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218-111
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 3S-612 50103207770000 2181110 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3S-612 KUPARUK RIV UNIT 3S-612 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 3S-612 50-103-20777-00-00 218-111-0 W SPT 5058 2181110 1500 800 800 800 800 801 829 826 824 4YRTST P Guy Cook 8/21/2022 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3S-612 Inspection Date: Tubing OA Packer Depth 1840 2490 2465 2465IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220821062204 BBL Pumped:1.2 BBL Returned:1 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 13:59:15 -08'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 iSGVGI v 1. LLO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 18 2020 REPORT OF SUNDRY WELL OPERATIONS .. 0%e%e% 1. Operations Abandon LJ Plug Perforations Ll Fracture Stimulate LJ Pull Tubing tdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Change Approved Program ❑ Plug for Redrill ❑ •erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well PROD to WAG ❑O 2. Operator 4. Well Class Before Work: ConocoPhillips Alaska, Inc. 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 218-111-0 3. Address: P. O. BOX 100360, Anchorage, Alaska Stratigraphic 171 Service ❑ 6. API Number: 99510 50-103-20777-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: MORTR04 35-612 ADL 380107, ADL 25544, ADL 25528 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field/Torok Oil Pool 11. Present Well Condition Summary: Total Depth measured 19,862 feet Plugs measured None feet true vertical 5,218 feet Junk measured None feet Effective Depth measured 19,854 feet Packer measured 13570, 13633 feet true vertical 5,218 feet true vertical 5058, 5073 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20 119 Surface 2,988 18 3,027 Intermediate 13,821 8 13,858 Production Liner 6,161 7 19,854 Perforation depth Measured depth frac'd liner feet See schematic True Vertical depth frac'd liner feet See schematic Tubing {(site, grade, measured and true vertical depth) 4.5 L-80 13,700 5090 Packers and SSSV (type, measured and true vertical depth) Baker Packer 4.5"X 7.625" Premier 13570, 13633 5058, 5073 12. Stimulation or cement squeeze summary: 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: 1483 3421 4832 1 1448 1 229 Subsequent to operation: 7632 1546 11104 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 9 Exploratory ❑ Development ❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q 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: 319-111 Authorized Name: Lynn Aleshire Contact Name: Lynn Aleshire Authorized Title: Staff Petroleum Engineer Contact Email: lynn.aleshire@cop.com Authorized Signature: Date: 7 / 3 J Contact Phone: 907-265-6525 YTL Form 10-004 Revised 4/2017 3/g/a a FIBM ILAJ FEB 19 2020 Submit Original Only 17 10 L/�o ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 February 17, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 35-612 (PTD# 218-111-0). If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Summary of Work Completed Schematic 1 3S-612 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/061191 Flow back completed. POP crew to rig down piping. 03/12/19 Slickline dummy off gas lift string 03/141191 Pressure test flowline connections to 3000 psi 03/16/19 Well commissioning checklist complete. Well BOL to PWI. 04/04/19 State witnessed MITIA (PASS) ConocoPhillips Alaska. Ine. KUP INJ WELLNAME 3S-612 WELLBORE 3S-612 3$812, yt]2VA 124255 PM Last Tag vePhi,Wnnmec[.) Mnotatbn DepM me) End Dab I VhIIM,e IUSIMe4 By .....................................................__.................._............. HGER: M4 LASTTAG.-RK6 19785.0 ""D,9 35-612 C0n8ilw Last Rev Reason Annotation End Deep wNbere Taal mW ay Rev Reason: Set Briny GLV's 3/1412019 35E12 Tembaej Casing Strings cssry Deeo,ip5on CONDUCTOR DD pnl 20 110 (h) 18.50 Top IRKS) SO 39.0 1190 Bitter nue., SO DepN nVan PiI...Glase 119.0 154.00 Top Tmod CONDUCTOR; 39.41180 mwv RUM-okwl:04 Desire DeacripXon SURFACE OD pn) 10314 IDpnl 9.95 TWRtKO) Set 38.6 3,OD.0 Depth (Me) SO De nVD)... VMlen(I Grade 2,5502 45.50 L-80 Top TMe1 HydRl 563 9.615.0: ivrsski6 NIPPLE; 1,92)5 Deslnp Pescriptbn INTERMEDIATE OD pn) ]518 ID(in) 6.88 INP ("i SO 36.6 13,85].9 Oeds ads) SO Deple Dr l... WULen IL.. Orade 5126.] 29]0 L80 I Top Thmd LESS Dieing Deec,i, n OD(ar, 10 (in) TOP MB) SN Depth MBI Set DepN(ThU) Ore -en p...O,ade TUPThread LINER 4112 1 3.96 13,693.7 19,854A 5,218.3 1250 L-80 -yd 563 SURFACE 3868.9270- Liner Details 045 UFL 36Na T,LUUIl PAfr DHvpd) TOpincU-) Ihm Des Com Nominal ID (in) 13,6937 5088.1 76.08 PACKER Liner TOp Paler, 5 X Me 1101710T,wll 4.820 Avwr FMd - CI 3®.wbR Seal Bore Extension s eves,1?XOO', PR.Ni 13,]13] 5,092.8 76.23 NIPPLE RS Nipple, 5-12", FIR1563 4.250 GASUFT; IZ0 13,7160 5,093.4 7825 HANGER Wer Hanger, FL pinned 1706 psi 4.800 GAuOEMDMP $135R. t?solo 13,]345 5,09].0 ]. SBE erlove x y i Pin up x 4.5" Hy9 521 box d. 4.020 PACIIEN: 13, 5wT 14,117.1 5,185.0 ]]. 1 A K R, -,BA ER,HYD563 SN 3.900 PACKER (002141-001-10)L NIPPLE, Bans 14,357.5 523].8 ]].88 FRACSLEEVE Aker raC seeve . "ball AsSy K,HYD563CN 2100 FPSC725 PN 1-1809080396. (MILLED TO 2.10" LOLATCR. f?Esat I 22]119) Up.; ...11 14,631.6 52]].3 85.91 bWELL PAC K E R. SAY ELL.41 Q %6. 7.BAKER,HYD563 3900 PACKER (0021410-001.11)K MULE skoE 1?tak?T 14,8]22 5, 9 90.89 FRAC SLEEVE Bels, Ins, sleeve (2,645"ball) Assy J, HYD563 CN 2,700 FPRC724 PN H8090S0395, (MILLED TO 230" 22]/19) 15,109.4 52792 8988 SWELL PACKEFLSVVELL,4 1/2 % .00',9AKEB,HY 3900 PACKER (002141-00146)J 153 4 5,280.0 89.66 FRACSLEEVE Badefrac sleeve(259Y ball) Asky f,1HYD562L CN 2700 INTERMEDIATE: 89.41?B6L9 FPSC]23 PN H809000394, (MILLED TO M' 2/28119) 15.T2-48 5,2830 89.21 SWELL PACKER,5WEu_,41 %6. A ,HY N 3SW PACKER (002141-001-12)I hid Fest. w. 1439.0 I 15,867.5 5,283.9 90.17 FRACSLEEVE Baker fires, sleeve(. sy HT HY 3 N 2.700 FPS= PN H809080393, (MILLED TO 2.70' 228119) 1 rl042 5,282.0 90.42 FACKER,510i 12 X &UV,BAKER,HYD563 SPI 3.900 PACKER (002141-0014)H Nyx..m F,.ceee; 14.9zo 1 ,345.3 5,281.1 90.35 FRACSLEEVE Baker bacsleeve ( 495 a ssy G, R7D1xYfN_ 2.700 FPSC721 PN H819 92, (MILLED TO 230" 228r19) 1 .1 5.2]94 90'43 I2X 00BAKE 3900 NyM1sdb Feen,e, 153eao I PACKER (0021414101A)G 1=.7A 52]].3 90.45 FRAUD SLEEVE Bakerrec sleeve 45' el Any F, HYD 563 2700 FPSC720 PN H809080391, (MILLED TO 2.70" 2/28119) hysteric F,se.. 15.81 I 1],1334 5,2754 90.44 A K FL WELL, 1 3.900 PACKER (002141-001-1)F 1],3].9 5,2]3.8 90.5 FRACSLEEVE N.7int0sleeve(2. 5e I ssy , 2.700 FPSC719 PN 11809080390, (MILLED TO2.10- Nyd,eves,R Wm; 111.0 L 2/28119) 1], B 5,2684 91.31 A KER,SWELL, 2 r' AN N 3900 -7M7 PACKER (002141-001-14)E 2),w ped-NaUenneii 13At h.10ari 11/11/adil revisit Fremee; 16.h9Z0 I 7 52636 91.40 MARC SLEEVE Baker csleeve (2.3]" II ss N Y matig�8 PN 11809090189, (MILLED TO 2.]0" 2.700 1=1 4 5,2573 91.29 SWELJ_ PACKERSWIELLLI12X N 3909 PACKER (002141-001-3)0 NymwR., 113P. ( 18,JW27 5,251.1 91.39 FRACSLEEVE Oak., fr.0 sleeve(2335' ball) Assy , N FPW717 PN H809000388, (MILLED TO 2.70" 2700 228119) 18,507.1 5.2466 9132WELT- K WREE-4 1Q_X700-,WER,HYD563 Sel 3.900 Nyarewp Fremv.i 17.853o I PACKER (002141-001J)C 18,865.2 5.240.1 9147 FRA SLEEVE Baker csleeve(2,29Y Ball) Assy N 2700 FPSC716 PN 11809080387, (MILLED TO 270' 311119) 19,1383 5,234.0 91.35 SWELL PACKER,BWELL,4 irz% U7FffAKTP,HYD 56TrN7 3.900 dediveN 1., 1. spar. L PACKER (0021414001-2) B 19,3396 5,2294 91.36 FRAC SLEEVE Baker list, sleeve 2255' ball Assy N 2700 FPSC715 PN UH809000386, (MILLED TO 2.79' Y1/19) .bck Ma Rem., 1488+.9 I 19,5]].2 52246 9124 WEL W LL4112%6. ",BAKER,HV D 56 3 S N 3.900 PACKER (DD2141-001.9)A 19,7518 52201 9126 FRACSLEEVE Alpha Pressere Sineve, rupwre disc 914 (7300 psi 3000 ow, 7900 psi high, 7613 nom psi) News Fnnae; Is arse I 19,765.3 5,220A 9125 FRAC SLEEVE WeIl09re IsDaron Valve Bell DO -/4-113w -90 0.000 psi shear Tubing SVings NTM1aufv Frei IPRII 0 I Tubing Deserlprlen TUBING PRODUCTION So -me ma_0)0111 4112 3.96 Topdffhd 344 setDeplh(n..Sel 13.]00) Deplh (rv0)(....311)X1 5,089.] 12.60 Dude L-80 Top connection .1cal 563 Completion Details TopIMBI Topg)(h (MB) Top i=I P) ". Des fµ11 Nominal IO 0111 IR LINER: 133]-19,8508 344 34.4 000I HANGER 1 Hanger.4-112'x10-314-Lien 5, FMC TC -1A EMS 3.920 ConocoPhillips KUP INJ WELLNAME 3S-612 WELLBORE 3S-612 Alaska, IM.r '"" NLSIz SNTyA 'sz da PM Completion Details VaRW vlwn&lacnall Top (rea) Top lent Nominal rap We) 16KB1 M Item oea com ID (In) ........................................................................................... MANGER: 31.a 1,920.6 1,829.9 36.33 NIPPLE Nipple, Cameo, 3. i "DB Profile, SN: 3654-3 3813 1350]0 5,043.0 76.10 UKDZUTUM7 Gauge Came,, SUB, SON win Sapoire tubing Weaker, gauge, 3864 SENSOR SN:CI5GM-M03 13,5693 5, 58.1 76.08 PACKER Packer, Baker 4117 x ] 518" Premier SN 11495193 3.870 13,633.3 5,0734 76.02 NIPPLE Nipple, Cameo, 375" DB3 ProNeSN: SN 4053-2 3707 1 ,690.1 5,0872 76.05 LOCATOR Mec nice ocator . "T II Box(OO4P) Qarge D above 3.950 CONOOCTOR; 3961190 heated) luarly FIW -Daek 0.a aeu.o,nn4rmle 3, 1.1 5,0874 7606 LOCATOR McCM1anical Locamr 4.5"TCII Box (small OD bebw located) 3950 NIPPLE, 1.Pi0.a 13699] 5,089.5 76.12 MULE SHOE lBaker Fluted WLEG (Wire line entry guide) 3.900 Frac Summary SURFACE: all.a OO.0— S1anDM Pmppant Despnee pb) Pansurrin Fomlatlanllbl 101712018 207,200.0 19],]550 - — 9tpe s—.--0----Tap OepM IBBBI BNnIKK81 LMkb Flutl $ysMm ichum lbd) VOI31urry1pbg GAS LrFT SRM, 1 101]2 018 19,]51.0 19,]520 <typl>, <8uldname> 3.2]2.00 3,48507 AmLYFou ClSwnea; SINS ILI3T110.O,111a 8 Sam Dab Proppnl Deal, ilei Pmppantln Forinuffl pl 10172018 207,204.0 212,]68.0 Syl• Sm"DRS TeD llapIM1IKKB) Btm IMIN Llnk bFluids bm vd Cleanleeg VeIS1urryl6Nl 045 LIFT, 1],ro]3 2 101]12010 19,3390 19,340.0 Mpt>,<Ouidname> 2,006.00 2,236.00 GAUGEFIIMP SENSOR; 13emb SWROIN ProppaMOtllpnetlpb) PR,,Nmtln F*rmNMllbl IZ17IM18 207,204.0 201,375.0 PACNER; 13589.7 pM WkN BbipKin Link to PuiO Sydem VBICWn(Nal Vol Slurrylbbg .3%. 1-1-VII..-Mil-18` 3 101]2018 18,865.De0 18,866.0 Gelled Salt Water, 30 lb Berate 2,12300 2,425.00 Swap.. PmpWnt Uasipne4 pbl iinti lIn Formalbn 86) 12202018 207,204.0 196,1700 NIPPLEa3 SEES gimp gran Dab Top cepa gtKB) BIm 111118) LI k1oFluid4yshm VeILWn1669 Val Slurrylbba 6 102012018 D,3]fi0 1],3]].0 Gelled Salt Water, 3016 Borate 2,33200 2,549.00 LCCATDR; 13.630.1 Stan Dam proppnt 0-SnW paid "N"N"SlIS F."". (ON LOCATOR;ta4tl+� 12120(2018 20],2040 210,845.0 81ptl glart Date Tap OepM INtBI ehn lNte) Llnk to Fluid Sysbm Vo1CWn 1669 Vol Slurrylbbp MULE SHOE: A6w.T 4 102012018 18,389.0 18,390.0 Gelled Salt Water, 301b Berate 2,388.00 2,61600 SbNDaM Pnimanl ONt,w ut Propgnl In Funnel 8b) 12202018 20],204.0 215,101.0 Im 11IXBl U.kto lukl Syalem Sm 11 BMrt Deb Top DepM lld(BI W17-054 Vol CWn atoll Vd SNrry(ban 5 122012018 1],8530 1],8540 Gelled Salt Water, 3016 Borate 1,835.00 2,068.00 Sten N. 122312018 Promise, Deny lib) P IgNotln Formabanakl 207,2040 207,8750 INTERMEDL9TE; 33.61395re set Smnus. Tap DepN IXNBI Bbn WS) Llnk to nutl Sys@m Vo1LWn1669 Vd Slurrylabll ] 1212312018 16,8970 16,898.0 Gelled Salt Wake, 30 It Borate 2,246.00 2,4]100 Date Proppanl Ceslpnedpbl Ploppant In Fmmeaon IRS 1 1 22312018 207204.0 200,146.0 SIR Sian Deb Top OepM lakBl BM 1BBBl LinkbfluWSysMn VOICWnlab9 Vd3lmryrya9 Nyenda Fn ana4ssr.. I 8 10232018 16,345.0 16,346.0 Gelled Sall Water, W lb Borate 2,086.00 2,311.00 SMrt Dab 12232018 ProppaMMFomlaki 207,2040 211,6470 814• SMd Dab Top OeplM1 at KB) Bbnatl(B) unkb Flutl System VOICWn 16N) Vol sl110Mpap 9 121202018 15,Bfi].0 15,868.0 Gelled Sall Water, 3014 Borate 2,33200 2,561.00 Nyan lc FrcMa; 14.8720 I Sam Dab 122]2018 2P --n, Oespned gal PMp pnl In Fwmabon big 20],204.0 210,67].0 61pY Saa,Oab Top Oew two, BM atl(Bl LMYb Fbq Sysbm VOICWn labp Vdrlarryp" 10 122]2018 15,388.0 15,389 0 Gelled Saa Water, 30lb Borate 2,45300 2.68100 Xyenlx Feria.: 15.S39 .0 I 8brtpab 22 1]2018 proppsnt DesgnBd(lb) P PI.H.F.M.0b) 20],204.0 211,332.0 an" lessOgle Top DOp16 MEM BM WB) U..Fluq Syabm Vd ClmnlbE9 Vol slum teal 11 122]12018 14,8]2.0 14,8730 Gelled Salt Water, 30 IS Borate 2,21400 2.4 2.00 Sad Dons Pmppant Desbned1161 Prappnt In Fwmatlon (b) 10282018 20],204.0 211,104.0 Nyasa Fn000 150.41.0 I SIpY SM,DNe Tap D0g6 aMBl BM W13) LNY b ease .1. ValCWnlab9 Vol Slurrylabg 12 112282018 114,357.0 14,358.0 IGEItsd Sag Wale, 30 In Borate 2,6]0,00 2,898.00 Mandrel Inserts St Xy4reu4 FncWn: 18.30.50 I W N Top Indu Top (M 1- laL6 Pon Sua TRO Run WS' Mab Model OIDPRI Sery Type Tai gm Ipsll Run Dea Com Aan"Faa-Nae a,ae Iamo at....:+vlueote+ 3,644.8 2,]95.1 Cameo KBMG 1 GAS LIFT DMY BK OOOD 00 31132019 2 12,080) 4)048 Camco IKSMIJ I 1 GAS LIFT IUMY INK 1 0000 00 31142019 HySc4e Faclun,, la,an.o I Notes: General&Safety End role Annoallon 1.13¢018 INCTE: View Schematic wl Alaska Sc6ement10.0 Hpmlk[ FncWraaT.3180 I Nyareac Frwpxe,17..0 IfrbsuE FracWn: 16.307 0 I Nye' Fnd,re less 0 1 See.. F.... IS.. .0. F.. 1.,1510 LINER: IS 7-1..`A.4� MEMORANDUM To: Jim Regg P.J. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 25, 2019 SUBJECT: Mechanical Integrity Tests ConowPhillips Alaska, Inc. 35-612 KUPARUK R1V UNIT 35-612 Sire: Inspector Well Name KUPARUK RIV UNIT 35-612 API Well Number 50-103-20777-00-00 Inspector Name: Matt Herrera Permit Number: 218-111-0 Inspection Date: 4/4/2019 " Insp Num: mitMFH 190407055351 Rel Insp Num: Thursday, July 25, 2019 Page 1 of 1 Packer Depthre es m to 15 Min 30 Mtn 45 Mtn 60 Min 35612 Well --- - - - Type Inj w'TVD 5059 Tubing 1075 — 1075 ? 1075 - _ f 1075 1075 -- -- -- 7181110 Type Test sPt Test psi 1500 IA 290 2200 - 2750 - 2180 -' 2140 - BBL Pumped: T 3.6 ' BBL Returned: 3 6 OA 748 532 794 780 ns — Interval T Initial Test �/ Pass Notes: MIT -IA per Sundry 319-111 post conversion from producer to injector Thursday, July 25, 2019 Page 1 of 1 THE STATE °fJ IL GOVERNOR MIKE DUNLEAVY Lynn Aleshire Staff Petroleum Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-612 Permit to Drill Number: 218-111 Sundry Number: 319-111 Dear Mr. Aleshire: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this t day of March, 2019. ®MS�Mp� � 61p19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I iAH ll 6 ^��9 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 - 1. Type of Request: Abandon Plug Perforations ❑ Fracture Stimulate U Repair Well Ll Operations shutdown Li Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ *?07 6 QA& Other: ❑ 2. Operator Name: 4. Cunent Well Class: 5. Permit to Drill Number: COnocoPhilli 5 Alaska Inc. Exploratory ❑ Development 0 St ❑ mtigraphic El 218-111-0 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-103-20777-0000 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? �� Will planned perforations require a spacing exception? N A Yes L1 No El KRU 3S-612 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380107, ADL 25544, ADL 25528 1 Kuparuk River Field/Torok Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,862' 5,218' 19854' 5,218' 7,000 Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' Surface 3,027' 10.75 3,027' 2,588' Intermediate 13,866' 7.625" 13,866' 2,218' Production Liner 1 6,161' 1 4.5" 19,854' 5,218' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See attached schematic See attached schematic 4.500" L-80 13,699' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - PACKER, BAKER 4 1/2" X 7 5/8" PREMIER SN: 11495193 MD= 13569 TVD= 5057 12. Attachments: Proposal Summary LJ Wellbore schematic L4J 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for • 3/11/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG El - 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: Lynn Aleshire Contact Name: Lynn Aleshire Authorized Title: Staff Petroleum Engineer Contact Email: lynn.aleshire@cop.com Contact Phone: 907-265-6525 3�(e �:g Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: ,,,,(/ Post Initial Injection MIT Req'd? Yes M No Spacing Exception Required? Yes ❑ No EK Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: r 1-./z-403 p0/117—L 3/b//8 O R I G I N A L RBOMS AR 0 8 2011.t Formand v ' Qor/m 1�� 0403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Anchments in Npliwte a ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 March 6, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 35-612 from Oil Production service to Water Alternating Gas Injection service. This request for conversion concludes the pre -production d for this rotar tal well in the Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding KRU 35-612, (PTD# 218-111).' If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry application Summary of Proposal AOR Detail Area Map Well Schematic 3S-612 SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 3S-612 (PTD# 218-111) from oil production service to water alternating gas injection service. Area of Review: KRU Well 3S-612 was completed as a rotary horizontal producer 2/2/19. The long-term plan for the well is to provide enhanced recovery injection support for producers 3S-611 and 3S-620. The top of the Torok sand was found at 13,948' MD/ 5,248' TVD. • Area map with 1/4 mile radius around target injection zone (see attachment) The attached map shows that two wells, KRU 3S-613 and Nuna 1, are within 1/4 mile radius of the 3S-612 penetration of the Torok sand. Mechanical condition of well to be converted: The mechanical condition of KRU Well 3S-612 is good. The injection tubing/ casing annulus is isolated via a Baker packer located at 13,569' MD/ 5,057' TVD. A State -witnessed MIT -IA will be performed once Well 3S-612 is converted to water injection , online and stabilized. CBL and interpretation of cement quality: See attached AOR Detail The 10-3/4" surface casing was cemented with 1,496 sx of 11.0 Class G and 219 sx of 12.0 Class G. The 7-5/8" intermediate casing was cemented with 1,466 sx of 15.8 Class G. A sonic log run on 11/11/18 found top of cement at 8,270' MD AOR Detail Top of Torok Top of Torok Sand Top of Cement Top of Cement Top of Cement PTD API WELL NAME $TANS Sam 011 Oil PopIfND$$) SMD) SND$$) Determined By Resemalr Status Zonal Isolation Cement Operations Summary Mechanical Integrity Pool(MD) 10-3/4" 600sa PF T, 260as Class 211-155 50-103-20645 Nuns Suspended 6895' 4930' 2350' 4893' CBL Suspended SI P llnertop packer and WRP G;7-5/8' 192sa Class G; 4-1/2" 4/28/12 MIT -IA liner uncemented. 16" Driven; 10-3/4" 1743. Class G Lead, 290. Class G tall; 7-5/8" 216-020 50-103-20735 35-613 Injecting 4339' 3644' 6,095 3,711 Sonic log Parts open for injection BAKER HRD-E UP 10,90- MD Stage 1: 228m Class G, Stage 2: 9/21/16 MIT -IA to 3000 psi 1210sa Class G; 4-1/2' liner uncemented Oooguruk Unit I � i.>_ Y 13 V I O 17 iY 1 I 1 Si I i i i 1 190697 I i i i ConocoPhillips Alaska 3S-612 Injection Sundry 3/5/2019 12 or w' w ti :m 0Y Cyrz 'z Nf :N Other Torok Wells Well Trajectory Open Interval (01) OI Quarter Mile Radius CPAI Lease Caelus Lease T12NR8E T12N 6 ADL380106 ADL380107 0 0.2 0.4 0.6 ■Miles KUP PROD WELLNAME 3S-612 WELLBORE 3S-612 ��CO'"'ns Well Attribut! Max Angle T TD P Field Name Wellbore AVYUl4 WeIIWre Slzlus Irl" l MDIh. Fd ahn lXXa1 Alaska. Inc. TRACT OPERATION MORTRO4 501032077100 PROD 1 fit 1A Rad Kr 19 Rfi20 sini.11032ns AM Last Tag VeYtel etmamR Ra4mll Anndarbn OepM MKS) EMDah Wellbore Las[MW ay XAxaER, 34. _-- ....____._.. LAST TAG: RKB 19,1650 3/112019 35812 colMilw Last Rev Reason AnndatlanEnd Data WNIMre Lesl MM By ........................................................ . Rev Reason '. MILLED FRAC SLEEVES ahzu19 I., ironer. Casing Strings Casing Dencrai oO she 1.Set I"NKEb Set edb lXKet SN Depm RnAoi WLLen p... GSM. Top Tbrea9 CONDUCTOR 20 18.50 39.0 1190 119.0 154.00 coxoucTOR; 33.a116.o "'Ne rad- .Oo Caring oaamipnon SURFACE ODDig 10 L4 1113 ('.1 9.95 Top MBI Sd 38.6 3.02)0 oevlb mKa) Senega 11VO1... YNLen p... Code 2,5582 45.50 L80 Top Tarta4 Hydrd 563 Solt pN s x1PPLEamaO Casing installation INTERMEDIATE O011n) 158 1 ID BadTop BBB MKB) Seat 366 13.8579 adopt MD) Seel OeWa ITVDI... WtlLan 11...OMe 5,128) 29]0 LBO Tap Talead 11563 Casingoeecbglon ..,.a,1D are Top MKS) Sal DeptoM O) Set Dash ITVDr.. stores 6... Brox Top Traded LINER 4112 3.96 13.693.] 19,854.4 5,218.3 1260 L-80 Hyd 563 SURFACE: So S3,02].0� Liner Details appeal lin BAs un; seu.9 Top111KS) p"DIV01(BKa) molohn (°I team INS Con. (in) 13,6933 5,008.1 76.08 PACKER Liner Top Packer, 5S X 7,63".H LXP, w110 4820 nmwr RUB -Cl s..ad.r. Seal Bore Extension aa1501rmon1V142Xa 13,7133 5,092.8 7623 NIPPLE RS NIpple, 5-10, Hy4563 4.250 ane UFT: 12.000 3 70930 ]625 HANGER Liner Hanger, FL pinned 1706 psi 4800 BwaFPUMPs3W70 13,]345 5,0978 76.38 SBE SealOore x "Hytl 1Pin upx4.5"Hyd 521 box tlown 4020 PACKER', rassey 14,117.1 5,1850 77.21 S ELL PACKERSINELLA IQ X-EAKER,HYD563 SIN 3900 PACKER (002141-001-10)L NlvvLa; Ism 3 14,357.5 5,23].8 ]].88 FRAC SLEEVE a r fiew s eeye 5' ball May K, HY 5 2,700 FPSC725 PN HSO9080396, (MILLED TO 2670" .R:;3 ,Ma1 ?8]119) LouTOR: mm1 t 14,6316 5,211.3 85.91 SWELL A KER, AI 112 X 6 Op'.8AKER,HYD56G SN 3.900 PACKER (0021410-001-11)K MULE ENDS :ls.ase.] 14,872.2 5,280.9 90.89 FRACSLEEVE MUMUsleeve (2. 5"ball) ASsy J.H D N 2100 FPSC724 PN H809080395 (MILLED TO 230" 212]119) 15,109.4 S. 19.2 89.88 71 PA KER,SWELL,d I Q X 6 00",BAK R,HYD N 3.900 PACKER (002141-001-6)J 15,386.4 5, 0 8966 FRAC SLEEVE Baker URESleeve a say 1, Hy 5 N 2.700 INTERMEDIATE; 3619 FPSC723 PN 11809080394, (MILLED TO 2.10' 2128119) 15,624.8 52830 8921WELL PACKE ",BAKER,11YD5 SN 3.900 PACKER (002141-001-12)1 Hall Frames, 14,3570 ' I 15,861.5 5,283,9 90.17 FRAC SLEEVE dn"Ids TIRE seeve Q 545m ball) sy H, HYDS N 2700 FPSC722 PN H809080393, (MILLED TO2 70" 2120119) 16,1043 5,2828 W42 7WELL PACKER,SWELL,4 112,HYD%3 SUN 3.900 PACKER (002141-0014)H HybaJb Fein;14.9]20 16,345.3 5,281.1 90.35 CRAG SLEEVE Baker firs, Sleevebat Ass, HYD N 2.700 FPSC721 PN 9809090 80392, (MILLED 702]0" 2/281191 16,618.1 5229d 9043 WELL P BAKER,RY) N 3.900 HWm.e vk" , Mail ' ' PACKER (002141-0018)G 16,8978 5,2773 90.45 FRACSLEEVE BaIde, spe,sesse 'ball) Assy F, HY 5 N 2.700 FPSC720 PN 11809080391, (MILLED TO 2.10- 228119) Hydral Frahm.; Islas? 0 I ' 11,133.4 5,2754 9044 SWELL PACKERSWELL.4 11 KERRYD 563 N 3.900 PACKER (002141-001-1)F 17,376.9 5.2738 90.58 FRACSLEEVE Ba r raCseeve . " all Assy E, HYD 563 ON 2700 FPSC719 PN 118090801 (MILLED TO 2.10" Xydau& Fa4n', 18,3480 288119) 17850.8 5268.4 9131WELL 1 ',BAKER,HV 35N 3.900 PACKER (002141-001-14)E 13: 4seez.o,i ni Ended Hyhm4"e Fireman 'a.. I I 178537 5,263.6 9140 FRACSLEEVE eraCsceve . " balq,Aesy DHYD563CN FPS0118 PN 9809080389, (MILLED TO 210" 288119) 2.300 18,121.4 5.257.3 91.29 SWELL BAKER,HYD56351N 3.900 PACKER (002141-0013)D Named. Fw9ee, IT.... I I 18,389.2 5,251.1 91.39 FRACSLEEVE Baker i sleeve 33Y ball) Assy C, HYD 563 CN FPSC717 PN 9808080388. (MILLED TO 2.]0- 2300 228119) 18,58].1 5246.6 91.32 WELL ACKLL, I X ",BAKER,HYDSfi35N 3900 Hyna4H Fixwad; n,es3.o I I PACKER (002141-001-7)C 18,8652 5,240.1 9147 FRACSLEEVE Baker bad, seeve 'ball) Assy B, HY05 CN .7 FPSC716 PN H8090B038], (MILLED TO 2 70" 311119) 19138.] 5234.0 91.35 WELL PA L, . ', AKER,HYD563 N madomicmmva F 181 I I PACKER (002141-001-2)B 19,339.6 522964 9136 FRACSLEEVE Baker ins, Sleeve . ssy A, HYDS N 21 FPSC715 PN M-1809080386, (MILLED TO 2.10' 311119) XyRm4a Frcdre; 149 .0 9 9 19,51/.2 5224.6 9124 SWELL PA KER, E 1 UO-,BAKER,HY0 N 3.900 PACKER (002141-001-9)A 19,751.8 5,220.1 9126FRAC SLEEVE Alpha Pressure Sleeve apture oiscp4 psi 3000 low, 7900 Psi high, 1613 nam psi) H,hasmkamm 1933SO ' ' 19.]65.3 5,2204 9125 FRACSLEEVE Wellbore hadallmn Valve Ball OD -14->I 4', 0.000 psi shear Tubing Strings Tubing Dencroban SRI Ma...[30. to 1157) Tov mKel ea Depla m.."Noepla mol (.. w+nWn1 arwle Top Cannecllm .Va"Vea I.. la,]s1n I I TUBING PRODUCTION 412 3.96 34.4 13]00] 5,111 12.60 180 Hydri1563 Completion Details ToPOND) TopiMB) RUNIN Topinal 1 0 lash Des Com Numinel mpnl 34.4 34.4 00 HANGER Hanger, 4-112"x10-314"Gen S FMC TC -1A EMS 3.920 LINER; 13699.T�18m4.4 �, Ant KUP PROD WELLNAME 3S-612 WELLBORE 3S-612 ConocoPhillips0410) q Alaska, lrlc. anal],s 910M15M Completion Details Vernon national (nation Top IVB) TopIncl 1, (Me) ImcB) 1°I Irm Das Com Nomirnl m(in) rvANG8R1 ala 19205 1,829.9 3633 NIPPLE Nipple, Cance, 3.813" OB Profile, SN'. 3654-3 3.813 13.5070 5.430 7610 1Gauge Carrier,SLB, SGM with Sapphire tubing pressure gauge, 3,864 SENSOR SN:CI5GM-0403 13,569.] 5.058.1 76.08 PACKER Packer, Baker 4 112 " x7518' Premier AN 11495193 3.870 13,633.3 5,0734 76.02 NIPPLE Nipple, Camco, 375" D04i Profile, 51,1714 3.750 13,690.1 5,087.2 76.05 LOCATOR Mechamce o—Mo(large OD above 3.950 CONOULTOR:vn1190 IDcaed) Amrrodd-orer:bo 38150: 11na2ma 13,091.1 5,087.4 ]8.06 LOCATOR Mechanical Local 45"]CII Bos (Small OD below located) 3.950 NIPPLE, .9ra 13,699.7 5,089.5 75.12 MULE SHOE Baker Flubed WLEG(Wirs line envy guide) 3900 Frac Summary Srn ong,Pfoppart 1211712018 Daswred lib) 207,200.0 Proppam In Formal 1161 197,755.0 SIMmonal 39.6a.O1).O� SqX %nDar T-DepM lal(B) NE Me) Link m"LM Syerm Vol Llea^Ibbn Vol Slurry lbbn ors UFT: a.aaa.8 1 12/1)12018 19,]51.0 19,7520 atypt>, a0uidname> 3,272.00 3,485.00 %.Dar Proppam Deatune0110I 20],204.0 "an.. (Ind 212,768.0 NrruWFlW �LISmaarL Alij3.T000 gearing Sty/ %rtDar Tap Mptlr MIKE) 2 1Ml]r=8 19,339.0 11fing B) 19,340.0 LinxrFluksyarm atypl>, aeuidname> VelCwn@bre Volslmrylbbn 2,006.00 2,236.00 GAdr UFT'.IZ0! (ii11GE/%IMP SENSQP: 1351121]2018 stat1W712018 Prappml0ulyne4 ad 20),204.0 Propynl In Formation Use 201.3]50 Sty/ Ybrt DNe Tap -01 MM) Mm MKB) U kWFluMsprm VolCwr ging VOI81urry(bbn PACs R;la,W7 3 121]2018 18,865.0 18,866.0 Gelled Salt Water, 30111 Borate 2,123.00 242500 NODar Peoppnl Geagrail In Formation (11b) 122012018 207,2040 IPmp-nt 1961700 NIPPLE: meV.a Syli Srnoar Tap celatlr MM) BM MKB) Lrkr FluMsysrm volchum Mbn volswrry(bbn 6 12202018 1],3]60 17,3]]0 Gelled Salt Water, W Iib Borar 2,33704 2,549.00 LOWTOR: t3,6MI sun Cele Proppand Desened(lot Pmppnt In Formatlon(to) LOcar7ORg3sv 122012018 207,2040 210,8450 610Y %nNta TopeNnaans) o"Wel Ynxr FlUM Sysrm VdOwn Mbig Vaslurrylbbl) WOSKOEnawe.r 4 102 01818,389.0 18,390.0 Gelletl Salt Wacer, 30111 Borate 2,38800 12,616M Saint a p,agnm(to) Proppam r Formrm 061 122042018 20]2ce 215,1010 Stan srn Dar Tbp NFb al BM WB) r and System VolCwntbbn Vd Srag Mbll 5 JZ202018 1],8530 17,854.0 June Gelled Salt Water, 30 lb Borate 1,83500 2,06800 Srn Dale Proppanl0esi0netl 1161 Prpppnl In FmmeWntlbl 1212312(18 204,204.0 20],8]5.0 INTeKMEOIATe, asalaesr.a Stan srn Date no Depth Obs) BE. IMLBI 7 122312018 16,897.0 18,690.0 Lmxm Flnla sraNm Gelled Salt Water, 30 IS Borar volcwn(ebn van slunY tea) 2,246.00 2,4]1.00 S mtDW PropfinnIN ipnMpbl P10ppnlM FornWlon pb) 12234018 207,204.0 20$148.0 Styr srn Dar raP oeplM1 MKaI atm mKe) Linxr Form sra2m volcwn(bbn vol srrry leas Kraarpo Pndal league i i 8 122312m8 18,3450 16,346.0 Gell ed Salt Water, 30 to Borate 2,08600 2,31100 %rtDarP,oppanmaaianm 0e) PmPpnlM 1.rm nOb) 12234o18 2072040 211,64].0 Sty/ Srrt DM Tap Oepllr(IS.) BMMKB) Lin Fr Oursysrm Vr Oranlbbn vol Slurry(ebn 9 12234018 15,86].0 15,868.0 Gelled Sad Water, 30111 Borate 2,332.00 2,561.0 Nylvnk Frcnns: 14.910 I ' srrtwrProppam Denfined (WE Plopanun FormaBorl(m) 122]12018 207,2040 210,677.0 sqi %nDar Topwptlwsl BMIKKBI Lanto Flui46prm VOI CIedu,bb1) Vol Slurry (b a1) 10 12274018 15,3118.0 15,389.0 Gelled Sall Water, W m Borar 2,453.00 2,681.00 %nwr reopen, wegned (ib) Proppam In Formseat fib) PA.. FnaMn: "Band ' ' 122712018 207.2040 211,332.0 Sq• srn wr Tap wpM (KK0) WB) LInFr FlUM Bnrm Crean MN) Vo16Nrry,bbn 11 122]2018 148720 IB. 14,873.0 Gelled Sall Water, 30111 Borar IV., 2,214.00 2,442.00 Stan Oar Pmppnt wsgnea 06) Pwppnt In Formation fid 122812m8 20],2040 211,1040 Npnur Fracture: 15,!8].0 ' I Sip• SYrt tub Tap wplb,KKB) Bbn MKBI Ir Fluid Bysrm Vol crap (bbl) Vol Slurry lbbn 12 122&2018 143570 14,358.0 Gelled Sao Water, 30111 Borate 2,8]0.00 2,898.00 Mandr ll Inserts St rvybaJb Fracture: 16,3,150 1 1 BE KB) Tap (NOL ,KKBI Maar MWeI Valva Inkh 00 in) sery Typ iyp PartSW ,inn TRORun Lpsi) Run Der Com 44.8 2]95.1 Camco KBMG 1 GAS LIFT GLV BK .188 1,800.0 11192019 PmrJvr F4W-NaCl Brve: 13.iM.alB.ri.O ttntrzme� .7 4,)448 Camco KBMG i GAS LIFT OV BK 0.250 0.0 1181019 Bymmlm Fran. i,ral Notes: General B Safety End wr i Anrowon 1211312018 NOTE: View Schematic wl Alaska Schematic 10.0 Kybarh Fracbve,1],3]8.0 1 1 Nideri Frat 17,85as 0 I i Kronur FracW re,'it'.0 1 1 Kyorur Frmpnq 19,9 0 a r KI.. 1.; lB 3300 KybaYo "..19,]510 f LINER: 13.03] -19,98f.4 ---,l w 0 IL W w W 0 Z J 0. 2C O 0 N VN N J `Q ``r r M2 W Q F— Q 0 L IL c: Q h w m w H E M 2 12 IS MI IK � 3 O OLL� O r OyMaIMIa w ° O —M>�>_>>UUU❑ a❑ a❑ a❑ a J J NJNIJ NIJ NJ N m 3 m � m � m K � � K m °I —0 o�°I io °I co a Na N a it a o a N d N d "y) a LL O LL O a 0 a m a N a woo N a U N U N U a U m 0, 0, 0, U m LL' m LL' a a ❑ N m m N Ui Gi N N 3 N N Ui a ❑ z ❑ z C,z C,z LL zl ILL zl LL z LL JI LL JI ii JI LL JI iLL E':ow Y 0 Yo of 3U pU �F pD pD pD o E"c m 'c m 'o mE Fn, c 'c m 0 o j o f Oj o o N o O j o= oo'- o"? o W c0 W 6 W m W 6 W 6 W 6 W tp W K W LL' W LL' W K W ,m M m m m m m m m m m m j 0 0 m o O O O o O O O O N N N N 2!.J m N N N N N N N a m m m w w m m w m m ro xx OU a N N n in c f°n 0 O U N N N U Eo 0 ❑ ❑ 7 ua E Z C C d g j 0 0 O C O W p Z M M a0 E ry E Om = Pa a Z J C f U U Q V J a 0% T❑ ° m m m m m m m m m m m m m m io m m m m m m m ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N N 5 76 76 N N N N o N N N N N N N N N N N N r r r r r r r r r r r N N N N N N N N N N N O O O O O O O O O O O M M M M M M M M M M M U U U U U U U U U U U ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ W W W W W W W W W W W 0 m a w O CL W w W U Z Q cJ GT O ON LO UN N J LQ Lr r 2 m La r Q 0 3 N N Imq N N N IN/1 N NO N Z LL _ EEp E E E E pE E E E E �3 3 3 3 3 3 3 3 3 >. O O O O O O O O O O a:O w w w w w w w w w w ❑ ❑ I r r r r r M m m M M O > ❑ > N N N N N N 0 W 0 W g i ❑ ❑ ❑ C30 ❑ ❑ ❑ ❑ N TI N �I N z z z z z z z z z z m m= M m m m= m M N N N N N N N N N N I> I> I> I> I> I> I> I UW¢IULC :�roNN I UW¢UC vNN I QUUC 0N <U�C VN5 QUUC gN U¢ }% ?C rS>m mC �m o a aaa0- U) W vC mmC am wco o hmMyC wmMoC MmMoC ' 0 MMQ Mm m— mO KI KI hiIrld KI uKI 5i KI ti KI am o d 6 ai i' w e 00 0- d Z Z zZzzz% L �-L ImMUL N0 0 0 0 0 0 0 gv o0N'/1'U'vi'(D 'E (D 'E NC> Q 2 E°> Q> °> o> °> °°oZ od o Q Q I I U KU U U U U U U U G NI A? mro m m m m m ?vm m m NmdoC DmmaZ Wtp Wtp W W W0 WN W0) W0) W0) WN w W0) WN wU) W07 w U Q7 O) 01 m m m m O) D7 O) 0) O O O) Q7 D7 O) A O O O O O O O O O O O O O O O O O O N N N N N N N N N N N N N N N N N N J 0 m N 0 m E U w 0 a m m O 0 6 a E 0 U N b ❑ H B2 m m 2 yg }3 m m m m m m m m m m m m m m m m m m m m m m m m m m m m ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ - - - - - - - - -- - - - - - - - m m m m m m m m m m m m m m m m - m m ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N N n N N N N N n n N n N N N N N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M M M M M M M M M M M M M M M M M M U U U U U U U U U U U U U U U U ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ LU w w w w w w w w w w w w w w w 2 U O C: c E 0 0 0 O d O 0 6 a O U O1 N N fA m y d O. T L m m Q a o Z A 9 O ❑ ry = C O L d _W ❑ 00 J € } } ❑ lL o C r � � � d — m 0 '� N J 0 C v E a N M a Z p>� d c E 0 m E U U d � C � am E r o U a 6 T � f/1 p d p W J d d i d Ed Z �J U O a N N d O. T L m m Q a o Z L L O U d m 2 no U U � } } ❑ lL o d m O d d d � iT E N d N W O E °0 E — m 0 '� N J 0 C v E � U U a Z p>� d c E 0 m E 0 v d � C � am E r o 6 T � f/1 p d p d d c � n p m O � � T m m O O N N V o7 W O N r r � T m Z ❑ y m d H N LU V d m ❑ 00 C d d i 0 O a o d a V ❑ a mE K 6 O C N a 0 U Ud U U �J U O a STATE OF ALASKA I ALASK L AND GAS CONSERVATION COMMISSIO. . REPORT OF SUNDRY WELL OPERATIONS E CE IV F. D, JAN 2 JE 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑v Pull Tubing ❑ Oper£Yo,5fs� 'rc 0 Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approve rogrbb9m F—d Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: n 2. Operator 4. Well Class Before Work: 5. Permit to Orill N F Name: ConocoPhillips Alaska, Inc. Development El Exploratory ❑ Strafigraphic❑ Service ❑ 218-111 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20777-00 7. Property Designation (Lease Number): 8. Well Name and Number. KRU 3S-612 ADL 380107, ADL 25528, ADL 25544 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10, Field/Pool(s): Already provided Kuparuk River Field/Torok Oil Pool 11. Present Well Condition Summary: Total Depth measured 19,862 feet Plugs measured None feet true vertical 5,218 feet Junk measured None feet Effective Depth measured 19,854 feet Packer measured 13,694 feet true vertical 5,218 feet true vertical 5,088 feet Casing Length Size MD TVD Buret Collapse CONDUCTOR 80 feet 20 119' MD 119' TVD SURFACE 2,988 feet 10 3/4 " 3,027' MD 2558' TVD INTERMEDIATE 13,821 feet 7 5/8 " 13,858' MD 5127' TVD LINER 6,161 feet 4 1/2 " 19,854' MD 5218' TVD Perforation depth:/FRAC SLEEVES Measured depth: 14357 14872 15388 15867 16345 16898 17377 17854 18389 18865 19340 19752 feet True Vertical depth: 5238 5281 5280 5284 5281 5277 5274 5264 5251.5240 5229.5221 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 13,701' MD 5,090' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - HRDE ZXP LINER TOP PACKER 13,694' MD 5,088' TVD PACKER- BAKER PREMIER PACKER 13,570'MD 5,043'TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): 14357-19751 Treatment descriptions including volumes used and final pressure: Total Well -12 stages 2.4 million be proppant placed ....see attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: WA - - - - Subsequenttooperation: N/A - - - - 14. Attachments(regmred per 20 AAC 25.070, 25.071, a 25283) 15. Well Class after work: Daily Report of Well Operations ❑r Exploratory ❑ Development (] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ a 16. Well Status after work: Oil ❑� Gas ❑ WDSPL ❑ 1(217$11 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: 318511 Contact Name: Hanna Sylte Authorized Name: Hanna S Ite Contact Email: Hanna.Sylte@cop.com Authorized Title: Completions Engineer Contact Phone: (907) 265-6342 '� ( 25 Authorized Signature: Date: Form 10-404 Revised / 1 L CV N J Xl9 RBDMS% FSR U i ?019 Submit Original Only 3S-612 FRAC STIMULATE DTTMSTARJOBTYP SUMMARYOPS 12/17/18 DRILLING Performed fracture stimulation treatment on intervals Data SUPPORT- frac, 1, 2, and 3 per design, ramping from 1-7 ppa stages CAPITAL using 30# Hybor-G fluid system @ 40 bpm. Placed total 611738# of proppant (Stage #1: 197,595, Stage #2: 212768, Stage #3, 201,375). Well freeze protected with 30 bbls of LVT. 12/20/18 DRILLING Performed fracture stimulation treatment on intervals 4, 5, SUPPORT- and 6 per design, ramping from 1-7 ppa stages using 30# CAPITAL Hybor-G fluid system @ 39 bpm. Placed total 607,600# of proppant (Stage #4: 203,600, Stage #5: 207,830, Stage #6, 196,170). Well freeze protected with 30 bbls of LVT. 12/23/18 DRILLING Performed fracture stimulation treatment on intervals 7, 8, SUPPORT- and 9 per design, ramping from 1-7 ppg stages using 30# CAPITAL Hybor-G fluid system @ 39 bpm. Placed total 628,670# of 12/27/18 DRILLING Performed fracture stimulation treatment on intervals 10, SUPPORT- and 11 per design, ramping from 1-7 ppg stages using 30# CAPITAL Hybor-G fluid system @ 39 bpm. Placed total 422,009# of proppant (Stage #10: 211,332, Stage #11: 210,677). Lost blender/pump prime due to restriction in SW tank manifold. Flush 2000# of 100Mesh to Stage 12 with 226 bbl 30# Hybor-G and 55 bbl LVT. Shut down for night. Trouble shoot and repair tank farm manifold restriction. JOB IN PROGRESS, STAGE 12 TO BE PUMPED NEXT DAY. 12/28/18 DRILLING Performed fracture stimulation treatment on interval 12 per SUPPORT- design, ramping from 1-7 ppg stages using 30# Hybor-G CAPITAL fluid system @ 39 bpm. Placed total 211,104# of proppant. Well freeze protected with 30 bbls of LVT. 12 Stage Frac Complete. Ready for Slickline. Hydraulic Fracturing Fluid Product Component Information Disclosure .. Job Start Date: 12/16/2018 L Job End Date: 12/28/2018 State: Alaska Co B ounty. arnson ay API Number: 50-103-20777-00-00 1 Operator Name: ConocoPhillips Company/Burlington alowlh,Mz now Well Name and Number: Latitude: tr Longitude: Datum: Federal Well: Indian Well: True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: Hydraulic Fracturing Fluid Composition: Resources 3S-612 70.39417600 -150.19655700 NAD83 NO NO 5,218 1,172,986 0 C Chemical Disclosure Registry GROUNDWATER I OU Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments .. .. Number iRAdditive. in HF Fluid Eby mass)'" Sea Water Operator Base Fluid Water 7732-18-5 96.00000 75.36390 Density = 8.540 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.11864 CL-31 CROSSLINKER Halliburton Crosslinker Listed Below OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below Wanli 20/40 Ceramic Halliburton Additive Listed Below LVT 200 Penreco Freeze Protect Listed Below BE-6 MICROBIOCIDE Halliburton Biocide Listed Below Wanli 20/40 Ceramic Halliburton Additive Listed Below CL-22 UC Halliburton Crosslinker Listed Below OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker Listed Beim MO -67 Halliburton pH Control Additive Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below SP BREAKER Halliburton Breaker Listed Below WG -36 GELLING AGENT Halliburton Gelling Agent Listed Below SAND -COMMON WHITE -100 MESH, SSA -2, BULK (100003676) Halliburton Proppant Listed Below Items above are Trade Names with the ext;eption of Base VWter Items below are the individual Corundum ingredients 1302-74-5 55.00000 10.37477 Mullits 1302-93-8 45.00000 8.48845 Sodium chloride 7647-14-5 4.00000 3.14175 Hydrotreated Distillate, Light 64742-47-8 100.00000 1.36009 Crystalline silica, quartz 14808-60-7 100.00000 0.69417 Guar gum 9000-30-0 100.00000 0.28853 Potassium formate 590-294 1 60.00000 0.05752 Borate salts lProprietary 1 60.000001 0.05752 Ethanol 64-17-5 60.00000 0.04141 Oxylated phenolic resin jProprietary 1 30.000001 0.02760 • Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on Me maximum potential for concentration and thus the total may be over 100% ^' If you are calculating a percentage of total ingredients do not add the water volume below the green line to Me water volume above the green line Note: for Field Development Products (products Mat begin with FDP), MSDS level only information hes been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Dela Sheats (MSDS) Potassium metaborale 13709-94-9 60.00000 0.02688 Ammonium persulfate 7727-54-0 100.00000 0.02137 Heavy aromatic 64742-94-5 30.00000 0.02070 petroleum naphtha Sodium hydroxide 1310-73-2 30.00000 0.01890 Cured acrylic resin Proprietary 30.00000 0.00641 Poly(oxy-1,2ethanediyl), 127087-87-0 5.00000 0.00345 alpha-(4-nonylphenyl)- omega-hydroxy-, branched Naphthalene 91-20-3 5.00000 0.00345 Potassium hydroxide 1310-58-3 5.00000 0.00224 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00140 propanediol Sodium carboxymethyl 9004-32-4 1.00000 0.00096 cellulose Sodium glycollale 2836-32-0 1.00000 0.00096 Acrylate polymer Proprietary 1.00000 0.00096 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 1,2,4 Trimethylbenzene 95-63-6 1 1.000001 0.00069 Sodium persulfate 7775-27-1 100.00000 0.00045 Sodium sulfate 7757-82-6 1 0.100001 0.00000 • Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on Me maximum potential for concentration and thus the total may be over 100% ^' If you are calculating a percentage of total ingredients do not add the water volume below the green line to Me water volume above the green line Note: for Field Development Products (products Mat begin with FDP), MSDS level only information hes been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Dela Sheats (MSDS) d KUP SVC- WELLNAME 35-612 WELLBORE 3S-612 COii�COr171II1p5Am1TRArT(iLFRAT1�rrUnPTQr,[ Well Attributes Max Angle Bl TDc^^ Frets Name Wellbore API, miltoreadbi nolc') MD lin 8.1, A[191m INKa) Alaska. IFIL. 5Mn4MTT]M c,rr �G "n 3selz,rzsrz.,sr;1a3+AN last Tag Wrw"aha" pori Annerabon DCRIMMIS Enclave, I WNa. Lvelm eBy XANGEfl: AAjCnndl ..................... LAST TAG: 35-612 Last Rev Reason Annoblwn Ene Ga+e Wellpare tali Moe ey . ..........................................................._.. __............ Rev Reason: FRA el ulletl RB ,an IIna69ellted, Corratled GLV ICON42-DMY et archer or E- 112412019 3Sfi12 pproven strings CONDUCTOR, asnn9D T7Casing Cavin DoelPlron Gv 111 10fnl CONDUCTOR 20 1850 TOP mrcal Set DepM mKB1 aei pepM nVO1... wuLen ll... Greve rop TbeW 39.0 1190 1190 154.00 MrJVFlub-..;.6 A.ar 11n4rzme NIPPLE. 1...a Casing Deecrlpeon OD (in) N(In) SURFACE 10314 995 TOp1+Nl En SN PLAN MKS) SN Dept (1VD1... Wtl"ng...Graee Top Thai 38.6 3,027.0 2,558.2 45.50 LZ H ri1563 Coda; Disce"NT OD(on 106721 INTERMEDIATE ]SIB 6.08 F.;mKal BN ppKrm e, Set ENNUI` IND)... A. B.-Gmd. Top Tana 36.6 13,857.9 5126.] 2970 LBO H563 SURFACE;39.6$On"o- Diving Description ODjvq 110011 LINER 4112 3.96 TOP MULL) per depth inks) Set Degh QVIDQ. WLen(L.Gride T,Trreae 13,693] 19.8544 5.218.3 12.60 L-80 Hytl 563 Liner Details GAS Ui 3.6148 TapmKB) iaplNDI mKB1 Toplrml l'1 Nominei rD Bem Oes Co. lip Anew. FLae-a'; Assee-IORP0 NN'eb118 13,693.7 5,088.1 ]6.08 PACKER Liner o0 adker,55%7. . RUE ZXP, w110' 4820 Seal Bore Excension G45 LIFT; 12m]3 13,]13.] 5,092.8 76.23 17ILERS Nipple, 5-1Q', Hyd563 4.250 CAUGBPUMP SENSOR, WO 3,] 5,093.4 76.25 HANGER Liner Hanger, FL pinned 17M ON 4.800 13,]34.5 5,097.8 76.38 SBE Sea bore 8040 x 20, 5 Hytl 521 Pin up x yd 4.020 PACKER; taSfBr 521 box Gown 14,117.1 5,185.0 7221 WELL ER,SWELLA 112 X 6.00,13AKER.HYD563N awe CNERNAvenay;+3E]5.5 -77 PACKER (002141-001-10)1. NIPPLE; 13,Se.3 14,3525 5,23].8 FRACSLEEVE Baker han,sleeve (2,696' ballAss, K, HYO563 CN 2.655 FPSC725 PN 11809080396 LOCATOR; u.W31 LocAroa; tl.wta 14.6316 5,2773 85.91 SWELLA KER, W L, X ;BA R. 5 N 3.900 PACKER (0021410-001-11)K RULE sane 13.0991 14,8]22 5,280.9 90.89 FRAC -LE EVE aker hadseeve 5"ball)Asay J, N 2.605 FPSC724 PN H809080395 15,1094 5,279.2 89.88 PACKER.SWELL,4 la % 6.00"BAKE17,7I 3900 PACKER (002141-001-6)J 15,388.4 5,80.0 89.66 RA SLEEVE Bake"n"sieve .55"balq Assy I, HVD GN 2555 FPSCJ23 PN 11809080394 INTERMEDIATE; 3a6,a.sso. 15,624.8 5.283.0 89.21 L PACKS LL,41 X6. K ,HVD SN 3,900 PACKER (002141-001-12)l ) 15,8625 5,283.9 90.17 FRAC SLEEVE Baker Oak, sleeve 545' a Assy H,HYD 2,505 FPSC722 PN H80908030 Kyw.am iimkn; 1435]. I 1 16,104.2 5,2828 9.42 W LL PACKERSAIl BAKER,HYD 3900 PACKER (002141{1014)A 16,345.3 5,281.1 90.35 FRACSLEEVE a racsleeve(2.9 Assy G, HYD563 CN 2465 FPSC]21 PN H8090803N n]mrio Fracture; 14,372 o 1 ' 16,618.1 5.2794 90.43 W LLLL, 12 ',BAKER,HYD 3900 PACKER (002141-001-B)G 16,8928 5,277.3 W-45 FRAC SLEEVE Baker had sleeve (2,455- 6 Assy F, HYD 563 CIN 2.425 FPSC720 PN HM80391 nywwkFrxtunl t5,3mo17,133.4 1 1 5.2754 44 TWLL PACKIEK,Si 1QX ",SAKER,H D 3.900 PACKER (002141-001-1)F 1],3]8.9 5.273.8 90.58 FRAC SLEEVE Baker Red sleeve (2 ball) Assy E, HYD 563 CIN 2385 FPSC719 PN H8090B039O on.n. er". 1 1 1],650.8 5,2684 91.31 LL ELLp ",BAKER ,HYD S N 3.900 PACKER (002141-001-14)E 1],853) 5,263.6 9140 FRAC SLEEVEBaker had Peeve2.7"sl ,Assy D HYD 2345 FPSC718 PN H&1908038, nwi,i. FMwe;I .0 t i 18,1274 5,257.3 9129 WELL W LL,411 . •, AKERHY 5 N 3900 PACKER (002141-0013)D Awaar Rae . Ninnax.VAT91 7W a1p. 1$' 18,3892 5.251.1 9139 FRAC SLEEVE 'b Baker sleeve(35all Assy C, HYD 2.305 FPSC717 PN 1-809080388 Npnm Fr..:leear.. I I 18,567.1 5?46.6 91.32 WELL LLp 112 ",BAKER,HYD563 3.900 PACKER (002141401-7)C 18,865.2 5,240.1 914] FRAU SLEEVE Baker Red sleeve-(2295"bal Assy -B-HY-D5-6TCN 2265 FPSC716 PN 11809080387 NO.. F..: flared t t 19,138.7 5.234.0 91.5 LL ACKEH,SWELL,4 V2 6 OOd,I3AKER7Y5`ST3SN 3900 PACKER (002141-0 14)B 19,339.6 5,2294 9136 FRACSLEEVE aeracsleeve(225'allssy A, HYD563CN 2.225 FPSC715 PN MBOOOB03M Iyawo F. .. lTssao 1 1 19,5772 5,2246 124 SWELL PACKER,SWELL,4 V2 X 6-00", AKER,HVD5fi3 3900 PACKER (002141-W1.9)A 19,7518 5,220.) 91. FRACSLEEVE Alpha Pressure Sleeve, rupWreiscx 4(7Opsi 3000 low, 7900 psi high, 7613 nom psi) Ne.,m F-11 'a t 0 19765.3 5,2204 91.25 FRACSLEEVE Weilhore Isolation Valve Ba -I-a11L4',990 0.000 psi sheer Tubing Strings try Pvxxil e.. cores.. I I Tubi.. Description String Me... TUBING 4112 PRODUCTION I06p TopIRRS) 3.96 34.4 Rd Depth IN Is. 13.700.7 5,0 Depth"D)I... ext WL(INfl) 12.fi0 Getle L-80 lap ConnMion Hytl1i1563 Completion Details MYnnWO FracMe; ,9339. 1 1 Top".) ropbct Top MKS) (I (•) Nem Dos Nomllel Com ID lip 34.4 344 VOO HANGER Hanger, 4-10 x 1031P' Gen 5, FMC TC -1A EMS 3920 1,920.6 7829.9 38.33 NIPPLE Nipple, Comm, 3.813" DB Profile. SN: 36543 3813 13,50].0 5,0430 76.10 PUMP auge arrier, LB.SGM wit .ppM1istubing pre..Nigauge, 3.864 HYErwfi[Frxpue; ,..]510 t l SENSOR SN;C15(3M-0403 13,5697 5,058.1 76.08 PA KER Par cke9 Beker 4112'x7518^ Premier SN' 1149519 3.870 13,6333 5,073 4 76.02 NIPPLE Nipple, Camm.3 75' DBE Pro Ie,SN: SN 4053-2 3.750 13,690.1 50822 7605 LO ATOR Mechanics Locator .Y TCII Box( (large GDebve 3950 LINER. 1%. ]-IS.I located) ConocOP11llip5 Aleskai is aY1W6 d sOM�lllps '��1 WELLNAME 3S-612 WELLBORE 3S-612 I 3s61Z Uteri 18MM Completion Details ve,YYZMma&(scull Top I'M TOP] -1 Nominal TRP Nagn doug rl Item a¢ coal m(ml _....................__.........-............._.............................._ IUNGBR'. 34e 13,6911 5.08]4 ]806 LOCATOR ereguanm8l Locator 4 a"TCI]Box (Small OD below located) 3.950 13,6997 5,089.5 ]6.12 jslULl SHGE Baker Fluted WLEG(Wire line entry guide) 3.900 .. ........... ................ Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Ton(WIN Toprna iapIKKBI Me) I fl ODs Com Run We ID (in) i ,6255 5,0]1.5 ]B0 Storer Calder Assembly=41I2'Bait a 0),401 1/19/2019 CON ou P"d-denueo MnJV84E.. w[06 Assembly 1/8"Scem,83J8'Gauge Ring (Belongs to Stirhllse Unit ]60 9012"GAL i aeNIPPLEN4Dm6 NIPPLE; I,PN.6 Frac Summa rY SbM1Oah PmppanlOngM elle) Proppanlln Fwmalbn pal 121172019 207,200.0 19].]55.0 SURFACE', 30.8a,01ll See• Sbrl Dab Tap OepbltlKB) MPIIIKOI ILL (10FluWSyabm Vd Ckan(ong VOIShoo, leg 1 1Z1]2018 19,]51.0 19,]52.0 Gelled Sall Water, W III Borace 3,27200 3,4&5.00 One LET', S. MrvbrPus-Ll slaw; a.816.613.iN0: t1N Vp18 m w61aFT:12.o3 sun Dab 121172018 Wined fib) Prcppant In Paralleled gC) 20],204.0 212,]68.0 Stan SMDak Top Oeplp IKKOI OM(fle0) Llnhb FluM Spkm VOICbnIbM) Vd Slmrylbal 2 121]2018 19,3390 19,3400 Gelled Salt Water, 30 IS Smate 2,006.00 2,23600 Sled Dab proppnt Oe¢ asset.)pmppnt b Formation lett 121712010 20]204.0 201,3]5.0 awLamuMv65xwe. a5m.0 Peemar; 1....7 SIpY Skrl Dale Topen IdNOI BhnIKKBI Ban kr Fluke Syahm Vaiekan (ebg VoiEmor a) 3 12/1]12018 18,6650 LS866.0 BanSab Water. W It, Bonds 2,123.00 2,425.00 Sbrt DakProppaM0"Wasend ienparun Famaboadle 12202018 20],204.0 196,1]0.0 StBP SMrtOat, Top DepbtRKa) IRM (MB)Llnkbl'sMSyabm VOban (bleb VOISbrry lObp 6 12202018 117,3760 117,3770 Gdied Sall Water, 30 Th Borate 2,337.00 2,54900 Gltlw Nnmty; 13,625.5 NIPPLE', ISMS SbrteMe Prcppanlisrana dib) Prappntln Formate lb) 122012018 207,204.0 210,945.0 51pY Slvl Dah TeP s"'MKBl BbnpeKB) Llnkb FlUWSyslam Vel Cbanlbbb Val361UO OMl 4 12202018 1&3890 18,390.0 Gelled Salt Water, 30 to BoWle 2,388.00 2,618.00 LOLPTOR.,'3,eWl LOCATORSM I Sprt Oab 12202018 pro e0 sisedllbl PPppamin Formation lb 20] 040 2141010 1 I MULE SHOE; t3.�] 4111Y Sled Mb Top CagdpMB) BM IIMB) Llnkb Fluty Byakm V.1cle-lb VOI Blurrylbbb 5 1ZMM18 17,853.0 1],854.0 Gelled Sall Water, 30 lb Borate 1035.00 2068.00 Shd OWe 12232018 Proppant OFFgnM elle) Propme, In Fwmabon as 20,204.0 20],8]50 San sWdDM IT. Deal need Ismadeam Llnkk FlUW Byabm Vw twnlebb Vol Slu,rylbbll ] 12232018 16,89]0 16,898.0 Gelled Sal[ Wale, 30111 Borace 2,246.00 2,4)L00 Sprt034Prappne 12232o18 Deaanedtlb) leanantln FormaebnllM 20],204.0 208,148.0 MERMEOPTE36a1a632.9 SbY 8 $bR Dak top Oepl SME) 8"MKB) ILL k b FILM Syabm 122312018 16.3450 16,346.0 Gelled Salt Water, 30111 Borate VOl Clean lea) land slurry bbl) 2,006.00 2,311.00 srmtoateproppm Deagned trot pbppm In Panel add 12232018 20,204.0 211,6470 S" Som Das Top Oepld ME) DIP IKKBI Llnkb Fluitl SyzWe Val Ckar (bleb VOISIYrry(bbb 9 1Z2W2018 15,80.0 15,868.0 Gell ed Salt Wale,, 30 lb BMW 2,332W 2,56100 XTanufc FrsOxe', 14.3510 I Sled Deft s,",., Deagmd(b) proppanlb FngM1l(In) 1027/2018 207,204.0 210,07.0 SWN 811x00 Top Mpl lMBl BM Centel Link s Flan System Va Ckmleb0 Val Slurrynbl) 10 122]2018 15,388.0 15,389,0 Gelled Salt Water, 30 lb Borrow 2,453.00 2,68100 MpIm,J[FracNe', 14.0]20 glee. Psssant Magnedaid Proppantb FomWem(a) 12272018 20104.0 211,3320 SIBY Sbd Dale Top MPl Me) BM(KKB) WhsP.-ing. VOICkan lbbb Vel Slurry IBM) 11 12/2]2018 14,02.0 14,8]3.0 Gelled Salt Water, W IS Borate 2.214.00 2,44200 WHIS. 1 S1lamOar 2sawn De¢'Ped pOl Prapanlb Fa,mlon lbXndF.., 21282018 0],204.0 2111040 SIpP Sbrl Vale Top pepiF lnKB) Btm (tIKB) Llnks FluMSy¢sm Val Clean lbbb vol Stunw(bbll 12 122812018 14,357.0 14,358.0 Gelled Salt W.W130lb Boase 2,0000 2,8M OO Mandrel Inserts XYWaWb F.M. leare.0 I ' St eH N T"and, TOPMD) nalMake Valve Lakd all 00 (in) 9ery rypa TyIk ends" TRORun and arMa PanelLam 3,644.8 2,795 11 Coleco KBMG 1 GAB LIFT GLV BK 0.188 1,900.0 1/192019 HYesen FncWrc 163eEo r k 2 12,0803 d,]04.8 Camco KBMG 1 GAS LIFT DMY M 0000 00 11/2412018 BK Arras Fn.e-NaCl Brine Notes: General B Safety 1JTOJ 615.x.6, IV112N6\ Kpnuk Fvb.e', Wer, C I I End Dale Annablbn 1Z1y2018 NGT E: View SCM1ematic w/Alaska SCM1ematic100 XydmYO Freabn; 1),3260 I f Nsken. Fracwn; 1]681.0 ' HYM,s,' Fn[bn: uslog 0 f t Hytlnu4c Fncon; 16A% 0 1 f MydnWk FracWre; 193%0 ' ' .ex.. I., t 8,]510 f f LINER, I9Ces".te4.4� HALLIBURTON Sales Order# 905321854 Conoco Phillips Alaska, Inc. Kuparuk River 3S-612 Intervals 0-12 Lower Moraine Moraine Formation Harrison Bay County, AK API: 50-103-20777 Preparedfor: Hanna Sylte December 30, 2018 Stimulation Treatment Post Job Report Treatments 1-12 30# Hybor-G Prepared By: Landon Harrison Daniel Salazar Nanook Crew Notice: Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk. HALLISURTON Table of Contents Section Page(s) Executive Summary 3 Wellbore Information 4 Fluid System-Proppant Summary 5 Interval Details 6 Actual Design ]-9 Interval Summary 10 -22 DFIT Plots 23-24 Interval 1 Plots 25 - 35 Interval Plots 36-39 Interval Plots 40-43 Interval Plots 44-49 Interval 5 Plots 50-53 Interval 6 Plots 54-57 Interval 7 Plots 58-63 Interval a Plots 64-67 Interval Plots 68-71 Interval 10 Plots 72-77 Interval 11 Plots 78-81 Interval 12 Plots 82 -92 Appendix 93 Chemical Summary 94 Planned Design 95-97 Water Straps - DFIT-Zone 3 98 Water Straps -Zones 4-6 99 Water Scraps -tones J-9 100 Water Straps -Zones 10.12 101 Water Analysis - DFrf-Zone 3 102 Water Analysis -Zones 4-6 103 Water Analysis -Zones 7-9 104 Water Analysis - Zones 10-12 105 Real -Time QC -Zones 1-3 106 Real -Time qC-Zones 4-6 107 Real -Time QC -Zones 7-9 108 Real -Time qC-tones 10.12 109 Bacteria Testing - DFrr-Zone 3 110 Bacteria Testing -Zones 4-6 111 Bacteria Testing -Zones 7-9 112 Bacteria Terting Zones 30-12 113 Event List- Minifrac-Zone 3 114-115 Event Dst - Zones 46 116-117 Event List - Zones 7-9 118 Event list- Zones 10-12 119 Fann 15 Min - Minifrac 120 Fann 15 Min - Zone 1 121 Fann 15 Min - Zane 2 122 Fann 15 Min - Zone 3 173 Fann 15 Min - Zone 4 124 Fann 35 Min - Zone 5 125 Fann 15 Min - Zone 6 126 Fann 15 min -Zone 7 127 Fann 15 Min -Zone 8 128 Fann 15 Min -Zone 9 129 Fann 15 Min -Zone 10 130 Fann 15 Min - Zone 11 131 Fann 15 Min - Zane 12 132 Lab Testing 133-140 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-612 TOC Engineering Executive Summary On December 16, 2018 a stimulation treatment was performed in the Moraine formation on the Kuparuk River 3S-612 well in Harrison Bay County, AK. The Kuparuk River 3S-612 was a 13 stage Vertical Sleeve Design. The proposed treatment consisted of: 4,200 gallons of Sea Water 0 gallons of Treated Water 55,109 gallons of 30# WaterFrac-G 1,177,622 gallons of 30# Hybor-G 7,300 gallons of Freeze Protect 86,400 pounds of Premium - 100m 2,400,044 pounds of Wanli - 20/40 The actual treatment fully completed 13 of 13 stages. 0 stages were skipped, and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 4,223 gallons of Sea Water 0 gallons of Treated Water 64,641 gallons of 30# WaterFrac-G 1,104,122 gallons of 30# Hybor-G 10,395 gallons of Freeze Protect 87,814 pounds of Premium - 100m 2,406,983 pounds of Wanli - 20/40 A more detailed description of the actual treatment can be found in the attached reports. The following comments were provided to summarize events and changes to the proposed treatment: After performing the Mini -frac the customer requested that Pad Volume be reduced before going to the 100M sand stage. The initial stage (DFM was performed on the 16th of December. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid MO -67 set points were adjusted during the stages to maintain a constant pH per the request of the customer. Ran into issues with frozen sand and frozen castle gates in our 100 mesh and 20/40 Wanli stages. While priming up MO -67 on LA3 of the FB4k, operator left pump running causing 294 gallons of MO -67 to be sent downhole to start stage during initial displacement of treatment 4. This value is shown in the prime -up value so that is differentiated from what was send downhole during the primary portion of treatment 4. Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have. Halliburton again thanks you for the opportunity to perform service work on this well. We hope to be your solutions provider for future projects. Thank you, Landon Harrison Technical Professional Halliburton Energy Services Conoco Phillips Alaska,Inc. - Kuparuk River 35-612 Executive Summary Keegan Lambe Technical Professional Halliburton Energy Services n .im oolw•r ICMI Vnlq n ,Yaxn x xunrm 1.1 um+Klnp ur� wn� IWnV Ml,u� LeMl Conoco Phillips Alaska, Inc. - Kuparuk River 33-613 Wellbore Information �111 MMI W, IINH un In Conoco Phillips Alaska, Inc. - Kuparuk River 33-613 Wellbore Information Customer Conoco Fbillips Alaska, Inc. Fomn0on Lower Moraine Lea. Kuparuk River 31612 AN Sa-103-20]2) Date Oecember 16, 2018 Well Summery HALLISURTON Planned Recorded Fluids I PrepP+MF Interval Sea Water 308Wsbu Fmc-G 30p Hybor-G Freeze Protect Total Fluid Premium -100m Want[ -2o/4o Twompropp+0t Want! 20/40 gal bbl gal bbl gal bbl gal bbl gal bbl lbs lbs lbs p 4,2]3 101 92,900 2,400,044 1 2,492,944 4,223 101 1,266 30 5,489 131 1,183,381 28,176 1 07,014 2,406,983 1 12,702 302 124,744 2,970 87,814 2,406,983 137,446 3,273 6,750 191,005 197,755 2 84,236 2,006 84,236 3.006 6,946 205,822 214768 3 12,159 290 79,085 1,8&1 1,461 35 92,705 2,207 8,294 393,081 201,375 4 100,307 2,383 100,307 2,388 7,245 203fi00 210,845 5 77,082 1,835 A,682 1,035 7,271 207,830 215,101 6 11,424 272 85,449 2,035 1,261 30 98,134 2337 7,287 188,883 196,170 7 94,331 2,246 94,331 2,246 7,265 206,610 207,875 8 87,591 2,086 8,7,591 2,086 7,236 200,912 208,148 9 10,%6 261 85;30 2,031 1,60 40 97,933 2,332 7,269 204,378 211,647 10 103,019 2,453 103,019 3653 7,227 203,450 210,677 11 92,M 2,214 92,900 2,214 7,212 204,120 211,332 12 17,390 414 89,991 2,143 4,747 113 112,128 2,670 7,812 203,292 211,104 Minimum 4223 101 10966 261 77082 1835 1261 30 5489 131 6] 50 188883 196170 Avetage 4233 101U. 3. 92010 2191 209 49 91039 2167 ]310 200582 207900 Maximum 4223 103 1]390 434 124]44 29]0 414] 113 137446 3213 8290 20830 215101 Planned Recorded welables 11 Proppant Is billed from Weight Ticket volumes COnpc. Phillips Alaska, Inc. - Ku, uk Riuec 35-612 Fluid System-Proppant Summary Fluids Prpppae. Sea Wales 37WaterFraE± 1 30d Hybm- Freeze Protect Tmal Fluid Premium -100m Want! 20/40 Tcdm Pmppint gal bbl 8+I bbl gal bbl gal bbl gal bbl lbs lbs Total 4,200 100 55,109 1,313 1,1A,622 28,039 ,7,300 3]4 1,244,231 29,625 1 92,900 2,400,044 1 2,492,944 4,223 101 64,643 1 1,539 1 1,104,122 26,289 10,395 247 1,183,381 28,176 1 07,014 2,406,983 1 2,494,797 Welght TldeK 87,814 2,406,983 1 2,494,797 welables 11 Proppant Is billed from Weight Ticket volumes COnpc. Phillips Alaska, Inc. - Ku, uk Riuec 35-612 Fluid System-Proppant Summary HAUIRURTON Conoco Phillips Alaska, Inc - Kuparuk River 3S 612 Interval Details in, Re Conoco Phillips Alaska, Inc - Kuparuk River 3S 612 Interval Details Conoco Phill,, Alaska, Inc.-K.,a kRiver 35-613 Acnal Oezil m��� mm�� m0�� m®�m,m m•mtmm� mmm®� m ®�®®m•�� mmtmmm mmmm� m���mm m•�®mm®m•mmtmmtm ®®mmm mmm��mm�®m•m•�®mmt�mmmmmm� m��� m®�®00m•®m®�mtm m®m•mt�'. m���m®m®�0�m•mmtmmmmmmm� ®���m®�®�m•�m•mmtm•mtmmmm®� „ mmr���m®�®�m•�m•®mt�mtmm®m®� m��m� m®mmt©0�� ®mtomtm m®mmt�. m�®� m®®®®®��mmtmmtm®®m•m•�� mm���a�m��®�®m.m•®mtm mm®m.m. - m���m®�®�0�m•Omlmmtmm®®®� m�� m®mtmtm�®gym• ®mtmmtmm®®m•� - ®���m®0mtm•0�m•�mtmmtm®®m•®� m��m�mmt®m•�m•�mmmtmmmtmmr� m��m®��om•m®mmtmmtmmmtm•mt� m���m®��m•®�m•mmtmmlmmmtm•®� 0ccma� m®�®®®m•mmtmmtmmmtm.m.� . mm��m� m��� m� m®m•m•ma0mmtmmtmm®mmm.. m���m®��om•m,m•mmtm•mtmm®mm�j - m���m�m�mm•�®mmtmmtmm®mm�� m��� m®mlmtm•®mm•mmtm®mmmm®� m���m�m�®®�m•mmtmmtmmmtmm� ' m���mmmt®m•®m•m•mmtm®mm®mmml m���m��m0m•m•�mmtmmtmm�mm•ml :: m��m�m®�®m•®�m•0mtmmtm®mlmmml m�m_�m®mmm®m•m•��mmtm•mtmm®m.®�, m ���mm ��®m•®®mmtm®mm®®®� ®®.ac��m®pmt®am.m• �®mmtm m®m®� - mm���mm��0m�m•�mtmmtmmmtm.m,� m �� m m ��m•m•�� mmtmmtmmmlmm� m��� m m m� m•®mmm mmtmmtmmmmm� m�� m m pmt m•am.m. mtmtm.®mmmlmm,� ®�� m m ��m•m•�m• m®m®mm®mm. ®mm�m�m®mm,m•m•��®®®mtmm®®mmm m���om �®®m•��mmtmmtmm®mmm. m���m� pmt m.m•m.®mmtmmtmmmmm� m���m®pmt®®m.m•m�m.mmm®m®� mmm��m®mmt m•m•m.m•mmtmmtmm®mmm m ®�m� m���m�mmtm•®�m•mmtmmtmm®mm�'. m���m ®mm, �m•m.m•mmtmmtmmmmm�i m���m ®�� �®m.m•mmtmmmm®mm.�l m���mmm®®m•�m•mtmtmmtmmmmm�l m��m� � � m®om•�� mtmtmmm mmmm� Conoco Phill,, Alaska, Inc.-K.,a kRiver 35-613 Acnal Oezil Conoco Phillips Alaska, Inc.-Kuperuk River 3S-612 Actual Design a Dkn . ".,7 I rewbvm sM r,Po W., mroV e m no , bl 1poew o1 1.11 ronu M,r opox Avn oroxe ii .44n•1 wxw 4 045 1 11 mexwo,a .am�:vna gpm voxw�,< coon aaoo wox lv c.ol 11/.o nv lel 21% w� eAe yexww4 A�mNo .1A1 AN3 m &i2 ow in Shut in 3w. u r4 w mrt •& wxema m}o/m 'g Fm un NWer4 -m/m LLmi max,iww -.vm '_ �a 3wxwo,4 mr.o 1112 -5 4 �r. wermo,4 w.o 3o..xwo,4 -m/.o w xwn,a ]R) m+.mo< 11 H99 r mro aemInv �vv .xw�,z no go, _ oxwo,.e .meo o. -m/.o �� xx Nn {{ exwera -xo/.ro ep]d 3� exµorc Y-m/.o 2..axwo4 mim 11 HPor¢ w xpe r. nplGMywe H r< 2-0 wxwo.4uo .9 xw11414 a,4 sono 111 Hi "Rm" roan 2 _ or xw..4 -xvNoo mw 5 wwac 3 ve�l $ rm ff m1.ollo 1. PY a.xxe.a m/m LE m/m pm.1v eexa,4 Hme m/wxm4 muo .un><.xps4 Conoco Phillips Alaska, Inc.-Kuperuk River 3S-612 Actual Design a ....... �.w:. .,... , .wmah Sw,uumo-, C h.. Phil I!, Alaska, Inc - Kupamk RIPP, 35612 A,tuai De91p —AOI. moor m.mr ren r.°n I'm ..II nY r ., r�5.r r.m rwo ro n rmp ..o rwoa nmr gmra.11 non .1PO I r wr i eu.. PIP mIuio 001 mx�d _T4 .w.x�m,i 1. H3F.� mvxpartl �OIm.A4 o. R���•anpe a :�nu e , iw,o y YwxAwd wsapmtuMn Hae 400 1. 1..Spm ®OAPP,.rtmyntYhneWlePA. .Nv 3mMped yema Yl6p Ol POP 00 w xpmc wxp d mnexmmn5 vem m� 45w 43V w�^0.ywxpwc wxpwd PAO,", 011 la/Svm 40V 4W1 L [F� SwxyuG 1-0 ueen{luiA A. u.OY j m APA POO Fwpa r.1d mNo 11 -mA. A. n MAerd ww��lsk�xwe wpm OA1 A. POP 2 ® lW'xkoId W/w w.m1 Mug10-0 SvvM,6orc N/w a}5z ml p WOA� 'It'. C h.. Phil I!, Alaska, Inc - Kupamk RIPP, 35612 A,tuai De91p Kuparuk River 3S-612 -Lower Moraine - DFIT Interval Summary Start Dalerrime: 12/16/18 12:18 End Daterrime: 12/16/18 13:27 Pump Time: 69 min Initial Rate (Breakdown): NA bpm Initial Surface Pressure (Breakdown): NA psi Initial BH Pressure (Breakdown): NA psi Max Rate: 8.47 bpm Max Surface Pressure: 7173 psi Max BH Pressure: 1662 psi Average Rate: 8.0 bpm Average Missile Pressure: 1616 psi Average Surface Pressure: 1564 psi Average BH Pressure: 3356 psi Average Missile HHP: 317 hhp Average Surface HHP: 307 hhp Initial Braden Pressure. 550 psi Max Braden Pressure: 638 psi Max Prop Con: 0 poll Average Vied: NA CP Average Temp: NA F Average pH: NA BH ISDP: 3146 psi Final Fracture Gradient: 0.596 psyft Proppant Summary Premium- 100m Pumped: 0 lbs Wanli - 20/40 Pumped: 0 lbs Total Proppant Pumped' : 0 lbs Proppant in Formation: 0 lbs Fluid Summary (by fluid description) Sea Water Volume: 4,223 gal 101 bills Treated Water Volume: 0 gal 0 bbis 30# WaterFrai Volume: 0 gal 0 bbis 3D# Hybor-G Volume: 0 gel 0 bbis Freeze Protect Volume: 1,266 gal 30 bbis Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbis Pad Vokime: 0 gal 0 bbis Conditioning Pad Volume: 0 gal 0 bola Proppant Laden Fluid Volume: 0 gal 0 bbis Displacement Volume: 0 gal 0 bbis Flush Volume: 0 gal 0 bbls Mini-Frac Volume: 4,223 gal 101 bills Spacer & Ball Drop Volume: 0 gal 0 bbls Freeze Protect Volume: 1,266 gal 30 bbis Treatment Slurry Volume (Calculated): 5,489 gal 131 bills Total Clean Fluid Volume: 5,489 gal 131 bbis Interval Status: Completed Comments: To shear the alpha sleeve the wellbore was pressurized with LVr in the event that the pins did not Engineer. Keegan Lambe sheer. Used 46bI of LV7 to shear Me pin at 5460psi. No initial breakdown Was observed. Tearer Daniel Salazar SupervisorDaniel Salazar -Values for proppanl are taken from software calculations based on multiple ventures. Customer Eng: Sandeep Pedant Proppant is billed off of weight ticket whines and may vary slightly from this number. Customer Rep' Paul Besset e Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval Summary 10 Kuparuk River 3S-612 -Lower Moraine - Interval 1 Interval Summary Start Date/Time: 12/17/18 14:28 End Dale/Time: 12/17/18 16:26 Pump Time: 118 min Initial Rate (Breakdown): 37.0 bpm Initial Surface Pressure (Breakdovm): 6937 psi Initial BH Pressure (Breakdown): 6182 psi Max Rate: 40.9 bpm Max Surface Pressure: 5276 psi Max BH Pressure: 5612 psi Average Rate: 40.3 bpm Average Missile Pressure: 4100 psi Average Surface Pressure: 4080 psi Average BH Pressure: 4869 psi Average Missile HHP: 4050 hhp Average Surface HHP: 4030 hhp Initial Braden Pressure: 470 psi Max Braden Pressure: 632 psi Max Prop Con: 5.17 1 Average Visc: 25 CP Average Temp: 76.6 F Average pH: 9.59 Proppant Summary Premium- 100m Pumped: 6,760 lbs Wanli - 20/40 Pumped: 191,005 It's Total Proppant Pumped' : 197,755 lbs Proppant in Formation: 197,755 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 Oils Treated Water Volume: 0 gal 0 bbls 30# WalerFraxi Volume: 12,702 gal 302 bbls 300 Hybor-G Volume: 124,744 gal 2,970 MIS Freeze Protect Volume: 0 gal 0 MIS Fluid Summary (by stage description) Breakdown Volume: 3,498 gal 83 MIS Pad Volume: 0 gal 0 Oils Conditioning Pad Volume: 28,818 gal 686 bbls Proppant Laden Fluid Volume: 69,173 gal 1,647 Oils Displacement Volume: 0 gal 0 bbls Flush Volume: 12,702 gal 302 bbls Mini -Frac Volume: 21,225 gal 505 bolts Spacer & Ball Drop Volume: 2,030 gal 48 bbls Freeze Protect Volume: 0 gal 0 Oils Interval Status: Completed Comments: Performed a mini -frac at the begning of this stage. After shutting down for pressure analysis, the Engineer. Keegan Lambe initail pad was cut from design. Treater. Daniel Salazar Supervisor Daniel Salazar Values for proppant are taken from software calculations Weed on multiple variables. Customer Eng: Sandeep Petlam Proppant is billed off of weight ticket vclumea and may vary slightly from this number. Customer Rep: Paul Bassette Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 11 Kuparuk River 35-612 - Lower Moraine - Interval 2 Interval Summary Start Dalerrime: 121171181626 End Daleriime: 12/17/1817:23 Pump Time: 57 min Initial Rate (Breakdown): 11.2 bpm Initial Surface Pressure (Breakdown): 5194 psi Initial BH Pressure (Breakdown): 6121 psi Max Rate: 40.51 bpm Max Surface Pressure: 6393 psi Max BH Pressure: 6127 psi Average Rate: 40.2 bpm Average Missile Pressure: 4765 psi Average Surface Pressure: 4462 psi Average BH Pressure: 4955 psi Average Missile HHP: 4695 hhp Average Surface HHP: 4396 hhp Initial Braden Pressure: 618 psi Max Braden Pressure: 633 psi Max Prop Con: 6.92 ppg Average Visc: 26.1 cP Average Temp: 79 F Average pH: 9.33 Proppant Summary Premium - 100m Pumped: 6,946 lbs Wanli - 20/40 Pumped: 205,822 lbs Total Proppant Pumped' : 212,768 lbs Proppant in Formation: 212,768 Ica Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbds Treated Water Volume: 0 gal 0 bills 30M WaterFrac-C Volume: 0 gal 0 bbls 30M Hybor-D Volume: 84,236 gal 2,006 bbls Freeze Protect Volume: 0 gal 0 bids Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bills Pad Volume: 4,687 gal 112 bbls Conditioning Pad Volume: 25,601 gal 610 bbds Proppam Laden Fluid Volume: 51,794 gal 1,233 bids Displacement Volume: 0 gal 0 bbls Flush Volume: 0 gal 0 bills Mini -Frac Volume: 0 gal 0 bills Spacer & Ball Drop Volume: 2,154 gal 51 bills Freeze Protect Volume: 0 gal 0 bbls Interval Status: Completed Comments: Pad "a reduced per customer request. Adjusted MO.67 Set points to maintain a constant pH. HES Engineer Keegan Lambe Treater Daniel Salezer Supervisor Daniel Salazar -Values for proppant are taken ham software calculations based on multiple vanabks. Cuslomer Eng: SaMBep Pedam Proppam is billed off of weight ticket volumes and may vary slightly them this number. Cuslomer Rep: Paul Besbetle Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval Summary 12 Kuparuk River 3S-612 - Lower Moraine - Interval 3 Interval Summary Start Dalerrime: 12/17/1817:23 End Date/Time: 12/17/18 18:16 Pump Time: 57 min Initial Rate (Breakdovm): 11.4 bpm Initial Surface Pressure (Breakdown): 5328 psi Initial BH Pressure (Breakdown): 6293 Psi Max Rate: 40.56 bpm Max Surface Pressure: 6141 psi Max BH Pressure: 6358 psi Average Rate: 40 bpm Average Missile Pressure: 4340 psi Average Surface Pressure: 4263 psi Average BH Pressure: 4794 psi Average Missile HHP: 4276 hhp Average Surface HHP: 4200 hhp Initial Braden Pressure: 624 psi Max Braden Pressure: 632 psi Max Prop Con 7.30 ppg Average Visc: 25 CP Average Temp: 76 F Average pH: 9.4 BH ISDP: 3364 psi Final Fracture Gradient: 0.638 psya Proppant Summary Premium - 100m Pumped: 8,294 lbs Wanli - 20/40 Pumped: 193,081 lbs Total Proppant Pumped' : 201,375 lbs Proppant in Formation: 201,375 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 MIS 30# WaterFrac-G Volume: 12,159 gal 290 bolts 30# Hybor-G Volume: 79,085 gal 1,883 bbls Freeze Protect Volume: 1,461 gal 35 bills Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bills Pad Volume: 1,765 gal 42 bills Conditioning Pad Volume: 27,423 gal 653 blue Proppant Laden Fluid Volume: 49,897 gal 1,188 bola Displacement Volume: 0 gal 0 bills Flush Volume: 12,159 gal 290 bbls Mini -Frac Volume: 0 gal 0 bbls Spacer & Ball Drop Volume: 0 gal 0 bbls Freeze Prated Volume: 1,461 gal 35 bbis Interval Status: Completed Comments: Cut pad short per customer request. No breaker run in Flush per customer request HESEngmeer Keegan Lambe Treater. Daniel Salazar Superelsor: Daniel Salazar 'Values for proppanl are taken from software calculations based on multiple variables. Customer Eng: Sandeep Pedam Proppant is bulled alt of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessette Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 13 Kuparuk River 3S-612 - Lower Moraine - Interval 4 Interval Summary Start Dalerrime: 1 212011 8 12:44 End Daterrime: 12120/181410 Pump Time: 86 min Initial Rate (Breakdown): 26.8 bpm Initial Surface Pressure (Breakdown): 4638 psi Initial BH Pressure(Breakdown): 3800 psi Max Rate: 39.90 bpm Max Surface Pressure: 5908 psi Max BH Pressure: 5493 psi Average Rate: 39.80 bpm Average Missile Pressure: 3913 psi Average Surface Pressure: 3828 psi Average BH Pressure: 5295 psi Average Missile HHP: 3817 bhp Average Surface HHP: 3734 hhp Initial Braden Pressure: 449 psi Max Braden Pressure: 641 psi Max Prop Con: 7.03 PP9 Average Visc: 27 CP Average Temp: 86 F Average pH: 9.7 Proppant Summary Premium - 100m Pumped: 7,245 lbs Wanli - 20140 Pumped: 203,600 lbs Total Proppant Pumped* : 210,845 lbs Proppant in Formation: 210,845 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 MIS Treated Water Volume: 0 gal 0 bbis 301 WaterFreo-G Volume: 0 gal 0 bbis 30# Hybor-G Volume: 100,307 gal 2,388 bbis Freeze Protect Volume: 0 gal 0 bible Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbis Pad Volume: 13,423 gal 320 bbis Conditioning Pad Volume: 29,036 gal 691 bbis Proppant Laden Fluid Volume: 52,700 gal 1,255 bbis Displacement Volume: 0 gal 0 bbis Flush Volume: 0 gal 0 bbis Mini -Frac Volume: 0 gal 0 bb/s Spacer & Ball Drop Volume: 5,148 gal 123 bbis Freeze Protect Volume: 0 gal 0 bbis Treatment Slurry Volume (Calculated): 109,881 gal 2,616 bible Total Clean Fluid Volume: 100,307 gal 2,388 bbis Interval Status: Completed Comments: Came offline shortly after starting to evaluate small minor leak on a sound valve, issue was Engineer Landon Harrison resolved by greasing the unit. During displacement blender operator realized ACE could not see TreaterDaniel Salazar the tachometer reading out OptiFlo-Ili, came offline to reboot Had issues with preloads kitting Supervisor Daniel Salazar e units waned up, this resulted in noticeable drops in fluid rate. Our out our HHP as mn M0,67 concentration was mugh during the early pan of the stage, but pH was corning in consistently, so we continued zone with customers approval. All proppant placed per design. Values for pmppant are taken from software calculations based on multiple variables. Customer Erg: Adam Klein Proppant is billed off of weight ticket volumes and may vary slightly from this number. Culdhaier Rap: Paul Beasette Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval Summary 14 Kuparuk River 3S-612 - Lower Moraine - Interval 5 Interval Summary Stan Date/rime: 12/20/18 14:10 End Date7Tirt 12/2011815:08 Pump Time: 58 min Initial Rate (Breakdown): 13.60 bpm Initial Surface Pressure (Breakdourni 5246 psi Initial BH Pressure (Breakdown): 6080 psi Max Rate: 40 bpm Max Surface Pressure: 5254 psi Max BH Pressure: 6065 Psi Average Rate: 39.6 bpm Average Missile Pressure: 3847 psi Average Surface Pressure: 3813 psi Average BH Pressure: 4481 psi Average Missile HHP: 3734 hhp Average Surface HHP: 3701 blip Initial Braden Pressure: 635 psi Max Braden Pressure: 662 psi Max Prop Con: 6.92 ppg Average Visa 27 CP Average Temp: 86 F Average PH: 9.7 Proppant Summary Premium- 100m Pumped: 7,271 lbs Wall - 20140 Pumped: 207,830 lbs Total Proppam Pumped' : 215,101 lbs Proppam in Formation: 215,101 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 bbls 30# Waterferl Volume: 0 gal 0 bbls 30# Hybol Volume: 77,082 gal 1,835 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbls Pad Volume: 2,379 gal 57 bbls Conditioning Pad Volume: 29,011 gal 691 table Proppam Laden Fluid Volume: 44,071 gal 1,049 bible Displacement Volume: 0 gal 0 Wits Flush Volume: 0 gal 0 table Mini -Frac Volume: 0 gal 0 bbls Spacer 8 Ball Drop Volume: 1,621 gal 39 bb/s Freeze Protect Volume: 0 gal 0 bible Treatment Slurry Volume (Calculated): 86,849 gal 2,068 bible Total Clean Fluid Volume: 77,082 gal 1,835 bola Interval Status: Completed Comments: Cut pad shaft par customer engineer's request. All pmppant placed per design. Engineer: Landon Harr son Treater. Daniel Salazar Supervisor Daniel Salazar -values for proppantamtaken from software calculations based on multiple variables Completions Engineer Adam Klein Proppant is thre t off of weight ticket volumes and may vary slightly from this number. Customer RepPaul Bessette Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 1 s Kuparuk River 3S-612 - Lower Moraine - Interval 6 Interval Summary Stan Date/Time: 12/20/18 15:08 End Daterime: 12/20/18 16:07 Pump Time: 59 min Initial Rate (Breakdown): 16.0 bpm InRial Surface Pressure (Breakdown): 6430 psi Initial BH Pressure (Breakdown): 5893.0 psi Max Rate: 39.9 bpm Max Surface Pressure: 5851 psi Max SH Pressure: 5041.0 psi Average Rate: 39.4 bpm Average Missile Pressure: 4278 psi Average Surface Pressure: 4231 psi Average SH Pressure: 4494 psi Average Missile HHP: 4131 hi Average Surface HHP: 4086 hhp Initial Braden Pressure: 651 psi Max Braden Pressure: 634 psi Max Prop Con: 7.24 poll Average Visc: 29 cP Average Temp: 81 F Average pH: 9.5 BH ISDP: 3342 psi Final Fracture Gradient: 0.633 psi/ft Proppant Summary Premium - 100m Pumped: 7,287 lbs Wanli - 20140 Pumped: 188,883 lbs Total Proppant Pumped' : 196,170 his Proppant in Formation: 196,170 los Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis Treated Water Volume: 0 gal 0 bbds 30# WaterFrac,G Volume: 11,424 gal 272 bbis 30# Hybor-G Volume: 85,449 gal 2,035 bbis Freeze Protect Volume: 1,261 gal 30 bbis Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbis Pad Volume: 3,926 gal 93 bbis Conditioning Pad Volume: 29,891 gal 712 bills Proppant Laden Fluid Volume: 51,632 gal 1,229 bills Displacement Volume: 0 gal 0 bbis Flush Volume: 11,424 gal 272 bbis Mini -Frac Volume: 0 gal 0 bola Spacer R Ball Drop Volume: 0 gal 0 bills Freeze Protect Volume: 1,261 gal 30 bbis Treatment Shirty Volume (Calculated): 107,042 gal 2,549 bb6 Total Clean Fluid Volume: 98,134 gal 2,337 bids Interval Status: Completed Comments: Culpads onpercuswmerengineer'srequest Total Warth 20/40 was determined by taking total Engines, Landon Harrison ticketed proppant delivered for today and subtracting the two previous zones. All proppand placed Theater: Daniel Salazar per design. Supervisor: Daniel Salazar Nalues for proppanl are taken ham sonwere calculations based on multiple variables. COmpletions Engineer Adam Klein Proppant is biNed ori of weight ticket volumes and may vary slightly from this number. Customer Rep: Ped Bessefte Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 16 Kuparuk River 35-612 -Lower Moraine - Interval 7 Interval Summary Start Daterrime: 12/23118 10:57 End Daterlime: 12/2W1812 11 Pump Time: 74 min Initial Rate (Breakdown): 12.7 bpm Initial Surface Pressure (Breakdown): 4922 psi Initial SH Pressure (Breakdown): 5981 psi Max Rate: 41.2 bpm Max Surface Pressure: 5801 psi Max SH Pressure: 5982.0 psi Average Rate: 39.5 bpm Average Missile Pressure: 3717 psi Average Surface Pressure: 3705 psi Average BH Pressure: 4180 psi Average Missile HHP: 3599 hhp Average Surface HHP: 3587 hhp Initial Braden Pressure: 408 psi Max Braden Pressure: 561 psi Max Prop Con: 6.98 AN Average Visc: 27 CP Average Temp: 75 F Average pH: 9.4 Proppant Summary Premium - 100m Pumped: 7,265 lbs Wanli - 20/40 Pumped: 200,610 lbs Total Proppant Pumped' : 207,875 lbs Proppant in Formation: 207,875 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bhls Treated Water Volume: 0 gal 0 little 30p WalerFrac-G Volume: 0 gal 0 bbis 30B Hybor-G Volume: 94,331 gal 2,246 bills Freeze Protect Volume: 0 gal 0 bola Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 little Pad Volume: 2,317 gal 55 bbis Conditioning Pad Volume: 33,336 gal 794 bbis Proppant Laden Fluid Volume: 52,957 gal 1,261 bbis Displacement Volume: 0 gal 0 cols Flush Volume : 0 gal 0 bbis Mini -Frac Volume: 0 gal 0 bbis Spacer 8 Ball Drop Volume: 5,721 gal 136 bills Freaze Protect Volume: 0 gal 0 bills Treatment Slurry Volume (Calculated): 103,770 gal 2,471 facts Total Clean Fluid Volume: 94,331 gal 2,246 bbis Interval Status: Completed Comments: Had issues with HHP kickout out due to preload pressures as well as debris getting caught in Engineer: Landon Harrison pumps, resulting in drop in rale. During 0.25 ppg 100m stage, lost proppant concentration due to Treater, Daniel Salazar sand operator dosing 100m bin early to prevent over pumping 100m for stage, but the gale Supervisor Daniel Salazar temporarily froze shut Operator was able to free the No Nen we regained proppant concentrin.m. Customer engineer requested we pump the stage long on volume to pump designed proppant total for 100m for stage. Staged forward into 5 ppg stage but didn't increase screw setpoint due to communication error, once it was caught staged into 5 ppg and then gaged through 6 ppg and early to ensure we got a sufficient 7 ppg stage per customer engineer request. Treatment advanced to treatment 1 instead of treatment 8 at end of stage, also treatment went to stage 0, resulting in temporary loss of BH calculations. W.Iues for proppant are taken from software calcWmols based on multiple variables. Completions Engineer Hanna Sylle Proppant Is t iral oft of weight tkket volumes and may vary slightly from this number. Customer Rep: Paul Sessions Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval Summary 17 Kuparuk River 3S-612 - Lower Moraine - Interval 8 Interval Summary Start Date/Time: 12/23/1812:11 End Dale/Time: 12/23/1813:11 Pump Time: 60 min Initial Rate (Breakdown): 39.1 bpm Initial Surface Pressure (Breakdown): 5520 psi Initial BH Pressure (Breakdovm): 5748.0 psi Max Rale: 41.3 bpm Max Surface Pressure: 5520 psi Max BH Pressure: 5748.0 psi Average Rate: 39.1 bpm Average Missile Pressure: 4029 psi Average Surface Pressure: 3895 psi Average BH Pressure: 4098 psi Average Missile HHP: 3861 hi Average Surface HHP: 3733 hhp Initial Braden Pressure: 561 psi Max Braden Pressure: 588 psi Max Prop Con: 7.01 ppg Average Visc: 30 CP Average Temp: 76 F Average pH: 9.3 Proppant Summary Premium- 100m Pumped: 7,236 lbs Want - 20/40 Pumped: 200,912 Its Total Proppant Pumpetl• : 208,148 lbs Proppant in Formation: 208,148 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bats Treated Water Volume: 0 gal 0 bbis 30# WaterFrac-G Volume: 0 gal 0 bbis 30# Hybor-G Volume: 87,591 gal 2,086 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage descnption) Breakdown Volume: 0 gal 0 bids Pad Volume: 5,015 gal 119 bbis Conditioning Pad Volume: 29,231 gal 696 bbis Proppant Laden Fluid Volume: 50,897 gal 1,212 bbis Displacement Volume: 0 gal 0 bbis Flush Volume: 11,022 gal 262 MIS Mini -Frac Volume: 0 gat 0 bbis Spacer 8 Ball Drop Volume: 2,448 gal 58 bbis Freeze Protect Volume: 0 gal 0 bids Treatment Slurry Volume (Calculated): 97,042 gal 2,311 MIS Total Clean Fluid Volume: 87,591 gal 2,086 bbis Interval Status: Completed Comments: Had issues with HHP kidcout out due to preload pressures as well as colors gaining caught in Engineer. Landon Harrison pumps, resulting in drop in rate, Lost hopper going into 7 ppg stage due to castle swap. All Treader Daniel Salazar proppant placed per design. Supervisor. Daniel Salazar 'Values for proppant are taken from software calculations based an multiple variables. ComPletrons Engineer Hanna Sylte Proppant is billed off ofweighl ticket volumes and may very slightly from this number, Cuscame-Rep: Paid Bessefte Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval Summary 18 Kuparuk River 3S-612 - Lower Moraine - Interval 9 Interval Summary Start Daterrime: 12/23/181311 End Date/Time: 12/23/1814:08 Pump Time: 57 min Initial Rate (Breakdown): 12.7 bpm Initial Surface Pressure (Breakdown): 5464 psi Initial BH Pressure (Breakdown): 5946 psi Max Rale: 39.2 bpm Max Surface Pressure: 4518 psi Max BH Pressure: 42DO psi Average Rate: 38.9 bpm Average Missile Pressure: 3610 psi Average Surface Pressure: 3570 psi Average SH Pressure: 3915 psi Average Missile HHP: 3442 hhp Average Surface HHP: 3404 hhp Initial Braden Pressure: 580 psi Max Braden Pressure: 582 psi Max Prop Con: 7.16 ppg Average Visc: 30 CP Average Temp: 75 F Average pH: 9.4 BH ISDP: 3347 psi Final Fracture Gradient 0.634 Psyh Final 5 min: 3314 psi Final 10 min: 3298 psi Final 15 min: 3284 psi Proppant Summary Premium - 100m Pumped: 7,269 lbs Wanli - 20/40 Pumped: 204,378 los Total Proppant Pumped' : 211,647 lbs Proppant in Formation: 211,647 its Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bola Treated Water Volume: 0 gal 0 bola 309 WaterFrat>G Volume: 10,966 gal 261 bola 30# Hybor-G Volume: 85,307 gal 2,031 bbls Freeze Protect Volume: 1,660 gal 40 bola Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbls Pad Volume: 3,842 gal 91 bb/s Conditioning Pad Voklme: 28,897 gal 688 bola Proppant Laden Fluid Volume: 52,568 gal 1,252 bbls Displacement Volume: 0 gal 0 bbls Flush Volume: 10,966 gal 261 bols Mini -Frac Volume: 0 gal 0 bbls Spacer & Ball Drop Volume: 0 gal 0 bible Freeze Protect Volume: 1,660 gal 40 bible Treatment Slurry Volume (Calculated): 107,543 gal 2,561 bola Total Clean Fkrid Volume: 97,933 gal 2,332 bbls Interval Status: Completed Comments: Had issues with HHP kickout out due to preload pressures as well as debris getting caught in Engineer: Landon Harr son pumps, resulting In drop in rate. Experienced issues catching concentration on sand due to frozen 7realer Daniel Salazar sand in Me hopper during 1 and 2 ppg proppant stages. All proppant placed per design. Supervisor. Daniel Salazar Values for proppant are taken from software calculations based on mukple variables. COmplatlans Engineer Hanna Sylte Proppam is billed ce of weight ticket volumes and may vary slightly from this number. Cuscmerne p: Paul Bessette Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 19 Kuparuk River 3S.612. Lower Moraine - Interval 10 Interval Summary Start DatelTime: 12/27/18 11:44 End Date/Time: 12127/1813:15 Pump Time: 91 min Initial Rate (Breakdown): 12.7 bpm Initial Surface Pressure (Breakdown): 5079 psi Initial BH Pressure (Breakdown): 5893.0 psi Max Rate: 41.2 bpm Max Surface Pressure: 5080 psi Max BH Pressure: 5894.0 psi Average Rate: 39.3 bpm Average Missile Pressure: 3646 psi Average Surface Pressure: 3547 psi Average SH Pressure: 3836 psi Average Missile HHP: 3512 hhp Average Surface HHP: 3417 hhp Initial Braden Pressure: 482 psi Max Braden Pressure: 647 psi Max Prop Con: 7.20 poll Average Visc: 31 cP Average Temp: 79 F Average pH: 9.4 Proppam Summary Premium - 100m Pumped: 7,227 lbs Wanit - 20/40 Pumped: 203,450 Ibis Total Proppam Pumped* : 210,677 lbs Proppam in Formation: 210,677 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 309 WaterFrac-G Volume: 0 gal 0 bblis 30# Hybor-G Volume: 103,019 gal 2,453 MIS Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbls Pad Volume: 6,904 gal 164 bits Conditioning Pad Volume: 28,962 gal 690 little Proppam Laden Fuld Volume: 52,206 gal 1,243 ibis Displacement Volume: 0 gal 0 bbls Flush Volume: 0 gal 0 bbls Mini -Frac Volume: 0 gal 0 b61s Spacer & Ball Drop Volume: 14,947 gal 356 bits Freeze Protect Volume: 0 gal 0 bbls Treatment Slurry Volume (Calculated): 112,585 gal 2,681 bbls Total Clean Fluid Volume: 103,019 gal 2,453 bbls Interval Status: Completed Comments: Cama offline shortly to troubleshoot issues with our flow meters and determine why we couldn't Engineerlandon Harrison establish crosslink, both issues were resolved and we continued with tone. Heard ball to start Treater Daniel Salazar zone. Had issue with HHP kicking out due to preload pressure. All proppant placed per design. Supervisor Daniel Salazar 'Values for proppant are taken from software calculators based on multiple variables. Completions Engineer Hanna Sylte Proppam is billed off or weight ricket vommes and may vary slightly from this number. Customer Rep: Phil Rasfferty, Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 20 Kuparuk River 3S-612 - Lower Moraine - Interval 11 Interval Summary Start Daterrime: 12/27/18 1315 End DateMme: 12/27/1814:20 Pump Time: 65 min Initial Rate (Breakdown): 10.7 bpm Initial Surface Pressure (Breakdown): 5405 psi Initial BH Pressure (Breakdown): 6270 psi Max Rate: 39.8 bpm Max Surface Pressure: 5406 psi Max BH Pressure: 6270 psi Average Rate: 39.7 bpm Average Missile Pressure: 3454 psi Average Surface Pressure: 3356 psi Average BH Pressure: 3636 psi Average Missile Al 3361 hhp Average Surface Al 3266 hhp Initial Braden Pressure: 651 psi Max Braden Pressure: 679 psi Max Prop Con: 7.05 ppg Average Vise: 37 cP Average Temp: 76 F Average pH: 9.3 Proppant Summary Premium - 100m Pumped: 7,212 lbs Wanli - 20140 Pumped: 204,120 lbs Total Proppant Pumped* : 211,332 lbs Proppant in Formation: 211,332 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bills 309 WaterFrac-G Volume: 0 gal 0 bbls 306 Hybor-G Volume: 92,980 gal 2,214 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbls Pad Volume: 2,034 gal 48 bb/s Conditioning Pad Volume: 28,719 gal 684 blas Proppant Laden Fluid Volume: 60,461 gal 1,440 bbls Displacement Volume: 0 gal 0 bills Flush Volume: 0 gal 0 bbls Mini -Frac Volume: 0 gal 0 MIS Spacer 8 Ball Drop Volume: 1,766 gal 42 bills Freeze Protect Volume: 0 gal 0 bbls Treatment Slurry Volume (Calculated): 102,576 gal 2,442 bbls Total Clean Fluid Volume: 92,980 gal 2,214 bills Interval Status: Completed Comments: Heard ball on me, saw strong seat response. Experienced high Ncbon due to higher Viscosity Engineer Landon Harrison Nan design, which was caused by blow by though DA1 while blowing off WG -36 into Ute dry Treater Daniel Salazar hopper of the ADP. Lost rate due to catching air at blender, continued win zone after issues was resolved, Staged back into sand in shat 1 ppg steps per customer engineers request Lost Supervisor. Daniel Salazar hopped due to operator tailing to open all bins on the unit. All proppant placed per design. 'Values for proppam are taken from software calculations eased on multiple variables. Completions Engineer Hanna Sylte Proppant is billed off of weight ricket volumesand may vary slightly hon this number. Customer Rep: Phil Restrarty Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval Summary 21 Kuparuk River 3S-612 -Lower Moraine - interval 12 Interval Summary Stan Date/Time: 12/28/1810:14 End Daterrime: 12/26/18 11:24 Pump Time: 70 min Initial Rale (Breakdown): 10.7 bpm Initial Surface Pressure (Breakdown): 5107 psi Initial BH Pressure (Breakdown): 6047 psi Max Rate: 40.3 bpm Max Surface Pressure: 5542 psi Max BH Pressure: 3709.0 psi Average Rate: 39.5 bpm Average Missile Pressure: 5474 psi Average Surface Pressure: 3664 psi Average BH Pressure: 3547 psi Average Missile HHP: 5300 hill Average Surface HHP: 3547 hhp Initial Braden Pressure: 511 psi Max Braden Pressure: 603 psi Max Prop Con: 7.36 ppg Average Vsc: 29 CP Average Temp: 62 F Average pH: 9.3 BH ISDP: 3396 psi Final Fracture Gradient 0.657 psi41 Proppant Summary Premium - 100m Pumped: 7,812 lbs Wall - 20/40 Pumped: 203,292 lbs Total Proppant Puml : 211,104 his Proppant in Formation: 211,104 lbs Fluid Summary (by fluid description) Sea Water Volume: 0 gal 0 bbis Treated Water Volume: 0 gal 0 bbis 306 WaterFr co -G Volume: 17,390 gal 414 bbis 306 Hybor-G Volume: 89,991 gal 2,143 bbis Freeze Protect Volume: 4,747 gal 113 bbis Fluid Summary (by stage description) Breakdown Volume: 0 gal 0 bbis Pad Volume: 6,577 gal 157 bills Conditioning Pad Volume: 31,558 gal 751 bills Proppant Laden Fluid Volume: 51,856 gal 1,235 MIS Displacement Vokfine: 0 gal 0 bblS Flush Volume: 17,390 gal 414 bills Mini -Frac Volume: 0 gal 0 bbis Spacer & Ball Drop Volume: 0 gal 0 bbis Freeze Protect Volume: 4,747 gal 113 bbis Treatment Slurry Volume (Calculated): 121,713 gal 2,898 MIS Total Clean Fluid Volume: 112,128 gal 2,670 bblS Interval Status: Completed Comments: Dropped ball following zone 11, heard on mic, saw propper seat. While It was dropping water Engineer: Landon Harrison transfer had issues providing rale to HES' FBbk and ADP blenders. With customer approval we TreaterDaniel Salazar pumped the ball down at approximately 12 BPM to keep fluid moving and give water transfer time Supervisor, Daniel Salazar to troubleshoot the issue. No solution was found, so we called flush on our first attempt at zone 12 (had started 0.25 ppg 100 Mesh stage). Lost all rate at the F84k and ADP, so we finished Flush with LVF -200 (approximately 55 total. Due to not having enough LVr-200 on location to be able to freeze protect the well and equipment following another attempt, it was decided that we needed to freeze protect the equipment for the night, reload LW -200, and complete the remainder of the zone the next tlay. Reloaded LW -2W came from Ml-Swaco. The following day we pumped the remainder of zone 12 to completion. All castles were emptied at the end of the zone. All proppant placed per modified design. 'Values for proppam are taken from software calculai based on multiple variable.. Completions Engineer Hanna Sylte Proppant is billed off of weight ticket volumes and may vary slightly them mis number. Customer Rep: Phil RasHeny Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval Summary 22 Pressure Test - DFIT 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 Kickout Pressure (psi) _.. IF i �D 11:54 1156 1158 1200 12:02 12:04 12:06 1211612019 Time 1211612018 Global Event Log ] Pressure Test - Globals 11:52:41 F41 Pressure Test -Locals 11:53:02 Pressure Test -Max First Half 12:01:15 Q Pressure Test - Max Second Half 120337 Pressure Test -Good Test Bleed Down 12:04:35 Cuslorrer. CONOCOHiLLLPS NOR iH SLOPE- ®LIS Job Date 1GDeo-2018 Sales Order N: 0905321854 MI Description: Kuparuk'ver Wit 3S-612 LAM 50-103-20777 Coraco Phfillips Alaska, Inc. � Kuparuk River 35-612 Interval Plats 23 Treatment Plot - DFIT T,raungProfore (psi) A $lar,y Rale (bpml tt A. , P.',.ppaa, CTn, tli, -,A, , BillProPDan, Coaeph/gall C A B oRu rrea Iry it A Aural RN Twup Pal c C 12/16/2018 12/IW22018 Time Gomco Phillips Alaska, Inc. - Kuparuk Rimer 35612 Interval 0 Plots 24 Pressure Test - Minifrac 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 Kickoul Pressure (psn 1044 10:46 10:48 10:50 10:52 10:54 1211712018 1211712018 Time Global Event Log ❑Q Pressure Test- Globals 10:44:44 FT Pressure Test -Locals 10:45:25 Pressure Test- Max Pressure Test 10:5204 Customer: CONOCOPHILLIPS NORTH SLOPE- ESUS Job Date: 17 -Dec -2018 Sales Order#: 0905321854 WeII Description: Kuparuk Wer and 35-612 LW: 50-103-20777 Conom Phillips Alaska, Inc. - Kuparuk Aber 35612 Interval 1 Plots Nitrogen Pop Off Test - Minifrac 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 Kickout Pressure (psi) Time Global Event Log © Pressure Test -Pop Off 11:18:34 ❑7 Pressure Test -Pop Off 8200 11:20:50 ❑8 Pressure Test- Good Test Bleed oft 112355 Customer: CONOCOPHILLIPS NORTH SLOPE- EBLIS Job Date: 17 -Dec -2018 Sales Order #: 0905321854 Wd Description: Kuparuk RNer Lhd3S-612 LAM: 50-103-20777 Conoco Phillips Alaska, Inc.- Kopamk River 33-612 Interval 1 Plots 26 Pressure Test - #2 Minifrac It Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure@Pump (psi) P2 Kickout Pressure (par, — Time Global Event Log Pressure -rest -max 13:06:58 Flil Pressure Test -Good Test 13:09:43 Oustoner: CONOCOR*-LIPS NORTH SLOPE-EBUSJob Date: 17 -Dec -2018 Sales Order#: 0905321854 Well Description: KupamkRver Unft3S-612 UW: 50-103-20777 Conoco Phillips Alaska, Inc. - Kuparuk River 35612 Interval i Flats Off - #2 Minifrac Pressure @Pump (psi) P2 Kickout Pressure (psi 12117t201e 1211712018Time Global Event Log 1© Pressure Test- Pop Off 13:11:521® Pressure Test- No Pop Bleed down to reset 1314:43 A Adjusting Pop -Off 13:16:40 No Pop 13:18:26 Pressure Test -Pop -Off 13:22:58 Pressure Test -Pop Off 8393 13:24:21 Customer CONOCOPHILLIPS NORTH SLOPE- ESUS .bb Date: 17 -Dec -2018 Sales Order #: 0905321854 Well Description: Kuparuk River lni 35-612 UM 50-10320777 Wnow Phillips Alaska, Inc.-Kuparuk River 35-612 Interval l Plots 28 9117 r.1Prnlrlraut tivre (i I>/gaI) Gauge BH 1'ws (psi) A B a�nsml,3eolrnm} Treatment Plot - Minifrac t BI I Proppant G'unc(I t Ac[aal B11 crop( -Fl r. C C ( C E G 0 X500 12/17/2015 12/17/2019 Time Intersection SR TPP UBP ABT TP JSV Open Well 14:18:54 0.000 0.000 2219 130.7 313.8 0.000 Break Formation 14:28:02 3701 0.000 6182 118.2 6937 146.6 ® Stage Al Top Perf=4 14:32:16 4078 0.000 5113 105.5 4947 314.6 l Stage At Top Perf= 5 14:34:20 40.87 0.000 5034 100.5 4823 3989 go] Conoco Phillips Alaska, Inc. - Kuparuk aber 35-612 Interval 1 Plots 29 Blender Chemical Plot - Interval 1 M0-67 Conc (gal/Mgal) B CL-22 UC Conc (gallMgaq — A Optiflo-ll Conc pblMgal) B A I Optiflo-III Conc (Ib/Mgal) B C.-31 Conc (gaUrOgap A B 111 1eVlC Time 191712018 Customer: CONOCORM.LIPS NORTH SLOPE -EBUS I Job Date: 17 -Dec -2078 Sales Order#: 0905321854 Well Description: Kuparuk Flier Lh@3S-612 INN: 50-103-20777 Conoco Phillips Alaska, Inc.-Kuparuk River 35-612 Interval l Plots 30 ADP Chemical Plot - Minifrac A I Losurf-3O0D Cono (gal/Mgal) A WG -36 Conc (lb/Mgal) E rzn nzultl Time 12117/2018 Customer CONOCOPHILLIPS =SLOPE EBUS Job Date: 17 -Deo -2018 Sales Ober #: 0905321854 Well Description: Kuparuk River Unk 3S612 LW. 50.10320777 Conoco Phillips Alaska, Inc. - kuparuk River 35-612 Interval 1 Plots Treatment Plot - Interval 1 A B Tensing Presare (Psi) A 9n:., Ralelbpml B Sn"''IRoppnnl cone lllvfnll- C BH IP PPant Cone (1b/gal) � C A Afmal BII Temp (°F) E 12/17/20I8 Ivllrzolb Time Wroco Phillips Alaska, Inc. - Kuparuk River 35612 Interval 1 Plots 32 Blender Chemical Plot -Interval 1 MOE7 Conc (gal/Mgap B CL -22 UC Conc (gal/Mgal) — A Optiflo-ll Conc Qb/Mgal) B A Optiflo-III Conc (Ib/Mgal) B CL -31 Conc (galmlgap G. B nme Custoner. CANOCOPI-ILLPSNOFiiH SLOPE -®US ,bb Date: 17 -Dec -2018 Sales Order#: 0905321854 Well Description: Kuparuk River Chi 35-612 UM: 50-103-20777 Conoco Phillips AlasU, Inc. - Kuparuk River 3S-612 Interval 1 Plots ADP Chemical Plot- Interval 1 A I LosurL300D Cone (gal/Mgal) A VVG-36 Cone (Ib/Mgal) E 1211712010 12117/2018 Time Customer: CONOCOFMLLIPS NORTH SLOPE- ®LS .bb Dale: 17 -Dec -2018 Saks Order #: 0905321854 Well Description: Kuparuk River Ond 3$-612 INN: 50-103-20777 Conoco Phillips Alaska, Inc. - Kuparuk River 35612 Interval 1 Plats 34 Net Pressure Plot -Interval Net Gauge BH Pres (psi) A A BH Proppant Conc (Ib/gal) B Time (min) Customer: CONOCORRLLPS NORM SLOPE- ®US .bb Date: 17 -Dec -2018 Sales Order #: 0905321854 Well Descripibn: Kuparuk River Uni13S-612 LAM: 50-10&20777 Conoco Phillips Alaska, Im. - Kuparuk River 35612 Ime.11 Plots 35 Treatment Plot - Interval 2 A T113041=71-vfingPmmre (Psi) A Slur,)' Ralelbpml B 'I-n' B Pmpp arl Cnnc llL/enq— (' B11 R41=Cone llblK.al)— C Cane B l I Pm(psil A Aural BH Tern, ff) E 12/19/2019 12/17120 IS Time Conoco Phillips Alaska, Inc.- Kuparuk River 35632 Interva12 Plots Blender Chemical Plot -Interval 2 MO -67 Conc (gallMgal) B CL -22 UC Conc (gal/Mgal) — A Optiflo-ll Conc (lblMgal) 8 A Optiflo-lll Conc (Ib/Mgal) B CI _ -31 Core. (gal/P,19al) A B Time O.Istomer CONOCOPHLLIPS NORTH SLOPE- EBUS Job Date: 17 -Dec -2018 Saks Order M 0905321854 Well Description: Kupawk River link 3S-612 INA: 50-10320777 Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval 2 Plots 37 ADP Chemical Plot - Interval 2 A I Losurf-300D Conic (gal/Mgai) A WG -36 Conic (Ib/Mgal) E E 1211712018 Time 1v1712a1e Customer: CONOCOPHLLIPS NORTH SLOPE- EBLIS I Job Date: 17 -Dec -2018 Saks Oroer#: 0905321854 Well Description: Kuparuk Rver Link 3S-612 UM: 50-103-20777 Conon Phillips Alaska, Inc. - Kuparuk River 35612 Interval 2 Plots Net Pressure Plot- Interval 2 —Net Gauge BH Pres (psi) A BH Proppant Conc (lb/gal) B 6 1u Time (min) Qlsloner: CONOODPrYLLIPS NORTH SLOPE- ®LIS Job Oat.: 17 -Dec -2018 Sales Order #: 0905321854 Well Descriptlon: Kuparuk River LbA3S-612 llWl: 50-10320777 Conow Phillips Alaska, 1r, - Kuparuk River 35-612 Interval 2 Plots FA Treatment Plot - Interval 3 B ITreafing Prmmre(,i) A Sinn,Roaelb,ml B Slurn PrnPpam Conc IN/gall-- C BH Proppant Cone (Ib/gal) - C Gnnge BII Pees (Pai)A ACIun1 BH Tem, (°F) F C Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval 3 Plots 40 A 2. 1. 1. 1. 1. 1. 0. 0. 0. 0. 0 Blender Chemical Plot - Interval 3 MO -67 Cone (gallMgaq B CL -22 UC Cone (gal/Mgal) — A Optiflo-II Cone (16/Mgal) B Optlflo-III Cone (@/MgaO B CL -3: " -- (yal/Mgal) P. E 0 8 6 4 2 0 6 2 0 � I 16:20 16:40 17:00 17:20 17:40 18:00 12/17/2018 1217/2018 Time Customer: CONOCOPHLLIPSNORTrISLOPE - WeIlDescription: Kuparuk RNer Lhd3S-612 IPM: 50-103-20777 Conow Phillips Alaska,Inc. - Kuparuk River 31612 Inte1a13 Plots 41 ADP Chemical Plot - Interval 3 Losurf-300D Cono (gal/Mgal) A WG -36 Cam (Ib/Mgal) E I i 1 ' I I 17:20 17:30 17:40 17:50 18:00 18:10 12/172018 Time 1211712018 Customer: CONOCOPHILLRS NORTH SLOPE- EBUS I ,bb Dale: 17 -Dec -2018 Sales Order #: 090.5321854 Well Description: Kuparuk Rber Unk 35612 1M7: 50-103-20777 E 00 10 10 0 0 10 0 10 '0 0 Conoco Phillips Alaska, Inc. - Nupamk River 35-612 Internal 3 Plots 42 Net Pressure Plot - Interval 3 Net Gauge BH Pres (psi) A BH Proppant Conc (lb/gal) B Time (min) Customer: CONOCOPHILLIPS NORTH SLOPE- EBUS Job Date: 17 -Dec -2018 Sales Order #: 0905321854 Well Description: Kuparuk River Unit 35-612 IMA: 50-103-20777 Coro. Phillips Alaska, Inc. - Kuperuk law, 3Y612 Interval 3 Plots Pressure Test - Zones 4-6 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) time Customer. CONOCOPHLLPS NORTH SLOPE- ®IS I Job Date: 17 -Deo -2018 Sales Order H: 0905321854 MU Description: Kuparuk Rver LhR 3S-612 IMA: 50-103-20777 Conoco Phillips Alaska, Inc.- Kuparuk River 35612 Interval Plots 44 Global Event Log Pressure Test -Global Kickouts 10:39:07 7® Pressure Test -Local Kickouts 10:40:09 Pressure Test -70% 10:43:19 q Pressure Test -Max 10:44:53 Customer. CONOCOPHLLPS NORTH SLOPE- ®IS I Job Date: 17 -Deo -2018 Sales Order H: 0905321854 MU Description: Kuparuk Rver LhR 3S-612 IMA: 50-103-20777 Conoco Phillips Alaska, Inc.- Kuparuk River 35612 Interval Plots 44 Pressure Test - Nitrogen Pop -Off Tests Treating Pressure @Pump (psi) P2 Kiskout Pressane (nsi) --- --- 1D W2019 1212 2019 Time Global Event Log Pressure Test -N2 Popoff Test 10:51:45 ✓3 Pressure Test -N2 Popoff Test- Confinnation 11:01:49 Qtstarer: CONOCOPHILLIPS NORTH SLOPE- ®US Job Vie: 17 -Deo -2018 Sales Order #: 0905321854 WeA Description: Kuparuk River Unit 35612 IMA: 50-103-20777 Conoco Phillips Alaska, Inc. - Kuparuk River 35-x12 Interval 4 Plots Treatment Plot - Interval 4 Linn, VmP P.m i T..... eap C R11 ProPpanl Coal@/gal) C $ Gnug�llFl Pm' Nrp-4tsual en'Ieanp (°F] F C 12/20/2018 Time 12/20/2018 Conoco Phillips Alaska, Inc. - Kuparuk River 31612 Interval4 Plots 46 Blender Chemical Plot - Interval 4 00-67 Cone (gal/Mgal) B CL -22 UC Cone (gal/Mgap A )ptiflo-ll Cone (Ib/Mgal) B Optiflo-III Cone (Ib/Mgal) B G9 u 12:40 12:50 13:00 13:10 13:20 13:30 13:40 13:50 14:UU 1v2a1201e 1V=2018Time Custarrer: CONOCORALLIPS NORTH SLOPE- ®LS Job Date: 17 -Dee -2018 Sales Order p: 0905321854 N.NII Des 01on: Kuperuk Rver lir@ 35612 Lim 50-103-20777 Conoco Phillips Alaska, Inc.- Kuparuk arver 35612 Interval4 Plots 47 A 2.0 1.8- 1.6- 1.4- 1.2 .81.61.41.2 1.0 M- 0.6- 0.4- 0.2 .80.60.40.2 00 ADP Chemical Plot- Interval Losurf-300D Conc (gal/Mgal) A WG -36 Conc (IWMgal) E E 100 90 80 70 80 50 40 30 20 10 0 12:40 12:50 13:00 13:10 13:20 13:30 13:40 13:50 14:00 12/MX16 Time 1212N2019 Oustorrer: COWOOR-LLIPS M1OM H SLOPE- EBLk4 Job Date: 17-Deo2018 Sales Order #: 0905321854 Well Description: Kuparuk Rver Lhft 33-612 UM: 50-103-20777 Conom Phillips Alaska, Inc. - Kupamk River 35-612 Interval 4 plots 48 Net Pressure Plot - Interval 4 Net Gauge BH Pres (psi) A —BH Proppant Conc (Ib/gal) B A Slope of Net Pressure (psi/min) C Time (min) Well Description: CONDO HIL lJS NORTH SLOPE- EBUS I bob Dete. DeI Sales Order uparuk C.. Phillips Alaska, Inc. - Kuparuk ftu 35612 Interval 4 Plats 49 Treatment Plot - Interval 5 A B Shur. Pmppan, Cnue Ilh d, C BN propp, caneo BIT P,n Ansi) A Ach,M BH C 14:10 1420 1430 14:40 14:50 1500 15:10 12/20n018 12120/2018 Time Conoco PMllips Alaska, Inc. - Kuparuk River 35-633 Interval5 Plots 50 Blender Chemical Plot - Interval 5 Optiflo-II Conc pb/Mgal) B Optiflo-III Conc A CL -- 4 lW2N2016 m2N201e Time FS FORTH SLOPE- ®US �Q3te: 50-0320777 Saes Order #: 0905321854 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval 5 plots ADP Chemical Plot - Interval 5 A I Losurf--300D Cone (gal/Mgal) A WG -36 Conic (Ib/Mgal) E E lime Custerrer: CONOCAR-9LLP5 NORTH SLOPE- ®US .bb Date: 17-Da>2018 Sales Order M 0905321854 Well Description: Kuparuk Fiver Lhrt 3$-612 LW: 50-103.20777 Gomco Phillips Alaska, Inc. - Kuparuk River 35612 Interval 5 Plots Net Pressure Plot - Interval 5 Net Gauge BH Pres (psi) A — BH Proppant Conc (Ib/gap B A Slope of Net Pressure (psi/min) C Time (min) Costo r: CONO ORALLIPS NORTH SLOPE- E811S .bb Date: 17 -Dc -2018 Sales Order #. 0905321854 Well Descnptim: Kuparuk RverWft3S-612 U✓ut: 50-103-20777 Conoco Phillips Alaska, I.. - Kupamk River 35-612 Interval 5 Plotz 53 Treatment Plot - Interval 6 Lvn PIII'Ppanl C nnc IIL%gn1) C BH Pmppant Conc (lL/gal)C A B 4auge BII Pm (Nxi) A Actual BH Temp 1°f1 P. C 12/202016 12120/2018 Time Conocn Phillips Alaska,Inc.- Kuparuk BMer 35-612 Interval6 plots 54 9 Blender Chemical Plot - Interval 6 Optiflo-ll Conc (1b/Mgal) B Optiflo-lll Conc Vgal) A r' urzrvauln Time IV2012018 Customer: CONOCOAA.LIPS NORTH SLOPE- EBUS .bb tate: 17 -Dec -2016 Sales Order #: 09053218% Wei Description: Kuparuk Rver UnK 3S-612 LAM 50.10&20777 Coiwm Phillips Alaska, Inc.- Kuparuk River 3S-612 Interval Plots 55 r( ADP Chemical Plot - Interval 6 Losurf-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgal) E E lime Custorrer. CONOCGRILPS NORTH SLOPE- EB115 Job Date: 17 -Deo -2018 Sales Order #: 0905321854 V�kll T3eacdption: Kuparuk Rver l -W 35-812 LAM 50-103-20777 Conoco Phillips Alaska, Inc. - Kuperuk River 35-613 Interval 6 Plots Net Pressure Plot - Interval 6 —Net Gauge BH Pres (psi) A —BH Proppant Conc (Ib/gal) B A Slope of Net Pressure (psi/min) C Time (min) Customar: CONOCOFliLIPS NORTH SLOFE-EBUS I ,bb Date: 17 -pec -2018 Sales Order#: 0905321854 Wal Description: Kuparuk Rver Unk 3S-612 1Na 50-103-20777 Conoco Phillips Alaska, Inc. - Kuparuk River 3$-612 Interval 6 Plots Pressure Test - Zones 7-9 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) Time Global Event Log ❑2 Pressure Test-Globals 09:47:15 ❑3 Pressure Test. Locals 09:47:26 ® Pressure Test -70% 09:49:54 W PressureTest-Max 09:53:33 Custorrer. CONOCOFFiILLPS NORTHSLOPE-BBUS .Wb Date: 23 -Dec -2018 Sales Omer#: 0905321854 Npll Description: =ruk fiver lkla 35-612 LMA: 50-103-20777 Conoco Phillips Alaska, Inc. - Kuperuk RWer 35-612 Interval? Plots 58 Nitrogen Pop -Off Tests -Zones 7-9 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 KiCkad PreSSu,c tps.; _ -- wza'zole lxizvzols Time Global Event Log ®6 Pressure Test -Nitrogen Pop -Off 10:00:07 ❑7 Pressure Test -Nitrogen Pop -Off Confirmation 10:05:54 Customer: C94000R-LLFS NORTH SLOPE- ®US I Job Date: 23-Deo2018 Sales Order N: 0905321854 VM Description: Kuparuk Rver Link 3S-612 INN: 50-103.20777 Conoco Phillips Alaska, Inc.- Kuparuk River 35-612 7 Plots 59 Treatment Plot - Interval 7 T.th, Prtssore (Pai) A Slnny Rate Npm) B A B Sinm Prnp P:un Cunc lllrigall C BH Proppant Cone (lb/gal) C Caugo BH Pna Q�s7 A Amul BH Temp PP) g C 12238018 1lnsnota Time Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Interval) Plots w Blender Chemical Plot - Interval 7 MO -67 Cone (gal/Mgal) B CL -22 UC Conc (gal/Mgal) A Optiflo-II Conc Qb/Mgal) B Optiflo-III Conc (Ib/Mgal) B CL -31 Conc (gal/M-4) ------ A 10:50 11:00 11:10 11:20 11:30 11:40 11:50 12:00 1X231201e1=2018 'rime Custer r CONOCORiLPS NORTH SLOPE- EBUS Job Date: 23 -De 2018 Sales Order p: 0905321854 """ Wall Description: Kuparuk River Unit 3S.612 LAM 50-10320777 Conoco Phillips Alaska, Ina.- Kuparuk River 35-612 Interval7 Plots A 2.0 1.8- 1.6- 1.4- 1.2- 1.0- 0.8- 0.6- 0.4- 0.2- 0.0- ADP .81.61.41.21.00.80.60.40.20.0 ADP Chemical Plot- Interval 7 Losurf-300D Conc (gal/Mgal) A WG -36 Cone (Ib/Mgal) E E 100 90 80 70 60 50 40 30 20 10 0 10:50 11:00 11:10 11:20 11:30 11:40 11:50 12:00 12:10 1X2W2018 Time 12/2W2018 Olstorrer: CONOCOPI-0.LIPS NORTH SLOPE- ®US Job gate: 2&Opc-2018 Sales Order #: 0905321854 N.pl Description: KuparukRver Uttt3S-612 UM: 50-103.20777 Conoco Phillips Alaska, Inc.- Kupawk River 3Y612 Interval? Plots 62 E 100 90 80 70 60 50 40 30 20 10 0 10:50 11:00 11:10 11:20 11:30 11:40 11:50 12:00 12:10 1X2W2018 Time 12/2W2018 Olstorrer: CONOCOPI-0.LIPS NORTH SLOPE- ®US Job gate: 2&Opc-2018 Sales Order #: 0905321854 N.pl Description: KuparukRver Uttt3S-612 UM: 50-103.20777 Conoco Phillips Alaska, Inc.- Kupawk River 3Y612 Interval? Plots 62 Net Pressure Plot- Interval 7 —Net Calc'd BH Pres (psi) A BH Proppant Conc (lb/gal) B ci—s s Not Proecure lnci/min) C Time (min) Customer CONOCpRiLIPB NORTH SLOPE- 133U5 .bb ate: 23Oeo-2018 Sal- Ortler #: 0905321854 Wag Description: Kuparuk Rver Unit 3S-612 I LMA: 50-10320777 Conoco Phillips Maspoi, Inc. - kup mk River 35612 Interval? Plots (r Treatment Plot - Interval 8 Pn,ppam rnn, u12"1' C 3H Proppant Conc (lb/&l) c A B cm,e� era rr., (m0 A Achial eH Tann (61F)e C ¢123120(e ¢i23rz018 Time Conoco Phillips Alaska, Inc.-Kuparuk River 31612 Interoal8 Plots Blender Chemical Plot - Interval 8 Optillo-ll Cone (Ib/Mgal) B Optifio-lll Cone (Ib/Mgal) B A CL-�1 Cozr, f:gal;M,,�ii A I B urn. Oustoner: CONOCOR-LLPS NORTH SLOPE- ®IS Job Date: 23 -Deo -2018 I Sales Order #: 0905321854 NSA Description: Kuparuk Rver LhR 3SS812 IAA: 50-103-20777 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval 8 Plots 65 ADP Chemical Plot - Interval 8 A I mai--300D Conc innumnal) A WG -36 conc Qb/Mgap E E 10 0 0 11 12:10 12I2&2018 • • • • • 0 • • 1220 1230 1240 12:50 13:00 208 Time N KrHSLOFE-®l1S .bb Cale: 23 -Dec -2018 Salee Order #: 0905321854 35612 WN: 50-10320777 Ell Conoco Phillips Alaska, Inc. - Kuparuk River3Y612 Ime1a18 Plats 66 Net Pressure Plot - Interval 8 =Net Caled BHPres (psi) A —BH Proppant Conc (Ib/gal) B B cin—s nfmsst Pm oime rnsi/mini C Time (min) gtstorter. CONCCOR-YLLJPS NORTH SLOPE- ®liS I Job Dele: 23 -Ds 2018 Well Description: Kuparuk River Urdt 35-612 WN: 00-10.420777 Conoco Phillips Alaska, Inc.-Kuparuk River 35-612 Innerva18 Plots 67 Treatment Plot - Interval 9 tilarn Pmllpam(^nc llLienp (' BH Proppanl Conc(Ib19.I) C C A B C.:mve BI{ Pm (ari) A penial BH Temp (OF) E 12/23/2018 sueamma Time Conoco Phillips Masks, Inc. - Kupamk River 35612 Inrerval9 Pb(s 68 Blender Chemical Plot - Interval 9 Optiflo-II Conc (1WMgal) B Optiflo-III Conc A CE -31 Cono (gal,Mgal) A in 192L2018 ,o<vmio Time Sales Order #: Watl Deac6ption: Kuparuk Rver Unit 35612 UM: 50-103-20777 Conoco Philli, Alaska, Inc. - Kaparvk Riva, 35612 Interval9 Plou ADP Chemical Plot - Interval 9 A Losurf300D Conc (gal/Mgap A WG -36 Conc (ib/Mgal) El E 13:10 13:20 13:30 13:40 13:bu -14:uu 12/2312018 Time 1212312018 Customr: CONOCO FLLPS 1JORIH SLOPE- ®US .bb Ike: 23-Oec-2018 Seles Order #: 0905321854 VM Description: Kuparuk River LhA 3S-612 INN: 50-10320777 Conaca Phillips Alaska, Inc. - Ruparuk River 35-612 Irderval 9 Plots Net Pressure Plot- Interval 9 Net Calc'd BH Pres (psi) A — BH PrOppant Conc (Ib/gal) B A Slope of Net Pressure (psi/min) C Time (min) Custoner: CONOCOR-RLFS NORTH SLOPE- EBUS I .lob Date: 23 -De 2016 Wel Description: Kuparuk River Lh t 3S-612 IAM: 50-103-20777 Conow Phillips Alwx ,Inc. - Wpawk River 3Se12 I0e1a19 Plots 71 Treating Pressure Pressure Test - Treatments 10-11 P ressure I.Psp unit- -- -- 12/P1201e Time Global Event Log 04 Pressure Test -Global Kickouts 09:33:57 ❑5 Pressure Test -Locals Kickouts 09:34:22 T Pressure Test -60% 09:36:05 Ln Pressure Test -Max 09:40:49 .PS PIOFi1li SLOPE- ®LS .bb Cate: 26-Oeo-2018 Sales Order M. 0905321854 Lki 3S-612 I MA: 50-103.20777 Conoco Phillips Alaska, Inc. - Kuparuk fluter 35-612 Interval 10 Plots J2 N2 Pop -Off -Treatments 10-11 Treating Pressure @Pump (psi) P2 Kickout Pressure (psi) Time 1212712018 Global Event Log Pressure Test- N2 Pop-off (Too Low) 09:47:26 09 Pressure Test -N2 Popoff 09:54:50 Pressure Test- N2 Popoff Confination 0958:37 Oistoner: CONOOOPFRLPS NORM SLOPE- ®US I Job Cate: 25 -Dec -2018 Sales Order #: 0905321854 "'""" VM Description: Kuparuk River Lhd 35-612 UM: 50-103-20777 Conoco Phillips Alaska. Inc. -Kuparuk River 35-612 1nW,.l 10 Plots 73 Treatment Plot - Interval 10 T.finSPsessum(Psi) A Slurry Rate(bpm) B Sinm ProVPnm Cuncllb�gall� C BH PropPanl Cont (Ib/gal) � C Gauge Bll Pres (Psi)A Acnlol BR Temp (°P) E Time Conoco Phillips Alaska, Inc. -Kup ruk Rivet 35612 1rterval 10 Plots 74 A 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2- 0.0 Blender .2- 0.0 Blender Chemical Plot - Interval 10 M0-67 Conc (gal/Mgal) B CL -22 UC Conc (gallMgal) — A Optiflo-II Conc (Ib/Mgal) B Optiflo-III Conc (Ib/Mgal) B CL -31 Conc (galiMgal) A Al Illy i i i10 i L 1111111111f1w 11:40 12:00 12:20 12:40 13:00 12127/2018 Time 1&27/2018 Oustorrer: CONOCOR-LLFS NORTH SLS- ®US Job Date: 26 -Dec -2018 Sales Order #: 0905321854 Well Description: Kuparuk Rver Unfl 35-612 WN: 50-103-20777 B 3 2 1 0 Conoco Phillips Alaska, Inc. - Kuparuk River 35612 Intern] 10 Plots 75 A 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 0.0 - ADP Chemical Plot- Interval 10 Losurf-300D Conc (gal/Mgal) A WG36 Conc (Ib/Mgalj E 11:50 12:00 12:10 1220 12:30 12:40 12:50 13:00 +a27/201e Time lN21r2018 0.lstoner. CONOCOFFILLFS NORTH SLO E- ®L8 .bb Dale: 26 -Dec -2018 I Sales Order t 0905321854 Well Description: Kuparuk fiver U1R 35-612 UM: 50-103-20777 E -100 90 80 70 60 50 40 30 20 10 0 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval 10 Plots 76 11:50 12:00 12:10 1220 12:30 12:40 12:50 13:00 +a27/201e Time lN21r2018 0.lstoner. CONOCOFFILLFS NORTH SLO E- ®L8 .bb Dale: 26 -Dec -2018 I Sales Order t 0905321854 Well Description: Kuparuk fiver U1R 35-612 UM: 50-103-20777 E -100 90 80 70 60 50 40 30 20 10 0 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval 10 Plots 76 A Net Pressure Plot - -Net Gauge BH Pres (psi) A BH Proppant Cone (lb/gal) B Slope of Net Pressure (psilmin) C Treatment 10 Time NetPr BPC Slope -145.62 0.000 0.000 0.000 Time (min) Ouslorrer: CONOCOPFQLPS NORTH SLOPE- ®L6 Job fie: 26DeC-2018Sales Order #: 0905321854 Wall Description: KuparukRverlhA3S-612 WN: 50-10320777 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Interval 10 Plots Treatment Plot - Interval 11 !i B Trnfing Reasure(psi) g A Shin, Rate (bpin) B Sin m Pioppanl Con c(I it all�� (' BH ProPPant Coni (Ib/ nll C Gangs B I I Pres lPsil A Acbml BHT., (oF) E a 13:10 1320 1330 13:40 13:50 14:00 14:10 1420 1127/1618 Time 12n7/2019 Conoco Phillips Alaska, Inc.- Kupamk River 3S-613 Interval 11 Plots 78 Blender Chemical Plot - Interval 11 M0-67 Conc (gal/Mgal) B CL -22 UC Conc (gal/Mgal) — A Optiflo-ll Cone (Ib/Mgal) B Optifio-lll Conc (Ib/Mgal) B CI. 31 Conc (gallhrtgai) A B 13:10 13:20 13:30 13:40 13:50 14:00 14:10 1921/2018 192712018 Time Custoner: CONOCOPHILLIPS.NORTH SLOPE -ALIS Job Date: 26 -Dec -2018 Sales Order p: 0905321854 Wei Description: Kuparuk Rver Link 3$-612 LAM: 50-103-20777 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Intenel 11 Plots 79 A 2.0 1.8- 1.6- 1.4- 1.2 .81.61.41.2 1.0 0.8- 0.6- 0.4- 0.2 .80.60.40.2 00 ADP Chemical Plot- Interval 11 Losurf-30OD Conc (gal1Mgal) A WG -36 Conc (ib/Mgal) E E 100 90 80 70 60 50 40 30 20 10 0 13:10 13:20 13:30 13:40 13:50 14:00 14:10 12/27/2018 Time 12/2]/2018 Custcrler CONOCOPHLLFS NORTH SLOPE -®LIS Job Date: 26Dec-2018 Sales Order#: 0905321854 Nkll Description: Kuperuk laver Lnd 3S-612 LW. 50.103-20777 Conaw Phillips Alaska, Inc - Kuparuk Ri r35612 Intorvj11 Plots 80 E 100 90 80 70 60 50 40 30 20 10 0 13:10 13:20 13:30 13:40 13:50 14:00 14:10 12/27/2018 Time 12/2]/2018 Custcrler CONOCOPHLLFS NORTH SLOPE -®LIS Job Date: 26Dec-2018 Sales Order#: 0905321854 Nkll Description: Kuperuk laver Lnd 3S-612 LW. 50.103-20777 Conaw Phillips Alaska, Inc - Kuparuk Ri r35612 Intorvj11 Plots 80 Net Pressure Plot - Treatment 11 Net Gauge BH Pres (psi) A Time NetPr BPC Slope — BH Proppant Cone (Ib/gal) B �1 -236.62 0.000 0.000 0.000 A Slope of Net Pressure (psi/min) C E Time (min) Custa r: CONOCOR LLIPS NORTH SLOPE- EBUS .bb Date: 26 -De 2018 Sales Order #: 0905327854 ""'""" Wall Description: Kuparuk River Unit 3$672 IMA: 50-703-20777 Conoco Phillips Alaska, I nc.-K.,a kRW.r 35-612 Interval 11 Plots 81 Pressure Test - Treatment 12 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 Kickout Pressure lost) __.47 1212&2018 MW2018 Time Global Event Log Pressure Test-Globals 08:38:51 99 Pressure Test -Locals 08:3943 Pressure Test -70% 08:40:55 9A PressureTest-Max 08:44:40 Custom: CONOCOPHILLIPS Well Description: Kuper lNORTH SLOPE- IBLIS I UM�e'3S-612 50. 0320777 Saks Order #: 0905321854 C nocn Phillips Alaska, Inc. - Nuparuk River 35-632 Interval 12 Plots 82 N2 Pop -Off Test - Treatment 12 Treating Pressure @Pump (psi) P2 Kickout Pressure (psi) Time ° Global Event Log Pressure Test -N2 Popoff 08:54:04 M Pressure Test- N2 PopoRConfirmation 08:58:48 Customer: CONOCOPHILLPS NORTH SLOPE- EBUS I Job Date: 26 -Dee -2018 Sales Ortler #: 0905321854 "'""'" Wel Description: Kuparuk fiver Lhd 35812 W1A: 50-103-20777 Conoco Phillips Alaska, Inc.- Kuparuk River 35-612 Interval 12 Plots 83 A B b00, 50 40 30 20' 10 0 - Treatment Plot - Interval 12.1 Trnfing Pressure lPsi) .4 Slurn'Rou lblunl B Sln rn Pro PP ant Cmmllhlgnl)� C BHProppant Cona(lb/gal)- C Gauge BRPIn IP+il A Aca.l BHTemp1°PI E 14:15 1420 1425 12/]1/2018 1430 1435 Time C E 10 50C 9 8 400 7 6 300 5 4 200 3 2 100 I 0 0 14:40 14:45 14:50 12121/2018 Conoco Phillips Alaska,Inc.- Kupamk River 35-512 Inteml 12 Plots 84 14:15 1420 1425 12/]1/2018 1430 1435 Time C E 10 50C 9 8 400 7 6 300 5 4 200 3 2 100 I 0 0 14:40 14:45 14:50 12121/2018 Conoco Phillips Alaska,Inc.- Kupamk River 35-512 Inteml 12 Plots 84 Blender Chemical Plot - Interval 12.1 A 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0.6 0.4 0.2 o-III Conc (Ib/Mgal) B M0-67 Conc (gai/Mgal) B CL -22 UC Conc (gal/MgaI)— A Opti'0-::'C Optiflo-ll Conc (Ib/Mgal) B CL-31Conc (galiMgal) A ww B -4 -3 -2 1 0.0 0 14:15 14:20 14:25 14:30 14:35 14:40 122712018 Time 1927/2018 GletOner: COhlOCOPHILLIPSfJOR1H SLOPE- EBUS Job Date: 26 -Deo -2018 Sales Order #. 0905321854 WeX Description: Kuparuk Rver LhR 35612 LAM 50-10&20777 Ccnoca Phillips Alaska, Inc. - Kuparuk Riuer 35612 Interval 12 PloK 85 A 2.0 1.8- 1.6- 1.4- 1.2- 1.0 0.8 .81.61.41.21.00.80.60.40.2 00 r ADP Chemical Plot- Interval 12.1 Losurf-300D Cone (gal/Mgal) A WG -36 Conc (ib/Mgal) E E 100 90 80 70 60 50 40 30 20 10 0 14:15 14:20 14:25 14:30 14:35 14:40 12127/2018 Time 1212712018 Oustomar: CONOCORiLFS NORTH SLOPE- ®tS I Job Date: 26 -Deo -2018 Sales Doer #: 0905321854 1Abl Description: KuWuk Rver ula3Sfi72 LW: 50-103-20777 Conoco Phillips Alaska,Inc.- Kuparuk River 3S-612 Inte1a112 Plots 86 E 100 90 80 70 60 50 40 30 20 10 0 14:15 14:20 14:25 14:30 14:35 14:40 12127/2018 Time 1212712018 Oustomar: CONOCORiLFS NORTH SLOPE- ®tS I Job Date: 26 -Deo -2018 Sales Doer #: 0905321854 1Abl Description: KuWuk Rver ula3Sfi72 LW: 50-103-20777 Conoco Phillips Alaska,Inc.- Kuparuk River 3S-612 Inte1a112 Plots 86 Pressure Test -Treatment 12 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) - - 08:39 08:40 08:41 08:42 08:43 08:44 08:45 08:46 08:47 1vza�zole 12128I2o19 Time Global Event Log &1 Pressure Test-Globals 08:38:51 Pressure Test -Locals 083943 Pressure Test -70% 08:40:55 Pressure Test -Max 08:44:40 Cusloner: CIXWCOPFILLPS NORM SLOPE- ®LIS .bb Date: 26-Deu2018 Sees Order p: 0905321854 YVEI Description: Kuparuk Rver Lnft3S-812 lMt 50.10&20777 Conow Phillips Alaska, Inc. - Kuparuk River 35612 Interval 12 Plots 87 N2 Pop -Off Test - Treatment 12 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 Kickout Pressure (psi) 102W2018 102812018 Time Global Event Log Pressure Test -N2 Popoff 08:54:04 ® Pressure Test- N2 Popoff Confirmation 08:58:48 Customer: CONOCOPHILLPS NOriRi SLOPE- EBUS Job Date: 26Dec-2018 Sales Order p: 0905321854 MU Description: Kuparuk Rver LInR 36812 UM: 50-10320777 Conoco Phillips Alaska, Inc. - Kupamk River 3S-612 Interval 12 Plots Be Treatment Plot - Interval 12.2 A B Sliviy Bi"H"' of Cnnv'il'211 f dd Pmppant Cone(Ib/pal) Cnu6e Pre (Psi) A Aown1 RH Tem. PFI — C 12/28/2018 - 1])18MIS Time Conoco Phillips Alaska, Inc. - Kuppruk Hiwr 35-612 Interval 12 Plots 89 Blender Chemical Plot - Interval 12.2 OptiBo-II Cone (Ib/Mgal)_— — B Optiflo-111 Cone (Ib/Mgal) B A Cl—, A. B I ime Wsto r: CDNOCOR-LLLIPStJORI}i SLOPE- ®ll$ Job Date: 28 -Dao -2018 Sales Order #: 0905321854 Wel Description: Kuparuk Rver Lh8 35812 LN61: 50-103-20777 Conoce Phillips Alaska, Inc.- Kuperuk River 35-612 Interval 12 Plots 90 ADP Chemical Plot- Interval 12.2 A I Losurf-300D Conc (gal/Mgal) A WG -36 Conc Qb/Mgal) El E lime Oul loner. CONOCOR-ILLR S NORTH SLOPE- ESUS Job Dale: 28 -Dec -2018 I Sakes Order #: 0905321854 Wd Description: Kuperuk Rver W 3S-612 LAM: 50-10320777 Conoco Phillips Alaska, Inc. - Kuparuk River 3S-612 Interval 12 Plotz A Net Pressure —Net Calc'd BH Pres (psi) A —BH Proppam Conc Ob/gal) B Slope of Net Pressure (psi/min) C Plot - Treatment 12 Time NetPr BPC Slope 0 50.95 2889 3.996 2.026 B Time (min) Custarer: CU4000PFILLIPS NORTH SLOPE- EBUS Job Gate: 28 -Deo -2018 Sales Order #: 0905321854 Well Description: Kuparuk Rver Lk* 35812 1N41: 50-10&20777 Conoco Phillips Alaska, Inc. - Kuparuk NWer 35612 Interval 12 Plots 92 HALLIBURTON Sates Order,4' 905329854 Conoco Phillips Alaska, Inc. Kuparuk River 3S-612 Intervals 0-12 Lower Moraine Moraine Formation Harrison Bay County, AK API: 50-103-20777 Preparedfor: Hanna.Sylte December 2, 2018 Stimulation Treatment Appendix Chemical Summary Planned Design Water Straps - DFIT-Zone 12 Water Analysis - DFIT-Zone 12 Real -Time QC - DFIT-Zone 12 Bacteria Testing - DFIT-Zone 12 Event List - DFIT-Zone 12 Farm 15 Minute Testing - DFIT-Zone 12 Lab Testing Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Appendix 93 Customer Conoco Phillips Alaska, Inc. Formation Lower Moraine HALLIBURTDN I nr.auocelon E neapemeat Lease Kuparuk River 3S-612 API 50-103-20777 Date 12/16/2018 Interval Summary - Chemicals Conoco Phillips Alaska, Inc.-Kupamk River 35-612 chemical Summary Liquid Additives Dry Additives Interval LoSurf-300D CL -31 CL -22 UC MO -67 LVT-200 WG -36 BE -6 OptiFlo-III Opti Flo -II SP (gal) (901) (901) (gal) (909 (lbs) (lbs) (lbs) (Ibs) Obs) Prime Up 0 0 0 294 0 0 0 0 0 0 0 0 0 0 0 2940 0 0 0 0 0 1 138 56 113 fit 0 4070 21 275 35 0 2 84 38 76 25 0 2467 13 169 21 0 3 94 34 62 31 3150 2737 12 176 20 10 4 101 45 93 37 0 3455 15 169 25 0 5 85 38 76 36 0 2905 12 170 22 0 6 59 37 78 38 4200 3108 15 211 36 10 7 95 43 85 33 0 2672 14 189 24 0 8 88 40 79 31 0 2873 12 177 22 0 9 112 62 72 41 4200 2845 14 184 24 15 10 103 46. 92 37 0 3250 15 192 26 0 11 102 45 134 61 5670 3532 21 268 54 10 12 110 40 81 31 5250 2903 15 211 27 13 Total 1171 524 1041 757 25410 36817 179 2391 336 58. w/o Prime Up 1171 $24 1041 463 25420 36817 179 2391 336 58 Conoco Phillips Alaska, Inc.-Kupamk River 35-612 chemical Summary IIIIIIIIHI c. . . , . 1-b me m oms ae00e/ 0 e. Conoco Phillips Alaska, Inc - Klpamk River 3Y612 Planned Design 95 ae= m,e robs] lanm; toll -B^Clo niBn SWr OeriB^p0e Ie . m6ntea]e lin., /finml:.,/nn .1b,l-3000 mpn^r Gan].; [,1011 an 1.11) lent; aon ..%hill OWn-H ] r1 rpmm 11 mw; 0 1 Shut in 11. InW1. 111 F 30 0 3N Hwor-GJ 1� 11 l+ OA+:+6 1", Op -word FXarlrirarl 13l 11 IW .41 � 301 III I, I 1 1 19 13 tan 30 Cd 015 lW 015 � $ ShutMrao M HwerL I.3W i61 361 Im 015 090 1W 30A0 0.15 lW 015 1 6 1.X01116 1.15 988W 6B6 691 ],}W Ols zm 0,35 _ ^ 1. Nvbo,G Ilaem .110 IW 1 1,, 111 e6 399 1". IW 30.W 5 MHwarU --30/m IW e0 ... n9 16E 36.aW 30.W Iis xao I'M ' Otl NypprG am LMm Fll'b 30/10 IE9 0.15 ® 30pHworL rlaIHI-I Waell-30/10 090 I. p�IS }.WI Is 1.Hw1,G MI. 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Hw016 yW OAS 0.9J 0.35 I. x00rc m114El 011 691 ).}W all 11x1 3W.NNwrG C 0/e 1W 8. 3 49 1.. 1W 015 090 035 015 035 �,i - MHwOrG "p- H,1 I 0/JO 1W 6,W0 113 156 13.Q1 0}5 2 £ m 5 5 30tl HvbeL en fleitl wanll-3cle 11. 0:11:38 1W 011 090 0.35 E 'oma WN06r4 pr0ppeane to s. wa.se0/10 aW 10 8.� D:0538 03313 IIn ..Il 090 035 3RW 1.W 0.}5 WHw01G ".-I llJ-F He -30/40 00551 0:1'06 0.15 11 30 W 0 15 1 111 l� 309xw0iL an[laJen fl ultl Wan11-30/+0 6W 10 ],631 lI, 30.On 015 H 11 59 tlXw0r4 eSwaer&1Ba110`ep -30/10 186 1E.M0 001:93 005:16 lm Ol5 'In30pNworL I.Utl E1' 09U 30W 3.W Conoco Phillips Alaska, Inc - Klpamk River 3Y612 Planned Design 95 a53agEg c PhM ,vue.ln,. Os.A]n to lb/9^0 x. - su3sbew Xn pq r -._.- Conoco Phillips Alaska, Inc. -Kuparuk River 35612 Planned Design 96 ash 'e.teMe9ohal �nremX IaeN-'rF</ wvAaalti+e 3rcaM1nmt mval SUge xumlX. ilWa pmdrptnn Sup Dentnwaa PropryM Demdpnm pnleneClean Cana X M1mal !Mall Vfppe V(w0e gn6lue Dmign Prop VOWme olal len11 Ills) Stlge ]Me' T.e FF:mmuy en:nml:m Surl-3000 fpPl~ Cl -3l (131 VC Iwl !pal MOb) fegl ".]W rlaWlw WG -36 fpw! Ofd (ow) co,IO XIe.,01 (PNI Ipvp SP I101 bl .l' -s Pmt N 161 ... Ice" im OAS 050 D35 015 W xwne4Pre�Wm Coneilianing hf -I1Y3m 035 M 38800a 61 111. 0:1) 0:54 13 I.W d" 0se D35 3010 0.15 1.0] 035 ' 63110XyForG Preppanr Letlm Fluitl Wan11 30/IO tA] M Ila l<9 1. OWI< .1 15 W OAS 050 A35 30M o.15 30] 0.15 .i'." Proppanr Laden Iliad es'a 101.9 Ida 136 1E.� 0. 038:07 IA3 OAS 050 035 30N 0.15 lW Ol5 eQ - 65 Wea1130/10 1.W 1.1 1. .1 0:3kss SA3 le. 0.15 100 0.35 , n se G en AI eOla J. 00538 019:39 1. 035 30M 015 1. 0,15 6] 1O1c a .1. 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IOM 90 3}5 310. 0:0,:38 855 . 005 035 3000 0 S ]W 635 $Lam _ - owxwu.4 Preppantuem fmm z0n0 110 x31 0M:51 0:z3:v 100 Das 30. 0u Em ms 111 - 30XMwnrU tlaaen ilrltl 11.30/d0 600 7830 33] eJ,009 0-056 DAS 035 0.15 0.35 035 J� MHwo.G1Leeen Hina 30/e0 40 8180 113 1. 0d5 3090 015 9-10 308 WarerfeaeG Ida 0M93 09611 1. 3000 0.15 050 Fr A 0 Slml intetl la 14 0:01 es.A} 0.15 100 111 101 6nrG OMAD 0:51 0. 035 el .,Nd %emlum-10.1n .1 11 ]1. 136 1.03 015 ON 0a5 30M 015 3A3 0E5 �$ .1 6arG FWM Wm9-l0/M 1. 10 193 6= 00344 015116 035 015 3. 0.25 -Sm n" ,b.,s 1.004, Uem f -E 9-30/90 3de 0 8000 193 351 IS.IV] 0:03:51 0:31:31 1. Oe5 ON 0.35 3090 0.t5 E. 0}5 Lba 10d YHw00G %OPMm W I". I.. MI -.1. 3. 10 7090 IG1 B9 "ced OWA4 0:21]8 I. 015 090 035 50.W 015 W 035 WHyhnr4 %OpWm ladma flu. Want -20/10 0. 0 e,WO 190 215 32.gq 605:38 0:12:13 ].O3 O. 090 0. .39.00 0.15 190 035 108 3M.'0, pM Laden Rud WaaY-20/90 i.. 10 8..0 t. 1. 005:51 A. 1. 035 3000 O. tS 1. UF9 3MXwwG mlatlm fluid Want-l0/N 600 10 }3] OO5:SG 0:11:15 A0.S 0.90 0. 3O. 0 5 3Fl0 035 1610 dXpw.G %0ppnt Laden F101d Wentl.2p/N >.. 113 Ige 0:05:18 l.. 015 093 0.35 3A. 0.15 EAO 0E5 1011 3MXVM'G m88e110e0p 10 .16 O.N:36 l.. AAS 0.90 0.35 0.15 025 Conoco Phillips Alaska, Inc. -Kuparuk River 35612 Planned Design 96 F�ITITAAIN .d..l..ANI D g m O SWN.MA P RAIRuusd3Hs31?/ C.N. Phillips AaMls.,IIs. -Kuparuk 0.iver 35-612 Planned Design 97 FORMATION ...I. pnn I... waa m..... mm .1.1.1. W,a p,nnu,r IAM..Fv 0naw6re Amb^ Oe[Prdraaian F- ", )-R,1 vn wp (awl M'.) 00n9e ONm Clean lame IgMM V",`9 0.d�v (,a) u'. In rnn IT,Rle :.i n 1n5mraW0 �lawl «al Clal J1 r/.Aa) (.Fd M.6 O (dP0 '1. ron,ls wG-s 1 of eII Iwo 0µ9md IPP,) (PPu IF (Pm) 30NHV�o� 169 1W OAS 090 I. OES 11 2p Xyhor.G CwOXwnln6vao llim I.A. 6P6 OI]EO 059:036 09D 0,35 300D 0.15 20D �11 u S 30pxMoeG IO/i0^ Ids 1W Oi5 }OD _ WN'." 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Ol5 090 035 sass 0.15 1. 015 1E-3 3W HOMAI Wanll-201W SW AO ArNOR I. 2M d0.gp 095:51 013:13 SW pA5 OW A, 3].W 0.15 }W .,I 0.35 ® 12i Mat HSOnr6 -10/10 6W N I3p4 pp5:56 016:. 11M aa5 090 035 W,W 0.15 1. 15 OES 124 30p .0""`1 -Fluid Fall 20/10 >W lis IM 12." RW:55 IDs OIS OAR) 30M 015 }p3 015 0,50 W4ehnoG 10 13D O:pS;}e 0.06;19 M90 p,11 2W 015 p.50 Il Il30Y S' eR 30 O:C0:15 OW:aS ICW W S6uLln C.N. Phillips AaMls.,IIs. -Kuparuk 0.iver 35-612 Planned Design 97 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35612 Date: 12/17/2018 Formation: Moraine SC#: 905321854 DaV: DFIT-Zone 3 Conoco Phillips Alaska,Inc.-Kuparuk Rivera -612 Water Straps -DFIT-Zone3 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (*F) Inches Gallons Barrels 1 Wichita CPF3 100 20,160 480 113 12 2,268 54 2 Wichita CPF3 100 20,160 480 119 12 2,268 54 3 Wichita CPF3 100 20,160 480 103 12 2,268 54 4 Atigan CPF3 105 19,755 470 101 9 1,262 30 5 Atigan CPF3 106 19,949 475 94 9 1,262 30 6 Atigan CPF3 106 19,949 475 103 9 1,262 30 7 Atigan CPF3 105 19,755 470 112 9 1,262 30 8 Atigan CPF3 105 19,755 470 98 9 1,262 30 9 Atigan CPF3 106 19,949 475 99 9 1,262 30 10 Wichita CPF3 102 20,580 490 102 12 2,268 54 11 Atigan CPF3 105 19,755 470 110 9 1,262 30 12 Atigan CPF3 106 19,949 475 100 108 20,336 484 13 Atigan CPF3 106 19,949 475 106 89 16,660 397 14 Atigan CPF3 105 19,755 470 110 87 16,273 387 15 Wichita CPF3 102 20,580 490 104 98 19,740 470 16 Atigan CPF3 105 19,755 470 100 105 19,755 470 17 Wichita CPF3 102 20,580 490 103 99 19,950 475 18 Atigan CPF3 105 19,755 470 103 104 19,562 466 19 Atigan CPF3 105 19,755 470 104 57 10,367 247 20 Atigan CP 105 19,755 470 117 56 10,159 242 21 Atigan CPF3 105 19,755 470 97 9 1,262 30 22 Atigan CPF3 107 20,142 480 106 9 1,262 30 23 Atigan CPF3 108 20,336 484 117 9 1,262 30 24 Atigan CPF3 109 20,529 489 112 9 1,26230 25 Atigan CPF3 109 20,529 489 111 11 1,627 39 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons I Barrels Gallons Barrels 501,050 11,930 177,384 1 4,223 323,665 7,706 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 810 2 445 2 3,450 7 339 3 5,590 12 254 4 8,000 17 157 5 0 477 6 0 477 7 0 477 Conoco Phillips Alaska,Inc.-Kuparuk Rivera -612 Water Straps -DFIT-Zone3 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35612 Date: 12/20/2018 Formation: Moraine SC#: 905321854 Dav: Zone 4 - Zone 6 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Water Straps - Zones 4-6 99 General Beginning Strap Ending Strap Tank Type Source Inches Gal BBL Temp (°F) Inches Gal BBL 1 Wichita CPF3 100 20,160 480 109 16 3,024 72 2 Wichita CPF3 101 20,370 485 111 17 3,213 77 3 Wichita CPF3 100 20,160 480 112 76 15,120 360 4 Atigan CPF3 105 19,755 470 105 89 16,660 397 5 Atigan CPF3 93 17,434 415 99 76 14,146 337 6 Atigan CPF3 110 20,722 493 109 109 20,529 489 7 Atigan CPF3 106 19,949 475 107 106 19,949 475 8 Atigan CPF3 103 19,368 461 116 102 19,175 457 9 Atigan CPF3 103 19,368 461 99 94 17,627 420 10 Wichita CPF3 100 20,160 480 117 30 5,670 135 11 Atigan CPF3 105 19,755 470 125 32 5,460 130 12 Atigan CPF3 105 19,755 470 87 9 1,262 30 13 Atigan CPF3 107 20,142 480 115 91 17,047 406 14 Atigan CPF3 107 20,142 480 109 83 15,500 369 15 Wichita CPF3 100 20,160 480 91 41 7,802 186 16 Atigan CPF3 105 19,755 470 85 25 4,182 100 17 Wichita CPF3 102 20,580 490 90 17 3,213 77 18 Atigan CPF3 102 19,175 457 88 23 4,000 95 19 Atigan CPF3 103 19,368 461 113 23 4,000 95 20 Atigan CPF3 104 19,562 466 124 9 1,262 30 21 Atigan CPF3 103 19,368 461 103 9 1,262 30 22 Atigan CPF3 105 19,755 470 127 9 1,262 30 23 Atigan CPF3 97 18,208 434 113 9 1,262 30 24 Atigan CPF3 104 19,562 466 113 9 1,262 30 25 Ati an CPF3 105 19,755 470 110 9 1,262 30 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 492,488 11,726 205,149 4,885 287,339 6,841 Pre -Job Barrel Bottoms Volume Zones: Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 2,412 5 373 2 4,551 10 287 3 6,961 15 191 4 0 469 5 0 469 6 0 469 7 0 469 Conoco Phillips Alaska, Inc. - Kuparuk River 35-612 Water Straps - Zones 4-6 99 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 3S-612 Date: 12/23/2018 Formation: Moraine SO#: 905321854 Dav: Zone 7 - Zone 9 Conoco Phillips Naska, Inc. - Kuparuk River 35-612 Water Straps - Zones 7-9 100 General Beginning Strap Ending Strap Tank Type Source Inches Gal BBL Temp (°F) Inches Gal BBL 1 Wichita CPF3 98 19,740 470 105 12 2,268 54 2 Wichita CPF3 98 19,740 470 108 13 2,457 59 3 Wichita CPF3 99 19,950 475 109 14 2,646 63 4 Atigan CPF3 101 18,981 452 100 9 1,262 30 5 Atigan CPF3 106 19,949 475 98 9 1,262 30 6 Atigan CPF3 104 19,562 466 104 9 1,262 30 7 Atigan CPF3 103 19,368 461 100 9 1,262 30 8 Atigan CPF3 104 19,562 466 105 9 1,262 30 9 Atigan CPF3 101 18,981 452 94 10 1,444 34 10 Wichita CPF3 95 19,110 455 94 9 1,701 41 11 Atigan CPF3 101 18,981 452 96 9 1,262 30 12 Atigan CPF3 104 19,562 466 94 60 10,992 262 13 Atigan CPF3 102 19,175 457 105 90 16,854 401 14 Atigan CPF3 106 19,949 475 107 99 18,595 443 15 Wichita CPF3 99 19,950 475 99 97 19,530 465 16 Atigan CPF3 105 19,755 470 94 106 19,949 475 17 Wichita CPF3 102 20,580 490 85 18 336 8 18 Atigan CPF3 105 19,755 470 99 106 19,949 475 19 Atigan CPF3 104 19,562 466 101 106 19,949 475 20 Atigan CPF3 105 19,755 470 97 104 19,562 466 21 Atigan CPF3 106 19,949 475 98 106 19,949 475 22 Atigan CPF3 104 19,562 466 93 98 18,401 438 23 Atigan CPF3 109 20,529 489 138 31 5,277 126 24 Atigan CPF3 104 19,562 466 87 9 1,262 30 25 Atigan CPF3 105 19,755 470 99 9 1,262 30 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons I Barrels GallonsBarrels 491,322 11,698 209,954 4,999 281,368 6,699 Pre -Job Barrel Bottoms Volume Zones: Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 2,412 5 371 2 4,550 10 286 3 6,907 15 192 4 0 468 5 0 468 6 0 468 7 0 468 Conoco Phillips Naska, Inc. - Kuparuk River 35-612 Water Straps - Zones 7-9 100 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35-612 Date: 12/27/2018 Formation: Moraine SON: 905321854 Day: Zone 10 - Zone 12 Conoco Phillips Alaska, Im.- Kuparuk River 35-612 Water Straps - Zones 10-12 101 General Beginning Strap Ending Strap Tank Type Source Inches Gal BBL Temp ('F) Inches Gal BBL 1 Wichita CPF3 0 2 Wichita CPF3 0 3 Wichita CPF3 0 4 Atigan CPF3 99 18,595 443 102 0 5 Atigan CPF3 99 18,595 443 96 0 6 Atigan CPF3 103 19,368 461 106 0 7 Atigan CPF3 108 20,336 484 80 0 8 Atigan CPF3 99 18,595 443 101 0 9 Atigan CPF3 99 18,595 443 94 0 10 Wichita CPF3 99 19,950 475 101 0 11 Atigan CPF3 104 19,562 466 99 0 12 Atigan CPF3 103 19,368 461 97 0 13 Atigan CPF3 99 18,595 443 99 0 14 Atigan CPF3 98 18,401 438 91 0 15 Wichita CPF3 99 19,950 475 80 0 16 Atigan CPF3 104 19,562 466 71 0 17 Wichita CPF3 0 18 Atigan CPF3 104 19,562 466 76 0 19 Atigan CPF3 103 19,368 461 80 0 20 Atigan CPF3 103 19,368 461 80 0 21 Atigan CPF3 104 19,562 466 77 0 22 Atigan CPF3 98 18,401 438 70 0 23 Atigan CPF3 98 18,401 438 64 0 24 Atigan CPF3 0 25 Atigan CPF3 0 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 364,131 1 8,670 0 0 364,131 8,670 Pre -Job Barrel Bottoms Volume Zones: Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 2,163 5 342 2 4,302 9 230 3 6,645 35 107 4 0 456 5 0 456 6 0 456 7 0 456 Conoco Phillips Alaska, Im.- Kuparuk River 35-612 Water Straps - Zones 10-12 101 Specific Gravity PH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity Crosslink pH C.,r1ink Test (Y/N) I Ir.;,. Tnn41 Tnn4> T..-,4 T.. -,r --T. HALLIBURTON 1.026 ALASKA DISTRICT FIELD LABORATORY 1.024 WATER ANALYSIS REPORT Company. ConocoPhi0ips Alaska, Inc. Minifeac-Zone3 Well Name/No.: 35412 Date Tested December 16, 2018 Water Tvoe: Seawater Specific Gravity PH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity Crosslink pH C.,r1ink Test (Y/N) I Ir.;,. Tnn41 Tnn4> T..-,4 T.. -,r --T. Unita Taut 10 Taut Il Tank 12 Tunic U Tank 14 Tank 15 Tank 16 Tauc 17 Tank 18 Specific Gravity PH Iron (Fe) Chloride (CI) Sufate (SO4) Calcium (Ca) Hardness Linear Viscosity Crer sfink pH C.Wiuc Test (Y/N) 1.024 1.026 1.026 1.024 1.026 1.0260 1.0260 1,0260 1.0260 7.61 7.54 7.58 7.61 7.61 7.71 7.65 7.7 7.57 7.56 . /L 0 0 0 0 0 0 0 0 0 . /L 18000 17600 18200 17600 17800 186M 18400 18200 184M m /L 1200 800 1200 800 No 800 1200 800 800 m../L 760.00 840.00 960.00 720.0 840.00 920.00 960.00 960.00 800.00 m /L 2880 2720 2560 2280 2200 2400 2280 2520 28M ep 31 32 31 31 29 30 32 32 31 H 9.85 9.91 9.78 10.2 9.99 10.11 10.12 9.87 10.01 Y Y Y Y Y Y Y Y V Unita Taut 10 Taut Il Tank 12 Tunic U Tank 14 Tank 15 Tank 16 Tauc 17 Tank 18 Specific Gravity PH Iron (Fe) Chloride (CI) Sufate (SO4) Calcium (Ca) Hardness Linear Viscosity Crer sfink pH C.Wiuc Test (Y/N) Urate Tank 19 Taut 20 Tank 21 Tank 22 Tank 23 Tank Tauc25 Specific Gravity PH 1. (Fe) Chloride (CI) Suface (5(34) C.1d. (Ca) Hardness Linear Viscosity Crossliuc pH Croasliut Test (Y/N) L0260 L0240 1.0260 1.0240 1.0260 1.0240 1.0240 L025 1.026 7.61 7.0 7.54 7.49 7.65 7.7 7.6 7.55 7.64 7.62 m /L 0 0 0 0 0 0 0 0 0 un/L 17600 H2O0 17800 17600 174N 16400 18000 16800 172M . /L 800 800 1200 800 1200 1200 1200 800 800 . /L 960.00 360.00 840.00 720.00 720.00 1720.0 1720.00 800.00 680.00 /L 250 2360 2720 2600 2320 2840 3320 2200 2240 tit 29 30 32 M 31 29 31 30 28 H 9.89 9.99 9.81 10.1 10.05 9.81 9.9 10.02 10.01 Y Y Y Y Y Y Y Y Y Urate Tank 19 Taut 20 Tank 21 Tank 22 Tank 23 Tank Tauc25 Specific Gravity PH 1. (Fe) Chloride (CI) Suface (5(34) C.1d. (Ca) Hardness Linear Viscosity Crossliuc pH Croasliut Test (Y/N) hIwvvru16v ryrpem- NHalbOumnaelviw wW.iY itmra aa-lrr, pylllvwtmry Le%EIisIM orNxlasW vvitlnw.rectum¢Yree,,PrevsuriPm apprwalat4Eomury m-,-11, eo-.InI rn w-ofm,Avbwianopuauow bYam Pmaal«upcemm mPlmtev Ilmrofws lu vwu rryon even HeI re aevien. NOTICE: lLu rePoa iv timi1W mNe@oenbol mmpk ua1 MY uxrofNiv mpona®ev NUHallibwonvM1allm M 4nEle forany kv v �mape. ufiMer Jue bularamissim rcWlinq fimn secM1repanmia Cenom PMIIIs.l11,Inc-1u1-Y aIrwdr M-".- 3 1. 1.026 1.0% 1.026 1.024 1.024 1.026 1.026 7.56 7.61 7.62 7.69 7.67 7.65 7.58 ca/L 0 0 0 0 0 0 0 /L 17400 172M 17400 16400 1700 17600 17400 /L 800 1200 1200 1200 800 800 800 . /L 760.00 920.00 800.00 760.00 760.00 720.00 680.00 m /L MW 2240 2400 2400 2000 2240 2320 30 32 28 31 30 M 31 H 10.05 9.85 9.82 9.81 10.12 10.11 10.1 Y Y Y Y Y Y Y hIwvvru16v ryrpem- NHalbOumnaelviw wW.iY itmra aa-lrr, pylllvwtmry Le%EIisIM orNxlasW vvitlnw.rectum¢Yree,,PrevsuriPm apprwalat4Eomury m-,-11, eo-.InI rn w-ofm,Avbwianopuauow bYam Pmaal«upcemm mPlmtev Ilmrofws lu vwu rryon even HeI re aevien. NOTICE: lLu rePoa iv timi1W mNe@oenbol mmpk ua1 MY uxrofNiv mpona®ev NUHallibwonvM1allm M 4nEle forany kv v �mape. ufiMer Jue bularamissim rcWlinq fimn secM1repanmia Cenom PMIIIs.l11,Inc-1u1-Y aIrwdr M-".- 3 1. HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: Co nocoPhillipa Alaska, Inc. Zones 4-6 Well Name/No.: 35612 Date Tested: December 19, 2018 Water Type: Seawater Units Tank 1 Tank 2 Tank 3 Tank 4 Tank 5 Tardt 6 Tank 7 Toads 8 Tank 9 Specific Gravity PH Iron (Fe) Chloride (CI) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity CrosskNk pH Crossliulk Test (Y/N) Specific Gravity PH Iron (Fe) Chloride (q) S.Vate (SO4) Calcium (Ca) Hardness Linear Viscosity CrosslinlrpH Crosslklk Test (Y/N) Units Tank 10 Tack 11 Tank 12 Tank 13 Tank 14 Tank 15 Tex.k 16 Tn.h la Ta.h IA 1.024 1.022 1.026 1.025 Loo 1.0220 1.0220 1.0180 1.0220 - 7.1 7.21 7.63 7.4 7.47 7.24 7.31 7.36 7.15 .9/L 0 0 0 0 0 0 0 0 0 mg/L 18600 17800 20000 17800 19000 18000 18000 18400 18200 n,/L 800 1200 800 800 1200 800 800 800 800 /L 600 800 760 480 1280 880 1160 12M1 720 mg/L 2680 2720 2720 2320 2440 2560 2480 2240 2280 cp 26 28 27 27 26 28 25 25 26 PH 9.43 9.7 9.45 9.75 9.53 9.79 9.41 9.32 9.65 Y Y Y Y Y Y Y Y Y Units Tank 10 Tack 11 Tank 12 Tank 13 Tank 14 Tank 15 Tex.k 16 Tn.h la Ta.h IA Units Tank 19 Tank 20 Tank 21 Tank 22 Tank 21 Tank 24 Tank n Specific Gravity PH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calchmn (Ca) Hardness linear Viscosity Crossllyds pH Crosslink Test (Y/N) 1.0200 1.0240 1.0240 1.0260 L0260 1.0260 1.0260 1.026 L026 - 7.1 7 7 7 7 7 7 7.5 7.42 .9/1, 0 0 0 0 0 0 0 0 0 mg/L 18800 18400 18600 18400 18800 18600 18400 17800 18400 mg/L 800 16N 1200 800 800 800 800 800 1200 /L 920 1080 1960 1920 1840 UN 880 1280 1040 mg/L 2440 2240 moo 2560 2360 2240 2640 2400 2480 cp 27 31 31 31 30 30 30 30 31 H 9.91 9.5 9 9 9 8.9 9.27 9.1 9.38 Y Y Y Y Y Y Y Y Y Units Tank 19 Tank 20 Tank 21 Tank 22 Tank 21 Tank 24 Tank n Specific Gravity PH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calchmn (Ca) Hardness linear Viscosity Crossllyds pH Crosslink Test (Y/N) mmrea«krima PreP«gaxpuibamn km.«aam ®am a npram wn u.rew�nrkwrabrk�rmarbe Pnbb.bm W mMl«w w;awenl reaama �6k«anaaa.,;naoavw��larlpb«pmoma�aexmxm. a mar M1m,a.er. x as in ma ewr: prreawn bam«k operaema m may Pe<.an o..w,oe,n bm m,vlora«uaanr r«.i.,�y men aaPnn rmm xaum�mrea san;r«. Nrnrlm lTix regnia4miled b Ibe JexnEM amOb leaba. Myuwor JtiSrePonapnes WlNeltibwbneM11 re1M liable yam bss mavmige. WxJirrdue b moxomiaiay r«Wli� fiom embrcpona i6 we. Conxe PM1ltlips Rlaxke.Inc. Nuparvk Riaer3S613 Watnpnalyxlx-E nn46 103 1.026 1.026 1.026 1.026 1.026 1.026 1.026 7.46 7.32 7.33 7.41 7.37 7.40 7.31 mg/L 0 0 0 0 0 0 0 /L 18600 18600 18400 18600 18600 19200 18200 /L 800 800 800 800 800 800 800 mg/L 1040 1080 1320 1680 1080 1600 2080 ,ng/L 2600 2440 2680 2600 2480 2480 2800 eP 30 29 31 30 31 30 30 H 9.12 9.26 9.08 9.23 9.1 939 9.16 Y Y Y Y Y Y Y mmrea«krima PreP«gaxpuibamn km.«aam ®am a npram wn u.rew�nrkwrabrk�rmarbe Pnbb.bm W mMl«w w;awenl reaama �6k«anaaa.,;naoavw��larlpb«pmoma�aexmxm. a mar M1m,a.er. x as in ma ewr: prreawn bam«k operaema m may Pe<.an o..w,oe,n bm m,vlora«uaanr r«.i.,�y men aaPnn rmm xaum�mrea san;r«. Nrnrlm lTix regnia4miled b Ibe JexnEM amOb leaba. Myuwor JtiSrePonapnes WlNeltibwbneM11 re1M liable yam bss mavmige. WxJirrdue b moxomiaiay r«Wli� fiom embrcpona i6 we. Conxe PM1ltlips Rlaxke.Inc. Nuparvk Riaer3S613 Watnpnalyxlx-E nn46 103 HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: ConocoMflips Alaska, Inc. Zones 7-9 Well Name/No.: 3S -6t2 Date Tested: December 22, MIS Water Type: Seawater Specific Garvin PF Iron (Fe Chloride (CI Sulfate (5134' Calciton (Ca: Hardness Linear Viscosity ConalinkpF Crosskrdr Test(Y/N I lni,e Tnn41 Tun4I T -n4 Tan4d Tan.I Tan4l. Tan4'r, Tan4a T-1. Units Tank 10 Tardr 11 Took 12 Tank 13 Tank 14 Tank 15 Tarek 16 Tank 17 Tank 18 Specific Gravity PH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calcium (Ca) Hardness LinearViscosity Crosshnk pH C.,Hnk Test (Y/N) LN6 1.024 1026 1.026 1.026 L0260 1.0260 1.0260 1.0250 7.2 6.8 6.9 7.2 7.1 7.4 7.2 7.2 7.2 7.3 mg/L 0 0 0 0 0 0 0 0 0 mg/L 19,600 18,800 18,800 18,600 18,600 19,600 19,2110 18,800 19,200 mg/L 800 800 800 800 800 800 800 800 800 /L 2280 2120 1720 1160 1920 1240 1010 1240 1440 /L 2,280 2,240 2,480 2,720 2,400 2,520 2,480 2,720 2,760 tP 31 31 31 32 30 30 31 31 31 H 8.9 9.0 8.8 8.9 8.8 8.9 8.9 8.8 8.8 Y Y Y Y Y Y Y Y Y Units Tank 10 Tardr 11 Took 12 Tank 13 Tank 14 Tank 15 Tarek 16 Tank 17 Tank 18 Specific Gravity PH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calcium (Ca) Hardness LinearViscosity Crosshnk pH C.,Hnk Test (Y/N) Units Tank 19 Tank 20 Took 21 Tank 22 Tank 23 Tank N Tank Ti Specific Gravity PH Iron (Fe) Chloride (CI) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity CmsstlnkpH Crosslink Test (Y/N) t I 1 1 1 1 I I 1 7.2 6.8 6.9 7.2 7.1 7.4 7.2 7.2 7.2 13 mg/L 0 0 0 0 0 0 0 0 0 mg/L 19,600 18,800 18,800 18,600 18,600 19,600 19,200 18,800 19,200 mg/L 800 800 800 800 800 800 Soo 800 800 mg/1. 2280 2120 1720 1160 1920 1240 1040 1240 1440 na/L 2,280 2,240 2,480 2,720 2,400 2,520 2,480 2,720 2,760 85 31 31 31 32 30 30 31 31 31 PH 8.9 9.0 8.8 8.9 8.8 8.9 8.9 8.8 8.8 Y Y Y Y Y Y Y Y Y Units Tank 19 Tank 20 Took 21 Tank 22 Tank 23 Tank N Tank Ti Specific Gravity PH Iron (Fe) Chloride (CI) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity CmsstlnkpH Crosslink Test (Y/N) iltie rcpon i„IepopMYolNaNbwmrmiuzmgrciNer itwampM Yer<olna ecpylMmfmvyMpubluMJw JiwlnsW xiNout li,v stewing lLeuy„sxxaalenapp,aW oflabmamynw,geoim. II mw Mxeaa. M uN in Ne wmx of rt8ular b,uineas opsaucm by ens' prawn u cmcem arA emplgm tMe W ,e,eie vuig sucp repo, hm, HaYibwm Smico. NMICQ: thurtp u WwW w Jit Jaen mmple Cr M-uofdasrtp_n flWc dot191tibu, near ml W MbW fim9 bv«Jmuge,wMWSJue w-mmisme ail c,as auchre ,e de - Canon pbillipr M,a ,Inc-Y.upamk RMrM422 Wa4r A-iy r-2enn 2.9 nu 1 l 1 I 1 I 1 6.9 7.2 7.1 7.1 7.0 7.1 7.1 an/L 0 0 0 0 0 0 0 mg/L 18,000 I8,o a, 17,600 19,200 18,400 19,600 17,200 m9/L 800 800 800 1,200 1,200 1,200 1,200 m /L 2200 1840 2160 2480 2480 2520 23M mg/L 2,320 2,320 2,600 2,560 2,480 2,520 2,520 c'P m 32 30 30 31 31 32 H 8.9 8.9 8.9 8.9 8.7 85 8.7 Y Y Y Y Y Y Y iltie rcpon i„IepopMYolNaNbwmrmiuzmgrciNer itwampM Yer<olna ecpylMmfmvyMpubluMJw JiwlnsW xiNout li,v stewing lLeuy„sxxaalenapp,aW oflabmamynw,geoim. II mw Mxeaa. M uN in Ne wmx of rt8ular b,uineas opsaucm by ens' prawn u cmcem arA emplgm tMe W ,e,eie vuig sucp repo, hm, HaYibwm Smico. NMICQ: thurtp u WwW w Jit Jaen mmple Cr M-uofdasrtp_n flWc dot191tibu, near ml W MbW fim9 bv«Jmuge,wMWSJue w-mmisme ail c,as auchre ,e de - Canon pbillipr M,a ,Inc-Y.upamk RMrM422 Wa4r A-iy r-2enn 2.9 nu HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company. C ... Phillips Alaska, Ie. Zonesl0-12 Well Name/No.: 3S-612 Date Tested: December 24, 2018 Water Type: Seawater Units Tatar 1 Tank 2 Tank 3 Tank 4 Tank 5 Tank 6 Tatar 7 TaWc 8 Tank 9 Specific Gmvin Pi Iron (Fe Chloride (CI; SWfate (SO4; Calcium (Ca Hardness Linear Viswsip CrossliW pH Croasfink Test (Y/N, Specific Gravity PH Iron (Fe; Chloride (0) SWfate (SO4) Calcium (Ca) Hardnem Linear Viscoslq C.IiI r pH CmssliW Tem (Y/M Specific Gmvi y PH Iron (Fe) CNoride (Cl) Sulfate (S(4) Calcium (Ca) Hardness Linear Viscosity CrossflnkpH Cmssfink Test (Y/N) N/A N/A N/A 1.026 Lon 1.0270 1.0260 1.0280 LU80 1.0280 N/A 7.2 7.1 7.4 7.4 7.5 7.3 mg/l, 0 0 0 0 0 0 mg/L 19600 18800 18800 18800 18800 19200 m9/1, 800 800 1200 800 800 800 mg/L 2070 1920 2080 2480 2480 2480 mg/L 2520 2480 2520 2600 2480 2560 Cp 30 31 31 30 31 32 pH 8.8 8.9 8.8 9.1 9.1 9 IF Y Y Y 30 33 32 Ilnhe Tank IA Tank 1t Tank 12 Tank 11 Tnnk U Tnnk 15 Tank 16 Tnnk 17 Tank IN - 1.0260 1.027 1.0280 Lomo LM80 1.0270 1.0280 N/A L028 7.3 7.3 7.3 7.2 7.6 7.4 73 7.3 7.3 mg/1. 0 0 0 0 0 0 0 0 m9/1, 19200 1%00 19600 19200 18800 19200 0800 19200 /L 1200 800 moo mo 800 800 Soo 800 mg/L 2440 2240 1920 2200 1600 2000 2320 1840 /L 2480 2560 2520 2600 2400 2520 2400 2400 IF 31 31 31 30 33 32 32 33 PH 8.7 8.7 8.8 8.9 8.9 8.7 8.9 9 Y y Y Y Y y y Y Tlnnc Tonk 10 Tnnkln Tank 21 Tank 97 Tank %.; TnnkU Tank 25 TM1ivrtpoa ix Ne poperryofHo1,In-d i. MmiWn ilmrxv b.,.-.,. .,.-.EepublWetl tt pl, wiYmf- ,-Ye eapmx Mflfi pmu w.Mnarymem8emms Ix mev Wxever, be -d i. We waxofrtgWwbusircuopwatlwebY ertipnwnwnarsem oM emplayea Nmmfrtceixi�g rlxM1 report fimm Halllbunm Rn'kes. NOTICE:T rcputis Iimi1WwJsdnavibWmmpkus .PVYvsx*oflF'swp:n vgas Jmt HW46ww vlmll notMIwbk fwurylossw&mvee, xvFMer Jue ioanoromasirn,raW�ioB fiom xmM1rerynw Canom Milllq Rlada, Inc XUWmk Rarver3S613 Water Analysb 3onnl613 105 1.026 L026 L028 1.028 1 1.028 L028 N/A 7.4 7.3 7.3 7.4 7.1 7.30 mg/L 0 0 0 0 0 0 mg/L 18400 17600 19200 19200 19200 20800 mg/L 800 1200 1200 1200 1200 800 m /L moo 1840 2160 2320 2280 2280 . /L 2320 2320 2600 264D 2400 2280 cP m 32 32 31 31 31 H 9.1 8.8 8.8 8.9 9 8.7 Y Y Y Y Y Y TM1ivrtpoa ix Ne poperryofHo1,In-d i. MmiWn ilmrxv b.,.-.,. .,.-.EepublWetl tt pl, wiYmf- ,-Ye eapmx Mflfi pmu w.Mnarymem8emms Ix mev Wxever, be -d i. We waxofrtgWwbusircuopwatlwebY ertipnwnwnarsem oM emplayea Nmmfrtceixi�g rlxM1 report fimm Halllbunm Rn'kes. NOTICE:T rcputis Iimi1WwJsdnavibWmmpkus .PVYvsx*oflF'swp:n vgas Jmt HW46ww vlmll notMIwbk fwurylossw&mvee, xvFMer Jue ioanoromasirn,raW�ioB fiom xmM1rerynw Canom Milllq Rlada, Inc XUWmk Rarver3S613 Water Analysb 3onnl613 105 HALLIBUF TON Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 612 Date: December 17, 2018 Interval Stage Visc pH Ternp °F XL pH Comments 1 Mini -Frac 28 73 10.1 Pad 74 0.25 25 74 9.9 1# 23 78 9.8 2# 1 25 1 80 9.4 3# 25 79 9.3 4# 25 77 9.3 5# 24 75 9.3 2 Pad 0.25 25 78 9.3 1# 25 86 9.1 2# 30 1 1 88 9.1 3# 27 80 9.5 4# 25 78 9.4 5# 25 74 9.4 6# 27 74 9.4 7# 25 74 9.4 3 Pad 0.25 25 78 9.5 1# 25 86 9.3 2# 25 74 9.4 3# 25 74 9.4 4# 25 74 9.4 5# 25 74 9.5 6#25 74 9.4 7# 25 74 9.3 Conoco Phillips Alaska,Inc. - Kuparuk River 35-612 Real -Time QC -Zones 1-3 10b In' FA 11011 = MIN it■ Customer: conocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 612 Date: December 20, 2018 Interval Stage Vise Temp T XL pH Comments 4 Pad 28 85 9.5 0.25 23 82 9.7 14 25 90 9.7 2# 26 92 9.5 3# 28 90 9.5 4# 28 82 9.7 54 28 84 9.7 6# 28 84 9.7 74 28 84 9.7 5 Pad 0.25 28 80 9.5 1# 28 80 9.7 2# 1 28 84 9.7 3# 28 84 1 9.8 4# 27 90 9.8 5# 28 90 9.3 69 26 90 9.7 79 26 90 9.8 6 Pad 0.25 25 78 9.5 1# 30 80 9.4 24 30 80 9.3 3# 30 84 9.3 4# 30 84 93 5# 29 84 9.7 6# 27 82 9.5 7# 1 28 78 9.6 Conoco Phillips Alaska,Inc.-Kuparuk River 3S-612 Real -Time QC -Zones 4-6 107 Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 612 Date: December 23, 2018 Interval Stage Vise Temp °F XL pH Comments 7 Pad 0.25 33 72 9.2 1# 22 80 9.4 2# 24 80 9.5 3# 24 80 9.4 4# 26 72 9.4 5# 30 72 9.5 6# 30 72 9.4 7# 30 74 9.4 8 Pad 0.25 27 83 9.3 1# 29 84 9.3 2# 29 84 9.4 3# 25 72 9.3 4# 37 72 9.3 High visc due to blowing off gel into ADP 5# 30 70 9.3 6# 1 30 70 9.3 7# 30 72 9.3 9 Pad 0.25 30 82 9.2 1# 29 72 9.3 2# 31 72 9.5 3# 30 72 9.5 4# 30 74 9.4 5# 30 74 9.5 6# 28 78 9.4 7# 29 1 78 1 9.4 Conoco Phillips Alaska,Inc. - Kuparuk River 35-612 Real -Time QC -tones 7-9 108 HALL1BUFITC]N Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 612 Date: December 27, 2018 Interval Stage Vise Temp °F XL pH Comments 10 Pad 0.25# 29 78 9.5 1# 30 82 9.3 2# 30 82 9.3 39 30 80 1 9.4 4# 30 75 9.3 5# 33 80 9.3 6# 31 80 9.4 7# 31 75 9.3 11 Pad 0.25# 1 31 75 9.3 1# 30 80 9.2 2# 30 78 9.2 3# 50 78 9.2 High vise due to blowing off gel 4# 50 74 9.2 5# 40 74 9.4 6# 35 74 9.3 7# 30 72 9.3 12 Pad 0.25# 35 62 9.2 1# 27 62 9.3 2# 27 62 9.3 3# 28 60 9.5 4# 28 62 9.3 5# 30 223 6# 30 62 9.4 7# 28 62 9.4 Conoco Phillips Alaska,Inc. - Kuparuk River 35-612 Real -Time QC -Zones 10-12 109 HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Co.": CoaocoPJil6ps Alaska, Inc. Project Number Alioirme-Z.3 Wcu Name/No.: 35-612 Dam Tes¢d: December 17, 2018 Were, Type: Sea swear Sample lD Room temp Reaction time Analytical Blank Value Sample Volume filtered Dilution Multiplier Sample Analysis value BQ vaWe (de C) (min( (FUJI (mil Nneeded (FLU) Calculated Tank 15.60 30 38 50 1 2219 9524 Tank 15.60 30 43 50 1 7203 31269 Tank3 15.60 30 41 50 1 6361 27602 Tank4 15.60 30 37 50 1 10066 43798 Tank 15.60 30 41 50 1 8947 38892 Tank 15.60 30 41 50 1 39325 171557 Tank T 15.60 30 31 50 1 4997 21685 Tank 8 15.60 1 30 42 50 1 1 13910 60563 Tank 15.60 30 41 50 10525 45786 Tank 10 15.60 30 37 50 14248 62063 Tank 11 15.60 30 37 50 15932 69413 Tank 12 15.60 30 44 50 66351 289570 Tank 13 15.60 30 31 50 29531 128828 Tank 14 15.60 30 38 50 ii 23065 100562 Tank 15 15.045 37 50 25118 73019 Tank 16 ISM 30 41 50 34382 149972 Tank 17 15.60 30 37 50 5368 23283 Tank 18 15.60 30 37 50 3022 13037 Tank 19 15.60 30 42 50 1 2808 12078 Tank20 15.60 30 36 50 1 1541 6571 Tank21 15.60 30 43 50 1 69548 281701 Tank 22 15.60 30 37 50 1 16408 71493 Tank 23 15.60 30 27 50 1 W74 26409 Tank 24 15.60 30 42 50 1 12729 55405 Tank 25 15.60 30 37 50 1 7580 32957 .r—toisrs on., ln[.-Ruparu4 a., 35.12 ... Tatty-uF", n 110 Compan, Well Name/No.: Waar Type: HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT ConocoPbil4pa Alaska, Inc. Project Number Zone 4- Zoae 6 35 12 Dace Tesred: December 19, 2018 Sea mar SamplelD Room temp Reaction time Analytical Blank Value Sample Volume filtered Dilution Multiplier Sample Analysis value Bp value (de C) (min) (FLU) (ml) Rneeded (FWI Calculated Tank 15.60 30 41 36 1 4035 24224 Tank2 15.60 30 41 20 1 3085 33232 Tank 15.60 30 41 20 1 6773 73496 Tank 15.60 30 41 60 1 4457 16071 Tanks 15.60 30 41 60 1 12804 46448 Tank6 15.60 30 41 60 1 10582 38361 Tank 7 15.60 30 41 60 1 2310 8257 Tank6 1 15.60 1 30 41 60 1 2088 7449 Tank 1 15.60 30 41 60 1 1528 5,111 Tank 10 15.60 30 41 60 1 629.7 2142 Tank 11 15.60 30 40 60 1 419.1 1379 Tank 12 15.60 30 40 60 1 9746 35322 Tank 13 15.60 30 40 60 1 32150 116856 Tank 14 15.60 30 40 60 1 1884 6711 Tank 15 15.60 30 40 60 1 12211 44293 Tank 16 15.60 34 42 fi0 1 13463 43095 Tank 17 15.60 34 42 60 1 1868 $863 Tank 18 15.60 34 42 60 1 323 901 Tank 19 15.60 34 42 60 1 509.3 1500 Tank 20 15.60 34 42 60 1 543.3 1609 Tank 21 15.60 37 37 60 1 46947 138419 Tank 22 15.60 37 37 60 1 1457 4190 Tank 23 15.60 37 37 60 1 1422 4087 Tank 24 15.60 37 37 60 1 5628 16497 Tank25 15.60 37 37 60 1 2130 6176 G--IN"n gYska.lrc.-Kupnk.... 613 1--T-, 1-111 111 HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: Conoer,Phillips Alaska,Fnc. Project Number Zone7-Zone9 Well Nem./No.: 35-612 Do. Tesmd: Dezember 22, 2018 Were, Type: Sea weer SamplelD Room temp Reaction time Analytkal Blank Value Sample Volume filtered Dilution Multiplier Sample Ana1ya4 value BQ value (degC( (min( (FLU( (ml( iFneeded (FLU( Calculated Tank 15.60 30 38 W 1 2069 2390 Tank 15.60 30 38 60 1 2419 8663 Tank3 15.60 30 38 60 1 4907 12218 Tan1,4 1560 30 38 60 1 3090 LILTS Tanks 15.60 30 38 60 1 2828 28348 Tank6 15.60 30 40 60 1 8238 29834 Tank 7 15.60 30 40 60 1 2052 25536 Tank 8 1 15.60 1 30 40 60 1 1251 6226 Tank 15.60 30 40 W 1 3462 12471 Tank 10 15.60 30 40 60 1 1825 6622 Tank 11 15.60 30 43 60 1 2080 2413 Tank 12 15.60 30 43 60 1 2103 25693 Tank 33 15.60 30 43 60 1 4560 16439 Tank 14 15.60 30 43 60 1 3002 10787 Tank 15 15.60 30 43 60 1 1782 6329 Tank 16 15.60 34 40 60 1 2152 6292 Tank 17 15.60 34 40 W 1 1349 4202 Tank 18 15.60 34 40 60 1 895.1 2745 Tank 19 15.60 34 40 60 1 653.6 1969 Tank20 15.60 34 40 60 1 1554 4861 Tank 21 15.60 37 43 60 1 8392 24636 Tank 22 15.60 37 43 60 1 426.6 1132 Tank 23 15.60 37 43 60 1 322.5 825 Ian k1 15.60 37 43 W 1 1050 2971 Tank 25 15.60 37 43 60 1 397 1045 Uro[o P�IIIR rdnk; In[.Wna YaMp 35613 aan[m int Fl-IDnn 1 u Co.,.,: Well Name/No.: Water Type: H^"IBURYUM ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT ConocoPbillips Alaska, Inc. Project Number Zone 10 -Zone 12 35412 Dme Tesaed: December 26, MIS Sea wmr Sam Ie ID Roorntemp Reaction time Ana Notal Blank Value Sample Volume Rkered Dilution ukipler Sample Anal,, Value Bq Value (degC( (min( (FW( (.11 Ifneeded IRU( Calculated Tank 15.60 30 60 1 0 Tank 15.60 30 60 1 0 Tank 15.60 30 60 1 0 Tank 15.60 30 49 60 1 108 5966 Tanks 15.60 30 49 60 1 W03 21669 Tank 15.60 30 49 60 1 1700 6010 Tank 7 15.60 30 51 60 1 2487 8864 Tank 8 1 15.60 30 51 60 1 1 1530 5381 Tank 15.60 30 51 60 1 2210 7856 Tank 10 15.60 30 49 60 1 548.9 IB21 Tank 11 15.60 30 49 60 1 6153 22215 Tank 12 15.60 30 47 60 1 3002 10754 Tank" 15.60 30 47 60 1 1828 6482 Tank 14 15.60 30 51 fi0 1 1193 4155 Tank 15 15.60 30 51 60 1 1679 5924 Tank 16 15.60 34 44 60 1 2571 8116 Tank 17 15.60 34 60 1 0 Tank 18 15.60 34 44 60 1 437 1263 Tank 19 15.60 34 d4 60 1 637.1 1906 Tank 20 15.60 34 64 60 1 861.7 2627 Tank21 15.60 37 44 60 1 3767 10987 Tank 22 SS.fi0 37 47 60 1 1263 3588 Tank 23 15.60 37 45 60 1 682.9 1882 Tank 24 15.60 37 0 1 0 Tank 25 15.60 37 60 1 0 Cantu IaIrrpn<...Io,-oxna RMx I.tZ Bane. Tnnna.,.t l3 113 r" HALLIBURTON F'p"Asbraken °°p Minifrac Crosslink Tests ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report —Fad —1 Me —2 ppS —3 pp9 —4 ppg —5 pp9 NI CMMGN cnmmrrtbna below are In palbna p ln[Nunn. —a Temp F pX LOSURF4ND CL- UC C., 1087 Opsin -e Test mini Frac Pad 73 10.10 1.00 0.90 0.45 1.00 2.00 Time Imin.) I muMa pmt um -m! Cp---'ipsTlnlu.lnc-ftmmi,nnnr.i6 Fenn IS in 1N1 Fluid System: Date: 12/17/2018 Company: ConocoPhillips Project No: Well Name: 35-612 Stage(s): Minifrac BHST(aF): 140 Water Source: Tank Water L' Depth: 6217 Water pH: Formation: Moraine Hydration pH: Analyst: Hydration Vise: 28 cp@ 73 NI CMMGN cnmmrrtbna below are In palbna p ln[Nunn. —a Temp F pX LOSURF4ND CL- UC C., 1087 Opsin -e Test mini Frac Pad 73 10.10 1.00 0.90 0.45 1.00 2.00 Time Imin.) I muMa pmt um -m! Cp---'ipsTlnlu.lnc-ftmmi,nnnr.i6 Fenn IS in 1N1 Zone 1 Crosslink Tests —PN —1 PR —2pp9 —3 PR —4 Ppg —5 PPg 2 1 1 T1 6 6 2 nme lmmseq al cn°mcalcar.nvmm�e n.le. ere m9Mlona P.rmeuaand 1 peones p.rmeuxm Lo[Number� Temp F pX -GSURF. 00 C1.3211C C1.51 Mod) 000 11 Test mini Frac 3PPG 80 9.30 1.00 0.90 0.45 0.25 2.00 C,—PhMiMMannw.lm. nupnwknwr3 12 Fann IS Min Rne1 12l ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Date: Company: ConocoPhillips Project No:_ Well Name: 35-612 Stage(s):_ BHST ff): 140 Water Source: Ta Depth: 6217 WaterpH:_ Formation: Moraine Hydration pH:_ Analyst: Hydration Visc: 27 cp@ Zone 1 Crosslink Tests —PN —1 PR —2pp9 —3 PR —4 Ppg —5 PPg 2 1 1 T1 6 6 2 nme lmmseq al cn°mcalcar.nvmm�e n.le. ere m9Mlona P.rmeuaand 1 peones p.rmeuxm Lo[Number� Temp F pX -GSURF. 00 C1.3211C C1.51 Mod) 000 11 Test mini Frac 3PPG 80 9.30 1.00 0.90 0.45 0.25 2.00 C,—PhMiMMannw.lm. nupnwknwr3 12 Fann IS Min Rne1 12l flifdisfi "'w' P Zone 2 Crosslink Tests —Pad —t PpS —2PP9 —3 PP9 —4PP9 —SPP9 3s33 3M 2WO an i5N 5 1090 80 1 sa D 1,1,11,■'�„1,,,,,,,,,,,,,,�■■ ----------------------------- Timp lmin:.e All cMmical comentrrtbns Ee are In 9albne pa thousand/ yunda per mousaM Lot Hinc.— Teri PH LOSURFJ D CL3311C C1,41 MIT51 Ope., Pad 1 ppg 80 9.10 1.00 0.90 0.46 0.26 2.00 2 ppg 3 ppg 4 pp9 Cw Milllps Almk;Inc. - Nupavk River 33612 Fann 11 Min -Ean.l 131 ALASKA DISTRICT LABORATORY 16 Minute Fann Model 3S Crosslinked Fluid Report Fluid System: Date: Company: _ ConocoPhillips Project No:_ Well Name: Stage(s):_ BHST(oF(: 140 Water Source:_ Depth: Water pH:_ Formation: Hydration pH:_ Analyst: Hydration Vise: 26 pp@ flifdisfi "'w' P Zone 2 Crosslink Tests —Pad —t PpS —2PP9 —3 PP9 —4PP9 —SPP9 3s33 3M 2WO an i5N 5 1090 80 1 sa D 1,1,11,■'�„1,,,,,,,,,,,,,,�■■ ----------------------------- Timp lmin:.e All cMmical comentrrtbns Ee are In 9albne pa thousand/ yunda per mousaM Lot Hinc.— Teri PH LOSURFJ D CL3311C C1,41 MIT51 Ope., Pad 1 ppg 80 9.10 1.00 0.90 0.46 0.26 2.00 2 ppg 3 ppg 4 pp9 Cw Milllps Almk;Inc. - Nupavk River 33612 Fann 11 Min -Ean.l 131 ""dxbm° nate Pp Zone 3 Crosslink Tests —Pad —1 Mg —2 PN —3 wg —4PP9 —SPP9 a m ■■■■i�!1■■■I\Iii■■■■■■■■■■■■■■ "ii■�■■■iiiiiiiiiiiiiiiiiiiiiii■ Torre anin:sacl NI cNmwal concettrnlons below are In gallon Pat, Mouacnd IpcuM Per Uwuc Ld Number— +7—,V PH LOSURF4WD LL4U UC CWt Mo., OPY 11 Pad 1 PP9 86 9.30 1.00 0.90 0.45 0.35 2.00 2 PP9 3 PP9 4 PP9 5 ppg Fan, 11 MIn-..3 133 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: Company: ConocoPhillips Project No:_ Well Name: Stage(s): BHST ff): 140 Water Source:_ Depth: Water pH: Formation: Hydration PH:— H:_Analyst Analyst- Hydration Vise: 25 DP ""dxbm° nate Pp Zone 3 Crosslink Tests —Pad —1 Mg —2 PN —3 wg —4PP9 —SPP9 a m ■■■■i�!1■■■I\Iii■■■■■■■■■■■■■■ "ii■�■■■iiiiiiiiiiiiiiiiiiiiiii■ Torre anin:sacl NI cNmwal concettrnlons below are In gallon Pat, Mouacnd IpcuM Per Uwuc Ld Number— +7—,V PH LOSURF4WD LL4U UC CWt Mo., OPY 11 Pad 1 PP9 86 9.30 1.00 0.90 0.45 0.35 2.00 2 PP9 3 PP9 4 PP9 5 ppg Fan, 11 MIn-..3 133 C ... mPMlllps Alaskann.1 Min.Sgea 120 HALLIBLIRTON FWW1801Ohene1tw•g Zone 4 Crosslink Tests ALASKA DISTRICT LABORATORY 16 Minute Farm Model 35 Crosslinked Fluid Repoli -Psd -1 gpg -2 wa -3 PP9 -4Pp9 -5 ppg Fluid System: two Company: Date: ConocoPhlllips Project No: zaoo Well Name: KRU 3S-612 Stage(s): 4 E two BHST(•F): 140 Water Source: Depth: Water pH: 8 t00o Formation: Hydration pH: Analyst Hydration Vise: 28 cp® SSF soo 0 w.w gt:w az:co 03:00 w:ao osw os:go w:w oe:oo ag:ao to.00 1100 tzw tzgo taw tsoo Time (muxe) NI chamical conceMMlons below are in gallons gar lLeugnal I Poupc Par thousand Lm xombar� TampsF PH LOSURF41001) ci-ouc Cldt M047 OOFb11 OOFWI Pad 85 9.50 1.00 0.90 0.46 0.35 2.00 0.25 1 ppg 90 9.70 1.00 0.90 0.45 0.36 2.00 0.26 2 ppg 92 9.60 1.00 0.90 0.46 0.35 2.00 0.25 3 ppg 90 9.50 1.00 0.90 0.45 0.35 2.00 0.25 4 ppg 82 9.70 1.00 0.90 0.46 0.35 2.00 0.25 5 ppg 84 9.70 1.00 0.90 0.45 0.36 2.00 0.26 6 ppg 84 9.70 1.00 0.90 0.45 0.36 2.00 0.25 7 ppg 84 9.70 1.00 0.90 0.45 0.35 2.00 0.25 C ... mPMlllps Alaskann.1 Min.Sgea 120 ,an.. %dnia, aW.mc. C.Parv4 anw an, F.nn RMIn-.-5 1ss HALLIBURTON Pawm'm"en.' , Zone 5CrosslinkTests ALASKA DISTRICT LABORATORY F -pad -1 Mg -2.pag -S PP9 -4ppg -5 ppg 15 Minute Farm Model 35 Crosslinked Fluid Report Company: Fluid System: Date: ConocoPhillips Project No: 1000 gw Bm Tm Well Name: KRU 35-612 Stage(s): 6 _$ B00 BHST rla): Depth: Formation: Analyst: 140 Water Source: Water pH:8 Hydration pH: Hydration Vsc: 28 cp@ 86F Z' y s00 °00 3W 2a0 1W 0 Time lmin:aecl NI chemical cemano-»an. macm arc In gallonsWUmimand 1 P^und.parM sane ,A NuMber-+ LOT NUMBER TemPR PH LOSURF. D CL42 UC CL.1 M"7 Opil'I"I 0011'. Pad 1.00 0.90 0.46 0.35 2.00 0.26 1 ppg 80 9.70 1.00 0.90 0.45 0.35 2.00 0.26 2 ppg 84 9.70 1.00 0.90 0.45 0.36 2.00 0.26 3 ppg 84 9.80 1.00 0.90 0.46 0.36 2.00 0.25 4 ppg 90 9.80 1.00 0.90 0.45 0.36 2.00 0.26 5 ppg 90 9.30 1.00 0.90 0.45 0.35 2.00 0.25 6 ppg 90 9.70 1.00 0.90 0.46 0.35 2.00 0.25 7 ppg 90 9.80 1.00 0.90 0.46 0.36 2.00 0.25 ,an.. %dnia, aW.mc. C.Parv4 anw an, F.nn RMIn-.-5 1ss Conow Phillips aleck In[.- Kupamk Piwr34611 fano IS Man - I .c I36 HALLIBURTON FAadis°rokan"pgoP Zone 5 Crosslink Tests ALASKA DISTRICT LABORATORY -Pled -IPpg -2M -3Png -4ppg -5ppg 15 Minute Farm Model 36 Crosslinked Fluid Report Fluid System: 4M Date: 12M Company: ConocoPhillips Project No: IBpg Well Name: KRU 3S•612 Stage(s): 6 BHST ff): Depth: 140 Water Source: Water pH: Z' $ soo Formation: Hydration pH: aoo Analyst Hydration Vise: 29 cp@ 82F Zoo 0 Tyre Iml .:KI NI chemical conceMratcas eclmaam M gallore Per Hammond r PPPIMs Par impend LM Number -a LOTNUMBER Temp F PH LOSURFiWO CL -12 UC CL., M047 001'"I OPIIFKnII Pad 1.00 0.90 0.45 0.35 2.00 0.25 1 ppg 80 9.40 1.00 0.90 0.45 0.36 2.00 0.25 2 ppg 80 9.30 1.00 0.90 0.46 0.35 2.00 0.25 3 ppg 84 9.30 1.00 0.90 0.45 0.36 2.00 0.25 4 ppg 84 9.30 1.00 0.90 0.45 0.35 2.00 0.25 5 ppg 84 9.70 1.00 0.90 0.45 0.35 2.00 0.26 6 ppg 82 9.50 1.00 0.90 0.46 0.35 2.00 0.25 7 ppg 78 9.60 1.00 0.90 0.46 0.35 2.00 0.25 Conow Phillips aleck In[.- Kupamk Piwr34611 fano IS Man - I .c I36 c..o�pnmwuas.. i.�-x�wntniw, xs.°u F... zsmm. m..z m HALLIBURTON ""'°"""°°° Zone 7 Crosslink Tests ALASKA DISTRICT LABORATORY -Pea -1m -xmp -amp -q ppg -5 ppg 15 Minute Fann Model 35 Crosslinked Fluid Report mp Fluid System: Date: uoo Company: ConocoPhillips Project No: +200 Well Name: KRU 3S-612 Stage(s): 7 goo° BHST j°F): 140 Water Source: Depth: Water pH: sm Formatiore Hydralion pH: .m Analyst: Hydration Visc: 27 ePg 76F zm 0 Oom arm ox:m mm w:m osm oam prm oem oem zom zim zxm zam ia�m zsao mmgmm:eael uz mimxr-, •nro.meM<ooa�maoo. miow.r.m eM�=.. m,eo•,...a z m..mwmo...� Tmpi P. LOsuawWo claxUC cwl MO 7 OpaMOAII OpaRoa aP Pad 1.00 0.90 0.45 0.35 2.00 0.25 0.00 1 ppg 80 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 2 ppg 80 9.50 1.00 0.90 0.45 0.35 2.00 0.25 0.00 3 ppg 80 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 4 ppg 72 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 5 ppg 72 9.50 1.00 0.90 0.45 0.35 2.00 0.25 0.00 6 ppg 72 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 7 ppg 74 9.60 1.00 0.90 0.45 0.35 2.00 0.25 0.00 c..o�pnmwuas.. i.�-x�wntniw, xs.°u F... zsmm. m..z m HALUBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: _ Company: ConocoPhillips Project No: Well Name: KRU 3S-612 Stagelsl:_ BHST (OF): 140 Water Source: Hydration Hydration Visc: 30 Zone 8 Crosslink Tests -Pea -f Ppa -z DP3 -3 pP9 -9 PP9 -5 PD9 3040 zwo 'n zao4 tsm S tang Sao O IV. 1 1 1 1 1 1 1 1 1 1 1 1 H nmelmm:mel f Phnlw A61b. me.. O,p.,a4 nM, 34612 was iI Nm. A -n txe All chemkW-ceftPA"wa PH -In gallons per ffi-Of I Pwn°e WUOOO,end brHun°er> Tempi PH WBURF40D CL -NUC CL11 M047 OAtnOm OPUFIa4l BP Pad 1.00 0.90 0.45 0.35 2.00 0.25 0.00 I ppg 84 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 2 ppg 84 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 3 ppg 72 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 4 ppg 72 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 5 ppg 70 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 6 ppg 70 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 7 ppg 72 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 f Phnlw A61b. me.. O,p.,a4 nM, 34612 was iI Nm. A -n txe co.om vnlelm a.La,ln<..cww•uxw,zscu f... Lzmm.zmez rn HALLISURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report vbwwewwexpmP Zone 9 Crosslink Tests Fluid System: -Pw -ippp -zwp -zppq -<vva -svve Data: ' Company: ConocoPhillips Project No: Well Name: KRU 3S-612 Stage($): 9 BHST ff): 140 Water Source: � 1000 It e Depth: Water pH: s` n Formation: Hydration pH: am Analyst: Hydration Vis<: 30 cps 74F m nam mHb azm vim oa.a Psm Pem azm oem mm tom .em 1zm lrm lam is nm.lml .kl Lot HumOn+ NI chemical cmcenbaacns Eebw am palans per NeuvnC 1 Pounis Per Mou.and Tempi PH ..uPli.. CL -x91. CLdl ...I Optlflo l OP11.41 SP Pad 1.00 0.90 0.45 0.35 2.00 0.25 0.00 1 ppg 72 9.30 1.00 0.90 0.45 0.35 2.00 0.25 0.00 2 ppg 72 9.50 1.00 0.90 0.45 0.35 2.00 0.25 0.00 3 ppg 72 9.50 1.00 0.90 0.45 0.35 2.00 0.25 0.00 4 ppg 74 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 5 ppg 74 9.50 1.00 0.90 0.45 0.35 2.00 0.25 0.00 6 ppg 78 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 7 ppg 78 9.40 1.00 0.90 0.45 0.35 2.00 0.25 0.00 co.om vnlelm a.La,ln<..cww•uxw,zscu f... Lzmm.zmez rn Gnom Saffid:Ah:W Inc.-xYp+Ne a... an is Mlm zonem 110 HALLIBURTON F'nddiv..natrmcd Zone 10 Crosslink Tests ALASKA DISTRICT LABORATORY -Ped -1 ppg -z PPg -3 PPe -4 ppg -5 ppg 15 Minute Farm Model 35 Crossiinked Fluid Report wo +Aoo Fluid System: Date: Company: ConocoPhillips Project No: 1200 Well Name: Stage(s): 10 $ BHST (nF): 140 Water Source: .F 800 Depth: Water pH: `y am Formation: Hydration pH: 41 Analyst: Hydration vsc: 31 0P@ 79F z00 0 0000 0100 az:00 ma0 od:0o 05:110 os:oo 07 00 0:00 08:00 1o:a0 11:00 12:0o 1x.00 1400 1s:0o Tlme Imxd:xq al cMmaL cokemrtlbns Exmw are In gallons per Noussnd I pounds per IFousand Lod NumGer-+ Temp°F LOSURFJWO CL-23UC CI -41 M04T 001F. -M 00FIoAI SP Pad 78 9.5 1.00 0.90 0.46 0.35 2.00 0.25 1 ppg 82 9.3 1.00 0.90 0.45 0.35 2.00 0.25 2 ppg 82 9.3 1.00 0.90 0.46 0.36 2.00 0.25 3 ppg 80 9.4 1.00 0.90 0.45 0.35 2.00 0.25 4 ppg 75 9.3 1.00 0.90 0.46 0.36 2.00 0.25 5 ppg 80 9.3 1.00 0.90 0.45 0.35 2.00 0.25 6 ppg 80 9.4 1.00 0.90 0.45 0.35 2.00 0.26 7 ppg 75 9.3 1.00 0.90 0.45 0.35 2.00 0.25 Gnom Saffid:Ah:W Inc.-xYp+Ne a... an is Mlm zonem 110 Fuf h;Jac""a' Zone 11 Crosslink Tests -Pad -109 -2 PPg -3 PP9 -4 ppg -5 ppg 2Y g' 1x $ la x r (min.) tI1 Ld Numbar-a HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: PH Date: Company: _ ConocoPhillips Project No:_ Well Name: Stage(s):_ BHST(aF): 140 Water Source:_ Depth: Water pH: _ Formation: Hydration pH:_ Analyst: Hydration Vsc: 37 Pp@ Fuf h;Jac""a' Zone 11 Crosslink Tests -Pad -109 -2 PPg -3 PP9 -4 ppg -5 ppg 2Y g' 1x $ la x r (min.) tI1 Ld Numbar-a NJ cnemial commih9bn: mi -v arc In galbna WOO and [ Pounds Pe[1Muund T-peF PH LOSURFJ000 CL-33UC CL41 Mea) OPNFbNI 001'" SP Pad 1.00 0.90 0.46 0.36 2.00 0.25 0.26 ppg 76 9.3 1.00 0.90 0.45 0.35 2.00 0.26 1 ppg 80 9.2 1.00 0.90 0.46 0.36 2.00 0.25 2 ppg 78 9.2 1.00 0.90 0.46 0.35 2.00 0.25 3 ppg 78 9.2 1.00 0.90 0.45 0.36 2.00 0.26 4 ppg 74 9.2 1.00 0.90 0.46 0.35 2.00 0.26 6 ppg 74 9.4 1.00 0.90 0.45 0.35 2.00 0.25 6 ppg 74 9.3 1.00 0.90 0.45 0.35 2.00 0.26 7 ppq 72 9.3 1.00 0.90 0.45 0.35 2.00 0.26 Cama MiMip/.NW, Int. -[uparu4PiWr.12 n. 1S Min - Fane 11 131 Lonaro Mlnanal.. nn .-ftimmY RNer 35-613 Fann LS Min-Rne U i.. HQLLIBURTON Zone 12 Crosslink Tests ALASKA DISTRICT LABORATORY F --P-1 Me -2pn -o ppg -4ppg -5ppg 15 Minute Farm Model 36 Crosslinked Fluid Report sea Fluid System: Date: 14M Company: ConocoPhillips Project No: +200 Well Name: Stage(s): 12 S +w0 BHST ('F): 140 Water Source: =' a. Depth: Water pH: m eW Formation: Hydration pH: am Analyst Hydration Vise: 29 cp@ 62 zoo 0 m.w 01.g0 az:DO o.R.aO w:w as:ao ae.ao 07ao ag.aD re.ro 10:a0 11.00 tz:m +300 ta:DO 15,00 Thin, Imn:uq NI<hama,alconcentrations Oelow are In galbm per axamand I pouMa per thousand Lot NumWF TempoF PN LOSRRF D CLd uc CL.' M"T 00Fb111 Op11Flo-11 SP Pad 1.00 0.90 0.45 0.36 2.00 0.25 0.25 ppg 62 9.2 1.00 0.90 0.46 0.35 2.00 0.25 1 ppg 62 9.3 1.00 0.90 0.45 0.36 2.00 0.25 2 ppg 62 9.3 1.00 0.90 0.46 0.35 2.00 0.25 3 ppg 60 9.5 1.00 0.90 0.45 0.35 2.00 0.25 4 ppg 62 9.3 1.00 0.90 0.46 0.35 2.00 0.25 5 ppg 60 9.3 1.00 0.90 0.45 0.35 2.00 0.25 0.26 6 ppg 62 9.4 1.00 0.90 0.46 0.35 2.00 0.25 0.25 7 ppg 62 9.4 1.00 0.90 0.45 0.35 2.00 0.25 0.60 Lonaro Mlnanal.. nn .-ftimmY RNer 35-613 Fann LS Min-Rne U i.. EMWI_iA14 1 0 Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065820 Customer: ConocoPhillips Well Name & Number: KRU 3S-612 Fluid System: Hybor G Date: December 16, 2018 10 minutes at 511 1/sec 10 minutes the shear rate was decreased to 100 1/sec SL#957 additive samples SL4947a,b,c,d,e and SL#950a,b,c Technician(s) Performing Testing: Reviewed & Approved By: HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065821 Customer: ConocoPhillips Well Name & Number: KRU 3S-612 Fluid System: Hybor G Date: December 19, 2018 0 minutes at 511 l/sec 10 minutes the shear rate was decreased to 100 1/sec SL#958 additive samples SL#947a,b,c,d,e and SL#950a,b,c Technician(s) Performing Testing: Jason Reviewed & Approved By: HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065893 Customer: ConocoPhillips Well Name & Number: KRU 3S-612 Fluid System: Hybor G Date: December 22, 2018 10 minutes at 511 1/sec 10 minutes the shear rate was decreased to 100 1/sec •SL#962 additive samples SL4947b, e and SL#961 a, c ,e, f, g, It Technician(s) Performing Testing: Jason Reviewed & Approved By: • Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065903 Customer: ConocoPhillips Well Name & Number: KRU 3S-612 Fluid System: Hybor G Date: December 25, 2018 ,0 minutes at 511 I/sec 10 minutes the shear rate was decreased to 100 1/sec SL#967 additive samples SL#947b, e and SL#961 a, c ,e, f, g, h Technician(s) Performing Testing: Jason Doyle Reviewed & Approved By: 218111 30 27 2 Schlumberger -Private RECEIVED STATE OF ALASKA ALA.. A OIL AND GAS CONSERVATION COMIC SION WELL COMPLETION OR RECOMPLETION REPORT ANU'L`OVG 1a.Well Status: Oil❑+ Gas[] SPLUG❑ Other ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20MC 25.110 1b.Well Class: f',, ��?�Ne�-%✓� Development ❑✓', a �� E�p,-"' Y ❑ GINJ ❑ WINJ ❑ WAG[_J ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 11114/2018 218-111 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 10/24/2018 50-103-20777-00-00 ' 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 2510' FNL, 1032' FEL, Sec 18, T12N, R8E, UM 11/9/2018 KRU 35-612 - Top of Productive Interval: 9. Ref Elevations: KB:63.6, 17. Field / Pool(s): 958' FNL, 482' FEL, Sec 11, T12N, R7E, UM GL: 24.5 - BF: Kuparuk River Field/rorok Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: _ - 517' FNL, 1903' FEL, Sec 2, T12N, R7E, UM N/A ADL 380107, ADL 25544, ADL 25528 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 476227 y- 5993906 - Zone- 4 19862/5218 ' 932060000,931869000,931866000 TPI: x- 466718 y-6000773 Zone- 4 12. SSSV Depth MDfrVD: 20. Thickness of Permafrost MDRVD: Total Depth: x- 465317 y- 6006500 Zone- 4 NONE • 1615/1411 - 5. Directional or Inclination Survey: Yes 21 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/lateral Top Window MDr VD: Submit electronic and printed information per 20 AAC 25.050 1 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res/Micro Scope/Sonic Scope 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 20 94 H40 39 119 39 119 42 Installed 103/4 45.5 L-80 39 3027 39 2558 131/2 1496 sx 11.0 Class G, 219 sx 12.0 Class G 75/8 29.7 L-80 37 13858 37 5127 97/8 1466 sx 15.8 Class G 41/2 12.6 L-80 13694 19854 13694 5218 63/4 LINER 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDlTVD) If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 41/2 13701 13570/5058 FRAC SLEEVES @: 14,357 MD and 5238 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14,872 MD and 5281 TVD 15,388 MD and 5280 TVD 15,867 MD and 5284 TVD COMPLETION 16,345 MD and 5281 TVDDEPTH 16,898 MD and 5277 TVD PPA7�E 17,377 MD and 5274 TVD 11 17,377 -_ Was hydraulic fracturing used during completion? Yes ❑ No ❑r Per 20 AAC 25.283 (i)(2) attach electronic and printed information INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 17,854 MD and 5264 TVD VERIFIED 18,389 MD and 5211 TVD A (� 18,865 MD and 5240 TVD 19,340 MD and 5229 TVD 19,765 MD and 5220 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A WAITING FOR HOOKUP Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casinq Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API (corr): Press. 24 -Hour Rat Form 10-407 Revised 5/2017 V7 -l-, 218Iy `j CONTINUED ON PAGE 2 ,� Submit ORIGINAL o �L i�8�(y RBDMS Tl Er" 0 6 2018 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1615 1411 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 13946 5148 information, including reports, per 20 AAC 25.071. Formation @ TPI -Top of Morein West Sak 2163 2020 C80 3312 2686 C50 5622 3243 C35 8778 3947 K3 9471 4103 Base Coyote 10114 4249 Formation at total de the Moraine 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloaical report, production or well test results. per 20 AAC 2&070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. L. Alvord Contact Name: Ben Tolman Authorized Title Alaska DOlini Manager Contact Email: ben.v.tolman co .com Authorized >(I (�• 1— t'iLV© ? Contact Phone: 265-6828 Signature: Date: 2 -ZO J INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item tb: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Bax 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Moraine 3S-612 Grass Roots Horizontal Multi -Stage Frac'd Infector ConocoPhillips Final Wellbore Schematic Cameron 1 OK 4-'G" tree, top joint is 4-'/:" 12.6# HYD563 New Conductor: 20" Conductor 31 9'/20." 'MCamcuD De Nipple 3.813' , I I I I , 13-112" Surface Hole 4'/."x1"KDMG wkM1 SGV 3,64d' MD Surface Casino: 1,027' D/2567- Hydril 563/'fXP 3,027' MD / 2,567' ND @ 55° SS F] i i i nL ..SND 4-1/2" 12.6# L-80 Hydril 563 6 PPG Y'x1"KBMGwIDV u 080' MD 11 SLB Gauge Cartier, 13,506' MD 4.5" x 7-518' Baker Premier Packer H-13,569MD 7-5/8" x 4-%" Baker Flex Lack Liner hanger Z P liner top packer wl RS Nipple, @ *I-13693' MD Production Liner 4-1/2" 12.6# HYD563 Production Hole 91° 19,854'MD/ 5,218' TVD 19,862'MD/ 5,218 TVD _,�___ty� KUP SNC. WELLNAME 3S-612 WELLBORE 3S-612 Tel Conoco�hllllp$ Well Attribute Max Angle Fkkl Name WeIINre APOUAw well4ore 51itua ndl°I MU (M1. ACI Btm(ad.) Alaska, Ir1C. TRACT OPERATION MCRTRW 5010390777(0 SVC tfi9 to Aad A3 10 SGIA ssatg,,vrvar m.mu4 Last Rev Reason emra sparesss.) Annwedroo End gree yMlawe bet MM By ....._......_. __.._....... ......................... Rev ReaWb PUlled 75" DFCV,Pulled SOV Replace Wl OV Mognal bK 11/24/2018 35-612 Jhansen8 emare:sa4 latch Casing Strings Caamg Description OD(A1 lofmj Top MKS) an Legroom Gel papa Herb. gemen(I... Grade TopThraaa ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,__,_..._......sagead......._ Conductor 20 18.50 39.0 119.0 119.0 154.00 cooing DeaDnpaan oD nnl ID (m) Top lnKBl semepm (xKal Gel Depen HND)... VNLan n._Gmde Top mreM Surface 10314 995- 78.6 3,OD.0 2,5582 4550 L -BD Hydd1563 Faaing Ceaulpllon OO (In) IDpn) Top HN(B) Sat Depla(XKB) eel Depla(em- WVLen Q_.Grbe Top IDrW Intermediate 798 688 MS 13,85].9 5,126.7 2970 L80 H563 Cad CxmM,EpaI(BM�'K CDnwrmr,;.onto'`.' { Casing Geacripurei OGlin IG(ir) TDPMKa) Set DepN pas.) age ..IS1.sed- WtlLen 9... Greae TaP Tareaa 9uao Dung cam, d30 aka Liner 41/2 3.96 13,693] 19,854.0 5.218.3 1260 LA0 Hyd 563 mreWFnab-Drew Da 9adso, ..n4rmle Liner Detail8 Nom DaID TDpgles) Tep(WMMIKS) Top Ir2IB ihm Das Com (la) 13,]13] 5,092.8 76.23 Nipple - RS RS Nipple, 5-1/2", Hyd563 4.250 surae; as ,,.a- 3,716.0 SOW 7625 Hanger Gner Hanger, FL pinned 17M psi 4.800 -17M 5 5-.0-97 76.38 eat ore ealborex W. F Hyd 521 Pin up x 4.5" Hyd 4.020 Extension 521 box dawn MVMM: 9,861.8 14,11].1 5.1850 ))21 Swell Packer PA KER,SWELL41 % B'18AK RH 3. DO muvarFlukl-ci seaxaY, AaW.8t3.TW a: nna2lte Inaau4W ca.tg C.Denr. (002141-001-10)L sa7o.pwa16,357.5 meNM; p.IYJ0.9 5,23].8 77.88 Frac Sleeve Baker racsleeve (2.695"bau)Assy K,H 2655 FPSC725 PN H809080396 14,6316 5.2]].3 85.91 Swell Packer PA KE ,SWELL41/2x6. 0",BAKE h N 3.900 G..®s rpamp verso,, taa0r.o (0021410-001-11)K 14,872.2 5,280.9 90.89 Frac Sleeve Baker frac sleeve (2.645" ban) Assy J, HYD563 ON 2.605 h.r-LnS' :Iltar ] FPSC724 PN H809080395 15,1094 5,2792 89.88 Swell Packer PACKER, SWELL 4112 X 6 DY.BAKERHYD563 SN 3.900 (002141-001-6)J 15,3884 5,2800 89.66 Frac Sleeve Baker frac sleeve (2595" ball) Ally I, HYD563 ON 2.555 FPSC723 PN H8090803N tamwl166m.t Imbr, S. 15,624.8 5,283.0 89.21 $e PaP8cker ,SW E LL,4t Q X 6 00-BAKERHYD N 3900 (002141-001-12)1 15,86].5 5,283.9 90.1] Frac Sleeve Baker frac sleeve(. ' ball) Assy H, HYD5 N 2505 mlav slw:taaW.T FPSC722 PN H809080393 16,104.2 5,282.8 90.42 Swell Packer PACK R,SW LL,4 112 % 6BUEAKER HYD N 3.900 (002141-0014) H 16,3453 5,281.1 9.35 Fred Sleeve Baker madsleeye(.4 - bi Argy G,HY05 N 2,465 FPSC721 PN HM080392 16,618.1 5,2794 90.43 Masi Swell Pecker PACKER,SWl IQ X &UWBAKEFLHYD563 SN 3.900 (0021414101-8) G InMmaSeb: 99.&19,65] 9 168979 5277.3 90,45 Frac Sleeve Ba r ac sleeve ball) Assy F, HYD 5 N 2.425 0603 FPSCPN H809080391 MO 1],1334 5754 9044 Sweil Packer PACKER,SWEU,4112X 6.02EBAKER,HYD563SN 3.900 (002141-001-1)F 1],3]69 5,2738 90.58 Frac Sleeve Baker foldsleeve .15"ball Assy E. HYD 563 ON 2.385 FPSC719 PN HM9080390 17,650.8 52684 91.31 Swell Packer PA KER, WELL,4 IQX 6.00E.BAKER,HYD 563 SN 3,900 (002141-001-14),E 1775-37 5. 636 9140 Frac Sleeve Baker fracsleeve 2.375 -ball ,Assy 0 -HYD -93 -TN- 2.345 FPSC718 PN H809060389 8,1 7. 5.5].7 9129 Swell Packet PA KE W LL, 1l % ',BAKER,HVD563 N 3.00 (002141-001-3) D 18.389.2 5,251 1 9139 Frac Sleeve Baker acsleeye(. 5"bali)May C,HYD 563 C N 2.305 FPSC717 PN H809NO388 18,58].1 5, 91.32 Swell Packer PACKER,SWELL,41 X 6 DW,SBKER,-HY-Dr6TTN-- 3.900 (002141-001-])C 18,8652 5, 4 .1 147 Frac Sleeve Baker bad sleeve(. 5" ball) Assy B, HYD563 ON 2.265 FPSC716 PN HM080397 19,138.7 5,234.0 91.35 Swell Packer PACKER,SVgl la X 8. ',BAKER,HYD 563 SN 3.900 (002141-0014) B ArvW V Ertl-Skes.dre19.3 9.6 5, 9.4 9136 Frac Sleeve Baker frac seeeve (2,25Y ball) Assy A, HYD563 ON 2.225 ta'. s or.,a.......Gore FPSC715 PNS BOM0386 19577-2 ----5=4 91.24 Swell Packer PA KER, WELL,4 1Q X 6.WrBAKER,HYDR3 SN 3.900 (002141-001-9)A 19,751.8 5220) 1.6 FreC Sleeve Ip F. ressureleeve, rupture disC Ar 14 17300psi 3.000 Tow, 7900 p e high, 7613 nom psi) 19Jfi5.3 5,220.4 9125 Frac Sleeve Wellbore lsolagon Valve Ball uid - lot -tl 4",9977 0000 psi shear Tubing Strings Tubing Desmipuon stone ma... m pn) Top MKS) Gel oepM (a_ Stl Gepta (Wag (... wlpads GrMe TDp CDnnmaan Tubing -production 61/2 3.96 344 13,700] 5089.] 1260 L-80 Hydri1563 Completion Details mp BVM Trained NDmmal TaPMKM MKS) I-) Item Des core to (in) 344 344 000 Hanger Hanger,4-1/2"x10-V4"Gen 5, FMC TC-1AEM5 3.920 ISM6 1,8299 36.33 Nipple -.1 Nipple, Cal 3SIY Be Room, SN: 3654-3 3.813 DB -6 13.007 0 5043.0 76.10 a-ge l Pump Bad, Came, BUS. SOMwi a ngtu Ing pressure gauge, 3864 Sensor SN CI5GM-0403 13633.3 5,07ST 7602 Nipple- .5" -DB Nipple, amcq 3.75" Dal PGdlle, :(dual flapper plug installed) 3750 6 SN 40532 13690.1 --577-2 7.5 Locator echanical Locates 4.5"TOO Box D WI, (large Onabove 3950 located) Locamr Mechkal Loosel-45"TCII Box (small ODbelowlocaned) 3.950 13,691.1 5,0874 696ul anFlutes 13,699.] 5,089.5 ]8.12 Me Shpe Baker WLEG(Wine line entry guide) 3.900 DIw, Ia.7.igae4 ♦ KUP SVC WELLNAME 35-612 WELLBORE 35-612 Conoco`Phillips / Alaska, In[. 6 L- 33-61, I.. rm'.zlu4 Mandrellnser[s Va�tralamenmec(xromll St as .._......................... .. ..._.._......... N Ya I- talcll Port.. TRO flan Wroa: &.a TOP(Nnl rap(..) m") naw Mural oolml Sen Typa type (,n) IW9 Run Data Com 3,8448 2,795.1 Camco PN'. 1 CAS LIFT OMY MONS O.OW 0011/2412018 05584- --BK ............................................................... ................ 0IF 0 sur# 03MK0 c�iuw'c:aa�r"volia M�; 2 2 co�aaowra, 3soneSti�' . sumo.cau..p cem.M 43,3 2 12, .3 4,704.8 Camco SLIFT DMY MON 0000 0.0 11I24I2018 u0 5564- --BK Mo reaa. Geeat ou 000- 3.61SO; 1111VNI8 00009. # 038AKo 3a ..53,O27.3-. MVIMe{3.wa PmuYr iIW -CI Seamb: ]a15613,M301111I(mla IrlbnlvJeb Ceshp CxnelR 9,3]001 m...; 120.tl.6 Gaulp /Pump $amr, l3.bi.0 P=1w ITuanu, 13.5k.7 Laab. 13.89J1 lamr 13, e mWa 91ww 13.67 MIVNFMO-NaCl Bha, 137W 619,BR.O; 11Mlgla LM: 13,®37 -IB BSC♦ Operations Summary (with Timelog Depths) 3S-612 I& Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur (h) Phase Op Code AcONty Code Time P-T-X Operation (ftKB) End Depth (MB) 10/23/2018 10/2312018 6.00 MIRU MOVE MOB P Move and stage pump and pits mods. 0.0 0.0 06:00 12:00 skid floor & Pin raise and secure stompers. Hook up trucks move sub off of 3S-611, Position cellar matt install floor and berm. spot sub over 3S-612. Lower stompers remove tongue, skid rig floor and pin in the drill position. Spot pits adn pipeshed. spot Pump and power modules, spot rock washer. 10123/2018 10/23/2018 4.50 MIRU MOVE MOB P Spot cuttings tank and Berm. 0.0 0.0 12:00 16:30 Complete rig acceptance checklist. Connect all electrical and fluid interconnects, Lower and secure skate rail Rig Accepted @16.30 HRS 10/23/2018 10/2312018 1.50 MIRU MOVE NUND P Obtain RKB's , NU 4" conductor 0.0 0.0 16:30 18:00 valves , torque diverter tee flange bolts, pick and position riser nipple atop annular. 10123/2018 10/23/2018 3.50 MIRU MOVE NUND P Install pitcher nipple & riser, Install 0.0 0.0 18:00 21:30 turnbuckles and Mousehole . Obtain diverter Measurements Pick up DP & tag blm of conductor @ 110'MD 10/23/2018 10/23/2018 1.50 MIRU MOVE BOPE P Diverter test witnessed by AOGCC rep 21:30 23:00 Lou Laubenstem 10-24-18 @ 23:00 HRS. Tested diverter with a joint of 5" DP . Annular Closing time=29 Sec's. Knife Valve open fully--4 Secs. Drawdown test performed. Initial Psi=3000, Function all preventers 1925 Psi, 200 Psi Built in 6 secs. Full PSi= 39 sea. 6 Bottles AVG @ 2163 psi. Fail pass on visual LEL pit sensor. Calibrated and retested all good. Pit Level & Flow Meters tested all good. 10123/2018 1012312018 0.50 MIRU MOVE SFTY P Pre spud safety meeting w/ all 0.0 0.0 23:00 23:30 personnel. 10/2312018 10/24/2018 0.50 MIRU MOVE BHAH P Make up 13-1/2" BHA 1 to 44' MD, as 0.0 44.0 23:30 00:00 per SLB DD. 10/24/2018 10124/2018 0.50 MIRU MOVE BHAH P Continue MU/BHA F/ 44'-119'MD,AS 44.0 119.0 00:00 00:30 per SLB DD 10/24/2018 10/24/2018 0.25 MIRU MOVE SEOP P Flood Lines, Pressure test Mud lines 119.0 119.0 00:30 00:45 and surface equipment V 3500 PSI. Good test. 10124/2018 10/2412018 0.50 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 119.0 139.0 00:45 01:15 f/ 119'-139' MD, 139' TVD,@ 400gpm, 430 psi, FO 25%,40 rpm, Tq -2K, - WOB -10K, 10124/2018 10/2412018 2.25 SURFAC DRILL SHAH P RK Bk STD DP& Cont MU/ BHAT 139.0 139.0 01:15 03:30 130'MD/ MU Collar STD in Mouse- hole 10/24/2018 1012412018 2.50 SURFAC DRILL DDRL P Ddg 131/2"F/139'MD T/350'MD. 130.0 350.0 03:30 06:00 350' TVD @ 420 GPM 720 PSI 27% FO, @50 RPM'S- 3k To- 10K WOB, / 609 PSI Off Btm - PUNVT=75K - SO/WT=70K-ROT WT= 68K- TO Off--.5- Max Gas=0 Units,AST=.27-- ART=.95-ADT=1.22--Jar HrS= 70.4 10/24/2018 10/24/2018 0.25 SURFAC DRILL DDRL P Cont Ddg f/ 350' MD-T/407' MD 407' 350.0 407.0 06:00 06:15 TVD, @ 425 GPM 620 PSI 27% FO- W/ 50 RPM'S -3K To on BTM- 1K WOB, Off BTM PSI=609- PU WT= 75K-SO WT= 70K,--ROT= 68K To Off--.5K Page 1120 ReportPrinted: 1112012018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op code Activity Cade Time P -T -x Opsrawn (RKB) End DepM(ftK8) 10/24/2016 101242018 1.50 SURFAC DRILL CIRC T Lose 60 bbls to the hole, PU Circ & 407.0 407.0 06:15 07:45 Reciprocate F/ 407'w/ Adding 4PPB background LCM in the active system until nut plug returns verified at surface. While Mixing 30 BBL pill 1024/2018 10/24/2018 4.25 SURFAC DRILL DDRL P Resume Drlg 13 1/2" hole F/ 407' MD 407.0 875.0 07:45 12:00 T/ 875' MO 870' TVD @ 430 GPM -- 1026 PSI- W/ 28% FO- 40 RPM'S - 5K TQ/ 16K WOB, Off Btm Psi= 738 - PU WT=88K-SO=92K-RT=90K-- 1.3K TO, Max Gas = 0 Units- AST=1.02--, ART=1.54--ADT=2.56, Bit Hrs= 3.78--, Jar HRS= 72.96 10/24/2018 10/24/2018 5.50 SURFAC DRILL DDRL P Resume Drlg 13 1/2" hole F/ 875' MD 875.0 1,396.0 12:00 17:30 T/1396' MD 1371' TVD @ 500GPM - 1200 PSI- W/ 29% FO- 60 RPM'S - 6K TQ/ 28K WOB, Off Btm Psi= 970 - PU WT=101 K-SO=97K--RT=101 K -- 2.4K TQ, Max Gas = 0 Units-- AST=2.51-, ART=.98-ADT=3.49, Bit Hrs= 7.27 -Jar HRS= 76.45 1012412018 102412018 1.50 SURFAC DRILL RGRP T Riser & Flow line Packed off w/ Clay 1,396.0 1,396.0 17:30 19:00 & Large rocks Rk Bk Std Clear Flow line Of obstruction, PU std run Bk U BTM encounter 40K drag @ 1301'MD PU Turn String 1/2 Tum Repeal SLK Off RIH U BTM. 10/24/2018 1025/2018 5.00 SURFAC DRILL DDRL P Resume Ddg 13112" hole F/ 1396' MD 1,396.0 1,938.0 19:00 00:00 T/ 1936' MD 1844' TVD @ 500 GPM -- 1080 PSI- W/ 30% FO- 60 RPM'S -- 6K TQ-- W/20K WOB,-- Off Btm Psi= 980 - PU WT113K--SO=104K-- RT=107K-- 3K TQ --Max Gas=5OUnits --AST=1.76-- ART=1.26--ADT=3.02, Bit Hrs=10.29-- Jar HRS= 79.47 10/25/2018 10/252018 6.00 SURFAC DRILL DDRL P Resume Drlg 13 1/2" hole F/ 1938' MD 1,938.0 2,623.5- 00:00 06:00 TI 2623' MD 2340' TVD 111650 GPM - 1850 PSI- W/ 34% FO- 60 RPM'S -- 6.5K TQ- W/28K WOB,-- Off Stun Psi= 1685 - PU WT122K--SO=105K-- RT=111 K-- 3K TQ -Max Gas =100 Units--AST=.68-- ART=3.53-- ADT=4.21, Bit Hrs=14.5-- Jar HRS=83.68 10/25/2018 10/25/2018 2.25 SURFAC DRILL DDRL P Resume Ddg 13 1/2" hole F/ 2623' MD 2,623.0 2,768.0 06:00 08:15 T/ 2768' MD 2420' TVD @ 650 GPM -- 1880 PSI- W/ 34% FO- 80 RPM'S -- 7K TQ- W/28K WOB,- Off Btm Psi= 1680- PU WT127K--SO=106K-- RT=113K- 3K TO --Max Gas =126 Units 10125/2018 10/25/2018 0.50 SURFAC DRILL SVRG P Service Topdrive Energy Track 2,768.0 2,768.0 08:15 08:45 10125/2018 10/25/2018 0.50 SURFAC DRILL RGRP T Reposition and secure electrical cable 2,768.0 2,768.0 08:45 09:15 1 1 1 in the topddve energy track. 10/2512018 10/25/2018 2.50 SURFAC DRILL DDRL P Resume Ddg 13 1/2" hole F/ 2768' MD 2,768.0 3,034.0 09:15 11:45 T/3034' MD 2564' TVD/ (TO Picked 3034')@ 650 GPM --1995 PSI- W/ 33% FO- 80 RPM'S --6-7K TO-- W/25K WOB,-- Off Btm Psi= 1795 - PU WT123K--SO=106K-RT=112K-- 5K TQ --Max Gas =20 Units--AST=.51- -ART=2.92-ADT=3.43, Bit Hrs=17.93 - Jar HRS=87.11 Page 2120 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Marl cepM Start Time End Time Dur (hr) Phase Op Cada Activity Code Time P -T-% Operation (aK8) End Depth (f KB) 10/25/2018 10/2512018 0.25 SURFAC CASING CIRC P Obtain Survey final @ TD, Pump 30 3,034.0 3,034.0 11:45 12:00 BBI LCM Pill SSS Rotate & Reciprocate Pipe F/ 3034 T/ 2957 MD @ 650 GPM, 1800 PSI, 33% FO, -W/ 80 RPM'S = TQ =5K 10/25/2018 10/25/2018 0.75 SURFAC CASING CIRC P Conti Circulate Sweep SSS W/ Rot & 2,957.0 2,957.0 12:00 12:45 Recip Pipe. F/ 3034'@ 650 GPM 1785 PSI, 33% F/O--W/ 80 RPM'S TQ=4k- PU=118K 5O=108K Sweep Returns T/ SURF 1800 STKS Early Total strokes pumped 5825. Monitor Well 10 Mins Verify Dead. 10/25/2018 10/25/2018 6.25 SURFAC CASING BKRM P BROOH F/ 2957'T/ 1735'MD @ 650 2,957.0 1,735.0 12:45 19:00 GPM 1546 PSI W/ 33% F1O W/ 60 RPM'S 5K TO Work lhru light spot @ 1873' MD 10/25/2018 10/25/2018 0.50 SURFAC CASING BKRM T Clay Packed off Rotary Table./Clean 1,735.0 1,735.0 19:00 19:30 & Clear Clay from Inner Bowl area. Resume backreaming out of hole. 10/25/2018 10/25/2018 1.25 SURFAC CASING BKRM P BROOH F/ 1735'T/ 1630'MD @ 620 1,735.0 1,630.0 19:30 20:45 GPM 1470 PSI W/ 33% F/O W/ 60 RPM'S 3.5K TQ 10/25/2018 10/25/2018 0.25 SURFAC CASING OWFF P Monitor well, static 1,630.0 1,630.0 20:45 21:00 10/25/2018 10/25/2018 1.75 SURFAC CASING PMPO P Pump OOH F/ 1630' MD T/ 784 MD 1,630.0 784.0 21:00 22:45 @ 2 BPM 200 PSI, 22% F/O 40 FPM pulling speed , Wiping all spots W/ 20K Drag was observed. PU WT =75K -S/O WT=73K 10/25/2018 10/26/2018 1.25 SURFAC CASING PMPO P Conti POH LD HWDP F/ 784' MD T/ 784.0 318.0 22:45 00:00 318' MD @ 2 BPM, 170 PSI 22% F/O W/ 40 FPM pulling speed Wiping all spots W 20K Drag was observed Previously PU WT= 75K SIO WT=73 K 10/26/2018 10/26/2018 3.50 SURFAC CASING BHAH P LD/ Bha #1, As per DD F/ 318' MD. / 318.0 0.0 00:00 03:30 Clean and Clear Floor. 10/26/2018 10/26/2018 1.25 SURFAC CASING RURD P RU / T Run 10 3/4" CSG 0.0 0.0 03:30 04:45 10/26/2018 10/26/2018 1.25 SURFAC CASING PUTB P MU/ 10 3/4" Shoe Track T/ 168' MD, 0.0 168.0 04:45 06:00 Break Circ check Floats. Good. 10/26/2018 10126/2018 3.00 SURFAC CASING PUTB P Cont PU/ 10 3/4" CSG F/168' T/ 576' 168.0 576.0 06:00 09:00 Md/ Stage up Pump T/ 8 BPM 113 PSI, 20% F/O PU WT = 69K S/O 65K 10/26/2018 10/26/2018 3.00 SURFAC CASING PUTB P Conti RIH F/ 576'T/ 1267' MD Circ/ 576.0 1,267.0 09:00 12:00 Conditioning Mud & Hole w/ Working pipe T/ Clean Hole Staging Pump T/ 8 BPM 228 PSI, 21% F/O, PU=104K-- S/O= 72K 10/26/2018 10/26/2018 1.50 SURFAC CASING PUTB T CO/ JTS # 32 & #31 F/ Joints # 75 & 1,267.0 1,267.0 12:00 13:30 # 76 Due T/ Improper MU 10/26/2018 10/26/2018 3.00 SURFAC CASING PUTB P Conti RIH F/ 1267' T/ 1839' MD 1,267.0 1,839.0 13:30 16:30 Circulating and Working Pipe as Hole land Mud Dictate 10/26/2018 10/26/2018 0.75 SURFAC CASING CIRC P Circulate SSS w/ Recip/ pipe F/ 1,839.0 1,839.0 16:30 17:15 1804' T/ 1839 Md @ 8 BPM 294 PSI 22% F/O. PU WT= 122 SIO = 70K 10/26/2018 10/26/2018 0.75 SURFAC CASING PUTB P Cont, RIH F/ 1839' MD T/ 2207' MD 1,839.0 2,207.0 17:15 18:00 Up Wt= 150k DN WT= 72K 10/26/2018 10/26/2018 2.25 SURFAC CASING PUTB P Conti RIH F/ 2207' MD T/ 2985' MD 2,207.0 2,985.0 18:00 20:15 UP WT=190K SIO WT= 92K Page 3120 Report Printed: 1112 012 01 8 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Our (hr) Phase Op Corte Activity Cade Time P -T-% Operation 01m) End Depth (fixe) 10/26/2018 10/26/2018 0.50 SURFAC CASING HOSO P Make up hanger & landing joint as per 2,985.0 3,026.0 20:15 20:45 FMC Tech. & continue in the hole 2985'-3026' MD, PU 190K, SO 92K. 10/26/2018 10/27/2018 3.25 SURFAC CEMENT CIRC P Circulate & condition mud for 3,026.0 3,026.0 20:45 00:00 cementing. Stage up pumps from 1-7 bpm, 215-380 psi, PU 169K, SO 93K. 10/27/2018 10/27/2018 0.50 SURFAC CEMENT CIRC P Circulate & condition mud for 3,026.0 3,026.0 00:00 00:30 cementing. Stage up pumps from 1-7 bpm, 318 psi, FO 18%, PU 170K, SO 95K. 10/27/2018 10/27/2018 4.50 SURFAC CEMENT CMNT P Line up & SLB pump 5 bbls of CW100. 3,026.0 0.0 00:30 05:00 Pressure test lines to 3500 psi, good. Pump 34.9 bbls of CW100 @ 4.7 bpm, 186 psi, FO 17%, PU 171 K, SO 98K. Pump 80.2 bbls of 10.5 ppg MP II @ 5.5 bpm, 190 psi, FO 16%. Drop bottom plug & start batching lead. Pump 508.8 bbls of 11.0 ppg lead cement at 3-6 bpm, 108-310 psi, FO 18%-8%, final PU 177K, SO 74K. Land out casing with 360 bbls of lead away. Pump 64.1 bbls of 12.0 ppg tail cement @ 4.6-6 bpm, 240-390 psi, FO 16%. Drop top plug & kick out with 10 bbis of fresh H2O. Swap to rig & displace w/ 9.9 ppg spud mud @ 6.5 bpm, 283-608 psi, FO 17%. Reduce rate to 2 bpm, 330 psi, FO 9%. Bump plug with 2715 strokes, 273.7 bbls pumped. Pressure up to 850 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 04:55 hrs. 280 bbls of 11.0 ppg cement to surface & 80 Obis total losses while pumping job. 10/27/2018 10/27/2018 2.00 SURFAC CEMENT RURD P Drain surface stack & hg down CRT. 0.0 0.0 05:00 07:00 Remove & lay down landing joint. 10/27/2018 10/27/2018 1.00 SURFAC CEMENT W W WH P Make up stack wash tool & flush stack 0.0 0.0 07:00 08:00 with black water pill at 717 gpm. Function bag 4 times. Lay down flush tool & blow down TD. SIMOPS service cement manifold valves & clean pits. 10/27/2018 10/27/2018 5.00 SURFAC CEMENT NUND P Pull riser & riser nipple. Nipple down 0.0 0.0 08:00 13:00 surface annular, diverter tee, FMC diverter connector, knife valve & diverter line. SIMOPS service drawworks. 10/27/2018 10/27/2018 3.75 SURFAC WHDBOP NUND P Nipple up FMC Gen 5 Unihead 0.0 0.0 13:00 16:45 wellhead & orient. Nipple up adapter, spacer spool, & set BOP stack on wellhead. Obtain RKB's. TOC 3.4' from hanger flutes. 10/27/2018 10/27/2018 0.25 SURFAC WHDBOP PRTS P Test seals between rasing hanger & 0.0 0.0 16:45 17:00 wellhead to 1000 psi for 10 minutes, witnessed by CPAI Rep. 10/27/2018 10/27/2018 6.50 SURFAC WHDBOP NUND P Torque flanges, install choke & kill 0.0 0.0 17:00 23:30 lines. Install annulus valves. SIMOPS install & nipple up MPD equipment. 10/27/2018 10128/2018 0.50 SURFAC WHDBOP RURD P Rig up to test BOPE. Flood lines & fill 0.0 0.0 23:30 00:00 stack. Page 4120 ReportPrinted: 11/2012018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our(hr) Phase Op Cade Aavity Code Time P -T -x Operation (NS) End Depth(flKB) 10/28/2018 10/28/2018 4.00 SURFAC WHDBOP BOPE P BOP test witness waived by AOGCC 0.0 0.0 00:00 04:00 Lou Laubenstein. Test BOPE T/250 Low, 3500 PSI High. Test w/ 5" & 4" test Joints with all rams, annular, upper and lower VBR'S, Test choke valves 1-14. Rig Floor, Mezzanine, HCR and Man Kill. HCR and Manual Chokes Test 4" & 5" TIW & Dart Valves. Test Upper and Lower IBOP. Test Inner and Outer top most annulus valves, Test Super Choke & Manual Choke T/ 2500 PSI Show Bleed off. Test Blinds, Perform Drawdown test. System pressure 2950 psi, after function 1850 psi, 200 psi obtained 6 seconds, full pressure obtained 43 seconds. 6 nitrogen bottles averaged 2000 PSL Tested gas alarms, flow meter, & pit level alarms. SIMOPS rig up MPD equipment 10/28/2018 10/28/2018 1.50 SURFAC WHDBOP MPDA P Remove trip riser & install MPD test 0.0 0.0 04:00 05:30 cap. Perform body test on RCD 250- 1200 psi. Test MPD air valve 250- 1200 psi all test good. 10/28/2018 10/28/2018 1.50 SURFAC WHDBOP MPDA P Pull test cap and install trip nipple. 0.0 0.0 05:30 07:00 Blow down all lines. Install Mouse Hole. Install 9-15/16" ID wear bushing. 10/28/2018 10/28/2018 1.25 SURFAC CEMENT BHAH P Make up 9-7/8" Intermediate BHA as 0.0 300.0 07:00 08:15 per SLB DO T/ 300' MD. PU 65K, SO 72K. 10/28/2018 10/28/2018 2.25 SURFAC CEMENT PULD P Single in the hole with 5" DP 11300'- 300.0 2,663.0 08:15 10:30 1 2663' MD. 10/28/2018 10/28/2018 2.00 SURFAC CEMENT CIRC P Circulate & condition mud @ 501 gpm, 2,663.0 2,758.0 10:30 12:30 920 psi, FO 27%, 60 rpm, Tq 4K. PU 113K, SO 98K, ROT 105K. 10/28/2018 10/28/2018 1.50 SURFAC CEMENT PRTS P Rig up test equipment. Perform casing 2,758.0 2,758.0 12:30 14:00 and OA valve test to 3000 psi for 30 minutes, charted. Pressure up with 4 bbls. Shut in & observe pressure initial 3110 psi to 3075 psi in 30 minutes. Bled off same volume. Rig down test equipment. 10/28/2018 10/28/2018 0.50 SURFAC CEMENT SVRG P Service & inspect top drive / blocks. 2,758.0 2,758.0 14:00 14:30 10/28/2018 10/28/2018 3.50 SURFAC CEMENT RGRP T Trouble shoot drewworks drive 2,758.0 2,758.0 14:30 18:00 motors. Reset backlash on motors, torque bolts, repair encoder & test. 10/28/2018 10/28/2018 0.50 SURFAC CEMENT TRIP P TIH from 2758'-2934' MD tagging top 2,758.0 2,934.0 18:00 18:30 of plugs on float collar. 10/28/2018 10/28/2018 3.00 SURFAC CEMENT DRLG P Drill out shoe track & rat hole f/ 2934'- 2,934.0 3,034.0 18:30 21:30 3034' MD, 409 gpm, 644 psi, FO 24%, 40 rpm, Tq 11 K, WOB 5-11 K, PU 115K, SO 94K, ROT 105K. SCR's @ 3034' MD, 2553' TVD, MW 9.6 ppg, 20:30 hrs. #1 @30= 100 psi; @40= 120 psi #2 @ 30 = 100 psi; @ 40 = 130 psi 10/28/2018 10/28/2018 0.25 SURFAC CEMENT DDRL P Drill 9-7/6" intermediate hole from 3,034.0 3,054.0 21:30 21:45 3034'-3054' MD, 2573' TVD, 506 gpm, 950 psi, FO 27%, 80 rpm, Tq 7K, WOB 6K, off bottom 920 psi, PU 115K, SO 94K, ROT 105K, Tq 6K, Max Gas 24, ADT .25, Bit .25, Jars 59.66. 10/28/2018 10/28/2018 0.50 SURFAC CEMENT BKRM P BROOH from 3054'-3013' MD, 506 3,054.0 3,013.0 21:45 22:15 1 gpm, 915 psi, 60 rpm, Tq 12K. Page 5/20 ReportPrinted: 11120120181 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Sten Tme End Time our (0 h Phase Op Code Activit' Code Time P -T -X Operation (ftKB) End Depth (RKB) 10/28/2018 10/28/2018 1.00 SURFAC CEMENT FIT P Rig up & perform FIT to an EMW of 3,013.0 3,013.0 22:15 23:15 13.0 ppg, with 9.7 ppg MW, at 2558' TVD. Pressure up 440 psi with .7 Wis. Shut in & observe pressure for 10 minutes, initial 440 psi / final 400 psi. Bled back .6 bbls. Rig / blow down test equipment. 10/28/2018 10/28/2018 0.25 INTRMI DRILL TRIP P TIH f/ 3013'-3054' MD. 3,013.0 3,054.0 23:15 23:30 10/28/2018 10/29/2018 0.50 INTRMI DRILL DDRL P Drill 9-7/8" intermediate hole from 3,054.0 3,110.0 23:30 00:00 3054'-3110' MD, 2598' TVD, 506 gpm, 950 psi, FO 27%, 80 rpm, Tq 7K, WOB 6K, off bottom 920 psi, PU 115K, SO 94K, ROT 105K, Tq 6K, Max Gas 24, ADT .5, Bit .75, Jars 60.16. SIMOPS displace to 9.0 ppg LSND mud system. 10/29/2018 1012912018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/3110'MD T/ 3900' 3,110.0 3,900.0 00:00 06:00 MD 2852' TVD @ 650 GPM 1084 PSI, F/0=29%,150 RPM'S 7K TQ,W/ 8K WOB — OFF BTM PSI= 1052-- PU - 123K, SIO -97K, ROT -108K, 5K TQ , MAX GAS = 25 UNITS, ADT=4.15, BIT HRS=4.9, JAR HRS=68.46 SCR's @ 3323' MD, 2696' TVD, MW 9.0 ppg, 02:00 hrs. MP #1 @ 30 = 120 psi; @ 40 = 140 psi MP#2@30=110 psi; @40=140 psi 10/29/2018 10/29/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 3900' MD T/ 4798' 3,900.0 4,798.0 06:00 12:00 MD 3053' TVD @ 700 GPM 1435 PSI, F/0=31%-150 RPM'S 7.51K TQ,W/ 9K WOB — OFF BTM PSI= 1430— PU 126K, S/0 -96K, ROT - 110K, 5.3K TQ , MAX GAS = 36 UNITS, ADT=4.4, BIT HRS=9.3, JAR HRS=72.86 SCR's @ 3987' MD, 2872' TVD, MW 9.1 ppg, 06:30 hrs. MP#1 @30=140 psi; @40=170 psi MP #2 @ 30 = 140 psi; @ 40 = 160 psi 10/29/2018 10/29/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 4798' MD T/ 5597' 4,798.0 5,597.0 12:00 18:00 MD 3235' TVD @ 750 GPM 1960 PSI, F/0=32%--170 RPM'S 7.3K TQ,W/ 11K WOB — OFF BTM PSI= 1950-- PU- 138K, S/0 -97K, ROT - 110K, 6K TO , MAX GAS = 30 UNITS, ADT=4.42, BIT HRS=13.72, JAR HRS=77.28 10/29/2018 10/30/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/5597' MD T/6354' 5,597.0 6,354.0 18:00 00:00 MD, 3406' TVD @ 750 GPM 2360 PSI, F/0=32% --150 RPM'S -- 12 K TQ,W/11KWOB—OFF BTM PSI=2330 -- PU-146 K, S/0-92 K, ROT=113 K, --7K TO, MAX GAS = 30 UNITS, ADT= 5, BIT HRS=18.72 , JAR HRS=82.28 SPR'S @ 5785' MD 3270 TVD, MW=9.3 PPG, @ 1920 HRS, MP#1) 30 SPM=220, 40 SPM= 260 PSI MP#2) 30 SPM=220, 40 SPM= 260 PSI Page 6/20 ReportPrinted: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tnne our (hr) Phase op Coce AWAY Code Time P -T -X operation (MB) End Dept (fiKB) 10/30/2018 10/30/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 6354' MD T/6977' 6,354.0 6,977.0 00:00 06:00 MD, 3545' TVD @ 750 GPM, 2360 PSI, 32% Flo W/ 130 RPM'S' 12K TQ, W/ 11 K WOB, OFF BTM PSI=2148, PU= 146K S/0=102K, ROT=116K, 8K TO, MAX GAS =30 UNITS, ADT=4.96, BIT HRS=23.68, JAR HRS=87.24 10/302018 10/30/2018 5.00 INTRM1 DRILL DDRL P Drill 9 7/8" Hole F/ 6977' MD T/7490' 6,977.0 7,490.0 06:00 11:00 MD, 3660' TVD @ 750 GPM ,2340 PSI, 30% F/O W/ 130 RPM'S' 8.51K TQ, W/ 10K WOB, OFF BTM PSI=2335, PU= 144K S/0=104K, ROT=120K, 81K TQ, MAX GAS =52 UNITS SPR'S @ 7017' MD 3553 TVD, MW=9.2 PPG, @ 0615 HRS, MP#1) 30 SPM=250, 40 SPM= 300 PSI MP#2) 30 SPM=250, 40 SPM= 300 PSI 10/30/2018 10/30/2018 0.50 INTRMI DRILL SVRG P INSPECTAND SERVICE #2 MUD 7,490.0 7,490.0 11:00 11:30 1 PUMP PULSATION DAMPENER. 70/30/2018 10/302018 0.50 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 7490' MD T/7563' 7,490.0 7,563.0 11:30 12:00 MD, 3674' TVD @ 750 GPM ,2370 PSI, 31% F/O W/ 160 RPM'S' 8.5K TQ, W/ 8.51K WOB, OFF BTM PSI=2360, PU= 144K S/O=104K, ROT=120K, 8K TQ, MAX GAS =52 UNITS, ADT=4.16, BIT HRS=27.84, JAR HRS= 91.4 10/30/2018 10/30/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 7563' MD T/8248' 7,563.0 8,248.0 12:00 18:00 MD, 3824' TVD @ 750 GPM ,2315 PSI, 31 % F/O W/ 160 RPM'S' 8.9K To, W/ 9K WOB, OFF BTM PSI=23620 PU= 146K S/0=111 K, ROT=122K, 7.5K TO, MAX GAS =78 UNITS, ADT=4.57, BIT HRS=32.41, JAR HRS= 95.97 10/30/2018 10/30/2018 0.50 INTRMI DRILL SFTY P ATTEND CPAI QUARTERLY 8,248.0 8,248.0 18:00 18:30 ASSESSMENT MTG, SIMOPS, CIRC W/ ROTATE AND RECIPROCATE F/ 8248' MD T/ 8192' MD @ 750 GPM 2380 PSI, 31 % F/O, 120 RPM'S 8K To. SPR'S @ 8247' MD 3821 TVD, MW=9.5 PPG, @ 18:20HRS, MP#1) 30 SPM=280, 40 SPM= 320 PSI MP#2) 30 SPM=280, 40 SPM= 320 PSI 10/30/2018 10/31/2018 5.50 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 8248' MD T/8941' 8,248.0 8,941.0 18:30 00:00 MD, 3984' TVD @ 750 GPM ,2768 PSI, 31% Flo W/ 160 RPM'S' 1 O TQ, W/ 12K WOB, OFF BTM PSI=2748 PU= 153K S/0=108K, ROT=1126K, 7.5K To, MAX GAS =33 UNITS, ADT=4.57, BIT HRS=32.41, JAR HRS= 95.97 -MDT/ 10/31/2018 10/31/2018 6.00 INTRMI DRILL DDRL P Drill 97/8"Hole F/894 96W 8,941.0 9,638.0 00:00 06:00 MD, 4141' TVD @ 750 GPM ,2850 PSI, 31 % F/O W/ 160 RPM'S' 1 OK TO, W/ 12K WOB, OFF BTM PSI=2800, PU=161K, S/0=111K, ROT=129K, 9K, MAX GAS UNITS =33, ADT 4.7, BIT HRS- 41.67, JAR HRS -105.23 Page 7120 Report Printed: 11 /2 012 01 8 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Cade Activity Code Time P -T -X Operation (MB) End Depth(td(B) 10/31/2018 10/31/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 9638 MD T/ 10400' 9,638.0 10,400.0 06:00 12:00 MD, 4313' TVD @ 750 GPM ,2485 PSI, 31 % F/O W/ 170 RPM'S' 11.81K TQ, W/ 8K WOB, OFF BTM PSI=2480, PU=170K, S/0=110K, ROT=135K, 9.51K, MAX GAS UNITS =26, ADT 4.69, BIT HRS- 46.36, JAR HRS -109.92 SPR'S @ 9856' MD 4191' TVD, MWT=9.7 PPG @ 07:30 MP#1) 30 SPM= 320 PSI, 40 SPM= 370 PSI MP#2) 30 SPM= 320 PSI, 40 SPM= 380 PSI 10/31/2018 10/31/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 10400 MD T/ 10,400.0 11,275.0 12:00 18:00 11275' MD, 4517' TVD @ 750 GPM ,2757 PSI, 32% F/O WI 170 RPM'S' 12.6K TQ, W/ 11 K WOB, OFF BTM PSI=2745, PU=173K, S/0=117K, ROT=137K, 12.5K TQ , MAX GAS UNITS =25, ADT 4.51, BIT HRS- 50.87, JAR HRS -114.43 10/31/2018 11/1/2018 6.00 INTRM1 DRILL DDRL P Drill 9718" Hole F/ 11275 MDT/ 11,275.0 12,124.0 18:00 00:00 12124' MD, 4695' TVD @ 750 GPM ,2660 PSI, 32% F/O W/ 150 RPM'S' 13.2K TQ, W/ 12K WOB, OFF BTM PSI=2663, PU=174K, S/0=125K, ROT=142K, 12K TQ , MAX GAS UNITS =34, ADT 4.02, BIT HRS- 54.89, JAR HRS -118.45 SPR'S @ 11464' MD 4560' TVD, MWT=9.7 PPG @ 19:30 MP#1) 30 SPM= 320 PSI, 40 SPM= 370 PSI MP#2) 30 SPM= 320 PSI, 40 SPM= 380 PSI 11/1/2018 11/1/2018 6.00 INTRMI DRILL DDRL P Drill 97/8"Hole F/12124'MD T/ 12,124.0 13,040.0 00:00 06:00 13040' MD, 4925" TVD @ 750 GPM ,2600 PSI, 32% F/O W/ 130 RPM'S' 12K TO, W/ 1 O WOB, OFF BTM PSI=2550, PU=185K, S/0=124K, ROT=144K, 11K TQ, MAX GAS UNITS =34, ADT 5.0, BIT HRS - 59.85, JAR HRS -123.40 11/1/2018 11/1/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 13040' MD T/ 13,040.0 13,829.0 06:00 12:00 13829' MD, 5121" TVD @ 750 GPM ,2858 PSI, 30% F/O W/ 130 RPM'S' 15K TO, W/ 15K WOB, OFF BTM PSI=2845, PU=197K, S/0=123K, ROT=147K, 14K TO, MAX GAS UNITS =27, ADT 4.69, BIT HRS- 64.54, JAR HRS -128.09 SPR'S @ 13166' MD 4962' TVD, MWT 9.5+ PPG, HRS 07:00 MP #1) 30=480 40=560 MP #2) 30=480 40=560 11/1/2018 11/1/2018 0.50 INTRMI DRILL DDRL P Drill 9 7/8" Hole F/ 13829' MD T/ 13,829.0 13,866.0 12:00 12:30 13866' MD, 5121" TVD @ 750 GPM ,2845 PSI, 31% F/O W/ 130 RPM'S' 15.5K TO, W/ 15K WOB, OFF BTM PSI=2810, PU=180K, S/0=130K, ROT=150K, 9K TQ , MAX GAS UNITS =27, ADT .25, BIT HRS - 64.79, JAR HRS -128.34 Page 8/20 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depm Sten Time End Tim Dur (hr) Phase Op Code Activity Code Time P -T -X Opembon (fMe) End Depth (ftKB) 11/1/2018 11/1/2018 3.00 INTRMI CASING CIRC P DUMP & DILUTE 580 BBLS NEW 13,866.0 13,824.0 12:30 15:30 _SND W/ CIRCULATING W/ ROT & RECIPROCATING F/ 13866'T/ 13796'MD @ 780 GPM, 2800 ICP, 2540 FCP, 33% F/O, 160 RPM'S, W/ 10K TO, ECD'S = 10.95, 24900 STK'S PUMPED. PU =180K„ S10=130, ROT=150K, 9K TQ OBTAIN SURVEY & SPR'S , LD/ DBL T/13824' MD MONITOR STATIC WELL F/ 30 MINS. SPR'S @ 13866' MD 5129' TVD, MWT 9.2 PPG, @ 14:55 HRS MP #1) 30=380 40=440 MP #2) 30=380 40=440 11/1/2018 11/1/2018 2.50 INTRMI CASING BKRM P BROOH F/ 13824' T/ 13072 MD' @ 13,824.0 13,072.0 15:30 18:00 775 GPM, 2500 PSI, 30% F/O, ECD=10.81, 160 RPM'S W/ 10K TO, PU=174K, S/0=130K, OBTAIN SURVEY'S @ 13685', 13592, 13497' MD'S 11/1/2018 11/2/2018 6.00 INTRMI CASING BKRM P BROOH F/ 13072'T/ 10400' MD, @ 13,072.0 10,400.0 18:00 00:00 775 GPM 2300 PSI 32% F/O, ECD=10.91, 160 RPM'S 8.6 TO ROTATING UP WT =128K. BROOH @ 850 - 1000 FT/HR. LDDP W/ MOUSE HOLE. 11/2/2018 11/2/2018 6.00 INTRMI CASING BKRM P BROOH F/ 10400' T/ 7600 MD @ 775 10,400.0 7,600.0 00:00 06:00 GPM, 2040 PSI, 32% F/O, ECD= 10.86, 160 RPM'S 8K TO ROTATING UP WT=115K. BROOH @ 850 - 1000 FT/HR. LDDP W/ MOUSE HOLE. 11/2/2018 11/2/2018 6.00 INTRMI CASING BKRM P BROOH FI 7600'T/ 4659' MD @ 775 7,600.0 4,659.0 06:00 12:00 GPM, 1800 PSI, 32% F/O, ECD= 11.1, 160 RPM'S 7K TQ ROTATING UP WT=100k. LDDP W/ MOUSE HOLE. OBSERVED HOLE ATTEMPTING TO PACK -OFF AT 5230' MD. SLOW SPEED AND CONT TO BROOH. 11/2/2018 11/2/2018 6.00 INTRMI CASING BKRM P BROOH F/ 4659' 713517 MD @ 775 4,659.0 3,517.0 12:00 18:00 GPM, 1508 PSI, 32% FIO, ECD= 10.37, 150 RPM'S 3K TO ROTATING UP WT=99K. LDDP W/ MOUSE HOLE. OBSERVED HOLE ATTEMPTING TO PACK -OFF AT 4600 MD & 4320' MD. SLOW SPEED AND CONT TO BROOH. 11/2/2018 11/2/2018 2.50 INTRMI CASING BKRM P CONT/ BROOH F/ 3517'T/ 3020' MD 3,517.0 3,020.0 18:00 20:30 @ 775 GPM, 1331 PSI, 31 % F/O, ECD= 9.72, 150 RPM'S 3K TO ROTATING UP WT=97K. LDDP W/ MOUSE HOLE. 11/2/2018 11/2/2018 1.25 INTRMI CASING BKRM P ROTATEAND RECIPROCATE F/ 3,020.0 2,850.0 20:30 21:45 3020' T/ 2850' MD @ 775 GPM, 1321 PSI, 31% F/0, ECD=9.65, 120 RPM'S, 3K TQ, UP WT=105, S/O WT=102, ROT WT=97K, TOTAL STKS PUMPED = 12166. 11/2/2018 11/2/2018 0.75 INTRMI CASING OWFF P OBSERVE SLIGHT FLOW W/ 2,850.0 2,850.0 21:45 22:30 MONITORING @ SHOE, OBSERVE UNTIL STATIC AND CONTINUE OBSERVE F/ 10 MINS. VERIFY NO FLOW. Page 9120 ReportPrinted: 1112 012 01 8 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start l ime End Tme Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (fiKB) End Depth(ttKB) 11/2/2018 11/2/2018 0.50 INTRMI CASING CIRC P PUMP 15 BBL, SLUG, 238 PSI, 2,850.0 2,850.0 22:30 23:00 BLOW DN TOP DRIVE. 11/2/2018 11/3/2018 1.00 INTRMI CASING PULD P POOH & CONT LD 5" DP F! 2850' MD 2,850.0 435.0 23:00 00:00 T/ 435' UP WT=58K, ON WT= 60K 11/3/2018 11/3/2018 1.00 INTRMI CASING PULD P CONT POOH, W/ 5" DP F/ 435' MD Tl 435.0 300.0 00:00 01:00 300' UWT- 58K, DWT=60K. 11/3/2018 11/3/2018 1.00 INTRMI CASING BHAH P LD, BHA#2 AS PER DD. 300.0 0.0 01:00 02:00 11/3/2018 11/3/2018 1.50 INTRMI CASING WWWH P PULL WEAR RING, FLUSH STACK 0.0 0.0 02:00 03:30 W/ JETTING TOOL, INSTALL TEST PLUG., REMOVE JT AND CLOSE BLIND RAMS, OPEN AND MONITOR ANNULAS 11/3/2018 11/3/2018 1.00 INTRMI CASING BOPE P REMOVE 3 1/2" X 6" VBR'S FROM 0.0 0.0 03:30 04:30 UPPER CAVITY & INSTALL 7 5/8" RAMS. 11/3/2018 11/3/2018 0.75 INTRMI CASING BOPE P INSTALL TEST JOINT, PURGEJT 0.0 0.0 04:30 05:15 W/ WATER TEST 7 5/8" RAMS & ANNULAR 250/3500 PSI 5 MINS EACH. ALL GOOD TESTS. 11/3/2018 11/3/2018 0.25 INTRMI CASING BOPE P PULL TEST PLUG, BLOW DOWN 0.0 0.0 05:15 05:30 KILL LINE DRAIN STACK. 11/3/2018 11/3/2018 1.75 INTRMI CASING RURD P RU/ T/RUN HYDRIL 563 29.7#-7 0.0 0.0 05:30 07:15 5/8" CASING/ RU FILL UP LINE, RU/ CRT" VOLANT", RU/ POWER TONGS, & FULL OPENING SAFETY VALVE T/ CROSSOVER. 11/3/2018 11/3/2018 4.50 INTRMI CASING PUTB P MU SHOE TRACK & CHECK 0.0 3,023.0 07:15 11:45 FLOATS. ALL GOOD. RIH Wl 7 5/8" T/ 3023 MD' FILLING EVERY JT ON THE FLY. TOPPING OFF EVERY 10 JTS,- TO CONNECTIONS T/ 10,300 FT/LBS T0- UP WT =109K SOI 106K 11/3/2018 11/3/2018 0.25 INTRM1 CASING CIRC P ESTABLISH CIRCULATION @ 3023' 3,023.0 3,023.0 11:45 12:00 MD STAGE UP PUMPS T/ 7.5 BPM, ICP=138 PSI FCP=191 PSI W/21% FIC, UP WT=109K S/0=106K-- TOTAL STKS PUMPED = 2679 11/3/2018 11/3/2018 0.50 INTRMI CASING CIRC P CONTINUE CIRC/CONDITIONING 3,023.0 3,023.0 12:00 12:30 MUD @ 3023' MD @ 7.5 BPM,--191 PSI W/ 21% F/O UP WT=109K S/0=106K-- TOTAL STKS PUMPED= 2679 11/3/2018 11/312018 5.50 INTRMI CASING PUTB P RIH W/ 7 5/8" 29.7# L-80 HYDRIL 563 3,023.0 7,000.0 12:30 18:00 F/ 3023' T/ 7000' MD CONT/ FILLING ON THE FLY & TOPPING OFF EVERY 10 JTS. TO CONNECTIONS T/ 10,300 FT/LBS . 11/3/2018 11/3/2018 1.00 INTRMI CASING CIRC P EST CIRC / STAGE UP PUMPS T/ 5 7,000.0 7,000.0 18:00 19:00 BPM 300 PSI W/ 13 % F/0 UP WT=109K SIO =106K TOTAL STKS PUMPED =2878 11/3/2018 11/4/2018 5.00 INTRMI CASING PUTB P CONT/ RIH F/ 7000'T/ 10677' AS 7,000.0 10,677.0 19:00 00:00 PER CASING DETAIL, CONT/ FILLING ON THE FLY, TOPPING OFF EVERY TEN JOINTS. 11/4/2018 11/412018 0.50 INTRMI CASING PUTB P RIH W/ 7 5/8" 29.7# L-80 HYDRIL 563 10,677.0 10,890.0 00:00 00:30 F/ 10677'T/ 10890' MD CONT/ FILLING ON THE FLY & TOPPING OFF EVERY 10 JTS. TO CONNECTIONS T/ 10,300 FT/LBS . Page 10120 Report Printed: 11120/2018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Startrime End rime Our (hr) Phase Op Code Activity Code Time P-T-X Operation (MB) End Depth (ftKB) 11/4/2018 11/4/2018 1.00 INTRMI CASING CIRC P ESTABLISH CIRC/ COND MUD @ 10,890.0 10,890.0 00:30 01:30 10890' STAGE UP PUMP T/ 5.5 BPM 514 PSI, 13% F/O, UP WT=189K S/O WT=114K TOTAL STROKES PUMPED=4111 11/412018 11/4/2018 1.00 INTRMI CASING PUTS P RIP W/75/8"29.7#L-80 HYDRIL 563 10,890.0 11,572.0 01:30 02:30 F/ 10890'T/ 11 572'MD CONT/ FILLING ON THE FLY & TOPPING OFF EVERY 10 JTS. TO CONNECTIONS T/ 10,300 FT/LBS . 11/4/2018 11/4/2018 0.50 INTRMI CASING SVRG P TROUBLESHOOT PIPE SKATE, 11,572.0 11,572.0 02:30 03:00 CIRCULATE AND RECIPROCATE PIPE 11/4/2018 11/4/2018 3.75 INTRMI CASING PUTB P RIH W/ 7 5/8" 29.7# L-80 HYDRIL 563 11,572.0 13,857.9 03:00 06:45 F/ 11562'MD T/ 13857.9' MD CONT/ FILLING ON THE FLY & TOPPING OFF EVERY 10 JTS. TO CONNECTIONS T/ 10,300 FT/LBS . 11/4/2018 11/4/2018 1.75 INTRMI CEMENT CIRC P ESTABLISH CIRCULATION, 13,857.9 13,857.9 06:45 08:30 RECIPROCATING PIPE 10'-20' STAGE PUMP UP T/ 7 BPM, ICP=500 PSI, FCP= 730 PSI W/ 17% F/0, UP WT=189K SIO WT= 114K, TOTAL STROKES PUMPED =5843 11/4/2018 11/4/2018 0.75 INTRMI CEMENT RURD P BLOW DN TOP DRIVE, RU/ CEMENT 13,857.9 13,857.9 08:30 09:15 HOSE & CMT MANIFOLD T/ VOLANT CRT,& CLOSE LOWER IBOP ON TD. 11/4/2018 11/4/2018 2.75 INTRMI CEMENT CIRC P ESTABLISH CIRC/ @ 13874' MD, 13,857.9 13,857.9 09:15 12:00 RECIPROCATE PIPE 10'-20' STAGE PUMPS UP T/ 7 BPM, ICP=300 PSI, FCP=640 PSI 11/4/2018 11/4/2018 1.00 INTRMI CEMENT CIRC P CONT CIRC & COND MUD@ 13874' 13,857.9 13,857.9 12:00 13:00 MD. W/ RECIPROCATING PIPE, CIRC THROUGH CMT LINE @ 7 BPM 640 PSI, W/ 17% F/0. UP WT=217K S/0 WT=109K TOTAL STROKES PUMPED =16035, FCP=654, UP WT=220K S/O WT=112K 11/4/2018 11/4/2018 0.25 INTRMI CEMENT CIRC P CONTI CIRC & CONDITION MUD, 13,857.9 13,857.9 13:00 13:15 PJSM W/SCHLUMBERGER CEMENTERS & RIG PERSONNEL. 11/4/2018 11/412018 4.00 INTRMI CEMENT CMNT P CEMENTAS PER DETAIL 13,857.9 0.0 13:15 1715 Pump 5 bbls water. Test lines to 4000 psi. Drop bottom plug. Batch & pump 75 bbls of 12.5 ppg Mud Push II, @ 3 bpm, W/ ICP=450 FCP=220 W/8% FO. Drop intermediate plug. Batch & pump 303 bbls 15.8 ppg Class G cement @ 5 BPM ICP=305 FCP=215 psi, w/15% FO. Drop top plug. Pump 10 bbls water. Swap to rig and displace with 9.5 ppg treated LSND @ 7 bpm ICP=121 psi, FCP= 676 psi. Land casing @ 3650 STKS W167K hookload. Reduce rate t/6 bpm @ 5075 stks, w/ 1100 psi, F/0=16% Reduce Rate T/ 3 bpm, @ 6700 STKS,ICP= 955 FCP=1071 8% FIG. Bump plug 6166 STKS. Pressure up to 1500 psi, hold 5 Mins, verify floats. CIP at 1705 hrs. 0.75 INTRMI CEMENT PRTS P 7 518'CSG T/ 3500 PSI F/ 30 0.0 0.0 MINS/ GOOD TEST. 81 STKS T/ =114102018 JPT/ REACH TEST PSI/ 8.1 BBLS BLED OFF Page 11120 ReportPrinted: 11/2012018 Summary (with Timelog Depths) isOperations 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time I End Time Duron Phase Op Code Activity Code Time P-T-X Operation (fiKB) End Depth(fiKB) 11/4/2018 11/4/2018 1.00 INTRMI CEMENT RURD P BLOW DN CEMENT LINE, REMOVE 0.0 0.0 18:00 1900 & CLN CEMENTING VALVES RD CMTASSEMBLY. RD VOLANT TOOL. REM LANDING JT CLEAN & CLEAR FLR. 11/4/2018 11/4/2018 1.50 INTRMI CEMENT WWSP P MU RUNNING TOOL T/ HWDP 0.0 0.0 1900 2030 INSTALL 7 5/8" X 10 3/4" PACK OFF TEST SEALS T/ 5000 PSI, 10 MINS WITNESSED BY CPAI REPRESENTATIVE. 11/4/2018 11/4/2018 1.50 INTRMI CEMENT ROPE P REMOVE UPPER 7 5/8" FIXED 0.0 0.0 20:30 22:00 RAMS & CO/ T 3 1/2" X 6" VBR'S. SIMOPS CHANGE TD SAVER SUB T/ XT-39. LOAD AND STRAP 4" DP IN PIPE SHED 11/4/2018 11/5/2018 2.00 INTRMI WHDBOP BORE P Perform bi-weekly BOPE test. Test 0.0 0.0 22:00 00:00 waived by AOGCC Rep Adam Earl Test w/ 4 1/2" test joint. 250/3500 psi- 5 min each. Following tests done with 4 1/2" test joint. Test #1-Annular & CV's 1,12,13,14, 4" kill Demco, 4" dart valve. Test #2-Upper 3 1/2" x 6" VBR, CV's 9,11, mezzanine kill line valve, 4" FOSV Test #3-CV's 8,10, kill HCR. Test #4- CV's 6,7, manual kill line valve. Test #5- Super choke and manual choke at 250/3000 psi. Test #6 - CV's 2 & 5 & Lower IBOP 11/5/2018 11/5/2018 2.50 INTRMI WHDBOP BOPE P PERFORM ACCUMULATOR TEST, 0.0 0.0 00:00 0230 KOOMEY PSI=2950, MANIFOLD PSI=1450, 1800 PSI AFTER FUNCTIONS PERFORMED, 200 PSI GAIN=10 SECONDS, . FULL RECHARGE= 53 SECONDS. TEST BLINDS,CV'S 3,4,6. TESTANNULAR W/ 4' TEST JOINT & HCR CHOKE, TEST UPPER RAMS W/ 4' TEST JOINT, MAN CHOKE, TEST LOWER RAMS W/ 4'AND 4 1/2" TEST JOINTS ALL GOOD TESTS. 11/5/2018 11/5/2018 0.50 INTRMI WHDBOP RURD P RD TESTING EQUIPMENT, B/D 0.0 0.0 02:30 03:00 CHOKE AND KILL LINES. PULL TEST PLUG INSTALL 9 1/16" ID WEAR BUSHING. 11/5/2018 11/5/2018 1.00 INTRMI CEMENT SLPC P SLIP & CUT 75' 1.625 DRILLING 0.0 0.0 03:00 0400 LINE CALIBRATE BLOCKS 11/5/2018 11/5/2018 0.75 INTRMI CEMENT BHAH P PICK UP BHA COMPONENTS T/ RIG 0.0 0.0 04:00 0445 FLR & STAGE / PICK UP MPD BEARING. 11/5/2018 11/5/2018 1.75 INTRMI CEMENT BHAH P MU/ 6 3/4" BHAAS PER PLAN T/ 375' 0.0 375.0 04:45 06:30 1 1 1MD, 11/5/2018 11/5/2018 0.50 INTRMI CEMENT SVRG P SERVICE TD, VISUAL INSPECTION. 375.0 375.0 06:30 07:00 11/5/2018 11/5/2018 1.50 INTRMI CEMENT PULD P CONT RI W/ BHA#3. PU/ 4' XT-39 375.0 2,275.0 07:00 0830 DP FROM PIPE SHED,/ SINGLE IN HOLE F/ 375' MD T/ 2275' MD. 11/5/2018 11/5/2018 0.50 INTRMI CEMENT DHEA P SURFACE TEST MWD (PULSE) @ 2,275.0 2,275.0 08:30 0900 2275' MD. @ 225 GPM.--1066 PSI, W/ 14% F/O. UP WT =87K, S/0 WT =76K 11/5/2018 11/5/2018 1.25 INTRMI CEMENT PULD P CONT/ PU 4' XT-39 DP F/ 2275'T/ 2,275.0 3,034.0 09:00 10:15 1 1 1 13034' Page 12120 ReportPrinted: 11/2012018 , Operations Summary (with Timelog Depths) =1 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Stars Depth (ttKB) End Depth (WB) 11/5/2018 11/5/2018 1.00 INTRMI CEMENT QEVL P MAD PASS F/ 3034' MD T/ 3605' MD 3,034.0 3,605.0 10:15 11:15 @ 900' PER HOUR BUILDING STANDS VIA THE MOUSEHOLEJ FILLING PIPE EVERY 20 STDS. BLOW DOWN TD AFTER EACH FILL. 11/5/2018 11/5/2018 0.75 INTRMI CEMENT PULD P CONT/ PU 4' XT -39 DP F/ 3605' MD 3,605.0 4,270.0 11:15 1200 T/ 4270' MD, UP WT=98K S/O ST=76K. FILL PIPE EVERY 20 STDS. BLOW DN TOP DRIVE AFTER EACH FILL. 11/5/2018 11/5/2018 2.25 INTRMI CEMENT PULD P CONT/ PU 4' XT -39 DP F/ 4270' MD 4,270.0 5,978.0 12:00 1415 T/ 5978' MD, UP WT=115K S/O ST=75K. FILL PIPE EVERY 20 STDS. BLOW DN TOP DRIVE AFTER EACH 11/5/2018 11/5/2018 3.75 INTRMI CEMENT QEVL P CONT. PU XT 39 DP W/ MADD 5,978.0 8,060.0 14:15 18:00 PASSING @ 900' HOUR F/ 5978 MD T/ 8060' MD. SIMOPS FREEZE PROTECT THE OA (10 3/4" X 7 5/8") ANNULAS W/ LRS 650 PSI T/ INJECT W/ DIESEL. 5 BBLS INJECTED , 118 BBLS H2O PUMPED @ 2 BPM ICP=550 PSI, FCP=590 PSI, 128 BBLS DIESEL PUMPED @ 2 BPM, ICP= 600 PSI, FCP=750 PSI. 11/5/2018 11/5/2018 1.50 INTRM1 CEMENT MPDA P PULL TRIP NIPPLE AND INSTALL 8,060.0 8,060.0 18:00 1930 MPD BEARING ON STD, INSTALL DRILL NIPPLE, PRACTICE RAMP W/ CREW 11/5/2018 11/5/2018 1.50 INTRMI CEMENT MPDA P PULL MPD BEARING, REMOVE 8,060.0 8,060.0 19:30 21:00 DRILL NIPPLE AND INSTALL TRIP NIPPLE. 11/5/2018 11/6/2018 3.00 INTRMI CEMENT QEVL P CONT/ RIH- PICKING UP 4" XT -39 8,060.0 9,872.0 21:00 0000 DP F/ 8060' MD T/ 9872' MD @ 15' PER MINUTE/900' HR MAX SPEED/ CONTINUE FILLING PIPE EVERY 20 STDS. BLOW DOWN TO AFTER EACH FILL. 11/6/2018 11/6/2018 0.75 INTRMI CEMENT QEVL P Continue to RIH with BHA#3 picking 9,872.0 10,347.0 00:00 0045 up 4" DP MAD passing at 58'/hr. from 9872' MD to 10347' MD. PU 157K SO 51 K. Fill pipe every 20 stds. 11/6/2018 11/6/2018 8.25 INTRMI CEMENT QEVL P Continue to RIH with BHA#3 picking 10,347.0 13,665.0 00:45 0900 up 4" DP MAD passing at 58'/hr from 10347' MD to 13665' MD. Rotate at 40 rpm, 15K tq, 220 gpm, 1669 psi. Rotating down weight 96K. 11/6/2018 11/6/2018 0.50 INTRMI CEMENT RGRP T Repair top drive service loop power 13,665.0 13,665.0 09:00 0930 track. 11/6/2018 11/6/2018 0.50 INTRM1 CEMENT COCF P Wash and ream from 13665' MD to 13,665.0 13,759.0 09:30 1000 13759' MD. 220 gpm, 1712 psi, 14% FO, 40 rpm, 14K tq. PU 183K Rot 100K. Tag cement plugs at 13759' MD. 11/6/2018 11/6/2018 2.00 INTRMI CEMENT DRLG P Drill plugs, float collar and cement 13,759.0 13,855.0 10:00 1200 from 13759' MD to 13855' MD. 176- 247 gpm, 1272-2312 psi, 11-14% FO, 40-80 rpm, 17K tq, 2-8K WOB. PU 183K Rot 100k. 11/6/2018 11/6/2018 7.00 INTRMI CEMENT DRLG P Drill85ing on float shoe.from 13855' MD 13,855.0 13,858.0 12:00 19:00 to 138' MD. 230 gpm, 2040 psi, 17% FO, 40-100 rpm, 17-20K tq, 2-15 WOB. PU 183K Rot 100K. Experiencing 23 to 40K overpull. . Page 13120 ReportPrinted: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Mme End Time Dur (ho Phase Op Code Activity Ca a Time P -T -X Operation Start Depth (aKS) Ed Depth Irks) 11/6/2018 11/6/2018 1.25 INTRMI CEMENT DRLG P Displace to 9.5 ppg KlaSheild mud 13,858.0 13,866.0 19:00 20:15 system while drilling shoe and rathole fro 13858' MD to 13866' MD. 260 gpm, 1900 psi, 17% FO, 90-100 rpm, 11 K tq, 2K WOB, PU 180K SO 86K Rot 114K. 11/6/2018 11/6/2018 0.25 INTRMI CEMENT DDRL P Drill 20' new hole from 13866' MD to 13,866.0 13,886.0 20:15 20:30 13886' MD. 5129' TVD, 260 gpm, 2000 psi, 19% FO, 100 rpm, 11 K tq, 4- 7k WOB, 11.2 ECD, PU 183K SO 86K Rot 114K Max gas 22, ADT=.25 Bit hrs=.25 Jar hrs=198.18 11/6/2018 11/6/2018 2.50 INTRMI CEMENT CIRC P Circulate and condition mud for LOT. 13,886.0 13,755.0 20:30 23:00 Rotate and reciprocate from 13886' MD to 13850' MD. 260 gpm, 1900 psi, 16% FO, 90 rpm, 11 K tq, PU 115K SO 86K Rot 114K. Total strokes pumped 4700. Stand back stand #143. 11/6/2018 11/7/2018 1.00 INTRMI CEMENT LOT P Rig up and perform LOT. 13,755.0 13,755.0 23:00 00:00 11/7/2018 11/7/2018 1.50 INTRMI CEMENT LOT T Repeat LOT due to inconclusive 13.755.0 13,755.0 00:00 01:30 results. 16.2 ppg EMW acheived. Consult with rig engineer on results. Rig down and blow down test equipment. 11/7/2018 11/7/2018 1.25 PROD1 DRILL MPDA P Pull trip nipple. Install drill nipple and 13,755.0 13,886.0 01:30 02:45 RCD. Obtain SPR and break in bearing. Wash and ream down from 13755' MD to 13886' MD. 80 rpm, 10K tq, 250 gpm, 1990 psi. SCR @ 13852' MD, 5126' TVD, MW 9.5ppg, 02:30 hrs. #1 @ 20 = 500 psi; @ 30 = 730 psi #2 @ 20 = 500 psi; @ 30 = 730 psi 11/7/2018 11/7/2018 3.25 PROD1 DRILL DDRL P Directional drill 3/4" production hole 13,886.0 14,232.0 02:45 06:00 section from 13866' MD to 14232' MD, 5210' TVD, 260 gpm, 2190 psi, FO 19%,140 rpm, Tq 13K, WOB 8K, ECD 11.31, OFF BTM 2166 psi, PU 169K, SO 72K, ROT 112K, Tq 10K, Max Gas 22 ADT 2.43 hrs, Bit hrs=2.68, Jars hrs=200.61. Total footage 346'. 11/7/2018 11/7/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 14,232.0 14,993.0 06:00 12:00 section from 14232' MD to 14993' MD, 5279' TVD, 260 gpm, 2312 psi, FO 11%, 140 rpm, Tq 13K, WOB 8K, ECD 11.57, OFF BTM 2298 psi, PU 172K, SO 66K, ROT 114K, Tq 11 K, Max Gas 94 ADT 4.73 hrs, Bit hrs=7.16, Jars hrs=205.34. Total footage 761'. 11/7/2018 11/7/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 14,993.0 15,733.0 12:00 18:00 section from 14993' MD to 15733' MD, 5284' TVD, 260 gpm, 2424 psi, FO 11%, 140 rpm, Tq 13.5K, WOB 4-7K, ECD 11.64, OFF BTM 2403 psi, PU 173K, SO 53K, ROT 113K, Tq 12K, Max Gas 77 units ADT 4.19 hrs, Bit hrs=11.35, Jars hrs=209.53. Total footage 740'. Page 14120 ReportPrinted: 11/20/2018 Operations Summary (with Timelog Depths) r 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hn Phase Op Cade Activity Code Time P -T -X Operation Sen Depm IfiKB) End Depth (ftKB) 11/7/2018 11/8/2018 6.00 PRODt DRILL DDRL P Directional drill 6 3/4" production hole 15,733.0 16,402.0 18:00 00:00 section from 15733' MD to 16402' MD, 5281' TVD, 260 gpm, 2630 psi, FO 12%,140 rpm, Tq 14K, WOB 7-9K, ECD 11.8, OFF BTM 2590 psi, PU 170K, SO 53K, ROT 11 OK, Tq 13K, Max Gas 35 units ADT 4.35 hrs, Bit hrs=15.7, Jars hrs=213.88. Total footage 669'. 11/8/2018 11/8/2018 6.00 PROD1 DRILL DDRL P Directional drill 63/4" production hole 16,402.0 17,160.0 00:00 06:00 section from 16402' MD to 17160' MD, 5275' TVD, 260 gpm, 2739 psi, FO 12%,140 rpm, Tq 14K, WOB 7-9K, ECD 12.04, OFF BTM 2730 psi, PU 170K, SO 48K, ROT 114K, Tq 13K, Max Gas 42 units ADT 4.3 hrs, Bit hrs=20, Jars hrs=218.18. Total footage 758'. 11/8/2018 11/8/2018 6.00 PRODt DRILL DDRL P Directional drill 63/4" production hole 17,160.0 17,836.0 06:00 12:00 section from 17160' MD to 17836' MD, 5264' TVD, 260 gpm, 2776 psi, FO 12%,140 rpm, Tq 14K, WOB 7K, ECD 11.77, OFF BTM 2769 psi, PU 181 K, SO N/A, ROT 128K, Tq 12K, Max Gas 180 units ADT 4.5 hrs, Bit hrs=24.5, Jars hrs=222.68. Total footage 676'. SCR @ 17236' MD, 5274' TVD, MW 9.5ppg, 06:30 hrs. #1 @ 20 = 790 psi; @ 30 = 1060 psi #2 @ 20 = 790 psi; @ 30 = 1020 psi 11/82018 11/8/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 17,836.0 18,518.0 12:00 18:00 section from 17836' MD to 18518' MD, 5248' TVD, 260 gpm, 2793 psi, FO 11%, 140 rpm, Tq 15K, WOB 7K, ECD 11.88, OFF BTM 2750 psi, PU 183K, SO 60K, ROT 130K, Tq 13.5K, Max Gas 104 units ADT 4.16 hrs, Bit hrs=28.66, Jars hrs=226.84. Total footage 682'. 11/82018 11/9/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 18,518.0 19,274.0 18:00 00:00 section from 18518' MD to 19274' MD, 5231' TVD, 260 gpm, 2900 psi, FO 11 %, 140 rpm, Tq 14K, WOB 8K, ECD 11.88, OFF BTM 2878 psi, PU 187K, SO 70K, ROT 134K, Tq 11.4K, Max Gas 50 units ADT 4.59 hrs, Bit hrs=33.25, Jars hrs=231.43. Total footage 756'. SCR @ 18709' MD, 5244' TVD, MW 9.5 ppg, 19:00 hrs. #1 @ 20 = 695 psi; @ 30 = 1000 psi #2 @ 20 = 700 psi; @ 30 = 970 psi 11/9/2018 11/9/2018 5.25 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 19,274.0 19,862.0 00:00 05:15 section from 19274' MD to 19862' MD, 5219' TVD, 260 gpm, 3081 psi, FO 11%, 140 rpm, Tq 13.6K, WOB 8K, ECD 11.97, OFF BTM 3072 psi, PU 180K, SO 48K, ROT 127K, Tq 11.4K, Max Gas 50 units ADT 3.83 hrs, Bit hrs=37.08, Jars hrs=235.26. Total footage 588'. Page 15120 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 .. Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Tune End Tme our (hr) Phase Op Code Ac vRy Code Time P-T-X Operation start Depth (RKB) End Depth (RKB) 11/9/2018 11/9/2018 0.75 PROD1 CASING CIRC P Take final survey, Set RSS to zero 19,862.0 19,862.0 05:15 06:00 deflection and obtain SPR's. SCR @ 19862' MD, 5219' TVD, MW 9.5 ppg, 05:30 hrs. #1 @ 20 = 770 psi; @ 30 = 1080 psi #2 @ 20 = 770 psi; @ 30 = 1095 psi 11/9/2018 1119/2018 1.75 PROD1 CASING CIRC P CBU while BROOH with 1 stand DP 19,862.0 19,742.0 06:00 07:45 from 19862' MD to 19742' MD. 250 gpm, 3078 psi, 14% FO, 115 rpm, 10.5K tq, 11.68 ECD. PU 180K SO 88K Rot 130K. 6311 total strokes pumped. 11/9/2018 11/9/2018 0.25 PROD1 CASING OWFF P Perform MPD drawdown test. No 19,742.0 19,742.0 07:45 08:00 indication of flow or ballooning. 11/9/2018 11/9/2018 0.50 PROD1 CASING OWFF P Monitor well. Static. 19,742.0 19,742.0 08:00 0830 11/9/2018 11/9/2018 3.50 PROD1 CASING BKRM P BROOH from 19742' MD to 18801' 19,742.0 18,801.0 08:30 1200 MD. 800 fph, 260 gpm, 3046 psi, 14% FO, 140 rpm, 12K tq, 11.68 ECD. PU w/pump=136K. Hold 400 psi on connections. 11/9/2018 1119/2018 6.00 PROD1 CASING BKRM P Continue to BROOH from 18801' MD 18,801.0 16,963.0 12:00 18:00 to 16963' MD. 800 fph, 260 gpm, 2634 psi, 24% FO, 140 rpm, 10K tq, 11.46 ECD. PU w/pump=121 K. Hold 400 psi on connections. 11/9/2018 11/10/2018 6.00 PROD1 CASING BKRM P Continue to BROOH from 16963' MD 16,963.0 14,711.0 18:00 00:00 to 14711' MD. 800 fph, 260 gpm, 2380 psi, 26% FO, 140 rpm, 9K tq, 11.16 ECD. PU 153K SO 86K. Hold 400 psi on connections. 11/10/2018 11/10/2018 2.75 PRODt CASING BKRM P Continue to BROOH from 1471 VMD 14,711.0 13,752.0 00:00 02:45 to 13752' MD. 800 fph, 260 gpm, 2370 psi, 23% FO, 140 rpm, 6K tq, 11.18 ECD. PU 146K SO 89K. Hold 400 psi on connections. 11/10/2018 11/10/2018 2.25 PRODt CASING CIRC P CBU x2. Rotate and reciprocate from 13,752.0 13,752.0 02:45 05:00 13752' MD to 13662' MD. 260 gpm, 2400 psi, 14% FO, 120 rpm, 6.2K tq, 11.1 ECD. PU 142K SO 95K. 11/10/2018 11/10/2018 0.75 PROD1 CASING OWFF P Monitor well. Slight flow diminishing to 13,752.0 13,752.0 05:00 0545 static. 11/10/2018 11/10/2018 0.25 PRODt CASING CIRC P Pump 25 bbl 12.5 ppg dry job. Blow 13,752.0 13,752.0 05:45 06:00 down TD. Drop 1 7/8" rabbit. 11/10/2018 11/10/2018 5.50 PROD1 CASING SMPD P Strip OOH as per schedule from 13,752.0 3,034.0 06:00 11:30 13752' MD to 3034' MD. PU 142K SO 95K. 11/10/2018 11/10/2018 1.00 PROW CASING CIRC P Circulate out dryjob. 210 gpm, 1024 3,034.0 3,034.0 11:30 12:30 psi, 8% FO. Total strokes pumped=1326. Blow down TD. 11/10/2018 11/10/2018 1.25 PROD1 CASING SMPD P Continue to Strip OOH as per 3,034.0 375.0 12:30 13:45 schedule from 3034 MD to 375' MD. PU 86K SO 85K. 11/10/2018 11/10/2018 1.25 PRODi CASING MPDA P PJSM-Pull drain nipple, remove RCD. 375.0 375.0 13:45 15:00 Install trip nipple. 11/10/2018 11/10/2018 0.75 PROD1 CASING RURD P Clean and clear dg floor due to wet 375.0 375.0 15:00 15:45 trip. Sim-ops/Blow down MPD lines. 11/10/2018 11/10/2018 1.25 PROW CASING SHAH P Lay down BHA #3 as per SLB DD. 375.0 0.0 15:45 17:00 11110/2018 11/10/2018 1.00 PROD1 CASING BHAH P Clean and clear rig floor. 0.0 0.0 17:00 18:00 1 1 Page 16/20 Report Printed: 11120/2016 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stars Time End Time Our (hd Phase Op Code Activity Code Time P -T -X Operation Start Depth mKB) End Depth(ffKB) 17/70/2078 11/10/2018 1.50 COMPZN CASING RURD P Rig up casing running equipment. 0.0 0.0 18:00 19:30 Position jewelry in running order in pipe shed. Mobilize frac sleeves to rig floor and drift same 11/10/2018 11/10/2018 0.75 COMPZN CASING WWWH P Make up stack washing tool. Flush 0.0 0.0 19:30 2015 BOPE at 20 bpm. Rig down and blow down. 11/10/2018 11/10/2018 0.25 COMPZN CASING SFTY P Conduct PJSM for picking up liner. 0.0 0.0 20:15 2030 11/10/2018 11/10/2018 0.75 COMPZN CASING PUTB P Make up float track and WIV assy 0.0 150.0 20:30 21:15 Pump through floats at 2 bpm, 70 psi. Blow down TD. 11/10/2018 17/11/2018 2.75 COMPZN CASING PUTB P RIH picking up 4 1/2" L-80 12.6# Hyd 150.0 1,560.0 21:15 00:00 563 liner from 150' MD to 1560' MD installing centralizers as per running order. Torque connections to 3800 fUlbs- PU 57K SO 62K 11/11/2018 11/11/2016 6.50 COMPZN CASING PUTS P RIH picking up 4 1/2" L-80 12.6# Hyd 1,560.0 6,099.0 00:00 06:30 563 liner from 1560' MD to 6099' MD installing centralizers as per running order. Torque connections to 3800 ft/lbs. PU 83K SO 74K 11/11/2018 11/11/2018 1.25 COMPZN CASING OTHR P Make up liner hanger and liner top 6,099.0 6,166.0 06:30 07:45 packer and one stand of DP. 11/11/2018 11/11/2018 1.00 COMPZN CASING CIRC P Make up TD. TIH to 6260' MD. 6,166.0 6,260.0 07:45 08:45 Circulate one liner volume. 127 gpm, 430 psi, 9% FO, Total strokes=950. PU 82K SO 75K Blow down TD. Sim- ops/Rig down casing running equipment. 11/11/2018 11/11/2018 2.00 COMPZN CASING RUNL P RIH with 4 1/2" liner on 4" DP out of 6,260.0 9,425.6- 08:45 1045 derrick from 6260' MD to 9425' MD at 90 fpm. Fill pipe with fill up line. 11/11/2018 17/17/2018 0.50 COMPZN CASING CIRC P Break circulation. 3 bpm, 516 ps, 9% 9,425.0 9,425.0 10:45 11:15 FO. Obtain rotating parameters. 10 rpm, 3.5K tq, PU 110K SO 86K Rot 98K. Blow down TD. 11/11/2078 11/11/2018 2.50 COMPZN CASING RUNL P RIH with 4 1/2" liner on 4" DP out of 9,425.0 13,765.0 11:15 1345 derrick from 9425' MD to 13765' MD at 90 fpm. Fill pipe with fill up line. 77/11/2018 11/11/2018 0.50 COMPZN CASING CIRC P Break circulation. 3 bpm, 700 psi 9% 13,765.0 13,765.0 13:45 1415 FO. Obtain rotating parameters. 10 rpm, 10K tq, PU 137K SO 91 K Rot 106K. Blow down TD. 17/11/2018 11/11/2018 4.00 COMPZN CASI -NG RUNL P RIH with 4 112" liner on 4" DP out of 13,765.0 19,853.0 14:15 1815 derrick from 13765' MD to 19853' MD at 90 fpm. Fill pipe with fill up line. PU 190K SO 94K 17/11/2018 11/11/2018 0.25 COMPZN CASING HOSO P RIH and tag TD at 19867.43' MD. 19,853.0 19,857.0 18:15 18:30 Pick up and set shoe on depth at 19857' MD. 17/17/2018 11/11/2018 2.00 COMPZN -EASING CIRC P Circulate and condition mud. 3.5 bpm, 19,857.0 19,857.0 18:30 2030 1070 psi, 9% FO. Total strokes pumped=4000 11/11/2018 11/17/2018 1.50 COMPZN CASING DISP P Displace liner and open hole to 9.5 19,857.0 19,857.0 20:30 22:00 ppg NaCl brine. Pump 40 bbls 10.2 ppg hi -vis spacer followed by180 bbls 9.5 ppg NaCl brine. 3 bpm, 1250 psi. Page 17120 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur(hd Phase Op Code Activity Code Time P -T -X Operation Stan Depth (fiKa) End Depth(ffKa) 11/11/2018 11/12/2018 2.00 COMPZN CASING PACK T Drop 1.25" OD WiV ball. Pump 10 bbls 19,857.0 19,857.0 22:00 00:00 10.2 ppg hi -vis spacer/100 bbls 9.5 ppg NaCl brine/30 bbls 10.2 ppg hi -vis spacer/77 bbls 9.5 ppg NaCl brine. 3 bpm, 1250 psi. At 170 bbls into displacement reduce rate to 2 bpm, 796 psi, 5% FO. Ball on seat at 2121 stks. Pressure up to 2200 psi. Set down 50K to confirm hanger is set. Observed weight increase to 106K indicating hanger not set. Attempt to set down 50K and observed liner moving down hole. PU and attempt to set hanger 2x with increased pressure of 2300 and 2500 psi. Unsuccessful. PU 190K SO 94K, 11/12/2018 11/12/2018 0.50 COMPZN CASING PACK T Pick up to shoe depth of 19854' MD. 19,857.0 19,854.0 00:00 00:30 Increase pressure to 4000 psi. Set down 50K. Bleed off pressure. Pick up to free weight. Rotate at 15 rpm, 5K tq.Set down 40K to set packer Pick up and release running tool. TOL=13693.75' MD Shoe=19854.43' MD, 11/12/2018 11/12/2018 0.50 COMPZN CASING PRTS P Rig up and test liner top packer to 19,854.0 19,854.0 00:30 01:00 3900 psi/15 mins on chart. Good test. Rig down and blow down lines. 11/12/2018 11/12/2018 2.00 COMPZN WELLPR DISP P Pick up 66'. Displace well to seawater. 19,854.0 42 13,6.0 01:00 03:00 10 bpm, ICP=3100 psi FCP=2878 psi 22% FO. Total strokes pumped=6159. 11/12/2018 11/12/2018 0.50 COMPZN WELLPR CRIH P Spot Cl seawater up to lower GLM 13,642.0 13,642.0 03:00 03:30 depth of 12080' MD. Pump 30 Ions CI seawater and chase with 137 bbls seawater. 7 bpm, 1545 psi, 17% FO. PU 165K SO 130K. 11/12/2018 11/12/2018 0.75 COMPZN WELLPR OWFF P Monitor well. Static. 13,642.0 13,642.0 03:30 0415 11/12/2018 11/12/2018 7.75 COMPZN WELLPR PULD P POOH laying down DP from 13642' 13,642.0 6,250.0 04:15 1200 MD to 6250' MD. PU 100K SO85K 11/12/2018 11/12/2018 5.50 COMPZN WELLPR PULD P POOH laying down DP from 6250' MD 6,250.0 65.0 12:00 1730 1 to 65' MD. 11/12/2018 11/12/2018 1.00 COMPZN WELLPR BHAH P Lay down liner running tool as per 65.0 0.0 17:30 18:30 Baker rep. 11/12/2018 11/12/2018 1.00 COMPZN WELLPR TRIP P RIH with DP from derrick to 2560' MD, 0.0 2,560.0 18:30 1930 11/12/2018 11/12/2018 2.00 COMPZN WELLPR PULD P POOH laying down DP from 2560' 2,560.0 0.0 19:30 21:30 MD. 11/12/2018 11/12/2018 0.50 COMPZN RPCOMP WWWH P Make up stack washing tool. Flush 0.0 0.0 21:30 22:00 BOPE. 20 bpm. Blow down TD. 11/12/2018 11/12/2018 0.25 COMPZN RPCOMP RURD P Rig up and pull wear ring. 0.0 0.0 22:00 22:15 11/12/2018 11/12/2018 1.50 COMPZN RPCOMP RURD P Rig up to run 4 1/2" tubing. Verify pipe 0.0 0.0 22:15 23:45 count in pipe shed. 11/12/2018 11/13/2018 0.25 COMPZN RPCOMP SFTY P Conduct PJSM on running tubing. 0.0 0.0 23:45 00:00 11/13/2018 11/13/2018 1.00 COMPZN RPCOMP PUTB P Make up 41/2" upper completion to 0.0 203.0 00:00 01:00 gauge carrier at 203' MD. Make up TEC wire SLB DHG to gauge carrier and test connection to 5000 psi/5 mins. Page 18/20 Report Printed: 11/20/2018 Operations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hi Phase Do Code Activity Code Time P -T -X Cpembon Start Depth htKB) End Depth (ftKB) 11/13/2018 11/13/2018 5.00 COMPZN RPCOMP PUTB P Pick up and RIH with 4 1/2", 12.6#, L- 203.0 3,843.0 01:00 06:00 80 Hydril 563 upper completion as per running order from 203' MD to 3843' MD. Torque connections to 4500 ft/lbs using Jet Lube Seal Guard dope. PU 78K SO 77K. 11/13/2018 11/13/2018 6.00 COMPZN RPCOMP PUTS P Pick up and RIH with 4 1/2", 12.6#, L- 3,843.0 8,770.0 06:00 1200 80 Hydril 563 upper completion as per running order from 3843' MD to 8770' MD. Torque connections to 4500 ft/lbs using Jet Lube Seal Guard dope. PU 106K SO 75K. 11/13/2018 11/13/2018 6.75 COMPZN RPCOMP PUTS P Pick up and RIH with 4 112", 12.6#, L- 8,770.0 13,656.0 12:00 18:45 80 Hydril 563 upper completion as per running order from 8770' MD to 13656' MD. Torque connections to 4500 ft/lbs using Jet Lube Seal Guard dope. PU 137K SO 71 K. 11/13/2018 11/13/2018 0.75 COMPZN RPCOMP HOSO P RIH and tag at 13702.33' WLEG 13,656.0 13,699.0 18:45 19:30 depth. Observe shear screws shear with 8K down weight.. Continue down and no-go at 13703.29' WLEG depth. Pick up 4' above no-go. TOL at 13693.75' MD. PU 137K SO 71 K. 11/13/2018 11/13/2018 2.50 COMPZN RPCOMP CRIH P Reverse circulate 265 bbls CI 13,699.0 13,699.0 19:30 2200 seawater followed by 105 bbls seawater. 2 bpm, 230 psi, 6% FO. 11/13/2018 11/14/2018 2.00 COMPZN RPCOMP HOSO P Lay down 3 its tubing. Pick up 5.83' 13,699.0 13,700.0 22:00 0000 space out pup jt and replace joint 356 with joint 363. Make up hanger and landing joint. Terminate TEC wire and test connections to 5000 psi/5 min. Land hanger. Spaced out 2.61' from fully located. WLEG at 13,700.68' MD. 11/14/2018 11/14/2018 0.50 COMPZN RPCOMP THGR P RILDS and torque to spec. 13,700.0 13,700.0 00:00 0030 11/14/2018 11/14/2018 2.75 COMPZN RPCOMP PRTS P Test tubing to 4000 psi/30 mins on 13,700.0 0.0 00:30 0315 chart. Good test. Bleed tubing to 2500 psi. Test IA to 3850 pis/30 mins on chart. Good test. Bleed IA and then tubing to 0 psi. Pressure up on IA and observe SOV shear at 2830 psi. Pump additional bbls at 2 bpm, 430 psi. Pump 2 bbls down tubing at 2 bpm, 400 psi. Monitor well for 10 mins. Static. Lay down landing joint. 11/14/2018 11/14/2018 0.75 COMPZN WHDBOP MPSP P Dry rod in HP BPV. Test BPV from 0.0 0.0 03:15 0400 below to 2500 psi/10 mins on chart. Good test. 11/14/2018 11/14/2018 0.50 COMPZN WHDBOP OTHR P Blow down and rig down lines. 0.0 0.0 04:00 0430 11/14/2018 11/14/2018 2.00 COMPZN WHDBOP MPDA P Nipple down Katch Kan and RCD. Sim 0.0 0.0 04:30 0630 -ops/Change out saver sub to 4 1/2 IF. 11/14/2018 11/14/2018 2.50 COMPZN WHDBOP NUND P NO choke and kill lines, BOPE, 0.0 0.0 06:30 0900 spacer spool and DSA. 11/14/2018 11/14/2018 1.50 COMPZN WHDBOP NUND P Clean wellhead and cellar. NU adapter 0.0 0.0 09:00 1030 Flange. Terminate and test TEC wire. Final DHG readings=2357 psi and 129.54 F. Test adapter void to 250/5000 psi for 15 mins. Test witnessed by CPA( rep. Sim-ops/Blow down rig water. Rig up returns line for freeze protect. Page 19/20 Report Printed: 11/20/2018 Uperations Summary (with Timelog Depths) 3S-612 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time EndTime Dur (hr) F Phase Op Code Adimly Cotle Time P -T -X tion Operation Depth (itKB) Entl Depth(ftKB) 11/14/2018 11/14/2018 1.50 COMPZN WHDBOP NUND P NU 10,000 psi Cameron 4-1/16" frac 0.0 0.0 10:30 1200 tree. Sim-ops/Prep skate rail for removal. Blow down pit complex. 11/14/2018 11/14/2018 1.00 COMPZN WHDBOP PRTS P Test hanger seals to 250/5000 for 10 0.0 0.0 12:00 1300 mins ea. Good test.Witnessed by CPAI rep.. 11/14/2018 11/14/2018 1.25 COMPZN WHDBOP NUND P Nipple up wing valve. 0.0 0.0 13:00 1415 11/14/2018 11/14/2018 5.00 COMPZN WHDBOP PRTS P Rig up test equipment and purge air 0.0 0.0 14:15 19:15 from tree. Test Cameron 4-1/6" 1 Ok tree to 250 psi low and 10k high f/ 15 minutes. Test witnessed by CPAI rep. Rig down testing equipment. 11/14/2018 11/14/2018 0.75 COMPZN WHDBOP MPSP P Dry rod out test dart and BPV. 0.0 0.0 19:15 20:00 11/14/2018 11/14/2018 3.00 COMPZN WHDBOP FRZP P Rig up and freeze protect w/ LRS 0.0 0.0 20:00 2300 pumping. Pressure test lines to 2500 psi. Pump 151 bbls diesel at 1.5 bpm down the IA taking returns up the tubing until diesel at surface. ICP = 120 psi, FCP=165 psi. Rig down and blow down lines. Sim-ops/Stare skate rail for move. Jack and move motor, pump and pit complexes 11/14/2018 11/15/2018 1.00 DEMOB MOVE RURD P Set BPV Secure well. 0.0 0.0 23:00 00:00 Final pressures : OA = 460 psi, IA= 0 psi, TBG= 0 psi. SIM Ops: Pull motor complex away, preparing to move rig to 3S-612. Rig released @ 23:59 hrs 11/14/2018 to move to 2S-315. Move distance of 33 miles. Page 20120 ReportPrinted: 11/20/2018 NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-612 3S-612 ConocoPhillips Definitive Survey Report Final Definitive Survey Verified and Signed -off Ali targets and/or well position objectives have been achieved. Yes No I have checked to the best of my ability that the following data is correct: Surface Coordinates -- Declination & Convergence GRS Survey Corrections Survey Tool Codes Brandon Tem Digitally signed by8nindon Temple SLB „le DE: h Date: 2019,11,27 1375450 -09'0(Y Client Representative: Date: .. I 1-IP30e9 November 27th, 2018 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 35-612 Project Kuparuk River Unit TVD Reference: 3S-612 actual @ 63.64usft (Doyon 142) Sits: Kuparuk 3S Pad MD Reference: 35512 actual (dU 63.64usft (Doyon 142) Wen: Rig: 35512 North Reference: True Wellbore: 35-612 Survey Calculation Method: Minimum Curvature Design 35..612 Database: EDT 14 Alaska Production Project Kupamk River Unit, North Slope Alaska, United States 13,803.053R-612 Srvy 3- SLB _MWD+GMAG(3S- Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Goo Datum: NAD 1927 (NADCON CONUS) Declination Using Well Reference Point Map Zone: Alaska Zone 04 -24.50 Using geodetic scale factor well Rig: 3S-612 From Well Position +N/.S 0.00 usft Northing: 5,993,905.49 usft Latitude: Tool Name +FJ -W 0.00 usft Easting: 81.97 476,227.30 usft Longitude: Position Uncertainty 10/24/2018 11:41 0.00 usft Wellhead Elevation: 2,946.1535-612 Srvy 2 - SLB_MWD+GMAG (3S- 0.00 usft Ground Level: WaNbon 35-612 13,803.053R-612 Srvy 3- SLB _MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/28/2018 8AEM Mooned" Model Name Sample Dab Declination Dip Angle 0.00 39.14 -24.50 0.00 0.00 5,993,90549 476,227.30 BGGM2018 10/31/2018 0.00 UNDEFINED 16.77 80.88 231.65 81.97 18.33 -0.03 -0.04 5,933,905.46 Design 35-612 0.01 GYD-GC-SS(1) 167.68 0.30 278.41 Audit Notes: 104.04 -0.06 -0.35 5,993,905.43 476,226.95 Version: 1.0 Phase: ACTUAL 0.00 Te On Depth: 39.14 Vertical Section: 199.27 Depth From (TVD) -N/-S +E/ -W Direction 0.32 0.47 GYD-GCSS(1) (usft) (usft) (usft) (°) 294.49 0.71 39.14 0.00 0.00 305.32 70" 23'40.127 N 150° 11'36.321 W 24.50 usft Field Strength (nT) 57,430 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 81.97 1,466.97 35512 Srvy 1 - SLB_GWD70 (38-612) GYD-GC-SS Gyrodata gyro single shots 10/24/2018 11:41 1,545.27 2,946.1535-612 Srvy 2 - SLB_MWD+GMAG (3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/24/201811:5' 3,045.59 13,803.053R-612 Srvy 3- SLB _MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/28/2018 8AEM 13,693.91 19,807.393R-612 Srvy 4-SLB_WD+GMAG(3S- MWD+IFR-AK-CAZSC MWD+IFRAKCAZSCC 11/6/2018 8:46:1 Survey 11272018 1:42:37PM Page 2 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Seating DLS Section (usft) (1 (°) (usft) (waft) (waft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 39.14 0.00 0.00 39.14 -24.50 0.00 0.00 5,993,90549 476,227.30 0.00 0.00 UNDEFINED 81.97 0.14 231.65 81.97 18.33 -0.03 -0.04 5,933,905.46 476,227.26 0.33 0.01 GYD-GC-SS(1) 167.68 0.30 278.41 167.68 104.04 -0.06 -0.35 5,993,905.43 476,226.95 0.27 0.24 GYD-GC-SS(1) 262.91 0.00 259.66 262.91 199.27 -0.03 4).59 5,993,905.46 476,226.71 0.32 0.47 GYD-GCSS(1) 358.14 1.67 302.07 358.13 294.49 0.71 -1.77 5,993,906.20 476,225.53 1.75 1.85 GYD-GCSS(1) 451.18 3.71 302.63 451.06 387.42 3.05 5.45 5.993,908.56 476,221.86 2.19 6.21 GYD-GC-SS(1) 544.03 3.99 310.68 543.70 480.06 6.78 -10.43 5,993,912.30 476,216.89 0.65 12.43 GYD-GC-SS(1) 636.04 6.85 316.46 635.29 571.65 12.84 -16.64 5,993,918.38 476,210.70 3.16 21.00 GYD-GCSS(1) 729.36 9.19 312.44 727.69 664.05 21.91 -25.97 5,993,927.48 476,201.40 2.58 33.86 GYD-GCSS(1) 823.93 9.63 308.83 820.99 757.35 31.96 57.71 5,993,937.57 476,189.70 0.78 49.25 GYD-GC-SS(1) 918.37 10.11 309.66 914.03 850.39 42.21 -50.25 5,993,947.85 476,177.19 0.53 65.40 GYD-GC-SS(1) 11272018 1:42:37PM Page 2 COMPASS 5000.14 Build 850 ConocoPhillips ( Definitive Survey Report Company: NADConversion Local Co�ordinate Reference: Well Rig: 3S-612 Project: Kuparuk River Unit TVD Reference: 3SS12 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3SS12 actual @ 63.64usft (Doyon 142) Well: Rig: 3SS72 North Reference: True Wellbore: 35-612 Survey Calculation Method: Minimum Curvature Design: 35-612 Database: EDT 14 Alaska Production Survey 1112712018 1:42:37PM Page 3 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc AZI TVD NDSB +N1-3 +EJ -W Northing Easting DLS Section Nam (1) (1) (usft) (usR) ("It) (usf) (fry (ft) (`/1007 (N) Survey Tool Name 1,013.04 12.91 304.96 1,006.79 943.15 53.57 .65.31 5,993,959.26 476,162.16 3.12 84.26 GYD-GC-SS(1) 1,107.91 15.53 305.94 1,098.74 1,035.10 67.10 -84.28 5,993,972.85 476,143.24 2.77 107.56 GYD-GC-SS(1) 1,202.79 17.11 306.18 1,189.80 1,126.16 62.80 -105.83 5,993,988.61 476,121.74 1.67 134.22 GYD-GCSS(1) 1,297.16 19.55 304.51 1,279.37 1,215.73 99.94 -130.05 5,994,005.83 476,097.58 2.64 163.90 GYD-GCSS(1) 1,392.33 22.65 301.44 1,368.16 1,304.52 118.52 -15B.82 5,994,024.51 476,068.87 3.46 198.11 GYD-GCSS(1) 1,486.97 23.88 303.16 1,55.10 1,391.46 138.51 -190.40 5,994,044.59 476,037.36 1.48 235.44 GYD-GC-SS(1) 1,545.27 25.17 303.14 1,508.14 1,444.50 151.74 -210.67 5,994,057.89 476,017.14 2.21 259.62 MND+IFR-AK-CAZSC (2) 1,641.05 28.07 304.60 1,593.76 1,530.12 175.68 -246.28 5,994,081.93 475,981.61 3.10 302.51 MWD+IFR-AK-CAZ-SC(2) 1,735.30 32.11 305.46 1,675.29 1,611.65 202.81 -284.95 5,994,109.19 475,943.03 4.31 349.75 MWD+IFR-AK-CAZ-SC(2) 1,829.12 32.68 305.53 1754.51 1,690.87 232.00 -325.87 5,994,138.50 475,902.20 0.61 400.02 MWD+IFR-AK-CAZ-SC(2) 1,923.87 36.46 305.54 1,832.51 1,768.87 263.24 -369.61 5,994,169.88 475,858.56 3.99 453.77 MWD+IFR-AK-CAZSC(2) 2,018.57 37.72 305.20 1,908.05 1,844.41 2%.30 416.18 5,994,203.06 475,812.10 1.35 510.88 MWDAFR-AK-CAZSC (2) 2,113.24 41.14 305.77 1,981.17 1,917.53 331.20 455.13 5,994,238.14 475,763.27 3.63 571,0 MWD+IFR-AK-CAZSC (2) 2,207.70 43.33 306.12 2,051.10 1,987.46 368.47 -516.63 5,994,275.57 475,712.00 2.33 634.48 MWD+IFR-AK-CAZSC(2) 2,302.27 43.71 307.86 2,119.68 2,056.04 407.65 .568.54 5,994,314.91 475,660.12 1.33 69957 MWD+IFR-AK-CAZSC (2) 2,397.01 45.64 305.01 2,187.05 2,123.41 447.18 522.13 5,994,354.61 475,606.66 2.94 765.15 MWD+IFR-AK-CAZ-SC(2) 2,491.05 49.05 303.44 2,250.77 2,187.13 486.05 .679.32 5,994,393.65 475,549.60 3.83 835.29 MWD+IFR-AKCAZ-SC(2) 2,586.02 51.97 303.59 2,311.15 2,247.51 526.52 -740.42 5,994,434.31 475,488.64 3.08 908.54 MWD+IFR-AK-CAZ-SC (2) 2,679.94 53.17 303.94 2,368.24 2,304.60 567.97 502.42 5,994,475.95 475.426.77 1.31 983.09 MWD+IFR-AK-CAZSC (2) 2,774.29 55.35 303.64 2,423.34 2,359.70 610.56 566.06 5,994518.74 475,363.27 2.32 1,059.64 MV4D+IFR-AK-CAZSC (2) 2,868.97 57.31 304.61 2,475.83 2,412.19 654.77 -931.28 5,994.563.15 475,298.20 2.24 1,138.41 MND+IFR-AK-CAZSC (2) 2,946.15 58.46 304.81 2,516.86 2,453.22 691.99 -985.01 5,994,600.54 475,244.59 1.51 1,203.78 MNDAFR-AK-CAZSC (2) 3,045.59 60.42 304.40 2,667.42 2,503.78 740.61 -1,055.49 5,994,649.38 475,174.27 2.00 1,289.39 MND+1FR-AKCAZSC(3) 3,073.14 61.16 304.12 2,SB0.87 2,517.23 754.15 -1,075.37 5,994,662.98 475,154.44 2.83 1,313.44 MWD+IFR-AK-CAZ-SC(3) 3,123.27 62.20 303.39 2,604.65 2,541.01 778.67 -1,112.06 5,994,687.61 475,117.84 2.44 1,357.55 MWD+IFR-AK-CAZ-SC(3) 3,167.99 63.24 302.98 2,625.14 2,561.50 800.42 -1,145.32 5,994,709.47 475,084.64 2.46 1397.27 MWD+IFR-AK-GAZ-SC(3) 3,221.16 64.36 302.53 2,648.62 2,584.98 826.23 -1,185.44 5,994,735.41 475,044.61 2.24 1,444.92 MWD+IFR-AK-CAZSC (3) 3,262.46 65.10 303.07 2,666.25 2,602.61 846.47 -1,216.83 5,994,755.74 475013.28 2.15 1,482.24 MND+IFR-AK-CAZSC(3) 3,312.24 66.43 302.85 2,686.68 2,623,4 871.16 -1,254.92 5,994780.55 474,975.28 2.70 1,527.59 MWD+IFR-AK-CAZSC (3) 3,357.08 67.35 302.85 2,704.28 2,640.64 893.53 -1,289.57 5,994,803.03 474,940.71 2.05 1,568.79 MND+IFR-AK-CAZSC (3) 3,409.02 68.52 302.71 2,723.79 2,660.15 919.59 -1,330.04 5,994,829.22 474,900.33 2.27 1.616.88 MWD+IFR-AK-CAZ-SC(3) 3,451.33 69.77 302.93 2,738.86 2,675.22 941.02 -1,363.26 5,994,850.75 474,867.17 2.99 1,656.38 MWD+IFR-AKCAZ-SC(3) 3,545.77 73.04 303.79 2,768.97 2,705.33 990.24 -1,438.01 5,994,900.20 474,792.59 3.57 1,745.82 MWD+IFR-AKCA7-SC(3) 3,640.27 76.23 304.42 2,794.00 2,730.36 1,041.33 -1,513.45 5,994,951.52 474,717.32 3.44 1,836.91 MND+IFR-AK-CAZ-SC (3) 3,734.96 77.07 304.90 2,815.87 2,752.23 1,093.73 -1,589.23 5,995,004.16 474641.72 1.01 1,929.04 MWD+IFR-AK-CAZ-SC(3) 3,829.62 77.24 305.30 2,836.91 2,773.27 1,146.79 -1,684.74 5,05,057.46 474,566.38 0.45 2,021.33 MWD+IFR-AK-CAZSC (3) 3,924.56 76.99 305.30 2,858.08 2,794.44 1,200.27 -1,740.27 5,995,111.17 474,491.03 0.26 2,113.88 MND+IFR-AK-CAZSC (3) 4,018.79 76.96 304.83 2,879.32 2,815.68 1,253.02 -1,815.41 5,995,164.15 474,416.06 0.49 2,205.68 MV4D+1FR-AK-CAZSC (3) 4,113.77 77.30 303.73 2,900.48 2,836.84 1,305.17 -1,891.92 5,995,216.54 474,339.73 1.18 2,298.26 MWD+IFR-AKCAZSC(3) 4,208.07 77.08 302.18 2,921.38 2,857.74 1,355.19 -1,969.08 5,995,266.80 474,262.74 1.62 2,390.13 MWD+IFR-AK-CAZ-SC(3) 1112712018 1:42:37PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 35-612 Project Kuparuk River Unit TVD Reference: 35-612 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 35-612 actual @ 63.64usft (Doyon 142) Well: Rig: 35-612 North Reference: True Wellbore: 3SS72 Survey Calculation Method: Minimum Curvature Design: 3S4612 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc AZI TVD TVDSS +N/3 +E/ -W Northing Seating DLS Section (waft) (°) (°) (usft) Wall) (Wft) (usft) (in (ft) (°/100') (ft) Survey Tool Name 4,303.36 77.45 301.56 2,942.39 2,878.75 1,404.26 -2,048.01 5,995,316.12 474,183.97 0.74 2,482.91 MWD+IFR-AK-CAZ-SC (3) 4,397.87 77.25 301.25 2,963.09 2,899.45 1,452.31 -2,126.72 5,995,364.41 474,105.42 0.38 2,574.91 MWD+IFR-AK-CAZSC(3) 4,492.71 77.35 301.50 2,983.94 2,920.30 1,500.48 -2,205.71 5,995,412.83 474,026.60 0.28 207.21 MWD+1FRAK-CAZSC(3) 4,587.27 77.15 300.97 3,004.81 2,941.17 1,548.31 -2,284.57 5,995,460.90 473,947.90 0.59 2,759.20 MWD+IFR-AK-CAZSC(3) 4,681.91 76.29 301.08 3,026.55 2,962.91 1,595.78 -2,363.50 5,995,508.62 473,869.12 0.92 2,851.05 MND+IFR-AK-CAZSC (3) 4,776.77 76.64 301.55 3,048.75 2,985.11 1,643.72 -2,442.29 5,995,556.80 473,790.49 0.61 2,943.05 MND+IFRAK-CAZSC (3) 4,871.19 77.37 300.88 3,069.98 3,006.34 1,691.39 -2,520.97 5,995,604.72 473,711.97 1.04 3,034.81 MND+IFR-AK-CAZSC (3) 4,965.56 76.78 300.65 3,091.09 3,027.45 1,738.44 -200.00 5,995,652.02 473,633.10 0.67 3,126.50 MND+IFRAK-CAZSC(3) 5,061.05 76.66 300.05 3,113.02 3,049.38 1,785.40 -2,680.20 5,995,699.23 473,553.05 0.62 3,219.09 MND+IFRAK-CAZSC(3) 5,155.03 76.92 299.94 3,134.50 3,070.86 1,831.14 -2,759.44 5,995,745.21 473,473.97 0.30 3,310.19 MND+IFR-AK-CAZSC(3) 5,249.99 76.87 300.31 3,156.03 3,092.39 1,877.56 -2,839.44 5,995,791.88 473,394.13 0.38 3,402.29 MND+IFRAK-CAZSC(3) 5,344.55 75.64 301.22 3,178.50 3,114.86 1,924.54 -2,918.37 5,995,639.11 473,315.35 1.60 3,493.86 MN4D+IFRAK-CAZSC(3) 5,439.27 77.37 302.07 3,200.60 3,136.96 1,972.86 -2,996.77 5,995,887.68 473,237.12 2.02 3,585.76 1vlND+IFRAK-CAZSC(3) 5,534.13 76.69 302.62 3,221.69 3,158.25 2,022.32 5,074.86 5,995,937.38 473,159.19 0.91 3,678.8 MND+IFR-AK-CAZSC(3) 5,628.60 75.96 303.77 3,244.23 3,180.59 2,072.57 5,151.68 5,995,987.87 473,082.54 1.41 3,769.811 MM+IFRAK-CAZ-SC(3) 5,723.95 77.01 305.18 3,266.51 3,202.87 2,125.05 5,228.10 5,996,040.58 473,006.30 1.81 3,862.W MND+IFRAKCAZ-SC(3) 5,818.78 77.42 306.31 3,287.50 3,223.86 2,179.07 5,303.15 5,996,094.84 472,931.42 1.24 3,954.97 MWD+IFRAK-CAZ-SC (3) 5,912.97 77.08 304.97 3,308.29 3,244.65 2,232.60 5,37.81 5,996,148.60 472,856.94 1.43 4,046.84 MND+IFRAKCAZ-SC (3) 6,007.52 76.99 303.68 3,329.50 3,265.86 2,284.56 5,453.90 5,996,200.79 472,781.02 1.33 4,138.96 MWD+IFRAK-CAZ-SC(3) 6,102.88 76.87 302.55 3,351.06 3,287.42 2,335.30 -3,531.70 5,996,251.78 472,703.39 1.16 4,231.78 MWD+IFR-AK-CAZ-SC (3) 6,197.46 77.25 303.89 3,372.24 3,308.60 2,385.80 5,608.82 5,996,302.52 472,626.45 1.44 4,323.89 MND+IFR-AK-CAZ-SC (3) 6,292.56 77.56 304.60 3,392.98 3,329.34 2,438.03 -3,685.54 5,996,354.99 472,549.90 0.80 4,416.69 MWD+IFRAK-CAZ-SC (3) 6,387.29 77.53 303.34 3,413.41 3,349.77 2,489.72 -3,762.25 5,996,406.91 472,473.36 1.30 4,509.16 MWD+IFR-AK-CAZ-SC (3) 6,481.96 77.28 301.46 3,434.06 3,370.42 2539.22 -3,840.25 5,996,456.66 472,395.52 1.96 4,601.43 MWD+IFR-AK-CAZ-SC(3) 6,575.28 77.10 299.44 3,454.75 3,391.11 2,585.33 5,918.69 5,996,503.02 472,317.24 2.12 4,692.09 MWD+IFRAK-CAZ-SC (3) 6,671.03 76.90 299.84 3,476.29 3,41265 2,63147 5,999.78 5,996,549.41 472,236.30 0.46 4,784.93 MWD+1FR-AK-CAZ-SC(3) 6,765.22 77.10 301.93 3,497.48 3,433.84 2,678.58 -4,078.54 5,996,596.76 472,157.70 2.17 4,876.42 MNDAFRAK-CAZSC(3) 6,859.22 77.25 302.87 3,518.35 3,454.71 2,727.69 4,155.93 5,996646.11 472,080.48 0.99 4,967.96 MND+IFR-AK-CAZSC(3) 6,954.39 77.31 302.72 3,539.30 3,475.65 2,777.97 4,233.96 5,996,696.64 472,02.61 0.17 5,060.70 MWD+IFRAK-CAZSC (3) 7,048.90 77.31 303.38 3,560.06 3,496.42 2,828.26 4,311.25 5,996,747.16 471,925.50 0.68 5,152.83 MND+IFRAK-CAZSC(3) 7,143.66 77.22 304.11 3,580.95 3,517.31 2,879.60 4,388.10 5,996,798.74 471,848.81 0.76 5,245.22 MWD+IFRAK-CAZ5C (3) 7,237.60 77.35 303.15 3,601.63 3,537.99 2,930.35 4,464.40 5,996,649.73 47172.68 1.01 5,336.82 MND+IFRAK-CAZSC(3) 7,332.79 77.13 302.63 3,622.66 3,559.02 2,980.77 4,542.36 5,996900.39 471,694.90 0.58 5,429.57 MWD+IFRAK-CAZSC(3) 7,426.81 77.13 303.40 3,643.60 3,579.96 3,030.71 4,619.21 5,996,950.57 471,618.21 0.80 5,521.16 MND+IFRAK-CAZSC (3) 7,521.45 77.36 303.76 3,664.49 3,600.85 3,081.76 4,696.11 5,997,W1.86 471,541.48 0.44 5,613.42 MND+IFRAK-CAZ-SC(3) 7,616.29 77.11 303.39 3,685.45 3,621.81 3,132.91 4.773.18 5,997,053.25 471,464.58 0.46 5,705.87 MND+IFRAK-CAZSC (3) 7,711.23 76.99 301.45 3,706.73 3,643.09 3,182.52 4,851.28 5,997,103.10 471,386.65 2.00 5,798.27 MND+IFRAK-CAZ-SC(3) 7,80i88 76.93 302.31 3,728.08 3,664.44 3,231.21 4,929.58 5,997,152.04 471,308.51 0.89 5,890.32 MND+IFRAK-CAZ-SC(3) 7,900.60 76.87 301.98 3,749.55 3,685.91 3,280.30 5,007.69 5,997,201.37 471,230.56 0.35 5,982.43 MND+IFR-AKCAZ-SC (3) 7,995.00 76.90 302.54 3,770.97 3,707.33 3,329.37 5,085.44 5,997,2W.69 471,152.98 0.58 6,074.23 MND+IFR-AK-CAZ-SC(3) 11272018 1:42:37PM Page 4 COMPASS 5000.14 Build 850 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 35-612 Project: Kuparuk River Unit TVD Reference: 35-612 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 35-612 actual (a) 63.64usft (Doyon 142) Well: Rig: 33-612 North Reference: True Wellbore: 35-612 Survey Calculation Method: Minimum Curvature Design: 3SS12 Database: EDT 14 Alaska Production Survey - Map Map Vertical MD Inc AN TVD TVDSS +i +EI -W Northing Easting OLS Section (waft) (*) (') (uaft) (usft) (usft) (usm (1t) (ft) (°1100') (1t) Survey Tool Name 8,089.97 77.30 302.06 3,792.17 3,728.53 3,378.84 .5,163.68 5,997,300.40 471,074.90 0.65 6,166.68 MWD+IFR-AK-CAZSC(3) 8,183.78 77.17 302.42 3,812.90 3,749.26 3,427.65 5,241.07 5,997,349.44 470,997.68 0.40 6,258.04 MWD+IFR-AK-CAZ-SC(3) 6,279.70 77.17 302.77 3,834.20 3,770.56 3,478.03 .5,319.86 5,997,400.07 470,919.05 0.36 6,351.46 MWD+IFR-AK-CAZ-SC(3) 8,373.69 76.99 302.83 3,855.22 3,791.58 3,527.65 5,396.87 5,997,449.94 470,842.21 0.20 6,442.98 MWD+IFR-AKCAZ-SC(3) 8,469.06 77.12 302.72 3,876.58 3,812.94 3,577.97 .5,475.02 5,997,500.50 470,764.23 0.18 6,535.83 MWD+IFR-AK-CAZ-SC(3) 8,562.96 76.87 303.56 3,897.71 3,834.07 3,627.99 5,551.63 5,997,550.75 470,687.79 0.91 6,627.26 MWD+IFR-AKCAZ-SC (3) 8,657.58 76.72 302.83 3,919.33 3,855.69 3,678.42 5,628.71 5.997.601.42 470,610.87 0.77 6,719.31 MWD+IFR-AK-CAZ-SC (3) 8,752.06 76.67 304.46 3,941.07 3,877.43 3,729.36 5,705.25 5,997,652.60 470,534.50 1.68 6,811.21 MWD+IFR-AK-CAZ-SC (3) 8,846.22 77.09 304.21 3,962.44 3,898.80 3,781.08 5,780.97 5,997,704.55 470,458.95 0.52 6,902.90 MWD+IFR-AK-CAZ-SC(3) 8,941.32 77.17 303.99 3,983.63 3,919.99 3,833.06 5,857.74 5,997,756.78 470,382.36 0.24 6,995.59 MWD+IFR-AK-CAZ-SC (3) 9,035.78 77.13 302.89 4,004.63 3,940.99 3,883.81 5,934.59 5,997,807.76 470,305.68 1.14 7,087.63 MWD+IFR-AK-CAZSC (3) 9,130.76 77.04 302.14 4,025.86 3,962.22 3,933.57 5,012.66 5,997,857.77 470,227.78 0.78 7,180.10 MWD+IFR-AK-CAZ-SC(3) 9,225.34 76.87 302.99 4,047.21 3,983.57 3,983.16 3,090.31 5,997,907.60 470,150.29 0.89 7,272.13 MWD+IFR-AK-CAZ-SC(3) 9,319.33 77.02 302.39 4,068.44 4,004.80 4,032.61 5,167.37 5,997,957.29 470,073.40 0.64 1363.59 MWD+IFR-AK-CAZSC (3) 9,415.77 77.09 301.99 4,090.05 4,026.41 4,082.68 .6,246.91 5,998,007.61 459,994.03 0.41 7,457.44 MWD+IFR-AK-CAZ-SC (3) 9,509.30 76.85 301.27 4,111.14 4,04250 4,130.47 5,324.49 5,998,056.64 169,916.60 0.79 7,548.37 MWD+IFR-AK-CAZSC (3) 9,603.62 76.75 301.66 4,132.67 4,069.03 4,178.40 5,402.82 5,998,103.82 469,838.44 0.42 7.639.99 MWD+IFR-AK-CAZSC(3) 9,698.79 76.87 301.37 4,154.39 4,090.75 4,226.84 3,481.81 5,998,152.50 469,759.61 0.32 7,732.45 MWD+IFR-AK-CAZSC(3) 9,793.35 77.02 301.12 4,175.75 4,112.11 4,274.62 3,560.58 5,998,200.53 469,681.W 0.30 7,824.34 MWD+IFR-AK-CAZSC (3) 9,888.48 77.21 301.40 4,196.96 4,133.32 4,322.74 3,639.84 5,998,248.89 469,601.90 0.35 7,916.83 MWD+IFR-AK-CAZSC(3) 9,983.07 76.78 301.66 4,218.25 4,154.61 4,370.94 5,718.40 5,998,297.33 469,523.51 0.53 8,008.80 MWD+1FR-AK-CAZSC (3) 10,077.01 76.76 301.96 4,239.75 4,176.11 4,419.14 3,796.11 5,998,345.78 469,445.96 0.31 8,100.07 MWD+IFR-AK-CAZSC(3) 10,172.27 77.09 302.42 4,261.30 4,197.65 4,468.57 5,874.63 5,998,395.45 469,357.59 0.58 8,192.72 MWD+IFR-AK-CAZSC(3) 10,266.04 77.02 303.21 4,282.30 4,218.66 4,518.10 5,951.44 5,998,445.22 469,290.96 0.82 8,284.02 MWD+1FR-AK-CAZSC(3) 10,360.71 77.02 303.65 4,303.57 4,239.93 4,568.92 -7,028.43 5,998,496.28 469,214.14 0.45 8,376.22 MWD+1FR-AK-CAZSC(3) 10,455.64 77.00 304.15 4,324.91 4,261.27 4,620.51 -7,105.20 5,998,548.11 469,137.53 0.51 8,468.69 MWD+IFR-AK-CAZSC(3) 10,550.03 76.44 303.80 4,346.59 4,282.95 4,671.85 -7,181.38 5,998,599.69 469,061.52 0.69 8,560.53 MWD+IFR-AK-CAZSC(3) 10,644.71 76.88 303.30 4,358.44 4,304.80 4,722.76 -7,258.16 5,998,650.84 468,984.91 0.69 8,652.61 MWD+1FR-AK-CAZSC(3) 10,738.77 75.88 302.87 4,390.58 4,326.94 4,772.66 -7,334.75 5,998,700.98 468,908.49 1.15 8,743.96 MWD+1FR-AK-CAZSC(3) 10,833.68 76.26 303.51 4,413.43 4,349.79 4,823.09 -7,411.84 5,998,751.65 468,831.57 077 8,836.01 MWD+IFR-AK-CAZSC(3) 10,928.19 76.62 304.01 4,435.59 4,371.95 4,874.15 -7,488.22 5,998,802.94 468,755.36 0.64 8,927.85 MWD+1FR-AK-CAZSC(3) 11,023.10 76.46 303.85 4,457.68 4,394.04 4,925.67 -7,564.81 5,998,854.70 468,678.94 0.24 9,020.13 MWN+1FR-AK-CAZSC (3) 11,118.16 76.59 304.29 4,479.84 4,416.20 4,977.46 -7,641.39 5,998,906.72 468,602.54 0.47 9,112.55 MWD+IFR-AK-CAI-SC(3) 11,212.72 76.55 304.65 4,501.80 4,438.16 5,029.51 -7,717.21 5,998,959.02 468,526.89 0.37 9,204.51 MWD+IFR-AK-CAZ-SC (3) 11,306.31 76.77 303.91 4,523.39 4,459.75 5,080.80 -7,792.46 5,999,010.54 468,451.81 0.80 9,295.56 MWD+IFR-AK-CAZ-SC(3) 11,401.41 76.41 304.06 4,545.45 4,481.81 5,132.51 -7,869.16 5,999,062.49 468,375.28 0.41 9,3B8.04 MWD+IFR-AKCAZ-SC (3) 11,495.72 76.43 303.76 4,567.59 4,503.95 5,183.65 -7,945.24 5,999,113.87 468,2W.37 0.31 9,479.69 MWD+1FR-AKCAZ-SC (3) 11,589.90 76.46 303.38 4,589.67 4,526.03 5,234.28 5,021.53 5,999,164.73 468,223.25 0.39 9,571.20 MWD+1FR-AKCAZ-SC (3) 11,684.66 76.63 302.77 4,611.71 4,548.07 5,284.57 5,09875 5,999,215.27 468,146.20 0.65 9,663.29 MWD+IFR-AK-CAZ-SC (3) 11,779.41 76.75 302.21 4,633.53 4,569.89 5,334.10 3,176.53 5,999,265.4 468.6 .59 059 9,755.38 MWD+IFR-AI(-CAZ-SC (3) 112712018 1:42:37PM Page 5 COMPASS 5000.14 Build 850 Survey I ConocoPhillips ( Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well Rig: 35-612 Project: Kuparuk River Unit TVD Reference: 3S-612 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3SS72 actual @ 63.64usft (Doyon 142) Well: Rig: 35-612 North Reference: True Wellbore: 35-612 Survey Calculation Method: Minimum Curvature Design: 35-612 Database: EDT 14 Alaska Production Survey 15,415.32 89.59 346.79 5,280.18 5,216.54 8,249.34 5,876.09 6.02,185.37 466,378.47 0.62 12,827.58 MWD+IFR.AK-CAZ-SC (4) 11/27/2018 1:42:37PM Page 6 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azl TVD TVDSS +N/ -S +E/ -W Northing Easgng DLS Section (tett) 0 (') (waft) (usft) (usft) (wit) (ft) (ft) r/100') (ft) Survey Tool Name 11,873.93 76.00 301.16 4,655.79 4,592.15 5,382.35 5,254.69 5,999,313.53 467,990.58 1.34 9,647.06 MW0+1FR-AK-CAZ-SC(3) 11,967.91 76.22 301.04 4,678.35 4,614.71 5,429.48 5,332.81 5,999,360.90 467,912.62 0.26 9,938.04 MWD+IFR-AK-CAZ-SC(3) 12,063.08 76.47 300.97 4,700.82 4,637.18 5,477.11 $412.08 5,990408.78 467,833.52 0.27 10,03026 MWD+IFR-AK-CAZSC(3) 12,157.63 76.49 300.99 4,722.93 4,659.29 5,524.43 5,490.89 5,999,455.35 467,754.86 0.03 10,121.92 MM+IFR-AK-CAZ-SC(3) 12,252.21 76.40 301.22 4,745.09 4,681.45 5,571.93 5,569.62 5,999,504.09 467,676.29 0.25 10,213.62 MWD+IFR-AK-CAZSC (3) 12,346.94 76.34 301.19 4,767.42 4,703.78 5,619.63 5,648.36 5,999,552.03 467,597.71 0.07 10,305.45 MWD+IFR-AK-CAZSC(3) 12,442.03 76.56 301.83 4,769.70 4,726.06 5,667.95 5,727.17 5,999,600.60 467,519.06 0.69 10,397.68 MWD+IFR-AK-CAZSC(3) 12,536.30 76.37 303.93 4,811.76 4,748.12 5,717.70 5,804.14 5,999,650.59 467,442.26 2.18 10,489.25 MWD+IFR-AK-CAZSC(3) 12,630.95 76.17 307.81 4,834.23 4,770.59 5,771.56 5,878.63 5,999,704.68 467,367, 95 3.99 10,581.17 MWD+IFR-AK-CAZSC (3) 12,725.64 76.31 310.12 4,856.76 4,793.12 5,829.39 5,950.14 5,999,762.73 467,296.63 2.37 10,672.95 MWD+IFR-AK-CAZSC(3) 12,820.19 76.3B 312.90 4,879.08 015.44 5,890.28 -9,018.93 5,999,823.63 467,228.04 2.86 10,764.28 MWD+IFR-AK-CAZSC(3) 12,914.93 76.44 315.61 4,901.35 4,837.71 5,954.54 -9,084.88 5,999,888.29 467,162.30 2.78 10,855.24 MWD+IFR-AK-CAZSC(3) 13,008.17 76.20 319.44 4,923.41 4,859.77 6,021.34 9,146.05 5,999,955.29 467,101.36 4.00 10,943.77 MWD+IFR-AK-CAZSC(3) 13,103.29 76.02 322.68 4,946.25 4,882.61 6,093.15 -9,209.07 6,000,027.27 467,043.56 3.31 11,032.63 MWD+IFR-AK-CAZSC(3) 13,197.83 76.21 326.54 4,968.94 4,905.30 6,167.96 5,257.21 6,000,102.24 466,990.67 3.97 11,119.24 MWD+IFR-AK-CAZSC(3) 13,291.98 76.11 328.41 4,991.47 4,927.83 0245.03 -9,306.36 6,000,179.46 466,941.7] 1.93 11,203.90 MWD+IFR-AK-CAZSC(3) 13,387.41 76.21 330.63 5,014.30 4,950.66 6,324.88 -9,353.36 6,000,259.45 466,895.03 2.26 11.288.42 MWD+IFR.AK-CAZ-SC(3) 13,434.80 76.08 331.38 5,025.65 4,962.01 6,365.12 -9,375.66 6,000299.76 466,872.86 1.56 11,329.88 MWD+IFR-AK-CAZ-SC (3) 13,529.31 76.11 336.40 5,048.37 4,984.73 6,447.47 5,416.02 6,000,382.23 466,832.76 5.16 11,410.42 MWD+IFR-AK-CAZ-SC (3) 13,622.81 76.05 341.00 5,070.88 5,007.24 6,532.00 -9,448.98 6,000,466.86 466,800.08 4.78 11,486.19 MWD+IFR-AK-CAZ-SC (3) 13,67D.80 75.91 341.82 5,082.50 5,018.86 6,576.13 -9,463.82 6.WD,511.03 460785.38 1.66 11,523.81 MWD+IFR-AK-CAZ-SC (3) 13,765.06 76.61 345.16 5,104.90 5,041.26 6,663.91 -9,489.84 6,000,598.88 466,759.65 3.52 11,595.78 MWD+IFR-AK-CAZ-SC (3) 13,803.05 76.27 346.27 5,113.80 5,050.16 6,699.69 5,498.95 6,000,634.69 460750.65 2.98 11,623.91 MM+IFR-AK-CAZ-SC(3) 13,893.91 76.76 347.16 5,134.99 5,071.35 6,785.68 4),519.25 6,000720.74 466,730.62 1.09 11,690.19 MWD+IFR-AK-CAZ-SC(4) 13,98B.87 77.07 346.54 5,156.49 5,092.85 6,875.75 -9,540.29 6,000,810.86 466,709.87 0.71 11,759.43 MWD+IFR-AK-CAZSC (4) 14,083.94 77.25 347.12 5,177.62 5,113.98 6,966.01 -9,561.41 6,000,901.17 460689.04 0.62 11,828.85 MWD+IFR-AK-CAZSC(4) 14,179.05 77.14 347.02 5,198.70 5,135.06 7,056.40 -9,582.17 6,000,991.62 460668.57 0.15 11,898.04 MWD+1FR-AK-CAZSC(4) 14,272.44 77.17 346.84 5,219.46 5,155.82 7,145.09 -9,602.76 6,001,080.37 460648.27 0.19 11,966.12 MWD+IFR-AK-CAZSC(4) 14,368.05 77.97 346.76 5,240.04 5,176.40 7,236.00 -9,624.08 6,001,171.33 460627.24 0.84 12,036.07 MWD+1FR-AK-CAZSC(4) 14,463.12 80.42 345.92 5,257.86 5,194.22 7,326.73 -9,645.13 6,001,262.13 465,605.47 2.72 12,106.53 MWD+1FR-AK-CAZSC(4) 14,558.22 B3.93 345.46 5,270.81 5,207.17 7,418.01 4),669.42 6,001,353.47 466,582.48 3.72 12,178.30 MWD+IFR-AK-CAZSC(4) 14,653.36 86.50 - 345.41 5,278.74 5,215.10 7,509.76 -9,693.26 6001,445.29 460558.94 2.70 12,250.80 MWD+IFR-AK-CAZSC(4) 14,749.84 89.78 345.55 5,281.87 5,218.23 7,603.10 4),717.43 6,001,538.69 466,535.06 3.40 12,324.49 MWD+IFR-AK-CAZSC(4) 14,843.86 90.91 345.65 5,281.31 5,217.67 7,694.16 -9,740.81 6,001,629.82 466,511.97 1.21 12,396.21 MWD+IFR-AK-WSC(4) 14,939.38 90.83 346.36 5,279.86 5,216.22 7,786.83 -9,763.91 6,001,722.56 466,489.17 0.75 12,46B.64 MWD+IFR-AK-CAZ-SC(4) 15,033.08 90.07 346.18 5,279.12 5,215.48 7,877.85 5,786.15 6,001,813.64 460467.23 0.83 12,539.41 MWD+IFR-AK-CAZ-SC (4) 15,128.23 89.83 346.53 5,279.20 5,215.55 7,970.32 -9,808.59 6,001,906.16 466,445.08 0.45 12,611.18 MWD+IFR-AK-CAZSC (4) 15,223.34 89.87 345.19 5,279.45 5,215.81 8,02.64 -9,831.83 6.01,998.45 466,422.14 1.41 12,683.46 MWD+IFR.AK-CAZ-SC (4) 15,318.49 89.84 347.34 5,279.69 5,216.05 8,154.97 -9,854.42 6,002,090.94 466,399.84 2.26 12,755.33 MWD+IFR-AK-CAZ-SC (4) 15,415.32 89.59 346.79 5,280.18 5,216.54 8,249.34 5,876.09 6.02,185.37 466,378.47 0.62 12,827.58 MWD+IFR.AK-CAZ-SC (4) 11/27/2018 1:42:37PM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 35-612 Project: Kupamk River Unit TVD Reference: 35-612 actual @ 63.64usft (Doyon 142) Site: Kupamk 3S Pad MD Reference: 35-612 actual @ 63.64usft (Doyon 142) Well: Rig: 35-612 North Reference: True Wellbore: 35-612 Survey Calculation Method: Minimum Curvature Design: 3S-612 Database: EDT 14 Alaska Production Survey 11272018 1:42:37PM Page 7 COMPASS 5000.14 Build 85D Map Map vertical MD Inc Azi TVD TVDSS +NIS +El4N Northing Easting DIS Section ("I" C) P) (usft) (usft) (usft) (usrt) (ft) (ft) (°I100-) (ft) Survey Tool Name 15,508.20 89.18 346.58 5,281.17 5,217.53 8,339.71 -9,897.48 6,002,275.81 466,357.37 0.50 12,897.28 MVID+IFR-AK-CAZSC (4) 15.602.86 89.04 347.28 5,282.64 5,219.00 8,431.91 x,918.88 6,002,368.06 466,336.26 0.75 12,998.05 MWD+IFR-AK-CAZSC(4) 15,699.36 89.80 347.25 5,283.62 5,219.98 8,526.03 -9,940.16 6,002,462.24 466,315.29 0.79 13,039.82 MWD+IFR-AK-CAZSC (4) 15,792.28 89.83 346.67 5,283.92 5,220.28 8,616.55 A,961.12 6,002,552.82 466,294.62 0.63 13,109.27 MWD+IFR-AK-CAZSC(4) 15,886.26 90.25 346.38 5,283.85 5,220.21 8,707.95 -9,983.02 6,002644.27 466,273.01 0.54 13,179.97 MWD+IFR-AK-CAZSC(4) 15,985.43 90.18 346.54 5,283.48 5,219.84 8,804.36 -10,005.24 6,002,740.75 466250.10 0.18 13,254.66 MWD+IFR-AK-CAZSC(4) 16,077.54 90.38 347.00 5,283.03 5,219.39 8,894.02 -10,027.32 6,002,830.47 466229.31 0.54 13,323.70 MWD+IFR.AK-CAZSC(4) 16,166.91 90.52 345.68 5,282.33 5,218.69 8,980.86 -10,098.42 6,002,917.37 966,208.48 1.49 13,391.13 MWD+IFR-AK-CAZ-SC (4) 16,258.32 90.35 344.37 5,281.64 5,218.00 9,069.16 -10,072.04 6,003,005.73 466,185.15 1.45 13,461.45 MWD+IFR-AK-CAZ-SC (4) 16,352.83 90.35 345.40 5,281.06 5,217.42 9,160.40 -10,096.69 6,003,097.04 466,160.80 1.09 13,534.31 MWD+IFR-AK-CAZ-SC(4) 16,443.55 WW 344.23 5,280.48 5,216.84 9,247.95 -10,120.45 6,003,184.66 466,137.32 1.29 13,604.31 MWD+IFR-AK-CAZ-SC(4) 16,534.88 90.28 344.57 5,279.96 5,216.32 9,335.91 A0,145.01 6,003,272.69 466113.04 0.39 13,675.21 MWD+IFR-AK-CAZ-SC(4) 16,626.93 90.45 343.79 5,279.37 5,215.M 9,424.47 -10,170.10 6,003,361.32 466,086.23 0.87 13,746.89 MWD+IFR-AK-CAZ-SC(4) 16,720.78 90.42 394.50 5,278.66 5,215.02 9,514.75 -10,195.74 6,003,451.67 466,062.88 0.76 13,820.00 MWD+IFR-AK-CAZSC(4) 16,812.49 90.42 343.90 5,277.98 5,214.34 9,602.99 -10,220.71 6003,539.98 466,038.19 0.65 13,891.39 MWD+IFR-AK-CAZSC(4) 16,905.41 90.45 344.64 5,277.28 5,21364 9,692.43 -10,245.90 6,003,629.49 466,013.29 0.80 13,963.66 MWD+IFR-AK-CAZSC(4) 16,996.87 90.42 345.37 5,276.58 5,212.94 9,780.77 -10,269.56 6,003,717.90 465,989.91 0.80 14,034.04 MWD+IFR-AK-CAZSC(4) 17,089.49 90.56 344.46 5,275.79 5,212.15 9,870.20 -10,293.67 6,003,807.39 465,966.09 0.99 14,105.41 MWD+IFR-AK-CAZSC(4) 17,181.94 90.31 346.23 5,275.09 5,211.45 9,959.63 -10,317.06 6,003,896.89 465,942.99 1.93 14,176.20 MWDNFR-AK-CAZSC(4) 17,274.73 90.31 346.95 5,274.59 5,210.95 10,049.89 -10,338.57 6,003,987.21 465,921.76 0.78 14,245.94 MWD+IFR-AK-CAZ-SC(4) 17,366.73 90.52 347.56 5,273.92 5,210.28 10,139.62 -10,358.87 6,004,076.99 465,901.75 0.70 14.314.38 MWD+IFR-AK-CAZ-SC(4) 17,458.33 91.04 347.12 5,272.67 5,209.03 10,228.99 -10,378.94 6,004,166.41 465,881.97 0.74 14,382.43 MWD+IFR-AK-CA7-SC (4) 17,549.95 91.35 347.34 5,270.76 5,207.12 10,318.32 -10,399.19 6,004,255.80 465,862.01 0.41 14,450.60 MWDAFR-AK-CAZ-SC (4) 17,641.54 91.31 346.81 5,268.64 5,205.00 10,407.56 -10,419.67 6,004,345.10 465,841.81 0.58 14,518.90 MWD+IFR-AK-CAZ-SC(4) 17,733.46 91.34 347.77 5,266.51 5,202.87 10,497.21 -10,439.89 6,004434.80 465,821.8B 1.04 14,567.23 MWD+IFR-AK-CAZSC(4) 17,824.67 91.41 347.45 5,264.32 5,200.68 10,586.27 -10,459.45 6,004523.91 465,802.60 0.36 14,654.68 MWD+IFR-AK-CAZSC (4) 17,916.90 91.38 347.76 5,262.08 5,198.44 10,676.32 -10,479.25 6,004,614.02 465,783.10 0.34 14,722.90 MWD+IFR-AK-CAZSC(4) 18,000.81 91.31 347.71 5,259.92 5,196.28 10,766.11 -10,498.77 6,004)03.86 465,763.87 0.09 14,790.74 MWD+IFR-AK-CAZSC(4) 18,100.55 91.27 34243 5,25286 5,194.22 10,655.67 -10,518.51 6,004,793.48 465,744.41 0.31 14,858.63 MWD+IFR-AK-CAZSC(4) 18,193.83 91.34 347.11 5,255.73 5,192.09 10,946.64 -10,539.06 6,004,884.50 965,724.15 0.35 14,927.99 MWD+IFR-AK-CAZSC(4) 18,285.10 91.31 347.80 5,253.62 5,189.98 11,035.70 -10,558.88 6,004973.62 965,704.62 0.76 14,995.65 MWD+IFR-AK-CAZ-SC (4) 18,375.95 91.41 348.20 5,251.46 5,187.82 11,124.54 -10,577.76 6,005,062.51 465,686.02 0.45 15,062.42 MWD+IFR.AK-CAZSC (4) 18,46B.78 91.27 347.68 5,249.29 5,185.65 11,215.30 -10,597.15 6,005,153.32 965,666.92 0.58 15,130.72 MWD+IFR-AK-CAZ-SC(4) 18,559.37 91.31 347.45 5,247.25 5,183.61 11,303.74 -10,616.65 6,005,241.81 466647.70 0.26 15,197.76 MWD+IFR.AK-CAZ-SC(4) 18,651.09 91.34 347.25 5,245.13 5,181.49 11,393.21 -10,636.73 6,005,331.34 465,627.91 0.22 15,265.87 MWD+IFR-AK-CAZ-SC (4) 18,746.64 91.17 347.16 5,243.04 5,179.40 11,486.37 -10,657.89 6,005,424.55 465,607.05 0.20 15,337.00 MWD+IFR-AK-CAZ-SC(4) 18,834.83 91.62 346.42 5,240.89 5,177.25 11,572.20 40,678.03 6,005,510.43 465,587.18 0.98 15,403.06 MWD+IFR-AK-CAZ-SC(4) 18,926.60 91.17 346.26 5,238.66 5,175.02 11,661.34 -10,699.70 6,005,599.64 465,565.80 0.52 15,472.28 MWD+IFR-AK-CAZSC (4) 19,022.43 91.24 345.78 5,236.69 5,173.00 11,754.32 -10,722.85 6,005,692.68 465,542.95 0.51 15,544.91 MWD+IFR-AK-CAZ.SC(4) 19,117.07 91.38 345.75 5,234.48 5,170.84 11,846.03 -10,746.11 6,005,784.45 465,519.98 0.15 15,616.92 MWD+IFR-AK-WSC(4) 11272018 1:42:37PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well Rig: 35-612 Project.. Kuparuk River Unit TVD Reference: 35-612 actual @ 63.64us(t (Doyon 142) Site: Kupamk 3S Pad MD Reference: 35-612 actual @ 63.64usft (Doyon 142) Well: Rig: 3SS72 North Reference: True Wellbore: 3SS72 Survey Calculation Method: Minimum Curvature Design: 35-612 Database: EDT 14 Alaska Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Fasting DLS Section Wait) (•) (•) fuel" (usR) (usft) (usfg (ft) (ft) (°1100') (R) Sumay Tool Name 19,211.96 91.24 345.57 5,232.31 5,168.67 11,937.94 -10,769.61 6,005,876.42 465,496.78 0.24 15,689.23 MWD+IFR-AK-CAZSC(4) 19,306.77 91.38 345.93 5,230.14 5,166.50 12,029.80 -10,792.94 6,005,968.36 465,473.74 0.41 15,761.38 MWD+IFR-AK-CAZ-SC(4) 19,402.25 91.31 345.96 5,227.90 5,164.26 12,122.40 -10,816.12 6,006,061.02 465,450.86 0.08 15,833.83 MVVD+IFR-AK-CAZ-SC (4) 19,497.72 90.86 342.97 5,226.09 5,162.45 12,214.35 -10,841.68 6,006,153.04 465,425.59 3.17 15,907.85 MWD+IFR-AK-CAZSC (4) 19,591.81 91.31 342.64 5,224.31 5,160.67 12,304.27 -10,869.34 6,006,243.04 465,398.23 0.50 15,982.40 MWDAFR-AK-CAZSC(4) 19,686.97 91.31 342.17 5,222.14 5,158.50 12,395.01 -10,897.94 6,006,333.86 465,%9.92 0.70 16,058.20 MWD+IFR-AK-CAZ-SC(4) 19,780.86 91.24 341.46 5,220.05 5,156.41 12,484.18 -10,927.23 6,006,423.12 465,340.91 0.76 16,133.66 MWO+IFR-AK-CAZ-SC (4) 19,807.39 91.36 342.60 5,21445 5,155.81 12,509.41 -10,935.41 6,006,448.37 465,332.81 4.32 16,154.92 MWD+IFR-AK-CAZSC(4) 19,862.00 91.36 342.60 5,218.15 5,154.51 12,561.51 -10,951.74 6,006,500.51 465,316.65 0.00 16,198.36 PROJECTED to TO 111272018 1 4237P Page 8 COMPASS 5000.14 Build 85D Cement Detail Report 3S-612 String: Conductor Cement Job: DRILLING ORIGINAL, 10/231201806:00 Cement Details Description Conductor Cement Cementing Start Date 8/4/2018 14:00 lCementing End Date 18/4/20181800 Wellbore Name 3S-612 Comment Cement Stages Stage # 1 Description Conductor Cement Objective I Top Depth (ftKB) 39.0 Bottom Depth (ftKB) 119.0 Full Return? No Vol Cement... Top Plug? No Btm Plug? No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Elm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1214/2018 Cement Detail Report 3S-612 String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/23/2018 06:00 Cement Details Description Cementing Start Date Cementing End Dale Wellbore Name Surface Casing Cement 10/27/2018 01:30 10/27/2018 03:45 35-612 Comment Line up & SLB pump 5 bbls of CW100. Pressure lest lines to 3500 psi, good. Pump 34.9 bbls of CW100 Q 4.7 bpm, 186 psi, FO 17%, PU 171 K, SO 98K. Pump 80.2 bbls of 10.5 ppg MP II @ 5.5 bpm, 190 psi, FO 16%. Drop bottom plug & start batching lead. Pump 508.8 bbls of 11.0 ppg lead cement at 3-6 bpm, 108-310 psi, FO 18%-8%, final PU 177K, SO 74K. Land out casing with 360 bbls of lead away. Pump 64.1 bbls of 12.0 ppg tail cement @ 4.6-6 bpm, 240.390 psi, FO 16%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.9 ppg spud mud @ 6.5 bpm, 283-608 psi, FO 17%. Reduce rate to 2 bpm, 330 psi, FO 9%. Bump plug with 2715 strokes, 273.7 bbls pumped. Pressure up to 850 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 04:55 hrs. Cement Stages Stage # <Stage NumbeR> Description ObjectiveTop Depth (ftKB) Bottom Depth (ftKB) Full Realm? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 43.0 3,034.0 Yes 280.0 Yes I Yes Q Pump [nit (bbl/m... Q Pump Final (bbll... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 6 220.0 350.1 Yes 10.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Line up & SLB pump 5 bbls of CW100. Pressure test lines to 3500 psi, good. Pump 34.9 bible of CW100 @ 4.7 bpm, 186 psi, FO 17%, PU 171 K, SO 98K. Pump 80.2 bbls of 10.5 ppg MP II @ 5.5 bpm, 190 psi, FO 16%. Drop bottom plug & start batching lead. Pump 508.8 bbls of 11.0 ppg lead cement at 3-6 bpm, 108-310 psi, FO 18%-8%, final PU 177K, SO 74K. Land out casing with 360 bible of lead away. Pump 64.1 bbls of 12.0 ppg tail cement @ 4.6-6 bpm, 240-390 psi, FO 16%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.9 ppg spud mud @ 6.5 bpm, 283-608 psi, FO 17%. Reduce rate to 2 bpm, 330 psi, FO 9%. Bump plug with 2715 strokes, 273.7 bbls pumped. Pressure up to 850 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 04:55 him. Cement Fluids & Additives Fluid Fluid TypeFluid Description Estimated Top (ftKB) Est Son (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 43.0 2,534.0 1,496 G 508.8 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.76 1 1 11.00 59.5 4.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Eat Btm (ftKB) Amount (sacks) ClassVolume Pumped (bbl) Tail Cement 2,534.0 3,034.0 219 G 64.1 Yield (ft'/sack) Mix H2O Ratio (Belles... Free Water (%) Density (lb/gal) Plastic Viscm ity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.64 5.63 1 12.00 122.2 2.50 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 121412018 Cement Detail Report Aim 3S-612 String: Intermediate Casing Cement Job: Cement Details Description CementingStart Date Cementing End Date Wellbore Name Intermediate Casing Cement 11/4/2018 13:15 11/4/2018 17:00 3S-612 Comment CEMENTAS PER DETAIL Pump 5 We water. Test lines to 4000 psi. Drop bottom plug. Batch & pump 75 bbls of 12.5 ppg MudPush II, @ 3 bpm, W/ ICP=450 FCP=220 W/ 8% FO. Drop intermediate plug. Batch & pump 303 bbls 15.8 ppg Class G cement @ 5 BPM CP=305 FCP=215 psi, w/15% FO. Drop top plug. Pump 10 bbls water. Swap to dg and displace with 9.5 ppg treated LSND @ 7 bpm ICP=121psi, FCP= 676 psi. Land casing @ 3650 STKS W/67K hookload. Reduce rate t/6 bpm @ 5075 stks, w/ 1100 psi, F/0=16% Reduce Rate T/ 3 bpm, @ 6700 STKS,ICP= 955 FCP=1071 8% F/O. Bump plug 6166 STKS. Pressure up to 1500 psi, hold 5 Mins, verify floats. CIP at 1705 hrs. Cement Stages Stage # <Stage Numl Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... ITop Plug? Btm Plug? Intermediate Casing 8,270.0 13,866.0 Yes 0.0 Yes Yes I Cement O Pump [nit (bbl/m... O Pump Final (bbl/... O Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 5 5 1,070.0 1,500.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment CEMENTAS PER DETAIL Pump 5 bola water. Test lines to 4000 psi. Drop bottom plug. Balch & pump 75 bbls of 12.5 ppg Mud Push ll, @ 3 bpm, W/ ICP=450 FCP=220 W/ 8% FO. Drop intermediate plug. Batch & pump 303 bbls 15.8 ppg Class G cement @ 5 BPM ICP=305 FCP=215 psi, w/15% FO. Drop top plug. Pump 10 bbls water. Swap to rig and displace with 9.5 ppg treated LSND @ 7 bpm ICP=121 psi, FCP= 676 psi. Land rasing @ 3650 STKS W/67K hookload. Reduce rate t/6 bpm @ 5075 stks, w/ 1100 psi, F/0=16% Reduce Rate T/ 3 bpm, @ 6700 STKS,ICP= 955 FCP=1071 8% F/0. Bump plug 6166 STKS. Pressure up to 1500 psi, hold 5 Mins, verify floats. CIP at 1705 hrs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Top (ftKB) Est Bon (ftKB) Amount (sacks) Class Volume Pump atl (bbl) Mud Push II JEstimated 5,410.0 6,811.0 75.0 Yield (ft /sack) Mix H2O Ratio (gages... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bbn (ftKB) Amount (sacks) Class Volume Pumped (titin Intermediate Cement 6,811.0 13,877.0 1,466 G 303.0 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.07 1 15.80 110.3 7.50 Additives Additive Type Concentration Cone Unit label Page 1/1 ReportPrinted: 1214/2018 PTD Loepp, Victoria T (DOA) From: Sylte, Hanna<Hanna.Sylte@conocophiIli ps.com> Sent: Monday, December 3, 2018 9:01 AM To: Schwartz, Guy L (DOA); Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: 3S-611(Sundry #318-488) and 3S-612(Sundry#318-511) Freeze Protect Fluid Follow Up Flag: Follow up Flag Status: Flagged Guy, Sounds good, thank you for the quick reply! Hanna From: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Sent: Monday, December 3, 2018 8:59 AM To: Sylte, Hanna <Hanna.Sylte@conocophillips.com>; Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE: 35-611(Sundry #318-488) and 3S-612(Sundry #318-511) Freeze Protect Fluid Hanna, No issue with swapping fluids for Freeze protect. Good luck. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-7931226 ) or (Guv.schwortz@alaska aov). From: Sylte, Hanna<Hanna.Svite@conocoohillips.com> Sent: Monday, December 3, 2018 8:55 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: RE: 3S-611(Sundry #318-488) and 3S-612(Sundry #318-511) Freeze Protect Fluid Victoria, Due to the supply chain issues we are also considering sourcing LVT from a different supplier. The chemical ingredients are the same as the LVT-200 listed in the initial chemical disclosures but it has a different trade name, ESCAIDTm 110 FLUID. I have attached the SDS information for this product as well. Please let me know if you have any concerns with this or using the methanol mixture described in my last email. Thank you, Hanna 713-449-2197 From: Sylte, Hanna Sent: Sunday, December 2, 2018 8:29 PM To:'Loepp, Victoria T (DOA)' <victoria Ioepp@alaska.gov> Cc: 'guy.schwartz@alaska.gov' <guy. schwa rtz2aIaska.gov> Subject: 35-611(Sundry #318-488) and 35-612(Sundry #318-511) Freeze Protect Fluid Victoria, We are currently working on the 35-611 and 35-612 fracs. In the sundry application we listed LVT-200 as the freeze protect fluid. Due to logistical issues, we are running short on the LVT supply we have on location and the shipment we have on order has been delayed. We are proposing using a 60/40 mixture if methanol and water for the freeze protect fluid instead on the remainder of the 35-611 frac as well as the 35-612 frac, I have attached the SDS for your information. I apologize for the last minute change in plans. Please let me know if you approve this change from the original sundry applications or if you have any concerns, we are hoping to resume frac operations tomorrow. Thank you, Hanna Sylte Completions Engineer ATO 1556 Office: (907) 265-6342 Mobile: (713) 449-2197 Material Safety Data Shut Il"? Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 1. Product and company identification Manufacturer, importer, supplier Celanese Ltd. 1601 W. LBJ Freeway P.O. Box 819005 Dallas, TX 75381-9005 United States Phone: 972 443 4000 Internet: www.celanese.com Transportation emergency phone numbers: In USA, call 800 424 9300 Outside USA, call 703 527 3887, collect calls accepted Synonyms: Methyl alcohol; Carbinol; Monchydroxymethane; Methyl hydroxide. End use: Chemical raw material, chemical intermediate 2. Hazards identification Emergency Overview DANGER! Celanese Canada, Inc. P.O. Box 99 Station Main Edmonton, Alberta, Canada T5J 21-17 Flammable liquid and vapor. Prolonged or repeated contact may dry skin and cause irritation. May be fatal or cause blindness if swallowed. Harmful if inhaled. Causes eye irritation. May cause respiratory tract and skin irritation. Possible birth defect hazard. Contains material which may cause birth defects based on animal data. Vapours are heavier than air and may spread along floors. Product Description Appearance Form liquid Odour alcoholic Colour colourless Potential health effects Routes of exposure Skin, eyes, inhalation, ingestion. 1 of 10 Material Safety Data Sher. i"? Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number Immediate effects 1 Issuing date Sep.27.2006 Inhalation May cause irritation of respiratory tract Symptoms of exposure may include: Central nervous system depression with nausea, dizziness, headache, stupor, uncoordinated or strange behavior or unconsciousness. Adverse effects on vision. Skin May cause skin irritation. Prolonged or repeated contact may dry skin and cause irritation. May be harmful if absorbed through skin. Symptoms of exposure may include: Drying, cracking or inflammation of skin. Central nervous system depression with headache, stupor, uncoordinated or strange behavior or unconsciousness. Prolonged and /or repeated skin contact with methanol -soaked material has produced toxic effects including vision effects and death. Eyes Exposure to vapors and liquid causes eye irritation. Symptoms of exposure may include: Eye irritation, burning sensation, pain, watering, and/or change of vision. Eye injury which may persist for several days. Ingestion May be fatal is swallowed. Symptoms of exposure may include: A small amount of Methanol (usually two or more ounces) can cause mental sluggishness, nausea and vomiting leading to severe illness, and may produce adverse effects on vision with possible blindness or death if treatment is not received. Methanol Reproductive toxicity No toxicity to reproduction Carcinogenic effects No evidence of carcinogenicity in vitro Mutagenicity Not mutagenic in AMES Test in vivo Mutagenicity Mouse micronucleus - negative Developmental effects Induced developmental toxicity and malformations at 20,000 ppm Target organ effects Overexposure (prolonged or repeated exposure) may cause: Central nervous system depression Injury to the eyes Drying of the skin Local irritation at the site of exposure Medical conditions which may be aggravated by exposure: Significant exposure to this chemical may adversely affect people with acute or chronic disease of the: Skin Eyes Central nervous system Digestive tract 2of10 Material Safety Data Sheta Product name Metha MSDS number 80056 Revision Number 1 3 Composition/information on ingredients Celanese Revision Date Sep.27.2006 Issuing date Sep.27.2006 Components CAS -No Percent % Methanol 7-56-1 199.85 min. 4. First aid measures NA/EN General Information Take off all contaminated clothing immediately. Wash contaminated clothing before re -use. Inhalation Move to fresh air in case of accidental inhalation of vapours. If symptoms persist, call a physician. Skin Wash off immediately with plenty of water. If symptoms persist, call a physician. Eyes In the case of contact with eyes, rinse immediately with plenty of water and seek medical advice. Ingestion If swallowed, seek medical advice immediately and show this container or label. Do not induce vomiting without medical advice. 5 Fire4ighting measures NFPA: Health: 1 Flammability: 3 Suitable extinguishing media alcohol -resistant foam, dry powder, carbon dioxide (CO2), water spray Extinguishing media which must not be used for safety reasons Do not use a solid water stream as it may scatter and spread fire. Instability: 0 Special exposure hazards arising from the substance or preparation itself, its combustion products, or released gases Under conditions giving incomplete combustion, hazardous gases produced may consist of carbon monoxide carbon dioxide (CO2) Vapours are heavier than air and may spread along floors Special protective equipment for firefighters Wear self contained breathing apparatus for fire fighting if necessary. Other Information In the event of fire, cool tanks with water spray. Thoroughly decontaminate bunker gear and other fire -fighting equipment before re -use. 3of10 Material Safety Data Sheet ll`� Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 6 Accidental release measures Personal precautions Avoid contact with the skin and the eyes. Keep unnecessary people away; isolate hazard area and deny entry. Stay upwind; keep out of low areas. Isolate for 800 meters or 0.5 miles in all directions if tank, rail car, or tank truck in involved in fire. Evacuate downwind areas as conditions warrant to prevent exposure and to allow vapors or fumes to dissipate. Spills may expose downwind areas to toxic or flammable concentrations over considerable distances in some cases. Environmental precautions Do not allow material to contaminate ground water system. Do not flush into surface water or sanitary sewer system. Dike and collect water used to fight fire. Methods for cleaning Up Soak up with inert absorbent material (e.g. sand, silica gel, acid binder, universal binder, sawdust). Keep in suitable, closed containers for disposal. Dispose of in accordance with local regulations. Authority Notification Within the United States, call the National Response Center (800-424-8802) and appropriate state and local authorities if the quantity released over 24 hours is equal to or greater than the reportable quantity listed below: 5000 Ib/ 2270 kg 7 Handling and storage Handling Advice on safe handling Provide sufficient air exchange and/or exhaust in work rooms. Avoid contact with skin, eyes and clothing. Wash off with soap and water. Decontaminate soiled clothing thoroughly before re -use. . Protection - fire and explosion: Keep away from sources of ignition - No smoking. Take necessary action to avoid static electricity discharge (which might cause ignition of organic vapours). Keep in an area equipped with sprinklers. Storage Technical measures/Storage conditions Keep container tightly closed in a dry and well -ventilated place. Handle and open container with care. Keep away from direct sunlight. 8 Exposure controls /personal protection OSHA Exposure Limits Components TWA Methanol 200 ppm 4of10 Material Safety Data Sheet Product name Methanol MSDS number 80056 Revision Number ACGIH Exposure Limits II`� Celanese Revision Date Sep.27.2006 Issuing date Sep.27.2006 li UNW1l om onents TWA Methanol 200 m [Components STEL Methanol 250 ppm Com onents 111990 NIOSH IDLH 11994 NIOSH IDLH Methanol 125,000 PPM 000 m Exposure controls Engineering measures General or dilution ventilation is frequently insufficient as the sole means of controlling employee exposure. Local ventilation is usually preferred. Where reasonably practicable this should be achieved by the use of local exhaust ventilation and good general extraction. Explosion -proof equipment (for example fans, switches, and grounded ducts) should be used in mechanical ventilation systems. Protective Equipment A safety shower and eyebath should be readily available. General advice Avoid contact with skin and eyes. Do not breathe vapours or spray mist. Hold eye wash fountain available. Remove and wash contaminated clothing before re -use. Respiratory protection Based on workplace contaminant level and working limits of the respirator, use a respirator approved by NIOSH. The following is the minimum recommended equipment for an occupational exposure level. To estimate an occupational exposure level see Section 8 and Section 11. For concentrations > 1 and < 100 times the occupational exposure level: Use Type C full facepiece supplied -air respirator operated in positive -pressure or continuous -flow mode. For concentrations > 100 times the occupational exposure level or greater than the IDLH level or unknown concentrations (such as in emergencies): Use self-contained breathing apparatus with full facepiece in positive -pressure mode or Type C positive -pressure full facepiece supplied -air respirator with an auxiliary positive -pressure self-contained breathing apparatus escape system. For escape: Use self-contained breathing apparatus with full facepiece or any respirator specifically approved for escape. Skin protection: Wear impervious clothing and gloves to prevent contact. Butyl rubber is recommended. Other protective material may be used, depending on the situation, if adequate degradation and permeation data is available. If other chemicals are used in conjunction with this chemical, material selection should be based on protection for all chemicals present Eye/face protection: Wear chemical goggles when there is a reasonable chance of eye contact. 6of10 Material Safety Data Sheet lll`� Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 9 Physical and chemical properties Appearance Form Colour Odour Molecular Weight Flashpoint Autoignition Temperature Lower explosion limit Upper explosion limit Melting point/range Boiling point/range Density Vapour pressure Vapour density 10 Stability and re liquid colourless alcoholic 32.04 12°C(54 °F) 464 °C (867 °F) 6 Vol % 36 Vol % -97.8°C (144°F) 64.7°C (148.5°F) 0.7866 g/ml @ 25°C 127 mm Hg @ 25°C 1.11 (Air -1 @ 20 °C) ctivity Stability Stable under recommended storage conditions Conditions to avoid Keep away from heat,sparks and flame. Materials to avoid Keep away from:, strong acids, oxidizing agents Hazardous Combustion or Decomposition Products: Thermal decomposition products may include oxides of carbon. Hazardous reactions No hazards to be especially mentioned 11 Toxicological information Methanol Oral LD50: 5.6-6.2 g/kg, rat- Not toxic - Based on human exposure reports, a small amount (usually two or more ounces) can cause mental sluggishness, nausea and vomiting leading to severe illness, and may produce adverse effects on vision with possible blindness or death if treatment is not received. Dermal LD50: 15.8 g/kg, rabbit- Not toxic - Repeated exposure causes defatting dermatitis - Based on human exposure reports, prolonged and repeated skin contact methanol - soaked material has produced toxic effects including vision effects and death. 6of10 Material Safety Data Sheet ll"? Celanese Product name Methanol NA/t MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 Inhalation LC50: 83.6 mg/I, rat, 4h- Non-toxic - Based on human exposure reports, levels substantially above the TLV cause stupor, headache, nausea, dizziness, unconsciousness and may produce adverse effects on vision. Skin Sensitization Species Eye Irritation Species Carcinogenic effects Species Study in vitro Mutagenicity in vivo Mutagenicity Reproductive toxicity Routes of exposure Species Developmental effects Species Routes of exposure Developmental effects Species Route of exposure Repeated exposure Species Routes of exposure Neurotoxicity - positive Human experience Moderate eye irritation rabbit eye No evidence of carcinogenicity rats and mice inhalation study Not mutagenic in AMES Test Mouse micronucleus - negative No toxicity to reproduction inhalation rat NOAEL: 1000 mg/kg/day Induced developmental toxicity and malformations at 20,000 ppm rat Inhalation NOAEL: 5000 ppm Induced developmental toxicity and malformations at 5000 ppm mouse inhalation NOAEL:2000 ppm 28 -day No adverse effects Cynomolgus monkey Inhalation NOAEL: 5000 ppm No data 12. Ecological information Methanol Toxicity to fish Species Method Species Method Toxicity to daphnia Species Toxicity to algae Species LC50: 28 g/I (96h) Pimephales promelas (Fathead minnow) Flow- through LC50: 15.4 g/I (96h) Lepomis macrochirus (Bluegill sunfish) Flow-through EC50: 24.5 g/I (48h) Daphnia magna EC50: 7.1 mg/I (48h) Selenastrum capricornutum (green algae) 7of10 Material Safety Data Sheet Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 Biodegradation Bioconcentration factor (BCF) Bioaccumulation 13 Disposal considerations 48 % (5d) <10 Bioaccumulative potential - low Disposal Considerations: Dispose of spilled material in accordance with state and local regulations for hazardous waste. Recommended methods are incineration or biological treatment at a federally or state -permitted disposal facility. Note that this information applies to the material as manufactured; processing, use, or contamination may make this information inappropriate, inaccurate, or incomplete. Note that this handling and disposal information may also apply to empty containers, liners and rinsate. State or local regulations or restrictions are complex and may differ from federal regulations. This information is intended as an aid to proper handling and disposal; the final responsibility for handling and disposal is with the owner of the waste. EPA Hazardous Waste Code(s): U154 14 Transport information US Department of Transportation UNINA Number: UN 1230 Proper Shipping Name Methanol Hazard class 3 Subsidiary hazard 6.1 Packing Group II Reportable Quantity (RQ) 5000 Ib/ 2270 kg TDG UN/NA Number: UN 1230 Proper Shipping Name METHANOL Class: 3 Subsidiary Risk: 6.1 Packing Group: II ICAO/IATA UN -No. UN 1230 Proper Shipping Name Methanol Hazard Class 3 Subsidiary Hazard(s) 6.1 Packing group II IMDG UN/ID No. UN 1230 Proper Shipping Name Methanol 8of10 Material Safety Data Sheet Product name Methanol MSDS number 80056 Revision Number 1 Hazard Class 3 Subsidiary Hazard(s) 6.1 Packing group II EmS Code F -E, S -D 15 Regulatory information Celanese Revision Date Sep.27.2006 Issuing date Sep.27.2006 NA/EN U.S. STATE REGULATIONS Chemicals associated with the product which are subject to the state right -to -know regulations are listed along with the applicable state(s): Methanol 67-56-1 Pennsylvania Listed New York Listed New Jersey Listed Illinois Listed Massachusetts Listed Rhode Island Listed U.S. FEDERAL REGULATIONS TSCA Inventory: We certify that all components are either on the TSCA inventory or qualify for an exemption. Environmental Regulations: Methanol 67-56-1 EPCRA Section 313 Listed CERCLA Hazardous Substance Listed SARA 311 Acute health: Yes Chronic health: Yes Fire: Yes Sudden release of pressure: No Reactive: No INTERNATIONAL REGULATIONS International Chemical Inventory Listed on the chemical inventories of the following countries or qualifies for an exemption: AUSTRALIA,CHINA,CANADA, EUROPE, KOREA, PHILIPPINES, JAPAN 9of10 Material Safety Data Sheec ill"? Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number Canadian Regulations: 1 Issuing date Sep.27.2006 WHMIS Classification: Class B, Division 2. Class D, Division 2, Subdivision A. Division 2, Subdivision B. This product has been classified in accordance with the hazard criteria of the CPR and the MSDS contains all the information required by the CPR. 16 Other information Prepared By Product Stewardship Department Celanese NFPA: Health: 1 Flammability: 3 Instability: 0 HMIS: Health: 2 Flammability: 3 Physical hazard: 0 For more information, other material safety data sheets or technical data sheets please consult the Celanese homepage (www.celanese.com) Sources of key data used to compile the datasheet The absence of data elements required by ANSI or 2001/58/EC indicates, that no data meeting these requirements is available. This information is based on our present state of knowledge. It shall describe our products regarding safety requirements and shall not be construed as a guarantee or statement of condition and/or quality. 10 of 10 Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 1 of 12 SAFETY DATA SHEET SECTION 1 PRODUCT AND COMPANY IDENTIFICATION PRODUCT Product Name: ESCAIDw 110 FLUID Product Description: Dearomatized Hydrocarbons Intended Use: Drilling muds, oil-based COMPANY IDENTIFICATION Supplier: EXXONMOBIL CHEMICAL COMPANY SDS -LOC. 106 22777 Springwoods Village Parkway Spring, TX 77389-1425 USA 24 Hour Health Emergency (800) 726-2015 Transportation Emergency Phone (800) 424-9300 or (703) 527-3887 CHEMTREC Product Technical information (832)624-8500 Supplier General Contact (832) 624-8500 SECTION 2 HAZARDS IDENTIFICATION This material is hazardous according to regulatory guidelines (see (M)SDS Section 15) CLASSIFICATION: Flammable liquid: Category 4. Aspiration toxicant: Category 1. LABEL: Pictogram: Signal Word: Danger Hazard Statements: H227: Combustible liquid. H304: May be fatal if swallowed and enters airways. Precautionary Statements: P210: Keep away from flames and hot surfaces. --No smoking. P280: Wear protective gloves and eye /face protection. P301 + P310: IF SWALLOWED: Immediately calla POISON CENTER or doctor/physician. P331: Do NOT induce vomiting. P370 + P378: In case of fire: Use water fog, foam, dry chemical or carbon dioxide (CO2) to extinguish. P403 + P235: Store in a well -ventilated place. Keep cool. P405: Store locked up.P501: Dispose of contents and container in accordance with local regulations. E;�(onMobil Product Name: ESCAIDTm 110 FLUID Revision Date: 29 Mar 2018 Page 2 of 12 Contains: DISTILLATES (PETROLEUM), HYDROTREATED LIGHT Other hazard information: HAZARD NOT OTHERWISE CLASSIFIED (HNOC): None as defined under 29 CFR 1910.1200. PHYSICAL / CHEMICAL HAZARDS Material can accumulate static charges which may cause an ignition. Material can release vapors that readily form flammable mixtures. Vapor accumulation could flash and/or explode if ignited. Combustible. HEALTH HAZARDS May be irritating to the eyes, nose, throat, and lungs. Repeated exposure may cause skin dryness or cracking. ENVIRONMENTAL HAZARDS No significant hazards. NFPA Hazard ID: Health: 1 Flammability: 2 Reactivity: 0 HMIS Hazard ID: Health: 1* Flammability: 2 Reactivity: 0 NOTE: This material should not be used for any other purpose than the intended use in Section 1 without expert advice. Health studies have shown that chemical exposure may cause potential human health risks which may vary from person to person. SECTION 3 COMPOSITION I INFORMATION ON INGREDIENTS This material is defined as a complex substance. --- i.% mn..:rod fnr diarinsnrn nazaravus ouuwtai 'C6151 as.....„ - ^••-- - - -- ----- CAS# GHS Hazard Codes Name Concentration' DISTILLATES (PETROLEUM), HYDROTREATED LIGHT 64742-47-8 100% H227, H304 * All concentrations are percent by weight unless material is a gas. Gas concentrations are in percent by volume. Concentration values may vary. As per paragraph (i) of 29 CFR 1910.1200, formulation is considered a trade secret and specific chemical identity and exact percentage (concentration) of composition may have been withheld. Specific chemical identity and exact percentage composition will be provided to health professionals, employees, or designated representatives in accordance with applicable provisions of paragraph (i). SECTION 4 FIRST AID MEASURES INHALATION Remove from further exposure. For those providing assistance, avoid exposure to yourself or others. Use adequate respiratory protection. If respiratory irritation, dizziness, nausea, or unconsciousness occurs, seek immediate medical assistance. If breathing has stopped, assist ventilation with a mechanical device or use mouth-to-mouth resuscitation. E*(onMobil Product Name: ESCAIDTm 110 FLUID Revision Date: 29 Mar 2018 Page 3 of 12 SKIN CONTACT Wash contact areas with soap and water. Remove contaminated clothing. Launder contaminated clothing before reuse. EYE CONTACT Flush thoroughly with water. If irritation occurs, get medical assistance. INGESTION Seek immediate medical attention. Do not induce vomiting. NOTE TO PHYSICIAN If ingested, material may be aspirated into the lungs and cause chemical pneumonitis. Treat appropriately. SECTION 5 FIRE FIGHTING MEASURES EXTINGUISHING MEDIA Appropriate Extinguishing Media: Use water fog, foam, dry chemical or carbon dioxide (CO2) to extinguish flames. Inappropriate Extinguishing Media: Straight Streams of Water FIRE FIGHTING Fire Fighting Instructions: Evacuate area. Prevent runoff from fire control or dilution from entering streams, sewers, or drinking water supply. Firefighters should use standard protective equipment and in enclosed spaces, self-contained breathing apparatus (SCBA). Use water spray to cool fire exposed surfaces and to protect personnel. Unusual Fire Hazards: Combustible. Hazardous material. Firefighters should consider protective equipment indicated in Section 8. Hazardous Combustion Products: Incomplete combustion products, Oxides of carbon, Smoke, Fume FLAMMABILITY PROPERTIES Flash Point [Method]: 83°C (181°F) [ASTM D-93] Flammable Limits (Approximate volume % in air): LEL: 0.6 UEL: 5.0 Autoignition Temperature: 228°C (442°F) [ASTM E659] SECTION 6 ACCIDENTAL RELEASE MEASURES NOTIFICATION PROCEDURES In the event of a spill or accidental release, notify relevant authorities in accordance with all applicable regulations. US regulations require reporting releases of this material to the environment which exceed the applicable reportable quantity or oil spills which could reach any waterway including intermittent dry creeks. The National Response Center can be reached at (800)424-8802. PROTECTIVE MEASURES Avoid contact with spilled material. Warn or evacuate occupants in surrounding and downwind areas if required due to toxicity or flammability of the material. See Section 5 for fire fighting information. See the E*onMobil Product Name: ESCAIDTA/ 110 FLUID Revision Date: 29 Mar 2018 Page 4 of 12 Hazard Identification Section for Significant Hazards. See Section 4 for First Aid Advice. See Section 8 for advice on the minimum requirements for personal protective equipment. Additional protective measures may be necessary, depending on the specific circumstances and/or the expert judgment of the emergency responders. For emergency responders: Respiratory protection: half -face or full -face respirator with filter(s) for organic vapor and, when applicable, H2S, or Self Contained Breathing Apparatus (SCBA) can be used depending on the size of spill and potential level of exposure. If the exposure cannot be completely characterized or an oxygen deficient atmosphere is possible or anticipated, SCBA is recommended. Work gloves that are resistant to aromatic hydrocarbons are recommended. Note: gloves made of polyvinyl acetate (PVA) are not water- resistant and are not suitable for emergency use. Chemical goggles are recommended if splashes or contact with eyes is possible. Small spills: normal antistatic work clothes are usually adequate. Large spills: full body suit of chemical resistant, antistatic material is recommended. SPILL MANAGEMENT Land Spill: Stop leak if you can do it without risk. Recover by pumping or with suitable absorbent. Water Spill: Stop leak if you can do it without risk. Warn other shipping. Remove from the surface by skimming or with suitable absorbents. Seek the advice of a specialist before using dispersants. Water spill and land spill recommendations are based on the most likely spill scenario for this material; however, geographic conditions, wind, temperature, (and in the case of a water spill) wave and current direction and speed may greatly influence the appropriate action to be taken. For this reason, local experts should be consulted. Note: Local regulations may prescribe or limit action to be taken. ENVIRONMENTAL PRECAUTIONS Large Spills: Dike far ahead of liquid spill for later recovery and disposal. Prevent entry into waterways, sewers, basements or confined areas. SECTION 7 HANDLING AND STORAGE HANDLING Avoid contact with skin. Prevent small spills and leakage to avoid slip hazard. Material can accumulate static charges which may cause an electrical spark (ignition source). When the material is handled in bulk, an electrical spark could ignite any flammable vapors from liquids or residues that may be present (e.g., during switch -loading operations). Use proper bonding and/or ground procedures. However, bonding and grounds may not eliminate the hazard from static accumulation. Consult local applicable standards for guidance. Additional references include American Petroleum Institute 2003 (Protection Against Ignitions Arising out of Static, Lightning and Stray Currents) or National Fire Protection Agency 77 (Recommended Practice on Static Electricity) or CENELEC CLC/TR 50404 (Electrostatics - Code of practice for the avoidance of hazards due to static electricity). Loading/Unloading Temperature: [Ambient] Transport Temperature: [Ambient] Transport Pressure: [Ambient] Static Accumulator: This material is a static accumulator. A liquid is typically considered a nonconductive, static accumulator if its conductivity is below 100 pS/m (100x10E-12 Siemens per meter) and is considered a semiconductive, static accumulator if its conductivity is below 10,000 PS/m. Whether a liquid is nonconductive or semiconductive, the precautions are the same. A number of factors, for example liquid temperature, presence of contaminants, anti -static additives and filtration can greatly influence the conductivity of a liquid. E*(onMobil Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 5 of 12 STORAGE The type of container used to store the material may affect static accumulation and dissipation. Keep container closed. Handle containers with care. Open slowly in order to control possible pressure release. Store in a cool, well -ventilated area. Storage containers should be grounded and bonded. Fixed storage containers, transfer containers and associated equipment should be grounded and bonded to prevent accumulation of static charge. Storage Temperature: [Ambient] Storage Pressure: [Ambient] Suitable Containers/Packing: Drums, Tank Cars; Tank Trucks; Barges Suitable Materials and Coatings (Chemical Compatibility): Carbon Steel; Stainless Steel; Teflon; Polyethylene, Polypropylene Unsuitable Materials and Coatings: Butyl Rubber; Polystyrene; Ethylene-proplyene-diene monomer (EPDM); Natural Rubber SECTION 8 EXPOSURE CONTROLS I PERSONAL PROTECTION EXPOSURE LIMIT VALUES Exposure limits/standards (Note: Exposure limits are not additive) Substance Name Form I Limit / Standard NOTE Source DISTILLATES (PETROLEUM), TWA 400 mg/m3 100 ppm N/A OSHA Z1 HYDROTREATED LIGHT DISTILLATES (PETROLEUM), Vapor. -1200 165 ppm Total ExxonMobil HYDROTREATED LIGHT TWA m /m3 H drocarbons NOTE: Limits/standards shown for guidance only. Follow applicable regulations. No biological limits allocated. ENGINEERING CONTROLS The level of protection and types of controls necessary will vary depending upon potential exposure conditions. Control measures to consider: Adequate ventilation should be provided so that exposure limits are not exceeded. Use explosion - proof ventilation equipment. PERSONAL PROTECTION Personal protective equipment selections vary based on potential exposure conditions such as applications, handling practices, concentration and ventilation. Information on the selection of protective equipment for use with this material, as provided below, is based upon intended, normal usage. Respiratory Protection: If engineering controls do not maintain airborne contaminant concentrations at a level which is adequate to protect worker health, an approved respirator may be appropriate. Respirator selection, use, and maintenance must be in accordance with regulatory requirements, if applicable. Types of respirators to be considered for this material include: E*(onMobil Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 6 of 12 Half -face filter respirator For high airborne concentrations, use an approved supplied -air respirator, operated in positive pressure mode. Supplied air respirators with an escape bottle may be appropriate when oxygen levels are inadequate, gas/vapor warning properties are poor, or if air purifying filter capacity/rating may be exceeded. Hand Protection: Any specific glove information provided is based on published literature and glove manufacturer data. Glove suitability and breakthrough time will differ depending on the specific use conditions. Contact the glove manufacturer for specific advice on glove selection and breakthrough times for your use conditions. Inspect and replace worn or damaged gloves. The types of gloves to be considered for this material include: If prolonged or repeated contact is likely, chemical resistant gloves are recommended. If contact with forearms is likely, wear gauntlet style gloves. Eye Protection: If contact is likely, safety glasses with side shields are recommended. Skin and Body Protection: Any specific clothing information provided is based on published literature or manufacturer data. The types of clothing to be considered for this material include: If prolonged or repeated contact is likely, chemical, and oil resistant clothing is recommended. Specific Hygiene Measures: Always observe good personal hygiene measures, such as washing after handling the material and before eating, drinking, and/or smoking. Routinely wash work clothing and protective equipment to remove contaminants. Discard contaminated clothing and footwear that cannot be cleaned. Practice good housekeeping. ENVIRONMENTAL CONTROLS Comply with applicable environmental regulations limiting discharge to air, water and soil. Protect the environment by applying appropriate control measures to prevent or limit emissions. SECTION 9 PHYSICAL AND CHEMICAL PROPERTIES Note: Physical and chemical properties are provided for safety, health and environmental considerations only and may not fully represent product specifications. Contact the Supplier for additional information. GENERAL INFORMATION Physical State: Liquid Form: Clear Color: Colorless Odor: Slight Odor Threshold: N/D IMPORTANT HEALTH, SAFETY, AND ENVIRONMENTAL INFORMATION Relative Density (at 15.6 °C): 0.8 [With respect to water) [Calculated] Density (at 15.6 °C): 800 kg/m' (6.68 lbs/gal, 0.8 kg/dm') [ASTM D4052] Flammability (Solid, Gas): N/A Flash Point [Method]: 83°C (181°F) [ASTM D-93] Flammable Limits (Approximate volume % in air): LEL: 0.6 UEL: 5.0 Autoignition Temperature: 228°C (442°F) [ASTM E6591 Boiling Point I Range: 207°C (405°F) - 237°C (459°F) [ASTM D86) Decomposition Temperature: N/D E*(onMobil Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 7 of 12 Vapor Density (Air = 1): 5.9 at 101 kPa [In-house method] Vapor Pressure: 0.01 kPa (0.08 mm Hg) at 20 °C [Calculated] Evaporation Rate (n -butyl acetate = 1): 0.01 [In-house method] pH: N/A Log Pow (n-Octanol/Water Partition Coefficient): > 4 [Estimated] Solubility in Water: Negligible Viscosity: 1.7 cSt (1.7 mm2/sec) at 40 °C I 2.5 cSt (2.5 mm2/sec) at 20°C [Calculated] Oxidizing Properties: See Hazards Identification Section. OTHER INFORMATION Freezing Point: N/D Melting Point: N/A Pour Point: -39-C (-38°F) [ASTM D59501 Molecular Weight: 172 G/MOLE [Calculated] Hygroscopic: No Coefficient of Thermal Expansion: 0.00074 per Deg C [Calculated] SECTION 10 STABILITY AND REACTIVITY REACTIVITY: See sub -sections below. STABILITY: Material is stable under normal conditions. CONDITIONS TO AVOID: Avoid heat, sparks, open flames and other ignition sources. MATERIALS TO AVOID: Strong oxidizers HAZARDOUS DECOMPOSITION PRODUCTS: Material does not decompose at ambient temperatures. POSSIBILITY OF HAZARDOUS REACTIONS: Hazardous polymerization will not occur. SECTION 11 TOXICOLOGICAL INFORMATION INFORMATION ON TOXICOLOGICAL EFFECTS Hazard Class Conclusion / Remarks Inhalation Acute Toxicity: (Rat) 4 hour(s) LC50 > 5000 m/m3 (Vapor) Minimally Toxic. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 403 Irritation: No end point data for material. Negligible hazard at ambient/normal handling temperatures. Ingestion Acute Toxicity (Rat): LD50 > 5000 mg/kg Minimally Toxic. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 401 Skin Acute Toxicity (Rabbit): LD50 > 5000 mg/kg Minimally Toxic. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 402 Skin Corrosion/Irritation: Data available. May dry the skin leading to discomfort and dermatitis. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 404 Eye Serious Eye Damage/irritation: Data May cause mild, short -lasting discomfort to eyes. Based on test Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 8 of 12 available. data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 405 Sensitization Respiratory Sensitization: No end point data Not expected to be a respiratory sensitizer. for material. Skin Sensitization: Data available. Not expected to be a skin sensitizer. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 406 Aspiration: Data available. May be fatal if swallowed and enters airways. Based on physico- chemical properties of the material. Germ Cell Mutagenicity: Data available. Not expected to be a germ cell mutagen. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 471 473 474 476 478 479 Carcinogenicity: Data available. Not expected to cause cancer. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 453 Reproductive Toxicity: Data available. Not expected to be a reproductive toxicant. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 413 414 415 Lactation: No end point data for material. Not expected to cause harm to breast-fed children. Specific Target Organ Toxicity (STOT) Single Exposure: No end point data for Not expected to cause organ damage from a single exposure. material. Repeated Exposure: Data available. Not expected to cause organ damage from prolonged or repeated exposure. Based on test data for structurally similar materials. Test(s) equivalent or similar to OECD Guideline 408 413 OTHER INFORMATION For the product itself: Vapor/aerosol concentrations above recommended exposure levels are irritating to the eyes and respiratory tract, may cause headaches, dizziness, anesthesia, drowsiness, unconsciousness and other central nervous system effects including death. Prolonged and/or repeated skin contact with low viscosity materials may defat the skin resulting in possible irritation and dermatitis. Small amounts of liquid aspirated into the lungs during ingestion or from vomiting may cause chemical pneumonitis or pulmonary edema. The following ingredients are cited on the lists below: None. --REGULATORY LISTS SEARCHED-- - = NTP CARC 3 = IARC 1 5 = IARC 2B 2 = NTP SUS 4 = IARC 2A 6 = OSHA CARC SECTION 12 ECOLOGICAL INFORMATION The information given is based on data available for the material, the components of the material, and similar materials. ZZA Product Name: ESCAIDTm 110 FLUID Revision Date: 29 Mar 2018 Page 9 of 12 ECOTOXICITY Material -- Not expected to be harmful to aquatic organisms. Material -- Not expected to demonstrate chronic toxicity to aquatic organisms. PERSISTENCE AND DEGRADABILITY Biodegradation: Material -- Expected to be readily biodegradable. Hydrolysis: Material -- Transformation due to hydrolysis not expected to be significant. Photolysis: Material -- Transformation due to photolysis not expected to be significant. Atmospheric Oxidation: Material -- Expected to degrade rapidly in air OTHER ECOLOGICAL INFORMATION VOC (EPA Method 24): 6.676 lbs/gal ECOLOGICAL DATA FmMvirity Test Duration Organism Type Test Results Aquatic - Acute Toxicity 48 day(s) Daphnia magna ELO 1000 m /I Aquatic - Acute Toxicity 96 hour(s) Oncorhynchus m kiss LLO 1000 mg/I Aquatic - Acute Toxicity 72 hour(s) Pseudokirchneriella subca itata ELO 1000 mg/I Persistence Degradability and Bioaccumulation Potential Media Test Type I Duration Test Results Water Ready Biode ra ability 1 28 day(s) Percent Degraded 69 SECTION 13 DISPOSAL CONSIDERATIONS Disposal recommendations based on material as supplied. Disposal must be in accordance with current applicable laws and regulations, and material characteristics at time of disposal. DISPOSAL RECOMMENDATIONS Product is suitable for burning in an enclosed controlled burner for fuel value or disposal by supervised incineration at very high temperatures to prevent formation of undesirable combustion products. REGULATORY DISPOSAL INFORMATION RCRA Information: The unused product, in our opinion, is not specifically listed by the EPA as a hazardous waste (40 CFR, Part 261 D), nor is it formulated to contain materials which are listed as hazardous wastes. It does not exhibit the hazardous characteristics of ignitability, corrositivity or reactivity and is not formulated with contaminants as determined by the Toxicity Characteristic Leaching Procedure (TCLP). However, used E*(onMobil Product Name: ESCAIDTm 110 FLUID Revision Date: 29 Mar 2018 Page 10 of 12 may be regulated. Empty Container Warning Empty Container Warning (where applicable): Empty containers may contain residue and can be dangerous. Do not attempt to refill or clean containers without proper instructions. Empty drums should be completely drained and safely stored until appropriately reconditioned or disposed. Empty containers should be taken for recycling, recovery, or disposal through suitably qualified or licensed contractor and in accordance with governmental regulations. DO NOT PRESSURISE, CUT, WELD, BRAZE, SOLDER, DRILL, GRIND, OR EXPOSE SUCH CONTAINERS TO HEAT, FLAME, SPARKS, STATIC ELECTRICITY, OR OTHER SOURCES OF IGNITION. THEY MAY EXPLODE AND CAUSE INJURY OR DEATH. SECTION 14 TRANSPORT INFORMATION LAND (DOT): Not Regulated for Land Transport Footnote: Testing (ASTM D4206) has shown product does not sustain combustion. LAND (TDG): Not Regulated for Land Transport SEA (IMDG): Not Regulated for Sea Transport according to IMDG-Code Marine Pollutant: No AIR (IATA): Not Regulated for Air Transport SECTION 15 REGULATORY INFORMATION OSHA HAZARD COMMUNICATION STANDARD: This material is considered hazardous in accordance with OSHA HazCom 2012, 29 CFR 1910.1200. Listed or exempt from listing/notification on the following chemical inventories: AICS, DSL, ENCS, IECSC, KECI, PICCS, TCSI, TSCA SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 302 CERCLA: This material is not subject to any special reporting under the requirements of the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA). CERCLA petroleum exclusion applies for this product. Contact local authorities to determine if other reporting requirements apply. CWA / OPA: This product is classified as an oil under Section 311 of the Clean Water Act (40 CFR 110) and the Oil Pollution Act of 1990. Discharge or spills which produce a visible sheen on either surface water, or in waterways/sewers which lead to surface water, must be reported to the National Response Center at 800-424-8802. SARA (311/312) REPORTABLE GHS HAZARD CLASSES: Aspiration Hazard, Flammable (gases, aerosols, liquids, or solids) SARA (313) TOXIC RELEASE INVENTORY: This material contains no chemicals subject to the supplier notification E*onMobil Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 11 of 12 requirements of the SARA 313 Toxic Release Program. The following ingredients are cited on the lists below: Chemical Name I CAS Number List Citations DISTILLATES (PETROLEUM),64742-47-8 4, 17, 18 HYDROTREATED LIGHT Code key: CARC=Carcinogen; REPRO=Reproductive SECTION 16 OTHER INFORMATION N/D = Not determined, N/A = Not applicable KEY TO THE H -CODES CONTAINED IN SECTION 3 OF THIS DOCUMENT (for information only): H227: Combustible liquid; Flammable Liquid, Cat 4 H304: May be fatal if swallowed and enters airways; Aspiration, Cat 1 THIS SAFETY DATA SHEET CONTAINS THE FOLLOWING REVISIONS: Section 01: Company Mailing Address information was deleted. Section 01: Company Mailing Address information was modified. ----------------------- The information and recommendations contained herein are, to the best of ExxonMobil's knowledge and belief, accurate and reliable as of the date issued. You can contact ExxonMobil to insure that this document is the most current available from ExxonMobil. The information and recommendations are offered for the user's consideration and examination. It is the user's responsibility to satisfy itself that the product is suitable for the intended use. If buyer repackages this product, it is the user's responsibility to insure proper health, safety and other necessary information is included with and/or on the container. Appropriate warnings and safe -handling procedures should be provided to handlers and users. Alteration of this document is strictly prohibited. Except to the extent required by law, re- publication or retransmission of this document, in whole or in part, is not permitted. The term, "ExxonMobil" is used for convenience, and may include any one or more of ExxonMobil Chemical Company, Exxon Mobil Corporation, or any affiliates in which they directly or indirectly hold any interest. Internal Use Only MHC: 1A, 0, 0, 0, 1, 0 DGN: 4400260HUS (1019199) --REGULATORY LISTS SEARCHED -- 1 = ACGIH ALL 6 = TSCA 5a2 11 = CA P65 REPRO 16 = MN RTK 2 = ACGIH Al 7 = TSCA 5e 12 = CA RTK 17 = NJ RTK 3 = ACGIH A2 8 = TSCA 6 13 = IL RTK 18 = PA RTK 4 = OSHA Z 9 = TSCA 12b 14 = LA RTK 19 = RI RTK 5 = TSCA 4 10 = CA P65 CARC 15 = MI 293 Code key: CARC=Carcinogen; REPRO=Reproductive SECTION 16 OTHER INFORMATION N/D = Not determined, N/A = Not applicable KEY TO THE H -CODES CONTAINED IN SECTION 3 OF THIS DOCUMENT (for information only): H227: Combustible liquid; Flammable Liquid, Cat 4 H304: May be fatal if swallowed and enters airways; Aspiration, Cat 1 THIS SAFETY DATA SHEET CONTAINS THE FOLLOWING REVISIONS: Section 01: Company Mailing Address information was deleted. Section 01: Company Mailing Address information was modified. ----------------------- The information and recommendations contained herein are, to the best of ExxonMobil's knowledge and belief, accurate and reliable as of the date issued. You can contact ExxonMobil to insure that this document is the most current available from ExxonMobil. The information and recommendations are offered for the user's consideration and examination. It is the user's responsibility to satisfy itself that the product is suitable for the intended use. If buyer repackages this product, it is the user's responsibility to insure proper health, safety and other necessary information is included with and/or on the container. Appropriate warnings and safe -handling procedures should be provided to handlers and users. Alteration of this document is strictly prohibited. Except to the extent required by law, re- publication or retransmission of this document, in whole or in part, is not permitted. The term, "ExxonMobil" is used for convenience, and may include any one or more of ExxonMobil Chemical Company, Exxon Mobil Corporation, or any affiliates in which they directly or indirectly hold any interest. Internal Use Only MHC: 1A, 0, 0, 0, 1, 0 DGN: 4400260HUS (1019199) E*onMobil Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 12 of 12 Copyright 2002 Exxon Mobil Corporation, All rights reserved STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED NOV 15 2018 Anna 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑✓ Repair Well ❑ f--4 Weled dWsWdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development ❑' Stratigraphic ❑ Service ❑ 218-111 - 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20777-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? KRU 3S-612 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL380107, ADLO25528, ADI -025544 Kuparuk River Field, Torok Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,862' 5,218' 19,854' 5,218' 7,000 Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' Surface 3027' 10-3/4" 3027' 2,588' Intermediate 131866' 7-5/8" 13,866' 2,218' Production Liner 6,161' 4-1/2"1 19,854' 5,218' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 4.5" L80 13,699' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Packer 13,569' MD/5,057' TVD 12. Attachments: Proposal Summary LJ Wellbore schematic v1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/2/2018 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Dale: 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. Contact Hanna Sylte, 907-265-6342 Email Hanna.Sylte@ConocoPhillips.com Printed Name Hanna Sylte Title Completions Engineer k\ K5 2Ck c� Signature Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / (✓^ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No [� Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10-104 Q.1D4. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I 1 I 2-1 tp'v OD^�A� Submit Form and Form 10-403 Revised 11/2015 Approved a Ilcati d Nle YTL !! ! pp q/'� V 1kN s�Ap ll� t lflWl val. N(�b /�,p lachment . Duplicate 010 � �. Moraine 3S-612 Grass Roots Horizontal Multi -Stage Frac'd Iniector ConocoPhillips Final Wellbore Schematic Cameron 10K 4-'h" tree, lop joint is 4-'/" 1264 HYD563 New Conductor: 20" Conductor @ 119' 3'/e" Camco DB Nipple 3.813" 1920WD 13-1/2" Surface Hole d'/" x 1 " KBMG with SOV 3,644' MO Surface Casing: 10-3/4" 45.5# L-80 Hydril 563/TXP 15(250 3,027' MD / 2,567' TVD 55° :ampanian SS - pof rant 8.210 MD /3,830'TVD - TVD above the K-3) _.._..._ 'ap K=2(Caya e)9<58'M9 14 00 __._c... 9-718" Intermediate Hole Tubina7 4-1/2" 12.6# L-80 Hydrll 563 Ria•G"x1"KBMGwIDV 4,OB0' MD SLB Gauge Cartier, 13,506 MO ker +/- 13,569' MD 4.5" x 7-51�Flex 4 K' Camco DS Nipple 3.]5" nogo 13,633- MD 7-5/8" x 4-ner hanger ZXP liner top packer w/ RS Nipple, @ H- 13693' MD ! Intermediate Casing Set —25' TVD above too Moraine: r°p°t M°rame s 104 rvD �� - 7-5/8" 29.7# L-80 Hydril 563 _. 13,866'MD/5,104'TVD@77° ,. 6.3/4" Production Hole 'oduction Liner Production Hole 0 91D: 1/2" 12.6# HYD563 19,862' MD / 5,218 TVD Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). ConocoPhillips Alaska To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3S-612 Well Kuparuk River Unit, Alaska ADL 380107, KRU Tract 150; ADL 380106 ADL 25528, KRU Tract 147 Dear Sirs: Paul K. Wharton Staff Landman P.O. Box 100360 — Suite ATO 1482 Anchorage, Alaska 99510-0360 Phone (907) 263-4076 Paul. K. Wharton@conocophillips.com KRU Tract 146; ADL 25544, KRU Tract 149; and ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 3S-612 Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about November 14, 2018. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Paul Wharton Staff Landman cc: Hanna Sylte Rebecca Swensen 3S-612 Hydraulic Fracturing Notice Let,_ November 14, 2018 Page 2 Exhibit 1 G¢9 � Frac Points Well Trajectory u ADL355038 Open Interval r Half Mile Frac Point Radius 55039 = 09 Q Half Mile Well Trajectory Radius CPAI Lease Ci ASRC Lease i m . � as j� Caelus Lee Y AyZ 71Y OI 0. A 0! ADL025528 IY i i f e % 009043¢ w _�! ADL380106 <n Ci i i i N 0 ry I 3 S i I s, 3S-620 38,18 PALM.1 I 36-913 �� 3Sbee i 3g OB 35-23A 15 1 3S -08A i � DL390697 ADL0255" ppC' ADL 107 i i i ConocoPhillips Aaska 3S-612 b N Lease Plat 111IW201e L025551 '•-•-•-' ; fO 0.2 0.4 0.6 OMiles 3S-612 Hydraulic Fracturing Notice LetL_. November 14, 2018 Page 3 Exhibit 2 Mineral Owners Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 Anchorage, AK 99501 Attention: Misty Alexa, Manager, NS Development Operator ADL 355038 Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Non -Operators: BP Exploration (Alaska) Inc. 900 E. Benson Boulevard Anchorage, AK Zip 99508 Attention: Mr. Weston Nash Chevron U.S.A. Inc 1400 Smith Street Room 40116 Houston, TX 77002 310 Attention: Dave White ExxonMobil Alaska Production Inc 3700 Centerpoint, Suite 600 Anchorage, AK 99503 Attention: Mr. Jamie Long Non -operator ADL 355038 Eni Petroleum US LLC 1200 Smith, Suite 1700 Houston, TX 77002 Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO THL .,�ASKA OIL AND GAS CONSERVATION CON...,iSSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K. Wharton Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the 3S-612 well ) under the Provisions of 20AAC 25.280 STATE OF ALASKA m THIRD JUDICIAL DISTRICT Paul K. Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton, and I have personal knowledge of the matters set forth herein. 2. 1 am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ('Notice"). 4. On or about November 14, 2018, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 141h day of November, 2018. STATE OF ALASKA M THIRD JUDICIAL DISTRICT x. Paul K. Wharton This instrument was acknowledged before me this 14' day of November, 2018, by Paul K. Wharton. Notary Public, State of Alaska STATE OF ALASKA MDB6410RYSPl96Plpir p, REBECCA SW NSEN M f,pnmiesion Ex ares Aug.. 27, 2020. Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 3S-612 Landowners ,P6 9 0 Frac Points — Well Trajectory m ADL355038 Open Interval 0 O Half Mile Frac Point Radius 55039 0 o Hatt Mile Well Trajectory Radius _ _._.—. 2 it i— _._._. _- _._ - _ _... ? 21,'R(`c _ _ T12 CPAILease ASK Lease �,1 m Z � Caelus lease 71Y 01 i 0°i C ADL025528 IY i i DL390434 ADL380106 rn 1 cif ca 1 — I i ! SSIy, in o � 3S �7? i o I 35-11P °• y p }S 3S�620 35-18 26 i 3519 PALM.1: s I 3S 13 3S 2� 3S�BB p`l 3S i 3S 0B 3S'Z� 9 -23 3S -08A I I --44p•� Y DL39069;7 ADL025544 0� ADL380107 I i i Asti i r ConocoPhillips Alaska N o 3S-612 Asti ry Lease Plat [•-----' 0 0.2 0.4 0.6 11/1312018L025551 I pMiles Table 1: Wells within .5 miles Wells within 1/2 mile buffer of well track * Data from SDE laver: AK WELL BOTTOM TO ATDB DD83 501032045800 35-03 ACTIVE Well In Frac Point API WELL NAME Status Type Radius 501032045800 35-03 ACTIVE PROD 501032045400 35-06 PA INJ 501032045401 3S -06A ACTIVE INJ 501032043000 35-07 ACTIVE PROD 501032045000 3S-08 PA PROD 501032045001 3S -08A PA PROD 501032045002 3S -08B PA PROD 501032045003 3S -08C ACTIVE PROD 501032043200 35-09 ACTIVE INJ 501032044000 35-10 ACTIVE PROD 501032043900 35-14 ACTIVE INJ 501032044400 35-15 ACTIVE PROD 501032044500 35-16 ACTIVE INJ 501032044800 35-17 PA INJ 501032044801 3S -17A ACTIVE INJ 501032043300 35-18 ACTIVE PROD 501032046000 35-19 ACTIVE PROD 501032045200 35-21 ACTIVE INJ 501032044600 35-22 ACTIVE INJ 501032045300 35-23 PA PR00 501032045301 3S -23A ACTIVE PROD 501032045600 35-24 PA PROD 501032045601 3S -24A ACTIVE PROD 501032036101 35-26 ACTIVE INJ 501032077400 35-611 ACTIVE PROD 501032073500 35-613 ACTIVE INJ 501032069500 35-620 ACTIVE PROD 501032069900 MORAINE PA EXPLOR 501032066000 NDST-02 SUSP EXPLOR 501032066070 NDST-02PB1 PA EXPEND 501032064500 NUNA 1 SUSP EXPLOR 501032064570 NUNA 1PB1 PA EXPEND 501032036100 PALM 1 PA EXPLOR Yes Yes Yes . Yes Yes Yes Yes SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See conclusion of the Aquifer Exemption Title 40 CFR 147.102(b)(3) 'The portions of aquifers on the North Slope described by a '% mile area beyond and lying directly below the Kuparuk River Unit oil and gas producing field" as exempt freshwater aquifers under 10 AAC 25.440" SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing was cemented on 10/27/2018. The cement job was pumped with 80 bbls MPII and 509 bbls of 11 ppg lead cement, this was followed by 64 bbls of 12 ppg tail cement and displaced with 9.9 ppg mud. The plug bumped at 850 psi and the floats were checked and they held. The 7-5/8" casing cement report on 11/4/2018 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 303 bbls 15.8 ppg Class G cement and dropped top plug. This was chased with 9.5 ppg LSND mud. Full returns were seen throughout the job. The plug bumped at 1500 psi. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. Ar k/Z, SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 10/28/2018 the 10 & 3/4" casing was pressure tested to 3000 psi for 30 mins. On 11/14/2018 the 7 & 5/8" casing was pressure tested to 3850 psi. The 7 & 5/8" casing will be pressure tested to 3,850 psi prior to frac'ing. The 4.5" tubing will be pressure tested to 4,100 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,000 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7 5/8" Annulus pressure test 3,850 A1/2" Tubing pressure Test 4,100 Nitrogen PRV 8,550 Highest pump trip 8,050 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10&3 d' 45.5 L-80 5,210 psi 2,470 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 4.5" 12.6 L-80 8,430 psi 7,500 psi Table 2: Pressure Ratings Stimulation Surface Rig -Up a 2 P 1 at,/Tattle Teck Tele yMj dumd `m E E c Pop -0B Tank Frac Pump • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3600 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree rated to 10,000 psi Pop -Off Tack Pump Truce Frac Pump Frac Pump -i--I'63'�-pFl-) Fm Pump Rote: Dimensional information reflected on this drawing are estimated measurements only. 13 10K Frac Tree 4" IOK Valve + Tree Cap — 39.5" 4" IOK Valve + 4" IOK z 4" 1002 ^ 333,5" ConocoPhillips Drill Site 2S- i OK Frac Tree Weight of entire tree is —6,200 lbs 4" IOK HWO Valves —860 lbs Tree Cap —250 Is ,'CAMERON SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the Torok "Moraine" reservoir, has an average thickness of approximately 280 ft TVD over the course of the lateral section of the 3S-612, from where it intersects the top formation at 13,948 ft MD to TD of the well. The Torok is comprised of thinly interbedded sandstone, siltstone, and mudstone layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and very fine grained. The mudstones are composed of clay -rich, moderately to poorly sorted silt and mud grains. The estimated fracture pressure for the Moraine interval is =12.5-13.5 ppg. The overlying confining interval of the Torok Formation consists of mudstone and siltstone with an average thickness of =1,000 ft. TVD. The top of the Torok confining interval starts at 4,039 ft. TVDSS (9,471 ft. MD). The estimated fracture gradient of the overlying Torok formation is =0.82 psi/ft. The underlying confining zone consists of lower Torok, HRZ, and Kalubik shales totaling approximately 500' TVD. The estimated fracture gradient for this section ranges from 15-18 ppg, with the gradient increasing down section. The top of the HRZ is estimated to be at approximately 5,550 ft TVDSS at the heel, and approximately 5,540 ft TVDSS at the toe of the well. (no MD as the HRZ is not penetrated in the 3S-612 well). SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(1O) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casina & Cement assessments for all wells that may transect the confining zone: 3S-611: The 7-5/8" casing cement report on 10/13/2018 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 270 bbls 15.8 ppg Class G cement and dropped top plug. This was chased with 9.4 ppg LSND mud. Full returns were seen throughout the job. The plug bumped at 1500 psi. 3S-620: The 7 & 5/8 casing cement pump report on 2/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement, displaced with 9.7 ppg mud. The plug bumped at 1,000 psi and the floats were checked and they held. 3S-613: The 7-5/8" casing cement report on 5/2/2016 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 15.8 ppg cement and dropped top plug. This was chased with 9.3 ppg LSND mud. Full returns were seen throughout the job. The plug bumped at 941 psi and the floats were checked and they held. NDST-02: According to the Pioneer Natural Resources job log on the AOGCC website, the 7- 5/8" casing was cemented on 2/9/2013. The cement report indicates that the job was pumped with 60 bbl 15.8ppg Premium Cement. Full circulation was seen throughout the job. The plug pumped at 3500 psi and the floats were checked and they held. Source: http://aogweb.state.ak.us/WebLink/DocView.aspx?id=43019&searchid=d7567104- bOf6-4da3-b564-d294f7b6ed84&dbid=0&cr=1&cc=1#, Page 108 NDST-02PB1: According to the Pioneer Natural Resources job log on the AOGCC website, the top plug was pumped in NDST-02PB1 on 1/31/2013. The plug was pumped with 254 sx of Premium Cement with full returns throughout the job. The TOC was tagged at 8,012'. Source: http://aogweb. state. ak us/WebLOWDocView. aspx?id=43019 &searchid=d7567104- bOf6-4da3-b564-d294f7b6ed84&dbid=0&cr-1&cc=1#, page 110 Nuna 1: According to the Pioneer Natural Resources job log on the AOGCC website, the 7- 5/8" casing was cemented on 2/16/2012. The cement report indicates that the job was pumped with 192 sx 15.8ppg Class G cement. Partial returns were seen. Source: http://aogweb. state. ak. us/WebLinWDocView. aspx?id=39505&searchid=edb77d4c- f03e-45le-ae3b-baa6eeea8f35&dbid=0&cr=1&cc=1#, page 201 Nuna 1 PBI: According to the Pioneer Natural Resources job log on the AOGCC website, the top plug was pumped in Nuna 1 PB1 on 2/10/2012. The top plug was pumped with 280 sx of Premium Cement. Firm cement was encountered at -5766'. Source: http://aogweb.state.ak.us/WebLinWDocView.aspx?id=39505&searchid=edb77d4c- f03e-45le-ae3b-baa6eeea8f35&dbid=0&cr-1&cc=1#, page 201 35-612 Fracture Stimulation Area of Review 7F (h {�oim a. /'i or -a 5"ovrGG� {�✓o -2.y, �O(z C'C WG.b Si�ti VPab/s fb /Ocart o/ er opr /ar in Fe � �l� Top of Torok Oil Top of Torok Top of Cement Top of Cement Top of Cement Cement Operations WELL NAME STATUS Casing She Pool (MD) Oil Pool (MD) (WM) Determined By Reservoir Status Zonal Isolation Summary Mechanical Integrity (TVOSS) 35{31 Active 7-5/8" 12,810' 4,885' 8,228' 3,904' Sonic Scope Open hole liner for production T0C at 8,228'and packer at 270 bbis 15.8 ppg Class G 10/22/18 MITA to 39W 12,338'MD cemnet psi 35-013 Active 7-5/8" 10,962' 5,088' 6,100' 3,644' Sonic Scope Open hole liner for injection T0C at 6,10)'and packer at 47 bbis 15.eppg class 8/5/18 MITIA to 1985 psi 10909'MD cement 35-620 Active 7-5/8" 9,108' 5,099' 6,034' 3,790' Calculated Open hole liner forproduction TOC at -6,034' and production 181 bbis 15.8 ppg class G 2/17/2015 MITIA to 3500 packer at 9,093'MD cement psi NDST-02• SUSP 7-5/8" 8650' 4,836' •• ** "• Suspended TOC at 8650'and ZXP packer at GO bbls 15.8ppg Premium 10191' Cement NDST-02 PBI• PA ne •• "• "+ •' `• PA Cement plugs Top Plug pumped with 254 sx na Premium cement None SUSP 7-5/8" 6,895' 4,993' "* •• `• Suspended ." 192 sx 15.8 ppg Class G cement •+ Nona 1PB3" PA na PA Cement plugs Top plug pumped with 280 sx no Premium Cement 7F (h {�oim a. /'i or -a 5"ovrGG� {�✓o -2.y, �O(z C'C WG.b Si�ti VPab/s fb /Ocart o/ er opr /ar in Fe � �l� SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that there is a single fault that transects the Torok oil pool within one half mile radius of the wellbore trajectory of the 3S-611 well. This fault was encountered during the drilling of the offset 3S-611 wellbore (as detailed in the table below). No faults were ✓ encountered during the drilling of the subject 3S-612 well. This fault is interpreted to not extend up through the confining interval. CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the fault will not interfere with containment. Well Name Depth MD (ft) Depth TVDSS Vertical Losses (bbl/hr) (ft) Displacement ft 3S-611 17,517 5,173 10 None Plat 2: Fault Analvsis �G\y9 Frac Points — Well Trajectory ADL355038 — Open Interval a N ti — Faults within Frac Point Radius N 0 4 55039 z o Wells within Frac Point Radius ._. ......... ........... 2 _.—._ _._._._ _... i jj Half Mlle Frac Point Radius .. �,i C� Half Mile Well Trajectory Radius YCPAI qGy Lease I ASRC Lease 71Y 0. O O I m = Caelus Lease 0! _ ADL025528 IY i i DL390434 ADL380106 i I I I I � i 3 s�71 i I ds i �7? I i I 3's i n i 35 i3 I I LJ DL390697 ADL025544- i ADL380107 I i I ConocoPhillips Alaska N 3S-612 Fault Analysis r•-•---- 0 0.2 o.a os 11/13/2018 1-025551 i oMiles SECTION 12 - PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3S-612 was completed in 2018 as horizontal injector in the Torok formation. The well was completed with 4.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 151 stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Torok Formation Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 22 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 29,000 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the —500 bbl breakdown stage (30# Hybor G) according to the attached PDF HES pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 7000 psi. 12. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). ConocoPhillips discloses that it will be using Chemical Frac Tracers and Oil Frac Tracers for tracing purposes in the concentrations detailed in the attached ProTechnics Hydraulic Fracturing Fluid Product Component Information Disclosure. In support of this application, ConocoPhillips provides the front page of the Core Lab/Protechnics' MSDSs for each of the chemical additive, as well as the Hydraulic Fracturing Fluid Product Component Information Disclosure provided by Core Lab/Protechnics. Core Lab/Protechnics will supply the AOGCC with additional chemical disclosure information for the proprietary additives listed in the Hydraulic Fracturing Fluid Product Component Information Disclosure KRU 3S-612 Stages Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 207,200 19,754 5,074 390 236 0.246 2 207,200 19,342 5,082 320 232 0.221 3 207,200 18,867 5,086 330 232 0.222 4 207,200 18,391 5,090 330 232 0.221 5 207,200 17,856 5,098 350 228 0.219 6 207,200 17,379 5,102 350 228 0.218 7 207,200 16,900 5,106 360 228 0.224 8 207,200 16,347 5,114 350 240 0.221 9 207,200 15,870 5,118 330 228 0.225 10 207,200 15,391 5,122 330 228 0.227 11 207,200 14,874 5,126 330 228 0.228 12 207,200 14,360 5,126 330 232 0.236 Disclaimer Notice: This model was generated using commercially available modeling software reservoir properties. Conoco Phillips is providing these model results as Because of the inherent limitations in assumptions required to generate this may differ from the model results Propped half-length calculated using 1 Ib/sqft cutoff and is based on engineering estimates of an informed prediction of actual results. model, and for other reasons, actual results CUSTOMER ConowPhilllps Alaska, Inc API 50-10340777 FD(Ib/9PIf 8.54 - 12879084 N4LLIBIIRTON ' LEASE KRU 35-611 SALES ORDER BHST(-F) 165 -- .2823663 ;;,,wn Adaibues Ory Additives reatmen Interval Stige Number FORMATION Fluid Description Moralise sop Description Preppant Description ^ Prop C rc 10 urry Rate (bpm ^^ can Volume W Volume (bbl urry Volume bbl) Prop Total lbs tags Time (hh:mmss Intervalo- Time blit sJ u ludeconr (#pr) a., (9PU - Gmrlinkn (9pU D.OkAer t - I erern,,M (9PU Gel L tllarNe (APT) mil o- Breaks, ( L ptl 0-11 &e.. LI SF (P1H) 1-1 30#HborG Load Well 5 1.000 24 24 0:04:46 1:17:48 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-2 309 HborG Mini -Frac SO 21.000 500 500 0:10:00 1:13:02 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-3 3Dft Dr., Flush 935 284 284 0:05:41 1:03:02 1.00 30.00 0.15 2.00 0.25 1-4 Shut -In Shut -In 0:5>:21 3-5 30#H borG Pad 200 267 267 0:05:20 0:57:21 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 2 1w6 30#H borG Pad 100 mesh 0.25,800 68fi 686 7,200 01352 0:52:01 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 $'gym 1w7 30#HborG Proant Laden Fluid Wan1i 20/40 1.002,000 286 298 12,000 0:05:58 0:38:09 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-8 30#HyborG Pro ant laden Fluid Wank 20/40 2.00s WO 429 466 36,000 0:09:21 0:32:11 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 LAB 30P HyborG Pra nt Laden Fluid WanIi 20/40 3.008000 J267 429 484 54000 0:09:45 0:22:49 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-10 30#H borG Pro ant Laden Fluid WanIi 20/40 4.002,000 286 335 48,000 0:06:45 0:13:05 1.00 0.80 0.911 0.45 30.00 0.15 2.00 0.25 1-11 30#H borG Proant Laden Fluid WanIi 20/40 5.000,000 238 290 50,000 0:05:51 0'.06:19 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 1-12 30#H borG S acer&Drop Ball 000 24 24. 0:00:29 0:00:29 1.00 0.80 0.90 045 30.00 0.15 200 0.25 2-1 30#HyborG Pad 1200 267 267 0:05:20 0:52:41 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 2-2 30# N bor G Pad 100 mesh 0.258 666. 686 7,200 0:13:52 0:47:21 1.OD 0.80 0.90 0.45 30.00 0.35 2.00 0.25 23 30#HyborG Pro ant laden Fluid WanIi 20/40 1.0000O 143149 6000 0:02:59 0:33:29 1.00 0.80 0.90 0.45 3000 0.15 2.00 0.25 2-4 30#H bore Pro nt Laden Fluid Wanll 20/40 2.00000 143 15S 12.000 0:03:07 0:30:30 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 �S b5 30p HyborG Proppart Laden Fluid Wadi 20/40 3.00 50 7000 167 188 23OWI 0:03:47 0:27:23 1.00 0.80 0.90 0.45 MOD OAS 2.00 0.25 2.j 2-6 30#HbcrG ProanHaden Fluid Wang 2040 4.00 50 8000 190 223 32,000 0:04:30 0:23:35 1.00 D.80 0.90 OAS 30.00 0.15 2.00 0.25 jB 2-7 30#HborG Pro ntladen Fluid WanIi 2040 5.00 50 8000 190 232 40,000 004:41 01905 1.00 0.80 0.90 0,45 30.00 0.15 2.00 0.25 2-8 3ONH borG Pro ant Laden Fluid WanIi 2040 6.00 50 7834 187 235 47,004 0:04:45 0:14:24 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 2-9 3O#H orG Proant laden Fluid Wanii 20/40 7.00 50 6,000 143 186 42,000 0:03:46 0:09:39 3.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 As 2-10 3W Linear Flush 50 11523 274 274 0:05:29 0:05:53 1.00 30.00 0.15 2.00 0.25 0.50 2-11 Freeze Protect Freeze Profen 50 840 20 20 0:00:24 0:00:24 100000 3-1 30#HyborG Spacer &Drop Ball 50 1000 24 24 0:00:29 0:52:45 1.00 0.80 0.90 0.45 30.00 on 2.00 0.25 3-2 30#HyborG Dis lacment 50 10,475 249 249 0:04:59 0:52:16 1.00 0.80 0.90 OAS 30.00 0.15 2.00 0.25 se 3-3 30p HyborG Pad 100 mesh 50 11200 267 267 0:05:20 0:4):17 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 3.4 3O#HyborG Pad 100 mesh 0.25 50 28800 686 686 7,200 0:13:52 0:41:57 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 ^ 3-5 304HborG Pro ant Laden Fluid WanIi 20/40 1.00 50 6000 143 149 6,000 0:02:59 0:28:04 1.00 0.80 0.90 0.45 30.00 GAS 2.00 0.25 4: }6 30# llborG Proant Laden Fluid WanIi 20/40 2.00 50 6000 143 155 12,000 0:03:07 0:25:05 1.00 0.80 0.9D 0.45 30.00 0.15 2.00 0.25 2@m cPm }) 30p HyborG Pro n[Laden Fluid WanIi 20/40 3.00 50 7000 167 188 21000 0:0347 0:21:58 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 3-8 30#HborG Proant Laden Fluid Wanll 20/40 4.00 50 8000 190 223 32000 0:04:30 0:18:11 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 3-9 30#H borG Pro ant Laden Fluid WanIi 20/40 5.00 50 8000 190 232 40.000 0:04:41 0:13:40 100 0.80 0.90 0.45 30.00 0.15 2.00 0.25 3-10 30#H borG Pro ant Laden Fluid WanIi 20/40 &DO 50 7.834 187 235 4]004 0:04:45 0:09:00 1.00 0.80 0.90 0.45 30.W 0.15 2.00 0.25 3.11 30#HyborG Pro ant Laden Fluid WanIi 20/40 7.00 50 6000 143 186 42000 0:03:46 0:04:15 1.00 0.80 0.90 0.45 3000 0.15 200 0.25 3-12 30#HyborG S ... I,&Dro 8.11 50 1,000 24 24 CM 29 0'.00',29 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 4-1 30#HyborG Pad 50 11.200 267 267 0.0520 0:47:17 1.00 0.80 DEC, 0.45 30.00 0.15 200 0.25 4-2 30#H borG Pad 100 mesh 0.25 50 28.800 686 686 7200 0:13:52 0:41:57 1.00 0.80 0.90 0.45 30.00 0.15 200 0.25 4-3 30# borG Pro am Laden Flultl WanIi 2040 100 50 6.000 143 149 fi000 0:02:59 0:28:04 1.00 0.80 0.90 OAS 30.00 0.15 2.00 0.25 4-4 30#HborIS Pro ant Laden Fluid Wang 20/40 2.00 50 6.000 143 155 12000 0:03:07 0:25:05 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 m'LL 4-5 30 HborG Pro ant Laden Fluid Wang 2040 300 50 7,000 167 188 21000 0:03:47 0:21:58 IN 0.80 0.90 0.45 30.00 0.15 2.00 0.25 2^ cSn� 4-6 30#NyborG Pro pant laden Fluid WanIi 2040 4.00 50 8.000 190 223 32000 0:04:30 0:18:11 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 4-7 30#H orG Propant Laden Fluid WanIi 2040 500 50 8.000 190 232 40000 0:04:41 0:13:40 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 a8 30# borG Proppant Laden Fluid Wank 2040 6.00 50 ]834 187 235 47,004 0:04:45 0:09:00 1.00 0.60 0.90 0,45 3000 0.15 2.00 0.25 4-9 30#HberG Pop ntLaden Fluid WanIi 20/40 7.00 50 6000 143 186 42000 0:03:46 0:04:15 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 4-10 30#Hbo1G 5 acer&OroBall 50 000 24 24 0:00:29 0:00:29 1.00 0.80 0.90 0.45 MOD 0.15 2.00 0.25 5-1 30#HborG Pad 50 11200 267 267 0:05:20 0:52:14 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 5-2 30p HyborG Pad 100 mesh 0.25 50 28800 636 686 7200 0:13:52 0:46:54 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 5-3 30#H bo,G P,.pct Laden Fluid WanIi 20/40 1.00 50 6000 143 149 6000 0:02:59 0:33:02 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 5-4 30#HborG Pro ant Laden Fluid WanIi 2040 2.00 50 6000 43 1!L4- 155 12000 0:03:07 0:30:03 1.00 DAD 0.90 0.45 30.00 0.15 200 0.25 5-5 30#HborG Pro am Laden Fluid WanIi 2040 3.00 50 ]000 167 188 21,000 0:03:47 0:26:56 1.00 0.80 0.90 0.45 MOD 0.15 2.00 2 Es:L }fi 30#M borG Pro n[Laden Fluid Wan1120/40 4.00 50 8000 190 223 32,000 0:04:30 0:23:08 1.00 0.80 0.90 0.45 30.00 0.15 2.00 5-] ?OkH bore Pro ant Laden Fluid WanIi 2040 5.00 50 8000 190 232 40,000 0:04:41 0:18:38 1.00 0.80 0.90 0.45 30.00 0.15 2.00 5-8 30#H bore Pro ant Laden Fluid Wanli 2040 6.00 50 7834 187 235 47,004 0:04:45 0:13:5] 1.00 0.80 0.90 OAS 30.00 0.15 2.00 A0.25 SA 3MlH bore Pro ant Laden Fluid WanIi 2040 7.00 50 6000 143 186 42,000 0:03:46 0:09:12 1.00 0.80 0.90 0.45 30.00 0.15 2.00 5-10 30p Unear Flush 50 10574 252 252 0:05:02 0:05:26 1.00 30.00 0.15 200 5-11 Freeze Protect Freeze Protect 50 840 20 20 0:00:24 0:00:24 1000.00 a co fm CUSTOMER ConocoPhillips Alaska, Inc. API SO -103-20777 FD libIVI)s.5a "- R87NSo LEASE RR03S-611 SALES ORDER BHSTrF) 165 HA4.L�WT� v. _ .2823663 FORMATION Moraine DATE Mas Pressurelpsd 0.80 0.90 0.45 30.00 rop urry urry rop 8e n erva Fluid Stade Pr000ant Conc Pate Volume Volume Volume Total Time Time 1-1 1 3flp HvberG I Pad I In. msch 1 .15 E In I JPPnn I PPF I fiPfi 1 71. 1 111311 I n41-17 1 inn I n n 1 n.r, 1 7-3 30RH borG Pnoppent Laden Fluid Wanli 20/40 1.00 50 6,000 143 149 6,000 0:02:59 0:28:04 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 7-4 30pHborG Pro ant Laden Fluid Wanli 2040 2.00 50 6,000 143 155 12,000 0:03:07 0:25:05 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 7-5 30RH borG Proppant Laden Fluid We nii 20/40 3.00 50 7,000 167 188 21,000 0:03:47 0:21:58 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 7-6 30#H bore Proppant Laden Fluid Wanli 20/40- COD 50 8,000 190 223 32000 094:30 0:18:11 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 7-7 3011,HbmG Proppant Laden Fluid v Wanli 2040 5.00 50 8000 190 232 40000 0:04:41 0:13:40 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 7-8 308HborG Proppant Laden Fluid Wanli 20/40 6.00 50 7,834 187 23S 47W4 0:04:45 0:09:00 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 777 30#H borG Proppant Laden Fluid Wanll 2040 ]9O 50 6,D00 143 186 42,000 0:03:46 0:04:15 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 7-10 309 HyborG 5 e,s,r & Drop Ball 50 1,OOD 24 24 0:00:29 0:00:29 1.00 0.80 0.90 D.45 30.00 0.15 2.00 0.25 8-1 30IIHyborG Pad 50 11,20D 267 267 0:05:20 0:51:47 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 B-2 30R H bor G Pad 100 mesh 0.25 50 28,800 686 686 7,200 0:13:52 0:46:27 1.00 0.80 0.90 0.45 1 30.00 0.15 2.00 1 0.25 8-3 30RH borG Proppant Laden Fluid Ward WM I 1.OD 50 6,000 143 149 6,000 0:02:59 0:32:34 1 1.00 1 0.80 090 0.45 1 3000 0.15 2.00 0.25 84 300HborG Proppant laden Fluid Wanli 2040 2.00 50 6,000 143 155 12,000 0:03:07 0:29:35 190 0.80 0.90 0.45 W.OD 0.15 2.00 0.25 8-5 30#H bwG Pro ant Laden Fluid Wan112040 3.00 50 7000 167 188 21,000 0:03:47 0:26:28 1.00 0.80 0.90 0.45 30.00 0.15 290 0.25 8-6 30UH borG Pro ant Laden Fluid Wen82040 4.00 50 8,000 190 223 3200D 0:04:30 0:22:41 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 8-7 300 HyborG Proppant Laden Fluid Wanll 2040 5.00 50 8,000 190 232 40,000 0:04:41 01810 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 8-8 30 HyborG Proppant Laden Fluid Wanli 20/40 6.00 50 7,834 187 235 47,004 0:04:45 0:13:30 1.00 0.80 0.90 0.45 30DD 0.15 2.00 0.25 0.25 8-9 30p loo,G Prpp nt Laden Fluid Wanli 2040 7.00 50 6,000 143 186 42,000 0:03:46 D:08:45 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 &30 W# linear Flush 50 9,609 229 229 0:0435 D:04:59 1.00 30.00 0.15 2.00 0.25 0.50 &11 Freeze Protect Freeze Protect 50 840 20 20 0:00:24 3:00:24 1000.00 9-1 308H borG S acer & Drop Ball 50 11000 24 24 0:00:29 0:52:45 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 C 5£u Z CU90MER Cnnocophlllips Also, Inc. API 50-103-20777 FD(16/polJ a.54 - -- Iz8]s094 LUSE KRU 35-611 SALES ORDER MST rF) 165 NAl_LI... TM - 2923663 11,235,9461 28,939 131,408 1 2,486,444 110:37:04 I Proppant Type ign TO[al (Ibsf 71 6 0/40 2,400,044 100 mesh 8fi,400 Initial Design Material Volume Max Additive Rate Min Additive Rate Lo-Surf3000 MO -61 CL -22 UC C1-31 FORMATION Moraine BE -6 DATE OpdFI.-II Max Pressure lase (get) (gal)(gal (gap (01) lbs I 165 b' uid Additives I lbs 1211.2 934.1 1 1,050.8 525.4 Ory Additives 1 36,337.4 181.7 1 2,422.5 302.8 1 41.6 0.2 0.2 0.2 0.1 Prep Slurry Clean C11 n Slur, 0.1 Mage, Interval Lo -bur,- - - ph ia o ¢atmen Stage Fluadpt PropDescription Cane Rate Volume Volume Volume TotalTime TIm! $u/feclanl Buffer GNsllnktt Crfalin4er Freere %orect Gel alaclEe Breakcr an ¢reakee Interval Number Oescri tion stag¢ Description Deuription (bpm) (gall L. 661 ibs) am:ss) hh:mm:ss t t 11 c (got) (pot (ppt) (pat (ppt) (opt) 11-1 30 Militia,G Pad 50 11,200 261 267 0:05:20 0:51:20 1.00 0.80 0.90 Oa,S 30.00 0.15 2.00 0.25 a. Il -2 3011 Hybor G Pad 100 mesh 0.25 50 28,800 686 686 7,200 0:13:52 0:46:00 1.00 0.80 0.90 0.45 MIX) 0.15 2.00 0.25 11-3 30#HyborG Proant Laden Fluid Wan112040 1.00 50 ISOM 143 149 630 O:D2:59 0:32:07 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 Y 11-4 30#H borG Pro ant Laden Fluid WanIi 2040 2.00 50 6000 143 155 12,000 0:03:07 0:29:08 1.00 0.80 0.90 0.45 30.00 0.15 2.0D 0.25 _ 11.5 30#HyborG Proant Laden Fluid WanIi 20/40 3.00 50 7000 167 188 21,000 0:03:47 0:26:01 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 2 E •' 11-6 30#H b.rG Proant Laden Fluid Wanli 20/40 4.00 50 8,000 190 223 32000 O:D4:30 0:22:14 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 `c f 11-7 30# HyborG Proant Laden Fluid WanIi 20/40 5.00 50 8,000 190 232 40,000 0:04:41 0:17:44 1.00 0.90 0.90 0.45 30.00 0.15 2.00 0.25 31-8 30#HyborG Pro and Laden Fluid Wanli 20/40 6.00 50 ]834 187 235 47004 0:04:45 0:13:03 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 11.9 30#HyborG p roppant Laden Fluid WanIi 20/40 7.00 50 6000 143 386 42000 1 0:03:46 0:08:18 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 11-10 30# Linear Flush 50 8667 206 206 0:04:08 0:04:32 1.00 0.80 0.90 0.45 30.00 0115 2.00 0.25 0.50 31-11 Freese Protect Freeze Protect 50 840 20 20 0:00:24 0:00:24 1000.00 12-1 3HIf borG Part 50 11200 261 267 0:05:20 0:51:10 1.00 0.80 0.90 0.45 1 30.00 0.15 2.00 0.25 u. 12-2 30#HyborG Pad 100 mesh 0.25 50 28,800 686 686 7,200 0:13:52 0:45:50 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0,25 12-3 30#HyborG Pm,tv,1 Laden Fluid WanIi 20/40 1.00 50 6,000 143 149 6,000 0:02:59 0:31:58 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 C 12-4 30#HyborG Proppant Laden Fluid Wa0 20/40 2.00 50 6,000 143 155 12,000 O:D3:07 0:28:59 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 _ 12-5 30#HborG Propant Laden Fluid Wank 20/40 3.00 50 7000 167 188 23000 003:47 0:25:52 1.00 0.30 0.90 0.45 30.00 0.15 2.00 0.25 2ov 12-6 3WHborIS Propant Laden Fluid Wank 20/40 4.00 50 8,000 190 223 32000 0`.04:30 0:22:04 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 RBE 124 30#HborG Pro ant Laden Fluid WanIi 20/40 5.00 50 8000 190 232 40,000 0:04:41 0:17:34 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 so 12-6 30#HborG Proppant Laden Fluid WanIi 20/40 6.00 50 7,834 181 235 47004 0:04:45 0:1253 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0.25 12-9 30#HborG Proant Laden Fluid WanIi 20/40 ].00 50 6000 143 186 42,000 0:03:46 0:08:08 1,00 0.80 0.90 0.45 30.00 0.15 2.OD 0,25 0.25 12-10 30#Linear Flush 50 8339 199 199 003:58 0:04:22 2.3 0.80 D.90 0.45 3000 0.15 2.013 0.25 0.50 12-13 Freeze Protect Freeze Prated 50 840 20 1 20 0:00:24 0:3:24 1000.00 11,235,9461 28,939 131,408 1 2,486,444 110:37:04 I Proppant Type ign TO[al (Ibsf 71 6 0/40 2,400,044 100 mesh 8fi,400 Initial Design Material Volume Max Additive Rate Min Additive Rate Lo-Surf3000 MO -61 CL -22 UC C1-31 LW -200 WG -36 BE -6 OptiFlo-III OpdFI.-II SP (get) (gal)(gal (gap (01) lbs I 165 107 lbs I lbs 1211.2 934.1 1 1,050.8 525.4 1 4,200.0 1 36,337.4 181.7 1 2,422.5 302.8 1 41.6 Lo- OD M0-61 CL -22 UC CL,11 VT -2W WG -36 3E-6 0010. -III OptlFlo-II SP (gam) (gam (earn) (gam) pm) ppm ppm ppm ppm 2.1 1.7 1.9 1 0.9 2,100.0 63.0 0.3 4.2 0.5 1.1 0.2 0.2 0.2 0.1 210.0 5.3 0.0 0.4 0.1 0.1 Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 2018-1143 State: Alaska County; Harrison Be AN Number. 5010320777 NORTHSLOPE. Operator Name: EBUS Well Name and Number. KRU 31sG12 Longitude: 450.28 Latifutle: 70.43 Longllal Projection: IndianlFedam none production Type True Vertical Depth ITVD): 0 Total Water Volume( at': 1,211,246 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Neme Supplier Purpose Ingredients Service Concentration in Additive Concentration In Ingredient Mass Comments Company First Name. Last Name Email Phone Number ICAS I% by mass)`' HF Fluid (%by Ihs mass)- ass "Sea SeaWater Operator Base Fluid Water 7732.1&5 96.00% 16.88692- 9930247 Density -8.540 Halliburron Biodde Listed Below Listed Below 0 NA IC MICROBIOCIDE CL-22 UC HalliDurlon Cresslinker Listed Below Listed Below 0 NA CL -31 Halldmrlon Crosslinker Listed Below Listed Below 0 NA CROSBLINKER LOSUMC-67 JWD Halliburton Non-ionic Listed Below Listed Below 0 NA MO -67 HalliburWn Additive pH Coal Additive Listed Below L'nletl Below 0 NA OKIFL DEI-AYD DELAYED RELEASE Halliburton Breaker Listed Below Listed Below 0 NA BREAKER OPTIF-111 DELAY D DELAYEDRELIEASE Halliburton Breaker Listed Below Listed Below 0 NA BREAKER BREAKER SANDCOMMON WHITE -100 Haliburlon MESH, SSA -2. Proppant Listed Below Listed Below 0 NA 2500 LB BACK SP BREAKER Helllburlon Breaker Listed Below Listed Below 0 NA WG -36 GELLING Helllourton AGENT Gelling Agent Listed Bellow Listed Below 0 NA LVM1200 gemago Atltlitive Listed Below Listed Below 0 NA Xinmi Wanli Industry 20140 Werk Developmen Additive Listed Below Listed Below 0 NA t Co. Ltd Ingredients Listed Above 1,24 Tnmeth benzene 95-63-6 1.00% 0.000718 92 2-13. o -2 -nitro -1,3- roanediol 52-51-7 100.008 0.001418 182 Denise Tud, Halibuilon, 3000 Acrylate polymer Proprietary, 1.00% 0.000968 124 N. Sam Houston Denise.Tuck Halliburton Denise Tuck HaAiburton.rn 281-571-6226 Pkwy E., Houston, TX 77032,281- in 871-6226 Ammonium meetings 7727-540 100.00% 0.02111% 2727 OeniesTuck@ Seems salts Proprietary 60.008 0.05737% 7410 Halliburlon Denise Tuck Halliburton.a 281-871-6226 in Corontlum 1302-7-5 55.008 10.065944 1300056 Crystalline elks, giuntc 1480860-7 100.008 0.67494% 87171 Denise.Tuck@ Cured acrylic resin Proprietary 30.00% 0.00633% 818 Halliburton Denise Tuck H.Riburton.co 281-871-6226 in Ethanol 6417-5 60.00% 0.042341 5469 Gouges 9000-30-0 100.00% 0.281368 36339 Heavy aromalie patimleurn naphtha 64742-94-5 30. 008 0.02110%2735 H d ended Curitiba, Lill 100. DO% 0.224718 29022 MuWile 1302-93-8 45.00%1 8.362468 11080045 5.00*1 0.003538 456 Oxylaad phenolic resin Proprietary 30.00% 0.02824% 3647 Danise.Tuck® Hailibudon Denise Tuck Halllb oun.co 281-871-226 m alpha-(4 Poly1phon-omegaroq-, 12]]-B]-0 branchhenyl)l)-omega-hyd 08 etl 5.008 0353k 0.00353%56 4 Potass Potassium formate 59629-0 60.008 0.05]3]8 7410 PotassiumM1draude 1310-&3 5.008 0.002228 287 Potassium metabo ale 1370&94-9 60.006 0.02667% 3444 Sodium carboxymethyl cellulose 901 1.006 0.00096% 124 Sodium chloride 7647-14-5 4.008 3.20536% 413985 Sodium gly.ollet. 2836-32-0 1.008 0.000968 124 Sodium h tlrosde 1310-]3-2 30.00% 0.023078 2979 sodium persulfiste ]7]527-1 100.60% 0.00033% 42 Sodium sulfate 7]57-82-6 0.10% 0.000018 1 Water ]]32-18-5 100.00% 0.13224% 1]0]9 • Total Water Volume sources may include fresh water, produced water, anchor recycled water _ " Information is based on the maAmum Potential far concentration and thus the total may be over 100% Note: For Field Development Products (producls that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate ands incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note Met Federal Law protects "proprietary", "trade secret", and "confidential business information" and Me criteria for how this information is reported on an MSDS is sub act to 29 CFR 1910.1200(i) and Appendix D. SAFETY DATA SHEET RESUND13 aenauutua Date -Issued: 05-2015 SDS Ref. No: CFT Date -Revised: 4/10/17 Revision No:007 1. PRODUCT AND COMPANY IDENTIFICATION 1.1 Product Identifiers Product name Chemical Frac Tracer Product number 1000, 1100, 1200, 1300, 1400, 1500, 1600, 1700, 1900, 2000, 2100, 2200, 2300, 2400, 2500, 2800, 2900, 3000, 3700, 3900, 4000, 4800, 10100, 10125, 10175, 10200, 10225, 10250, 10275, 10300, 10325, 10350, 10375, 10400, 10425, 10450, 10475, 10500, 10525, 10550, 10575, 10600, 10625, 10650, 10675, 10700, 10725, 10750, 10775, 10800, 10825, 10850, 10875, 10900, 10925 Generic name CFT-1000, CFT-1100, CFT-1200, CFT-1300, CFT-1400, CFT-1500, CFT-1600, CFT-1700, CFT-1900, CFT-2000, CFT-2100, CFT-2200, CFT-2300, CFT-2400, CFT-2500, CFT-2800, CFT-2900, CFT-3000, CFT-3700, CFT-3900, CFT-4000, CFT-4800, CFT-10100, CFT-10125, CFT-10175, CFT-10200, CFT-10225, CFT-10250, CFT-10275, CFT-10300, CFT-10325, CFT-10350, CFT-10375, CFT-10400, CFT-10425, CFT-10450, CFT-10475, CFT-10500, CFT-10525, CFT-10550, CFT-10575, CFT-10600, CFT-10625, CFT-10650,. CFT-10675, CFT-10700, CFT-10725, CFT-10750, CPT -10775, CFT-10800, CFT-10825, CFT-10850, CFT-10875, CFT-10900, CFT-10925. 1.2 Relevant identified used of the substance or mixture and uses advised against Identified uses Diagnostic Uses advised against Not available 1.3 Details of the supplier of the safety data sheet Company ProTechnics Division of Core Laboratories 6510 W. Sam Houston Parkway N. Houston, Texas 77041 Telephone 713-328-2320 1.4 Emergency telephone number Emergency phone number 713-328-2320 Transportation emergency 1-800-535-5053 (inside US) 1-352-323-3500 collect (outside US) 2. HAZARDS IDENTIFICATION 2.1 Classification of the substance or mixture GHS classification in accordance with 29 CFR 1910 (OSHA HCS) Skin irritation (Category 2), H315 Eye irritation (Category 2), H319 Specific target organ toxicity — single exposure (Category 3), Respiratory system, H335 2.2 GHS Label elements, including precautionary statements Pictogram Signal word Warning Hazard statement(s) H315 Causes skin irritation. H319 Causes serious eye irritation. H335 May cause respiratory irritation. Precautionary statement(s) P261 Avoid breathing dust/ fume/ gas/ mist/ vapours/ spray. P264 Wash skin thoroughly after handling. P280 Wear protective gloves. P302+ P352 IF ON SKIN: Wash with plenty of soap and water. P304+ P340 IF INHALED: Remove affected person into fresh air and keep at rest in a position comfortable for breathing. P332+ P313 If skin irritation occurs: Get medical advice/ attention. 2.3 Hazards not otherwise classified (HNOC) or not covered by GHS - none 3. COMPOSITION / INFORMATION ON INGREDIENTS 3.1 Substances Substance/ mixture Mixture 4. FIRST AID MEASURES 4.1 Description of first aid measures General advice Consult a physician. Show this safety data sheet to the doctor in attendance. Move out of dangerous area. If inhaled Move person into fresh air. If cough or other symptoms develop, consult a physician. In case of skin contact Remove contaminated clothing including shoes and immediately wash affected area with plenty of soap and water. If irritation continues, consult a physician. Wash contaminated clothing and shoes before reuse. In case of eye contact Immediately flush eyes with plenty of water for two to three minutes. Remove any contact lenses and continue flushing for 15 minutes. If irritation continues, consult a physician. If swallowed Wash out mouth with water and keep at rest. Consult a physician. Inaredient 11 CAS/Exempt No Percent Hazardous Proprietary Ingredient supplied as 10% w/v Proprietary 10 No A ueous Solution Water 7732-I8-5 90 No 4. FIRST AID MEASURES 4.1 Description of first aid measures General advice Consult a physician. Show this safety data sheet to the doctor in attendance. Move out of dangerous area. If inhaled Move person into fresh air. If cough or other symptoms develop, consult a physician. In case of skin contact Remove contaminated clothing including shoes and immediately wash affected area with plenty of soap and water. If irritation continues, consult a physician. Wash contaminated clothing and shoes before reuse. In case of eye contact Immediately flush eyes with plenty of water for two to three minutes. Remove any contact lenses and continue flushing for 15 minutes. If irritation continues, consult a physician. If swallowed Wash out mouth with water and keep at rest. Consult a physician. 4.2 Most important symptoms and effects, both acute and delayed The most important known symptoms and effects are described in the labeling (see Section 2.2) and/or in Section 11. 4.3 Indication of any immediate medical attention and special treatment needed No data available. 5. FIRE FIGHTING MEASURES 5.1 Extinguishing media Suitable extinguishing media Use fire -extinguishing media appropriate for surrounding materials. 5.2 Special hazards arising from the substance or mixture Carbon oxides, halogenated hydrogen gas. 5.3 Advice for firefighters As in any fire, wear full protective clothing and equipment. 5.4 Further information No data available. 6. ACCIDENTAL RELEASE MEASURES 6.1 Personal precautions, protective equipment and emergency procedures Use personal protective equipment. Avoid breathing vapours or mist. Evacuate personnel to safe areas. 6.2 Environmental precautions Do not let product enter drains, if safe to do so. 6.3 Methods and materials for containment and cleanup Construct temporary dikes of dirt or any appropriate readily available material to prevent spreading of the material. Cover with appropriate absorbent and sweep or shovel into an appropriate container. 6.4 Reference to other sections For protective clothing, see Section 8. For disposal, see Section 13. 7. HANDLING AND STORAGE 7.1 Precautions for safe handling Avoid contact with skin and eyes. Avoid formation of aerosols. Provide adequate exhaust ventilation at places where aerosols are formed. For precautions, see Section 2.2. Handle and use in a manner consistent with good industrial/manufacturing techniques and practices. 7.2 Conditions for safe storage Keep container tightly closed in a dry, cool, and well -ventilated place. Do not store with, or close to, strong acids. 7.3 Specific end uses(s) Apart from the uses mentioned in Section 1.2, no other specific uses are stipulated. 8. EXPOSURE CONTROLS / PERSONAL PROTECTION 8.1 Control parameters Components with workplace control parameters No PELs, TLVs, or OELs for this product or its ingredients are listed in the current issue of ACGIH's Guide to Occupational Exposure Values, nor have they been determined by the manufacturer. 8.2 Exposure controls Appropriate engineering controls Handle in accordance with good industrial hygiene and safety practice. Wash hands before breaks and at the end of the workday. Personal protective equipment Eye/face protection Safety glasses with side -shields conforming to EN166. Use equipment for eye protection tested and approved under appropriate government standards such as NIOSH (US) or EN166 (EU). Skin protection Handle with chemical -resistant gloves. Gloves must be inspected prior to use. Use proper glove removal technique (without touching glove's outer surface) to avoid skin contact with this product. Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory practices. Wash and dry hands. Body protection Impervious clothing. The type of protective equipment must be selected according to the amount of dangerous substance at the specific workplace. Control of environmental exposure Do not let product enter drains. 9. PHYSICAL AND CHEMICAL PROPERTIES 9.1 Information on basic physical and chemical properties a) Appearance Form: aqueous liquid Color: translucent b) Odor Odorless C) Boiling point Approximately 100°C d) Freeze point 0°C C) Density 1.05 g/mL I) Flash point Not flammable g) pH Approximately 9 h) Evaporation factor Not determined i) Solubility Soluble in water D Vapor pressure Not determined k) Oxidizing properties Not determined I) Vapor density Not determined m) Viscosity Not determined 9.2 Other safety information No data available. 10. STABILITY AND REACTIVITY 10.1 Reactivity Strong acids. Oxidizing materials. 10.2 Chemical stability The product is stable under normal ambient conditions of temperature and pressure. 10.3 Possibility of hazardous reactions Will not polymerize. 10.4 Conditions to avoid Extreme cold. 10.5 Incompatible materials Strong acids. Oxidizing materials. 10.6 Hazardous decomposition products None. 11. TOXICOLOGICAL INFORMATION 11.1 Information on toxicological effects Acute toxicity— oral Based on available data the classification criteria are not met. Acute toxicity— dermal Based on available data the classification criteria are not met. Acute toxicity— inhalation Based on available data the classification criteria are not met. Skin corrosion/irritation Skin irritant 2— H315 Causes skin irritation. Serious eye damage/irritation Eye irritant 2 — H319 May cause severe eye irritation. Respiratory sensitization Based on available data the classification criteria are not met. Skin sensitization Based on available data the classification criteria are not met. Germ cell mutagenicity Genotoxicity — in vitro Based on available data the classification criteria are not met. Genotoxicity- in vivo Based on available data the classification criteria are not met. Carcinogenicity IARC: No component of this product present at levels greater than or equal to 0.1% is identified as probable, possible, or confirmed human carcinogen by IARC. ACGIH: No component of this product present at levels greater than or equal to 0.1% is identified as a carcinogen or potential carcinogen by ACGIH. NTP: No component of this product present at levels greater than or equal to 0.1% is identified as a known or anticipated carcinogen by NTP OSHA: No component of this product present at levels greater than or equal to 0.1% is identified as a carcinogen or potential carcinogen by OSHA. Reproductive toxicity Reproductive toxicity—fertility Based on available data the classification criteria are not met. Reproductive toxicity — development Based on available data the classification criteria are not met. Specific target organ toxicity—single exposure STOT SE 3 — H335 May cause respiratory irritation. Specific target organ toxicity—repeated exposure Based on available data the classification criteria are not met Aspiration hazard Not anticipated to present an aspiration hazard, based on chemical structure. Additional information RTECS: Not available. To the best of our knowledge, the chemical, physical, and toxicological properties have not been thoroughly investigated. 12. ECOLOGICAL INFORMATION 12.1 Toxicity No data available. 12.2 Persistence and degradability Presumed to be persistent. 12.3 Bioaccumulative potential No data available. 12.4 Mobility in soil No data available. 12.5 Results of PBT and vPvB assessment PBT/vPvB assessment are not available as chemical safety assessment not required/ not conducted. 12.6 Other adverse effects No data available. 13. DISPOSAL CONSIDERATIONS 13.1 Waste treatment methods Product Dispose of at a supervised appropriate waste disposal facility according to current applicable laws and regulations and product characteristics at time of disposal. Contaminated packaging Contaminated containers should be cleaned and disposed of in the same manner as the product in accordance with applicable regulations. 14. TRANSPORT INFORMATION DOT (US) Not dangerous goods. IMDG Not dangerous goods. IATA Not dangerous goods. 15. REGULATORY INFORMATION SARA 302 Components SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title 111, Section 302. SARA 313 Components SARA 313: This material does not contain any chemical components with known CAS numbers that exceed the threshold (De Minimis) reporting levels established by SARA Title III, Section 313. SARA 311/312 Hazards SAR 311/312: No chemicals in this material are subject to the reporting requirements of SARA Title III, Section 311/312. CERCLA (Comprehensive Response, Compensation, and Liability Act) Not Applicable. TSCA (Toxic Substance Control Act) The components of this product are in compliance with the chemical notification requirements of TSCA. German Water Endangerment Class WGK: I 16. OTHER INFORMATION HMIS Rating Health Hazard: Chronic Health Hazard: Flammability: Physical Hazard: NFPA Rating Health Hazard: Fire Hazard: Reactivity Hazard: MANUFACTURER DISCLAIMER: Information given herein is offered in good faith as accurate, but without guarantee. Conditions of use and suitability of the product for particular uses are beyond our control; all risks of use of the product are therefore assumed by the user. Nothing is intended as a recommendation for uses which infringe valid patents or as extending license under valid patents. Appropriate warnings and safe handling procedures should be provided to handlers and users. Prepared by: ProTechnics Environmental Compliance Department Date of revision: 4/10/17 Contact information: 713-328-2320 SAFETY DATA SHEET RSMBIR aPi4lnAmM Date -Issued: 05-2015 SDS Ref. No: OFT Date -Revised: 04/10/2017 Revision No:008 1. PRODUCT AND COMPANY IDENTIFICATION 1.1 Product Identifiers Product time Oil Frac Tracer Product number 15000, 15010, 15020, 15040, 15050, 15070, 15110, 15140, 15150, 15160, 15170, 15190, 15200, 15210, 15250, 15300, 15350, 15400, 15450, 15500, 15550, 15600, 15650, 15700, 15750, 15800, 15850, 15900, 15950, 16000, 16050, 16100, 16150, 16200, 16250, 16300, 16350, 16400, 16450, 16500, 16550, 16600, 16650, 16700, 16750, 16800, 16850, 16900, 16950, 17000, 17050, 17100, 17150 1.2 1.3 1.4 Generic name OFT -15000, OFT -15010, OFT -15020, OFT -15040, OFT -15050, OFT -15070, OFT -151 10, OFT -15140, OFT -15150, OFT -15160, OFT -15170, OFT -15190, OFT -15200, OFT -15210, OFT -15250, OFT -15300, OFT -15350, OFT -15400, OFT -15450, OFT -15500, OFT -15550, OFT -15600, OFT -15650, OFT -15700, OFT -15750, OFT -15800, OFT -15850, OFT -15900, OFT -15950, OFT -16000, OFT -16050, OFT -16100, OFT -16150, OFT -16200, OFT -16250, OFT -16300, OFT -16350, OFT -16400, OFT -16450, OFT -16500, OFT -16550, OFT -16600, OFT -16650, OFT -16700, OFT -16750, OFT -16800, OFT -16850, OFT -16900, OFT -16950, OFT -17000, OFT -17050, OFT -17100, OFT -17150 Relevant identified used of the substance or mixture and uses advised against Identified uses Diagnostic Uses advised against Not available Details of the supplier of the safety data sheet Company ProTechnics Division of Core Laboratories 6510 W. Sam Houston Parkway N. Houston, Texas 77041 Telephone 713-328-2320 Emergency telephone number Emergency phone number 713-328-2320 Transportation emergency 1-800-535-5053 (inside US) 1-352-323-3500 collect (outside US) 2. HAZARDS IDENTIFICATION 2.1 Classification of the substance or mixture CHS classification in accordance with 29 CFR 1910 (OSHA HCS) Flammable liquids (Category 4 - Combustible), H227 Skin irritation (Category 2), H315 Eye irritation (Category 2A), H319 Specific target organ toxicity— single exposure (Category 3), Respiratory system, H335 2.2 GHS Label elements, including precautionary statements Pictogram Signal word Warning Hazard statement(s) H227 Combustible liquid. H315 Causes skin irritation. H319 Causes serious eye irritation. H335 May cause respiratory irritation. Precautionary statement(s) P210 Keep away from heat/sparks/open flames/hot surfaces. No smoking. P261 Avoid breathing dust/ fume/ gas/ mist/ vapours/ spray. P264 Wash skin thoroughly after handling. P280 Wear protective gloves. P280 Wear eye protection/ face protection. P302+ P352 IF ON SKIN: Wash with plenty of soap and water. P304+ P340 IF INHALED: Remove affected person into fresh air and keep at rest in a position comfortable for breathing. P305+ P351+ P338 IF IN EYES: Rinse cautiously with water for several minutes. Remove contact lenses, if present and easy to do. Continue rinsing. P332+ P313 If skin irritation occurs: Get medical advice/ attention. P337+ P313 If eye irritation persists: Get medical advice/ attention. P362 Take off contaminated clothing and wash before reuse. P370+ P378 In case of fire: Use dry sand, dry chemical or alcohol -resistant foam for extinction. P403 +P233 Store in a well -ventilated place. Keep container tightly closed. P403 +P235 Store in a well -ventilated place. Keep cool. P501 Dispose of contents/ container to an approved waste disposal plant. 2.3 Hazards not otherwise classified (HNOC) or not covered by GHS - none 3. COMPOSITION / INFORMATION ON INGREDIENTS 3.1 Substances Substance/ mixture Mixture Intmedient Proprietary Ingredient CAS/Exempt , Proprietary 0-30 No r Proprietary Ingredient Proprietary 70-100 No 4. FIRST AID MEASURES 4.1 Description of first aid measures General advice Consult a physician. Show this safety data sheet to the doctor in attendance. Move out of dangerous area. If inhaled Move person into fresh air. If cough or other symptoms develop, consult a physician. In case of skin contact Remove contaminated clothing including shoes and immediately wash affected area with plenty of soap and water. If irritation continues, consult a physician. Wash contaminated clothing and shoes before reuse. In case of eye contact Immediately Flush eyes with plenty of water for two to three minutes. Remove any contact lenses and continue Flushing for 15 minutes. If irritation continues, consult a physician. If swallowed Do NOT induce vomiting. Wash out mouth with water and keep at rest. Consult a physician. 4.2 Most important symptoms and effects, both acute and delayed The most important known symptoms and effects are described in the labeling (see Section 2.2) and/or in Section 11. 4.3 Indication of any immediate medical attention and special treatment needed No data available. 5. FIRE FIGHTING MEASURES 5.1 Extinguishing media Suitable extinguishing media Use dry chemical, alcohol -resistant foam, water spray, or carbon dioxide. 5.2 Special hazards arising from the substance or mixture Carbon oxides, Halogenated hydrogen gas. 5.3 Advice for firefighters As in any fire, wear full protective clothing and equipment. 5.4 Further information Use water spray to cool unopened containers. 6. ACCIDENTAL RELEASE MEASURES 6.1 Personal precautions, protective equipment and emergency procedures Use personal protective equipment. Avoid breathing vapors, mist, or gas. Ensure adequate ventilation. Remove all sources of ignition. Evacuate personnel to safe areas. Beware of vapors accumulating to form explosive concentrations. Vapors can accumulate in low areas. 6.2 Environmental precautions Prevent further leakage or spillage if safe to do so. Do not let product enter drains. 6.3 Methods and materials for containment and cleanup Construct temporary dikes of dirt or any appropriate readily available material to prevent spreading of the material. Cover with absorbent and collect spillage with an electrically powered vacuum cleaner or by wet - brushing. Place in container for disposal according to local regulations. Keep in suitable, closed containers for disposal. 6.4 Reference to other sections For protective clothing, see Section 8. For disposal, see Section 13. 7. HANDLING AND STORAGE 7.1 Precautions for safe handling Avoid contact with skin and eyes. Avoid inhalation of vapors or mist. Keep away from sources of ignition. No smoking. Take measure to prevent the buildup of electrostatic charge. Provide adequate exhaust ventilation at places where aerosols are formed. For precautions, see Section 2.2. Handle and use in a manner consistent with good industrial/manufacturing techniques and practices. 7.2 Conditions for safe storage Keep container tightly closed in a dry, cool, and well -ventilated place. 7.3 Specific end uses(s) Apart from the uses mentioned in Section 1.2, no other specific uses are stipulated. S. EXPOSURE CONTROLS / PERSONAL PROTECTION 8.1 Control parameters Components with workplace control parameters No PELs, TLVs, or OELs for this product or its ingredients are listed in the current issue of ACGIH's Guide to Occupational Exposure Values nor have they been determined by the manufacturer. 8.2 Exposure controls Appropriate engineering controls Handle in accordance with good industrial hygiene and safety practice. Wash hands before breaks and at the end of the workday. Personal protective equipment Eye/face protection Safety glasses with side -shields conforming to EN 166. Use equipment for eye protection tested and approved under appropriate government standards such as NIOSH (US) or EN 166 (EU). Skin protection Handle with chemical -resistant nitrile gloves. Gloves must be inspected prior to use. Use proper glove removal technique (without touching glove's outer surface) to avoid skin contact with this product. Dispose of contaminated gloves after use in accordance with applicable laws and good laboratory practices. Wash and dry hands. Body protection Impervious clothing. The type of protective equipment must be selected according to the amount of dangerous substance at the specific workplace. Control of environmental exposure Prevent further leakage or spillage if safe to do so. Do not let product enter drains. 9. PHYSICAL AND CHEMICAL PROPERTIES 9.1 Information on basic physical and chemical properties a) Appearance Form: liquid Color: colorless b) Odor Mild. Resembling mothballs. C) Boilingpoint Approximately 175°C d) Freeze point Not determined. e) Density Not determined. f) Flash point Approximately 65°C — closed cup g) pH Not determined. h) Evaporation factor Not determined. i) Solubility Not soluble in water. j) Vapor pressure Not determined. k) Oxidizing properties Not determined. I) Vapor density Not determined. M) Viscosity Not determined. n) Auto -ignition temperature Not determined. o) Explosive properties Not determined. 9.2 Other safety information No data available. 10. STABILITY AND REACTIVITY 10.1 Reactivity No data available. 10.2 Chemical stability Stable under recommended storage conditions. 10.3 Possibility of hazardous reactions Will not polymerize. 10.4 Conditions to avoid Heat, flames, and sparks. 10.5 Incompatible materials Strong oxidizing agents. 10.6 Hazardous decomposition products Other decomposition products— No data available. In the event of a fire: see Section 5. 11. TOXICOLOGICAL INFORMATION 11.1 Information on toxicological effects Acute toxicity — oral Based on available data the classification criteria are not met Acute toxicity— dermal Based on available data the classification criteria are not met Acute toxicity— inhalation Based on available data the classification criteria are not met Skin corrosion/irritation Skin irritant 2 — H315 Causes skin irritation. Serious eye damage/irritation Eye irritant 2 — H319 May cause severe eye irritation Respiratory sensitization Based on available data the classification criteria are not met Skin sensitization Based on available data the classification criteria are not met. Germ cell mutagenicity Genotoxicity — in vitro Based on available data the classification criteria are not met. Genotoxicity- in vivo Based on available data the classification criteria are not met. Carcinogenicity IARC: No component of this product present at levels greater than or equal to 0.1 % is identified as probable, possible, or confirmed human carcinogen by IARC. ACGIH: No component of this product present at levels greater than or equal to 0.1% is identified as a carcinogen or potential carcinogen by ACGIH. NTP: No component of this product present at levels greater than or equal to 0.1% is identified as a known or anticipated carcinogen by NTP. OSHA: No component of this product present at levels greater than or equal to 0.1 %is identified as a carcinogen or potential carcinogen by OSHA. Reproductive toxicity Reproductive toxicity — fertility Based on available data the classification criteria are not met. Reproductive toxicity—development Based on available data the classification criteria are not met. Specific target organ toxicity—single exposure STOT SE 3 — H335 May cause respiratory irritation. Specific target organ toxicity— repeated exposure Based on available data the classification criteria are not met. Aspiration hazard Not anticipated to present an aspiration hazard, based on chemical structure. Additional information RTECS: Not available. Prolonged or repeated single exposure without adequate ventilation can cause: Nausea, headache, vomiting. To the best of our knowledge, the chemical, physical, and toxicological properties have not been thoroughly investigated. 12. ECOLOGICAL INFORMATION 12.1 Toxicity No data available. 12.2 Persistence and degradability Presumed to be persistent. 12.3 Bioaccumulative potential No data available. 12.4 Mobility in soil No data available. 12.5 Results of PBT and vPvB assessment PBT/vPvB assessment are not available as chemical safety assessment not required/ not conducted. 12.6 Other adverse effects No data available. 13. DISPOSAL CONSIDERATIONS 13.1 Waste treatment methods Product This combustible material may be burned in a chemical incinerator equipped with an afterburner and scrubber. Offer surplus and non -recyclable solutions to a licensed disposal company. Contact a licensed professional waste disposal service to dispose of this material. Contaminated packaging Dispose of as unused product. 14. TRANSPORT INFORMATION DOT (US) Not dangerous goods. IMDG Not dangerous goods. IATA Not dangerous goods. 15. REGULATORY INFORMATION SARA 302 Components SARA 302: No chemicals in this material are subject to the reporting requirements of SARA Title I11, Section 302. SARA 313 Components SARA 313: This material does not contain any chemical components with known CAS numbers that exceed the threshold (De Minimis) reporting levels established by SARA Title 111, Section 313. SARA 311/312 Hazards Fire hazard — Combustible. CERCLA (Comprehensive Response, Compensation, and Liability Act) Not Applicable. TSCA (Toxic Substance Control Act) The components of this product are in compliance with the chemical notification requirements of TSCA. German Water Endangerment Class WGK: 1 16. OTHER INFORMATION HMIS Rating Health Hazard: 2 Chronic Health Hazard: Flammability: 2 Physical Hazard: 0 NFPA Rating Health Hazard: 2 Fire Hazard: 2 Reactivity Hazard: 0 MANUFACTURER DISCLAIMER: Information given herein is offered in good faith as accurate, but without guarantee. Conditions of use and suitability of the product for particular uses are beyond our control; all risks of use of the product are therefore assumed by the user. Nothing is intended as a recommendation for uses which infringe valid patents or as extending license under valid patents. Appropriate warnings and safe handling procedures should be provided to handlers and users. Prepared by: ProTechnics Environmental Compliance Department Date of revision: 04/10/2017 Contact information: 713-328-2320 SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Davies, Stephen F (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Thursday, November 15, 2018 5:09 PM To: Davies, Stephen F (DOA) Cc: Boyer, David L (DOA) Subject: RE: [EXTERNAL]RE: KRU 3S-612 (PTD 218-111, Sundry 318-511) - Request Attachments: CPAI_3S-612_VISION_Resistivity_RM_LWD002.zip Steve, Please see the intermediate section logs attached. I made it a zip file as the original file was too large to send via email, please let me know if this works for you. Yes, we saw 280 bbls of 11 ppg cement to surface during the job. I apologize for not clarifying this in the cement assessment. Thank you, Hanna From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Thursday, November 15, 2018 4:19 PM To: Sylte, Hanna<Hanna.Svlte@conocophillips.com> Cc: Boyer, David L (DOA) <david.bover2@alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 3S-612 (PTD 218-111, Sundry 318-511) - Request Hanna, Did surface -casing cement reach the surface? CPAI's description in the "Casing & Cement Assessments" portion of Section 6 does not mention this. Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.daviesfla alaska.eov. From: Davies, Stephen F (DOA) Sent: Thursday, November 15, 2018 3:57 PM To: 'Sylte, Hanna' <Hanna.SVlte@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 3S-612 (PTD 218-111, Sundry 318-511) - Request Hanna, Could CPAI please provide gamma ray and resistivity data in .las format for the interval from the surface casing shoe to the intermediate casing shoe at 13,866'? Thanks for your help, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or Steve daviesidalaska.gov. From: Sylte, Hanna <Hanna Sylte@conocophillips.com> Sent: Thursday, November 15, 2018 1:29 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Cc: Boyer, David L (DOA) <david.boyer22alaska.gov> Subject: RE: [EXTERNAL]RE: KRU 35-612 (PTD 218-111, Sundry 318-511) - Request Steve, Please see frac sleeve depths below and survey and resistivity/gamma ray attached for 3S-612. We did not run density or neutron logs in this well. I will provide the same information for 35-611 in a separate email. Please let me know if you need any other information. 4S -Ft 7 Frar Port Denths Frac Sleeve # Ball Diam. (in) Depth [MD) Depth (TVD) 11 2.695 14357 5,238 10 2.645 14,872 5,281 9 2.595 15,388 5,280 8 2.545 15,867 5,284 7 2.495 16,345 5,281 6 2.455 16,897 5,277 5 2.415 17,376 5,274 4 2.375 17,853 5,264 3 2.335 18,389 5,251 2 2.295 18,865 5,240 1 2.255 19,339 5,229 Alpha Sleeve 1 1 19,751 1 5,221 Thank you, Hanna Sylte Completions Engineer ATO 1556 Office: (907) 265-6342 Mobile: (713) 449-2197 From: Davies, Stephen F (DOA) <steve.davies@alaska.eov> Sent: Thursday, November 15, 2018 12:29 PM To: Sylte, Hanna <Hanna Sylte@conocophillips.com> Cc: Boyer, David L (DOA) <david boyer2@alaska.e;ov> Subject: [EXTERNAL]RE: KRU 3S-612 (PTD 218-111, Sundry 318-511) - Request Hanna, The measured and true vertical depths for the perforations and/or slotted liner are not provided on CPAI's Sundry Application form or on the Final Wellbore Schematic drawing attached to it. Could CPAI please provide these depths? Thank you for your help. Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.daviesPalaska.gov. From: Davies, Stephen F (DOA) Sent: Thursday, November 15, 2018 12:13 PM To:'hanna.sylte@conocophillips.com' <hanna sylte r2conocophillips.com> Cc: Boyer, David L (DOA) <david.boyer2CcDalaska.gov> Subject: KRU 3S-612 (PTD 218-111, Sundry 318-511) - Request Hanna, I'm reviewing CPAI's Sundry Application to fracture stimulate KRU 3S-612. Could CPAI please provide the digital well log data and directional survey data recorded in this well? I only need gamma ray, resistivity, and porosity curve data. Field copies of the digital well log data are fine in .las or.dlis format. The directional data should be in Excel spreadsheet or ASCII table format. I only need measured depth, inclination and azimuth data. Quick turnaround would be appreciated as I will be out of the office next week and CPAI's specified date for commencing operations is December 2"d. Please note that providing these field -quality digital data does not relieve CPAI of the final reporting requirements specified in 20 AAC 25.071. Thank you for your help. Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Steve Davies at 907-793-1224 or steve.daviesfaalaska.pov. p770 35-6 17- ';? Za 16 - /11 Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Sunday, November 11, 2018 4:02 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re: KRU 3S-612 (PTD 218-111) Intermediate Cement Evaluation Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the quick response. Hope you have a good evening. Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Sunday, November 11, 2018 3:50 PM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL]Re: KRU 3S-612 (PTD 218-111) Intermediate Cement Evaluation Ben, Thanx for the log, interpretation and summary. It looks like a good cement job. Approval is granted to proceed as planned. Thanx, Victoria Sent from my Whone On Nov 11, 2018, at 3:29 PM, Tolman, Ben V <Ben V Tolman@conocophillips.com> wrote: Victoria, Good afternoon on this "winterish" Sunday. As per the 3S-612 PTD, included are the cement job and cement evaluation results of the 7-5/8" intermediate cement job. Following a similar format as our last submitted cement evaluation, attached are two files: • Cement Job Evaluation/Review and Cement Job Report. • Full cement evaluation log. The execution of the intermediate cement job went smoothly and as planned. The cement evaluation indicates TOC around 8,270' MD / 3,830' TVD with good to great coverage above the shoe and through the Coyote interval. See details of cement job in attached intermediate cement report. Please let me know if you have any follow-up questions. Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907) 265-6828 (o) 1 (307) 231-3550 (m) <3S-612 Intermediate Cement Review.pdf> <ConocoPhillips_3S-612_SonicScope_Top_of Cement600.pdf> COMPANY WELL: FIELD: STATE: COUNTRY: DateLogged: Surface Location Elevations: API Number: *Techlog Processed Interpretation C7�117C[7 ConocoPhillipsAlaska, Inc 3S-612 Kuparuk River Unit Alaska USA 10 November 2018 X 1616259.37 ft US ': 1 50-103-20777-00-00 •leze • * A Mark of Schlumberger Date Processed: 11 November Y. 5993656.03 ft US DF: 63.64 ft GL: 29.4 E o a 10 8 1�g Z E V s� � a is 03 yW2 (N G EP ,6� iTM �F- = 'N� Schlumberger SonicScope Top of Cement Evaluation e e 7-5/8" Intermediate Casing • Set at 13,858' MD / 5,128' TVD Cement Slurry: • 1,466 sks 15.8 ppg tail Job Comments: • Maintained proper cement mixing density • Returns throughout job • Reciprocated casing • Saw good lift pressure during displacement • Bumped Plug. Floats Held. Pressure tested 7-5/8' casing to 3,500 psi for 30 minutes Performed LOT to 16.2 ppg Cement Evaluation • SLB calling TOC at 8,270' MD. • Good cement coverage from shoe up to 12,350 MD. • 1516' MD / 544' TVD above shoe • Good to intermittent cement from 12,350 to 10,150' MD. • Good cement coverage from 10,150' — 8,270' MD. TOC @ 8,270' D C-35 8,747' MD / 3,941 Coyote 9,447' MD / 4,09 Base Coyote / Toro 10,039' MD / 4,23 Conoc4hillips Cement Detail Report 3S-612 String: Intermediate Casing Cement Job: Cement Details DescriptionCememing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 1114/2018 13:15 11/4/2018 1700 3&612 Comment CEMENTAS PER DETAIL Pump 5 bola water. Test lines to 4000 psi. Drop bottom plug. Batch & pump 75 bbls of 12.5 ppg MudPush II, @ 3 bpm, W/ ICP=450 FCP=220 W/ 8% FO. Drop intermediate plug. Batch & pump 303 bbis 15.8 ppg Class G cement @ 5 BPM ICP=305 FCP=215 psi, w/15% FO. Drop top plug. Pump 10 bbis water. Swap to ng and displace with 9.5 ppg treated LSND @ 7 bpm ICP=121 psi, FCP= 676 psi. Land casing @ 3650 STKS VV/67K hooklmd. Reduce rate V6 bpm @ 5075 stks, w/ 1100 psi, F/0=16% Reduce Rate T/ 3 bpm, @ 6700 STKS,ICP= 955 FCP=1071 8% F/O. Bump plug 6166 STKS. Pressure up to 1500 psi, hold 5 Mins, verify floats. CIP at 1705 hrs. Cement Stages Stage # <Stage Number7> Description Objective Top Depth (1`111(9) Bottom Depth (ftKB) Full Return? Vol Cement... Tap Plug? Btm Plug? Intermediate Casing 6,811.0 13,866.0 Yes 0.0 Ves Yes Cement Q Pump Init (bblim... Q Pump Final (bbg... Q Pump Avg (boll...P Pump Final (psi) P Plug Bump (psi) Recip7 Stroke (ft) Rotawoe Pipe RPM (rpm) 4 5 5 1,070.0 1,500.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ttKB) Drfll Out Diameter (in) Comment CEMENTAS PER DETAIL Pump 5 bbis water. Test lines to 4000 psi. Drop bottom plug. Batch & pump 75 bbis of 12.5 ppg MudPush it, @ 3 bpm, W/ ICP=450 FCP=220 W/ 8% FO. Drop intermediate plug. Batch & pump 303 bbis 15.8 ppg Class G Cement @ 5 BPM ICP=305 FCP=215 psi, w/15% FO. Drop top plug. Pump 10 bbis water. Swap to ng and displace with 9.5 ppg treated LSND @ 7 bpm ICP=121psi, FCP= 676 psi. Land casing @ 3650 STKS W/67K hookload. Reduce rate V6 bpm @ 5075 siks, w/ 1100 psi, F/0=16% Reduce Rate T/ 3 bpm, @ 6700 STKS,ICP= 955 FCP=1071 8% F/O. Bump plug 6166 STKS. Pressure up to 1500 psi, hold 5 Mins, verify floats. CIP at 1705 his. Cement Fluids & Additives Fluid Fluid TypeFluid Description Estimated Top (ftK8) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (obit Mud Pud II 5,410.0 6,811.0 75.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water I%) Density (lblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprSV 1 (pal) 12.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Flultl Description Estimated Top (ttKB) Est Btm (ftK8) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 6,611.0 13,877.0 1,466 G 303.0 Yield (f -/sack) Mix H2O Ratio (gallsa... Free Water (°/.) Density gDlgal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.07 15.80 110.3 7.50 Additives Additive Typa Concentration Conc Unit label Page 111 Report Printed: 1111112018 THE STATE °fALASKA GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S-612 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-111 Surface Location: 2510' FNL, 1032' FEL, SEC. 18, T12N, R08E, UM Bottomhole Location: 511' FNL, 1867' FEL, SEC. 2, T12N, R07E, UM Dear Mr. Alvord: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, % Cathy � FOerster Commissioner DATED this day of September 2018. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL nn n nr oa nnc R"'GO ` a SEN f 4 2018 1a. Type of Work: 1b. Proposed Well Class: Exploratory -Gas ❑GvService- WAG ❑v Service - Disp ❑ 1c. Specify if well is proposed for: ❑ Drill D. Lateral ❑ I Stratigraphic Test ❑ Development -Oil ❑+ • Service - Winj ❑ Single Zone ❑' Coalbed Gas ❑ Gas Hydrates Redrill ❑ Reentry[:11 Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑' Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 KRU 3S-612 - 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 19884 TVD: 5214 Kupamk River Field Torok Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2510' FNL, 1032' FEL, Sec 18, T 12N, R 08E, UM ' ADL380107: ADL025544, ADL025528 8. DNR Approval Number: 13. Approximate Spud Date: Top of Productive Horizon: 1065' FNL, 466' FEL, Sec 11, T 12N, R 07E, UM 932060000 931869000,931866000 10/16/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 511 FNL, 1867' FEL, Sec 2, T 12N, R 07E, UM 2447, 2560, 2560 511' to ADL355038 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 63.5 15. Distance to Nearest Well Open Surface: x- 476227.35 y- 69689905G2-- Zone -4 GL / BF Elevation above MSL (ft): 24.5 to Same Pool: 1173'to 3S-613 . 6ycickoff depth: 350 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.35) tDeviated ylgy3,& y r Maximum Hole Angle: 90.56 degrees Downhole: 2,150 psi Surface: 1,641 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole F Casing Weight I Grade I Coupling Length MID TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 80 Surface Surface 119 119 Installed 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 2967 Surface Surface 3006 2565 1192 sx 11.0 Lead, 191 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 13827 Surface Surface 13866 5104 1398 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6018 13866 5104 19884 5214 N/A: Un -cemented liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑' No ❑ 20. Attachments: Property Plat❑ BOP Sketch ❑' Drilling Program ❑' Time v. Depth Plot El Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program ❑' 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be 4•f'. deviated from without prior written approval. Contact Name: Ben Tolman Authorized Name: G. Alvord Contact Email: ben v tolman@_ggp.com Authorized Title: Alaska/Drilling Manager Phone: 907-265-6828 rContact Date: -`/3 tut 'fJ Authorized Signature: -4-� Commission Use Only Permit to Drill API Number: Permit Approval ,r See cover letter for other Number: A - 50- - O -OO - d Date://� requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Other: Samples req'd: Yes ❑ t'✓NoMud log req'd: Yes[-]NoR' �DFj %-<<5 f 3.r00�Sr L ter'5 / ZSU�easures: Yes ' No❑ Directional svy req'd: Yes(�No❑ Q No[' Spacing ex tion req'd: Yes ElNo[91 Inclination -only svy req'd: Yes[] 5� e a l I aCh a C_7! Post initial injection MIT req'd: Yes F;3/ No❑ G'o7 clitl'onS of Tipprova-I -Af) rv+) LWD-sem+ G - APPROVED BY / Date: Approved by: COMMISSIONER THE COMMISSION �P � 'J � �p (9) suomn Form and Form 10.401 R ised 5/2017 This permit is valid f r n ijV°'l;, t a f royal par 20 AAC 25.005 'Attachments in Duplicate KRU 3S-612(PTD 218-111) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well KRU 3S-612 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the a -line log does. CPAI must start the log at a depth to insure the free pipe above the TOC is captured as well as the TOC. Starting the log below the actual TOC based on calculations predicting a different TOC will not be acceptable. 3. CPAI will provide a cement job summary report and evaluation along with the cement log and evaluation to the AOGCC when they become available 4. CPA[ will provide the results of the FIT when available. 5. Depending on the cement job results indicated by the cement job report, the logs and the FIT, remedial measures or additional logging may be required. Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-6828 Email: ben.v.tolman(a)conocophillips.com September 11, 2018 Alaska Oil and Gas Conservation Commission 333 West 711 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Torok (Moraine) Injector, 3S-612 Application for Permit to Drill, Well 35-612 Saved: 11 -Sep -18 ConocoPhillips Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore pre -produced injector, a single - lateral horizontal well in the Torok (Moraine) formation. The expected spud date for this well is October 16, 2018. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 day cycle in accordance with COP and AOGCC policy. The intermediate hole section will drill a 9- 7/8" hole with 7-5/8" casing run to total depth & cemented in place. The production lateral will drill a 6-3/4" production hole that will be geo-steered in the Torok (Moraine) formation and lined with 4-1/2" liner with swell packers and frac sleeves. The upper completions will be run with 4-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Ben Tolman at 907-265-6828 (ben.v.tolman (a),cop.com) or Chip Alvord at 907-265-6120. Sincerely, Chip Alvor/4 Drilling Manager Application for Permit to Drill Document Torok (Moraine) Well 3S-612 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 3S-612 Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accomparted by each of the folio nig items. except Joran item already on file with the commission and identified in the application: (2) a plat identifying the p, opera, and the properg,'s owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objectire fmvtation, and a1 total depth, referenced to gorermnental section lines. (B) the coo,dinaes of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Surrey in the National Oceanic and Annoepheric Administration: (C) the proposed depth of the well at the top of each objectire fornwtion and at total depth: Location at Surface 2510' FNL, 1032' FEL, Sec 18, T 1.2N, R 08E, UM NGSCoordinares Northings: 5993905.62' Eastings: 476227.35' RKB Elevation 63.5' AMSL ' Pad Elevation 24.5' AMSL Location at Surface asing 1 1806 FNL, 2034' FEL, Sec 18, T12N, R08E UM NGS Coordinates Northings: 5994612.2' Eastings: 475224.97' Measured Depth,' RKB: 3 006' Total Vertical Depth, RKB: 2,565' Total Vertical Depth, SS: 2,502' Location at Intermediate Casing 1065' FNL, 466' FEL, Sec 11, T12N, R07E, UM NGS Coordinates Northings: 6000665.7' Eastings: 466733.06' Measured Depth, RKB: 13,866' Total Vertical De th, RKB: 1 5,104' Total Vertical Depth, SS: 1 5,040' Location at Total De th 511' FNL, 1867' FEL Sec 2 T12N, R07E, UM NGS Coordinates Northings: 6006505.73' Eastings: 465354.23' Measured De th, RKB: 19,884' Total Vertical De th, RKB: 5,214' Total Vertical Depth, SS: 5,150' and (0) other information ierluired by 10 AAC 25.050(6): Requirements of 20 AAC 25.050(b) /f a well is to be intentionally derided. Ore application fa' a Permit to Drill (Form 10-401) local (1) include a plat. drorn to a suitable scale, shoring the path of the proposed wellbore, including all adjacent a ellba'es within 200 feet of any portion of the proposed well, Please see Attachment: Directional Plan And (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operata's of Jose wells, to the extent that those naves are known or discoverable in public records. and shoe that each named operator has been fin'nished a copy of the application by cert fed nuril; or (B) state that the applicant is the only alleeled owner. . The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) Arc application for a Permit m Drill most be accorupanted by each of the following rooms. except for an item oh'eaelp on file wish the commission and identified in lite application: (3) a diagram and description of the blowout prevention equipment (BOPE) as'requo ed by 20 AAC 25.035, 20.4AC 25.036. or 20 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information �(�' 14,Requirements of 20 AAC 25.005 (c)(4) /j� An application for a Permit to Drill must be accompanied by each of Ore following items, except far an item already onfile it ah the commission and identified in the application: ` /� (4) information on drilling hazards, including 0 (A) the maxion nt downhole pressure that nay be encountered, crion to used�Vetermme it, and maximum potential surface pressure based on a methane gradient; The maximum potential surface pressure (MPSP) while drilling 3S-612 is calculated using an estimated maximum reservoir pressure of 2,150 psi (estimate from reservoir simulator based on offset well injection/pressure data), a gas gradient of 0.10 psi/ft, and the estimated formation depth: Moraine Sand Estimated BHP = 2,150 psi akt- • g_I H'•✓ Moraine Sand estimated depth = 5,104' TVD 40e'ar1 Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 511 psi (5,104' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,641 psi (2,150 psi — 524 psi) (8) data on potential gas cones; The wellbore is not expected to penetrate any shallow gas zones. - And (C) data concerning potemial causes ofhole problems such as abnonially geopressured strata. lost circulation zones. and cones that have a propensity for differential sticldng: See attached Drilling Hazards Summary _Requirements of 20 AAC 25.005 (c)(5) An application far a Permit to Drill must be accompanied by each of the following items. escep foran item already onT le with the commission and identified in the application: (5) a description of lite procedure for conducting formation mlegrtp, tests. as required under 20 AAC 25.030 f: A procedure is on file with the commission for performing FIT's/LOT's. As per previous discussion with the AOGCC, the intermediate casing will be purposely set in Torok Shale formation (above targeted sand). A formation test will be performed outside the intermediate casing shoe to determine strength of overburden. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application jor a Pei ndt-m Drill mist be accompmtied by each of the follomtrag items, except for an item aheady on file with the conuulssion and identified in the application: (6) a complete proposed casing and cementingprogram as required by 20 AAC 25.030. and a description ofany slotted liner, pre -perforated hner. a,- screen rscreen to be installed Casing and Cement Program 10-3/4" Surface casing run to 3,006' MD / 2,565' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a leads slurry with 11.0 ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. Lead slurry from 2,506' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119' —0') x 1.364 ft3/ft x 1.0 (0%excess) = 162 ft3 Bottom of Permafrost to Conductor (1,614'— 119') x 0.3637 ft3/ft x 2.50 (150%excess) = 1,359 ft3 Casing and Cementing Program (2,506' — 1,614') x 0.3637 ft3/ft x 1.50 (50% excess) = 487 ft3 Total Volume = 162 + 1,631 + 487 = 2,008 11:3 => 1192 sx of 11.0 ppg LiteCRETE @ 1.91 ft3 /sit Hole Casing Weight Grade Coupling Length MD Top TVD Bottom MD Bottomh TVD Cement Details 42" 20" 94# H-40 Welded 80 Surface Surface 119 119 Installed 13-12" 10-3/4" 45.54 L-80 Hyd 563 2,967 Surface Surface 3,006 2,565 1192 sx 11.0 Lead, 191 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 13,827 Surface Surface 13,866 5,104 1398 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6,018 13,866 5,104 19,884 5,214 N/A: Un -cemented liner 10-3/4" Surface casing run to 3,006' MD / 2,565' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a leads slurry with 11.0 ppg LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. Lead slurry from 2,506' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119' —0') x 1.364 ft3/ft x 1.0 (0%excess) = 162 ft3 Bottom of Permafrost to Conductor (1,614'— 119') x 0.3637 ft3/ft x 2.50 (150%excess) = 1,359 ft3 Bottom of Lead to Permafrost (2,506' — 1,614') x 0.3637 ft3/ft x 1.50 (50% excess) = 487 ft3 Total Volume = 162 + 1,631 + 487 = 2,008 11:3 => 1192 sx of 11.0 ppg LiteCRETE @ 1.91 ft3 /sit Tail slurry from 3,006' MD to 2,506 MD with DeepCREET @ 12 ppg Shoe to Top of Tail (3,006'— 2,506') x 0.3637 ft'/ft x 1.50 (50% excess) = 273 ft3 Shoe Joint (80') x 0.5400 ft3/ft x 1.0 (0% excess) = 43 ft3 Total Volume = 273 + 43 = 316 113 => 191 sx of 12.0 ppg DeepCRETE @ 1.65 ft3/sk 7-5/8" Production casing run to 13,866' MD / 5,104' TVD Single stage slurry is designed to be placed from TD to 8,348' MD which is 250' TVD above top of K3 (Coyote / Nanushuk); 35% excess annular volume. Slurry from 13,866' MD to 8,348' MD with 15.8 ppg Class G + additives Shoe to Top of Cement (13,866' — 8,348') X 0.2148 ft3/ft X 1.35 (35% excess) = 1600 ft3 Shoe Joint (80') X 0.258 ft3/ft X 1.0 (0% excess) = 21 ft3 Total Volume = 1600 + 21 = 1621 ft3 => 1398 sx of 15.8 ppg Class G @ 1.16 ft3/sk Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applawron fora Pennn to Drill i n it be accon+panied b)• each ofibe Jollmving items. exceptfman hent ab'eadt on file with the commission and idem fed in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25035, unless this requirement is waived by the commission under 20 AAC25035(h)(2),' Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill nmsl be accompanied by each of the following items. ercepi for an item ab-eady on file with the commission and idenulaid in the application: (B) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25033, Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Mud System Spud WBK LSND (WBM) Kla-Shield (WBM) Density 8.8-9.5 9.0-9.4 9.0-10.0 S.\ PV ALAP ALAP ALAP YP 30-80 15-30 15-25 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 8-15 5 — 10 10 minute Gel 30-50 < 20 7— 15 API Filtrate NC <10 < 6 HTHP Fluid Loss at 150 F N/A N/A <10 H 9.0-10.0 9.0-10.0 9.5-10.5 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit io D'dt Hurst be accompanied br each of the follmring ileuis. except for an item ahradv on file with the commission and identified in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 13-1/2" hole to casing point as per directional plan. Survey/log with MWD/LWD (Gamma, Resistivity) and gyro (as required). 3. Run and cement 10-3/4", 45.5#, L80, Hyd-563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. Evacuate top 2 feet of cement from annulus for sealant job (post rig). 4. Remove diverter system, install and test wellhead, and install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 9-7/8" PDC bit and directional drilling assembly, with MWD/LWD (Gamma, Resistivity, PWD). RIH and clean out to 100' above shoe. Test surface casing to 3,000 psi for 30 minutes. 6. Drill out shoe track and 20' of new formation. Perform LOT/FIT (to a minimum of 11.5 ppg), record results. 7. Directionally drill to intermediate hole TD (setting pipe above Moraine formation). 8. BROOH to surface shoe, circulate well clean then POOH on elevators. 9. Laydown intermediate BHA. 10. Run 7-5/8", 29.7#, L80, Hyd-563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Top cement to be placed @ +/- 8,348' MD (250' TVD above K-3 / Coyote formation). 12. If plugs bump, pressure test casing to 3,500 psi for 30 minutes. 13. Install 7-5/8" packoff & test to 5000 psi. 14. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel to freeze protect. 15. PU 6-3/4" bit, and drilling assembly with MWD/LWD (Gamma, Resistivity, MicroScope, SonicScope, and PWD). (SonicScope for cement evaluation only) 16. RIH on DP to top of float equipment. Clean out any residual cement to top of float equipment. Log TOC with sonic LWD (log section of free pipe for base line and TOC). If not previously tested, test intermediate casing to 3,500 psi for 30 minutes. 17. Drill out shoe track and 20' of new formation. Perform FIT/LOT of overburden and intermediate casing shoe, recording results. 18. Directionally drill 6-3/4" hole geo-steering through the Moraine formation per directional plan. 19. Circulate 1 BU after TD and BROOH to 7-5/8" shoe. CBU to clean casing and POOH on elevators. 20. 21. 22. 23. 24. 25. 26. 27. 28. Lay down production BHA. PU and run 4-1/2", 12.6# liner with liner hanger/packer placed at -13,666' (200' overlap in the 7-5/8" casing). Set liner hanger & packer. swell packers, and frac sleeves. The top of liner will be PT liner top packer to 3,000 psi, chart results. Flow check well. POOH with liner running tools and lay down. Run 4-1/2" upper completions. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. RDMO. Please Note - This well will be frae'd. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application far a Permit to Drill unalc be accompanied by each of the folltiring items. ercepi for an item ahead), on file it rth the commission and identified in the application: (N) a general description of hmr the operant,plans to dispose of drilling na,d and cuttings and a statement of nhether the operator intends to Y equest auntunuation under 10 AAC 15.080 for an mmulm' disposal operation in the it Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Area of Review (AOR) Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary Attachment 1: AOR An Area of Review plot is shown below of the 3S-612 planned wellpath and offset wells. The included table identifies any of the offset wellbores within the V4 -mile review. Well Name Status 3S-612wp06 Quarter Mile View TOC DeterBmyined Reservoir Status Zonal Isolation Cement Operations Summary 1 ! ! Proposed 13,866' MD / planned: 8,348' MD / Sonic LWD Not Yet Drilled Column of cement to be over Well does not exist yet. 3SA 12wp06 ! I I I 250' TVD above pool top. _-—! T 34 0— Well has been Stage 1: 228 sx 15.8 ppg u Intermediate pipe cemented Class G. Active 10,958' MD / _ 6100' MD / Currently shut through reservoir section to Stage 2: 1210 sx 15.8 ppg ! ! y2 ! 5 3&- 5,152' TVD 3712' TVD Sonic LWD .16Doo .1,000 -12000 -10000 .5000 -6000 -4000 -2000 0 2000 Wesq yEastld (2000 uston) Well Name Status Top of Torok (MD TVD) TOC (�/T�) TOC DeterBmyined Reservoir Status Zonal Isolation Cement Operations Summary 3S-612 Proposed 13,866' MD / planned: 8,348' MD / Sonic LWD Not Yet Drilled Column of cement to be over Well does not exist yet. Injector 5,104' TVD 250' TVD above pool top. 3,847' TVD Well has been Stage 1: 228 sx 15.8 ppg injecting. Intermediate pipe cemented Class G. Active 10,958' MD / _ 6100' MD / Currently shut through reservoir section to Stage 2: 1210 sx 15.8 ppg 3S-613 Injector 5,152' TVD 3712' TVD Sonic LWD in for drilling of —4858' MD / 1440' TVD Class G. 3S-611 and 3S- above reservoir top. Full circ through both 612. stages. Bumped plugs. DRILL SITE 3S DRAWN BY: ALKET MICI SCALE 100 o so 100 lips (TITLE: DRILL SITE 3S (a, Inc. DRAWN BY: ALKET MIC( I DATE August 2118 REN 1 2D,6DDI 3S-612wp06 1.035 plan Summa `41 ----[Lo 3/4x13-11/JI__. m m N �I n �j"j',',. N 0 O 0 3750 7500 11250 15000 18750 Measured Depth Plan @ 63.50usft (Doyon142) Horizontal Departure m Measured Depth From Depth To Sury yrPlan Tool Ari 39.00 1400.00 35612 --(Plan: 356121 GVD-Glias +FJ -W Dleg 1400.00 2400.00 35612ep06 (Fum:3S6121 MWD !tal�ls t> ame 1400.00 3005" 95612xp06 (%an:3S612) MWOaIFR-AK-0AZSC 06 3005: 3S612) 3005.000.505.00 MWD 2565.00 3006.35 103'4x13-1/2 3005. 013865.00 3S-612ap06 (Ren: 35612) MWDAFR-AKCAZSC 5103.50 1386569 7-5/8 x 9-7/8 13865.0015365.00 3S-612epW(Plan: 3S612) 13865.0019883.46 3S-612ap06(Plan: 3S612) MWD MWD+IFR-AK-CAZSC 5213.50 19883.48 41/2x63/4 ® 1 Inc Ari TVD +N/ -S +FJ -W Dleg TFace VSec1 Target !tal�ls t> 0.00 0.00 1 E .t �s 0.00 0.00 , 0.00 0.00 Hold la 8853.91' 11 0.00 0.00 r p 0.00 0.00 •Tel T 0.00 0.00 ;ADO 4.50 305.00 U, 6.75 -9.65 V 305.00 11.42 4 1671.39 30.03 305.00 1617.00 179.22 -255.95 2.50 0.00 303.15 51786.91 30.03 305.00 GIyY 212.38 -303.31 0.00 0.00 359.24 •a,f 111 sn +, m 60.52 305.00 2565.00 703.51 -1004.72 EM MID 0.00 1189.99 tec MD Inc Ari TVD +N/ -S +FJ -W Dleg TFace VSec1 Target 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 Hold la 8853.91' 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 3 650.00 4.50 305.00 649.69 6.75 -9.65 1.50 305.00 11.42 4 1671.39 30.03 305.00 1617.00 179.22 -255.95 2.50 0.00 303.15 51786.91 30.03 305.00 1717.00 212.38 -303.31 0.00 0.00 359.24 6 3006.35 60.52 305.00 2565.00 703.51 -1004.72 2.50 0.00 1189.99 7 3026.35 60.52 305.00 2574.84 713.50 -1018.98 0.00 0.00 1206.89 8 3581.57 77.01 302.44 2775.28 999.22 -1448.27 3.00 -8.75 1704.10 812435.48 77.01 302.44 4765.93 5626.53 -8729.55 0.00 0.00 9972.40 1013865.69 77A0 346.53 5103.50 6729.92-9517.11 3.00 95.2111321.88 35612 Tot Heel OM718 PP 1114358.69 7/.00 346.53 5214.40 7197.07 -9629.02 0.00 0.0011747.94 1214792.03 90.00 346.53 5263.35 7614.88 -9729.10 3.00 0.0012128.99 1314810.76 90.56 346.53 526326 7633.10 -9733.46 3.00 0.0012145.61 1419883.48 90.56 346.53 5213.50 12566.02 -10915.12 0.00 0.0016644.66 35-612 T02 Toe 120717 PP i Q 1aD 16860 18370 1W70 - 19683 Magnetic Model & Date: BGGM2018 15 -Oct -18 North is 16.79° East of True North (Magnetic Declination) itic Dip & Field Strength: 80.880 57431 nT Annotation Lifhdogy Column KOP: Start 1.51100' DLS, WSOTF, for 300' CS DeLapp Start 2.51/100' DLS, 0' TF, far 1021.39' V Osara HOW for 115.51' 11Top¢UP'9nu Stad 2.51100' DLS, WTF, for 1219.45 Hold for 24' C tlgnu� Stan 31100 DLS, -8.75° TF, for 555.21' Hold la 8853.91' Top U9nu A Start 31100' DLS, 95.21"TF, for 1430.21' Hold for 493' Top WS Start 31100' DLS, 0° TF, for 433.33' Adjust TF to 0", for 18.73' Fold for 5072.72' Beat WS TD: 19883.48' MD, 5213.5' TVD C-80 C-50 x�6�-35 o W (Nanushuk) Base C yote (Nanushuk) sTelok (Moraine) Prepared by Checked by: ccepted by Approved by: CS DeLapp V Osara Jeff Ryan DE Name Northing (3500 usft/in) 3S-612wp06 Section View 2500- i Top Ugnu C Base Perm Top Ugnu B 10 3/4 x 13-1/2 Top Ugnu A 0° Top WS - 10O() Base, WS Top Coyote (Nanushu ) 3 p0� C-80 w C 50 Base Coo 55 2500 5000 7500 0 2500 5000 7500 10000 12500 Vertical Section at 319.020 15000 4 1/2 x 6-3/4 17500 Y e ausu) 0 o o ,^ C-35 v o_ - o ^� 7-5/8 x 9-7/8Top Torok (Moraine) n o 00 o 0 0)o0 o, 0 r, 0 0 y 0 r N 0 0 rn OCD) o m .. .,._.. T ^oo 00 0 ^ 0 o0 o CO ^o rn 0, 0 2500 5000 7500 10000 12500 Vertical Section at 319.020 15000 4 1/2 x 6-3/4 17500 3S-612wp06 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 19883 - 12500 g�2W_P_p6 1gp00 4 1/2 x 6-3/4 180p0 10000 17p00 16000 15000 '7500 1403°0 z 7-5/8 x 9-7/8 0 U) o 5000 - oo° o 0 rn° o0 °° o0 0 o00 10 3/4 x 13-1/2 2500 h° o0 a° 0 -15000 -12500 -10000 -7500 -5000 -2500 0 2500 West( -)/East(+) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-612 50103xxxxx00 Plan: 3S-612 Plan: 3S-612wp06 Standard Proposal Report 04 September, 2018 i ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kupamk 3S Pad Well: Plan: 3S-612 Wellbore: Plan: 3S-612 Design: 35-612wp06 ConocoPhillips Standard Proposal Report Local Coordinate Reference: Well Plan: 35-612 TVD Reference: Plan @ 63.50usft (Doyon142) MD Reference: Plan @ 63.50usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, NOM Slope Alaska, United States Plan: 3SS12 Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 3S Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 In Grid Convergence: -0.18 • Well Plan: 3SS12 Audit Notes: Well Position -N/-S 61.76 usft Northing: Latitude: Depth From (TVD) +E/ -W -227.92 usft Easting: Longitude: Position Uncertainty 39.00 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 24.50 usft WellborePlan: 3S-612Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) P) (nT) BGGM2018 10/15/2018 16.79 80.88 57,431 Design 3SS12Wp06 Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/S (usft) (usft) 39.00 0.00 Tie On Depth: +EI -W (usft) 0.00 39.00 Direction (`) 319.02 9142018 2:17:24PM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project Kupamk River Unit MD Reference: Site. Kuparuk 3S Pad North Reference: Well: Plan: 35612 Survey Calculation Method: Wellbore: Plan: 35612 GVD-GCSS Design: 3S612WP06 Depth Plan Survey Tool Program Date 914/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,400.00 35-612wp06 (Plan: 35612) GVD-GCSS Tum Depth Inclination Gyrodata gyro single shots 2 1,400.00 2,400.00 35-612wp06(Plan: 35612) MWD Rate TFO (usft) (°) MWD - Standard 3 1,400.00 3,005.00 3S612wp06 (Plan: 3S612) MWD+IFR-AK-CAZ-SC (°MOOusft) (^) Target 39.00 0.00 MWD+IFRAK CAZ SCC 4 3,005.00 4,505.00 3S612wp06(Plan: 35612) MWD 0.00 0.00 350.00 0.00 MWD - Standard 5 3,005.00 13,865.00 35-612Wp06(Plan: 35612) MWD+IFR-AK-CAZSC 0.00 0.00 650.00 4.50 MWD+IFR AK CAZ SCC 6 13,865.00 15,365.00 3S612Wp06(Plan: 3S612) MWD 0.00 305.00 1,671.39 30.03 MWD - Standard 7 13,865.00 19.883.48 3S.612wp06(Plan: 38612) MWD+IFR-AK-CAZ-SC 0.00 0.00 1,786.91 30.03 MWD+IFR AK CAZ SCC ConocoPhillips Standard Proposal Report Well Plan: 35-612 Plan @ 63.50usft (Doyonl42) Plan g 63.50ust (Doyonl42) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NIS +E/.W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (1100usft) (°MOOusft) (^) Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 650.00 4.50 305.00 649.69 6.75 -9.65 1.50 1.50 0.00 305.00 1,671.39 30.03 305.00 1,617.00 179.22 -255.95 2.50 2.50 0.00 0.00 1,786.91 30.03 305.00 1,717.00 212.38 -303.31 0.00 0.00 0.00 0.00 3,006.35 60.52 305.00 2,565.00 703.51 -1,004.72 2.50 2.50 0.00 0.00 3,026.35 60.52 305.00 2,574.84 713.50 -1,018.98 0.00 0.00 0.00 0.00 3,581.57 77.01 302.44 2,775.28 999.22 -1,448.27 3.00 2.97 -0.46 6.75 12,435.48 77.01 302.44 4,765.93 5,626.53 -8,729.55 0.00 0.00 0.00 0.00 13,865.69 77.00 346.53 5,103.50 6,729.92 9,517.11 3.00 0.00 3.08 95.213S612 TOt Heel 07Z 14,358.69 77.00 346.53 5,214.40 7,197.07 -9,629.02 0.00 0.00 0.00 0.00 14,792.03 90.00 346.53 5,263.35 7,614.88 -9,729.10 3.00 3.00 0.00 0.00 14,810.76 90.56 346.53 5,263.26 7,633.10 -9,733.46 3.00 3.00 0.00 0.00 19,883.48 90.56 346.53 5,213.50 12,566.02 -10,915.12 0.00 0.00 0.00 0.00 35612 T02 Toe 1207 9/42018 2:17:24PM Page 3 COMPASS 5000.14 Build 85 Planned Survey ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Coordinate Reference: Well Plan: 35-612 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan @ 63.50usft (Doyon142) Project: Kupamk River Unit MD Reference: Plan t8 63.50usft (Doyonl42) Site: Kuparuk 3S Pad North Reference: True Well: Plan: 35-612 Survey Calculation Method: Minimum Curvature Wellbore: Pian: 3S-612 Azimuth Depth Design: 35-612Wp06 +E/ -W Section Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +KIS +E/ -W Section Rate Rate Rate (usft) (') (•) (usft) (usft) (usft) (usft) ('/100usft) ('MOOusft) ('FlOOusft) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.DO 0.00 0.00 0.00 0.00 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°1100' DLS, 305° TF, for 300' 400.00 0.75 305.00 400.00 0.19 -0.27 0.32 1.50 1.50 0.00 500.00 2.25 305.00 499.96 1.69 -2.41 2.86 1.50 1.50 0.00 600.00 3.75 305.00 599.82 4.69 -6.70 7.93 1.50 1.50 0.00 650.00 4.50 305.00 649.69 6.75 -9.65 11.42 1.50 1.50 0.00 Start 2.6Y100' OLS, 0• TF, for 1021.39' 700.00 5.75 305.00 699.49 9.32 -13.30 15.76 2.50 2.50 0.00 800.00 8.25 305.00 798.74 16.31 -23.29 27.58 2.50 2.50 0.00 900.00 10.75 305.00 897.36 25.77 -36.81 43.59 2.50 2.50 0.00 1,000.00 13.25 305.00 995.17 37.70 -53.83 63.76 2.50 2.50 0.00 1,100.00 15.75 305.00 1,091.97 52.06 -74.34 88.05 2.50 2.50 0.00 1,200.00 18.25 305.00 1,187.60 68.82 -98.29 116.42 2.50 2.50 0.00 1,300.00 20.75 305.00 1,281.85 87.97 -125.63 148.80 2.50 2.50 0.00 1,400.00 23.25 305.00 1,374.56 109.45 -156.32 185.14 2.50 2.50 0.00 1,431.59 24.04 305.00 1,403.50 116.72 -166.69 197.43 2.50 2.50 0.00 Top Ugnu C 1,500.00 25.75 305.00 1,465.55 133.24 -190.28 225.37 2.50 2.50 0.00 1,600.00 28.25 305.00 1,554.65 159.28 -227.47 269.41 2.50 2.50 0.00 11610.06 28.50 305.00 1,563.60 162.02 -231.39 274.05 2.50 2.50 0.00 Base Penn 1,671.39 30.03 305.00 1,617.00 179.22 -255.95 303.15 2.50 2.50 0.00 Hold for 115.61' 1,678.90 30.03 305.00 1,623.50 181.37 -259.03 306.79 0.00 0.00 0.00 Top Ugnu B 1,700.00 30.03 305.00 1,641.76 187.43 -267.68 317.04 0.00 0.00 0.00 1,786.91 30.03 305.00 1,717.00 212.38 -303.31 359.24 0.00 0.00 0.00 Start 2.6'/100' DLS, 0• TF, for 1219.45' 1,800.00 30.36 305.00 1,728.32 216.16 -308.70 365.63 2.50 2.50 0.00 1,836.31 31.27 305.00 1,759.50 226.83 -323.94 383.67 2.50 2.50 0.00 Top Ugnu A 1,900.00 32.86 305.00 1,813.47 246.22 -351.64 416.48 2.50 2.50 0.00 2,000.00 35.36 305.00 1,896.26 278.38 -397.57 470.89 2.50 2.50 0.00 2,100.00 37.86 305.00 1,976.52 312.59 -446.42 528.74 2.50 2.50 0.00 2,138.22 38.82 305.00 2,006.50 326.19 465.84 551.75 2.50 2.50 0.00 Top WS 2,200.00 40.36 305.00 2,054.11 348.77 498.09 589.94 2.50 2.50 0.00 2,300.00 42.86 305.00 2,128.87 386.86 -552.49 654.37 2.50 2.50 0.00 2,400.00 45.36 305.00 2,200.66 426.78 -609.50 721.90 2.50 2.50 0.00 2,500.00 47.86 305.00 2,269.35 468.46 -669.03 792.40 2.50 2.50 0.00 2,600.00 50.36 305.00 2,334.80 511.82 -730.95 865.74 2.50 2.50 0.00 2,700.00 52.86 305.00 2,396.89 556.77 -795.15 941.78 2.50 2.50 0.00 2,751.46 54.15 305.00 2,427.50 580.50 -829.04 981.92 2.50 2.50 0.00 Base WS 2,800.00 55.36 305.00 2,455.51 603.24 -861.51 1,020.38 2.50 2.50 0.00 2,900.00 57.86 305ol) 2,510.53 651A3 -029.90 1,101.38 2.50 2.50 0.00 3,000.00 60.36 305.00 2,561.87 700.34 -1,000.20 1,184.63 2.50 2,50 0.00 3,006.35 60.52 305,00 2,565.00 703.51 -1,004.72 1,189.99 2.50 2.50 0.00 Hold for 20'. 10 314 x 13-1/2 9/42018 2:17:24PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMP2 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kupamk 3S Pad Plan: 35-612 Plan: 3S-612 35-612vry06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan: 35-612 Plan @ 63.50usft (Doyon142) Plan @ 63.50usft (Doyon142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI4 +E/ -W Section Rate Rate Rate (usR) � V) (°I (usR) (usR ) (uan) (usn) pnoousn) (°no6aaR) (°nooasR) 3,026.35 60.52 305.00 2,574.84 713.50 -1,018.98 1,206.89 0.00 0.00 0.00 Start 3°1100' DLS, 875° TF, for 565.21' 3,100.00 62.71 304.62 2,609.85 750.48 -1,072.18 1,269.69 3.00 2.97 -0.51 3,200.00 65.67 304.13 2,653.39 801.30 -1,146.47 1,356.78 3.00 2.97 -0.49 3,245.14 67.01 303.92 2,671.50 824.44 -1,180.74 1,396.71 3.00 2.97 -0.47 C80 3,300,00 0,64 303,66 2,692,21 852.69 -1,222,96 1,445.73 3,00 2.97 -0.46 3,400.00 71.61 303.21 2,726.20 904.51 -1,301.43 1,536.31 3.00 2.97 -0.45 3,500.00 74.58 302.78 2,755.27 956.61 -1,381.67 1,628.26 3.00 2.97 -0.43 3,581.57 77.01 302.44 2,775.28 999.22 -1,448.27 1,704.10 3.00 2.97 -0.42 Hold for 8853.91' 3,600.00 77.01 302.44 2,779.43 1,008.85 -1,463.43 1,721.32 0.00 0.00 0.00 3,700,00 77.01 302.44 2,801.91 1,061.11 -1,545.67 1,814.70 0.00 0.00 0.00 3,800.00 77.01 302.44 2,824.39 1,113.37 -1,627.91 1,908.09 0.00 0.00 0.00 3,900.00 77.01 302.44 2,846.88 1,165.64 -1,710.14 2,001.47 0.00 0.00 0.00 4,000.00 77.01 302.44 2,869.36 1,217.90 -1,792.38 2,094.86 0.00 0.00 0.00 4,100.00 77.01 302.44 2,891.84 1,270.16 -1,874.62 2,188.25 0.00 0.00 0.00 4,200.00 77.01 302,44 2,914.33 1,322.43 -1,956.86 2,281.63 0.00 0.00 0.00 4,300.00 77.01 302.44 2,936.81 1,374,69 -2,039.10 2,375.02 0.00 0.00 0.00 4,400.00 77.01 302.44 2,959.29 1,426.95 -2,121.33 2,468.40 0.00 0.00 0.00 4,500.00 77.01 302.44 2,981.78 1,479.22 -2,203.57 2,561.79 0.00 0.00 0.00 4,600.00 77.01 302.44 3,004.26 1,531.48 -2,285.81 2,655.18 0.00 0.00 0.00 4,700.00 77.01 302.44 3,026.74 1,583.74 -2,368.05 2,748.56 0.00 0.00 0.00 4,800.00 77,01 302.44 3,049.23 1,636.00 -2,450.29 2,841.95 0.00 0.00 0.00 4,900.00 77.01 302.44 3,071.71 1,688.27 -2,532.53 2,935.33 0.00 0.00 0.00 5,000.00 77.01 302.44 3,094.19 1,740.53 -2,614.76 3,028.72 0.00 0,00 0.00 51100.00 77.01 302.44 3,116.68 1,792.79 -2,697.00 3,122.10 0.00 0.00 0.00 5,200.00 77.01 302.44 3,139.16 1,845.06 -2,779.24 3,215.49 0.00 0.00 0.00 5,300.00 77.01 302.44 3,161.64 1,897.32 -2,861.48 3,308.88 0.00 0.00 0.00 5,400.00 77.01 302.44 3,184.13 1,949.58 -2,943.72 3,402.26 0.00 0.00 0.00 5,500.00 77.01 302.44 3,206.61 2,001.84 -3,025.95 3,495.65 0.00 0.00 0.00 5,600.00 77.01 302.44 3,229.09 2,054.11 -3,108.19 3,589.03 0.00 0.00 0.00 5,700.00 77.01 302.44 3,251.58 2,106.37 -3,190.43 3,682.42 0.00 0.00 0.00 5,800.00 77.01 302.44 3,274.06 2,158.63 -3,272.67 3,775.80 0.00 0.00 0.00 5,900.00 77.01 302.44 3,296.54 2,210.90 -3,354.91 3,869.19 0.00 0.00 0.00 61000,00 77.01 302.44 3,319.03 2,263.16 -3,437.14 3,962.58 0.00 0.00 0.00 6,086.62 77.01 302.44 3,338.50 2,308.43 -3,508.38 4,04387 0.00 0.00 0.00 C-50 6,100.00 77.01 302.44 3,341.51 2,315.42 -3,519.38 4,055.96 0.00 0.00 0.00 6,200.00 77.01 30284 3,363.99 2,367.68 -3,601.62 4,149.35 0.00 0.00 0.00 6,300.00 77.01 302.44 3,386.48 2,419.95 -3,683.86 4,242,73 0.00 0.00 0.00 6,400.00 77.01 302.44 3,408.98 2,472.21 -3,766.10 4,336.12 0.00 0.00 0.00 6.500.00 77.01 302.44 3,431.44 2,524.47 3,848.33 4,429.50 0.00 0.00 0.00 6,600.00 77.01 302.44 3,453.92 2,576.74 -3,930.57 4,522.89 0.00 0.00 0.00 6,700.00 77.01 302.44 3,476.41 2,629.00 4,012.81 4,616.28 0.00 0.00 0.00 6,800.00 77.01 302.44 3,498.89 2,681.26 4,095.05 4,709.66 0.00 0.00 0.00 6,900.00 77.01 302.44 3,521.37 2,733.53 4,177.29 4,80305 0.00 0.00 0.00 7,000.00 77.01 302.44 3,543.86 2,785.79 4,259.52 4,896.43 0.00 0.00 0.00 7,100.00 77.01 302.44 3,566.34 2,838.05 4,341.76 4,989.82 0.00 0.00 0.00 7,200.00 77.01 302.44 3,588.82 2,890.31 4,424.00 5,083.21 000 0.00 0.00 7,300.00 77.01 302.44 3,611.31 2,942.58 4,506.24 5,176.59 0.00 0.00 0.00 7,400.00 77.01 302.44 3,633.79 2,994.84 4,588.48 5,269.98 0.00 0.00 0.00 __ 7,500_00 77.01_ 302:44 3,656.27 3047.10 4,670.71_ 5,363.36__ 0.00 0.00 0.00 9/4/2018 2:17:24PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 35512 Company: ConocoPhillips (Alaska) Inc. -Kup2 TV0 Reference: Plan @ 63.50usft (Doyon142) Project: Kuparuk River Unit MD Reference: Plan @ 63.50usft (Doyon142) Site: Kuparuk 3S Pad North Reference: True Well: Plan: 35-612 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3&612 Azimuth Depth Design: 3S512wp06 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +NIS +Ef-W Section Rate Rate Rate (usft) (<) (•) (usft) (usft) (usft) (usft) ('1100usft) ('1100usft) ('1100usft) 7,600.00 77.01 302.44 3,678.76 3,099.37 4,752.95 5,456.75 0.00 0.00 0.00 7,700.00 77.01 302.44 3.701.24 3,151.63 4,835.19 5,550.13 0.00 0.00 0.00 7,800.00 77.01 302.44 3,723.72 3,203.89 4,917.43 5,643.52 0.00 0.00 0.00 7,900.00 77.01 302.44 3,746.21 3,256.15 4,999.67 5,736.91 0.00 0.00 0.00 8,000.00 77.01 302.44 3,768.69 3,308.42 -5,081.90 5,830.29 0.00 0.00 0.00 8,100.00 77.01 302.44 3,791.17 3,360.68 -5,164.14 5,923.68 0.00 0.00 0.00 8,200.00 77.01 302.44 3.813.66 3,412.94 -5,246.38 6,017.06 0.00 0.00 0.00 8,300.00 77.01 302.44 3,836.14 3,465.21 5,328.62 6,110.45 0.00 0.00 0.00 8,400.00 77.01 302.44 3,858.62 3,517.47 5,410.86 6,203.83 0.00 0.00 0.00 8,500.00 77.01 302.44 3,881.11 3,569.73 -5,493.09 6,297.22 0.00 0.00 0.00 8,600.00 77.01 302.44 3,903.59 3,621.99 -5,575.33 6,390.61 0.00 0.00 0.00 8,700.00 77.01 302.44 3,926.07 3,674.26 5,657.57 6,483.99 0.00 0.00 0.00 8,759.72 77.01 302.44 3,939.50 3,705.47 -5,706.68 6,539.76 0.00 0.00 0.00 C-35 81800.00 77.01 302.44 3,948.56 3,726.52 -5,739.81 6,577.38 0.00 0.00 0.00 8,900.00 77.01 302.44 3,971.04 3,778.78 -5,822.05 6,670.76 0.00 0.00 0.00 9,000.00 77.01 302.44 3,993.52 3,831.05 5,904.28 6,764.15 0.00 0.00 0.00 9,100.00 77.01 302.44 4,016.01 3,883.31 5,986.52 6,857.54 0.00 0.00 0.00 9,200.00 77.01 302.44 4,038.49 3,935.57 -6,068.76 6,950.92 0.00 0.00 0.00 9,300.00 77.01 302.44 4,060.97 3,987.84 -6,151.00 7,044.31 0.00 0.00 0.00 9,400.00 77.01 302.44 4,083.46 4,040.10 5,233.24 7,137.69 0.00 0.00 0.00 9,458.01 77.01 302.44 4,096.50 4,070.42 5,280.94 7,191.87 0.00 0.00 0.00 Top Coyote(Nanushuk) 9,500.00 77.01 302.44 4,105.94 4,092.36 -6,315.47 7,231.08 0.00 0.00 0.00 9,600.00 77.01 302.44 4,128.42 4,144.62 5,397.71 7,324.46 0.00 0.00 0.00 9,700.00 77.01 302.44 4,150.91 4,196.89 5,479.95 7,417.85 0.00 0.00 0.00 9,600.00 77.01 302.44 4,173.39 4,249.15 -6,562.19 7,511.24 0.00 0.00 0.00 9,900.00 77.01 302.44 4,195.87 4,301.41 -6,644.43 7,604.62 0.00 0.00 0.00 10,000.00 77.01 302.44 4,218.36 4,353.68 5,726.66 7,698.01 0.00 0.00 0.00 10,054.01 77.01 302.44 4,230.50 4,381.90 5,771.08 7,748.45 0.00 0.00 0.00 Base Coyote(Nanushuk) 10,100.00 77.01 302.44 4,240.84 4,405.94 -6,808.90 7,791.39 0.00 0.00 0.00 10,200.00 77.01 302.44 4,263.32 4,458.20 -6,891.14 7,884.78 0.00 0.00 0.00 10,300.00 77.01 302.44 4,285.81 4,510.46 -6,973.38 7,978.16 0.00 0.00 0.00 10,400.00 77.01 302.44 4,308.29 4,562.73 -7,055.62 8,071.55 0.00 0.00 0.00 10,500,00 77.01 302.44 4,330.77 4,614.99 -7,137.85 8,164.94 0.00 0.00 0.00 10,600.00 77.01 302.44 4,353.26 4,667.25 -7,220.09 8,258.32 0.00 0.00 0.00 10,700.00 77.01 302.44 4,375.74 4,719.52 -7,302.33 8,351.71 0.00 0.00 0.00 10,800.00 77.01 302.44 4,398.22 4,771.78 -7,384.57 8,445.09 0.00 0.00 0.00 10,900.00 77.01 302.44 4,420.71 4,824.04 -7,466.81 8,538.48 0.00 0.00 0.00 11,000.00 77.01 302.44 4,443.19 4,876.30 -7,549.04 8,631.87 0.00 0.00 0.00 11,100.00 77.01 302.44 4,465.67 4,928.57 -7,631.28 8,725.25 0.00 0.00 0.00 11,200.00 77.01 302.44 4,488.16 4,980.83 -7,713.52 8,818.64 0.00 0.00 0.00 11,300.00 77.01 302.44 4,510.64 5,033.09 -7,795.76 8,912.02 0.00 0.00 0.00 11,400.00 77.01 302.44 4,533.12 5,085.36 -7,878.00 9,005.41 0.00 0.00 0.00 11,500.00 77.01 302.44 4,555.61 5,137.62 -7,960.23 9,098.79 0.00 0.00 0.00 11,600.00 77.01 302.44 4,578.09 5,189.88 5,042.47 9,192.18 0.00 0.00 0.00 11,700.00 77.01 302.44 4,600.57 5,242.15 -8,124,71 9,285.57 0.00 0.00 0.00 11,800.00 77.01 302.44 4,623.06 5,294.41 -8,206.95 9,378.95 0.00 0.00 0.00 11,900.00 77.01 302.44 4,645.54 5,346.67 -8,289.19 9,472.34 0.00 0.00 0.00 12,000.00 77.01 302.44 4,668.02 5,398.93 -8,371.42 9,565.72 0.00 0.00 0.00 12,100.00 77.01 302.44 4,690.51 5,451.20 5,453.66 9,659.11 0.00 0.00 0.00 12,200.00 77.01 302.44 4,712.99 5,503.46 -8,535.90 9,752.49 0.00 0.00 0.00 914/2018 2:17:24PM Page 6 COMPASS 5000.14 Build 85 Planned Survey Measured ConocoPhillips ConocoPh i I I i ps Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 35-612 Company: ConocoPhillips(Alaska) Inc.-Kup2 TVD Reference: Plan @ 63.50usft(Doyon142) Project: Kuparuk River Unit MD Reference: Plan @ 63.50usft (Doyonl42) Site: Kuparuk 3S Pad North Reference: True Well: Plan: 35-612 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3S-612 (usft) (usft) Design: 3S612wp06 (usft) (°1100usft) Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N14 +EFIN Section Rale Rate Rate (usft) (') V) (usft) (usft) (usft) (usft) (°1100usft) ('1100usft) (,1100usft) 12,300.00 77.01 302.44 4,735.47 5,555.72 -8,618.14 9,845.88 0.00 0.00 0.00 12,400.00 77.01 302.44 4.757.96 5,607.99 -8,700.38 9,939.27 0.00 0.00 0.00 12,435.48 77.01 302.44 4,765.93 5,626.53 -8,729.55 9,972.40 0.00 0.00 0.00 Start 3°1100' DLS, 95.21° TF, for 1430.21' 12,500.00 76.84 304.42 4,780.53 5,661.15 -8,782.00 10,032.93 3.00 -0.26 3.07 12,600.00 76.61 307.49 4,803.50 5,718.28 -8.860.78 10,127.72 3.00 -0.23 3.07 12,700.00 76.41 310.57 4,826.83 5,779.50 -81936.31 10,223.48 3.00 -0.19 3.08 12,800.00 76.26 313.65 4,850.46 5,844.65 -9,008.39 10,319.93 3.00 -0.16 3.08 12,900.00 76.14 316.74 4,874.32 5,913.54 -9,076.82 10,416.81 3.00 -0.12 3.09 13,000.00 76.06 319.83 4,898.35 5,985.99 -9,141.40 10,513.86 3.00 -0.08 3.09 13,100.00 76.02 322.92 4,922.47 6,061.80 -9,201.98 10,610.81 3.00 -0.04 3.09 13,200.00 76.02 326.01 4,946.63 6,140.75 -9,258.37 10,707.40 3.00 0.00 3.09 13,300.00 76.06 329.10 4,970.76 6,222.64 -9,310.43 10,803.36 3.00 0.04 3.09 13,400.00 76.14 332.19 4,994.79 6,307.24 -9,358.01 10,898.43 3.00 0.08 3.09 13,500.00 76.25 335.28 5,018.66 6,394.31 -9,400.97 10,992.34 3.00 0.12 3.09 13,600.00 76.41 338.36 5,042.30 6,483.62 -9,439.22 11,084.85 3.00 0.15 3.08 13,700.00 76.60 341.44 5,065.64 6,574.93 -9,472.63 11,175.69 3.00 0.19 3.08 13,800.00 76.83 344.51 5,088.63 6,667.97 -9,501.12 11,264.62 3.00 0.23 3.07 13.865.69 77.00 346.53 5,103.50 6,729.92 -9,517.11 11,321.88 3.00 0.26 3.07 Hold for 493'- Top Torok (Moraine) -7518 x 9-718 13,900.00 77.00 346.53 5,111.22 6,762.43 -9,524.90 11,351.53 0.00 0.00 0.00 14,000.00 77.00 346.53 5,133.71 6,857.19 -9,547.60 11,437.95 0.00 0.00 0.00 14,100.00 77.00 346.53 5,156.21 6,951.95 -9,570.30 11,524.37 0.00 0.00 0.00 14,200.00 77.00 346.53 5,178.70 7,046.70 -9,593.00 11,610.79 0.00 0.00 0.00 14,300.00 77.00 346.53 5,201.20 7,141.46 -9,615.69 11,697.22 0.00 0.00 0.00 14,358.69 77.00 346.53 5,214.40 7,197.07 -9,629.02 11,747.94 0.00 0.00 0.00 Start 3.1100' DLS, 0° TF, for 433.33' 14,400.00 78.24 346.53 5,223.26 7,236.31 -9,638.42 11,783.72 3.00 3.00 0.00 14,500.00 81.24 346.53 5,241.07 7,331.99 -9,661.34 11,870.99 3.00 3.00 0.00 14,600.00 84.24 346.53 5,253.71 7,428.45 -9,684.44 11.958.96 3.00 3.00 0.00 14,700.00 87.24 346.53 5,261.13 7,525.42 -9,707.67 12,047.40 3.00 3.00 0.00 14,792.03 90.00 346.53 5,263.35 7,614.88 -9,729.10 12,128,99 3.00 3.00 0.00 Adjust TF to 0°, for 18.73' 14,800.00 90.24 346.53 5,263.33 7,622.63 -9,730.96 12,136.07 3.00 3.00 0.00 14,810.76 90.56 346.53 5,263.26 7,633.10 -9,733.46 12,145.61 3.00 3.00 0.00 Hold for 5072.72' 14,900.00 90.56 346.53 5,262.38 7,719.88 -9,754.25 12,224.76 0.00 0.00 0.00 15,000.00 90.56 346.53 5,261.40 7,817.12 -9,777.55 12,313.45 0.00 0.00 0.00 15,100.00 90.56 346.53 5,260.42 7,914.37 -9,800.84 12,402.14 0.00 0.00 0.00 15,200.00 90.56 346.53 5,259.44 8,011.61 -9,824.13 12,490.83 0.00 0.00 0.00 15,300.00 90.56 346.53 5,258.46 8,108.95 -9,847.43 12,579.52 0.00 0.00 0.00 15,400.00 90.56 346.53 5,257.48 8,206.10 -9,870.72 12,668.21 0.00 0.00 0.00 15,500.00 90.56 346.53 5,256.50 8,303.34 -9,894.02 12,756.90 0.00 0.00 0.00 15,600.00 90.56 346.53 5,255.52 8,400.59 -9,917.31 12,845.60 0.00 0.00 0.00 15,700.00 90.56 346.53 5,254.54 8,497.83 -9,940.61 12,934.29 0.00 0.00 0.00 15,800.00 90.56 346.53 5,253.56 8,595.07 -9,963.90 13,022.98 0.00 0.00 0.00 15,900.00 90.56 346.53 6,252.57 8,692.32 -9,987.19 13,111.67 0.00 0.00 0.00 16,000.00 90.56 346.53 5,251.59 8,789.56 -10,010.49 13,200.36 0.00 0.00 0.00 16,100.00 90.56 346.53 5,250.61 8,886.81 -10,033.78 13,289.05 0.00 0.00 0.00 16,200.00 90.56 346.53 5,249.63 8,984.05 -10,057.08 13,377.74 0.00 0.00 0.00 16,300.00 90.56 346.53 5,248.65 9,081.29 -10,080.37 13,466.43 0.00 0.00 0.00 16,400.00 90.56 346.53 5,247.67 9,176.54 -10,103.67 13,555.12 0.00 0.00 0.00 16,500.00 90.56 346.53 5,246.69 9,275.78 -10,126.96 13,643.81 0.00 0.00 0.00 16,600.00 90.56 346.53 5,245.71 9,373.03 -10,150.25 13,732.51 0.00 0.00 0.00 9142018 2:17:24PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: Concoolahlllips(Alaska) Inc.-Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site Kuparuk 3S Pad North Reference: Well: Plan: 3S-612 Survey Calculation Method: Wellbore: Plan: 3S-612 Dogleg Design: 3"12wp06 Depth ConocoPhillips Standard Proposal Report Well Plan: 3S-612 Plan rQ 63.50usft(Doyonl42) Plan @ 63.50usft(Doyon142) True Minimum Curvature Planned Survey Measured vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +RIS +EIAV Section Rate Rate Rate (usft) (1) (usft) (usft) (usft) (usft) (°1100usft) (°1100usft) (°1100usft) 16,700.00 90.56 346.53 5,244.73 9,470.27 -10,173.55 13,821.20 0.00 0.00 0.00 16,800.00 90.56 346.53 5,243.75 9,567.52 -10,196.84 13,909.89 0.00 0.00 0.00 16,900.00 90.56 346.53 5,242.77 9,664.76 -10,220.14 13,998.58 0.00 0.00 0.00 17,000.00 90.56 346.53 5,241.78 9,762.00 -10,243.43 14,087.27 0.00 0.00 0.00 17,100.00 90.56 346.53 5,240.80 9,859.25 -10,266.73 14,175.96 0.00 0.00 0.00 17,200.00 90.56 346.53 5,239.82 9,956.49 -10,290.02 14,264.65 0.00 0.00 0.00 17.300.00 90.56 346.53 5,238.84 10,053.74 -10,313.31 14,353.34 0.00 0.00 0.00 17,400.00 90.56 346.53 5,237.86 10,150.98 -10,336.61 14,442.03 0.00 0.00 0.00 17,500.00 90.56 346.53 5,236.68 10,248.22 -10,359.90 14,530.72 0.00 0.00 0.00 17,600.00 90.56 346.53 5,235.90 10,345.47 -10,383.20 14,619.42 0.00 0.00 0.00 17,700.00 90.56 346.53 5,234.92 10,442.71 A0,406.49 14,708.11 0.00 0.00 0.00 17,800.00 90.56 346.53 5,233.94 10,539.96 -10,429.79 14,796.80 0.00 0.00 0.00 17,900.00 90.56 346.53 5,232.96 10,637.20 -10,453.08 14,885.49 0.00 0.00 0.00 18,000.00 90.56 346.53 5,231.98 10,734.44 -10,476.37 14,974.18 0.00 0.00 0.00 18,100.00 90.56 346.53 5,230.99 10,831.69 -10,499.67 15,062.87 0.00 0.00 0.00 18,200.00 90.56 346.53 5,230.01 10,928.93 -10,522.96 15,151.56 0.00 0.00 0.00 18,300.00 90.56 346.53 5,229.03 11,026.18 -10,546.26 15,240.25 0.00 0.00 0.00 18,400.00 90.56 346.53 5,228.05 11,123.42 -10,569.55 15,328.94 0.00 0.00 0.00 18,500.00 90.56 346.53 5,227.07 11,220.66 -10,592.85 15,417.63 0.00 0.00 0.00 18,600.00 90.56 346.53 5,226.09 11,317.91 -10,616.14 15,506.33 0.00 0.00 0.00 18,700.00 90.56 346.53 5,225.11 11,415.15 -10,639.43 15,595.02 0.00 0.00 0.00 18,800.00 90.56 346.53 5,224.13 11,512.40 -10,662.73 15,683.71 0.00 0.00 0.00 18,900.00 90.56 346.53 5,223.15 11,609.64 -10,686.02 15,772.40 0.00 0.00 0.00 19.000.00 90.56 346.53 5,222.17 11,706.89 A0,709.32 15,861.09 0.00 0.00 0.00 19,100.00 90.56 346.53 5,221.19 11,804.13 -10,732.61 15,949.78 0.00 0.00 0.00 19,200.00 90.56 346.53 5,220.20 11,901.37 -10,755.91 16,038.47 0.00 0.00 0.00 19,300.00 90.56 346.53 5,219.22 11,998.62 -10,779.20 16,127.16 0.00 0.00 0.00 19,400.00 90.56 346.53 5,218.24 12,095.86 -10,802.49 16,215.85 0.00 0.00 0.00 19,500.00 90.56 346.53 5,217.26 12,193.11 -10,825.79 16,304.54 0.00 0.00 0.00 19,600.00 90.56 346.53 5,216.28 12,290.35 -10,849.08 16,393.24 0.00 0.00 0.00 19.700.00 90.56 346.53 5,215.30 12,387.59 -10,872.38 16,481.93 0.00 0.00 0.00 19,800.00 90.56 346.53 5,214.32 12,484.84 -10,895.67 16,570.62 0.00 0.00 0.00 19,883.48 90.56 346.63 5,213.50 . 12,566.02 -10,915.12 16,644.66 0.00 0.00 0.00 TD: 19883.48' MD, 6213.5' TVD .4 112 x 6-314 9/42018 2:17:24PM Page 8 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kupamk 3S Pad Well: Plan: 3S-012 Wellbore: Plan: 35512 Design: 35512wp06 Design Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD -Shape (1) C) (usft) 35-612 Geo Poly (H) 08: 0.00 0.00 5,103.50 - plan hits target center - Polygon Point 1 Point 2 Point 3 Point 4 3S-612 T01 Heel 072711 - plan hits target center - Circle (radius 100.00) 35-612 T02 Toe 120717 - plan hits target center - Circle (radius 100.00) 35-612 Geo Poly (T) 08: - plan hits target center - Polygon Point 1 Point 2 Point 3 Pomt 4 35512 North Lease Lim - plan hits target center - Polygon Point 1 Point 2 ConocoPhillips Standard Proposal Report Local Coordinate Reference: Well Plan: 35-612 TVD Reference. Plan ® 63.50usft (Doyon142) MD Reference: Plan @ 63.50usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature +N/ -S +E/ -W (usft) (usft) 6.729.92 -9,517.11 5,103.50 -107.21 -24.22 5,103.50 13.72 -54.78 5,103.50 38.04 41,45 5,103.50 -82.90 72.01 0.00 0.00 5.103.50 6,729.92 -9,517.11 0.00 0.00 5,213.50 12,566.02 -10,915.12 0.00 0.00 5,213.50 12,566.02 -10,915.12 5,213.50 -5.847.83 1,348.45 5,213.50 -0.93 -51.58 5,213.50 -0.61 47.04 5,213.50 5,823.67 1,446.82 0.00 0.00 5,213.50 12,566.02 -10,915.12 5,213.50 504.91 7,146.85 5,213.50 516.64 -3,413.07 Casing Points Measured VerOcal Cuing Hole Depth Depth Diameter Diameter (usft) (usft) Name Qn) (in) 3,006.35 2,565.00 10 3/4 x 13-1/2 10.750 13.500 13,865.69 5,103.50 7-518 x 9-718 7.625 9.875 19,883.48 5,213.50 4112x6-3/4 4.500 6.750 914/2018 2: 17 24P Page 9 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kupamk River Unit MD Reference: Site: Kuparuk 3S Pad North Reference: Well: Plan: 35612 Survey Calculation Method: Wellbore: Plan: 3S612 1,403.50 Design: 3S612wp06 1,610.06 ConocoPhillips Standard Proposal Report Well Plan: 35612 Plan @ 63.50usft (Doyon142) Plan @ 63.50usft (Doyon142) True Minimum Curvature Formations -- Measured vertical vertical Dip Depth Depth Depth Dip Direction (usft) (usft) Name Lhhology 1,431.59 1,403.50 Top Ugnu C 350.00 1,610.06 1,563.50 Base Penn KOP: Start 1.5°1100' DLS, 305° TF, for 300' 1,678.90 1,623.50 Top Ugnu B -9.65 1,836.31 1,759.50 Top UgnuA 179.22 2,138.22 2,006.50 Top WS 1,717.00 2,751.46 2,427.50 Base WS 3,006.35 3,245.14 2,671.50 C-80 Hold for 20' 6,086.62 3,338.50 C-50 -1,018.98 8,759.72 3,939.50 C-35 999.22 9,458.01 4,096.50 Top Coyote (Nanushuk) 4,765.93 10,054.01 4,230.50 Base Coyote (Nanushuk) 13,865.69 13,865.69 5,103.50 Top Tarok(Moraine) Hold for 493' Plan Annotations -- Measured vertical Local Coordinates Depth Depth +N/ -S +E/4N (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP: Start 1.5°1100' DLS, 305° TF, for 300' 650.00 649.69 6.75 -9.65 Start 2.5°/100' DLS, 0' TF, for 1021.39' 1,671.39 1,617.00 179.22 -255.95 Hold for 115.51' 1,786.91 1,717.00 212.38 303.31 Start 2.5°1100' DLS, 0° TF, for 1219.45' 3,006.35 2,565.00 703.51 -1,004.72 Hold for 20' 3,026.35 2,574.84 713.50 -1,018.98 Start 3.1100' DLS, 5.75° TF, for 555.21' 3,581.57 2,775.28 999.22 -1,448.27 Hold for 8853.91' 12,435.48 4,765.93 5,626.53 6,729.55 Start 3°/100' DLS, 95.21 ° TF, for 1430.21' 13,865.69 5,103.50 6,729.92 -9,517.11 Hold for 493' 14,358.69 5,214.40 7,197.07 -9,629.02 Start 3°1100' DLS, 0° TF, for 433.33' 14,792.03 5,263.35 7,614.88 -9,729.10 Adjust TF to 0°, for 18.73' 14,810.76 5,263.26 7,633.10 -9,733.46 Hold for 5072.72' 19,883.48 5,213.50 12,566.02 -10,915.12 TD: 19883.48' MD, 5213.5' TVD 9142018 2:17:24PM Page 10 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-612 Plan: 3S-612 50103xxxxx00 3S-612wp06 ConocoPhillips Clearance Summary Anticollision Report 04 September, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3S Pad - Plan: 3S-612 - Plan: 3S-612-3S-612wp06 Datum Height: Plan@ 63.50usft(Doyonl42) Scan Range: 0.00 to 19,883.48 usft. Measured Depth. Scan Radius is 2,184.45 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 3S-612 - 3S-612wpO6 7ray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3S Pad - Plan: 35812 - Plan: 35-612 .35-612wp06 Scan Range: 0.00 to 19,883.48 usft. Measured Depth. Scan Radius Is 2,184.45 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name - Design Kuparuk 3S Pad 35-03 - 35-03 - 3S-03 35-03 - 35-03 - 35-03 35-06-35-06.3S-06 35-06 - 35-06 - 35-06 3S-06 - 3S-D6A- 3S -06A 35-06 - 3S -06A- 3S -06A 3S-07 - 3S-07 - 35-07 35-07-35-07-35-07 35-08-3S-08-35-08 35-08 - 3S-08 - 3S-08 3S -08 -3S -08A -3S -08A 3S-08 - 3S -08A- 3S -08A 35 -08 -3S -08B -3S -08B 3S -08 -3S -08B -3S -08B 35-08 - 3S -08C - 3S -08C 35-08 - 3S -08C - 3S -OBC 35 -08 -3S -08C -3S -08C 3S-09 - 35-09 - 35-09 3S -09-3S-09-35-09 35-10 - 35-10 - 35-10 35-10 - 35-10 - 3S-10 35-14 - 35-14 - 35-14 35-14 - 3S-14 - 35-14 35-15 - 35-15 - 35-15 35-15 - 35-15 - 3S-15 35-16 - 3S-16 - 35-16 35-16 - 35-16 - 35-16 35-17 - 35-17 - 35-17 Measured Minimum @Measured Depth Distance Depth (usft) (usft) (usft) Conocophillips (Alaska) Inc. -Kup2 Kuparuk River Unit Ellipse @Measured Clearance Summary Based on Separa0on Warning Separation Depth Factor Minimum (usft) usft 502.02 621.55 381.16 429.84 381.16 429.84 179.01 179.92 118.47 118.97 118.47 118.97 502.02 621.55 381.16 429,84 361.16 429.84 170.28 169.29 111.81 111.60 111.81 111.60 500.00 625.00 375.00 425.00 375.00 425.00 20.515 Centre Distance 16.921 Clearance Factor 17.790 Centre Distance 16.142 Clearance Factor 17.790 Centre Distance 16.142 Clearance Factor Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk 57.13 282.11 23218 331.96 232.18 331.96 100.16 100.79 79.80 80.66 79.80 80.66 57.13 282.11 23218 331.96 232.18 331.96 98.94 96.08 75,74 75.03 75.74 75.03 50.00 275.00 225.00 325.00 225.00 325.00 82.727 Centre Distance 21.421 Clearance Factor 19.634 Centre Distance 14.334 Clearance Factor 19.634 Centre Distance 14.334 Clearance Factor Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk 232.18 331.96 42.20 208.29 333.06 79.80 80.66 80.21 79.80 80.68 232.18 331.96 42.20 208.29 333.06 75.74 75.03 79.21 76.10 75.03 225.00 325.00 35.80 200.00 325.00 19.634 Centre Distance 14.334 Clearance Factor 80.069 Clearance Factor 21.577 Centre Distance 14.290 Clearance Factor Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk 57.00 206.99 107.20 207,18 558.73 608.91 60.22 61.17 39.92 40.73 39.49 39.92 57.00 206.99 107.20 207.18 558.73 608.91 59.01 57.63 37.92 37.04 30.10 29.63 50.00 200.00 100.00 200.00 550.00 600.00 49.833 Centre Distance 17.284 Clearance Factor 19.964 Centre Distance 11.037 Clearance Factor 4.203 Centre Distance 3.879 Clearance Factor Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk 206.84 256.82 959.69 984.13 207.01 58.97 59.40 58.51 58.73 99.60 206.84 256.82 959.69 984.13 207.01 55.04 54.63 42.87 42.68 95.60 200.00 250.00 950.00 975.00 200.00 15.022 Centre Distance 12.462 Clearance Factor 3.741 Centre Distance 3.660 Clearance Factor 24.947 Centre Distance Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk COMPASS Page 2 of 6 04 September, 2018 - 14:78 GonocoPhillips Anticollision Report for Plan: 3S-612 - 3S-612wp06 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) @Measured Clearance Summary Based on Reference Design: Kuparuk 3S Pad - Plan: 3S-612 - Plan: 3S-612 - 3S-612wp0S Separation Depth Scan Range: 0.00 to 19,883.48 usft. Measured Depth. Max Ellipse Separation is Unlimited (usft) Scan Radius is 2,184.45 usft. Clearance Factor cutoff is Unlimited. 4328 Measured Minimum @Measured Clearance Factor Depth Distance Depth Site Name(usft) Centre Distance (usft) (usft) Comparison Well Name - Wellbore Name - Design 1.325 Clearance Factor Pass - Major Risk 118.72 4,042.79 176.74 4,042.79 3S-77 - 3S-17 - 3517 207.01 99.60 207.01 3SA7-3517A-3S-17A 4,042.79 176.74 4,042.79 35 -17 -3517A -3S -17A 57.23 119.93 57.23 3S-18 - 3518 - 3S-18 232.22 120.83 232.22 35-18 - 3518 - 3S-18 75.00 112.186 Centre Distance Pass - Major Risk 82.47 139.89 82.47 3S-19 - 3S-79 - 3519 232.46 140.76 232.46 3S-19 - 3S-19 - 3519 81.55 179.79 81.55 3S-21 - 3S-21 - 3521 281.43 187.03 281.43 3S-21 - 3S-21 - 3521 693.46 789.97 693.46 3S-22 - 3S-22 - 3522 719.75 190.22 719.75 3S-22 - 3522 - 3522 Pass - Major Risk 213.74 225.00 48.974 208.29 218.19 208.29 3S-23 - 3S-23 - 3523 283.28 218.68 283.28 3S-23 - 3S-23 - 3523 1,325.00 218.19 230.84 3S-23 - 3S -23A- 3S -23A230.84 280.83 218.65 280.83 3 S -23 -3S -23A -3S -23A 1,345.70 203.21 1,345.70 3S -26-3S-26-3526 Centre Distance Pass - Major Risk 14,47 400.00 1,345.70 203.21 1,345.70 3526 - PALM 1 - PALM 7 39.20 79.87 39.20 3S-613 - 35613 - 3S-613 399.10 21.49 399.10 35613 - 3S-613 - 3S-613 515.01 153.79 515.01 3S-620 - 35620 - 3S-620 1,182.51 163.88 1,182.57 35620 - 3S-620 - 3S-620 325.00 20.59 325.00 Plan: 35611 - Plan: 35-611 - 3S-611wP06 23.66 748.28 Plan: 3S-611 - Plan: 3S611 - 35-611wD06 748.28 ConocoPhilGps (Alaska) Inc. -Kup2 Kupatuk River Unit Ellipse @Measured Clearance Summary Based on Separation Warning Separation Depth Factor Minimum (usft) usft 4328 3,800.00 1.324 Clearance Factor pass. Major Risk 95,71 200.00 25.649 Centre Distance Pass - Major Risk 43.34 3,800.00 1.325 Clearance Factor Pass - Major Risk 118.72 50.00 98.969 Centre Distance Pass - Major Risk 116,99 225.00 31.499 Clearance Factor Pass - Major Risk 138.36 75.00 92.840 Centre Distance Pass - Major Risk 136.50 225.00 33.018 Clearance Factor Pass - Major Risk 178,18 75.00 112.186 Centre Distance Pass - Major Risk 175,58 275.00 33.209 Clearance Factor Pass - Major Risk 178.71 675.00 16.871 Centre Distance Pass - Major Risk 178.53 700.00 16.277 Clearance Factor Pass- Major Risk 214,78 200.00 54.364 Centre Distance Pass - Major Risk 213.24 275.00 40.155 Clearance Factor Pass - Major Risk 213.74 225.00 48.974 Centre Distance Pass - Major Risk 213,24 275.00 40.463 Clearance Factor Pass - Major Risk 180.46 1,325.00 8.932 Clearance Factor Pass - Major Risk 180.35 1,325.00 8.889 Clearance Factor Pass - Major Risk 18.86 39.77 19.612 Centre Distance Pass - Major Risk 14,47 400.00 3.060 Clearance Factor Pass - Major Risk 145.11 500.00 17.713 Centre Distance Pass - Major Risk 143.69 1,150.00 8.120 Clearance Factor Pass -Major Risk 14.81 325.00 3.562 Centre Distance Pass - Major Risk 10.66 750.00 1.820 Clearance Factor Pass - Major Risk COMPASS Page 3 of 6 04 September, 2018 - 14:19 ConocoPhillips Anticollision Report for Plan: 3S-612 - 3S-612wp06 SurveV tool program From (usft) 39.00 1,400.00 1,400.00 3,005.00 3,005.00 13,865.00 13,865.00 To Waft) 1,400.00 3S-612wp06 2,400.00 3S-612wp06 3,005.00 3S-612wp06 4,505.00 3S-612Wp06 13,865.00 3S-612Wp06 15,365.00 3S-612wp06 19,883.48 3S-612Wp06 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Surveylplan Survey Tool GYD-GC-SS MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 04 September, 2018 - 14'19 Page 4 of 6 COMPASS 14:22, September 04 2018 3S-612wp06 Ladder View If U1 m ' N M M N t0 (O 300 I I 0 i ro Q. U h c150 Q N M r i i i I I N U t� I Equivalent Magnetic Distance I 0 0 3000 6000 9000 12000 15000 18000 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool I VD MD Name 39.00 1400.00 3S-612wp06 (Plan: 3S-612) GYD-GC-SS 2565.00 3006.35 10 3/4 x 13-1/2 1400.00 2400.00 3S-612wp06 (Plan: 3S-612) MWD 5103.50 13865.69 7-5/8 x 9-7/8 1400.00 3005.00 3S-612wp06 (Plan: 3S-612) MWD+IFR-AK- 5213.50 19883.48 4 1/2 x 6-3/4 3005.00 4505.00 3S-612wp06 (Plan: 3S-612) MWD 3005.0013865.00 3S-612wp06 (Plan: 3S-612) MWD+IFR-AK- 13865.0015365.00 3S-612wp06(Plan:3S-612) MWD 13865.0019883.48 3S-612 06 Plan: 3S-612 MWD+IFR-AK- o M a m Ul n M M M � o 3 M n M 60 c 0 I cd CL m d U 0 m C5 U Equivalent Magnetic Distance 0 400 800 1200 1600 2000 Partial Measured Depth Easting (3000 usftJn) Easting (3000 usttlin) 14:28, September 04 2018 Easting (70 usft/in) 3S-15 3S-612wp06 ;5;;. 3,, 10 -- - 3S:61Im 0 ___ _ -- ... 3S: -06A 8icier) IIWUl 18 -..-. p 2 ,, r' �3 3S-07 � � I 17 �2 I 3S-26 rb 10 10 A6 9LP !7 e IN C5 C S-16 fr y N ^ 7pi q B 1R �9 �' 4 3 o ^ a 0 --6 ^co� q-__. .. r Mr �s . 6 -_ _.. m Cb _ ro e 5 6R 5 'R 3 A N Zzus�Z Fie i� n` IcN >s—. 5_� a p k 3S Pad- `m _a_ �^ h 2 z Ku aru � .......... 9 w 1 I I � I s— B -._ 35-086 Easting (70 usft/in) W U) V, 1j j 10 W N N�'N� m m O O O C (T fl�N N00 ooccoo�.+ q ,QN N J V oma oo00oo!OOT j O 000 mlilmNOAA3 m NN00 Q W N 1 W mmc a ImJ mbo Oo bb 0000000 S A O O mmo m o a, mNNo ON NaK D V'�j D D N K x h z z mNmy !Zara. W A m 3 N �i O n n c dpAAN W(.1N'� tll JfY4)mANOOJmm(J NOm J_ N W y+_ ♦ N WONO(ml�(ml�m+ ppplj pO00� � PJOmWyy fl�4)WfO (J mmfJ fD IDmJNN�mO00O V (OJJmm41N O0O . O 1 J 1 J A O O J J O O O OOD O 1TU000o0(NU OO VNOO� mmO00��NNL1 (p000[] O V co Q AA 4 p O A O O O O O O O m m j O j W W m j m 01m N N N N N N N O O NNN 4n inA OOO OHO OOD W ny � N � NmNmmA�0000000N. O \ j N_NN_N +JJfNIiU J_m_m!J plJAWVmi (J)IANJ JIApON� j OOINOO(mi10A000�SOO N ..... O N O N O N— 0 0 0 W � 1� I � � � 000 O OOOOVI O NNCCa o0000000Om0000m ''�` \ j (pJ 0000(mli0 iN 0000(1i00T O O O O N O N O O O O 0.0. w O W O N W n 1I m m N W Cp O C13W O O �zr 9z n>nauana'o 'o m0 NOVO �OTNO N(A \/ ,^ V' O =. O O m�00NOm0�'1NON v O m O 0 N o V q�-3 ONa+41 o III N �O (O m N IAO O O C—nW W N O v v IP A W N� C m m T u y W W OD W W j DD W O N N (T J COW N A J (P W O W °-' o y' y 'r J M W (P A W N O A J -� N (D W m O� N N W A W A (.n W Z r T cp o�� N O V P 41O O J O) A W W N-4 CA IV - (O O) O) W N O W W W O N 1 M V N A -4 W CA0. W. W A A W " W W w W OD W O O A J w Ul (D W O O N N 0 0 0 0 M OJ 0 A W N 0 0 0 0 0 0 0 0 0 0 0 0 0 W 0 0 O 0 O 0 0 O 3S-612wp06 I 39.00 To 1500.00 I AC Flipbook 39 350 pth From Depth To Tool 314 39.00 1400.00 GYD-GC-SS 35-15 350 540 1400.00 2400.00 MWD 1400.00 3005.00 MWD+IFR-AK-C 540 740 3005.00 4505.00 MWD 120 3005.0013865.00 MWD+IFR-AK-C 1'07 13865.0015365.00 MWD 330 132 30 740 930 13865.0019883.48 MWD+IFR-AK-C 930 1120 1009 1120 1320 CASING DETAILS 909 0 3S-70 611wp0 i 1320 151 TVD MD Name 2565.00 3006.35 10 3/4 x 13-1/2 300 60 5103.50 13865.69 7-5/8 x 9-7/8 79 1510 1700 5213.50 19883.48 4 1/2 x 6-3/4 _ 35.091 809 SS 1 70 69 40 60 1700 2460 MD Azi TFace 6 5 2460 3230 39.00 0.00 0.00 / 350.00 0.00 0.00 6 t, 6 3s o7 3230 3990 650.00 305.00 305.00 609 6 1671.39 305.00 0.00 1� 3s o6 3990 4750 1786.91 305.00 0.00 270 q 90 3006.35 305.00 0.00 7 4750 5510 3026.35 305.00 0.00 07 'S 08 3581.57 302.44 -8.75 307 y*7 x,'207 5510 6270 12435.48 302.44 0.00 '107 10 13865.69 346.53 95.21 71 6 6270 70401 14358.69 346.53 0.00 19 1 3s -os' 4 14792.03 346.53 0.00 3S 9 70140 780 14810.76 346.53 0.00 19883.48 346.53 0.00 10 8 7800 9310 240 1u 120 9310 10820 1199 10820 1233C 9 1291 12330 1384C 210 150 13840 1535C 1 15350 1686C 35-16 16860 1837C VS -611380 18370 _-1988 2018 3S-612wp06 1500.00 To 3000.00 AC Flipbook 39 350 pth From Depth To Tool 240000 MWD c -ss 350 540 1400.00 Q 1400.00 3005.00 MWD+IFR-AK-C 3005.00 4505.00 MWD 120 S-611wp09 540 740 3005.0013865.00 MWD+IFR-AK-C 13865.0015365.00 MWD 330 30 740 930 13865.0019883.48 MWD+IFR-AK-C 930 1120 80 206 6 /1983 1120 1320 1320 151 CASING DETAILS TVD MD Name 2565.00 3006.35 10 3/4 x 13-1/2 F 5103.50 13865.69 7-5/8 x 9-7/8 300 3 1u69 6Q �� 1510 1700 5213.50 19883.48 4 1/2 x 6-3/4 1790 16 ' 1700 2460 MD Azi TFace 40 2460 3230 39.00 0.00 0.00 350.00 0.00 0.00 3230 3990 650.00 305.00 305.00 1671.39 305.00 0.00 3990 4750 1786.91 305.00 0.00 27Q 90 3006.35 305.00 0.00 _ 4750 5510 3026.35 305.00 0.00 3581.57 302.44 -8.75 5510 6270 12435.48 302.44 0.00 13865.69 346.53 95.21 6,270 7040 14358.69 346.53 0.00 14792.03 346.53 0.00 40 7040 _ 780 14810.76 346.53 0.00 19883.48 346.53 0.00 240 7800 9310 120 9310 1082C 80 10820 1233C 12330 1384C 210 150 13840 1535C 120 15350 1686C 180 16860 1837C 18370 19883 O O LL W 15 co RimM 00 00 a) `T r 0 0 ci O coM r L 0 0 0 0 0 0 0 0 0 0 C O N M� LC) Cfl I- M 0 0 0 0 N N T O CO M M Ln T r�'t O T W M M M M M M LO dt/t /M/T M M I— "t N M 1-- LC) N O CO M O N M LO W W M N M M � LO (D r�1^_ (Y) T T T T T T T I m O O O O O O O O O O O O O O O O O O O O O O O M L(7 I, O T M M r� d' N M r� In N O M M M M M M M M 0 a N �% U L% �NNv N 0000000 � O r 0000 y y y Wmmw U 000000OI� O N 0000 z"O UIOoovi0006C6660000 0000000 ¢ —0000000avMMMMM $>333333: w ora Q0000000actLnLIQ UnLnLq O O O O G O O N 1-000 OooC C7 Q N OI N O O O O O O O V M MMMMMMMM MMM LOOOOfp z �N(Oa (pN QC v o �n N N N M O(ON o N N � O O O m r tli to I� M m m M (O N Q.-Nc'J V MNO� U NMOL 000MO1 MMl('1a (O (001 7 �000a000 000 � O)OOr-gyp (D IOr i(j �UNNOM o O�nN M�u11� W ON NMcO lnor CO u'Mo00ocp co ��00� M M M N M 77 V' O r d HN��O I ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-612 50103xxxxx00 Plan: 3S-612 Plan: 3S-612wp06 Error Ellipse Survey Report 04 September, 2018 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 35-612 Project: Kuparuk River Unit TVD Reference: Plan @ 63.50usft (Doyon142) Site: Kuparuk 3S Pad MD Reference: Plan @ 63.50usft (Doyon142) Well: Plan: 35-612 Norm Reference: True , Wellbore: Plan: 3SE72 Survey Calculation Method: Minimum Curvature Design: 3SS12wp06 output errors are at 1.00 sigma 3,005.00 Design Database: OAKEDMP2 Project Kupawk River Unit, North Slope Alaska, United States Audit Notes: Map System: 13,865.00 System Datum: Mean Sea Level Version: Phase: PLAN Using Well Reference Point Geo Datum: Vertical Section: Depth From (TVD) Using geodetic scale factor Map Zone: Direction (usft) (usft) (usft) (1) Site Kuparuk 3S Pad 0.00 319.02 Site Position: Northing: Latitude: From: Map Fasting: Longitude: -0.18, Position Uncertainty: 0.00 usft Slot Radius: Grid Convergence: Well Plan: 3S-612 Plan: 3SS12 Well Position +NIS 0.00 usft Northing: Latitude; +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 24.50 usft Wellbore Plan: 3SS12 From Magnetics Model Name Sample Data Declination Dip Angle Field Strength Tool Name Description (') (•) (nT) Gyrodata gyro single shots BGGM2018 10/15/2018 2,400.00 35-612Wp06(Plan: 3SS12) 16.79 80.88 57,431 1,400.00 3,005.00 35-612wp06(Plan: 35612) MWD+IFR-AK-CAZSC MWD+IFRAKCAZSCC 3,005.00 Design 3SS12WP06 MWD -Standard 3,005.00 13,865.00 35-612wp06(Plan: 3SS12) Audit Notes: MWD+IFR AK CAZ SCC 13,865.00 15,365.00 3S-612wp06(Plan: 3S-612) MWD Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +NIS +E1 -W Direction (usft) (usft) (usft) (1) 39.00 0.00 0.00 319.02 Survey Tool Program Date 9/4/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,400.00 3S-612wp06 (Plan: 3SS12) GYD-GC-SS Gyrodata gyro single shots 1,400.00 2,400.00 35-612Wp06(Plan: 3SS12) MWD MWD -Standard 1,400.00 3,005.00 35-612wp06(Plan: 35612) MWD+IFR-AK-CAZSC MWD+IFRAKCAZSCC 3,005.00 4,505.00 3"12wp06(Plan: 3SS12) MWD MWD -Standard 3,005.00 13,865.00 35-612wp06(Plan: 3SS12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,865.00 15,365.00 3S-612wp06(Plan: 3S-612) MWD MWD -Standard 13,865.00 19,883.48 35-612wp06(Plan: 3S-612) MWD+IFR-AK-CAZSC MWD+IFRAKCAZSCC 9142018 2:45:31 PM Page 2 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupawk River Unit Site: Kuparuk 3S Pad Well: Plan: 3S-612 Wellbore: Plan: 35612 Design: 3S612wp06 ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Plan Survey Tool Program Date 9142018 Depth From Depth To NOR) (usft) Survey( Wellbore) Tool Name Remarks 1 39.00 1,400.00 3S612wpC6 (Plan: 3S-612) GYD-GC-SS Measured Inclimtim Gyrodata gyro single shots 2 1,400.00 li 2,400.003S612wp06(Plan: 3S-612) MWD V."IcA MWD - Standard 3 1,400.00 3,005.00 3S-612wp06 (Plan: 35612) MWD+IFR-AK-CAZSC MWD+IFRAK CAZ SCC 4 3,005.00 4,505.00 3S612wp06 (Plan: 35612) MWD MWD - Standard 5 3,005.00 13,865.00 3S612WP06 (Plan: 3S612) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 6 13,865.00 15,365.003S612wp06(Plan: 3S-612) MWD MWD - Standard 7 13,865.00 19,883.483S-612Wp06(Plan: 3S-612) MWD+IFR-AK-CAZSC MWD+IFRAK CAZ SCC Well Plan: 35-612 Plan @ 63.50usft (Doyon142) Plan @ 63.50usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and blas at survey station Measured Inclimtim MinuM wu0u1 MlehsMn blml V."IcA Me,.Wde semi+nalor semiminor Minn Ener BW Enor She Ermr alas WBlas Error ErrorAZImuM Tool OayM (--ft) r) O Wo Mn) (era) (Baal (-M (-fa (-ft) (use) (ural Nuft) PI 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0 0.00 0.00 UNDEFINED 0.00 0.00 100.00 001 0.00 0.04 0.00 1.15 0.00 0.0 0.04 0.04 0.00 GYCIGDS3(1. 1) 10000 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 019 0.00 GYDGGSS(1, 1) 20.00 0.00 0.0 200.00 0.0 1.15 0.01 0.01 0.33 0.33 0.0 GY GCSS(1, 1) 300.0 0.0 0.00 30.0 0.33 0.00 0.33 0.01 0.01 0.41 0.41 0.00 GYDGCSS(1, 1) 350.00 0.00 0.00 350.00 0.41 0.00 0.41 0.00 1.15 0,75 305.00 400.00 0.47 0.00 0.47 0.00 1.15 002 0.02 0.47 0.47 4500 GYPGC-SS(1. 1) 400.00 305.00 489.96 0.00 0.00 0.60 0.00 1.15 0.03 0.03 0.60 0.80 45.00 GYD-GCSB(1, 1) 500.00 2.25 599.82 0,73 0.00 0.73 0.0 1.15 001 0.04 0.73 0.73 3406 GYbGCSS(1. 1) 600.0 3.75 305.0 0.0 1.15 0.05 0.05 0.80 0.0 33.94 GYDGCSS (1, 1) 650.0 4.0 305.0 649.69 0.80 000 0.0 097 0.87 33.33 GYD4CSS(111) 70.00 5.75 305.0 699.49 0.87 000 0.07 00 1.15 0.05 OAS 30.0 788,74 1.0 -0.01 1.02 0.0 1.15 0.07 0.07 1.02 1.0 135.0 GYD-GCSS(1, 1) 00.0 8.25 305.0 89!.36 1.15 -0an 1.18 0.0 1.15 0.0 0.0 1.18 1.17 126]8 GYDGCSS(L 1) 00.00 10.75 129 1.35 0.0 1.15 0.12 0.12 1.35 1.32 125.99 GY GOSS(1, 1) 1.00.0 1325 305.0 895.17 -0.01 0.14 0.14 1.53 108 125.69 GYDGC-SS(1, 1) 1110.0 15.75 305.0 1,01.97 143 042 1,53 0.0 1.15 1.64 45.54 GYD-GC-SS (1,11 1,20.0 18.25 30.0 1.187.60 1.50 -0.03 1,74 0.0 1.15 0.17 0.17 1,74 1,300.00 20.]5 305.0 1,281.85 1.74 -0.0 1.96 0.0 1.15 0.20 0.20 1.98 1.80 12544 GY G6 S (1, 1) 1,40.0 23.25 305.0 1,374.56 1.90 -0.04 2.21 0.m 1.16 0.23 0.23 221 1.97 125.36 GY0.GG53 (1, 1) 1,43199 24.04 305.00 1,403.50 1.97 -0.05 2.36 4.05 1.15 0.26 0.27 2.36 207 125.27 MM (1, 2) 1,50.0 25.75 305.0 1465.55 1.97 -0AS 2.36 -0.05 1.15 0.26 0.27 2.36 2.07 1252] MWD (1, 2) 1,600.00 2825 305.0 1,554.85 1.98 -0.07 2.58 -0.16 1.14 039 0.35 2.50 2.10 124.05 M (1, 2) 1.610.08 28.50 305.0 1.563.50 197 -0.08 2.07 -0.26 1.14 0.32 0.42 297 213 124.66 MD (1. 2) 1,671.39 30.0 305.0 1.617.0 1.97 -0.08 2.87 4.26 1.14 0.32 0.42 2.87 2.13 124.66 MM (1, 2) 1,670.80 30.03 305.0 1,62&50 1.98 4.0 3.01 -0.30 1.14 0.33 045 3.01 2.14 124.61 MAD (1. 2) I 1,]0.0 3003 305.0 1641A6 198 408 3.01 -0.0 1.14 0.33 0.45 3.01 .2.14_ 124.61 _ (1, 2) COMPASS 5000.14 Build 85 91412018 2:45:31PM Page 3 ConocoPhillips Error Ellipse Report Company: Project: Site: Well: Wellbore: Design: ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 38 Pad Plan: 3S-612 Plan: 35-612 3S-612wp06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: output errors are at Database: Well Plan: 3S-612 Plan @ 63.50usft (Doyonl42) Plan @ 63.50usft (Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station MeacurW Inc,1w1.n Oep18 Nsnl NI 1.]86.91 30.03 1,800.00 30.38305M 1,038.31 3127 1,900.00 32.86 2,000.0 35M "..th NI 30500 305.0 305.00 305.00 Vm.1 Depth (Oft) 1)1].00 1,#8.322,04 1.759.50 1.6180 1,096.26 11196aMa Emir Blas (Uan) (uaN 2.04 -0.W 4.08 210 4.10 2.10 410 2.17 -0.11 Lateml Emr (van) 3.51 3.59 4.29 4.29 5.10 B]as (am) 4.42 4,43 41.50 -0.W 476 VeNcal MaBaiNee Semimajor bamiminor E., Blaa of BE.. Emr Emr Azimuth Tao] (uas) (v+al (van) (van) Gaal r) 1.17 0.36 0.56 3.51 2.18 124.52 MWD(1, 2) 1.17 0.38 0.58 3.59 2.19 124.51 MwD(1, 1) 1.21 0.40 on 4.29 2.26 124.47 BIWD(1. 2) 1.24 0,10 0.72 4.29 2.26 124.7 MWD(1, 2) 1.24 0.44 0.89 5.10 2.34 124,16 MM(1.2) 21W.W 2.138.22 2.20000 2.30000 2,1W00 37.86 38.82 40.38 42.86 45.36 305.00 305.0 30.5.00 305.00 305.W 1,978.52 2.WB.W 2,054.11 21288? 2,200.68 230 2M 240 2.54 2.70 -0.14 [)A6 4.16 4.18 4.21 6.01 7.02 7.02 8.10 9.25 41.95 -1.17 -1.17 -1.41 -1.68 1.30 1.38 1.38 1.48 1.61 0.0 o31 0.61 0.55 0.58 1.08 1.0 1.30 1.53 180 6.01 7.02 7.02 8.10 9.25 2." 2.55 2.55 2.68 2.80 124.7 MWD(1, 2) 124M MWD(1. 2) 124.40 MWD(1. 2) 124.50 MM (1, 21 124.52 MM(1.2) 2.000.00 2.600.W 2,)0000 2,751.46 2,800.00 7,86 50.36 52.86 54.15 55.36 30500 W5.W 305.00 3W.W 305.00 2269.35 2334.80 2,396.89 2.427.W 2,455.51 2.18 223 2.30 2.37 257 4.24 4.27 4.W 4.33 4.33 4.83 5.28 5.78 6.29 8.29 O.W 0.00 O.W 0.00 0.00 1.33 1.40 1.47 1.56 1.00 0.62 0.65 0.0 072 0.72 0.70 0.75 O.W 0.85 0.0 4.83 5.30 5.79 6.30 8.30 2.19 2.58 2.62 268 2,68 122.28 MWD+IFR-MK-SC(2.2) 12255 MWD+IFR-AK-CAZSC(2.21 122A5 MWD+IFR-WCA -SC (2,2) 42.55 MNVAFR-AKLA C(2.2) 122.55 MWD+IFR-AKC SC(2,2) 2,900.00 3.=.00 3,006.35 3,026.35 3.103.00 III VAS W.36 60.52 00.52 0.71 305.W W5.W WS.W 305.00 304.62 2,510.53 2,561.87 2.M5.W 2,674.84 2,600.85 2,44 2.16 2.46 2.46 2." 4.37 -0,10 4E.40 4,10 4)." 6.02 7.38 7.39 7.52 BOB 0.00 4.21 422 4.00 4.61 1.66 1.67 167 1.67 1.70 0.75 0.77 0.n 0.70 ow O.W 0.97 0.87 1.01 1.17 6.83 7.36 7.40 7.52 6.08 2.74 2.82 283 284 2.00 122.65 MWD+IFR-MC-SC (2,21 122.87 MM (2,3) 4288 M 043) 122.911 1EV+11(2,3) 12124 MWD(2, 3) 3.2W.W 3.245.14 3500.00 3,400.00 3,5W.00 65.67 67.01 68.64 71,61 74.58 304.13 303.92 303.88 303.21 302.78 2.653.39 2.671,50 2.0221 2.726.20 2.78527 2.15 2.51 2.51 2.61 2.75 4,18 -0.53 -0.53 4).57 4.82 9.00 10.17 10.17 11." 12.82 4.05 -1.51 4.51 -1.98 -2.49 1.79 1.93 1.93 2,11 234 0.82 0.04 0.& 0.08 0.87 1.48 1.87 157 230 in 9.00 10.17 10.17 11.45 12.82 2.88 292 2.92 2.95 2.0 123.64 MWD(2.3) 123.70 NwD(2,3) 123.70 MWD (2.3) 123.74 MM (2,3) 123.71 MWD(2,3) 3,501.57 3,800.00 3,7W.W 3MOM 1MA0 n.01 77.01 71,01 17.01 77.01 302." 302." 902." 302," 302." 2,.5.28 2.]/9.43 2,W1.91 8024.39 2.846.88 2.89 2,94 3.21 3.W 3.W 4.00 4.66 -0.66 41.88 -0.66 1309 14.26 15.75 1717 18.81 -2,91 3.01 -3.54 4.06 4.59 2.54 259 2.88 3.17 3.48 0.88 0.88 0.89 0,91 0.92 3.17 3.26 117 4.28 4.79 13.99 14.26 15.75 179 18.82 3.02 3.02 3.00 3.08 3.11 123.64 1^D (2.3) 123.62 MEND (2,3) 123.52 MM(2,3) 123." MWD(2.3) 123.36 MVN(2.3) 4,000.0 4,100.W 4,20.0 4,3W.00 4,400.W 77.01 77.01 77.01 77.01 ".01 302A4 302." 302." 302." 302M 2.86936 2,891,84 2.914.33 2.06.81 2.959.29 4.11 4.43 4.78 5.00 5.42 4.66 4.00 -0.66 4).66 41.86 20.38 21.97 23.56 25.17 26.78 -5.12 5.64 5.17 5.70 -7.22 3.79 4.11 1." 4,77 5.10 0.93 0.94 0.95 0.96 0,97 5.31 5.83 6.35 6.88 7.40 20.38 21.97 23.58 25.17 26.79 3.15 1.18 3.22 3.26 3.30 10.29 MWD(2.3) 123.23 MWD(2.3) 123.17 MWD(2,3) 123.12 MWD(2,3) 10W MWD(2.3) 4,500.00 4,000.00 47W.W 4.800.00 4,900.00 77.01 77.01 n.01 A.01 77.01 302.M 302M 302." W2.M 002." 2,901.78 3.004.26 3,026.74 804823 3,071.71 5.75 3.48 3.62 3.n 3.93 ().66 4.68 4.68 -0.68 4.68 2811 13." 13.0 14,17 1800 -7.75 0.03 O.W O 3 0.03 5M 3.19 3.34 3.49 864 0.98 1.00 1.01 1.02 1.03 7.93 1.65 1.70 1.75 1.80 28.41 13.44 13.95 14.47 law 3.34 3,08 3.10 3.12 3.14 123.04 B (2.3) 122.81 MWD+IFR-MC -SC (3,3) 122.78 MWDNFR-AK-CA 4EC(3,3) 12276 MWD+IFR-AK -SC (3.3) 122J3 MWCAD+IFR-M-&C(3,3) 5.000.00 5,1W.0 5,200.0 5,300.00 5,100.00 ]7.01 77.01 77.1 77.1 7].01 302,14 302.44 302.44 302.4 302." 3,094.19 3,116.68 3.139.16 3,161.64 3.181.13 4.00 424 4.39 4.55 471 4.0 4.68 4.68 4.0 40 15.53 16.00 16.00 17.14 17.69 0.00 0.03 0.03 0.00 0.03 3.80 3.98 4.12 4.28 4.M 1,05 1.00 1.07 1.00 110 1.85 1.90 1.95 2.01 2.00 15.53 16,00 16.80 17.14 17.69 3.16 3.18 3.20 3,22 3.24 122.71 MWDNFR-AKC C(3,3) 122.60 M AF&AKCAZSC(3,3) 122.66 MWD+IFR-MK -SC (3 1) 122.84 MWD+IFR.M cC -SC(3, 3) 122.62 MMAFR-M-CAZ C(3,3) 5,500.0 5,600.00 57W.W S,BW.W 5,900.W 77.01 17.01 TI.01 77.01 P.01 302,14 302." 302." 302.44 W2A4 3,200,61 3,229.00 3.251.58 3,274.00 3,296.54 4.87 5.04 5.20 5.36 5.53 4.68 4.88 -060 -0,68 4.68 1824 18.1`9 19.34 19.00 20.16 0.03 O.W 0.0 0.03 0.03 4.W 4.76 4.93 5.09 5.25 1.11 1.12 1.14 1.15 1.16 2.12 2.17 2.23 2.29 2.35 18.24 18.79 19.34 1590 20A6 3.27 1.29 3.31 3.34 3.38 122.61 MWD+IFR-AKCAZSC(3.3) 12259 MND+IFR-AK-c 2SC(3.3) 122.57 MMAFR-AK-CA ,SC (3,3) 122.56 MWD+IFR-AKCAZSC(13) 122.54 MM+IFR-AKCA2-SC(3, 3) 6,000.W 8,086.62 6,100.00 8200.00 77.01 77.01 17.01 77,01 302." 302.M 302." W2.M 3,31803 3,330.50 3,341.51 3.363.99 5.69 5.86 5.88 6.00 4.68 4.68 41.60 4.60 21.02 2158 21.58 22.14 0.0 0.03 0.00 0.03 5.42 5.0 5.00 5.75 118 1.19 1.19 1.21 2.00 2,18 246 2.52 21.02 21.58 21.58 22.14 3.39 141 3.41 3.44 122,W MWDAFR-AKCA -SC (3.3) 122,51 MWD+IFR-A-BC (3.3) 122.51 MWD+IFR-MC -SC (3.3) in.W MWD+IFR-AKC C(3,3) 9/4/2018 2:45:31PM Page 4 COMPASS 5000.14 Build 85 ConocoPhil lips Error Ellipse Report Company: Project: site: Well: Wellbore: Design: ConocoPhillips (Alaska) Inc. -Kup2 Kupawk River Unit Kupawk 3S Pad Plan: 3S-612 Plan: 3S-612 38-612wp06 Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: output amers are at Database: Well Plan: 35-612 Plan @ 63.50usft (Doyonl42) Plan @ 63.50us6 (Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Meesurw DapM (pse) 6,wem 6,400.00 6,500.00 &800.00 6,700.00 Indlmtlon P) 19.01 77.01 77,01 1.01 7711 Atlmuth C) 302." W2." 302.44 %214 302.44 Ventral DepN (..m 3,388.40 3,408.96 313tH 3,453.92 3.416,41 KI,W" Enor Bla (use) (.00 8.19 AW 8.35 4.68 6.53 4).68 6.70 -0.68 8.87 4.68 laurel Eno, (use) 22.71 23.27 23.84 2411 24.90 Bu. (use) 0.03 ew ew 0.03 ow Venical Emor Blaa (ush) (use) 5.92 1.22 6.0 1.23 sm 125 6.42 1.26 6.50 1.28 Wlniwde of Blaa (usn) 2.58 2.66 211 2.77 2.83 semimaler Enor (UsB) 22.71 239 23.84 24AI 24.98 Semiminw Ermr ".U,% Tatl (Usa) r) 3.46 122.49 MWD+IFR-AKC -SC (3,3) 3.49 122,48 MWD+IFR-AKCAZ (3.3) 3.52 12217 MWD+IFR-AI(CAZ-W(3,3) 3.54 122.46 MWD+IFR-MK- SC(3,3) 3.57 122.45 MWD+IFR-AKCAZ C(3,3) 6,800.00 61900.00 7,000.00 7.100.00 7,200.W 77.01 77.01 77.01 net 1.01 302.44 302.." %214 30214 302" 3,498.89 3.521.37 3,543.86 3,568.34 3,588.82 7.04 7.21 7.35 7.55 712 AN -0.68 -0.% 4.68 -0.60 25.55 26.13 26.70 27.27 27.85 0.03 0.03 0.03 0.03 0.03 6.75 &92 7.09 7.28 7.42 1.29 1.31 1.32 1.34 1,35 2.90 2.96 3.03 3.10 316 25.55 26.13 26.70 27.27 27.85 300 3.89 3.66 3.60 3.71 12266 MWONFR-MK-SC(3,3) 17213 MWD+IFR-WK ,SC (3.3) 122.42 MWD+IFR-N(CAZ-W(3,3) 122.41 MWWIFR-AK-CAZSC(3.3) 12210 MWD+IFR-AHCAZSC(3,3) 7,300.00 7100.00 7,W0.00 7,600.00 7,700.00 77.01 7)01 77.01 77.01 7.01 302.44 3M." 302.44 302M 302." 3,611,31 3,633.78 3,6569 3.678.76 3,101.24 7.89 8.07 6.24 8.41 &w 4),60 AM -0.% -0.60 -0.60 28.43 29.00 29.50 30.16 50.74 0.03 0.03 003 0.03 0.03 7.59 7.76 7.93 8110 8.27 1.37 1.38 1.40 1.42 113 123 3,30 3.37 3." 3.51 28.43 29.00 29.50 30.18 30.74 3.74 3." 3.80 3103 3.87 122.39 MWD+1FR-MK SC(3,3) 12139 MWD+IFR-AK-C SC(3,3) 122.38 MMD+IFR-AK- -SC(3.3) 12237 M IFR-AKCA -W (3, 3) 122.37 MWD+IFR-N(-CAZSC(3,3) 7,800.00 7,900.00 eooew 8,1oew 8200.00 77.01 77.01 7701 77.01 77.01 302." 30214 M." 302." 30244 3,723,n 3.746.21 3,7069 3,791.17 3,813.66 8.75 8.93 8.10 9.27 915 e68 -0.68 4.80 468 -0.60 31.31 31.89 32.47 33.06 33.64 ew 0.03 0.03 0.03 0.03 6." 8.61 8.78 &M 9.12 1.45 116 1.48 1.50 151 300 3.65 3.72 3,79 3.87 31.31 31.89 32.47 33.06 33.64 390 3.93 &W 3.99 4.03 122% MWD+IFR-AKCAZ C(3.3) 122.35 MWD -IFR -MC -SC (3, 3) 122.35 MWD+IFR.MW -SC (3.3) 122.34 MND+IFR-AKCA2-SC(3.3) 122.34 E1WD•IFR-AKCA2-SC (3.3) &300.00 810000 8,W0,w 0,600.00 &80.00 77.01 77.01 77.01 77.01 non 302.44 302." 30214 302." 302." 3,836.14 3,858.62 3,881.11 3.903.59 3,926.7 9.62 9.79 9.97 10.14 10.31 4.68 4.88 AN -0.6B -0.68 34.22 34180 %.% 35.97 36.55 ew ow 0.03 0.03 0.03 929 9.48 9.63 9.80 9.97 1.53 1.55 1.57 1.58 1.60 3.94 4.02 4.09 4.17 4.24 34.22 34.80 35.38 %.97 38.55 4.06 409 4.12 4.16 4.19 122.% MWD+IFR-AK-CA SC(3.3) 122.32 MW IFR -MK 41C(3,3) 122.32 MW0+1FR-AK-C SC(3,3) 122.31 6MD+IFR-AKCA SC (3.3) 122.31 MW IFRAKCA-W(3,3) 8,7%.72 8,80000 emeo emew j9,100.00 77.01 77.01 77.01 77el 77.01 302.44 %2.44 902." 30244 302." 3,93eW 3,948,56 3.71.04 3,993.52 4,016.01 1019 10.19 10.66 10.84 11.01 4.68 468 4.0 460 4.68 3713 37.13 37.72 38.30 38.08 0.03 0.03 0.03 0.03 0.03 10.14 10.14 10.31 WAS 10.65 1.62 1.62 1.64 1.65 1.67 4.32 4.32 4.40 4," 4.56 37.13 37.13 37.72 38.30 %.80 4.23 4.23 4.26 4.29 4.33 12231 MWD+IFR.M-cA -SC (3,3) 122.31 MWD+1FR-AKCA C(3,3) 122.30 MM -IFR -M- SC(3,3) 122.30 MWD+IFR-AK-C SC(3,3) 122.29 MWD+IFR-AKCA-SC (3.3) 90.00 20 9,900.00 9,400.00 9,458.01 1. 9,50000 77.01 72.01 77.01 77.01 77.01 %2M 302.44 302.44 302." 30214 4.03&49 4,060.7 4,083.46 4.096.60 MM" 11.18 11.36 11.53 11.71 11.71 -0.68 4.0 -ew -0.68 -em 39.47 10.05 40.84 4122 41.22 003 ow 0.03 0.03 0.03 10.82 less 11.17 11.34 11.34 1.69 1.71 113 1.74 114 4.64 4.72 4.80 4.88 4.88 39.47 40.05 40.64 41.22 4132 4.% 4.40 4.43 4.47 4.47 122.29 MWD+IFR-AKCAZSC (3.3) 122,28 MWDHFR-AKCA2-SC(3,3) 122.28 MWD+IFR-AKCA-SC (3.3) 12228 MND+IFR-MK ,SC (13) 122.28 MWD+IFR-A -CA (3,3) 9.800.00 9,700.00 9,800.00 1 9,900.00 1emoo 77.01 77.01 77.01 77.01 77.01 302." 302.44 302." 302." W2M 4,128.42 4,1511.91 4.17.39 4,195.87 4,218.36 11.88 12.06 1223 12.41 1250 4.68 -0.68 -0.60 -e68 -0.60 41.81 42.40 4290 43.57 ".16 0.03 am 0.03 0.03 0.03 11.51 11.68 11.85 12.02 12.19 1.76 110 1.00 1.82 1.84 4.96 &04 &13 521 5.30 41.81 4210 42.98 43.57 44.16 4.00 4.54 4.58 4.61 4.65 1229 MV IFR-AKCA-$C(3,3) 1229 MWD+IFR-AKCFZ C(3,3) 1229 MWD+IFR-AK SC(3,3) 12226 MWD+IFR-AKCA25C(3,3) 122.26 MWD+IFR-MK- -SC (3,3) 1%054.01 1D.100.00 10,20000 10,300.00 10,40000 77.01 77.01 77.01 77.01 "Al 002." M." %2." 302." 302." 4,2%.W 4.240.84 4.263.32 4,285.81 4,308.29 1216 12.76 12.93 13.11 1328 4.6a -0160 Ass -0.% -0.68 "14 ".74 45.33 45.92 48.50 0.03 0.03 0.03 0.03 0.03 12.36 12.% 12.53 12.71 12.88 1.86 1,88 1.80 1.00 1.92 &38 5.% 5.47 5.55 5164 "14 44]4 4533 45.92 46.0 4.68 4.00 412 4.76 4.80 122.26 MWD+IFR-AKCAZ C(3,3) 12228 M IM -MK SC(3,3) 122.25 MWD+IFR-AKCA2-SC(3.3) 122.25 M IFR-AKC -SC (3.3) 122.25 MWD+IFR-AKC-00(3,3) lesoa 0 10,600.00 1010.00 1%000.00 10.900.00 77,01 77.01 77.01 77.01 77.01 302." W2M 002." %214 30214 4,33017 4,353.26 4,375.74 4,308.22 4.420,71 13.46 13.0 1311 13.98 14.16 0." -0.68 4.60 -0.68 4.68 47.09 47.68 M17 48.05 49." 0.03 0.03 0.03 0.03 0.03 13.05 13.22 1339 13.56 13]3 1.84 1.98 tse 2.00 2.02 5.73 5.82 &91 6.00 6.00 47.09 47.68 48.27 48.85 49.44 4.83 4.87 4.91 4.94 4.98 122.24 MM+lFR-AKCA -SC (3,3) 12224 MWD+IFR-AKCAZSC(3,3) 12224 MND+IFR-MC C(3,3) 122.24 MWD+IFR-AKCA2-W(3.3) 1n.23 MND+IFR-AK-C -SC (3,3) 11.000.00 11,100.00 11,200.00 17.300.00 77.01 77.01 n.01 77.01 %2.44 302." 302." 30214 4,"3.19 4,465.7 4188.16 4.510.64 14.% 14.51 14.60 14.86 4.68 -0.68 -0.w 4.68 50.03 W.62 51.21 51.80 0.03 0.03 0.03 ew 13.91 14.08 14.25 14.42 2.04 2.06 2.08 2.10 6.18 6.27 6.% 8145 50eo 50.62 $121 51.80 5.02 &06 5.10 5.13 122.23 MWD+IFR-MC C(3.3) 122,23 MWD+IFR-AKCA SC(3,3) 1n.23 MWD+IFR-AKC-SC(3,3) 172.22 MWD+11FR-AKC-SC (3.3) 9/42018 2:45:31PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: Project: Site: Well: Wellbore: Design: ConocoPhillips (Alaska) Inc. -Kup2 Kupamk River Unit Kupanik 3S Pad Plan: 35-612 Plan: 35-612 3S-612wp06 Local Coordinate Reference: ND Reference: MD Reference: Norm Reference: Survey Calculation Method: output errors are at Database: Well Plan: 3S-612 Plan @ 63.50usft (Doyon142) Plan ® 63.50usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and blas at survey station We Uu Inclinallon "..0 WrO al lfi f Ma i.eYrN Vx9w M4aD 84lnlreyer SaalM DSPM Wpo E. &aa Favr 9125 E. at. orale Error Elroy "Mudi 11" (UBm :-1 (°I (Yam W -M wFa) (u8W) 99a) Nam (Wa) cure (-K) (WE) r) 11,400.00 A.01 302." 4.533.12 15.0! 4).0 5238 0.03 14.69 2.12 6.55 52.30 5.17 122.22 MWD+IFR-WK-SC(3,3) 111500.00 77.01 302." 4,555.61 1621 4.0 52.91 0.03 14.76 214 6.64 52.97 5.21 122.22 MWDHFR-A&CAZSC(3.3) 11,600.00 77,01 3325 4,578.09 15.39 -0.68 53.56 0.03 14." 2.16 673 53.56 5.25 122.22 MWD+IFR-AK ,80(3.3) 11,700.0 77.01 302." 4,600.57 1556 4).0 54.15 0.03 15.11 2.19 6.03 54.15 5.29 12222 MWD+IFR-AK-CA2-SC(3,3) 11,000.00 not 302." 6,623.6 15.74 4).88 51.74 0.03 15,28 2.21 6.0 54]4 5.33 122.21 MA)AFR-AK-CAZ-SC(3,3) 11.900.00 n.01 302." 4,645.54 15.91 -0.68 65.33 0.03 15.45 2.23 7.02 55.33 5.37 122.21 MWD+IFR-AK42AZSC(3,3) 12,000.00 no, 302." 4,668.02 16,09 -0.88 55.92 0.03 15.62 2.25 7.12 55.92 5.41 12221 MWD+IFA-AKCAZSC(3.3) 12.100.00 77.01 302." 4,690.51 1&27 4.68 58.51 0.03 15.79 2.27 7.22 58.51 S." 122.21 MWD+IFR- Z6 -SC(3,3) 12.20000 77.01 302." 4,71299 16.44 -0.68 57.10 0,03 16.87 230 7.31 57.10 5." 122.21 MWD+IFR-AK-CPZSC(3,3) 12,300.00 77.01 302," 47M47 16.62 -0,68 57,69 0.03 18.14 2.32 7,41 57.89 5.52 12220 MMAFR-AK-0 SC (3, 3) 12,40&00 7r.01 302.4 4,757.90 1879 4.98 58.28 0.03 16.31 234 7.51 5828 5,56 122.20 MM+IFR-MW SC(3,3) 12,435.48 77.01 302." 4,765.93 18.66 4.0 58.49 0.03 16.37 235 7.65 58.49 5.50 12220 MW"FR-MK -SC (3.3) 12,500.00 76.84 304.42 4.780.63 17.02 465 58.60 -0.22 16.48 2.36 7.61 58.85 5.60 122.21 MW IFR-MK-SC(3,3) 12,600,00 7651 307.49 4,803.50 17.30 -0.63 59.12 4.61 1655 2.39 7.71 59.37 5.66 122.23 MWD+IFR-MCA (3,3) 12.73.3 76.41 310.57 4,828.83 1282 461 5927 -1100 16M 2.41 7.82 59.88 5.68 12229 MWD+IFR-M-CA SC(3,3) 12,800.00 7816 313.65 4,80.46 17.96 4.61 59.23 -1.40 16,99 2" 7.92 60.38 S.n 12237 MWD+IFR-AK-0AZ-SC(3.3) 76+14 31674 4,074.32 18.36 -051 59.01 -1.60 17.16 2.46 8.02 60.87 536 122A7 M"+IFR-M-CA SC (3.3) 12,960.0 13.000.00 76.06 319.83 4,898,35 18.73 4.63 MAI -2.20 17.33 2.49 8.12 61.34 5.60 122.59 MM+IFR-AK-CA (3.31 13.100.00 763 32292 4,922.47 19.15 4.0 58.04 -2.60 17.0 251 &23 also 5.5 122.73 MVN+IFR-M(-0A (3,3) 13.200.00 76.02 326.01 4.94663 19.58 -0.69 57.28 -3.00 17.67 2.54 8.33 62,23 5.90 1n.89 MMAFR-A& G(3,3) 13,300.00 76.06 329.10 4,970,76 20.02 -074 56.35 a.3 17.61 20 0.43 82.85 5.95 123.06 MWD+IFR-AK-0 G(3,3) 13,400.0 76.14 332.19 4,994.79 NAS 4.79 55.24 -378 18.01 2.59 8.0 63.04 6.01 123.24 MWD+IFR-MK-0 SC P. 3) 13,00.0 7625 33520 5,018.86 20.88 4).86 53.97 4.9 18.18 282 682 63.41 &W 123A4 MWD+IFR-MC -SC (3.3) 13,60.0 76A1 338.36 5.04230 21.30 -0.0 52.53 4.54 10,35 2.64 8.72 63.78 6.16 123.65 MW0+1FR-AK4A24C(3.3) 13.70.0 76.0 341." 5106&84 21.0 -1.02 0,94 4.91 18.52 2.67 8.01 64.0 6.25 123.86 MWDrIFR-M-cA-W(3.3) 13,00.00 7&83 344.51 5.088.63 22.05 -1.11 49.19 -5.27 18.69 2.0 8.89 60.39 63 124.09 MM+IFR41(-CA (3,3) 13,865.69 77.0 348.53 5,103.60 n22 -1.17 48,0 -5.60 18.74 2.71 9.01 6432 6.18 124.25 MWD (3,4) 13,900.0 71.0 3"53 5.111.29 2923 -1.17 48.39 -5.69 18.74 232 9.10 64.89 6.21 124.39 MM (3.4) 14,000.0 A40 348.53 5,133.71 2223 -1.17 49.01 -5.97 18.75 2.74 au 65.40 6." 124.62 51600(3.4) 14,10.0 A.3 34653 5,158.21 22.24 4.17 49.76 -6.24 18.76 2D 9.61 65.93 6.29 125.28 MMD(3,4) 14,20.0 720 346.53 5.17830 22.28 -1.17 50.54 5.52 18.70 2.79 9.80 66148 7.19 125.72 MWD (3.4) 14.30,00 77.0 346.53 5,201.20 n.29 -1.17 51.35 579 18.81 2.82 10.14 67.05 7.67 126.20 X600(3,4) 14,35&69 77.0 346,53 5,214.40 22.30 -1.17 51.85 -6.95 18.83 2.83 10,30 67.39 7.98 128.48 MM (3,4) 14,40.0 7824 366.53 5,n3X 21.87 -1.36 52.20 .7.07 18.84 2.8,1 10.41 67.64 6,21 law MW13(3,4) 14,500.0 8114 348.53 5,241.07 20.90 .1.73 53.08 -7.35 16.08 2.86 1068 0,25 &78 127.19 MM (3.4) 14,60,0 8424 346.53 5153.71 20.08 -213 54.0 4.64 10.93 2.87 10.94 68.89 9.39 127.71 MWD (3,4) 14,70.0 0724 316,53 5,281.13 19.45 -2.52 54.95 4.92 18.99 2.88 1120 6955 10.01 12825 MM (3.4) 14,792.03 90.00 346.53 5.26335 19.01 -2.88 55.05 4.19 19.04 288 11." 70.18 10.0 128.75 MWD (3.4) 14,00.00 90.24 348.53 5,263.33 19.02 4.91 65.93 521 19.05 2,88 11.46 70.24 10,64 12879 MIND (3,4) 14.810.76 90.56 346.53 5.26326 18.98 -2.5 56.03 5.25 19.6 2.88 11.40 70,31 1090 128.85 MWD (3.4) 14,90.0 90.58 34&53 5262.38 19.05 -2.95 56.93 5.50 19.12 2.80 11.71 70.94 1127 129.35 MWD (3,41 15,00.0 0.58 34653 5,261.40 19.12 -2.95 57.96 479 19.19 2.88 11,96 71.67 11.0 129.91 MWD (3, 4) 15,10.0 0.56 346,53 5.20.42 19.21 -2.95 590 5.3 1920 2.0 12.29 72.41 12.53 130,47 X600(3,4) 15,20.00 0.56 346.53 5.259.4 19.30 -2.95 60.07 -9.37 19.37 2.88 1248 73.16 13.18 131.04 MVA) (3,4) 15,30.0 90.56 346.53 5,258.46 19.39 -2.95 61.16 4.67 19.46 2.86 12.74 73.97 1397 131.62 M60D(3,4) 15.40.0 0.56 346.53 5,257.48 10.87 -2.95 51.67 -5.51 18.6 2.00 10.01 0.20 elm 1M.39 MWD+IFR41<4 ZSC(4,4) 15,500.0 90.0 348.53 5.256.0 10.0 -2.95 51.0 -&51 18.97 2.80 10.07 67.39 8.0 1X,56 MMIIFR-N4CA2SC(4, 4) 15,800.3 90.58 31653 5,255.52 16.92 -2.95 52.25 5.51 19.0 2.87 10.12 67.59 9.04 126.73 MWD+IFR-AK-C SC(4,4) 15.73.3 0.56 34&53 5,254.54 18.95 -2.95 52.55 5.51 19.03 2.67 10.17 67.79 9.29 1X.91 MMAFR-AK- -SC (4, 4) 15,80.00 0.0 346.53 5,253.56 18.99 -2.95 52.66 -5.51 19,06 287 1023 67.99 9.54 127.09 MWD+IFR-AK UC C(4,Q 15,00.0 0.56 346.53 5,252.57 19.02 -2.0 53.17 3,51 19.9 2.87 1028 8020 9.0 127.27 MWD+IFR-AK -SC (4.4) 1600.0 058 346.53 5.251.59 19,05 -2.95 53.48 -5.51 19.13 2.87 10.33 68.41 10,0 127.45 MM+1FRd6(CA -aC (4.4) 16.13.00 0,56 346.53 &250.61 19.3 -2,95 53.3 -5.51 19.16 2,87 10.39 68.62 10.32 127.64 MWD+IFR-AK-CA-SC(4.4) L1&20.00 0.58 316.53 5,249.63 19.13 -2.95 54.12 5.51 1920 2.87 10." 88.84 10.60 129.83 MWD+IFR-AWCALSC(4,4) 9/4/2018 2:45:31PM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordlnate Reference: Well Plan: 35-612 Project: Kuparuk River Unit TVD Reference: Plan @ 63.50ustt (Doyonl42) Site: Kupa(uk 3S Pad NO Reference: Plan @ 63.50usf1(Doyon142) Well: Plan: 35.612 North Reference: True Wellbore: Plan: 3S-612 Survey Calculation Method: Minimum Curvature Design: 3S-512Wp06 output errors are at 1.00 sigma W.% 9056 9058 90.56 9056 346.53 346.53 31853 346.53 34453 Database: OAKEDMP2 Position uncertainty and bias at survey station MeesaraE Inclreah. Depth (use) 18,900.00 16,400.00 14500.00 18,600.00 16)00.00 rl 00.56 90.56 90.58 90.56 90.56 Azimuth r) 318.53 346.53 346.53 348.53 346.53 vertical Depth least) 5.248.65 5,247.67 5.246.69 5.245.71 5,24.473 K198e16a Evar Blas ("en) (..it) 19.17 -2.95 19.21 -2.95 19.25 -2.95 19.30 .2.95 19.31 -2A!i Letxal Error team 54.45 54.70 55.12 55.46 55.80 Blas Neal -5.51 .5.51 5.51 5.51 .5.51 Vertical Error heal 19.24 1e28 19.32 19.37 19.42 Blas (uan) 2.87 2.07 2.87 287 2.87 M.'rewc4 of Blas lose) 10.49 10.55 10.60 10.88 10.71 6smirmiar Error (ush) 69.05 69.28 69.50 69.73 69.96 Semiminor Env, Azimuth (-an) 1'1 10.84 11.10 11.37 11.63 11.90 Tool 128.01 MWD•IFR-AKCAZ-SC(4,4) 128.21 MWD+IFR-AKCAZSC(4.4) 128.40 MWD+IFR-AKCAZ-SC(4.4) 120.60 MWD+IFR-AKCAZSC(4, 4) 1n.n MVA+IFR.M-caZ-SC(4,4) 18,800.00 16,900.00 17,000.00 17.100.03 17,200.00 W.% 9056 9058 90.56 9056 346.53 346.53 31853 346.53 34453 5,243.75 5242.77 5,241.78 5,240.80 5,239.82 19.39 19.41 19.49 19.55 19.60 -2.95 -2.95 -2.95 .2.95 -2.95 WAS Me) 56.86 57.22 57.58 5.51 5.51 -5.51 -5.51 5.51 19.46 19.51 19.56 19.61 19.67 267 2.87 2.87 2.88 2.86 10.77 10.82 10.88 10.93 10.99 70.19 70.43 70.67 70.91 71.16 12.16 12.43 1269 12.96 1122 128.99 MW0+IFR-AKI:AZSC(4,4) 129.19 M .IFR-AK-0AZ45C(4.4) in.40 MWD+IFRAKCAZSC(4, 4) 129.60 MWD+IFR-AK-CAZSC(4,4) 129.81 MWD+IFR-AKCAZSC(4,4) 17,WoW 17.400.00 17,500.00 17,600.00 17700.00 90.58 90.56 90.58 80.55 90.56 346.53 346.53 346.53 348.53 346.53 423404 5.237.88 5.236.88 5,235.80 5,234.92 19.65 19.71 18.77 1400 19.89 -2.95 -295 -2.95 -2.95 -2.95 57.95 50.32 56.69 59.07 WAS -5.51 5.51 5.51 5.51 -5.51 19.72 19.78 19.61 19.90 19.96 2.86 2.86 2.86 2.86 2.86 11.04 11.10 11.15 11.21 11.26 71.41 71.66 71.92 72.17 72.44 13.48 13.74 14.00 14.28 14.52 130.01 MWD+IFR-AKCAZSC(4,4) 13022 MVA+IFR-AK-CA2-SC(4.4) 130,43 MWD+IFR-AKCAZ-SC(4,4) 130.84 MWD.IFRAK-C 2SC(4.4) 130.85 MVA+IFR-AKCAZSC(4,4) 17,800.00 17,900.00 18,000.00 10,100.0 18,200.00 90.55 0058 90.56 90.56 90.58 346.53 318.53 346.53 346.53 346.53 5,233.94 5,232.96 5,231+90 5,230.99 5,230.01 19.95 20.02 20.08 20.15 20.22 -2.95 -2.95 .2.95 -295 -2,95 59.83 60.22 80.81 81.00 61.40 5.51 5.51 -5.$1 -5.51 5.51 20.02 20.08 20.15 2022 2028 2.88 2.86 2.86 2.86 2.86 11.32 11.38 11.43 11.49 11.54 7270 72.97 7324 73.51 73.79 14.78 15.03 15.19 15.54 15.78 131.07 MWD+IFR-M-CAZ-SG(4.4) 13128 MWD+IFR-AK4AZSC(4,4) 131.50 MWD+IFR-AKCAZSC(4,4) 131.71 MWD+IFR-AKCAZSC(4, 4) 131.93 MWDAFWAK-CAZSC(4,4) 18,300.0 14400.00 18,500.00 18,600.00 10.700.00 90.56 90.56 90.56 00.56 90.56 348.53 346.53 318.53 34853 346.53 5,229.03 5,22405 5227.07 4226.09 5,225.11 20.29 20.36 20.43 20.50 29.50 -2.95 .2.95 -2.95 -2.95 -295 61.80 62.20 62.80 63.01 63.42 5.51 .5.51 5.51 .5.51 -5.51 20.35 20.42 20.50 10.57 20.84 2.88 2.65 2.86 2.85 2.85 11.80 11.66 11.71 11.77 11.83 74.07 74.35 74.64 7493 75.22 16.04 16.28 16.53 16.17 17.01 132.15 MWD+IFRAKCAZSC(4,4) 132.36 MWDHFR-AKLAZSC (4.4) 132.58 MWD+IFR-AKCAZSC(4,4) 132.83 MWD+FR-AKCAZSC (4.4) 1W.02 MWD+IFRAKCAZSC(4.4) 18,800.0 18,900.00 19.000.00 19,100,00 19,200.00 00.56 90.56 Base 90.58 9456 346.53 34653 946.53 348.53 348.53 5,224.13 5.223.15 5,24217 5.221.19 4220.20 20.65 2073 20.81 20.8) 20.97 -2.95 -2.95 .2.95 -2.95 .2.95 63.03 64.25 64.65 65.09 65.51 5.51 5.51 .5.51 5.51 5.51 20.72 20.80 20.80 20.96 21.04 295 2.85 2.85 2.85 295 11.88 11.94 12.00 12.5 12.11 75.52 75.61 76.12 76.42 7673 17.25 17.49 17.73 17.05 18.19 133.24 MWDAFR-AKCAZSC(4.4) 133.46 MWD+IFRAKCALSC(4,4) 133.60 MWD+IFR-AK-CAZSC(4,q 133.90 MWDAFR-M-GA -SC (4,4) 134.12 MWD+IFR-AKCAZ-SC (4.4) 19.300.00 14400.00 18.500.00 191600.00 19.700.00 90.56 90.56 00.50 90.56 90.56 346.53 348.53 seem 346.53 346.53 5.219.22 5,218.24 5,217.26 5.216.28 5.215.30 21.5 21.14 21.22 21.31 21.39 .2.95 .295 8.95 .2.95 -2.95 65.93 66.36 6479 67.22 67.88 -5.51 5.51 5.51 -5.51 5.51 21A2 2120 21.29 21.37 21.46 2.85 295 295 2.85 2.85 12.17 12.23 IZ28 12.34 12.40 77.4 77.35 77.67 77.99 78.31 18.42 18.65 18.87 19.09 19.32 134.34 MVAMFR-AKCAZSC(4,41 134.56 MWDMFR-AKCAZ-SC(4.4) 10478 MWD+IFR-AKCA2-SC(4,4) 135.01 MWD+IFRAKCAZSC(4,4) 135.23 MWD+IFR-AKCAZSC (4.4) 19,800.00 19,803.48 . 90.66 90.56 346.53 345.53 5,214.32 5,213.50 21.48 21.56 .2.95 -2.95 68.10 88.48 -5.51 .5.51 21.55 21.62 2.85 2.85 12.48 12.50 78.0 70.91 19.53 19.72 135.45 MWD+IFR-AKCAZSC(4,4) 135.63 MWD+IFR-AKCAZSC(4.4) 9/4/2018 2.45:31PM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Coordinate Reference: Well Plan: 35-612 Project: Kupamk River Unit TVD Reference: Plan @ 63.50usfl (Doyon142) Site: Kupamk 3S Pad MD Reference: Plan @ 63.50usft (Doyon142) Well: Plan: 35-612 North Reference: True Wellbore: Plan: 3S-612 Survey Calculation Method: Minimum Curvature Design: 3SS12wp06 Output errors are at 1.00 sigma - plan hits target center 13,865.69 Database: OAKEDMP2 Design Targets Target Name VeNcal Casing Hole -hiVmiss target Dip Angle Dip Dir. TVD +NIS +E/ -W -Shape (°) (°) Wait) (usR) (usR) 3S-612 Geo Poly (H) 08: 0.00 0.00 5,103.50 6,729.92 -9,517.11 - plan hits target center 13,865.69 5,103.50 7-5/8 x 9-7/8 7.625 - Polygon 19,883.48 5,213.50 41 /2 x 6-3/4 4.500 Point 1 5,103.50 -107.21 -24.22 Point 5,103.50 13.72 -54.78 Point 5,103.50 38.04 41.45 Point 5,103.50 -82.90 72.01 35-612 T01 Heel 072711 0.00 0.00 5,103.50 6,729.92 -9,517.11 - plan hits target center - Circle (radius 100.00) 35-612 T02 Toe 120717 0.00 0.00 5,213.50 12,566.02 -10,915.12 - plan hits target center - Circle (radius 100.00) 35-612 Geo Poly (T) 08: 0.00 0.00 5,213.50 12,566.02 -10,915.12 - plan hits target center - Polygon Point 1 5,213.50 -5,847.83 1,348.45 Point 5,213.50 -0.93 -51.58 Paint 3 5,213.50 -0.61 47.04 Point 5,213.50 -5,823.67 1,446.82 35.612 North Lease Lim 0.00 0.00 5,213.50 12,566.02 -10,915.12 - plan hits target center - Polygon Point 5,213.50 504.91 7,146.85 Point 2 5,213.50 516.64 -3,413.07 Casing Points Measured VeNcal Casing Hole Depth Depth Diameter Diameter (usR) NMI Name (in) (in) 3,006.35 2,565.00 10 3/4 x 13-111 10.750 13.500 13,865.69 5,103.50 7-5/8 x 9-7/8 7.625 9.875 19,883.48 5,213.50 41 /2 x 6-3/4 4.500 6.750 9142018 2:45:31PM Page 8 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3S Pad Wen: Plan: 3S-612 Wellbore: Plan: 38-612 Design: 3S-612WP06 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 3S-612 Plan @ 63.50usft (Doyoni42) Plan @ S3.50usft(Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMP2 Fonnalions Measured Vertical Vertical Dip Dip Direction Depth Depth Depth 0 (usft) (usft) Name Lithofogy 0 1,431.59 1,403.50 Top Ugnu C 350.00 1,610.06 1,563.50 Base Penn KOP: Start 1.5°7100' DIS, 305° TF, for 300' 1,678.90 1,623.50 Top Ugnu B -9.65 1,836.31 1,759.50 Top UgnuA 179.22 2,138.22 2,006.50 Top WS 1,717.00 2,751.46 2,427.50 Base WS 3,006.35 3,245.14 2,671.50 C-80 Hold for 20' 6,086.62 3,338.50 C-50 -1,018.98 8,759.72 3,939.50 C-35 999.22 9,458.01 4,096.50 Top Coyote (Nanushuk) 4,765.93 10,054.01 4,230.50 Base Coyote (Nanushuk) 13,865.69 13,865.69 5,103.50 Top Torok (Moraine) Hold for 493' Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +Ei-W (usft) (uaR) (usft) (usft) comment 350.00 350.00 0.00 0.00 KOP: Start 1.5°7100' DIS, 305° TF, for 300' 650.00 649.69 6.75 -9.65 Start 2.5°/1D0' DLS, 0° TF, for 1021.39 1,671.39 1,617.00 179.22 -255.95 Hold for 115.51' 1,786.91 1,717.00 212.38 -303.31 Start 2.5`1100' DLS, 0° TF, for 1219.45' 3,006.35 2,565.00 703.51 -1,004.72 Hold for 20' 3,026.35 2,574.84 713.50 -1,018.98 Start 3°1100' DLS, -8.75' TF, for 555.21' 3,581.57 2,775.28 999.22 -1,448.27 Hold for 8853.91' 12,435.48 4,765.93 5,626.53 -8,729.55 Start 3°/100' DLS, 95.21- TF, for 1430.21' 13,865.69 5,103.50 6,729.92 -9,517.11 Hold for 493' 14,358.69 5,214.40 7,197.07 -9,629.02 Start 3°1100' DLS, 0" TF, for 433.33' 14,792.03 5,263.35 7,614.88 -9,729.10 Adjust TF to 0', for 18.73' 14,810.76 5,263.26 7,633.10 -9,733.46 Hold for 5072.72' 19,883.48 5,213.50 12,566.02 -10,915.12 TD: 19883.48' MD, 5213.5' TVD Checked By: Approved By: Date: 9/42018 2:45:31PM Page 9 COMPASS 5000.14 Build 85 14:51, September N 2018 3S-612wp06 Quarter Mile View 14000 _... _ ....._ ',..-. 3S-611wp06 12000 3S-612wp06 10000- 8 0 0 0 00008000 0 52 52 3S-620 z 1 5A 9 p N 6000 a 0b a^ 3S-�6 zclnr 3S-613 Moraine 1 16000 -14000 -12000 -10000 3S- 5� 1s�yv" 5C2�,�S-1 51 -8000 -6000 -4000 West( -)/East(+) (2000 usft/in) -2000 0 3S- 3S-91 F, C -1----- - __ , -- -�� -- I 3S-612wp06 Surface Location -n, CPAI C�rtllinate Converter _1J Xi From: To: Datum: NAD83 Region: alaska Datura: NAD27 . Region: alaska f Latitude/Longitude IDecimalDegrees . C Latitude/Longitude IDecimalDegfees r UTM Zone: I r South C UTM Zone: True r South G State Plane Zone: q Units: us -ft G State Plane Zone: F4 ----,l Units: us -R r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: Endng Coordinates: X: 11616259.37 X: 476227.29924449 Y: 15993656.03 Y: 5993905.49464912 i _Transform Quit Help 3S -612w 06 Surface Location ie,CPAI Coordinate Converter Ioi xJ i- From: To:- — - -- Datum: FN -A --D-8-3-71 Region: alaska Datum: NAD27 Region: jalaska * Latitude/Longitude IDecimalDegrees f Latitude/Longitude Decimal Degrees f UTM Zone: F— r South C UTM Zone, True r South f: State Plane' Zone: q Units: FuTF-w-1 f State Plane Zone: True w Units: us -ft . C Legal Description (NA.D27 onlyl r Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 1616259.37 Township: 012 FN --,l Range: o08 E Y: 5993656.03 Meridian: U Section:l8 FNL • 2509.9270 FEL 1032.25J21\ { _ _ Transform ! 0uit Help 3S-612wp06 Surface Casing CPAI Coordinate Converter 1131 x1 From: -- To: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska + r Latitude/Longitude IDecimalDegrees C Latitude/Longitude IDecimalDegrees C UTM Zone:I — r South r UTM Zone: True r South G State Plane Zane: F4---] Units: us -Ft + State Plane Zone: q Units: u7 + r Legal Description (NAD27 only] r Legal Description (NAD27 only) Starting Coordinates:— - X: 11615257.03 Ending Coordinates: — X: 475224.972492336 Y: 15994362.71 Y: 5994612.19516374 I if. Transform! Quit Help 3S-612wp06 Surface Casing iaiCPAI Coordinate Converter _1171 XJ From: -- To:—.... Datum: NAD83 + Region: alaska + Datum: NAD27 + Region: Pi—as—k7--, T Latitude/Longitude iDecimalDegrees C Latitude/Longitude IDecimaiDegrees + C UTM Zone: F_ F South r UTM Zone: True r South r- State Plane Zone: I' J Units: us -k +: r State Plane Zone: F-3- J Units: -tt r Legal Description (NAD27 only) i C Legal Description (NAD27 only) Starting Coordinates: X: 1615257.03 Legal Description -.. Township: 072 FN-- iJ Range: 008 Y: 5994362.71 Meridian: F ----w3 Section:16 FNL + 1FB06. 1139 FEL + 2034.3355 Transforms Quit Help J 3S-612wp06 Top of Production CPAI Coordinate Converter From --- To: Datum: NAD83 Region: alaska . Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees i Latitude/Longitude Decimal Degrees f UTM Zone: r South r UTM Zone: True r- South t: State Plane Zone: F Units: us -ft G State Plane Zone:r1-4+ Units: u-, -ft r Legal Description (NAD27 only) C` Legal Description (NAD27 only) I _ Starting Coordinates:— X: 1606765 Ending Coordinates: x 1466733.059067155 y f6000416 y 16000665.70850971 f Transform a Quit Help r....................................................... . . 3S-612wp06 Top of Production CPAI Coordinate Converter _LoJ From To: - - Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska + r Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees + f UTM Zone: F— r South (- UTM Zone: True r South F State Plane Zone:_":q Units: us -ft Units: us -ft + r State Plane Zone: q -:1 CLegal Description [NAD27 only) C Legal Description (NAD27 only) - Starting Coordinates: Legal Description X: 1606765 Township: 012 rN J Range: F66-7FE- + Y: 6000416 Meridian: U Section: 11 FNL 1065.3401 FEL -1 466.20179 ifTransform Quit Help 3S-612wp06 Intermediate Casing I 1%, CPAI Coordin,ate Converter 101 X1 From: To: Datum: INAD83IRegion alaska Datum: NAD27 Region: alaska i Latitude/Longitude +pecimal Degrees r Latitude/Longitude IDecimaiDegrees r UTM Zone: r— r South r UTM Zone: True r South I r- State Plane Zone: q - Units: us -ft �� r- State Plane Zone: I ' -1 Units: us -ft rr Legal Description (NAD27 only) r Legal Description [NAD27 only) Starting Coordinates: Ending Coordinates: -- X: 11606765 X: 466733.059067155 Y: 16000416 Y: 6000665.70850971 I ........................................................ Quit Help 3S-612wp06 Intermediate Casing I 1oJ XI Front: To:- Datum: NAD83 . Region: alaska - 1 Datum: NAD27 Region: alaska f Latitude/Longitude Decimal Degrees r Latitude/Longitude Decimal Degrees * UTM Zone: r- r South C UTM Zone: True r South * State Plane Zone: F----] Units: us -ft D r State Plane Zone: I " E Units: us -ft r Legal Description (NAD27 only) G Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 1606765 Township: 012 FN -,l Range 007 Y: 6000416 Meridian: U Section: F, FNL - 1065.3401 PFFEL - 466.20179 ( Transform Quit Help 3S-612wp06 TD CPAICoortfinate Converter XJ From: Datum: NAD83 Region: alaska To: --------.._-- Datum: NAD27 Region: alaska r Latitude/Longitude IDecimal Degrees r Latitude/Longitude IDecimal Degrees C UTM Zone:I r South r UTM Zone: fTrue r South G State Plane Zone: 4 - Units: us -ft C State Plane Zone: I " J Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates Ending Coordinates. X: 11605366 X: 465354.225348691 i Y: 16006256 Y: 6006505.73236736 Transform Quit Help 3S-612wp06 TD CPAI Coordinate Converter From: To: Datum: NAD83 . Region: alaska - Datum: NAD27 Region: alaska r Latitude/Longitude IDecimaiDegrees r LatitudelLongitude Decimal Degrees r UTM Zone: _ r South r UTM Zone: True r South C• State Plane Zone: q Units: us -ft r State Plane Zone: f q H] Units: us -ft r Lega! Ge>cription JNAD27 onk!I G Legal Description (NAD27 only) Starting Coordinates: - Legal Description--—-—, X 1605386 Township: 012 FN --,l Range: 007 E Y: 6006256 Meridian: U Section: FNL 511.34133 1 1866.6877 r_. .... _...._........_.._......_....__._.... y ,Transform_ .� Quit Help 5 18/17/11 LGM I JFC Add Well 611 & 612 Per K180005ACS 4 06/29/1 JLS I JFC 1 10 PER K180005ACS NOTES, 6 25 w 9 28 27 26 1. BASIS OF LOCATION AND ELEVATION IS DS3SMONUMENTATION Of PER LOUNSBURY & ASSOC.35 S3O 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, 36Y32 3 34 35 ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES T13N ARE NAD 27. 4 T12N 1 6 5 3. ELEVATIONS ARE B. P.M.S. L. UNA momilm 3 2 1 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTEDii N OT SECTION 18, TOWNSHIP 12 NORTH, 1 12 7 8 9 10 113 RANGE 8 EAST, UMIAT MERIDIAN, ALASKA. 12 5. DATES OF SURVEY:8/6/18. 4 13 16 15 14 13 6. ALL DISTANCES SHOWN ARE GROUND. 7 22 124 LEGEND 3 24 19 20 ®AS—BUILT CONDUCTOR LOCATION P1 2 3 3G • EXISTING CONDUCTOR LOCATION 6 w W 30 29 28 25 z 26 25 SEE SHEET 2 FOR LOCATION INFORMATION VICINITY 1"= MAP 2 MILES 7 18 DS3S PAD rn CP 11 :• a m �•�0 .LO (51 �•.�� GRAPHIC SCALE 75 150 300 1 inch = 150 ft. 18 1 17 LOUNSBURY & ASSOCIATES, INC. '.WYM HNGWZ8 PI Ni AREA: 3S MODULE: XXXX UNIT: D3 ConocoPhWip$ WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CARD -ME NO. DRAWING NO. PART: REV: LK6319d42 11 07 14 CEA-DS3S-6319D42 1 1 OF 2 5 5 18/17/1q LGM I JFC I jAdd Well 611 & 612 Per K180005ACSI 4 106/29/18 JLS I JFC I 110 PER K180005ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 18, T. 12 N., R. 8 E., UMIAT MERIDIAN WELL No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. "Y" X. Lot Long. F.N.L F.E.L O.G. PAD 1 5,993,955.06 476,441.80 N 70' 23' 40.621" W 150' 11' 30.043" 2460' 818' 22.7' 27.7• 2 5,993,950.55 476,422.25 N 70' 23' 40.576" W 150' 11' 30.615" 2464' 837' 22.8' 27.7' 3 5,993,946.19 476,402.92 N 70' 23' 40.533" W 150' 11' 31.181" 2469' 857' 22.8' 27.7' 6 5,993,932.58 476,344.38 N 70' 23' 40.397" W 150' 11' 32.894" 2483' 915' 23.0' 27.7' 7 5,993,928.18 476,324.84 N 70' 23' 40.353" W 150' 11' 33.466" 2487' 935' 23.0' 1 27.7' 8 5,993,923.52 476,305.45 N 70' 23' 40.307" W 150' 11' 34.033" 2492' 954' 23.0' 1 27.7' 9 5,993,919.05 476,285.95 N 70' 23' 40.262" W 150' 11' 34.604" 2497' 974 23.0' 27.7' 10 5,993,914.52 476,266.35 N 70' 23' 40.217" W 150' 11' 35.178" 2501' 993' 23.0' 27.7' 14 5,993,896.63 476,188.43 N 70' 23' 40.039" W 150' 11' 37.459" 2519' 1071' 23.0' 27.7' 15 5,993,892.07 476,168.97 N 70' 23' 39.993" W 150' 11' 38.028" 2524' 1091' 23.0' 27.7' 16 5,993,887.49 476,149.43 N 70' 23' 39.948" W 150' 11' 38.600" 2528' 1110' 23.0' 27.7' 17 5,993,883.06 476,130.01 N 70' 23' 39.903" W 150' 11' 39.168" 2533' 1130' 23.0' 27.7' 18 5,993,878.54 476,110.46 N 70' 23' 39.858" W 150' 11' 39.741" 2538' 1149' 23.0 27.7' 19 5,993,874.02 476,091.01 N 70' 23' 39.813" W 150' 11' 40.310" 2542' 1169' 23.0' 27.7' 21 5,993,865.00 476,052.15 N 70' 23' 39.723" W 150' 11' 41.447" 2551' 1207' 22.9' 27.7' 22 5,993,860.59 476,032.71 N 70' 23' 39.679" W 150' 11' 42.016" 2556' 1227' 22.7' 27.7' 23 5,993,856.07 476,013.11 N 70' 23' 39.634" W 150' 11' 42.590" 2560' 1246' 22.5' 1 27.7' 24 5,993,851.58 475,993.50 N 70' 23' 39.590" W 150' 11' 43.164" 2565' 1266' 2204' 27.7' 26 5,993,842.53 475,954.69 N 70' 23' 39.499" W 150' 11' 44.300" 2574' 1305' 23.0' 27.7' *611 5,993,909.97 476,247.39 N 70' 23' 40.172" W 150' 11' 35.733" 1 2506' 1012' 23.0' 24.5' *612 5,993,905.49 476,227.30 N 70' 23' 40.127" 1 W 150' 11' 36.321" 1 2510' 1032' 23.0' 1 24.5' u,� T, �,��..�� ry iv ZJ 4u.utla w uU" 11- Sti.tltlY 2515" 1051" 23.0 24. - 620 1 5,993,869.28 1 476,071.97 1 N 70' 23' 39.766" W 150' 11' 40.867" 1 2547' 1188' 23.0' 24.7' * CONDUCTOR ASBUILT THIS SURVEY SURVEYORS CER71FICATE ��,��,e I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND �.?.`P•,.••......'••••• �,p, LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY 49th '• DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION R;^•••••• ••••• •.. •••• ARE CORRECT AS OF AUGUST, 2018. c JEREMIAH F. CORNELL� `I LS -12663 •,•t LOUNSBURY �jeo•^�.F�,o O 10 & ASSOCIATES. INC. Vu. �;SYONS ENGINMS PL Sgs ConocoPhilli S DS3S WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATIONS CALK6 9d42 11/07/14 DRAwINc No. CEA-DS3S-6319D42 PART: 2 OF 2 REV: 5 ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ DriIling within 30' of horizontal inclination AND driIIingwithin 30' of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations Moraine 3S-612wp06 Grass Roots Horizontal MultiStaae Frae'd In'ector ConoeoPhillips Proposed Wellbore Schematic 14V a I - KBMG wIM Dummy Campanian SS -., h 41 a1"KBMG wl to Dummy E] 4A e1-KBMG'. a" ,.v Carrie, is 4-%'12.6# HYD563 IR New Conductor: 20" Conductor @ 119' 13-1/2" Surface Hole .Surface Casino0 10-3/4" 45.5# L-80 Hydril 563(fXP 3,006' MD 12,565' ND @ 60.52° 9 7B Intermediate Hole y Tubina. 4Y 12,6# L-60 Hydnl 563 4.6 x 7-98". Barret Phemk+Packer H-13168' MD 15( ]-9B'z I, Baker Flex Lock Wet tangw 2 PAnertoppacktt , RS M.W. 0 H - 13th' MD 15054 ND Attachment 5: Drilling Hazards Summary 35-612 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Low Follow real time surveys very closely, gyro survey as needed to ensure survey accuracy. Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Gas Hydrates Moderate Reduced pump rates, Reduced drilling fluid temperatures, Additions of ScreenKleen Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strate Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Coyote / K3 Low Control with higher MW and proper drilling practices. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strateev Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck. Anti -Collision Low Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, utilize PWD to monitor or hole cleaning. Differential Sticking Moderate Follow mud program, keep j2ipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin . Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer if necessary, monitor torque and drag. TRANSMITTAL LETTER CHECKLIST WELL NAME: K R GL 3 5- 6I Z PTD: 215-b L I Development VService _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: Kq D d V U k R 1, ✓e ms' POOL: TU rb k D 1 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by ✓ (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, TOROK OIL _490169 PTD#:2181110 Company CONQCCOPH LLIPS ALASKA INC, Initial Class/Type Well Name: KUPARUK RIV UNIT 3S-612 Program SER — _ Well bore seg __$5$_LP_ENIZGeoArea 890 Unit 11160 On/Off Shore On Annular Dispo Administration 17 Nonconven, gas conforms to A$31,05,0300. 1.A)&2.A-D) _ _ .. _ _ - . NA _ .. _ _ _ _ _ 1 IU11y Permit fee attached _ _ .. NA 2 Lease number appropriate_ _ _ _ _ _ _ _ _ Yes 3 Unique well name and number _ _ _ ..... _ _ _ _ Yes _ 4 Well located in defined pool. _ _ Yes 5 Well located proper distance from drilling unit. boundary_ _ _ _ Yes 6 Well located proper distance from other wells _ _ _ _ Yes 7 Sufficient acreage available in drilling unit. _ _ Yes 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ No. 19 Operator Only affected party. _ _ _ _ Yes 10 Operator has.appropriate bond in force _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order.. _ .. Yes 12 Permit can be issued without administrative. approval _ _ Yes DLB 9/18/2018 13 Can permit be approved before 15-day wait - - - - _ _ _ Yes 14 Well located within area and. strata authorized by Injection Order # (put IO# in comments) (For Yes _ 15 All wells. within 114 mile area of review identified (For service well only) _ _ _ _ _ _ _ _ Yes _ Area of Review plot submitted for Quarter Mile View _ X116 Pre-produced injector; duration of pre produgtion less than 3 months. (For service well only) Yes 18 Conductor string_ provided _ _ _ _ _ ___ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ ___ _ Yes 80' conductor Engineering 19 Surface casing. protects all. known USDWs .. _ _ _ _ Yes set to. 3006' MID 20 CMT. vol adequate to circulate on conductor & surfesg _ _ _ _ _ _ _ _ _ _ Yes _ 137%_ excess 21 CMT. vol adequate to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ No 22 CMT will cover. all known productive horizons. _ _ _ No Productive. interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost _ _ _ _ _ _ _ ..... Yes 24 Adequate tankage or reserve pit _ _ _ .. Yes Rig has steel tanks; all waste to approved disposal wells 25 If re-drill, has 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ NA....... 26 Adequate wellbore separation proposed. _ _ _ _ _ Yes Anti-collision analysis complete; no major risk failures _ 27 If.d]verter required, does it meet regulations _ _ .... _ Yes Diverter size and route acceptable.. 28 Drilling fluid program sghematic & equip list adequate. _ _ .. Yes Max formation pressure is 2150 psig(8.1 ppg EMW); will drill w/ 8.8-10.0 ppg. EMW Appr Date VTL 9/27/2018 29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ Yes 30 BOPE.press rating appropriate; test to (put psig in comments)_ _ _ _ _ _ _ ______ _ _ _ Yes MPSP is 1641 prig: will test BOPs to 3500.psig.... 31 Choke manifold complies w/API RP-53 (May 84) _ _ _ _ _ _ _ _ Yes 32 Work will occur without operation shutdown Yes 33 _ Is presence of H2$ gas probable _ .. - - - - .. Yes H2$ measures required 34 _ Mecbanieatcondition of wells within AOR verified (For service well only)Yes _ _ _ KRU 3S-613 adequate mechanical condition _ _ . _ .. . 35 Permit can be issued w/o hydrogen sulfide measures ..................No........ H2S is present in reservoir, measures required. Well 3S-620 measured 60 ppm H2S on 12/15/17. Geology 36 Data presented On potential overpressure zones _ _ _ _ _ _ _ _ Yes Appr Date 37 Seismic analysis of shallow gas.zones. _ _ _ _ _ _ _ _ _ _ _ _ NA _ DLB 9/18/2018 38 Seabed condition survey.(if Off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA 39 Contact name/phone for weeklyprogress reports [exploratory only] _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ NA . ❑■ Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date ':;–:�S� IU11y � 9
