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191-129
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ _WpliwatInh silk3wn ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Atter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: hi t k 1712. Operator 4. Well Class Before Work: 5. Permit to Dri I Number: Name: ConocoPhillips Alaska, Inc. Development [Z Exploratory ❑ Stratigraphic ❑ Service ❑ 191-129 3. Address: P_ 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20156-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2M-21 ADL 0025588 ADL 0025571 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,599 feel Plugs measured None feet true vertical 6,119 feel Junk measured None feet Effective Depth measured 10,599 feet Packer measured 9916',10004' feet true vertical 6,119 feet true vertical 5804', 5845' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 feet 16" 123' MD 123' TVD SURFACE 3.877 feet 9-5/8" 3,926' MD 2825' TVD PRODUCTION 1,753 feet 7" 1,795' MD 1703' TVD PRODUCTION 8,804 feet T' 10,599' MD 611 9'TVD Li LINER 3533 feet 23/8" 13764' MD 5938' TVD L1-01 LINER 3,787 feet 2-3/8" 13791' MD 5870' TVD Tubing (size, grade, measured and true vertical depth) 3.5 " L -80/J-55 10,030' MD 5,856' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER 7" X 31/2" FHL PACKER 9,916' MD 5,804' TVD PACKER - OTIS HVT RETRIEVABLE PACKER 10,004' MD 5,845' TVD SSSV - None 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas NIcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 100 50 710 1270 235 Subsequent to operation: 166 1 4655 1304 255 14. Attachments (required per 20 A C 25.070, 25.071.8 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development ❑Z Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil L�j Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data❑ GSTOR ❑ WINJ❑ WA❑ GINJ ❑ SUSP❑ SPLUG ❑� 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-459 Contact Name: Shane Germann Authorized Name: James Ohlinger Contact Email: Shane.Germann@conocophillips.com Authorized Title: Staff CTD Engineer Contact (907) 263-4597 Date: 12—AI / f Phone: Authorized Signature. ABUIVIJJtVAJlAN 0 L Z0Z0 Form 10-404 Revised 4/2017 � w� Submit Original Only I_ O n c � �f u ❑ ffa b C t0O p V �oNN O om a0 Joc v �6od b lV O N � m n m C E m o b c N � a U m 3 ❑H ❑ Fes- z gim m Oo � ❑ �i n m❑ m NS E m W J q U� ClLL K mx ❑ 3 N� x I_ O n c � �f u ❑ ffa b C t0O p V �oNN O om a0 Joc v �6od o. Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur (hr) Phase Dp Corte Activity Code Time RT -X Operation (MB)End Depth 0.0 11/7/2019 11/7/2019 4.00 MIRU MOVE MOB P Complete RDMO at 1 F 00:00 04:00 1117/2019 11/7/2019 1.00 MIRU MOVE MOB P Peak on location, Load up shop on 0.0 0.0 04:00 11/7/2019 11/7/2019 05:00trailer 2.50 MI RU MOVE MOB P PJSM w/ Peak and dg crew. Move dg 0.0 0.0 05:00 07:30 off well. Jeep up 11 f7120 99 11/7/2019 6.50 MIRU MOVE MOB P Leave 1F pad enroute to 2M pad 0.0 0.0 07:30 1117/2019 14:00 11/7/2019 2.00 MIRU MOVE MOB T Arrive at 2M pad. De Jeep modules, 0.0 0.0 Start spotting up sub. Discovered 14:00 16:00 damaged king pin on sub. Formulate plan forward 1I 712019 11/7/2019 2.00 MIRU MOVE MOB P Continue spotting modules on 2M-21 0.0 0.0 16:00 11/7/2019 18:00 11R/2019 2.00 MIRU MOVE RURD P MIRU. Safe out rig, Connect PUTZ. 0.0 0.0 Work Rig up check lists 18:00 11/7/2019 20:00 1117/2019 2.50 MIRU WHDBOP -ITU-ND P Nipple up stack, Valve crew her to 0.0 0.0 service tree. Spot check tree bolts. 20:00 22:30 Obtain stack height measurements. Service rig valves, RIG ACCEPT 21:00 11/7/2019 11/8/2019 1.50 MIRU WHDBOP BOPS P PJSM, for BOPE test, Test pressure 4000 PSI high, 250 PSI Low. Test 22:30 00:00 witness wived by Austin McLeod, AOGCC, All components passed initial inspection 11/8/2019 11/8/2019 4.50 MIRU WHDBOP TOPE P he lost/ Continue fule. l BOFE per checklist 0.0 0.0 50 PSI low 00:00 04:30 high. Test witness waived by Austin Mcleod, AOGCC. No failures. All components passed initial inspection, Drawdown test Q 22 seconds 11/8/2019 11/8/2019 1.25 MIRU WHDBOP CTOP P Rig down test joint, Skid injector to 0.0 0.0 floor. Stab injector on well. Break 04:30 05:45 circulation in coil. PT Inner reel iron and stripper 019 11/8/2019 1.00 MIRU WHDBOP CTOP P Unstpackalnes,IH, walk tank line, id end 0.0 0.0 test PDL's tigertank 05:45 06:45 06:45 liner (good test), 11/8/2019 11/8/2019 0.75 PROD, WHPST PULD P NS on location, load WFD motors into 0.0 0.0 06:45. 11/8/2019 07:30 11/8/2019 1.50 PR0D1 WHPST TU -LD P pipeshed. PJSM, PD milling assembly -BHA #1 0.0 76.9 07:30 11/8/2019 09:00 11/8/2019 1.00 PROD1 WHPST PULD P PJSM, remove bulster from rig, set up 76.9 76.9 dike under reel area, continue PD 09:00 10:00 milling assembly. 118!2019 11/812019 11/8/2019 1.90 PROD1 WHPST TRIP P RIH, with BHA#1 w11.0° alto motor, 76.9 9,930.0 2.74" DSM, and 2.73" string reamer, 11:54 pumping SW -* Note: Initial Pressures 930 psi/1,078 psi/94 11/8/2019 11/6/2019 0.30 PR0D1 WHPST DLOG P for formwelation), continue 9,930.0 9,956.0 flushing to SW 11:54 11/8/2019 12:12 11/8/2019 1.30 PR001 WHPST DISP P to Milllpumpng Rnabletolget 10,125.0 fwell t 2.6 9.956.0 12:12 13:30 bpm 0.74 bpm returns with open choke, 11/8/2019 11/8/2019 1.00 PROD1 WHPST DISP P Pump 120k LSRV 50 bbl pill down 10,125.0 10,125.0 coil, shut in choke and squeeze away, 13:30 14:30 choke shut WHP=54 psi and slowly climbing WHP=596, open choke 2.6 bpm in and 0.95 bbl returns. Page 1125 ReportPrinted: 1 21312 01 9 14:30 114:54 11/8/2019 11/8/2 14:54 15:18 111912 05:12 11/8/2019 111812 15:18 15:30 15:30 1118/2 16:15 119:24 16:15 11%812 18:06 19:24 11/8/: 22:24 05:00 23:24 23:30 11/9/2019 11/8/2019 111912 05:12 23:30 00:00 05:12 11/9/2019 11/9/2 00:00 01:18 05:42 11/9/2019 1119/1 01:18 02:06 05:00 05:06 11/9/2019 11/912 05:06 05:12 11/9/2019 11/9/2 05:12 05:42 11/912019 11/9/1 05:42 06:00 Operations Summary (with Timelog Depths) 2M-21 NABORS CDR3-AC Job: DRILLING down coil, shut in choke and squeeze away, choke shut WHP=680, open choke pumping 1.89 bpm at 4,229', 0.97 returns. shut down pump. RIH and dry tag Wedge @ 10,138'/ 2.5k DHWOB PU Wt 33 k lbs, RIH to mill Ct 4,073 psi psi @ 1.910.8 bpm in/out I ni1A=1 i, BHP 3348 psi, g EMW @the si, IA 1078 psi, OA 92 eB @ 10,137.5'. WOB teWindow Exit off of itp Sag Wagner, 1.89 ff-745, WHP=O, ,31078, OA=93 Continue Milling Window Exit off of HEW with NS rep Sag Wagner, 1.89 bpm OFB FS Diff -745, WHP=O, BHP=3,372, IA=599, OA=93 "Note: Bleed IA down from 1,078 psi to 599 psi 10,140.0, Call BOW, 1.9 BPM @ 4184PSI FS, BHP=3331, Continue to time mill for string reamer String reamer has exited. Start milling rathole. Low ROP with 2-3K DHWOB. Decide to pull for Bi -Center and 1° AKO motor due to low ROP with mill. Start reaming passes. As drilled 30L, 30R, and low side and Bi -Center bit, PUW=31K BHA#1. Lay down mills and WFD motor. Mill out @ 2.73 No -Go. Reamer out@ 2.72 Bo -Go PD BHAL#2 with 1° AKO motor and RR Hughes Bi center. Make up to coil and surface test tool. Trip in well, BHA#2, Bleed down IA from 927 PSI, All gas got down to 790 after 90 minutes ugh window nps online, 1.9 BPM @ 3725 PS BHP=3156, Return rate .9 BPM vly climbing. RIW=14K rat hole, wiper up hole, PUW=2f 7 inch x 3 Operations Summary (with Timelog Depths) 2M-21 Rlg: NABORS CDR3 AC Job: DRILLING SIDETRACK Time Log Start Depth (ftKB) End Depth (ft Start Time End Time our (hr) Phase Op Cotla Activity Code P Time P -T -X RIH Operation to log RA 9,942.0 10,155.0 11/9/2019 11/9/2019 0.15 PROD1 DRILL TRIP 06:12 06:2110,155.0 DLO G P Log the RA @ 10,141' 10,169.0 11/9/2019 11/9/2019 0.20 PROD1 DRILL 06:21 06:33 •^• Note: TOWS 10,134' TOW 10,137' BOW 10,140' RA 10,141- 1119/2019 1119/2019 1.40 PRODt DRILL TRIP P POOH 10,169.0 870.0 06:33 07:57 DRILL CTOP T Brown out on rig lost opower, 870.0 870.0 11/9/2019 11/9/2019 0.20 PROD1 powerb warm up gens, bring power back 07:57 08:09 phone CPF 2/Highline to come out and check switch gear trailer. Found E -Stop had been tripped. Bring Highline back on @ 09:38am 11/9/2019 11/9/2019 0.20 PROD1 DRILL TRIP P Continue POOH 870.0 62.6 08:09 08:21 DRILL PULD P At surface, PUD build assembly BHA 62.6 D.0 11/9/2019 11/9/2019 0.75 PROD1 08:21 09:06 PULD P PD, second buid assembly BHA #3 0.0 72.2 11/9/2019 11/9/2019 120 PROD1 DRILL 09:06 10:18 TRIP P Function IRIH 722 9,915.0 11/9/2019 1119/2019 1.90 PROD1 DRILL up, reset counters, seeing collars 10:18 12:12 on trip in hole. stop and close EDC, bring pump online min rate continue IH DRILL DLOG P ation for depth control 9,915 .0 9,932.0 11/912019 11/9/2019 0.20 PROD1 (og15; 12:12 12:249,932.0 DRILL TRIP P Cpntinue IH 10,205.0 11/9/2019 11/9/2019 0.20 PROD1 12:24 12:36 DRILL DRLG P OBD,Diff-1. 9 bpmt 4,233 psi, OB492, 10,205.0 10,305.0 11/9/2019 11/9/2019 1.15 PROD1 WH 12:36 13:45 IN -782, OA=95, on closed choke. DRILL WPRT P Wiper up hole to 10,205', PUW 29 k 10,305.0 10,205.0 1119/2019 11/9/2019 0.20 PROD1 13:45 13:57 WPRT P Wiper back in hole, RIW 9.2 k 10,205.0 10,305.0 11/9/2019 11/9/2019 0.20 PROD1 DRILL 13:57 14:09FS DRILL DRLG P 4,996 Psi, FS 13013D, 1.87 m t3 10,305.0 10,362.0 11/9/2019 11/9/2019 2.10 PROD1 Diff =584 p i, WHP0, BH 603, 14:09 16:15 IA=776, OA=96, (66% losses) DRILL WPRT P BHA Wiper up hole, PUW 33 k 10,362.0 10,362.0 11!9!2019 11/9/2019 0.20 PROD1 16:15 16:27 DRLG P BOBD, 1.87 bpm at 4,678 psi, FS 10,362.0 10,391. 11/9/2019 11/9/2019 0.70 PROD1 DRILL Diff=545 psi, WHP=271, BHP=3,563, 16:27 17:09 IA=785, OA --96 DRILL TRIP Pi- 10,391.0 10,098.0 11/9/2019 11/9/2019 0.30 PROD1 motor.. ep out to d al down motoKO 17:09 17:27 CIRC P Pump 100 BBI high pill 302.6 10'098.0 10,098. 11/9/2019 11/9/2019 2.80 PROD1 DRILL LSRVSqueeze away SGot 1 17:27 20:15 EMW at window DRILL TRIP P 110098, Trip out choke closed, maitain 10,098.0 96.0 11/9/2019 11/9/2019 .80 ROD1 1 P 20:15 22:03 DRILL PULD P nd space out. 96.0 0 11/9/2019 11/9/2019 0.95 PROD1 pJSM PLO BHA #3 22:03 23:00 DRILL ULD P 2.5' to il Osurface oMake 0.0 72. 11/9/2019 11/9/2019 0.80 PROD1 up to cotors BHA#4,wap and 23:00 23:48 test. 11/9/2019 11/10/2019 0.20 PROD1 DRILL TRIP P Trip in well BHA #4 72.1 450.0 23:48 00:00 Page 3125 Report Printed: 12/312019 Operations Summary (with Timelog Depths) 2M-21 Job: DRILLING SIDETRACK Rig: NABORS CDR3-AC Time Log - Stan Depth Start Time End Time our (hr) Phasa Op Code Atllvity Coda Tim P -T-% Operation. tinue iwell, SlowPP g d (110) End Dep N (ft 450.0 6,500.0 11110/2019 11/10/2019 1.10 FROM DRILL TRIP P t o FPMn High bend mppingfinding 00:00 01:06 joints 11/10/2019 1.40 FROM DRILL TRIP P BypasMM to dear. Full of indoclea 6,500.0 9,915.0 11110/2019 debdes Had to knock off. 01:06 02:30 DRILL DLO G P Log K1 for +16- correction, PUW=32 9,915.0 9,930.0 11/10/2019 11110/2019 0.10 PRODS 02:30 02:36 TRIP P ue in hole, Clean passthrough 9930.0 10,390.0 11/10/2019 11/10/2019 0.80 PROD1 DRILL w�01 indow. Set down @ 10,330.. U th 02:36 03:24 negative WOB, PUW=41 K. Pull up to 10250. RBIH and work pipe dowm. Setdown Q 10,335, 10,340, 10,345' then goto bottom at 10,390 11/1012019 0.20 PROD1 DRILL WPRT P At TD. K. an 10,390.0 10,391.0 11/1012019 Cleer PUW=31 toback bottom 03:24 03:36 DRLG P 10,SI 0,391.0 10,487.0 11/10/2019 11/10/2019 2.90 PROD1 DRILL F53BHPD34251 6PBPM returns. 03:36 06:30 RIW=12.06K, Diff -522 PSI PROD1 DRILL WPRT T Highline power failure, whileeon 10,487.0 10,487.0 11/10/2019 11/10/2019 0.10 bottom, bring gen's on line, switch to 06:30 06:36 gen power DRILL DR LG P PUH 80', PUW 38 k, RBIH, OBD 1.9 10,487.0 10,509.0 11/10/2019 11110/2019 0.10 PRO bpm at 4,737 psi, FS Diff=506, 06:36 06:42 WHP=219, BHP=3,555 DRILL WPRT P Wiper up hole to 10,205', PUW 38 k 10,509.0 1),205.0 11/10/2019 11/10/2019 0.30 PROD1 06:42 07:00 DRILL WPRT P Wiper back in hole, RIW 7 k 10,205.0 10,509.0 11/10/2019 11/10/2019 0.30 PROD1 07:00 07:18 DRLG P 10,509.0 10,577.0 11/10/2019 11/10/2019 4.40 PROD1 DRILL DI00g5D1� psii,Fm WHP5145?BHPF3,641, 07:18 11:42 IA=797, OA47, -- Note: 76% returns, 1.9 bpm in/1.44 bpm out DRILL WPRT P to the window, PON 38 k, jog the 10,577.0 10,100.0 11/10/2019 11/10/2019 0.70 PROD, 7lnl ch 11:42 12:2410,100.0 11/1012019 11/10/2019 1.60 PROD1 DRILL TRIP P POOH 72.2 12:24 14:00 1.75 PROD1 DRILL PULD T PUD, build assembly, unstabbed 72.2 72.2 11/10/2019 11/10/2019 INJH, tools became stuck in tree, 14:00 15:45 attempt to free up BHA, line up and pump, function closed swab valve, function closed annular, function closed deployment rams, MU test cable to tools oreient TF 90° with no TRIP T success builds pail semblpace 722 172.0 11/10/2019 11/10/2019 0.75 PROD, DRILL back out ofPD, hoe, o00 15:45 16:30 DRILL PULD P build assembly. No further 172.0 0.0 11/10/2019 11/10/2019 1.50 PROD1 issues 16:30 18:00 5ROD1 DRILL PULD P r ihM/U to BJSIV, PD BHand 0 78.2 11/10/2019 11!10!2019 1.20 0.UD HYC B8 bAcenter oil and 18:00 19:12 surface test - Good. Strip on injector. Tag up 1.80 PROD1 DRILL TRIP P Trip in well. Shallow test agietorQ 78.2 9,925.0 11/10/2019 11/10/2019 Continue in 19:12 21:00500'. DLOG P 9925'. Tie into for . Inspect 9,925.0 9,959.0 11!1012019 11/10/2019 0.10 PRODI DRILL counter on injector. Looksoks ggood, 21:00 21:06 PUW=32K DRILL TRIP P Continue in well.ass ugh 9,959.0 10,575.0 11/10!2019 11110/2019 0.30 PROD, window and downto build TD (03 21:06 21:24 10,575' Page 4126 ReportPrinted: 121312019 Operations Summary (with Timelog Depths) ARM I. 2M-21 Job: DRILLING SIDETRACK Rig: NABORS CDR3-AC Time Log start Depth 5012019 End Time Dur(Phase Code Activity Code Tnne P-T-X 10575', Operatlon Drill, 1.77 BPM @ 5264 PSI (RKB) End 10,575.0 Depth (ftKB) 10,680.0 11/10/2019 11/10/2019 1.6.6 0 PROD1 DRILL L DRLG P FS, BHP=3550, RIW=9.7K 21:24 23:00 WPRT P 10680 10,680.0 10,679.0 11/1012019 11/10/2019 0.50 PRODI DRILL pUW 36K. Clean hip up and down 23:00 23:30 DRLG P 10,679.0 10 BPM PSI 10,702.0 11/10/2019 11/11/2019 0.50 PROD1 DRILL BHP=35417 2.1K@5353 23:30 00:00 Rate 1.43 BPM DRILL DRLG P (95353PSIFS, 107 2', Drns 10,702.0 10,780.0 11/1112019 11/11/2019 1.30 PROM @ 1A2 BI 00:00 01:18 DRILL WPRT P 10,7 10,780.0 10,162.0 11/11/2019 11/11/2019 0.80 PROD1 sweeps, P'UWper=39KnJdet ct casing up 01:18 02:06 to 10160'. DRILL DLOG P Log RA marker for=4' correction 10,162.0 10,180.0 11/11/2019 11/11/2019 0.10 PROD1 02:06 02:12 WPRT P Continue wiper back to bottom to drill 10,180.0 10,783.0 11/1112019 11/11/2019 0.20 PROD1 DRILL 02:12 02:24 DRLG P 2M.SI 10,783.0 10,880.0 11/11/2019 11/11/2019 0.70 PROW DRILL FS?BHP=3442. Returns B 02:24 03:06 ROP has increased. 115 to 160 DRILL WPRT P 10880'wiper to 10180'. PUW=35K 10,880.0 10,879.0 11/11/2019 11/11/2019 0.60 PROD1 03:06 03:42 DRLG P 10879 SIFS, 10'879'0 11,000.0 11/11/2019 11/11/2019 0.90 PROD1 DRILL BHP=5368, RePms@@ 1635 03:42 04:36 11.1 PPG EMW DRILL WPRT P to window with sweeps 11,000.0 10,162.0 11/11/2019 11/11/2019 1.00 PROD1 re000in,PUWer 04:36 05:36 DLOG P + Log RA marker( 3.0') 10,162.0 10,176.0 11/11/2019 11/11/2019 0.20 PROD1 05:36 05:48 -0 WPRT P Wiper back in hole, RIW 7 k 10,176.(1 10,338.0 11/11/2019 11/11/2019 30 PROD1 05:48 06:06 DRILL WPRT T Set d'atH10 338' mntopl tc ownonsuccess, 10,338.0 10,033.0 11/11/2019 11/11/2019 0.20 PRGD1 x6 wth nPUsing 06:06 06:18 DRILL WPRT T Jog to clean 7inch with mulitple ---10-,033.0 10,115.0 119 2,00 PR0D1 11/11/2019 /11/2(), sweeps, 06:18 08:18 WPRT T Close choke,al set down l@ra 10,115.0 10,338.0 11/11/2019 11/11/2019 0.75 PROD1 DRILL work of pass , c continue 08:18 09:03 IH with muliple set downs, 10,163', 10,176', 10,212', 10.224%10,274', and 10,338', unable to pass through tight area, confer with town team, DRILL TRIP T POCH for on iMP 72.2 11/11/2019 11/11/2019 2.00 PROD1 scheduleun choke maintaining . 09:03 11:0372.2 PROD1 DRILL PULD T PUD, lateral ddlling BHA#5, 0.0 11/11/2019 11/11/2019 1.00 11:03 12:03 *** Note: Bit Grade 1-5 PROD1 DRILL PULD T PD, cleanout assembly BHA#6 0.0 82.4 11/11/2019 11/11/2019 1.40 12:03 13:27 DRILL TRIP T R sembly BHA #6 62.4 9,915. 11/11/2019 11/11/2019 2.00 PROD1 D331 w/o Res. 13:27 15:27 0.30 PROD1 DRILL DLOG T Log the K1 (+47,5' BHI) (nabors 9,915.0 9,957.6 11/11/2019 11!1112019 counter +35) 15:27 15:45 PROD1 DRILL CTOP T Repair orswap out lNJH counter 9,957.6 9,957.6 11/11/2019 11/11/2019 0.65 15:45 16:24 TRIP T Continue IH through window (clean) 9,957.6 10,333. 11!11/2019 11/11/2019 0.20 PROD1 DRILL 16:24 16:36 TRIP T Set down @ 110,333', PUH, obtain 10,333.0 10,333. 11/11/2019 11/11/2019 0.20 PROD1 DRILL pump parameters, 16:36 16:48 WASH T 10,333.0 10,366.0 11/11/2019 11/11/2019 1.00 PROD1 DRILL 4,969 psi, FS D91f=480,tWHP=1056at 16:48 17:48 BHP=3,693, IA=781, OA=97 Page 5125 Report Printed: 121312019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time log End Time Dur (hr) 0.10 PROD1 Phase DRILL Op Cotle BKRM Activity Code Time T P -T -X Back withup Operation holE 6 verpull Q Start Depth (ftKB) End Dept], WS) 10,366.0 10,319.0 Stan Time 11/11/2019 11/11/2019 17:48 17:54 0.20 PROD1 DRILL WASH T ash back down hole.n to Stack. 1 Of 10,319.0 10,242.0 11/1112019 11/11/2019 17:54 18:06 three gens goes down due to overheat. PUH slowly getting another 11/11/2019 0.80 PROD1 DRILL WASH IT gen online W sh do t speeds and Twn. Stack out QF'su No lulck. 10,242.0 10,040.0 11/11/2019 18:06 18:54 PUH through window to see ifwe might be dragging something. Pass 11/11/2019 19:12 11111/2019 0.30 2.40 PROD PROD DRILL DRILL TRIP MILL T T through clean. Stalk Cleanpass mrough window. ds I F's no good. g Ir ng olt pie spee 169 10,040.0 10,317.0 10,317.0 10,320.0 11/11/2019 18:54 11/11/2019 19:12 21:36 PSI FS, BHP=3611, Choke still closed. 3K DHWOB with 400 PSI motor work. Consult with town 11/11/2019 1.20 PROD1 DRILL TRIP T Trip out to set whipstock in backup window location. PUH slowly waiting 10,320.0 10,069.0 11/11/2019 21:36 22:48 on Hi vis pill to slow Ould losses 11/1212019 1.20 PROD1 DRILL CIRC T qua Hi see 12.6 Pushing nhg pil�46l LSRVReduIntrate well. to 10,069.0 10,069.0 11/11/2019 22:48 00:00 not exceed 12.8 11/12/2019 0.30 PROD1 DRILL CIRC T e squeezing 148K LSRV into wellbore 10,069.0 10,069.0 11/12/2019 00:00 00:18 11/12/2019 02:06whipstock 11/12/2019 1.80 1.30 PROD1 PROD? DRILL DRILL TRIP FU -LD T T Pill in place, POOH for NS HEW At surface, PJSM, PUD BHA# 6 FCO 10,069.0 57.0 57.0 0.0 11/12/2019 00:18 11/1212019 02:06 03:24 11/12/2019 1.00 PRODt DRILL WPST T S/U NS HEW whipstock. r. track and PD. Skid cto upto co injector. 0.0 73.5 11/12/2019 03:24 04:24 M/U to coil and surface test 11/12/2019 1.85 PROD1 DRILL WPST T RIH with BHA#7 73.5 9,940.0 11/12/2019 04:24 11/12/2019 06:15 06:15 11/12/2019 06:27 11!1212019 0.20 0.50 PROD1 PR0D1 DRILL DRILL WPST WPST T T dLog epth formation (+5.0') , RIH to setting Bring mud pump up to shear 3,663 psi/1,985 psi Dlff, no DHWOB noted, 9,940.0 10,105. 10,105.0 10,130.0 11/12/2019 06:27 06:57 continue IH pushing Wedge to 10,130' 11/12!2019 08:51 11112/2019 1.90 1.00 PROD1 PROD1 DRILL DRILL WPST WPST T T POOH, clean to surface, pumping min rate with open EDC At surface. PUD setting tools 10,130.0 75.0 75.0 0. 11/12/2019 06:57 11/12/2019 08:51 09:51-Coffrak 11/12/2019 1.25 PROD1 DRILL CTOP T tools. plaanit ry oiD and l, inspect reel and INJJH, 0.0 0. 11/12/2019 09:51 11:06 change pac-offs, continue to standby 11112/2019 11/12/2019 1.00 PROD1 URILL T for orders. Change of out Tools in PDLawith pno DGS orpHOT, 00 0.0 11:05 12:06 Phone out BOT w/under-reamer and 11/12/2019 11/12/2019 2.50 PROD? DRILL . CTOP T straight mud motor. Continueed Rig anoint nce,PJSBulsterloc-O arr12:06 00 0.0 14:36 equipment and attempt to install 11/12/2019 1.00 PROD1 DRILL UREM T repaired bulster, with no success. PU/PD, under -reamer assembly 0.0 65.7 11/12/2019 14:36 15:36 11/12/2019 1.50 PROD1 DRILL UREM T w/DB under -reamer max expansion 6.12" on a BOT straight 55 7 9 925 11/12/2019 15:36 17:06 motor. Page 6125 Report Printed: 12/3/2019 Operations Summary (with Timelog Depths) AIM 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth sten Time End Tuna our (hr) Phase op Code Activity Code Time T P-T-X Log Operation formation for depth control (+5.0'), (g 25.0 End Depth 6 0 11/12/2019 11112/2019 0.20 PRODt DRILL UREM PUW 30 k 17:06 17:18 11/12/2019 11/1212019 0.40 1R0D1 DRILL UREM T Continue IH 9,956.0 10,096.0 17:18 17:42 0.40 PROD1 DRILL UREM T Bring pump online 1.8 =ppm at 51141 10,096.0 10,113.0 11/12/2019 11/1212019 psi, FS Diff735, 17.42 18:06 134, 60, OA=138, BHP=3,735, IN-760, OA=91, work down hole Q 1 fpm 11!1212019 11112/2019 0.30 PROD1 DRILL UREM T Under-ream up hole Qo 1 fpm 10,113.0 10,103.0 18:06 18:24 0.30 PROD1 DRILL UREM T Parkdown 624bbl l.4bpmcirculate 10,103.0 10,103.0 11/12/2019 11/12/2019 the bake side 18:24 18:42 DRILL UREM T Untler-ream down at 1 fpm to 10,113' 10,103.0 10,113.0 11/12/2019 11/12/2019 0.30 PRODt 18:42 11/12/2019 19:00 11/12/2019 0.50 PROD1 DRILL UREM T Under-ream up at 1 fpm 10,113.0 10,103.0 19:00 19:30 0.70 PROD1 DRILL UREM T 60 bbi 10,103.0 10,100.0 11!12/2019 11/12/2019 2461pdown a bacokesidetAbpmate 19:30 20:12 1.80 PR0D1 DRILL UREM T Line up down the back side. POOH 10,100.0 65.7 11/12/2019 11/12/2019 pumping 0.7 bpm 20:12 11/12/2019 22:00 11/12/2019 1.30 PROD1 DRILL PULD T At surface, spaceout, PUD Under- 65.7 D.0 Lay down 22:00 23:18 anassembly, underreamer/cleanout under reamer and straight BOT motor. 11/12/2019 11/13/2019 0.70 PRODt DRILL WPST T M/U NS HEW whipstock. PD BHA#9 0.0 0.0 Whipstock 23:18 00:00 0.50 PROD1 DRILL WPST T Continue U Hand ysthip 73.5 73.5 11/13/2019 11/13/2019 surface 00:00 00:30 DRILL WPST T RIH BHA#9 Whipstock, EDC Open 73.5 9,933.0 11/13/2019 11/13/2019 2.00 PROD1 00:30 11/13/2019 02:30 11/13/2019 0.10 PR0D1 DRILL WPST T Log K1 for +4.5 9,933.0 9,960.0 02:30 02:36 DRILL WPST T TOWSose to set dntd 9960.0 10,111.8 11/13/2019 11/13/2019 0.20 PROD1 OH to0HS.78, 02:36 02:46 Pressure up setting tool. See tool shift Q 3800 PSI with 3.8K DHWOB. Set down to 5.8K. 11/13/2019 11/13/2019 1.80 PROD1 DRILL WPST T EDC, POOH BHA#9 setting 10,111.8 76.0 02:48 04:36 0.90 PR0D1 DRILL WPST T tools At surface, Tag up and space out. 76.0 0.0 11/13/2019 11/1312019 PJSM PUD BHA#9 whip stock setting 04:36 05:30 tools 11/13/2019 11/13/2019 0.90 PROD, DRILL WPST T M!U&PDB7W'Win owmilldow milling 2. BHA withWindowmill 2.73" 0.0 76.0 05:30 06:24 it a string reamer. make up to coil and mer. surface test. Tag up and set counters 11M3/2019 11/13/2019 1.70 PROD1 DRILL WPST T Trip in hole, EDC open 76.0 9,930.0 06:24 08:06 WPST T Log K1 for+4', PUW=31 K, Close EDC 9,930.0 9,967.0 11/13/2019 11/13/2019 0.20 PROD1 DRILL 08:05 08:18 0.10 PRO01 DRILL WPST T Continue in well, Dry tag whip stock 9,967.0 10,107.6 11/13/2019 11/13/2019 pinch point @ 10,107.6 08:18 08:24 DRILL WPST T PUH, Bring pumps online, 1.85 BPM 10,107.6 10,110.6 11/13/2019 11/13/2019 4.60 PROD1 PSI BHPpoint Returns 0824 13.00 1.65 BPM. Tag pinch point @,0107.2. 1.65 B g Mill window per procedure / NS window rep. 11/13/2019 11/13/2019 0.50 PROD1 DRILL WPST T f aII.X C: W. Time mill for stung reamer 10,110.6 10,111.6 13:00 13:30 DRILL WPST T it Milling rathole, Speed up 10,111.6 10,126.0 11/13/2019 11/13/2019 1.00 PROD1 13:30 14:30 Page 7125 Report Printed: 12/312019 114:30 18:06 11/131 18:48 16:06 11/13/ 18:06 111131 18:48 11/13. 19:30 19:30 120:12 11/13/2019 11/130 20:12 11/13/201922:48 t2:11/13/201921:30 11/13/20193.30 00:00 02:24 11%141 02:30 05:00 11%14, 05:12 00:24 11%141 02:24 10:06 Operations Summary (with Timelog Depths) 2M-21 NABORS CDR3-AC Job: DRILLING 30L, 180°, Dry drift. Pump 5 X 5 mill & string reamer came out 2.73" no .go PD BHA#11 Build Assembly (2.5° AKO motor, RB Dynamus bit) BHA became jammed in stack attempting to space -out (tagged no- go), pump across the top, work slick - line, no good, open Romeo 1, pump, work slick -line, no good, open Romeo 3, pump, continue to work slick -line, snap slick -line (never pulling past design limits) Decision made to kill well, obtain SBHP, begin arranging pits Hydrostatic = 2553 psi, WHP = 215 psi (stabalized), ND window = 5742' EMW = 9.27 ppg Complete fluid transfer in pits, water I W F to 9.5 ppg (140 bbl total) ad 9.6 ppg KWF to window,= 1500 psi @ 1.3 bpmheck, well charged up, bleed cle times, well Is dead, PJSMdown PDL, pop off, MU tugger BHA, work BHA up, open, continue PU tools over deadslide in cartin cart, check pack -offs, MU toag-up, set counters swapping to drilling fluid, PUW = 32K, close EDC Drilling,FS = 519 psi @ 1.9 bpm, CW1 = 9.4K @ 0.7K WOB, annular = 3226 psi, choke fully open, pump = 4375 psi, 10.45 ppg ECD at bit Binding up @ 10,133', stacking WOB wl no motor -work, PUW = 34K, work through, again bind up at 10,141', continue drilling (BHA continues to bind -up across window occasionally) Increase LSRV of DuoVis system to —50K, begin breaking down DS PDL BHAwiper at 1O0drilled, PUW = 35V null -8K WOB, Operations Summary (with Timelog Depths) .t 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our (hr) Phase Dp Code Activity Code Time T P -T -X Operation trip to window with be in. 10,325.0 End D9hMKS) 20.0 1 019 11/142019 open EDC, PJSM 0.40 PROD? DRILL WPRT PUW=35K, Observed dragging on PROD DRILL 10:080:06 10:30 T PUD BHA #12, bit came out a 1-2 72.0 DHWOB sensor near window 01:54 02:42 11/14/2019 11/14/2019 PRO -DI 0.20 PROD? 5RLG DRILL DLOG T Log K1 for+1.5'. RIH to 10125'. Log RA in @ 10111.5', TOWS=10104, 9,920.0 10,144.0 10:30 10:42 11/15/2019 11/15/2019 BOW=10111 11/14/2019 11114/2019 0.10 PROM DRILL WPRT T RBIH to tlrill 10,144.0 10,321.0 10:42 10:48 Dynamus bit), slide in cart, check pack DRLG T 10321', Drill, 1.9 BPM @ 5200 PSI 10,321.0 10,329.0 11/14/2019 11/14/2019 0.30 PROD1 DRILL -offs, change out checks in UQC, MU FS, BHP=3571 10:48 11:06 DRILL TRIP T to dial down 10,329.0 73.0 11114/2019 11/14/2019 3.40 PROW 11!15/2019 1.80 PROD1 motor AKO, PUWe35Kip TRIP 11:06 14:30 1.00 PROD1 DRILL PULD T U, and ce out a S 2 PUD gHA# 73.0 D.0 11/14/2019 11/14/2019 Shallow test agitator: 1.8 bpm, FS = 11 b tp 'meout 14:30 15:30 PROD1 DRILL ROPE P Pertorm Bi Weekly BOPE function test D.0 0.0 11/14/2019 11/14/2019 0.50 0.10 PROD1 DRILL -All components passed initial T 15:30 16:00 9,930.0 9,986.0 11115/2019 11115!2019 inspection 11/14/2019 11/14/2019 1.10 PROD' DRILL PULD T BHA Bi tenth , -YAKOchange motor and HCC Bi center, change out motorPJSMand 0.0 72.0 16:00 17:06 DRILL TRIP T pack -offs 9'986.0 11/14/2019 11/14/2019 1.70 PR0D1 DRILL TRIP T RIH w/ BHA#12 72.0 9,925.0 17:06 11/142019 18:48 11/14/2019 0.30 PROD1 DRILL CLOG T Log K1 for +5' connection 9,925.0 10,329.0 18:48 19:0610,329.0 2.00 PROD1 DRILL DRLG T Drilling, 11/15/2019 10,430.0 11/14/2019 11/14/2019 WOB, annular = FS5BHP==3618, BPM597 19:06 21:06 06:18 07:24 3639 psi, W HP = 122 psi, 11.8 ppg @ _ ,-,_,_,_ r .n cery tnn..e. o-i�tn hninw window.1 10.610.01 window, pump = 5578 psi 11/14/2019 11/142019 0.30 PROD, DRILL WPRT T Pull 240' wiper, PUW = 37K 10,430.0 10,430.0 21:24psi 2.00 PRODt DRILL DRLG T F)t21:06 hipm,10,430.0 Cril 2K 10,512.0 11114/2019 11/1412019 WT = @ 0.5K WOB, annular = 21:24 23:24 3645 psi, WHP = 162 psi, pump= 5344 psi, reduce WOB in attempt to lower DLS, drill to called EOB at 10,512', pump sweeps 11/14/2019 11/15/2019 0.60 PRODt DRILL TRIP T Begin POOH. PUW = 35K 10,512.0 9,400.0 23:24 00:00 .... ...,...., rlO 1 1 TRIP T Complete POOH, negative DWOB 9,400.0 72.0 11!15!2019 11115/2UIU tugs from 10,500 to 10,163', tag up, 00:00 01:54 open EDC, PJSM 11/15/2019 11/15/2019 0.80 PROD DRILL PULD T PUD BHA #12, bit came out a 1-2 72.0 0.0 01:54 02:42 1.30 PRO -DI DRILL 5RLG PD BHA 013 L1 Drilling Assembly O,D 7g,0 11/15/2019 11/15/2019 (NOV agitator, 0.5° AKO motor, & RB 02:42 04:00 Dynamus bit), slide in cart, check pack -offs, change out checks in UQC, MU to coil, tag up, set counters 11/15/2019 11!15/2019 1.80 PROD1 DRILL TRIP T RIH w/ BHA #13, close EDC 78.0 9,930.0 04:00 05:48 Shallow test agitator: 1.8 bpm, FS = 5873 psi 1016, pump =6 0.10 PROD1 DRILL DLOG T specllclean 9,930.0 9,986.0 11115/2019 11115!2019 counter, 05:48 05:54 DRILL TRIP T 9'986.0 10,514.0 11/15/2019 11/15/2019 0.40 PROD1 Window and down to TD @ 10514gh 05:54 06:18 DRILL DRLG T PSI 5 B @ 51 8 10,514.0 10,610.0 11/15/2019 11/15/2019 1.10 PROD1 FS5BHP==3618, BPM597 06:18 07:24 _ ,-,_,_,_ r .n cery tnn..e. o-i�tn hninw window.1 10.610.01 10,610.0 FS, BHP=3663, Returns @ 1.6 BPM Operations Summary (with Timelog Depths) Rig: NABORS CDR -)-AU 2M-21 Job: DRILLING Time Log Operation ataa Deplh (ft4 End OepN (ftKa7 Start Time End Tme Our Cho Phase Op Code Activity Code Time P -7-X T to TT with tie into RA 10,710.0 10,125.0 11/15/2019 11/1512019 0.50 PROD1 DRILL WPRT rnarker10710. wt'h sweeps. PUW=33Kper 09:24 09:54 DLOG T Log RA marker for +2'correction 10,125.0 10,149. 11/15!2019 11/15/2019 0.10 PROD1 DRILL 09:54 10:00 WPRT T Continue wiper trip back to bottom 10,149.0 10,711.0 11/15/2019 11/1512019 0.30 PROD1 DRILL 10:00 10:18 DRLG T SI 10,711.0 10,81 . 11/15/2019 11/15/2019 1.50 PROD1 DRILL PS?BHP=3661 ?Retums�l.5 BPM 10:18 11:48 DRILL WPRT T i10.88110.1000" wiper. with sweeps, 10,810.0 10,810.0 11/15/2019 11/15/2019 0.50 PROD1 11:48 12:18 DRLG T 10,810.0 10,910.0 11/1512019 11/15/2019 1.70 PROM DRILL FS. SHP=3677, Returns @ 9 61 BPM 12:18 14:00 DRILL WPRT T 10,9107"with sweeps. 10,910.0 10,125. 11/15/2019 11/15!2019 0.60 PROD1 � 35Kerto 14:00 14:36 DRILL D T Gamma tie in for+1.5' correction 10,125.0 10,150.0 11/15/2019 11/15/2019 0.10 PROM 14:36 14:42 WPRT T Run back in hole to drill 10,150.0 10,908.0 11/15/2019 11!1512019 0.30 PROD1 DRILL 14:42 15:00 DRLG T 109 1.79 10,908.0 11,010. 11/15/2019 11/15/2019 1.10 PROD1 DRILL tums@1 7 BPMSI FS, BHP=3l, 15:00 16:06 WPRT P 11010' Wiper trip to window, PUW 38K 11,010.0 11,010.0 11/15/2019 11/15/2019 0.60 PROD1 DRILL 16:06 16:42 DRLG P T= 2.5K WOB, 11,010.0 1 , 11/1512019 11/15/2019 1.20 PROD1 DRILL e3.1K annularC34841 16:42 17:54 = 6017 psi, 1.8 bpm in, 1.67 bpm out WPRT P W Wiper to tubing tail, PU=38K, jog 11,110.0 10,1 15.0 11/15/2019 1116 11!1512019 0,70 PROD1 DRILL 7", stack at 10,104', PU, clean through 17:54 18:36 window PR Di URILL P Log RA tag for+7'correction 10,115.0 10,140.0 11 /1512019 11/15/2019 0.20 18:36 18:46 WPRT P Continue RIH, RIW = 10.9K 10,140.0 .110.0 11/15/2019 11/15/2019 0.40 PROD, DRILL 18:48 19:12 DRLG P 11,210.0 11/15/2019 11/15/2019 1.40 PROD? DRILL CWTDrillin= 8K @ 2K WOB, annular 11,110.0 7 19:12 20:36 3471 psi, pump = 5894 psi, 1.6 bpm out WPRT P to EOB, PUW = 38K, RIW = 11,210.0 11,210.0 11/15/2019 11/15/2019 0.60 PROM DRILL 3i 4K 20:36 21:12 DRILL DRLG P 11,210.0 11,310.0 11/15/2019 11/15/2019 1.60 PROD1 CWT9 10.6K1@05K@WOB, annular= 21:12 22:48 3514 psl, pump = 5832 psi, 1.63 bpm out, pump sweeps WPRT P per to tubing tail, PUW = 34K, jog 11,310.0 10,125.0 11!15/2019 11/15 11/15!2019 11/1 1,00 PROD, DRILL 7", stack weight at 10,111' (3X), 22:48attempt at 15 fpm & 101-, get right through, pump 5x5 sweeps PROD1 DRILL DLOG P Log RA tag for +3' correction 10,125.0 10,146.0 11(1512019 11/15/2019 0.10 23:48 23:541,046.0 DRILL WPRT P Continue RIH 10,335.0 11/1512019 11/1612019 o.10 PROD1 23:54 00:00 WPRT P exit bit, 10,335.0 11,310. 11/1612019 11/16/2019 1.20 PROD1 DRILL jog ba k to BOW, RBIH o drill 00:00 01:12 DRLG P Drilling, 11,310.0 11,410.0 11/16/2019 11/16/2019 1.20 PROD1 DRILL 8.9K @ K WOB, annular= 01:12 02:24 3507 psi, pump = 5925 psi, 1.57 bpm returns, pump sweeps as required WPRT P Wiper 10,560', PUW = 38K, RIW = 11,410.0 11,410.0 11/16/2019 11/16/2019 OD 0.70 PR1 DRILL 02:24 03:06 Page 10125 Report Printed: 1213/2019 Operations Summary (with Timelog Depths) 2M-21 Job: DRILLING SIDETRACK Rig: NABORS CDR3-AC Time Log OP Code Aativlty Code Time P -T-% Operation start Depth (1tK8) End DePin (RKa) start Time End Time our (hr) Phase DRILL WP RT P W tail, PUW 12,310.0 10,125.0 11/17/2019 11/17/2019 1.00 PROD1 additional nal 5x5 7",6clean 04:00 05:00 through window up/down 0.10 PROD1 DRILL DLOG P Log RA tag for+2.5' correction 10,125.0 10,147.0 11/17/2019 11!17/2019 05:00 05:06 1.10 PRODt DRILL WPRT P Continue RIH 10,147.0 12,311.0 11/17/2019 11/1712019 05:06 06:12 DRILL DRLG P BPM @ 5452 PSI 12,311.0 12,422.0 11/17/2019 11/17/2019 2.60 PROD1 FS, BHP=3162175 06:12 08:48 11/17/2019 0.70 PROD'I DRILL WPRT P 12422, BHA wiper, 400', PUW=38K 12,422.0 12,420.0 11/17/2019 0848 09:30 11/17/2019 1.70 PROD1 DRILL DRLG P 12420', Drill, 1.79 BPM @ 5648 PSI FS, BHP=3566, 12490' started loosing 12,420.0 12,510.0 11/17/2019 09:30 11:12 returns .9 BPM. 1.00 PROD1 DRILL WPRT P 1251Y, I 00 trip, PUW=41 K. 12,510.0 12,508.0 11/17/2019 11/17!2019 Returns BPM 11:12 12:12 11/17/2019 3.30 PROD1 DRILL DRLG P 12508', Drill, 1.5 FS, BHP=56487 BPM @5648 P I 12,508.0 12,710.0 11/17/2019 12:12 15:30 11/17/2019 1.00 PROD1 DRILL WPRT P PUW=3Wiper K, jog 7ws ack n window with tie in, 12'710.0 10,125.0 11/77/2019 15:30 16:30 muttiple times, get through at 15 fpm, oriented 10 LOHS 11/17/2019 11/17/2019 0.10 PROD DRILL DLOG P Log RA tag for+4.5' correction 10,125.0 10,140.0 16:30 11/17/2019 16:36 11/17/2019 1.70 PROD1 DRILL WPRT P Cotinue RIH 10,140.0 12,710.0 16:36 18:1812,710.0 DRILL DRLG P Dri g, 12,800.0 11/17/2019 11/17/2019 1.60 PROD1 K 052KWOB,annular= 18:18 19:54 3550 psi, pump = 5531 psi, 0.8 bpm returns (47%), drill ahead in attempt to heal losses, returns to 1.16 bpm @ 12,769' 2.80 PROD1 DRILL DRLG P Drilling, 1.1 bpm out, CWT = 0.9K @ 12,800.0 12,874.0 11/17/2019 11/17!2019 1.8K WOB, annular = 3615 psi, Pump 19:54 22:42 = 5817 psi PUW = 39K from 12,819' 1.30 PROD1 DRILL DRLG P P 2K 12,874.0 12,910.0 11117/2019 11!18/2019 WOS P nnularC 3581 psi, pump 22:42 00:00 = 5253 psi, pump sweeps 11/18/2019 11/18/2019 1.40 PRODt DRILL WPRT P vairiable850' P K), diffcuty working 12,910.0 12,910.0 00:00 01:24 to bottom, work at reduced speed 11118/2019 11/18/2019 2.10 PROD1 DRILL DRLG P annular FS 35970psi,Ppump = 5365 psi, 12,910.0 12,960.0 01:24 03:30 1.1 bpm out, cuttings ratio = 1.0 Variable ROP, 10 fph - 90 fph PROD1 DRILL DRLG P P 12,960.0 12,977.0 11/18/2019 11/18/2019 1.20 51K WOB annular=s 3555 psi, pump 03:30 04:42 = 5195, avg ROP = 14 fph Low ROP, decision made to pull to check bit, pump sweeps 11/18/2019 11/18/2019 3.80 PROD1 DR ILL TRIP P Trip for bit, PUW = 36K 12,977.0 78.0 08:301812019 1.00 PROD1 DRILL PULD P 2 up, PJSM, PUD BHA#13, Bit out 780 D30 11/18/2019 [04:42 18!2019 09:30 11/18!2019 0.50 PRODt DRILL BHAH P30 00 0.0 10:00 Page 12126 ReportPrinted: 1 21312 01 9!, Operations Summary (with Timelog Depths) 2M-21 Rig: End Time NABORS our (hd 1.00 PROD1 CDR3-AC phase DRILL Job: DRILLING Op Code Adlvity Code 'fine P -T -X Operation PUL P PJSM, BHA#14..5° AKO motor, tor, and bit. HCC Dtest. SIDETRACK Stan Depth (ftKB) End 0.0 Dapth(ftK8) 78.2 Time Log Stars Time 11/1812019 11/18/2019 10:00 11:00 , Strip M/U to coil and surface test. Strip on. M/ d Change out pack offs. Tag up and set counters 1.80 PROD'I DRILL TRIP P Trip in rJ11, @ 450 feet, HA , Surfa a to well ce test 782 9,925.0 11/18/2019 11/18/2019 11:00 12:48 11/18/2019 0.10 PROD1 DRILL DIL P Log K1 for+5' correction, PUW=31K 9,925.0 9,958.0 11/18/2019 12:48 12:54 11/18/2019 1.30 PROD1 DRILL TRIP P PUH orient to 110°CONS. Go through 9958.0 12,977.0 11/18/2019 12:54 14:12 window clean. Clean trip to bottom @ 50 - 30 FPM RIW=6.4K 11/18/2019 4.10 PRODt DRILL DRLG P FS, BHP=3555?Return$ �5; PSI PM 13,087.0 11/18/2019 14:12 18:18 11/18/2019 20:30 2.20 PROM DRILL DRLG P Drilling, FS = 894 psi @ -3.3K, @ 0.7K WOB, annular= 3548 psi, pump = 5370 psi, 1.0 bpm returns, low ROP 13,087.0 13,154.0 11/18/2019 18:18 (down to 9 fph), PUW = 39K from 13,154' 11/18/2019 11/18/2019 0.80 PROD1 DRILL DRLG P annlularin = 98 psi, pump 85 00 psi, 13,154.0 13,170.0 20:30 11/18/2019 21:18 11/18/2019 1.50 PROD 1.12 bpm returns, pump 5x5 sweeps DRILL WPRT P to ba (850s, PLI ng @ reduced rage IH 13,170.0 13,170.0 21:18 11118!2019 22:48 11/19/2019 1.20 PROD1 1 s OB, annular= DRILL DRLG P Drilling,CWT e: � 3K @ K 13,170.0 13,219.0 22:48 00:00 3587 psi, pump = 5505 psi, 1.0 bpm returns Struggling with weight transfer, pump 10x10 beaded pill, drill to midnight 11119/2019 2.00 PRODt depth of 13219 DRILL DRLG P annular= 3 38 psis, pump =5 25 psi, 13,219.0 13,241.0 11/ 19/2019 00:00 02:00 1.0 bpm returns, beads exit bit to limited effect, pump additional 20 bbl beaded pill 11/19/2019 11/19/2019 0.70 PROD1 DRILL WPRT P back bottom snubbng low working op 13,241.0 13,241.0 02:00 11/19/2019 02:42 02:42FS 11/19/2019 04:18 1.60 PROD1 ze 936 GRILL DRLG P CWT=rillin' 1K@02K OB ccontnue stuggling w/ weight transfer & low 13,241.0 13,280.0 ROP, rate out drops to 0.9 bpm. builds back to 1 bpm quickly Drilling break at 13,251', pump 11/1912019 04:18 11/19/2019 11/19/2019 06:48 11/19/2019 2.50 0.10 PROD1 PROD1 sweeps, returns to 1.2 bpm DRILL WPRT P Pull wiper to tubing tail, PUW = 42K, jog 7", wiper up to 7000' DRILL DLOG P Log K1 for +6.5' correction 13,280.0 9,925.0 9,925.0 9,955.0 06:48 11119/2019 06:54in 11/19/2019 2.00 PROD1 hole DRILL WPRT P uaw 9dn55Passnwindow @tinr10° LOHS to 9,955.0 13,281. 06:54 11/19/2019 08:54 11/19/2019 08:54 11/19/2019 10:36 11/19/2019 1.70 5.311 PROD, PROD1 DRILL DRLG P FS, BHP=36738@PSI 13,281.0 Closed DRILL DRLG P 133FPH to 36r11ling FPHbRIW 6 OP from 19 13,340.0P133,,.480.010:36 13,340.0 15:54 DHWOB=I.1K, Pumping sK. weeps11/19/2019 11/19/2019 00 PROD1 DRLL WPRT P up4StackOuu ng wiplow g, u300 feetfr�dll 13,480.0 15:54 16:54 bottom Page 13126 ReportPrinted: 12/312019 Operations Summary (with Timelog Depths) 2M-21 . ..cPhil lips—' 6kI Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log at Depth StartTime Time End Time End Our (hd Phase Op Code Activity Cotle Thee P -T -x P 13480', OpersBon Drill, 1.79 BPM? @5548 PSI (rUCB) 13,480.0 Endo (fIKB) 13,623.0 11/19/2019 11/1 3.50 PROD1 DRILL DRLG FS, BHP=3709 Choke cloed 16:54 20:24 11/19/2019 11/19/2019 0.10 - PROD? DRILL WPRT P BHAwiper, PUW=46K 13,623.0 13,623.0 20:24 20:30 11/19/2019 11/19/2019 2.00 PRODt DRILL DRLG P ,Drill, 1.78 BPM ok 5750 PSI 13,623.0 13,680.0 FS, BHP=3725 PSI, Choke closed FS, B 20:30 11/19/2019 22:30 11/20/2019 1.50 PRODt DRILL WPRT P Wipertowindow, PUW =48K 13,680.0 70,422.0 22:30 00:00 Observe motor -work at various dpethPUH, begin observing sustained motor -work beginning at EOB & up 11/20/2019 11/20/2019 0.20 TRO D1 DRILL WPRT P Continue wiper up -hole, observe 10,422.0 10,100.0 significant motor -work PUH through 00:00 00:12 build (up to 1500 psi), no Indication on WOB or CWT, reduce speed to 25 fpm, motor -work falls off at 10,184% pull through window clean 11/20/2019 11120/2019 0.20 PROD1 DRILL WPRT P Jog logRA, stack RBIHto), ""rising,dow 10,100.0 10,125.0 atw orient 15 fpm, 00:12 00:24 through clean 11/20/2019 11/20/2019 0.10 PR0D1 DRILL DLOG P Log RA for+6.5' correction 10,125.0 10,148.0 00:24 11/20/2019 00:30 11/20/2019 1.80 PROD1 DRILL WPRT P Continue wiper in-hole, reduce speed 10,148.0 13,680.0 beginning at 13,252' 00:30 11/20/2019 02:18 11/20/2019 2.70 PROD1 DRILL DRLG P Drilling, FS = 807 psi @ 1.8 bpm, 13,680.0 13,722.0 CWT= -7K @ 1.1 WOB, annular= 02:18 05:00 3699 psi (12.0 ppg ECD), pump = 5422 psi, pump sweeps as required Low ROP (5-20 fph), drilling "break" at —13,694', up to 65 fph Avg ROP over interval = 15.5 fph, PUW = 47K 10/2019 1/2 11/20/2019 2.30 PROD1 DRILL DRLG P Drilling, CWT= -7K @ 0.9K WOB, 13,722.0 13,733.0 annular = 3731 psi, WHIP= 733 psi, 05:00 07:18 pump = 5881 psi, avg ROP = •-5 fph 11/20/2019 11/20/2019 2.00 PROD1 DRILL DRLG P Drilling, CWT= -3K Q O.5K WOB, 13,733.0 13,750.0 annular = 3737 psi, pump 5x10 07:18 09:18 beaded pill, continued low ROP (5-10 fph) Decsion made to call TD, pump 5x5 sweeps, decsion changed to point straight down. 11/2012019 11/20/2019 4.00 PROD1 DRILL DRLG P straight 13,750.0 13,787.0 gC4Sadnds, difficulty dropping 09:18 13:18 past 88° inclination 11/20/2019 11/20/2019 1.90 PROD1 DRILL WPRT P TD called at 13,787, PUW =48K, 13,787.0 9,925.0 pump 5x5 sweeps, await sweeps to 13:18 15:12 bit, wiper to window, clean through window 11120/2019 11/20/2019 0.10 PR0D1 DRILL DLOG P Log K1 for .5.6 correction 9,925.0 9,947.0 15:12 15:18 _ __.-_. ...,,, , ,nloo'r o 1 RiH in window. rlean un & ioa 7" 9,947.0 10,100.0 11/20/2019 15:30 15:30 79 aeu rrtvv� ��� •-• __ - - 15:18 11/20/2019 11/20/2019 0.50 PROD1 DRILL TL—OG P Obtain SBHP: MD= 10,100', 10,100.0 10,100.0 15:30 18:00 TVD sensor= 5866.4, allow annular to drop to 2881 psi (still dropping, though slowly), EMW = 9.44 ppg, confer with town, decsion made to build KWF to 9.7 ppg 16-00 17:36 I& diluting KWF Operations Summary (with Timelog Depths) 2M-21 Job: DRILLING SIDETRACK Rig: NABORS CDR3-AC Time Log Stan Capin Stan Time End Time Cur (hr) Phase Op Coda Activity Code P Time P -LX Opendlon LRP, 15 bbls total, [op (111<13) End 13,784.0 Depth MIKE) 9,925.0 11120/2019 11/20/2019 1.80 PROD1 DRILL DISP le 12550'ing 17:36 19:24 Park@1 2308.21'paint Yellow TD flag 11120/2019 11/20/2019 0.10 PROD1 DRILL DLOG P Tie int tohe K1 for a + 10' correction 9,925.0 9,954.3 19:24 19:30 DRILL DIS P P Open EDC, Line up down the back 9,954.3 9,937.0 11/20/2019 11120!2019 1.50 PRODt side, 19:30 21:00 Bullhead 33 WE LRP, Initial stabilized WH 1447 psi @ 1.4 bpm. Chase LRP with 75 WE KWF 11/20/2019 11/20/2019 0.50 PROM DRILL OWFF P Park and flow check, Bled down charged pressure in steps, S/I 9,937.0 9,937.0 21:00 21:30 pressure dropped steadily, 7.6 bbls total bled, Flow Check at the stack good. 11/20/2019 11/20!2019 1.80 PROD1 DRILL TRIP P POOH over pumping pipe displacement with KW -0.76 bpm in. 9,937.0 103.0 21.30 23.18 CT 1010 psi, WH 0, IA 773 psi, OA 95 psi out Park at 8578 and paint a white window flag Continue out of hole - lost 10 bbls on the trip 0.10 PROD DRILL OWFF P Paark check for flow, well on a 103.0 103.0 11/20/2019 11/20/2019 c. PJSMw, 23:18 23:24 Loss rate 1 bbl in 10 minutes 0.60 PROD1 DRILL PULD P Inspect pipe, found flat spot -12' back 103.0 0.0 11/20/2019 11/21/2019 wall thickness 0.126' 23:24 00:00 lay down BHA#14, L1 Iatteral drilling BHA over a dead well. 0.30 PROD1 DRILL PULD P to LD BHA#14 over adead 0.0 0.0 11/21!2019 11/21/2019 well. 00:00 00:18 Fill hole - 1 bbl If 2 total since flow check. 11/21/2019 11/21/2019 0.50 COMPZI CASING PUTB P Prep rig floor for running liner 0.0 0.0 00:18 00:48 2.00 COMPZ1 CASING PUTB P completion, 38 0.0 1,505.5 11/21/2019 11/21/2019 R3 2 3/8" slotted a non - 00:48 02:48 00:48 ported bull nose under a shorty deployment sleeve. 1504,27' liner, 1505.52' LOA. 11/21!2019 11!21/2019 0.20 COMPZI CASING PUTB P Clear floor post liner inn, 1,505.5 1,505.5 02:48 03:00 completion a11!2112019 1,505.5 1,549.7 11/21/2019 070 running assembly. inspect pack 03:00 03:42 good. 11/21/2019 11/21/2019 6.20 COMPZt CASING RUNL P Bump up, set completion, begintst eking eight at IH With lower 1 1,549.7 13,784.0 03:42 09:54 10,972', work pipe, pump down coil & back -side to aid in working liner down, begin making good progress from -11,815', difficulty working past 13,532' & 13,554' Arrive on bottom, bring up pumps, release off liner (PUW = 36K), TOL - 12,278.5' 11/21/2019 11/21/2019 3.40 COMPZ1 CASING TRIP P cOOIH,Ppumping 50 bbl LRP, flow- 13,784.0 44.0 09:54 13:1844.0 11/21/2019 11/21/2019 0.30 COMPZ1 EASING PULD P LD BHA#15 0.0 13:18 13:36 Page 15125 Report Printed: 1213/2019 13:36 116:00 11/21/2019 1111211 1600 16:18 11/21/2019 11121, 16:18 22:00 23:30 23:42 11/21/2019 11/21/ 23:42 23:54 11/21/2019 11/221 23:54 00:00 11/22/2019 11/22 00:00 01:30 11/22/2019 11/22 01:30 02:00 11/2212019 11/22 02:00 03:00 11/22/2019 11122 03:00 03:4', 11/22/2019 11/22 03:42 04:4: 11/22/2019 11/2. 04:42 05:3( Operations Summary (with Timelog Depths) 2M-21 Rip: NABORS CDR3-AC Job: DRILLING SIDETRACK Completion (non -ported bullnose, 51 jnts slotted liner, & liner -top billet) Static losses at 6 bph PU BHA#16 Running Tools, slide in cart, MU to coil, tag up, set counters RIH w/ upper completion, tie into Window flag for 4 correction. PU Wt 34 k lbs. Continue in hole First set down, 10,757' - PU Wt 38 k lbs. Start working liner @ 11,298' PU Wts to 50 k Itis 11,450' PU Wt 54 k lbs WOB -18.3 k lbs 11,662' PU Wt 56 k lbs WOB -18.3 k lbs 11,850' PU Wt 58 k lbs WOB -20.8 k lbs 12,180' PU Wt 63 k lbs WOB -20.8 k and re -attempt. POOH with upper completion. CT PUH vvt 54 k At 10,929, CT wt dropped from 33.4 k to 26.9 k lbs, WOB at -6.7 k spiked to - 11 k then fell to -1.5 k lbs. RBIH and tag slight WOB bobble@ 11,328, PU wt 29k Ibs, no liner, continue in hole, WOB slowly building to 4.7 k. Sharp increase in WOB to 7.5 k, CT wt to -5k, bit depth 12,272' PU Wt 29 k, RBIH, stack out 2 more times. Pump off liner, going thrugh the motions. PU Wt 30 k lbs, WOB -0.39 k 016 over a dead well. GS clean, no pillet top retrieved. Pull checks, Install nozzle, stab Injector, jet stack while turning reel over to water, un stab Install large port down jet nozzle, stab injector,reverse circulate, test inner reel valve and stripper to 250/4000 psi -Test #13. Un Stab, install nlght cap, Valve crew service tree, grease valves in nreoaration for BOP test End Operations Summary (with Timelog Depths) Rig: NABORS CDR3-AC 2M-21 Job: DRILLING SIDETRAC Time Log End rime Dur (hr) 0.30 PROD2 Phase Op Cote AUiviy Coca WHDBOP BOPE T Time P -T-% AOGCC Stan Depth Operation (ftKB), End Depth (110) Witne waived Watt Herrera of the 0.0 0.0 Start Time 11/22/2019 11/22/2019 05:30 05:48 Test pressure 250/4000 psi low/high. valve Test 1.Leaking past Swab 2, call out crew to grease, carry on with 11/22/2019 06:18 11/22/2019 11122 0.50 0.60 PROD2 WHDBOP BOPE PROD2 WHDBOP BOPE test P T BOP N2, Chadie 0.0 0.0 QesSt 8. &12 0.0 Test 3. BOP N 1, Charlie 3, 7, & 11, 0.0 0.0 not holding pressure, trouble -shoot, 11/22/2019 05:48 11!2212019 11/22 06:64bleeding pressure past swab 1, test 11/2212019 0.40 PROD2 WHDBOP BOPE P against master valve, good test Test 4. choke C anal choke D & Super 0.0 0.0 11/22/2019 06:54 07:18 3.00 PROD2 WHDBOP BOPE T 2 0.0 0.0 CharTest lie 2, & 10, unable to get good 11/22/2019 11/22/2019 07:18 10:18 high test, trouble -shoot, chart not rotating, grab new test chart, valve crew arrives, re -grease swabs & tangos, re -grease Charlie 2, 7, & 10, hammer up flow block to swab 1 Re -test #1 post greasing, good, then re -test #5, difficulty on low, come up to high, holding, re -test low, good, high, 11/22/2019 10:48 0.50 PROD WHDBOP BOPE T good test Test 6. Tango 1 arlie 1, 9, Bravo 5, and 0 0.0 -install TlW est joint, unable to hold pressure on low, shut in TP2, 11/22/2019 10:18 rock solid, losing pressure at test pump, carry on isolating at test pump, 220 PROD WHDBOP BOPE P good low, good high #1, Romeo Tet 1r, Bleeder 1pipe p rams, TIW 0.0 0.0 11/22/2619 11/22/2019 10:48 13:00 Test 8. Annular BOP Test 9. Upper 2" pipe slip rams. Bravo 6, & 8 Test 10. Bravo 7 - swap out 2" test joint for 2-3/8" Test 11. 2-3/8" pipe slip rams, TIW#2 - check N2 levels, swap to 2" test joint Test 12. Draw down accumulator, stabilized starting pressure 2350 psi, time to 200 psi increase 24 sec, full recovery time until pumps shut down 53 sec, N2 bottles - average of 4. 1950 psi. Tested all gas detectors, pits, cellar, rig floor all functioned properly. Verified flow alarms - PVF 11/22/2019 11122!2019 1.70 PR0D2 STK CTOP P Clear l ow -down, cut CTC Off, 0'0 0.0 protect a Tineend, pump back slack (2 13:00 14:42 bpm, twice, hear wire move), roll coil 11/22/2019 1112272619 1.80 PR052 STK CTOP P to KWF Pop-off, cut ew coil le len70'gth 17,936')et of coil , bevel o find wire 0.0 0.0 14:42 16:30 11/22/2019 11/22/2019 1.20 FR STK CTOP P ream pipe, install CTC 0.0 0.0 pressure test, crew change, PJSMe 16:30 17:42 11/22/2019 11/22!2019 1.00 PROD2 STK CIRC P Stab on, pump slat forwaM. 0.0 0' 17:42 18:42t. 11/22/2019 11/22/2019 1.00 PROD2 STK PULD P PU and agitator AIover a Hcy AKO motor 0.0 78. bit 18:42 19:42 P9 age 17125 Report Printed: 1213/2019 Operations Summary (with Timelog Depths) 2M-21 00 00:3U Rig: NABORS CDR3-AC Time Log 11/23/2019 11/231: 00:54 01:30 ,11/23/2019 11/23/; Start Time Entl Time Our (hr) Phase Op Code 11/22/2019 11/22/2019 1.90 PROD2 STK 19:42 21:36 0.20 PROD2 STK 11/22/2019 11/2212019 21:36 21:48 11/2212019 11/22/2019 1.00 PROD2 STK 21:48 22:48 0.20 PROD2 STK 11/22/2019 11/22/2019 22:48 23:00 1.00 PROM STK 11/22/2019 11/23/2019 23:00 00:00 00 00:3U 11/23/2019:00 111231: 00:30 00:54 11/23/2019 11/231: 00:54 01:30 ,11/23/2019 11/23/; 01:30 01:42 11/23/2019 11/23/ 01:42 01:54 11/23/2019 11/23/ 01:54 04:54 04:54 07:30 Job: DRILLING SI bpm. iue to RIH displacing coil to is K1 fnr a +A' correct, PU Wt 31 k lbs RIH, lots of magnetic interference @ 10,100',5 k WOB spike @ 10143'. Continue in to TOL SID 4.8 k WOB @ 10,236'. PU Wt 33 k lbs. PUH set rate, establish retunes RBIH, encounter high vibrations (5) possibly have broken ring from billet on the bit CT 4446 psi @ 1.79 /1 �31bmp in/out, Free spin diff 1175 psi, BHP 3181 psi, 10.35 EMW @ the window w choke wide open, WH 0 psi, IA 771 psi, OA 66 psi, CT RIH Wt 15.37 k lbs, WOB 0.3 k lbs, get into billet, sharp spike in motor work that fell quickly to more typical value, fed a few tenths, all smooth, engage auto driller at 1 ft/hr Tool face HS Increase ROP to 2 fUhr CT Wt 15.3 k lbs, WOB 0.3 lbs Increase ROP to 3 ft/hr CT Wt 15.3 k lbs, WOB 0.39 lbs Start to push on it, targeting 20 will and up to WOB of 1.2 k lbs 10,244' star to push on KROP to 38 ft/hrWOB 1.2 k/lbs Drilling ahead, CT 4762 psi, 1.79/1.55 bpm in/out, WOB 1.9 k Isb CT Wt 13.4 k Isb, ROB variable to 100 ft/hr. BHP 3204 psi, EMW 10.4 ppg, WH Opsi, IA 788 psi, OA 96 psi 10,265', stall, PU Wt 36 k lbs, PUH, RBIH, dry drift billet, a little ratty but ok, RBIH ;pin 1119 psi, BHP 3157, WH 0 psi, CT Wt 10 k Isb, WOB 2.8 k lbs, ROP variable to 100 ft/hr 10,339' PU 36 k lbs 10,396' PU 40 k lbs 10,415' PU 35 k Ibs - start new mud Power Pro down the coil New mud at the bit -10447' Drilling, CWT = 8.8K @ 2K WOB, bore pressure spike at -10,440', returns began to slowly drop to 1.45 bpm, 250' wiper from 10,500', stall at 10,521', PUW = 37K Wiper to tubingtail, PUW = 35K, jog 7" casing Stack at bottom of window (HS), orient 10°L, stack again, attempt 10°L @ 15 fpm, stack again (2X), attempt 10R, no good, come to 2K WOB, work HOT back & forth, no good, attempt HS, no EM ., Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log sten Depth Stan Time EntlT n our (hr) Phase Op Code Activity Code P Time P -T -X Operation no pass through window, PUH (ftKa) 10,111.0 End Depth Mai 9,930.0 11/23/2019 11/23/2019 0.20 PROD2 DRILL WPRT t log K1 07:30 07:42 11/23/2019 11/23/2019 0.10 PROD2 DRILL D LOG P Log K1 for +2' correction 9,930.0 9,951.0 07:42 07:48 11/23/2019 0.30 PROD2 DRILL WPRT P RBIH, & get through window at 10L @ 9,951.0 10,560.0 11/23/2019 15 fpm clean, stacked weight 07:48 08:06 @10,146', clean past billet, pump 5x5 sweeps, RIW = 10.5K 11/23/2019 11/23/2019 0.30 PROD2 DRILL DRLG P Dtilling, FS = 1036 psi @ 1.8 bpm, 10,560.0 10,583.0 CWT= 10.3K@ 1.1KWOB, annular= 08:06 08:24 3386 psi (choke open), pump = 4658 psi, 1.5 bpm returns 11/23/2019 11/23/2019 2.90 PROD2 DRILL DRLG P PU for new numbers, PUW = 32K 10,583.0 10,760.0 08:24 11:18 Drilling, FS = 1144 psi @ 1.8 bpm, CWT= 10.2K @ 0.5K WOB, annular= 3386 psi, pump = 4749 psi, 1.52 bpm returns, PUW = 40K from 10,699' Two stalls at 10,722' (torquing up drilling through hard spots), pump sweeps, avg ROP = 61 fph 11/23/2019 11/23/2019 0.60 PROM DRILL WPRT P Wippe(rt' BOW, PUW = 37K, RIW = 10,760.0 10,760.0 11:18 11/23/2019 11:54 11/2312019 2.20 PROD2 DRILL DRLG P Drilling, FS = 1079 psi @ 1.8 bpm, 10,760.0 10,960.0 CWT= 9.8K @ 1.4K WOB, annular= 11:54 14:06 3428 psi, pump = 5033 psi, 1.5 bpm returns, avg ROP = 91 fph 11/23/2019 11/23/2019 0.50 PROD2 DRILL WPRT P Wiper to tubing tail, PUW =35K, drag 10,960.0 10,125.0 a bit of negative WOB off bottom & up 14:06 14:36 through window, jog 7", clean down through window 11/2312019 11/23/2019 0.10 PROD2 DRILL DLOG P Log RA for +1.5' correction 10,125.0 10,144.0 14:36 11/23/2019 14:42 11/23/20 19 0.30 PRGD2 DRILL WPRT P Wiper back in-hole, RIW =1UK 10,144.0 10,960.0 14:42 11/23/2019 15:00 11 123/2019 1.40 R P0D2 DRILL DRLG P Drilling, FS - 1280 psi @ 1.86 bpm, 10,96D.0 11,160.0 CWT= 9.5K @ 1.75K WOB, annular= 15:00 16:24 3489 psi, pump = 5241 psi, 1.55 bpm returns, cuttings ratio = 0.94, pump sweeps, pump up the volume, avg ROP = 143 fph, CR = 0.93 11/2312019 11/23/2019 0.50 PROD2 DRILL WPRT P 600' wiper, PUW = 35K, RIW = 10.9 11,160.0 11,160.0 16:24 16:54 1.70 PROD2 DRILL DRLG P CT 4653 psi 1.78 / 1.57 bpm in/out, 11,160.0 11,367.0 11!2312019 11/23/2019 Free spin 1142 psi, BHP 3315 psi 16:54 18:36 CT Wt 11.1 k Itis, 2.3 k Itis. Crew change PU, 39 k lbs, free spin 1096 psi OBD, pump 5x5 in anticipation of wiper to window average ROP over interval, 121 ft/hr 11/2312019 11!23/2019 0.90 PROD2 DRILL WPRT P PU k lbs, PUH on lonI 11,367.0 10,041.0 18:36 18:36 19:30 window. Brief -2.8 k WOB tug @ 11,287'- Itis of motor work Jog build section, pull throug @ 10 ft/min and 0.5 bpm -1 k WOB tug pulling througwindow et 7" 11/23/2019 11/23/2019 0.30FPRU0D2 D2 DRILL WPRT P RBIHS/D 10111, 3x, orient 10,041.0 10,126.0 19:30 19:48 WPRT P Tie in to RA tag+2.5'correction 10,126.0 10,154.0 11/23/2019 11/ean 23/2019 0.20DRILL 19:48 20:00 Page 19125 Report Printed: 1213/2019 Operations Summary (with Timelog Depths) NABORS CDR3-AC 2M-21 Job: DRILLING SIDETRACK Set down 4x, first at 10,931, and again at 10937, orient 300 ROHS RIH and SID @ 10,937 and 10, 947' Pick ups clean. Reduced pump to min rate, RIH clean, Back up on the pump continue to RIH. CT RIH Wt 10 k lbs 11/23/2019 11/2312UIy PROD2 DRILL WPRT P PU Wt 35 k lbs 11,635.0 free 1027 psi, BHP 3515 psi, 11.1 0.30 PROD2 20:42 23:24 0 11,635.0 03:36 03:54 pin ppg EMW @ the window, open choke. P CT 4656 psi @ 1.8111 .11 bpm in lout, 11,635.0 11,708.0 /24/2019 /24/2019 11 11 1.10 FR free spin 1074 psi, BHP 3468 psi , 11 WH 0 psi, IA 798 psi, OA 96 psi. CT 03:54 05:00 ppg EMW at the window, 11.3 ppg at Wt 0 k lbs, WOB 2.7 k lbs. the bit. OBD. CT 6.9 k1 bs, WOB 1.4 k lbs 11,389' PU 39 k lbs 3.00 PROD2 DRILL DRLG P Drilling, CWT = 9.4K @ 3.4K WOB, 11,708.0 11,835.0 11/24/2019 11/24/2019 1_124 11124 11,410' PU 37 k lbs annular= 3493 psi, pump =4709 psi, 05:0008:001.2 11429'36 k lbs & -3 k lbs WOB 0.60 PROD DRILL WPRT P fe foal ll 1118 11,541.0 10,172.0 11/23/2019 11/24/2019 /0 inU0.12 bpm/ outReturns Wrapping gamma cut at -11,747' (157 23:24 00:00 API), -2' section, pump sweeps, PUH on wiper, losses slowly healing. 11/24/2019 11/24/2019 0.20 PROD2 DRILL WPRT P Continue to PUH to window 10,172.0 10,040.0 00:00 00:12 0.40 PROD DRILL WPRT P window 10,040.0 10,125.0 11/24/2019 11/24/20 19OW, DRILL DLOG P Log RA for correction, stack out at 10,125.0 10,140.0 11/24/2019 11/24/2019 First HS, second cond 10 L@thiirrd attempt PRO D2 00:12 00:36 08:54 09:00 DRILL WPRT passed cleanly. 10,140.0 11,835.0 11/24/2019 11/24/2019 0.70 0.20 PROD2 DRILL DLOG P Log the RA lag for a +2' correction 10,125.0 10,145.0 11/24/2019 11/24/2019 Page 20126 Report Printed: 1 21312 01 9 00:36 00:48 SID while loggingg, 41k WOB @ 10,143 (corected) PU and pop through 11/24120.19 11/24/2019 0.40 PR0D2 DRILL TRIP P RIH 10,145.0 11,541.0 00:48 01:12 DRILL DRLG P CT psi, 1.801 0M bpm psi. 11,541.0 11,635.0 11/24/2019 11/24/2019 2.20 PROD2 spin psi, BHP 3388 psi, 1 0.8 free spin 11 01:12 03:24 the the ppg EM @the window, 11 ppg at the bit. WH 0, IA 789, OA 95 psi. CT 10 k lbs WOB 11/24/2019 11/24/2019 0.20 PROD2 DRILL WPRT P PU Wt 35 k lbs 11,635.0 10,952.0 03:24 03:36-1-0,_952 11/24/2019 11/24/2019 0.30 PROD2 DRILL WPRT P RBIH RIH Wt 11.5 k lbs 0 11,635.0 03:36 03:54 DRILL DRLG P CT 4656 psi @ 1.8111 .11 bpm in lout, 11,635.0 11,708.0 /24/2019 /24/2019 11 11 1.10 FR free spin 1074 psi, BHP 3468 psi , 11 03:54 05:00 ppg EMW at the window, 11.3 ppg at the bit. OBD. CT 6.9 k1 bs, WOB 1.4 k lbs 3.00 PROD2 DRILL DRLG P Drilling, CWT = 9.4K @ 3.4K WOB, 11,708.0 11,835.0 11/24/2019 11/24/2019 1_124 11124 annular= 3493 psi, pump =4709 psi, 05:0008:001.2 bpm returns, lower ROP beginning -11,775' BHAWper from 11,761', PUW =40K Wrapping gamma cut at -11,747' (157 API), -2' section, pump sweeps, encounter a bit of aired up mud 0.90 PROD2 DRILL WPRT P Wiper to tubing tail, PUW = 42K, jog 11,835.0 10,125.0 11/24/2019 11/24/2019 7", stack at BOW (3X) 011248:00 011248:54 DRILL DLOG P Log RA for correction, stack out at 10,125.0 10,140.0 11/24/2019 11/24/2019 0.10 PRO D2 during 10,141' during tie-in 08:54 09:00 DRILL WPRT P IH,at 10,140.0 11,835.0 11/24/2019 11/24/2019 0.70 PROD2 109 666', cl an p st got gammaat 09:00 09:42 11,747', RIW = 9.5K Page 20126 Report Printed: 1 21312 01 9 Operations Summary (with Timelog Depths) rug: NABORS Gvrx C 2M-21 Job: DRILLING Time Log Start Time 11/24/2019 EndDur( 11124/201 01 9 Phase Code 2.4.4 0 PROD2 DRILL L Activity Code Time DRLG P P -T-% OP don 115- @1@WOB, annular= CWTg 865K5K start Depth (WS) End 11,835.0 Depth (ftKB) 11,936.0 09:42 12:06 3515 psi, pump = 4906, 1.12 bpm 11/24/2019 11/24/2019 2.60 PROD2 DRILL DRLG returns, avg ROP = 42 fph P DrIIIIar C3542354Psi, psi, annu12:06 11,936.0 12,035.0 14:42 1.27 bpm retums, pump 5x5 sweeps, ROP picking up at -12,009', abg ROP 11/24/2019 11/24/2019 0.60 PROD2 DRILL WPRT = 40 fph P 800' wiper, PUW = 34K, RIW = 9.8K 12,035.0 12,035.0 14:42 15:1812035.0 11124/2019 3.70 PROD DRILL DRLG P �9. 610 7 -1.5K @5K WOB, annular , 12,226.0Drilling,11/24/2019 15:18 19:00 = 3591 psi, pump = 5176 psi, 1.35 bpm returns Crew change PU, 12,179' PU Wt 36 k lbs, CT 4830 psi @ 1.83/1.38 bpm in/out, diff 1034 psi, BHP 3621 psi, WH 0, IA 797, OA 94 psi. CT -5 k lbs, WOB 2 it lbs. launch 6x5 in 11/24/2019 11/24/2019 1.00 PROD2 DRILL WPRT anticipation of wiper. Average ROP over interval - 51 f 1hr D ,tie m on long wiper to P tPU he w n 8 k IDS, 12,226.0 10,072.0 19:00 20:00 Hole, billet and window clean. 11/24/2019 11/24/2019 0.80 PROD2 DRILL CIRC P Jet 7", chase bottoms up 10,072.0 9,914.0 20:00 11/24/2019 20:48 11/24/2019 R2 DRILL 0.20 POD DLOG P Tie into the K1 or+2.5' correction 9,914.0 9,952.4 20:48 11124/2019 21:00 21:00 11/24/2019 21:54 0.90 PROD2 DRILL TRIP P billet clean, WOB spike to 2 k lbs, Carted 12k CT wt while RIH 9,952.4 12,226.0 '• Add 2 ppb alpine beads to high vis 11/24/2019 11/25/2019 2.10 PROD2 DRILL DRLG sweeps. P 94free spin psi @ .7 11.26 bpm HP 3633 psin o 3 12,226.0 12,285.0 21:54 00:00 ppg EMW @ the window, 11.87 ppg @ the bit. OBD, CT 0 k lbs, WOB to 3 k 11/25/2019 11/2512019 1.70 PROD2 DRILL DRLG lbs, P free spin 112077 psi,BHP 3633 psi48psi T1.7811 26 --bpm , 11 3 12'285.0 12,299.6 00:00 01:42 ppg EMW @ the window, 11.87 ppg @ the bit. OBD, CT 0 k lbs, WOB to 3 k 11/25/2019 01:42 11/25/2019 02:18 11!2512019 02:18 11/25/2019 02:30 0.60 PROD2 DRILL 0.20 PR0D2 DRILL DRLG WPRT IDS, l from P 3010 psi tole on 1076Psi. PU, diff cmotor work llimbed to a stady 1224 psi. Pump inlet pressure dropped mirroring the diff. P PU Wt 35 k IDS, Pull 300wiper. pump 5x5 sweep RIH Wt 9.5 k lbs 12,299.6 12,302.0 12,302.0 12,302.0 11/25/2019 02:30 11/25/2019 04:12 1,70 PROD2 DRILL DRLG P diff 1198 psi, @ 1.83/1.5 bpm in/out, OBD, diff fell 193 psi with 3.7 k WOB 12,302.0 12,312.0 Multiple attempts to drill ahead, PUS 35 k lbs. No sucess. Rotate the HOT while drilling w 3 k WOB, suddent spike in WOB and motor work, able to drill ahead, ROP/diff fell of, rotated again with similar results, drilled ahead. 11/25/2019 11/25/2019 1.60 PROD2 DRILL DRLG Fl- riff 1029 psi, HP 3633 psi, 1 3 ppg 12,312.0 12,351.0 04:12 05:48 EMW at the window, 11.8 ppg @ the bit. CT -4 k lbs, WOB 2.2 k lbs Page 21125 Report Printed: 1213/2019 105:48 09:541036 17:54 11/25/2019 11/25/: 10:36 13:42 11/26/2019 11/26/: 11/25/2019 11/251 13:42 16:42 16:42 17:54 11/25/2019 11/25/: 11/26/2019 11/26/: 00:00 01:24 a17:5419:06:21:12 11/26/2019 111261 01:24 02:36 24 Z"1:18 125/2019 11/251 :18 23:00 23:00 123:Su 11/25/2019 11/26/: 23:30 00:00 11/26/2019 11/26/: 00:00 01:24 11/26/2019 111261 01:24 02:36 11/26/2019 11/261 naas 03:12 Operations Summary (with Timelog Depths) 2M-21 NABORS CDR3-AC n,.,fm Phase Page Job: DRILLING SIDETRACK Crew change, drilling, CWT =-3.bK G 1.9K WOB, annular = 3645 psi, pump = 5253 psi, 1.5 bpm returns, lower ROP w/ low differential Drilling, low ROP, down to 4 fph, CWT = -3.6K @ 2.9K WOB, pump = 5080 psi, oriented HS, working through hard spot back up through, extremely low ROP (to 4 fph), pump 5x5 sweeps 800' wiper, PUW = 35K, bit oriented LS pulling up -hole, RIW = 7.8K Drilling, FS = 1204 psi @ 1.9 bpm, CWT = 6.6K1.056 @ 1.8K WOB, 11.5 pp9 at window, 1.56 bpm returns, PUW = 36K from 12,484', clay over shakers, decsion made to trip for bit, avg ROP = 19 fph POOH for new bit (closed EDC), PUN = 33K, jog 7", open EDC at surface), PJSM Pre -load PDL :rynamus bit), inspect pack offs - good. Bump up, set ounters, RIH, Shallow test agitator - good - 1 diff, Baker counter feed locked up at 1745', troublshot and repaired continued in hole. WOB spikes, setting down on )pen hole clean. ,^,T 5012 psi @ 1.7811.43 bpm indou Jiff 1051 psi, BHP 3730 psi, Get kicked down, trying to target higher WOB, pump beaded sweep Encounter High ROP drilling break snubbing -5 k lbs, max 1.4 k WOB PU W135, PUH on short wiper whil beads travel to bit. 839 psi, BHP 3665 psi, CT Wt -5 k lbs, WOB 1.9 k lbs CT 4189 psi @ 1.5/1.4 bpm in/out, diff 839 psi, BHP 3665 psi, CT Wt -5 k lbs, WOB 1.9 k lbs Drilling break at 12,596', resistivity trending back up Increase pump rate to 1.8 bpm, drill ahead CT 5180 psi @ 1.7811.45 bpm in/out, BHP 3689 psi, CT Wt -4 k lbs, WOB 2.6 k lbs PU as directed by Geo, circ sample bottoms up, catch sample and deliver to Geo. Operations Summary (with Timelog Depths) 2M-21 IRINEW Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Depth Stan Time End Nne Durno Phase Op CDde ActiNry Code DRLG Time P -T -X P Operation 5113 psi m Infout, (RI(a) 12,658.0 End Depth (MB 12,749.0 11/26/2019 11/26/2019 1.20 PROD2 DRILL drff 1089�TT psi BHP811.47 3762, 1p56 EMW 03:12 04:24 @ the window, 12.25 ppg @ the bit, CT -2 k Ibs, WOB 1.5 k lbs 11/26/2019 11/26/2019 0.60 PROD2 DRILL WPRT P PU Wt 41 k Has, PUH on short 800' 12,749.0 12,749.0 04:24 11/26/2019 05:00 11/26/2019 3.70 PROD2 DRILL DRLG P wiper. Drilling, FS = 1087 psi @ 1.8 bpm, 12,749.0 12,950.0 CWT= -5K@ 1.3K WOB, annular= 05:00 08:42 3775 psi pump = 5270 psi, 1.55 bpm returns, pump 5x5 beaded sweeps 11/26/2019 11/26/2019 1.50 PROD2 P Wiper to tubing tail, PUW = 36K, clean 12,950.0 9,935.0 08:42 10:12 all the way, jog 7" 11/26/2019 11/26/2019 0.10 PROD2 P Log K1 for +6' correction 9,935.0 9,946.0 10:12 11/2612019 10:18 11/26/2019 1.1() PROD2 TDRILLWPRT P RBIH, clean through window, clean 9,946.0 12,950.0 past billet, RIW variable (getting into 10:18 11:24 negative weight near bottom, at reduced speed) 11/26/2019 11/26/2019 260 PROD2 P Drilling, FS = 1100 psi @ 1.86 bpm, 12,950.0 13,063.0 CWT = 5.2K @ 0.9K WOB, 11.6 ppg 11:24 14:00 at window, pump = 5730 psi, 1,54 bpm returns, pump 10 bbl beaded pill to good effect, continue pumping beaded pills as required, avg ROP = 43 fph PUW =36K from 13060' 11/26/2019 711262019 1.90 PROD2 DRILL DRLG P Drilling, CWT = OK @ 1 K WOB, 11.7 13,063.0 13,150.0 @ the window, pump = 5700 psi, 14:00 15:54 continue to pump beaded pills, 1.64 bpm returns 71/26/2019 11/26/2019 0.70 PROD2 DRILL WPRT P 800'wiper, PUW =35K, near neutral 13,750.0 73,150.0 weight with beads coming around @ 15:54 16:36 reduced -20 fpm 11/26/2019 11/26/2019 2.90 PROD2 DRILL DRLG P Drilling, FS = 1089 psi @ 1.85 bpm, 13,150.0 13,294.() CWT = -2.5K @ 1.2K WOB, 11.6 ppg 16:36 19:30 at window, pump = 5374 psi, 1.55 bpm returns, avg ROP = 50 fph 11/26/2019 11/26/2019 1.00 PROD2 DRILL DRLG P annlular-CWT13K WOB. --f3-294 13,294.0 13,350.0 ps?pu@m 19:30 20:30 5x5 beaded sweeps, avg ROP = 56 fph 11/262019 11/26/2019 1.70 PROD2 DRILL WPRT P Wiper to window, PUW = 35K, jog 7" 13,350.0 9,935.0 20:30 11/26/2019 22:12 11/26/2019 0.10 PROD2 DRILL DLOG P Log Kt for+3.5' correction 9,935.0 9,956.0 22:12 17/26/2019 22:18 11/26/2019 1.30 PROD2 DRILL WPRT P RBIH, clean window, billet and open 9,956.0 13,350.0 22:18 11/26/2019 23:36 11/27/2019 0.40 PROD2 DRILL WPRT P hole -- 5299 psi @ 1.78/1.5 bpm inlout, diff 9,958.0 13,350.0 1034 psi, BHP 3817 psi, 11.4 ppg 23:36 00:00 ECD at the window, 12.3 ppg @ the bit. CT Wt -5 k Ibs, 1 k lbs 11/27/2019 11/27/2019 5.90 PROD2 DRILL WPRT P 5299 psi @ 1.78/1.5 bpm in/out, diff 13,350.0 13,608.0 1034 psi, BHP 3817 psi, 11.4 ppg 170:00 05:54 ECD at the window, 12.3 ppg @ the bit. CT Wt -5 k lbs, 1 k lbs Pumping beaded active mud pills with little observable effect. 11/27/2019 11/27/2019 0.30 PROD2 DRILL WPRT P PU Wt 38 k Ibs, PUH on short 800' 13,608.17 12,817.() 05:54 11/2712019 06:12 11/27/2019 0.60 PROD2 tD7R[LL7::�]-WPRT P wiper RBIH - 3-4 k Ibs 12,817.11 137608.0 06:12 06:48 Page 23126 Report Printed: T2-1312019 Operations Summary (with Timelog Depths) 2M-21 V Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth startrime End Time our (hr) Phase Op Code Activity Code DRLG Time P-T-X P Operation CT 4399 pis, @ 1.56/1.37 bpm out, (ftKB) End Depth(ftKB) 13,608.0 13,735.0 11/27/2019 11/27/2019 4.90 PROD2 DRILL diff 772 psi, BHP 3794 psi, WH 0, IA 06:48 11:42 810, OA 98. CT -3 k lbs. WOB 1.1 k lbs. 11/27/2019 11/27/2019 0.90 PROD2 DRILL WPRT P PU 38 k lbs, atempting to restart 13,735.0 13,735.0 11:42 12:36 unable to RBIH. Pull up hole on wiper while displacing sweep to bit. 11/27/2019 11/27/2019 3.10 PROD2 DRILL DRLG f CT 3928 psi, @ 1.79/1.56 bpm in/out, 13,735.0 13,804.0 12:36 15:42 diff 924 psi, BHP 3928, CT -8 k WOB 0.8 k lbs, 11/27/2019 11/27/2019 3.70 PROD2 DRILL W PRT P PU 35 k lbs, chase TO sweeps to bit 13,804.0 78,2 15:42 19:24 and out of hole. 11/27/2019 11/27/2019 0.20 15ROD2 DRILL TRIP P Tag up, reset counters depths 78.2 78.2 19:24 19:36 11/27/2019 11/27/2019 1.60 PROD2 DRILL TRIP P RIH 78.2 9,935.0 19:36 21:12 11/27/2019 11/27/2019 0.20 PROD2 DRILL DLOG P Log formation for depth contro1(+8.0') 9,935.0 9,946.0 21:12 21:24 11/27/2019 11/27/2019 0.20 PROD2 DRILL TRIP P Continue IH 9,946.0 10,061.0 21:24 21:36 11/27/2019 11!272019 0.50 PROD2 DRILL TRIP P Obtain SBHP, 9.969 ppg EDC @ 10,061.0 10,061.0 10,061' CTMD, 5,848.8 TVD, 3,029 21:36 22:06 psi 9:25p - 3304 psi 9:30p - 3248 psi 9:35p - 3194 psi 9:40p - 3120 psi 9:45p - 3091 psi 9:50p - 3041 psi 9:53p - 3029 psi Confer with town team 10.3 ppg KVJF 11/27/2019 11127/2019 1.40 PR0D2 DRILL TRIP P Continue IH through window 350 10,061.0 13,807.0 ROHS w/1.2k bobble @ 10,112', 1.0 k 22:06 23:30 weight bobble @ billet as we passed by 10,236' 11/27/2019 11/28/2019 0.50 PROD2 DRILL CIRC P Confirm TO 13,807', work pipe while 13,807.0 13,591.0 23:30 00:00 circulating beaded LRP to bit. 11/28/2019 11/28/2019 0.20 PROD2 DRILL TRIP P RBIH to bottom 13,802' 13,591.0 13,802.0 00:00 00:12 11/28/2019 11/28/2019 3.30 PROD2 DRILL TRIP P POOH, laying in beaded 10.3 ppg liner 13,802.0 78.2 00:12 03:30 running pill EDP flags 12,043' (yellow), 8,278' (white) 11/28/2019 11/28/2019 0.50 PROD2 DRILL OW FF P At surface, open valve on dser, 78.2 78.2 03:30 04:00 monitor for flow, PJSM 11/28/2019 11/28/2019 0.50 PROD2 DRILL PULD P Unstab INJH, inspect CT above CTC 78.2 0.0 0.127", continue LD drilling assembly 04:00 11/28/2019 04:30 11/28/2019f2.20 50MPZ2 CASING PUTB P Prep Floor for running liner 0.0 0.0 04:30 11/28/2019 05:00 11/28/2019 COMPZ2 CASING PUTB P PU Lower L1-01 liner, 45 joints R3 0.0 1,704.7 05:00 07:12 over a solid bull nose under a shorty deployment sleeve. Liner 1793.47' LOA 1704.72'. 115 joints loaded in the shed, ran 45, confirmed 70 joints in shed. 11/28/2019 11/28/2019 0.50 COMPZ2 CASING PUTB P PU BHA#19 1,704,7 1,839.0 07:12 07:42 1 Page 24/25 ReportPrinted: T21312-019 Operations Summary (with Timelog Depths) 2M-21 • r' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start"rime End Time I our (hr) Phase Op code Activity Code Time P -T -X Operation (ftKB) End Depth (M) 11/28/2019 11/2812019 3.70 COMPZ2 CASING RUNL P RIH W Lower L1-01 completion. Tie 1,839.0 13,807.0 07:42 11:24 into window flag for no correction, CT PU wt 30 k lbs, First set down 11,852', PU 49 k lbs, Work liner to about 12,050'. RIH clean from 12,051' down. 11/2812019 11/28/2019 0.80 COMPZ2 CASING TRIP P PU, set counters, POOH 13,807.0 9,900.0 11:24 12:12 11/2812019 11/28/2019 0.20 COMM CASING DLOG P Tie into the K1 for+4.5' correction. 9,900.0 9,930.9 12:12 12:24 11/28/2619 11/28/2019 0.20 COMPZ2 CASING DLOG P Log CCL to tubing tail, +7' correton to 9,930.9 10,008.0 12:24 12:36 convert PDC to original RKB. 11/28/2019 11/28/2019 1.70 COMP72 CASING TRIP P POOH painting flags, pumping down 10,008.0 64.0 12:36 14:18 the back side. yellow @10,024.22. White flag at 8044 11/28/2019 11/28/2019 0.50 COMPZ2 CASING PULD P Park short, Flow check- good, LD 0.0 0.0 14:18 14:48 1 1 BHA#19 over a dead well. 11/28/2019 11/28/2019 0.20 COMPZ2 CASING PUTS P Prep floor for running liner. 0.0 0.0 14:48 15:00 11/28/2019 11/28/2019 1.90 COMP72 CASING PUTS P Pick up Upper LTi -01 completion, 50 0.0 1,992.5 15:00 16:54 R3 joints of slotted liner (1983.17') under a shorty deployment sieve, over a 8.09' pup and a ported bull nose LOA 1992.51'. 11/28/2019 11/28/2019 0.40 COMPZ2 CASING PULD P Pick up BHA#19 1,992.5 2,056.5 16:54 17:18 11/28/2019 11/28/2019 1.40 COMPZ2 CASING RUNL P RIH with upper L1-01 completion. 2,056.5 10,037.0 17:18 18:42 11/28!2019 11/28/2019 '0.15 COMPZ2 CASING RUNL P Log formation for depth control (+2.7') 10,037.0 10,037.0 18:42 18:51 11/28/2019 11128!2019 0.70 COMPZ2 CASING RUNL P Continue RIH 10,037.0 12,012.0 18:51 19:33 11/28/2019 11/28/2019 0.20 COMM CASING RUNL P Tag top of liner @ 12,012', PUW 44 k, 12,012.0 10,019.8 19:33 19:45 set back down @ 12,012', bring pump up of 5,540'1,766 psi diff, PUW 28 k, TOL @ 10,019.8- 11128/2019 11/28/2019 0.50 DEMOB WHDBOP DISP P Line up and circulte SW to the bit. 10,019.8 10,019.8 19:45 20:15 11/28/2019 11/28/2019 1.60 DEMOB WHDBOP TRIP P POOH, displacing well to SW, LRS on 10,019.8 2,500.0 20:15 21:51 location, spot in, RU to customer line, PT 4,000 psi 11/28/2019 11/28/2019 1.00 DEMOB WHDBOP DISP P PSJM, load reel with 32 bbl of diesel 2,500.0 2,500.0 21:51 22:51 11/28/2019 11/28/2019 0.80 DEMOB WHDBOP TRIP P POOH, displacing well to deisel from 2,500.0 44.2 22:51 23:39 2,500' 11/28/2019 11/29/2019 0.35 DEMOB WHDBOP PULD P At surface, PUD setting tools. 44.2 44.2 23:39 00:00 FTP=400 psi 11/29/2019 11/29/2019 1.50 DEMOB WHDBOP PULD T ------Continue PUD/LD setting tools, 44.2 0.0 00:00 01:30 11/29/2019 11/29/2019 1.50 DEMOB WHDBOP CTOP P Install no&e, jet stack and surface 0.0 0.0 01:30 03:00 1 lines with FW 11/29/2019 11/29/2019 0.70 DEMOB WHDBOP -W-RG P Run bore -0 -scope, prep to changout 0.0 0.0 03:00 03:42 Annular Element. 11/29/2019 11!2912019 3.80 DEMOB WHDBOP SVRG P PJSM, swap annulara preventer 0.0 0.0 03:42 07:30 element 11/29/2019 11129/2019 4.50 DEMOB WHDBOP DMOB P Work RD checklist, Blow down, nipple 0.0 0.0 07:30 12:00 down Rig release 12:00 Page 25125 Report Printed: 121312019 (WS-11- ProActive Diagnostic Services, Inc. WELL LOG TRA1 SM/ 7TAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 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 : 1) Caliper Report 2) Signed: Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Pdsanchorage(a2memorvlog.com 07 -Oct -19 2M-21 1 Report/ CD 191129 31414 Rec�elvjjz�r-t Nov 05 ?019 AJ AO(3C 50-103-20156-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEPMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM https://readcasedhole-my.sharepointcom/personal/diane_williams readcasedhole_com/Documents/D Drive/Achives/MasterTemplateFi les/Cemplates/Distribution/TransmittalSheets/ConocoPhillips_Transmit. docx CASED HOLE Company: ConocoPhillips Alaska, Inc. Log Date: October 7, 2019 Log No.: 1 Run No.: 14406 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE Pipe Use: Tubing Pipe Description: 7 inch 26 Ib. J-55 BTC Pipe Use: Casing 191129 31414 Memory Multi -Finger Caliper Log Results Summary Well Field State API No Top Log Interval Bottom Log Interval Top Log Interval Bottom Log Interval Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: 2M-21 Kuparuk Alaska 50-103-20156-00 Surface 10,021 Ft. (MD) 10,021 Ft. (MD) 10,369 Ft. (MD) This caliper data is tied into the K-1 gamma ray marker at 9,918 feet per the attached PDC log. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 3.5 inch tubing appears to be in mostly good to fair condition, with the exception of a 41 % wall penetration in a line of pits in pup joint 315.4 (10,008 ft). Wall penetrations ranging from 20% to 41 % wall thickness are recorded in 3 of the 335 joints logged. Recorded damage appears as isolated pitting and a line of pits from 9,982 feet to 10,021 feet (end of tubing). No significant areas of cross-sectional wall loss are recorded. The caliper recordings indicate deposits at the bottom of the tubing, restricting the I.D. to 2.77 inches at 10,021 feet. A graph illustrating the minimum recorded diameters on a joint -by -joint basis across the tubing is included in this report. The caliper recordings indicate the 7 inch casing logged appears to range from good to poor condition outside of the perforation intervals, with a maximum recorded wall penetration of 43% in a line of pits in joint 2 (10,067 ft). Recorded damage appears as isolated pitting and a line of pits. The caliper recordings indicate oval deformation at —10,119 feet, restricting the I.D. to 5.80 inches. Light to moderate deposits are also recorded throughout the casing logged, restricting the I.D. to 5.75 inches at 10,340 feet. A graph illustrating the minimum recorded diameters on a joint -by -joint basis across the casing logged is included in this report. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting 41 315.4 10,008 Ft. (MD) Isolated Pitting 34 315.6 10,015 Ft. (MD) Isolated Pitting 22 313.3 9,879 Ft. (MD) No other significant wall penetrations (> 18%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 11 %) are recorded. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(a)readcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: Deposits 2.77 inches 315.6 10,021 Ft. (MD) No other significant I.D. restrictions are recorded. 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Description Line of Pits 43 2 10,067 Ft. (MD) Isolated Pitting 24 1 10,031 Ft. (MD) No other significant wall penetrations (> 19%) are recorded outside of the perforation intervals throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded outside of the perforation intervals throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: Description. Heavy Deposits 5.75 inches 10 10,340 Ft. (MD) Oval Deformation 5.80 inches 3 10,119 Ft. (MD) Deposits 5.90 inches 8 10,262 Ft. (MD) No other significant I.D. restrictions are recorded throughout the casing logged. C. Goerdt C. Waldrop J. Condio ei Analyst(s) l ritw5s. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(areadcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Minimum Measured Diameters (in.) 1.75 2 2.25 2.5 2.75 0.1 22 47 72 97 119 144 d 3 Z 169 c 'o 191.3 216 241 263 287.1 310 34 709 1,488 2,260 3,033 3,746 4,514 _C 5,286 s w. a d 6,012 6,765 7,541 8,251 9,028 9,735 CASED === = HOLE Minimum Diameter Profile Well: 2M-21 SurveyDate: October 7, 201 9 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 1.75 2 2.25 2.5 2.75 0.1 22 47 72 97 119 144 d 3 Z 169 c 'o 191.3 216 241 263 287.1 310 34 709 1,488 2,260 3,033 3,746 4,514 _C 5,286 s w. a d 6,012 6,765 7,541 8,251 9,028 9,735 CASED 400 300 1 200 100 Penetration (% wall) v 0 to 20 to 40 to over 20% 40% 85% 85% L _ Number of -joints -analyzed -(total = 335)- 332 2 1 0 Damage Configuration (body) 10 - - - - 8 ; I - -- --L- 6 - 4 - - I 2 -- - -- p - - Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged (total 5 0 6 0 0 Damage Profile (% wall) Penetration body Metal loss body ^ 0 50 100 GLM 1 (7:00) GLM 2 (11:00) GLM 3 (4:00) GLM 4 (9:00) GLM 5 (5:30) Bottom of Survey = 315.7 == _ HOLE Body Region Analysis Well: 2M-21 Survey Date: October 7, 2019 i Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10011398 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 - _ ---Analyst_ - - Waldrop Pipe Nom OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 Mf L-80 EUE 2.992 in. 34 ft. 10,021 ft. 400 300 1 200 100 Penetration (% wall) v 0 to 20 to 40 to over 20% 40% 85% 85% L _ Number of -joints -analyzed -(total = 335)- 332 2 1 0 Damage Configuration (body) 10 - - - - 8 ; I - -- --L- 6 - 4 - - I 2 -- - -- p - - Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged (total 5 0 6 0 0 Damage Profile (% wall) Penetration body Metal loss body ^ 0 50 100 GLM 1 (7:00) GLM 2 (11:00) GLM 3 (4:00) GLM 4 (9:00) GLM 5 (5:30) Bottom of Survey = 315.7 CASED HOLE Joint Tabulation Sheet Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE Tubing 2.992 in. 0.254 in. 34 ft 10,021 ft. ! Joint No. )t. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 0.1 34 0 0.03 11 6 2.93 Pu _ 1 37 0 0.02 8 3 2.92 Lt. Deposits. 1.1 67 0 0.05 18 5 2.91 Pup Shallow Line of Pits. Lt. De osits. 1.2 75 0 0.05 18 4 2.91 Pun Shallow Line of Pits. Lt. De osits. 1.3 83 0 0.03 13 4 2.92 PUD Lt. Deposits. 2 89 0 0.02 7 4 2.93 _ Lt. Deposits. 3 121 0 0.02 8 4 2.95 4 152 0 0.02 9 3 2.94 5 183 0 0.02 7 2 2.93 Lt. Deposits. 6 215 0 0.02 7 2 2.94 7 246 0 0.02 9 4 2.93 8 276 0 0.02 8 4 2.94 9 305 0 0.02 9 2 2.90 Lt. Deposits. 10 336 0 0.02 8 3 2.94 11 368 0 0.02 9 4 2.94 12 398 0 0.02 7 3 2.93 Lt. Deposits. 13 430 0 0.02 8 2 2.95 14 461 0 0.02 9 3 2.94 15 492 0 0.02 8 3 2.93 Lt. De osits. 16 521 0 0.02 7 2 2.94 17 552 0 0.02 7 5 2.94 18 584 0 0.02 7 2 2.94 19 615 0 0.02 8 3 2.93 Lt. Deposits. 20 647 0 0.02 9 3 2.94 21 678 0 0.02 9 4 2.94 22 709 0 0.02 9 3 2.93 23 739 0 0.02 7 2 1 2.91 Lt. Deposits, 24 771 0 0.02 8 4 2.93 Lt. Deposits. 25 802 0 0.03 11 2 2.93 Lt. Deposits. 26 833 0 0.02 9 3 2.93 27 865 0 0.02 9 4 2.94 28 896 0 0.02 9 5 2.93 29 927 0 0.02 7 2 2.94 30 958 0 0.02 7 2 2.94 31 989 0 0.02 7 2 2.92 Lt. De osits. 32 1020 0 0.02 8 2 2.94 33 1052 0 0.02 9 3 2.93 34 1083 0 0.03 10 3 2.92 Lt. Deposits. 35 1114 0 0.02 7 1 3 2.95 36 1145 0 0.02 6 2 2.95 _ 37 1176 0 0.02 9 4 2.95 38 1207 0 0.02 8 3 2.96 39 1239 0 0.02 7 4 2.95 40 1270 0 0.01 6 2 2.95 41 1301 0 0.02 9 7 2.95 42 1332 0 0.02 7 2 2.97 43 1363 0 0.03 10 6 2.95 44 1395 0 0.03 13 7 2.95 45 1426 0 0.02 7 2 2.96 46 1457 0 0.02 9 4 2.96 Penetration Body Metal Loss Body Page 1 CASED HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Joint Tabulation Sheet Survey Date: October 7, 2019 Analyst: Waldrop Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE Tubing 2.992 in. 0.254 in. 34 ft 10,021 ft. Penetration Body Metal Loss Body Page 2 Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 47 1488 0 0.01 6 2 2.96 48 1519 0 0.02 8 3 2.94 49 1 1551 0 0.02 1 7 3 1 2.97 50 1582 0 0.02 7 2 2.95 51 1613 0 0.03 10 3 2.95 52 1644 0 0.02 7 3 2.97 53 1675 0 0.02 7 2 2.96 54 1704 0 0.03 10 5 2.95 55 1735 0 1 0.03 13 8 2.98 56 1767 0 0.02 7 4 2.97 57 1798 0 0.02 7 3 2.96 58 1828 0 0.01 6 2 2.98 59 1858 0 0.03 11 5 2.98 0 1886 0 0.03 11 7 2.94 61 1918 0 0.02 6 2 2.97 62 1949 0 0.02 9 5 2.96 _ 63 1981 0 0.02 7 3 2.96 64 2012 0 0.02 7 4 2.95 65 2043 0 0.01 6 3 2.96 66 2074 0 0.02 7 3 2.95 67 2105 0 0.02 7 3 2.98 68 2136 0 0.02 9 5 2.97 69 2167 0 0.02 7 3 2.97 70 2199 0 1 0.02 9 5 2.96 71 2228 0 0.02 7 3 2.96 72 2260 0 0.02 7 2 2.97 _ 73 2291 0 0.02 8 3 2.97 74 2322 0 0.01 6 2 2.96 75 2354 0 0.02 7 2 2.97 76 2385 0 0.01 6 2 2.95 77 2416 0 0.03 13 7 2.96 78 2447 0 0.03 11 7 2.98 79 2478 0 0.02 7 2 2.98 80 2509 0 0.01 6 2 2.98 81 2540 0 0.02 9 4 2.97 82 2571 0 0.03 11 6 2.97 83 2602 0 0.02 7 3 2.97 84 2633 0 0.02 7 3 2.98 85 2664 0.05 0.03 13 7 2.98 86 2695 0 0.02 8 4 2.98 87 2727 0 0.02 7 3 2.97 88 2757 0 0.02 9 3 2.97 89 2789 0.04 0.04 14 9 2.98 90 2817 0 0.02 9 6 2.97 91 2848 0 0.02 9 4 2.96 92 2880 0 0.02 7 3 2.95 93 2910 0 0.02 7 2 2.97 2941 0 0.02 9 4 2.98 t994 2972 0 0.03 13 6 2.97 3003 0 0.02 7 3 2.96 Penetration Body Metal Loss Body Page 2 Well: Field: Company: CASED HOLE 2M-21 Kuparuk ConocoPhillips Alaska, Inc. � oint Tabulation Sheet Survey Date: October 7, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 34 ft 10,021 ft. Joint No. Jt. Depth Pen. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. 1. D. (in.) Damage Profile Comments (% wall) 0 50 100 97 3033 1 0 0.02 7 3 2.97 98 3065 0 0.02 7 2 2.98 _ 99 3095 0 0.02 9 3 2.96 100 3126 0 0.02 7 3 2.96 101 3157 0 0.02 9 2 2.96_ 102 3189 0.04 0.04 14 9 2.96 103 3220 0 0.02 7 3 2.96 104 3251 0 0.02 7 4 2.97 105 3282 0 0.02 8 3 2.96 105.1 3313 0 0.03 13 4 2.95 Pu 105.2 3323 0 0 0 0 2.92 GLM 1 Latch @ 7:00 105.3 3332 0 0.04 16 7 2.95 PUP Shallow Line of Pits. 106 3343 0 0.02 9 4 2.95 107 3373 0 0.02 7 4 2.96 108 3404 0 0.03 11 6 2.96 109 3435 0 0.01 6 2 2_97 110 3466 0 0.01 6 2 2.97 111 3497 0 0.02 9 5 2.97 112_ 3528 0 0.02 7 4 2.95 113 3559 0 0.02 9 4 2.95 114 3590 0 0.03 10 5 2.96 115 3621 0 0.02 6 2 2.96 116 3653 0.04 0.03 13 7 2.94 117 3685 0 0.01 6 2 2.96 118 3715 0 0.02 7 3 2.96 119 3746 0 0.02 8 4 2.95 120 3777 0 0.02 9 3 2.96 121 3808 0 0.02 8 3 2.96 122 3838 0 0.02 7 3 2.97 123 3869 0 0.03 11 4 2.96 124 3899 0 0.02 7 3 2.96 125 3930 0 0.03 11 4 2.96 126 3962 0 0.02 7 3 2.97 127 3992 0 0.02 7 3 2.97 128 4020 0.04 0.05 18 11 2.97 Shallow Pitting. 129 4052 0 0.02 6 3 2.97 130 4082 0 0.02 9 5 2.95 _ 131 4114 0 0.01 6 3 2.95 132 4145 0 0.02 7 2 2.97 133 4176 0 0.02 7 4 2.96 134 4207 0 0.03 11 6 2.96 135 4238 0 0.02 7 2 2.97 136 4269 0 0.02 _ 8 5 2.96 137 4300 0 0.02 9 3 2.96 138 4330 0 0.03 13 5 1 2.95 139 4361 0 0.03 11 5 2.96 140 4392 0 0.01 6 2 2.96 141 4423 0 0.02 7 3 2.95 142 4454 0 0.03 10 3 2.97 143 4485 0 0.02 8 4 2.95 Penetration Body Metal Loss Body Page 3 CASE HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in 9.3 nnf 1 -Rn FI IF Tuhinu Joint Tabulation Sheet Survey Date: October 7, 2019 Analyst: Waldrop Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 34 ft 10,021 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.)0 Damage Profile Comments (% wall) 50 100 144 4514 0 0.02 9 2 2.96 145 4545 0 0.03 11 5 2.96 146 4577 0 0.02 8 3 2.96 147 4608 0 0.02 9 4 2.95 148 4640 0 0.02 9 2 2.90 Lt. De osits. 149 4670 0 0.02 8 2 2.91 Lt. Deposits. 150 4702 0 0.04 14 4 2.93 Lt. De osits. 151 4732 0 0.02 7 2 2.94 152 4763 0 0.02 7 2 2.96 153 4793 0 0.02 8 3 2.96 154 4824 0 0.03 13 7 2.94 155 4856 0 0.02 7 2 2.95 156 4887 0 0.03 10 2 2.95 157 4918 0 0.01 6 2 2.96 158 4949 0 0.03 10 6 2.95 159 4979 0 0.03 10 3 2.93 160 5009 0 0.03 12 8 2.89 Lt. De osits. 161 5041 0 0.02 9 5 2.90 Lt. Deposits. 162 5072 0 0.02 7 3 2.93 Lt. De osits. 163 5103 0 0.02 9 4 2.92 Lt. De osits. 164 5132 0 0.02 9 2 2.93 Lt. De osits. 165 5162 0 0.03 13 8 2.96 166 5193 0 0.02 9 2 2.96 _ 167 5223 0 0.03 11 4 2.93 168 5254 0 0.03 12 7 2.97 169 5286 0 0.04 14 9 2.96 170 5317 0 0.02 7 3 2.96 171 5348 0 0.03 11 5 2.96 172 5378 0 0.02 7 2 2.97 173 5408 0 0.03 13 6 2.96 174 5440 0 0.02 8 2 2.95 175 5471 0 0.03 11 4 2.97 176 5502 0 0.02 7 3 2.96 177 5533 0 0.02 7 4 2.95 178 5564 0 0.02 7 3 2.97 179 5595 0 0.03 12 6 2.93 180 5627 0 0.02 7 2 2.96 181 5656 0 0.02 7 3 2.96 182 5684 0 0.03 11 4 2.97 183 5716 0 0.02 9 3 2.97 184 5748 0 0.02 7 4 2.95 185 5778 0 0.03 11 5 2.94 186 5809 0 0.02 7 1 2 2.90 Lt. De osits. 187 5840 0 0.03 11 1 4 2.89 Lt. De osits. 188 5870 0 0.02 9 3 2.91 Lt. Deposits. 189 5899 0 0.02 7 3 2.92 Lt. Deposits. 190 5930 0 0.02 7 3 2.94 191 5961 0 0.02 6 2 2.95 191.1 5993 0 0.02 8 4 2.95 Pu 191.2 6003 0 0 0 0 2.89 GLM 2 Latch 6--11:00 Penetration Body Metal Loss Body Page 4 CASED Joint Tabulation Sheet HOLE Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE Tubing 2.992 in. 0.254 in. 34 ft 10,021 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 191.3 6012 0 0.02 9 2 2.96 Pu 192 6022 0 0.02 9 2 2.93 193 6053 0 0.02 7 4 2.94 _ 194 6085 0 0.02 6 2 2.95 195 6116 0 0.02 9 3 2.96 196 6147 0 0.02 8 3 2.96 197 6177 0 0.02 6 2 2.95 198 62080 0.02 7 2 2.97 199 623 7O 0.02 6 2 2.95 _ 200 6269 0 0.02 6 2 2.96 201 6299 0 0.02 8 2 2.95 202 6331 0 0.03 11 3 2.95 203 6363 0 0.01 6 2 2.96 204 6393 0 0.02 9 3 2.94 205 6422 0 0.02 7 3 2.96 2061 6454 0 0.02 8 4 2.95 207 1 6486 0 0.02 8 3 2.95 208 6516 0 0.02 9 4 2.97 209 6547 0 _0.02 6 3 2.96 210 6579 0 0.02 7 2 2.93 _ Lt. Deposits. 211 6610 0 0.02 7 1 2 2.95 212 6641 0 0.02 7 2 2.96 213 6672 0 0.02 8 2 2.95 214 6703 0 0.02 7 4 2.95 215 6733 0 0.02 7 3 2.95 216 6765 0 0.03 10 3 2.95 _ 217 6795 0.04 0.04 17 9 2.92 Shallow Line of Pits. Lt. Deposits. 218 6827 0 0.04 14 6 2.95 219 6858 0 0.02 9 3 2.95 220 6889 0 0.02 7 2 2.95 221 6920 0 0.02 6 3 2.95 222 6951 0 0.02 7 3 2.95 223 6982 0 0.02 7 3 2.95 224 7014 0 0.02 7 3 2.95 225 7046 0 0.02 8 4 2.96 226 7076 0 0.02 9 2 2.95 227 7108 0 0.02 7 2 2.95 _ 228 7139 0 0.02 8 2 2.95 229 7171 0 0.01 5 2 2.96 230 7201 0 0.02 9 1 2 2.93 231 7233 0 0.02 9 1 3 2.95 _ 232 7263 0 0.03 11 7 2.92 Lt. Deaosits. 233 7295 0 0.02 7 4 2.96 234 7324 0 0.02 7 4 2.96 235 7354 0 0.02 7 2 2.96 236 7387 0 0.02 9 3 2.94 237 7417 0 0.03 13 4 2.92 Lt. De osits. 238 7447 0 0.02 7 2 2.94 239 7478 0 0.02 9 5 2.95 240 7510 0 0.03 12 6 2.92 Lt. Deposits. Penetration Body Metal Loss Body Page 5 Well: Field: Company: CASED HOLE 2M-21 Kuparuk ConocoPhillips Alaska, Inc. � oint Tabulation Sheet Survey Date: October 7, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 34 ft 10,021 ft. Joint Jt. Depth Pen. No. (Ft.) Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 241 7541 0 0.02 9 2 2.90 Lt. Deposits. 242 7572 0.04 0.02 9 3 2.86 Lt. Deposits. 243 7603 0 0.02 9 2 2.87 _ Lt. Deposits. 244 7633 0 0.02 7 3 2.90 Lt. De osits. 245 7663 0 0.02 7 3 2.90 Lt. Deposits. 246 7695 0 0.03 io-T 5 2.90 Lt. De osits. 247 7725 0 0.02 8 3 2.89 Lt. Deposits. 248 7756 0 0.03 10 5 2.90 Lt. Deposits. 249 7788 0 0.02 9 4 2.91 _ Lt. Deposits. 250 7818 0 0.03 10 3 2.90 Lt. De osits. 250.1 7850 0.04 0.03 13 4 2.87 Pu Lt. De osits. 250.2 7860 0 0 0 0 2.77 GLM 3 Latch @ 4:00 250.3 7868 0 0.03 13 4 2.90 Pu Lt. Deposits. 251 7878 0 0.03 11 4 2.90 Lt. Deposits. 252 7910 0 0.02 7 3 2.95 253 7940 0 0.01 6 3 2.94 254 7971 0 0.03 12 6 2.93 255 8003 0 0.02 7 4 2.94 256 8033 0 0.04 14 7 2.94 257 8064 0.04 0.02 9 4 2.93 Lt. De osits. 258 8095 0 0.03 11 5 2.95 259 8127 0.04 0.01 6 2 2.90 Lt. De osits. 260 8158 0 0.02 7 2 2.95 261 8188 0 0.02 7 3 2.93 Lt. Deposits. 262 8220 0 0.02 8 4 263 8251 0 0.02 7 2 _2.94 2.93 Lt. Deposits. 264 8283 0 0.02 9 4 2.96 265 8313 0 0.02 9 4 2.92 Lt. Deposits. 266 8346 0 0.04 14 11 2.94 267 8377 0 0.03 10 4 2.93 268 8408 0 0.03 10 4 2.94 269 8439 0 0.03 10 3 2.94 270 8469 0 0.03 13 7 2.94 271 8501 0 0.03 11 4 2.96 272 8532 0 0.03 10 4 2.94 273 8562 0 0.02 8 3 2.95 274 8594 0 0.02 8 4 2.96 275 8625 0 0.02 9 3 2.94 276 8657 0 0.02 9 4 2.94 277 8688 0 0.03 10 4 2.95 278 8718 0 0.02 7 2 2.94 279 8749 0 0.02 7 3 2.94 280 8780 0 0.02 9 3 2.95 281 8811 0 0.02 7 3 2.94 282 8843 0 0.03 11 3 2.95 283 8872 0 0.03 11 5 2.95 284 8903 0 0.01 6 2 2.94 285 8935 0 0.02 9 4 2.94 286 8966 0 0.02 7 2 2.95 287 8997 0 0.02 7 4 2.93 _ Lt. De osits. Penetration Body Metal Loss Body Page 6 CASED Joint Tabulation Sheet HOLE Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 34 ft 10,021 ft. joint No. jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Damage Profile Comments (% wall) 0 50 100 287.1 9028 0 0.04 15 2 2.93 Pu Shallow Pitting Lt. De osits. 287.2 9039 0 0 0 0 2.87 GLM 4 Latch Q 9:00) 287.3 9048 0 0.04 16 3 2.90 PUD Shallow Pitting Lt. Deposits. 288 9058 0 0.02 7 3 2.93 Lt. Deposits. 289 9089 0 0.02 8 3 2.94 290 9120 0 0.03 13 8 2.93 Lt. Deposits. 291 9152 0 0.02 7 2 2.93 292 9182 0 0.02 9 2 2.93 Lt. De osits. 293 9213 0 0.03 10 3 2.95 294 1 9245 0 1 0.03 11 1 4 2.94 295 9272 0 0.03 13 5 2.93 296 9304 0 0.02 7 3 2.93 297 9336 0 0.03 13 9 2.93 Lt. Deposits. 298 9367 0 0.03 11 4 2.93 299 9397 0 0.02 9 2 2.92 Lt. Deposits. 300 9425 0 0.03 13 4 2.92 Lt. Deposits. 301 9457 0 0.02 9 4 2.93 Lt. De osits. 302 9488 0.04 0.03 13 5 2.90 Lt. Deposits. 303 9520 0 0.02 7 2 2.93 Lt. De osits. 304 9551 0 0.02 T 8 3 2.93 305 9582 0 0.02 1 8 2 2.94 306 9613 0 0.04 14 7 2.94 307 9643 0 0.02 9 5 2.93 Lt. De osits. 308 9675 0 0.03 11 5 2.93 Lt. De osits. 309 9704 0 0.03 11 5 2.94 _310 9735 0 0.02 9 4 2.90 Lt. De osits. 311 9766 0 1 0.02 9 2 1 2.93 9797 0 0.02 9 2 2.93 3 9829 0 0.02 7 2 2.93 .1 P 9860 0.04 0.04 17 2 2.92 Pu Shallow Line of Pits. Lt. De osits. .2 9869 0 0 0 0 2.88 GLM 5 Latch @ 5:30.3 9878 0.05 0.06 22 5 2.93 Pu Isolated Pitting 313.4 9888 0 0.03 13 3 2.90 Pu Lt. Deposits. 313.5 9895 0 0 0 0 2.95 Seal Assembly 313.6 9908 0 0 0 0 2.85 7" x 3.5" FHL Packer 313.7 9916 0.05 0.03 11 3 2.93 Pu Lt. Deposits. 313.8 9921 0 0.02 9 2 2.97 Pu 313.9 9930 0 0 0 0 2.79 3.5" HES X Nipple 314.1 9933 0 0.03 10 2 2.92 PuD Lt. Deposits. 315 9942 0 0.02 7 2 2.94 315.1 9973 0 0.02 9 4 2.92 Pun Lt. Deposits. 315.2 9980 0 1 0 0 0 2.93 Seal Assembly 315.3 9990 0 0 0 0 2.98 _ 7" x 3.5" Otis HV- Retrievable Packer 315.4 10004 0.08 0.11 41 6 2.83 PuI2 Line of Pits. Lt. De osits. 315.5 10012 0 0 0 0 2.71 3.5" Camco D Ni le 315.6 10013 0.05 0.09 34 4 2.77 PUD Isolated Pittin De osits. 315.7 10021 0 0 1 0 0 3.54 WLEG Penetration Body Metal Loss Body Page 7 == = CASED HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing:_ 3.5 in. 9.3 ppf L-80 EUE Cross-sectional Illustration Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext. No. 10011398 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Cross Section for Joint 315.4 at depth 10,007.930 ft. Tool speed = 48 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 64° 1 Finger = 17 Penetration = 0.105 in. Line of Pits 0.11 in. = 41% Wall Penetration HIGH SIDE = UP CASED == = I HOLE Cross-sectional Illustration Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3ppf L-80 EUE Analyst: Waldrop Cross Section for Joint 315.6 at depth 10,015.480 ft. Tool speed = 49 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 96% - - Tool deviation = 66° ` i i 1 i Finger = 18 Penetration = 0.086 in. Isolated Pitting 0.09 in. = 34% Wall Penetration HIGH SIDE = UP DI CASE D HOLE == _ Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubi_ _ _3.5 in. 9.3 ppf L-80 EUE Cross-sectional Illustration Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext. No. 10011398 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Cross Section for Joint 315.6 at depth 10,020.770 ft. Tool speed = 48 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 99% Tool deviation = 66° Minimum I.D. = 2.766 in. Deposits Minimum I.D. = 2.77 in. HIGH SIDE = UP r" Minimum I.D. = 2.766 in. Deposits Minimum I.D. = 2.77 in. HIGH SIDE = UP == = CASED HOLE Minimum Diameter Profile Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 6.276 inches Minimum Measured Diameters (in.) 1.75 2 3 4 5 6 1 2 3 4 y 5 E 0 Z c O 6 7 8 9 10 10,022 10,046 10,089 10,132 10,150 _c 10,172 s a v 10,214 10,256 10,297 10,337 CASED HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Pipe 7 in. 26 ppf J_55 BTC Pipe Nom.OD Weight Grade & Thread 7 in. - 26 ppf -55 BTC Penetration (% wall) 10 - —� g - - - - 6 - ---4- i 2 - 1- - 0 Body Region Analysis Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext. No. 10011398 Tool Size: 1.69 inches No. of Fingers: 24 Angst: Waldrop Nom.ID Top Depth Bottom Depth 6.276 in. 10,022 ft. 10,369 ft. Damage Profile (% wall) �+ Penetration body Metal loss body 0 50 100 2 3 4 Perforations 0 to 20 to 40 to over 20% 40% 85% 85% - -( -� Number ofjoints analy zed total 2 1 1 0 Damage Configuration (body) 10 I 7 6 -- i 8 4 �. - -- 2 - -- - 0 - 10 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole - Number of onts da� a ed total - 4 ISI � 0 0 0 I, Bottom of Survey = 10 Perforations CASED HOLE Joint Tabulation Sheet Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 7 in. 26 ppf J-55 BTC Casing Nom. ID Body Wall Top Depth 6.276 in. 0.362 in. 10,022 ft. Bottom Depth 10,369 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 1 10022 0 0.09 24 6 6.13 Isolated Pitting Lt. Deposits. 2 10046 0 0.16 43 5 6.09 Line of Pits. Lt. De osits. 3 10089 0.20 0.41 100 1 12 5.80 Perforations Oval Deformation. 4 10132 0.15 0.18 50 7 6.06 Marker loint Perforations Lt. Deposits. 5 10150 0.12 0.29 79 4 6.07 Marker Joint Perforations Lt. Deposits. 6 10172 0.07 0.21 57 8 5.97 Perforations Lt. Deposits. 7 10214 0.47 0.48 100 34 5.93 Perforations Lt. Deposits. 8 10256 0.20 0.45 100 14 5.90 Perforations De osits. 9 10297 0.07 0.07 19 4 5.91 Shallow Line Corrosion. Lt. Deposits. 10 10337 0 0.06 17 2 5.75 Shallow Pitting. HeavyDe osits. 'Penetration Perforations Metal Loss Perforations Page 1 Penetration Body Metal Loss Body ICASED HALE Cross-sectional Illustration Well: 2M-21 Survey Date: October 7, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubm&: 7 in. 26 ppf J-55 BTC Analyst: Waldrop Cross Section for Joint 2 at depth 10,066.770 ft. Tool speed = 49 Nominal ID = 6.276 Nominal OD = 7 / — — Remaining wall area = 96% Tool deviation = 68° Finger = 22 Penetration = 0.156 in. Line of Pits 0.16 in. = 43% Wall Penetration HIGH SIDE = UP !CASED HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 7 in. 26 ppf J-55 BTC Cross-sectional Illustration Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext. No. 10011398 Tool Size: 1.69 inches No. of Fingers: 24 Anaa�st: Waldrop Cross Section for Joint 1 at depth 10,030.629 ft. Tool speed = 48 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 94% Tool deviation = 66° Finger = 18 Penetration = 0.087 in. Isolated Pitting 0.09 in. = 24% Wall Penetration HIGH SIDE = UP Cross-sectional Illustration Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext, No. 10011398 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Cross Section for Joint 10 at depth 10,340.129 ft. Tool speed = 50 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 100% Tool deviation = 67° CASED HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Tubing_ 7 in. 26 ppf J-55 BTC Cross-sectional Illustration Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext, No. 10011398 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Waldrop Cross Section for Joint 10 at depth 10,340.129 ft. Tool speed = 50 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 100% Tool deviation = 67° CASED HOLE Well: 2M-21 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA L Tubing_ 7 in. 26ppf J -55 -BTC Cross-sectional Illustration Survey Date: October 7, 2019 Tool Type: UW MFC 24 Ext. No. 10011398 Tool Size: 1.69 No. of Fingers: 24 Analyst-.________ Waldrop Cross Section for Joint 3 at depth 10,119.329 Tool speed= 50 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = N/A Tool deviation = 69° Minimum I.D. = 5.802 in. Oval Deformation Minimum I.D. = 5.80 in. HIGH SIDE = UP r Minimum I.D. = 5.802 in. Oval Deformation Minimum I.D. = 5.80 in. HIGH SIDE = UP ConocoPhillips Alaska, Inc. V Drilling & Wells ConocoPhillips Coiled Tubing Drilling Alaska 2M-21 PDC Log ---------------- -------- Geo vb[ t ------------------ --------------------- ----- -- ----------------------- ---------_-- -- -------- ---------- -------s391�5 _ -9950- 9975- - ----------------- --- ----- t iflOflO- M011 --10400-. L - October 3, 2019 2M-21 Pre -CTD Procedure Page 4 of 5 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-21 Permit to Drill Number: 191-129 Sundry Number: 319-459 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �r Je m . Price Chair DATED this 9 day of October, 2019. ABDMS� OCT 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED OCT 0 8 2019 AOGM 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CO261 B Whipstock Q . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. 1 Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 191-129 r 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 r 50-103-20156-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2M-21 0 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (L ase Number): ADr_ooz56 APLooZ55y 10. Field/Pool(s): , Ku aruk River Field / Kuparuk River Oil Pool 11. 013hq 01gPRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,599 6119 10,599 6119 3523 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 84' 16" 123' 123' Surface 3877' 9-5/8" 3926' 2825' Tie -Back String 1753' 7" 1797' 1703' Production 10,555' 7" 10,599' 6119' Perforation Depth MD(ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,109' - 10,150' 5892'- 5911' 10.170'- 10,292' 5921'- 5977' 3-1/2" J-55 10,029' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): FHL Packer, Otis Retrievable Packer 9916'/ 5804', 10,004'/ 5845' 12. Attachments: Proposal Summary 0 Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development .r❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 14 -Oct -19 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane. Germann COP.Corn Contact Phone: 907-263-4597 16'Qi Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: El Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: '50P rfrj y J'Z' 40'7 o y s / / %r6 i' i✓ln t�r p rY55vrC �o Z 5d O U A-1 n v/etr /pi Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: /O _ -{ 04 3BDMS &/OCT 10 2019 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: )0 /� I VTL /0 8l/9 -A' /1 1 Fq -adze is MQ4{�l pprbved application is rang R1I f )tls4RRe ate of approval. Submit Form and chments in Duplicate Ci�tta I okh- ( ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 7, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock to drill two laterals out of the KRU 2M-21 (PTD# 191-129) using the coiled tubing drilling rig, aborts CDR3-AC. CTD operations are scheduled to begin in mid October 2019. The objective will be to drill two laterals, KRU 2M- 21 L1, and 2M-21 L1-01, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variaa from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length f the parent lateral instead of being limited to 500' from the original point. nLw PrD Attached to the sundry application are the following documents: — Sundry Application Form (10-403) for 2M-21 — Operations Summary in support of the 10-403 Sundry Application — Current Wellbore Schematic — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 2M-21 (PTD: 191-129) CTD Summary for Sundry Summary of Operations: KRU well 2M-21 is a Kuparuk A/C -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C -sands to the north and south of 2M-21. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 10,120' MD. The 2M-21 L1 lateral will exit through the 7" casing at 10,120' MD and drill to a planned TD at 15,500' MD, targeting the C sand to the south. The lateral will be completed with 2-3/8" slotted liner from TO up to 10,300' MD with an aluminum billet for kicking off. The 2M-21 L1-01 lateral will kick off at 10,300' MD and drill to a planned TD of 14,500' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,010' MD with a deployment sleeve. CTD Drill and Complete 2M-21 Laterals: Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered. Y1 4. RU E -Line: Set top of high expansion wedge at 10,120' MD 5. Prep site for Nabors CDR3-AC. Ria Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2M-21 L1 Lateral (C sand -South) a. Mill 2.80" window at 10,120' MD. b. Drill i-cen er lateral to TD of 15,500' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 10,300' MD. 3. 2M-21 L1-01 Lateral (C sand -North) nr{,vt7 a. Kickoff of the aluminum billet at 10,300' MD. b. Drill 3" bi-center lateral to TD of 14,500' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 10,010' MD. 4. Obtain SBHP, freeze protect, ND BOPS, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Page 1 of 1 10/7/2019 00 --- 7-- !i =\ m §\ } \{ \ { 00 --- 7-- !i =\ m Loepp, Victoria T (CED) From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, October 8, 2019 1:47 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 2M-21(PTD 191-129, Sundry 319-459) BOP test pressure Victoria, MPSP for this well is 3523 psi (based on max formation pressure in the area of 4113 psi in 2A-06 and gas gradient of 0.1 psi/ft). Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4000 psi. Annular preventer will be tested to 250 psi and 2500 psi. Thanks, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, October 8, 2019 1:39 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNAL]KRU 2M-21(PTD 191-129, Sundry 319-459) BOP test pressure Shane, What is the BOP test pressure for KRU 2M-21 laterals? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(c)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or VictoCia.Loer)ip@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED ADD 1 7n,; -n 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q 0 at'�pV4 ttlpwn El Performed: Suspend E] Perforate ❑ Other Stimulate E] Alter Casing [� Change Approved Program ❑ Plug for Redrill ❑ perforate New Pool ❑ Repair Well Q Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 191-129 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20156-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2M-21 ADL 25640 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field / Kuparuk River Oil Pool 1 I. Present Well Condition Summary: Total Depth measured 10,599 feet Plugs measured None feet true vertical 6,119 feet Junk measured None feet Effective Depth measured 10,599 feet Packer measured 9916, 10004 feet true vertical 6,119 feet true vertical 5804, 5845 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 feet 16 123' MD 123' TVD SURFACE 3,877 feet 9 5/8 " 3,926' MD 2825' TVD E -BACK STRING 1,753 feet 7 " 1,797' MD 1703' TVD PRODUCTION 10,555 feet 7 10,599' MD 6119' TVD Perforation depth: Measured depth: 10109.10124.10135.10150.10170.10179.10195 -10212,10232-10252,10252-10272,10272-10292 feet True Vertical depth: 5893.5900 5905.5912 5921.5925 5932.5940 5949.5959 5959.5968 5968.5977 feet Tubing (size, grade, measured and true vertical depth) 3.5" J-55 10,029' MD 5,856' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL PACKER 9,916' MD 5,804' TVD PACKER - OTIS HVT RETRBLE PACKER 10,004' MD 5,845' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA 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: 150 400 900 1030 1 235 Subsequent to operation: 115 46 1200 1275 220 14. Attachments (required per 2D AAC 25.070, 25.071, a 25.293) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O 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: 381-481 Contact Name: Ron Phillips Authorized Name: Ron Phillips C ContactEmail: Ron.L.PhilIips@cop.com Authorized Title: Sr. Wells Engineer Authorized Signature: Date: {,J Contact Phone: (907) 265-6312 / %� O/9 �/6 9 RBDM51f�i✓APR 18 7019 KUP PROD WELLNAME 211 WELLBORE 2M-21 1• �' ' WNI Attributes Max Angle S MD TD �AhOCO�)��)p5 FIeMName WpllOpl¢pPYN51 WellWmafaWs ril(°) N.RG1 pct E. nine) Alaska. InC. IKDPARUK RIVER UNIT I5010320156G) PROn T1 oIRR nn In IrA M-21, YIHGGH it'1]:10 PM Last Tag Vc'bal °cIY^uY (MW) AnndedOn GepM pros)End Date 'T IsslnloE By ._ Last Tag; RKB IESLBJRalhole) 103]6.6 71812016 214-21 Izerabaej Last Rev Reason HANGER, 39.0 pnnodlion End Oale I Wellbore IaN Matl By Rev Reason GLVRD 32812019 2.-21 laappleh Casing Strings Cash, nesnrl,unn OD(1n)ID (in) Top 14X91 9N Gep1M1 IXNBI Sel GepiM1 IND1... WYLm 11... G/Me Top Tp,eaO CONDUCTOR 16 15.06 390 1230 123.0 62.58 H40 WELDED rasing Dasnrlplbn oO(n) ID (in) Top61KB) Bel DepM (XKsh iN D.Ph, IND)... WRE. p... Grata Top Threatl SURFACE 9516 8.92 488 3,92fi.0 2,8246 36.00 J-55 BTC cas no description 00 (in) ID(in) Top(IINBI Set DepM IIMB) SN Mp1a (NDL_ WpLm p... Gude Top TM1reaE TIE BACK STRING ) 6.28 440 1,]9].3 1,]02.8 26.00 L-86 Hyd563 Ceabq Dnviption Go (in, .(int Top Me) the Depth Me) aHDepNIN0)...YFLE, 6... Oral Top Th"'d PRODUCTION 7 628 44.0 10,599.0 6,119.0 2606 J-55 BTC CONDUCTOR; V 0 -IMO Tubing Strings OF TIRO Amus Fad-DYr: YSa Tubing oarlbon IS Ma... lDlinl Top lnKsl sM GepM In..SM depth (TVD) I... WlhbdN G,aee ropconnnwn TUBING 2019 3112 '2 38.8 9,988.] 5.83].5 9.30 L80 EUE Completion Details "o saram9 Top HIVE) Top incl Nominal Top prial MKB) 1°) goonan Cam 10 (in) 388 3.8 4107 HANGER FMC GenTubing Hanger wl dbl pinalp T77- EUE -land 2902 the NEeAOKBTNI.G go- eta 9,9023 5,7979 6290 SEAL ASSY Baker 312' PER EUE 3,000 9,916.0 5,8042 6285 PACKER Baker7'x311TFHLPaCker EUE -292 9937S 5,814.1 6277 NIPPLE HET3 TO x 2.81r X Nipple with R lug installed (SN 5844. 2,813 6) GAsurT,3330.1 99877 5,8370 62.56 ILOCATOR OTIS Locator spaced out ll' above PER 3.000 1.1,6 Description Strl,p Ma... IG SI Top MKBI Sal DepM M.. SN DepM ITVGI I--WIIIb1X Gra4e Tnp Gonnedion TUBING ORIGINAL 541 2.97 9,988.6 10.029.] 5856.4 Completion Details Top' Ird Top mA Nominal BUNFACE, eeaaa2so iop(nxe) 014411 (°I Nem Des Goes 'Olin) 9,988,6 5,8375 62.56 PBR OTIS 10 STROKE PER .14' SEAL BORE2.9]0 10,004.3 5.8443 62.54 PACKER OTIS HNT RETRIEVABLE PACKER 3250 10,09.] 5.851.8 62.55 NIPPLE -D CAMCO D NIPPLE Gas un; Epv.e ,.,H0._5EATSUL100291 58561 6256 WLEG TI R6E(SHEARED), IIJAHJ I I L2.8]5 An., Rod -s.bboughke' 10021' PER SWS PERF (10111199) Z,75"Ase.rarab Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) GIS LIFT, 78gg,8 pINopncl To@KB)O) T Top lUN l°Il Dn Can Run Dah IO (Int 708.0 ]05.6 9. LEAN U FACE4A IA D WITH CEMENT 31141111 9 ] GAs uFr; e.aTe Perforations &Signs Shot Gen Topa) son M(B) Top(NG) (nKB) Btm (ND) 11"I LIblan a DMe lano6m ) Type Com .UFT:&ens 10,109.0 10,124.0 5 .9 5,899.8 C4,2M-21 10/1111999 40 APERF deg. ph, no oranted sEu4ssr:e.eoz.3 PACKER: e.Meo 10,1350 10,150.0 5, 5,911.8 74° 2M-21 31112000 40 APERF ,b'HSD PJ 60 deg ph 10,170.0 10,1]90 5,921. 5,925.1 A-3, 2M-21 7192013 6.0 APERF L A D, PHASED 60 DEGREES NIPPLE e.wTe 10,195.0 10,212.0 5932.5 5,NO3 A-3, 2M-21 &282013 6.0 APERF N, E PHASING, 102 SHOT TOTAL 10,2320 10,252.0 59495 5,958.7 A -,2M41 10029/1992 401PERF rr7og ffida Tffd.g. ph', LOCATOR'. %W7 Oriente 1179 deg. ph 182520 10,2720 5,9583 5,9679 A-3,21421 102001992 4.0 IPERF 14S Cap Gun, 180 deg. ph; Oriented 169 deg. ph PBR:a.8Pd.8 PACKER; 1o.mla 10,272.0 1 10,292.0 5, 7.9 5977.1 A .2M-21 1002&1992 4.0 IPERFsg un, deg. ph Odemed 176deg, ph NIPPLE -D:10.0187 Frac Summary WLEG: 10.tlA.1 Su,t Dale Proppenl Ceagnetl(Ibl Prapynlln forintlun lib) 0111$(101 SIgY osa,l OaR Top Daptb IXKE4 Bwibrig Link MFIUHSpum VOICNan lbbp VOISIurry(bM) 1 &12001 10,109.0 10,1500 Mandrel Inserts st APERF,t FWxi 10.Ib0 FRAC;10.1W0 mn op,,g Valve IJtM1 Pont. 7("I) K To Type (In) (peg RunCom (2,49 Make MOM' 0d gj1112 Sen APERF, 1o,tas.bm.lxio 3(330. LVTyp 1 3,3304 2,493.3 Camco MMG i ill GAB LIFT LV qK 0.188 $11.0 31282019 '1' 6,00).8 3,899.3 Camco MMG 112 G45 LIFT GLV RK 0.108 1,211.p 31282019 7,862.8 4,8439 Camco MMG 1112 GASLIFT OV RK 0.250 0.0 32812019 d 90118 5,405.3 Camco MMG 1 1112 GASLIFT JUMY RK3118/2019 5 9,873.9 5,]85.0 Camco MMU 1112 GASLIFT DMY RK 311812019 APERF; tat]aP10.178.0_ I Notes: General & Safety CEno page Annotation PPERF 10,165 .61113120 1 1124'201] NOTE: SCLD(FAILED-SC LEAK @708'). t2rzO20D NOTE: LEAK FOUNDV]505'-Little 411112019 NOTE: View ScnemgliCw/Alaska Schemaflc10.0 PERF: loMO-10.251.0 PERF', ta292.p-KMO� FERF', f0,.s3 IQagO_ ro..JCTGN,1 ]9s.0 HRAGE Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time End Time our (hr) Phase Op code AdWlry Code Time P -T -X Operation start Depth (aKB) End Depth (RKB) 3/1/2019 3/2/2019 17.00 MIRU MOVE MOB P Pull pits away from substructure, 07:00 00:00 stage same. Remove dg mats. Roll up herculite. Bundle up blocks, lower cattle chute. Lay down derrick. RDMO from 2T-218 5.7mi to 2M pad. 3/2/2019 3/2/2019 18.00 MIRU MOVE MOB P Rig arrived on location at 00:00 18:00 approximately 00:00 hours. Install plywood around cellar and wheel rooms for walkways. Install Herculite secondary containment. Back rig over 210-21; witnessed by company representative. Install mats. Spot pit complex to sub. Spot and set up cuttings pits tank. Connect steam lines, hoses and pit interconnects. Berm around dg. Spot smoke shack, mud shack. Prep cellar and tie in hard line for kill well operations. Spot tiger tanks, choke house and rig up hard line. Take on fluid in pits to prepare 9.1 ppg NaCl kill weight fluid. Note: Rig accepted at 18:00 hours. 3/2/2019 3/212019 5.00 MIRU WELCTL RURD P Rig up tree to squeeze manifold/tiger 18:00 23:00 tank in cellar to kill well. Complete berming. 3/2/2019 3/3/2019 1.00 MIRU WELCTL MPSP P PU and make up lubricator to pull 23:00 00:00 BPV. 3/3/2019 3/32019 1.00 MIRU WELCTL MPSP P PT lubricator. Pull BPV. TWO 00:00 01:00 1001200/100 Close master, Bleed pressure, RD lubricator. PT lines to Tiger tank with fresh water, blow down with air. 3/3/2019 3/3/2019 3.50 MIRU WELCTL OWFF P Take on 9.1 ppg KWF to pits. Open 01:00 04:30 tubing up to tiger tank, bled off immediately, no flow. Opened up IA to tiger tank, bled off immediately, no flow. Observe well 15min, no flow. 3/3/2019 3/3/2019 2.50 MIRU WELCTL KLWL P Circulate 9.lppg KWF down tubing up 04:30 07:00 IA ramp up to 5bpm, taking returns to the tiger tank. Total volume pumped 518 bbls, approximately 518 bbls returned. Mud weight out 8.7ppg. 3/3/2019 313/2019 2.50 MIRU WELCTL KLWL P Shut down pumps and shut in well to 07:00 09:30 build volume. Monitor IA and Tubing pressure. IA pressure 100 psi. Build 9.1 ppg KWF. 3/3/2019 3/3/2019 2.00 MIRU WELCTL KLWL P Pump an additional 130 bbis of 9.1 09:30 11:30 ppg KWF at 4 bpm at 580 psi. 9.1 ppg MW in and 9.1 ppg MW out. Shut down mud pump and monitor well. Tubing static, IA u -tubing fluid. Bleed off IA to tiger tank. Both tubing and IA static. Blow down all lines and rig down lines. 3/32019 3/312019 0.50 MIRU WHDBOP MPSP P Pick up T -bar and make up'ISR BPV. 11:30 12:00 Install BPV. Prepare to ND production tree. 3/3/2019 3/32019 2.50 MIRU WHDBOP NUND P Nipple down production tree. Inspect 12:00 14:30 tubing hanger threads 3.5in 8rd. Threads good. Screw in blanking plug. 3/3/2019 3/3/2019 4.50 MIRU WHDBOP NUND P Nipple up 13-5/8" BOP, adaptor spool 14:30 19:00 and assoicated lines and equipment. Page 1111 Report Printed: 3/19/2019 s Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Stan Time End Time Our (hr) Phase Op Cade Activity Cade Time P -T -X Operation MG) End Depth (fe(e) 3/3/2019 3/4/2019 5.00 MIRU WHDBOP OTHR P Open all doors on BOP stack and 19:00 00:00 perform in between well maintenance. 3/4/2019 3/4/2019 1.50 MIRU WHDBOP OTHR P Complete in -between -wells BOP 00:00 01:30 maintenance. Install riser. Fill test lines to purge air in preparation to test BOPE. 3/4/2019 3/4/2019 6.00 MIRU WHDBOP BOPE P Test BOPE 250psi low, 2500psi high 01:30 07:30 with 3-1/2" test joint. Pressure test Blind rams, Upper pipe rams, lower pipe rams, and annular. Pressure test choke manifold, HCR valves/ line, and kill line. Test witnessed by AOGCC inspector Austin McLeod. 3/4/2019 3/4/2019 1.50 MIRU WHDBOP RURD P Lay down test tool. Rig down test 07:30 09:00 hoses. Pull test dart and lay down test joint. Blow down choke manifold, choke and kill lines. 3/4/2019 3/4/2019 1.00 COMPZN RPCOMP RURD P Rig up tubing tongs. Install 3 1/2" 09:00 10:00 elevators. Make up TIW and crossover. Rig up spooler for control line. 3/4/2019 3/4/2019 0.50 COMPZN RPCOMP MPSP P Pull'ISA' BPV. Make up 31/2" EUE 10:00 10:30 landing joint. Pull hanger free wth 120k string weight. Pull tubing hanger Vo dg Floor with 100k. 3/4/2019 3/4/2019 1.50 COMPZN RPCOMP CIRC P Circulate bottoms up at 5 bpm and 10:30 12:00 345 psi. Until well clean. Continue rigging up tubing equipment in preparation to pull 3 1/2" completion string. 3/4/2019 3/4/2019 6.00 COMPZN RPCOMP PULL P POOH with 3 1/2" completion string 12:00 1800 F/9966' T/8261'. No issue pulling SSSV (OD 5.25") through suspected casing restriction at 1000'. Continue POOH spooling SSSV control line and removing clamps. While pulling out of hole observed rapid increase in overpull, SSSV stuck in wellhead. Drain stack and visually confirm SSSV stuck in well head. A total of 28 clamps were ran on original completion, 21 clamps recovered. 3/4/2019 3/4/2019 5.00 COMPZN RPCOMP WAIT P Discuss plan with town and service 18:00 23:00 companies. Round up tools. Service rig while waiting on Eline unit. 3/4/2019 3/5/2019 1.00 COMPZN RPCOMP RURD P Rig up AK Eline. 23:00 0000 3/5/2019 3/5/2019 3.00 COMPZN RPCOMP ELNE P RU AK Eline, pull SSSV hold open 00:00 03:00 sleeve. RU to control line. Drift SSSV, operate control line, see some pressure on cable but still able to drift. 3/5/2019 3/5/2019 5.00 COMPZN RPCOMP MPSP P Eline PU Baker 2.5" OD inflatable 03:00 08:00 bridge plug, RIH tag on tubing cut at 9966' PU to 9910' and set IBP, 1.5 hour to inflate. 3/5/2019 3/5/2019 1.50 COMPZN RPCOMP RURD P POOH with E -line. Rig down sheave 08:00 09:30 and tools in preparation to pressure test IBP. 3/5/2019 3/5/2019 1.50 COMPZN RPCOMP RURD P Rig up test equipment to stump, 09:30 11:00 approximately 20' in air. Pressure test 2.5" IBP to 1500 psi for 10 mins and chart. Test good. Rig down testing equipment and blow down the same. Page 2111 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 1 2M-21 .. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depm start Time Erb Time Dur (hr) phase Op coEe Ac viry Code Tim. P -T -X Opeiatlon (kKe) HM DepN (flKB) 3/5/2019 3/5/2019 1.00 COMPZN RPCOMP RURD P Rig up E -line sheave. Pick up tool 11:00 12:00 string and make up second 2.5" IBP. 3/5/2019 3/512019 4.00 COMPZN RPCOMP MPSP P RIH tag first IBP at 9910' and PU 20' 12:00 16:00 and set second 2.5" IBP at approximately 9890' WLM. Approximately 1.5 hours to set when on depth. POOH with E -line. 3/5/2019 3/5/2019 0.50 COMPZN RPCOMP RURD P Rig down E -line sheave and 16:00 16:30 1 1 1 equipment. 3/5/2019 3/5/2019 5.00 COMPZN RPCOMP OTHR P Cut 20' stump in the rotary table to 16:30 21:30 working height of approximately 4'. Dump 3" of sand down tubing and allow to fall and settle on 2.5" IBP set at 9890' WLM. Unable to dump sand down 3.5" tubing due to restriction in tubing Pack off and Clean out w/ 10' ConduitSlacks to clean out sand plug 50' 3/5/2019 3/6/2019 2.50 COMPZN RPCOMP NUND P Nipple down BOP stack. Hoist slack 21:30 00:00 with bridge crane and utilize Wachs cutter to cut 3.5" tubing about the tubing head.Remove 3.5" tubing from the BOP. Rack back BOP,Remove adaptor flanges and .PIU Baker Over shot and latch on stub for Secure Tubing 3/6/2019 3/6/2019 1.50 COMPZN RPCOMP NUND P Continue nippling down Well head. 00:00 01:30 Remove DSA, 7 1/16" x 11" adapter flange, and both IA valves off tubing head. Pick up 1 -joint of 3 1/2" drill pipe and overshot. Engage overshot to 3 1/2" tubing stub above tubing head and secure string. 3/6/2019 3/6/2019 5.50 COMPZN RPCOMP CUTP P Rig up HydraTight equipment to tubing 01:30 07:00 head and casing head. Perform HydraTight 7" casing growth as per procedure. Perform 21 growth cycles for a total of 14.5" of casing growth. Leave HydraTight equipment rigged up and monitor casing for residual growth. No residual growth observed. Rig down HydraTight equipment. 3/6/2019 3/6/2019 3.50 COMPZN RPCOMP NUND P Make up top drive to 3 1/2" drill pipe 07:00 10:30 stump and pick up string to neutral (901k). Prepare to cut 7" casing and free tubing spool. Cut 7" casing with wachs cutter. Secure tubing head with air hoist tugger. Pick up on tubing head with overshot, exposing 3 1/2" tubing below tubing head. Install C - plate on top of 7" casing and install airslips. Slack off and engage airslips. Release overshot and pull back to rig floor through rotary and lay down. Cut the 3 1/2" tubing below well head leaving approximately 4' stump. Lay down tubing head and stuck SSSV. Engage overshot on to 3 1/2" tubing, pick up removing C -plate and airslips. Pull 3 1/2" tubing through the rotary and set slips and secure 3 1/2" tubing on the rig floor. Back out cut joint. 3/6/2019 3/6/2019 0.50 COMPZN RPCOMP PACK P Pick up Storm Packer and make up to 10:30 11:00 3 1/2" stump. Set storm packer in the 7" casing hanging off 3 1/2" drill pipe at approximately 100'. Page 3111 Report Printed: 311912019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Tme End Time our (hr) Phase op code MAY Cade Time P -T -x Dperafton Stant Depth (fiKB) End Depei (fiKB) 3/6/2019 3/6/2019 3.50 COMPZN RPCOMP CUTP P Pick up single of 3 1/2" drill pipe and 11:00 14:30 7" spear. RIH and spear top of casing in well head. Engage spear and stretch casing with 200k on weight indicator. Casing stretch an additional 13 3/4". Set casing slips in casing head with 75k in tension. Disengage 7" casing spear and pull to Floor and lay down. Note: Hydra -Fight Casing Growth - 14.5" Spear stretch - 13.75" Total Stretch - 28.25" 3/6/2019 3/6/2019 3.50 COMPZN RPCOMP NUND P Install 7" pack off and 11" 3m x 11" 5 14:30 18:00 tubing head. Test tubing head and pack off to3000 psi for 10 mins. Test good. 3/6/2019 3/62019 3.50 COMPZN RPCOMP NUND P NIU BOP and Adaptor flange Install 18:00 21:30 Wear Ring bushing 3/6/2019 3/6/2019 0.50 COMPZN RPCOMP BOPE P R/U to Test 7" X 13 3/8" Flange T/ 21:30 22:00 250/250OPSI 3/6/2019 3/6/2019 1.50 COMPZN RPCOMP BHAH P PIU Baker Overshot RIH 100' and 22:00 23:30 Latch up on Baker Storm Packer Release PKR POOH and UD same and R/U to UD 3/6/2019 3/7/2019 0.50 COMPZN RPCOMP PULD P Continue UD 3 1/2" 9.3# J-55 ABM - 23:30 00:00 EUE IPC Tubing 3/7/2019 3/7/2019 14.00 COMPZN RPCOMP PULD P Continue UD 3 1/2" 9.3# J-55 ABM - 00:00 14:00 EUE IPC Tubing from 8169' to 832'. While POOH pulled approximately 5k over string weight at 832'. GLM #8 OD 5.75" pulled into restriction at approximately 795' as per original completion tall. Screw in top drive and attempt to go down. Unable to go back down. Pump bottoms up at 224 gpm at 107 psi, observed sand at shakers. Pick up 1 joint of 3 1/2" tubing and make up to stump and wash down to 856'. Mix hi -Vis pill and pump down tubing. As hi -vs pill exited tubing and turned the corner pull tubing through casing restriction. Continue POOH one stand of tubing and rack back. POOH to surface laying down all jewelry. Upon POOH to surface observed 3 12" tubing was not cut. Recoverd locator and sealbore assembly, pulled out of PBR. Run 1 stand of 3 1/2" tubing back in hole and break down while POOH. 3/7/2019 3/7/2019 1.00 COMPZN RPCOMP RURD P Clean and Gear dg floor. Rig down 14:00 15:00 tubing tongs. 3/7/2019 3/7/2019 1.50 COMPZN WELLPR RURD P PJSM with rig crew and SLB E -line 15:00 16:30 crew. Rig up SLB E -line equipment. 3/7/2019 3/82019 7.50 COMPZN WELLPR ELOG P RIH with 40 arm caliper to 3500' 16:30 00:00 WLMD and log to surface. Lay down caliper tools and pick up CBL tools. RIH and perform CBL log from 3500' WLMD. Send data to town to process. 3/8/2019 3/8/2019 2.50 COMPZN WELLPR ELOG P Continue Logging W/ SLB F/ 3500'w/ 00:00 02:30 1 1 1 1 1 1 caliper tool U suface Page 4/11 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time EM TimeDur thatPhasa Op Code ANvity Cade rime P-T-X Operation Stan Depth (MR) End Depth (ftKa) 3/8/2019 3/812019 1.00 COMPZN WELLPR ELOG P RID SLB E-line unit and send data to 02:30 03:30 engineers in town 3/8/2019 3/8/2019 2.50 COMPZN WELLPR GRVL P P/U 4 1/2" Joint and RIH Below Wear 03:30 06:00 ring bushing and Dump 50' sand on top of plug @ 8990'. Rig up circulating iron to OA in preparation to circulate out arctic pack. 3/8/2019 3/8/2019 3.50 PROD1 CSGRCY SHAH P P/U and M/U Baker Mechanical 06:00 09:30 cutter. RIH picking up singles of 3 1/2" HT 38 Drill pipe to 1795'. Cut 7" casing at 1795' md. While cutting 7" casing observed decrease in torque, positive indication casing is cut. 3/8/2019 3/8/2019 7.00 PROD1 CSGRCY CIRC P Close annular after 7" casing cut. 09:30 16:30 Pump 50 bbls of hot diesel down drill string taking arctic pack returns out the OA to tiger tanks. Pump rate 1.3 bpm at 450 psi. Chase diesel with 15 bbls to clear drill string volume of diesel. Allow diesel to soak for 1 hour. Pump heated 9.1 ppg brine to displace diesel from the 9 5/8" x 7" OA. Circulate until 9.1 ppg fluid weight observed. 3/8/2019 3/8/2019 1.50 PRODI CSGRCY TRIP P POOH and Stand Back 3 112" HT 38 16:30 18:00 j Drill pipe and LID Baker Cutter 3/8/2019 3/9/2019 6.00 PROD1 CASING NUND P N/D BOP and set Back Stack,remove 18:00 00:00 Tubing Head spool and Pack off,M/U baker spear Pull 7" casing up, Remove slips B.0 7"casing stub and RIH Drop oft 7" casing below Well head spool POH w/ Baker spear LID same Install test Plug 3/9/2019 3/9/2019 5.50 PROD1 CASING NUND P N/U BOP, Double studded adapter 00:00 05:30 flange IV 3K 13 5/8" 5K. Change out 2 7/8" X 5" VBR's and install 7" Wipe Rams. 3/9/2019 3/912019 1.50 PROD1 CASING RURD P Pick up BOP test plug and set in well 05:30 07:00 head. R/U Test Equipment and hoses. Pick up 7" lest joint. Fill stack and purge air. 3/9/2019 3/9/2019 0.50 PROD1 CASING BOPS P Test 7" rams, DSA and well head 07:00 07:30 connection to 250/2500 PSI 5 mins each. Chart pressure test. 3/9/2019 3/9/2019 1.50 PROD1 CASING RURD P Rig down testing equipment, hoses 07:30 09:00 and side entry sub. Make up crossover to joint of drill pipe and pull test plug. Lay Down the same. 3/9/2019 3/912019 2.00 PROD? CASING OTHR P Make up running tool and set wear 09:00 11:00 bushing in well head. Lay down running tool. Observed diesel migrating in BOP stack. Drain diesel from stack and fill hole and observe. Diesel migrating to surface. Fluid swapping. Continue to drain stack and observe until no more diesel. 3/9/2019 3/9/2019 1.00 PROD1 CASING PULL P RIH with 7" casing spear. Engage 7" 11:00 12:00 casing spear and pull casing to rig floor. Disengage spear. Lay down spear and 2 joints of drill pipe. Rig up rasing elevators and make up well control safety valve. Page 5/71 ReportPrinted: 3/19/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Depth start Tine, End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operatics (!K5) End Depth (fi(e) 3/9/2019 3/9/2019 4.00 PROD1 CASING PULL P Pull 7" casing from approximately 12:00 16:00 1768'. First joint pulled, pulling light approximately 135k string weight, normal free weight 721k. Strap and number 7" casing in shed. UD Tot 40 Full joint 2 cut joints 3/9/2019 3/9/2019 1.50 PROD1 CASING BHAH P Clean up Floor R/D GBR casing 16:00 17:30 equipment R/U and M/U Baker BHA# 7 w/ 8 1/8" Rough String Mill w/ D.P 3/9/2019 3/9/2019 4.00 PROD1 CASING TRIP P RIH tag up @ 792' M/U Top drive 17:30 21:30 PUW 47K SOW 47K ROT 45K RPM 60 Tq 4K wash and Ream F/ 791' U 793 Back ream 2X Continue RIH on Elevators and Tag up on Stub @ 1796' w/ D.P 3/9/2019 3/9/2019 1.00 PROD1 CASING CIRC P CBU @ 8 BBIs w 450 psi 2X Blow 21:30 22:30 Down T.D 3/9/2019 3/10/2019 1.50 PROW CASING TRIP P POOH and Stand Back 3 1.2" HT 38 22:30 00:00 Drill pipe M/U BHA# 8Add 8 1/2" mill with the 8 1/4" Rough String Mill 3/10/2019 3/10/2019 4.00 PROW CASING MILL P Continue RIH on Elevators with BHA8 00:00 04:00 w/ Tandem mills Tag up @ 790' M/U Top Drive and Ream F/ 790 T/804' and Back Ream 2X Cont RIH w/ Elevator T/1056'. Milling parameters as follows: 60 rpm, 2 bpm, 50 psi, Tq off-btm 800 fllbs, and Tq on- birth 1200 ft Itis. Up, down and rotating weight 46k. 3/10/2019 3/10/2019 1.00 PROD1 CASING TRIP P POOH from 1057'to surface. Up 04:00 05:00 weight 48k. No issue tripping back through subsidence area at approximately 790 - 805'. 3/10/2019 3/10/2019 3.00 PROD1 CASING MILL P Pick 81/4" and 81/2" tandem string 05:00 08:00 mill and trip in hole from surface to 790'. Wash and ream at 804' with following parameters: 60 rpm, Tq off- btm 870 Nbs, Tq on-bim 1400 ftlbs, 4 bpm, and 70 psi. Work string through subsidence area 3 times. Continue tripping in hole and tag 7" casing stub at 1795'. 3/10/2019 3/10/2019 0.50 PROD1 CASING CIRC P Circulate bottoms up with 7bpm at 350 08:00 08:30 psi. Shut down pump and blow down top drive. Remove blower hose. 3/10/2019 3/10/2019 1.00 PROD1 CASING TRIP P POOH from 1795', racking back drill 08:30 09:30 pipe. 3/10/2019 3/10/2019 1.00 PROD1 CASING BHAH P Lay down 8 1/2" mills and rack back 09:30 10:30 stand of drill collars. Clean and clear rig floor. 3/10/2019 3/10/2019 1.50 PROD1 CASING BHAH P Pick 8 1/2" polish mill shoe and make 10:30 12:00 up 1 stand of 6 1/4" drill collars. 3/10/2019 3/10/2019 2.50 PROD? CASING OTHR P RIH with 3 1/2" drill pipe to dress off 12:00 14:30 top of 7" casing stub at 1795'. While tripping in hole tagged up on subsidence area at approximately 795 with 10k. Able to rotate through spot. Continue in hole to dress off top of 7" casing stub as follows: 2 bpm, 70 psi, 60 rpm and 1600 - 1750k ftibs. Able to drift to 1801' md. Rotate off of 7" casing stump and circulate bottoms up at 7 bpm and 364 psi. Page 6/11 Report Printed: 311912019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth rt start Time End Time Our (hr) Phase OP Code Activity Code TimP-T-X O peration Ke) End Depen (ft(e) 3/10/2019 3/10/2019 0.50 PROD1 CASING TRIP P POOH 1 stand and rack back. Blow 14:30 15:00 down top drive. Remove blower hose. 3/10/2019 3/10/2019 0.50 PROD? CASING SVRG P Perform rig service. Grease top drive, 15:00 15:30 black jack, swivel packing and blocks. 3/10/2019 3/10/2019 2.50 PRODt CASING TRIP P POOH with polish mill assembly. Lay 15:30 1800 down the same. 3/10/2019 3/10/2019 2.50 PROD1 CASING SHAH P Pick up and make up 8 1/2" and 8 3/4" 18:00 20:30 tandem string mill assembly. Make up 1 stand of 6 1/4" drill collars. 3/10/2019 3/10/2019 2.50 PRODt CASING MILL P RIH with tandem string mill assembly 20:30 23:00 on 3 1/2" drill pipe. Tag up 793' wash and ream F/ 793' T/ 802' POW 48K SOW 48K ROT 47K Back ream 3X 3/10/2019 3/10/2019 0.50 PRODi CASING TRIP P Continue with tandem string mill 23:00 23:30 assembly RIH to Top of 7" stub 1795' 3/10/2019 3/11/2019 0.50 PROD? CASING OTHR P CBU @ 8 BBLs min w/ 250 PSI 23:30 00:00 3/11/2019 3/11/2019 1.50 PROD1 CASING TRIP P POOH from 1793'to 108'. Racking 00:00 01:30 1 1 1 back 3 1/2" HT 38 D.P 3/11/2019 3/11/2019 1.50 PRODi CASING BHAH P L/D 381/4" D.C. and Pulled Wear 01:30 03:00 Ring Bushing 3/11/2019 3/11/2019 1.50 PROD1 CASING PUTB P R/U 7" GBR Casing Equipment 03:00 04:30 3/11/2019 3/11/2019 4.00 PROD1 CASING PUTB P M/U 7" Tie-Back Casing w/ Baker poor 04:30 08:30 Boy over shot w/ HES cementer and P/U 7" casing as per tally M/U Tq 9000 fit/ib. Confirm make up torque with GBR torque tum computer. Install centralizers on every otherjoint around rasing collar for a total of 21 centralizers ran. Engage sealing overshot over 7" casing slump at 1796', a total of 2.28' of swallow on 7" casing stump. Up weight 74k, down weight 36k. 3/11/2019 3/11/2019 2.00 PROD1 CEMENT RURD P Rig down GBR rasing equipment. Rig 08:30 10:30 up SLB. Rig up Halliburton Cement head and load plug. Rig up cement line. Rig up return line from OA to tiger tank to take cement returns. 3/11/2019 3/11/2019 0.50 PRODt CEMENT SFTY P Pre-job safety meeting with rig crew, 10:30 11:00 SLB and Halliburton on 7" cement job. Page 7111 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Depth start Time End Time our (hr) Phew op coda Aa fty Code Time P -T -X opembon (ilia) End Depth (WS) 3/11/2019 3/11/2019 1.50 PROD1 CEMENT CMNT P Flush cementing lines and pressure 11:00 12:30 test the same. Pressure test to 4000 psi, test good. Pump fresh water with SLB cementing unit to shift Halliburton cementing staging tool open, tool shifted open at approximately 3400 psi. Continue pumping an additional 5 bbls to verify flow and tool shifted open. Pump cementjob as follows: 10 bbls of 15.7 ppg Neat 60 bbls of 15.7 ppg PressureNet 10 bbls of 15.7 ppg Neat Drop plug followed by 5 bbls of FW Switch to Rig pumps and displace with 63.5 bbls of 9.1 ppg brine final circulating pressure approximately 700 psi, plug pumped on calculated displacement. Continue to pressure up to 1500 psi above final circulating pressure to 2100 psi to shift staging tool closed. Hold 2000 psi on casing for 5 minutes, bleed pressure off, approximately 2 bbls of flow back and then stopped. Stage tool closed. Approximately 10 bbls of cement observed at surface. Cement in place at 12:15 pm. 3/11/2019 3/11/2019 4.00 PRODt CEMENT RURD P Rig down cement head and crossover. 12:30 16:30 Latch elevators on to stump and apply 75k of tension over casing string and block weight. Flush rigs lines and bop slack with citric acid, taking returns to tiger tank. 3/11/2019 3/12/2019 7.50 PRODi WELLPR NUND P Nipple down BOP stack.Set Slips, Cut 16:30 00:00 7" casing off and Polish off top on stub install pack off bushing N/U Tubing spool and Test Pack off T/ 3000 psi 10 mins All good N/U BOP 3/12/2019 3/12/2019 2.00 PROD1 WELLPR NUND P Continue N/U BOP and C/0 7" Rams 00:00 02:00 T/ 3 1/2"x5" VBR. 3/12/2019 3/12/2019 1.00 PROD1 WELLPR BOPE P R/U test Equipment and Test 3 1/2" 02:00 03:00 x5" VBR and Flange 250/2500 5 min each All good R/D test Plug and Install Wear Ring Bushing L/D running Tool 3/12/2019 3/12/2019 2.50 PRODt WELLPR SHAH P M/U B.O.T Clean-out Assembly with 03:00 05:30 1/8 Junk Mill 3/12/2019 3/12/2019 5.50 PROD1 WELLPR MILL P RIH Start washing down and drilling 05:30 11:00 cement F/ 1716'T/ 1780' and drill up plug 1781' The cement retainer would no drill up having issues POH to check Junk Mill 3/12/2019 3/12/2019 1.00 PRODi WELLPR TRIP P POOH and Stand Back BHA#12 4 11:00 12:00 3/4" D.C. 3/12/2019 3/12/2019 1.00 PROD1 WELLPR SHAH P Change out Junk mill to Rock tooth 12:00 13:00 6.125 Bit Junk mill had no issues on face. 3/12/2019 3/12/2019 2.00 PROD1 WELLPR TRIP P RIH w/ BHA#13 wl rock bit and Tag 13:00 15:00 up @ 1782' Page 8111 Report Printed: 3/19/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Stall Time End Time our(m) Phase Op code Activity Code Time P -T -X Operabon (eKB) End Depth (WB) 3/12/2019 3/12/2019 3.00 PROW WELLPR MILL P M/U T.D PUW 60K SOW 58K ROT 15:00 18:00 60K pumping @ 4 bbls min w/ 245 Continue Dilling on Cement retainer @ 1782' U 1784 Back ream F/ 175011 1800 3X 3/12/2019 3/13/2019 6.00 PRODt WELLPR PULD P Continue P/U 3 1/2" HT 38 work string 18:00 00:00 @8226'. 3/13/2019 3/13/2019 2.00 PROD1 WELLPR PULD P Continue P/U 3 1/2" HT 38 work string 00:00 02:00 1 1 1 @ 9849' No sand at that point 3/13/2019 3/13/2019 1.50 PROD1 WELLPR CIRC P PUMP 20 BBLS HI VIS SWEEP AND 02:00 03:30 CHASE W/ 9.1 BRINE @ 9 BBLS MIN W/ 3100.PSI 3/13/2019 3/13/2019 5.50 PROD1 WELLPR TRIP P POOH AND L/D BIT CLEAN OUT 03:30 09:00 BOOT BASKETS 1/2 CUP SMALL ALUMINUM PIECES 3/13/2019 3/13/2019 6.00 PROD1 WELLPR TRIP P M/U BAKER REVERSE JET 09:00 15:00 BASKET W/ BOOT BASKET RIH T/ 9870 TAG UP ON SAND @ 9870' 3/13/2019 3/13/2019 1.50 PROD1 WELLPR WASH P WASH DOWN F/ 9870' T/ 9880' W/ 15:00 16:30 REVERSE BASKET PUW 195K SOW 80K ROT 115K PUMP @ 87 SKS 1175PSI 3/13/2019 3/13/2019 2.50 PROD1 WELLPR TRIP P POOH from 9882' TO 7000' and stand 16:30 19:00 back 3 1/2' HT 38 work string in derric. UPW=195K DNW=80K 3/1312019 3/13/2019 4.00 PROD1 WELLPR SLPC P Slip and curt 461' of drill line. 19:00 23:00 3/13/2019 3/14/2019 1.00 PRODi WELLPR TRIP P Continue to POOH from 7000' to 4427' 23:00 00:00 and stand back work string in derrick. 3/14/2019 3/14/2019 3.00 PRODt WELLPR TRIP P Continue to POOH from 4427' and 00:00 03:00 stand back work string in derrick. UPW=100K. LD BHAand inspect RCJB for debris. Call town engineer and made decision to make another CO run before going after IBP. 3/14/2019 3/14/2019 6.00 PROD1 WELLPR TRIP P MU Second RCJB BHA#15 to make 03:00 09:00 another CO run to top of IBP. Tag up @ 9880' 3/14/2019 3/14/2019 1.00 PROD1 WELLPR WASH P Wash down F/9880' w/ RCJB T/ 9903' 09:00 10:00 PUW 185K SOW 80K Washing down @ 4 bbls min w/ 1250 psi 3/14/2019 3/14/2019 1.00 PROD1 WELLPR CIRC P CBU @ 6 BBLS min w/ 1720 PSI 10:00 11:00 3/14/2019 3/1412019 7.00 PROD1 WELLPR TRIP P POOH and Stand Back 3 1/2" HT 38 11:00 18:00 Drill pipe from 9903'. LD BHA and inspect RCJB for debris. Found 2 large pieces of aluminum, 2 lugs and 4 banding straps. Called town and made decision to make another CO run before going after IBP. 3/14/2019 3/15/2019 6.00 PROD1 WELLPR TRIP P MU Third RCJB BHA#16 and TIH to 18:00 00:00 9873'. UP WT=200K, ON WT=80K. 3/15/2019 3/15/2019 0.50 PROD1 WELLPR TRIP P Continue tripping in hole to 9904'. 00:00 00:30 Wash down to 9910', 5 bpm @ 1300 psi. UP WT=205K, ON WT=80K. 3/15/2019 3/15/2019 1.00 PRODi WELLPR CIRC P Circulate and pump bottoms up at 6 00:30 01:30 bpm @ 2290 psi. 3/15/2019 3/15/2019 4.50 PROD1 WELLPR TRIP P Trip out of hole from 9910'. UP 01:30 06:00 WT=195K, ON WT=80K. L/D RJB Recover 2 small pieces of s.s bands 3/15/2019 3/15/2019 5.00 PROW WELLPR TRIP P M/U BHA# 17 w/ Baker Retrieving 06:00 1100 tool RIH T/9911' Page 9111 ReportPrinted: 3/19/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Tme P-T-x Operetlon (eKB) End Dept(ftK6) 3/15/2019 3/15/2019 3.00 PROD1 WELLPR CIRC P Circulate and pump bottoms up at 3 11:00 14:00 bpm Q 450 psi. pump 40 BBL HI vis sweep Around PUW 215 SOW 80K 3/15/2019 3/15/2019 1.50 PROD1 WELLPR PULL P Latch up on retrievable plug at 9918' 14:00 15:30 and release plug had to work PKR 5k tt 10k over Several time Pull Free could not set back down past latch up. POOH 3/15/2019 3/15/2019 5.50 PROD1 WELLPR TRIP P POOH /Stand Back 3 1/2" HT 38 Dill 15:30 21:00 pipe from 9918' to surface. UP WT=215K. DN WT=80K. 3/15/2019 3/15/2019 1.50 PROD? WELLPR SHAH P Attempt to remove upper IBP from 21:00 22:30 retrieval tool with no luck. 3/15/2019 3/16/2019 1.50 PROD1 WELLPR WAIT T Waiting on backup fishing tools to 22:30 00:00 arrive to location from Baker Shop in Deadhorse. 3/16/2019 3/16/2019 2.00 PROD1 WELLPR WAIT T Waiting on backup fishing tools to 00:00 02:00 arrive to location from Baker Shop in Deadhorse. 3/16/2019 3/16/2019 0.50 PROD1 WELLPR PULD P PU IBP retrieval BHA#18. 02:00 02:30 3/16/2019 3/16/2019 5.00 PRODt WELLPR TRIP P TIH with IBP retrieval BHA.tt 9934' 02:30 07:30 3/16/2019 3/16/2019 5.00 PROD1 WELLPR CIRC P Mix and pump 40 bbis Hi vis Sweep 07:30 12:30 aroud @ 8 bbls min w/ 2100 psi and RIH t/ 9957' latch up and release pkr Pull up 10' pump 40 bbls hi vis sweep @ 7 bbls w/ 1950 psi tell well clean up f/ sand 3/16/2019 3/16/2019 1.00 PROD1 WELLPR PRTS P POOH and UD 5 single and test 12:30 13:30 casing t/ 2500 PSI f/ 15 mins All good. Notified AOGCC of BOPE test tomorrow. Matthew Herrera waived witness. 3/1612019 3/16/2019 7.00 PROD1 WELLPR PULD P POOH UD 3 1/2" HT 38 Drill pipe to 13:30 20:30 1991'. UP WT=100K, SOW=65K. 3116/2019 3/16/2019 1.50 PROD1 WELLPR SLPC P Slip and cut 95' of drill line. 20:30 22:00 3/16/2019 3/16/2019 1.50 PROD1 WELLPR PULD P POOH UD 3 1/2" HT 38 Drill pipe from 22:00 23:30 1 11991'to surface. 3/16/2019 3/17/2019 0.50 PROD? WELLPR BHAH P LD IBP #2 and retrieval tool BHA. 23:30 00:00 Clean and clear dg floor. 3/17/2019 3/1712019 2.50 PRODt WHDBOP RURD P Circulate and condition BOP stack. PU 00:00 02:30 test tools, MU 3-1/2 test JT, set test plug, MU dart & TIW, grease HCR and manual stack valves. 3/17/2019 3/1712019 5.00 PRODt WHDBOP BOPE P Test BOPE 250psi low, 2500psi high 02:30 07:30 with 3-1/2" test joint. Pressure test Blind rams, Upper pipe rams, lower pipe rams, and annular. Pressure lest All choke manifold, HCR valves/ line, and kill line. Test Witness waived by AOGCC inspector Matthew Herrera.By E- mail 3-16-19 12:13PM 3/17/2019 3/18/2019 16.50 COMPZN RPCOMP RUST P PJSM M/U 3-1/2" 9.3# L-80 8rd EUE 07:30 00:00 Mod Tubing as gas lift completion M/U Tq 2300 lb. Completion at 8167' (1822' off bottom) at midnight. Page 10/11 Report Printed: 3119/2019 Operations Summary (with Timelog Depths) 2M-21 Rig: NABORS 7ES Job: RECOMPLETION Time Log Statl Time End Time Our (hp Phase Op Code Anvity Code Time P -T -X Operation Start Depth (/tKB) End Depth (ftKB) 3/18/2019 3/18/2019 3.00 COMPZN RPCOMP RCST P Continue M/U 3-1/2" 9.3# L-80 8rd 00:00 03:00 FILE Mod Tubing as gas lift completion M/U Tq 2240 ft/ Ib. From 8167' to 991 Jet Lube Run & Seal thread compound. UP Wt=110K, DN WT=54K. RIH to Togo at 9968.78' PU to install headpin and circulate 1 bpm @ 85 psi. RIH slowly and saw pressure increase to verify depth of stinger to PBR. 3/18/2019 3/18/2019 2.50 COMPZN RPCOMP CIRC P Displace well with 280 bbl of 9.1 ppg 03:00 0530 CI brine followed by 80 bbls clean 9.1 ppg brine. Pump 3 BPM at 320 psi. 3/18/2019 3/18/2019 5.00 COMPZN RPCOMP RCST P Lower Down and Tag no go @ 9987' 05:30 10:30 and dropBall & Rod Set PKR Pump Down Tubing 3000PSI 10 mins ok Bleed down to 0 P/U Shear out of PBR and Space out 1.54' off no go w/ pups M/U hanger RIH RILDS and test Ann t/ 2500 psi 30 mins w/ 1500 PSI on Tubing bleed down Tubing to 0 and shear the SOV Bleed all pres off and R/D landing joint Tot Joints run 314 +3 space out pups+ Hanger w/pup 3/18/2019 3/18/2019 8.50 COMPZN WHDBOP MPSP P Install TWC and test TWC t/ 1000PSI 10:30 19:00 All good N/D and N/U FMC tree Test / Pack off 250/5000 Tree T/ 250/5000 3/18/2019 3/18/2019 4.50 COMPZN WHDBOP FRZP P Reverse circulate 73 bbls diesel down 19:00 2330 IA. Connect tubing to IA and let diesel U tube. Sucking out both tiger tanks and cuttings box. Breaking down hardlines to tiger tanks. 3/18/2019 3/19/2019 0.50 COMPZN WHDBOP MPSP P Set BPV and release the well at 23:30 0000 midnitghl. Page 11111 ReportPrinted: 3/19/2019 PTD l 4 l — lZ <f Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton @conocophill ips.com> Sent: Wednesday, March 6, 2019 8:20 PM To: Loepp, Victoria T (DOA) Cc: Senden, R. Tyler, Livingston, Erica 1 Subject: RE: [EXTERNAL]Re: 2M-21 Change in Procedure Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you very much for following up with us. After talking with our night rigsite supervisor, he was concerned with fluid containment while pulling tubing, so we are going to go ahead and nipple up the BOPS for when we pull tubing. Once nippled up, we are going to test the break on the BOPS to have a complete, tested stack. Nippling up the BOPS is intended simply for fluid containment. 1 really appreciate the time you've taken to clear this, and I apologize for the last minute change. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, March 6, 2019 5:41 PM To: Hampton, Kyle <Kyle.Hampton @conocophillips.com> Subject: [EXTERNAL]Re: 2M-21 Change in Procedure Kyle, Approval is granted for the change in procedure outlined below including operations performed without BOPS but with tested barriers as indicated. Please include this approval with the approved Sundry. Thanx, Victoria Sent from my iPhone On Mar 6, 2019, at 4:30 PM, Hampton, Kyle <KVIe.Ham pton@conocophillips.com> wrote: Victoria, I don't mean to be pushing for a response, but we are about 30 minutes from being ready to either pull tubing or begin NU of BOPS. Have you had a chance to review the proposed operations? Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.Hampton@cop.com From: Hampton, Kyle Sent: Wednesday, March 6, 2019 10:54 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler<R.TVIer.Senden@conocophillips.com> Subject: 2M-21 Change in Procedure Victoria, Based on our discussion this morning, we are looking to change the procedure. The SSSV became stuck in the tubing head when pulling the tubing out of the hole. We have completed the following deviation, starting on step 6a from the summary in the sundry: 1. Rig up E -line. a. Run first IBP and set 30' above the tubing cut (9,936' RKB). Drop 20' of sand on top of the plug. Pressure test to 1,500 psi for 10 min. b. Run second IBP and set another 30' above the first IBP (9,900' RKB). Drop 100' of sand on top of the plug. c. RDMO E -line. 2. Perform a 30 minute no -flow test to verify the barriers are maintaining integrity. 3. Break BOP stack. 4. Place dog collar on tubing just above the top of the tubing head. Cut the tubing above the dog collar. Remove the BOPS. S. Using Hydratight, nipple down the tubing head and allow the 7" production casing to grow. 6. Once the 7" casing has grown to the point that Hydratight is no longer required, remove the tubing head. Remove the old casing slips and packoff. 7. Make up the 3-1/2" overshot and overshoot the tubing stub above the SSSV. Pull the 3-1/2" tubing into slight tension (<2k lbs) to ensure it will not slip downhole once the 7" casing is cut. 8. Cut the 7" casing externally. 9. Pull the SSSV / swedged casing up to expose the 3-1/2" tubing. 10. Place C -plates on the 7" casing. Set the 3-1/2" tubing on air slips with a dog collar on the C -plates. 11. Cut the 3-1/2" tubing above the dog collar and lay down the 3-1/2" SSSV assembly. 12. Make up and overshot and make up to the 3-1/2" tubing stub. 13. Bring the tubing up to the floor and break the next lower connection. We will be completing the following operation in preparation for pulling the tubing: 14. On that same connection, make up a storm packer to the 3-1/2" tubing and run in hole to -100' MD. 15. Back off the storm packer and pull of out the hole. 16. Pick up a 7" casing spear and stab into the casing. 17. Pull the casing into tension and land the casing on emergency slips. Set packoffs and test the void to 2,500psi for 30 minutes. We are proposing to perform the following operation without BOPS attached. 18. Pick up workstring and retrieve storm packer. Pull storm packer out of the hole. 19. Continue to pull the 3-1/2" tubing out of the hole, being careful when the first GLM approaches the suspected tight spot at 708' MD. 20a. If the tubing is able to be pulled out of the hole, return to step #7 of the procedure. 20b. If the GLM hangs up at 708', return to step #6.a.vi of the procedure. Once the tubing is out of the hole, we would perform our logging operation and determine path forward based on the state of the 7" casing. 1 have attached a schematic of the well with labeled barriers. I look forward to your response. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@cop.com P7 -D lgi-iz9 Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, March 6, 2019 10:54 AM To: Loepp, Victoria T (DOA) Cc: Senden, R. Tyler Subject: 2M-21 Change in Procedure Attachments: 2M-21 Schematic_v4.jpg Follow Up Flag: Follow up Flag Status: Flagged Victoria, Based on,our discussion this morning, we are looking to change the procedure. The SSSV became stuck in the tubing head when pulling the tubing out of the hole. We have completed the following deviation, starting on step 6a from the summary in the sundry: 1. Rig up E -line. a. Run first IBP and set 30' above the tubing cut (9,936' RKB). Drop 20' of sand on top of the plug. Pressure test to 1,500 psi for 10 min. b. Run second IBP and set another 30' above the first IBP (9,900' RKB). Drop 100' of sand on top of the plug. c. RDMO E -line. 2. Perform a 30 minute no -flow test to verify the barriers are maintaining integrity. 3. Break BOP stack. 4. Place dog collar on tubing just above the top of the tubing head. Cut the tubing above the dog collar. Remove the BOPS. 5. Using Hydratight, nipple down the tubing head and allow the 7" production casing to grow. 6. Once the 7" casing has grown to the point that Hydratight is no longer required, remove the tubing head. Remove the old casing slips and packoff. 7. Make up the 3-1/2" overshot and overshoot the tubing stub above the SSSV. Pull the 3-1/2" tubing into slight tension (<2k lbs) to ensure it will not slip downhole once the 7" casing is cut. 8. Cut the 7" casing externally. 9. Pull the SSSV / swedged casing up to expose the 3-1/2" tubing. 10. Place C -plates on the 7" casing. Set the 3-1/2" tubing on air slips with a dog collar on the C -plates. 11. Cut the 3-1/2" tubing above the dog collar and lay down the 3-1/2" SSSV assembly. 12. Make up and overshot and make up to the 3-1/2" tubing stub. 13. Bring the tubing up to the floor and break the next lower connection. We will be completing the following operation in preparation for pulling the tubing: 14. On that same connection, make up a storm packer to the 3-1/2" tubing and run in hole to —100' MD. 15. Back off the storm packer and pull of out the hole. 16. Pick up a 7" casing spear and stab into the casing. 17. Pull the casing into tension and land the casing on emergency slips. Set packoffs and test the void to 2,500psi for 30 minutes. We are proposing to perform the following operation without BOPS attached. 18. Pick up workstring and retrieve storm packer. Pull storm packer out of the hole. 19. Continue to pull the 3-1/2" tubing out of the hole, being careful when the first GLM approaches the suspected tight spot at 708' MD. 20a. If the tubing is able to be pulled out of the hole, return to step #7 of the procedure. 20b. If the GLM hangs up at 708', return to step #6.a.vi of the procedure. Once the tubing is out of the hole, we would perform our logging operation and determine path forward based on the state of the 7" casing. I have attached a schematic of the well with labeled barriers. I look forward to your response. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle. Hampton@cop.com Pulling TBG Open to surface 7"x 9-5/8" annulus N ew c asi ng pac koffs 1191 Will test 3/6/19 7" x 9-5/8" annulus Arctic packcement Held pressure priarto SC leak in 2016 Inside 7" Production Casing Kill weight fluid 30 minute no flow test on 3/2/19 Inside 7" Production Casing Two IBPs Passed test to 1,500 psi an 3/5/19 Inside 7" Production Casing Packer/ plugcamha Passed CMITta 2,500 psi on 10/30/18 Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273 4760 fax Delivered to: AOGCC ATTN: Natural Resou rces Tech nici an II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 19 1129 l TRANSMITTAL DATE 9 TRANSMITTAL M'®• 1R-17 50-029-22212-00 SERVICE ORDER # EA77-00002 FIELD NAME KUPARUK RIVER DESCRIPTION WL DELIVERABLE DESCRIPTION IPROF Vert DATA TYPE FINAL FIELD DATELOGGED Prints 13 -Feb -19 CD's 1 1E-1681-1 50.029-23230-60 E90U-00005 KUPARUK RIVER WIL (PROF FINAL FIELD 23 -Feb -19 1 1C-190 50-029.23136.00 E90U-00006 KUPARUK RIVER WL IPROF FINAL FIELD 23 -Feb -19 1 U-164 50-029-23278-00 E901.1-00007 KUPARUK RIVER Memory IPROF FINAL FIELD 25 -Feb -19 1 U-136 50.029-23331-00 E901.1-00009 KUPARUK RIVER Memory IPROF FINAL FIELD 26 -Feb -19 1 2M-21 50-103-20156-00 E540-00062 KUPARUK RIVER WL Caliper FINAL FIELD 7 -Mar -19 1 cc 6 11L I neSfiVT A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the 1, X package have been verified to match the media noted above. a Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this return via courier or sign/scan and email a copy S lumberger and CPAI. point. Schlumberger -Private • • 191129 WELL LOG TRANSMITTAL #904606630 2 9 3 8 To: Alaska Oil and Gas Conservation Comm. June 14, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 202018 RE: Packer Set Record: 2M-21 AO G C C Run Date: 2/5/2018 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 FRSANC@halliburton.com 2M-21 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20156-00 Packer Set Record (Field Print) �u 1 color log 50-103-20156-00 SCAN NED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS ANC@halliburton.com Date: 0/9/04W Signed: A 14/ • STATE OF RECEIVED _ ALASKAOIL AND GAS CONSERVATION COMMIS ION REPORT OF SUNDRY WELL OPERATIONS MAR 0 7 2018 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate U Pull Tubing ❑ eaGs dU Performed: Suspend El El Other Stimulate El Alter Casing 111Chan ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well❑ Other: _tbg patch_ ❑., 2.Operator ConocoPhillips Alaska,Inc 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development 0 Exploratory ❑ 191-129 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99510 50-103-20156-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25571 KRU 2M-21 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 10599 feet Plugs measured N/A feet true vertical 6119 feet Junk measured N/A feet Effective Depth measured 10303 feet Packer measured 10004 feet true vertical 5982 feet true vertical 5845 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 16" 123' 123' Surface 3877' 9-5/8" 3926' 2825' Intermediate Production 10555' 7" 10599' 6119' Liner Perforation depth Measured depth 10109'-10292' feet True Vertical depth 5893'-5977 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 10030'MD 5856'TVD Packers and SSSV(type,measured and true vertical depth) PKR OTIS HVT Retrievable 10004'MD 5845'TVD Safety Valve CAMCO TRDP-4A-RO 1782'MD 1692'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): 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: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory ❑ Development❑., Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: n1617@cop.com Authorized Signature i,,../11 Date: 3/6/18 Contact Phone: 669-7224 VTL- 3/16/15 , plir Form 10-404 Revised 4/2017 „N „ ,s t, �„ Submit Original Only • . • • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAR 0 7 2018 March 6, 2018 AOGCC Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. Development KRU well 2M-21 (PTD 191-129). The report is for a tubing patch that was set to repair a leak above the packer. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, /4// Kelly Lyons Well Integrity Supervisor Attachments • • Date Event Summary 11/26/17 SET DV @ 8674' RKB. ATTEMPT MIT-T 2500 PSI, IA TRACKING. PULLED OV @ 7456' RKB & REPLACE WITH IN KIND. ATTEMPT MIT-T 2500 PSI, SAME IA TRACKING. WITH HOLEFINDER, DETECT LEAK IN TBG BETWEEN 8065' & 7495' RKB (GLM's 4 &5) IN PROGRESS. LRS ATTEMPT TO MITT 2500 PSI, IA TRACKS IMMEDIATELY. 12/20/17 RIH W/LDL TOOLS, PERFORM BASELINE TEMPERATURE DOWN TO TOP OF PLUG @ 10020'. START PUMPING @ 0.5 BBL/MIN. LOG UP LOOKING FOR LEAK. LEAK FOUND @ 7505'. UP/DOWN PASSES PERFORMED OVER INTERVAL 7350' -7650'. PERFORMED STATION SURVEYS @ 7515'/7510'/7505'. PERFORM DYNAMIC TEMPERATURE PASS FROM TOP OF PLUG TO SURFACE. 12/21/17 RIH W/24 ARM CALIPER. PERFORM REPEAT PASS OVER LEAK FROM 7650' -7350'. PERFORM MAIN PASS OVER INTERVAL 10000'TO SURFACE. 02/13/18 SET LOWER PARAGON 2 PACKER (P2P) @ 7512' (RKB). RIH W/ UPPER P2P WITH 24.51' OF SPACER PIPE AND ANCHOR LATCH, SET UPPER PACKER @ 7482' RKB. RIH W/TTS TEST TOOL, STING IN UPPER PACKER, ATTEMPT MIT-T, IA INSTANTLY TRACKED TUBING UP TO 2500PSI. PERFORMED MIT-COMBO TO 2500 PSI, FOR 30 MIN, PASSED, PUMPED 7.5 BBLS DIESEL. BLED BACK TO 650 PSI (4 BBLS RETURNED). PULLED TEST TOOL, RDMO, RELEASED FOR PLAN FORWARD. LOWER P2P (S/N CPP 35142), ANCHOR LATCH (S/N CPAL35075), UPPER P2P (S/N CPP35124) CMIT: Pre TIO: 200/200/0. Initial TIO: 2300/2520/0. 15 min TIO: 2550/2475/0. 30 min TIO: 2510/2475/0. 02/14/18 SET TEST TOOL IN PATCH @ 7482' RKB. PERFORM BASELINE TEMP PASS TO SAME. ATTEMPT TO ESTABLISH LEAK RATE AND TBG PSI UP TO 2500. MIT TBG TO 2500 (PASS ON THIRD ATTEMPT/NO GAIN IN IA PSI DURING TESTS). JOB COMPLETE. MIT-T: START=2525/250/30 15 MIN=2450/250/30 30 MIN=2415/250/30. CONFER W/CO REP. 45 MIN=2400/250/30 Executive A 30'TTS Retrievable tubing patch was installed to cover a leak at 7505'. Integrity of the Summary patch was confirmed with MITT/CMIT pressure test. • KUP PROD • 2M-21 ConocoPhillips et, Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Wellbore Status ncl(1 MD(ftKB) Act Btm(ftKB) !;; Irn.. , 501032015600 KUPARUK RIVER UNIT PROD 64.31 9,100.00 10,599.0 CorocoeWllps i Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... SSSV:TRDP 40 12/5/2016 Last WO: 8/30/1992 43.00 11/14/1991 2M-21,3/5/201811152 PM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By _......................._.....................__... _.__..Last Tag:RKB 10,303.0 11/20/2017 pproven '! Last Rev Reason HANGER;38.8-- - Annotation End Date Last Mod By . .,, .., , . ,., a ,Rev Reason:String shot to loosen debris,flush the tubing&SET TUBING PATCH 3/5/2018 pproven Casing Strings Casing Description OD ID TopftKB Set Depth ftKB Set Depth TVD Wt/Len I Grade Top Thread iv 4,J(; 9 Pion (in) (in) (ftKB) P (ftKB) P (TVD)... (... CONDUCTOR 16 15.062 39.0 123.0 123.0 62,58 H-40 WELDED Casing Description OD(in) ID(in) Top(8KB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 48.8 3,926.0 2,824.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 44.0 10,599.0 6,119.0 26.00 J-55 BTC Tubing Strings .AA/CONDUCTOR;390-123.0 I ' Tubing Description String Ma...ID lin) Top(ftKB) Set Depth Rt..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection > I TUBING 31/2 2.992 38.8 10,029.7 5,856.4 9.30 J-55 ABM-EUE LEAK;708.0 Completion Details IL Top(ND) Top Incl Nominal Top(ftKB) (ftKB) CI Item Des Corn ID(in) 38.8 38.8 0.07 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV;1,781.5 r.' 4 1,781.5 1,691.9 46.10 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812' 9,988.2 5,837.2 62.58 LOCATOR OTIS LOCATOR 2.992 9,988.7 5,837.5 62.58 PBR OTIS 10'STROKE PBRw/4"SEAL BORE 2.970 GAS LIFT;3,381.7 I 4, 10,004.4 5,844.7 62.54 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 10,019.7 5,851.8 62.55 NIPPLE CAMCO D NIPPLE 2.750 10,029.2 5,856.1 62.56 WLEG OTIS RH BALL SEAT SUB/WL GUIDE(SHEARED),ELMD TTL© 2.875 10021'PER SWS PERF(10/11/99) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE:48.8-3,926.0 4. Top(ND) Top Incl Top(ftKB) (ftKB) )'I Des Corn Run Date ID(In) 708.0 705.6 9.23 LEAK SURFACE CASING LEAK 11/24/201 GAS LIFT;5,764.3 CI... 7 • 7,482.0 4,654.0 59.91 PATCH UPPER P2P(S/N CPP35124)WITH 24.51'OF SPACER 2/13/2018 2.800 PIPE AND ANCHOR LATCH(S/N CPAL35075) GAS LIFT;6,879.4 ' 7,505.0 4,665.5 59.95 LEAK LEAK 12/20/201 GAS LIFT;7,456.1 7 7,512.0 4,669.0 59.96 PATCH LOWER PARAGON 2 PACKER(P2P)(S/N CPP 35142) 2/13/2018 2.800 PATCH;7,482.0 I LEAK;7,5050IFTFIl Perforations&Slots I' Shot Dens Top(ND) Btm(TVD) (shots/ft Top(ftKB) atm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com PATCH;7,512.0 10,109.0 10,124.0 5,892.9 5,899.8 C-4,2M-21 10/11/1999 4.0 APERF 2.5"HOD,60 deg.ph,non- • • oriented GAS LIFT;6,064.8 1100,117305.00 1100,,117590..00 55,,992041.09 592156 AC--34,,2264M--2211. 73/91/12/020130 0 64..00 AAPPEERRFF 22..55HHSSCD GPJU6N0 LtlOeAg DpEh D, GAS LIFT;8,673.6imi ilMi. PHASED 60 DEGREES 10,195.0 10,212.0 5,932.5 5,940.3 A-3,2M-21 6/28/2013 6.0 APERF 21/2"HSC GUN,60 DEG PHASING,102 SHOT GAS LIFT;9,345.8 TOTAL 10,232.0 10,252.0 5,949.5 5,958.7 A-3,2M-21 10/29/1992 4.0 IPERF 4.5"Csg Gun,180 deg.ph; Oriented 179 deg.ph GAS LIFT;n,532.3 S' 10,252.0 10,272.0 5,958.7 5,967.9 A-3,2M-21 10/29/1992 4.0 IPERF 4.5"Csg Gun,180 deg.ph; Oriented 169 deg.ph 1.11 10,272.0 10,292.0 5,967.9 5,977.1 A-3,2M-21 10/29/1992 4.0 IPERF 4.5"Csg Gun,180 deg.ph; 11 Oriented 176 deg.ph Stimulations&Treatments LOCATOR;9,988,2 r Proppant Designed(lb) I Proppant In Formation(Ib) I Date PER;9,988.7 5 8/1/2001 Stimulations&Treatments Vol Clean Pump PACKER;10,004.4 ` Stg s Top(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) II1 10,109.0 10,150.0 8/1/2001 NIPPLE;10,019.7 -' Mandrel Inserts MI St ati WLEG;10,029.2 j. on Top(ND)• Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,381.7 2,522.9 MACCO SPM-1A 1 GAS LIFT GLV BK1 0.156 1,280.0 7/1/2009 2 5,764.3 3,775.3 MACCO SPM-1A 1 GAS LIFT GLV BK1 0.188 1,279.0 7/1/2009 APERF;10,109.0.10,124.0 3 6,879.4 4,345.6 MACCO SPM-1A 1 GAS LIFT GLV BTM 0.188 1,307.0 7/1/2009 FRAC;10,109.0 APERF;10,135.0-10,150.0 4 7,456.1 4,641.0 MACCO SPM-1A 1 GAS LIFT OV INT 0.250 0.0 11/26/2017 5 8,064.8 4,947.3 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 3/23/1998 APERF;10,170.0-10,179.0 6 8,673.6 5,241.6 MACCO SPM-1A 1 GAS LIFT 'DMY BK 0.000 0.0 11/26/2017 APERF;10,195.0.10,212.0 7 9,345.8 5,542.1 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 3/23/1998 IPERF;10,232.0-10,252.0 8 9,932.3 5,811.6 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 7/24/2001 IPERF;10,252.0-10,272.0 Notes:General&Safety IPERF;10,272.0-10,292.0 End Date Annotation 11/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 11/24/2017 NOTE:SCLD(FAILED-SC LEAK(41708). 12/20/2017 NOTE:LEAK FOUND©7505'-Eline PRODUCTION;44.0.10,593.0 co T i V O X (0 1 O N D _0 j N ,� �, O L .0 2 J t0 C7�Q N t O +-' 0 N Z flI ! i oCAm a hQY O iO O �� U a _C — N C T ca 0 O Q El Q =t O u c Q 0 m O J t7 co co Co co co co co co Co 4-, Q) O C C CU U L Q p c .6 Q .61 a _6 .6 _6 E -p cn oJ 06 a) CN a) co N a) of F c), LL LL LL LL LL � LL CoC no U .0 N N N a- N M a N l0 N oo O +'' L C 0 Z Q '- u "0 M 0 a-' Z a O >Q' E u o L 0 c L F ce ~ '' u *' M O Oa 0000001000 C � (1) 0 L J J J J J J J J J ti4 C w O y W W W W W W W W ,o N .L U `� F LL LL LL LL LL LL LL LL LL a-, N QJ Q1 -o Q J J J J J J J J JQ 'Q > a=- au , - to F- Q Q Q Q Q Q Q Q Q c co C "' Z Z Z Z Z Z Z Z Z N t v O a)0) 0 1Ccc - > LL LL LL LL LL LL LL LL LL O v CO U 0 C LC Co f6 >Y C s y F L 0. 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Q M O) Of O M tT O M O O Ta) .n 0 ONNNONNONNN 'i 0) o O O O o 0 O O 3 0 0 0 0 0 0 O O o 0 0 -' O wOO v U) 0 In U) IA N U) U) I[) N I!) Q 0 N C C 63 I- al a .0 j> QJ �i• f N L w Y 0 CC C E Q O- � O M Qr- n MO N N N O N 0) az , OA f)'1ZCI o a+ E co v H 19 tY n W 0 Z Q Q Z N (6 C a < 0 N W N M N M N M (( v) Y s� C a"' CD Ln 00e. U ^ ai .0 u) ro O CA a (Zo Q •`?'' H 0 a Q kNi �° • ! v o N a _ -0 .i u) U °Ao w a �_ Y ' > LD V w�_°w u • w 0700 x co V C fl c•I 0 0(Ni Z a a o N OW a C JCO of L N Q Y 0 C C w > ' ops U a. u o > E }' o Q C O LO .C 6 W o c 0 co as a a < Q w r` r� ti ti ro o E m Q l7 •- ,- e- t u , Y _1 F- Q H 0 () ate) aW aa: aa: `^ CC C co ,-10°) 0000 E J--+ coL VI Z Q O N C co a >- a Z Q 0 O4 CC u O O > 0 0 0 0 0 @ u _o s cr CU u a J J J J J c co} O O y W W W W W tip FF LL LL LL LL LL 7) v E -O ' O Q J J J J J • a �O C a G 0 F F— Q Q Q Q Q C (til 0 Z Z Z Z Z - m p� u O C) LL LL LL LL LL a) -C . U a ta }• a L G 42) :i{. 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'O O C • W CU CM r o E o 00 • O. _• Z 0 LL1CG ' E E Q O^ N N 4 )( a Oa aZ ZN MO N C Y pa M M A = E N J _ co C CLO c•I11,1 N M N z m ..= i s C 0 f0 E E O Va a If a m F- a a ° F- Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢/'-/~'~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: E] Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -El' Logs-of various kinds . Other COMMENTS: Scanned by: Beverly Dianna(~~than Lowell Date://¢ [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ STATE OF ALASKA RECEIVED ` AL4 OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS JUL 2 5 2013 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate I✓ Other Pull Tubing r Time Extension 0 Alter Casing ("" 9 � Stimulate-Frac Waiver Change Approved Program EOperat. Shutdown r Stimulate-Other `" Re-enter Suspended Well j'°'m 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development i✓ , Exploratory r 191-129 • 3.Address: 6.API Number:r P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20156-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25571 2M-21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool . 11.Present Well Condition Summary: Total Depth measured 10599 . feet Plugs(measured) none true vertical 6119 feet Junk(measured) none Effective Depth measured 10501 feet Packer(measured) 10004 true vertical 6073 feet (true vertical) 5845 Casing Length Size MD ND Burst Collapse CONDUCTOR 84 16 123 123 SURFACE 3877 9.625 3916 2819 PRODUCTION 10555 7 10594 6117 SCANNED NOV 4 51013 Perforation depth: Measured depth: 10109-10124, 10135-10150, 10170-10179, 10195-10212, 10232-10292 True Vertical Depth. 5893-5899, 5905-5912, 5921-5925, 5933-5941, 5950-5977 Tubing(size,grade,MD,and ND) 3.5,J-55, 10030 MD, 5857 TVD Packers&SSSV(type,MD,and ND) PACKER-OTIS HVT RETRIEVABLE PACKER @ 10004 MD and 5845 TVD SSSV-CAMCO TRDP-4A SSSV @ 1782 MD and 1692 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-8bl Casing Pressure Tubing Pressure Prior to well operation 254 952 1178 -- 208 Subsequent to operation 158 1155 1538 -- 212 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory Development - Service Stratigraphic r, 16.Well Status after work: Oil -, r Gas `"` WDSPL E Daily Report of Well Operations XXX GSTOR E WINJ r WAG r GINJ 1 SUSP r SPLUG E 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact John Peirce an 265-6471 Email John.W.Peirceaconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date /4141C-5-:" — V CI1Z K1- 8`1 13 RBDMS AUG - 2 2043 ,,,,,, 0ii) Form 10-404 Revised 10/2012 Submit Original Only 2M-21 Well Work Summary DATE SUMMARY • • 5/24/2013 TAGGED @ 10343' SLM, EST. 98' RATHOLE. IN PROGRESS. 5/25/2013 DRIFT TBG. w/ 17'x 2.5" DUMMY PERF GUN TO 10340' SLM. READY FOR E-LINE. 5/26/2013 RAN IN HOLE WITH 42' OF PERF GUN TOOLSTRING (17' OF PERF, OD: 2.5", 60 DEG PHASE, 6 SPF, CHARGE TYPE: DP, CHARGE WEIGHT: 11.1g)AND TOOL CAME TO STOP @ 8700', COULD NOT MOVE DOWNHOLE, LITTLE RED PUMPED 35 BBLS AND MOVED TOOL TO 9300', POOH AND REPLACED WITH A SHORTER 36'TOOSTRING (7' OF PERF, OD: 2.5", 60 DEG PHASE, 6 SPF, CHARGE TYPE: DP, CHARGE WEIGHT: 11.1g), RAN IN HOLE A SECOND TIME AND STOPPED @ 7700', LITTLE RED PUMPED 12 BBLS BUT TOOLS DID NOT MOVE DOWNHOLE, COMPANY REP DECIDED TO POOH UNTIL AN ALTERNATE SOLUTION CAN BE FOUND 6/28/2013 PERFORATED WELL SUCCESSFULLY WITH 17' GUN. CCL STOP DEPTH = 10184.4' CCL TO TOP SHOT= 10.6' SHOT INTERVAL 10195' - 10212' 6 SPF, 60 DEG PHASING, 102 SHOT TOTAL. 7/9/2013 PERFORATED 2M-21 FROM 10170'- 10179' USING 2.5" HSC LOADED 6SPF, PHASED 60 DEGREES, DP CHARGES. LOG CORRELATED TO SLB PERFORATING RECORD DATED 29-FEB-1992. WELL SHUT IN FOR DSO TO BRING BACK ONLINE. JOB COMPLETE KUP 2M-21 ConocoPhillips Well Attributes Max Angle&MD TD:iv Alaska,Inc Wellbore API/UWI Field Name Well status Inc](°) MD(MB) Act Btm(RKB) co,wclkps 3i 501032015600 KUPARUK RIVER UNIT PROD 64.31 9,100.00 10599.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:TRDP 80 12/20/2012 Last WO: 8/30/1992 43.00 11/14/1991 Well Confiq.-2M-21,7/18/20136:14:16AM Schematic Actual Annotation Depth(ttKB) End Date Annotation Last Mod...End Date Last Tag:SLM 10,343.0 5/24/2013 Rev Reason:ADD PERFS haggea 7/17/2013 Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd HANGER,39 CONDUCTOR 16 15.062 39.0 123.0 123.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(ttKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd _--_ __ '" SURFACE 9 5/8 8.921 38.7 3,915.9 2,819.3 36.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 39.1 10,594.1 6,116.8 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ttKB) Set Depth(1...Set Depth(TVD)... String Wt...String...String Top Thrd TUBING 31/2 2.992 38.8 10,029.7 5,856.5 9.30 J-55 ABM-EUE Completion Details Top Depth CONDUCTOR, Nomi... 38!123 (ND) Top Intl Top(ftKB) (RKB) (% Item Description Comment ID(In) -- 38.8 38.8 0.20 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV, { 1,781.5 1,691.8 46.10 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 1,781 1 F,° I 9,988.2 5,837.2 62.58 LOCATOR OTIS LOCATOR 2.992 ___ 9,988.7 5,837.5 62.58 PBR OTIS 10'STROKE PBR w/4"SEAL BORE 2.970 10,004.4 5,844.8 62.64 PACKER OTIS HVT RETRIEVABLE PACKER 3.250 GAS LIFT, 10,019.7 5,851.8 62.64 NIPPLE CAMCO D NIPPLE 2.750 3,382 10,029.2 5,856.2 62.64 WLEG OTIS RH BALL SEAT SUB/WL GUIDE(SHEARED),ELMD TTL @ 2.875 ,4 10021'PER SWS PERF(10/11/99) Perforations&Slots Shot c 4 Top(ND) ate(TVD) Dens SURFACE, 39-3,916 Top B) (Btm R ) KB (RKB) (RKB) Zone Dote (sh... Type Comment 10,109.0 10,124.0 5,892.9 5,899.8 C-4,2M-21 10/11/1999 4.0 APERF 2.5"HSD,60 deg.ph,non-oriented 10,135.0 10,150.0 5,904.9 5,911.8 C-4,2M-21 3/11/2000 4.0 APERF 2.5"HSD PJ 60 deg ph GAS LIFT, 10,170.0 10,179.0 5,921.0 5,925.1 A-3,2M-21 7/9/2013 6.0 APERF 2.5"HSC GUN LOADED,PHASED 5764 60 DEGREES GAS LIFT [ 10,195.0 10,212.0 5,932.5 5,940.7 A-3,2M-21 6/28/2013 6.0 APERF PHASING,'HS102 NGUN,60 DEG AL 6,879 _ 10,232.0 10,252.0 5,949.7 5,958.8 A-3,2M-21 10/29/1992 4.0 IPERF 4.5"Csg Gun,180 deg.ph;Oriented GAS LIFT, _ .m 179 deg.ph 7,456 10,252.0 10,272.0 5,958.8 5,968.0 A-3,2M-21 10/29/1992 4.0 IPERF 4.5"Csg Gun,180 deg.ph;Oriented ��++-- 169 deg.ph GAS LIFT, j 10,272.0 10,292.0 5,968.0 5,977.1 A-3,2M-21 10/29/1992 4.0 IPERF 4.5"Csg Gun,180 deg.ph;Oriented 8,065 Lz, 176 deg.ph GAS LIFT, Stimulations&Treatments 8,674 Bottom Min Top Max Btm Top Depth Depth GAS LIFT. RKB) RKB) (ND) (MB) 9,346 sa ( ) ( l ( ) Type Date Comment 10,109.0 10,150.0 5,892.9 5,911.8 FRAC 8/1/2001 'C'SAND FRAC-50%of treesaver rubber left in ■ welibore. Notes:General&Safety -. GAS LIFT, End Date Annotation _ 0932 11/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR, 9,988 --... PBR,9,989 --1 1 .a PACKE10,1xR, 14 , a NIPPLE,10,020 a . WLEG,10,029 -- APERF, 1 I 10,103.10,124 FRAC,10,109 gg APERF, K 9 10.13510,150 APERF, T 10,170-10,179 Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run APERF, N...Top(MB) (RKB) (°) Make Model (in) Sera Type Type (in) (psi) Run Date Com... 10.19510,212 1 3,381.7 2,522.8 53.96 MACCO SPM-1A 1 GAS LIFT GLV BK1 0.156 1,280.0 7/1/2009 2 5,764.3 3,775.3 59.29 MACCO SPM-1A 1 GAS LIFT GLV BK1 0.188 1,279.0 7/1/2009 (PERF, 3 6,879.4 4,345.6 59.07 MACCO SPM-1A 1 GAS LIFT GLV BTM 0.188 1,307.0 7/1/2009 10,232-10.252 IPERF, -6 B 4 7,456.1 4,641.0 59.89 MACCO SPM-1A 1 GAS LIFT OV BTM 0.250 0.0 7/1/2009 10,252-10,272 _ IPERF, 5 8,064.8 4,947.2 58.70 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 3/23/1998 10,272-10,292 6 8,673.6 5,241.6 63.10 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 7/1/2009 7 9,345.8 5,542.0 62.30 MACCO SPM-1A 1 GAS LIFT DMY BK 0.000 0.0 3/23/1998 8 9,932.3 5,811.6 62.79 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 7/24/2001 !, PRODUCTION. 39-10,594 . ■ TD,10.599 Conoco~Phillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 10~~~~1.~' ~~~ ~ ~ ~~~ Anchorage, AK 99501 Dear Mr. Maunder: • RECEfVED JAN 0 8 200 Alaska Oil & Gaa Cans, Gun~~~ion Anchorage ~~ ~ ~'~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similaz manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, Perry ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404j Kuparuk Field nate+, Sc~lIIIbepgep NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth , .",,,1>. ~,r!\r\:.: ì ) ."....."'1:. ,,""" Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ! C1 ( - I dLi Field: Kuparuk Well Job # Log Description BL Color CD Date ,,1.0 ',j' 1 E-1 82 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-105L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07/17/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1 F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04' 11320991 INJECTION PROFILE 07/03/06 1 1 D-HN N/A INJECTION PROFILE 06/27/06 1 2Z-U 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1 E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Z Ð J - ¡" 0 3H-10B <-of-toe¡ 1F-16A IQ( - Iz..cr 2M-21 ~!,1' -( '1" 3C-13 f1t. -f)f( f 2M-20 2F-07 1'1'1-~ 2E-11 'l~4... (CÇ2G-09 j z. -1ft, 1 F-07 I '8tf-~!l2B-1 0 I fJ(..¡t!>lf 1A-05 I t/~{5L 1A-09 /3" ..2.3 If 1 Q-04 I '3 "'" 1 H-01 10802919 10884016 10884017 10884018 10884009 10884005 10884007 10884008 10884001 10884004 10884013 10884015 10802926 10802921 Log Description RST-SIGMA SBHP SURVEY PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE SBHP SURVEY SBHP SURVEY PIEZO SONA TOOL PIEZO SONA TOOL s~ ./J~ Date 08/12/04 09/06/04 09/07/04 09/07/04 09/02/04 08/29/04 08/31/04 09/01/04 08/27/04 08/28/04 09/05/04 09/05/04 08/19/04 08/15104 SCANNED NO'; n B 2004 DATE: 09/17/04 NO. 3209 Company: Alaska Oil & Gas Cons Comm _AttrY. RvtJh I D~a~Clh ... 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL --/ Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 <~ (0-10 - t)¥ Please sign and retur one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. PI-I LLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 August 27, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2M-21 (191-129) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the frac treatment on the KRU well 2M-21. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED SEP 0 5 ZOO1 .Aloska Oil & Gas Cons. Commissior,. .AnChorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 114' FSL, 479' FWL, Sec. 27, T11N, RSE, UM At top of productive interval 1817' FSL, 1839' FEL, Sec. 22, T11 N, RSE, UM At effective depth At total depth 2237' FSI, 1711' FEL, Sec. 22, T11 N, RSE, UM 5. Type of Well: Development _X Explorato~__ Stratigraphic__ Service__ (asp's 488319, 5948986) (asp's 491276, 5955966) (asp's 491404, 5956386) 6. Datum elevation (DF or KB feet) RKB 147 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2M-21 9. Permit number / approval number 191-129 10. APl number 50-103-20156 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing CONDUCTOR SURF CASING Length 123' 3767' 10440' PROD CASING 10599 feet Plugs (measured) 6119 feet 10276 feet Junk (measured) 5970 feet Size Cemented 16" 220 SxAS II 9-5/8" 543 Sx PFE, 660 Sx G, & 110 Sx PFC 7" 280 Sx Class G Tagged Fill (3/7/00) @ 10276' MD. Measured Depth 123' 3916' 10589' True vertical Depth 123' 2819' 6114' Perforation depth: measured 10109- 10124'; 10135 - 10150'; 10232- 10292' true vertical 5893 - 5900'; 5905 - 5912'; 5950 - 5977' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3.5", 9.3#,J-55, Tubing@ 10030' MD. Otis 'HVT' Packer @ 10004' MD. Camco 'TRDP-4A-RO' @ 1781' MD. A, ~chorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 455 Subsequent to operation 524 Representative Daily Average Productionorlnjection Data Gas-Mm W~er-Bbl 669 1006 766 1120 Casing Pressure Tubing Pressure 232 219 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 4,~../~/~~ Tit,e: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 2M-21 DESCRIPTION OF WORK COMPLETED ADD PERFORATING OPERATIONS 3/7/00: RIH & tagged fill at 10276' MD. 3/11/00: MIRU & PT equipment. RIH w/perforating guns & shot 15' of perforations in the 'C4' sand as follows: Added perforations: 10135- 10150' MD Used a 2-1/2" HSD carrier & shot the perfs at 4 spf at 60 degree phasing. POOH w/guns. RD. Returned the well to production & obtained a valid well test. THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 E E C:LO~M.DOC PL E W M A T E R IA L U N D ER TH IS M A R K ER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 147' RKB 3. Address: Exploratory _~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service _~. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 114' FSL, 479' FWL, Sec 27, T11N, R8E, UM 2M-21 At top of productive interval: 9. Permit number/approval number: 1817' FSL, 1839' FEL, Sec 22, T11 N, R8E, UM 91-129 At effective depth: 10. APl number: 2154' FSL, 1736' FEL, Sec 22, T11N, R8E, UM 50-103-20156-00 At total depth: 11. Field/Pool: 2237' FSL, 1711' FEL, Sec 22, T11N, R8E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 10598 feet Plugs (measured) None true vertical 6118 feet Effective Deptl measured 10501 feet Junk (measured) None true vertical 6073 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 220 Sx AS II 122' 122' Surface 3877' 9-5/8" 1200 Sx PF E & 3916' 2819' 660 Sx Class G Production 10548' 7" 280 Sx Class G 10589' 6114' Liner Perforation Depth measured 10109'-10124', 10232'-10292' OF~iGIN4L true vertical 5893'-5900', 5949'-5976' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft., J-55 ABM-EUE @ 10030' Packers and SSSV (type and measured depth) RECEIVED Pkr: Otis 'HVT' @ 10004'; SSSV: Camco TRDP-4A-RO @ 1781' OCT 2', 13. Stimulation or cement squeeze summary Perforate 'C4' sand on 10/11/99.- ! ' Oi~ Intervals treated (measured) ~];~$[(~J & Gas Co,rlg. ,.,offi....SSiO[1 P. rni 10109'-10124' Anchorage Treatment description including volumes used and final pressure Perforated using 2.5" HSD guns @ 4 spt, final pressure = 1300 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 618 1169 1023 1253 228 Both sands Subsequent to operation 714 1622 1045 1271 225 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Dally Report of Well Operations _~X Oil X Gas _ Suspended _ Service _ ,17. I hereb~y,certify that the foregoing is true and correct to the_best of my knowledge. "~/~~ Title Signed . : wc.,,$ o~pe.i-,,en Date ~J~/~,.~'/~' ~ Form 10-404 Re~ /15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. =~---.~. .~.. KUPARUK RIVER UNIT .. ~1~1~ .,rELL SERVICE REPORT . .,,,'~.'~.IF' 2M-21(4-1)) WELL JOB SCOPE JOB NUMBER 2M-21 PERFORATIONS-E-LINE 1009991844.7 DATE DAILY WORK UNIT NUMBER 10/11/99 PERFORATING 2145 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I ~ Yes O NoI ~'~ Yes O No SWS-STEPHENSON SCHUDEL , ~ FIELD AFC# I CC# I DAILY COST ACCUM COST Signed..,,,.. ///~// ESTIMATE AK0034I 230DS28MLI $5,799 $8,150 ~,%~~ Initial Tbg IFinal Tbg I Initial IA I Final IA I Initial oa Ifinal OA ITTL Size IMin ID Del~th 650PSII 1300PSII 1280PSI 1300PSII 900PSII 700PSII 3.500" 2.750" 10020FT DALLY SUMMARY PERFORATED C-4 FROM 10109' - 10124' USING 15' 2.5" HSD @ 4 SPF & 60 DEG PHASING (EHD=0.17" & TTP=17.3"). TAG TD AT 10,428' ELM. [Perf] TIME 12:30 12:35 13:15 LOG ENTRY MOVE FROM 2M-15 TO 2M-21 START RIG UP PRESSURE TEST TO 3000# 13:20 I RIH WITH CCL-SAFE-15' 2.5" HSD @ 4 SPF & 60 DEG PHASING 14:15 14:25 ILOG TIE IN STRIP · LOG INTO POSTION & PERFORATE FROM 10109' -10124' USING 15' 2.5" HSD @ 4 SPF & 60 DEG PHASING 14:30 RIHTO TAG PBTD 14:35 TAG PBTD @ 10428' & POOH 15:30 START RIG DOWN 15:35 RELEASE RADIO SILENCE 16:30 COMPLETE RIG DOWN 17:00 RETURN TO KCC SERVICE COMPANY- SERVICE DALLY COST ACCUM TOTAL $0.00 $126.00 APC $0.00 $0.00 HALLIBURTON $0.00 $1,115.00 LITTLE bED $0.00 $1,110.00 SCHLUMBERGER $5,799.50 $5,799.50 TOTAL FIELD ESTIMATE $5,799.50 $8,150.50 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate__~X Plugging _ Perforate _ Pull tubing Alter casing Repair well Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 147' RKE 3. Address: Exploratory ~. 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 114' FSL, 479' FWL, Sec 27, T11N, R8E, UM 2M-21 At top of productive interval: 9. Permit number/approval number: 1817' FSL, 1839' FEL, Sec 22, T11N, R8E, UM 91-129 At effective depth: 10. APl number: 2154' FSL, 1736' FEL, Sec 22, T11N, R8E, UM 50-103-20156-00 At total depth: 11. Field/Pool: 2237' FSU 1711' FEL, Sec 22, T11 N, R8E, UM Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 10598 feet Plugs (measured) None true vertical 6118 feet Effective Deptt measured 10501 feet Junk (measured) None true vertical 6073 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 220 Sx AS II 122' 122' Surface 3877' 9-5/8" 1200 Sx PF E & 3916' 2819' 660 Sx Class G Production 10548' 7" 280 Sx Class G 10589' 6114' Liner measured 10232'- 10292 [*~ ! true vertical 5949' - 5976 Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft., J-55 ABM-EUE @ 10030' Packers and SSSV (type and measured depth) Pkr: Otis 'HVT' @ 10004'; SSSV: Camco TRDP-4A-RO @ 178' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 3/28/98. Intervals treated (measured) 10232' - 10292' Treatment description including volumes used and final pressure Pumped 214223 lbs of 16/20 and 12/18 ceramic proppant into the formation, final pressure = 8500 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 812 1696 484 600 255 Subsequent to operation 1527 3237 1195 600 258 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~X Oil _~X Gas_ Suspended _ Service _ 17. I hereby ~he f~. i~g is t~u,~/~d correct to the best of my knowledge. Signed ~ Title: Wells Superintendent Date ~////~ ~~ Form 10-404 Re/~ k,,. / SUBMIT IN DUPLICATE~~ ARCO Alaska, Inc. ' KUPARUK RIVER UNIT - A K1(2M-21(W4-6)) 'WELL JOB SCOPE JOB NUMBER 2M-21 FRAC, FRAC SUPPORT 0321981638.3 "DATE 'DAILY WORK UNIT NUMBER 03/28/98 "A" SAND REFRAC -'DAY bPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~) Yes O No DS-GALLEGOS CHANEY , .. -'FIELD '"AFC# CC# DALLY COST ACCUM COST '-Signed .-;' / ESTIMATE KD1907 230DS28ML $146,358 $160,422 , / ~ ....... ' Initial TbgPress "'Final TbgPress Initial lnnerAnn Final lnnerAnn I In,t,alOutor~nn 'l Final O~r Ann.. 1300 PSI 500 PSI 350 PSI 500 PSI 500 PSI 400 PSI j,- DALLY SUMMARY "A" SAND REFRAC COMPLETED. SCREENED OUT EARLY. INJECTED 214223 LBS OF PROP IN THE FORM W/10# PPA OF #12/18 @ THE PERF'S. UNABLE TO FREEZE PROTECT WELLBORE. MAXIMUM PRESSURE 8500 PSI. AND F.G. (.89). TIME 07:30 12:00 12:30 13:45 15:00 18:15 ~19:15 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (16 PEOPLE ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 8900 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 25 TO 15 BPM. SLURRY VOLUME PUMPED 430 BBLS. USED 5674 LBS OF #16/20 PROP FOR SCOURING. MAXIMUM PRESSURE 8300 PSI AND ENDING PRESSURE 2975 PSI. S/D AND OBTAINED ISIP OF 2651 PSI W/F.G. @ (.89). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 13 MINS @ 2265 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SLURRY VOLUME PUMPED 207 BBLS. MAXIMUM PRESSURE 6000 PSI AND ENDING PRESSURE 3700 PSI. S/D AND OBTAINED ISIP OF 2398 PSI W/F.G. @ (.85). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 9 MINS @ 1939 PSI. PAD VOLUME 1200 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. SCREENED OUT EARLY. SLURRY VOLUME PUMPED 2415 BBLS. PUMPED 242117 LBS OF PROP (22265 LBS OF #16/20 & 219852 LBS). INJECTED 214223 LBS OF PROP IN THE FORMATION W/10# PPA OF #12/18 @ THE PERF'S. LEFT 27894 LBS OF PROP IN THE WELLBORE, W/FILL @ SURFACE. EST BHP @ 3100 PSI. FREEZE PROTECTED WELLHEAD W/ DIESEL, BUT UNABLE TO FREEZE PROTECT ANY LOWER. MAXIMUM AND ENDING PRESSURE 7200 PSI. STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI. PUMP DIESEL AROUND THE TREESAVER W/HOT OIL TO FREEZE PROTECT WELLHEAD AND CLEAR. R/D HOT OIL UNIT. REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,038.00 APC $7,100.00 $7,100.00 DIES EL $400.00 $400.00 DOWELL $136,658.71 $136,658.71 HALLIBURTON $0.00 $8,425.78 LITTLE RED $2,200.00 $6,800.00 . TOTAL FIELD ESTIMATE $146,358.71 $160,422.49 TIME 20~0 LOG ENTRY R/D COMPLETED AND ALL ,,, ,:LL SERVICE PERSONNEL AND EQUIP LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing __ Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address Stimulate X Plugging__ Perforate Repair well Other Po Co Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) RKB 147' 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 114' FSL, 479' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1817' FSL, 1839' FEL, SEC 22, T11N, R8E, UM At effective depth 2154' FSL, 1736' FEL, SEC 22, T11N, R8E, UM At total depth 2237' FSL, 1711' FEL, SEC 22, T11N, R8E, UM 8. Well number 2M-21 9. Permit number/approval number 91-129 10. APl number 5o-103-20156 11. Field/Pool feet Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured true vertical 10,598' 6118'feet feet Effective depth: measured 10,501' feet true vertical 6073' feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 1 23' 1 6" 220SX ASII Surface 3916' 9 5/8" 543 SX PR E Intermediate 660 SX CLASS G Production 10,589' 7" 280 SX CLASS G Liner Perforation depth: measured 10,232' - 10,292' true vertical 5949' 5976' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 ABM-EUE, @ 10030' Packers and SSSV (type and measured depth) CAMCO TRDP-4A-RO @ 1781', OTIS HVT PKR @ 10004' 13. Stimulation or cement squeeze summary Fracture A Sands Measured depth 122' 3916' 10589' True vertical depth 122' 2819' 6114' RECEIVED SEP 2 5 1994 AIr~ska fJil & Gas Cons. Commission Anchor[ ~ Intervals treated (measured) 10232' - 10292 14. Treatment description including volumes used and final pressure 13.8 Mlbs 20/40, 16.8 Mlbs 16/20, & 156.5 Mlbs 12/18 ceramic proppant. Final WHTP - 6800 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1222 755 42 575 231 × 2536// 4123 81 125 269 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~C~/~. ~/~ ~ Form 10-404 Rev 06/15/88 Title Wells Superintendent Date ~'ZO- qy SUBMIT IN DUPLICATE ARCO Alaska, inc. O Subsidiary of Atlantic Richfield Company WELL DESCRIPTION OF WORK 2M-21 DATE 7/13/94 DAY 1 TIME O6OO 0800 0900 0920 1015 1130 1500 iA' Sand Re-fracture Stimulation i CONTRACTOR I KEY PERSON Dowell-Yokum 'PBTD (RKB) ILAST TAG (RKB) . DATE 10,501' 110,355' (6/16/94). FIELD COST EST. $172,834 Wellhead/Tree FMC Gen IV KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# - SCA# 9,98337, 80429 ACCUMULATED COST $185,174 . LOG ENTRY Initial Pressures: Tbg = 1050#, 7" = 50#, 9-5/8" = M1RU DS frac equipment, Veco pump, vac truck. QC frac fluids, perform seive analysis on proppant. Held safety meeting (15 people on location). Pump up 7" casing pressure to 1000g (took 10 bbls to pressure up). Prime turbines/pumps (3 total). Pressure test lines to 8900g. Pump 140 bbl breakdown stage w/20 lb/1000 gal polymer @ 14 BPM. SD for closure pressure. ISIP = 1980#, FG = 0.77 psi/ft. (Increase pressure on 7" to 3000g while pumping and reduced back to 1000g before shutting down). Pump 150 bbl 50g gel, 50 bbl w/1 PPA 20/40 carbo-lite, flushed w/95 bbls non-crosslinked gel. SD for closure. Final pump pressure = 3812#,-ISIP = 1812#, FG = 0.74 psi/ft. Pump 150 bbl 50g gel, 50 bbl w/l PPA 20/40 carbo-lite, flushed w/95 bbls non-crosslinked gel. (pumped first 81 bbls at 7 BPM and remainder at 14 BPM). SD for closure. Final pump pressure = 3579#, ISIP = 1780g, FG = 0.74 Psi/fi, closure pressure = 4220#, fluid effeciency = 35%. Engineer recommended increasing pad size from 250 bbls to 255 bbls based on data frac results. Pump frac as per design (see attached frac summary for details). Flushed frac to completion. Total proppant in formation: 187,113# (20/40: 13780#, 16/20: 16800g, 12/18: 156,533#). Bled down 7" casing to 150#. RDMO frac equipment. SUMMARY Fractured 'A' Sands as per design. Pumped total of 190,113# carbo-lite (187,113# in formation). Flushed to completion. before shutting down at each stage). Held 3450g on 7" casing while pumping frac (bled down RECEIVED Final Pressures: tbg = 2100,9, 7" = 150,9, 9-5/8" = 300g ]CHECK TInS BLOCK IF SUMMARY IS CONTINUED ON BACK Weather Report bas Cons. Anchor~, ~: FRAC / STIMULATION SUMMAH , WELL NO: 2M-21 PROCEDURE DATE: SERVICE CO: ANNULUS PRESS: 6/29/94 Dowell 3450 # AFC: 998337 DATE: 7/13/94 BEGIN FRAC: 0600 ZONE: A Sands PSI TEST LINES TO: 8900# PSI PERFS: 10,232'- 10,292' ,,, ,STAGE I VOL. FLUID !PROP CONC. PROP S!ZE, RATE (BPM) PR. ESS,URE BKDN 140 XL Gel SW - - 14 4900 / 3700 BK DN 150 XL Gel SW - - 14 3700 / 6100 ,1 PPA 50 ... XL Gel SW 1 ppa . 20/40 14 6100 / 5950 Flush 95 Non XL Gel - - 14 5950 / 3800 DF . 81 XLGel SW - - 7 3750 / 4700 DF 69 XL Gel SW - - 14 4700 / 6600 1 PPA 50 XL Gel SW 1 ppa 20/40 14 6600 / 6600 Flush 95 Non XL Gel - - 14 6600 / 3579 Pad 255 XL Gel SW - - 14 4400 / 5820 , ,, 1 PPA 200 XL Gel SW 1 PPA 20/40 CL 14 5820 / 5600 ,, , , , 2 PPA 200 XL Gel SW 2 PPA 16/20 CL 14 5600 / 5380 , ~ , 4 PPA 100 XL Gel SW 4 PPA 12/18 CL 14 5380 / 5500 6 PPA 100 XL Gel SW 6 PPA 12/18 CL 14 5500 / 5630 8 PPA 100 XL Gel SW 8 PPA 12/18 CL 14 5630 / 6040 ,1,0 PPA 110 XL Gel SWI 10 PPA 12/18 GL 14 7 12 ,,,6040 / 6400 12 PPA 110 XL Gel SW { 12 PPA 12/18 CL 12- 10 6400 ! / 6520 · , , 14 PPA 100 XL Gel SW , 14 PPA 12/18 CL 10 - 7 6520 / 6700 Flush 25 XL Gel SW - - 7 6700 ? 6800 Flush 25 Non XL Gel - - 7 - 8 6800 / 6800 Flush 37 Diesel - - 8- 10 6800 / , 5000 ISIP: 1780 PSI 15 MIN. FLUID TO RECOVER: 1825 BBL , SAND IN ZONE: 187,113 LB ITEMIZED COST: FRAC: $159,746 ROUSTABOUTS: $4,000 DIESEL: $1,008 T~ATE~. ST:_.~/ $172'834 '~V~E1suPE~ PSI AVG. PRESS: 6500 JOB COMPLETE: 1500 SAND IN CASING: 3000 VECO DH PUMP $1,080 TRUCKING: $7,000 SUPERVISION: R£E£1V£D SEP ?-zo 1994, A~S~ Oil .& Gas Cons. Commission PSI LB ARCO Alaska, Inc.,~-''* Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION ¢':'-'"'~" 2M-03 Stimulate ,': ;' ~- : ,-? 2M-18 Stimulate ~.~.. t~...,, 2M-10 Stimulate ';..· !;;.-~ 2M-19 Stimulate ~..~__,,. 5.-~. 2M-11 Stimulate .,:?,,.,.. ~ 2M-20 Stimulate .... -, 2Mo13 Stimulate ~.;~r~,~i 2M-21 Stimulate c~t- 53 2M-15 Stimulate qz.t~ct 2M-22 Stimulate · 2M- 16 Stimulate Stimulate c~t~t~ 2M-17 Stimulate ct~_2_~ 2M-25 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (arch only) FTR051696 (w/o atch) AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 479' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1817' FSL, 1839' FEL, SEC 22, T11N, RSE, UM At effective depth At total depth 2237' FSL, 1711' FEL, SEC 22, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0,598' feet 61 1 8' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 1 47' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-21 9. Permit number/approval number ?,/-/,~.- ? 10. APl number 50-1 03-201 56 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 1 0,501' feet true vertical 6073' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 123' 3916' 10,589' Size 16" 9 5/8" measured 10,232' 10,292' true vertical 5949' - 5976' Cemented Measured depth 220SX ASII 543 SX PR E 660 SX CLASS G 7" 280 SX CLASS G True vertical depth Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 ABM-EUE, @ 10030' ~¥ ~. 0 ~99~ Packers and SSSV (type and measured depth) CAMCO TRDP-4A-RO @ 1781', OTIS PBR @9989', OTIS HVT PKR @ 10004' ~,~.~ka 0il & Gas Cons. Commission 13. Stimulation or cement squeeze summary .... Allchorage Intervals treated (measured)10,232' - 10,292' Treatment description including volumes used and final pressure See Attached Summary 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation None Subsequent to operation 7/28/92 2326 Tubing Pressure 2678 0 1500 223 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby c, eftify that the foregoing is true and correct to the best of my knowledge. Slain ed '~~'~, ~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 2M-21 05/02/92 GSW FRAC W/DS YF1GOD. PUMP 266 BBL PREPAD @ 25 BPM, LAST WHTP=4806 PSI, ISIP=1661 PSI, FG=0.72 PSI/FT, PERF/XS FRIC= 1390 PSI. MONITOR PRESS F/30 MINS. PUMP 149 BBL PAD @ 25 BPM, LAST WHTP=6198 PSI. PUMP 10.1 MLBS 12/18 CL IN 2 PPA STAGE, SCREEN OUT 30 BBLS AFTER 2 PPA HIT PERFS. MAX WHTP= 8300 PSI. PUMP EXTRA 10 BBLS NON-XL GW @ 5-1 BPM & 8300 PSI TO FLUSH SURFACE LINES. TOT PROP: DESIGN=170.9 MLBS, IN FORM=2.9 MLBS & 2.0 PPA @ PERFS. TOT FLUIDS: WATER=498 BBLS, DSL(FLA)=17 BBLS, ADD'S=37 BBLS. ALL SAMPLES LOOKED GOOD. (ANGLEN/PALISCH/CHIVVIS) POST FRAC CTU COMPLETE, NO INFO RECEIVED. (ANGLEN) R£CE ¥£D N1A¥ 20 1994 Gas Cons. Commission Anchorage PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page' 1 Date' 02/08/94 RUN DATE_RECVD 91-1~Q~,~ CBT L 6000-I0485 1 12/09/91 1 11/27,/91 1 11/27/91 1 12/09/91 03/20/92 03/20/92 03/20/92 1 12/09/91 9 1 - 12 9 CDN L 3914-10599 91-129 CDR L 3914-10599 91-129 US!T 91-129 407 91-129 DAILY WELL OP SS DIRECTIONAL L 5770-10478 R COMP DATE:03/01/92 R 11/05/91-03/01/92 R 0-10598 91-129 5135 T 3787-10598, OH-CDR/CDN Are dry ditch samples required? yes ~And received? Was the well cored.? yes no Analysis & description received? Are well tests required? yes no Received? yes no Weli is ill compliance Initial 'yes ~ yes no STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing x;. Alter casing Stimulate __ Plugging __ Repair well __ Other Perforate 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 114' FSL,479' FWL, SEC 27, T11N, RSE, UM At top of productive interval 1817' FSL, 1839' FEL, SEC 22 , T11N, RSE, UM At effective depth 2154' FSL, 1736' FEL, SEC 22, T11N, RSE, UM At total depth 2237' FSL, 1711' FEL, SEC 22, T11N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 10598' 6118' feet feet 6. Datum elevation (DF or KB) RKB 147', PAD 105' 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-21 9. Permit number/approval number ~1-129 (Conserv Order No. 261) lO. APl number 50-103-20156 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 1 0501 ' true vertical 6073' feet feet Junk (measured) Casing Length Size Structural 8 0' 1 6" Conductor Surface 3874' 9-5/8" Intermediate Production 10547' 7' Cemented 22O SX AS II Measured depth 122 ' 543 SX PF E & 660 SX CLASS G, 110 SX PF "C' TOP JOB 280 SX CLASS G 3916' 10589' Liner Perforation depth: measured 10232'-10292', M D true vertical 5949'-5976', TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 10030' Packers and SSSV (type and measured depth) BAKER HVT RETR PKR @ 10004', CAMCO TRDP-4A-RO SSSV @ 1781' MD True vertical depth 122 ' 2819' 6114' RECEIV[D N0V - 3 1992 Alaska 0il & Gas Cons. 6omr~issi0r~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-~4~04 Rev (~/17/~9 Title Area Drillin~l Encjineer SUBMIT IN I~UPI_,I/CATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-21 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-103-20156 91-129 ACCEPT: 08/28/92 SPUD: RELEASE: 08/31/92 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 08/28/92 ( 1) TD: 8598 PB:10501 08/29/92 ( 2) TD: 8598 PB:10501 PREPARE TO PULL VR PLUG MW: 8.5 FSW MOVING RIG F/IL TO 2M PAD. HOLD RIG @ SPINE ROAD & iF/iL ROAD FOR ARCO CREW CHANGE. CONT MOVING RIG TO 2B PAD. ROAD SLOUGHED OFF & RIG STUCK COMING OFF 2B PAD. CRIB UP ROAD W/PLYWOOD & DRIVE RIG OUT. CONT MOVING RIG TO 4 WAY STOP, 2-1/2 MILES F/2M PAD. CONT MVE TO 2M PAD. ROAD VERY SOFT MOST OF THE WAY. CRIB UP W/PLYWOOD & GET STUCK 5 TIMES. HOOKUP 2-D8 WINCH CATS & PULL RIG LAST 1-1/4 MILE TO 2M PAD. REMOVE AUXILIARY WHEELS F/WELL HOUSE. INSTALL CELLAR STAIRS, CHOKE & KILL LINES. SET BOP STACK IN CELLAR. LAY OUT LINER UNDER RIG & SPOT MATTING BOARDS. MVE RIG OVER HOLE. (19 MILE RIG MVE). RIG ACCEPTED @ 05:00 HRS 08/28/92. LEVEL RIG. RU HARD LINE TO RIG. TIE-IN CHOKE LINE. PREPARE TO PULL VR PLUG F/3-1/2" X 7" ANN. WATER BACK & VISC BRINE MW: 9.8 NaCl/Br FIN PULLING VR PLUG & TIE IN CHOKE LINE. PULL BPV. RU TO KILL WELL. LOAD PITS W/SW. TIGHTEN ALL UNI-BOLT CONN ON HARD LINE TO OUTSIDE TANK & TO PROD FLOWLINE. TEST HARDLINE TO 800 PSI. OPEN WELL. LINE UP TO LOAD WELL W/SW, TAKING RETURNS THRU CHOKE DOWN PROD FLOWLINE. BLED ANN TO 220 PSI, FLUID RETURNS. BLEED GAS HEAD OFF TBG. LOAD TBG W/105 BBL 8.5 PPG SW, CIRC ON CHOKE @ 3 BPM. INJECT 20 BBLS SW TO FLUSH TAIL & PERFS @ 2 BPM. TRANSFER REMAINING SW TO PIT WHILE MONITOR WELL. RESUME CIRC ON CHOKE & LOAD WELL W/SW-GETTING 9.9 - 10.3 PPG RETURNS. SI & MONITOR WELL WHILE BRING ON BRINE & WATERING BACK TO 10.0 PPG. LOAD TBG W/ 10.0 PPG BRINE-CIRC. 96 BBLS @ 3 BPM, RETURNS THRU CHOKE DOWN PROD FLOWLINE. INJECT 20 BBLS @ 2 BPM TO FLUSH TAIL & PERFS. TBG ON VACUUM, SICP=250 PSI. BRING ON MORE BRINE & WATER BACK TO 9.8 PPG. CIRC 9.8 PPG BRINE INTO WELL UNTIL GETTING 10.0+ PPG RETURNS. SI & FREEZE PROTECT PRODUCTION FLOWLINE W/30 BBLS DIESEL. RESUME CIRC THRU OPEN CHOKE UNTIL 9.9 PPG RETURNS INTO PITS. MONITOR WELL-WELL DEAD & ON LIGHT VACUUM. SET BPV, ND FMC TREE. NU BOPE. SET TEST PLUG. TEST BOPE-0K. ACCUM TEST-OK. WITNESSING OF TEST WAIVED BY DOUG AMOS OF AOGCC. PULL TEST PLUG. PULL BPV. MU LD JT & CIRC LINES. FILL HOLE W/20 BBL. PULL TBG HGR TO FLOOR & LD SAME. MU CIRC HEAD. BREAK CIRC TO CBU. LOST 40+ BBLS AFTER CIRC 150 BBLS. SHUT DN CIRC & SI WELL. START WATERING BACK BRINE TO 9.6+-9.7 & VISC SYSTEM TO CONTROL FLUID LOSS. REEEJVED NOV - 5 !992 A~aska Oil & Gas Cons. CommissiO'c' Anchorage WELL : 2M-21 OPERATION: RIG : NORDIC 1 PAGE: 2 08/30/92 ( 3) TD: 8598 PB:10501 08/31/92 ( 4) TD: 8598 PB:10501 PREP TO LOC PBR & SP OUT MW: 9.6 NaC1/Br TRANS BRINE TO PITS. WATER BACK TO 9.6+ & VISC SURF BRINE TO 37 TO CONTROL LOSS. DISPLACE WELL TO 9.6+ PPG VISC BRINE. CIRC 155 BBL @ 38 BPM, 450 PSI-THEN REDUCE RATE. MONITOR WELL-VERY SLOW LOSS. LD 1 JT 3-1/2" TBG, PULLED WET. PMP 40 BBLS SLUG 9.8+ PPG CLEAR BRINE FOR DRY JOB. POH W/3-1/2" COMP STRING-CHANGE SEAL RINGS, DRIFT & STD BACK. LD CAMCO SSSV. LD OTIS GLMS -REPLACED W/REDRESSED MACCO SPM-1A GLM ON POH & STOOD BACK. LD OTIS LB GLM. LD OTIS LOCATOR/SEAL A$SY-SEALS SCUFFED UP & DAMAGED ON POH. RECOVERED 30 SS BANDS-1 LEFT IN HOLE. MU NEW SEAL ASYY ON OTIS LOCATOR. RIH W/3-1/2" COMP ASSY: OTIS LOCATOR/SEAL ASSY, 1 JT 3-1/2" TBG, NEW CAMCO MMG-2 GLM ASSY,REDRESSED MACCO SPM-1A GLMS W/DVS IN STANDS F/DERRICK, ETC. MU NEW CAMCO TRDP-4A-RO SSSV ASSY & TEST CONTROL LINE TO 5000 PSI-OK. CONT RUNNING STANDS OF 3-1/2" TBG, BANDING CL EVERY OTHER JT. LOST STAND IN HOLE @ 0600. PREP TO TAG, LOCATE, & SPACE OUT @ 0600. RIG RELEASED MW: 9.6 NaC1/Br SERV RIG. STAB-IN SEALS & LOC OUT Im OTIS PBR, VERIFY W/MUD PMP. SPACE OUT. INSTALL SPACE OUT PMPS 1 JT BELOW HGR. MU FMC TBG HGR. MU CONTROL LINE & TEST TO 5000 PSI-OK. LAND HGR. RILDS. BTM OF TBG TAIL @ 10030' OTIS HVT RETR PKR @ 10004' CAMCO SSSV @ 1781' RU OTIS SL. TEST LUB TO 1200 PSI. RIH & SET STANDING VALVE IN D-NIPPLE @ 10020' TEST STANDING VALVE TO 500 PSI. POH & RIG ASIDE SL. RU LINE TO TEST. PRESS ANN & TBG TO 1000 PSI. CLOSE SSSV. BLEED TBG ABOVE SSSV TO 500 PSI. EQUALIZE & REOPEN SSSV. PRESS ANN & TBG TO 2500 PSI-OK. HOLD ANN @ 2500 PSI, PRESS TBG TO 3500 PSI & TEST SEALS-OK. BLEED OFF PRESS. LDJT. SET BPV. ND BOPE. NU FMC TREE. TEST PACK-OFF-OK. PULL BPV. SET TP. TEST TREE TO 250 PSI & 5000 PSI-OK. RU TO DISPLACE WELL. BREAK CIRC & REVERSE IN WATER FLUSH, CHECK VALVE, PACKED OFF AFTER REVERSING 16 BBL WATER. RU OTIS SL. RIH TO PULL CV F/BTM GLM @ 9932' POH-3/4" CV LOOKS GOOD & FUNCTIONS OK. MU DV & HANG IN LUBRICATOR. REVERSE CIRC & DISPLACE WELL TO DIESEL. RIH W/SL & SET DV IN BTM GLM @ 9932'. BLEED OFF ANN & PRESS TBG TO 1000 PSI-0K. POH W/SL. RIH TO PULL STD VALVE F/D-NIPPLE @ 10020'. POH-MISRUN. CHANGE TOOLS. RIH & RETRV STANDING VALVE. RD OTIS SL. CLEAN REMAINING FLUIDS OUT OF PITS & RINSE DOWN PITS. DRAIN LINES. SECURE WELL. BACK OFF WELL. CLEAN LOCATION & PU PIT LINER UNDER CELLAR AREA. RIG RELEASED 03:00 HRS 08/31/92. SIGNATURE: DATE: NOV - 3 1992 ,Alaska 0ii & Gas Cons. L, ommissio~ Ar~chorage STATE OF ALASKA 0 R I G I N A L ALASKA OIL AND GAS CONSERVATION CL~MMISSION ~ .._~,~_~ WELL COMPLETION OR FIECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS ~ SUSPENDED F'-'] ABANDONED r~ SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-129 & 91-348(403 SA NO.) 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0 ~360;i, ~ ;;:~;~;~;~--.-~ 50-103-20156 4 Location of well at surface ' ' '~ ~: 9 Unit or Lease Name 114' FSL, 479' FWL, SEC 27, Tll N, RSE, U~...~.//~.~.~_ i KUPARUK RIVER At Top Producing Interval ~ ~./~!i~:i~ ~ 10 Well Number 1817 FSL, 1839 FEL, SEC22, Tl1., 2M-21 At Total Del~h 11 Field and Pool 2237' FSL, 1711' FEL, SEC 22, T11N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 147', PAD 105' GLI ADL 25571, ALK 2669 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 11/05/91. 11/11/91. 03/01/92.I N A feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 0,598' MD, 6118' TVD 10,501' MD, 6073' TVD YES ~ NO ~ 1792' feet MD 1400' APPROX 1 22 Type Electric or Other Logs Run CDR,CDN,GR,USIT, CBT, GYRO 23 CASING, LINER AND CEMENTING RECORD I SEl-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING-RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 123' 24" 220 SX ASII 9-5/8" 36# J-55 SURF 3916' 12-1/4" 543 SX PF E, 660 SX CLASS G 110 SX PFC TOP JOB 7" 26# J-55 SURF 10,589' 8-1/2" 280 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET IMD) PACKER SET (MD) 3-1/2" 10,030' 10,004' 10,232' -10,292' W/4-1/2" CSG GUN @ 4 SPF MD 5949'-5976' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,~ FIowTubing Casing Pressure CALCULATED OIL-BBL .GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE · 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Subrnit core chips, Alaska 0il & Gas Cons. Commts~,On Form 10-407 Anctmmg~ Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 10103' 5890' NA KUPARUK C BOTTOM 10153' 5913' KUPARUK A TOP 10157' 5915' KUPARUK A BOTTOM 10436' 6043' 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ....... ~~'~~ Title AREA DRILLING ENGINEER Date .~~-~ ~2_ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCQ ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-21 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25571 ALK 2669 50-103-20156 91-129 ACCEPT: 11/04/91 SPUD: 11/05/91 RELEASE: 11/14/91 OPERATION: DRILLING RIG: POOL 7 AFE: AK5989 WI: 55.252072 11/05/91 ( 1) TD: 800' ( 800) SUPV:KKL 11/06/91 (2) TD: 3532' (2732) SUPV:DS 11/07/91 (3) TD: 3926' ( 394) SUPV:DS 11/08/91 ( 4) TD: 3926'( SUPV:DS o) 11/09/91 (5) TD: 6542'(2616) SUPV:DS 11/10/91 ( 6) TD: 9812' (3270) SUPV:DS 11/11/91 ( 7) TD:10577' ( 765) SUPV:DS 11/12/91 (8) TD:10598' ( 21) SUPV:DS DRLG MW: 8.8 VIS: 50 DAILY:S39,215 CUM:$39,215 ETD:S39,215 EFC:$1,700,000 PUMP DRY JOB & POH MW: 9.7 VIS: 50 DRLD 800'-2523'. FLUID INFLUX FROM INJ WELL 2M-23. CIRC AND SI INJ WELL. DRLD 2523'-3532'. CIRC FOR BIT TRIP. DAILY:S65,556 CUM:$104,771 ETD:S104,771 EFC:$1,700,000 RU TO RUN 9-5/8" CSG MW:10.0 VIS: 47 CONTINUE POH, LOST 1/3 OF NOSE CONE FROM BIT, CHANGE BIT, REORIENT MW/), RIH, WASH AND REAM TIGHT SPOT @ 1640' SIDE , TRACK NOSE CONE, DRILL F/3531-3926, CIRC FOR SHORT TRIP TO HWDP, POH TO HWDP, NO TIGHT SPOTS, RIH, TIGHT F/1368- 1470, TAG BTM @ 3926', CIRC & COND MUD, PUMP 50 BBLS LOW VIS SWEEP AND 50 BBLS HI VIS SWEEP, POH, WASH AND REAM TIGHT SPOTS, POH TO HWDP, RIH, CONT WASH AND REAM TIGHT SPOTS, TAG BTM @ 3926', CIRC & COND MUD, PUMP 50 BBLS HI VIS SWEEP, POH, NO TIGHT SPOTS, LD MWD AND BIT, RU TO RUN 9-5/8" CSG DAILY:S45,065 CUM:$149,836 ETD:S149,836 EFC:$1,700,000 NU BOP 9-5/8"@ 3915' MW:10.1 VIS: 43 RAN 9-5/8" CSG. CMTD W/ 543 SX PF E AND 660 SX G. DID TOP JOB. SET SLIPS. WELD BRADENHEAD. NU BOP. DAILY:S155,973 CUM:$305,809 ETD:S305,809 EFC:$1,700,000 DRLG 9-5/8"@ 3915' MW: 9.2 VIS: 35 NU BOP. RIH. DRLD CMT. TESTED CSG 2000 PSI. DRLD FC, FS, 10' NEW HOLE. TESTED FORMATION TO 12.5 EMW. DRLD 3932'-6542' DAILY:S51,144 CUM:$356,953 ETD:S356,953 EFC:$1,70~,000 DRLG DRLD 6542'-9812' 9-5/8"@ 3915' MW:10.4 VIS: 38 DAILY:S66,440 CUM:$423,393 ETD:S423,393 EFC:$1,700,000 DRLG DRLD 9812'-10577' DAILY:S68,898 9-5/8"@ 3915' MW:10.6 VIS: 38 CUM: $492,291 ETD: $492,291 EFC: $1,700,000 LD BHA 9-5/8"@ 3915' MW:10.8 VIS: 40 DRLD 10577'-10598' POH. HOLE SWABBING. CIRC OUT GAS & INCR MW TO 10.8. SHORT TRIP. POH. DAILY:S82,109 CUM:$574,400 ETD:S574,400 EFC:$1,700,000 WELL: 2M-21 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 11/13/91 ( 9) TD:10598' ( 0) SUPV:DS 11/14/91 (10) TD:10598' ( SUPV:DS o) RUNNING 7" CSG 7"@10588' MW:10.8 VIS: 44 LD BHA. RAN USI LOG. RIH W/ BIT TO TD. CIRC. POH. DAILY:S145,168 CUM:$719,568 ETD:S719,568 EFC:$1,700,000 RIG RELEASED 7"@10588' MW:10.8 VIS: 0 RAN 7" CSG. LOST RETURNS WHILE CIRC. PMPD LCM. CMTD W/ 280 SX CL G. ND BOP. SET SLIPS. NU TBG HD. FREEZE PROTECTED ANNULUS. RELEASED RIG 11/14/91 0430. DAILY:S350,493 CUM:$1,070,061 ETD:S1,070,061 EFC:$1,700,000 SIGNATURE: ~ ~ DRILLING S~EkINTEND~T DATE: A~aska Oil & Gas Cons. ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-21 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25571 ALK 2669 50-103-20156 91-129 ACCEPT: 02/28/92 SPUD: RELEASE: 03/01/92 OPERATION: COMPLETION RIG: NORDIC AFE: AK5989 WI: 55.252072 02/29/92 (11) TD:10598 PB:10501 SUPV:SB/DB RIH W/ PERF GUN #2 7"@10588' MW:10.8 NaC1 MOVE RIG FROM 2M-19 TO 2M-21. ACCEPT RIG @ 2200 HRS, 28-FEB-92. ND TREE. Nil AND TEST BOP TO 3000 PSI. RU SWS. TEST LUBRICATOR TO 1500 PSI. MU AND RIH WI GUN # 1. PERFORATE F/10,272'-10,292' @ 4 SPF, 180 PHASING, ORIENTED. (COULD NOT GET PAST 10,306' W/GUNS) POH W/ GUN #1. MU AND RIH W/ GUN #2. NOTE: AFC FOR THIS WELL IS ACTUALLY AK5989. DAILY:S24,799 CUM:$1,094,860 ETD:SO EFC:$2,794,860 03/01/92 (12) TD:10598 PB:10501 SUPV:SB/DB RIG REL 7"@10588' MW:10.8 NaC1 CONT RIH W/GUN #2 PERF FROM 10252'-10272' @ 4 SPF 180 PHASING ORIENTED. POH. MU AND RIH W/ GUN #3. PERF F/10232-10252' @ 4 SPF 180 PHASING, ORIENTED. POH LD SWS WL. RU FLOOR FOR TBG. RIH W/3-1/2" SINGLE COMPL ASSY. PU AND MU CAMCO SSSV. ATTACH CL AND TEST SAME TO 5000 PSI. CONT RIH W/TBG. PU AND MU TBG HANGER. ATTACH CONTROL LINE, AND TEST SAME TO 5000 PSI - OK. (DROP PKR SETTING BALL 10 JTS BEFORE HANGER) LAND TBG. RILDS. PRESS TBG TO 500 PSI AND HOLD FOR 5 MIN. INCR PRESS TO 1500 PSI TO SET PKR. INCR PRESS IN 500 PSI INCR TO 3000 PSI. BLEED OFF PRESS. BOLDS. PRESSTBG TO 2000 PSI AND PU 112 K TO SHEAR PBR. BLEED OFF PRESS. RE LAND TBG. RI LDS. TEST SSSV TO 1000 PSI FOR 15 MIN - OK. PRESS TEST ANN TO 2500 PSI FOR 15 MIN - OK. PRESS TBG TO 3700 PSI TO SHEAR SOS. SET BPV AND ND BOP. NU TREE. PULL BPV, SET TEST PLUG. TEST TREE AND PACK OFF TO 5000 PSI - OK. PULL TEST PLUG. RU PUMP LINES. PUMP 14 BBL DIESEL DOWN ANN TAKING RETRUNS ON TBG. CV NEARLY PLUGGED OFF(PUMPING @ 0.5 BPM @ 3000 PSI). BULLHEAD 5 BBL DIESEL DOWN TBG. BLEED OFF 1 BBL DIESEL FROM 7" TO BLEED PRESS OFF. SI TBG PRESS = 200 SPI, SI 7" CSG PRESS = 0 PSI. RD PUMP LINES. CLEAN MUD PITS. SECURE WELL. MOVE RIG OFF WELL. CLEAN LOCATION AROUND WELL. REL RIG @ 0330 3/1/392 DAILY:S201,136 CUM:$1,295,996 ETD:SO EFC:$2,995,996 SIGNATURE: ~ ~ DRILLING S~ERINTEN~T ORIGINAL SUB - SURFA CE DIRECTIONAL r~l UIDANCE I'~ ONTINUOUS ~ OOL SURVEY RECEIVED Company ARCO ALASKA, INC. MAR 2 0 1992 Alaska .Oil .& Gas Cons. commiss~O~ ~chorage i Well Name 2M-21(114'FSL,479'FWL,SEC 27,T11N,R8E) i Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 75323 Locjcjed By: D. WARNER Date 28-NOV-1991 Computed BV:_ R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2M - ;'1 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 28-NOV-g1 ENGINEER: D. WARNER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged Oeviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 23 DEG 55 MIN EAST COMPUTATION DATE: 05-JAN-92 PAGE 1 ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-NOV-gl KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0.00 -140.00 100 O0 -40.00 2OO O0 60.00 3OO O0 160.00 399 95 259 95 499 61 359 61 598 81 458 81 697 6O 557 6O 796.26 656 894.63 754 0 0 N 0 0 E 0 10 N 3 9 W 0 8 N 71 0 E 0 34 N 13 57 E 3 9 N 23 52 E 5 29 N 27 1 E 8 34 N 29 55 E 9 11 N 29 37 E 26 9 46 N 30 17 E 63 10 52 N 30 O E 0 O0 0 16 0 29 0 90 3 55 11 67 24 18 39 62 55 84 73 68 0 O0 0 O0 0 2O 0 37 4 22 1 75 1 53 0 52 2 O9 0 90 0 O0 N 0 14 N 0 28 N 0 81 N 3 31N 10 60 N 21 58 N 35 08 N 49 23 N 64 72 N 0 O0 E 0 06 E 0 09 E 0 40 E 1 28 E 4 88 E 10 99 E 18 63 E 26 73 E 35 81 E 0.00 N 0 0 E 0.16 N 22 44 E 0.29 N 17 23 E 0.90 N 26 20 E 3 55 N 21 13 E 11 67 N 24 44 E 24 22 N 27 0 E 39 72 N 27 58 E 56 01 N 28 30 E 73 97 N 28 57 E 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 992.64 852.64 12 16 O0 1090.00 950.00 13 53 O0 1186.77 1046.77 15 31 O0 1282.30 1142.30 19 1 O0 1375.72 1235.72 22 52 O0 1466.35 1326.35 26 53 O0 1553.19 1413.19 32 59 O0 1633.11 1493.11 40 53 O0 1704.68 1564.68 47 17 O0 1768.87 1628.87 52 38 N 27 42 E N 26 19 E N 25 37 E N 25 16 E N 23 36 E N 21 38 E N 21 48 E N 23 8 E N 23 29 E 427 N 25 11E 504 93.45 116.22 141.38 170 88 206 47 248 68 298 09 358 O0 74 36 2 44 081 2 47 4 O0 4 3 7 8 5 4 65 62 83 05 56 73 82 08 N 102 125 151 184 223 269 324 388 458 45 42 E 42 N 55 07 N 66 71N 79 08 N 94 10 N 110 08 N 128 43 N 151 53 N 179 29 N 210 93.81 N 28 58 E 73 E 116.60 N 28 33 E 74 E 141.76 N 28 5 E 41 E 171.24 N 27 38 E 21 E 206.79 N 27 6 E 33 E 248.89 N 26 19 E 53 E 298.21 N 25 32 E 52 E 358.07 N 25 2 E 02 E 427.79 N 24 44 E 70 E 504.40 N 24 41 E 2000.00 1826.79 1686.79 56 22 N 26 52 E 585 79 2100.00 1880.08 1740.08 59 14 N 27 34 E 670 23 2200.00 1929.61 1789.61 61 5 N 26 57 E 756 96 2300.00 1977.86 1837.86 60 56 N 26 57 E 844 42 2400.00 2026.46 1886.46 61 4 N 25 21 E 931 74 2500.00 2074.52 1934.52 61 27 N 25 14 E 1019 42 2600.00 2122.58 1982.58 61 0 N 25 36 E 1107.08 2700.00 2171.74 2031.74 60 13 N 25 32 E 1194.13 2800,00 2221,60 2081.60 59 58 N 27 0 E 1280.74 2900.00 2271.69 2131.69 60 12 N 27 0 E 1367.13 3 54 2 65 0 90 1 51 0 76 0 40 1 04 091 1 67 3 14 531.53 N 246 41 E 585.87 N 24 52 E 606 66 N 285 31 E 670.40 N 25 11 E 683 761 840 919 998 1077 1155 1232 89 N 325 07 E 757.22 N 25 25 E 96 N 364 79 E 844.78 N 25 35 E 40 N 403 31 E 932.16 N 25 38 E 72 N 440 71 E 1019.86 N 25 36 E 88 N 478 43 E 1107.55 N 25 36 E 51 N 515 87 E 1194.63 N 25 35 E 29 N 554.12 E 1281.30 N 25 37 E 15 N 593.92 E 1367.82 N 25 44 E 3000.00 2320.74 2180.74 60 49 3100.00 2370.29 2230.29 59 37 3200.00 2421.79 2281.79 58 19 3300.00 2475 69 2335.69 56 21 3400.00 2532 84 2392.84 54 5 3500.00 2591 33 2451.33 54 47 3600.00 2649 48 2509.48 53 54 3700.00 2706 65 2566.65 56 53 3800.00 2758 86 2618.86 59 39 3900.00 2810 31 2670.31 58 21 N 25 8 E 1454.23 N 24 22 E 1541 07 N 23 33 E 1626 N 24 51 E 1711 N 26 1 E 1793 N 25 16 E 1874 N 25 24 E 1955 N 22 55 E 2037 N 22 25 E 2122 N 23 57 E 2208 78 O0 01 O9 41 42 67 41 0 99 301 2 04 2 55 1 74 1 52 1 69 4 3O 0 96 1 67 1310.66 N 631.72 E 1454.96 N 25 44 E 1389.34 N 668.51 E 1541.81 N 25 42 E 1467.87 N 702.86 E 1627.46 N 25 35 E 1544 69 N 737.38 E 1711.67 N 25 31 E 1618 73 N 772.72 E 1793.71 N 25 31 E 1691 83 N 807.88 E 1874.82 N 25 32 E 1765 31 N 842.78 E 1956.17 N 25 31 E 1840 13 N 876.39 E 2038.17 N 25 28 E 1918 92 N 908.99 E 2123.33 N 25 21 E 1997 71 N 942.81 E 2209.01 N 25 16 E ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 05-JAN-92 PAGE 2 DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 2863 22 2723.22 57 58 4100.00 2916 47 2776.47 57 45 4200.00 2969 71 2829.71 57 54 4300.00 3022 85 2882.85 57 49 4400.00 3076 10 2936.10 57 53 4500.00 3128 13 2988.13 59 24 4600.00 3178.69 3038.69 59 47 4700.00 3229.07 3089.07 59 37 4800.00 3280.00 3140.00 59 10 4900.00 3331.40 3191.40 59 N 23 49 E 2293.27 N 23 45 E 2377.91 N 23 34 E 2462.55 N 23 42 E 2547.27 N 23 42 E 2631.91 N 23 27 E 2717.30 N 23 19 E 2803.57 N 23 10 E 2889.95 N 22 54 E 2975.99 N 22 41 E 3061.76 0.39 0.45 0.37 0.34 0.55 0.88 0.19 0.56 0.48 0.16 2075.27 N 977 24 E 2293 85 N 25 13 E 2152.74 N 1011 2230.27 N 1045 2307 88 N 1079 2385 37 N 1113 2463 62 N 1147 2542 84 N 1181 2622 19 N 1215 2701 39 N ~249 2780 49 N 1282 35 E 2378 32 E 2463 28 E 2547 32 E 2632 51 E 2717 70 E 2804 82 E 2890 48 E 2976 69 E 3062 47 N 25 10 E 09 N 25 7 E 77 N 25 4 E 39 N 25 1 E 76 N 24 59 E O0 I~ 24 56 E 35 ~ 24 53 E 36 N 24 49 E 09 N 24 46 E 5000 O0 3382.99 3242.99 58 54 5100 5200 5300 54OO 5500 5600 570O 5800 5900 O0 3434.63 3294.63 58 54 O0 3486.22 3346.22 59 O0 3537.69 3397 69 59 5 O0 3588.92 3448 92 59 16 O0 3639.92 3499 92 59 21 O0 3690.91 3550 91 59 19 O0 3742.00 3602 O0 59 15 O0 3793.05 3653 05 59 19 O0 3844.02 3704.02 59 27 N 22 38 E 3147.40 N 22 35 E 3233.01 N 22 34 E 3318.65 N 22 25 E 3404.36 N 22 5 E 3490.21 N 21 49 E 3576.18 N 21 42 E 3662.14 N 21 33 E 3748.03 N 21 29 E 3833.94 N 21 30 E 3919,90 0.15 0.07 0.01 0.34 0.30 0.33 0.18 0.12 0.23 0.03 2859 54 N 1315.68 E 3147.70 N 24 42 E 2938 60 N 1348.60 E 3233.28 N 24 39 E 3017 69 N 1381.49 E 3318.89 N 24 36 E 3096 90 N 1414.32 E 3404.57 N 24 33 E 3176 39 N 1446.84 E 3490.39 N 24 29 E 3256 17 N 1478.99 E 3576.32 N 24 26 E 3336 07 N 1510.87 E 3662.25 N 24 22 E 3415 98 N 1542.54 E 3748.12 N 24 18 E 3495.98 N 1574.08 E 3834.00 N 24 14 E 3576.04 N 1605.58 E 3919.94 N 24 11 E 6000.00 3894.79 3754 79 59 28 6100.00 3945.64 3805 6200.00 3996.65 3856 6300.00 4047.71 3907 6400 O0 4098.79 3958 6500 O0 4150.04 4010 6600 O0 4201.48 4061 6700 O0 4252.99 4112 6800 O0 4304,36 4164 6900 O0 4355.72 4215 64 59 23 65 59 18 71 59 20 79 59 10 04 59 7 48 58 59 99 59 2 36 59 10 72 59 1 N 21 32 E 4005.98 N 21 23 E 4092 01 N 21 11 E 4177 N 21 1 E 4263 N 22 15 E 4349 N 23 0 E 4435 N 22 46 E 4521 N 22 29 E 4606 N 22 24 E 4692 N 22 28 E 4778 93 81 69 54 28 97 74 51 0 11 0 27 0 25 0 3O 2 43 0 25 0 23 015 0 11 0.34 3656.19 N 1637 17 E 4006 01 N 24 7 E 3736.32 N 1668 3816.47 N 1699 3896.68 N 1730 3976.74 N 1762 4055.87 N 1795 4134.87 N 1828 4213.99 N 1861 4293.30 N 1894. 4372.61 N 1927 69 E 4092 92 E 4177 87 E 4263 20 E 4349 54 E 4435 90 E 4521 87 E 4606 59 E 4692 34 E 4778 02 N 24 4 E 93 N 24 1 E 81 N 23 57 E 69 N 23 54 E 54 N 23 53 E 28 N 23 52 E 98 N 23 50 E 75 N 23 49 E 53 N 23 47 E 7000 O0 4407.45 4267 45 58 43 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 4459.43 4319 O0 4511.22 4371 O0 4561.98 4421 O0 4612 30 4472 O0 4662 53 4522 O0 4712 52 4572 O0 4762 19 4622 O0 4811 83 4671 O0 4862 11 4722 43 58 39 22 59 9 98 59 46 30 59 43 53 59 57 52 60 4 19 60 21 83 60 11 59 36 N 23 44 E 4864.08 N 23 53 E 4949.51 N 24 28 E 5035 06 N 24 54 E 5121 21 N 24 37 E 5207 61 N 24 22 E 5294 07 N 23 57 E 5380 68 N 23 36 E 5467 48 N 23 0 E 5554 28 N 22 46 E 5640 71 1.05 0.20 1 .80 0.63 0.26 0.32 0.36 0.32 0.89 0.84 4451.37 N 1960.81 E 4864 10 N 23 46 E 4529.48 N 1995.41 E 4949 53 N 23 47 E 4607.61 N 2030.24 E 5035 07 N 23 47 E 4685.80 N 2066 44 E 5121 22 N 23 48 E 4764.27 N 2102 62 E 5207 62 N 23 49 E 4842.96 N 2138 48 E 5294 08 N 23 49 E 4921.98 N 2173 93 E 5380 69 N 23 50 E 5001.41 N 2208 92 E 5467.48 N 23 50 E 5081.12 N 2243 29 E 5554.29 N 23 49 E 5160.78 N 2276 85 E 5640.72 N 23 48 E COMPUTATION DATE: 05-JAN-92 PAGE 3 ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WES3 DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG 8000 O0 4913.18 4773 18 58 53 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 4965.13 4825 O0 5016.62 4876~ O0 5067.84 4927 O0 5117.35 4977 O0 5162.99 5022 O0 5208.13 5068 O0 5253.29 5113 O0 5298.46 5158 O0 5343.09 5203 13 58 49 62 59 8 84 59 15 35 62 6 99 63 9 13 63 8 29 63 10 46 63 12 09 63 49 N 22 32 E 5726.66 N 22 58 E 5812 09 N 22 50 E 5897 N 22 29 E 5983 N 22 45 E 6070 N 22 45 E 6159 N 22 26 E 6248 N 22 4 E 6337 N 21 45 E 6427 N 21 19 E 6516 80 66 51 46 67 8~ 43 1 47 0 93 0 48 0 22 3 45 0 22 O 52 0 43 0 75 0 6~ 5240 10 N 2310.02 E 5726.67 N 23 47 E 5318 539~ 5477 5557 5639 5721 5804 5887 5970 95 N 2342,93 E 5812.11 N 23 46 E 88 N 2376.37 E 5897.82 N 23 46 E 16 N 2409.41 E 5983.69 N 23 45 E 36 N 2442.79 E 6070.54 N 23 44 E 39 N 2477.25 E 6159.50 N 23 43 E 75 N 2511.58 E 6248.72 N 23 42 E 34 N 2545.34 E 6337.9] N 23 41 E 10 N 2578.66 E 6427.0~ N 23 39 E 35 N 26~.50 E 6516.52 N 23 38 E 9000.00 5386.86 5246.86 64 14 9100.00 5430.27 5290.27 64 19 9200.00 5474.17 5334.17 63 5 9300.00 5520.39 5380.39 62 15 9400.00 5566.83 5426.83 62 9500.00 5613.03 5473.03 62 36 9600.00 5658.93 5518.93 62 42 9700.00 5704.88 5564.88 62 42 9800.00 5750.77 5610.77 62 40 9900.00 5796.43 5656.43 62 54 N 21 4 E 6606.24 N 20 41 E 6696.20 N 20 15 E 6785.88 N 19 44 E 6874.35 N 19 12 E 6962.64 N 18 43 E 7051.00 N 18 23 E 7139.45 N 18 7 E 7227.84 N 17 55 E 7316.21 N 17 50 E 7404.68 031 0 2 0 0 0 0 0 0 0 6054 19 N 2643.97 E 6606.35 N 23 36 E 61 6138 35 N 2676.11 E 6696.33 N 23 33 E 77 6222 53 N 2707.49 E 6786.05 N 23 31 E 67 6305 85 N 2737 86 E 6874.56' N 23 28 E 56 6389 35 N 2767 38 E 6962.91 N 23 25 E 38 6473 22 N 2796 18 E 7051.33 N 23 22 E 46 6557 45 N 2824 47 E 7139,87 N 23 18 E 33 6641.80 N 2852 28 E 7228.34 N 23 14 E 39 6726.29 N 2879 76 E 7316.83 N 23 11 E 55 6810.97 N 2907 05 E 7405.42 N 23 7 E 10000.00 5842 30 5702.30 62 32 10100.00 5888 39 5748.39 62 37 10200.00 5934 48 5794.48 62 34 10300.00 5980 44 5840.44 62 38 10400.00 602655 5886.55 62 23 10500.00 6072 81 5932.81 62 28 10598.00 6118 12 5978.12 62 28 N 17 47 E 7493.03 N 17 41 E 7581 27 N 17 1 E 7669 42 N 16 53 E 7757 58 N 16 51 E 7845 64 N 16 49 E 7933 73 N 16 49 E 8019 96 0 15 0 76 0 30 0 23 031 0 O0 0 O0 6895 58 N 2934.18 E 7493.90 N 23 3 E 6980 09 N 2961 29 E 7582 27 N 22 59 E 7064 83 N 2987 63 E 7670 58 N 22 55 E 7149 77 N 3013 57 E 7758 92 N 22 51 E 7234 69 N 3039 33 E 7847 18 N 22 47 E 7319 62 N 3065 10 E 7935 47 N 22 43 E 7402 80 N 3090 23 E 8021 91 N 22 39 E COMPUTATION DATE: 05-JAN-92 PAGE 4 ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATE5 HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 -140 O0 0 0 N 0 0 E O0 992 64 852 O0 1826 79 1686 O0 2320 74 2180 O0 2863 22 2723 O0 3382 99 3242 O0 3894 79 3754 O0 4407 45 4267 O0 4913 18 4773 O0 5386 86 5246 0 O0 64 12 16 N 27 42 E 93 45 79 56 22 N 26 52 E 585 79 74 60 49 N 25 8 E 1454 23 22 57 58 N 23 49 E 2293 27 99 58 54 N 22 38 E 3147 40 79 59 28 N 21 32 E 4005 98 45 58 43 N 23 44 E 4864 08 18 58 53 N 22 32 E 5726.66 86 64 14 N 21 4 E 6606.24 0.00 2.44 82 3.54 531 0.99 1310 0.39 2075 0.15 2859 0.11 3656 1.05 4451 1.47 5240 0.31 6054 0 O0 N 08 N 45.42 E 93 53 N 246.41 E 585 66 N 631.72 E 1454 27 N 977.24 E 2293 54 N 1315.68 E 3147 19 N 1637.17 E 4006 37 N 1960.8~ E 4864 10 N 2310.02 E 5726 19 N 2643.97 E 6606 0.00 E 0 O0 N 0 0 E 81 N 28 58 E 87 N 24 52 E 96 N 25 44 E 85 N 25 13 E 70 N 24 42 E 01 N 24 7 E 10 N 23 46 E 67 N 23 47 E 35 N 23 36 E 10000.00 5842.30 5702.30 62 32 N 17 47 E 7493.03 10598.00 6118.12 5978.12 62 28 N 16 49 E 8019.96 0.15 6895.58 N 2934.18 E 7493.90 N 23 3 E 0.00 7402.B0 N 3090.23 E 8021.91 N 22 39 E COMPUTATION DATE: 05-JAN-92 PAGE 5 ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE. ALASKA DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M[N VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 140.00 240.00 340.01 440.15 540.63 641.68 742.96 844.43 946.23 0.00 -140.00 140.00 240.00 340 O0 440 O0 54O O0 640 O0 740 O0 840 O0 940 O0 0 0 N 0 0 E 0.00 0 5 N 13 8 W 100.00 0 19 N 41 6 E 200.00 1 3 N 16 49 E 300.00 4 44 N 26 6 E 400.00 7 3 N 28 49 E 500.00 8 54 N 29 18 E 600.00 9 19 N 29 45 E 700.00 10 18 N 30 34 E 800.00 11 18 N 29 17 E 0 O0 0 23 0 42 1 41 6 33 16 06 3O 52 46 49 63 57 82 50 0 O0 0 O0 0 67 2 54 1 92 4 42 0 O0 0 46 0 54 1 3O 0 O0 N 0 23 N 0 37 N 1 30 N 5 83 N 14 49 N 27 11 N 41 08 N 55 94 N 72 42 N 0.00 E 0.05 E 0 0.20 E 0 0.53 E 1 2,48 E 6 6.94 E 16 14.14 E 30 22.05 E 46 30.67 E 63 40.20 E 82 0 O0 N 0 0 E 24 N 11 27 E 42 N 29 6 E 41 N 21 57 E 33 N 23 5 E 06 N 25 36 E 58 N 27 32 E 63 N 28 14 E 80 N 28 44 E 83 N 29 2 E 1048.56 1040.00 900.00 13 16 N 26 49 E 1151.58 1140.00 1000.00 14 32 N 25 55 E 1255.48 1240.00 1100.00 17 15 N 25 27 E 1361.45 1340.00 1200,00 21 16 N 24 30 E 1470.56 1440.00 1300.00 25 49 N 21 58 E 1584.27 1540.00 1400.00 31 46 N 21 37 E 1709.24 1640.00 1500.00 41 35 N 23 9 E 1853.69 1740.00 1600,00 50 13 N 24 29 E 2023.97 1840.00 1700.00 57 6 N 27 18 E 2221.53 1940.00 1800.00 61 14 N 26 56 E 104.17 128.87 157.00 191.98 235.56 289.52 364.15 468.16 605.76 775.79 1 .63 1 .66 3.80 8.84 3.74 7.79 7.72 5.72 2,96 0.50 91.63 N 113.79 N 61.30 E 129 139.16 N 73.47 E 157 170.84 N 88.31 E 192 210.91 N 105.47 E 235 261.13 N 125.35 E 289 330.08 N 153.94 E 364 425.44 N 195.49 E 468 549.36 N 255.48 E 605 700.70 N 333.61 E 776 50.33 E 104 54 N 28 47 E 25 N 28 19 E 37 N 27 50 E 32 N 27 2O E 81 N 26 34 E 66 N 25 39 E 21 N 25 0 E 20 N 24 41 E 86 N 24 56 E 07 N 25 28 E 2428.02 2040.00 1900 O0 61 13 2635.73 2140.00 2000 2836.69 2240.00 2100 3039.33 2340.00 2200 3234.36 2440 O0 2300 3412.22 2540 O0 2400 3583.87 2640 O0 2500 3762.90 2740 O0 2600 3956.24 2840 O0 2700 4144.15 2940 O0 2800 O0 60 39 O0 59 51 O0 60 31 O0 57 43 O0 53 52 O0 54 2 O0 59 13 O0 57 57 O0 57 50 N 25 13 E 956.27 N 25 25 E 1138.26 N 27 32 E 1312.43 N 25 22 E 1488.5~ N 24 ~ E 1655.9~ N 26 3 E 1802.9i N 25 30 E 1942.37 N 22 17 E 2090.74 N 23 57 E 2256.17 N 23 41 E 2415.26 0,60 1 11 1 18 1 22 2 3,4 1 14 2 02 2.87 0.30 0.31 862 58 N 413,80 E 956.70 N 25 38 E 1027 1183 1341 1494 1627 1753 1889 2041 2186 04 N 491.86 E 1138.74 N 25 35 E 51 N 568.66 E 1313.04 N 25 40 E 68 N 646.34 E 1489.25 N 25 43 E 53 N 714.61 E 1656.59 N 25 33 E 63 N 777.06 E 1803.61 N 25 31 E 54 N 837.18 E 1943.13 N 25 31 E 38 N 896.84 E 2091.43 N 25 24 E 35 N 962.23 E 2256.77 N 25 14 E 94 N 1026.38 E 2415.81 N 25 9 E 4332.21 3040.00 2900 O0 57 49 4523.35 3140,00 3000 4721.56 3240.00 3100 4916.69 3340 O0 3200 5110.39 3440 O0 3300 5304.48 3540 O0 3400 5500.16 3640 O0 3500 5696.09 3740 O0 3600 5892.09 3840 O0 3700 6088.93 3940 O0 3800 O0 59 34 O0 59 31 O0 58 59 O0 58 54 O0 59 6 O0 59 2~ O0 59 15 O0 59 26 O0 59 24 N 23 44 E 2574.53 N 23 21 E 2737.41 N 23 6 E 2908.53 N 22 40 E 3076.06 N 22 35 E 3241 91 N 22 25 E 3408 21 N 21 49 E 3576 31 N 21 33 E 3744 67 N 21 29 E 3913 10 N 21 25 E 4082 49 0.31 0 39 0 57 0 23 0 O6 0 0 0 0 0 2332.84 N 1090.24 E 2575.03 N 25 3 E 2482.07 N 1155:50 E 2737.86 N 24 58 E 2639.29 N 1223.12 E 2908.93 N 24 52 E 2793.69 N 1288.20 E 3076.38 N 24 45 E 2946.81 N 1352.02 E 3242.17 N 24 39 E 36 3100.45 N 1415.79 E 3408.41 N 24 33 E 33 3256.30 N 1479.04 E 3576.45 N 24 26 E 12 3412.85 N 1541.31 E 3744.76 N 24 18 E 05 3569.70 N 1603.09 E 3913.14 N 24 11 E 26 · 3727.45 N 1665.21 E 4082.50 N 24 4 E COMPUTATION DATE: 05-JAN-92 PAGE 6 ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140,00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 6284.89 4040 O0 3900.00 59 19 N 21 3 E 4250 83 6480.43 4140 6674.76 4240 6869.44 4340 7062.63 4440 7256.49 4540 7455.06 4640 7655.20 4740 7856.17 4840 8051.64 4940 O0 4000.00 59 10 N 23 2 E 4418 O0 4100.00 59 1 N 22 33 E 4585 O0 4200.00 59 4 N 22 27 E 4752 O0 4300.00 58 40 N 23 56 E 4917 O0 4400.00 59 34 N 24 58 E 5083 O0 4500.00 59 52 N 24 29 E 5255 O0 4600.00 60 15 N 23 45 E 5428 O0 4700.00 59 49 N 22 48 E 5602 O0 4800.00 58 38 N 22 37 E 5770 0 28 3884.55 N 1726 21 E 4250.83 N 23 58 E 74 34 32 60 66 19 56 8£ 7.'7, 28 4040.40 N 1788 26 4194.00 N 1853 O0 4348.39 N 1917 30 4500.30 N 1982 49 4651.74 N 2050 36 4807.56 N 2122 64 4965.76 N 2193 20 5125.88 N 2262 57 5280.85 N 2326 97 E 4418.74 N 23 53 E 58 E 4585.34 N 23 51 E 33 E 4752.33 N 23 48 E 47 E 4917 61 N 23 46 E 60 E 5083 67 N 23 47 E 40 E 5255 20 N 23 49 E 29 E 5428 57 N 23 50 E 19 E 5602 87 N 23 49 E 94 E 5770 79 N 23 47 E 8245.59 5040.00 4900.00 59 10 N 22 37 E 5936.93 8449.22 5140.00 5000.00 63 0 N 22 49 E 6114.19 8670.56 5240.00 5100.00 63 11 N 22 9 E 6311.60 8893.00 5340.00 5200.00 63 46 N 21 21 E 6510.15 9122.45 5440.00 5300.00 64 21 N 20 34 E 6716.39 9342.18 5540.00 5400.00 62 20 N 19 30 E 6911.59 9558.71 5640.00 5500.00 62 43 N 18 33 E 7102.93 9776.54 5740.00 5600.00 62 38 N 17 58 E 7295.49 9995,01 5840.00 5700.00 62 33 N 17 47 E 7488.63 10212.00 5940.00 5800.00 62 36 N 17 1 E 7679.99 0.58 5433.98 N 2391.49 E 5936 95 N 23 45 E 0.53 5597.64 N 2459.72 E 6114 0.51 5780.00 N 2535.45 E 6311 0.59 5964.49 N 2609 22 E 6510 0.43 6157.28 N 2683 24 E 6716 0.39 6341.03 N 2750 40 E 6911 0.32 6522.64 N 2812 85 E 7103 0.23 6706.46 N 2873 35 E 7296 0.21 6891.36 N 2932 82 E 7489 0,27 7075.02 N 2990 75 E 7681 22 N 23 43 E 65 N 23 41 E 23 N 23 38 E 53 N 23 33 E 82 N 23 27 E 31 N 23 20 E 08 N 23 12 E 48 N 23 3 E 18 N 22 55 E 10429.01 6040.00 5900.00 62 28 N 16 48 E 7871.15 10598.00 6118.12 5978.12 62 28 N 16 49 E 8019.96 0.81 7259.29 N 3046.76 E 7872.74 N 22 46 E 0.00 7402.80 N 3090.23 E 8021.91 N 22 39 E COMPUTATION DATE: 05-JAN-92 PAGE 7 ARCO ALASKA, [NC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8 CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7 CASING TD DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 114' FSL & 479' FWL, SEC27 T11N RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3916.00 10103 O0 10153 O0 10157 O0 10436 O0 10436 70 10501 O0 10589 O0 10598 O0 2818.70 5889.77 5912.80 5914 65 6043 23 6043 55 6073 27 61!3 96 6118 12 2678.70 5749.77 5772.80 5774.65 5903.23 5903.55 5933.27 5973.96 5978.12 2010.17 N 6982.62 N 7024.97 N 7028 36 N 7265 23 N 7265 89 N 7320 47 K 7395 17 N 7402 80 ~ 948.34 E 2962 10 E 2975 38 E 2976 43 E 3O48 55 E 3048 87 E 3065 36 E 3087 92 E 3090 23 E COMPUTATION DATE: 05-JAN-92 PAGE 8 ARCO ALASKA, INC. 2M - 21 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8 CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7 CASING TD DATE OF SURVEY: 28-NOV-91 KELLY BUSHING ELEVATION: 140.00 FT ENGINEER: D. WARNER SURFACE LOCATION = 114' FSL & 479' FWL, 5EC27 T11N RSE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3916.00 10103.00 10153.00 10157 O0 10436 O0 10436 70 10501 O0 10589 O0 10598 O0 2818 70 5889 77 5912 80 5914 65 6043 23 6043 55 6073 2; 6113 96 61~8 12 2678 ?0 5749 77 5772 80 5774 65 5903 23 5903 55 5933 27 5973 96 5978 12 2010. 17 N 6982.62 N 7024.97 N 7028.36 N 7265.23 N 7265.89 ~ 7320.47 N 7395. 17 N 7402.80 N 948.34 E 2962 10 E 2975 38 E 2976 43 E 3048 55 E 3048 87 E 3065 36 E 3087 92 E 309O 23 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10598.00 6118.12 5978.12 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8021.91 N 22 39 E DIRECTIONAL SURVEY COMPANY FIELD COUNTRY RUN ARCO ALASKA, INC. 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"'?"?i .......... ~ ....... ~"'~ ....... ~ ................ i ....... ~ ....... "'."","'"~'"~ ....... ."'"!"T"? ...... :'"'F".""':' ..... ?'!"?': ...... !"':'"!'-~ ....... !'"?"'?'! '":'"'?'?":'"'J '"..'"'F"?"!" ~"'?"'??~ ...... "'.:'-.:"',:'"~ ..... ~"'.:'".:'"~ ...... .:"'~-"!-".:'":--i'"i'-.,"-.~ ...... i"+-+--i ...... :'-'i'-+'-~ ..... ,;--'i"..~'"~ ..... ~'.'i"'i.-', ...... ~--+--~--~ '"!"+"!'"!"i"'!"'!"T"! ..... !'":'"i'": .... ~'"?i'"!'": ~-" ~ : :" : : i :. ". ! ' : i : :. ' i ' i :. ~ :. ! ', :. : : i i :, :, i : :. :, . : : I : ! ' : ~'.' ! ! ~ ! ! ! ! .: : : : .. ~ : : .. : : . :. : - : : : : : . : ............ : ' : : : ·. : ".'."'T"T'.'F"'"F'T"'?!":'":'-.""'.:"r'~-."'"."'"!"'? ...... ?"?'"~ '"!'"?? ..... :'"'..'?"? ..... r"~'"? "'?":'"!'-i ..... !"'i"'!"'!'" ,..:.,~...~...~ ............. .,,...:...........~...:.. _~ .... :...:...;...: ...... :...;...;...; ...... ;.. :...: ......... :...;...:...: ..... :...:,..:...: ...... :...: ............. -.,--.,-+-: ::::::::::::::::::::::: ::i:::i:: :::i:::!:::!::;::: ::: :: :::::::::::::::::::::::::::::: WELL' 2M-21 ( 114'FSL,479'FWL,SEC 27,TllN,RSE) VERTICAL PROJECT~ON AOGCC GEOLOGICAL MAT£RIALS INVENTOFIY LIST COMPLETION DAI'E ~ ! ,// /, ,~;P'~' CO. CONTACT & NO. //~2~ O form ' received receive'd da~e comments 40, ~.~ no .,~/..;~,/~~ completion report 403 ..... yes 'no '" sUndry application 404' ' yes no report oi Sundry application hole log hole log MUD GCT ( .~/ "D'iUSFL .... CNL PIIOD BHC/SL CET sPINNER ..... ~EC SSS '' pACKER Digital ~/~' , Data FDC- ~ Well FDC RWD rcqui~cd ~cccivcd SAMPLES ~cqui~cd ~cceived MWD LDi!CNL ....... d~' ditch ' ,,, / ~ ,, , ML , , , cor~ , .... ~ ,, ARCO Alaska, Inc. Date: February 21, 1992 Transmittal #: 8369 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3Q-03 - LIS Tape and Listing I -27-92 92095 3 R- 12 D LIS Tape and listing 2 - 4 - 9 2 92115 THE FOLLOWING LIS TAPES ARE STAMPED WITH A CORRECTED COPY STAMP. PLEASE REPLACE THE PREVIOUS COPY THAT YOU HAVE ALREADY RECEIVED WITH THIS ONE. THANK YOU. I R - 1 7 LIS Tape and Listing 9 - 1 9 - 91 92026 1 R - 20 LIS Tape and Listing 9 - 9 - 91 92026 1 R - 21 LIS Tape and Listing I 0 - 6 - 91 92026 1 R - 22 LIS Tape and Listing 9 - 24 - 91 92026 I R - 23 LIS Tape and Listing I 0 - 2 2 - 91 92026 1 R - 24 LIS Tape and Listing 7 - 3 0 - 91 92026 1 R - 26 LIS Tape and Listing 7 - 1 8 - 91 92026 I R- 27 LIS Tape and Listing 8 - 31 - 91 92026 1 R - 29 LIS Tape and Listing 8 - 1 4 - 91 92026 ~/---,~/ I R-19 ?/-/~? 2M-21 ¢'1 --/3~.2 M - 1 9 I L-24 f~/-?o I L-25 ¢/--'~f~ 1 L-26 Receipt LIS Tape and Listing. 6 - 1 9 - 91 92026 LIS Tape and Listing 1 1 - 1 1 - 91 92026 LIS Tape and Listing 1 1 - 1 7 - 91 92026 LIS Tape and Listing 5 - 9 - 91 92026 LIS Tape and Listing 5 - 1 9- 91 92026 LIS Tape and Listing 5 - 2 6 - 91 92026 LIS Tape and Listing 6 - 3 - 91 92026 Ackn ow I e d g e d' --~~ Da te' R-EC--EtV E D DISTRIBUTION: Lynn Goettinger FEB 2 8 1992 Alaska 0il & Gas Cons. Commission Anchorage State of Alaska ARCO Alaska, Inc. Date: February 7, 1992 Transmittal #: 8355 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return o. ne signed copy of this transmittal. 2M-10 2M-10 I3Q-04 3Q-04 Litho-Density & Casing Neutron Porosity Data Litho-Density & Casing Neutron Raw Data CCN ~/ 1-12-16-92 CDR ~ 1-12-16-92 11-29-91 & 12-29-91 11-29-91 & 12-29-91 Please acknowledge receipt 7000-7756,~ ~ 7000-7669 7000-7756 7000-7669 4517.7-7720 4517.7-7720 i3Q-03 CCtq ~2 1-24-27-92 5090-9640 i~l>~_3Q-03 CDR ~2 1-24-27-92 '5090-9640 ..~THE FOLLOWING LOGS ARE CORRECTED COPIES. IT HAS BEEN REQUES-~J'LL'D THAT YOU THROW OUT THE PREVIOUS (UNCORRECT) COPY OF THIS LOG. .]'HANK YOU. ' . ,------------------ - ' - ?/~ 1 L- 26 (~-~'/CDN 6,3-6-91 ' 5225-10065 ~ [-I~- 2M- 19~/ ~ 11-17-'91 3835-9250 ~,~q 2M-21.v~ CaN 11-11-91 3914-10599 -t' '.., 1R-17';,~,.../,7.. m .,,.J, CCN 9-15-19-91 5698-10345 -- ,," ..?~j.. ~ ln-~/ CE~ 6-19-23-91 . 5390-9841 q['~ 1R-20J CDN 9-9-91 5568-10080 ~J l"' ~,~ 1R.21 ~/~ CCN 10-6-11-91 5070-10180 ~[~[,'~','~"') 1R - 22 ~'~ ~ 9--24-29-91 6001-10813 '~".,m11R'23"/ . CI~ 10-22-91 6330-1 21 88 ~ 7-18-21-91 5591-10218 ~1/~.~¢ 1R ;29 ~ C[~//~, 8-31-91 6547-9250 8-14-91 6042-11368 ~ 1L-24 ~' CC~ ~ 5-19-22-91 5081-9241 / eli' olL'25 ~ C[~ J 5-26-29-91 4978-9352 RECEIVED FEB 1 1 1992 Alaska 0il & Gas Cons. C~mrnission Anchorage ARCO Alaska, Inc. Date: January 10, 1992 Transmittal #: 8326 RETURN TO: ARCO Alaska, Inc. Altn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. l~'l '" I? 2M- 1 8 .-."' Sub-Surface Directional Survey ~/I ~' ! 2.? 2 M- 2 1 -// Sub-Surface Direclional Survey ~ I ...11~ 1 R-21 ~'/ Sub-Surface Directional Survey Receipt Acknowledged' D&M 1 - 13-9 1 75324 1 -28-91 75323 0-27-91 75122 - re: ........... ~~i~'ska JAN 1992 Alaska 011 & gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: December 6, 1991 Transmittal #: 8300 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage,. AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Receipt Please acknowledge receipt and Drilling Cement Bond Log 1 I - 22 - 91 Cement Bond Log 11 - 28 - 91 Ultrasonic Imager 1 I - 28 - 91 Ultrasonic Imager 1 1 - 28 - 91 Cement Bond Log ~ I I - 28 - 91 Acknowledge' ~~/~~~e- v State of Al~a~,s.~ka(.+sepia) NSK RECEIVED 200-3940 6140-8988 6146-8994 5770-10478 6000-10485 DEC 0 9 1991 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' December 6, 1991 "e,~o~O~ Transmittal #: 8299 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy/of this transmittal. ?--/~-M~- 21 3 ~..".,. LIS Tape and Listing 1 1-1 1-91 751 61 ~~-lOt' - 5'1'5_~,, LIS Tape and Listing . 11-17-91 75206 ~U 185"1'~,~ LISTapeandListing~._..11-2-91_ ~ .,,,-~ 75120 Receipt Acknowledged.' ~~~-;,,z-~z-~--- Date: .......... DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: November 22, 1991 Transmittal #: 8295 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed cop. p.p~ of this transmittal. , 2M-21 11-11-91 3914-10599 Receipt Acknowledged' - ............................ Date' - ......... DISTRIBUTION: D&M Drilling NSK State of Alaska(+Sepia) Vendor Package(Johnston) RECEIVED NOV 2 ? 1991 Alaska 0ti & Gas Cons. Commission Anchorage APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X~_ Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 479' FWL, Sec. 27, T11N, R8E, UM At top of productive interval 1825' FSL, 1700' FEL, Sec. 22, T11N, R8E, UM (proposed) At effective depth At total depth 2208' FSL, 1530' FEL, Sec. 22~ T11N, R8E, UM (proposed) 12. Present well condition summary Total Depth: measured 3926' feet Plugs (measured) true vertical 2 81 3' feet 6. Datum elevation (DF or KB) RKB 140 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2M-21 9. Permit number 91-129 10. APl number so-103-20156 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 3838' feet Junk (measured) true vertical 2 7 6 9' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 8O' 16" 3 91 6' 9 5/8" measured true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth 225 sx Perm. C 1 1 5' 1 1 5' 540 Sx Perm. E 391 6' 2808' (proposed) w/660 sx 13. Attachments Description summary of proposal ~ Detailed operation program _ Reduce 9-5/8" lead cement volume from 700 sx to 540 sx Permafrost Type E. 14. Estimated date for commencing operation November 7, 1991 16. If proposal was verbally approved Name of approver Mike Minder Date approved 11/6/91 15. Status of well classification as: oi~ _X (proposed) Gas Service BOP sketch Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~J~L/~/~/~ _~-,~ Title: Area Drilling Engineer ~ FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIu,~',!AL SIGNED BY JAppr°val ~7 10-~ 7 " ~ Commissioner Date I I - :). 2 - ~'t t SUBMIT IN TRIPLICATE KUPARUK WELL 2M-21 9-5/8" LEAD CEMENT VOLUME REDUCTION The lead cement volume for Well 2M-21 was permitted for 700 sacks of cement which is 100% over the calculated hole volume from 500' above the West Sak interval to the surface. In an attempt to minimize operational problems of handling excess cement returns at the surface, ARCO Alaska, Inc. requests approval to decrease the lead cement volume on Well 2M-21 to 75% over the calculated hole volume (540 sacks). If cement does not reach the surface, ARCO will perform a top cement job to ensure a cement plug from the surface to a depth of 100'. ALASKA OIL AND GAS CONSERVATION COMMISSION October 23, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-21 ARCO Alaska, Inc. Permit No.91-129 Sur. Loc. ll4'FSL, 479'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc. 2208'FSL, 1530'FEL, Sec. 22, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. David W. J~ohnst~n, Chairman Alaska~ Oil~as Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~:',~ prinled on recycled paper b y C.O. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 23, 1991 Mr. L. C. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' SUBJECT: Isolation of Significant Hydrocarbon Zones Kuparuk River Field Revisions to Permits to Drill for 3Q-1,3Q-3, 3Q-4, 2M-21 This letter is to clarify the Permits to Drill for Kuparuk River Unit Wells 3Q-1, 3Q-3, 3Q-4 and 2M-21. The previously submitted General Procedures for the above referenced wells did not include any mention of the possibility of encountering significant hydrocarbon zones at shallower depths than the Kuparuk. If such zones are encountered, a sufficient volume of cement will be used to provide annular fill- up to a minimum of 500' above ali significant hydrocarbon zones in accordance with Rule 20 AAC 25.030. Subsequent applications for Permits to Drill will include a statement in the General Procedure referencing the isolation of any significant hydrocarbon zones above the Kuparuk. Thank you for your consideration on this matter. If ARCO can furnish any further information, contact me at 265-6575. Sincerely, Senior Drilling Engineer TAB/mac A. W. McBride-'~_/~'?'~ ~,,-,-,- S. D. Bradley E. D. Fitzpatrick 3Q Pad General Wellfile RECEIVED OCT 2 ;~ 1991 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA AI_A~,~ OIL AND GAS CONSERVATION COMMIS,51ON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill m I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil ..~ Re-Entry _ Deepen --I Service m Development Gas ~ Single Zone Z~_ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 140'. Pad Elev: 105' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25571 ALK 2669 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 479' FWL, Sec. 27, T11N, R8E, UM Ku~aruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1825' FSL, 1700' FEL, Sec. 22, T11N, R8E, UM 2M-21 #U630610 At total depth 9. Approximate spud date Amount 2208' FSL, 1530' FEL, Sec 22, T11N, R8E, UM 28-Oct-91 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2M-23 10575' MD 1530'@ TD feet 46' at 561' MD feet 2560 6184' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300' feet Maximum hole an~le 59° Maximum surface 1657 ps~ At total depth (TVD) 3200psicj @ 6184' 18. casing program Setting Depth size specification Top Bottom Quantity of cement Hole Casinc, I Wei~lht Grade Couplinc~ Lenc~th IVD TVD IVD TVD (include stat, la dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3900' 35' 35' 3935' 2790 700Sx. PFE& HF-ERW 660 Sx. Class G 8.5 7" 26.0# J-55 BTC 10540' 35' 35' 10575' 6184' 190 Sx Class G HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ISn~refraCjedi ate R ~ C ~-- IV ~ Production Liner OC~ Of.. "~ Perforation depth: measured true vertical j~l~.St(a Oil & P~as Cons, 20. Attachments Filing fee .~X Property plat ~ BOP Sketch .~ Diverter Sketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Sic~ned ~r~~//'~ H~~~? Title Area Drillin~l Engineer Date Commission Use Only Permit Number , APl number I Appr~v~ date / See cover letter for _I50- /O.~" ~ 43//'-~I ---- -~'~,,c.~ '~ ~"~f~ other recluiromonts ~;onoifions el' approval Samples required __Y e s ~z~ N o Mud log required~ Y e s N o Hydrogen sulfide measures ~ Yes ~ N o Directional survey required ~ Yes __ N o Required working~.E[~~OPE ~ 2M; ~ 3 M; ~ 5 M; ~ 1 0 M' ~ I 5 M Approv~ commissioner tho commission Date Form 10-401 Rev. 7-24-89 S~ubmit in triplicate DRILLING FLUID PROGRAM WELL 2M-21 Spud to 9-5/8" Drill out to Weight up surface casing yvei_aht uo to TD Density 9.0-10.0 9.0-9.3 10.5 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-12 8-10 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 <10-12 Drilling Fluid System: - Tandem Brandt Shale Shakers - Tandem Derrick Shale Shakers - Solids Processing System to minimize drilling waste - Mud Cleaners, Centrifuge, Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated ir 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1657 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-21 will be 2M-23. As designed, the minimum distance between the two wells would be 46' at 561' TVD. The wells would diverge from that point. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (>4 hrs) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 sec/qt to drill gravel beds. 400 o 4-0O 800 1200 -i-- 16oo- _ C) 2000- _ 24oo- em -'!--- 2800~ ~600- - ¢000- _ 4400- I - V 480O- 5200- ARCO ALASKA, Structure · Pad 2M Well · 21 Field · Kuparuk River Unit Location · North Slope, Alaska Created by : jones For: T BILLINGSLEY Date plotted : 23-Mar-91 tPIot Reference is 21 Version ICoordinates are in feet reference slot ~21. rrrue Vertical ~pths ~eAref ....... ellhead / I--])~Jfl E ST N ! IZ//J/IIJC H RI STE N $ E N N 23 DEC 55 MINE 7648' (TO TARGET) East --> /2208' FSL, 1530' FEL/ .| SEC, 22~ T11N~ RSE / TARGET LOCATION: 1825' FSL, 1700' FEL SEC. 22, Tl lN~ RBE TARGET TVD=5955 TMD=lO087 DEP=7648 NORTH 6991 EAST 3101 RKB ELEVA~ON: 140' KOP TVD=300 TMD=500 DEP=O 3.00 g.o0 15.00 21.00 BUILD ;3 DEG/IO0 FT 27.00 33.00 B/ PERMAFROST PqD=1390 TMD=1460 DEP=342 39.00 T/ UGNU SANDS 'rVD=1460 TMD=,1547 DEP=393 45.00 51.00 57.00 EOC '[VD=19¢1 TblD=2275 DEP=934 T/ W SAK SNOS TVD=2025 TblD=2439 OEP=lO74 B/ W SAK SNDS TVD=2590 TMD=$54¢ DEP=2024 9 5/8"CSO PT TVD=2790 TMD=3955 DEP=2560 K-10 TVD=2870TMD=4092 DEP=2495 ISURFACE LOCATION; 114' FSL, 479' I~L SEC. 27, T11N~ R8E K--5 TVD=4350 TMD=6987 DEP=4985 -7600 ~7200 ~6800 ~6400 ~6000 ~5600 ~5200 4800 _ -4400 -3600 Z O 3200 ~2400 ~2000 ~1600 ~1200 8oo 400 Alaska Oit& Gas Cons. C0mt 'tss' ° Anchora[IO AVERAGE ANGLE 59 DEG 15 MIN TARGET -T/ ZONE C 1VD=5935 TMD=10087 DEP=7648 T/ ZONE A TVD=5960 TMD-10136 DEP=7690 B/ KUP SNDS TVD=6082 TMD=I0375 DEP=7895 TD / LOGGING PT TVD=6184 /MD=10575 OEP=8067 i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 400 0 400 BO0 1200 160(32000 2400 2800 3200 3600 4000 4400 ¢800 5200 5600 6000 6400 6800 7200 7600 8000 8400 Scale 1 ' 200.00 Vertical Section on 23.92 azimuth with reference 0.00 N, 0.00 E from slot #21 Scale 1 ' 50.00 F.ast 200 1 50 1 O0 50 I I I I I I ! I ARCO ALASKA, Inc. Structure: Pad 2M Field: Kuparuk River Unit Well: 21 Location: North Slope, Alaska 0 50 I I 2300 1 O0 150 200 I I I I I I 3100 1500 O0 1300 1900 2300 2100 2500 }00 1300 1100 1300 900 1100 25O 500 -450 -400 -550 __ -300 I - -250 -200 -150 -100 - 50 - 0 -- 0 - 50 o , , o , , , , . o 10 11 12 13 14 15 16 17 GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD Well 2M-21 Move in and rig up Pool 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole logging while drilling to total depth according to directional plan. Run and cement 7" casing. Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED OCT 2 1 1,991 Alaska 0il & Gas Cor~s. comrnissiO~ Anchorage ,.JPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC 5 J 5 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20"- 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 7 , 6 13 5/8" 5000 BOP STACK ,~(~CUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 15(X) PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(XX) PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BO'i-rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE ~2~8g NO. ~$ I ~, 94~; ~8.8~ 4 ~Y; 7~.61 . ?0° I~ ' t~.~X6" ~ ~,94~,98~.9~ 4~7~ ??~.~8 ?0~t~' /O.~??" $ ~, 9~a, ge~.O; ~ aT, aO~.~ YO~/~' tO.~" NO, Y X ~ ~, 9~a~ ~e5.~$ 4e~, ~. 41' ?0~/~' I~.~79" t/ 5, 9~0, 9a5. 95 400,004.~ ?OOl$'lO,~EI " /4 1~ /~ I? /~ ~1 ~3 ~4 ~,940, 90~7~ 4~0, 394~ ?0~1~'10.~0~'' RECEIVED LON¢~. , F.~.&. F.E./.. OD. PaD I$OeOe'$X. ff~' " I14 ' 11t ' 101.0' 104.; 150e 0~' ~$, ~6' /14 ' ~G ' I01.0' !04.9 1~0°0~'5~.0~ " / t 4 ' ~$' I01.0' 105.0 /~0o O~' E~35~ " 114' I/' I01.0' 105.0 LONG. m,$.L. ~,W,L. I~0e 05',e$. ~30 " t 14 ' 14 ' i00.9' 105. I t50°05'$R.$05" II4' 39' ~0.8' tO&2 I$0e0~'$~. 178" 114 ' 64' 100.8' 105.3 /~OeO~'~/.~$O'' //~' ~' 10~8' t05.4 /$O°~'EO.~20 " //~' //4 ' ~00.?' I0~.~ 150e05'~.~94'' ltd ~ 139' 100.6' /~0e0~'~.~84" //4 ' /~4' I00.~~ 105,5 / ~0~ 08'4~E~4 " //4 ' / ~' 1~,5' I0~.~ /~0a0~4~.919 " //4' ~?~' 100.3' 105.6 I ~0° 0~'4~. I~, / 14 ' 304 ' ~.2' 10~.6 /~0°0~'44.470~ 114' 52~' I00.~' 105.~ I gOe OS'43. X~R " I t ~ ' 3~4' I~.1' 105.6 I~OoOS"40. O~E" 1t4 ' 4X~' 99.7' 105.5 /50e0~'~.~4" //q' 504' 99.7' 105.0 /~000~,~.6~0, //~, 5~' 99.6' t04.9 /~0°0~'~9// ' //~' 55~' 99.5' 104.9 AND THAT THIS PLAT' REPRESENTS 'MADE BY ME OR UNDER MY DIRECT 8URE~91ON~ ~'~";'. . aS~., ,,',,. ,, AND ~ &&& O~lON~ ~ 0~ % ~, ~e,..~ e ~... ' . , Date De s crib/ion ARCO ALASKA, INC. DWG ~ NSDK. ~MO0. CEA.DRMX. 6213 D 7 $ka, Inc. ITEM (1) Fee , , (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru 8] (3) Admin~hru/l~ [10 & 13] (4) Casg El4 thru 2{] (5) BOPE [23 thru [29 thrG 3~[3" (6) Addl geol og¥' eng i neer i n~: DWJ MTM // LCS dH~ Company . ~,/~C, _~ 1. Is permit fee attached ............................................... , 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper distance from property line ................... ~. 4. Is well located proper distance from other wells ..................... ~. .. 5. Is sufficient undedicated acreage ava[-l'able in this pool ............. ~__ 6. Is well to be deviated & is wellbore Plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ Lease & Well YES NO REMARKS 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Does Operator have a bond in force ................................... /~. Is a conservation order needed ....................................... ~a Is administrative approval needed .................................... Is lease number appropriate .......................................... ~ .. Does well have a unique name & n~rnber ................................ ~ conductor string provided ......................................... ~ Is Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~=r~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Add i t i ona l rev 03/29/91 jo/6.011 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special 'effort has been made to chronologically organize this category of information. ,o C{'~p~Y NA~E ! ARCO ALASKA, INC, FIELD ~4AME : KUDAR~JK RIVER BOROUGh4 : NO~TH SLOPE STATE : ALASK~ API NUMBER : 50-103-20156 REFERENCE NO : 920~6 RECEIVED FEB 2 5 1992 Alaska 011 & Gas Cons. Commission Anchorage LIS Tape Verification Listin~ ScblumberQer AlasKa. Com.nutlnq.. Center 20-JAN-~ 992 15:29 PAGE: 1 $~vICE ~h~E : El)IT O~IGI~ : F'L!C ~E[, ~ : 7%!6! C~V~]a'r : APCQ ALA$~ IBC,, 2D-21, K!tP~RUK RIVER, 50-103-20156-00 SENVICE ~A~M : E?)IT DATF : 9~/01/20 OPlCIN : FbIC T~PF ~iA~ : 75161, CO~TIN~ATIO~ ~ : t CO~!~E~T : A~CO AL&SKA !NC,, 2~-71, KUPARUK RIVER, **** FIBE HEADFR **** FILF ~.iA~ : EDIT .001 $~VIC[ : FLIC VW~$IO~ : O01h06 u~× REC SIZE : 1024 F!U~ TY~E t,~S~~ WILE ****************************************************************************** FILF - EDIT.O01 &PCO AbASK~ IzC. 5n-10)-2015~: MAIN PASS l, wl) bOG 9ATA TM? OE~,~ST'rY OAT^ PRESt{~'~'r~]P O!',J THIS blBpAPY TAPE IS FROM LOG(;I:~!G :,..'aI[,~' I)[~!LLING ~E:$ISTlVlTY/GR 3914' TO 1.0535' [~i~CI.NC wNIL, E D.~I[.,i~I~,:C-, ~EI~1'IRO~;/D.~:NSIT¥ 3914' TO 10467' LIS ~aDe Yerffication Listing Schlumberger ~las<a Computing Cemter 20-JA!~-1992 15:29 ']:HIS L, IT~R~RY TAPE Ig~S G~E~ REVISED TO INCbUD~] RECALIBRATED Cr)~,,~ ;)~SITY [)~T~. DA.T~ PRESENTED IS f'ROM 'RHOB ~AX'. PAGE: 2 TABLF TYP~: : CONS 7' I~,i I ¥ AL;.i QEFI TYPE C &~CO AbaSKA I~C. Company Name KUPARUK RIVER Field Name 50-103-20156 114' FSL & 479' FWL 27 ~ORTH SLOPE 599384 0 FT 149. FT 149. FT 149, ~'r 106 b,'i? 105~9. ~T 10599. ~'f 10599, FT 3914. i, SND ~fc3 10.4 A. PlN FI, SFC~ NATT LaTT L~W A TDL DF'r B~'F CP OEGv 62. 0 i"~ >-~ !~ 4 ?50001 OEGW -q99.25 :)EGF 147. Well Name AP1 serial Number Field Location Section Township Range County State or Province ~ation Latitude Longitude Witness' Name Service Order Number Permane.t datum Elevation of Perm. Da Log ~easured From ABOVE PER~ANENT D~TU~ Elevation of Kelly Ou F!evation of Derrick Elevation of Ground L Total DePth - Dr~ller Total Depth Logger Bottom Log I~terval Top Lo9 Interval Drlll. in~ Fluid Type Drllling Fluid Densit Drillin~ Fluid Ph ZOnE Drilling Fluid ¥iscos ZOnE Drillino Fluld Loss ZOnE Resistivity of ~ud Sa ~ud SamD].e Temperatur ~esistivit¥ o~ mud fi ~!ud Filtrate Sample T Resistivity of ~ud Ca ZONE ~u8 Cake Sample Tempe ZONE Surface Temperature Bottom Hole TemDeratu bis Tame Verification Ltstin~ Schlumberger hlaska Co~putinu Center 20-JAN-1992 15:29 PAGE: 3 T ~.BLE TYPE ~I,E TYP~ : CURV DFPT Depth Channel Name ROS? SS2 ~HO Density - hOT RHO~ 8u1~ Density DPHO Oelta RHO PEF P~otoelectric Factor DCAI, Differential Caliper DPN% Dens!tv Porosity DPOP Density Porosity Output from an Application Program T~gP~ Thermal Neutron Porosity ATP ~GS BHC ATTENUATION RESISTIVITY PSR RGS BHC PHASE SHIFT ~ESISTIV'ITY DER nIELECTRIC RESISTIVITY FRf]~ RGS ROPE ~ATE OF DRTI, I~ING PENETRATION GP Gamma Ray ** UA'PA FORMAT SoECI~'IC,~TIf.)N RECORO ** ** SET TYPE - 64E~ ** T EPR CODE VAbUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 9 6~ 0.5 12 6~ 13 6~ 0 14 65 ~T !.5 66 6~ 0 66 0 LIS Tape ;/erl. fJcatJon Listino Schlumberq. er AlasKa ComputJnO Center 20-JAN-1992 15:29 PAGE: 4 ,'~ .... P"' C lO OROER ~ ......... .................. . ........... . .... FT · 599384 OO 000 00 ROS? t'.,~?~G/C3 599384 00 000 RHOP LWD G/C3 59o3~4 O0 000 O0 DPHO b~:~)') G/C] 5993~4 O0 000 O0 ~ ~ P L ~'~ n 599384 00 O 00 00 DCA~, Lw~) IN 59q]~4 O0 000 O0 DPHT LwO pU 59q384 o0 000 O0 DP()P ~,wp PU 599384 T~PM L W ['~. PU 590384 O0 000 O0 ATR f, '~ f) {.) F! ~',~ ~ 599394 O0 000 OO pSr~ L,~<D 0 Fi ~:~ ~599384 OO o00 00 DTR f., 'd D Og~~ 59~3n4 00 RO~F L~;!'~ F/HR 59q384 00 000 00 G~ r.,Wb G~PI 599384 O0 000 O0 1 4 68 0000000000 ~ 4 68 0000000000 ~ 4 6~ 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 ! 4 6g 0000000000 DEPT. 1,059R.500 ROS2.bWD -999.250 PEF.SwD -999.250 DCAL.I,,wO -999.250 T~,!pE' , f,~'~!) -999. 250 ATR. [,%t'l) -999,250 ROF, F..I.~wO 15,96? GR, LWD -999. 250 PEF.Lwi) -999.250 DCAL.LWD -999.250 T~p~, L';.¢O -99o, 25(~ AT~. LWD 3,1 O ] ROPE, L ~-'; n 30.87,1 GR, b t.,~ D 88. 747 DFPT. 1040~).,)0~ ROS2.~>;D 2.439 PEF.b;~O 3.11.2 DC~I.,.LWD 0.26~ T~P~.Li~n 30.~('~0 ATR,~O 6.246 ROPW.L~.~f) 52.7~7 GR.L~i) 73,942 ')00 ~{OS2. !,v,;P 2.334 536 DC/~L. L,D 0. 000 200 ATP. L~'D 16. 394 [89 Gr<. Lv:D 50.945 DEPT. 10 i O0. ,,~ n C: P r). S 2. [,Wr, 2. 545 ~EF'. f, ;,,. D 3. 179 DCA[ . [ t'~?~ 0. R 14 m'"~ ~ P. b~" i~ 32.90o ATP. t,*b :]. 597 ~HOB.SWt) -999.250 DRHO.LwD DPHI,SWD -999.250 DPOR.LWD PSR,LWD -999.~50 DER.LWD R~OB,LWO -999.250 DRHO.L~D OPHI.bWD -999.250 DPOR.LWD P$~,LWD 4.094 DER.LWD ~HOS,hWD 2.439 DRHO LWD DPHI,bWD 12 800 DPOR:LWD PSP,LWD 7:044 DER.LND RhOB. L:'~D 2.442 DRHO.[,WD OPF!] .LWD 12.600 DPOR.LWD PSR, L~:J0 10.118 DEP.. LW.D RHOe.bWn 2.334 DRHO.LWD DPHI.LWl) 19.100 DPOR.LWD DSP.t, wD 30.980 DER.LWD R!qO.~!. L ~,; 0 2.545 DRHO.t, ND PptI] .Lw9 6.400 DPO~.LwD PS,P.. h~O 3.]51 DER.,,,, -999,250 -999,250 -999,250 -9991.250 0 O06 12:800 6,825 0,005 12,600 9.840 0,001 19,100 28.419 -0,006 LIS Tame Verif!catior, t,istlnq 20-JAN-!992 1.5:29 Scblumherqer Alaska Computi, nq Center PAGE~ lO0oO,Ono R[!S2,LWD 2,400 RHOB,L~D 3.245 DC~L.L~D 0.323 DPHI..L~D 46,600 ~TP,L~ 2,003 PSR.LWD DEPW~. 9900,000 ROS2,I.,~D 2.4a3 PHOS.BWD PTW.L~t) 3.466 DCAI,.L~O 0.857 DPMI.LWD TNpI4 [.,tgD 43.000 ~TP.I,~'D 2,263 PSR,Lw9 RaPF~G~O 160,393 GR.I.,~[') 101.722 D !;'P T q 80 0. .... , . PEF t,~D 3.152 [)C~L. Lv, D 0.089 DP}.i I, I, WD T-~'3PU:b%'~r) 38,100 ATR.LWD 3,756 PSF~,.LWO. DFPT. 9760.000 ROS2.I~WD 2.456 RI. iOB. b!~D PEF. ~.~<D 3,847 DC~L.LWD 0.313 DPHI,L~D T~JP~'~. l,~'O.. 38.60o. ~T~,LWD 2,709 PSR.LW9 ROpw.t,?0'9 9g. 363 G~.LwD 178.315 l-)gpT 9600.000 aO$2.LWD 2.406 ' Pg~l,w~> ~t. 227 DCA I..,. bl~D 0,375 DPFI.L, WD TNPF~. b{~9 41,600 AT~.LWD 3.588 RODW. L:,'~D 109. 763 Gl{. LWD 205. 445 DrPT, 9400,000 aOS2.b~D 2.~11 R}!Oe. DWD Ph;F.I,:.~D 3.502 DC~L.Lt~O 0,157 DPHI'.I, W9 T~!P..[,~> 41.400 ATR.LWD 4.~06 PSR.bwD ~OPF.Lv!O !62.151 G~.[,~D 117.205 DKpm, q300,oO0 ROS2,LwD 2.570 RHOf.;., Lw D t~F]w, L ~'~D 3.5.,37 DC~ L.. b~'¢ D 0.344 DPHI .LWD T~:OF:. b:,'~ ~ 32.500 ATR,bt~D 4,494 PS~{. l,wO ~OpF. t,~9 212.5~0 ~,Lt~D 95,311 9200.000 ROS2.DWD 2.446 RHF, B.L~D 3 527 OCAL.LWO 0.185 DP~I.LWD 36:700 ATP.b~D 3 923 pSR,LWD 75.~83 G~.L~D 95~796 9100.900 ~082, I::.~B 2,490 3.q79 DCt [,. b'.~ D 0 25i DPH!. !,WL) ~. . 5~73 PSF:.b*O 33.q00 AT~ 130,544 (;R. I,t~;[> 84,783 90(:0.90n R C)52. [,?; [',, 2.495 3.278 DC~L..bwp 0.364 3,200 ATP. L~. [: 5.891 PSP. I.. 143 CP. b:,"9 93.884 2 40O 15~200 3,293 2.483 10.100 3,504 2 446 12i400 4 87! 2.456 11.800 3.776 ~,406 1,4.800 6.104 2.350 18.200 6.224 2.411 4 500 2.570 a 8'00 4:814 2.446 12.400 5.301 2.490 9.700 9.411. 2.495 9.400 5.654 DRHO. I, WD DER.bwD DRHO.bWD DPO~,LWD DER.D~D DRHO.LWD DPOR.DWD DER.I, WD DRMO.L~D DPOR.LwD DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOP.LWD DRHO.LWD DPOR LWD DER.~LWD DRHO.LwD DPOR.LwD DER.LWD DRNO.LWD DPO~.SWD DER.LwD DRMO.[,WD DPOP.LWD DER,L~D DR~O.I, WD OPo~.bwD DER.LWD -0.003 !5,200 2,506 '0,002 '0,018 12,400 4,372 -0 046 1 1 BO0 3, 230 74O -0.027 18,200 5,862 -0.023 14 500 5~.313 '0,004 4,800 4.702 -0,013 12.400 5.053 -0.008 9.700 8.455 -0.004 9.400 5.728 LIS Ts~e Yeriflcation Listin~, Scblurnherqer AlasKa Computlnq Center DEPT. 8900.00t? RO82. TNP~. t,~D 32,40t~ r>Fp'r. B8.eO.O0o ROS2,LWD T~:P~;. L ~O 32,700 aTR, LwP ROPE. b'~O 160. 363 d~. LSD DFOT. 87~0,000 ROS PEF. I,~<D 3.572 DC~L.L~ID T~!PF{. Lw~) 42. q00 ~TR. LWD ROPE. L~D 119,563 GR. LWD DE~T. 8600.000 ROS2.LWD PEF', b t'~r~ 2.557 T~PN. L~'O 35, ~00 AT~. LWD ROPF. LwO 2C~O. 96~ GR. LWD DEPT. 8500.000 ROS2.LWD RoP~. !,,~~n 1 OO. 04~ G!~. 2.506 DCAL. 0.763 {)FOT. 79o0. pmpF. ', i-' ~ 439, 20-JAN-1992 15:29 2.486 RHOB,LWn 0.315 DPHI,[,WD ~,727 2.483 RHOB,L~D 0.443 DPHI,hgD 3,927 PSR.LWD 84.306 2,330 0.000 DPIiI,LbD 3.9~9 PSR,LWD 85,379 2.4,06 0,5!1 DPHI,LWD 5.420 PSR.LWD 72.547 2,508 RHOB,L~iD 0,689 DPMI.bWD 2,969 PSR,L~D 73.304 2.480 RNOB,LWD 0,347 DPHI.LWD 3.312 PS~.bWD 103.974 2.432 RHOB.LWD 0.282 DPHI,LWD 4.342 PSR.LWD 85,701 2.477 R{~OB.L~D 0.274 DPhI.LWO 3,898 PSR,LWD 97.414 2.376 RHDB.LWD 0.21.5 DFH1.LWD 2.915 PSR.LWD 7~.810 2.374 RHOB.I,~ 1,281 PPHI,LWO 2.713 PSR,LWD 72.907 2.262 2.47~ 2.486 9.900 4.180 2.483 10.t00 4.553 2.330 19.400 6,391 2.406 14 800 5:989 2.508 8.600 3.497 2.480 10.300 4.081 2.432 3 200 14:404 2.477 10.500 4.371 2.376 16.600 2.753 2.374 16 700 2.262 23.500 2.402 DPOR.LWD DER.LWD ORHO.LWD DPOR.LWD DER,LWD DRMO.b~D DPO~,LWD DER.LWD DRHO.LWD DPOR,LWD DER,LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR,LWD DER.t, WD DRHO.LWD. DPOR.LWD DER.LWD DRHO.LWD DPOR.D~D DER.LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LwD DER.LWD DRHn.bND DPOR.LWD DER.I.,WD PAGE: -o:go 9 O0 4'078 ~0.007 0,~00 4,'06 '0.013 996 0,0~1 14,8 0 5,830 '0,046 8,600 3,272 '0.014 10,300 3.745 0.012 13,200 4,384 '0,012 10.500 4,191 0 011 16i600 2 807 0.016 16i700 2 634 ]0.031 3.50O 2,429 LIS Ta~e Yeriflcatlon Listino Schlumberger Alaska Computlnq Cemter 20-JAN-1992 15:2q PAGE: D~PT, 7R00,aO0 ROS2.L~D 2,4.53 RHOa,L!ND 2.453 DRHO.LWD PEW L~I) 3.113 DCAL,.I.~t:,~'D 0.3q0 DPMI.LWD 1!.900 DPOR.LWD T~P~L~9 35.1.00 ~Wa.L~.:0 3.275 PSa,L~fO 3.464 DER.LWD ~Op~.l,~;!D 290.277 GP.[,~9 85.142 D~V'r, 7700.©0c. ROS2,[~<O 2.468 RHOB,SWD 2.468 DR[.~O,LWD ~EF.~D :].051 DC~I~.LWD 0.287 DPHI.LwD 11.100 DPOR.LWD TNP~.L~9 36.600 aTR.L~D 3.498 PS~.bWO 3.640 DER.LWD ROP~o[,~D 353.051. GR,L~9 9o.408 DFPT. 7600.000 ROS2.L~D 2.416 R}iO~.L~D 2.416 DRHO.L~D PEW.LbD 3.042 DC~L.I,,WO 0.30~ DPEI.L~!D 14.~00 DPOR.LWD TNP~.L%?D 39.900 AT~.LWb 3~723 PSR.LW~ 4.020 DE~.LWD ~opF,LWQ 338.522 GR.LWD 106,233 DFPT. 7500.00o ROS2,LWD 2,42(3 RNOa,bWO 2,420 DRBO,LWD .... ~EF,LWD 3,15~ DC~L.LWD 0,264. DPHI,LWD 13,900 DPOR,LWD TNP}~.I.,~D 38.900 ATR.LWD 3.~98 PSR.LWD 4.605 DER.L~D POP~i. LwD 286,467 GP.L~D 120,515 740~ 00O ROS2.LW[) 2,283 RHO~.bWD 2,283 DRHO,LWD 3~218 DCAL.I,WD 0.000 DPNI.LWD 22.200 DPOR.L~D 43.400 ATR.LWD 4.228 PSR,LWD 6.253 DER.L'WD 269.333 GR,i..wD 143.1;82 7300.000 RD$2 LWD 2.471 RHOB.DWD 2 471 DRMO.L~D 3.007 DCAL.bWD 0.499 DPM!.LWD 10.900 DPOR.LWD 37'200 ATR.LWD 3.6t9 PSR.LWD 3.779 DER.LWD 348.075 gq.I,wD 115.909 DFPT, 7200.000 ROS2,LW[) 2,349 RHOB.LWD 2 349 DRMO.LWD PE~'.[,:'~9 ~.146 PC~i.,.LW!'~ 0.279 DPHI.LWD 18~200 DPOR.LWD T~P~.b~,) 37.900 ATR.LWD 2.049 PSR.Lw~ 2.118 DER.LWD R~P~.b:~D 177.033 GR.L~D 109.369 DJ'PT 7100.000 ROS2.LWD 2,248 RHOB,LWD 2 248 DRHO,,bWD "~EW'[.,'~D 2.625 OCAL.D'~D 0.064 DPHI.LWD 24~300 DPOR.uWD 'l~P~ [ L~D 42,100 ATR. b'~D 1 ,g02 PSa, LWD 2. 132 DER, LWD POPF,LWD 186,1~7 GR.L~D B6.716 DFPT. 7000.00o ~OS2.L~P 2.320 RHUB.LWD 2.320 DRHO.LWD PC~.L~n 2.776 DCAL.I, wD 0.073 DP~I.bwD 20.000 DPOR.LWD TNP~.[~'~9 a2.100 A!'~.I,~D 1.865 PSR.LWD ~.086 DER.LWD ~OPW.L~4n 264,3!2 GP.I..k;D 92.733 6900.000 P 952. I.,'~;P 2.370 RI~OL~,. L,,~ 0 2.370 DRHO.L~D 2.63:1 L%CAL. L:,~ [) o.00O Dp!.:; l. %~: O 17.000 DPOR.LWD 4c.00(~ AT~. [,~'~D 1 .873 ps~.bwD 2.124 DER.LWD 424. {~64 Gr~. l, ~v r:, a4.1 I 6 6800,00o P(~$2. !,'~ [:, 2.359 R[.!O g. !,~'~ 9 2 359 DRHO,LWD 2.7q/~ DC~L.LWL> 0 0go DP~i.'~':~ i7:600 DPOR LWD ]7.500 ~T~. !,','~P 1.760 PER. L~,~[) 1.82'¢ DER.LWD . 2~g 41 4.458 gP.bW~ 87. ~ 0.019 11.900 3.394 ~0,007 1,: O0 3,~89 0'014 ~4,200 3,910 '0,024 9O0 '0,028 22,200 5,892 '0'006 li,900 ,733 '0.008 1~.200 ,.090 -0,010 24,300 2,031 0 013 ;o:ooo 1,989 0,002 17,000 2,012 0.018 17.600 1.797 bis ?ave ueriflcation b.i. stinq 5chlumherqer Alaska Compt!tln~ Center 20-JAN-1992 I5:29 2.439 0.375 06.589 9FPT. 6500.000 aOS2.LWD 2.27~ P~IF. l~Wf) 2.645 DCAL.I,W9 0.000 T~,~H. LWO 30. 600 ATR.I,WD 3,623 RopF. [,Wp 22~. 203 ~R. b~,~9 110. 246 DFpT. 6400.000 ROS2.I, WD 2.334 PEF.LWO 2.614. PCAL.SWD 0.358 T~'~P~. l,, ~,, [) 41. 300 ATR. !.,W t~ '~. 579 Ra~F'. L'~,~9 223.383 (:~.L~D 73. 574 g o C, ~ [) $ 2. !., w I) 2.311 2.600 DCAL.LWD 0.248 576 GR. t.,~9 86.016 6200.000 RD$2,LwD 2.316,. 2.55F DCAL.bWD 0.264 35.4.00 AT~.!,WD 3.840 377. 630 ~R. LWD 89.159 6.100 000 R O52. [,'~dD 2.319 .... 2:637 DCA[,. I~WD 0. ~ 64 33. 900 A~R. LWD 3. 572 420.7 ~F GR. !,WU 90.52g DFPT. 6000.000 ROS2.LWD 2.303 PEF.L~O 2.724 DC~L.[,WD 0.OO0 T~:'PlI.L~:n 35.900 ATP.LWD 3.264 ROPV.I.,~O 499.055 G~.bWR 87.~39 g~P~'. 59o0.000 ROS2. bk, 9 2.336 PFF. LwD 2. ~ 1 ~ 9CA[,. !,wP 0.0gO T~gU. Lw 9 3~. 4 O0 ~wk. L~D 2. 729 pepv, ~,~p 459.232 GR. L, WD 93. ~52 bE .p'r. 58ev~.COO ~ 0S2. [,'~,, 0 2.295 PFF. [,,,,0 2.587 ~)CAD. LwD 0.n00 ~ODF'. L?~ 0 395.7~ 1 CP. [,wD 77. 756 P g H .[. L W D PSP. L~:~ D DPHI. PSR,LWD RNOB.LWD DPNI,bWg PSR.bWD RHOB.b~D DPHI,bWD PSR.LW9 RHOB.LWD DPHI.bWD PS~.LWD RHOB. TjWD DPHI.SWD PSR. ~WD RHOB.LWO DPMI.DWD PSR.LWD RHOB.LWD DPHI,LWD PSR,LWD ~HOB.bWD DPHI.DWD PSR.LWD RH[I~. LWD D P H I. L '~ O PSR, I,WD R~Oa. bWO DPHI. D'"D PSR. Lw !) 2.439 DRHO.LWD 12.800 DPOR LWD 2 928 D_~R:LWD 2.322 DRHO LWD 19.900 DPORiLWD 3.324 DER LWD 2 27] DRHO,LWD 23:0oo oPo . 3.432 DER.SWD 2 334 DRHO 5WD 2.861 DER.LWD 2 ]11 DRHO.bWD 20:500 DPOR"LWD 3.266 DER.LWD 2.316 DRHO LWD 20.200 DPOR:bWD 3.886 DER'bWD 2.319 DRHO.LWD 20 100 DPOR.LWD 3:570 DER.LWD 2.303 DRHO.LWD 21.000 DPOR.LWD 3.486 DER.LWD 2.336 DDHO.LWD 19.000 DPOR.t, WD 2.827 DER.L~D 2.295 DRHO.LWD 2].500 DP~R.L, WD 2.785 DER.LWD 2.266 ' DRMO.LWD 23.300 DPOR.LWD 2.884 DRR.LWD PAGE: -0.024 ~'09. 012 900 3;343 000 49 3 '0,008 93,1 O0 ,0.44 020 o°: oo 3.286 -0.022 -0.0! 1 20.100 3.571 0 002 000 213 403 0.015 19 000 2:790 '0,003 21,500 2.727 -0.007 23.300 2.889 Sch!u,?.berqer Ala..ska Co-.".~putinC Center . D.,Fpm, 5600,000 ROS2. l.,wP ROp~', LWD 225,240 GP. LWD DPPT, 5300.000 ROS2.LWD PEP I,,WO 2.388 [)CAb ROPE, !,,~ 248,867 DPPT. 51©0.000 ROS2.LWD PEP. [,t<[> 2.626 DCAL.LWD TNI,-"[,~ t..,~r~ 42 500 ATR,LWD D~F'T. 500(;. OOO kOS2.6wD T~PN, 1.,~9 44. 400 ATR, LWD 4900. 000 Rr!S2, LWD 3.576 DCAL.LW!> 35. ~00 ATR, 2a7,163 GR, LWD 4800.000 ROS2.LWO 2.596 DCAL.LWD 49. 300 a~. LWD 42o. 400 20-JAN-lPg2 !5129 2,237 Rl~0[i. bWD 0.063 DPHI.LWO 'Il .046 2.~91 RHO~,LWD 0,248 DPHI,LWD 3.497 PSR,LWD 79.5~8 2.205 RHOB.LWD 0.000 OPHI.bWD 3,645 PSR.t.,ND 78,859 2.204 RHOa,LWO 0 334 DPHI,bWO 3 290 PSP,bWD 81. 378 2,178 RHPi~.hWD 0,205 DPF~I,LWD 3.623 PSR.LWD 74,770 2.194 RNO~.~.LWD 0.100 DPHI,LWD 3,702 PS~,LWD 77.1~8 ~.264 RHOB,LWO 0.216 DPNT.LWD 3,767 PS~,BwD 84.607 ~,291 RNOR.LwI) 0.132 DPH!.LWD 4,384 PSR.bWD ~6,51B 2.131 RHO~.bWD 0,073 DPHI.LWO 3.824 PSR.LWD 77.2~7 2.126 RltO~3.hwl) 3.247 PSP.LxO 90.257 2.1~9 RHOS-q. LWr) 0.045 4.355 9n,2qO 2.237 25.100 3.t4'7 2,191 27.800 3.633 2.205 27.000 3,715 2,204 27.000 3.302' 2.178 28 600 3:747 2,194 27.600 3.871 2 264 2 1 oo 3.~69 2.291 2 i,. 800 5.034 '2.131 31,500 3.865 2.126 3!.700 3.!a4 2.189 27.900 4.488 DRNO.LWD DPOR.LWD DER.bWD DRHO.LWD DPOR.LwD DER.LWD DRHO LND DPOR:LWD DER,[,WD DRHO,LWD DPOR.bWD DER.LWD DRHO,LWD DPO~,LWD DER,bWD DRHO.LWD DPOR.LWD DER,LWD DRHO L~D DPOR:GWD DER,LWD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD OER.LWD DRHO.L, MD DPOR.LwD OPR.LWD DRHO.LwD DPOR.LWD DER.LWD PAGE: ~0,017 5,100 3,!24 ,~0., ! 3~584 ~0,030 7,000 3,690 -0 027 27 000 3 298 -0,027 28,600 3'703 '0,013 l:*oo 81! 400 0,032 21,800 4,872 '0,020 31,500 3.85! ~0 017 11700 3,179 0 013 4.443 LIS Ta~e Verification L,isti. nq Schlumberoer ~laska Cott~utlnq Center 20-jA~-1992 J5:29 PAGE: i0 D~PT. 4500.o0(; Tr~P~. I.,W9 39. 500 hTR. ROP~'.L~,~O 121,623 GR.L~WD DEPT. 4300.000 PEF.L~U !.g8~ DCAL,LWD T~:~PH.LW~ 39.700 ATR.LWD RsPF.LWO 435.942 GR.LWD DFPT. 4200.000 R052. t, WD PEF.L~O 2.412 DCAL.LWD TNP~4, L ~,~J' D 44. 300 ATR. LWD ROPF. L~;P b! 7. 568 GR. LWP D~PT. 4100,000 RO$2.bWD PEW.LWD 2.b59 DCAL.LWD T~.L~? 44,000 AT~,LWD ROP~.b~O 616.387 GR.L~D DEPT. 4000.000 ROS2.LWD DEl.'. L ~,~ 0 2.7~8 DCA[,. LwO T~Pw. L~,;D 42,600 AT~. LWD R{~PE. L~ 495,986 GR. bwP pwDT. ]900.000 ROS2,L~D PEP. L~,~ 100,000 DCA[... LWD TN~N. l..t.~:~ 6C,. 800 ATR. t, WD ROpF · 1.,, ~,~ r) -999.25C GR. LWD DFPT. 3800.0Oo ROS2.I,wU PNF.L~D 20,264 DCAL.LWD T~:P~,LW9 -999.250 ATR.LWr~ 2.?09 RhOB.LWO 0.154 hPHI.LWD 5.344 PSR.LWO 9~.712 2.309 0.197 5.420 ~4,383 2.046 RHOB.LWD 0.416 DPHI.L, WO 4,471 PSR,LWD 95.125 2.1~2 RHDB.LWD 0.1~4 DPBI,L~D 6.872 PSR.LWD 90.214 2.257 RNOB.LWD 0,1,16 DPHI,LWO 5.745 PSR,LWO 89.591 ~.36! RHOB.I,~D 0.806 DPHI.DWD 0 02~ PSP.I.,WD 2.380 RNOB.LWP 0.999 DPHI.bwD -999,~50 PSR.LWD -999.250 2.209 26.700 5.239 2.30g 20.7O0 4.801 2.046 36 600 2.192 27.800 7.81.0 2,251 24,200 257 25 733 2.36~ 1'!.500 2,276 2.380 16.400 -999.250 -999.250 RHOB.LWD =999.250 -09g.250 DPH!.LWD -999.250 -99o.250 PSR.LWO -999.250 -99~.250 DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.[,WD DER.LWD ORHO.LWD DPOR.I..WD DER.LWD DRNO.LWD DPOR.LWD DRHO.LWD DPOR.LWD DER.LWD PRHO LWD DPOR:L'~D DER.LND DRHO.LWD DPOR DWD DER~[,WD DRHO.LWD DPOR.LWD DER.LWD DRHO.LWD DPOR.LWD DER.LWD 0,000 26,700 5,274 .i61 2 700 · 996 2 20 0 207 ,014 5,736 '0,315 17,500 0,022 '0,441 t6,400 -999,250 -999 250 -999:250 -999o250 ** ;j;'~c t!F DATA '.,IS Ta~e Yerl~ication Ll. st. lr~q 5¢hlumberger .AlasKa Comoutln~ Center SERVICE ~ FbIC PAT? : 92101120 ~X REC 8~ZE : ~024 b~S'r FiLE : 20-JAN-lA92 15:29 PAGE: 11 **** T~PE TRAILER **** SEC'VICE N~M : EDIT ORICI~ :FLIC T~PE NA~E : 75161. COi'4TIN~ATIOM # : I. P~E~VIOUS TAPE : CO~4E~T ~ ARCO ALASKA INC., ~M-21, KUPARUK RIVER, 50-103-20156-00 **** REEL TRAILER **** SERVICE g~aME : EDIT DaTE : 92101120 OPI~IN : FDIC RFEL NA~E : 75161 COi%:TTNI~ATIOM ~ : PREVIOUS COv~ENT : ARCO ALASKA INC., 2M-21, ~[JPARUK RIVER, 50-103-20156-00
