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Home My WebLink About209-090STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r'1 3 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑� Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑� Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: Subsidence 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Stratigraphic❑ Exploratory ❑ Service ❑ 209-090 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20217-01 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2T -27A ADL 25569 ADL 25548 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,791 feet Plugs measured 8854 feet true vertical 5,875 feet Junk measured None feet Effective Depth measured 8,827 feet Packer measured 8765, feet true vertical 5,624 feet true vertical 5,701 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 16 121' MD 121' TVD SURFACE 3,667 feet 9 5/8 " 3,706' MD 2875' TVD PRODUCTION 8,966 feet 7 9,005' MD 5874' TVD LINER 2,189 feet 2 3/8 " 11,791' MD 5875' TVD Perforation depth: Measured depth: 9610-10494. 10497-11789 feet True Vertical depth: 5875-5880. 5880-5874 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 8,869' MD 5,777' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER FHL RETRIEVABLE PACKER 8,765' MD 5,701' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): WA 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: - Subsequent to operation: 200 - 600 1370 190 14. Attachments (required Per 20 AAC 25.070, 25.071, a 25.281) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 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: 318.527 Contact Name: James Hayes Authorized Name: James Hayes Contact Email: james.c.hayes@cop.com Authorized Title: Sr. Wells Engineer 2 �3 Contact Phone: (907) 265-6927 Authorized Signature: C Date: Form 10-404 Revised 4/2017 V VTL 2 20 /9 RBDMS1 FEB 14 2019 Submit Original Only AT Al"1J KUP PROD WELLNAME 2T -27A WELLBORE 2T -27A sP ��-" Well Attributes Max Angle & MD To �.OnOCO�)��(p5 (Field Name IW¢Ilbole APYUVA WeIIMre Slalui ncl l-1 MGIXKBI ACIBIm IN BI Alaska, Inc. KUPARUK RIVER UNIT 501032021701 PROD nn �� nun as ft 7wn eTT&.I.IBi$i1%PM Last Tag ..,Ni Annoation OepM111Ne1 EngadineWNIMreI Lut Mini By ..................................................................................... _ _ _. Lass Tag'. 2T -27A Osbotl Hanger, ggg Last Rev Reason Reputation End cab I Wellbore dental Rev Reason: SET CATCHER, GLV C/O 573120P 2T -27A Ippoeiter Casing Strings Coding DeaCrlption oo 0n1 11I Top (ends) setaentharin Set Depth pvOl... vmLen V... Orae TOP Tbeed CONDUCTOR 16 15.06 41.0 1210 121.0 62.58 H40 WELDED conpucrofl. atamo Caa4,g pvuaplion ODlln) Ip 9n) TopIKKB) SM Depin laKBj Set Depin IN01-. rWe Top Thread SURFACE 9516 am 388 3.7056 2,8755 A0 BTC MaMM:zAR CaMng Dead a page) land, Topsi dee DeptnleNel set Depth RUIN. rgp ToPTmead PRODUCTION Post SM 7 6.28 386 9,0046 5,8744 LA0 AP-Ow. Cdng CedicdplW, Op (In) ID and Topgtl(BI Sel pepin lM1ndB) Sel Depth Ti Gr Top Thread WINDOW AL1 J 6.00 8,971.0 8,981.0 5,858.] LA0 Casing Ondecrbfwn OD nn) ID (in) Tap WB) se Depen (alc8) sn Depth mall... M4e Top Thread LINERA (S,'Toff AL1) 2318 1.99 )SIL5 11,790.5 5,8)4.5 LA0 STL JL Liner Details SoflFPC E; A.6a,]16.fi Nominal lD Rach. Aget Trailer ioplN"b'd) Topinch') sem Dei Com gel bb 9.6015 5874.3 88.25 JDIILCT 11,Nlo Alluminum Billet (270"Glot 1.992 10496.3 1 586031 91.32 DEPLOY 27-G unplynentolieve 1.920 Maccon AA59.5 Tubing Strings Nbmg peaedpnon smog Ma._t0 pm rap leKB) do chain la..SM Death IM, I... w1nNh) made Top connxwn Tubing-Protlunion 3112 2.99 00 8,760.1 5,6971 930 L-80 TUE Malxpa:9.YAp Completion Details ToplNp) I Topmm Near I Top(pres) (MB) p) Mm pea Com I JOB 36.91 0.00 Hanger FMC Gen IV Tubing Hanger (6" x 3112' EUE SRM Bx P) 2.990 M.Mrat can6 8,747.3 5,687.8 43.2] Locemr Locator Baker Sub 3000 8,748.3 5,68.5 4329 Seal Assembly anAssembly. Baker, 8040(`1' off No- o) 3.00D ManRM; 8,131.5 Tubing phwnl n String Ma.. ID Pn) robing - Lower 0 600 Complann5 TOP M-1 8,714.9 del Depth (a., 8,846.1 lest Depta noun (....yea, 5,7614 0.00 Gmde do Tap connection Completion Details MenM9: e,eW.a TPvfNa) Top Incl xominal Ta (MB) (MBI 1.1 Imm pas Com thud) 8,751.8 5,6910 432) PBR Baker 10'PBR 8040 4.IXp 8,7652 5.]00.8 42,96 Packer Baker T X 312" FHL Relievable Packer 2.94 8,818.1 5.7395 42.9] Nipple HES 31/2" X 2.813' X Nipple 2. 1 ..47411 8,8354 5,752.1 42.813 LOCa1Gr Baker Locator Sub 3. 0 8836.2 57528 42.89 Seal Assembly Baker GHB-22 Molded Seal Assembly 3000 SnIAssaMb: 9,]9aa Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) plu;% 61 a PoCMv:a Kb3 Top (TVD) Tap Incl TOP MKS( burni P, IMa Cmm Be. DaN IDlinl 840 3,0242 57.00 Pat& Widurarkid,MelpiSkin Cases Hole DART 1 V111 1 5620 16 891 x 7" OD 23pp1 8,809.0 5]32.8 43.15 CMT MILLOUT MILLOUT CEMENT FOR SIDETRACK V1 5 O.ODO 8, 60 5759.9 4294 Junk usual 279'x 88' Catcher on BP (Top @ 8846' RKER 1211 0.000 8 Iaam,;eLv54 ,854.0 5.7658 42.96 n ge Iug- Baker 255 Direct Shur Cpanposge Bodge Plug Ok iZ 0.000 CMT pwG e,eaoMd aver nwman x.836.3 q r• Permanem above: Bk betow.09'length. 8 8,971.0 5,851.5 42.67 WHIP T CN BAKER WHIPSTOCK ddPA FOR SIDETRACK, 2 SIS" 11/72009 OR greaamp. p. ,Z" Perforations & Slots eeslo CMT mILOUT; R&9.p sea Den TOPMB) BM (M81 Top (1o0) Me) atm Tan doi Linked lane pmo Nem:m , Type Cam 9,610. 10.494.0 58746 580.4 A$2T-27A 11/2412009 320 SLOTS ALLPERF WELLBORE: Altemagng soliWslotted pipe - 0.125'x2.5" Ill 4 circ anile ernal adjacent a rows, 3" centers staggered 18 deg, 3 nontUdotted ends WMlParpck 9,T1a WINDOW an ago' u t a 1049].0 11]89.0 5,6603 5874.4 A -2,2T -2A 11/2412099 320 SLOTS ALLPERF IN WELLBORE: Alternating mliWsbtted pipe - PRODUCTION Poor W 366 0.125"x2.5" @ 4 apm,s cimumleren9al adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends Mandrel Inserts ar atl N Tap INOI Valve taka Facture TRO Be Top (We) (MBI Make Model 00(mThan n Sery po Type nen ILMI Bun cab Co. 2,8938 2,453.0 Vanal KBMM 3112 GAS LIFT Dumm 1.000 1/132019 y 5 4,898.6 3,974 Vanoil KBMM 312 = LIFT Dumm 1000 1UN2019 y 4 6,256.1 4,2987 Vanoil KBMM 312 GASLIFT SOV 1. 17132019 3 7,2976 4,857.9 Vanoil KBMM 312 GASLIFT umm 1.000 11132019 y 2 811340 5,2987 Vasal KBMM 312 GAS LIFT Debtor -TWO 1/13/2019 aLOT5: 8,8t061p.091.0 y 1 8,692,4 5648.1 Vanoil KBMM 312 GASLIFT Umm 1.000 1/13/2019 y 1 2p14.3 1,9162 CAMC R-20 112 GAS LIFT DMY RK 0000 00 513012017 2 4,298.0 3,209.1 CAMCO R-20 1112 GASLIFT DMY RK 0000 0.0 5TJ020D SLOTS; low"'v,]W.p 3 5,701.0 4,004.4 CAMCO RDO-20 1112 CASDMV RK 0000 UU 57302017 4 7,138.0 4,]]2.9 CAMCO MMM 112 11 LIFT DMY RK 0000 DUE UNERA (S?eeaLlI,aand l 95 5 8,166.1 5,316.4 CAMCO MMM Y 12 GASLIFTDMY JUN 0000 I 00 529/2013 COWco✓PKUP hillips Kaska, Im PROD WELLNAME 2T -27A WELLBORE 2T -27A zr-na 3n3aIB lz4i sa PN Mandrel Inserts waa w.m.M(.mwl s, an .......... _. ... ........... __.......... H Ma�888 on N Top (11NB1 TAP BVD) MKB) Make MMBI Oe lin) Sery Valve TyPS LettM1 TYpe Por Slss (1u) TRO Run "Pi, Run Oale Coln 6 8,815.0 5,]3]2 112 GAS LIFT OPEN 121112018 Notes: General & Safety End Dale AanoMlron 1113012009 NOTEVIEW SCHEMATIC wIAla;ka SCM1emaUc9.0 CO..TOB, 410-rn0 INVTE: WELL SIDE TRACKED TO A, AL1 624@01]UBIN LEAK F NIP, AT 882]' PA APPEARS TO BE LEA IN FR M ManeN 2093.b TEMPERATURE INCREASE BEL SURFACE: 39.8$T6.8 PeM1: S,�1.0 WMIA4,898.0 MaMM; B,ffi0 MerNJ: ].A)8 MVMre� 613f.6 MVMM, 8693.4 &W )urmpy;&)48.3 PBR:B>519 P.aw:e.re69 CMT PLVO: B.NIONB SW Axamgy,RB'18.] N A n Sncga PLV -Pyaercn0 �n 8,6540 C CMT MILLOUT', BS19.0 W IPSTOCR; BWIO .N.AL1;8,9)100.5810 PROOUCTIONF SR;Y,b B.DXS SLOT5:9.010.0.10.IB4.0 SLOTS; 104970-11 MO LINERA (Wa0ALIT%.S---A 1131.5 Operations Summary (with Timelog Depths) 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log SWR Depth StartTime End Time our (m) Phase Op Code Activity Code Time P-T-X Operation (fiKB) End Depm(9KB) 12/28/2018 12/28/2018 12.00 MIRU MOVE PRLO P De-Mobilize rig from 2T-203 and stage 00:00 12:00 out of way, prep pad, grade area for setting pits (take 3-4 inches off grade for level) Set matting boards and Herculite. 12/28/2018 12/28/2018 6.00 MIRU MOVE MOB P Mobilize rig to 2T-27, spot rig over well 12:00 18:00 center and level rig, spot and set cuttings pit and mud pits and secure interconnect. Rig up Kill tanks and choke, run hard lines. Set scaffolding around cellar area and secure walkways around well centers and Beavalator. Set Envirovac and Mud Lab. 12/28/2018 12128/2018 4.50 MIRU MOVE RURD P Rig up rig and equipment, begin filling 18:00 22:30 mud pits with Brine and taking on fresh water, prepare rig for Shore Power. Rig accepted at 22:30 Hrs 12/28/2018 12/29/2018 1.50 MIRU WELCTL RURD P Install secondary annulus valve. RU 22:30 00:00 circulating lines to kill the well, continue taking on 8.9 PPG brine 12/29/2018 12/29/2018 2.50 MIRU WELCTL RURD P Continue taking on 9.0 PPG brine 00:00 02:30 12/29/2018 12/29/2018 3.50 COMPZN WELCTL MPSP P RU lubricator. Pressure test to 2500 02:30 06:00 PSI. Bleed PSI to 1500 PSI. Pull BEV. RD lubricator. Take readings on well: 700 psi on Tubing, 1400 psi on IA, and 220 psi on OA, continue taking on 9.0 ppg Brine on tanks for 527 bible total on board. 12/29/2018 12/29/2018 5.50 MIRU WELCTL KLWL P PJSM for killing well operations and 06:00 11:30 pressure testing kill line to Tiger Tank. Pressure test lines to Tiger Tank to 2,500 psi, tested good. Tubing at 800 psi, IA at 1290 psi, and OA at 220 psi. Begin bleed well back, bleed tubing down to 100 psi with good fluid returns, bleed IA down to 200 psi with good fluid returns bringing pump online with 9.0 ppg Brine at 3 bpm at 200 psi, total 452 bbls 9.0 ppg Brine in and out, good clean fluid. 12/29/2018 12/29/2016 0.50 MIRU WELCTL OWFF P Observe well for flow for 30 minutes 11:30 12:00 observing 70 psi static on tubing, IA- 0 psi. 12/29/2018 12/29/2018 5.50 MIRU WELCTL CIRC T Begin second circulation with 9.0 ppg 12:00 17:30 while calling out 9.3 ppg Brine for new calculated KWF. Bring pumps online at 3 bpm with 300 psi on pumps taking returns through gas buster back to pits, no oil contamination observed, dean 9.0 ppg Brine in and out throughout circulation, pumped 385 bbls with 140 bible lost to well. Shut in well to observe for pressure build, still 70 psi on tubing and 0 psi on IA. Continue to weight up to a 9.3ppg and awaiting 9.3 Brine KWF from Baroid mud plant. 12/29/2018 12/30/2018 6.50 MIRU WELCTL COND T Continue to weight up to a 9.3ppg and 17:30 00:00 offload 9.3 Brine KWF from Baroid t mud plant, and prepare to circulate 9.3 pgg KWF Brine, Tubing 70 psi and IA 0 psi. Page 1/15 Report Printed: 112112019 Operations Summary (with Timelog Depths) 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time PJA Operation (ftKB) End Depth (flKB) 12/30/2018 12/3012018 1.50 MIRU WELCTL COND T Continue to weight up to a 9.3ppg and 00:00 01:30 offload 9.3 Brine KWF from Baroid mud plant, and prepare to circulate 9.3 pgg KWF Brine, Tubing 70 psi and IA 0 psi. 12/30/2018 12/30/2018 3.00 MIRU WELCTL KLWL T Circulate 9.3 PPG brine around down 01:30 04:30 tubing 3 BPM 230PSI. Lost to well bore 133 Bbis, with 438 bbls total pumped. 12/30/2018 12/30/2018 3.00 MIRU WELCTL OWFF T Flow check well, Tubing build to 25 psi 04:30 07:30 and hold static 25 psi for 1.5 hours while building 9.5 ppg KWF Brine in pits. 12/30/2018 12/30/2018 4.00 MIRU WELCTL KLWL T Circulate 9.5 PPG brine around down 07:30 11:30 tubing 3 BPM 230PSI. Lost to well bore 290 Bbls, with 438 bbls total pumped, slow down to 2 bpm at 167 psi 12/30/2018 12/30/2018 1.50 MIRU WELCTL OWFF T Flow check well, Tubing and IA 0 psi 11:30 13:00 on gauges, open IA and Tubing to atmosphere and flow check, well on losses of 6 bbl/hr. 12/30/2018 12/30/2018 2.00 MIRU WHDBOP MPSP P PJSM, Rig up T-Bar and set "IS-A" 13:00 15:00 BPV and prepare to nipple down Tree. 12/30/2018 12/30/2018 1.50 MIRU WHDBOP NUND P PJSM, Nipple Down Tree and Adapter 15:00 16:30 and clean hanger threads. 12/30/2018 12/30/2018 0.50 MIRU WHDBOP MPSP P MID Blanking plug in BPV and prep 16:30 17:00 Tubing Head for N/U of BOPE. 12/30/2018 12/30/2018 4.50 MIRU WHDBOP NUND P Nipple up 7-1/16" 5k flange w/ 11" 5k 17:00 21:30 flange to 11" 51k x 13-5/8" 5k DSA to Tubing Head, Nipple up BOPE to DSA and torque bolts. Continue to build 9.5 ppg KWF Brine in pits, 12/30/2018 12/30/2018 1.50 MIRU WHDBOP RURD P MU testing equipment, 31/2" test joint. 21:30 23:00 Blanking plug on TD. Fill stack and surface lines with fresh water. 12/30/2018 12/31/2018 1.00 MIRU WHDBOP BOPE P Pressure test BOPE 250/2500 PSI for 23:00 0000 5 Min each as per test procedure. Test witnessed by AOGCC rep Austin McLeod 1) Blind Rams, CMV 1. 2. 3. 16, Demco Kill, IBOP 2) CMV 4, 5, 6, HCR Kill, Lower Kelly Valve Sierra gas detection system 12/31/2018 12/31/2018 4.50 MIRU WHDBOP BOPE P Cont testing BOPE 250/2500 for 5 Min 00:00 04:30 each. Witnessed by AOGCC rep Austin McLeod 3) CMV 7, 8, 9, Manual Kill, HT-38 FOSV 4) Super Choke, Manual Choke 5) Annular, CMV 10, 11, HT-38 IBOP 6) UVBR, CMV 13, 13, 15 7) CMV 14 8) HCR Choke 9) Manual Choke - failed test 10) LVBR Accumulator Drawdown test Lay down test joint and blow down choke and lines. 12/31/2018 12/31/2018 1.00 MIRU WHDBOP BOPE T Replace manual choke valve on choke 0430 05:30 line and service. Page 2/15 Report Printed: 1121/2019 e Operations Summary (with Timelog Depths) # 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth rtKB) End Depth mKB) 12/31/2018 12/31/2018 2.50 MIRU WHDBOP BOPE T Fill lines and test Manual Choke valve 05:30 08:00 and 4-1/2" FOSV for landing joint to 250/2500 psi for 5 min. Good Test. Attempt to test 3-1/2" EUE FOSV and fail test, rebuild FOSV and test, good test. 12/31/2018 12/31/2018 1.00 MIRU WHDBOP RURD P Rig down testing equipment and blow 08:00 0900 down lines, circulate 9.5 ppg Brine KWF through stack and gas buster, pull blanking plug from hanger and lay out test joint. 12/31/2018 12/31/2018 7.50 MIRU WHDBOP KLWL T 7 psi on IA, pump 9.8 ppg Brine down 09:00 16:30 tubing, flow check, well on vacuum, attempt to pull BPV, while observing BPV with dart open observed burping into the BOP stack. Pull T -Bar and shut blinds and circulate 9.5 ppg Brine across the stack under the blinds at 2 bpm observing 10 bola lost to well after pumping 20 bbls of 9.5 ppg Brine. Flow check well, well on a vacuum on tubing but IA back to 7 psi. Weight up Brine to 9.6 ppg and circulate down tubing with 9.6 ppg Brine with no returns to the IA, pump away 90 bbis at 1 bpm under the blinds through the BPV down tubing, line up on IA and monitor tubing and pump 200 bbls 9.6 ppg Brine with no returns through the tubing at 2 bpm. 12/31/2018 12/31/2018 0.50 MIRU WHDBOP OWFF T Flow check well 16:30 17:00 12/31/2018 12/31/2018 1.00 MIRU WHDBOP RURD P Pull BPV 17:00 18:00 12/31/2018 12/31/2018 0.50 COMPZN RPCOMP RURD P Obtain loss rate of 40-60 bbl an hour, 7,700.0 18:00 18:30 blow down all lines while observing well and make up landing joint with TIW valve made up to landing joint and M/U TDS to pull hanger. BOLDS. Hanger released when LDS were backed out. Tubing grew 8". 12/31/2018 12/31/2018 1.00 COMPZN FTP—COMP PULL P Work seals free of seal bore 8,837.0 8,807.0 18:30 19:30 receptacle. Seals pulled free after working up to 165K PUWT on tubing with pump on at 5 BPM 530 psi. Pull hanger to RF. LD hanger and landing joint. PUWT 90K DWT 60K with blocks. 12/31/2018 12/31/2018 0.50 COMPZN RPCOMP CIRC—�:: Pump 20 BBLS 9.8 PPG brine slug 8,8070 8,807.0 19:30 20:00 down tubing due to well being out of FP balance. BD TD. Loss rate 85 BPH.12/31/20181/1/2019 4.00 COMPZN RPCOMP PULLLD 3 1/2" 9.3# L-80 tubing string T/ 8,807.0 7,700.0 20:00 00:00 7700'. Loaded backside with 80 Bbls HEC pill at 120 Vis 1/1/2019 1/1/2019 —1.50 COMPZN RPCOMP PULL P ContC ont to LD 3 1/2 —Completion string F/ 7,700.0 6,900.0 00:00 01:30 7700' T/ 6900'. Had over pull of 80K with 1937' of tubing pulled out of the hole. Page 3115 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stag Tima End Time Dur (hr) Phase Op Cotle Activity Code Time P -T -X Operation Start Depth (fiKB) End Depth(%KB) 7/7/2019 1/1/2019 5.50 COMPZN RPCOMP PULL X Slack of 70K string weight - no 6,900.0 6,900.0 01:30 07:00 movement. MU TO to tubing stump 12' above rig floor. Set 30K TO weight down onto string - no movement. Break of TD. RU head pin and cement hose fill hole down tubing. 80 BPH loss rate. Contact town engineer and baker fishing to develop plan toward. 1/1/2019 1/1/2019 2.50 COMPZN RPC 0 MMP CIRC X Pump 40 Bbls HEC pill 150 Vis down 6,900.0 07:00 09:30 tubing at 1 BPM. Fill tubing pumping 3 Bbls of 9.6 PPG brine down tubing every 10 Min. 1/7/2019 7/1/2079 1.50 COMPZN RPCOMP BHAH X MU Baker surface jar to 4 3/4" DC 6,900.0 09:30 11:00 crossed over to tubing stub on rig floor. 1/1/2019 1/1/2019 2.00 COMPZN RPCOMP JAR X Use surface jar as bumper sub to 6,900.0 11:00 13:00 attempt to tree GLM from collapsed 7" casing. Joint of tubing sticking above rig floor bent due to compression. No movement of GLM or tubing string below. 1/1/2019 1/1/2019 1.00 COMPZN RPCOMP CIRC X Pump 40 Bbls HEC pill 150 Vis down 5,900,0- 13:00 1400 tubing at 2 BPM. Chased pill with 20 Bbls 9.6 PPG brine. 1/1/2019 117/2019 1.00 COMPZN RPCOMP BHAH X LD Baker surface jar and 4 3/4" DC 6,900.0 14:00 1500 1/1/2019 1/1/2019 0.50 COMPZN RPCOMP PULL X Back off bent joint of 3 1/2' tubing in 6,900.0 15:00 15:30 stack. Now have a pin looking up 19' down from 7ES RKB. 1/1/2019 1/7/2019 2.50 COMPZN RPCOMP CIRC X Circulate over top of hole with trip 6,900.0 15:30 18:00 pump filling hole through tubing in stack. Loss rate 5 BPH 1/1/2019 7/7/2019 2.00 COMPZN RPCOMP BHAH X MU Baker surfacejarto 43/4"DC, 6,900.0 18:00 20:00 crossed over to one joint of 3 1/2" DP, to spear. 7/1/2019 1/2/2019 4.00 COMPZN RPCOMP JAR X Use surface jar as -bumper sub to 6,900.0 20:00 00:00 attempt to free GLM from collapsed 7" casing. No movement of GLM. 1/2/2079 1/2/2019 2.00 COM -PZ N RPCOMP JAR X Use surface jar as bumper sub to 00:00 02:00 attempt to free GLM from collapsed 7" casing. No movement of GLM. DROPS inspection. 1/2/2019 1/2/2019 2.00 COM PZN RPCOMP BHAH X LD Baker surface jar to 43/TDC, 02:00 04:00 crossed over to one joint of 3 1/2" DP, to spear. MU Baker surface jars to two 6 1/4" DC's, bumper sub, 3 1/2" IF pup joints, drain sub, spear. 1/2/2019 1/2/2019 4.00 COMPZN RPCOMP JAR X PJSM, DROPS inspection. Utilize 04:00 0800 surface jars and bumper sub to pull up to 75-80k and fire jars down, utilize the closed annular to apply 1000 psi down, no leak by, no movement of fish. 1/2/2019 1/2/2019 1.00 COMPZN RPCOMP BHAH X L/D Baker surfacejar and bumper 08:00 0900 sub. P/U and M/U Weatherford Daily double acting jars made up to a 6-1/4" DC, crossed over to one joint of 3 1/2" DP, to spear. DROPS Inspection. Found keeper pin had come free of brake linkage pin, pin was unable to move due to placement of pin in brake linkage, good catch. Page 4115 ReportPrinted: 1/21/2019 Operations Summary (with Timelog Depths) Ace �l 2T-27 mr Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Stan Depth (ftKB) End Depth(tIKB) 1/2/2019 1/2/2019 3.00 COMPZN RPCOMP JAR X Utilize drilling jars to pull up to and 09:00 12:00 calk jars and set down full weight with TDS and fire jars down, utilize the closed annular to apply 1000 psi down, no leak by, no movement of fish. DROPS Inspection. 1/2/2019 1/2/2019 0.50 COMPZN RPCOMP BHAH X L/D drilling jars and P/U and M/U 12:00 12:30 Baker Rattler made up to a 6-1/4" DC, crossed over to one joint of 3 1/2" DP, to spear Make up 113-1/2" Pup and screw into the TDS. 1/2/2019 1/2/2019 2.00 COMPZN RPCOMP JAR X Continue squatting on the fish and 12:30 14:30 running the rattler at 2 bpm (full rate allowed by rattler) with 1200 psi and attempt to free fish without success. Perform DROPS Inspection and found Blackjack on TDS leaking. 1/2/2019 1/2/2019 2.00 COMPZN RPCOMP BHAH X UD Rattler, 6-1/4" DC, and 3 1/2" pup 14:30 16:30 joint. Utilize 3-1/2" joint and spear and attempt to back out bent joint of 3-1/2" EUE from the GLM and lay out. Make up newjoint of 3-1/2" EUE and screw into the fish and make up to 3k with no movement of fish observed, Make up drilling jars on tubing. 1/2/2019 1/2/2019 2.00 COMPZN RPCOMP JAR X With the drilling jars, attempt to jar up 16:30 1830 with 80k, 100k, 121 150k over pull, no observable movement of fish. DROPS Inspection. 1/2/2019 1/2/2019 1.00 COMPZN RPCOMP CIRC X Bullhead 40 Bbls HEC pill 150 Vis at 2 18:30 1930 BPM followed by 20 Bbls 9.6 PPG brine. Loss rate 2 BHP 1/2/2019 1/3/2019 4.50 COMPZN RPCOMP ELNE X PU Pollard E -Line. Run 2.65" drift 19:30 0000 down to 22'. Run CCL log to confirm cut depth in middle of second full joint below GLM. Run Jet Cutter and cut tubing at 81' RKB. Log down to 750' to confirm string dropped far enough to set IBP's. Log back up to surface. 1/3/2019 1/3/2019 1.00 COMPZN RPCOMP ELNE X POOH and inspect jet cutter 00:00 01:00 assembly, All indication jet cutter worked as per design. Loss rate increased to 70 bbl/hr 1/3/2019 1/3/2019 2.00 COMPZN RPCOMP CIRC X Pump and spot 40 bbl HEC Pill and 01:00 0300 chase with 20 bbl 9.6 ppg Brine. Observe loss rate down to 2-3 BPH. 1/3/2019 1/3/2019 2.00 COMPZN RPCOMP ELNE X Rig back up E -Line pack off, and RIH 03:00 0500 with 1st IBP, RIH to 620' RKB and log up to set in middle of 7" joint. Set IBP at 624' with fishing top at 621'. POOH and lay back tools to rig up for pressure testing IBP. 1/3/2019 1/3/2019 1.00 COMPZN RPCOMP PRTS X Rig up lines and pressure test IBP to 05:00 06:00 500 psi for 5 minutes, good test. 1/3/2019 1/3/2019 2.00 COMPZN RPCOMP ELNE X M/U IBP #2 and RIH to 520' and log 06:00 08:00 up to middle of 7" joint and set IBP #2 at 506' with fishing top at 503'. POOH to rig down E -Line. 1/3/2019 1/312019 1.00 COMPZN RPCOMP RURD X Rig down E -Line, clear and clean rig 08:00 09:00 floor. 1/3/2019 1/3/2019 1.00 COMPZN RPCOMP OWFF X Observe well for Flow, well static for 1 09:00 1000 hour. Page 5115 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stad Time End Time our (hrJ Phase O Did Code Activity Code Time P-T-% Operelion Star) Depth (ftKB) End Depth(fi 1/3/2019 1/3/2019 3.00 COMPZN RPCOMP NUND X PJSM, N/D BOP and pick up off of 13- 10:00 13:00 5/8" 5k flange Sand set collar clamp on 3-1/2" tubing fish with top pup joints tied into winch to support the weight of tubing. Complete all hot work permits and utilize Wachs saw to cut 3-1/2" tubing and lay out tubing from rig floor Rack back BOP on BOP stump. Utilize winch to pull DSA and Adapter flange off of 7-1/16" 5k Tubing Head and re- install collar clamp on 3-1/2" tubing and observe 7" casing has grown 2.25' from bottom of C-21 well head through tubing head. 1/3/2019 1/3/2019 2.00 COMPZN RPCOMP OWFF X PJSM, utilize pump-in tee to fil OA 1300 15:00 after 48 hour bleed down to atmosphere with 0 psi, Fill OA with 3 bbls of 9.6 ppg Brine and burp air/gas out of OA until fluid / Artic Pack returns and observe for flow. 1/3/2019 1/3/2019 1.00 COMPZN RPCOMP NUND X Remove IA2-1/16" 5k valve and 15:00 16:00 companion flange off of tubing head and prepare for rigging up Hydra Tight. 1/3/2019 1/3/2019 1.00 COMPZN RPCOMP RURD X PJSM, rig up Hydra Tight equipment 16:00 1700 to grow casing. 1/3/2019 019 5.00 COMPZN RPCOMP PULL X PJSM, Utilize Hydra Tight to allow 7" 17:00 to grow. 7" growth total of 55". 28" Flange to flange with Hydra Tight. 27" F2230 through well head. 1/3/2019 19 0.50 COMPZN RPCOMP RURD X Rig down Hydra Tight equipment 22:00 1/3/2019 19 1.50 COMPZN RPCOMP PULL X RU bridge crane to picking eyes on 7 22:30 0000 1/16" tubing flange hole in tension. Remove slips from 7". RU Wachs cutter Cut 7" casing. PU with bridge crane to give access to pup joint below GLM. Set C plate and dog collar on 3 1/2" pup joint. Cut 3 1/2" pup joint with Wachs saw. LD Tubing head with section of 7" inside of it with GLM inside of 7" and pack off on 7" in cellar with bridge crane. 1/4/2019 1/4/2019 1.50 COMPZN RPCOMP PULL P Engage 3 1/2" tubing fish pull to rig 00:00 01:30 floor and LD. 1/4/2019 1/4/2019 2.00 COMPZN RPCOMP CUTP X Spear 7" casing. PU to 50K string 01:30 03:30 weight and slack off. Casing grew 1". PU to 150K verify cement at appoximately 2000' using pipe strech calculations. SO to 100K wt indicator, 20 K over string weight at 2000'. Set C -21 slips. LD 7" spear. 1/4/2019 1/4/2019 1.50 COMPZN RPCOMP WWSP X Cut 7" casing stub with Wachs cutter. 03:30 05:00 Install packoff. 1/4/2019 1/4/2019 2.00 COMPZN RPCOMP NUND X Install 7-1/6" 5M x 11"3M Tubing 05:00 0700 Head Gen IV and install 2-1/16" 5M valve and monitor gauge and torque all bolts. 1/4/2019 1/4/2019 1.50 COMPZN RPCOMP NUND X N/U 7-1/16" 5M x 11" 5M adapter 07:00 08:30 spool x 11"5M x 13-5/8" 5M DSAand torque all bolts. 1/4/2019 1/4/2019 3.00 COMPZN RPC0MP NUND X N/U 13-5/8" 5M BOPE and torque all 08:30 11:30 bolts. Page 6/15 Report Printeii 1/21/2019 e r , Operations Summary (with Timelog Depths) t`r'ot 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X operation Stan Depth (ftKB) End Depth (ftKB) 1/4/2019 1/4/2019 0.50 COMPZN RPCOMP RURD X P/U and M/U test plug and set, back 11:30 12:00 off test plug and shut blinds and line up to pressure test down Kill to closed choke HCR to test BOP cavity and Tubing Head and BOP adapter. 1/4/2019 1/4/2019 0.50 COMPZN RPCOMP 50-P -E X Pressure test BOPE, Tubing Head and 12:00 12:30 BOP adapter to 250 low psi 5 minutes 12,500 psi High 5 minutes good test. 1/4/2019 1/4/2019 1.00 COMPZN RPCOMP RURD X Retrieve test plug and layout blow 12:30 13:30 down all lines. P/U and M/U and set Wear Bushing and lay outjoint. 1/4/2019 1/4/2019 1.00 COMPZN RPCOMP BHAH X P/U and M/U Baker fishing BHA #1 13:30 14:30 with overshot for retrieving IBPs. 1/4/2019 V4/2019 1.00 COMPZN RPCOMP TRIP X RIH with fishing BHA#1 and P/U 3- 14:30 15:30 1/2" DP from surface to 494'. 1/4/2019 1/4/2019 0.50 COMPZN RPCOMP FISH X M1U TDS and engage IBP at 494', 15:30 1600 bleed off by slacking down 10k and picking up to shear with 10k over pull, set to neutral and allow to relax for 15 minutes. 1/4/2019 1/4/2019 1.00 -EO`MPZN RPCOMP TRIP X POOH from 494' with IBP on fishing 16:00 17:00 BHA#1 racking back pipe, inspect IBP, all good. 1/4/2019 1/4/2o19 Too COMPZN RPCOMP BHAH X Break down and lay out IBP #1, 17:00 18:00 inspect BHA, all good. RIH to retrieve IBP #2. 1/4/2019 1/4/2019 1.00 COMPZN RPCOMP TRIP X RIH from surface with fishing BHA#1 18:00 19:00 to retrieve IBP #2 from surface picking up 3-1/2" DP from surface to 621'. 1/4/2019 1/4/2019 1.00 COMPZN RPCOMP FISH X M/U TOS and engage IBP at 623', set 19:00 20:00 down 3K, weight indicator bobbeled indicating equalization valve shifted. 1/4/2019 1/5/2019 4.00 COMPZN RPCOMP OWFF XT Saw bubbles in stack. Shut annular 20:00 00:00 PU 5'. 0 PSI Open choke, RIH tag up on IBP at same depth. Repeat process still 0 PSI. Repeat process again when opening choke flow was observed. Closed in for 30 min 10 PSI on back side. Circ BU. Closed back in for 30 min10 PSI on back side. Circ second BU closed back in 10 PSI on back side. Open up choke and check for flow 1 Bbls in 6 Min. Closed back in for 30 min 14 PSI on backside. Circ 9.8 PPG fluid around at 618', flow seen through gas buster. 1/5/2019 1/5/2019 4.50 COMPZN RPCOMP OWFF XT Shut in and monitor pressure 10 PSI 618.0 618.0 00:00 04:30 on back side. Vis up available 9.8 PPG brine to 40 Vis and weight up to 9.9 PPG. Pump 9.9 PPG brine around at 618'2 BPM. Bullhead 5 Bbls through equalization port on IBP. Observe well for flow no flow 1/5/2019 1/5/2019 0.50 COMPZN RPCOMP TRIP XT POOH F/ 618to surface monitoring 618.0 8.0 04:30 0500 well, well static. 1/5/2019 1/5/2019 -0 50 COMPZN RPCOMP BHAH XT LD Retrieving head. PU overshot and 8.0 7.0 05:00 05:30 ported sub. 1/5/2019 1/5/2019 0.50 COMPZN RPCOMP TRIP XT RIH to 618' and monitor well, well 7.0 618.0 05:30 06:00 static. 1/5/2019 1/5/2019 0.50 COMPZN RPCOMP FISH X RIH and engage IBP fishing head at 618.0 633.0 06:00 06:30 623' with 5k down, pull 10k over and allow to relax for 15 minutes. RIH T/ 633' Page 7115 Report Printed: 1/2112019 Operations Summary (with Timelog Depths) Ain, 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur (hQ Phase Op Colo Achmly Code Time P -T -X Operation Start Depth (flK8) End DepN(11KB) 1/5/2019 1/5/2019 1.50 COMPZN RPCOMP KLWL XT Observe Flow, close annular on 3-1/2" 633.0 633.0 06:30 0800 DP with IBP engaged at 623' and monitor pressure build to 8 psi. Bullhead down drill pipe and down back side with 5 bpm with 9.6 ppg Brine for 308 bbls at 190 psi. Monitor well, well static, open annular. 1/5/2019 1/5/2019 1.00 COMPZN R`PCOMP TRIP X POOH with IBP from 623' to surface 633.0 0.0 08:00 09:00 and lay out IBP and fishing BHA. Observe well start to flow. 1/5/2019 1/5/2019 2.50 COMPZN RPCOMP KLWL XT Close Blind rams and monitor for 0.0 0.0 09:00 11:30 pressure, observe 6.8 psi build after 10 minutes while building 325 bbls of 9.7 ppg Brine. Bullhead 325 bbls 9.7 ppg Brine at 5 bpm down kill line with 490 psi. 1/5/2019 1/5/2019 0.50 COMPZN RPCOMP OWFF XT Observe well for flow, well on slight 0,13 0.0 11:30 1200 losses 1/5/2019 1/5/2019 1.50 COMPZN RPCOMP TURD XT P/U Test Plug and pull wear bushing, 0.0 0.0 12:00 1330 drain stack and install test plug while monitoring well on IA, observe slight flow begin on IA, pull test plug and observe well building volume up BOP stack. Shut Blind Rams. 1/5/2019 1/5/2019 1.00 COMPZN RPCOMP KLWL XT Observe well under blind rams, no 0.0 0.0 13:30 14:30 pressure build and no Flow through choke manifold, open blinds to observe well, observe well begin to fill BOP stack again, Shut in Blind Rams. While building 9.8 ppg Brine observe well for pressure build under blind rams, no pressure build up. Bull Head 325 bb)s of 9.8 ppg at 490 psi. 1/5/2019 1/5/2019 2.00 COMPZN RPCOMP OWFF XT Open Blind Rams and observe well for 0.0 0.0 14:30 16:30 Flow, well on 41 bbl/hr losses over 2 hours. 1/5/2019 1/5/2019 1.00 COMPZN RPCOMP KURD XT P/U Test Plug and pull wear bushing, 0.0 0.0 16:30 17:30 drain stack and install test plug while monitoring well on IA, observe well still on losses, rig up pump in tee to IA to monitor and keep 9.8 ppg Brine pumping down hole at 40 bph rate. 1/5/2019 1/512019 2.00 COMPZN RPCOMP BOPE XT Pressure test BOPS 250 psi low 5 0.0 0.0 17:30 19:30 minutes and 2,500 psi high 5 minutes. Test witnessed by AOGCC rep Jeff Jones. Test 1) Annular, CMV 7, 8 & 13, and Kill Line HCR, Test 2) Blind rams, Choke HCR Accumulator Draw Down Test, and PVT System Test 1/5/2019 1/512019 1.00 COMPZN RPCOMP RURD XT RD testing equipment. BD choke & 0.0 0.0 19:30 20:30 kill lines and choke manifold. Install wear bushing. Filling hole 9.8 PPG brine with loss rate of 25 BPH. 1/5/2019 1/5/2019 1.50 COMPZN RPCOMP BHAH X MU overshot BHA T/ 30' 0.0 30.0 20:30 22:00 1/5/2019 1/5/2019 0.50 COMPZN RPCOMP TRIP X RIH with Overshot out derrick T/ 627' 30.0 627.0 22:00 22:30 1/5/2019 1/6/2019 1.50 COMPZN RPCOMP PULD X PU DP and RIH with Overshot T/ 627.0 1,590.0 22:30 0000 1590' 1/6/2019 1/6/2019 1.50 COMPZN RPCOMP PULD X Cont PLOP F/ 1590'T/ 1990' 1,590.0 1,990.0 01:30 r00:00 Page 8115 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 0 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our (hr) Phase Op Corte Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 1/6/2019 1/6/2019 2.50 COMPZN RPCOMP MILL X Screw in Top Drive obtain parameters 1,990.0 2,032.0 01:30 04:00 PUWT 60K, SOWT60K. Pump 3 BPM 125 PSI. Free TO 1 K at 20 RPM. Wash down from 1990' to stump at 2032'. Mill on stump 2-5K 20-30 RPM 1.2-1.5K TQ. Unable to engage fish. 1/6/2019 1/6/2019 1.00 COMPZN RPCOMP TRIP X POOH racking back drill pipe, 15 2,032.0 0.0 04:00 05:00 bbl/hr loss rate from 2032' to surface. 1/6/2019 1/6/2019 0.50 COMPZN RPCOMP BHAH X Lay down polish mill overshot with 0.0 10.0 05:00 05:30 confirmation the mill guide tang broke but was retained in overshot, 3-1/2" top of fish made it up 6" down to 3- 5/8" OD from 4" OD of jet cut seen on cut end of tubing on surface. Make up mill guide with pack off in overshot and drop overshot extension and RIH to engage fish. 1/6/2019 1/6/2019 1.50 COMPZN RPCOMP TRIP X RIH from with fishing BHA to 2012', 10.0 2,012.0 05:30 07:00 string weight 60k UP/DN, 15 bbl/hr loss rate. 1/6/2019 1/6/2019 1.00 COMPZN RPCOMP FISH X M/U TDS and wash down over fish 2,012.0 2,032.0 07:00 0800 from 2012' to 2032' and mill over fish stump with 20 rpm at 1900k torque and 2 bpm with 135 psi seen as overshot engaged fish, worked overshot down over fish to 2037' lip guide depth and observe full swallow, set 20k down and pick up to 40k over and jars fired, pipe free. Top of fish engaged at 2032' and bottom of fish at 8837'. 1/6/2019 1/6/2019 1.50 COMPZN RPCOMP CIRC X Circulate bottoms up with 9.8 ppg 2,032.0 8,837.0 08:00 09:30 Brine at 2 bpm with 20 bph loss rate, pump 40 bbl HEC pill and spot on bottom. 1/6/2019 1/6/2019 0.50 COMPT RPCOMP TRIP X POOH with fish racking back drill pipe 8,837.0 6,927.0 09:30 10:00 from 8837' to 6927', 85k string weight, losses at 2 bph. 1/6/2019 1/6/2019 1.00 COMPZN RPCOMP BHAH X POOH with fishing BHA from 6927'to 6,927.0 6,833.0 10:00 11:00 6833'. Lay down fishing BHA and 16' cut off joint in overshot, loss rate 2bph. 1/6/2019 1/6/2019 0.50 COMPZN RPCOMP KURD X Change out elevators to 3-1/2" YT 6,833.0 6,833.0 11:00 11:30 tubing elevators and rig up tubing ons. 1/6/2019 1/6/2019 11.50 COMPT RPCOMP PULL P POOH with tubing from 6833' to 6,833.0 0.0 11:30 23:00 surface, laying out GLMs, inspecting each joint for excessive wear and damage, loss rate at 2-3 bph. One 1" hole in tubing joint #275 5' up from pin directly above seal assembly. Seal assembly is good condition. 1/6/2019 1/7/2019 1.00 COMPZN RPCOMP RURD P RD tubing pulling equipment. Clean 0.0 0.0 23:00 00:00 and rig floor 1/7/2019 1/7/2019 0.50 COMPT RPCOMP RURD P Cont cleaning and clearing rig floor. 00:00 00:30 1/7/2019 1/7/2019 0.50 COMPZN RPCOMP SFTY P PJSM with Halliburton Rep, Pollard 00:30 01:00 Rep and rig crew on RU and run E - Line. 1/7/2019 1/7/2019 1.00 COMPZN RPCOMP RURD -PT-— RU Pollard E -Line and MU Halliburton 01:00 02:00 40 arm caliper Page 9115 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur (hp Phase Op Code Activity Code Tme P-T-X Operation Start Depth (flKB) End Depth(ftKB) 1/7/2019 1/7/2019 8.00 COMPZN RPCOMP ELOG 5 RIH with 40-Arm Caliper from surface 02:00 1000 to 8,824' and log 7" casing up to surface with 2 passes from 4,700' back to surface, preliminary results show hole in 7" at 4,210'. Loss rate while running caliper at 6 bph. 1/7/2019 1/7/2019 0.50 COMPZN RPCOMP RURD P Rig down Halliburton 40-Arm Caliper 10:00 10:30 and rig up Alaska E-Line CBL 1/7/2019 1/7/2019 3.00 COMPZN RPCOMP ELOG P RIH with Alaska E-Line CBL and find 10:30 13:30 top of cement TOC at 2,080', run second pass and confirm, POOH to surface. Losses slowed from 6 bph to 3 bph. 1/7/2019 1/7/2019 1.00 COMPZN RPCOMP RURD P Rig down Alaska E-Line equipment 1330 14:30 and prepare to pick up test packer, —0 loss rate stopped and well went static. 1/7/2019 1/7/2019 50 COMPZN RPCOMP KLWL T Observe well and observe well go 14:30 1500 from static to flow with 0.25 bbl gain, shut blind rams and monitor, no pressure build, open back through choke to check for flow and observe well still flowing. Shut back in well. 1/7/2019 1/7/2019 2.00 COMPZN RPCOMP KLWL T Bullhead well with 9.8ppg Brine down 15:00 17:00 kill below blind rams for 325 bbls, 5700 strokes at 5 bph 510 psi. 1/7/2019 1/7/2019 3.50 COMPZN RPCOMP OWFF T Observe well for flow, indication of 0.5 17:00 20:30 bbl an hour flow with 0 psi build in 30 minutes to choke. Continue to monitor well while weighting up system from a —1 9.8 ppg Brine to 9.9 ppg Brine. 1/7/2019 1/7/2019 00 COMPZN RPCOMP KLWL T Bullhead well with 9.9 PPG Brine 20:30 21:30 down kill line below blind rams for 325 BbIE, 5700 strokes at 6 BPM 530 PSI, 1/7/2019 1/7/2019 0.50 COMPZN RPCOMP OWFF T Observe well for flow, no flow. Fluid 21:30 22:00 falling in stack. Initial loss rate of 3 BPH, 1/7/2019 1/8/2019 2.00 COMPZN RPCOMP RURD T Pull wear bushing. Took several 22:00 00:00 attempts to latch up with running tool due to over torque of LDS. Set test plug. O-ring rubber failed on first attempt. Pulled test plug and replaced element and re-landed. 1/8/2019 1/8/2019 3.50 COMPZN RPCOMP BOPE 37— Pressure test BOPE 250 psi low 5 00:00 03:30 minutes and 2,500 psi high 5 minutes. Witness waived by AOGCC rep Jeff Jones. Test 1) Blind rams, CMV 7, 8 8,13, and Kill Line HCR, Test 2) Choke HCR Accumulator Draw Down Test 1/812019 1/812019 1.50 COMPZN RPCOMP RURD X Pull test plug. RD testing equipment. 03:30 05:00 Install wear bushing. Blow down choke manifold, choke and kill lines. Page 10/15 ReportPrinted: 1/21/2019 --: Operations Summary (with Timelog Depths) 2T-27 • Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 1/8/2019 1/8/2019 7.00 COMPZN RPCOMP TRIP P Make up 7" EA Retdevamatic Test 05:00 12:00 packer and trip in hole with 3-1/2" drill pipe stands to 4270'. Set packer at 4270' and shut in annular and pump down kill line and pressure up annulus to 2500 psi. Held 2500 psi for 5 minutes, test good. POOH from 4270' to 4180', set packer at 4180'. Pressure test annulus to 2500 psi, test failed. POOH from 4180' to 4025', set test packer at 4025'. Pressure test annulus to 2500 psi, pressure test good. Leaking between 4270' 4020' 1/8/2019 1/8/2019 1.00 COMPZN RPCOMP CIRC P Build 40 bbls of N -Vis pill at 4020' and 12:00 13:00 pump at 4 bpm with 275 psi spotting Ion bottom. 1/8/2019 1/8/2019 0.50 COMPZN RPCOMP OWFF P Circulate across top of well observing 13:00 13:30 dynamic losses after pumping 40 bbl N -Vis pill. Observed a loss rale of approximately 15 bph. Shut trip tank off and perform a 15 min flow check. Well slightly taking fluid. 1/8/2019 1/8/2019 4.00 COMPZN RPCOMP TRIP P POOH with 7" EA test packer racking 13:30 1730 back 3-1/2" drill pipe. Lay down 7" test packer and prepare to pick up 7" clean out assembly BHA. 1/8/2019 1/8/2019 1.50 COMPZN WELLPR BHAH P M/U BHA# 13 w/ baker clean out 17:30 19:00 assembly 1/8/2019 1/9/2019 5.00 COMPZN WELLPR TRIP P RIH F/ Derrick 3 1/2" work string t 19:00 00:00 4500' and P/U Singles out of pipe shed V 5300' 1/9/2019 1/9/2019 5.00 COMPZN WELLPR PULD P RIH F/ Derrick 3 1/2" work string t 00:00 05:00 4500' and PIU Singles out of pipe shed V 4500' U 8799' 1/9/2019 1/9/2019 1.50 COMPZN WELLPR WASH P Start washing f/ 8799' to tap of packer 05:00 06:30 at 8818'. Sting into packer from 8818' to 8827', 500psi increase of pressure observed while stinging into packer. - Monitor well on trip tank, while cleaning rig Floor. Approx 11bb1 per hour loss rate. 1/9/2019 1/9/2019 1.50 COMPZN WELLPR RGRP T While washing and reaming, noticed 06:30 08:00 swivel packing leaking. Change out swivel packing. Attempt to test, still leaking. Change out blackjack swivel packing. Service top drive and test packing, test good. 1/9/2019 1/9/2019 0.50 COMPZN WELLPR TRIP P POOH LD one single at 8797' and 08:00 08:30 hook up top drive blower hose. 1/9/2019 1/9/2019 1.00 COMPZN WELLPR WASH P Break circ at 5bpm 1070psi stand pipe 08:30 09:30 pressure 40RPM and 7.5k torque. Ream and clean packer setting area from 8797' to 8708'. PU one joint DP and wash on top of packer at 3bpm 400psi while stinging into PBR. 1/912019 1/9/2019 0.50 COMPZN WELLPR CIRC P Circ high vis sweep at 61bpm 09:30 10:00 @1350psi. CBU. LD two joints to shed. 1/9/2019 1/9/2019 3.50 COMPZN WELLPR TRIP P POOH to 8767' blow down Top Drive, 10:00 13:30 remove blower hose. Monitor well. 20bph loss rate. Install stripping rubbers. Continue TOH from 8767' to 4319'. Page 11/15 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth StartTime End Time our (h) Phase Op Code Activity Code Time P -T -X Operation (RKS) EM DWh (W -B) 1/9/2019 1/9/2019 1.50 COMPZN WELLPR SLPC P Slip and cut 78' of drill line. Grease 13:30 15:00 drawworks. 119/2019 1/92019 4.00 COMPZN WELLPR TRIP P POOH f/4319'. Reciprocate string 15:00 19:00 mills from 4270' to 4020' ensuring clearance through metal sking patch setting area. Continue POOH to surface. 1/92019 1/9/2019 2.00 COMPZN WELLPR BHAH P UD BHA# 13 and clean up floor 19:00 21:00 1/9/2019 1/9/2019 2.00 COMPZN RPCOMP BHAH P M/U BHA# 14 with lower PKR easy w/ 21:00 23:00 PBR w/ no seals 1/9/2019 1/102019 1.00 COMPZN RPCOMP TRIP P RIH If derrick I/ 1000' lost rate 16 bbls 23:00 00:00 hr 1110/2019 1/10/2019 5.50 COMPZN RPCOMP TRIP P Continue RIH w/ lower pkr easy f/ 00:00 05:30 derrick f/1000' t/ 8600' 1/10/2019 1/10/2019 0.50 COMPZN RPCOMP PULD P Pick up 3-1/2" single drill pipe joints 05:30 06:00 from 8600'to 8829'. Tag top of packer at 8818' and sting in to no-go locator at 8829'. Pick up weight of 155k and Slack off weight of 90k 1/10/2019 1/10/2019 1.00 COMPZN RPCOMP CIRC P Prepare to pump 20 bbls of corrosion 06:00 07:00 inhibited fluid. Unsting from packer and break circulation and establish returns. Pump 20 bola of corrosion inhibited fluid, displace drill string with +9.8 ppg NaCL, under displace by 5 bbls. Leaving 5 bbis of Cl fluid in tubing. Sting into packer and space out, placing end of seal assembly at approximately 8828.87'. 1/10/2019 1/10/2019 1.00 COMPZN RPCOMP PACK P Break connection and drop ball/rod. 07:00 08:00 Make connection back up and allow balllrod to free fall, wait approximately 20 mins. Pressure up ball/rod to 1640 psi and observe shift. Continue to pressure up to 2500 psi, hold 2500 psi for 5 mins. After 5 minutes pressure decreased to 2300 psi. Pick up 15 k over PU weight (155k), shear out of PBR. Blow down top drive and observe well for 15 mins. Approximate loss rate of 15 bph. Baker FHL packet set at 8745.97'. 1/10/2019 1/102019 7.50 COMPZN RPCOMP TRIP P POOH from 8816', laying down 148 08:00 15:30 singles of 3-1/2" drill pipe. Continue POOH racking back 43 stands of 3- 1/2" drill pipe and running tool. 1/10/2019 1/102019 0.50 COMPZN RPCOMP CLEN P Clean and clear rig floor of excess 15:30 16:00 equipment. Prepare rig floor to run 7" casing patch. 1/102019 1/10/2019 1.00 COMPZN RPCOMP SVRG P Perform rig service and service top 16:00 17:00 drive. 1/10/2019 1/11/2019 7.00 COMPZN RPCOMP SHAH P Due to loader breakdown, had to 17:00 00:00 borrow a loader to offload patch equipment. Load tools in shed to prepare to run metal skin patch. 1/112019 1/11/2019 4.00 COMPZN RPCOMP RURD P Continue to prep 3.5" tubing. Stage 00:00 04:00 casing patch tools in shed and prepare to run metal skin patch. Strap and drift all tools. Rig up Weatherford rasing running equipment. Service iron roughneck, drewworks and power tongs. Simultaneously monitoring well on trip tank, approximately 18 bph loss rate. Page 12/15 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) r� 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time Dur (hr) Phase Op Code Agivity Cotle Time P -T -X Operation Stan Depth rtKB) End Depth(fiKB) 1/11/2019 1/11/2019 3.00 COMPZN RPCOMP BHAH P PJSM w/ Crew M/U 3 112" IBMT 04:00 0700 (special clearance) inner string and stand back in derrick. 1/11/2019 1/11/2019 5.50 COMPZN RPCOMP PUTB P Pick 51/2" 16.89#x 7" 23# Metal Skin 07:00 1230 Cased Hole Liner as follows: Cone/Cone mandrel, MCL Anchor Joint, MCL Standard Joints (261'), MCL Top Cap and liner stop. Torque liner to approximately 2400 ftlbs, all torques confirmed by Weatherford torque turn and witnessed by company rep. Rig up false rotary. PU/MU Inner string BHA as follows: GS Spear, Debris Sub, 3 1/2" IBTM tubing from derrick (279'), Hydraulic setting tool, Bumperjar, Sliding valve, and Shear Pin Drain Sub. 1/11/2019 1/11/2019 5.50 COMPZN RPCOMP RUNL P Run 5 1/2' x 7" MCL Skin patch liner 12:30 1800 and inner string on 3 1/2" drill pipe from derrick from 348' to set 4294', 50fpm. Rig up TIW and Side entry Sub to top drive and slump. Install pressure gauge on Side entry sub and test pump. PU weight of 90k, Slack off weight of 75k. Pick up 24' and get on depth. Bottom of Skin patch located at 4270' and top of skin patch located at approximately 3983'. Losses 19bph. Pressure up inner string, observed pressure fluctuation at 2300 psi, indicating cone released and hydraulic tool stroking. Continue pressuring up to 4500 psi ensure tool full stroked out. Bleed pressure off and re pressure up to 4000 psi, no pressure fluctuations observed, indicating tool fully stroked and cone released. Anchorjoint set. Pickup drill string and expand liner with approximately 250k weight, 160k over pick up weight. Continue to POOH reciprocating one single at a time and laying down to ensure liner fully expanded do this for 10 singles. POOH LD one single verify out of patch. Observe well, static. 1/11/2019 1/11/2019 1.00 COMPZN RPCOMP PRTS P Closed pipe rams and pressure test r 18:00 19:00 casing patch to 250/2500psi 5mm each, charted. Released pressure. Tested good. Prep to UP D D 1 19 1/12/2019 5.00 COMPZN RPCOMP PULD P Prep to UD 3 1/2" DP. POOH LD DP. 19:009:00 00:00 1/12/2019 1/12/2019 3.50 COMPZN RPCOMP BHAH P POOH L/D 3 1/2" inner string and 00:00 0330 Weatherford casing patch BHA running tools. 1/12/2019 1/12/2019 2.50 MPZN CO RPCOMP BHAH P Clean up Floor and pulled wear Ring 03:30 06:00 Bushing and load GLM in pipe shed prep U run 3 1/2" Completion string Page 13/15 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) Ain, qW 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth(ftKB) 1/12/2019 1/12/2019 8.00 COMPZN RPCOMP RCST P M/U Baker Seal Assembly locator and 0.0 06:00 14:00 P/U 3 1/2" 9.3# L-80 EUE RD CompletionTubing String. RIH with 3- 1/2" upper completion string. No issue with first GLM running through Top of casing patch at 3983.96'. Continue RIH, while RIH tagged up at approximately 4088' MD (GLM Depth -4028'MD) with 10k weight. GLM fully entered in 5 1/2" x 7" casing patch. Able to pick up from hang up depth with no over pull. Attempt to pass hang up depth several times unsuccessfully. PUWT 57k and SOWT 50k. Discuss forward plan with town. Decision made to POOH racking back 3 112" 8RM EUE and laying down GLM. 1/12/2019 1/12/2019 0.50 COMPZN RPCOMP TRIP T POOH and lay down 2 joints of 3 1/2" 14:00 14:30 EUE and GLM. Rack back two stands of 3 1/2" EUE. 1/12/2019 1/12/2019 0.50 COMPZN RPCOMP TRIP T Decision made to run back in hole. 14:30 15:00 Pick up GLM, 2 stands and 2 singles previous laid down. Screw in with TO and rotate 1 full turn and reciprocate pipe to transfer torque down hole. Release torque and received 1/2 turn back, 1/2 turn in string. Work string back down and tag up at 4088. Put another 1/2 wrap in string and work torque, tagged up at 4088' and weight resumed back to normal Slack off weight of 50k. GLM passed through tight spot. 1/12/2019 1/12/2019 7.50 COMPZN RPCOMP RCST P Continue to run 3 112" 9.3# 8RM EUE 15:00 22:30 upper completions. Tagging up at every collar, work rotation into string and fall through continued to tag up after first GLM passed through and out of patch. 1/13/2019 1/13/2019 2.00 COMPZN RPCOMP RCST P Continue RIH with 3 1/2" upper 00:00 0200 completion string from 8563'to 8744'. Torquing each connections to 2600 ft Ibs. Rig up cement hose and pump at 2 bpm while stabbing seal assembly into packer, observe increase in pressure. Positive indication seal assembly in packer. NO-GO at 8743.67'. PUWT 87k and SOWT 68k. 1/13/2019 1/13/2019 2.50 COMPZN RPCOMP RCST P While POOH to lay dawn 2 singles 02:00 0430 from 8744'to 8684' observed 10k over pull (97k). Make up TO and turn pipe and pump 5 bpm to work pipe free. Lay down 2 joints and space out with 25.21' of space out pups. RIH with same. 1/13/2019 1/13/2019 2.50 COMPZN RP_COMP RCST P Make up 7 1/2" x 3 1/2" tubing hanger 04:30 07:00 and landing joint to the string. Bottom of seal assembly depth 8740.21' (KB), 8.31' of seal assembly stung into packer, 3.49' from No -Go. Rig up TIW and side entry sub and cement line in preparation to displace well. Page 14/15 Report Printed: 1/21/2019 Operations Summary (with Timelog Depths) i- 2T-27 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Time Dur(hr) Phase Op Catle Activity Cotle Time P-T-X Operation ,tart Depth (flKe) End Depth (fli(B) 1/13/2019 1/13/2019 2.50 COMPZN RPCOMP CIRC P Displace 9.8 ppg KWF to 1 k 07:00 09:30 Corrosion Inhibited Seawater at 2 bpm and 375 psi. 1/13/2019 1/13/2019 1.00 COMPZN RPCOMP RCST P Drain BOP stack and land tubing 09:30 10:30 hanger. Run in lock down screws. Lay down landing joint, break down cement line and side entry sub. 1/13/2019 1/13/2019 1.50 COMPZN RPCOMP PRTS P Pressure test 3 1/2" tubing string via 10:30 12:00 kill line against blinds to 3000 psi. Hold pressure for 5 minutes. Test good. Bleed tubing pressure to 1500 psi. Pressure up IA to 2500 psi while maintain 1500 psi on tubing. Hold pressure for 30 minutes. Bleed tubing pressure down from 1500 psi to 0 psi quickly and observe IA pressure decrease, indicating SOV sheared open. Tubing and IA equalized. Pressure tests charted and witnessed by co rep. 1/13/2019 1/13/2019 2.00 COMPZN RPCOMP PRTS P RID Circulation equipment and M/U 12:00 14:00 FMC BPV and set same Test from below to 1000 psi All good RID Weatherford Euipment and clear floor 1/13/2019 1/13/2019 7.00 COMPZN WHDBOP NUND N/D BOP and N/U FMC CIW 3 1/8" 14:00 21:00 5K production Tree 1/132019 1/13/2019 2.00 COMPZN WHDBOP THGR Teating Tubing head Adapter seals t/ 21:00 23:00 5000 Psi 10 mins All good 1/13/2019 1/14/2019 1.00 COMPZN WHDBOP MPSP R/U FMC lubricator and pull BPV and 23:00 00:00 install TWC and test Tree U 5000 psi 15 mins 1/14/2019 1/14/2019 4.00 COMPZN WHDBOP MPSP P FMC lubricator and pull Test Pulg and 00:00 04:00 RID FMC lubricator and R/U LRS. FMC had issues due to tool failure Pulling TWC 1/14/2019 1/142019 1.00 COMPZN WHDBOP RURD P Prepare cellar and well head. Rig up 04:00 05:00 lines and hoses to freeze protect well. Pressure test lines to 2000 psi. Test good. 1/142019 1/14/2019 5.00 COMPZN WHDBOP FRZP P Start pumping Down IA with Diesel to 05:00 10:00 freeze protect well. Approximately 50 bits, into displacement, Little Red switched over to secondary diesel tank to pump remaining volume. Unable to pump due to frozen valves on truck. Thaw valves and resolve issue. Continue pumping remainder of diesel volume of 30 bbl, for a total of 80 bbls. Allow diesel to u-tube and equalize. 1/14/2019 1/14/2019 2.00 COMPZN WHDBOP MPSP P M/U FMC dry rod and RIH w/ FMC 10:00 12:00 1 BPV and set Secure well RID release Rig F/ 2T-27 T/ 2T-22 @ 12:00 Page 15/15 Report Printed: 1/2112019 WELL LOG TRANSMITTAL #905351698 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Set Record: 2T -27A Run Date: 12/16/2018 RECEIVED FEB 0 5 2019 AOGCC 30 32 5 January 14, 2019 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 2T -27A Digital Data in LAS format, Digital Log Image file 50-103-20217-01 1 CD Rom 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: ULOL��Z'( Signed: Kf(,t Z-r-Z7A PM ZM 000 Reqq, James B (DOA) From: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Monday, January 7, 2019 4:31 PM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: rwocoman@conocophillips.com; Kneale, Michael L (SolstenXP); Henson, James; Yearout, Paul Subject: Nabors 7ES BOPE retest due to well control 1-5-19 Attachments: Nabors 7ES WELL 2T-27 1-5-19 BOP retest.xlsx Regards, Kelly Cozby Nabors 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907-670-6126 Cell 907-715-9055 Kelly. Cozbyna.nabors.com I www.nabors.com NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report •AII BOPE reports are due to the agency within 5 days of testing' Submit to: iim reaaCrDalaska cov AOGCC Inspectors(cDalaska cov7 phoebe brooks(rDalaska oov Contractor: Nabors Rig No.: 7ES DATE: 1/5119 " 0 Rig Rep.: Kelly Cozby / Paul Yearout Rig Phone: 907 670-6126 I GK 13 5/8 P - Operator: Conoco Phillips Op. Phone: 907 670-6130 - NA #2 Rams 1 Rep.: Matt Dangerfield f Kevin Barr E -Mail nvocoman(c,conocoghillips.com 0 2 7/8" X 5" Well Name: 2T -27A PTD # 2090900 Sundry # 318-527 #5 Rams 0 Operation: Drilling: Workover: X Explor.: NA Test: Initial: Weekly: Bi -Weekly: HCR Valves , st Pressure (psi): Rams: 250/2500 Annular 250/2500 Valves: 250/ 2500 MASP: 1975 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: NA BOP Misc Test Result Test Result NA Quantity Test Result Location Gen. P - Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P - Hazard Sec. P Ball Type 0 NA ing Order Posted P Misc. NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result Stripper 0 Manual Chokes NA Annular Preventer I GK 13 5/8 P - #1 Rams 0 2 7/8" X 5" - NA #2 Rams 1 Blinds - P - #3 Rams 0 2 7/8" X 5" - NA - #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 0 3 1/8" Gate NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 0 3 1/8" NA - Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD MUD SYSTEM: Visual Trip Tank Quantity Test Result No. Valves 3 P Manual Chokes 0 NA Hydraulic Chokes 0 NA CH Misc 0 NA MUD SYSTEM: Visual Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector NA H2S Gas Detector NA MS Misc 0 Quantity Inside Reel valves 0 ACCUMULATOR SYSTEM: Time/Pressure System Pressure (psi) Pressure After Closure (psi) 200 psi Attained (sac) Full Pressure Attained (sec) Blind Switch Covers: Nitgn. Bottles # & psi (Avg.): ACC Misc Alarm P Test Result Test Result j Test Results Number of Failures: 0 Test Time: 2_0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors alaska. ov Remarks: Tested Blind rams and Annular, Kill and Choke HCR, CMV #7, 8 and 13, due to closure with well bore pressure, All test 250/2500 psi AOGCC Inspection 24 hr Notice Yes Datelrime 1/512019 - 09:00 Waived By Start Date/Time: (date) (time) I Witness Finish Date/Time: 1/5/2019 19:30:00 PM Form 10-424 (Revised 04/2018) Nabors 7ES WELL 2T-27 1-5-19 BOP retest Kcu( 16 -114 Regg, James B (DOA) X4(710 From: NSK West Sak Prod Engr <n1638@conocophiIlips.com> Sent: Wednesday, January 9, 2019 10:23 AM To: Regg, James B (DOA) 10/11 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt; NSK Optimization Engr; Autry, Sydney; Braun, Michael (Alaska) Subject: LPP/SSV Returned to Service on well 1 E-114 Jim, The low pressure pilot (LPP) on well 1E-114 PTD (204-171, 204-172, 204-173) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 1/9/2019, after the well was shut-in fc owinlf g the completion of diagnostic wellwork for a matrix -bypass -event (MBE). The LPP had been defeated on 12/19/2018 after the wellhead injection pressure fell below the LPP setpoint due to an MBE. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Sydney Autry for: Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 7, 2019 (RU 2T- Z?.A- pTb zo2o900 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nabors 7ES with a written report. This report is being submitted for completeness in order to close out the original email notification on 1/07/2019 at 16:30 hrs. Time of BOPE Use: 1/7/19 at 15:05 hours Well Location: 2T -27A API Number: 50-103-20217-01 PTD Number: 209-090 Rig Name: Nabors 7ES Operator Contact: Kevin Barr or Matthew Dangerfield 907-670-6130. Nskrwocoman@conocophillips.com Operations Summary: On 1/7/19 at 15:05 hours the blind rams were shut after observing a 0.25 bbl gain and observable flow at flow linea er pulling the CBL tool out o thf— a hole on E -Line and rigging down E -Line. E -Line - CBL had been out of the hole for 15 minutes when flow was observed. No pressure was observed at choke, but when opened through choke, well flowed an additional 0.25 bbl. Shut in and Bullhead 325 bbls of 9.8ppg Brine down well and flow check, observe well for 2 hours still with observable flow to trip tank. Weighted system to a 9.9 ppg Brine, bullhead 325 bbls 9.9 ppg Brine and flow check, observe well for flow, well on slight losses, pull wear ring and install test plug. Begin pressure test of BOPE at 00:00 hrs 01/08/2019 testing Blind Rams with the choke and kill HCRs, and choke mam old valves #7, 98, #13 to 250 / 2500 psi 5 min. All pass tests. Monitor well throughout test with losses increasing to 50 bbl/hr. Well continues to be on 50 bbl/hr losses filling well with 9.9 ppg Brine. BOPE Used: Blind Rams on 13-5/8" 5M BOP Reason for BOPE Use: The Blind Rams were closed to control well flow and bullhead KWF. Actions to Be Taken: The Blind Rams will be retested after confirmed no -flow test along with the choke and kill HCRs and choke manifold valves #7, #8, #13 to 250 / 2500 psi 5 min. If you have any questions or require any further information, please contact me at 670-6130 or 670-6135. Sincerely, Matthew Dangerfield and Kevin Barr Well Site Supervisor CPAI Drilling and Wells 2C�-c, )cam Regg James B (DOA) From: NSK RWO CoMan <NSKRWOCoMan@conocophillips.com> Sent: Saturday, January 5, 2019:22 PM q�ej /711?To: DOA AOGCC Prudhoe Ba Cc: Regg, James B (DOA) Subject: RE: [EXTERNAL]AOGCC Inspection Form Confirmation Email Attachments: Notification Letter for BOP use 1-4-19.doc; Notification Letter for BOP use 1-5-19.doc BOPE usage on Nabors 7ES is being submitted for completeness in order to close out the original email notification on 1/05/2019 at 09:00 hrs In addition to the two attached with explanations below, as we were flow checking after the 9.7 ppg Brine bull head, we experienced a slight flow when attempting to drain the stack to set test plug. We shut the blind rams again at 12:45 P.M. too serve or pressure and there was no recordable pressure. However, we did have a slight flow at the IA gauge and it was showing a small pressure. So we bullheaded a 9.8 ppg, and we are now flow checking with a 3 -10 bbl /hr loss rate, will monitor for 2 hours to ensure well is dead before proceeding with the BOP test of elements and valves that were utilized throughout this process. Additionally, we have located two wells on Tango Pad that are injecting, and the production engineer has brought them off line since 3:00 P.M. Thanks Matt Operations Summary: On 1/5/19 at 8:45 hours, after bull heading well with the annular closed with 9.6 ppg Brine, flow check showed static well bore. POOH wit the IBP to lay down tools. The Blind Rams was shut in to observe well for flow after the inflatable bridge plug (IBP) was pulled to surface and laid out. The initial casing pressure was 0 psi but after a few minutes climbed to 6.8 psi. Final casing pressure built to 6.8 psi. Bull headed below the blind rams through the kill line observing pressure on choke gauge with Power Choke, choke manifold valves #7, #8, and #13 closed. Well was successfully bull headed with 315 bbls of 9.7 ppg Brine and flow check was negative with a static well bore with slight losses of 1-2 bbls/hr. BOPE Used: Annular Preventer, Blind Rams, Power Choke, choke manifold valves #7, #8, and #13 13-5/8" 5M BOPE. Reason for BOPE Use: The annular and blind rams were closed to monitor the well, and to bull head against to fill the well with KWF. Actions to Be Taken: The Annular Preventer, Blind Rams, Power Choke, choke manifold valves #7, #8, and #13 will be pressure tested to 250 psi / 2,500 psi 5 minutes tests and verified with help from Jeff Jones with AOGCC. Additional notice was provided earlier with the initial shut in of the annular: On 1/4/19 at 20:15 hours, the annular was shut in to observe well for flow while pulling inflatable bridge plug. The initial casing pressure was 10 psi. Final casing pressure built to 10 psi. Pressure was bled, well continued to flow. The well was shut in and pressure built to 10 psi in 10 minutes. Bottoms up was circulated and the well was shut in once more and pressure again built to 10 psi. 50 bbls of the fluid system was weighted up to 10.0 PPG. The well was circulated at inflatable bridge plug depth of 618'. BOPE Used: Annular Preventer on 13-5/8" 5M BOP '� Reason for BOPE Use: The annular was closed to determine if we had pressure below the inflatable bridge plug. Actions To Be Taken: The annular will be retested when the inflatable bridge plug is removed from the well. If you have any questions or require any further information, please contact me at 670-6130 or 670-6135. Cheers, Matt Dangerfield / Kevin Barr CPAI Wells Supervisors RWO / Nabors Rig 7ES Site Office: (907) 670-6130 Rig Office: (907) 670-6135 Mobile: (907) 223-6303 WELLS TEAM c000coaramps From: Dangerfield, Matt A <Matt.A.Dangerfield@conocophillips.com> Sent: Saturday, January 5, 2019 6:17 AM To: NSK RWO CoMan<NSKRWOCoMan@conocophillips.com> Subject: FW: [EXTERNAL]AOGCC Inspection Form Confirmation Email From: AOGCC Inspections <noreply iotform.com> Sent: Saturday, January 5, 2019 6:17 AM To: Dangerfield, Matt A <Matt A Dangerfield Caconocophillips.com> Subject: [EXTERNAL]AOGCC Inspection Form Confirmation Email This email confirms your request for an inspection with the following information: Type of Test Requested: BOPE Other Requested Time for Inspection: 01-05-2019 12:00 PM Location: Nabors 7ES, 2T-27, KPRU, CPAI Name: Matthew Dangerfield E-mail: matt.a.dangerfield@conocophillips.com Phone Number: (907) 6706130 Company: CPAI Other Information: Re -Test Annular Preventer on 3.5" DP after shutting annular for well flow and bullheading well dead. If you are not contacted within 12 hours, please notify Jim Regg at 907-793-1236. Thank you! Alaska Oil and Gas Conservation Commission ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 5, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nabors 7ES with a written report. This report is being submitted for completeness in order to close out the original email notification on 1/05/2019 at 06:15 hrs. Time of BOPE Use: 1/4/19 at 22:15 hours — Well Location: 2,T,2'lr Zr—Z?,l API Number: 50-103-20217-01 PTD Number: 209-090 Rig Name: Nabors 7ES Operator Contact: Kevin Barr or Matthew Dangerfieldrep 907-670-6130. Nskrwocoman@conocophillips.com Operations Summary: On 1/4/19 at 20:15 hours, the annular was shut in to observe well for flow while pulling inflatable bridge plug. The initial casing pressure was 10 psi. Final casing pressure built to 10 psi. Pressure was bled, well continued to flow. The well was shut in and pressure built to 10 psi in 10 minutes. Bottoms up was circulated and the well was shut in once more and pressure again built to 10 psi. 50 bbls of the fluid system was weighted up to 10.0 PPG. The well was circulated at inflatable bridge plug depth of 618'. BOPE Used: Annular Preventer on 13-5/8" SM BOP Reason for BOPE Use: The annular was closed to determine if we had pressure below the inflatable bridge plug. Actions To Be Taken: The annular will be retested when the inflatable bridge plug is removed from the well If you have any questions or require any further information, please contact me at 670-6130 or 670-6135. Sincerely, Matthew Dangerfield and Kevin Barr Well Site Supervisor CPAI Drilling and Wells ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 5, 2019 AOGCC Industry Guidance Bulletin No. 10-003 Reporting BOPE Use to Prevent the Flow of Fluids from a Well Dear Commissioner: As per AOGCC Industry Guidance Bulletin No. 10-003, this letter is to follow up the email notification of BOPE usage on Nabors 7ES with a written report. This report is being submitted for completeness in order to close out the original email notification on 1/05/2019 at 09:00 hrs. Time of BOPE Use: 1/5/19 at 08:45 hours Well Location: 2Ti2%' 0r --27A, API Number: 50-103-20217-01 PTD Number: 209-090 Rip Name: Nabors 7ES ' Operator Contact: Kevin Barr or Matthew Dangerfield. 907-670-6130. Nskrwocoman@conocophillips.com Operations Summary: On 1/5/19 at 8:45 hours, after bull heading well with the annular closed with 9.6 ppg Brine, flow check showed static well bore. POOH with the IBP to lay down tools. The Blind Rams was shut in to observe well for flow after the inflatable bridge plug (IBP) was pulled to surface and laid out. The initial casing pressure was 0 psi but after a few minutes climbed to 6.8 psi. Final casing pressure built to 6.8 psi. Bull headed below the blind rams through the kill line observing pressure on choke gauge with Power Choke, choke manifold valves #7, #8, and #13 closed. Well was successfully bull headed with 315 bbls of 9.7 ppg Brine and flow check was negative with a static well bore with slight losses of 1-2 bbls/hr. BOPE Used: Annular Preventer, Blind Rams, Power Choke, choke manifold valves #7, #8, and 413 closed. 13-5/8" 5M BOPE. Reason for BOPE Use: The annular and blind rams were closed to monitor the well, and to bull head against to fill the well with KWF. Actions to Be Taken: The Annular Preventer, Blind Rams, Power Choke, choke manifold valves #7, #8, and #13 will be pressure tested to 250 psi / 2,500 psi 5 minutes tests and verified with help from Jeff Jones with AOGCC. If you have any questions or require any further information, please contact me at 670-6130 or 670-6135. Sincerely, Matthew Dangerfield and Kevin Barr Well Site Supervisor CPAI Drilling and Wells 0 ) Ol ~ O [[ di n x al m ti c700 o L N Z - �° asp ° Y 3 OJ�CO nfl , > a (VI Q n Y O p co (/ Q r p C u +-, E > p n CO +:., O ,n al '- o a a C C T o j @ Y �o L +., 'a i-III frJ ; ra a o o •0 4 n n n n n n O 7 > > > > > > WJ f07 7 OO a1 ew ;a) CE -C o im ,,V1 C (0 cu s. Y Nr N N N CQ u -° (0 0 +.' Z a o ) > E C v h'. C+ U + a3 O ~ C v a L O 0 0 0 0 0 0 g ii W J J J J J J J C y= O 9 } W W W W W W W v, • C 'L U C t- LL LL LL LL LL LL LL +-' aJ > a1 -0 C a J J J J J J J a > C K Qom) a Z Z Z Z Z Z 2 U CO N 00 co a O LL LL LL LL LL LL LL CL -0 C > pd• ' - +gtt �' Y > C al y u nl O . 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RECEIVED DATA LOGGED M.K.BENDER JUL 13 2017 To: AOGCC AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 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 attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED AUG 0 3 2017 1) Caliper Report 23-Jun-17 2T-27A 1 Report /CD 50-103-20217-01 2) Signed : //) ,A4,261.474 ,04/7) OAdedgel, Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(t MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFi les\Templates\Distribution\TransmittalS heets\ConocoPhillips_Transmit.docx 20"1 - 090 °RECEIVED • 2.-IS 3/S JUL 13 2017 Memory Multi-Finger Caliper AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2T-27A Log Date: June 23, 2017 Field: Kuparuk Log No.: 12784 State: Alaska Run No.: 2 API No. 50-103-20217-01 Pipe Description: 3.5 inch 9.3 lb. L-80 EUE ABM Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,849 Ft.(MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : This caliper data is tied into the Camco W-1 Landing Nipple at 8,827.4 feet per the tubing detail dated August 28, 1995. This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage and to look for signs of tubing buckling due to subsidence. The caliper recordings indicate slight to moderate buckling from—3,000 feet to 8,849 feet(end of log). A 3-D log plot overlay of the centered and un- centered caliper recordings across the tubing logged is included in this report. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to fair condition, with the exception of a hole recorded in joint 275 (8,825 ft)where the caliper also recorded 15%cross-sectional wall loss. A 3-D log plot of the caliper recordings across the recorded hole is included in this report. Additional wall penetrations ranging from 20%to 28%wall thickness are recorded in 51 of the 292 joints logged. Recorded damage appears as a line of pits and line corrosion. No other significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. This is the second time a PDS caliper has been run in this well and the 3.5 inch tubing has been logged. A comparison of the current and previous log (February 21, 2009) indicates an increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint-by-joint basis between logs is included in this report. MAXIMUM RECORDED WALL PENETRATIONS : Description Percent Mill Penetration ioini 1A-.nt! Hole 100 275 8,825 Ft. (MD) Line Corrosion 28 166 5,306 Ft. (MD) Line Corrosion 26 152 4,868 Ft. (MD) Line of Pits 26 274 8,756 Ft. (MD) Line Corrosion 26 60 1,954 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: [ scripiial Percent Jail Loss Jo i(ti riP Hole 15 275 8,825 Ft. (MD) No other significant areas of cross-sectional wall loss (> 9%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. R. Holden C. Waldrop J. Fama Field Erginee!(5) ,Analyst(s) b'Jiinc'ssies's ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 0 0 414 -.• PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-27A Date : June 23, 2017 Description : Detail of Caliper Recordings Across Hole Recorded in 3.5 Inch Tubing. Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map 11ft:100ft I 0 10012.5 3.5 33° 0° 90° 180° 270° 0° Maximum I.D. 2.5 3.5 Minimum I.D. I I 2.5 3.5 CO,0_, 3 - �3 1? 8800 i 1 __ ,,,..: 8805 Joint 275 - Hole(8,825') 8810 15% Cross-Sectional Wall Loss - 8815 ! i,: 8820 8825 . __��.i�__... �.. _ _ ,__- _...;�it W-1 Nipple 7 • 8830 _.___ Pup Joint . 8835 -- _.: _ ___.______ 8840 Seal Assembly = a LI' 8845 Packer 0 • 116 .. PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2T-27A Date : June 23, 2017 Description : Overlay of Centered and Un-Centered Caliper Recordigns Across 3.5 Inch Tubing Logged. Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 2.5 3.5 1:800 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° Maximum I.D. I 2.5 inches 3.5 Minimum I.D. 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" _ q MINI!!MIIIE IIM8500- _ !!!lEtra�®i! !!!-E1EI_iiil!! !!!lIMt1!!!!miummmirvirAIIIMMEISMENI8550 !!ENIMM UF!®ii1! -- !!4l111ltillil� .=_ !!!li�A�OlAll�q! ! !lEiki!!® 8600 ! - ■l��INrAlIl��i! , - . 1111:11111111;111111111:111111 1 . :a !!!lE�E�!!!!8650 _ r 11110hom® iim _ !!!l=1111!!!! - 11111111112111111111111111111111 ! :7.: 4111111101maimiiiiiimm • • .gryg•h• rm • 1 1 - • rt =7�r� 8750 = ,', ....., ..fir x,.,... snma��. �... ..=„n+,� 8800 _ it.,,,., I+smuuuui UM Minimum Radius 1.25 inches 1.75 Maximum Radius 1.25 inches 1.75 Minimum I.D. I I 2.5 inches 3.5 Maximum I.D. I ( 2.5 inches 3.5 Nominal I.D. Depth 3-D Log(Un-Centered) Image Map(Un-Centered) 3-D Log(Centered) Image Map(Centered) 2.5 3.5 1:800 ' 0° 0° 90° 180°270° 0° 0° 0° 90° 180°270° 0° • • Maximum Recorded Penetration Comparison To Previous Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Previous Date: February 21,2009 Company: ConocoPhillips Alaska, Inc. Tool Type: UW MFC 24 No. 214320 Country: USA Tubing: 3.5"9.3 lb L-80 EUE ABM Overlay Difference Maximum Recorded Penetration(mils) Difference in Maximum Penetration(mils) 0 50 100 150 200 250 -300 -150 0 150 300 0.1 _ _ 0.1 - 21 21 46 46 GLM 1 68 — 68 93 . 93 118 118 d L GLM' cc � G 140w Z 140 3 c 'o 165 165 GLM 3 187 187 212 212 GLM 4 234 234 GLM 5- 256 • 256 GLM 6 _ 275.3 275.3 -36 -18 0 18 36 June 23,2017 El February 21,2009 Approximate Corrosion Rate(mpy) Corrosion Rate(mpy) Top 10 Jts. Overall Average 6 1 I Median ; 3 0 • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (81.1'-8,848.8') Well: 2T-27A Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: June 23,2017 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 84 25 855 50 _ 1,638 GLM1 75 2,439 100 3,221 125 4,001 GLM 2 150 _ 4,802 2 GLM 3 5,585 „_ Z s .*E. 200 6,386 0 GLM 4 225 7,190 GLM 5 250 7,973 GLM 6 275 8,796 275.4 8,847 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=275.4 • • 111111 PDS Report Overview Body Region Analysis Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE ABM Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM 2.992 in. 81 ft. 8,849 ft. Penetration(%wall) Damage Profile(%wall) 250 NM Penetration body An Metal loss body 0 50 100 0.1 200 150 100 46 50 GLM 1 (10:00) 0 0 to 20 to 40 to over 93 20% 40% 85% 85% Number of joints analyzed(total=292) 240 51 0 1 GLM 2 (9:00) 140 Damage Configuration(body) 200 GLM 3 (2:00) 150 187 100 GLM 4(3:00) 50 234 0 Isolated General Line Other Hole/ GLM 5 (8.00) Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=206) GLM 6(8:00) 7 0 198 0 1 Bottom of Survey=275.4 • • so (A 0., . PDS Report Joint Tabulation Sheet Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 81 0 0.01 4 1 2.96 Pup 1 84 0 0.04 16 3 2.92 Shallow Line of Pits.Lt. Deposits. 1.1 115 0 0.03 12 , 4 2.92 Pup Lt. Deposits. 1.2 126 0 0.01 5 1 2.94 Pup 1.3 131 0 0.01 5 0 2.90 Pup Lt. Deposits. 2 133 0 0.04 16 4 2.93 Shallow Line of Pits.Lt. Deposits. 3 164 0 0.05 19 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 4 195 0 0.04 17 4 2.93 Shallow Line Corrosion.Lt. Deposits. 5 227 0 0.03 10 3 2.89 Lt. Deposits. 6 258 0 0.05 18 4 2.93 Shallow Line Corrosion.Lt. Deposits. 7 289 0 0.05 18 4 2.93 Shallow Line Corrosion.Lt. Deposits. 8 321 0 0.05 18 4 2.93 Shallow Line Corrosion.Lt. Deposits. ■ 9 352 0 0.05 20 4 2.92 Line Corrosion. Lt.Deposits. ■ _ 10 383 0 0.03 13 4 2.88 Lt. Deposits. 11 413 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. 12 445 0 0.05 19 4 2.93 Shallow Line Corrosion. • 13 477 0 0.05 21 4 2.93 Line Corrosion. Lt.Deposits. ■ 14 508 0 0.05 18 4 2.91 Shallow Line Corrosion.Lt. Deposits. 14.1 540 0 0 0 0 2.80 CAMCO DS LANDING NIPPLE 15 541 0 0.05 20 3 2.92 Line of Pits. Lt.Deposits. 16 572 0 0.05 18 , 4 2.93 Shallow Line of Pits.Lt. Deposits. 17 604 0 0.05 20 4 2.92 Line Corrosion. Lt.Deposits. 18 635 0 0.05 18 4 2.92 Shallow Line of Pits.Lt. Deposits. 19 666 0 0.04 15 3 2.93 Shallow Line of Pits.Lt. Deposits. 20 698 0 0.04 16 4 2.93 Shallow Line of Pits. 21 729 0 0.05 18 4 2.93 Shallow Line of Pits.Lt. Deposits. 22 760 0 0.04 14 3 2.93 Lt. Deposits. 23 792 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. 24 823 0 0.06 24 5 2.92 Line Corrosion. Lt.Deposits. • 25 855 0 0.04 16 4 2.93 Shallow Line of Pits.Lt. Deposits. 26 886 0 0.03 10 3 2.92 Lt. Deposits. 27 918 0 0.04 17 4 2.93 Shallow Line of Pits.Lt. Deposits. 28 949 0 0.05 18 5 2.93 Shallow Line Corrosion.Lt. Deposits. ■ 29 981 0 0.04 14 4 2.93 Lt. Deposits. 30 1012 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. 31 1043 0 0.04 14 3 2.93 Lt. Deposits. 32 1075 0 0.04 17 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 33 1106 0 0.03 10 1 2.94 34 1137 0 0.03 12 4 2.92 Lt. Deposits. 35 1169 0 0.04 15 4 2.92 Shallow Pitting. Lt.Deposits. 36 1200 0 0.04 16 4 2.94 Shallow Line Corrosion. ■ 37 1231 0 0.05 18 4 2.93 Shallow Line Corrosion.Lt. Deposits. 38 1263 0 0.03 11 2 2.94 39 1294 0 0.04 17 4 2.93 Shallow Line of Pits.Lt. Deposits. 40 1326 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. 41 1357 0 0.04 16 4 2.93 Shallow Line of Pits. 42 1388 0 0.05 18 6 2.93 Shallow Line Corrosion. ■ 43 1420 0 0.04 17 4 2.94 Shallow Line of Pits. • 44 1451 0 0.03 12 2 2.93 45 1482 0 0.05 18 4 2.93 Shallow Line Corrosion.Lt. Deposits. IPenetration Body Metal Loss Body Page 1 • • III PDS Report Joint Tabulation Sheet Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 46 1514 0 0.04 17 4 2.93 Shallow Line of Pits. 47 1545 0 0.03 13 3 2.92 Lt. Deposits. 48 1576 0 0.05 18 4 2.93 Shallow Line of Pits.Lt. Deposits. 49 1608 0 0.03 12 4 2.89 Lt. Deposits. 50 1638 0 0.03 13 3 2.93 Lt. Deposits. • 51 1668 0 0.04 17 4 2.92 Shallow Line Corrosion.Lt. Deposits. 52 1699 0 0.03 10 3 2.93 • 53 1730 0 0.04 15 4 2.93 Shallow Line of Pits.Lt. Deposits. 54 1762 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. 55 1793 0 0.02 9 2 2.93 Lt. Deposits. • 56 1824 0 0.06 22 5 2.93 Line Corrosion. Lt.Deposits. r 57 1856 0 0.04 17 4 2.93 Shallow Line of Pits.Lt. Deposits. 58 1887 0 0.04 14 3 2.93 Lt. Deposits. • 59 1918 0 0.06 24 5 2.92 Line Corrosion. Lt.Deposits. 60 1950 0 0.07 26 5 2.93 Line Corrosion. • 61 1981 0 0.06 22 4 2.93 Line Corrosion. Lt.Deposits. 61.1 2012 0 0.04 15 4 2.92 Pup Shallow Line of Pits.Lt. Deposits. 61.2 2018 0 0 0 0 2.90 GLM 1 (LATCH @ 10:00) 61.3 2027 0 0.02 9 3 2.92 Pup Lt. Deposits. 62 2033 0 0.04 17 3 2.93 Shallow Line of Pits.Lt. Deposits. 63 2064 0 0.03 10 3 2.92 Lt. Deposits. 64 2095 0 0.04 16 4 2.92 Shallow Line of Pits.Lt. Deposits. 65 2126 0 0.05 19 5 2.93 Shallow Line Corrosion.Lt. Deposits. ■ 66 2158 0 0.03 12 2 2.92 Lt. Deposits. 67 2189 0 0.02 7 2 2.93 68 2220 0 0.04 15 4 2.91 Shallow Line Corrosion.Lt. Deposits. 69 2251 0 0.05 19 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 70 2282 0 0.04 16 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 71 2314 0 0.04 17 4 2.92 Shallow Line Corrosion.Lt. Deposits. 72 2345 0 0.04 14 4 2.93 Lt. Deposits. 73 2376 0 0.03 11 3 2.92 Lt. Deposits. 74 2408 0 0.05 20 5 2.91 Line Corrosion. Lt.Deposits. ■ 75 2439 0 0.04 16 3 2.92 Shallow Line of Pits.Lt. Deposits. 76 2470 0 0.04 15 3 2.93 Shallow Line of Pits.Lt. Deposits. 77 2502 0 0.05 18 2 2.92 Shallow Line of Pits.Lt. Deposits. 78 2533 0 0.04 16 4 2.92 Shallow Line Corrosion.Lt. Deposits. 79 2564 0 0.04 16 2 2.93 Shallow Line Corrosion.Lt. Deposits. 80 2596 0 0.04 17 3 2.92 Shallow Line of Pits.Lt. Deposits. 81 262 7 0 0.03 13 4 2.92 Lt. Deposits. 82 2658 0 0.04 14 3 2.92 Lt. Deposits. 83 2690 0 0.03 13 3 2.92 Lt. Deposits. s 84 2721 0 0.04 16 4 2.92 Shallow Line Corrosion.Lt. Deposits. 85 2753 0 0.03 13 2 2.91 Lt. Deposits. 86 2784 0 0.05 21 5 2.93 Line Corrosion. Lt.Deposits. ■ 87 2815 0 0.05 20 5 2.93 Line Corrosion. Lt.Deposits. ■ 88 2846 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. 89 2878 0 0.05 19 , 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 90 2908 0 0.04 15 5 2.93 Shallow Pitting. Lt.Deposits. ■ 91 2939 0 0.04 14 4 2.92 Lt. Deposits. 92 2971 0 0.04 14 3 2.89 Lt. Deposits. IPenetration Body Metal Loss Body Page 2 0 • 11111 - Report PDS Joint Tabulation Sheet �� Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 93 3002 0 0.06 22 4 2.93 Line Corrosion. Lt.Deposits. ■ 94 3033 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 95 3064 0 0.06 23 4 2.92 Line Corrosion. Lt.Deposits. ■ 96 3096 0 0.03 11 3 2.91 Lt. Deposits. • 97 312 7 0 0.05 18 4 2.93 Shallow Line Corrosion.Lt. Deposits. ■ 98 3158 0 0.04 14 4 2.92 Lt. Deposits. • 99 3190 0 0.04 17 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 100 3221 0 0.05 18 5 2.92 Shallow Line of Pits.Lt. Deposits. a 101 3253 0 0.04 16 2 2.92 Shallow Line of Pits.Lt. Deposits. ■ 102 3283 0 0.05 21 4 2.92 Line Corrosion. Lt.Deposits. ■ 103 3314 0 0.05 21 3 2.93 Line Corrosion. Lt.Deposits. ■ 104 3345 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 105 3377 0 0.06 22 5 2.92 Line Corrosion. Lt.Deposits. I 106 3408 0 0.05 20 4 2.93 Line of Pits. Lt.Deposits. • 107 3439 0 0.05 19 5 2.93 Shallow Line of Pits.Lt. Deposits. ■ 108 3471 0 0.05 18 4 2.93 Shallow Line of Pits.Lt. Deposits. ■ 109 3502 0 0.04 15 3 2.94 Shallow Line of Pits. • 110 3533 0 0.03 11 3 2.93 • 111 3564 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 112 3596 0 0.03 13 3 2.88 Lt. Deposits. ■ 113 3627 0 0.05 20 4 2.92 Line Corrosion. Lt.Deposits. a 114 3658 0 0.04 17 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 115 3689 0 0.03 13 4 2.92 Lt. Deposits. • 116 3720 0 0.04 17 3 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 117 3752 0 0.04 15 4 2.93 Shallow Line of Pits.Lt. Deposits. ■ 118 3783 0 0.03 12 2 2.93 Lt. Deposits. • 119 3814 0 0.05 18 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 120 3845 0 0.05 20 3 2.92 Line of Pits. Lt.Deposits. • 121 3876 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 122 3907 0 0.05 19 4 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 123 3939 0 0.05 19 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 124 3970 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. a 125 4001 0 0.05 20 4 2.93 Line of Pits. Lt.Deposits. • 126 4033 0 0.04 14 2 2.92 Lt. Deposits. ini 127 4064 0 0.04 17 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 128 4095 0 0.03 13 3 2.92 Lt. Deposits. • 129 412 7 0 0.03 11 2 2.92 Lt. Deposits. is 130 4158 0 0.04 16 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 131 4189 0 0.04 17 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 132 4221 0 0.03 13 4 2.92 Lt. Deposits. s 133 4252 0 0.04 15 3 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 133.1 4283 0 0.05 19 3 2.92 Pup Shallow Line Corrosion.Lt. Deposits. 133.2 4289 0 0 0 0 2.88 GLM 2(LATCH @ 9:00) 133.3 4297 0 0.04 15 6 2.92 Pup Shallow Line of Pits.Lt. Deposits. i 134 4303 0 0.05 21 4 2.92 Line Corrosion. Lt.Deposits. a 135 4335 0 0.05 20 3 2.93 Line of Pits. Lt.Deposits. • 136 4366 0 0.03 11 2 2.91 Lt. Deposits. 137 4397 0 0.02 9 2 2.92 Lt. Deposits. • 138 4428 0 0.03 11 2 2.93 Lt. Deposits. III 139 4460 0 0.03 10 2 2.93 Lt. Deposits. IPenetration Body Metal Loss Body Page 3 • Ili PDS Report Joint Tabulation Sheet Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 140 4491 0 0.05 19 4 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 141 4522 0 0.03 13 3 2.93 Lt. Deposits. ■ 142 4553 0 0.03 13 4 2.91 Lt. Deposits. ■ 143 4585 0 0.04 16 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 144 4616 0 0.05 18 4 2.93 Shallow Line of Pits.Lt. Deposits. ■ 145 4647 0 0.03 11 2 2.92 Lt. Deposits. • 146 4678 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. ■ 147 4709 0 0.05 18 5 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 148 4739 0 0.05 19 4 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 149 4771 0 0.03 10 3 2.89 Lt. Deposits. r 150 4802 0 0.05 20 4 2.92 Line Corrosion. Lt.Deposits. 151 4834 0 0.04 15 3 2.88 Shallow Line of Pits.Lt. Deposits. ■■3 152 . 4865 0 0.07 26 7 2.92 Line Corrosion. Lt.Deposits. 153 4896 0 0.04 . 16 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 154 4927 0 0.04 15 3 2.91 Shallow Pitting. Lt.Deposits. 155 4959 0 0.02 9 2 2.91 Lt. Deposits. 156 4990 0 0.03 12 3 2.93 Lt. Deposits. a 157 5021 0 0.03 11 3 2.91 Lt. Deposits. ■ 158 5052 0 0.05 18 4 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 159 5084 0 0.04 16 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 160 5115 0 0.04 14 3 2.91 Lt. Deposits. ■ 161 5146 0 0.05 21 4 2.92 Line Corrosion. Lt.Deposits. ■ 162 5177 0 0.04 17 3 2.90 Shallow Line of Pits.Lt. Deposits. ■ 163 5209 0 0.04 15 4 2.92 Shallow Pitting. Lt.Deposits. ■ 164 5240 0 0.04 15 2 2.92 Shallow Line of Pits.Lt. Deposits. ■ 165 5271 0 0.03 13 4 2.90 Lt. Deposits. ■ 166 5303 0 0.07 28 4 2.92 Line Corrosion. Lt.Deposits. ■ 167 5334 0 0.03 11 2 2.92 Lt. Deposits. ■ 168 5365 0 0.03 13 2 2.92 Lt. Deposits. a 169 5397 0 0.04 17 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 170 5428 0 0.03 13 3 2.90 Lt. Deposits. ■ 171 5459 0 0.05 19 4 2.89 Shallow Line Corrosion.Lt. Deposits. ■ 172 5490 0 0.04 17 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 173 5522 0 0.04 14 3 2.92 Lt. Deposits. ■ 174 5553 0 0.05 19 3 2.90 Shallow Line Corrosion.Lt. Deposits. ■ 175 5585 0 0.03 13 2 2.91 Lt. Deposits. ■ 176 5616 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 177 5647 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 177.1 5679 0 0.03 12 2 2.90 Pup Lt. Deposits. 177.2 5685 0 0 0 0 2.90 GLM 3(LATCH @ 2:00) 1 177.3 5693 0 0.03 13 2 2.92 Pup Lt. Deposits. ■ 178 5699 0 0.05 19 3 2.92 Shallow Pitting. Lt.Deposits. ■ 179 5730 0 0.06 25 4 2.91 Line Corrosion. Lt.Deposits. ■ 180 5761 0 0.03 13 3 2.91 Lt. Deposits. ■� 181 5793 0 0.03 13 3 2.92 Lt. Deposits. ■ 182 5824 0 0.05 19 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 183 5855 0 0.05 20 4 2.91 Line Corrosion. Lt.Deposits. ■ 184 5887 0 0.04 16 3 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 185 5918 0 0.05 20 3 2.92 Line Corrosion. Lt.Deposits. ■ 186 5949 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. IPenetration Body Metal Loss Body Page 4 • S ill PDS Report Joint Tabulation Sheet Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 187 5980 0 0.05 19 ' 4 2.90 Shallow Line of Pits.Lt. Deposits. 188 601 1 0 0.05 19 3 2.90 Shallow Line of Pits.Lt. Deposits. 189 6043 0 0.03 12 3 2.92 Lt. Deposits. • 190 6074 0 0.05 18 4 2.86 Shallow Line of Pits.Lt. Deposits. 191 6105 0 0.04 16 3 2.91 Shallow Line of Pits.Lt. Deposits. 192 6136 0 0.03 13 3 2.86 Lt. Deposits. 193 6167 0 0.04 14 2 2.90 Lt. Deposits. • 194 6199 0 0.06 24 4 2.88 Line of Pits. Lt.Deposits. 195 6230 0 0.06 22 4 2.89 Line Corrosion. Lt.Deposits. ■ 196 6261 0 0.05 21 4 2.92 Line Corrosion. Lt.Deposits. 197 6292 0 0.05 20 4 2.88 Line Corrosion. Lt.Deposits. 198 6323 0 0.04 17 3 2.92 Shallow Line of Pits.Lt. Deposits. 199 6355 0 0.04 . 16 3 2.92 Shallow Line of Pits.Lt. Deposits. 200 6386 0 0.05 19 3 2.92 Shallow Line Corrosion.Lt. Deposits. 201 6417 0 0.04 15 3 2.89 Shallow Line of Pits.Lt. Deposits. ■ 202 6449 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 203 6480 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 204 651 1 0 0.04 17 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 205 6543 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. 206 6574 0 0.03 13 4 2.86 Lt. Deposits. 207 6605 0 0.03 13 3 2.87 Lt. Deposits. 208 6636 0 0.05 20 3 2.91 Line Corrosion. Lt.Deposits. 209 6667 0 0.05 20 3 2.91 Line of Pits. Lt.Deposits. 210 6699 0 0.06 25 4 2.92 Line Corrosion. Lt.Deposits. 211 6730 0 0.03 12 2 2.92 Lt. Deposits. 212 6762 0 0.04 17 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 213 6793 0 0.03 13 4 2.92 Lt. Deposits. 214 6825 0 0.05 21 4 2.93 Line of Pits. Lt.Deposits. 215 6856 0 0.05 19 4 2.92 Shallow Line of Pits.Lt. Deposits. 216 6887 0 0.04 14 3 2.92 Lt. Deposits. 217 6919 0 0.05 18 5 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 218 6950 0 0.05 19 3 2.92 Shallow Line Corrosion.Lt. Deposits. 219 6981 0 0.04 17 3 2.92 Shallow Line Corrosion.Lt. Deposits. 220 7013 0 0.04 16 3 2.92 Shallow Line of Pits.Lt. Deposits. 221 7044 0 0.05 18 4 2.91 Shallow Line Corrosion.Lt. Deposits. 222 7076 0 0.04 14 3 2.92 Lt. Deposits. 222.1 7107 0.05 0.04 14 3 2.90 Pup Lt. Deposits. 222.2 7113 0 0 0 0 2.89 GLM 4(LATCH @ 3:00) 222.3 7121 0 0.04 15 3 2.91 Pup Shallow Line of Pits.Lt. Deposits. 223 7127 0 0.05 19 3 2.92 Shallow Line Corrosion.Lt. Deposits. 224 7159 0 0.05 21 4 2.92 Line of Pits. Lt.Deposits. 225 7190 0 0.04 16 4 2.92 Shallow Line Corrosion.Lt. Deposits. 226 7221 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 227 7252 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. 228 7284 0 0.04 16 3 2.92 Shallow Line of Pits.Lt. Deposits. 229 7315 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. 230 7346 0 0.05 18 2 2.92 Shallow Line of Pits.Lt. Deposits. 231 7377 0 0.03 13 2 2.92 Lt. Deposits. 232 7409 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. 233 7440 0 0.04 14 4 2.90 Lt. Deposits. Penetration Body Metal Loss Body Page 5 • • ilil PDS ReportJoint/10...... PDS Io nt Tabulation Sheet Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 234 7472 0 0.05 19 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 235 7503 0 0.04 14 3 2.91 Lt. Deposits. • 236 7534 0 0.04 17 4 2.91 Shallow Pitting. Lt.Deposits. a 237 7565 0 0.05 18 4 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 238 7597 0 0.04 15 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 239 7628 0 0.04 17 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 240 7660 0 0.05 18 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 241 7691 0 0.04 14 4 2.92 Lt. Deposits. • 242 7722 0 0.05 20 3 2.92 Line of Pits. Lt.Deposits. ■ 243 7754 0 0.05 20 4 2.92 Line Corrosion. Lt.Deposits. ■ 244 7785 0 0.05 18 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 245 7816 0 0.06 24 6 2.92 Line Corrosion. Lt.Deposits. a 246 7848 0 0.04 16 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 247 7879 0 0.05 19 5 2.92 Shallow Line Corrosion.Lt. Deposits. a 248 791 1 0 0.05 19 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 249 7942 0 0.05 20 3 2.91 Line Corrosion. Lt.Deposits. 250 7973 0 0.02 9 3 2.91 Lt. Deposits. 251 8005 0 0.04 15 4 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 252 8036 0 0.05 21 4 2.91 Line Corrosion. Lt.Deposits. • 253 8067 0 0.04 15 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 254 8099 0 0.05 18 3 2.92 Shallow Line of Pits.Lt. Deposits. ■ 254.1 8130 0 0.03 11 2 2.92 Pup Lt. Deposits. 254.2 8136 0 0 0 0 2.89 GLM 5(LATCH C4)8:00) 254.3 8144 0,04 0.04 15 4 2.93 Pup Shallow Line of Pits. • 255 8150 0 0.06 22 4 2.92 Line Corrosion. Lt.Deposits. ■ 256 8182 0 0.03 11 3 2.92 Lt. Deposits. • 257 8213 0 0.05 20 3 2.90 Line Corrosion. Lt.Deposits. a 258 8244 0 0.05 21 4 2.91 Line of Pits. Lt.Deposits. • 259 8276 0 0.04 15 4 2.92 Shallow Line of Pits.Lt. Deposits. ■ 260 8307 0 0.04 16 3 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 261 8339 0 0.03 13 3 2.90 Lt. Deposits. ■ 262 8370 0 0.05 21 3 2.90 Line Corrosion. Lt.Deposits. • 263 8402 0 0.04 17 4 2.90 Shallow Line of Pits.Lt. Deposits. ■ 264 8433 0 0.03 13 4 2.91 Lt. Deposits. • 265 8464 0 0.05 19 4 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 266 8495 0 0.04 15 3 2.91 Shallow Line of Pits.Lt. Deposits. ■ 267 852 7 0 0.05 19 3 2.92 Shallow Line Corrosion.Lt. Deposits. ■ 268 8558 0 0.04 14 4 2.92 Lt. Deposits. • 269 8590 0 0.04 15 3 2.91 Shallow Line Corrosion.Lt. Deposits. ■ 270 8621 0 0.04 17 4 2.91 Shallow Line of Pits.Lt. Deposits. ■ 271 8651 0 0.04 . 16 5 2.91 Shallow Pitting. Lt.Deposits. • 272 8682 0 0.06 22 4 2.92 Line Corrosion. Lt.Deposits. • 273 8714 0 0.05 21 3 2.90 Line Corrosion. Lt.Deposits. NI 274 8745 0 0.07 26 9 2.91 Line of Pits, Lt.Deposits. 1 274.1 8776 0 0.02 9 3 2.94 Pup 274.2 8782 0 0 0 0 2.89 GLM 6(LATCH @ 8:00) II 274.3 8790 0 0.04 16 . 5 2.94 _Pup Shallow Line of Pits. a 275 8796 0 0.36 100 15 2.91 Hole!Lt. Deposits. 275.1 8827 0 0 0 0 2.78 CAMCO W-1 LANDING NIPPLE 275.2 8829 0 0.03 13 1 2.91 Pup Lt. Deposits. IPenetration Body Metal Loss Body Page 6 • • 11111 PDS Report Joint Tabulation Sheet Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE ABM Tubing 2.992 in. 0.254 in. 81 ft 8,849 ft. Joint jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 275.3 8835 0 0 0 0 2.94 SEAL ASSEMBLY 275.4 8847 0 0 0 0 2.86 BAKER FB-1 PERMINENT PACKER IPenetration Body Metal Loss Body Page 7 • • PDS Report Cross Sections tit Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE ABM Analyst: C.Waldrop Cross Section for Joint 275 at depth 8,824.563 ft. Tool speed= 51 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=89% Tool deviation=42° I I Finger=9 Penetration=0.358 in. Hole 0.36 in.= 100%Wall Penetration HIGH SIDE= UP • • III PDS Report Cross Sections 4_1 I`_ Well: 2T-27A Survey Date: June 23,2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE ABM Analyst: C.Waldrop Cross Section for Joint 166 at depth 5,305.763 ft. Tool speed=66 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area=96% Tool deviation=58° / \ ./( _---- 1 Finger=4 Penetration=0.072 in. Line Corrosion 0.07 in.=28%Wall Penetration HIGH SIDE=UP • • PDS Report Cross Sections Well: 2T-27A Survey Date: June 23, 2017 Field: Kuparuk Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE ABM Analyst: C.Waldrop Cross Section for Joint 275 at depth 8,824.533 ft. Tool speed=51 Nominal ID=2.992 Nominal OD=3.5 • Remaining wall area=85% Tool deviation=42° 1 Finger= 10 Penetration=0.227 in. Hole 15%Cross-Sectional Wall Loss HIGH SIDE=UP • • 70.' KUP PROD 2T-27A ConocoPhillips Well Attributes Ms x Angle&MO TO Alaska-Inc. 'W.aoo+APSI3VO nod.wln4 V44400 44 SON. '...(1 V0{16181 Act Don OM 501032021 701 K41+A81.45 015/SM 05411 P1404) 108 33 9 350 05 11 791 0 ... CownM w28 5o4n1 Da* 8556116105 Eng Or. 88616 01 510 A14Ne 0a. 2T-978,4361101722?24 Pe SSSV NIPPLE $0 121512016 :441'1404 4715:1905 M44144141 OS Navas 44461 Anna46en door foal 844 a. 85000465 Ir1lied Its 65404. _..._.__._............_.__..... . . .. . .. ;J/F Tag Roe 854400 LEAK GL CIO 4pRRECTEO woven 4'30)2017 w/N9EA0,1 a .A4Gr4G NIPP;£52 SET 0.-208 5.1P 6705 gi 610551/af<NPlaal GO On: b 7-s Toe Oral s.014th MOe! 5.l 0.4.{1001-. WM..4...0+a6. Tap Tb.4 CONOUCTOR 10 05002 410 121 0 121 n tC sb N+IO 'a' .9fO Cosby 1514006410. 00 ON 1 4551 lop Neel 144 Own peel 0,r 0o 1 411105,,. Welen p.,.Ora* TOO Tb.d - 'CONO(ICTOA,41.613+C,danr ...4..'+ 908586E 9 SJA 8 974 38 8 3 745 8 2 875 5 40 DD 080 RTC ..�Caone 0440.41$4454 00441 10 OS Top prat 844 booth 41111.44 So.NOM(1005...0461451.Orae 14.'Doom/ 8188C.48!.: Sfl 0000.0J;:7 K7N 5057On 7 0275 I.8 90045 5 614 4 2500180 _ Casing 04strpran 001.i 1 Ors Top 90.81 40.sol n 90.81 So.Nem(1001...wean 5...00.406 Top Tbeed ii ii '.464 ICA.A..1 1 43 0(0 0)911 0 0101 0 5 458 7 25 00 0-80 Casing A 4IV on OO rynl Or(,nl Tan 7'0;I s Nos 47,164 641 aye!{7074 Wel4n p..arae Toa Tn•.4 OAa 11'7'.165, _1007RA ;5/I 06 AL1! :'"LFI I00 1;1'• l!. 715745 411.50 SI. Liner Detail 00.445!0 Top45561 lop1T10.118001 Toolnu(0 :km Ce. CO.. {an 96014 •,0741 8824 0;,;011 1625 AC.l0fl.00.181 810.' 70.713151 1992 J L 10 401 1 '00.3 9132 a".•.h• 27'05^.epl7rnem 5!45.+5 1920 44644406,1eaa.rae a Twang Strings T:I:.og 4.444,-•a,., Sr-so V. nl Tao Orel 444 OtotO al.941 Je804 TV W1"o"1: 0444 Tao Conna0.00 ) . '.I'. 244123."0 aJCJ : _ . .L' ,.AJV CVA UFT:4264.7 Completion Details rnsa SID Tephla) Top 411/6041111.1D Too find 04 I d4-1 700,5Me.06 ■ 310 37 0 003 "-08.0'.:,)'4 LMC GEN N'70801•031.00.. 3 000 W0,UST.0,647n IL 4972 4971 052 NIPPLE CNCO084.ANOINQNIPPLE{Creme*torn 28561 2812 111188274 5.7453 4284 NIPPLE CASCO W-1 SELECTNE LANDING NoPLE 2812 8 535 5 5 752 2 42 88 WA.ASST RAKER 081422 LOCATOR SEAL A8668484Y 3 000 85373 57538 42 82'PACKER SAKER F13.1 PERMANENT PACKER 3250 1348 LTOT.1.104 7- 44-- 88406 57850 4291 381 8AKER SEAL SONE EXTENSION 3250 8 858 7 57802 4295 410PS CAMCO Tr LANDING 41Pet.E93 O0{65 MIMEO TO 2785 2 785'1 1.4- r,'70:1 .:"u 5''°. 1AA.::-85,EAR Ours...-1 I . GAD Puri 6152 4 Other In Hole(WIretne retrievable plugs,valves,pumps,fbttt,e00.) 1oo':r401 Too via' Ton 70.8! Ora] 51 04s Can a,,,:..ab 1154451 I. a0091 41125 4314 "M1 Me...:.;),it GEMENT POR 967E 728(.04 471 1;18.4 9000 M.-0Jf Om 111?6761 6 8 855 5 57659 4295 5,P STOP 3"St IP STOP(OAL.18"1,C*TOP OF K 351.30 323'201' 0000 8 857 0 5 708 0 42 95 '033 P,J0 61.3 PACK OPP PLUG ei 006E KNOCK O:IT 323'2017 0 000 000e.0400EVCE(79.0o.I 79710 888615 4237 ?..-9P STOCK 6AKER.nseaST000 w7RA(OR 5CSETOACK 2 1157'2305 10.110.0.8x0 4 512"0u1 508E 41606(755 El Perforation*&Slots ■ Ss. Oen 54.61.84:4637.3 - too gran ser AKS? 11'11161058 ~0.00! 0154 Oe. OMI)AN 195. Com I 9 610 0 10 494 0 58748 58804 11.2.27-27A 11242000 320 SLOTS Aka PEA(5104 am.8443 ! W0u.008£Alteml,ng 80107808414 pipe- i 0125".28'®,, c1RLmIswnlal 5450851 row►,3"Denied : summed 18 deg,3'nm • .84ends 010001r000.41.016810 : alk .0 10 497 0 1 1 789 0 5 030 3 5 074 4 A2 2727A 11242009 32 0 SLOTS 'ALL PEROS 84 >,x 0.Eu80RE.A14ematng r6Rt.8,5,ese 7 4011410406.0 Pies- K:d 00-00.16er C 0 125'x5' 4 CNOarIlMdfllal aslaosnl I rade.3"omen ace_aper 6 staggered to Mel 3'nen TI -006.0 ends 0105 Mt1OUT.64000 Ma ndrol Insorte Sr S. 40 Tao(TAN 01(44 14.11 Pensee TA0 Ren N sop 44004 84481 M!0, each OD OnI 860.0. 15l T}p4 X115 f0 Run a. Can 1' 19811 18800 CAMW 14-2U 1102 645.715 (LV/ 010., 0188 1080 22042317 2 42647 3 189 1 CAMOO 820 1172 GAS LFT OLV 80 0188 12580 2202717 VAaPlTOCK;0.871.:. 1 568:5 39594 CAMCO 4400,20 112 OAS,...IST OV 140 0250 00 2242017 W:NC444 A.1:6671.04,N6• "` 4 71047 4 755 1 CAM00 '.,..014i411;'2 OAS,-,1,7 !T re RK 0000 00 22442317 _ 0800u1110.0 00e78,r.34.a 5 A 132 8 5 297 8 CAMCO 00 4M 1 172 CAS:01 100,05' 120 0 000 00 52572313 0.604 6 0 ,1:01,1 5 713 0 CAMCO Moa 117.u..,..,'I ::M,' . 0000 00 :)27,:31:' Notes:General$Seely find a. An+K4avr1 11/302039 40'71 AEU.SIOETRACKEOTOA AL1 1110,2069 'NOTE VIEW SCnt3AiATIC%ersion Schemata°0 ceroo.o15415 NO 4'3412017 NOT6 TVee4O LEAKP01JN0 AT Nie AT 8527 PACKR A'Pp-AM 5 To 111-.'A•.'230'0.05/ TEMPERATVJ86*CREASE Ent 51056,4:6160.16,464 454� 6078;i6,.Ta11,Tq.6 UNERA (Wr11A1II: IL 6,67.0.01,0408 4P CASING /TUBING/ LINER DETAIL 3-1/2"Single Completion WELL: 2T-27 KRU ARCO Alaska, Inc. DATE: 8/28/95 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES #ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Tubing Head/Hanger Lockdown Screws - Parker #245 36.95 FMC Gen IV, 3-1/2" Tbg Hanger w/ dbl pin pup, 3-1/2" EUE land ihd 3.13 36.95 14 jts 3-1/2", 9.3#, L-80, ABM-EUE Tubing, w/ 2', 6', 10' pups 457.07 40.08 Nipple CAMCO 3-1/2" DS Landing Nipple, 4.50" OD, 2.856" No Go, 2.812" ID 1,22 497.15 47 jts 3-1/2", 9.3#, L-80, ABM-EUE Tubing 1476.47 498.37 Pup Joint, 3-1/2" Tubing 6.23 1974.84 GLM#6 CAMCO 3-1/2' X 1-1/2' MMM, DV, TG Latch, 6.018"OD, 2.920"ID 8.49 1981 .07 Pup Joint, 3-1/2" Tubing 5.65 1989.56 72 jts 3-1/2", 9.3#, L-80, ABM-EUE Tubing 2263.36 1995.21 Pup Joint, 3-1/2" Tubing 6.17 4258.57 GLM#5 CAMCO 3-1/2" X 1-1/2" MMM, DV, TG Latch, 6.018'OD, 2.9201D 8.48 4264.74 Pup Joint, 3-1/2" Tubing 5.61 4273.22 44 its 3-1/2", 9.3#, L-80, ABM-EUE Tubing 1382.85 4278.83 Pup Joint, 3-1/2" Tubing 6.10 5661.68 GLM #4 CAMCO 3-1/2' X 1-1/2' MMM, DV, TG Latch, 6.018"OD, 2.92010 8.49 5667.78 Pup Joint, 3-1/2" Tubing I 5.65 5676.27 45 jts 3-1/2", 9.3#, L-80, ABM-EUE Tubing 1416.59 5681.92 Pup Joint, 3-1/2" Tubing 6.21 7098.51 GLM#3 CAMCO 3-1/2" X 1-1/2' MMM, DV, TG Latch, 6.018'OD, 2i9201D 8.48 7104.72 Pup Joint, 3-1/2" Tubing 5.57 7113.20 32 Its 3-1/2", 9.3#, L-80, ABM-EUE Tubing 1008.01 7118.77 Pup Joint, 3-1/2" Tubing 6.07 8126.78 GLM#2 CAMCO 3-1/2' X 1-1/2' MMM, DV, TG Latch, 6.018'OD, 2.9201D 8.48 8132.85_ Pup Joint, 3-1/2" Tubing 5.56 8141.33 20 jts 3-1/2", 9.3#, L-80, ABM-EUE Tubing 628.85 8146.89 Pup Joint, 3-1/2" Tubing 6.06 8775.74 GLM #1 CAMCO 3-1/2' X 1-1/2' MMM, DV, TG Latch, 6.018'OD, 2.92010 8.44 8781.80 Pup Joint, 3-1/2" Tubing 5.57 8790.24 1 JT 3-1/2", 9.3#, L-80, ABM-EUE Tubing 31.62 8795.81 Nipple CAMCO 3-1/2" W-1 Selective Landing Nipple, 4.50" OD, 2.812" ID 1.95 8827.43 Pup Joint, 3-1/2" Tubing 6.11 8829.38 BAKER GBH-22 Locator Seal Assy, 4.750" OD, 3" ID 0.78 8835.49 Space out 1.00 8836.27 Packer BAKER FB-1 Permanent Packer, 5.687" OD, 3.25" ID 3.34 8837.27 Baker Seal Bore Extension 9.34 8840.61 "B" Guide 0.59 8849.95 Pup Joint, 3-1/2" Tubing _ 8.12 8850.54 Nipple CAMCO 3-1/2" D Landing Nipple, 4.50" OD, 2.795" No Go, 2.750" ID 1 .00 8858.66 Pup Joint, 3-1/2" Tubing 8.11 8859.66 BAKER 3-1/2" Shear Out Sub 0.97 8867.77 Bottom of Tubing Tail =_» _ 8868.74 Remarks: String Weights with Blocks: 48K Up, 24K Down, 6K Blocks. Ran 275 joints of tubing. Drifted tubing, GLMs, & hanger with 2.867" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Tubing is non-coated. Nordic Rig #1 Drilling Supervisor: M. D. Dunn �� • 0 ° r a.� o ; E v, NI J a arW o co U` .-0 CID 4-' C9 > c6 h� C7 ON Z (6 w 'a (0 O W I _Y O v E a1 J P iL7 O • U ++ H Y • a n a c c c O w , O � a ra a Q 0 , Q F O I--' W' N- I N- n N- r n N = O a m Q 1- 0 Q Q Q Q Q Q Q ,_ S- O n s cv w o o N N N N p CO u L g ` O C L I- 0:3a) _a v, U C L L a 0 ❑ 1=1 ❑ ❑ t7 ❑ CO C Q O W W W W W W W VI (1) L .. )- I.L. LL LL LL LL LL LL (� Q J J J J J J - +' • v c I- < Q Q Q Q Q Q a) 'nw -% Z Z Z Z Z Z Z a1 L al j LL LL LL LL LL LL LL CC .-. -❑ C Z co O .Q Z. E u > rC Z C ca a) U 05 .- 2. 2 v Y U -c t' Z O1..... a 1- .� Q a) co a O a p a) tea) N E a) QLu :33 a . c)co COLtia a m J a 70.0 cc 0 J v W0 o sS ") '75 :_. U C0 ho a 0 2 G f0 J _ w o ....1- j j > j j j 8 •FIN Z tri V) • V ' > > ' > > > 1 w 1 -Or p XtrtrtrCLCYX W W W W W W W w > > > > > > > 2aixaacecea z Y Y Y Y Y Y Y > > > > > ❑ > > Scea' a' n' a' a cc Lu Q Q Q Q Q Q a , ' ii a a a 0. d LL a 111 ate.' t) a ,; Y Y Y Y Y Y Y CO em cc X (7) v� w CD n n *ch N CO co CD,--..�, ❑ n n r r r E , O O O o 0 0 0 • 0 0 0 0 O 0 o v =Zsi, 0 O O 0 0 0 0 g� - w co co O O O coO > 2 2 2 co co 2 U -0 cc cot:3000owa. v) U co E . 0 _ U $ , 0 CO 0 0 � 0 0 0 U i..., O O O O O O O Q hMt N CO CO O NO h i, : v, •JY CO Co N a- 1� V ++ a \ N) MM (O N M O _ - N • . a N N N N N N in 1� Q C) CO M O) M O) C) C 0 O• 001 N0 ONONN CO O r O O O '- OO U rC 0 NNN01Ca i+ c 0 d O 0 C u ft v. E E I" I M � 1 E Z t '� ' Z N N N N '- 0 !_' Eri, H a) L E ar m a, ROE U Y Y S v6 2 — < O Q�` N N N N N Vf Z O O LAJ QCH (� Q � 3 H L °1 0 0 a a I