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218-103
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-611 50103207740000 2181030 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 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 18685'feet None feet true vertical 5222' feet None feet Effective Depth measured 18685'feet 11465', 12338'feet true vertical 5222' feet 4796', 5025' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 12475' MD 5062' TVD Packers and SSSV (type, measured and true vertical depth) 11465' MD 12338' MD N/A 4796' TVD 5025' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3027' 2580' Burst Collapse Production Liner Liner 12573' 6204' Casing 5099' 5222' 12609' 18671' 2988' 119'Conductor Surface Intermediate 20" 10-3/4" 80' measured TVD 7-5/8" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-103 50-103-20774-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025528, ADL0380106, ADL0380107 Kuparuk River Field/ Torok Oil Pool KRU3S-611 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1014 Gas-Mcf MD 160 Size 119' 3247 1027676 0 8260 189 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Premier Packer Packer: Baker Premier Packer SSSV: None Lynn Aleshire lynn.aleshire@conocophillips.com (907) 265-6525Surveillance Reservoir Engineer Hydraulic Frac: 12487- 18628' Hydrarulic Frac: 5065- 5223' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:51 pm, Jul 13, 2023 DTTMSTART JOBTYP SUMMARYOPS 8/2/2022 REPAIR WELL MIRU RIH W / VENTURI JUNK BASKET VENTURI ON TOP OF MOTOR AT SURFACE RECOVERED A O-RING AND SOME PIECES OF PLASTIC. RBIH W / 1.375" TO 1.5" SPEAR BUT UNABLE TO LATCH INNER MANDREL AT 11344' CTMD, RIH W / 1.937" TO 2.062' SPEAR BUT UNABLE TO LATCH INNER MANDREL AT 11344, RIH W / TAPER TAP TO FISH BROKEN MOTOR, JOB IN PROGRESS. 8/3/2022 REPAIR WELL RIH WITH TAPER TAP, DID NOT RECOVER BROKEN MOTOR, RIH WITH VENTURI / RIH W / ITCO SPEAR RUN TEMPRESS SETTING -24 K PULLED HEAVIER COMING OOH HAD A OVER PULL AT 3600' COMING OOH AT SURFACE NO FISH OR BAIT SUB, RIH AND RECOVER BAIT SUB, RE-CONFIGURE BHA TO RUN THE ITCO SPEAR RIGID, JOB IN PROGRESS. 8/27/2022 REPAIR WELL RIH W / MOTOR AND TAPERED MILL AND LIGHTLY MILLED TRYING TO CUT ANY POSSIBLE WIRES 8/28/2022 REPAIR WELL RUN VENTURI DOWN TO TOP OF FISH AT 11,360'. RUN LIMAR SPEAR AND RECOVER ESP MOTOR FROM 11,360'. SHIFT CMU AT 11,418' CLOSED. SET ACP ISO SLEEVE AT 11,365'. START WEEKLY BOP TEST. 8/29/2022 REPAIR WELL PERFORM WEEKLY BOP TEST. CLOSE GAS VENT SLIDING SLEEVE AT 11,313'. WELL READY FOR FCO. RIG DOWN COIL SO THAT DOYON 19 CAN GET ON 3S-21. JOB IN PROGRESS. 9/1/2022 REPAIR WELL DEPLOY 3.78'' CATCHER. PULLED SOV (NOT SHEARED) & SET OV @ 11188' RKB. PULLED DMY @ 3608' RKB & SET GLV. PULLED CATCHER @ 11365' RKB. HAND OVER TO OPS TO BOL. 9/13/2022 ACQUIRE DATA (AC EVAL) TIFL FAILED DUE TO IA PRESSURE INCREASE AND IA FLUID LEVEL INFLOW T POT PASSED. 10/7/2022 REPAIR WELL ATTEMPT TO RUN 4.5" D&D HOLEFINDER W/ SLIP STOP (COULDN'T GET ANY DEEPER THAN 9194' RKB. RUN 4.5" STUBBY HOLEFINDER (COULDN'T GET ANY DEEPER THAN 6134' RKB). IN PROGRESS. 10/8/2022 REPAIR WELL RAN 4.5" D&D HOLEFINDER ON SLIP STOP & TRIPPED THE SLIP STOP TRYING TO GET PAST STATION 2 MANDREL @ 11,187' RKB. ATTEMPT TO TEST TUBING @ 11,133' RKB (NO TEST); TESTED TUBING @ 10,023' RKB (GOOD TEST). RAN HOLEFINDER AGAIN; TESTED TUBING ON TOP OF ISO SLEEVE 11,365' RKB (NO TEST); PICKED UP BELOW STATION 2 MANDREL @ 11,223' RKB (GOOD TEST). READY FOR PLAN FORWARD. 10/11/2022 REPAIR WELL RAN 4.5" GR & LATCHED ACCESS ISO SLEEVE @ 11,365' RKB (PULLING TOOL SHEARED AFTER 1 JAR HIT); RAN 4.5" GS (UNDERSIZED SHEAR PIN), LATCHED ISO SLEEVE @ 11,365' RKB AND JARRED UP FOR 1 HOUR W/ NO MOVEMENT. AFTER TRYING TO SHEAR OFF FOR OVER 2 HOURS (WITH & WITHOUT PUMPING), DISPLACED TBG W/ 200 BBLS OF DIESEL (776) @ 4 BPM WHILE TRYING TO SHEAR OFF AND TOOLS FINALLY CAME FREE (SUSPECT MOTOR SHROUD GUIDES AFFECTING ABILITY TO MANIPULATE TOOLS). IN PROGRESS. 10/13/2022 REPAIR WELL RIH AND LATCH ISOSLEEVE @ 11,356' CTMD(11,365' RKB). PAINT FLAG ON PIPE. PULL 30K OVER, HIT 4 JAR HITS UP AND MOVED UPHOLE 15'. HIT 7 MORE JAR HITS UP AND THEN TEMPRESS UP WITH NO MOVEMENT. CONTINUE JAR HITS UP FOR TOTAL OF 50 HITS. PUMP OFF ISOSLEEVE. CUT 100' OF PIPE. LAY DOWN FOR THE NIGHT. JOB IN PROGRESS. 10/14/2022 REPAIR WELL RIH AND SAT DOWN @ 11,348' CTMD. UNABLE TO LATCH ISOSLEEVE. MAKE MULTIPLE ATTEMPTS UNSUCCESSFULLY. POOH CHECK TOOLS. NO CLEAR INDICATION, TOOL FUNCTIONING PROPERLY. RIH AND LATCH ISOSLEEVE @ 13,350' CTMD. HIT 20 UP AND DOWN JAR HITS, TEMPRESS UP AND DOWN. CONTINUE JARRING WHILE PUMPING 1.5 BPM DOWN THE BACKSIDE OF THE COIL WITH S/D WITH 776. JAR HIT 36, MOVED UPHOLE. ACCESS ESP ISOSLEEVE AT SURFACE. LAY DOWN FOR THE NIGHT. JOB IN PROGRESS. 10/15/2022 REPAIR WELL RIH WITH 4.5" PARAGON RBP. TAG BAKER NO GO AND MAKE DEPTH CORRECTIONS. PULL UP AND SET RBP @ 11,517' RKB (MID-ELEMENT). PUMP BALL DOWN AND SET PACKER. STACK 2.5K DOWN WITH NO MOVEMENT. PERFORM WEEKLY BOP TEST. LRS TO CIRC OUT WELL TONIGHT. LAY DOWN FOR THE NIGHT. JOB IN PROGRESS. 10/15/2022 REPAIR WELL CIRC-OUT PUMPED 390 BBLS OF SEAWATER CONTAINING 164 GALLONS CRW-132 FOLLOWED BY 82 BBLS DIESEL, U-TUBE TBG AND IA TO FREEZE PROTECT AND EQUALIZE. CMIT-TxIA 2500 PSI **PASSED** JOB COMPLETE 10/16/2022 REPAIR WELL RIH AND SET ACCESS ESP ISOSLEEVE @ 11,365' RKB. RIH WITH READ LOGGING TOOLS. IDENTIFIED A POSSIBLE O-RING WEEP. BLED WHP TO 0 PSI AND PULL OUT OF HOLE. LAY DOWN FOR NIGHT. JOB IN PROGRESS. 10/17/2022 REPAIR WELL RIH WITH READ LDL TOOLS TO 11,500' CTMD. ATTEMPT TO ESTABLISH LEAK AND TUBING PRESSURED UP. LRS PRESSURED UP AND PERFORMED PASSING MITT TO 2650 PSI. LAY DOWN FOR NIGHT. JOB IN PROGRESS. 3S-611 Convert ESP to GL Summary of Operations 10/18/2022 REPAIR WELL RIH AND PULL 4-1/2" ACCESS ISOSLEEVE @ 11,365' RKB. POOH L/D SAME. RIH & PULL 4-1/2" PIIP RBP @ 11,512' RKB. POOH L/D RBP & TOOLS. 4-1/2" RBP MISSING 1 ELEMENT. FREEZE PROTECT TUBING. SDFN. JOB IN PROGRESS. 10/19/2022 REPAIR WELL RIH AND SET 4-1/2" ACCESS ESP ISOSLEEVE AT 11,365' RKB. TURN OVER WELL TO DSO TO BRING ONLINE. JOB COMPLETE. 10/22/2022 REPAIR WELL (AC EVAL) RE-TIFL (PASSED) 11/13/2022 ACQUIRE DATA HDF/ PUMPED 140 BBLS OF 180* DIESEL DOWN TBG (JOB COMPLETE) 11/17/2022 MAINTAIN WELL PUMPED 290 BBLS HOT DSL DOWN TBG SHUT DOWN PUMP 5/30/2023 ACQUIRE DATA RUN UP TO 3.77" DRIFTS TO ST# 2 @ 11187' RKB, UNABLE TO WORK TOOLS THROUGH, JOB IN PROGRESS 5/31/2023 ACQUIRE DATA SET SLIP-STOP CATCHER (41"OAL) @ 11360' RKB. JOB IN PROGRESS... 6/1/2023 ACQUIRE DATA PULL AND REPLACE ST# 2 @ 11187' RKB W/ 5/16" OV. PULL AND REPLACE ST# 1 GLV @ 3607' RKB, PULL SLIP-STOP CATCHER @ 11360' RKB JOB IN PROGRESS... 6/2/2023 ACQUIRE DATA DRIFT TO 11380' RKB W/ 2.78" DMMY PATCH DRIFT (OAL= 23') UNABLE TO PASS, DRIFT W/ 3.60" BARBELL (OAL=86") TO TOP OF ISO-SLEEVE @ 11365' RKB READY FOR E-LINE 6/5/2023 ACQUIRE DATA PERFORM DARK VISION TUBING EVALUATION LOG OVER INTERVAL 11395' - 10835. HAD DIFFICULTIES GETTING TO DEPTH. TOOLS HAD TO BE PUMPED AT 5 BPM TO GET STARTED THEN COULD BACK OFF THE RATE TO 2 BPM. JOB COMPLETE 6/13/2023 REPAIR WELL RIH TO PERFORM FILL CLEANOUT, RUN IN DRY AND TAGGED UP AT 16633' CTMD', UNABLE TO MAKE MORE HOLE, CALL FOR A MOTOR/MILL AND LRS TO PUMP DOWN THE BACKSIDE FOR F-N-S FCO, LRS TIED UP WITH RIG JOB, F-N-S DOWN TO 16700' CTMD, JOB IN PROGRESS. 6/14/2023 REPAIR WELL CONTINUE FLUFF-N-STUFF FCO DOWN TO 18350' CTMD, (EST 413' OF RATHOLE BELOW LOWEST FRAC SLEEVE), F/P TBG TO 3500', TURN WELL OVER TO OPS TO BOL, JOB COMPLETE Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: C/O GLV's, Update tag depth 3S-611 6/2/2023 rogerba Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 20 18.50 39.0 119.0 119.0 154.00 X52 SURFACE 10 3/4 9.95 38.8 3,027.3 2,580.2 45.50 L-80 Hydril 563 INTERMEDIATE 7 5/8 6.88 0.0 12,609.0 5,098.9 29.70 L80 H563 PRODUCTION LINER 4 1/2 3.96 12,467.3 18,671.4 5,222.4 12.60 L-80 Hyd 563 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 34.2 Set Depth 12,279.8 Set Depth 5,008.5 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 ID (in) 3.90 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 34.2 34.2 0.00 Gen 5, FMC TC-1A EMS 11.000 Hanger, 4-1/2" x 10-3/4" Gen 5, FMC TC-1A EMS FMC P100023 4399 3.910 3,607.9 2,793.7 75.23 Mandrel GAS LIFT 4.500 Schlumb erger KBMG 3.900 11,187.7 4,725.1 75.21 Mandrel GAS LIFT 4.500 Schlumb erger KBMG 3.900 11,215.1 4,732.1 75.23 Sensor - Discharge Gauge 4.500 SLB Guage Carrier, (w/ SLB guage, tec wire and card) Schlumb erger Single Tubing Gauge Carrier 3.900 11,303.6 4,754.7 75.19 XO 4.500 X-O Pup Joint, 4-1/2", 12.6 ppf, L-80 Hyd-563 Box x Vam Top pin 3.900 11,313.3 4,757.2 75.19 Sleeve - Sliding 5.500 Gas Vent Sliding Sleeve 4-1/2" 12.6#, Vam Top Box x VAM FJL Box. Closed 8/29/22 Access ESP 3.910 11,317.2 4,758.2 75.19 Motor 5.500 Motor Shroud 5-1/2", 23#, L-80, Vam FJL, P x P Motor Centralizer 5-1/2", 23#, VAM FJL B x B Access ESP 3.893 11,335.4 4,762.8 75.20 Motor - Adapter 5.500 Motor Shroud 5-1/2", 23#, L-80, Vam FJL, P x P Motor Centralizer 5-1/2", 23#, VAM FJL B x B Access ESP 3.893 11,359.2 4,768.9 75.21 Motor 5.500 Motor Shroud 5-1/2", 23#, L-80, Vam FJL, P x P Access ESP 4.548 11,365.5 4,770.5 75.21 Annular Connection Port (ACP) 5.950 Annular Connection Port (ACP), 5", 18#, Vam FJL Box x 4-1/2", 12.6#, Vam Top pin Access ESP 3.860 11,389.2 4,776.5 75.22 B Profile Assembly 4.967 B Profile Assembly, 4-1/2", 12.6#, L- 80, VAM Top BxB Access ESP 3.913 11,418.6 4,784.0 75.22 Sleeve - Sliding 4.500 Baker CMU sliding sleeve 3.812" BX. Closed 8/28/22 Baker CMU 3.810 11,446.3 4,791.1 75.20 Valve 4.500 Chemical Injection Valve HALLIBURTON#1108135 3.927 11,465.1 4,795.9 75.19 Packer 7.625 Packer, Baker 4-1/2" x 7-5/8" Premier Baker Premier 3.880 11,490.7 4,802.5 75.17 Nipple - X 4.500 X-nipple 4-1/2"x3.813" Halliburt on X Nipple 3.813 12,272.6 5,006.5 73.97 Locator 6.070 Baker No-Go Baker 3.920 12,273.8 5,006.8 73.97 Overshot 4.500 Non Sealing overshot 4-1/2" tbg x 6.00"OD (Set above Tbg stump) Baker 3.970 12,279.8 5,008.5 73.98 4.500 Top (ftKB) 12,310.0 Set Depth 12,474.9 Set Depth 5,062.2 String Ma 4 1/2 Tubing Description Tubing Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hydril 563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,338.2 5,024.6 74.04 PACKER 6.580 Packer, Baker 4 1/2" x 7 5/8" Premier Baker Comm No.: H784-63 -0018, control # 1064316 05-01, cpai mm# 1149519 3 3.860 12,404.6 5,042.8 74.01 NIPPLE 5.200 Nipple, Camco, 3.75" DB Profile,SN:4053-4 Camco PN: 1017426 46 3.750 12,464.5 5,059.3 74.00 LOCATOR 4.500 Mechanical Locator 4.5" TCII Box (OD 6.40") (large OD above located) Baker Fluted no go w/ shear screws 3.940 12,465.5 5,059.6 74.00 LOCATOR 4.500 Mechanical Locator 4.5" TCII Box (small OD below located) Baker Fluted no go w/ 3.940 Hydraulic Fracture; 16,930.0 Hydraulic Fracture; 16,398.8 Hydraulic Fracture; 15,865.4 Hydraulic Fracture; 15,370.9 Hydraulic Fracture; 14,876.1 Hydraulic Fracture; 14,343.3 Hydraulic Fracture; 13,847.4 Hydraulic Fracture; 13,349.9 Hydraulic Fracture; 12,486.9 INTERMEDIATE; 0.0-12,609.0 NIPPLE; 12,404.6 PACKER; 12,338.2 Tubing ; 11,502.2 Nipple - X; 11,490.7 Tubing - Pup; 11,447.3 Sleeve - Sliding; 11,418.6 Tubing - Pup; 11,402.7 ISO-SLEEVE; 11,365.0 Tubing - Pup; 11,218.8 Tubing - Pup; 11,195.4 Mandrel GAS LIFT; 11,187.7 Tubing - Pup; 11,177.9 Tubing - Pup; 3,615.6 Mandrel GAS LIFT; 3,607.9 Tubing - Pup; 3,598.0 SURFACE; 38.8-3,027.3 CONDUCTOR; 39.0-119.0 Tubing - Pup; 35.0 Gen 5, FMC TC-1A EMS; 34.3 , , , g, 4" GS FN Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,607.9 2,793.7 75.23 1 GAS LIFT GLV BK 1 1,396.0 6/1/2023 Camco KBMG 0.188 11,187.7 4,725.1 75.21 2 GAS LIFT OV BK 1 0.0 6/1/2023 Camco KBMG 0.313 Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 18,606.4 18,628.5 1 Hydraulic Fracture 12/4/2018 207,204.0 202,120.0 2,949.00 3,176.00 17,635.2 18,276.9 2 Hydraulic Fracture 12/4/2018 207,204.0 211,000.0 2,352.00 2,532.00 16,930.0 17,415.8 3 Hydraulic Fracture 12/7/2018 207,204.0 0.0 2,524.00 2,752.00 16,398.8 16,918.3 4 Hydraulic Fracture 12/7/2018 207,204.0 0.0 2,586.00 2,814.00 15,865.4 16,387.2 5 Hydraulic Fracture 12/7/2018 207,204.0 0.0 2,559.00 2,780.00 15,371.0 15,853.7 6 Hydraulic Fracture 12/9/2018 207,204.0 0.0 2,969.00 3,195.00 14,876.1 15,359.3 7 Hydraulic Fracture 12/9/2018 207,204.0 0.0 2,422.00 2,649.00 14,343.3 14,864.4 8 Hydraulic Fracture 12/9/2018 207,204.0 0.0 2,544.00 2,773.00 13,847.4 14,864.4 9 Hydraulic Fracture 12/14/2018 207,204.0 207,348.0 2,712.00 2,936.00 13,349.9 13,835.8 10 Hydraulic Fracture 12/14/2018 207,204.0 213,544.0 2,261.00 2,492.00 12,486.9 13,338.3 11 Hydraulic Fracture 12/14/2018 207,204.0 202,202.0 2,382.00 2,600.00 Hydraulic Fracture; 16,930.0 Hydraulic Fracture; 16,398.8 Hydraulic Fracture; 15,865.4 Hydraulic Fracture; 15,370.9 Hydraulic Fracture; 14,876.1 Hydraulic Fracture; 14,343.3 Hydraulic Fracture; 13,847.4 Hydraulic Fracture; 13,349.9 Hydraulic Fracture; 12,486.9 INTERMEDIATE; 0.0-12,609.0 NIPPLE; 12,404.6 PACKER; 12,338.2 Tubing ; 11,502.2 Nipple - X; 11,490.7 Tubing - Pup; 11,447.3 Sleeve - Sliding; 11,418.6 Tubing - Pup; 11,402.7 ISO-SLEEVE; 11,365.0 Tubing - Pup; 11,218.8 Tubing - Pup; 11,195.4 Mandrel GAS LIFT; 11,187.7 Tubing - Pup; 11,177.9 Tubing - Pup; 3,615.6 Mandrel GAS LIFT; 3,607.9 Tubing - Pup; 3,598.0 SURFACE; 38.8-3,027.3 CONDUCTOR; 39.0-119.0 Tubing - Pup; 35.0 Gen 5, FMC TC-1A EMS; 34.3 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϮϭϴϭϬϯϬ Ͳ^Ğƚ͗ϯϲϮϳϱJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1H-11950029235910000 KRU WLIPROFFINAL FIELD24-Jun-211H-11750029236020000 KRU WLIPROFFINAL FIELD16-Jun-213H-31A50103202050100 KRU WLCUTTERFINAL FIELD31-Jul-213S-61150103207740000 KRU WLCUTTERFINAL FIELD11-Oct-211R-10150029214040300 KRU WLSAMPLINGFINAL FIELD30-Jun-213H-3750103208220000 KRU WLGLSFINAL FIELD29-May-213F-0450029214490000 KRU WLIPROFFINAL FIELD23-Feb-211J-10150029232860000 KRU WLPPROFFINAL FIELD2-Mar-211D-0250029204290000 KRU WLIPROFFINAL FIELD17-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD18-Feb-21MP-150029205730000 KRU WLPERFFINAL FIELD20-Feb-21MP-150029205730000 KRU WLSCMTFINAL FIELD28-Mar-211G-0250029208130000 KRU WLIPROFFINAL FIELD1-Apr-211C-19050029231360000 KRU WLIPROFFINAL FIELD30-Oct-212L-31850103206810000 KRU WLIPROFFINAL FIELD24-Jul-21 ! 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Senden, R. Tyler To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Regg, James B (OGC); Phillips, Ron L Subject:Re: [EXTERNAL]Re: KRU 3S-611 (PTD 218-103) Operational Variance Request for BOP Test Interval, Nabors 7es Date:Friday, November 19, 2021 3:00:16 PM Attachments:image001.png Victoria, Just communicating our current status. The packer is set, the hangar is in and back pressure valve is in and tested. We’ve charted the tubing and IA pressures and are in the process of removing the BOP’s to install the tree. We have not released from the well but wanted to give you a heads up before the weekend. Do you still need me to let you know when we actually release from the well or is this inform sufficient? Thank you! Ty Thanks, Ty From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, November 18, 2021 4:48:59 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]Re: KRU 3S-611 (PTD 218-103) Operational Variance Request for BOP Test Interval, Nabors 7es Approval is granted to complete current work to rig release without the BOP test deadline. Please let us know when the rig is released or if there are additional delays. Thanx, Victoria Sent from my iPhone On Nov 18, 2021, at 3:30 PM, Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> wrote: Victoria and Jim, An update to Ron’s e-mail from this morning. The tubing hanger is installed and aligned. The Rig is optimistic about the progress and are installing the adapter flange. Ron, and I discussed it and, while most likely not needed, I prefer to reach out and request a waiver for the BOP test at midnight. This request is due to the unforeseen alignment issue with the final completion installation due to custom machining of the wellhead equipment that was required for powering the submersible pump in the well. With your concurrence, I want to remove the test deadline from the equation and allow the rig to focus on their current efforts. Thank-you, Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Thursday, November 18, 2021 9:36 AM To: Victoria T Loepp <victoria.loepp@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Inform KRU 3S-611 (PTD 218-103) Victoria, I am sending this email to inform you that last night on KRU 3S-611, we landed the tubing hanger and determined that the holes were drilled improperly so they would not line up with the adapter flange. Also, the ESP cable would not fit through the holes. Below is a picture of the misaligned holes in the tubing hanger. The machine work to fix this problem is being performed on the slope and is being finished up as I am typing this email. If everything goes as planned, we should have the tubing hanger installed, packer set, IA and tubing pressure tested and charted before the BOPE test is due tonight. We wanted to keep you informed and will let you know if further mechanical issues arise that defer rig release today and create a situation where the BOP test interval is not met. Thanks, Ron Phillips From:Hobbs, Greg S To:Loepp, Victoria T (OGC) Cc:Regg, James B (OGC); Senden, R. Tyler; Phillips, Ron L Subject:RE: [EXTERNAL]Re: KRU 3S-611 (PTD 218-103) Operational Variance Request for BOP Test Interval, Nabors 7es Date:Thursday, November 18, 2021 3:50:31 PM Attachments:image001.png Thank-you- Will do! Greg From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, November 18, 2021 3:49 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]Re: KRU 3S-611 (PTD 218-103) Operational Variance Request for BOP Test Interval, Nabors 7es CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Approval is granted to complete current work to rig release without the BOP test deadline. Please let us know when the rig is released or if there are additional delays. Thanx, Victoria Sent from my iPhone On Nov 18, 2021, at 3:30 PM, Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> wrote: Victoria and Jim, An update to Ron’s e-mail from this morning. The tubing hanger is installed and aligned. The Rig is optimistic about the progress and are installing the adapter flange. Ron, and I discussed it and, while most likely not needed, I prefer to reach out and request a waiver for the BOP test at midnight. This request is due to the unforeseen alignment issue with the final completion installation due to custom machining of the wellhead equipment that was required for powering the submersible pump in the well. With your concurrence, I want to remove the test deadline from the equation and allow the rig to focus on their current efforts. Thank-you, Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Thursday, November 18, 2021 9:36 AM To: Victoria T Loepp <victoria.loepp@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Inform KRU 3S-611 (PTD 218-103) Victoria, I am sending this email to inform you that last night on KRU 3S-611, we landed the tubing hanger and determined that the holes were drilled improperly so they would not line up with the adapter flange. Also, the ESP cable would not fit through the holes. Below is a picture of the misaligned holes in the tubing hanger. The machine work to fix this problem is being performed on the slope and is being finished up as I am typing this email. If everything goes as planned, we should have the tubing hanger installed, packer set, IA and tubing pressure tested and charted before the BOPE test is due tonight. We wanted to keep you informed and will let you know if further mechanical issues arise that defer rig release today and create a situation where the BOP test interval is not met. Thanks, Ron Phillips From:Hobbs, Greg S To:Loepp, Victoria T (OGC); Regg, James B (OGC) Cc:Senden, R. Tyler; Phillips, Ron L Subject:KRU 3S-611 (PTD 218-103) Operational Variance Request for BOP Test Interval, Nabors 7es Date:Thursday, November 18, 2021 3:30:56 PM Attachments:image001.png Victoria and Jim, An update to Ron’s e-mail from this morning. The tubing hanger is installed and aligned. The Rig is optimistic about the progress and are installing the adapter flange. Ron, and I discussed it and, while most likely not needed, I prefer to reach out and request a waiver for the BOP test at midnight. This request is due to the unforeseen alignment issue with the final completion installation due to custom machining of the wellhead equipment that was required for powering the submersible pump in the well. With your concurrence, I want to remove the test deadline from the equation and allow the rig to focus on their current efforts. Thank-you, Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Thursday, November 18, 2021 9:36 AM To: Victoria T Loepp <victoria.loepp@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Inform KRU 3S-611 (PTD 218-103) Victoria, I am sending this email to inform you that last night on KRU 3S-611, we landed the tubing hanger and determined that the holes were drilled improperly so they would not line up with the adapter flange. Also, the ESP cable would not fit through the holes. Below is a picture of the misaligned holes in the tubing hanger. The machine work to fix this problem is being performed on the slope and is being finished up as I am typing this email. If everything goes as planned, we should have the tubing hanger installed, packer set, IA and tubing pressure tested and charted before the BOPE test is due tonight. We wanted to keep you informed and will let you know if further mechanical issues arise that defer rig release today and create a situation where the BOP test interval is not met. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From:Phillips, Ron L To:Loepp, Victoria T (OGC) Cc:Senden, R. Tyler; Hobbs, Greg S; NSK RWO CM Subject:Nabors 7ES on well 3G-24 (PTD218-103) Date:Thursday, October 28, 2021 11:17:49 AM Victoria, This morning on Kuparuk well 3G-24, the Nabors 7ES crew thought the mud was foaming up so we closed the annular and checked the drill pipe / casing pressures and they were both zero. We opened the well back up and continued with operations. When we get to surface with our drill pipe we will re-pressure test the Annular. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 Regg, James B (CED) From: Sent: To: Subject: Oops. PTD # is 190-134 Jim Regg Supervisor, Inspections AOGCC 333 W. 7`h Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Regg, James B (CED) Thursday, October 28, 2021 2:18 PM��� Phillips, Ron L RE: Nabors 7ES on well 3G-24 (PTD218-103) From: Regg, James B (CED) Sent: Thursday, October 28, 20212:16 PM To: Phillips, Ron L < Ron. L.Phil Iips@conocophilIips.com> Subject: RE: Nabors 7ES on well 3G-24 (PTD218-103) PTD is 218-134 Jim Regg Supervisor, Inspections AOGCC 333 W. 71" Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Phillips, Ron L <Ron. L. Phillips@conocophiIIiPs.com> Sent: Thursday, October 28, 2021 11:24 AM To: Regg, James B (CED) <iim.reR@alaska. ov> Subject: FW: Nabors 7ES on well 3G-24 (PTD218-103) Jim, I am not sure if I needed to include you or not. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO -06-656 From: Phillips, Ron L Sent: Thursday, October 28, 2021 11:18 AM 1 ,�-r,ixj 5 ins To: Victoria T Loepp <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senders@conocophillips.com>; Hobbs, Greg S (Greg.S.Hobbs(@conocophillips.com) <Greg.S.Hobbs@conocoDhillips.com>; NSK RWO CM <NSKRWO.CM@conocoPhil lips.com> Subject: Nabors 7ES on well 3G-24 (PTD218-103) Victoria, This morning on Kuparuk well 3G-24; the Nabors 7ES crew thought the mud was foaming up so we closed the annular and checked the drill pipe / casing pressures and they were both zero. We opened the well back up and continued with operations. When we get to surface with our drill pipe we will re -pressure test the Annular. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO -06-656 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: ? t� P. 1. Supry BOPE Test Report for: KUPARUK RIV UNIT 35-611 ✓ Comm Contractor/Rig No.: Nabors 7ES _ PTD#: 2181030 ' DATE: 11/4/2021 ' Inspector Jeff Jones - Insp Source Operator: ConocoPhillips Alaska, Inc. Operator Rep: L. Toussant / M. Adams Rig Rep: T. Morales/ N. Wheeler Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopJJ211115132006 Type Test: INIT 321-469 ✓ Rams: An Valves: MASP: 250/3000 " 250/2500 - 250/3000 - 1539 . Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly I - P/F lower Kelly Visual Alarm Time/Pressure P/F Location Gen.: P- - Trip Tank P P System Pressure 2900 P_ - Housekeeping: P Pit Level Indicators P - FP Pressure After Closure 1500 P ' PTD On Location P Flow Indicator P P 200 PSI Attained 17 P Standing Order Posted -_P-- Meth Gas Detector P P Full Pressure Attained 113 P ' Well Sign P - H2S Gas Detector P P Blind Switch Covers: all P ' Drl. Rig _P_" MS Misc NA NA_ Nitgn. Bottles (avg): 5(&_2080- P• Hazard Sec. P - Check Valve _ _ 0 ACC Misc _ 0 NA Misc NA NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly I - P- lower Kelly 1 P - Ball Type - - 1 P - Inside BOP 1 P - FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 16 P Annular Preventer 1- 135/8 - P Manual Chokes 1 P #1 Rams - 1 2 7/8 x 5 P Hydraulic Chokes — 1 P" #2 Rams 1 Blind P CH Misc 0 NA #3 Rams 1 ' 3.5 x 5.5 P - #4 Rams 0 NA #5 Rams ------- _ _ _ 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 -31/8 - P ' Quantity PIF HCR Valves 1 . 31/8 P Inside Reel Valves 0 NA Kill Line Valves 1 - 3 1/8 - 2 - P Check Valve _ _ 0 NA BOP Misc 0 NA Number of Failures: Iv Test Results Test Time 6 Remarks: Nabors 7ES personnel performed the tests today in a safe and proficient manner with one failure observed. The audible alarm for the PVT system "gain/loss" failed to operate property and was repaired and passed a retest. . Th -gas detection system was tested and operated properly. The rig and surrounding location appeared clean an or . annular: 28 sec. UPR: 5 sec. Blind: 5 sec. LPR: 5 sec. HCRK: 2 sec. HCRC: 2 sec. z/ ! " # $! % " &&&&&&&&&&&&&&&&&&& ' $ (" " ) *$ +,*# - #./$ 0/ 1 $ $ " # # ! 2 3 ,2 4 $ 5* 67 $ 8936 8 * :*6 8 * ;*6 8 + #* :* + #* ;* : 6 8 6:*8< =6:*8 1>.1)?)'''?1>.0?)'''?)-5 $$ " / 7 = ;= ;:*6 8;*6 8 @= (%3'A,0%)31A='>--1?:*?3)9')?;* ' - " != * @ = +, *# # (+ * ) != " /7 /$< * 7 .;#*B B B 7CB " #B/$< ! "$ +"+ " 590%'.)%.-' * " #$ " # ! $ /@ : / 7" //D:/ ?24 $ +, 24 $ ;+*@4 # " ::/ / $+ E+" ::/ / $ * " " + B + 7 F G$ B :*6 8 + 7 H 7 H /7$*B " $ + ;/ $" ::/ / $ '9"')'19 *7-1990>*7-199.>*79'))'1 '1%9- @,99-.9> >H55)9 )9%9-%'900(%99 " =>/ H C- %. H = #3= !" '>(0)? 5? ')19? 5? -9'0? )955?'>.95? '9A>)(I 9-3(A>())I 19? '511? # ->95-?%1>..? '>)0-? (%3'A>'.I # )''?%)'19? * ;*6 8 G 0%)31A>'50I G 0/ # ! # ! !# G 9313'9' 1>.0?.'9(? (%3'A>'.I )'''? * :*6 8 7%19 9%(9- # -3'9'9 "# $ % #$ &" '( ) &") $ & "#* By Meredith Guhl at 12:49 pm, Sep 13, 2021 321-469 Ron Phillips Digitally signed by Ron Phillips Date: 2021.09.10 10:46:43 -08'00' X DSR-9/13/21 DLB 09/13/2021 -00 DLB 10-404 VTL 10/4/21 X BOP test to 3000 psig Annular preventer to 2500 psig X dts 10/4/2021 JLC 10/4/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.04 13:23:04 -08'00' RBDMS HEW 10/7/2021 !""! # $ % &$"'$ &$"'$!&($" #" )$! # !""! # *"+, )#--! #., $/ &$"'$ 0$ !""! # 1 #,!&&!" #! *&&"#/!# 20 !&&!#/$#3*&&" # . ,!&&!" &$"'$2#., 4"- !"$# &!.$! #% -#3 4 )$& 5 ' ) 62#7. 890: ; < *&& 5$"3 !&&3!# ; 40 4 #= $#3. &3$"$, !> #$&$& #$!#/"5&&$.' $#3% $."&) . &! #!#,9 '% $! # 2%4 -,$)$#4?-"! #" ?-! $#4%- , !#% $! #&$". #$. $ 9, "35 ' ) ". % 5!&&!#.&-3-&&!#/,=@ A/$"&!%. &! #$#3!#"$&&!#/$# !#. $" 3-.! # Ron Phillips Digitally signed by Ron Phillips Date: 2021.09.10 10:47:23 -08'00' VTL 10/4/21 Producer !"# $ %!&" %%'()*&+,-. *"%"%! /+0 (1 +# 2 " 3."4 3." 3. +5 6" " 4 78 7 2 6"&" ! 2 "! 3 )%& 5& %"3 90 .- #$ 0+:2 4; 4 0 7 % .. + < + . %1 !'+ . ## = < . > ?/ 1 < < 4 ( " +3@A * 5& 4 ( %3 5 82# 1 ##2 " . !5. 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F . 1 !!! > ! !!!# !. % !!# !. %0 # . 1 7( ## 4 ( ?A47 A@ 4 (1# G 1 4 ( &3+7 #$ 3 )- # #= % 4 ( 3@ > 8 1 0+@1 . . ?; ## > !"#$% &'() *(+ , -./0* + 1 !!!234%!!23&!2/$ 4% 54 ! 13 !5/$ / 6 !& %% ! 1&3!42/$ ! % 7% 152/$ ! 89 1 3 4/$ . : ,4% : 13&& 2/$ . : ,4% : 13%%2/$ : *(13&52/$3 * ; <=:;:1 3 2/$ > / 1 3 2 . /?= * & .7134!2 = . * (* 1 3&42 7 >() 13%&2 6/0 % '.0 * . * 13&!2 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:3S-611 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: New Well 11/21/2018 3S-611 jennalt Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.50 Top (ftKB) 39.0 Set Depth (ftKB) 119.0 Set Depth (TVD) … 119.0 Wt/Len (l… 154.00 Grade X52 Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 38.8 Set Depth (ftKB) 3,027.3 Set Depth (TVD) … 2,580.2 Wt/Len (l… 45.50 Grade L-80 Top Thread Hydril 563 Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 0.0 Set Depth (ftKB) 12,609.0 Set Depth (TVD) … 5,098.9 Wt/Len (l… 29.70 Grade L80 Top Thread H563 Casing Description PRODUCTION LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 12,467.3 Set Depth (ftKB) 18,671.4 Set Depth (TVD) … 5,222.4 Wt/Len (l… 12.60 Grade L-80 Top Thread Hyd 563 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,467.3 5,060.1 74.01 PACKER Liner Top Packer, 5.5 X 7.63", HRDE ZXP, w/10' Seal Bore Extension 4.820 12,486.9 5,065.5 74.03 NIPPLE RS Nipple, 5-1/2", Hyd563 4.250 12,489.2 5,066.2 74.03 HANGER Liner Hanger, FL pinned 1706 psi 4.800 12,508.2 5,071.4 74.06 SBE Sealbore 80-40 x 20', 5" Hyd 521 Pin up x 4.5" Hyd 521 box down 4.000 12,839.3 5,157.0 75.43 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-11) A 3.890 13,092.9 5,220.6 75.48 FRAC SLEEVE Baker frac sleeve (2.695" ball) #10, HYD563 CN (H810-09-0315 Old# FPSC-310) 10 2.665 13,338.3 5,272.2 83.46 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-3) B 3.880 13,587.8 5,280.1 90.47 Frac Sleeve Baker frac sleeve (2.645" ball) #9, HYD563 CN (10437070 Old# FPSC-217) 9 2.605 13,835.8 5,274.3 91.67 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-13) C 3.890 14,086.1 5,268.1 91.75 Frac Sleeve Baker frac sleeve (2.595" ball) #8, HYD563 CN (H810 -09-0420 Old# FPSC-1976) 8 2.555 14,331.6 5,261.0 91.67 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-2) D 3.890 14,582.8 5,253.6 90.87 FRAC SLEEVE Baker frac sleeve (2.545" ball) #7, HYD563 CN (H810 -09-0333 Old# FPSC-328) 7 2.505 14,864.4 5,248.3 91.81 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-5) E 3.900 15,113.8 5,241.5 91.93 Frac Sleeve Baker frac sleeve (2.495" ball) #6, HYD563 CN (10437089 Old# FPSC-226) 6 2.465 15,359.3 5,234.9 91.15 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-7) F 3.890 15,609.4 5,233.7 89.44 FRAC SLEEVE Baker frac sleeve (2.455" ball) #5, HYD563 CN (H810090419 Old# FPSC-1975) 5 2.425 15,853.7 5,240.0 88.45 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-1) G 3.900 16,141.8 5,250.4 86.90 FRAC SLEEVE Baker frac sleeve (2.415" ball) #4, HYD563 CN (10437089 Old# FPSC-1810) 4 2.385 16,387.2 5,260.4 91.01 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-6) H 3.900 16,635.7 5,255.2 91.21 FRAC SLEEVE Baker frac sleeve (2.375" ball) #3, HYD563 CN (10402828 Old# FPSC-1976) 3 2.345 16,918.3 5,249.6 91.20 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-4) I 3.910 17,169.1 5,244.7 91.05 FRAC SLEEVE Baker frac sleeve (2.335" ball) #2, HYD563 CN (10437059 Old# FPSC #1810) 2 2.305 17,415.8 5,239.5 91.07 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-10) J 3.900 17,623.5 5,235.3 91.22 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-8) K 3.900 17,952.5 5,231.4 90.64 FRAC SLEEVE Baker frac sleeve (2.295" ball) #1, HYD563 CN (A- 42878) 1 2.265 18,276.9 5,227.4 90.52 SWELL PACKER PACKER,SWELL,4 1/2 X 6.00",BAKER,HYD563 SN (002142-001-9) L 3.900 18,602.7 5,223.4 90.84 FRAC SLEEVE Alpha Pressure Sleeve, rupture disc #14 (7300 psi low, 7900 psi high, 7613 nom psi) 3.000 18,616.3 5,223.2 90.86 FRAC SLEEVE Wellbore Isolation Valve Bball OD 1-1/4 -->1/3/4", 990 psi shear 0.000 Tubing Strings Tubing Description TUBING PRODUCTION String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 34.3 Set Depth (ft… 12,474.9 Set Depth (TVD) (… 5,062.2 Wt (lb/ft) 12.60 Grade L-80 Top Connection Hydril 563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 34.3 34.3 0.00 HANGER Hanger, 4-1/2" x 10-3/4" Gen 5, FMC TC-1A EMS 3.920 1,974.1 1,869.6 32.57 NIPPLE Nipple, Camco, 3.813" DB Profile, SN:3654-8 (32° hole angle) 3.813 12,276.0 5,007.4 73.97 GAUGE Gauge Carrier, SLB, SGM with Sapphire tubing pressure gauge, SN:C15GM-0002 3.864 12,338.2 5,024.6 74.04 PACKER Packer, Baker 4 1/2" x 7 5/8" Premier 3.860 12,404.6 5,042.8 74.01 NIPPLE Nipple, Camco, 3.75" DB Profile,SN:4053-4 (dual flapper plug installed) 3.750 12,464.5 5,059.3 74.00 LOCATOR Mechanical Locator 4.5" TCII Box (OD 6.40") (large OD above located) 3.940 12,465.5 5,059.6 74.00 LOCATOR Mechanical Locator 4.5" TCII Box (small OD below located) 3.940 Comment SSSV: NIPPLE 3S-611, 11/21/2018 8:34:05 AM Vertical schematic (actual) PRODUCTION LINER; 12,467.3 -18,671.4 Annular Fluid - Saltwater/Brine; 12,467.0-18,671.0 INTERMEDIATE; 0.0-12,609.0 MULE SHOE; 12,473.9 LOCATOR; 12,465.5 LOCATOR; 12,464.5 NIPPLE; 12,404.6 PACKER; 12,338.2 GAUGE; 12,276.0 Annular Fluid - Corrosion inhib brine; 11,869.0-12,467.0 GAS LIFT; 11,869.4 Annular Fluid - Saltwater/Brine; 2,174.0-11,869.0 GAS LIFT; 3,620.6 SURFACE; 38.8-3,027.3 NIPPLE; 1,974.1 Annular Fluid - Diesel; 0.0- 2,174.0 CONDUCTOR; 39.0-119.0 HANGER; 34.3 KUP PROD KB-Grd (ft) 39.14 Rig Release Date 10/23/2018 Annotation LAST WO: End Date 3S-611 H2S (ppm) Date... TD Act Btm (ftKB) 18,685.0 Well Attributes Field Name TRACT OPERATION MORTR04 Wellbore API/UWI 501032077400 Wellbore Status PROD Max Angle & MD Incl (°) 92.31 MD (ftKB) 14,471.48 WELLNAME WELLBORE3S-611 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 Permit to (hill 2181030 MD 18685 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Well Name/No. KUPARUK RIV UNIT 35-611 DGt1• Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20774-00-00 TVD 5222 Completion Date 10/23/2018 Completion Status 1-0I1. CurrentStatus 1-0I1 UIC No REQUIRED INFORMATION 611—VISION Mud Log No ✓ Samples Np✓ C Directional Survey Yes ✓ DATA INFORMATION Electronic File: CPAI 3S-611 VISION List of Logs Obtained: GR/Res/Microscope/Sonic Scope Resistivity_LW D001_RM_DLIS.dlis (from Master Well Data/Logs) Well Log Information: 30D94 Digital Data 12/11/2018 Electronic File: CPAI-3S-611 VISION Log/ Electr Data Digital Dataset Log Log Run Interval OHI C 30094 Digital Data Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30094 Digital Data _ 30 3034 12/11/2018 Electronic Data Set, Filename: CPAI _3S- C 30094 Digital Data 12/11/2018 611_VISION Resistivity_LWD001_RM.las ED C 30094 Digital Data 3000 12620 12/11/2018 Electronic Data Set, Filename: CPAI _3S- Resistivity_LW D002_RM_DLIS. html ED C 611_VISION Resistivity_LW0002_RM.las ED C 30094 Digital Data 12450 18684 12/11/2018 Electronic Data Set, Filename: CPAI 3S- Resistivity_LW D003_RM_DLI S.dlis 611—VISION Resistivity_LWD003_RM.las ED C 30094 Digital Data 34 18684 12/11/2018 Electronic Data Set, Filename: CPAI 3S- S- AOGCC Page 1 of 4 Monday, February 25, 2019 611_VISIONResistivity_RM.las ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI 3S-611 VISION Resistivity_LW D001_RM_DLIS.dlis ED C 30D94 Digital Data 12/11/2018 Electronic File: CPAI-3S-611 VISION Resistivity_LW D001_RM_DLIS.html ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI_3S-611 VISION Resistivity_LW D002_RM_DLIS.dlis ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI 3S-611 VISION Resistivity_LW D002_RM_DLIS. html ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI _3S-611_VISION Resistivity_LW D003_RM_DLI S.dlis ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI 3S-611 VISION Resistivity_LW D003_RM_DLI S.html ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611 _VIS ION_Resistivity_RM_DLIS.dlis ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI 3S- 611 _VIS ION_ Resistivity_RM_DL I S.html ED C 30094 Digital Data 12/11/2018 Electronic File: CPAI-3S- 611—VIS ION_Resistivity_2MD_RM.Pdf AOGCC Page 1 of 4 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181030 Well Name/No. KUPARUK RIV UNIT 3S-611 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20774-00-00 MD 18685 TVD 5222 ED C 30094 Digital Data ED C 30094 Digital Data ED C 30094 Digital Data ED C 30094 Digital Data ED C 30094 Digital Data ED C 30094 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C Log C Log C ED C AOGCC 30094 Digital Data 30094 Digital Data 30094 Digital Data 30094 Digital Data Completion Date 10/23/2018 Completion Status 1 -OIL 30094 Digital Data 30094 Digital Data 30094 Digital Data 30094 Digital Data 30094 Digital Data 30094 Log Header Scans 30095 Log Header Scans 30095 Digital Data Page 2 of 4 0 0 0 0 30 3034 Current Status 1 -OIL UIC No 12/11/2018 Electronic File: CPAI_3S- 611 _VISION_Resistivity_2TVD_RM.Pdf 12/11/2018 Electronic File: CPAI_3S- 611_VISION_Resistivity_5MD_RM. pdf 12/11/2018 Electronic File: CPAI_3S- 611 _VIS ION_Resistivity_5TVD_RM. Pdf 12/11/2018 Electronic File: CPAI_3S-611 1381GYRO SURVEYS.xlsx 12/11/2018 Electronic File: 3S-611 NAD27 EOW Compass Surveys [Canvas].bd 12/11/2018 Electronic File: 3S-611 NAD27 EOW Compass Surveys [Macro].txt 12/11/2018 Electronic File: 3S-611 NAD27 EOW Compass Surveys [Petrel].txt 12/11/2018 Electronic File: 3S-611 NAD27 EOW Compass Surveys [Surveys].txt 12/11/2018 Electronic File: 35-611 NAD27 EOW Compass Surveys.pdf 12/11/2018 Electronic File: 3S-611 NAD83 EOW Compass Surveys [Canvas].txt 12/11/2018 Electronic File: 3S-611 NAD83I Compass Surveys [Macro].txt 12/11/2018 Electronic File: 3S-611 NA083 EOW Compass Surveys [Petrel].txt 12/11/2018 Electronic File: 3S-611 NAD83 EOW Compass Surveys [Surveys].txt 12/11/2018 Electronic File: 3S-611 NAD83 EOW Compass Surveys.pdf 12/11/2018 Electronic File: CPAI_3S- 611_PrintSurveyList_FINAL SURVEYS.csv 2181030 KUPARUK RIV UNIT 3S-611 LOG HEADERS 2181030 KUPARUK RIV UNIT 3S-611 PB1 LOG HEADERS 12/11/2018 Electronic Data Set, Filename: CPAI_3S- 611 PB1_VISION_Resistivity_LW D001_RM.las Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/2512019 Permit to Drill 2181030 Well Name/No. KUPARUK RIV UNIT 3S-611 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20774-00-00 MD 18685 TVD 5222 Completion Date 10/23/2018 Completion Status 1-011- Current Status 1-0I1- UIC No ED C 30095 Digital Data 30 3034 12/11/2018 Electronic Data Set, Filename: CPAI 3S- —7 611PB1_VISION_Resistivity_RM.las ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI 3S- 611 PB1_VISION_Resistivity_LW D001_RM_OLIS Alis ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI 3S- 611 PB1_VISION_Resistivity_LW D001_RM_DLIS .html ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611 PB1_VISION_Resistivity_RM_DLIS.dlis ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611 PB1_VISION_Resistivity_RM_DLIS.html ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611 PB1_VISION_Resistivity_2MD_RM.pdf ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611 PB1_VISION_Resistivity_2TVD_RM.pdf ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611PB1_VISION _ Resistivity_5MD_RM.pdf ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611 PB t_VISION_Resistivity_5TVD_RM.pdf ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S-611PB1_GYRO SURVEYS.xlsx ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD27 EOW Compass Surveys [Canvas].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD27 EOW Compass Surveys [Macro].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-61112131 NAD27 EOW Compass Surveys [Petrel].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD27 EOW Compass Surveys [Surveys].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD27 EOW Compass Surveys.pdf ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 P51 NAD83 EOW Compass Surveys [Canvas].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD83 EOW Compass Surveys [Macro].bd AOGCC Page 3 of 4 Monday, February 25, 2019 DATA SUBMITTAL COMPLIANCE REPORT 2/25/2019 Permit to Drill 2181030 Well Name/No. KUPARUK RIV UNIT 3S-611 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20774-00-00 MD 18685 TVD 5222 Completion Date 10/23/2018 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD83 EOW Compass Surveys [Petrel].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD83 EOW Compass Surveys [Surveys].txt ED C 30095 Digital Data 12/11/2018 Electronic File: 3S-611 PB1 NAD83 EOW Compass Surveys.pdf ED C 30095 Digital Data 12/11/2018 Electronic File: CPAI_3S- 611PB1_PrintSurveyList_FINAL SURVEYS.csv Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVEDr Completion Report) Directional / Inclination Data L.% Mud Logs, Image Files, Digital Data Y / 1�A Core Chips Y /pVA Production Test Information Y NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files if Core Photographs Y NSA Geologic Markers/Tops 'O Daily Operations Summary V Cuttings Samples Y /(A Laboratory Analyses Y COMPLIANCE HISTORY Completion Date: 10/23/2018 Release Date: 9/6/2018 Description Date Comments Comments: Compliance Reviewed By: Date: AOGCC Page 4 of 4 Monday, February 25, 2019 STATE OF ALASKA ALASi JIL AND GAS CONSERVATION COMMISS...d REPORT OF SUNDRY WELL OPERATIONS 1� 5 • 1. ( ] _ k JAN 14 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Pull Tubing ❑ ❑ ,f�@n )y Performed: Suspend ❑ Perforate E] Other Stimulate E] Alter Casing ❑ Chang- e Approve g ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 218-103-0 3. Address: P. O. Box 100360, Anchorage, Stratigraphic❑ Service ❑ 6. API Number: Alaska 99510 50-103-20774-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380107, ADL 380106, ADL 25528 KRU 3S-611 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A - Submitted w/10-403 Kuparuk River Field, Torok Oil Pool 11. Present Well Condition Summary: Total Depth measured 18,685 feet Plugs measured 3656 feet true vertical 5,222 feet Junk measured None feet Effective Depth measured 18,671 feet Packer measured 12,338 feet true vertical 5,222 feet true vertical 5,025 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 20 119' MD 119' TVD SURFACE 2,989 feet 10 3/4 " 3,027' MD 3,027' TVD INTERMEDIATE 12,609 feet 7 5/8 " 12,609' MD 12,609' TVD PRODUCTION 6,204 feet 4 1/2 " 18,671' MD 18,671' TVD Perforation depth:/FRAC SLEEVES Measured depth: 13093 -13095,13588 -13590,14086 -14088,1458&14585,15114 -15116,15609-15612,1614216144,16636-16638, 17169-17171,17952-17955,18602-18606,18616-18619 True Vertical depth: feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 12,474' MD 5,062' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - PACKER, BAKER PREMIER 12,338' MD 5,025' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 18602-13093 Treatment descriptions including volumes used and final pressure: Total Well - 11 stages 2.2 million Ibs20140 proppant placed ....see attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing PTubing Pressure ressure Prior to well operation: N1A _ Subsequent to operation: N/A 14. Attachments (required per 20 AAC 25.070, 25.071, 4 25.283) 1 15. Well Class after work: Daily Report of Well Operations 4 A-01 5 �1�.I Exploratory El Development Q Service ElStratigraphic E]Copies 16. Well Status after work: Oil Q Gas E]WDSPL ❑ of Logs and Surveys Run 1:1 l Printed and Electronic Fracture Stimulation Data Lyl GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-488 Contact Name: Hanna Sylte Authorized Name: Hanna S Ite Contact Email: Hanna.Sylte@cop.com .Authorized Tile: Completion Engineer Authorizetl Signature: "XI Date: 1 L1 ZU I Contact Phone: 907 265-6342 rA / � /i . r , `'b"' V�)w 415 /bi I °I RBDMS3v JAN 15 2019 Form 10-404 Revised 4/2017 g , 21J-111 Submit Original Only 3S-611 FRAC STIMULATE DTTM JOBTYP SUMMARYOPS START 12/2/18 DRILLING Performed data frac as designed. Encountered a number of problems including gel SUPPORT- quaility issues preventing us with continuing with frac. Well freeze protected with 30 CAPITAL bbls LVT. Will resume in A.M. 12/4/18 DRILLING Performed mini -frac and stages 1 & 2 of frac per design @ 40-45 bpm (ran short of SUPPORT- sand during 6 ppa stage so unable to achieve 7 ppa during stage #2). 428,123# of CAPITAL 20/40 placed (209,872 in stage #1 and 218,251 in stage #2). Well freeze protected with 30 bbls of LVT. In Progress. 12/7/18 DRILLING Performed fracture stimulation treatment on intervals 3, 4, and 5 per design, SUPPORT- ramping from 1-7 ppa stages using 30# Hybor-G fluid system @ 40-43 bpm. Had CAPITAL difficulties achieving stable sand concentrations primarily on 4 to7 ppa stages due to clumping of frozen proppant in the hopper. Placed total 625,852 of proppant (Stage #3: 210,917, Stage #4: 210,375, Stage #5 204,560). Well freeze protected with 30 bbls of LVT. In Progress. Note: Will attach treating report when available. 12/9/18 DRILLING Performed fracture stimulation treatment on intervals 6, 7, and 8 per design, SUPPORT- ramping from 1-5 ppa stages using 30# Hybor-G fluid system @ 43-55 bpm. Had CAPITAL difficulties achieving stable sand concentrations again again Burring 5 ppa stage due to clumping of frozen proppant in the hopper, unable achieve stable 6-7 ppa concentratration so stayed @ 5 ppa and extended. Placed total 631062# of proppant (Stage #6: 209,100, Stage #7: 210,022, Stage #8 211,940). Well freeze protected with 30 bbls of LVT. In Progress. Note: Will attach treating report when available. 12/14/18 DRILLING Performed fracture stimulation treatment on intervals 9, 10, and 11 per design, SUPPORT- ramping from 1-7 ppa stages using 30# Hybor-G fluid system @ 43-55 bpm. Placed CAPITAL total 622794# of proppant (Stage #9: 199,115, Stage #10: 206,075, Stage #11 202,202). Well freeze protected with 30 bbls of LVT. 1/3/19 DRILLING LOCATE GLM @ 3621'RKB & FLAG WIRE. SET RBP w/ MID ELEMENT @ SUPPORT- 3656'RKB. MULTIPLE FAILED MIT -T'S. TBG APPEARS TO BE STABALIZING CAPITAL FROM THE WARM FLUID THAT WAS PUMPED. LEAVE LRS NIGHT CREW TO CONTINUE TESTING. IN PROGRESS. 1/3/19 DRILLING MIT -TUBING TO 3000 PSI (PASSED) SUPPORT- DDT -TUBING AND IA (PASSED) CAPITAL JOB COMPLETE Conoco`Phillips Alaska. II KUP PRC- WELLNAME 3S-611 WELLBORE 3S-611 NIPPLE .1.11 rm+ealna PM I Last Tag valval xlwreCc (( I Annalalion DepmtnKIB I Enc Dmo I wellWre Last MW By ..................._................__ ....................... ......... LAST A. 35-fi11 Ilempalft Last Rev Reason ACJOBn en, mw walm"' Leal Mae By Rev Reason: SET GLV(#1)BFRAC JOB 1I14I2019 35-fi11 proven 10 Casing Strings Casing Description ODpnj ID(in) Tap l•tej ale BehM like) Sed Daps mD)... WIILen (l_. Gmv. Tap Trivial......7oRa 9una0 CONDU CTOR 20 18.50 39.0 1190 1190 15400 X52 MrYm DUE-Owt n6 Cables Dommigion OD (in) IDpn) T.,MBj Set Depth INKS) SN Depth Tiger Nolum ll.. 0a0e Top TMeW ?+Tao SURFACE 10314 9.95 38.8 3,027.3 2,580.2 45.50 L60 Hyip 583 MPPLE:191 Gsles Dexrlption ODlinl ID fnj Tep (lma) Set Depth 98(61 SM (1 VI when ll._ Grave Tap TMeae INTERMEDIATE 7518 6.88 00 12,609.0 5,098.9 2931 L80 11563 Cash, Description DD (in) ID lin) Tap9IXe) Set Depth 9H(S) Stl Depth (nOL.. WSLen 9... GrYe iap Tbeatl s FACE:ae.o-3.Dn3 PRODUCTION LINER 4112 396 12,467.3 18,fiJ1.4 5,222.4 12.60 L-80 Ny0563 uner D4ltalls W6UFT:a,6A.a theaterDeal0 Barrie-Rammtla Bloke Fee.aan Top 9Nl9) Tap mo)(Me) Tap lnel P) tem Des Nominal ID Co. 9q 12,467.3 5,060.1 74.01 PACKER Liner op ac e r, . DE XP,w1104.820 mne. Rua -Si.- Seal Bore Extension z.nao-n.mao 12,486.9 5,0865 74.03 NIPPLE RS Nipple, S12", 1-1 4.250 w -exam nAfiB4 mmavam 1 ,489. 5,066.2 74.03 HANGER Liner Hanger, FL pinned 1706 psi 48(10 ake0-12,070 IM: 1veW o-1?sa)o GAVGep?neo 12508.2 5,0714 74.08 SBE Ibore x -y In upx4. "Nytl 4.000 521 box Sown PACKER,?siez 128393 5.157.0 75.43 SWELL PA K R, W L 1 ,H 5 3SN 3.890 PACKER (002142-001-1HA NIPPLE:I?4Me 13.0929 5,220.6 75.48 FRAC SLEEVE Baker frac sleeve S? 5"1#10, HYD2,665 (11810-09-0315 Old# FPSC-310)10 LOCATOR 12.x&.5 LOCATOR 120856 13,3383 5,2722 83.46 SWELL PACKER PACKER,SWELL,4112 X 6. ", BAKER ,HYD5 N 3880 (002142-001-3)B Mute SHOE: 12 A7.e 13.587 8 5280.1 90.47 Frac Sleeve Baker hoc sleeve (2645"ba10#5 HYD563 N 2605 (10437070 Old# FPSC-217) 9 13.8358 5,274. 9167 SWELL PACKERSWELL412 X SONY BAKER.HYD563 SN 3890 PACKER (002142-001-13)C INTEflMEIXAlE:06t?N3.0 14,086.1 5268.1 1.75 Frac Sleeve Baker frac sleeve .95"ba10#l, HYD56 N 2555 (11810-091 OM# FPSC-1976) 8 14,331.6 5,2610 9167 MEL PACKER, SWELL,412XSW'BAKER,HYD N 3890 PACKER (002142-001-2)D HAMom Fr M. 13me • • 14,582.8 5253.6 9087 FRAC SLEEVE Baker frac sleeve(2.545"ball) #7, HYD563 N 2505 (11810-09-0333 DItl# FPSC X?IB J 14,8644 5.2483 91.81 SWELL PACKER,SWELL,41I2X609;BAKER,HYD N 3900 PACKER (002142-001-5)E Hyemuta Fx M: Isse[0 a • 15,113.8 52415 91.W Free Sleeve Baker I. sleeve(2495"ball) N6 HYD563 714 2065 (10,13708901tl# FPSC-226) 6 15,359.3 5.2349 91.15A L, 112X60P',BAKER,HYD SN 3890 PACKER (002142-001-7) F Hyemutc Freemm:loaea.o • 15,6094 5,233] 89A4 FRAC SLEEVE akar roe sleeve 5 ball)#5,11 6563 CN 2.425 (Ha 0090419 010# FPSC-1975) 5 15,853.7 5.2400 88.45 MEL PACKER,SwI 12X 600';BAKER,HYD563 SN 3900 PACKER (002142-001-1)G 16,141.8 5.2504 86.M FRAC SLEEVE Baker [me seeve(241S ball) as, HYD563 CN 2.305 Hyermum Fmowm; troor 0 ' 1 (10437089010#FPSC-1810)4 16,3872 5,2600 91.01 SWELL PACKESESVI 112 X800';BAKER,HYDS N 3.90D PACKER (002142-0016) H 16,6357 5,2552 91.21 FRAC SLEEVE Baker [me sleeve (237F ball) #3, HYD9B9 N 2.345 (10402828 Old# FPSC-1976) 3 .Apsee Ines :15.11.0 re a 16,916.3 5,2496 91,20 MEL= AGKER,6WELL,d 12X600';BAKER,HYD53 SIN 3.910 PACKER (002142-001-0f1 sale 17,1691 5,2447 91.05 FRAC-SLEEVE Baker rbc seeve(2. " ball) 41 HYD563 N 2.305 "nnuh'P°i4IZ en 1B� o (1043705901tlN FPSC#1810)2 .Arm. Flxeae: +aall ' 1 17,4158 5,2395 91.07 SWELL PACKER,SWELL,4 IQ X 600",BAKER,HYD5N 3900 PACKER (002142-001-10)J 17.623.5 5,235.3 91.22 LL PACKER,SWELL,4112 X 6 00"RAKER HYD5UTN 3.900 PACKER (002142-001-8) K Hymamio Frcere: tm410 1 17,952.5 5,2314 90.64 FRAC SLEEVE Bakerfree sleeve (2295" ball) #1, HYD563 PH(A-2265 42878)1 18,2769 5,2274 90.52 SWELL 7ACKER,SWELL,4112 X 600'; BAKER HYD563 N 3.900 PACKER (002142-001-9)L 10.6027 52234 90.84 FRAC SLEEVE Alpha Pressure Sleeve, wNpeisc#14(J psi 3000 pe4 Hs A.,, In.. , , Ow, 7900 psi high, 7613 nom psi) 18.616.3 5223.2 9066 FRAC SLE EVE We1lbe,. laolBtier Valve Bball D1-1 -111I", 0.000 990 pershear Tubing Strings Tubing D le"Imon Smne Mz TUBING 4112 m lin !3 SIS Top (ime) Set 34.3 12,474.9 Depth In.. set Depth mD) L.. 5,0622 wt 96th) 12.60 Grave L-80 Topco-NUUon Hy@i 563 Himea it Fracture: lZ1W.0 , PRODUCTION Completion Details TOPmm Phlnct Nominal Top lime) UNS) f) I Iem Da Com ID lin) 34.3 34.3 0,00 HANGER Hanged 4-11T x 10-314" Can 5, FMC TC -1A EMS 3.020 1,974.1 1,869.6 32.57 NIPPLE Nipple, German, 3.813"OB Pr011e. SN Be 3.813 Hy4m4m Fmcwml n,es2a 1 angle) 12,276.0 5,0074 73.97 GAUGE Gauge or ISTfflowep apDMre tubing pressure gauge, 3.864 SIN CI SGM-0002 1=,8.2 5,024.6 7404 PACKER Packer, Baker 4 UP x 7 S/8" Premier 3.860 .0 ' HiemarcFxwra,laen 12 ,4048 5,042.8 7401 NIPPLE Nipple, amm, JSDB role,(dual deeperpug 3.750 installed) 464.5 5,059.3 74.00 LOCATOR Mechanical Localor x 12,640")(large GOabove 3.940 totaled) le.pC00NUNE0. ¢se7.a 12,485.5 5,059.6 74 00LOCATOR Mechanical Locator 4S TCH Box all OD below locate 0) 3940 fa.aH a KUP PRr- WELLNAME 38-611 WELLBORE 3S-611 CmmoPhillips ^" Alaska. Inc. ase,I,lnwmleamuPM Completion Details va,udw+lr.ue(.eewl Top pvol rnp mel Naminnl TOp mag(tIKB) (') Ilem Ms Com IO (nl NN4OER 9e.9 12,4]3.9 1 5.0619 ]401 MOLESROE Baker Fluted WLEG(Wire line ed de ].900 ry guide) .........._................... .... ...... ...._.. _.. .. _.......... Other In Hole ryYireline retrievable plugs, valves, pumps, fish,etc. ro;nVDl rota mel TOP IM1I<91 Irearg 11'1 Dee co' Runte 110 (ini 3,5.0 2,804.6 J528Catc11er CMera6et on RBP. 4.5"GG lopull. 11412019 0.000 3.656.0 2,805.9 352] arrier- Se(3]5'RBP 9.13'long . 1/412019 0.000 cOxpucioR: }96119U Retrievable Mnuhr Flava-pmei as 3.Oao Britlge Pup NIPPLE. +9T`t Free Summary &bROale Pmpwn[ DuipnM 1116) Propwnl In FlIndea (IM 12142018 0 209,8]20 SVRFACE; N"jul SddD TOP DoEn M1KM Blmw I Llokb FluMSyeYm Vol Clean (Pull VMalurrylbbb 1 12/42018 18,602.0 18,603.0 Gelled Safi Water, 30 Ib Borate ? 94900 3,1]6.00 WS LIR ara.I Spit palePmpwn)Deal.ned(to) Proam" In Foemalion(to) cemrer. aML1 12/412018 20],204.0 165,98].0 Pgriar- Woevaw drily Plu&90ded SI9Y SprtDM TOp OepIIIBNte1 Bnn(Po(B) Link W Flutl Sy¢Ym VOIC,...(bb1) VOlalurrylbbg emm Flue-sYmnanBmm: 2 121412018 1],952.0 ",953.0 Gelled Balt Wakr, 3016 B0rak 2,35?00 2,5]2.00 Ina OI1.aAD MYn Data pmPwntialowleO1141 Propwd m Found -(In) 00.6 uR 11. add 1WI2018 20],2".0 210,98].0 NnJOFlW-[urofaniMe 9WY start TPoDW"61Ka) eM(fing Link m Fluid Sysh Vol clean Wbp vol fil«ry Wbp WmaL89BDn,4fi70 102 Oft 3 12012018 1],1690 1],1]00 Gelletl Salt Water, 3016 Berate 2,52400 2]52.00 WVGE;12PS0 Start Dar Propwd se-kerred ala Propwnnn FounaXonllu) 12012018 20],2".0 210,3750 PRLKER: 12,el qY hart OMe Tep pepM (Itl(B) Bim (M1KBI LinXWFluN 6yshm VOI Ctran Wbp Vd blwry(pbq 4 121]12018 16,6350 16,636.0 Gelletl Sall Water, 3016 Borate 2,586.00 28 NIPPLE;I2A04.8 StartONeprepwd 0eagrIW 06) Propwnt In FPMdion all121212018 20].2".0 2",5600 LOCATOR:12A.1 3WX Spn0. Top D.pm(8KB) ate MKS) -ink FluNl6yslam Vol lObp Vd SWrry 11169 LOCATOe,12a665 5 12012018 16,1410 16,1420 11 Gelletl Salt Water, 3016 Berate 2,559.00 2.]80.00 spit OaW vrepwdOMbned(11M Propwnt 110 Formdbn fib) MOLE SINCE, 12.0739 12/912018 20],2"0 209,100.8 9Wi Start Dap Tomo lMKS) Burn (MB) Link W Fluid Samoan Vol Clun(ud) Vd 9Wrryluu9 6 12812018 15,609.0 15,610.0 Gelled Sall Water, 30111 BMak 2,969.00 3,19500 spit Dapvlopwd Damianee(to) PrOpwM m F«mdlon (ib) 12/912018 20],294 0 210,022.0 sto Soniate Tap pepM 6tl(B) LinkWFluitl system Viacom 166p Vol9k0w(bb9 IMERNEWITE;0p12609.0 landless) ] 12/912018 15,113.0 15,1140 Gelled Sall Water, 3016 Searle 2,422.00 2."900 Start Dow Propwd Cemigned(m prapwnun Formation (M) 1OW2018 20].2".0 211,940.0 Srgb 8Wrt0ao Top CryM(MB) BM(M1KB) Wk WFWk 9nom Vol mean@up Vo11311urrylbbl) Nano" F.. 13 a • 8 ib82018 14,582.0 14,583.0 GNletl Gall Water, 3916 Bonk 2,544.00 2,3]].00 SprtpaW PrPownt De e— (In) P,Pownl In lomien 1Ml 12842018 20],2"0 20],"80 slat .d Dao DepM(Mt8) BM@rin PnkoFlub Samoan VeILWn(bbp VOI SImry Ob) IT 9 12/142018 14,086.0 14,087.0 Gelletl Sall Water, 3016 Borak 2,]12.00 2,93600 aria. 0ra.Ne; tales 0 ■ ■ $No.. Propnt Deagnetl lib) Pmpwn) in Formation and 12/1412018 2w0],204.0 213,5411 slay ed"I'Me Top Oegll MKS) M. MB) Llpkro FluM9yaom Vol dean "0"V`IOfil69 10 12/14/018 13,58].0 13,588.0 Gelled Sall Water, 3016 Borate 2,261.00 2,492.00 stanpde Pmpwn) pensiona(11M Propwdln Formation fib) Mill 207,204.0 202,2020 Np uW FrmMr.:l4.oefio ■ ■ SIpY Sprl DdeTop OapM(M1KBI B. MB) Lmand'uie Sy:om Vd SWrry(bb9 11 12/1412018 13,0920 13,093.0 I Gelled Sag Water, 30 lb Borate Metal 2,382.00 2,600.00 Mandmi Inserts at xpntlb FrxWre: la We ' 1 anti Top (FOOD) Ved. Lided, Paris iu TRO Run N Top me) MB) all Medial ODOM Sery Tye Taw (In) (Pani) Run Done Com 1 3.620.6 2,nB.9 Cameo Killing 1 IGAS LIFT JGLV Il 0188 18500 11112019 2 11,8694 4,898.9 Cameo KBM t GAS LIFT DMV BEK 0000 00 111202018 ONE Kpm&Fndwe:t5t110 • • III L LATC Notes: General S Safety M,uW FNN-SeMaMrBrke: EnO Dale Anrw . ,x.asTa-re.eno Raenal FncW.Ns.mao , 11no1201a NOTE: KyElea. andeal 161a1U ' Imi—ad Prxbm, 18.6%O , Nren�tt hied.: 121®o 1 1 NPpeeb Fl 117.95x0 xyenuW Fnd,e.'.Ie.m2.o ' PRODDCTWNLINER: 1Z 1ar]u Hydraulic Fracturing Fluid Product Component Information Disclosure 12/2/2018 12/15/2018 Alaska Harrison Bay 50-103-20774-00-00 ConocoPhillips Company/Burlington Resources 3S611 u„sur HC o.e Cn!n FLdrl f`n nneifinn 70.39418900 -150.19639500 NAD83 NO NO 5,284 1,286,565 0 Frac FOCUS Chemical Disclosure Registry GROJ\DWATER IVOil & Gas Job Start Date: Job End Date: W66, State: rCounty: '- API Number: Operator Name: LWell Name and Number: �- Latitude: .. Longitude: Datum: EENW�Federal Well: Ingredient Indian Well: True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: 12/2/2018 12/15/2018 Alaska Harrison Bay 50-103-20774-00-00 ConocoPhillips Company/Burlington Resources 3S611 u„sur HC o.e Cn!n FLdrl f`n nneifinn 70.39418900 -150.19639500 NAD83 NO NO 5,284 1,286,565 0 Frac FOCUS Chemical Disclosure Registry GROJ\DWATER IVOil & Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)`” (% by mass)" Sea Water Operator Base Fluid Water 7732-18-5 96.00000 77.34175 Density = 8.540 Ingredients Listed Above Listed Above Water 7732-18-5 100.00000 0.15524 LVr 200 Penreco Freeze Protect Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below Wanli 20/40 Ceramic Halliburton Additive Listed Below MO -67 Halliburton pH Control Additive Listed Below OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker Listed Below SP BREAKER Halliburton Breaker Listed Below Wanli 20/40 Ceramic Halliburton Additive Listed Below CL -31 CROSSLINKER Halliburton Crosslinker Listed Below BE -B MICROBIOCIDE Halliburton Biocide Listed Below WG -36 GELLING AGENT Halliburton Gelling Agent Listed Below OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below SAND -COMMON WHITE -100 MESH, SSA -2, BULK (100003676) Halliburton Proppant Listed Below CL -22 UC Halliburton Crosslinker items above are Trade Names with the exception of Base Water Items below are the individual Corundum Listed Below ingredients. 1302-74-5 1 55.00000 9.22524 Mullite 1302-93-8 45.00000 7.54793 Sodium chloride 7647-14-5 4.00000 3.22450 Hydrotreated Distillate, Light 6474247-8 100.00000 1.44279 Crystalline silica, quartz 14808-60-7 100.00000 0.61978 Guar gum 9000-30-0 100.00000 0.27651 Potassium formate 590-294 60.00000 0.05469 Borate salts Proprietary 60.00000 0.05469 Ethanol64-17-5 60.00000 0.04231 Sodium hydroxide 1310-73-2 30.00000 0.03046 Oxylated phenolic resin jPropnetary 30.00000 0.02821 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water " Information Is based on the maximum potential for concentration and thus the total may be over 10D% ••• If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note. For Field Development products (products that 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 Data Sheets (MSDS) Potassium metaborate 13709-94-9 60.00000 0.02635 Heavy aromatic 64742-94-5 30.00000 0.02116 petroleum naphtha Ammonium persulfate 7727-54-0 100.00000 0.02040 Cured acrylic resin Proprietary 30.00000 0.00612 Poly(oxy-1,2-ethanediyl), 127087-87-0 5.00000 0.00353 alpha-(4-nonylphenyl)- omega-hydroxy-, branched Naphthalene 91-20-3 5.00000 0.00353 Potassium hydroxide 1310-58-3 5.00000 0.00220 2-Bromo-2-nitro-1,3- 52-51-7 100.00000 0.00140 propanediol Sodium carboxymethyl 9004-324 1.00000 0.00091 cellulose Sodium glycellate 2836-32-0 1.00000 0.00091 Acrylate polymer Proprietary 1.00000 0.00091 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871-6226 1,2,4 Trimethylbenzene 95-03-6 1.00000 0.00071 Sodium persuHate 7775-27-1 100.00000 0.00024 Sodium sulfate 7757-82-6 0.10000 0.00000 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water " Information Is based on the maximum potential for concentration and thus the total may be over 10D% ••• If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note. For Field Development products (products that 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 Data Sheets (MSDS) HALLISURTON sales +order# 0903873945 Conoco Phillips Alaska, Inc. Kuparuk River 3S-611 Intervals -2-11 Lower Moraine Moraine Formation Harrison Bay County, AK API: 50-103-20774 Prepared for: Hanna Sylte December 15, 2018 Stimulation Treatment Post Job Report Day 4: Zones 6-8 30# Hybor-G Prepared By: Keegan Lambe Chad Burkette 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. HALLI611J9iT0N ; Table of Contents Section page(s) Executive Summary 3 Wellbore Information 4 Actual Design Interval Summary 5-7 8-21 Well Summary 22 Interval -2 Plots Interval -1 Plots _ _ 23-26 27-29 _ Interval Plots 30-33 Interval 1 Plots 34-37 Interval 2 Plats 38-41 Interval Plots 42-47 Interval Plots 48- 51 Interval 5 Plots 52 -SS Interval Plots 56-69 Interval 7 Plots 64-67 Interval Plots 68-71 Interva19 Plots 72-81 Interval 10 Plots 82-85 Interval 11 Plots 86-89 Appendix 90 Chemical Summary 91 Planned Design 92-94 Hydration Testing 95 WA- Minifac and Zones 1-2 96 Water Analysis Zones 3-5 97 Water Analysis Day Zones 6-8 g8 Water Analysis Day 9-11 99 Bacteria Testing Zones 3-5 100 Bacteria Testing Zones 6.8 101 Bacteria Testing Zones 9-11 102 Water Straps-Minifracs 103 Water Straps -Minifrac-Zone2 104 Water Straps -Zones 3-5 105 Water Straps -Zones 6-8 106 Water Straps -Zones 9-11 107 Real -'rime QC -Zones 1-2 108 Real -Time QC -Zones 3-5 109 Real -Time QC- Zones 6-8 110 Real -Time QC- Zones 9-11 111 Fan 15 Zone 1 112 Fan 15 Zone 2 113 Fan 15 Zone 3 114 Fan 15 Zone 4 219 Fan 15 Zone 5 116 Fan 15 Zone 6 117 Fan 15 Zane 7 118 Fan 15 Zone 8 119 Fan 15 Zone 9 120 Fan 15 Zane 10 121 Fan 15 Zone 11 122 Event List - Minifrac 123 Event List- Zone 1-2 124 Event List- Zone 3-5 125 Event List - Zone 6-8 126 Event List -Zone 9-11 127-128 Lab Testing 129-148 Conoco Phillips Alaska, Inc.- Kuparuk River 35-611 TOC Engineering Executive Summary On December 02, 2018 a stimulation treatment was performed in the Moraine formation on the Kuparuk River 3S- 611 well in Harrison Bay County, AK. The Kuparuk River 35-611 was a 14 stage Vertical Sleeve Design. The proposed treatment consisted of: 0 gallons of Fresh Water 0 gallons of Treated Water 54,360 gallons of 30# WaterFrao-G 1,084,657 gallons of 30# Hybor-G 3,762 gallons of Freeze Protect 79,200 pounds of Premium- 100m 2,200,040 pounds of Wanli - 20/40 The actual treatment fully completed 14 of 14 stages. 0 stages were skipped, and 0 stages screened out or were otherwise cut short of design. The actual treatment consisted of: 5,947 gallons of Fresh Water 0 gallons of Treated Water 85,407 gallons of 30# WaterFrao-G 1,195,211 gallons of 30#Hybor-G 8,064 gallons of Freeze Protect 83,740 pounds of Premium- 100m 2,203,757 pounds of Want - 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: During intervals 3-5 there was issues with frozen sand. The frozen sand caused issues gaining higherproppant concentration. Proppant concentration was capped at 5ppg and the same designed proppant total was run. Halliburton is strongly committed to quality control on location. Before and after each job all chemicals, proppants, and fluid volumes are measured to assure the highest level of quality control. Tank fluid analysis, crosslink time, and break tests are performed before each job in order to optimize the performance of the treatment fluids. MO -67 concentrations were adjusted to maintain a consistent pH. 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. Thankyou, Keegan Lambe Technical Professional Halliburton Energy Services Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Executive Summary Landon Harrison Technical Professional Halliburton Energy Services f]o.Phillips Alaska,Inc.-Kupamk Rivera 611 Wellbore Information n n f]o.Phillips Alaska,Inc.-Kupamk Rivera 611 Wellbore Information �I f]o.Phillips Alaska,Inc.-Kupamk Rivera 611 Wellbore Information Conoco Phillips Alaska, Inc. - Kupamk River 35-611 Actual Design mmm•®�� mm�a� ��mmfmm�m®m®m mmmmlm ®��� 0mommi�®®®m®m®mtm�®mmmm 0mm��0amm0mm.o�m®mmm 0 ��� 0m��o®mmmmm©�mmmmm ®�� 0 ��� mm��ommt�®mom,m�m®mmm �m0�00��mmm,m_m®mmm mm® mm ®��� 0 m m®®� m�m�m•mm.m�mmmmm o ��� � m ��I�®�®m•®m•m•�mmmmm - o���mm�®®®®®®®®®gym•®m,mt� m•���� m�®�®®®®®®®gym®mmtm - m.�����mm��®®��m•®m.m�mmlm®m Conoco Phillips Alaska, Inc. - Kupamk River 35-611 Actual Design is—wl.11 Conoco Phillips Alaska, Inc. - Kuomk River 35611 Actual Design 6 1-1 nv—_iw,-Xv. —seent ZIT w_ a° -. .Mom _ re.r ,mrM wr raa m.rwr e..�..i as mw o -a we mi rw mw T,.,sae l°„nazv.yea mm r ssal• ; ii m/ 1µO 55$ 1^ macc TxM<G m— rtlti mic ' N �S jv Mn A sw�— on e vis m90 i,e IT sm sal g wMmmM em 12 In I. rtmw 999f� wnlaWl 14T mmm lvmwz .Aaolo li- gf_ 1. ra vemms. o-Mis 12663GO x— iL sv�i a -teric . is tea. xsa +>sml v.— vi w... ww Tixa< vw ME m. ad vm m nau _ell in 6ric a§` 3-11 n io .14 Txpnv kmseuum Conoco Phillips Alaska, Inc. - Kuomk River 35611 Actual Design 6 C now Phillips Alaska,Inc. - Kuparuk River 35611 Actual Oesign v _ m1-1 w ,wM ire x.v nn nom riw rw� am ani nwt im,. mu m., rwi au. as 2 w.n. ww saoo sIe..i wW.av,e wn .;3.� ,�.m Issv a Iwo A lust nes 25 a s mwwe c m^.a oaeV,I 2 Iff,11 C now Phillips Alaska,Inc. - Kuparuk River 35611 Actual Oesign Interval Summary Kuparuk River 3S-611 - Lower Moraine - MiniFrac #1 Interval Summary Start Daterfime: 1212/1814 09 End Date/Time: 1212/18 14:44 Pump Time: 35 min Initial Rate (Breakdown): 4.7 bpm Initial Surface Pressure (Breakdovm): 1507 psi Initial BH Pressure (Breakdown): N/A psi Max Rate: 55.6 bpm Max BH Pressure: 6186 psi Average Rate: 43.6 bpm Average Surface Pressure: 5499 psi Average BH Pressure: 5528 psi Average Suface HHP: 5876 hhp Initial Braden Pressure: 223 psi Average Vise: NIA CP Average Temp: NIA F Average pH: N/A BH ISDP: 3220 psi Final Fracture Gradient: 0.615 psi/R Proppant Summary Premium - 100m Pumped: 0 lbs Wanli - 20140 Pumped: 0 lbs Total Proppant Pumped' : 0 lbs Proppant in Formation: 0 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 bills 309 WaterFrac-G Volume: 12,250 gal 292 bbis 30# Hybor-G Volume: 22,631 gal 539 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbis Breakdown Volume: 1,451 gal 35 bills Pad Volume: 0 gal 0 bbls Conditioning Pad Volume: 0 gal 0 bbis Proppant Laden Fluid Volume: 0 gal 0 bbis Flush Volume: 12,250 gal 292 bbis Mini -Frac Volume: 21,180 gal 504 bills Spacer & Ball Drop Volume: 0 gal 0 bbis Freeze Protect Volume: 0 gal 0 bills Treatment Slurry Volume (Calculated): 34,881 gal 831 bbis Total Clean Fluid Volume: 34,881 gal 831 bbis Interval Status: Completed Comments: After establishing rate, came off line to troubleshoot Schlumberger downhole guages. Proppant Engineer Landon Harrison concentration to start zone was false as we could not rebase densometer until rate was Treater Chad Burkett established (no proppant was run during this minifrac). Could not establish desired pH w we Supervisor Chad Burkett came offline to troubleshoot per customer request and to analyze the Minffrac as pumped. No proppant pumped per design. Values for proppant are taken from soltware calculations based on multiple variables. Customer Eng: Hanna Syke Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Re p: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary 8 Kuparuk River 35-611- Lower Moraine - MiniFrac #2 Interval Summary Start Date/Time: 12/2/18 15:33 End DaterTime: 1212/181703 Pump Time: 90 min Initial Rate (Breakdown): 7,8 bpm Initial Surface Pressure (Breakdown): 5075 psi Initial SH Pressure (Breakdown): 4020 psi Max Rate: 33.2 bpm Max BH Pressure: 4020 psi Average Rate: 14.9 bpm Average Surface Pressure: 2044 psi Average BH Pressure: 3606 psi Average Suface HHP: 746 hhp Initial Braden Pressure: 187 psi Average Vise: N/A CP Average Temp: NIA F Average pH: NIA BH ISDP: 3116 psi Final Fracture Gradient: 0.595 ps(dt Proppant Summary Premium - 100m Pumped: 0 lbs Wanli - 20140 Pumped: 0 lbs Total Proppant Pumped' : 0 lbs Proppant in Formation: 0 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 bbis 30# WaterFmc-G Volume: 13,195 gal 314 bbls 30# Hybor-G Volume: 14,548 gal 346 bills Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bills Breakdown Volume: 14,548 gal 346 bbis Pad Volume: 0 gal 0 bills Conditioning Pad Volume: 0 gal 0 bbis Proppant Laden Fluid Volume: 0 gal 0 bbis Flush Volume: 13,195 gal 314 bbis Mini -Frac Volume: 0 gal 0 bbis Spacer & Ball Drop Volume: 0 gal 0 bbis Freeze Protect Volume: 0 gal 0 bbis Interval Status: Completed Comments: Could not establish desired pH wth a reasonable setpoint of MO -67, so we came offline again Engineer Landon Harrison for the HES engineer to perform lab testing to isolate the issue per customer request. No Treater Chad Burkett proppant pumped per design. Supervisor Chad Burkett -values for proppant are taken from software calculations based on multiple variables. Customer Eng: Hanna Sybe Proppant is hired art of weight ticket volumes and may vary slightly from this number Customer Rep.' Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 9 Kuparuk River 3S-811 - Lower Moraine - MinlFrac #3 Interval Summary Start Daterl-ime: 12/4118 13:04 End Date/Time: 1214/1813:43 Pump Time: 39 min Initial Rate (Breakdown): 14.8 bpm Initial Surface Pressure (Breakdown): 2799 psi Initial BH Pressure (Breakdown): 3740 psi Max Rate: 40.1 bpm Max Surface Pressure: 5151 psi Max BH Pressure: 5327 psi Average Rate: 39.9 bpm Average Surface Pressure: 4907 psi Average BH Pressure: 5068 psi Average Surface HHP: 4799 hhp Initial Braden Pressure: 369 psi Max Braden Pressure: 632 psi Average Visc: 34 CP Average Temp: 74 F Average pH: 9.8 ISDP: 3278 psi Final Fracture Gradient: 0.626 psiRt 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) Fresh Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bb/s 30# WaterFrac-G Volume: 11,948 gal 284 bbls 30# Hybor-G Volume: 33,127 gal 789 bbls Freeze Protect Volume: 0 gal 0 bb/s Fluid Summary (by stage description) Load Well Volume: 12,167 gal 290 bbls Breakdown Volume: 0 gal 0 bb/s Pad Volume: 0 gal 0 bbls Conditioning Pad Volume: 0 gal 0 bola Proppant Laden Fluid Volume: 0 gal 0 bbls Flush Volume: 11,948 gal 284 bbls Mini -Frac Volume: 20,960 gal 499 bbls Spacer & Ball Drop Volume: 0 gal 0 bbls Freeze Protect Volume: 0 gal 0 bbls Interval Status: Completed Comments: Pumped MiniFrac according to Customer Engineer's request. Increased rate from 15 BPM to 40 HES Engineer. Landon Harrison BPM when a good crossfink system was established and confirmed with second sample. Treater: Chad Burkett Modified CL -31 setpoint on the fly due to overcrosslinked sample (preceded with Customer Supervisor. Chad Burkett Engineers approval). No closure was seen from analysis. No proppant pumped per design. Values for proppant am taken from software calwlations based on multiple variables. CustOmer Eng: Hanna Sylte Proppant is billed off of weight ticket volumes and may vary slightly from this number Customer Re pChristopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 10 Kuparuk River 3S-611 - Lower Moraine - Interval 1 Interval Summary Start Date/Time: 1214/18 14:10 End Date/Time: 1214/18 15:26 Pump Time: 76 min Initial Rate (Breakdown): 16.4 bpm Initial Surface Pressure (Breakdown): 2920 psi Initial BH Pressure (Breakdown): 4244 psi Max Rate: 40.5 bpm Max Surface Pressure: 6717 psi Max BH Pressure: 6330 psi Average Rate: 40 bpm Average Surface Pressure: 5275 psi Average BH Pressure: 5442 psi Average Suface HHP: 5159 hhp Initial Braden Pressure: 529 psi Max Braden Pressure: 631 psi Average Vise: 32 cP Average Temp: 72 F Average pH: 9.9 ISDP: N/A psi Final Fracture Gradient: - PSW Proppant Summary Premium - 100m Pumped: 7,752 lbs Wanli - 20140 Pumped: 202,120 lbs Total Proppant Pumped' : 209,872 lbs Proppant in Formation: 209,872 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 301E WaterFrac-G Volume: 0 gal 0 bbls 30# Hybor-G Volume: 123,872 gal 2,949 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage descdpfion) Load Well Volume: 0 gal 0 bbls Breakdown Volume: 0 gal 0 bb/s, Pad Volume: 11,644 gal 277 bbls Conditioning Pad Volume: 29,657 gal 706 bbls Proppant Laden Fluid Volume: 72,573 gal 1,728 bbls Flush Volume: 0 gal 0 bbls Mini -Frac Volume: 0 gal 0 bbls Spacer R Ball Drop Volume: 9,998 gal 238 bbls Freeze Protect Volume: 0 gal 0 bbls Interval Status: Completed Comments: HES and Customer engineer modifed CL -31 setpoint in reponse to samples coming into the van HES Engineer. Landon Harrison (slightly overcrosslinked samples at higher CL -31 setpoints). All proppant placed per design. Treater. Chad Burkett Supervisor. Chad Burkett 'Values for proppant are taken from software calculations based on multiple variables. Customer Eng: Hanna Syne Proppare is billed oft of weight ticket volumes and may vary slightly from this number. Customer Rep: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary t 1 Kuparuk River 3S-611- Lower Moraine - Interval 2 Interval Summary Start Date/Time: 1214/18 15:26 End Date/Time: 12/4/18 16:28 Pump Time: 62 min Initial Rate (Breakdown): 12.00 bpm Initial Surface Pressure (Breakdown): 5298 psi Initial BH Pressure (Breakdown): 6440 psi Max Rate: 45.20 bpm Max Surface Pressure: 6584 psi Max BH Pressure: 6441 psi Average Rate: 44.40 bpm Average Surface Pressure: 5787 psi Average BH Pressure: 5550 psi Average Suface HHP: 6298 hhp Initial Braden Pressure: 593 psi Max Braden Pressure: 618 psi Average Viso: 31 cP Average Temp: 75.30 F Average pH: 10.10 ISDP: 3309 psi Final Fracture Gradient: 0.632 psilt Final 5 min: 3297 psi Final 10 min: 3291 psi Final 15 min: 3286 psi Proppant Summary Premium - 100m Pumped: 7,251 lbs Wanli - 20/40 Pumped: 158,736 lbs Total Proppant Pumped' : 165,987 lbs Proppant in Formation: 165,987 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 30R WaterFrao-G Volume: 14,355 gal 342 bbls 30# Hybor-G Volume: 83,183 gal 1,981 bills Freeze Protect Volume: 1,260 gal 30 bbis Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Breakdown Volume: 0 gal 0 bills Pad Volume: 11,175 gal 266 bills Conditioning Pad Volume: 28,953 gal 689 bbls Proppant Laden Fluid Volume: 43,055 gal 1,025 bbls Flush Volume: 14,355 gal 342 bbls Mini -Frac Volume: 0 gal 0 bbis Spacer & Ball Drop Volume: 0 gal 0 bbls Freeze Protect Volume: 1,260 gal 30 bbis Treatment Slurry Volume (Calculated): 106,335 gal 2,532 bbis Total Clean Fluid Volume: 98,798 gal 2,352 bbls Interval Status: Completed Comments: Sand did not track accurately during zone, resulting in us running out of sand before the Engineer. Landon Harrison designed end of zone. We could not track sand actively during zone due to the castle's scale not Treater. Chad Burkett working. All proppant placed. Supervisor. Chad Burkett 'Values for proppant are taken from software calculations based on multiple variables. Hanna 6ylle Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep; Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 12 Kuparuk River 3S-611 - Lower Moraine - Interval 3 Interval Summary Start DatefTime: 12/7/18 11:30 End Daterlime: 12/7/18 13:18 Pump Time: 108 min Initial Rate (Breakdown): 12.35 bpm Initial Surface Pressure (Breakdovm): 4936 psi Initial BH Pressure (Breakdown): 5467 psi Max Rate: 40.49 bpm Max Surface Pressure: 5949 psi Max BH Pressure: 5553 psi Average Rate: 39.96 bpm Average Surface Pressure: 4478 psi Average BH Pressure: 4691 psi Average Suface HHP: 4386 hhp Initial Braden Pressure: 304 psi Max Braden Pressure: 613 psi Average Visa 30.5 CP Average Temp: 75 F Average pH: 10.16 Proppant Summary Premium - 100m Pumped: 7,953 lbs Werth - 20/40 Pumped: 203,034 lbs Total Proppant Pumped` : 210,987 lbs Proppant in Formation: 210,987 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 30# WaterFrac,G Volume: 0 gal 0 bills 30ft Hybor-G Volume: 106,011 gal 2,524 bb/s Freeze Protect Volume: 0 gal 0 bills Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Breakdown Volume: 0 gal 0 obis Pad Volume: 11,241 gal 268 bola Conditioning Pad Volume: 28,253 gal 673 bbls Proppant Laden Fluid Volume: 54,384 gal 1,295 bilis Flush Volume: 0 gal 0 bills Mini -Fret Volume: 0 gal 0 bbls Spacer 8 Ball Drop Volume: 12,133 gal 289 bbls Freeze Protect Volume: 0 gal 0 bbls Treatment Slurry Volume (Calculated): 115,591 gal 2,752 bbls Total Clean Fluid Volume: 106,011 gal 2,524 bola Interval Status: Completed Comments: Before opening the well the nitrogen Pop -Off was checked. Due to a poor-visc ADP tub, the Engineer Keegan Lambe initial tub was pumped as a linear gel to remove the low vise fluid. Due to pre -bad issues pumps Treater. Chad Burkett kicked multiple times during the zone. Due to the ceramic clogging the hopper gate, desired Supervisor. Chad Burkett proppant concentration was not able to be achieved. Due to the issues with this the concentration was held as high as possible during the zone, during the spacer and pad following the hopper grate was cleaned out. -Values for proppant are taken from scream calculations based on multiple variables. Completions Engineer Hanna Sylte Proppant is billed off of might ticket volumes and may vary slightly from this number. Cusromar Rep: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 13 Kuparuk River 3S-611 - Lower Moraine - Interval 4 Interval Summary Start Date/Time: 121-7/18 13:18 End DateTme: 1217/18 14:11 Pump Time: 53 min Initial Rate (Breakdown): 12.2 bpm Initial Surface Pressure (Breakdown): 4646 psi Initial BH Pressure (Breakdown): 5183.0 psi Max Rate: 42.46 bpm Max Surface Pressure: 6788 psi Max BH Pressure: 5695.0 psi Average Rate: 42 bpm Average Surface Pressure: 4946 psi Average BH Pressure: 4880 psi Average Suface HHP: 5055 hip, Initial Braden Pressure: 622 psi Max Braden Pressure: 681 psi Average Visc: 32 CP Average Temp: 80 F Average pH: 10.2 ISDP: 3469 psi Final Fracture Gradient: 1.105 psilt Proppant Summary Premium - 100m Pumped: 7,806 lbs Wanli - 20140 Pumped: 202,569 lbs Total Proppant Pumpetl` : 210,375 lbs Proppant in Formation: 210,375 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 bills 30# WaterFrac-G Volume: 10,653 gal 254 bbls 30# Hybor-G Volume: 97,975 gal 2,333 bbls Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Breakdown Volume: 0 gal 0 bbls Pad Volume: 11,181 gal 266 bbls Conditioning Pad Volume: 28,766 gal 685 bbls Proppant Laden Fluid Volume: 50,217 gal 1,196 bills Flush Volume: 10,653 gal 254 bbls Mini -Frac Volume: 0 gal 0 bbls Spacer & Ball Drop Volume: 7,811 gal 186 bbls Freeze Protect Volume: 0 gal 0 bills Treatment Slurry Volume (Calculated): 118,181 gal 2,814 bbls Total Clean Fluid Volume: 108,628 gal 2,586 bills Interval Status: Completed Comments: Due to an issue with the ball dropper the ball could not be dropped in zone. The well was flushed Engineer: Keegan Lambe as a result per request of customer, once resolved the next zone was started. All proppant was Treater. Chad Burkett placed into formation. Supervisor. Chad Burkett 'Values for proppant are taken from software calwladons based on multiple variables. Completions Engineer Hanna Syne Proppant is cited off of weight ticket volumes and may vary slightly from this number Customer Rep: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary 14 Kuparuk River 3S-611- Lower Moraine - Interval 5 Interval Summary Start Date/Time: 12/7/18 14:25 End Daterrime: 12/7/18 15:39 Pump Time: 74 min Initial Rate (Breakdown): 11.8 bpm Initial Surface Pressure (Breakdown): 4733 psi Initial BH Pressure (Breakdown): 5369.0 psi Max Rate: 43.5 bpm Max Surface Pressure: 6031 psi Max BH Pressure: 5320.0 psi Average Rate: 43 bpm Average Surface Pressure: 4845 psi Average BH Pressure: 4725 psi Average Suface HHP: 5135 hhp Initial Braden Pressure: 622 psi Max Braden Pressure: 681 psi Average Visc: 30.5 cP Average Temp: 80.5 F Average pH: 10.13 ISDP: 3347 psi Final Fracture Gradient: 1.081 psiAt Final 5 min: 3294 psi Final 10 min: 3277 psi Final 15 min: 3264 psi Proppant Summary Premium - 100m Pumped: 8,100 lbs Werth - 20/40 Pumped: 196,460 lbs Total Proppant Pumped` : 204,560 lbs Proppant in Formation: 204,560 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bbis Treated Water Volume: 0 gal 0 bbis 30# WaterFrac-G Volume: 0 gal 0 bbis 30#Hyhor-G Volume: 105,184 gal 2,504 bbis Freeze Protect Volume: 2,287 gal 54 bbis Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bb/s Breakdown Volume: 0 gal 0 bills Pad Volume: 14,938 gal 356 bbis Conditioning Pad Volume: 28,825 gal 686 bbis Proppant Laden Fluid Volume: 50,825 gal 1,210 bbis Flush Volume: 10,596 gal 252 bills Mini -Frac Volume: 0 gal 0 bbis Spacer & Ball Drop Volume: 0 gal 0 bbis Freeze Protect Volume: 2,287 gal 54 bbis Treatment Slurry Volume(Calculated): 116,760 gal 2,780 bbis Total Clean Fluid Volume: 107,471 gal 2,559 bbis Interval Status: Completed Comments: Frozen ceramic sand was causing issues with the sand concentration due to packing off the Engineer. Keegan Lambe hopper grate. Maximum proppanl concentration achieved was 6.5lbs. The well was freeze Treater Chad Burkett protected at the end of the zone. Supervisor. Watl Burkett -values for proppanl are taken from soflwmre calculations based an multiple vanebles. Completions Engineer Hanna Sylte Pmppant is billed off of weight ticket volumes and may vary slightly from this number, Customer Rep: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 15 Kuparuk River Start Date/Time: 12/9/18 14:27 End Daterrime: 1219/18 16:45 Pump Time: 138 Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Average Surface Pressure: Average BH Pressure: Average Surface HHP: Initial Braden Pressure: Max Braden Pressure: Average Visc: Average Temp: Average pH: 11.7 5083 5583.0 43.69 5390 5611.0 42 4039 4303 4162 607 850 32 85 9.86 Proppant Summary min bpm psi psi bpm psi psi bpm psi psi hhp psi psi CP F Premium - 100m Pumped: 7,085 lbs Treater.Chad Burkett flushed at 14:32 12/9/2016. Due to the lower than sesired pH MO -67 Concentration was Wanli - 20140 Pumped: 202,015 Ibis •Values for pmppant are taken from software calculations based on multiple variables. Completions Engineer Hanna Syne Total Proppant Pumped*: 209,100 lbs Proppant in Formation: 209,100 lbs Fluid Summary (by fluid description) Fresh Water Volume: 5,947 gal 142 bbls Treated Water Volume: 0 gal 0 bible 30k WaterFrac-G Volume: 5,075 gal 121 bible 306 Hybor-G Volume: 113,660 gal 2,706 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbis Breakdown Volume: 0 gal 0 bbis Pad Volume: 11,552 gal 275 bbis Conditioning Pad Volume: 28,864 gal 687 blas Proppant Laden Fluid Volume: 59,430 gal 1,415 bbis Flush Volume: 11,022 gal 262 bbis Mini -Frac Volume: 0 gal 0 blas Spacer & Ball Drop Volume: 13,814 gal 329 bbis Freeze Protect Volume: 0 gal 0 bbis Treatment Slurry Volume(Calculated): 134,176 gal 3,195 bbis Total Clean Fluid Volume: 124,682 gal 2,969 bbis Interval Status: Completed wellneaa openea at sunace pressure or t[upsi, cownnore pressure at zzai psi ano a c000m engineer. Keegan Lambe hole temperature of 127.4 F. Due to a malfunction in the mixing bowl of the ADP the well was Treater.Chad Burkett flushed at 14:32 12/9/2016. Due to the lower than sesired pH MO -67 Concentration was Supervisor. Chad Burkett increased to a 1.3aot. All or000ant placed in formation. •Values for pmppant are taken from software calculations based on multiple variables. Completions Engineer Hanna Syne Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary 16 Kuparuk River 3S-611 -Lower Moraine - Interval 7 Interval Summary Start DateTrime: 12/9118 16:45 End Date7Time: 1219118 17:40 Pump Time: 55 min Initial Rate (Breakdown): 12.2 bpm Initial Surface Pressure (Breakdown): 1988 psi Initial BH Pressure (Breakdown): 4727.0 psi Max Rate: 50.99 bpm Max Surface Pressure: 6571 psi Max BH Pressure: 5053.0 psi Average Rate: 47 bpm Average Surface Pressure: 4987 psi Average BH Pressure: 4543 psi Average Suface HHP: 5815 hhp Initial Braden Pressure: 782 psi Max Braden Pressure: 888 psi Average Vise: 33 cp Average Temp: 87 F Average pH: 9.86 Proppant Summary Premium - 100m Pumped: 7,531 lbs Wanli - 20/40 Pumped: 202,491 lbs Total Proppant Pumped' : 210,022 lbs Proppant in Formation: 210,022 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 bbls 30# WaterFrec-G Volume: 0 gal 0 bb/s 30#Hybor-G Volume: 101,718 gal 2,422 MIS Freeze Protect Volume: 0 gal 0 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Breakdown Volume: 0 gal 0 bbls Pad Volume: 14,667 gal 349 bbls Conditioning Pad Volume: 27,076 gal 645 bbls Proppant Laden Fluid Volume: 58,127 gal 1,384 bible Flush Volume: 0 gal 0 bills Mini -Frac Volume: 0 gal 0 bbls Spacer 8 Ball Drop Volume: 1,848 gal 44 bb/s Freeze Protect Volume: 0 gal 0 bbis Treatment Slurry Volume (Calculated): 111,255 gal 2,649 bbls Total Clean Fluid Volume: 101,718 gal 2,422 bbls Interval Status: Completed Comments: Par cutomer request the proppant concentration was rapped at 5ppg and rate was increased Engineer. Keegan Lambe through the zone as pressure allowed. All proppant placed in formation. Treater Chad Burkett Supervisor. Chad Burkett -Values for proppant are taken from software calculations based on multiple variables. Completions Engineer Hanna Syt e Proppant is billed off of weight ticket volumes and may vary slightly from this number. Customer Rep: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 17 •611 - Lower Moraine - interval Summary Start Daterrime: 1219118 17:42 End Date/Time: 1219118 18:33 Pump Time: 51 min Initial Rate (Breakdown): 12.2 bpm Initial Surface Pressure (Breakdown): 4911 psi Initial BH Pressure (Breakdown): 5519.0 psi Max Rate: 55.11 bpm Max Surface Pressure: 6553 psi Max BH Pressure: 5520.0 psi Average Rate: 50 bpm Average Surface Pressure: 4598 psi Average BH Pressure: 4171 psi Average Suface HHP: 5663 hi Initial Braden Pressure: 790 psi Max Braden Pressure: 826 psi Average Vise: 30 CP Average Temp: 85 F Average pH: 9.9 ISDP: 3325 psi Final Fracture Gradient: 1.076 psilft Final 5 min: 3293 psi Final 10 min: 3290 psi Final 15 min: 3285 psi Proppant Summary Premium - 100m Pumped: 8,094 lbs Wanli - 20140 Pumped: 203,846 lbs Total Proppant Pumped" : 211,940 Ibis Proppant in Formation: 211,940 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal Treated Water Volume: 0 gal 30# WaterFrac-G Volume: 9,383 gal 30# Hybor-G Volume: 95,708 gal Freeze Protect Volume: 1,747 gal Fluid Summary (by stage description) Load Well Volume: 0 gal Breakdown Volume: 0 gal Pad Volume: 12,683 gal Conditioning Pad Volume: 27,226 gal Proppant Laden Fluid Volume: 55,799 gal Flush Volume: 9,383 gal Mini -Frac Volume: 0 gal Spacer & Ball Drop Volume: 0 gal Freeze Protect Volume: 1,747 gal Treatment Slurry Volume (Calculated): 116,462 gal Total Clean Fluid Volume: 106,838 gal Interval Status: Completed 0 bbls 0 bbis 223 bbls 2,279 bbls 42 bbls 0 bbls 0 bbls 302 bills 648 bbls 1,329 bills 223 bills 0 bills 0 bbls 42 bbls 2,773 bola 2,544 bbls Proppant remained capped at 5ppg and rate was increased during the bib stage as pressure tn9rneer. Keegan Lambe allowed. The well was freeze protected after the 5, 10, 15 shut down. Treater Chad Burkett Supervisor. Chad Burkett 'Values for proppant are taken from software calculations based on multiple vanables. Completions Engineer Hanna Sylte Proppant is hVed off of weight ticket volumes and may vary slightly from this number. CustomBr RB p: Christopher Kennedy Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary 18 Stan. Date/Time: 12/12118 12:55 End Daterrime: 12/15118 15:19 Pump Time: 80 Initial Rate (Breakdown): Initial Surface Pressure (Breakdown): Initial BH Pressure (Breakdown): Max Rate: Max Surface Pressure: Max BH Pressure: Average Rate: Avenge Surface Pressure: Average BH Pressure: Average Suffice HHP: Initial Braden Pressure: Max Braden Pressure: Average Visc: Average Temp: Average pH: 12.2 3914 4875.0 52.24 7156 4563.0 50 5231 4160 6430 378 723 26 75 9.95 Proppant Summary min bpm psi psi bpm psi psi bpm psi psi hhp psi psi cP F Premium - 100m Pumped: 7,933 lbs Treater. Chad Burkett packed off. Shut down, freeze protected downhole (301bb0 and shut in the wrell at 13:53 Wanli - 20140 Pumped: 199,115 lbs hit. No initial ball ha was observed. Secondary Ball was dropped. Total Proppant Pumped' : 207,048 lbs Customer Re p: Paul Besselte Proppant in Formation: 207,048 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bills Treated Water Volume: 0 gal 0 bbls 309 WalerFrac-G Volume: 0 gal 0 bbls 30k Hybor-G Volume: 112,309 gal 2,674 bbls Freeze Protect Volume: 1,615 gal 38 bbls Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbls Breakdown Volume: 0 gal 0 bbls Pad Volume: 13,784 gal 328 bbls Conditioning Pad Volume: 28,814 gal 686 bbls Proppant Laden Fluid Volume: 51,023 gal 1,215 bb/s Flush Volume: 0 gal 0 bbls Mini -Frac Volume: 0 gal 0 bbls Spacer 8 Ball Drop Volume: 18,688 gal 445 bills Freeze Protect Volume: 1,615 gal 38 bbls Treatment Slurry Volume (Calculated): 123,326 gal 2,936 bbls Total Clean Fluid Volume: 113,924 gal 2,712 bbls Interval Status: Completed Wellhead opened at a surface pressure of 627psi. Used the ADP to direct supply gel to the Engineer. Keegan Lambe Blender to dispose of a low visc gel. Atter pumping to displace the ball the ADP mixing bowl Treater. Chad Burkett packed off. Shut down, freeze protected downhole (301bb0 and shut in the wrell at 13:53 Supervisor. Chad Burkett 1211212018. After Reoppening the well on 12/1412018 at 469psi) pumped 50bb1 to observe ball hit. No initial ball ha was observed. Secondary Ball was dropped. Values for proppent are taken from software calculations based on multiple variables. Completions Engineer Sandeep Pedam Proppant is billed off of weight ticket volumes and may vary slightly from this number, Customer Re p: Paul Besselte Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Summary 19 Kuparuk River 3S-611 - Lower Moraine - Interval 10 Interval Summary Start DaterTime: 12/15/18 15:19 End Daterl-ime: 12/15/18 16:32 Pump Time: 73 min Initial Rate (Breakdown): 12.1 bpm Initial Surface Pressure (Breakdown): 1589 psi Initial BH Pressure (Breakdown): 3260.0 psi Max Rate: 55.62 bpm Max Surface Pressure: 7263 psi Max BH Pressure: 4232.0 psi Average Rate: 54 bpm Average Surface Pressure: 4836 psi Average BH Pressure: 3859 psi Average Suface HHP: 6428 hhp Initial Braden Pressure: 750 psi Max Braden Pressure: 801 psi Average Visc: 33 cp Average Temp: 78 F Average pH: 10.03 Proppant Summary Premium - 100m Pumped: 7,469 lbs Wanli - 20/40 Pumped: 206,075 Its Total Proppant Pumped' : 213,544 lbs Proppant in Formation: 213,544 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bbis Treated Water Volume: 0 gal 0 bbis 30# WaterFrac-G Volume: 0 gal 0 bbis 30#Hybor-G Volume: 94,960 gal 2,261 bbis Freeze Protect Volume: 0 gal 0 bbis Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bbis Breakdown Volume: 0 gal 0 bbis Pad Volume: 12,004 gal 286 bbis Conditioning Pad Volume: 28,771 gal 685 bbis Proppant Laden Fluid Volume: 51,219 gal 1,220 bbis Flush Volume: 0 gal 0 bbis Mini -Frac Volume: 0 gal 0 bbis Spacer & Ball Drop Volume: 2,966 gal 71 bbis Freeze Protect Volume: 0 gal 0 bbis Treatment Slurry Volume (Calculated): 104,656 gal 2,492 bbis Total Clean Fluid Volume: 94,960 gal 2,261 bbls Interval Status: Completed Comments: Dropped ball Initially and did not we a ball hit. Dropped a second ball, no noticable ball hit. Engineer. Keegan Lambe Trucks kicked out during the zone. Treater: Chad Burkett Supervisor: Chad Burkett -values for proppant are taken from software calculations based on multiple variables. Completions Engineer Sandeep Pedam Proppant is billed off of weght ticket volumes and may vary sightly from this number. Customer Rep: Paul BesseHe Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary 20 Kuparuk River 3S-611 -Lower Moraine - Interval 11 Interval Summary Start Daterrime: 12115/18 16:32 End DateRme: 12/15118 17:36 Pump Time: 64 min Initial Rate (Breakdown): 12.2 bpm Initial Surface Pressure (Breakdovm): 4483 psi Initial BH Pressure (Breakdown): 4836.0 psi Max Rate: 55.74 bpm Max Surface Pressure: 6045 psi Max BH Pressure: 3736.0 psi Average Rate: 53 bpm Average Surface Pressure: 4783 psi Average BH Pressure: 3649 psi Average Suface HHP: 6046 hhp Initial Braden Pressure: 768 psi Max Braden Pressure: 806 psi Average Visc: 27.5 op Average Temp: 79.5 F Average pH: 10.11 ISDP: 3335 psi Final Fracture Gradient: 1.082 psi/It Final min: 3310 psi Final 10 min: 3310 psi Final 15 min: 3309 psi Proppant Summary Premium - 100m Pumped: 7,922 lbs Wanli - 20140 Pumped: 194,280 Ibs Total Proppant Pumped' : 202,202 lbs Proppant in Formation: 202,202 lbs Fluid Summary (by fluid description) Fresh Water Volume: 0 gal 0 bbls Treated Water Volume: 0 gal 0 bbls 30# WaterFrac-G Volume: 8,548 gal 204 bbls 30# Hybor-G Volume: 90,325 gal 2,151 bbls Freeze Protect Volume: 1,155 gal 28 bills Fluid Summary (by stage description) Load Well Volume: 0 gal 0 bills Breakdovm Volume: 0 gal 0 bbls Pad Volume: 10,801 gal 257 bbls Conditioning Pad Volume: 28,863 gal 687 bbls Proppant Laden Fluid Volume: 50,661 gal 1,206 bbls Flush Volume: 8,548 gal 204 bbls Mini -Frac Volume: 0 gal 0 bbls Spacer & Ball Drop Volume: 0 gal 0 bills Freeze Protect Volume: 1,155 gal 28 bbls Treatment Slurry Volume (Calculated): 109,210 gal 2,600 bits Total Clean Fluid Volume: 100,028 gal 2,382 bbls Interval Status: Completed Comments: Cut breakers during Flush per customer request. Engineer. Keegan Lambe Treater: Chad Burkett Supervisor Chad Burkett Values for propt ant are taken from sdrovers calculations based on multiple variables. Completions Engineer Sandeep Pedam Proppant is billed o8 of weight ticket volumes and may vary slightly from this number. Customer Rep: Paul Bessene Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Interval Summary 21 .t,' . t=—',� Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Well Summary sa— Conoco Phillips Alaska, Inc. - Kuparuk River 3S-611 Well Summary Pressure Test - Initial Test (..:1 ns -- -- Pressure Treating Pressure @Pump (psi) nnc Customer. tion: K paOruk PHILLIPOS- Aaska UW:Job ate. 50-1303-20774 Sales Order#: 0903873945 Wall Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval -2 Plots '0 Me Treatment Plot - MiniFrac 41 tilusrzw l4nplwm ('nnc lll_all-----'—'—'--' lm Rni Cone (lb/g.1) C A B Ga nge E6H rres (Pr4) k Acm,d 1111 Temp(°r) V C Time Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval -2 Plats 24 Blender Chemical Plot - MiniFrac #1 A IMO -67 Conc (gallMgal) B CL -22 UC Colic (gal/Mgap — A Optiflo II Cone (lb/Mgal) 6 Optiflo-Ill Cone (Ib/Mgal) B ---- B B 14:10 14:15 14:20 14:25 14:30 14:35 14:40 14:45 12MO18 1212/2018 Time PHILLIPS -Kaska I Job Date: 01 -Dec -2018 I Sales Order#: 0903873945 1 — Nall Description: Kuparuk Riwr3S-611 1 UVe1: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval .2 Plotz ADP Chemical Plot - MiniFrac #1 A I Losurf-3001) Conic (gal/Mgal) A WG -36 Conic (lb/Mgal) E 121vz016 Time 12Iv2018 Customer: tion: CONOC PHiL IPS-Aaska Job ate. 50-11)03-20774 Sales Order#: 0903873945 Well Kupawk iver C rvw Phillips Alaska, Im.- Kuparuk River 35611 Interval -2 Plotz 26 Treatment Plot - MiniFrac #2 A B IStun} Proppant( nnci I M„all (. BH Proppant Co IC(lb/gal) (' Ga.,,BH 3'ros(pxi) A Actual 13HTemp(°P) E C 1313no1a 121V2018 Time Conoco Phillips Alaska, Inc. - Kuperuk RWer 3S-611 Interval -1 Plots 27 A 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0. 0. 0. 0 Rlender Chemical Plot - MiniFrac #2 MO -67 Conc (gal/Mgal) B CL -22 UC Conc (gal/Mgal) — A Optiflo II Conc (IWMgal) B Optiflo-III Conc (Ib/Mgal) B CL -31 - -- - E 6 4 0 h e 15:40 15:50 16:00 16:10 16:20 16:30 16:40 16:50 Time 1210N19 1DV2018 Customer. CONOCO PHILLIPS - Alaska Job Date: 01 -Dec -2018 Sales Order* 0903873945 Nell Description: Kupamk River 3S-611 LIM 50-103-20774 Conoco Phillips Kaska, Inc. - Ruparuk River 35611 Interval -1 Plots 28 ADP Chemical Plot - MiniFrac #2 A I Losurf-300D Conc (gal/Mgal) A WG -36 Conc (ib/Mga1) E E 1VV2018 1111.1pTime Job Date: 01 -Deo -2018 I Sales Order* 0903873945 1 '"— Wall Descdptlon: Kuparuk Rmr3S-811 I U\M: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval -1 Plats Pressure Test - Day #2 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) -- — mazale Time 1V412018 Global Event Log Pressure Test 10:56:35 ❑3 Global Kickout 10:57:05 ❑4 Local Kckouts 10:58:22 Pressuretestend 11:16:18 ❑6 Testing Pop Off 11:19:53 ❑7 Tesling Pop Off 11:26:19 Customer: CONOCO PHILLIPS - Alaska Job Date: 04 -Deo -2018 Sales Order#: 0903873945 Well Description: Kupamk River 35-611 UVN: 50-103-20774 Conoco Phillips Alaska, I nc.-K,.a kNiver3i611 Inteml 0 Plotz 30 Treatment Plot - MiniFrac #3 SIurn PrnFrpnm ('nnr (Ibl�=q ( Nn Pivplhnt Cunc(14/gal) C A B Lange Rll Res (Inil A Ac(ual Rn Temp ff) E C E 12/4/2018 — Time 12/4/2018 Conoco Phillips Alaska, Inc. - Kuperuk River 35611 Interval 0 Plots 31 Blender Chemical Plot - MiniFrac #3 MO-67C (gal/Mgal) 6 CL-22 UC Conc (gal/Mgal)— A Optiflo II Conc Qb/Mgal) 13 A Optiflo-111O Conc (Ib/Mgal) B ---- B B wawie 12141018 Time Job Date: 04-DeG2018 I Sales Order#: 0903873945 1 Well Description: Kuparuk RiveOS-611 I INN: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Plotz 32 ADP Chemical Plot - MiniFrac #3 A Losurf-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgal) El E 1v4/2o1e "— - - -- - Time 12/4/4018 Time Customer CONOCO PHILLIPS -Alaska Job Date: 04 -Dec -2018 Sales Order* 0903873945 Well Description: Kuparuk Riwr 3S-611 Uw 50-103-20774 Conoco Phillips Alasia, Inc. - Kuparuk River 35-611 Interval 0 Plots n Treatment Plot - Interval 41 1m,Trrrilpant Cnnc (Ib/;;.ill C Ell proppant Conc(16lgal) C RB Prca trail a Actual BBTemp(°P} E C 13/4/2018 Tum1<rmevie Conon Phillips Alaska, Inc. - Kuppruk River 35-611 Interval 1 Plota 34 Blender Chemical Plot - Interval #1 MOfi7 Conc (gaUtvlgal) B CL -22 UC Conc (gal/Mgal)— A Optiflo II Conc (Ib/Mgal) B Optiflo-III Conc (Ib/Mgal) B Time Customer. CONOCO PHILLIPS- Naska Job Date: 04-DeP2018 Sales Order* 0903873945 Well Description: Kuparuk Ri�er3S-611 UVU: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval 1 Plots 35 ADP Chemical Plot - Interval #1 A I Losulf--300D Conc (gal/Mga1) A UUG-36 Conc (IblMgal) E E In 100 1 1 1 1.2- 1.0- 0.8 0.6F _. 0.4 0.0 1, 1 !lo 1410 14:20 14:30 14:40 14:50 15:00 15:10 15:20 15:30 121N201e Time 121NM18 Customer: CONOCOPHILLIPS-Plaska Job Date: 04 -Deo -2018 Sales Order#:0903873945 Ih�ll Description: Kuparuk River 35-611 JIM 50-103-20774 C na Phillips Alaska, Inc.- Kuparuk River 35-611 IRtemil1 Plots 36 A Net Pressure — Net Gauge BH Pres (psi) A PH Pmppant Conic (Ib/gal) B Slope of Net Pressure (psi/min) C Plot- Interval #1 Time NetPr BPC Slope �i -197.98 0.000 0.000 0.000 Time (min) Customer:criCONOCO PHILLIPS -Aaska Job Date: 04 -Dec -2018 Sales Order M: 0903873945 NkIl Desption: Kuparuk River 3S-611 U\M: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval l Plats A ling Pressure Treatment Plot - Interval #2 an Proppant Conc(lb/gal)C 12/4/2018 12/6/2018 Time Conoco Phillips Alaska, Inc. - Kuparuk River 3Y611 In.,.l2 PIOts Blender Chemical Plot - Interval #2 A IMOfi7 Conc (ga1/Mga1)6 CL -22 UC Conc (gal/Mgap — A Optiflo II Cone (Ib/Mgal) B Optiflo-III Cone (Ib/Mgal) B CL -31 Cone (gal/Mgal) 6 I B lime #: 0903873945 1 Well Descripflon: Kupamk Rieer3S-811 I uw 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparvk River 35611 Interval 2 Plots 39 ADP Chemical Plot - Interval #2 A Losurf-300D Conc (gal/Mgal) A WG -36 Conc (ib/Mgap E E _ 10 1 I 1 15:30 15:40 1550 1600 16:10 16,2121N0 18 IVNM18 Time Customer: CONOCOPHILLIPS-Alaska Job Date: 04 -Deo -2018 Sales Order#: 0903873945 "' Nkll Description: Kupamk Riwr 3S-611 LINA: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 2 Plots Q Net Pressure Plot - Interval #2 —Net Gauge BH Pres (psi) A Time NetPr BPC Slope — BH Proppant Conc (Ib/gal) B -1 -273.98 0.000 0.000 0.000 A Slope of Net Pressure (psi/min) C B 10 11 Time (min) Cuslomer. CONOCO PHILLIPS-Plaska Job Date: 04-Dea2018 Sales Order* 0903873945 Wall Description: Kuparuk Riser 3S-611 UIM: 50-103-20774 Conoco Phillips Alaska, Inc. - Kupasuk River 35611 Interval 2 Plots Pressure Test - Treating Pressure @Pump (psi) P5 Kickout Pressure (psi) I—— Time Global Event Log ❑e Pressure Test -Testing Locals 10:28:06 10 Pressure Test- Max Pressure First Half of Fleet 103512 11 Pressure Test- Max Pressure Second Half of Fleet 103803 1© Pressure Test -Good Pressure test, Bleed down to test Pop -OR 10:44:28 oustorner OC cONRer3LIIP5S; Kaska Job ate. 07 -Deo -201 8 Sales Order** 0903873945 WeIlOescription: Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Inteml 3 Plots 42 Pop -Off Test - Day 3 _._-_.._._..__. - -._,D_., Treating Pressure lo�PumO (,DS-Kickoklr r; ��c;•..-- ---- -- I n is Customer: CONOCO PHILLIPS - Plaska Job Date: 07 -Dec -2018 Sales Order#: 0903873945 Well Description: Kuparuk River3S-611 UW 50-103-20774 Conoco Phillips Alaska, Inc.-Kuparuk River 35-611 Interval 3 Plots 43 Pressure Test -Checking Pop-off 10:47:33 A Pressure Test- Pop -Off did not pop@ 8700 10:50:43 Pressure Test -Ensuring Pop -Off functionality 10:53:041© Pressure Test-Reseting Pop-OR1o8500 10:55:49 IA Truckside Pressure Released due to Pop -Off 10:58:24i® Verificationof Pop-Offrelease 11:00:59 Q Pressure Test- Pop -Off Release at 11:02:02 21 Bleeding down to 300psi to Open Well 11:03:10 Customer: CONOCO PHILLIPS - Plaska Job Date: 07 -Dec -2018 Sales Order#: 0903873945 Well Description: Kuparuk River3S-611 UW 50-103-20774 Conoco Phillips Alaska, Inc.-Kuparuk River 35-611 Interval 3 Plots 43 Trcatin. l`rcvsR rc (Psi) A B Gm,rvc RII Prez (p"0 Treatment Plot - Interval 3 .A $lorry Wtte (bpm) 13 M proppont Conc(lb/gan C' -------' t ketuul RH Temp (of) E 1217/2018 12/0/2018 Time Conow Phillips Mas", Inc.- Kupawk River 31611 Interval Plots 4 Blender Chemical Plot - Interval 3 o n. 'o i in r--- e nit A I Optillo-III Conc (Ib/Mgal) B CL -31 Conc 1219/2018 I'll.,. Time Sales Order#: 0903873945 I '"" — Wall Description: Kupamk River3S-811 I UVM 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval 3 Plots ADP Chemical Plot- Interval 3 Losurf-3001 Conc (gal/Mgal) A WG -36 Conc (16/Mgal) E —" V.. Time Wall Descdpbon: Kupamk Ri�er3S-611�as I UW: a� 50-1103-20774 Sales Order#: 0903873945 Conow Phillips Alaska, Inc. - Kupaiuk River 35-611 Interval 3 Plots Net Pressure Plot - Interval 3 —Net Gauge BH Pres (psi) A A — BH Proppant Conc (Ib/gal) B B Time (min) PHILLIPS-Aaska I Job Date: 07 -Dec -2018 I Sales Order#: 0903873945 I — Nell Desciipbon: Kupamk Rieer35-611 I uw 50-103-20774 Conow Phillips Alaska, Inc.- Kuparuk River 35611 Interval Plots Treatment Plot - Interval 4 A B Ilorry Prnplv:,t (lrne (➢;:p_dl C BFI Proppant Cole(lb/gan C Cunee B11 Pres (psi) % Actoal 1311 Temp( -F) E C 12MO19 -- Time 12/7/2019 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval 4 Plets 48 Blender Chemical Plot - Interval 4 MO -67 Conc (gallMga[)B CL -22 UC Conc (gal/Mgal)— A Optiflo II Cone Qb/Mgal) B A Optiflo-III Conc (Ib/Mgal) B CI_ -31 Conc (gal/Mgal) -- B tv71281e m712018 Time Customer: ption: - CONOC PHIL IPSAlaska Job ate. 50- 0320774 Sales Order#: 0903873945 WeIl C naca Phillip Alaska, Inc.-Kuparuk River 35-611 Intarva14 Plots 49 ADP Chemical Plot- Interval 4 nsurtanOD Cnnr- (oaUMcal) A VV6-3& Conc (Ib7Mg21) E E IIMe Customer CONOCO PHILLIPS - Alaska Job Date: 07 -Dec -2018 Sales Ober#:0903873945 Well Descrip8on: Kuparuk Ri,ver3S-811 UVNA: 50-103-20774 Conoco Phillips Flasks,Inc.1 - Kup amk River 35-611 Interva14 plots Net Pressure Plot - Interval 4 Net Gauge BH Pres (psi) A A — BH Proppant Conic (lb/gal) B Time (min) Customer: CONOCO PHILLIPS - Alaska Job Date: 07-13e�2018 Sales Order#: 0903873945 Wall Description: Kupamk Riser3S£11 JIM 50-103-2(774 Conoco Phillips Alaska, Inc. - Kuparvk River 3Y611 Interval Plots Slurry A B Gauoe BH Pres losn Treatment Plot - Interval 5 A Slurw Rate (born) BH Proppant Conc (Ib/gal) C A. Actual BH Temp ("F) E C lime Conow Phillips Alaska, Inc. - Kuparuk River 35611 Interval 5 Place 52 Blender Chemical Plot - Interval 5 MO -67 Conc (gallMgal)B CL -22 UC Conc (gal/Mgap A Optiflo II Conc ob/Mgal) B Optiflo-III Conc Qb/Mgal) B 1v7M19 IW712015 Time MIIDescription: Koparruk Ri�er9S617aaska Job UW: Date: 50-103.20774 Sales Order* 0903873945 Conoco Phillips Alaska, Inc.-Kuparuk River 35611 Intervel5 Plots 53 ADP Chemical Plot - Interval 5 A I Losurf--300) Cone (gal/Mgal)A VVG-36 Conc Qb/Mgal 1 1 0 14:30 14:40 1X0/2016 Customer: CONOCOPHILLIPS - NkllDesciiption: Kuparuk Ri,ver3S-611 000 0 0 15:00 15:10 1E Time Job Date: 07 -Dec -2018 Sales Ord( LINA: 50-103-20774 E E _ 1n 0 0 0 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval Plods 54 Net Pressure Plot- Interval 5 — Net Gauge BH Pres (psi) A — BH Proppant Conc (ib/gal) B Time (min) Customer: CONOCOPHILLIPS-Alaska 101 Date: 07-0eo-2018 Sales Order#:0903873945 M11 Description: Kupamk River 3S-811 UW 50-103-20774 Cnnoca Phillips Alaska, Inc. - Rupamk Giver 33.631 Interval 5 Plo[s ss Pressure Test- Interval 6 11 Global Kickcut Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) wall ❑5 Pressure Test-Pnme-Up Line Shut 12:58:28 © Pressure Test- Globals(100psi) 12:59:01 r Pressure Test -Locals 12:59:34 ® Pressure Test - Max Frsl Half 13:05:57 Q Pressure Test-MaxSewnd Half 13:08:40 Good Test, Bleeding down 13:14:03 4p Pressure Test -Testing Pop -Off 13:16:18 FIA Pressure Test -Pop Off Released 13:17:52 Pressure Test-Uenfication of Pop -Off 13:21:54 PHILLIPS -Alaska Job Date: 09 -Deo -2018 ive I UVA 50-103-20774 5 18 Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 6 Plots 56 Treatment Plot - Interval 6.1 Alam, i'n>pp�ut ('msc (Itdgap (' Bn Pcoppant Conc(l6/gap C R c,a.. rcw Pm, hw;t :4 Actual BFi'I'emp(-F) E C E Illi5o18 - - 111111— Time Conoco Phillips Alaska, Inc.- Kuparuk River 35-611 Intemal6 Plots Treatment Plot - Interval 6.2 �lvrry t'roppaot f'anc ilb!-allC 13n Proppaat Couc(lb/gan A B Gnoge ltli fres (psil A Actual6li'remp(°r)— C 12/9f2018 Time 12/9/2018 C rcco Phillips Alaska, Inc.- Kusaruk River 31611 Interval Plots 58 Blender Chemical Plot - I nterval 6.1 MO -67 Conc (galfMgal) 6 CL -22 UC Conc (gal/Mgal) — A Optiflo II Conc (IblMgal) B Optiflo-lll Conc (Ib/Mgal) B - - E _ B. lime Customer: CONOCO PHILLIPS -Alaska Job Date: 09 -Deo -2018 Sales Order*: 0903873945 VIkll Description: Kuparuk Rirter3S-611 UM 50-103-20774 Conoco Phillips Alaska, Inc. -Kuparuk pNer 35-611 Intenal6 Plots 59 Blender Chemical Plot -Interval 6.2 A IMO -67 Cone (gal/Mgal) B CL -22 LIC Cone (gal/Mgal) — A Optiflo If Cone (Ib/Mgal) B Optiflo-III Cone (Ib/Mgal) B CL -31 Colic (93llMO-31) — B lime Customer CONO OPHI LIPS -Rask Job : Date: 50-Dec320774 I Sales Order* 0903873945 tlon: MIlDescrip Conow Phillips Kaska, Inc. - Kuperuk River 35-611 Interval 6 Plots 60 ADP Chemical Plot- Interval 6.1 I..�rr_vnnn cone InavMaall A 4NG-36 Conc (IbfMgap E E 1&912018 Time Customer: CONOCO PHILLIPS - Alaska Job Date: 09 -Deo -2018 Sales Order* 0903873945 Wail DesCripfion: Kupamk Riaer3S-811 UW: 50-103-20774 Cor Phillips Alaska, Inc.- Kuparuk River 35611 Interval 6 Plots ADP Chemical Plot- Interval 6.2 Losurf-300D Conc (gaVMgap A CVG -36 Conc (Ib/Mgal) E time Sales Order#: 0903873945 1 — Well Description: Kuparuk River3S-611 I UVA: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval 6 Plats 62 Net Pressure Plot - Interval 6 Net Gauge BH Pres (psi) A A — BH PrObgant Conc (Ib/gal) B Time (min) Customer: CONOCO PHILLIPS-Plaska Job Date: 09 -Deo -2018 Sales Order#: 0903873945 Well Description: Kuparuk Riwr3Sfi11 UW: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35.611 Interval 6 Plots Treatment Plot - Interval 7 Shrcq Proppao I(Onc(Ildgail— (. BI Proinvant colic (INgal) C A B c:mge Rn Pres (pxh % Actaal BII Temp (eP s C ••,,,`"„' Time Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 7 Plats KI Blender Chemical Plot - Interval 7 MO -67 Conc (gal/Mgal) B CL -22 UC Conc (gal%Mgal) — A Optiflo II Cone (IWMgaI) B A Ootiflo-lll Conc (Ib/Meal) B __ B 1 13 Time Customer. CONOCO PHILLIPS -Aaska Job Date: 09 -Dec -2018 Sales Order#:0903873945 WaIl Description: Kuparuk Rh,er3S-611 UW: 50-103-20774 eonow Phillips Alaska, Inc. - Kuparuk River 35611 Interval 7 Plots 65 ADP Chemical Plot- Interval 7 Losulf--300D Conc (gall 1) A VVG-36 Conc (lblMgal) E 121&2018 1OW2016 Time Customer CONOCO PHILLIPS -Alaska Job Date: 09 -Dec -2018 Sales Order#: 0903873945 MIl Description: Kupamk Rieer3S-811 I UW: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparvk River 35-611 Irterval 7 Plots Net Pressure Plot - Interval 7 Net Gauge BPre H s (Psi) A A ..BH Pr000ant Conc (Ib/gap 6 B Time (min) Customer: CONOCO PHILLIPS - Alaska Job Date: 09 -Deo -2018 Sales Order#:0903873945 M11 Description: Kupamk Riper 3S-611 UW: 50-103-20774 Conoco Phillips Alaska,Inc.- Kupawk River 35-611 Intar l7 Plots 67 Slum• Praplaurt ('nn<(th'yali A B CaageBliPres(µri) Treatment Plot - Interval 8 BII Proppaw Conc (Ib{gal) Actual BH Temp (°F) — 13/98018 - @/92018 Time Cance Phillips Alaska, Inc. - Kupamk River 3$-611 Interval 8 Plots Blender Chemical Plot - Interval 8 MO -87 Conic (gal/Mgal) B CL -22 UC Conic (gal/Mgal) — A Optiflo II Conic (IblMgal) B A Ootiflo-III Conic (Ib/Meal) B B B 121WO18 Time imam Customer: CONOCO PHILLIPS -Alaska Job Date: 09 -Deo -2018 Sales Order#:0903873945 Nall Description: Kuparuk River 3S-811 I UIM: 50-103-20774 Conow Phillips Alaska, Inc. - Kup wk River 31611 Interval 8 Plots 69 ADP Chemical Plot- Interval 8 A I Losurf-300D Cone (qal/Maal) A WG -36 Cone (Ib/Mgal) E I E Customer: CONOCO PHILLIPS -Masks Job Date: 09 -Dec -2018 I Sales Order#:0903873945 MI Description: Kuparuk Riper 35-611 I LIM 50-103-20774 Wnow Phillips Alaska, Inc.- Kuparuk River 3S-611 Inteml8 Plots M Net Pressure Plot - Interval 8 —NeGauge BH Pres (psi) A A — BHt Proppant Conc (Ib/gap B Time (min) Customer: CONOCOPHILLIPS-Plaska Job Date: 09 -Dec -2018 Sales Order#:0903873945 Well Description: Kuparuk River 3S-811 I UW1: 50-103-20774 Conow Phillips Alaska, Inc. - Kuparuk River 35-611 Interval a Plats 71 Treating Pressure @Pump (p 10000 9000- 8000- 7000- 000 80007000 Fnnn - - — Pressure Test- Interval 9 Treating Pressure (psi) — P2 Kickoul Pressure (psi) 1144 11:46 11:48 11:50 11:52 11:54 11:56 1211]/2018 12/1}12016 Time Global Event Log Pressure Test - Test Globals 11:43:13 r5l Pressure Test -Locals 11:4, Pressure Test- Wx pressure First half of fleet 11:49:51 0 Pressure Test- f&xPressure test Second Half 11:5, Pressure Test- Good Test Bleed dawn 11:56:57 Customer. CON000PHILLIPS- Wall Description: Kuparuk River 3S-611 Job Date: 09-13eC 2018 UVA: 50.103-20774 0903873945 conow Phlllips Alaska,Inc.- Kuparuk Rlwr 35-611 Interval9 Plots J2 Nitrogen Pop-OffTest - Interval 9 It Global Kickout Pressure (psi) Treating Pressure (ps lj Treating Pressure @@Pump (psi) 12:00 12:01 12:02 12:03 12:U4 12/122018 12/12/2018 Time Global Event Log Pressure Test -Check Nitrogen Pop -Off 12:00:22 F5'N Pressure Test -Pop -Off 12:02:23 ® Pressure Test -Good Test Bleed off 12:03:11 Customer CONOCO PHILLIPS -Alaska Job Date: 09 -Deo -2018 Sales Order#: 0903873945 Well Description: Kupamk Riwr3S-611 UM 50-103-20774 Coraco Phillips Alaska, Inc. - Kuparuk River 35-611 Interval 9 Plots Pressure Test- Interval 9.2 11 Global Kickout Pressure (psi) Treating Pressure (psi) Treating Pressure @Pump (psi) P2 "ressure (psi) 1PI ;i1018 . rvtaeutn Time Global Event Log Pressure Test-Globals 11:48:06 Pressure Test -Locals 11:49:20 Pressure Test -Max First Half 11:55:24 Pressure Test -Second Half 11:58:44 Pressure Test -Good Test 12:00:32 Customer: CONOCO PHILLIPS -Alaska Job Date: 09 -Deo -2018 Sales Order#: 0903873945 Well Description: Kuparuk Riwer3S-611 UVA 50-103-20774 Conoco Phillips Alaska, Inc.- Kuparuk River 3&s1l Intenvil9 Plots 74 Treatment Plot - Interval 9.1 tihmy PrnPi�nt ('onc(Ib!2aq C BHPnppant Conc(Ib/gal) C A B Cauce BR A'ea (twi i 1 Ae M BH'1'emp (°n E I C 12/1](10 18 itnumm Time Conocp Phillips AW,inc.- Kup-pk Hive, 35-611 Interval9 Plon 75 Treatment Plot - Interval 9.2 Siom R'npryuu ('noc(B:/gap C BHPmppant Conc(lb/gal) C A AMual BH Temp(*F) H C E —1—.." Time .85 Conoco Phillips Alaska, Inc. - Kupatuk River 35611 Interval 9 plots J6 A 2.0 1.8 1.6- 1.4- 1.2- 1.0- 0.8- 0.6- 0.4- 0.2 .61.41.21.00.80.60.40.2 0.0 13:00 13:02 1DID2018 RlcnAcr i"homirml Pint - Interval 9.1 MO -u7 Conc (gal/Mgaq B CL -22 UC Conc (gal/Algal)— A Optiflo II Conc (IblMgal) B Optiflo-lll Conc (Ib/Mgal) B C'_ 31 i;nne. `naVP-dgaq B Customer: CONOCO PHILLIPS - Alaska Well Desaiptlon: Kuparuk River 3S-611 13:04 Time UW: 50-103-20774 13:06 1s:Ut5 1211&2016 B 4 3 2 1 Sr Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 9 Plms 77 Customer: CONOCO PHILLIPS - Alaska Well Desaiptlon: Kuparuk River 3S-611 13:04 Time UW: 50-103-20774 13:06 1s:Ut5 1211&2016 B 4 3 2 1 Sr Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 9 Plms 77 Blender Chemical Plot - Interval 9.2 0 19 00 I Ir ( ^— /nal IKA—l\ � A nmif Obtiflo-Ill Conc (Ib/Meal) B 0I_-31 Conc (gal/Mgal) " "'" Time Customer: CONOCO PHILLIPS -Kaska Job Date: 09 -Deo -2018 I Sales Order#: 0903873945 Wall Description: Kuparuk River 3S-811 UM 50-103-20774 Conoco Phillips Nasal, Inc. - Kupaiuk River 35-611 Interval 9 Plots 79 ADP Chemical Plot- Interval 9.1 A I Losurf-300D Conc (gal/M1) A WG -36 Conc (lb/Mgap E E 100 90 80 70 60 50 40 30 20 10 0 13:00 13:02 13:04 13:06 13:08 13:10 Time 1VIV2019 12112/2018 Customer: CONOCO PHILLIPS -Aaska Job Date: 09 -Dec -2018 Sales Order#: 0903873945 Nkll Description: Kupamk Riwr 3S-611 UW: 50-103-20774 2. 1.8 1. 1. 1. 1. 0. 0. 0. 0. 0 0 6 4 0 8 6 4 2 0 Conoco Phillipa Alaska, Inc -Kuparvk River 35-811 Intenal9 Plots 9 Conoco Phillipa Alaska, Inc -Kuparvk River 35-811 Intenal9 Plots 9 ADP Chemical Plot- Interval 9.2 Losurf-300D Conc (pal/Mgaq A WG -36 Conc (IblMgap E Customer: CONOCO PHILLIPS -Alaska Job Date: o9-UeOzuta Well Description: Kuparuk River3S-611 UVA 50-103-20774 Conoco Phillips Alaska, IrC.- Kuparuk River 35-611 Interval9 Pbts Net Pressure Plot - interval 9 Net Gauge BH Pres (psi) A A — BH Proppent Conc (Iblgal) B Time (min) CONOCO PHILLIPS -Aaska Job Date: 09-13eo-2018 Sales Order* 0903873945 Kupamk River 35-611 I LIM: 50-103-20774 Conow Phillips Alaska, Inc.- Kupawk fter 35611 Interval9 Plots Treatment Plot -Interval 10 Slurry Povpt.nnt C'nnc(Uilyap C Bn Ptoppant Cone(16/gal) C A B (:nnee ISn Prrs Gni) A .Actual BI1Ten,p(oF) E C .., ..�.,,... Tinx Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 10 Plots A 2.0 1.8 1.6 1.4 1.2 1.0 0.8 0. 0. 0. 0.0 I Blender Chemical Plot -Interval 10 MOE7 Conc (gal/Mg3" B CL -22 UC Conc (galiMgap — A uPnn0 n wrn: kIwlmga0 Optiflo-III Conc (Ib/Mgal) B .: ^. Cf) Es 6� 4 1 1550 12/1412018 Customer: CONOCOPHILLIPS- I/MiDescliption: Kupamk Riwr3S-611 16:00 16:10 Time UNA: 50-103-20774 16:20 16:3u 12/1412018 Sales Order#: 0903873945 B -4 -3 -2 I LO Conoco Phillips Nasky,Inc. - Kuparuk River 31611 Interval 10 Plots 83 ADP Chemical Plot - Interval 10 A I I ncIIrVAM1D Conc /aal/Maal1 A WG -36 Conc (IblMgaq E 12HM2018 I- —. Time Customer: CONOCO PHILLIPS-Aaska Job Date: 09 -Dec -2018 Sales Order#: 0903873945 WaIl Description: KupawkRi1-3 11 UVv1: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk River 35611 Interval 10 Plots ✓a Net Pressure Plot - Interval 10 — Net Gauge BH Pres (psi) A — BH Pr000ant Conc Ob/gal) B I Time (min) Sales Order#:0903873945 1 "'"""""- Well Description: Kupamk Rieer 3S-611 1 UW- 50-103-20774 Conga Phillips Alaska, Inc. - Kuparuk River 31611 Interval 10 Plots 85 Treatment Plot - Interval 11 A B I�lmn l'rop�aot Cmic (Ild�all (. BHPrappant Conc(lb/gal) C GaugC BH Rr5 (p+q A Actual BH Temp (oil C C 11114/12019 IL/IR2mX Time Condo Phillips Alazke, Inc.- Kuperuk RW, 35611 Interval 11 Plotz Blender Chemical Plot - Interval 11 MO -67 Cone (gallMgal)B cL-zz uC Conc (gapmgap — H upiino R tori ponvlgap o A Optiflo-III Conc (Ib/MgaI) B E3 B I Ime Customer: bon: K NOC RP,HILLIIPeS-Alaska Job ate: 50 -De 20774 Sales Order* 0903873945 WaIlDescrip Conow Phillips Alaska, Inc. - Kupamk River 35611 Interval 11 Plots ADP Chemical Plot - Interval 11 A I Losurt-300D Conc (gal/Mgal) A WG -36 Conc (Ib/Mgal) E IWV2018 121IV2018 Time Customer: tlon: CONOkRPHILLI S -Alaska UNC ate: 50-1D03-20774 Sales Order* 0903873945 Vikl[ Kuparu Conoco Phillips Alaska, Inc. - Kupawk Ri 33-611 Interval 11 Plots Net Pressure Plot -Interval 11 Net Gauge BH Pres(psi) A A — BH Proppent Conic (Ib/gal) B Time (min) Customer: CONOCO PHILLIPS -Alaska Job Data 09 -Dec -2018 Sales Order#: 0903873945 Well Description: Kuparuk River 3S-611 1 11VN: 50-103-20774 Conoco Phillips Alaska, Inc. - Kuparuk Riwr 35611 Intenxl 11 Plots HALLIMURTON Sales order# 0903873945 Conoco Phillips Alaska, Inc. Kuparuk River 35-611 Intervals -2-11 Lower Moraine Moraine Formation Harrison Bay County, AK API: 50-103-20774 Prepared for: Hanna Sylte December 2, 2018 Stimulation Treatment Appendix - Chemical Summary - Planned Design - Hydration Testing - Water Analysis - Bacteria Testing - Water Straps - Real Time QC - Event Log - Lab Testing Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Appendix 90 Customer Conoco Phillips Alaska, Inc. HALLISURTON n,—iu"h'n Formation Lower Moraine eonancar..enx Lease Kuparuk River 35-611 API 50-103-20774 Date 12/2/2018 Interval Summary - Chemicals Dry Additives Liquid Additives Interval LoSurf-3000 CL -31 CL -22 LIC MO -67 LVF -200 WG -36 BE -6 Opti Flo -III Opti Flo -II SP (!bs) (got) (got) (eoU (pot) (gal) (Ibs) (lbs) (16s) (lbs) qp IQ 20 11 0 1120 5 64 8 0 -2 6 13 16 9450 783 4 48 6 0 -1 26 29 26 0 1305 7 90 11 0 0 45 17 99 0 3734 19 247 31 0 1 134 60 111 2730 2842 15 195 25 9 2 91 52 84 92 80 127 0 3075 16 206 26 0 3 107 46 0 3117 35 207 26 0 4 110 44 86 117 120 5250 2808 16 193 28 9 5 107 47 85 0 3612 18 235 30 0 6 113 52 105 150 0 2779 15 192 24 0 7 94 43 86 125 131 5625 3039 16 223 26 7 8 110 45 89 91 101 3234 3500 15 200 25 0 9 101 45 100 0 2862 15 190 25 0 10 100 43 85 101 2520 3134 15 180 21 8 11 102 39 82 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Chemical Summary .nae, e „D --eas e- se T— i Conedo Phillips Alaska, Inc. - Kuparuk River 33-611 Planned Design se r s. ass as $ „m f p . D a 4 vD n s;;. ` ses�v as I Is w wa awI es sa 24 M. ` F � w yp 0 u4nFW NNO sPD Dm lm Mwa pwr,a:YPY' LPD mlWtl ,� 4 w. as �.4 °W�.�a&°wvp � nxpws rD° Conedo Phillips Alaska, Inc. - Kuparuk River 33-611 Planned Design r T I I I I I I I I I 93 canom Phillips Alaska,Inc.-Kuparuk giver 35-611 Planned Design . .... N�lA4` lsWw IwV 19PIm fWN 17,7 M1IU rNl l�vl (n• IM*wW b%1 bNl 243 1,9 •d g: w wm mw ia3 ppb w 9 aww 0 Nunn wxp s m.,.p„.v _ metre 5ua gg �xdv_ "Ww py €40 wx,m,-a �.a ti roHo mxx.ma �oiw uw w m.xe,. 4mjss ga® o A nW &IS 2W 02 nxyts x'� 9 mrww.a 'ar Mo .yaw 93 canom Phillips Alaska,Inc.-Kuparuk giver 35-611 Planned Design .— .-- e[oIWfW ess — ui mau[w[ HT' Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Planned Design 94 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 3S-611 Date: 12/2/2018 Formation: Moraine SOM 0903873945 Day: 1 Hydration Tests, Viscosity (c P) Time (min) Tank 1 Tank 2 Tank 3 1 15 15 15 3 22 24 23 6 26 29 27 9 26 29 28 12 26 30 28 15 26 30 28 18 - 30 - 21 30 24 30 *Full hydrations listed for tanks 1-25 Conoco Phillips Alaska,Inc. - Kuparuk River35-611 Hydration Testing 95 HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: ConocoPhillips Alaska, Inc. Well Name/No.: Kupamk River 3S-611 Date Tested: December 3, 2018 Water Type: Sea water Specific Gravity pH Iron (Fe) Chloride (Cl) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity Crosslink pH Crossknk Test (Y/N) m....1. 1 7-tr 1 T -t, a T-11, d Tunk c Tank 6 Tank 7 Took 8 Tank 9 units Tank 10 Tank it Tank 12 Tank 13 Tank 14 Tank 15 Tank 16 Tank 17 Tank 18 Specific Gravity pH Iron (Fe) Chloride (C1) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity Crosslink pH Crossknk Test (Y/N) Specific Gravity PH Iron (Fe; Chloride (Cl] Sulfate (SO4; Calcium (Ca' Hardness Linear Viscosity Crossknk pH Crosslink Test (Y/N; - 1.028 1.028 1.029 1.028 1.028 1.0280 1.0280 1.0280 1.0280 - 7.16 7.12 7.11 7.16 7.18 7.24 7.2 7.2 7.1 . /L 0 0 0 0 0 0 0 0 0 m /L 27830 30270 36130 33010 30270 30270 25640 30270 25640 mg/l, >1200 >800 >800 >1200 >1200 >1200 >1200 >1200 >800 m /L 380 400 440 360 280 240 240 240 240 m /L 2160 2560 2280 2320 2560 2720 2600 2160 2400 CP 26 30 28 28 28 29 30 30 30 H 10.4 10.2 10.1 10.2 10.3 10.2 10.2 10.2 10.2 Y Y Y IY Y Y Y Y Y units Tank 10 Tank it Tank 12 Tank 13 Tank 14 Tank 15 Tank 16 Tank 17 Tank 18 Specific Gravity pH Iron (Fe) Chloride (C1) Sulfate (SO4) Calcium (Ca) Hardness Linear Viscosity Crosslink pH Crossknk Test (Y/N) Specific Gravity PH Iron (Fe; Chloride (Cl] Sulfate (SO4; Calcium (Ca' Hardness Linear Viscosity Crossknk pH Crosslink Test (Y/N; - 1.0280 1.0280 1.0290 1.0280 1.0280 1.0280 1.0280 1.028 1.028 6.95 7.2 7.17 6.97 6.95 7.06 7.08 7.18 7.17 7.19 /L 0 0 0 0 0 0 0 0 0 m /L 30270 30270 27830 27830 27830 27830 27830 30270 20060 /L >1200 >800 >900 >1600 >1600 >1600 >1200 >800 >1200 nag/L 240 240 210 240 280 200 240 280 400 /L 2440 2320 2740 2600 2320 2400 2320 2320 2440 29 29 30 31 30 30 28 28 29 H 10.3 10.3 10.1 103 10.1 10.3 10.1 10 10 Y Y Y Y Y Y Y Y Y -r. 1. 1. T..-,11 T. -t, 11 T..-. 91 T -n 11 Tnnk 24 - 1.028 1.028 1.029 1.028 - 1.028 1 1.028 - 7.07 7 6.95 6.92 6.97 6.91 mg/L 0 0 0 0 0 0 mg/L 25640 21860 27830 30270 23660 25640 mg/l, >1600 >1200 >1200 >1200 >1200 >1200 m /L 320.00 320.00 360.00 400.00 360.00 400.00 m /L 2480 2480 2320 2400 2320 2440 CP 29 27 28 30 28 27 28 - 10.1 10.1 10.2 10.1 10.1 10.1 10.1 Y Y Y I Y Y Y Thi+report is dss propem of Halliburton semen+ pop oeiNerit nor any part there of.copy thereofmay be published or disclosed oithou, fnIl securing the express ufaen appmval ofl+b.Ince Nasagoscol. nII.. howesey k oust N We tours ofregular business oW... ps, by sny pmson or concern and cinpl.,ce, Nereofrecoiving such report Som Milburn. Scnicea such report or rause. Conoco Phillips Nash, Inc. -Kuparuk Pier 35611 WP -M uih, and Zones 1-2 96 HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Compan, ConocoPhillips Alaska, Inc. Project Number Zones 3-5 Well Name/No.: 35-611 Date Tested: December 6, 2018 Water Type: Seawater Specific Gerrit) PB Iron (Fe; Chloride (CI; Sulfate (SO4,' Hardness Alk.h.itl Linear Viscositi CrosslinkpF Crossfirdr Test (YIN Specific Graviv PF Iron (Fe Chloride (CI Sulfate (SO4 Hardie. Alkakrdr Linear Visco.it Cro.slink pF Crasslink Test (YIN Specific Gravity pF Iron (Fe; Chloride (CI Sulfate (SO4 Hardin. Allialmio Linear Viscusin Crosslink pF Crosalirlle Test (YIN m_ .- 1.. IN +1.026 LOU B.Sll B.SJB 9.530 8.5299 8.5383 8.5383 8.5299 7.43 8.25 7.9 1 7.33 1 7.64 1 7.36 1 7.21 I ].25 17.33 7.38 7.38 mg/L 0 0 0 0 0 1 0 I01 0 0 0 . /L 17670 19725 17670 17670 17670 15910 15910 19725 17670 mg/L 1200 2560 80 1200 2400 80 800 800 DAO 1200 800 800 800 m /L 30 31 2400 2240 2720 2400 2560 2400 2240 mg /L 10.15 10.16 120 80 80 80 BO 80 80 N 30=29 Y 29 29 30 29 32 31 31 pH 10.1 10.15 10.2 10.15 10.15 10.21 10.17 Y Y Y Y Y Y Y m_ .- 1.. IN fm+mpcn is os.,o mof-dubwanz-WTrueraror.m vvn Uercorwmpy NcwfmaYbe vablisM1elmaiaYSNwiuewfiw xsuvg lMervrevw+ilunepmoralotUMrawry manvpemmt Ilmau, M1ox'eer.he maim Ure.'mureofrepWarbuirci, opentv.m q'en) R'r000r wxan aM empl%ttv IM.mfreeervmg+ueM1rtyWl ffmm Hd4bwm 3ervms. N.c.: 1hihn .il Hml M lioble6rvm'W.maamey, wbMnauc battoremu+io¢issulwp (rcm susM1repm or vias. c,,om PhH1,,n Nmk,,1M auaa.uka-135 611 Wuer Fnalysis tunes 11 97 8.5466V 8.5466 1 8.5466 8.5466 1 85632 8.5466 8.5466 8.547 8.547 7.43 7.25 7.22 1 7.28 1 248 1 7.36 7.34 7.48 7.38 7.56 mg/L 0 0 1 0 0 0 0 0 0 0 ing/L 17715 17670 19725 19725 17715 ME 17670 15910 17670 mg/L mg/L /L 1200 2560 80 1200 2400 80 1200 24002560 80 800 80 800 2080 80 B00 2400 80 800 2240 120 1200 1920 120 800 2560 120 cp 30 31 30 29 31 29 33 29 30 PH 10.15 10.16 10.17 10.2 10.23 10.24 10.16 10.18 10.16 10.1 Y Y Y Y Y Y Y I V Y fm+mpcn is os.,o mof-dubwanz-WTrueraror.m vvn Uercorwmpy NcwfmaYbe vablisM1elmaiaYSNwiuewfiw xsuvg lMervrevw+ilunepmoralotUMrawry manvpemmt Ilmau, M1ox'eer.he maim Ure.'mureofrepWarbuirci, opentv.m q'en) R'r000r wxan aM empl%ttv IM.mfreeervmg+ueM1rtyWl ffmm Hd4bwm 3ervms. N.c.: 1hihn .il Hml M lioble6rvm'W.maamey, wbMnauc battoremu+io¢issulwp (rcm susM1repm or vias. c,,om PhH1,,n Nmk,,1M auaa.uka-135 611 Wuer Fnalysis tunes 11 97 +8.547 8.530 8.547 8.547 8.530 8.530 9.515 738 7.43 7.31 7.44 7.46 7.42 7.47 mg/L 0 0 0 0 0 0 0 /L 19725 19725 17715 22165 15910 17670 19725 nag/L >S00 800 800 800 800 800 800 mg/L 2440 2240 2240 2200 2140 2640 2400 /L 80 80 120 80 80 120 80 ep 28 31 32 29 31 31 3D PH 10.22 10.15 10.2 10.18 10.24 10.1 10.2 Y Y Y Y Y Y Y fm+mpcn is os.,o mof-dubwanz-WTrueraror.m vvn Uercorwmpy NcwfmaYbe vablisM1elmaiaYSNwiuewfiw xsuvg lMervrevw+ilunepmoralotUMrawry manvpemmt Ilmau, M1ox'eer.he maim Ure.'mureofrepWarbuirci, opentv.m q'en) R'r000r wxan aM empl%ttv IM.mfreeervmg+ueM1rtyWl ffmm Hd4bwm 3ervms. N.c.: 1hihn .il Hml M lioble6rvm'W.maamey, wbMnauc battoremu+io¢issulwp (rcm susM1repm or vias. c,,om PhH1,,n Nmk,,1M auaa.uka-135 611 Wuer Fnalysis tunes 11 97 HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company. Conocophieips Alaska, Inc. Project Number Zones 6.8 Well Name/No.: 3S.611 Date Tested: December 8, 2018 Water Type: Seawater __. �-. TnnL'/ Tan4A Tnn40 Specific Gravir p} Iron (Fe Chloride (CI Sulfate (SO4 Hardnes Misalinit, Linear Visemit Croselink pk Cmsslimc Test (Y/N Specific Gravip PB Iron (Fe) Chloride (0) Sulfate (SO4) Hardness Alkaliniq Linear Viscosity Crossimic pH Crosshulr Test (Y/N, Specific Gmviry pP Iron (Fe Chloride (CI; Sulfate (SO4; Hardness Alka4niry Linear Viscasin Cmsslink pF Co s diuls Test (Y/N - 1.024 1.022 LOU I L024 I L024 1.0240 1 1.0260 1.0250 1.0260 - 7.31 7.41 7.46 7.43 7.5 7.48 7.71 7.51 7.44 ra/L 0 0 0 0 0 0 0 0 0 . /L 15910 17670 17670 15910 17715 17715 15910 177H 15910 m9/1. 800 800 800 800 S00 1200 800 800 800 mg/L 2360 2440 2400 2400 3200 2400 3200 3120 3160 en/L 120 180 180 180 120 120 120 120 SO eP 29 30 29 31 29 29 31 30 31 pH 10.10 10.25 10.16 10.22 10.10 10.00 10.40 10.10 10.10 Y Y Y Y Y Y Y Y Y - -Kpg,p/L L0240 1.0260 1.0260 1.0280 1.0260 1.0260 L0250 1.025 L025 - 7.49 7.51 7.43 7.48 7.36 7.34 7.56 7.38 7.56 mg/L 0 0 0 0 0 0 0 0 0 .9/L 15910 17670 19725 17670 17715 17715 15910 15910 17670 mg/L 1200 800 1200 800 800 S00 800 1200 800 mg/L 3200 3200 3000 3200 2080 24110 3120 1920 2560 mg/L 80 80 120 120 80 80 180 120 120 cp 29 30 29 31 31 29 31 29 30 pH 10.30 10.10 10.20 10.10 10.23 10.24 10.05 10.18 10.16 Y Y Y Y Y Y Y Y Y - -Kpg,p/L 1.025 1.024 1.024 1.024 1.024 LON 1.026 7.38 7.33 7.54 7.49 7.45 7.51 7.51 0 0 0 0 0 0 0 19725 17260 19120 19120 17280 15680 17280 800 1200 800 800 1200 1200 1200 2440 3200 3200 3200 3000 3200 3000 80 120 I80 120 120 I80 120 28 29 31 31 31 29 3l 10.22 10.10 9.80 10.10 10.00 10.05 9.80 Y Y Y Y Y Y Y Thi:areann ieapopanrarxmAnwrtre,viasammiva ama.nr van WeRorttm wracr.r o,b,Wuna mdaamamw finunabg,h ayre•..w.ttapp.aai ariaeaalm nogg mit Mhft,rn km Wiebomn 5ensma. NMIC6: Thurtpxtia4miud io iMae¢nbMumOk lived A,ryueerofihiartpon�eesaw HW4bwton aNll mt be lwbk rmamkavatlartuge. xfiMaauewva, o,emvaim.,ewlmg fiam anae rein -in ux. Conam Milliq Rkitr.kcRupamk Rirva35b11 WaYrAnaNsis oaY3ane568 9a Specific Gmviq pE Iron (Fe; Chloride (Cl; Sulfate (SO4' Calcium (Ca; Hardness Linear Viscosity Crosslints pi Crmsli3dc Test (YIN Specific Gmvit. p1 Gon (Fe Chloride (CI Sulfate (SO4 Calcium (Ca Hardnes Linear Viscosit Crosslhdc p1 Crosslmk Test (YIN Specific Graviq PE Iron (Fe; Chloride (Cr Sulfate (SO4' Calcium (Ca; Hirci.. Lnear Viscosity Camalink p1 C..1mc Test (VIN HALLIBURTON 1.024 ALASKA DISTRICT FIELD LABORATORY 1.022 WATER ANALYSIS REPORT Company. ConocoPhillips Alaska, Inc. Project Number Zones 9.11 Well Name/No.: 3S-611 Date Tested: December 12, 2018 Water Type: Seawater Specific Gmviq pE Iron (Fe; Chloride (Cl; Sulfate (SO4' Calcium (Ca; Hardness Linear Viscosity Crosslints pi Crmsli3dc Test (YIN Specific Gmvit. p1 Gon (Fe Chloride (CI Sulfate (SO4 Calcium (Ca Hardnes Linear Viscosit Crosslhdc p1 Crosslmk Test (YIN Specific Graviq PE Iron (Fe; Chloride (Cr Sulfate (SO4' Calcium (Ca; Hirci.. Lnear Viscosity Camalink p1 C..1mc Test (VIN m_1_ae -. Tnn41a aia..0 1.024 1.024 1.024 1.022 1.024 1.0240 1.0260 1.0260 10260 7.63 0 0 0 0 0 0 0 0 0 mg/L 0 0 0 0 0 0 0 0 0 mg/L 18000 17200 19200 17200 19200 18400 19600 00 18333.33333 . /L 800 800 800 800 800 800 800 0 800 mg/L 1120.00 1800.00 1800.00 1800.00 200000 1800.00 ff26OO2800 0.00 1800.00 /L 2800 2080 2800 3200 2560 2800 2600 2800 2800 c'P 31 32 29 31 31 28 31 9 30 pH 10.0.4 10.07 9.93 9.97 10.03 9.96 9.94 85 9.94 Y Y Y Y Y Y Y Y Y m_1_ae -. Tnn41a aia..0 . 10260U60 .a.... 1.0240 ... L0240 10260 _. 10260 10260 1.0240 1.026 1.025 7.63 7.62 7.54 7.61 7.50 7.8 9.61 7.64 7.53 7.61 mg/L 0 0 0 mg/L 18400 0 0 0 0 mg/L 17600 19200 17200 800 1200 D200 19600 17600 16800 /L 1200 800 800 M2000.00 E-- 800 800 800 800 mg/L 2000.00 2000.00 2000.00 2800 3400 1800.00 1600.00 2600.00 1400.00 - mg/L 2800 2800 2600 pH 9.78Y 3120 2600 2800 Mw silly 30 30 30 Y 30 30 31 28 31 PH 9.91 9.91 9.80 9.98 1 9.81 9.91 9.94 9.75 9.81 Y Y Y Y Y Y Y Y Y 1-11,1 Tan. lS This Non is theWms, Of Ha14bwm:erviws"rciuer it mr am p^^osoofnor trier moofmay be publulM or dittWvol%iYwt Doss xvuNB lk y,,aay xnlun NprwaloN.1-a'n7 nuragmma Ilmay Mxever.beoeM mare muxofrcgWvrbuvineacpuvlorsbyamµrsonmawv+n eM entploreev Wrrmrrteeb'irs ewM1rtpon ffomlWltibuton Yrviwa. Nmcj:'f,,,,,on istaroe b aredexdmistor touvea. Np uw ofdtisreponagrtv WIHeIGbubnsbvllrcata 4abk Imatry Ion mdvrege. wM1elhndw baclwunuam reaWbng Gem vucb«pon or lug. C.yoo"I". AlaiMa. I nc- euPouk abler 35611 Water Analysis Day 411 99 1.026 1.024 1.026 1.026 1.026 1.026 1.026 7.61 7.63 7.51 7.57 7.45 7.50 7.53 mg/L 0 0 0 1 0 0 0 0 mg/L 18400 1960018200 17800 17400 17000 78000 /L 800 800 1200 800 800 No 1200 mg/L 1800.00 1800.00 1800.00 1800.00 1600.00 2000.00 2000.00 an/L 2600 2600 2600 2600 2900 2800 3400 cP 31 30 30 31 29 30 31 pH 9.78Y 0Y 9.93 9.97 9.9 Y Y Y Y Y This Non is theWms, Of Ha14bwm:erviws"rciuer it mr am p^^osoofnor trier moofmay be publulM or dittWvol%iYwt Doss xvuNB lk y,,aay xnlun NprwaloN.1-a'n7 nuragmma Ilmay Mxever.beoeM mare muxofrcgWvrbuvineacpuvlorsbyamµrsonmawv+n eM entploreev Wrrmrrteeb'irs ewM1rtpon ffomlWltibuton Yrviwa. Nmcj:'f,,,,,on istaroe b aredexdmistor touvea. Np uw ofdtisreponagrtv WIHeIGbubnsbvllrcata 4abk Imatry Ion mdvrege. wM1elhndw baclwunuam reaWbng Gem vucb«pon or lug. C.yoo"I". AlaiMa. I nc- euPouk abler 35611 Water Analysis Day 411 99 H^"IBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: ConocopbiBips Alaska, Inc. Project NVmbes Kann }.5 AOIName/No.: 35-611 Das. Tested: December 6, 2018 Water Type: Sea rwker Sample ID temp Reaction time Analytical Blank Value Sample Volume filtered Dilution Mukiplier Sample Analysis Value BQValue Tankl Ol (mint 30 (FLU) 200 (tell 60 'dneeded 1 (FLU) 1150 Calculated 3457 Tank256 t15.56 30 200 503181 4284Tank356 30 257 50 3 13534]86 Took456 30 2)1 50 1 751 2096 56 30 281 50 1 27M 10843 Tank656 30 291 50 1 2189 8289 Tank7 15.56 30 297 50 1 1116 3577 Tank 8 15.56 30 276 50 1 1129 3725 Tank 9 15.56 30 293 50 1 2322 8861 Tank W 15.Sfi 30 238 50 3 2103 8145 TanX 11 15.56 30 224 50 1 1906 7346 Tank 12 15.56 30 217 50 1 1470 54)2 Tank 13 15.56 30 214 50 1 $564 23364 Tank 14 15.56 30 221 50 1 4540 18862 Tank 35 15.56 30 247 50 1 187fi ]114 Tank 16 15.56 30 217 50 1 435.5 954 Tank 17 15.56 30 212 50 1 358) 14739 Tank 18 15.Sfi 30 50 3 527 1555 Tank 19 15.56 30 50 1 689 2336 Tank 30 IS.Sfi 30 50 1 685 SJ99 Tank 21 15.56 30 5224 50 1 546.2 1337 Tank 22 15.56 30 50 1 49313Tank 2315.56 30 50 1 519 1332 Tank 24 15.56 30 240 50 1 2)96 11164 Tank 25 15.56 30 226 50 1 603.1 1646 1.n 1Fa,..u, l--eu,kBmr 95611 Banerla T-IM711" tro HA,"IBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Compan, ConocoPluMps Alaska, Inc. Project Number Zoaes 6$ Well Name/No.: 384U Dam Tested: December 8, 2018 Water Type: Sea oyster Sample 10 Roam temp ReaRion time Analytical Blank Value Sample Volume filtered Dilution Multiplier Sample Analysis value gQ value (degC) (min( IsLUI (ml) Hateled (FW) Calculated Tank 15.56 30 218 50 1 583.5 1598 Tank2 15.56 30 215 50 1 558.9 1501 Tank3 15.56 30 231 50 1 1061 3623 Tank4 15.56 30 219 50 1 1444 5352 Tanks 15.56 30 230 50 1 1405 5130 Tank 6 15.56 30 254 50 1 1122 3792 Tank7 15.56 30 202 50 1 1170 4228 Tank 1 15.56 1 30 209 50 1 938.5 3186 Tank 15.56 30 211 50 1 807 2601 Tank10 15.56 30 21250 1 1115 3942 Tank 11 15.56 30 223 50 1 689 2036 Tank 12 15.56 30 149P550 1 2265 9241 Tank 13 15.56 30 166 1 3242 13433 Tank 14 15.56 30 221 1 4540 18862 Tank IS 15.56 30 247 1 1876 7114 Tank 36 15.56 30 219 1 3444 14066 Tank 17 15.56 30 217 1 658.2 1927 Tank38 15.56 30 171 1 527 1555 Tank 19 15.56 30 154 1 689 2336 Tank20 15.56 30 210 1 1799 6938 Tank21 15.5630 204 1 1104 3930 TmI22 15.56 30 228 1 667.3 1918 Tanit 15.56 30 238 50 1 473.1 1028 Tenk 24 15.56 30 212 50 1 1179 4223 Tank 25 15.56 30 33 50 1 1457 6220 CenaoP6iAiµ ln[Ma. In[1(WmlPnr 31611 tn.w. T.,Z eto M HALLIBURTON ALASKA DISTRICT FIELD LABORATORY WATER ANALYSIS REPORT Company: Coaocdaluffi, Alaaka, Inc. Project Number Zone. 941 We0 Name/No.: 3SLI1 Dam Tr,.d: Ilecember 12, 2018 Wamc Type: Seawater Sample ID Roam temp Reaction time Analytical Blank Value Sample Volume Ditered Dilution Multiplier Sample e Bgwlue (degQ (min FLU( (ml) if needed (FLU) Calculated Tank I 15.60 30 233 50 1 2293 7498 Tank 2 Tank Tank Tanks Tank6 15.60 30 225 50 1 4635 19258 Tank T Tank Tank 9 Tank 10 123 15.60 30 222 50 1 631.2 1)88 456T8 E 15.60 30 214 - 50 1 288.8 2509 92021 15.60 30 223 50 1 10255 43811 Tank 22 Tank 23 Tank 24 Tank 25 I—. rr.' aska. in<.-oup nrvn 35611 aMemlann{hna411 1{I Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35-611 Date: 12/2/2018 Formation: Moraine SOM 0903873945 nav: 1 Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Water slaps-Minifracs 103 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Wichita CPF3 98 19,740 470 116 97 19,530 465 2 Wichita CPF3 0 0 0 N/A 90 18,060 430 3 Wichita CPF3 97 19,530 465 95 90 18,060 430 4 Atigan CPF3 100 18,774 447 106 97 19,530 465 5 Atigan CPF3 99 18,606 443 101 95 19,110 455 6 Atigan CPF3 98 18,396 438 101 94 18,900 450 7 Atigan CPF3 101 18,984 452 102 100 20,160 480 8 Atigan CPF3 101 18,984 452 101 99 19,950 475 9 Atigan CPF3 100 18,774 447 96 91 18,270 435 10 Wichita CPF3 99 19,950 475 96 92 18,480 440 11 Atigan CPF3 98 19,236 458 98 89 17,850 425 12 Atigan CPF3 102 19,194 457 107 89 17,850 425 13 Atigan CPF3 100 18,774 447 103 90 18,060 430 14 Atigan CPF3 102 19,194 457 98 101 20,370 485 15 Wichita CPF3 101 20,370 485 98 77 16,170 385 16 Atigan CPF3 101 18,984 452 101 101 20,370 485 17 Wichita CPF3 99 19,950 475 103 96 19,320 460 18 Atigan CPF3 103 19,362 461 90 101 20,370 485 19 Atigan CPF3 103 19,362 461 88 104 21,000 Soo 20 Atigan CPF3 104 19,572 466 101 103 20,790 495 21 Atigan CPF3 101 18,984 452 89 78 15,540 370 22 Atigan CPF3 105 19,782 471 98 14 3,486 83 23 Atigan CPF3 105 19,782 471 104 8 1,512 36 24 Atigan CPF3 102 19,194 457 9513 4,536 108 25 Atigan CPF3 95 17,808 424 96 78 15,540 370 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons I Barrels 461,286 10,983 422,814 10,067 38,472 1 916 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 810 2 424 2 3,450 8 314 3 5,590 12 225 4 8,000 17 124 5 0 458 6 0 458 7 C 458 Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Water slaps-Minifracs 103 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35-611 Date: 12/2/2018 Formation: Moraine SOM 0903873945 naw- 2 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Water Straps -Minifrac-Zone2 104 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (°F) Inches Gallons Barrels 1 Wichita CPF3 97 19,530 465 111 10 1,890 45 2 Wichita CPF3 90 18,060 430 92 13 2,436 58 3 Wichita CPF3 90 18,060 430 101 13 2,436 58 4 Atigan CPF3 97 19,530 465 102 12 1,806 43 5 Atigan CPF3 95 19,110 455 101 13 1,974 47 6 Atigan CPF3 94 18,900 450 92 10 1,428 34 7 Atigan CPF3 100 20,160 480 89 10 1,428 34 8 Atigan CPF3 99 19,950 475 87 7 882 21 9 Atigan CPF3 91 18,270 435 95 11 1,596 38 10 Wichita CPF3 92 18,480 440 83 13 1,974 47 11 Atigan CPF3 89 17,850 425 83 9 1,260 30 12 Atigan CPF3 89 17,850 425 91 75 13,944 332 13 Atigan CPF3 90 18,060 430 95 43 7,476 178 14 Atigan CPF3 101 20,370 485 91 47 8,274 197 15 Wichita CPF3 77 16,170 385 86 83 2,814 67 16 Atigan CPF3 101 20,370 485 86 88 1 16,464 392 17 Wichita CPF3 96 19,320 460 90 50 9,660 230 18 Atigan CPF3 101 20,370 485 76 42 7,266 173 19 Atigan CPF3 104 21,000 500 75 43 7,476 178 20 Atigan CPF3 103 20,790 495 92 7 882 21 21 Atigan CPF3 78 15,540 370 77 11 1,596 38 22 Atigan CPF3 14 3,486 83 N/A 15 2,352 56 23 Atigan CPF3 8 1,512 36 N/A 52 9,324 222 24 Atigan CPF3 13 4,536 108 N/A 14 2,142 51 25 Atigan CPF3 78 15,540 370 83 8 4,158 99 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons Barrels Gallons Barrels 422814 1 10067 112938 2689 309876 7378 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms BBL): 1 3,000 7 307 2 6,000 14 177 3 0 438 4 0 438 5 0 438 6 0 438 7 0 438 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Water Straps -Minifrac-Zone2 104 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35-611 Date: 12/7/2018 Formation: Moraine SOM 0903873945 nom.,. 3 Znnes 3-5 Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Water Straps - Zones 3-5 105 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (*F) Inches Gallons Barrels 1 Wichita CPF3 102 20,580 490 107 13 2,457 59 2 Wichita CPF3 101 20,370 485 100 13 2,457 59 3 Wichita CPF3 102 20,580 490 107 13 2,457 59 4 Atigan CPF3 106 19,950 475 103 9 1,262 30 5 Atigan CPF3 104 19,572 466 100 9 1,262 30 6 Atigan CPF3 106 19,950 475 98 9 1,262 30 7 Atigan CPF3 105 19,740 470 104 9 1,262 30 8 Atigan CPF3 106 19,950 475 106 9 1,262 30 9 Atigan CPF3 104 19,572 466 100 9 1,262 30 10 Wichita CPF3 101 20,370 485 102 11 2,079 50 11 Atigan CPF3 106 19,950 475 101 24 4,182 100 12 Atigan CPF3 105 19,740 1 470 98 77 14,339 341 13 Atigan CPF3 105 19,740 470 102 67 12,405 295 14 Atigan CPF3 106 19,950 475 103 94 17,627 420 15 Wichita CPF3 101 20,370 485 112 97 19,530 465 16 Atigan CPF3 105 19,740 470 96 77 14,339 341 17 Wichita CPF3 105 21,210 505 102 96 19,320 460 18 Atigan CPF3 109 20,538 489 117 102 19,175 457 19 Atigan CPF3 106 19,950 475 112 97 18,208 434 20 Atigan CPF3 105 19,740 470 122 39 6,737 160 21 Atigan CPF3 104 19,572 466 93 41 7,102 169 22 Atigan CPF3 107 20,160 480 112 41 7,102 169 23 Atigan CPF3 107 20,160 480 112 9 1,262 30 24 Atigan CPF3 107 20,160 480 94 9 1,262 30 25 Atigan CPF3 105 19,740 470 113 9 1,262 30 Location Summary Starting Volume Ending Volume Total Used Gallons Barrels Gallons I Barrels Gallons Barrels 501354 11937 180875.5 1 4306.56 320478.48 7630.44 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms BBL): 1 2,160 5 391 2 4,320 9 305 3 6,480 14 218 4 8,640 18 132 5 0 477 6 0 477 7 0 477 Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Water Straps - Zones 3-5 105 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35-611 Date: 12/9/2018 Formation: Moraine 5OM 0903873945 Da • 4Zones 6-8 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Water Straps - Zones 63 106 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature(°F) Inches Gallons Barrels 1 Wichita CPF3 102 20,580 490 112 13 2,457 59 2 Wichita CPF3 101 20,370 485 113 13 2,457 59 3 Wichita CPF3 100 20,160 480 113 12 2,268 54 4 Atigan CPF3 105 19,755 470 115 9 1,262 30 5 Atigan CPF3 106 19,949 475 113 9 1,262 30 6 Atigan CPF3 105 19,755 470 115 9 1,262 30 7 Atigan CPF3 107 20,142 480 114 9 1,262 30 8 Atigan CPF3 105 19,755 470 116 10 1,444 34 9 Atigan CPF3 106 19,949 475 116 9 1,262 30 10 Wichita CPF3 101 20,370 485 114 12 2,268 54 11 Atigan CPF3 105 19,755 470 119 9 1,262 30 12 Atigan CPF3 106 19,949 475 112 45 7,873 187 13 Atigan CPF3 105 19,755 470 120 46 8,078 192 14 Atigan CPF3 106 19,949 475 114 92 17,241 410 15 Wichita CPF3 100 20,160 480 111 70 13,860 330 16 Atigan CPF3 106 19,949 475 116 107 20,142 480 17 Wichita CPF3 101 20,370 485 97 60 11,760 280 18 Atigan CPF3 105 19,755 470 110 60 10,992 262 19 Atigan CPF3 105 19,755 470 105 58 10,576 252 20 Atigan CPF3 106 19,949 475 118 57 10,367 247 21 Atigan CPF3 106 19,949 475 100 57 10,367 247 22 Atigan CPF3 107 20,142 480 102 50 8,910 212 23 Atigan CPF3 90 16,854 401 105 52 9,327 222 24 Atigan CPF3 105 19,755 470 103 57 10,367 247 25 Atigan CPF3 105 19,755 470 160 50 8,910 212 Location Summary Starting Volume Ending Volume Total Used Gallons I Barrels Gallons I Barrels Gallons Barrels 496584.9 1 11823.45 1177237.11 4219.93 319347.84 7603.52 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms (BBL): 1 2,160 5 387 2 4,320 9 300 3 6,480 14 214 4 8,640 18 127 5 0 473 6 0 473 7 0 473 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Water Straps - Zones 63 106 Customer: Conoco Phillips Alaska, Inc. Well: Kuparuk River 35-611 Date: 12/14/2018 Formation: Moraine SON: 0903873945 Dav: 5 Zones 9-11 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Water Straps - Zones 9-11 101 General Beginning Strap Ending Strap Tank Type Water Source Inches Gallons Barrels Temperature (*F) Inches Gallons Barrels 1 Wichita CPF3 102 20,160 480 103 34 6,426 153 2 Wichita CPF3 101 20,160 480 99 16 3,024 72 3 Wichita CPF3 100 20,160 480 93 16 3,024 72 4 Atigan CPF3 105 19,562 466 108 9 1,262 30 5 Atigan CPF3 106 19,755 470 104 25 4,182 100 6 Atigan CPF3 105 19,755 470 103 9 1,262 30 7 Atigan CPF3 107 19,755 470 107 10 1,444 34 8 Atigan CPF3 105 19,949 475 105 47 8,286 197 9 Atigan CPF3 106 19,755 470 102 26 4,365 104 10 Wichita CPF3 101 20,160 480 113 46 8,820 210 11 Atigan CPF3 105 19,755 470 100 47 8,286 197 12 Atigan CPF3 106 19,755 470 101 98 18,401 438 13 Atigan CPF3 105 19,755 470 91 79 14,726 351 14 Atigan CPF3 106 19,755 470 101 48 8,494 202 15 Wichita CPF3 100 20,160 480 103 94 18,900 450 16 Atigan CPF3 106 19,949 475 99 47 8,286 197 17 Wichita CPF3 101 20,160 480 102 46 8,820 210 18 Atigan CPF3 105 19,949 475 106 47 8,286 197 19 Atigan CPF3 105 19,949 475 106 47 8,286 197 20 Atigan CPF3 106 19,755 470 95 9 1,262 30 21 Atigan CPF3 106 19,949 475 106 12 1,809 43 22 Atigan CPF3 107 19,562 466 109 14 2,174 52 23 Atigan CPF3 90 0 0 NA 47 8,286 197 24 Atigan CP 105 19,562 466 120 9 1,262 30 25 Atigan CPF3 105 19,562 466 104 8 1,079 26 Location Summary Starting Volume Ending Volume Total Used Gallons I Barrels Gallons I Barrels Gallons I Barrels 476745.78 1 11351.09 1160452.21 3820.29 1 316293.6 1 530.8 Pre -Job Barrel Bottoms Zones: Volume Needed for X Intervals (BBL): Number of Tanks Needed: Tank Bottoms BBL): 1 2,160 5 383 2 4,320 9 293 3 6,480 14 203 4 8,640 18 113 5 0 473 6 0 473 7 0 473 Conoco Phillips Alaska,Inc. - Kuparuk River 3S-611 Water Straps - Zones 9-11 101 HALLIBURTCS1\I Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 611 Date: December 4, 2018 Interval Stage Visc pH Temp T XL pH Comments I Mini -Frac 30 74 9.8 Pad 34 74 10 1# 34 74 9.8 2# 33 74 9.9 3# 1 32 72 9.8 4# 33 1 72 9.8 5# 30 69 10 6# 7# 2 Pad 34 69 10 1# 29 70 10 2# 1 30 69 10 3# 30 1 67 10.5 4# 34 69 10.5 5# 32 69 10 64 32 65 10 7# Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Real -Time QC - Zones 1-2 108 01011411 =Mb tORT WMEA Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 611 Date: December 7, 2018 Interval Stage Visc pH Temp T XL pH Comments 3 Pad 35 65 10.2 0.25 28 72 10.2 1# 31 79 10.1 12//7/18 2# 31 87 10.03 3# 30 1 75 10.25 4# 30 75 10.1 5# 30 75 10.2 6# 30 75 10.2 7# 30 75 10.2 4 Pad 79 10.1 0.25 34 1# 30 77 10.05 2# 32 81 10.05 3# 32 81 10.1 4# 32 81 10.5 5# 32 78 10.5 6# 80 10.1 7# 5 Pad 33 78 10.1 0.25 31 82 10.5 1# 31 80 10 2# 32 80 10.05 30 80 10.05 4# 30 80 10.5 5# 30 1E3# 80 10 6# 28 80 10 7# 29 85 10 Conoco Phillips Alaska,Inc. - Kuparuk River 35-611 Real -Time QC - Zones 3-5 109 ... Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 611 Date: December 9, 2018 Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Real -Time QC - Zones 6-8 110 MEN= Conoco Phillips Alaska, Inc. - Kuparuk River 35-611 Real -Time QC - Zones 6-8 110 , M � , Ofti ■ Customer: ConocoPhillips Alaska, Inc. Wellname & #: Kuparuk River 3S - 611 Date: December 14, 2018 Interval Stage Vise pH Temp °F XL pH Comments 9 Pad 24 62 9.9 0.25 35 72 9.9 1# 24 82 9.9 12/14/2018 2# 25 80 10 3# 25 70 10.1 4# 25 80 9.9 5# 25 78 10 6# 25 74 9.9 7# 27 77 10 10 Pad 35 78 82 10 0.25 25 10 1# 1 35 78 10 2# 35 78 10 3# 35 78 9.9 4# 35 78 10 5# 33 78 10 6# 33 78 10.2 7# 31 74 10.2 II Pad 0.25 28 74 10.1 1# 28 82 10.1 2# 27 80 10.1 3# 28 82 10.1 4# 28 82 10.1 5# 28 78 10.1 6# 1 28 1 78 10.1 7# 25 80 10.2 Conoco Phillips Alaska,Inc.-Kuparuk River 3S-611 Real Time QC - Zones 911 111 PN,J,a bmksnn:PPry Zone 1 Crosslink Tests -Pai -1 Me -g PPP -3 PN -4 PP9 5 PP9 'e .g ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■M■■■92■■■■■■■■■■■■■■MR:20 .,,, ■■■■■�iii����■�■■■I!■\iii■/■■■■■ ■■■11■��■■■■■■��■■■■■■1■■■■■■■■■ „■ ■■■■■■■■■ E 91MIMENNEWEENEMENEMENNEUMENn Tim(minxc) ALASKA DISTRICT LABORATORY 16 Minute Farm Model 35 Crosslinked Fluid Report Temp°F Fluid System: L.URF4(I00 Date: 1 Company: ConocoPhillips Project No:_ Well Name: 3S-611 Stage(s):_ BHST CF): 140 Water Source: s Depth: Water pH:_ Formation: Hydration pH: Analyst: Hydration vsc: cp@ PN,J,a bmksnn:PPry Zone 1 Crosslink Tests -Pai -1 Me -g PPP -3 PN -4 PP9 5 PP9 'e .g ■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ ■■■■M■■■92■■■■■■■■■■■■■■MR:20 .,,, ■■■■■�iii����■�■■■I!■\iii■/■■■■■ ■■■11■��■■■■■■��■■■■■■1■■■■■■■■■ „■ ■■■■■■■■■ E 91MIMENNEWEENEMENEMENNEUMENn Tim(minxc) Cane. P"114,MaW,I.. 6uparvk Wrw3S611 is 14111-1 NI CMmICY connnlMbns E im are In gYbne in, Min,zaM I p Temp°F .46 L.URF4(I00 CL42UC CL41 MO87 Optlg li 0p111 , Test 30.00 1.00 0.90 0.45 1.20 2.00 0.26 mini Frac 30.00 1.00 0.90 0.46 1.20 2.00 0.26 Pad 30.00 1.00 0.90 0.45 1.20 2.00 0.25 1# 30.00 1.00 0.90 0.46 1.20 2.00 0.25 2# 30.00 1.00 0.90 0.45 1.20 2.00 0.25 3# 30.00 1.00 0.90 0.46 1.20 2.00 0.26 4# 30.00 1,00 0.90 0.45 1.20 2.00 0.25 5# 30.00 1.00 0.90 0.46 1.20 2.00 0.25 Cane. P"114,MaW,I.. 6uparvk Wrw3S611 is 14111-1 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Farm Model 35 Crosslinked Fluid Report Fluid System: Company: ConocoPhillips Project No: Well Name: 35-511 Stage(s): BHST(°F): 140 Water Source: Depth: Water pH: Formation: Hydration pH: Analyst- Hydration Visc: al W Nu..— Temp'F M45 LMURFJWD CL -22 UC Job 30.00 1.00 0.90 1 ppg 2 PP9 3 ppg 4 ppg "'°"bon i 00q Zone 2 Crosslink Tests —PM —1 ppp —z ppg —3 ppg —4 PP9 —5 PP9 woo 4wo moo 3sao 'n u 3000 wo two loon soo 0 perlMueaM 1 powas pern�e.m CL11 MO87 OpllfloAl OpU ] 0.45 0.50 2.00 0.25 W'Oo 1000 itoo UN 13:00 14:W 19 TNe lmi :se=I LanaW FM1iIIIps Alaska.ln[.�Ruyrvk Pires31d11 Fan ]S IDne] 11i Canom 14, [lip Asia. I m.-Rupar.k Rl 35 11 Fen l,. -s 114 HALLIBURTON °"° " °gyp Zone 3 Crosslink Tests ALASKA DISTRICT LABORATORY -Pea -1 ppg -2 P9 -3 W,g -4ppg -5 ppg 15 Minute Farm Model 36 Crosslinked Fluid Report 4909 3sao Fluid System: Date: 12/7/2018 Company: ConocoPhillips Project No: 31M Well Name: 3S.611 Stage(s): zup BHST (-F): 140 Water Source: sea water 3000 Depth: Water pH: y 1sc9 Formation: Hydration pH: 1009 a Analyst: Hydration Visc: gp@ sco 1 I � 1 I I I I . �-4 0 . . . 00'.00 o1 O] . - 03:011 p]:oll -cWeo WOO 0700 000 WW 10M 1100 lzoo 13'.00 14:00 16M Time Im . eq NI chemical concentrations below am In gallons par t pppi/ pawtls per lMusand Lot Number- Tnapi W333 LOSURFd000 CL42 UC CL41 1687 00iM41 owner SP eroaar ad 100 Meet 30.00 1.00 0.90 0.45 1.20 2.00 0.26 1 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.25 2 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.26 3 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.26 4 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.26 5 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.25 Canom 14, [lip Asia. I m.-Rupar.k Rl 35 11 Fen l,. -s 114 Mid ""aRx f00co Zone 4 Crosslink Tests -Psd -1 Ppa -2 Mg -3pg -4 PP9 -5 PP9 3500 3aoo " " "11111111'Ill III II In In Turelrineq Lot NumCer-+ ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Temp F Fluid System: LOSURF4KIm Date: i Company: ConocoPhiliips Project No:_ Well Name: 35-511 Stage(s): BHST CF): 140 Water Source: sl Depth: Water pH: Formation: Hydration pH: Analyst: Hydration Visc: -PG Mid ""aRx f00co Zone 4 Crosslink Tests -Psd -1 Ppa -2 Mg -3pg -4 PP9 -5 PP9 3500 3aoo " " "11111111'Ill III II In In Turelrineq Lot NumCer-+ All clamacal concemralona bebw are In gallon pn Monaca 1 pomMa W notational Temp F W 6 LOSURF4KIm CL -32 UC CL41 Modl 0p41floJ11 ad 100 Meet 30.00 1.00 0.90 0.45 1.20 2.00 0.25 1 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.26 2 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 3 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.26 4 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 5 ppg 6ppg 7 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.25 Lonoco MIIIIpe Mason,Inc. - Xunauk PMr 35411 rn 15 Annn9 115 HALLIBURTON ALASKA DISTRICT LABORATORY 15 Minute Fann Model 35 Crosslinked Fluid Report Fluid System: Date: 121`712018 Company: ConocoPhillips Project No: Well Name: 3S-611 Stagels): BHST VF): 140 Water Source: sea water Depth: Water pH: Formation: Hydration pH: Analyst: Hydration Vise: cp@ F"1tl1 p1o1enaf p Zone 5 Crosslink Tests -Pea -1 ppg -2M -3 ppg -4 ppg -5 ppg 4" 3YA 3000 2SM Z 2(M 1500 S ]qao 500 D nm[Im�n. eq ]oao It '12!1J) ]soo laao ]s lnl Number-+ NI[FeM[L eozeMru]bns Eebwvningallonf pa MDuzvM I pouMc pertlwuuM Imp F .1. LOSURF. D CL42 UC CL411 M047 OptIPOJII Optiflcll 3F ad 100 Most 30.00 1.00 0.90 0.45 1.20 2.00 0.26 1 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 2 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.26 3 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 4 ppg 30.00 1.00 010 0.45 1.20 2.00 0.25 5 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 (nno[o PM1llllprflntr.lnr.. Kupank gNn35�6t1 Fan 133one5 3]6 I., ss m.ae m HALLIBURTON Runs! Isbmasnaf100c^ Zone 6 Crosslink Tests ALASKA DISTRICT LABORATORY -pad 100 unah -1 ppg -2 ppg -3 ppp -3.5 ppg -4 ppg 15 Minute Fann Model 35 Crosslinked Fluid Report 3500 Fluid System: Date: 121912018 3000 Company: ConocoPhillips Alaska Project No: 2WO Well Name: 35-611 Stage(s): $ -2000 77 BHST rF): 140 Water Source: Sea Water e no two Depth: Water pH: Formation: Hydration pH: 1000 Analyst: Hydration Visc: cp@ 500 0 WOO 0100 0300 0300 MOO 0600 MOO 07'.00 WOO MOO 1000 11:00 12M 13:00 1G00 1500 Time lmlnseq Ld Numla r� AH CImmis.l CmmaMmtion. Eabw are In gallons W lMusand / munals pmr UhousaM Temp°F WWB LOSUp.FJ000 CL -22 UC CLll Mow o0soin 0pged41 ad 100 Meal 35.00 1.00 0.90 0.45 1.20 2.00 0.25 1 ppg 35.00 1.00 0.90 0.45 1.20 2.00 0.25 2 ppg 35.00 1.00 0.90 0.45 1.20 2.00 0.26 3 ppg 36.00 1.00 0.90 0.45 1.20 2.00 0.26 3.5 ppg 35.00 1.00 0.90 0.45 1.20 2.00 0.26 4 ppg 35.00 1.00 0.90 0.45 1.20 2.00 0.26 I., ss m.ae m 0 0 i M Nu., HALLIBURTON CPtIMAII ALASKA DISTRICT LABORATORY Mk 16 Minute Farm Model 36 Crosslinked Fluid Report Y1036 Fluid System: CL42 UC Date: 1 Company: ConocoPhillips Alaska Project No:_ Well Name: 3S-611 Stage(s):_ BHST rF): 140 Water Source: SI Depth: Water pH: Formation: Hydration pH: Analyst: Hydration Visc: cp@ 0 0 i M Nu., louMs per tlmumM CPtIMAII All chemical concen4albns Mk Tempi Y1036 ..11ald00D CL42 UC C111 M0d1 ad 100 Meal 35.00 1.00 1.20 0.46 1.20 1 ppg 35.00 1.00 1.20 0.45 1.20 2 ppg 35.00 1.00 1.20 0.45 1.20 3 ppg 35.00 1.00 1.20 0.45 1.20 3.5 pPg 36.00 1.00 1.20 0.46 1.20 4 ppg 35.00 1.00 1.20 0.45 1.20 so0 sw oao sro 000 sw Zone 7 Crosslink Tests -PeE 100 MeM -IM -2ppg -3ppg-3.5pp9 -4PP9 gallons Pn tMusand/ louMs per tlmumM CPtIMAII 0"flo-g 2.00 0.25 2.00 0.25 2.00 0.26 2.00 0.25 2.00 0.26 2.00 0.25 r Ima-1 I I I .I 1100 1200 13:M Consoo PMIIIp Ms..Inc-l.n..k Mw.11 fen 11 Zone] 118 ALASKA DISTRICT LABORATORY 15 Minute Farm Model 36 Crosslinked Fluid Report Fluid System: Fwx"°'oNxiaf00`° Zone 8 Crosslink Tests �paa too M°vM1 -lppe -2ppe -�ppa -3.5 ppg -4ppg sco rop soo ��El���NEMEMNENEWEENEEME\11MENE0��. 7L7lM�l1 Tine !min ac) d NumW Date: 12/9/2018 Company: ConocoPhillips Alaska Project No: .O o LOSORF4ND Well Name: 3S-611 Stage(s): ooifloNl u BHST rF): 140 Water Source: Sea Water' 0.90 Depth: Water pH: 2.00 E Formation: Hydration pH: 1.00 0.90 Analyst: Hydration Visc: cp@ 0.25 sco rop soo ��El���NEMEMNENEWEENEEME\11MENE0��. 7L7lM�l1 Tine !min ac) d NumW NI cM cal-MrY ns Ezbwan 1. .M- per M..nd IF TmpF .O o LOSORF4ND CL -22 UC CL11 M047 ooifloNl Opalbll 3d 100 Meal 30.00 1.00 0.90 0.46 1.20 2.00 0.26 1 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 2 ppg 30.00 1.00 0.90 0.45 1.20 2.00 0.25 3 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.26 3.5 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.26 4 ppg 30.00 1.00 0.90 0.46 1.20 2.00 0.26 Gnem MIIIIMAWFaInc � Xupyuk Plver 35 61] Fan 153om 0 13y ulalwmiaconcentralona "n'°'ea,paenatrapnp Zone 9 Crosslink Tests -Paatoo Mean -frog -2ppg -3rog -35 PP9 �4pP9 mmmt�NUMEMEMENEENE1 monoFLINN NONE O MEMO IMOM�����1 M■■■MMMM 11■■■■■■■■■■■■I �Mo�ilmosommosommolmommiloommummonnowlMINOR !!MMMEMwEMMMM1------------ new an in gallons Per tlwuyn0 / pouMe per taauaarlel Temp F ALASKA DISTRICT LABORATORY LOs,,pp .. 15 Minute Farm Model 35 Crosslinked Fluid Report CL41 Fluid System: Optifl u Date: 1: Company: ConocoPhillips Alaska Project No: Well Name: 3S-611 Stage(s):_ BHST(aF): 140 Water Source: S Depth: Water pH:_ Formation: Hydration pH:_ Analyst: Hydration Met: cp® ulalwmiaconcentralona "n'°'ea,paenatrapnp Zone 9 Crosslink Tests -Paatoo Mean -frog -2ppg -3rog -35 PP9 �4pP9 mmmt�NUMEMEMENEENE1 monoFLINN NONE O MEMO IMOM�����1 M■■■MMMM 11■■■■■■■■■■■■I �Mo�ilmosommosommolmommiloommummonnowlMINOR !!MMMEMwEMMMM1------------ new an in gallons Per tlwuyn0 / pouMe per taauaarlel Temp F wo. LOs,,pp .. CL -}3 UC CL41 MOA) Optifl u 0011o41 id 100 Meal 30.00 1.00 0.90 0.45 1.00 2.00 0.25 1 ppg 30.00 1.00 0.90 0.46 1.00 2.00 0.25 2 ppq 30.00 1.00 0.90 0.45 1.00 2.00 0.25 3 ppq 30.00 1.00 0.90 0.45 1.00 2.00 0.25 3.5 ppg 30.00 1.00 0.90 0.45 1.00 2.00 0.25 4 ppg 30.00 1.00 0.90 0.46 1.00 2.00 0.25 W0-0 FMllipe Alana, IM-Nuparvk Weer 35612 Fan 152ane 9 1l0 [uew TlillimAliew, lne.- Nupamk River/ 11 fan lS Zone l0 ]33 HALL18URTON ALASKA DISTRICT LABORATORY � Hkbveenar�p Zone 10 Crosslink Tests 15 Minute Farm Model 35 Cmsslinked Fluid Report -pee100 Mem -lppg -3pM -3ppg-3.5ppg -4ppg two Fluid System: Company: Date: ConocoPhillips Alaska Project No: 10/12/2018 2M Well Name: 3S-671 Stage(s): =�wp BHST(oF): 140 Water Source: Sea Water Depth: Formation: Water pH:caX03^ Hydration pH: Analyst: Hydration Viso: gp g! wo a wN 01,w 02w moo ww OS.w W:oo ,7w MW MOD 10.00 1100 1200 1"0 1400 1500 rewe M xumbn-+ NI chemical conmmratnne Wbw zre m galbne per uwusane r pouMs pe•1MuauM ad 100 Masi Temp°F WOde LOSURF.WO CLQ3 UC 30.00 1.00 0.90 CL31 MOd7 Ophwal 0.45 1.00 2.00 0"fic-1 0.26 1 ppg 30.00 1.00 0.90 0.45 1.00 2.00 0.25 2 ppg 30.00 1.00 0.90 0.45 1.00 2.00 0.25 3 ppg 30.00 1.00 0.90 0.45 1.00 2.00 0.25 3.5 ppg 30.00 1.00 0.90 0.45 1.00 2.00 0.26 4 ppg 30.00 1.00 0.90 0.45 1.00 2.00 0.25 [uew TlillimAliew, lne.- Nupamk River/ 11 fan lS Zone l0 ]33 Fwmbcr.x.n rt]pp.P ZC one 11 rossllnk Tests -Pad �1ppg �1 pre -3pp9 -35 PP9 �4pG9 ON W00 W00 MM 0700 NM MW MOO 11:M IZOO 1300 Tim. erun:secq Lal NumEer- M1 <eemic.r mn..nb@wn. MIm m in gtlbna per Muvani ( ALASKA DISTRICT LABORATORY LOSURF400D CL -M UC 15 Minute Farm Model 35 Crosslinked Fluid Report ..7 ooifl n Fluid System: 26# Hybor G 2a 1.00 Date: 1211212018 is 1e Company: ConocoPhillips Alaska Project No: 1 ppg 30.00 1.00 191 Well Name: 3S-611 Stage(s): $ 1x BHST (PF): 140 Water Source: Sea Water " is Depth: Water pH: & 6( Formation: Hydration pH: > 6( Analyst: Hydration Visc: -P� u x one 11 rossllnk Tests -Pad �1ppg �1 pre -3pp9 -35 PP9 �4pG9 ON W00 W00 MM 0700 NM MW MOO 11:M IZOO 1300 Tim. erun:secq Lal NumEer- M1 <eemic.r mn..nb@wn. MIm m in gtlbna per Muvani ( Ca-pM1Hlipr P1.W. lnc-itniu k 1rra3Sb1, 1.n IS... 11 "1 T-P-F WGJB LOSURF400D CL -M UC CL41 ..7 ooifl n Pad 30.00 1.00 0.90 0.46 1.00 2.00 1 ppg 30.00 1.00 0.90 0.45 1.00 2.00 2 ppg 30.00 1.00 0.90 0.45 1.00 2.00 3 ppg 30.00 1.00 0.90 0.46 1.00 2.00 3.6 ppg 30.00 1.00 0.90 0.45 1.00 2.00 4 ppg 30.00 1.00 0.90 0.45 1.00 2.00 Ca-pM1Hlipr P1.W. lnc-itniu k 1rra3Sb1, 1.n IS... 11 "1 Canem Phillly AlaAa.Inc - ALparuk Pico 35611 .rc ,..-Mim'- 123 Treating Type Seg No. Time Activity Code Comment lob Slurry Vol Pressure Slurry Gauge BH naPump Rate Pres (bbl) (psi) (bpm) (psi) E 1 14:12:53(12/01/18) StartJob Starting Job 0 0 0 2173 T 114:12:53(12/01/18) Next Treatment Treatment Interval l 0 0 0 2173 E 2 16:34:20 Pause Suspending Job 60.08 0 0 0 E 3 07:27:45(12/02/18) Resume Resuming Job 60.08 18 0 2173 E 4 7:31:16 Pause Suspendinglob 60.08 0 0 0 E 5 9:26:14 Resume Resuming lob 60.08 17 0 0 E 6 12:34: 32 Prime Pumps Prime Pumps 123.41 -2 1.8 2172 E 7 12:35:02 Pressure Test Pressure Test 124.07 1917 0 2172 E 8 12:48:05 Pressure Test Pressure Test S Minute 124.42 9243 0 2172 E 9 12:52:40 Pressure Test Testing Pop off 125.08 3130 3.9 2172 E 10 13:07:03 Pressure Test Pressure Test -N2 Popoff 125.1 8544 0 2172 E 11 13:11:36 Pressure Test Pressure Test- N2 Popoff Confirmation 125.1 8550 0 2172 E 12 13:13:28 Other Pulling on chems, Mixing Gel 125.1 7641 0 2172 5 1 14:09:25 Next Stage Load Well 125.1 819 0 2172 E 13 14:09:53 Other Breakdown 0.68 1540 4.7 2172 S 2 14:24:09 Next Stage Mini -Frac 26.31 960 0 2946 5 3 14:38:21 Next Stage Flush 522.74 2627 8.1 3463 E 14 14:44:30 Perform Formation Test Mini Frac Pressure analysis 802.94 5390 49.4 5255 E 15 14:44:441SIP ISIP 809.31 80 0.2 3554 S 4 14:44:50 Next Stage Shut -In 809.34 41 0 3139 5 2 15:3139 Next Stage Mini -Frac 809.34 25 0 3105 5 1 15:32:14 Next Stage Load Well 809.34 26 0 3104 E 16 15:33:06 Other Mirfrac%2 809.34 50 0 3102 E 17 16:21:48 Other Breakdown 925.65 2814 14 4000 S 3 16:35:34 Next Stage Flush 1132.25 2062 SS 3822 5 4 16:57:13 Next Stage Shut -In 1446.04 2169 15 3597 E 18 17:03:351SIP 151P 1538.2 765 0 3172 E 19 203547 Pause Suspending Job 1591.76 0 0 0 E 20 30:47:58(12/03/18) Resume Resuming Job 1591.76 34 0 3169 E 21 11:07:51 Pause Suspending lob 1607.51 0 0 0 E 22 1118:43 Resume Resuminglob 1607.51 37 0 3169 5 1 11:19:05 Next Stage Load Well 1607.51 37 0 3169 5 2 11:20:28 Next Stage Mini -Frac 1607.51 36 0 3169 5 1 11:20:37 Next Stage Load Well 1607.51 35 0 3169 5 4 11:2116 Next Stage Shut -In 1607.9 49 0 3169 E 23 15:54:29 Pause Suspending Job 1612.39 0 0 0 E 24 09:04:14(12/04/18) Resume Resuming Job 1612.39 38 0 2299 E 25 9:04:19 End lob Ending Job 1612.39 38 0 2275 Canem Phillly AlaAa.Inc - ALparuk Pico 35611 .rc ,..-Mim'- 123 type Sey No, Tine bei EOEe [ommem lob$ium var Treating Pressure@Pump Slurrvwte Geroge BN Fres (660 mew) (bpm) �pN� 1 10:01:00(13/0418( Shallot Starting Mb 0 0 6.3 0 110:01:21(13/M1lg� NeHTre 0 0 63 0 l 16.56:35 Pressure Test Test Preatme Testervall lo T6[ 6196 79 O 2273 3 3058:21 Other Other Global Globallockout61.86 131 0 2372 < 1O161S Other LDas gMouts 61.86 1166 0 2272 5 11:1952Other PressuTestinretestff 61.91 911E O 2272 6 111952 Other Testing Pop ON 6203 8330 O 2272 ] 11:26:18Other Testing Popparding ON 62.03 9339 0 3272 8 12:18:28 use Suspenr.J.bb 62.18 0 p p 9 13:3041 Remi Pump ingl.E 62.18 34 0 2383 10 13:00:58 Pump Prepatl Pump P pump P66.08 2803 108 3692 1 13:25:31IfirstStage mai- Well <II 78.23 2853 10.2 3233 3 1331:20 N. Stege Puimp 275.31 3596 19.2 3586 IS 13:3I360ther Mi Min4Fmc 26753 3180 356 3811 3 13:36:16 NeM518ge Rump Rush 4M 40 5059 0 13:83:50 .1P5Other ge S .3.31 1003.35 95 0 3380 11 13M3fi Other Pressure Pressure Moni[OYMB 3003.36 111 0 3281 5 16:10:67 Next Stage Pad 1013.36 110 0 3320 6 10:38,41 Next Stage Pad 1315.28 OSEB 00.1 4690 ] 10:35FO Nea[Stage Rapport La Fragrant Latlen Fluid 2015.9 596E 50.1 5]00 8 15:54:55 Next Stage stoppers laden Fluid 2306.09 411103 00.1 5025 9 15:55:16 Nert Stage Proppant len Fluid 396063 5019 39.9 5235 10 15:06:03 NeelProppant laden Fluid 353533 5215 39.9 5510 11 15:16:10 Neat Stage Spacer lBetlen Fluid 35622.8 SJ99 39.6 5771 12 15:23:11 Drop 3912.6 2138 398 6081 13 1£25:19 Other Other Drop Orap Ball 3998.50 6809 39.8 6336 115:39:30 (32/21/1g) Nan Treatment Treatment lnteml2 6139.96 5593 36.8 SMO 1 15:2930 NeH Pad 0139.95 1593 36.7 0999 16 nStage 1592:50W Sea Belton Sea[ 5235.0 5357 5989 3 SSeal 1598:38 Nen Stage Pad CondPropprinst 50M.36 5868 45 5236 3 15:53:38 NediStage Le srorprut Latlen Fluid 5088.30 S6. .a H.8 5258 6 15:56:00 Neal Prospers Fluid 5339.30 S. H.8 520 5 15:59: 33 Next Stage toden Rop08nt Laden Fluid 5389.30 S539 44.9 5291 6 160336 Ness Stage Proppant Laden fluid 5579.35 6093 d5.9 5581 ] Ness Stage Proppant Laden Fluid 5895.13 6631 85.6 5828 8 Ill 16:13:50 Nest Stage Specer m Laden FNitl 6221.36 6031 502 5695 10 16:19:11 N<M 518ge DSII D[Dr 636616 6327 39.1 5955 15 16:33:05 ISIPShu 1SOp GDP 6575.81 83 0 3398 16 16:38:58 Pressure de Strut -In Pressure@ 6575.81 13 0 3397 18 0Minutes Shu -in 16:33:58 Strut -In Pressure @IO Minutes 0Minutes Shut -In Pressure @1O Minutes 03 0 3291 Se Strut -M Pressure @15 Minutes Sull. Pressure @35 Minutes 075.81 6585.81 51 O 3386 19 ]8:23:22 pause 18:222 Susrendinglob 6668.39 0 0 0 30 1833:21 Fntllab Entlinglob 6658.39 0 p p [avv Iepaua.b,iT-uw�ya..nasu _nun cars 124 Seq No, time Activity CWe ...a t 1eb51urryVd Trends, Pressure@Pum Slurrygate Gouge SH Pros 1 01:15:09(12/07/18) Start lob Startin lob 0 0 0 0 2 7:..0 Pouse Suspendin lob 2.54 46 0 0 3 7:5533 Resume Resuminglab 2.54 0 0 0 4 10:00:40 Name Pumps Prime Pumps 193.55 261 ]A 1323 5 10:22:22 Pressure Test Pressure Test -Shutting Prime up 22.74 98 0 2358 6 10:23:28 Pressure Test Pressure Tent TestwAGbbals(IOOpsi) 226J4 130 0 2340 ] 10:23:58 Pressure Test Preuure Test Testing Lomis(300pu) 216.74 686 0 3337 8 10:E4A1 Other Small leak on Acid pumper 226.74 876 0 2334 9 10:28:05 Pressure Test P.Jure Tesl Testmglacab 227.38 127 0 2329 20 10:35:12 Pressure Test Pressure Test Mao Pressure First Half of Fleet 227644 9508 0 2326 11 ID:38A2 Pressure Test Pressure Test- Max Pressure Second Half of Hear 22744 9534 0 2325 13 10:44:38 Pressure test Pressure Test - Goad Pressure test, Bleed down to test Pop -Off 9101 0 2324 13 10:46:08 Other Nitrogen Battle Checked at 200 [I 227.44 111 0 237. 14 10:4233 Pressure Test Pressure Test-GedingPo -of EE7A4 143 0 2324 15 10:50.43 Pressure Test Pressure Test -Pop Off did not pop P 8700 227.59 8667 0 2324 16 10:53:03 Pressure Test Pressure Test Ensuring PopON functionality 227.59 4193 0 2323 17 10:55:48 Pressure Test Pressure Test-Racein ng Pop -OH to eSW 12759 875 0 3323 18 10:58:23 other Truccude Pressure released due to Pop -OH 227.63 8644 0 2323 19 11:00:59 Other Verification of Pop -of release 227,63 4341 0 2323 20 1192:01 Pressure Test Pressure Test -Pop -0H Release at 227.64 8598 0 2323 21 1193:10 Other Weeding down to 3001511. 00en Well 227.64 7963 0 2323 22 11:0894 Other Badtubrif Gel, Rolled Tub until viscosity came 22764 659 0 2323 723 11:oB:d4 Otherulled Testingcb22 rot as torrow, crowlinkwn be tO the blender. 22764 6]3 0 2322 24 11:30:15 Open Well Open Well 0 497 0 1322 25 11:3128 Other Horaulic leak on Blender 0.]l 12W 6.6 2694 26 11:47.29 Other Start PumpingO.75 502 0 1468 27 11:56:35 Other Ball Loaded 136.]1 228E 15.7 Mrs 28 11:57:15 Other Ball Dropped IGAel Out) 1424E 2431 15.7 3665 29 11:57:23 Other Bell Dropped (Audio heard) 148.98 2509 15.] 3R9 30 12:12:26 Ball on Seat WE on Seat 3]8.65 2440 12.3 3955 31 12:12:35 Break Formation Break FormaOon 390.7 4808 12.3 5490 32 12:22:30 Other Pump dropped due to Pre -bad ]61.9] 4103 40.1 45]] 33 12:24:23 Other Pum dropped due to Pre -bed 836.22 .53 40.1 4620 34 12:42:11 Other Pump dropped due to Prcload 1550.95 4104 40.1 4730 35 12:54:13 Other Pump droppetl due to Pre -load 2029.6 5209 39J 1E17 36 12:55:50 other Pump dropped due to Pm -load 209339 5266 40.1 5247 37 33:02:47 Other Pump dropped due to Wcload 2371.7 5699 40.3 5431 38 13:0]:11 Omer Ball Down hole 254501 5823 40A 5395 39 13:07:17 Other Audi. B9l Sent 239.73 5940 40A 5494 40 13:14:10 Ball on Seat Ball on Seat 2790.57 1984 12.1 3617 41 13:14:20 Break Formation Weak Formation 2792.59 4559 12.1 5189 42 33:39:45 Other Pro -Technics Here separated and they shut in Mew equipment Tracer was given to the blender operator o place in tub. 3401.3 "a 40.5 4589 43 14:04:25 Other loaf concentration on screws 484508 M73 419 5487 44 1 14:07:40 Other Will wouldn't Orap due to equipment. 498161 6862 422 5538 45 14:0399 Other Duetothe ball drop issues Howell was flushed. 5072.31 fi258 423 5615 46 14:1]'.13 61p ISIP 53]3.36 338 0 3409 47 1119'.10 Drop gall Drop Ball 5419.55 701E 15.2 3638 48 1133:57 Ball on Seat Ball on Seat 564].]8 1861 11.8 3502 49 14:44:08 Weak Formation Break Formation 5649.94 4683 113 530) 50 15:3992 Ocher Cason Air on the blender ]995.18 2644 225 3872 51 15:39:59 DIP ISIP 8034.34 91 0 3264 52 15:44:59 Shut In Pressure @ 5 Minute Shut -In Pressure@ 5Mlnutes 8024.36 35 0 3394 53 154959 Shut-in Pressure de lO Minutes Shut -1n Pressure@l0 Minutes 8024.36 36 0 3D] 54 15'.54A9 In Pressure @ l5 MI Shut -In Pressure @ 15 Minutes 8014.36 35 0 3264 55 15'.%:20 other Start Freeze protect 8024.36 63 0 3261 56 161015 Other End Freeze Protest 80808 954 0 3249 57 18:55:43 Pause Sus emdw,l b 8148.76 37 0 2789 58 18:56:05 End bb Endinglob 8148.]6 0 1 0 10 . envoi srab.-uwenk-a-ris awalun. z.z Bail Time K1Mrycode Comment lobslur vol Treed, Preuss¢®Pump slurry Rate Gauge BN Pres 1 089:36(12109118) Startlob Starting Kb B 0 0 0 1 08:]9:36(12/09/18) Nen Treatment Treatment Interval l 0 0 0 0 2 10:33A7 Prime Pumps Prime Pumps 0 1. 0 2297 3 11:32'.49 Other Fanning out Pump to remove it from missile 0 165 0 2291 4 11:56'.20 Other Firing Pumps Back up 0 21 0 2291 5 125927 Pressure Test Pressure Test -Prime -Op Line Shut 0 170 0 2291 6 12'.59:00 Pressure Test Pressure Test- Globals(10Cpsil 0 1. B 2291 7 12'.59:33 Pressure Test Pressure Test Locals 0 020 0 2291 B 13:115:56 Ressure Test Pressure Tot -Max First Ralf 0 9617 0 Will 9 13:08:39 Pressure Test Pressure Test -Max Second Half 0 9613 0 229] 10 13:14:02 PresmrtTest (installed, Weeding dawn 0 9260 0 2291 11 13:16:17 Pressure Test Pressure Test -Testing Pop 4H 0 126 0 2291 12 13:1751 PressureTest Pressure Test Pop OO Released 0 8398 0 2291 13 13:21:54 Pressure Test Pressure Test Verification of Pop Off 0 970 0 1291 14 14:03:09 Other Chnonag AOPFunctimon., o 2. 0 2291 1s 14:25:32 Open Well Open Well 0 544 0 2291 16 14:32:08 Other Flushed well due to an fault wHh Me mixing bowl on Me AOP 2808 2167 15.4 2291 6 14:33:10(12/03/18) Netl Treatment Treatment Interest 3545 2136 15.5 2291 1 14:33:14 Hands., Spacer &Ball Drop 3545 2131 ]S.a 2291 17 14:39:54 Other Switched to Seawater to finish Flush 7859 1963 153 2291 10 1•ASAO 51P ISIP 13666 252 0 2291 19 14:57:45 Other I BH Gauge Reut 60 0 2998 2 15:20:58 Bea Stage Space,&Ball Drop 636 0.8 2869 20 15:29:34 Other Ball Launched 2233 159 3587 3 15:29:40 He, Stage Pad 3344 154 3609 21 15.43:19 Ball on Seat Ball on Seat 2360 11.6 3551 22 15:4330 Break Formation Break Formation 5162 11.8 5583 4 15:4589 Next Stage ConditioningPad 3824 W...I'�1'4162 392 4265 5 16:01:20 NMStage Ippg 20/40 Wanli 4140 43.3 4271 6 16:04:59 Hands., 2pp 20/40 Wanli 4005 43.2 4266 7 16:08:37 Next Stage 3ppe 20/dO Wanli 3911 431 4236 8 16:]2:59 Nea Sta a 4Pp, 20/40 Wenli 4240 43 4323 9 16:1915 Beat Stage 5ppg 20/40 Wanli 4515 42.9 4519 30 16:24:8 Hea Nage 600620/40 Wenli 5113 429 4600 11 16:38:20 Nea Stage 1 Ippg 20/40V i 125738 5325 43.2 4831 23 ]6:30:41 Other Ball Launched 126343 5447 438 4892 7 16:4013(12/09/18) NMTreatment Treatment lnteml 7 129432 831 43.4 4797 ] 16:40:28 Nese Stage Pad 129432 803 43.4 4786 24 16:45:10 Ball on Seat Ball on Seat 135731 2069 12.2 3633 25 16:45:18 Breek Formation Break Formation 135799 4708 123 5%3 2fi 16:46:24 Other Blander Tub dropped 136937 3570 38.9 4179 2 16:49:02 N. Stage constraining Pad 140626 4399 46 4355 3 17:03:21 N. She Ippg 20/40 Wan11 167834 4311 45.1 4296 4 17:0631 N. Stage 1 2ppg 20140 Wanli 173789 803 45 800 5 17:10:21 Ned She 3pPg 20/40 Win11 18107 4228 "A 4288 6 17:13:59 Next Stage • ppg 20140 Wong 18812D 4361 ..1 4309 7 17:18:54 Nea Stage 5pp 20/40 Wari 197820 530 8 4562 21 17:2681 Other Pump reacted local klQom 212614 6449 48.8 4931 28 1718:21 Other Pump reached local eckout 21.591 021 49.6 495s 8 17:36:38(12/09/18) Nea Treaunent Treatment Interval 8 2339. 6373 50.4 4939 1 1736:43 Nast Stage Pad 2339. 047 50.7 4941 29 17:37:03 Other Ball Launched 23450 .7 BILL 4988 30 174243 Ball on Seat Bart on Seat 243765 talks 12.2 3513 31 17A2:53 Break Formation Break Formation 243842 4963 12.E 5519 2 17:4515 Next Stage Conditioning Pad 248219 4245 ..1 3990 32 175226 OIL., Dropped rate to prevent sucki Nb try 262282 4544 SOL INS 3 17:58:44 He. Shge Ippg 20140 Wanli 27/493 4657 50.3 4065 4 18:01:36 Next Stage 2ppg 20/40 W.0 28158 449] 50.3 4064 S 18:091 Nea S1., 3pP9 20/40 WILD 29.58 43% 50.4 4042 6 18:0:0 Next Spa 4Fee 20/40 Wank 295333 835 50.1 4111 7 18:12:31 No. Stage, 5ppg 20/40 Wash 304551 IS. 50 41,101 33 18:21:11 Other Pump reacM1ed local Thai 322954 6587 53.1 463E 34 18:21,19 Other Pump reached local lockout 324268 6425 518 4543 35 1823:28 other Pump Shming into higher Bear 327867 6601 53.3 .59 36 18:23:38 Other Pump died ScI... 62% 51.1 4631 8 188981 NeMSM1ge 6ppg 20/40 Wanll 3.00 3817 51.6 403 10 18:2952 K.Sta a Flush 3.1%0 3902 51.7 4040 37 1833'.46 Pip SO, 35007 1102 0 3325 11 18:33'.51 Next Stage Freeze Predict %0307 990 0 3297 38 18:38:8 In Preume @ s Mir Shut -In Pressure @ 5 Minutes 35007 106 0 3293 39 18:43:45 In Pressure @]5 Mo Shui Pressure @15 Minutes 350307 1033 0 3290 40 18:48:47 In Pressure 11115 Mi Shut In Pressure@iS Minutes 35007 1028 0 3385 41 18:51:0 OtM1tt Freese Pratec[ 35007 103 0 3282 8 19:085 Other Shut in well 351053 1052 0 3283 8 201]:14 Pause Suspendinglob 353480 0 O 0 44 20:11:15 Fla,us General 353480 1 0 0 0 Seq No, Time AttMry Code comment lnbsarr Pot Thertlq Pressure Psi slurrYRrte Gauge SH Pres 46 0.399664352 Alarm General test Gauge SH Pres= 0 psi 353480 1 0 IS 47 Si Other Mln mag memr rausin false read 358229 1 234 15 48 10:51,44 Other Prime Pumps 372354 0.5 0 2286 49 11:43:13 Pressure Test Pressure Test -Tell Ghmals 312354 6.4 0 2285 50 11:44:35 Pressure Test pressure Test - locals 372354 126.4 0 2285 51 11:49:51 Pressure Test Pressure Test- Max pressure First half offleet 372354 661.6 0 2285 52 11:54:13 Pressure Test Pressure Test- Max Pressure test Second HAD 37E35a 6633 0 2285 53 1156:56 Prex Tert Pressure Test- Good Test Bleed down 312354 6528 0 2285 54 1 12:00721 Pressure Test Pressure Test - Check Nitrogen Pop Off 372354 ]J 0 1285 55 12:02:23 N ... ure Test Pressure Test- P., -Off 392354 589.6 0 2285 56 12:03:10 Pressure Test Pressure Test Good Test Bleed off 372354 581.5 0 2285 57 12:21:13 Other Waming On Gel tub 372354 28.5 0 2285 58 12:37:55 Other Waiting on Down howuaa 372354 9.2 0 2286 9 12:52,46(32/12/18) Neat Treatment Treatment interval 9 322354 el 0 2285 59 12:55:05 Open Well Open Well 332354 29.5 0 2309 1 12:56:18 Next Stage SpaarB Ball Drop 372354 32 6 0 2394 60 13:00:52 Drop Ball OmP Ball 373WO 1162 0.93 3056 61 13:02:,1 Other Blender Starved or Fluty 3]382] 43.9 0 2984 2 13:04:33 Neat Stage Ped 374100 10167 1.. 3015 62 13,46:18 Other DA-l(WG-36)Stopped moving 374977 106.1 1.12 3121 63 13:08:39 Other Gaging due to ADP Mixing Bowl Packed off 376160 .5 .1 1.12 3155 64 13:39:16 Other Freeze Protect 376211 19.9 0 2413 3 13:42:31 Nett Sta a Freeze Protect 376211 19.4 0 2405 65 134543 Other .,her 376459 61 0.61 2]]0 66 13:53:20 Shut In Well Shut In Well 377826 50.9 0 2669 67 140609 that Freeze protea Reel 377836 3 0 5457 4 14:05:12 NertSta a Spur1,3]]826 3 0 2457 68 15:4536 Pause Suspentling Job 377826 1 0 IS 69 15:45:27 Alarm General test Gauge 8H Press =O psi 3]]826 1 0 15 70 10:26:50(12/13/18) Resume Resumin IOb 377826 1 0 15 73 10:26:51 Alarm General test Gauge SH Pres=Opsi 3]]826 1 0 ]5 72 10:33:21 Alarm High Tub Lerel Bl Tub .1 A 90.0% 3]]826 1 0 2283 73 12:49:13 Prune Pumps Prime Pun" 377826 3 0 2281 74 12:54:51 Other Westphal. in Chidsan goingtp WellM1eed 3]]826 0.9 0 2281 75 12:56:00 Other Blopirt, Down 1. last Does 3"/826 0.5 0 2280 76 14:07:x3 Pause Suspendin lob 377.26 1 0 15 77 1407:45 Alarm General Is. Wuge BH Far =O psi 3"826 I 0 IS 78 09:36:42(12/14/181 Resume Resuminglob 3"826 1 0 63 79 996:43 Alarm General test Gauge BH Post =0 psi 377826 1.2 0 279 80 30:4848 Other CMckon lesson Pump 377826 8.9 0 2264 81 10:54:09 ONer Transduttr Was Read 3"826 0.3 O 2264 82 11:03:31 Other Prune Truck 377826 04 0 116. 83 1024:59 Other Load Balls 371826 1.2 0 2263 84 11:48:05 Pressure Test Rasure Test Globals 377826 sta 0 2363 85 114919 Pressure Test Pressure Tert- Locals 30826 151.3 0 2263 86 11:5583 Pressure Test Pressure Test - Max First Half 3]]826 663.8 0 2263 87 11:58,14 Pressure Test Pressure Test-5econtl Half 377826 6" 0 2263 88 12:0]:31 Pressure Test Frei Tex Good Test 3]]826 659.6 0 2263 89 13:15:3¢ Other Swapping hyrou is hoses 3]]826 l.] 0 2263 90 13:43:10 Other Miving Gel Tub 377826 2.8 0 2261 91 14:14:07 Open Well Open Well 377826 31.8 0 2274 5 14:15:56 NertStage Conditiamng Pad 177921 256 0 22]1 92 14:23:41 Other load Ball 381025 115.9 1.. 3272 93 14:23:54 Drop Bag Drop Ball 383136 IIS-, 1.14 3285 94 34:33:06 Btll an Seat Ball oa Seat 389700 103 1.14 3251 95 14:33:0 Break Formation Break 1-ati0n 309768 269.8 1,14 4890 6 14:35:23 Neat stage Cnndaioning an 392256 346 xi 4093 7 14 49 10 Next Stage I mS 20/40 Wanli 421035 1 316.3 A]S 4000 8 14:5209 NMStae 2ppg 20/40 Wanli 421453 306.9 a." 3959 9 14:55'.08 NB.She 3 p 20/40 Wan It 433790 314 4.71 3949 10 14:59:" Next Stage 4ppg 20/40 Wan li .2.3 361.9 4.69 4094 11 15:03:10 Next Stage 5pp9 20/40 Wan It 450873 383.3 A67 4161 12 15:07:44 Next stage 6 P 20/40 Wan It 460231 .0.8 4.65 6334 96 15:1134 Other Truck Fri Out due to local 460243 471 464 4373 13 15:12:28 NexiStage 7pp. 20/40 Wanli 469968 464.1 453 .95 97 15:14:29 Other Trucked pcked Out due to Local 474065 406.6 463 4451 14 15:17:16 Near stage Spacer Bit Pall Drop 4]9]41 463.74A7 4438 98 15:17:41 Crop Ball Drop Ball 480546 470.5 4.44 4466 30 15:111:25 (12/14/18) Next Treatment Treatment Interval 10 .2007 4115 444 .33 1 15:19:07 Next Stage Pad 482007 4. 4.68 4547 99 15:30:54 Other Oxine to load new ball 492736 1395 1.. 34.9 IN 0:41:59 Or Bell Orap Ball 493213 2M 1.12 3625 101 15:50:49 BaO on Seat Hall on Seat 502119 1135 1.14 3275 2 15:53:16 Nen stage Conditioning Pad 5.715 292.5 4.71 3767 3 i6:.U2 Neral Stage 1ppg 20/4011darb 533700 21 5.17 3845 4 16:08x43 Nen Stage 2 ppg 20/40 Wangs 539932 .1.4 5.16 3836 5 0.674780093 NeM5tage 3ppg ZO/40 Wanll U6785 332.9 5.16 3825 6 0.6]71527]8 Neal 4ppg 20/40 Wanli 554681 371G 515 3888 7 0.679976852X¢775168¢ Sppg 20/40 Wash 564083 4378 5.12 4066 202 0.682766204 Offer Truck Bldad 573274 06.5 5.14 4131 8 0.6829282411111111, 6ppg 20/40 With 573740 380.8 4.36 3981 103 0.683200741 OfM1er irucktlied 574674 471.5 4.94 4093 1. 0..asJa ,he, Truck Kicked Out 580259499.] 4.98 4134 9 0.686203]. Nen Stage 7ppg 20/40 Warth 583481 499.8 d.% 4203 105 0.68562037OtM1er Truck Nicked Out 510824 506.9 5.. 4236 HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065596-1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: November 30, 2018 0 minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1 /sec Water SL#930 Filed samples of CL -22 andCL-31 used for testing. Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: Customer: ConocoPhillips Well Name: 0 Date: November 30, 2018 .JOB INFORMAI ION AN DT Fluid System: Water Source: BHST ("F): EST] NG CONDITIONS Hybor G Bob Type: B5 Seawater Shear Rate(I/sec): 511 / 100 156 Lab Project ID: 2065596-1 FLUID DESIGN Test No: 1 z 3 -. s o Water Analysis Lot # Chemical Unita Chemical Concentrations Sample ID: Pre/Post BE -6 ppt 0.15 0.15 0.15 0.15 Total Alkalini m) LoSurf 300D gpt 1.00 1.00 1.00 1.00 Total Hardness m) WG -36 ppt 30.00 30.00 30.00 30.00 Chloride m ) Water Chloride m Base MO -67 get 0.75 0.75 0.75 0.75 Chloride (m ) Broke CL -22 gpt 0.90 0.90 0.90 0.90 Iron to ) CL31 gpt 0.45 0.45 0.45 0.45 H Sulfate (m ) Optiflo 111 plat 0.00 2.00 2.00 2.00 Temperature °F) Optiflo 11 ppt 1 0.00 1 0.25 1 0.25 1 1 1 Specific Gravity, SP Breaker ppa 0.00 0.00 0.25 0.50 TDS m Water TDS m Base TDS m) Broken 'calculated values FLA ID PROPERTIES Iest No: Water pH Base Gel (N) Base Gel Vise (cP) Base GCI pH Base Gel Temp. (eF) Buffered pH Crosslink pH Final pH Test Temp. (°F) Break Time (hr:min) 1 3 4 5 6 7.16 7.16 7.16 30.00 30.00 30.00 26.0 26.0 26.0 N26, 7.45 7.57 7.51 80 80 80 10.10 10.13 10.17 1001 10.03 10.06 8.58 8.52 8.94 156 156 156 1:12 0:52 0:57 052 Test Notes: 1 gram of SP Breaker was added to 50mL of distilled water. The testing was done with the liquid SP. 800 BREAK TEST -----Shear Rale -Viscosity .......... Shear Rate -Viscosity - - Shear Rate -Viscosity ... Shear Rate -Viscosity --- Temperature- -- Temperature - -- Temperature CHART ---Shear Raie -Viscosity ----- shear Rate -Viscosity Temperature - -- Temperature - -- Temperature 180 700 160 600 ,_ _ 140 500 ....:., 120 m c�%l X400 100 Sc 300 il, ._-.- 8o 200 60 100 40 20 0 0:00 0:14 0:28 0 043 0:57 1:12 1:26 1:40 Time, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065642-1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 1, 2018 IU minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1 /sec led water used for 15. r SL#933 4 bottle comp sample used for I1,2&6 additive samples SL#931 and SL#934 a,b,c,d,e,f,g used. Technician(s) Performing Testing: Amanda Morison Reviewed & Approved By: HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065645-1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 1, 2018 0 minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1/sec - SL#933 4 bottle comp sample additive samples SL#931 and SL#934 a,b,c,d,e,f,g used. Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: ,JOB I NFORMATION AND TESTING CONDITIONS Customer: ConocoPhillips Fluid System: Hybor G Bob Type: B5 Well Name: 0 Water Source: Seawater Shear Rate (1/sec): 511/100 Date: December 1, 2018 BHST("F): 140 Lab Project ID: 2065645-1 FLUID DESIGN Test No: I 2 3 Nater Analysis Lot # Chemical Units Chemical Concentrations Sample ID: Pre/Post Be -6 ppt 0.15 0.15 0.15 0.15 Total Alkalinity(ppm) Lo8ar000D gin 1.00 1.00 1.00 1.00 Total Hardness m) WG -36 Ire 30.00 3000 30.00 30.00 Chloride (m ) Water Chloride m Base MO -67 gpt 0.75 0.75 0.75 0.75 Chloride m Broke CL -22 gpt 0.90 0.90 0.90 0.90 Iron (m ) CL31 9pt 0.45 0.45 0.45 045 pH Sulfate m Optiflo 111 ppt 0.00 2.00 2.00 200 Temperature F) Optiflo II ppt 0.00 0.25 0.25 0.25 $ ecific Gravity SP Breaker ppt 0.00 0.00 0.25 0.50 TDS m) Water TDS (ppm) Base TDS m) Broken "calculated values Test No: 1 2 3 4 Water pH 7.06 7.06 7.06 7.06 Base Gel (#) 30.00 30.00 30.00 30.00 Base Gel Vise (cP) 2TO 27.0 27.0 27.0 Base Gel pH 7,51 7.51 7.66 7.56 Base Gel Temp. (eF) 80 80 80 80 Buffered pH 10.16 10.16 10.26 10.12 Crosslink pH 10.07 10.07 10.18 10.02 Final pH 8.13 7.98 7.99 7.94 Test Temp. (OF) 140 1 140 1 140 j 140 Break Time (hr:min) 8.49 1 4:02 1 1:57 1 126 ---Sheat Rate -Viscosity BREAK ---..- TEST CIIARI Shear Rate -Viscosity - Shear Rate -Viscosity Shear Rate --Viscosity .......... Shear Rate -Viscosity -- -- Shear Rate -Viscosity - - - Temperature- - - Temperature - - - Temperature - - - Temperature- - - Temperature - - - Temperature 1000 160 900 80011111- - 140 r 120 700 All If 600 j 100 500 80 400 S 300 40 200 z0 100 0 0 0:00 1:12 2:24 3:36 4:48 6:00 7:12 8:24 9:36 Time, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065649-1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 2, 2018 0 minutes at 511 I/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1/sec r SL#933 4 bottle comp sample additive samples SL#931 and SL#934 a,b,c,d,e,f,g used. Technician(s) Performing Testing: Amanda Reviewed & Approved By: Test No: 1 2 3 J Water pH z06 7.06 Base Gel (#) 30.00 30.00 Customer: Well Name: Date: ConocoPhilh s 0 December 2, 2018 Base Gel pH 7.46 7 46 Fluid System: Water Source: BHST (°F): Hybor G Seawater 140 Bob Type: B5 Shear Rate (1/sec): 5111100 Lab Project ID: 2065649-1 Buffered pH 9.52 9.52 Crosslink pH 9.56 9.65 Final pH 7.93 8.00 Test Temp. (°F)l40 140 Break Time (hrmin) 124 FLUID DESIGN BREAK TESTCIIART .... --Shear Rate -Viscosity .......... Shear Rate -Viscosity -----Shear Rate -Viscosity Test No t 1 2 3 - - - Temperature- - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature Water Analysis Lot # Chemical B66 LoSurf 3000 WG -36 Units ppt gp[ ppt 0.15 1.00 30.00 0.15 1.00 30.00 0.15 1.00 30.00 Chemical Concentrations 0.15 LO0 30.00 Sample ID: Pre/Posi Total Alkalim m) Total Hardness m) Chloride (m ) Water Chloride (m Base MO -67 9pt 0.40 040 040 0.40 Chloride m )Broke CL -22 CL31 got gpt 0.90 0.45 0.90 0.45 0.90 0.45 0.90 0.45 Iron m pH Sulfate m L) 120 Optiflo In Optiflo II SP Breaker ppt ppt la 0.00 0.00 0.00 2.00 0.25 0.00 2.00 0.25 0.25 2.00 0.25 0.50 s / Tem era[ure (°F) Specific Gravity TDS m Water TDS m) Base 500 ................ TDS m Broken 80 t 400 6 Z 60 300 S 40 200 'calculated va/uec Test No: 1 2 3 J Water pH z06 7.06 Base Gel (#) 30.00 30.00 Base Gel Vise (CP) 26.0 26.0 Base Gel pH 7.46 7 46 Base Gel Temp. (°F) 80 80 Buffered pH 9.52 9.52 Crosslink pH 9.56 9.65 Final pH 7.93 8.00 Test Temp. (°F)l40 140 Break Time (hrmin) 124 BREAK TESTCIIART .... --Shear Rate -Viscosity .......... Shear Rate -Viscosity -----Shear Rate -Viscosity - -Shear Rate -Viscosity --^-- Shear Rate �UscositV --- 'Shear Rate -Viscosity - - - Temperature- - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature 160 800 40 / 120 600 s / 100 500 ................ 80 t 400 6 Z 60 300 S 40 200 20 too 0 0 0:00 0:16 0:28 0:43 057 1:12 1:26 1:40 1:55 2:09 Time, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065653-1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 3, 2018 .0 minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1 /sec SL#933 4 bottle comp sample additive samples SL#931 and SL#934 a b,c,d,e,f,g used. Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: mner: ConoccPhillips Fluid System: HyborG Bob Type: B5 Name: 0 Water Source: Seawater Shear Rate (1/sec): 511 / 100 December 3. 2018 BHST ("F): 140 Lab Project ID: 2065653 - Water Lot# Chemical Units Chemical Concentrations Sample ID: Pre/Post 8&6 ppt 0.15 0.15 0.15 0.15 Total Alkallm ( m LoSurt'300D spt 1.00 1.00 1.00 1.00 Total Hardness m) WG -36 ppt 30.00 30.00 30.00 30.00 Chloride m Water FAXWWL-71 01 m h It 010 Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065670/1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 3, 2018 0 minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1/sec Water SL#936 3 bottle comp sample Filed additive samples SL#931, SL#934f and SL#937a,b,c,d used. Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: Base Gel Temp. (°F) tl 80 80 80 1 1 Customer: ConocoPhillips 10.32 10.41 10.41 Fluid System: HyborG Bob Type: B5 10.35 0 Final pH Water Source: Seawater Shear Rate (1/sec): 511 / 100 Well Name: Test Temp. (aF) 140 140 BHST ("F): 140 Lab Project ID: 2065670/1 Date: December 3, 2018 3:10 none none none - ..-- Shear Rate -Viscosity ........ "Shear Rate �Viscaelty ---"Shear Rate -Viscosity --. -Shear Rate -Viscosity FLUID DESIGN ..-.-Shear Rate -ViscostV -----'Shear Rate -Viscosity - - - Temperature- - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature Water Analysis Test No: 1 2 3 1200 Lot k Chemical Units Chemical Concentrations Sample ID: Pre/Post BE -6 ppt 0.15 0.15 0-15 0.15 Total Alkahni m LoSu f300D 8pt 1.00 1.00 1.00 100 Total Hardness m) WG -36 ppt 3000 30.00 30.00 30.00 Chloride m Water Soo Chloride m Base - MO -67 gpt 1.00 1.50 2 00 2.50 it 'Y oil Chloride mg 2) Broke 'M 1�� CIl22 gpt 0.90 0.90 0.90 0.90 Iron m /L CL31 91A 0.45 0.45 0.45 0.45 p H Sulfate m L aco Temperature ( ) Specific Gravity 200 20 TDS m Water ................._ _.................. _..... . --r -, 0 a 0:00 TDS m) Base 2:24 3:36 4:4a 6:00 7:12 TDS (ppm) Broken Time, h:mm *calculmed va/aes Base Gel Temp. (°F) 80 80 80 80 Buffered pH 10.15 10.32 10.41 10.41 Crosslink pH 10.09 10.35 10.43 10.41 Final pH 7.87 8.78 8.61 8.81 Test Temp. (aF) 140 140 140 140 Break Time(hCmin) 3:10 none none none - ..-- Shear Rate -Viscosity ........ "Shear Rate �Viscaelty ---"Shear Rate -Viscosity --. -Shear Rate -Viscosity ..-.-Shear Rate -ViscostV -----'Shear Rate -Viscosity - - - Temperature- - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature 160 1200 __________________. 140 1000 120 t 1 Soo - V� - - 100 600 it 'Y oil AA 1 A 'M 1�� �Li1)� 60 aco 40 200 20 ................._ _.................. _..... . --r -, 0 a 0:00 1:12 2:24 3:36 4:4a 6:00 7:12 Time, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065698/1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 5, 2018 irst 10 minutes at 511 1/sec at 100 degrees ,fter 10 minutes the shear rate was decreased to 100 I/sec Vater SL#936 used on 11&2. Water SL#939 used on 13,4&5. iled additive samples SL#934 d,e,f and SL#937a,b,c,d used for all testing. L# 936 Total Alkalinity(strip) 120ppm L# 939 Total Alkalinity(strip) 80ppm 1,2,4&5 were set concentrations of MO -67. I3 was a titration of MO -67 to get the pH at a 10.0+. Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: Customer: ConocoPhillips Fluid System: Hybor G Bob Type: BS 0 Water Source: Seawater Shear Rate (1/sec): 511/100 Well Name: BHST ("F): 140 Lab Project ID: 2065698/1 Date: December 5, 2018 Test No: i 2 1 3 5 L014 Chemical Units 'Chemical Concentrations Sample ID: Pre/Post 13E-6 ppt 0.15 0.15 0.15 0.15 0.15 m) Total Alkalinity(ppm) Lo8urf 300D Rpt 100 1.00 1.00 1.00 Loo Total Hardness m WG-36 ppt 000 30.00 30.00 30.00 30.00 Chloride (m )Water Chloride (mg/L Base MO-67 Wt 0.80 1.00 1.20 0.80 1.00 Chloride nt 2) Broke CL 22 gpt 0.90 0.90 0.90 0.90 0.90 Iron m CL31 gpt 0.45 0.45 0.45 0.45 0.45 PH Optiflo 11 ppt 0.25 0.25 0.25 025 0.25 Sulfate (m Tem ¢nature (°F) Op[iflo III ppt 2.00 2.00 2.00 2.00 2.00 Specific Gravity TDS m) Water TDS m) Base TDS (ppm) Broken �COICtid re(I VpILCS FLUID PROPERTIES Test No: 1 2 3 a 5 6.71 6.71 6.62 6.62 6.62 Water pH 30.00 30.00 30.00 30.00 30.00 Base Gel (it) 26.0 26.0 26.0 26.0 26.0 Base Gel Viso (0) 7.78 7.67 7.67 7.48 7.39 Base Gel pH 80 80 80 80 80 Base Gel Temp. (°F) 1024 10.42 10.12 9.83 9.98 Buffered pH 10.27 10.44 10.09 9.78 9.55 Crosslink pH 7.83 8.17 7.99 Final pH Test Temp. (°F) 140 140 140 140 140 11 Break Time (hr:min) 2:15 151 1:33 1 . --- Shear Rate -Viscosity BREAK .......... TESTC[IART Shear Rate -Viscosity -" ... Shear Rate -Viscosity Shear Rate -Viscosity -- ^Shear Rate -Viscosity ----Shear Rate-ViscositV - - - Temperature- - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature 160 1200 ------------------ 140 1000 T � 120 / J � � 800 /" � 100 m h 80 600 d 0 't �n 400 40 200 ............................................................................................................................. 20 0 0;00 0:28 0:57 1:26 1:55 2:24 2:52 3:21 3:50 4:19 Tlme, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065733-1 Customer: ConocoPhillips Well Name & Number: Fluid System: Hybor G Date: December 7, 2018 0 minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1/sec SL9943 17 tank comp sample additive samples SL4934d,e,f,g and SL#937a b,c,d Technician(s) Performing Testing: Amanda Morison Reviewed & Approved By: 1 Customer: ConocoPhillips Fluid System: Hybor G Bob Type: 135 Well Name: 0 Water Source: Seawater Shear Rate (1/sec): 5111100 Date: December 7, 2018 BHST ("F): 140 Lab Project ID: 2065733-1 DESIGNFLI ID Test No: 1 2 1 3 1 a Water Analysis Lot # Chemical Units Chemical Concentrations Sample ID: Pre/Post BE -6 ppt 0.15 0.15 0.15 0.15 ITotal Alkalinity( m) LoSurf300D spit 1.00 1.00 1 00 1.00 Total Hardness m WG -36 pp[ 30.00 30.00 30.00 30.00 Chloride m ) Water Chloride m ) Base MO -67 spit 1.20 1.20 1.20 1.20 Chloride m )Broke CL -22 spit 0.90 0.90 1 0.90 0.90 Iron ) CL31 0.45 0.45 HSulfate m ) Optiflo 111 2.00 200 2.00 Tem erature F) Optifio 11 0.25 0.25 0.25S eeifiC GralSP MgptO.450.45 Breaker 0.00 0.25 0.50 TDS (ppm) Water TDS m Base TDS m Broken 'calculated values Test No: 1 1 2 1 FLUID PROPERTIES Water pH 6.62 1 6.62 1 6.62 Base Gel (#) 30.00 30.00 30.00 Base Gel Viso (cP) 26.0 260 26.0 Base Gel pH 7.47 7.49 7.49 Base Gel Temp. (°F) 80 So 80 Buffered pH 10.32 10.32 10.33 Crosslink pl- 10.31 10.29 10.32 Final pH 8.34 8.03 8.55 Test Temp. (°F) 140 140 140 Break Time (hrmin) 4:53 1 3:07 2:47 ........ Rate -Viscosity BREAK .---.- TEST CHART Shear Rate -Viscosity - - -Shear Rate -Viscosity - - -Shear Rate -Viscosity ..---^ Shear Rate - Viscosity ----Shear Rate -Viscosity - - - Temperature - - - Temperature - - - Temperature - - Temperature - - - Temperature - - - Temperature 60 1200 __________________- 140 1000 i 120 1 r 800 y lac so 600 a d 60 s 400 40 200 20 ".......... _.... _.._"^.-......................................................... 0 0 0;00 1:12 2:24 3:36 4:68 6:00 rime, h:mm HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065746-1 Customer: ConocoPhillips Well Name & Number: Kuparuk River 3S-611 Fluid System: Hybor G Date: December 9, 2018 0 minutes at 511 1/sec at 100 degrees 10 minutes the shear rate was decreased to 100 1/sec •SL#944 additive samples SL#934d,e,f,g and SL#937a b,c,d Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: omer: Name: F: ConocoPhillips Kupamk River 3S-611 December 9, 2018 JOB INFORMATION I AND TESTING Fluid System: Water Source: BHST (°P): CONDITIONS Hybor G Seawater 140 Bob Type: BS Shear Rate (1/sec):SIl/100 Lab Project ID: 2065746-1 4 Test No: I 2 3 FLUID DESIGN -I Rate Water Analysis Loi 4 Chemical Units -Viscosity Chemical Concentrations Sample 1D. Pre/Post - - - B&6 pptF30 -Vlsaosity .......... Shear Rate -Viscosity ---- 0.15 0.15 Total Alkalini ( m) Lo8uff300D grit0 - - - Temperature- 1.00 -I0-0E-Total - - Temperature - Hardness ( m) WO -36 p [0R2.00 30.00 Chloride m /L) Water Chloride me/L) Base MO -67 apt0 60 1000 1.20 Chloride m /L) Broke CL -22 apt0 0.90 900 Iron (m L) CL31 apt5 0.45 140 H 800 Sulfate m )Optiflo 120 III Von0 2.00 Tem emture (°F) Optiflo II ppt 0.00 0.25. 700 0.25 Specific Gravi SP Breaker ppt 0.00 0.00 US 050 TDS m Water TDS m) Base 600 N TDS (ppm) Broken N 80 � 500 'calculated values Test No: Water pH Base Gel (N) Base Gel Vise (0) Base Gel pH Base Gel Temp. (°F) Buffered pH Crosslink pH Final pH Test Temp. (°F) Break Time (hr:min) 1 7.08 30.00 26.0 7.38 80 10.31 10.29 8.52 140 none 2 708 30.00 26.0 7.35 80 10.38 10.34 741 140 4:28 FLUID 3 708 30.00 26.0 7.45 s0 10.26 10.25 8.02 140 3:53 PROPERTIES 4 7.08 30.00 260 741 80 10.28 10.26 863 140 3 07 = 400 i l a �I �ifljlr•��� II I BREAK TEST CAART 4 ...--.-Shear Rate -Viscosity ....... - Shear Rate -viscosity --- -Shear Rate -Viscosity - - - Shear Rate -Vlsaosity .......... Shear Rate -Viscosity ---- Shear Rate - Viscosity - - - Temperature- - - Temperature - - - Temperature - - - Temperature - - - Temperature - - - Temperature 60 1000 900 140 800 120 700 u100 600 N N 80 � 500 = 400 N 300 40 200 - 20 100 0 0 0:00 1:12 2:24 3:36 4:48 6:00 7:12:m Time, hm i l a �I �ifljlr•��� II I 4 HALLIBURTON Prudhoe Bay Field Laboratory - Rockies NWA Laboratory Project ID Number: 2065776/1 Customer: ConocoPhillips Well Name & Number: Kuparuk River 35-611 Fluid System: Hybor G Date: December 11, 2018 First 10 minutes at 511 I/sec at 100 degrees After 10 minutes the shear rate was decreased to 100 1/sec SL#949 additive samples SL#947a b,c,d,e and SL#950a,b,c Technician(s) Performing Testing: Amanda Morrison Reviewed & Approved By: JOB INFORMATION A 1 T I US I IfIkik,91ii a Customer: ConocoPhillips Fluid System: Hybor G Bob Type: B5 Well Name: Kuparuk River 3S -61I Water Source: Seawater Shear Rate (1/sec): 5111100 BUST ('F): 140 Lab Project ID: 2065776/1 Date: December 11, 2018 FLUID DESIGN Wx[er Analysis Test No:I 'Chemical � Sample ID: Baroid SL#949 Lot ft Chemical Units Concentratiars I60 B&6 ppt 0.15 0.15 0.15 -100 0.15 Calciu m) Total Hardness m 2240 LoSurF300D gpt 1.00 L00 1 00 Chloride m L) Water 1700 WG -36 p t 30.00 30.00 30.00 30.00 MO -67 gp[ 0.75 0.75 0.75 0.75 CL -22 Spt 0.90 0.90 0.90 0.90 0131 Sp(( 0.45 0.45 0.45 0.45 Optiflo III pp[ 0.00 2.00 2.00 2.00 Optiflo 11 ppt 000 0.25 0.25 0.25 SP Breaker ppt 0.00 0.00 0.25 0.50 �C(/iCr11GlC!%Vp(4CS Test No: 1 2 FLUID 3 PROPERTIES Water pH 7.06 7.06 7.06 7.06 Base Gel (#) 3000 30.00 30.00 30.00 Base Gel Vise (cP) 2Z0 27.o 27.0 27.0 Base Gel pH 7.33 7.24 7.31 7.33 Base Gel Temp. (°F) 80 80 8o 80 Buffered pH 9.93 9.95 9.92 9.89 Crosslink pH 9.92 9.92 9.90 9.86 Final pH 7.81 7.85 8.20 7.82 Test Temp. (°F) 140 140 140 140 Break Time (hr:min) 6:30 3:02 3:14 1 128 ...... Shear Rate -Viscosity BREAK ----" TESTCHART Shear Rate -Viscosity ----- Shear Rate -Viscosity - Shear Rate --Viscosity ...... ^..Shear Rate -Viscosity --- Shear Rate -Viscosity - - - Temperature- - - Temperature - - - Temperature -- - Temperature- - - Temperature - - - Temperature 160 1000 900 k _____________ _________________________________. 140. 800 120 700 j 100 600 M 1 .� 80 t 500 a � = 400 o � S 300 40 200 20 100 0 0 L- 1:12 2:24 3:36 4:48 6:00 7:12 0:00 Time, h:mm 21, 8103 30094 Schlumberger Transmittal#: 10DEC18-SP01 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resources Tech Well Name: 3S-611 Date Dispatched: 10 -Dec -18 Service Order #: 18AKA0036 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: N/A Contents on CD 19 -Oct -18 VISION Resistivity 2" MD x 5" MD x 2" TVD x 5" TVD RECEIVED x DEC 1 1 2018 A GCC Digital Data N/A Contents on CD LAS/DLIS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x Gyrodata Survey x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to: Please sign and email a copy to: Tom.Osterkamp(a)conocophillips.com Ala ka SPrintCenter slb.com Attn: Tom Osterkamp Attn: tephano Pacillo Received By: I Schlumberger -Private 218103 30095 Scni umberger-vrivate PTO a/D'- 103 Loepp, Victoria T (DOA) From: Sylte, Hanna<Hanna.Sylte@conocophillips.com> Sent: Monday, December 3, 2018 9:01 AM To: Schwartz, Guy L (DOA); Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: 3S-61 1 (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: 3S-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 if, 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 (907-793-1226) or (Guvschwartz@alaska.aov). From: Sylte, Hanna <Hanna.SvlteC@conocophillips.com> Sent: Monday, December 3, 2018 8:55 AM To: Loepp, Victoria T (DOA) <victoria.loepp(a@alaska.eov> Cc: Schwartz, Guy L (DOA) <Ruv.schwartz@alaska.aov> 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, ESCAID'" 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.loepp@alaska.gov> Cc: 'guy.schwartz@alaska.gov' <guy.schwartz@alaska.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 Sheet �? Celanese Product name Methanol NA/EN MSDS number Revision Number 01111- 11 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; Monohydroxymethane; Methyl hydroxide. End use: Chemical raw material, chemical intermediate 2. Hazards identification Emergency Overview DANGER! Revision Date Sep.27.2006 Issuing date Sep27.2006 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. W -19t9 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 Immediate effects 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 Sheet Celanese Product name Methanol NA/EN MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 3 Composition/information on ingredients 4. First aid measures 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. S. Fire -fighting measures NFPA: Health: 1 Flammability: 3 Instability: 0 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. 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 Ill"? Celanese Product name Methanol 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 omonents TWA Methanol 200 ppm 4of10 Material Safety Data Sheet 0? Celanese Product name Methanol MSDS number 80056 Revision Date Sep.27.2006 Revision Number 1 Issuing date Sep.27.2006 ACGIH Exposure Limits Components TWA Methanol1 200 ppm Com onents STEL Methanol 250 porn Components 11990 NIOSH IDLH 11994 NIOSH IDLH Methanol 125,000 PPM r0000 ppm 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. 5of10 Material Safety Data Sheet il"? Celanese Product name Methanol Colour 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 liquid Colour colourless Odour alcoholic Molecular Weight 32.04 Flashpoint 12°C(54 °F) Autoignition Temperature 464 °C (867 °F) Lower explosion limit 6 Vol % Upper explosion limit 36 Vol % Melting pointirange -97.8°C (144°F) Boiling point/range 64.7°C (148.5°F) Density 0.7866 g/ml @ 25°C Vapour pressure 127 mm Hg @ 25°C Vapour density 1.11 (Air -1 @ 20 °C) 10. Stability and reactivity 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 Celanese Product name Methanol NA/EN 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 - positive Species Human experience Eye Irritation Moderate eye irritation Species rabbit eye Carcinogenic effects No evidence of carcinogenicity Species rats and mice Study inhalation study in vitro Mutagenicity Not mutagenic in AMES Test in vivo Mutagenicity Mouse micronucleus - negative Reproductive toxicity No toxicity to reproduction Routes of exposure inhalation Species rat NOAEL: 1000 mg/kg/day Developmental effects Induced developmental toxicity and malformations at 20,000 ppm Species rat Routes of exposure Inhalation NOAEL: 5000 ppm Developmental effects Induced developmental toxicity and malformations at 5000 ppm Species mouse Route of exposure inhalation NOAEL:2000 ppm Repeated exposure 28 -day No adverse effects Species Cynomolgus monkey Routes of exposure Inhalation NOAEL: 5000 ppm Neurotoxicity 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 Product name Methanol MSDS number 80056 Revision Number 1 Biodegradation Bioconcentration factor (BCF) Bioaccumulation 13 Disposal considerations ll"? Celanese Revision Date Sep.27.2006 Issuing date Sep.27.2006 48 % (5d) <10 Bioaccumulative potential - low NA/EN 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 UN/NA 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 Celanese Product name Methanol NA/EN MSDS number Revision Number Hazard Class 3 Subsidiary Hazard(s) 6.1 Packing group II EmS Code F -E, S -D 15. Regulatory information Revision Date Sep.27.2006 Issuing date Sep.27.2006 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 CERCLA Hazardous Substance SARA 311: Acute health: Chronic health: Fire: Sudden release of pressure: Reactive: INTERNATIONAL REGULATIONS Listed Listed Yes Yes Yes No No International Chemical Inventory Listed on the chemical inventories of the following countries or qualifies for an exemption: AUSTRALIA, CHI NA,CANADA, EUROPE, KOREA, PHILIPPINES, JAPAN 9of10 Material Safety Data Sheet Product name Methanol MSDS number 80056 Revision Number 1 Canadian Regulations: Ill'? Celanese Revision Date Sep.27.2006 Issuing date Sep.27.2006 WHMIS Classification: Class B, Division 2. Class D, Division 2, Subdivision A. Division 2, Subdivision S. 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 HMIS: Health: 2 Flammability: 3 Flammability: 3 Instability: 0 Physical hazard: 0 NA/EN 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: ESCAIDTM 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: Al 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. Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 2 of 12 Contains: DISTILLATES (PETROLEUM), HYDROTREATED LIGHT Other hazard information: E*(onMobil 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 / INFORMATION ON INGREDIENTS This material is defined as a complex substance. Hazardous Substance(s) or Complex Substancelsl renuired fnr diaclnaura Name CAS # Concentration* GHS Hazard Codes (PETROLEUM), HYDROTREATED LIGHT 1 64742-47-8 100 % _,dDISTILLATES 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 firefighting information. Seethe n Mob Product Name: ESCAIDTm 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 / PERSONAL PROTECTION EXPOSURE LIMIT VALUES Exposure limits/standards (Note: Exposure limits are not additive) Substance Name Form Limit / Standard NOTE Source DISTILLATES (PETROLEUM), TWA 400 mg/m3 100 ppm N/A OSHA Z1 HYDROTREATED LIGHT DISTILLATES (PETROLEUM), Vapor. RCP - 1200 165 ppm I Total ExxonMobil HYDROTREATED LIGHT TWA I mg1m3 Hydrocarbons 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 E659] Boiling Point / Range: 207°C (405°F) - 237-C (459°F) (ASTM D86) Decomposition Temperature: N/D Product Name: ESCAIDTM 110 FLUID Revision Date: 29 Mar 2018 Page 7 of 12 Vapor Density (Air = 11: 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 mg/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 I 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 -- 1 = 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. E*onMobil 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 Ecotoxicity 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, De radability and Bioaccumulation Potential Media Test Type 77 Duration Test Results Water Ready Biodegradability 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: ESCAID'm 110 FLUID Revision Date: 29 Mar 2018 Page 10 of 12 product 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 HYDROTREATED LIGHT 4, 17, 18 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 1-1304: 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-- - = ACGIH ALL 6 = TSCA 5a2 11 =CA P65 REPRO 16 = MN RTK 2 = ACGIH At 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 1-1304: 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 THE STATE Alaska Oil and Gas OfAT ASKA Conservation Commission GOVERNOR BILL WALKER Hanna Sylte Completions Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-611 Permit to Drill Number: 218-103 Sundry Number: 318-488 Dear Ms. Sylte: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.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. s. DATED this Z' day of November, 2018. Sincerely, Hollis S. French Chair ABDMS 2(/ NOV 2 6 2018 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV U Z 2018 APPLICATION FOR SUNDRY APPROVALS ozs 20 AAC 25.280 A r%/—% III I 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑A Repair Well ❑ 1'%%-0 Wehfons shutdown❑ 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 Ej Stratigraphic ❑ Service ❑ 218-103 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20774-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? KRU 3S-611 Will planned perforations require a spacing exception? Yes ❑ No 0 , 9. Property Designation (Lease Number): 10. Field/Pool(s): 7, ADL380107, ADI -380106, ADL02552 h Kuparuk River Field, Torok Oil Pool it. FlWStNT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 18,685 5,222 18,671 5,222 7,000 Casing Length Size MD TVD Buret Collapse Structural Conductor Surface 3,023 10-3/4" 3,023 5210 2470 Intermediate 12,609 7-5/8" 12,609 6890 4790 Production 8430 7500 Liner 6,182 45-1 18,671 5,222 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic ISee Attached Schematic 4.5" L80 12,474' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Premier Packer 12,338' MD/5024' TVD 12. Attachments: Proposal Summary ❑ Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 21 Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/26/2018 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Hanna Sylte, 907-265-6342 Email Hanna.Sylte@ConocoPhillips.com Printed Name HannaSylte Title Completions Engineer Signature Phone 907-265-6342 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n (e 1 n Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑%/-� Other: Post Initial Injection MIT Req'd? Yes ❑ No m Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION ate: I I I66 Z''ff�(I''oo t eJ f^� --rrte� •oV GV� tti kill It V/L 11 ?)J NOV 2501>Mltpbrmand ti\ Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Grass Roots Horizontal Mulfi-Sum Frac'd Pmducer COnOCO�PFlillips Post Rig Wellbore Schematic FMC a=h-fix. W J Ri-S' 12.>i SYOM N w Condnrtor• kL 20" Conductor @ 106' nfeeeum camwdmftda m.,w. 13-1:2" Surface Hole Spud Mud 10ePPG SurfaceCasino: 10-3/4" 45.5# L-80 Hydril 563TTXP 3,027' MD 12,580' LamRanian v5 V ntelli �.(lidtk HO e Tubino; 4-M-12.6# L-80 Hydril 563 12.474' MD •�. , navu,,.n aov ,f re Monne nc; awl .g° an�o pa lgYm L7V l ': Y. sYl, eat FlY:it[ lM nmr! SYP M Co MGc IIS �a^ �� Inlermedlate Casma:6-3 4 Protlucuat HOIe 7--W' 29.78 L-80 Hydril 563 KtnSH1ElD 12.609' MD l 5,099'TVD 95PPG _ c. : dlf Swe9Pikers FrxE ent 0 0 0 Production Liner 4-112" 12.6# HYD563 Production Hole fat - 90.88°: 18,671' MD 15,222' TVD 18.685 MD t 5.222' T'D 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 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 To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3S-611 Well Kuparuk River Unit, Alaska ADL 380107, KRU Tract 150; ADL 380106, KRU Tract 146; ADL 25528, KRU Tract 147 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPA]") 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-611 Well (the "Well'). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about October 25, 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-611 Hydraulic Fracturing Notice Letter October 25, 2018 Page 2 I\ q'< I Y C � 7 CL N 5 ADL390434'. I •c: �I Yi 7. 3� o ADL025528 or O; i Exhibit 1 ADL355038 I i i' ADL355032 ya�r i i i i TI�PvRi'- ADL025544 COr1000Phillips Alaska 3S-611 Lease Plat 1012412018 ADL380106 1 ADL025532 —ri —.—.—.—._.—.—.—.— �i 1 I i ADL392374 I I I 0 0.2 0.4 0.6 0.8 1 m Miles ADL025546 I Frac Points Well Trajectory Open Intentel OHatt Mile Frec Point Radius OHalf Mile Well Trajectory Radius nCPAI Lease ASRC Lease Ceelus Leese 3S-611 Hydraulic Fracturing Notice Letter October 25, 2018 Page 3 Exhibit 2 Mineral Owners: OOperator ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 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. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Weston Nash Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Suite 406 Attention: Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601 (Zip for PO Box 99519) Anchorage, AK 99503 (Street zip) Attention: Mr. Jamie Long Non -Operator: ADL 355038 Eni Petroleum US LLC 1200 Smith, Suite 1700 Houston, TX 77002 3S-611 Hydraulic Fracturing Notice Letter October 25, 2018 Page 4 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 THE ALASKA OIL AND GAS CONSERVATION COMMISSION 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-611 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. ("CPAP') 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about October 25, 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 25' day of October, 2018. fl_ /.-"A2.:� Paul K. Wharton STATE OF ALASKA THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 25th day of October, 2018, by Paul K. Wharton. Notary Public, State of Alaska My Commission Expires: =,,RESECCASWENSEN NOTARY N Au Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 3S-611 Landowners .c! 71 A�2 I � 71 CL ADL025528 01 !Ya, AI .- .c! 71 1 �i 71 o! ADL025528 01 01 1 i 1 1 I I ADL390697! i ADL025544 i 1 1 I i / ci LI ConocoPhillips Alaska 3S-611 Lease Plat 10/24/2018 ADL355038 ; I i I i i _._ _ ADL380106 _.._._._._._._._._._ 1 I ' ADL392374 1 0 0.2 0.4 0.6 0.8 1 m Miles ADL355032 ADL026532 ADL025546 L380107 Frac Points Well Trajectory Open Interval Half Mile Frac Point Radius OHalf Mile Well Trajectory Radius CPAILease ASRC Lease Caelus Lease Table 1: Wells within .5 miles Wells within 1/2 mile buffer of well track * Data from SDE laver: AK WELL BOTTOM TD 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 35-08 PA PROD 501032045001 35-08A 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 PROD 501032045301 3S -23A ACTIVE PROD 501032045600 35-24 PA PROD 501032045601 3S -24A ACTIVE PROD 501032036101 35-26 ACTIVE INJ 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 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 10/4/2018. The cement job was pumped with 73 bbls MPII and 11 ppg lead cement, this was followed by 12 ppg tail cement and displaced with 10 ppg mud. Returns were lost with 580 bbls of lead cement pumped. The plug bumped at 890 psi and the floats were checked and they held. A top job was pumped on 10/5/2018, with 11 ppg DeepCrete cement with returns to surface. 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. 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. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 10/6/2018 the 10 & 3/4" casing was pressure tested to 3250 psi for 30 mins. On 10/22/2018 the 7 & 5/8" casing was pressure tested to 3900 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 3 1/2" 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 2,090 psi 3,580 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 Bleed I Tattle Tale TaH m; 9 4=.L dwry PopdM Tank Free Pump Frac Pump Stimulation Surface Rig -Up m E • 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 -OB Tam PumPTnxk Frac Pump Fmc Puup 10K Frac Tree Note: Dimensional information reflected on this drasevmg are estimated measurements otdv. 4-1116" 10.006# 4-1116" 10.0008 130.08"' 4-1/16" 10.000# Hydraulic 56.94" 01 44-1/ ! 4-1116° 10.000# 4" 10K Valve + Tree Cap — 39.5' 4" IOK Valve + 4" 10K x 4" 1002 — 32.25" ConocoPhillips Mn71 Srie 2S- 1 OK Frac Tree 66" 4-1!16" 10.0009 RRN Weight of entire tree is —6.300 The 4" I OK HWO Valves —860 lbs Tree Cap —250 lbs ,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-611, from where it intersects the top formation at 12,810 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 4,046 ft. TVDSS (8,781 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 5,541 ft TVDSS at the heel, and 5,550 ft TVDSS at the toe of the well. (no MD as the HRZ is not penetrated in the 3S-611 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. Casing & Cement assessments for all wells that may transect the confining zone: 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/WebLink/DocView. 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/WebLink/DocView. aspx?id=39505&searchid=edb77d4c- fO3e-451e-ae3b-baa6eeea8f35&dbid=0&cr-1&cc=1#, page 201 Nuna 1 PB1: According to the Pioneer Natural Resources job log on the AOGCC website, the top plug was pumped in Nuna 1 P131 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/WebLink/DocView.aspx?id=39505&searchid=edb77d4c- f03e-45le-ae3b-baa6eeea8f35&dbid=0&cr-1&cc=1#, page 201 35-611 Fracture Stimulation Area of Review WELLNAME STATUS Casing Size Top of Torok Oil Top Oil ofTorok Top of Cement Top of Cement Top of Cement Cement Operations Pool(MD) (MD) (3VDSS) Determined 8y Reservoir Status conal Isolation Summary Mechanical lnte ri g ty (TVDSS) 35-613 Active 7-5/8" 10,962' 5,088' 6,100' 3,644' Sonic Scope Open hole liner for injection T0C at 6,100'and packer at 47 bbls 15.8ppg class G 8/5/18 MITIA to 1985 10,909'MD cement psi 35-620 Active T-5/8" 9,108' 5,099' 6,034' 3,790' Calculated Open hole liner forproduction T0Cat`6,034'andproduction 181bbIs15.8ppgc1azsG 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 Z%P packer at 60 bbis 15.appg Premium +• 10,191' Cement NDST42 PW PA na •* •' •• •• '• PA Cement plugs Top Plug pumped with 254 sx Premium cement na None SUSP 7-5/8" 6,895' 4,993' •* ** *• Suspended .. 192 sx 15.8 ppg Class G *+ cement Nun. 1P81• PA na "' •• +" *• *+ PA Cement plugs Top plug pumped with 280sx na •mio.mab"—u f,nm Aosc<—.i'n Premium Cement "Vnetler"beate M�aopeeaerllnleemaXen 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. The fault was encountered during drilling and intersects the 3S-611 wellbore at an approximate MD of 17,517'. The throw of this fault is interpreted to be approximately 10'. The fault is interpreted to not extend up through 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 If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. 2: Fault 2 1 'E I Y C L D CIL L i 13 N 34; 1 =i C; YI 7. LI 3. of ADL025528 01 O; i I i I 1 I ADL355038 gmmm� ADL025544 ConocoPhillips Alaska 3S-611 Fault Analysis 1012412018 ADL380106 ADL380107 ADL355032 AD ADL025532 ADL025546 Frac Points Well Trajectory Open Interval Fauns within Frac Point Radius I I Wells within Frac Point Radius I Half Mile Frac Point Radius ADL392374 O Half Mile Well Trajectory Radius I j CPAI Lease ASRC Lease 0 0.2 0.4 0.6 0.8 1 Caelus Lease m Miles SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3S-611 was completed in 2018 as horizontal producer in the Torok formation. The well was completed with 4.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 11 stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2na 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. 27,000 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 RLI 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-611 Stages Job Size (lb) Top MD (ft) Top TVD (ft) Propped Half- length (ft) Fracture Height (ft) Avg Fracture Width (in) 1 207,200 18,602 5,054 420 236 0.248 2 207,200 17,952 5,066 330 232 0.225 3 207,200 17,169 5,074 330 232 0.223 4 207,200 16,635 5,078 330 232 0.227 5 207,200 16,141 5,090 330 232 0.227 6 207,200 15,609 5,094 330 232 0.230 7 207,200 15,113 5,098 330 236 0.229 8 207,200 14,582 5,106 330 236 0.228 9 207,200 14,086 5,110 330 236 0.233 10 207,200 13,587 5,118 330 236 0.231 11 207,200 13,092 5,122 350 232 0.245 Disclaimer Notice: • This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results Propped half-length calculated using 1 Ib/sqft cutoff CUSTOMER WnocoP61111ps Alazka, Inc. API 50-103-20774 iD (Ib/ppl/ 856 '- 19669685 ' 3.00 LEASE RRu 35-611 SALES ORDER 9038]3965 MST ('F/ 165 HALMTM o .1932684 � �� �• 0:03:47 FORMATION moraine DATE Max Pressure (psi) 0.90 Liquid Additives Ory Atlditives 1 0.15 0.15 2.00 2.00 1 0.25 0.25 Prop Slurry 1.a.n can urry Prop ageInc.-o- u - - - - - - p o- pu o- reatmen Stage Fluid Stage Proppant Inc Rate Volume Volume Volume 1 Total Time 190 223 32,000 0.0:30 0:23:10 1.00 0.80 Time 5ndanam -oxer Doamn-n oossanl.r F,tt:evmlen OeI erocwe ere-ke. mea6e� 0 LL 2-2 30p H bore Pad 100 mesh 0.25 50 28,800 686 686 2-3 30#H borG Proant laden Fluid Wanii 2040 1.00 50 6,000 143 149 24 30#H borG Pro ant Laden Fluid Wanii 20/40 200 50 6000 143 155 9) zer 'eft U ae a� a 2-5 30#H bore Pro ant Laden Fluid Wanii 20140 ' 3.00 50 7000 167 188 •• �•� 21000 � �� �• 0:03:47 0:26:57 1,00 0.80L 0.90 u.4p 1 0.45 1 30.00 30.00 1 0.15 0.15 2.00 2.00 1 0.25 0.25 2-6 30#HborG Pro ant Laden Fluid Wanii 2040 4.00 50 8,000 190 223 32,000 0.0:30 0:23:10 1.00 0.80 0.90 OAS 30.0 0.15 2.00 0.25 2-7 30#HborG Propan, Laden Fluid Wanli 2040 5.00 50 8000 190 __232__L 40,000 0.0:41 0:18:40 1.000.80 0.90 0.45 30.00 0.15 2.00 0.25 2-8 30#N 6prG Proponent Laden Fluid Wanii 2040 6.00 50 7634 187 235 47004 0:04:45 0:13:59 1.00 0.80 0.90 0.45 30.0 0.15 2000 0.25 0.25 2-9 30#HborG Pro ant Laden Fluid Wanli 2040 7.00 50 6,000 143 186 42,000 0:03:6 0:09:14 1.00 am 0.90 0.45 30.00 0.15 2.00 025 0.25 240 30# linear Flush 50 10,635 253 253 0:05:04 D:05:28 1.00 30.00 0.15 2.00 025 050 2-11 Freeze Protect freexe.Prohct So 840 20 20 0:00:24 0:00:24 100000 3-1 30#H bore 5 ttr&DroBall 50 1,000 20 24 0:00:29 0:52:45 1.00 D90 090 0.45 30.00 0.15 2.0 025 3.2 Nif HyborG Displacment 50 10,475 249 249 0:04:59 0:52:16 1.00 080 0.90 0.45 30.00 0.15 200 0.25 3-3 30#H borG Pad 100 mesh 50 11,200 267 267 0:05:20 0:47:17 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 34 30 H bore Pad TOO mesh 0.25 50 28800 686 686 7,200 0:13:52 041:57 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 M 30#H bore Pr0 ant Laden Fluid Wanii 2040 1.00 50 6000 143 149 6000 0:02:59 0:26:04 1.00 0.80 0.90 0.45 x10 0.15 2.00 0.25 3-6 30pH bore Pro ant laden Fluid Wanii 2040 2.00 50 6000 143 155 12,000 0:03:07 0:25:05 1.0 0.80 0.90 0.45 30.00 0.15 2.00 0.25 3-7 30HborIS Pro ant Laden Fluid Wanii 2040 3.00 50 ]WD 167 188 21,000 0:03:47 0:2158W000 0 0.90 OAS 30.0 0.15 2,00 0.25 3-8 3WHborIS Pro ant Laden Fluid Wanii 2040 4.00 50 8000 190 223 32,000 0:04:30 0:18:110 0.90 0.45 30.00 0,15 2.00 0.25 39 30pH bore Pro ant Laden Fluid Wanii 2040 5.00 50 80011 19D 232 40,000 0:04:41 0:13:400 0.90 0.45 30.00 0.15 2.00 0.25 3-10 30p bore Pro at Laden Fluid Wanli 20140 6.00 50 7834 187 235 47,004 0:04:45 0:09:000 0.90 0.45 30.00 0.15 2.00 0.25 3.11 3I)rtI O! ;....net Laden Fluid Wanli 20/40 7.00 50 6000 143 186 42,000 0:03:46 0:04:150 0.90 0.45 30.00 0.15 2.00 0.25 3-12 30#HvborG Space, & DroBall 50 1,000 24 24 0:00:29 0:00:290 090015 2.00 0.25 4-1 30#H borG Pad 50 11200 267 26] 0:05:20 0:6]a 0.90 DAS 30.00 0.15 2.00 0.25 CUSTOMER [onowPhillips Alaska, Inc. LEASE ROU 35b11 FORMATION Mora Fluid Stage 4: 7-3 3D4H bore I Pro ant laden Fluid Prop ani laden Fluid 74 SON H borG Pro pant laden Fluid 188 --I--- 21,000 ........... 0:03:47 .....1...1 0:21:58 .... 1.00 .- 0.80 t^e - 0.45 JU.UU 30.00 U.1J 0.15 L.W 2.00 U.l] 0.25 7-6 30pH bore ProO ant Latlen Fluitl Wank 20/40 4.00 50 8000 190 223 32,000 0:04:30 Asu 2@s M t a API 50-103-20774 FD (Ib/golf 8.54- 19449685 SALES ORDER 903873945 BHST('F) 165 MALSlURTpN 1932684 DATE Mad Pressure Dsll rOP Yfly Pin edn Y(n/ rOP tdB[ n [Nd Y Conc Rate Volume Volume Volume Total Time Time sunananv GW 1 11-6,1 6,e W I drea4m 7-5 30pH bore Prop ani laden Fluid - Wan1120/40 3.00 50 7,000 167 188 --I--- 21,000 ........... 0:03:47 .....1...1 0:21:58 .... 1.00 .- 0.80 -- 0.90 - 0.45 JU.UU 30.00 U.1J 0.15 L.W 2.00 U.l] 0.25 7-6 30pH bore ProO ant Latlen Fluitl Wank 20/40 4.00 50 8000 190 223 32,000 0:04:30 0:18:11 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 79 ]-8 30MH bore 30NH bore Proant Laden Fluid Proant Laden Fluid WanIi 2040 WanIi 2040 5.00 6.00 50 50 SOOD 7,834 190 187 232 235 40000 47,004 0:04:41 O:W:45 0:13:40 0:09:00 1.00 1.00 0.80 0.80 0.90 0.90 0.45 0.45 30.00 30.00 0.15 0.1.5 2.00 2.00 0.25 0.25 7-9 30RH borG Prop ant Laden Fluid WanIi 20/40 7.00 50 6,000 143 186 42,000 0:03:46 0:04:15 1.00 0.80 0.90 0.45 30.0 0.15 2.00 0.25 7-10 30RH borG Spacer & D,.Ball 50 1,000 24 24 0:00:29 0:00:29 1.0 0.60 0.90 0.45 30.0 0.15 2.00 0.25 8.1 3NHyb.rG Pad 5o 13200 267 267 0:05:20 0:51:14 1.00 D.80 0.90 0.45 30.00 0.15 2.00 0.25 8.2 300 HyborG Pad 100 mesh 0.25 50 28,800 685 686 7200 0:13:52 0:45:54 1.00 D.W 0.90 0.45 30.00 0.15 2100 0.25 8-3 McHborG i Pro ant Laden Fluid WanIi 2040 1.0D 50 6000 143 149 6000 0:02:59 0:32'.02 1.D0 D.W 0.90 0.45 30.00 0.15 2.00 0.25 S-4 30RHborG Pro ant laden Fluid Wanli 2040 200 50 6000 143 155 12000 0:03:07 0:29.03 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 8-5 30NH borG Pro ant Laden Fluid W..1120/40 3.0 50 7000 167 188 21D00 0:03:47 0:25',56 1.00. 0.80 0.0 D.45 30.00 0.15 2.00 0.25 8-6 308H bore PropantLatlen Fluld WanIi 20/40 4.00 50 8000 190 223 32,000 0:04:30 0:22:08 1.0 0.80 0.90 0A5 30.00 0.15 100 0.25 8-7 309HborG Pro ant Laden Fluid Wanli 2040 5.0 50 9.000 190 232 40WD 0:04:41 0:17:38 1.0 0.80 I 0.90 D.45 30.00 OAS 2.00 0.25 8-8 30p HyborG Pro pant Laden Fluid Wa nli 20/40 6.00 50 7,834 187 235 47004 0:04:45 0:12:58 1.00 O.BO 0.90 0.45 30.00 0.15 2.0 0.25 0.25 8-9 309 HyborG Pro nt Laden Fluid We nli 20/40 7.00 50 6,000 143 186 42,000 0:03:46 0:08:12 1.00 0.80 0.90 OAS 30.00 0.15 2.00 025 0.25 810 30n linear Flush 50 8,481 202 202 0:04:02 0:04:26 100 30.00 0.15 2.00 0.25 050 8-11 Freeze Protect Freeze Protect SD 840 20 20 0:00:24 0:00:24 1000.00 9-1 30NHborG Spacer &Drop Ball 50 1000 24 24 0:00:29 0:52:45 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 9-2 30P bore Diz iacment 50 10475 249 249 0:04:59 0:52:16 1.00 0.80 0.90 0.45 3D.00 0.15 2.00 0.25 9-3 308 bore Pad 1 100 mesh 50 11,200 267 267 0:05:20 0:47:17 1.00 0.80 1 0.90 0.45 30.00 0.15 2.00 0.25 CUSTOMER WnocoPhilllps Nash, Inc. API 50-10380774 FD(Ib/gGl) 8.54 --- 19aa9685 LEASE GRIT 35-631 SALES ORDER 903873945 BHS7 f -F)165 HA MWTDN _ .1932684 FORMATION Moralise DATE Max Pressure geil 1 30h Linear 1 48.056 1 Proppant TYpe Ign Total(lbs) WanIi 20/40 2,200,040 100 mesh 1 79,200 -P-Surf 3000 1 MO -67 CL -22 UC CL -31 Prep urry Clean can slurry Prop btage nterva o- u - b4md Addmves - - /gpm) - Ory Additives p o- p4 0- p m eatmen Stage Fluid Stage Proppant Con Rate Volume Volume Volume Total Time Time sunaaam eunv oassnnaer Wssan4er FRere amen Gel 8wcke ereawer 0.4 0.1 1 Interval Number Description Dincri tion Description IAPW) m 901 (bbp (bbl) lbs hh:mmss (hM1:mmss (9pU toot) [apt) t t (pp[) [) Q ereaxa� t ft) 11-1 30aH borG Pad 50 11,200 267 267 0:05:20 0:50:47 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 u. 11-2 30HborG Pad 100 mesh 0.25 50 28,800 686 0 0:13:52 0:45:2] 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 11-3 30pH bore Pro nt Laden Fluid WanIi 20/60 1.00 50 6000 143 00 0:02:59 0:31:35 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 Y 11-4 30RH borG Pro nt Laden Fluid WanIi 2040 2.00 50 6000 143 00 0:03:07 0:28:36 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 11-5 30 H borG Prp nt Laden Fluid WanIi 2040 3600 50 7000 167 00 0:03:47 0:25:29 1.00 0.80 0.90 GAS 30.00 0.15 2.00 0.25 31-fi 30 H borG Pro aM laden Fluid WanIi 20/40 4.00 50 8000 190 00 0:04:30 0:21:41 1.00 0.80 0.90 0.45 30.00 0.352.00 0.25 11-] 30BH borean Propect Laden Fluid WanIi 2040 5.00 50 8000190 00 &12,0000:03:07 0:04:41 0:1]:11 1.00 0.80 0.90 0.45 30.00 0.15 2.00 0.25 0H bore Pro pant Laden Fluid Wan112040 6.00 50 ]830 1B) 04 0:00:45 0:12:30 1.00 080 0.90 0.45 30.00 0.15 2.00 0.25 0.25 11-9 30hH bore Prop ant Latlen Fluid WanIi 20/40 7.00 50 6000 143 00 0:03:46 OD]:45 1.00 0.80 0.90 045 30.00 0.15 2.00 0.25 0.25 11-10 30h Linear Flush SO 7528 179 0:03:35 0:03:59 1.00 30.00 0.15 2.00 0.25 0.50 11-11 Freeze Protect Freeze Protect 50 840 20 0:00:24 0:00:24 1000.00 1 30h Linear 1 48.056 1 Proppant TYpe Ign Total(lbs) WanIi 20/40 2,200,040 100 mesh 1 79,200 -P-Surf 3000 1 MO -67 CL -22 UC CL -31 LVF -200 WG -36 81-6 OptiFlo-III OpdFlo-II SP (pmf (gpm pm) (ppm /gpm) ppm ppm ppm p m ppm Max AdditNe Fetal 2.1 1 1.7 1.9 0.9 2,100.0 fi3.0 0.3 4.2 0.5 I1.1 Min Additive Rural 0.2 1 0.2 1 0.2 1 0.1 210.0 1 5.3 0.0 0.4 0.1 1 D.1 Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Data 2018-10-26 State: Alaska County: Harrison Be API Number 5010320]]4 NORTHSLOPE. Operator Name: EBUS Well Name and Number. KRU 3S411 Longitude: -150.19 Latibuds: 70.39 LonglLat Projection IndumlFederal: none production Type, True Vertical Depth (TV nk 0 Total Water Volume feel)-, 1,113,181 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Ingredient Mass Comments Company First Name Last Name Email Phone Number (CAS (% by mass)" HF Fluid I% by lbs 2e massr* Sea Water Operator Base Fluid Water ]]32-18-5 96.00, 79.14321 9126273 Gensi =6.540 MICRO91OCIDE Halliburton MIC Biocide Listed Below Listed Below 0 NA CL-22 UC Halliburton Croeslinker LMed Below Listed Below 0 NA CL -31 Halliburton CROSSUNKER Crosslinker Listed Below Listed Beim 0 NA LOSURF-3000 Hellibutlon Non-ionic Su laden Listed Below Listed Below 0 NA MO 7 Halliburton pH Control Additive Listed Below Listed Below 0 NA OPTIFLO-11 DELAYED RELEASE Halliburton Breaker Listed Below Listed Below 0 NA BREAKER OPTIFLO-111 DELAYED RELEASE Helliburron Breaker Listed Below Listed Below 0 NA BREAKER MIT&100 MESH, S00 HaMbuman MESH,SSAC Proppant Listed Below Listed Below 0 NA LB SACK BE B SP BREAKER lHallitamon Breaker Listed Below Listed Below 0 NA WG -36 GELLING Hallibutlon Gelling Agent Listed Below Listed Below 0 AGENT NA LVT-200 permos Additive Listed Below Listed Below 0 NA Xinmi Wanli 20140 Weill Industry Additive Listed Below Listed Below Developmen 0 NA t Co. Lttl Ingredients Listed Above 1.2,4 Tdmelh Ibenzene 9$63-6 1.008 0.000718 84 2-Bromo-2-nitro-1,3- ro enediol 52-51-7 100.008 0.001418 167 Denise Tuck, Halliburton, 30W Acrylate polymer Proprietary 1.008 0.000958 113 N. Ban- Houston Halliburton Danlse.TUCk@ Denise Tuck HallibuMn.co 281-871-6226 Pkwy E., Houston, Tx 77032,281- 871.6226 Ammonium persurne 7727-54-0 100.008 0.02111% 2507 Oenise.T.k@ Borate salts Propdelery 60.008 0.056]98 6]40 Halliburton Denise Tuck Halliburton.. 281-871-6226 Corundum 130244.5 55.008 10.166688 1210055 Cr,a1a111ne sills, uart2 1480&fi0-] 100.008 0.6]2]28 799M Denise.Tuck® Cured acrylic resin Propdetery 30.008 0.006348 753 Halliburt. Denise Tuck Halliburton.. 281-671-6226 m Ethanol fi4-17-5 60.008 0.042328 5027 Guargum 9000.30.0 100.00t 0.281158 33396 Hea malic etmieum naphtha fi4742-94-5 30.008 0.021168 2514 rolreatetl Distillate, ❑ hL.0&18 64]42-0]-8 100.008 0.195468 23218 WOE 1302-93-8 45.008 8.334]28 990045 008 0 00353% 419 Oxylated phenolic resin Propdelary 30.008 0.02122% 3352 OenTuck� Halliburton Denise Tuck Halliburton.co 281-8]h6226 m Ponyhphe1,2l)-onnanetliyg,alpM1a(4- n0nylphenygcme9a-M1ytlroxy-, 127087-87-0 branMetl 5.008 0.00353% 419 Potassium 590.29-0 60.008 0.05619% 6740 hydro i Potassium hydroxide 13105&3 5.008 0.002208 261 POte3510m rMtabOfale 137099M9 61.008 1.026398 3129 Sodium carboxymethyl cellulose 9004-324 1.008 0.00095% 113 Sodium chloride ]54)-145 4.002 3.202964 380466 Sodium fliv.1lifle 283632-0 1.008 0.000958 113 Sotlium hd.de 131043-2 30.00% 0.022118 2709 Sotlium ersuflale ]]]S2]-1 300.008 0.000298 34 Sodium sulfate 7757-82-6 0.10% 0.00001% 1 Water ]]32-185 100.00% 0.130118 155H ' Total Water Volume sources may induce fresh water, produced water, andlor recycled water " Information is based on the maximum potential for concentration and thus the total may be over 100% — Note: For Field Development Pmtlucts (products that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from the suppliers Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the wntent Wthe MSDS should be directed tothe supplier"m provided it. The Occupational Safety and Health AdMinistration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary",'grade secret", and "confidential business information" and the criteria for how this infonnaAon is re rted on an MSDS is sub act to 29 CFR 1910.1200 and Aooendix D. SAFETY DATA SHEET Date -Issued: 05-2015 SDS Ref. No: CFT Date -Revised: 2/04/15 Revision No:004 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, 10200, 10250, 10300, 10350, 10400, 10450, 10500, 10550, 10600, 10650, 10700, 10750, 10800, 10850 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-10200, CFT10250, CFT-10300, CFT-10350, CFT-10400, CFT-10450, CFT-10500, CFT-10550, CFT-10600, CFT-10650, CFT-10700, CFT-10750, CFT-10800, CFT-10850 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) Hazardous H315 Causes skin irritation. H319 Causes serious eye irritation. H335 May cause respiratory irritation. Precautionary statement(s) P261 Avoid breathing dust/ fame/ 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 imitation 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 imitation 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. Ingredient 11 CAS/Exempt No Percent Hazardous ProprietaryIngredient supplied as 10% w/v Proprietary 10 No A ueous Solution Water 7732-18-5 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 imitation 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. 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 ENI 66. 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 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 9.2 b) Odor Odorless C) Boiling point Approximately 100°C d) Freeze point 0°C e) Density 1.05 g/mL f) 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 1) Vapor density Not determined M) Viscosity Not determined 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 stmcture. 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 111, 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. 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: 02/04/2016 Contact information: 713-328-2320 SAFETY DATA SHEET Wcl� armmia srntivat®t Date -Issued: 05-2015 SDS Ref. No: OFT Date -Revised: 05/05/2016 Revision No:006 1. PRODUCT AND COMPANY IDENTIFICATION 1.1 Product Identifiers Product name 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 Generic name OFT -15000, OFT -15010, OFT -15020, OFT -15040, OFT -15050, OFT -15070, OFT -15110, 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 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) 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 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. Ingredient Proprietary Ingredient CAS/Exempt , Proprietary Percent 0-30 Hazardous No 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 PoII 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. 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 ACGHTs 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 EN166 (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) Boiling point Approximately 175°C d) Freeze point Not determined. e) Density Not determined. Flash point pH Evaporation factor Solubility Vapor pressure Oxidizing properties Vapor density Viscosity Auto -ignition temperature Explosive properties 9.2 Other safety information No data available. 10. STABILITY AND REACTIVITY 10.1 Reactivity No data available. Approximately 65°C — closed cup Not determined. Not determined. Not soluble in water. Not determined. Not determined. Not determined. Not determined. Not determined. Not determined. 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. IL 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 corrosionlirritation Skin irritant 2-11315 Causes skin irritation. Serious eye damage/irritation Eye irritant 2 — 11319 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 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 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. 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: 05/05/2016 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.) From: Svlte, Hanna To: Boyer, David L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL]Estimated Top of Cement for Csasing Stirs in KRU 3S-611 Date: Monday, November 19, 2018 3:20:49 PM Attachments: 35-611 Intermediate Cement Review.odf Hi David, Thank you for reviewing the sundry. We had losses during the original surface casing cement job and didn't get cement to surface, so performed a top job after the fact. Cement was seen at surface during the top job. The top of intermediate cement was indicated at ^'8,228' MD on the sonic log, intermediate cement review attached. Please let me know if you need any more information for this sundry. Thank you, Hanna Sylte Completions Engineer ATO 1556 Office: (907) 265-6342 Mobile: (713) 449-2197 From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Monday, November 19, 2018 3:00 PM To: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: [EXTERNAL] Estimated Top of Cement for Csasing Stins in KRU 3S-611 Hi Hanna, I just began reviewing the Sundry Permit No. 318-488 for fracture stimulating the KRU 3S-611 well. Do you have estimated tops of cement in the surface and intermediate casing strings? It appears that the top of the cement for the surface casing is at 329.61' according to correspondence between Ben Tolman and Victoria Loepp but I would like to confirm both TOC's. Thanks, Dave Boyer P.S. Steve Davies is out of state on vacation this week. 7-5/8" Intermediate Casing Set at 12,620' MD / 5,101' ND Cement Slurry: • 1,310 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 16.0 ppg Cement Evaluation • Good cement coverage from shoe up to 10,522 MD. • 2098' MD/ 544' TVD above shoe • Poor cement between 10,522 to 9,450' MD. • Good to intermittent cement coverage from 9,450' — —8,228' MD. C -so 5,460' MD / 3,268' TVD C-35 8,161' MD / 3,952' TVD Coyote 8,782' MD / 4,111' TVD Base Coyote / Torok Shale 9,461' MD / 4,284' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Nov 7 1 9Mo WELL COMPLETION OR RECOMPLETION REPORT ANDIGG 1a. Well Status: Oil Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well CI t 20AAC 25,105 20AAC 25.110 "G x Development � Exploratory ❑ GINJ ❑ WINJ ❑ WAG[] WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Abend.: 10/23/2018 • 218-103/318-458 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510.0360 9/25/2018 50-103-20774-00-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 2505' FNL, 1013' FEL, Sec 18, T12N, R7E, UM - 1011712018 KRU 3S-611/3S-611PB1 Top of Productive Interval: 9. Ref Elevations: KB:63.6d - 17. Field / Pool(s): 933' FNL, 4251' FEL, Sec 12, T12N, R7E, UM GL: 24.50 BF: Kuparuk River FieldRorok Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: - - 514' FNL, 297' FEL, Sec 2, T12N, R7E, UM N/A I ADL 380107, ADL 380106, ADL 025520 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 476247 - y- 5993910 - Zone- 4 ' 18685/5222 ' 932060000,932059000,931866000 TPI: x- 468229 y- 6000791 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 466924 y- 6006496 Zone- 4 N/A - 163011573 - 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 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 CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 94 X-52 39 119 119 119 42 Installed 103/4 45.5 L-80 39 3027 39 2580 131/2 223 sx 12.Oppg Class G 2401 sx 11.Oppg Class G 332 sx 1 1.0ppq Class G 75/8 29.7 L-80 36 12609 36 5099 97/8 1310 sx 15.8ppg Class G 4112 12.6 L-80 12467 18671 5060 5222 63/4 Uncemented Liner 24. Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perf l): 41/2 12475 12338/5025 FRAC SLEEVES @: 13093 MD and 5221 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13588 MD and 5280 TVD 14086 MD and 5268 TVD COMPLETION 14583 MD and 5254 TVD DATE 15114 MD and 5241 TVD l oZ 3 1 Was hydraulic fracturing used during completion? Yes ❑ No F Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 15609 MD and 5234 TVD 16141 MD and 5250 TVD VERIFIED 16636 MD and 5255 TVD 17169 MD and 5245 TVD 17952 MD and 5231 TVD 18603 MD and 5223 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): WAITING FOR HOOK-UP Date of Test: Hours Tested: Production for Oil-Bbl:Gas-MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casinq Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): P I 24 -Hour Rate v`rZ- 2/s/i 9 Form 10-407 Revised 5/2017 /i �8�f�' CONTINUED ON PAGE 2 RBDMS r, () (f NOV 2 1 20 8 Submit ORIGINAL onlyC, 28. CORE DATA Conventional Corals): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored (MD[TVD, Fromfro), 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 El If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1630 1573 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 12805 5149 information, including reports, per 20 AAC 25.071. Formation c@ TPI - Top Moraine West Salk 2162 2024 C-80 3255 2684 C-50 5456 3268 C-35 8159 3952 K-3 8782 4111 3S-611 PB1 3034 2575 TD 18685 5222 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, l report, production or well test results, per 20 AAC 25070, 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 R � Authorized Title: laska Drillin Mana erL:V✓ Contact Email: Ben.V.Tolmanaco .com Authorized — Contact Phone: 265-6828 Signature: Date: I//," INSTRUCOtIONS 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 10-404 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 1 a: 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 Box 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 SS ( Moraine 3S -61'i Crass Roots Horizontal Multi -Stage Frac'd Producer ConoeoPhillips Post Rig Wellbore Schematic FMC 4-56" tree, top joint is 4-Y2" 12.6# HYD563 New Conductor: 20" Conductor @ 106' cameo Ion�za4• a surf. a -z cameo BB waple aslr 13-1/2' Surface Hole Spud Mud 10.0 PPG 1 "RBMG wi1N Dummy (a,fi31' M., g"97' ND) Surface Casina: 10-3/4" 45.5# L-80 Hydril 563/TXP Tubino7 4-1/2" 12.6# L-80 Hydril 563 12,474' MD 4%, a 1 " nemG with SOV (11,869 MD) 4,899 ND) SLB Gauge Carrier 12,275MD 7-518"v4-X"Baker Flex Lock Liner han9er2 Pfuer by packer al RS Ni ale,, 12,489' MD Intermediate Casino: 7-5/8" 29.7# L-80 Hydril 563 12,609' MD / 5,099' TVD 9-7/8" Intermediate Hole LSND 9.6 PPG 16-3/4" Production Hole 1. 0 0 0 0 PPG Production Liner - D 4-1/2" 12.6# HYD563 Production Hole ' - 90.88 18,671' MD / 5,222' TVD 18,685 MD / 5,222' ND COnOCOPhillips Alaska, Irw. KUP PROD WELLNAME 3S-611 MORTR04 WELLBORE 3S-611 asdiT 111lecon.:50:on PM C$$mg $frmg3 VxtlnlWxneR(ecwul Casln9DezSIV Conow., OD (in) 20 IDllnlTopmKtg See Ospib 11IX B1 But Depth B1eB. WYLen 11... Orale Top 18.50 390 119.0 1190 154.00 X52 Threat _................ aryac 343 L Casing Panaanin OD ons Ib lin) Top rdKEg Bsl down 1.1 ael Oeptb T'ItUb ..WIILen ll... 6rn4e rep Th"d .........._.................._........._......... - . .. 1` +�....... ... -Intermediate Surface 103!4 995 388 3,027.3 2580.2 45.50 LA0 Hyddl 563 casing DwwNggdn OO (in) 7518 ID lin) Tap Ulna) Set Depth ladle set Depth (1VD1... WBLm 11... Gms TOpT- 688 00 12.6030 5,098.9 29]0 L80 H563 relocm.cmem:an xe s,wce c.z um.rti n m.o0lra coanam., saollgo -Y i� ; .♦ «„p "Liner case, Des,Igun Protluclion Liner DID did 412 IDp) Top laza) SM dapth(uKal see Nam lND)-waLan 11 GmNr TOP Threed 3.96 12,46].3 18,671.4 5,222.4 12.60 L-80 Hyd 563 Details tomNal to MPatly Fl„i4-Dn&', oo ?1740 TuplaKel Tnp(WDllxKel mPmdr) mm Dee Co. One sumo temp careen, ae>0 MB 12,4969 5065.5 7403 Nipple - R RS Nipple, 5.10 Hyd563 4250 12,4892 5,0662 7403 Hanger Liner Hanger, FL pinned 1706 psi 4.000 12,5082 5,071.4 7406 eal Bore Sealboure 8040 x 20,5"Hyd S Pin up x 4.S Hyd 4,000 Extension 521 box down s,mm: xlea,ce7.a 12.839.3 5,157.0 7543 Swell Packer PACKER,SWELL,4112 X SAY BAKER,HYD563 SN 3.890 ., S'Qh (002142-001-11) A Mass Bmd szll.-awlaw: 13,092.9 522(1.6 75.48 Frac Sleeve Baker cs1eeve(2.6 'ball 71 6,HYDS 3CN 2.665 2,179 o-tl res. mmnuave'varo clmwa', (H01049-0315 0100315 Oltl#FPSC-310)10 s.e.eonxe 13,338.3 5,272.2 8346 Swell Packer PACKER,SWELL4112 X 6 00".BAKERHYD563 Ed 3.880 M.no. 11.91 (002142-001-3) B Mnwl . u seormbn Moe ennmNmw.ln. X Gauge/Pump anrtn: 1228.0 13,587.8 5,280.1 90.4] Frac Sleeve Be er rat sleeve (2645" ball D 1043]070 OM#FPSC-21] 9 ( ) 2.605 13,035.8 5,274.3 91.67 Swall Packer PJuCKGR,SWEU41 X 6 00i.BAKER,HYD5633.890 Pxw'.t2oaez (002142-001-13)C 14,086.1 5,268.1 91 ]5 Fret Sleeve 9.7. ft.seeve "bell) a,H 2.555 (1-1810-09Akln 010 FPSC-1976) 8 14,3316 5.261.0 91.67 Swell Packer PA7KER,SVVEI-L,41J2X6W BAXEP,HYD5n3890 Lmex', 1246te.a (002142-001-2) D 14,582.8 5253.6 W87 Frac Sleeve Baker racs ve 12 545' ball) #, HY563 CN 2505 Leisure, 2.4gi (H810-09-0 nOld#FPSC3 )7 Mob sna:f2aag 14,064.4 5,248.3 91.01 Swell PackerL, GYD563 SN 3900 (002142-001-5)E 15,113.8 5,241.5 91.93 Fre: Sleeve MW rat sleeve " -W117#9, HYD BIG CN 2 465 (10437089 Old# FPSC-226) 6 15,359.3 5,234.9 91.15 T.ell PackerFAURMTMIF 1 -. A . HYD 511 SN 3.090 InMma. D0,12.®o (002142-001-7) F 15,609.4 5, 7 44 Frac Sleeve Bait., inicseeve 'Gal#,H N 2425 (Hall 0091 19010 FPS61975) 5 15.8537 5240.0 8845 Swell Packer PACKER, LL, X 6.01Y,BAKER,HYD5 N 3900 (002142-001-1) G 16141.8 5250.4 86.90 Frac Sleeve Bakerrac sleeve (2.416' ball#,Al2385 (l U37M Old# FPSC-1810) 4 16,3872 5.2804 9101 Swell Packer PACKER,MELL,4 la X ',BAKER, HYD563 SIN 3.900 (002142-001-6)H 16,6357 5255 2 9121 Frac Sleeve Baker sleeve (2,375" ball) #3, HYD -575 -CN 2.345 (1040215MO 8FPSC-1976)3 169183 5249.6 91.20 Swell Packer PA KER, WELL, 1 X W",BAKER,HYDS N 3910 (0021424014)1 17169.1 5244.6 9105 Frac Sieeve Baker frapshave 5- ball) #,HYD5J N 2305 (1043]059 Old# FPSC #1810) 2 174158 5,239.5 91.07 Swell Packer PACKEGSVVI ",BAKER,HYD N 3900 (Ni J 17,823.5 52353 9122 Swell Packer PACKLL,411 X ',BAKER,HYD5 N 3.900 (0021424IOtA)K 17,952.5 5.2314 9064 Frac Sleeve Baker firal sleeve 5" ball) #1, HYD N (A- 2 265 42878)1 EMS 18,2769 5.2274 90.52 1 Swell Packer PA KER, VVELLA V2 X 6,00 BAKER,Hl SN 3.900 (002142-001-9) L 18602.7 52234 9084 Frac Sleeve Alpha Pressure Sleeve, rupture disc #14--(M psi 3.000 rvn,u R,4a-smlamare. low, 7900 psi high, 7613 nom psi) 1?.a7.o-te.e».o 18,616.3 5223.2 90.86 Frac Steeve 7Vellbore15o1.ihm Valve Bball i5 Ti-ilive, OWO 990 psi shear iiiiiii Tubing Strings Tubing 0esc,ipene, 31,1174 Ma... ID lin) Top!Alltel SM Death la. BN Depth (ND) (... 071110710 Graee Tap Lonnecllon Tubing - Prgtludian 4112 3.96 34.3 124]4.9 5,062.2 12fi0 L -BO Hydru Sfi3 Completion Details Top (WD) Topinel .-Ind Topol Vi r) Item Des, Com mlml 34.3 34.3 0.00 Hanger Handed. 4-117' x 10314" Gen 5, FMC TC -1A EMS 3.920 1,974.1 1,869.6 32.57 Nipple -3. SIT' Nipple, Carruce, 3.813n OR Profile, ole 3.813 DB -6 angle) 12,2760 5,0074 73.97 Most l Pump Gauge Carrier, SLB, SGM vnth Sapphire tubing pressure gauge, 3.864 Sensor SN:CISGM-0002 12,338.2 5,024.6 7404 Packer Packer, Baker 412'x] NV Premier 3.860 12,4046 5042.0 ]401 fipple- .7S DB Nipple, amco, 3.75" BE Pmfiec N45 (dual flapper plug 3.750 A installed) 12,464.5 5,059.3 7400 Locator Mechanical Locator .5"TCII Box( D 6 4" large ODabove 3940 located) 1246551 5,059.6 74.00 iLocal., Mechanical Lowlor4S"TCII Box (small OD below located) 3.940 124]39 5,0619 ]4.01 Mule Shoe Baker Fluted WLEG(Wire line entry guide) 3.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, aft.) TDp NO) Top incl Top (M(8) I IY Des I Com Run Deh IOlinl 12,mPl6 5,042.8 14.01 Dual dapper X-0 above vaNe ,valve e, o valve 1 0.900 I valve is.90". Whole assembly is CAL 33.5"_ 8 This was used in place of ball and rod. Pwucmn L-1 12 467 186714 KUP PROD WELLNAME 3S-611 WELLBORE 3S-611 ConocoPhillips Alaska. Inc. 6 1-1 35E++. 1111.1B3 54'. 10 PM Mandrel Inserts vmd aw.veclacem9 s1 m TopIN01 VaM Lien .... TRO Run Many -30.3 X �<z......... N Top ntlL0 Make MOEeI OD Sew TYpa Type (in) (Wd Run Com ..... Za, Yti 3,620.6 796 2,]98.9 emco 1 1 GAS LIFT Dumm BK -5 10/1112018 41 ........................... .... .. ... (KBMG) 05564- Y 000- c> -aim, c.nre�r.4z.Tna9 Xi s�.ro uamacm,.m* 5$' 0S,, g Jeb, 00 film Cvqucux, A.b11B0 / i5X' 4 sera 0]3AK0 5 MwIn FWq-O'wM,0.9 Y.. .+f 2 2n4.o - 2 11,869.4 4,8989 amco PN: 1 GAS LIFT OV BEK 1022201 s�.xac.alre cama43ssa nKe (KBMG) 05564- 000- 00009. 7 0 4 24AK0 2 9m1am: ]9.630Z/.3 MagM; 3,BID.8 MnJn FLp-3eMabNBrce; $1]40.1199.0 Inbmxbb Fees C. S,e oeem v aa; ll.ees.a .b Mnua,n�.11..a 12, b re: n.B39..12Mo Wtq/ PumP3a�%/. 122m.0 P.I.', 12,.2 Lssb; t$Ni.3 Lenb; 124895 MW SPU: 124239 211, InWrMela;06+2.�0 .uku FIUL-SYMDtr9ma; +z<92.o-�9.n1.9 I Miss P�meuoow.', 1zasTs +48]34 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Siad Depen Steri Time End Time our (hr) Phase Op Code Activity Code Time P -TA Operation (ftKB) End Dept,(ftKB) 9/19/2018 9/20/2018 24.00 MIRU MOVE MOB P Pull sub off well and stage for BOP 0.0 0.0 00:00 00:00 removal. Remove BOP while simops cleaning area around 1 H-104. Simops moving Pits, Pipeshed, Motors, and pumps to CPF3. Move sub to 3F pad. Pumps and motors to 3S pad. Pipe shed pits to 3G pad. Simops staging and setting rig mats / portable road / plywood. 9/20/2018 9/20/2018 0.50 MIRU MOVE MOB Jack up and move rig to 33. 0.0 0.0 00:00 00:30 9/20/2018 9/21/2018 23.50 MIRU MOVE MOB T Made less than 1 00'when rig whent 0.0 0.0 00:30 00:00 through road. Jacked tires up and filled void with dunage / plywood. Utilized dozer and grader to pull Sub back onto 3F pad and stage. Allow DTH to pull all rig mats from previous distance (from 1 H -pd) and re -deploy on road from 3F- 3G pad. Allow DTH to pull all rig mats / plywood from 3G - 3S pad and re -deploy from 3F - 3G in preparation to move sub. Simops dg maintenance. Crews working on prep to pull traction motors and drawworks motors. Also, prep to pull energy track / rebuild pumps. 9121/2018 9/2112018 14.00 MIRU MOVE MOB T Continue to shuffle mats from 3F -3G 0.0 0.0 00:00 14:00 to assist in rig move. Simops rig maintenance. 9/21/2018 9/21/2018 1.50 MIRU MOVE MOB P Move sub from 3F - 3G no issues. 0.0 0.5- 14:00 15:30 9/21/2018 9/21/2018 4.50 MIRU MOVE MOB P Start rig mat shuffle from 3F/3G 0.0 0.0 15:30 20:00 access road and move to 3G/3S access road. Pull and roll up portable road, ply wood. Begin disengagement of energy track system for complete replacement. 9/21/2018 9121/2018 2.00 MIRU MOVE MOB P Move Rock washer/two parts 0.0 0.0 20:00 22:00 1 trailers / #16 shop to 3S pad and set.. 9/21/2018 9/2212018 2.00 MIRU MOVE MOB P Continue to shuffle mals from 3G - 3S 0.0 0.0 22:00 00:00 to assist rig move. 9/22/2018 9/23/2018 24.00 MIRU MOVE MOB P Continue to redistribute dg mats / 0.0 0.0 00:00 00:00 plywood / portable road from 3F -3G access road to 3G -3S access road for purpose of moving Sub structure, Pipe shed, pits of Doyon 142. Simops replace rig energy track, continue prep work for draw works traction motor removal / replacements. 9/23/2018 9/23/2018 10.00 MIRU MOVE MOB P Continue to recoup rig mats from 0.0 0.0 00:00 10:00 3G/3G and set from 3G to 3S. Portable road and plywood. 9/23/2018 9/23/2018 4.00 MIRU MOVE MOB P Move sub from 3F - 35 0.0 0.0 10:00 14:00 9/23/2018 9/23/2018 5.50 MIRU MOVE MOB P Set rig mats on pad to for sub. Set 0.0 0.0 14:00 19:30 stompers / inslalll BOP and pull stompers prep to spot over well. 9/23/2018 9/23/2018 1.50 MIRU MOVE MOB P Set sub over 35-511 0.0 0.0 19:30 21:00 9/2312018 9/23/2018 2.25 MIRU MOVE MOB P Move Pits and pipeshed from 3G - 3S 0.0 0.0 21:00 23:15 while simops pull low tongue and skid rig floor over well. 9/23/2018 9/24/2018 0.75 MIRU MOVE MOB P Spot pit complex and MU mud and 0.0 0.0 23:15 00:00 service lines. Page 1122 Report Printed: 1 012 512 01 8 operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DepM Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Dept (ftKB) 9/24/2018 9/24/2018 7.00 MIRU MOVE MOB P Spot all rig modules and install inner 0.0 0.0 00:00 07:00 connects. Install handrails and stairs. Rig up beaver slide and spot cuttings lank. Prep for rig maintenance. 9/25/2018 9125/2018 1.50 MIRU MOVE RURD P Nipple up mouse hole & riser. 0.0 0.0 12:00 13:30 SIMOPS work pipe in the shed, service TD & blocks. 9/25/2018 9/25/2018 1.75 MIRU MOVE NUND P Remove 1/2" plug in test port of 0.0 0.0 13:30 15:15 landing ring(assisted by welder). Test landing ring with nitrogen to 500 psi for 10 minutes, witnessed by CPAI Rep. Test landing ring on 3S-612 same as above. SIMOPS weld well #'s on cellar boxes 3S-611 and 3S-612; work pipe in the shed; build stand of 5" DP; tag bottom of conductor at 71'& mouse hole at 92'. 9/25/2018 9/25/2018 0.75 MIRU MOVE BOPE P Perform diverter test as follows: knife 0.0 0.0 15:15 16:00 valve open time 6.5 sec; annular closed time 20 sec; initial system pressure 3000 psi; pressure after closure 1950 psi; 200 psi recharge time 7 sec; full recharge time 36 sec; 6 nitrogen bottles average 2217 psi; tested pit level & gas detection alarms; FP on mud pits & trip tank alarms (horn turned off in cab); test witness waived by AOGCC Rep. Jeff Jones. 9/25/2018 9/25/2018 2.50 MIRU MOVE RGRP T Trouble shoot noise in drawworks. 0.0 0.0 16:00 18:30 Hang blocks & remove drilling line from the drum. Align & shim traction motor. Spool drill line on drum. 9/25/2018 9/25/2018 1.50 MIRU MOVE BHAH P Mobilize BHA 1 to the rig floor & make 0.0 0.0 18:30 20:00 up safety valves. 9/25/2018 9/25/2018 0.75 MIRU MOVE SFTY P Hold pre -spud meeting reviewing 0.0 0.0 20:00 20:45 presentation, reviewing section plan & holding table top diverter drill with entire rig team. 9125/2018 925/2018 1.00 MIRU MOVE BHAH P Make up clean out BHA to 70' MD as 0.0 70.0 20:45 21:45 per SLB DD. 9/25/2018 9252018 0.25 MIRU MOVE SEQP P Flood all mud lines & fill conductor / 70.0 70.0 21:45 22:00 surface stack, checking for leaks. Test high pressure mud lines to 3500 psi, good. 9/2512018 9/252018 0.75 MIRU MOVE DRLG P Clean out conductor f/ 70'-119' MD, 70.0 119.0 22:00 22:45 11 9'TVD, 400 gpm, 385 psi, FO 26%, 30 rpm, Tq 1 K, WOB 4K, off bottom 340 psi. 9/2512018 9/252018 0.25 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 119.0 135.0 22:45 23:00 f/ 119'-135' MD, 135' TVD, 450 gpm, 440 psi, FO 29%,40 rpm, Tq 2K, WOB 5K, off bottom 400 psi, PU 48K, SO 47K, AST 0, ART .15, BIT .15, JARS 38.05. 925/2018 9262018 1.00 SURFAC DRILL SHAH P Lay down clean out BHA & pick up 135.0 96.0 23:00 00:00 BHA 2 to 96' MD as per SLB DD. 926/2018 9262018 0.25 SURFAC DRILL SHAH P Continue making up BHA 2 as per 96.0 135.0 00:00 00:15 1 1 ISLBDDf/96'-135'MD. 926/2018 926/20185.75 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 135.0 591.0 00:15 06:00 f/ 135'-591' MD, 591' TVD, 450 gpm, 800 psi, FO 30%, 50 rpm, Tq 3K, WOB 15K, off bottom 620 psi, PU 78K, SO 85K, ROT 82K, Tq 1 K, AST .46, ADT 2.83, BIT 2.98, JARS 39.01. Page 2122 Report Printed: 10126/2018 '- Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Stall Trme End Time Dur (hr) phase Op Cods Activity Cafe Time P-T-X Operation (8Ka) End Depth (flK8) 9/26/2018 9/26/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 591.0 1,145.0 06:00 12:00 f/ 591'-1156' MD, 1145' TVD, 500 gpm, 1100 psi, FO 31%, 50 rpm, Tq 6K, WOB 30K, off bottom 845 psi, PU 95K, SO 98K, ROT 93K, Tq 1 K, AST 2.59, ADT 3.55, BIT 6.53, JARS 42.56. Swap to high line power @ 10:55 hrs. 9/26/2018 9/26/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 1,145.0 1,724.0 12:00 18:00 f/ 1156'-1724' MD, 1653' TVD, 550 gpm, 1360 psi, FO 32%, 50 rpm, Tq 6K, WOB 25K, off bottom 1100 psi, PU 106K, SO 100K, ROT 99K, Tq 2K, AST 1.46, ADT 3.48, BIT 10.01, JARS 46.04. 9/26/2018 9/27/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 1,724.0 2,181.0 18:00 00:00 f/ 1724'-2181' MD, 2050' TVD, 550 gpm, 1230 psi, FO 31 %, 50 rpm, Tq 5K, WOB 12K, off bottom 1080 psi, PU 118K, SO 102K, ROT 109K, Tq 2K, AST 2.13, ADT 3.98, BIT 13.99, JARS 50.02. 9/27/2018 9/27/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 2,181.0 2,575.0 00:00 06:00 U 2181'-2575' MD, 2315' TVD, 550 gpm, 1380 psi, FO 31 %, 50 rpm, Tq 6K, WOB 20K, off bottom 1230 psi, PU 142K, SO 101K, ROT 110K, Tq 4.6K, AST 1.36, ADT 4.0, BIT 17.99, JARS 54.02. 9/27/2018 9/27/2018 6.00 SURFAC DRILL DDRL P Directional drill 13-1/2" surface section 2,575.0 3,034.0 06:00 12:00 f/ 2575-3034' MD, 2574' TVD, 700 gpm, 2100 psi, FO 36%, 50 rpm, Tq 8K, WOB 23K, off bottom 1855 psi, PU 133K, SO 106K, ROT 112K, Tq 4K, AST 1.34, ADT 4.70, BIT 22.69, JARS 58.72. 9/27/2018 9/27/2018 1.00 SURFAC CASING BKRM P BROOH f/ 3034'-2953' MD at 650 3,034.0 2,953.0 12:00 13:00 gpm, 1730 psi, FO 35%, 50 rpm, Tq 6K, PU 130K, SO 114K, pumped bottoms up while pulling the stand. Obtained final survey & torque/drag @ 3034' MD. 9/27/2018 9/27/2018 0.50 SURFAC CASING OWFF P Monitor well, static. 2,953.0 2,953.0 13:00 13:30 9/27/2018 9/27/2018 4.50 SURFAC CASING BKRM P BROOH f/ 2953'-1726' MD at 650 2,953.0 1,726.0 13:30 18:00 gpm, 1385 psi, FO 33%, 50 rpm, Tq 4- 5K, PU 112K, SO 98K. Adjust pulling speed as hole conditions dictated. 9/27/2018 9/27/2018 1.00 SURFAC CASING BKRM P BROOH f/ 1726'-1535' MD at 550 1,726.0 1,535.0 18:00 19:00 gpm, 1040 psi, FO 32%, 50 rpm, Tq 3.5K, PU 107K, SO 98K, pumped bottoms up while pulling the stand. Observed losses starting at 1565' MD. 9/27/2018 9/27/2018 0.25 SURFAC CASING OWFF P Monitor well, fluid level dropped 8" in 1,535.0 1,535.0 19:00 19:15 10 minutes. 9/27/2018 9/27/2018 2.75 SURFAC CASING BKRM P Attempt to pull on elevators, picking 1,535.0 776.0 19:15 22:00 up 10'twice with imediate 40K over pull. BROOH f/ 1535'-776' MD, 500 gpm, 850 psi, FO 31%, 50 rpm, Tq 2.5K, CBU while pulling last stand. 9/27/2018 9/27/2018 0.25 SURFAC CASING OWFF P Monitor well, fluid level dropped 2" in 776.0 776.0 22:00 22:15 10 minutes. 9/27/2018 9/28/2018 1.75 SURFAC CASING BHAH P Rack back 1 stand of HWDP & lay 776.0 150.0 22:15 00:00 down rest of BHA 2 as per SLB DD 776'-150' MD. Page 3/22 Report Printed: 1012512018 Uperations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Steri Tmie End Time our (hr) Phase Op Corte Activity CoEe Time P -T -X OpiinnWn (WEI) End Depth (RKB) 9/28/2018 9/28/2018 2.00 SURFAC CASING BHAH P Continue laying down BHA 2 f/ 150'to 150.0 0.0 00:00 02:00 surface. 9/28/2018 9/28/2018 0.50 SURFAC CASING BHAH P Clear & clean rig floor. 0.0 0.0 02:00 02:30 9/28/2018 9/28/2018 1.00 SURFAC CASING RURD P Rig up to run 10-3/4" casing. Make up 0.0 0.0 02:30 03:30 CRT, bails extensions, & elevators. Verify pipe count on location, 78 joints. 9/2812018 9/28/2018 0.25 SURFAC CASING SFTY P Pre -job safety meeting for running 0.0 0.0 03:30 03:45 casing. 9/28/2018 928/2018 0.75 SURFAC CASING PUTS P Make up 10-3/4" 45.5 #, L-80, Hyd 0.0 115.0 03:45 04:30 563, DL casing shoe track as per detail to 164' MD. Baker Lok connections & torque to 19.41K ftAbs. Install bow spring centralizers as per detail. Pick back up to 115' MD, inside of conductor to check floats. 9/28/2018 9128/2018 0.25 SURFAC CASING CIRC P Check floats pumping 2-8 bpm, good. 115.0 115.0 04:30 04:45 9/28/2018 9/28/2018 3.75 SURFAC CASING PUTS P Run 10-3/4" 45.5 #, L-80, Hyd 553, DL 115.0 1,298.0 04:45 08:30 casing f/ 115'-1298'10D. Install bow spring centralizer on each connection, torque to 23K, fill each joint on the fly & top off every 5 joints. PU 97K, SO 76K. 9128/2018 9/28/2018 9.50 SURFAC CASING PUTB T Work pipe from 1298'-1322' MD, stage 1,298.0 1,322.0 08:30 18:00 up pumps to 9 bpm, vary parameters & bit weight. 9/2812018 9/29/2018 6.00 SURFAC CASING PUTB T Work pipe from 1322'-1324' MD, vary 1,322.0 1,324.0 18:00 00:00 pump parameters & bit weight. Turn string in 1/4 increments intermittently. 92912018 9/292018 6.00 SURFAC CASING PUTS T Work pipe at 1324' MD, 3 bpm, 100 1,324.0 1,324.0 00:00 06:00 psi, FO 13%, PU 101 K, SO 86K. Sit on hard spot & stage up to 9 bpm, 190 psi at 05:00 hm. Tum string in 1/4 increments intermittently. 9/29/2018 9/29/2018 4.00 SURFAC CASING PUTB T Work pipe at 1324' MD, at various 1,324.0 1,324.0 06:00 10:00 1 pump rates, PU 108K, SO 86K. 9/29/2018 9/29/2018 11.50 SURFAC CASING PULL T Pump out of the hole laying down 10- 1,324.0 0.0 10:00 21:30 3/4" casing 3 bpm, 85-50 psi. Heat Baker -Lok connections to break connections. All jewelry recovered. 9/29/2018 9/29/2018 0.50 SURFAC CASING CLEN T Clear & clean rig floor. 0.0 0.0 21:30 22:00 9/292018 9292018 1.00 SURFAC CASING RURD T Change out handling equipment & 0.0 0.0 22:00 23:00 prep for TIH. 9/29/2018 9/30/2018 1.00 SURFAC CASING BHAH T Mobilize BHA 3, clean out assembly, 0.0 19.0 23:00 00:00 to the rig floor. Pick up BHA 3 as per SLB DO to 19' MD. 9/30/2018 9/302018 2.00 SURFAC CASING BHAH T Continue to make up BHA 3, clean out 19.0 373.0 00:00 02:00 assembly H 19'-373' MD as per SLB DD. 9/30/2018 9130/2018 1.00 SURFAC CASING TRIP T TIH f/ 373'-1320' MD, PU 90K, SO 373.0 1,320.0 02:00 03:00 85K, ROT 88K. At 1082'& 1121' it took 15K weight to work by. 9/30/2018 9/30/2018 6.25 SURFAC CASING REAM T Set down at 1320' MD, approximate 1,320.0 3,034.0 03:00 09:15 depth of hole issue w/ running casing. Ream through with 400 gpm, 475 psi, 40 rpm, Tq 3-61K. Continue to ream hole as necessary to TO 3034' MD. Worked through the following depths 1320'-1509'; 1877'-1883'; 1941'-2075'; 'all MD's. Page 4122 ReportPrinted: 10/25/2018 Uperations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sart Depth SWM Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (NCB) End Depth (ftKa) 9/30/2018 9/30/2018 2.75 SURFAC CASING CIRC T Circulate & condition mud f/ 3034'- 3,034.0 2,736.0 09:15 12:00 2736' MD, 795 gpm, 1775 psi, FO 40%, 70 rpm, Tq 4-5K, PU 123K, SO 95K. 9/30/2018 9/30/2018 0.50 SURFAC CASING OWFF T Monitor well, static. 2,736.0 2,736.0 12:00 12:30 9/30/2018 9/30/2018 0.50 SURFAC CASING TRIP T Attempt to TOH from 2736', observing 2,736.0 2,721.0 12:30 13:00 40K overpull at 2721' MD. Run back in to 2830' MD & pull back to 2721' MD w/ 40K over. 9/30/2018 9/30/2018 0.50 SURFAC CASING PMPO T Attempt to pump out of the hole from 2,721.0 2,640.0 13:00 13:30 2721'-2640' MD, 700 gpm, 1480 psi, FO 35%. Pumped out to 2545' MD & encountered pack off. Ran back in to 2640' MD & established circulation. Attempted to pull with out pumps & observe 30K over pull. 9/30/2018 9/30/2018 2.75 SURFAC CASING BKRM T BROOH f/ 2640'-1695' MD, 700 gpm, 2,640.0 1,695.0 13:30 16:15 1250 psi, FO 36%, 130 rpm, Tq 4.5K, PU 112K, SO 88K. 9/30/2018 9/30/2018 0.50 SURFAC CASING PMPO T POOH U 1695'-1414' MD, 550 gpm, 1,695.0 1,4T4-0- 16:15 16:45 1 780 psi, FO 30%. 9/30/2018 9/30/2018 1.25 SURFAC CASING TRIP T TOH f/ 1414'-370' MD. 1,414.0 370.0 16:45 18:00 9/30/2018 9/30/2018 1.50 SURFAC CASING BHAH T Lay down BHA 3 as per SLB DD to 370.0 0.0 18:00 19:30 surface. Observe stabilizers fluid course full packed with clay & bit balled up w/ same. 9/30/2018 9/30/2018 1.00 SURFAC CASING RURD T Rig up to run 10-3/4" casing. 0.0 0.0 19:30 20:30 9/30/2018 9/30/2018 0.25 SURFAC CASING SFTY T PJSM for running 10-3/4" casing with 0.0 0.0 20:30 20:45 all personnel involved. 9/30/2018 9/30/2018 0.75 SURFAC CASING PUTB T Make up 10-3/4" 45.5 #, L-80, Hyd 0.0 160.0 20:45 21:30 563, DL casing shoe track as per detail to 160' MD. Baker Lok connections & torque to 23K ft/lbs. Install bow spring centralizers as per detail. Pick back up to 115' MD, inside of conductor and floats check good. 9/30/2018 10/1/2018 2.50 SURFAC CASING PUTB T Run 10-3/4" 45.5 #, L-80, Hyd 563, DL 160.0 1,095.0 21:30 00:00 casing f/ 160'-1095' MD. Install bow spring centralizer on each connection, torque to 23K, fill each joint on the fly & top off every 5 joints. PU 103K, SO 88K. 10/1/2018 10/1/2018 0.50 SURFAC CASING PUTB T Run 10-3/4" 45.5 #, L-80, Hyd 563, DL 1,095.0 1,298.0 00:00 00:30 casing 9 1095'-1298' MD. Install bow spring centralizer on each connection, torque to 23K, fill each joint on the fly & top off every 5 joints. PU 103K, SO 88K. 10/1/2018 10/1/2018 2.25 SURFAC CASING PUTB P Run 10-3/4" 45.5 #, L-80, Hyd 563, DL 1,298.0 2,116.0 00:30 02:45 casing f/ 1298'-2116' MD. Install bow spring centralizer on each connection, torque to 23K, fill each joint on the fly & top off every 5 joints. PU 160K, SO 90K. 10/1/2018 10/1/2018 9.25 SURFAC CASING PUTB T Set down 20K over at 2116' MD, Work 2,116.0 2,158.0 02:45 12:00 casing from 2116'-2158' MD, PU 160K, SO 90K. Try varying parameters of weight & pump rate. Pumps staged up to 8 bpm, 160 psi. Some over pull up to 21 OK & slack off to 40K. Page 5122 Report Printed: 1 012 512 01 8 Uperations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Ac" Code rime P -T-% Operetlon (WB) End Depth (BHB) 10/1/2018 10/1/2018 8.00 SURFAC CASING PUTB T Continue to work 10-3/4" surface 2,158.0 2,160.0 1200 20:00 casing f/ 2158'-2160' MD, PU 160K, SO 90K. Stage up pump to 11 bpm, 200 psi, FO 30%. Try rotary at 20 rpm, ROT 124K, Tq 18K, set down 10K for 10 rotations. Work in the hole with no rotary. Try rotary again at 10 rpm & work down with IOK WT for 20 turns, Tq 17K, 8 bpm, 150 psi. Then work in the hole with no rotary. Continue to work pipe with no rotary & weight up mud system from 9.6-10.0 ppg. SIMOPS prepare to lay down casing. 10/1/2018 10/2/2018 4.00 SURFAC CASING PMPO T Pump out of the hole laying down 10- 2,160.0 1,743.0 20:00 00:00 3/4" casing it 2160'-1743' MD, 4 bpm, 60 psi, PU 107K, SO 95K. Account for all bowspdng centralizers on connections. 1012/2018 10/212018 7.75 SURFAC CASING PMPO T Pump out of the hole laying down 10- 1,743.0 119.0 0000 07:45 314" casing f/ 1743'-119' MD, 4 bpm, 60 psi, PU 62K, SO 67K. Account for all bowspdng centralizers on connections. Half a strap missing off bowspdngs on joints 10 & 18. 10/212018 10/2/2018 2.00 SURFAC CASING PULL T Lay down 10-3/4" shoe track 119'-0', 119.0 0.0 07:45 09:45 heading up Baker Lok connections to break. 10/2/2018 10/2/2018 1.25 SURFAC CASING RURD T Rig down casing handling equipment 0.0 0.0 09:45 11:00 & blow down top drive. Clear & clean rig floor. 10/2/2018 10/2/2018 0.50 SURFAC CASING SVRG T Service & inspect blocks & top drive. 0.0 0.0 11:00 11:30 1012/2018 10/22018 0.50 SURFAC CASING BHAH T Mobliize BHA 4 to the rig floor. 0.0 0.0 11:30 12:00 1012/2018 1012/2018 3.00 SURFAC CASING BHAH T PJSM, pick up Motor 13-1/2" clean out 0.0 413.0 12:00 15:00 BHA 4, as per SLB DO to 413' MD. Adjust motor bend to 1.15°, PU 71 K, SO 77K. 10/22018 10/22018 0.50 SURFAC CASING TRIP T TIH f/ 413'-886' MD. 413.0 886.0 15:00 15:30 1012/2018 10/2/2018 0.25 SURFAC CASING DHEQ T Shallow hole test MWD @ 517 gpm, 886.0 886.0 15:30 15:45 780 psi, FO 32%, PU 74K, SO 80K. 10/22018 10/2/2018 1.25 SURFAC CASING TRIP T TIH f/ 886'-2153' MD, PU 11 OK, SO 886.0 2,153.0 15:45 17:00 91 K. Tag up at the following depths w/ t OK & wipe once 1373'& 1711' MD; wipe twice at 1867' MD.Tag up at 2153' & work twice with no progress. 10/22018 102/2018 1.00 SURFAC CASING REAM T Pick up to 2116' MD & stage up 2,153.0 2,160.0 17:00 18:00 pumps to 452 gpm, off 800 psi, on 965 psi, FO 29%, 40 rpm, Tq 5-8K, WOB 15K Wash & ream 2116'-2160' MD. Pick back up to 2116' MD & take a survey. 10/2/2018 10/3/2018 6.00 SURFAC DRILL DDRL T Directional drill 13-1/2" surface section 2,160.0 2,549.0 1800 0000 f/ 2160'-2549' MD, 2302' TVD, 541 gpm, 1320 psi, FO 32%,60 rpm, Tq 8K, WOB 20-30K, off bottom 1148 psi, PU 116K, SO 98K, ROT 105K, Tq 4K, AST 2.43, ADT 3.85, BIT 3.85, JARS 62.57. Page 6122 Report Printed: 10125/2018 Uperations Summary (with Timelog Depths) a 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start DOW Stan Time 10/3/2018 End Tons 10/3/2018 Dur(hr) 6.00 Phase SURFAC Op Code DRILL ActivM Code DDRL Time P -T -X T Operation Directional drill 13-1/2" surface section (aKS) 2,549.0 End Depth (aKB) 3,034.0 00:00 06:00 f/ 2549' MD, 2302' TVD - 3,034' MD 2,583 TVD, 594 gpm, 1,492 psi, FO 32%, 60 rpm, Tq 8K, WOB 20-30K, off bottom 1,420 psi, PU 120K, SO t00K, ROT 108K, 6Tq 4K, AST 2.91, ADT 1.83, BIT 4.74, JARS 65.59. 10/3/2018 10/3/2018 2.75 SURFAC CASING CIRC T Circulate while rotating from 3,034' 3,034.0 3,034.0 06:00 08:45 MD - 2,960' MD (a] 700 GPM, 1,765 PSI DPP with 37% F/O. 80 RPM with 4-5K TO. 9,300 STKS pumped. Punp 60 BBLS marker pill and circ same to surface while BKRM OOH 1 stand. 2,960' MD. No indication of maker pill to pits. Pumped a total of 9,966 STKS. 10/3/2018 10/3/2018 0.25 SURFAC CASING OWFF T OWFF. Sialic. 3,034.0 2,967.0 08:45 09:00 10/3/2018 10/3/2018 5.00 SURFAC CASING BKRM T BKRM OOH from 2,967' MD - 1,942' 2,967.0 1,941.0 09:00 14:00 MD. @ 700 GPM 1,560 PSI DPP. 36% F/0, 90 RPM with 5K TO. UP WT=108K, OWN WT=93K. BKRM to 2,018' MD (((RIH with no pump or rotary to 2,203' MD X4) Pump OOH from 2,203' MD -2,018' MD. 700 GPM, 1,600 PSI DPP. Heavy solids over shakers. 10/3/2018 10/3/2018 1.50 SURFAC CASING TRIP T TOH f/ 1734'-013' MD, PU 69K, SO 1,941.0 413.0 14:00 15:30 73K. 10/3/2018 10/3/2018 0.25 SURFAC CASING OWFF T Monitor well, static. 413.0 413.0 15:30 15:45 10/3/2018 10/3/2018 2.75 SURFAC CASING SHAH T Lay down BHA 4 as per SLB DD. 413.0 0.0 15:45 18:30 10/3/2018 10/3/2018 0.50 SURFAC CASING BHAH T Clear & clean rig floor. 0.0 0.0 18:30 19:00 10/3/2018 10/3/2018 1.00 SURFAC CASING RURD T Rig up to run rasing. Install new 0.0 0.0 19:00 20:00 packer cup on CRT. 10/3/2018 10/3/2018 1.00 SURFAC CASING PUTB T Make up 10-3/4" 45.5 #, L-80, Hyd 0.0 170.0 20:00 21:00 563, DL casing shoe track as per detail to 170' MD. Baker Lok connections & torque to 23K ft/lbs. Install bow spring & solid centralizers as per detail. Pick back up to 115' MD, inside of conductor and floats check good. 10/3/2018 10/4/2018 3.00 SURFAC CASING PUTS T Run 10-314" 45.5 #, L-80, Hyd 563, DL 170.0 1,271.0 21:00 00:00 casing f/ 170'-1271' MD. Install solid body centralizers on joints 4-14, bow spring centralizer on each connection after, torque to 24K, fill each joint on the fly & top oft every 5 joints. PU 95K, SO 85K. 10/4/2018 10/4/2018 2.00 SURFAC CASING PUTB T Run 10-3/4" 45.5 #, L-80, Hyd 563, DL 1,271.0 2,160.0 00:00 02:00 casing f/ 1271'-2160' MD. Install bow spring centralizer on each connection, torque to 24K, fill each joint on the fly & top off every 5 joints. 10/4/2018 10/4/2018 2.00 SURFAC CASING PUTB Pun 10-314" 45.5 #, L-80, Hyd 563, DL 2,160.0 2,986.0 02:00 04:00 casing f/ 2160'-2986' MD. Install bow spring centralizer on each connection, torque to 24K, fill each joint on the fly & top oft every 5 joints. PU 186K, SO 90K. Page 7)22 Report Printed: 10125/20181 Uperations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth Stan Time End Time Dur (hp Phase Op Code Activity Code Time P-T-XOperetien (ftKB) End Depth (ftKB) 10/4/2018 10/4/2018 0.50 SURFAC CASING HOSO P Make up hanger & landing joint 2986'- 2,986.0 3,027.0 04:00 04:30 3027' MD, wash down at 2 bpm, 240 psi, PU 160K, SO 105K. 10/412018 10/4/2018 2.50 SURFAC CEMENT CIRC P Stage up pump to 7 bpm, 200 psi, FO 3,027.0 3,027.0 04:30 07:00 23%, PU 165K, SO 111K. 10/4/2018 10/4/2018 0.50 SURFAC CEMENT RURD P Blow down top drive. Rig up cement 3,027.0 3,027.0 07:00 07:30 hose to CRT. 10/4/2018 10/4/2018 3.75 SURFAC CEMENT CIRC P Stage up pump to 7 bpm, ICP 340 psi, 3,027.0 3,027.0 07:30 11:15 FCP 280 psi, FO 23%, PU 172K, SO 116K. SIMOPS PJSM for cementing with SLB & DDI rig crew. 10/4/2018 10/4/2018 6.00 SURFAC CEMENT CMNT P Line up & SLB pump 5 bbis of CW 100. 3,027.0 0.0 11:15 17:15 Pressure test lines to 4000 psi, good. Pump 35 bbls of CW 100 @ 5.4 bpm, 169 psi, FO 18%, PU 169K, SO 116K. Pump 73.1 bbls of 10.5 ppg MP II @ 5 bpm, 100 psi, FO 18%. Drop bottom plug & start batching lead. Pump 816.7 bbls of 11.0 ppg lead cement at 3.4-6 bpm, 60-345 psi, FO 18%-0%, final PU 205K, SO 60K. CW100 at surface with 520 bbls of lead away. Land out casing with 570 bbls of lead away. Loose returns with 580 bbls of lead away. Pick up string to re- establish returns, no success. unable to land back out. Hanger .09' off landing ring. Pump 65.5 bbts of 12.0 ppg tail cement @ 3.4-5 bpm, 166-270 psi, FO 0%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 10.0 ppg spud mud @ 8 bpm, 510-638 psi, FO 0%. Reduce rate to 3 bpm, 330 psi, FO 0%. Bump plug with 2730 strokes, 275.2 bbls pumped. Pressure up to 890 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 17:12 hrs. 10/4/2018 1014/2018 1.75 SURFAC MENT RURD P Rig down & blow down cement line. 0.0 0.0 17:15 19:00 Rig down CRT. Lay down landing joint. Lay down casing handling equipment. 10/4/2018 10/4/2018 0.75 SURFAC WW WH P Make up stack wash tool & flush 0.0 0.0 19:00 19:45 [CEMENT surface stack w/ black water @ 758 gpm. Lay down stack wash tool & blow down TD. SIMOPS clean pits 10/4/2018 10/4/2018 0.50 SURFAC MENT RURD P Pull mouse hole, drain stack, lay down 0.0 0.0 19:45 20:15 riser, & service cement manifold valves. 10/4/2018 10/52018 3.75 SURFAC CEMENT NUND P Nipple down surface annular, diverter 0.0 0.0 20:15 00:00 tee, & speed head adapter. Clean up hanger, cellar box & flush 4" outlet valves. Hanger measured 0.09' off of the landing ring. 10/512018 10/5/2018 2.00 SURFAC CEMENT KURD T Prep cement tap job .75" tubing; thaw, 0.0 0.0 00:00 02:00 dress threads, clear ID, & tally. Rig up Ito run. 10/5/2018 1015/2018 1.25 SURFAC CEMENT PULD T TIH with .75" tubing down annulus & 0.0 368.0 02:00 03:15 1 1 1 tag up on cement at 368.79' MD. 10/5/2018 10/52018 1.25 SURFAC CEMENT PULD T TOH f/ 368'to surface, flushing tubing, 368.0 0.0 03:15 04:30 verify tally & strap. 10/52018 10/512018 3.50 SURFAC CEMENT WAIT T Notify AOGCC Rep Austin McLeod to 0.0 0.0 04:30 08:00 witness cement top job. Mobilize cementers & returns trucks. Page 8/22 Report Printed: 1012512018, Uperations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Srad Depth Steri Time End Torre Dur (m) Phase Op Code Activity Code Time P-T-X Operetlan (ftKB) End Depth (RKB) 10/5/2018 10/5/2018 0.25 SURFAC CEMENT SFTY T PJSM for cement top job with all 0.0 0.0 08:00 08:15 involved personnel. 101512018 10I5I2018 1.75 SURFAC CEMENT PULD T TIH with .75" tubing down annulus & 0.0 234.0 08:15 10:00 tag up on cement at 234.88' MD. 10/5/2018 10/5/2018 5.25 SURFAC CEMENT CMNT T Rig up cement lines to .75" pipe. 234.0 234.0 10:00 15:15 Pump 100 bible of fresh H2O flush at .75 bpm, 330 psi. Batch up & pump 113 bbis of 11 ppg DeepCrete cement at 1 bpm, 620 psi, with cement returns to surface. Neat cement at 40 BBLS away. 10/5/2018 10/5/2018F2.00 SURFAC CEMENT PULD T TOH w/.75" tubing, flushing each & 234.0 0.0 15:15 16:00 laying down to surface. 10/5/2018 10/5/2018 SURFAC CEMENT RURD T Clean & clear cellar from cementing. 0.0 0.0 16:00 16:45 10/5/2018 10/5/2018 SURFAC WHDBOP NUND P Nipple up & orient FMC 5K, Gen 5 0.0 0.0 16:45 18:45 wellhead as per technician. 10/5/2018 10/5/2018 SURFAC WHDBOP PRTS P Test seals between casing & wellhead 0.0 0.0 18:45 19:00 to 1000 psi for 10 minutes, witnessed by CPAI Rep. 10/5/2018 10/6/2018 5.00 SURFAC WHDBOP NUND P Nipple up 11" x 13-5/8" Flange, 2' riser, 0.0 0.0 19:00 00:00 j BOP stack, & RCD body. 10/6/2018 10/6/2018 5.00 SURFAC WHDBOP NUND P Nipple up wellhead & BOPE. Torque 0.0 0.0 00:00 05:00 flanges from wellhead to BOP stack. j Install choke & kill hoses. Rig up MPD equipment & install MPD drip pan. 10/6/2018 10/6/2018 1.00 SURFAC WHOBOP RURD P Rig up to test BOPE. Install 5" test 0.0 0.0 05:00 06:00 joint & plug. Make up valve assemblies. Install lest sub on top drive. Flood all lines with fresh H2O. 10/6/2018 10/6/2018 5.50 SURFAC WHDBOP BOPE P Test witness waived by AOGCC Rep 0.0 0.0 06:00 11:30 Lou Laubenstein. Test w/ 5" & 4" test joints. Perform initial ROPE lest. 250/3500 psi- 5 min each. Following tests done with 5" test joint. Test #1- Annular,CV's 1,12,13,14,4" kill Demco, 5" dart valve. Test #2-Upper 3 1/2" x 6" VBR, CV's 9. 11, mezzanine kill line valve, 5" 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 250/2000 psi. Test #6- CV's 2,5 & 4" dart valve. Test #7- Lower 3 1/2" x 6" VBR. Test #8- Blind rams, CVs 3,4 &6. Following tests done with 4" test joint. Test #9- Annular, upper IBOP & choke line HCR. Test #10- Upper 3 1/2" x 6" VBR & manual choke, lower IBOP,. Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 3000 psi, after functioning 1750 psi, 200 psi recovery in 7 seconds, full in 47 seconds. Nitrogen bottles 6 @ 2208 psi. Tested gas detection system, flow & pit level indicators. 10/6/2018 10/6/2018 1.00 SURFAC WHDBOP MPDA P Install MPD test cap & test to 1200 psi 0.0 0.0 11:30 12:30 for 10 minutes. Line up & test air valve to 1200 psi for 10 minutes. Both tests charted. 10/6/2018 10/6/2018 1.50 SURFAC WHDBOP RURD P Rig down test equipment, test donal & 0.0 0.0 12:30 14:00 plug. Install trip nipple. Install 10" ID wear bushing & RILDS X2. Lay down test joint. Clear & clean rig floor. Page 9122 Report Printed: 10/2512018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth Sten Time End Torre Dur(hr) Phase Op Code Ac4vtty Code Time P -T -x Operation (ttKB) End Depth (RKB) 10/6/2018 10/6/2018 2.00 SURFAC CEMENT BHAH P PJSM, make up BHA 5 9-718" 0.0 302.0 14:00 16:00 intermediate steerable assembly to 302' MD, PU 56K, SO 68K. SIMOPS finish testing MPD system. 10/6/2018 1016/2018 0.50 SURFAC CEMENT TRIP P TIH f/ 302'-11700'1013. 302.0 1,700.0 16:00 16:30 10/6/2018 10/6/2018 0.25 SURFAC CEMENT DHEQ P Shallow hole test MWD at 475 gpm, 1,700.0 1,700.0 16:30 16:45 1 1 740 psi, FO 30 %, good. 10/6/2018 1016/2018 0.75 SURFAC CEMENT TRIP P TIH f/ 1700'-2845' MD, PU 115K, SO 1,700.0 2,845.0 16:45 17:30 93K. 10/6/2018 10/6/2018 1.50 SURFAC CEMENT SLPC P PJSM, cut & slip 58' of drill line. 2,845.0 2,845.0 17:30 19:00 SIMOPS circulate & condition mud at 213 gpm, 218 psi, FO 15%, MW 10+ in & out. 10/6/2018 10/612018 1.00 SURFAC CEMENT PRTS P Rig up to lest. Test 10-3/4" casing 2,845.0 2,845.0 19:00 20:00 pressuring up 3250 psi with 4.1 bbls. Shut in & record pressure for 30 minutes. Final shut in pressure 3200 psi. Bleed back 4.0 bbls. Rig down test equipment. 10/6/2018 10/6/2018 2.75 SURFAC CEMENT DRLG P Tag TOC at 2927' MD, drill out shoe 2,845.0 3,034.0 20:00 22:45 track & rat hole to 3034' MD, 420-500 gpm, 685-961 psi, 40-80 rpm, Tq 6- 7K, WOB 4-1 OK. 10/6/2018 10/6/2018 0.50 SURFAC CEMENT DDRL P Directional drill 9-7/8" intermediate 3,034.0 3,054.0 22:45 23:15 hole section f/ 3034'-3054' MD, 2600' TVD, 500 gpm, 970 psi, FO 31%, 80 rpm, Tq 7K, WOB 8K, OFF BTM 950 psi, PU 114K, SO 96K, ROT 104K, Tq 6K, Max Gas 8, ADT .22, JARS .22 10/6/2018 10/7/2018 0.75 SURFAC CEMENT CIRC P CBU f/ 3054'-2948' MD, 420 gpm, 830 3,054.0 2,948.0 23:15 00:00 psi, 40 rpm, Tq 6K. 1017/2018 10/7/2018 0.75 SURFAC CEMENT FIT P Rig up & perform FIT to an EMW of 2,948.0 2,946.0 00:00 00:45 13.0 ppg, wl 10.Oppg MW at 2580' TVD. Pressure up to 418 psi with 1.01 bbls. Shut in & record pressure for 10 minutes. ISIP 418 psi & FSIP 390 psi. Rig down test equipment. 1017/2018 10/712018 0.50 INTRMI DRILL REAM P Displace well to 9.0 ppg LSND system 2,948.0 3,054.0 00:45 01:15 while reaming back to bottom, f/ 2948'- 3054' MD, 400 gpm, 700 psi, 40 rpm, Tq 6K. 10/7/2018 10/7/2018 4.75 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 3,054.0 3,650.0 01:15 06:00 hole section f/ 3054'-3650' MD, 2800' TVD, 650 gpm, 1088 psi, FO 31%, 120 rpm, Tq 8K, WOB 10K, ECD 10.71, OFF BTM 1050 psi, PU 120K, SO 96K, ROT 106K, Tq 6K, Max Gas 8, ADT 3.31, Bit 3.53, JARS 3.53. Total footage 596'. 10/7/2018 10/7/2018 6.00 INTRM1 DRILL DDRL P Directional drill 9-7/8" intermediate 3,650.0 4,588.0 0600 12:00 hole section f/ 3650'4588' MD, 3045' TVD, 650 gpm, 1406 psi, FO 33%, 150 rpm, Tq 8K, WOB IOK, ECD 11.9, OFF BTM 1400 psi, PU 133K, SO 92K, ROT 109K, Tq 6K, Max Gas 62, ADT 4.31, Bit 7.84, JARS 7.84. Total footage 938'. SCR @ 3704' MD, 2816' TVD, MW 9.1 ppg, 06:20hrs. #1 @ 30 = 160; @ 40 = 180 psi #2 @ 30 = 140; @ 40 = 180 psi Page 110122 Report Printed: 1 012 512 01 8 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Tens End Torre Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (it)(B) End Depth nti(B) 10/7/2018 1017/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 4,588.0 5,314.0 12:00 18:00 hole section f/ 4588'-5314' MD, 3230' TVD, 675 gpm, 1630 psi, FO 33%, 150 rpm, Tq 8K, WOB 10K, ECD 12.21, OFF BTM 1615 psi, PU 141 K, SO 93K, ROT 114K, Tq 6K, Max Gas 67, ADT 4.59, Bit 12.43, JARS 12.43. Total footage 726'. 10!7/2018 10/8/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 5,314.0 5,909.0 18:00 00:00 hole section f/ 5314'-5909' MD, 3382' TVD, 675 gpm, 1664 psi, FO 33%, 150 rpm, Tq 8K, WOB IOK, ECD 11.9, OFF BTM 1630 psi, PU 148K, SO 94K, ROT 114K, Tq 6K, Max Gas 23, ADT 4.71, Bit 17.14, JARS 17.14. Total footage 595'. 10/6/2018 10/8/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-718" intermediate 5,909.0 6,590.0 00:00 06:00 hole section f/ 5909'-6590' MD, 3552' TVD, 675 gpm, 1950 psi, FO 33%, 150 rpm, Tq 8K, WOB 10K, ECD 11.73, OFF BTM 1936 psi, PU 146K, SO 97K, ROT 114K, Tq 7K, Max Gas 35, ADT 4.92, Bit 22.06, JARS 22.06. Total footage 681'. 10/8/2018 10/8/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 6,590.0 7,303.0 06:00 12:00 hole section f/ 6590'-7303' MD, 3733' TVD, 675 gpm, 2063 psi, FO 35%, 150 rpm, Tq 8K, WOB 8K, ECD 11.53, OFF BTM 2061 psi, PU 152K, SO 106K, ROT 124K, Tq 7K, Max Gas 51, ADT 4.82, Bit 26.88, JARS 26.88. Total footage 713'. SCR @ 6640' MD, 3566' TVD, MW 9.5 ppg, 06:20hrs. #1 @ 30 = 260; @ 40 = 320 psi #2 @ 30 = 260; @ 40 = 320 psi 10/8/2018 10/8/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 7,303.0 7,964.0 12:00 18:00 hole section f/ 7303'-7964' MD, 3901' TVD, 675 gpm, 2073 psi, FO 35%, 150 rpm, Tq 1OK, WOB 12K, ECD 11.43, OFF BTM 1973 psi, PU 168K, SO 105K, ROT 125K, Tq 8K, Max Gas 57, ADT 4.41, Bit 31.29, JARS 31.29. Total footage 661'. 10/8/2018 10/9/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-718" intermediate 7,964.0 8,727.0 1800 0000 hole section f/ 7964-8727' MD, 4097' TVD, 675 gpm, 2262 psi, FO 35%, 150 rpm, Tq 1OK, WOB 15K, ECD 11.91, OFF BTM 2250 psi, PU 165K, SO 107K, ROT 126K, Tq 8K, Max Gas 40, ADT 4.99, Bit 36.28, JARS 36.28. Total footage 763'. SCR @ 8342' MD, 3998' TVD, MW 9.5 ppg, 20:30hrs. #1 @ 30 = 280; @ 40 = 310 psi #2 @ 30 = 280; @ 40 = 330 psi 10/9/2018 10/9/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 8.727.0 9,476.0 00:00 06:00 hole section f/ 8727'-9476' MD, 4289' TVD, 675 gpm, 1953 psi, FO 35%, 150 rpm, Tq 10K, WOB 10K, ECD 11.21, OFF BTM 1966 psi, PU 175K, SO 112K, ROT 133K, Tq 8K, Max Gas 88, ADT 4.54, Bit 40.82, JARS 40.82. Total footage 749'. Page 11122 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time Dur (hr) Phase Dp Code Activity Code Tim P -T -X Opereeon Sten Depth (aKa) End Depth (MB) 10/9/2018 10/9/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 9,476.0 10,283.0 06:00 12:00 hole section f/ 9476'-10283' MD, 4495' TVD, 675 gpm, 2334 psi, FO 33%, 150 rpm, Tq 1OK, WOB 1 OK, ECD 11.55, OFF BTM 2316 psi, PU 180K, SO 112K, ROT 133K, Tq 11K, Max Gas 138, ADT 4.76, Bit 45.58, JARS 45.58. Total footage 807'. SCR @ 9573' MD, 4313' TVD, MW 9.6 ppg, 06:30hrs. #1 @ 30 = 280; @ 40 = 340 psi #2 @ 30 = 280; @ 40 = 340 psi 10/9/2018 10/9/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 10,283.0 10,960.0 12:00 18:00 hole section f/ 10283'-10960' MD, 4668' TVD, 675 gpm, 2343 psi, FO 33%,150 rpm, Tq 12K, WOB 12K, ECD 11.5, OFF BTM 2310 psi, PU 201 K, SO 113K, ROT 141 K, Tq 12K, Max Gas 75, ADT 4.29, Bit 49.87, JARS 49.87. Total footage 677'. 10/9/2018 10/10/2018 6.00 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 10,960.0 11,848.0 18:00 00:00 hole section f/ 10960'-11848' MD, 4896' TVD, 675 gpm, 2275 psi, FO 33%.150 rpm, Tq 13K, WOB 12K, ECD 11.34, OFF BTM 2190 psi, PU 200K, SO 119K, ROT 144K, Tq 11 K, Max Gas 93, ADT 5.25, Bit 55.12, JARS 55.12. Total footage 888'. SCR @ 11183' MD, 4725' TVD, MW 9.7 ppg. 19:13hrs. #1 @ 30 = 320; @40 = 360 psi #2 @ 30 = 300; @ 40 = 380 psi 10/10/2018 10/10/2018 5.50 INTRMI DRILL DDRL P Directional drill 9-7/8" intermediate 11,848.0 12,620.0 00:00 05:30 hole section f/ 11848'-12620' MD, 5091' TVD, 675 gpm, 2200 psi, FO 33%,150 rpm, Tq 13K, WOB 10K, ECD 11.34, OFF BTM 2190 psi, PU 214K, SO 118K, ROT 146K, Tq 11K, Max Gas 93, ADT 4.28, Bit 59.4, JARS 59.4. Total footage 772'. SCR @ 12600' MD, 5099' TVD, MW 9.5 ppg, 07:00hrs. #1 @ 30 = 340; @ 40 = 380 psi #2@ 30 = 320; @ 40 = 380 psi 10/10/2018 10/10/2018 1.50 INTRMI CASING CIRC P Pump hi -vis sweep surface to surface. 12,620.0 12,620.0 05:30 07:00 675 gpm, 2200 psi, 32% FO, 150 rpm, 11 K tq, PU 212K, SO 120K, ROT 149K. Pump total of 11,500 stks. 50% increase in cuttings on sweep returns. 10/10/2018 10/10/2018 0.50 INTRMI CASING OWFF P Lay down single It OF. Monitor well. 12,620.0 12,600.0 07:00 07:30 Static. 10/10/2018 10/10/2018 4.50 INTRMI CASING BKRM P BROOH from 12600' MD to 11000' 12,600.0 11,000.0 07:30 12:00 MD. 675 gpm, 1875 psi, 32% FO, 150 rpm, 12K tq, ECD 10.77, PU while reaming 136K. 10/10/2018 10/10/2018 6.00 INTRMI CASING BKRM P BROOH from 11000' MD to 8821' MD. 11,000.0 8,821.0 12:00 18:00 675 gpm, 1608 psi, 32% FO, 150 rpm, 11.51K tq, ECD 10.52, PU while reaming 126K. 10/10/2018 16/11/2618 6.00 INTRMI CASING BKRM P BROOH from 8821' MD to 6100' MD. 8,821.0 6,100.0 18:00 00:00 675 gpm, 1300 psi, 32% FO, 150 rpm, 8K tq, ECD 10.34, PU while reaming 110K. Page 12122 ReportPrinted: 10/25/2018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten oepm Stmt Tune End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operafion (WS) End Depen (flKe) 10/11/2018 10111/2018 6.50 INTRM1 CASING BKRM P BROOH from 6100' MD to 2949' MD. 6,100.0 2,949.0 00:00 06:30 675 gpm, 1000 psi, 32% FO, 150 rpm, 6K tq, ECD 10.34, PU while reaming 100K. 10/11/2018 10111/2018 1.75 INTRM1 CASING CIRC P Circulate to clean rasing. Rotate and 2,949.0 2,949.0 06:30 08:15 reciprocate from 2949' MD to 2853' MD. Stage pump rate up to 770 gpm. ICP=1000 psi FCP=1293 psi. 33% FO, 80 rpm, 3K tq, PU 115K SO 96K Rot 99K. 18,701 total strokes pumped. 10/11/2018 10/11/2018 0.75 INTRM1 CASING OWFF P Monitor well. Slight flow -diminishing to 2,949.0 2,949.0 08:15 09:00 static. Sim-ops/Service rig. 10/11/2018 10/11/2018 1.00 INTRMI CASING CIRC P Circulate to clean casing. Rotate and 2,949.0 2,570.0 09:00 10:00 reciprocate from 2949' MD to 2570' MD. Stage pump rate up to 750 gpm. 1234 psi. 34% FO, 60 rpm, 3K tq, PU 98K. 5,802 total strokes pumped. 10/1112018 10/11/2018 0.25 INTRM1 CASING OWFF P Monitor well. Slight flow -diminishing to 2,570.0 2,570.0 10:00 10:15 static. 10/1112018 10/11/2018 2.75 INTRM1 CASING PULD P Pump dry job. POOH laying down DP 2,570.0 300.0 10:15 13:00 from 2570' MD to 300' MD. 10/11/2018 10/11/2018 1.50 INTRM1 CASING SHAH P PJSM-Lay down BHA as per DD. 300.0 0.0 13:00 14:30 10/11/2018 10/11/2018 1.00 INTRM1 CASING WWWH P Make up stack washer. Flush BOPE. 0.0 0.0 14:30 15:30 900 gpm, 105 psi, 35% FO, .5K tq. Sim -ops/ Clean and clear rig floor. 10111/2018 10/11/2018 0.50 INTRM1 CASING RURD P Rig down stack washer. Pull wear ring. 0.0 0.0 15:30 16:00 10/11/2018 10/11/2018 1.50 INTRM1 CASING BOPE P Change out upper VBR's to 7 5/8" 0.0 0.0 16:00 17:30 solid body rams. 10111/2018 10/1112018 1.50 INTRM1 CASING BOPE P Install test plug with 7 5/8" test joint. 0.0 0.0 17:30 19:00 Test annular preventer and upper 7 5/8" pipe rams to 250/3500 psi for 5 mins each. Pull test plug and rig down test equipment. 10/11/2018 10/11/2018 1.00 INTRM1 CASING [TURD P PJSM-Rig up casing running 0.0 0.0 19:00 20:00 equipment. Rig up CRT, casing tongs, fill up line and spiders. Make up FSV onto X -O. 10/11/2018 10/1212018 4.00 INTRM1 CASING PUTS P Make up shoe track. Check floats. 0.0 2,976.0 20:00 00:00 Continue RIH picking up 7 5/8", L-80, 29.7# H563, doped/dopeless casing to 2976' MD. Torque dopeless connections to 12,400 ft/lbs and doped connections to 10,300 ft1lbs 10/12/2018 10/12/2018 0.50 INTRMI CASING CIRC P CBU at 2976' MD. Stage pump rate up 2,976.0 2,976.0 00:00 00:30 to 6 bpm, 135 psi. Reciprocate from 2976' MD to 2936' MD. PU 110K SO 107K 10/12/2016 10/12/2018 2.75 INTRM1 CASING PUTB P Continue RIH picking up 7 5/8", L-80, 2,976.0 4,894.0 00:30 03:15 29.7# H563, doped/dopeless casing from 2976' MD to 4894' MD. 10/12/2018 10/12/2018 0.50 INTRMI CASING OWFF P Monitor well. Slight flow diminishing to 4,894.0 4,894.0 03:15 03:45 static 10/12/2018 10/12/2018 0.75 INTRM1 CASING PUTB P Continue RIH picking up 7 5/8", L-80, 4,894.0 5,305.0 03:45 04:30 29.7# H563, dopedldopeless casing from 4894' MD to 5305' MD. 10/12/2018 10/12/2018 0.25 INTRM1 CASING OWFF P Monitor well. Slight flow diminishing to 5,305.0 5,305.0 04:30 04:45 1 1 Istatic 1011212018 10/12/2018 1.25 INTRM1 CASING PUTB P Continue RIH picking up 7 5/8", L-80, 5,305.0 5,907.0 04:45 06:00 1 I 29.7# H563, dopedldopeless casing I from 5305' MD to 5907' MD. Page 13/22 Report Printed: 10125/2018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (no Phase Op Code Activity Cafe Time P -T -X Operation Stan Depth (flKB) End Depth(tlKB) 10/12/2018 10/12/2018 1.00 INTRMI CASING CIRC P Circulate at 5907' MD. Stage pump 5,907.0 5,907.0 06:00 07:00 rate up to 6 bpm, 242 psi. 20% FO, Reciprocate from 5907' MD to 5880' MD. PU 138K SO 114K 10/12/2018 10/12/2018 4.00 INTRMI CASING PUTB P Continue RIH picking up 7 5/8", L-80, 5,907.0 8,550.0 07:00 11:00 29.7# H563, doped/dopeless casing from 5907' MD to 8550' MD. 10/12/2018 10112/2018 1.50 INTRMI CASING CIRC P Circulate at 8550' MD. Stage pump 8,550.0 8,550.0 11:00 12:30 rate up to 6 bpm, 300 psi. 18% FO, Reciprocate from 8550' MD to 8520' MD. PU 170K SO 107K 10/12/2018 10/12/2018 3.50 INTRMI CASING PUTB P Continue RIH picking up 7 5/8", L-80, 8,550.0 10,925.0 12:30 16:00 29.7# H563, doped/dopeless casing from 8550' MD to 10925' MD. 10/12/2018 10/12/2018 1.00 INTRMI CASING CIRC P Circulate at 10925' MD. Stage pump 10,925.0 10,925.0 16:00 17:00 rate up to 6 bpm, 433 psi. 18% FO, Reciprocate from 10925' MD to 10905' MD. PU 200K SO 107K 10/12/2018 10/12/2018 2.75 INTRMI CASING PUTB P Continue RIH picking up 7 5/8", L-80, 10,925.0 12,570.0 17:00 19:45 29.7# H563, doped/dopeless Casing from 10925' MD to 12570' MD. 10/1212018 10/12/2018 0.50 INTRM1 CASING HOSO P Make up hanger and landing joint. 12,570.0 12,611.0 19:45 20:15 Wash down from 12570' MD to 12611' MD. Land hanger on depth. 10/12/2018 10/13/2018 3.75 INTRMI CEMENT CIRC P Circulate and condition mud for 12,611.0 12,611.0 20:15 00:00 cement job. Stage pump rate up to 7 bpm. Reciprocate from 12611' MD to 12591' MD. 10/13/2018 10/13/2018 1.25 INTRMI CEMENT CIRC P Circulate and condition mud for 12,611.0 12,611.0 00:00 01:15 cement job. 7 bpm, 660 psi, 23% FO PU 220k SO 109K. Reciprocate from 12611' MD to 12591' MD. 10/13/2018 10/13/2016 3.75 INTRMI CEMENT CMNT P Pump 5 bbis water. Test lines to 4000 12,611.0 12,611.0 01:15 05:00 psi. Drop lower bottom plug. Batch up and pump 76.3 bbis of 12.5 ppg MucIPush II, 4 bpm, 380 psi, 15% FO. Drop upper bottom plug. Batch up and pump 270.7 bbls 15.8 ppg Class G Cement, 5.2 bpm, 215 psi, 22% FO. Drop lop plug. Pump 10 bbis water. Swap to dg and displace with 9.4 ppg -SND. Land Casing at 3350 stks with 83K hookload. Reduce rate to 3 bpm at 4600 stks. Initial rate at 7 bpm, 180 psi, 24% FO. Final rale 3 bpm, 1080 psi, 12% FO. Bump plug at 5629 stks. Pressure up to 1500 psi and hold for 5 mins. CIP at 04:59 hrs. 10/13/2018 10/13/2018 1.25 INTRMI CEMENT PRTS P Test 7 5/8" casing to 3500 psi for 30 12,611.0 12,611.0 05:00 06:15 mins. 71 stks to pressure up. 7.1 bbis bled back. Check floats. Good. 10/13/2018 10/13/2018 0.75 INTRMI CEMENT RURD P Rig down casing running equipment.. 12,611.0 0.0 06:15 07:00 Lay down landing joint. 10/13/2018 10/13/2018 0.75 INTRMI CEMENT WWWH P Make up stack flushing tool. Flush 0.0 0.0 07:00 07:45 BOPE w/900 gpm, 120 psi, 26% FO, 40 rpm. Rig down flushing tool and blow down TD. Sim-ops/Lay down casing running equipment from rig floor Page 14122 ReportPrinted: 10125/2018 - Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity COde Time P-T-X Operadw (BKB) End Depth(flKB) 10/13/2018 10/13/2018 1.25 INTRMI CEMENT W WSP P Install 10 3/4" X 7 5/8" packoff. Test 0.0 0.0 0745 09:00 packoff to 5000 psi/10 mins. Good. Test witnessed by CPAI CoMan. Rig down packoff running tool. 10/13/2018 10/13/2018 2.00 INTRMI CEMENT BOPE P Change out upper 7 5/8" solid body 0.0 0.0 09:00 11:00 rams to 3 1/2" x 6" VBR's. Sim- ops/Change out saver sub to XT-39. 10/13/2018 10/13/2018 1.00 INTRMI WHDBOP RURD P Rig up to test BOPE. Set test plug. 0.0 0.0 11:00 12:00 Flood lines with fresh water. Perform body test. 10/13/2018 10/13/2018 6.00 INTRMI WHDBOP BOPE P Perform bi-weekly BOPE test. Test 0.0 0.0 12:00 18:00 witnessed by AOGCC Rep Jeff Jones. Test w/ 4 1/2" & 4" test joints. Perform bi-weekly BOPE test. 250/3500 psi- 5 min each. Following tests done with 4 1/2" test joint. Test #1- AnnuIar,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. Test #7- Lower 3 1/2" x 6" VBR. Test #8- Blind rams, CV's 3,4 W. Following tests done with 4" test joint. Test #9-Annular, lower IBOP (failed), lower IBOP & choke line HCR. Test #10- Upper 3 1/2" x 6" VBR & manual choke, Test #11- Lower 3 1/2" x 6" VBR. Accumulator draw down initial system pressure 2950 psi, after functioning 1800 psi, 200 psi recovery in 8 seconds, full in 55 seconds. Nitrogen bottles 6 @ 1992 psi. Tested gas detection system, flow & pit level indicators. 10/13/2018 10/13/2018 0.50 INTRMI WHDBOP RURD P Pull test plug. Install 9 1/16" ID 0.0 0.0 18:00 18:30 wearring. 10/13/2018 10/13/2018 2.00 INTRMI CEMENT FRZP P Freeze protect 7 5/8" X 10 3/4" 0.0 0.0 18:30 20:30 annulus. Rig up and test lines to 3000 psi. Pump 100 bbls water at 3 bpm. Initial injection pressure=800 psi. Final injection pressure=600 psi. Pump 80 bbls diesel at 2 bpm. IIP-= 625 psi, FIP=800 psi. Final static OA pressure =350 psi. Sim-ops/Change out upper IBOP. 10/13/2018 10/13/2018 0.50 INTRMI CEMENT SVRG P Service top drive. Continue to change 0.0 0.0 20:30 21:00 out upper IBOP. 10/13/2018 10/13/2018 0.50 INTRM1 WHDBOP BOPE T Test upper IBOP to 250/3500 psi for 5 0.0 0.0 21:00 21:30 mins each. 10/13/2018 10/13/2018 1.75 INTRMI CEMENT SHAH P PJSM-Make up BHA #6 as per DO to 0.0 375.0 21:30 23:15 375' MD. PU 54K SO 60K. 10/13/2018 10/14/2018 0.75 INTRMI CEMENT PULD P RIH picking up 4" DP from 375' MD to 375.0 1,321.0 23:15 00:00 1321' MD. PU 62K SO 65K 10/14/2018 10/14/2018 1.25 INTRMI CEMENT PULD P RIH picking up 4" DP from 1321' MD 1,321.0 2,270.0 00:00 01:15 to 2270' MD. PU 82K SO 79K 10/14/2018 10/14/2018 0.50 INTRMI CEMENT DHE O P Break circulation. Shallow hole test 2,270.0 2,270.0 01:15 01:45 MWD. 250 gpm, 1230 psi, 20% FO. Good test. Blow down TD. 10/14/2018 10/14/2018 0.75 INTRMI CEMENT PULD P RIH picking up 4" DP from 2270' MD 2,270.0 2,940.0 01:45 02:30 to 2940' MD. Page 15122 Report Printed: 10125/2018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depm Start Time End Time Dw (hr) Phase op Code Acdvity Code Time P -T -X Operation (fiKB) End Depm (WS) 10/14/2018 10/1412018 1.75 INTRMI CEMENT QEVL P Send downlink and RIH picking up 4" 2,940.0 3,630.0 02:30 04:15 DP performing free ring of casing. Log from 2940' MD to 3630' MD at 900 fph. PU 94K SO 77K. 10/14/2018 10/14/2018 2.50 INTRMI CEMENT PULD P RIH picking up 4" DP from 3630' MD 3,630.0 5,600.0 04:15 06:45 to 5600' MD. PU 109K SO 79K 10/14/2018 10/14/2018 9.00 INTRMI CEMENT QEVL P RIH picking up 4" DP from 5600' MD 5,600.0 10,445.0 06:45 15:45 to 10466' MD. MAD pass at 900 fph for SonicScope cement evaluation. Build doubles in mouse hole. Fill pipe every 20 aids. PU 162K . Lost all down weight at 10466' MD. Pick up to 10445' MD. 10114/2018 10/14/2018 5.50 INTRMI CEMENT QEVL P Wash and ream from 10445' MD to 10,445.0 12,343.0 15:45 21:15 12343' MD. 220 gpm, 1600 psi, 17% FO, 40 rpm, 12K tq, PU 205K SO 52K Rot 120K .centinueing with MAD pass for cement evaluation... 10/14/2018 10/14/2018 0.50 INTRMI CEMENT MPDA P Pull trip nipple. Install RCD. 12,343.0 12,343.0 21:15 21:45 10/14/2018 10114/2018 1.50 INTRMI CEMENT MPDA P Calibrate MPD system. Practice ramp 12,343.0 12,343.0 21:45 23:15 up and down procedure. 10/14/2018 10/1412018 0.50 INTRMI CEMENT MPDA P Pull RCD. Rack back stand with 12,343.0 12,251.0 23:15 23:45 bearing. Install trip nipple. 10/14/2018 10/15/2018 0.25 INTRMI CEMENT QEVL P Wash and ream from 12251' MD to 12,251.0 12,343.0 23:45 00:00 12343' MD. 235 gpm, 1900 psi, 15% FO, 40 rpm, 15K tq, continueing with MAD pass for cement evaluation. 10/15/2018 10/1512018 1.00 INTRMI CEMENT QEVL P Wash and ream from 12343' MD to 12,343.0 12,511.0 00:00 01:00 12511' MD. 233 gpm, 1890 psi, 17% FO, 40 rpm, 15K tq, continueing with MAD pass for cement evaluation. Tag cement plugs at 12511' MD. 10/15/2018 10/15/2018 4.75 INTRMI CEMENT DRLG P Drill out shoe track and clean out rat 12,511.0 12,620.0 01:00 05:45 hole from 12511' MD to 12620' MD. Drill plugs and float collar with 120- 180 gpm, 40-80 rpm, 5-18 WOB. Drill cement with 220 gpm, 1780 psi, 15% FO, 80 rpm, 15K tq, 5K WOB. Drill float shoe with 225 gpm, 40-140 rpm, 2-18K WOB. 10/15/2018 10/15/2018 4.00 INTRMI CEMENT DDRL P Directional drill 6 3/4" production hole 12,620.0 12,640.0 05:45 09:45 section from 12620' MD to 12640' MD, 5107' TVD, 250 gpm, 2170 psi, FO 18%,60 rpm, Tq 15K, WOB 18K, ECD 10.93, PU 21 OK, SO 68K, ROT 111 K, ADT 1.42, Bit 1.42, JARS 86.7. 10/15/2018 10/15/2018 1.50 INTRMI CEMENT CIRC P CBU. Rotate and reciprocate from 12,640.0 12,640.0 09:45 11:15 12640' MD to 12618' MD. 275 gpm, 2461 psi, 18% FO, 60 rpm, 15K tq, ECD 10.69, MW in/out 9.5 ppg. PU 21 OK SO 68K 10/15/2018 10/1512018 1.75 INTRMI CEMENT LOT P Stand back DP to 12533' MD. Rig up 12,640.0 12,533.0 11:15 13:00 for LOT. Purge air from kill line. Perform LOT. Leak off occurred at 16.0 ppg EMW, 1740 psi, 9.5 ppg MW, 51 01'TVD. Rig down test equipment. 10/1512018 10/15/2018 1.00 PROD1 DRILL MPDA P Pull trip nipple and install RCD. 12,533.0 12,533.0 13:00 14:00 10/1512018 10/15/2018 0.75 PROD1 DRILL WASH P Unable to RIH on elevators. Kelly up 12,533.0 12,640.0 14:00 14:45 and wash down from 12533' MD to 12640' MD. 2 bpm, 620 psi. 11% FO. SO wt with pump on 50K. Page 16122 Report Printed: 10125/2018 Operations Summary (with Timelog Depths) jhdink 3S-611 NW Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log StartTime End Time Our (hr) Phase Op Code Ao tiny Code Time P -T -X Operation Start Depth (NKB) End Depen (flKB) 10/15/2018 10/15/2018 3.25 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 12,640.0 12,911.0 14:45 18:00 section from 12640' to 12911' MD, 5174' TVD, 260 gpm, 2054 psi, FO 16%, 130 rpm, Tq 11 K, WOB 7-10K, ECD 10.87, OFF BTM 1991 psi, PU 180K, SO 74K, ROT 114K, Tq 1 OK, Max Gas 20, ADT 2.26, Bit 3.68, Jars 88.96. Total footage 271'.Displace to 9.5 ppg KlaShield mud on the fly. SCR @ 12814' MD, 5150' TVD, MW 9.5ppg, 16:40hrs. #1 @ 20 = 820/330; @ 30 = 970/230 psi #2 @ 20 = 820/320; @ 30 = 940/230 psi 10/15/2018 10/16/2018 6.00 PROW DRILL DDRL P Directional drill 6 3/4" production hole 12,911.0 13,667.0 18:00 00:00 section from 12911'to 13667' MD, 5280' TVD, 260 gpm, 2180 psi, FO 15%, 130 rpm, Tq 12.4K, WOB 9K, ECD 11.21, OFF BTM 2175 psi, PU 186K, SO 68K, ROT 117K, Tq 9K, Max Gas 40, ADT 4.84, Bit 8.52, Jars 93.8. Total footage 756'. 10/16/2018 10/16/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 13,667.0 14,333.0 00:00 06:00 section from 13667' MD to 14333' MD, 5261' TVD, 260 gpm, 2300 psi, FO 14%,140 rpm, Tq 13K, WOB 8K, ECD 11.36, OFF BTM 2290 psi, PU 183K, SO 58K, ROT 112K, Tq 11 K, Max Gas 25, ADT 3.96, Bit 12.48, Jars 97.76. Total footage 666'. 10/16/2018 10/16/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 14,333.0 15,100.0 06:00 1200 section from 14333' MD to 15100' MD, 5244' TVD, 260 gpm, 2337 psi, FO 14%, 140 rpm, Tq 14K, WOB 10K, ECD 11.49, OFF BTM 2300 psi, PU 180K, SO NA, ROT 112K, Tq 11K, Max Gas 254, ADT 4.27, Bit 16.75, Jars 102.03. Total footage 767'. SCR @ 14427' MD, 5257' TVD, MW 9.6ppg, 06:40hrs. #1 @ 20 = 630; @ 30 = 860 psi #2 @ 20 = 620; @ 30 = 840 psi 10/16/2018 10/162018 6.00 PROD1 DRILL DDRL P Directional drill 314" production hole 15,100.0 15,252.0 12:00 18:00 section from 15100' MD to 15252' MD, 5236' TVD, 260 gpm, 2210 psi, FO 15%, 100-140 rpm, Tq 11 K, WOB 7K, ECD 10.94, OFF BTM 2204 psi, PU 170K, SO NA, ROT 111 K, Tq 10K, Max Gas 74, ADT 4.35, Bit 21.10, Jars 106.38. Total footage 152'. Page 17/22 Report Printed: 10/25/2018 . Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sort Time End Time W, (hr) Phase Op Code Activity Code Time P -T -X OpeiVkm son Depth (ftKB) End Depm(flKB) 10/16/2018 10/17/2018 6.00 PRODi DRILL DDRL P Directional drill 6 3/4" production hole 15,252.0 15,855.0 18:00 00:00 section from 15252' MD to 15855' MD, 5239' TVD, 260 gpm, 2280 psi, FO 14%, 140 rpm, Tq 13.5K, WOB 9K, ECD 11.16, OFF BTM 2270 psi, PU 182K, SO 60K, ROT 115K, Tq 8.5K, Max Gas 30, ADT 4.35, Bit 25.45, Jars 110.73. Total footage 603'. SCR @ 15475' MD, 5227' TVD, MW 9.4+ ppg, 20:35hrs. #1 @20=560;(0330=810 psi #2 @ 20 = 550; @ 30 = 800 psi 10117/2018 10/17/2018 6.00 PRODi DRILL DDRL P Directional drill 6 3/4" production hole 15,855.0 16,549.0 00:00 06:00 section from 15855' MD to 16549' MD, 5256' TVD, 260 gpm, 2480 psi, FO 15%,140 rpm, Tq 13.8K, WOB 10K, ECD 11.41, OFF BTM 2465 psi, PU 178K, SO 54K, ROT 116K, Tq 9K, Max Gas 32, ADT 4.16, Bit 29.61, Jars 114.89. Total footage 694'. 10/17/2018 10/17/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 16,549.0 17,281.0 06:00 12:00 section from 16549' MD to 17281' MD, 5241' TVD, 260 gpm, 2608 psi, FO 14%, 140 rpm, Tq 14.5K, WOB 9K, ECD 11.59, OFF BTM 2600 psi, PU 185K, SO NA, ROT 122K, Tq 12.5K, Max Gas 79, ADT 4.43, Bit 33.95, Jars 119.23. Total footage 732'. SCR @ 16589' MD, 5255' TVD, MW 9.5 ppg, 06:30 hrs. #1 @ 20 = 625; @ 30 = 890 psi #2 @ 20 = 625; @ 30 = 850 psi 10/17/2018 10/17/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 17,281.0 17,973.0 12:00 18:00 section from 17281' MD to 17973' MD, 5230' TVD, 260 gpm, 2852 psi, FO 14%,140 rpm, Tq 14.5K, WOB 6-12K, ECD 11.85, OFF BTM 2840 psi, PU 195K, SO NA, ROT 129K, Tq 13K, Max Gas 82, ADT 4.13, Bit 38.08, Jars 123.36. Total footage 692'. 10/17/2018 10/18/2018 6.00 PROD1 DRILL DDRL P Directional drill 6 3/4" production hole 17,973.0 18,685.0 18:00 00:00 section from 17973' MD to 18685' MD, 5221' TVD, 260 gpm, 2770 psi, FO 15%.140 rpm, Tq 13.6K, WOB 8K, ECD 11.92, OFF BTM 2760 psi, PU 196K, SO NA, ROT 132K, Tq 8K, Max Gas 25, ADT 4.57, Bit 42.65, Jars 127.93. Total footage 712'. SCR @ 18065' MD, 5259' TVD, MW 9.6 ppg. 18:40 hrs. #1 @ 20 = 760; @ 30 = 1100 psi 42 @ 20 = 750; @ 30 = 1050 psi 10/18/2018 10/18/2018 2.00 PROD1 CASING CIRC P CBU. Rotate and reciprocate from 18,685.0 18,609.0 00:00 02:00 18684' MD to 18609' MD. 260 gpm, 2900 psi, 15% FO, 140 rpm, 10.5 tq, 11.57 ECD, MW in 9.6 ppg, PU 198K Rot 135K 10/18/2018 10/18/2018 0.75 PROD1 CASING OWFF P Monitor well. Static. 18,609.0 18,609.0 02:00 02:45 Page 18122 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stet Time ErgTi� our(hr) Phase Op Codo Activity Code Time P -T -X Operabon Start Depth (flKB) End Depth(f1KB) 10/18/2018 10/18/2018 8.00 PROD1 CASING BKRM P BROOH from 18609' MD to 15858' 18,609.0 15,858.0 02:45 10:45 MD standing back HWDP. 260 gpm, 2402 psi, 28% FO, 140 rpm, 10K tq, ECD 11.19, Hold 360 psi back pressure during connections. 10/18/2018 10/18/2018 9.25 PROD1 CASING BKRM P BROOH from 15858' MD to 12536' 15,858.0 12,536.0 10:45 20:00 MD laying down DP via mousehole.. 260 gpm, 2217 psi, 28% FO, 140 rpm, 9.6K tq, ECD 11.09, Hold 360 psi back pressure during connections. 10/18/2018 10/18/2018 1.50 PROD1 CASING CIRC P CBU X2. Rotate and reciprocate from 12,536.0 12,530.0 20:00 21:30 12530' MD to 12445' MD. 260 gpm, 2216 psi, 30% FO, 120 rpm, 6K tq, ECD 11.04, PU 143K SO 103K, Rot 113K 10/18/2018 10/1812016 0.75 PROD1 CASING OWFF P Monitor well. Slight flow diminishing to 12,530.0 12,530.0 21:30 22:15 static. 10/18/2018 10/18/2018 0.50 PROD1 CASING CIRC P Downlink to MWD. Pump 20 bbl dry 12,530.0 12,530.0 22:15 22:45 job. Blow down TD. Drop 1.89" rabbit on stand #128 10/18/2018 10/19/2018 1.25 PROD1 CASING SMPD P Strip OOH from 12530' MD to 10920' 12,530.0 10,920.0 22:45 00:00 MD. Maintain 275 psi back pressure while pulling and 60 psi while in the slips. PU 129K SO 94K 10/19/2018 10/19/2018 6.00 PROW CASING SMPD P Strip OOH from 10920' MD to 557' 10,920.0 557.0 00:00 06:00 MD. Maintain 275 psi back pressure while pulling and 60 psi while in the slips. PU 129K SO 94K 1011912018 10/19/2018 0.50 PRODt CASING OWFF P Monitor well. Static. PJSM on pulling 557.0 597-0- 06:00 06:30 RCD. 10/19/2018 10/19/2018 0.50 PROD1 CASING MPDA P Pull RCD and install trip nipple, 557.0 557.0 06:30 07:00 10/19/2018 10/19/2018 0.25 PROD1 CASING TRIP P POOH from 557' MD to 375' MD. 557.0 375.0 07:00 07:15 Recover rabbit in lop of HWDP. 10/19/2018 10/19/2018 1.50 PROD1 CASING SHAH P Lay down BHA as per DD. 375.0 0.0 07:15 08:45 10/19/2018 10/19/2018 0.50 COMPZN CASING W W WH P Make up stack washing tool. Flush 0.0 0.0 08:45 09:15 BOPE. 850 gpm, 160 psi. Blow dawn TD, Function lest BOPE on 4" DP. Sim -ops/Clean and clear rig floor. 10/1912018 10/19/2018 1.50 COMPZN CASING RURD P Rig up GBR casing equipment. 0.0 0.0 09:15 10:45 10/19/2018 10119/2018 1.25 COMPZN CASING PUTB P Pick up and RIH with 4 1/2" 12.6# L- 0.0 198.0 10:45 12:00 80 Hyd 563 liner shoe track to 198' MD. Baker lock connections. Pump through shoe at 2 bpm, 30 psi, 9% FO. 10/19/2018 10119/2018 9.00 COMPZN CASING PUTB P Pick up and RIH with 4 1/2" 12.6# L- 198.0 6,142.0 12:00 21:00 80 Hyd 563 liner from 198' MD to 6142' MD as per running order. Torque connections to 4500 ft/lbs. 10/19/2018 10/19/2018 1.50 COMPZN CASING OTHR P Pick up and make up liner top 6,142.0 6,211.0 21:00 22:30 packer/liner hanger/SBE assembly and RIH on a stand of DP to 6308' MD 10/19/2018 10/19/2018 0.75 COMPZN CASING CIRC P Circulate one liner volume. 3 bpm, 365 6,308.0 6,308.0 22:30 23:15 psi, 11 % FO, PU 88K SO 79K Rot 84K. 15 rpm= 2K tq 10 rpm=1.8K tq. 10/19/2018 10/20/2018 0.75 COMPZN CASING RUNL P RIH with liner on DP from 6308' MD to 6,308.0 7,257.0 23:15 00:00 7257' MD. Monitor displacement via TT Fill on the fly and top off every 10 stands. PU 91K SO 81K Page 19122 ReportPrinted: 10/25/2018 Operations Summary (with Timelog Depths) 3S-611 9 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time our (h0 Phase Op Code Activity Cotle Time P -T -X Operation Stars Depth ptKB) End Depth (MB) 10/20/2018 10/20/2018 6.00 COMPZN CASING RUNL P RIH with liner on DP from 7257' MD to 7,257.0 14,951.0 00:00 06:00 14951' MD. Monitor displacement via TT. Fill on the fly and top off every 10 stands. PU 147K SO 89K. At 9536' MD 10 rpm=3K tq 15 rpm=3.4K tq. At 12575' MD 10 rpm=5.1 K tq 15 rpm=5.2K tq. PU 138K SO 99K Rot 07K. 10/20/2018 10/20/2018 3.25 COMPZN CASING RUNL P RIH with liner on DP from 14951' MD 14,951.0 18,656.0 06:00 09:15 to 18656' MD. Monitor displacement via TT. Fill on the fly and top off every 10 stands. PU 198K SO 98K. 10/20/2018 10/20/2018 0.50 COMPZN CASING HOSO P Pick up 2 singles DP. RIH and tag 18,656.0 18,672.0 09:15 09:45 bottom at 18691.85' MD. Pick up and set shoe on depth at 18672' MD. TOL at 12467.86 10/20/2018 10/20/2018 2.25 COMPZN CASING C I Rc P Pump 30 bbls hi -vis 10 ppg NaCl brine 18,672.0 18,672.0 09:45 12:00 spacer Drop 1.25" WIV ball. Pump 10 bbls 10 ppg hi -vis NaCl spacer. Pump 94 bbls 9.5 ppg NaCL brine staging pump up to 3 bpm, 975 psi, 12% FO. Pump 40 bbls 9.5 ppg hi -vis NaCL brine spacer followed by 62.2 bbls 9.5 ppg NaCl brine. 3 bpm, 925 psi, 12% FO, At 1800 stks reduce pump rate to 2 bpm, 690 psi, 10% FO. Ball on seat at 2047 stks. 10/20/2018 10/20/2018 0.50 COMPZN CASING PACK P Pressure up to 2500 psi and hold for 2 18,672.0 18,672.0 12:00 1230 minutes SO to block weight to confirm liner hanger is set. Increase pressure to 4000 psi and hold for 2 minutes. Bleed pressure off. Pick up to free weight of 173K plus 5'. Rotate at 15 rpm, 5K tq 143 Rot wt. Slack off 40K to 103K hook load to set packer. PU to free weight of 173K to release running tool 10/20/2018 0.50 COMPZN CASING PRTS P Line up and test Liner Top Packer to 18,672.0 12,463.0 110/20/2018 12:30 13:00 3900 psi/10 mins. Good test. Pumped 5.8 bbls and bled back 5.6 bbls. Lay down 2 singles DP 10/20/2018 10/20/2018 2.00 COMPZN WELLPR DISP P Displace well bore to 9.5 ppg NaCL 12,463.0 12,434.0 13:00 1500 brine. Stage pump up to 10 bpm, 3400 psi, 18% FO. Reciprocate from 12434' MD to 12371' MD. Pump total 4874 stks. PU 168K SO120K 10/20/2018 10/20/2018 0.75 COMPZN WELLPR CRIH P At 12430' MD pump 30 bbl's 9.5 ppg 12,434.0 12,430.0 15:00 15:45 inhibited NaCL brine at 5 bpm, 850 psi. Chase with 114 bbls 9.5 ppg NaCl brine at 9 bpm, 2625 psi, 24% FO. Total of 1433 stks pumped. Blow down TD 10/20/2018 10/20/2018 0.25 COMPZN WELLPR PULD P Lay down 4 jts DP from 12430' MD to 12,430.0 12,309.0 15:45 16:00 12309' MD. PU 170K. 10/20/2018 10/20/2018 1.75 COMPZN WELLPR SLPC P PJSM-Slip and cut 102' drilling line. 12,309.0 12,309.0 16:00 1745 Sim-ops/Monitor well. Static. 10/20/2018 10/20/2018 0.50 COMPZN WELLPR SVRG P Service top drive, traveling blocks and 12,309.0 12,309.0 17:45 1815 crown. 10/20/2018 10/20/2018 0.50 COMPZN WELLPR SFTY P Clear derrick of ice. 12,309.0 12,309.0 18:15 18:45 Page 20122 ReportPrinted: 10/25/2018 C., Operations Summary (with Timelog Depths) t� 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hd Phase Op Code Activity Code Tme P -T -X Operation Start Depth (flKB) End Depth (flKB) 10/20/2018 10/2112018 5.25 COMPZN WELLPR PULD P POOH laying down DP from 12309' 12,309.0 6,704.0 18:45 00:00 MD to 6704' MD. Lay down 92 its 4" HWDP and 85 its 4" DP. PU 109K SO 87K 10/21/2018 10/21/2018 1.75 COMPZN WELLPR PULD P POOH laying down DP from 6704' MD 6,704.0 5,185.0 00:00 01:45 to 5185' MD. Lay down 50 jts 4" DP. PU 98K SO 87K 10/21/2018 10/21/2018 1.00 COMPZN WELLPR TRIP P RlH with standsfromderrick from 5,185.0 7,720.0 01:45 0245 5185' MD to 7720' MD. PU 118K SO 84K 10/21/2018 10/21/2018 7.50 COMPZN WELLPR PULD P POOH laying down DP from 7720' MD 7,720.0 56.0 02:45 10:15 to 56' MD. Lay down 247 its 4" DP. 10/21/2018 10/21/2018 0.75 COMPZN RPCOMP SHAH P Lay down liner running tool as per 56.0 0.0 10:15 11:00 Baker Rep. Clean and clear rig Floor. 1 018 10/21/2018 0.25 COMPZN RPCOMP KURD P- Rig up and pull wear ring. 0.0 0.0 11:00 11:15 10/21/2018 10/21/2018 0.75 COMPZN RPCOMP WWWH P Make up stack washing tool. Flush 0.0 0.0 11:15 12:00 BOPE. 835 gpm, Rig down and blow down TD. 10/21/2018 10/21/2018 225 COMPZN RPCOMP RURD P Rig up TEC wire spooler and GBR 0.0 0.0 12:00 14:15 casing equipment. Sim-ops/Test and chart liner top packer to 3000 psi/30 mins. 6.1 bbls to pressure up. Bleed off 6.1 bbls. 1 018 10/21/2018 0.50 COMPZN RPCOMP SVRG P Service top drive and traveling blocks. 0.0 0.0 4:15 14:15 14:45 10/21/2018 10/21/2018 0.50 COMPZN RPCOMP KURD P Verify pipe count in pipe shed. 0.0 0.0 14:45 15:15 Position tubing jewelry in order. 10/21/2018 10/21/2018 0.25 COMPZN RPCOMP SFTY P PJSM on running upper completion. 0.0 0.0 15:15 15:30 10/21/2018 10/21/2018 2.50 COMPZN RPCOMP PUTB P Pick up and RIH with 4 1/2", 12.6#, L- 0.0 1,143.0 15:30 18:00 80 Hydril 563 upper completion as per running order to 1143' MD. Torque connections to 4500 ft/lbs using Jet Lube Seal Guard dope. PU 59K SO 53K. 10/21/2018 10/22/2018 6.00 COMPZN RPCOMP PUTB P Continue to pick up and RIH with 4 1,143.0 7,132.0 18:00 0000 1/2", 12.6#, L-80 Hydril 563 upper completion as per running order from 1143' MD to 7132' MD. Torque connections to 4500 fUlbs using Jet Lube Seal Guard dope. PU 96K SO 73K. 10/22/2018 10/22/2018 6.50 COMPZN RPCOMP PUTB P Continue to pick up and RIH with 4 7,132.0 12,476.0 00:00 06:30 112", 12.6#, L-80 Hydril 563 upper completion as per running order from 7132' MD' Tag and shear locator pins with 15K set down weight, fully located at 12476.61' MD. Torque connections to 4500 Wiles using Jet Lube Seal Guard dope. PU 134K SO 75K. 10/22/2018 10/22/2018 2.00 COMPZN RPCOMP HOSO P Lay down 3 joints #326, #325,#324. 12,476.0 12,474.9 06:30 08:30 Pick up joint #329. Make up hanger and landing joint. Terminate and test TEC wire to 5000 psi. Rinse out BOPE. RIH and land hanger. Spaced out 1.76' from fully located. WLEG at 12474.85' MD. 10/22/2018 10/22/2018 0.75 COMPZN RPCOMP THGR P Verify that hanger is landed through IA 12,474.9 12,474.9 08:30 09:15 valve. RILDS. Rig up bail extensions and test equipment. Purge air from lines. Page 21122 Report Printed: 10/25/2018 Operations Summary (with Timelog Depths) 3S-611 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stara Time End Tlme Dur (hr) Phase Op Code ACGvity Code Time P-T-X Operation Start Depth (flKa) End Depth(flKS) 10/22/2018 10/22/2018 2.00 COMPZN RPCOMP PRTS P Test tubing to 4000 psi/30 mins on 12,474.9 0.0 09:15 11:15 chart. Good test. Bleed tubing to 2500 psi. Test lA to 3900 pis/30 mins on chart. Good test. Bleed IA and then tubing to 0 psi. Pressure up on IA and observe SOV shear at 2350 psi. Pump additional 5 bbls at 1.5 bpm, 308 psi, 12% FO. Monitor well for 10 mins. Static. Rig down bail extensions and lay down landing joint. 10/22/2018 10/22/2018 0.75 COMPZN WHDBOP MPSP P Dry rod in HP BPV Test BPV from 0.0 0.5- 11:15 12:00 below to 2500 psi/10 mins on chart. Good test. 10/22/2018 10/22/2018 0.50COMPZN WHDBOP OTHR P Blow down and rig down lines. Pull 0.0 12:00 12:30 mousehole. 10/22/2018 10/22/2018 2.00 COMPZN WHDBOP MPDA P Nipple down Katch Kan and RCD. Sim 0.0 0.0 12:30 14:30 -ops/Change out saver sub to 4 1/2 IF. 10/22/2018 10/22/2018 4.25 COMPZN WHDBOP NUND P ND BOPE, spacer spool and DSA. 0.0 0.0 14:30 1845 Sim-ops/Commence rigging down interconnects. 10/22/2018 10/22/2018 2.75 COMPZN WHDBOP NUND P Clean wellhead and cellar. NU adapter 0.0 0.0 18:45 21:30 flange. Terminate and test TEC wire. Final DHG readings=2476 psi and 129° F. Test adapter void to 250/5000 psi for 15 mins. Test witnessed by CPAI rep. 10/2212018 10/22/2018 2.00 COMPZN WHDBOP TU ND P NU 10,000 psi Cameron 4-1/16" frac 0.0 0.0 21:30 23:30 tree and wing valves. 10/22/2018 10/23/2018 0.50 COMPZN WHDBOP PRTS 5 Rig up test equipment and purge air 0.0 0.0 23:30 0000 from tree. 10/23/2018 10/23/2018 1.25 COMPZN WHDBOP PRTS P Test Cameron 4-1/6" 10k tree to 250 0.0 0.0 00:00 01:15 psi low and 10k high f/ 5 minutes. Test witnessed by CPAI Rep Bob Finkbiner. Rig down testing equipment. 10/23/2018 10/23/2018 1.00 COMPZN WHDBOP VPSP P Pull test dart and BPV. 0.0 0.0 01:15 02:15 10/23/2018 10/23/2018 2.25 COMPZN WHDBOP FRZP P Rig up and freeze ptotect w/ little Red 0.0 0.0 02:15 0430 Services pumping. Pressure test lines to 2000 psi. Pump diesel at 2 bpm down the IA.. ICP = 500 psi, final circ pressure 850 psi. Connect IA 8 tubing together. Allow to "U" tube f/ 1 hr to move diesel to the tubing. Rig down and blow down lines. 10/23/2018 10/23/2018 0.75 COMPZN WHDBOP MPSP P PuII tree cap and set BPV wl dryrod. 0.0 0.0 04:30 0515 Sim ops: Pull out pipeshed preparing to move to 3S-612. 10/23/2018 10/23/2018 0.75 DEMOB MOVE KURD P Install flanges and jewlery on tree. 0.0 0.0 05:15 0600 Securing well. Final pressures : OA = 0 psi, IA= 0 psi, TBG= 0 psi. SIM Ops: Pull motor complex away, preparing to move rig to 3S-612. Rig released @ 0600 hrs 10/23/2018 to move to 3S-612. Page 22/22 Report Printed: 10/25/2016 NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-611 3S-611 NAD 27 ConocoPhillips Definitive Survey Report 09 November, 2018 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Yes INo I have checked to the best of my ability that the following data 1s correct: Surface Coordinates Decimation & Convergence GRS Survey Corrections Survey Tool Codes Brandon Temrt-l�le Digitally signed by Brandon Temple SLB DE: N Date: 2018.11.0912:03:24-69'00' Client Representative: Dale: 11/9118 -. ConocoPhillips Design 35-611 ConocoPhillips From Audit Notes: Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 35-611 Project: Kuparuk River Unit TVD Reference: 35-011 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 35-611 actual @ 63.64usft (Doyon 142) Well: 3SS71 North Reference: True Wellbore: 3SS71 Survey Calculation Method: Minimum Curvature Design: 35-611 Database: OAKEDMPI Project Kuparuk River Unit, North Slope Alaska, United States 2,460.24 Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) MWD+IFR-AK-CAZ-SC Using Well Reference Point Map Zone: Alaska Zone 04 7,144.86 3S-611 Srvy 7-SLB_MWD-INC-ONLY_F Using geodetic scale factor Well 35-611 7,239.05 12,555.51 3S-611 Srvy 8-SLB_MWD+GMAG(3S- Well Position +N/S 0.00 usft Northing: 5,993,909.97 usft Latitude: 70° 23'40.172 N 12,573.4335-611 Srvy 9-SLB_MWD-INC-ONLY_F +E/ -W 0.00 usft Easting: 476,247.39 usft Longitude: 150° 11'35.733 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 24.50 usft MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/15/2D1811:4: 0.78 Wellbore 35-611 0.31 256.53 Magnetics Model Name Sample Data Declination Dip Angle Field Strength 5,993,909.53 476,247.10 (1) (1) (n) 253.63 BGGM2018 9/30/2018 16.62 80.88 57,433 Design 35-611 From Audit Notes: (usft) Version: 1.0 Phase: ACTUAL Tle On Depth: 2,113.08 Vertical Section: Depth From (TVD) +WS +Ef-W Direction 2.113.08 3S-611 PBl Srvy 2- SLB _W MD+GMAG (uslt) (usft) (usft) (I 2,319.6835-611 Srvy 3- SLB_MWD+GMAG(3S- 39.14 0.00. 0.00 307.86 Survey Program Data From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 85.07 1,013.24 35-611 Srvy 1 - SLB_GWD70 (35-611 PB GYD-GC-SS Gyrodata gyro single shots 9/26/2018 826- 1,072.31 2.113.08 3S-611 PBl Srvy 2- SLB _W MD+GMAG MWD+IFR-AK-CAZSC MWD -IFR AK CAZ SCC 9/26/2018 8:36:- 2,116.00 2,319.6835-611 Srvy 3- SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 10/2/20181230 2,415.86 2,415.86 3SS71 Srvy 4-SLB_MWD-INC-ONLY_F MWD-INC_ONLY MWD -INC -ONLY -FILLER 10/3/2018 1232 2,460.24 2,958.6435-611 Srvy 5- SLB _MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/3/20181234 3,057.82 7,050.2935-611 Srvy 6-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/6/201812:38 7,144.86 7,144.86 3S-611 Srvy 7-SLB_MWD-INC-ONLY_F MWD -INC _ONLY MWD-INC_ONLY_FILLER 10/8/2018 11:16: 7,239.05 12,555.51 3S-611 Srvy 8-SLB_MWD+GMAG(3S- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/8/201811:19: 12,573.43 12,573.4335-611 Srvy 9-SLB_MWD-INC-ONLY_F MWD-INC_ONLY MWD4NC_ONLY _FILLER 10/15/201811:4' 12,667.90 18,629.78 3S-611 Srvy 10-SLB_MWD+GMAG(3S MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/15/2D1811:4: Survey Map Map Vertical AND Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Eluding DLS Section (usft) 111 (1 (usft) (usft) (usft) (usft) (ft) (N) (•/100') (ft) Survey Tool Name 39.14 0.00 0.00 39.14 -24.50 0.00 0.00 5,993,909.97 476,247.39 0.00 0.00 UNDEFINED 85.07 0.36 191.66 85.07 21.43 4.14 -0.03 5,993,909.83 476,247.36 0.78 -0.06 GYD-GCSS(1) 164.91 0.31 256.53 164.91 101.27 4).44 -0.29 5,993,909.53 476,247.10 0.45 4).04 GYD-GCSS(1) 253.63 0.48 221.37 263.63 199.99 -0.81 -0.82 5,993,909.16 476,246.56 0.29 0.15 GYD-GGSS(1) 357.74 1.31 302.20 357.73 299.09 -0.53 -1.99 5,993,909.44 476,245.39 1.40 1.25 GYD-GC-SS(1) 451.25 2.71 311.12 451.18 387.54 1.49 4.56 5,993,911.48 476,242.83 1.53 4.52 GYD-GC-SS(1) 11A92018 11:46:52AM Page 2 COMPASS 5000.14 Build 85D survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 35511 Project Kuparuk River Unit TVD Reference: 35511 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 35-611 actual @ 63.64usft (Doyon 142) Well: 35511 North Reference: True Wellbore: 35511 Survey Calculation Method: Minimum Curvature Design: 35511 Database: OAKEDMPI survey 11/92018 11:46:52AM Page 3 COMPASS 5000.14 Build 85D Map Map Verdian MD Inc AN TVD TVDSS -N/-S +E/4N Northing Eutlng DLS Section Will 0 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 544.17 2.67 312.66 543.99 480.35 440 -7.61 5,993,914.40 476,239.59 0.09 8.87 GYD.GC-66(1) 636.47 4.52 328.10 636.11 572.47 8.95 -11.31 5,993,918.95 476,236.11 2.24 14.42 GYD-GCSS(1) 729.51 5.95 327.82 728.76 665.12 16.14 -15.82 5,993,926.16 476,231.62 1.54 22.40 GYD-OCSS(1) 823.64 7.76 318.73 822.22 758.58 25.05 -22.61 5,993,935.09 476,224.86 2.24 33.22 GYD-GC-S$(1) 918.31 9.39 317.14 915.83 852.19 35.51 52.08 5,993,945.58 476,215.43 1.74 47.12 GYD-GC-SS(1) 1,013.24 12.65 314.99 1,008.99 945.35 48.54 44.70 5,993,958.65 476,202.85 3.46 65.09 GYD-GCSS(1) 1,072.31 15.94 311.79 1,066.23 1,002.59 58.52 55.33 5,993,968.66 476,192.25 5.73 79.60 MWD+IFR-AK-CAZSC(2) 1,103.38 18.18 311.13 1,095.93 1,032.29 64.56 52.16 5,993,974.72 476,185.44 7.24 88.70 MWD+IFR-AK-CAZSC(2) 1,166.95 19.76 310.71 1,156.04 1,09240 78.09 -77.78 5,993,988.30 476,169.87 2.49 109.33 MWD+IFR-AK-CAZ-SC(2) 1,202.20 19.81 310.46 1,189.21 1,125.57 85.85 56.84 5,993,996.09 476,160.83 0.28 121.25 MWD+IFR-AK-CAZSC(2) 1,261.51 21.34 310.27 1,244.74 1,181.10 99.35 -102.72 5,994,009.64 476,145.00 2.58 142.07 MWD+IFR-AK-CAZSC(2) 1,356.39 24.57 313.50 1,332.10 1,26846 124.09 -130.21 5,99,034.46 476,117.59 3.65 178.96 MWD+IFR-AK-CAZ-SC(2) 1,451.02 29.22 316.28 1,416.47 1,352.83 154.35 -16046 5,994,064.81 476,087.44 5.09 221.41 MWD+IFR-AK-C0iZ-SC (2) 1,545.36 31.00 318.24 1498.08 1,434.44 189.12 -192.56 5,994,099.68 476,055.45 2.16 268.09 MWD+IFR-AK-CAZSC(2) 1,640.26 29.85 320.09 1,579.91 1,516.27 225.46 -223.99 5,994,136.12 476,024.14 1.55 315.22 MWDAFR-AK-CAZ-SC(2) 1,735.82 29.12 315.42 1,663.11 1,599.47 260.27 -255.57 5,994,171.03 475,992.67 2.52 361.52 MWD+IFR-AK-CAZSC(2) 1,829.96 29.22 316.17 1,745.31 1,681.67 293.16 -287.56 5,994,204.02 475,960.79 0.40 406.96 MWD+IFR-AK-CAZSC(2) 1,924.16 30.43 316.10 1,827.03 1,763.39 326.94 520.03 5,994,237.89 475,928.43 1.29 453.32 1AWD+IFR-AK-CAZ-SC(2) 2,019.28 34.51 313.19 1,907.27 1,843.63 362.76 356.39 5,994,273.82 475,892.19 4.59 504.01 MWD+IFR-AK-CAZ-SC(2) 2,113.08 37.22 311.62 1,983.28 1,919.64 399.79 596.98 5,994,310.98 475,851.72 3.05 558.79 MWD+IFR-AK-CAZSC(2) 2,116.00 37.33 311.60 1,985.60 1,921.96 400.97 598.31 5,994,312.16 475,850.40 339 560.55 MWD+IFR-AK-CAZSC(3) 2,131.80 37.43 312.84 1,998.16 1,934.52 407.41 105.41 5,994,318.63 475,803.32 4.81 570.12 MWD+IFR-AK-CAZ-SC (3) 2,195.84 37.87 313.04 2,048.86 1,985.22 434.06 434.05 5,994,345.36 475,814.77 0.71 609.08 MWD+IFR-AK-CAZSC(3) 2,268.94 41.34 311.86 2,105.17 2,041.53 465.49 468.44 5,994,376.90 475,780.48 4.86 655.53 MWD+IFR-AK-CAZSC(3) 2,319.68 44.60 311.84 2,142.29 2,078.65 488.57 494.19 5,994,400.05 475,754.80 6.42 690.02 MWD+IFR-AK-CAZ-SC(3) 2,415.86 45.53 311.84 2,210.23 2,146.59 533.98 544.92 5,99,445.63 475,704.22 0.97 757.94 MWD -INC _ONLY (4) 2,460.24 47.49 311.84 2,240.77 2,177.13 555.46 568.91 5,994,467.18 475,680.31 4.42 790.06 MWD+IFR-AK-W-SC(5) 2,509.34 48.14 311.78 2,273.74 2,210.10 579.71 596.02 5,99,491.52 475,653.27 1.33 82636 Mv10+IFR-AK-CAZ-SC(5) 2,605.24 49.14 310.88 2,337.11 2,273.47 627.24 550.08 5,994,539.21 475,599.38 1.26 898.20 MWD+IFR-AK-CAZSC(5) 2,699.61 50.39 310.42 2,398.06 2,334.42 674.17 -704.73 5,99,566.31 475,54487 1.38 970.16 MWD+IFR-AK-GAZSC(5) 2,794.24 54.46 308.57 2,455.76 2,392.12 721.83 -762.61 5,994,634.15 475,487.15 4.57 1,045.11 MWD+IFR-AK-CAZ-SC (5) 2,888.64 57.49 308.63 2,508.58 2,444.94 770.64 523.75 5,99,683.15 475,426.17 3.21 1,123.33 MWD+IFR-AK-CAZ-SC (5) 2,958.64 58.94 308.15 2,545.45 2481.81 807.59 570.39 5,994,720.24 475,379.66 2.15 1,182.83 MWD+IFR-AK-CAZSC(5) 3,057.82 W.76 309.00 2,595.26 2,531.62 861.07 -937.43 5,99,773.92 475,312.79 1.98 1,268.58 MWD+IFR-AK-CAZSC(6) 3,074.28 61.46 309.22 2,603.21 2,539.57 870.16 -948.61 5,994,783.05 475,301.64 4.41 1,282.99 MWDAFR-AK-CAZ-SC(6) 3121.87 62.75 309.46 2,625.48 2,561.84 896.82 -981.14 5,994,809.61 475,269.20 2.75 1,325.03 MWD+IFR-AK-GAZSC(6) 3,167.64 64.13 309.31 2,645.94 2,582.30 922.80 -1,012.78 5,994,835.89 475,237.64 3.03 1,365.96 MWD+IFR-AK-CAZ-SC(6) 3,216.70 65.57 309.11 2,666.79 2,603.15 950.87 -1,047.19 5,994,864.07 475,203.33 Z% 1,410.35 MWD+IFR-AK-CAZ-SC(6) 3,264.24 66.57 308.95 2,686.07 2,622.43 978.23 -1,080.95 5,99,891.53 475,169.66 2.13 1,453.80 MWD+IFR-AK-CAZSC(6) 3,357.43 69.05 309.33 2,721.27 2,657+63 1,032.70 -1,147.87 5,994,946.20 475,102.93 2.69 1,540.06 MWD+IFR-AK-CAZ-SC (6) 11/92018 11:46:52AM Page 3 COMPASS 5000.14 Build 85D Survey ConocoPhillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 3S-611 Project: Kupamk River Unit TVD Reference: 3S-611 actual @ 63.64usft (Dayan 142) Sib: Kuparuk 3S Pad MD Reference: 35-611 actual @ 63.64usft (Doyon 142) Well: 35-611 North Reference: True Wellbore: 3SS11 Survey Calculation Method: Minimum Curvature Design: 35-611 Database: OAKEDMPI Survey 111912018 11:46.52AM Page 4 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azi TVD TVDSB i11143 +E/ -W Northing Easting DLS Section (usft) 0 r) (usft) (usft) (usft) (usft) (m ((U (•1100') (1t) Survey Tool Name 3,452.71 73.05 309.26 2,752.20 2,686.56 1,089.76 -1,217.59 5,995,003.48 475,033.39 4.20 1,630.12 MWD+IFR-AK-CAZSC(6) 3,547.70 75.10 309.33 2,778.26 2,714.62 1,147.60 -1,288.28 5,995,061.55 474,962.89 2.16 1,721.44 MM+IFR-AK-CAZ-SC(6) 3,642.20 75.30 307.18 2,802.41 2,738.77 1,204.17 -1,360.02 5,995,118.33 474,891.34 2.21 1,812.79 MWD+IFR-AK-CAZ-SC(6) 3,736.49 75.08 305.74 2,826.51 2,762.87 1,25634 -1,433.33 5,995,172.73 474,818.20 1.49 1,903.92 MWD+IFR-AK-CAZSC(6) 3,830.89 75.02 305.80 2,850.86 2,787.22 1,311.65 -1,507.33 5,995,226.27 474,744.38 0.09 1,995.06 MWD+IFR-AK-CAZSC(6) 3,925.89 75.18 305.66 2,875.28 2,811.64 1,365.23 -1,581.82 5,995,280.09 474,670.07 0.22 2,08676 MWD+IFR-AK-CAZ-SC (6) 4,020.09 75.11 306.81 2,899.44 2,835.80 1,419.08 -1,655.30 5,9%,334.16 474,595.77 1.18 2,177.82 MWD+IFR-AK-CAZSC(6) 4,114.63 75.17 307.80 2,923.69 2,860.05 1,474.46 -1,727.98 5,995,389.77 474,524.27 1.01 2,269.19 MWD+IFR-AK-CAZSC(6) 4,209.37 75.17 309.05 2,947.94 2,884.30 1,531.38 -1,799.73 5,995,446.91 474,452.71 1.28 2,360.77 MWD+IFR-AK-CAZSC(6) 4,304.28 75.01 309.68 2,972.36 2,906.72 1,589.55 -1,870.64 5,995,505.30 474,382.00 0.66 2,452.45 MWD+IFR-AK-CAZ-SC(6) 4,399.12 75.18 309.35 2,996.75 2,933.11 1,647.86 -1,941.34 5,995,563.63 474,311.49 0.38 2,544.06 MWD+IFR-AK-CAZSC (6) 4,493.33 75.11 308.64 3,020.91 2,957.27 1,705.16 -2,012.11 5,995,621.35 474,240.91 0.73 2,635.11 MWD+IFR-AK-CAZSC(6) 4,587.71 75.05 307.29 3,045.21 2,981.57 1,761.26 -2,089.01 5,995,677.67 474,169.19 1.38 2,726.30 MWD+IFR-AK-CAZSC(6) 4,682.48 75.08 306.20 3,069.63 3,005.99 1,816.04 -2,15238 5,9%,732.68 474,0%.00 1.11 2,817.85 MWD+IFR-AK-CAZ-SC(6) 4,775.62 75.20 305.915 3,093.57 3,029.93 1,869.18 -2,230.30 5,995,786.04 474,023.26 0.28 2,908.03 MWD+IFR-AK-CAZSC(6) 4,870.95 75.29 305.40 3,117.80 3,054.16 1,922.83 -2,305.02 5,995,839.92 473,948.72 0.58 2,999.95 MWD+IFR-AK-CAZSC(6) 4,966.74 75.29 304.96 3,142.12 3,078.48 1,976.21 -2,350.75 5,995,893.54 473,873.17 0.44 3,092.50 MWD+IFR-AK-CAZ-SC(6) 5,061.57 75.31 304.29 3,166.19 3,102.55 2,028.33 -2,456.23 5,995,945.89 473,797.86 0.68 3,184.08 MWD+IFR-AK-CAZ-SC(6) 5,156.29 75.54 306.98 3,190.03 3,126.39 2,081.73 -2,530.73 5,995,999.53 473,723.54 2.76 3,275.67 MW0+11FR-AK-W-SC(6) 5,251.67 75.19 308.76 3,214.13 3,150.49 2,138.38 -2,603.57 5,9%,056.40 473,650.88 1.84 3,367.95 MWD+IFR-AK-CAZ-8C(6) 5,346.95 75.08 306.66 3,238.55 3,174.91 2,194.78 -2,676.25 5,996,113.02 473,578.39 1.93 3,459.94 MW13+1FR-AK-CAZSC(6) 5,441.09 75.38 305.59 3,262.57 3,198.93 2,248.63 -2,749.76 5,9%,167.10 473,505.06 1.34 3,551.03 MWD+IFR-AK-CAZ-SC (6) 5,535.76 75.44 305.09 3,286.42 3,222.78 2,301.62 -2,824.50 5,996,220.32 473,430.50 0.52 3,692.56 MWD+IFR-AK-CAZ-SC(6) 5,630.13 75.19 305.49 3,310.34 3,246.70 2,354.35 -2,899.01 5,996,273.29 473,356.17 0.49 3,733.75 MWD+IFR-AK-CAZSC(6) 5,724.6 75.47 305.23 3,334.23 3,270.59 2,407.17 -2,973.43 5,996,326.33 473,281.92 0.40 3,824.92 MWD+IFR-AK-CAZSC(6) 5,819.41 75.22 305.64 3,358.26 3,294.62 2,460.43 -3,048.27 5,9%379.82 473,207.25 0.49 3,916.70 MWDAFR-AK-CAZSC(6) 5,913.77 75.41 305.18 3,382.18 3,318.54 2,513.31 -3,122.67 5,996,432.94 473,133.03 0.51 4,007.89 MWD+IFR-AK-CAZ-SC 16) 6,008.48 75.31 305.39 3,406.11 3,342.47 2,566.25 -3,197.47 5,9%,486.11 473,058.41 0.24 4,099,44 MWDAFR-AK-CAZSC(6) 6,103.14 75.44 305.36 3,430.01 3,366.37 2,619.27 5,272.15 5,996,539.37 472,983.90 0.14 4,190.94 MWD+IFR-AK-CAZSC (6) 6,198.04 75.31 304.55 3,453.98 3,390.34 2,671.89 3,347.41 5,996,592.21 472,908.82 0.83 4,282.65 MWD+IFR-AK-CAZ-SC(6) 6,292.77 75.47 306.23 3,477.87 3,414.23 2,724.98 5,422.13 5,996,645.54 472,834.26 1.71 4,374.23 MWD+IFR-AK-CAZSC(6) 6,387.36 75.37 308.20 3,501.69 3,438.05 2,780.34 5,4%.03 5,996,701.13 472,761.56 2.02 4,465.76 MWD+IFR-AK-CAZSC.(6) 6,482.42 75.41 307.56 3,525.66 3,462.02 2,836.82 -3,567.63 5,9%757.83 472,669.14 0.65 4,557.75 MWD+1FR-AK-CAZ-SC (6) 6,576.97 75.38 307.19 3,549.51 3,485.87 2,892.36 5,640.34 5,996,813.60 472,616.62 0.38 4,649.24 MWD+IFR-AK-CAZ-SC(6) 6,672.38 75.25 306.87 3,573.69 3,510.05 2,947.95 5,714.02 5,9%,869.41 472,543.12 0.35 4,741.52 MWD+IFR-AK-CAZSC(6) 6,766.6 75.51 307.27 3,597.44 3,533.80 3,002.82 5,786.66 5,996,924.51 472,470.67 0.50 4,832.55 MWD+IFR-AK-CAZSC (6) 6,861.13 75.25 307.57 3,621.33 3,557.69 3,058.48 5,859.41 5,9%,980.40 472,398.10 0.41 4,924.15 MWD+IFR-AK-CAZ-SC (6) 6,955.78 75.38 307.43 3,645.33 3,581.69 3,114.22 5,932.05 5,997,036.36 472,325.65 0.20 5,015.70 MWD+IFR-AK-CAZ-SC(6) 7,050.29 75.36 307.06 3.669.10 3,605.54 3,169.57 4,004.84 5,997,091.0 472,253.03 0.38 5,107.15 MWD+IFR-AK-CAZSC(6) 7.144.86 75.34 307.39 3,693.09 3,629.45 3,22492 4.077.70 5,997,147.51 472,180.36 0.34 5,198.64 MWD -INC -ONLY (7) 111912018 11:46.52AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 35-611 Project: Kuparuk River Unit TVD Reference: 35-611 actual @ 63.64usft (Doyon 142) Site: Kupamk 3S Pad MD Reference: 35511 actual @ 63.64usft (Doyon 142) Well: 35511 North Reference: True Wellbore: 35511 Survey Calculation Method: Minimum Curvature Design: 35511 Database: OAKEDMPI Survey 11191201811:46:52AM Page 5 COMPASS 5000.14 Build 85D Map Map Section MD Inc Azl TVD TVDSS +N/.S +E/ -W N Ee( ting DLS Seaton (usft) C) P) (usR) (uslt) (usR) (usfQ (R) (ft) (R) (°/1001 (R) Survey Tool Name 7,239.05 75.50 307.73 3,716.80 3,653.16 3,280.49 4.149.96 5,997,203.30 472,108.28 0.39 5,289.80 MWD+IFR-AK-CAZSC(8) 7,334.00 75.22 307.59 3,74019 3,677.15 3,336.62 4.222.69 5,997,259.66 472,03514 0.33 5,381.66 MWD+IFR-AK-CAZSC(8) 7,428.09 75.29 307.61 3,764.74 3,701.10 3,392.14 -4294.78 5,997,315.40 471,963.83 0.08 5,472.65 MWDAFR-AK-CA -SC(8) 7,522.52 75.29 307.06 3,78812 3,725.08 3,447.53 4,367.40 5,997,371.01 471,891.40 0.56 5,563.99 MWD+IFR-AK-CAZSC(8) 7,617.67 75.41 307.20 3,812.78 3,749.14 3,503.10 4,440.80 5,997,426.81 471,818.19 0.19 5.656.03 MWD+IFR-AK-CAZSC(a) 7,712.95 75.37 306.76 3,836.82 3,773.18 3,558.56 4,514.45 5,997,482.50 471744.72 0.45 5,748.22 MW13+1FR-AK-CAZ-SC(8) 7,806.69 75.50 306.26 3,860.39 3796.75 3,612.54 -0,587.37 5,997,53610 471,671.98 0.53 5,838.92 MWD+IFR-AK-CAZSC(8) 7,901.73 75.19 308.09 3,884.44 3,620.80 3,668.09 -0,660.63 5,997,592.49 471,598.90 1.89 5,930.96 MWD+IFR-AK-CAZ-SC(8) 7,996.29 75.11 307.84 3,908.67 3,845.03 3,724.32 4,732.69 5,997,648.94 471,527.03 0.27 6,022.26 MWD+IFR-AK-CAZ-SC(8) 8,090.62 75.24 307.38 3,932.81 3,869.17 3,779.97 4,804.93 5,997,704.81 471,454.97 0.49 6,113.45 MWD+IFR-AK-CAZ-SC(8) 8,185.67 75.10 307.71 3,957.14 3,893.50 3,835.95 4,877.78 5,997,761.03 471,382.30 0.37 6,205.33 MWD+IFR-AK-CAZSC(8) 8,279.83 75.41 307.21 3,981.10 3,917.46 3,891.35 4,950.06 5,997,816.64 471,310.21 0.61 6,296.39 MWD+IFR-AK-CAZ-SC (8) 8,374.68 75.16 308.65 4,005.20 3,941.56 3,947.74 5,022.42 5,997,873.25 471,238.04 1.49 6,388.13 MWD+IFR-AK-CAZ-SC (8) 8,468.77 75.20 308.52 4,029.26 3,965.62 4,004.47 5,093.52 5,997,930.20 471,167.12 0.14 6,479.08 MWD+IFR-AK-CAZSC(a) 8,563.71 75.11 308.24 4,053.59 3,989.95 4061.44 5,165.46 5,997,987.40 471,095.37 0.30 6,570.85 MWD+IFR-AK-CA2-SC (8) 8,659.33 75.02 307.89 4,078.23 4,014.59 4,118.41 5,238.20 5,998,044.59 471,022.82 0.37 6,663.24 MWD+IFR-AK-CAZSC(8) 8,764.19 75.26 307.49 4,102.56 4,038.92 4,174.46 5,310.76 5,998,100.87 470,950.45 0.48 6,754.92 MWD+IFR-AK-WSC(8) 8,848.53 75.14 307.39 4,126.66 4,063.02 4,229.91 5,383.18 5,998,156.54 470,878.21 0.16 6,846.13 MWD+IFR-AK-CAZ-SC(8) 8,942.90 75.23 307.41 4,150.79 4,087.15 4,285.33 5,455.65 5,998,212.18 470,805.92 0.10 6,937.36 MWD+IFR-AK-CAZ-SC(8) 9,037.12 75.23 307.36 4,174.81 4,111.17 4,340.64 -5,528.05 5,998,267.72 470,733.71 0.05 7,028.6 MWD+IFR-AKCAZSC(8) 9,132.30 75.17 308.74 4,199.12 4,135.48 4,397.36 5,600.51 5,998,324.66 470,661.44 1.40 7,120.48 MWD+IFR-AK-CAZ-SC (8) 9,226.74 75.08 308.44 4,223.37 4,159.73 4,454.29 5671.85 5,998,381.82 470,590.28 0.32 7,211.75 MWD+IFR-AK-CAZSC(8) 9,320.98 75.11 307.80 4,247.61 4,183.97 4,510.51 5,743.50 5,998,438.26 470,518.62 0.66 7,302.82 MWD+IFR-AKCAZSC(8) 9,415.74 75.14 307.63 4,271.93 4,208.29 4,566.53 5,815.95 5,998,494.51 470,446.56 0.18 7,394.40 MWD+IFR-AK-CAZ-SC(8) 9,510.71 75.05 306.65 4,296.36 4,232.72 4,621.94 -5,889.10 5,998,550.14 470,373.58 1.00 7,486.17 MWDAFR-AK-CAZSC(8) 9,605.88 75.14 306.20 4,320.84 4,257.20 4,676.55 5,963.11 5,998,604.98 470,299.77 0.47 7,578.11 MWD+IFR-AK-CAZSC(a) 9,700.57 75.10 306.07 4,345.16 4,281.52 4,730.52 5,037.02 5,998,659.17 470,226.03 0.14 7,669.58 MWD+IFR-AK-CAZ-SC(8) 9,795.02 75.27 306.84 4,369.31 4,305.67 4,784.77 5,110.46 5,998,713.66 470,152.77 0.81 7,760.86 MWD+IFR-AK-CAZSC(8) 9,889.17 75.14 308.51 4,393.35 4,329.71 4,840.40 5,182.50 5,998,769.51 470,080.91 1.72 7,851.89 MWD+IFR-AK-WSC(a) 9,983.94 75.17 308.76 4,417.63 4,353.99 4,897.60 5,254.06 5,998,826.93 470,009.54 0.26 7,943.48 MWD+IFR-AK-CAZ-SC(8) 10,078.83 75.23 308.70 4,441.87 4,378.23 4,955.00 5,325.63 5,998,884.55 469,938.16 0.09 8,035.22 MWD+IFR-AK-CAZ-SC(8) 10,173.08 75.38 309.53 4,465.78 4,402.14 5,012.51 5,396.36 5,998,942.28 469,867.62 0.87 8,126.36 MWD+IFR-AKCAZSC(8) 10,268.12 75.07 309.71 4,490.02 4,426.38 5,071.12 6,467.15 5,999,001.10 469,797.03 0.37 8,218.21 MWD+IFR-AK-CAZ-SC(8) 10,362.52 75.11 308.26 4,514.31 4,450.67 5,128.50 5,538.06 5,999,058.71 469,726.31 1.48 8,309.42 MWD+IFR-AK-CAZSC(8) 10,456.77 75.17 307.54 4,538.48 4,474.84 5,184.46 6,609.94 5,999,114.89 469,654.61 0.74 8,400.51 MWD+1FR-AK-CAZSC(8) 10,551.35 75.14 307.13 4,562.71 4,499.07 5,239.91 5,682.63 5,999,170.56 469,582.11 0.42 8,491.93 MWD+IFR-AK-CAZ-SC(8) 10,646.34 75.20 307.48 4,587.03 4,523.39 5,295.56 6,755.67 5,999,226.44 469,509.25 0.36 8,58315 MWD+IFR-AK-CAZ-SC (8) 10,741.32 75.32 307.02 4,611.19 4,547.55 5,351.16 6,828.79 5,999,282.27 469,436.32 0.49 8,675.60 MWD+IFR-AK-CAZSC(8) 10,835.98 75.22 306.93 4,635.26 4,571.62 5,406.22 6,901.92 5,999,337.56 469,353.36 0.14 8,767.14 MWD+IFR-AK-CAZSC(8) 10,930.78 75.19 30616 4.659.47 4,595.83 5,461.18 6,975.27 5,999,392.75 469,290.20 0.18 8,85818 MWDAFR-AK-CAZSC(8) 11191201811:46:52AM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 38-611 Project Kuparuk River Unit TVD Reference: 3S-611 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 3S-611 actual @ 63.64usR (Doyon 142) Well: 3S-611 North Reference: True Wellbore: 3S-611 Survey Calculation Method: Minimum Curvature Design: 3S-611 Database: OAKEDMPI Survey Map Map Vertical MD Inc AZI TvD TVDSS +NTS +E7 -W Northing Eaating DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/too.) (ft) Survey Tool Name 11,025.50 75.23 307.18 4,683.65 4,620.01 5516.26 -7,048.49 5,999,448.05 469,217.21 0.43 8,950.35 MWD+IFR-AK-CAZSC(8) 11,120.00 75.17 308.16 4,707.79 4,644.15 5,572.09 -7,120.76 5,999,504.11 469,145.08 1.00 9,041.72 MWD+IFR-AK-CAZ-SC(8) 11,214.64 75.23 308.90 4,731.96 4,668.32 5,629.09 -7,192.34 5,999,561.33 469,073.69 0.76 9,133.21 MWD+IFR-AK-CAZSC(8) 11,308.77 75.19 308.71 4,755.99 4,692.35 5,686.13 -7,263.26 5,999,618.58 469,002.95 0.20 9,224.21 MM+IFR-AK-CAZSC(8) 11,403.71 75.23 309.54 4,780.23 4,716.59 5,794.05 -7,334.47 5,999,676.72 468,931.93 0.85 9,315.98 MWD+IFR-AK-CA7-SC (8) 11,497.94 75.17 310.93 4,804.30 4,740.65 5,802.89 -7,404.02 5,999,735.78 468,862.58 1.43 9,407.00 MWD+IFR-AK-CAZSC(8) 11,592.21 75.20 312.39 4,828.41 4,764.77 5,863.47 -7,472.11 5,999,796.57 468,794.69 1.50 9,497.94 MWD+IFR-AK-CAZSC(8) 11,686.96 75.29 313.90 4,852.54 4,788.90 5,926.13 -7,538.96 5,999,859.43 468,728.05 1.54 9,589.17 MWD+1FR-AK-CAZ-SC(8) 11,781.24 75.29 316.49 4,876.48 4,812.84 5,990.82 -7,603.21 5,999,924.32 466,664.01 2.66 9,679.60 MWD+IFR-AK-CAZSC(8) 11,875.32 75.20 318.92 4,900.45 4,836.81 6,056.11 -7,664.43 5,999,991.80 468,603.01 2.50 9,769.23 MWD+IFR-AK-CAZSC(a) 11,970.12 75.00 322.35 4,924.83 4,861.19 6,128.92 -7,722.53 6,000,062.79 468,545.14 3.50 9,858.56 MWD+IFR-AK-CAZ-SC (8) 12,064.60 74.64 325.70 4,949.58 4,885.94 6,202.70 -7,776.08 6,000,135.73 468,491.83 3.44 9,946.13 MWD+IFR-AK-CAZSC(8) 12,158.61 74.00 328.91 4,974.99 4,911.35 6,278.86 -7,824.97 6,000,213.04 468,443.19 3.36 10,031.47 MWD+IFR-AK-CAZSC(8) 12,253.75 73.95 332.14 5,001.26 4,937.62 6,358.45 -7,869.96 6,000,292.77 468,398.46 3.26 10,115.83 MWD+IFR-AK-CAZ-SC(8) 12,349.69 74.05 335.09 5,027.71 4,964.07 6,441.06 -7,910.94 6,000,375.49 468,M7.74 2.% 10,198.89 MWD+IFR-AK-CAZSC(8) 12,444.32 73.98 338.66 5,053.78 4,990.14 6,524.71 -7,946.66 6,000,459.24 468,322.29 3.63 10,278.42 MWD+IFR-AK-CAZSC(8) 12,537.87 74.09 342.4 5,079.52 5,015.88 6,609.40 -7,976.90 6,000,544.02 468,292.32 3.48 10,354.28 MWD+IFR-AK-CAZ-SC (8) 12,555.51 73.97 342.52 5,084.37 5,020.73 6,625.55 -7,982.06 6,000,560.19 468,287.21 2.70 10,368.27 MWD+IFR-AK-CAZSC(8) 12,573.43 74.10 343.14 5,089.30 5,025.65 6,642.01 -7,987.15 6,000,576.67 468,282.18 3.40 10,382.38 MWD-INC_ONLY (9) 12,667.90 75.44 346.39 5,114.12 5,050.46 6,729.95 -8,011.09 6,000,664.67 468,258.52 3.61 10,455.25 MWD+1FR-AK-CAZSC(10) 12,761.66 75.60 347.18 5,137.57 5.073.93 6,816.32 -8,031.64 6,00,753.10 468,238.05 0.83 10,525.88 MWD+IFR-AK-CAZSC(10) 12,856.54 75.39 346.55 5,161.33 5,097.69 6,907.78 -8,052.71 6,000,842.61 468,217.47 0.68 10,597.26 MWD+IFR-AK-CAZ-SC (10) 12,951.87 75.60 347.48 5,185.21 5,121.57 6,997.71 -8,073.45 6,000,932.60 468,197.02 0.97 10,668.82 MWD+IFR-AK-CAZSC(10) 13,046.58 75.39 347.00 5,208.93 5,145.29 7,087.13 -8,093.70 6,001,022.08 468,177.05 0.54 10,739.70 MWD+IFR-AK-CAZSC(10) 13,141.62 75.58 347.58 5,232.75 5,169.11 7,176.88 -8,113.94 6,001,111.89 468,157.10 0.62 10,810.76 MWD+IFR-AK-CAZ-SC(10) 13,236.57 77.13 347.75 5,255.15 5,191.51 7,267.02 -8,133.65 6,001,202.08 468,137.67 1.64 10,881.65 MWD+IFR-AK-CAZSC(10) 13,331.52 83.11 348.51 5,271.43 5,207.79 7,358.52 -8,152.88 6,001,293.63 468,118.74 6.35 10,952.98 MWD+IFR-AK-CAZSC(10) 13,426.65 88.07 349.65 5,278.75 5,215.11 7,451.62 -8,170.84 6,001,386]8 468,101.08 5.35 11,024.30 MWD+IFR-AK-CAZ-SC(10) 13,523.26 90.00 347.83 5,280.37 5,216.73 7,546.35 -8,189.70 6,001481.55 468,082.52 2.75 11,097.33 MWD+IFR-AK-CAZSC(10) 13,617.23 90.68 348.09 5,279.82 5,216.18 7,63825 -8,209.30 6,001,573.51 968,063.22 0.77 11,169.21 MWD+IFR-AK-CAZ-SC(10) 13,712.36 91.60 348.03 5,277.92 5,214.28 7,731.31 5,228.98 6,001,666.61 468,043.84 0.97 11,241.85 MWD+1FR-AK-CAZ-SC (10) 13,807.3 91.74 346.06 5,275.16 5,211.52 7,823.52 -8,250.19 6,001758.89 468,022.92 2.09 11,315.20 MWD+IFR-AK-CAZSC(10) 13,902.96 91.50 396.90 5,272.45 5,208.81 7,916.76 -8,272.61 6,01,852.18 468.000.80 0.91 11,390.12 MWD+IFR-AK-CAZ-SC(10) 13,995.00 91.08 Wet) 5,270.38 5,206.74 8,006.54 -8,292.76 6,001,942.02 467,980.93 1.08 11,461.13 MWD+IFR-AK-CAZ-SC(10) 14,089.17 91.77 343.47 5,268.04 5,204.40 8,097.71 -8,316.11 6,02,033.26 467,957.88 4.65 11.535.52 MWD+IFR-AK-CAZ-SG(10) 14,186.67 91.53 341.23 5,265.23 5,201.59 8,190.58 -8,345.66 6,002,126.21 967,928.63 2.31 11,615.85 MWD+IFR-AK-CAZ-SC(10) 14,280.06 91.77 344.81 5,262.54 5,198.90 8,279.85 5,372.92 6,002,215.55 467,901.66 3.84 11,692.15 MWD+1FR-AK-CAZSC(10) 14,375.64 91.59 345.26 5,259.74 5,196.10 8,372.14 -8,397.59 6,002,307.92 467,87228 0.51 11,768.28 MWD+IFR-AK-CAZSC(10) 14,471.48 92.31 346.03 5,256.48 5,192.84 8,464.95 -8,421.29 6,002,400.79 467,853.88 1.15 11,843.95 MWD+IFR-AK-CAZ-SC(10) 14,566.36 90.90 348.50 5,253.82 5,190.18 8,557.46 5,442.14 6,002,493.36 467,833.32 2.94 11,917.19 MWD+IFR-AK-CAZSC(10) 111912018 11:46:52AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-611 Project Kuparuk River Unit TVD Reference: 35-611 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 35-611 actual @ 63.64usft (Doyon 142) Well: 38-611 North Reference: True Wellbore: 35-611 Survey Calculation Method: Minimum Curvature Design: 35-611 Database: OAKEDMPI Survey IIA12018 11:46:52AM Page 7 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc Art TVD TVDSS +N/46 +B/ -W Northing Basting DLS Section (Mft) (1) (1) (usft) Net) Wait) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 14,661.65 90.74 347.87 5,252.45 5,188.81 8,650.72 5,461.65 6,002,586.67 467,814.11 0.68 11,989.83 MM+IFR-AK-CAZSC (10) 14,756.28 90.92 347.76 5,251.08 5,187.44 8,743.21 5,481.62 6,002,679.21 467,794.43 0.22 12,062.36 MWD+IFRAK-CAZ-SC(10) 14,851.50 91.89 353.74 5,248.75 5,185.11 8,837.12 5,496.92 6,002,773.16 467,779.44 6.36 12,132.07 MWD+11FR-AK-CAZ-SC(10) 14,947.52 91.26 1.69 5,246.10 5,182.46 8,932.95 5,500.74 6,002,868.99 467,775.92 8.30 12,193.91 MWD+IFR-AK-CAZSC(10) 15,040.78 91.57 359.73 5,243.80 5,180.16 9,026.17 5,499.58 6,002,962.20 467,777.37 2.13 12,250.21 MWD+IFRAK-CA7-SC(10) 15,078.24 91.84 357.38 5,242.69 5,179.05 9.063.60 5,500.53 6,002,999.63 467,776.55 6.31 12,273.92 MNA+IFR-AK-CAZSC (10) 15,135.29 91.98 352.55 5,240.78 5,177.14 9,120.38 5,505.53 6,003,056.42 467,771.72 8.47 12,312.72 MWD+IFRAK-CAZSC(10) 15,180.47 91.88 348.83 5,239.26 5,175.62 9,164.93 5,512.63 6,003,100.99 467,764.56 8.23 12,345.83 MWD+IFR-AK-CAZ-SC(10) 15,229.68 91.31 344.60 5,237.89 5,174.25 9,212.81 5,524.05 6,003,148.91 467,753.50 8.27 12,384.08 MWD+IFRAK-CAZSC (10) 15,250.69 91.43 343.96 5,237.39 5,173.75 9,233.04 5,529.71 6,003,169.15 467,747.91 404 12,400.96 MWD+IFR-AK-CAZ-SC(10) 15,324.90 91.33 340.77 5,235.60 5,171.96 9,303.74 5,552.18 6,003,239.91 467,725.66 4.30 12,462.08 MWD+IFRAK-CAZ-SC(10) 15,417.92 90.85 339.59 5,233.83 5,170.19 9,391.23 5,563.71 6,003,327.49 467,694.41 1.37 12,540.68 MWD+IFRAK-CAZSC (10) 15,514.99 89.92 338.86 5,233.18 5,169.54 9,481.98 5,618.14 6,003,418.34 467,660.27 1.22 12,623.56 MWD+IFR-AK-CAZ-SC(10) 15,609.61 8944 337.37 5,233.71 5,170.07 9,569.78 5,653.41 6,003,506.24 467,625.29 1.65 12,705.29 MWO+IFR-AK-CAZ-SC(10) 15,702.07 88.22 339.14 5,235.60 5,171.96 9,655.64 5,687.66 6,003,592.20 467,591.32 2.32 12,785.02 MWD+IFR-AK-CAZSC(10) 15,799.20 88.34 341.33 5,238.51 5,174.87 9,747.00 5,720.49 6,003,683.66 467,558.78 2.26 12,867.01 MWD+IFRAK-CAZ-SC(10) 15,892.13 88.52 344.93 5,241.06 5,177.42 9,835.88 5,747.44 6,003,772.62 467,532.11 3.88 12,942.84 MWD+IFR-AK-CAZSC(10) 15,984.02 88.10 345.55 5,243.77 5,180.13 9,924.70 5,770.83 6,003,861.50 467,509.01 0.82 13,015.82 MWD+IFR-AK-CAZSC(10) 16,076.57 87.55 344.8 5,247.28 5,183.64 10,014.04 5,794.74 6,003,950.91 467,485.39 1.31 13,089.53 MWD+IFR-AK-CA7-SC(10) 16,168.81 86.63 348.02 5,251.96 5,188.32 10,103.51 5,816.63 6,00,040.43 467,463.78 3.% 13,161.72 MWD+IFR-AK-CAZSC(10) 16.258.45 86.56 347.38 5,257.29 5,193.65 10,190.93 5,835.69 6,004,127.91 467,45.00 0.72 13,230.43 MWD+IFR-AK-CAZ-SC(10) 16,350.21 89.36 349.30 5,260.56 5,196.92 10,280.73 5,854.22 6,004,217.76 467,426]6 3.70 13,300.17 MWD+IFRAK-CAZ-SC (10) 16,397.20 91.46 349.19 5,260.22 5196.58 10,326.89 5,862.99 6,00,263.94 467,418.14 4.48 13,335.42 MWD+IFR-AK-CAZSC(10) 16,443.06 91.04 349.59 5,259.22 5,195.58 10,371.96 5,871.43 6,004,309.03 467,409.84 1.26 13,369.74 MWD+IFRAK-CAZ-SC(10) 16,531.42 91.26 349.6 5,257.45 5,193.81 10,458.77 5,887.80 6,004,395.69 467,393.75 0.65 13,435.94 MWD*1FRAK-CAZSC(10) 16,626.34 91.23 348.06 5,255.38 5,191.74 10,551.78 5,906.60 6,00,488.95 467,375.24 1.03 13,507.88 MWD+IFR-AK-CAZSC(10) 16,717.33 90.99 347.17 5,253.62 5,189.98 10,640.64 5,926.10 6,00,577.86 467,356.03 1.03 13,577.80 MWD+IFRAK-CAZ-SC(10) 16,811.58 91.19 347.62 5,25183 5,188.19 10,732.60 5,946.66 6,004,669.88 467,335.76 0.52 13,650.48 MWD+IFR-AK-CAZSC(10) 16,903.83 91.23 349.05 5,249.88 5,186.24 10,822.93 5,965.31 6,00,760.25 467,31240 1.55 13,720.64 MWD+IFR-AK-CAZSC(10) 16,996.68 91.02 348.54 5,248.06 5,184.42 10,913.99 5,983.35 6,004,851.36 467,299.66 0.59 13,790.77 MWD+IFRAK-CAZSC(10) 17,089.37 91.23 347.27 5,246.24 5,182.60 11,004.60 -9,002.77 6,004,942.03 467,280.53 1.39 13,861.71 MWD+1FR-AK-CAZSC(10) 17,181.86 91.02 34676 5,244.42 5,180.78 11,094.71 5,023.54 6,005,032.19 467,260.04 0.60 13,933.42 MVIDHFRAK-CAZ-SC (10) 17,273.73 91.33 346.09 5,242.54 5,178.90 11,183.99 -9,045.10 6,005,121.53 467,238.77 0.80 14,005.23 MWD+IFRAK-CAZ-SC(10) 17,364.99 91.19 345.20 5,240.53 5,176.89 11,272.38 -9,067.72 6,005,209.98 467,216.43 0.99 14,077.34 MWD+IFR-AK-CAZSC(10) 17,456.41 90.98 344.98 5,238.80 5,175.16 11,360.71 .,091.24 6,005,298.37 467,193.19 0.33 14,150.12 MWD+IFRAK-CAZ-SC(10) 17,547.85 91.33 344.62 5,236.96 5,173.32 11,448.93 5,115.21 6,005,386.66 467,169.51 0.55 14,223.19 MWD+IFRAK-CAZSC(10) 17,640.41 91.19 344.65 5,234.92 5,171.28 11,538.16 -9,139.73 6,005,475.96 467,145.27 0.15 14,297.31 MWD+IFRAK-CAZSC(10) 17,732.31 90.57 345.51 5,233.51 5,169.87 11,626.95 .,163.39 6,005,564.82 467,121.90 1.15 14,370.48 MWD+IFRAK-CAZ-SC(10) 17,825.73 90.50 344.16 5,232.64 5,169.00 11,717.11 -9,187.83 6,005,655.05 467.9]75 1.45 14,445.11 MWD+IFRAK-CAZSC(10) 17,916.98 90.61 346.54 5,231.75 5,168.11 11,805.38 5,210.90 6005,743.39 467,074.96 2.61 14,517.50 MWD+IFRAK-CAZ-SC (10) IIA12018 11:46:52AM Page 7 COMPASS 5000.14 Build 850 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 3S-611 Project Kuparuk River Unit TVD Reference: 35511 actual @ 63.64usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: 35511 actual @ 63.64usft (Doyon 142) Well: 35-611 North Reference: True Wellbore: 35511 Survey Calculation Method: Minimum Curvature Design: 35-611 Database: OAKEDMP7 Survey 11/92018 11:46:52AM Page 8 COMPASS 5000.14 Build 85D Map Map vertical MD Inc Azl TVD TVDSS +WS +E1 -W Northing Easgng DLS Section (usft) 0 (') (usft) (usft) (usft) (uslq (ft) (ft) (°/1001 (R) Survey Tool Name 18,009.33 90.68 348.07 5,230.71 5,167.07 11,895.47 9,231.19 6,005,833.52 467,054.95 166 14,588.81 MWD+IFR-AK-CAZSC(10i 18,101.94 90.78 348.43 5,229.53 5,165.89 11,986.13 9,250.05 6,005,924.24 467,036.39 0.40 14,659.34 MWD+IFR-AK-CA7-SC (10) 18,192.74 90.74 346.45 5,228.33 5,164.69 12,074.74 -9,269.79 6,006,01290 467,016.93 2.1e 14,729.32 MWD+IFR-AKI:AZSC(10) 18,285.90 90.50 347.51 5,227.32 5,163.68 12,165.50 9,290.78 6,006,103.72 466,996.23 1.17 14,801.59 MM+IFR-AK-CAZSC(10) 18,378.19 90.64 349.76 5,226.40 5,16276 12,255.97 9,30897 6,006,19424 466,978.34 2.44 14,871.47 MWD+1FR4kK-CAZSC(10) 18,468.35 90.78 350.80 5,225.28 5,161.64 12,344.83 -9,324.19 6,006,283.14 465,963.40 1.16 14,938.02 MWD+IFR-AK-CAZSC(10) 18,559.77 90.78 349.08 5,224.04 5,160.40 12,434.83 -9,340.15 6,006,373.18 466,947.72 1.88 15,005.87 MWD+IFR-AK-CAZSC(10) 18,629.78 90.88 348.91 5,223.03 5,159.39 12,503.55 9,353.52 6,006,441.93 466,934.58 0.28 15,058.59 MWD+IFR-AK-CAZSC(10) 18,685.00 90.88 348.91 5,222.18 5,158.54 12,557.73 9,364.14 6,006,496.14 466,924.13 0.00 15,100.23 PROJECTED to TD 11/92018 11:46:52AM Page 8 COMPASS 5000.14 Build 85D NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-611PB1 3S-611PB1 NAD 27 ConocoPhillips Definitive Survey Report nQ mnvcmha, 2n1R Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. Yes No I have checked to the hest of my ability that the following date /s correct: Surface Coordinates Declination & Convergence GRS Survey Corrections Survey Tool Codes Brandon Temt�Ie Digitally signed by Brandon Temple SLB DE: p Date: 2018.11.0912:14:27-09'00' Z: Client Representative: Date: 11/9/18 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 35-611 Project: Kuparuk River Unit TVD Reference: 35-611 actual @ 63.64usft (Doyon 142) Site: Kupamk 3S Pad MD Reference: 3S-611 actual C 63.64usft (Doyon 142) Well: 3SS71 North Reference: True Wellbore: 35-611PB1 Survey Calculation Method: Minimum Curvature Design: 35-611PB1 Database: OAKEDMP1 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zane: Alaska Zone 04 Using geodetic scale factor Well 35-611 ACTUAL Tie On Depth: 39.14 Well Position +NIS 0.00 usft Northing: 5,993,909.97 usft Latitude: 70° 23'40.172 N +EI -W 0.00 usft Easting: 476,247.39 usft Longitude: 150° 11'35.733 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 24.50 usft Wellbore 35-611PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) C) (nT) BGGM2018 9/30/2018 16.82 80.88 57,433 Design Audit Notes: Verson: Vertical Section: 35-611PB1 1.0 Phase: ACTUAL Tie On Depth: 39.14 Depth From (TVD) -NIS +E/ -W Direction (usft) (usft) (usft) r) 39.14 0.00 0.00 313.61 Survey Program Date From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 85.07 1,013.2435-611 Srvy 1- SLB _GWD70(35-611PB GYD-GC-SS Gyrodata gyro single shots 9/26/2018 f 1,072.31 2,951.503SS11PB1Srvy2-SLB MWD+GMAG MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/26/2018 f Survey 111912018 11:28:27AM Page 2 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc An TVD TVDSS +NIS +E/ -W Northing Easgng DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/1007 (ft) Survey Tool Name 39.14 0.00 000 39.14 -24.50 0.00 0.00 5,993,909.97 476,247.39 0.00 0.00 UNDEFINED 85.07 0.36 191.66 85.07 21.43 -0.14 -0.03 5,993,909.83 476,247.36 0.78 -0.08 GYD-GCSS(1) 164.91 0.31 256.53 164.91 101.27 -0.44 -0.29 5,993,909.53 476247.10 0.45 -0.09 GYD-GCSS(1) 263.63 0.48 221.37 263.63 199.99 -0.81 4).82 5,993,909.16 476,246.56 0.29 0.04 GYD-GCSS(1) 357.74 1.31 302.20 357.73 294.09 -0.53 -1.99 5,993,909.44 476,245.39 1.40 1.08 GYD-GCSS(1) 451.25 271 311.12 451.18 387.54 1.49 -0.56 5,993,911.48 476,242.83 1.53 4.33 GYD4C-SS(1) 544.17 2.67 312.66 543.99 480.35 4.40 -7.81 5,993,914.40 476,239.59 0.09 8.69 GYD-GC-SS(1) 636.47 4.52 328.10 636.11 572.47 8.95 -11.31 5,993,918.95 476,236.11 2.24 14.36 GYD-GC-SS(1) 729.51 5.95 327.82 728.76 665.12 16.14 -15.82 5,993,926.16 476,231.62 1.54 22.59 GYD-GC-SS(1) 823.64 7.76 318.73 822.22 758.58 25.05 -22.61 5,993,935.09 476,224.86 2.24 33.65 GYD-GC-SS(1) 918.31 9.39 317.14 915.83 852.19 35.51 J2.08 5,993,945.58 476,215.43 1.74 47.72 GYD-GCSS(1) 1,013.24 12.65 314.99 1,008.99 945.35 48.54 -0470 5,993,958.65 476,202.85 3.46 65.85 GYD-GCSS(1) 1,072.31 15.94 311.79 1,066.23 1,002.59 58.52 55.33 5,993,968.66 476,192.25 5.73 80.43 MWD+IFR-AK-CAZSC(2) 111912018 11:28:27AM Page 2 COMPASS 5000.14 Build 85D Survey Conocoftillips Definitive Survey Report Map Company: NADConversion Local Coordinate Reference: Well 3S-611 Project: Kuparuk River Unit TVD Reference: 35-611 actual @ 63.64usft (Doyon 142) Site: Kuparuk 35 Pad MO Reference: 3S-611 actual @ 63.64usft (Doyon 142) Well: 35511 North Reference: True Wellbore: 3SS11PB7 Survey Calculation Method: Minimum Curvature Design: 3S-611PB1 Database: OAKEDMPI Survey 11/9/2018 11:28:27AM Page 3 COMPASS 5000.14 Build 65D Map Map Vertical MD Inc Ari TVD TVDSS +N/.4 +E/ -W Northing Easting OLS Section (waft) (') (1) (usft) (usft) (waft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,103.38 18.18 311.13 1,095.93 1,032.29 64.56 52.16 5,993,974.72 476,185.44 7.24 89.53 MWD+IFR-AK-CAZ-SC(2) 1,166.95 19.76 310.71 1,156.4 1,092.40 78.09 -77.78 5,993,988.30 476,169.87 2.49 110.18 MWD+IFR-AK-CAZ-SC(2) 1,202.20 19.81 310.6 1,189.21 1,125.57 85.85 56.84 5,993,996.09 476,160.83 0.28 122.09 MWD+IFR-AK-CAZSC(2) 1,261.51 21.34 310.27 1,249.74 1,181.10 99.35 -102.72 5,994009.64 476,145.00 2.5B 142.90 MWD+IFR-AK-CAZSC(2) 1,356.39 24.57 313.50 1332.10 1,268.46 124.09 -130.21 5,994,034.46 476.117.59 3.65 179.87 MWD+1FR-AKCAZSC(2) 1,451.02 29.22 316.28 1,416.47 1,352.83 154.35 -160.46 5,994,064.81 476,087.44 5.09 222.64 MWD+IFR-AK-CAZ-SC(2) 1,545.36 31.00 318.24 1,498.08 1,434.44 189.12 -192.56 5,994,099.68 476,055.45 2.16 269.86 MWD+IFR-AK-CAZSC (2) 1,640.26 29.85 320.09 1,579.91 1,516.27 225.6 -223.99 5,99Q136.12 476,024.14 1.56 317.69 MWD+IFR-AK-CAZ-SC (2) 1,735.82 29.12 315.42 103.11 1,599.47 260.27 -255.57 5,994,171.03 475,992.67 252 364.57 MWD+IFR-AK-W-SC (2) 1,829.96 29.22 316.17 1,745.31 1,681.67 293.16 -287.56 5,994,204.02 475,0.79 0.40 410.42 MWD+IFR-AK-CAZSC(2) 1,924.16 30.43 316.10 1,827.03 1,763.39 326.94 -320.03 5,994,237.89 475,928.43 1.29 457.22 MWD+IFR-AK-CAZSC(2) 2,019.28 34.51 313.19 1,907.27 1,843.63 362.76 556.39 5,994,273.82 475,892.19 4.59 508.26 MWD+IFR-AK-GAZSC (2) 2113.08 37.22 311.62 1,983.28 1,919.64 399.79 -396.98 5,994,310.98 475,851.72 3.05 563.19 MWD+IFR-AK-CAZ-SC (2) 2,208.12 40.73 311.15 2,057.15 1,993.51 439.30 441.83 5,994,350.63 475,87.00 3.71 622.91 MWDAFR-AK-CAZSC(2) 2,302.93 43.29 309.90 2,127.59 2,063.95 480.51 490.07 5,994,391.99 475,758.90 2.84 686.27 MWD+IFR-AK-CAZSC(2) 2,397.72 45.74 309.00 2,195.18 2,131.54 522.73 541.39 5,994,434.36 475,707.72 2.67 752.54 MWD+IFR-AK-CAZSC(2) 2,491.62 48.51 308.06 2,259.6 2,195.42 565.58 595.22 5,994,477.38 475,654.03 3.04 821.07 MWD+IFR-AK-CAZSC(2) 2,586.12 51.11 308.05 2,320.04 2,256.40 610.7 552.D6 5,994522.05 475,597.34 2.75 892.92 MWD+IFR-AK-CAZ-SC (2) 2,680.16 54.13 308.28 2,377.13 2,313.49 656.24 -710.80 5,994,568.0 475,538.74 3.22 967.30 MWD+IFR-AKCAZ-SC (2) 2,775.46 53.86 308.41 2,433.15 2,369.51 704.7 -771.27 5,994,616.42 475,478.44 0.30 1,044.07 MMAFR-AK-W-SC (2) 2,869.57 56.17 308.49 2,487.11 2,423.47 752.02 531.65 5,994,664.55 475,416.22 2.46 1,120.86 MWD+IFR-AKCAZ-SC(2) 2,951.50 58.15 307.17 2,531.53 $467.89 794.22 586.02 5,994,706.93 475,363.99 2.77 1,189.34 MND+IFR-AK-CAZSC(2) 3,034.0 58.15 307.17 2,575.07 2,511.43 836.56 -941.86 5,994,749.44 475,308.29 0.00 1,258.97 PROJECTED to TD 11/9/2018 11:28:27AM Page 3 COMPASS 5000.14 Build 65D Cement Detail Report 3S-611 String: Conductor Cement Job: DRILLING ORIGINAL, 9/19/201800:00 Cement Details Description Cementing Start Date Cementing End Date 1wellbore Name Conductor Cement 8/5/2018 17:00 8/5/2018 18:00 3S-611 Comment 42" hole drilled to 38' below pad level and top brought up to 3.75' below pad level (under cellar box). Total of 34.25' is cemented) Calc to be 45.38 bbls of cement. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement cement the drillled hole to 42.8 77.0 No 0.0 No No 38' below pad. O Pump Init (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) No I INo I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement the 42" drilled hole f/ 3.75' below pad to 38' below pad on the outside of the 20' OD driven pipe (drove to 80' below pad level). Pipe drove to 80' below pad level. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ft(B) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Primary Cement 42.8 77.0 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 111 ReportPrinted: 11/15/2018 Cement Detail Report 3S-611 String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/19/2018 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/4/2018 12:30 11014/201817:15 3S-611 Comment Line up & SLB pump 5 bbls of CW100. Pressure test lines to 4000 psi, good. Pump 35 bbls of CW100 @ 5.4 bpm, 169 psi, FO 18%, PU 169K, SO 116K. Pump 73.1 bbls of 10.5 ppg MP II @ 5 bpm, 100 psi, FO 18%. Drop bottom plug & start batching lead. Pump 816.7 bbls of 11.0 ppg lead cement at 3.4-6 bpm, 60-345 psi, FO 18%-0%, final PU 205K, SO 60K. CW100 at surface with 520 bbis of lead away. Land out casing with 570 bbls of lead away. Loose returns with 580 bbls of lead away. Pick up string to re-establish returns, no success. unable to land back out. Hanger .09' off landing ring. Pump 65.5 We of 12.0 ppg tail cement @ 3.4-5 bpm, 166-270 psi, FO 0%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 10.0 ppg spud mud @ 8 bpm, 510-638 psi, FO 0%. Reduce rate to 3 bpm, 330 psi, FO 0%. Bump plug with 2730 strokes, 275.2 bbls pumped. Pressure up to 890 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 17:12 hrs. Cement Stages Stage 01 Description ObjectiveTop Depth (ftKB) Bottom Depth (ftKB) Full Return? V01 Cement... Top Plug? Bum Plug? Surface Casing Cement 369.0 3,034.0 No 0.0 Yes I Yes O Pump Init (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) 2 2 5 330.0 890.0 1 Yes 10.00 INC 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 4000 psi, good. Pump 35 bbls of CW100 @ 5.4 bpm, 169 psi, FO 18%, PU 169K, SO 116K. Pump 73.1 bbis of 10.5 ppg MP II @ 5 bpm, 100 psi, FO 18%. Drop bottom plug & start batching lead. Pump 816.7 bbls of 11.0 ppg lead cement at 3.4-6 bpm, 60-345 psi, FO 18%-0%, final PU 205K, SO 60K. CW100 at surface with 520 bbls of lead away. Land out casing with 570 bbls of lead away. Loose returns with 580 bbls of lead away. Pick up string to re-establish returns, no success. unable to land back out. Hanger .09' off landing ring. Pump 65.5 bbls of 12.0 ppg tail cement @ 3.4-5 bpm, 166-270 psi, FO 0%. Drop lop plug & kick out with 10 We of fresh H2O. Swap to rig & displace w/ 10.0 ppg spud mud @ 8 bpm, 510-638 psi, FO 0%. Reduce rate to 3 bpm, 330 psi, FO 0%. Bump plug with 2730 strokes, 275.2 bbls pumped. Pressure up to 890 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 17:12 hrs. Cement Fluids & Add@ives Fluid Fluid Type Fluid Description I Estimated Top (ftKB) Est Bum (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW100 I I 1 1 40.0 Yield (R%sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ClassVolume Pum petl (bbl) MudPushll 73.1 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water 1%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bum (ftKB)Amount (sacks) Class Volume Pumped (bbl) Tail cement 2,534.0 3,034.0 223 G 65.5 Yield (R -/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.60 1 12.00 97.9 3.75 Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead cement 368.0 2,534.0 2,401 G 816.7 Yield (Wisack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.76 1 11.00 83.3 5.75 Additives Additive Type Concentration Cone Unit label Page 111 ReportPrinted: 11/1 512 01 8 e Cement Detail Report 3S-611 String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/191201800:00 Cement Details Description Surface Casing Cement Cementing Start Date 10/5/2018 12:00 Cementing End Date 10/5/2018 15:15 Wellbore Name 3S-611 Comment TIH with .75" tubing down annulus & tag up on cement at 234.88' MD. Rig up cement lines to .75" pipe. Pump 100 bbls of fresh H2O flush at .75 bpm, 330 psi. Batch up & pump 113 We of 11 ppg DeepCrete cement at 1 bpm, 620 psi, with cement returns to surface. Cement Stages Stage # <Stage Number?> Description Surface Casing Cement Top Job JObjective Top job Top Depth (ftKB) 0.0 Bottom Depth (ftKB) 234.0 Full Return? Yes Vol Cement... 73.0 Tap Plug? Nc Btm Plug? No Q Pump Ink (bbllm... 1 Q Pump Final (bbl/... 1 1 Q Pump Avg (bbl/... 1 P Pump Final (psi) 620.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No I Pipe RPM (rpm) Tagged Depth (f KB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Lead cement Fluid Description Estimated Top (ftKB) 0.0 Est Ben (ftKB) 234.0 Amount (sacks) 332 Class G Volume Pumped (bbl) 113.0 Yield (ft'/sack) 1.91 Mix H2O Ratio (gal/sa... 6.76 Free Water (°k) Density (lbigal) 11.00 Plastic Viscosity (0) 83.3 Thickening Time (hr) 5.75 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 ReportPrinted: 11/15/2018 Cement Detail Report 3S-611 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 9/19/201800:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/13/2018 01:15 10/13/2018 05:00 3S-611 Comment Pump 5 tools water. Test lines to 4000 psi. Drop lower bottom plug. Batch up and pump 76.3 bbls of 12.5 ppg MudPush II, 4 bpm, 380 psi, 15% FO. Drop upper bottom plug. Batch up and pump 270.7 bbls 15.8 ppg Class G cement , 5.2 bpm, 215 psi, 22% FO. Drop top plug. Pump 10 bbls water. Swap to rig and displace with 9.4 ppg LSND. Land casing at 3350 stks with 83K hookload. Reduce rate to 3 bpm at 4600 stks. Initial rate at 7 bpm, 180 psi, 24% FO. Final rate 3 bpm, 1080 psi, 12% FO. Bump plug at 5629 silks. Pressure up to 1500 psi and hold for 5 mins. CIP at 04:59 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Ron Plug? Intermediate Casing 5,648.0 12,620.0 Yes Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 3 5 1,080.0 1,500.0 1 Yes 2000. No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 163/4 Comment Pump 5 bbls water. Test lines to 4000 psi. Drop lower bottom plug. Batch up and pump 76.3 bbls of 12.5 ppg MudPush II, 4 bpm, 380 psi, 15% FO. Drop upper bottom plug. Batch up and pump 270.7 bbls 15.8 ppg Class G cement , 5.2 bpm, 215 psi, 22% FO. Drop top plug. Pump 10 bbls water. Swap to rig and displace with 9.4 ppg -SND. Land casing at 3350 silks with 83K hookload. Reduce rate to 3 bpm at 4600 stks. Initial rate at 7 bpm, 180 psi, 24% FO. Final rate 3 bpm, 1080 psi, 12% FO. Bump plug at 5629 stks. Pressure up to 1500 psi and hold for 5 mins. CIP at 04:59 hrs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ft(B) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 5,648.0 12,620.0 1,310 G 270.7 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.0 1 1 15.80 117.2 Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 11/15/2018 pro a/ S -103 Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Sunday, October 21, 2018 5:48 PM To: Loepp, Victoria T (DOA) Subject: Re: [EXTERNAL]Re: KRU 3S-611 (PTD 218-103) Intermediate Cement Evaluation Follow Up Flag: Follow up Flag Status: Flagged Thank you for the quick reply. Have a great Sunday evening. Tolman 307-231-3550 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Sunday, October 21, 2018 5:24:15 PM To: Tolman, Ben V Subject: [EXTERNAL)Re: KRU 3S-611 (PTD 218-103) Intermediate Cement Evaluation Ben, Thanx for the intermediate cement job results and evaluation. The cement job appears good. Approval is granted to proceed. Thanx, Victoria Sent from my Whone On Oct 21, 2018, at 3:41 PM, Tolman, Ben V < > wrote: Victoria, Good afternoon and I hope your weekend is going well. As requested in the 3S-611 PTD included are the cement job and cement evaluation results of the 7-5/8" intermediate cement job. The following two .pdf files are attached: • Full Cement Evaluation Log • Cement Job/Evaluation Review and Cement Job Report In short, execution of the intermediate cement job went well. The cement evaluation log indicates great cement coverage well above the shoe along with cement coverage through the Coyote formation. Please refer to attachment for further details. Please let me know if you have any questions. Thanks, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) <3S-611 Intermediate Cement Review.pdf> <Conoco Phil Ii ps_3S-611_ Top_of_Ceme nt_PDF. pdf> Loepp, Victoria T (DOA) From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Friday, October 5, 2018 4:03 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]Re: KRU 3S-611: PTD 218-103 (Surface Hole Operations Update) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for the approval this evening. The rig as contact the State Inspector, they are on their way out to witness the job. We will be sure to follow-up and submit the 10-403 paperwork as well. Thanks again. 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: Friday, October 5, 2018 3:56 AM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (DOA) <jim.regg@alaska.gov> Subject: Re: [EXTERNAL]Re: KRU 3S-611: PTD 218-103 (Surface Hole Operations Update) Ben, Approval is granted to proceed with the top job as outlined below after the State Inspector has been notified for an opportunity to witness. Thanx, Victoria Sent from my iPhone On Oct 5, 2018, at 3:50 AM, Tolman, Ben V < Victoria, > wrote: As discussed on the phone we ran our 3/4" pipe down the annulus and tagged up at 329.61'. As per our volume calculations (from the Mud Push) we were anticipating tagging up ^317' MD. Do we have approval to proceed as follows and perform top job? • Displace/flush annulus with fresh water. Pump 11.0 DeepCrete cement as required to circulate cement to surface. Our discussed, our rig supervisor did talk with an inspector (Austin McLoud) earlier this evening. The rig was instruction to give them another call once we had approval to proceed. The rig will be re - contacting the inspector as requested. Please let me know if you have any questions. Thanks, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307) 231-3550(m) From: Tolman, Ben V Sent: Thursday, October 4, 2018 11:01 PM To: Toepp, Victoria T (DOA)' < > Subject: RE: [EXTERNAL]Re: KRU 35-611: PTD 218-103 (Surface Hole Operations Update) Victoria, I apologize for the second email, I was wanting to get something headed your way as early as possible, and I didn't have my hands on our cement report yet. For your convenience, attached is the cement report from the Surface Cement job. Please let me know if your need additional information while reviewing approval for the top off job. Thanks, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307) 231-3550(m) From: Tolman, Ben V Sent: Thursday, October 4, 2018 9:12 PM ToAoepp, Victoria T (DOA)' < > Subject: RE: [EXTERNAL]Re: KRU 35-611: PTD 218-103 (Surface Hole Operations Update) Victoria, As discussed on the phone, we finished pumping our surface casing cement job this evening. During the job, returns were lost and cement was not circulated to surface. Below is outline of the cement job and our plan forward for the remedial cementjob. Based on current operations, we should anticipate to have the diverter nippled down and ready to start lowering our small diameter pipe down the annulus sometime this evening between 10:00 pm and mid -night. Would it be possible to obtain approval to proceed with top job this evening? Wellbore Specifics • Drilled surface depth: 3,034' MD / 2,588' TVD @ 60.50° inclination • Surface Casing: 10-3/4", 45.5#, L-80, HYD563 • Surface Casing set depth: 3,027' MD / 2,582' TVD • No issues with casing run. o 1 centralizer/joint was ran and 2 centralizers/joint on each joint of shoe track. • Staged up pumps (to 7 bpm) and circulated mud 6.75 hrs prior to cement job. Cement Program: • Spacer: 45 bbls Chem Wash & 73 bbls MudPush II • Dropped bottom plug • Lead Cement: 816.7 bbls 11.0 ppg DeepCrete Lead cement • Tail Cement: 65.5 bbls 12.0 ppg DeepCrete Tail cement • Dropped top plug • Displacement: 285.2 bbls • Plugs pumped. Floats held. • Pipe was reciprocated until loss in slack -off weight was observed. • Cement job summary: o No issues were seen while running casing. o No issues were seen while staging pumps up to circulating rate (7 bpm). o Pumped spacer program and start of lead slurry without any issues. o Reduced slack -off weight was also observed while reciprocating casing, so the casing hanger was landed out. Lost returns were observed with 580 bbls of lead cement away. Attempted to pick-up on hanger to help re-establish cement circulation, unable to move hanger. Leave hanger landed out. o The cement program was continued as per plan (finished pumping lead cement, tail cement, and displacement). o Lift pressure was observed while pumping displacement. o No issues maintaining cement density throughout job. o Prior to losses, 40 bbls of Mud Push was seen at surface. Plan Forward • Based on gauge hole, the volume of Mud Push pumped, and the volume of Mud Push seen at surface (leaving —33 bbls in hole) we anticipate finding top of cement 317' below surface. (Note: that top could vary based on actual excess of the open hole.) • Nipple down diverter and adapter to gain access top of casing hanger. • Run in with 3/4" pipe ("spaghetti" string) down the annulus until tag up/take weight on cement. • Displace/flush annulus with fresh water. • Pump 11.0 DeepCrete cement as required to circulate cement to surface. Please call me with any questions, best number to reach me this evening would be my mobile phone (307-231-3550). Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(0)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) < > Sent: Thursday, October 4, 2018 9:28 AM To: Tolman, Ben V < > Subject: Re: [EXTERNAL]Re: KRU 35-611: PTD 218-103 (Surface Hole Operations Update) Great! Sent from my Whone On Oct 4, 2018, at 9:12 AM, Tolman, Ben V < Victoria, > wrote: Good morning. Just a quick update regarding the 35-611 (PTD 218-103). Last night we successfully ran casing to bottom without any issues. We are currently circulating on bottom rigging up cement trucks. Please let me know if you have any questions. Thanks, Ben Tolman Drilling Engineer I Conoco Phillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Loepp, Victoria T (DOA) < > Sent: Tuesday, October 2, 2018 10:20 PM To: Tolman, Ben V < > Subject: [EXTERNAL]Re: KRU 3S-6-11: PTD 218-103 (Surface Hole Operations Update) Ben, Thanx for the update. We will talk in the morning. Victoria Sent from my iPhone On Oct 2, 2018, at 10:03 PM, Tolman, Ben V < wrote: Good evening Victoria, I apologize for the after -hour communications (email and phone calls to your office and mobile phone), but we did want to'give you a current update on the 3S-611 (PTD 218-103) surface hole and our planned forward. I will give you a follow-up phone call in the morning to discuss any details. Below is an operational summary, the current status, and our planned forward. Please feel free to contact me on my mobile phone at any time if you would like to have a conversation before tomorrow. Operation Summary: • Spud well on 9/25 (Last Tuesday). • TD's surface interval at 3,034' MD on 9/27 (last Thursday). • Started to run 10-3/4" surface casing on morning of 9/28 (last Friday). Tagged up 1,298' MD. Worked casing down to 1,324' MD. • After working casing for 25.5 hrs (with no progress the last 12 hours) decision was made to lay down casing on 9/29 (Saturday) • Made 111 clean out run on 9/30 (Sunday). Started to run 10-3/4" surface casing on evening of 9/30 (Sunday). Tagged up 2,113'. Worked pipe to 2,160'. After working casing for 17.25 hrs (with no progress over last 8 hours) decision was made to lay down casing for second time on evening of 10/1 (Monday). It appears we have an obstruction in wellbore (not acting sticky). Started in hole with 2nd clean out run mid-day today (10/2). Tagged up 2,153'. P/U and began to ream down. • Upon getting that stand down (2,205' MD bit depth) the MWD was trending 0.6° below original wellbore. Indicating potential sidetrack. Attempted to get back in original wellbore (slide drilling). By next stand down (2,300' MD with MWD at 2,225' MD), the MWD was showing 2.31' below trend of original wellbore. Current Status: • We believe we sidetracked the original wellbore "' 2,129' MD while working casing down yesterday. • We believe it impracticable to re -locate the original wellbore at this time. • The permafrost has been open for a week now. It has not been an issue for us so far; however, we do anticipate the longer we have it open the potential for issues will only increase. • Being a clean-out BHA, we currently only have MWD tools in the hole (no LWD GR or resistivity tools). Planned Forward • Our plan forward is to re -drill this lower section with current BHA (without LWD tools). • With potential concerns of permafrost deteriorating, we do not feel it prudent to make trip for LWD tools. We believe the additional time and trips through the permafrost could jeopardize and compromise the integrity of the wellbore. • Our geology group feels comfortable drilling ahead and picking a TD without LWD tools, based on position and what we saw in original LWD logs and offset wells. • Offset Kuparuk wells on 3S pad were drilled without logs in surface interval. • We will be happy to provide LWD logs from original wellbore. As mentioned above, I will contact you tomorrow morning. Thanks and hope you have a good evening, Ben Tolman Staff Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) THE STATE. Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER Ben Tolman Staff Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-611 Permit to Drill Number: 218-103 Sundry Number: 318-458 Dear Mr. Tolman: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.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. k� DATED this �_ day of October, 2018. Sincerely, Hollis S. French Chair RBDMS�� OCT 1 9 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 CIC I o 19 CC:Ala OGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Apgfnygd Program I of :l' � Plug for Redrill El Perforate New Pool [IRe-enterSusp Well El Alter Casing ElRemedial cCement � 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development D Stratigraphic ❑ Service ❑ 218-103 3. Address: 6. API Number: - 3,. -77'1-Lc_ P.O. Box 100360, Anchorage, Alaska 99510 5774-00-00 jj 7. If perforating: 8. Well Name and Number: A7 /F What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations inquire a spacing exception? Yes ElNo (ZKRU 3S-611 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL380107:ADL380106, ADL025528 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): 3,034' 2,588' N/A N/A 1,638 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 119' 119' Surface 2,988' 10-3/4" 3,027' 2,582' 5,210 psi 2,470 psi Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): None N/A 12. Attachments: Proposal Summary Wellbore schematic ❑ 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: 10/5/2018 OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Dale: 10/5/2018 Commission Representative: Victoria Loepp 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: Ben Tolman Contact Name: Ben Tolman Authorized Title: Staff Drilling Engineer Contact Email: ben.v.tolman Conoco hjlll S.com Contact Phone: 307-231-3550 Authorized Signature: 7,61 Tu'w A^ Date: 1,102,19 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: SIS - I✓� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: V 1 -kW ss fop J°b �,—ee- Post Initial Injection MIT Req'd? Yes ❑ No Er--' SSG yvd� car/ Spacing Exception Required? Yes El No Subsequent Form Required: god APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: lb IL-4 I.8 ":P 7- J Zft``../ DMS_ qCT 9 LU 10 Submit Form and Fdid1t10-403 Revised 412017 Approved application is valid for 12 months from t e date of approve �� /I achments io Duplicate CC 35-611 (PTD 218-103) Surface Cement and Top Job Summary On October 4, 2018 the surface casing primary cement operation was performed on 35-611. During the cement job, lost returns were observed. 40 bbis of MudPush was circulated/observed at surface however, no cement was observed. On October 5, 2018 a top job was performed (witnessed by AOGCC ✓ State Inspector). Wellbore Specifics: • Drilled surface depth: 3,034' MD / 2,588' TVD @ 60.50° inclination • Surface Casing: 10-3/4", 45.5#, L-80, HYD563 • Surface Casing set depth: 3,027' MD / 2,582' TVD • No issues with 3`d attempt to run casing. o 2 centralizers/joint on each joint of shoe track and 1 centralizer/joint above shoe track. • Staged up pumps (to 7 bpm) and circulated mud 6.75 hrs prior to cement job. • Note: Two previous unsuccessful attempts were made to run casing. Both times casing was pulled due to not being able to work casing any further (lit run to 1,324' MD and 2nd run to 2,160' MD) and a cleanout run was performed. While making the 2nd cleanout run, it was discovered that wellbore was sidetracked the previous day while working casing. The lower section was then re -drilled to surface TD. Primary Cement Program: • Spacer: 40 bbis Chem Wash & 73 bbls Mud Push II • Dropped bottom plug • Lead Cement: 816.7 bbis 11.0 ppg DeepCrete Lead cement • Tail Cement: 65.5 bbis 12.0 ppg DeepCrete Tail cement • Dropped top plug • Displacement: 285.2 bbis • Plugs pumped. Floats held. • Pipe was reciprocated until loss in slack -off weight was observed. • Cement job summary: o No issues were seen while running casing. o No issues were seen while staging pumps up to circulating rate (7 bpm). o Pumped spacer program and start of lead slurry without any issues. o Reduced slack -off weight was also observed while reciprocating casing, so the casing hanger was landed out. Lost returns were observed with 580 bbis of lead cement away. Attempted to pick-up on hanger to help re-establish cement circulation, unable to move hanger. Leave hanger landed out. o The cement program was continued as per plan (finished pumping lead cement, tail cement, and displacement). o Lift pressure was observed while pumping displacement. o No issues maintaining cement density throughout job. o Prior to losses, 40 bbis of Mud Push was seen at surface. Top Job: • Based on a gauge hole, the volume of MudPush pumped, and the volume of Mud Push seen at surface (leaving —33 bbls in hole) it was anticipated the top of cement should be found —317' below surface. • The diverter and adapter were rippled down to gain access top of casing hanger. • A top job string of 3/4" pipe ("spaghetti" string) was ran down the annulus of the conductor and surface casing. • Top of cement was identified at 329.61' below surface (368.79' KB) at which pipe weight decreased and it became "sticky" to lift pipe back up. • Notifications were made to AOGCC. Approval was granted to proceed with top job. An AOGCC State Inspector was also called to witness the job. • Spaghetti string was pulled out of hole to mitigate plugging string while coordinating personnel and equipment for top job. • Spaghetti string was re -ran in the hole tagging up at 234.88' KB. Tag witnessed by AOGCC State Inspector. • 100 bbls fresh H2O was pumped to flush annulus followed by 113 bbls 11.0 ppg DeepCrete cement. 73 bbls of 11.0 ppg cement was observed at surface. Top job witnessed by AOGCC State Inspector. Shoe Test: • A successful shoe test was performed on surface shoe (FIT to 13.0 ppg). Cement Detail Report 3S-611 CotTocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 9/19/2018 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/4/2018 1230 10/4/2018 17:15 3S-611 Comment Line up & SLB pump 5 bbls of CW100. Pressure test lines to 4000 psi, good. Pump 35 bbls of CW100 @ 5.4 bpm, 169 psi, FO 18%, PU 169K, SO 116K. Pump 73.1 bbis of 10.5 ppg MP II @ 5 bpm, 100 psi, FO 18%. Drop bottom plug & start batching lead. Pump 816.7 bbls of 11.0 ppg lead cement at 3.4-6 bpm, 60-345 psi, FO 18%-0%, final PU 205K, SO 60K. CW 100 at surface with 520 bbis of lead away Land out casing with 570 bbis of lead away. Loose returns with 580 bbis of lead away. Pick up string to re-establish retums, no success. unable to land back out. Hanger .09' off landing ring. Pump 65.5 bbls of 12.0 ppg tail cement @ 3.4-5 bpm, 166-270 psi, FO 0%. Drop top plug & kick out with 10 bbis of fresh H2O. Swap to rig & displace w/ 10.0 ppg spud mud @ 8 bpm, 510-638 psi, FO 0%. Reduce rate to 3 bpm, 330 psi, FO 0%. Bump plug with 2730 strokes, 275.2 bbis pumped. Pressure up to 890 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 17:12 hrs. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Bum Plug? Surface Casing Cement 1 369.0 3,034.0 No 0.0 Yes Yes Q Pump Init (bbllm... IQ Pump Final (bbl/... IQ Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? I Stroke (fl) Rotated? I Pipe RPM (rpm) 2 12 5 330.0 890.0 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 CW 100. Pressure lest lines to 4000 psi, good. Pump 35 bbis of CW 100 @ 5.4 bpm, 169 psi, FO 18%, PU 169K, SO 116K. Pump 73.1 bbls of 10.5 ppg MP II @ 5 bpm, 100 psi, FO 18%. Drop bottom plug & start batching lead. Pump 816.7 bbls of 11.0 ppg lead cement at 3.4-6 bpm, 60-345 psi, FO 18%-0%, final PU 205K, SO 60K. CW100 at surface with 520 bbls of lead away. Land out casing with 570 bbls of lead away. Loose returns with 580 bbis of lead away. Pick up string to re-establish returns, no success. unable to land back out. Hanger .09' off landing ring. Pump 65.5 bbls of 12.0 ppg tail cement @ 3.4-5 bpm, 166-270 psi, FO 0%. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 10.0 ppg spud mud @ 8 bpm, 510-638 psi, FO 0%. Reduce rate to 3 bpm, 330 psi, FO 0%. Bump plug with 2730 strokes, 275.2 bbis pumped. Pressure up to 890 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 17:12 hrs. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Bon (ftKB) Amount (sacks) ClassVolume Pumped (bbl) CW100 40.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr t (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftK8) Est BVn (RKB) Amount (sacks) Class Volume Pumped (bbl) MudPushll 73.1 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cP) Thickening Time (hr) CmpStr 1 (psi) 10.50 Additives Additive Type Concentration Conic Unit label Fluid Fluid Type Fluid Descripgon Estimated Top (ftKB) Stm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail cement 2,534.0 JEst 3,034.0 223 G 65.5 Yield (W/sack) Mix H2O Ratio (gal/sa... Free Water I%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) Cmpstr 1 (psi) 1.65 5.60 12.00 97.9 3.75 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluitl Description ESUmaled Top fftKB) Est Bum (ft nn (sacks) Class Volume Pumped (bbl) Lead cement 368.0 2,534.0 2,401 G 816.7 Yield (ft'/sack) M . ix H2O Ratio (gal/sa.. Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.76 11.00 83.3 5.75 Additives Additive Type Concentration Conc Unit label Page 111 ReportPrinted: 10/8/2018 .. Cement Detail Report 3S-611 String: Surface Casing Cement Job: DRILLING ORIGINAL, 91191201800:00 Cement Details Description Cementing Start Date Cementing End Dale Wellbore Name Surface Casing Cement 10/5/2018 12:00 10/5/2018 15:15 3S-611 Comment TIH with .75" tubing down annulus & tag up on cement at 234.88' MD. Rig up cement lines to .75" pipe. Pump 100 bbls of fresh H2O flush at.75 bpm, 330 psi. Batch up & pump 113 bbls of 11 ppg DeepCrete cement at i bpm, 620 psi, with cement returns to surface. Cement Stages Stage # <Stage Number9> Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Ptug? Bum Plug? Surface Casing Cement Top job 0.0 234.0 Yes 73.0 No I No Top Job O Pump Init (bbllm... O Pump Final (bbl/.., O Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 1 1 i 620.0 No No 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 Btm (ftKB) Amo nit (sacks) Class Volume Pumped (bbl) Lead cement 0.0 234.0 332 G 113.0 Yield (ft-/sack) Min H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.76 11.00 83.3 5.75 Additives Additive Type Concentration Conc Unit label Page 1/1 ReportPrinted: 10/812018 MEMORANDUM TO: Jim Regg P. I. Supervisor FROM: Austin McLeod State of Alaska Alaska Oil and Gas Conservation Commission I�q DATE: Petroleum Inspector SUBJECT: 10/5/18 Surface Cement Top Job KRU 3S-611, Doyon 142 CPAI PTD 218-103 10/5/18: 1 traveled to Doyon 142 to witness their top job after no cement returns were observed at surface. Once on location I met up with Company Rep Rock Rauchenstein to discuss details. Prior to me arriving on location they ran a W string (muleshoe cut on bottom) outside of the 1 OW surface casing and tagged at 368 ft. Ready to proceed, the W string was run in the hole again and at 234 ft it came to a stop. Numerous attempts - were made trying to get deeper with no progress. This was done - 9 hours after the original tag. Rotating, pumping down the string via test pump, hoisting and lowering rapidly were all utilized and again no progress was made. It was now determined the top of cement in the conductor/open-hole by surface casing annulus was 234 ft (all measurements taken from rotary table). The calculated volume to fill the annular space to surface was approximately 20 bbls. Schlumberger was then rigged up and came online with water, seeing instant mud push/contaminated returns out of the conductor valves. The conductor by surface casing annulus was swept with 100 bbls of water. After batching 11 ppg Deeperete cement, Schlumberger pumped a total of 113 bbls, seeing good 11 ppg cement back at 40 bbls away. Returned fluid was weighed in 10 bbl intervals, seeing good 11 ppg cement returns throughout the remaining pump schedule. 2018-1005_Surface_Csg_Topjob_KRU_ 3S-611_am.docx Page 1 of 1 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, September 11, 2018 10:51 AM To: 'mike.mccracken@conocophillips.com' Subject: KRU 3S-611 (PTD 218-103) - Corrected AN Number on Permit to Drill Form Attachments: 2181030-KRU-3S-611-PTD-Form Corrected-API-20180911.pdf Mike, Attached is a scanned copy of the Permit to Drill form for KRU 3S-611 (PTD 218-103) containing a hand -correction to the API Number for the well. The API Number shown on this form changed from 50-103-20744-00-00 to 50-103-20774-00- 00. 1 made this error when I hand -wrote the API Number onto the form. The API Number for this well was entered correctly into the AOGCC's databases. Please accept my apology for this error. Regards, 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.davies@alaska.gov. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION OMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED AUG 0 8 2018 n nr1 � 1a. Type of Work:tb. Prhatoposed Well Class: Exploratory - Gas [IService - WAG Service - Disp E]1c. Speci Drill Q • Lateral ElSigraphic Test ❑ Development - Oil Q ' Service - Winj ❑ Single Zone Q • Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Q Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 KRU 35-611 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 18670 TVD: -5237 Kuparuk River Field Torok Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2505' FNL, 1013' FEL, Sec 18,'T 12N, R 08E, UM • ADL380107, ADL380106, ADL02552 5 Top of Productive Horizon: 8. DNR Approval Number:13. (� Approximate Spud Date: 1064' FNL, 4187' FEL, Sec 12, T 12N, R 07E, UM 932060000 932059000 931866000 9/9/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 510 FNL, 306FEL, Sec 2, T 12N, R 07E, UM 2447, 2437, 2560 510'to ADL355038 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10, KB Elevation above MSL (ft): 66.7' 15. Distance to Nearest Well Open Surface: x- 476246.87 • y- 5993909.98 ' - Zone -4 GL / BF Elevation above MSL (ft): 27.7' to Same Pool: 1035' to 3S-620 16. Deviated wells: Kickoff depth: 350 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 44 degrees Downhole: 2,150 psi • Surface: 1,638 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD (including stage data) 42" 20" 94# H-40 Welded 81 Surface 120 Installed 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 2963 Surface 1800 1192 sx 11.0 Lead, 191 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 12612 =Surface3002 Surface 5117 1243 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6019 12651 5237 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 21 No ❑ 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis e ® Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements8 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ben Tolman 6' ' Authorized Name: G. Alvord Contact Email: ben.v.tolman ce .corn Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6828 ' �ENWv114 p. lDaa• Authorized Signatu /i5 818 Commission Use Only Permit to Drill �/- r6 (i API Number `��T� �•r/-�, Permit Approval q i� See cover letter for other Number. 50- - 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: IV Other: 130P f« �- a -o SU OP S, ` �r Samples req'd: Yes ,_❑,/.NoE Mud log req'd: Yes❑ NoLvU 25400 easures: Yes Ly NOE] Directional svy req'd: Yes•L-K,/No❑ r.la r p/ c ✓L v1 ✓fr.5 Ile) J7 Inclination L'G yvi C n T/ e YGl 1 riq -/-r'a» b ct Spacing ex tion req'd: Yes ❑ NoLFEI• -only svy req'd: Yes❑ Nog ✓ Po l initlal injection MIT req'd: Yes❑ NoL7 af�cas ����,' ��1� 8r• Svbn .'t fio s+o�cc whrraYa,labtr „Ir/t� ccs cnt�o[z�rs�tts . APPROVED BY I I Approved by: - COMMISSIONER THE COMMISSION Date: t /� " v7L 6115-1 !® ///��� ^ /� ♦♦ Submit Foam and tt(j( �ipy 0401 Revised 512017 This permit is vall� i��/t�r� 0Re approval per 20 AAC 25.005(8 Attach encs In Duplicate THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Torok Oil Pool, KRU 3S-611 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-103 Surface Location: 2505' FNL, 1013' FEL, SEC. 18, TI 2N, R08E, UM Bottomhole Location: 510' FNL, 306' 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.00gcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development 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, Hollis S. French Chair DATED this day of September, 2018. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 8 2018 PERMIT TO DRILL 20 AAC 25.005 Ia. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas 0 Service- WAG Service -Disp ❑ 1c. Speci Drill El - Lateral ❑ Stratigraphic Test ❑ Development -Oil p - Service - Winj ❑ Single Zone ❑3 • Coalbed Gas El Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket ❑' Single Well ❑ 11. Well Name and Number: ConomPhillips Bond No. 59-52-180 KRU 3S-611 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 18670 TVD: .5237 Kuparuk River Field Torok Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2505' FNL, 1013' FEL, Sec 18, T 12N, R 08E, UM • ADL380107, ADL380106, ADL02552 Top of Productive Horizon: 8. DNR Approval Number: (� 13. Approximate Spud Date: 1064' FNL, 4187' FEL, Sec 12, T 12N, R 07E, UM 932060000 932059000 931866000 9/9/2018 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 510 FNL, 306' FEL, Sec 2, T 12N, R 07E, UM 2447, 2437, 2560 510'to ADL355038 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 66.7' 15. Distance to Nearest Well Open Surface: x- 476246.87 • y- 5993909.98 ' Zone -4 GL / BF Elevation above MSL (ft): 27.7' to Same Pool: 1035' to 3S-620 16. Deviated wells: Kickoff depth: 350 feet 17. Maximum Potential Pressures in pail (see 20 AAC 25.035) Maximum Hole Angle: 90.44 degrees Downhole: 2,150 psi • Surface: 1,638 psi 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f, or sacks Hole Casing Weight Grade Coupling Length MD I TVD MD TVD (including stage data) 42" 20" 94# Hao Welded 81 Surface Surface 120 120 Installed 13-1/2" 10-3/4" 45.5# L-80 Hyd 563 2963 Surface Surface 3002 ' 1800 1192 sx 11.0 Lead, 191 sx 12.0 Tail 9-7/8" 7-5/8" 29.7# L-80 Hyd 563 12612 Surface Surface 12651 5117 1243 sx 15.8 Class G 6-3/4" 4-1/2" 12.6# L-80 Hyd 563 6019 1 12651 5117 18670. 5237 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 B Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements8 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ben Tolman Authorized Name: G. Alvord Contact Email: ben.v.tolmanna.cop.corn Authorized Title: Alaska Drilling Manager Contact Phone: 907-265-6828 r �iENWvR4 fNJk{I.OSX�+' fd2 Authorized SignaturLI' cl, A 11/ Date: Commission Use Only Permit to Drill ///� ,/�� API Number: --7 _ ♦� �T Permit Approval See cover letter for other G �$ Number: C4/! 50- �� ( 7- �'r/ 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: mop fits f A0 SD bP t ` q Samples req'd: Yes ❑ Nod Mud log req'd: Yes ❑ NoLy fU 2500/J easures: Yes [{/ No[] Directionalsvyreq'd:Yes�L No,❑✓ hnu/ar /L✓G vt •5 Inclination req'd: Yes❑ No CO Spacing ex tion req'd: Yes ❑ Nol �J -only svy Ly C G Y✓rCrs7 eV'R lva tr'cr� Ivct �/ J 5- Post initial injection MIT req'd: Yes❑ No1r1 ihC I'n f-Cr.lrtcd 1a i-� CRS /'r T�� vl'rf c� /a o!` 1 Svb it a'o iF06CC Lvl c Le. val ia6/r I,to re- ,f-Ja(Yr-i-5 s APPROVED BY I / 11P_ Approved by: - COMMISSIONER THECOMMISSION Date: O V / {- q15 -11g J� l� �1� Submit Form and 0-401 Revised 512017 This permit is valigrq �Jr n;L-r� e 6f approval per 20 AAC 25.005(9 / Attach ents in Duplicate \V V 1R` V L ,��j�i/j�� r� { Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone(907)265-6828 Email: ben. v.tolman(a)conocophillips.com August 8, 2018 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Torok (Moraine) Producer, 3S-611 Dear Commissioner: Application for Permit to Drill, Well 3S-611 Saved: 8 -Aug -18 C01101Ip5 ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a single -lateral horizontal well in the Torok (Moraine) formation. The expected spud date for this well is September 9, 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 layout 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 nu,cop.com) or Chip Alvord at 907-265-6120. Si erely, ChipChip A vo ��rJFFL Drilling Manager i_aJ Application for Permit to Drill Document Torok (Moraine) Well 3S-611 Well Name Requirements of 20 AAC 25.005 (fl The well for which this application is submitted will be designated as KRU 35-611 Drilling -� B�Welis ConocoF'h➢lips Location Summary Requirements of 20 AAC 25.005(c)(2) An application /or a Permit to Drill must be accompanied by each of the follmring items, except far an item already on file ivith the commission and identified in the application: (2) a plat identf),ing the properp) and the property's owners and shoring (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system far this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface* 2505' FNL, 1013' FEL, Sec 18, T 12N, R08E, UM ' NGS Coordinates Northings: 5993909.98' Eastings: 476246.87' ' KB Elevation 66.T AMSL Pad Elevation 27.7' AMSL * Surface locationg based on as -staked survey. Suface locations will be re -surveyed once conductors have been set. Location at Surface Casing 1683 FNL, 1910' FEL, Sec 18, T12N R08E, UM NGS Coordinates Northings: 59947358.60' Eastings: 475349.65' i Measured De th,RKB: 3002' Total Vertical Depth, RKB: 2565' Total Vertical Depth, SS: 2498' Location at Intermediate Casing NGS Coordinates Northings: 6006499.67' Eastings: 466914.23' 1064' FNL, 4187' FEL, Sec 12, T12N, R07E, UM NGS Coordinates Northings: 6000660.65' Eastings: 468292.06' Measured De th, R/CB: 12651' Total Vertical De th, RKB: 5117' Total Vertical Depth, SS: 1 5050' Location at Total Depth 510' FNL, 306' FEL, Sec 2, T 12N, RO7E, UM NGS Coordinates Northings: 6006499.67' Eastings: 466914.23' I Measured Depth, RKB: 18670' Total Vertical DEEM,_- RKB5237' Total Vertical De th, SS: 5170' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated. the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale. showing the path of the proposed it ellbore. including all adjacent 11 ellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan And (2) far all it within 200 feet of the proposed wellbore (A) list the names of the operators of those is ells. to the extent that those names are known or discoverable in public records, and show that each maned operator has been furnished a copy of the application by certified mall: or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An applicalion for a Permit to Drill Hurst be accompanied by each of the following items, except for an item already on file wah the commission and identified in the application: (3) a diagram and description of the b1mi out prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 10 AAC 25.037, as applicable: Please reference BOP schematics on file for Doyon 142. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the follmring items, ezcepl for an item already on file with the commission and identified in the application: (4) information on drilling ha=ands, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it. and maximum potential surface pressure based on a methane gradient The maximum potential surface pressure (MPSP) while drilling 3S-611 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 Moraine Sand estimated depth = 5,117' TVD Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (e)(4)(A) 6� Q Hydrostatic of full gas column = 512 psi (5,117' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 1,638 psi (2,150 psi — 512 psi) 1 \J (B) data on potential gas cones; The wellbore is not expected to penetrate any shallow gas zones. 5l' � And (C) data concerning potential causes of hole problems such as abnormal/v geo-pressured strata. lost circulation zones, and cones that have a propensity, r differential slicking: See attached Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An applicalion fora Permit io Drill tuts! be accompanied by each of the following items, except for on item alr eady on file iwi li the commission and identified in the application: (5) a description of the procedure for conducting formation lntegray tests, as required under 20,4,4C25.03009; 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 for a Permit to Drill must be accompanied by each of the follairing items, except for an nen, already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 10 AAC 15.030, and a description of any slotted liner. pre -perforated liner, or screen to be installed Casing and Cement Program 10-3/4" Surface casing run to 1,826' MD / 1,743' 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 2,502' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119'— 0') x 1.364 ft3/ft x 1.0 (0% excess) = 162 ft' Bottom of Permafrost to Conductor (1,614'— 119') x 0.3637 ft3/ft x 3.00 (200% excess) = 1,631 ft3 Casing and Cementing Program (2,502'— 1,614') x 0.3637 ft3/ft x 1.50 (50% excess) = 484 ft' Total Volume = 162 + 1,631 + 484 = 2,277 ft' => 1192 sx of 11.0 ppg LiteCRETE @ 1.91 ft3/sit Hole Casing Weight Grade Coupling Length Top MD Top TVD Bottom MD Bottom TVD Cement Details 42" 20" 944 H-40 Welded 81 Surface Surface 120 , 120 Installed 13-1/2" 10-3/4" 45.54 L-80 Hyd 563 2963 Surface Surface 3,002. 1,800 1192 sx 11.0 Lead, 191 sx 12.0 Tail 9-7/8" 7-5/8" 29.79 L-80 Hyd 563 12,612 Surface Surface 12,651. 5,117 1243 sx 15.8 Class G 6-3/4" 4-1/2" 12.64 L-80 Hyd 563 6,019 12,651 5,117 18,670 5,237 N/A: Un -cemented liner 10-3/4" Surface casing run to 1,826' MD / 1,743' 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 2,502' MD to surface with Arctic LiteCRETE @ 11 ppg Conductor (119'— 0') x 1.364 ft3/ft x 1.0 (0% excess) = 162 ft' Bottom of Permafrost to Conductor (1,614'— 119') x 0.3637 ft3/ft x 3.00 (200% excess) = 1,631 ft3 Bottom of Lead to Permafrost (2,502'— 1,614') x 0.3637 ft3/ft x 1.50 (50% excess) = 484 ft' Total Volume = 162 + 1,631 + 484 = 2,277 ft' => 1192 sx of 11.0 ppg LiteCRETE @ 1.91 ft3/sit Tail slurry from 3,002' MD to 2,502 MD with DeepCREET @ 12 ppg Shoe to Top of Tail (3,002'— 2,502') x 0.3637 ft3/ft x 1.50 (50% excess) = 273 ft' Shoe Joint (80') x 0.5400 ft3/ft x 1.0 (0% excess) = 43 ft' Total Volume = 273 + 43 = 316 ft3 => 191 sx of 12.0 ppg DeepCRETE @ 1.65 ft3/sk 7-5/8" Production casing run to 12,651' MD / 5,117' TVD Single stage slurry is designed to be placed from TD to 7,751' MD, which is 250' TVD above top of K3 (Coyote / Nanushuk); 35% excess annular volume. Slurry from 12,651 MD to 7,751' MD with 15.8 ppg Class G + additives Shoe to Top of Cement (12,651'— 7,751') X 0.2148 Of: X 1.35 (35% excess) = 1421 ft' Shoe Joint (80') X 0.258 Oil X 1.0 (0% excess) =21 ft' Total Volume = 1421 + 21 = 1442 ft3 => 1243 sx of 15.8 ppg Class G @ 1.16 ft3/sk ( Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill most be accompanied by each of the following items, except for an item already on file mitt fire commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC25 035, unless this requirement is waived by the commission under 20 AAC 25,035(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 most be accompanied by each of 1he following items, except for an item already on file with the co n tassion and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,• 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 (WBM) LSND (WBM) Kla-Shield (WBM) Density 8.8-9.5 • 9.0-9.4 9.0-10.0 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 fora Permit to Drill must he accompanied by each of the following items. except for an item already on file mith the commission and idemified 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 Jus 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. -e- 7. - 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 @ +/- 7,751' MD (250' TVD minimum ✓ 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, and PWD). 16. RIH on DP to top of float equipment. Clean out any residual cement to top of float equipment. If not previously tested, test 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. Lay down production BHA. 21. PU and run 4-1/2", 12.6# liner with liner hanger/packer, swell packers, and frac sleeves. The top of liner will be placed at -12,451' (200'; overlap in the 7-5/8" casing). 22. Set liner hanger & packer. 23. PT liner top packer to 3,000 psi, chart results. 24. Flow check well. 25. POOH with liner running tools and lay down. 26. Run 4-1/2" upper completions. 27. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. 28. RDMO. Please Note - This well will be frac'd.r Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (e)(14) An application for a Permit to Drill music be accompanied by each of the follon ing items, except for an item abeady on fife will, the commission and identified in the application: (14) a general description of horn the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authonianon under 20 AAC 25.080 for an annular disposal operation in the well,; 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 1 B 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 Well Schematic _Attachment 2 Diverter Layout Diagram Attachment 3 Directional Plan Attachment 4 Drilling Hazards Summary I Moraine 3S-611wp05 Grass Roots Horizontal Multi -Stage Frac'd Producer ConocoPhillips Proposed Wellbore Schematic FMG 4-% tree. top joint is 4-%" 12.6# IBTM, crossed over (for frac equlpmenl) New Conductor: 20" Conductor @ 120' 500a co BB Nipple 8.8]5' 5oo 'MD 1 M I 13-112" Surface Hole ® ds• a- KBMG with Dummy II dv,'.r KBMG with Dummy 4'h"x1"K8MG wRM1 60V 10-3/4"45.5#L-80 Hydril 563/TXP 3 002' MD 12 565' TVD @ 60° SLB Gauge Canter Campanian SS d 5" x 9518", eakel Premier Pader •1 12251' MD 15011TVD - -. TDF rf _emantT]5 I11;3849'TVp . (B mlmmum 012$0' TVD abovetne K -S d'/a" Camco DB Nipple 3.812" nogo d /J'at"KBMG with Dummy Top K ] (Loyale) 4,099' TVD 2%P Itner sop packer 9-718" Intermediate Hole Tiu bin 4-'/," 12.6# L-80 Hydril 563 - k'..- w/RS Nipple.�H12d51' MDI5084' ND 4'G'x1"KBMGwilh Dummy : rOp Dr Mpralne s.l n' Tvo :'' Intermediate Casing Set -25' T' .I 7-5/8" 29.7# L-80 Hydril 563 19.5 4'h"x1"K8MG wRM1 60V SLB Gauge Canter d 5" x 9518", eakel Premier Pader •1 12251' MD 15011TVD d'/a" Camco DB Nipple 3.812" nogo 7-518' x 4-'/.' Baker Flex Lock Llner hanger 2%P Itner sop packer k'..- w/RS Nipple.�H12d51' MDI5084' ND : rOp Dr Mpralne s.l n' Tvo :'' Intermediate Casing Set -25' T' .I 7-5/8" 29.7# L-80 Hydril 563 _ 5° .. -. -12,651' MD / 5,117' TVD @ 75- 19.5 PPG n MegaTUNitlile• 0 6-314" 4 / Swell Packet Production Liner Production Hole (d -90 4-112" 12.6# HYD563 18,670' MD / 5,237' TVD DRILL SITE 3S El 6 4 3 2 1 191 171 1514 m 2 1 a 6 0 61 o s ❑ ❑❑❑❑ ❑❑❑❑❑ ❑❑ ❑ DS 3S PLOT PLAN Ppe1inP5 DRAWN BY: ALKET MICI SCALE 100 0 50 100 ConocoPhillipS TITLE: DRILL SITE 3S Alaska, Inc. DRAWN BY: ALKET MICI DAIS August 2010 REV: 1 Or 8 as ca ca 0 `o 02 201E 3S-611 WpO5 LmjPe= 10 3/4" x 13-1/2 Measured Depth 7-5/8" x 9-7/8" 4 1/2" x 6-31. o WELL C& 66.70usft (Doyon 142) ' 0 2500 ,, 5000 20" 10 3/4" x 13-1/2 12500 15000 r 7-5/8" x 9-7/8" 4 1/2" x 63/4" S 3 3S -612w;:05 MWO8000 MWD+IFB-AK CtZ SD MWD MWDJFRAK-GAZ-3C 2565.00 30001b0 103/4'.13 5116J0 12651.33 ]-5r8 x 9are" 5236.70 18669.5D 412" x 6-3/4" - Magnetic Model &Date: 8GGM2018 15 -Sep -18 Magnetic North is 16.841 East of True North (Magnetic Declination) Magnetic Dip &Field Strength: 80.88° 57434nT Sec MD 6 ( _ TVD aNl-S +EoVV 8 Equivalent Magnetic Distance - AnnMatbn Uthology Column 1 39.00 0.00 0.00 39.00 2W -p65 0.00 0.00 0.00 0.00 0 r� 0.00 0.00 350.00 0.00 0.00 0 2500 5000 7500 10000 12500 15000 17500 WNh From Dgxh To Survgl%an Tool East/X: 39.00 68000 3S611wp851Plw3ladn GYD GD -SS pad Elevation: 27]0 eKnOO 16MM 3S611wp051PIan:3S811) MWD 600.00 301 3S6llwp051PIan:3S611) MWDdF6-A&WW TVD MD 240 Plan Summ 3301.50 450150 3S-611) 3301.5012651.33 3S611wp051Ran: W-611) 12551,33;41 1,33 3561twool plan:3S611) 12651.3318869.50 3S6llwp05 (Pl., 3S dl) MWO8000 MWD+IFB-AK CtZ SD MWD MWDJFRAK-GAZ-3C 2565.00 30001b0 103/4'.13 5116J0 12651.33 ]-5r8 x 9are" 5236.70 18669.5D 412" x 6-3/4" - Magnetic Model &Date: 8GGM2018 15 -Sep -18 Magnetic North is 16.841 East of True North (Magnetic Declination) Magnetic Dip &Field Strength: 80.88° 57434nT Sec MD 1. Azi TVD aNl-S +EoVV Dleg Trace VSect Target AnnMatbn Uthology Column 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 r� 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 KOP: Blatt 1.51100' DLS, 315' TF. or 300' 3 650.00 4.50 315.00 649.69 8.33 .8.33 1.50 315.00 11.65 -Id' 4 1671.39 30.03 315.00 161 ].00 220.94 220.94 2.50 0.00 309.21 Hold for 115.51' �4I 51]86.81 �4 315.00 1]1].00 261.82 -261.82 0.00 0.00 366.43 Start 2.51100'DLS,-10°T5for 1214.6' Iyp UppnuC `pq,Pennafrl 6 3001.50 60.15 309.19 2565.00 822.78 899.99 2.50 -10.00 1197.69 Hold for 20' I44i 7 3021.50 60.15 309.19 2574.96 833]5 413.43 000 0.00 1214.51 Start 31109 DLS,-].OB°TF, for 503.63' ns pP llJgnutl 8 3525.13 ]5.15 f 2765.94 1120.87 -1278AB 3.00 �7.08 1662.96 Hold for 78632 Top Ugnu A 911388.34 75.15 I 4780.81 5725.27 -7325]7 000 0.00 8969.97 Stan 3710V DL8, 95.21 'TF, for 1263' mm 1012651.33 75.16 34654 5116.70 6725.43 -7977.49 3.00 95.2110161.31 35611 TO1.0 Heel Update 072718 I'Mold for 375' TO West Bak 11 13026.33 75.16 346.54 5212]5 ]0]7.96 -8061.89 0.00 0.0010494.31 Stan 31100' DLS, 0° TF, for 494.67' P 1213521.00 90.00 34654 527645 7553.67 -8175.78 300 0.0010943.67 Adjust TF to 0', for 14.77' u 13 1353537 9044 34654 5276.39 7568.03 -8179.22 3.00 0.0010957.23 Hold for 5133.74' Base West Sa 1418669.50 90.44 34654 5236.70 12560.53 -9374.48 000 0.0015673.15 3S-611 T020 T. 120717 PP TD: 18669.5'MD, 52X.7'TVD an, 3301.50 450150 3S-611) 3301.5012651.33 3S611wp051Ran: W-611) 12551,33;41 1,33 3561twool plan:3S611) 12651.3318869.50 3S6llwp05 (Pl., 3S dl) MWO8000 MWD+IFB-AK CtZ SD MWD MWDJFRAK-GAZ-3C 2565.00 30001b0 103/4'.13 5116J0 12651.33 ]-5r8 x 9are" 5236.70 18669.5D 412" x 6-3/4" - Magnetic Model &Date: 8GGM2018 15 -Sep -18 Magnetic North is 16.841 East of True North (Magnetic Declination) Magnetic Dip &Field Strength: 80.88° 57434nT Sec MD 1. Azi TVD aNl-S +EoVV Dleg Trace VSect Target AnnMatbn Uthology Column 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 350.00 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 KOP: Blatt 1.51100' DLS, 315' TF. or 300' 3 650.00 4.50 315.00 649.69 8.33 .8.33 1.50 315.00 11.65 Stan 2.51100' DLS, 0' TF, for 1021.39' 4 1671.39 30.03 315.00 161 ].00 220.94 220.94 2.50 0.00 309.21 Hold for 115.51' �4I 51]86.81 30.03 315.00 1]1].00 261.82 -261.82 0.00 0.00 366.43 Start 2.51100'DLS,-10°T5for 1214.6' Iyp UppnuC `pq,Pennafrl 6 3001.50 60.15 309.19 2565.00 822.78 899.99 2.50 -10.00 1197.69 Hold for 20' I44i 7 3021.50 60.15 309.19 2574.96 833]5 413.43 000 0.00 1214.51 Start 31109 DLS,-].OB°TF, for 503.63' ns pP llJgnutl 8 3525.13 ]5.15 307.29 2765.94 1120.87 -1278AB 3.00 �7.08 1662.96 Hold for 78632 Top Ugnu A 911388.34 75.15 307.29 4780.81 5725.27 -7325]7 000 0.00 8969.97 Stan 3710V DL8, 95.21 'TF, for 1263' mm 1012651.33 75.16 34654 5116.70 6725.43 -7977.49 3.00 95.2110161.31 35611 TO1.0 Heel Update 072718 I'Mold for 375' TO West Bak 11 13026.33 75.16 346.54 5212]5 ]0]7.96 -8061.89 0.00 0.0010494.31 Stan 31100' DLS, 0° TF, for 494.67' P 1213521.00 90.00 34654 527645 7553.67 -8175.78 300 0.0010943.67 Adjust TF to 0', for 14.77' u 13 1353537 9044 34654 5276.39 7568.03 -8179.22 3.00 0.0010957.23 Hold for 5133.74' Base West Sa 1418669.50 90.44 34654 5236.70 12560.53 -9374.48 000 0.0015673.15 3S-611 T020 T. 120717 PP TD: 18669.5'MD, 52X.7'TVD an, C-80 Surface Location is subject to Change C-50 .35 pp Coyote Base Coyote ,,,Tap Torok Oil By signirg this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured its completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.l approve it as Me basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 1 W feet lateral tolerance. repared by hecked by ccepted by Approved by: B. Temple V. Osara E. Sterk B. Tolman 8:29, A ust 02 2018 3S-611 wp05 39.00 To 18669.50 Spider ---3S-611wp05 c 0 N_ m C L C z 3S-613 620 3S-06 3S-06A 3S-09 3S-15 3S-10 `Nfrna e 1 3S-17 3 -14 35-26 3S-17A 35- -18 5-19 -16 08 Easting (2500 usft/in) 91 3S-611 wp05 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 12500 - 4 1/2" x 6-3/4"--- 16670 1g000 3S-611 T02.0 Toe 120717 P 17000 10000 160p0 ------ 3S-611 T01.5 Mid Update 072718 P 15p00 14000 +7500 13000 3S-611 T01.0 Heel Update 072718 P z7-5/8" z x 9-7/8"--- , --- °o O 0 U)5000 o °o o° 00 o° o° °o 2500 y°oo o° �o o° 00 0 °00 10 3/4" x 13-1/2-----� 0 20" -12500 -10000 -7500 -5000 -2500 0 2500 West( -)/East(+) 1 3S-611 wp05 Section View 0 0 20 0 Top Ugnu C /Base Permafrost Top" Ugnu B 900 X000 Top Ugnu A Top West Sak Base West Sak 1800 2o�p -' C-80 n o" --------- C? C-50 x2700 --- ----._..._,-_ p , , � o 10 3/4" x 13-1/2 0 " C-35 F o Top Coyote (Top Nanushuk), K3 R•I1 4500 0 N -_.----..... ..------ --..._.....-------- 5400 --- 7-5/8" x 9-7/8_ 0 2000 4000 6000 8000 10000 0 1200 0 1 Vertical Section at 323.260 D� I o 816000 4 1/2': x I Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-611 50029xxxxx00 Plan: 3S-611 Plan: 3S-611 wp05 Standard Proposal Report 02 August, 2018 ConocoPhillips ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 3S Pad Well: Plan: 3S-611 Wellbore: Plan: 3S-611 Desian: 35-611wp05 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 35-611 TVD Reference: WELL @ 66.70usft (Doyon 142) MD Reference: WELL @ 66.70usft (Doyon 142) Norm Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Using Well Reference Point Geo Datum: Using geodetic scale factor Map Zone: Site Kuparuk 3S Pad Site Position: es: Northing: From: Map Easting: Position Uncertainty: Tie On Depth: 0.00 usft Slot Radius: Well Plan: 3S-611 -NAS +EI -W Well Position +NI -S 66.31 usft Northing: (usft) +E/ -W -208.36 usft Easting: Position Uncertainty 0.00 0.00 usft Wellhead Elevation: Latitude: Longitude: 0" Grid Convergence: -0.18, Latitude: Longitude: 0.00 usft Ground Level: 27.70 usft Shore Plan: 3S-611 gnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM201B 9/15/2018 16.84 80.88 57,434 35-611Wp05 es: Phase: PLAN Tie On Depth: 39.00 ection: Fmi Depth From (TVD) -NAS +EI -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 323.26 8/22018 651:4IAM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kupamk 3S Pad North Reference: Well: Plan: 35-611 Survey Calculation Method: Wellbore: Plan: 3S-611 GYD-GC-SS Design: 35-611wp05 Depth Plan Survey Tool Program Date 8/2/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,20000 3S-611wp05(Plan: 3S-611) GYD-GC-SS Turn Depth Inclination Gyrodata gyro single shots 2 1,200.00 2,200.00 3S-611wp05(Plan: 3S-611) MWD Rate TFO (usft) (°) MWD - Standard 3 1,200.00 3,001.50 35-611wp05(Plan: 3S-611) MWD+IFR-AK-CAZ-SC (°1100usit) V) Target 39.00 0.00 MWD+IFR AK CAZ SCC 4 3,001.50 4,501.50 35-611wp05(Plan: 3S-611) MWD 0.00 0.00 350.00 0.00 MWD - Standard 5 3,001.50 12,651.33 3S-611wp05(Plan: 3S-611) MWD+IFR-AK-CAZ-SC 0.00 0.00 650.00 4.50 MWD+IFR AK CAZ SCC 6 12,651.33 14,151.33 35-61 lwp05(Plan: 3S-611) MWD 0.00 315.00 1,671.39 30.03 MWD - Standard 7 12,651.33 18,669.50 35-611wp05(Plan: 3S-611) 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: 35-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NIS +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usit) V) 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 4.50 315.00 649.69 8.33 -8.33 1.50 1.50 0.00 315.00 1,671.39 30.03 315.00 1,617.00 220.94 -220.94 2.50 2.50 0.00 0.00 1,786.91 30.03 315.00 1,717.00 261.82 -261.82 0.00 0.00 0.00 0.00 3,001.50 60.15 309.19 2,565.00 822.78 -899.99 2.50 2.48 -0.48 -10,00 3,021.50 60.15 309.19 2,574.96 833.75 -913.43 0.00 0.00 0.00 0.00 3,525.13 75.15 307.29 2,765.94 1,120.87 -1,278.48 3.00 2.98 -0.38 -7.08 11,388.34 75.15 307.29 4,780.81 5,725.27 -7,325.77 0.00 0.00 0.00 0.00 12,651.33 75.16 346.54 5,116.70 6,725.43 -7,977.49 3.00 0.00 3.11 95.21 35-611 T01.0 Heel UI 13,026.33 75.16 346.54 5,212.75 7,077.96 -8,061.89 0.00 0.00 0.00 0.00 13,521.00 90.00 346.54 5,276.45 7,553.67 -8,175.78 3.00 3.00 0.00 0.00 13,535.77 90.44 346.54 5,276.39 7,568.03 -8,179.22 3.00 3.00 0.00 0.00 18,669.50 90.44 346.54 5,236.70 12,560.53 -9,374.48 0.00 0.00 0.00 0.00 35-611 T02.0 Toe 12( 822018 6:51.:41AM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 35-611 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: WELL @ 66.70usft (Doyon 142) Project: Kuparuk River Unit MD Reference: WELL @ 66.70usft (Doyon 142) Site: Kuparuk 3S Pad North Reference: True Well: Plan: 3S-611 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3S-611 (^) (usft) Design: 35-611wp05 (usft) (°HOOusk Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/S rEl-W Section Rate Rate Rate (usft) O (^) (usft) (usft) (usft) (usft) (°HOOusk 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 0.00 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 0.00 400.00 0.75 315.00 400.00 0.23 -0.23 0.32 1.50 1.50 0.00 500.00 2.25 315.00 499.96 2.08 -2.08 2.91 1.50 1.50 0.00 600.00 3.75 315.00 599.82 5.78 -5.78 8.09 1.50 1.50 0.00 650.00 4.50 315.00 649.69 B.33 -8.33 11.65 1.50 1.50 0.00 700.00 5.75 315.00 699.49 11.48 -11.48 16.07 2.50 2.50 0.00 800.00 8.25 315.00 798.74 20.10 -20.10 28.13 2.50 2.50 0.00 900.00 10.75 315.00 897.36 31.77 -31.77 44.46 2.50 2.50 0.00 1,000.00 13.25 315.00 995.17 46.47 -46.47 65.04 2.50 2.50 0.00 1,100.00 15.75 315.00 1,091.97 64.17 -64.17 89.81 2.50 2.50 0.00 1,200.00 18.25 315.00 1,187.60 84.85 -84.85 118.75 2.50 2.50 0.00 1,300.00 20.75 315.00 1,281.85 108.45 -108.45 151.78 2.50 2.50 0.00 1,400.00 23.25 315.00 1,374.56 134.93 -134.93 188.85 2.50 2.50 0.00 1,500.00 25.75 315.00 1,465.55 164.26 -164.26 229.88 2.50 2.50 0.00 1,600.00 28.25 315.00 1,554.65 196.36 -196.36 274.80 2.50 2.50 0.00 1,671.39 30.03 315.00 1,617.00 220.94 -220.94 309.21 2.50 2.50 0.00 1,700.00 30.03 315.00 1,641.76 231.06 -231.06 323.38 0.00 0.00 0.00 1,786.91 30.03 315.00 1,717.00 261.82 -261.82 366.43 0.00 0.00 0.00 1,800.00 30.36 314.89 1,728.32 266.47 -266.48 372.94 2.50 2.46 -0.86 1,900.00 32.82 314.09 1,813.49 303.17 -303.86 424.71 2.50 2.47 -0.79 2,000.00 35.29 313.40 1,896.33 341.88 -344.32 479.93 2.50 2.47 -0.69 2,100.00 37.77 312.79 1,976.68 382.54 -387.78 538.51 2.50 2.47 -0.61 2,200.00 40.24 312.24 2,054.39 425.06 -434.18 600.34 2.50 2.48 -0.55 2,300.00 42.72 311.74 2,129.30 469.36 383.41 665.29 2.50 2.48 -0.50 2,400.00 45.20 311.29 2,201.28 515.37 -535.39 733.24 2.50 2.48 -0.45 2,500.00 47.68 310.88 2,270.18 562.98 -590.01 804.07 2.50 2.48 -0.41 2,600.00 50.17 310.49 2,335.89 612.12 -647.17 877.64 2.50 2.48 -0.38 2,700.00 52,65 310.14 2,398.26 662.68 -706.76 953.80 2.50 2.48 -0.36 2,800.00 55.14 309.81 2,457.18 714.57 -768.67 1,032.42 2.50 2.49 -0.33 2,900.00 57.62 309.49 2,512.55 767.70 -832.79 1,113.35 2.50 2.49 -0.31 3,000.00 60.11 309.20 2,564.25 821.96 -898.98 1,196.42 2.50 2.49 -0.30 3,001.50 60.15 309.19 2,565.00 822.78 -699.99 1,197.69 2.50 2.49 -0.29 3,021.50 60.15 309.19 2,574.96 833.75 -913.43 1,214.51 0.00 0.00 0.00 3,100.00 62.48 308.86 2,612.63 877.10 -966.93 1,281.25 3.00 2.98 -0.42 3,200.00 65.46 308.47 2,656.51 933.23 -1,037.08 1,368.20 3.00 2.98 -0.40 3,300.00 68.44 308.09 2,695.65 990.23 -1,109.31 1,457.08 3.00 2.98 -0.38 3,400.00 71.42 307.72 2,729.96 1,047.92 -1,183.42 1,547.64 3.00 2.98 -0.36 3,500.00 74.40 307.37 2,759.34 1,106.17 -1,259.20 1,639.64 3.00 2.98 -0.35 3,525.13 75.15 307.29 2,765.94 1,120.87 -1,278.48 1,662.96 3.00 2.98 -0.34 3,600.00 75.15 307.29 2,785.12 1,164.71 -1,336.06 1,732.53 0.00 0.00 0.00 3,700.00 75.15 307.29 2,810.75 1,223.27 -1,412.96 1,625.46 0.00 0.00 0.00 3,800.00 75.15 307.29 2,836.37 1,281.82 -1,489.87 1,918.39 0.00 0.00 0.00 3,900.00 75.15 307.29 2,862.00 1,340.38 -1,566.78 2,011.31 0.00 0.00 0.00 4,000.00 75.15 307.29 2,887.62 1,398.94 -1,643.68 2,104.24 0.00 0.00 0.00 4,100.00 75.15 307.29 2,913.24 1,457.49 -1,720.59 2,197.17 0.00 0.00 0.00 4,200.00 75.15 307.29 2,938.87 1,516.05 -1,797.50 2,290.09 0.00 0.00 0.00 4,300.00 75.15 307.29 2,964.49 1,574.61 -1,874.40 2,383.02 0.00 0.00 0.00 4,400.00 75.15 307.29 2,990.12 1,633.16 -1,951.31 2,475.95 0.00 0.00 0.00 4,500.00 75.15 307.29 3,015.74 1,691.72 -2,028.21 2,568.87 0.00 0.00 0.00 4,600.00 75.15 307.29 3041.36 1750.27 -2,105.12 2661.80 0.00 0.00 0.00 822018 6:51:41AM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 Local Co-ordinate Reference: Well Plan: 3S-611 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: WELL @ 66.70usft (Doyon 142) Project: Kuparuk River Unit MD Reference: WELL @ 66.70usft (Doyon 142) Site: Kuparuk 3S Pad North Reference: True Well: Plan: 35-611 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3S-611 Azimuth Depth Design: 35-611 wp05 Section Rate Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +EFW Section Rate Rate Rate (usft) (') (I (usft) (usft) (usft) (usft) (.1100usft) (°1100usft) (°/100usft) 10,100.00 75.15 307.29 4,450.69 4,970.87 -6,334.96 7,772.76 0.00 0.00 0.00 10,200.00 75.15 307.29 4,476.31 5,029.43 -6,411.87 7,865.69 0.00 0.00 0.00 10,300.00 75.15 307.29 4,501.94 5,087.98 -6,488.78 7,958.62 0.00 0.00 0.00 10,400.00 75.15 307.29 4,527.56 5,146.54 -6,565.68 8,051.54 0.00 0.00 0.00 10,500.00 75.15 307.29 4,553.19 5,205.10 -6,642.59 8,144.47 0.00 0.00 0.00 10,600.00 75.15 307.29 4,578.81 5,263.65 -6,719.49 8,237.40 0.00 0.00 0.00 10,700.00 75.15 307.29 4,604.43 5,322.21 -6,796.40 8,330.32 0.00 0.00 0.00 10,800.00 75.15 307.29 4,630.06 5,380.76 -6,873.31 8,423.25 0.00 0.00 0.00 10,900.00 75.15 307.29 4,655.68 5,439.32 -6,950.21 8,516.18 0.00 0.00 0.00 11,000.00 75.15 307.29 4,681.31 5,497.88 -7,027.12 8,609.10 0.00 0.00 0.00 11,100.00 75.15 307.29 4,706.93 5,556.43 -7,104.03 8,702.03 0.00 0.00 0.00 11,200.00 75.15 307.29 4,732.55 5,614.99 -7,180.93 8,794.96 0.00 0.00 0.00 11,300.00 75.15 307.29 4,758.18 5,673.55 -7,257.84 8,887.88 0.00 0.00 0.00 11,388.34 75.15 307.29 4,780.81 5,725.27 -7,325.77 8,969.97 0.00 0.00 0.00 11,400.00 75.12 307.65 4,783.81 5,732.13 -7,334.72 8,980.82 3.00 -0.27 3.09 11,500.00 74.87 310.74 4,809.70 5,793.16 -7,409.57 9,074.50 3.00 -0.25 3.10 11,600.00 74.67 313.84 4,835.97 5,858.08 -7,480.94 9,169.21 3.00 -0.20 3.10 11,700.00 74.51 316.95 4,862.55 5,926.71 -7,548.62 9,264.70 3.00 -0.16 3.11 11,800.00 74.39 320.06 4,889.36 5,998.86 -7,612.44 9,360.89 3.00 -0.12 3.11 11,900.00 74.32 323.18 4,916.34 6,074.33 -7,672.22 9,456.93 3.00 -0.07 3.11 12,000.00 74.29 326.29 4,943.40 6,152.93 -7,727.80 9,553.15 3.00 -0.03 3.12 12,100.00 74.30 329.41 4,970.48 6,234.42 -7,779.01 9,649.10 3.00 0.01 3.12 12,200.00 74.36 332.52 4,997.50 6,318.59 -7,825.73 9,744.50 3.00 0.06 3.12 12,300.00 74.46 335.64 5,024.38 6,405.21 -7,867.83 9,839.09 3.00 0.10 3.11 12,400.00 74.61 338.75 5,051.06 6,494.04 -7,905.18 9,932.63 3.00 0.15 3.11 12,500.00 74.79 341.85 5,077.45 6,584.84 -7,937.69 10,024.84 3.00 0.19 3.10 12,600.00 75.03 344.95 5,103.49 6,677.35 -7,965.27 10,115.47 3.00 0.23 3.10 12,651.33 75.16 346.54 5,116.70 6,725.43 -7,977.49 10,161.31 3.00 0.26 3.09 12,700.00 75.16 346.54 5,129.16 6,771.18 -7,988.44 10,204.53 0.00 0.00 0.00 12,800.00 75.16 346.54 5,154.78 6,865.19 -8,010.95 10,293.33 0.00 0.00 0.00 12,900.00 75.16 346.54 5,160.39 6,959.20 -8,033.46 10,382.12 0.00 0.00 0.00 13,000.00 75.16 346.54 5,206.00 7,053.20 -8,055.96 10,470.92 0.00 0.00 0.00 13,026.33 75.16 346.54 5,212.75 7,077.96 -8,061.89 10,494.31 0.00 0.00 0.00 13,100.00 77.37 346.54 5,230.24 7,147.55 -8,078.55 10,560.04 3.00 3.00 0.00 13,200.00 80.37 346.54 5,249.54 7,242.96 -8,101.39 10,650.17 3.00 3.00 0.00 13,300.00 83.37 346.54 5,263.68 7,339.22 -8,124.44 10,741.10 3.00 3.00 0.00 13,400.00 86.37 346.54 5,272.62 7,436.07 -8,147.63 10,832.59 3.00 3.00 0.00 13,500.00 89.37 346.54 5,276.33 7,533.25 -8,170.89 10,924.38 3.00 3.00 0.00 13,521.00 90.00 346.54 5,276.45 7,553.67 -8,175.78 10,943.67 3.00 3.00 0.00 13,535.77 90.44 346.54 5,276.39 7,568.03 -8,179.22 10,957.23 3.00 3.00 0.00 13,600.00 90.44 346.54 5,275.90 7,630.50 -8,194.17 11,016.24 0.00 0.00 0.00 13,700.00 90.44 346.54 5,275.12 7,727.75 -8,217.46 11,108.10 0.00 0.00 0.00 13,800.00 90.44 346.54 5,274.35 7,824.99 -8,240.74 11,199.96 0.00 0.00 0.00 13,900.00 90.44 346.54 5,273.58 7,922.24 -8,264.02 11,291.82 0.00 0.00 0.00 14,000.00 90.44 346.54 5,272.80 8,019.49 -8,287.30 11,383.68 0.00 0.00 0.00 14,100.00 90.44 346.54 5,272.03 8,116.74 -8,310.58 11,475.54 0.00 0.00 0.00 14,200.00 90.44 346.54 5,271.26 8,213.99 -8,333.87 11,567.41 0.00 0.00 0.00 14,300.00 90.44 346.54 5,270.48 8,311.24 -8,357.15 11,659.27 0.00 0.00 0.00 14,400.00 90.44 346.54 5,269.71 8,408.49 -8,380.43 11,751.13 0.00 0.00 0.00 14,500.00 90.44 346.54 5,268.94 8,505.74 -8,403.71 11,842.99 0.00 0.00 0.00 14,600.00 90.44 346.54 5,268.16 8,602.99 -8,427.00 11,934.85 0.00 0.00 0.00 14,700.00 90.44 346.54 5,267.39 8,700.23 -8,450.28 12,026.71 0.00 0.00 0.00 14,800.00 90.44 346.54 5,266.62 8,797.48 -8,473.56 12,118.57 0.00 0.00 0.00 14,900.00 90.44 346.54 5265.84 8,894.73 -8,496.84 12,210.43 0.00 0.00 0.00 8/2/2018 6:51: 41AM Page 6 COMPASS 5000.14 Build 85 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP2 local Coordinate Reference: Well Plan: 35-611 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: WELL @ 66.70usft (Doyon 142) Project: Kuparuk River Unit MD Reference: WELL @ 66.70usft (Doyon 142) Site: Kuparuk 3S Pad North Reference: True Well: Plan: 35-611 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 3S-611 Design: 35-611wp05 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +10414 +E/ -W Section Rate Rate Rate (usft) (°) (I (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) ("1100usft) 15,000.00 90.44 346.54 5,265.07 8,991.98 -8,520.13 12,302.30 0.00 0.00 0.00 15,100.00 90.44 346.54 5,264.30 9,089.23 -8,543.41 12,394.16 0.00 0.00 0.00 15,200.00 90.44 346.54 5,263.52 9,186.48 -8,566.69 12,466.02 0.00 0.00 0.00 15,300.00 90.44 346.54 5,262.75 9,263.73 -8,589.97 12,577.88 0.00 0.00 0.00 15,400.00 90.44 346.54 5,261.98 9,380.98 -8,613.26 12,669.74 0.00 0.00 0.00 15,500.00 90.44 346.54 5,261.21 9,478.22 -6,636.54 12,761.60 0.00 0.00 0.00 15,600.00 90.44 346.54 5,260.43 9,575.47 -8,659.82 12,853.46 0.00 0.00 0.00 15,700.00 90.44 346.54 5,259.66 9,672.72 -8,683.10 12,945.33 0.00 0.00 0.00 15,800.00 90.44 346.54 5,258.89 9,769.97 -8,706.39 13,037.19 0.00 0.00 0.00 15,900.00 90.44 346.54 5,258.11 9,867.22 -8,729.67 13,129.05 0.00 0.00 0.00 16,000.00 90.44 346.54 5,257.34 9,964.47 -8,752.95 13,220.91 0.00 0.00 0.00 16,100.00 90.44 346.54 5,256.57 10,061.72 -8,776.23 13,312.77 0.00 0.00 0.00 16,200.00 90.44 346.54 5,255.79 10,158.97 -8,799.52 13,404.63 0.00 0.00 0.00 16,300.00 90.44 346.54 5,255.02 10,256.22 -8,622.80 13,496.49 0.00 0.00 0.00 16,400.00 90.44 346.54 5,254.25 10,353.46 -8,846.08 13,588.36 0.00 0.00 0.00 16,500.00 90.44 346.54 5,253.47 10,450.71 -8,869.36 13,680.22 0.00 0.00 0.00 16,600.00 90.44 346.54 5,252.70 10,547.96 -8,892.65 13,772.08 0.00 0.00 0.00 16,700.00 90.44 346.54 5,251.93 10,645.21 -8,915.93 13,863.94 0.00 0.00 0.00 16,800.00 90.44 346.54 5,251.15 10,742.46 -8,939.21 13,955.80 0.00 0.00 0.00 16,900.00 90.44 346.54 5,250.38 10,839.71 -8,962.49 14,047.66 0.00 0.00 0.00 17,000.00 90.44 346.54 5,249.61 10,936.96 -8,985.78 14,139.52 0.00 0.00 0.00 17,100.00 90.44 346.54 5,248.83 11,034.21 -9,009.06 14,231.38 0.00 0.00 0.00 17,200.00 90.44 346.54 5,248.06 11,131.45 -9,032.34 14,323.25 0.00 0.00 0.00 17,300.00 90.44 346.54 5,247.29 11,228.70 -9,055.62 14,415.11 0.00 0.00 0.00 17,400.00 90.44 346.54 5,246.52 11,325.95 -9,078.90 14,506.97 0.00 0.00 0.00 17,500.00 90.44 346.54 5,245.74 11,423.20 -9,102,19 14,598.83 0.00 0.00 0.00 17,600.00 90.44 346.54 5,244.97 11,520.45 -9,125.47 14,690.69 0.00 0.00 0.00 17,700.00 90.44 346.54 5,244.20 11,617.70 -9,148.75 14,782.55 0.00 0.00 0.00 17,800.00 90.44 346.54 5,243.42 11,714.95 -9,172.03 14,874.41 0.00 0.00 0.00 17,900.00 90.44 346.54 5,242.65 11,812.20 -9,195.32 14,966.28 0.00 0.00 0.00 18,000.00 90.44 346.54 5,241.88 11,909.44 -9,218.60 15,058.14 0.00 0.00 0.00 18,100.00 90.44 346.54 5,241.10 12,006.69 -9,241.88 15,150.00 0.00 0.00 0.00 18,200.00 90.44 346.54 5,240.33 12,103.94 -9,265.16 15,241.86 0.00 0.00 0.00 18,300.00 90.44 346.54 5,239.56 12,201.19 -9,288.45 15,333.72 0.00 0.00 0.00 18,400.00 90.44 346.54 5,238.78 12,298.44 -9,311.73 15,425.58 0.00 0.00 0.00 18,500.00 90.44 346.54 5,238.01 12,395.69 -9,335.01 15,517.44 0.00 0.00 0.00 18,600.00 90.44 346.54 5,237.24 12,492.94 -9,358,29 15,609.31 0.00 0.00 0.00 18,669.50 90.44 346.54 5,236.70 12,560.53 -9,374,48 15,673.15 0.00 0.00 0.00 812V2018 6."51:41AM Page 7 COMPASS 5000.14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: Plan: 3S-611 Wellbore: Plan: 3S-611 Design: 35-611wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Design Targets Vertical Target Name Depth -hitimiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing -Shape (°) (°) (usft) (usft) (usft) (usft) 35-611 T01.0 Heel UP& 0.00 0.00 5,116.70 - plan hits target center 20" - Circle (radius 100.00) 2,565.00 35-611 T02o Toe 12071 0.00 0.00 5,236.70 - plan hits target center 7-5/8"x 9-7/8" -Circle (radius 100.00) 5,236.70 35-611 T01.0 Heel 1207 0.00 0.00 5,276.70 - plan misses target center by 154.66usft at 12692.31 usft MD (5127.20 TVD, 6763.95 N. -7986.71 E) - Circle (radius 100.00) 2,418.70 35-611 T01.5 Mid Updat 0.00 0.00 5,276.70 - plan misses target center by 16.81 usft at 15669.29usft MD (5259.90 TVD, 9642.86 N. -8675.95 E) - Circle (radius 100.00) 3,325.70 Casing Points Formations Measured Vertical 10-3/4 Depth Depth 9-7/8 (usft) (usft) Name 80.00 80.00 20" 3,001.50 2,565.00 10 3/4" x 13-1/2 12,651.33 5,116.70 7-5/8"x 9-7/8" 18,669.50 5,236.70 4 1/2" x 6-3/4" Measured Vertical 10-3/4 Depth Depth 9-7/8 (usft) (usft) Name 1,428.52 1,400.70 Top Ugnu C 1,613.71 1,566.70 Base Permafrost 1,662.60 1,626.70 Top Ugnu B 1,834.20 1,75270 Top UgnuA 2,149.77 2,015.70 Top West Bak 2,734.03 2,418.70 Base West Bak 3,229.87 2,668.70 C-80 5,709.64 3,325.70 C-50 8,070.70 3,930.70 C-35 8,730.24 4,099.70 Top Coyote (Top Nanushuk), K3 9,233.67 4,228.70 Base Coyote (Base Nanushuk) 12,651.33 5,116.70 Top Torok Oil Pool (Top Moraine) Lithology ConocoPhillips Standard Proposal Report Well Plan: 3S-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature Easting (usft) Latitude Longitude Casing Hole Diameter Diameter 20 42 10-3/4 13-1/2 7-5/8 9-7/8 4-1/2 6-3/4 Dip Dip Direction 822018 6:51:41AM Page 8 COMPASS 5000 14 Build 85 ConocoPhillips Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: Plan: 3S-611 Wellbore: Plan', 35-611 Design: 35-611wp05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: r ConocoPhillips Standard Proposal Report Well Plan: 3S-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP: Start 1.5"/100' DLS, 315° TF, for 300' 650.00 649.69 8.33 -8.33 Start 2.5"/100' DLS, 0' TF, for 1021.39' 1,671.39 1,617.00 220.94 -220.94 Hold for 115.51' 1,786.91 1,717.00 261.82 -261.82 Start 2.5'/100' DLS, -10' TF, for 1214.6' 3,001.50 2,565.00 822.78 -899.99 Hold for 20' 3,021.50 2,574.96 833.75 -913.43 Start 3-/100' DLS, -7.08° TF, for 503.63' 3,525.13 2,765.94 1,120.87 -1,278.48 Hold for 7863.2' 11,388.34 4,780.81 5,725.27 -7,325.77 Start 3°/100' DLS, 95.21° TF, for 1263' 12,651.33 5,116.70 6,725.43 -7,977.49 Hold for 375' 13,020.33 5,212.75 7,077.96 -8,061.89 Start 3°/100' DLS, 0° TF, for 494.67' 13,521.00 5,276.45 7,553.67 -8,175.78 Adjust TF to 0°, for 14.77' 13,535.77 5,276.39 7,568.03 -8,179.22 Hold for 5133.74' 18,669.50 5,236.70 12,560.53 -9,374.48 TD: 18669.5' MD, 5236.7' TVD &22018 6: 51 41A Page 9 COMPASS 5000.14 Build 85 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-611 Plan: 3S-611 50029xxxxx00 3S-611 wp05 ConocoPhillips Clearance Summary Anticollision Report 02 August, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3S Pad - Plan: 3S-611 - Plan: 3S-611-3S-611wpD5 Well Coordinates: Datum Height: WELL@ 66.70usft(Doyon 142) Scan Range: 0.00 to 18,669.50 usft. Measured Depth. Scan Radius is 2,063.05 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIEDAll wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 3S-611 - 3S-611wp05 530.68 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) 525.00 Reference Design: Kuparuk 3S Pad - Plan: 3S4611 - Plan: 35.611-3S-611wp05 Centre Distance Scan Range: 0.00 to 18,669.60 usft. Measured Depth. Major Risk Scan Radius is 2,063.05 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited 650.66 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Clearance Factor Kuparuk 3S Pad 35-03-3S-03-35-03 530.68 158.59 530.68 149.40 525.00 17.258 Centre Distance Pass - Major Risk 3S -03 -3S -03-3S-03 650.66 159.60 650.66 148.47 650.00 14.335 Clearance Factor Pass - Major Risk 3S -06 -3S -06-3S-06 384.53 98.40 384.53 91.69 375.00 14.668 Centre Distance Pass - Major Risk 3S -06 -3S -06-3S-06 433.54 98.87 433.54 91.44 425.00 13.307 Clearance Factor Pass - Major Risk 35 -06 -3S -06A -3S -06A 384.53 98.40 384.53 91.69 375.00 14.668 Centre Distance Pass - Major Risk 3S -06 -3S -06A -3S -06A 433.54 98.87 433.54 91.44 425.00 13.307 Clearance Factor Pass - Major Risk 35-07 - 35-07 - 35-07 60.33 80.08 60.33 77.64 50.00 32.870 Centre Distance Pass - Major Risk 35-07-3S-07-35-07 285.31 80.71 285.31 75.96 275.00 16.995 Clearance Factor Pass - Major Risk 3S -D8 -3S-08-35-08 210.39 59.72 210.39 56.00 200.00 16.031 Centre Distance Pass - Major Risk 35-08-35-08-35-08 335.16 60.71 335.16 55.04 325.00 10.705 Clearance Factor Pass - Major Risk 35 -08 -3S -08A -3S -08A 210.39 59.72 210.39 55.00 200.00 16.031 Centre Distance Pass - Major Risk 35 -08 -3S -08A -3S -08A 335.16 60.71 335.16 55.04 325.00 10.705 Clearance Factor Pass -Major Risk 35 -08 -3S -08B -3S -08B 210.39 59.72 210.39 56.00 200.00 16.031 Centre Distance Pass - Major Risk 35 -08 -3S -08B-35-086 335.16 60.71 335.16 55.04 325.00 10.705 Clearance Factor Pass - Major Risk 35 -08 -3S -08C -3S -08C 211.49 59.72 211.49 56.09 200.00 16.439 Centre Distance Pass - Major Risk 35 -08 -3S -08C -3S -08C 336.26 60.73 336.26 55.15 325.00 10.883 Clearance Factor Pass - Major Risk 35-09-35-09-35-09 60.20 40.14 60.20 37.70 50.00 16.491 Centre Distance Pass - Major Risk 3S-09 - 38-09 - 35-09 85.20 40.19 85.20 37.42 75.00 14.526 Clearance Factor Pass - Major Risk 3S-10-35-10-35-10 110.40 19.84 110.40 17.80 100.00 9.709 Centre Distance Pass - Major Risk 35-10-35-10-35-10 210.38 20.69 210.38 16.95 200.00 5.540 Clearance Factor Pass - Major Risk 3S-14-35-14-35-14 637.88 56.97 637.88 46.04 625.00 5.214 Centre Distance Pass - Major Risk 35-14-3S-14-35-14 738.99 58.06 738.99 45.25 725.00 4.533 Clearance Factor Pass - Major Risk 35-15-3S-15-35-15 210.04 79.05 210.04 75.08 200.00 19.914 Centre Distance Pass - Major Risk 3S -15-35-15-3S-15 26D.02 79.47 260.02 74.66 250.00 16.521 Clearance Factor Pass - Major Risk 35-16-3S-16-35-16 962.75 83.80 962.75 68.07 950.00 5.327 Centre Distance Pass - Major Risk 38.16-35-16-35-16 987.17 84.00 987.17 67.86 975.00 5.204 Clearance Factor Pass - Major Risk 35-17-35-17-35-17 210.21 119.67 210.21 115.64 200.00 29.649 Centre Distance Pass - Major Risk 3S-17-35-17-35-17 310.04 120.25 310.04 114.35 300.00 20.358 Clearance Factor Pass - Major Risk 02 August, 2018 - 6:50 Page 2 of 6 COMPASS 111110-- ConocoPhillips Anticollision Report for Plan: 3S-611 - 3S-611wp05 7ray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kupamk 3S Pad - Plan: 3S-611 - Plan: 35-611-3S-611wpg5 Scan Range: 0.00 to 18,669.60 usft. Measured Depth. Scan Radius is 2,063.05 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 02 August, 2018 - 6:50 Page 3 of 6 COMPASS Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft 35 -17 -3S -17A -3S -17A 210.21 119.67 210.21 115.64 200.00 29.649 Centre Distance Pass - Major Risk 35 -17 -3S -17A -3S -17A 310.04 120.25 310.04 114.35 300.00 20.358 Clearance Factor Pass - Major Risk 35-18-3S-18-35-18 60.43 140.01 60.43 137.57 50.00 57.445 Centre Distance Pass - Major Risk 35-18-3SAB-3S-18 235.42 140.91 235.42 137.03 225.00 36.318 Clearance Factor Pass - Major Risk 35-19-35-19-35-19 85.67 159.97 85.67 157.24 75.00 58.549 Centre Distance Pass - Major Risk 35-19-35-19-35-19 235.66 160.84 235.66 156.54 225.00 37.343 Clearance Factor Pass - Major Risk 3S-21 - 3S-21 - 3S-21 84.75 199.87 84.75 197.04 75.00 70.673 Centre Distance Pass - Major Risk 35-21 - 35-21 - 3S-21 284.63 201.10 284.63 195.61 275.00 36.596 Clearance Factor Pass - Major Risk 35-22-35-22-35-22 668.97 211.87 668.97 200.97 650.00 19.437 Centre Distance Pass - Major Risk 35-22-35-22-35-22 695.06 212.06 695.06 200.76 675.00 18.730 Clearance Factor Pass - Major Risk 35 -23 -3S -23-3S-23 211.49 238.27 211.49 234.21 200.00 58.724 Centre Distance Pass - Major Risk 35-23-35-23-35-23 286.48 238.76 266.48 233.28 275.00 43.492 Clearance Factor Pass - Major Risk 35 -23 -3S -23A -3S -23A 234.04 238.27 234.04 233.77 225.00 52.959 Centre Distance Pass - Major Risk 35 -23 -3S -23A -3S -23A 284.03 238.73 284.03 233.28 275.00 43.612 Clearance Factor Pass - Major Risk 35-26-3S-26-35-26 1,269.72 246.01 1,269.72 224.69 1,250.00 11.537 Centre Distance Pass - Major Risk 35-26-3S-26-35-26 1,292.88 246.15 1,292.88 224.45 1,275.00 11.340 Clearance Factor Pass - Major Risk 35 -26 -PALMI -PALMI 1,269.72 246.01 1,269.72 224.69 1,250.00 11.537 Centre Distance Pass - Major Risk 35-26- PALM I - PALM 1 1,292.88 246.15 1,292.88 224.45 1,275.00 11.340 Clearance Factor Pass - Major Risk 3S-613-35-613-35-613 52.23 39.96 52.23 37.58 50.00 16.828 Centre Distance Pass - Major Risk 3S-613 - 35-613 - 3S-613 427.47 41.71 427.47 34.22 425.00 5.565 Clearance Factor Pass - Major Risk 35-620-35-620-35-820 492.26 174.13 492.26 165.82 475.00 20.942 Centre Distance Pass - Major Risk 35-620-35-620-35-620 543.19 174.67 543.19 165.50 525.00 19.047 Clearance Factor Pass - Major Risk Plan: 3S -612 -Plan: 3S-612 - 3S-612wp05 350.00 20.00 350.00 13.79 350.00 3.218 Centre Distance Pass - Major Risk Plan: 3S -612 -Plan: 38-612-35-612WP05 751.27 23.11 751.27 10.06 750.00 1.772 Clearance Factor Pass - Major Risk 02 August, 2018 - 6:50 Page 3 of 6 COMPASS ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 3S-611 - 3S-611wp05 Survey tool oroaram From To Survey/Plan Survey Tool (usft) (usn) 39.00 1,200.00 35-611wp05 GYD-GC-SS 1,200.00 2,200.00. 35-611wp05 MWD 1,200.D0 3,001.50 3S-611wp05 MWD+IFR-AK-CAZSC 3,001.50 4,501.50 3S-611wp05 MWD 3,001.50 12,651.33 3S-611wp05 MWD+IFR-AK-CAZ-SC 12,651.33 14,151.33 3S-611wp05 MWD 12,651.33 18,669.50 3S-611wp05 MWD+IFR-AK-CAZ-SC 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. 02 August, 2018 - 6:50 Page 4 o/ 6 COMPASS Ladder View 7:12. August 022016 3S-611 wp05 Ladder View _ � N 85 285- < M N C o .t CIS a4l 90 m J o � i li m i d6 Equivalent Magnetic Distance 0 0 2000 4000 6000 8000 10000 12000 Measured Depth SURVEY PROGRAM CASING DETAILS Y pth From Depth To Survey/Plan Tool T D MD Nam 39.00 600.00 3S-611wp05 (Plan: 3S-611) GYD-GC-SS 80.00 80.00 20" 600.00 1600.00 3S-611wp05 (Plan: 3S-611) MWD 2565.00 3001.50 10 3/4" x 13-1/2 600.00 3001.50 3S-611wp05 (Plan: 3S-611) MWD+IFR-AK-CAZ-SC 5116.70 12651.33 7-5/8" x 9-7/8" 3001.50 4501.50 3S-611wp05 (Plan: 3S-611) MWD 5236.70 18669.50 41/2"x6-3/4" 3001.5012651.33 3S-611wp05 (Plan: 3S-611) MWD+IFR-AK-CAZ-SC 12651.3314151.33 3S-611wp05 (Plan: 3S-611) MWD 12651.3318669.50 3S-611wp05 (Plan: 3S-611) MWD+IFR-AK-CAZ-SC m V � m 9 u V m m 60 c O i I � CIS u . n 0 ' O. N 0l 530 Z530- 0 O m N C Ol Equivalent Magnetic Distance '.. 0 0 550 1100 1650 2200 2750 Partial Measured Depth 8:34, August 92 2118 3S-611 wp05 Ladder View I �i m c`o 285 \ F, S CC W) go --- — N c 95 - U I a d'M Equivalent Magnetic Distance 0 0 3000 6000 9000 12000 15000 18000 Measured Depth SURVEY PROGRAM CASING DETAILS pth From Depth To Survey/Plan Tool T D MD Nam 39.00 600.00 3S-611wp05 (Plan: 3S-611) GYD-GC-SS 80.00 80.00 20" 600.00 1600.00 3S-611wp05 (Plan: 3S-611) MWD 2565.00 3001.50 10 3/4" x 13-1/2 600.00 3001.50 3S-611wp05 (Plan: 3S-611) MWD+IFR-AK-CAZ-SC 5116.70 12651.33 7-5/8" x 9-7/8" 3001.50 4501.50 3S-611wp05 (Plan: 3S-611) MWD 5236.70 18669.50 41/2"x6-3/4" 3001.5012651.33 3S-611wp05 (Plan: 3S-611) MWD+IFR-AK-CAZ-SC 12651.3314151.33 3S-611wp05 (Plan: 3S-611) MWD 12651.3318669.50 3S-611wp05 (Plan: 3S-611) MWD+IFR-AK-CAZ-SC es m v 0 n N i 60 O tC O. U N E030— C)Py 0 ru c d U 0 0 550 1100 1650 2200 2750 Partial Measured Depth I c`o S Equivalent Magnetic Distance I I 7:16,A W02 X18 3S-611 wp05 39.00 TO 18669.50 AC we(Is ONLY 5 3S-611 T02.0 Toe 120717 PP 3S-611 T01.5 Mid Update 072718 PP i 3S-611 T01.0 Heel Update 072718 PP c 3S-06 o 3S-67 3S -06A 3S-09 m 3S-62 3S-15 3S-10 t 3S-1 0 Z -14 3S-26 3S -17A _ 3 - S-19 8c S-16 S-16 08B -22 3S -08A 23 3S- -08 Easting (3000 uslUin) Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-611 50029xxxxx00 Plan: 3S-611 Plan: 3S-611wp05 Error Ellipse Survey Report 02 August, 2018 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupamk 3S Pad Well: Plan: 3S-611 Wellbore: Plan: 35611 Design: 3S-611wp05 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-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic wale factor Site Kuparuk 3S Pad SHO Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: Well Plan: 3S-611 MWD MWD - Standard gncs Maeti Well Position +N/ -S 0.00 usft Northing: Latitude: MWD +E/ -W 0.00 usft Easting: Longitude: Position Uncertainty Design 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 27.70 usft WellborePlan: 3S-611 MWD MWD - Standard gncs Maeti Model Name Sample Date Declination Dip Angle Field Strength MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD Ind MWD+IFR-AK-CAZ-SC BGGM2D18 9/15/2018 16.84 80.88 57,434 Design 3S-611wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) V) 39.00 0.00 0.00 323.26 Tool Program Date 8/2/2018 From To (usft) (usft) Survey (Wellbore) 39.00 1,200.00 35-611wp05(Plan: 3S-611) 1,200.00 2,200.00 35-611wp05(Plan: 3S-611) 1,200.00 3,001.50 35-611wp05(Plan: 3S-611) 3,001.50 4,501.50 35-611wp05(Plan: 3S-611) 3,001.50 12,651.33 35-611wp05(Plan: 3S-611) 12,651.33 14,151.33 35-611wp05(Plan: 3S-611) 12,651.33 18,669.50 35-611wp05(Plan: 3S-611) Tool Name Description GYD-GC-SS Gymdata gyro single shots MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD -Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC MWD MWD- Standard MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 8/2/2018 6.51:20AM Page 2 COMPASS 5000.14 Build 85 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 35-611 Project: Kuparuk River Unit TVD Reference: WELL @ 66.70usft (Doyon 142) Site: Kuparuk 3S Pad MD Reference: WELL @ 66.70usft (Doyon 142) Well: Plan: 35-611 North Reference: True Wellbore: Plan: 35811 Survey Calculation Method: Minimum Curvature Design: 3S811wp05 Output errors are at 1.00 sigma Depth Database: OAKEDMP2 j Plan Survey Tool Program Date 8/2/2018 Depth From Depth To (Bart) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,200.00 35-611wpO5 (Plan( 35-611) GYD-GC-SS Gyrodata gyro single shots 2 1,200.00 2,200.00 35-611wp05 (Plan: 35-611) MWD MWD - Standard 3 1,200.00 3,001.5035-611wp05(Plan:3S-611) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 3,001.50 4,501.50 3S-611wp05 (Plan: 3S-611) MWD MWD - Standard 5 3,001.50 12,651.3335-611wp05(Plan: 3S-611) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6 12,651.33 14,151.33 35-611wp05 (Plan: 35-611) MWD nighslde lateral MWD - Standard 7 12,651.33 18,669.50 3S-611wp05 (Plan: 35-611) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Position uncertainty and bias at survey station Masi Imlianion A nium Veni4a1 nighslde lateral Vertical Ma9nitua, ssaimator semlminor Depth Dspih Error Bias Error Bias Ertor Bus of Bias E., Error Azimuth Tool (uau) P) 1°1 IiuB) (Ben) lean) (Bea) (lean) (oan) (oan) Pian) (use) Burt) 1°) 3900 0.00 0.00 39.00 000 000 0.00 0.00 000 0.00 000 000 0.00 0.00 UNDMNED 100.00 am 0.00 100.00 0.04 0.00 004 000 1.15 am 0.00 0.04 004 0.00 GYGGC-SSn 1) 200.00 000 000 200.00 0.19 000 0.19 000 1.15 0.00 000 0.19 OAS 0.00 GY c.sS(1. 1) 300.00 000 0.00 300.00 0.33 0.00 033 0.00 1.15 0.01 0.01 0.33 0.33 000 GYD-GCSS(1, 1) 350.00 0.00 000 350.00 041 0.00 041 000 1.15 001 0.01 041 041 0,00 GYD-GC-SS(1, 1) 400.00 075 315.00 400.00 0.47 0.00 0.47 0.00 1.15 0.01 0.01 0A7 0.47 45.00 GYD-GC-SS (1, 1) 500.00 225 31500 499.96 0all 000 0.61 000 1.15 003 003 0.61 081 45.00 GYD-GC-SS(1, 1) mom 375 31500 599.62 O,74 0.00 074 000 1.15 004 004 075 076 45.00 GYD-GC-SS(1, 1) 650.00 4.50 315.00 64969 0.81 000 0.81 0.00 1.15 005 0.05 On 0.81 4500 GYD cG s(1. 1) 700.00 5.75 315.00 699.49 0.80 0.00 089 0.00 1.15 005 O.D5 089 0.89 45.00 GYD-GC-SS(1. 1) 000.00 8.25 31500 79874 102 -001 1.04 0.00 1.15 0.07 OW 1'04 1.03 135.00 GYD-GC-SS(1, 1) 900.00 1075 31500 897.36 1.16 -001 1.20 000 1.15 009 0.09 1.20 1.19 136.52 GYD-GC-SS(1, 1) 1,00000 1325 31500 995.17 1.31 -0.01 1.37 0.00 1.15 0.12 012 1.37 1.34 135.85 GYD-GC-SS(1, 1) 1,10000 15.75 315.00 1,09197 145 -O.02 155 0.00 115 0.14 0.14 1.55 1.50 135.0 GYD,GC-SS(1, 1) 1,20000 18.25 315.00 1,187.60 1.60 -0.03 176 0.00 1.15 0.17 0.17 1]6 1.66 13546 GYDGCSS(1, 1) 1.300.00 20.75 315.00 1,28185 187 -0ao 189 -0.03 1.14 DID 0.20 1.89 1.75 13526 mm (1. 2) 1,400.OD 23.25 315.00 1,374.56 1.67 -0.04 206 -0.10 1.13 023 025 2.06 1.78 134.68 MM (1. 2) 1150000 25.75 31500 1,465.55 1.69 -0.05 241 -0.19 1.13 0.26 0.33 241 1.82 134.43 MWo(1, 2) 1,60000 20.25 315.00 11554.65 173 -0,07 2.93 -0.30 1.13 029 042 293 1.88 134.37 MM (1, 2) 1,67139 30.03 315.00 1,617.00 1.77 -0.0 3.38 -0.30 1.14 032 0.50 3.38 194 134.35 MWD(1, 2) 1,700.00 30.03 315.00 1.64176 1.80 -0.08 IN 4).42 1.14 0.33 054 3.58 1.96 134.37 MM (1, 2) 11708.91 3003 31500 1,717.00 1.89 -0.08 4.19 -053 1.18 0.36 0.65 4.19 2.03 134.37 MM (1, 2) 1000.00 3036 31689 1.728.32 1.90 -0.08 429 -055 1.18 0.36 067 4.29 2.04 134.37 MM (1. 2) 1.900.00 3282 314.09 1,813.49 2.00 -0.09 5.08 -0.68 1.23 0.40 0.81 506 2.14 134.30 MM (1. 2) 822018 6:51: 20AM Page 3 COMPASS 5000.14 Build 85 Company: ConowPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kupamk 3S Pad Well: Plan: 3S-611 Wellbore: Plan: 3S-611 Design: 3S-611wp05 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 35-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination AZNnuth vertical aigirside lateral vara®I Magnitude senni+najor Siam inar Depth Depth Error Bias Emr Blas E., Blas of Bias En r Emr Azimuth Tool (asrt) P) (1) fusel loan) (ush) loan) lost) lawn) lose) refs) (een) (-ft) P) 2,00000 3529 31340 1,896.33 213 .0.10 595 -0.84 126 044 097 5.95 226 134.13 MWD(1, 2) 2.100.00 37.77 312.79 1197868 2.27 -0.11 0.90 -1.02 1.35 047 1.15 6.90 2.38 133.91 MWD(1. 2) 2,200.00 4024 312.24 2,054.39 243 -0.13 7.92 -1.23 144 0.51 1.35 7.92 2.52 133.65 MWD(1. 2) 2.300.00 4272 311.74 2,129.30 1.96 -0,18 4.11 001 1.26 0.65 060 4.11 2.23 130.73 MWO+IFRAWCAZ-SC(2,2) 2,40000 45.20 31129 2.20128 2.04 -0.21 4.55 0.01 1.30 056 085 4.55 2.30 13057 MWDOFR-AK-CA.W(2.2) 2.50000 47.68 310.88 2.270.10 2.12 -023 5.01 0.01 136 062 070 5.01 2,38 130.41 MWD+1FR-AK-CA -W(2, 2) 21600.00 50.17 31049 2.335.89 2.20 -0.26 5.50 0.02 1.43 065 075 5.50 2.45 130.26 MWD+IFR-AK-CAZ C(2, 2) 2,700.00 5285 310.14 2,398.28 228 -0.30 6.01 002 1.51 0.60 OBO 6.01 2.52 130.11 MWD+IFR-AK-CAZ-SG(2, 2) 2.800.00 55.14 30981 2,457.18 237 -0.33 6.53 002 1.61 0.72 085 6.53 260 12996 MVa3+1FRAK-CAZ-SC(2,2) 2,900.00 57.62 30949 2,512.55 245 -0.36 7.07 0.02 171 075 0.90 7.07 2.67 129.83 MWD+1FRAKZAZ-SC(2,2) 3,000.00 60.11 309.20 2,58425 2.48 -040 7.62 -0.17 171 077 096 7.62 2.76 129.84 MWD(2,3) 3,001.50 60.15 309.19 2,565.00 2.46 -0.40 7.63 -0.18 171 0.77 0.96 7,83 236 12984 MM (2.3) 3,021.50 60.15 309.19 2,57496 2.48 640 7.75 -0.26 1.71 078 0.99 7.75 2.77 12986 MWD(2. 3) 3,100.00 8248 308,86 2,61263 2.46 -0.43 334 -0.58 1.75 080 1.15 8.35 2.70 12987 MM (2, 3) 3,20000 6546 30347 2,656.51 248 -0.48 9.30 -1.00 183 082 1.45 9.30 2.81 129.79 MWD(2, 3) 3,300.00 68.44 300.09 2.695.65 2.54 -0.53 1042 -1.45 1.97 084 182 1042 2B5 12963 MM (2. 3) 3,400.00 7142 307.M 2,729.96 2.64 -0.57 1168 -192 2.15 ow 2.24 1160 2.89 129.42 MVV) (2. 3) 3.500.011 744D 307.37 2,759.34 278 -0.62 13.03 -241 2.37 0.87 269 1304 2.92 12821 MM (2, 3) 3,525.13 75.15 307.29 2.765.94 2.82 063 1339 -2.53 2.43 088 281 13.39 2.94 129.15 MWD(2.3) 3'soono 75.15 307.29 2,785.12 3.01 -0.63 1646 .291 2.62 0.89 3.16 1447 2.96 120.99 MWD(2,3) 3,700.00 75.15 30]29 2.81075 3.28 .083 15.93 -3.41 2.90 090 3.65 15.93 2.99 128.81 mm (2.3) 3,800.00 75.15 307.29 2,83837 3.56 -0.63 17.43 -392 3.19 0.91 4.14 17.43 3.03 128.66 MWD (2, 3) 3,900.00 75.15 30T29 2,882 00 3.86 -0.63 16.95 -4.42 3.49 0.92 4.63 18.96 3.07 128.53 MM (2,3) 4.000.00 75.15 307.29 2,887.62 616 -0.63 20.50 -4.93 3.80 094 5.13 20.51 3.11 128.42 MVID(2, 3) 4,100.00 75.15 307.29 2.913.24 4.47 -0 83 22,07 -5.43 4.11 0.95 5.83 n,07 3.15 128.33 MWD (2, 3) 4,20000 75.15 307.29 2,930.87 479 -0.63 2364 -5.94 443 096 6.13 2365 320 128.24 MWD(2. 3) 4,300.00 75.15 307.29 2,984.49 5.12 -063 2523 644 4.75 098 6:63 25.23 3.24 128.17 MM (2, 3) 4.40000 75.15 307.29 2,990.12 544 -0.63 26.82 694 507 0.99 7.13 2863 329 128.11 MM (2. 3) 4,50000 75.15 307,29 3,015.74 5.77 .0.63 2843 -7.45 5.40 1.01 7.63 28.43 334 126.06 MWD(2, 3) 4,60000 75.15 307,29 3,041.36 353 -0.65 4367 005 3.20 1.02 167 1367 3.04 12838 MWD+IFR-AK-CAZ-SC(3, 3) 4700.00 75.15 30129 3,066.99 3.66 -065 14.18 0.05 3.35 1.03 173 14.19 306 128.31 MWD+IFR-AK-CM-SC(3.3) 4,60000 75.15 307.29 3,08261 3.02 -065 14,70 0.05 3.50 1.05 178 14.71 3.09 128.24 MW IFR -AK -CQ -SC (3.3) 4,900.00 7515 307.29 3,11324 397 -0.65 15.23 005 365 1.06 1.83 1523 3.11 128.18 MWD+IFR-M-CP-SC(3,3) 5,000.00 75.15 30129 3,143.86 4.13 -065 15.76 0.05 3.80 1.08 1.89 15.76 3.13 128.12 MWD+IFR-MCP-SC (3,3) 5,100.00 75.15 307.29 316948 4.28 -0.65 1629 0.05 3.96 1.09 194 1629 3.16 128.06 MWD+1FR-AK-CASC(3,3) 5.200.00 75.15 307.29 3,195.11 443 -0.65 16.83 0.05 4.11 1.11 2.00 16.83 3.18 128.01 MWD+VFR-AK-CAZ-SC(3,3) 5300.00 75.15 30729 322013 4.59 -0.65 17.37 0.05 4.27 112 2.05 17.37 321 127.96 MWD+IFR-AK-OA-W(3,3) 5,40000 75.15 307,29 3,246.36 4.75 -0.65 17,92 005 443 1.14 2.11 17.92 3.23 127.92 MW13+IFR-M-CAZ-SC(3,3) 5.50000 7515 307,29 3,271.98 491 -0.65 18.47 0.05 659 1.15 2.17 1847 326 127,80 14wi3+1FR-AK-CA-SC (3,3) 5,60000 75.15 30729 3,297.60 5.07 -OAS 1902 0.05 4.75 1.17 223 1902 3.28 127.84 MWD+IFR-AK-CPZ C(3.3) 5.700.00 75.15 307,29 3,32323 523 -065 1957 0.05 491 1.19 229 19.57 3.31 127.80 MWD+1FR-AK-CA-SC(3, 3) 51800.00 75.15 30729 3.348.85 589 -065 20,13 0.05 5.07 1.20 235 20.13 3.34 127.77 MWD+1FR-AK-CA250(3,3) 8900.00 75.15 307.29 3,37448 5.58 -0.65 20.69 0.05 5.23 1.22 241 20.89 3.37 127.74 MIND+IFR-AK-CAZ-SC(3,3) 6,000.00 75.15 30129 3,40D.10 572 .0.65 21.25 0.05 5.39 1.24 2.47 21.25 340 12771 MWD+IFRAK-OA2-SC(3,3) 8100.00 75.15 307.29 3,425.73 5.89 -065 21.81 0.05 5.56 125 2.54 21.81 3.43 12766 shND+1FR-AK-CM-W(3.3) 8,200.00 75.15 307.29 3,45135 305 -0.65 22.37 005 572 127 2.60 22.37 3,45 127.85 MWD+IFR-MC -SC (3,3) 8300.OD 75.15 307.29 3,478.87 622 -OBS 22.94 005 5.88 1.29 2.67 22.94 349 127.63 MWD+IFR-AK-CP-SC(3,3) 6,400.00 75.15 307.29 3,50260 6.38 -0.65 23.51 0.05 8.05 1.30 273 23.51 3.52 127.60 MWD+1FR-AK-CA -SC is 3) 6,500.00 75.15 307.29 3.528.22 6.55 -065 24.07 0.05 8.21 132 2.00 24.07 3.55 127,58 MWD+1FRAK-C Z-SC(3,3) 6,600.00 75.15 307.29 3,55385 6.72 -0.65 24,641 005 6.30 1.34 286 24.64 3.58 127.55 MWDOFR-AK-CAZ-SC(3,3) 570000 7515 307.29 3.57947 6.69 -065 25.21 0.05 854 1.36 2.93 2522 361 12754 MVID+IFR-AK-CAZ-SC(3.3) 61800,03 75.15 30]29 3,60509 7.06 -085 2579 0.05 671 1.37 300 25.79 3.64 127.52 MM+1FR-AK-CA-SC(3. 3) 6.900.00 75.15 307.29 3,63072 723 -065 26.36 005 6.87 1.39 307 28.35 3.58 127.50 MWD+IFR-AK-CA SC (3, 3) 7,000.00 75.15 307.29 3.656.34 739 -065 26.93 0.05 7,04 141 3.14 26.93 371 12748 MWD+1FRAK-CAZ-8C(3,3) 8122018 6:51 2OAM Page 4 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: Plan: 3S-611 Wellbore: Plan: 3S-611 Design: 35-611Wp05 Position uncertainty and bias at survey station 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-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70uslt (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination Az6 mlh V4N4al RigKside 1 uml Wmwl MagneWe 9emimaj4r Semianinor Depth Depth Error Bias Eno, 91. E.r alas as. E., Error A ".M Tool (usin (1) M (usR) (uan) (usR) (..ft) (uan) (usn) (uan) (usn) (usn) (van) V) 7,10000 75.15 307.29 3.68197 7,56 -0.65 27.51 005 720 143 321 27,51 174 12)4] MWD+IFR-AK-CAZ-SC(3, 3) 7.200.00 75.15 307.29 3,]0].59 7.73 -065 28.09 095 7.37 1.45 3.28 28.09 378 127.45 MW IFR-AK-CM-SC(3, 3) 7,307.00 75.15 307.29 3,733.21 7.90 -0.65 28.66 005 7.54 147 3.36 28.66 3.81 127.43 MWD+IFR-AK-CAZ-SC(3, 3) 7,400.00 75.15 30129 3,758.84 807 -0.65 2924 005 7.70 149 343 29.24 3.85 127A2 MWD+IFR-AK-CAZ-SC(3,3) 7150000 75.15 307.29 3.784.46 8.25 -0.65 29.82 0.05 7.87 1.51 3.50 2982 3.88 127.41 MWD+1FR-AK-CAZSC(3,3) 7.600.00 75.15 307.29 3,810.09 842 -0.65 30.40 0.05 8.04 1.52 358 30.40 3.92 12739 MWD+IFR-MK- -SC (3, 3) 7]00.00 75.15 307.29 3,03571 869 -085 30.98 0.05 021 1.54 3.65 30.98 3.95 12138 MWD+1FR-AK-CAZ-SC(3,3) 7,800.00 75.15 30].29 3,861.33 8.76 -085 3156 O.D5 83] 1.55 3.73 31.56 399 12137 MWD+IFR-AK-CAZ-SC(3.3) 7,90000 75.15 307.29 3,886.96 8.93 -0.65 32.14 0.05 0.54 1.56 380 32.14 402 12136 MWD+IFR-AK-CAZ-SC(3,3) 8,000.00 75.15 37.29 3,912.58 9.10 -0.65 32.72 095 8.71 1.0 388 32.72 4,06 127.34 MWDHFR-AK-CAZ-SC(3, 3) 8,100.00 75.15 30129 3,93821 927 -0.65 3330 0.05 888 1.62 3.96 3330 4.10 127.33 MWD+IFR-AK-CA2-SC(3,3) 8,200.07 75.15 307.29 3,963.83 945 -065 33.88 0.05 9.04 165 4.01 3388 4.14 12132 MWDAFR-AK-CAZ-&C(3, 3) 8.30000 75.15 307.29 3.989.46 882 -065 34.46 005 9.21 167 4.12 34.46 4.17 127.31 MWD+IFR-AK-CAZSC(3, 3) 8,400.00 75.15 30129 4,015.08 9.79 -065 35.05 0.05 9.36 1.69 420 3505 4.21 127.30 MWD+IFR-A&CAZ-SC(3, 3) 8,500.00 75.15 37.29 4,04070 9.96 -0.65 3583 0.05 9.55 171 4.20 35.63 4.25 12129 MW IFR-AK-CAZ-SC(3,3) 8,600.00 75.15 30129 4,066,33 10.14 -0.65 3621 005 9.72 1.73 4.36 3621 4.29 12129 MWD+IFR-AK-CAZ-SC(3.3) 8,70000 75.15 3729 4.091.95 1031 -0.65 36.80 0.05 988 1.75 4A4 36.80 4.33 127.20 MWD+1FR-AK-CAZ-SC(3.3) 8,80000 75.15 307.29 4,117.58 10.40 -0.65 37.38 005 10.05 1.77 453 37.30 4.36 12127 MWD+IFR-AK-CAZSC(3,3) 8.900.00 75.15 37.29 4,143.20 10.66 -0.65 37.97 005 10.22 1.79 4.61 37.97 4.40 127.28 MWDHFR-AK-CAZ-SC(33) 9,007.00 75.15 307.29 4,18882 10.83 -0.0 3855 005 10.39 182 4.69 3855 4.44 127.25 MWD+IFR-WK AZ -SC (3.3) 9,100.00 75.15 30129 4,194.45 11.00 -0.65 39.14 005 10.56 1.84 4.78 39.14 448 12].25 MWD+IFR-AK-CAZ-SC(3,3) 9,200.00 75.15 307.29 4,220.7 11.17 -065 39.72 0.05 1073 IN 487 3972 4.52 12124 MWD+IFR-AK-CAZ-SC(3,3) 9,300.00 75.15 3D7.29 4,245.70 11.35 -065 40.31 0.05 Mao 1.88 495 40.31 4.56 127.23 MVM+IFR-N(-CAZSC(3,3) 9,407.00 75.16 307.29 4,271.32 11.52 0.65 4090 0.05 11.06 190 504 40.90 460 12722 MWD+IFR-AR-CAZ-SC(3, 3) 9,50.00 75.15 37.29 4,29694 1170 -065 41.48 0.05 1123 193 5.13 41.48 4.64 12122 MWD+IFR-AK-0AZ-SC(3. 3) 9.800.00 75.15 307.29 4,322.57 11.87 -0.65 42.07 005 11.40 195 522 42.07 4.68 127.21 MW3+IFR-AK-CAZ-SC(3,3) 9,700.00 75.15 30129 4,348.19 12.04 -0.65 42,66 0.05 11.57 1.97 5.31 4268 4.72 127.20 MWD+1FR-AK-CAZ-S0(3.3) 9,00000 75.15 307.29 4,373 a2 12.22 -0.65 4324 0.05 1134 200 54D 4324 4.77 127.20 MWD+IFR-AK-CAZ-SC(3,3) ewco0 76.15 37.29 4399.44 12.39 -0.65 43.83 0.05 11.91 2.02 549 43.83 461 127.19 MWD+1FR-AK-CAZ-SC(3,3) 1000.0 75.15 30129 4.425.06 1257 .065 0,42 0.05 12.08 2.04 5.58 44.42 4.85 127.19 MWD+1FR-AK-CAZ-SC(3,3) 10100.0 MIS 307.29 4,450.69 12.74 -0.65 45.01 0.05 12.25 2.07 567 45.01 4.89 127.18 MWD+IFR-AK-CPZ-SC(3,3) 10,200.00 75.15 37.29 4.476.31 12.91 -065 45.60 0.05 12.42 2.0 576 4560 4.93 127.10 MWD+1FR-AK-CAZ-SC(3,3) 10,300.00 75.15 307.29 450194 13.09 -0.65 4818 0.05 1269 2.12 5.86 46.18 4.07 12].1] MWD+IFR-AK-CAZSC(3,3) 10.400.00 75.15 307.29 4,52758 1326 -0.65 4617 0,05 1276 2.14 5.95 46.77 5.01 127.17 MWD+IFR-AK-CAZ-SC(3, 3) 10,50.00 75.15 30129 4,55119 1344 -065 47.36 0.05 12.92 2.16 80 4736 50 127.16 MWD+IFR-ML -SC (3, 3) 10,600.00 75.15 307.29 4,576.81 13.61 -0.65 4195 005 1309 2.19 6.14 47.95 5.10 127.16 MWD+1FR-AK-CAZ-SC(3, 3) 10,700.00 75.15 307.29 4,604.43 1379 -0.65 48.54 0.05 13.26 2.21 824 40.54 5.14 127.15 MWD+IFR-AK-CAZ-SC(3,3) 10180000 75.15 30129 4,830.06 13.96 065 49.13 0.05 1343 2.24 6.34 49.13 5.18 127.15 MWD+1FR-AK-CAZ-50(33) 10.900.0 75.15 307.29 4,85568 14.13 -0.65 49,72 0.05 1360 226 644 4912 523 127.14 MWD+1FR-N(-CAZ-SC(3,3) 11,00.00 75.15 30129 4,681.31 14.31 -065 50.31 0.05 13.77 2.29 6.53 5031 5.27 127.14 MWDHFR-AK-CA-SC(3,3) 11.107.07 7515 307.29 4,706.93 14.48 -065 50.90 0.05 13.94 2.32 6.63 50.90 5.31 127.13 MWD+IFR-AK-CAZ-SC(3,3) 11,200.0 75.15 37.29 4,732.55 14.68 -065 51.49 005 14.11 2.34 073 51.49 5.36 127.13 MWD+1FR-AK-CAZ-SC(3,3) 11.30000 75.15 307.29 4,758.18 14.83 -0.65 520 0.05 1428 237 SM 52.0 5.40 127.13 MMHFR-AK-CAZ-SC(3,3) 11,38834 75.15 37.29 4,780.81 1499 -0.65 5260 0.05 1443 239 6.92 52.60 5.44 127.12 MWD+1FR-AK-CA-SC(3,3) 11,400.00 75.12 307.0 4,78381 1502 -064 62.66 001 14.45 239 6.94 5266 SA4 127.12 MWD+1FR-AK-CAZSC(3,3) 11.500.07 7487 31034 4,809.70 15.29 -0.61 53.07 -035 1462 242 7.04 53.17 549 127.14 MVr➢HFR-AK-CAZ-SC(3,3) 11,600.0 74.67 31364 4,835.97 15.59 -0.60 5331 -071 1479 2.45 114 5367 5.53 127.18 MWD+IFR-AK-CV-SC(3.3) 11,700.00 74.51 316.95 4,88255 15.93 -0.59 53.39 -1.07 1495 2.48 7.25 51.15 5.57 127.25 MWD+IFR-AK-CA SC (3.3) 11,80000 74,39 320.06 4,889.36 1830 -0.59 53.30 -143 15.12 250 7.35 5462 582 127.34 MWD+IFR-AK-CPZ-SC(3, 3) 11,900.00 74.32 323.18 4,91634 18]0 -081 53.04 -1.80 1529 2.53 145 5508 566 127.46 MWD+1FR-AK-CAZ-SC(3, 3) 12.000.07 74.29 326.29 4,94340 17.13 -0.63 52.62 -2.17 1546 2.56 7.56 55.52 5.71 127.60 MWD+1FR-AK-CAZ-SC(3,3) 12,10.0 7430 32841 4,970.48 17.57 -067 52.04 -264 15.62 2.59 166 55.94 5.76 12].]5 MWDHFR-AK-CAZ-SC(3,3) 12,2000 74.36 332.52 4,97.50 18.02 -0,72 5129 -2.90 15.79 2.62 Z76 58.34 5.82 127.93 MWD+IFR-AK-CAZ-SC(3, 3) 12,30000 74.46 33584 5,024.38 18.47 A77 50.38 -3.27 15.96 2.65 186 56.73 5.89 128,11 MWDHFR-AK-CPZ-SC(3,3) 8/2/2018 5 51 20A Page 5 COMPASS 5000,14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3S Pad Well: Plan: 3S-611 Wellbore: Plan: 3S-611 Design: 3S-611wpD5 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output among are at Database: Well Plan: 3S-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Measured Inclination AN ult W.r .l Iighside lateral Vertical Magnllude Semime3or Semiminor D PtS 0eoh E.r Bias Error 91as Ertor Blas of SMs Error Enm A lmuM Taol (usft) 19 (°) lusm lung) (unm lusm (usg) luso) (ueR) (usm lenft) long) (1) 12.400.00 7461 338.75 5,051.06 1692 5.6 49.31 -3.63 16.12 288 7.95 5709 5% 12631 MWD+IFR-AK-CA-SC(3. 3) 12,500.00 74.79 6105 5,077.45 19.35 -092 40.10 .3.98 16.29 2.71 am 57.42 8.470 12053 MWD+IFR-AK-CA-SC(3,3) 12,800.00 7$03 344.95 $,103,49 19.75 -101 /6.73 -4.33 16,46 2.74 SAS 577/ 6.14 128]5 MWD+IFR-MK- -SC (3,3) 12,651.33 75.16 346.54 5,116.70 19.91 -1.05 4605 -4.57 16.49 2.75 8.24 58.00 6.00 12886 MM (3. 4) 12.700.00 75.16 346.54 5,129.16 1991 -1.05 46.39 .4.70 16.5D 2.77 836 58.26 807 129.06 MWD(3,4) 12,800.00 75.16 34654 5,154.78 19.92 -1.05 47.10 4,97 1650 2.50 860 Mai 6.28 129.50 MM (3. 4) 12,900.00 75.16 348.54 5.180.39 19.94 -1.05 4785 -525 16.52 2.82 6.85 59.38 6.57 12996 MM (3, 4) 13,00000 75.16 346.54 5205.00 1996 -105 4864 -5.52 1850 2.85 9.11 5998 6.94 130,44 MM (3, 4) 13,026.33 75.16 346.56 521275 19.96 -1.05 46.65 -5.59 16.55 2,86 9.17 60.14 7.04 130.57 MWD(3,4) 13,100.00 77.37 34854 5,230.24 19.32 -1.33 49413 -579 16,57 2.66 936 60.60 7,36 130.93 MM (3,4) 13,20000 00.37 348.54 5,249.54 18.53 -171 5032 5.07 18.61 2.90 9.61 6125 7.82 131AS MM (3, 4) 13,300.00 8337 346.54 5,283.88 17,84 -2.09 51.22 -6.35 18.68 291 9.87 also 8.32 131.98 MM (3, 4) 13.400.00 8637 346.54 5,27262 17.26 -2.47 52.15 -6.64 1671 2.92 10.11 6263 884 132.53 MWD(3,4) 13,50000 89.37 3485/ 5,276.33 16.86 -2.85 53.12 5.93 16,78 2.92 10.38 63.36 9.37 133.08 MM (3,4) 13,521.00 9000 346.54 5,278.45 16.79 -292 5332 5.99 1679 292 10.41 63,52 9.48 133.20 MM (3. 4) 13.53577 90.44 Mom 5,276.39 1675 -2.98 53.47 4.6 16.80 292 10.45 was Sea 133.26 MW0(3,4) 13,60000 90.44 3485/ 5,27590 16.79 -2.98 54.11 -J22 16.85 2.92 10.80 64.12 9.90 13365 MM (3+ 4) 13,700.00 9040 Mau 5,275.12 16.67 -2.98 55.12 -7.51 18.93 2.92 10.85 8/.89 10.44 134.22 MYM (3.4) 13,800.00 90.M 34854 5,274.35 18.98 -2.90 56.16 -7.60 17.01 2.92 11.10 6569 10.97 16.79 MM (3.4) 13,900,40 90.44 346.54 5.273.50 1i 05 .2.98 5L23 5.10 17.11 2.92 11.35 66.52 11.50 13537 MM (3, 4) 14.000.00 90.44 346.54 5,272.80 17.15 -2.90 58.31 -839 17,21 2.92 11.80 67.35 12.02 135.95 MWD(3,4) 14,100.00 9044 6854 527203 17,26 -298 59.42 -8.88 1732 2.92 1186 60.23 12.54 130.53 MWD(3,4) 14,200.00 80.46 6654 5,27126 16.67 -2.98 4977 4.50 16.72 2.92 9.30 6077 0.12 131.15 MWD+IFR-AWCM-SC(4,4) 14,300.00 go" 346.54 5,27048 18.70 -2.98 5008 4.50 16.75 292 9.36 was 832 131.33 MW IFR -AW -SO(4A) 14,40000 90.44 348.54 5,269.71 1673 -2.98 50.35 -4.50 16.79 292 942 61.20 8.53 131.52 MV IFR-AK-CA-SC(4,4) 14.500.00 9044 346.54 5,26894 16.77 -2.90 50.87 -450 16,82 2.92 9.47 61.42 875 131.70 MWD+IFR-AK-CA-SC(4,4) 14,60000 90.44 3/854 5.268.16 16.00 -298 50.90 4.50 16.86 2.92 9.53 61.65 097 131.69 MW +IFR -AK -CA -SC (4.4) 14,700.00 9044 66.54 5,267.39 16.84 -298 5129 4.50 16.69 2.92 9.58 8186 9.19 132.09 MWD+1FR-AK-CA-SC(4, 4) 14,800.00 90.44 346.54 5.265.62 1888 -2.98 51.61 -4,50 16.93 292 9.64 62.11 9A1 13220 MWD+IFR-AK-CP-SC(4,4) 14,90000 so" 346.54 5,265.84 16.92 .2.98 51.93 -4.50 1897 2.92 970 62.35 963 132A8 MWD+IFR-MKCO -SC (4,4) 15.000.00 90A4 Mem 5,26507 16.97 -2.98 52.26 4.50 Woo 292 9.75 62.59 985 132.67 MWD+IFR-AK-CA-SC(4.4) 15,100.00 9040 3/854 5.264.30 17.01 -2.98 52.60 3.50 9.50 2.92 981 62.83 10.06 13287 MWD+IFR-AK-CA-SC(4,4) 15,200.00 9044 34854 5,263.52 17.06 -2.98 5293 3.50 17.11 292 9.87 6308 1030 133.08 MWD+IFR-M-W-SC(4.4) 15,300.00 90.44 34654 5,262.75 17.11 -2.98 5327 4.50 17.16 291 993 63.33 10.53 133.28 MWWIFR-AI(LA-SC(4,4) 15,40000 90.44 306.54 5.261.98 17.16 -2.96 5362 -4.50 17.21 2.91 998 63.59 10.76 133.49 MW IFR-M-CAZ C(4, 4) 15,50000 9044 346.54 5,261.21 17.21 -2.98 5397 4.50 17.26 2.91 10.04 Das 10.98 133.69 MWD+IFR-AK-CA -50(4.4) 15,600.00 9044 3/6.54 5,26043 1726 -2.98 6.32 4.50 17.31 2.91 10.10 64.11 11.21 133.90 MWD+IFR-AK-CA-SC(4,4) 15,700.00 90.44 34854 5,25966 17.32 -298 5468 3.50 17.37 2.91 WAS 64.37 1143 134.11 MWOHFR-AK-CA-W(4,4) 15,800.00 9044 346.54 5,258.89 17.37 -298 5504 -4.50 17.43 291 1021 80.84 1166 134.32 MWD+1FR-AK-CA-SC(/,4) 15,90000 90.44 346.54 5.258.11 1743 -2.90 55.41 450 17.08 2.91 10.27 6,tsl 11.88 13/54 MM -IFR -MK- ,SC (4,4) 16.00000 9044 36.54 5,257.6 17.49 -2.98 55,78 -4.50 17.54 2.91 10.33 65.19 12.11 13475 MWD+IFR-AK-CA -50(4.4) 16,100,00 90u 6854 5,25657 17.56 -298 56.15 3.50 1761 2.91 10.39 65.47 1233 16.95 MWD+IFR-AK-CA-SC(4,4) 16,200.00 9044 34654 5,255.79 17.62 -298 5653 3.50 17,67 291 10.44 65.75 12.55 135.18 MWD+IFR-AK-CA2-SC(4,4) 16.30000 90.44 Us," 5,255.02 17.68 -2.98 5690 -450 17.74 2.91 1050 66.04 12.77 135.40 MWD+IFR-AK-CA-SC(4,4) 16,400.00 90.44 348.54 5,254.25 17.75 -2.90 57.29 -450 17.80 2.91 1056 65.32 12.99 13561 MWD+IFR-Pl(-CA-SG(4,4) 18.50000 90.44 Mem 5,25347 17.82 -2.98 57.67 -4.50 17.87 2.91 1062 88.62 1320 135.83 MWD+IFR-AK-CA-SC(4,4) 16,60000 90,44 6854 5,25270 17.89 -290 50.06 3.50 9.94 2.91 1088 6691 13.42 136.05 MWD+IFR-AK-CA-SC(0,4) 16,700.00 90.44 66.54 5,251,93 9.96 -298 5846 4.50 18.01 291 10.74 67,21 13.63 135.27 MWD+IFR-AK-CMSG(4,4) 16,800.00 90.4 3/6.54 5,251.15 16.03 -2.98 58.85 -4.50 18.08 291 10.80 67.52 13.85 136./9 MWD+IFR-AK-CA-SC(4,4) 16,900.00 9D.44 306.54 5,250.30 10.11 .2.96 59.25 4.50 1816 2.91 loss 67.82 1406 13871 MWD+lFR-AK-CA-SC,(3,4) 17,00000 9044 346.54 5,24961 18.16 -2.98 5865 -4.50 1823 2.91 10.91 88.13 1427 136.93 MWD+IFR-AK-CA SC (4,4) 17,100.00 90.44 68.54 5,24883 18.26 -298 60.06 -4.50 18.31 2.91 10.97 60.44 14.47 137.15 MW0+IFR-AK-CA-SC(4,4) 17,200.00 90,44 66.54 5,248.06 18.6 -298 80.47 3.50 18.39 2.90 11.03 68.76 14.68 137.37 MWD+IFR-AK-CAL-50(4.4) 17,300.00 9044 34654 5,247.29 18A2 -298 60.88 3.50 18.47 2.90 11.09 69.08 td86 137.59 MM -IFR -AK -CA -SC (4,4) 82/2018 6:51 20AM Page 6 COMPASS 5000.14 Build 85 Conocol"hillips Error Ellipse Report Company: ConocoPhillips(Alaska) Inc.-Kup2 Local Co-ordinate Reference: Project: Kupamk River Unit TVD Reference: Site: Kuparuk 3S Pad MD Reference: Well: Plan: 3S-611 North Reference: Wellbore: Plan: 3S-611 Survey Calculation Method: Design: 3S-611wp05 Output errors are at venical Warred. Database: Well Plan: 3S-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) True Minimum Curvature 1.00 sigma OAKEDMP2 Position uncertainty and bias at survey station Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape V) (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 35-611 T01.0 Heel Upde 0.00 0.00 5,116.70 Measured Inclination Azinuth veni"I Highelde 0.00 5,236.70 reterel Name venical Warred. samimaior eeptWitor - plan misses target center by 154.66usft Depth - Circle (radius 100.00) 3,001.50 Depth Evor site Eear at. Errdr Bias of Sias Emir Eeor A ftewh lhol (usft) I°) (°) lush) (usft) (usft) theft) )usft) )usft) Petal pan) (oeft) teeft) (°) 17,40000 9044 34654 5.246.52 18.50 -298 61.29 .0 18.55 2.90 11.15 6940 15.08 13781 MND+IFR-AK-CA-SC(4,4) 17,50000 9044 34854 5.24574 18.59 -2.98 61 ]1 -450 1863 2.90 11.21 ben 15.28 13003 MWD+1FR.M.0 -SC (4, 4) 17.600.00 9044 346.54 5,24497 1867 -2.98 62.13 -4.50 19]2 2.90 1127 70.06 15.48 138.25 MM+IFR-MKCA-SC pr 4) 17,700.00 9044 34em 5,24420 18.76 -298 62.65 -4.50 1880 2.90 1133 7039 15.60 13847 MWWIFR-W-CA -SG (4, 4) 17.80D00 9044 346.54 5,243.42 18.84 -2.90 62.97 1.50 1889 2.90 11.39 70,72 15.87 13869 MWD+IFR-AKCA-SC(4,4) 17,90000 9044 31654 5,24265 18.93 -290 6340 -4.50 10.98 2.90 1145 7108 16.06 13891 MWD+1FR-AK-CAASC(4, 4) 18.00001) 9044 34854 5.241.88 19.02 -2.99 6183 150 1907 2.90 11.51 7140 1825 139.12 MWD+IFR-AK-CA-W(4,4) 10.100.00 90.44 346.54 5,241A0 19.11 -2.98 64.26 450 19.16 290 11.57 71.75 16.44 139.34 MWDHFR-AK-CP-SC (4,4) 10,200.00 9044 346.54 5,24033 1920 -298 84.69 4.50 19.25 290 1163 72.10 16.62 139.56 MWD+IFR-AK-CAZSC(4,41 18,300.00 W.44 346.5t 5.23956 19.30 -2.98 65.13 1.50 19.34 2.90 11.68 7245 1681 13974 MWWIFR-AK-CA -SC (4,4) 18400.00 9044 34854 5,230.78 1939. -298 65.57 -4.50 1940 2.90 11.74 72.80 16.99 13999 MWD+1FR-AK.CM-60(4,4) 18,500.00 9044 34654 5,230.01 19.49 298 6601 4,50 19.53 290 118(1 73.16 17.17 140.20 VM+IFR-AK-CALSC(4, 4) 18,60000 9044 346.54 5,237.24 19.50 -298 68.45 -4.50 19.63 2.90 11.86 73.52 17.35 14042 MWD+1FR-Al(-CA -SC (4, 4) 1 sees 50 90.44 348.54 5,236]0 19.65 -2.98 66]6 1.50 1970 2.90 11.91 73.77 17.47 140.57 MWMIFR.MWC -SC (4.4) Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting -Shape V) (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 35-611 T01.0 Heel Upde 0.00 0.00 5,116.70 - plan hits target center Depth - Circle (radius 100.00) Diameter 3S-611 T02.0 Toe 12071 0.00 0.00 5,236.70 - plan hits target center Name -Circle (radius 100.00) 3S-611 T01.0 Heel 1207 0.00 0.00 5,276.70 - plan misses target center by 154.66usft at 12692.3lusft MD (5127.20 TVD, 6763.95 N, -7986.71 E) - Circle (radius 100.00) 3,001.50 3S-511 T01.5 Mid Updat 0.00 0.00 5,276.70 - plan misses target center by 16.81 usft at 15669.29usft MD (5259.90 TVD, 9642.86 N, -8675.95 E) - Circle (radius 100.00) 5,116.70 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 80.00 80.00 20" 20 42 3,001.50 2,565.00 10 3/4" x 13-1/2 10-3/4 13-1/2 12,651.33 5,116.70 7-5/8" x 9-7/8" 7-5/8 9-7/8 18,669.50 5,236.70 41/2" x 6-3/4" 4-1/2 6-3/4 822018 6.51: 20AM Page 7 COMPASS 5000.14 Build 85 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupawk River Unit Site: Kuparuk 3S Pad Well: Plan: 3S-611 Weflbom: Plan: 3S-611 Design: 3S-611wp05 Formations 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-611 WELL @ 66.70usft (Doyon 142) WELL @ 66.70usft (Doyon 142) Tme Minimum Curvature 1.00 sigma OAKEDMP2 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 1,428.52 1,400.70 Top Ugnu C 1,613.71 1,566.70 Base Permafrost 1,682.60 1,626.70 Top Ugnu B 1,834.20 1,757.70 Top UgnuA 2,149.77 2,015.70 Top West Salk 2,734.03 2,418.70 Base West Salk 3,229.87 2,668.70 C-80 5,709.64 3,325.70 C-50 8,070.70 3,930.70 C-35 8,730.24 4,099.70 Top Coyote (Top Nanushuk), K3 9,233.67 4,228.70 Base Coyote (Base Nanushuk) 12,651.33 5,116.70 Top Torok Oil Pool (Top Moraine) Plan Annotations Measured Vertical Local Coordinates Depth Depth «N/ -S -E/-W (usft) (usft) (usft) (usft) Comment 350.00 350.00 0.00 0.00 KOP: Start 1.5°/100' OLS, 315° TF, for 300' 650.00 649.69 8.33 -8.33 Start 2.5'/100' OLS, 0° TF, for 1021.39' 1,671.39 1,617.00 220.94 -220.94 Hold for 115.51' 1,786.91 1,717.00 261.82 -261.82 Start 2.5'/100' DLS, -10° TF, for 1214.6' 3,001.50 2,565.00 822.78 -899.99 Hold for 20' 3,021.50 2,574.96 833.75 -913.43 Start 3°/100' OILS, -7.08° TF, for 503.63' 3,525.13 2,765.94 1,120.87 -1,278.48 Hold for 7863.2' 11,388.34 4,780.61 5,725.27 -7,325.77 Start 3°/100' DLS, 95.21° TF, for 1263' 12,651.33 5,116.70 6,725.43 -7,977.49 Hold for 375' 13,026.33 5,212.75 7,077.96 -8,061.89 Start 3°/100' OILS, 0° TF, for 494.67' 13,521.00 5,276.45 7,553.67 -8,175.78 Adjust TF to 0°, for 14.77' 13,535.77 5,276.39 7,568.03 -8,179.22 Hold for 5133.74' 18,669.50 5,236.70 12,560.53 -9,374.48 TD: 18669.5' MD, 5236.7' TVD Checked By: Approved By: Date: I 8/2/2018 6:51:20AM Page 8 COMPASS 5000.14 Build 85 Pool Report � � / EE am E 5:26 AUgUSI OZ 2016 3S-611 wp05 Quarter Mile View WELLBORE TARGET N�e , D 35dtI T010 Heol 717 PIP P9116.)0 35-611 T020 TM 1IM71 PP 52]6.]0 3&611 TOL', HeN10]972 52]6]0 35611 T01.51h0 Uplale 0]2]10 PP527GI0 DETAILS (MAP O CHDINATES) Grde(R ilius: 1=00j mm) Grde 1Ra]ius'.1 MOD) Oi de Wins I=M) GNe (Ra'lius'. 1320.00) AC Wells Only 3g.611WP66 I. 3$'612WPp5 I. 12500 ` 2,"I z3, c it X0000 0 0 L N +7'5500 5 90 100 O z 8641° 5000 y,99 39,6522 2500— eo 52p0 525 01 -12500 -10000 -7500 -5000 -2500 N� 2500 5000 7500 ,saeo 8:22, August 022018 WELLBORE TARGET DETAILS (MAP C ORDINATES) 3J-611wp05 Quarter Mile View Name WE She, 3& 611 T01.0 Heel U ale 0]2]18 PEI 16.70 Ctrde(Redius: 13M W) 3&611 T02.0 Too 120]1] PP 5236.70 C4tle (R..ee. 1320,W) 3&611 TO1O Hee1120]1>PP 52]6]0 120710]2]18 PP 596.]0 Co 3&611 TO1S Mql 1320.W) l(R... peato o(R,deus13W.W) All Wells Drilled i 38'614WP�. I3V 12500 z3' I 0000 0 0 LON +7500 525QQ O Z 684v £5000 35-6'' �s 5199 5220 BftA @ �'Fb O Zok,® u� N a s O 2500 vo 52p0 5250 A^ g1 me 0 -12500 -10000 -7500 -5000 -2500 N� amo 2500 5000 7500 12500 0000 U) LO0 0 N +7500 0 z 3S'E'11W'Pp5.. 6041 5000 _ 5108...365229 .35.620 ___ r 6 0,p° O o ff' C/) % 2500 e. p165 rjw 52pp 5250 � ...6��0 0- -12500 —10000 —7500 —5000 —2500 0 West( -)/East(+) (2 00 us aT� 2500 5000 7500 WELLBORE TARGET DETAILS (MAP 060RDINATES) Name ND Shape 35611 TOIO IT. Uplale 092718 PB11670 GLde (FMiu: 1320.03) 35-611 T02.0 TAe IM717 PP 5236.70 Grde)R Yu5: 1320.M) 35611 T01.0 Heal 1M717 PP 52]6.]0 CmI. IRWIN, IM.Po) 35611 T01.5 MO UWa1e 0]2]18 PP 6]0 arde (Ramco: 1320.M) All Wells - Encroachment Only I� 6041 5000 _ 5108...365229 .35.620 ___ r 6 0,p° O o ff' C/) % 2500 e. p165 rjw 52pp 5250 � ...6��0 0- -12500 —10000 —7500 —5000 —2500 0 West( -)/East(+) (2 00 us aT� 2500 5000 7500 Surface Location Q CPAI Coordinate Conv From: _. _.. _ -_-_— To: - Datum NA083 Region: alaska Datum: NAp27 Region: falaska r' Latitude/Longitude DecimalDegrees —] T Latitude/Longkude IDearnalDegrees C UTM Zone: [— r South r UTM Zone: True r- South G State Plane Zone: I" J Units: ]s -It . f• State Plane Zone: Units: usfit . r Legal Description (NAD27 only) C' Legal Description W27 ony) - Starting Coordinates: -- -- .. -- Ending Coordinates:— X: 1616276.94 X: r476246.869583042 Y: 5993660.52 I Y: 5993909.98407128 i Transform Quit Help Surface Location Q CPAI Coordinate Converter •` From: _. - - To: Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska i r Latitudekongitude IDecimal Degrees C' Latitude/Longitude DecimalDegrees . r UTM Zone: F— r South f UTM Zone: True F- South G State Plane Zone: I' -7-] Units: us -It r State Plane Zone. F-----] Units: us.lt -71 R Legal Description (NAD27 ony) Starting Coordinates: -------- - - - --� X: 1616278.94 (- Legal Description ----- - - Township: 012 Range: Q08 IPF -El Y: 5993660.52 Meridian: Section: tg FNL . 2505.3759 FEL 1012.6780 _,Transform __ I Quit Help 3S-611wp05 Surface Casing `� r7 ® CPA: Coordinate MELML From. —__ FTo., Datum: NAD63 Region: alaska Datum: NAD27 Region: alaska f Latitude/Longitude Decimal Degrees Latitude/Longitude IDecimal Degrees C' UTM Zone r South,. r UTM Zane: True r South r• State Plane Zone: r--::] Units: us -ft { State Plane Zone: F�-:1 Units: usdt C Legal Description (NAD27 only) Legal Description (NAD27 only) - Starting Coordinates:— --- Ending Coordinates - --- - ---- - X: 1615381.70 X: 475349.647758197 Y: 5994486.12 Y: 5994735.60054177 Transform Quit Help 3S-611wp05 Surface Casing a. CPA: Coordinate Com• From: - _.__ _. __ _— ____- —._,. -To Datum: NAD83 Region: alaska Datum: NAD27 Reg alaska ' Latitude/Longitude Decimal Degrees C' Latitude/Longitude Decimal Degrees r UTM Zone: r South r UTM Zone: True r South <•' State Plane Zone: �� Units: us -ft r' Slate Plane Zone: I"� Units: urft Legal Description (NAD27 only) t- Starting Coordinates:--- - - - - --- X: 1615381.70 Legal Description------------------- TownsNp: 012 Range: 008 F:_1 Y: 15994486.12 Meridian: I� Section 18 • 1682.5901 FEL 1909.5899 I Transform _� Quit Heb 3S-611wp05 Production Horizon Q. CPA! Coordinate Camerter. From: _ _... _- _ To: Datum NAD83 Region alaska Datum: 1{AD27 - Region: alaska C Latitude/Longitude Decimal Degrees —] C Latitude/Longitude IDecimal Degrees (' UTM Zone: F— r South r UTM Zone: True r South G State Plane Zone: F4---Units: us-ft . [: State Plane Zone: I4 J Unds: us-ft f Legal Description (NAD27 only) r Legal Description [NAD27 only) Starting Coordinates: —. - Ending Coordinates:---- -- - X: 1608324.00 X: 468292.06441518 Y: 6000411.00 Y: 6000660.6465996 L ' _ Transform Quit Help 3S-611wp05 Production Horizon Q CPA! Coordinate Comerf o 0� From: -.- _ __—..___. .- FTo: — Datum: NAD83 Region: alaska Datum: NAD27 Region alaska C' Latilude/Longitude DecimalDegreesCLatitude/Longitude Decimal Degrees r UTM Zone: r— r South r UTM Zone: True r South F State Plane Zone: Units: us{t C' Stale Plane Zone: rq --�,] Urets: us4t s Legal Description (NAD27 only) - Starting Coordinates:--------- Legal Description - - ------ - X: 1608324.00 Townshp: 612 P'-1 Range: W7 1` 37 Y: 6000411.00 Meridian: IV J Sechon:12 FNL . 1063.6206 FEL 4187.6291 Quit Help J 3S-611wp05 TD From: -_-_ %]. CPA! Coordinate Converter Datum: NAD63 Region alaska Datum: NAp27 � Region: alaska From: To: C' Latitude/Longitude Decimal Degrees t' UTM Zone:1 r South Datum NA393 Region: alask� Datum: NAD27 Region: alaska i 7-3 f• State Plane Zone: F-7,7] Units C' State Plane Zone: rq--_�-] Umts: usdt . t' Latitude/Longitude Decimal Degrces—� {' Latitude/Longitude Decimal Degrees i F Legal Description [NAD27 only) Starling Coordinates: ---- (' UTM Zone: �- r South /' UTM Zane: True r South X. 1606946.00 Township: p12 fW:_] Range: 007 IT State Plane Zone: lq s u � Units.R . f• State Plane Zone:�� Units: us -ft Meridian: rU—� Section: r Legal Description (NAD27 only) i !" Legal Description (NAD27 only) Transform Quit Help -Slatting Coordinates:- - � Ending Coordinates: - -- - - - - - X. 1606946.00 X: 466914.233066515 Y: 6006250.00 V: 6006499.66690933 ,Transform _ Quit Help 3S -611w 05 TD fa, CPA[Coordinate Convert From: -_-_ -Tc:----—__-___ Datum: NAD63 Region alaska Datum: NAp27 � Region: alaska T Latitude/Longitude Decimal Degrees ] C' Latitude/Longitude Decimal Degrees t' UTM Zone:1 r South f UTM Zone: True r South f• State Plane Zone: F-7,7] Units C' State Plane Zone: rq--_�-] Umts: usdt . i - i F Legal Description [NAD27 only) Starling Coordinates: ---- -Legal Description- - X. 1606946.00 Township: p12 fW:_] Range: 007 Y: 6006250.00 Meridian: rU—� Section: fa, CPA[Coordinate Convert From: -_-_ -Tc:----—__-___ Datum: NAD63 Region alaska Datum: NAp27 � Region: alaska T Latitude/Longitude Decimal Degrees ] C' Latitude/Longitude Decimal Degrees t' UTM Zone:1 r South f UTM Zone: True r South f• State Plane Zone: F-7,7] Units C' State Plane Zone: rq--_�-] Umts: usdt . i - i F Legal Description [NAD27 only) Starling Coordinates: ---- -Legal Description- - X. 1606946.00 Township: p12 fW:_] Range: 007 Y: 6006250.00 Meridian: rU—� Section: FNL 510.33479 FEL 306.51249 Transform Quit Help As -built Appendix ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 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 ConocoPhillips ■ 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 7 ?ei33 M. U: ConocoPhillips Attachment 4: Drilling Hazards Summary 3S-611 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellaz 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 Miti ation Strategy 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 proEam, keep pipe 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 necessa , monitor for ue and dra . Davies, Stephen F (DOA) Davies, Stephen F (DOA) From: Thursday, August 9, 2018 10:48 AM Sent: 'Tolman, Ben V To: RE: [EXTERNAL)KRU 3S-611 (PTD 218-103) Request q Subject: Hi Ben,so there is my answer I looked in a GKA H2S report and found that 3S-620 measured 60 ppm H2S on Dec., 2017, should have remembered this report earlier. Sorry to waste your time. Thanks again, Steve Davies Alaska Oil and Gas Conservation Commission AOGCC 907-793-1224 including any attachments, contains information from the Alaska Oil and Gas Conservation Commission without first saving or forwarding CONFIDEN7IALITy NOTICE: This e-mail message, It may contain confidential and/or privileged information. The unauthorized review, use (AOGCC), State of Alaska and is for the sole use of the intended recipient(sl davies alaska.eo_v. violatestate contact Steve Davies at 907-793-1224 or (A disclosure CQ,a[ the AOGCC is a1ware of the m staon may ke o sending it to YOU, contact are an unintended recipient of this e-mail, please delete i , f such it, and, so From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Thursday, August 9, 2018 9:52 AM To: Davies, Stephen F (DOA) <steve.davies@alaska.g vuest Subject: RE: [EXTERNALjKRU 3S-613- (PTD 218-103) q Good deal. side, nothing has been noted on any I regarding H25. From a drilling could better answer if Sorry, I have been dragging my feet on the reply g nearby penetrations during dthe reservoirloln the productiong on a n soidee from aur production folks, they we have seen anything Thanks, Ben Tolman Alaska Drilling Engineer I Conocophillips, (907) 265-6828 (0) 1 (307) 231-3550 (m) From: Davies, Stephen F (DOA) < steve 4avieshalaska.hov> Sent: Thursday, August .V.TOI8 n(ccoMocophillips.com> To: Tolman, Ben \/ < Request Subject: RE: [EXTERNAL]KRU 35-611 (PTD 218-103) Inclination and Azimuth, but this is Thank you Ben. The format that you sent works perfectly. I really only need MD, great.H2S has been of the Torok Oil Pool wells or any of Did you have a chance to look into whether or not that have penetrated that poo17 encountered in any the nearby exploratorywells Thanks again, 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.davies(@alaska.gov. From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Sent: Wednesday, August 8, 2018 10:03 PM To: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-611 (PTD 218-103) - Request Not a problem. Any specific format your needing it in? Let me know if you need formatted differently. Thanks, Ben Tolman Drilling Engineer I ConocoPhillips, Alaska (907)265-6828(o)1(307) 231-3550(m) From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Wednesday, August 8, 2018 6:00 PM To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com> Subject: [EXTERNAL]KRU 3S-611 (PTD 218-103) - Request Ben, Could CPAI please provide the planned directional survey data for KRU 3S-611 in digital form (Excel spreadsheet or ASCII table)? Having these data in electronic format speeds permit processing. Thank you, Steve Davies Senior Petroleum Geologist AOGCC 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.daviesRalaska.eov. Remark: AOGCC PTD No. 218-103 Coordinate Check 8 August 2018 INPUT State Plane, NAD27 5004 - Alaska 4, U.S. Feet NorthingN: 5993909.98 EastinglX: 476246.87 Convergence: -0 10 55.41250 Scale Factor: 0.999900641 OUTPUT Geographic, NAD27 KRU 3S-611 1f1 Latitude: 70 23 40.17191 Longitude: 150 11 35.74807 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: le tll( PTD: Z/" -/D Development —Service —Exploratory _ Stratigraphic Test Non -Conventional FIELD: (t Y Lc /� C�j v� ✓ POOL:ZXL 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' sam le 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 ar also required for this well: �cl%c Well Logging cr++t Lig 5�" G c tis Requirements o `, 2�) 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#:2181030 Company CONOCOPHILLIPS ALASKA, INC. Initial Class/Type _DEV Well Name: KUPARUK RIV UNIT 3S-611 Program DEV Well bore seg ❑ / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration '17 Nonconven. gas conforms to AS31,05.0300.1.A),Q.2.A-D) _ _ _ _ _ _ _ _ _ _ NA. 1 Permit fee attached _ ... NA 2 Lease number appropriate.. _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Surfers Location lies within ADL0380107; Portion. of Well Passes Thru ADL0380106; 3 Unique well. name and number ........ _ _ _ Yes _ Top. Prod Int& TO lie within ADL0025528. 4 Well located in.a defined pool. _ _ _ Yes 5 Well located proper distance from drilling unit boundary. _ _ _ _ _ _ _ _ _ _ .. - Yes KUPARUK RIVER,_TOROK OIL — 490169 governed by Conservation Order 725. 6 Well located proper distance from other wells _ _ _ _ _ _ _ _ _ _ _ _ Yes CO 725, Rule 3 Well Spacing: There shall be no restrictions as. to wellspacing except that. no pay _ 7 Sufficient acreage. available in. drilling unit _ _ Yes _ _ shall be opened to a well within 500 feet of an externalproperty line where the owners and 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes landowners are not the same on both sides of the line. As proposed, well will conform to. 9 Operator only affected party. .. ... Yes spacing requirements... 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 SFD 8/8/2018 13 Can permit be approved before 15 -day wait. _ _ _ _ _ Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For: NA 15 All wells within 1/4. mile area. of review identified (For service well only). _ _ _ _ _ _ _ _ _ _ _ NA .... . 16 Pre -produced injector: duration of pre production less than 3 months (For service well only) _ NA 18 Conductor string provided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .......... Yes ... _ 80' conductor provided Engineering 19 Surface casing protects all known U&DWS .. _ _ _ Yes _ Surface casing set to 3002' MD 20 CMT vol adequate to circulate on conductor & surf csg ....... Yes _ 138% 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 uncemented slotted liner 23 Casing designs adequate for C,. T, B 8_ permafrost......... _ _ _ _ _ _ _ _ _ _ Yes 24 Adequate tankage or reserve pit _ _ Yes _ Rig has steel tanks., all waste. to approved disposal wells _ 25 If a 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 diverter required, does it meet regulations _ _ _ .. _ Yes Appr Date 28 Drilling fluid. program schematic .& equip list adequate _ _ _ _ Yes _ _ _ _ Max formation pressure is. 2150 psig(8.08 ppg-EMW); will drill w/ 8,8-10,0 ppg EMW _ VTL 8/28/2018 29 BOPES,. do they meet regulation _ _ _ . _ _ Yes 30 BOPE.press rating appropriate; test to (put psig in comments) .... ..... . . . . . . . . Yes _ _ MPSP is 1638 psig; will test BOPsto 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 1-12S gas probable.... _ _ _ _ _ _ .. Yes H2S measures required _ _ _ ......... _ 34 _Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ _ _ . NA .. . 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 _ _ _ _ _ _ Expected reservoir pressure is 8.4 ppg EMW; will be drilled with 8.8 - 10 ppg_mud. Appr Date 37 Seismic analysis of shallow gas. zones .. NA _ Some potential for encountering gas hydrates and some. potential for lost circulation. Mitigation SFD 8/9/2018 38 Seabed condition survey (if off -shore) _ _ _ _ _ _ _ _ _ _ _ .. NA. _ _ _ _ measures discussed in Drilling Hazards section.... 39 Contact name/phone for weekly, progress reports [exploratory only.]. NA. Geologic Engineering Public Date: Date Date Commissioner: Commissioner: Commissioner ti is 1111119 ?�e
