:42 annular = 3920 psi, WHIP = 44 psi, pump = 5320 psi, begin continuous rotation drilling, avg ROP = 48 fph 1 00'wiper from 12,080', PUW = 44K PUW = 41 from 12,126' Drilling break at 12,114' 4/10/2019 4/10/2019 1.10 PROD2 DRILL DRLG P Drilling, CWT = 1.31K, WOB = 2.5K, 12,138.0 12,250.0 11:42 1248 annular= 4007 psi, WHIP = 18 psi, pump sweeps 4/10/2019 4/10/2019 1.20 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 45K, pull 12,250.0 10,325.0 12:48 1400 heavy at 10,915'(55K), RBIH, PUH, pull heavy at 10,795', RIBH, stack —9K WOB, pull -13K WOB, begin packing off, work free, PUH, RBIH to surge BHA prior to pulling through window 4/10/2019 4/1012019 0.20 PROD2 DRILL DLOG P RBIH & Log K1 for+6.5' correction 10,325.0 10,467.0 14:00 14:12 (circulate bottoms up from window at surface) 4/10/2019 4/10/2019 1.30 PROD2 DRILL WPRT P Wiper in-hole, sweeps timed to exit at 10,467.0 12,250.0 14:12 15:30 EOB, clean through build, PUH to 10,710', RBIH, stack weight at 11,677' 4/10/2019 4/10/2019 2.60 PROD2 DRILL DRLG P Drilling, FS = 1200 psi @ 1.9 bpm, 12,250.0 12,420.0 15:30 18:06 CWT = 1.5K, WOB = 1 K, annular = 4113 psi, WHIP = 18 psi PUW = 47K from 12,350' Average ROP over section - 65 ft/hr 4/1012019 4/10/2019 1.10 PROM DRILL DRLG P PU post crew change, CT Wt 62 k lbs, 12,420.0 12,496.0 18:06 19:12 RBIH CT 5396 psi @ 1.90 bpm in and 1.86 bpm out, Free spin 1398 psi, BHP 3991 psi, open choke, WH 16 psi, IA 124 psi, OA42 psi CT Wt 6 k to -5 k lbs, WOB —1.8 klbs, More and more frequent pick ups, CT Wt — 55-60 k lbs Average ROP over section - 69 ft/hr Page 16/35 Report Printed: 5128/2019 . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth a De Start Time EM Time Dur(hr) Phew Op Code AcIJ Catle y Time P-T-% operation on End Deptl (fiKa) 4110/2019 4/10/2019 0.40 PROD2 DRILL DRLG P Last PU 69 k lbs, 100' short BHA 12,496.0 12,526.0 19:12 19:36 wiper. RBIH, Drill ahead, start preparing for mud swap. Small short lived pack off event, 4/10/2019 4/10/2019 0.30 PROD2 DRILL WPRT P PU 52 k Ibs, 100' BHA wiper, pump 12,526.0 12,526.0 19:36 19:54 54 RBIH 4/10/2019 4/10/2019 0.80 PROD2 DRILL DRLG P PU 69 k Ibs, 100'short BHA wiper. 12,526.0 12,620.0 19:54 20:42 RBIH, Drill ahead, start preparing for mud swap. Small short lived pack off event, 4/10/2019 4/1012019 0.40 PROD2 DRILL WPRT P PU , 55 k lbs, new mud started down 12,620.0 12,620.0 20:42 21:06 the coil, Slowly PUH timing out new mud to the bit while RBIH. 4/10/2019 4/10/2019 0.60 PROD2 DRILL DRLG P CT 4944 psi @ 1.9 bpm in and 1.89 12,620.0 12,738.0 21:06 21:42 bpm out. FS diff 1352 psi, BHP 4049 psi. CT Wt 5 k Ibs, WOB 1.5 k Ibs Average ROP over section - 148 R/hr '•New Mud at the bit 12,620' 4/10/2019 4/10/2019 0.50 PROD2 DRILL WPRT P PU Wt 50 k Ibs - Wiper trip #1 12,738.0 11,940.0 21:42 22:12 Trouble turning around, reduced rate to 1.5 bpm, 4/10/2019 4/1012019 0.80 PROD2 DRILL WPRT P Multiple set downs while RBIH, 11,940.0 12,738.0 22:12 23:00 11,965, 11,984, 11,989, 11,982'-Hot gamma areas, - 140 API 0.4 bbls of cuttings returned per WIN 4/10/2019 4/11/2019 1.00 PROD2 DRILL DRLG P CT 4785 psi @ 1.89 bpm in and 1.85 12,738.0 12,878.0 23:00 00:00 bpm out, Free psi diff 1303 psi, BHP 3940 psi, targeting 11.1 ppg EMW @ the window. WH 73 psi, IA 122 psi, OA 38 psi. CT Wt 5 to -5 k Ibs, WOB 1.2 to 0.3 k lbs. Average ROP over section - 140 R/hr 4/11/2019 4/11/2019 0.20 PROD2 DRILL DRLG P CT 4785 psi @ 1.89 bpm in and 1.85 12,878.0 12,889.0 00:00 00:12 bpm out, Free psi diff 1303 psi, BHP 3940 psi, targeting 11.1 ppg EMW @ the window. WH 79 psi, IA 122 psi, OA 38 psi. CT Wt 5to-5klbs, WOB 1.2 to 0.3k lbs. Average ROP over section - 55 R/hr 4/11/2019 4/11/2019 4.80 PROD2 DRILL DRLG P On something hard, Geo thinks 12,889.0 12,964.0 00:12 05:00 siderite CT 5127 psi @ 1.9 bpm, BHP 3898 psi, CT Wt 5.8 k Ibs, WOB 3 k Ibs. 12,946' PU Wt 40 k Ibs RBIH CT 5000 psi @ 1.90 bpmfree spin diff 1335 psi, BHP 3947 psi, WH 117 psi, Ct Wt 7 k Ibs, WOB 3 k Ibs Average ROP over section - 15 R/hr 4/11/2019 4/11/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT =7.3K, WOB =3.2K, 12,964.0 12,986.0 05:00 07:00 annular = 3933 psi, WHP = 117 psi, slow drilling w/ siderite in samples 4/11/2019 4/11/2019 3.50 PROD2 DRILL DRLG P Drilling, CWT =6.3K, WOB =3.4K, 12,986.0 13,035.0 07:00 10:30 annular= 3948 psi, WHP = 125 psi, pump = 5271 psi, PUW = 43K from 13,012', Continued low ROP w/ Siderite in samples, avg ROP = 14 fph 4/11/2019 4/11/2019 2.30 PROD2 DRILL DRLG P Drilling, CWT = T9K, WOB = 2.5K, 13,035.0 13,050.0 10:30 12:48 1 1 1 annular = 3942 psi, WHP = 104 psi 4/11/2019 4/11/2019 0.30 PROD2 DRILL WPRT P Wiper up-hole, PUW = 43, clean 13,050.0 12,250.0 12:48 13:06 I Page 17135 Report Printed: 512812019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log S[atl Time End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T -X Operation Stan Depth (ttKS) End Dep0(ftKa) 4/11/2019 4/11/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, RIH = 6.SK, clean 12,250.0 13,050.0 13:06 1324 4/11/2019 4/11/2019 1.10 PROD2 DRILL DRLG P Drilling, FS = 1304 psi @ 1.88 bpm, 13,050.0 13,058.0 13:24 14:30 CWT = 9.6K, WOB = 2.9K, annular = 3940 psi, WHP = 97 psi, pump = 5306 psi 4/11/2019 4/11/2019 1.90 PROD2 DRILL DRLG P Drilling break at 13058', CWT = 7.2K, 13,058.0 13,200.0 14:30 1624 WOB = 1.3K, annular = 3952 psi, begin snubbing, PUW = 51 pump 5x5 beaded sweeps to good effect i PUW w/ beads out) Grab new parameters: FS = 1325 psi 4/11/2019 4/11/2019 2.10 PROD2 DRILL DRLG P Driling, CWT = 1.6K, WOB = 1.8K, 13,200.0 13,310.0 16:24 18:30 annular = 3961 psi, WHIP = 82 psi avg ROP = 52 fph 4/11/2019 4/11/2019 1.20 PROD2 DRILL WPRT P PU W152 k lbs - Bit trip 13,310.0 10,650.0 1830 1942 13,137-13,048' light WOB tugs -300 lbs 12,250-12,218 firm WOB tugs - 680 lbs 11,962 - 11,934 heavy WOB tugs 2.5 - 3klbs 10,788' -6 k WOB tug, believe it was a tool orientation issue not a hole issue. Window clean -150 lb WOB tug 4/11/2019 4/11/2019 2.00 PROD2 DRILL TRIP P Park, open EDC, Online @ 1.95 bpm, 10,650.0 65.0 19:42 21:42 POH Saw coil weight swing and a small pack off event when passing the Mule shoe @10,331'. Preloaded drillers side PDL in order to swap our Res tool per town request. 4/11/2019 4/11/2019 1.40 PROD2 DRILL PULD P PUD BHA 17 65.0 0.0 21:42 23:06 Lowest WH 690 psi, estimate BHP @ 10.8-10.9 ppg or lower Inspected pipe, 0.174, 0.175, 0.109, 0.175" - low reading from long shallow gouge, sliding across the window or something similar. 4/11/2019 4/11/2019 0.50 PROD2 DRILL PULD P PU/PD BHA 18 0.0 65.0 23:06 23:36 Re highside motor post resistivity tool swap, 4/11/2019 4/11/2019 0.30 PROD2 DRILL PULD T PHASE 3 called - no email from 65.0 0.0 23:36 23:54 security, radio announcement, CPF 1&2 Phase 3, CPF 3 Phase 2. Pulled BHA above swab closed same. Lined up on managed pressure 4/11/2019 4/12/2019 0.10 PROD2 DRILL WAIT T Wait on weather 0.0 0.0 23:54 00:00 1 Phase 3 4/12/2019 4/12/2019 6.00 PROD2 DRILL WAIT T Waiting on weather while pumping 0.0 0.0 00:00 06:00 managed pressure. Phase 3 4/12/2019 4/12/2019 12.00 PROD2 DRILL WAIT T Waiting on weather, pumping 06:00 1800 mangaged pressure, -16 bbl lost to formation, Phase 3 `Weather prediction calls for decreasing winds by midnight tonight. Page 18135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time our(hr) phaseOp Code Activity Cafe Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 4/12/2019 4/13/2019 6.00 PROD2 DRILL WAIT T Convoy crew change @ 19:30. 0.0 0.0 18:00 00:00 PJSM, unstab DSPDL, LD /agitator/motor. Set PDL in dedicated mount, lower blocks below windwalis, straighten mast and insert pins. -standby Weather has improved drastically, can see the shop stationed at the other end of the pad. No change in Phase conditions. Waiting on weather, pumping mangaged pressure, 4/13/2019 4/13/2019 4.50 PROD2 DRILL WAIT T Waiting on weather while pumping 0.0 0.0 00:00 04:30 managed pressure. - Phase 3 Weather has improved drastically, can see the shop stationed at the other end of the pad. Phase2 called @ 4:15, Rousted crew, called R&P to confirm our access road was clean 4/13/2019 4/13/2019 1.50 PROD2 DRILL PULD P PJSM, PU agitator and motor, PD 0.0 68.0 04:30 06:00 BHA#18, 0.5 °AKO motor over a P104 BH bit, replace checks, check pack offs. 4/13/2019 4/13/2019 2.10 PROD2 DRILL TRIP P RI w/BHA #18, shallow test agitator, 68.0 10,435.0 06:00 08:06 1.87 bpm, dip = 1265 psi, pump = 5181 psi Many various alarms on HMI, park at 9054', evaluate, VFD room door open, possibly cold conditions causing issue 4/13/2019 4/13/2019 0.20 PROD2 DRILL DLOG P Log K1 for -5.5' correction, PUW = 10,435.0 10,473.0 08:06 08:18 37K 4/13/2019 4/13/2019 0.30 PROD2 DRILL DLOG P Confirm 11.1 ppg kills well, trap 3795 10,473.0 10,676.0 08:18 08:36 psi SBHP: MD = 10,676 psi, annular = 3677 psi, TVD -sensor = 6492, 10.9 ppg EMW (stopped once hitting 10.9 ppg) 4/13/2019 4/13/2019 1.20 PROD2 DRILL TRIP P Continue RIH, 2K WOB bobble at 10,676.0 13,310.5- 08:36 0948 10,685' (window) Stack WOB 11,805', PUW = 42K, -3K WOB, & 11,785' Stack CWT at 12044' (no WOB indication) Annular increasing, PU, stack CWT at 12,711' Stack CWT at 13,088' 4/13/2019 4/13/2019 1.20 PROD2 DRILL DRLG P Drilling, FS = 1275 psi @ 1.87 bpm, 13,310.0 13,426.0 09:48 11:00 CWT = 5K, WOB = 1.6K, annular = 4285 psi, annular higher than expected w/ choke fully open (11.8 ppg at window, dropping as mud shears, cheesing over shakers), 4/13/2019 4/13/2019 1.00 PROD2 DRILL DRLG P PUW = 42K from 13,426', stacking 13,426.0 13,520.0 11:00 12:00 CWT getting to bottom, annular = 4115 psi, pump = 5419 psi, pump 5x5 sweeps (1 % LoTorq / 2% 776), -98% I returns 4/13/2019 j 4/13/2019 0.60 PROD2 DRILL DRLG P Hard spot 13,520', rate out fell to 1.3 13,520.0 13,558.0 12:00 12:36 bpm( -70% returns), annular = 3944 Italia psi, BHA wiper, PUW = 58K, rate out to 1.15 bpm (-62% returns) Page 19/35 Report Printed: 5/28/2019 . Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Deem Sran Time End Time our (hr) Phase Op Code Ad rty Code Time P-T-X Operation (ttKB) End Depm (Wa) 4/13/2019 4/13/2019 0.40 PROD2 DRILL DRLG T Unable to PU off bottom, differentially 13,558.0 13,558.0 12:36 13:00 stuck, work pipe, pull to 70K+ multiple limes, pull free @ 79.51K 4/13/2019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper up-hole, load LVT to rig & begin 13,558.0 12,753.0 1300 13:18 warming 4/13/2019 4/13/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, work a bit to gel down 12,753.0 13,558.0 13:18 13:36 beginning at 13,326' 4/13/2019 4/13/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT = OK, WOB = 1.2K, 13,558.0 13,640.0 13:36 14:48 annular = 4000 psi, 1.87 bpm in, 1 bpm out, drilling ahead, rate out continues to drop (.85 bpm), 61 K PUW from 13,623', 68K PUW from 13,626', pumped 5x5 sweeps, difficulty drilling, stacking weight 4/13/2019 4/13/2019 0.30 PROD2 DRILL WPRT P Pull 300'wiper, PUW =46K 13,640.0 13,640.0 14:48 15:06 4/13/2019 4/13/2019 3.70 PROD2 DRILL DRLG P Drilling, rate out increased to 1.15 13,640.0 13,894.0 15:06 18:48 bpm, sweeps exiting bit w/ 4K CWT, WOB = 1.32K, annular = 4008 psi, nuetral to snubbing CWT, returns climb to 1.4 bpm PUW = 50K from 13,711' PUW = 47K from 13,769' PUW =48K from 13,827' 4/13/2019 4/13/2019 0.20 PROD2 DRILL WPRT P PU Wt 54 k lbs, wiper trip 13,894.0 1,349.0 1848 19:00 4/13/2019 4/13/2019 0.20 PROD2 DRILL WPRT P RBIH 1,349.0 13,984.0 19:00 19:12 4/13/2019 4/14/2019 4.80 PROD2 DRILL DRUG P OBD CT 4481 psi @ 1.89 bpm in and 13,984.0 14,055.0 19:12 00:00 1.70 bpm out. Free spin diff 1340 psi, BHP 3970 psi. CT Wt -4 k Is, WOB 2.8 klbs. " Drilled out the lop into Kuparuk D, average 165 API, max 180. 4/14/2019 4/14/2019 0.60 PROD2 DRILL DRLG P Ct 5424 psi @ 1.85 bpm in and 1.69 14,055.0 14,070.0 00:00 00:36 bpm out BHP 4023 psi, CT Wt -3 k lbs 2.4 k lbs WOB. Gamma - 160 +API ROP - 25 ft/hr 4/14/2019 4/14/2019 3.30 PROD2 DRILL DRLG P Gamma dropping below 160 API, ROP 14,070.0 14,208.0 00:36 03:54 increasing to - 80 it/hr CT 5326 psi @ 1.88 bpm in and 1.69 bpm out, BHP 4069 psi, CT Wt -5.5 k Ib, WOB 600 lbs, ROP 80 ft/hr, pump 5x5 beaded lubed sweep - 1 ppb beads, no noticible effect on weight transfer. 4/14/2019 4/14/2019 2.10 PROD2 DRILL WPRT P PU Wt 45 k lbs, 14,208.0 10,330.0 03:54 06:00 13,779' Baker surface read out glitched, bore pressure shot up to 22k psi, artifact, continue wiper following tripping schedule, tools return normal read-outs, MWD feels confident RIH to continue drilling, Annular appears to be correct. Fault transitio(s) - clean Saw 4-5 k CT Wt over pull and -1 k WOB across hot gamma 11995-11915' billet dean, jog 5" up to mule-shoe 4/14/2019 4/14/2019 0.10 PROD2 DRILL WPRT P Log K1 for+13.5' 10,330.0 10,468.0 06:00 06:06 Page 20135 Report Printed: 5128/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth(RKB) 4/14/2019 4/14/2019 1.60 PROD2 DRILL WPRT P Wiper in-hole, bore pressure spikes to 10,468.0 14,208.0 06:06 07:42 21K psi, WOB at 15K (faulty readings from DPS) beginning at 12,962' (similar issue as wiper up- hole), MWD's trouble-shoot issue, perform power cycle, returned to normal values, continue in-hole, watching closely Stack at 14,009', continue in-hole w/ negative CWT through high gamma interval, reduce rate to 0.6 bpm, bring rate up as soon a possible, stacking working to bottom, PUW = 44K, pump 5x5 sweeps, 4/14/2019 4/14/2019 1.50 PROD2 DRILL DRLG P Drilling, FS = 1260 psi @ 1.87 bpm, 14,208.0 14,288.0 07:42 09:12 CWT-6K, WOB =0.6K, annular= 4128 psi, pump 5440 psi, rate out 1.7 bpm Bring HiVis to 2 ppb beads with lubes, pump 13 bbl pill, no significant improvement, PUW = 47 from 14288', Avg ROP = 53 fph 4/14/2019 4/14/2019 1.80 PROD2 DRILL DRLG P Drilling, CWT=-8K, WOB .6K, 14,288.0 14,352.0 09:12 11:00 annular = 4007 psi, pump = 5097 psi, pump 15 bbl, 2ppb pill to limited effect, 4/14/2019 4/14/2019 0.50 PROD2 DRILL DRLG P Drilling, CWT=-8K, WOB =0.5K, 14,352.0 14,365.0 11:00 11:30 continue struggling w/ weight transfer, continue pumping beaded pills to limited effect, unable to transfer weight to bit effectively, continual PU's 4/14/2019 4/14/2019 0.20 PROD2 DRILL WPRT P 500' wiper up-hole, PUW = 46K, clean 14,365.0 11:30 11:42 pulling through high gamma interval 4/14/2019 4/14/2019 0.30 PROD2 DRILL WPRT P Wiper in-hole, losing CWT through 13,865.0 14,365.0 11:42 1200 high gamma interval, reduce running speed 4/14/2019 4/14/2019 2.00 PROD2 DRILL DRLG P Drilling, attempt 15 bbl 2% Drill Zone / 14,365.0 14,467.0 12:00 14:00 2% Screen Kleen pill to good effect, increased weight transfer & able to drill, continue pumping Drill Zone / Screen Kleen pills binging active to —1%, avg ROP = 51 fph PUW = 65K from 14,375' PUW = 63K from 14,403' PUW = 52K from 14,412' 4/14/2019 4/14/2019 2.00 PROD2 DRILL DRLG P Drilling, CWT = -3K, WOB = 0.8K, 14,467.0 14,565.0 14:00 1600 annular = 4081 psi, pump = 5546 psi, 85% returns, continue to struggle w/ weight transfer, pumping pills to keep weight to the bit, avg ROP = 49 fph PUW = 54K from 14,565' 4/14/2019 4/14/2019 3.60 PROD2 DRILL DRLG P Drilling, CWT=-1.8K, WOB =0.5K, 14,565.0 14,734.0 16:00 1936 annular = 4117 psi, pump = 5620 psi, continue pumping pills as required PUW = 60K from 14,579', turn into BHA wiper Average ROP over interval drilled - 47'/hr Page 21/35 ReportPrinted: 5/28/2019 r Operations Summary (with Timelog Depths) yt.,. 1113-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Statl Time End Time Dur (hr) Phase Op Cotle Activity Cotle Time P -T -X Operation Stag Depth (ftKB) End Depth(ftKB) 4/14/2019 4/14/2019 0.40 PROD2 DRILL WPRT P PU Wt 45 k Is, Wiper #2- 1000' 14,734.0 13,676.0 19:36 20:00 chasing sweep up hole Clean hole, CT puling weight smooth at 39k while POOH, slight increase to 41 k @ /after 13,848' 4/14/2019 4/14/2019 0.40 PROD2 DRILL WPRT P RBIH, - preemptively reduced rate to 1 13,676.0 14,734.0 20:00 20:24 bpm and running speed to 30 ft/min from 13,800 - 14,173, back on pump 4/14/2019 4/15/2019 3.60 PROD2 DRILL DRLG P CT 5654 psi @ 1.90 bpm in and 1.78 14,734.0 14,905.0 20:24 00:00 bpm out, Free spin off 1287 psi, BHP 4149 psi, 11.2 EDC at the window, ( targeting 11.1 choke is full open). WH 21 psi, IA 124 psi, OA 34 psi. OBD Ct wt -5 k Ibs WOB 0.67 k lbs, ROP 117 - 20 Average ROP over interval drilled - 47.57hr 4/15/2019 4/15/2019 2.10 PROD2 DRILL DRLG P OBD CT 5655 psi @ 1.88 bpm in and 14,905.0 14,980.0 00:00 0206 1.77 bpm out, BHP 4175 psi, 11.26 EDC at the window, ( targeting 11 A choke is full open). WH 17 psi, IA 125 psi, OA 39 psi. Ct wt -6 k bs WOB 0.58 k lbs, ROP -50 ROP and weight transfer fell off @ 14,945', sweeps not helping Average ROP over interval drilled - 377hr 4/15/2019 4/15/2019 2.20 PROD2 DRILL WPRT P PU Wt 47 k lbs, Wiper trip to the 14,980.0 10,430.0 02:06 04:18 window for tie in. CT weight stepped up from 37 k t 43 k lbs @ 13,670'. Weight slowly fell off over the remainder of the trip up hole. Saw hot gamma spot @ 11,934' on CT wt, -450 lbs WOB, and motor torqued up. Billet clean, window clean. Jog 5" 4/15/2019 4/15/2019 0.20 PROD2 DRILL DLOG P Tie into the K1 for +10' correction, set 10,430.0 10,476.0 04:18 0430 counters, 4/15/2019 4/15/2019 0.30 PROD2 DRILL TRIP P RIH, window, build and billet clean, 10,476.0 11,100.0 04:30 04:48 4/15/2019 4/15/2019 1.80 PROD2 DRILL TRIP P Continue to RIH, begin pumping new 11,100.0 14,980.0 04:48 06:36 mud system #4 4/15/2019 4/15/2019 2.40 PROD2 DRILL DRLG P Drilling, FS = 1150 psi @ 1.8 bpm, CT 14,980.0 15,110.0 06:36 0900 = 3K, WOB = 0.71K, annular = 4240 psi, pump = 5712 psi. new mud at bit 15,006', avg ROP = 54 fph 4/15/2019 4/15/2019 2.50 PROD2 DRILL DRLG P Drilling, CWT= -1.5K, W0B=1K, 15,110.0 15,215.0 09:00 11:30 annular= 4004 psi, pump = 5053 psi, begin increasing active system to 2% LoTorq / 2% 776 (per town request), avg ROP = 42 fph ** Intermitent DPS glitches sending faulty readings to surface. Continue to watch closely 4/15/2019 4/15/2019 2.50 PROD2 DRILL DRLG P Drilling, CWT = -6K, WOB = 0.5K, 15,215.0 15,336.0 11:30 14:00 annular = 4114 psi, pump = 5244 psi PUW = 44K from 15,266' 4/15/2019 4/15/2019 0.80 PROD2 DRILL DRLG P Drilling, additional lube all the way 15,336.0 15,380.0 14:00 1448 around, modest results 4/15/2019 4/15/2019 0.30 PROD2 DRILL TRIP P Wiper up -hole, PUW = 45K, pump 15,380.0 14,555.0 14:48 1506 DrillZone pill to aid trip to bottom Page 22/35 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 4h 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log slart Dep h Sten Time End Time our (hr) Phase Op Code AcUity Code Time P -T -X Operation (RKB) End Depth (RKB) 4/15/2019 4/15/2019 0.60 PROD2 DRILL TRIP P Wiper in-hole, struggl to bottom, 14,555.0 15,380.0 15:06 15:42 squatting up to -10K CWT, PU, continue in-hole, reduce rate to .75 bpm to reach bottom 4/15/2019 4/15/2019 2.30 PROD2 DRILL DRLG P Drilling, FS = 1233 psi @ 1.9 bpm, 15,380.0 15,437.0 15:42 18:00 CWT = -8.5K, WOB = 0.6K, annular = 4070 psi, pump = 5542 psi PUW = 42K from 15,387' PUW = 53K from 15,426' 4/15/2019 4/15/2019 1.20 PROD2 DRILL DRLG P Drilling, CWT= -3K, WOB=1.8K, 15,437.0 15,458.0 18:00 19:12 annular = 4078 psi, pump = 5557 psi, drill to called TO of 15,458', pump 10 x 10 sweeps 4/15/2019 4/15/2019 0.50 PROD2 DRILL CIRC P Wait for sweeps to exit bit 15,458.0 15,458.0 19:12 19:42 4/15/2019 4/16/2019 4.30 PROD2 DRILL WPRT P Wiper to swab, PUW =44K, pump 15,458.0 137.0 19:42 00:00 1Oat 0 sweeps timed for EOB, jog 5", park at 4861'& reboot Orion 4/16/2019 4/16/2019 0.20 PROD2 DRILL WPRT P Continue out of hole, tag up, reset 137.0 78.0 00:00 00:12 counters. 4/16/2019 4/16/2019 1.80 PROD2 DRILL TRIP P RBIH 78.0 10,430.0 00:12 02:00 4/16/2019 4/16/2019 0.20 PROD2 DRILL DLOG P Tie in for -3.5' correction 10,430.0 10,470.0 02:00 02:12 4/16/2019 4/16/2019 0.20 PROD2 DRILL DLOG P Park @ 15458.74' CTMD, 6473.88' 10,650.0 10,650.0 02:12 02:24 TVD, trap psi and observe bleed down. Time Pressure EMW Initial 3765 11.18 /min 3748 11.13 2min 3695 10.98 3min 3634 10.79 5 min 3606 10.71 4/16/2019 4/16/2019 3.80 PROD2 DRILL TRIP P Continue to RIH 10,650.0 15,462.0 02:24 06:12 Some CT Weight bobbles and motor work sliding by 11,900. CT Wt set downs @ 13,770' and 13,852'. Reducet pump rate to 1 bpm @ 13,950', increased to 1.48 bpm @ 14,100'. Continue in hole. S/D 14,204', PU 45 k lbs, continue in hole, reduce RIH speed to 25 ft/min @ 14518, reduce running speed to 14 it/min @ 14,740'. 8 ft/min @ 14,800'. PU @ 15,120' for a restart, 40 k lbs, Continue in hole, 0.71 bpm & 7 B/min. Stall out 15428, pump liner running pill, RIH on LRP, tag bottom with 5-6 k lbs CT Wt. 4/16/2019 4/16/2019 3.70 PROD2 DRILL TRIP P POOH laying in LRP. 15,462.0 72.0 06:12 09:54 Park and paint Yellow Flag @ 13570.75' Park and paint White Bag @ 9378.29' Continue out of hole Top of beaded liner running pill 4/16/2019 4/16/2019 1.10 PROM DRILL PULD P LD BHA#18,over a dead well. Inspec 72.0 0.0 09:54 11:00 coil and CTC 4/16/2019 4/16/2019 0.40 COMM CASING PUTS P Prep Boor for running liner. 0.0 0.0 11:00 11:24 4/1612019 4/16/2019 1.90 COMM CASING PUTSP PU / MU jointed pipe, L2-01 first run, 0.0 1,212.0 11:24 13:18 40 joints with a solid bullnose under a shorty deployment sleeve. ( Liner 1212.44' LOA 1213.69') Page 23135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Tim Dur hr ( ) Phase O Code p Aotivi Code ly Time P- - T X Operation (n Ka) End Depth (nKB) 4/16/2019 4/16/2019 0.70 COMPZ2 CASING PULD P PJSM, PU BHA#19, 1-2-01 lower 1,212.0 1,265.0 13:18 14:00 completion BHA. 4/16/2019 4/16/2019 4.10 COMPZ2 CASING TRIP P RIH with 1-2-01 liner. Tie into flag for- 1,265.0 15,462.0 14:00 18:06 10.68'. PU Wt 38 k WOB -6 k lbs. Contiune in hole, drive by the Kt, + 6'. No correction made. Continue in hole S/D 11,648'- PU 49 k bs. 4/16/2019 4/16/2019 0.85 COMPZ2 CASING CIRC P Line up to 40 beaded LRP, recep pipe 15,462.0 14,457.0 18:06 18:57 4/16/2019 4/16/2019 1.50 COMPZ2 CASING TRIP P POOH, while laying in beaded LRP 14,457.0 10,670.0 18:57 20:27 4/16/2019 4/16/2019 1.90 COMPZ2 CASING TRIP P Pull through the window, continue 10,670.0 44.2 20:27 22:21 POOH 4/16/2019 4/16/2019 0.50 COMPZ2 CASING OWFF P At surface, check well for flow, PJSM 44.2 44.2 22:21 22:51 4/16/2019 4/16/2019 0.25 COMPZ2 CASING PULD P LD liner running tools 44.2 0.0 22:51 23:06 4/16/2019 4/16/2019 0.60 COMPZ2 CASING PUTS P Prep RF for liner ops, inspect 0.0 0.0 23:06 23:42 Traveling Blocks, inspect INJH 4/16/2019 4/17/2019 0.30 COMPZ2 CASING PUTS P Start PU upper liner segment 0.0 151.7 23:42 00:00 4/17/2019 4/17/2019 1.50 COMPZ2 CASING PUTS P Continue PU upper liner segment, 151.7 2,970.0 00:00 01:30 filling the hole every 10 its, Joint #40 @ 01:30 ,Joint #80 @ 03:10,Joint #99 @ 04:00 4/17/2019 4/17/2019 3.30 COMPZ2 CASING PUTS P Continue picking up upper 1-2-01 2,970.0 3,497.0 01:30 04.48 1 completion. 4/17/2019 4/17/2019 0.90 COMPZ2 CASING PULD P PU BHA # 20, Lower 1-2-01 BHA. 3,497.0 3,541.0 04:48 05:42 4/17/2019 4/17/2019 1.50 COMPZ2 CASING RUNL P RIH with upper 1-2-01 compelion. 3,497.0 10,599.0 05:42 07:12 4/17/2019 4/17/2019 0.10 COMPZ2 CASING DLOG P Tie into fag, note flag painted without 10,599.0 10,554.0 07:12 07:18 tying in prior to painting, it showed as a -17.2' correction, we arbitrarily set the correction t0 -4.5 to better reflect typical corrections. PU Wt 45 4/17/2019 4/17/2019 6.60 COMPZ2 CASING RUNL P Continue to RIH, first SD @ 11,438', 10,554.0 14,246.0 07:18 13:54 multiple set downs after ROP slowed @ 12,977' and really slowed down @ 13,695' Fight liner to bottom. Multiple S/D's @ 14,245' up to -25 k lbs CT Wt. Hard bottom. consult with town, Pump off liner PU 38 k WOB -5 klbs. Guestimate top @ 10747.7 Drive by of K1 showed 4.5' correction drive by of the RA tag showed -3' correction. 4/17/2019 4/17/2019 2.00 COMPZ2 CASING TRIP P PUH, park, reset counters. POOH 14,246.0 58.0 13:54 15:54 4/17/2019 4/17/2019 0.80 COMPZ2 CASING PULD P LD BHA 20 over a dead well. 58.0 0.0 15:54 1642 Losses 4 bbpl/hr 4/17/2019 4/17/2019 1.25 PRODS STK CIRC P Skid cart, pull checks, stab on, flush 0.0 0.0 16:42 17:57 stack.test inner reel valve, inner reel iron, and stripper. 4/17/2019 4/17/2019 1.50 PROD3 STK CTOP P Prep RF for testing operations, grease 0.0 0.0 17:57 19:27 crew on location service tree valves and tango's. 4/17/2019 4/18/2019 4.55 PRODS STK BOPE P Start bi-weekly BOPE test, low 250 0.0 0.0 19:27 00:00 psi/High 3,500 psi, Annular 2,500 psi, , witness waived by AOGCC (Adam Earl) Page 24/35 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Sart Time End Time our (hr) Phase Op Cod. Activity Code Time P -T -X Operation (ftKS) End Depth(ftKa) 4/18/2019 4/18/2019 2.50 PROD3 STK BOPE P Continue bi-weekly BOPE test, low 0.0 0.0 00:00 02:30 250 psi/High 3,500 psi, Annular 2,500 psi, witness waived by AOGCC (Adam Earl), call out grease/valve crew re -test Tango #1 (pass). Fail/pass=Swab #2 Fail/pass=Tango #1 Fail/pass=R3 4/18/2019 4/18/2019 0.50 PROD3 STK CTOP P Coil Mangement (flat spot @ 0.0 0.0 02:30 03:00 7' (WT=0.120"), Slide cart forward, remove UQ, cut/remove CTC, trim coil P.O.) 4/18/2019 4/18/2019 1.00 PROD3 STK CTOP P Install CTC 0.0 0.0 03:00 04:00 4/18/2019 4/18/2019 0.80 PROD3 STK CTOP P Re -head BHI UQ, PT UQ to 4,500 psi 0.0 0.0 04:00 04:48 (good -test) 4/18/2019 4/18/2019 0.30 PROD3 STK CTOP P Install QTS, MU build assembly 0.0 0.0 04:48 05:06 4/18/2019 4/18/2019 1.20 PROD3 STK PULD P PU BHA#21, turn build assemble, 2.2 0.0 90.0 05:06 06:18 ° AKO motor over a rerun P14 BH bit with an agitator. 4/18/2019 4/18/2019 2.00 PROD3 STK TRIP P Bump up, set counters, RIH. 90.0 10,435.0 06:18 0818 Shallow agitator test, 1.9 bpm diff 1451 psi, strong vibrations. Continue in hale, star turning the coil over to mud. 4/18/2019 4/18/2019 0.20 PROD3 STK DLOG P Tie into the Ki for a -3.5' 10,435.0 10,468.0 08:18 08:30 4/18/2019 4/18/2019 1.10 PROD3 STK TRIP P Open EDC, circulate well to mud. 10,468.0 10,625.0 08:30 0936 Mud to surface, Cose EDC, PU Wt 35k lbs. 4/18/2019 4/18/2019 0.10 PROD3 STK TRIP P RIH, window clean, dry tag billet @ 10,625.0 10,706.0 09:36 0942 1 10743' PU Wt 37 It Ibs 4/18/2019 4/18/2019 0.20 PROD3 STK KOST P Set rate, RBIH, CT 5118 psi @ 1.90 10,706.0 10,742.4 09:42 0954 bpm in and 1.81 bpm, Free spin 1025 psi, CT Wt 11.37 k lbs, 4/18/2019 4/18/2019 1.00 PROD3 STK KOST P Tag TOB start time milling @ 1 ft/hr 10,742.4 10,743.6 09:54 10:54 4/18/2019 4/18/2019 0.60 PROD3 STK KOST P Increase ROP to 2 ft/hr 10,742.4 10,744.6 10:54 11:30 4/18/2019 4/18/2019 0.10 PROD3 STK KOST P Increase ROP to 3 ft/hr 10.744.6 10,745.2 11:30 11:36 4/18/2019 4/18/2019 0.30 PROD3 STK KOST P Gradually target 1 k lbs WOB 10,745.2 10,752.0 11:36 11:54 CT Wt 13 k lbs, WOB 0.8 It lbs - 50 ft/hr 4/18/2019 4/18/2019 0.60 PROD3 DRILL DRLG P Drilling ahead 10,752.0 10,800.0 11:54 1230 CT 4844 psi @ 1.88 bpm in and 1.83 bpm out BHP 3787 psi, 11.1 ppg EMW at the window. CT Wt 11.79 k lbs, WOB 1.61 It lbs ROP 62 fUhr 4/18/2019 4/18/2019 0.20 PROD3 DRILL WPRT P PU Wt 39 k lbs, PUH for dry drift. 10,800.0 10,800.0 12:30 12:42 RBIH Window clean 4/18/2019 4/18/2019 4.20 PROD3 DRILL DRLG P Ct 4776 @ 1.88 bpm in and 1.84 bpm 10,800.0 11,018.0 12:42 16:54 out, free spin diff 837 psi, BHP 3823 psi, WH 16, IA 121 psi, OA 26 psi, OBD, CT Wt 11.7 k lbs, WOB 3.8 k lbs, ROP 50 Page 25/35 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth slart rime EM Time our (hr) phase Op Cade Activity Code Time P-T-X Opeiaaon (flKe) End Depth (ftKa) 4/18/2019 4/18/2019 1.10 PROD3 DRILL DRLG P Ct 4776 @ 1.88 bpm in and 1.84 bpm 11,018.0 11,070.0 16:54 18:00 out, free spin diff 837 psi, BHP 3823 psi, WH 16, IA 121 psi, OA 26 psi, OBD, CT Wt 11.7 k lbs. WOB 3.8 k lbs, ROP 50 4/18/2019 4/18/2019 0.20 PRODS DRILL TRIP P Pull up hole allowing sweep to exit the 11,070.0 10,684.0 18:00 18:12 bit, PUW 391k, continue pulling to the window, jog the 5 inch. 4/18/2019 4/18/2019 0.20 PRODS DRILL TRIP P At the TOW, shut down pump, open 10,684.0 10,684.0 18:12 18:24 EDC 4/18/2019 4/18/2019 1.60 PRODS DRILL TRIP P POOH, pumping 2.0 bpm at 3,822 psi 10,684.0 1,584.0 18:24 20:00 4/18/2019 4/18/2019 0.20 PRODS DRILL TRIP P Active choke plugged off (B) 900 psi 1,584.0 1,389.0 20:00 20:12 WHP line up to choke (A), choke (A) plugging off, cycle choke to advoid plugging off, continue POOH slowly, clearing choke (B) @ 35 fpm 4/18/2019 4/18/2019 0.60 PRODS DRILL TRIP P Continue POOH taking returns 1,389.0 69.0 20:12 20:48 1 through choke (A) 4/18/2019 4/18/2019 0.15 PRODS DRILL PULD P At surface, space out 69.0 69.0 20:48 20:57 4/18/2019 4/18/2019 1.10 PRODS DRILL PULD P PUD build section assembly 69.0 0.0 20:57 22:03 4/18/2019 4/18/2019 0.60 PRODS DRILL PULD P Crew change (Nabor's), Tools OOH, 0.0 0.0 22:03 22:39 LD motor and brake off agitator 4/18/2019 4/18/2019 0.75 PRODS DRILL CTOP P MU N=le and jet BOPE stack and 0.0 0.0 22:39 23:24 flush choke (B) 4/18/2019 4/19/2019 0.60 PRODS DRILL PULD P MU & PD Lateral Drilling Assembly, 0.0 17.2 23:24 00:00 j w10.5° ako motor and RB bi-center bit 4/19/2019 4/19/2019 0.30 PROD3 DRILL PULD P MU & PD Lateral Drilling Assembly, 17.2 78.3 00:00 00:18 w/0.5° ako motor and New A3 HYC, bi-center bit, stab onto tools, perform surface test (good-test), check pac- offs (good-test) 4/19/2019 4119/2019 2.00 FROM DRILL TRIP P Tag up, reset counters, RIH 78.3 10,430.0 00:18 02:18 4/19/2019 4/19/2019 0.20 PROD3 DRILL DLOG P Log formation (Ki) for depth control 10,430.0 10,463.0 02:18 02:30 1 minus 2.0' 4/19/2019 4/19/2019 0.38 PRODS DRILL TRIP P Continue IH 10,463.0 11,070.0 02:30 02:52 4/19/2019 4/19/2019 3.00 PRODS DRILL DRLG P OBD, 1.87 bpm at 4,057 psi, 11,070.0 11,470.0 02:52 05:52 Diff--1,250 psi, WHP=14, BHP=3,920, IA=120, OA=22, avg ROP 133 ftlmin, 4119/2019 4/19/2019 0.10 PRODS DRILL WPRT P PU Wt 35 k lbs, Wiper#1 to just below 11,470.0 11,070.0 05:52 05:58 the build - 400' 4/19/2019 4/19/2019 0.20 PRODS DRILL WPRT P RBIH 11,070.0 11,470.0 05:58 06:10 4/19/2019 4/19/2019 8.20 PRODS DRILL DRLG P 1.87 bpm at 5007 psi, Free spin diff 11,470.0 11,900.0 06:10 14:22 1080 psi, WHP=14, BHP=3885psi, IA=122, OA=28, OBD CT 6 k lbs, WOB 2.8 k lbs. Ran into siderite - 11,490-11,584' and many more stringers 11,601' PU 39 k lbs 11,777' PU 38 k lbs 11,890' PU 40 k Ibs avg ROP 52 fUmin, 4/19/2019 4/19/2019 0.30 PRODS DRILL WPRT P PU Wt 40 k Ibs, Wiper 11,900.0 11,078.0 14:22 14:40 Page 26135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tyne End Time Dur (hr) Phase Op Cod. Activity Coda Time P-T-x Operation Start Depth (WB) End Depth (RKB) 4/19/2019 4/19/2019 0.20 PROD3 DRILL WPRT P RBIH 11,078.0 11,900.0 14:40 14:52 SID 11634'- CT Wt -3 k Is, WOB 1.7 k lbs, PU and continue in hole 11,779 WOB spike to 700 lbs, 11,797' WOB spike to 835 lbs 4/19/2019 4/19/2019 2.20 PRODS DRILL DRLG P 1.86 bpm at 5951 psi, Free spin diff 11,900.0 11,984.0 14:52 17:04 1034 psi, WHP=15, BHP=3944 psi, IA=124, OA=29, CT 1 k lbs, WOB 2.11 k lbs. 11,935' PU 41 k lbs avg ROP 38 ft/min, 4/19/2019 4119/2019 1.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,107 psi, 11,984.0 12,057.0 17:04 18:34 Diff-1,100 psi, WHP=13, BHP=3,922, IA=125, OA=32 4/19/2019 4/19/2019 0.90 PRODS DRILL WPRT P Ratty Drilling, with increased weight 12,057.0 10,430.0 18:34 19:28 on pickup's, pull early wiper up hole, pull through window, jog the 5inch. RIH to log K1 marker 4/19/2019 4/1912019 0.20 PRODS DRILL DLOG P Log formation (K1), correction of plus 10,430.0 10,463.0 19:28 19:40 4.0' 4/19/2019 4/19/2019 0.60 PRODS DRILL WPRT P Continue wiper IH 10,463.0 12,057.0 19:40 20:16 4119/2019 4119/2019 2.15 PRODS DRILL DRLG P BOBD, 1.87 bpm at 4,078 psi, 12,057.0 12,156.0 20:16 22:25 Diff=1,048 psi, WHP=14, BHP=3,910, IA=122, OA=28 New mud at the bit @ 12,110' 4/19/2019 4/19/2019 0.20 PRODS DRILL DRLG P PUH, obtain new pumping 12,156.0 12,156.0 22:25 22:37 parameters, PUW 40 k 4119/2019 4/19/2019 0.20 PRODS DRILL DRLG P BOBO, 1.87 bpm at 4,078 psi, Diff-1, 12,156.0 12,173.0 22:37 22:49 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4119/2019 0.50 PRODS DRILL DRLG P Hard spot, PUW 38 k, restart, BOBO, 12,173.0 12,184.0 22:49 23:19 1.87 bpm at 4,078 psi, Diff=1,060 psi, WHP=222, BHP=3,897, IA=122, OA=289 4/19/2019 4/19/2019 0.30 PROD3 DRILL WPRT P PUH, mud weight falling, MM out 0.00, 12,184.0 12,184.0 23:19 23:37 take returns outside (35 Obis), returns Leaned up, bring returns back inside. 4/19/2019 4/19/2019 0.20 PRODS DRILL DRLG P BOBO, 1.87 bpm at 4,078 psi, 12,184.0 12,195.0 23:37 23:49 Diff--1,060 psi, WHP=222, 8HP=3,897, IA=122, OA=289 4/19/2019 4/20/2019 0.18 PROD3 DRILL WPRT P PUH, PUW 51 k, pull short wiper up 12,195.0 11,795.0 23:49 00:00 hole, pumping BU 4/20/2019 4/20/2019 0.25 PRODS DRILL WPRT P Wiper back in hole, RM 6 k 11,795.0 12,195.0 00:00 00:15 4/20/2019 4/20/2019 0.50 PRODS DRILL DRLG P BOBD, 1.86 bpm at 4,050 psi, 12,195.0 12,198.0 00:15 00:45 Diff=1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4120/2019 4/20/2019 1.10 PRODS DRILL WPRT T HOT has failed, circulate 5x5 sweep 12,198.0 10,684.0 00:45 01:51 and chase to the window 4/20/2019 4/20/2019 0.25 PRODS DRILL WPRT T Jog the 5inch x1, Open EDC, POOH 10,684.0 10,348.0 01:51 02:06 4/20/2019 4/20/2019 2.00 PRODS DRILL TRIP T Shut down the pump, open EDC, 10,348.0 67.0 02:06 04:06 POOH pumping 2 bpm 4/20/2019 4/20/2019 1.50 PRODS DRILL PULD T LD BHA #22 67.0 0.0 04:06 0536 4/20/2019 4/20/2019 1.50 PROD3 DRILL PULD T PU BHA #23 0.0 72.0 05:36 07:06 4/20/2019 4/20/2019 1.20 PRODS DRILL TRIP T RIH, shallow tested agitator, 940 psi 72.0 10,440.0 07:06 08:18 1 free spin diff @ 1.83 bpm Page 27135 ReportPrinted: 5/2812019 . Operations Summary (with Timelog Depths) .,r 1 C-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur hr ( ) Phase O Code p Activi Cotle ty Time RT- X Operation Start Depth (W8) End Depth (flKa) 4/20/2019 4/20/2019 0.20 PROD3 DRILL DLOG T Tie into the K1 for a -5' correction 10,440.0 10,464.4 08:18 08:30 4/20/2019 4/20/2019 0.50 PROD3 DRILL TRIP T PU Weight 35 k lbs, continue to RIH. 10,464.4 12,198.0 08:30 0900 Window and billet clean, S/D @ 10,669', both CT Wt and WOB, PU clean continued to RIH, we were oriented as drilled on both runs. 4/20/2019 4/20/2019 0.10 PROD3 DRILL DRLG P CT 4522 psi, @ 1.86 bpm in and 1.82 12,198.0 12,207.0 09:00 09:06 bpm out, free spin diff 1005 psi, OBD, CT Wt 0 k lbs, WOB 2.3 k lbs. ROP 90 /hr 4/20/2019 4/20/2019 3.20 PROD3 DRILL DRLG P OBD, CT 4726 psi, @ 1.86 bpm in and 12,207.0 12,332.0 09:06 12:18 1.82 bpm out, BHP 3896 psi, CT Wt 0 k lbs, WOB 1.9 k lbs. " Faulted into the D, -180 API rock ROP 40 ft/h 12,327' PU 40 k lbs 12,332' PU 40 k lbs Average ROP 39 ft1hr 4/20/2019 4/20/2019 0.90 PROD3 DRILL WPRT P PU 42 k lbs, PUH on BHA wiper, 12,332.0 11,079.0 12:18 1312 12,225' CT wt increased from 37k to 44 k lbs, Some -1k WOB tougs up to 12,147' RBIH S/D @ 12,184'2.6 k WOB. PUH, -6 k WOB 54k CT Wt, slight pack off event pump 5x5, slow pull UH whie sweep exits, turn around once sweep in cased hole " 1253' wiper #1 4/20/2019 4/20/2019 0.40 PRODS DRILL WPRT P RBIH, 11,079.0 12,332.0 13:12 13:36 Saw spot @ 12,230', dropped pump rate bumped through 4/20/2019 4/20/2019 1.30 PROD3 DRILL DRLG P CT 4573 psi, @ 1.86 bpm in and 1.85 12,332.0 12,361.0 13:36 14:54 bpm out, BHP 3899 psi, CT Wt -1.6 k lbs, WOB 2.6 k lbs. Diff pressure jumpingg, assuing plugged no=le(s) cleared. 12,339' PU 40 k lbs 12,355' PU 40 k Ibs 12,355' PU 40 k Ibs Average ROP 22 fUhr 4/20/2019 4/20/2019 0.60 PROD3 DRILL DRLG P Required the sand 12,361.0 12,439.0 14:54 15:30 CT 4893 psi @ 1.85 bpm on bottom diff 1304 psi, BHP 3905 psi, WH 99 psi, IA 125 psi, OA 29 psi CT Wt 4 k lbs, WOB 1.8 k lbs, ROP 220 ft/hr in between siderite stringers. Average ROP ft/hr 4/20/2019 4/20/2019 0.40 PRODS DRILL WPRT P PU 41k Pull up above the fault, 12,439.0 12,439.0 15:30 1554 12,151' RBIH, set down @ fault 3 times, tried reducign rate and orienting. Made it through by orienting TF to low side and droping the pump. 4/20/2019 4/20/2019 1.10 PRODS DRILL DRLG P CT 4633 psi, @ 1.85 bpm in and 1.83 12,439.0 12,581.0 15:54 17:00 bpm out, BHP 3896 psi, CT Wt -2 k Ibs, WOB 2. k Ibs. Average ROP ft/hr 4/20/2019 4/20/2019 1.00 PROD3 DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 12,581.0 12,700.0 17:00 1800 Diff=1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4/20/2019 4/20/2019 0.35 PROD3 DRILL WPRT P Wiper up hole, PUW 38 k 12,700.0 11,700.0 18:00 1821 1 4'2"114/21 0.20 PROD3 DRILL WPRT P Wiper back in hole, RIW 10 k 11,700.0 12,183.0 18:21 1833 Page 28135 Report Printed: 5128/2019 Operations Summary (with Timelog Depths) 110-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log De Start Depth Start rime End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Op eration (WB) End Depth (tIKB) 4/20/2019 4/20/2019 0.20 FROM DRILL WPRT P Work pipe past Kuparuk D, PUW's 38- 12,183.0 12,183.0 18:33 18:45 40 k, minipulating pump rate 4/20/2019 4/20/2019 0.25 FROM DRILL WPRT P Continue IH 12,183.0 12,700.0 18:45 19:00 4/20/2019 4/20/2019 3.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 12,700.0 13,115.0 19:00 22:30 Diff --1,049 psi, WHP=227, BHP=3,910, IA=122, OA=26 4/20/2019 4/20/2019 1.25 FROM DRILL WPRT P Wiper up hole, PUW 38 k, pull through 13,115.0 10,324.0 22:30 23:45 1 1 window, jog the 5 inch, w/sweep 4/20/2019 4/21/2019 0.25 PRODS DRILL WPRT P RIH to log formation 10,324.0 10,361.0 23:45 00:00 4/21/2019 4/21/2019 0.10 FROM DRILL WPRT P Continue IH 10,361.0 10,430.0 00:00 0006 4/21/2019 4/21/2019 0.20 FROM DRILL DLOG P Log formation (K1), correction of plus 10,430.0 10,458.0 00:06 0018 8.01 4/21/2019 4/21/2019 1.00 PRODS DRILL WPRT P Continue wiper back in hole, RIW 10,458.0 12,300.0 00:18 01:18 4/21/2019 4/21/2019 0.50 FROM DRILL WPRT P Work pipe through rough area 12,300.0 12,371.0 01:18 01:48 maniplulating pump rate, one pickup, PUW 43 k, continue IH 4/21/2019 4/21/2019 4.20 PRODS DRILL DRLG P BOBD, 1.89 bpm at 4,950 psi, 13,115.0 13,205.0 01:48 06:00 Diff=1006, WHP=77, BHP=4,017, IA=125, OA=32 4/21/2019 4/21/2019 6.70 FROM DRILL DRLG P Post crew change Pick up. CT Wt 43 13,205.0 13,494.0 06:00 12:42 lbs CT 5002 psi @ 1.89 bpm in, 1.83 bpm out, BHP 4124 psi, free spin diff 1010 psi Ct Wt -5 k lbs, WOB 1.1 k lbs WHP=96, IA=131, OA=48 13307' PU 48 k lbs 13342' PU 46 k Ibs 13377' PU 49 k lbs add 1 pbb beads to the high vis 5x5 sweep pumped with good results. 4/21/2019 4/21/2019 0.40 FROM DRILL WPRT P PU Wt 45 k lbs, Wiper#1 - 1000' 13,494.0 12,495.0 12:42 13:06 4/21/2019 4/21/2019 0.80 FROM DRILL WPRT P RBIH Wt 9 k to 5 k CT @ 50 ft/min 12,495.0 13,494.0 13:06 13:54 Stack out CT Wt 12896, reduce rate and running speed, struggle to bottom. 4/21/2019 4/21/2019 3.10 FROM DRILL DRLG P CT4767 psi @ 1.79 bpm in and 1.73 13,494.0 13,679.0 13:54 17:00 bpm out, Free spin diff 864 psi, BHP 413 psi, OBD, CT Wt -7.7 k lbs, WOB 0.5 k Is, ROP 70-30 ft/hr 13,632' PU Wt 53 k lbs 4/21/2019 4/21/2019 4.50 PRODS DRILL DRLG P OBD, 1.80 bpm at 4,814 psi, 13,679.0 13,910.0 17:00 21:30 Diff=1,100 psi, WHP=214, BHP=4,123, IA=135, OA=46 4/21/2019 4/21/2019 0.40 FROM DRILL WPRT P Wiper up hole PUW 45 k, leave 13,910.0 13,110.0 21:30 21:54 beaded sweep in hole 4/21/2019 4/21/2019 0.60 PRODS DRILL WPRT P Wiper back in hole, RM 6 k 13,110.0 13,910.0 21:54 22:30 4/21/2019 4/22/2019 1.50 FROM DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 13,910.0 13,955.0 22:30 00:00 Diff=1,100 psi, WHP=163, BHP=3,910, IA=122, OA=26 4/22/2019 4/22/2019 4.50 PRODS DRILL DRLG P OBD, 1.86 bpm at 4,050 psi, 13,955.0 14,045.0 00:00 04:30 Diff=1,100 psi, WHP=163, BHP=3,910, IA=122, 0A=26 4/22/2019 4/22/2019 0.30 FROM DRILL WPRT T Unable to achieve DLGS to stay within 14,045.0 14,045.0 04:30 04:48 the polygon PUH, PUW 46 k, Circ beaded sweep 4/22/2019 4/22/2019 0.70 PRODS DRILL WPRT T POOH, laying 8.76 ppg beaded pill 14,045.0 12,543.0 04:48 05:30 Page 29135 Report Printed: 5128/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Tim Ti End Time Dur (hr) Phase Op Code Activity Code Time P=T=X Operation Stan Depth (r De End Depth (fiK8) 4/22/2019 4/22/2D19 0.20 PRODS DRILL WPRT T Pulled 10 k over CT WT and up to -8 k 12,543.0 12,132.0 05:30 05:42 WOB. Motor stalled, bit stuck, worked pipe over interval, pulled free. 4/22/2019 4/22/2019 2.80 PROD3 DRILL TRIP T Continue to POOH, Billet and window 12,132.0 65.0 05:42 08:30 clean, Jog the 5', POOH, bump up 4/22/2019 4/22/2019 1.40 PRODS DRILL PULD T PUD BHA 23, checks not holding, 65.0 0.0 08:30 09:54 close EDC, follow new PUD procedure. Bit graded out 1-1 4/22/2019 4/22/2019 1.20 PROD3 DRILL PULD T PD BHA 24, 1.1-AKO, over a RR 0.0 64.0 09:54 11:06 P104 BH bit. Swap checks post pumping beads, check pack offs, stab injector, tool test good, bump up and space out. 4/22/2019 4/22/2019 2.00 PRODS DRILL TRIP T RIH, shallow test agitator. 64.0 10,440.0 11:06 13:06 4/22/2019 4/22/2019 0.20 PROD3 DRILL DLOG T Tie into the K1 for -3.5' correction 10,440.0 10,469.0 13:06 13:18 4/222019 4/22/2019 0.20 PROD3 DRILL DLOG T Continue to RIH. Park at 10,469.0 10,679.0 13:18 13:30 10,679.18CTMD - 6494.82 TVD and measure BHP. Trapped 3860 psi and watched it limb to 3987, bled off 20 psi, observed pressure climb back to 3987 - 11.82 EMW 4/22/2019 4/22/2019 1.20 PROD3 DRILL TRIP T PU Wt 33 k Is, continue to RIH, 10,679.0 12,175.0 13:30 1442 window and billet clean. 12,175' observe gas at surface, export returns to the tiger tank. S/D 3 K WOB @ 12,295', PUH, pulling -5 k WOB @ 12,215' Clean after 12,179' 4/22/2019 4/22/2019 0.40 PRODS DRILL TRIP T PUH whil holding 12 ppg EMW @ the 12,175.0 12,225.0 14:42 15:06 window and exporting returns to the tiger tank. tum around @ 11,596', Atempt to RBIH. Returns cleaned up, brought back inside ( 100 bbls to the tiger lank) 4/22/2019 4/22/2019 0.60 PROD3 DRILL TRIP T S/D 12,220' 11 times, varied running 12,225.0 12,395.0 15:06 15:42 speed, pump rates, TF until popping through to 12,306 varied parameters 3 times popped through 4/22/2019 4/22/2019 1.30 PROD3 DRILL TRIP T Continue to RICH. Struggling W poor 12,395.0 14,045.0 15:42 17:00 weight transfer, pump 20 bbl bead sweep, dde to bottom on beads. 4/22/2019 4/22/2019 1.80 PROD3 DRILL TRIP T On bottom drilling, rammped up purr 14,045.0 14,074.0 17:00 18:48 as we kissed bottom, no free spin diff. CT 5562 psi @ 1.78 bpm, OB diff 1245, BHP 4381 argeling 12 ppg at the window. CT -5 k lbs, WOB 2.55 k lbs ROP 20 f /hr 4/222019 4/22/2019 1.70 PROD3 DRILL TRIP T "New mud at the bit 14,074' 14,074.0 14,100.0 18:48 20:30 New mud all the way around @ 19:30 -14,085', PU Wt 44 k lbs, CT 4984 psi @ 1.81 bpm in and 1.71 bpm out, Free spin Diff 1141 psi, BHP 4339 psi holding 12.1 ppg @ the window. CT Wt -8 k lbs, WOB 2.2 k lbs, ROP 15 ft/hr 14,108' PU Wt 47 k lbs 4/22/2019 4/23/2019 3.50 PRODS DRILL TRIP T Reaquired sand 14,100.0 14,285.0 20:30 00:00 OBD, CT 5294 psi, @ 1.86 bpm, BHP 4357 psi, CT -8.4 k lbs, WOB 1.64 k lbs, WH 357 psi, IA 124, OA 50 psi Page 30135 Report Printed: 5/282019 Operations Summary (with Timelog Depths) IC -11 Niw Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start-rimeStart-rimeEnd Time our (hr) Phase Op Code Activity Corte Time P -T -X Operation Star( Depth (XKB) End Depth ntKB) 4/23/2019 4/23/2019 4.00 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,285.0 14,447.0 00:00 0400 Diff=1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54 -Osculating: 14,302'-14309' 14,333'-14,416' 14,438'-14,447' 4/23/2019 4/23/2019 0.50 PRODS DRILL WPRT P Wiper up hole to 13,447', PUW 47 k 14,447.0 13,647.0 04:00 04:30 4/23/2019 4/23/2019 0.40 PRODS DRILL WPRT P Wiper back in hole, RM 0-4k CTSW 13,647.0 14,447.0 04:30 04:54 4/23/2019 4/23/2019 1.90 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,447.0 14,577.0 04:54 06:48 Diff=1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54 Osculation 14,447'-14,574' 4/23/2019 4/23/2019 0.60 PRODS DRILL WPRT P 800' wiper up hole, 55 k 14,577.0 14,577.0 06:48 0724 4/23/2019 4/23/2019 6.00 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,577.0 14,850.0 07:24 1324 Diff=1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54, (average DLGS 4' while osculating) Osculation 14,613'-14,644' 14,668'-14,717' 4/23/2019 4/23/2019 0.40 PRODS DRILL WPRT P 800' wiper up hole, PUW 47 k 14,850.0 14,050.0 13:24 13:48 4/23/2019 4/23/2019 0.60 PRODS DRILL WPRT P Wiper back in hole,RIW 0.0-2.Ok 14,050.0 14,850.0 13:48 1424 4/23/2019 4/23/2019 2.50 PRODS DRILL DRLG P OBD, 1.87 bpm at 5,446 psi, 14,850.0 14,942.0 14:24 16:54 Diff=1,150 psi, WHP=347, BHP=4,388, IA=133, OA=54, (average DLGS 4° while osculating), Heavy PU @ 14,920- 4/23/2019 4/23/2019 0.20 PROD3 DRILL WPRT P 14942, BHA wiper, PUW=62K 14,942.0 14,942.0 16:54 17:06 4/23/2019 4/24/2019 6.90 PRODS DRILL DRLG P 14942', Drill, 1.8 BPM @ 4970 PSI 14,942.0 15,152.0 17:06 00:00 FS, BHP=4430. RIW=-7.1K, DHWOB=.9K, ROP=45-25 FPH. Oscillate from 15017. Pump sweeps with BHa wipers as needed 4/24/2019 4/24/2019 1.60 PRODS DRILL DRLG P Continue drilling, 1.8 BPM @ 5207 15,152.0 15,190.0 00:00 01:36 PSI FS, BHP=4417 PSI, RIW=-5.5, DHWOB=1.1 K, ROP=33 FPH 4/24/2019 4/24/2019 0.50 PROD3 DRILL CIRC P Call TD @ 15190'. PUH for sweeps 10 15,190.0 15,190.0 01:36 02:06 low vis 50 Hi vis with beads. PUW=47K 4/24/2019 4/24/2019 2.30 PROD3 DRILL WPRT P Start swab wiper. See ratty area 15,190.0 10,437.0 02:06 0424 12,300' to 12,100' with light over pulls. Did not have to RBIH. See RA marker - 20 off. PUH and jog 5" tubing. Continue up hi=ole 4/24/2019 4/24/2019 0.10 PRODS DRILL DLOG P Log K1 for+17.5 10,437.0 10,455.0 04:24 04:30 4/24/2019 4/24/2019 2.00 PRODS DRILL WPRT P Continue swab wiper 10,455.0 78.3 04:30 06:30 4/24/2019 4/24/2019 1.70 PRODS DRILL TRIP P Tag up reset counters, RBIH 78.3 10,435.0 06:30 0812 4/24/2019 4/24/2019 0.20 PRODS DRILL DLOG P Log formation (K1), correction of plus 10,435.0 10,467.0 08:12 0824 2.0' 4/24/2019 4/24/2019 0.20 PRODS DRILL TRIP P Continue IH 10,467.0 10,680.0 0824 0836 Page 31135 Report Printed: 5/28/2019 Operations Summary (with Timelog Depths) 113-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time Eno Time Dur (hn Phase Op Code Activity Code Time P-T-X Operation Stan Depth (KKa) End Depth (IIKS) 4/24/2019 4/24/2019 0.50 FROM DRILL OWFF P Obtain static hole pressure @ 10,680', 10,680.0 10,680.0 08:36 09:06 6495.91' TVD, 11.806 ppg (3,984 psi AP), 973 WHP, weight check 4/24/2019 4/24/2019 1.50 FROM DRILL TRIP P Continue IH through window exit, S/D 10,680.0 15,201.0 09:06 10:36 12,238', and 14,607', confirm TO @ 15,201- 4/24/2019 4/24/2019 0.50 PRODS DRILL TRIP P Circulate 12.1 ppg completion fluid, 15,201.0 15,201.0 10:36 11:06 1 1 PUH slowly 4/24/2019 4/24/2019 4.50 FROM DRILL TRIP P POOH, laying in 12.1 ppg beaded liner 15,201.0 78.3 11:06 15:36 running pill, painting EOP flags 13,960' (yellow) 4/24/2019 4/24/2019 0.50 FROM DRILL OWFF P At surface, check well for flow, PJSM 78.3 78.3 15:36 16:06 4/24/2019 4/24/2019 0.50 FROM DRILL PULD P LD drilling assembly on a dead well. 78.3 0.0 16:06 16:36 4/24/2019 4/24/2019 2.80 FROM DRILL CTOP P Test coil for flat spot wall thickness 0.0 0.0 16:36 19:24 @ .100. Trim 14' of CT. Prep CT install connector. Pull test CTC to 35K. Retread E-line to UQC. Test wire @ +2000 / 75.6. Pressure test to 450OPSI 4/24/2019 4/24/2019 0.60 FROM DRILL BOPE P Perform Biweekly BOPE function test 0.0 0.0 19:24 20:00 4/24/2019 4/24/2019 2.20 COMPZ3 CASING PUTB P PJSM, Prep floor for liner pick up. P/U 0.0 1,223.1 20:00 22:12 1-2-02 lower liner segment with non ported bullnose, 41 joints 2 3/8" slotted liner, and shorty deployment sleeve 4/24/2019 4/24/2019 0.70 C0MPZ3 CASING PULD P M/U coil trek to liner. M/U injector and 1,223.1 1,267.0 22:12 22:54 surface test. Check pack offs 4/24/2019 4/25/2019 1.10 COMPZ3 CASING TRIP P Trip in hole, BHA#25 1,267.0 7,450.0 22:54 00:00 4/25/2019 4/25/2019 0.60 COMPZ3 CASING TRIP P Continue in hole with BHA #25 12-02 7,450.0 10,567.0 00:00 00:36 lower liner segment, First pick up @ 10,490'start working liner in hole 4/25/2019 4/25/2019 0.10 COMPZ3 CASING DLOG P Stop and correct to flag + 13.5' 10,567.0 10,580.0 00:36 00:42 4/25/2019 4/25/2019 0.80 COMPZ3 CASING RUNL P Continue in hole with liner. Working 10,580.0 11,635.0 00:42 01:30 liner with headway 4/25/2019 4/252019 0.20 COMPZ3 CASING DLOG P Log K1 for-22' 11,635.0 11,685.0 01:30 0142 4/25/2019 4/25/2019 5.40 COMPZ3 CASING RUNL P Continue working liner to bottom 11,685.0 12,185.0 01:42 07:06 4/25/2019 4/25/2019 2.30 COMPZ3 CASING TRIP T Unable to get liner to bottom, POOH 12,185.0 1,267.0 07:06 09:24 4/25/2019 4/25/2019 0.50 COMPZ3 CASING OWFF T At surface, check well for flow (no- 1,267.0 1,267.0 09:24 09:54 flow), 5 bbl static losses 4/25/2019 4/25/2019 0.50 C0MPZ3 CASING PULD T LD, CoilTrak tools 1,267.0 1,222.8 09:54 10:24 4/25/2019 4/25/2019 2.50 COMPZ3 CASING PULL T PJSM, lay down liner segment #1 1,222.8 0.0 10:24 12:54 4/25/2019 4/25/2019 0.70 COMM CASING PULD T MU cleanout assembly 0.0 68.4 12:54 13:36 4/25/2019 4/25/2019 1.80 COMPZ3 CASING TRIP T Tag up, reset counters, RIH with BHA 68.4 10,430.0 13:36 15:24 #26, surface tets agitator, 1.8 bpm at 1,050 psi, 4/25/2019 4/25/2019 0.20 COMPZ3 CASING DLOG T Log formation (K1) correction of minus 10,430.0 10,469.2 15:24 15:36 4,5' 4/25/2019 4/25/2019 0.30 COMPZ3 CASING TRIP T Continue IH 10,469.2 10,859.0 15:36 15:54 Page 32135 Report Printed: 5/2812019 Summary (with Timelog Depths) IC -11 lipOperations Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log StartTime Eno Time our (hr) Phase Op Code ActivityCotle Time P -T -X Operation start Depth (fiKB) End Depth (ftKB) 4/25/2019 4/25/2019 0.60 C0MPZ3 CASING TRIP T Set down @ 10,859', PUH, PUW 38 k, 10,859.0 12,193.0 15:54 16:30 adjust TF RBIH, popped through, continue IH to next SO @ 12,193' 4/2512019 4/25/2019 1.10 COMPZ3 CASING CIRC T PUH slowly displacing well to drilling 12,193.0 10,700.0 16:30 17:36 fluid 4/25/2019 4/25/2019 1.20 7OMPZ3 CASING REAM T Clean out 10,700' to setdown @ 10,700.0 12,190.0 17:36 18:48 12,190 4/25/2019 4/25/2019 2.90 COMPZ3 CASING REAM T Set down @ 12,190, Start working 12,190.0 12,365.0 18:48 21:42 area 12,190 to 12,365 with 100'bites and wipers up to 11,800'. Good amount of material over shaker. Circulate multiple Bottoms up. 4/25/2019 4/25/2019 0.90 COMPZ3 CASING REAM T 12,365 able to run in hole @ 1.8 BPM. 12,365.0 13,800.0 21:42 22:36 i 25 FPM with minor stacking untill 13,800 4/25/2019 4/26/2019 1.40 COMPZ3 CASING REAM T 13,800'. Loose surface weight, 13,800.0 15,170.0 22:36 00:00 Continue to work pipe to 15170 with multiple attempts to gel there. Multiple BHA wipers. Get gas cut mud at surface. Ship returns to tiger tank. Send 60 BBIs out. 4126/2019 4/26/2019 1.10 COMPZ3 CASING REAM T Pick up from 15170 to 15127. Unable 15,170.0 15,170.0 00:00 01:06 to get back to 15170. RIW=-BK. 4/26/2019 4/26/2019 2.00 COMPZ3 CASING REAM T Back at 15,165. Trip up to tie into RA 15,170.0 10,700.0 01:06 03:06 for hole assessment. Good trip up. Some slight overpulls 12,250 to 12,150. Looks good coming up Pumping 1.8 BPM 4/26/2019 4/26/2019 0.10 7OMPZ3 CASING DLOG T Log RA in for +13' 10,700.0 10,721.0 03:06 03:12 4/26/2019 4/26/2019 1.30 COMPZ3 CASING REAM T RBIH 50 FPM, 1.86 BPM. Set down 10,721.0 14,125.0 03:12 04:30 12,284, P/U went right through. Clean down to 12,354'. Pick up and went right through. Continue in. Set down 13034 No DHWOB. Pick up went right through 4/26/2019 4/26/2019 1.30 COMPZ3 CASING REAM T Lost surface weight, RIW=-6K, Slow 14,125.0 15,186.0 04:30 05:48 run in speed 4/26/2019 4/26/2019 1.70 COMPZ3 CASING TRIP T PUH laying in beaded 8.8 ppg LRP 15,186.0 10,684.0 05:48 0730 4/2612019 4/2612019 1.60 COMPZ3 CASING TRIP T Above window, continue POOH 10,684.0 1,500.0 07:30 09:06 pumping beads, encountered gassed up returns, set out 12 bbl of fluid to tiger tank, returns cleaned up, continue POOH 4/26/2019 4/26/2019 0.20 COMPZ3 CASING TRIP T Perform jog back in hole 1,500.0 2,186.0 09:06 09:18 0.60 COMPZ3 CASING TRIP T Continue POOH 2,186.0 68.4 09:18019 09:18 09:54019 09:54 4/26/2019 4/26/2019 2.00 COMPZ3 CASING TRIP T Tag up, reset counters, RIH 68.4 10,435.0 09:54 11:54 4/26/2019 4/26/2019 0.30 COMPZ3 CASING DLOG T Log formation (K1) correction of minus 10,435.0 10,680.0 11:54 12:12 4.5', continue IH to check pressures 4/26/2019 4/2612019 0.15 COMPZ3 CASING OWFF T Obtain static pressure above window 10,680.0 10,680.0 12:12 12:21 6502.79' TVD, 11.852 ppg, 864 psi WHP, 4,004 AP 4/26/2019 4/2612019 0.50 COMPZ3 CASING TRIP T Continue IH to 10,900', PUH slowly 10,680.0 10,900.0 12:21 12:51 circulating 12.1 ppg beaded completion fluid down coil. 4/26/2019 426/2019 0.80 COMPZ3 CASING TRIP T POOH, laying in beaded 12.1 ppg 10,900.0 7,640.0 12:51 13:39 LRP, encounter gas cut returns 8,670', send out to the tiger tank. Paint I flag 13,180' Page 33135 Report Printed: 5128/2019 Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Cade AnOty Code Time P.T.X Operadon Start Depth (qKB) End Depth (IIKB) 4/26/2019 4/2612019 0.50 COMPZ3 CASING TRIP T Stop moving OOH, continue 7,640.0 7,640.0 13:39 14:09 displacing well to completion fluid. 4/26/2019 4/26/2019 1.25 COMPZ3 CASING TRIP T Continue POOH, paint EOP flag 7,640.0 68.4 14:09 15:24 7,639.3' 4/26/2019 4126/2019 0.50 COMPZ3 CASING PULD T Check well for flow (no -flow), PJSM 68.4 68.4 15:24 15:54 4/2612019 4/26/2019 0.50 COMPZ3 CASING PULD T LD cleanout BHA on a dead well. 68.4 0.0 15:54 16:24 '•* Note: 2.80 no-go 4126/2019 4/26/2019 0.50 COMPZ3 CASING SHAH T Prep RF for liner ops 0.0 0.0 16:24 16:54 4/26/2019 4/26/2019 3.00 COMPZ3 CASING PUTS T PU 66 joints of slotted (liner 0.0 1,973.0 16:54 19:54 4/26/2019 4/26/2019 1.40 COMPZ3 CASING PULD T P/U Coiltrak tools. Make up to liner. 1,973.0 1,018.0 19:54 21:18 M/U coil and surface test tools 4126/2019 4126/2019 1.60 COMPZ3 CASING TRIP T Trip in well, EDC shut 1,018.0 10,627.0 21:18 22:54 4/26/2019 4/26/2019 0.10 COMPZ3 CASING DLOG T Tip into EOP flag for -9.7', PUW=38K 10,627.0 10,618.0 22:54 23:00 4/26/2019 4/27/2019 1.00 COMPZ3 CASING TRIP T Continue in well. Initial setdown with 10,618.0 12,247.0 23:00 00:00 P/U @J 12047'. Work pipe down to midnight depth @ 12,247 4127/2019 4/27/2019 1.90 COMPZ3 CASING RUNL T Continue working liner to bottom 12,247.0 12,580.0 00:00 01:54 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Pump down coil in compression, .5 12,580.0 12,580.0 01:54 02:00 BPM 4/27/2019 4/2712019 1.10 COMPZ3 CASING RUNL T S/D pump. Continue to work liner 12,580.0 12,713.0 02:00 03:06 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Roll pump in compression, .5 BPM 12,713.0 12,713.0 03:06 03:12 4/27/2019 4/27/2019 0.60 COMPZ3 CASING RUNL T Work liner towards bottom 12,713.0 12,767.0 03:12 03:48 4/27/2019 4/27/2019 0.10 COMPZ3 CASING RUNL T Roll pump 12,767.0 12,767.0 03:48 03:54 4/27/2019 4/27/2019 1.20 C0MPZ3 CASING RUNL T Continue Working liner, 12,878 tough 12,767.0 12,901.0 03:54 05:06 spot. Pump 1 BPM in compression. No returns. 4/27/2019 4/27/2019 1.65 COMPZ3 CASING RUNL P Continue IH, setting down 15,188', 12,901.0 15,201.0 05:06 06:45 4/27/2019 4/27/2019 0.20 COMPZ3 CASING CIRC P Bring pump up to 1.9 bpm and 1,230 15,201.0 13,214.0 06:45 06:57 psi diff, PUW 35 k 4/27/2019 4/27/2019 3.75 COMPZ3 CASING TRIP P Remove liner length from counters, 13,214.0 10,900.0 06:57 10:42 circulate 8.8 ppg drilling fluid around to clear annulus of mixed fluids, PUH laying in beaded 8.8 ppg LRP up to 10,900' 4/27/2019 4/27/2019 0.25 COMPZ3 CASING TRIP P Continue POOH, laying in 12.1 ppg 10,900.0 10,420.0 10:42 10:57 beaded LRP 4/27/2019 4/27/2019 0.20 COMPZ3 CASING DLOG P Log formation (K1) for depth control 10,420.0 10,458.0 10:57 11:09 plus 11.0 4/27/2019 4/27/2019 2.00 COMPZ3 CASING TRIP P Continue POOH, laying in 12.1 ppg 10,458.0 44.2 11:09 13:09 beaded LRP 4/27/2019 4/27/2019 0.50 COMPZ3 CASING OWFF P Tag up, check well for flow (no -flow), 44.2 44.2 13:09 13:39 PJSM 4/27/2019 4/27/2019 0.75 COMPZ3 CASING PULD P LD setting tools 44.2 0.0 13:39 14:24 4/27/2019 4/27/2019 0.50 COMPZ3 CASING PUTS P Prep RF for liner OPS 0.0 0.0 14:24 14:54 Page 34135 ReportPrinted: 5/28/2019 . ` Operations Summary (with Timelog Depths) 1c-11 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Op Code I Aa tty Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 4/27/2019 4/27/2019 4.40 COMPZ3 CASING PUTB P Start picking up liner segment #2 with 0.0 2,976.3 14:54 19:18 large ported, 1.25" bullnose, 99 jts slotted liner and shorty deployment sleeve 4/27/2019 4/27/2019 0.90 COMPZ3 CASING PULD P PJSM, P/U Coiltrak, M/U to liner and 2,976.3 3,020.6 19:18 20:12 hang in deployment rams. Change out floats in UQC. Inspect packoffs. M/U coil and surface test. Strip on. Tag up and set counters 4/27/2019 4/27/2019 1.60 COMPZ3 CASING TRIP P RIH BHA#28, EDC closed pumping 3,020.6 10,628.0 20:12 21:48 1 min rate 4/27/2019 4/27/2019 0.10 COMPZ3 CASING DLOG P Tie into flag for -8.1', PUW=37K 10,628.0 10,619.0 21:48 21:54 4/27/2019 4/27/2019 0.30 COMPZ3 CASING RUNL P Continue in well, Initial stack out @ 10,619.0 11,415.0 21:54 22:12 —1 11,415 4/27/2019 4/28/2019 80 60MPZ3 CASING RUNL P 11,415, Working liner to bottom 11,415.0 12,305.0 22:12 00:00 4/28/2019 4/28/2019 3.40 COMPZ3 CASING RUNL P Continue working 1-2-02 liner to 12,305.0 13,213.0 00:00 03:24 bottom 4/28/2019 4/28/2019 0.10 COMPZ3 CASING RUNL P Hard tag @ 13213, PUW=62K. 13,213.0 13,195.6 03:24 03:30 Repeat twice. Same spot. Bring pumps online 1.5 BPM @ 3145 PSI. Release liner. PUW=32K 4/28/2019 4/28/2019 0.40 DEMOB WELLPR PRTS P PUH to 13195. Remove liner length 13,195.6 10,219.2 03:30 03:54 left in hole 2976.34. Perform static test, Sensor depth TVD 6184.98', Pressure stabilized @ 3882 PSI, EMW=12.07 25 Minute test 4/28/2019 4/28/2019 2.00 DEMOB WELLPR CIRC P Dispace well to seawater 10,219.2 10,219.2 03:54 05:54 4/28/2019 4/28/2019 1.20 DEMOB WELLPR TRIP P POOH 10,219.2 2,500.0 05:54 07:06 4/28/2019 4/28/2019 1.00 DEMOB WELLPR FRZP P LRS on location, PJSM, move unit in, 2,500.0 2,500.0 07:06 08:06 RU, and PT hose to 4,000 psi, Freeze Ideisel protect well from 2,500' with 32 bbls of 4/282019 4/26/2019 0.55 DEMOB WELLPR TRIP P Continue POOH 2,500.0 44.2 08:06 08:39 4/28/2019 4/28/2019 1.25 DEMOB WELLPR PULD P At surface, PUD and LD setting tools 44.2 0.0 08:39 09:54 "` FTP 1,200 psi 4/28/2019 4/28/2019 2.00 DEMOB WELLPR CTOP P MU Nozzle, slab onto stump, flush 0.0 0.0 09:54 11:54 stack and surface lines to tiger tank, vac truck on location remove returns from tank 4/28/2019 4/28/2019 6.10 DEMOB WELLPR RURD P RDMO 0.0 0.0 11:54 18:00 Rig Release 18:00 hrs Page 35135 ReportPrinted: 5/28/2019 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TRANSMITTAL DATE: TRANSMITTAL #: 1 FIELD .® BP North Slope 1 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. GGV- 6 �p19 1 0 0 Attn: NSK-69 v 700 G Street to 0 G Anchorage, Alaska 99501 n nGG AOGCC 1 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Print Name/ J ' Signature It (/`�,✓ Date Please return via e-mail a copy to both Alaska E -Line Services and Co c Phillips Alaska: ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 196172 Kuparuk 30 62 5 BP North Slope 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. 44 0 0 Attn: NSK-69 AQ 700 G Street A®GCC Anchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 ame( I Signature � � return via e-mail a copy to both Alaska E -Line Services and C no Phillips Alaska: terkamo@conocophillip .com receotionC�ake-line.com THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 C-11 Permit to Drill Number: 196-172 Sundry Number: 319-125 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, qDel. eamount, Jr. Commissioner V5, DATED this �% day of March, 2019. RBWSk MAR 212019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS MAP 1,/t ?n -n, 1. Type of Request: Abandon El Plug Perforations ❑ `Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _CO261 B Whipstock ❑� . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ DevelopmentQ Stratigraphic❑ Service ❑ 196-172 ' 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-029-22714-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1 C-11 ' Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field/Pool(s): R Z ADL 25638 I Kuparuk River Field / Kuparuk River Oil Pool - 11. 2ddryPRESENT WELL CONDITION SUMMARY tal Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7011 11,211 6939 2955 N/A 10,266,10,780 Length Size MD Tf TVD Burst Collapse 80' 16" 121' 121' 9-5/8" 6943' SurfaceTpth 4439' Production7" 10,427' 6344' Liner5" 11,300' 7011' Scab Liner3-1/2" 10,271' 6231' Perforation Depth M TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,660'-10,-6559' 3_1/2" L-80 5193' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): FHL Retriev, Baker Premier, Camco SSSV 52031,10,141', 2297-13518p, 6143',19941 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 27 -Mar -19 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: William Lang ��� Authorized Title: Staff CTD Engineer Contact Email: William. R. Lon COP.COm Contact Phone: 907-263-4372 Authorized Signature: Date: .J 10 1100' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n �1�-1 ZS Plug Integrity ❑ BOP Test nX Mechanical Integrity Test E] Location Clearance ❑ Other: 30 rl-571 f0 3520 C7 P5r �S�" RBDMS-h-✓MAR 2 7 2019 Post Initial Injection MIT Req'd? Yes No ❑ Spacing Exception Required? ❑ No Subsequent Form Required: ,Yes / APPROVED BY J��/� ^ Approved by: COMMISSIONER THE COMMISSION Date: [/ 7 rrr r ✓/ G b/ /7 Submit Form and Form 10-403 Revised 4/2017 Approved application is v li l f r 2 d to of approval.p�� achm is in Duplicate .100 / �3,21'57 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 13, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill three laterals out of the KRU 1C-11 (PTD# 196-172) using the coiled tubing drilling rig, Nabors CDR3-AC. Also included in this submission is a sundry application to cut and remove liner from KRU 1 C-11 L1-02 (PTD# ✓ 209-078) to gain access to the kick off point in 1 C-11. CTD operations are scheduled to begin in late March 2019. The objective will be to drill thre laterals, KRU 1 C- 11 L2, 1C-111-2-01, and 1C-111-2-02, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry applications are the following documents: - Sundry Application Forms (10-403) for 1C-11 and 1C-11 L1-02 - Operations Summary in support of the 10-403 Sundry Applications - Current Wellbore Schematic - Proposed CTD Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10-401) for 1C-11 L2, 1C-11 L2-01, and 1C-11 L2-02 - Detailed Summary of Operations - Directional Plans for 1C-11 L2, 1C-111-2-01, and 1C-11 L2-02 - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, 1-6 %er2�� William R. Long Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 1C-11 (PTD: 196-172) KRU 1 C-11 L1-02 (PTD: 209-078) CTD Summary for Sundry Summary of Operations: KRU well 1 C-11 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 5" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and north-east of 1C-11. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, the CTD liner landed in the 1C-11 L1-02 will be cut. CDR3-AC will pull the cut liner and set a mechanical thru tubing whipstock inside the 5" casing at the planned kick off point of 10,684' MD. The 1C-11 L2 lateral will exit through the 5" and drill to a planned TD at 13,000' MD, targeting the C sand to the north. The lateral will be left unlined. An aluminum billet for kicking off will be set at 12,490' MD. The 1C-111-2-01 lateral will kick off at 12,490' MD and drill to a planned TD of 15,800' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 10,780' MD with an aluminum billet. The 1C-11 L2-02 lateral will kick off at 10,780' MD and drill to a planned TD of 15,600' MD targeting the C sand to the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 5" casing at 10,600' MD with a deployment sleeve. CTD Drill and Complete 1C-11 Laterals: Pre -CTD Work 1. RU wire line: Change out GLV's, record SIBP, and drift 2-3/8" liner. Pull 2-3/8" x 3-1/2" liner top packer. Cut 2-3/8" Liner 2. Prep site for Nabors CDR3-AC. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Prep wellbore for sidetrack a. Pull 2-3/8" slotted liner above cut b. Set Thru-Tubing Whip Stock in 5" Casing 3. 1C -11L2 Lateral (C sand -North) a. Mill 2.80" window at 10,684' MD. b. Drill 3" bi-center lateral to TD of 13,000' MD. c. Run an aluminum billet with open hole anchor at 12,490' MD. 4. 1C-11 L2-01 Lateral (C sand - North) a. Kickoff the aluminum billet at 12,490' MD. b. Drill 3" bi-center lateral to TD of 15,800' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 10,780' MD. Page 1 of 2 3/14/2019 5. 1C -11L2-02 Lateral (C sand - North-East) a. Kick off of the aluminum billet at 10,780' MD. b. Drill 3" bi-center lateral to TD of 15,600' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 10,600' MD. 6. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rip Work 1. Return to production Page 2 of 2 3/14/2019 1C-11 Proposed CTD Schematic 9-5/8"40# L-80 shoe @ 6943' MD 7"2" L-80 shoe @ 10A MD Hole in T' casing at 5466' MD (526108) Updated: 13 -Mar -2019 WRL 3-1/2" Camco TRMAXX,SE SCSSV @ 2297' MD Minimum ID = 2.813" (X -profile) 3-1/2" Cameo KBMG gas lig mandrels @ 3194', 4217', 5118' 3-12" 9.38 L-80 EUE 8rd Tubing to surface Baker 8040 seal assemblyY 5172' MD 3-1/2" mllleshoe at 5193' M8, 3-1/2" Scab Liner (5163'-10271' MD) Baker HL Retnev a paw acker al 5203' MD Baker Premier packer at 10,149' MD D -nipple at 10,189' MD Milled out to 2.80" (414109) mm 2318" Liner& LinerTo Packer o atom D Muleshoe Jnt at 10,261)-10,266' MD, inside of 525" ID tieback sleeve ID=4.40', OD=5.2" Fish - 80.40 Seal Assembly 10266'- 10313' (5/252008) Length = 46.55', ID = 3.150" Muleshoe at 10,313' MD KOP @ 10,684' MD Baker 3.5"XS"TTWS -- Gsantl Paris (sqi d) 10,660' - 10,716' MD R -Nipple at 10725' MD ID =1 ID = 1.71" • P @ 10,747' MD 1C-111,2 ,er 3.5"x5"TTWS at 10,747' MD set 15 deg LOHS - 2.80" Window Exit Top of Billet: 12,490' MD Fish at 10,990' (failed IBP) 5", 188 L-80 liner at 10,271' -11,300' MD Z P liner -top packer at 10,2]1' Hole in T' casing at 5466' MD (526108) Updated: 13 -Mar -2019 WRL 3-1/2" Camco TRMAXX,SE SCSSV @ 2297' MD Minimum ID = 2.813" (X -profile) 3-1/2" Cameo KBMG gas lig mandrels @ 3194', 4217', 5118' 3-12" 9.38 L-80 EUE 8rd Tubing to surface Baker 8040 seal assemblyY 5172' MD 3-1/2" mllleshoe at 5193' M8, 3-1/2" Scab Liner (5163'-10271' MD) Baker HL Retnev a paw acker al 5203' MD Baker Premier packer at 10,149' MD D -nipple at 10,189' MD Milled out to 2.80" (414109) mm 2318" Liner& LinerTo Packer o atom D Muleshoe Jnt at 10,261)-10,266' MD, inside of 525" ID tieback sleeve ID=4.40', OD=5.2" Fish - 80.40 Seal Assembly 10266'- 10313' (5/252008) Length = 46.55', ID = 3.150" Muleshoe at 10,313' MD Swell packer at 1 D,758' MD D = 1.68" 1-q 123/8' liner 11, 1,T - 11,802' anchor billet et 11,40T MD_ iC-111-1: 10,750' ' -1385' MD aluminum liner 11,750' 1,750' 9' aluminum billet at 11,750' MD iC-111-2-01 Plan TD: 15,800' MD Tap of Billet: 10,780' MD 1C-111,2 Plan TD: 13,000' MD 1C-111,2-02 Top of Billet: 12,490' MD Plan TD: 15,600' MD Top of Liner. 10,600' MD Swell packer at 1 D,758' MD D = 1.68" 1-q 123/8' liner 11, 1,T - 11,802' anchor billet et 11,40T MD_ iC-111-1: 10,750' ' -1385' MD aluminum liner 11,750' 1,750' 9' aluminum billet at 11,750' MD 1C-11 L1, L1-01, L1-02 Actual CTD Sidetrack ,-' Update: 07127,09 ConocoPhillips Alaska 9-5/8"40# L-80 shoe 6943' MD 10,244'un 7" 269 L-80 shoe 10,427' MD C -sand perfs (sgz'd) 10,660' -10,716' MD er 3.5" x 5" TTWS at 10,747' MD set 15 deg LOHS - 2.80" Window Fail Fish at 0,990' (failed IBP) 5", 168 L-801iner at 10,271'-11,300' MD ZXP liner -top packer at 10,271' Hole in 7" casing at 5466' MD (5/26/06) D =1.71" ell packe =1.66" ID = 1.00" Camcc TRMAXX-5E SCSSV ® 229T MD Minimum ID = 2.813" (X -profile) Cameo KBMG gas lilt mandrels @ 3194', 4217', 5118' 9.38 L-60 EUE 6rd Tubing to surface 800 seal assembly ® 5172' MD muleshoe at 5193' MD Baker Premier packer at 10,149' MD D -nipple at 10,189' MD Milled out to 2.80" (414109) 5.75" OD Locator at 10,259' MD Muleshoe Jnt at 10,260-10,266'101), inside of 5.25" ID tieback ID=4.40",OD=5.2" Fish - 80-00 Seal Assembly, 10266'- 10313'(512512008) Length = 46.55', ID = 3.00" Muleshoe at 10,313' MD IC -111-1-02:11,407'- 13,031' MD 2-38" liner 10,248'- 13,0301 slotted 11,386'- 12,992' R4M JJ 2-38" liner11.750'- 13,369' 1.750'-13,369' aluminum billet at 11,750' MO .:� KUP PROD 1 C-11 L 1-02 ConOCoPhillips If Attributes Max An & MD ro Alaska lnG walewe nvwvn Flele Name 500292271482 KUPARUK RIVER UNIT weleoee slalua PROD ncl f) mO1n, 96.30 11,99).6) ncl elm pnet 13.031.0 Comment KVUPW) Date SSSV:TROP Mmblbn End Oale K fl Last WO: 6x812008 47.011 Rlg aelWse OaM 11141199) mw Ll$4Ia1015f aLt6pM FR;Eon Dapin ") End one, Annotation IMOD By EM OaIe Lasa Tag' I Rev Reason: GLVCIO be99ea 51142013 RANGEk.as.)— es n9 ngs ....... ........._. carinP OeecnPllcn o011nl mlio) TOP"K.I sal Oepin lnK al sal Oepm QVDf.. WULen ll._Glaee iop Tnreza LINER 1C-1111-02 2318 1.905 10,240.8 13,030.0 6,635.9 4.60190 ST -L Liner Details to :M Tomm"I TOpIrvo11NK0) TopinWC) Uem Lee COm !n) 10,240.8 6.209.6 46.47 PACKER BAKER HYD KB LINER TOP PACKER 1.7 CONDUCTOR, 4101210 1 .46.4 6,213.5 46.30 SEAL 6 seal assembly stu11g into deployment eeve 1.730 10.247.9 6,214.5 46.25 DEPLOY Depbyment sleeve with Seel We 2.250 10.725.4 6,565.7 41.51 NIP LE RSEALING Nipple 1.71 10757.8 6,589.9 4 . 5well oder TAM swe8 packer. Tap of element al 10,760' 1.8 6AFETY 122291.4 10,885.1 6,634.8 9040 DEPL Y 3- GS DEPLOYMENT Sleeve 1. 12,992.2 6621.3 67O.RING O-RING SUB 1710 13,0249 6633.9 ).201NDE —TOOL Baker Oil Tool R B R INDE%MG TOOL 160 GP6 LIFT:].IW9 Perforailena i$lets snm TOpIKE) Ed. (snalsn GAS UST: 031]4 Tap INM BIm (ISSIB) MIKE) (IIKB) e) Zona OYe q Type Z 11,3864 1$992.2 6616.7 6.621.3 C3, C-d,C-3, )2)I2009 3205LOTS 2318"SLOTTED LINER 1C-1111-02 GPS L1R: 5.1175 Notes: General & Sig ':. =End— Am . 7-00 NOTE: MULTILATERAL lC l l,1 -1 lLl,1 111 -01,1GJILI-02 LOCATOR51702 6EPL:51125 sURFPCE d236 W52— JG.A9UNER;5,163.3 los)l o sEALA.1; W.M. aR000cTi.N 2e11o46sa RPERF:IOfW010 FRAC.100M0 PERF: 106/0.010)IGO WHIRSIGM10)1)0 LINER; 10.2T9Yvpl.O 6LOT5', 113a6.4.12Sm2 t LINERIGII1.1p,IOI d- ,JMo 10,000,000 1,000,000 L C 0 CL 100,000 2s u) 10,000 ro_ 0 'o oM d Ii Y 1,000 U O B _ V 10 1 Jan -1995 CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV UNIT 1C-11 (196-172) KUPARUK RIVER, KUPARUK RIV OIL Monthly Production Rates P 10111 F] I 10,150,996 7,330,578 �� �� Jr.riS11Y�(r. �719'i rSrL.11 -ar�� IL�i �t� 14 L 11 ���a■�■I ��rJF!��■ '. >'7IJ� SJI■1'-li ' �:.L,.+71 Will ire a� 1/t 1a1. rte.\t Ij�` :. MEEM�� Jan -2000 Jan -2005 Jan -2010 Jan -2015 — Produced Gas (MCFM) . GOR - Produced Water (SOPM) -- Produced Oil (BOPM) 10,000,000 W Ol 1,000,000 CIDH O 0 100,000 O s 10,000 0 - 1 Jan -2020 SPREADSHEET_Prod-Inject_Cu wes_W el I_V119_1961720_KRU_1C-11_20190321.xlsx 3/21/2019 CV rs... • 0 _ N s lD. . .- e- .- rte . z ~ Ta NO s_ O _0 O a CD ro >- co 4- -....1o _x O E > o - N cv U Q. O_ C C C ? O ly +' C a a ' OO Q Q ❑ _CaO W ' S COO coDWOWcoCO WW N O❑ l7 N J Q ... -wme(0 - 0 a > a R co ( CO( E � O-0 Q 2C 5 rc W 7 co C U N `" 1-- M M 6 i.:. 00 O O N M M 4 a) (O O L- C F.' +C+ •N O c i O i- CO N -O 0 U ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ c) C i N s- 1 W J J J J J J J J J J J J J J J '-� C � U - OO. W W W W W W W W W W W W W vQ1 's- >- I- LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL N Q1 a1 -0 Q J J J J J J J J J J J J J J J _ > Y N I- Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q cu in C ,_ :4-."- ‹ Z Z Z Z Z Z Z Z Z Z Z Z Z Z UL O s_ 0 cua) LL LL LL IL LL LL LL LL LL LL LL LL LL LL LL K ..-. .p > I DA C E a1 u N _O z Q N u _ tin > II H ON Y U L u C �_ c 1_ C CO O_ O O U O V m 1- Q a. O_ .n C Q U LL T ,- 3 U C p 't J C1 -107; a ' a U a 't C O O O ar ❑ Ts ❑ R - •- (n _, �cJa a) Ta u) RHa Baa v ? o mQ U a --) U = U m H a a U CU z 03 U O O , pCJ e-1 > Non .:9: O .0 Q Q Q 4, _ t ai a Z U d uZ � N. o �' 0 2 > U z Y t U a J J J J J J J J J J J J J J J = Tv CI °a a a m M CI a W 3 3 3 ` —' VI W 0.0 L. +t'1)1, Ilr ,....1 .o CLEtCLCLCLWCLELCLCLCLo: CLCLCL E o W W W W W W W W W W W W W W W ` O U W > > > > > > > > > > > > > > > l UOI Qcececew 2 w cex R rxcece2 cec a in Z Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y rewceczwce 2 2 o W Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q 7 a U (,. aaaaaaa0- aaaaaaa Co > > > > > > > > > > > > > > > (0 0u 0 O Y Y Y Y Y Y Y Y Y Y Y Y Y Y Y ' p O W e- N 00 Tr in N 00 Tr e1 in in co h 0 Tovum x N Q coiii ❑ 1- 1` n r 1- N N N N N N N N N N CC 1.-- 0 0 0 0 e- e- . . . . . . e- E E O O O O O O O O O O O O O O O O @ OOCOLaO. w (n (n (n (n (n (nv) CO( n Y m m CO m m 0 0 0 0 0 0 0 0 0 0 C v LU Q > F- F- I- I- I- U) V) N (A U) U) U) U) U) V) a) vs I- LLI ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ Co cr x H (6 E ro in O O O o o O O O O O O o O O O O - C ~ CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 pa 00 00 (n 4 4 N 0 0 0 N N - N 1 N N 'V1 T CO co ti 1` in O) 0) O O N 0 in in - 0 00 O N 1- CO 0 00 00 CO (O 1` (O of u (. O O O 0 N 0 0 e- 00 00 O 00 N N N N N NNNNNNNNNN N N N .0 RM M M M o O c;) chO) O)O) o o W O) ' cu p 0 0 0 O N N O N N N N N N N N '�, Ol e- e- e- e- 0 0 e- 0 0 0 0 0 0 0 0 O O O O O O O O O O O O O O O 0 C (n (n (n in (n (n in (n (n (n (n (n (n In (n Q, o +j C I co ac, Dom) .� a) o . O ad p) J U W Y .. .. W. - u C C U Q $ v O a. p F- (Do y .1 Q e- rn rn e- r rn CO CO ,_ c r 4, s+ V)) 2 *t m A Z N N N M e- O O O O e- e- r r }' _ Ed H C . OC (11 LC N' -i 2 2 2 J 6 O 2 U U 2 2 2 2 m m E (o ,_ d a < O N W 00 N N N N 00 00 h -.�.� Z a1 co TO . . .-f s h ' ' C N CO in = C F - C O (0 ._` a! N 0 C/A a LO Q D) , I- aa Qf XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /q~:,~"'//7'2 File Number of Well History File RESCAN Complete 1:3 I'1 Color items - Pages: GraYScale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED [] .Logs of various kinds Other COMMENTS: Scanned b~ildred. D'are~"~ TO RE-SCAN Notes: Nathan Lowell r-.,... ~,,'--.~mn--.~l h'u,' ~,.,.,,.~, u~,,~ nnmthn Nathan Lowell Dale: /s/ • • • • Conoco Phillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 MAR 14 2012 March 9, 2012 : MAR r?° t' Alaska 011 & Gas Cons. Commission Anchorage Commissioner Dan Seamount Alaska Oil & Gas Commission )q6 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 l — I Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerel �� MJ veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Adaska Inc" Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 3-09-2012 1B, 1C, 1 D, 1E PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 18-02 50029205310000 1801330 SF NA 16" NA 2.98 1/21/2012 18-06 50029206030000 1810750 8' 1.50 5'6" 9/11/11 18 1/21/2012 WSW-04 50029208330000 1821590 6'4" 1.30 24" 9/11/11 6.8 1/21/2012 WSW-06 _ 50029208510000 1821770 20" NA 20" NA 2.13 1/21/2012 1C-11 50029227140000 1961720 SF 1.50 22" 9/11/11 4.68 2/10/2012 1C-18 50029229390000 1990050 SF NA 18" NA 2.55 2/10/2012 1C-26 50029229440000 1990510 SF NA 18" NA 3.75 2/10/2012 1D-128 50029229000000 1981330 2" NA 26" NA 3.83 2/10/2012 To: ~10GCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/I~/lechanical Logs and/orTubing Inspection(Caliper/ MTf) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~ (907) 245-8952 1) MTt' Report 15tlun-09 1 G111 1 Report 50-029-2302g00 2) Caliper Report 20,1un-09 1 G11 1 Report / EOE 50-029-2271400 ~ ~~ ~-x ~ ~~~f1 ~a ~~'~a`~~~~~~ t,ii~ s ~ii~, ~o~ _ i~~ ~1 Signed : Date : Print Name: PROACTIVE DIAGNOSTIC $ERVICES, (NC., 130 W. INTERNATIONAL A~RPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fnx: (907~245-88952 E-NAAII : . _ __ .._ _... _ _ ~ _ _ __ VNEBSITE : . _ _ ~ C:~Documents and Settings\Owner~Desktop\Transmit_Conoco.docx • • S Memory Mut~i-Fir~ger Caliper ~og Results Summary Company: Cona:oPhillips Alaska, lnc. _ Well: _ _ _ ---_ 1C-11 Log Date: June 20, 2009 Field: Kuparuk Log No. : 6758 Sta#e: Afaska Run No,: 6{5t`' Caliper) API No.: 50-029-22714-00 Pipe1 Desc.: 3.5" 9.3 Ib. L-80 EUE 8Rb ABMOD Top Log Intvl1.: 8,900 Ft. (MD) Pipe1 Use: Scab Liner Bot. Log Intvl1.: 10,265 Ft. {MD) Pipe2 Desc.: 5" 18 Ib. L-80 Top Log Intvl2.: 10,265 Ft. (MD) Pipe2 Use: Liner Bot. Log Intvl2.: 10,659 Ft. (MD) Inspection Type : Restriction & Corrosive & Mechanical Damage 1-xspection COMMENTS : This caliper data is tied into the Baker Premier Pmduction Packer ~ ~ 0,149' (Drf/ler's Depth). This log was run to assess the condition of the 5" liner cement job to determine impact on future whipstock operations. Minimum diameters between 2.72" and 2.79° are recorded throughout the 5" liner logged. The p~esence of cement prevents the caliper fingers from recording the interior condition of the 5" finec A 3-D log plot of the caliper recordings across the 5" finer logged is included in this report. The caliper recordings indicate the 3.5" tubing and scab liner are in gaod candition with respect to corrasive and mechanical damage, with no significant wall penetrations, areas af cross-sectional wall loss, or I,D. restrictions recorded. This is the f+fth time a PDS caliper has been run in this well and the third time the 3.5" scab liner and 5" finer have been logged. A comparison between the current and previous log (April 19, 2009) indicates no change in corrosive damage to the 3.5" scab liner. The 5" liner has been filled with cement during the time between tags. 3.5" SCAB LINER - MAXIMUM RECORDED WALL PENETRATIONS: hlo signiflcant waft penefrations {> 16%} are recorded. 3.5" SCAB LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sec#ional wall loss (> 12%) are recorded throughout the liner logged. 3.5" SCAB LINER - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recarded throughout the liner logged. 5" LINER - MAXIMUM RECORDED WALL PENETRATIONS: Cement deposits prevented the caliper from reco~ding any wall penetrations throughout the liner logged. 5" LINER - MAXIMUM REC4RDED CROSS-SECTIONAL METAL LOSS : Cement deposifs prevented the caliper from recording any circumferentia! walt loss throughout the liner logged. ProActive Diagnostic Senrices, ?nc. / P.E~. Box i:i69, 5tafford, TX 7?497 Phone: (281) or {$88) 565-9085 Fax: (281) 565-1369 E-mail: PD5~~umemarylog.cam Prudhoe Bay Field Office Phone: (907) 6~59-23J~ Fax: (9G7) ~59-231~ f ~(n-l~~ ', ~ ~ ' 5" LINER - MAXIMUM RECORDED ID RESTRICTIONS : No significant I_D. restrictions are recorded throughout the liner logged. ' ' J ' Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: T. Senden ~' ProActive Diagnostic Ser~rices, Inc. / P.~. Box 1369, Stafford, 7X 77497 Pt~one: (281} or ($88) 565-9085 Fax; (281) 565-1369 E-maii: PDSramemorylog.com ' Prudhoe Bay Fieid Office Phone: (907) 659-23Q7 Fax: (90;') 659-2314 ~ , , PDS Multifinger Caliper 3D Log Plot ~_ .~ ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1C-11 Date : June 20, 2009 . Description : Detail of Caliper Recordings Across Cemented 5" Liner o° so° ~ao• 2~0° o° I _-~_.~.. ~.' ` ~ ^ ' ' , • --- _. ~ _ .-,,:~ _- _~ Joint 1 - , 10350 ~ " . . - - .. _ :~_ - - _ ~~ ~ Joint 2 . e --.. ~.--- - °~ - :~~:_ ._ . , g~.,._ , # ---..~ ' 10400 ; ' - . - ._ ~ ~ ~ Joint 3 - 10450 - ° Joint 4 ,,. ° - . . ,,, 0500 . . -- ,..:;~... ~ ' ~? Joint 5 : - .loint s 10550 . , _ ~ - - ~ ~ =-~^ "' Joint 7 10600 .loint s _- : Joint 9 10650 ~ Nominal I.D. r . . . . . . . . . . . . . . . » . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . i 2000 5000 Min I.D. (1/1000 in.) 2000 5000 Avg I.D. (1/1000 in.) 2000 5000 Comments Depth Max I.D. (1l1000 in.) 3D Log Image Map 1ft:600R 2000 5000 0° 0° 90° 180° 270° 0° `-~ -- ~ Minimum Diameter Profile Well: 1C-11 Survey Date: June 20, 2009 Field: Kuparuk Tool: UW MFC 24 XR No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 4.151 inches 1 3 ~ ~ E Z 5 C O 7 9 Minimum Measured Diameters (In.) 1.69 2.19 2.69 3.19 3.69 PDS Report Overview ~-~ ~. Body Region Analysis Well: 1 C-11 Survey Date: June 20, 2009 Field: Kuparuk Toot Type: UW MFC 24 XR No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. o( Fingers: 24 Anaiyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lowe~ len. 3.5 ins 93 f L-80 2.992 ins 35 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~;: metal loss body 30 20 10 ~ 0 to 1 tu 10 to 1% 10% 20`% 20 to 40 to over 40°/u 85% 85% Number of 'oints anal se d rotal = 54 pene. 10 25 19 loss 24 25 5 0 0 0 0 0 0 Damage Configuration ( body ) 10 O isolatcsl gc~n~nl line rtng hole/poss piuing corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 8 5 2 1 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 2 78 298 Bottom of Survey = 9 100 316 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 5. in 18.0 ppf L-80 Well: Body Wall: 0.425 in Field: Upset Wall: 0.425 in Company: Nominal I.D.: 4.151 in Country: Survey Date: ~LATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc. USA June 20, 2009 Joint No. Jt. Depth (Ft.) I'en. t l~~~c~i (In..) Pen. Body (Ins.) Pc~n. % ~I~~tal I c>ss `~~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 278 901 tt 0.~0 1 I 2.94 279 8925 U 0. 3 1 1 I_' 29 L De osi . 280 8957 U 0.02 ~~ ~' 2.97 281 8988 ~~ 0.03 I s Iu 2.96 S low it'n . Lt. e its. 282 9021 u 0.03 I U I 2.96 283 9053 U 0.02 ~) ' 298 t. D o'ts. 284 9085 ~~ 0.02 ~) 1 u 2.93 Lt. D osits 285 9116 u 0.02 8 ' 2.98 286 9148 O 0.02 £~ I 2.96 287 9179 U 0.02 7 _' 2.97 288 9211 u 0.01 5 ~ 2.95 289 9243 t) 0.03 l> 1~' 2.96 Shal w corro ' 290 9276 ~~ 0.03 11 1 2.98 297 9307 i~ 0.03 l s I ~ 2.95 Shall w ittin . 292 9339 t~ 0.03 1~~ : 2.96 293 9371 l~ 0.02 9 II 2.94 294 9402 ~~ 0.04 1 ~ 1(1 2.95 Shallow ittin . 295 943 u 0.02 7 1 2.98 296 946 (~ 0.0 i ' ~ 2.96 297 9499 i~ 0.02 t~ I l 2.96 298 9530 t~ 0.02 ~~ I .98 299 9 61 U 0.03 11 ' 2.95 300 9592 U 0.03 11 ~' .93 301 9623 ~) 0.03 11 I 2.94 2 96 (1 0. 7 ' .97 303 9687 (~ 0.02 7 ~ 2.92 304 9720 U 0.02 i I 2.98 305 9751 U 0.03 12 ' 2.97 306 9784 O 0.02 7 I 2.96 307 9815 ~) 0.04 15 1 i~ 2.96 Shallow ~ttin . 308 9847 ~? 0.03 13 2.95 Shallow itti . 309 9879 U 0.03 I1 -t 2.97 310 9910 U 0.03 ll 2.95 311 9943 U 0.02 ~) ' 2.96 312 9974 U 0.03 11 ' 2.95 313 10005 U 0.03 I1 ~~ 2.93 14 10038 ~) .02 i I 2.95 315 10069 ~~ 0.02 ~~ 2.91 316 10102 U 0.02 7 i~ 2.93 316.1 10132 ~! 0.02 I 2.96 PUP 316.2 10141 U 0 U ~~ 2. 7 Baker Pre ium Pr uction Packer 3163 10148 ~1 0.01 ~ I 2.97 NUP 317 101 SS l~ 0.02 7 > 2.96 317.1 10189 (~ 0 U U 2.80 D Ni le milled to 2.80 18 10192 u 0.04 15 U 2.97 Line shallow corrosion. 319 10222 U 0.03 13 t~ 2.96 Shallow corrosion. 319.1 10254 l~ 0.02 6 t1 .94 PU 319.2 10259 i) 0 ~~ ~ ~ 3.00 Mule Shoe Fluted No Go 3 9.3 10264 ~~ ~~ ~~ N A Fish - 0-40 eal Assem I 1 10312 ~~ 0 i~ ;~ 2.79 Cement. ~Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI. Pipe: 5. in 18.0 ppf L-80 Well: Body Wall: 0.425 in Field: Upset Wall: 0.425 in Company: Nominal I.D.: 4.151 in Country: Survey Date: ~LATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc USA June 20, 2009 Joint No. Jt. Depth (Ft.) I'~~n. UF~~~~I (Irn.) Pen. Body (Ins.} I'~~n. °i~, ~~Ic•i.il I~nti ~ Min. I.D. (Ins.) Commentr Damage Profile (%wall) 0 50 100 2 10357 t~ 0 O ~i 2J9 Cement. 3 10400 U 0 U ~~ 2.79 Cement. 4 10445 ~ ~ 0 (1 ~~ 2.79 Ceme t. 5 10490 t~ 0 (1 l1 2J8 C ment. 6 10533 ~~ 0 U ~ i 2.72 Cement. 7 10559 t~ 0 U 2.77 Cement. 8 10582 ~~ 0 0 ~~~ 2J6 Cement. 9 10625 ~~ 0 l) 2J6 Cement. ~ Penetration Body Metal Loss Body Page 2 ConocoPhillips :1~~~.1.n..1.'! 1. ~R 37 ' _ '- _ - ~ _- F-~ ~ 4 - ws uFr GAS GAS 3.5" SCAB U1gR. 5,t83-t0.21t KUP 1 C-11 WeN Attributes Max M le a MD TD Wellborc APLl/W1 500292271400 fi¢IA Mame KUPARUK RIVER UNIT WeB StaNC PRODUCING ProMnj Typa Mtl (') MD (M(B) 60.81 4,079.00 Act Bhn (ftl(B) 11,300.0 CommeM H23 (ppm) SSSV: TRDP 80 Dam 1!1/2009 Annobdon End DMa Last VYO: 6/8/20D8 KB-0N (1q 47.01 ftig Rolease Dam 1/14/1997 Amon6on D Last Tag~. SLM oqh~flKB) 10.900.0 Entl~am 4/19/'L009 Mnotation Rev (ieason: MILL NIPPLE 10J89', TAG EnADam 4@2/2009 Casln Stri a Gtwg Dsscription CONDUCTOR Strin4 0.. 16 . &rin41D _. 15D60 7op (M(B) 38.0 Set Dap1A (f... 121.0 5¢tDOph Rwl ... 121.0 StrMg W1... 62.50 Sbing ... H-00 Seriig Top Thrtl Casing Dascription SURFACE Se,wq O._ 9 5~8 llrimp D_. 8.525 Top (11KB) 38.0 Jet DaPM~ (f_. 6,943.0 9¢t DoW~ (T'U) ... 4,439.0 String YYI.. 40.00 ~erinp _ L-BO Str6p Top ThM Casiq Desapdon PRODUCTION S'Iring 0.. 7 . 9bLq D_. 6.151 ToP Ntl(B) 38.0 Sot Deph (f_ 10,427.0 Sat DaM (TVD) ... 6,344.0 Strinq YIt.. 26.00 String _ L-BO 9uw9 Top TM Gsing Deceripaon LINER Snni~q 0.. 5 . ]1rYp U_.. 4.151 Top (NCB) 10,271.0 Sa1 Deph (f_. 11,300.0 Sot DepA Rw) ._ 7,010.7 StrYg ril.. 18.00 9trYg ... L-80 StrMg Tep ThrA Gzing Duseription 3.S'SCABLWER SHinq O_ 312 . Sering D... 2.992 ToP (~B) 5.163.3 Sel Daqh (f... 10,277.0 5¢t Uaph (ND) --. 6,230.6 String YYt.. 9.30 Strwg ... ~~0 String Top EUE&dABMOD Liner Detafla To (flKB) Top DapM (ND) (~B) Top Md (9 I mm Dweriptlo n ComnaH ID (in) 5,163.3 3,496. 2 57.33 S LEEVE H tine~ Sett~g Skeve 4A20 5,177.7 3,504. 0 .34 X O BU HING Xove18ustwK~ 4.250 5,178.9 3,50A. 6 57.34 S BE 80~10 Seal Bore Ez[eneon 4.000 5.198.2 3,515. 0 57.35 X O BUSHING Xover Bushing 2.990 5,202.9 3,517. 5 57.35 P AC R FHL trievable Vadcei 2.992 10,140.9 6,142. 8 492G P ACKER Baker Premier Roduction Paci~r 2.870 10,189.0 6.175. 6 4827N IPPLE 2J5'D'Npqe-MILLEDT02.80"4/42009 2.800 10.262.0 6,224. 3 45 80 N IPPLE Fluled NdGo 3.000 Tubin Strln TuGing Detcription Sbw~g 0... Striig 10 ... Top (flKB) Sa1 Dep1A (f" Sat OaPM (TVU) ... String VYt.. String ... Strin9 Top TArd TUBING4.5"x3.5" 3112 2.992 36.7 5,193.0 3.5122 9.30 L~0 EUESrdABMOD Com letlon Detalls 7oD (~B) ToP DapM (TV~) (~B) TopMd (9 k um Dasvipdo n Commak ID (in) 36.7 36. 7 -0.72 H ANGER T~birg Hargei Gx3.5" "ISA" BPVG 2.992 2,297.4 7,994.4 55.61 S AFETYVLV TRMAX)Crd2.813°X-PROFILE-REQUIRED3500psiABOVETBG PRESSURE TO OPEN 2.812 5,1702 3.489. 9 57.34 L OCATOR LDCator w/ 1.04'space ou~ 2.992 5,172.5 3,5012 57.34 S EAL SealASSembly 2.992 Other I n Hole nHne roMwabl a I s valves m flsh etc. Top I~B) Top DepM (TVO7 (~B) TopNel (") Do~niyeo~ Comeon[ Run Oam ID (in) 10,266 6,227.7 45. FI SH 8040 SEAL ASSEMBIY, OAL 46.55 - s~l parted ~e d vas phrt~ged irto S finer (see anarJied cYawin9) SYlSl2008 3.000 10171 6,230.6 45.50 BR BakerGBH-22 17/16/1996 3.000 10,321 6,266.4 43.82 S HOE MULE SHOE - has 4.4' ~D, causig 6p at tlie top of ISH 17l16f1996 4.40D 10,780 6.606.8 41.36 FI SN Set 2 1/8" Baka IBP in 5: iner: rated 3600 psF, fdrrg nedc 1.375" OD; 5500p release pu~ - moved to 10780 CTMD 6/21/08 4I20I2008 U.D00 Pertora tlons & Slots Top itl(B) BM (flKB ToP (N~) ) (11KB) BOm (1VD) (1U(B) zp~p DaOO sn« Danr (~- 7 pe commant 10,660 10,67 0 6,516.8 6,524.3 C ~, 1C-11 6/19/2008 6.0 RPERF 2.5' HSD w/2506 HJ, 60 Deg Phase, est .43" hole diameter iQ670 10,7 6 6,524.3 6,SSSJ C -4, C-3, 1C-11 1/14/1997 2.0 I PERF Zem deg. Phasing; 21/8" Enerjet 9qmu1 ns 3 Tre~dne~Ks Yin Top DepM (MC61 Mai Blm DaP~ (RKB) Top DapW RVO) MKB) 6onom ~oP~ (Tw) (111[B) ypo afe ammcnt 10,660.0 10,716. 0 6.516 8 6,558. F RAC 6202008 C-SAND Hy6auGc FRAC; 140,530# 16/20 CarboFe behind pipe; 9J% design; 10ppa into forma5on. Notes: General 8 Saf ~a oam aMwno~ 4/3/2008 N OTE: SWS LDL INDICA7ES IBP ~ 10.355 LEAKING FROM BELOW 572&Z008 N OTE: HOIE IN T CASING ~l 546G MD 6!8/20~8 N OTE: NEW 3.5' TBG INSERTED INTO 3.5" SCAB UNER @ 10277 6/162008 N OTE: VIEW SC EMA C wl AlasYa Schematic9.0 11/SI2008 N OTE Reoovered sevesely aotled OV fe1511 T, GLM 6kdy damaged Mgndrel Detalls gm Top (~) TopOepth (TVD) ~B) Top Incl l') Mako Modal pp (in) g¢rv VaM TYPa LnM TYPe Port Siu (~) 7R0 Run (psq Run Daro Comm._ 1 3,193.9 .472.8 58.84 Cameo BMG 1 Gas Lifl V BK-5 0.156 1,263.0 ZI74/2009 2 4,217.4 2,9932 59.14 Camm KBMG 1 Gas Lift OV BKS 0250 0.0 2/14/2009 3 5,117.5 3,471.5 57.31 Camto KBMG 1 Gas Lifl DMY BK5 0.000 0.0 2l13I2009 EXT PKG • Ta: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fay [907 245-8952 1) Caliper Report 14Aprv09 1 A-11 Caliper Report 19-Apr09 1 G11 ~~ 1 Report / EDE 50-029-20685-00 1 Report / EDE 50-029-2271 ,, ~~ Signed Print Name: Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W, INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907!245-88952 E-MAIL : _ _ -_ = _ _ __ WEBSITE D~\00_PDSANC-2009\Temporary\ZT• 10\CD_Parts\Transmit_Conoco.docx .~ • Memory Multi-finger Caliper L.,og Results Summary Company: ConocoPhillips Alaska, Inc. Well: __ 1 C-11 Log Date: April 19, 2009 Field: Kuparuk Log No.: 7321 State: Alaska Run No.: 5 (4th Caliper) API No.: 50-029-2271400 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD ABMOD Top Log Intuit.: Surface Pipet Use: Tubing & Scab Liner Bot. Log Intuit.: 10,265 Ft. (MD) Pipet Desc.: 5" 18 fb. L-80 Top Log Intuit.: 10,265 Ft. (MD) Pipet Use: Liner Bot. Log Intuit.: 10,894 Ft. (MD) Inspection Type : Restriction +& Corrosive 8 Mechanical Damage Inspection COMMENTS ; This caliper data is tied into fhe D Nipple ~ 70,189' (Driller's Depth). This log was run to assess the cond~ion of the 5" liner with respect to LD. restrictions and corrosive and mechanical damage, particularly around the proposed whipstock placement (10,747'). Although not presenting a significant LD. restriction, the caliper recordings indicate slight oval deformations in the 5" liner, restricting the LD. to 3.96" in the perforation interval in joint 10 (10,666'). Across-sectional picture of the most severe deformation and a log plot of the caliper recordings across the proposed whipstock placement highlighting these deformations are included in this report. The caliper recordings indicate the liner logged is in good condition with respect to corrosive damage, with no significant wall penetrations or areas of cross- sectionalwall loss recorded. The caliper recordings indicate the 3.5" tubing and scab liner are in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross-sectional Walt loss, or I.D. restrictions recorded- This is the fifth time a PDS caliper has been run in this well and the second time the current 3.5" tubing, 3.5" scab liner, and 5" liner have been logged. A comparison between the current and previous log (November 6, 2008) indicates an increase in corrosive damage in the 3.5" tubing and scab finer during the time between logs. A graph illustrating the difference in maximum recorded penetra#ions on a joint by joint basis between (ogs is included in this report. ' A comparison between the current and previous log (November 6, 2008) indicates little, if any increase in corrosive damage in the 5" liner during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. 5" LINER -MAXIMUM RECORDED WALL PENETRATIONS: ' No significant wall penetrations (> 15%) are recorded throughout the liner logged. 5" LINER -MAXIMUM RECORDED CROSS~ECTIONAL METAL LOSS : ~,' No significant areas of cross-sectional wall loss (> 2%) are recorded throughout the liner logged. 5" LINER -MAXIMUM RECORDED ID RESTRICTIONS ' No significant I.D. restrictions are recorded throughout the liner logged. a ;~ ~~~~ ~~~ Ar ~ ~~~ ~ ProActive Diagnostic Services, Inc. (P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 ~~ 19(~ - l'~~ l~9dl ~ • ' 3.5" TUBING 8~ SCAB LINER -MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 16%) are recorded. 3.5" TUBING 8~ SCAB LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No significant areas of cross-sectional waN loss (> 8°r6) are recorded. 3.5" TUBING & SCAB LINER -MAXIMUM RECORDED ID RESTRICTIONS No significant i.D. restrictions are recorded. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: S. Ferguson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax: (281} 565-1369 E-mail: PDS~czmemoryiog.com Prudhoe Bay Field Office Phone: {907) 659-2307 Fax: {907) 659-2314 PDS Multifinger Caliper 3D Log Plot ~~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1C-11 Date : April 19, 2009 Description : Detail of Caliper Recordings Across Proposed Whipstock Placement (10,747 in 5" Liner Depth Max ID (1!1000 In.) (Off-Center) Image Map (Centered) Image Map 1ft.300ft 3800 4800 0' 90° 180° 270° 0° 0° 90° 180° 270° 0• Min ID (1/1000 in.) 3800 4800 Nominal ID (1/1000 in.) 3800 4800 woniv~c~a~ unaae maN 0' 0° 90° 180° 270° 0° • s Correlation of Recorded Damage to Borehole Pro>~ile Pipe 1 3.5 in (-6.1' -10265.3') Well: 1 C-11 Pipe 2 5. in (10265.3' -10868.6') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 19, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profile 1 -2 1552 GLM 1 3143 GLM 2 4755 ~ GLM 3 ~ Y ~.~. _~ s Y 6417 p 8005 9592 10313 15 10869 0 50 1 00 Da mage Pr ofile {% wall) /Tool D eviatio n (degr ees) Bottom of Survey = 15 50 150 v .. I_ Y Z ~0 200 250 300 1 • • Maximum Recorded Penetration -- Comparison To Previous Well: 1 C-11 Survey Date: April 19, 2009 Field: Kuparuk Prev. Date: November 6, 2008 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 Ext No. 211390 Country: USA Tubing: 5" 181b L-80 Overlay Max. Rec. Pea (mks) 0 100 200 300 0.1 i E 0 z 1= 'S i 7 ^April 19, 2009 ^November 6, 2008 n,s~~.,,.,~~ • PDS Report Overview ~ ~~ Body Region Analysis Well: 1 C-11 Survey Date: April 19, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper ten. Lower ten. 5 ins 18 f L-80 4.151 ins 5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body x~ metal loss body 20 10 0 0 to 1 to 10 ro 20 ro 40 to over 1% 10% 20% 4t)% 85% 8$% Number of ~oints anal se d total = 15 pene. 0 11 2 0 1 1 loss 7 5 3 0 0 0 Damage Configuration (body ) 10 - 0 isolated general line ring hole /pons pitting corrosion corrosion consion ible hole Number of ~oints dams ed total = 1 1 0 0 0 0 Damage Profile (°A° wall) ~ penetration body ;,~~, metal loss body 0 50 100 0 10 Bottom of Survey ~ 15 Analysis Overview page 2 PDS REPORT JOINT TABI. Pipe: 5. in 18.0 ppf L-80 Well: Body Wall: 0.425 in Field: Upset Wall: 0.425 in Company: Nominal I.D.: 4.151 in Country: Survey Date: • ELATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc USA April 19, 2009 Joint No. Jt. Depth (Ft.) I'c~n. UI~s~~t (Ins.) Pen. Body (Ins.) {'en. % ~t~~i.il I css ",~~ Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 1 0265 U 0 l) U 3 00 er GBH-2 PB To of in r .2 10311 O 0 0 U 4.40 e Sh 1 10313 O 0.0 5 2 4. 8 2 10358 t) 0.01 ~' 1 4.08 3 104 2 t ~ 0.02 5 4.06 4 1 44 t? 0.01 ~ I 4.0 5 0 88 t) 0.01 ' I 4.08 6 10 31 U 0.01 2 1 4.0 Marker oin 7 10 53 U 0 2 I 4.10 Mar er oint 8 10578 a 0.01 3 ._' 4.04 1 617 O 0.23 .54 I ~ 4.04 P r orati n . Sli ht b cklin Lt. De osi 1 10661 l)..'S 0.45 1(ri) Ifl 3.9~ P rfora'o s. Sli ht ovaldef rm tion. Lt. 11 10703 t ~ 0.07 17 I ~' 4.04 Perforations. Lt. De si 1 744 U 0. 6 15 ~' 4. Isoalt d it 13 0785 U 0.03 t3 2 4 06 14 108 6 U 0.01 2 I 4.09 1 1869 U 0. 2 5 1 4. 8 _ Penetration Body Metal Loss Body Page 1 ~ PDS Report Cross Sections Well: 1C-11 Survey Date: April 19, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext No. 211390 Company: ConocoPhi-lips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: l4 Tubin 5 ins 18 f L-80 Anal st: C. Waldro Cross Section for Joint 10 at depth 10666.47 ft Tool speed = 44 Nominal fD = 4.151 Nominal OD = 5.000 Remaining wall area = 88 Tool deviation = 41 ° Finger 16 Projection =-0.171 ins Deposit in Slight Oval Deformation Minimum I.D. = 3.96 ins HIGH SIDE = UP • Cross Sections page 1 • • J ~ Maximum Recorded Penetration Comparison To Previous Well: 1C-11 Survey Date: April 19, 2009 Field: Kuparuk Prev. Date: November 6, 2008 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 Fxt. No. 211390 Country: USA Tubing: 3.5" 9.31b L-80 Overlay Max. Rec. Pen. (mils) -46 54 154 254 9 19~ 29 39 49 59 69 76 86 96 103 113 123 32.1 140 ~° 150 E 3 160 Z 61.6 0 169 179 189 199 209 219 229 239 249 259 - 269 279 289 299 309 _ 16.3 11 April 19, 2009 ~ November 6, 2008 f~iffPranrn • • PDS Report Overview ~ S~ Body Region Analysis Well: 1 C-11 Survey Date: April 19, 2009 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 AnalysL•__ _ _________ C. Waldrop _____ Tubing: Nom.OD Weight Grade & Thread Norn.ID Nom. Upset Upper len. Lower lert. 3.5 ins 9.3 f L-80 2.992 ins 3.756 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 20 ro 40 to over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 335 pene. 0 126 209 0 0 0 loss 86 249 0 0 0 0 Damage Configuration (body ) 10 0 isolated gene2l line ring hole /you pitting corrosion corrosion corrosion ible hole Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (°~ wall) ~ penetration body metal loss body 0 50 100 M GLM 1 GLM 2 GLM 3 t3ottom of Survey = 319.3 Analysis Overview page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc USA April 19, 2009 Joint No. Jt. Depth (Ft.) I'c~n. l ll>u~t (Irn.1 Pen. Body (Ins.) Pen. % ~Icl,il I oss , ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -6 rl 0.02 ~) I 2.92 PUP 1 -2 tl 0.0 9 5 2.96 1.1 3 (1 0.03 12 2.93 PUP 2 41 (I 0.03 1 ~ b 2.95 73 t I 0.02 7 2.95 4 1 4 t l .0 1 1 ~ .94 5 136 t) 0.04 14 ~ .95 6 167 (I 0.0 11 ; 2.96 7 19 U 0.01 0 .9 8 31 l) .03 1 I 2.96 9 6 U 0.0 ~) .95 10 93 U 0, 9 -~ .96 1 325 r I 0. 3 1O 2.95 1 356 (I 0.0 1U 2 2. 6 1 3 8 U 0.03 11 ; 2.96 14 419 U 0.03 11 2.96 5 450 U 0. 2 - ~ 2.96 16 48 U 0. 1 4 .95 17 513 (1 0.02 7 .95 1 545 t ~ 0. 7 , .95 19 57 t1 .0 6 I 9 ZO 608 ~ ? 0.02 7 I 2.96 640 t I 0.04 I ~ 2.96 22 671 r ~ 0.01 r; I 2.95 703 r ~ 1 6 ' .9 24 734 U 0.01 6 I 2.95 2 766 I ~ 02 7 2.94 26 797 (1 0.02 9 2.95 27 828 [) 0.0 14 ~ 2.94 28 860 (I 0.01 6 ~ 2.95 29 8 1 a 0.0 7 I .96 30 92 3 (I 0.03 11 1 2.94 31 954 t) 0.0 7 2.9 3Z 986 t) 0.02 ~) _' 2.94 33 1017 (I 0.0 1_~ 93 34 1049 t ~ 0.02 ~> I 2.96 35 1 0 u 0. 4 16 ' .96 36 1111 U 0.02 ~) .94 7 1143 U 0.02 9 -t .93 38 1175 (t 0.01 (~ _' .95 39 1206 U 0.03 11 .96 40 1237 a 0.03 1 I 2.95 4 1 69 t? 0 ~) I 2. 6 42 1300 i I 0.04 14 -1 2.95 43 1332 ~ 1 0.04 I -1 .96 44 1363 a 0.03 11 t 2.93 45 1394 U 0.0 ~~ I 2.96 1426 II 0.02 q I 2.95 47 14 r ~ .0 1 G t~ 2.95 48 1489 t ~ 0.03 13 2.96 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • -LATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc. USA April 19, 2009 Joint No. Jt. Depth (Ft) I'r~n. Ul~sc~i Ilrn.) Pen. Body (Ins.) Pen. %> ~1c~t~rl I oss `%, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1520 ~) 0.0 9 Z 2. 5 5 155 U .03 12 t 6 51 1 83 t) 0.02 9 ~ 2.95 52 1 15 ~) .01 (~ I 2.95 53 1646 t ~ .0 11 ~ 2.96 54 167 U 0. 9 ~ .95 55 1709 U 0.04 14 2.94 56 1740 U 0.03 1(1 I 2.95 57 1772 U 0.02 ~) -F 2.95 58 1803 U 0.03 13 5 .95 59 1835 0 0.04 I4 1 .96 60 1866 U 1 v 1 2.96 61 1 98 ~ ~ 0 1 U .96 6 1929 rr 0.02 9 -t 2.96 63 1961 U 0.03 13 2.96 64 199 a 0.03 11 .95 65 024 (~ 0.04 16 -1 Z.96 66 0 5 ) ~ 0.03 1 _t .95 67 2087 U .04 16 Z 2.97 68 1 8 ~) 0.0 1:~ 1 2.96 69 49 t ~ 0.02 7 ~' 2. 70 2181 ~) 0.03 1 1 ~' 2.94 71 2213 ! ~ 0.01 6 _' 2.94 72 2244 O 0.02 ~ 2.93 7 1 2 75 U 2 u 96 P P 72.2 2283 U 0 t) r~ N A TRMAXX W 2.813" Profile SSSV 72.3 2288 O 0.01 4 u 2.95 PUP 73 2296 a 0.02 9 2.94 74 23 7 U 0.0 14 1 2.93 75 2358 ci 0.03 12 I 2.95 7 2389 U 0.03 13 5 2.96 77 2421 U 0.03 11 I 2.94 7 24 t) .03 11 I 2.96 79 2484 U 0.02 ~) -F 2.93 Lt. De osits. 80 2515 c) 0.03 1 i 2.96 81 2546 a 0.01 E> 2.96 2 78 O 0.0 ~~ ~ .9 83 2609 l) 0.01 6 1 2.96 84 63 ~) 0.03 1 1 2.9 85 2671 a 0.02 7 s 2.96 8 70 a 0.0 7 4 .95 87 2734 a 0.03 11 1 2.94 88 765 U 0.02 ~) I 2.94 89 2797 (~ 0.02 ~ I 2.96 90 82 8 ~ ~ 0 03 13 2.93 91 2860 ~) 0.03 I ~ I 2.93 9 2 91 a 0.03 I S I 2.95 93 2923 ~~ 0.03 1 ? Z 2.96 4 54 ~ ~ 0. 12 I .95 95 2986 !) 0.02 7 2.95 __ Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 C-1 1 Kuparuk ConocoPhillips Alaska, Inc. USA April 19, 2009 Joint No. Jt. Depth (FtJ P~~n. l )I,tic~I (In,.) Pen. Body (Ins.) Pc~n. %> ~Ic~l~il Loss ~. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 016 U 3 1 U ._' 2.95 9 3048 I ~ 0.04 14 I 2 98 3080 I ~ 0 03 12 1 2.96 9 3112 t) 0.03 13 4 2.94 100 3143 i) 0.04 14 ~' 2.94 100.1 3175 t l 0.0 I 2.96 P P 100.2 3182 ct U t) N A GLM 1 atch ®12:30 10 .3 3189 t) 0.02 8 I 2.96 UP 01 3197 t) 0.02 9 _' 2.95 102 3229 I) 0.0 7 I .93 103 3259 0 0.0 13 1 6 104 3290 a .03 13 4 .95 105 3322 tl 0.04 15 1 2.9 106 33 4 u 0.0 ~ .97 107 3384 U 0.04 14 .' 2.96 08 34 5 O 0.0 1 a 2 .96 109 3 7 U 0.04 14 3 2.95 11 479 t) .0 7 4 2.9 11 510 1) 0.03 1 " 4 .95 112 3541 t~ 0. 11 ~ 2. 6 113 3573 a 0.03 13 ? 95 114 360 a 0.03 1:3 1 .95 115 3 33 U 0. 3 13 ~' 2.94 116 3665 t) 0.02 ~~ I 2.96 1 3696 U 3 I n I .9 118 3727 t) 0.02 ~ I 2.95 119 3759 t1 0.0 9 -l 2.96 120 3790 t) 0.03 12 ; 2.97 1 1 3821 u 9 5 94 122 3853 a 0.03 11 ' 2.95 12 38 5 U 0 0 ~~ I 2.94 124 3916 II 0.03 11 ~ 2.95 125 3 48 a .O1 6 I 2.95 126 3979 U 0.03 13 ? 2.94 Lt. D osits. 127 4011 U 0. 4 14 ' .95 128 4042 t) 0.03 13 1 2.96 129 4073 l) 13 4 6 130 4105 U 0.01 4 1 2.94 131 136 I I 0.03 t t) 1 .95 132 4168 U 0.04 16 b 2.92 132.1 4199 a 0.02 ~) I .9 PUP 132.2 4206 t) 0 O U N A GLM 2 Latch ®6:30 132.3 4 14 II O.D t3 I 2.93 PUP 133 4222 tl 0.03 1 1 ~ 2.95 Lt. De osits. 134 4 54 )) .02 ~) 4 .95 135 4285 tl 0.0 i 4 2.94 136 43 7 U 0.02 9 2.95 137 4348 a 0.02 9 1 2.96 1 8 4380 U .O1 6 1 .95 139 4411 U .03 13 ? 2.96 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 C-11 Kuparuk ConocoF'hitlips Alaska, Inc. USA April 19, 2009 Joint No. Jt. Depth (Ft.) Nc~n. Ulric°t (Ins.) Pen. Body (Ins.) PE~n. °i~> ~tcial I oss °4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 4443 0 0.03 13 1 2.96 141 4474 l) 0.04 16 i 2.95 142 4 05 U 0. 14 4 143 53 a 0.03 II I .95 144 4567 ~) 0.04 14 2.96 14 4599 U 0. 11 Z 96 146 46 0 t) .03 1 3 4 2. 5 147 4661 U 0.03 12 -i 2.94 148 4 2 U 0.02 7 ~ 2.95 149 472 4 U 0.04 14 2.94 150 475 U 0.04 14 5 .96 151 4787 !J 0. I ' ~ ~ 2 96 1 2 48 8 u 0.03 1 3 2.95 1 3 4850 i ~ 0.02 ~~ 6 154 4881 ~~ 0. 9 2. 155 491 U 0.0 1 3 3 sits. 156 4945 a 0.03 1 a I 2,95 157 4975 U 0.0 I5 5 .93 58 5007 U 0.0 ~? i~ L e i 59 503 i) 0.04 I V ~ 2.96 160 070 U 0.02 ~> 2. 16 .1 510 t) 0.01 E, I .91 PUP 160.2 5110 i~ 0 U U N A GLM 3 L tc ~ 7:30 160.3 5117 t~ 0.02 9 I 2.94 PUP r) 4 14 161.1 5157 U 0.02 ~ I 2.91 PUP 161.2 5162 U i) a 2.99 Locator W 1.04' S ce Out 161.3 5165 0 0 t) U 2.99 Seal Assemb 16 .4 5 6 u 0 i) ~) 4. 0 80 Sal Bor Extention 161.5 5190 t ? 0 t ~ i ~ 2.99 X-Over Bushin 16 .6 192 ~) 0. 1 ~i ~ 9 PUP 161.7 5194 U 0 l) (> 2.99 FHL Retrievable Packer 161.$ 202 U 0.03 1O I 2 90 PUP 162 5206 (1 0.02 9 1 2.96 163 5238 O 0.04 14 i .9 164 5271 U 0.04 I6 I 2.95 165 5302 ~) 0.04 15 i~ .95 166 5334 U 0.03 10 t, 2.95 167 5365 U 0.0 11 .9 168 5396 O 0.02 ~~ I 2.91 169 54 8 0 0.03 I U I .9 170 5459 U 0.01 4 1 2.93 171 5492 u 0 03 1 l) I 2.96 172 5524 t> 0.03 11 1 2.93 173 5555 i) 0. 4 14 S 94 174 5587 U 0.03 t 1 1 2.93 175 5619 i ~ 0.03 I I ' ~ 2.95 176 5651 ~ ? 0.03 1 1 I 2.92 177 5683 0.03 1 U .96 178 5715 0.04 1 t, I 2.95 Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 C-1 1 Kuparuk ConocoPhillips Alaska, Inc. USA April 19, 2009 Joint No. Jt. Depth (Ft.) I'~~n. Ulxc~t (Ins.) Pen. Body (Ins.) Pcvi. °~~> ~tet,~l I ~>ss ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 179 5747 U 0. 3 11 I 2.92 1 5779 U 0.02 t~ 5 2.95 t. si 1 1 5 11 t ~ 0.03 13 ~' .9 182 584 tt 3 1 , ~ 2.96 183 5874 t 1 0.04 14 b 2.96 184 5 06 ~ I .03 1 5 .9 185 5937 a 0.0 13 .93 186 596 t I 0.02 9 (~ 2.95 1 6001 U .0 ~) 5 2.9 t. o f 88 6033 U 0 1 _ 1 2.94 1 9 6065 l~ 0. 3 1 3 2 2.9 e i 190 6097 U 0.04 14 (; 2.95 e sits 191 6129 t~ 0.03 13 5 4 192 6 61 t~ 0.0 1 "~ ~ 9S 93 6193 U 1:~ .92 194 6225 U 0 13 t~ .94 195 6257 U 0. ~) 2.92 96 62 9 l~ 0.03 1 1 I 5 197 6321 O 0 0 1 3 5 .95 1 635 tJ 0. 3 IZ .9 0 199 85 U 0.04 t b .96 200 6417 t~ 0.0 I ~ 2.94 201 6449 t~ 0.03 I:~ I 2.94 202 6481 U 0.03 11 1 2.93 6 1 U 4 15 ~ .95 04 6544 a 0.03 I t I 2.94 20 6577 U 0.0 14 5 2.9 206 6608 (1 0.04 16 1 2.96 20 6640 l l 0.04 1 G ~' 2.95 208 6672 n 0.04 15 I 2.95 0 6704 U 0.03 l U > .9 210 6736 t ~ 0.03 t U I 2.95 11 768 t I .03 I Z 2.9 12 6799 U 0.02 ~~ t> 2.95 Lt. De o its. 2 3 683 O 0.04 1.3 I 2.95 214 6864 c I 0.04 L5 > 2.96 5 6 9 a 0.0 9 6 216 6928 (I 0.03 ltl 1 2.94 17 69 0 t? 0.02 ~~ ~~ .95 218 6992 t) 0.04 14 5 2.94 Lt. De osits. 19 70 4 t ~ 0. 3 12 6 .94 220 7056 a 0.03 I a a 2.95 221 70 7 U 0.03 I I 5 .94 222 7119 t~ 0.02 9 (~ 2.97 3 7152 U 0.0 tI ~ 2. 6 224 7182 t ~ 0.04 1 ~ > 2.95 2 5 7214 (~ 0.0 10 I 2.92 226 7245 n 0.04 15 6 2.94 7 7277 ~~ 0.03 11 I .95 228 7309 ~ ? 0.04 15 i 2.96 _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.382 in Company: Nominal I.D.: 2.992 in Country: Survey Date: iLATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc USA April 19, 2009 Joint No. Jt. Depth (Ft.) Nc~n. Ul~~c~t (Ins.) Pen. Body (Ins.) I'c~n. ",4, ~~t~~l,~l I ~,~5 ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 29 34 (~ 0 0 1 1 2. 1 230 7 72 U 0.03 10 ~ .96 23 7404 U .03 13 ti 2.9 3 7436 t~ 0.04 1 ~ 2 96 33 7468 U .04 1 ~ f> .95 4 7500 (? 0.02 ~~ 9 23 753 U 0.03 11 i 2.93 236 7564 U 0.04 1.5 1 .95 237 7 96 t) 0. I Z 5 2.96 8 7627 U 0.0 13 5 6 39 7659 a 0.03 13 ~ .9 t i 40 76 1 ~) 0.02 ~~ -1 .9 241 7722 a 0.03 13 42 7753 t) 0.0 i i .95 43 7785 U 0.04 1~ i 2.9 244 7817 a 0.03 13 5 2.94 24 7848 U 0.0 11 2.95 46 7 79 It 0.03 1O 5 .95 247 7911 O 0.0 1 1 -1 .94 48 7942 (~ 0. 3 1 1 -1 2.94 249 7974 U .03 13 -1 2.96 2 0 8005 U 0.04 15 i 5 251 8037 tl 0.02 7 4 .95 252 8068 0 0.02 7 i 2.94 25 810 O 0.0 12 4 6 254 8132 (1 0.02 i 2.94 255 8163 a 0.03 13 5 2.94 256 8195 O 0.03 11 -~ 2.96 2 7 8227 (? .03 I I ~' 2.94 258 8258 O 0.04 14 ~ .94 59 89 a 0.03 13 -1 94 260 8321 n 0.02 ~) a 2.95 61 835 U 0.04 ! 5 ~ 2.94 262 8383 O 0.03 I3 -1 2.94 3 8415 (t 0.02 7 4 .94 264 $4116 U 0.02 9 (~ 2.96 65 8478 O 0.0 10 ' 266 8509 O 0.03 I 1 5 2.96 267 8540 O 0.03 13 (~ 2.94 268 8572 O 0.03 13 5 2.96 t. D osits. 69 8605 (~ 0.0 13 (~ 2.91 270 8637 a 0.03 11 ~, 2.93 271 86 8 l~ 0.03 1 I i 2.94 272 8700 U 0.04 14 b 2.95 Lt. De o 'ts. 27 8732 t1 0.04 15 5 2.93 274 8764 t) 0.03 1 ~ (~ 2.96 275 8796 l) 0.04 1 ~ (~ 2.9 276 8828 O 0.03 11 5 2.94 77 886 U .0 1 ~ 2. 4 278 8892 (~ 0.03 11 ~ 2.91 _ Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 19, 2009 Joint No. Jt. Depth (Ft) Pen. Ulxc~t (Inti.j Pen. Body (Ins.) Pen. % Metal Ions `;i, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 79 8924 ~) 0.04 1.5 > 2.95 895 (~ 0.04 14 2.93 281 8988 U .04 1 ~ 5 .93 82 9020 U 0.03 11 1 2.9 283 9052 U 0.03 12 ~ .95 284 908 U 0.03 13 i .92 285 9116 U 0.04 14 (~ 2.96 286 9147 U 0.0 11 ~ 2.95 87 9179 O 0.04 16 5 2.95 288 9211 O 0.04 15 5 2.95 289 9243 U 0.03 13 (~ 2.94 290 9274 U .04 1~ 5 .9 291 9306 U 0.04 15 (> 2.92 292 9338 t) 0.0 1 i i~ .94 2 9370 U 0.03 13 (~ 2 92 294 9 2 U 0.04 1 E, ~ 2.94 Lt. De sits. 295 9433 U 0.03 13 5 2.95 296 946 t) 0.01 6 t~ 2.95 297 9498 U 0. 4 15 ~ .93 t. e sits 2 8 9529 U 0. 4 14 5 .94 299 9561 O 0 1 U > 2.9 300 9592 O 0.02 9 -~ 2.91 01 9622 (1 0.02 9 2.92 302 9654 U 0.04 14 (, 2.95 03 687 a 0.03 13 (~ 2. 304 9719 l1 0.03 l3 2.95 305 9750 l) 0.03 1 ~ (, 2.96 306 9782 U 0.04 14 (, 2.95 07 9814 U 0.03 13 5 2. 4 308 9845 (1 0.03 13 5 2.93 3 9 987 a 0.0 1 ~ ~ .93 310 9910 a 0.03 13 I 2.94 3 1 994 U .03 13 (, 2.95 312 9973 n 0.03 13 ~~ 2.94 313 100 5 u 0.03 1 I '~ .92 Lt. osits. 314 10037 U 0.03 1 1 2.90 Lt De osits. 315 10069 a 0. 3 13 -1 .90 316 10101 U 0.03 12 -1 2.92 316. 101 2 U 0.02 7 I .94 P 316.2 10141 O 0 0 U 2.87 Baker Pre ier Production Packer 316.3 1 148 U .02 9 1 .9 PUP 317 10158 O 0.03 13 2.95 317.1 10189 U 0 0 O .7 2.75" D-Ni I 318 10191 O 0.01 -1 I 2.95 319 10 2 U 0. 4 1-1 ~ 2.95 319.1 10253 0 0.01 6 I 2.94 PUP 319. 10 8 U 0 U U 3.00 FI ted No Go Ni le 319.3 10260 U 0 0 O 4.40 Mule Shoe Penetration Body Metal Loss Body Page 7 ConocoPhillips niask~,. o w: 1C-11 (PTD 1961720) Report of failed TIFL Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, January 15, 2009 10:47 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 C-11 (PTD 1961720) Report of failed TIFL Attachments: 1 C-11 schematic.pdf; 1 C-11 90 day TIO plot.gif Tom and Jim, ~~~, 'f ~~ Page 1 of 1 Kuparuk gas lifted producer 1 C-11 (PTD 1961720) failed a diagnostic TIFL on 01/13/09 and has been added to the weekly SCP report. The TIO prior to SI for the test was leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible. Attached is a schematic and 90 day TIO plot. «1 C-11 schematic.pdf» «1 C-11 90 day TIO plot.gif» 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 y ~ _ ~~p ~ ra ~~t~ as+.rJ~L.~~~dl ~..`f-'lit V Lv1is 1 /15/2009 KRU 1C-11 PTD 196-172 1 / 15/2009 TIO Pressures `~- ~C7(1(?CQI`i 11~~~~?S ~ / ~ KUP Well Attributes ~ `Max Angle 8 MD 1C-11 TD ru ~ ~ ~ / Wellbore API/UWI Fleltl Name Wall _ _ _ Stat Prodllnj Type Intl (-I MO (ftKB) _- _ Act Btm IftK6) . ... 500292271400 KUPARUK RIVER UNIT PR OD 60.8 1 4,079.00 11,300.0 ___ __ Comment H2S (ppm) Dale Annotation End Date KB-Grtl (N) Rig Release Date -. - SSSV: TRDP 60 7/1/2008 Last WO: 6/8/2008 47.01 1/14/1997 1eT~ ~ a.3p.~ <,t __ _ __ A notation Depth (ftKB) End Date Annotation End Date Last Tag: SLM 10,705.0 11122/2008 - _ Rev Reason: GLV C/O, PULL PLUG 12/9/2008 Casing String s _ Caamg Desenphon String 0. .. String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER, 37 - CONDUCTOR 16 15.060 0.0 121.0 121.0 62.50 H-40 Casing Description String 0. .. String ID ... Top (flK8) Set Depth (f... Set Depth (TVD)... String Wt... String... String Top Thrd SURFACE 9 5/8 8.525 0.0 6,943.0 4,439.0 40.00 L-80 ' ,. Casing Description String 0. .. String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 0.0 10,427.0 6,344.0 26.00 L-80 ~; Casing Deacription String 0. .. String ID ... Top (ftKB) Set Dep[h (f... Set Depth (ND) ... Shing Wt... String ... String Top Thrtl 1 LINER 5 4.151 10,271.0 11,300.0 7,010.7 18.00 L-80 I - Casing Description String 0. .. String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrtl CDNDUCTDR, 9-1z1 35"SCAB LINER 31/2 2992 51633 1(17710 fi.2R0fi 930 I_-Rn Fl1FRrdABMOD Liner Details lop Oepl h ~ (TVD) Top Intl SAFETY VLV, 2.297 r ~k:~ l Top (ftKB) _ .__ _ (flK8) _ .__ _ (°) I __ __ tem Description _. __. _ _ _ _ _ Comment _. ID (in) GAS LIFT, 3,194 GAS LIFT GAS LIFT 5,11. SEAL, s,nz $ ~ I r / x _1 , `-_.7 E m - t~ Y- 110,262.01 6,224.31 45.801 NIPPLE (Fluted No/Go 1 3.00( ~ Tubin Strin s _ _ Tubing Des Plion 51 gC _,.r , G T,~I~ ~C, ~n'.C I ~.~ID pth (TVD). 9W1... 'li I ~i- r~ Thrd TUBING 4 5 3.5" d 1/`[ ~ . 3 5122 30 i ~ Cl ;, BMOD ~CompletlonDetails _ _ ley Uapth (ND) Top Intl Top (NKB) (ftKB) (°) Kam Daaerlptbn Comment ID (in) 36.7 36.7 -0.72 HANGER Tubing Hanger 6"x3.5" "ISA" BPVG 2.99e 2,297.4 1,994.4 55.61 SAFETY VLV TRMAXX w/2.873" X-PROFILE -REQUIRED 3500 psi ABOVE TBG 2.812 PRESSURE TO OPEN 5,170.2 3,499.9 57.34 LOCATOR Locetor w/1.04'space out 2.992 Otherln Hole (1rYireline retrievable plugs, valves, pumps, fish, etc. Ley U«pth (TVD) ToP Intl Top (ftKB) (kK6) (°) Desuiptlon Comment Run Date ID (in) 10,266.0 6,227.1 45.67 FISH 80-40 SEAL ASSEMBLY, OAL 46.55'-seal parted where it 5/2512008 3.000 was plugged into 5" liner (see attached drawing) 10,271.0 6,230.6 45.50 PBR Baker GBH-22 11/1611996 3.000 10,321.0 6,266.4 43.82 SHOE MULE SHOE -has 4.4" ID, causing lip at the top of FISH 11/16/1996 4.400 10,780.0 6,606.8 41.36 FISH Set 2 1/8" Baker IBP in 5: liner; rated 3600 psi; fishing neck 4/2012008 0.000 1.375" OD; 5500# release pull -moved to 10780 CTMD 621/08 ,Perfora tions snot rap (rvD) Btm (rvD) Dana .43" hole diameter SURFACE. 0-6,943 3.5' SCAB LINER, 5,163-10,271 FISH, 10,266 ~, . ~f ~ RPERF, 10,660-10,670 FRAC. 10,660 ~ IPERF, ~ _ 10,6]0-10,]16 FISH, 10,760 ^) LINER, 1o,z71-11.300 TD, 11,300 Stimulations 8 Treatments BOROm MIn Top Max Btm Top Depth Depth Depth Depth (ND) (ND) (ftKB) (ftKB) (ftKB) (ftKB) Typs Date Comment 10,660.0 10,716.0 6,516.8 6,558.7 FRAC 620/2008 C-SAND Hydraulic FRAC; 140,830# 1620 Carbolite behind pipe: 93% design; tOppa into tormation. Notes: General & Safety 4/32008 NOTE: SWS LDL INDICATES IBP @ 10,385 LEAKING FROM BELOW '.. 5262008 NOTE: HOLE IN 7" CASING @5466' MD I 6/8/2008 NOTE: NEW 3.5" TBG INSERTED INTO 3.5" SCAB LINER @ 10272' 61162008 NOTE: VIEW SCHEMATIC w/ Alaska Schematic9.0 Mandrel D - - etails - __ __ Stn Top (ftKB) --- 'Top Depth (ND) tkK6) Top Inel (°) Maka Model OD tin) Sarv Valve Type Latex Type Port Siza lint TRO Run (psi) T Run Dale Comm... 1 3,193.9 2,472.8 58.84 Camco KBMG 1 Gas Lih GLV BK-5 0.156 1,263.0 11/6/2008 2 4.217.4 2,993.2 59.14 Camco KBMG 1 Gas Lik DMY BK-5 0 0.0 6/82008 3 5,117.5 3,471.5 57.31 Camco KBMG 1 Gas Lift OV BK-5 1/4 0.0 12/6/2008 12/30/08 -~ ^.__ ~il~~l#l~~~i~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~) I ~ `4~ t~F~i~.t ~f f ~f ~. S.:Ut urrc,. F. t - NO.5024 Company: Alaska'-Oil' & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~1 I. J I ~,.. G~ ~.,,.~ Log Description Date BL Color CD 2U-03 12080460 INJECTION PROFILE "~' Cy 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE `~ - 12/07/08 1 1 1C-11 12114998 PRODUCTION PROFILE a 12/14/08 1 1 1 D-07 12114999 USIT a 12/15/08 1 1 1 B-09 12115001 INJECTION PROFILE ~ L ~ 12/18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP I 12/19/08 1 1 1C-18 12100472 INJECTION PROFILE ~ 12/21/08 1 1 1 E-21 12115005 p INJECTION PROFILE 12/22!08 1 1 2C-02 12100475 INJECTION PROFILE V ~ 3 12!24/08 1 1 C~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317, Thank you. ~V~~ ~- .: _ T14.4/~S/TEAL ProActive Diagnostic Services, Inc. • • To: AOC~C Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659-5102 E; ~~W~~~ ~;~ ~ ~. RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following f~oActive Diagnostic Services, Inc. Attn: Robert A. Richey 180 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1) Caliper Report 08-Nov-08 1 A-27 1 Report /EDE 50-029-22124-00 2) Caliper Report 0&Nov-08 1 C-11 1 Report /EDE 50-029-22714-00 ~, ~"_ - ~ `~~ l~i~- I~~- ~ I ~~~~ I~lb-1 $O a t ~/5'~ Signed : Date:: Print Name: ~.~_ ..o PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~d,ai~~i~o~a€~e{r~rrae~car?19oc~.carrl WEBSITE : wr°:n~+ra.a~e~ssl°~cssl.~~l~ J C:\Documents and Settings\Owner\Desktop\Tcansmit_Conoco.docx • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-11 Log Date: November 6, 2008 Field: Kuparuk Log No.: 8721 State: Alaska Run No.: 4 (3`d Caliper) API Na.: 50-029-22714-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8rd ABMOD Top Log Intvl.: Surface Pipet Use: Tubing & Scab Liner Bot. Log Intvl.: 10,265 Ft. (MD) Pipet Desc.: 5" 18 Ib. L-80 Top Log Intvl.: 10,265 Ft. (MD) Pipet Use: Liner Bot. Log Intvl.: 10,713 Ft. (MD) Inspection Type : Cornasive & Mechanical Damage Inspection COMMENTS This caliper data is ded into the `D' Nipple w/RHC Plug ~ 10,189' (Driller's Depth). This log was run to assess the condition of the tubing, scab liner and liner with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing and scab liner is in good condition. There are no significant wall penetrations (> 12%), areas of significant cross sectional wall loss (> 9%) or I.D. restrictions recorded. The caliper recordings indicate that the 5" liner logged is in good condition. Outside perforation intervals, there are no significant wall penetrations (> 9%), areas of significant cross sectional wall loss (> 5%) or I.D. restrictions recorded. This is the third time a PDS caliper has been run in this well but the first time on the current 3.5" tubing, 3.5" scab liner and 5° liner. 3.5" TUBING & SCAB LINER -MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (> 12%) are recorded. 3.5" TUBING & SCAB LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL. LOSS No areas of significant cross-sectional wall loss (> 9%) are recorded. 3.5" TUBING & SCAB LINER -MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. k~~~ ~'~~~~ ~ ~~~ ProActive Diagnostic Services, Inc, J P.O, Box 1369, Stafford, TX 77497 Fhone: {281) or {888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~~z~memorylog.com Prudhoe Bay Field Office Phone: {907) 659-230? Fax; {907) 659-2314 ~~~-tea ~ ~~rs6 ~ • • ' 5" LINER -MAXIMUM RECORDED WALL PENETRATIONS ' No significant wall penetrations (> 9%) are recorded outside perforation intervals. 5" LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (> 5%) are recorded outside perforation intervals. 5" LINER -MAXIMUM RECORDED ID RESTRICTIONS ' No significant I.D. restrictions are recorded. Field Engineer: K. Miller Analyst: HY. Yang Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (883) 565-9085 Fax: (281) 565-1369 E-mail: PDS~cumemorylog.com ' Prudhoe Bay Field Office Phone: 1907) 659-2307 Fax: (907 F 659-2314 • • PDS Report Overview ~~ S . Body Region Analysis Well: 1 C-11 Survey Date: November 6, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 211390 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE8rdABMOD 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (% wall) ~ penetration body ti metal loss body 400 300 200 100 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of "oints anal sed total = 336 pene. 0 324 12 0 0 0 loss 38 298 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GlM 1 GLM 2 GLM 3 Bottom of Survey = 319.3 Analysis Overview page 2 PDSREPORT JOINT TABULATION ~EET Pipe: 3.5 in 9.3 ppf L-80 EUE8rdABMOD Well: 1 C-1 1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (Ft.) P~~n. Utnc~t (Ins.) Pen. Body (Ins.) Pen. °~ Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 -1 U 0.02 7 3 2.96 PUP 1 2 0 0.02 7 3 2.96 1.1 35 0 0.02 7 1 2.96 PUP 2 43 0 0.02 7 3 2.96 3 75 0 0.02 8 7 2.95 4 106 0 0.02 7 V 2.95 5 138 0 0.02 7 2 2.97 6 169 0 0.02 7 2 2.98 7 201 U 0.02 7 1 2.98 8 232 t) 0.02 7 1 2.98 9 264 0 0.02 7 G 2.97 10 295 0 0.02 7 7 2.96 11 327 U 0.02 7 2 2.96 12 358 0 0.02 7 2 2.98 13 390 0 0.02 7 6 2.97 14 421 0 0.02 7 1 2.99 15 453 0 0.02 7 2 2.97 16 484 0 0.02 7 2 2.97 17 516 0 0.02 7 2 2.97 18 547 0 0.03 11 9 2.98 19 579 0 0.01 6 3 2.97 20 610 0 0.02 7 2 2.97 21 642 0 0.02 7 2 2.96 22 673 0 0.02 7 6 2.94 23 705 0 0.02 7 2 2.98 24 736 0 0.02 7 2 2.98 25 768 0 0.02 7 5 2.97 26 799 0 0.01 6 4 2.95 27 831 U 0.02 7 2 2.98 28 862 0 0.02 7 2 _ 2.97 29 8_94 U 0.02 7 2 2.97 30 925 0 0.02 7 2 2.97 31 957 0 0.02 7 1 2.98 32 988 0 0.02 7 2 2.97 33 1020 0 0.01 6 1 2.99 34 1051 0 0.02 7 ~~ 2.97 35 1082 0 0.02 7 1 2.97 36 1114 0 0.02 7 2 2.97 37 1145 0 0.02 7 7 2.94 38 1177 0 0.02 7 5 2.96 39 1208 l) 0.02 7 1 2.98 40 1240 0 0.02 7 2 2.98 41 1271 0 0.02 7 2 2.98 42 1303 0 0.02 7 6 2.96 43 1334 0 0.01 6 2 2.96 44 1366 U 0.02 7 4 2.95 45 1397 0 0.02 7 1 2.98 46 1429 O 0.02 7 2 2.97 47 1460 0 0.02 7 5 _ __ 2.95 48 1491 0 0.02 7 2 2.98 _ Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION•EEf Pipe: 3.5 in 9.3 ppf L-80 EUE8rdABMOD Well: 1 C-1 1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (FtJ Pen. UI>s~~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1523 O 0.02 7 3 2.97 50 1554 () 0.02 7 2 2.97 51 _ 1586 t~ 0.02 7 2 2.97 52 1617 ~ 0.02 7 3 2.98 53 1649 O 0.02 7 2 2.97 54 1680 0 0.02 7 2 2.97 55 1712 0 0.02 7 3 2.96 56 1743 0 0.02 7 1 2.97 57 1775 0 0.02 7 6 2.96 58 1806 l) 0.02 7 6 2.96 59 1838 (1 0.02 7 1 2.98 60 1869 l) 0.02 7 2 2.96 61 1901 l) 0.02 7 3 2.96 62 _ 1932 U 0.02 7 2 2.94 63 1964 l) 0.02 7 1 2.99 64 1995 l) 0.02 7 1 2.98 65 2027 l) 0.02 9 8 2.97 66 2058 0 0.02 7 2 2.97 67 2090 U 0.02 7 1 2.98 68 2121 0 0.02 7 1 2.98 69 2152 0 0.02 7 2 2.99 70 2184 0 0.01 6 4 2.94 71 2215 0 0.02 7 3 2.96 72 _ 2247 ll 0.02 7 5 2.95 72.1 2279 0 0.01 6 1 2.96 PUP 72.2 2287 0 0 0 0 2.81 SCSSV 72.3 2291 0 0.01 4 0 2.97 PUP 73 2299 0 0.02 9 2 2.96 74 2329 0 0.02 7 8 2.94 75 2361 O 0.02 7 2 2.98 76 2392 0 0.02 7 7 2.96 77 2423 0 0.02 9 2 2.95 78 2455 () 0.02 8 3 2.98 79 _2486 l1 0.03 11 2 2.94 80 25_17 0 0.02 7 2 2.96 81 2549 0 0.02 9 4 2.96 82 2580 0 0.02 7 2 2.95 83 2612 O 0.02 7 2 2.97 84 2642 0 0.02 7 4 2.95 85 2673 0 0.02 7 2 2.96 86 2705 0 0.02 9 7 2.96 87 2736 (1 0.02 7 2 2.96 88 2768 0 0.02 7 2 2.96 89 2799 0 0.02 7 2 2.97 90 2831 O 0.02 7 6 2.95 91 2862 O 0.03 11 2 2.98 92 2894 (1 0.02 7 1 2.98 93 _2925 O 0.02 7 2 2.97 94 2957 O 0.01 Ei 2 2.98 95 2988 11 0.02 7 2 2.96 Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE8rdABMOD Well: 1 C-1 1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (FtJ Pc~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 96 3020 0 0.02 7 2 2.96 97 3051 0 0.02 7 3 2.97 98 3082 0 0.02 7 2 2.97 99 31 14 l) 0.02 7 4 2.94 100 3145 l) 0.02 7 2 2.96 100.1 3177 l) 0.02 7 2 2.97 PUP 100.2 3185 0 0 0 0 N A GLM 1 latch ~ 10:30 100.3 3191 0 0.01 6 1 2.97 PUP 101 3200 U 0.02 7 1 2.97 102 3231 C) 0.02 7 2 2.97 103 3261 t) 0.02 7 2 2.95 104 3293 0 0.02 7 2 2.95 105 3324 0 0.02 7 1 2.97 106 3356 0 0.02 7 2 2.96 107 3387 t) 0.02 7 3 2.96 108 3419 0 0.02 7 L 2.97 109 3450 0 0.02 9 2 2.97 110 3482 0 0.02 8 3 2.96 111 3513 0 0.02 7 5 2.95 112 3544 0 0.02 7 2 2.96 113 3576 0 0.02 7 2 2.96 114 3606 0 0.02 7 2 2.96 115 3635 0 0.02 7 2 2.94 116 3667 0 0.02 2 2.95 117 3698 0 0.02 7 1 2.96 118 3730 0 0.02 7 1 2.96 119 3761 0 0.01 6 2.95 120 3793 0 0.01 6 ? 2.96 121 3824 0 0.02 9 ~ 2.96 122 3856 0 0.01 6 ? 2.95 123 3887 U 0.01 4 2 2.97 124 3918 0 0.02 7 3 2.97 125 _ 3951 U 0.02 7 2 2.98 126 3982 0 0.02 7 2 2.96 127 __4013 0 0.02 7 1 2.96 128 _4045 0 0.01 6 2 2.96 129 4076 0 0.02 7 1 2.95 130 4107 0 0.02 7 2 2.96 131 4139 U 0.02 7 2 .97 2 132 4170 0 0.03 11 ~ _ _ 2.92 132.1 4202 0 0.01 4 2 2.96 PUP 132.2 4209 0 0 0 0 N A GLM 2 Latch ~ 5:00 132.3 4219 0 0.01 4 1 2.96 PUP 133 4225 0 0.02 7 3 2.96 134 4257 U 0.02 5 2.96 135 4288 0 0.02 2 _ 2.97 136 4319 0 0.02 7 1 2.97 137 __4351 0 0.02 7 1 2.98 138 4382 0 0.01 6 2 2.96 139 4414 0 0.02 7 2 2.97 Penetration Body Metal Loss Body Page 3 PDSREPORT JOINT TABULATION•EEf Pipe: 3.5 in 9.3 ppf L-80 EUE8rdABMOD Well: 1 C-1 1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (Ft) Pen. Upset (tns.) Pen. Body (Ins.) Pen. % Metal Loss % Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 140 4445 0 0.02 7 1 2.96 141 4477 O 0.02 7 2 2.95 142 4508 O 0.02 7 7 2.94 143 4539 O 0.02 7 2 2.96 144 4570 0 0.02 7 2 2.96 145 4601 0 0.02 7 2 2.96 146 4632 0 0.01 6 3 2.93 147 4663 0 0.02 7 4 2.94 148 4695 0 0.02 7 4 2.95 149 4726 (1 0.02 9 4 2.96 150 4758 U 0.02 7 2 2.96 151 4789 0 0.01 6 2 2.96 152 4821 0 0.02 7 2 2.96 153 4852 0 0.02 7 2 _ 2.95 154 4883 0 0.02 7 2 2.94 155 4915 0 0.02 9 2 2.96 156 4947 0 0.02 7 1 2.97 157 4977 Q 0.02 8 2 2.93 158 5009 0 0.02 9 9 2.97 159 5041 0 0.02 7 3 2.96 160 5073 0 0.02 9 2 2.95 160.1 5105 0 0.02 7 1 2.95 PUP 160.2 5112 0 0 0 0 N A GLM 3 Latch ~ 6:00 160.3 5119 0 0.01 6 5 2.96 PUP 161 5128 0 0.02 7 2 2.99 161.1 5159 cl 0.01 6 2 2.94 PUP 161.2 5165 0 0 0 0 2.99 Locator 161.3 5167 t) 0.00 2 2 2.96 Seal Assembl 161.4 5187 O 0 0 0 N A SBE 161.4 5191 0 0 0 O 2.99 Xover Bushin 161.5 5192 0 0.02 7 2 2.93 PUP 161.6 5196 0 0 0 0 2.99 FHL Retrievable Packer 161.7 5204 U 0.02 7 1 2.94 PUP 162 5207 0 0.02 8 2 2.98 163 5239 O 0.02 9 1 2.97 164 5272 0 0.02 7 2 2.97 165 5304 (1 0.02 9 3 2.96 166 5336 0 0.01 (i 2 2.96 167 _ 5366 t) 0.02 7 2 2.96 168 5398 (1 0.02 8 2 2.95 169 _ 5429 0 0.03 10 2 2.97 170 5461 l) 0.02 8 2 2.95 171 5493 O 0.02 7 2 2.96 172 5525 0 0.01 6 1 2.96 173 5557 l) 0.02 7 2 2.96 174 5589 O 0.02 7 2 2.96 175 5621 0 0.02 7 2 2.96 176 5652 0 0.02 7 2 2.97 177 5684 0 0.03 10 2 2.97 178 5716 O 0.02 7 2 2.97 Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINTTABUTATION SHEEN Pipe: 3.5 in 9.3 ppf L-80 EUE8rdABMOD Well: 1 C-1 1 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Cornpany: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (Ft.) Pen. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 179 5748 (1 0.02 7 2 2.97 180 5780 0 0.02 9 2 2.96 181 5812 U 0.02 7 6 2.97 182 5844 t) 0.02 9 2 2.97 183 5875 0 0.02 7 8 2.96 184 5907 0 0.02 7 7 2.96 185 5939 l) 0.02 7 2 2.96 186 5971 11 0.02 7 2 2.98 187 6003 0 0.02 7 2 2.97 188 6035 O 0.02 7 2 2.96 189 6067 0 0.02 9 2 2.97 190 6099 0 0.02 7 1 2.98 191 6131 O 0.02 7 8 2.96 192 6163 C) 0.02 7 1 2.98 193 6195 t) 0.02 9 1 2.98 194 6227 U 0.02 9 8 2.97 195 6259 0 0.02 7 4 2.94 196 6290 (1 0.02 9 2 2.95 197 6322 11 0.02 9 6 2.92 198 6355 0 0.02 7 2 2.96 199 6386 0 0.02 7 2 2.96 200 6418 U 0.03 11 6 2.92 201 6451 t) 0.02 7 2 2.97 202 6482 (1 0.01 4 2 2.92 203 6514 0 0.02 7 6 2.95 204 6546 0 0.01 6 2 2.94 205 6578 0 0.02 9 (> 2.94 206 6610 O 0.02 9 2 2.98 207 6641 0 0.02 9 2 2.96 208 6673 l) 0.03 11 1 2.93 209 6705 U 0.02 7 5 2.97 210 6737 O 0.02 7 2 2.97 211 6769 (1 0.03 10 2 2.97 212 6801 t) 0.02 9 2 2.97 213 6832 0 0.02 7 2 2.96 214 6865 t) 0.02 7 2 2.97 215 6897 0 0.02 7 6 2.96 216 6929 () 0.02 7 2 2.95 217 6961 0 0.02 7 2 2.97 218 6992 0 0.02 U 3 2.94 219 7025 0 0.02 7 5 2.96 220 7057 0 0.02 7 4 2.94 221 7089 0 0.02 7 2 2.97 222 7120 11 0.02 7 1 2.98 223 7152 l1 0.02 7 1 2.97 224 7183 0 0.03 11 7 2.96 225 7215 0 0.02 7 2 _ 2.97 226 7246 0 0.03 10 7 2.97 227 7278 0 0.02 7 2 2.95 - 228 7310 0 0.02 7 2 2.98 Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 EUE8rdABMOD Well: 1 C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (Ft.) Pc~n. Ulxc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss `% Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 229 7342 (1 0.02 ' 4 2.92 230 7374 (1 0.02 9 ? 2.98 231 7405 t) 0.03 12 9 2.97 232 7437 U 0.02 7 2 2.98 233 7469 0 0.02 7 6 2.97 234 7501 l) 0.02 7 2 2.94 235 7533 l) 0.02 7 5 2.96 236 7565 0 0.02 7 2 2.98 237 7597 0 0.02 7 7 2.95 238 7628 0 0.01 6 V 2.97 239 7660 0 0.02 7 2 2.96 240 7692 0 0.02 9 4 2.95 241 7723 E) 0.01 6 2 2.92 242 7755 E) 0.02 7 3 2.94 243 7786 O 0.02 9 2 2.95 244 7818 l) 0.02 7 3 2.94 245 ___7849 l) 0.02 7 2 2.95 246 7880 l) 0.02 7 4 2.95 247 7912 O 0.01 6 Z 2.92 248 7943 0 0.02 7 6 2.95 249 7975 a 0.02 3 2.94 250 8006 1) 0.02 7 3 2.92 251 8038 0 0.02 7 2 2.95 252 8069 0 0.02 9 2 2.94 253 8101 0 0.02 7 2 2.93 254 8132 0 0.02 9 3 2.92 255 8164 U 0.02 7 2 2.96 256 8195 0 0.02 7 1 2.96 257 8227 0 0.02 7 2 2.94 258 8258 O 0.02 7 2 2.95 259 8290 U 0.02 7 2 2.96 260 8321 0 0.02 7 2 2.96 261 8352 O 0.02 7 4 2.95 262 8384 O 0.02 7 2 2.95 263 8_415 0 0.02 7 2 _ 2.93 264 8447 0 0.02 7 2 2.95 265 8478 0 0.01 6 2 2.95 266 8510 0 0.02 7 2 2.95 267 8541 0 0.02 9 5 _ 2.96 268 8573 0 0.02 7 2 2.97 269 8605 l) 0.03 11 2 2.95 270 8637 U 0.02 7 6 2.96 271 8669 U 0.02 7 6 2.95 272 8701 O 0.02 7 6 2.94 273 8733 E) 0.03 10 2 2.97 274 _ 8765 l) 0.02 7 2 2.97 275 8797 l) 0.02 7 t3 2.97 276 8829 0 0.02 9 (> 2.96 277 8861 0 0.02 7 2 2.96 278 8893 0 0.02 7 2 2.92 _ Penetration Body Metal Loss Body Page 6 PDS REPORT JOINT TABULATION S•HEEf Pipe: 3.5 in 9.3 ppf L-80 EUESrdABMOD Well: 1 C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (Ft.) Pc~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 279 8924 0 0.02 9 6 2.95 280 8956 0 0.02 7 4 2.96 281 8988 0 0.02 9 2 2.96 282 9020 0 0.02 7 2 2.95 283 9052 0 0.02 7 2 2.97 284 9084 0 0.02 7 5 2.94 285 9116 0 0.02 7 2 2.98 286 9148 0 0.02 7 2 2.95 287 9180 0 0.02 9 6 2.96 288 9212 0 0.03 11 2 2.97 289 9243 0 0.02 8 8 2.97 290 9276 0 0.02 9 2 2.93 291 ___9306 0 0.02 9 2 2.95 292 __ 9338 0 0.02 7 6 2.96 293 9370 0 0.02 7 6 2.93 294 9402 0 0.03 10 6 2.96 295 9434 0 0.02 9 2 2.96 296 9466 0 0.02 7 2 2.96 297 9498 U 0.02 9 6 2.95 298 9529 0 0.03 11 6 2.96 299 9561 () 0.02 7 2 2.95 300 9592 0 0.02 S 2.94 301 9623 0 0.02 ,' ? 2.94 302 9655 0 0.03 12 2 2.97 303 9687 0 0.02 7 2 2.94 304 9719 U 0.02 7 3 2.96 305 9751 0 0.02 7 2 2.96 306 9783 0 0.02 7 6 _ 2.96 307 9815 0 0.02 9 V 2.94 308 9846 0 0.02 9 2 2.96 309 9878 0 0.02 7 2 2.95 310 9910 U 0.02 7 Z 2.95 311 9942 0 0.01 6 2 2.96 312 9974 0 0.02 9 i 2.95 313 10005 0 0.02 7 5 2.94 314 10037 0 0.02 7 2 2.95 315 10069 0 0.02 7 3 2.93 316 10101 0 0.02 7 2 2.93 316.1 10131 0 0.01 6 2 _ 2.94 PUP 316.2 10141 0 0 0 0 2.87 Baker Premier Production Packer 316.3 10147 l) 0.02 7 2 2.93 PUP 317 10157 0 0.03 10 3 2.91 317.1 10189 O 0 0 0 2.75 D Ni le w RHC Plu 318 10191 () 0.01 4 3 2.94 319 10222 0 0.02 7 3 2.93 319.1 10253 0 0.01 6 2 2.92 PUP 319.2 10258 (~ 0 0 0 3.00 Fluted NO GO Ni le 319.3 ._ 10260 0 0 0 O 4.40 Half Mule Shoe w Mill Out Extention Penetration Body Metal Loss Body Page 7 PDS REPORT JOINT TABULATION SHEET Pipe: 5. in 18.0 ppf L-80 Well: 1 C-11 Body Wall: 0.425 in Field: Kuparuk Upset Wall: 0.425 in Company: Conoco Phillips Alaska, Inc. Nominal I.D.: 4.151 in Country: USA Survey Date: November 6, 2008 Joint No. Jt. Depth (Ft.) Parr. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °ii, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 10265 0 0.02 9 5 2.93 Baker GBH-22 PBR To of 5" Liner .2 10311 0 0 0 0 3.50 Shoe 1 10313 0 0.02 5 2 _ 4.10 2 10358 0 0.03 6 2 4.09 3 10401 U 0.01 2 0 4.10 4 10445 0 0.01 2 1 4.10 5 10488 0 0.01 2 2 4.10 5.1 10531 0 0.01 3 1 4.08 Marker 5.2 10552 0 0.00 1 1 4.11 Marker 6 10577 0 0.01 2 2 4.05 7 10617 U 0.21 50 11 4.06 Perforation intervals. 8 10660 0.1 S 0.41 96 20 _ 3.94 _ Perforation intervals. 9 10702 O 0.23 55 12 _ 4.12 Perforation intervals. Penetration Body Metal Loss Body Page 1 ConocoPhillips :d~~4~,1 I ~ n nMNGER, 37 ~---~-~ CONDUCTOR. anzl sssv.zza7 cAS LIFT. 3.194 GAS LIFT, x,277 sfu. s i 7z 3 S SCAe LMJER, 5.183101]1 PRODUCTION, o-lopv 10 880-10 610 FRAC, 10 660 IPERf, 10870-tO T16 KUP . 1 C-11 Well Attributes W e0tgre APW W I Fl d Name 1 Slavs flodlsnl Well Inci (') hD gd1a1 7D Imaxl fR- 500292271400 KUPARUK RIVER UNIT PROD 60.81 4,079.00 11,300.0 Continent ~ H2S gtptt4 Dote Alnatatlon E}Id Dae ID;~rtl III) Rlg Rdease Dae SSSV_ TROP 60 7!4/2008 Last WO: 61812006 47.01 1/14!7997 Amalatlan GPSt rytlm) Last Tag: 10,867.0 DM Dae 6122!2008 Amolatlan Rev Reason: FORMAT UPDATE fiM Dae 10/30/2008 Casin Strin s _ Casing Des an CONDUCTOR Stfkg O_. 16 Stfkng b.. 15.060 . Top IR1m1 s 0.0 et epm lf_. 121.0 aD (TWI._ 121.0 .. 62.50 String _. H•40 Stdng op d Casnng Descrptlon SURFACE Sttkng O_ 95/8 ShYng tD .. 8.525 . Top 11110) S 0.0 d'Deplt p... 6,943.0 Sa DepN (TVDI ._ 4,439.0 SlrauJ YIN_. 40.00 stm9-• L~0 SDky ap Tfrd fasatg Dee on PRODUCTION Slrkn90_ 7 _ 6.151 . opl 1 8 0.0 M (L.. 10,427.0 SdD ( 1•_ 6.344.0 Sldng Wt_. 26.00 SMng _. L~0 Top d an LINER SMng o_ 5 - 4.751 . op 1 s 10,271.0 d It_ 11.3D0.0 sd eW+l7vol .- 7,010.7 StMgwt. 18.00 LBO op Casing Destrlptlan 3.5"SCAB LINER Stfktg O._ 31/2 etrhtg D.. 2.992 . Top lfDml s 5,163.3 et Deptll lf_. 10,271.0 Sd DeptltlNq._ 6.230.6 Strrhg W4. 9.30 9wq... L-00 Stdry TOp 71x0 EUEBrdABMOD liner D4ltails Top IRKBI Top Depth fT'!DI Intel Top Ind 11 Item Desulpllon Comment D flnl 5,163.3 3,496.2 5 .33 SL EVE HR Liner Sleeve 4.420 5,177.7 3,504.0 57.34 XO BUSHING Rover Bushing 4.250 5,178.9 3,504.6 57.34 SBE 800 Seal Bore Extenoon 4.000 5,198.2 3,515.0 57.35 XO BUSHIN Rover Bushing 2.990 5,202.9 3,517.5 67.35 PACKER FHL Reuievable Paler 2. 2 10,140.9 ,142.8 49.26 PACKER Baker Prertia Production Packer 2.870 10,189.0 6,175.6 48.27 NIPPLE 2.75'D'Nipple r/RHC Plug 2.750 10,262.0 6,224.3 45.80 NIPPLE Fluted No/Go 3.000 Tubin Strin s Turing Desplptlon 3tdng O_ 9tdng ~ .., Top (11K6) Set Depm IL Sd Depth (T~l •- StMg Wt. String -. String Top Md TUBING 312 2.992 36.7 5,193.0 3,512.2 9.30 L-80 EUESrdABMOD Coin le _ tion Details Top (1M6) Top DepM 1~1 (NYB) Top InN (~ ksm Descrlpgon Comment D MI 36.7 J6.7 -0.72 HANGER Tubing Hanger 6713.5 "ISA' BPVG 2.992 2,297.4 1,994.4 55.61 SSSV SCSSV wills 2.813" Xyrofde 2.812 5,170.2 3,499.9 57.34 LOCATOR Locator w! 1.04' space out 2.992 5,172.5 3,501.2 57.34 SEAL Seal Assembly ---~- 2.992 l)fher I n Hole reline retrievatNe w vaWes, fish etc. Top (tDlB) Top Depm ITVDI (R~) Top Y1d 1'1 Descrlpgtn Camman Rvt Dae p 1„1 10,271.0 6,230.6 45.50 PBR Baker GBH-22 11/1617996 3.000 10,321.0 6,266.4 43.82 SHOE 11/16/7996 3.500 10,780.0 6,606.8 41.36 PLUG Set 2 1!8° Baker IBP in 5: krner; rated 3600 psi; faking neck 1.375 OD; 5500k release puS -moved to 10780 CTMD 6/21 /08 4202008 0.000 77,796.0 6,927.1 36.85 FISH stainer Pin 3' GU Adapter core remiw~ (2.7711°x5') 12!142007 Perforations Top IN1e1 can pDi6) Topl~l f~l ~Itwl mil Zane Dae she oera 1~~ TYPe eammert 10,660.0 10,670.0 6,516.8 6,524.3 C~, iC-11 61192008 6.0 RPERF 2.5 HSD vA2606 HJ, 60 Deg Phase, est .43' hole diameter 10,670.!1 1 ,716.0 6,524.3 558.7 G4, C , 1 -11 1/14/199 2.0 IPERF Zsro lag. Phasig; 21/8° Eneryet Stimulations b Treatments hit Tap Depth IhKBI Matt &Itn Deptln 1~1 Top Depth ffvDl ptlm) Isottom Depdn ITVDI 1~1 ae ommem 10.660.0 70,716.0 6,516.8 6,558.7 F RAC 6202008 CSAND Hydraukc FRAC; 140,830# 1620 Carbo6te behind pipe; 93% design; 10ppa into formation. Cement ueezes Top 11N(B) rop Depth 1~1 Ban lRKel IRKISI enn Depm ITwI IRKaI Descrtpdon Start Dae Comment 5,900.0 6,000.0 ~ L iner Cerrnernl 52812008 Sand plug above RBP a[ 6000'. Notes: General 8 Safety ___.- Bid Dae _______ -_ - ---.AmiMalon 4!32008 NOTE: SWS LDL INDICATES IBP ~ 10,385 LEAKING FROM BELOW 61812008 NOTE: NEW 3.5 TBG INSERTED INTO 3.5° SCAB LINER @ 10272' 61762008 NOTE: VIEW SCHEMATIC w REPORT CALLED Alaska Schemalic9.0 Mandrel Details stn lap IUKl1 op (iVD) IRiml op Ina 1"I Mtke ModN oD 8n) 8srv Valve type L.attln type Port ate lasl 1R0 R1n (pal) Run Dee Camm_ 1 3,193.9 2.472.8 58.&4 CAMCO KBMG 1 Gas lift GLV BK3 1/8 1,227.0 6/222008 2 4,217.4 2,993.2 69.14 CAMCO KBMG 1 DMY BK-5 0 0.0 6/&'1008 3 5,1 7.5 3,471.5 57.31 CAMCO KBMG i Gas Lift OV BK~ 1/4 0.0 6/222008 PLUG, 70,780 fISN, 17,196 1 C- T 1 (PTD 196-172) Report Of ~ed TIFL • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, October 20, 2008 2:46 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 DS Lead Techs; CPF1 Prod Engr; Kappel, Erica J Subject: 1C-11 (PTD 196-172) Report Of Failed TIFL Attachments: 1C-11 Wellbore Schematic.pdf; 1C-11 TIO Plot.ppt Jim/Tom, /~~ Kuparuk gas lifted producer 1C-11 (PTD 196-172) failed_,a diagnnctic TIFL on 10/19/08 and has been added to the SCP report. The T/IA/OA prior to the TIFL was 240/1230/650. A leaking ~aslift valve is suspected so ConocoPhillips will attempt to troubleshoot and repair with slickline or be shut-in by 11/16/08. Attached is a 90 day TIO plot and a Wellbore schematic. «1C-11 Wellbore Schematic.pdf» «1C-11 TIO Plot.ppt» / Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 •~s! lY"~~Y fii.ir ~ ~ IL~ F~ o' ,( I~ ~ ~,/ 12/10/2009 IAP 1200 1000 800 o. 600 400 200 0 OAP FTT T/l/0 Plot -1 C-11 -_ ~- ~, ~~ ~~ ~~ 200 150 a E as 100 Y O s v 50 01-Aug-08 01-Sep-08 Date 01-Oct-08 0 _ ~ ~P _ ~ 1C-11 ConoeoPE~illips i ~ ~ ~eIl Attributes---- _ _--- --- - - ^, i,.;. i API / ;; i Feltl Name W II Status Maximum Inclination (°) Total Depth (ftK8) ' 1500' .'.' ".4 KUPARUK RIVER UNIT (PROD 60.81 --~ 11,300.0 Comment H2S (ppm) Dato Annotati... End Date KB-Ground Distance (R) Rig Release Date '" TRDP 60 7/4/2008 Lasl WO: 6/82008 47.01 1114/1997 WeA Confi~ 1020081'.3410 PM - - ' Annotation Depth (RKB) End Date Annotation Entl Date _.. _.-, Last Tag. 10.867.0 6222008 Rev Reason: ADD PERFS, TAG SLM, GLV C/O 7/52008 Casin Strings_ _ - --- _. .... ~~,,,,.,,,_ _ ___ .Casing Description OD (inl ID (ink Top {ftK8) Set Depth (ft... Sat Depth (ND) (ft... Wt (Iba/... Grade Top Oonnech HANGER, 37 '. `~ ~ CONDUCTOR 16 15.060 0.0 121.0 121.0 62.50 H-40 "~;-"-_' - -' Casing Description OD (in) ID (In) Top (RKB) Set Depth (R... Set Depth (ND) (ft... Wt (Iba/... Oratle Top Connecti - - "~ ~.,_, ~ SURFACE 95/8 8.525 0.0 6,943.0 4,439.0 40.00 L-80 Caaing Deacription OD (in) ID (in) Top (ftK8) Set Depth (R... Set Depth (ND) (tt... Wt (Ibsl... Grade Top Connect) ~, ,~". 3.5" SCAB LINER 31/2 2.992 5,163.3 10,271.0 6,230.6 9.30 L-80 EUE 8RD ~~aewxmr:. . i ~NDUeroR. a1z1 j ~.,~ sssv,z,zs7 ~ i GA6 LIFT, F-` -,7 3,194 ,. 1 GAS LIFT, i a,z17 ~-~ '. ~ GAS LIFT, r, _- . 5.117 , 1 L~~ ~, ~ h,~ ~ ~ . I SEAL, 5,172 i ~,j - i k*.i T- < x SURFACE, -1 3.5"SCAB LINER, 5,ifi310,271 PRODUCTION, 0.10,427 RPERF, 10,660-10,670 FRAC, 10,660 IPERF, 10.670-10.716 PLUG. 10.780 FISH, 11.196 FISH. 11.198 LINER, 10,271-11,300 TD, 11.300 Liner Details PRODUCTION 7 6.151 0.0 10,427.0 6,344,0 26.00 L-80 Casing Description OD (in) ID (in) Tap (RKB) Set Depth (tt... Sat Depth (ND) (R... Wt (Ibsl. .. Grade Top Connection LINER 5 __. 4,151 10,271.0 11,300.0 ___ 7n1n7 18.00 L-80 Tubing Strings _ c Tuhing Dea pt on OD (In) _ ID (In) ''Top (ft S t Depth (ftK -Set Dep I f ~ '-v,N t I ,sift) ?Grade Top C nnect'on TUBING ' 3 1/2 2.992 36.7 I 5,193.0 ~ ., ... ~ .,.?~ L 80 EUE SRD '~ '~ 1 AB-modLerl fin letwn Details r.,,aeawA~ i -n __ __ r,.. n _._ ___ _~ , . - _ __..._ _ ___._._-. _ i-ommeM _ - _ - - _. -_.__ , iU iinl 2,297.4 SSSV 3.5" TRMAXX-5E Safety Valve Ser.# CXS-21 2.81[ 5,172.5 SEAL Seal Assembly 2.992 Other In Hole I ,.,r. ,........(P U~JL., Flsh, etc,.-___ -_ _.. ,,, Ru7;~aee ro-ii~l 10,271.0 PBR Baker GBH-22 11/16/1996 3.000 10,320.0 TTL 11/16/1996 2.992 10,321.0 SHOE 11/16/1996 3.500 10,780.0 PLUG SET 2 1/8" BAKER IBP AT 10385' IN 5" LINER. PLUG RATED FOR 3600 4202008 0.000 PSI SET IN 5" LINER. FISHING NECK IS 1.375" OD. 5500# TO PULL RELEASE. 11.05' OAL MID ELEMENT@ 10,380' '*FAILED"-MOVED IPB TO 10780 CTMD ON 6212008. 11,196.0 FISH Retainer Pin 3" GU ADAPTER CORE RETAINER PAIN (2.7" x 1"x .5") 12/142007 POSSIBLY LOST DOWNHOLE 12/14/2007 11,198.0 FISH 1 12" Dummy Valve LOST 1/7/1997 1!7!1997 Perforati ons ~ - - - p elm - ~- sno i -- -- 7op Btm (rvD) (ND) Dena (RKB) (RKB) (RKB) (RKB) Type Zone (ahO^• Data Comment 10,660.0 1 0,670.0 6,516.8 6,524.3 RPERF C-4, 1C-11 6.0 6/19/2008 2.5" HSD LOADED W/ 2506 HVPERJET CHARGES (60 DEG PHASING, EST. 0.43" HOLE DIAMETER) 10,670.0 10,716.0 6,524.3 6,558.7 IPERF C-4, C-3, 1C-11 2.0 1/14/1997 Zero deg. Phasing; 2 1/8" Enerjet (Stimulations & Treatment_s_ _ _ _ _ _- _.______ _ min Top Max dtm Depth (RKB) Depth (ftK8) Date Type Comment 10,660.0 10,716.0 620/2008 FRAC C SAND HYDRAULIC FRACTURE STIMULATION. PLACED 140,820# OF 1620 CARBOLITE BEHIND PIPE, '93°k OF DESIGN, FRAC PRESSURED OUT WITH 210 BBLS OF 10 PPA SAND INTO FORMATION. Q --- __.._ t n~ e2 oet c m ' s1 n o ie I D s~rrpr n at (R Ka l 1 _ _ P 1 _ 5,900.0 6 000-0~5i28/2008 Line Cement Sand plug above RBP at 6000. Notes: General &_ Safety ___ __ _ End Data Annotation 4/32008 NOTE: SWS LDL INDICATES IBP @ 10,385 LEAKING FROM BELOW 6/82008 NOTE: NEW 3.5" TBG INSERTED INTO 3.5" SCAB LINER @ 10272' 6/162008 NOTE: VIEW SCHEMATIC w REPORT CALLED Alaska Schematlc9.0 Mandrel Details _ _ ~- ..._.-_ . . _.... _ _____ _ T Sel Depth' Port lop (ND) Valve Latch Size TRO Run Stn (RKB) (ftK8) Make Model OD (in) Type Type (in) (psi) Run Date Comment 1 3,193 .9 3,512.2 CAMCO KBMG 1 GLV BK-5 1/8 1,227.0 6222008 '. 2 4,217 .4 3,512.2 CAMCO KBMG 1 DMY BK-5 0 0.0 6/82008 3 5,117 .5 3,512.2 CAMCO KBMG 1 OV BK-5 1/4 0.0 6/22J2008 °~ ,..~ • i i r ~ ~~ ~, ,_ -~ STATE OF ALASKA `" `" `~° ~ ~'t~Uu~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~' ~°~ 1. Operations Performed: Abandon ^ Repair Well ~ Plug Pertorations ^ Stimulate Q Other ^ Alter Casing ^~ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ^ Exploratory ^ 196-172 / 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-22714-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', 61' Pad 1 C-11 8. Property Designation: 10. Field/Pool(s): ADL 25638, ALK 463 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 11300' ~ feet true vertical 7011' feet Plugs (measured) 10354', 10380' Effective Depth measured 11116' feet Junk (measured) 11196', 11198' true vertical 6864' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 6902' 9-5/8" 6943' 4439' PRODUCTION 10386' 7" 10427' 6344' LINER 1029' 5" 11300' 7011' SCAB Liner 5108' 3.5" 10271' 6231' Perforation depth: Measured depth: 10660'-10716' MD ~~~~~ ~~ ~ ~ ~ ~~UU True vertical depth: 6517'-6559' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5193' MD. Packers and SSSV (type & measured depth) FHL retriev. Pkr, Baker Premier pkr @ 5203', 10141' Camco SSSV @ 2297' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10660'-10716' Treatment descriptions including volumes used and final pressure : C Sand hydraUllC fraC StlmUlatlOn 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Si -- Subsequent to operation 656 1132 2327 -- 223 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 308-079 contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature Phone: 263-4220 Date ~12~///~ ~-- ~~ ~ Pre re b Sharon Allsu -Dr 263-4612 Form 10-404 Revised 04/2006 S ~ ~~~ ~ ~ 24~~ ,~ TL9.o~ ! \ ~ ~ I ~ /~ ~ Submit Original O[~~~ .. -11P 1 C-11 ConUCOpflillip5 ~ Well Attributes __ --- Algyw, ~ „_ { I API / UWI Field Name Maxim um l I tlon (°) (Total Depth (ttKB) Well Status 1 .. ,,. 5002922714 ( IKDPARDK RIVER UNIT PROD 6081 _~ 11,300.0 Comment '~~ H25 (ppm) .Date Annotati... End Date KB-Ground Distance (ft) Rig Release Date teat 7/s¢ooa 45e3e rmn -- w I e SSSV: TRDP 60 7/4/2008 Last WO: 6/8/2008 47.01 1/1 M1997 m : - _~ __.,_. _ __ _,, ,, emeaS -Acwal A ration ~IDepth (ftKB) End Date 'i End Dete Annotat-on L~ . I Tay: '. 10,867.0 ( 6/22/2008 Rev Reaso n_ ADD PERF INTERVAL 10660-10670, TAG SLM, NEW 7/5/2008 __. _- -_. Casing Strings Casing Description OD (in) ID (in) Top (ttKB) 'Set Depth (tt... ',Set Depth (TVD) (tt... WL (Ibs/... Grade 'Top Connecti HANGER, 37 CONDUCTOR 16 15.060 0.0 121.0 121.0 62.50 H-40 - Casing Description OD (in) ID (in) Top (flKB) Set Depth (tt... Set Depth (TVD) (tt... Wt (Ibs/... Grade Top Connecti SURFACE 195/8 8.525 0.0 6,943.0 ~ 4,439.0 40.00 L-80 n 9 P D in OD ( ) 1 ( ) ITo ) (ft... P ( ) ' Mt ( ep ~~ i~Set D B Sct Wts 0"''' Gratle ( Tap Connecti PRODU CT ON I 7 6'151 10,427 0 6,344.0 0 0 L-80 ' Casinq Description OD (in) ID (in) Top (ft KB) jSef Depth (h... 'Set Depth (TVD) (ft... ~ Wt (Ibs/... Grade Tap Connecti LINER '' S 4.151 10,271.0 11,300.0 7,010.7 18.00 L-80 CONWCTOR, Casing Description OD (in) ID (in) Top (ft K8) Set Depth (ft... Set Depth (TVD) (ft... Vh (Ibs/... Grade Top Connecti o-t2t 3.5' SCAB LINER ~ 3 1/2 2 992 5,163.3 10,271.0 6,230.6 9.30 L-80 EUE 8RD - _ AB-modified Liner Details _ __ _ _.. _ _ _ _ ~ ~ SSSV. 2,297- Top (ttK8) hem Description Comment ID 5,177.7 XO BUSHING 'Rover Bushing 4. MANDREL, 3.194 MANDREL, 4,217 MANDREL. _ _- _ _ 5.11 sFaL. s.t 72 SURFACE. 0-6.90.1 3.6" SCAB LINER. 5,163-10,271 IBP, 10,760 FISH, 11,186 FISH, 11,196 -- EWER, 10,271-11,300 \ - TD, 11.300 Fluted No/Go- _ _ _ _ _ (m) ID (in) (Top (ft (Set Depth (ftK Set Depth (TVD) (flKB) W[ (Ibs/ft) Grade lop Conne 3 1/2 2 992 ~ 36J 1 - 5,193 0 3,512.2 - 9.30 ~ L-80 EUE 8RD AB-modifi 31115 ription Commem 1'~,Tubing Hanger 6"x3.5" "ISA' BPVG ~~~.SSSV: TRDP 3.5' TRMAXX-SE Safely Valve SeL# CXS-21 10,780.0 IBP SET 2 1/8' BAKER IBP AT 10385' IN 5' LINER. PLUG RATED FOR 3600 4/20/2008 0.000 PSI SET IN 5' LINER. FISHING NECK IS 1.375' OD. 5500# TO PULL RELEASE. 11.05' OAL MID ELEMENTS 10,380' "FAILED" -MOVED IPB TO 10780 CTMD ON 6/21/2008. 11,196.O~ FISH Retainer Pin 3' GU ADAPTER CORE RETAINER PAIN (2.T x 1' x .5') 12/14Y2007 ( POSSIBLY LOST DOWNHOLE 12/14/2007 11,198.0 FISH ' - 1 1!2' Dummy Valve LOST 1!7/1997 1/7/1997 I erforati ons ToP Btm Shm - -. Tap flKB) Btm (TVD) (ft KB) (ttKB) (TVD) Dens (flKB) Type Zone (sho-~ Date Comment 1,660.0 10,670.0 6,516.8 6,524.3 RPERF C-4, 1 C-11 6.0 6/19/2008 2.5' HSD LOADED W/ 2506 HYPERJET CHARGES (60 DEG PHASING, EST. 0.43' HOLE ~, DIAMETER) 1,670.0 10,716.0 6,524.3 6,558.7 (PERF C-4, C-3, 1 C-11 2.0 1!1411997 'Zero deg. Phasing; 2 1/8' Enerjet simulations & Treatments Min Tap Max Bnn I pth (IIKB) Depth (ftKe)' Oate Type Commem 10,660.0 10,716.016/20/2008 Hydraulic C SAND HYDRAULIC FRACTURE STIMULATION. PLACED 140,820# OF Fracture 16/20 CARBOLITE BEHIND PIPE, -93°~ OF DESIGN. FRAC PRESSURED OUT WITH 210 BBLS OF 10 PPA SAND INTO FORMATION. W Valve Latch Size TRO Run )D (in) TYPe TYPe (N (Psi) Run Dal 1 GLV BK-5 1/8 1,227.0 6/22/200f 1 DMY BK-5 0 0.0 6/8/2008 1 OV BK-5 1/4 0.0 6/22/200f L CanocoR~iips Time Log & Summary Wetfriesv Web ReyortJnq ^ e Y O Well Name: 1 C-11 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/20/2008 8:00:00 PM Rig Release: 6/11/2008 9:00:00 PM Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 5/20/2008 2a hrsummarv Complete well 1 D-126. Rig released form 1 D-126 @ 20:00 HRS. Demob & move rig & camp to 1 C-11. 20:00 00:00 4.00 MIRU MOVE MOB P Demob & Move rig from 1 D-126 to 1C - 11. Ri move = 5 miles. 5/21 /2008 Continue move rig to 1C-11. Spot rig. ACCEPT NORDIC RIG 3 THIS DATE 0100 HRS. Bullhead 200 BBLS 9.6 brine in the OA. Load well with 9.6 brine. Set BPV. ND tree. NU BOP's. 00:00 01:00 1.00 MIRU MOVE RURD P Spot rig over 1C-11. RU /prep for well work. AC~C,FPT NORDIC RIG 3 01:00 02:30 1.50 COMPZ WELCTL OTHR P Make u Lubricator. Pull BPV as er FMC rep. Observed Tbg pressure Cc~ 500 psi. IA = 600 PSI and the OA = 350 PSI. 02:30 03:30 1.00 COMPZ WELCTL OTHR P Plumb kill lines to tree. Test same 3000 si. 03:30 07:00 3.50 COMPZ RPCOM OTHR P Load 3-1/2 DP to shed. Rack /tally same while wait on delayed vac trucks. 07:00 10:30 3.50 COMPZ WELCTL CIRC P PJSM, kill well, displace wellbore (tbg & annulus) with 9.6 ppg brine. ICP = 2 bpm - 620 psi, FCP = 4 bpm - 740 psi. Bleed, monitor well. Well static. 10:30 18:00 7.50 COMPZ RPCOM CIRC P PJSM, bullhead 200 bbls 9.6 brine do 7 X 9-5/8 ann. No press rise on IA. Attempt bleed. All brine pumped returning to surface turning to diesel. Shut in. 160 psi on OA. Pump 2nd bullhead do OA at which point press drops and returns now builds press to IA. (Csg hole becomes un I . Cont bullhead OA 200 blls total. Bleed tbg / IA / OA to "0" si. Well static. 18:00 20:00 2.00 COMPZ RPCOM OTHR P Attempt to install BPV. Observed that the OA had 500 PSI. Bleed OA back to pits observing returns almost all diesel, flow slowing to only a small stream. Flowed back 31 BBLS. IA & TBG =dead. Install BPV as er FMC re . 20:00 20:30 0.50 COMPZ RPCOM NUND P Rig down circulating lines. Rig up to take OA returns to Kill tank, monitor returns. Flow steady at a small stream. _ Page 'i of 20 r~ Time Logs _ _ Date From To Dur S. De th E. De th Ph se Code Subcode T Comment 20:30 22:00 1.50 COMPZ RPCOM NUND P Nipple down Tree. Doulble check threads in hanger -good. Obtain pictures of tree for reference of orientation when ni le u a ain. 22:00 00:00 2.00 COMPZ RPCOM NUND P Nipple up BOP stack & lines. Install choke & kill lines. 5/22/2008 Continue NU BOP's & test same. Witness of BOP test waived by AOGCC rep Bob Noble. RU & Pull on 3 1/2" tb .Would not ull free. RU SWS E-line, cut tb at 10250' MD. Pull tb free with 105K u wei ht. 00:00 02:00 2.00 COMPZ WELCTL NUND P Continue Nipple up BOP stack & lines. 02:00 05:00 3.00 COMPZ WELCTL BOPE P Ri u & test BOP's. Test all choke manifold valves, manuals, HCR's & floor valves. Test all equipment to 250 / 2500 PSI as per well plan. Witness of test waived by AOGCC re Bob Noble. 05:00 06:00 1.00 COMPZ WELCTL BOPE P Pull blanking plug, attempt pull BPV, ress build under BPV. 06:00 08:00 2.00 COMPZ WELCTL CIRC P Displace tbg volume with 9.6 brine throu h BPV. 08:00 09:30 1.50 COMPZ WELCTL BOPE P Attem t ull BPV retrieving tool damaged. MU new tool, pull BPV. T on sli ht vacuum. 09:30 10:00 0.50 COMPZ RPCOM PULD P MU Ldg jt, BOLDs. 10:00 14:00 4.00 COMPZ RPCOM PULD P Attempt pull seal assy free from PBR. Work to max pull 190K. Re-tip tbg, work various parameters. Sharp braking on do stroke in attempt to reverb waves to seal assy. Cont work tb while wait on SWS for tb cut. 14:00 16:30 2.50 COMPZ RPCOM RURD P PJSM, RU SWS for tbg cut.Set tbg strin in tension with 50K ulled. 16:30 18:00 1.50 COMPZ RPCOM OTHR P PJSM, RIH string shot on wireline, locate /confirm on depth, shoot string shot 10241 -10253 ft, POH wireline for them cut. 18:00 20:00 2.00 COMPZ RPCOM OTHR P WLOH with string shot assembly, la down same. 20:00 22:00 2.00 COMPZ RPCOM OTHR P Make up Chemical cutter assembly. WLIH to locate cutter at 10250' as planned. Fire cutter. Observed good wireline weight loss ood,indication of ood cut. 22:00 23:30 1.50 COMPZ RPCOM OTHR P WLOH. Notify all personnel to stay clear. Pull and lay down cutter assembly. Cutter indicated complete discharge, good cut. Rig down sheaves and pump in sub with valves. Pull on tbg string observing free travel at 105K u wei ht. Complete rig down of SWS a-line crew. 4~aga 2 zaf 2Q r~ • Time Logs ' Da. e From To Dur S. De th E. De th Phase Code Subcode T Comment 23:30 00:00 0.50 COMPZ RPCOM PULD P Pull and lay down landing joint & hanger assembly with pup. Observed OA still flowing as the 9.8 ppg fluid in_ IA balancing. Shut in OA for full circulation to veri ood 9.8 PPG fluid in wellbore. 5/23/2008 Pull tbg, standing back with SLM. MU Fishing assembly & TIH picking up singles of 3 1/2 DP from shed. 00:00 02:00 2.00 COMPZ RPCOM CIRC P Make up Head pin & valve. Circulate 1 1/2 hole volume to ensure good 9.8 ppg brine balanced in well. Pumps at 4 BPM - 390 PSI. Observed 1600 ,_.-_. units of as on bottoms u .Monitor well -static. Observed OA shut into circulate and built to 120 PSI. 02:00 13:30 11.50 COMPZ RPCOM PULD P Pull 3 1/2" tb standing back in derrick. Spool control line, and obtain SLM on tbg. Drift tbg in derrick when POOH to 2.91" to 500', and then 2.883". Begin lay do corroded / washe cont la out 147 its total for funk. Tot tbg pulled 317 jts, 1 tbg cut off stub 16.60 ft, 1 - ssv, 7 - GLMs, 17 -pups, tbg hgr with pup. Note clean cut on last jt. No losses 120 si ui .Recovered 9 - SS bands to SSSV. 13:30 14:30 1.00 COMPZ RPCOM OTHR P Clear floor, prep for fish BHA. 14:30 15:30 1.00 COMPZ RPCOM PULD P PJSM, load fish tools to pipe shed. Stra / re same. 15:30 16:00 0.50 COMPZ RPCOM OTHR P PJSM, Install bowl protector. 16:00 17:30 1.50 0 315 COMPZ FISH PULD P PJSM, flow check, MU BHA #1 overshot fish ass RIH same 17:30 00:00 6.50 315 10,240 COMPZ FISH TRIP P PJSM, flow check, follow BHA #1 with 3-1/2 DP to 10240' DPM. Observed proper displacement on TIH. Total fluid loss for the day = 41 BBLS. 5/24/2008 Continue jarring operations on seal assembly. POOH. Lay down same. MU BHA #2, with OS extension. TIH, en a e & 'ar fish free. CBU. Monitor well -static. 00:00 03:30 3.50 10,240 10,240 COMPZ FISH JAR P Obtain parameters. UP WT = 160K, SO WT = 85K, ROT WT = 120K with 5K TO. Pump at 4 BPM - 650 PSI. Ta & en a e fish 10240' DPM. Observe full swallow offish. Pull to 50K over to verify catch. Perform jarring operations pulling up to 105K over up weight. Allow jars to fire and continue with straight pull to 275K. Utilize m cb. as 28 P 03:30 04:00 0.50 10,240 10,240 COMPZ FISH CIRC P Displace wellbore with Safe Lube @ 3 BPM - 1350 PSI. Page 3 of 2q ~ Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 04:00 05:30 1.50 10,240 10,240 COMPZ FISH JAR P Resume jarring on fish (3-1/2 tbg stub), pulling up to 150K over up wei ht, with no success. 05:30 07:00 1.50 10,240 10,240 COMPZ FISH OTHR P Release fish, flow check, prep POH for BHA #2 Wash i e ass 07:00 08:00 1.00 10,240 10,240 COMPZ RIGMNT OTHR P PJSM, flow check, slip / cut drlg line. 08:00 13:00 5.00 10,240 315 COMPZ FISH TRIP P PJSM, flow check, POH 3-1/2 DP for BHA #2 13:00 14:30 1.50 315 0 COMPZ FISH PULD P Flow check at BHA, LD BHA #1, ins ect overshot, all com onents. 14:30 16:30 2.00 0 0 COMPZ FISH OTHR P Clear floor, prep for trip. Perform Derrick & top drive inspection after 'arrin o erations. 16:30 18:00 1.50 0 320 COMPZ FISH PULD P MU BHA #2, flow check, RIH same. Total length of BHA # 2 = 320.87'. Note: added washpipe extension to washover fish top to within 2' of liner to . 18:00 20:30 2.50 320 10,174 COMPZ FISH TRIP P TIH with BHA #2 to 10174'. Observed ro er dis lacement. 20:30 21:00 0.50 10,174 10,174 COMPZ RIGMNT SVRG P Service rig &Top Drive. 21:00 22:30 1.50 10,174 10,250 COMPZ FISH FISH P Obtain parameters. UP WT = 140K, SO WT = 100K. ROT WT = 115K with 4K TQ. Line up, rev circulate over top of fish to engage fish with 3 BPM - 600 PSI. Engage fish. Pull to verify good catch to 50K over. Work string to fire jars to 100K over. Continue to 125K over firing jars to observe pulled free. Work string attempting to verify seals going back into seal bore, or passing through top of liner. Pump pressure -same, with no good indication of pressure up as we had a plain control in the fishing BHA. 22:30 23:30 1.00 10,250 10,250 COMPZ FISH CIRC P Circulate bottoms u at 4 BPM - 750 PSI. Observed no oas. Monitor well - static. 23:30 00:00 0.50 10,250 10,108 COMPZ FISH TRIP P Blow down Top Drive, POOH with BHA #2 from 10108'. UP WT = 140K, SO WT = 100K. 5/25/2008 POOH with BHA #2 & fish. MU & run &" scraper asssmy. POOH. MU & run retrievable bridge plug & test acker to 2932". 00:00 05:15 5.25 10,108 320 COMPZ FISH TRIP P Continue POOH with BHA#2, and fish from 10108' - 320. Observed ro er dis lacement. 05:15 06:30 1.25 320 0 COMPZ FISH PULD P Breakout & lay down BHA #2, and fish. Total length recovered 24.23'. Recov r 1 1.00' D nipple, 6.09' Pup, and 1.44' of the loca .The pin parted in the bottom of the locator. Left in hole approx 46' of tube & seal ass mbl Page 4 rsf ZC1 s r Time Logs Date From To Dur S De th E. De th Ph Code Subcode T Comment i 06:30 07:30 1.00 0 0 COMPZ FISH OTHR P Clean & clear rig floor. Pull tools to floor for next run, 7" casing scraper assembl . 07:30 09:00 1.50 0 317 COMPZ FISH PULD P PJSM, MU BHA #3 (7 in Scraper / Clean out Ass , RIH same. 09:00 12:30 3.50 317 10,260 COMPZ FISH TRIP P Flow check, follow BHA with 3-1 /2 DP to tag TOL at 10,260 ft. PU 2 ft, re for circ. 12:30 16:00 3.50 10,260 10,260 COMPZ FISH CIRC P Flow check, begin circ well clean 8 bpm - 2565 psi. Rev circ hole vol. Scale to shakers first half circulation. Circ conv, addtnl scale to shakers. Rev circ final hole volume. Shaker clean. 16:00 20:00 4.00 10,260 300 COMPZ FISH TRIP P Flow check, OA continued slow bleed. POH 3-1/2 DP 20:00 21:00 1.00 300 0 COMPZ FISH PULD P Rack Back drill collars. Breakout & la down scra er BHA #3 21:00 22:00 1.00 0 0 COMPZ FISH OTHR P Clean & clear rig floor. Send toots out, pull bridge plug & test packer to ri floor. Stra same. 22:00 00:00 2.00 0 2,932 COMPZ RPCOM PULD P Held PJSM. Make up BHA #4. BOT Retrievable bridge plug & test packer i assembl . TIH with BHA #5 to 2932' DPM. UP WT = 65K, SO Wf = 60K. Observed proper displacement. Total fluid loss for the da = 124 BBL 5/26/2008 Continue run BP & test PKR. Set & test/ Test to locate casing leak @5465' - 5467'. POOH. POOH to surface, decision to re osition RBP 6000' TIH with retrievin tool to 3786'. 00:00 04:30 4.50 2,932 10,200 COMPZ RPCOM TRIP P Continue trip in hole with BHA #4, Retrievable bridge plug & test PKR assembly to locate & set BP at 1020 ' 04:30 06:00 1.50 10,200 10,089 COMPZ RPCOM DHEQ P Release from bridge plug, pull up hole one stand. Rig up and test BP & casin to 2500 PSI as planned. UP WI' = 130K DN WT = 95K. Rig up & Establish OA injection rate @ 1 BPM - 720 P I. Bleed pressure. Rig down lines. Release test PKR. Record tests on chart. 06:00 07:30 1.50 10,089 10,089 COMPZ RIGMNT SVRG P Held PJSM. Rig up. Slip & cut 84' drillin line. Service ri . 07:30 17:30 10.00 10,089 5,043 COMPZ RPCOM DHEQ P PJSM, flow check, POH, commence test cs for leak de th. Test 7" csg at 5043, 5335, 5431, 5501, 5511, 5528, 6013, 10089. Final d rm' 1 i 6 - 5467 All ood tests 2500 si / 10 17:30 21:00 3.50 5,043 0 COMPZ RPCOM TRIP P PJSM, POOH to surface. 21:00 00:00 3.00 0 3,786 COMPZ RPCOM TRIP P Decisin to reposition RBP at 6000' MD for sand plug & cement sgeeze 'ob. TIH with RBP running tool. Total fluid losses for the da = 171 BBL Page 5 0{ Z#7 • Time Logs Date From To D r S. De th E. De th Ph e Code Subcode T Comment 5/27/2008 za hr summary Retrieve RBP and set at 6000'. Drop 100' of sand on top of RBP. Schlumberger mixed 11.5 bbl with 2300# of sand slurry (100' of sand plug inside the 7" casing). Pumped 11.5 bbl of slurry followed by 3 bbl of gel. DP displacement is 43 bbl. Rig displaced DP with 37 bbl of 9.8 brine, POOH 10 stands pumped 5 bbl down the DP. POOH 5 more stands and reverse circ 70 bbl. Rig up & pressure test to 2500 PSI. Make up & Run cement retainer to 4088' DPM 00:00 04:00 4.00 3,786 10,200 COMPZ RPCOM TRIP P Continue TIH with RBP retrieving tool to retrieve RBP @ 10200' DPM. Observed ro er dis lacement. 04:00 04:30 0.50 10,200 10,200 COMPZ RPCOM OTHR P En a RBP 102 '. I o release RBP. Monitor ell -static. 04:30 06:00 1.50 0 COMPZ RPCOM CIRC P Circulate bottoms up at 3 BPM - 400 PSI. Observed 100 units of gas on bottoms u .Monitor well -static. 06:00 08:30 2.50 10,200 6,004 COMPZ RPCOM TRIP P POOH with RBP from 10200' to locate 6000' DPM'. 08:30 09:00 0.50 6,004 6,004 COMPZ RPCOM OTHR P Set RBP (a~ 6004', set PKR ~ 5916'. PT to 2500 esi. Release PKR. UP WT = 90K, SO WT = 77K. 09:00 12:00 3.00 6,004 0 COMPZ RPCOM TRIP P POOH and lay down test PKR & settin tool. 12:00 14:00 2.00 0 5,840 COMPZ RPCOM TRIP P MU and RIH with mule shoe and RIH with drill i e to 5840' DPM. 14:00 15:00 1.00 5,840 4,285 COMPZ RPCOM OTHR P Held PJSM. Schlumberger mixed 11.5 bbl with 2300# of sand slurry (100' of sand plug inside the 7" casing). Pumped 11.5 bbl of slurry followed by 3 bbl of gel. DP displacement is 43 bbl. Rig displaced DP with 37 bbl of 9.8 brine, POOH 10 stands pumped 5 bbl down the DP. POOH 5 more stands and reverse circ 70 bbl. Rig up & ressure test to 2500 PSI. 15:00 16:30 1.50 4,285 4,774 COMPZ RPCOM CIRC P POOH with DP and mule shoe from 5840' - 4774'. Pump 5 BBLS to clear drill string. Rig up & reverse circulate 2 drill string volumes at 3 BPM - 220 PSI. UP WT = 75K, SO WY = 70K. 16:30 18:00 1.50 4,774 0 COMPZ RPCOM TRIP P POOH to surface & lay down mule shoe. 18:00 18:30 0.50 0 0 COMPZ RPCOM OTHR P Clean & clear rig floor. Pull tools to ri floor. 18:30 00:00 5.50 0 4,088 COMPZ RPCOM TRIP P Held PJSM. MU BOT K-1 snap latch settin tool & cement reatiner. Trip in hole @ 90 seconds /stand as per BOT rep. Total fluid loss for the day = 79 BBLS: ~+~ge 6 of 20 Time Logs ~ ! D From To Dur 5 Depth E. Depth Phase Code Subcode T Comment ~ 5/28/2008 zahrsummarv Set cement retainer @5400' MD & perform cement sgeeze. Set Cement retainer on depth as planned @ 5400' DPM. Establish injection rate through the 7" casing leak at 1 BPM - 950 PSI. Rig up and perform test on annulus to test retainer pressure to 2500 PSI - 5 minuntes. Good test. Release from retainer, pull stinger above to verify free movement. Sting back into cement retainer. UP WT - 85K, SO WT = 73K. RU to OA and pump 160 bbl of freeze protect diesel down OA @ 2 bpm. Initial injection press 1600 psi. Injection press after 160 bbl 2050. SI OA press 1275 psi. With Schlumberger & crew. Mixed and pumped 62 bbl of 15.8 ppg class "G" cement. Displaced 40 bbl of cement behind casing. SI OA pressure 370 psi. Open OA pumping 1.5 bpm down the DP taking returns up the OA at 1.3 bpm. OA was choked at 1030 psi and pump press 730 psi. After 15 bbl of returns the OA was SI and DP was displaced with 1 bbl of cement remaining in the DP. SI pressures DP/OA = 670/990 psi. Pull out of retainer. and displace remaining 1 bbl of cement out of the DP. CIP @ 0730 HRS. Pulled up 1 stand and reverse circulated 2 DP volumes. POOH, MU drilling assembly. WOC - 4 HRS. Tag & drill cement retainer, no cement on top. Tag & drill hard cement from 5414' - 5468'. Wash & ream to 5541'. Pump 35 BBLS sweep. Tested 7" packoff to 3000 psi held for 15 min. Witnessed by Co-Man. 00:00 01:30 1.50 4,088 5,400 COMPZ RPCOM TRIP P Continue trip in hole with BOT cement retainer. Locate to set at 5400' DPM. 01:30 02:30 1.00 5,400 5,400 COMPZ RPCOM DHEQ P Establish circulation and pump drill string volume as per BOT rep at 3 BPM - 300 PSI. Set Cement retainer on depth as planned @ 5400' DPM. Establish injection rate throu h the 7" cesin leak a 1 BP - 0 P I. Ri u and erfomt test on annulus to test retainer ressure to 2500 PSI - 5 minuntes. Good test. Release from retainer, pull stinger above to verify free movement. Sting back into cement retainer. UP WT - 85K, SO WT = 73K. 02:30 05:00 2.50 5,400 5,400 COMPZ RPCOM FRZP P Held PJSM with AES reps & crew, RU to OA and pump 160 bbl of freeze rotect diesel down OA 2 b m. Initial injection rate 2 BPM press 800 si. Injection ress after 160 bbl 1550. SI OA ress 1275 si. 05:00 09:00 4.00 5,400 5,400 COMPZ CEMEN" DISP P Spot & rig up Dowell cementers. Held PJSM with Schlumberger & crew. Pressure test lines to 3000 PSI. Mixed and pumped 5 BBLS H2O, 62 bbl of 15.8 ppQ class "G" cement 5 BBLS H2O. Displaced 40 bbl of cement behind casin SI OA ressure 370 si. O en OA um in 1 m down the DP r u the OA at 1.3 b m. OA was choked at 1030 si and um r 7 After 15 bbl of returns the_ OA was SI and DP was displaced with 1 bbl of cement remaining in the DP. SI pressures DP/OA = 670/990 psi. Pull out of retainer and displace remaining 1 bbl of cement out of the DP. Pulled up 1 stand and reverse circulated 2 DP volumes. 09:00 11:30 2.50 5,400 0 COMPZ CEMEN" TRIP P POOH with retainer stinger. Lay down retainer stin er. Page 7 of ZO ~~ Time Logs Date From To Dur S. D th E. D th Pha e Code Subcode T Comment 11:30 12:00 0.50 0 312 COMPZ RPCOM PULD P MU drillout assembl and RIH to 5315'. Total BHA len th = 312'. 12:00 14:00 2.00 312 5,320 COMPZ RPCOM WOC P TIH with BHA #6 to 5320' DPM, while waitin on cement. 14:00 18:00 4.00 5,320 5,320 COMPZ RPCOM WOC P WOC after casing squeeze job. 18:00 21:30 3.50 5,320 5,402 COMPZ CEMEN" DRLG P RIH to to retainer (a~ 5400' DPM. Observed no cement on t~ of ply. Continue drill out retainer to 5402'. 24 hr notice to AOGCC for weekly BOP test John Cris 21:30 22:00 0.50 5,402 5,402 COMPZ CEMEN" CIRC P Pump 35 BBLS Hi-Visc sweep around observing good cement returns. 22:00 23:30 1.50 5,541 5,541 COMPZ CEMEN" DRLG P Chase plug to tag hard cement at 5414'. Continue drill hard cement from 5414' - 5468', then stringers to stop at 5541'. UP WT = 90K, SO WT = 78K, ROT WT = 83K with 3K TO. 23:30 00:00 0.50 5,541 5,541 COMPZ CEMEN' CIRC P Pump 35 BBLS Hi-Visc sweep around observing good cement returns. Total Fluid loss for the day = 28 BBLS 5/29/2008 Test 7" casing to 3500 PSI. Observed leak from 3500 1750 PSI in 30 minutes. POOH, Perform weekly BOP test. Test witnessed by AOGCC rep John Crisp. Observed Koomey test, first 200 PSI in 15 seconds, with full pressure in 1 min, 30 seconds. 4 Nitrogen bottles average pressure = 2100 PSI. RIH with dring assembly and clean out sand (/5,534' to 5,990'. POOH for RBP model L retrievin head. 00:00 00:30 0.50 5,541 5,541 COMPZ CEMEN' CIRC P Continue circulate 35 BBL sweep observing good cement returns to surface. 00:30 03:00 2.50 5,541 5,541 COMPZ RPCOM DHEQ P Ri u to test. OA = 1400 PSI. Pum down DP to test 7" casina to 2500 PSI. Shut in, observe ressure drop to 1700 PSI in 15 minutes. OA went from 1400 to 1750 PSI. Bleed all ressures. Re-test with same results. Bleed OA from 1400 - 500 PSI. RU to isolate, and pressure to 3500 PSI fora 30 minute test, with pressure drop to 1750 PSI. OA went from 500 PSI to 850 PSI, and pressure dropped along with IA pressure. Recorded all tests on chart. Bleed pressures, monitor well -static. 03:00 06:00 3.00 5,541 0 COMPZ RPCOM TRIP P POOH with drilling assembly from 5541- surface. 06:00 07:00 1.00 0 COMPZ RPCOM PULD P Breakout & lay down drilling assembly. Grade & inspect bit. Grade At 5-2-LT-NM-E-1-BT-BHA 07:00 09:00 2.00 0 5,163 COMPZ RPCOM TRIP X MU muleshoe on drillpipe and RIH to 5163'. Change of plans and availablili of cement. 09:00 10:30 1.50 5,163 0 COMPZ RPCOM TRIP X POOH with drillpipe and muleshoe from 5163'. 3 hr notice to AOGCC for week) ROPE test John Cris .Page ~ of 2D Time Lcgs D e From To Dur 5. De th E De th Ph e Code Subco e T Comment _ 10:30 15:30 5.00 0 0 COMPZ WELCTI BOPE P PressureTest BQPE including Annular 250/2500 psi. Witnessed by AOGCC (John Crisp). Pull test plug and install wear ring. Observed Koomey test, first 200 PSI in 15 seconds, with full pressure in 1 min, 30 seconds. 4 Nitrogen bottles averse ressure = 2100 PSI. 15:30 18:30 3.00 0 5,534 COMPZ RPCOM TRIP P MU drillou ,RIH on 3 1/2" drill i e to 5,534'. 18:30 20:30 2.00 5,534 5,900 COMPZ CEMEN" DRLG P MU TD and wash dwn f/5,534' to 5,545', up wt 100K, dwn wt 75K, and drill cement stringers f/ 5,545' to 5,900', pumping @ 10 bpm, 2,400 psi, on bottom torque 3,810 ft Ibs, off bottom for ue 3,750 ft Ibs. 20:30 21:00 0.50 5,900 5,990 COMPZ DRILL CIRC P Ta sand at 5 900', wash dwn @ 1/2 bpm and 20 rpm to 5,905', increase pump rate to 8 bpm 0 rpm and wash dwn to 5,910', increased to 40 rpm 8 bpm 1,750 psi and wash dwn f/5,910' to 5,990'. 21:00 22:00 1.00 5,990 5,990 COMPZ RPCOM CIRC P Pumped 35 bbl Hi-Vis sweep and circ hole clean at 8 bpm 1,750 psi. Observed clean returns on shakers after considerable amount of sand recoverd. 22:00 23:00 1.00 5,990 5,990 COMPZ RPCOM CIRC P Dropped 1 7/8" ball to open BOT POS, RU and reverse circ DP volume 3x at 5 bpm 730 psi. Observed clean returns at shakers. 23:00 00:00 1.00 5,990 5,045 COMPZ RPCOM TRIP P Monitor well f/15 min (static), and POOH f/ 5,990' to 5,045'. Total fluid loss for the da -79 bbls. 5/30/2008 RIH w/model L retrieving head and engage RBP. POOH.Lay down RBP. RIH with 55 studs 3 1/2" tubing f/ derrick and POOH to 3,845' L/D same. 00:00 02:00 2.00 5,045 301 COMPZ RPCOM TRIP P Continue POOH with BHA #7 to BHA. 02:00 03:30 1.50 301 0 COMPZ RPCOM PULD P Rack back drill collars, break out & lay down boot baskets. Grade bit at 5/2/LT/NM/E/1/BT/BHA Clean boot baskets, recovered approx 2 Ibs of iron & sand. Clean & clear rig floor area. 03:30 05:00 1.50 0 0 COMPZ RIGMNT SVRG P RU, hang blocks & slip & cut 84' of drillin line. 05:00 05:30 0.50 0 17 COMPZ RPCOM PULD P Make u BOT K1 retrieving tool with_ 'unk baskets. Total BHA length = 17.66'. 05:30 09:30 4.00 17 5,990 COMPZ RPCOM TRIP P TIH with BHA #8, to top of sand at 5990' DPM. Clean sand and trash off top of RBP. Latched onto and released RBP; Work up and down to confirm. 09:30 10:30 1.00 5,990 5,990 COMPZ RPCOM CIRC P Circulate hi-vis sweep @ 6 BPM 950 si. SD, monitor well, static. Page ~ t~~ 24 Time Logs D to From To Dur S. D th E. De th Phase Code Subcode T Comment i 10:30 16:30 6.00 5,990 0 COMPZ RPCOM TRIP P Start POOH with RBP hanging up eve 40' workin free and continue to uIIL broke free at 4000' +/_„_. , Continued to POOH to surface, drained stack. Pulled RBP up to wear ring and hung up. BOLDS on wear ring. Pulled RBP, ND and laid down. Three large pieces of cement retainer on to of tools but no si tr in 16:30 19:00 2.50 0 0 COMPZ RPCOM RURD P Installed new wear ring, cleared rig floor, moved 4 3!4" DC's to drillers side derrick, RU to run tubing from derrick. 19:00 22:00 3.00 0 5,292 COMPZ RPCOM TRIP P RIH with old 3 1/2" tubing from derrick to 5,292'. 22:00 00:00 2.00 5,292 3,845 COMPZ RPCOM TRIP P POOH, LD 45 jnts 31/2" tubing and off load from i eshed. No fluid loss. 5/31 /2008 LD 3 1/2" tubing from derrick, PU RIH w/FHL-PBR assembly and set at 10,260'dpm, POOH to 6,032' LD 3 1/2" DP and stood remainder in derrick, serviced ri . 00:00 03:30 3.50 3,845 0 COMPZ RPCOM TRIP P Cont POOH and LD 3 1/2" tubing f/ 3,845'. 03:30 04:00 0.50 0 0 COMPZ RPCOM RURD P Clear pipeshed and rig floor, prep to run FHUPBR assembl . 0 108 COMPZ RPCOM PULD P PJSM, PU and MU WLEG assembly, 1 jnt 3 1/2" EUE, D nipple, 1 jnt 3 1/2" EUE and FHUPBR assembl . 04:00 12:30 8.50 108 10,185 COMPZ RPCOM RCST P MU X-O and continue to RIH w/ 3 1/2" DP from derrick to 10,185'. Up wt 155K, down wt 80K. 12:30 14:30 2.00 10,185 10,260 COMPZ RPCOM CIRC P Reverse circulate to est. rate @ 3 PPM @ 450 psi. Lowered in hole taaaed too of 5.5" liner lad 10.254' and to ed to r Pumped down backside to est. rate 1 BPM @ 850 psi. SD pump, held 650 psi. Bled off. Picked up out of liner top to 10,253'. Pumped 200 bbls brine w/1 % by volume CRW 132 Corrosion Inhibitor. Chased with 110 bbls 9.8 brine to s of from 10 254' to 5000' +/-. Top of PBR = 10,154'. 14:30 15:30 1.00 10,260 10,260 COMPZ RPCOM PACK P Broke connection, dropped ball & rod. MU connection. Lowered back down to 10.260,• Wait 30 min. for ball to drop. PU 3000 psi to set packer, wait 10 minim bled pressure to 1000 si. Picked U 145K PU to 2000 si Pulled 155K sheared out of PBR. Bleed off ress. 15:30 20:00 4.50 10,260 6,032 COMPZ RPCOM PULD P POOH laying down 120 jts of 3 -1/2' drill i e. 20:00 23:30 3.50 6,032 0 COMPZ RPCOM TRIP P Cont POOH racking in derrick, LD FHL runnin tool. Pa€Je 1 fl of Zt1 r~ Time Logs D to From To Dur 5. De th E. De th Ph e Code Subco T Comment 23:30 00:00 0.50 0 0 COMPZ RIGMNT SVRG P Service Top Drive, PJSM on RIH w/Storm Packer. 6/01 /2008 RIH w/Storm Packer to +/- 5,700' and test 7" csg and FHL assembly to 2,500psi f/30 min on chart. Good test. OA=0psi during test, POOH and run 5 1/2" scab liner, w/CPH and 3D packers, RIH to locate and attempt setttin 3D packer. Observed packer would not set, repeat attempt with no success,. POOH, inspected packer at surface, observed setting slips missing and packer was egg'd and damaged. Took pictures and placed on "S"drive, discussed options with town and decision was made to RIH w/reverse circ 'unk basket to fish sli se ments. MU reverse circjunk basket and RIH to 302'. 00:00 01:00 1.00 0 0 COMPZ RPCOM PULD P PU " r trievamatic storm ck r, break off storm valve section. 01:00 03:30 2.50 0 5,700 COMPZ RPCOM TRIP P RIH with storm acker on 3 1/2" DP_ from derrick, to 5 700'd m. 03:30 03:45 0.25 5,700 5,700 COMPZ RPCOM SFTY P PJSM on RU and test csg and FHL assembl . 03:45 04:30 0.75 5,700 5,700 COMPZ RPCOM SIPB P RU and test 7" cs and FHL assembl at 2,500 psi f/ 30 min on chart. Load 3 1/2" EUE in i eshed. 04:30 08:30 4.00 5,700 0 COMPZ RPCOM TRIP P POOH w/ 7" storm acker. 08:30 13:30 5.00 0 5,517 COMPZ RPCOM PACK P Pull wear ring. PJSM. MU Baker 7" x 5.5" 3D liner hanger packer, 2 jts 5.5", 15.5#, L-80 Hydril 563 casing and 7" x 5.5" CPH liner hanger packer. RIH on 3 1/2' drillpipe workstring. Stradle hole in casing with liner, (top of liner Cad 5413' and bottom 5517' . 13:30 15:30 2.00 5,517 5,517 COMPZ RPCOM PACK T Attempted to set 3D liner hanger Sat down 40K. Circulated by packer, would not test. Worked pipe trying to transfer weight, sat down max weight available (50K) could not get packer to packoff. Closed annular, pumped down annulus, pressured to 2500 psi to assist weight transfer. Attempted to testa ain still wo I Pulled 150k (45K over) and released packer hanger. PU 5', attempted to reset, would not reset. 15:30 19:00 3.50 5,517 0 COMPZ RPCOM TRIP T POOH with scab liner, standing back drillpipe. No slip dies or straps remainin on the 3D liner han er and hanger section was a 'd above the cone section. 19:00 21:00 2.00 0 0 COMPZ RIGMNT WOOR T Service Top Drive, cunt load 31/2" EUE in i eshed, while WOO. 21:00 23:00 2.00 0 0 COMPZ FISH WOEQ T Load pipeshed w/ 3 1/2" DP. 23:00 00:00 1.00 0 316 COMPZ FISH PULD T PU and MU BHA #11, 6 1/8" reverse circjunk basket, bumper/oil jar, and 4 3/4" DC's. 6/02/2008 R&T 120jnts 3 1/2" DP, PU 6 1/8" reverse circjunk basket and RIH, recovered one set of slips w/ strap, RIH w/ 6" magnet on slickline while waiting on caliper batteries, retrieved only metal shavings, performed Casing Cali er to on 7" cs . 00:00 05:00 5.00 316 10,154 COMPZ FISH TRIP T RIH with BHA # 11and 66 studs 3 1/2" DP from derrick, PU 120 juts and sin le in hole to 10,154'. f~~gc 11 ~rf Zi} Time Low D e From To Dur S. De th E. De th Pha e Code Subcode T Comment 05:00 06:00 1.00 10,154 10,154 COMPZ FISH CIRC T Obtained parameters with 150K up 90K down. Rot wt 110K 20 RPM, 4000 torque. Pumped @ 94 SPM (230 gpm) 1900 psi. Worked drillstring down close to PBR, tagged on depth 2 @ 10,154'. Repeat steps 5 times attempting to wash junk up into junk basket. NOTE: Ball was ran in place on reverse circulating junk basket. 06:00 10:30 4.50 10,154 0 COMPZ FISH TRIP T Crew change, POOH standing back drillpipe and LD Rev. Junk basket. Retrieved 1 slip from CPH acker and half 1/3 cu of metal chunks from Cement Retainer. 10:30 14:00 3.50 0 0 COMPZ FISH OTHR T Clean rig floor. Change dies in Grabber on Top Drive. RU slickline and PDS Caliper Log. Battery failure on to in tools. 14:00 15:00 1.00 10,154 0 COMPZ FISH SLKL T MU 6" magnet on slickline and RIH while waiting on PDS tools. Ran ma net to 10,154'. POOH, em tied ma net. Retrieved onl metal shavin s, no sli s. 15:00 00:00 9.00 10,173 0 COMPZ EVALWE OTHR T MU PDS Casing Caliper Logging tools on slickline and RIH. Ran PDS casin tali er from 10,173' to surface at 50 f m. Waited on caliper fingers to close, POOH and RD slickline. 6/03/2008 Ran Casing caliper Log. Slip and cut drill line. Rih w/ RCJB to 10,154' and function. Pooh and RCJB was empty. MU retrieving tool for FHL Pkr. Rih w/ BHA to 10,125'. Pump 200 bbls 9.8 brine w/ 1% by vol. CRW 132 corrosion inhibitor and spot from 5,100' to 10,125'. Engage PBR and FHL pkr and shear release. Pooh to 10,100'. Shear out um out sub. 00:00 00:30 0.50 0 0 COMPZ EVALWE PULD T RD slickline, LD tool. Sent caliper data to Houston. 00:30 02:30 2.00 0 0 COMPZ RIGMNT SVRG P Slip and cut drill line, install wear ring, calibrate lotto w/top drive and check crown saver. 02:30 08:00 5.50 0 10,154 COMPZ FISH TRIP T PU and RIH with BHA # 13 (reverse circ junk basket) on 31/2" DP from derrick at 90f m, ball in lace. 08:00 08:30 0.50 10,154 10,154 COMPZ FISH CIRC T Obtained perameters. Up wt 150K dwn wt 90K , Est.circuation 5.5 bpm @ 1900 psi. Rot 20 RPM. Free torque 4180 ,Rot wt 115k. Washed down with Reverse Junk Basket , tagged lightly fad 10.154'. Worked up and down, tagged 5 times. Surged pump 3 times trying to suckup slips se ments and an other debris. 08:30 15:00 6.50 10,154 0 COMPZ FISH TRIP T POOH standing back 3 1/2"drillpipe. Stand back 9 drill collars, LD Reverse Junk Basket and clean out. Nothing recovered in junk baske ~" emt Pane 12 ct ~{a Time Logs Da From To Dur S De th E. De th Phase Code Subcode T Comment I 15:00 18:30 3.50 0 331 COMPZ FISH TRIP T MU retrieving tool and Pump Out Sub for PBR,and FHL packer and RIH. Load pipe shed with 122 jts 5 1/2" 563 H dril, stra and drift. 18:30 22:00 3.50 331 10,125 COMPZ FISH TRIP T Rih w/ dp f/ 331' to 10,125' 165k up wt, 93k do wt. 22:00 23:00 1.00 10,125 COMPZ RPCOM CIRC P Pump 200 bbls 9.8 brine w/ 1 % by vol. CRW132 corrosion inhibitor @ 4 bpm @ 700 psi. and follow w/ 38 bbls 9.8 brine to displace and spot corrosion inhibited fluid @ 5,100' to 10,125'? 23:00 00:00 1.00 10,125 10,100 COMPZ FISH FISH T En a e PBR and FHL Pkr~a 4;. Set 10k down and pull 15k OSW of 165k. Set 20k down and pull to 20k OSW and allow jars to bleed. Pull to 225k (60k OSW) and shear out FHL Pkr. Let kr relax. POOH 50' and drop ball and rod and let fall. Pressure to 2,050 psi and shear out um out sub. 6/04/2008 Pooh w/ FHL Pkr. Recovered remaining lost Baker 3D PKR slips in PBR. Lay down fishing assy. Change lower pipe rams to 5 1/2 and conduct weekly BOPE Test. Notified AOGCC @ 04:45 on 6-4-08 and witness was waived b Chuck Scheve 05:00 hrs on 6-4-08. Rih w/ 5 1/2 563 h dril scab liner to 3,276' 00:00 07:30 7.50 10,100 0 COMPZ FISH TRIP T Pooh w/ FHL Packer assy f/ 10,100'. 07:30 09:30 2.00 0 COMPZ FISH PULL T Stand back drill collars, LD BHA, BR. FHL and tail assembly. Two sli se ments from the failed Baker 3D packer came out in bottom of the PBR. ND all fishing tools and load out. 09:30 16:30 7.00 COMPZ WELCTL ROPE T Chan a lower iae rams from 3 1/2" to 1/2". Test BOPE including annular to 250/2500 psi. (Weekly test due within 24 hrs). Witnessing waived by AOGCC (Chuck Scheve). Finished loading pipe shed with 5 1/2" 563 Hydril, drifting and stra in . 16:30 00:00 7.50 0 3,276 COMPZ CASING RUNL T Be in runnin 5.5" 563 H dril scab liner ass to 3 276' 6/05/2008 Continue to Rih to 5,097' w/ 5 1/2 scab liner and carry in on DP to 8,187' and started to take wt. Pull up to 8,096' and hung up. Not able to work down. Call Anc. Release of liner w/ top @ 2,999' and Bottom @ 8,096'. Pooh w/ Running tool. MU spear assy and Rih to 2,999'. Engage @ 3,012'. Jar on fish up to 65k osw of 135k - 20x's. Releases ear and disen a e. 00:00 03:00 3.00 3,276 5,100 COMPZ CASING RUNL T Continue to Rih w/ 51/2, 15.5# 563 Hydril Scab Liner from 3,276' to 5,100' 03:00 09:30 6.50 5,100 8,261 COMPZ CASING RUNL T Continue to Rih w/ 51/2, 15.5# 563 Hydril Scab Liner from 5,100' on 3 1/2 DP to 8261'. Started taking weight. PU free to 8187'. Up wt 135K down 85K. I''ac;e 13 €~f Z£b n Time Logs Date From To D r S. De th E. De th Ph Code Subcode T Comment 09:30 10:30 1.00 8,261 8,187 COMPZ CASING CIRC T Top drive up, est circulation 1 BPM @ 80 psi. increased to 2 BPM 450 psi. SD pump, bleed pressure to 0. Open bleeder, Set down @ 8187' took 10K. 10:30 12:00 1.50 8,187 8,096 COMPZ CASING OTHR T POOH f/8187' to 8096'. Hun up. ulled 150K Set down to 75K. 12:00 13:00 1.00 8,096 8,096 COMPZ CASING OTHR T Top drive up, atttempted to circulate, press came up to 1050' no circulation SD pump. Pulled 170K up slacked off to 65K setting 10K on it. Let set, liner not falling down hole, sta sin lace. 13:00 14:30 1.50 8,096 8,096 COMPZ CASING WOOR T Discuss options with Engineering. Decision made to release from Liner and fish out with s ear. 14:30 16:00 1.50 2,999 0 COMPZ CASING OTHR T Turn 15 rounds to the right. PU and confirm released from Liner assembly. Left liner assembly top @ 2999' and bottom 8096'. POOH with drillpipe and running tool from 2999'. 16:00 18:30 2.50 0 COMPZ CASING WOEQ T Wait on fishing tools to be delivered 18:30 20:00 1.50 0 331 COMPZ FISH PULD T MU and Rih w/ S ear ass to fish 5.5" Scab liner ass . 20:00 22:00 2.00 331 2,999 COMPZ FISH TRIP T Rih w/ Spear assy on 3 1/2 DP f/ 331' to 2,999'. 73k u wt, 65k do wt. 22:00 00:00 2.00 2,999 3,012 COMPZ FISH JAR T PJSM, conduct pre jar derrick inspection. Engage and pull 15k OSW. set down 15k. Not able to en a e as dee as wanted. Call Baker Supervisor and Anc -discuss options. Pull 15k ows of 135k, let jars bleed and straight pull to 200k 65k osw then to 275k, 140k osw. No movement. Be in 'arrin on fish 45k - 5x's and 65k -15x's osw then dead pulling to 275k. No movement. Release S ear and disen a e from fi h. 6/06/2008 Conduct post jarring derrick inspection. Pooh w/ Spear assy and MU Multi string cutter assy. Rih t/ 3,036' and make cut. Pooh and inspect cutter - no cut. Change knives, Rih to 3,036' and re-cut. Pooh and confirm cut. Rih w/ spear assy to 3,023' and jar on fish. Hydrualic fish free. Pooh to Spear assy BHA. No Fluid losses. 00:00 02:00 2.00 3,012 2,999 COMPZ RIGMNT OTHR T Post jarring derrick inspection 02:00 03:00 1.00 2,999 331 COMPZ FISH TRIP T Pooh w/ spear assy f/ 2,999' t! 331' 03:00 04:00 1.00 331 0 COMPZ FISH PULD T Pooh w/spear BHA and lay down s ear. 04:00 05:00 1.00 0 282 COMPZ FISH PULD T PU and MU Multi s ring~~tt,~aysy and Rih w/ BHA to 282'. Crew chan e. Pays 1~t of 20 l Time Logs Date From To Dur S. De th E. De th Pha e Code Su6code T Comment 05:00 07:30 2.50 282 3,090 COMPZ FISH OTHR T Rih w/ Multi string cutter assy f/ 282' to 2999'.Located 5 1/2" collar on bottom of Hanger Packer @ 3020'. RIH to 3036' inside of 51/2" liner 16' below collar. TD up and pump 3.5 BPM @ 600 psi to kick out blades on cutter, torq 1200 off bottom 1430 while attemting to cut. Attempted to cut no dro in ressure. After 30 lowered string and thinking we were pushing liner down. Stopped @ 3090'. PU to 3036' again to confirm cut umped 1 BPM @ 80 psi, and pulled 15K over. SD pump POOH. 07:30 09:30 2.00 3,090 0 COMPZ FISH TRIP T POOH with cutter assembly. Inspect cutting tool. No signs of wear or cu marks n bla .Replace blades. 09:30 13:00 3.50 0 3,036 COMPZ FISH OTHR T Installed Wear Ring. RIH w/Multi String cutter assy from 0' to 3020'. Located 5 1/2" collar on bottom of Hanger Packer again. Lowered down to 3036'. Pumped 5 BPM w/1330 psi. Torque 1200 RPM 60. Rotated & pumped for 20 min. Torque up to 1700 at cutting ,lost 500 psi and torque dropped down to 1300. Rotate & pump another 5 min. to make sure of good cut. Slowed pump to 1 BPM 150 psi to keep blades out and attempt to lower to confirm liner fell. Stacked out immediate) uttin 15K wt down. Attem ted to PU and ~.~.i~, Liner Han er was loose b are to eyed and retracted up inside liner, ressure increased to 1500 psi to confirm this. SD pump, bleed ressure. 13:00 15:00 2.00 3,036 0 COMPZ FISH OTHR T POOH from 3036' to 0'. -nspect cutting tool. Good indi tions that the cut was successful. Break out cutting tool. MU 5 1/2" spear assemb . 15:00 17:30 2.50 0 3,023 COMPZ FISH TRIP T RIH with spear assembly to 2939' TD up 70K up wt 63 dwn wt. Lowered to 3010' engaged liner top. PU to 200K pump on @ 800 PSI 5 BPM. No movement. SD um .Jarred fish 17:30 19:00 1.50 3,023 2,995 COMPZ FISH JAR T Jar o Pkr anrt HMC:, Liner Hanger 62x's w/ no movement. Begin to circulate and pressure up to 3,123 psi @ 5 bbls pumped and H drualic release han er free. 19:00 20:00 1.00 2,995 2,995 COMPZ FISH OTHR T Inspect rig crown sheeves and drum wra s. 20:00 00:00 4.00 2,995 322 COMPZ FISH TRIP T Pooh w/ fish from 2,995' to 322' Pag€~ 15 ~,f 2Q r-~ ! Time Logs _ Date From To Dur S. Depth E. Depth Ph~„se Code Subcode T Comment 6/07/2008 z4 hr Summary Pooh w/ fish and break down fishing assy. Slip and cut drill line. MU Spear assy and Rih to 5,191' and en a e fish. Pooh f/ 10,244' t/ 5,064' w/ DP and be in la in down 5 1/2 liner to 2,574'. 00:00 02:00 2.00 322 0 COMPZ FISH PULD T Pooh w/ BHA and break down fish. 02:00 02:30 0.50 0 0 COMPZ FISH OTHR T Pull wear ring. 02:30 04:30 2.00 0 0 COMPZ RIGMNT SVRG T Cut and Slip 84' of drill line. Inspect derrick. 04:30 11:30 7.00 0 5,191 COMPZ FISH PULD T MU and Rih w/ Baker "B" Type spear ass to 3036' lookin for 2g of ~, 1!7" liner to .Liner did not sta in lace but dropped down hole. Continued in ~~ ._ hole slow looking for liner top. Ta ed to of liner 5191'. 11:30 12:00 0.50 10,260 10,260 COMPZ FISH FISH T TD up, kicked on pump to 2 BPM w/180 psi. Lowered spear down inside liner top, pressure increased to 225 psi. Lowered spear into liner top 7' engaging fish. PU to string wt including liner, weight broke over @ 162K ullin u hole free. Top of liner 5191' bottom of liner 10,260'. 12:00 17:00 5.00 10,260 5,069 COMPZ FISH PULL T POOH slow with drill pipe and liner standin back drill i e to 5069'. 17:00 00:00 7.00 5,069 2,574 COMPZ FISH PULL T Continue POOH laving down 5.1/2 liner and Premier Packer. 63k up wt. 57k do wt. 6/08/2008 Continue to Pooh f/ 2,574' laying down 5 1/2 Liner. Close Blind rams and attempt to PT 7" csg t/ 2,500 psi. IBP @ 10,380' let loose @ 900 psi. Notified AOGCC (C.Scheve) and CPAI Feild Sup. (M.Chaney). RU SWS and Rih and set IBP @ 10,300'. Bleed off pressure. Notified AOGCC (C.Scheve) RD SWS and Install riser. 28.6 bbl loss toda 00:00 05:00 5.00 2,574 0 COMPZ FISH PULL T Continue to Pooh f/ 2,574' to Premier Pkr and la down the same. 05:00 07:00 2.00 0 COMPZ CASING DHEQ T Close blind rams and o~ Pp~d.thr~ the kill line attempti~a to PT and chart record 7" cs test, to 2,500rpsi, Pressured u to 90 strokes and ressur ISICP. SD pump. Monitor well. Line up to Tiger Tank and bleed down to 210 psi in 5 minutes and Pressure increased to 220 psi. Open choke and pressure fell to 210 psi in 5 min. the increased to 220 psi. SWI ISICP 250 si. Monitor. l~ag~ t b a~f 20 Time Lomas Date From To Dur S De th E. De th Pha e Code Subcode T Comment 07:00 09:30 2.50 ~. COMPZ WELCTI OWFF T Pressured built back up to 250 psi. Strapped kill tank. Notified security, and PO of ventin as. Opened up through choke to kill tank to bleed off and measure returns for 2 bbls pumped during pressure test atttempt. Pressure would only bleed off to 160 psi. SI and monitor press. Press built up to 680 psi. Pressure dropped off to 450 psi. built back up to 580 psi and leveled off. Actin like IBP 10,380' broke loose and leakin .Notified AOGCC (Chuck Sheve and Field Su t. Mark 09:30 13:00 3.50 COMPZ WELCTI NUND T ND riser on BOP stack. NU 11" x 7" otis shooting flange. RU SWS grease pack and lubricator. Pressure test to 2000 psi. Equalized pressure, o ened blind rams. 13:00 16:00 3.00 COMPZ WELCTL OTHR T RIH with 2 23" gaoe ring (swsige) w/, Press,Tempt, Gamma Ray, & CCL tool. To of fluid at 425'. Ran to 10 660' w/ no si n of the IBP. POOH. Close blind rams, bleed off ress from lubricator. 16:00 20:00 4.00 COMPZ WELCTL OTHR T MU 2 1/8' IBP, RIH on depth with log. Set IBP 10,300' to element 10 293' to to .POOH with setting tool u into lubricator. 20:00 21:00 1.00 COMPZ WELCTL OWFF T Bleed off pressure f/ 580 psi to 0 psi. Monitor well. Notify AOGCC (C.Scheve) that was re installed and pressure bled off and Blind Rams would be re tested. 21:00 22:30 1.50 COMPZ WELCTI NUND T RD SWS and ND the Shooting Flan e. 22:30 00:00 1.50 COMPZ WELCTL NUND T NU Flow Riser 6/09/2008 PT Blind Rams 250/2,500 psi. MU and Rih w/ csg scraper assy to 10,263' and Reverse circulate clean. Pooh la in down 5,000' ? DP and Stand back the remainin alon w/ DC's. La down Cs scra er BHA. 00:00 01:00 1.00 COMPZ WELCTL NUND T Continue to NU Riser 01:00 02:00 1.00 COMPZ WELCTL OWFF T Fill hole and stack w/ 14 bbls and Monitor for flow 02:00 03:30 1.50 COMPZ WELCTI OTHR T Attempt to install Test plug and had slight pressure below. Monitor and RU to IA w/ Bleed line to ti er tank. 03:30 04:30 1.00 COMPZ WELCTL BOPE T Install Test oyg and PT,~SO/ sno. psi. on blind rams due to well shut in. As per State guidelines. RD and Pull Test Plu .Install wear rin . 04:30 05:00 0.50 COMPZ RPCOM OWFF T Monitor well. 05:00 09:00 4.00 0 10,238 COMPZ RPCOM PULD T MU and Rih w/ csg scraper assy BHA to 293'. Crew change. Continue RIH w/casing scraper on 3 1/2"drill pipe f/293' to 10,238'. up wt 155K dwn 93K Page 17 of 2Q Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 11:00 2.00 10,238 10,238 COMPZ RPCOM CIRC T TD up, circulate out 300 bbls of corrosion inhibitor to kill tank, 4 BPM 500 si. 11:00 14:30 3.50 10,238 10,263 COMPZ RPCOM CIRC T Open annul. RIH from 10,238' to 10 263' tagged top of stub. PU to 10,260' Reverse circulate 50 sweep 4 BPM @ 1350 psi. chased with 76 bbls 9.8 brine 4 BPM @ 1500 psi. Pumped second 70 bbls sweep 4 BPM 1500 psi Chased with 9.8 ppg brine with SafeLube until sweeps cleaned up. Pumped total of 608 bbls. SD monitor well for 30 min. 14:30 19:30 5.00 10,263 5,232 COMPZ RPCOM RCST T POOH with 3 1/2"drill pipe laying down 1st 5,232'. 100k up wt., 68k do wt. 19:30 22:00 2.50 5,232 0 COMPZ RPCOM TRIP T Pooh standing back 51 stands of DP and 3 stands DC's 22:00 23:00 1.00 0 COMPZ RPCOM PULD T La in down Casin scra er ass . Brin u tools for scab liner 23:00 00:00 1.00 COMPZ RPCOM OTHR T Clean and clear rig floor and RU e ui . to Rih w/ 3 1/2 scab liner. 6/10!2008 PU and MU 3 1/2 Scab liner assy Set Premier Pkr @ 10,144' t/ 10,151' w! WLEG @ 10,269'. Set FHL @ 5,206' t/ 5,213' w/ SBE @ 5,182' t/ 5,201' w/ HR Setting sleeve @ 5,102' U 5,112'. PT 7" csg to 2,500 psi for 30 min and chart. Release setting tool and Pooh laying down DP and Setting BHA. Pull wear ring and Pre are to Rih w/ 3 1/2 Prod. Strin . 00:00 02:00 2.00 0 COMPZ RPCOM PULD T PU w/ 3-1 /2" Scab Iiner.Plug loose, SWS called to confirm lu OK 02:00 08:30 6.50 COMPZ RPCOM RCST T RIH with 3-1/2" scab liner and FHL acker 08:30 09:00 0.50 COMPZ RPCOM PULD T RD liner running equipment, RU DP runnin a ui ment 09:00 12:15 3.25 COMPZ RPCOM RCST T RIH with 3-1/2" scab liner on 3-1 /2" DP. 12:15 13:00 0.75 COMPZ RPCOM RCST T Land scab liner while pumping 1 bpm. Pressure increased from 70 psi to 140 psi at 10262'. Sit down 5K# with an additional 6'. PU 10'. 13:00 14:45 1.75 COMPZ RPCOM CIRC T Circ 147 bbl of inhibited 9.8 brine down the IA. Displace with 127 bbl of 9.8 brine down the IA taking returns u the DP. Page 18 of 20 Time Logs Date From_ To Dur S. De th E. D th Ph e Code S code T Comment 14:45 16:45 2.00 10,269 COMPZ RPCOM PACK T Dro ball and rod sit down ' at 10269'. Pressure up to 4000 psi, PU 10K#. Pressure up to 4200 psi and chart for 15 min. Bleed down DP to 1050 psi and pressure up IA to 2500 psi and chart for 15 min. Bleed DP and IA to 0 psi. Set Premier Pkr 10 144' U 10,151' w/ WLEG 10,269'. Set FHL @ 5,206' U 5,213' w/SBE 5,182' U 5,201' w/ HR Settin sleeve 5,102' U 5,112'. Set down from 85K# to 55K# and pressure up DP to 500 psi. P" of FHL packer, DP pressure dropped to 0 si, PU wt 95K#. 16:45 22:30 5.75 5,166 0 COMPZ RPCOM TRIP P POOH with 3-1 /2" DP, DC's and Settin tool. 22:30 23:00 0.50 0 COMPZ RPCOM OTHR P Clear Pipe shed. 23:00 23:30 0.50 COMPZ RPCOM OTHR P Pull wear ring. 23:30 00:00 0.50 COMPZ RPCOM OTHR P Change out DP equip to Tbg Equip. 6/11 /2008 PU and Rih w! 3 1/2 Prod. String. Stab into SBE and Space out. MU Hanger and land. RILDS and PT Tbg @ 2,750 psi and bleed back to 1,750 psi. PT IA @ 2,500 psi and attempt to shear SOV w/ no luck. Bring up to 3,000 psi -Bled Tbg - no shear. Bleed IA to 0 psi. Set BPV and ND BOPE, NU Tree. Pull BPV and install Test plug. PT tree and Pack off to 250/5,000 psi. Pull Test plug and install BPV. Back rig off 1 C-11 and clean !ins ect celler area. Release Nordic ri 3 21:00 hrs on 6-11-08. 00:00 03:00 3.00 0 2,891 COMPZ RPCOM PULD P PU and Rih w/ seal assy and~ily,kV/ 3 1/2 Completion to 2,891' installing GLM's and SSSV. 03:00 04:00 1.00 2,891 2,891 COMPZ RPCOM OTHR P RU sheeve and spool of control tine. PT control line to 6,500 psi for 10 min. 04:00 07:30 3.50 2,891 5,193 COMPZ RPCOM PULD P Continue to RIH PU 3 1/2 Tbg com letion f/ 2,891' to 5202'. 07:30 09:45 2.25 5,193 COMPZ RPCOM HOSO P Pumping 1 bpm at 70 psi, press increased to 120 psi at 5193'. RIH 16' no-go, sat down 10K#. Pull up, MU 8.05' pup joint fora 1.04' space out on the seal assembly. Make up SSSV control line to hanger and PT to 6500 psi. SWS used 77 bands for the control line. Land han er, RILDS. 09:45 11:45 2.00 COMPZ RPCOM DHEO P PT tubing to 2750 si for 15 min chartZ Bleed tubing down tr, ~7Fo psi. PT IA to 2500 i chart). Blled down tubing to 0 psi, IA holding 2500 psi. Pressure IA up to 3000 psi, holding pressure with tubing at 0 psi. Bleed IA down to 0 psi and pressure IA back up to 3000 psi. Could not get SOV to shear. Blled IA to 0 si. 11:45 17:45 6.00 COMPZ RPCOM NUND P Pull landin 'oint and ND BOPE. NU Tree. Page 18 of 20 ~ Time Logs Date From To Dur S. De th E. De th Ph e Code Subcode T Comment _ 17:45 20:00 2.25 COMPZ RPCOM SFEO P Pull BPV and install Test plug. Test Tree and Pack off @ 250/5,000 psi. Pull test lu and install BPV. 20:00 21:00 1.00 COMPZ RPCOM OTHR P Pick rig up and back off well 1C-11 and Clean and inspect cellar area. elease Nordic r 3 1:00 rs on 6-11-08. Page 20 0# 2i~ 1C-11 Well Events Summary • DATE SUMMARY 6/15/08 PULLED BALL & ROD @ 10,192' RKB. PULLED SOV @ 5118' RKB, REPLACED W/ DV. PERFORMED MITIA T - ASS. PULLED 2.75"CR PLUG BODY @ 10,192' RKB. IN PROGRESS. 6/16/08 HAVE DIFFICULTIES GETTING EQUALIZING TOOL TO DRIFT THRU SEAL AREA. RAN LIB AND GOT GOOD IMPRESSION OF STUB LIP @ 10,247' SLM. ABLE TO "JUMP" BY WITH 2.70" SWEDGE. RE-CONFIGURE TOOLS 8~ ATTEMPT TO PULL 2 1/8" IBP @ 10,293' RKB, ABLE TO MAKE IT TO 10,266' SLM (MARKS ON EQ-SLEEVE). JOB IN PROGRESS. 6/17/08 PULLED 2 1/8" IBP FROM 10,266' SLM, DRIFTED TUBING W/ 10' OF 2.5 "DD BAILER, TAGGED @ 10,637' SLM, SET CAT @ 10,192' RKB, 3500PSI TEST ON TUBING, PASSED, PULL SV @ 10,192' RKB, LDFN, IN PROGRESS 6/18/08 MOVED IBP FROM 10,637' SLM TO 10,701' SLM. ESTIMATE IBP IS @ 10728 RKB, BELOW BTM PERF LOCATED @.10_7.16' RKB_. WELL READY FOR E- 6/19/08 PERFORATED C-SAND FROM 10660'-10670' WITH 2.5" HSD LOADED 6SPF WITH 2506 HYPERJET CHARGES (60-DEG PHASING; 0.43" HD). 6/19/08 DRIFT TO SSSV @ 2297' RKB W/ 2.90" GAUGE RING. SET 3.5" TRMAXX-5E FRAC SLEEVE (OAL=80", 2.855" NO-GO, MIN ID 2.313") @ 2297' RKB, NOTE ENCOUI~IIER MULTIPLE TIGHT SPOTS WHILE RIH W/ FRAC SLEEVE. JOB COMPLETE 6/20/08 COMPLETED C SAND HYDRAULIC FRACTURE STIMULATION. PLACED 140,820# OF 16/20 CARBOLITE BEHIND PIPE, ^'93% OF DESIGN. FRAC PRESSURED OUT WITH 210 BBLS OF 10 PPA SAND INTO FORMATION. PUMPED A TOTAL OF 1537 BBLS OF SW @ AN AVERAGE TREATING PRESSURE OF 3515 PSI. LEFT LOWER RUBBER OF TREESAVER IN WELL. 6/21/08 PERFORM POST FRAC FCO. USED 625 BBLS OF SSW, 50 BBLS OF FLOZAN, 80 BBLS OF SD AND A 1.75" OD JSN TO CLEANOUT FRAC SAND DOWN TO 10780' CTMD,.ESL.. 65' OF RATHOLE. WELL LEFT SI AND FREEZE PROTECTED. READY FOR SLICKLINE. 6/22/08 PULL FRAC SLEEVE (c~ 2297' RKB. TAGGED @ 10,867' SLM. REPLACE DV @ 5117' RKB W/ 1/4" OV. REPLACE DV @ 3193' RKB W/ GLV. JOB COMPLETE • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 09, 2008 1:55 PM To: 'Ennis, J J' Subject: RE: 1 C-11 casing repair update (PTD# 196-172) Jim, I had heard that "things" didn't go as planned over the weekend. Down-sizing is the obvious choice. Nothing further is needed. I will place a copy of this message in the file. Best regards, Tom Maunder, PE AOGCC -----Original Message----- ~~~~ ~UN ~ ~ 2~~~ From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Monday, June 09, 2008 12:20 PM To: Maunder, Thomas E (DOA) Subject: RE: 1C-11 casing repair update (PTD# 196-172) Tom, _~ Events at 1C-11 over the weekend have prompted yet another change in completion plan. A proposed schematic is attached for your review. As shown on the schematic, the previously approved 5.5" liner is planned to be replaced w/ 3.5" tbg between two packers. This change is necessary because the last available 7"x5.5" liner hanger tools were trashed during fishing to remove the liner which hung up 2000' off bottom. We have successfully recovered the liner and are currently performing a clean out run down into the tie back extension. Please let me know if any questions or concerns. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 29, 2008 4:16 PM To: Ennis, J J Subject: RE: 1C-11 casing repair update (PTD# 196-172) Jim, The mechanical alternative looks appropriate. Nothing further is needed. I will place a copy of this message in the file. Good luck with the repairs. Tom Maunder, PE AOGCC -----Original Message----- From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Thursday, May 29, 2008 4:00 PM To: Maunder, Thomas E (DOA) Subject: 1C-11 casing repair update (PTD# 196-172) Tom, As we discussed on phone this morning subsequent to email below, prohibitive delays in pumping fine grind cement to heal bleeding leak have necessitated a change in plans. Rather than attempt squeeze, we're going to install a 5.5" straddle across the 7" casing leak to restore integrity. The 5.5" straddle is preferred over a 5.5" liner because risk of tubular integrity failure during subsequent frac operations is reduced. A revised conclusion to the original procedure along w/ a proposed completion sketch are attached for your review. Please let me know if you have any questions or concerns. 1 • • Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) -----Original Message----- From: Ennis, J J Sent: Thursday, May 29, 2008 7:17 AM To: 'Maunder, Thomas E (DOA)' Subject: 1C-11 remedial cementing update (PTD# 196-172) Good morning Tom, Pumping cement went well. PT afterwards not so much, loses 1000 psi in 15 minutes. No communication upward to OA so must be bleeding toward surface casing shoe. Plan is to spot & squeeze cmt into leak today to restore integrity. If that proves fruitless, our plan is to run a liner from existing tie back extension to above leak. I'll keep you updated on progress or lack thereof. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 27, 2008 2:28 PM To: Ennis, J J Subject: RE: 1C-11 remedial cementing procedure (PTD# 196-172) Jim, Thanks for the calls and updated procedure. I have apprised Commissioner Foerster of the change in plans and she has given her oral approval of your revised plan. The actual work should be documented in the operations summary submitted with the 404. Nothing further is needed at this time. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Tuesday, May 27, 2008 12:51 PM To: Maunder, Thomas E (DOA) Subject: 1C-11 remedial cementing procedure (PTD# 196-172) «1C-11 remedial cementing procedure 5-27-08.pdf» Tom, The cementing forward plan we discussed this morning is attached for your review. Please let know if any questions or concerns. I'm scheduled to be in a meeting most of this afternoon so please call my cell number below if any issues need resolved. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) 2 • Well: 1 C-11 API: 50-029-22714-00 Co~IrxxoF'~til~jpr~ Field: Kuparuk PTD: 196-172 PROPOSED COMPLETION 6-9-08 WELLHEAD A Lift threads: 3'/z' 8rd EUE NEW COMPLETION BPV: 3" FMC ISA Model: FMC Kuparuk Gen IV a A: SSSV: 3-1/2" SCSSSV with 2.813" X @ 2300' MD CONDUCTOR e 16", 62.5 ppf, H-40 e B: Gas Lift Mandrels C No. MD TVD TYPE 7" Casing leak @5466' KB 1 3183 2300 1" KBMG 2 4222 3000 1" KBMG SURFACE CASING p 3 5149 3491 1" KBMG 9.625", 40 ppf, L-80 C: FHL packer w/ SBE on top @ 5200' E MD PRODUCTION CASING ~ D: 3.5" tubing 7.0", 26 ppf, L-80, BTC-MOD ~ E: Premier packer @ 10200' MD LINER F: Nipple: 3-1/2"with 2.75" D profile @ 5", 18 ppf, L-80 10,265' MD TUBING G: Seal Assembly @ 10,272' MD 3.5", 9.3 ppf, L-80, 8rd-MOD Last Tag: 12/13/07 PERFS Tag Depth: 11,121' RKB C-3, C-4: 10,660' -10,716' MD Fill: no fill over perfs TD: 11,300' RKB Last Updated: 9-Jun-08 Updated by: JJE 1C-11 Proposed completion • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, June 04, 2008 10:53 AM To: 'Gober, Howard' Cc: Ennis, J J; Nordic 3 Company Man Subject: RE: 1C-11 Proposed completion Page 1 of 1 1~~-~~~ Howard, et al, As is normally the case with a workover, you find out more is broken as you proceed. Running the long scab is appropriate. Nothing further is needed. I will place a copy of this message in the file. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Wednesday, June 04, 2008 10:36 AM To: Maunder, Thomas E (DOA) Cc: Ennis, ] J; Nordic 3 Company Man Subject: 1C-11 Proposed completion ~~~~~ JUN d 9 2008 Tom, Attached is the proposed completion sketch that I promised last night to go along with the procedure I sent. I have also attached the results of a caliper log we ran. The casing below 5390' appears to be in bad shape. We are going to isolate this behind a 5-1/2" scab liner. The scab will run from the new Baker Premier packer that we set at 10200' to a liner hanger at 5200'. As you can see from the caliper data, the casing is in very good shape above 5390'. The 5-1/2' scab liner will be set with corrosion inhibited brine in the annulus. «1C-11 06-02-08 Casing Caliper Graph.pdf» «1C-11 Proposed Completion 06-04-08.pdf» Please let me know if you have any questions or if you require further information. We are currently installing 5- 1/2" rams and preparing for a BOP test. After that we will be ready to run the scab liner. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com 6/4/2008 1C-11 Re-Revised #2 Procedure Page 1 of 1 • • Maunder, Thomas E (DOA) From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Tuesday, June 03, 2008 6:49 PM To: Nordic 3 Company Man; Ennis, J J; CPA Wells Supt; Bjork, David(Baker Oil Tools); Maunder, Thomas E (DOA) Cc: Packer, J.Brett; Gauer, Cody Subject: 1C-11 Re-Revised #2 Procedure Attachments: 1C-11 Re-Revised #2 WO Ptan HBG 06-03-08.pdf Attached is the latest revised procedure for 1 C-11. Please let me know if you have any questions. «1C-11 Re-Revised #2 WO Plan HBG 06-03-08.pdh> Tom - i wilt follow this up with a revised proposed schematic and a phone call in the morning. This is very similar to the o#her procedure other than we will have 5-1/2" down to a packer instead of just across the leaks. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howa rd. Gober@conocophillips. com 6/4!2008 • • Re-Revised #2 Rig Workover Procedure after Scab Liner Failed to Set 1C-11 Kuparuk Producer Repair Casing Leak PTD #196-172 Pull FHL Packer/PBR 35. RIH with PBR retrieving tool on 3-1/2" drill pipe. Just above PBR, circulate drill pipe and casing full of corrosion inhibited brine (1 % CRW 132) from PBR to 5000' RKB. Engage PBR and straight pull release the FHL packer/PBR. Let etements relax. POOH with packer assembly. Note: There are 2 slips that have not been recovered from the 3D liner hanger packer. Verify slips are present in either the PBR or the tail pipe. 36. Break down the BHA below the FHL and remove the 2.75" D Nipple. Run 5-1/2" Scab Liner 37. Set test plug in wellhead. Install 5-1/2" rams in lower cavity of BOP stack. Perform full BOP test to 250/2500 psi. Notify AOGCC at least 24 hours in advance. 38. RIH with 5-1/2" scab liner assembly on workstring as follows: a. Baker 5" seal assembly replacement sub (5.125" OD, 4.4" ID, 6' long w/ half muleshoe). This is the same assembly on the bottom of the FHL that was pulled. b. 1 joint 3-112", 9.3# L-80, EUE 8rd-Mod tubing c. 2.75" Camco D nipple w/RHC plug installed and ported check valve sub d. 1 joint 3-1/2", 9.3# L-80, EUE 8rd-Mod tubing e. X-over pup joint, 10 ft, 3-1/2" TC-II box x 3-1l2" EUE $rd pin f. 7" Baker Premier packer g. X-over pup joint, 10 ft, 3-1/2" EUE 8rd box x 3-1/2" TC-II pin . h. 4' pup joint 3-1/2" EUE 8rd i. Baker SBE j. XO to 5-1/2" Hydril 563 k. 5-1/2" 15.5#, L-80 Hydril 563 Casing • Recommended make-up torque: 5200 ft-Ib min, 5980 ft-Ib target • Jet Lube Enviro-Safe pipe dope recommended for Hydril 563 connections I. X-Over, 5-1/2" BTC box x Hydril 563 pin m. Baker 5-1/2" x 7" HMC Hanger n. 5-1/2" CPH Packer • Re-Revised #2 Rig Workover Procedure after Scab Liner Failed to Set 1C-11 Kuparuk Producer Repair Casing Leak PTD #196-172 o. Baker Liner Running tool 39. Record pickup and slackoff weights on the last 5 stands of drill pipe. 40. Locate 5.25" tieback extension and tag btm of barrel. Attempt to swallow any 4° OD stub that might be available in SBE. Set down 10K Ibs w/ last motion being downward. (Verify set down weight with Workover engineer prior to setting packer and hanger). Drop bal[ and rod. Set Premier and liner hanger as per Baker rep. Set dawn weight on liner hanger to ensure slips are set. good. Drop ball and release running tool. Stroke up ~10' to expose dogs. Stroke down and stack weight to set HMC liner hanger. POOH w/ one stand of workstring. PT csg to 2500 psi. POOH laying down workstring. Run 3'/i' Completion Assembly • Daft and tally alt tubing, pups, and completion equipment to 2.867" (Exceptions: min. ID of SCSSV = 2.8?2'). • Record ODs and IDs of all auxiliary equipment on tubing detail. • Ensure seal rings are in place and replace any damaged sea! rings as needed.. Apply Jet Lube Run-N-Seal pipe dope sparingfy on both the pin and box ends of tubing. • Torque for IBT tubing is determined by averaging the make up torque required for the first 75 joints. Proper makeup occurs when the btm of the pin makeup mark is flush with the top of the collar. • Verify that the rig is centered over the well prior to running the completion. 41. PU and TIH with the following completion assembly: A. Baker seal assembly w/ 4.5" locator B. 1 joint 3'/" 9.3#, L-80, EUE 8rd-Mod tubing. C. Camco 3-1/2" x 1° KBG2-9 gas lift mandrel with DV installed (10' handling pups above and below). D. 3'/2" 9.3#, L-80, IBT Mod SCC tubing E. Camco 3'/a' x 1" gas lift mandrels (10' handling pups above and below) spac~ct out as follows. GLM's Tvpe MD TVD Loaded with 1 KBMG 3150 2450 DV 2 KBMG 4985 3400 DV 3 KBG2-9 6473 4200 DCR Shear-Out Valve* 4 KBG2-9 8026 5000 DV 5 KBG2-9 9360 5696 DV 6 KBG2-9 10,217 6193 DV*" "'DCR valve is rated to shear out at 1500 psi IA-to-tubing differential. '"'This is the GLM shown in item C above. F. Schlumberger 3-1/2 TRMAXX SSSV set at 2308' MD (2C~` TVD). Re-Revised #2 Rig Workover Procedure after Scab Liner Failed to Set 1C-11 Kuparuk Producer Repair Casing Leak PTD #196-172 G. 3'/" 9.3#, L-80, IBT Mod SCC tubing to surface. Space out ~ Land Completion 42. Locate PBR. Space out with tubing pups, positioning one full joint immediately below hanger. Space out should leave locator about 2 feet above fully located position when tubing hanger is in tubing spool. Land tubing hanger. Run in lock down screws. 43. With the annulus open, pressure 3'/" tubing to 2,500 psi for 15 minutes. Monitor annulus for returns. Bleed down pressure in tubing to 1,750 psi. While holding 1,750 psi on tubing, pressure 3'/" x 7" annulus to 2,500 psi for 30 minutes. Record casing pressure test on chart recorder. Finish Completion 44. Bleed down tubing pressure to zero. With tubing open, annulus pressure should shear the dump kill valve (1,500 psi casing-to-tubing differential needed to shear) in the #3 GLM. Monitor well. 45. Pull landing joint. Set BPV. ND BOP stack. 46. NU 3-1/8" 5M tree. Refer to picture taken in Step #3 for proper tree orientation. Pull BPV, set tree test plug. Pressure test tree to 250/5000 psi. Test packoff to 250/5000 psi. Pull tree test plug. 47. RU pump to freeze protect the well by pumping a minimum of 115 bbl diesel down the annulus taking returns from the tubing. Hook up a jumper hose from the IA to tubing and allow diesel to equalize, freeze protecting to 3246' MD (2500' TVD). 48. Set BPV. RDMO Nordic 3 rig. Post-Riot Work 1. Pull BPV. 2. RU slickfine. Pull SOV and run new GLD. Pull ball/rod & RHC plug. Bail out calcium carbonate. Pull IBP's. RDMO Slickline. 3. Turn well over to Production via Handover Form. • • Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (25.5' - 10173.2') Well: 1 C-11 Field: Kuparuk Company: ConocoPhillips Country: USA Survey Date: June 2, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 25 50 75 100 a~ ~ 125 Z C .O 150 175 200 225 240 0 50 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 240 26 1050 2123 3191 4246 5304 ~ L_ Q v 6368 7440 8502 9545 10173 100 ConocoPhilli s p Alaska Subject S, I C- -- "P~oPC~ Cow-pc~--`~-{~ ._ ... _ __, ___ ___ ,____ _~_ ~.____ .z..._._ i 3 _.._._._-- _.-._ ._.._. _.__ ,__.~_ .._ .r.__._ _ ..--_-- -__ _-- ~ p t~ ~J Calculations Chart of ' ti • • Memory Mu{ti-Finger Ca{iper Log Results ~urnmary Company: ConoeoPhllllps Alaska, Inc. Well: 1C-11 Log Date: June 2, 2008 Field: Kuparuk Log No.: 7705 State: Alaska Run No.: 2 API No.: 50-029-22714-00 Pipet Desc.: 7" 26 Ib. L-80 Top Log Intvll.: Surface Pipet Use: Casing Bot. Log Intvl1.: 10,173FL (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into Sch/umberger Leak Detect Log (2/20/08). This log was run to assess the condition of the casing with respect to internal corrosive and mechanical damage, and to evaluate the casing for placement of a scab liner. The caliper recordings indicate that the interval of 7" casing logged is in good to poor condition, with a hole recorded ~ 5,482', wall penetrations in excess of 20% wall thickness are recorded in 59 of the 240 joints logged. The damage recorded appears mostly in the form of Isolated Pitting, Lines of Pits and general corrosion. An area of 34%Cross-sectional wall loss is recorded @ 5,415'. There are no areas of significant I.D. restrictions recorded throughout the interval of casing logged. This is the second PDS caliper of this welt. This is the first PDS caliper log of the 7" casing in this well. A 3-D Log plot of the area near the hole is included in this report to assist with packer placement. Cross- sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Hole (100%) Jt. 129 @ 5,482 Ft. (MD) Corrosion (62%) Jt. 195 @ 8,287 Ft. (MD} Isolated Pitting (60°~) Jt. 131 ~ 5,564 Ft. (MD) Isolated Pitting (59%) Jt. 128 ~ 5,472 Ft. (MD) Corrosion (53°~) Jt. 194 (d3 8,284 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Corrosion (34%) Jt. 127 @ 5,415 Ft. (MD) No other areas of significant cross-sectional wall loss (>9%) are recorded. ~~~~E®~ur~ ~ ~ zao~ MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: J. Halvorsen Analyst: J. Thompson Witness: R. Overstreet ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, T:X 77497 Phone: (281) 431-7100 or (888} 565-90$5 Fax: (281) 431-7125 E-mail: PDS@memorylog.com Prudhoe Bay F+eid Office Phone: (907} 659-2307 Fax: (907) b59-2314 • PDS Multifinger Caliper 3D Log Plot `-,- _ ~_ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1C-11 Date : June 2, 2008 Description : Detail of Caliper Recordings for Scab Liner Placement, 5490 Jt129 HOLES X5482' 5500 5510 5520 5530 Jt 130 46% Max Pen ~ 5520' 5540 5550 5560 5570 Jt.131 60% Max p~ 5580 ~ 5564' 5590 5600 5610 Jt. 132 5620 • Correlation of Recorded Damage to Borehole Profile Pipe 1 7. in (25.5' - 10173.2') Well: 1 C-11 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: June 2, 2008 A pprox. Tool D eviation ~ A pprox. Boreho le Profil e 1 `. 2 (; 25 1050 50 ~~ 2123 75 3191 100 4246 ~ a~ .n ~ 125 5304 ~ Z s c ' n. a, o 150 6368 175 7440 200 --~ 8502 225 ~ 9545 240 10173 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degre es) Bottom of Survey = 240 • • PDS Report Overview ~, ~. Body Region Analysis Well: 1 C-11 Survey Date: June 2, 2008 Field: Kuparuk Tool Type: UW MFC 40 No 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 ___ _ Analyst: J. Thompson Tubing: Norn.OD Weight Grade & Thread Norn.ID Nom. Upset Upper len. Lower len. 7 ins 26 f L-80 6.276 ins 7 ins 6.0 ins 0.0 ins Penetration and Metal Loss (%wall) ~ penetration body ~ metal loss body 250 200 50 1 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 l0 40 to over 40% 85% 85% Number of 'oints anal se d total = 240 pene. 0 129 52 loss 8 231 0 44 14 1 1 0 0 Damage Configuration (body ) 80 6U ~t 0 20 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion iblehole Number of 'oints dama ed total = 113 67 8 37 0 1 Damage Profile (°~ wall) ~ penetration body ~, .N, metal loss body 0 50 1 51 Bottom of Survey = 24C 100 101 151 201 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 7. in 26.0 ppf L-80 Well: 1 C-1 1 Body Wall: 0.362 in field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, tnc. Nominal I.D.: 6.276 in Country: USA Survey Date: June 2, 2008 Joint No. Jt. Depth (Ft.) Pc~n. I lLsFt (In.l Pen. Body (Ins.) Pc~n. % ~tct.al I c», ,~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 2 (? 0.0 t9 6.18 2 69 U 0.01 3 6.19 3 112 U.llb 0.02 4 6.19 4 155 U 0.0 (~ ? 6.15 5 197 (t.l? 0.02 (> s 6.13 6 239 tt 0.01 -3 6.20 7 282 l t 0.01 3 6.13 8 326 (t 0.02 6 6.14 9 366 U 0.01 a _' 6.19 10 410 (] 0.02 6 6.16 11 452 O.(t(~ 0.03 8 ~' 6.14 12 497 ~1 0.03 8 _' 6.14 13 539 c) 0.01 ~ 6.14 14 582 t } 0.04 I _' 6.14 Line shallow cor osio . 15 624 U.13 0.04 1 U 6.13 ine hallow corrosion. 16 665 U 0.02 4 t 6.15 17 707 (1.U(, 0.05 1 ~ 6.18 Line shallow corrosion. 18 751 I1 0.01 2 _' 6.1 19 792 U 0.01 4 6.14 20 834 ~.t.1U 0.02 6 6.14 1 878 t ~ 0.01 =1 6.18 2 922 U 0.02 5 ! 6.13 2 964 a 0.02 G 6.12 24 1008 O 0.02 ~ 6.14 5 1050 lt.u5 0.02 6 6.15 26 1095 (1 0.02 (> ~' 6.15 27 1137 l) 0.01 4 ? 6.11 28 1177 tt.tt~t 0.02 b _' 6.19 29 1221 n t.' 0.02 6 6.14 30 1264 tt 0.02 (~ 6.17 31 1306 a 0.01 ~i 6.20 32 1348 U 0.02 5 ~ 6.11 3 1391 U 0.02 (> 6.15 34 1434 l) 0.02 5 ~' 6.13 35 1477 U.Ob 0.02 b I 6.20 36 1521 U.U6 0.02 6 Z 6.15 37 1565 t).l)9 0.02 6 _' 6.14 38 1608 (t 0.01 4 -1 6.17 39 16 2 t t 0.02 E~ t 6.11 40 1693 ti 0.01 ~t ! 6.15 41 1736 a 0.02 5 ~ 6.18 42 1780 t ~ 0.02 6 3 6.19 43 1824 tt 0.02 (i Z 6.12 44 1867 (t 0.01 -1 _' 6.16 45 1909 U 0.02 6 ~ 6.13 46 1951 i t 0.02 4 1 6.16 47 1992 i t. l 1 0.02 (~ ? 6.14 48 2036 i? 0.02 (> 6.20 49 2079 0.02 -1 ~' 6.18 50 2123 0.02 -1 6.13 Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 1 C-1 1 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2008 Joint No. Jt. Depth (Ft.) Nen. Upset (Ins.) Pen. Body (Ins.) Pc~n. °~ 1Aetal Ic~ss `~~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 51 2165 O 0.02 4 ~' 6.18 52 208 t? 0.02 5 ~' 6.13 53 2251 ti 0.02 4 ~' 6.13 54 294 t~.t>; 0.02 E, ~ 6.21 55 2338 t).UiS 0.02 b 6.13 56 2380 t~ 0.02 (~ 6.15 57 2423 (1 0.02 5 6.15 58 2466 U 0.01 3 _' 6.15 59 2508 U 0.0 5 2 6.15 60 2551 0. I "~ 0.02 (~ 6.19 61 2593 l) 0. 1 4 3 6. 0 62 2636 lL I S 0.02 6 ~ 6.14 63 2679 O 0.01 4 _' 6.16 4 2720 i~.l)~ 0.02 S 6.18 6 2763 U .O1 4 ! 6.10 Lt. De osits. 66 2806 U 0.01 4 i 6.15 67 2850 U 0.01 4 ~ 6.17 68 2894 (~ 0.0 4 ~ 6.13 69 2934 tr 0.02 7 6.21 70 2978 U 0.01 4 ~ 6.15 71 3019 (~ 0.01 =1 ~' 6.16 72 3062 U 0.01 4 i 6.19 73 3105 U. I r) 0.02 t~ 6.16 74 3148 U 0.02 > ' 6.14 75 3191 (x.11 .02 6 _' 612 76 3232 U 0.02 4 _' 6.16 77 3276 l).Ub 0.02 V _' 6.1 78 3317 U 0.01 d ~ 6.16 79 3360 O. I ~ 0.02 (~ I 6.13 Lt. D osits. 80 3403 O 0.02 t, 6.12 81 3443 U 0.01 ; _' 6.15 82 3485 U 0.01 a 6.11 83 3527 t~ 0.01 _' 6.14 84 3571 l) 0.01 3 i 6.16 85 3612 l).12 0.02 6 2 6.21 86 3656 U 0.02 5 ,' 6.20 87 3698 (~ 0.02 ~ s 6.20 88 3740 O.U(, 0.02 b _' 6.20 89 3781 U 0.02 ~, _' 6.17 90 3824 U.1 Z 0.02 t, _' 6.22 91 3867 U 0.01 -t _' 6.1 92 3907 U 0.02 6 ~ 6.15 93 3951 11 .01 4 t 6. 0 Sh Ilow ittin . 94 3990 U 0.01 3 ? 6.19 95 4033 ~ 0.01 4 1 6.14 96 4075 (l.O9 0.02 U _' 6.23 97 4118 (l.Ui 0.02 ~ ~' 6.17 98 4160 (~ 0.02 t, ? 6.18 99 4205 ~ ~ 0.01 ~ 6.14 100 4246 ! ` 0.02 4 I 6.18 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINTTABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: -LATION SHEET 1 C-11 Kuparuk ConocoPhillips ALaska, Inc USA June 2, 2008 Joint No. Jt. Depth (Ft.) f'cvi. tll~se~t {In..! Pen. Body (Ins.) Pcn. % ~1~~I,il I~~ss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 101 4290 0 0.01 4 6.16 102 4333 U 0.02 6 ~ 6.18 103 4376 t~ 0.02 6 6.19 104 4417 t ? 0.02 t~ 6. 7 105 4460 a 0.02 (~ 6.14 106 4499 ~) 0.02 4 6.14 107 4540 a 0.01 ~ 6.17 108 4583 (LU7 0.02 4 6.1 109 4623 U 0.02 ~ 6.15 110 4666 U.U7 0.02 6 6.11 111 4708 U 0.02 5 6.16 112 4751 U 0.02 5 6.18 11 4793 (1 0.02 t> 6.15 114 4836 t) 0.02 t> 6.17 115 4 79 U 0.01 4 6.19 116 4920 ?) 0.01 3 6.16 117 4963 U 0.01 4 ~ 6.18 118 5004 tt.U7 .02 6 ) 6.21 119 5047 U 0.02 (i 6.15 120 5090 t?.I ~ 0.02 b 6.18 121 5131 ~? 0.02 5 6.20 122 5174 t?. I ? 0.02 6 6.18 123 5218 ?) 0.02 b _' 6.24 124 5261 t) 0.02 E~ ~' 6.22 1 5 53 4 u 0 02 r, 6.13 126 5347 t) 0.02 ~1 I 6.20 127 5390 U.U~ 0.19 52 ;-3 6.15 Corrosion. 128 5433 l) 0.21 ~~) 6.14 Isolated ittin . 129 547 (1.1 ~ 0.44 I t)U ~.~ 6.24 HOLE ! 130 5515 t) 0.17 46 6.22 Corrosion. 131 5558 c? 0.22 6U t 6.20 Isolated ittin . 132 5601 a 0.10 18 Z 6.21 Isolated ittin . 133 5644 U.1 ~ 0.10 2' 6.21 Isol ted ittin . 134 5686 t) 0.12 ~2 ~ 6.17 Isolated ittin . 135 5729 t) 0.08 22 _' 6.21 Isola ed ittin . 136 5773 t).l)5 0.08 ? ~ _' 6.19 Isolated ittin . 137 5815 t) 0.14 off 6.23 Isolat d ittin . 138 5858 U 0.09 Z4 6.16 Isolated ittin . 139 5901 U. I ~ 0.09 '=1 _' 6.20 Isolated ittin . 140 5945 l1 0.05 13 ) 6.21 Shallow ittin . 141 5988 U 0.13 ;b ~ 6.13 Isolated ittin . 142 6032 U 0.10 2ti ~ 6.16 Isolated ittin . 143 6074 U.2E; 0.07 1l) -l 6.12 Corrosion. 144 6112 U 0.10 2£3 Z 6.16 Isolated ittin . 145 6151 U 0.09 24 2 6.15 Isolated ittin . 146 6195 U 0.05 1.~ 2 6.18 Shallow ittin . 147 6238 U 0.07 ~U 6.13 Isolate ittin . 148 6281 U.U~ 0.08 2 6.14 Isolated ittin . 149 6324 t~ 0.04 11 6.19 Shallow ittin . 150 6368 !? 0.06 1S 6.15 Shallowt~ittin . Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 1 C-1 1 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2008 Joint No. Jt. Depth (FL) I'r~n. lll~tr~t (lns.) Pen. Body (Ins.) I'cvr. %, Me~rrl Icxs •~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 151 6412 U .09 'S _' 6.18 Isolate ittin 152 6454 l) 0.13 ,b ~ 6.17 Line corrosio . 153 6496 a 0.09 Zb 6.14 Isolated itti 154 6539 tr 0.10 Z') ! 6.19 Isolated ittin . 155 6582 U 0.04 1 I ~ 6.16 Shallow ittin . 156 6626 (I 0.13 ,~ .19 Isolated ittin . 157 6668 0 0.14 ;~i a 6.17 Isolated ittin . 158 6710 11 0.04 11 6.22 Shallow ittin . 159 6754 U.IS 0.07 18 6.16 Shallow ittin . 160 6796 U.u£3 0.03 8 a 6.21 161 6839 (1.11) 0.06 17 ~ 6. 6 Shallow ittin . 162 6883 tl 0.04 12 6.17 Shallow ittin . 163 6925 U 0.06 l o ~ 6.13 Shallow it ~n . 164 6967 u.ltt 0.08 22 '~ .O1 A arentBucklin 165 7010 0 0.05 1 ~ ' ~ 6.05 A anent Bucklin Shallow ittin . 166 7053 tl 0.04 10 6.16 Shallow ittin 167 7096 U 0.07 19 6.14 Shallow ittin . 68 7140 U.U(, 0.05 15 t 6.21 Shallow it i 169 7182 11 0.04 11 I 6.23 Shallow ittin . 170 7226 11 0.07 19 2 6.18 Shallow ittin . 171 7269 a 0.09 25 1 6.17 Line corrosion. 172 7312 tr.l2 0.09 Z4 ; 6.20 Isolated ittin . 173 7355 1t.07 0.04 IZ Z 6.22 Shallow ittin . 174 7398 0 0.04 11 6.18 Shallow ittin . 7 7440 0 0 8 '2 .' 6. 2 1 lat d itti 176 7484 O.Ob 0.06 15 _' 6.24 Shallow ittin . 177 7528 O.UB 0.07 20 ~' 615 Isolated ittin . 178 7571 U 0.04 12 S 6.24 Shallow ittin . 179 7614 0.117 0.05 13 ~ 6.19 Shallow it in 180 7655 l~ 0.05 I~1 _' 6.23 Shallow ittin . 181 7697 (1.U7 0.02 b 6.16 182 7740 (~ 0.05 1 a _' 6.20 Shallow ittin . 183 7781 0 0.04 1 Z 6.16 Shallow ittin . 184 7823 U.0(~ 0.07 1 £3 ! 6.18 Shallow ittin . 185 7866 0 0.08 21 I 6.18 Isolated ittin . 186 7907 0 0.06 15 3 6.23 Shallow ittin . 187 7951 (1 0.06 18 ~ 6.17 Shallow ittin . 188 7992 01a 0.05 14 , 6.22 Line shallow corrosion. 189 8034 U 0.06 17 1 6.18 Shallow ittin . 190 8077 (1 0.09 Zb 2 6.19 Isolated ittin . 191 8120 1t.07 0.09 Z4 s 6.20 Isol ted ittin . 192 8163 (1.11 0.15 41 2 6.19 Isolated ittin . 19 8202 0.0 5 0.15 41 ; 6.23 Isolated ittin . 194 8245 0.0(~ 0.19 53 (~ 6.22 Corrosion. 195 8287 U.2 , 0.23 V2 7 6.19 Corrosion. 196 8331 0.12 0.17 48 3 .18 Corrosion. 197 8374 ~~ 0.19 52 ~~ 6.21 Corrosion 198 8416 c~.'u 0.15 -11 a 6.16 Line of Pits. 199 8460 ~ r _' 'I 0.18 '; I 6.16 Line of Pits. 200 8502 0.14 t, r 5.90 Line of Pits. De osits. Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI, Pipe: 7. in 26.0 ppf L-80 Well: Body Wall: 0.362 in Field: Upset Wall: 0.362 in Company: Nominal I.D.: 6.276 in Country: Survey Date: • ELATION SHEET 1 C-11 Kuparuk ConocoPhillips Alaska, Inc. USA June 2, 2008 Joint No. Jt. Depth (Ft.) P<•n. t 11>.~~t (Inti.) Pen. Body (Ins.) Nf~n. %, ~~lc~l,~l I uss `i~, Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 201 8544 t~ 0.17 47 i 6.18 Line of Pits. 202 8583 c~. I I 0.12 i3 i 6. 1 Line of Pits. 203 8627 t~ 0.12 33 ~ 6.16 Li e of Pits. 204 8670 U.1 U 0.18 49 i 6.22 Line of Pits. 205 8712 t).t)9 0.07 Zl) a 6. 3 Line f Pits. 206 8756 tt.12 0.09 .'~ 2 6.15 Line of Pits. 207 8798 a 0.09 Z4 6.17 Line of Nits. 208 8839 tt.15 0.10 'fl _' 6.17 Line of Pits. 209 8 81 U 0.08 ~' i 6.24 Line of its. 210 8925 U.12 0.02 i _' 6.20 211 8966 U 0.05 15 s 6.17 Shallow ittin Lt. a sits. 212 9009 t1 0.07 19 _' 6.15 Shallow ittin . 213 9053 U.U~~ 0.09 26 -1 6.16 Corrosio . 214 9095 tt 0.05 15 6.20 Shallow ittin . 15 913 7 ~ ~ 0.08 21 -t 6.17 Line of Pi 216 9179 a 0.05 13 i 6.22 Shal ow ittin . 217 9218 t? 0.07 _'U t 6.19 Line corrosion. 218 9262 tt 0.09 25 s 6.19 ine corrosi n. 219 9300 tt 0.09 4 ~ 6.21 Line corrosion. 20 9339 l1 0.06 1 5 ~ 6.21 Line shallow corrosion. 221 9380 (1 0.08 21 6.18 Li a corrosion. 222 9421 U 0.1 2' -7 6.20 Line corrosion. 223 9462 c) 0.07 I t3 -1 6. 9 Shall w itti 224 9501 tt.(u~ 0.06 I5 i 6.20 Shallow ittin . 225 9545 l). I U 0.07 I ~~ ~ .17 in shat ow corrosion. 226 9587 11.t)i 0.05 14 6.21 Shallow ittin . 227 9629 U 0.08 ~ 1 6.23 Line corrosion. 228 9673 U.US 0.07 I ~) 6.20 Shallow ittin . 229 9713 t1 0.06 17 ~' 6.20 Shallow ittin . 230 9754 U 0.08 Z <' 6.21 Line corrosion. 231 9796 t~ 0.07 Zt) -1 6.22 Line corrosion. 232 9838 it 0.10 2ti > 6.17 Isolated ittin . Lt. De sits. 233 9879 t) 0.10 Z8 ~} 6.15 Li e corrosion. 234 9921 U.U7 0.10 _'i 3 6.26 Line corrosion. 235 9964 t) 0.06 I ti 6.20 Lines allow c rrosion. 236 10007 tt 0.05 15 ; 6.17 Line shallow corrosion. Lt De osits. 237 10049 O 0.07 1 ti i 6 19 Line shallow corrosion. Lt De osits. 238 10094 tt 0.06 I E, 3 6.21 Line shallow corrosion. 239 10134 t~ tt ~ 0.05 L; 5.99 Shallow ittin . De sits. 240 10173 n 0.01 a 6.22 Penetration Body Metal Loss Body Page 5 C~1 ~~ PDS Report Cross Sections u . Well: 1C-11 Survey Date: June 2, 2008 Field: Kuparuk Tool Type: UW MFC 40 No 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 4U Tubin 7 ins 26 f L-80 Anal st: .Thom son Cross Section for Joint 129 at depth 5481.58 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 95 Tool deviation = b9 ° Finger 35 Penetration = 0.443 ins HOIe 0.44 ins = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ ~^ ~ ~ i ~ ~ ~ o ~ ~ ~ ~ ~ r ~ ~ ~ ~~ ~~ PDS Report Cross Sections Well: 1 C-11 Survey Date: June 2, 2008 Field: Kuparuk Tool Type: UW MFC 40 No 213121 Company: ConocoPhillips ALaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubin 7 ins 26 ppf L-80 Analyst: I. Thomason Cross Section for Joint 195 at depth 8287.11 ft Tool speed = 43 Nominal ID = 6.276 Upset OD = 7.000 Remaining wall area = 99 In upset region Tool deviation = 68 ° Finger 36 Penetration = 0.234 ins Corrosion 0.23 ins = 62°~ Wall Penetration HIGH SIDE = UP • Cross Sections page 2 ~~ ~~ PDS Report Cross Sections Well: 1C•11 Survey Date: June 2, 2008 Field: Kuparuk Tool Type: UW MFC 40 No 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA ;~'o. of Fingers: 4U Tubin 7 ins 26 f L-80 Analyst:. J. Thompson Cross Section for Joint 127 at depth 5415.26 ft Tool speed = 43 Nominal ID = 6.276 Nominal OD = 7 Tool deviation = 68 ° Corrosion 34% Cross-Sectional Wall Loss HIGH SIDE = UP • • Cross Sections page 1 • ConocoPhiliips Alaska, Inc. KRU 1 C-11 1 G11 API: 500292271400 Well T : PROD An le TS: 42 d 10656 SSSV Type: TRDP Orig 1/14/1997 Angie ~ TD: 37 deg ~ 11300 Com letion: sssv Annular Fluid: Last W/O: Rev Reason: TAG FILL (502-503, OD:3 500) Refe ence L R ef L Date: Last U ts: 128/20 5 . TUBING Last Ta : 11147 TD: 11300 ftKB (a1o3z1, Last Tap Date: 1/132004 Max Hole 81 deg 014079 OD:3.500, ID 2 992 Art le: : . ) Casin Strin -ALL STRI NGS ~ Descri bon Size To Bottom TVD Wt G rade Thread $ Lnt Mandrewahe CONDUCTO 16.000 0 1 1 21 82.50 H-40 1 SURFACE 9.825 0 8943 4439 40.00 L$ (3592-3593, PRODUCTION 7.000 0 10427 6344 26.00 L-80 I LINER 5.000 10271 11300 11300 18.00 L-80 cas Lift Tubi Strin -TUBING Manarewane Size To Bottom TVD Wt Grade Thread 2 (5442-5443 3.500 0 1032 1 6287 9.30 L-80 E E 8RD MOD , Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 10660 - 10716 6517 - 6559 C-4,C-3 Open 56 2 1/14/1997 IPERF Zero deg. Phasing; 2 1/8" Ener'et Ga s Lift Mandr els/Valve s St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mir Run Cmnt 1 3592 2878 Camco KBMM GLV 1.0 BK 0.158 1300 8/8/2003 2 5442 3647 Camco KBMM OV 1.0 BK 0.250 0 8/8/2003 3 6950 4443 Camco KBMM DMY 1.0 BK 0.000 0 8/8/2003 4 8266 5125 Camco KBMM DMY 1.0 BK 0.000 0 8/7/2003 5 9204 5613 Camco KBMM DMY 1.0 BK 0.000 0 82/2000 8 10109 6122 Camco KBMM DMY 1.0 BK 0.000 0 1/16/199 7 10220 6196 Camco MMM DMY 1.5 RK 0.000 0 1/7/1997 Oth er lu s ui .et c. -JEWEL RY De th TVD T Descri lion ID 502 502 SSSV Camco TRDP-4E 2.813 10265 6227 NIP Camco 'D' Ni le NO GO 2.750 10272 6232 PBR Baker GBH-22 3.000 10321 6267 SHO 3.500 ` 10321 8267 TTL 2.992 ~ ~ Fish - FISH De th Desai lion Comment 11198 1 12' Dumm Valve NIP 1026610266, OD:3.500) ' RODUCiION (0.10427, OD:7.000, Wt26.00) i PBR 10272-10273, ~~ OD:3.500) LINER 10271-11300, OD:5.000, '~ Wf.18.00) SHOE 10321-10322, OD:4.000) TTL 10321-10322, OD:3.500) Pert 10660-10716) 1 12" Dummy VaWe 1119& 11199, • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 29, 2008 4:16 PM To: 'Ennis, J J' Subject: RE: 1 C-11 casing repair update (PTD# 196-172) Jim, The mechanical alternative looks appropriate. Nothing further is needed. I will place a copy of this message in the file. Good luck with the repairs. Tom Maunder, PE AOGCC -----Original Message----- From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Thursday, May 29, 2008 4:00 PM To: Maunder, Thomas E (DOA) Subject: 1C-11 casing repair update (PTD# 196-172) Tom, As we discussed on phone this morning subsequent to email below, prohibitive delays in pumping fine grind cement to heal bleeding leak have necessitated a change in plans. Rather than attempt squeeze, we're going to install a 5.5" straddle across the 7" casing leak to restore integrity. The 5.5" straddle is preferred over a 5.5" liner because risk of tubular integrity failure during subsequent frac operations is reduced. A revised conclusion to the original procedure along w/ a proposed completion sketch are attached for your review. Please let me know if you have any questions or concerns. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) ~p~p~ ~~(t~dtli ~U~ ~% ~ 2008 -----Original Message----- From: Ennis, J J Sent: .Thursday, May 29, 2008 7:17 AM To: 'Maunder, Thomas E (DOA)' Subject: 1C-11 remedial cementing update (PTD# 196-172) Good morning Tom, Pumping cement went well. PT afterwards not so much, loses 1000 psi in 15 minutes. No communication upward to OA so must be bleeding toward surface casing shoe. Plan is to spot & squeeze cmt into leak today to restore integrity. If that proves fruitless, our plan is to run a liner from existing tie back extension to above leak. I'll keep you updated on progress or lack thereof. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) -----Original Message----- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 27, 2008 2:28 PM To: Ennis, J J Subject: RE: 1C-11 remedial cementing procedure (PTD# 196-172) Jim, Thanks for the calls and updated procedure. I have apprised Commissioner Foerster of the change in plans and she has given her oral approval of your revised plan. The actual work should be documented in the operations summary submitted with the 404. Nothing further is needed at this time. I will place a copy of this message in the well file. 1 Call or message with any qu~ions. • Tom Maunder, PE AOGCC -----Original Message----- From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Tuesday, May 27, 2008 12:51 PM To: Maunder, Thomas E (DOA) Subject: 1C-11 remedial cementing procedure (PTD# 196-172) «1C-11 remedial cementing procedure 5-27-08.pdf» Tom, The cementing forward plan we discussed this morning is attached for your review. Please let know if any questions or concerns. I'm scheduled to be in a meeting most of this afternoon so please call my cell number below if any issues need resolved. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) 2 Re-Revised Rig Workover Procedure after Casing PT Failed 1C-11 Kuparuk Producer Repair Casing Leak PTD #196-172 30. RIH w/ bit on workstring & clean out to-5990' MD. POOH. 31. RIH with RBP retrieving head. Reverse circulate sand from on top of RBP. Engage and release RBP. POOH, lay down RBP. . 32. RIH w/ fiollowing FHL packer BHA on workstring: a. Baker 5" seal assembly replacement sub (5.125" OD, 4.4" ID, 6' long w/ half Muleshoe) b. 1 joint 3%" 9.3#, L-80, EUE 8rd-Mod tubing c. 2.75" Camco D nipple w/ RHC plug installed d. 1 joint 3%s" 9.3#, L-80, EUE 8rd-Mod tubing e. FHL packer (60M# shear) &PBR (40M# shear} 33. Locate 5.25" tieback extension and tag btm of barrel. Attempt to swallow any 4" OD stub that might be available in SBE. Spot brine containing 1% CRW-132 corrosion inhibitor below 5000' MD. Space out seal assembly locator 6" off bottom w/ last motion being downward. Drop balllrod & pressure workstring to 2500 psi to set FHL pkr. Shear PBR & POOH w! workstring. 34. RIH w/ Baker 7"x5.5" 3D liner hanger packer, 2 joints 5.5", 15.5#, L-80 Hydril 563 csg and 7"x5.5" CPH liner hanger packer on 3.5" workstring to straddle csg leak @ 5466' MD. Rotate and set 3D hanger. Stack weight to verify set. Drop ball and release running tool. Stroke up ~10' to engage dogs. Stroke down and stack weight to se# CPH. POOH w/ one stand of workstring . PT csg to 2500 psi. POOH, laying down workstring. 5.5", 15.5#, L-80 Hydril 563 make-up torque: 5200 ft-Ib min, 5980 ft-Ib target • Jet Lube Enviro-Safe pipe dope recommended for Hydril 563 connections Run 3'/Z" Camgletion Assembly • Drift and tally all tubing, pups, and completion equipment to 2.867" (Exceptions: min. ID of SCSSV = 2.812'x. • Record ODs and IDs of all auxiliary equipment on tubing detail. • Ensure seal rings are in place and replace any damaged seal rings as needed. Apply Jet Lube Run-N-Seal pipe dope sparingly on both the pin and box ends of tubing. • Torque for IBT tubing is determined by averaging the make up torque required for the frrst 75 joints. Proper makeup occurs when the btm of the pin makeup mark is flush with the top of the collar. • Verify that fhe rig is centered over the well prior to running the completion. 35. PU and TIH with the following completion assembly: A. PBR seal assembly w/ 4.5" locator B. 1 joint 3%2" 9.3#, L-80, EUE 8rd-Mod tubing. • Re-Revised Rig Workover Procedure after Casing PT Failed 1 C-11 Kuparuk Producer Repair Casing Leak PTD #196-172 C. Camco 3-1/2" x 1" KBG2-9 gas lift mandrel with DV installed (10' handling. pups above and below). D. 3%2" 9.3#, L-80, IBT Mod SCC tubing E. Camco 3%Z" x 1" gas lift mandrels (10' handling pups above and below) spaced out as follows. GLM's Tvpe MD TVQ Loaded with 1 KBMG 3150 2450 DV 2 KBMG 4985 3400 DV 3 KBG2-9 6473 4200 DCR Shear-Out Vafve* 4 KBG2-9 8026 5000 DV 5 KBG2-9 9360 5696 DV 6 .KBG2-9 -10,217 -6193 DV** *DCR valve is rated to shear out at 1500 psi IA-to-tubing differential. **This is the GLM shown in item C above. F. Schlumberger 3-1/2 TRMAXX SSSV set at 2308' MD (2000' TVD). G. 3%2' 9.3#, L-80, IBT Mod SCC tubing to surface. Space out ~ Land Completion 36. Locate PBR. Space out with tubing pups, positioning one fuA joint immediately below hanger. Space out should leave locator about 2 feet above fully located position when tubing hanger is in tubing spool. Land tubing hanger. Run in lock down screws. 37. With the annulus open, pressure 3%" tubing to 2,500 psi for 15 minutes. Monitor annulus for returns. Bleed down pressure in tubing to 1,750 psi. While holding 1,750 psi on tubing, pressure 3%2" x 7" annulus to 2,500 psi for 30 minutes. Record casing pressure test on chart recorder. Finish Com,~letion 38. Bleed down tubing pressure to zero. With tubing open, annulus pressure should shear the dump kill valve (1,500 psi casing-to-tubing differential needed to shear) in the #3 GLM. Monitor well. 39. Pull landing joint. Set BPV. ND BOP stack. 40. NU 3-1/8" 5M tree. Refer to picture taken in Step #3 for proper tree orientation. Pull BPV, set tree test plug. Pressure test tree to 250/5000 psi. Test packoff to 250/5000 psi. Pull tree test plug. 41. RU pump to freeze protect the well by pumping a minimum of 115 bbl diesel down the annulus taking returns from the tubing. Hook up a jumper hose from the IA to tubing and allow diesel to equalize, freeze protecting to 3246' MD (2500' TVD). 42. Set BPV. RDMO Nordic 3 rig. • Re-Revised Rig Workover Procedure- after Casing PT Failed 1 C-11 Kuparuk Producer Repair Casing Leak . PTD #196-172 Post-Rig Work 1. Pull BPV. 2. RU slickline. Pull SOV and run new GLD. Pull ball/rod & RHC plug. Bail out calcium carbonate. Pull IBP's. RDMO Slickiine. 3. Turn well over to Production via Handover Form. ~ -I I w~ /~'TQ~# 196- 17~ a ~. 0 ~L ~~ ~~ ~ .~ ~ ~ ~~ c~5 S ti~~ ~ ~`-~ ~~~ k ~~~ d6~~~-'$D~16~a-?r f~~ C'~.~,~ 1w~~ s~~~~~~~6v~~~ ®r~ mot, lam ~~ 3.S ~ ~ of S ~r~~ ~l+c. $CJ acS P~~~a s ~d F K ~ ~°k ~- ~ ~~~ oC .7 ~ t r z:t} r n t p~ ~a. C s~~~ 16~~0` ~0'l1~' ~r~ j~#i L-~~'d 13®~0' • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 27, 2008 2:28 PM To: 'Ennis, J J' Subject: RE: 1 C-11 remedial cementing procedure (PTD# 196-172) Jim, Thanks for the calls and updated procedure. I have apprised Commissioner Foerster of the change in plans and she has given her oral approval of your revised plan. The actual work should be documented in the operations summary submitted with the 404. Nothing further is needed at this time. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Tuesday, May 27, 2008 12:51 PM To: Maunder, Thomas E (DOA) Subject: 1C-11 remedial cementing procedure (PTD# 196-172) «1C-11 remedial cementing procedure 5-27-08.pdf» Tom, The cementing forward plan we discussed this morning is attached for your review. Please let know if any questions or concerns. I'm scheduled to be in a meeting most of this afternoon so please call my cell number below if any issues need resolved. Jim Ennis j.j.ennis@conocophillips.com (907)265-1544 (W) (907)632-7281 (C) ~~~ MAY ~ ~ 2D0~ • • 1 C-11 Supplemental RWO Procedure Cement squeeze 7" casing leak @ 5465-67' MD PTD# 196-172 Network# 10215166 1. Move RBP up to 6000' MD & PT 2500 psi. POOH w/ test packer. 2. RIH w/ mule shoe on workstring & spot sand on RBP. POOH w! mule shoe. 3. RIH w/ cement retainer on 3.5" workstring & set @5400' MD. PT backside 2500 psi. 4. Pump 160 bbls diesel down OA to ensure freeze protect & verify surface communication to IA is still intact. Record OA SI pressure for max cement rise calculation. Leave OA SI. Establish rate into casing leak down DP w/ 9.8 ppg brine. 5. If OA SI pressure is < 600 psi: a. Mix & pump 200 sx 15.8 ppg Class `G' w/ additives @ 2 BPM. b. Flush w/ 9.8 ppg brine to 2 bbls below casing leak. SD. c. If SIDPP exists, close surface valve & WOC 4 hrs. d. If vacuum on DP, sting out of retainer & WOC 4 hrs. e. After WOC, establish circ rate up OA w/ 9.8 ppg brine. Minimize volume pumped. f. Mix & pump 100 sx 15.8 ppg Class `G' w/ additives & flush to 1 bbl from retainer. Sting out & dump remaining cement on retainer. g. POOH w/ a stand of DP & reverse circ 2 DP volumes for cleanup. 6. If OA SI pressure is > 600 psi: a. Mix & pump 300 sx Class `G' w/ additives @ 2 BPM b. After 40 bbls cement pumped down past casing leak & if OA pressure still >100 psi, open OA valve @ surface to allow cement to rise in OA. If OA pressure < 100 psi, do not open OA valve & flush cement 2 bbls below leak to WOC. Pump 2"d stage as in Step #5. c. SI OA after 15 bbls diesel is recovered or flow stops. d. Continue to pump flush to 1 bbl from retainer, sting out of retainer & dump cement on top. POOH w/ a stand of DP & reverse circ 2 DP volumes for cleanup. 7. POOH w/ retainer stinger. RIH w/ cement drilling assembly. WOC 6 hrs. Jim Ennis 5/27/2008 • A ~..~ 4 ~ a~ ~ : .. a .) ~~ rat( (ti""S ~~ ~~ I~°"~ /k! ~~ f~~j~ t~4 ~~(~ COI~TSERQg ATip CO1~II~IISSI41S1T Howard Gober Wells Group Engineer ConocoPhillips Alaska., Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 C-11 Sundry Number: 308-079 • SARAH PALMY, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~~INE€~ APR 2 9 2008 Dear Mr. Gober: ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ ay of April, 2008 Encl. Sincerely • ~~ ~onocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 13, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7"' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • RECEIVED MAR 1 ~ 2008 Alaska Oi( 8~ Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 1C-11 (PTD# 196-172). Producing well 1 C-11 has been shut-in since December of 2007 when preparations for a frac began. The casing failed to pressure test during pre-frac wellwork. A temperature log has determined the leak to be between 1600' and 2300' RKB. The leak rate is approximately 0.75 bpm at 1950 psi. The purpose of the proposed workover is to repair the casing leak. We will pull the existing 3-1/2" L-80 tubing string. The casing leak will be repaired by backing off and replacing the bad casing. After this we will re-run the 3-1/2" L-80 tubing string. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, ~~~' Howard B. ~ober Wells Engineer CPAI Drilling and Wells ORIGINAL ,~ ~o~ ~- ,~16 ~tfa~ (~til-off ~ RECEIVED • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR ~ ¢ ZOQ8 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Commissi~r- 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Wai ~C Other ^ Alter casing ^~ Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 196-172 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22714-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO Q 1C-11 ' 9. Property Designation: 10. KB Elevation {ft}: 11. Field/Pool(s): ADL 25638,•ALK 463 RKB 41', 61' Pad Kuparuk River Field / Kuparuk Oil Pool • 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11300' 7011' 11121' 11196', 11198' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 121' 121' SURFACE 6902' 9-5/8" 6943' 4439' PRODUCTION 10386' 7" 10427' 6344' LINER 1029' 5" 11300' 7011' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10660'-10716' MD 6517'-6559' 3-1 /2" L-80 10321' Packers and SSSV Type: Packers and SSSV MD (ft) liner hanger packer @ 10279' Camco SSSV @ 502' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat March 25, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober Printed Name Howard Gober Title: Wells Group Engineer Signature Phone 263-4220 Date ~/j Commission Use Onl Sund Number: Conditions of approval: Notify Commission so that a representative may witness ~~_ O T Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: a S®~ r r~ i ~~ ~ ~ ~ ~L."~ Subsequent Form Required: ~..( i"~ ' ~~ ~~~ ~ ~ 2~~~ APPROVED BY ~ Approved by: SSIO R THE COMMISSION ~~ Date:. Form 10-403 Revised 06/2006 ~ ~ t ~ ~ ~ ~ Submit in rD~„uplyc~~~ ,~~ ~ / • Sundry RWO Procedure • REVISED 1 C-11 Kuparuk Producer Repair Casing Leak PTD# 196-172 Procedure Outline 1. Lockout SSSV at 502' RKB. 2. Set inflatable bridge plug in liner at +/-10,385' RKB. Dump bail CaC03 on top. Pressure test IBP to 2000 psi. 3. Set plug in tubing tail nipple at 10265' RKB. 4. Pull DV at 10,220' and 3592' RKB. Leave open pockets. 5. Obtain SBHP at 3592' RKB with gradient stop at 3399' RKB. 6. Set DV at 3592' RKB. Pull plug at 10265' RKB. Leave pocket open at 10,220' RKB. 7. Circ weU fuH of kilt weight brine. Current assumption is ~10 ppg. 8. Set BPV. 9. MIRU Nordic 3. 10. Pull BPV. Verify well is dead. Set BPV. ND tree, NU BOP with 3-1/2" and 7" rams. Test BOP to 250/2500 psi. MASP is 2385 psi based on SBHP of 3039 psi at 10,690` RKB (6539' TVD) taken an 1/19108. 11. Load OA with kill weight brine. OA has an open shoe. 12. Pull and stand back 3-112" L-80 tubing. Inspect exterior condition of pipe. Lay dawn any joints that have corrosion. 13. RIH with casing scraper and stinger on 3-112" drill pipe. Circulate PBR Gean. POOH. 14. RIH with retrievable bridge plug and test packer on 3-112" drill pipe. Set RBP at 10,250' RKB (just above liner hanger}. Pull up and set test packer. Test casing below to 2500 psi. Release test packer. Pull up hole setting packer and testing casing to find top and bottom of leak. POOH. 15. RU Schlumberger. Run UCI log from RBP 10,272' RKB to surface. RD Schlumberger 16. RIH and dump sand on top of RBP. POOH. 17. RIH w/ mechanical cutter cut casing beknN bad casing. POOH. 18. R!H with storm packer and set at +/-150. Pn:ssure test to 2500 psi. 19. ND BOP and tubing head. NU BOP to casing head. Test BOP below bends to 25012500 psi. 20. Break BOP at casing head. Pull casing packoffs. NU BOP. Test below blinds by pumping into OA. OA leak rate through open shoe was 1 bpm at 1225 psi on 5/28/07. 21. Pull storm packer. 22. Spear and POOH with 7" casing. 23. Set test plug in casing head. Pressure test below blinds to 250!2500 psi. Pull test plug. 24. RIH with backoff tool Rackoff T' casing stub. POOH w/ backoff tool. 25. RIH with spear. Latch onto and POOH w/ casing stub. 26. RIH with 7" casing. Screw into existing Casing and pressure test to 2500 psi. 27. ND BOP. Land casing on slips and ins#aN packoff. NU tubing head. i • Sundry RWO Procedure REVISED 1C-11 Kuparuk Producer Repair Casing Leak PTD# 196-172 28. NU and test BOP. Pressure test 7° casing to 2500 psi. Freeze protect OA with diesel. 29. RIH and pull RBP at 10,250' RKB. POOH laying down drill pipe. 30. Run 3-112" L-80 tubing out of derrick with new GLM's. RIH with gas lift completion including SSSV at 2300' RKB (2000' TVD) for future CTD option. 31. Sting into PBR. 32. Space out and land completion. 33. Pressure test tubing and IA. 34. Set BPV. ND 8OP, NU and test tree. Pull BPV. 35. Freeze protect well. Set BPV. 36. RDMO workover rig. 37. Slickline pull SOV and run gas lift valves. Bali CaCO3. Pull IBP. 38. Put well on producfion. • • Well: 1 C-11 API: 50-029-22714-00 `~/ ~t~t'1CIC~?~"11~~~~5 Field: Kuparuk PTD: 196-172 2008 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3'/2' 8rd EUE BPV: 3" FMC ISA Model: FMC Kuparuk Gen IV CONDUCTOR 16", 62.5 ppf, H-40 SURFACE CASING 9.625", 40 ppf, L-80 PRODUCTION CASING 7.0", 26 ppf, L-80, BTC-MOD LINER 5", 18 ppf, L-80 TUBING 3.5", 9.3 ppf, L-80, 8rd-MOD PERFS C-3, C-4: 10,660' - 10,716' MD A NEW COMPLETION e A: SSSV: 3-1/2" SCSSSV with 2.813" X @ -2300' M D e a B: Gas Lift Mandrel No. MD TVD TYPE s 1 3150 2450 1"KBMG 2 4985 3400 1" KBMG " g 3 6473 4200 1 KBMG 4 8026 5000 1" KBMG 5 9360 5696 1"KBMG B 6 10220 6196 1"KBMG c C: Nipple: 3-1/2" with 2.75" D profile @ 10,265' MD D D: Seal Assembly @ 10,272' MD Last Tag: 12/13/07 Tag Depth: 11,121' RKB Fill: no fill over perfs TD: 11,300' RKB - Last Updated: 13-Mar-08 Updated by: HBG • Sundry RWO Procedure 1 C-11 Kuparuk Producer Repair Casing Leak PTD# 196-172 1. Lockout SSS t 502' RKB. 2. Set inflatable bri a plug in liner at +/- 10,385' RKB. Dump bail aC03 on top 3. Pull DV at 10,220' d 3592' RKB. Leave open pockets. 4. Obtain SBHP at 359 KB with gradient stop at 3399' RKB 5. Set DV at 3592' RKB. L ave pocket open at 10,220' RKB 6. Circ well full of kill weight e. Current assumption is ppg. 7. Set BPV. 8. MIRU Nordic 3. 9. Pull BPV. Verify well is dead. N ee, NU and to BOP to 250/2500 psi. MASP is 2385 psi based on SBHP of 3039 psi at 10,6 'RKB (653 TVD) taken on 1/19/08. 10. Load OA with kill weight brine 11. Pull and stand back 3-1/2" L-80 tubing. have corrosion. 12. RIH with casing scraper and stinger. C 13. RU Schlumberger. Run UCI log from F 14. RIH with test packer on 3-1/2" drill ~!' identified during logging. Test casin top and bottom of leak. exterior condition e. Lay down any joints that ~urface. RD Schlumberger 500' RKB or below any bad casing e setting packer and testing casing to find 15. Set storm packer in 7" casing bel ny bad casing. 16. RIH w/ mechanical cutter cut c ing below bad casing. P H. 17. ND BOP and tubing head. P packoffs. NU BOP to casing ead. Test BOP. 18. Spear and POOH with 7" c ing. 19. RIH with backoff tool. Ba off 7" casing stub. POOH w/ backoff t I. 20. RIH with spear. Latch to and POOH w/ casing stub. 21. RIH with 7" casing. s ew into existing casing and pressure test. 22. ND BOP. Land cas~ g on slips and install packoff. NU casing head. 23. NU and test BOP. reeze protect OA with diesel. 24. RIH and retriev torm packer. POOH laying down drill pipe. 25. Run 3-1/2" L- tubing out of derrick with new GLM's. RIH with gas lift comple at 2300' RK 2000' TVD) for future CTD option. 26. Sting into R. 27. Space o and land completion. 28. Pressu test tubing and IA. 29. ND P, NU and test tree. 30. Fre e protect well. SSSV Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, April 25, 2008 8:15 AM To: 'Gober, Howard' Cc: Gauer, Cody; Alisup-Drake, Sharon K; Ennis, J J; Packer, J.Brett Subject: RE: KRU 1C-11 (196-172} Workover Sundry Howard, Cody, et al, This looks good. It addresses the concerns I had with the original proposal. Well done. Tom Maunder, PE AOGCC • From: Gober, Howard [mailto:Howard.Gorr@conocophillips.com] Sent: Thursday, April 24, 2008 5:43 PM To: Maunder, Thomas E (DOA) Cc: Gauer, Cody; Allsup-Drake, Sharon K; Ennis, 7 3; Packer, J.Brett APR 2 g 200F~ Subject: RE: KRU 1C-11 (196-172) Workover Sundry ~~~~~ Tom, Attached is the Revised Sundry Procedure for 1 C-11 casing repair. I think it addresses your questions and also reflects our discussion last week. Please let me know if you have any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard. Gober@conocophillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent; Friday, March 21, 2008 8:46 AM To: Gober, Howard Subject: RE: KRU 1C-11 (196-172) Workover Sundry Not a problem Howard. Good idea having Dave review. Tom From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Thursday, March 20, 2008 4:59 PM To: Maunder, Thomas E (DOA) Subject: RE: KRU iC-11 (196-172) Workover Sundry Tom, 4/25J2008 Page 2 of 2 C] • Please bear with me until early next week. As I reviewed my procedure outline, I came up with a few more things that I want to investigate. I will respond with a revised procedure on Monday or Tuesday. Thanks for your patience and your thorough review. I am having Dave Reem review my procedure and give me some comments as well. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard. Gober@conocophillips.com From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 19, 2008 10:33 AM To: Gober, Howard Subject: KRU 1C-11 {196-172) Workover Sundry Howard, This note is a follow-upon our conversation this morning regarding items in the procedure. 1. You indicated that pressure tests would be conducted after setting the IBP (step 2) and the RBP, rather than storm packer (step 15). Could you please provide the planned pressure test values? 2. In step 9, do you not intend to have a BPV in place to ND the tree and NU the BOP? 3. Similar to employing CaC03 on the iBP, will sand be employed on top of the RBP? 4. You indicated that the OA shoe is open and that 7" rams will t~ installed when that casing is pulled, however that information is not included in your procedure. Would you look into these points. As discussed, if a revised procedure is necessary send it by email Call or message with any questions. Tom Maunder, PE AOGCC 4/25/2008 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth "~ I I. h'¢ ~~~ A~Fi I ~ ~~a~ C~.~-- NO. 4650 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 04/08/08 • Well Job # Log Description Date BL Color CD 1A-19 12031469 LEE TOOL PROD PROFILE 03/21!08 1 1 F-07 12031470 PROD PROFILE r ~ ~-~~ 03/22/08 1 3A-09 11980648 PROD PROFILE ~ ~q 03/22/08 1 2A-22 11970645 MULTI-FINGER CALIPER 03/20!08 1 1 F-15 11970659 INJECTION PROFILE 04/02/08 1 1 C-11 11994642 LDL 04/03/08 1 1 G-09 11996613 INJECTION PROFILE V = 04!05/08 1 iJ-159 11994646 GLS (o.r 04!06/08 1 2W-15 11996615 PRODUCTION PROFILE -a 04/07/08 1 1 L-08 11996616 PRODUCTION PROFILE L 04/08/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • f m • ILL LOG T13~4/1/~l{~l/TT~4 _ __ _..__...-11- ProActive Diagnostic Services, Tnc. To: ACC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorege, AK 99518 Fax: (907) 2458952 1 ] MTT Report 2] 25-Mar-OS 1 G11 1 Repprt 50-029-2271400 ~~,~~ APR ~ ~ 20t~~ Igo-l~~ Signed Print Name: ~ ~ ~,. `~~ i/1-P ~,~ ~ ,~, ~,(.P.ri Date ;~;~+i ;fti~ ,i,,yd" ~_ ,ail ~. PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAtL : pctsanchorage a~memorylaa.com WEBSITE : www.memorvloq.com C:U~ocuments and 5ettings\Owner\Desktop\Trer~smit_Conoco.doc • • Memory Magnetic Thickness Lag. Results aummary Company: ConocoPhilfips Alaska, Inc. Log Date: March 25, 2008 Log No.: 8672 Run No.: 2 (MTT Run 1) Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD MOD Pipet Use: Tubing Pipet Desc.; 7" 26 Ib. L-80 Pipet Use: Production Casing Pipe3 Desc.: 9.625" 40 Ib. Welded Pipe3 Use: Surface Casing Well: 1C-11 Field: Kuparuk State: Alaska API No.: 50-029-22714-00 Top Log Intvt.: 6,941 F't. (MD) Bot. Log Intvl.: 10,278 Ft. (MD) Top Log Intvl.: 6,941 Ft. (MD) Bot. Log Intvl.: 10,278 Ft. (MD) Top Log Intvl.: 6,941 Ft. (MD) Bot. Log Intvl.: 6,951 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS The MTT data from this log has been tied into the D-Nipple ~ 10,265' (Driller's Depth). This is the first log of this well made with the 12 Arm Magnetic Thickness Tool (MTT) in this well. The MTT ' responds to the total thickness of metal of the 3.5" tubing and 7" production casing. A pass at 10Hz was made at 20 fpm from surtace to 10,278'. The additional metal volume of the 9.625" surface casing interteres with the normal function of the MTT, so no interpretable results are available from the end of the 9.625" surface casing (6,951') to surtace. ' ~~~~R~~~ APR ~ ~ 2008 INTERPRETATION OF MTT LOG RESULTS ' A tog plot of the MTT recordings at 10Hz from just above the end of the 9.625" surtace casing to 7,220' and an interval from 9,990' to 10,278' are included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool, which includes both the tubing and casing strings. ' Circumferential metal loss of 1 °~ to 2% is indicated throughout the logged interval below the 9.625" surface casing. A graph illustrating the average recorded metal thickness on a joint-by joint basis for the interval logged is included in this report. ' The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding ta, which includes influences from the 3.5" and 7" pipe. if all of the metal toss is specific to ' the 7" production casing, the percent metal loss ftom that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could also be from the exterior of the 3.5" tubing. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall ' increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness ocx:urS. In this log, the MTT was calibrated downhole (10,025'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 7" production casing. 1 ' Field Engineer: K. Mi//er Analyst: J. Burton /M. Lawrence/HY Yang Witness: C. Fitzpatrick ?roActive Diagnostic Services, Inc. % P.O. Bax 1369, Stafford, Tk 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memarylog.cam ' Prudhoe Bay Field GffiCe Phone; (907) 659-2307 Fax: (907) b59-2314 ' r~~-rya • • Average Recorded Metal Thickness Relative to Calibration Point Pipe 1 3.5 in (6946.9' -10271.7') WeN: 1 C-11 Field: Kuparuk Company: ConocoPhilips Alaska, Inc Country: USA Survey Date: January 21, 2008 D ecrease ^ In crease 220 7050 230 7368 240 7685 250 8002 GLM 4 260 8337 ~ ~ a~ y ~ 270 8654 .c Z .~ 0 Q. Q~ Q 280 8971 GLM 5 290 9307 300 9625 310 9940 GLM 6 GLM 7 318.3 10272 - 50% 0 5 0% C hange in Metal Thiclm ess (% ) Bottom of Survey = 318.3 5" 3.5" 3.~' 7030 Jt. 219 7040 7" Casing Col lar 7050 7060 Jt. 220 7070 7080 7" Casing Coll ar 7090 7100 Jt. 221 7110 3.5" Collar 7 " Ca sing Co llar 7130 Jt 222 . 7140 - - _. ~ _.. 3 5" Collar _ -- - - . ~ - -- - - ,- - ~ _ 7150 ` 7160 Jt. 223 7170 7 " Ca sing Co llar - ---- - I .5" Colla i r _ t_ 7180 7 90 1 Jt.224 ~ 7 200 5" C ollar ~ -f ~. ~4f~~ - I ~- - - i ~ ...~,,., 7 " C asin g Co llarJt. 225 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -100 -6.2 MTTP12 (rad) 3.8 ~ Magnetic Thickne~Log (10Hz) March 25, 2008 9,990'to 10.278' ~~~,~ o.k sE,r~g, ice. Database File: 1c-11.db Dataset Pathname: passJ.1 Presentation Format: 2.6 scale Dataset Creation: Wed Mar 26 13:54:59 2008 by Ca-c Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:120 -50 Delta Metal Thickness {%) 50 2.6 MTTP01 {rad) 12.6 0 Line Speed (ft/min) -100 -6.2 MTTP12 (rad) 3.8 7" Casing Collar Joint 311 10000 5" 10010 Joint 312 10020 10030 5" Collar ~ " Casing Collar --~--~---~ 10040 Joint 313 10050 10060 5" Collar 10070 ~ Joint 316 Collar SSSV (502-503, OD:3.500) Gas Lift MandreWaNe 1 (3592-3593, OD:5.500) Gas Lift MendreWaMe 2 (5442-5443, OD:5. Sf10) NIP (10265-10266, OD:3.500) PBR (10272-10273, OD:3.500) TUBING (a1o321, OD:3.500, ID:2.992) TTL (10321-10322, OD:3.500) Pert (10660.10716) 112'Dunmy Vane (11198-11199, OD:1.500) ConocoPhillips Alaska, Inc. KRU 1 C-11 ~c-~~ API: 500292271400 Well T : PROD An le TS: 42 d 10656 SSSV T : TRDP Or' Com Ietion: 1 /1 411 997 An le TD: 37 11300 Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference L Ref L Date: Last U ate: 11/24/2006 Last Ta : 11136 TD: 11300 ftK6 Last Ta Date: 11/21/2006 Max Hole An k:: 61 d 4079 Casin Strip -ALL ST RINGS Descri ion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 SURFACE 9.625 0 6943 4439 40.00 L-80 PRODUCTION 7.000 0 10427 6344 26.00 L-80 LINER 5.000 10271 11300 11300 18.00 L-80 Tubin Strip -TUBING Size To Bottom ND VJt Grade Thread 3.500 0 10321 6267 9.30 L-80 EUE 8RD MOD Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 10660 - 10716 6517 -655 9 C-4,C-3 Open 56 2 1/14/1997 IPERF Zero deg. Phasing; 2 1/8" Ene 'at Gas Lift MandrelsNalve s St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3592 2678 Camco KBMM GLV 1.0 BK 0.156 1300 &8/2003 2 5442 3647 Camco KBMM OV 1.0 BK 0.250 0 8J82003 3 6950 4443 Camco KBMM DMY 1.0 BK 0.000 0 8/82003 4 8266 5125 Camco KBMM DMY 1.0 BK 0.000 0 8J7/2003 5 9204 5613 Camco KBMM DMY 1.0 BK 0.000 0 6/22000 6 10109 6122 Camco KBMM DMY 1.0 BK 0.000 0 11/16/199 7 10220 6196 Camco MMM DMY 1.5 RK 0.000 0 1/7/1997 Otfier lu s ui ., etc. -JEWELR Y De h ND T e Descri tio n ID 502 502 SSSV Camco TRDP-4E 2.813 10265 6227 NIP Camco'D' Ni le NO GO 2.750 10272 6232 PBR Baker GBH-22 3.000 10321 6267 SHOE 3500 10321 6267 TTL 2•~2 Fish - FISH De h Descri tion Comment 11198 1 1/2" Dum Valve LOST 1/7!1997 Yh1~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth { ~ ~ ~t 'i ~, _ ~~~C/1(~ ~~ ~k ~'Utlfi ~~ i/ C{ N0.4617 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 02/28/08 • Weil Job # Log Description Date BL Color CD 1A-02 (REVISED) 11994615 INJECTION PROFILE /- 02111108 1 1C-27 11970632 WFL V - C 02/21!08 1 3R-21 11970633 LDL j _ CJ 02/22/08 1 2P-451 11996604 SBHP SURVEY O - Q4S 02/22/08 1 1C-11 11968846 LDL j - j 02120/08 1 2P-438 11964581 SBHP SURVEY ap j -~ 02/26108 1 2P-448A 11964582 SBHP SURVEY 02/27/08 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ ~ WELL LOG TRANSM/TTAL ~~, ProActive Diagnostic Services, Inc. To: AOC~C Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 {907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 1) Caliper Report 2) and ~~~~ FEB ~ ~. 7Qn ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 21 ~1an-08 1 G11 l ~ (o -t`'~-~ ~5~5~ 1 Report / EDE 50-029-2271400 :~y Y '1 ~ ;tea ~ :- `) ~,~~'~ _ ~` ' UL's Signed : Date Print Name: .Cy~r~3~; ~ti~'Y~daAti~(.P,'-. ~ '~'~ ~ ~ ;~ ~4, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8851 FAX: (907)245-88952 E-MAIL : pdsanchorageCu~memorylog com WEBStTE : www.memorylog.com D:VNaster_Copy_00_PDSANC-207a~Z_WordlDislriFw8on173ansmittal_Sheets\Trans~nit Otiginal_New.doc ~ ~ Memory Multi-Finger Caliper S, Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-11 Log Date: January 21, 2008 Field: Kuparuk Log No.: 6693 State: Alaska Run No.: 1 API No.: 50-029-22714-00 Pipet Desc.: 3.5" 9.3 Ib L-80 Top Log Intvl1.: Surface Pipet Use: Tubing Bot. Log Intvl1.: 10,321 Ft. (MD) Inspection Type : Corrosive 8 Mechanical Damage lnspection COMMENTS This caliper data is tied into the Cameo `D' Nipple NO GO @ 10,265' (Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing is in good condition. There are no significant wall penetrations (>15°~), areas of significant cross sectional wall loss (>6%) or I.D. restrictions recorded. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS No significant wall penetrations (>15%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional wall loss (>6°~) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D, restrictions are recorded. Field Engineer: Kesseru Analyst: HY. Yang Witness: C. Kennedy Pro.Active Diagnostic Services, tnc, J P.O. Box 1369, Stafford, TX 7?497 Phone: (281) or {888) 565-9085 Fax: {281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 t~(o=1'~2 ,~ f~sa • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (21.8' -10319.T) Well: 1 C-11 Field: Kuparuk Company: ConocoPhinips Alaska, Inc Country: USA Survey Date: January 21, 2008 Approx. Tool Deviation ^ Approx. Borehole Profile 1 25 50 1608 100 3194 GLM 1 150 4791 O ~ GLM 2 -- ~ ~ ~ .~ Z Y ~ 200 6397 a o p GLM 3 250 8002 GLM 4 GLM 5 300 9625 GLM 66 GLM 7 318.4 10320 0 50 100 Damage Profile (% wall) / Tod Deviation (degrees) Bottom of Su rvey = 318.4 • • PDS Report Overview ~ ~w Body Region Analysis Well: 1C-11 Survey Date: January 21, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 21330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 irts 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ,~ :, metal loss body 300 2 50 200 150 100 50 0 0 to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of 'oints anal sed total = 338 pene. 0 266 loss 94 244 72 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 6 5 1 0 0 0 Damage Profile (% wall) ~ penetration body ,F, ;, metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 7 Bottom of Survey = 318.4 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wafl: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (FtJ Nc~n. UI>~~~t Iln~.! Pen. Body (Ins.) Pc~n. % ~1~•t,il lo,t ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 22 U 0.02 - 2.89 PUP 1 25 t~ 0.02 ~~ 2.94 1.1 57 U 0.01 ~' I 2.95 PUP 1.2 62 t~ 0.01 4 ~' 2.95 PUP 2 68 U 0.03 11 2.95 3 100 U 0.02 9 > 2.94 4 132 U 0.02 7 s 2.94 5 163 t ~ 0.02 ~ I ~' 2.93 6 195 ~ ~ 0.01 5 4 2.92 7 226 i ! 0.02 7 2 2.93 8 58 t ~ 0.02 9 2.91 9 290 U 0.01 6 -1 2 93 10 322 U 0.02 9 a 2.93 11 353 (I 0.03 12 ~~ 2.93 12 385 c ~ 0.02 9 a 2.93 13 418 ! ~ 0.02 9 2.92 14 449 t ~ 0.03 1 U _' 2.93 14.1 482 U 0.01 2 _' 2.9 PUP 14.2 488 U 0 0 t~ 2.81 Camco TRDP-4E SSSV 14.3 494 U 0.02 8 2.93 PUP 15 500 t ~ 0.02 7 2.92 16 532 t> 0.03 1 U 2.92 17 564 t? 0.02 9 2.92 18 595 a 0.02 8 I 2.94 19 627 U 0.01 5 2.94 20 659 U 0.02 -1 2.94 21 691 a 0.02 9 ~ 2.94 22 722 t ~ 0.03 12 i 2.91 23 754 U .02 ~~ -1 2.93 24 786 c1 0.03 II a 2.93 25 817 U 0.02 ~) t 2.92 26 849 tt 0.02 7 ~1 2.93 27 881 U 0.01 6 2.93 28 913 l) 0.02 9 _' 2.94 29 945 c~ 0.02 t3 ~ 2.94 30 977 tl 0.02 7 a 2.94 31 1008 a 0.01 i~ 2.94 32 1040 t ~ 0.01 5 -1 2.93 33 1072 t ~ 0.03 1 1 -l 2.94 34 1104 (~ 0.03 11 _' 2.93 35 1134 t~ 0.03 13 ~ 2.93 Shallow itUn . 36 1166 t ~ 0.02 7 I 2.93 37 1198 U 0.03 11 !, 2.93 38 1229 U 0.02 9 ' 2.93 39 1261 t) 0.03 11 :' 2.92 40 1293 t1 0.03 1l) 2.90 41 1324 i~ 0.02 9 ~ 2.95 42 1355 t ~ 0.02 8 2.94 43 1387 t? 0.02 9 2.93 44 1418 ! ~ 0.01 V 2.92 Penetration Body Metal Loss Body Page 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhi9ips Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (Ft.) 1'~~n. Ul,r~t Iln~.l Pen. Body (Ins.) PFn. °i~> ~~k~i,~l I u~ ",'~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 45 1449 ~) 0.01 6 ~' 2.93 46 1481 t) 0.03 12 5 2.9 47 1513 c) 0.02 ~) -' 2.95 48 1545 i! 0.02 2.92 49 1577 U 0.02 9 -1 2.94 50 1608 c) 0.01 5 2.93 51 1640 ~1 0.02 ~! 2.92 52 1672 O 0.02 7 2.94 53 1704 t t 0.01 (> 2.94 54 1735 U 0.02 £3 t> 2 93 55 1767 ~) 0.03 11 4 2.93 56 1799 U 0.02 7 -! 2.93 57 1830 a 0.02 7 2.92 58 1862 c ~ 0.03 I I ~ 2.96 59 1895 t) 0.03 I I 2.92 60 1926 t1 0.02 t3 t 2.93 61 1957 tt 0.03 II _' 2.91 62 1989 ~) 0.03 12 2.92 63 2020 U .03 12 2.91 64 2 52 U 0.03 1 t) 2.90 65 2083 t) 0.02 ~~ 2.94 66 2115 i) 0.03 12 I 2.92 67 2146 tt 0.01 5 2.91 68 2177 n 0.03 1O d 2.91 69 2209 t ~ 0.03 1 Z -1 .94 70 2241 i ~ 0.02 i 2.94 71 2274 a 0.03 I1 2.93 72 2305 (1 0.03 1l i 2.94 73 2337 tt 0.02 ~t ~ 2.91 74 2368 t ~ 0.03 1 U Z 2.93 75 2400 t) 0.02 9 ? 2.91 76 2432 U 0.02 9 2.93 77 2463 U 0.03 11 a 2.93 78 2495 a 0.03 1 Z ~ 2.91 79 25 7 u 0.03 10 I 2.90 80 2559 U 0.02 £t ~~ 2.94 81 2591 U 0.03 11 ' 2.91 82 2622 a 0.03 11 ~' 2.92 83 2654 U 0.03 12 2.93 84 2686 t) 0.01 6 2.95 5 2717 U 0.03 1Z 2.91 86 2 749 U 0.02 7 2.92 87 2781 !) 0.01 I 2.93 88 2812 U 0.01 !~ 2.92 89 2844 U 0.02 ~ 2.91 90 2876 t) 0.02 ~t _' 2.90 91 2908 U 0.03 I ? 1 2.92 92 2940 U 0.02 ~t ? 2.91 93 2971 l) 0.03 11 I 2.91 94 3004 U 0.01 (i 2.93 ._ Penetration Body ' Metal Loss Body Page 2 1 r ~ PDS REPORT JOINTTABUTATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Body Wall: 0.254 in Upset WaH: 0.254 in Nominal I.D.: 2.992 in Well: 1 C-11 Field: Kuparuk Company: ConocoPhiMips Alaska, Inc Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (Ft.) I'~rn. ~ it>ti~~t ~ li ~~.'~ Pen. Body (Ins.) I'c~n. °~ ~1c~i,il I css "<~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 95 3036 ! ! 0.03 1 1 2.92 96 3067 ~ ~ 0.03 1 1 2.93 97 3099 U 0.03 11 2.91 98 3131 U 0.03 1 "? S 2.91 99 162 ~) 0.02 9 ~' 2.93 100 3194 t) 0.03 1 I 2.91 101 3226 U 0.03 1 i 2.89 102 3258 U 0.02 ~) 2.94 103 3289 ~) 0.03 1 U i 2.91 10 3322 U 0.03 1l) I 2.91 105 3353 U 0.01 U I 2.91 106 3384 O 0.03 13 S 2.92 Shallow ittin . 107 3416 U 0.02 ') ; 2.92 108 3447 ~) 0.03 1(t ~ 2.91 109 3479 U 0.03 1 U ~ 2.92 110 3511 U 0.01 5 I 2.93 111 3543 t~ 0.0 (> 2.93 111.1 3574 U 0.01 ~ I 2.91 PUP 111.2 3580 U 0 U t) N A GLM 1 Latch @ 7:30 111.3 3587 ~t 0.01 !~ I 2.93 PUP 112 3593 ~ ~ 0.01 t~ 2.93 113 3625 ~) 0.03 1 ~' 2.93 114 3657 t) 0.02 7 I 2.93 115 3688 a 0.03 11 2.90 116 3720 it 0.04 15 2.91 Shallo it'n . 117 3752 ~) 0.02 I 2.94 118 3783 t1 0.02 ~) t~ 2.94 119 3815 { t 0.03 10 .' 2.92 120 3847 ~ ~ 0.02 7 _' 2.95 121 3879 ~ ~ 0.01 -1 I 2.93 122 3911 ~ ~ 0.02 ~' 1 2.94 123 3942 ~) 0.02 ii .' 2.92 124 3975 U 0.01 (~ I 2.94 125 4006 !) 0.02 7 -1 2.94 126 4037 U 0.03 11 2.91 127 4070 t) 0.02 7 I 2.94 128 4101 ~) 0.03 lu ~' .92 129 4133 U 0.03 It) 1 2.92 130 4165 U 0.02 ~f _' 2.93 131 4193 t) 0.01 t, ~' 2.92 132 4224 0 0.02 ~> 2.9 133 4254 l) 0.02 ~) _' 2.92 134 4285 C1 0.01 ? i 2.94 135 4316 0 0.01 E, 2.93 136 4348 ~ 0.02 ~) _' 2.92 137 4381 t) 0.01 (, ~ 2.92 138 4412 U 0.02 is 1 2.93 139 4444 t) 0.01 G 1 2.92 140 4474 !? 0.02 `) 2.92 141 4505 ~) 0.02 2.92 Penetration Body Metal Loss Body Page 3 ~ i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (Ft.) Pc~n. (Jlrn~~t (Ins.i Pen. Body (Ins.) Pen. °i~ Mct,il Icss "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 142 4538 U 0.02 ~) 2.91 143 4569 t I 0.02 7 .94 144 4601 U 0.02 ~) I 2.94 145 4633 a 0.03 I I 2.91 146 4664 U 0.01 (~ 2.94 147 4695 (~ 0.02 `) 2.91 148 4728 (I 0.02 tt 2.92 149 4760 a 0.02 ') 2.90 150 4791 U 0.01 5 I 2.92 151 4823 (1 0.02 ~~ ' .95 152 4854 U 0.03 1O 2.91 153 4886 (~ 0.02 tt 2.91 154 4918 I ( 0.01 (~ 2.93 155 4949 t t 0.03 1 Z 2.92 156 49 2 u 0.02 ') 2.94 157 5013 (~ 0.02 ~) 2.93 158 5044 t t 0.02 ' ~ 2.91 159 5077 a 0.02 I3 ~ 2.93 160 5108 (( 0.02 I 2.92 161 5140 (t 0.02 I 2.92 162 5172 tt 0.02 £S I 2.93 163 5204 (t 0.01 ~ ~' 2.94 164 5235 n 0.03 I0 ? 2.92 165 5268 a 0.02 8 ? 2.94 166 5299 (( .01 5 I 2.94 167 5330 n 0.01 5 2.93 168 5 63 ~ t 0.02 ~) .92 169 5394 I) 0.02 7 2.93 169.1 5426 U 0.03 10 ~ 2.92 PUP 169.2 5432 (> 0 0 (t N A GLM 2 Latch ~ 4:30 169.3 5438 O.U; 0.02 ~) 2.91 PUP 170 5445 (~ 0.02 8 _' 2.93 171 5476 (~ 0.02 8 ~' 2.91 172 5508 a 0.03 11 2.91 173 5540 (t 0.03 I u I 2.92 174 5572 ~ ~ 0.02 ~) I 2.91 175 5604 U 0.02 ~) 1 2.91 176 5635 0 0.02 9 _' 2.92 177 5667 a 0.02 £3 _' 2.92 178 5699 (~ 0.01 i 2.93 179 5730 (t 0.02 7 2.92 180 5762 t ~ 0.03 1 1 1 2.92 181 5794 ~~ 0.02 '~ f 2.91 182 5826 U 0.03 11 s 2.91 183 5858 a 0.02 ~) ~' 2.92 184 5890 (~ 0.02 ~t 2.90 185 5921 (~ 0.02 ~) 2.91 186 5953 (~ 0.03 I t t 2.92 187 5985 ~ ? 0.02 2.92 188 6017 0.03 2.91 Penetration Body Metal Loss Body Page 4 i ~ PDS REPORT JOINT TABUI~TION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc Nominal I.D.: 2.992 in Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (Ft.) I'~•n. tllnc~l (In>_) Pen. Body (Ins.) Pen. `;4. alci.il Lose °i. Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 189 6048 ~ ~ 0.01 ~ _' 2.92 190 6079 ~ I 0.03 1 1 1 .90 191 6111 ~ ~ 0.01 6 _' 2.93 192 6143 t~ 0.01 ~ 2.93 193 6174 ~ ~ 0.02 9 2.92 194 6206 ~ ~ 0.02 ~ I 2.94 195 6238 i ~ 0.03 1 1 2.91 196 6270 i ~ 0.02 8 2.90 197 6303 ~ ~ 0.02 ti 5 2.92 198 6334 ~ ~ 0.03 I i) 1 2.92 199 636 i? 0.02 8 2.94 200 6397 U 0.02 7 1 2.92 201 6429 I ~ 0.02 9 1 2.94 202 6460 ~> 0.02 7 _' 2.94 203 6492 II 0.03 11 :.~ 2.93 204 6523 ~ ~ 0.02 9 2.92 205 6555 ~ ! 0.03 1 ~ I .91 206 6588 U 0.03 12 ' 2.93 207 6619 ~? 0.03 11 2 2.91 208 6651 ~ ~ 0.02 7 2.93 209 6683 ~ ~ 0.02 3 I 2.93 210 6714 ~ ~ 0.03 1O 2.93 211 6746 ~ ~ 0.03 1 ~) 2.92 212 6778 ~ ~ 0.01 b I 2.92 213 681 t~ 0.01 (> I 2.95 214 6841 U 0.02 I 2.92 215 6873 U 0. 1 5 2.92 216 6905 U 0.02 6 2.92 21 .1 6936 c~ 0.01 4 1 2.91 PUP 216.2 6942 ~~ 0 ~1 U N A GLM 3 Latch ®8:30 216. 6947 U 0.03 11 ~ 2.92 PUP 217 6956 t ~ 0.03 1 1 ~' 2.92 218 6987 t ~ 0.03 12 I 2.92 219 7019 t) 0.03 11 ~' 2.92 220 7050 O 0.01 4 2.92 221 7082 a 0.01 6 ~' 2.92 222 7114 U 0.02 - _' 2.92 223 7145 (~ 0.02 tf _' 2.91 224 7177 i) 0.02 ~~ ? 2.93 225 7209 ~ ~ 0.02 3 2.91 226 7241 ~ I 0.02 ~) I .90 227 7273 II 0.03 11) I 2.91 228 7304 U 0.02 t1 I 2.91 229 7336 t ~ 0.03 11 I 2.91 230 7368 a 0.03 11 ? 2.91 231 7400 U 0.02 9 1 2.92 232 7431 l~ 0.02 ti ? 2.91 233 7463 I ~ 0.03 I 1 _' 2.91 234 7495 ~~ 0.02 `~ I 2.93 235 7526 ~~ 0.03 2.92 Penetration Body Metal Loss Body Page 5 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 1 C-11 Field: Kuparuk Company: ConocoPhilips Alaska, Inc Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (Ft.) P~~n. Ul~~~~t IIrn.1 Pen. Body (Ins.) Pen. °/, ~tc~t.~l Ic~ss ~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 236 7558 i ~ 0.03 1 1 ~' 2.93 237 7590 II 0.02 ~) ~' 2.92 23 7622 II 0.02 ~) 2.93 239 7654 I~ 0.02 ~) 2.93 240 7685 ~ ~ 0.02 7 2.93 241 7717 ~ I 0.03 1 1 ~' 2.90 242 7749 i I 0.03 1 ~' I 2.92 243 7781 i ~ 0.02 ti ' 2.91 244 7812 ~ ! 0.03 12 2.90 245 7844 t I 0.02 8 1 2.90 246 7876 ~~ 0.03 1 Z I 2.90 247 7908 ~~ 0.03 1 u 1 2.91 248 7939 a 0.02 ~~ i 2.90 249 7971 a 0.02 iS I 2.91 250 8002 U 0.03 I ,' 2.91 51 8034 U 0.02 ') 2.91 252 8064 a 0.02 ~~ 2.91 253 8097 U 0.02 ~ I 2.91 254 8129 a 0.03 11 2.91 255 8160 U 0.03 I ~ I 2.91 256 8192 ~~ 0.02 'I I 2.93 257 8223 ~I 0.02 t3 Z .92 257.1 255 ~I 0.01 4 U .93 PUP 257.2 8261 U 0 U U N A CLM 4 Latch ~ 1 fl0 7.3 8267 a 0.01 4 II .93 PUP 258 8273 ~ I 0.03 l Z 2.91 Shallow it6n . 259 8306 I~ 0.0 ~I _' 2.91 260 8337 U 0.02 ~) 1 2.91 261 8369 ~ ~ 0.02 t3 I 2.92 262 8400 ~~ 0.03 Il) 2.93 263 32 (I 0.03 lU 1 291 264 8464 (~ 0.01 (~ _' 2.94 265 8496 l1 0.03 11 ~' 2.93 266 8528 U 0.03 l U 2.92 67 8559 0 0.02 ~) 2.93 268 8591 tl 0.02 t3 2.93 269 8623 tl .01 ~ 2.94 2 70 8654 I ~ 0.02 f3 I 2.93 271 8685 II 0.03 12 I 2.91 272 8718 U 0.01 6 I 2.94 273 8749 U 0.02 7 2.93 2 74 8781 t ~ 0.02 7 ~ 2.92 275 8813 rl 0.02 ti I 2.92 276 8845 ~~ 0.02 t3 _' 2.91 277 8877 tl 0.01 5 I 2.93 278 8909 i~ 0.01 i I 2.91 279 8941 l~ 0.02 ti 1 2.93 280 8971 U 0.02 t3 I 2.93 281 9003 ! 0.02 7 2.9 282 9035 0.02 2.92 Penetration Body Metal Loss Body Page 6 ~ ~ PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 1 C-11 Field: Kuparuk Company: ConoooPhilips Alaska, Inc Country: USA Survey Date: January 21, 2008 Joint No. Jt. Depth (Ft.) Pc~n. Ulric~t (Ins.) Pen. Body (Ins.) Pc~n. %, M~~t,~l Liss °~~> Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 283 9068 t) 0.02 8 I .93 284 9098 a 0.02 ~ 2.92 285 9130 a 0.02 '~ 2.9 286 9163 t~ 0.02 f~ I 2.93 286.1 9194 t) 0.01 > I 2.93 PUP 286.2 9199 U 0 u ~~ N A GLM 5 Latch ®1:30 286.3 9206 t~ .01 > ~I 2.93 PUP 287 9213 tI 0.02 ti I 2.93 288 9 43 t) 0.03 12 _' 2.91 289 9276 a 0.02 t3 I 2.92 290 9307 ~? 0.03 Il 2. 1 291 9339 a 0.01 ~ _' 2.94 292 9371 U 0.01 o t 2.94 293 9402 c~ 0.02 1 2.93 294 9434 U 0.02 '~ 2.91 295 9465 i) 0.03 11 I 2.91 296 9497 t) 0.0 7 2.93 297 9528 !~ 0.03 lt1 2.91 298 9561 U 0.02 ~~ ~ 2.91 299 9593 U 0.02 ~~ 2 2.91 300 9625 I ~ 0.02 7 ' 2.92 301 9657 I) 0.02 ~ 1 2.92 302 9686 ~) 0.02 t3 1 2 90 303 9718 I) 0.02 ~~ U 2.92 304 9750 U 0.01 5 11 2.91 305 9782 I ~ 0.02 I 2.91 306 9814 I ~ 0.02 ~ 2.91 307 9845 ~. ~ 0.02 ~ ~ 2.92 08 9877 U .02 ~l U 2.92 309 9909 O 0.01 5 I 2.93 310 9940 l) 0.02 7 1 2.94 311 9973 U 0.02 £i ~' 2.93 312 1000 3 U 0.02 6 1 2.90 313 1003 6 t) 0.02 r3 I 2.93 314 1006 7 U 0.02 tS _' 2.93 314.1 10098 t~ 0.01 5 -l 2.93 PUP 314.2 10104 t) 0 U u N A GLM 6 La ch ~ 9:00 314.3 10110 t) 0.02 7 I 2.92 PUP 315 10117 U 0.02 ') I 2.92 316 10149 t) 0.02 £s 2.93 317 10181 t) 0.02 ') 2.92 317.1 10212 i) 0.01 ~~ 2.96 PUP 317.2 1021 5 ~) 0 U U N A GLM 7 Latch ~ 11:30 317.3 10227 U 0.02 7 ~' 2.92 PUP 318 10233 U 0.02 7 _' 2.94 318.1 10264 U 0 U i) N A Camco'D' Ni le NO GO 318.2 10266 U 0.01 3 2.92 PUP 318.3 10272 U 0 t) t) 0.00 PBR 318.4 103 0 tt 0 O ~~ N A Tubin Tail Penetration Body Metal Loss Body Page 7 ConocoPhillips Alaska, Inc. KRU 1 C-11 ~ 1 C-11 - API: 500292271400 Well T e: PROD An le TS: 42 de 10656 SSSV T : TRDP Ori Com letion 1/14/1997 An le TD: 37 de 11300 ~y Annular Fluid Last W/O: Rev Reason TAG FILL (502.503, Reference Lo Ref Lo Date Last U ate: 11/24/2006 OD3.500) ` LastTa : 11136 TD: 11300ftK6 Last Ta Date 1 1 /2 112 0 06 Max Hole An le 61 de 4079 Casin Strin -ALL STRINGS Descri tion Size To Bottom TVD YVt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 Gas Litt SURFACE 9.625 0 6943 4439 40.00 L-80 MandreWal''e PRODUCTION 7.000 0 10427 6344 26.00 L-80 1(3592-3593, OD:5 500) LINER 5.000 10271 11300 11300 18.00 L-80 . I Tubin Strin -TUBING Ges Lift Size To Bottom TVD 1IVt Grade Thread MandreWahe 3.500 0 10321 6267 9.30 L-80 EUE SRD MOD 2(5442-5443, Pertorations Summa oD:5.500) I Interval TVD Zone Status Ft SPF Date T e Comment 10660 -10716 6517 -6559 C-4,C-3 Open 56 2 1/14!1997 IPERF Zero deg Phasing; 2 1/8" Ener' t Gas LIR MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3592 2678 Camco KBMM GLV 1.0 BK 0.156 1300 818/2003 2 5442 3647 Camco KBMM OV 1.0 BK 0.250 0 818/2003 3 6950 4443 Camco KBMM DMY 1.0 BK 0.000 0 8/8!2003 4 8266 5125 Camco KBMM DMY 1.0 BK 0.000 0 8/7/2003 5 9204 5613 Camco KBMM DMY 1.0 BK D.000 0 6/2!2000 6 10109 6122 Camco KBMM DMY 1.0 BK 0.000 0 1/16/19 7 10220 6196 Camco MMM DMY 1.5 RK 0.000 0 1/7/1997 Other lu s e ui ., etc. -JEWE LRY De h TVD T e Descri ion ID 502 502 SSSV Camw TRDP-4E 2.813 10265 6227 NIP Camco'D' Ni le NO GO 2.750 10272 6232 PBR Baker GBI-~22 3.000 10321 6267 SHOE 3.500 10321 6267 TTL 2,982 Fish - FISH De h Descri tion Comment 11198 1 t/2" Dum Valve LOST 1/7!1997 NIP (10265-10266, OD:3.500) °BR j10272-10273, OD:3.500) TUBING (0-10321, OD:3.500, ID:2.992) TTL (10321-10322, OD:3.500) Pert (10660-10716) 1 1l2' Dunmy Value (11198-11199, OD:1.500) Producer 1 C-11 (PTD 196-172)• Page 1 of 1 • Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Thursday, December 20, 2007 3:32 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) /"~ ~~//,~, (~Z~ ~~~~~ Cc: NSK Problem Well Supv; NSK Well Integrity Proj ,` C (' Subject: Producer 1 C-11 (PTD 196-172) /. Attachments: 1C-11 90 day TIO.gif; 1C-11.pdf Jim, During pre frac operations the tubing and IA were loaded with sea water in producer 1 C-11 (PTD 196-172). Immediately after loading the IA, the OA began to rapidly track the IA. The OA has an open shoe and has not been antic packed. Initial T/I/O before loading the well was 1200/1000/50. Immediately after loading the T/I/O pressures were 550/450/450. An IA pressure test was attempted and aborted when the IA and OA tracking was observed. A passing tubing pressure test to 3500 psi was completed which ensures well Integrity from the reservoir. Inner casinq.~ack „off testing was completed while pressuring up on the IA which indicated that the IAxOA communi~on,does not appear to be through the well head. Current T/l/O pressures are 285/0/300. The immediate plans are to leave the well SI (due to the loss of a barrier) and run an ultrasonic leak detection log to locate r/ the production casing leak. The repair options will depend on the LDL results but may include OA Cement Shoe and/or a Rig workover. Any required 10-403 Sundry Approval will be applied for before repair work is started. The schematic and 3 month T/I/O are attached. «1C-11 90 day TIO.gif» «1C-11.pdf» ~'~~ JAN 4 ~ 2Q~8 Please let me know if you would like anymore information. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907} 659-7043 Cell Phone (907) 943-1687 12/21 /2007 SC WELL NAME +~t.RRU1C-11 3000 2700 2400 2100 1800 1500 1200 900 600 300 0 • ------------------------- ; PLOT START TIME 21-SEP-07 13:04 ----------------- MINOR TIME MAJOR TIME WEEK D PLOT ,DURATION PLO,,,,.,,, HRS 'T EN, TIM,~E PICK TIRE: ~~ ~ ~i TAG H~HE DESCRIPTION P-V~LIIE 95 LbTEST DRILLSITE WELL WL1C-7l-CHOKE FLOW TUBING CHOKE . 390 PREV WELL I C ~~ SCRATCH 30 FLOW TUBING PRESSURE . SCRATCH_30 FLOW TUBING TEMP 4. ~ NEXT WELL PI-1C5002-11 GL CASING PRESSURE -1. ??????? ENTRY TYPE BOTH ??????? OPERATOR VERIFIED 30 SCRATCH INNER ANNULUS PRES 100. SYSTEM AUTO ENTRY _ SCRATCH 30 OUTER ANNULUS PRES 300_ ~ BOTH • ~`~ ; Cot~ocoPhllips Alaska,_lnc, 1C-11 -_ sssv (502-503, OD:3.500) Gas Lin MandreWaNe 1 (3592-3593, OD:5.500) Gas Lin MandreWaNe 2 (5442-5443, OD:5.500) NIP (10265-10266, OD:3.500) PBR (10272-10273, OD:3.500) TUBING (0-10321, OD:3.500, ID:2.992) TTL (10321-10322, OD:3.500) Perf (losso-1m1s) Mfr Cmnt 1 3592 2678 Camco KBMM GLV 1.0 BK 0.156 1300 8/8/2003. 2 5442 3647 Camco KBMM OV 1.0 BK 0.250 0 8/8/2003 t ~ 3 6950 4443 Camco KBMM DMY 1.0 BK 0.000 0 8/8/2003 ~ 4 8266 5125 Camco KBMM DMY 1.0 BK 0.000 0 8/7/2003 ~ 5 9204 5613 Camco KBMM DMY 1.0 BK 0.000 0 6/2/2000 6 10109 6122 Camco KBMM DMY 1.0 BK 0.000 0 11/16/199 S ~ ` i _ 7 10220 6196 Camco _ - _ Other (plugs, equip., et -- De th TVD T e MMM __ - - c.) -JEWELRY _ - DMY __ 1.5 escri tion RK 0.000 0 1/7/1997 _ ID 502 502 SSSV Camco TRDP-4E 2.813 I 10265 6227 NIP Camco'D' Ni le NO GO 2.750 _ ,~ 10272 6232 PBR Baker GBH-22 3.000 j ~ 10321 6267. SHOE 3.500 53~ ' ~ `"] ~ 10321 6267 -- Fish -FISH Depth ~ TTL _ _ -_ escription _ - -_ - - ~, _ _ - _ Comment _ _ 2.992 ~ i' 1 ~ 11198 1 1/2" Dummv Valve LOST 1!7/1997 ~.I - ~ ., ~ Tubint~String -TUBING - - - - ff Size T Top Bottom I TVD I ~ I Grade Thread _3.500_ 0 10321 T - - 6267 9.30 L-80 EUE 8RD MOD '-" ~' Perforations Summar r~ _ _ - Interval TVD ' Zone Status Ft SPF Date T e Comment ~ 10660 - 10716 6517 - 6559 C-4,C-3 Open 56 2 1/14/1997 IPERF Zero deg. Phasing; 2 1/8" '' Enerjet ~ ~ Gas Lift MandrelsNalves ''' St MD TVD Man Man Type V Mfr V Typ e V OD Latch Port TRO Date Run Vlv KRU 1 C-11 API: 500292271400 Well T e: PROD An le TS: 42 d 10656 SSSV T e: TRDP Ori Com letion: 1/14/1997 An le TD: 37 d 11300 Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference L Ref L Date: Last U date: 11/24!2006 Last Ta : 11136 TD: 11300 ftKB Last Tag Date:, 11/21/2006 Max Hnle Angle: Casing String -ALL STRINGS Descri tion Size To 61 deg 4079 Bottom TVD Wt _ __, Grade Thread ' CONDUCTOR 16.000 0 121 121 62.50 H-40 SURFACE 9.625 0 6943 4439 40.00 L-80 PRODUCTION 7.000 0 10427 6344 26.00 L-80 LINER 5.000 10271 11300 11300 18.00 L-80 1 112" Dummy ~ Valve (11198-11199, OD:1.500) d . . ConocJ'Phillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 nr¡ì Anchorage,AK99501 5cANNEO SE? 06 2uu \qh-- 1:J- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of these wells was rÖUnd to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water trom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. :~4~~· M.J.¿el~d ConocoPhillips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date - ft bbls ft Qal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 \(:¡G:.- {',; ¡) ~ 7)01 '1C-11 .. n" ..-' - SF NA NA NA ~O.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1 C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 AOGCC Individual Well Geological Materials Inventory Page: 1 Date: 01/21/99 PERMIT DATA T DATA PLUS RUN RECVD .-96-=~l/2 ........ GAS~LIFT ................... L~-~00='12200 ................................ FINAL-01/17/97 ~"~10186-11186 ~r-6~113oo 96-172 CBL 96-172 MWD SRVY 96-172 DSR/RZS-MD ~9S3-11300 96-~72 PROD-SPI~/TEM/ ~PRES 10S~-1077~ 10-407 ~O~,~.T~O~ Are dry ditch samples required? yes ~~d received? Was the well cored? yes ~~alysis & description received? Are well tests required? ~es ~Received? ye~~ Well is in compliance Initial CO~ENTS FINAL 01/29/97 02/12/97 FINAL 02/26/97 FINAL 02/26/97 3-5 04/02/97 04/09/97 FINAL 11/21/97 11/1 9/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11575 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1C-11 ~lLe' Iq'~, PRODuCTION PROFILE LOG 970906 1 1 1E-31 °!"'1. I~[ CBT 970905 I 1 1E-31 ,4, CET 970905 I 1 1Y-2 o~>. O5~ J~,l d' INJECTION PROFILE/WFL/(TDT-P) 970810 I 1 2A-14 ~,,.~. i c{,,~ GAS LIFT SURVEY & FBHP 970917 I 1 2 A- 16 ~ · 14 '7' FLOWING PRESSURE SURVEY 970909 I 1 3C-02 ~,~. i~ i,~,{ ( WATER INJECTION PROFIi F 970901 I 1 3C-02 q,-" ,,,[,.- INJECTION PROFll F 970904 I 1 31-12L1 <:~-~--- ~"/._. ~ JCBT 970923 I I ,,, SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above addrbss. Thank you. DATE: ARCO Alaska, Inc. Post Office Box 1 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 7, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: lC-11 (Permit No. 96-172) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU lC-11. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad RECEiVt D APR. 09 1997 Pdaska 0il & Sas Cons. c0mmissim~ Anchorage ' ' STATE OF ALASKA ALAo,~A OIL AND GAS CONSERVATION ~,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~1. Status of Well ....... (~iassificatio~"of'Ser~ice"Wei'l ....... [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-172 396-215, 396-231 3. Address ....... '§~ APl'~umber P. O. Box 100360, Anchorage, Alaska 99510 ....... 50-029-22714 ...................................... ~:::;.::_, ::':_:::.: :. ::_:~ 4. Location of well at surface i .... :' :':':-': ..... 9. Unit or Lease Name 1225' FNL, 637' FWL, Sec. 12, T11 N, R10E, UM i ~~.{ ] ~--"'*'"--r'"--'--'--'--~ Kuparuk River Unit At top of productive interval i10. Well Number 1309' FSL, 559' FEL, Sec. 35, T12N, R10E, UM ! v~rli:.:') ~, ! ._ _~BI~ 1C-11 At tot,al depth , i"~~'~-~ ....... i 11 Field and P001 1712 FSL, 627 FEL, Sec. 35, T12N, R10E, UM .......................................................... Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RBK 41', Pad 61'I- ADL 25638, ALK 463 '~'2. Date Spudded !13. Date T.D. Reached I 14. Date Comp., Susp., or Aband.i15. Water depth, if offshore 116. No. of Completions 10/28/96 ! 11/10/96 I 1/14/97 I N/A MSL One '171 ~otai Depth (MD+TVI~) I"i8. Plug Back Depth (MD+TVD)I19. Directional Surveyi20. Depth where SSSV set~21. Thickness of Permafrost 11300 7011 FT] 11211 6939 FT~ IXIYes I-INo j 502' MD/ 1650' (Approx.) 22. Type Electric or Other Logs Run . GR/Res, GR/CCL/SLTJ 23. . CASING, LINER AND CEMENTING RECORD CASING ! ...... .S__E__ _ _Tr I _N G_ __D_E__P__T_ _H ...... HOLE SIZE ~/-I-. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED ....... :1--6;; ....... 6~:5# ...... H40 ..... s~-rfj - i2i~ ..... ~-~," -'i287 S~-AS i 9.625" 40.0¢ L-80 Surf. 6943' 12.25" 775 sx AS III (Iow weight), 710 sx Class G & 60 sx AS I 7" 26.0¢ L-80 Surf. 10427' 8.5" 112 sx Class G 5" 18.0¢ L-80 10271'i 11300' , 6.125" 112sxClassG '- ~4. PerfOrations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD)" PACKER'~ET (MDi' 3.5" 1 0321' PBR @ 10303' MD TVD MD TVD ................................................................................................................... 10660'-10716' 6517'-6559' __L 2 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. · r DEPTH iNTERvAL (MD) AMouNT & KIND oF MATERIAl_ UsED '~7. pRODt~cTION TEST ....... Dat~ FirSt ProducticJn " iMethOd of Operatio~ (Flowing', ga~ lift, etc.) ........... 1/16/97 i Flowing '~ate of Test iHours Tested PRODUCTION Fc~ IOIL-BBL GAS-MCF iWATER-BBL CHOKE SIZE i GAs-OIL RATIO 3/26/97 i 4 TEST PERIOD° t 287 2964 2 176 i 10322 F-fS-W--¥UiS-i~-~iC-~-i-~-P-~-~-~-~-¢;~I~-~:;CU,--~:~5---; ...... I-OiL:~i~i: ................ i~Xs:i~-~ .......... ~WATER-BBL ~-OiE-~-~,'~i~--API*(b5~-¢i) ....................................... Press. .48~ .0 ~4-HouR RATE ! 1720 17750 12 24° ~28. CORE DATA ' " Brief description of litholo~'y, porosit'~/, f~'~ures, appare'~t dips and presence of oil, gas or water. Submit core chips. RECEIVED L ............................... Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. ........... Annulus left open - freeze protected with diesel. Top Kuparuk C 10656' 6514' Total pump volumes for this event: Bottom Kuparuk C 10854' 6662' Category 1. 34885 Top Kuparuk A 11056' 6817' Category 2. 100 Bottom Kuparuk A 11186' 6919' Category 3. 0 Total: 34985 Total To Date: 34985 31 .¥ist Of Attachments Summary of Daily Drilling Reports, Surveys ~32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Title ~(/..~ ~\~.~¢,.~~~v~ Date ~r/~7/~r Prepared Bj/ Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL RECEIVED 09 1997 ~,Jaska Oil & 6a~ Cons. Commission Anchorage Date: 1/30/97 ARCO ALASKA INC. WELL SUMMARY REPORT WELL:lC-Il t ECEIVED Page: 1 WELL ID: AK8661 TYPE: AFC:--AK8661 AFC EST/UL:$ 2000M/ 2400M STATE:ALASKA API NUMBER: 50-029-22714-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:10/28/96 START COMP: FINAL:il/17/96 10/26/96 (D1) TD: 121' (121) S UP V: RLM DAILY: $ 10/27/96 (D2) TD: 121' ( 0) S UP V: RLM DAILY: $ 10/28/96 (D3) TD: 1265' (1144) SUPV: RLM DAILY: $ 10/29/96 (D4) TD: 3783' (2518) SUPV: DCL DAILY:$ 10/30/96 (D5) TD: 5093' (1310) SUPV:DCL DAILY: $ 10/31/96 (D6) TD: 6783' (1690) SUPV: DCL DAILY:$ 11/01/96 (D7) TD: 6953' (170) SUPV:DCL DAILY:$ MW: 0.0 risc: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG Move rig 5.3 miles from IF to lC. 71,709 CUM:$ 71,709 ETD:$ 202,899 EFC:$ 1,868,810 MW: 8.3 VISC: 28 ?V/YP: 1/ 0 APIWL: 0.0 PICK UP DRILL PIPE Finish moving rig 5.3 miles from iF to lC. Accept rig at 2000 hrs. 10/27/96. Nipple up diverter. 93,959 CUM:$ 165,668 ETD:$ 202,899 EFC:$ 1,962,769 MW: 9.5 VISC: 72 PV/YP: 23/22 APIWL: 8.4 DRILLING Function test diverter. Held pre-spud safety meeting. Spud at 1200 hrs. 10/28/96. Directional drill from 121' to 1265' 79,546 CUM:$ 245,214 ETD:$ 244,360 EFC:$ 2,000,854 MW: 9.9 VISC: 66 PV/YP: 25/ 0 APIWL: 4.6 DRILLING Drilling from 1265' to 3036'. Circ out gas. Small gas bubbles around conductor. Drill from 3036' to 3504'. Circ out gas. Large amounts of sand in returns. Drill from 3504' to 3783'. Circ out gas. Large amount of sand in returns. 80,088 CUM:$ 325,302 ETD:$ 335,619 EFC:$ 1,989,683 MW: 10.8 VISC: 73 PV/YP: 33/ 0 APIWL: 5.2 DRILLING Drilling from 3783' to 5093' Small amount of gas breaking out at surface. Circ and condition mud. Monitor well. CBU. Gas cut mud at bottoms up. Increase mud weight to 10.8. Monitor well. Back ream tight hole from 1524' to 1363' 111,448 CUM:$ 436,750 ETD:$ 383,096 EFC:$ 2,053,654 MW: 10.7 VISC: 67 PV/YP: 30/34 APIWL: 5.2 SHORT TRIP TO RUN CSG Ream tight hole from 1480' to 1540' and 1660' to 1725' Drill from 5093' to 5832' CBU in top of West Sak. No problems. Drill from 5832' to 6783' 75,408 CUM:$ 512,158 ETD:$ 444,346 EFC:$ 2,067,812 MW: 10.7 VISC: 60 PV/YP: 32/30 APIWL: 4.8 RIH W/9-5/8" CSG Drilling from 6783' to 6953' Back ream tight hole from 4067' to 3880' and 2570' to 1360' Ream from 1570'-1687' ! 2218'-3366', 3985'-4017'. Circ aind condition mud. Circ hi vis sweep. Drop survey. Pump pil!l. Blow down. POH. Tight at 2910'-2818' 75,989 CUM'6 588,147 ETD'$ 715,780 EFC:$ 1,872,367 Date: 1/30/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/02/96 (D8) TD: 6953'( SUPV:DCL 0) DAILY:$ 11/03/96 (Dg) TD: 6953' ( 0) SUPV:DCL DAILY:$ 11/04/96 (D10) TD: 8800' (1847) SUPV:DCL DAILY:$ 11/05/96 (Dll) TD:10427' (1627) SUPV:DCL DAILY:$ 11/06/96 (D12) TD:10427' ( 0) SUPV:DCL DAILY:$ 11/07/96 (D13) TD:10427' ( 0) SUPV:DCL DAILY:$ 11/08/96 (D14) TD:10615' (188) SUPV:DCL DAILY:$ MW: 10.5 VISC: 51 PV/YP: 28/21 APIWL: 5.6 TEST BOPE Held prejob safety meeting. RIH w/9-5/8" to 6943' Pump cement. Bump plug. Floats OK. Shear open "ES" cementer at 2035 psi. Pump cement. Bump plug and pressure casing to 1600 psi to close cementer. OK. 136,313 CUM:$ 724,460 ETD:$ 715,780 EFC:$ 2,008,680 MW: 10.0 VISC: 42 PV/YP: 15/ 9 APIWL: 12.6 DRILLING Flush out diverter to clear cement. Gas and cement perculating out between conductor and surface casing and around cellar. Monitor well. Test BOPE to 300/5000 psi. Test casing to 2000 psi. Drill out cementer at 2041' Retest casing to 2000 psi. OK. Drill out cement from 6693' to 6802' Test to 2000 psi. OK. Drill out landing collar, float collar and cement. 227,117 CUM:$ 951,577 ETD:$ 715,780 EFC:$ 2,235,797 MW: 9.0 rISC: 48 PV/YP: 14/25 APIWL: 7.8 DRILLING AT 9550' Finish drill out cement, float shoe and new formation to 6963'. Perform LOT. Drilling from 6963' to 8800' Torqued up and packed off. Rotate and reciprocate pipe while CBU. Back ream to shoe. CBU to shoe. RIH to TD. No problems. CBU. Pump sweep. 123,213 CUM:$ 1,074,790 ETD:$ 818,705 EFC:$ 2,256,085 MW: 9.0 VISC: 48 PV/YP: 15/27 APIWL: 5.6 DOWNLOAD LWD Drilling from 8800' to 10427' ROP slowed at 10427'. Indicating formation change. Circ and condition mud. Pump hi/lo vis sweep. Monitor well. Pump pill. Pump out from 9764' to 8544' 91,009 CUM:$ 1,165,799 ETD:$ 909,371 EFC:$ 2,256,428 MW: 9.2 VISC: 46 PV/YP: 18/22 APIWL: 6.0 CHANGE RAMS Held pre-job safety meeting. RIH w/7" casing to 10427' Pump cement. Bumped plug. Floats OK. PU BOP stack. Cut off casing. ND BOPE. 198,809 CUM:$ 1,364,608 ETD:$ 909,371 EFC:$ 2,455,237 MW: 8.7 VISC: 32 PV/YP: 5/ 3 APIWL: 12.2 RIH W/3.5" DP Finish ND BOPE. Dress off 7" casing. Set pack-off and install tubing head. Test to 3000 psi. Set test plug. NU BOPE. Test rams and flanges to 300 and 5000 psi. MU BHA. Program LWD. PU HWDP. Shallow test MWD. RIH w/3.5" DP. 112,401 CUM:$ 1,477,009 ETD:$ 909,371 EFC:$ 2,567,638 MW: 11.9 VISC: 48 PV/YP: 25/20 APIWL: 5.2 WT UP TO 12.4 PPG Test casing to 3500 psi for 30 min. Drill float equipment, cement and 10' new formation. Perform FIT. Displace hole w/ll.8 ppg mud. Drilling 6.125" hole from 10437' to 10615'. 75,412 CUM:$ 1,552,421 ETD:$ 683,303 EFC:$ 2,869,118 Date: 1/30/97 11/09/96 (D15) TD: 10968' (353) SUPV: DCL DAILY:$ 11/10/96 (D16) TD:ll300' (332) SUPV:DCL DAILY:$ 11/11/96 (D17) TD:ll300' ( 0) SUPV:DCL DAILY:$ 11/12/96 (D18) TD:ll300' ( 0) SUPV:GRW DAILY:$ 11/13/96 (D19) TD: 11300' ( 0) S UP V: GRW DAILY: $ 11/14/96 (D20) TD:ll300' ( 0) SUPV:GRW DAILY:$ 11/15/96 (D21) TD:ll300' ( 0) SUPV:GRW DAILY:$ ARCO ALASKA INC. Page: 3 WELL SUMMARY REPORT ~ ~ ~ · ~u, a~ AP I WL: 4.4 POH W/HWDP Drilling from 10615' to 10670' Monitor well. Very slight flow. Gas cut mud at bottoms up. Raise mud weight to 12.4. Drilling from 10670' to 10968' After connection, survey and SPR, 3.5" IF saver sub pulled out of DP. Bit was approx. 1' off bottom. Change out saver sub and top drive grab. RIH to TD. Had oil and gas cut mud at bottoms up. Increase weight to 12.5. No problems· 88,238 CUM:$ 1,640,659 ETD:$ 818,433 EFC:$ 2,822,226 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 POH TO RUN LINER Check torque on each tool it. Download MWD. Inspect bit. No damage to BHA or bit. RIH. Check torque on DC's. Shallow test MWD. Monitor well at shoe. RIH to TD. CBU. No major gas or oil cut mud. Drilling from 10968' to 11300' Circ and condition mud. 76,293 CUM:$ 1,716,952 ETD:$ 945,524 EFC:$ 2,771,428 MW: 0.0 VISC: 52 PV/YP: 30/24 APIWL: 3.8 RIH W/5" LINER Monitor well. No problems. Inside BOP valve froze. POH to shoe. Thaw valve. CBU. Gas cut mud at bottoms up. Pump out of hole to shoe. Monitor well. OK. Drop 2" rabbit. Well not taking proper fill. RIH to TD. CBU. Gas to surface at 1/2 bottoms up. Increase mud weight to 12.6+ ppg. Pump out to shoe. Monitor well. 77,734 CUM:$ 1,794,686 ETD:$ 945,524 EFC:$ 2,849,162 MW: 12.6 rISC: 50 PV/YP: 29/24 APIWL: 4.4 POOH AFTER RUNNING LINER R/U to run casing and hold safety meeting. RIH with 5" casing. RIH w/liner to 11299'. CBU. Packing off. 72,239 CUM:$ 1,866,925 ETD:$ 945,524 EFC:$ 2,921,401 MW: 12.6 VISC: 49 PV/YP: 28/22 APIWL: 4.4 RUNNING PRODUCTION TUBING Pump cement. CIP @ 0140. Set packer. Test BOPE. R/U to run tubing and hold safety meeting. Run tubing. 174,772 CUM:$ 2,041,697 ETD:$ 945,524 EFC:$ 3,096,173 MW: 12.6 VISC: 50 PV/YP: 28/22 APIWL: 4.6 CIRCULATING BOTTOMS UP Finish running tubing. Test casing. Initially broke down at 1500 psi. Inject at 1.25 bpm @ 1300 psi. SI and pressure dropped to 400 psi. Run LOT: 980 psi w/12.6 ppg mud - EMW = 15.57 ppg. 75,647 CUM:$ 2,117,344 ETD:$ 945,524 EFC:$ 3,171,820 MW: 12.6 VISC: 53 PV/YP: 30/23 APIWL: 4.8 LAYING DOWN 3.5" DP Set packer. Test casing. TIH w/3.5" DP and liner top packer to 10264'. 73,746 CUM:$ 2,191,090 ETD:$ 945,524 EFC:$ 3,245,566 Date: 1/30/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 11/16/96 (D22) TD:ll300' ( 0) SUPV:GRW DAILY:$ MW: 12.6 VISC: 50 PV/YP: 28/20 RIGGING UP Run 3.5" tubing, test tubing. 126,179 CUM:$ 2,317,269 ETD:$ 945,524 EFC:$ APIWL: 5.0 3,371,745 11/17/96 (D23) TD:11300' ( 0) SUPV: GRW DAILY: $ MW: 12.6 VlSC: 50 PV/YP: 28/20 APIWL: 5.0 RIG RELEASED TO 1C-12 N/U tubing head adaptor and master valve and test to 5000 psi for 15 min. Release rig at 0430 hrs. 11/17/96. 96,117 CUM:$ 2,413,386 ETD:$ 945,524 EFC:$ 3,467,862 End of WellSummary for Well:AK8661 ARCO Alaska, Inc. A KUPARUK RIVER UNIT WELL SERVICE REPORT WIZ3 ~. JOB SCOPE 1C-II PERFORATE, PERF SUPPORT DATE DAILY WORK 01/14/97 PERFORATE F/10,660 - 10,716' ELM DAY 5 OPERATION COMPLEFE [ SUCCESSFUL YES [ YES KEY PERSON APC-GRIGSBY Initial Tbg Press I 0 PSI I Kl(1C-11(W4-6)) IJOB NUMBER 1130961250.1 UNIT NUMBER 8293 SUPERVISOR BLACK DAILY SUMMARY Final Tbg Press 1750 PSI Initial Inner Ann Final Inner Ann I 550 PSI 600 PSI I Initial Outer Ann I Final Outer Ann 900 PSI[ 900 PSI PERFORATE F! 10,660 - 10,716' ELM W/2-1/8" ENERJETS (DP CHARGES) @ 2 SPF W/0 PHASING TIME LOG ENTRY 09:30 MIRU SWS UNIT 8293 (SHWARTZ & CREW). TGSM - PERFORATING SAFETY & WORK OBJECTIVES. PT TO 3500 PSI. MU GUN ASSEMBLY gl (CCL/WT BAR/30' 2-1/8"EJ) 11:30 RIH W/GUN ASSEMBLY gl. TIE IN WITH 11/10/96 GR/ROP LWD & 1/1/97 GR/SLTJ. PERFORATE +/- 1500 PSI UNDERBALANCE F/10,660 - 10,690' ELM. SAW IMMEDIATE PRESSURE INCREASE TO 1700 PSI. 13: 00 POOH W/GUN ASSEMBLY gl. ALL SHOTS FIRED. 13:45 MU GUN ASSEMBLY #2 (CCL/WT BAR/26' 2-1/8" EJ). RIH & TIE IN. SHOOT F/10,690 - 10,716' ELM. 15:45 POOH W/GUN ASSEMBLY #2. RD SWS 16: 3 0 OFF LOCATION & TURNED TO PRODUCTION 00:00 qRRY-SLTN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / lC-11 500292271400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 111096 MWD SURVEY JOB NUMBER: AK-MM-60154 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS DIRECTION DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -102.00 0 0 121.00 121.00 19.00 0 0 193.31 193.31 91.31 0 37 283.74 283.73 181.73 0 35 372.98 372.94 270.94 2 5 N .00 E .00 N .00 E .00 S 73.49 E .86 N 69.26 E .43 N 19.11 E 1.98 .00N .00E .00 .00N .00E .00 .liS .38E -.17 .09S 1.28E -.28 1.61N 2.24E 1.25 463.32 463.14 361.14 552.90 552.40 450.40 643.82 642.68 540.68 734.20 731.77 629.77 824.63 819.97 717.97 4 1 N 1.59 E 2.36 5 30 N 2.56 W 1.70 8 3 N 2.69 E 2.87 11 13 N 2.94 E 3.51 14 14 N .53 E 3.39 6.34N 2.87E 5.82 13.79N 2.76E 13.19 24.51N 2.87E 23.77 39.62N 3.62E 38.57 59.53N 4.17E 58.16 914.96 907.24 805.24 15 39 1005.26 993.50 891.50 18 40 1095.54 1077.61 975.61 23 52 1188.64 1161.67 1059.67 27 2 1282.26 1244.18 1142.18 29 18 N 1.71 E 1.61 N .15 W 3.39 N 5.35 W 6.12 N 6.51 W 3.45 N 6.89 W 2.43 82.82N 4.64E 81.10 109.47N 4.96E 107.37 142.13N 3.22E 139.90 181.92N .94W 179.86 225.81N 6.10W 224.02 1373.75 1323.19 1221.19 1468.30 1402.85 1300.85 1560.00 1477.79 1375.79 1654.76 1553.04 1451.04 1747.61 1624.67 1522.67 31 12 N 5.61 W 2.19 33 57 N 3.98 W 3.05 36 25 N 2.25 W 2.89 38 25 N 2.11 W 2.11 40 34 N 3.43 W 2.49 271.63N Ii. IOW 270.06 322.37N 15.33W 320.84 375.13N 18.18W 373.40 432.66N 20.37W 430.58 491.63N 23.23W 489.28 1841.43 1694.31 1592.31 43 34 1935.18 1761.40 1659.40 45 0 2029.61 1826.96 1724.96 47 1 2122.39 1888.25 1786.25 50 16 2215.89 1946.03 1844.03 53 21 N 3.99 W 3.23 N 5.21 W 1.78 N 6.89 W 2.49 N 7.01 W 3.50 N 7.36 W 3.31 554.36N 27.31W 551.88 619.61N 32.57W 617.15 687.16N 39.75W 685.00 756.29N 48.17W 754.60 829.20N 57.37W 828.06 2401.31 2052.95 1950.95 56 12 2682.97 2206.26 2104.26 57 49 2959.40 2351.34 2249.34 58 50 3333.45 2544.86 2442.86 58 50 3706.40 2737.45 2635.45 58 58 4079.01 2924.32 2822.32 60 48 4455.55 3115.28 3013.28 58 15 4737.21 3265.67 3163.67 57 12 5015.81 3416.47 3314.47 57 16 5390.96 3618.87 3516.87 57 25 N 9.49 W 1.80 N 9.09 W .59 N 9.21 W .37 N 8.31 W .21 N 8.17 W .05 N 8.96 W .52 N 5.88 W .98 N 8.46 W .86 N 11.51 W .92 N 11.29 W .07 979.02N 79.61W 979.51 1212.17N 117.74W 1215.75 1444.46N 155.16W 1451.03 1760.82N 203.91W 1771.12 2076.90N 249.68W 2090.48 2395.60N 297.70W 2412.77 2717.32N 339.71W 2737.11 2953.53N 369.40W 2975.07 3184.21N 410.01W 3209.26 3493.85N 472.45W 3524.84 ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / lC-11 500292271400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 111096 MWD SURVEY JOB NUMBER: AK-MM-60154 KELLY BUSHING ELEV. = 102.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5766.86 3824.52 3722.52 56 13 6048.91 3978.02 3876.02 57 49 6331.22 4126.72 4024.72 58 36 6611.76 4270.42 4168.42 59 45 6871.31 4401.86 4299.86 59 23 N 9.85 W .45 3803.11N 530.18W 3839.31 N 9.02 W .62 4036.50N 568.95W 4075.89 N 9.37 W .30 4273.38N 607.30W 4315.85 N 9.32 W .41 4511.11N 646.42W 4556.77 N 9.02 W .17 4732.05N 682.09W 4780.57 7086.85 4513.48 4411.48 58 13 7458.48 4705.65 4603.65 59 29 7831.03 4897.82 4795.82 58 24 8204.73 5093.08 4991.08 58 35 8571.41 5283.41 5181.41 58 51 N 10.90 W .92 4913.63N 713.96W 4964.89 N 8.68 W .61 5227.00N 767.99W 5282.86 N 9.59 W .36 5542.09N 818.64W 5601.99 N 7.70 W .43 5857.06N 866.52W 5920.57 N 7.99 W .10 6167.54N 909.30W 6233.93 8954.45 5480.58 5378.58 59 10 9325.94 5677.15 5575.15 56 54 9698.38 5880.30 5778.30 56 58 9789.90 5930.64 5828.64 56 16 9881.90 5983.07 5881.07 54 12 N 8.65 W .17 6492.47N 956.82W 6562.30 N 9.37 W .63 6803.71N 1006.15W 6877.43 N 9.05 W .07 7111.85N 1056.11W 7189.58 N 10.40 W 1.45 7187.18N 1069.02W 7266.00 N 11.31 W 2.39 7261.40N 1083.24W 7341.53 9976.50 6039.11 5937.11 53 7 10069.94 6096.80 5994.80 50 36 10164.83 6158.16 6056.16 48 47 10257.67 6221.02 6119.02 45 57 10351.40 6288.01 6186.01 42 47 N 11.92 W 1.25 7336.04N 1098.58W 7417.65 N 12.47 W 2.74 7407.87N ll14.10W 7491.02 N 13.00 W 1.95 7478.45N 1130.05W 7563.22 N 12.35 W 3.11 7545.09N 1145.04W 7631.38 N 11.75 W 3.40 7609.18N 1158.73W 7696.82 10370.41 6301.97 6199.97 42 44 10495.53 6394.23 6292.23 42 14 10689.89 6538.85 6436.85 41 37 10881.85 6682.98 6580.98 41 3 11167.77 6904.32 6802.32 37 27 N 12.03 W 1.04 7621.81N 1161.39W 7709.71 N 13.07 W .69 7704.30N 1179.75W 7794.05 N 9.00 W 1.44 7831.72N 1204.63W 7923.78 N 10.26 W .52 7956.72N 1225.83W 8050.55 N 10.81 W 1.26 8134.58N 1258.87W 8231.39 11211.15 6938.97 6836.97 36 31 N 6.97 W 5.75 11300.00 7010.38 6908.38 36 31 N 6.97 W .00 8160.35N 1262.91W 8257.48 8212.84N 1269.33W 8310.32 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8310.35 FEET AT NORTH 8 DEG. 47 MIN. WEST AT MD = 11300 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 351.07 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 11,300.00' MD ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / lC-11 500292271400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 111096 JOB NUMBER: AK-MM-60154 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -102.00 .00 N .00 E .00 1000.00 988.52 886.52 107.79 N 4.97 E 11.48 2000.00 1806.78 1704.78 665.65 N 37.15 W 193.22 3000.00 2372.35 2270.35 1478.76 N 160.72 W 627.65 4000.00 2885.79 2783.79 2327.46 N 286.96 W 1114.21 11.48 181.74 434.44 486.56 5000.00 3407.92 3305.92 3171.18 N 407.38 W 1592.08 6000.00 3951.97 3849.97 3995.62 N 562.46 W 2048.03 7000.00 4467.75 4365.75 4841.12 N 699.99 W 2532.25 8000.00 4986.36 4884.36 5683.99 N 842.61 W 3013.64 9000.00 5503.92 5401.92 6531.14 N 962.71 W 3496.08 477.86 455.95 484.22 481.39 482.45 10000.00 6053.21 5951.21 7354.44 N 1102.47 W 3946.79 11000.00 6773.06 6671.06 8031.91 N 1239.59 W 4226.94 11300.00 7010.38 6908.38 8212.84 N 1269.33 W 4289.62 450.70 280.15 62.69 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / lC-11 500292271400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 111096 JOB NUMBER: AK-MM-60154 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 102.00 102.00 202.00 202.00 302.01 302.00 402.06 402.00 -102.00 .00 100.00 200.00 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .14 S .47 E .00 .00 .02 S 1.46 E .01 .00 2.62 N 2.59 E .06 .05 502.28 502.00 602.79 602.00 703.90 702.00 806.12 802.00 909.52 902.00 400.00 500.00 600.00 700.00 800.00 9.12 N 2.94 E 19.19 N 2.70 E 34.02 N 3.33 E 55.10 N 4.11 E 81.36 N 4.59 E .28 .22 .79 .51 1.90 1.11 4.12 2.22 7.52 3.40 1014.25 1002.00 1122.31 1102.00 1233.99 1202.00 1348.97 1302.00 1467.29 1402.00 900.00 1000.00 1100.00 1200.00 1300.00 112.42 N 4.92 E 153.11 N 2.15 E 202.51 N 3.30 W 258.86 N 9.85 W 321.83 N 15.28 W 12.25 4.73 20.31 8.05 31.99 11.68 46.97 14.98 65.29 18.31 1590.09 1502.00 1717.76 1602.00 1852.05 1702.00 1993.02 1802.00 2144.10 1902.00 1400.00 1500.00 1600.00 1700.00 1800.00 392.98 N 18.88 W 472.26 N 22.07 W 561.66 N 27.82 W 660.60 N 36.55 W 772.96 N 50.24 W 88.09 22.80 115.76 27.68 150.05 34.29 191.02 40.96 242.10 51.08 2311.33 2002.00 2489.50 2102.00 2674.97 2202.00 2864.01 2302.00 3057.32 2402.00 1900.00 2000.00 2100.00 2200.00 2300.00 905.77 N 68.03 W 1051.31 N 91.69 W 1205.49 N 116.67 W 1363.87 N 142.09 W 1527.18 N 168.57 W 309.33 67.23 387.50 78.17 472.97 85.47 562.01 89.04 655.32 93.32 3250.61 2502.00 3443.88 2602.00 3637.62 2702.00 3831.66 2802.00 4033.25 2902.00 2400.00 2500.00 2600.00 2700.00 2800.00 1690.68 N 193.66 W 1854.32 N 217.56 W 2018.55 N 241.30 W 2183.16 N 264.93 W 2356.13 N 291.48 W 748.61 93.29 841.88 93.26 935.62 93.74 1029.66 94.05 1131.25 101.58 4235.66 3002.00 4430.25 3102.00 4619.67 3202.00 4804.28 3302.00 2900.00 3000.00 3100.00 3200.00 2530.19 N 317.41 W 2695.90 N 337.46 W 2855.81 N 354.86 W 3009.24 N 378.06 W 1233.66 102.41 1328.25 94.59 1417.67 89.42 1502.28 84.61 ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / lC-11 500292271400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 111096 JOB NUMBER: AK-MM-60154 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 4989.04 3402.00 3300.0 5173.99 3502.00 3400.0 5359.63 3602.00 3500.0 5545.38 3702.00 3600.0 5726.34 3802.00 3700.0 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3162.14 N 405.59 W 3314.61 N 436.57 W 3467.95 N 467.28 W 3621.47 N 497.93 W 3769.93 N 524.42 W MD-TVD VERTICAL DIFFERENCE CORRECTION 1587.04 84.76 1671.99 84.95 1757.63 85.63 1843.38 85.76 1924.34 80.96 5906.41 3902.00 3800.0 6093.94 4002.00 3900.0 6283.76 4102.00 4000.0 6475.98 4202.00 4100.0 6674.46 4302.00 4200.0 3917.47 N 549.99 W 2004.41 80.06 4074.14 N 574.93 W 2091.94 87.53 4233.41 N 600.71 W 2181.76 89.83 4395.38 N 627.43 W 2273.98 92.22 4564.56 N 655.19 W 2372.46 98.48 6871.58 4402.00 4300.0 7065.05 4502.00 4400.0 7254.98 4602.00 4500.0 7451.30 4702.00 4600.0 7648.07 4802.00 4700.0 4732.29 N 682.13 W 2469.58 97.12 4895.43 N 710.45 W 2563.05 93.47 5053.99 N 740.98 W 2652.98 89.93 5220.89 N 767.05 W 2749.30 96.32 5388.40 N 792.71 W 2846.07 96.77 7839.00 4902.00 4800.0 8029.92 5002.00 4900.0 8221.85 5102.00 5000.0 8413.98 5202.00 5100.0 8607.35 5302.00 5200.0 5548.78 N 819.77 W 2937.00 90.93 5709.19 N 846.53 W 3027.92 90.91 5871.54 N 868.48 W 3119.85 91.93 6034.10 N 890.57 W 3211.98 92.13 6198.00 N 913.58 W 3305.35 93.37 8801.08 5402.00 5300.0 8996.26 5502.00 5400.0 9188.29 5602.00 5500.0 9371.45 5702.00 5600.0 9554.70 5802.00 5700.0 6362.26 N 937.01 W 3399.08 93.73 6527.97 N 962.22 W 3494.26 95.18 6689.93 N 987.37 W 3586.29 92.03 6841.34 N 1012.36 W 3669.45 83.17 6992.87 N 1037.16 W 3752.70 83.25 9738.21 5902.00 5800.0 9914.26 6002.00 5900.0 10078.14 6102.00 6000.0 10230.07 6202.00 6100.0 10370.45 6302.00 6200.0 7144.83 N 1061.36 W 7287.14 N 1088.39 W 7414.06 N 1115.47 W 7525.57 N 1140.73 W 7621.84 N 1161.40 W 3836.21 83.51 3912.26 76.06 3976.14 63.88 4028.07 51.93 4068.45 40.38 10506.02 6402.00 6300.0 10640.53 6502.00 6400.0 10774.36 6602.00 6500.0 10907.01 6702.00 6600.0 11037.41 6802.00 6700.0 7711.17 N 1181.32 W 7799.34 N 1199.20 W 7887.13 N 1213.40 W 7972.92 N 1228.77 W 8055.22 N 1243.91 W 4104.02 35.57 4138.53 34.52 4172.36 33.82 4205.01 32.65 4235.41 30.40 RE,C !V b ,~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ~RCO ALASKA, INC. KUPARUK RIVER UNIT / lC-11 500292271400 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/10/97 DATE OF SURVEY: 111096 JOB NUMBER: AK-MM-60154 KELLY BUSHING ELEV. = 102.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 11164.84 6902.00 6800.00 11300.00 7010.38 6908.38 8132.83 N 1258.54 W 4262.84 27.43 8212.84 N 1269.33 W 4289.62 26.79 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS CI F:! I I--I_ I BI G WELL LOG TRANSMITTAL To~ State of Alaska April 2, 1997 Alaska Oil and Gas Conservation Comm. ~01% ~ Atm.: Lod Taylor / \/[ 3001 Porcupine Dr. ~(O ~ ~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS lC-11, AK-MM-60154 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22714-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 !:t I I--I--I IM G WELL LOG TRANSMITTAL To: State of Alaska February 26, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs DS lC-11, AK-MM-60154 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS lC-11: ~(f ~ ]7 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22714-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22714-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 F! I L-I--I N 13 SEFI~ICES February 11, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Dear Sir/Madam, Re: MWD Survey lC-11 Enclosed is one hard copy of the above mentioned file(s). Well 1C-Il Tie in point 0.00 to interpolated depth at 11,300.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser industries, Inc. Company 1/29/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10753 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1 C- 11 ~ ~, .--- I "7 ~-- CEMENT BOND LOG 9701 01 I 1 1E-26 7~-I~(~ PRODUCTION PROFILE W/DEFT 970117 I 1 1F-20 C~ (r~, - ©'~' ,.~ :CEMENT BOND LOG 961215 I 1 3J-18 c~(,~ _ t"--/"-{ CEMENT BOND LOG 961213 I I SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ARCO ALASEA INC · --~. No. 3328 STATE OF N.ASKA ~ OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ?. 2/3 !i. Type of Request; Abandon_ Suspend _ Alter casing _ Repair well _ Change approved program _ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension_ Stimulate _ Pull tubing _ Variance - Perforate _ Other X 2. Name of Operator ~RQO Alaska. Inc.. .... 3. Address P, O, Box 100360, Anchorage, AK 99510 . 4, Location of well at surface 1225' FNL, 637' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1304' FSL, 590' FEL, Sec. 35, T12N, RIOE, UM At effective depth At total depth ._1784' ._F_S._L_~ 6.6_6' FEL, Sec. 35, T12Nr R10E= UM 12. Present well condition summary Total Depth: measured 1 1 3 0 0 true vertical 701 1 EffeeUve depth: measured 1 1 21 1 true vertical 6 9 4 3 Casing Length Size Structural Conductor 8 O' I 6" Sudace 6 8 2 2' 9 - 5 / 8 '~ Intermediate 1 0386' 7" Uner 1 0 31 ' 5" Perforation depth: measured None true vertical $. Type of Well: Development Exploratory Stratigraphic Service feet feet 6. Datum elevation (DF or KB) Rig RKB 41' Pad level 45' feet 7. Unit or Property name _Kupa__r:uk River Unit 8. Well number ..... 1_C~11 9. Permit number 96-172 10. APl number 5~-929-2271 4 11. Field/Pool Kuparuk River Field , .Kuparuk River Oil Pool .. _ Plugs None feet Junk None ORIGINAL Cemented Measured depth True vertical depth 250 Sx AS I 1 21 ' 330/445 sx AS 6943' III; 710 sx Class G; & 60 sx ASJ 112 sx Class G 1 0427' 112 sx Class G 1 1 300' 121' 4437' 6345' 7011' Tubing (size, grade, and measured depth 3-1/2" 9.3# L-80 EUE 8rd MOD Tail @ 10321' Packers and SSSV (type and measured depth) PBR (part of liner top assembly) Top. @ 10303' 13. Attachments Description summary of proposal _X_ Detailed operation program :14. Estimated date for commencing operation 115. Status o! well 12/9/96 _. ! Oil X (~as _ 16. If proposal was verbally approved I ' I ..Name of approver Date approved I Service ___ 17. I~ereby certify that the foregoing is true and correct to the be~;t of my knowledg-e: " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness BOP sketch_ Suspended _ Date l~-(~- DG Plug integrity _ BOP Test Mechanical Integrity Test _ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Approved Copy Returned Location clearance Subsequent form require 10- Original Signed By D vid W. Johnston RECEIVED DEC 0 6 1996 Alaska Oil & Gas Cons, Commission Anchorage IApproval Commissioner SUBMIT IN TRIPLICATE , :AM ARCO ALASKA iltC No. 3328 3/3 KRU 1C41 Annular Pumping Volume Increase Application Additional Information lC-11 was approved for annular pumping pertaining to development drilling operations in Kuparuk. The volume limit at that time was set at 35,000 bbls. As of midnight on 12/05/96, we have pumped 24,860 bbl down the 1C-11 annulus. The fluids included waste from completing lC-II, drilling 1C42, and Nordic 2% approved drilling operations on 3J-17 and 1F-20. ARCO Alaska, Inc., is requesting that the limit be increased to 45,000 bbls. for the purposes of finishing the drilling program at DS 1C. We expect to be conducting operatio~ on 1C-12 for approximately six more days. Based on our anticipated rate of generation of drilling waste as we finish this well, we would be very dose or slightly over our 35,000 bbl. limit. In addition, unplanned events may prolong our operations and place more of a burden on our waste disposal. lC-11 is the only open annulus on DS 1C. Our alternative to annular pumping is hauling the fluids offsite to one of the Kuparuk Class II dedicated disposal wells. We would prefer to continue annular pumping o,n 1C-Il for two main reasons: 1.) The cost of hauling drilling wastes offsite is +$6000~additional per day; and 2.) we will not be able to dispose of our cement wash water into the Class II disposal well, if our annular limit is exceeded at that point, and would have to store the fluid until another open annuli is available. There have been no problems with the annular pumping operations conducted thus far on lC-11. The request for increasing the annular volume limit only pertains to completion of operations on DS lC, with a "safety" amount to cover any trouble time while on 1C-12. Annular pumping operations on DS lC will not continue once Parker 245 leaves the drill site. RECEIVED DEC 0 g 1996 Alaska Oil & Gas Cons. Comrnis$iol~ Anchora. g~ .AM A~CO ALASKA ARCO Alaska, Inc. - FACSIMILE TRANSMISSION I ate: ..,t-z. [ &/_~_ ~_ Time: umber of Pages (Cover +): L fO :40 Phone: 2 ~.~ 4 ~ ~ ~ ~Location: ~1 Location: ~o~c~ . Ph,ne ~: Copies To: ~% ~~ ~ ~I~o v~. -- ,- iiii _ _ I1 II I1 II I Ii Ii ll ll I! II I1 I1 I I1 II ll 1 il ii II ii i ii ii ii II II ii ii i ii ii ii Subject: AL Kuparuk Drill Site Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 ATO- 12O9 im. Comments: DEC 0 ~ 1996 Alaska 0il & Gas Cons. Commissinn ~ nnf ..... __ _ · ill --- m TONY KNOWLES, GOVERNOR ~XLASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 15, 1996 William S. Isaacson Drilling Engineer Kuparuk Drill Site Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: request for waiver to 20 AAC 25.080(d)(4), Annular Disposal of Drilling Waste Dear Mr. Isaacson: The Commission has received your request for waiver to 20 AAC 25.080(d)(4), which restricts annular disposal of drilling waste from drilling operations in wells on the same pad. The request for waiver is intended for welP3J-17. ARCO seeks authorization to inject drilling wastes from the 4 3/4" hole section of well 3J-17 into the annulus of well lC-11 on lC pad. The 4 3/4" section of the 3J-17 well will be drilled by Nordic #2, which does not have the abili~' to dispose of waste by annular injection. ARCO has indicated that all solids generated by the drilling operation will be hauled to CC-2A for grind and inject and drilling waste fluids will be hauled to Parker 245 for annular injection. Well lC-11 was approved for annular injection on November 8, 1996. Well 3J-17 was originally drilled by Parker 245 and lost circulation problems required that a 5 1/2" casing string be set before TD was reached. Drilling plans were thenm. odi~ ,~modi led to allow' Nordic #2 to drill the remaining hole section and run a3 1/2" liner to TD. / ~'~,~_...~/· The Commission hereby ~ants a waiver to ARCO Alaska, Inc. for well 3t/- 17 from the limitations of 20 AAC 25.080(d)(4). Under the circumsta,nces, the Comudq/ission finds that it would be imprudent to limit annular disposal to a well on oJ pad. The ~illing wastes from well 3J-17 may be taken to Parker 245 for annular disposal into well~.(-~ttbject to the other terms and conditions of the Commission's authorization covering the latter well. Chairman MEMORANDUM TO: State of Alaska // Alaska Oil and Gas Conservation Commission David Joh~~, DATE: November 13, 1996 Chairman THRU' Blair Wondzeli, ~,.0..~ P. I. Supervisor ttfl~ FROM: Bobby F o-s'~-~ SUBJECT: Petroleum InsC)ector FILE NO: AAXIKMDD.doc BOPE Test - Parker 245 ARCO - KRU - 1C-11 PTD # 96-0172 Wednesday, November 13, 1996: I traveled this date to ARCO's KRU well 1C - 11 being drilled by Parker rig 245 to witness to witness the upcoming weekly BOPE test. i arrived at the rig at 10:00 AM and the test began at 10:45 AM. The first pressure test was to be the annular preventer and the last set of valves in the choke manifold. The element began leaking and continued to leak after crew cycled the element. I told the driller that we should continue with the test and replace the element after competition of the test. The next test was to be the upper set of pipe rams, the inside kill line valve and the last set of valves in the choke manifold. There was another leak, so the valves were cycled in the choke manifold. There was still a leak so the process of elimination started and it was determined that the inside kill line was leaking. The outside kill line valve was closed and the test was continued. A\~f the valves in the choke manifold were successfully tested until the last valve was being tested along with the floor safety valve. There was another leak and the crew was looking for that leak when, due to this being change out day for me, i had to depart the location at 1:15 PM, i told the toolpusher, Fred Hebert, to be sure to repair ali items and to fax a copy of the BOPE test to the Anchorage office. As a note, this rig usually can be tested in 2.5 hours and has very few failures, but~ there has not been a test witnessed by an inspector since 8~20~96 due to various } t reasons. This is a very good reason that ever rig should have a witnessed BOPE ) test at least every 4 to 6 weeks. Summary: ! attempted to witness the BOPE test o Parker rig 245 drilling ARCO's KRU well 1C - 11. _X_ Unclassified Confidential (Unclassified if doc. removed ) STATE OF A!.ASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Ddg Contractor: PARKER Rig No. Operator: ARCO Well Name: 1C-11 Casing Size: 7"X5" Set @ 11,300' Test: Initial Weekly X Other 245 PTD # Rep.: Rig Rep.: Location: Sec. 96-0172 DATE: f 1/13/96 Rig Ph.# 659-7670 GUY WHITL OCK FRED HEBERT 12 T. lfN R. fOE Meddian Urn. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: O (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Dri. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F f 500/5,000 P 1 500/5,000 P I 500/5,000 * · 500/5,000 * BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves 2 Check Valve 500/5,000 500/5,000 * 500/5,000 * 500/5,000 * 500/5,000 P Test Press. P/F 300/3,000 F P 500/5,000 N/A F MUD SYSTEM: Visual Alarm Tdp Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector * * H2S Gas Detector * * CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure 16 ! 500/5,000 4~. 500/5,000 ¢ Functioned I Func§oned P/F P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2300 I. minutes * sec. minutes * sec. YES Remote: YES Psig. Number of Failures: 4 ,Test Time: 2.5 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within f days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Due to having to make change out with Chuck Sheve ! had to depart the Ioca~fon before thettest was completed. This is not a good test. This rig has not had a witnessed BOPE test since 8/20/96 to various reasons. it is a good reason why we should witness a test every 3 to O weeks. Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER F1-021L (Rev. 12/94) AAXIKMDD.XLS NOV, 6, !996 9'08AM AR~o~O=~ALASKA INC No. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type o[ Request: Abandon 2. Name of Operator AB_CO Alasl~. Inc, ,3. Address P, O. Box 100360, Anchorage, AK 99510 4. Localion of well at surface Suspend Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair weT_ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing -- Variance - Perforate_ Other ~ $. Type of Well: 6. Datum elevation (DF or KB) Development ~ Exploratory _ Rig RK_B 41' Pad Level 45' fee[ Stratigraphic _ 7. Unit or Property name Service 1225' FNL, 637' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1304' FSL, 590' FEL, Sec. 35, T12N, R10E, UM (planned) At effective depth At total depth 1784' FSL~ 666' FEL, Sec,. 35~ T12N,_R_!OE, UM (p!anned) 12. Present well condition summary Total Depth; measured 10427' feet Plugs None true vertical Kuparuk River Unit _ Et. weli number , 1¢-11 . 9. Permit number ._9_6-'172 lO, APl number s0-0__.2_9 - 2 2 71 4 11, Field/Pool Kuparuk River Field , Kupa...r. uk River Oil ,.pool _ 6345' feet (,Note: prep to set casing @ 00:01 11/6/96) Effective depth: measured 10427' teat Junk None true vertfcal 6345' lee[ Casing Structural Conductor Surface Intermediate Production Liner Perforation deplh: Lenglh Size 80' 16" 6822' 9-5/8" measured None true vertical Cemented Mgasured depth True radical depth 250 Sx AS I 121' 330/445 sx AS 6943' I11; 710 sx Class G; & 60 sx ASI 121' 4437' ORIGINAL 13. Tubing (size, grade, and measured depth None Packers and S$$V (type and measured depth) None Attachments Description summ~ry of proposal Detailed opera[ion program _ BOP sketch_ 14, Estimated date [or commencing operation 15. Stalus of well classification as' , 1 1/1'1/96 o, _X~ 6;,s _ 16. If proposal was verbally approved approver Date approved $ervice 17. I hereby cattily' the1 the.~/reg-~ing is true and correct I,o the best of my knowledge. S__i.gned~ .!~ Ti,e Drill Site Dev, Supv~ FOR COMMISSION USE ONLY C~)nditions of al~l~;ovah Noti~ ~f'~nission S; repre,en~'atiw may witness Plug integrity ~ BOP Test_ Location clearance Mechanical Integrity Test_ Subsequenl [orm r-'~quire lO- ,~/"~"/ Original Signed By Approved by the order o[ the Commission Oavid W. Johnston Commissioner Suspended _ IAPl~roval ~odj/.' ,___ -alS. -'orrn 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE RECEIVED NOV 0 6 ~' , Alaska Oil & [-',as Cons. Commission A r '"' .... nj! ,~,lu.', ,0:, .~,9 Nov, 6, 1996 9'08AM AP, CD_ALASKA iNC ARCO Alaska, inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 27'6 1215 November 6, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Annular Pumping Approval for KRU Well 1C-Il Dear Mr. Johnston: Kuparuk River Unit Well lC-11 was perrrdtted to drill on October 25, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the lC-11 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. Lf you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Mike Drill SiteCDevelopment Supervisor Ala,~l(~, Oil 8.,. Gas Cc, ns C,omrnission /'.. ,~,, i: ,,. ,.~;': ...~ , AR,Cl. E-6003-93 242' ?_.~ 03 Nov. 6. i996 9'09AM AR6.ff.ALASKA iNC No, 2794 ?, 4/6 KRU 1C-11 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 1C-II for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska I_nc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 6953' MD / 4442' TVD Surface Hole Conditions: Tight spots were seen during drilling and tripping operations from mid-permafrost to base Ugnu, necessitating a hole opener run at TD, Large amounts of sand sloughing and persistent shallow hydrates (first noted in the original 1981 drilling program on DS lC) resulted in weighting up the mud to 10.8 ppg for hole stability. Casing was run to bottom with one tight area in the Ugnu, with precautionary circulation occurring at 2200' and 4200'. No fill was seen on bottom. Full returns were seen at all times. Mud weight was reduced slightly to 10.5 ppg without problems, as the new blend of lightweight lead AS III would be pumped at a density of 10.5 ppg. Stage Tool Placement: 1Cd. 1 was cemented as a two stage job using Halliburton's Type H ES Cementer placed at the base permafrost (2041' MD). Casing Placement: The casing was reciprocated until approximately halfway through the first stage cement job. The pipe was completely free prior to this point. The surface casing shoe was placed at 6943' MD, 10' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing (9.5 bpm) and during the cementing operation itseIf (7-9 bpm). Cement contaminated mud was circulated out after shifting open the ES Cementer. 10.5 ppg cement (the pumped weight of the new lightweight slurry) was seen at surface prior to dropping the plug and shifting the Cementer dosed. Excess on the first stage lead cement was 40%, with 35% on the tail cement. The second stage lead was pumped until cement came to surface. The first stage excess factors were based on historical data (3A-17 surface hole bond log) and surface hole caliper logs performed at Milne Point, and were very conservatively calculated with the intent of bringing tail cement to 500' above the top of West Sak. Based on the data, there should be an adequate seal for safe ara~ular pumping operations. Diagnostic LogS: None. Oil & (las Cons. f: nr~ ".¢ ~.,~ ..... I'4ov, 15, lYY5 Y'UYAM ARGO~._ALASKA iNC .... J)4o, Z'/Y4 F, ~RCO Alaska, Inc. Well#: Casing Size 9 518" Centralizers Mud Spacer Lead Cement STAGE 1/2 Tall Cement STAGE 112 Displacement STAGE 112 Cementing Details 1 O- 11 Field; KUPARUK I Date: . 1 1 / 0,.3/.9 6 Hole Diameter Hole Angle Shoe Depth ! Float DepthI % washout 12.25" 58° 6,943' 6,855' State type u~edr intervals covered and sp_aci, ng 30 Gemco centralizers. 4 Gemeco Stop Collars. let 28 Its and either side of cementer Weight 10.9/10,5 YP(prior cond) 40 lbs/100 it2 YP(after cond) I PV(prior cond) 21 lbs/100 ft2J 35 cP Gels before Gels after Total Volume Circulated 1 2/22 7/1 0 1500 bbls Type Volume Water 20/20 Type IMix wtr temp No. of sacks Weight ASLW ! 60 330/445 10,5110.5 ~V(after cond) 28 cP ,, We'ight 8.3 PPG Yield 4,41 Additives iG + 3.5% DO44~ ,4% DO46, 30% D53r 1.5% DO79, 50%._ D124~ 1.5% SOO1 'Type [MiX wa~;r tempi No. of sacks 'J Weight[ ¢,eld ;G/AS 1 710/60 J 15.8/15.8 1,15/o.93 STAGE 1' G, 2.66% DO29, .2% DO46, .3% DO65, 1% SOO1 STAGE 2: ASI Rate(before tail at shoe) g Reciprocation length 15' Theoretical Displacement 516/155 Rate(tail around shoe) 7 Reciprocation speed 10 fpm Actual Displacement 526/1 57 Str. Wt. Up 250 Str. Wt, Dh. 150 Str. Wt. Mud 150 Calculated top of cement I CIP 11/3/96 Bumped plug J FIoats held ~surface ]2o:34 / 23:21 yes/yes _ [ yesl~/es Remarks; Include whether full returns were obtained, reciprocation thrgughout operation and any. other pertinent_information, _Stage 1' Pumped 1st stage lead and tail slurries w/100% returns through out entire job. Stopped reciprocating_220 bbls into displacement due to drag. Floats OK. Opened ES cementer at 2035 psi. circ out approx 30 bbls cement contaminated mud, Circ hole clean at 9.5 BPM Stage 2: Pumped 1st stance lead and tail slurries w/100% returns through out entire job, _ Had cement to surface with 350 bbls lead pumped. Switch to tail cement, Displace with rig pumps. Closed ES cementer at 1050 psi. Press to 1600 psi and hold 2 min. Bleed off. Cementer OK, , Cement Company J Rig Contractor J Signature Dowell J Parker [Donald Lutrick 9 09AM ARC~ALASKA iNC No. 2794 P. 6/6 CASING.AND LEAK-OFFFRACTU. RE TESTS Well Name: KRU lC-11 Supervisor: Donald Lutrick Date: 10/9/96 Casing Size and Description: Cesing Setting Depth: Mud Weight: 9 8,5 9 5/8", 40#~ L-00, BTC LOT = 850 psi / (0.052 x 4449 ft) + 8.5 ppg = 12.2 ppg Fluid Pumped = 1.38 bbb. # TMD 4439' _,TVD ppg EMW = Leak-off Pressure (PL_O) + MW 0.052 x TVD Hole Depth (md)-- 6953 Pump output = ,085 bps 2000 lg00 1800 1700 1600 1600 1400 1300 1200 1100 1000 9O0 800 700 600 60O 400 30o 200 lO0 0 STROKES RECEIVE[) Cons. 6ommlssio~ A n..'-.'.':o."? rm .... ,,~-' ~ov. 5. !995 9'08AM ARC0~ALASKA II~C FAX,COVER SHEET TO: AOGCC FAX NUMBER: FROM: PHONE NUMBERS: FAX NUMBERS: 907-276-7542 Sharon Allsup-Drake (907) 263.4612 (work) (907) 265-6224 (fax) ORIGINAL NUMBER OF PAGES: 6 (INCLUDING THIS COVER SHEET) MESSAGE: PLEASE RUSH. WE WILL NEED BY MONDAY NOVEMBER 11, 1996. Best Regards, Sharon AIIsup-Drake RECEIVED TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATI ON C OMMISSI ON 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 25, 1996 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Unit 1 C-11 ARCO Alaska, Inc. Permit No: 96-172 Sur. Loc. 1225'FNL, 637'FWL, Sec. 12, T11N, R10E, UM Btmhole Loc. 1784'FSL, 666'FEL, Sec. 35, T12N, R10E, UM Dear Mr. Zanghi' Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operatiop, s until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling belo~v the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~ hyai~InaRl~~OMMiS S i ON - dlf/Enclosures CC~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental ConserYation w/o encl. STATE OF ALASKA ALA,.,,,A OIL AND GAS CONSERVATION COMMISL. N PERMIT TO DRILL 2O AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [~] Deepen [--] Service [] Development Gas [--] Single Zone X Multiple Zone [-1 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25638, ALK 463 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 1225' FNL, 637' FWL, Sec. 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1304' FSL, 590' FEL, Sec. 35, T12N, R10E, UM 1C-11 #U-630610 At total depth 9. Approximate spud date Amount 1784' FSL, 666' FEL, Sec. 35, T12N, R10E, UM 1 0/25/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 C-1 2A 11377 MD 1304' @ Target feet 15' @ 300' feet 2560 7086' TVD feet 1~. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 57.72° Maximumsudace 41 45 psig At total depth (TVD) 4500 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD '1'VD linclude stage dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625" 40.0# L-80 BTC 6898' 41' 41' 6939' 4433' 2190 Sx Arcticset III & HF-ERW 560 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 10487 41' 41' 10528' 6437' 100 Sx Class G 6.125" 5" 18.0# L-80 LTC 849' 10528' 6437' 11377 7086' 140 Sx Class G HF-ERW 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 Structural Conductor R E C E IV E D Production Liner OCT Perforation depth: measured true vertical A]~ska 0il & Gas Cons. c0mmissio~ 20. Attachments Filing fee X Property plat r~ BOPSketch X Diverter Sketch X li~31~¢~ram X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report r~ 20 AAC 25.050 requirements X 21. I hereby certify that the f/bregoing is/~,rue and correct to the best of my knowledge S,gned .~'. ~ T, tle Drill Site Develop. Supv. Date ir /" ~ Commission Use Only Permit Number I ~P,I nu.~Cer , I Approval date - ~ I See cover letter for I- I /O---,~,~ I other requirements Conditions of approval Samples required [~ Yes ~ No Mud log required E~ Yes ~ No Hydrogen sulfidemeasures '~ Yes ~ No Directional survey required ~ Yes ~ No Required working pressure for BOPE [] 2M r-] 3M J~ 5M r~ 1OM [] 15M Other: Original Sign ,o '" by order of l % Approved by David W. J0h!ls'i:0rl Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplic~ · , . , , · . , · 10 11 12 13 14 15 16 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 1C-11 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6939')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 5000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (10,528') according to directional plan. Run and cement 7" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 7" casing to 3500 psi. Drill 6-1/8" hole to total depth (11,377') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run & cement 5" liner. Set 7" x 5" liner hanger and liner - top packer. Run completion assembly. Test tubing & annulus to 3500 psi. ND BOPE. NU tubinghead and production tree. Shut in and secure well. Clean location and release rig. RECEIVED OCT2 1 1996 DRILLING Well FLUID PROGRAM KRU 1C-1 1 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 12.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2624 psi could be reached. Maximum anticipated intermediate pressure is calculated using a intermediate casing leak- off of 14.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 4145 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 5000 psi. The nearest existing well to 1C-11 is 1C-12A. As designed, the minimum distance between the two wells would be 15' @ 300' MD. Drilling Area Risks: Risks in the 1C-11 drilling area include lost circulation and high pressures in the Kuparuk formation, which are addressed: 7" casing will be topset above the Kuparuk and Parker 245 will drill out a 6-1/8" hole, and run a 5" liner to TD. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 12.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to leak-off or to a maximum of 16 ppg EMW upon drilling out of the surface casing. The 7" casing shoe will be tested to an equivalent mud weight of 14.0 ppg upon drilling out of the intermediate casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. /-,.,NULAR PUMPING OPERATI(.,..,S WELL KRU lC-ll Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). (Note that cement rinseate will not be injected down the ~ledicated disposal well but will be recycled or held for an open ann~Jlus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1C-11 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1C-11 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4266 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Pad lC Hell : 11 slot #11 K~ruk River Unit North Slope, Alaska RECEIVED 0(',1"2. 'i Ar,~ho.~ege 3-D M I N I M U M D I S T A N C E C L E A R A N C E Baker Hughes INTEQ REPORT Your ref : 11Version~r~ ' Our ref : prop18~O License : Date printed : 10-0ct-96 Date created : 9-0ct-96 Last revised : 10-0ct-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.17~,w149 30 19.124 Slot Location is nTO 19 33.125,w149 30 0.530 Slot Grid coordinates are N 5969008.463, E 561640.514 Slot Local coordinates are 1225.00 S 637.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wel[path PGMS <O-9002'>,,lOGI,Pad 1C GMS <0-7780'>,,1,Pad lC GMS <O-7615'>,,2,Pad 1C GMS <O-9700'>,,3,Pad 1C GMS <0'7575'>,,4,Pad lC GMS <O-7753'>,,5,Pad 1C GMS <O-10243'>,,6,Pad 1C GMS <O-978~'>,,7,Pad 1C GMS <O-9600'>,,8,Pad 1C HSS <O-7000'>~,gGI,Pad 1C 1C-12A Version fl4,,A,Pad 1C Closest approach with 3-D Minimu~ Distance method Last revised Distance M.D. Diverging from M.D. 5-Aug-92 248.9 20.0 20.0 5-Aug-92 878.4 300.0 300.0 5-Aug-92 757.5 300.0 300.0 5-Aug-92 637.9 300.0 300.0 5-Aug-92 517.8 20.0 20.0 5-Aug-92 398.0 220.0 220.0 5-Aug-92 277.9 300.0 300.0 5-Aug-92 158.4 300.0 300.0 5-Aug-92 35.7 280.0 280.0 5-Aug-92 165.7 300.0 300.0 10-0ct-96 15.0 300.0 300.0 5OO 5OO lOOO 1500 2OO0 2500 3000 3500 4000 ,-- --I,-- 4500 k_ 5000 I 55OO 6000 65OO 7OOO 75OO 8000 ARCO ALASKA, Inc. Structure : Pad lC Well: 11 Field : Kuparuk River Unit Location : North Slope, Alaska <-- West (feet) Created by hfinch FOR: O. PETt~.~SH~ 1800 1200 600 0 600 [ ' ' ' ' ' ' ' ' ' ' C~rdrnot~ om ;n f~ re~ ....... I~ ~11. [ [ TD LOCATION: Tree Ve~col ~s ore r~ence RKB (Po~er ~245}.[ 1784' FSL, 666' FEL 5 Liner l~ ~ 7 Casing ~ u.~o ~ ~ I 1304' FSL, 590' FEL[ DEP=7904 NORTH=7809 WEST= 1227 RKB EL~ATION: 102' KOP ~O=300 TMD=300 DEP=O 3.00 _~. 9 5/8 Casing ~.oo 15.00 ~ 21~00 BLS: 3.00 deg per lOOf~ k 3~.oo X ~9.oo ~ 51.~ O0 B/ PERMAFROST WD=1802 TMD=2028 DEP=750 ' EOC WD=1915 TMD=2224 DEP=890 , 1 P SURFACE:E Ub~X~ON:uoCX~'~.- ~¢~rage T/W SAK SNDS WD=3809 TMD=5771 DEP=3 1225' FNL'637' ~L B/ W SAK SNDS ~D=4233 TMD=6564 DEP=4559 9 5/8" CSG PT ~D=4433 TMD=6939 DEP=4876 T/ COLVILLE ~D=4664 TMD=7571 DEP=5242 9000 8400 78OO 72OO 6600 6O0O 5400 4800 Z 0 4200 '-~ 3600 3000 -6800 6OO 6OO B/ COLVILLE TVD=5702 TMD=9315 DEP=6885 BEG ANGL DRP TVD=5927 TMD=9755 DEP=7240 HRZ MBPT TVD=6249 TMD=10265 DEP=7659 K-1 MARKER TVD=6395 TMD=10471 DEP=7805 7" CSG PT TVD=6457 TMD=10528 DEP=7844 TARGET-T/ KUP SNDS(EOD) TVD=6507 TMD=10621 DEP=7904 56.00 52.00 48.00 DLS: 2.00 deg per 100 ft _~ 44.00 T/ UNIT C '[VD=6549 TMD=10§76 DEP=794~, ~ T/ UNIT B TVD=6701 TMD=10874 DEP=8067 T/ UNIT A TVD=6837 TMD=11052 DEP=8181 T/ UNIT A4 TVD=6858 TMD=11079 DEP=8199 B/ KUP SNDS TVD=6953 TMD=I 1177 DEP=8262 TD 5" LINER 71/0=7086 TMD=11377 DEP=8390 TARGET ANGLE 40 DEG i i i i i i i 0 500 1000 1500 I I I I i i I I I I i I I I i II I 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Vertical Section (feet) -> Azimuth 351.07 wHh reference 0.00 N, 0.00 E from slot #11 I I I I J I 7000 7500 8000 I I 8500 ARCO ALASKA, Inc. Structure: Pad 1C Well: 11 Field : Kuparuk River UnH Location : North Slope, Alaska Crea~(ed by hfinch For: D PETRASH Dote plotted : 13-0ct-96 Plot Reference is 11 Version Coordinotes ore in feet reference slot ~11. l'rue Ver~icol Depths ore reference RKB (Porker #245). 320 3OO 280 260 240 220 2OO 180 1 ~.-- 140 ~- 120 · 0 Z lO0 2o E~]sf (feet) -> 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 120 140 I , , I , I '~X~ 110' ~ ' ' ' ' ' ' ~ ' ' ' ' ' ' ' ' ' '0 x~ 1300 ; \ ~ soo //900 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 t I" i i i 140 120 1 O0 80 60 60 80 1 O0 120 140 40 20 0 20 40 Eost (feet) -> 160 320 300 280 26O ?40 22O 20O 180 140 120 10o 20 40 16o Z 7 < < , 6 5 > > 13 5/8" 5000 PS1 BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. 16' -2000 PSI STARTING HEAD 2, 11' - 3000 PSI CASING HEAD 3. 11' -3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4, 13-5/8' - 5000 PSI PIPE RAMS 5, 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13.-5/8' - 5(X)O PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7, 13-5/8" - 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH. WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3(X)O PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTOR AND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILLAND CHOKE UNES. 7. TEST TO 250 PSI AND 3(:XX) PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X:X) PS! HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND ENES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR, 14, PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY, NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BE TESTED TO 5000 PSI HIGH. ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL ALSO BE TESTED TO 250 PSI LOW. RECEIVED Naska 011 & Gas Cons. Aucho~,ge ,<UPARUK RIVER Uh, ~' 20" DIVERTER SCHEMATIC 6 4 3 2 ) DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES, , . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 , WELL PERMIT CHECKLIST COMPANY ~,DMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................ 4. Well located in a defined pool ................. 5. Well located proper distance from ddg unit boundary ..... 6. Well located proper distance from other wells ......... 7. Sufficient acreage available in drilling unit. .......... 8. If deviated, is wellborn plat included .............. 9. Operator only affected party .................. 10. Operator has appropriate bond in force ............ 11. Permit can be issued without conservation order ...... 12. Permit can be issued without administrative approval .... 13. Can permit be approved before 15-day wait. ........ ENGI~f:RiNG ..... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. G[::C)LOG~Y ......... .30. 31. 32. 33. ~P_PR DA'];E~ 34. day reddl [] [] wellbore seg l-lann, disposal para req ~ WELL E PROGRAM: exp [] serv GEOI' AREA ~? ~,~-~ UNIT# _ ~ ON/OFF SHORE O ~ IN N Conductor s~'ing provided .................. .(,,~...~ Surface casing protects all known USDWs ......... L.Y~N CMT vol adequate to circulate on conductor & surf csg . . . (~. N CMT vol adequate to tie-in long string to surf csg ...... ..~ CMT will cover all known productive horizons ......... Casing designs adequate for C, T, B & permaJmst ..... ~r~ , Adequate tankage or reserve piL ............... ~)N If a re-drill, ~ a 10-403 for abndnmnt been approved .... Adequate wellbore separation proposed ........... . ~..~ Ddlling fluid program schemalJc & equip list adequate .... ~N BOPEs adequate ............. ~ ......... Y~,2N Choke m~ifold complies w/APl RP-53 (May 84) ....... { Work will occur without operation shutdown .......... ~ N Is presence of H2S gas probable ............... fyi,,.>, N REMARKS Permit can be issued w/o hydrogen sulfide measures ..... Y N J., ~ Data presented on potential overpressure zones ....... Y,,A~ ~,,,)~ ~. Seismic analysis of shallow gas zones ............. ,,~ N Seabed condition survey (if off-shore) ........... /". Y N Comact name/phone for weekly prcx3ress reports ... ,,,'f... Y N GEOLOGY: ENGINEERING: COMMISSION: JDH ~__.~<t~r.. JDN~ TAB Comments/Instructions: IOWA~ - A.'~-ORM~ my 4/96 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, informatii)n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Su~ Drilling Services LIS Scan Utility Fri Mar 28 11:23:55 1997 Reel Header Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scienti~~hnical Services Tape Header Service name ............. ii!i! . Date ..................... 8 Origin ................... Tape Name ................ Continuation Number ...... ~ Previous Tape Name ....... ~~"/~/ - ' ..... e ' 'cal Comments ................. STS LIS Writing Library. Scientific T cnni Services Physical EOF RECE!VE } Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPA/~Y: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD lC-11 500292271400 A~RCO AiJ~SKA, INC. IST STRING APR 02 199 ' Alaska Oil & Gao Cons. ¢'ommJssion ~chor~e SPERRY-SUN DRILLING SERVICES 28-MAR-97 MWD RUN 3 MWD RUN 4 MWD RUN 5 AK-MM-60154 AK-MM-60154 AK-MM-60154 M. HANIK R.KRELL R.KRELL D. LUTRICK D.LUTRICK D.LUTRICK 12 liN 10E 1225 637 .00 102.00 60.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING ~ PRODUCTION STRING REMARKS: 12.250 9.625 6943.0 8.500 7.000 10427.0 6.125 11300.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR). 5. MWD RUN 4 AND 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1300'MD, 7011'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 6896.5 6949 5 10419 0 10419 0 10419 0 10419 0 10419 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 6896.0 6900.0 10195.5 10199.5 10207.5 10212.0 10213.0 10216.5 STOP DEPTH 11224.5 11298.0 11231.5 11231.5 11231.5 11231.5 11231.5 EQUIVALENT UNSHIFTED DEPTH 10220.0 10z24.0 10229.0 10232.5 10233.5 10238.5 10236.5 10240.0 10275.0 10277.5 10387.5 10389.5 10390.0 10391.0 10425.0 10426.5 10497.0 10499.0 10499.5 10501.5 10512.5 10513.5 10529.0 10530.0 10531.5 10532.0 10533.5 10534.5 10565.5 10567.0 10568.5 10570.0 10611.5 10608.5 10614.0 10612.0 10615.5 10614.0 10616.5 10615.5 10618.0 10617.5 10655.0 10654.5 10658.5 10658.5 10700.0 10700.0 10716.0 10717.0 10743.0 10744.0 10777.5 10777.5 10784.5 10785.5 10841.5 10842.5 10850.5 10851.5 10869.5 10870.0 10871.0 10872.0 10878.5 10879.5 10947.5 10948.5 10960.5 10962.0 11054.0 11054.0 11069.0 11069.0 11086.0 11086.0 11090.0 11090.5 11102.0 11102.5 11105.5 11106.0 11114.0 11114.5 11115.5 11116.0 11119.5 11120.0 11123.0 11123.5 11159.0 11160.0 11298.0 11299.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 MWD 5 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP 6953.0 10427.0 10968.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet MERGE BASE 10427.0 10968.0 11300.0 Data Reference Point .............. Undefined Frame Spacing.. .................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR ROP RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD AAPI 4 1 68 MWD FT/H 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHM~ 4 1 68 MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 6896.5 11298 9097.25 8804 GR 22.5528 468.089 115.265 8657, ROP 5.5353 940.43 229.26 8698 RPX 1.1552 2000 10.9782 1626 RPS 0.7404 2000 8.58421 1626 RPM 0.213 2000 12.0873 1626 RPD 0.0933 2000 6.19334 1626 FET 0.7679 74.6392 4.91225 1626 First Reading 6896.5 6896.5 6949.5 10419 10419 10419 10419 10419 Last Reading 11298 11224.5 11298 11231.5 11231.5 11231.5 11231.5 11231.5 First Reading For Entire File .......... 6896.5 Last Reading For Entire File ........... 11298 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE S U74MARY VENDOR TOOL CODE START DEPTH GR 6900.5 ROP 6953.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10384.0 10427.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHN~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 05-NOV- 96 ISC 4.88 CIM 5.46 MEMORY 10427.0 6953.0 10427.0 42.7 59.5 TOOL NUMBER PO595CG6 8.500 8.5 LSND 9.00 48.0 9.5 600 7.8 .000 .000 .000 .000 48.3 Datum Specification ~lock sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6900.5 10427 8663.75 7054 6900.5 GR 22.5528 468.089 121.156 6968 6900.5 ROP 19.2015 940.43 268.824 6948 6953.5 Last Reading 10427 10384 10427 First Reading For Entire File .......... 6900.5 Last Reading For Entire File ........... 10427 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10263.5 10895.0 ROP 10339.5 10968.5 RPX 10360.0 10902.0 RPS 10360.0 10902.0 RPM 10360.0 10902.0 RPD 10360.0 10902.0 FET 10360.0 10902.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 09-NOV-96 SURFACE SOFTWARE vERSION: DOWNHQLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT):. BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 4.88 CIM 5.46 MEMORY 10968.0 10427.0 10968.0 41.1 42.2 TOOL NUMBER P0388SP4 P0388SP4 6. 130 6.1 LSND 11.80 46.0 8.5 450 5.2 2.800 1.530 2. 600 3.300 60.6 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 FET MWD 4 · HOUR 4 1 68 24 28 Name Min Max Mean Nsam DEPT 10263.5 10968.5 10616 1411 GR 26.1744 185.665 94.1164 1264 RPX 1.1552 2000 52.9419 1085 RPS 0.7404 2000 39.111 1085 RPM 0.213 2000 144.365 1085 RPD 0.0933 2000 124.278 1085 ROP 5.5353 308.789 77.7784 1259 FET 0.7679 75.7307 11.5534 1085 First Reading 10263.5 10263.5 10360 10360 10360 10360 10339.5 10360 Last Reading 10968.5 10895 10902 10902 10902 10902 10968.5 10902 First Reading For Entire File .......... 10263.5 Last Reading For Entire File ........... 10968.5 File Trailer Service name .......... ~...STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10896.5 RPD 10902.5 RPM 10902.5 RP$ 10902.5 RPX 10902.5 FET 10903.0 ROP 10969.5 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 11225.5 11232.5 11232.5 11232.5 11232.5 11232.5 11299.0 10-NOV-96 SOFTWARE SURFAGE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERV]LL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 4.88 CIM 5.46 MEMORY 11300.0 10968.0 11300.0 36.5 37.5 TOOL NUMBER P0388SP4 P0388SP4 6 130 6.1 LSND 12.50 49.0 9.0 500 4.4 2.000 3.400 1.700 2.800 56.1 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 RPX MWD 5 OHMS4 4 1 68 8 3 RPS MWD 5 OHMM 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD ROP FET MWD 5 MWD 5 ,, MWD 5 Or~4M 4 1 68 FT/H 4 1 68 HOUR 4 1 68 20 24 28 Name DEPT GR RPX RPS RPM RPD ROP FET Min 10896.5 24 8202 1 6676 1 6215 1 6168 i 7052 6 1852 0.9746 Max Mean Nsam 11299 11097.8 806 115.932 83.1611 659 2000 6.22868 661 12.2925 3.15711 661 10.0395 3.04453 661 8.6148 3.14516 660 240.339 71.3596 660 27.5838 6.73055 661 First Reading 10896.5 10896.5 10902.5 10902.5 10902.5 10903 10969.5 10902.5 Last Reading 11299 11225.5 11232.5 11232.5 11232.5 11232.5 11299 11232.5 First Reading For Entire File .......... 10896.5 Last Reading For Entire File ............ 11299 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/03/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/03/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
