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214-167
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O N f-▪ : o m zc STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate Pull Tubing r Operations Shutdown r Performed: Suspend p r Perforate r Other Stimulate r Alter Casing r Change Approved Program Plug for Redrill n Perforate New Pool fl Repair Well Re-enter Susp Well Other: i'-" 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development f" Exploratory r 214-167-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20695-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380107,25544,25528 KRU 3S-620 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Meltwater Oil Pool 11.Present Well Condition Summary: Total Depth measured 13768 feet Plugs(measured) none true vertical 5215 feet Junk(measured) none Effective Depth measured 13655 feet Packer(measured) 9093, 9144 true vertical 5218 feet (true vertical) 5148, 5161 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 106 106 SURFACE 3116 10.75 3145 3145' INTERMEDIATE 9253 7.625 9279 5185 LINER-41/2" 4511 4.5 13655 5218 RECEIVED MAY 2 9 2015 Perforation depth: Measured depth: frac ports from 9981-13584 AOGCC True Vertical Depth: 5249-5224 %OW APR 0 12016. Tubing(size,grade,MD,and TVD) 4.5, L-80, 9150 MD, 5162 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PRODUCTION PACKER @ 9093 MD and 5148 TVD PACKER-BAKER HRD-E ZXP @ 9144 MD and 5161 TVD NIPPLE-CAMCO DB NIPPLE @ 504 MD and 504 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9970-13300 Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development Service r Stratigraphic ii Copies of Logs and Surveys Run cAY) 16.Well Status after work: Oil Gas fl WDSPL fl Printed and Bectronic Fracture Stimulation Data ri GSTOR r VVINJ n WAG r GINJ r SUSP '" SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-135 Contact Sindy Tam (c�265-6830 Email Sindy.P.Tam(c�conocophillips.com Printed Name Sindy'Tam Title Well Design Engineer Signature Phone:265-6830 Date 6— ,. / v-T` 3/ 7.-11(,.. caw )o1oS�ir RBDRAS- JUN - 3 2015 .. E p re cc ,ic.d 1$Mar t( Form 10-404 Revised 5/2015 /l l?/ "‘ Submit Original Only KUP PROD • 3S-620 , 4 ConocoPhaIips ; Well Attributes Max Angle&MD TD Alaska.InC Wellbore API/UWI Field Name Wellbore Status ncl("I MD(ftKB) Act Btm(ftKB) c...JR.luy 501032069500 TRACT OPERATION MORTRO2 PROD 9328 13,310.99 13,768.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 35-620,5/13/20159.36;56 AM SSSV:NIPPLE Last WO: 27.50 2/19/2015 Vertical schematic(accuah Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:MILLED FRAC PORT IDs hipshkf 5/13/2015 HANGER,24.2- iiiillikilk. ......... `r ........Casing Strings Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth IND)... Wt/Len(I...Grade Top Thread fes` CONDUCTOR 16 15.250 29.4 106.0 106.0 164.80 B-35 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread SURFACE 103/4 9.950 28.9 3,145.0 2,548.0 45.50 L-80 HYD 563 CONDUCTOR;29.4-106.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 26.4 9,279.4 5,186.3 29.70 L-80 Hyd 563 NIPPLE;504.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WI/Len(I...Grade Top Thread LINER-41/2" 41/2 3.958 9,144.0 13,655.0 5,C22.0,„.5 12.60 L-80 IBTM GAS LIFT;3,028.8 Liner Details I I Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl I") Item Des (in) 9,144.0 5,160.6 76.46 PACKER BAKER HRD-E ZXP W/HD's 4.810 SURFACE;28.93,145.0 - 9,166.0 5,165.6 77.33 NIPPLE BAKER RS NIPPLE 4.250 GAS LIFT;S,W9.3 9,168.4 5,166.1 77.42 HANGER BAKER FLEX-LOCK HANGER 4.850 9,707.3 5,232.0 82.84 SWELL PACKERS PLUS SWELL PACKER"H" 3.958 PACKER 9,980.8 5,249.1 89.38 FRAC PORT PACKERS PLUS FRAC PORT W/2.0625"SEAT 3.625 GAS LIFT;6,557.9 (2.1250"BALL)-MILLED TO 3.625 10,238.3 5,255.2 88.31 SWELL PACKERS PLUS SWELL PACKER"G" 3.958 GAS LIFT;7,7&5.1 PACKER M 10,513.0 5,260.9 89.08 FRAC PORT PACKERS PLUS FRAC PORT W/2.0"SEAT 3.625 (2.0625"BALL)-MILLED TO 3.625 GAS LIFT;8,8126 �... 10,772.6 5,259.3 91.05 SWELL PACKERS PLUS SWELL PACKER"F" 3.958 PACKER 11,047.4 ' 5,254.6 90.31 FRAC PORT PACKERS PLUS FRAC PORT W/1.9375"SEAT 3.625 NIPPLE;9505.9 (2.0"BALL)-MILLED TO 3.625 iik. GAUGE;9027.3 __ 11,304.7 5,255.7 89.79 SWELL PACKERS PLUS SWELL PACKER"E" 3.958 PACKER MI. irk11,582.5 5,255.1 90.26 FRAC PORT PACKERS PLUS FRAC PORT W/1.8750"SEAT 3.625 PACKER;9,093.2 (1.9375"BALL)-MILLED TO 3.625 11,802.9 5,256.3 89.16 SWELL PACKERS PLUS SWELL PACKER"D" 3.958 NIPPLE;9,120.0 PACKER SUB,NO GO;9,139.0 12,078.1 5,253.3 90.77 FRAC PORT PACKERS PLUS FRAC PORT W/1.8125"SEAT 3.625 SOS;9,140.0 7 (1.8750"BALL)-MILLED TO 3.625 F11l 12,299.5 5,249.7 90.43 SWELL PACKERS PLUS SWELL PACKER"C" 3.958 rr PACKER rl I1 12,556.7 5,245.0 91.47 FRAC PORT PACKERS PLUS FRAC PORT W/1.75"SEAT 3.625 ,.,�,.. (1.8125"BALL)-MILLED TO 3.625 I ' I 12,822.1 5,2420 89.96 SWELL PACKERS PLUS SWELL PACKER"B" 3.958 PACKER INTERMEDIATE;26.49,279.4 13,101.8 5,243.2 89.51 FRAC PORT PACKERS PLUS FRAC PORT W/1.6875"(1.75" 3.625 BALL)-MILLED TO 3.625 13,364.6 5,235.4 93.13 SWELL PACKERS PLUS SWELL PACKER"A" 3.958 PACKER II Tubing Strings I PERFP;9.980.&9,983.5 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth)ND)I...Wt(I Mt) Grade Top Connection TUBING 41,'2 3.958 24.2 9,150.3 5,162.0 12.60 L-80 IBTM Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 24.2 24.2' 0.00 HANGER FMC TUBING HANGER 3.958 PERFP;10,513.0.10,515.8 504.3 504.0 2.83 NIPPLE CAMCO DB NIPPLE 3.875' 9,005.9 5,123.2, 72.17 NIPPLE CAMCO DB NIPPLE 3.813 9,027.3 5,129.6 72.88 GAUGE SCHLUMBERGER GAUGE CARRIER 3.879 Hydraulic Fracture;9,970.0 9,0932 5,148.0 74.81 PACKER BAKER PREMIER PRODUCTION PACKER 3.760 PERFP;11,047.011,050.2 II, I 9,120.1 5,154.8 75.64 NIPPLE CAMCO DB NIPPLE 3.687 9,139.0 5,159.4 76.26 SUB,NO GO FLUTED NO GO SUB 3.950 9,140.0 5,159.6' 76.30 SOS SHEAR PIN 3.950 9,149.2 5,161.8 76.67 SHOE MULE SHOE 3.950 PERFP;11,582.5-11,585.3 11 Perforations&Slots Shot Dens Top(ND) Btm)TVD) (shots/f Top(ftKB) Btm(IBB) (ftKB) (ftKB) Zone Date t) Type Com I 9,980.8 9,983.5 5,249.1 5,249.1 2/14/2015 PERFP Frac Port 1 10,513.0 10,515.8 5,260.9 5,260.9 2/14/2015 PERFP Frac Port PERFP;12,078.1-12,080.9 # 11,047.4 11,050.2 5,254.6 5,254.6 2/14/2015 PERFP Frac Port 11,582.5 11,585.3 5,255.1 5,255.1 2/14/2015 PERFP Frac Port 12,078.1 12,080.9 5,253.3 5,253.2 2/14/2015 PERFP Frac Port 12,556.7 12,559.5 5,245.0 5,244.9 2/14/2015 PERFP Frac Port 13,578.5 13,584.3 5,224.5 5,224.2 2/14/2015 PERFP Perf Pup PERFP;12,556.7-12559.5 I Stimulations&Treatments Hydraulic Fracture;11.852.5 Min Top Max Btm I Depth Depth Top IND) Btm(ND) (5KB) (ftKB) (ftKB) (ftKB) Type Date Com 9,970.0 13,300.0 5,249.0 5,256.6 Hydraulic 5/7/2015 PUMPED LAST 4 STAGES,EST 803K LBS 16/20 Fracture PROPPANT I I 9,970.0 13,300.0' 5,256.6 5,239.0 Hydraulic 5/7/2015 PUMPED LAST 4 STAGES,EST 803K LBS 16/20 I Fracture PROPPANT Mandrel Inserts . -. - St III a8 OP Top(ND) Valve Latch Port Size TRO Run PERFP;13,578.5-13,584.3 :lit i N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 3,028.8 2,494.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 LINER-4 1/2";9,144.013,655.0 KUP PROD • 3S-620 ConocoPhillips Alaska,Inc, C:..aJINGpJ 35-620,5/132015 9.36.57 AM Vertical schematic(actual) HANGER,24.2- ,iitindlie-: Mandrel Inserts st 11.1111111P1 I Oun Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com CONDUCTOR;29.4-106.0 2 5,009.3 3,390.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 3 6,557.9 4,090.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 NIPPLE;504.3 ' 4 7,785.1 4,646.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 5 8,812.6 5,059.7 CAMCO KBMG 1 GAS LIFT SPG BK 0.000 0.0 4/27/2015 DCK-2 GAS LIFT;3,028.8 IF Notes:General&Safety J 4 End Date Annotation NOTE:7 5/8"Casing weight change:29.7#x 39#@8841.88 SURFACE;28.9-3,145.0 GAS LIFT;5,009.3 GAS LIFT;6,557.9 • GAS LIFT;7,785.1 GAS LIFT;8,812.6 Y� ■ NIPPLE;9005.9 GAUGE;9,027.3 PACKER;9,093.2 • NIPPLE;9,120.0 SUB,NO GO;9,139.0 SOS;9,140.0 F" J 71 I � t INTERMEDIATE;26.4-9,279.4 I ' PERFP;9,980.8-9,983.5 ? : 1 1 PERFP;10,513.0.10,515.8 Hydraulic Fracture,9,970.0 PERFP;11,047.3-11,150.2 1 PERFP;11.582.5-11,585.3 PERFP;12,078.1-12,080.9 1._ . PERFP;12,556.7-12,559.5 1 Hydraulic Fracture;11,852.5 1 1 PERFP;13,578.5-13,584.3 IIEE LINER-4 1/7,9,144.0.13,655.0 3E120 FRAC SUMMARY . DATE SUMMARY 3/14/2015 SET BAITED PULLING TOOL ON BALL & ROD @ 9100' SLM; PULLED SOV AND REPLACED WITH DV @ 8812' RKB. IN PROGRESS 3/15/2015 MITT TO 3000 PSI PASSED; PULLED BALL & ROD; PULLED RHC @ 9120' RKB; MEASURED SBHPS @ 9326' RKB: MAX PSI 2648. COMPLETE 4/26/2015 PUMPED PORTLAND TYPE 1 CEMENT INTO CONDUCTOR (COMPLETE) 4/27/2015 TAGGED DB @ 9005' RKB. WORKED HANGER AREA WITH 3.86" SWAGE. SET 3.813" CAT SV @ 9005' RKB. PULLED DV @ 8812' RKB, SET SPG @ SAME. ATTEMPTED MIT TBG, FAILED. MIT-IA PASSED. IN PROGRESS. 4/28/2015 MITT (PASS); PULLED 3.813" CSV @ 9005' RKB; SWAGE TIGHT SPOT @ 1' OPEN TO 3.86"; UNABLE TO WORK 3.905 SWAGE THRU TIGHT SPOT; IN PROGRESS. 4/29/2015 ATTEMPTED TO SWAGE OUT TBG HANGER TO 3.89" & PARTED WIRE; AFTER DISPENSATION APPROVAL, KILLED WELL W/ 380 BBLS 10.7 BRINE; PERFORMED NO FLOW TEST FOR 30 MIN. SECURED WELL W/ SECONDARY SWAB; FISHED TS. & DRIFT TO TBG DOWN TO 600'W/ 2.625" STEM. PERFORM 2 CALIPER PASSES F/600' TO SURFACE (FP W/40 BBLS DIESEL). IN PROGRESS WAITING ON CALIPER DATA. 5/4/2015 Pumped data frac and first 4 stages of fracture stimulation treatment of the Moraine (est. 522k 16/20 proppant total placed in well). Well freeze protected w/45 diesel. 5/7/2015 Pumped last 4 stages of fracture stimulation treatment of the Moraine (est.803k 16/20 proppant placed in last 4 stages). Well freeze protected w/45 diesel. 5/11/2015 COMPLETE WEEKLY BOPE TEST. MILL THRU PACKERS PLUS FRAC SLEEVES @ 9980', 10513' & 11047' RKB WITH DIESEL W/776 & DIESEL GEL. 24 HOUR OPPS IN PROGRESS. 5/12/2015 MILL FRAC SEATS @ 11,583', 12,078,12,556, 13,101. LOG FROM 9100' TO 13591'W/MEMORY SPECTRASCAN GAMMA LOGGING TOOL. WELL READY FOR SLICKLINE. 5/15/2015 WEATHER-DELAYED START. GAUGED TBG TO 2.69"TO 9190' SLM. MEASURED BHP @ 9190' SLM: 2263 PSI. IN PROGRESS. 5/16/2015 GAUGED TBG TO 3.83"TO 9005' RKB. SET 3.81 DB LOCK @ SAME. SET BAITED PRONG &TESTED TBG, GOOD. PULLED SPG FROM 8812' RKB. READY FOR CIRC OUT. IN PROGRESS. 5/17/2015 PUMPED 370 BBL DSL DOWN IA UP TBG, TAKING RETURNS TO PRODUCTION VIA 3S-18. READY FOR S/L GLVs. 5/18/2015 SET OV @ 8805' SLM. PULLED/REPLACED DV @ 7780' SLM. PULLED DV @ 6550' SLM. IN PROGRESS. 5/19/2015 SET DV @ 6550' SLM. PULLED/REPLACED DV @ 4997' SLM. PULLED DV @ 3017' SLM. IN PROGRESS. 5/20/2015 SET GLV @ 3028' RKB. TBG x IA COMMUNICATION. REPLACED GLV WITH BOTTOM LATCH GLV, SAME RESULT. REPLACED WITH EXT PKG DV, SAME RESULT. IN PROGRESS. 5/21/2015 WITH HOLEFINDER BELOW GLM @ 3028' RKB, TBG FAILED TEST. H/F ABOVE GLM, TBG TEST PASSED. PULLED DV @ 3028' RKB. REPLACED WITH NEW. TBG x IA COMMUNICATION CONTINUES. IN PROGRESS. 5/22/2015 SET HOLEFINDER @ 3092' SLM, EST. 3102' RKB, TESTED TBG, PASSED: LEAK BELOW GLM @ 3029' RKB. PULLED DV SET GLV @ 4997' SLM. READY FOR E/L. 5/23/2015 PERFORM LEAK DETECAliALIPER SURVEY. LOGGED 24 ARM CatER FROM 8968'TO SURFA BLEED DOWN IA TO 200 PSI AND BOLWS AT '0.5 BPM WHILE LOGGING LEAK DETECT LOG. TUBING IMMEDIATELY PRESSURE UP TO 3000 PSI AND HOLDING DURING LOGGING. LOG PAST THE SUSPECTED ZONE BELOW THE GLM AT 3028'. NO OBVIOUS CHANGE IN SPINNER OR TEMERATURE. PEFORM 30 MINUTE MIT AT 3000 PSI ONCE ON SURFACE. MIT PASS. INSTRUCTED TO RIG DOWN PER CWG REP. LOG CORRELATED TO TUBING TALLY RECORD DATED 17-FEB-2015. JOB COMPLETE. • • Client: ConocoPhillips Alaska Inc. SChillMbePller Well: 35-620 Basin/Field: Colville Delta/Alpine State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Post-Job Well Completed: 5/7/2015 Date Prepared: 5/13/2015 9:23 AM Report ID: RPT-36843 Fluid Name&Volume _ Additive Additive Description Concentration Volume F103 Surfactant 1 Gal/1000 Gal 643.0 Gal J218 Breaker1 0.5 Lb/1000 Gal 286.0 Lb J475 Breaker 8.3 Lb/1000 Gal 5,253.0 Lb J532 Crosslinker 2.9 Gal/1000 Gal 1,831.0 Gal g YF127ST:WF127 629,538 Gal 29.8 Lb/1000 Gal 18,789.0 Lb J580 GellingAgent L065 Scale Inhibitor 2.1 Gal/1000 Gal 1,329.0 Gal M002 Additive 0.7 Lb/1000 Gal 439.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 207.0 Lb S100 Fluid Loss Additive varied concentrations 14,951.0 Lb S522-1620 Propping Agent . varied concentrations 1,413,792.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* 78.02534 % 66402-68-4 Ceramic materials and wares,chemicals 21.13681 % 9000-30-0 Guar um 0.28020 14808-60-7 Quartz,Crystalline silica 0.22355 % 7727-54-0 Diammonium peroxitlisulphate 0.06832 % 56-81-5 1,2,3-Propanetriol 0.06397 % 107-21-1 Ethylene glycol 0.03973 % 1303-96-4 Sodium tetraborate decahydrate 0.03838 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 0.03716 % 111-76-2 2 butoxyethanol 0.01444 % 67-63-0 Propan-2 of 0.01444 % ................ -_......... 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.01388 % 7647-14-5 Sodium chloride 0.00750 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) 0.00722 % 68131-39-5 C12-15 alcohol ethyoxylated 0.00722 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) 0.00722 % 1310-73-2 Sodium hydroxide(impurity) 0.00676 % 10043-52-4 Calcium Chloride 0.00379 % 91053-39-3 Diatomaceous earth,calcined 0.00155 % 7631-86-9 Non-crystalline silica(impurity) 0.00070 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00042 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00040 10377-60-3 Ma nesium nitrate 0.00031 % 9002-84-0 poly(tetrafluoroethylene) 0.00018 % 26172-55-4 5-chloro-2-meth I-2h-isothiazolol 3 one 0.00017 7786-30-3 Magnesium chloride 0.00015 % 7447-40-7 Potassium chloride(impurity) 0.00012 % 2682-20-4 2-methyl-2h isothiazol 3-one 0.00005 % 14464-46-1 Cristobalite 0.00003 % Total 100% *Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. l Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 • • . . ProTechnics Division 6510 West Sam Houston Parkway North 4,97A: Hosuton,Texas 77041 4,, Phone:713-328-2320 Fax:713-328-2163 re www.corelab.com Mrstwn s aencOF w Tracing Records for: Operator: ConocoPhillips Alaska, Inc Well Name: 3S-620 Stage 1 May 4,2015 1— Trade NimeAdditive e bdai -e 1i( .;: dAW.. .. Number Loading-Rate- _ CFT1400 Tracer "Trade Secret Status" 0.00005%by weight;Y OFT5600 Tracer "Trade Secret Status" 0.00005%by weight IRZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan 'urn minor 1113866-2 Stage 2 May 4,2015 Tradei Chemical NumberLoadingRate , _ CFT1100 Tracer "Trade Secret Status" ° 0.00005 /o b wei•ht OFT5700 Tracer 'Trade Secret Status" 0.00005%b wei•ht SCZW Tracer Trade Secret Status" 0.00005%b wei•ht Carrier Fluid Carrier Fluid Water ma'or 7732-18-5 0.00037%by weight Methanol ma'or 67-56-1 Di.ro• lene .1 col meth I ether minor 34590-94-8 Xanthan sum minor 1113866-2 ; Stage 3 May 4,2015 -Trade CAS Num ata; CFT1200 Tracer "Trade Secret Status" •..i., ° • weis t OFT5800 Tracer Trade Secret Status" 0.00005%blj SBZW Tracer "Trade Secret Status" 0.00005%b wei•ht [Carrier Fluid Carrier FluidWater(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan .um minor 1113866-2 Stage 4 May 4,2015 Trae Name Chemical ComPeund Name "+ Number Rate , CFT1300 i Tracer "Trade Secret Status" 0.00005%b wei ht' OFT5900 Tracer "Trade Secret Status" 0.00005%by weight IRZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732 18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 i Stage 5 May 7,2015 • • : Trade Name Additive Type , Chemical Conner Loadino CFT1700 Tracer "Trade Secret Status 0.00005%b weight {OFT5500 Tracer "Trade Secret Status 0.00005%b wei•ht Ei2111111111111 Tracer "Trade Secret Status 0.00005%b wei•ht Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 6 May 7,2015 �..: ode Natne'= t _thetni4"aQ i x �t CFT2000 Tracer "Trade Secret Status 0.00005%b weight OFT5200 11 "Trade Secret Status" 0.00005%b weight SBZW Tracer "Trade Secret Status" 0.00005%b weight Carrier Fluid Carrier Fluid Water ma.or 7732-18-5 0.00037%by weight IIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIIIIIII Methanol ma.or 67-56-1 1.1111111111111111111111 Di•ro• lene •I col meth I ether minor 34590-94-8 IIIIIIIIIIIIIIIIIINIIIIIIIIIIIIIII 4590 94 8 IIS Xanthan •um minor 1113866-2 Stage 7May 7,2015 e ja Ate 4 -obernica Po d tAb ! Rafe Ww CFT1900 1 Tracer 1 "Trade Secret Status" 0.00005%b weight OFT5000 Tracer "Trade Secret Status" 0.00005%by weight IRZW Tracer "Trade Secret Status" 0.00005%by weight jCarrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 1 Stage 87 May 7,20155i '' p .,:, (Additive II 7^"�': ... Chi i7 u 2v. ...0nd rvm zr ti tW..<- e ii_s 'Loa .--._.,Rate oy' L ,CFT2200 Tracer "Trade Secret Status" 0.00005%b wei•ht OFT5100Tracer "Trade Secret Status" 0.00005%b weight, SCZW Tracer "Trade Secret Status" 0.00005%b wei•ht Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 ........ 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cpri - I (7 Well History File Identifier Organizing(done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: figs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: I DI V 15 /s/ M P Project Proofing BY: Maria Date: I ,,.� S /s/ r P Scanning Preparation 5 x 30 = 15& + o...(0 =TOTAL PAGES ) 7 6 (Count does not include cover sheet) ifi BY: Date: ! g 16— /s/ 1 Production Scanning Stage 1 Page Count from Scanned File: j 7 7 (Count does include cove sheet) Page Count Matches Number in Scanning Preparation: 1/ YES NO BY: Maria Date: { Ti/5 /s/ Op I Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: mg Digital version appended by: Meredith Michal Date: 12101 I ( S /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: acll Scanning is complete at this point unless rescanning is required. 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E N U Zi Uo O E N Q ° a (/) U M I- in Z o COco rt N Y • a) °3 m m D Q o Yp o Il Qa o CI d U co z d LO v • ,n o 0 N N N CO 7 LO N N N ff- ; i i Guhl, Meredith D (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Thursday, September 24, 2015 12:57 PM To: Guhl, Meredith D (DOA) Subject: RE: KRU 3S-620, PTD 214-167, Complete list of Geologic Markers required Attachments: 3S-620_final_tops_ForState.xlsx Meredith, Here are those tops for Moraine. Don't hesitate to call for anything. Thanks, Steve From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, September 24, 2015 8:20 AM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]KRU 3S-620, PTD 214-167, Complete list of Geologic Markers required Steve, During a review of the 10-407 form submitted for KRU 3S-620, PTD 214-167, completed 2/18/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the top of the K3, base of the K3, and top of the Moraine are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 8, 2015. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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, 1 please delete it,without first saving or forwarcit,and,so that the AOGCC is aware of the mistake ending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl(E)alaska.gov. 2 • • 3S-620 * Name MD (feet) TVD (feet) TVDSS (feet) T-3 617 616 564 K-15 762 761 708 UG_C 1399 1387 1335 PFROST 1582 1557 1505 UG_B 1654 1621 1568 UG_A 1800 1745 1693 NA 1889 1817 1765 NB 1929 1850 1797 NC 1974 1884 1832 NF 2108 1984 1932 WS_TOP 2122 1994 1942 WS_U 2122 1994 1942 WS_D 2122 1994 1942 WS_C 2196 2047 1994 WS_B 2226 2067 2015 WSL 2267 2095 2043 WS—_A4 2267 2095 2043 WS_A3 2339 2142 2089 WS_A2 2454 2212 2159 WS_A1 2638 2313 2260 WS BASE 2867 2420 2367 CAMPANIAN_SS 3215 2580 2528 C-35 6182 3920 3868 K-3 6534 4080 4027 TOPSET_BASE 6890 4241 4189 TOP_MORAINE 9110 5152 5100 TOP_MEGATURB 9699 5231 5179 BASE_MEGATURB 9782 5240 5188 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 12, 2015 Attn.: Meredith Guhl 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED OCT 14 2015 RE: 3S-620 : 50-103-20695-00 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3S-620 Memory Multifinger Caliper Survey 1-May-15 1 color log 25 b t" Multi Finger Caliper Report 1-May-15 1 report 24 Arm Caliper Log 23-May-15 1 color log d6611 Multi Finger Caliper Report 23-May-15 1 report PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com • S Date: ` II Signed: _ CoriocoPhillips TRANSMITTAL AAfr FROM: Sandra D. Lemke,ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave.,Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 35-620 DATE:06/09/2015 Transmitted: Kuparuk River Unit, Alaska 3S-620 1 CD and hardcopy report UrT J G S 6 I 'r'v\ 1n ' 1-AS Revised-portion of the log display missing in original distribution Halliburton-Surface data logging and End of Well report-mud logging data for 3S-620; 01/17/2015; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations,one set each for wellbore 1 color print each: Formation Evaluation 2"MD Gas ratio 2"MD Drilling Engineering 2"MD !Please promptly sign,scan and return electronically to Sandra.D.Lemke ai OP.com CC: 3S-620 transmittal folder, production well files,eSearch R E C E I V E D 1, Receipt: /�� _ Date:. L J 31 2015 AOGCC "Ammommisk‘ GIS-Technical Data Management I.ConocoPhillips (Anchorage, Alaska I Ph: 907 265.6947 2_5 cd WELL LOG TRANSMITTAL DATA LOGGED "1/1/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. June 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUN 19 2015 RE: Multi Finger Caliper (MFC)/Leak Detect Log: 3S-620 OGOC Run Date: 5/23/2015 RE-SEND "E-Set#25879" The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3S-620 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20695-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMI'1"1'AL LE 1"I LR TO THE A FI ENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 5_e6c.€ 214167 25 879 WELL LOG TRANSMITTAL DATA LOGGED /14,/2015 ivl.K.BENDER To: Alaska Oil and Gas Conservation Comm. June 2, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 VD JUN 0 4 ZO15 RE: Multi Finger Caliper(MFC)/Leak Detect Log: 3S-620 Run Date: 5/23/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3S-620 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20695-00 Leak Detect Log 1 Color Log 50-103-20695-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: iiirak, • • ConocoPhillips Alaska '���! u1 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 '.0 0 r. . June 22, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: 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(one with carbolite) 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 MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, r ////7 / MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc, Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 6/22/2015 1 E,1Y,2E,2F,2M,2N,2V,3N&3S Pads Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 1E-32 50029227880000 1971320 15" na 15" na 1.8 6/18/2015 1Y-10 50029209340000 1830510 36' 3.70 13" 5/10/2015 4.6 6/20/2015 2E-02 50029235170000 2140780 9' 0.60 24" 6/14/2015 5.1 6/16/2015 2E-03 50029235090000 2132030 4' 0.62 7" 6/13/2015 3.9 6/16/2015 2E-04 50029235050000 2131680 10' 1.29 19" 6/15/2015 7.7 6/16/2015 2F-20 50029227390000 1970160 6' 0.80 13" 4/20/2015 3 6/20/2015 2F-21 50029223525000 2141360 22" 0.10 22" 4/25/2015 15.3 6/19/2015 2F-22 5002923530000 2141500 64" 1.10 17" 4/25/2015 11.5 6/19/2015 2M-36 50103206910000 2141020 8'7" 0.70 10" 5/23/2015 2.1 6/20/2015 2N-322 50103206780000 2131790 13" na 13" na 2.5 6/19/2015 2V-02 50029210370000 1831610 11" 1.00 14" 5/20/2015 2 6/16/2015 3N-11A 50029215800100 2120950 34' 27 cu.ft carbolite 10" 5/26/2015 2 6/18/2015 3S-620 50103206950000 2141670 6'3" 0.60 12" 4/26/2015 2.6 6/18/2015 214167 • 25815 WELL LOG TRANSMITTAL DATA LOGGED !c/2i2o15 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 7, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 2'x. 7 RE: Multi Finger Caliper(MFC) : 3S-620 (')e Run Date: 5/1/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3S-620 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20695-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: .) ettiza4se2a. emiedit • ,w\��\�j/��sT THE STATE Alaska Oil and Gas h��" �i�� O Conservation Commission - ____ fALAS :A i si}#_y-__ 333 West Seventh Avenue 7: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -'T., - ...„" Main: 907.279.1433 0.0; .0., Fax: 907.276.7542 www.aogcc.alaska.gov Sindy Tam 6211-1 lx//�1 Well Design Engineer l ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Torok Undefined Oil Pool, KRU 3S-620 Sundry Number: 315-135 Dear Ms. Tam: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, - 0 / 1.---)xezfit.- Cathy '. Foerster Chair DATED this 2-7day of March, 2015 Encl. RECEIVED STATE OF ALASKA •SKA OIL AND GAS CONSERVATION COIOSION MAR 1 i 2015 APPLICATION FOR SUNDRY APPROVALS D7S 31271 IS 20 AAC 25.280 AOGCC 1.Type of Request: Abandon f Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend I" Rug Perforations f Perforate r Pull Tubing r Time Extension r Operational Shutdown r' Re-enter Susp.Well r Stimulate �, Alter casing Other:Frac Treatment �✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. , Exploratory r Development F., 214-167-0 . 3.Address. Stratigraphic r Service 6.API Number. P.O.Box 100360,Anchorage,Alaska 99510 50-103-20695-00 r 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I✓ ✓ KRU 3S-620 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380107,25544,25528 . Kuparuk River Field/Torok Undefined Oil 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13768' 5218' 13655' 5218' none none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 106' 106' Surface 3117' 10.75" 3145' 3145' Intermediate 9253' 7.625" 9279' 5185' Liner 4511' 4.5" 13655' 5218' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 4.5" L-80 9150' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-Baker Premier Packer MD=9093 TVD=5148 PACKER-Baker HRD-E ZXP Packer MD=9144 TVD=5161 NIPPLE-Camco DS Nipple MD=504 TVD=504 12.Attachments: Description Summary of Proposal pi 13. Well Class after proposed work: r Detailed Operations Program fl BOP Sketch r Exploratory r Stratigraphic Development Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/1/2015 Oil I✓ , Gas r WDSPL r Suspended 16.Verbal Approval: Date: VVINJ r GINJ [ WAG r Abandoned I-. Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sindy Tam @ 265-6830 Email: Sindv.P.Tam@.conocophillips.com Printed Name Sindv Tam Title: Well Design Engineer Signature ,/ //'l, Phone:265-6830 Date 3//;/2","/-5- t.../ . Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -SIG--135 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r . * cri Other: i O 0"C\ r�o,? 4 # `Q, rine-Poc,c-, s 0%6m I CQ/� Di— 3'1re ret s-1- t i wi„) . -ra.c fa w s.0r/ p/u s a ftNs.z- re;ui re,vne4 s of .0 MC 2S'20. Spacing Exception Required? Yes ❑ No Ec Subsequent Form Required: I 0 — 4-0 4- APPROVED BY Approved by: f � ��� COMMISSIONER THE COMMISSION Date: 3 - a- - �,S vrL /Z F/4pproved application is valid for 12 months f to the date of approval..p/f 3'A7_.is, Form 10- (Revised 10/2012) �'� / t"Jl -' Submit' Form and Attachments in Duplicate RBDMS) - ORIGINAL ,, 3X1/j3-- cA o3 j26/is APR3 1015 3S-tit Hydraulic Fracturing Sundry Application Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners an 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, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com Date: February 19, 2015 To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 3S-360 Kuparuk River Unit, Alaska Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 3S-620 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 25, 2015. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 380107, KRU Tract 150; ADL 25544, KRU Tract 149; and ADL 25528, KRU Tract 147 as depicted on Exhibit 1 as follows: Surface Location: 2546' FNL, 1188' FEL, Section 18, T12N, RO8E, UM Target Location: 769' FNL, 2973' FEL, Section 13, T12N, RO7E, UM Bottomhole Location: 2148'FNL, 3930' FEL, Section 12, T12N, RO7E, UM 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, 0a44-1 U/ )0 - 9 Paul Wharton Staff Landman cc: Sindy Tam 3S-620 Hydraulic Fracturing Notice Letter February 18, 2015 Page 2 Exhibit 1 ' - II e, 2 NDS1 1 1/2 mile radius from 3S-620 Well :; 72t DL380106 13L025528 CPAI, CPAI, BPXA, BPXA, ,.--.�.� CN VELD sIL,>,co 10 CHEVRON, EXXON MOBIL EXXON MOBIL 1/31/2003 11/11/2002 3S-620 3& fi 146 sS-,:% " MI 7 \,35-•6A I S 15 Y OS-10 /I ; I S-17 111, $-14 ! / 1 / T12t IR7E 7A '' 2 E �� `� �� sem , V 6 W-1- 3S-2 f '."y - 17 1d� 3S 2 C. ADLIV5544 skss-z' tiaP ADL38 ~' CR I, �y CPAI,' �' CHEBP RON, / BPXA, C- —.._ CHEVRON,- EXXO MOB 5-Z3 )/ EXXON MOBIL111411 11/112002 / 1/31/2003 I C / 3S-084.-------- I 24 - - �� 21 21 S-23A i Kuparuk River 24 Unit m 29 Well Legend INN MN 25 30 28 AIll 20947A te PRODUCTION VILLE� ,a, INJECTION �i -UULVfLLL , ConocoPhillips PLUGGED and ABANDONED Kuparuk River Unit Sources: L 3S-620 ConocoPhillips Alaska Inc. 36 33 business records and e.g... Paul Wharton la.P.r.db, Lauruhn/Roso public records File Name 15012002D00_3S-620 I D. 2-16-15 1 3S-620 Hydraulic Fracturing Notice February 18, 2015 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Patrick J. Wolfe, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owner: 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 TIALASKA OIL AND GAS CONSERVATION CMISSION 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-620 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations("Notice"). 4. On or about February 19, 2015, 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 19th day of February, 2015. 6)sa, .1 Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 19th day of February, 2015, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBLIC ,' T REBECCA SWENSEN - -► My Commission Expires Aug.27,2016 3S--0 Hydraulic Fracturing Sundrytpplication Section 2 — Plat 20 AAC 25.283 (a)(2) • • ils91/1 3S'6 211 11 dk 0.1 T12 R *--. 3S a-'-- 4 ;.48.i I e y�e — + T12N R8E .ails~ Rive __ r f j jfJry/fy 95-CRA / /J Legend V IIs Tramectore Radius —Proposed Traleetory sem Open to Reservoll Reservoir 1+'2 Mile Radius Traec orp 112 Mle radius Drill Site Primary Road oCPAI Operated Units Alaska Protracted Sections 1:351391 Townships REFERENCES: *r"' 'r'*Il DataennonnPl iaipsAlanka YMis Datanane ATDB [OI'IOCO 11 �IpS Skim**Facllltles NcNn Slope 6K Survey TISSN2 Published 120(13 A'anka Statewide Q&Gas Leases 1!1212015 Alaska,Inc.. %t rer lAtell pate'DNR-Groundwater Matsu No PolaEle 4WIerWells are in the Kuearuk Rver uct. 35-620 Plat Anaysis Nn Pn1e k 4"kaler Aquifers are in tiro Kopgnrk RNcr UnR Wells 214)2015 r P 04,1 3S-P0 Hydraulic Fracturing Sundry!pplication Well Name API BUS_AREA_ID PERMIT_NUM WELL_TYPE STATUS 3S-03 501032045800 KRU 203-091 PROD ACTIVE 3S-06 501032045400 KRU 202-057 INJ PA 3S-06A 501032045401 KRU 203-088 INJ ACTIVE 3S-07 501032043000 KRU 202-187 PROD ACTIVE 3S-08 501032045000 KRU 203-022 PROD PA 3S-08A 501032045001 KRU 203-037 PROD PA 3S-08B 501032045002 KRU 203-043 PROD PA 3S-08C 501032045003 KRU 207-163 PROD ACTIVE 3S-09 501032043200 KRU 202-205 INJ ACTIVE 3S-10 501032044000 KRU 202-232 PROD ACTIVE 3S-14 501032043900 KRU 202-221 INJ ACTIVE 3S-15 501032044400 KRU 202-254 PROD ACTIVE 3S-16 501032044500 KRU 203-007 INJ ACTIVE 3S-17 501032044800 KRU 203-015 INJ PA 3S-17A 501032044801 KRU 203-080 INJ ACTIVE 3S-18 501032043300 KRU 202-206 PROD ACTIVE 3S-19 501032046000 KRU 203-096 PROD ACTIVE 3S-21 501032045200 KRU 203-031 INJ ACTIVE 3S-22 501032044600 KRU 203-011 INJ ACTIVE 3S-23 501032045300 KRU 203-045 PROD PA 3S-23A 501032045301 KRU 206-043 PROD ACTIVE 3S-24 501032045600 KRU 203-079 PROD PA 3S-24A 501032045601 KRU 204-061 PROD ACTIVE 3S-26 501032036101 KRU 201-040 INJ ACTIVE PALM 1 501032036100 KRU 201-005 EXPLOR PA 3S-P0 Hydraulic Fracturing Sundryypplication 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. Please see the attached 40 CFR 147.102 Aquifer exemptions. / • 4110 AUTHENTICATED , U.S.COVERNMENT INFORMATION GPO §147.101 40 CFR Ch. ! (7-1-13 Edition) (d)The Program Description and any (iii)Middle Ground Shoal Field. other materials submitted as part of (iv)Trading Bay Field. the original application or as supple- (3) The portions of aquifers on the merits thereto. North Slope described by a'A mile area [51 FR 16684, May 6, 1986, as amended at bs beyond and lying directly below the FR 9411,Mar.6,1991] Kuparuk River Unit oil and gas pro- dueing field. §147.101 EPA-administered program. (a) program in the §147.103 Existing Class I, H (except Contents. The UIC enhanced recovery and hydro- State of Alaska for Class I,III,IV, and carbon storage) and III wells au- V wells, and for all classes of wells on thorized by rule, Indian lands, is administered by EPA, Maximum injection pressure. The This program consists of the UIC pro- owner or operator shall limit injection gram requirements of 40 CFR parts 124, pressure to the lesser of: 144,146,148,and any additional require- (a)A value which will not exceed the merits set forth in the remainder of operating requirements of §144.28(1)(3) this subpart,Injection well owners and (i)or(ii)as applicable; or operators, and EPA shall comply with (b)A value for well head pressure cal- these requirements, culated by using the following formula: (b) Effective dates. The effective date of the 1110 program for all non-Class II Pm=(0.733-0.433 Sg)d wells in Alaska and for all wells on In- dian lands,is June 25,1984. where: Pm=injection pressure at the well head In [52 FR 17680, May 11,1987, as amended at 68 pounds per square inch FR 9412,Mar.6,1991] Sg=specific gravity of inject fluid(unitless) d=injection depth in feet. §147.102 Aquifer exemptions. (a) This section identifies any *147.104 Existing Class II enhanced aquifers or their portions exempted in recovery and hydrocarbon storage accordance with §§14.4,7(b) and 146.4 of wells authorized by rule. this chapter at the time of program (a) Maximum injection pressure. (1) To promulgation. EPA may in the future meet the operating requirements of exempt other aquifers or portions, ac- §144.28(f)(3)(ii) (A) and(B) of this chap- cording to applicable procedures, with- ter,the owner or operator: out codifying such exemptions in this (i) Shall use an injection pressure no section. An updated list of exemptions greater than the pressure established will be maintained in the Regional of- by the Regional Administrator for the five. field or formation in which the well is (b) The following aquifers are ex- located. The Regional Administrator emptied in accordance with the provi- shall establish maximum injection sions of§§144.7(b)and 146.4 of this ohap- pressures after notice, opportunity for ter for Class II injection activities comment, and opportunity for a public only: hearing, according to the provisions of (1) The portions of aquifers in the part 124, subpart A of this chapter, and Kenai Peninsula,greater than the indi- will inform owners and operators in cated depths below the ground surface, writing of the applicable maximum and described by a'/9 mile area beyond pressure;or and lying directly below the following (ii) May inject at pressures greater oil and gas producing fields: than those specified in paragraph (i)Swanson River Field-1700 feet. (a)(1)(1) of this section for the field or (ii)Beaver Creek Field-1650 feet. formation in which he is operating pro- (iii)Kenai Gas Field-1500 feet. vided he submits a request in writing (2) The portion of aquifers beneath to the Regional Administrator, and Cook Inlet described by a 1/4 mile area demonstrates to the satisfaction of the beyond and lying directly below the Regional Administrator that such in- following oil and gas producing fields: jection pressure will not violate the re- (i)Granite Point. quirement of §144.28(f)(3)(ii) (A) and (ii)McArthur River Field. (B). The Regional Administrator may 890 3S-6, Hydraulic Fracturing Sundry�pplication 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. 3S-S Hydraulic Fracturing Sundryypplication 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. 3S-At Hydraulic Fracturing Sundryypplication 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: 3S-620: 10-3/4" casing cement pump report on 1/27/2015 shows that the cement job lost return after 40bbls tail cement pumped. Did not get cement to surface. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.7 ppg mud. The plug bumped @ 1000 psi and the floats were checked and they held. Perform top out cement job. Pumped 26bbls of 11 ppg LiteCRETE cement, 16bbls of cement returns to surface. 7" 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 15.8ppg Class G cement, displaced with 9.7 ppg mud. Reciprocated pipe and full returns were seen throughout the job. The plug bumped @ 1500 psi and the floats were checked and they held. 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. 3S-6 Hydraulic Fracturing Sundryypplication SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 1/31/2015 the 10 & 3/4" casing was pressure tested to 3000 psi for 30 mins. On 2/17/2015, the 7" casing was pressure tested to 3500 psi for 30 mins. On 2/17/2015, the 3.5" tubing was pressure tested to 4000 psi for 30 mins. 3S-M Hydraulic Fracturing Sundry!pplication 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 Collaspe 10-3/4 45.5 L-80 5210psi 2470psi 7-5/8 29.7 L-80 6890psi 4790psi 7-5/8 39 TN-110SS 12620psi 11080psi 4-1/2 12.6 L-80 8430psi 7500psi 3S- 0 Hydraulic Fracturing Sundryikpplication Moraine 3S-620 Grass Roots Horizontal Multi-Stade Frac'd Producer ConoeoPhillipS Final Wellbore Schematic FMC 4-W tree,to)joint is 4-W 12.6#IBTM,crossed over(for frac equipment) r l New Existing Conductor: 16"62.6#HW�106' Spud Mud 9.6 PPG 7 K"cameo DB +-3 Nippie 3 875" 500.1104 k"a 1•KBMG(2,500'TVD) with Dunxny Surface Casing: 10-3/4"45.5#L-80 Hydril 563 3,161'MD/2,556'TVD g 46° 13-1/2"Surface Hole 4 S"x 1.KBMG 3,400'TVD) Iii with Dummy Campanian Top 3.381'MD 2,65V Iv. J;S•.x I"KBMG(4(00'TVD) h,. -I with Dummy 9-7/8"Intermediate Hole Tubing: 4-'/z'12.6#L-80 IBTM x 1"KBMG(1,650'TYD) . 4-W 12.6#L-80 Hydril 563(bottom 3000ft) w NDummy LSNDr 1Estimated top of cement @+1-6,000'MD 9.6 PPG (SOPMD above the C-40) Keep up with Dilution `!"x 1"KBMG 700(5,072'TVD) with SOV OLE Gauge Garner i-9200'001 ■ 4.5"z 7-5/8`,Baker Premier Packer+/-0215'MD 4'h"cameo DO Kipple 3512" rropo sj■ 7-5/8'z 4-5/Baker Flex Look L'rwe 55+907 ZXP liner top packer 1 RS Nipple.a 00-0.205' Intermediate Casing Set into the Moraine 7-5/8"29.7#L-80&bottom 300'..711.1:0.S.::)..:,:9..3 # �. t ijt(I�f,s crar3rle� io-ts. i?112' • . .,Tso of MOrame 4 40$MO 0 06 TL4 :' .--' 44 S:MC;' s I Y ki 8 . 4W'SWtrell Packef5(Packerlus FrdC E4uipmeil:) yW KLASHrELD � . . �`: O O O • :1111.:.,.,:::,,,, Tradttatlon Lfn+r(d 4 11� .12 6#3$1'M .. t : : 4aP5:Mia rs:1s3. ' TQ 13,571 vl� p./$21 TSD 3S-0 Hydraulic Fracturing Sundrypplication Stimulation Surface Rig-Up Bleed/Tattle 1-t 1=, t+t LA1 Tale Tank 0 7 d i1 •0 11 /6 • Minimum pressure rating on all surface 00.241 �� treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure _ • IA parallel PRV set to 3500 psi Ts.; = �' '�'� • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 .. t w" psi. �! 1.:01 )P u j dwnd c� Pap-0B Tank 3.3ffi Pop-Off Tank 1�1 Pump Truck Pc' W21K" J Frac Pump +yd--D]-- -{ Frac Pump Frac Pump r,J y - Frac Pump Frac Pump — Frac Pump Stimulation Tree Saver 3S!0 Hydraulic Fracturing Sundryypplication OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON /f CONNECTION 1• TT:.. REMOTE OPERATED MASTER VALVE mommommi 10 RIP TO i ACJ ���At. '� MANUAL OPERATED M�'`' MASTER VALVE asmoomm. o.� atil .ls‘a ,\cif III Stinger MANDREL ill M 1-1\ ,, , 2 VENT i . ••0 I.t--VALVE _ ■•`. /, OPEN Rolf% /III`I\ iii 4i \16 FLOW TEE AND •�/ f VENT VALVE WELLHEAD iij am Am VALVES %/• //. OPEN 4,.401 "iuL 4F...,. 1 . WEUMEAD .. 1 VALVES F ,'I r ! ! f. .,. CLOSED y t w .� �� u +L�' QUAD PACKOFF Y••9 '— ,t"..4::, -4 ;" , ASSEMBLY IN ( ' r. PLACE IN TUBING T ~S'I ti TUBING o }`,.,. V i +M • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 %2 tubing and 1.75" down 3 %2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75" mandrel 36 bpm 3S-0 Hydraulic Fracturing Sundryikpplication 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 Moraine interval is approximately 200 ft TVD thick at the heel and 220 ft TVD thick at the heel of the well with the Top Moraine starting at 9,108 ft MD/5,099 ft TVDSS. The Moraine is thinly bedded sand and mudstone interval with the sandy components being composed of quartz-rich, moderately to well sorted, very fine grained sand and the muddy components being composed of quartz-rich, moderately to poorly sorted silt and mud. The estimated fracture gradient for the Moraine interval is 12.0 ppg. The overlaying Torok Formation comprises the confining layer, which consist of clay rick beds interbedded with silty layers ranging in total thickness from 910 ft TVD at the heel to 870 ft TVD at the toe with the top of the Torok starting at 6,890 ft MD/4,189 ft TVDSS.The estimated fracture gradient for the overlaying Torok Formation is 14.5-15.5 ppg. 410 3S-11110 Hydraulic Fracturing Sundry Application SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) 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 transect the confining zone: 3S-17 - No production casing. Drilling report for 4/28/2003 shows that 33bb1 15.8ppg Class G cement pumped from 8906-8561ftMD and 57bbls of 17.1 ppg Class G cement pumped from 6777-6200ftMD. Well PA on 4/29/2003. 3S-17A— 7" casing cement pump report on 5/2/2003 shows that 62 bbls of 15.8ppg Class "G" Cement pumped at 4.6bpm, displace with 8.6ppg Seawater. After 300bbls of 8.5ppg seawater displacement and 23.5bbls cement out of the shoe. Lost return. The plug bumped @ 2150psi and the floats were checked and they held. Ran CBL on 5/7/2003 from 8265 to 8752ftMD. Good Cement across Kuparuk C sand. Cement quality in the Moraine Formation is uncertain. 3S-19 — 7" casing cement pump report on 7/2/2003 shows that job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G Cement, displaced with seawater. The plug bumped at 2000psi, and the floats were checked and they held. CBL conducted on 12/22/2012 from 9170ft to surface. CBL log indicates good to fair cement from 9170ft to 7350ftMD. • 3S-0 Hydraulic Fracturing Sundry Application 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 five faults or fractures that transects the Moraine Interval and may enter the lower portion of the confining zone within one half mile radius of the wellbore trajectory for 3S-620. These features are noted on the map and cross-section. Additional smaller, sub-seismic scaled features were not encountered or inferred while drilling. CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the apparent faults will not interfere with containment. 35!O Hydraulic Fracturing Sundry Application • Kuparuk 112N est_ River Unit Legend —Fault —Proposed Traiectory +■**Open to Reservoir Reservoir 172 Mite Radius Onll Site Primary Road QCPAI Operated Unde Alaska Protracted Sections E3BL61 Townships REFERENCES. �j SAktilwink* Data C.^.nr Phill Slope Wells Database ATM /�"'..n�C .1r Sr.lrtsne Factleias Well Stape 6K Sstn�ey 7,'251r12 Pubhsharl 1.20•13 �C...�o (J�11 Alaska Statewide 0,1&Ges ieuses 1012'2015 NANer 6011 Dery DNR-Grorndeerer Dirision Alaska,Inc. No Potable Miler Wefle are in the y(uparuk R,ser Una. 3S-620 Plat.Anaysts s No PataNP With Anklikors em in 1hn Kupon*RMrr ting Faults 2/5/2015 59 Map view depiction of seismically mapped faults and sub-seismic inferred faults (orientation unknown) from drilling data faults located within 1/z mile radius of the reservoir well section (highlighted in red) in which the hydraulic fracture is planned • 3S-0 Hydraulic Fracturing Sundry Application SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) Well 3S-620 has an approximately 4,250' horizontal placed in the Moraine Formation completed with an openhole 4.5" liner with 7 ball actuated sliding sleeves, perforated sub, and swellable packers between each sleeve. We will pump both injection test and stage 1 frac thru the perforated pup joint. Then, we will drop a ball (progressively getting larger) after each stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. We expect the production to be 742 bpd in 2015 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Moraine 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 17 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. 13040bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB 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 210 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi 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 @ 40bpm with a maximum expected treating pressure of 6500 psi. See attached Frac schedule for details. 12. RDMO SLB 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 CTU). 40 3S0 Hydraulic Fracturing Sundry PPlication . ATTACHMENT 1:PUMP SCHEDULE 426.66 7X02 14890 144ry R1 40 14904 REM ITO RoppN00nOry 572 1094 Nim 21.040 mama 824241 00065700 50990 SW 0118 1/1 10715151 Prow.Um 1410 WOE. STEP STAGE 006WENT9 000 PUP ERR VOLUME .070790700007 CLEANV041 Eno.. PUMP TII • 1 TYPE RATE W 01 E PATE STAGE CSTAGE M STAGE Cot 115E GROSS C10T11140444STAGE GLM 1 <RPIWO (SSW r041.31 MALI (LW (LEW (400204 MEW) mama. wase 1 I 09101693 W 612 4 4100 210 210 0033 0833 2'.0 210 10 0005:15 0005:15 WE 00241*0 Gordis 31.11.. 001000 9025:15 2 p4.._-_.._.._... 101237 40 4P.�_ CO 290 3950 41193 03 290 10 001200 50:37:15 0.._ ____...._.. 3 1 6.487 16125.07 YF12 T 40 38.3 340 2100 14293 2011 2011 6059460560 42 336 80 5091:15 003930 4 524.1111 YF12557 40 40.0 00 420 3360 17663 93 6111 60 001200 034080 s 0140/1401 396126V0 -0.,- 210 031 0033 26496 210 629 10 0005:15 0546:46 120042010 mom 1110430- 033090 0115:45 sum ma Cl 401TV811aE P40MN0T 9.0011891IE Era.E. NEi111E STEP STAGE MENAGE COMMENTS TYPE MTF RATE STAGE CW STAGE CUM STAGE RIM 115E GROSS CMM 14004 STAGE OM A PM 11114 ,ERIE 1941 1111113 1040 18102 (1310 030 414) XVI *04901 1403 (4010 6 0795 0612514 40 4064 200 901 15120 1606 0 2011 0 360 999 10 COMM 012446 7 1 RAT 1612081' M 49.2 130 1121 6460 7066 5229 7,241 03CMIMa 125 1113 110 000316 013090 8 2 RAT YF12557 40 36.9 150 1271 6300 3366 _ 11679 10620 161164100 124 1261 10 000345 0131;46 0 3 RAT 0012597 40 06 2. 180 1421 6300 59666 16692 35,512 40010000004 122 1283 10 000366 013520 10 4 RAT 9602537 40 .24.0. 170 1551 6400 5126 1056654,079 1024164020 -' 111 1494 100 0012:15 03065 5 RAT 1F1268T 40 3.9. 130 1001 6460 0506 '22369 76.440 14104020 107 1600 000 0003:15 01:4200 32 8 RAT TF12591 403.E. 120 1411 5160 .6046 25908 102,356 207144951 103 1703 120 000315 01:45:15 IT 0191.70' 00060E 11112581 40 4U. 20 1031 900 5006 0 102.355 20 1723 10 000020 0165:45 IA TAD 1612531 43 44CC 300 2141 15120 2336 0 102,3562 360 2002 80 000900 01:5445 IS 1 RAT YF12081 46 29.2 130 2321 5460 7466 5229 107,505 1059041100 125 2209 9.0 0003:15 01:5900 16 2 MT 1012651 16 36.4 150 2471 6300 03766 11579 119,164 0204x01 138 2346 00 000366 020145 17 3 RAT 161231 16 3..2 150 2021 6700 10066 16692 135,907 440200002 132 2479 10 0003:46 020690 4 RAT 1692957 40 14.0 130 2751 5460 15525 10566 156423 0594901414 111 2589 150 0003:15 0209865 10 5 RAT 16125S1 40 32.4 130 2091 5460 20906 22369 176,793 003/000101 107 2696 ILO 0003:15 02:1200 29 8 RAT 16125S1 40 31.6 130 3011 6960 26446 25000 .112,700 1040061184 103 7190 120 0003:15 022:16:16 20 8101.0105 01121000 961281 40 63.6 13 3024 546 26992 0 202,700 13 2911 10 0000:10 02:1534 a MO TF12567 M 40C 470 3404 10740 40732 0 207,700 470 3281 50 00:1125 0227:19 3 1 RAT 96125S1 40 35.2 130 3024 5460 52192 5229 207,930 0200990 125 3475 10 0003:15 02:3184 24 2 RAT 1012897 40 36.9 150 3774 6300 60492 11579 219500 10212/10184 130 3542 10 0003:15 0234:19 a 3 MT 0012591 40 36.3 150 3124 6700 64702 16692 236201 1059045620 132 2676 10 030346 021404 a 4 RAT 1712591 40 31.0 130 4064 6460 70252 18566 254,757 1004420134 111 3706 100 0003:15 0261:19 27 5 RAT 1612587 402^.8 120 4104 5460 75712 22369 277,137 0204420100 107 3093 11.0 0003:15 624434 59 8 RAT 1612581 40 3t 6 120 4304 5040 97752 23915 301,052 14594115620 96 3000 120 000300 02:424 74 7 RAT 0612501 40 3G.E. 110 4414 4620 05372 24714 325,765 100100049E 04 4072 120 000265 02:50:19 00 8 RAT 1612501 40 ,5.E 110 4524 4620 09902 27324 253,009 102000600 01 4163 120 0002:45 02:5304 9f 009 1.074 GERAGE YF12551 40 40.C, 13 4537 546 90530 0 353,019 13 4166 10 0000:19 92.5323 m MO 1012557 40 41.0 470 6001 19740 10278 0 353,909 470 4636 10 001146 930598 33 I RAT 1612837 40 30.2 130 5137 5460 15736 5226 250,319 1020000440 125 4761 10 000215 039023 14 2 RAT 0612551 10 36.9 150 5217 5300 222036 11579 369004 90594405644 130 4890 10 000225 03:1200 95 3 RAT YF12581 40 Y..3 150 5437 6300 226218 16692 396910 1059445604 132 5031 00 500315 03:1553 w 4 RAT 5612537 40 34.0 130 6567 5450 733,555 13866 405,107 0114441.1 111 5141 100 0003:15 031900 97 5 RAT 9F1253T 40 311,6 170 6407 5460 239058 22369 427,526 mamma 107 5240 110 0002:15 037223 30 0 RAT 1012 5017 10 3,6 120 0017 5040 244294 27915 451,441 0M9020420 95 5343 120 000300 032523 20 7 RAT 1012697'-40 Coal 110 5927 4620 248919 2014 475.155 159011440 84 5427 120 000245 032998 40 8 RAT 16125S1 40 290 110 4037 1620 26364 27324 603,479 1204490 01 5608 120 COMM , 033053 04019734 G044A00 171255T 40 40 3 13 4060 546 254084 0 003,479 13 5621 10 50090:19 0331:12 40 1410 7012537' 40 40 0 550 4000 23100 277184 0 603,679 550 6071 10 00:1345 03:4457 11 1 RAT 3612557 40 393 100 0700 6720 203904 6436 509,915 14600406400 153 6224 10 000490 036857 44 2 MT 0612581 40 36 b 170 430 7140 291044 12123 623,039 /0/440016 156 6301 10 0004:15 0331:12 as 3 RAT 16121ST' 40 35.0 190 7120 7990 299024 _ 21144 644,102 asecama 168 6649 10 000445 093257 44 4 RAT 961255 40 249 100 7700 7660 306684 25707 664809 03B44920 163 6701 900 000430 040227 47 b MT 16125S12 40 22 II 170 7470 7040 313724 29252 599,141 05944090 129 6011 110 000415 0406:42 Al 6 MT TF12307"-40 its 100 7430 6720 32044 31896 631020 0594115600 127 6067 120 000400 54:10242 a 7 RAT 16-12 6617 M CO f. 158 7705 6610 326954 34024 665,652 9059159/920 119 7006 120 000352 041434 10 0 RAT 96125ST 40 29 6 180 793.5 6.700 333264 37260 703,112 004492 111 7197 110 8000:15 04:19:19 SI 640 2004 10R4.6F 1612097 40 40.0 13 7940 546 333800 0 703,112 13 7210 10 00040:19 04:1938 52 100 5612531 40 403 550 1406 22100 356900 0 703.112 500 7760 60 00:13:45 043223 51 1 RAT 16125S1 40 09.3 100 0016 6720 363620 6436 709,540 00000620 152 7913 10 500400 062622 2 RAT TF125137 40 36.9 100 MM 7140 370760 13123 722,671 059448184 158 8169 00 000015 04:4030 55 a RAT 76125S1 40 053 190 4016 7900 379740 21144 743115 10595/9984 100 0237 10 0004:45 04:45223_ 5O 4 RAT 1612501 M 343 100 0116 7660 366300 25707 769,522 0a0M010 153 0390 910 005430 046953 6 RAT 0612581 40 02.0 170 6080 7140 393440 00252 790,774 /004000424 129 9529 11,0 13000:16"'"04:5/99 1 8 RAT 661231 64 2,3 100 9616 6720 400160 31006 030,660 05900049E 121 0656 120 000400 041891 10 7 RAT maw a 30.6 155 0001 6610 406670 34144 965,480 9059089820 110 4774 120 005352 35:0200 02 0 RAT 1,612531 10 96 100 0033 6300 412970 27260 902,746 059005600 111 1005 110 0003:46 98.6:0525 Al 84020026 19511175056 51125S1 M 4.0 13 0084 616 413515 0 102745 13 0090 10 0090:19 050604 62 010 5612551 45 40.:4 650 10206 23100 436614 0 002,745 600 8448 10 001245 05:19:49 10 1 RAT TF1259T M 393 100 18000 6720 443736 6436 004,191 13450090 162 0001 10 0400400 0623:40 64 2 RAT 36725.07 M 569 170 10720 7140 450475 13123 822,304 059000684 156 0760 10 0004:15 052904 E6 3 RAT 36-12591 14 26,3 100 10010 7900 458456 21144 003.40 140049110 iM 0325 10 0004465 0532:49 if 4 RAT 1T1255 p 342 100 19M11 7660 466015 25707 869,156 11001001610 153 10079 110 000430 0527:10 67 0 3447 361264 1 CC.3 170 11216 7140 473166 29252 998,407 0599.2045 139 10210 11.0 6004:15 05:4134 1$ Cl 0 100 11420 6720 479076 3140 1.030,293 00044x20 127 10344 120 900408 05:4534 ss 7 RAT 361250 40 300 155 11161 6610 466986 34824 1065,117 010445620 118 10463 120 000352 004925 70 It RAT 3-6-125137 /009 6 150 11731 6300 492696 37260 1.102277 04411x4111 10674 120 000365 055311 M 445 13 11744 646 493232 0 1,102,97 13 10637 10 000319 05:5330 72 nv 9612515 0 400 650 1224 23100 516332 0 1,102377 500 1119 10 00:13:15 06:07:15 72 I 7 T61255 11111:111111111EIMII 0720 623052 11111177111111111=07111=1=M1 160 11297 10 000490 0611:15 74 2 RAT T6-1258 M 26 9 171 12624 7140 630192 13123 1.121,937 1059440420 170 1143 110 0094:15 061530 75 2 NAT 1,612513 40 2£3 190 121114 7980 531172 21144 1,1421000 mamma 190 11667 10 0094:45 0620:15 76 • RAT 161255 M 24.0 100 1204 7660 545732 26707 1,155703 0x04920 100 1149 110 600430 062465 . 5 RAT 1401 40 000 170 13114 7140 56297 _ 29252 0,191940 190000420170 900004 170 12007 ILO 00104:15 162800 rs 41 FLAT ieifis M 100 12324 6720 659692 31086 3329,926 1590461100 160 12167 12.0 009400 06:3300 7s FIAT 1151-555 M '3C 6 155 13179 6510 566102 34824 1,264,750 1012910114 156 02422 120 000252 062612 90 6 RAT YF92651 q 49 4 100 13429 6300 572402 37250 1.302010 1110411920 156 12472 120 000365 004037 II 4 8100 101126 M116 13747 4900 577382 119 12590 160 000257 06:1334 P4 10 0 01130Fa400ME M « 90 13779 1275 570660 ........ 30 12621 009045 06:44:18 101440 13.779 bbl 0302.010 1 12621 Bbl 06:14:19 01101 P F 11114430.13 9001 WAT¢1 VOL FLU3110E0R1AT101 WEARS)TMEAT90 PRESSURE 4EdIMAT1044 W94LAMFE091Y9E•1110#115‘11011 027510. 42609E VOL TO TOP P0RT=1521 1107000164491. a a4 40:411594 WO 101.H.O_ 11619408. /19021104 OVA 40 400 -1.11.3ERFLUSR30 104,065. -463490 9TALJ04 42690844 RUSH 4042149 MUMS LOSS c 514 .POE FRC. 13044 Ms 422 comma. 1®10149 TW. 11010 .HY0 HOC,0:C14' An9R1TIO14 Pin.SO' GENERAL 409IEO WO FEST 541)6. WO E91 W4WHp:W10 p9 WM WWII 000114,3407 TAWS 1004900T F£ ME.insrv._51 41.13711101 SIVA. 1120 �v 2814 tnpw trl.SAVE. PA541MY 0071007 POOAA4 TOTAI 6 011 411 RTA 9 95011 51* ESP 291. 4FP.Til6643 NTE.. 4500 0.052 :451 8101.2118 54941 221 P wA'1115-934}11 War 1304C eels 50039!8 80940 296corn...,S50n0 264014 001, LMA 501904318 CATO.SWt.t 4.5000 5055 304.1 *4rpupl.A:142 L14v Add 51T MG 593.5295 R4Gry 51A1 NOTES: rump M4 0444.19 mmm.m -3100110.connection to 1.1111 9091 Pc.%0C 0µ0w1 51a9 Pods MO WAWA %WS 544520 we w• DM 116 984 9111P 1364 003669 Port pup 544,7 10351 1102604 250 An 5214 lb 9001 11100 500-NW 14475 51x040 3c4i 1431101 103 404 106C 34 1507 12664 1024 Ops 175 0100 600 94 91111212.'^0 1411.5 4012 1057 GE 3591 11501 1751 Wa 1005 595 07 I6 904. 11341 1402 Ms 10175 111E 3300 Os1 7201st • 0 Client: ConocoPhillips Alaska Inc. SCIIIMberler Well: 3S-620 Basin/Field: Colville-Prudhoe Basin/ Kuparuk River Unit State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 1/22/2015 2:45 PM Report ID: RPT-34094 Fluid Name&Volume Additive Additive Description Concentration Volurne B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 3,339.0 Gal D047 AntiFoam Agent 0.2 Gal/1000 Gal 116.0 Gal F103 Surfactant 1 Gal/1000 Gal 530.0 Gal J475 Breaker 9.9 Lb/1000 Gal 5,214.0 Lb YF125ST:WF125 528,788 Gal J532 Crosslinker 5.8 Gal/1000 Gal 3,067.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 1,060.0 Gal M002 Additive 0.6 Lb/1000 Gal 307.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 145.0 Lb S522-1620 Propping Agent varied concentrations 1,302,010.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* -76% 66402-68-4 Ceramic materials and wares,chemicals -23 % 64742-47-8 Distillates(petroleum),hydrotreated light <1 % 9000-30-0 Guar gum <1 % 56-81-5 1,2,3-Propanetriol <1 % 1303-96-4 Sodium tetraborate decahydrate <0.1 % 7727-54-0 Diammonium peroxodisulphate <0.1% 107-21-1 Ethylene glycol <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 25322-69-4 Polypropylene glycol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1% 67-63-0 Propan-2-ol <0.1% 111-76-2 2-butoxyethanol <0.1% 7647-14-5 Sodium chloride <0.01% 68953-58-2 . Dihydrogenated tallow dimethyl ammonium bentonite <0.01% 68131-39-5 * C12-15 alcohol ethyoxylated <0.01% 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01% 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) <0.01% 1310-73-2 Sodium hydroxide(impurity) <0.01% 7631-86-9 Silicon Dioxide <0.01% 10043-52-4 CALCIUM CHLORIDE <0.01% 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 111-46-6 2,2"-oxydiethanol(impurity) <0.001% 68153-30-0 • Amine treated smectite clay <0.001% 10377-60-3 Magnesium nitrate <0.001 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 7786-30-3 Magnesium chloride <0.001 % 7447-40-7 Potassium chloride(impurity) <0.001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 14808-60-7 Crystalline silica(impurity) <0.0001 % 14464-46-1 Cristobalite <0.0001 % Total 100" *Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. II 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 3StO Hydraulic Fracturing Sundry Application ConocoPhillips discloses that it will be using the listed volumes of ZeroWash®Tracer, Chemical Frac Tracer, and Oil Frac Tracer for tracing purposes in the concentrations detailed in the attached Core lab 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 * • { 0 iti ° ` 2 / \ \ k ® / \ - : waR ! ; ' a Huj 2 § � � „ , , ! | � ( k \ \ } _ ,Ali . . � 2 i , II!§ \ 0..). _ \ \ CD C ' /\ = S co 0 E .t. _/ \ 0 Eo I C2i t 2 = \ ,9 ; / E « f k. • ®\ { , 34 * *CD k { .- \ KK (§ » E \ , - ® m o <£ f/ a\ 4— C To 46 22 { f / ,oS r ±oS ; a \/ / 2 / ) Gk \ } ) { / 22ER G = : ss 2 r �rE7 = 0 E { O co ) U cu _ L {_ • f{{ -0 - — / ” («{ [ \ 2' r ± CL ca' \ � ) {\ ±$ ) ) § -0 \ / \ ! ) ) \) /\/ 5 a) - — 2 i / 2 ( ( .E } \ J ) 2 3 3 } CCS q. q I 0 72. ) )\ u / I/ -o cl. _LI— | To •U ! - # \ | @N)\. - � 0 / a a \ £ = o2a � >- % o _ \) A - ) • i RECEIVED MAR 262015 AOA AC Pro0Wesics DiHoion Alm 0 i tt (�•:1(V' 6510 West Sam Houston Parkway North Hosuton,Texas 77041 Phone:713-328-2320 Fax:713-328-2163 Cure M �3 www.corelab.com UMW UMW= =N Tracing Records for: Operator: ConocoPhillips Alaska Well Name: 3S-620 Stage 1 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate / CFT1000 Tracer "Trade Secret Status" 0.00005%by weight OFT5600 Tracer "Trade Secret Status" 0.00005%by wei ht IRZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 2 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate / CFT1100 Tracer "Trade Secret Status" 0.00005%by weight / OFT5700 Tracer "Trade Secret Status" 0.00005%by weight SCZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 3 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate / CFT1200 Tracer "Trade Secret Status" 0.00005%by weight ,/ OFT5800 Tracer "Trade Secret Status" 0.00005%by weight SBZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 4 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate / CFT1300 Tracer "Trade Secret Status" 0.00005%by weight / OFT5900 Tracer "Trade Secret Status" 0.00005%by weight IRZW Tracer "Trade Secret Status" .0.00005%by weight — Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Attachment I 1 • • Stage 5 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate / CFT1700 Tracer "Trade Secret Status" 0.00005%by weight y OFT5500 Tracer "Trade Secret Status" 0.00005%by weight SCZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 6 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate l CFT2000 Tracer "Trade Secret Status" 0.00005%by weight J OFT5200 Tracer "Trade Secret Status" 0.00005%by weight SBZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 7 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate CFT1900 Tracer "Trade Secret Status" 0.00005%by weight ( OFT5000 Tracer "Trade Secret Status" 0.00005%by weight ./ IRZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Stage 8 April 15,2015 Trade Name Additive Type Chemical Compound Name CAS Number Loading Rate I CFT2200 Tracer "Trade Secret Status" 0.00005%by weight ,/ OFT5100 Tracer "Trade Secret Status" 0.00005%by weight V SCZW Tracer "Trade Secret Status" 0.00005%by weight Carrier Fluid Carrier Fluid Water(major) 7732-18-5 0.00037%by weight Methanol(major) 67-56-1 Dipropylene glycol methyl ether(minor) 34590-94-8 Xanthan gum(minor) 1113866-2 Attachment I • • • ProTechnics Completion Diagnostics Core Lab Material Safety Data Sheet Product Name: Chemical Frac Tracers (CFT) Updated: 02-13-2014 Generic Name(s): Cyr 1000-4800 Usage: Diagnostic Composition: , _— Ingredi CAS No Per, Haza Proprietary Ingredient supplied as 10% Proprietary 10 No w/v Aqueous Solution Water 7732-18-5 90 No Manufacturer Emergency Telephone Numbers ProTechnics 24Hr.Response Division of Core Laboratories Emergency: 713-328-2320 6510 W.Sam Houston Pkwy N. Transportation Emergency: Houston,Texas 77041 US: 1-800-535-5053 Tel:713-328-2320 International: 1-352-323-3500 collect II Health Hazard Data/ Identification III First Aid EMERGENCY OVERVIEW EYES:Immediately flush eyes with water for two to three minutes.Remove PHYSICAL APPEARANCE:Cream colored liquid with no odor any contact lenses and continue flushing for 15 minutes.If irritation IMMEDIATE CONCERNS:May cause eye and skin irritation continues,seek medical attention. POTENTIAL HEALTH EFFECTS SKIN:Remove contaminated clothing including shoes and wash affected EYES:May cause irritation to the eyes. area with soap and water.If irritation continues,seek medical attention. SKIN:May cause irritation to the skin. Wash contaminated clothing and shoes before reuse. INGESTION:May cause irritation to the digestive tract. INGESTION:Wash out mouth with water.Seek medical attention. INHALATION:May cause irritation to the lungs,upper respiratory INHALATION:Although unlikely,remove from further exposure.If cough Tract and nose. or other symptoms develop,seek medical attention. SIGNS AND SYMPTOMS OF OVEREXPOSURE EYES:Irritation or tearing of the eyes. SKIN: Irritation or itching of the skin INGESTION:Possible nausea and/or vomiting. INHALATION:Possible coughing,burning,tightness of chest and/or shortness of breath. ACUTE TOXICITY:No test data is available for acute dermal toxicity. No test data is available for acute oral toxicity. No test data is available for acute inhalation toxicity. CARCINOGENICITY:Not Listed by NTP,IARC,or OSHA MUTAGENICITY:Not Available REPRODUCTIVE TOXICITY REPRODUCTIVE EFFECTS:Not Available TERATOGENIC EFFECTS:Not Available MEDICAL CONDITIONS AGGRAVATED:None known TARGET ORGAN STATEMENT:Contains material which may cause gastrointestinal tract and respiratory tract irritation. SENSITIZATION:Not Available IV Fire Fighting Measures V Accidental Release Measures FLASHPOINT AND METHOD:Not Available SMALL SPILL:Construct temporary dikes of dirt,sand,or any appropriate FLAMMABLE LIMITS:None—nonflammable readily available material to prevent spreading of the material AUTOIGNITION TEMPERATURE:Not Available Wearing the appropriate personal protective equipment designated in Section FLAMMABLE CLASS:Nonflammable 7,move the leaking container to a containment area FLAME PROPAGATION OR BURNING RATE OF SOLIDS:Not Available GENERAL HAZARD:None EXTINGUISHING MEDIA:Non-needed HAZARDOUS COMBUSTION PRODUCTS:None FIRE FIGHTING PROCEDURES:product is a nonflammable substance SENSITIVE TO STATIC DISCHARGE:Not Available SENSITIVITY TO IMPACT:Not Available • ProTecbnics ANA Completion Diagnostics CaryLati Material Safety Data Sheet Product Name: Oil Frac Tracers (OFT) Updated: 06-05-2014 OFT 5000,OFT 5100,OFT 5200,OFT 5300,OFT 5400,OFT 5500,OFT 5600,OFT 5700,OFT 5800, Generic Name(s): OFT 5900,OFT 15000,OFT 15010,OFT 15020,OFT 15030,OFT 15040,OFT 15050,OFT 15060,OFT 15070,OFT 15080,OFT 15090,OFT 15100,OFT 15110,OFT 15120,OFT 15130,OFT 15140,OFT 15150, OFT 15160,OFT 15170,OFF 15180,OFT 15190,OFT 15200,OFT 15210 Usage: Diagnostic Composition: :clients CAS No Percent Hazardous Proprietary Ingredient Proprietary 25-100 No Proprietary Ingredient Proprietary 0-75 No Manufacturer Emergency Telephone Numbers ProTechnics 24Hr.Response Division of Core Laboratories Emergency: 713-328-2320 6510 W. Sam Houston Pkwy N. Transportation Emergency: Houston,Texas 77041 US: 1-800-535-5053 Tel: 713-328-2320 International: 1-352-323-3500 collect II Health Hazard Data/ Identification III First Aid EMERGENCY OVERVIEW EYES:Immediately flush eyes with water for two to three minutes. PHYSICAL APPEARANCE:Clear,colorless to light yellow liquid. Remove any contact lenses and continue flushing for 15 minutes.If IMMEDIATE CONCERNS:May cause eye and skin irritation. irritation continues,seek medical attention. POTENTIAL HEALTH EFFECTS SKIN:Remove contaminated clothing including shoes and wash affected EYES:May cause irritation to the eyes. area with soap and water.If irritation continues,or other symptoms are SKIN:May be harmful if absorbed through the skin.May cause observed,seek medical attention.Wash contaminated clothing and shoes irritation to the skin. before reuse. INGESTION:May be harmful if swallowed. INGESTION:Wash out mouth with water.Seek medical attention. INHALATION:May be harmful if inhaled.Causes respiratory tract INHALATION:Remove to fresh air.If breathing is difficult,provide irritation. oxygen and seek medical attention SIGNS AND SYMPTOMS OF OVEREXPOSURE EYES:Irritation or tearing of the eyes. SKIN: Irritation with discomfort or rash INGESTION:Possible nausea and/or vomiting. INHALATION:Possible sneezing,sore throat,or rash ACUTE TOXICITY:No test data is available for acute dermal toxicity. No acute oral toxicity. No acute inhalation toxicity. CARCINOGENICITY:Not Listed by NTP,IARC,or OSHA MUTAGENICITY:Not Available REPRODUCTIVE TOXICITY REPRODUCTIVE EFFECTS:Not Available TERATOGENIC EFFECTS:Not Available MEDICAL CONDITIONS AGGRAVATED:None known TARGET ORGAN STATEMENT:Contains material which may cause gastrointestinal tract and respiratory tract irritation. SENSITIZATION:Not Available IV Fire Fighting Measures V Accidental Release Measures FLASHPOINT AND METHOD:Not Available SMALL SPILL FLAMMABLE LIMITS:Combustible when exposed to heat or flame PERSONAL PROTECTION: Safety glasses with side shields or goggles, AUTOIGNITION TEMPERATURE:Not Available rubber gloves.(If in confined area wear respirator) FLAMMABLE CLASS:Combustible liquid METHOD: Construct temporary dikes of dirt,sand,vermiculite,dry-lime, FLAME PROPAGATION:Not Available soda ash,or any appropriate readily available material to prevent spreading GENERAL HAZARD:Combustible when exposed to heat or flame of the material.Move the leaking container to a well-ventilated outdoor EXTINGUISHING MEDIA:Water spray,alcohol-resistant foam,dry containment area. chemical or carbon dioxide HAZARDOUS COMBUSTION PRODUCTS:Refer to Section VIII FIRE FIGHTING PROCEDURES:Product is combustible SENSITIVE TO STATIC DISCHARGE:Not Available SENSITIVITY TO IMPACT:Not Available 1 41 411 ProTechnics Completion Diagnostics r°'pLati Material Safety Data Sheet Product Name: Zero Wash Tracer 1 Updated: 03-21-12 Generic Name(s): IRZW,SCZW,SWAN Usage: Diagnostic Composition: — Ceramic Proppant Proprietary 100 Yes A mixture of inorganic earthen material(Oxides) Manufacturer Emergency Telephone Numbers ProTechnics 24Hr. Response Division of Core Laboratories Emergency: 713-328-2320 6510 W.Sam Houston Pkwy N. Transportation Emergency: Houston,Texas 77041 US: 1-800-535-5053 Tel:713-328-2320 International: 1-352-323-3500 collect II Health Hazard Data/ Identification Ill First Aid EMERGENCY OVERVIEW EYES: In case of-contact with eyes,flush with copious amounts of water for PHYSICAL APPEARANCE:Small grey colored ceramic bead at least 15 minutes. Assure that adequate flushing occurs by separating IMMEDIATE CONCERNS: short term toxicity hazards if ingested eyelids with fingers. Obtain services of a qualified physician. POTENTIAL HEALTH EFFECTS SKIN: In case of skin contact,wash area with water and a detergent. EYES:May cause irritation to the eyes. INGESTION:Seek medical attention. SKIN:Long term skin contact should be avoided. INHALATION:Although unlikely,remove from further exposure.If cough INGESTION: short term toxicity hazards if ingested. or other symptoms develop,seek medical attention. INHALATION:properties make inhalation improbable. SIGNS AND SYMPTOMS OF EXPOSURE EYES:Irritation or tearing of the eyes. SKIN: Irritation or itching of the skin INGESTION: toxicity hazards if ingested. INHALATION: properties make inhalation improbable. ACUTE TOXICITY: May cause Eye and Mucous membrane irritation. ZERO WASH particle is too large to inhale. Ingestion is the only method of internal consumption. CARCINOGENICITY:Not Listed by NTP Not listed by IARC Not listed by OSHA MUTAGENICITY:Not Available REPRODUCTIVE TOXICITY REPRODUCTIVE EFFECTS:Not Available TERATOGENIC EFFECTS:Not Available MEDICAL CONDITIONS AGGRAVATED:Not Available TARGET ORGAN STATEMENT:Contains material which may cause gastrointestinal tract exposure. SENSITIZATION:Not Available IV Fire Fighting Measures V Accidental Release Measures FLASHPOINT AND METHOD:Not Available SPILL: CONTROL THE AREA. Rubber gloves,boots and safety glasses FLAMMABLE LIMITS:None—nonflammable should be worn when handling. Clean up spill area by scooping up spilled AUTOIGNITION TEMPERATURE:Not Available material and transfer to a container. If clothing indicates the presence of FLAMMABLE CLASS:Nonflammable Zero Wash material, remove the bead with adhesive tape, hold tape FLAME PROPAGATION OR BURNING RATE OF SOLIDS:Not containing bead for decay in proper storage area. If numerous beads are Available found on clothing,remove clothing and place in a container for later cleaning GENERAL HAZARD: Gamma exposure or disposal. When any spill or release occurs, ProTechnics should be EXTINGUISHING MEDIA: Carbon Dioxide or Halon(This reduces the notified(713-328-2320)to supervise clean-up efforts. spread of Zero Wash material). HAZARDOUS COMBUSTION PRODUCTS:None FIRE FIGHTING PROCEDURES: Self Contained Breathing Apparatus and fire protective clothing is sufficient when extinguishing a fire involving this product. SENSITIVE TO STATIC DISCHARGE:Not Available SENSITIVITY TO IMPACT:Not Available 3S-620 Hydraulic FracturingSundryApplication Y SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through Expro 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.) I • TD 0 -o c 2 • .... 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LL -a � w Z � ooc ° - CL 1 ca ca a. L W -0 0) " (13 co C 2 a) p a) O c .p N " aaaWQ .. E .00- = NN .� O (n N O O V F— E N N - E 0 0 il MN I . • • Loepp, Victoria T (DOA) From: Tam, Sindy P <Sindy.P.Tam@conocophillips.com> Sent: Tuesday, March 24, 2015 8:57 AM To: Loepp,Victoria T (DOA) Cc: Wallace, Chris D (DOA) Subject: RE: Frac Sundry for 3S-620 (PTD 214-167, Sundry 315-135) Thank you, I will work on that! Sindy From: Loepp, Victoria T(DOA) [mailto:victoria.loeppC@alaska.gov] Sent: Tuesday, March 24, 2015 8:47 AM To: Tam, Sindy P Cc: Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: Frac Sundry for 3S-620 (PTD 214-167, Sundry 315-135) Sindy, We have been waiting on the confidential Core chemical disclosure information from Core Lab. Will Williams is our contact. You may want to follow up with Will on the status of the submission. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loetva.alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Tam, Sindy P [mailto:Sindy.P.TamOconocophillips.com] Sent: Monday, March 23, 2015 3:49 PM To: Loepp, Victoria T(DOA) Subject: Frac Sundry for 3S-620 Hi Victoria, How are you doing? I am just wondering if you have an opportunity to review the Frac Sundry for 3S-620? Please advise, S • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, March 10, 2015 7:48 AM To: 'Williams,Will' Subject: RE:Chemical Disclosure Attachments: image001.png Will, Your call on if you wish to send us the first well chemicals or if you wish to submit all your potential chemicals. We can accept either way- but be aware that a public records request can be quite broad in its scope so could be on a specific per well, used in Alaska, or possibly"on file with AOGCC" etc. I do not need the same CORE chemicals twice. The Sundry Application for Hydraulic fracturing from Conoco (per well) should list your chemicals and we will cross check to ensure we have the confidential information for the chemicals on file. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Williams, Will [mailto:Will.Williams@corelab.com] Sent: Tuesday, March 10, 2015 6:35 AM To: Wallace, Chris D (DOA) Subject: RE: Chemical Disclosure Chris, Thanks and that is good news. I think the statement"Chapter 3,Section 45" pertains to Wyoming regulations. Sorry for the confusion. I will edit that and resend. In reference to the confidential documents, how would you like us to handle those? Do we send you the list of all chemicals for you to keep on file or do we send a sealed envelope marked confidential for each well that we work on? I will visit with our team here and see if there are any more questions or concerns with this. Will Williams D.713-328-2325 I M.713-328-2320 1 C:713-516-7392 /F:713-328-2163 • S will.williams a(�.corelab.com/www.corelab.com/Drotechnics From:Wallace, Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday, March 09,2015 6:06 PM To:Williams,Will Subject: FW:Chemical Disclosure Will, We have reviewed and discussed your submission plan and relate back to you these points: 1. Under the 20 AAC 25.283 regulation requirements,AOGCC will accept a separate 3rd party chemical disclosure. The operator, in their Sundry Application,should make reference to all chemicals proposed as per 20 AAC 25.283 (a)(12) and used as per 20 AAC 25.283(h). The operator should make a reference to the chemical trade name and identify what required information is not provided under confidential trade secret protections and make a statement similar to"this information is filed with AOGCC as a nondisclosable confidential trade secret". 2. AOGCC doesn't agree to keep Attachment 1 as confidential. We see this as fairly generic language satisfying AOGCC criteria that meets the requirements for nondisclosure of the trade secrets—we just do not see Attachment 1 itself as confidential. 3. In Attachment 1 it references "Justification for Request for Exception From Disclosure Pursuant to Chapter 3, Section 45". I am not sure what Chapter 3,Section 45 is? You could sight 20 AAC 25.283(k). 4. I sense you are looking for a ruling on confidentiality. AOGCC as per 20 AAC 25.283(k)will keep the documents contained in the envelope marked "confidential" as confidential. However, upon a public records request(could be 10 years from now or 1 week)we will notify you and request the affidavit from you stating which documents remain wholly or partially confidential. The process on keeping this information nondisclosable is subject to the judicial process (not AOGCC at that point) and your company would be involved in defending the case. As a part of the disclosable information we would appreciate the MSDS sheets be submitted for the additives. We are under the opinion that OSHA and Department of Transportation, as well as the Alaska Department of Environmental Conservation require access to the MSDS for first responder purposes-and AOGCC is requesting this also for our information. If there are any additional questions or concerns, please get back with me. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 2 From: Williams, Will [mailto:Will.Williams@corelab.com] Sent: Monday, February 09, 2015 3:07 PM To: Wallace, Chris D (DOA) Cc: Carlisle, Samantha 3 (DOA); Blush, Ron Subject: RE: Chemical Disclosure Chris, Here is a request similar to what was submitted to Wyoming. I edited to fit what I believe you are requesting. Please let me know if you need any additional information. Again,thanks for all the help on this. Will Williams D:713-328-2325/M:713-328-2320 C:713-516-7392 /F:713-328-2163 will.williams(o�corelab.com I www.corelab.com/orotechnics From:Wallace,Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, February 06,2015 12:58 PM To:Williams,Will Cc:Carlisle,Samantha J (DOA) Subject: RE:Chemical Disclosure Will, We are in the early stages of this and so we are finalizing the process of if a 3rd party can submit required information separately from the operator. I will let you know the process as it is relayed to me. Conoco (Robert Blakney) also relayed this to me and so we will work through this. Either way,the AOGCC will need accompanying trade secret justification for each chemical where trade secret confidentiality is requested. State and Federal trade secrets statutes go into the criteria that must be met to establish trade secrets. I imagine you already have these similar packets for each chemical submitted to the other state agencies. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Williams, Will [mailto:Will.Williams@corelab.com] Sent:Thursday, February 05, 2015 8:55 AM 3 • • To: Wallace, Chris D (DOA) Cc: Carlisle, Samantha 3 (DOA) Subject: RE: Chemical Disclosure Mr. Wallace, Thank you for the quick response. I have attached a snippet from the example of 3 different types of chemicals I sent you yesterday. Presently we have approximately 70 different chemicals and testing additional ones every day. Each of these chemicals have a unique CAS number and we need to maintain Trade Secret Status. If I am reading the comments below correctly, it appears we need to provide the confidential information to the AOGCC through the operator(s)? Is that correct as we would prefer not to go that route either? Trade LarneA ve 7 eM Oen cal Oom l a CAS fiber OFT 1000 1111111111UM11.1111 }_ _ OFT5000 ra•e ecret taus OFT8000 � r •e ecret vtatus Will Williams D:713-328-23251 M:713-328-2320 C:713-516-7392 I F.713-328-2163 will.williamsCc corelab.com!www.corelab.com/protechnics From:Wallace,Chris D(DOA) [mailto:chris.wallace@alaska.gov] Sent:Wednesday, February 04,2015 7:01 PM To:Williams, Will Cc:Carlisle,Samantha J (DOA) Subject: RE:Chemical Disclosure Will, Thank you for the email. The hydraulic fracturing regulations 20 AAC 25.283 are in effect as of January 7, 2015 and are accessed via the AOGCC home pages at http://doa.alaska.gov/ogc/Regulations/20AAC25-005c13.pdf The hydraulic fracturing application regulations and requirements relating to chemical disclosure are quite specific (20 AAC 25.283 (a)(12)) in that they require the actual CAS numbers of each component, but allow the concentration to be expressed as an estimated or maximum. In that way several service companies have indicated that they are able to provide the CAS numbers for each component while not disclosing a trade secret or proprietary ingredient mix or concentration. If after review you are unable/unwilling to provide the required CAS numbers,the AOGCC has a procedure for an operator/service company to claim as trade secret and claim confidentiality(20 AAC 25.283 (k)). This should be coordinated with the submitting operator. 4 • • (k)Any information required to be filed under this section that the filing party believes to be a confidential trade secret shall be separately filed in an envelope clearly marked "confidential" along with a list of the documents that the party believes to be wholly or partially nondisclosable as trade secrets, and the specific legal authority and specific facts supporting nondisclosure.The commission will review the information, and will maintain it as confidential. If the commission receives a request under AS 40.25.100-40.25.295 (Alaska Public Records Act)for disclosure of the information, the commission will promptly forward the request to the party claiming confidentiality. Not later than five business days after receiving the request, the party claiming confidentiality shall file with the commission an affidavit verifying that the documents remain wholly or partially confidential, identifying any portions of the document that are not confidential, and setting out the specific facts and legal authority supporting nondisclosure.After reviewing the affidavit, in accordance with and within the time allowed to respond under 2 AAC 96.325, the commission will determine whether to provide the party making the public records request the requested documents or the list of nondisclosable documents,the specific legal authority and facts supporting nondisclosure, and the affidavit provided by the party claiming confidentiality.The commission will notify the party claiming confidentiality if an appeal is requested under AS 40.25.123(e) and 2 AAC 96.340, or if judicial relief is sought under AS 40.25.124 or 40.25.125. We can discuss in more detail and coordinate a meeting with the operator if requested. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace©alaska.gov. From: Williams, Will [mailto:Will.Williams@corelab.com] Sent: Wednesday, February 04, 2015 11:53 AM To: Carlisle, Samantha 3 (DOA) Subject: FW: Chemical Disclosure Ms. Carlisle, I sent the following email to Jodi but received her Out of Office and to contact you Hello my name is Will Williams and one of our clients informed us about the new regulation on disclosure that is now in effect. I have a couple of questions concerning this regulation before we continue operating in Alaska 5 • completes less than a dozen jobs a year in Alaska and we have been requested to do one in a week or so. 1. vur Chemicals are "Trade Secret" so do we need to register with the state before we can work in Alaska 2. Please see attached Alaska Sample Disclosure document that we currently provide to our clients that they use for disclosure requirements or to obtain proper permits or approval for fracturing operations. It list each separate chemical that is used in the well 3. The Wyoming document list the four different chemicals We have registered our chemicals with the state of Wyoming and Arkansas. We were in the process of registering with California, but it appeared that their regulations provided no guarantee of maintaining Trade Secret Status so we have basically stopped working in that state. I am hopeful that one of the two attached documents will suffice, but if not what would the next step in the process be? I appreciate your time and a speedy response would be much appreciated. Will Williams Director of US Operations Core Lab Pro Technics Division D:713-328-2325 I M: 713-328-2320 C:713-516-7392 /F:713-328-2163 6510 W.Sam Houston Pkwy NJ Houston,TX 77041 will.williams(a�corelab.com/www.corelab.com/protechnics 6 • 114167 RECEIVED 25 546 ConocoPhillipsMAR 19 2015 TRANSMITTAL AOGCC --6ONFtD€ivtT1A -DAT (7._ 3 DATA LOGGED M.K.BENDER FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3S-620 DATE: 03/18/2015 Transmitted: Kuparuk River Unit, Alaska 3S-620 1 CD and hardcopy report Halliburton -Surface data logging and End of Well report- mud logging data for 3S-620; 01/17/2015; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 color print each: Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeCOP.com CC: 3S-620 transmittal folder, production well files, eSearch Receipt: 1'22,d. 1z.#zL1'i 13--eikeate: 7IFA GIS-Technical Data Management ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 214167 • ConocoPhillips DATA LOGGED 3/ /2o15 M.K.BENDER TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO14-1412 TO: Makana Bender RCCEIVED ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 tr'A %$ GI RE: 3S-620 AStelIC DATE: 03/17/2015 Transmitted: Kuparuk River Unit, Alaska 3S-620 1 CD and 1 log 2 5 5 3 1 SonicScope (TOC); logged 14FEB15; contains PDF logs, DLIS and LAS data 1 CD and 1 log print each 2 5 5 3 0 EcoScope 2"=100'TVD EcoScope 5"=100'TVD EcoScope 5"=100' MD EcoScope 2"=100' MD Microscope Resistivity Image 5"=100' CD contains Graphics: PDF/tiff; data ascii/dlis; directional survey data in .pdf/txt 1 hardcopy print of the definitive directional survey in NAD27 and NAD 83 Please promptly sign, scan and return electronically to Sandra.D.LemkegCOP.com CC: 3S-620 transmittal folder, production well files, eSearch o_eoteezt Receipt: Date: - 7-- - GIS-Technical Data Management I ConocoPhillips Anchorage, Alaska I Ph: 907.265.6947 214167 ConocoPhillips DATA LOGGED /(g/2015 M.K.BENDER TRANSMITTAL - CONFIDENTIAL DATA M FROM: Sandra D. Lemke, ATO14-1412 TO: Makana BenderVG® ConocoPhillips Alaska, Inc. AOGCC G P.O. Box 100360 333 W. 7th Ave., suite 100 I', Anchorage AK 99510-0360 Anchorage, Alaska 99501 . "1 I$ li RE: 3S-620 (C,'(0( DATE: 03/17/2015 Transmitted: li Kuparuk River Unit, Alaska 3S-620 1 CD and 1 loq 2 5 5 3 1 SonicScope(TOC); logged 14FEB15; contains PDF logs, DLIS and LAS data 1 CD and 1 log print each 2 5 5 3 0 EcoScope 2"=100'TVD EcoScope 5"=100'TVD EcoScope 5"=100' MD EcoScope 2"=100' MD Microscope Resistivity Image 5"=100' CD contains Graphics: PDF/tiff; data ascii/dlis; directional survey data in .pdf/txt 1 hardcopy print of the definitive directional survey in NAD27 and NAD 83 Please promptly sign, scan and return electronically to Sandra.D.Lemke( COP.com CC: 3S-620 transmittal folder, production well files, eSearch Receipt: �: s .,: GIS-Technical Data Management ConocoPhillips !Anchorage, Alaska I Ph: 907.265.6947 25530 FINAL NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-620 Definitive Survey Report NAD 27 24 February, 2015 • i Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 35-620 Database: OAKEDMP2 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 Zone: Alaska Zone 04 Using geodetic scale factor Well 3S-620 Well Position +N/-S 0.00 usft Northing: 5,993,869.45 usft Latitude: 70°23'39.768 N +EI-W 0.00 usft Easting: 476,071.76 usft Longitude: 150°11'40.873 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 24.70 usft Wellbore 3S-620 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2014 1/19/2015 18.85 80.92 57,568 Design 3S-620 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 27.50 0.00 0.00 346.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 96.63 1,122.70 3S-620 Srvy#1-GYD-GC-SS(3S-620) GYD-GC-SS Gyrodata gyro single shots 1/26/2015 12:41 1,269.47 3,070.24 3S-620 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 11:28: 3,157.32 9,218.45 3S-620 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 1:36: 9,299.87 13,689.40 3S-620 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 3:04: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -24.70 0.00 0.00 5,993,869.45 476,071.76 0.00 0.00 UNDEFINED 96.63 0.25 278.61 96.63 44.43 0.02 -0.15 5,993,869.47 476,071.61 0.36 0.06 GYD-GC-SS(1) 132.87 0.59 278.90 132.87 80.67 0.06 -0.41 5,993,869.51 476,071.35 0.94 0.16 GYD-GC-SS(1) 173.73 0.52 261.74 173.73 121.53 0.07 -0.80 5,993,869.52 476,070.96 0.44 0.26 GYD-GC-SS(1) 237.33 1.46 129.65 237.32 185.12 -0.49 -0.46 5,993,868.96 476,071.29 2.91 -0.36 GYD-GC-SS(1) 273.07 2.72 119.48 273.04 220.84 -1.20 0.62 5,993,868.25 476,072.38 3.66 -1.31 GYD-GC-SS(1) 331.59 3.54 131.52 331.47 279.27 -3.08 3.19 5,993,866.36 476,074.94 1.79 -3.76 GYD-GC-SS(1) 424.89 2.57 149.17 424.64 372.44 -6.78 6.41 5,993,862.65 476,078.15 1.44 -8.13 GYD-GC-SS(1) 473.46 2.24 185.60 473.17 420.97 -8.66 6.88 5,993,860.76 476,078.61 3.16 -10.07 GYD-GC-SS(1) 562.26 3.95 237.74 561.85 509.65 -12.02 4.12 5,993,857.41 476,075.84 3.52 -12.66 GYD-GC-SS(1) 654.20 6.15 265.52 653.44 601.24 -14.10 -3.47 5,993,855.36 476,068.25 3.51 -12.84 GYD-GC-SS(1) 2/24/2015 8:27:36AM Page 2 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 747.03 6.37 283.12 745.73 693.53 -13.32 -13.44 5,993,856.17 476,058.28 2.07 -9.67 GYD-GC-SS(1) 840.56 7.42 283.52 838.58 786.38 -10.73 -24.36 5,993,858.80 476,047.36 1.12 -4.52 GYD-GC-SS(1) 934.26 7.18 284.69 931.52 879.32 -7.83 -35.91 5,993,861.73 476,035.83 0.30 1.09 GYD-GC-SS(1) 1,027.29 7.79 283.39 1,023.76 971.56 -4.90 -47.67 5,993,864.71 476,024.08 0.68 6.78 GYD-GC-SS(1) 1,122.70 9.18 286.46 1,118.12 1,065.92 -1.24 -61.26 5,993,868.40 476,010.50 1.53 13.62 GYD-GC-SS(1) 1,272.97 12.89 279.50 1,265.59 1,213.39 4.92 -89.30 5,993,874.66 475,982.49 2.62 26.38 MWD+IFR-AK-CAZ-SC(2) 1,364.86 16.22 279.09 1,354.52 1,302.32 8.64 -112.08 5,993,878.45 475,959.71 3.63 35.50 MWD+IFR-AK-CAZ-SC(2) 1,456.31 20.00 281.06 1,441.42 1,389.22 13.66 -140.06 5,993,883.56 475,931.76 4.19 47.14 MWD+IFR-AK-CAZ-SC(2) 1,551.41 24.55 280.42 1,529.40 1,477.20 20.36 -175.47 5,993,890.37 475,896.38 4.79 62.20 MWD+IFR-AK-CAZ-SC(2) 1,642.85 28.85 279.18 1,611.08 1,558.88 27.32 -215.95 5,993,897.46 475,855.92 4.74 78.75 MWD+IFR-AK-CAZ-SC(2) 1,734.86 32.43 281.24 1,690.23 1,638.03 35.67 -262.07 5,993,905.96 475,809.83 4.05 98.01 MWD+IFR-AK-CAZ-SC(2) 1,828.05 33.99 281.31 1,768.20 1,716.00 45.65 -312.13 5,993,916.10 475,759.81 1.67 119.81 MWD+IFR-AK-CAZ-SC(2) 1,923.47 38.09 279.22 1,845.34 1,793.14 55.60 -367.36 5,993,926.22 475,704.62 4.49 142.82 MVVD+IFR-AK-CAZ-SC(2) 2,015.33 41.22 277.88 1,916.06 1,863.86 64.29 -425.32 5,993,935.10 475,646.69 3.53 165.28 MWD+IFR-AK-CAZ-SC(2) 2,108.67 43.99 277.85 1,984.75 1,932.55 72.94 -487.91 5,993,943.94 475,58414 2.97 188.81 MWD+IFR-AK-CAZ-SC(2) 2,201.77 45.70 278.40 2,050.76 1,998.56 82.22 -552.90 5,993,953.43 475,519.18 1.88 213.54 MWD+IFR-AK-CAZ-SC(2) 2,296.02 49.16 278.52 2,114.51 2,062.31 92.43 -621.54 5,993,963.86 475,450.58 3.67 240.05 MWD+IFR-AK-CAZ-SC(2) 2,389.88 52.56 276.60 2,173.75 2,121.55 101.98 -693.70 5,993,973.64 475,378.46 3.95 266.77 MWD+IFR-AK-CAZ-SC(2) 2,483.01 55.16 277.50 2,228.67 2,176.47 111.22 -768.33 5,993,983.12 475,303.87 2.90 293.79 MWD+IFR-AK-CAZ-SC(2) 2,577.29 56.72 277.04 2,281.47 2,229.27 121.10 -845.80 5,993,993.25 475,226.43 1.70 322.12 MWD+IFR-AK-CAZ-SC(2) 2,669.63 61.46 274.36 2,328.90 2,276.70 128.92 -924.61 5,994,001.32 475,147.66 5.70 348.78 MW1D+IFR-AK-CAZ-SC(2) 2,719.27 63.34 274.76 2,351.89 2,299.69 132.42 -968.46 5,994,004.95 475,103.83 3.85 362.78 MWD+IFR-AK-CAZ-SC(2) 2,760.93 62.93 274.90 2,370.72 2,318.52 135.55 -1,005.49 5,994,008.20 475,066.81 1.03 374.77 MWD+IFR-AK-CAZ-SC(2) 2,855.90 62.13 275.03 2,414.53 2,362.33 142.84 -1,089.44 5,994,015.76 474,982.89 0.85 402.16 MWD+IFR-AK-CAZ-SC(2) 2,948.61 62.68 274.51 2,457.47 2,405.27 149.67 -1,171.32 5,994,022.86 474,901.05 0.77 428.59 MWD+IFR-AK-CAZ-SC(2) 3,042.95 62.61 276.52 2,500.83 2,448.63 157.72 -1,254.71 5,994,031.17 474,817.68 1.89 456.58 MWD+IFR-AK-CAZ-SC(2) 3,145.00 62.38 276.44 2,547.95 2,495.75 167.94 -1,344.65 5,994,041.68 474,727.79 0.23 488.25 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 3,160.82 62.35 276.43 2,555.29 2,503.09 169.51 -1,358.58 5,994,043.29 474,713.87 0.23 493.15 MWD+IFR-AK-CAZ-SC(3) 3,223.14 63.20 276.68 2,583.80 2,531.60 175.84 -1,413.63 5,994,049.79 474,658.84 1.41 512.60 MWD+IFR-AK-CAZ-SC(3) 3,317.18 63.21 277.13 2,626.19 2,573.99 185.93 -1,496.96 5,994,060.15 474,575.55 0.43 542.56 MWD+IFR-AK-CAZ-SC(3) 3,410.21 63.18 276.47 2,668.14 2,615.94 195.76 -1,579.41 5,994,070.25 474,493.14 0.63 572.04 MWD+IFR-AK-CAZ-SC(3) 3,503.84 63.14 276.43 2,710.42 2,658.22 205.15 -1,662.43 5,994,079.90 474,410.16 0.06 601.23 MWD+IFR-AK-CAZ-SC(3) 3,596.00 63.14 276.84 2,752.06 2,699.86 214.65 -1,744.09 5,994,089.66 474,328.53 0.40 630.21 MWD+IFR-AK-CAZ-SC(3) 3,687.72 63.12 275.96 2,793.51 2,741.31 223.77 -1,825.40 5,994,099.04 474,247.27 0.86 658.72 MWD+IFR-AK-CAZ-SC(3) 3,781.30 63.13 276.22 2,835.82 2,783.62 232.62 -1,908.40 5,994,108.16 474,164.30 0.25 687.40 MWD+IFR-AK-CAZ-SC(3) 3,873.74 63.08 276.00 2,877.63 2,825.43 241.40 -1,990.37 5,994,117.19 474,082.37 0.22 715.74 MWD+IFR-AK-CAZ-SC(3) 3,965.62 63.10 276.28 2,919.22 2,867.02 250.16 -2,071.84 5,994,126.22 474,000.94 0.27 743.95 MWD+IFR-AK-CAZ-SC(3) 4,058.93 63.15 275.93 2,961.40 2,909.20 259.01 -2,154.60 5,994,135.33 473,918.22 0.34 772.56 MWD+IFR-AK-CAZ-SC(3) 4,152.89 63.15 276.59 3,003.83 2,951.63 268.15 -2,237.93 5,994,144.74 473,834.93 0.63 801.59 MWD+IFR-AK-CAZ-SC(3) 2/24/2015 8:27:36AM Page 3 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,247.85 63.10 276.84 3,046.76 2,994.56 278.06 -2,322.05 5,994,154.91 473,750.84 0.24 831.55 MVVD+IFR-AK-CAZ-SC(3) 4,341.09 63.16 276.40 3,088.90 3,036.70 287.65 -2,404.67 5,994,164.76 473,668.26 0.43 860.84 MWD+IFR-AK-CAZ-SC(3) 4,434.57 63.17 276.57 3,131.10 3,078.90 297.07 -2,487.55 5,994,174.45 473,585.42 0.16 890.03 MVVD+IFR-AK-CAZ-SC(3) 4,526.99 63.12 276.59 3,172.85 3,120.65 306.52 -2,569.46 5,994,184.16 473,503.55 0.06 919.02 MWD+IFR-AK-CAZ-SC(3) 4,619.40 63.16 276.70 3,214.60 3,162.40 316.06 -2,651.34 5,994,193.96 473,421.71 0.11 948.08 MWD+IFR-AK-CAZ-SC(3) 4,713.18 63.15 276.70 3,256.95 3,204.75 325.82 -2,734.44 5,994,203.98 473,338.64 0.01 977.66 MWD+IFR-AK-CAZ-SC(3) 4,805.11 63.19 276.89 3,298.44 3,246.24 335.52 -2,815.90 5,994,213.95 473,257.23 0.19 1,006.79 MWD+IFR-AK-CAZ-SC(3) 4,897.05 63.19 276.37 3,339.91 3,287.71 345.00 -2,897.41 5,994,223.68 473,175.76 0.50 1,035.70 MWD+IFR-AK-CAZ-SC(3) 4,989.62 63.10 275.90 3,381.73 3,329.53 353.82 -2,979.52 5,994,232.77 473,093.68 0.46 1,064.13 MWD+IFR-AK-CAZ-SC(3) 5,082.59 63.10 275.44 3,423.79 3,371.59 362.02 -3,062.03 5,994,241.23 473,011.21 0.44 1,092.03 MWD+IFR-AK-CAZ-SC(3) 5,176.51 63.28 274.34 3,466.15 3,413.95 369.16 -3,145.54 5,994,248.64 472,927.73 1.06 1,119.17 MWD+IFR-AK-CAZ-SC(3) 5,269.10 63.17 275.37 3,507.87 3,455.67 376.16 -3,227.91 5,994,255.90 472,845.39 1.00 1,145.88 MVVD+IFR-AK-CAZ-SC(3) 5,360.86 63.14 275.84 3,549.30 3,497.10 384.15 -3,309.39 5,994,264.15 472,763.95 0.46 1,173.35 MWD+IFR-AK-CAZ-SC(3) 5,452.61 63.21 276.35 3,590.71 3,538.51 392.85 -3,390.80 5,994,273,11 472,682.57 0.50 1,201.49 MWD+IFR-AK-CAZ-SC(3) 5,546.24 63.13 276.25 3,632.97 3,580.77 402.01 -3,473.85 5,994,282.54 472,599.56 0.13 1,230.47 MWD+IFR-AK-CAZ-SC(3) 5,638.25 63.15 275.81 3,674.54 3,622.34 410.64 -3,555.48 5,994,291.42 472,517.97 0.43 1,258.59 MWD+IFR-AK-CAZ-SC(3) 5,732.53 63.13 275.45 3,717.13 3,664.93 418.89 -3,639.18 5,994,299.94 472,434.30 0.34 1,286.84 MVVD+IFR-AK-CAZ-SC(3) 5,824.91 63.21 276.11 3,758.83 3,706.63 427.19 -3,721.20 5,994,308.50 472,352.32 0.64 1,314.74 MWD+IFR-AK-CAZ-SC(3) 5,917.99 63.16 276.38 3,800.82 3,748.62 436.23 -3,803.77 5,994,317.80 472,269.78 0.26 1,343.48 MWD+IFR-AK-CAZ-SC(3) 6,011.12 63.20 275.66 3,842.84 3,790.64 444.94 -3,886.43 5,994,326.78 472,187.16 0.69 1,371.94 MWD+IFR-AK-CAZ-SC(3) 6,102.87 63.17 275.86 3,884.23 3,832.03 453.16 -3,967.90 5,994,335.26 472,105.73 0.20 1,399.62 M1N3+IFR-AK-CAZ-SC(3) 6,196.11 63.18 276.01 3,926.30 3,874.10 461.76 -4,050.66 5,994,344.13 472,023.00 0.14 1,427.99 MWD+IFR-AK-CAZ-SC(3) 6,288.23 63.19 275.90 3,967.86 3,915.66 470.29 -4,132.43 5,994,352.92 471,941.27 0.11 1,456.05 MWD+IFR-AK-CAZ-SC(3) 6,380.99 62.68 275.92 4,010.07 3,957.87 478.80 -4,214.59 5,994,361.69 471,859.14 0.55 1,484.18 MWD+IFR-AK-CAZ-SC(3) 6,474.69 63.03 276.00 4,052.82 4,000.62 487.46 -4,297.52 5,994,370.61 471,776.25 0.38 1,512.64 MWD+IFR-AK-CAZ-SC(3) 6,567.60 63.23 276.67 4,094.81 4,042.61 496.60 -4,379.89 5,994,380.02 471,693.92 0.68 1,541.44 MWD+IFR-AK-CAZ-SC(3) 6,663.92 63.03 277.12 4,138.34 4,086.14 506.92 -4,465.19 5,994,390.60 471,608.66 0.47 1,572.09 MWD+IFR-AK-CAZ-SC(3) 6,754.32 62.62 277.12 4,179.63 4,127.43 516.88 -4,544.99 5,994,400.83 471,528.90 0.45 1,601.06 MWD+IFR-AK-CAZ-SC(3) 6,847.74 62.97 275.24 4,222.34 4,170.14 525.83 -4,627.59 5,994,410.03 471,446.34 1.83 1,629.72 MWD+IFR-AK-CAZ-SC(3) 6,941.13 63.15 275.18 4,264.65 4,212.45 533.39 -4,710.50 5,994,417.86 471,363.46 0.20 1,657.11 MVVD+IFR-AK-CAZ-SC(3) 7,034.03 63.22 274.87 4,306.56 4,254.36 540.65 -4,793.09 5,994,425.38 471,280.90 0.31 1,684.14 MVVD+IFR-AK-CAZ-SC(3) 7,128.63 63.26 274.48 4,349.16 4,296.96 547.53 -4,877.28 5,994,432.53 471,196.74 0.37 1,711.19 MWD+IFR-AK-CAZ-SC(3) 7,220.74 63.23 275.20 4,390.62 4,338.42 554.47 -4,959.23 5,994,439.74 471,114.82 0.70 1,737.75 MWD+IFR-AK-CAZ-SC(3) 7,313.28 62.70 276.15 4,432.68 4,380.48 562.62 -5,041.25 5,994,448.15 471,032.83 1.08 1,765.50 MVVD+IFR-AK-CAZ-SC(3) 7,406.70 62.72 276.46 4,475.52 4,423.32 571.74 -5,123.77 5,994,457.53 470,950.35 0.30 1,794.31 MWD+IFR-AK-CAZ-SC(3) 7,500.89 63.20 276.15 4,518.34 4,466.14 580.95 -5,207.16 5,994,467.01 470,867.00 0.59 1,823.42 MVVD+IFR-AK-CAZ-SC(3) 7,593.47 63.19 276.69 4,560.09 4,507.89 590.19 -5,289.27 5,994,476.51 470,784.93 0.52 1,852.25 MWD+IFR-AK-CAZ-SC(3) 7,686.32 63.17 276.89 4,601.98 4,549.78 599.99 -5,371.55 5,994,486.57 470,702.69 0.19 1,881.66 MWD+IFR-AK-CAZ-SC(3) 7,778.78 63.22 276.68 4,643.68 4,591.48 609.74 -5,453.50 5,994,496.58 470,620.78 0.21 1,910.95 MWD+IFR-AK-CAZ-SC(3) 7,873.14 63.31 278.02 4,686.13 4,633.93 620.52 -5,537.08 5,994,507.63 470,537.24 1.27 1,941.63 MVVD+IFR-AK-CAZ-SC(3) 2/24/2015 8:27:36AM Page 4 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (") C) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,966.46 63.89 281.27 4,727.63 4,675.43 634.53 -5,619.47 5,994,521.90 470,454.91 3.18 1,975.15 MWD+IFR-AK-CAZ-SC(3) 8,061.82 64.50 284.88 4,769.15 4,716.95 653.95 -5,703.07 5,994,541.58 470,371.38 3.47 2,014.22 MWD+IFR-AK-CAZ-SC(3) 8,105.54 65.02 286.25 4,787.79 4,735.59 664.56 -5,741.17 5,994,552.32 470,333.32 3.07 2,033.74 MWD+IFR-AK-CAZ-SC(3) 8,154.03 65.24 289.46 4,808.19 4,755.99 678.05 -5,783.03 5,994,565.94 470,291.50 6.02 2,056.95 MWD+IFR-AK-CAZ-SC(3) 8,198.80 65.64 291.34 4,826.80 4,774.60 692.24 -5,821.20 5,994,580.25 470,253.39 3.92 2,079.96 MWD+IFR-AK-CAZ-SC(3) 8,247.08 65.96 293.17 4,846.59 4,794.39 708.92 -5,861.95 5,994,597.06 470,212.69 3.52 2,106.00 MWD+IFR-AK-CAZSC(3) 8,291.86 66.12 295.12 4,864.78 4,812.58 725.66 5,899.29 5,994,613.91 470,175.41 4.00 2,131.27 MVVD+IFR-AK-CAZ-SC(3) 8,339.30 66.44 297.29 4,883.87 4,831.67 744.84 -5,938.25 5,994,633.22 470,136.51 4.24 2,159.31 MWD+IFR-AK-CAZSC(3) 8,381.72 66.68 299.35 4,900.74 4,848.54 763.30 -5,972.51 5,994,651.79 470,102.31 4.49 2,185.51 MWD+IFR-AK-CAZ-SC(3) 8,431.49 67.04 302.36 4,920.30 4,868.10 786.77 -6,011.79 5,994,675.38 470,063.11 5.61 2,217.78 MWD+IFR-AK-CAZ-SC(3) 8,477.50 67.33 304.29 4,938.15 4,885.95 810.07 -6,047.23 5,994,698.79 470,027.76 3.92 2,248.96 MWD+IFR-AK-CAZ-SC(3) 8,524.46 67.80 306.50 4,956.07 4,903.87 835.21 -6,082.61 5,994,724.04 469,992.46 4.46 2,281.92 MVVD+IFR-AK-CAZ-SC(3) 8,567.64 68.13 309.07 4,972.27 4,920.07 859.73 -6,114.24 5,994,748.66 469,960.91 5.57 2,313.36 MWD+IFR-AK-CAZ-SC(3) 8,617.75 68.63 311.06 4,990.74 4,938.54 889.71 -6,149.89 5,994,778.75 469,925.36 3.82 2,351.08 MWD+IFR-AK-CAZ-SC(3) 8,663.03 68.86 313.57 5,007.15 4,954.95 918.12 -6,181.09 5,994,807.26 469,894.26 5.19 2,386.19 MWD+IFR-AK-CAZ-SC(3) 8,712.03 69.21 316.59 5,024.69 4,972.49 950.52 -6,213.39 5,994,839.75 469,862.06 5.80 2,425.44 MWD+IFR-AK-CAZ-SC(3) 8,760.60 69.62 319.11 5,041.77 4,989.57 984.22 -6,243.90 5,994,873.56 469,831.66 4.93 2,465.53 MWD+IFR-AK-CAZ-SC(3) 8,805.29 69.91 320.71 5,057.23 5,005.03 1,016.30 -6,270.90 5,994,905.72 469,804.77 3.42 2,503.18 MWD+IFR-AK-CAZ-SC(3) 8,857.17 70.35 323.65 5,074.86 5,022.66 1,054.84 -6,300.81 5,994,944.35 469,774.98 5.40 2,547.81 MWD+IFR-AK-CAZ-SC(3) 8,897.07 70.67 325.08 5,088.18 5,035.98 1,085.41 -6,322.73 5,994,974.98 469,753.17 3.47 2,582.78 MWD+IFR-AK-CAZSC(3) 8,941.51 71.06 327.76 5,102.74 5,050.54 1,120.39 -6,345.95 5,995,010.03 469,730.06 5.76 2,622.33 MWD+IFR-AK-CAZSC(3) 8,990.73 71.66 329.33 5,118.48 5,066.28 1,160.17 -6,370.28 5,995,049.89 469,705.86 3.26 2,666.82 MWD+IFR-AK-CAZSC(3) 9,034.13 73.11 331.33 5,131.61 5,079.41 1,196.11 -6,390.75 5,995,085.89 469,685.50 5.52 2,706.64 MWD+IFR-AK-CAZSC(3) 9,085.39 74.57 333.77 5,145.88 5,093.68 1,239.80 -6,413.44 5,995,129.64 469,662.96 5.39 2,754.52 MWD+IFR-AK-CAZ-SC(3) 9,135.39 76.12 335.51 5,158.53 5,106.33 1,283.51 -6,434.16 5,995,173.42 469,642.38 4.58 2,801.94 MWD+IFR-AK-CAZSC(3) 9,177.86 77.80 336.97 5,168.11 5,115.91 1,321.37 -6,450.82 5,995,211.33 469,625.84 5.18 2,842.72 MWD+IFR-AK-CAZ-SC(3) 9,218.45 79.44 338.93 5,176.12 5,123.92 1,358.25 -6,465.76 5,995,248.25 469,611.02 6.22 2,882.12 MWD+IFR-AK-CAZ-SC(3) 9,279.00 81.31 340.38 5,186.25 5,134.05 1,414.22 -6,486.51 5,995,304.29 469,590.45 3.88 2,941.44 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 9,299.87 81.95 340.88 5,189.29 5,137.09 1,433.70 -6,493.36 5,995,323.78 469,583.67 3.88 2,962.00 MWD+IFR-AK-CAZ-SC(4) 9,340.50 83.41 341.57 5,194.46 5,142.26 1,471.85 -6,506.33 5,995,361.98 469,570.82 3.97 3,002.16 MWD+IFR-AK-CAZ-SC(4) 9,434.89 85.17 343.72 5,203.86 5,151.66 1,561.49 -6,534.34 5,995,451.69 469,543.10 2.93 3,095.91 MWD+IFR-AK-CAZ-SC(4) 9,530.27 85.18 345.52 5,211.88 5,159.68 1,653.13 -6,559.54 5,995,543.40 469,518.19 1.88 3,190.92 MWD+IFR-AK-CAZ-SC(4) 9,579.10 83.88 346.95 5,216.53 5,164.33 1,700.34 -6,571.11 5,995,590.64 469,506.78 3.95 3,239.52 MWD+IFR-AK-CAZ-SC(4) 9,624.07 82.94 347.51 5,221.70 5,169.50 1,743.90 -6,580.98 5,995,634.23 469,497.05 2.43 3,284.19 MWD+IFR-AK-CAZ-SC(4) 9,719.15 82.83 347.23 5,233.47 5,181.27 1,835.97 -6,601.61 5,995,726.36 469,476.71 0.31 3,378.51 MWD+IFR-AK-CAZ-SC(4) 9,814.29 84.72 345.39 5,243.79 5,191.59 1,927.85 -6,624.00 5,995,818.30 469,454.62 2.76 3,473.08 MWD+IFR-AK-CAZ-SC(4) 9,844.56 86.26 344.59 5,246.17 5,193.97 1,957.00 -6,631.81 5,995,847.47 469,446.90 5.73 3,503.25 MWD+IFR-AK-CAZ-SC(4) 9,908.30 89.62 343.95 5,248.46 5,196.26 2,018.30 -6,649.08 5,995,908.82 469,429.83 5.37 3,566.91 MWD+IFR-AK-CAZ-SC(4) 9,955.36 89.48 344.95 5,248.83 5,196.63 2,063.64 -6,661.69 5,995,954.19 469,417.37 2.15 3,613.95 MWD+IFR-AK-CAZ-SC(4) 10,004.11 89.28 345.51 5,249.36 5,197.16 2,110.77 -6,674.12 5,996,001.36 469,405.09 1.22 3,662.69 MWD+IFR-AK-CAZ-SC(4) 2/242015 8:27:36AM Page 5 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7©52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100) (ft) Survey Tool Name 10,098.59 88.56 346.23 5,251.14 5,198.94 2,202.38 -6,697.18 5,996,093.03 469,382.33 1.08 3,757.15 MWD+IFR-AK-CAZ-SC(4) 10,192.65 88.15 346.40 5,253.84 5,201.64 2,293.73 -6,719.43 5,996,184.44 469,360.38 0.47 3,851.17 MVVD+IFR-AK-CAZ-SC(4) 10,287.33 88.49 346.19 5,256.61 5,204.41 2,385.67 -6,741.85 5,996,276.45 469,338.25 0.42 3,945.81 MW0+IFR-AK-CAZ-SC(4) 10,382.46 89.07 346.31 5,258.64 5,206.44 2,478.06 -6,764.45 5,996,368.90 469,315.94 0.62 4,040.92 MWD+IFR-AK-CAZ-SC(4) 10,476.36 88.97 346.50 5,260.25 5,208.05 2,569.31 -6,786.52 5,996,460.21 469,294.17 0.23 4,134.80 MWD+IFR-AK-CAZSC(4) 10,570.93 89.26 345.76 5,261.71 5,209.51 2,661.11 -6,809.19 5,996,552.08 469,271.80 0.84 4,229.36 MWD+IFR-AK-CAZ-SC(4) 10,665.35 91.18 344.57 5,261.34 5,209.14 2,752.38 -6,833.36 5,996,643.41 469,247.92 2.39 4,323.76 MWD+IFR-AK-CAZ-SC(4) 10,760.04 91.03 344.32 5,259.52 5,207.32 2,843.58 -6,858.75 5,996,734.69 469,222.83 0.31 4,418.40 MWD+IFR-AK-CAZ-SC(4) 10,853.73 91.16 343.74 5,257.73 5,205.53 2,933.64 -6,884.52 5,996,824.82 469,197.34 0.63 4,512.02 MWD+IFR-AK-CAZ-SC(4) 10,949.13 91.10 344.78 5,255.85 5,203.65 3,025.44 -6,910.40 5,996,916.70 469,171.77 1.09 4,607.35 MWD+IFR-AK-CAZ-SC(4) 11,043.81 90.34 344.98 5,254.66 5,202.46 3,116.84 -6,935.09 5,997,008.16 469,147.37 0.83 4,702.01 MWD+IFR-AK-CAZ-SC(4) 11,139.21 89.62 346.00 5,254.69 5,202.49 3,209.19 -6,958.99 5,997,100.58 469,123.76 1.31 4,797.40 MWD+IFR-AK-CAZ-SC(4) 11,233.00 89.59 341.81 5,255.34 5,203.14 3,299.29 -6,984.99 5,997,190.75 469,098.06 4.47 4,891.10 MWD+IFR-AK-CAZ-SC(4) 11,328.09 89.86 337.24 5,255.79 5,203.59 3,388.34 -7,018.24 5,997,279.90 469,065.10 4.81 4,985.56 MWD+IFR-AK-CAZ-SC(4) 11,422,11 90.07 334.41 5,255.85 5,203.65 3,474.11 -7,056.74 5,997,365.78 469,026.87 3.02 5,078.09 MWD+IFR-AK-CAZ-SC(4) 11,517.85 90.38 336.94 5,255.47 5,203.27 3,561.34 -7,096.17 5,997,453.13 468,987.72 2.66 5,172.27 MWD+IFR-AK-CAZ-SC(4) 11,611.51 90.20 342.41 5,255.00 5,202.80 3,649.14 -7,128.69 5,997,541.02 468,955.49 5.84 5,265.33 MWD+IFR-AK-CAZ-SC(4) 11,656.78 89.96 345.22 5,254.94 5,202.74 3,692.61 -7,141.31 5,997,584.53 468,943.01 6.23 5,310.56 MWD+IFR-AK-CAZ-SC(4) 11,706.56 89.55 348.27 5,255.15 5,202.95 3,741.05 -7,152.72 5,997,633.01 468,931.76 6.18 5,360.33 MVD+IFR-AK-CAZ-SC(4) 11,755.76 89.35 349.15 5,255.62 5,203.42 3,789.30 -7,162.36 5,997,681.28 468,922.28 1.83 5,409.47 MWD+IFR-AK-CAZ-SC(4) 11,800.54 89.12 349.56 5,256.22 5,204.02 3,833.30 -7,170.63 5,997,725.30 468,914.15 1.05 5,454.17 MWD+IFR-AK-CAZ-SC(4) 11,894.31 90.62 348.73 5,256.43 5,204.23 3,925.39 -7,188.29 5,997,817.44 468,896.79 1.83 5,547.80 MWD+IFR-AK-CAZ-SC(4) 11,988.63 91.28 351.31 5,254.87 5,202.67 4,018.26 -7,204.63 5,997,910.35 468,880.75 2.82 5,641.86 MWD+IFR-AK-CAZ-SC(4) 12,083.85 90.74 350.65 5,253.19 5,200.99 4,112.29 -7,219.55 5,998,004.42 468,866.12 0.90 5,736.71 MWD+IFR-AK-CAZ-SC(4) 12,177.85 91.45 348.84 5,251.39 5,199.19 4,204.77 -7,236.28 5,998,096.94 468,849.69 2.07 5,830.49 MWD+IFR-AK-CAZ-SC(4) 12,273.41 90.40 348.63 5,249.85 5,197.65 4,298.47 -7,254.95 5,998,190.70 468,831.33 1.12 5,925.92 M1ND+IFR-AK-CAZSC(4) 12,367.16 90.51 348.31 5,249.11 5,196.91 4,390.33 -7,273.69 5,998,282.60 468,812.88 0.36 6,019.58 MWD+IFR-AK-CAZ-SC(4) 12,462.56 91.51 347.93 5,247.42 5,195.22 4,483.67 -7,293.32 5,998,375.99 468,793.55 1.12 6,114.90 MW3+IFR-AK-CAZ-SC(4) 12,556.79 91.47 348.08 5,244.97 5,192.77 4,575.81 -7,312.90 5,998,468.19 468,774.27 0.16 6,209.04 MWD+IFR-AK-CAZ-SC(4) 12,651.72 91.31 346.35 5,242.67 5,190.47 4,668.36 -7,333.90 5,998,560.79 468,753.57 1.83 6,303.92 MWD+IFR-AK-CAZ-SC(4) 12,745.30 89.78 342.57 5,241.78 5,189.58 4,758.49 -7,358.97 5,998,651.00 468,728.79 4.36 6,397.44 MWD+IFR-AK-CAZ-SC(4) 12,840.31 90.00 342.93 5,241.96 5,189.76 4,849.23 -7,387.14 5,998,741.82 468,700.91 0.44 6,492.30 MWD+IFR-AK-CAZ-SC(4) 12,934.51 90.29 346.12 5,241.72 5,189.52 4,940.00 -7,412.27 5,998,832.66 468,676.07 3.40 6,586.45 MWD+IFR-AK-CAZ-SC(4) 13,029.20 89.06 347.05 5,242.26 5,190.06 5,032.10 -7,434.24 5,998,924.82 468,654.40 1.63 6,681.13 MWD+IFR-AK-CAZ-SC(4) 13,122.94 89.64 346.93 5,243.33 5,191.13 5,123.43 -7,455.34 5,999,016.21 468,633.60 0.63 6,774.85 MWD+IFR-AK-CAZ-SC(4) 13,216.61 91.51 348.11 5,242.39 5,190.19 5,214.88 -7,475.58 5,999,107.71 468,613.65 2.36 6,868.48 MWD+IFR-AK-CAZ-SC(4) 13,310.98 93.28 348.20 5,238.44 5,186.24 5,307.15 -7,494.93 5,999,200.04 468,594.60 1.88 6,962.70 MVVD+IFR-AK-CAZ-SC(4) 13,404.46 93.02 346.86 5,233.30 5,181.10 5,398.29 -7,515.09 5,999,291.23 468,574.74 1.46 7,056.00 MWD+IFR-AK-CAZ-SC(4) 13,498.15 92.78 345.11 5,228.56 5,176.36 5,489.07 -7,537.75 5,999,382.07 468,552.37 1.88 7,149.57 MWD+IFR-AK-CAZSC(4) 13,592.77 93.02 345.40 5,223.78 5,171.58 5,580.46 -7,561.80 5,999,473.53 468,528.61 0.40 7,244.06 MWD+IFR-AK-CAZSC(4) 2/24/2015 8:27:36AM Page 6 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 13,655.00 92.93 345.11 5,220.55 5,168.35 5,640.56 -7,577.62 5,999,533.67 468,512.99 0.49 7,306.20 MWD+IFR-AK-CAZ-SC(4) 4 1/2"x 6-1/2" 13,689.40 92.88 344.95 5,218.80 5,166.60 5,673.75 -7,586.49 5,999,566.88 468,504.22 0.49 7,340.55 MWD+IFR-AK-CAZ-SC(4) 13,768.00 92.88 344.95 5,214.86 5,162.66 5,749.55 -7,606.87 5,999,642.75 468,484.08 0.00 7,419.04 PROJECTED to TD 2/24/2015 8:27:36AM Page 7 COMPASS 5000.1 Build 65 • • 25 530 RECEIVED MAR 1 7 2015 FINAL AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad 3S-620 Definitive Survey Report NAD 83 23 February, 2015 • • . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7©52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7©52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 3S-620 Well Position +N/-S 0.00 usft Northing: 5,993,619.98 usfi Latitude: 70°23'38.676 N +E/-W 0.00 usft Easting: 1,616,103.83 usfi Longitude: 150°11'52.159 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 24.70 usft Wellbore 3S-620 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 1/19/2015 18.85 80.92 57,568 Design 3S-620 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 346.00 Survey Program Date 2/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 96.63 1,122.70 3S-620 Srvy#1 -GYD-GC-SS(3S-620) GYD-GC-SS Gyrodata gyro single shots 1/26/2015 12:4 1,269.47 3,070.24 3S-620 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 11:2 3,157.32 9,218.45 3S-620 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 1:31 9,299.87 13,689.40 3S-620 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 3:0, Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -24.70 0.00 0.00 5,993,619.98 1,616,103.83 0.00 0.00 UNDEFINED 96.63 0.25 278.61 96.63 44.43 0.02 -0.15 5,993,620.00 1,616,103.68 0.36 0.06 GYD-GC-SS(1) 132.87 0.59 278.90 132.87 80.67 0.06 -0.41 5,993,620.04 1,616,103.42 0.94 0.16 GYD-GC-SS(1) 173.73 0.52 261.74 173.73 121.53 0.07 -0.80 5,993,620.05 1,616,103.03 0.44 0.26 GYD-GC-SS(1) 237.33 1.46 129.65 237.32 185.12 -0.49 -0.46 5,993,619.49 1,616,103.37 2.91 -0.36 GYD-GC-SS(1) 273.07 2.72 119.48 273.04 220.84 -1.20 0.62 5,993,618.78 1,616,104.45 3.66 -1.31 GYD-GC-SS(1) 331.59 3.54 131.52 331.47 279.27 -3.08 3.19 5,993,616.89 1,616,107.01 1.79 -3.76 GYD-GC-SS(1) 424.89 2.57 149.17 424.64 372.44 -6.78 6.41 5,993,613.18 1,616,110.22 1.44 -8.13 GYD-GC-SS(1) 473.46 2,24 185.60 473.17 420.97 -8.66 6.88 5,993,611.29 1,616,110.68 3.16 -10.07 GYD-GC-SS(1) 562.26 3.95 237.74 561.85 509.65 -12.02 4.12 5,993,607.94 1,616,107.92 3.52 -12.66 GYD-GC-SS(1) 654.20 6.15 265.52 653.44 601.24 -14.10 -3.47 5,993,605.89 1,616,100.32 3.51 -12.84 GYD-GC-SS(1) 747.03 6.37 283.12 745.73 693.53 -13.32 -13.44 5,993,606.71 1,616,090.35 2.07 -9.67 GYD-GC-SS(1) 840.56 7.42 283.52 838.58 786.38 -10.73 -24.36 5,993,609.33 1,616,079.44 1.12 -4.52 GYD-GC-SS(1) 934.26 7.18 284.69 931.52 879.32 -7.83 -35.91 5,993,612.27 1,616,067.90 0.30 1.09 GYD-GC-SS(1) 1,027.29 7.79 283.39 1,023.76 971.56 -4.90 -47.67 5,993,615.24 1,616,056.15 0.68 6.78 GYD-GC-SS(1) 2123/2015 3:28:15PM Page 2 COMPASS 5000.1 Build 65 • • - ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100.) (ft) Survey Tool Name 1,122.70 9.18 286.46 1,118.12 1,065.92 -1.24 -61.26 5,993,618.94 1,616,042.58 1.53 13.62 GYD-GC-SS(1) 1,272.97 12.89 279.50 1,265.59 1,213.39 4.92 -89.30 5,993,625.19 1,616,014.56 2.62 26.38 MWD+IFR-AK-CAZ-SC(2) 1,364.86 16.22 279.09 1,354.52 1,302.32 8.64 -112.08 5,993,628.99 1,615,991.79 3.63 35.50 MWD+IFR-AK-CAZ-SC(2) 1,456.31 20.00 281.06 1,441.42 1,389.22 13.66 -140.06 5,993,634.10 1,615,963.84 4.19 47.14 MWD+IFR-AK-CAZ-SC(2) 1,551.41 24.55 280.42 1,529.40 1,477.20 20.36 -175.47 5,993,640.91 1,615,928.45 4.79 62.20 MWD+IFR-AK-CAZ-SC(2) 1,642.85 28.85 279.18 1,611.08 1,558.88 27.32 -215.95 5,993,648.00 1,615,888.00 4.74 78.75 MWD+IFR-AK-CAZ-SC(2) 1,734.86 32.43 281.24 1,690.23 1,638.03 35.67 -262.07 5,993,656.50 1,615,841.90 4.05 98.01 MWD+IFR-AK-CAZ-SC(2) 1,828.05 33.99 281.31 1,768.20 1,716.00 45.65 -312.13 5,993,666.64 1,615,791.89 1.67 119.81 MWD+IFR-AK-CAZ-SC(2) 1,923.47 38.09 279.22 1,845.34 1,793.14 55.60 -367.36 5,993,676.77 1,615,736.69 4.49 142.82 MWD+IFR-AK-CAZ-SC(2) 2,015.33 41.22 277.88 1,916.06 1,863.86 64.29 -425.32 5,993,685.65 1,615,678.76 3.53 165.28 MWD+IFR-AK-CAZ-SC(2) 2,108.67 43.99 277.85 1,984.75 1,932.55 72.94 -487.91 5,993,694.50 1,615,616.21 2.97 188.81 MWD+IFR-AK-CAZ-SC(2) 2,201.77 45.70 278.40 2,050.76 1,998.56 82.22 -552.90 5,993,703.99 1,615,551.26 1.88 213.54 MWD+IFR-AK-CAZ-SC(2) 2,296.02 49.16 278.52 2,114.51 2,062.31 92.43 -621.54 5,993,714.43 1,615,482.65 3.67 240.05 MWD+IFR-AK-CAZ-SC(2) 2,389.88 52.56 276.60 2,173.75 2,121.55 101.98 -693.70 5,993,724.21 1,615,410.54 3.95 266.77 MWD+IFR-AK-CAZ-SC(2) 2,483.01 55.16 277.50 2,228.67 2,176.47 111.22 -768.33 5,993,733.69 1,615,335.95 2.90 293.79 MWD+IFR-AK-CAZ-SC(2) 2,577.29 56.72 277.04 2,281.47 2,229.27 121.10 -845.80 5,993,743.82 1,615,258.51 1.70 322.12 MWD+IFR-AK-CAZ-SC(2) 2,669.63 61.46 274.36 2,328.90 2,276.70 128.92 -924.61 5,993,751.89 1,615,179.74 5.70 348.78 MWD+IFR-AK-CAZ-SC(2) 2,719.27 63.34 274.76 2,351.89 2,299.69 132.42 -968.46 5,993,755.54 1,615,135.91 3.85 362.78 MWD+IFR-AK-CAZ-SC(2) 2,760.93 62.93 274.90 2,370.72 2,318.52 135.55 -1,005.49 5,993,758.78 1,615,098.89 1.03 374.77 MWD+IFR-AK-CAZ-SC(2) 2,855.90 62.13 275.03 2,414.53 2,362.33 142.84 -1,089.44 5,993,766.35 1,615,014.97 0.85 402.16 MWD+IFR-AK-CAZ-SC(2) 2,948.61 62.68 274.51 2,457.47 2,405.27 149.67 -1,171.32 5,993,773.45 1,614,933.13 0.77 428.59 MWD+IFR-AK-CAZ-SC(2) 3,042.95 62.61 276.52 2,500.83 2,448.63 157.72 -1,254.71 5,993,781.77 1,614,849.77 1.89 456.58 MWD+IFR-AK-CAZ-SC(2) 3,145.00 62.38 276.44 2,547.95 2,495.75 167.94 -1,344.65 5,993,792.28 1,614,759.87 0.23 488.25 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 3,160.82 62.35 276.43 2,555.29 2,503.09 169.51 -1,358.58 5,993,793.89 1,614,745.95 0.23 493.15 MWD+IFR-AK-CAZ-SC(3) 3,223.14 63.20 276.68 2,583.80 2,531.60 175.84 -1,413.63 5,993,800.40 1,614,690.92 1.41 512.60 MWD+IFR-AK-CAZ-SC(3) 3,317.18 63.21 277.13 2,626.19 2,573.99 185.93 -1,496.96 5,993,810.76 1,614,607.63 0.43 542.56 MWD+IFR-AK-CAZ-SC(3) 3,410.21 63.18 276.47 2,668.14 2,615.94 195.76 -1,579.41 5,993,820.86 1,614,525.22 0.63 572.04 MWD+IFR-AK-CAZ-SC(3) 3,503.84 63.14 276.43 2,710.42 2,658.22 205.15 -1,662.43 5,993,830.51 1,614,442.25 0.06 601.23 MWD+IFR-AK-CAZ-SC(3) 3,596.00 63.14 276.84 2,752.06 2,699.86 214.65 -1,744.09 5,993,840.28 1,614,360.62 0.40 630.21 MWD+IFR-AK-CAZ-SC(3) 3,687.72 63.12 275.96 2,793.51 2,741.31 223.77 -1,825.40 5,993,849.66 1,614,279.35 0.86 658.72 MWD+IFR-AK-CAZ-SC(3) 3,781.30 63.13 276.22 2,835.82 2,783.62 232.62 -1,908.40 5,993,858.78 1,614,196.39 0.25 687.40 MWD+IFR-AK-CAZ-SC(3) 3,873.74 63.08 276.00 2,877.63 2,825.43 241.40 -1,990.37 5,993,867.83 1,614,114.45 0.22 715.74 MWD+IFR-AK-CAZ-SC(3) 3,965.62 63.10 276.28 2,919.22 2,867.02 250.16 -2,071.84 5,993,876.85 1,614,033.03 0.27 743.95 MWD+IFR-AK-CAZ-SC(3) 4,058.93 63.15 275.93 2,961.40 2,909.20 259.01 -2,154.60 5,993,885.97 1,613,950.31 0.34 772.56 MWD+IFR-AK-CAZ-SC(3) 4,152.89 63.15 276.59 3,003.83 2,951.63 268.15 -2,237.93 5,993,895.38 1,613,867.01 0.63 801.59 MWD+IFR-AK-CAZ-SC(3) 4,247.85 63.10 276.84 3,046.76 2,994.56 278.06 -2,322.05 5,993,905.56 1,613,782.93 0.24 831.55 MWD+IFR-AK-CAZ-SC(3) 4,341.09 63.16 276.40 3,088.90 3,036.70 287.65 -2,404.67 5,993,915.42 1,613,700.35 0.43 860.84 MWD+IFR-AK-CAZ-SC(3) 4,434.57 63.17 276.57 3,131.10 3,078.90 297.07 -2,487.55 5,993,925.11 1,613,617.51 0.16 890.03 MWD+IFR-AK-CAZ-SC(3) 4,526.99 63.12 276.59 3,172.85 3,120.65 306.52 -2,569.46 5,993,934.82 1,613,535.64 0.06 919.02 MWD+IFR-AK-CAZ-SC(3) 4,619.40 63.16 276.70 3,214.60 3,162.40 316.06 -2,651.34 5,993,944.62 1,613,453.80 0.11 948.08 MWD+IFR-AK-CAZ-SC(3) 4,713.18 63.15 276.70 3,256.95 3,204.75 325.82 -2,734.44 5,993,954.66 1,613,370.73 0.01 977.66 MWD+IFR-AK-CAZ-SC(3) 4,805.11 63.19 276.89 3,298.44 3,246.24 335.52 -2,815.90 5,993,964.63 1,613,289.32 0.19 1,006.79 MWD+IFR-AK-CAZ-SC(3) 4,897.05 63.19 276.37 3,339.91 3,287.71 345.00 -2,897.41 5,993,974.36 1,613,207.85 0.50 1,035.70 MWD+IFR-AK-CAZ-SC(3) 2/23/2015 3:28:15PM Page 3 COMPASS 5000.1 Build 65 • • . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 4,989.62 63.10 275.90 3,381.73 3,329.53 353.82 -2,979.52 5,993,983.46 1,613,125.77 0.46 1,064.13 MWD+IFR-AK-CAZ-SC(3) 5,082.59 63.10 275.44 3,423.79 3,371.59 362.02 -3,062.03 5,993,991.92 1,613,043.30 0.44 1,092.03 MWD+IFR-AK-CAZ-SC(3) 5,176.51 63.28 274.34 3,466.15 3,413.95 369.16 -3,145.54 5,993,999.33 1,612,959.82 1.06 1,119.17 MWD+IFR-AK-CAZ-SC(3) 5,269.10 63.17 275.37 3,507.87 3,455.67 376.16 -3,227.91 5,994,006.59 1,612,877.48 1.00 1,145.88 MWD+IFR-AK-CAZ-SC(3) 5,360.86 63.14 275.84 3,549.30 3,497.10 384.15 -3,309.39 5,994,014.85 1,612,796.04 0.46 1,173.35 MWD+IFR-AK-CAZ-SC(3) 5,452.61 63.21 276.35 3,590.71 3,538.51 392.85 -3,390.80 5,994,023.81 1,612,714.66 0.50 1,201.49 MWD+IFR-AK-CAZ-SC(3) 5,546.24 63.13 276.25 3,632.97 3,580.77 402.01 -3,473.85 5,994,033.25 1,612,631.66 0.13 1,230.47 MWD+IFR-AK-CAZ-SC(3) 5,638.25 63.15 275.81 3,674.54 3,622,34 410.64 -3,555.48 5,994,042.14 1,612,550.06 0.43 1,258.59 MWD+IFR-AK-CAZ-SC(3) 5,732.53 63.13 275.45 3,717.13 3,664.93 418.89 -3,639.18 5,994,050.66 1,612,466.40 0.34 1,286.84 MWD+IFR-AK-CAZ-SC(3) 5,824.91 63.21 276.11 3,758.83 3,706.63 427.19 -3,721.20 5,994,059.23 1,612,384.42 0.64 1,314.74 MWD+IFR-AK-CAZ-SC(3) 5,917.99 63.16 276.38 3,800.82 3,748.62 436.23 -3,803.77 5,994,068.53 1,612,301.88 0.26 1,343.48 MWD+IFR-AK-CAZ-SC(3) 6,011.12 63.20 275.66 3,842.84 3,790.64 444.94 -3,886.43 5,994,077.52 1,612,219.26 0.69 1,371.94 MWD+IFR-AK-CAZ-SC(3) 6,102.87 63.17 275.86 3,884.23 3,832.03 453.16 -3,967.90 5,994,086.00 1,612,137.83 0.20 1,399.62 MWD+IFR-AK-CAZ-SC(3) 6,196.11 63.18 276.01 3,926.30 3,874.10 461.76 -4,050.66 5,994,094.87 1,612,055.10 0.14 1,427.99 MW D+I FR-AK-CAZ-SC(3) 6,288.23 63.19 275.90 3,967,86 3,915.66 470.29 -4,132.43 5,994,103.66 1,611,973.37 0.11 1,456.05 MWD+IFR-AK-CAZ-SC(3) 6,380.99 62.68 275.92 4,010.07 3,957.87 478.80 -4,214.59 5,994,112.44 1,611,891.24 0.55 1,484.18 MWD+IFR-AK-CAZ-SC(3) 6,474.69 63.03 276.00 4,052.82 4,000.62 487.46 -4,297.52 5,994,121.36 1,611,808.35 0.38 1,512.64 MWD+IFR-AK-CAZ-SC(3) 6,567.60 63.23 276.67 4,094.81 4,042.61 496.60 -4,379.89 5,994,130.77 1,611,726.02 0.68 1,541.44 MWD+IFR-AK-CAZ-SC(3) 6,663.92 63.03 277.12 4,138.34 4,086.14 506.92 -4,465.19 5,994,141.36 1,611,640.76 0.47 1,572.09 MWD+IFR-AK-CAZ-SC(3) 6,754.32 62.62 277.12 4,179.63 4,127.43 516.88 -4,544.99 5,994,151.59 1,611,561.00 0.45 1,601.06 MWD+IFR-AK-CAZ-SC(3) 6,847.74 62.97 275.24 4,222.34 4,170.14 525.83 -4,627.59 5,994,160.80 1,611,478.44 1.83 1,629.72 MWD+IFR-AK-CAZ-SC(3) 6,941.13 63.15 275.18 4,264.65 4,212.45 533.39 -4,710.50 5,994,168.63 1,611,395.56 0.20 1,657.11 MWD+IFR-AK-CAZ-SC(3) 7,034.03 63.22 274.87 4,306.56 4,254.36 540.65 -4,793.09 5,994,176.16 1,611,313.00 0.31 1,684.14 MWD+IFR-AK-CAZ-SC(3) 7,128.63 63.26 274.48 4,349.16 4,296.96 547.53 -4,877.28 5,994,183.32 1,611,228.85 0.37 1,711.19 MWD+I FR-AK-CAZ-SC(3) 7,220.74 63.23 275.20 4,390.62 4,338.42 554.47 -4,959.23 5,994,190.52 1,611,146.92 0.70 1,737.75 MWD+IFR-AK-CAZ-SC(3) 7,313.28 62.70 276.15 4,432.68 4,380.48 562.62 -5,041.25 5,994,198.94 1,611,064.94 1.08 1,765.50 MWD+IFR-AK-CAZ-SC(3) 7,406.70 62.72 276.46 4,475.52 4,423.32 571.74 -5,123.77 5,994,208.32 1,610,982.45 0.30 1,794.31 MWD+IFR-AK-CAZ-SC(3) 7,500.89 63.20 276.15 4,518.34 4,466.14 580.95 -5,207.16 5,994,217.81 1,610,899.11 0.59 1,823.42 MWD+I FR-AK-CAZ-SC(3) 7,593.47 63.19 276.69 4,560.09 4,507.89 590.19 -5,289.27 5,994,227.31 1,610,817.03 0.52 1,852.25 MWD+I FR-AK-CAZ-SC(3) 7,686.32 63.17 276.89 4,601.98 4,549.78 599.99 -5,371.55 5,994,237.37 1,610,734.79 0.19 1,881.66 MWD+IFR-AK-CAZ-SC(3) 7,778.78 63.22 276.68 4,643.68 4,591.48 609.74 -5,453.50 5,994,247.39 1,610,652.88 0.21 1,910.95 MWD+IFR-AK-CAZ-SC(3) 7,873.14 63.31 278.02 4,686.13 4,633.93 620.52 -5,537.08 5,994,258.44 1,610,569.35 1.27 1,941.63 MWD+IFR-AK-CAZ-SC(3) 7,966.46 63.89 281.27 4,727.63 4,675.43 634.53 -5,619.47 5,994,272.72 1,610,487.02 3.18 1,975.15 MWD+IFR-AK-CAZ-SC(3) 8,061.82 64.50 284.88 4,769.15 4,716.95 653.95 -5,703.07 5,994,292.41 1,610,403.48 3.47 2,014.22 MWD+IFR-AK-CAZ-SC(3) 8,105.54 65.02 286.25 4,787.79 4,735.59 664.56 -5,741.17 5,994,303.14 1,610,365.43 3.07 2,033.74 MWD+IFR-AK-CAZ-SC(3) 8,154.03 65.24 289.46 4,808.19 4,755.99 678.05 -5,783.03 5,994,316.77 1,610,323.61 6.02 2,056.95 MWD+IFR-AK-CAZ-SC(3) 8,198.80 65.64 291.34 4,826.80 4,774.60 692.24 -5,821.20 5,994,331.08 1,610,285.50 3.92 2,079.96 MWD+IFR-AK-CAZ-SC(3) 8,247.08 65.96 293.17 4,846.59 4,794.39 708.92 -5,861.95 5,994,347.89 1,610,244.80 3.52 2,106.00 MWD+IFR-AK-CAZ-SC(3) 8,291.86 66.12 295.12 4,864.78 4,812.58 725.66 -5,899.29 5,994,364.75 1,610,207.52 4.00 2,131.27 MWD+IFR-AK-CAZ-SC(3) 8,339.30 66.44 297.29 4,883.87 4,831.67 744.84 -5,938.25 5,994,384.05 1,610,168.62 4.24 2,159.31 MWD+IFR-AK-CAZ-SC(3) 8,381.72 66.68 299.35 4,900.74 4,848.54 763.30 -5,972.51 5,994,402.62 1,610,134.43 4.49 2,185.51 MWD+IFR-AK-CAZ-SC(3) 8,431.49 67.04 302.36 4,920.30 4,868.10 786.77 -6,011.79 5,994,426.22 1,610,095.23 5.61 2,217.78 MWD+IFR-AK-CAZ-SC(3) 8,477.50 67.33 304.29 4,938.15 4,885.95 810.07 -6,047.23 5,994,449.63 1,610,059.87 3.92 2,248.96 MWD+IFR-AK-CAZ-SC(3) 8,524.46 67.80 306.50 4,956.07 4,903.87 835.21 -6,082.61 5,994,474.88 1,610,024.58 4.46 2,281.92 MWD+IFR-AK-CAZ-SC(3) 2/23/2015 3:28:15PM Page 4 COMPASS 5000.1 Build 65 • • • . ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 8,567.64 68.13 309.07 4,972.27 4,920.07 859.73 -6,114.24 5,994,499.51 1,609,993.03 5.57 2,313.36 MWD+IFR-AK-CAZ-SC(3) 8,617.75 68.63 311.06 4,990.74 4,938.54 889.71 -6,149.89 5,994,529.60 1,609,957.48 3.82 2,351.08 MWD+IFR-AK-CAZ-SC(3) 8,663.03 68.86 313.57 5,007.15 4,954.95 918.12 -6,181.09 5,994,558.11 1,609,926.38 5.19 2,386.19 MWD+IFR-AK-CAZ-SC(3) 8,712.03 69.21 316.59 5,024.69 4,972.49 950.52 -6,213.39 5,994,590.61 1,609,894.18 5.80 2,425.44 MWD+IFR-AK-CAZ-SC(3) 8,760.60 69.62 319.11 5,041.77 4,989.57 984.22 -6,243.90 5,994,624.41 1,609,863.79 4.93 2,465.53 MWD+IFR-AK-CAZ-SC(3) 8,805.29 69.91 320.71 5,057.23 5,005.03 1,016.30 -6,270.90 5,994,656.57 1,609,836.89 3.42 2,503.18 MWD+IFR-AK-CAZ-SC(3) 8,857.17 70.35 323.65 5,074.86 5,022.66 1,054.84 -6,300.81 5,994,695.20 1,609,807.11 5.40 2,547.81 MWD+IFR-AK-CAZ-SC(3) 8,897.07 70.67 325.08 5,088.18 5,035.98 1,085.41 -6,322.73 5,994,725.84 1,609,785.30 3.47 2,582.78 MWD+IFR-AK-CAZ-SC(3) 8,941.51 71.06 327.76 5,102.74 5,050.54 1,120.39 -6,345.95 5,994,760.89 1,609,762.20 5.76 2,622.33 MWD+IFR-AK-CAZ-SC(3) 8,990.73 71.66 329.33 5,118.48 5,066.28 1,160.17 -6,370.28 5,994,800.75 1,609,737.99 3.26 2,666.82 MWD+IFR-AK-CAZ-SC(3) 9,034.13 73.11 331.33 5,131.61 5,079.41 1,196.11 -6,390.75 5,994,836.75 1,609,717.64 5.52 2,706.64 MWD+IFR-AK-CAZ-SC(3) 9,085.39 74.57 333.77 5,145.88 5,093.68 1,239.80 -6,413.44 5,994,880.51 1,609,695.09 5.39 2,754.52 MWD+IFR-AK-CAZ-SC(3) 9,135.39 76.12 335.51 5,158.53 5,106.33 1,283.51 -6,434.16 5,994,924.28 1,609,674.52 4.58 2,801.94 MWD+IFR-AK-CAZSC(3) 9,177.86 77.80 336.97 5,168.11 5,115.91 1,321.37 -6,450.82 5,994,962.19 1,609,657.98 5.18 2,842.72 MWD+IFR-AK-CAZ-SC(3) 9,218.45 79.44 338.93 5,176.12 5,123.92 1,358.25 -6,465.76 5,994,999.12 1,609,643.17 6.22 2,882.12 MWD+IFR-AK-CAZ-SC(3) 9,279.00 81.31 340.38 5,186.25 5,134.05 1,414.22 -6,486.51 5,995,055.15 1,609,622.60 3.88 2,941.44 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 9,299.87 81.95 340.88 5,189.29 5,137.09 1,433.70 -6,493.36 5,995,074.65 1,609,615.82 3.88 2,962.00 MWD+IFR-AK-CAZ-SC(4) 9,340.50 83.41 341.57 5,194.46 5,142.26 1,471.85 -6,506.33 5,995,112.84 1,609,602.97 3.97 3,002.16 MWD+IFR-AK-CAZ-SC(4) 9,434.89 85.17 343.72 5,203.86 5,151.66 1,561.49 -6,534.34 5,995,202.56 1,609,575.26 2.93 3,095.91 MWD+IFR-AK-CAZ-SC(4) 9,530.27 85.18 345.52 5,211.88 5,159.68 1,653.13 -6,559.54 5,995,294.27 1,609,550.35 1.88 3,190.92 MWD+IFR-AK-CAZ-SC(4) 9,579.10 83.88 346.95 5,216.53 5,164.33 1,700.34 -6,571.11 5,995,341.51 1,609,538.94 3.95 3,239.52 MWD+IFR-AK-CAZ-SC(4) 9,624.07 82.94 347.51 5,221.70 5,169.50 1,743.90 -6,580.98 5,995,385.10 1,609,529.21 2.43 3,284.19 MWD+IFR-AK-CAZ-SC(4) 9,719.15 82.83 347.23 5,233.47 5,181.27 1,835.97 -6,601.61 5,995,477.23 1,609,508.88 0.31 3,378.51 MWD+IFR-AK-CAZ-SC(4) 9,814.29 84.72 345.39 5,243.79 5,191.59 1,927.85 -6,624.00 5,995,569.17 1,609,486.80 2.76 3,473.08 MWD+IFR-AK-CAZ-SC(4) 9,844.56 86.26 344.59 5,246.17 5,193.97 1,957.00 -6,631.81 5,995,598.34 1,609,479.08 5.73 3,503.25 MWD+IFR-AK-CAZ-SC(4) 9,908.30 89.62 343.95 5,248.46 5,196.26 2,018.30 -6,649.08 5,995,659.69 1,609,462.01 5.37 3,566.91 MWD+IFR-AK-CAZ-SC(4) 9,955.36 89.48 344.95 5,248.83 5,196.63 2,063.64 -6,661.69 5,995,705.07 1,609,449.55 2.15 3,613.95 MWD+IFR-AK-CAZ-SC(4) 10,004.11 89.28 345.51 5,249.36 5,197.16 2,110.77 -6,674.12 5,995,752.24 1,609,437.27 1.22 3,662.69 MWD+IFR-AK-CAZ-SC(4) 10,098.59 88.56 346.23 5,251.14 5,198.94 2,202.38 -6,697.18 5,995,843.91 1,609,414.51 1.08 3,757.15 MWD+IFR-AK-CAZ-SC(4) 10,192.65 88.15 346.40 5,253.84 5,201.64 2,293.73 -6,719.43 5,995,935.32 1,609,392.57 0.47 3,851.17 MWD+IFR-AK-CAZ-SC(4) 10,287.33 88.49 346.19 5,256.61 5,204.41 2,385.67 -6,741.85 5,996,027.33 1,609,370.45 0.42 3,945.81 MWD+IFR-AK-CAZ-SC(4) 10,382.46 89.07 346.31 5,258.64 5,206.44 2,478.06 -6,764.45 5,996,119.78 1,609,348.15 0.62 4,040.92 MWD+IFR-AK-CAZ-SC(4) 10,476.36 88.97 346.50 5,260.25 5,208.05 2,569.31 -6,786.52 5,996,211.09 1,609,326.38 0.23 4,134.80 MWD+IFR-AK-CAZ-SC(4) 10,570.93 89.26 345.76 5,261.71 5,209.51 2,661.11 -6,809.19 5,996,302.96 1,609,304.01 0.84 4,229.36 MWD+IFR-AK-CAZ-SC(4) 10,665.35 91.18 344.57 5,261.34 5,209.14 2,752.38 -6,833.36 5,996,394.29 1,609,280.14 2.39 4,323.76 MWD+IFR-AK-CAZ-SC(4) 10,760.04 91.03 344.32 5,259.52 5,207.32 2,843.58 -6,858.75 5,996,485.57 1,609,255.05 0.31 4,418.40 MWD+IFR-AK-CAZ-SC(4) 10,853.73 91.16 343.74 5,257.73 5,205.53 2,933.64 -6,884.52 5,996,575.70 1,609,229.57 0.63 4,512.02 MWD+IFR-AK-CAZ-SC(4) 10,949.13 91.10 344.78 5,255.85 5,203.65 3,025.44 -6,910.40 5,996,667.58 1,609,204.00 1.09 4,607.35 MWD+IFR-AK-CAZ-SC(4) 11,043.81 90.34 344.98 5,254.66 5,202.46 3,116.84 -6,935.09 5,996,759.05 1,609,179.60 0.83 4,702.01 MWD+IFR-AK-CAZSC(4) 11,139.21 89.62 346.00 5,254.69 5,202.49 3,209.19 -6,958.99 5,996,851.47 1,609,156.00 1.31 4,797.40 MWD+IFR-AK-CAZ-SC(4) 11,233.00 89.59 341.81 5,255.34 5,203.14 3,299.29 -6,984.99 5,996,941.64 1,609,130.30 4.47 4,891.10 MWD+IFR-AK-CAZ-SC(4) 11,328.09 89.86 337.24 5,255.79 5,203.59 3,388.34 -7,018.24 5,997,030.79 1,609,097.34 4.81 4,985.56 MWD+IFR-AK-CAZ-SC(4) 11,422.11 90.07 334.41 5,255.85 5,203.65 3,474.11 -7,056.74 5,997,116.68 1,609,059.13 3.02 5,078.09 MWD+IFR-AK-CAZ-SC(4) 2/23/2015 3:28:15PM Page 5 COMPASS 5000.1 Build 65 • ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 11,517.85 90.38 336.94 5,255.47 5,203.27 3,561.34 -7,096.17 5,997,204.03 1,609,019.98 2.66 5,172.27 MWD+I FR-AK-CAZ-SC(4) 11,611.51 90.20 342.41 5,255.00 5,202.80 3,649.14 -7,128.69 5,997,291.92 1,608,987.75 5.84 5,265.33 MWD+I FR-AK-CAZ-SC(4) 11,656.78 89.96 345.22 5,254.94 5,202.74 3,692.61 -7,141.31 5,997,335.43 1,608,975.28 6.23 5,310.56 MWD+I FR-AK-CAZ-SC(4) 11,706.56 89.55 348.27 5,255.15 5,202.95 3,741.05 -7,152.72 5,997,383.91 1,608,964.02 6.18 5,360.33 MWD+I F R-AK-CAZ-SC(4) 11,755.76 89.35 349.15 5,255.62 5,203.42 3,789.30 -7,162.36 5,997,432.18 1,608,954.55 1.83 5,409.47 MWD+IFR-AK-CAZ-SC(4) 11,800.54 89.12 349.56 5,256.22 5,204.02 3,833.30 -7,170.63 5,997,476.20 1,608,946.42 1.05 5,454.17 MWD+IF R-AK-CAZ-SC(4) 11,894.31 90.62 348.73 5,256.43 5,204.23 3,925.39 -7,188.29 5,997,568.34 1,608,929.07 1.83 5,547.80 MWD+IFR-AK-CAZ-SC(4) 11,988.63 91.28 351.31 5,254.87 5,202.67 4,018.26 -7,204.63 5,997,661.26 1,608,913.03 2.82 5,641.86 MWD+IFR-AK-CAZ-SC(4) 12,083.85 90.74 350.65 5,253.19 5,200.99 4,112.29 -7,219.55 5,997,755.32 1,608,898.41 0.90 5,736.71 MWD+IFR-AK-CAZ-SC(4) 12,177.85 91.45 348.84 5,251.39 5,199.19 4,204.77 -7,236.28 5,997,847.84 1,608,881.98 2.07 5,830.49 MWD+IFR-AK-CAZ-SC(4) 12,273.41 90.40 348.63 5,249.85 5,197.65 4,298.47 -7,254.95 5,997,941.60 1,608,863.62 1.12 5,925.92 MWD+I F R-AK-CAZ-SC(4) 12,367.16 90.51 348.31 5,249.11 5,196.91 4,390.33 -7,273.69 5,998,033.51 1,608,845.18 0.36 6,019.58 MWD+I F R-AK-CAZ-SC(4) 12,462.56 91.51 347.93 5,247.42 5,195.22 4,483.67 -7,293.32 5,998,126.90 1,608,825.85 1.12 6,114.90 MWD+I F R-AK-CAZ-SC(4) 12,556.79 91.47 348.08 5,244.97 5,192.77 4,575.81 -7,312.90 5,998,219.10 1,608,806.58 0.16 6,209.04 MWD+IFR-AK-CAZ-SC(4) 12,651.72 91.31 346.35 5,242.67 5,190.47 4,668.36 -7,333.90 5,998,311.70 1,608,785.88 1.83 6,303.92 MWD+IFR-AK-CAZ-SC(4) 12,745.30 89.78 342.57 5,241.78 5,189.58 4,758.49 -7,358.97 5,998,401.91 1,608,761.11 4.36 6,397.44 MWD+I F R-AK-CAZ-SC(4) 12,840.31 90.00 342.93 5,241.96 5,189.76 4,849.23 -7,387.14 5,998,492.73 1,608,733.24 0.44 6,492.30 MWD+I FR-AK-CAZ-SC(4) 12,934.51 90.29 346.12 5,241.72 5,189.52 4,940.00 -7,412.27 5,998,583.57 1,608,708.40 3.40 6,586.45 MWD+IFR-AK-CAZ-SC(4) 13,029.20 89.06 347.05 5,242.26 5,190.06 5,032.10 -7,434.24 5,998,675.74 1,608,686.74 1.63 6,681.13 MWD+IFR-AK-CAZ-SC(4) 13,122.94 89.64 346.93 5,243.33 5,191.13 5,123.43 -7,455.34 5,998,767.12 1,608,665.94 0.63 6,774.85 MWD+IFR-AK-CAZ-SC(4) 13,216.61 91.51 348.11 5,242.39 5,190.19 5,214.88 -7,475.58 5,998,858.62 1,608,646.00 2.36 6,868.48 MWD+IFR-AK-CAZ-SC(4) 13,310.98 93.28 348.20 5,238.44 5,186.24 5,307.15 -7,494.93 5,998,950.95 1,608,626.94 1.88 6,962.70 MWD+IFR-AK-CAZ-SC(4) 13,404.46 93.02 346.86 5,233.30 5,181.10 5,398.29 -7,515.09 5,999,042.14 1,608,607.09 1.46 7,056.00 MWD+I FR-AK-CAZ-SC(4) 13,498.15 92.78 345.11 5,228.56 5,176.36 5,489.07 -7,537.75 5,999,132.99 1,608,584.73 1.88 7,149.57 MWD+I FR-AK-CAZ-SC(4) 13,592.77 93.02 345.40 5,223.78 5,171.58 5,580.46 -7,561.80 5,999,224.45 1,608,560.97 0.40 7,244.06 MWD+IFR-AK-CAZ-SC(4) 13,655.00 92.93 345.11 5,220.55 5,168.35 5,640.56 -7,577.62 5,999,284.59 1,608,545.35 0.49 7,306.20 MWD+IFR-AK-CAZ-SC(4) 4 1/2"x 6-1/2" _.w_.. _ ____ _ 13,689.40 92.88 344.95 5,218.80 5,166.60 5,673.75 -7,586.49 5,999,317.80 1,608,536.59 0.49 7,340.55 MWD+IFR AKCAZ-SC(4) 13,768.00 92.88 344.95 5,214.86 5,162.66 5,749.55 -7,606.87 5,999,393.67 1,608,516.45 0.00 7,419.04 PROJECTED to TD 2/23/2015 3:28:15PM Page 6 COMPASS 5000.1 Build 65 RECEIVED • STATE OF ALASKA S MAR 0 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANEVIA CC la.Well Status: Oil O , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: •February 18,2015 214-167/315-046 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 *January 22,2015 50-103-20695-00-00 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2546.5'FNL, 1188'FEL,Sec. 18,T12N, R8E, UM •February 12,2015 V.&0 3S-620 Top of Productive Horizon: 8. KB(ft above MSL): 52'RKB 15.Field/Pool(s): 1290'FNL, 2474'FWL,Sec. 13,T12N, R7E, UM GL(ft above MSL): 24.7'AMSL Kuparuk River Field ' Total Depth: 9.Plug Back Depth(MD+TVD): 2081'FNL, 1289'FWL,Sec. 12,T12N, R7E, UM 13655'MD/5221'TVD Torok Undefined Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-476072 y- 5993869 Zone-4 .13768'MD/5215'TVD ADL 380107,25544,25528 • TPI: x-469653 y- 5995149 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-468484 y- 5999643 Zone-4 nipple @ 504'MD/TVD 4624,2639 18.Directional Survey: Yes ❑ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1582'MD/1560'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, Neutron, Density, sonic not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 29' 106' _ 29' 106' 24" Driven 10.75" 45.5# L-80 29' 3145' 29' 2548' 13.5" 1499 sx CI G,215 sx CI G,106 sx LiteCRETE 7.625" 29.7# L-80 26' 8829' _ 26' 5065' 9.875" 806 sx Class G 7.625" 39# P-110 8829' 9279' 5065' 5186' 9.875" same as above 4.5" 12.6# L-80 9144' 13655' 5161' 5221' 6.5" uncemented liner 24.Open to production or injection? Yes ❑ No If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4.5" 9150' 9093'MD/5148'TVD no perforationsI 9144'MD/5151'TVD 6U. n," 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. `.!'' Was hydraulic fracturing used during completion? Yes El No❑ ...... 11.:__..,' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED none 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on post drilling well work / Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-4rRe1vi 12i_ Q/ 2 I I CONTINUED ON E SRBDMS�C� APR 1 0 1015ubmit original only 29. GEOLOGIC MARKERS(List all formations and marncountered): 30. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom needed,and submit detailed test information per 20 AAC 25.071. K-3 6534' 4080' Base of K-3 6890' 4242' Top of Moraine 9108' 5152' 4,,,t, eLtfrAd40\4.911- Formation at total depth: Moraine 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic,cement detail reports,final directional survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 37:5 Contact: Steve Shultz @ 263-4297 Email: Steve.Shultz(a�contractor.conocophillips.com Printed Na e G.L.Alvord , Title: Alaska Drilling Manager S 7 ` f Signature J C'1�` Phone 265-6120 Date `_) '5 �`5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. 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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • • 3S-620 boy- 2-9 * Name MD (feet) TVD (feet) TVDSS (feet) T-3 617 616 564 K-15 762 761 708 UG_C 1399 1387 1335 PFROST 1582 1557 1505 UG_B 1654 1621 1568 UG_A 1800 1745 1693 NA 1889 1817 1765 NB 1929 1850 1797 NC 1974 1884 1832 NF 2108 1984 1932 W STOP 2122 1994 1942 WS_U 2122 1994 1942 WS_D 2122 1994 1942 WS_C 2196 2047 1994 WS—B 2226 2067 2015 WS_L 2267 2095 2043 -WS A4 2267 2095 2043 WS_A3 2339 2142 2089 WS_A2 2454 2212 2159 WS_A1 2638 2313 2260 WS BASE 2867 2420 2367 CAM PANIAN_SS 3215 2580 2528 C-35 6182 3920 3868 K-3 6534 4080 4027 TOPSET_BASE 6890 4241 4189 TOP_MORAINE 9110 5152 5100 TOP_MEGATURB 9699 5231 5179 BASE_MEGATURB 9782 5240 5188 Moraine 3S-620 Grass Roots rizontal Multi-Stage Frac'd Producer ConoeoPhillS Final Wellbore Schematic FMC 4-'/"tree,top joint is 4-1/2"12.6#IBTM,crossed over(for frac equipment) Al 1,„11 New Existing Conductor: 16"62.6#HW @ 106' Spud Mud 9.6 PPG • 3 W'Camco DB Nipple 3.875" 500'MD 13-1/2"Surface Hole 4%"x 1"KBMG(2,500'TVD) with Dummy Surface Casing: 10-3/4"45.5#L-80 Hydril 563 3,145' MD/2,548'TVD @ 46° 4%"x 1"KBMG(3,400'TVD) with Dummy Campanian Tobi 3;3$:1:,'MD:(2,656•TV' 4%"x1"KBMG(4,100'TVD( with Dummy 9-7/8" Intermediate Hole Tubing: 4-%" 12.6#L-80 IBTM 4%"x 1"KBMG(4,650'TVD) 4-'/2" 12.6#L-80 Hydril 563 (bottom 3000ft) with Dummy SND Top of cement above 6,000'MD 3.6 PPG (a minimum of 5OO'MD above the C-40) (eep up with ")ilution 4 h"x 1"KBMG TVD(5,072'TVD( , .I. with SOV SLB Gauge Carrier(9,027'MD/5129'TVD) 4.5"x 7-5/8",Baker Premier Packer*/-9093'MD/5,147'TVD 4 Y"Cameo DB Nipple 3.812"nogo 7-5/8"x 4-14"Baker Flex Lock Liner hanger ZXP liner top packer liii G '� w/RS Nipple,@ c/-9,145M015,160'TVD' Intermediate Casing Set into the Moraine: 7-5/8"29.7#L-80&bottom 300'TN110SS 39#-all drl 563 cortnecttctns 11 11 pr y o c t Gtltbli Hols Topp.....ne s a1s Mo S zos TVD .::: --9:279 MD J 5 'I$6;TVD A''Jx!' vv II ;re:iitegirli.idiririiiNE! ffLA3HEELD:: .. .: kers'Packers Frac P.Ac ( Plu sffqutpmenll ............. 1111 1111 11111--4 0 0 0 0 pst(8 6�ppgHHrtiiiiictton i ner @ 90 HH mHH4 112:`:12.8#:'€BTMHHHProduction:Hole Q—90° 9 134`Ml /;516Q TVD 13;7.6:8`MD 1.x;218:TSD 13,655''MD J 5,221 TVD. • • " '' ,1.'10',4i1:1;1,41$ ,Ar Cement Detail Report 0 3S-620 ConocoPhillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/6/2015 18:00 2/6/2015 21:00 3S-620 Comment PJSM,batch up CW-100,flood lines w/H2O&test lines 300&4100 psi. Pump 50 bbls CW-100 @ 4 bpm,400 psi.Pump 53 bbls of Mud Push II, 11.5 ppg,4-6 bpm,250-575 psi.Batch cement&drop bottom plug. Pump 181 bbls of Tail Cement, 15.8 ppg,4-6 bpm, 150-300 psi. Drop top plug&pump 10 bbls of H2O. Swap to rig&pump 419 bbls of 9.7 ppg mud,6 bpm, ICP 170 psi, FCP 1000 psi.Pressure up 500 psi over FCP to 1500 psi&hold for 5 min. Bleed off&check floats,good.CIP @ 20:38 hrs.Total losses for cement job 48.45 bbls. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate Casing 6,034.0 9,279.0 Yes Yes Yes Cement Q Pump!nit(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) 3 5 6 1,031.0 1,081.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PJSM,batch up CW-100,flood lines w/H2O&test lines 300&4100 psi.Pump 50 bbls CW-100 @ 4 bpm,400 psi.Pump 53 bbls of Mud Push II, 11.5 ppg,4-6 bpm,250-575 psi. Batch cement&drop bottom plug. Pump 181 bbls of Tail Cement, 15.8 ppg,4-6 bpm, 150-300 psi. Drop top plug&pump 10 bbls of H2O. Swap to rig&pump 419 bbls of 9.7 ppg mud,6 bpm, ICP 170 psi, FCP 1000 psi.Pressure up 500 psi over FCP to 1500 psi&hold for 5 min. Bleed off&check floats,good.CIP @ 20:38 hrs.Total losses for cement job 48.45 bbls. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 6,034.0 9,289.0 806 G 181.0 Yield(fP/sack) Mix H2O Ratio(gal/sa....Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.14 15.80 123.0 8.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Antifoam D047 0.1 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 0.05 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 1.0 gal/sx Additive Type Concentration Conc Unit label CemNET D967 2.0 lbs/bbl Page 1/1 Report Printed: 3/4/2015 ��_. . • ConocoPhiIIips Time Log & Summary We//view Web Reporting Report Well Name: 3S-620 Rig Name: DOYON 141 Job Type: DRILLING ORIGINAL Rig Accept: 1/21/2015 9:00:00 PM Rig Release: 2/19/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/19/2015 24 hr summary Clean drip pans, cellar box, mud pump manifold, &sumps. C/O saver sub to 4%IF. Dress handling equipment for 5"DP. Blow down rig H2O. Remove containment berming around Rock Washer.Various welding in pits&around the rig.Work on MP2's 00:00 03:00 3.00 0 0 MIRU MOVE RURD P PJSM, clean out drip pan, mud pump manifold&cellar box. Prep for welding in pits. 03:00 04:45 1.75 0 0 MIRU MOVE RURD P PJSM, C/O saver sub on TD from XT49 to 4%IF. 04:45 12:00 7.25 0 0 MIRU MOVE RURD P PJSM, pull skate rail,dress Iron Roughneck&mud bucket for 5"DP, service TD, remove containment berm from Rock Washer module. Continue welding in pits. 12:00 00:00 12.00 0 0 MIRU MOVE RURD P PJSM, adjust drag chain,weld trough&shaker frame. Clean out pipe shed sumps,weld peg on rig floor sub rack, C/O liners on pump 2, work on MP2's. 01/20/2015 Work on MP2's. Blow down and disconnect complexes. Pull rig off of 2F-22. Move rig to 3S pad. 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Work on MP2's, remove stairs from sub. Gather up all duck ponds. 03:30 06:30 3.00 0 0 MIRU MOVE RURD P Blow down steam system. Disconnect service lines between complexes. Disconnect air heater form pipe shed 06:30 10:30 4.00 0 0 MIRU MOVE MOB P Move rock washer, pipesheds and complexes to staging point at 2F pad. 10:30 12:00 1.50 0 0 MIRU MOVE MOB P Pull sub off 2F-22. Stage at 2F pad. 12:00 17:00 5.00 0 0 MIRU MOVE MOB P Move boiler, motor, pit, pump complexes and rock washer to 3S pad. Sim-ops: Clean 2F-22 location, install riding cabs on sub and shovel snow at ROC. 17:00 19:15 2.25 0 0 MIRU MOVE MOB P Load up shop and ROC. 19:15 21:30 2.25 0 0 MIRU MOVE MOB P Move shop, pipe sheds, sub and ROC to 2-X access road. 21:30 00:00 2.50 0 0 MIRU MOVE MOB T Wait on disabled Halliburton truck to be moved from roadway. 01/21/2015 Complete moving rig to 3S pad. Rig up on 3S-620.Accept rig @ 21:00 hrs. NU diverter. 00:00 01:00 1.00 0 0 MIRU MOVE MOB T Wait on disabled Halliburton truck to be moved from roadway. Page 1 of 29 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 01:00 07:00 6.00 0 0 MIRU MOVE MOB P Move shop, pipe sheds, sub and ROC from 2-X access road to 3S pad.. 07:00 09:00 2.00 0 0 MIRU MOVE MOB P Stage sub at 3S pad. Set ROC and shop. 09:00 11:00 2.00 0 0 MIRU MOVE MOB P Spot sub over well 3S-620 11:00 12:00 1.00 0 0 MIRU MOVE MOB P Prep location and set mats for service complexes. Set pit complex 12:00 14:00 2.00 0 0 MIRU MOVE MOB P Set pump, motor, and boiler complexes. Set rock washer and pipe sheds. 14:00 21:00 7.00 0 0 MIRU MOVE RURD P Work on rig acceptance checklist. Rig accepted @ 21:00 hrs. 1/21/15 21:00 21:00 0.00 0 0 MIRU MOVE NUND P Nipple up dirverter. Install 4" conductor valves and turnbuckles. Sim-ops:Take on spud mud. Load MWD tools into pipe shed. 31/22/2015 Finish NU of diverter. Load pipe shed w/5"DP. Take on spud mud. Conduct pre-spud meeting Pick up and stand back 38 stds of DP.Function diverter. Load 5" HWDP in pipe shed. Conduct pre-spud meeting. Test diverter and gas alarms.PU 6 stds of HWDP. Make up BHA.#1 Test surface lines. Clean out conductor. DDrlg from 106' MD to 222' MD. POOH. Make up BHA#2. 00:00 02:00 2.00 0 0 MIRU MOVE NUND P Nipple up dirverter. Install 4" conductor valves and turnbuckles. Sim-ops: Take on spud mud. Perform derrick inspection 02:00 04:30 2.50 0 0 MIRU MOVE RURD P Load and strap 5"DP into pipeshed. Install riser and mousehole/ 04:30 05:30 1.00 0 0 MIRU MOVE SFTY P Conduct pre spud meeting. 05:30 11:00 5.50 0 0 MIRU MOVE PULD P Install 5"elevators. PU and stand back in derrick 38 stds of 5"DP. 11:00 12:00 1.00 0 0 MIRU MOVE RURD P Function diverter. Load and strap 5" HWDP in pipeshed. 12:00 12:45 0.75 0 0 MIRU MOVE BHAH P PU NM stab from beaver slide. 12:45 13:45 1.00 0 0 MIRU MOVE SFTY P Conduct pre spud meeting. 13:45 15:15 1.50 0 0 MIRU MOVE BOPE P Perform diverter test, system pressure 2900 psi,after closure 1900 psi, 200 psi recharge time 42 sec, full recharge time 154 sec. 5 nitrogen bottles averaged 2000 psi. Knife vavle open time 4 sec, annular closed time 22 sec.Tested gas&PVT alarms, good. Test witnessed by AOGCC Rep Matt Herrera. 15:15 16:30 1.25 0 0 MIRU MOVE PULD P PU and stand back in derrick 6 stds of 5"HWDP 16:30 17:30 1.00 0 0 MIRU MOVE BHAH P Bring handling tools and BHA equip. to rig floor. 17:30 18:00 0.50 0 0 MIRU MOVE BHAH P PU and stand back in derrick 1 std of 6 5/8"non-mag flex collars 18:00 19:00 1.00 0 0 MIRU MOVE BHAH P Make up clean out BHA#1 as per SLB DD. Page 2 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T - Comment 19:00 20:30 1.50 0 0 MIRU MOVE SEQP P Flood conductor w/mud. Pressure test surface lines to 3500 psi/10 mins.Replace Willis choke and rebuild 2"bleeder valve. 20:30 21:15 0.75 38 106 MIRU MOVE DRLG P Wash and ream conductor f/38'MD t/106'MD.405 gpm,300 psi,40 rpm, 1Ktq,60%FO 21:15 22:15 1.00 106 222 SURFA( DRILL DDRL P DDrlg f/106-t/222'MD,222'TVD. ART= 1.14,AST=O Bit hrs=1.14, . PU 44K, SO 42K, Rot 42K Tq on 1K, Tq off 1K, FO 60%,WOB 2-5K, 40 rpm, 450 gpm, 300 psi. 22:15 22:45 0.50 222 222 SURFA( DRILL CIRC P Circ to clean hole. Obtain PU, SO and Rot wts. Blow down top drive. 22:45 23:00 0.25 222 40 SURFA( DRILL TRIP P POH f/222'MD t/40'MD. 23:00 00:00 1.00 40 0 SURFA( DRILL BHAH P MU BHA#2 as per SLB DD. Orient motor,gyro and MWD as per SLB DD. 01/23/2015 Make up BHA#2. DDrlg to f/222'MD t/470' MD. POOH. Make up BHA#3. RIH and ream through tight hole @ 405'MD. DDrIg f/470'MD t/1260'MD. 1252'TVD 00:00 02:45 2.75 0 193 SURFA( DRILL BHAH P Orient motor to gyro. MU BHA#2 to 193'MD. Check shot surveys @ 176' MD and 140' MD 02:45 06:15 3.50 193 470 SURFA( DRILL DDRL P Make up one std. HWDP DDrlg f/222' MD-t/470'MD,470'TVD.ART=.76 ,AST=1.13 Bit hrs=3.03. Jar hrs=40.84 PU=60K, SO=65K, Rot= 64K Tq on=3K,Tq off= 1K, FO= 80%,WOB=5-10K, 40 rpm,450 gpm, 500 psi. 06:15 07:00 0.75 470 470 SURFA( DRILL SRVY P Gyro survey downlink. Blow down TD 07:00 09:30 2.50 470 0 SURFA( DRILL TRIP P POOH one std. HWDP. Pump OOH two std's HWDP. POOH to surface. Calc disp=9.72 bbls.Act disp=23 bbls. 09:30 10:30 1.00 0 0 SURFA( DRILL BHAH P Clean and inspect bit. Drain motor 10:30 11:00 0.50 0 141 SURFA( DRILL BHAH P Make up BHA#3. Triple combo,arc -adn to 141'MD. 11:00 12:00 1.00 141 141 SURFA( DRILL BHAH P Install nuclear sources in BHA. Rig on hi-line power @11:15 hrs 12:00 12:45 0.75 141 405 SURFA( DRILL BHAH P Continue to MU BHA#3. Tight hole @405'MD. 12:45 13:15 0.50 405 470 SURFA( DRILL REAM P Wash and ream f/405'MD t/470' MD. 450 gpm, 500 psi,40 rpm.TQ=2K. No fill on bottom 13:15 18:00 4.75 470 850 SURFA( DRILL DDRL P Take gyro survey. DDrIg f/470-t/850' MD, 848'TVD.ART=1.27,AST=1.59 Bit hrs=5.89.Jar hrs=43.7 PU= 85K, SO=81K, Rot=85K Tq on =2K, Tq off=2-5K, FO=86%,WOB =5-15K, 60 rpm, 500 gpm,750 psi. Page3of29 Time Logs • 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 850 1,260 SURFA( DRILL DDRL P DDrIg f/850' MD-t/1260'MD, 1252' TVD.ART=1.74,AST=1.51 Bit hrs=9.14.Jar hrs=46.95 PU= 100K, SO=84K, Rot=92K Tq on=5-8K,Tq off=4K, FO=86%,WOB=10-35K, 60 rpm, 550 gpm, 900 psi, Max gas=54 units 01/24/2015 DDrlg f/1260' MD t/1688'MD.Circ&cond mud to deal with lost circulation. DDrIg f/1688'MD t/2065' MD. Circ &cond mud to deal with lost circulation. DDrlg f/2065'MD t/2190'MD. Conduct safety stand down. DDrlg f/2190 MD t/2388'MD. 00:00 05:30 5.50 1,260 1,688 SURFA( DRILL DDRL P DDrlg f/1260' MD-t/1688' MD, 1663'TVD.ART=.67,AST=2.70 Bit hrs= 12.51 .Jar hrs=50.88 PU= 100K, S0=89K, Rot=95K Tq on =6-8K,Tq off=2-5K, ECD=10.77 FO=91%,WOB=30-35K,60 rpm, 530 gpm, 850 psi, Max gas=27 units 05:30 06:00 0.50 1,688 1,688 SURFA( DRILL CIRC T Lost circ encountered. Pick up and monitor well. Fluid observed dropping in annulus. Circ @ 4 bpm. Loss rate @ 180 BPH. Reduce pump rate to 2 bpm. Fluid dropping in annulus. Increase rate to 2.5 bpm while adding LCM. 06:00 06:45 0.75 1,688 1,700 SURFA( DRILL DDRL P DDrlg f/1688-t/1700' MD, Tq on =5-8K,WOB=2-5K, 60 rpm, 105 gpm, 300 psi, Loss rate=84 bph. 06:45 08:45 2.00 1,700 1,700 SURFA( DRILL CIRC T Monitor losses @ 1700'MD. Stage up pumps f/2 bpm t/7 bpm in 1/2 bpm increments.while adding LCM. 375 psi,40 rpm,Tq=3-8K. Loss rate @ 29 bph. Loss rate subsiding. 08:45 12:00 3.25 1,700 1,927 SURFA( DRILL DDRL P DDrlg f/1700' MD-t/1927'MD, 1850'TVD.ART=.1.20,AST= 1.11 Bit hrs= 14.82 . Jar hrs=52.63 PU= 108K, SO=80K, Rot=95K Tq on =5-10K, Tq off=5-8K, ECD=10.65 FO=85%,WOB=15-20K,60 rpm, 550 gpm, 1200 psi, Max gas=77 units. Total losses to well bore for tour=287.5 bbls 12:00 15:15 3.25 1,927 2,065 SURFA( DRILL DDRL P DDrlg f/1927' MD-t/2065'MD, 1952'TVD.ART=..61 ,AST= 1.81 Bit hrs= 17.24. Jar hrs=55.05 PU= 110K, S0=86K, Rot=99K Tq on =7K,Tq off=3-8K, ECD=10.31 FO= 60%,WOB=5-15K,60 rpm, 517 gpm, 1875 psi, Max gas=87 units. Page 4 of 29 Time Logs ID Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:15 1.00 2,065 2,065 SURFA( DRILL CIRC T Lost circ encountered. Pick up and slow rotation to 40 rpm. Erractic tq f/2-12K. Slow pump to 4 bpm. Observe annulus and confirm losses. Slow pump to 2.5 bpm,250 psi. Increase water additions to 80 bph whit adding LCM. Stage pump to 5 bpm,400 psi,40%FO. @ 6 bpm, 450 psi,42%FO, @ 10.5 bpm, 800 psi, 51% FO, 17 bph loss rate 16:15 18:00 1.75 2,065 2,123 SURFA( DRILL DDRL P DDrlg f/2065' MD-t/2123'MD, 1998'TVD.ART=.26,AST=.66 Bit hrs= 18.16.Jar hrs=55.97 PU= 110K, SO=86K, Rot=99K Tq on =7K, Tq off=3-8K, ECD=10.31 FO= 60%,WOB=5-15K, 60 rpm, 517 gpm, 875 psi, Max gas=87 units. 18:00 19:00 1.00 2,123 2,190 SURFA( DRILL DDRL P DDrlg f/2123'MD-t/2190' MD, 2041'TVD.ART=.2 ,AST= .82 Bit hrs= 19.18.Jar hrs=56.99 PU= 110K, SO=86K, Rot=99K Tq on =6.5K, Tq off=4-8K, ECD=10.46, FO=60%,WOB=10K, 60 rpm, 525 gpm, 950 psi, Max gas=74 units. 19:00 19:30 0.50 2,190 2,190 SURFA( DRILL SFTY P Conduct safety stand down due to pit room accident. Discussed house keeping,dropped object policy, hands free policy, right tool for the job, hazard id and job scope changes. 19:30 00:00 4.50 2,190 2,388 SURFA( DRILL DDRL P DDrlg f/2190' MD-t/2388' MD, 2172'TVD.ART=.1.30,AST=.1.80 Bit hrs=22.28.Jar hrs=60.09 PU= 109K, S0=88K, Rot=95K Tq on =7K, Tq off=3-8K, ECD=10.23, FO= 66%,WOB=13-20K,60 rpm, 550 gpm, 1000 psi, Max gas=121 units. Total mud losses to well bore for tour=207 bbls 01/25/2015 DDrlg f/2388'MD t/3155' MD.2552'TVD. CBU x 3. OWFF. BROOH(/3155'MD t/1635'MD. 00:00 06:00 6.00 2,388 2,658 SURFA( DRILL DDRL P DDrIg f/2388' MD-t/2658' MD, 2323'TVD.ART=.1.75,AST=.3.11 Bit hrs=27.14.Jar hrs=64.95 PU= 115K, SO=85K, Rot=95K Tq on =5-12K,Tq off=5-9K, ECD=10.43, FO=65%,WOB=10-28K,60 rpm, 600 gpm, 1400 psi, Max gas=137 units. Page 5 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 2,658 2,936 SURFA( DRILL DDRL P DDrlg f/2658' MD-t/2936' MD, 2450'TVD.ART=.2.53,AST= 1.34 Bit hrs=31.01 . Jar hrs=68.82 PU= 112K, S0=84K, Rot=95K Tq on =8-10K, Tq off=5-8K, ECD=10.40, FO=60%,WOB=20-25K, 80 rpm, 690 gpm, 1800 psi, Max gas=183 units. Total mud losses to well bore for tour=180 bbls Conduct safety stand down due to pit room accident @ 0700 hrs. Discussed house keeping,dropped object policy, hands free policy, right tool for the job, hazard id and job scope changes. 12:00 15:45 3.75 2,936 3,155 SURFA( DRILL DDRL P DDrIg f/2936' MD-t/3155' MD, 2552'TVD.ART=.2.37,AST=.87 Bit hrs=34.25.Jar hrs=72.06 PU= 115K, S0=85K, Rot= 100K Tq on =6-10K,Tq off=7K, ECD=10.96, F0=61%,WOB=10-15K,80 rpm, 700 gpm, 1725 psi, Max gas=105 units. 15:45 16:00 0.25 3,155 3,155 SURFA( CASING PULD P Stand back one std of DP. PU one joint of DP from pipe shed. 16:00 18:15 2.25 3,155 3,155 SURFA( CASING CIRC P CBU x 3. 700 gpm, 1750 psi, 80 rpm,64% FO, 7K tq. __ _ 18:15 18:45 0.50 3,155 3,126 SURFA( CASING OWFF P Monitor well. Static. Lay down one jt. DP. 18:45 00:00 5.25 3,126 1,636 SURFA( CASING BKRM P BROOH f/3126'MD t/1636' MD.600 gpm, 1225 psi, 60 rpm, 7K tq. 55% FO. PU=91K S0=82K Hole unloaded @ 2050'MD& 1950'MD. No losses crossing lost circ zones @ 2065' MD& 1680'MD. Erratic torque and pump pressures observed while back reaming slide intervals. 31/26/2015 Con't to BROOH to HWDP. OWFF. Pump OOH w/HWDP. Lay down BHA. Perform hanger dummy run. Rig up to run casing.Run 10 3/4" L-80 Hyd 563 casing. 00:00 03:00 3.00 1,636 795 SURFA( CASING BKRM P BROOH f/1636' MD t/795' MD. 600 gpm, 1300 psi,60 rpm, 5-15K tq. Hole continuously unloading cuttings. 03:00 03:30 0.50 795 795 SURFA( CASING OWFF P Monitor well. Static. Hold PJSM for removing nuclear sources. 03:30 05:15 1.75 795 240 SURFA( CASING PMPO P Pump out of hole f/795'MD t/240' MD.400 gpm, 550 psi. 05:15 06:15 1.00 240 147 SURFA( CASING BHAH P Lay down BHA. 06:15 07:00 0.75 147 147 SURFA( CASING BHAH P Remove nuclear sources 07:00 09:30 2.50 147 0 SURFA( CASING BHAH P Con't to lay down BHA. Calc disp=39 bbls Act disp=60 bbls 09:30 10:30 1.00 0 0 SURFA( CASING BHAH P Clean rig floor. Guage and grade bit. Remove BHA tools from rig floor Page 6of 29 Time Logs 1111 41110 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:30 11:45 1.25 0 0 SURFA( CASING RURD P Bring Volant CRT to rig floor. Rig up Volant CRT, bail extensions and elevators. 11:45 12:15 0.50 0 0 SURFA( CASING WWWH P Drain and flush stack. 12:15 12:45 0.50 0 0 SURFA( CASING RURD P Perform casing hanger dummy run. 12:45 14:00 1.25 0 0 SURFA( CASING RURD P Rig up to run 10 3/4"casing 14:00 20:30 6.50 0 1,500 SURFA( CASING PUTB P Run 10 3/4" L-80 45.5#Hydril 563 casing to 1500'MD. PU=98K SO=60K 20:30 21:45 1.25 1,500 1,500 SURFA( CASING CIRC P CBU. Stage up pumps f/2 bpm t/5 bpm. ICP= 170 psi, FCP=180 psi. F0=49%@ 5 bpm. No losses while circulating 21:45 00:00 2.25 1,500 2,139 SURFA( CASING PUTB P Run 10 3/4" L-80 45.5#Hydril 563 casing (/1500'MD t/2139 MD. PU=138K SO=70K.Work through tight hole @ 1680'MD.42.81 bbls lost to hole while running casing. 00:00 00:45 0.75 2,139 2,139 SURFA( CASING PUTB P MU hanger and landing jt. 00:45 02:00 1.25 2,139 SURFA( CASING HOSO P Unable to sting Volant CRT into landing jt. Lay down landing jt and caliper upper pup jt. 31/27/2015 Run 10 3/4"L-80 Hyd 563 casing to 3145' MD. Establish circ. Change out pup jt on landing jt. Circ and cond. Cement csg as per program. Rig down casing and cementing equip OWFF. ND diverter. Observe flow from conductor nipple. Install bolts in diverter. Flow diminished to static. 00:00 03:00 3.00 2,139 3,113 SURFA( CASING PUTB P Run 10 3/4" L-80 45.5#Hydril 563 casing f/2139'MD t/3113 MD. PU=175K SO=75K 62 bbls lost to hole while running casing total. 03:00 03:45 0.75 3,113 3,113 SURFA( CASING HOSO P Make up hanger and landing jt. 03:45 05:00 1.25 3,113 3,145 SURFA( CASING HOSO T Unable to stab Volant CRT into landing jt. Lay down landing jt and caliper upper pup jt @ 9.5"id. PU landing jt and land csg.w/elevators. 05:00 10:30 5.50 3,145 3,145 SURFA( CEMEN-CIRC P RU circ. swedge. Circ and cond mud staging rate up f/2 bpm t/6 bpm. ICP =275 psi. FCP=375 psi. Reciprocate pipe PU=160K S0=85K 10:30 12:00 1.50 3,145 3,145 SURFA( CEMEN-RURD T Change out upper pup jt. on landing jt.with a pup that is compatible with the cement plugs. Drift replacement pup jt to 9.875" 12:00 13:30 1.50 3,145 3,145 SURFA( CEMEN-RURD P Rig up cement head and hoses 13:30 16:00 2.50 3,145 3,145 SURFA( CEMEN"CIRC P Circ and cond mud for surface cement job. Page 7 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 20:00 4.00 3,145 3,145 SURFA( CEMEN-CMNT P Perform surface cmt job as per Dowell pumping schedule. Pump 5 bbls water, check pump low trip,test lines to 4000 psi,pump 97 bbls 11 ppg MPII. Drop btm plug. Pump 515 bbls 11 ppg DeepCRETE lead cmt followed by 63 bbls 12 ppg DeepCRETE tail cmt. Lost total returns after 40 bbls tail cmt pumped. Drop top plug. Pump 10 bbls water. Displace with rig pump @ 6 bpm. Slow pump to 3 bpm final 10 bbls. Bump plug w,2815 stks. Pressure up to 1000 psi. Hold for 5 mins. Did not get cement to surface. Check floats. Good. CIP @19:40 hrs. 20:00 21:15 1.25 3,145 0 SURFA( CEMEN'RURD P Rig down and blow down cmt equip and lines. Lay down landing jt. 21:15 22:30 1.25 0 0 SURFA( CEMEN'OWFF P Monitor well. Static. Sim-ops-Cont to clear rig floor of csg and cementing equip. 22:30 00:00 1.50 0 0 SURFA( CEMEN-NUND P Nipple down diverter. Observed mud flow from 4"conductor nipple.Reinstall all bolts back in diverter system and charge up accumulator. Flow diminished to static. Flowed back total 10 bbls. 31/28/2015 OWFF. ND diverter Perform cmt top job. NU well head and BOPE. RU scaffold in cellar. 00:00 03:00 3.00 0 0 SURFA( CEMEN-OWFF T Monitor well. Static. 03:00 07:30 4.50 0 0 SURFA( WHDBO NUND P Nipple down diverter. Sim-ops-Clean pits,grease choke manifold 07:30 08:00 0.50 0 0 SURFA( CEMEN RURD T Prep for top out cement job. Make up 3/4"conduit into 30'sections 08:00 09:00 1.00 0 0 SURFA( CEMEN PULD T Run 3/4"conduit through hanger flutes into conductor x 10 3/4"casing annulus.Tag up at 142' MD 09:00 11:00 2.00 0 0 SURFA( CEMEN RURD T Blow out conduit to confirm it is not plugged. Rig up cementers 11:00 11:30 0.50 0 0 SURFA( CEMEN SFTY T PJSM for top out cement job 11:30 12:00 0.50 0 0 SURFA( CEMEN RURD T Spot trucks and supersucker to the cellar. 12:00 14:15 2.25 0 0 SURFA( CEMEN CMNT T Perform top out cement job. Flush annulus with 10 bbls water, batch up and pump 26 bbls 11 ppg LiteCRETE cement. 16 bbls of cement returns to surface. 14:15 14:45 0.50 0 0 SURFA( CEMEN SFTY P Conduct safety stand down. Discussed hand placement, PREP Alaska and change of scope. 14:45 15:30 0.75 0 0 SURFA( CEMEN'RURD T Rig down cement equipment in cellar. 15:30 17:00 1.50 0 0 SURFA( CEMEN MPDA P Rig up MPD air actuated valve on RCD head. 17:00 18:30 1.50 0 0 SURFA(WHDBO NUND P Spot wellhead equipment in cellar. Page 8 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 23:00 4.50 0 0 SURFA(WHDBO NUND P NU FMC wellhead. Set BOPE on wellhead and torque lock pins per FMC rep. Test to 1000 psi/10 mins. Con't to nipple up BOPE Sim-ops/ Load pipeshed w/5"DP 23:00 00:00 1.00 0 SURFA( WHDBO NUND P RU scaffold in cellar. 01/29/2015 NU BOPE. Rig up scaffold. Conduct safety stand down. Change out RCD clamp and rig up MPD hoses. Set test plugs. Test MPD equip. Pull MPD test plug. Set trip nipple. Rig up to test BOPE.Test BOPE. 00:00 01:45 1.75 0 0 SURFA(WHDBO NUND P PJSM, Cont to nipple up BOPE and R/U BOP scaffolding. 01:45 02:15 0.50 0 0 SURFA(WHDBO SFTY P Conduct safety stand down. Discussed hand placement, PREP Alaska and change of scope. 02:15 07:00 4.75 0 0 SURFA(WHDBO MPDA P PJSM, C/O RCD clamp from hyd. clamp to manual clamp 07:00 09:30 2.50 0 0 SURFA(WHDBO MPDA P PJSM, R/U circulating line to MPD equipment and set testing plugs on RCD. 09:30 10:30 1.00 0 0 SURFA(WHDBO MPDA P Flood MPD equipment and BOP stack, pump though equipment and check for leaks. 10:30 14:15 3.75 0 0 SURFA(WHDBO MPDA P Pressure test MPD equipment as per testing procedure.Test equipment to 250 psi for 5 min and 1800 psi for 10 min. 14:15 15:30 1.25 0 0 SURFA( WHDBO MPDA P Pull MPD test plug. Install 22"trip nipple. 15:30 16:45 1.25 0 0 SURFA( WHDBO RURD P Rig up to test BOPE 16:45 17:30 0.75 0 0 SURFA(WHDBO BOPE P Attempt to test BOPE w/5"test jt. Tubing spool control line ports leaking.Wellhead-BOP flange leaking. 17:30 19:30 2.00 0 0 SURFA( WHDBO BOPE T Wait on FMC wellhead rep. Install plug in termination sleeve. Retourque wellhead-BOP flange connection. 19:30 00:00 4.50 0 0 SURFA( WHDBO BOPE P PJSM, test BOPE w/5"test joint to 250/3500 psi for 5 min each.#1 Top VBR's, CV 1,12,13, 14, &manual kill line valve;#2 upper IBOP, HCR kill, CV's 9,11;#3 lower IBOP, CV's 5,8 & 10;#4 dart valve, CV's 4,6&7;#5 FSV&CV 2;#6 HCR choke, kill line 4"Demco;#7 Manual choke&HCR kill;#8 annular tested to 250/2500 psi for 5 min each;#9 lower VBR's; Accumulator test initial system 3000 psi; after closure 2000 psi; 200 psi attained in 41 seconds;full psi attained in 143 sec. 5 nitrogen bottles averaged 2000 psi.Tested gas alarms, PVT gain/loss trip tank gain/loss and flow show. Tubing spool control line ports leaked. Plug ports. retest good Leak between adapter spool&lower rams.Tighten flange, Retest good. Page9of29 Time Logs Date From To Dur S. DepthE. Depth Phase Code Subcode T Comment 31/30/2015 24 hr Summary Continue BOPE test.Change and test upper pipe rams. Rig down test equip. Set wear bushing. Install Katch Kan containment system. PU and stand back 37 stds DP. MU BHA and single in hole w/DP. 00:00 03:00 3.00 0 0 SURFA( WHDBO BOPE P PJSM, Cont to test BOPE. Re-grease CV#2 and attempt to test floor valve w/top 3-1/2"X 6"VBR close. Observed top rams leaking on low test but held on high. Closed bottom rams and tested floor valve to 250 psi/3500psi. Decision made to C/O top rams. 03:00 03:45 0.75 0 0 SURFA( WHDBO RURD T R/D testing equipment and blow down top drive, choke and kill lines. Drain stack. 03:45 06:30 2.75 0 0 SURFA( WHDBO NUND T PJSM, Change out top rams from 3-1/2"X 6"VBR to 2-7/8"X 5"VBR. 06:30 08:00 1.50 0 0 SURFA( WHDBO BOPE T R/U and test top pipe rams to 250 psi/3500 psi for 5 min each on chart. R/D testing equipment. 08:00 08:30 0.50 0 0 SURFA(WHDBO RURD P Set long slotted wear bushing. 10"ID 08:30 12:00 3.50 0 0 SURFA( CEMEN-MPDA P Rig up and modify new Katch Kan, install mud skirt and drain hoses. Sim-ops-Rig up to pick up and stand _ back 5"DP 12:00 16:30 4.50 0 0 SURFA( CEMEN'PULD P Pick up and stand back 111 jts of 5" DP. Clear rig floor. 16:30 18:15 1.75 0 0 SURFA( CEMEN BHAH P Mobilize BHA tools to rig floor 18:15 21:15 3.00 0 772 SURFA( CEMEN BHAH P MU BHA#4 to 772' MD. 21:15 22:30 1.25 772 1,707 SURFA( CEMEN PULD P PU and single in hole w/5"DP f/772' MD to 1707' MD. 22:30 23:00 0.50 1,707 1,707 SURFA( CEMEN DHEQ P Shallow pulse test MWD.430 gpm, 850 psi, 30 rpm.Tq=3K. F0=51% 23:00 00:00 1.00 1,707 2,739 SURFA( CEMEN PULD P PU and single in hole w/5" DP f/1707' MD to 2739'MD. 01/31/2015 Conduct safety stand down. RIH to 2926'MD. Service rig. CBU. Test casing to 3000 psi. Drill out float track, clean out rat hole. Drill 20' new hole.CBU. Perform LOT 14.7 ppg EMW. Dispace to 9.5 ppg LSND. DDrlg 9 7/8"intermediate hole section to xxxx' MD 00:00 00:30 0.50 2,739 2,739 SURFA( CEMEN"SFTY P Conduct safety stand down with new crew. Discussed hand placement, PREP Alaska and change of scope. Talked about the recent incidents around the field and how we are going to prevent them. 00:30 00:45 0.25 2,739 2,926 SURFA( CEMEN TRIP P PJSM, RIH f/2739'MD to 2926' MD. 00:45 01:15 0.50 2,926 2,926 SURFA( CEMEN SVRG P Service rig. 01:15 01:30 0.25 2,926 2,926 SURFA( CEMEN'SFTY P Hold PJSM on R/U and testing 10-3/4"casing. SIMOPS, fill pipe and circ lines. 01:30 02:00 0.50 2,926 2,926 SURFA( CEMEN CIRC P CBU @ 380 gpm, 1050 psi, 53% flow. 02:00 03:15 1.25 2,926 2,926 SURFA( CEMEN RURD T PJSM,Attempt to test casing, observed leak on mud manifold cement line. Remove leaking section of manifold and re-rig to bypass area. Page 10 of 29 410 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 04:00 0.75 2,926 2,926 SURFA( CEMEN-PRTS P Pressure test 10-3/4"casing to 3000 psi for 30 minutes on chart, good. 04:00 04:15 0.25 2,926 2,926 SURFA( CEMEN'RURD P Rig down testing equipment. 04:15 04:45 0.50 2,926 3,058 SURFA( CEMEN-COCF P RIH f/2926' MD to 3019' MD.Wash and ream f/3019'MD to top of FC @ 3058'MD, pump @ 450 gpm= 1000 psi,40 rpm's,Tq=7K. 04:45 08:45 4.00 3,058 3,155 SURFAt CEMEN-DRLG P Drill out float collar @ 3058' MD, shoe track,float shoe @ 3142' MD and rate hole to 3155'MD, pump @ 500 gpm- 1125 psi,60 rpm's, 64% flow. 08:45 09:00 0.25 3,155 3,175 SURFA( CEMEN-DDRL P Drill 20'of new hole to 3175'MD., TVD=2561',ADT=.25, Bit hrs= .25, Total Jar hrs=.25, P/U= 110K, S/O= 75K, ROT= 100K, Pump @ 630 gpm= 1800 psi w/59%FO, Rot @ 50-70 rpm's w/7-10K Tq on, 5-6K Tq off.WOB=5-25K. 09:00 09:30 0.50 3,175 3,175 SURFAt CEMEN-CIRCP CBU @ 630 gpm=1800 psi. MW= 9.6 ppg in/out. 09:30 09:45 0.25 3,175 3,111 SURFA( CEMEN-TRIP P POOH f/3175' MD to 3111'MD. Blow down top drive. 09:45 10:00 0.25 3,111 3,111 SURFAC CEMEN-SFTY P Hold PJSM on R/U and performing FIT/LOT. 10:00 10:30 0.50 3,111 3,111 SURFA( CEMEN'LOT P Perform LOT to 14.7 ppg EMW. 10:30 10:45 0.25 3,111 3,111 INTRM1 DRILL RURD P R/D testing equipment. 10:45 12:00 1.25 3,111 3,175 INTRM1 DRILL DISP P Displace well to 9.5 ppg LSND mud system, Pump @ 335 gpm=525 psi, 45%flow. Obtain SPR's post displacement. 12:00 12:15 0.25 3,175 3,175 INTRM1 DRILL CIRC P Obtain base line ECD's.@ 650 gpm= 1425 psi. ECD=10.25. @ 700 gpm=1650 psi ECD=10.32 12:15 18:00 5.75 3,175 3,690 INTRM1 DRILL DDRL P DDrlg f/3175'MD-t/3690' MD, 2794'TVD.ADT=.4.32. Bit hrs= 4.57. Jar hrs=4.57 PU= 112K, SO= 78K, Rot=96K Tq on=6-8K,Tq off= 5K, ECD=10.41, FO=63%,WOB =5-11K, 150 rpm, 696 gpm, 1750 psi, Max gas=217 units. Pumped 30 bbls hi-vis sweep @3500'MD w/450%cuttings increase. Page 11 of 29 Time Logs 410 1110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 3,690 4,318 INTRM1 DRILL DDRL P DDrIg f/3690' MD-t/4318' MD, 3078'TVD.ADT=.4.55. Bit hrs= 9.12. Jar hrs=9.12 PU= 122K, S0= 84K, Rot= 100K Tq on=5-12K, Tq off=6K, ECD=10.67, FO=63%, WOB=8-18K, 140 rpm, 699 gpm, 1975 psi, Max gas=233 units. Pumped 30 bbls hi-vis sweeps @3800'MD w/100%cuttings increase and @4100' MD w/320% cuttings increase.. SPR @ 3944'MD,2908'TVD. MW=9.5 20:26 hrs. #1 20 spm=140 psi 30 spm=200 psi #2 20 spm=140 psi 30 spm=200 psi 02/01/2015 Drill 9 7/8"intermediate hole section to—5155'MD. CBU. OWFF. Perform wiper trip to 3111'MD. Change out swivel packing. RIH f/3111'MD t/5064'MD.Wash and ream f/5064'MD t/5155' MD. Drill 9 7/8"intermediate hole section to 5709' MD. 00:00 06:00 6.00 4,318 4,875 INTRMI DRILL DDRL P DDrlg f/4318'MD to 4875' MD 3329'TVD.ADT=4.33. Bit hrs= 13.45.Jar hrs=13.45 PU= 136K, S0=87K, Rot= 106K Tq on=7-9K, Tq off=7-9K, ECD=10.74, FO=63%, WOB=8-12K, 140 rpm,695 gpm, 2100 psi, Max gas=139 units. Cont to pump 30 bbls of HighVis sweep every 300'w/50%to 150%increase @ shakers. 06:00 09:15 3.25 4,875 5,155 INTRMI DRILL DDRL P DDrlg f/4875'MD to 5155'MD 3456'TVD.ADT=2.72. Bit hrs=16.17.Jar hrs=16.17 PU= 138K, SO=88K, Rot= 105K Tq on =7-12K, Tq off=8K, ECD=10.77, FO=63%,WOB=10-16K, 140 rpm, 700 gpm, 2200 psi, Max gas=65 units. 09:15 09:30 0.25 5,155 5,155 INTRM1 DRILL SVRG P Swivel packing leaking, grease up packing and still leaking. Decision made to perform scheduled wiper trip 300'early. 09:30 10:15 0.75 5,155 5,155 INTRM1 DRILL CIRC P Circulate hole clean, pump @ 700 gpm=2275 psi,62%flow,8K Tq. 10:15 10:45 0.50 5,155 5,061 INTRM1 DRILL CIRC P Stand back one stand. Obtain SPR's and blow down top drive. SPR's MD=5155'MD TVD=3454' MW=9.5+ppg 10:30 hours Pump#1, 30 spm=170 psi ,40 spm=220 psi Pump#2, 30 spm=180 psi, 40 spm=240 psi. 10:45 11:00 0.25 5,061 5,061 INTRM1 DRILL OWFF P OWFF, static. Rotate pipe @ 20 rpm's. Page 12 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment I 11:00 12:30 1.50 5,061 3,111 INTRM1 DRILL WPRT P POOH on elevators f/5016' MD to 3111' MD.Actual displacement= 19.7 bbls, Calculated displacement= 16.3 bbls 12:30 12:45 0.25 3,111 3,111 INTRM1 DRILL OWFF P OWFF,static. SIMOPS, hold PJSM for C/O swivel packing. 12:45 16:30 3.75 3,111 3,111 INTRM1 DRILL RGRP T C/O swivel packing and add hyd oil to top drive. 16:30 17:30 1.00 3,111 5,064 INTRM1 DRILL WPRT P RIH on elevators f/3111'MD t/5064' MD. Calc disp=17.14 bbls Act disp=16.03 bbls 17:30 17:45 0.25 5,064 5,155 INTRM1 DRILL REAM P Wash and ream f/5064'MD t/5155' MD. No fill 17:45 18:15 0.50 5,155 5,155 INTRM1 DRILL CIRC P CBU @ 5155'MD.700 gpm, 2500 psi, 120 rpm, 7-9K tq. 18:15 00:00 5.75 5,155 5,709 INTRM1 DRILL DDRL P DDrlg f/5155' MD t/5709' MD 3706' TVD.ADT=4.03. Bit hrs=20.20. Jar hrs=20.20 PU= 136K, SO=95K, Rot= 113K Tq on=10K, Tq off=9K, ECD=10.68, FO=62%,WOB=10K, 140 rpm, 700 gpm,2250 psi, Max gas=150 units.Pump 30 bbl hi-vis sweep @ 5500'MD w/75%increase in cuttings. Momentary packoff event occurred @ 5533'MD. 12.41 ECD spike and SPP spiked to 2800 psi. SPR's MD=5709'MD TVD=3706' MW=9.5+ppg 12:58 hours Pump#1, 30 spm=180 psi ,40 spm=240 psi Pump#2, 30 spm=180 psi, 40 spm=250 psi. 02/02/2015 Drill 9 7/8"intermediate hole section to 6586' MD. Having problems w/rig generators. Circ and weight up mud to 9.7 ppg. OWFF.Attempt to POOH. Swabbing. Pump OOH to 6084' MD.Attempt to POOH. Swabbing. Backream to 5526'MD.Attempt to POOH. Swabbing. Backream to 4786'MD. OWFF. RIH to 6455.Wash and ream to 6586'MD.Drill intermediate hole section to 7105'MD. 00:00 06:00 6.00 5,709 6,333 INTRM1 DRILL DDRL P DDrlg f/5709' MD t/6333' MD 3987' TVD.ADT=4.68. Bit hrs=24.88.Jar hrs=24.88 PU= 147K, SO=97K, Rot= 116K Tq on=13K, Tq off=10K, ECD=10.898, FO=59%,WOB =5-10K, 120 rpm, 700 gpm,2510 psi, Max gas=144 units. Cont to pump HighVis sweeps every —300'-400'sweeps returned—50% increase in cuttings. 06:00 09:15 3.25 6,333 6,586 INTRM1 DRILL DDRL P DDrIg f/6333'MD t/6586' MD 4102' TVD.ADT=2.60. Bit hrs=27.48. Jar hrs=27.48 PU= 150K, SO=97K, Rot= 115K Tq on=14K,Tq off=10K, ECD=10.77, FO=58%,WOB =5-10K, 140 rpm, 645 gpm, 2225 psi, Max gas=850 units. Page 13 of 29 Time Logs 41110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:30 0.25 6,586 6,586 INTRM1 DRILL CIRC T Trouble shoot rig generators. The rig was running on Gen#2 and Gen#3 w/95%load due to water pump issues w/Gen#1. Gen#3 starting over heating, unable to drill ahead on one generator. Decision made to POOH to casing shoe. Contacted HILine to find out when power issues they have been having will be correctred.The decision made to increase MW to 9.7 w/gas observed when drilling into C-40. 09:30 10:45 1.25 6,586 6,586 INTRM1 DRILL CIRC T Circulate and increase MW to 9.7 ppg. Reduce pump rate to 600 gpm w/rotary @ 100 rpm's to reduce load on generators. P/U= 140K, S/0= 105K, ROT= 118. Obtain SPRs MD=6584', TVD= 4101', MW=9.7 ppg, 10:46 hrs MP#1, 30 spm=200 psi.40 spm= 260 psi MP#2,30 spm=200 psi.40 spm= 260 psi 10:45 11:15 0.50 6,586 6,549 INTRM1 DRILL OWFF T Stand back one stand to 6549' MD. OWFF, static ROT @ 20 rpm's 11:15 12:00 0.75 6,549 6,084 INTRMI DRILL PMPO T Pump OOH f/6549' MD t/6084'MD. Calc disp=3.9 bbls Act disp=5.1 bbls 12:00 14:45 2.75 6,084 4,786 INTRM1 DRILL BKRM T POOH f/6084'MD t/5945'MD. Improper hole fill. Decision made to backream.. RIH to 5991'MD. BROOH f/5991'MD t/5526' MD. POOH on elevators to 5341' MD. Improper hole fill. Backream f/5341' MD t/4786'MD. 14:45 15:00 0.25 4,786 4,786 INTRM1 DRILL OWFF T Monitor well. Static 15:00 16:15 1.25 4,786 6,455 INTRM1 DRILL TRIP T RIH f4786'MD t/6455'MD. Calc disp=14.7 bbls Act disp=12.6 bbls 16:15 16:30 0.25 6,455 6,586 INTRM1 DRILL REAM T Wash and ream f/6455' MD t/6586' MD. No fill. 16:30 17:00 0.50 6,586 6,586 INTRM1 DRILL CIRC T CBU. Stage pumps up to 650 gpm. 2500 psi. Erratic torque 5-18K, 59% FO. Max gas @ bottoms up=600 units Page 14 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 00:00 7.00 6,586 7,105 INTRM1 DRILL DDRL P DDrIg f/6586'MD t/7105'MD 4517' TVD.ADT=5.46. Bit hrs=32.94. Jar hrs=32.94 PU= 148K, S0= 105K, Rot= 120K Tq on=9-13K,Tq off=10-12K, ECD=10.80, FO=62%, WOB=5-9K, 140 rpm, 704 gpm, 2675 psi, Max gas=1632 units. SPR's MD=6910'MD TVD=4255' MW=9.7 ppg 21:45 hours Pump#1, 30 spm=220 psi ,40 spm=300 psi Pump#2, 30 spm=220 psi, 40 spm=280 psi. 32/03/2015 DDrill intermediate section to TD, f/7105'-9289'MD, 5188'TVD. Shoot survey at TD&obtain SPR's. Circulate &condition to strip out of hole utilizing MPD. 00:00 06:00 6.00 7,105 7,710 INTRM1 DRILL DDRL P DDrIg f/7105' MD t/7710'MD 4612' TVD.ADT=4.33. Bit hrs=37.27. Jar hrs=37.27 PU= 150K, SO= 110K, Rot= 130K Tq on=10-11K,Tq off=8-10K, ECD=10.71, FO=61%, WOB=8-12K, 140 rpm, 700 gpm, 2590 psi, Max gas=208 units. Fire Drill CRT=134 sec @ 04:00 hrs. 06:00 12:00 6.00 7,710 8,317 INTRMI DRILL DDRL P DDrIg f/7710' MD t/8317' MD 4875' TVD.ADT=4.90. Bit hrs=42.17. Jar hrs=42.17 PU= 162K, SO= 111K, Rot= 131K Tq on=13-14K,Tq off=15-16K, ECD=10.84, FO=62%, WOB=10-15K, 140 rpm, 700 gpm, 2550 psi, Max gas=175 units. SPR's MD=8224' MD TVD=4536' MW=9.7 ppg 10:50 hours Pump#1, 30 spm=280 psi ,40 spm=350 psi Pump#2, 30 spm=270 psi, 40 spm=330 psi. 12:00 18:00 6.00 8,317 8,877 INTRM1 DRILL DDRL P DDrIg f/8317' MD t/8877' MD 5081' TVD.ADT=4.28. Bit hrs=46.45.Jar hrs=46.45 PU= 170K, S0= 109K, Rot= 140K Tq on=14-16K,Tq off=15K, ECD=10.79, FO=61%, WOB=13K, 140 rpm, 700 gpm, 2650 psi, Max gas=244 units. 18:00 23:00 5.00 8,877 9,289 INTRMI DRILL DDRL P DDrIg f/8877' MD t/9289' MD 5188' TVD.ADT=3.53. Bit hrs=49.98.Jar hrs=49.98 PU= 172K, SO= 109K, Rot= 139K Tq on=12-20K,Tq off=14-16K, ECD=10.87, FO=61%, WOB=10-15K, 140 rpm, 700 gpm, 2650 psi, Max gas=1050 units. Page 15 of 29 'I Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 23:00 23:15 0.25 9,289 9,289 INTRM1 CASING'SRVY P Shoot surveys at TD. SPR's MD=9289' MD TVD=5188' MW=9.7 ppg 23:15 hours Pump#1, 30 spm=280 psi ,40 spm=360 psi Pump#2, 30 spm=290 psi, 40 spm=350 psi. 23:15 00:00 0.75 9,289 9,289 INTRM1 CASING CIRC P Circulate&condition @ 700 gpm, 2625 psi, 140 rpm,Tq 8-20K, FO 61%, pump 32 bbls Hi-vis sweep. 32/04/2015 CBU 6x racking back a stand each BU. OWFF&install RCD. Strip out of the hole as per schedule.OWFF. Remove RCD&install trip nipple. L/D BHA per SLB DD. Flush stack. C/O upper rams to 7 5/8". Remove wear bushing. 00:00 04:00 4.00 9,289 8,971 INTRM1 CASING CIRC P PJSM, continue to CBU's @ 700 gpm, 2680 psi, 140 rpm,Tq 14-20K, FO 60%, racking back stand on BU 9289-8971'MD. 04:00 04:45 0.75 8,971 8,971 INTRM1 CASING OWFF P Monitor well, static. Sim-op PJSM for installing RCD. 04:45 06:30 1.75 8,971 8,971 INTRM1 CASING MPDA P PJSM, clean out around trip nipple, pull trip nipple, install RCD, &check lines. Kept pipe rotating 20 rpm throughout job when possible. 06:30 11:15 4.75 8,971 3,111 INTRM1 CASING TRIP P PJSM, POOH f/8971'-3111'MD, holding 220-150 back psi as per schedule. Calculated fill 50.7, actual 66.22 bbls. 11:15 11:45 0.50 3,111 3,111 INTRM1 CASING OWFF P Monitor well at the shoe. Shut in MPD chokes, static. Open choke monitor 15 min, static. Kick w/Tripping CRT=69 sec @ 11:20 hrs. 11:45 13:15 1.50 3,111 1,614 INTRM1 CASING TRIP P PJSM, POOH f/3111'-1614'MD, holding 150-30 back psi as per schedule. Calculated fill 21.04, actual 22.07 bbls. 13:15 13:45 0.50 1,614 1,614 INTRMI CASING SVRG P PJSM, service rig, grease TD&DW. 13:45 14:30 0.75 1,614 780 INTRM1 CASING TRIP P PJSM, continue POOH f/1614'-780' MD, holding 30 psi. 14:30 14:45 0.25 780 780 INTRM1 CASING OWFF P Monitor well through MPD return line, static. 14:45 16:30 1.75 780 780 INTRMI CASING MPDA P PJSM, flush&blow down MPD equipment. Remove return line from flow line. C/O RCD for trip nipple& install splash curtain. 16:30 17:15 0.75 780 310 INTRM1 CASING TRIP P PJSM, continue to POOH 780'-310' MD. Spill Drill CRT=200 sec @ 17:00 hrs. 17:15 19:30 2.25 310 0 INTRM1 CASING BHAH P PJSM, lay down BHA 4 as per SLB DD. 19:30 20:45 1.25 0 0 INTRM1 CASING RURD P PJSM, clear&clean rig floor. 20:45 21:45 1.00 0 0 INTRM1 CASING WWWH P PJSM,flush stack, blow down TD& kill line. Drain stack. 21:45 23:15 1.50 0 0 INTRMI CASING BOPE P CIO upper VBR's to 7 5/8"solid body rams Page 16 of 29 Time Logs S • Date From To Dur S. Depth E. Depth Phase Code Subcode ' T Comment 23:15 00:00 0.75 0 0 INTRM1 CASING BOPE P PJSM, pull wear ring rinse hanger profile. 02/05/2015 Perform dummy run with intermediate casing hanger.Test 7 5/8"rams&bag. Rig up casing handling equipment. Run 7 5/8"intermediate casing as per detail to 7558'MD. 00:00 00:30 0.50 0 0 INTRM1 CASING SVRG P PJSM, service rig. 00:30 00:45 0.25 0 0 INTRM1 CASING RURD P PJSM, P/U 7-5/8"landing joint and hanger, perform dummy run. Mark KB on landing joint. 00:45 01:15 0.50 0 0 INTRM1 CASING BOPE P PJSM, R/U to test w/7-5/8"test joint. 01:15 02:00 0.75 0 0 INTRM1 CASING BOPE P PJSM,test top 7-5/8"rams and Annular to 250/3500 psi for 5 min each on chart. 02:00 02:15 0.25 0 0 INTRM1 CASING BOPE P R/D testing equipment. 02:15 04:30 2.25 0 0 INTRM1 CASING RURD P PJSM, mobilize casing equipment to rig floor. R/U Volant tool, slips and elevators. 04:30 11:15 6.75 0 3,129 INTRMI CASING PUTB P PJSM, RIH w/7.625",29.7#, L-80, Hyd 563 casing from surface to 3129' MD. Calculated displacement 33.84, actual 29.4 bbls. 11:15 12:00 0.75 3,129 3,129 INTRM1 CASING CIRC P CBU staging up 1-6 bpm,200 psi, FO 43%, PU 98K, SO 85K. Spill Drill CRT=148 sec @ 11:20 hrs. 12:00 13:15 1.25 3,129 3,808 INTRM1 CASING PUTB P PJSM, RIH w/7.625", 29.7#, L-80, Hyd 563 casing from 3129'-3808' String started taking up to 40K weight. Decision made to CBU. 13:15 14:15 1.00 3,808 3,808 INTRM1 CASING CIRC P CBU staging up 2-6 bpm,6 bpm= 250 psi, FO 48%. 14:15 17:15 3.00 3,808 5,328 INTRM1 CASING PUTB P PJSM, RIH w/7.625",29.7#, L-80, Hyd 563 casing from 3808'-5328', SO 92K. String drag trended up with less displacement. Decision made to CBU. 17:15 18:45 1.50 5,328 5,328 INTRMI CASING CIRC P CBU staging up 2-6 bpm,6 bpm= 350 psi, FO 45%. 18:45 23:30 4.75 5,328 7,558 INTRM1 CASING PUTB P PJSM, RIH w/7.625",29.7#, L-80, Hyd 563 casing from 5328'-7558', SO 100K. Calculated displacement 81.97,actual 62.65. 23:30 00:00 0.50 7,558 7,558 INTRM1 CASING CIRC P CBU staging up 2-3 bpm, 500 psi, FO 33%, PU 160K, SO 100K. 32/06/2015 Continue running 7 5/8"intermediate casing as per detail to 9279'MD. Make up hanger&landing joint. C&C mud system for cement job. Cement as per plan, CIP @ 20:38 hrs. Install pack off. 00:00 01:15 1.25 7,558 7,558 INTRM1 CASING CIRC P PJSM, Cont to CBU. Stage pumps up f/2 bpm to 6 bpm,410 psi,44% flow. S/0= 110K, P/U=190K 01:15 02:30 1.25 7,558 8,019 INTRM1 CASING PUTB P PJSM, continue RIH w/7-5/8"casing f/7558' MD to 8019'MD, MW going in increased to 10.2 ppg.decision made to circulate and condition MW in to 9.7 ppg. Page 17 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:45 1.25 8,019 8,019 INTRM1 CASING CIRC P CBU,stage pump up f/2 bpm to 6 bpm,410 psi,44%flow. Reduce MW in f/10.2+ppg to 9.7 ppg. Fire Drill CRT= 148 sec @ 02:45 hrs. 03:45 06:15 2.50 8,019 8,738 INTRM1 CASING PUTB P PJSM, continue RIH w/7-5/8"casing f/8019' MD to 8738' MD,Work through tight spot©8530' MD. Observed no returns, made several attempts to establish circualtion. Decision made to POOH til circulation could be established. 06:15 07:45 1.50 8,738 8,530 INTRM1 CASING PULL T PJSM, POOH f/8738'to 8530'MD, attempt to circulate @ 1 bpm, 600 psi,slight to no returns. Establish returns©8530' MD. Calculated fill 2.29, actual 7.5 bbls. 07:45 08:45 1.00 8,530 8,530 INTRM1 CASING CIRC T PJSM, stage pumps up f/1.5-4 bpm, 500-510 psi, 20%-40%flow. S/O= 115K, P/U=190K. 08:45 09:45 1.00 8,530 8,738 INTRM1 CASING PUTB T PJSM, pump down casing f/8530' MD to 8738' MD, 3.5 bpm, 510 psi, FO 40%. 09:45 11:45 2.00 8,738 9,249 INTRM1 CASING PUTB P PJSM, pump down casing f/8738' MD to 9249' MD, 3.5 bpm, 510 psi, FO 40%. PU 210K, SO 110K, calculated displacement 7.9, actual 3.1 bbls. 11:45 12:30 0.75 9,249 9,279 INTRM1 CASING HOSO P PJSM, pick up&make up hanger with landing joint. Land hanger @ 9279'MD. 12:30 14:00 1.50 9,279 9,279 INTRM1 CEMEN-CIRC P PJSM circulate staging up pumps 3.5-6 bpm,400 psi, FO 38-40%, MW 9.8 ppg, PU 200K, SO 110K. 14:00 14:45 0.75 9,279 9,279 INTRM1 CEMEN RURD P PJSM, rig down Volant CRT&rig up cement head. Blow down TD. 14:45 17:00 2.25 9,279 9,279 INTRM1 CEMEN CIRC P Circulate&condition @ 3.5-6 bpm, 510 psi, FO 42%, 17:00 21:00 4.00 9,279 9,279 INTRM1 CEMEN CMNT P PJSM, batch up CW-100,flood lines w/H2O&test lines 300&4100 psi. Pump 50 bbls CW-100 @ 4 bpm, 400 psi. Pump 53 bbls of Mud Push II, 11.5 ppg,4-6 bpm, 250-575 psi. Batch cement&drop bottom plug. Pump 181 bbls of Tail Cement, 15.8 ppg,4-6 bpm, 150-300 psi. Drop top plug&pump 10 bbls of H2O. Swap to rig&pump 419 bbls of 9.7 ppg mud, 6 bpm, ICP 170 psi, FCP 1000 psi. Pressure up 500 psi over FCP to 1500 psi&hold for 5 min. Bleed off& check floats, good. CIP @ 20:38 hrs. Total losses for cement job 48.45 bbls. 21:00 22:15 1.25 9,279 9,279 INTRM1 CEMEN-RURD P PJSM, blow down lines&clear rig floor. 22:15 22:45 0.50 9,279 9,279 INTRM1 CEMEN RURD P PJSM,drain stack, lay down landing joint, &clean stack. Page 18 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 9,279 0 INTRM1 CEMEN-WWSP P PJSM, make up running tool, prep& set 10 3/4"X 7 5/8"pack off, & RILD's as per FMC rep. 02/07/2015 Test 10 3/4"X 7 5/8"pack off. Lay down 5"DP. Flush&freeze protect OA. C/0 upper rams to VBR's. C/0 TD&handling equipment for 4"XT39. Pick up 4"DP 00:00 00:30 0.50 0 0 INTRM1 CEMEN-PRTS P PJSM,Test 7-5/8"X 10-3/4"packoff to 250/3500 psi for 10 minutes. 00:30 01:00 0.50 0 0 INTRMI CEMEN-SFTY P Conduct safety stand down with new crew. Discussed hand placement, PREP Alaska and change of scope. Talked about the recent incidents around the field and how we are going to prevent them. 01:00 01:45 0.75 0 0 INTRM1 CEMEN-RURD P PJSM, P/U mouse hole and R/U to lay down 5"drill pipe. 01:45 03:00 1.25 0 0 INTRM1 CEMEN-PULD P PJSM, L/D 16 stands of 5"DP from derrick. 03:00 03:30 0.50 0 0 INTRM1 CEMEN-SVRG P PJSM, service rig. 03:30 05:00 1.50 0 0 INTRM1 CEMEN-PULD P PJSM, L/D 18 stands of 5"DP from derrick. 05:00 05:45 0.75 0 0 INTRM1 CEMEN-FRZP P PJSM, rig up lines to flush&freeze protect OA. 05:45 07:15 1.50 0 0 INTRM1 CEMEN-FRZP P PJSM, flush&freeze protect 10 3/4" X 7 5/8", OA. Pump 140 bbls of fresh H2O @ 3bpm, ICP 1125 psi, FCP 1100 psi. Pump 100 bbls of deisel/isotherm @ 1-2.5 bpm, 1000-1900 psi. Shut in pressure 1100 psi. Spill Drill CRT=180 sec @ 06:00 hrs. 07:15 13:45 6.50 0 0 INTRM1 CEMEN-PULD P PJSM, L/D 64 stands of 5" DP from derrick. OA=700 psi @ 12:00 hrs. 13:45 14:45 1.00 0 0 INTRM1 CEMEN-SLPC P PJSM, slip&cut 84'drilling line. 14:45 15:15 0.50 0 0 INTRM1 CEMEN-SVRG P PJSM, service Top Drive. 15:15 16:00 0.75 0 0 INTRM1 CEMEN-RURD P PJSM, clear&clean rig floor. 16:00 17:30 1.50 0 0 INTRM1 CEMEN-BOPE P PJSM, C/O upper rams to 3.5"X 6" VBR's. Sim-ops C/0 saver sub to4" XT39. 17:30 19:00 1.50 0 0 INTRM1 CEMEN-RURDP PJSM, finish dressing TD for 4"DP& change out handling equipment for 4" DP. 19:00 00:00 5.00 0 0 INTRM1 CEMEN-PULD P PJSM, P/U 4"DP&rack back 55 stands in derrick. 0/A pressure 505 psi @ 24:00 hrs. 32/08/2015 Rig up&test BOPE w/4"&4 1/2"test joints. Test MPD choke equipment. Install wear bushing. P/U BHA 5 &single in the hole to 6260' MD. Sonic log f/5418'-6260' MD. 00:00 01:45 1.75 0 0 INTRMI WHDBO RURD P Rig up to test BOPE. Page 19 of 29 Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 01:45 07:30 5.75 0 0 INTRM1 WHDBO BOPE P PJSM,test BOPE w/4"&4.5"test joints to 250/3500 psi for 5 min each. #1 Top VBR's, CV 1,12,13, 14, & manual kill line valve;#2 upper IBOP, HCR kill, CV's 9,11;#3 lower IBOP, CVs 5,8& 10;#4 dart valve, CV's 4,6&7;#5 FSV&CV 2;#6 HCR choke, kill line 4" Demco;#7 Manual choke&HCR kill;#8 annular;#9 lower VBR's;#10 blind rams, CV 3:Lower IBOP failed, C/O&tested good. CV#3 failed,greased& functioned, retested good. Accumulator test initial system 3000 psi; after closure 1900 psi;200 psi attained in 44 seconds; full psi attained in 163 sec.5 nitrogen bottles averaged 2000 psi.;when bleeding off pressure electric pump kicked in at 2900 psi. Tested gas alarms, PVT gain/loss trip tank gain/loss and flow show. Test witness waived by AOGCC rep Jeff Jones on 2-7-15 @14:33 hrs. Accumulator Drill @ 04:30 hrs. 07:30 08:00 0.50 0 0 INTRM1 WHDBO RURD P PJSM, rig down test equipment& blow down lines. 08:00 10:00 2.00 0 0 INTRM1 CEMEN-MPDA P PJSM,test MPD chokes 250/800 psi, 10 min each. Sim-ops C/O lower IBOP. 10:00 10:45 0.75 0 0 INTRM1 WHDBO BOPE P PJSM,test new lower IBOP, 250/3500 psi 5 min each. 10:45 11:00 0.25 0 0 INTRM1 WHDBO RURD P PJSM, rig down remaining test equipment&blow down TD. 11:00 11:30 0.50 0 0 INTRM1 CEMEN'BHAH P PJSM, mobilize BHA 5 to rig floor. 11:30 11:45 0.25 0 0 INTRM1 CEMEN RURD P PJSM, install 9"wear bushing. 11:45 12:00 0.25 0 0 INTRM1 CEMEN"RURD P PJSM, Clear&clean rig floor. OA pressure 350 psi @ 12:00 hrs. 12:00 15:30 3.50 0 528 INTRMI CEMEN-BHAH P PJSM, pick up BHA 5 as per SLB DD. 15:30 15:45 0.25 528 528 INTRM1 CEMEN-SFTY P AAR on picking up BHA&PJSM for singling in the hole w/4" DP. 15:45 17:00 1.25 528 1,530 INTRM1 CEMEN'PULD P Single in the hole f/528'-1530' MD. 17:00 17:45 0.75 1,530 1,530 INTRM1 CEMEN-DHEQ P PJSM, shallow hole test MWD,220 gpm, 1200 psi, 30 rpm,Tq 2K. 17:45 20:15 2.50 1,530 4,720 INTRM1 CEMEN"PULD P PJSM, continue singling in the hole f/ 1530'-4720' MD,fill pipe every 20 stands. 20:15 21:00 0.75 4,720 4,720 INTRM1 CEMEN-SVRG P PJSM,service rig&fill pipe. 21:00 21:45 0.75 4,720 5,418 INTRM1 CEMEN-PULD P PJSM,continue singling in the hole f/ 4720'-5418'MD. 21:45 22:00 0.25 5,418 5,513 INTRMI CEMEN'DLOG P Single in the hole logging w/sonic tool f/5418'-5513'MD,900 fph. Page 20 of 29 Time Logs S S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 5,513 5,540 INTRM1 CEMEN-DLOG P Circulate to down link for tool set up. Logging 5513'-5540'MD, 220 gpm, 1500 psi, FO 41%, 900 fph. 22:30 00:00 1.50 5,540 6,260 INTRM1 CEMEN'DLOG P PJSM, continue singling in the hole logging w/sonic tool f/5540'-6260' MD, 900 fph, no pumps. OA pressure 400 psi @ 24:00 hrs. 02/09/2015 Continue singling in the hole sonic logging. Test 7 5/8"intermediate casing to 3500 psi. Drill out shoe track& 20'of formation. Perform LOT to 13.5 ppg EMW. Install RCD. Displace well to 9.5 ppg Kla-Shield mud. Drill ahead as per plan. 00:00 06:15 6.25 6,260 9,041 INTRM1 CEMEN'DLOG P PJSM, continue singling in the hole logging w/sonic tool f/6260'-9041' MD, 900 fph, PU 150K, SO 56K, calculated displacement 16.2, actual 8.75 bbls,fill every 20 stands. Kick w/Tripping Drill CRT= 165 sec. 06:15 07:30 1.25 9,041 9,041 INTRM1 CEMEN CIRC P CBU @ 230 gpm,2000 psi, FO 41%. 07:30 08:00 0.50 9,041 9,041 INTRM1 CEMEN RURD P PJSM, rig up to test 7.625"casing. 08:00 08:45 0.75 9,041 9,041 INTRM1 CEMEN PRTS P PJSM,test 7.625"casing to 3500 psi for 30 min. 08:45 09:15 0.50 9,041 9,041 INTRM1 CEMEN RURD P PJSM, rig down&blow down test equipment. 09:15 09:30 0.25 9,041 9,041 INTRM1 CEMEN PULD P PJSM, pick up&rack back 1 stand of 4"DP. 09:30 10:15 0.75 9,041 9,189 INTRM1 CEMEN COCF P PJSM,wash&ream f/9041'-9189' MD, 180 gpm, 1200 psi, FO 38%,40 rpm, Tq 12K, cement stringers 9149' MD. SPR's @ 9044'MD, 5134'TVD, MW 9.7+ppg, 09:30 hrs. #1 @ 20=520 @ 30=750 psi #2 @ 20=500 @ 30=770 psi 10:15 12:30 2.25 9,189 9,289 INTRM1 CEMEN-DRLG P PJSM, drill out float equipment, shoe track,&rat hole f/9189'-9289'MD, 180 gpm, 1200 psi, FO 38%,40-60 rpm,Tq 10-14K. 12:30 13:00 0.50 9,289 9,309 INTRM1 CEMEN"DDRL P PJSM, DDrill f/9289'-9309'MD, 5192' TVD, PU 120K, SO 95K, ROT 98K, Tq on 12K,off 9K, ECD 10.96, FO 51%,WOB 8-12K, 80 rpm,235 gpm, 2250 psi, max gas 26. 13:00 14:00 1.00 9,309 9,309 INTRM1 CEMEN-CIRC P Circulate&condition @ 235 gpm, 2250 psi,40 rpm, Tq 7-8K. 14:00 14:15 0.25 9,309 9,261 INTRM1 CEMEN LOT P Stand back one stand&rig up for LOT. 14:15 15:00 0.75 9,261 9,261 INTRM1 CEMEN LOT P PJSM, perform LOT to a EMW 13.5 ppg,shoe 9279' MD, 5187'TVD,TD 9309'MD, 5192'TVD, MW 9.7 ppg. Rig down test equipment. 15:00 16:45 1.75 9,261 9,261 PROD1 DRILL MPDA P PJSM, remove trip nipple&install RCD. Page 21 of 29 Time Logs 11 S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:30 1.75 9,261 9,309 PROD1 DRILL DISP P Displace mud system, pump 30 bbl spacer, 420 bbls of 9.5 ppg KlaSheild system,225 gpm, 2120 psi,40 rpm, Tq 9-10K. SPR's @ 9261'MD, 5183'TVD, MW 9.5+ppg, 18:30 hrs. #1 @ 20=480 @ 30=780 psi #2 @ 20=460 @ 30=785 psi 18:30 19:15 0.75 9,309 9,309 PROD1 DRILL OWFF P Monitor well, slight flow. 19:15 20:00 0.75 9,309 9,309 PROD1 DRILL CIRC P CBU 240 gpm, 2100 psi,40 rpm, 9-10k. 20:00 20:45 0.75 9,309 9,309 PROD1 DRILL MPDA T Choke B plugging up. Swap to choke A&attempt to clear choke B. Not able to clear choke B. Decision made to drill ahead. 20:45 21:15 0.50 9,309 9,309 PROD1 DRILL OWFF P Monitor well, static. 21:15 00:00 2.75 9,309 9,436 PROD1 DRILL DDRL P PJSM, DDrill f/9309'-9436' MD, 5205' TVD,ADT 2.36, Bit 2.36,Jars 2.36, PU 120K, SO 95K, ROT 98K, Tq on 11K, off 9K, ECD 10.63, FO 38%, WOB 10-15K, 80 rpm,230 gpm, 2100 psi, max gas 788. OA pressure 550 psi. 32/10/2015 Directional drill production section as per plan f/9436'- 11114' MD. 00:00 06:00 6.00 9,436 9,815 PROD1 DRILL DDRL P PJSM, DDrill f/9436'-9815'MD, 5243' TVD,ADT 5.04, Bit 7.9,Jars 7.9, PU 145K, SO 70K, ROT 105K, Tq on 11K, off 7-8K, ECD 10.78, FO 33%, WOB 10-12K, 120 rpm,230 gpm, 2150 psi, max gas 4316. 06:00 12:00 6.00 9,815 10,230 PROD1 DRILL DDRL P PJSM, DDrill f/9815'-10230'MD, 5254'TVD,ADT 4.48, Bit 12.38, Jars 12.38, PU 145K, SO 66K, ROT 104K,Tq on 11K, off 10K, ECD 10.91, FO 31%,WOB 12-14K, 120 rpm,230 gpm,2175 psi, max gas 6286. SPR's @ 10178'MD, 5251'TVD, MW 9.5 ppg, 11:10 hrs. #1 @ 20=550 @ 30=820 psi #2 @ 20=580 @ 30=860 psi Kick w/Drilling CRT=98 sec @ 05:40 hrs. OA pressure 750 psi @ 12:00 hrs. 12:00 18:00 6.00 10,230 10,669 PROD1 DRILL DDRL P PJSM, DDrill f/10230'-10669'MD, 5262'TVD,ADT 5.07, Bit 17.45, Jars 17.45, PU 144K, SO 64K, ROT 99K, Tq on 11K, off 8K, ECD 10.99, FO 27%,WOB 9-12K, 120 rpm,230 gpm, 2275 psi, max gas 2489. SPR's @ 10665'MD, 5262'TVD, MW 9.5 ppg, 18:00 hrs. #1 @ 20=620 @ 30=925 psi #2 @ 20=645 @ 30=960 psi Page 22 of 29 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 10,669 11,114 PROD1 DRILL DDRL P PJSM, DDrill f/ 10669'-11114'MD, 5253'TVD,ADT 4.97, Bit 22.42, Jars 22.42, PU 143K, SO 64K, ROT 97K, Tq on 11.5K, off 8-9K, ECD 11.04, FO 31%,WOB 9-12K, 120 rpm, 230 gpm, 2300 psi, max gas 2750 SPR's @ 11114'MD, 5252'TVD, MW 9.5+ppg, 23:50 hrs. #1 ©20=665 @ 30=1020 psi #2 @ 20=620 @ 30=945 psi. Held table top well kill&rig evacuation with Pusher&crew @ 18:30 hrs. OA pressure 800 psi @ 24:00 hrs. 02/11/2015 Directional drill production section as per plan f/11114'- 12825' MD. 00:00 06:00 6.00 11,114 11,598 PROD1 DRILL DDRL P PJSM, DDrill f/11114'-11598'MD, 5255'TVD,ADT 5.05, Bit 27.47,Jars 27.47, PU 150K, SO 64K, ROT 100K,Tq on 11K, off 7-8K, ECD 11.22, FO 32%,WOB 8-10K, 120 rpm, 250 gpm, 2650 psi, max gas 3633 06:00 12:00 6.00 11,598 12,024 PROD1 DRILL DDRL P PJSM, DDrill f/11598'-12024'MD, 5254'TVD,ADT 4.58, Bit 32.05,Jars 32.05, PU 152K, SO 66K, ROT 100K,Tq on 11-12K, off 8-9K, ECD 11.21, FO 36%,WOB 8-10K, 120 rpm, 232 gpm, 2480 psi, max gas 3633 SPR's @ 11780' MD,5256'TVD, MW 9.6 ppg, 08:30 hrs. #1 @ 20=670 @ 30=940 psi #2 @ 20=660 @ 30=950 psi. OA pressure 800 psi @ 12:00 hrs. 12:00 18:00 6.00 12,024 12,445 PROD1 DRILL DDRL P PJSM, DDrill f/12024'-12445' MD, 5248'TVD,ADT 5.12, Bit 37.17,Jars 37.17, PU 151K, SO 66K, ROT 97K, Tq on 11-12K, off 9K, ECD 11.33, FO 29%,WOB 11-12K, 120 rpm, 240 gpm, 2660 psi, max gas 1425 SPR's @ 12066'MD, 5254'TVD, MW 9.6 ppg, 12:30 hrs. #1 @ 20=645 @ 30=1000 psi #2 @ 20=660 @ 30=940 psi. 18:00 00:00 6.00 12,445 12,825 PROD1 DRILL DDRL P PJSM, DDrill f/12445'-12825'MD, 5238'TVD,ADT 4.17, Bit 41.88,Jars 41.88, PU 146K, SO 64K, ROT 94K, Tq on 12K,off 8.5K, ECD 11.45, FO 30%,WOB 8-12K, 120 rpm, 240 gpm, 2650 psi, max gas 2187 SPR's @ 12540' MD, 5247'TVD, MW 9.6 ppg, 19:30 hrs. #1 @ 20=680 @ 30=1025 psi #2 @ 20=665 @ 30=1020 psi. OA pressure 840 psi @ 24:00 hrs. Page 23 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T_ Comment 02/12/2015 24 hr Summary Directional drill production section as per plan to TD @ 13768'MD. CBU 2-3X&OWFF. BROOH 13768'-12450'MD. 00:00 06:30 6.50 12,825 13,295 PROD1 DRILL DDRL P PJSM, DDrill f/12825'-13295'MD, 5244'TVD,ADT 4.55, Bit 46.43, Jars 46.43, PU 160K, SO 56K, ROT 98K, Tq on 12K, off 11K, ECD 11.25, FO 29%,WOB 9-11K, 120 rpm,240 gpm, 2750 psi, max gas 2603 SPR's @ 13014'MD, 5242'TVD, MW 9.6+ppg, 02:30 hrs. #1 @ 20=700 @ 30=1010 psi #2 @ 20=670 @ 30=1030 psi. 06:30 07:00 0.50 13,295 13,203 PROD1 DRILL PMPO T PJSM, pump out of hole f/ 13295-13203'MD,2 bpm, 750 psi, PU 160k. RCD element started leaking, rack back one stand to CIO RCD bearing. 07:00 07:30 0.50 13,203 13,203 PROD1 DRILL OWFF T Monitor well, static. PJSM t o change out RCD. 07:30 09:00 1.50 13,203 13,138 PROD1 DRILL MPDA T Change out RCD as per MPD advisor. 09:00 09:15 0.25 13,138 13,295 PROD1 DRILL REAM T PJSM,wash&ream f/13138'-13295' MD,235 gpm, 2690 psi,40 rpm,Tq 9K, FO 45% 09:15 12:00 2.75 13,295 13,485 PROD1 DRILL DDRL P PJSM, DDrill f/13295-13485'MD, 5228'TVD,ADT 1.28, Bit 49.12,Jars 49.12, PU 160K, SO 56K, ROT 98K, Tq on 13K,off 9.5K, ECD 11.6, FO 29%,WOB 11-12K, 120 rpm, 240 gpm,2760 psi, max gas 2825 OA pressure 750 psi @ 12:00 hrs. 12:00 16:00 4.00 13,485 13,768 PROD1 DRILL DDRL P PJSM, DDrill f/13485'-13768'MD, • 5218'TVD,ADT 3.45, Bit 52.57, Jars 52.57, PU 154K, SO 62K, ROT 94K, Tq on 11K, off 8K, ECD 11.6, FO 35%,WOB 9-12K, 120 rpm, 240 gpm, 2750 psi, max gas 2601 TD @ 13768'MD • 16:00 20:00 4.00 13,768 13,768 PROD1 CASING CIRC P Pump 30 bbls high vis sweep, CBU 3X @ 240 gpm, 2750 psi, ROT 95K, 120 rpm, Tq 8K SPR's @ 13765'MD,5215'TVD, MW 9.6+ppg,20:00 hrs. #1 @ 20=625 @ 30=960 psi #2 @ 20=600 @ 30=940 psi. 20:00 21:00 1.00 13,768 13,768 PROD1 CASING OWFF P Monitor well, slight flow to static for 30 min. 21:00 00:00 3.00 13,768 12,450 PROD1 CASING BKRM P PJSM, BROOH f/13765'-12450' MD, 240 gpm, 2750 psi, 120 rpm, Tq 9k, 700 fph. OA pressure 700 psi @ 24:00 hrs. X2/13/2015 BROOH to the shoe 12450'-9279' MD.CBU 7X. Strip out of hole with MPD f/9279'-6155' MD. Remove RCD& install trip nipple. POOH 6155-4523'MD. Page 24 of 29 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 07:30 7.50 12,450 9,233 PROD1 CASING BKRM P PJSM, BROOH f/12450'-9233'MD, 240 gpm, 2550 psi, FO 40%, 120 rpm, Tq 5-6K, 700-1200 fph, calculated fill 20.52, actual 24.53 bbls. 07:30 07:45 0.25 9,233 9,233 PROD1 CASING OWFF P Monitor well, static. 07:45 12:45 5.00 9,233 9,233 PROD1 CASING CIRC P PJSM, pump 26 bbl Hi-vis sweep, CBU 2X, pump 27 bbls Hi-vis nut plug sweep, CBU 6X, 220 gpm,2150 psi, FO 43%, 100 rpm, Tq 5K, PU 125K, SO 85K, ROT 103K. Rotate BHA @ shoe 10 rpm=Tq 4K. OA pressure 700 psi @ 12:00 hrs. 12:45 13:30 0.75 9,233 9,233 PROD1 CASING OWFF P Monitor well, 30 min. static. Drop 2.25"drift in drill pipe. 13:30 14:30 1.00 9,233 9,140 PROD1 CASING TRIP T PJSM, TOH f/9233'-9140' MD,w/ MPD, holding 250 psi while pulling& 30 psi in slips.Floats in string not holding.Attempt to clear floats by pumping down string. 14:30 17:30 3.00 9,140 7,285 PROD1 CASING PMPO P PJSM, pump out of hole f/ 9140'-7285' MD, 3 bpm, 650 psi. 17:30 18:45 1.25 7,285 6,155 PROD1 CASING TRIP P PJSM, line up on MPD system& POOH f/7285'-6155' MD, holding 240 psi while pulling, 30 psi in slips. Experience electrical problems that might be related to MPD system. 18:45 21:15 2.50 6,155 6,155 PROD1 CASING MPDA P PJSM, shut down, blow down, remove RCD, &install trip nipple. 21:15 22:30 1.25 6,155 5,295 PROD1 CASING TRIP P PJSM, TOH f/6155'-5295' MD. Kick w/Tripping Drill CRT 131 sec @ 22:15 hrs. 22:30 23:15 0.75 5,295 5,295 PROD1 CASING SVRG P PJSM, service TD&rig. Sim-ops change out upper air boot. 23:15 00:00 0.75 5,295 4,523 PROD1 CASING TRIP P PJSM, TOH f/5295'-4523' MD, 1000-1500 fph, PU 85K, SO 70K, calculated fill 24.3, actual 31.66 bbls. OA pressure 260 psi @ 24:00 hrs. 02/14/2015 TOH f/4523'-528'MD. Lay down BHA 5 per SLB DD. Rig up to run liner. Make up&run 4.5"liner as per detail to 4493'. Pick up liner hanger&run liner on DP to 5561'. Make up TD to each stand as mud was running over the top. Inadvertently put left hand turns in string,while backing out of a stand.TOH 5561'-4493 to inspect liner hanger emergency shear screws. Shear screws check out ok. 00:00 04:00 4.00 4,523 528 PROD1 CASING TRIP P PJSM, POOH f/4523'-528' MD. 04:00 04:30 0.50 528 528 PROD1 CASING OWFF P Monitor well,static. 04:30 05:00 0.50 528 246 PROD1 CASING TRIP P PJSM, rack back HWDP&jars. 05:00 08:00 3.00 246 0 PROD1 CASING BHAH P PJSM, lay down BHA 5 as per SLB DD. 08:00 08:45 0.75 0 0 PROD1 CASING BHAH P PJSM clear&clean rig floor of BHA 5. 08:45 09:15 0.50 0 0 COMPZ CASING RURD P PJSM, pull wear bushing. 09:15 09:45 0.50 0 0 COMPZ CASING WWWH P PJSM, pick up single&wash stack @ 400 gpm, 10 rpm. Page 25 of 29 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 10:15 0.50 0 0 COMPZ CASING RURD P PJSM, install 9"ID wear bushing. 10:15 12:00 1.75 0 0 COMPZ CASING RURD P PJSM, mobilize casing handling equipment to the rig floor. Rig up to run 4.5"liner. OA pressure 240 psi @ 12:00 hrs. 12:00 20:00 8.00 0 4,451 COMPZ CASING PUTB P PJSM, Run 4.5", 12.6#, L-80, IBTM liner f/surface to 4493'. Run 1 orange peel jt, 1 perf pup, 8 swell packers, 7 frac port seats, 110 jts 4.5"liner. 20:00 20:30 0.50 4,451 4,493 COMPZ CASING OTHR P PJSM, pick up liner/hanger. Mix& pour Pal-mix, let set 30 min. 20:30 21:45 1.25 4,493 5,561 COMPZ CASING RUNL P PJSM, TIH f/4493'-5561' MD, PU 68K, SO 60K, calculated displacement 28.41, actual 20.31 bbls. Top drive was made up to each stand as mud was running over the top. 21:45 23:00 1.25 5,561 4,493 COMPZ CASING TRIP T PJSM,TOH f/5561'-4493'MD, calculated fill 5.94, actual 6.65 bbls. While backing out of a stand the Driller inadvertently turned the string 4-5 to the left. Decision was made to pull back to the liner hanger& inspect the shear screws for the emergency release. 23:00 00:00 1.00 4,493 4,493 COMPZ CASING OTHR T PJSM, break connection on tie back sleeve&inspect shear screws. Shear screws check out ok. OA pressure 200 psi @ 24:00 hrs. 02/15/2015 TIH w/4.5"liner on DP to set depth 13655'MD, liner top 9144' MD. Circulate DP volume&OWFF. Set hanger&test. Displace to 9.7 ppg kill weight brine. TOH racking back 7 stands of 4"DP 9046'-8390'MD. 00:00 01:00 1.00 4,493 4,493 COMPZ CASING OTHR T PJSM, make up tie back sleeve,fill with Baker gel. 01:00 02:45 1.75 4,493 5,561 COMPZ CASING RUNL T PJSM, TIH f/4493'-5561' MD, PU 68K, SO 60K.Top drive was made up to each stand as mud was running over the top. 02:45 05:45 3.00 5,561 7,928 COMPZ CASING RUNL P PJSM, TIH f/5561'-7928' MD. Top drive was made up to each stand as mud was running over the top. 05:45 06:15 0.50 7,928 7,928 COMPZ CASING OWFF P Flow check well after incorrect displacement. Observe slight flow to static, monitor static for 15 min. 06:15 06:30 0.25 7,928 8,117 COMPZ CASING RUNL P PJSM,TIH f/7928'-8117'MD, PU 105K, SO 82K. Top drive was made up to each stand as mud was running over the top. 06:30 07:45 1.25 8,117 8,117 COMPZ CASING CIRC P CBU @ 4.5 bpm, 780 psi, MW 9.7 ppg, no gain or losses. 07:45 08:45 1.00 8,117 9,253 COMPZ CASING RUNL P PJSM, TIH f/8117'-9253' MD, PU 108K, SO 83K.Top drive was made up to each stand as mud was running over the top. 08:45 09:45 1.00 9,253 9,253 COMPZ CASING CIRC P PJSM, circulate liner& DP volume at the shoe,4 bpm, 750 psi, PU 108K, SO 83K, ROT 95K, 10 rpm,Tq 5K. Page 26 of 29 Time Logs. • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 15:30 5.75 9,253 13,068 COMPZ CASING RUNL P PJSM, TIH f/9253'-13068'MD. Top drive was made up to each stand as mud was running over the top. OA pressure 250 psi @ 12:00 hrs. 15:30 16:30 1.00 13,068 13,668 COMPZ CASING RUNL P PJSM,wash down f/13068'-13668' MD, 1 bpm, 600 psi, 15 rpm,Tq 5K, PU 135K, SO 62K, ROT 75K, calculated displacement 47.2, actual 50.5 bbls. 16:30 18:00 1.50 13,668 13,655 COMPZ CASING CIRC P Circulate liner volume 3 bpm, 930 psi, PU 135K, SO 65K, ROT 80K. Position liner on depth @ 13655' MD, 18:00 18:45 0.75 13,655 13,655 COMPZ CASING OWFF P Monitor well, static 30 min. Blow down TD. 18:45 19:45 1.00 13,655 9,144 COMPZ CASING PACK P PJSM, drop 1.75"ball&pump down @ 3 bpm, 920 psi. Ball seated 754 stks. Pressure up 1450 psi&hold for 2 min. Pressure up to 3500 psi holding for 3 min, slack off 50K, setting liner hanger. Bleed off pressure&pick up to release tool from hanger. Set ZXP packer picking up to clear dog sub. Rotate 15 rpm& set down 45K to observe packer set. TOL 9144'MD. 19:45 20:15 0.50 9,144 9,144 COMPZ CASING PRTS P PJSM, pressure test 7 5/8"X 4 1/2" liner top packer.Test to 1500 psi for 10 min, good test. 20:15 20:30 0.25 9,144 9,046 COMPZ WELLPF TRIP P Rack back 1 stand&lay down 1 joint of DP,f/9144'-9046' MD. 20:30 23:00 2.50 9,046 9,046 COMPZ WELLPF DISP P PJSM, displace well to kill weight 9.7 ppg,filtered brine @ 5-6 bpm, 700 psi, pump 712 bbls of brine w/712 bbls of mud returns. 23:00 23:30 0.50 9,046 9,046 COMPZ WELLPF OWFF P Monitor well, static. 23:30 00:00 0.50 9,046 8,390 COMPZ WELLPF TRIP P PJSM, TOH f/9046'-8390' MD, racking stands in derrick. OA pressure 350 psi @ 24:00 hrs. 32/16/2015 TOH racking back 37 more stands,then lay down remaining 4"DP&HRD-E tool. Slip&cut drill line. Flush& blow down MPD lines&choke skid. Rig up&run 4.5"upper completion to 4281'MD. 00:00 01:30 1.50 8,390 6,435 COMPZ WELLPF TRIP P PJSM,TOH f/8390'-6435' MD, racking stands in derrick. 01:30 07:30 6.00 6,435 48 COMPZ WELLPF PULD P PJSM,TOH f/6435'-48'MD, calculated fill 48.6, actual 59.9 bbls, laying down drill pipe to shed. 07:30 08:00 0.50 48 0 COMPZ WELLPF BHAH P PJSM, lay down HRD-E running tool as per Baker Rep. 08:00 08:30 0.50 0 0 COMPZ WELLPF RURD P PJSM, remove wear bushing. 08:30 10:00 1.50 0 0 COMPZ WELLPF SLPC P PJSM, slip&cut 70'of drilling line. 10:00 10:30 0.50 0 0 COMPZ WELLPF SVRG P PJSM, service Top Drive. 10:30 11:00 0.50 0 0 COMPZ WELLPF MPDA X PJSM, rig up lines&MPD test head with shooting flange. Page 27 of 29 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 COMPZ WELLPF MPDA X PJSM, remove trip nipple. Install test head with shooting flange. OA pressure 350 psi @ 12:00 hrs. 12:00 13:00 1.00 0 0 COMPZ WELLPF MPDA P PJSM, rig up&flush choke skid with associated lines. Table Top Man Down Drill held @ 12:45 hrs. 13:00 13:45 0.75 0 0 COMPZ WELLPF MPDA X PJSM, remove test head with shooting flange. Install trip nipple. 13:45 16:30 2.75 0 0 COMPZ RPCOM RURD P PJSM, rig up to run upper _completion. 16:30 00:00 7.50 0 4,281 COMPZ RPCOM PUTB P PJSM, run 4.5", 12.6#, L-80, Hydril 563&IBTM tubing from surface to 4281'MD. Run mule shoe, shear pin sub, no go, DB nipple, packer, gauge carrier, DB nipple, SOV, 3 GLM dummy's,XO, 90 jts of Hyd 563, & 10 jts of IBTM tubing. Calculated displacement 18, actual 16.8 bbls. IA pressure 350 psi.@ 24:00 hrs. 02/17/2015 Finish running 4,5"upper completion&space out. Spot corrosion inhibited brine. Land hanger&RILDS. Drop ball&rod to set packer.Test tubing&IA. Shear SOV. Set TWC. Test TWC and hanger from below to 2750 psi. Flush BOPE. Monitor well. Change out kelly hose. 00:00 11:00 11.00 4,281 9,122 COMPZ RPCOM PUTB P PJSM-PU 4 1/2"upper completion f/4281'MD t/9122' MD. Check I-wire every 1000'. PU=110K SO=68K. Calc disp=23.7 bbls Act disp=20.8 bbls 11:00 12:30 1.50 9,122 9,126 COMPZ RPCOM HOSO P Space out 3.92'off of no-go as per Baker rep. 12:30 13:45 1.25 9,126 9,126 COMPZ RPCOM THGR P Make up hanger.Terminate I-wire at hanger as per Schlumberger 13:45 14:00 0.25 9,126 9,126 COMPZ RPCOM RURD P PJSM-Rig up to spot corrosion inhibitor. 14:00 15:15 1.25 9,126 9,126 COMPZ RPCOM CRIH P Pump 18 bbls 9.7 ppg inhibited brine down tbg. followed by 134 bbls 9.7 ppg brine. 15:15 16:45 1.50 9,126 9,150 COMPZ RPCOM HOSO P PJSM-Remove landing jt. Drop ball and rod. Make up landing jt. Land hanger. RILD as per FMC rep. 16:45 18:30 1.75 9,150 9,150 COMPZ RPCOM PACK P PJSM-Pressure up on tbg.to 4000 psi. Chart for 30 mins. Packer set @ 2800 psi. Bleed tbg pressure to 2000 psi.Test annulus to 3500 psi. Chart for 30 mins. 18:30 19:15 0.75 9,150 9,150 COMPZ RPCOM OTHR P PJSM-Bleed tbg pressure to 0 psi to shear SOV. SOV failed to shear. Repeat two more times. SOV failed to shear. Bleed off annulus pressure. Re-rig hoses to pressure up annulus and take tbg returns directly to pits. Pressure up on annulus. SOV sheared @ 3800 psi. 19:15 19:45 0.50 9,150 0 COMPZ RPCOM RURD P PJSM-Rig down lines. Lay down landing jt. Set two way check. 19:45 20:30 0.75 0 0 COMPZ RPCOM PRTS P PJSM-RU and test two way check to 2750 psi. Chart for 15 mins Page 28 of 29 Time Logs III IP Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 20:30 21:15 0.75 0 0 COMPZ1 RPCOM OTHR P PJSM-Rig up and flush BOPE. Rig down lines. 21:15 21:45 0.50 0 0 COMPZ RPCOM OWFF P Monitor well. Static. 21:45 22:00 0.25 0 0 COMPZ RIGMNT SF-FY P PJSM-Develop Hazard Recognition Worksheet for changing out kelly hose. 22:00 00:00 2.00 0 0 COMPZ RIGMNT RGRP P Remove kelly hose. OA=100 psi 02/18/2015 Finish changing out kelly hose. Rig down MPD. ND BOPE. NU tree.Terminate I-wire at wellhead. Freeze protect well. Set BPV. Secure tree. 00:00 04:30 4.50 0 0 COMPZ WHDBO RGRP T PJSM-Install new kelly hose. 04:30 09:00 4.50 0 0 COMPZ WHDBO MPDA P PJSM-Rig down MPD/RCD equip. Sim-ops-Clean mud pits 09:00 10:30 1.50 0 0 COMPZ WHDBO OTHR P Rig down scaffold in cellar. Rig up bridge cranes to ND BOPE. Sim-ops-Clean mud pits 10:30 11:30 1.00 0 0 COMPZ WHDBO NUND P ND BOPE 11:30 13:30 2.00 0 0 COMPZ WHDBO NUND P Prep tree. NU adapter flange 13:30 13:45 0.25 0 0 COMPZ WHDBO NUND P Orient and install tree. Orientation confirmed by drillsite operator. 13:45 15:15 1.50 0 0 COMPZ WHDBO NUND P Terminate I-wire at wellhead. 15:15 15:45 0.50 0 0 COMPZ WHDBO NUND P Make up and torque tree studs. 15:45 17:00 1.25 0 0 COMPZ WHDBO PRTS P Test hanger seals to 5000 psi f/10 min. Test tree to 250/5000 psi f/10 min. Tests witnessed by Co-man. 17:00 17:15 0.25 0 0 COMPZ WHDBO MPSP P PJSM-Pull two way check. 17:15 18:30 1.25 0 0 COMPZ WHDBO FRZP P PJSM-RU and test lines to 1500 psi. Pump 93 bbls diesel freeze protect down IA @ 2 bpm taking returns up tbg to pits.. ICP= 1000 psi, FCP=1300 psi. Sim-ops-Lay down drill pipe in mouse hole. 18:30 22:30 4.00 0 0 COMPZ WHDBO FRZP P Allow freeze protect diesel to u-tube from IA to tbg. Sim-ops-Lay down DP 22:30 23:30 1.00 0 0 COMPZ WHDBO MPSP P PJSM-Set BPV and test to 1000 psi/5 min.Test witnessed by Co-man 23:30 00:00 0.50 0 0 DEMOB MOVE RURD P Rig down lines. Secure tree. Release rig @ 00:00 hrs 2/19/15 Page 29 of 29 • NADConversion Kuparuk River Unit Kuparuk 3S Pad 3S-620 Definitive Survey Report NAD 27 24 February, 2015 III • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 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 Zone: Alaska Zone 04 Using geodetic scale factor Well 3S-620 Well Position +N/-S 0.00 usft Northing: 5,993,869.45 usft Latitude: 70°23'39.768 N +E/-W 0.00 usft Easting: 476,071.76 usft Longitude: 150°11'40.873 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 24.70 usft Wellbore 3S-620 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 1/19/2015 18.85 80.92 57,568 Design 3S-620 Audit Notes: Version: 1.0 Phase: ACTUAL lie On Depth: 27.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 27.50 0.00 0.00 346.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 96.63 1,122.70 3S-620 Srvy#1-GYD-GC-SS(3S-620) GYD-GC-SS Gyrodata gyro single shots 1/26/2015 12:41 1,269.47 3,070.24 3S-620 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 11:28: 3,157.32 9,218.45 3S-620 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 1:36: 9,299.87 13,689.40 3S-620 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/23/2015 3:04: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.50 0.00 0.00 27.50 -24.70 0.00 0.00 5,993,869.45 476,071.76 0.00 0.00 UNDEFINED 96.63 0.25 278.61 96.63 44.43 0.02 -0.15 5,993,869.47 476,071.61 0.36 0.06 GYD-GC-SS(1) 132.87 0.59 278.90 132.87 80.67 0.06 -0.41 5,993,869.51 476,071.35 0.94 0.16 GYD-GC-SS(1) 173.73 0.52 261.74 173.73 121.53 0.07 -0.80 5,993,869.52 476,070.96 0.44 0.26 GYD-GC-SS(1) 237.33 1.46 129.65 237.32 185.12 -0.49 -0.46 5,993,868.96 476,071.29 2.91 -0.36 GYD-GC-SS(1) 273.07 2.72 119.48 273.04 220,84 -1.20 0.62 5,993,868.25 476,072.38 3.66 -1.31 GYD-GC-SS(1) 331.59 3.54 131.52 331.47 279.27 -3.08 3.19 5,993,866.36 476,074.94 1.79 -3.76 GYD-GC-SS(1) 424.89 2.57 149.17 424.64 372.44 -6.78 6.41 5,993,862.65 476,078.15 1.44 -8.13 GYD-GC-SS(1) 473.46 2.24 185.60 473.17 420.97 -8.66 6.88 5,993,860.76 476,078.61 3.16 -10.07 GYD-GC-SS(1) 562.26 3.95 237.74 561.85 509.65 -12.02 4.12 5,993,857.41 476,075.84 3.52 -12.66 GYD-GC-SS(1) 654.20 6.15 265.52 653.44 601.24 -14.10 -3.47 5,993,855.36 476,068.25 3.51 -12.84 GYD-GC-SS(1) 2/24/2015 8:27:36AM Page 2 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 747.03 6.37 283.12 745.73 693.53 -13.32 -13.44 5,993,856.17 476,058.28 2.07 -9.67 GYD-GC-SS(1) 840.56 7.42 283.52 838.58 786.38 -10.73 -24.36 5,993,858.80 476,047.36 1.12 -4.52 GYD-GC-SS(1) 934.26 7.18 284.69 931.52 879.32 -7.83 -35.91 5,993,861.73 476,035.83 0.30 1.09 GYD-GC-SS(1) 1,027.29 7.79 283.39 1,023.76 971.56 -4.90 -47.67 5,993,864.71 476,024.08 0.68 6.78 GY0-GC-SS(1) 1,122.70 9.18 286.46 1,118.12 1,065.92 -1.24 -61,26 5,993,868.40 476,010,50 1.53 13.62 GYD-GC-SS(1) 1,272.97 12.89 279.50 1,265.59 1,213.39 4.92 -89.30 5,993,874.66 475,982.49 2.62 26.38 MVVD+IFR-AK-CAZ-SC(2) 1,364.86 16.22 279.09 1,354.52 1,302.32 8.64 -112.08 5,993,878.45 475,959.71 3.63 35.50 MWD+IFR-AK-CAZ-SC(2) 1,456.31 20.00 281.06 1,441.42 1,389.22 13.66 -140.06 5,993,883.56 475,931.76 4.19 47.14 MWD+IFR-AK-CAZ-SC(2) 1,551.41 24,55 280,42 1,529.40 1,477,20 20.36 -175.47 5,993,890.37 475,896.38 4.79 62.20 MWD+IFR-AK-CAZ-SC(2) 1,642.85 28.85 279.18 1,611.08 1,558.88 27,32 -215.95 5,993,897.46 475,855.92 4,74 78.75 MWD+IFR-AK-CAZ-SC(2) 1,734.86 32.43 281,24 1,690.23 1,638.03 35.67 -262.07 5,993,905.96 475,809.83 4.05 98.01 MWD+IFR-AK-CAZ-SC(2) 1,828.05 33.99 281.31 1,768.20 1,716.00 45.65 -312.13 5,993,916.10 475,759.81 1.67 119.81 MWD+IFR-AK-CAZ-SC(2) 1,923.47 38,09 279,22 1,845.34 1,793,14 55,60 -367.36 5,993,926.22 475,704,62 4,49 142.82 MW3+IFR-AK-CAZ-SC(2) 2,015.33 41.22 277.88 1,916.06 1,863.86 64.29 -425.32 5,993,935.10 475,646.69 3.53 165.28 MWD+IFR-AK-CAZ-SC(2) 2,108.67 43.99 277.85 1,984.75 1,932.55 72.94 -487.91 5,993,943.94 475,584,14 2,97 188.81 MW1D+IFR-AK-CAZ-SC(2) 2,201.77 45.70 278.40 2,050.76 1,998.56 82.22 -552.90 5,993,953.43 475,519.18 1.88 213.54 MWD+IFR-AK-CAZ-SC(2) 2,296.02 49.16 278.52 2,114.51 2,062.31 92.43 -621.54 5,993,963.86 475,450.58 3.67 240.05 MWD+IFR-AK-CAZ-SC(2) 2,389.88 52.56 276.60 2,173,75 2,121.55 101.98 -693.70 5,993,973.64 475,378.46 3.95 266,77 MWD+IFR-AK-CAZ-SC(2) 2,483.01 55.16 277.50 2,228,67 2,176,47 111.22 -768.33 5,993,983.12 475,303.87 2.90 293.79 MWD+IFR-AK-CAZ-SC(2) 2,577.29 56.72 277.04 2,281.47 2,229.27 121.10 -845.80 5,993,993.25 475,226.43 1.70 322.12 MWD+IFR-AK-CAZ-SC(2) 2,669.63 61,46 274,36 2,328.90 2,276,70 128,92 -924.61 5,994,001.32 475,147.66 5.70 348.78 MWD+IFR-AK-CAZ-SC(2) 2,719.27 63.34 274.76 2,351.89 2,299.69 132.42 -968.46 5,994,004.95 475,103.83 3.85 362,78 MWD+IFR-AK-CAZ-SC(2) 2,760.93 62,93 274.90 2,370.72 2,318.52 135.55 -1,005.49 5,994,008.20 475,066,81 1.03 374.77 MWD+IFR-AK-CAZ-SC(2) 2,855.90 62,13 275.03 2,414.53 2,362.33 142.84 -1,089.44 5,994,015.76 474,982.89 0.85 402.16 MWD+IFR-AK-CAZ-SC(2) 2,948.61 62.68 274,51 2,457.47 2,405.27 149,67 -1,171,32 5,994,022.86 474,901.05 0.77 428.59 MWD+IFR-AK-CAZ-SC(2) 3,042.95 62.61 276.52 2,500.83 2,448.63 157.72 -1,254.71 5,994,031.17 474,817.68 1.89 456.58 MWD+IFR-AK-CAZ-SC(2) 3,145.00 62.38 276.44 2.547.95 2,495.75 167.94 -1,344.65 5,994,041.68 474,727.79 0.23 488.25 MWD+IFR-AK-CAZ-SC(3) 103/4"x13-1/2 3,160.82 62.35 276.43 2,555.29 2,503.09 169.51 -1,358.58 5,994,043.29 474,713,87 0.23 493.15 MWD+IFR-AK-CAZ-SC(3) 3,223.14 63.20 276.68 2,583.80 2,531.60 175.84 -1,413,63 5,994,049.79 474,658.84 1.41 512.60 MW0+IFR-AK-CAZ-SC(3) 3,317.18 63,21 277.13 2,626.19 2,573.99 185.93 -1,496.96 5,994,060.15 474,575,55 0,43 542.56 MW0+1FR-AK-CAZ-SC(3) 3,410.21 63.18 276.47 2,668.14 2,615.94 195.76 -1,579.41 5,994,070.25 474,493.14 0.63 572.04 MWD+IFR-AK-CAZ-SC(3) 3,503.84 63,14 276,43 2,710.42 2,658.22 205.15 -1,662.43 5,994,079.90 474,410.16 0.06 601.23 MWD+IFR-AK-CAZ-SC(3) 3,596.00 63.14 276.84 2,752.06 2,699.86 214.65 -1,744.09 5,994,089.66 474,328.53 0.40 630.21 MWD+IFR-AK-CAZ-SC(3) 3,687.72 63,12 275.96 2,793.51 2,741.31 223.77 -1,825.40 5,994,099,04 474,247.27 0.86 658,72 MWD+IFR-AK-CAZ-SC(3) 3,781.30 63.13 276.22 2,835.82 2,783.62 232.62 -1,908.40 5.994,108.16 474,164.30 0.25 687,40 MWD+IFR-AK-CAZ-SC(3) 3,873.74 63.08 276.00 2,877.63 2,825.43 241.40 -1,990.37 5,994,117.19 474,082.37 0.22 715.74 MWD+IFR-AK-CAZ-SC(3) 3,965.62 63.10 276.28 2,919.22 2,867.02 250.16 -2,071.84 5,994,126.22 474,000.94 0.27 743.95 MWD+IFR-AK-CAZ-SC(3) 4,058.93 63,15 275.93 2,961.40 2,909,20 259.01 -2,154.60 5,994,135,33 473,918.22 0.34 772,56 MWD+IFR-AK-CAZ-SC(3) 4,152.89 63.15 276.59 3,003.83 2,951.63 268.15 -2,237.93 5,994,144.74 473,834.93 0.63 801.59 MW0+1FR-AK-CAZ-SC(3) 2/24/2015 8:27:36AM Page 3 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Wet 3S-620 Project Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,247.85 63.10 276.84 3,046.76 2,994.56 278.06 -2,322.05 5,994,154.91 473,750.84 0.24 831.55 MWD+IFR-AK-CAZ-SC(3) 4,341.09 63.16 276.40 3,088.90 3,036.70 287.65 -2,404.67 5,994,164.76 473,668.26 0.43 860.84 MWD+IFR-AK-CAZ-SC(3) 4,434.57 63.17 276.57 3,131.10 3,078.90 297.07 -2,487.55 5,994,174.45 473,585.42 0.16 890,03 MWD+IFR-AK-CAZ-SC(3) 4,526.99 63.12 276.59 3,172.85 3,120.65 306.52 -2,569.46 5,994,184.16 473,503.55 0.06 919.02 MWD+IFR-AK-CAZ-SC(3) 4,619.40 63.16 276.70 3,214.60 3,162.40 316.06 -2,651.34 5,994,193.96 473,421.71 0.11 948.08 MW3+IFR-AK-CAZ-SC(3) 4,713.18 63.15 276.70 3,256.95 3,204.75 325.82 -2,734.44 5,994,203.98 473,338.64 0.01 977.66 M1MD+IFR-AK-CAZ-SC(3) 4,805.11 63.19 276.89 3,298.44 3,246.24 335.52 -2,815.90 5,994,213.95 473,257.23 0.19 1,006.79 MW3+IFR-AK-CAZ-SC(3) 4,897.05 63.19 276.37 3,339.91 3,287.71 345.00 -2,897.41 5,994,223.68 473,175.76 0.50 1,035.70 MWD+IFR-AK-CAZ-SC(3) 4,989.62 63.10 275.90 3,381.73 3,329.53 353.82 -2,979.52 5,994,232,77 473,093.68 0.46 1,064.13 MW3+IFR-AK-CAZ-SC(3) 5,082.59 63.10 275.44 3,423.79 3,371.59 362.02 -3,062.03 5,994,241.23 473,011.21 0.44 1,092.03 MWD+IFR-AK-CAZ-SC(3) 5,176.51 63.28 274.34 3,466.15 3,413.95 369.16 -3,145.54 5,994,248.64 472,927.73 1.06 1,119.17 MWD+IFR-AK-CAZ-SC(3) 5,269.10 63.17 275.37 3,507.87 3,455.67 376.16 -3,227.91 5,994,255.90 472,845.39 1.00 1,145.88 MWD+IFR-AK-CAZ-SC(3) 5,360.86 63.14 275.84 3,549.30 3,497.10 384.15 -3,309.39 5,994,264.15 472,763.95 0.46 1,173.35 MWD+IFR-AK-CAZ-SC(3) 5,452.61 63.21 276.35 3,590.71 3,538.51 392.85 -3,390.80 5,994,273.11 472,682.57 0.50 1,201.49 MWD+IFR-AK-CAZ-SC(3) 5,546.24 63.13 276.25 3,632.97 3,580.77 402.01 -3,473.85 5,994,282.54 472,599.56 0.13 1,230.47 MWD+IFR-AK-CAZ-SC(3) 5,638.25 63.15 275.81 3,674.54 3,622.34 410.64 -3,555.48 5,994,291.42 472,517.97 0.43 1,258.59 MWD+IFR-AK-CAZ-SC(3) 5,732.53 63.13 275.45 3,717.13 3,664.93 418,89 -3,639.18 5,994,299.94 472,434.30 0.34 1,286.84 MWD+IFR-AK-CAZ-SC(3) 5,824.91 63.21 276.11 3,758.83 3,706.63 427.19 -3,721.20 5,994,308.50 472,352.32 0.64 1,314.74 MWD+IFR-AK-CAZ-SC(3) 5,917.99 63.16 276.38 3,800.82 3,748.62 436.23 -3,803.77 5,994,317.80 472,269.78 0.26 1,343.48 MWD+IFR-AK-CAZ-SC(3) 6,011.12 63.20 275.66 3,842.84 3,790.64 444.94 -3,886.43 5,994,326.78 472,187.16 0.69 1,371.94 MWD+IFR-AK-CAZ-SC(3) 6,102.87 63.17 275.86 3,884.23 3,832.03 453.16 -3,967.90 5,994,335.26 472,105.73 0.20 1,399.62 MWD+IFR-AK-CAZ-SC(3) 6,196.11 63.18 276.01 3,926.30 3,874.10 461.76 -4,050.66 5,994,344.13 472,023.00 0.14 1,427.99 MWD+IFR-AK-CAZ-SC(3) 6,288.23 63.19 275.90 3,967.86 3,915.66 470.29 -4,132.43 5,994,352.92 471,941.27 0.11 1,456.05 MWD+IFR-AK-CAZ-SC(3) 6,380.99 62.68 275.92 4,010.07 3,957.87 478.80 -4,214.59 5,994,361.69 471,859.14 0.55 1,484.18 MWD+IFR-AK-CAZ-SC(3) 6,474.69 63.03 276.00 4,052.82 4,000.62 487.46 -4,297.52 5,994,370,61 471,776.25 0.38 1,512.64 MWD+IFR-AK-CAZ-SC(3) 6,567.60 63.23 276.67 4,094.81 4,042.61 496.60 -4,379.89 5,994,380.02 471,693.92 0.68 1,541.44 MWD+IFR-AK-CAZ-SC(3) 6,663.92 63.03 277.12 4,138.34 4,086.14 506.92 -4,465.19 5,994,390.60 471,608.66 0.47 1,572.09 MWD+IFR-AK-CAZ-SC(3) 6,754.32 62.62 277.12 4,179.63 4,127.43 516.88 -4,544.99 5,994,400,83 471,528.90 0.45 1,601.06 MW0+1FR-AK-CAZ-SC(3) 6,847.74 62.97 275.24 4,222.34 4,170.14 525,83 -4,627.59 5,994,410.03 471,446.34 1.83 1,629.72 MWD+IFR-AK-CAZ-SC(3) 6,941.13 63.15 275.18 4,264.65 4,212.45 533.39 -4,710.50 5,994,417.86 471,363.46 0.20 1,657.11 MWD+IFR-AK-CAZ-SC(3) 7,034.03 63.22 274.87 4,306.56 4,254.36 540.65 -4,793.09 5,994,425.38 471,280.90 0.31 1,684.14 MWD+IFR-AK-CAZ-SC(3) 7,128.63 63.26 274.48 4,349.16 4,296.96 547.53 -4,877.28 5,994,432.53 471,196.74 0.37 1,711.19 MND+IFR-AK-CAZ-SC(3) 7,220.74 63.23 275.20 4,390.62 4,338.42 554.47 -4,959.23 5,994,439.74 471,114.82 0.70 1,737.75 MWD+IFR-AK-CAZ-SC(3) 7,313.28 62.70 276.15 4,432.68 4,380.48 562.62 -5,041.25 5,994,448.15 471,032.83 1.08 1,765.50 MWD+IFR-AK-CAZ-SC(3) 7,406.70 62.72 276.46 4,475.52 4,423.32 571.74 -5,123.77 5,994,457.53 470,950.35 0.30 1,794.31 MW3+IFR-AK-CAZ-SC(3) 7,500.89 63.20 276.15 4,518.34 4,466.14 580.95 -5,207.16 5,994,467.01 470,867.00 0.59 1,823.42 MWD+IFR-AK-CAZ-SC(3) 7,593.47 63.19 276.69 4,560.09 4,507.89 590.19 -5,289.27 5,994,476.51 470,784.93 0.52 1,852.25 MWD+IFR-AK-CAZ-SC(3) 7,686.32 63.17 276.89 4,601.98 4,549.78 599.99 -5,371.55 5,994,486.57 470,702.69 0.19 1,881.66 MWD+IFR-AK-CAZ-SC(3) 7,778.78 63.22 276.68 4,643.68 4,591.48 609.74 -5,453.50 5,994,496.58 470,620.78 0.21 1,910.95 MND+IFR-AK-CAZ-SC(3) 7,873.14 63.31 278.02 4,686.13 4,633.93 620.52 -5,537.08 5,994,507.63 470,537.24 1.27 1,941.63 MWD+IFR-AK-CAZ-SC(3) 2/24/2015 8:27:36AM Page 4 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 7,966.46 63.89 281.27 4,727.63 4,675.43 634.53 -5,619.47 5,994,521.90 470,454.91 3.18 1,975.15 MWD+IFR-AK-CAZ-SC(3) 8,061.82 64.50 284.88 4,769.15 4,716.95 653.95 -5,703.07 5,994,541.58 470,371.38 3.47 2,014.22 MWD+IFR-AK-CAZ-SC(3) 8,105.54 65.02 286.25 4,787.79 4,735.59 664.56 -5,741.17 5,994,552.32 470,333.32 3.07 2,033.74 MWD+IFR-AK-CAZ-SC(3) 8,154.03 65.24 289.46 4,808.19 4,755.99 678.05 -5,783.03 5,994,565.94 470,291.50 6.02 2,056.95 MWD+IFR-AK-CAZ-SC(3) 8,198.80 65.64 291.34 4,826.80 4,774.60 692.24 -5,821.20 5,994,580.25 470,253.39 3,92 2,079,96 MWD+IFR-AK-CAZ-SC(3) 8,247.08 65.96 293.17 4,846.59 4,794.39 708.92 -5,861.95 5,994,597.06 470,212.69 3.52 2,106.00 MWD+IFR-AK-CAZ-SC(3) 8,291.86 66.12 295.12 4,864.78 4,812.58 725.66 -5,899.29 5,994,613.91 470,175.41 4.00 2,131.27 MWD+IFR-AK-CAZ-SC(3) 8,339.30 66.44 297.29 4,883.87 4,831,67 744.84 -5.938.25 5,994,633.22 470,136.51 4.24 2,159.31 MW1J+IFR-AK-CAZ-SC(3) 8,381.72 66.68 299.35 4,900.74 4,848.54 763.30 -5,972.51 5,994,651.79 470,102.31 4.49 2,185.51 MWD+IFR-AK-CAZ-SC(3) 8,431.49 67.04 302.36 4,920.30 4,868.10 786.77 -6,011.79 5,994,675.38 470,063.11 5.61 2,217.78 MWD+IFR-AK-CAZ-SC(3) 8,477.50 67,33 304.29 4,938.15 4,885.95 810.07 -6,047.23 5,994,698.79 470,027.76 3.92 2,248.96 MWD+IFR-AK-CAZ-SC(3) 8,524.46 67.80 306.50 4,956.07 4,903.87 835.21 -6,082.61 5,994,724.04 469,992.46 4.46 2,281.92 MW1J+IFR-AK-CAZ-SC(3) 8,567.64 68.13 309.07 4,972.27 4,920.07 859.73 -6,114.24 5,994,748.66 469,960.91 5.57 2,313.36 MWD+IFR-AK-CAZ-SC(3) 8,617.75 68.63 311.06 4,990.74 4,938.54 889.71 -6,149.89 5,994,778.75 469,925.36 3.82 2,351.08 MW1J+IFR-AK-CAZ-SC(3) 8,663.03 68.86 313.57 5,007.15 4,954.95 918.12 -6,181.09 5,994,807.26 469,894.26 5.19 2,386.19 MWD+IFR-AK-CAZ-SC(3) 8,712.03 69.21 316.59 5,024.69 4,972.49 950.52 -6,213.39 5,994,839.75 469,862.06 5.80 2,425.44 MWD+IFR-AK-CAZ-SC(3) 8,760.60 69.62 319.11 5,041.77 4,989.57 984.22 -6,243.90 5,994,873.56 469,831.66 4.93 2,465.53 MW1D+IFR-AK-CAZ-SC(3) 8,805.29 69.91 320.71 5,057.23 5,005.03 1,016.30 -6,270.90 5,994,905.72 469,804.77 3.42 2,503.18 MWD+IFR-AK-CAZ-SC(3) 8,857.17 70.35 323.65 5,074.86 5,022.66 1,054.84 -6,300.81 5,994,944.35 469,774.98 5.40 2,547.81 MWD+IFR-AK-CAZ-SC(3) 8,897.07 70.67 325.08 5,088.18 5,035.98 1,085.41 -6,322.73 5,994,974.98 469,753.17 3.47 2,582.78 MWD+IFR-AK-CAZ-SC(3) 8,941.51 71.06 327.76 5,102.74 5,050.54 1,120.39 -6,345.95 5,995,010.03 469,730.06 5.76 2,622.33 MWD+IFR-AK-CAZ-SC(3) 8,990.73 71.66 329.33 5,118.48 5,066.28 1,160.17 -6,370.28 5,995,049.89 469,705.86 3.26 2,666.82 MVVD+IFR-AK-CAZ-SC(3) 9,034.13 73,11 331.33 5,131.61 5,079.41 1,196.11 -6,390.75 5,995,085.89 469,685.50 5.52 2,706.64 MWD+IFR-AK-CAZ-SC(3) 9,085.39 74.57 333.77 5,145.88 5,093.68 1,239.80 -6,413.44 5,995,129.64 469,662.96 5.39 2,754.52 MWD+IFR-AK-CAZ-SC(3) 9,135.39 76.12 335.51 5,158.53 5,106.33 1,283.51 -6,434.16 5,995,173.42 469,642.38 4.58 2,801.94 MWD+IFR-AK-CAZ-SC(3) 9,177.86 77.80 336.97 5,168.11 5,115.91 1,321.37 -6,450.82 5,995,211.33 469,625.84 5.18 2,842.72 MWD+IFR-AK-CAZ-SC(3) 9,218.45 79.44 338.93 5,176.12 5,123.92 1,358.25 -6,465.76 5,995,248.25 469,611.02 6.22 2,882.12 MWD+IFR-AK-CAZ-SC(3) 9,279,00 81.31 340.38 5,186.25 5,134.05 1,414.22 -6,486.51 5,995,304,29 469,590,45 3.88 2,941.44 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 9,299.87 81.95 340.88 5,189.29 5,137.09 1,433.70 -6,493.36 5,995,323.78 469,583.67 3.88 2,962.00 MWD+IFR-AK-CAZ-SC(4) 9,340.50 83.41 341.57 5,194.46 5,142.26 1,471.85 -6.506,33 5,995,361.98 469,570.82 3.97 3,002.16 MWD+IFR-AK-CAZ-SC(4) 9,434.89 85.17 343.72 5,203.86 5,151.66 1,561.49 -6,534.34 5,995,451.69 469,543.10 2.93 3,095.91 MWD+IFR-AK-CAZ-SC(4) 9,530.27 85.18 345.52 5,211.88 5,159.68 1,653.13 -6,559.54 5,995,543.40 469,518.19 1.88 3,190.92 MWD+IFR-AK-CAZ-SC(4) 9,579.10 83.88 346.95 5,216.53 5,164.33 1,700.34 -6,571.11 5,995,590.64 469,506.78 3.95 3,239.52 MWD+IFR-AK-CAZ-SC(4) 9,624.07 82.94 347.51 5,221.70 5,169.50 1,743.90 -6.580.98 5,995,634.23 469,497.05 2.43 3,284.19 MWD+IFR-AK-CAZ-SC(4) 9,719.15 82.83 347.23 5,233.47 5,181.27 1,835.97 -6,601.61 5,995,726.36 469,476.71 0.31 3,378.51 MWD+IFR-AK-CAZ-SC(4) 9,814.29 84.72 345.39 5,243.79 5,191.59 1,927.85 -6,624.00 5,995,818.30 469,454.62 2.76 3,473.08 MWD+IFR-AK-CAZ-SC(4) 9,844.56 86.26 344.59 5,246.17 5,193.97 1,957.00 -6,631.81 5,995,847.47 469,446.90 5.73 3,503.25 MWD+IFR-AK-CAZ-SC(4) 9,908,30 89.62 343.95 5,248.46 5,196.26 2,018.30 -6,649,08 5,995,908.82 469,429.83 5.37 3,566.91 MW1J+IFR-AK-CAZ-SC(4) 9,955.36 89.48 344.95 5,248.83 5,196.63 2,063.64 -6,661.69 5,995,954.19 469,417.37 2.15 3,613.95 MWD+IFR-AK-CAZ-SC(4) 10,004.11 89.28 345,51 5,249.36 5,197.16 2,110.77 -6,674.12 5,996,001.36 469,405.09 1.22 3,662.69 MWD+IFR-AK-CAZ-SC(4) 2/24/20 15 8:27:36AM Page 5 COMPASS 5000,1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 35-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,098.59 88.56 346.23 5,251.14 5,198.94 2,202.38 -6,697.18 5,996,093.03 469,382.33 1.08 3,757.15 MWD+IFR-AK-CAZ-SC(4) 10,192.65 88.15 346.40 5,253.84 5,201.64 2,293.73 -6,719.43 5,996,184.44 469,360.38 0.47 3,851.17 MWD+IFR-AK-CAZ-SC(4) 10,287.33 88.49 346.19 5,256.61 5,204.41 2,385.67 -6,741.85 5,996,276.45 469,338.25 0.42 3,945.81 MIND+IFR-AK-CAZ-SC(4) 10,382.46 89.07 346.31 5,258.64 5,206.44 2,478.06 -6,764.45 5,996,368.90 469,315.94 0.62 4,040.92 MWD+IFR-AK-CAZ-SC(4) 10,476.36 88.97 346.50 5,260.25 5,208.05 2,569.31 -6,786.52 5,996,460.21 469,294.17 0.23 4134.80 MWD+IFR-AK-CAZ-SC(4) 10,570.93 89.26 345.76 5,261.71 5,209.51 2,661.11 -6,809.19 5,996,552.08 469,271.80 0.84 4,229.36 MWD+IFR-AK-CAZ-SC(4) 10,665.35 91.18 344.57 5,261.34 5,209.14 2,752.38 -6,833.36 5,996,643.41 469,247.92 2.39 4,323.76 MWD+IFR-AK-CAZ-SC(4) 10,760.04 91.03 344.32 5,259.52 5,207.32 2,843.58 -6,858.75 5,996,734.69 469,222.83 0.31 4,418.40 MWD+IFR-AK-CAZ-SC(4) 10,853.73 91.16 343.74 5,257.73 5,205.53 2,933.64 -6,884.52 5,996,824.82 469,197.34 0.63 4,512.02 MWD+IFR-AK-CAZ-SC(4) 10,949.13 91.10 344.78 5,255.85 5,203.65 3,025.44 -6,910.40 5,996,916.70 469,171.77 1.09 4,607.35 MWD+IFR-AK-CAZ-SC(4) 11,043.81 90.34 344.98 5,254.66 5,202.46 3,116.84 -6,935.09 5,997,008.16 469,147.37 0.83 4,702.01 MWD+IFR-AK-CAZ-SC(4) 11,139.21 89.62 346.00 5,254.69 5,202.49 3,209.19 -6,958.99 5,997,100.58 469,123.76 1.31 4,797.40 MW3+IFR-AK-CAZ-SC(4) 11,233.00 89.59 341.81 5,255.34 5,203.14 3,299.29 -6,984,99 5,997,190.75 469,098.06 4.47 4,891.10 MWD+IFR-AK-CAZ-SC(4) 11,328.09 89.86 337.24 5,255.79 5,20a 59 3,388.34 -7,018.24 5,997,279.90 469,065.10 4.81 4,985.56 MWD+IFR-AK-CAZ-SC(4) 11,422.11 90.07 334.41 5,255.85 5,203.65 3,474.11 -7,056.74 5,997,365.78 469,026.87 3.02 5,078.09 MWD+IFR-AK-CAZ-SC(4) 11,517.85 90.38 336.94 5,255.47 5,203.27 3,561.34 -7,096.17 5,997,453.13 468,987.72 2.66 5,172.27 MWD+IFR-AK-CAZ-SC(4) 11,611.51 90.20 342.41 5,255.00 5,202.80 3,649.14 -7,128.69 5,997,541.02 468,955.49 5.84 5,265.33 MWD+IFR-AK-CAZ-SC(4) 11,656.78 89.96 345.22 5,254.94 5,202.74 3,692.61 -7,141.31 5,997,584.53 468,943.01 6.23 5,310.56 MWD+IFR-AK-CAZ-SC(4) 11,706.56 89,55 348.27 5,255.15 5,202.95 3,741.05 -7,152.72 5,997,633.01 468,931.76 6.18 5,360.33 MWD+IFR-AK-CAZ-SC(4) 11,755.76 89.35 349.15 5,255.62 5,203.42 3,789.30 -7,162.36 5,997,681.28 468,922.28 1.83 5,409.47 M1M2+IFR-AK-CAZ-SC(4) 11,800.54 89.12 349.56 5,256.22 5,204.02 3,833.30 -7,170.63 5,997,725,30 468,914.15 1.05 5,454.17 MWD+IFR-AK-CAZ-SC(4) 11,894.31 90.62 348.73 5,256.43 5,204.23 3,925.39 -7,188.29 5,997,817.44 468,896.79 1.83 5,547.80 MWD+IFR-AK-CAZ-SC(4) 11,988.63 91.28 351.31 5,254.87 5,202.67 4,018.26 -7,204.63 5,997,910.35 468,880.75 2.82 5,641.86 MWD+IFR-AK-CAZ-SC(4) 12,083.85 90.74 350.65 5,253.19 5,200.99 4,112.29 -7,219.55 5,998,004.42 468,866.12 0.90 5,736.71 MWD+IFR-AK-CAZ-SC(4) 12,177.85 91.45 348.84 5,251.39 5,199.19 4,204.77 -7,236,28 5,998,096.94 468,849.69 2.07 5,830.49 MWD+IFR-AK-CAZ-SC(4) 12,273.41 90.40 348.63 5,249.85 5,197.65 4,298.47 -7,254.95 5,998,190.70 468,831.33 1.12 5,925.92 MWD+IFR-AK-CAZ-SC(4) 12,367.16 90.51 348.31 5,249.11 5,196.91 4,390,33 -7,273.69 5,998,282.60 468,812.88 0.36 6,019.58 MWD+IFR-AK-CAZSC(4) 12,462.56 91.51 347.93 5,247.42 5,195.22 4,483.67 -7,293.32 5,998,375.99 468,793.55 1.12 6,114.90 MWD+IFR-AK-CAZ-SC(4) 12,556.79 91.47 348.08 5,244.97 5,192.77 4,575.81 -7,312.90 5,998,468.19 468,774.27 0.16 6,209.04 MWD+IFR-AK-CAZ-SC(4) 12,651.72 91.31 346.35 5,242.67 5,190.47 4,668.36 -7,333.90 5,998,560.79 468,753.57 1.83 6,303.92 MWD+IFR-AK-CAZSC(4) 12,745.30 89.78 342.57 5,241.78 5,189.58 4,758.49 -7,358.97 5,998,651.00 468,728.79 4.36 6,397.44 MWD+IFR-AK-CAZ-SC(4) 12,840.31 90.00 342.93 5,241.96 5,189.76 4,849.23 -7,387.14 5,998,741.82 468,700,91 0.44 6,492.30 MWD+IFR-AK-CAZ-SC(4) 12,934.51 90.29 346.12 5,241.72 5,189.52 4,940.00 -7,412.27 5,998,832,66 468,676.07 3.40 6,586.45 MWD+IFR-AK-CAZ-SC(4) 13,029.20 89.06 347.05 5,242.26 5,190.06 5,032.10 -7,434.24 5,998,924.82 468,654.40 1.63 6,681.13 MWD+IFR-AK-CAZSC(4) 13,122.94 89.64 346.93 5,243.33 5,191.13 5,123.43 -7,455.34 5,999,016.21 468,633.60 0.63 6,774.85 MWD+IFR-AK-CAZ-SC(4) 13,216.61 91.51 348.11 5,242.39 5,190.19 5,214.88 -7,475.58 5,999,107.71 468,613.65 2.36 6,868.48 MWD+IFR-AK-CAZ-SC(4) 13,310.98 93.28 348.20 5,238.44 5,186,24 5,307.15 -7,494.93 5,999,200.04 468,594.60 1.88 6,962.70 MWD+IFR-AK-CAZ-SC(4) 13,404.46 93.02 346.86 5,233.30 5,181.10 5,398.29 -7,515.09 5,999,291.23 468,574.74 1.46 7,056.00 MWD+IFR-AK-CAZSC(4) 13,498.15 92.78 345.11 5,228.56 5,176.36 5,489.07 -7,537.75 5,999,382.07 468,552.37 1.88 7,149.57 MWD+IFR-AK-CAZ-SC(4) 13,592.77 93.02 345.40 5,223.78 5,171.58 5,580.46 -7,561.80 5,999,473.53 468,528.61 0.40 7,244.06 MWD+IFR-AK-CAZ-SC(4) 2/24/2015 8:27:36AM Page 6 COMPASS 5000.1 Build 65 . • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 3S-620 Project: Kuparuk River Unit TVD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Site: Kuparuk 3S Pad MD Reference: Plan:27.5+24.7 @ 52.20usft(Doyon 141) Well: 3S-620 North Reference: True Wellbore: 3S-620 Survey Calculation Method: Minimum Curvature Design: 3S-620 Database: OAKE D M P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 13,655.00 92.93 345.11 5,220.55 5,168.35 5,640.56 -7,577.62 5,999,533.67 468,512.99 0.49 7,306.20 MWD+IFR-AK-CAZ-SC(4) 4 1/2"x 6-1/2" 13,689.40 92.88 344.95 5,218.80 5,166.60 5,673.75 -7,586.49 5,999,566.88 468,504.22 0.49 7,340.55 MWD+IFR-AK-CAZ-SC(4) 13,768.00 92.88 344.95 5,214.86 5,162.66 5,749.55 -7,606.87 5,999,642.75 468,484.08 0.00 7,419.04 PROJECTED to TD 2/24/2015 8:27:36AM Page 7 COMPASS 5000.1 Build 65 • • 0, Cement Detail Report 3S-620 CtoruscoPhiilips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/19/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/27/2015 16:00 1/28/2015 14:15 3S-620 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Casing Cement 143.5 3,145.0 No Yes Yes Q Pump!nit(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) 5 6 6 500.0 1,000.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbls water,check pump low trip, test lines to 4000 psi,pump 97 bbls 11 ppg MPII. Drop btm plug. Pump 515 bbls 11 ppg DeepCRETE lead cmt followed by 63 bbls 12 ppg DeepCRETE tail cmt.Lost total returns after 40 bbls tail cmt pumped. Drop top plug. Pump 10 bbls water. Displace with rig pump @ 6 bpm. Slow pump to 3 bpm final 10 bbls. Bump plug w,2815 stks.Pressure up to 1000 psi. Hold for 5 mins. Did not get cement to surface. Check floats.Good.CIP @19:40 hrs. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud Push II 100.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 11.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 143.5 2,645.0 1,499 G 510.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 1.4 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.02 %BWOC Additive Type Concentration Conc Unit label Dispersant D185 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,645.0 3,145.0 215 G 64.0 Yield(fe/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.66 5.74 12.00 Additives Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D046 0.07 gal/sx Additive Type Concentration Conc Unit label Antifoam D185 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D186 0.06 gal/sx Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Top Job 28.9 143.5 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 1 1 1 72.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Perform top out cement job. Flush annulus with 10 bbls water, batch up and pump 26 bbls 11 ppg LiteCRETE cement. 16 bbls of cement returns to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) LiteCRETE 27.0 142.0 106 G 36.0 Yield(fe/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.75 11.00 Page 1/2 Report Printed: 3/4/2015 • " � Cement Detail Report $0.,. � , 3S-620 COnOCt*h utps String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/19/2015 00:00 Additives Additive Type Concentration Conc Unit label Dispersant D046 0.07 gal/sx Additive Type Concentration Conc Unit label Antifoam D185 0.2 %BWOC Page 2/2 Report Printed: 3/4/2015 • s of �� THE STATE Alaska Oil and Gas 41- THE%%,; sem F,r� ofALASIc:A�� Conservation Commission _ Witt= 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 OFALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov Steve Shultz Drilling Engineer ! (07 ConocoPhillips Alaska, Inc. (�. ` P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Torok Undefined Oil Pool, KRU 3S-620 Sundry Number: 315-046 Dear Mr. Shultz: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this (J day of February, 2015 Encl. '" STATE OF ALASKA110 RECEIVED AL OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS JAN 2 8 2015 20 AAC 25.280 /��'7j ag� 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Chane ri7�il; ram r Suspend r Plug Perforations h Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate rAlter casingTo JO b Other:Cemeht Remediation Ir 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development F, 214-167-0 ` 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20695-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1 KRU 3S-620 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380107,25544,25528 ' Kuparuk River Field/Torok Undefined Oil , 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 3155 - 3155 . na na none none Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 106' 106' 1640 670 Surface 3117' 10.75" 3113' 2534' 5210 2480 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none ( none na na na Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no Packer no SSSV 1 na 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic rDevelopment V . Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/29/2015 Oil J`. ! Gas r WDSPL r Suspended r 16.Verbal Approval: Yes Date: 1/28/2015 WINJ r GINJ r WAG E Abandoned r Commission Representative:Jim Regg GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4297 Email: Steve.Shultz(a contractor.conocophillips.com Printed Name Ste e Shult Title: Drilling Engineer Si nature g • �,� �j Phone:263-4297 Date %/� �? /,'j • Commission Use Only tr- Sundry Number: 3 6_09(0 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: `/) — -9b 4 APPROVED BY 2 LS Approved by: t n . ovcd application is vaflQ TOt)1 rlOnths fron7 t C ISS vat. Date: p pp Y!4 //`Y/' A'�'/.S Form 10-403(Revised 10/2012) p RIG I N A L �� Submit Form and A ac a sin Duplicate arc A/3a/ice '5 RBDMS-M FEB - 5 2015 • Surface Cementing Operation on 3S-620 Moraine On January 27, 2015 a primary cement operation was performed on 3S-620. As the job progress and while pumping cement the well had total losses which required the rig to perform a top job. These are the facts leading up to that job. Drilled Surface Depth MD 3,155' RKB Drilled Surface Depth TVD 2,552' Surface Casing 10%", 45.5#, L-80, H563 Shoe Depth MD 3,113' RKB Shoe Depth TVD 2,534' Circulated prior to cement 6 hours (full returns) Cement Program Spacer 97 bbls of Mud Push Lead Cement 555 bbls of DeepCrete 11.0 ppg Tail Cement 63 bbls of DeepCrete 12.0 ppg Displacement 299 bbls Pump Rate 6-7 bpm Reciprocated Casing Reciprocated casing 30 feet Centralizers One 10 3/"X 15'/" per joint Wiper Plugs Bumped Floats Held The well lost 63 bbls of mud while running in the hole with the casing and once on bottom the rig circulated and conditioned the mud for 6 hours with full rates and full returns. Dowell- Schlumberger was then rigged up and pumped 97 bbls of mud push, followed by 555 bbls of DeepCrete 11.0 ppg lead cement, followed by 63 bbls of DeepCrete 12.0 ppg tail cement. The majority of the mud push and red dye indicator along with some cement were returned to surface when returns were lost. Pumping continued until the plugs were bumped with 299 bbls of displacement. The floats were tested and held. Calculating the volume of cement in the annulus at the time of losses equated out to 213 bbls. The hypothetical calculated volume with no wash out is 202 bbls. We ran the new Drillplex mud system from MI on this well which has proven to give us fairly gauge holes at Kuparuk. With a 10%washout the annular volume would have been approximately 222.6 bbls, which would theoretically place the top of cement at-140' from ground level. For the top job, %" piping was utilized and lower into the annulus between the conductor and the surface casing. Approximately 100 feet from ground level, the piping started taking weight and kept proceeding down but with resistance (mushy). The piping was worked down through the interface to 115' from ground level where it slowly stopped. Fresh water was then pumped to clean out the annulus for that 115' of annular space. The pH of the watery fluid coming back was 11.0-11.5. Once approval from the AOGCC was obtained,-10 bbls of DeepCrete 11.0 ppg was pumped to fill the annular space from the top of the primary cement interface to surface as they worked the conduit around the annulus. • 6 pin z /4—/ G� Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday, February 03, 2015 9:34 AM To: 'Shultz, Steve (Orbis Engineering,Inc.)' Subject: RE: 3S-620 Moraine (PTD 214-167) No additional conditions were on the approved sundry.You should have the approved sundry. Thanx, Victoria From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz©contractor.conocophillips.com] Sent: Tuesday, February 03, 2015 9:25 AM To: Loepp, Victoria T(DOA) Subject: 3S-620 Moraine Good Morning Victoria, We are in the process of drilling to TD for the 9 7/8" intermediate hole on the Moraine 3S-620 and will be running our 7 5/8" intermediate casing in the next couple of days. I sent in a sundry for the top off we did on the 10%" surface casing last week to which Jim Regg gave us a verbal approval to proceed. Could you tell me it that sundry has any special instructions we need to know about. Thanks, Steve Shultz Drilling Engineer 263-4297 1 PV OF T4, i �w ��I s?, THE STATE Alaska Oil and Gas t4 LVAL LAsKA. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS1°.' Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Torok Undefined Oil Pool, KRU 3S-620 ConocoPhillips Alaska, Inc. Permit No: 214-167 Surface Location: 2546.5' FNL, 1188' FEL, SEC. 18, T12N, R8E, UM Bottomhole Location: 2148' FNL, 3930' FEL, SEC. 12, T12N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for 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 a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 0/i /1/ Daniel T. Seamount, Jr. Commissioner (p DATED this Z I day of December, 2014. 4. ..,-- • RECEIVED < STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 16 2014 PERMIT TO DRILL �� � 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil D• Service-Winj ❑ Single Zone Q- 1c.Specify if well is proposed for: -Drill 0. Lateral ❑ Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas El Gas Hydrates❑ Redrill ❑ Reentry C Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: . u Blanket Li Single Well 11.Well Name and Number: w.44,‘,.,` ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • KRv 35-620 4.1 3.Address: 6.Proposed Depth: 12. Field/Pool(s): -fg P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13671' • TVD: 5221' - Kuparuk River Field, 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): ?Ilk /O PIC (kV. ©i I Surface:2546.5'FNL, 1188'FEL,Sec. 18,T12N,R8E,UM • ADL 380107,25544,4552g .Kupw.uk-Qil-Reel- Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1001'FNL,2916.5'FEL,Sec. 13,T12N, R7E,UM• 4624,2639 12/1/2014 Total Depth: 9.Acres in Property: 9/4.?, 14.Distance to 2148'FNL,3930'FEL,Sec. 12,T12N, R7E,UM. 25C0 7-S�e g Nearest Property: >1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 55.7 feet 15.Distance to Nearest Well Open Surface:x- 476072 y- 5993869 Zone- 4 • GL Elevation above MSL: • 27.7 feet to Same Pool: none, 16.Deviated wells: Kickoff depth: . 250 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 90° deg Downhole:2350 psig. Surface: 1829 psig . 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 164.8# B-35 Welded 106' 27.7 27.7' 106' 106' Driven 13.5" 10.75" 45.5# L-80 Hydril 563 3133' 27.7 27.7' 3161' 2556' 1465 sx LiteCRETE,195 sx LiteCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 9090' 27.7 27.7' 9115' 5153' 904 sx GasBLOK 9.875" 7.625" 39# TN-110 Hydril 563 300' 9115' 5151' 9415' 5206' same as above 6.5" 4.5" 12.6# C-110 Hydril 521 600' 9265' 5177' 9865' 5221' uncemented liner 6.5" 4.5" 12.6# L-80 IBTM 3806' 9865' 5221' 13671' 5221' uncemented 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) Effective Depth MD(ft): Effective 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): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch El Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-42971r4j Email Steve.Shultzancontracto . orE p.com Printed Name G.L. Alvord Title Alaska Drilling Manager A_( 0...k.Signature Phone:265-6120 Date (0((51 4- Commission Use Only Permit to Drill API Number: Permit Approval p See cover letter '� Number: ' 1 - 1 (27_ 50- 1 d 3-�0 is _00 -00 I Date: 's a q(I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: L)/1 Other:50 p tt.s f- fo 3 5 I CJ p5 , - Samples req'd: Yes ❑ No Cv Mud log req'd: Yes ET No[ir 4 r)h v is` r-e".5 f l0 2 5�L(.)S/ H2S measures: Yes No [►1 Directional svy req'd: Yes No❑ Spacing exception req'd: Yes I No ❑ Inclination-only svy req'd: Yes❑ No[t� APPROVED BY THE /ZJZ�// Approvedi&L#1 COMMIS�►/�(t1 AO Date:Form 10-40 Levis d 10/212) This permit is valid for E on1h 4 4o prov/all(20AAC25.005(g)) • Post Office Box 100360 ConocoPhillips Anchorage,Alaska 99510-0360 Phone(907)263-4297 Email: steve.shultz(&,contractor.conocophillips.com RECEIVED October 14,2014 OCT 16 2014 Alaska Oil and Gas Conservation Commission AOGCC 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill 3S-620 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 3S-620 from the 3S drill site. This well is intended to be a producing well in the Moraine horizon and the intended spud date for this well is Decemberl st, 2014 using Doyon 141. When the Doyon 141 moves onto 3S-620,the proposed plan is to nipple up and test the diverter system utilizing the existing 16"conductor, spud the well with a 13'/2'bit, drill to the surface casing point,then run and cement the 103/4'45.5#L-80 Hydril 563 surface casing in place. A 9%" bit will be made up and the surface casing drilled out. The well will be drilled down to the intermediate casing point where a string of 7%"29.7#L-80 Hydril 563 casing will be run and cemented in place.A 6W bit will be made up and the intermediate casing drilled out and a horizontal lateral will be drilled to TD. Once the drill string is pulled, a 4W production liner with swell packers and frac sleeves will be slid in position for future frac operations.The final upper completion will consist of 4'/2"tubing complete with gas lift equipment. 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. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. Cementing Program 8. Diverter placement and orientation Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Steve Shultz at 263-4297. Sincer: eve Shultz Drilling Engineer Attachments • *tion for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 3S-620 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 3 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 6 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 7 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 8 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 (Requirements of 20 AAC 25.005 (c)(14)) 9 3S-620 APD Page 1 of 14 Printed 15-Oct-14 ORIGINAL Allition for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Position and Orientation 3S-620 APD Page 2 of 14 Printed: 15-Oct-14 ORIGINAL • Alption for Permit to Saved:Drill,Well15 3S-620Oct14 1. Well Name (Requirements of 20 AAC 25.005(0) The well for which this application is submitted will be designated as 3S-620. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3S-620 is planned as a horizontal grass roots well to explore the possibilities of producing from the Moraine formation. The rig will drill a 13W surface hole which will be cased off with 10%" casing with premium connections. The 9'/8" intermediate section will be drilled to the top of the Moraine Sand where a string of 7%" casing will be run and cemented in place. A 6W bit will then be run to drill the horizontal portion of the well followed up with a 4W production liner(uncemented), equipped with swell packers and frac sleeves. Finally, a 4W gaslifted tubing assembly will be run for the upper completion. Location at Surface 2546.5' FNL, 1187.8' FEL, Sec 18, T12N/R8E, UM NAD 1927 RKB Elevation 55.7'AMSL Northings: 5,993,869.44 Eastings: 476,071.75 Pad Elevation 27.7'AMSL Location at 7%" Intermediate Csg Pt. 1000.8' FNL, 2916.5' FEL, Sec 13, T12N, R7E, UM (Top of Moraine) NAD 1927 Measured Depth, RKB: 9,415' Northings: 5,995,438.74 Eastings: 469,543.25 Total Vertical Depth, RKB: 5,206' Total Vertical Depth, SS: 5,150' Location at the Heel 768.8' FNL, 2973.5' FEL, Sec 13, T12N, R7E, UM NAD 1927 Measured Depth, RKB: 9654' Northings: 5,995,670.90 Eastings:469,487.10 Total Vertical Depth, RKB: 5,221' Total Vertical Depth, SS: 5,165' Location at Total Depth 2,147.6' FNL, 3,930' FEL, Sec 12, T12N, R7E, UM (Toe) NAD 1927 Measured Depth, RKB: 13,671' Northings: 5,999,575.6 Eastings: 468,544.90 Total Vertical Depth, RKB: 5,221' Total Vertical Depth, SS: 5,165' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: 3S-620 APD Page 3of14 OR I G I N A L Printed: 15-Oct-14 Alltion for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 Casing Csg Setting Fracture Pore ASP Size Marker Depth Gradient pressure Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 Surface 120/ 120 10.9 54 68 10% 100' TVD 3,161 /2,556 14.5 1,143 1,276 over C-80 7% Moraine 9,415/5,206 14 2,350 2,600 4% Moraine 13,671 /5,206 14 2,350 2,600 • Pore pressures above the Moraine calculated with a seawater gradient of 8.6 ppg • NOTE: The Doyon 141, 5000 psi BOP equipment is adequate. Testing BOPE to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 120' = 68 psi OR ASP = FPP—(0.1 x D) =1,143—(0.1 x 2,556') = 887 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052)—0.1] D _ [(14.5 x 0.052)—0.1]x 2,556' = 1,672 psi OR ASP = FPP—(0.1 x D) =2,350—(0.1 x 5,206') = 1,829 psi 3. Drilling below intermediate casing (7-5/8") ASP = [(FG x 0.052)—0.1] D = [(14 x 0.052)—0.1]x 5,206' = 3,269 psi OR ASP = FPP—(0.1 x D) =2,350—(0.1 x 5,206') = 1,829 psi (B) Data on potential gas zones; The well bore is not expected to penetrate any gas zones. 3S-620 APD Page 4of14 r--� I 6 I N L Printed: 15-Oct-14 • AlOtion for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 (C) Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The Moraine formation has never been produced from or injected into for production of gas and oil. As such the formation pressure is expected to be virgin pressure of approximately 2,350 psi or 8.7 ppg ✓ MWE. All of the previous wells drilled in the 3S region were in search of hydrocarbons in the Kuparuk sands below. Only one well has been drilled and completed in the Moraine (3S-19) as a vertical producer in December of 2012. Looking at this well and all the other wells drilled from the 3S pad, there appears that no substantial problems occurred while drilling to and through the Moraine. Any well problems in this area occurred below the Moraine in the HRZ and Miluveach formations. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 3S-620 APD Page 5 of 14 Printed: 15-Oct-14 ORIGINAL • Alption for Permit to Saved:Drill,Well15-Oct-14 3S-620 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 164.8 B-35 Welded 106' Surf 106'/106' Driven Hydril Cemented to Surface with 10/< 13% 45.5 L-80 563 3,133' Surf 3,161'/2,556' 1465 sx 11.0 ppg LiteCRETE Lead 195 sx 12.0 ppg LiteCRETE tail 7% 9% 29.7 L-80 563i1 9,090' Surf 9,115'/5,153' Cement Top planned @ 6,000'MD/ 3,845'TVD. Cemented w/ 7% 9% 39# TN110 Hydril 300' 9,115' 9,415'/5,206' 904 sx GasBLOK 15.8 ppgClass"G" SS 563 4% 61/2 12.6 C-110 H521'I 600' 9,265' 9,865'/5,221' Uncemented Liner 4% 6% 12.6 L-80 IBTM 3,806' 9,865' 13,671'/5,221' 4% 12.6 L-80 IBTM —9,212' Surf 9,240'/5,242' Production Tubing Casing / Liner Design: Wt Connection 85%of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10%" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7%" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 7%" 39.0 TN-110SS 3 Hyd563 10,370 psi 8,815 psi 11480 psi 9,758 psi 4%2" 12.6 C-110 3 Hyd521 9,200 psi 7,820 psi 11,590 psi 9,852 psi 4%2" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 7,700 psi 6,545 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 3S-620 APD Page 6 of 14 0 R1GIN p L Printed: 15-Oct-14 • A.tion for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 13'/2" hole 9'/8" hole 6h/2" hole 103/4" Casing 7%" Casing 41/2" Liner Spud Mud LSND Kla-Sheild Density 9.6- 10 ppg 9.6— 10.0 ppg 9.6-10.0 ppg YP 60 -80 18—28 18 -28 Funnel Viscosity(sec) 75—250 40-55 45 -55 PV 20 -60 20-25 20 -25 Initial Gels 10 -35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160°F 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. Maintain mud weight above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND/KLASHIELD water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. Maintain minimum mud weight of at least 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 3S-620 APD Page 7 of 14 0RIGINAL Printed: 15-Oct-14 • • A.tion for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAc 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 141 on 3S-620 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs out on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor(-250') to get 13'/" bit and BHA below ground level. 5. Spud and directionally drill 13%' hole to the 10-3/4"surface casing point(3,161' MD/2,556' TVD) according to the directional plan. Run MWD/ LWD logging tools in drill string (GR/RES/PWD/Gyro ✓ while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 103/"45.5# L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9%" intermediate hole to 9,415' MD/5,206' TVD into the Moraine formation. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)with on-site mud logging and / field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to 9,415' MD/5,206' TVD and cement in place with a minimum of 500' of cement above the Moraine formation. 13. MU 6%" bit and RIH on 4" drill pipe. 14. Directionally drill a 6%" hole to 13,671' MD/5,221' TVD. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Microscope) for navigational monitoring and formation data J gathering. 15. POOH and RU casing crew and cementers. 16. MU and run a 4'/" liner as follows: a. 4'/" shoe b. 4'/", 12.6#, L-80, BTCM liner(+/-3,806')with swell packers and frac sleeves c. 4%", 12.6#,C-110,Hydril 521 liner(+/-600') d. Liner hanger 17. Once on bottom, circulate, then drop plug in drill pipe, circulate, land plug. 18. Pressure up and set liner hanger, continue to pressure up and release the running tool 19. Pick up 30 feet to expose setting dogs, slack off on drill string until setting dogs engage liner top, set down to set the ZXP liner top packer on top of the liner hanger. 20. PU 10 feet on drill pipe without pulling the seals out of the RS nipple and pressure test liner top packer, change over well to brine, POOH and LD 4" drill pipe 3S-620 APD Page 8 of 14 G I G I N A L Printed: 15-Oct-14 • Alption for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 21. Run 4%" completion tubing with gas lift mandrels, premier packer and seals. Set packer at+/-9,240' MD/5,178' TVD. 22. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the 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. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Diverter Position and Orientation 3S-620 APD Page 9 of 14 Printed: 15-Oct-14 ORIGINAL • • 3S-620wp1 2 DDI 6 . �5o Plan Summary SURVEY PROGRAM { Depth From Depth To Survey/Plan Tool 11 t 28.00 1000.00 3S-620wp12(Plan:3S-620) GYD-GC-SS loco 1000.00 2000.00 3S-620wp12(Plan:3S-620) MWD 1000.00 3160.71 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC 1500 3160.71 4660.71 3S-620wp12(Plan:3S-620) MWD 3160.71 9414.66 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC r 500C 9414.66 10914.66 3S-620wp12(Plan:3S-620) MWD 250( 9414.6613671.40 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC i\ o __ ... -25 CASING DETAILS TVD MD Name Size r - 2555.70 3160.71 10-3/4" x 13-1/2" 10-3/4 5205.70 9414.66 7-5/8" x 9-7/8" 7-5/8 -tc 5220.7013671.40 4-1/2"x 6-1/2" 4-1/2 1 0 V 00 0ry� 0 0 N opO �jS1 0 O Vl r 19; Top Morraine _ o i 010-3/4"x 13-1/2" :'5- - BalepPA1 nS�lost -5 11,40`. . o > o 00 00 cu ao 00 ., { 7-5/8"x..7/8" - a 4,,,,,:„, o0 o0 00 7-5/8"x 9-7/8" 4-1/2"x 6-1/2 C80 Campanidd50 C40 n0 4,000 0110 ( o 0 i 1 1 1 1 1I is I I i 1 f I 1 I I I 0 0 13500 7000 10500 14000 0 1500 3000 4500 6000 7 o0 8 900e 1106-1 10-3/4"x 13-1/2" Measured Depth Horizontal Departure 0 _ II I • a eine Far-Reaehing-Latera8 O _ #� I 330 IX� -e'•s 20»911(Mora.Far F zw 04 --- m - 400 - 600 60 � ` I aro - etem ��;� Y 3S-23ap09 30Am!0 `w60 aoa - , a I • ,aaa �,ri I 1 _ ▪ 4/1,,,, u 2600 270 � 90 8 30 II r' 1, . NCO - a. U• Ip� I,.+li rL 1 ,I�� .. 240 .4 •.. '•6!.i-A Witt rib 120 1 11 1 1 1 ' I 1 ' 1 1 i 1 1 1 I 1 1 1 z10 4 ►=prir8,P0eo 9. - /0600 0 1500 3000 4500 6000 7500 9000 18010600 11. SECTION DETAILS 'gym - ." Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 -27.70 0.00 0.00 5993619.98 1616103.83 0.00 0.00 0.00 - 1755.7 2 250.00 0.00 0.00 250.00 194.30 0.00 0.00 5993619.98 1616103.83 0.00 0.00 0.00 Base Permafrost 3 400.04 2.25 136.00 400.00 344.30 -2.12 2.05 5993617.86 1616105.87 1.50 136.00 -2.55 -2025.7 4 600.08 0.88 279.53 600.00 544.30 -4.69 3.27 5993615.28 1616107.08 1.50 170.00 -5.34 5 1752.50 29.69 279.53 1700.00 1644.30 45.05 -293.13 5993665.98 1615810.88 2.50 0.00 114.62 Top W.Sak 6 2706.61 63.00 276.09 2349.52 2293.82 131.69 -968.00 5993754.80 1615136.36 3.50 -5.57 361.96 7 7879.26 63.00 276.09 4698.05 4642.35 620.43 -5550.78 5994258.40 1610555.65 0.00 0.00 1944.86 8 9414.66 82.81 346.24 5205.70 5150.00 1548.03-6534.21 5995189.10 1609575.34 4.50 87.46 3082.81 -2655.7 9 9654.18 90.00 346.24 5220.70 5165.00 1780.07-6591.01 5995421.30 1609519.30 3.00 0.00 3321.70 3S-620 Heel 060914 SB 10 13671.40 90.00 346.24 5220.70 5165.00 5682.07 -7546.20 5999326.00 1608576.90 0.00 0.00 7338.88 3S-620 Toe 060914 SB C80 Campanian -3605.7 C50 -4095.7 C40 -53 p/Morraine 54 P/Torok §i HRZ Base HRZ Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 TM Depth Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Magnetic Model Date: 09-Jun-14 A Magnetic Declination: 19.19° North /Y: 5993619.98 System(SS)Reference: Mean Sea Level To convert a Magnetic Direction to a True Direction,Add 19.19°East Ground Level/Mud Line: 27.70 East/X: 1616103.83 Rig: Do n $, GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference • a ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-620 Plan: 3S-620 Plan: 3S-620wp12 Standard Planning Report 10 June, 2014 ORIGINAL • • \:.,.� �; �."1",=. Easting(4000 Win) .y I , , I I I I , I I I , 1 i 1 1 1 1 1 I I I I I I , I , I , I I 1 1 I I I I I I , , , I i i i i I i i , , I i I I , I I I l I I I , I I I , ,m l7, , I I 1 1 1 1 , I , , , , I I I I i I I I , _ AC wells ONLY Ku auk 3W Pad (NOT a spfder) P 3H-32 _ 3S-20wp11(Moraine Far Reaching Lateral) 3H-25Agp 3H-28A 3H-'c;H-25APB — Nit.NINIAPB2 3.-28APB1 — .--16 3S-620 .12 3S-06 ...F1-0AP:1 3S-06A 3S-09 - 3S-15 3S-1. z - 3S-17 0 A tS-14 ? o - 7 ON 3S-26 ea -211i \ i _S-08C 2 Z - 2 ii -`08B S-23 3 3S-08 c;.Ceigt 3S-21 3S-08C(Rig Projection) 3S-23A _e- L1 3S-24A 3S-2 .$$9(®Proj) - �Q-'.1AL2PB1 '3g9, •Iv 2-01 3er -21AL1 - 11 ,' -21A Easting(4000 ft/in) i \ kJ INAL • • Planning Report , .V.Mo�w.a..A:M r k Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well Plan:3S-620 ;' Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Project: Kuparuk River Unit MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: Plan:3S-620 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3S-620 Design: 3S-620wp12 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 3S Pad Site Position: Northing: 5,993,593.54ft Latitude: 70°23'38.428 N From: Map Easting: 1,616,487.07ft Longitude: 150°11'40.931 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.18° Well Plan:3S-620 Well Position +N/-S 0.00 ft Northing: 5,993,619.98 ft Latitude: 70°23'38.676 N +E/-W 0.00 ft Easting: 1,616,103.83 ft Longitude: 150°11'52.159 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 27.70 ft PWellbore Plan:3S-620 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 6/9/2014 19.19 80.92 57,586 Design 3S-620wp12 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(TVD) +N/-S Direction 28.00 0.00 0.00 346.00 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI-S +E/-W Rate Rate Rate TFO (ft) (°) (0) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) Target 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 400.04 2.25 136.00 400.00 -2.12 2.05 1.50 1.50 0.00 136.00 600.08 0.88 279.53 600.00 -4.69 3.27 1.50 -0.69 71.75 170.00 1,752.50 29.69 279.53 1,700.00 45.05 -293.13 2.50 2.50 0.00 0.00 2,706.61 63.00 276.09 2,349.52 131.69 -968.00 3.50 3.49 -0.36 -5.57 7,879.26 63.00 276.09 4,698.05 620.43 -5,550.78 0.00 0.00 0.00 0.00 9,414.66 82.81 346.24 5,205.70 1,548.03 -6,534.21 4.50 1.29 4.57 87.46 9,654.18 90.00 346.24 5,220.70 1,780.07 -6,591.01 3.00 3.00 0.00 0.00 3S-620 Heel 060914: 13,671.40 90.00 346.24 5,220.70 5,682.07 -7,546.20 0.00 0.00 0.00 0.00 3S-620 Toe 060914 6/10/2014 1:37:26PM Page 2 COMPASS 2003.16 Build 69 iUINlAL ! • 3S-620wp12 Plan View 5700- !!S, 221 4-1/2"x 6-1/2" 4750- 3800- rn 62850- 0 z 1- q900 7-5/8" x 9-7/8" - 10-3/4" x 13-1/2" 950- �� o 0 � o 0 O O O N ricp •a 0 I I 1 I I I I ----- -7600 -7600 -6650 -5700 -4750 -3800 -2850 -1900 -950 0 West(-)/East(+) (950 ft/in) ORIGINAL i • 3S-620wp12 Section View 0 0° 900— Base Permafrost 1000 Top W. Sak 10-3/4" x 13-1/2" 30° ' 1800— 2000-- c _ - C80 Campanian 0 6 x009" l`' 0 700— 000 C50 ik ro r 000 C40 > 003 3600 . _. 00 I— ti'' w u) X000 0 Top Torok Top Morraine 4500— Top HRZ 0 •eP N C20 0o 4-1/2"x 6-1/2" ,-- Base HRZ _.. 0 5400- 7-5/8"x 9-7/8" 04 d o o co 0 0 0 o j 0 0 0 0 1 ' 1 1 1 1 1 1 1 1 0 900 1800 2700 3600 4500 5400 6300 7200 Vertical Section at 346.00° (900 ft/in) ORIGINAL , , • • Planning Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well Plan:3S-620 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan 28+27.7 @ 55.70ft(Doyon 141) Project: Kuparuk River Unit MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: Plan:3S-620 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3S-620 Design: 3S-620wp12 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) 28.00 0.00 0.00 28.00 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 0.00 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP:1.5°/100'DLS,136°TF,for 150.04' 300.00 0.75 136.00 300.00 -0.24 0.23 -0.28 1.50 1.50 0.00 400.00 2.25 136.00 399.96 -2.12 2.05 -2.55 1.50 1.50 0.00 400.04 2.25 136.00 400.00 -2.12 2.05 -2.55 1.50 1.50 0.00 Adjust TF to 170°,for 200.04' 500.00 0.82 154.59 499.92 -4.17 3.72 -4.95 1.50 -1.43 18.60 600.00 0.88 279.49 599.92 -4.69 3.27 -5.34 1.50 0.06 124.90 600.08 0.88 279.53 600.00 -4.69 3.27 -5.34 1.50 1.34 43.80 Start 2.5°/100'DLS,0°TF,for 1152.42' 700.00 3.37 279.53 699.84 -4.08 -0.39 -3.86 2.50 2.50 0.00 800.00 5.87 279.53 799.51 -2.75 -8.34 -0.65 2.50 2.50 0.00 900.00 8.37 279.53 898.73 -0.69 -20.57 4.30 2.50 2.50 0.00 1,000.00 10.87 279.53 997.31 2.07 -37.05 10.98 2.50 2.50 0.00 1,100.00 13.37 279.53 1,095.07 5.55 -57.76 19.36 2.50 2.50 0.00 1,200.00 15.87 279.53 1,191.83 9.73 -82.66 29.44 2.50 2.50 0.00 1,300.00 18.37 279.53 1,287.39 14.60 -111.70 41.19 2.50 2.50 0.00 1,400.00 20.87 279.53 1,381.57 20.16 -144.82 54.59 2.50 2.50 0.00 1,500.00 23.37 279.53 1,474.20 26.39 -181.96 69.63 2.50 2.50 0.00 1,600.00 25.87 279.53 1,565.10 33.29 -223.05 86.26 2.50 2.50 0.00 1,700.00 28.37 279.53 1,654.09 40.83 -268.00 104.45 2.50 2.50 0.00 1,752.50 29.69 279.53 1,700.00 45.05 -293.13 114.62 2.50 2.50 0.00 Start 3.5°1100'DLS,-5.57°TF,for 954.11' 1,800.00 31.34 279.22 1,740.92 48.97 -316.93 124.19 3.50 3.48 -0.65 1,817.36 31.95 279.11 1,755.70 50.42 -325.92 127.77 3.50 3.49 -0.61 Base Permafrost 1,900.00 34.83 278.65 1,824.69 57.43 -370.84 145.44 3.50 3.49 -0.56 2,000.00 38.32 278.17 1,904.99 66.14 -429.78 168.15 3.50 3.49 -0.48 2,100.00 41.81 277.77 1,981.51 75.05 -493.51 192.22 3.50 3.49 -0.41 2,160.28 43.91 277.55 2,025.70 80.52 -534.15 207.35 3.50 3.49 -0.36 Top W.Sak 2,200.00 45.30 277.41 2,053.98 84.15 -561.80 217.56 3.50 3.49 -0.34 2,300.00 48.79 277.10 2,122.11 93.38 -634.39 244.08 3.50 3.49 -0.31 2,400.00 52.28 276.82 2,185.66 102.73 -711.01 271.69 3.50 3.49 -0.28 2,500.00 55.78 276.56 2,244.38 112.15 -791.38 300.27 3.50 3.49 -0.26 2,600.00 59.27 276.32 2,298.07 121.60 -875.20 329.72 3.50 3.49 -0.24 2,700.00 62.77 276.10 2,346.51 131.06 -962.15 359.94 3.50 3.49 -0.22 2,706.61 63.00 276.09 2,349.52 131.69 -968.00 361.96 3.50 3.49 -0.21 Hold for 5172.65' 2,800.00 63.00 276.09 2,391.93 140.51 -1,050.74 390.54 0.00 0.00 0.00 2,900.00 63.00 276.09 2,437.33 149.96 -1,139.34 421.14 0.00 0.00 0.00 3,000.00 63.00 276.09 2,482.73 159.41 -1,227.94 451.74 0.00 0.00 0.00 3,100.00 63.00 276.09 2,528.14 168.86 -1,316.53 482.34 0.00 0.00 0.00 3,160.71 63.00 276.09 2,555.70 174.60 -1,370.32 500.92 0.00 0.00 0.00 10-3/4"x 13-1/2" 3,200.00 63.00 276.09 2,573.54 178.31 -1,405.13 512.94 0.00 0.00 0.00 3,300.00 63.00 276.09 2,618.94 187.76 -1,493.72 543.54 0.00 0.00 0.00 3,380.96 63.00 276.09 2,655.70 195.41 -1,565.45 568.32 0.00 0.00 0.00 C80 Campanian 3,400.00 63.00 276.09 2,664.34 197.20 -1,582.32 574.14 0.00 0.00 0.00 6/10/2014 1:37:26PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL • • Planning Report .,. ,,-ro .„ , ... . ..�,'i a Database: " EDM Alaska Prod v16 Local Co-ordinate Reference: Well Plan:3S-620 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan 28+27.7 @ 5570f(Doyon 141) Project: Kuparuk River Unit MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: Plan.3S-620 Survey Calculation Method: Minimum Curvature Wellbore: Plan 3S-620 Design: 3S-620wp12 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) 3,500.00 63.00 276.09 2,709.75 206.65 -1,670.92 604.75 0.00 0.00 0.00 3,600.00 63.00 276.09 2,755.15 216.10 -1,759.51 635.35 0.00 0.00 0.00 3,700.00 63.00 276.09 2,800.55 225.55 -1,848.11 665.95 0.00 0.00 0.00 3,800.00 63.00 276.09 2,845.95 235.00 -1,936.71 696.55 0.00 0.00 0.00 3,900.00 63.00 276.09 2,891.36 244.45 -2,025.30 727.15 0.00 0.00 0.00 4,000.00 63.00 276.09 2,936.76 253.90 -2,113.90 757.75 0.00 0.00 0.00 4,100.00 63.00 276.09 2,982.16 263.34 -2,202.50 788.35 0.00 0.00 0.00 4,200.00 63.00 276.09 3,027.57 272.79 -2,291.09 818.96 0.00 0.00 0.00 4,300.00 63.00 276.09 3,072.97 282.24 -2,379.69 849.56 0.00 0.00 0.00 4,400.00 63.00 276.09 3,118.37 291.69 -2,468.28 880.16 0.00 0.00 0.00 4,500.00 63.00 276.09 3,163.77 301.14 -2,556.88 910.76 0.00 0.00 0.00 4,600.00 63.00 276.09 3,209.18 310.59 -2,645.48 941.36 0.00 0.00 0.00 4,700.00 63.00 276.09 3,254.58 320.04 -2,734.07 971.96 0.00 0.00 0.00 4,800.00 63.00 276.09 3,299.98 329.49 -2,822.67 1,002.56 0.00 0.00 0.00 4,900.00 63.00 276.09 3,345.39 338.93 -2,911.27 1,033.16 0.00 0.00 0.00 5,000.00 63.00 276.09 3,390.79 348.38 -2,999.86 1,063.77 0.00 0.00 0.00 5,100.00 63.00 276.09 3,436.19 357.83 -3,088.46 1,094.37 0.00 0.00 0.00 5,200.00 63.00 276.09 3,481.59 367.28 -3,177.05 1,124.97 0.00 0.00 0.00 5,300.00 63.00 276.09 3,527.00 376.73 -3,265.65 1,155.57 0.00 0.00 0.00 5,400.00 63.00 276.09 3,572.40 386.18 -3,354.25 1,186.17 0.00 0.00 0.00 5,473.35 63.00 276.09 3,605.70 393.11 -3,419.23 1,208.62 0.00 0.00 0.00 C50 5,500.00 63.00 276.09 3,617.80 395.63 -3,442.84 1,216.77 0.00 0.00 0.00 5,600.00 63.00 276.09 3,663.20 405.07 -3,531.44 1,247.37 0.00 0.00 0.00 5,700.00 63.00 276.09 3,708.61 414.52 -3,620.04 1,277.98 0.00 0.00 0.00 5,800.00 63.00 276.09 3,754.01 423.97 -3,708.63 1,308.58 0.00 0.00 0.00 5,900.00 63.00 276.09 3,799.41 433.42 -3,797.23 1,339.18 0.00 0.00 0.00 6,000.00 63.00 276.09 3,844.82 442.87 -3,885.83 1,369.78 0.00 0.00 0.00 6,100.00 63.00 276.09 3,890.22 452.32 -3,974.42 1,400.38 0.00 0.00 0.00 6,200.00 63.00 276.09 3,935.62 461.77 -4,063.02 1,430.98 0.00 0.00 0.00 6,300.00 63.00 276.09 3,981.02 471.21 -4,151.61 1,461.58 0.00 0.00 0.00 6,400.00 63.00 276.09 4,026.43 480.66 -4,240.21 1,492.19 0.00 0.00 0.00 6,500.00 63.00 276.09 4,071.83 490.11 -4,328.81 1,522.79 0.00 0.00 0.00 6,552.57 63.00 276.09 4,095.70 495.08 -4,375.39 1,538.88 0.00 0.00 0.00 C40 6,600.00 63.00 276.09 4,117.23 499.56 -4,417.40 1,553.39 0.00 0.00 0.00 6,700.00 63.00 276.09 4,162.64 509.01 -4,506.00 1,583.99 0.00 0.00 0.00 6,800.00 63.00 276.09 4,208.04 518.46 -4,594.60 1,614.59 0.00 0.00 0.00 6,900.00 63.00 276.09 4,253.44 527.91 -4,683.19 1,645.19 0.00 0.00 0.00 7,000.00 63.00 276.09 4,298.84 537.35 -4,771.79 1,675.79 0.00 0.00 0.00 7,100.00 63.00 276.09 4,344.25 546.80 -4,860.39 1,706.39 0.00 0.00 0.00 7,200.00 63.00 276.09 4,389.65 556.25 -4,948.98 1,737.00 0.00 0.00 0.00 7,300.00 63.00 276.09 4,435.05 565.70 -5,037.58 1,767.60 0.00 0.00 0.00 7,400.00 63.00 276.09 4,480.45 575.15 -5,126.17 1,798.20 0.00 0.00 0.00 7,500.00 63.00 276.09 4,525.86 584.60 -5,214.77 1,828.80 0.00 0.00 0.00 7,600.00 63.00 276.09 4,571.26 594.05 -5,303.37 1,859.40 0.00 0.00 0.00 7,700.00 63.00 276.09 4,616.66 603.49 -5,391.96 1,890.00 0.00 0.00 0.00 7,800.00 63.00 276.09 4,662.07 612.94 -5,480.56 1,920.60 0.00 0.00 0.00 7,879.26 63.00 276.09 4,698.05 620.43 -5,550.78 1,944.86 0.00 0.00 0.00 Start 4.5°/100'DLS,87.46°TF,for 1535.4' 7,900.00 63.04 277.13 4,707.46 622.56 -5,569.14 1,951.36 4.50 0.22 5.04 8,000.00 63.37 282.16 4,752.56 637.52 -5,657.10 1,987.16 4.50 0.33 5.03 8,100.00 63.87 287.15 4,797.02 660.19 -5,743.73 2,030.11 4.50 0.50 4.99 6/10/2014 1:37:26PM Page 4 COMPASS 2003.16 Build 69 ,. 4 • . Planning Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well Plan:3S-620 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Project: Kuparuk River Unit MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: Plan:3S-620 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3S-620 Design: 3S-620wp12 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (°) (0) (ft) (ft) (C) (ft) (°/100ft) (°/100ft) (°/100ft) 8,200.00 64.54 292.10 4,840.55 690.42 -5,828.50 2,079.96 4.50 0.67 4.94 8,300.00 65.38 296.98 4,882.90 728.04 -5,910.88 2,136.39 4.50 0.84 4.88 8,400.00 66.37 301.79 4,923.79 772.82 -5,990.36 2,199.06 4.50 0.99 4.81 8,500.00 67.50 306.52 4,962.99 824.46 -6,066.46 2,267.58 4.50 1.14 4.73 8,600.00 68.78 311.17 5,000.24 882.67 -6,138.71 2,341.54 4.50 1.27 4.65 8,700.00 70.17 315.74 5,035.31 947.07 -6,206.66 2,420.46 4.50 1.40 4.57 8,800.00 71.69 320.22 5,068.00 1,017.27 -6,269.89 2,503.88 4.50 1.51 4.49 8,900.00 73.30 324.63 5,098.10 1,092.84 -6,328.01 2,591.26 4.50 1.61 4.40 9,000.00 75.01 328.96 5,125.41 1,173.32 -6,380.66 2,682.09 4.50 1.71 4.33 9,100.00 76.79 333.22 5,149.79 1,258.20 -6,427.53 2,775.78 4.50 1.79 4.26 9,200.00 78.65 337.41 5,171.06 1,346.96 -6,468.31 2,871.77 4.50 1.86 4.20 9,300.00 80.56 341.55 5,189.12 1,439.06 -6,502.77 2,969.47 4.50 1.91 4.14 9,400.00 82.52 345.65 5,203.83 1,533.92 -6,530.68 3,068.27 4.50 1.96 4.09 9,414.66 82.81 346.24 5,205.70 1,548.03 -6,534.21 3,082.81 4.50 1.99 4.07 Start 3°/100'DLS,0°TF,for 239.52'-Top Morraine-7-5/8"x 9-7/8" 9,500.00 85.37 346.24 5,214.48 1,630.47 -6,554.39 3,167.69 3.00 3.00 0.00 9,600.00 88.37 346.24 5,219.93 1,727.45 -6,578.13 3,267.53 3.00 3.00 0.00 9,654.18 90.00 346.24 5,220.70 1,780.07 -6,591.01 3,321.70 3.00 3.00 0.00 Hold for 4017.21'-3S-620 Heel 060914 SB 9,700.00 90.00 346.24 5,220.70 1,824.57 -6,601.91 3,367.52 0.00 0.00 0.00 9,800.00 90.00 346.24 5,220.70 1,921.70 -6,625.68 3,467.52 0.00 0.00 0.00 9,900.00 90.00 346.24 5,220.70 2,018.84 -6,649.46 3,567.52 0.00 0.00 0.00 10,000.00 90.00 346.24 5,220.70 2,115.97 -6,673.24 3,667.52 0.00 0.00 0.00 10,100.00 90.00 346.24 5,220.70 2,213.10 -6,697.02 3,767.52 0.00 0.00 0.00 10,200.00 90.00 346.24 5,220.70 2,310.23 -6,720.79 3,867.52 0.00 0.00 0.00 10,300.00 90.00 346.24 5,220.70 2,407.36 -6,744.57 3,967.52 0.00 0.00 0.00 10,400.00 90.00 346.24 5,220.70 2,504.50 -6,768.35 4,067.51 0.00 0.00 0.00 10,500.00 90.00 346.24 5,220.70 2,601.63 -6,792.13 4,167.51 0.00 0.00 0.00 10,600.00 90.00 346.24 5,220.70 2,698.76 -6,815.90 4,267.51 0.00 0.00 0.00 10,700.00 90.00 346.24 5,220.70 2,795.89 -6,839.68 4,367.51 0.00 0.00 0.00 10,800.00 90.00 346.24 5,220.70 2,893.03 -6,863.46 4,467.51 0.00 0.00 0.00 10,900.00 90.00 346.24 5,220.70 2,990.16 -6,887.23 4,567.51 0.00 0.00 0.00 11,000.00 90.00 346.24 5,220.70 3,087.29 -6,911.01 4,667.51 0.00 0.00 0.00 11,100.00 90.00 346.24 5,220.70 3,184.42 -6,934.79 4,767.51 0.00 0.00 0.00 11,200.00 90.00 346.24 5,220.70 3,281.55 -6,958.57 4,867.51 0.00 0.00 0.00 11,300.00 90.00 346.24 5,220.70 3,378.69 -6,982.34 4,967.51 0.00 0.00 0.00 11,400.00 90.00 346.24 5,220.70 3,475.82 -7,006.12 5,067.51 0.00 0.00 0.00 11,500.00 90.00 346.24 5,220.70 3,572.95 -7,029.90 5,167.50 0.00 0.00 0.00 11,600.00 90.00 346.24 5,220.70 3,670.08 -7,053.68 5,267.50 0.00 0.00 0.00 11,700.00 90.00 346.24 5,220.70 3,767.21 -7,077.45 5,367.50 0.00 0.00 0.00 11,800.00 90.00 346.24 5,220.70 3,864.35 -7,101.23 5,467.50 0.00 0.00 0.00 11,900.00 90.00 346.24 5,220.70 3,961.48 -7,125.01 5,567.50 0.00 0.00 0.00 12,000.00 90.00 346.24 5,220.70 4,058.61 -7,148.79 5,667.50 0.00 0.00 0.00 12,100.00 90.00 346.24 5,220.70 4,155.74 -7,172.56 5,767.50 0.00 0.00 0.00 12,200.00 90.00 346.24 5,220.70 4,252.87 -7,196.34 5,867.50 0.00 0.00 0.00 12,300.00 90.00 346.24 5,220.70 4,350.01 -7,220.12 5,967.50 0.00 0.00 0.00 12,400.00 90.00 346.24 5,220.70 4,447.14 -7,243.90 6,067.50 0.00 0.00 0.00 12,500.00 90.00 346.24 5,220.70 4,544.27 -7,267.67 6,167.49 0.00 0.00 0.00 12,600.00 90.00 346.24 5,220.70 4,641.40 -7,291.45 6,267.49 0.00 0.00 0.00 12,700.00 90.00 346.24 5,220.70 4,738.53 -7,315.23 6,367.49 0.00 0.00 0.00 12,800.00 90.00 346.24 5,220.70 4,835.67 -7,339.01 6,467.49 0.00 0.00 0.00 12,900.00 90.00 346.24 5,220.70 4,932.80 -7,362.78 6,567.49 0.00 0.00 0.00 13,000.00 90.00 346.24 5,220.70 5,029.93 -7,386.56 6,667.49 0.00 0.00 0.00 6/10/2014 1:37:26PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL • • Planning Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference:1, Well Plan:3S-620 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan.28+27.7©55.70ft(Doyon 141) Project: Kuparuk River Unit MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: Plan:3S-620 Survey Calculation Method: Minimum Curvature Wellbore: Plan.3S-620 Design: 3S-620wp12 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (0) (0) (ft) (ft) (ft) (ft) (°/100ft) (°/100ft) (0/100ft) 13,100.00 90.00 346.24 5,220.70 5,127.06 -7,410.34 6,767.49 0.00 0.00 0.00 13,200.00 90.00 346.24 5,220.70 5,224.19 -7,434.12 6,867.49 0.00 0.00 0.00 13,300.00 90.00 346.24 5,220.70 5,321.33 -7,457.89 6,967.49 0.00 0.00 0.00 13,400.00 90.00 346.24 5,220.70 5,418.46 -7,481.67 7,067.49 0.00 0.00 0.00 13,500.00 90.00 346.24 5,220.70 5,515.59 -7,505.45 7,167.49 0.00 0.00 0.00 13,600.00 90.00 346.24 5,220.70 5,612.72 -7,529.23 7,267.48 0.00 0.00 0.00 13,671.40 90.00 346.24 5,220.70 5,682.07 -7,546.20 7,338.88 0.00 0.00 0.00 TD:13671.4'MD,5220.7'TVD-3S-620 Toe 060914 SB Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 3S-620 Heel 060914 SB 0.00 0.00 5,220.70 1,780.07 -6,591.01 5,995,421.30 1,609,519.30 70°23'56.155 N 150°15'5.246 W -plan hits target center -Circle(radius 100.00) 3S-620 Toe 060914 SB 0.00 0.00 5,220.70 5,682.07 -7,546.20 5,999,326.00 1,608,576.90 70°24'34.523 N 150°15'33.344 W -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 3,160.71 2,555.70 10-3/4"x 13-1/2" 10-3/4 13-1/2 9,414.66 5,205.70 7-5/8"x 9-7/8" 7-5/8 9-7/8 13,671.40 5,220.70 4-1/2"x6-1/2" 4-1/2 6-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (ft) Name Lithology (°) (°) 1111111ir' 9,414.66 5,205.70 Top Morraine 5,665.70 Base HRZ 5,625.70 C20 6,552.57 4,095.70 C40 3,380.96 2,655.70 C80 Campanian 2,160.28 2,025.70 Top W.Sak 5,345.70 Top Torok 1,817.36 1,755.70 Base Permafrost 5,473.35 3,605.70 C50 5,495.70 Top HRZ 6/10/2014 1:37:26PM Page 6 COMPASS 2003.16 Build 69 ORIGINAL • • • Planning Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well Plan:3S-620 \,am. Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Project: Kuparuk River Unit MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site: Kuparuk 3S Pad North Reference: True Well: Plan 3S-620 Survey Calculation Method: Minimum Curvature Wellbore: Plan:3S-620 Design: 3S-620wp12 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 250.00 250.00 0.00 0.00 KOP:1.5°/100'DLS,136°TF,for 150.04' 400.04 400.00 -2.12 2.05 Adjust TF to 170°,for 200.04' 600.08 600.00 -4.69 3.27 Start 2.5°/100'DLS,0°TF,for 1152.42' 1,752.50 1,700.00 45.05 -293.13 Start 3.5°/100'DLS,-5.57°TF,for 954.11' 2,706.61 2,349.52 131.69 -968.00 Hold for 5172.65' 7,879.26 4,698.05 620.43 -5,550.78 Start 4.5°/100'DLS,87.46°TF,for 1535.4' 9,414.66 5,205.70 1,548.03 -6,534.21 Start 3°/100'DLS,0°TF,for 239.52' 9,654.18 5,220.70 1,780.07 -6,591.01 Hold for 4017.21' 13,671.40 5,220.70 5,682.07 -7,546.20 TD:13671.4'MD,5220.7 TVD 6/10/2014 1:37:26PM Page 7 COMPASS 2003.16 Build 69 ORIGINAL • • ConocoPhillips (Alaska) Inc. -Ku p2 Kuparuk River Unit Kuparuk 3S Pad Plan: 3S-620 Plan: 3S-620 3S-620wp12 Anticollision Summary Report 10 June, 2014 ORLGIt\ AL 0 • Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:35-620 Project: Kuparuk River Unit TVD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Reference Site: Kuparuk 3S Pad MD Reference: Plan:28+27.7 @ 55.708(Doyon 141) Site Error: 0.00ft North Reference: True Reference Well: Plan:3S-620 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:3S-620 Database: EDM Alaska Prod v16 Reference Design: 3S-620wp12 Offset TVD Reference: Offset Datum Reference 3S-620wp12 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,564.348 Error Surface: Elliptical Conic Warning Levels Evaluated at: 2.00 Sigma Survey Tool Program Date 6/10/2014 From To (ft) (ft) Survey(Wellbore) Tool Name Description 28.00 1,000.00 3S-620wp12(Plan:3S-620) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,000.00 3S-620wp12(Plan:3S-620) MWD MWD-Standard 1,000.00 3,160.71 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,160.71 4,660.71 3S-620wp12(Plan:3S-620) MWD MWD-Standard 3,160.71 9,414.66 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9,414.66 10,914.66 3S-620wp12(Plan:3S-620) MWD MWD-Standard 9,414.66 13,671.40 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/10/2014 1:38:20PM �Pao 5..J2ORLNAL COMPASS 2003.16 Build 69 Anticollision Summary Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:3S-620 Project: Kuparuk River Unit TVD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Reference Site: Kuparuk 3S Pad MD Reference: Plan:28+27.7 @ 55.70ft(Doyon 141) Site Error: 0.00ft North Reference: True Reference Well: Plan:3S-620 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan:3S-620 Database: EDM Alaska Prod v16 Reference Design: 3S-620wp12 Offset TVD Reference: Offset Datum Summary Reference Offset Distance Measured Measured Between Between Site Name Depth Depth Centres Ellipses Separation Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Factor Warning *Kuparuk 3S Pad 3S-23-3S-23-3S-23 200.49 200.00 58.51 55.00 16.642 CC 3S-23-3S-23-3S-23 250.48 250.00 58.69 54.38 13.608 ES,SF 3S-23-Plan 3S-23 L1-3S-23 L1 (Rig Proj) 222.99 225.00 58.52 54.04 13.068 CC 3S-23-Plan 3S-23 L1-3S-23 L1 (Rig Proj) 272.79 275.00 59.01 53.61 10.914 ES,SF Kuparuk 3S Pad 3S-08-3S-08-3S-08 403.90 400.00 239.23 232.56 35.856 CC 3S-08-3S-08-3S-08 427.76 425.00 239.31 232.26 33.956 ES,SF 3S-08-3S-08A-3S-08A 403.90 400.00 239.23 232.56 35.856 CC 3S-08-3S-08A-3S-08A 427.76 425.00 239.31 232.26 33.956 ES,SF 3S-08-3S-08B-3S-08B 403.90 400.00 239.23 232.56 35.856 CC 3S-08-3S-08B-3S-08B 427.76 425.00 239.31 232.26 33.956 ES,SF 3S-08-3S-08C-3S-08C 404.95 400.00 239.23 232.49 35.512 CC 3S-08-3S-08C-3S-08C 428.81 425.00 239.32 232.20 33.648 ES,SF 3S-09-35-09-3S-09 28.00 28.80 219.88 218.87 217.501 CC 3S-09-3S-09-3S-09 224.17 225.00 221.24 217.21 54.899 ES,SF 3S-10-3S-10-3S-10 99.40 100.00 199.60 197.53 96.368 CC 33-10-3S-10-3S-10 199.38 200.00 200.38 196.62 53.282 ES,SF 3S-14-3S-14-3S-14 401.57 400.00 119.51 112.87 17.996 CC 33-14-3S-14-3S-14 450.41 450.00 120.03 112.58 16.121 ES,SF 3S-15-3S-15-3S-15 498.27 500.00 93.98 85.53 11.120 CC 3S-15-3S-15-3S-15 547.35 550.00 94.44 85.18 10.203 ES,SF 3S-16-3S-16-3S-16 499.30 500.00 78.42 70.24 9.583 CC 3S-16-3S-16-3S-16 573.35 575.00 78.88 69.65 8.540 ES,SF 3S-17-3S-17-3S-17 399.14 400.00 59.59 52.27 8.141 CC 3S-17-3S-17-3S-17 448.42 450.00 59.83 51.86 7.507 ES,SF 3S-17-3S-17A-3S-17A 399.14 400.00 59.59 52.27 8.141 CC 3S-17-3S-17A-3S-17A 448.42 450.00 59.83 51.86 7.507 ES,SF 3S-18-3S-18-3S-18 598.22 600.00 21.88 11.95 2.204 No Errors,CC 3S-18-3S-18-3S-18 623.00 625.00 22.09 11.70 2.126 No Errors,ES,SF 3S-19-3S-19-3S-19 399.36 400.00 13.04 6.15 1.894 No Errors,CC 3S-19-3S-19-3S-19 424.19 425.00 13.15 5.91 1.817 No Errors,ES,SF 3S-21-3S-21-3S-21 73.75 75.00 20.11 18.42 11.917 CC 3S-21-3S-21-3S-21 248.69 250.00 21.16 16.13 4.207 ES,SF 3S-22-3S-22-3S-22 298.33 300.00 38.50 33.31 7.429 CC 3S-22-3S-22-3S-22 1,413.28 1,400.00 43.19 20.12 1.872 No Errors,ES,SF 3S-23-3S-23-3S-23 200.49 200.00 58.51 54.43 14.328 CC 3S-23-3S-23-3S-23 275.27 275.00 59.06 53.59 10.783 ES,SF 3S-23-3S-23A-3S-23A 223.04 225.00 58.52 53.99 12.930 CC 3S-23-3S-23A-3S-23A 272.84 275.00 59.01 53.57 10.848 ES,SF 3S-24-3S-24-3S-24 28.00 28.38 80.28 79.27 79.413 CC 3S-24-3S-24-3S-24 174.61 175.00 81.22 77.65 22.746 ES,SF 3S-24-3S-24A-3S-24A 28.00 28.40 80.28 79.27 79.413 CC 3S-24-3S-24A-3S-24A 174.59 175.00 81.22 77.65 22.748 ES,SF 3S-26-3S-26-3S-26 1,228.45 1,225.00 47.99 28.40 2.449 No Errors,CC,ES,SF 3S-26-PALM 1-PALM 1 1,228.45 1,225.00 47.99 28.40 2.449 No Errors,CC,ES,SF Plan:3S-620-Plan:3S-20(Moraine Far Reaching Later 400.04 400.04 0.00 -6.71 0.000 Major Risk,CC Plan:3S-620-Plan:3S-20(Moraine Far Reaching Later 624.99 625.00 1.22 -8.87 0.121 No Errors,ES,SF Plan:3S-620-Plan:3S-20(Vertical)-3S-20wp09 250.00 250.00 0.00 -4.62 0.000 Major Risk,CC Plan:3S-620-Plan:3S-20(Vertical)-3S-20wp09 9,654.18 9,600.00 6.82 -98.37 0.065 Minor 1/10 No Errors,ES,S CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/10/2014 1:38:20PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL - • 0 • conocoF't,i��ips g Alaska :g 3S-620wp 12 Schlumberger R oe a` 0 iS1 z! Q gn Ga & ^,OM I ("1), m N wS E. 0 W CO _ 1 diiII llll u,11d al ' // 1 300 �11111111ii����►111 lilt � I 1 i� 11 I Il 11�III ���� ��Il�I II 1 iiomgrs 1;111 1 , / L,1 ias mpIIIPr 11,,1 11 ,. ,.) ,I ��r to 1 j li r 1� 0 — nnnnpj11111 11111 9111 2 11'1 / �I' 11 Ards a� 1i 'I n n I N 150 L 1;Iid11111111111!r11��i,11 "I I,'' i illllIliiIl0 11111 cIl i1 1 111. �_ ..... .t I !;!� 11�1!IIO � lip.. ml till 111 ;��Iljil Gill 1111 Eq velant Magnetic Diistan•ii' - - -- .1111111111111111. 11i, 11r 0 I I I I I I 1 I I I I I I I I I I 1 I I 1 I I 0 1500 3000 4500 6000 7500 9000 Measured Depth Displayed Interval could be less than entire range: 28.00 To 13671.40 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 13671.40 Results Limited By: Centre Distance: 1564.34 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1000.00 3S-620wp12(Plan:3S-620) GYD-GC-SS 1000.00 2000.00 3S-620wp12(Plan:3S-620) MWD 1000.00 3160.71 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC 3160.71 4660.71 3S-620wp12(Plan:3S-620) MWD 3160.71 9414.66 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC 9414.66 10914.66 3S-620wp12(Plan:3S-620) MWD 9414.66 13671.40 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2555.70 3160.71 10-3/4" x 13-1/2" 10-3/4 5205.70 9414.66 7-5/8"x 9-7/8" 7-5/8 5220.70 13671.40 4-1/2"x 6-1/2" 4-1/2 LEGEND 1 -e- 3S-15,3S-15,3S-15 V4 —X— 3S-23,3S-23A,3S-23A V3 3S-23 L1(Rig Proj)VO -8- 3S-16,3S-16,3S-16 V4 --e— 3S-24,3S-24,3S-24 V9 5 -A.- 3S-17,3S-17,3S-17 V6 —X— 3S-24,3S-24A,3S-24A V1 I V3 —X— 3S-17,3S-17A,3S-17A V2 -a— 3S-26,3S-26,3S-26 V3 I V4 -h-- 3S-18,3S-18,3S-18 V4 3S-26,PALM 1,PALM 1 V2 VO — 3S-19,3S-19,3S-19 V4 -e- Plan:3S-620,Plan:3S-20(Moraine Far Reaching Lateral),3S-2058 2 -8- 3S-21,3S-21,3S-21 V4 -e- Plan:3S-620,Plan:3S-20(Vertical),3S-20wp09 VO 3 --e- 3S-22,3S-22,3S-22 V7 -9- 3S-620wp12 >- —At— 3S-23,3S-23,3S-23 V4 JRIGINAL i • Conoco hillips3S@620wp 12 Schlumberger Alaska Et4 a d C o me N A r. - S ' N d)fn ly9 n tN+l M CVI /V3 4..3.111111 IF , 4 0 ii 70 1"' jilt ' ai / / ls $ fo 1111:10114 11101" 1 / /. i / AI " )1 '4 - ri ,_) i , ro r 11 , ,e ., N 35 '1141111111 iiiiiiillitallINIII._.- CD Fr 11/1114111111V 1 lir �r Equlvelant Magnetle gats � Al��� ��_ -----\ I 111111110 pr I I I I I i 1 I I I I I I I I I I I I 0 500 1000 1500 2000 2500 3000 350C Measured Depth Displayed Interval could be less than entire range: 28.00 To 13671.40 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 28.00 To 13671.40 Results Limited By: Centre Distance: 1564.34 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 28.00 1000.00 3S-620wp12(Plan:3S-620) GYD-GC-SS 1000.00 2000.00 3S-620wp12(Plan:3S-620) MWD 1000.00 3160.71 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC 3160.71 4660.71 3S-620wp12(Plan:3S-620) M W D 3160.71 9414.66 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC 9414.66 10914.66 3S-620wp12(Plan:3S-620) MWD 9414.66 13671.40 3S-620wp12(Plan:3S-620) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2555.70 3160.71 10-3/4" x 13-1/2" 10-3/4 5205.70 9414.66 7-5/8"x 9-7/8" 7-5/8 5220.70 13671.40 4-1/2"x6-1/2" 4-1/2 LEGEND 1 -0- 3S-15,3S-15,35-15 V4 —X— 3S-23,3S-23A,3S-23A V3 3S-23 L1(Rig Prot)VO $ 3S-16,3S-16,3S-16 V4 -0- 3S-24,35-24,3S-24 V9 5 -g- 3S-17,3S-17,3S-17 V6 —X— 3S-24,3S-24A,3S-24A V1 t V3 — 3S-17,3S-17A,3S-17A V2 —1— 3S-26,3S-26,3S-26 V3 I V4 -g- 3S-18,3S-18,3S-18 V4 3S-26,PALM 1,PALM 1 V2 VO —I— 3S-19,3S-19,3S-19 V4 -0- Plan:3S-620,Plan:3S-20(Moraine Far Reaching Lateral),3S-201g 2 -9- 3S-21,3S-21,3S-21 V4 -e- Plan:3S-620,Plan:3S-20(Vertical),3S-20wp09 VO 3 -e- 3S-22,3S-22,3S-22 V1 -s- 35-620wp12 2 —A— 3S-23,3S-23,3S-23 V4 ORIGINAL Sec D Inc Azi TVD +N/-S +E/-W DLeg TFace Sec Target 1 00 0.00 0.00 26.00 0.00 0.00 0.00 0.0000 28 250 3S-620W 12 .00 0.00 0.00 250.00 0.00 0.00 0.00 0.002.56 250 400 „ 2 r 3 400.04 2.25 136.00 400.00 -2.12 2.05 1.50 136.00 28.00 To 13671.40 4 752.58 9.69 279.53 600.00 5.09 3.27 1.50 170.00 5.62 400 60U 5 1752.50 29.69 279.53 1700.00 45.05 -293.13 2.50 0.00 114.62 6 -2706.61 63.00 276.09 2349.52 131.69 -968.00 3.50 -5.57 361.96- 7 7879.26 63.00 276.09 4698.05 620.43 -5550.78 0.00 0.00 1944.86 8 9414.66 82.81 346.24 5205.70 1548.03 -6534.21 4.50 87.46 3082.81 600 800 13:44,June 10 2014 9 9654.18 90.00 346.24 5220.70 1780.07 -6591.01 3.00 0.00 3321.70 30-620 Heel 060914 SB 10 13671.40 90.00 346.24 5220.70 5682.07 -7546.20 0.00 0.00 7338.88 3S-620 Tae 060914 SB 800 1000 C LOBAL FILTER APPLIED: A 1000 1200 1200 -____ 1400 Dep Fran Deptl,To 05-02 lPlan Tool 1 400 1 600 26.00 1000.00 3o-Gao 2012(Plan:35620) Gy6GCSS 00.00 2000.00 3S-620wp12(Ran:35620) MWD 00.00 3160.71 35.620wp12(Ran:35620) MWD.IFFI-AK(CA2 SC 60.71 4660.71 3S-620wp12(Ran:36620) MWD 1600 2100 ;60.71 9414.66 36-620wp12(Ran:36620) MWD.IFA-AK-CA3 SC 14.66 1091466 35-6201,12(Ran:36620) MWD 14.66 1367140 35620wp12(Plan:35-620) MWD.IFFI-AK-C32 SC 2100 2600 CASING DETAILS 2600 3100 ND MD Name Size _ _ _ 2555.70 3160.71 103/4"x 13-1/2" 10-3/4 3100 ` _ 3600 5205.70 9414.66 7-5/8"x 9-7/8" 7-5/8 5220.70 13671.40 4-1/2"x8-1/2" 4-1/2 3600 4100 4100 4600 4600 - 5100 0/ 61.3 0 5100 5600 7,,, --��` 5600 6600 _ ,tr: mi B ___�_ ,_, �� 0 6600 7600 -30/330 \ 44,44 N.r' 21 1 I,i C`E >'r 7600 8600 '4:-::Z.- ' ,.. .'''' ,� � _I ` @'�@ Iq 8600 9600 ✓���� : g , T-1. ` a@ `i� 9600 10600 /. __-tZ�.� �s ��%' , - � � �� �'�1:�@1�������� 10600 11700 i%�� =z� � �l);....11;-'7:1'41_1:r.....\- / 7 •.ea .7541 ` • 11700 12700 l .rte �. 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F vit rtia. -ogni,,fiiiiorogo_ 1,= -180/180 23.35-2364 $ 36 4- 35.10, 36 .s. Nan adonru e.36201.,n(MorelneFarRe_ yee $ 35 -tr. a Is,33 Is,aaan Va $ R .30.20(68847.3szo�w 63 PA 0813, -� 36 �c 6 $ 390266472 -08CVe >F 6 6 69862 "o- .18,39.3,36.164 3924A,an 6, ORIGINAL • • 13:45,June 10 2014 Easting(3000 ft/in) I S20M IReaching 1I 11I11111111111FFIIIi � � 111111 � � � � 1111 11 � � � � 111111 � � � , 1111113 - wp1l( orane Far eac mg Latera) AC wells ONLY - (NOT a spider) 3S-620wp 3S-09 - 3S-15 3S-10 - 3S-17 - .03 3S-14 - _ o _ - 5 M= 3S-26 -o S-20w.s• c- 3S-17A a o S-1: 444.,4( 3 �ad Z-g 3S- -22 AS-23 3S-08 - 3S-08C - 3S-21 3S-23A - 3S-24A - gtits oj) 111 352II (ri 111 , 111 , , i , , 1 , 1 , 1 , , I , , , , 111111111111111111111IIIF11I11I1111I1111I1111I Easting(3000 ft/in) O1GINAL • Action for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 3S-620 Drilling Hazards Summary 131/2" Hole / 1034" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9'/8" Hole / 7%" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 61/2" Hole / 41/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 3S-620 APD Page 10 of 14 ORIGINAL Printed: 15-Oct-14 • Allition for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 3S-620 well plan. Drilling Area Risks: Reservoir Pressure: The Moraine formation has not been exploited as of yet and therefore no injection of any kind has been implemented for secondary recovery. The formation pressure is still and virgin pressures and should not pose a problem for the drilling of this well. Lower Shale Stability: Unstable shale and ash in the intermediate could require higher mud weights to stabilize due to the high hole angle required to drill the well. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 3S-620 APD Page 11 of 14 Printed: 15-Oct-14 ri R 1 G 1 N A L • • Alktion for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 Attachment 3— Proposed Well Schematic Grass Roots Horizontal Multi-Stacie Frac'd Producer COnOCOPIIIIIIPS Final Valiellhore Schematic PAC 4-1,i Tee up jciritr 1)14 1G,PA rrkirescri ay.:11M t T. . eqUirrlent: New Existinti Conductor: 1662.6#HW @ 106' • Spud Mud 9 6 PPG 3%°Caw*OS IIIPP•34113* 13-102"Surface Hole 4 z I'MING 111 Surface Casino: 10-3/4"45 5#L-8O Hydril 563 3,16V MD 2,556'WO 46° 1'KISbIt . :•: :•:::•:::•::::: :::•:.:•: :•:.:•:.: ?4P 0*. : : : : : : : : : : : : : : • : : : : : : 9-7/8"Intermediate Hole, 4 . 1 1 IMMO pi Tubing: 4-Vz" 12.6#1-80 1BTM to surface 6Alrnato1 frçi1,+0.extrrient Ct. fi Wi (tAXIMDatiM tr.D(A() ram II4 h' Bober riumm 4,41) 4!A'rAtre rI nrt. s.-rt•hnern• 27CP ir.LY(141 Ati 111-SNT4tet, Intermediate Casing Topset with Bonzal: A • 7-5/8"29,7#L-80&bottom IN"l"iUSS 39#- Hydril 563 Gormection5 - 6-112"ProdH-,;nn Tc Pranq,,, 4,e'r.,T.,5 21.9S'P.1) 9 415'MD/5206“TVD 83” • :•••••••••••••:•:::•:::•:•.E,•.•,•. .•:•:•: •••••••••.•.•.•.•.•...•.•.•.• .•.•.•.•.•.•.•.•.•.•.•.•.•.•.•.•.•.•.•.•. .•.•.•.•.• ;151•10,1-60E11:::::: 0431::::::::::::. • ••••••••••••••••••••••••:•:•• ••••••••••••••••••:•:•:••••••••••:•:•:•" • •:•:•:•:•• 0 0 0 0 0 , •:•:•:•:•:•:•:::::•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•. : :•:•:•:•:•:':•:•:•:':•:':':':•:':•: : : : : :.:::.: : •• dUtIthLU92 . . 10 13 71 MDt21tVP G -44,2 3S-620 APD Page 12 of 14 Printed: 15-Oct-14 ORIGINAL • Aption for Permit to Drill,Well 3S-620 Saved: 15-Oct-14 Attachment 4—Cement Summary 103/4" Surface Casing Cement Job Cement 10%" casing from shoe @ 3,161' MD to 2,661' MD (500' of fill) with 12 PPG LiteCrete, and from 2,661'to surface with 11 PPG Arctic LiteCRETE. Assume 250%excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,817'MD),zero excess in 16"conductor. Lead Slurry: 1.339 ft3/ft X 110=148 ft3 0.3637 ft3/ft X(1817-110)X 3.50(250%excess)=2,173 ft3 0.3637 ft3/ft X(2,661-1,817)X 1.50(50%excess)=461 ft3 Total volume=148 ft3+2,173 ft3+461 ft3=2,782 ft3=>1457 Sx @ 1.91 ft3/sk System: —1465 Sx Arctic LiteCRETE @ 11 PPG (495 bbls) Tail Slurry: 0.3637 ft3/ft X 3161-2661)X 1.5 (50%excess)=273 ft3 0.540 ft3/ft X 80ft(Shoe)=44ft3 Total volume=273 ft3+43.2 ft3=317 ft3=>195 Sx @ 1.63 ft3/sk System: 195 Sx LiteCRETE @ 12 PPG (56 bbls) 75/8" Intermediate Casing Cement Job Cement 7%" casing from shoe @ 8,410 MD to 5,603' MD(minimum of 500' above the top of the C-37 with 15.8 PPG Class G w/Ga5BLOK.Assume 40%excess in the open hole volume. Slurry: 0.2148 X(9,415'—6,000')x 1.40(40%excess)=1027 ft3 in open hole 80'shoe track x 0.258 ft3/ft x 1.0(0%excess)=20.6 ft3 Total volume=1027 ft3+20.6 ft3=1047.6 ft3=>904Sx @ 1.16 ft3/sk System: 904 Sx Class G @ 15.8 PPG (187 bbls) 3S-620 APD ORIGINAL Page15- of14 Printed:: 15-Oct-14 • Ailption for Permit to ,W Saved:Drillell 15-Oct3S-620 14 Attachment 5 - Diverter Orientation ConocoPhillips �'m t° t. f -- ►e • . •,-,,c,-7,4;ifc.47:47,::.'''..,:,:-,,' ...,",',,'1,,,---- ‘: '.,,,,,,,..,.:,,, ii•_ .4--''', d? , _ ,.-,.,„,,,,.. .,„4,,,.:.,;..„-i,.-,..,,,,,„.,,,,,. } 'h' ,,,,,,.,. h� M ,.,,.•-,,,.: ,�. .,,�Vim:..' _ a r t ' 'rf� .. tati'i 34 , �` ,• ..'',,:,,,'W . Y a:I 3 A g.3� xl tR 3yi Yit 3 1S. 1' `i Jt N N .}d 411, S 3S-620 APD Page 14 of 14 ORIGIN, AL Printed: 15-Oct-14 I / • • —I�Ec-E i v&- , /.s'i' a Vis, . .{, .. ... is _. 1......................... z ................:::: „0:::I.:: 1 • I Q 1a 8 0 A �ti•• 0 LO + o + + ? V d O CV ... vV O•CV' • 0 C ZS • �• 0 { V• M Z v� ./ 1 z z Q + C7 M . • • + tM1 I • • • ;O • • N. • d• • 1 Q • +1 Z + (Q r Z + 1 f• c.,1N M� ;• ▪..•. c. e N W + m• oI Lu o • z • I . N O me .m ■ — ? + h ( + Ili 4 2 -o N C 00 1 Q. - a w z rU ! >N Z Q O w + + -t- c > .0 Q CC J Tli> U) CD W O CO L > O Q J iii LI E3 73 a) a) O a) N. o 2 _ O w LL L - C'J 0 o o C Q O a) p a) n• (!) O Q Q 1,=, ) c N N w O O O O O Q w w X F- I- a) Z a) I- 2 F- a :� 1- m a a a a w C3 0 co o JU I I • 1 * 4 • 7 • • i] - Z Cl) • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, November 17, 2014 9:53 AM To: 'Seitz, Brian' Subject: RE: 3S-620 Spacing Exception Brian, Copies are fine. Thank you, Patricia From: Seitz, Brian [mailto:Brian.Seitz©conocophillips.com] Sent: Monday, November 17, 2014 7:44 AM To: Bettis, Patricia K (DOA) Subject: 3S-620 Spacing Exception Patricia- I received your phone message and we will provide the returned green cards notifying other parties once they are received. Are copies sufficient, or do you need the originals? Regards, Brian 1 411 • Bettis, Patricia K (DOA) From: Seitz, Brian <Brian.Seitz@conocophillips.com> Sent: Monday, November 17, 2014 7:44 AM To: Bettis, Patricia K(DOA) Subject: 3S-620 Spacing Exception Patricia- I received your phone message and we will provide the returned green cards notifying other parties once they are received. Are copies sufficient, or do you need the originals? Regards, Brian 1 • • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Tuesday, November 11, 2014 10:33 AM To: Bettis, Patricia K (DOA) Cc: Bearden, J Daniel Subject: 3S-620 Patricia, I finally had a conversation with the asset about the status of 3S-620 and found out that I was in error. Apparently the well was always to be a long term producer and any future plans for changing over to an injector have not been studied to determine its viability as such. So, it looks like I spoke out of turn. Also,the issue with the packer placement that we discussed, has proven to be a non-issue,since now it is felt we should be able to get access to the packer with conventional means of slick line. Therefore, CPAI doesn't plan on resubmitting another permit request for 3S-620 and would like to have AOGCC continue vetting the present one in your possession. The asset also assured me that they would be getting the"spacing exception"over to you this week. I have reiterated that time is of the essence. Thanks for your understanding, Steve 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday, October 28, 2014 9:27 AM To: 'Shultz, Steve (Orbis Engineering,Inc.)' Cc: Loepp,Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: RE: KRU 3S-620: Permit to Drill Steve, Thank you. The map was exactly what was needed. The reservoir objective for the KRU 3S-620 is not located within a defined pool; therefore, 20 AAC 25.055(a)(3), Drilling Units and Well Spacing, applies. ConocoPhillips needs to submit a request under 20 AAC 25.055(d)for an exception to the provisions of the statewide drilling units and well spacing regulations. This process will require public notice and the opportunity for a public hearing under 20 AAC 25.540. Thank you, Patricia From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillips.com] Sent: Tuesday, October 28, 2014 8:32 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 3S-620: Permit to Drill Patricia, Sorry this took so long, our directional planner was gone last week and once I received his spider map I didn't think it was what you really wanted and had to go to a second source. If you have any questions, please call. Steve From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, October 16, 2014 4:57 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 3S-620: Permit to Drill Steve, The reservoir objective for the KRU 3S-620 is not located within a defined pool; therefore, 20 AAC 25.055(a)(3), Drilling Units and Well Spacing, applies. "If oil has been discovered,the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool." Would you please provide a spider map showing the location for top and bottom of the "Moraine" reservoir for both 3S- 19 and the proposed KRU 3S-620. 1 I. IP • This may be submitted to me via a-mai Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Tuesday, October 28, 2014 8:32 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 3S-620: Permit to Drill Attachments: 3S-620buff.pdf Patricia, Sorry this took so long, our directional planner was gone last week and once I received his spider map I didn't think it was what you really wanted and had to go to a second source. If you have any questions, please call. Steve From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, October 16, 2014 4:57 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 3S-620: Permit to Drill Steve, The reservoir objective for the KRU 3S-620 is not located within a defined pool; therefore, 20 AAC 25.055(a)(3), Drilling Units and Well Spacing, applies. "If oil has been discovered,the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool." Would you please provide a spider map showing the location for top and bottom of the "Moraine" reservoir for both 35- 19 and the proposed KRU 3S-620. This may be submitted to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Wednesday, October 22, 2014 12:31 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 3S-620: Permit to Drill Application Patricia, The Moraine formation hasn't been produced yet on a regular basis. We did have 3S-19 on gaslift but those quantities of HZS from that well are suspect, because of the gas used is a combination of Kuparuk production from all over the field. Due to the fact that we have never injected into the Moraine, it is felt that the probability of H'S being present is remote. However, we do plan on taking a downhole gas sample with the MDT on this well to give us a definitive answer on whether HZS is present. Thanks, Steve From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, October 16, 2014 4:01 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 3S-620: Permit to Drill Application Good afternoon Steve, Under the Drilling Hazards Summary, ConocoPhillips did not address whether or not H2S is expected to be encountered in the drilling of the well or what mitigation measures will be available. Would you please address this issue in an e-mail to me. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 0 0 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, October 16, 2014 4:57 PM To: Shultz, Steve (Orbis Engineering,Inc.) (Steve.Shultz@contractor.conocophillips.com) Subject: KRU 3S-620: Permit to Drill Steve, The reservoir objective for the KRU 3S-620 is not located within a defined pool; therefore, 20 AAC 25.055(a)(3), Drilling Units and Well Spacing, applies. "If oil has been discovered,the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool." Would you please provide a spider map showing the location for top and bottom of the "Moraine" reservoir for both 35- 19 and the proposed KRU 3S-620. This may be submitted to me via e-mail. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Thursday, October 16, 2014 4:01 PM To: Shultz, Steve (Orbis Engineering,Inc.) (Steve.Shultz@contractor.conocophillips.com) Subject: KRU 3S-620: Permit to Drill Application Good afternoon Steve, Under the Drilling Hazards Summary, ConocoPhillips did not address whether or not H2S is expected to be encountered in the drilling of the well or what mitigation measures will be available. Would you please address this issue in an e-mail to me. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue Anchorage,Alaska 99501 Re: THE APPLICATION OF ) Docket Number: CO-14-032 ConocoPhillips Alaska, Inc. for an ) exception to the spacing requirements ) Conservation Order No. 711 of 20 AAC 25.055(a)(3) to drill and ) complete a development oil well ) Kuparuk River Field within the same governmental quarter ) Kuparuk River Unit section as wells that are, or may be ) Undefined Torok Oil Pool capable of, producing from the same ) Kuparuk River Unit 3S-620 pool ) Development Oil Well ) North Slope Borough,Alaska ) December 23, 2014 IT APPEARING THAT: 1. By letter received November 12, 2014, ConocoPhillips Alaska, Inc. (CPAI) requested an exception to the spacing provisions of 20 AAC 25.055(a)(3) to drill and complete a development oil well Kuparuk River Unit (KRU) 3S-620 within the same governmental quarter section as wells that are, or may capable of,producing from the same pool. 2. Pursuant to 20 AAC 25.540, the Alaska Oil and Gas Conservation Commission (AOGCC) tentatively scheduled a public hearing for December 18, 2014. On November 17, 2014, the AOGCC published notice of the opportunity for that hearing on the State of Alaska's Online Public Notice website and on the AOGCC's website, electronically transmitted the notice to all persons on the AOGCC's email distribution list, mailed printed copies of the notice to all persons on the AOGCC's mailing distribution list, and published the notice in the ALASKA DISPATCH NEWS. 3. Pursuant to 20 AAC 25.055(d)(1), CPAI sent by certified mail notice of the application to all owners, landowners, and operators of all properties within 1,000 feet of the proposed KRU 3S-620 oil well, i.e., CPAI, BP Exploration Alaska Inc., Chevron USA Inc., ExxonMobil Alaska Production inc., and the State of Alaska. CPAI provided the AOGCC the notice, date of mailing, addresses to which the notice was sent, and copies of the certified mail return receipts. 4. No comments on the application nor request for hearing were received. 5. Because CPAI provided sufficient information upon which to make an informed decision,the request can be resolved without a hearing. 6. The tentatively scheduled public hearing was vacated on December 8, 2014. • • CO 711 December 23,2014 Page 2 of 3 FINDINGS: 1. CPAI is a working interest owner in and operator of the KRU that is located in the North Slope Borough,Alaska. 2. KRU 3S-620 is a proposed horizontal development oil well with an onshore surface location of 2,547 feet from the north line and 1,188 feet from the east line of Section 18, Township 12 North, Range 8 East, Umiat Meridian (UM). The onshore bottom-hole location is approximately 2,148 feet from the north line and 3,930 feet from the east line of Section 12, Township 12 North, Range 7 East,UM. 3. The surface location of KRU 3S-620 will lie within State of Alaska oil and gas lease ADL 380107, and the horizontal productive portion of the well will lie within State of Alaska oil and gas leases ADL 25544 and ADL 25528. 4. KRU 3S-620 development well will target the oil-bearing Moraine sandstone within the Undefined Torok Oil Pool. 5. Development oil well KRU 3S-19 currently produces from the Undefined Torok Oil Pool within the same governmental quarter section as the planned oil well KRU 3S-620. 6. As planned, the horizontal productive interval within KRU 3S-620 will be 4,000 feet long. Ten percent of the horizontal portion of the well will fall within the Undefined Torok Oil Pool drainage area of KRU 3S-19. 7. Locating planned horizontal well KRU 3S-620 near existing well KRU 3S-19 within the same undefined oil pool allows direct comparison of horizontal versus deviated well performance. 8. The sail angle of well KRU 3S-620 is 69 degrees, approaching the upper limit at which the well can be reliably serviced with wireline-conveyed tools. Moving the landing point of KRU 3S-620 (the "heel" of the horizontal portion of the well) will increase the sail angle, increase drilling risk, and make future well maintenance difficult. 9. The AOGCC received no comments, objections or protests in response to the public notice regarding the proposed exception to the spacing requirements of 20 AAC 25.055 for KRU 3S-620 or to the notification sent by CPAI to all known owners, landowners, and operators within 1,000 feet of KRU 3S-620. CONCLUSIONS: 1, An exception to the well spacing provisions of 20 AAC 25.055(a)(3) is necessary to allow the drilling and completion of KRU 3S-620. 2. Drilling development oil well KRU 3S-620 near existing development oil well KRU 3S-19 will allow direct comparison of horizontal versus deviated well performance for the undefined Torok Oil Pool. 3. Locating KRU 3S-620 in conformance with statewide spacing requirements would reduce the effectiveness of the well performance comparison, increase drilling risks and make well intervention difficult. • • CO 711 December 23,2014 Page 3 of 4. A spacing exception to the well spacing provisions of 20 AAC 25.055(a)(3) for the KRU 3S- 620 is consistent with sound engineering and geoscience principles and will not result in waste or jeopardize correlative rights of adjoining or nearby owners. NOW THEREFORE IT IS ORDERED: CPAI's November 12, 2014 application for an order granting an exception to the well spacing provisions of 20 AAC 25.055(a)(3) to allow the drilling and completion of the KRU 3S-620 development oil well is approved. CPAI may proceed as long as it complies with the terms of all lease agreements, applicable Alaska laws, and all other legal requirements. OIL,t,v� DONE at Anchorage, Alaska and dated December 23, 2014. gitp ,,i4W11.41 • -41 tea. / n fOilf ti;i. 4",t, Daniel T. Seamount, Jr. a y 48� avid J. ayberry Commissioner Commissioner ` 7'toN CO14 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it, If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • CHECKLIST - SPACING EXCEPTION APPLICATION OPERATOR PROPERTY ID/LEASE S: FIELD/POOL PUBH: WELL NAME VERTICAL EXPLORATORY GAS DEVIATED DELINEATION OIL DEVELOPMENT SURFACE LOCATION ' F L and ' F L, S. ,T , R , M PRODUCTIVE INTERVALS ' F L and ' F L, S. , T , R , M (Top and Bottom) BOTTOM HOLE ' F L and ' F L, S. ,T , R , M Check applicable reason(s) for spacing exception per 20 AAC 25.055(a): (1)to drill a well for oil within 500 feet of a property line where ownership or landownership changes, (2)to drill a well for gas within 1500 feet of a property line where ownership or landownership changes, (3)to drill and complete more than one oil well in a governmental quarter section;or to drill and complete an oil well closer than 1000' to any well drilling to or capable of producing from the same pool, (4)to drill and complete more than one gas well in a governmental section;or or to drill and complete a gas well closer than 3000'to any well drilling to or capable of producing from the same pool. Does the application contain? A brief explanation for why the operator has chosen to drill the specified location. A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well or portion of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. The names of all owners, landowners,and operators of all properties within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. A copy of the notice sent by certified mail to the owners,landowners and operators described above,the date of mailing,and the addresses to which the notice was sent. An affidavit by a person acquainted with the facts verifying that all facts are true and that the plat correctly portrays pertinent and required data. If the operator requests a variance from the notice requirements of 20AAC25.055(d),sufficient information to demonstrate that it is not feasible to comply with the notice requirements because of the complexity of ownership • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • I TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: POOL: Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( 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 Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 0 • TL: y a) a y y_ .E.".. Cl) a) 0 O- O N C 0 _ C Q 30, y O '. a)' o' 0 O' 0 N �, C O 76 O a). 0. U• o O Cl) N N -6 o > 0) a) L E m 2, C. 4 > (n a) c W, � a> 0 - I Q O a O a p 0 m 2 2 • H 0 a) a rn 00 m c oi3. c a N 4 0 N 7, o N E �' 3. E a E. 0 o -- 0 m � co O a a) y y :; y 0 o LU a) 3 3 a) rn Q a o E •- 6;9 ' .0 -N ,— -p N C O w �.0 •C 3, L. O = C 0) N U 0 CO ..- a C C, O a V O < as V W a a o 2 a. O (A J_. .-. ON L . O 0- 00.. �, W. 0 M " > c6. 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O, L. a) a) a), a) a) 0 0 U caJD5 5 (n 0OaaU5Qaz 0uiUU, UUQ Qw, om, mU5, -(1), 2 a0 (O (n, 0 W CL O - N M V (n CO I- CO 0) 0 c- N CO V 1.1) CO I,- 00 0) 0 . N M •7 CO CO r CO 0) I E a- N CO V to (0 1-- 00 0) . . . . . . ,- ,- N N N N N N N N N N CO CO CO CO CO CO CO CO COCO o 0 -___.7r 1 . _... 0 N C a) ,-,9 - N �.1 w N 0 p p p a M G N o w W CO +0 0 c o 50 E CL 71- rn a) T O E cJ d tr. m E J : O a a m 0 Q Q a Cw Q > N < 0- C., Well History File APPENDIX Inforrrration of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 141 Date: January 17, 2015 Surface Data Logging End of Well Report 3S-620 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Doyon 141 Well: 3S-620 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20695-00-00 Sperry Job Number: AK-XX-0902065084 Job Start Date: 22 January 2015 Spud Date: 22 January 2015 Total Depth: 13768’ MD, 5214’ TVD North Reference: True Declination: 18.846° Dip Angle: 80.92° Total Field Strength: 57567.886 nT Date of Magnetic Data: 19 January 2015 Wellhead Coordinates N: North 70° 23’ 38.67463” Wellhead Coordinates W: West 150° 11’ 52.15299“ Drill Floor Elevation 55.2’ Ground Elevation: 23.0’ Permanent Datum: Mean Sea Level SDL Engineers: Douglas Acker, Autumn Gould SDL Sample Catchers: Kyle Blazian, Kruz Kleewein, Chris Woolley, Roy Brendible Company Geologist: Ashley Long Company Representatives: Robert Wall SSDS Unit Number: 105 DAILY SUMMARY 01/21/2015 Arrived on location and began rigging up. 01/22/2015 Nippled up diverter surface equipment and then took on mud and loaded pipe shed with 5” drill pipe. Then started installation of the riser, mouse hole, and 5” elevators. Picked up 5” drill pipe and racked back with 38 stands and also loaded heavy weight drill pipe into the pipe shed. The diverter was tested with a state witness present. Continued picking up 6 stands of heavy weight drill pipe with jars. Mobilize handling tools and bottom hole assembly. Made up bottom hole assembly per Schlumberger representative. Then the conductor was flooded to 3500 pounds per square inch from 10 pounds per square inch. Drilling from 106’ MD to 222’ MD and then pulled out of the hole and made up bottom hole assembly number two. Gas: No Gas was observed Fluids: No water based mud lost down hole. 01/23/2015 Oriented motor to gyroscope and made up bottom hole assembly to 193’ MD and took a survey at 176’ MD. Made up a stand of heavy weight drill pipe and drilled from 222’ MD to 470’ MD with a total vertical depth of 470’. Pulled out of hole one stand and pump out of the hole two stands of heavy weight drill pipe. Pulled out of hole on elevators to the surface and then the bit was cleaned and inspected. Made up bottom hole assembly triple combo, installed nuclear tool, and took a gyroscope survey. Then continued to drill from 470’ MD to 1257’ MD. Gas: The max gas was 54 units at 557’ MD and the average drilling background gas was 2 units. Fluids: No water based mud lost down hole. Geology: The samples have been predominantly light gray, gray, translucent, medium to fine grained sand with trace amounts of pyrite and coal 01/24/2015 Continued to drill from 1260’ MD to 1688’ MD and then pulled off bottom to monitor the well. Losses were observed and fluid was dropping in the well. Decision was made to keep well full with losses at 360 barrels per hour. The pump rate was also reduced to 2 barrels per minute. Lost circulation material was added and the decision was made to drill 10’. Continued to drill from 1688’ MD to 1700’ MD and monitored the losses to the formation. Pumps were staged up from 2 barrels per minute to 7 barrels per minute with a loss rate of 29 barrels per hour and losses started to subside. Continued to drill from 1700’ MD to 2388’ MD. Gas: The max gas was 274 units at 2375’ MD and the average drilling background gas was 25 units. Fluids: 495 barrel of water based mud lost down hole. Geology: The samples have been predominantly of dark gray siltstone with trace amounts of chert and black lithics 01/25/2015 Continued to drill from 2388’ MD to 3155’ MD with a total vertical depth of 2552’ MD. Then a stand was racked back and a single was picked up. Circulated bottoms up 3 times at 700 gallons per minute and then monitored the well which was static. Back reamed out of hole from 3126’ MD to 1635’ MD at 600 gallons per minute. The hole unloaded at 2050’ MD and 1950’ MD with no obvious losses crossing the lost circulation zones, erratic pump pressures observed while back reaming slides with no other problems. Gas: The max gas was 283 units at 2806’ MD and the average drilling background gas was 53 units. Fluids: 223 barrels of water based mud lost down hole. Geology: The samples have been predominantly of light to dark gray clay mixed with trace amounts of chert, black lithics, and tuff 01/26/2015 Back reamed out of hole from 1635’ MD to 795’ MD at 600 gallons per minute and monitored the well at the heavy weight drill pipe; then pumped out of the hole from 795’ MD to 240’ MD at 400 gallons per minute. Laid bottom hole assembly, cross over, and 3 joints of non-magnetic drill collars. Nuclear sources were then removed. Continued to lay down bottom hole assembly per Schlumberger representative. Laid down Schlumberger tools and picked up casing equipment; then rigged up casing equipment, bail extension, and elevators. Also drained and flushed the stack. Run 10.75” casing per detail. Fluids: 42 barrels of water based mud lost to the formation. 01/27/2015 Continued to run in hole with 10.75” casing to 3113’ MD and then made up hanger and liner joint. Observed heavier grade pipe with a smaller inner diameter. Decision was made to land the casing with elevators. Circulated and conditioned mud at 2 barrels per minute and staged up pumps to 6 barrels per minute; then changed out pup joint. Rigged up cement head and hoses and circulated and conditioned mud per mud man recommendations. Pumped cement per Dowell pumping schedule. Rigged down cement equipment lines and backed our liner joint and nippled down the diverter. Gas: No gas was observed. Fluids: No losses were observed. 01/28/2015 Nippled up diverter, monitored well (static), nippled down diverter, cleaned pits, and greased the choke. Prepped from the top of the cement job and made of 0.75” conduit 30’ sections; then ran into hole with 0.75” conduit. Tagged up at 115’ MD and blew air through conduit to confirm it was not plugged. Rigged up cementers and cemented top job. Continued by lining up trucks to the cellar and performed top job per Schlumberger representative. Rigged down cellar area and rigged up and made up air actuated valve on stack. Mobilized the well head; then nippled up the well head and set blow out prevention equipment stack on well and rigged up scaffolding. Gas: No gas was observed. Fluids: No losses were observed. 01/29/2015 Rigged up scaffolding and continued to nipple up blow out preventer equipment. Rigged up circulation lines to manage pressure drilling, reverse circulation drilling, and set test plugs. Flooded managed pressure drilling equipment and blow out preventer equipment to check for leaks. Pulled managed pressure drilling test plug and installed 22” triple nipple. Rigged up to test blow out preventer equipment; then attempted to test blow out preventer with 5” test joint when leaks were observed in the spool control line port. Waited on wellhead representative and plugged termination sleeve; then started to test blow out preventer equipment. Gas: No gas was observed. Fluids: No losses were observed. 01/30/2015 Tested blow out preventer equipment. Rigged down testing equipment and then blew down top drive, choke, and kill lines. Pulled a test joint and drained the stack. Circulated out top pipe rams to 2 7/8” by 5” variables and then rigged up blast out preventer testing equipment. Tested top pipe rams then rigged down testing equipment. Set long slotted wear bushing with a 10” inner diameter. Rigged up new catch can on the blow out preventer and installed mud skirt and drain hoses. Rigged up to pick up and rack back 5” drill pipe. Picked up and racked back 111 joints. Mobilized bottom hole assembly tools to the rig floor. Mobilized nuclear sources to the rig floor and continued to make up the bottom hole assembly; singled in hole from shed with 5” drill pipe from 772’ MD to 1707” MD. Started standard penetration test at 430 gallons per minute and then continued to single in hole from 1707’ MD to 2749’ MD. Gas: No gas was observed. Fluids: No losses were observed. 01/31/2015 Ran into hole from 2739’ MD to 2926’ MD and then serviced the rig. Rigged up to test casing and circulated bottoms up at 380 gallons per minute. Attempted to test casing when there was a wash out on the cement manifold so the washout was bypassed. Tested casing to 3000 pounds per square inch for 30 minutes and then rigged down testing equipment. Ran into hole from 1929’ MD to 3019’ MD and washed and reamed from 3019’ MD to 3058’ MD at 450 gallons per minute. Drilled out float equipment to 3155’ MD; then continued to drill from 3155’ MD to 3175’ MD and then circulated bottoms up at drilling rate. Pulled out of the hole to 3111’ MD and then performed a leak off test with a result of 14.7 parts per gallon. Displaced well to 9.5 parts per gallon low solids non-displaced mud and obtained baseline equivalent circulation density at 650 gallons per minute. Finished the day by continuing to drill from 3175’ MD to 4318’ MD with a total vertical depth of 3978’. Gas: The max gas was 59 units at 3920’ MD and the average drilling background gas was 17 units. Fluids: No water based mud lost down hole. Geology: The samples have been predominantly of light to dark gray silty clay mixed with common amounts of black lithics. 02/01/2015 Drilling from 4318' MD to 5155' MD with a total vertical depth of 3456' when swivel packing began to leak and then the decision was made to circulate bottoms up at 700 gallons per minute and pull up to the shoe. Tested swivel to 3500 pounds per square inch. The test was good so the cement line manifold was installed. Ran into hole from 3111' to 5064' MD and then washed and reamed from 5064' MD and circulated bottoms up at 700 GPM. Currently drilling ahead from 5156' to 5709' MD with a TVD of 3706'. Gas: The max gas was 85 units at 5526’ MD and the average drilling background gas was 49 units. Fluids: No water based mud lost down hole. Geology: The samples have been predominantly of light to dark gray silty clay mixed with common amounts of black lithics. 02/02/2015 Drilling from 5709' to 6586' MD when drilling through C-40 Zone and getting gas back when having trouble with CAT power so the decision was made to weight mud to 9.7 ppg and trip back to the shoe and circulate at 600 gpm. Pulled out of hole from 6586' to 6549' MD and monitored the well which was static. Pump out of hole from 6549' MD to 5945' MD and the hole was not taking the proper fill. The decision was made to back ream out of hole and run in hole to 5991' MD Kelly up. Continued to back ream out of hole to 4786' MD and monitored the well which was static. Run in hole from 4786' to 6455' MD. Continued drilling from 6586' to 7105' MD with a total vertical depth of 4461'. Gas: The max gas was 1632 units at 6641’ MD and the average drilling background gas was 267 units. Fluids: No water based mud lost down hole. Geology: The samples have been predominantly of light to dark gray silty clay mixed with some sands and included several oil shows. 02/03/2015 Continued drilling from 7105’ MD to 9289’ MD with a total vertical depth of 5191’. Circulated bottoms up at 700 gallons per minute and then pumped 32 barrels of high visibility sweep. Gas: The max gas was 1351 units at 9255’ MD and the average drilling background gas was 548 units. Fluids: No losses were observed. Geology: The samples have been predominantly of light to dark gray silty clay mixed with some sands and included several oil shows. 02/04/2015 Continued to circulate bottoms up at 700 gallons per minute and monitored the well (static) and then cleaned around triple nipple. Pulled triple nipple and installed managed pressure drilling bearing. Pulled out of hole from 8971’ MD to 8000’ MD holding 220 pounds per square inch at the surface; then pulled out of hole from 8000’ MD to 5000’ MD holding 170 pounds per square inch at the surface. Staged down pounds per square inch to maintain equivalent circulation density and then monitored well (static). Continued to pull out of hole on elevators and then laid down bottom hole assembly and cleaned out upper rams. Gas: The max gas was 1222 units with a max trip gas of 1067 units. Fluids: No losses were observed. 02/05/2015 Serviced rig and performed dummy run with hanger. Rigged up to test 7.625” test joint. Tested 7.625” test joint and annular preventer. Rigged down testing equipment and mobilized casing equipment. Ran in hole with 7.625” casing from surface to 3129’ MD and then circulated bottoms up ramping pumps up to 6 barrels per minute. Continued to run in hole from 3129’ MD to 3808’ MD and then encountered tight spot. Circulated bottoms up from 2 barrels per minute to 6 barrels per minute and continued to run in hole from 3808’ MD to 5328’ MD. Circulated bottoms up and continued to run in hole from 5328’ MD to 7558’ MD. Gas: The max gas was 244 units with a max trip gas of 244 units. Fluids: No losses were observed 02/06/2015 Circulated bottoms up and then ran into hole from 7558’ MD to 8019’ MD. Ran into hole from 8019’ MD to 8530’ MD and a tight spot was encountered at 8530’ MD; worked through it but lost returns. Picked up casing and continued circulating until returns were regained. Pump down casing from 8530’ MD to 9249’ MD. Made up landing joint and landed casing at 9279’ MD and then rigged up and pumped cement. Swap over and pumped 419 barrels mud to bump plug. Brought down lines and rigged down cement head. Cleaned stack and pulled landing joint. Made up pack off running tool and set pack off and ran in with lock downs. Gas: The max gas was 558 units with a max trip gas of 558 units. Fluids: No losses were observed. 02/07/2015 Tested pack off to 5000 pounds per square inch and it tested good and rigged up to lay down drill pipe. Laid down 5" drill pipe and then pumped 100 barrels ISOTHERM NT down outside annulus to freeze protect well with an insulating fluid. Serviced top-drive, cleaned and cleared rig floor, and rigged up to lay down 4" drill pipe. Gas: No gas was observed. Fluids: No losses were observed. 02/08/2015 Tested BOPE and MPD chokes and mobilized the BHA to the rig floor. Installed 9” wear bushing and picked up the BHA. Continued with singling in the hole with 4” drill pipe to 1530’ MD and then a shallow hole test with MWD pump was completed at 220 gpm. Continued to run in the hole 5418’ and then started logging with the sonic tool. Continued to run in the hole at 6260’ MD at 900’ per hour. Gas: No gas was observed Fluids: No losses were observed. 02/09/2015 Drilled out float equipment and shoe track from 9189' MD to 9270' MD. Circulated and conditioned mud, then performed a LOT. Installed bearing assembly and removed triple nipple. Run in hole from 9261' MD to 9309' MD and displaced mud. Monitored well and circulated bottoms up and monitored well. Continued to drill from 9309' MD to 9421' MD. Gas: The max gas was 1071 units at 9408’ MD and the average drilling background gas was 825 units. Fluids: No water based mud lost down the hole. Geology: The samples have been predominantly of light to dark gray siltstone with a trace amount of very fine grained sandstone. 02/10/2015 Continued to drill ahead from 9426’ MD with a TVD of 4243’ to 11114’ MD with a TVD of 5253’. Gas: The max gas was 4317 units at 9737’ MD and the average drilling background gas was 495 units. Fluids: No water based mud lost down the hole. Geology: The samples have been predominantly of light to dark gray siltstone with some very fine grained sandstone. 02/11/2015 Continued to drill from 11114' MD to 12825' MD with a TVD of 5238'. Gas: The max gas was 3635 units at 11342’ MD and the average drilling background gas was 494 units. Fluids: No water based mud lost down the hole. Geology: The samples have been predominantly of light to dark gray siltstone with some very fine grained sandstone. 02/12/2015 Continued to drill from 12825' MD to 13295' MD and then had to change out the MPD bearing. Continued to drill from 13295' MD and then TD at 13768' MD (TVD = 5218'). Circulated bottoms up 2 times and monitored the well (static). Back reamed out of the hole from 13758' MD to 124500' MD. Gas: The max gas was 3351 units at 13468’ MD and the average drilling background gas was 425 units. Fluids: No water based mud lost down the hole. Geology: The samples have been predominantly of light to dark gray siltstone with some very fine grained sandstone. 02/13/2015 Continued to back ream out of the hole from 12450' MD to 9233' MD and then monitored the well (static) and then circulated bottoms up 2 times. Pulled out of the hole with MPD and then the floats failed so unable to pull out of the hole on MPD so the decision was made to pump out of the hole 20 stands. Then line up on MPD pump out from 7295' MD to 6155' MD and then removed RCD; installed trip nipple and continued to pull out of the hole from 6185' MD to 5295' MD. Circulated out air boot then continued to pull out of hole from 5295' MD to 4523' MD. Gas: The max gas was 1110 units at 11936’ MD and the average drilling background gas was 77 units. Fluids: No water based mud lost down the hole. 02/14/2015 Pulled out of the hole from 4523' MD to 528' MD and monitored the well (static). Then racked back heavy weigh drill pipe and jars. Broke down and laid down the BHA. Pulled wear bushing and picked up single and wash stack. Set short wear ring. Picked up casing tools and rigged up to run casing. Ran into the hole with 4.5" liner and picked up hanger and installed cross over and ran in the hole with 4" drill pipe from 4493' MD to 5561' MD. Due to left hand rotation by driller the decision was made to pull out of the hole from 5561' MD to 4493' MD to check set screws on the hanger; currently checking the set screws on the hanger. Gas: No gas was observed. Fluids: 8 barrels of water based mud lost to the formation 02/15/2015 Ran in hole with lower completion on drill pipe to 7928' MD and monitored the well and it was static. Continued to run in hole from 8117' MD to 13068' MD and then completed wash down from 13068' MD to 13668' MD and positioned liner at 13654' MD. Dropped ball and completed a pressure test and released running tool after the liner was set. Pressure tested the annular. Displaced the well to 9.7 ppg filtered brine with 772 barrels and then monitored the well and it was static; started to pull out of the hole on elevators from 9144' MD to 8390' MD. Gas: The max gas was 2605 units. Fluids: No water based mud lost down the hole. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 3S-620 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 141 SPERRY JOB: AK-XX-0902065084 Days vs. Depth 22 January 2015 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 22-Jan-2015 TD: 12-Feb-2015 Commenced 13.5" Surface Hole Section On Bot: 20:26 22 Jan 2015 TD Surface Hole Section 3155' MD, 2552' TVD Off Bot: 15:30 25 Jan 2015 Commenced 9.875" Intermediate Hole Section On Bot: 08:30 31 Jan 2015 Landed 10.75" Casing 3144' MD, 2546' TVD 26 Jan 2015 TD Intermediate Hole Section 9289' MD, 5187.61' TVD Off Bot: 23:08 2 Feb 2015 Commenced 6.50" Production Hole Section On Bot: 12:10 09 Feb 2015 Landed 7.625" Casing 9279' MD, 5168' TVD 05 Feb 2015 TD Production Hole Section 13768' MD, 5214.68' TVD Off Bot: 15:35 12 Feb 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Despite getting the unit rigged up at the last minute, everything was set up correctly and the beginning of the well started off without any major problems. 3S-620 Moraine Conoco Phillips Alaska North Slope Borough AK-XX-0902065084 Alaska Doyon 141 Surface Doug Acker / Autumn Gould 25-Jan-2015 What went as, or better than, planned: Difficulties experienced: During the surface section, the possum belly was becoming heavily saturated with rock cuttings causing the gas trap to bog down and stop the flow of mud. Which in turn caused the gas trap to stop agitating the mud and we got some inaccurate gas readings. Recommendations: During the surface section it is especially important to keep an eye on the gas trap and make sure it is correctly agitating the mud and getting a flow so that you are getting accurate gas data. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The THA stopped working and had to be replaced. Miniumum data was lost. Recommendations: Always keep an eye on your gas gear to ensure that it is working properly. Innovations and/or cost savings: N/A The intermediate section went pretty smoothly. We were required to take 10 foot samples and were able to come up with an efficient method with the sample catchers to make sure that all the samples were being collected properly. 3S-620 Moraine Conoco Phillips Alaska North Slope Borough AK-XX-0902065084 Alaska Doyon 141 Intermediate Doug Acker / Autumn Gould 2-Feb-2015 What went as, or better than, planned: Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 The production section went smoothly and we were able to take photos of the oil shows under the flouroscope and gave the photos to the geologist. They seemed to be impressed with them. 3S-620 Moraine Conoco Phillips Alaska North Slope Borough AK-XX-0902065084 Alaska Doyon 141 Production Doug Acker / Autumn Gould 20-Feb-2015 What went as, or better than, planned: Difficulties experienced: We had a few instances where the depth tracking communication with the Totco was lost. Recommendations: Always keep an eye on the depth tracking to make sure you don’t lose any data. Innovations and/or cost savings: Providing pictures of the oil shows to the geologist gave them the oppurtunity to see what we were drilling in without having to be on location. Surface Data Logging After Action Review 3S-620 ConocoPhillips Alaska, Inc. MI Swaco Doyon 141 AK-XX-0902065084 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 22-Jan 75 9.50 54 7 46 33/33/33 -60/53/50/46/36/35 -5.5 /94 -0.95 11.1 8.8 0.82/1.45 1500 36 Spud Well 23-Jan 1048 9.50 181 3 104 62/54/51 -110/107/104/100/82/64 -6.0 /94 1.00 0.45 11.0 10.0 0.43/0.75 850 12 Drill 13.5" surface hole 24-Jan 2270 9.70 100 4 77 43/36/36 -85/81/77/73/59/54 -7.0 /93 0.50 1.00 10.9 11.5 0.50/0.70 400 12 Drill 13.5" surface hole 25-Jan 3351 9.70 83 10 43 48/58/76 -65/53/51/44/38/38 -8.0 /92 0.50 2.00 10.9 15.5 0.95/3.40 400 12 Drill 13.5" surface hole, TD surface 26-Jan 3351 10.80 133 10 47 42/61/69 -67/57/54/50/42/42 -8.0 /92 0.50 1.20 11.0 17.5 1.65/2.65 400 40 Running surface casing 27-Jan 3351 -133 16 17 8/10/12 -49/33/20/18/9/7 -7.8 /92 0.50 1.00 10.3 17.5 1.1/2.1 400 20 Cementing / Nipple Down Diverter 28-Jan 3351 9.50 50 15 19 8/10/12 -49/34/22/18/9/7 -7.8 /92 0.50 1.00 10.3 17.5 1.1/2.1 400 20 Nipple up BOPE 29-Jan 3351 9.50 79 17 31 28/34/38 -65/48/40/32/24/22 -7.8 /92 0.50 1.00 10.6 17.5 1.1/2.1 400 20 Testing BOPE 30-Jan 3351 9.50 114 17 31 28/34/38 -65/48/40/32/24/22 -7.8 /92 0.50 1.00 10.6 17.5 1.1/2.1 400 20 Singling In Hole with 5" Drill Pipe 31-Jan 4318 9.50 58 13 27 11/13/14 -53/40/32/26/11/10 -5.5 /92 0.25 0.30 10.0 5.5 0.25/1.1 350 72 Drill 9.875" intermediate hole 1-Feb 5709 9.50 55 13 26 10/11/12 -52/39/33/25/11/10 -7.3 /91 tr 0.20 9.6 18.8 .15/.95 350 45 Drill 9.875" intermediate hole 2-Feb 7105 9.50 51 13 24 10/11/13 -50/37/32/25/11/10 -8.3 /90 tr 0.25 9.8 25.0 .20/1.15 550 52 Drill 9.875" intermediate hole 3-Feb 9289 9.70 47 9 29 12/14/16 -47/38/33/26/12/11 -8.3 /90 tr 0.45 10.1 18.8 .40/1.7 500 25 Drill 9.875" interm. Hole / TD interm. 4-Feb 9289 9.70 45 10 25 11/12/15 -43/35/32/26/12/11 -8.3 /90 tr 0.26 9.9 19.5 .24/1.10 650 40 Testing 7 5/8" Rams 5-Feb 9289 9.70 53 9 21 9/10/13 -39/30/26/21/10/9 -8.3 /90 tr 0.26 9.8 19.5 .24/1.10 650 40 Running intermediate casing 6-Feb 9289 9.70 47 8 19 7/8/9 -35/27/23/18/8/7 -7.8 /91 tr 0.26 9.8 20.0 .24/1.1 650 40 Cementing 7-Feb 9289 9.70 51 10 18 8/9/10 -38/28/25/20/9/8 -7.8 /91 tr 0.26 9.3 20.0 .24/1.10 650 40 Laying Dowm Mouse Hole 8-Feb 9289 9.70 50 10 18 8/9/10 -38/28/25/20/9/8 -7.8 /91 tr 0.26 9.3 20.0 .24/1.10 650 40 Running in Hole with 4" Drill Pipe 9-Feb 9421 9.70 50 10 18 5/6/8 -38/28/23/17/6/5 -6.0 /92 tr 3.45 10.0 5.0 3.30/7.90 40000 80 Drill 6.5" production hole 10-Feb 11126 9.70 51 14 20 8/11/16 -48/34/29/22/8/7 -10.0 /88 tr 2.30 9.8 6.8 4.10/9.90 45000 120 Drill 6.5" production hole 11-Feb 12825 9.70 50 12 25 8/13/18 -49/37/31/23/8/7 -8.0 /91 tr 5.00 9.9 6.3 4.8/11.4 46000 80 Drill 6.5" production hole 12-Feb 13768 9.70 52 11 22 7/11/16 -44/33/27/20/7/6 -9.0 /89 tr 4.60 9.7 5.0 4.20/11.20 41000 80 Drill 6.5" production hole / TD prod. 13-Feb 13768 9.70 55 14 25 8/13/17 -53/39/33/24/9/7 -9.0 /89 tr 4.30 9.7 4.3 4.10/11.10 41000 80 Trupping out of the hole 14-Feb 13768 9.50 55 11 19 8/13/17 -41/30/25/17/7/6 -9.0 /89 tr 4.30 9.6 4.3 4.10/10.90 40000 80 Running production liner down hole 15-Feb 13768 9.70 27 12 19 8/13/17 -43/31/26/19/7/6 -9.0 /89 tr 4.20 9.6 4.3 4.00/10.80 40000 80 Set production liner Casing Record Remarks 16" Conductor @ 110' MD, 110'TVD 10.75" Casing @ 3144' MD, 2546'TVD 9.625" Casing @ 9279' MD, 5168'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:22-Jan-2015 SPERRY JOB:TD:12-Feb-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 1 Mill Tooth Smith - XR+VC 13.50 110 470 360 1.76 0.994 62.5 50 500 450 0-0-NO-A-0-I-NO-BHA Clean out run for drilling BHA 3 200 2 MillTooth Smith-RD2582 13.50 470 3155 2685 31.22 0.994 86.0 46 84 1675 700 1-4-FC-A-E-1-SD-TD 13.5" Surface Hole TD 4 300 3 ReedHycalog SKH516D 9.875 3155 9289 6135 49.98 0.990 122.8 21 143 2700 700 0-1-WT-N-X-I-NO-TD 9.875" Intermediate Hole TD 5 400 4 Hycalog SKH513M PDC 6.50 9289 13768 4479 52.62 0.383 85.1 15 121 2800 220 0-1-CT-G-X-I-PN-TD 6.5" Production Section TD Alaska RIG:Doyon 141 SPUD:22-Jan-2015 WELL NAME:3S-620 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902065084 TD:12-Feb-2015 MI Swaco STATE: B i t R e c o r d . . * 24 hr Recap: (max)(current) Cly Set AtSize Grade 907-670-4906Unit Phone:Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth C-5nC-2 in Minimum Depth Time: down hole losses. 106' 222' 116' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) W all / Finkbiner ShClyst TuffGvlCoal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV 24 hr Max Weight Hours C-3 CementCht Silt C-4i C-4n YP (lb/100ft2) Depth in / out Mud Type Lst Type Average 0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) W OB 100% Gas In Air=10,000 UnitsConnection 2 Max gas is 0 units. ConditionBit # 1 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 141 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Jan-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l SDL arrived on locatoin. Begin and complete rigup. Service commenced at 2300 hrs on 1/22/2015. No gas and no Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 6221 - Set AtSize Grade 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould - 862 0 491 57 Units* Casing Summary Lithology (%) 0 MBT pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.0181 C-5n 577' 133.8 C-2 54 in 2 1278'Minimum Depth Time: 0 barrels lost in the last 24 hours. 8 222' 1280' 1058' Max @ ft Current 1185'150.6 Date: Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 257.6 Flow In (gpm) Flow In (spm) - - Gas Summary 0 0 0 (current) W all / Finkbiner ShClyst - - TuffGvlCoal cP 3 Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV - 24 hr Max Weight 0 Hours C-3 - 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 11.00 000 DRILPLEX NC1257'104 Depth in / out Mud Type Lst 70 - Type Average -2Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools DGR, Resistivity API FL Chromatograph (ppm) W OB 100% Gas In Air=10,000 Units-Connection - 0 2 Max gas is 54 units from the formation. ConditionBit # 1 6.010.6010.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Jan-2015 12:00 AM Current Pump & Flow Data: 936 Max 0 Chlorides mg/l 850.00 Continued drilling surface section from 222' MD to 1280' MD. Running centrifuge and desilter continuously while drilling. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continue to drill ahead from 1280' MD to 2389' MD. Pulled off bottom to monitor well and losses were observed. It was Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 24-Jan-2015 12:00 AM Current Pump & Flow Data: 1189 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition - Bit # 1 7.0 13.5 10.21 Milled Tooth Bit 10.43 Size 2 were added. 0.5 barrel increments. Loss rate was determined to be 29 barrels per hour. Losses started to subside after nut plug and Torque Seal 100% Gas In Air=10,000 Units-Connection - 0 Tools DGR, Resistivity API FL Chromatograph (ppm) 16.9106' - W OB - - Avg Min Comments RPM ECD (ppg) ml/30min 25Background (max) Trip Average - Mud Type Lst - - Type 21.0 DRILPLEX NC2388'77 Depth in / out YP (lb/100ft2) 10.90 000 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 0 Hours C-3 -- Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV - Footage 22.00 W all / Finkbiner ShClyst - - TuffGvlCoal cP 4 - - Gas Summary 0 0 0 (current) Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 368.5 Flow In (gpm) Flow In (spm) 1280' 2389' 1109' Max @ ft Current 1759'92.9 Date: Time: decided to keep the well full and pump at 4 barrels per minute. Losses were monitored at 1700' MD and pumps were staged up at 36 Total losses was 495 barrels. Max Gas is 274 units from the formation. in 2 1280'Minimum Depth C-5n 2375' 60.9 C-2 274 SPP (psi) Gallons/stroke TFABit Type Depth 11.5100 MBT - pH 0.994 0 0 0 Siltst 537 65 Units* Casing Summary Lithology (%) 0 90% 3536 15 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize Grade (max)(current) 0 0 Cly 4586 - . . * 24 hr Recap:Currently back reaming out of the hole. Drilling of the surface section was completed at 3155' MD. Currently running Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 25-Jan-2015 12:00 AM Current Pump & Flow Data: 1294 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition - Bit # 1 8.0 13.5 10.98 Milled Tooth Bit 11.23 Size 2 Maximum gas was 283 units. No obvious losses crossing lost circulation zones. 100% Gas In Air=10,000 Units-Connection - 0 Tools DGR, Resistivity API FL Chromatograph (ppm) 16.9106' - W OB - - Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max) Trip Average - Mud Type Lst - - Type 21.0 DRILPLEX NC3155'43 Depth in / out YP (lb/100ft2) 10.90 000 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 9 Hours C-3 -80% Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV - Footage 22.00 W all / Finkbiner ShClyst - - TuffGvlCoal cP 10 - - Gas Summary 0 0 0 (current) Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 271.8 Flow In (gpm) Flow In (spm) 2389' 3155' 766' Max @ ft Current 2558'48.7 Date: Time: centrifuge while back reaming out of the hole. Water is being added at 15-25 barrels per hour. Hole unloaded at 2050' MD and 1950' MD. 53 in 2 1666'Minimum Depth C-5n 2806' 0.0 C-2 283 SPP (psi) Gallons/stroke TFABit Type Depth 15.583 MBT - pH 0.994 0 0 0 Siltst 592 79 Units* Casing Summary Lithology (%) 0 - 5602 278 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize Grade (max)(current) 5 0 Cly 3877 - . . * 24 hr Recap:Continuing to run in the hole with 10.75" casing from 29.27' MD to 3144' MD. Total losses to the formation was 42 barrels. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 26-Jan-2015 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition - Bit # 1 8.0 13.5 - Milled Tooth Bit - Size 2 Maximum gas was 0 units. 3145' 100% Gas In Air=10,000 Units-Connection - 0 Tools DGR, Resistivity, ECD API FL Chromatograph (ppm) -106' 3155' W OB Casing - - Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst - - Type - DRILPLEX NC3155'47 Depth in / out YP (lb/100ft2) 11.00 000 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 0 Hours C-3 -- Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Casing Surface Section PV 3049' Footage 33.60 W all / Finkbiner ShClyst - - TuffGvlCoal cP 10 - - Gas Summary 0 0 0 (current) Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3155' 3155' 0' Max @ ft Current -0.0 Date: Time: 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 17.5133 MBT - pH 0.994 0 0 0 Siltst - - Units* Casing Summary Lithology (%) 0 - 0 0 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize 45.5#- Grade 10.75'' (max)(current) 0 0 Cly 0 - . . * 24 hr Recap: (max)(current) 0 0 Cly 0 - Set AtSize 45.5#- Grade 10.75'' 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould - 0 0 - - Units* Casing Summary Lithology (%) 0 MBT - pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.5133 C-5n - 0.0 C-2 0 in 0 -Minimum Depth Time: equipment. Circulated and conditioned mud then pumped cement. Rigged down cement equipment and nipple down the diverter. 0 3155' 3155' 0' Max @ ft Current -0.0 Date: Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) - - Gas Summary 0 0 0 (current) W all / Finkbiner ShClyst - - TuffGvlCoal cP 16 3049' Footage 33.60 - Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 N/D Diverter PV - 24 hr Max Weight 0 Hours C-3 - 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.30 000 - DRILPLEX NC3155'17 Depth in / out Mud Type Lst - - Type Average -0Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools DGR, Resistivity, ECD API FL Chromatograph (ppm) -106' 3155' W OB Casing 100% Gas In Air=10,000 Units-Connection - 0 2 3145' Condition - Bit # 1 7.8 13.5 - Milled Tooth Bit - Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Jan-2015 12:00 AM Current Pump & Flow Data: - Max 0 Chlorides mg/l 400.00 Continue running casing into the hole. Made up hanger and liner joint and couldn't sting into it. Rigged up cementing Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Nippled up diverter and monitored well which was static. Nippled down diverter and prepared for cement job. Blew air Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 28-Jan-2015 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition - Bit # 1 7.8 13.5 - Milled Tooth Bit - Size 2 on W ell and rigged up scaffolding. 3145' 100% Gas In Air=10,000 Units-Connection - 0 Tools DGR, Resistivity, ECD API FL Chromatograph (ppm) -106' 3155' W OB Casing - - Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst - - Type - DRILPLEX NC/NA3155'19 Depth in / out YP (lb/100ft2) 10.30 000 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 0 Hours C-3 -- Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Nipple Up BOPE PV 3049' Footage 33.60 W all / Finkbiner ShClyst - - TuffGvlCoal cP 15 - - Gas Summary 0 0 0 (current) Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3155' 3155' 0' Max @ ft Current -0.0 Date: Time: through conduit to confirm it was not plugged. Rigged up cementers and cemented a top job. Nippled up well head and set BOPE stack 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 17.550 MBT - pH 0.994 0 0 0 Siltst - - Units* Casing Summary Lithology (%) 0 - 0 0 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize 45.5#- Grade 10.75'' (max)(current) 0 0 Cly 0 - . . * 24 hr Recap: (max)(current) 0 0 Cly 0 - Set AtSize 45.5#- Grade 10.75'' 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould - 0 0 - - Units* Casing Summary Lithology (%) 0 MBT - pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.579 C-5n - 0.0 C-2 0 in 0 -Minimum Depth Time: Flooded MPD and BOPE and tested for leaks. Attempted to test BOPE with 5" test joint and observed leak in TGB spoil control line port. 0 3155' 3155' 0' Max @ ft Current -0.0 Date: Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) - - Gas Summary 0 0 0 (current) Coates / Finkbiner ShClyst - - TuffGvlCoal cP 17 3049' Footage 33.60 - Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Testing BOPE's PV - 24 hr Max Weight 0 Hours C-3 - 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.60 000 - DRILPLEX NC/NA3155'31 Depth in / out Mud Type Lst - - Type Average -0Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools DGR, Resistivity, ECD API FL Chromatograph (ppm) -106' 3155' W OB Casing 100% Gas In Air=10,000 Units-Connection - 0 2 W aited on FMC wellhead Representative. Currently testing BOPE's. 3145' Condition - Bit # 1 7.8 13.5 - Milled Tooth Bit - Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 29-Jan-2015 12:00 AM Current Pump & Flow Data: - Max 0 Chlorides mg/l 400.00 Rigged up scaffolding and continued to nipple up BOPE. Rigged up circulation lines to MPD, RCD, and set test plugs. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Tested BOPE's and then rigged down testing equipement. Also rigged up new catch can on BOPE and installed mud skirt Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 30-Jan-2015 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Condition - Bit # 1 7.8 13.5 - Milled Tooth Bit - Size 2 continuing singles in hole from 1707' to 2749' MD. sources to the rig floor. Singles in hole from shed with 5" drill pipe from 772' to 1707' MD. Shallow Pulse Test MWD at 430 gpm. Currently 3145' 100% Gas In Air=10,000 Units-Connection - 0 Tools DGR, Resistivity, ECD API FL Chromatograph (ppm) -106' 3155' W OB Casing - - Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst - - Type - DRILPLEX NC3155'31 Depth in / out YP (lb/100ft2) 10.60 000 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 0 Hours C-3 -- Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Singling In Hole w/ 5" DP PV 3049' Footage 33.60 Coates / Finkbiner ShClyst - - TuffGvlCoal cP 17 - - Gas Summary 0 0 0 (current) Avg to 468' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3155' 3155' 0' Max @ ft Current -0.0 Date: Time: and drain hoses. Rigged up to pick up and rack back 5" drill pipe. Picked up and racked back 111 joints. MOB BHA tools and nuke 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 17.5114 MBT - pH 0.994 0 0 0 Siltst - 0 Units* Casing Summary Lithology (%) 0 - 0 0 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize 45.5#- Grade 10.75'' (max)(current) 0 0 Cly 0 - . . . * 24 hr Recap: (max)(current) 46 0 Cly 7025 - Set AtSize 45.5#- Grade 10.75'' 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould 10% 1942 515 694 86 Units* Casing Summary Lithology (%) 0 MBT - pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.558 C-5n 3920' 126.0 C-2 59 No losses to the formation. in 2 3288'Minimum Depth Time: cement manifold. Bypassed washout. Rigged down testing equipment. Running in hole from 2926' MD to 3019' MD to wash out and ream 17 Max Gas = 59 units 3155' 4318' 1163' Max @ ft Current 4223'96.9 Date: Avg to3155' Yesterday's Depth: Current Depth: 24 Hour Progress: 176.3 Flow In (gpm) Flow In (spm) - - Gas Summary 0 0 0 (current) Coates / Finkbiner ShClyst - - TuffGvlCoal cP 13 3049' 9.875 0.990 Footage 9.30 - 33.60 90% Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV - 24 hr Max Weight 10 Hours C-3 - 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.00 000 140 - PDC Bit LSND 5.9 3155' 4318'27 - Depth in / out Mud Type Lst - - Type Average -21Background (max) Trip 10.2510.47 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, ECD, Resistivity API FL Chromatograph (ppm) 6000 -106' 3155' WOB Casing 100% Gas In Air=10,000 Units-Connection - 0 2 3111' MD. Performed LOT test. Displaced well to 9.5 ppg LSND mud. Drilling from 3175' MD to 4318' MD. TVD=3978' MD. hole. Drill out float equipment to 3155' MD. Drilling from 3155' MD to 3175' MD. Circulated bottoms up at drilling rate. Pulled out of hole to 3145' Condition - Bit # 1 5.5 13.5 9.50 Milled Tooth Bit 9.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.72 Doyon 141 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 31-Jan-2015 12:00 AM Current Pump & Flow Data: 2004 Max 0 Chlorides mg/l 350.00 Rigged up to test casing. Circulated bottoms up at 380 gpm. Attempted to test casing and there was a wash out on the Density (ppg) out (sec/qt) Viscosity Cor Solids % . . . * 24 hr Recap:Drilling from 4318' MD to 5155' MD with a TVD of 3456' when swivel packing began to leak. Decision made to circulate Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 350.00 12 1-Feb-2015 12:00 AM Current Pump & Flow Data: 2380 Max - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.41 Doyon 141 Report For: Condition - Bit # 1 7.3 13.5 9.50 Milled Tooth Bit 9.50 Size 2 ahead from 5156' to 5709' MD with a TVD of 3706'. installed. Ran into hole from 3111' to 5064' MD. Wash and ream from 5064' MD and circulated bottoms up at 700 GPM. Currently drilling 3145' 100% Gas In Air=10,000 Units-Connection - 99 Tools Gamma, ECD, Resistivity API FL Chromatograph (ppm) 6400 -106' 3155' WOB Casing 8.5510.69 Avg Min Comments RPM ECD (ppg) ml/30min 49Background (max) Trip Average - Mud Type Lst - - Type 140 - PDC Bit LSND 4.5 3155' 5709'26 - Depth in / out YP (lb/100ft2) 9.60 010 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 85 Hours C-3 -20% Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV 3049' 9.875 0.990 Footage 21.00 - 33.60 Coates / Finkbiner ShClyst - - TuffGvlCoal cP 13 - - Gas Summary 0 8 0 (current) Avg to3155' Yesterday's Depth: Current Depth: 24 Hour Progress: 280.7 Flow In (gpm) Flow In (spm) 4318' 5709' 1391' Max @ ft Current 5161'191.2 Date: Time: bottoms up at 700 gpm and pull up to the shoe. Tested swivel PKG to 3500 PSI. The test was good so the cement line manifold was 27 Max Gas = 85 units No losses to the formation. in 2 5571'Minimum Depth C-5n 5526' 145.0 C-2 85 SPP (psi) Gallons/stroke TFABit Type Depth 18.855 MBT - pH 0.994 0 9 0 Siltst 694 86 Units* Casing Summary Lithology (%) 1 80% 2937 39 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize 45.5#- Grade 10.75'' (max)(current) 445 0 Cly 9117 - . . . * 24 hr Recap:Drilling from 5709' to 6586' MD when drilling through C-40 Zone and getting gas back when having trouble with CAT Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 1532 2-Feb-2015 12:00 AM Current Pump & Flow Data: 2666 Max - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.99 Doyon 141 Report For: Condition - Bit # 1 8.3 13.5 9.70 Milled Tooth Bit 9.50 Size 2 No losses to the formation. MD and monitored the well which was static. Run in hole from 4786' to 6455' MD. Continued drilling from 6586' to 7105' MD. TVD = 4461'. fill. The decision was made to back ream out of hole and run in hole to 5991' MD Kelly up. Continued to back ream out of hole to 4786' to 6549' MD and monitored the well which was static. Pump out of hole from 6549' MD to 5945' MD and the hole was not taking the proper 3145' 100% Gas In Air=10,000 Units-Connection - 6939 Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Chromatograph (ppm) 12500 -106' 3155' WOB Casing 10.4310.73 Avg Min Comments RPM ECD (ppg) ml/30min 309Background (max) Trip Average 603 Mud Type Lst - - Type 140 - PDC Bit LSND 4.3 3155' 7105'24 - Depth in / out YP (lb/100ft2) 9.80 190560160 00 CementCht Silt C-4i C-4n - 24 hr Max Weight 2639 Hours C-3 -20% Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Drilling Ahead PV 3049' 9.875 0.990 Footage 33.40 - 33.60 Coates / Finkbiner ShClyst - - TuffGvlCoal cP 13 - - Gas Summary 0 2045 515 (current) Avg to3155' Yesterday's Depth: Current Depth: 24 Hour Progress: 175.6 Flow In (gpm) Flow In (spm) 5709' 7105' 1396' Max @ ft Current 6180'85.9 Date: Time: power. Decision was made to weight mud to 9.7 ppg and trip back to the shoe and circulate at 600 gpm. Pulled out of hole from 6586' 267 Max Gas =1632 units in 5 6407'Minimum Depth C-5n 6641' 134.2 C-2 1632 SPP (psi) Gallons/stroke TFABit Type Depth 25.051 MBT - pH 0.994 14 854 0 Siltst 689 85 Units* Casing Summary Lithology (%) 220 80% 21242 237 907-670-4906Unit Phone: 583 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould Set AtSize 45.5#- Grade 10.75'' (max)(current) 13447 27 Cly 101841 - . . . * 24 hr Recap: (current) 10485 23 Cly 94053 - 45.5#- Grade 10.75'' 907-670-4906Unit Phone: 599 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould 40% 14136 0 681 85 Units* Casing Summary Lithology (%) 109 MBT 9289' pH 0.994 0 705 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.847 0.0 C-2 1351 Set AtSize Minimum Depth C-5n 9255' in 5 9011' (max) Time: pumped 32 barrels of High Vis sweep. 204 7105' 9289' 2184' Max @ ft Current 7962'93.9 Date: Avg to3155' Yesterday's Depth: Current Depth: 24 Hour Progress: 171.4 Flow In (gpm) Flow In (spm) - - Gas Summary 0 1810 510 (current) Coates / Lundale ShClyst - - TuffGvlCoal cP 9 3049' 9.875 0.990 Footage 49.60 6134' 33.60 15% Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 TD Intermediate. CBU. PV - 24 hr Max Weight 1377 Hours C-3 35% 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 10.40 160334120 138 - PDC Bit LSND 4.7 3155' 9289'29 9289' Depth in / out Mud Type Lst 10% - Type Average -548Background (max) Trip 10.5810.80 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Chromatograph (ppm) 3100 -106' 3155' W OB Casing 100% Gas In Air=10,000 Units-Connection - 5296 2 No losses to the formation. Max Gas = 1351 units 3145' Condition - Bit # 1 8.3 13.5 9.70 Milled Tooth Bit 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.98 Doyon 141 Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 3-Feb-2015 12:00 AM Current Pump & Flow Data: 2307 Max 708 % Chlorides mg/l 500.00 Drilled from 7105' to 9289' MD and TD 9.875' Intermediate Section. Currently circulating bottoms up at 700 bpm and Density (ppg) out (sec/qt) Viscosity Cor Solids . . . * 24 hr Recap: (current) 5122 0 Cly 34054 - 45.5#- Grade 10.75'' 907-670-4906Unit Phone: 492 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould - 4555 0 - - Units* Casing Summary Lithology (%) 109 MBT 9289' pH 0.994 0 482 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 19.545 0.0 C-2 1222 Set AtSize Minimum Depth C-5n - in -- (max) Time: from 8971' MD to 8000' MD holding 220 PSI at surface. Pulled out of hole from 8000' MD to 5000' MD holding 170 PSI at surface. Pulled 100 Max Gas = 1222 units 9289' 9289' 0' Max @ ft Current -0.0 Date: Avg to3155' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) - - Gas Summary 0 1302 407 (current) Coates / Lundale ShClyst - - TuffGvlCoal cP 10 3049' 9.875 0.990 Footage 49.60 6134' 33.60 - Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Testing 7 5/8" Rams PV - 24 hr Max Weight 766 Hours C-3 - 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.90 147318115 - - PDC Bit LSND 4.3 3155' 9289'25 9289' Depth in / out Mud Type Lst - - Type Average 1067-Background (max) Trip - - Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Chromatograph (ppm) - -106' 3155' W OB Casing 100% Gas In Air=10,000 Units-Connection - 3163 2 hole on elevators. Laid down BHA. Changed out upper rams to 7 5/8". out of hole from 5000' MD to surface. Staged down PSI to maintain desired ECD. Monitored well and it was static. Continue to pull out of 3145' Condition - Bit # 1 8.3 13.5 9.70 Milled Tooth Bit 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 14 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Feb-2015 12:00 AM Current Pump & Flow Data: - Max 597 % Chlorides mg/l 650.00 Trip Gas = 1067 units Continued to circulate bottoms up at 700 gpm. Monitored well & it was static. Installed MPD bearing and pulled out of hole Density (ppg) out (sec/qt) Viscosity Cor Solids . . . * 24 hr Recap: (current) Casing 1134 23 Cly 25798 - Maximum Report By:Logging Engineers:D. Acker / A. Gould 45.5#10.75'' 7.63'' 907-670-4906Unit Phone: 107 Autumn Gould Units* Casing Summary Lithology (%) 27 - MBT pH - 2977 119 8 Siltst C-2 144 Bit Type Depth 19.553 0.0 0.994 9289' 244 Set AtSize Minimum Depth in 7 C-5n 5250' 100% Gas In Air=10,000 Units- (max) Time:Coates / Lundale ShClyst SPP (psi) Gallons/stroke preventer. Mobilized casing equipment. Ran in hole with 7.625" casing from the surface to 3129' MD. Circulated bottoms up and ramped 34 No reported losses. 283745' 9289' 9289' 0' Max @ ft Current -0.0 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 173 40 (current)- Avg to3155' cP 9 3049' - Cement - - - Grade 0.990 Footage 49.60 6134' 33.60 - Coal TFA Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Circulating Bottoms Up PV 9.875 24 hr Max 39# Weight 167 Hours C-3 - 0 Cht Silt C-4i C-4n - TuffGvl Gas Summary YP (lb/100ft2) 9.80 407432 - - PDC Bit LSND 4.6 3155' 9289'21 9289' Depth in / out Mud Type Lst - - Type Average 244161Background (max) Trip - - Avg Min Comments - RPM ECD (ppg) ml/30min Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Chromatograph (ppm) - -106' 3155' W OB Casing Connection - 592 0 257 97 30 2 7558' MD. Continued to circulate bottoms up. BPM to 6 BPM. Continued to run in hole from 3808' MD to 5328' MD. Circulated bottoms up. Continued to run in hole from 5328' MD to pumps up t 6 BPM. Continued running in hole from 3129' MD to 3808' MD and encountered a tight spot. Circulated bottoms up from 2 9289' 3145' Condition - Bit # 1 8.3 13.5 9.70 Milled Tooth Bit 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 5-Feb-2015 12:00 AM Current Pump & Flow Data: 534 Max 120 % Chlorides mg/l 650.00 Max Gas = 244 Units Serviced rig and performed dummy run with hanger. Rigged up to test 7.625" test JT. Tested 7.625" JT and annular Density (ppg) out (sec/qt) Viscosity Cor Solids . . . * 24 hr Recap: (current) Casing 4060 0 Cly 48969 - Maximum Report By:Logging Engineers:D. Acker / A. Gould 45.5#10.75'' 7.63'' 907-670-4906Unit Phone: 256 Autumn Gould Units* Casing Summary Lithology (%) 52 - MBT pH - 6881 327 0 Siltst C-2 18 Bit Type Depth 20.047 0.0 0.994 9289' 558 Set AtSize Minimum Depth in 2 C-5n 7547' 100% Gas In Air=10,000 Units- (max) Time:Coates / Lundale ShClyst SPP (psi) Gallons/stroke 10.2 ppg. Continued to circulate until mud weight dropped to 9.7 ppg. Running in hole from 8019' MD to 8530' MD. There was a tight spot 79 Trip Gas = 558 Units 09288' 9289' 9289' 0' Max @ ft Current -0.0 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) - - (current)- Avg to3155' cP 8 3049' - Cement - - - Grade 0.990 Footage 49.60 6134' 33.60 - Coal TFA Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Running Lockdowns PV 9.875 24 hr Max 39# Weight 570 Hours C-3 - 0 Cht Silt C-4i C-4n - TuffGvl Gas Summary YP (lb/100ft2) 9.80 5713849 - - PDC Bit LSND 4.6 3155' 9289'19 9289' Depth in / out Mud Type Lst - - Type Average 5588Background (max) Trip - - Avg Min Comments - RPM ECD (ppg) ml/30min Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Chromatograph (ppm) - -106' 3155' W OB Casing Connection - 2055 0 777 237 0 2 plug. Rigged down cement head. Cleaned stack and pulled landing joint. Set pack off. Run in lock downs. from 8530' MD to 9249' MD. Landed casing at 9279' MD. Rigged up and pumped cement. Swap over and pump 419 barrels mud to bump at 8530' MD but worked through it. Lost returns so picked up casing and continued to circulate until regained returns. Pump down casing 9279' 3145' Condition - Bit # 1 7.8 13.5 9.70 Milled Tooth Bit 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk - - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 6-Feb-2015 12:00 AM Current Pump & Flow Data: - Max 305 % Chlorides mg/l 650.00 Max Gas = 558 Units Circulated bottoms up and running in hole from 7558' MD to 8019' MD. Circulated mud coming back had a mud weight of Density (ppg) out (sec/qt) Viscosity Cor Solids . . . * 24 hr Recap:Tested pack off to 5000 psi and the test was good. Rigged up to lay down drill pipe and then laid down 5" drill pipe. Density (ppg) out (sec/qt) Viscosity Cor Solids mg/l 650.00 0 % 7-Feb-2015 12:00 AM Current Pump & Flow Data: - Max Chlorides Depth ROP ROP (ft/hr) 4.23 @ Mud Data Morning Report Report # 17 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 Report For: 7.8 13.5 9.70 Milled Tooth Bit 9.50 Size Rigged up to lay down 4" drill pipe. 9279' 3145' Condition - Bit # 1 - - Connection - 0 0 0 0 0 Chromatograph (ppm) - -106' 3155' W OB Casing - - Avg Min Comments - RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst - - Type - PDC Bit LSND 4.6 3155' 9289'18 9289' Depth in / out 2 YP (lb/100ft2) 9.30 000 Cht Silt C-4i C-4n - TuffGvl Gas Summary 24 hr Max 39# Weight 0 Hours C-3 - 0 Ss (ppb Eq) C-1 C-5i AK-AM-0902065084 Lay down mouse hole PV 9.875 0.990 Footage 49.60 6134' 33.60 - Coal TFA - cP 10 3049' - Cement - - - Grade (current)- Avg to3155' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) - - 9289' 9289' 0' Max @ ft Current -0.0 Date: Pumped 100 barrels of ISOTHERM NT to freeze protect well with an insulating fluid. Serviced top drive. Cleaned and cleared rig floor. 0 0- (max) Time:Coates / Lundale ShClyst SPP (psi) Gallons/stroke C-5n - 100% Gas In Air=10,000 Units- 0 Set AtSize Minimum Depth in 0 Bit Type Depth 20.051 0.0 0.994 9289' Tools Gamma, ECD, Resistivity, Density, Nuetron API FL 0 0 Siltst C-2 0 Units* Casing Summary Lithology (%) 0 - MBT pH - 0 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers:D. Acker / A. Gould 45.5#10.75'' 7.63'' (current) Casing 0 0 Cly 0 - . . . * 24 hr Recap: -3 PDC Bit 6.5 0.383 - - (current) Casing 0 0 Cly 0 - D. Acker / A. Gould 45.5#10.75'' 7.63'' 907-670-4906Unit Phone: 0 Autumn Gould Maximum Report By:Logging Engineers: 0 - MBT pH - 0 0 Siltst C-2 0 Depth 20.050 0.0 0.994 - Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Set AtSize Minimum Depth in 0 Bit Type - 100% Gas In Air=10,000 Units- 0 Coates / Lundale ShClyst SPP (psi) Gallons/stroke C-5n - --- singled in the hole to 1530' MD. Shallow hole test MWD pump at 200 gpm was completed. Ran in hole to 5418'. Started logging with sonic 0 0- 9289' 9289' 0' Max @ ft Current -0.0 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) - - Avg to - 0 - Grade (current)- Units* Casing Summary Lithology (%) - cP 10 3049' - Cement - - AK-AM-0902065084 RIH with 4" Drill Pipe PV 9.875 0.990 Footage 49.60 6134' 0 Hours C-3 - 0 C-1 C-5i 33.60 - TuffGvl Gas Summary 24 hr Max 29# Weight Ss (ppb Eq) Coal 0 0 Cht Silt C-4i C-4n - 9289'18 9289' Depth in / out 2 YP (lb/100ft2) TFA Mud Type Lst - - Type Average -Background (max) Trip (max) - RPM ECD (ppg) ml/30min 0 - PDC Bit LSND 4.6 -106' 3155' WOB Casing - - Comments 3155' 9.30 Connection - 0 0 0 0 1 - - 9.70 Milled Tooth Bit 9.50 Size tool and ran in the hole to 6260' MD at 900' per hour. 9279' 3145' Condition - Bit # MWD Summary 96% Rig Activity: - Doyon 141 Report For: Avg Min Time:Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: ROP (ft/hr) 4.23 @ Mud Data Morning Report Report # 18 Customer: Well: Area: Location: 0 8-Feb-2015 12:00 AM Current Pump & Flow Data: - Max Chlorides Depth ROP 0 % 7.8 0 Chromatograph (ppm) - mg/l 650.00 13.5 Tested the BOPE and MPD chokes. Mobiliized BHA to rig floor and installed 9" wear bushing. Picked up the BHA and Density (ppg) out (sec/qt) Viscosity Cor Solids . . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids mg/l 40000.00 13.5 1055 % 6.0 140 Chromatograph (ppm) - 9-Feb-2015 12:00 AM Current Pump & Flow Data: 2027 Max Chlorides Depth ROP 90 ROP (ft/hr) 4.23 @ Mud Data Morning Report Report # 19 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.70 Doyon 141 Report For: Avg Min Time: 9.70 Milled Tooth Bit 9.50 Size and circulated bottoms up and monitored well. Continued to drill from 9309' MD to 9421' MD. 9279' 3145' Condition - Bit # Max Gas = 1071 units Drilled out float equipment and shoe track from 9189' MD to 9270' MD. Circulated and conditioned mud, then performed a Connection - 3391 20 871 207 WOB Casing 10.5810.62 Comments 3155' 10.00 - - - RPM ECD (ppg) ml/30min 825 - PDC Bit LSND 4.5 Background (max) Trip (max) Average - Mud Type Lst - - Type 18 9289' Depth in / out 2 YP (lb/100ft2) TFA -106' 3155' 289 75 Cht Silt C-4i C-4n - Gvl Gas Summary 24 hr Max 29# Weight Ss (ppb Eq) Coal 9421' 2418 Hours C-3 - 26 C-1 C-5i 33.60 - AK-AM-0902065084 Drilling Ahead PV 9.875 0.990 Footage 49.60 6134'- cP 10 3049' - Cement - - Tuff - Grade (current)- Units* Casing Summary Lithology (%) Avg to9289' 1071 Yesterday's Depth: Current Depth: 24 Hour Progress: 144.1 Flow In (gpm) Flow In (spm) 228 54 9289' 9421' 132' Max @ ft Current 9328'35.2 Date: LOT. Installed bearing assembly and removed tripple nipple. Run in hole from 9261' MD to 9309' MD and displaced mud. Monitored well 285 No reported losses. 619375' Coates / Lundale ShClyst SPP (psi) Gallons/stroke C-5n - -- 80 9408' 100% Gas In Air=10,000 Units- 351 Set AtSize Minimum Depth in 33 Bit Type 1 Depth 5.050 26.1 0.994 - Tools Gamma, ECD, Resistivity, Density, Nuetron API FL C-2 1574 - MBT pH 100% 23801 22 907-670-4906Unit Phone: 242 Autumn Gould Maximum Report By:Logging Engineers: 120 D. Acker / A. Gould 45.5#10.75'' 7.63'' Siltst (current) Casing 8142 217 Cly 83724 - -3 PDC Bit 6.5 0.383 2.80 9289' . . . * 24 hr Recap: -3 PDC Bit 6.5 0.383 20.90 9289' Casing 29227 130 Cly 265267 - D. Acker / A. Gould 45.5#10.75'' 7.63'' Siltst 907-670-4906Unit Phone: 1260 Autumn Gould Maximum Report By:Logging Engineers: 739 - MBT pH 90% 97774 11 C-2 973 Depth 6.851 82.0 0.994 - Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Set AtSize Minimum Depth in 35 Bit Type 1 9737' 100% Gas In Air=10,000 Units- 1834 Coates / Lundale ShClyst SPP (psi) Gallons/stroke C-5n - -- 71 1547 3110296' 9421' 11121' 1700' Max @ ft Current 10286'91.6 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 124.9 Flow In (gpm) Flow In (spm) 228 54 Avg to9289' 4317 - Grade (current)- Units* Casing Summary Lithology (%) - Cement - - Tuff AK-AM-0902065084 Drilling Ahead PV 9.875 0.990 Footage 49.60 6134' 10775 Hours C-3 - 15 C-1 C-5i 33.60 - Gas Summary 24 hr Max 29# Weight Ss (ppb Eq) Coal 11121' - 537 Cht Silt C-4i C-4n - Gvl 2 YP (lb/100ft2) TFA -106' 3155' cP 14 3049' Mud Type Lst 10% - Type 20 9289' Depth in / out Average - (max) Trip (max)(current) 495 - PDC Bit Kla-Shield 3.9 Background 10.5610.83 Comments 3155' 9.80 - RPM ECD (ppg) ml/30min Connection - 15014 9 4518 1111 1917 No reported losses. Continued to drill from 9436' MD (TVD = 4243') to 11114' MD (TVD = 5253'). Time: 9.70 Milled Tooth Bit 9.50 Size Max Gas = 4317 units 9279' 3145' Condition - Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.07 Doyon 141 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk 644 ROP (ft/hr) 4.23 @ Mud Data Avg Min Bit # Chlorides Depth ROP % 10.0 76 Chromatograph (ppm) - 10-Feb-2015 12:00 AM Current Pump & Flow Data: 2392 Max 13.5 5653 mg/l 45000.00 WOB Casing - - Density (ppg) out (sec/qt) Viscosity Cor Solids . * 24 hr Recap: - - Density (ppg) out (sec/qt) Viscosity Cor Solids 5315 mg/l 46000.00 11-Feb-2015 12:00 AM Current Pump & Flow Data: 2791 Max 13.5 WOB Casing % 8.0 573 Chromatograph (ppm) - Min Bit # Chlorides Depth ROP North Slope AK Kuparuk 664 ROP (ft/hr) 4.23 @ Mud Data Avg Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. Condition - Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.51 Doyon 141 Continued to drill from 11114' MD to 12825' MD with a TVD of 5238'. Time: 9.70 Milled Tooth Bit 9.50 Size Max Gas = 3635 units 9279' No reported losses. 139 4899 1318 1813 11.0211.25 Comments 3155' 9.90 - RPM ECD (ppg) ml/30min - PDC Bit Kla-Shield 3.8 Background Connection (max) Trip (max)(current) 494 Average - Lst 20% - Type - 14552 3145' 2 YP (lb/100ft2) TFA -106' 3155' cP 12 3049' 12825' - 533 Cht Silt C-4i C-4n 24 hr Max 29# Weight Ss (ppb Eq) Coal Mud Type 25 9289' Depth in / out 10216 Hours C-3 - 190 C-1 C-5i 33.60 - AK-AM-0902065084 Drilling Ahead PV 9.875 0.990 Footage 49.60 6134' - Cement - - TuffGvl - Grade (current)- Units* Casing Summary Lithology (%) Avg to9289' 3635 Yesterday's Depth: Current Depth: 24 Hour Progress: 126.8 Flow In (gpm) Flow In (spm) 237 56 11121' 12825' 1704' Max @ ft Current 11325'70.8 Date: 1532 34112737' W all / Lundale ShClyst SPP (psi) Gallons/stroke C-5n - - 13000 120 11342' 100% Gas In Air=10,000 Units- 1988 Set AtSize Minimum Depth in 171 Bit Type 1 Depth 6.350 82.8 0.994 - Tools Gamma, ECD, Resistivity, Density, Nuetron API FL C-2 4087 - MBT pH 80% 95110 113 907-670-4906Unit Phone: 1540 Autumn Gould Maximum Report By:Logging Engineers: 690 D. Acker / A. Gould 45.5#10.75'' 7.63'' Siltst 673 Cly 210558 - Gas Summary - -3 PDC Bit 6.5 0.383 40.70 9289' Casing 24808 . * 24 hr Recap: Max Gas = 3351 units 22885 -3 PDC Bit 6.5 0.383 50.50 9289' 629 Cly 206413 - Gas Summary 5% D. Acker / A. Gould 45.5#10.75'' 7.63'' 106 907-670-4906Unit Phone: 1139 Autumn Gould Maximum Report By:Logging Engineers: 806 2387 - MBT pH 70% 105100 Depth 5.052 0.0 0.994 13768' Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Minimum Depth in 24 Bit Type 1 13468' 100% Gas In Air=10,000 Units- 1561 Wall / Lundale ShClyst SPP (psi) Gallons/stroke C-5n 13768' 4479' - 120 MD and then TD at 13768' MD (TVD = 5218'). Circulated bottoms up 2 times and monitored the well (static). Back reamed out of the hole 1730 No reported losses. 47313219' 12825' 13768' 943' Max @ ft Current 13386'69.9 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 132.2 Flow In (gpm) Flow In (spm) 237 56 Avg to9289' 3351 - Units* Casing Summary Lithology (%) Set AtSize C-2 TuffGvl - Grade (current) Siltst Casing 9.875 0.990 Footage 49.60 6134' - Cement - - 315 C-1 C-5i 33.60 - AK-AM-0902065084 BROOH PV 9289' Depth in / out 11523 Hours C-3 - C-4i C-4n 24 hr Max 29# Weight Ss (ppb Eq) Coal Mud Type 2211 3049' 13768' - 581 Cht Silt 12256 3145' 2 YP (lb/100ft2) TFA -106' 3155' Lst 25% - Type - Average - (max) Trip (max)(current) 425 PDC Bit Kla-Shield 3.8 Background Connection 11.34 Comments 9.70 - Time: 9.70 Milled Tooth Bit 9.50 Size from 13758' MD to 124500' MD. 9279' 192 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.70 Doyon 141 11.53ECD (ppg) Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk 713 ROP (ft/hr) 4.23 @ Mud Data Avg Min Bit # Chlorides Depth ROP ConditionRPM ml/30mincP % 9.0 623 Chromatograph (ppm) - - 3775 13.5 WOB Casing 975 2049 3155' - 41000.00 12-Feb-2015 12:00 AM Current Pump & Flow Data: 2791 Max Density (ppg) out (sec/qt) Viscosity Cor Solids 6139 mg/l - - Continued to drill from 12825' MD to 13295' MD and then had to change out the MPD bearing. Continued to drill from 13295' . * 24 hr Recap: hole from 5295' MD to 4523' MD. Max Gas = 1110 units circulated bottoms up 2 times. Pulled out of the hole with MPD and then the floats failed so unable to pull out of the hole on MPD. The Installed trip nipple and continued to pull out of the hole from 6185' MD to 5295' MD. Circulated out air boot then continued to pull out of decision was made to pump out of the hole 20 stands. Then line up on MPD pump out from 7295' MD to 6155' MD and then removed RCD. No reported losses. - - Continued to back ream out of the hole from 12450' MD to 9233' MD and then monitored the well (static) and then Density (ppg) out (sec/qt) Viscosity Cor Solids 806 mg/l 41000.00 13-Feb-2015 12:00 AM Current Pump & Flow Data: - Max 13.5 WOB Casing 481 408 3155' - - - 1658 Chlorides Depth ROP ConditionRPM ml/30mincP % 9.0 Kuparuk 197 ROP (ft/hr) 4.23 @ Mud Data Avg Min Morning Report Report # 23 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 -ECD (ppg) Time: 9.70 Milled Tooth Bit 9.50 Size 9279' 50 Report For: - Comments 9.70 - Connection (max)(current) 77 PDC Bit Background - (max) Trip - - Type - Average 2 YP (lb/100ft2) TFA -106' 3155' Kla-Shield 3.8 Bit # 13768' - 152 Cht Silt 4700 24 hr Max 29# Weight Ss (ppb Eq) Coal Mud Type 2514 3049' 1117 Hours C-3 - 41 Chromatograph (ppm) C-5i 33.60 - AK-AM-0902065084 Tripping Out of Hole PV 9289' Depth in / out 9.875 0.990 Footage 49.60 6134' - Cement - - TuffGvl - Grade (current) Siltst Casing 3145' Lst Casing Summary Lithology (%) Set AtSize C-2C-1 C-4i C-4n Avg to9289' 1110 - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) - - 13768' 13768' 0' Max @ ft Current -- Date: 149 756168'72 W all / Lundale ShClyst SPP (psi) Gallons/stroke C-5n 13768' 4479' -- 11936' 100% Gas In Air=10,000 Units- 647 Minimum Depth in 3 Bit Type 1 Depth 4.355 - 0.994 13768' Tools Gamma, ECD, Resistivity, Density, Nuetron API FL 56 - MBT pH - 6495 19 907-670-4906Unit Phone: 582 Autumn Gould Maximum Report By:Logging Engineers: 143 D. Acker / A. Gould 45.5#10.75'' 7.63'' 16 Cly 69410 - Gas Summary - 8468 -3 PDC Bit 6.5 0.383 50.50 9289' Units* . * 24 hr Recap: 5561' MD to 4493' MD to check set screws on the hanger. Currently checking the set screws on the hanger. No max gas to report. -3 PDC Bit 6.5 0.383 50.50 9289' - Gas Summary - 0 Units* 10.75'' 4.50'' 7.63'' 0 Cly Report By:Logging Engineers: 0 D. Acker / A. Gould 0 0 907-670-4906Unit Phone: 0 Autumn Gould Maximum Depth 4.355 - 0.994 13768' Tools Gamma, ECD, Resistivity, Density, Nuetron API FL Minimum Depth in 0 Bit Type 1 - 100% Gas In Air=10,000 Units- 0 SPP (psi) Gallons/stroke C-5n 13768' 4479' -- - MBT pH 0 0-00 0 13768' 13768' 0' Max @ ft Current -- Date: Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) - - Avg to9289' 12.6# 0 - Size C-2C-1 C-4i C-4n ShClyst - 45.5# (current) Siltst Casing 3145' Lst Casing Summary Lithology (%) - Set At 49.60 6134' - - Cement - - TuffGvl - AK-AM-0902065084 POOH PV 9289' Depth in / out Footage W all / Lundale 0 Hours C-3 - 0 Chromatograph (ppm) Ss (ppb Eq) Coal Mud Type 1911 3049'33.60 9.875 0.990 Silt 0 24 hr Max 29# Weight C-5i - 106' 3155' Kla-Shield 3.6 Bit # 13768' Average 2 - 0 Cht - (max) Trip (current) 0 PDC Bit Background - - Connection (max) - Comments 9.60 - Casing Type - YP Time: 9.50 Milled Tooth Bit 9.50 Size 9279' Report For: (lb/100ft2) TFA - Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 -ECD (ppg) Morning Report Report # 24 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Kuparuk 0 ROP (ft/hr) 4.23 @ Mud Data Avg Min Chlorides Depth ROP ConditionRPM ml/30mincP % 9.0 - - 0 0 Grade 13.5 WOB Casing 0 0 3155' - 40000.00 14-Feb-2015 12:00 AM Current Pump & Flow Data: - Max Density (ppg) out (sec/qt) Viscosity Cor Solids 0 mg/l - - Pulled out of the hole from 4523' MD to 528' MD and monitored the well (static). Then racked back heavy weigh drill pipe and jars. Brokedown and laid down the BHA. Pulled wear bushing and picked up single and wash stack. Set short wear ring. Picked up with 4" drill pipe from 4493' MD to 5561' MD. Due to left hand rotation by driller the decision was made to pull out of the hole from casing tools and rigged up to run casing. Ran into the hole with 4.5" liner. Picked up hanger and installed cross over and ran in the hole 8 barrel loss to the formation. . * 24 hr Recap: No reported losses. Max Gas = 2605 units from 8117' MD to 13068' MD. Completed wash down from 13068' MD to 13668' MD and positioned liner at 13654' MD. Dropped ball and filtered brine with 772 barrels. Monitored the well and it was static. Started to pull out of the hole on elevators from 9144' MD to 8390' MD. completed a pressure test and released running tool after the liner was set. Pressure tested the annular. Displaced the well to 9.7 ppg - - Ran in hole with lower completion on drill pipe to 7928' MD. Monitored the well and it was static. Continued to run in hole out (sec/qt) Viscosity Cor Solids 367 mg/l 15-Feb-2015 12:00 AM Current Pump & Flow Data: - Max Density (ppg) - 40000.00 13.5 WOB Casing 292 137 3155' Chlorides Depth ROP ConditionRPM ml/30mincP % 9.0 Kuparuk 40 ROP (ft/hr) 4.23 @ Mud Data Avg Min Morning Report Report # 25 Customer: Well: Area: Location: Rig: 3S-620 ConocoPhillips Alaska, Inc. North Slope AK Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 141 -ECD (ppg) Time: 9.70 Milled Tooth Bit 9.50 Size 9279' Report For: (lb/100ft2) TFA - 9.60 - Liner Type - - - 1769 PDC Bit Background - - Connection (max) Trip (current) - (max) 32 Cht - 0 W BM - Other 3.6 Bit # 13768' Average 2 24 hr Max 29# Weight C-5i - 106' 3155' - - Comments 0.990 Silt 5347 Grade 0 Chromatograph (ppm) Ss (ppb Eq) Coal Mud Type 1912 3049'33.60 Hours C-3 - AK-AM-0902065084 POOH PV 9289' Depth in / out Footage W all / Lundale YP 49.60 6134' - - Cement - - TuffGvl -45.5# (current) Siltst Casing 3145' Lst Casing Summary Lithology (%) - C-2C-1 C-4i C-4n ShClyst - Avg to9289' 12.6# 2605 - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) - - 13768' 13768' 0' Max @ ft Current -- Date: 0-00 0 6119 SPP (psi) Gallons/stroke C-5n 13768' 4479' -- - MBT pH - 100% Gas In Air=10,000 Units- 0 in 0 Bit Type 1 Size Set At 9.875 Depth 4.327 - 0.994 13768' Tools Gamma, ECD, Resistivity, Density, Nuetron API FL 0 907-670-4906Unit Phone: 338 Autumn Gould Maximum Minimum 99 Report By:Logging Engineers: 0 D. Acker / A. Gould 8 13654' 10.75'' 4.50'' 7.63'' 0 Cly - Gas Summary - 118064 Units*Depth -3 PDC Bit 6.5 0.383 50.50 9289' WELL INFORMATION Created On : Feb 25 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :3S-620 Job Number :AK-XX-0902065084 Rig Name :Doyon 141 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 27.50 0.00 0.00 27.50 0.00 N 0.00 E 0.00 0.00 96.63 0.25 278.61 96.63 0.02 N 0.15 W 0.02 0.36 132.87 0.59 278.90 132.87 0.06 N 0.41 W 0.06 0.94 173.73 0.52 261.74 173.73 0.07 N 0.80 W 0.07 0.44 237.33 1.46 129.65 237.32 0.49 S 0.46 W -0.49 2.91 273.07 2.72 119.48 273.04 1.20 S 0.62 E -1.20 3.66 331.59 3.54 131.52 331.47 3.08 S 3.19 E -3.08 1.79 424.89 2.57 149.17 424.64 6.78 S 6.41 E -6.78 1.44 473.46 2.24 185.60 473.17 8.66 S 6.88 E -8.66 3.16 562.26 3.95 237.74 561.85 12.02 S 4.12 E -12.02 3.52 654.20 6.15 265.52 653.44 14.10 S 3.47 W -14.10 3.51 747.03 6.37 283.12 745.73 13.32 S 13.44 W -13.32 2.07 840.56 7.42 283.52 838.58 10.73 S 24.36 W -10.73 1.12 934.26 7.18 284.69 931.52 7.83 S 35.91 W -7.83 0.30 1027.29 7.79 283.39 1,023.76 4.90 S 47.67 W -4.90 0.68 1122.70 9.18 286.46 1,118.12 1.24 S 61.26 W -1.24 1.53 1179.17 10.12 286.38 1,173.79 1.43 N 70.34 W 1.43 1.66 1272.97 12.89 279.50 1,265.70 5.49 N 88.57 W 5.49 3.29 1364.86 16.22 279.09 1,354.63 9.21 N 111.36 W 9.21 3.63 1456.31 20.00 281.06 1,441.53 14.23 N 139.33 W 14.23 4.19 1551.41 24.55 280.42 1,529.51 20.92 N 174.74 W 20.92 4.79 1642.85 28.85 279.18 1,611.18 27.88 N 215.22 W 27.88 4.74 1734.86 32.43 281.24 1,690.34 36.23 N 261.35 W 36.23 4.05 1828.05 33.99 281.31 1,768.31 46.21 N 311.40 W 46.21 1.67 1923.47 38.09 279.22 1,845.45 56.16 N 366.63 W 56.16 4.49 2015.33 41.22 277.88 1,916.16 64.86 N 424.60 W 64.86 3.53 2108.67 43.99 277.85 1,984.86 73.50 N 487.18 W 73.50 2.97 2201.77 45.70 278.40 2,050.87 82.78 N 552.17 W 82.78 1.88 2296.02 49.16 278.52 2,114.62 93.00 N 620.82 W 93.00 3.67 INSITE V8.1.10 Page 1Job No:AK-XX-0902065084 Well Name:3S-620 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2389.88 52.56 276.60 2,173.86 102.54 N 692.97 W 102.54 3.95 2483.01 55.16 277.50 2,228.78 111.78 N 767.60 W 111.78 2.90 2577.29 56.72 277.04 2,281.58 121.66 N 845.08 W 121.66 1.70 2669.63 61.46 274.36 2,329.01 129.48 N 923.88 W 129.48 5.70 2719.27 63.34 274.76 2,352.00 132.98 N 967.73 W 132.98 3.85 2760.93 62.93 274.90 2,370.83 136.11 N 1,004.76 W 136.11 1.03 2855.90 62.13 275.03 2,414.64 143.40 N 1,088.71 W 143.40 0.85 2948.61 62.68 274.51 2,457.58 150.23 N 1,170.59 W 150.23 0.77 3042.95 62.61 276.52 2,500.93 158.29 N 1,253.98 W 158.29 1.89 3073.74 62.94 276.08 2,515.02 161.29 N 1,281.20 W 161.29 1.66 3160.82 62.35 276.43 2,555.03 169.72 N 1,358.08 W 169.72 0.77 3223.14 63.20 276.68 2,583.54 176.04 N 1,413.13 W 176.04 1.41 3317.18 63.21 277.13 2,625.94 186.13 N 1,496.47 W 186.13 0.43 3410.21 63.18 276.47 2,667.89 195.97 N 1,578.91 W 195.97 0.63 3503.84 63.14 276.43 2,710.16 205.35 N 1,661.93 W 205.35 0.06 3596.00 63.14 276.84 2,751.80 214.85 N 1,743.59 W 214.85 0.40 3687.72 63.12 275.96 2,793.26 223.97 N 1,824.90 W 223.97 0.86 3781.30 63.13 276.22 2,835.56 232.83 N 1,907.90 W 232.83 0.25 3873.74 63.08 276.00 2,877.38 241.60 N 1,989.88 W 241.60 0.22 3965.62 63.10 276.28 2,918.96 250.36 N 2,071.34 W 250.36 0.27 4058.93 63.15 275.93 2,961.14 259.22 N 2,154.10 W 259.22 0.34 4152.89 63.15 276.59 3,003.58 268.36 N 2,237.43 W 268.36 0.63 4247.85 63.10 276.84 3,046.51 278.26 N 2,321.55 W 278.26 0.24 4341.09 63.16 276.40 3,088.65 287.85 N 2,404.17 W 287.85 0.43 4434.57 63.17 276.57 3,130.85 297.27 N 2,487.05 W 297.27 0.16 4526.99 63.12 276.59 3,172.60 306.72 N 2,568.96 W 306.72 0.06 4619.40 63.16 276.70 3,214.35 316.26 N 2,650.84 W 316.26 0.11 4713.18 63.15 276.70 3,256.70 326.02 N 2,733.94 W 326.02 0.01 4805.11 63.19 276.89 3,298.19 335.73 N 2,815.40 W 335.73 0.19 4897.05 63.19 276.37 3,339.66 345.20 N 2,896.91 W 345.20 0.50 4989.62 63.10 275.90 3,381.47 354.03 N 2,979.02 W 354.03 0.46 5082.59 63.10 275.44 3,423.54 362.22 N 3,061.53 W 362.22 0.44 5176.51 63.28 274.34 3,465.90 369.36 N 3,145.05 W 369.36 1.06 5269.10 63.17 275.37 3,507.61 376.36 N 3,227.41 W 376.36 1.00 5360.86 63.14 275.84 3,549.05 384.35 N 3,308.89 W 384.35 0.46 5452.61 63.21 276.35 3,590.45 393.05 N 3,390.30 W 393.05 0.50 5546.24 63.13 276.25 3,632.71 402.22 N 3,473.35 W 402.22 0.13 5638.25 63.15 275.81 3,674.28 410.84 N 3,554.98 W 410.84 0.43 5732.53 63.13 275.45 3,716.88 419.09 N 3,638.68 W 419.09 0.34 5824.91 63.21 276.11 3,758.58 427.39 N 3,720.70 W 427.39 0.64 5917.99 63.16 276.38 3,800.57 436.43 N 3,803.27 W 436.43 0.26 6011.12 63.20 275.66 3,842.58 445.14 N 3,885.93 W 445.14 0.69 6102.87 63.17 275.86 3,883.97 453.36 N 3,967.40 W 453.36 0.20 6196.11 63.18 276.01 3,926.05 461.97 N 4,050.16 W 461.97 0.14 6288.23 63.19 275.90 3,967.61 470.49 N 4,131.93 W 470.49 0.11 INSITE V8.1.10 Page 2Job No:AK-XX-0902065084 Well Name:3S-620 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6380.99 62.68 275.92 4,009.81 479.00 N 4,214.09 W 479.00 0.55 6474.69 63.03 276.00 4,052.56 487.66 N 4,297.02 W 487.66 0.38 6567.60 63.23 276.67 4,094.56 496.80 N 4,379.39 W 496.80 0.68 6663.92 63.03 277.12 4,138.09 507.12 N 4,464.69 W 507.12 0.47 6754.32 62.62 277.12 4,179.38 517.08 N 4,544.49 W 517.08 0.45 6847.74 62.97 275.24 4,222.09 526.03 N 4,627.09 W 526.03 1.83 6941.13 63.15 275.18 4,264.40 533.59 N 4,710.00 W 533.59 0.20 7034.03 63.22 274.87 4,306.31 540.85 N 4,792.59 W 540.85 0.31 7128.63 63.26 274.48 4,348.90 547.73 N 4,876.78 W 547.73 0.37 7220.74 63.23 275.20 4,390.37 554.67 N 4,958.73 W 554.67 0.70 7313.28 62.70 276.15 4,432.43 562.82 N 5,040.76 W 562.82 1.08 7406.70 62.72 276.46 4,475.26 571.94 N 5,123.28 W 571.94 0.30 7500.89 63.20 276.15 4,518.08 581.15 N 5,206.66 W 581.15 0.59 7593.47 63.19 276.69 4,559.83 590.39 N 5,288.78 W 590.39 0.52 7686.32 63.17 276.89 4,601.73 600.19 N 5,371.06 W 600.19 0.19 7778.78 63.22 276.68 4,643.42 609.94 N 5,453.00 W 609.94 0.21 7873.14 63.31 278.02 4,685.87 620.72 N 5,536.58 W 620.72 1.27 7966.46 63.89 281.27 4,727.37 634.73 N 5,618.97 W 634.73 3.18 8061.82 64.50 284.88 4,768.90 654.15 N 5,702.57 W 654.15 3.47 8105.54 65.02 286.25 4,787.54 664.76 N 5,740.67 W 664.76 3.07 8154.03 65.24 289.46 4,807.94 678.25 N 5,782.53 W 678.25 6.02 8198.80 65.64 291.34 4,826.55 692.44 N 5,820.70 W 692.44 3.92 8247.08 65.96 293.17 4,846.34 709.12 N 5,861.45 W 709.12 3.52 8291.86 66.12 295.12 4,864.53 725.86 N 5,898.79 W 725.86 4.00 8339.30 66.44 297.29 4,883.61 745.04 N 5,937.75 W 745.04 4.24 8381.72 66.68 299.35 4,900.49 763.50 N 5,972.01 W 763.50 4.49 8431.49 67.04 302.36 4,920.05 786.97 N 6,011.29 W 786.97 5.61 8477.50 67.33 304.29 4,937.89 810.27 N 6,046.73 W 810.27 3.92 8524.46 67.80 306.50 4,955.81 835.41 N 6,082.11 W 835.41 4.46 8567.64 68.13 309.07 4,972.02 859.93 N 6,113.74 W 859.93 5.57 8617.75 68.63 311.06 4,990.48 889.91 N 6,149.39 W 889.91 3.82 8663.03 68.86 313.57 5,006.90 918.32 N 6,180.59 W 918.32 5.19 8712.03 69.21 316.59 5,024.43 950.72 N 6,212.89 W 950.72 5.80 8760.60 69.62 319.11 5,041.51 984.42 N 6,243.40 W 984.42 4.93 8805.29 69.91 320.71 5,056.97 1,016.50 N 6,270.40 W 1016.50 3.42 8857.17 70.35 323.65 5,074.61 1,055.04 N 6,300.31 W 1055.04 5.40 8897.07 70.67 325.08 5,087.92 1,085.61 N 6,322.23 W 1085.61 3.47 8941.51 71.06 327.76 5,102.49 1,120.59 N 6,345.45 W 1120.59 5.76 8990.73 71.66 329.33 5,118.22 1,160.37 N 6,369.78 W 1160.37 3.26 9034.13 73.11 331.33 5,131.36 1,196.31 N 6,390.25 W 1196.31 5.52 9085.39 74.57 333.77 5,145.63 1,240.00 N 6,412.94 W 1240.00 5.39 9135.39 76.12 335.51 5,158.28 1,283.71 N 6,433.66 W 1283.71 4.58 9177.86 77.80 336.97 5,167.86 1,321.57 N 6,450.33 W 1321.57 5.18 9218.45 79.44 338.93 5,175.87 1,358.45 N 6,465.26 W 1358.45 6.22 9299.87 81.95 340.88 5,189.03 1,433.90 N 6,492.86 W 1433.90 3.88 INSITE V8.1.10 Page 3Job No:AK-XX-0902065084 Well Name:3S-620 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 9340.50 83.41 341.57 5,194.21 1,472.05 N 6,505.83 W 1472.05 3.97 9434.89 85.17 343.72 5,203.60 1,561.69 N 6,533.84 W 1561.69 2.93 9530.27 85.18 345.52 5,211.63 1,653.33 N 6,559.04 W 1653.33 1.88 9579.10 83.88 346.95 5,216.28 1,700.54 N 6,570.61 W 1700.54 3.95 9624.07 82.94 347.51 5,221.44 1,744.10 N 6,580.49 W 1744.10 2.43 9719.15 82.83 347.23 5,233.22 1,836.17 N 6,601.11 W 1836.17 0.31 9814.29 84.72 345.39 5,243.54 1,928.05 N 6,623.50 W 1928.05 2.76 9844.56 86.26 344.59 5,245.92 1,957.20 N 6,631.31 W 1957.20 5.73 9908.30 89.62 343.95 5,248.21 2,018.50 N 6,648.58 W 2018.50 5.37 9955.36 89.48 344.95 5,248.58 2,063.84 N 6,661.20 W 2063.84 2.15 10004.11 89.28 345.51 5,249.10 2,110.97 N 6,673.62 W 2110.97 1.22 10098.59 88.56 346.23 5,250.88 2,202.58 N 6,696.68 W 2202.58 1.08 10192.65 88.15 346.40 5,253.58 2,293.93 N 6,718.93 W 2293.93 0.47 10287.33 88.49 346.19 5,256.36 2,385.87 N 6,741.35 W 2385.87 0.42 10382.46 89.07 346.31 5,258.39 2,478.25 N 6,763.96 W 2478.25 0.62 10476.36 88.97 346.50 5,259.99 2,569.51 N 6,786.03 W 2569.51 0.23 10570.93 89.26 345.76 5,261.45 2,661.31 N 6,808.69 W 2661.31 0.84 10665.35 91.18 344.57 5,261.09 2,752.58 N 6,832.87 W 2752.58 2.39 10760.04 91.03 344.32 5,259.26 2,843.78 N 6,858.25 W 2843.78 0.31 10853.73 91.16 343.74 5,257.47 2,933.84 N 6,884.03 W 2933.84 0.63 10949.13 91.10 344.78 5,255.59 3,025.64 N 6,909.90 W 3025.64 1.09 11043.81 90.34 344.98 5,254.40 3,117.04 N 6,934.59 W 3117.04 0.83 11139.21 89.62 346.00 5,254.44 3,209.39 N 6,958.50 W 3209.39 1.31 11233.00 89.59 341.81 5,255.08 3,299.48 N 6,984.49 W 3299.48 4.47 11328.09 89.86 337.24 5,255.54 3,388.54 N 7,017.75 W 3388.54 4.81 11422.11 90.07 334.41 5,255.60 3,474.31 N 7,056.24 W 3474.31 3.02 11517.85 90.38 336.94 5,255.22 3,561.54 N 7,095.68 W 3561.54 2.66 11611.51 90.20 342.41 5,254.75 3,649.33 N 7,128.20 W 3649.33 5.84 11656.78 89.96 345.22 5,254.68 3,692.81 N 7,140.81 W 3692.81 6.23 11706.56 89.55 348.27 5,254.90 3,741.25 N 7,152.23 W 3741.25 6.18 11755.76 89.35 349.15 5,255.37 3,789.50 N 7,161.86 W 3789.50 1.83 11800.54 89.12 349.56 5,255.97 3,833.50 N 7,170.13 W 3833.50 1.05 11894.31 90.62 348.73 5,256.18 3,925.59 N 7,187.79 W 3925.59 1.83 11988.63 91.28 351.31 5,254.62 4,018.46 N 7,204.13 W 4018.46 2.82 12083.85 90.74 350.65 5,252.94 4,112.49 N 7,219.06 W 4112.49 0.90 12177.85 91.45 348.84 5,251.14 4,204.97 N 7,235.79 W 4204.97 2.07 12273.41 90.40 348.63 5,249.60 4,298.67 N 7,254.45 W 4298.67 1.12 12367.16 90.51 348.31 5,248.85 4,390.53 N 7,273.19 W 4390.53 0.36 12462.56 91.51 347.93 5,247.17 4,483.87 N 7,292.83 W 4483.87 1.12 12556.79 91.47 348.08 5,244.72 4,576.01 N 7,312.40 W 4576.01 0.16 12651.72 91.31 346.35 5,242.42 4,668.56 N 7,333.40 W 4668.56 1.83 12745.30 89.78 342.57 5,241.53 4,758.69 N 7,358.47 W 4758.69 4.36 12840.31 90.00 342.93 5,241.71 4,849.43 N 7,386.64 W 4849.43 0.44 12934.51 90.29 346.12 5,241.47 4,940.20 N 7,411.78 W 4940.20 3.40 13029.20 89.06 347.05 5,242.01 5,032.30 N 7,433.74 W 5032.30 1.63 INSITE V8.1.10 Page 4Job No:AK-XX-0902065084 Well Name:3S-620 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13122.94 89.64 346.93 5,243.07 5,123.63 N 7,454.84 W 5123.63 0.63 13216.61 91.51 348.11 5,242.13 5,215.08 N 7,475.08 W 5215.08 2.36 13310.98 93.28 348.20 5,238.19 5,307.35 N 7,494.44 W 5307.35 1.88 13404.46 93.02 346.86 5,233.05 5,398.49 N 7,514.59 W 5398.49 1.46 13498.15 92.78 345.11 5,228.31 5,489.27 N 7,537.25 W 5489.27 1.88 13592.77 93.02 345.40 5,223.52 5,580.65 N 7,561.30 W 5580.65 0.40 13689.40 92.88 344.95 5,218.55 5,673.94 N 7,585.99 W 5673.94 0.49 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (Grid) - A total correction of 0.00 deg from Magnetic north to Grid north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 13,689.40 feet is 9,473.17 feet along 306.79 degrees (Grid) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 5Job No:AK-XX-0902065084 Well Name:3S-620 Survey Report Multi Finger Caliper Report Company: ConocoPhillips Alaska, Inc. Well: 3S-620 Field: Kuparuk River Unit Borough: North Slope State: Alaska API#: 50-103-20695-00 Formation and Reservoir Solutions – Anchorage AK Analyst: Fanny A. Sari Email: fannyartika.sari@halliburton.com Office: 907-275-2605 Report: 05/01/2015 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR R ECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES TH AT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF &DVLQJ,QVSHFWLRQ5HSRUW Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Tools Used in Analysis Multifinger Imaging Tool (UW 24F) Serial No:10020512 Zone Size (in) Weight (lb/ft) Length (ft) Nom ID (in) Grade 1 4.500 12.600 611.0 3.958 L-80 Analysis Overview Joints Analysed = 26 Reported depth range = 8.09ft - 619.09ft Joints with possible hole = 0 Most penetrated joints Penetration is not applicable in Joint 0.02 at depth 23.3ft Penetration of 6.70% (0.02in) in Joint 8 at depth 279.0ft (Coupling) Penetration of 5.71% (0.02in) in Joint 18 at depth 600.9ft Most projected joints Projection of 5.25% (0.10in) in Joint 0.02 at depth 23.8ft Projection of 0.89% (0.02in) in Joint 11 at depth 341.5ft Projection of 0.80% (0.02in) in Joint 2 at depth 63.7ft (Coupling) These results were generated semi-automatically, using Sondex WIPER analysis software. The data was acquired using Sondex casing inspection tools. Sondex accepts no responsibility for the accuracy of the results that are presented. All items in the string are referred to as 'Joints'. This includes completion items such as cross-overs. Normal joints are identified by integer numbers, sequential in depth. Short joints and completion items are identified by numbers after the decimal point. DISCLAIMER: All interpretations are opinions, based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretation, and we shall not, except in the case of gross or wilful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to our general terms and conditions. V-3.12 Multifinger caliper tool was run to inspect the 4.5" tubing from 619 ft MD to surface The caliper results showed that most of the 4.5" tubing are in a very good condition with less than 10% damage, recorded as light pitting. The minimum ID recorded was 3.85" in joint number 0.02 (liner hanger). [1] Correlation of Recorded Damage to Borehole Profile CONOCOPHILLIPS ALASKA, INC._3S-620_4.5" Tubing 0 100 200 300 400 500 600 700 0 10 20 30 40 50 60 70 80 90 100 0.02 1 1.01 1.02 2 3 4 5 6 7 8 9 10 11 12 13 14 15 15.01 15.03 16 17 18 19 De p t h i n F t . ( M D ) Damage Profile (% wall) / Tool Deviation (degrees) Jo i n t N u m b e r Approx. Tool Deviation Approx. Borehole Profile Minimum Diameter Profile CONOCOPHILLIPS ALASKA, INC._3S-620_4.5" Tubing 3.8 3.85 3.9 3.95 4 0.02 1 1.01 1.02 2 3 4 5 6 7 8 9 10 11 12 13 14 15 15.01 15.03 16 17 18 19 Jo i n t N u m b e r Minimum Measured Diameters (In.) [2] MIT Report Overview Body Region Penetrations Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Number of joints analysed (Total =26) P e n s22 3 0001 L o s s 1 51 00 0 1 0 Number of joints damaged (Total =22/26) 2 2 1011 Damage Profile (% Wall) [3] MIT Report Overview Coupling Region Penetrations Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Number of joints analysed (Total =26) P e n s22 4 0000 Number of joints damaged (Total =20/26) 2 0 0001 Damage Profile (% Wall) [4] MIT Report Overview Joint Projections Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Number of joints analysed (Total =26) Projs 25 1 0 0 0 0 Constrs 23 3 0 0 0 0 Damage Profile (% Radius) [5 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / c e n t S u r v e y D a t e : 0 5 - 0 1 - 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Mo d a l Ch a n g e % Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 0 100 0. 0 1 8. 1 3. 9 6 - - - - - - - - SU R F A C E I T E M S : N o t A n a l y s e d 0. 0 2 22 . 9 3. 9 5 8 3. 9 2 -0 . 9 0. 2 7 n/ a 0. 0 1 3. 9 n/ a n/ a HA N G E R 1 27 . 2 3. 9 5 8 4. 0 2 1. 5 0. 0 1 3. 3 0. 0 1 4. 4 1. 9 1 Li g h t P i t t i n g ; 1. 0 1 57 . 9 3. 9 5 8 4. 0 0 1. 0 0. 0 1 4. 6 0. 0 1 3. 8 2. 0 1 PU P : L i g h t P i t t i n g ; 1. 0 2 61 . 6 3. 9 5 8 3. 9 8 0. 5 0. 0 1 4. 9 0. 0 1 3. 7 2. 1 1 PU P : L i g h t P i t t i n g ; 2 63 . 4 3. 9 5 8 3. 9 9 0. 8 0. 0 1 4. 7 0. 0 1 3. 1 1. 9 1 Li g h t P i t t i n g ; 3 94 . 9 3. 9 5 8 4. 0 2 1. 6 0. 0 1 3. 3 0. 0 1 4. 0 2. 1 1 Li g h t P i t t i n g ; 4 12 6 . 0 3. 9 5 8 4. 0 1 1. 3 0. 0 1 3. 8 0. 0 1 2. 6 1. 4 1 Li g h t P i t t i n g ; 5 15 6 . 2 3. 9 5 8 4. 0 0 1. 1 0. 0 1 4. 3 0. 0 1 4. 3 2. 3 1 Li g h t P i t t i n g ; 6 18 7 . 6 3. 9 5 8 4. 0 2 1. 5 0. 0 1 3. 5 0. 0 1 3. 0 1. 3 1 Li g h t P i t t i n g ; 7 21 7 . 9 3. 9 5 8 4. 0 1 1. 2 0. 0 1 3. 3 0. 0 1 3. 7 1. 4 1 Li g h t P i t t i n g ; 8 24 8 . 4 3. 9 5 8 4. 0 1 1. 3 0. 0 1 3. 1 0. 0 2 6. 7 2. 1 1 Li g h t P i t t i n g ; 9 27 9 . 3 3. 9 5 8 3. 9 8 0. 5 0. 0 1 3. 7 0. 0 1 3. 1 1. 7 1 Li g h t P i t t i n g ; 10 31 0 . 3 3. 9 5 8 4. 0 0 1. 2 0. 0 1 4. 7 0. 0 1 3. 0 1. 5 1 Li g h t P i t t i n g ; 11 34 0 . 2 3. 9 5 8 3. 9 9 0. 8 0. 0 1 3. 7 0. 0 1 2. 1 1. 0 1 Li g h t P i t t i n g ; 12 37 0 . 8 3. 9 5 8 4. 0 1 1. 3 0. 0 1 3. 4 0. 0 1 4. 5 2. 3 1 Li g h t P i t t i n g ; 13 40 2 . 0 3. 9 5 8 4. 0 1 1. 2 0. 0 1 4. 2 0. 0 1 3. 2 1. 6 1 Li g h t P i t t i n g ; 14 43 2 . 8 3. 9 5 8 4. 0 0 1. 0 0. 0 1 3. 5 0. 0 1 3. 5 2. 2 1 Li g h t P i t t i n g ; 15 46 3 . 9 3. 9 5 8 4. 0 2 1. 6 0. 0 1 5. 0 0. 0 1 3. 2 2. 1 1 Li g h t P i t t i n g ; 15 . 0 1 49 5 . 1 3. 9 5 8 3. 9 9 0. 7 0. 0 1 2. 8 0. 0 1 2. 9 1. 6 1 PU P : - 15 . 0 2 50 4 . 9 3. 9 6 - - - - - - - - NI P P L E : N o t A n a l y s e d 15 . 0 3 50 6 . 5 3. 9 5 8 3. 9 9 0. 9 0. 0 1 2. 8 0. 0 1 4. 7 2. 3 1 PU P : L i g h t P i t t i n g ; 16 51 6 . 4 3. 9 5 8 4. 0 0 1. 2 0. 0 1 5. 3 0. 0 1 4. 7 2. 3 1 Li g h t P i t t i n g ; 17 54 7 . 6 3. 9 5 8 3. 9 9 0. 9 0. 0 1 5. 0 0. 0 1 5. 3 2. 2 1 Li g h t P i t t i n g ; 18 57 8 . 5 3. 9 5 8 4. 0 0 1. 0 0. 0 2 5. 7 0. 0 1 4. 2 1. 1 1 Li g h t P i t t i n g ; 19 60 9 . 5 3. 9 5 8 3. 9 7 0. 4 0. 0 1 3. 4 0. 0 1 5. 3 1. 7 1 Li g h t P i t t i n g ; [6 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / c e n t S u r v e y D a t e : 0 5 - 0 1 - 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Mo d a l Ch a n g e % Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)0 100 0. 0 1 8. 1 3. 9 6 - - - - - - - - SU R F A C E I T E M S : N o t A n a l y s e d 0. 0 2 22 . 9 3. 9 5 8 3. 9 2 -0 . 9 0. 1 0 5. 3 0. 0 1 0. 7 3. 8 5 3. 7 HA N G E R : L i g h t D e p o s i t s ; 1 27 . 2 3. 9 5 8 4. 0 2 1. 5 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 7 0. 0 - 1. 0 1 57 . 9 3. 9 5 8 4. 0 0 1. 0 0. 0 1 0. 6 0. 0 1 0. 7 3. 9 4 0. 2 PU P : - 1. 0 2 61 . 6 3. 9 5 8 3. 9 8 0. 5 0. 0 1 0. 5 0. 0 1 0. 6 3. 9 5 0. 0 PU P : - 2 63 . 4 3. 9 5 8 3. 9 9 0. 8 0. 0 1 0. 6 0. 0 2 0. 8 3. 9 5 0. 0 - 3 94 . 9 3. 9 5 8 4. 0 2 1. 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 6 0. 0 - 4 12 6 . 0 3. 9 5 8 4. 0 1 1. 3 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 7 0. 0 - 5 15 6 . 2 3. 9 5 8 4. 0 0 1. 1 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 5 0. 0 - 6 18 7 . 6 3. 9 5 8 4. 0 2 1. 5 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 6 0. 0 - 7 21 7 . 9 3. 9 5 8 4. 0 1 1. 2 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 7 0. 0 - 8 24 8 . 4 3. 9 5 8 4. 0 1 1. 3 0. 0 1 0. 5 0. 0 1 0. 7 3. 9 3 0. 4 - 9 27 9 . 3 3. 9 5 8 3. 9 8 0. 5 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 1. 6 - 10 31 0 . 3 3. 9 5 8 4. 0 0 1. 2 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 6 0. 0 - 11 34 0 . 2 3. 9 5 8 3. 9 9 0. 8 0. 0 2 0. 9 0. 0 1 0. 4 3. 9 3 0. 0 - 12 37 0 . 8 3. 9 5 8 4. 0 1 1. 3 0. 0 1 0. 6 0. 0 1 0. 6 3. 9 4 0. 0 - 13 40 2 . 0 3. 9 5 8 4. 0 1 1. 2 0. 0 1 0. 5 0. 0 1 0. 6 3. 9 4 0. 0 - 14 43 2 . 8 3. 9 5 8 4. 0 0 1. 0 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 0 1. 9 - 15 46 3 . 9 3. 9 5 8 4. 0 2 1. 6 0. 0 1 0. 7 0. 0 1 0. 6 3. 9 4 0. 0 - 15 . 0 1 49 5 . 1 3. 9 5 8 3. 9 9 0. 7 0. 0 1 0. 6 0. 0 1 0. 3 3. 9 4 0. 0 PU P : - 15 . 0 2 50 4 . 9 3. 9 6 - - - - - - - - NI P P L E : N o t A n a l y s e d 15 . 0 3 50 6 . 5 3. 9 5 8 3. 9 9 0. 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 7 PU P : - 16 51 6 . 4 3. 9 5 8 4. 0 0 1. 2 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 3 0. 0 - 17 54 7 . 6 3. 9 5 8 3. 9 9 0. 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 5 0. 0 - 18 57 8 . 5 3. 9 5 8 4. 0 0 1. 0 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 19 60 9 . 5 3. 9 5 8 3. 9 7 0. 4 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 5 0. 0 - [7] Pipe Cross-Section View Penetration damage in Joint 0.02 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Penetration Depth Sensor n/a% (0.27in) 23.33ft MIT 16 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.92in [8] Pipe Cross-Section View Penetration damage in Joint 8 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Penetration Depth Sensor 6.70% (0.02in) 279.02ft (Coupling) MIT 14 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 4.01in [9] Pipe Cross-Section View Penetration damage in Joint 18 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Penetration Depth Sensor 5.71% (0.02in) 600.87ft MIT 2 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 4.00in [10] Pipe Cross-Section View Penetration damage in Joint 17 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Penetration Depth Sensor 5.33% (0.01in) 578.15ft (Coupling) MIT 24 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.99in [11] Pipe Cross-Section View Penetration damage in Joint 16 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Penetration Depth Sensor 5.28% (0.01in) 537.77ft MIT 15 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 4.00in [12] Pipe Cross-Section View Metal loss in Joint 0.02 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Metal Loss Depth n/a 23.33ft Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.92in [13] Pipe Cross-Section View Metal loss in Joint 15.03 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Metal Loss Depth 2.3% 516.05ft (Coupling) Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.99in [14] Pipe Cross-Section View Metal loss in Joint 5 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Metal Loss Depth 2.3% 156.45ft (Coupling) Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 4.00in [15] Pipe Cross-Section View Projection in Joint 0.02 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Projection Depth Sensor 5.25% (0.10in) 23.84ft MIT 9 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.92in [16] Pipe Cross-Section View Projection in Joint 11 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Projection Depth Sensor 0.89% (0.02in) 341.52ft MIT 24 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.99in [17] Pipe Cross-Section View Projection in Joint 2 Company Field Well Country County State Analysed By Survey Date CONOCOPHILLIPS ALASKA, INC. KUPARUK RIVER UNIT 3S-620 USA N. SLOPE ALASKA FANNY SARI 05-01-2015 Section Data Projection Depth Sensor 0.80% (0.02in) 63.68ft (Coupling) MIT 15 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.99in Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.250 Top (ftKB) 29.4 Set Depth (ftKB) 106.0 Set Depth (TVD) … 106.0 Wt/Len (l… 164.80 Grade B-35 Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.950 Top (ftKB) 28.9 Set Depth (ftKB) 3,145.0 Set Depth (TVD) … 2,548.0 Wt/Len (l… 45.50 Grade L-80 Top Thread HYD 563 Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 26.4 Set Depth (ftKB) 9,279.4 Set Depth (TVD) … 5,186.3 Wt/Len (l… 29.70 Grade L-80 Top Thread Hyd 563 Casing Description LINER - 4 1/2" OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 9,144.0 Set Depth (ftKB) 13,655.0 Set Depth (TVD) … 5,220.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 9,144.0 5,160.6 76.46 PACKER BAKER HRD-E ZXP W/ HD's 4.810 9,166.0 5,165.6 77.33 NIPPLE BAKER RS NIPPLE 4.250 9,168.4 5,166.1 77.42 HANGER BAKER FLEX-LOCK HANGER 4.850 9,707.3 5,232.0 82.84 SWELL PACKER PACKERS PLUS SWELL PACKER "H" 3.958 9,980.8 5,249.1 89.38 FRAC PORT PACKERS PLUS FRAC PORT W/ 2.0625" SEAT (2.1250" BALL) 2.063 10,238.3 5,255.2 88.31 SWELL PACKER PACKERS PLUS SWELL PACKER "G" 3.958 10,513.0 5,260.9 89.08 FRAC PORT PACKERS PLUS FRAC PORT W/ 2.0" SEAT (2.0625" BALL) 2.000 10,772.6 5,259.3 91.05 SWELL PACKER PACKERS PLUS SWELL PACKER "F" 3.958 11,047.4 5,254.6 90.31 FRAC PORT PACKERS PLUS FRAC PORT W/ 1.9375" SEAT (2.0" BALL) 1.938 11,304.7 5,255.7 89.79 SWELL PACKER PACKERS PLUS SWELL PACKER "E" 3.958 11,582.5 5,255.1 90.26 FRAC PORT PACKERS PLUS FRAC PORT W/ 1.8750" SEAT (1.9375" BALL) 1.875 11,802.9 5,256.3 89.16 SWELL PACKER PACKERS PLUS SWELL PACKER "D" 3.958 12,078.1 5,253.3 90.77 FRAC PORT PACKERS PLUS FRAC PORT W/ 1.8125" SEAT (1.8750" BALL) 1.813 12,299.5 5,249.7 90.43 SWELL PACKER PACKERS PLUS SWELL PACKER "C" 3.958 12,556.7 5,245.0 91.47 FRAC PORT PACKERS PLUS FRAC PORT W/ 1.75" SEAT (1.8125" BALL) 1.750 12,822.1 5,242.0 89.96 SWELL PACKER PACKERS PLUS SWELL PACKER "B" 3.958 13,101.8 5,243.2 89.51 FRAC PORT PACKERS PLUS FRAC PORT W/ 1.6875" (1.75" BALL) 1.688 13,364.6 5,235.4 93.13 SWELL PACKER PACKERS PLUS SWELL PACKER "A" 3.958 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.958 Top (ftKB) 24.2 Set Depth (ft… 9,150.3 Set Depth (TVD) (… 5,162.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 24.2 24.2 0.00 HANGER FMC TUBING HANGER 3.958 504.3 504.0 2.83 NIPPLE CAMCO DB NIPPLE 3.875 9,005.9 5,123.2 72.17 NIPPLE CAMCO DB NIPPLE 3.813 9,027.3 5,129.6 72.88 GAUGE SCHLUMBERGER GAUGE CARRIER 3.879 9,093.2 5,148.0 74.81 PACKER BAKER PREMIER PRODUCTION PACKER 3.760 9,120.1 5,154.8 75.64 NIPPLE CAMCO DB NIPPLE 3.687 9,139.0 5,159.4 76.26 SUB, NO GO FLUTED NO GO SUB 3.950 9,140.0 5,159.6 76.30 SOS SHEAR PIN 3.950 9,149.2 5,161.8 76.67 SHOE MULE SHOE 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 9,980.8 9,983.5 5,249.1 5,249.1 2/14/2015 PERFP Frac Port 10,513.0 10,515.8 5,260.9 5,260.9 2/14/2015 PERFP Frac Port 11,047.4 11,050.2 5,254.6 5,254.6 2/14/2015 PERFP Frac Port 11,582.5 11,585.3 5,255.1 5,255.1 2/14/2015 PERFP Frac Port 12,078.1 12,080.9 5,253.3 5,253.2 2/14/2015 PERFP Frac Port 12,556.7 12,559.5 5,245.0 5,244.9 2/14/2015 PERFP Frac Port 13,578.5 13,584.3 5,224.5 5,224.2 2/14/2015 PERFP Perf Pup Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,028.8 2,494.3 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 2 5,009.3 3,390.6 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 3 6,557.9 4,090.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 4 7,785.1 4,646.5 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 2/16/2015 5 8,812.6 5,059.7 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/15/2015 DCK-2 Comment SSSV: NIPPLE3S-620, 3/16/2015 10:47:55 AM Vertical schematic (actual) LINER - 4 1/2"; 9,144.0-13,655.0 PERFP; 13,578.5-13,584.3 PERFP; 12,556.7-12,559.5 PERFP; 12,078.1-12,080.9 PERFP; 11,582.5-11,585.3 PERFP; 11,047.3-11,050.2 PERFP; 10,513.0-10,515.8 PERFP; 9,980.8-9,983.5 INTERMEDIATE; 26.4-9,279.4 SOS; 9,140.0 SUB, NO GO; 9,139.0 NIPPLE; 9,120.0 PACKER; 9,093.2 GAUGE; 9,027.3 NIPPLE; 9,005.9 GAS LIFT; 8,812.6 GAS LIFT; 7,785.1 GAS LIFT; 6,557.9 GAS LIFT; 5,009.3 SURFACE; 28.9-3,145.0 GAS LIFT; 3,028.8 NIPPLE; 504.3 CONDUCTOR; 29.4-106.0 HANGER; 24.2 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: GLV C/O, PULL BALL & ROD & PLUG Last Mod By hipshkf End Date 3/16/2015 KUP PROD KB-Grd (ft) 27.50 Rig Release Date 2/19/2015 Annotation Last WO: End Date 3S-620 H2S (ppm) Date... TD Act Btm (ftKB) 13,768.0 Well Attributes Wellbore API/UWI 501032069500 Field Name TRACT OPERATION MORTR02 Wellbore Status PROD Max Angle & MD Incl (°) 93.28 MD (ftKB) 13,310.99 Notes: General & Safety End Date Annotation NOTE: 7 5/8" Casing weight change: 29.7# x 39# @8841.88 3S-620, 3/16/2015 10:47:56 AM Vertical schematic (actual) LINER - 4 1/2"; 9,144.0-13,655.0 PERFP; 13,578.5-13,584.3 PERFP; 12,556.7-12,559.5 PERFP; 12,078.1-12,080.9 PERFP; 11,582.5-11,585.3 PERFP; 11,047.3-11,050.2 PERFP; 10,513.0-10,515.8 PERFP; 9,980.8-9,983.5 INTERMEDIATE; 26.4-9,279.4 SOS; 9,140.0 SUB, NO GO; 9,139.0 NIPPLE; 9,120.0 PACKER; 9,093.2 GAUGE; 9,027.3 NIPPLE; 9,005.9 GAS LIFT; 8,812.6 GAS LIFT; 7,785.1 GAS LIFT; 6,557.9 GAS LIFT; 5,009.3 SURFACE; 28.9-3,145.0 GAS LIFT; 3,028.8 NIPPLE; 504.3 CONDUCTOR; 29.4-106.0 HANGER; 24.2 KUP PROD 3S-620 ... Multi Finger Caliper Report Company: ConocoPhillips Alaska Well: 3S-620 Field: Tract Opertation Monitor 02 Borough: North Slope State: Alaska API#: 50-103-20695-00-00 Formation and Reservoir Solutions – Anchorage AK Analyst: Chris Gullett Email: chris.gullett@halliburton.com Office: 907-350-8453 Report: 05/27/2015 HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF Casing Inspection Report Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Tools Used in Analysis Multifinger Imaging Tool (UW 24F) Serial No:10000428 Zone Size (in) Weight (lb/ft) Length (ft) Nom ID (in) Grade 1 4.500 12.600 5202.6 3.958 L-80 2 4.500 12.600 3738.1 3.958 L-80 Analysis Overview Joints Analysed = 275 Reported depth range = 6.97ft - 8947.63ft Joints with possible hole = 0 Most penetrated joints Penetration of 10.40% (0.03in) in Joint 226.03 at depth 7788.5ft Penetration of 9.96% (0.03in) in Joint 197.01 at depth 6550.8ft Penetration of 9.33% (0.03in) in Joint 96.01 at depth 3025.4ft Most projected joints Projection of 2.32% (0.05in) in Joint 250.01 at depth 8804.3ft Projection of 2.00% (0.04in) in Joint 96.03 at depth 3037.0ft Projection of 1.72% (0.03in) in Joint 250.03 at depth 8815.6ft These results were generated semi-automatically, using Sondex WIPER analysis software. The data was acquired using Sondex casing inspection tools. Sondex accepts no responsibility for the accuracy of the results that are presented. All items in the string are referred to as 'Joints'. This includes completion items such as cross-overs. Normal joints are identified by integer numbers, sequential in depth. Short joints and completion items are identified by numbers after the decimal point. DISCLAIMER: All interpretations are opinions, based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretation, and we shall not, except in the case of gross or wilful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to our general terms and conditions. V-3.12 This MFC was ran to evaluate the condition of the 4.5" tubing from surface to 8970'. A leak detect log was also run on this well. Log depth correlated to tubing detail record dated 17-FEB-2015. The caliper results show the tubing to be in excellent condition. There were no possible holes reported in the recorded data. The highest recorded penetration damage was 10.4% in Joint 226.03 at depth 7788.5'. Light pitting was the only damage type reported, which is expected of new tubing in excellent condition. The minimum recorded ID was 3.83" in Joint 250.03. [1] Mandrel Orientation 3S‐620 ConocoPhillips Alaska, Inc. Tract Op Monitor May 23, 2015 Joint No. Depth Mandrel No. Tool Deviation Latch Orientation 96.02 3027.5' GLM 1 63 deg 3:00 159.02 5004.9' GLM 2 63 deg 9:30 197.02 6553.0' GLM 3 63 deg 9:30 226.02 7779.2' GLM 4 63 deg 2:30 250.02 8806.1' GLM 5 71 deg 7:30 Correlation of Recorded Damage to Borehole Profile ConocoPhillips Alaska – 3S-620 – 4.5” Tubing 0 1000 2000 3000 4000 5000 6000 7000 8000 0 1 02 03 04 05 06 07 08 09 0 1 0 0 0.01 7 15.01 22 31 40 49 58 67 76 85 94 100 109 118 127 136 145 154 160 168 177 186 195 201 210 219 226.02 234 243 250.02 De p t h in Ft . (M D ) Damage Profile (% wall) / Tool Deviation (degrees) Jo i n t Nu m b e r Approx. Tool Deviation Approx. Borehole Profile Minimum Diameter Profile ConocoPhillips Alaska – 3S-620 – 4.5” Tubing 3.7 3.75 3.8 3.85 3.9 3.95 0.01 6 14 19 27 35 43 51 59 67 75 83 91 96.03 104 112 120 128 136 144 152 159.01 165 172 180 188 196 201 209 217 225 230 238 246 251 Jo i n t Nu m b e r Minimum Measured Diameters (In.) [2] MIT Report Overview Body Region Penetrations Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Number of joints analysed (Total =275) Pens 9 265 1 0 0 0 Loss 246 29 0 0 0 0 Number of joints damaged (Total =262/275) 2 6 2 2000 Damage Profile (% Wall) [3] MIT Report Overview Coupling Region Penetrations Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Number of joints analysed (Total =275) Pens 9 266 0 0 0 0 Number of joints damaged (Total =143/275) 1 4 3 0000 Damage Profile (% Wall) [4] MIT Report Overview Joint Projections Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Number of joints analysed (Total =275) Projs 262 13 0 0 0 0 Constrs 230 45 0 0 0 0 Damage Profile (% Radius) [5 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 0. 0 1 7. 0 3. 9 6 - - - - - - - SU R F A C E I T E M S : N o t A n a l y s e d 1 31 . 1 3. 9 5 8 3. 9 7 0. 0 2 7. 3 0. 0 2 6. 8 3. 2 1 Li g h t P i t t i n g ; 1. 0 1 61 . 4 3. 9 5 8 3. 9 9 0. 0 1 3. 4 0. 0 1 3. 7 2. 2 1 PU P : L i g h t P i t t i n g ; 1. 0 2 65 . 1 3. 9 5 8 3. 9 5 0. 0 1 4. 9 0. 0 1 3. 3 1. 9 1 PU P : L i g h t P i t t i n g ; 2 66 . 9 3. 9 5 8 3. 9 7 0. 0 1 3. 8 0. 0 1 3. 3 2. 1 1 Li g h t P i t t i n g ; 3 98 . 4 3. 9 5 8 3. 9 7 0. 0 1 4. 0 0. 0 1 3. 0 1. 4 1 Li g h t P i t t i n g ; 4 12 9 . 4 3. 9 5 8 3. 9 7 0. 0 1 3. 2 0. 0 1 2. 8 0. 9 1 Li g h t P i t t i n g ; 5 15 9 . 5 3. 9 5 8 3. 9 7 0. 0 1 4. 9 0. 0 1 4. 3 1. 7 1 Li g h t P i t t i n g ; 6 19 0 . 8 3. 9 5 8 3. 9 6 0. 0 1 3. 5 0. 0 1 3. 0 1. 2 1 Li g h t P i t t i n g ; 7 22 0 . 9 3. 9 5 8 3. 9 8 0. 0 1 4. 8 0. 0 1 3. 5 1. 6 1 Li g h t P i t t i n g ; 8 25 1 . 3 3. 9 5 8 3. 9 6 0. 0 1 3. 7 0. 0 1 3. 5 1. 8 1 Li g h t P i t t i n g ; 9 28 2 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 2. 8 1. 2 1 Li g h t P i t t i n g ; 10 31 2 . 8 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 2. 9 1. 0 1 Li g h t P i t t i n g ; 11 34 2 . 6 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 1 2. 6 0. 8 1 Li g h t P i t t i n g ; 12 37 3 . 2 3. 9 5 8 3. 9 8 0. 0 1 3. 4 0. 0 1 4. 4 1. 3 1 Li g h t P i t t i n g ; 13 40 4 . 2 3. 9 5 8 3. 9 6 0. 0 1 4. 2 0. 0 1 4. 3 1. 7 1 Li g h t P i t t i n g ; 14 43 4 . 9 3. 9 5 8 3. 9 7 0. 0 1 3. 7 0. 0 1 4. 2 2. 0 1 Li g h t P i t t i n g ; 15 46 5 . 9 3. 9 5 8 3. 9 9 0. 0 1 4. 0 0. 0 1 3. 0 1. 5 1 Li g h t P i t t i n g ; 15 . 0 1 49 7 . 1 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 2. 7 1. 2 1 PU P : L i g h t P i t t i n g ; 15 . 0 2 50 6 . 8 3. 9 6 - - - - - - - NI P P L E : N o t A n a l y s e d 15 . 0 3 50 8 . 4 3. 9 5 8 3. 9 6 0. 0 1 3. 7 0. 0 1 3. 0 1. 5 1 PU P : L i g h t P i t t i n g ; 16 51 8 . 2 3. 9 5 8 3. 9 9 0. 0 1 4. 2 0. 0 1 4. 4 2. 2 1 Li g h t P i t t i n g ; 17 54 9 . 3 3. 9 5 8 3. 9 7 0. 0 1 4. 2 0. 0 1 4. 1 1. 7 1 Li g h t P i t t i n g ; 18 58 0 . 0 3. 9 5 8 3. 9 7 0. 0 2 5. 6 0. 0 1 3. 9 1. 4 1 Li g h t P i t t i n g ; 19 61 1 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 2. 2 0. 8 1 Li g h t P i t t i n g ; 20 64 2 . 8 3. 9 5 8 4. 0 0 0. 0 1 3. 4 0. 0 1 3. 5 1. 1 1 Li g h t P i t t i n g ; 21 67 4 . 0 3. 9 5 8 3. 9 9 0. 0 1 3. 5 0. 0 1 2. 9 1. 6 1 Li g h t P i t t i n g ; 22 70 4 . 8 3. 9 5 8 4. 0 0 0. 0 1 5. 2 0. 0 1 2. 9 1. 0 1 Li g h t P i t t i n g ; 23 73 5 . 8 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 2 1. 5 1 Li g h t P i t t i n g ; 24 76 6 . 9 3. 9 5 8 3. 9 9 0. 0 1 4. 3 0. 0 1 3. 9 1. 5 1 Li g h t P i t t i n g ; 25 79 7 . 8 3. 9 5 8 3. 9 9 0. 0 1 3. 8 0. 0 1 3. 1 1. 3 1 Li g h t P i t t i n g ; 26 82 8 . 5 3. 9 5 8 3. 9 8 0. 0 1 3. 8 0. 0 1 3. 0 1. 1 1 Li g h t P i t t i n g ; 27 85 9 . 7 3. 9 5 8 3. 9 8 0. 0 1 4. 8 0. 0 1 4. 1 1. 5 1 Li g h t P i t t i n g ; 28 89 0 . 5 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 3. 5 1. 3 1 Li g h t P i t t i n g ; 29 92 0 . 5 3. 9 5 8 3. 9 9 0. 0 1 3. 7 0. 0 1 2. 8 1. 2 1 Li g h t P i t t i n g ; [6 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 30 95 1 . 6 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 4. 6 2. 1 1 Li g h t P i t t i n g ; 31 98 2 . 7 3. 9 5 8 3. 9 9 0. 0 1 3. 4 0. 0 1 2. 8 1. 2 1 Li g h t P i t t i n g ; 32 10 1 3 . 3 3. 9 5 8 3. 9 9 0. 0 1 3. 5 0. 0 1 3. 4 1. 5 1 Li g h t P i t t i n g ; 33 10 4 3 . 5 3. 9 5 8 3. 9 9 0. 0 1 4. 6 0. 0 1 3. 2 1. 3 1 Li g h t P i t t i n g ; 34 10 7 4 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 2 0. 0 1 3. 3 1. 3 1 Li g h t P i t t i n g ; 35 11 0 6 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 2. 8 0. 8 1 Li g h t P i t t i n g ; 36 11 3 7 . 1 3. 9 5 8 3. 9 9 0. 0 1 3. 9 0. 0 1 3. 2 1. 0 1 Li g h t P i t t i n g ; 37 11 6 8 . 2 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 1 1. 7 1 Li g h t P i t t i n g ; 38 11 9 8 . 7 3. 9 5 8 4. 0 1 0. 0 1 3. 6 0. 0 1 3. 5 1. 5 1 Li g h t P i t t i n g ; 39 12 2 9 . 8 3. 9 5 8 3. 9 9 0. 0 2 5. 9 0. 0 1 3. 1 1. 1 1 Li g h t P i t t i n g ; 40 12 6 1 . 1 3. 9 5 8 3. 9 9 0. 0 1 4. 1 0. 0 1 3. 1 1. 4 1 Li g h t P i t t i n g ; 41 12 9 1 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 6 1. 5 1 Li g h t P i t t i n g ; 42 13 2 2 . 6 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 1 2. 5 0. 8 1 Li g h t P i t t i n g ; 43 13 5 3 . 6 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 3. 1 1. 2 1 Li g h t P i t t i n g ; 44 13 8 4 . 5 3. 9 5 8 3. 9 9 0. 0 1 3. 7 0. 0 1 3. 1 1. 7 1 Li g h t P i t t i n g ; 45 14 1 5 . 3 3. 9 5 8 3. 9 7 0. 0 1 5. 0 0. 0 1 2. 9 1. 1 1 Li g h t P i t t i n g ; 46 14 4 6 . 4 3. 9 5 8 3. 9 9 0. 0 1 4. 6 0. 0 1 4. 0 1. 9 1 Li g h t P i t t i n g ; 47 14 7 7 . 5 3. 9 5 8 4. 0 0 0. 0 1 5. 1 0. 0 1 2. 9 0. 9 1 Li g h t P i t t i n g ; 48 15 0 8 . 6 3. 9 5 8 4. 0 0 0. 0 1 3. 5 0. 0 1 2. 6 1. 2 1 Li g h t P i t t i n g ; 49 15 3 9 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 9 0. 0 1 3. 8 1. 8 1 Li g h t P i t t i n g ; 50 15 7 0 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 5 0. 0 1 3. 2 0. 8 1 Li g h t P i t t i n g ; 51 16 0 1 . 6 3. 9 5 8 3. 9 8 0. 0 1 4. 0 0. 0 1 3. 9 1. 6 1 Li g h t P i t t i n g ; 52 16 3 2 . 4 3. 9 5 8 3. 9 9 0. 0 1 3. 1 0. 0 1 2. 8 1. 3 1 Li g h t P i t t i n g ; 53 16 6 2 . 8 3. 9 5 8 3. 9 9 0. 0 1 4. 1 0. 0 1 3. 5 1. 7 1 Li g h t P i t t i n g ; 54 16 9 3 . 4 3. 9 5 8 3. 9 7 0. 0 1 3. 7 0. 0 1 3. 2 1. 3 1 Li g h t P i t t i n g ; 55 17 2 4 . 2 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 4. 2 1. 8 1 Li g h t P i t t i n g ; 56 17 5 5 . 3 3. 9 5 8 4. 0 0 0. 0 1 4. 4 0. 0 1 4. 2 1. 5 1 Li g h t P i t t i n g ; 57 17 8 6 . 3 3. 9 5 8 3. 9 9 0. 0 1 3. 3 0. 0 1 2. 9 1. 2 1 Li g h t P i t t i n g ; 58 18 1 7 . 2 3. 9 5 8 3. 9 8 0. 0 1 3. 5 0. 0 1 4. 8 1. 3 1 Li g h t P i t t i n g ; 59 18 4 8 . 0 3. 9 5 8 3. 9 8 0. 0 1 4. 9 0. 0 1 2. 7 1. 0 1 Li g h t P i t t i n g ; 60 18 7 7 . 2 3. 9 5 8 3. 9 9 0. 0 1 4. 0 0. 0 1 3. 5 1. 3 1 Li g h t P i t t i n g ; 61 19 0 7 . 7 3. 9 5 8 3. 9 8 0. 0 1 4. 6 0. 0 1 2. 9 1. 5 1 Li g h t P i t t i n g ; 62 19 3 9 . 5 3. 9 5 8 3. 9 9 0. 0 1 3. 5 0. 0 1 2. 6 1. 1 1 Li g h t P i t t i n g ; 63 19 7 0 . 6 3. 9 5 8 3. 9 8 0. 0 1 3. 2 0. 0 1 3. 1 1. 1 1 Li g h t P i t t i n g ; 64 19 9 9 . 0 3. 9 5 8 3. 9 7 0. 0 1 4. 0 0. 0 1 2. 6 1. 1 1 Li g h t P i t t i n g ; [7 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 65 20 3 0 . 0 3. 9 5 8 3. 9 9 0. 0 1 3. 6 0. 0 1 3. 2 0. 9 1 Li g h t P i t t i n g ; 66 20 6 0 . 6 3. 9 5 8 3. 9 8 0. 0 1 3. 9 0. 0 1 3. 9 1. 2 1 Li g h t P i t t i n g ; 67 20 9 1 . 6 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 4. 3 1. 4 1 Li g h t P i t t i n g ; 68 21 2 3 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 3. 1 1. 5 1 Li g h t P i t t i n g ; 69 21 5 4 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 5 0. 0 1 3. 6 2. 0 1 Li g h t P i t t i n g ; 70 21 8 5 . 2 3. 9 5 8 3. 9 7 0. 0 1 3. 7 0. 0 1 3. 0 1. 0 1 Li g h t P i t t i n g ; 71 22 1 5 . 7 3. 9 5 8 3. 9 8 0. 0 1 3. 4 0. 0 1 3. 1 1. 4 1 Li g h t P i t t i n g ; 72 22 4 6 . 9 3. 9 5 8 3. 9 9 0. 0 1 4. 3 0. 0 1 4. 7 2. 0 1 Li g h t P i t t i n g ; 73 22 7 6 . 4 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 3. 0 0. 9 1 Li g h t P i t t i n g ; 74 23 0 7 . 4 3. 9 5 8 3. 9 9 0. 0 1 4. 6 0. 0 1 4. 0 1. 8 1 Li g h t P i t t i n g ; 75 23 3 7 . 8 3. 9 5 8 3. 9 7 0. 0 1 3. 8 0. 0 1 2. 9 1. 1 1 Li g h t P i t t i n g ; 76 23 6 8 . 7 3. 9 5 8 3. 9 9 0. 0 1 3. 2 0. 0 1 3. 5 1. 7 1 Li g h t P i t t i n g ; 77 23 9 9 . 3 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 2. 7 1. 0 1 Li g h t P i t t i n g ; 78 24 3 0 . 1 3. 9 5 8 3. 9 7 0. 0 1 3. 3 0. 0 1 3. 0 1. 3 1 Li g h t P i t t i n g ; 79 24 6 1 . 4 3. 9 5 8 3. 9 9 0. 0 1 5. 0 0. 0 1 3. 2 1. 4 1 Li g h t P i t t i n g ; 80 24 9 2 . 4 3. 9 5 8 3. 9 9 0. 0 1 4. 4 0. 0 1 2. 9 1. 3 1 Li g h t P i t t i n g ; 81 25 2 3 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 4 0. 0 1 3. 4 1. 2 1 Li g h t P i t t i n g ; 82 25 5 4 . 0 3. 9 5 8 3. 9 9 0. 0 1 3. 7 0. 0 1 3. 1 1. 0 1 Li g h t P i t t i n g ; 83 25 8 5 . 1 3. 9 5 8 3. 9 9 0. 0 1 4. 6 0. 0 1 3. 7 1. 8 1 Li g h t P i t t i n g ; 84 26 1 6 . 5 3. 9 5 8 3. 9 9 0. 0 1 3. 6 0. 0 1 3. 6 1. 5 1 Li g h t P i t t i n g ; 85 26 4 7 . 5 3. 9 5 8 3. 9 6 0. 0 1 3. 3 0. 0 1 2. 6 0. 8 1 Li g h t P i t t i n g ; 86 26 7 7 . 9 3. 9 5 8 3. 9 7 0. 0 1 3. 9 0. 0 1 3. 8 1. 5 1 Li g h t P i t t i n g ; 87 27 0 9 . 3 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 1 2. 9 0. 9 1 Li g h t P i t t i n g ; 88 27 4 0 . 5 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 3. 2 1. 7 1 Li g h t P i t t i n g ; 89 27 6 9 . 7 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 3. 0 1. 4 1 Li g h t P i t t i n g ; 90 28 0 0 . 7 3. 9 5 8 4. 0 0 0. 0 2 6. 0 0. 0 1 3. 1 1. 3 1 Li g h t P i t t i n g ; 91 28 3 1 . 8 3. 9 5 8 4. 0 0 0. 0 1 3. 6 0. 0 1 4. 4 2. 9 1 Li g h t P i t t i n g ; 92 28 6 3 . 1 3. 9 5 8 3. 9 7 0. 0 1 4. 5 0. 0 1 2. 8 1. 0 1 Li g h t P i t t i n g ; 93 28 9 4 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 1 1. 7 1 Li g h t P i t t i n g ; 94 29 2 4 . 3 3. 9 5 8 3. 9 8 0. 0 1 3. 8 0. 0 1 3. 4 1. 3 1 Li g h t P i t t i n g ; 95 29 5 5 . 4 3. 9 5 8 3. 9 9 0. 0 1 4. 1 0. 0 1 2. 6 1. 0 1 Li g h t P i t t i n g ; 96 29 8 6 . 7 3. 9 5 8 3. 9 8 0. 0 1 4. 0 0. 0 1 2. 9 1. 1 1 Li g h t P i t t i n g ; 96 . 0 1 30 1 7 . 7 3. 9 5 8 3. 9 7 0. 0 3 9. 3 0. 0 1 4. 3 2. 3 1 PU P : L i g h t C o r r o s i o n ; L i g h t P i t t i n g ; 96 . 0 2 30 2 7 . 5 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 96 . 0 3 30 3 4 . 6 3. 9 5 8 3. 9 8 0. 0 1 5. 1 0. 0 1 3. 2 1. 3 1 PU P : L i g h t P i t t i n g ; [8 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 97 30 4 4 . 6 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 3. 1 1. 0 1 Li g h t P i t t i n g ; 98 30 7 5 . 7 3. 9 5 8 3. 9 9 0. 0 1 3. 4 0. 0 1 3. 6 1. 3 1 Li g h t P i t t i n g ; 99 31 0 7 . 0 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 4. 1 1. 0 1 Li g h t P i t t i n g ; 10 0 31 3 8 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 1 0. 0 1 2. 9 1. 1 1 Li g h t P i t t i n g ; 10 1 31 6 9 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 5 1. 0 1 Li g h t P i t t i n g ; 10 2 31 9 9 . 2 3. 9 5 8 3. 9 8 0. 0 1 4. 0 0. 0 1 2. 9 1. 8 1 Li g h t P i t t i n g ; 10 3 32 3 0 . 9 3. 9 5 8 3. 9 6 0. 0 1 3. 6 0. 0 1 3. 1 1. 2 1 Li g h t P i t t i n g ; 10 4 32 6 1 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 5 0. 0 1 3. 0 1. 4 1 Li g h t P i t t i n g ; 10 5 32 9 2 . 4 3. 9 5 8 3. 9 5 0. 0 1 3. 3 0. 0 1 2. 9 1. 0 1 Li g h t P i t t i n g ; 10 6 33 2 2 . 7 3. 9 5 8 3. 9 9 0. 0 1 3. 3 0. 0 1 2. 8 1. 4 1 Li g h t P i t t i n g ; 10 7 33 5 4 . 0 3. 9 5 8 3. 9 8 0. 0 1 3. 4 0. 0 1 2. 9 1. 0 1 Li g h t P i t t i n g ; 10 8 33 8 5 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 2. 9 0. 9 1 Li g h t P i t t i n g ; 10 9 34 1 5 . 6 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 3. 9 1. 6 1 Li g h t P i t t i n g ; 11 0 34 4 6 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 1 4. 4 2. 2 1 Li g h t P i t t i n g ; 11 1 34 7 7 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 1 2. 9 1. 1 1 Li g h t P i t t i n g ; 11 2 35 0 8 . 7 3. 9 5 8 3. 9 8 0. 0 1 3. 8 0. 0 1 3. 6 1. 9 1 Li g h t P i t t i n g ; 11 3 35 3 9 . 6 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 2. 6 1. 4 1 Li g h t P i t t i n g ; 11 4 35 6 9 . 8 3. 9 5 8 3. 9 8 0. 0 1 5. 0 0. 0 1 2. 9 1. 3 1 Li g h t P i t t i n g ; 11 5 36 0 0 . 7 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 9 1. 6 1 Li g h t P i t t i n g ; 11 6 36 3 2 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 3. 0 1. 2 1 Li g h t P i t t i n g ; 11 7 36 6 3 . 5 3. 9 5 8 3. 9 8 0. 0 1 3. 4 0. 0 1 3. 8 1. 2 1 Li g h t P i t t i n g ; 11 8 36 9 4 . 7 3. 9 5 8 3. 9 6 0. 0 1 4. 5 0. 0 1 4. 2 1. 0 1 Li g h t P i t t i n g ; 11 9 37 2 4 . 3 3. 9 5 8 3. 9 6 0. 0 1 4. 1 0. 0 1 2. 7 1. 1 1 Li g h t P i t t i n g ; 12 0 37 5 5 . 0 3. 9 5 8 3. 9 9 0. 0 1 3. 6 0. 0 1 3. 1 1. 6 1 Li g h t P i t t i n g ; 12 1 37 8 6 . 0 3. 9 5 8 3. 9 9 0. 0 1 3. 4 0. 0 1 3. 7 1. 3 1 Li g h t P i t t i n g ; 12 2 38 1 6 . 9 3. 9 5 8 3. 9 8 0. 0 1 4. 0 0. 0 1 3. 3 1. 1 1 Li g h t P i t t i n g ; 12 3 38 4 7 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 3. 1 1. 2 1 Li g h t P i t t i n g ; 12 4 38 7 9 . 1 3. 9 5 8 3. 9 9 0. 0 1 3. 8 0. 0 1 3. 0 1. 7 1 Li g h t P i t t i n g ; 12 5 39 0 9 . 9 3. 9 5 8 3. 9 6 0. 0 1 3. 3 0. 0 1 3. 8 1. 7 1 Li g h t P i t t i n g ; 12 6 39 4 0 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 8 0. 0 1 4. 7 3. 0 1 Li g h t P i t t i n g ; 12 7 39 7 1 . 1 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 2. 8 1. 3 1 Li g h t P i t t i n g ; 12 8 40 0 2 . 6 3. 9 5 8 3. 9 5 0. 0 1 4. 2 0. 0 1 5. 2 1. 1 1 Li g h t P i t t i n g ; 12 9 40 3 4 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 3. 7 1. 7 1 Li g h t P i t t i n g ; 13 0 40 6 4 . 7 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 3. 9 1. 7 1 Li g h t P i t t i n g ; 13 1 40 9 6 . 2 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 3. 1 0. 9 1 Li g h t P i t t i n g ; [9 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 13 2 41 2 7 . 1 3. 9 5 8 3. 9 6 0. 0 1 3. 8 0. 0 1 4. 0 1. 3 1 Li g h t P i t t i n g ; 13 3 41 5 7 . 6 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 2. 4 1. 0 1 Li g h t P i t t i n g ; 13 4 41 8 8 . 5 3. 9 5 8 3. 9 9 0. 0 1 4. 0 0. 0 2 8. 1 0. 8 1 Li g h t P i t t i n g ; 13 5 42 1 9 . 5 3. 9 5 8 3. 9 8 0. 0 1 3. 8 0. 0 1 2. 7 1. 2 1 Li g h t P i t t i n g ; 13 6 42 5 0 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 8 0. 0 1 2. 8 1. 2 1 Li g h t P i t t i n g ; 13 7 42 8 2 . 0 3. 9 5 8 3. 9 6 0. 0 1 3. 8 0. 0 1 3. 9 1. 5 1 Li g h t P i t t i n g ; 13 8 43 1 3 . 1 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 3. 0 1. 4 1 Li g h t P i t t i n g ; 13 9 43 4 4 . 2 3. 9 5 8 3. 9 7 0. 0 1 4. 2 0. 0 1 5. 1 1. 2 1 Li g h t P i t t i n g ; 14 0 43 7 4 . 9 3. 9 5 8 3. 9 9 0. 0 1 4. 3 0. 0 1 3. 1 1. 4 1 Li g h t P i t t i n g ; 14 1 44 0 5 . 6 3. 9 5 8 3. 9 9 0. 0 1 3. 2 0. 0 1 4. 4 1. 7 1 Li g h t P i t t i n g ; 14 2 44 3 6 . 4 3. 9 5 8 3. 9 9 0. 0 1 4. 1 0. 0 1 3. 0 1. 3 1 Li g h t P i t t i n g ; 14 3 44 6 7 . 4 3. 9 5 8 3. 9 9 0. 0 1 3. 5 0. 0 1 3. 2 1. 8 1 Li g h t P i t t i n g ; 14 4 44 9 8 . 5 3. 9 5 8 3. 9 7 0. 0 1 4. 9 0. 0 1 3. 3 1. 3 1 Li g h t P i t t i n g ; 14 5 45 3 0 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 4. 6 0. 9 1 Li g h t P i t t i n g ; 14 6 45 6 1 . 4 3. 9 5 8 3. 9 7 0. 0 1 4. 1 0. 0 1 4. 8 1. 6 1 Li g h t P i t t i n g ; 14 7 45 9 2 . 7 3. 9 5 8 3. 9 5 0. 0 1 3. 9 0. 0 1 2. 8 1. 3 1 Li g h t P i t t i n g ; 14 8 46 2 3 . 6 3. 9 5 8 3. 9 7 0. 0 1 4. 0 0. 0 1 2. 8 0. 9 1 Li g h t P i t t i n g ; 14 9 46 5 4 . 4 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 1 3. 1 1. 6 1 Li g h t P i t t i n g ; 15 0 46 8 5 . 7 3. 9 5 8 3. 9 9 0. 0 1 4. 0 0. 0 1 2. 6 1. 0 1 Li g h t P i t t i n g ; 15 1 47 1 7 . 0 3. 9 5 8 3. 9 7 0. 0 1 3. 8 0. 0 1 3. 6 1. 8 1 Li g h t P i t t i n g ; 15 2 47 4 7 . 9 3. 9 5 8 3. 9 6 0. 0 1 5. 2 0. 0 1 2. 8 0. 8 1 Li g h t P i t t i n g ; 15 3 47 7 9 . 0 3. 9 5 8 3. 9 7 0. 0 1 4. 6 0. 0 1 4. 2 1. 7 1 Li g h t P i t t i n g ; 15 4 48 0 9 . 5 3. 9 5 8 3. 9 7 0. 0 1 4. 2 0. 0 1 2. 8 1. 0 1 Li g h t P i t t i n g ; 15 5 48 4 0 . 9 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 2. 8 1. 0 1 Li g h t P i t t i n g ; 15 6 48 7 1 . 2 3. 9 5 8 3. 9 8 0. 0 1 3. 4 0. 0 1 3. 4 1. 5 1 Li g h t P i t t i n g ; 15 7 49 0 2 . 1 3. 9 5 8 3. 9 7 0. 0 1 4. 5 0. 0 1 3. 1 1. 6 1 Li g h t P i t t i n g ; 15 8 49 3 3 . 5 3. 9 5 8 3. 9 6 0. 0 1 4. 7 0. 0 1 2. 6 0. 9 1 Li g h t P i t t i n g ; 15 9 49 6 4 . 4 3. 9 5 8 3. 9 6 0. 0 1 4. 9 0. 0 1 4. 7 1. 1 1 Li g h t P i t t i n g ; 15 9 . 0 1 49 9 5 . 0 3. 9 5 8 3. 9 7 0. 0 2 6. 0 0. 0 1 2. 7 1. 9 1 PU P : L i g h t P i t t i n g ; 15 9 . 0 2 50 0 4 . 9 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 15 9 . 0 3 50 1 2 . 2 3. 9 5 8 3. 9 7 0. 0 2 6. 4 0. 0 1 4. 1 1. 2 1 PU P : L i g h t P i t t i n g ; 16 0 50 2 1 . 9 3. 9 5 8 4. 0 0 0. 0 1 3. 7 0. 0 1 3. 3 0. 9 1 Li g h t P i t t i n g ; 16 1 50 5 3 . 1 3. 9 5 8 3. 9 6 0. 0 1 5. 2 0. 0 1 4. 5 1. 5 1 Li g h t P i t t i n g ; 16 2 50 8 4 . 2 3. 9 5 8 3. 9 5 0. 0 1 3. 4 0. 0 1 4. 9 2. 2 1 Li g h t P i t t i n g ; 16 3 51 1 5 . 7 3. 9 5 8 3. 9 7 0. 0 1 3. 7 0. 0 1 3. 4 0. 9 1 Li g h t P i t t i n g ; [1 0 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 16 4 51 4 7 . 0 3. 9 5 8 3. 9 6 0. 0 1 3. 6 0. 0 1 3. 7 1. 5 1 Li g h t P i t t i n g ; 16 5 51 7 8 . 4 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 5. 1 2. 0 1 Li g h t P i t t i n g ; 16 5 . 0 1 52 0 9 . 5 3. 9 6 - - - - - - - X- O V E R : N o t A n a l y s e d 16 6 52 1 1 . 7 3. 9 5 8 3. 9 5 0. 0 1 3. 3 0. 0 1 2. 8 0. 9 1 Li g h t P i t t i n g ; 16 7 52 5 3 . 7 3. 9 5 8 3. 9 6 0. 0 1 3. 9 0. 0 1 2. 4 0. 6 1 Li g h t P i t t i n g ; 16 8 52 9 4 . 7 3. 9 5 8 3. 9 6 0. 0 1 3. 3 0. 0 1 2. 5 0. 9 1 Li g h t P i t t i n g ; 16 9 53 3 6 . 6 3. 9 5 8 3. 9 4 0. 0 1 3. 3 0. 0 1 3. 3 1. 0 1 Li g h t P i t t i n g ; 17 0 53 7 8 . 0 3. 9 5 8 3. 9 6 0. 0 1 3. 5 0. 0 1 2. 8 1. 0 1 Li g h t P i t t i n g ; 17 1 54 1 9 . 4 3. 9 5 8 3. 9 7 0. 0 1 3. 0 0. 0 1 3. 0 0. 6 1 Li g h t P i t t i n g ; 17 2 54 6 0 . 8 3. 9 5 8 3. 9 8 0. 0 1 3. 7 0. 0 1 2. 7 0. 6 1 Li g h t P i t t i n g ; 17 3 55 0 2 . 6 3. 9 5 8 3. 9 6 0. 0 1 2. 9 0. 0 1 2. 4 0. 7 1 - 17 4 55 4 4 . 2 3. 9 5 8 3. 9 6 0. 0 1 3. 4 0. 0 1 2. 9 0. 9 1 Li g h t P i t t i n g ; 17 5 55 8 6 . 3 3. 9 5 8 3. 9 7 0. 0 1 3. 2 0. 0 1 2. 6 0. 6 1 Li g h t P i t t i n g ; 17 6 56 2 8 . 4 3. 9 5 8 3. 9 7 0. 0 1 5. 4 0. 0 1 2. 8 0. 8 1 Li g h t P i t t i n g ; 17 7 56 7 0 . 2 3. 9 5 8 3. 9 7 0. 0 1 3. 5 0. 0 1 2. 3 0. 6 1 Li g h t P i t t i n g ; 17 8 57 1 1 . 6 3. 9 5 8 3. 9 6 0. 0 1 3. 2 0. 0 1 2. 8 0. 7 1 Li g h t P i t t i n g ; 17 9 57 5 3 . 1 3. 9 5 8 3. 9 6 0. 0 1 3. 2 0. 0 1 2. 6 0. 5 1 Li g h t P i t t i n g ; 18 0 57 9 4 . 6 3. 9 5 8 3. 9 6 0. 0 1 4. 5 0. 0 1 2. 4 0. 7 1 Li g h t P i t t i n g ; 18 1 58 3 5 . 9 3. 9 5 8 3. 9 7 0. 0 1 3. 4 0. 0 1 2. 6 0. 6 1 Li g h t P i t t i n g ; 18 2 58 7 7 . 5 3. 9 5 8 3. 9 5 0. 0 1 3. 4 0. 0 1 2. 7 0. 6 1 Li g h t P i t t i n g ; 18 3 59 1 9 . 2 3. 9 5 8 3. 9 7 0. 0 1 3. 2 0. 0 1 3. 8 0. 5 1 Li g h t P i t t i n g ; 18 4 59 6 0 . 9 3. 9 5 8 3. 9 5 0. 0 1 3. 2 0. 0 1 2. 2 0. 6 1 Li g h t P i t t i n g ; 18 5 60 0 2 . 5 3. 9 5 8 3. 9 4 0. 0 1 3. 1 0. 0 1 3. 0 0. 6 1 Li g h t P i t t i n g ; 18 6 60 4 4 . 3 3. 9 5 8 3. 9 3 0. 0 1 3. 1 0. 0 1 2. 8 0. 9 1 Li g h t P i t t i n g ; 18 7 60 8 6 . 1 3. 9 5 8 3. 9 5 0. 0 1 3. 3 0. 0 1 2. 7 0. 7 1 Li g h t P i t t i n g ; 18 8 61 2 7 . 3 3. 9 5 8 3. 9 5 0. 0 1 3. 3 0. 0 1 2. 4 0. 6 1 Li g h t P i t t i n g ; 18 9 61 6 9 . 1 3. 9 5 8 3. 9 6 0. 0 1 3. 4 0. 0 1 2. 4 0. 9 1 Li g h t P i t t i n g ; 19 0 62 1 0 . 9 3. 9 5 8 3. 9 6 0. 0 1 3. 4 0. 0 1 2. 6 0. 6 1 Li g h t P i t t i n g ; 19 1 62 5 2 . 5 3. 9 5 8 3. 9 6 0. 0 1 3. 3 0. 0 1 3. 0 0. 7 1 Li g h t P i t t i n g ; 19 2 62 9 3 . 7 3. 9 5 8 3. 9 6 0. 0 1 3. 2 0. 0 1 2. 6 0. 5 1 Li g h t P i t t i n g ; 19 3 63 3 5 . 5 3. 9 5 8 3. 9 5 0. 0 1 2. 8 0. 0 1 3. 4 0. 8 1 Li g h t P i t t i n g ; 19 4 63 7 7 . 3 3. 9 5 8 3. 9 8 0. 0 1 3. 3 0. 0 2 7. 8 0. 8 1 Li g h t P i t t i n g ; 19 5 64 1 8 . 8 3. 9 5 8 3. 9 7 0. 0 1 5. 5 0. 0 1 2. 3 1. 0 1 Li g h t P i t t i n g ; 19 6 64 6 0 . 3 3. 9 5 8 3. 9 8 0. 0 1 3. 0 0. 0 1 3. 3 0. 8 1 Li g h t P i t t i n g ; 19 7 65 0 1 . 5 3. 9 5 8 3. 9 5 0. 0 1 3. 5 0. 0 1 2. 1 0. 5 1 Li g h t P i t t i n g ; [1 1 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 19 7 . 0 1 65 4 3 . 2 3. 9 5 8 3. 9 3 0. 0 3 10 . 0 0. 0 1 2. 1 2. 1 1 PU P : L i g h t C o r r o s i o n ; L i g h t P i t t i n g ; 19 7 . 0 2 65 5 3 . 0 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 19 7 . 0 3 65 6 0 . 2 3. 9 5 8 3. 9 1 0. 0 1 5. 4 0. 0 1 2. 8 0. 7 1 PU P : L i g h t P i t t i n g ; 19 8 65 6 9 . 7 3. 9 5 8 3. 9 6 0. 0 1 3. 6 0. 0 1 2. 6 1. 0 1 Li g h t P i t t i n g ; 19 9 66 1 1 . 2 3. 9 5 8 3. 9 7 0. 0 1 3. 6 0. 0 1 2. 7 0. 6 1 Li g h t P i t t i n g ; 20 0 66 5 2 . 4 3. 9 5 8 3. 9 4 0. 0 2 7. 2 0. 0 1 2. 3 0. 5 1 Li g h t P i t t i n g ; 20 1 66 9 3 . 4 3. 9 5 8 3. 9 4 0. 0 1 3. 1 0. 0 1 3. 0 0. 6 1 Li g h t P i t t i n g ; 20 2 67 3 5 . 2 3. 9 5 8 3. 9 3 0. 0 1 4. 8 0. 0 1 4. 8 0. 6 1 Li g h t P i t t i n g ; 20 3 67 7 6 . 9 3. 9 5 8 3. 9 6 0. 0 1 3. 2 0. 0 1 2. 5 0. 7 1 Li g h t P i t t i n g ; 20 4 68 1 8 . 5 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 3. 9 0. 6 1 Li g h t P i t t i n g ; 20 5 68 6 0 . 3 3. 9 5 8 3. 9 3 0. 0 1 3. 2 0. 0 1 2. 8 0. 6 1 Li g h t P i t t i n g ; 20 6 69 0 2 . 2 3. 9 5 8 3. 9 6 0. 0 1 2. 9 0. 0 1 3. 1 0. 8 1 Li g h t P i t t i n g ; 20 7 69 4 4 . 0 3. 9 5 8 3. 9 8 0. 0 1 3. 6 0. 0 1 2. 8 0. 6 1 Li g h t P i t t i n g ; 20 8 69 8 5 . 2 3. 9 5 8 3. 9 3 0. 0 1 4. 0 0. 0 1 2. 8 0. 6 1 Li g h t P i t t i n g ; 20 9 70 2 7 . 0 3. 9 5 8 3. 9 5 0. 0 1 3. 1 0. 0 1 2. 7 0. 6 1 Li g h t P i t t i n g ; 21 0 70 6 8 . 2 3. 9 5 8 3. 9 5 0. 0 1 3. 2 0. 0 1 2. 5 0. 6 1 Li g h t P i t t i n g ; 21 1 71 0 9 . 8 3. 9 5 8 3. 9 2 0. 0 1 3. 2 0. 0 1 2. 6 0. 8 1 Li g h t P i t t i n g ; 21 2 71 5 1 . 6 3. 9 5 8 3. 9 5 0. 0 1 2. 8 0. 0 1 4. 4 1. 0 1 Li g h t P i t t i n g ; 21 3 71 9 2 . 8 3. 9 5 8 3. 9 8 0. 0 1 3. 2 0. 0 1 2. 3 0. 7 1 Li g h t P i t t i n g ; 21 4 72 3 3 . 9 3. 9 5 8 3. 9 7 0. 0 1 5. 1 0. 0 1 2. 6 0. 7 1 Li g h t P i t t i n g ; 21 5 72 7 5 . 2 3. 9 5 8 3. 9 5 0. 0 1 3. 2 0. 0 1 2. 8 0. 7 1 Li g h t P i t t i n g ; 21 6 73 1 6 . 8 3. 9 5 8 3. 9 5 0. 0 1 3. 6 0. 0 1 3. 1 0. 7 1 Li g h t P i t t i n g ; 21 7 73 5 8 . 4 3. 9 5 8 3. 9 7 0. 0 1 4. 1 0. 0 1 2. 8 0. 6 1 Li g h t P i t t i n g ; 21 8 74 0 0 . 1 3. 9 5 8 3. 9 4 0. 0 1 3. 9 0. 0 1 2. 1 0. 6 1 Li g h t P i t t i n g ; 21 9 74 3 7 . 6 3. 9 5 8 3. 9 3 0. 0 1 3. 3 0. 0 1 3. 0 0. 7 1 Li g h t P i t t i n g ; 22 0 74 7 9 . 2 3. 9 5 8 3. 9 7 0. 0 1 3. 3 0. 0 1 2. 4 0. 7 1 Li g h t P i t t i n g ; 22 1 75 1 9 . 5 3. 9 5 8 3. 9 7 0. 0 1 3. 1 0. 0 1 2. 2 0. 7 1 Li g h t P i t t i n g ; 22 2 75 6 1 . 2 3. 9 5 8 3. 9 4 0. 0 1 4. 9 0. 0 1 2. 2 0. 8 1 Li g h t P i t t i n g ; 22 3 76 0 2 . 7 3. 9 5 8 3. 9 6 0. 0 1 3. 5 0. 0 1 2. 2 0. 6 1 Li g h t P i t t i n g ; 22 4 76 4 4 . 8 3. 9 5 8 3. 9 4 0. 0 1 3. 0 0. 0 1 3. 0 0. 6 1 Li g h t P i t t i n g ; 22 5 76 8 6 . 4 3. 9 5 8 3. 9 3 0. 0 1 3. 2 0. 0 1 2. 7 0. 6 1 Li g h t P i t t i n g ; 22 6 77 2 7 . 7 3. 9 5 8 3. 9 7 0. 0 1 3. 2 0. 0 1 2. 6 0. 5 1 Li g h t P i t t i n g ; 22 6 . 0 1 77 6 9 . 3 3. 9 5 8 3. 9 2 0. 0 2 5. 7 0. 0 1 2. 9 1. 2 1 PU P : L i g h t P i t t i n g ; 22 6 . 0 2 77 7 9 . 2 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 22 6 . 0 3 77 8 6 . 2 3. 9 5 8 3. 9 4 0. 0 3 10 . 4 0. 0 1 2. 5 1. 5 1 PU P : M o d e r a t e P i t t i n g ; [1 2 ] MI T J o i n t T a b u l a t i o n S h e e t ( P e n e t r a t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pe n e t r a t i o n Bo d y in % Co u p l i n g in % Me t a l Lo s s % Gr a d e Da m a g e D e s c r i p t i o n Metal LossPenetration Profile (%) MI T G r a d e 1 [ 0 % - 1 9 % ] 2 [ 2 0 % - 3 9 % ] 3 [ 4 0 % - 5 9 % ] 4 [ 6 0 % - 6 9 % ] 5 [ 7 0 % - 1 0 0 % ] 01 0 0 22 7 77 9 5 . 9 3. 9 5 8 3. 9 7 0. 0 1 4. 6 0. 0 0 1. 8 0. 8 1 Li g h t P i t t i n g ; 22 8 78 3 7 . 9 3. 9 5 8 3. 9 6 0. 0 1 4. 7 0. 0 1 3. 5 0. 8 1 Li g h t P i t t i n g ; 22 9 78 7 9 . 9 3. 9 5 8 3. 9 6 0. 0 1 3. 4 0. 0 1 2. 4 0. 8 1 Li g h t P i t t i n g ; 23 0 79 2 1 . 5 3. 9 5 8 3. 9 5 0. 0 1 4. 9 0. 0 1 3. 8 0. 8 1 Li g h t P i t t i n g ; 23 1 79 6 3 . 3 3. 9 5 8 3. 9 6 0. 0 1 4. 5 0. 0 1 2. 3 0. 7 1 Li g h t P i t t i n g ; 23 2 80 0 5 . 3 3. 9 5 8 3. 9 5 0. 0 1 3. 8 0. 0 1 2. 5 0. 7 1 Li g h t P i t t i n g ; 23 3 80 4 7 . 3 3. 9 5 8 3. 9 5 0. 0 1 5. 2 0. 0 1 4. 5 1. 0 1 Li g h t P i t t i n g ; 23 4 80 8 8 . 8 3. 9 5 8 3. 9 3 0. 0 1 3. 2 0. 0 1 2. 4 0. 6 1 Li g h t P i t t i n g ; 23 5 81 3 0 . 8 3. 9 5 8 3. 9 3 0. 0 1 4. 8 0. 0 1 2. 3 0. 7 1 Li g h t P i t t i n g ; 23 6 81 7 2 . 6 3. 9 5 8 3. 9 4 0. 0 1 4. 7 0. 0 1 2. 9 0. 8 1 Li g h t P i t t i n g ; 23 7 82 1 4 . 2 3. 9 5 8 3. 9 7 0. 0 1 4. 7 0. 0 1 4. 0 1. 0 1 Li g h t P i t t i n g ; 23 8 82 5 6 . 4 3. 9 5 8 3. 9 4 0. 0 1 3. 1 0. 0 1 2. 6 0. 7 1 Li g h t P i t t i n g ; 23 9 82 9 8 . 4 3. 9 5 8 3. 9 2 0. 0 1 3. 4 0. 0 1 3. 4 0. 9 1 Li g h t P i t t i n g ; 24 0 83 4 0 . 2 3. 9 5 8 3. 9 4 0. 0 1 4. 7 0. 0 1 3. 2 0. 6 1 Li g h t P i t t i n g ; 24 1 83 8 1 . 2 3. 9 5 8 3. 9 9 0. 0 1 5. 4 0. 0 1 3. 8 1. 3 1 Li g h t P i t t i n g ; 24 2 84 2 1 . 8 3. 9 5 8 3. 9 4 0. 0 1 5. 4 0. 0 1 3. 4 1. 1 1 Li g h t P i t t i n g ; 24 3 84 6 2 . 8 3. 9 5 8 3. 9 4 0. 0 1 4. 6 0. 0 1 3. 6 0. 9 1 Li g h t P i t t i n g ; 24 4 85 0 4 . 3 3. 9 5 8 3. 9 3 0. 0 1 3. 4 0. 0 1 2. 5 0. 7 1 Li g h t P i t t i n g ; 24 5 85 4 6 . 3 3. 9 5 8 3. 9 2 0. 0 1 3. 1 0. 0 1 2. 3 0. 7 1 Li g h t P i t t i n g ; 24 6 85 8 8 . 0 3. 9 5 8 3. 9 4 0. 0 1 3. 8 0. 0 1 2. 8 0. 6 1 Li g h t P i t t i n g ; 24 7 86 2 9 . 8 3. 9 5 8 3. 9 3 0. 0 1 5. 2 0. 0 1 3. 0 0. 8 1 Li g h t P i t t i n g ; 24 8 86 7 1 . 6 3. 9 5 8 3. 9 2 0. 0 1 5. 0 0. 0 1 3. 6 0. 8 1 Li g h t P i t t i n g ; 24 9 87 1 3 . 4 3. 9 5 8 3. 9 6 0. 0 1 4. 8 0. 0 1 2. 9 1. 0 1 Li g h t P i t t i n g ; 25 0 87 5 4 . 9 3. 9 5 8 3. 9 5 0. 0 1 3. 7 0. 0 1 3. 2 0. 8 1 Li g h t P i t t i n g ; 25 0 . 0 1 87 9 6 . 3 3. 9 5 8 3. 8 9 0. 0 2 5. 6 0. 0 1 3. 1 0. 8 1 PU P : L i g h t P i t t i n g ; 25 0 . 0 2 88 0 6 . 1 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 25 0 . 0 3 88 1 3 . 4 3. 9 5 8 3. 9 1 0. 0 2 5. 9 0. 0 1 4. 0 0. 7 1 PU P : L i g h t P i t t i n g ; 25 1 88 2 2 . 9 3. 9 5 8 3. 9 5 0. 0 2 5. 7 0. 0 1 2. 8 0. 7 1 Li g h t P i t t i n g ; 25 2 88 6 5 . 0 3. 9 5 8 3. 9 4 0. 0 1 4. 9 0. 0 1 2. 8 0. 9 1 Li g h t P i t t i n g ; 25 2 . 0 1 89 0 6 . 2 3. 9 6 - - - - - - - IN V A L I D C A L I P E R F I N G E R S : N o t A n a l y s e d [1 3 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 0. 0 1 7. 0 3. 9 6 - - - - - - - SU R F A C E I T E M S : N o t A n a l y s e d 1 31 . 1 3. 9 5 8 3. 9 7 0. 0 2 1. 0 0. 0 1 0. 6 3. 9 2 0. 2 Li g h t D e p o s i t s ; 1. 0 1 61 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 1. 5 PU P : - 1. 0 2 65 . 1 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 7 3. 9 2 0. 5 PU P : - 2 66 . 9 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 8 - 3 98 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 2 - 4 12 9 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 4 - 5 15 9 . 5 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 0 1. 7 - 6 19 0 . 8 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 7 - 7 22 0 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 7 0. 0 1 0. 3 3. 9 1 0. 5 - 8 25 1 . 3 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 9 2. 2 - 9 28 2 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 0 2. 1 - 10 31 2 . 8 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 1 - 11 34 2 . 6 3. 9 5 8 3. 9 8 0. 0 2 0. 8 0. 0 1 0. 3 3. 9 2 0. 3 - 12 37 3 . 2 3. 9 5 8 3. 9 8 0. 0 1 0. 4 0. 0 1 0. 5 3. 9 2 0. 2 - 13 40 4 . 2 3. 9 5 8 3. 9 6 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 1 0. 5 - 14 43 4 . 9 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 7 2. 7 - 15 46 5 . 9 3. 9 5 8 3. 9 9 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 3 0. 4 - 15 . 0 1 49 7 . 1 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 2 0. 5 PU P : - 15 . 0 2 50 6 . 8 3. 9 6 - - - - - - - NI P P L E : N o t A n a l y s e d 15 . 0 3 50 8 . 4 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 1 1. 0 PU P : - 16 51 8 . 2 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 1 0. 8 - 17 54 9 . 3 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 7 3. 9 1 1. 4 - 18 58 0 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 1 0. 7 - 19 61 1 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 3 - 20 64 2 . 8 3. 9 5 8 4. 0 0 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 1 - 21 67 4 . 0 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 2 - 22 70 4 . 8 3. 9 5 8 4. 0 0 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 9 2. 1 - 23 73 5 . 8 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 3 - 24 76 6 . 9 3. 9 5 8 3. 9 9 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 2 0. 2 - 25 79 7 . 8 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 4 - 26 82 8 . 5 3. 9 5 8 3. 9 8 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 4 0. 0 - 27 85 9 . 7 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 4 - 28 89 0 . 5 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 1 0. 3 - 29 92 0 . 5 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 7 3. 9 3 0. 0 - [1 4 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 30 95 1 . 6 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 3 0. 2 - 31 98 2 . 7 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 8 2. 8 - 32 10 1 3 . 3 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 4 0. 0 - 33 10 4 3 . 5 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 34 10 7 4 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 3 0. 0 - 35 11 0 6 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 36 11 3 7 . 1 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 3 0. 0 - 37 11 6 8 . 2 3. 9 5 8 3. 9 8 0. 0 1 0. 8 0. 0 1 0. 3 3. 9 2 0. 1 - 38 11 9 8 . 7 3. 9 5 8 4. 0 1 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 5 0. 0 - 39 12 2 9 . 8 3. 9 5 8 3. 9 9 0. 0 3 1. 6 0. 0 1 0. 3 3. 9 0 1. 9 Li g h t D e p o s i t s ; 40 12 6 1 . 1 3. 9 5 8 3. 9 9 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 3 0. 1 - 41 12 9 1 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 2 - 42 13 2 2 . 6 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 43 13 5 3 . 6 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 6 3. 9 3 0. 1 - 44 13 8 4 . 5 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 45 14 1 5 . 3 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 4 3. 8 7 2. 8 - 46 14 4 6 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 3 0. 0 - 47 14 7 7 . 5 3. 9 5 8 4. 0 0 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 48 15 0 8 . 6 3. 9 5 8 4. 0 0 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 49 15 3 9 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 50 15 7 0 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 51 16 0 1 . 6 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 7 3. 9 1 0. 3 - 52 16 3 2 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 4 0. 0 - 53 16 6 2 . 8 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 54 16 9 3 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 5 - 55 17 2 4 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 6 3. 9 3 0. 1 - 56 17 5 5 . 3 3. 9 5 8 4. 0 0 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 4 0. 0 - 57 17 8 6 . 3 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 58 18 1 7 . 2 3. 9 5 8 3. 9 8 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 4 0. 0 - 59 18 4 8 . 0 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 9 2. 2 - 60 18 7 7 . 2 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 61 19 0 7 . 7 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 8 2. 7 - 62 19 3 9 . 5 3. 9 5 8 3. 9 9 0. 0 2 0. 9 0. 0 1 0. 4 3. 9 3 0. 0 - 63 19 7 0 . 6 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 0 1. 6 - 64 19 9 9 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - [1 5 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 65 20 3 0 . 0 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 0 - 66 20 6 0 . 6 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 3 - 67 20 9 1 . 6 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 2 - 68 21 2 3 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 8 2. 5 - 69 21 5 4 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 3 - 70 21 8 5 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 4 0. 0 - 71 22 1 5 . 7 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 4 0. 3 - 72 22 4 6 . 9 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 0 1. 9 - 73 22 7 6 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 74 23 0 7 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 3 0. 4 - 75 23 3 7 . 8 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 1 - 76 23 6 8 . 7 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 7 3. 9 2 0. 4 - 77 23 9 9 . 3 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 3 - 78 24 3 0 . 1 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 2 0. 2 - 79 24 6 1 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 4 0. 2 - 80 24 9 2 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 1 - 81 25 2 3 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 3 - 82 25 5 4 . 0 3. 9 5 8 3. 9 9 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 4 0. 0 - 83 25 8 5 . 1 3. 9 5 8 3. 9 9 0. 0 2 0. 8 0. 0 1 0. 4 3. 9 2 0. 7 - 84 26 1 6 . 5 3. 9 5 8 3. 9 9 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 3 0. 1 - 85 26 4 7 . 5 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 0 1. 6 - 86 26 7 7 . 9 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 3 - 87 27 0 9 . 3 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 0 - 88 27 4 0 . 5 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 0 1. 8 - 89 27 6 9 . 7 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 2 0. 3 - 90 28 0 0 . 7 3. 9 5 8 4. 0 0 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 1 0. 1 - 91 28 3 1 . 8 3. 9 5 8 4. 0 0 0. 0 1 0. 6 0. 0 1 0. 6 3. 9 3 0. 4 - 92 28 6 3 . 1 3. 9 5 8 3. 9 7 0. 0 2 0. 8 0. 0 1 0. 4 3. 8 7 1. 9 - 93 28 9 4 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 2 - 94 29 2 4 . 3 3. 9 5 8 3. 9 8 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 3 0. 4 - 95 29 5 5 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 96 29 8 6 . 7 3. 9 5 8 3. 9 8 0. 0 1 0. 7 0. 0 1 0. 3 3. 9 4 0. 0 - 96 . 0 1 30 1 7 . 7 3. 9 5 8 3. 9 7 0. 0 2 1. 3 0. 0 1 0. 4 3. 8 5 2. 6 PU P : L i g h t D e p o s i t s ; 96 . 0 2 30 2 7 . 5 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 96 . 0 3 30 3 4 . 6 3. 9 5 8 3. 9 8 0. 0 4 2. 0 0. 0 1 0. 5 3. 9 0 0. 7 PU P : L i g h t D e p o s i t s ; [1 6 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 97 30 4 4 . 6 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 3 3. 9 4 0. 0 - 98 30 7 5 . 7 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 3 0. 2 - 99 31 0 7 . 0 3. 9 5 8 3. 9 8 0. 0 2 1. 0 0. 0 1 0. 4 3. 9 4 0. 0 - 10 0 31 3 8 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 5 - 10 1 31 6 9 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 10 2 31 9 9 . 2 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 9 - 10 3 32 3 0 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 3 0. 2 - 10 4 32 6 1 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 8 2. 6 - 10 5 32 9 2 . 4 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 5 3. 8 8 1. 8 - 10 6 33 2 2 . 7 3. 9 5 8 3. 9 9 0. 0 1 0. 4 0. 0 1 0. 5 3. 9 3 0. 5 - 10 7 33 5 4 . 0 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 10 8 33 8 5 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 3 0. 1 - 10 9 34 1 5 . 6 3. 9 5 8 3. 9 8 0. 0 1 0. 6 0. 0 1 0. 7 3. 9 4 0. 3 - 11 0 34 4 6 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 6 3. 9 3 0. 2 - 11 1 34 7 7 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 11 2 35 0 8 . 7 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 5 3. 8 2 4. 5 - 11 3 35 3 9 . 6 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 1 - 11 4 35 6 9 . 8 3. 9 5 8 3. 9 8 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 4 0. 0 - 11 5 36 0 0 . 7 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 5 - 11 6 36 3 2 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 3 0. 0 - 11 7 36 6 3 . 5 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 6 3. 9 3 0. 5 - 11 8 36 9 4 . 7 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 3 3. 8 6 3. 8 - 11 9 37 2 4 . 3 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 4 - 12 0 37 5 5 . 0 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 3 - 12 1 37 8 6 . 0 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 2 0. 0 - 12 2 38 1 6 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 1 0. 5 - 12 3 38 4 7 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 2 0. 4 - 12 4 38 7 9 . 1 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 4 0. 0 - 12 5 39 0 9 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 1 0. 9 - 12 6 39 4 0 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 0 0. 5 - 12 7 39 7 1 . 1 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 2 0. 6 - 12 8 40 0 2 . 6 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 9 2. 2 - 12 9 40 3 4 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 2 0. 0 - 13 0 40 6 4 . 7 3. 9 5 8 3. 9 7 0. 0 3 1. 4 0. 0 1 0. 4 3. 8 5 4. 0 Li g h t D e p o s i t s ; 13 1 40 9 6 . 2 3. 9 5 8 3. 9 8 0. 0 2 1. 2 0. 0 1 0. 5 3. 9 3 0. 1 Li g h t D e p o s i t s ; [1 7 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 13 2 41 2 7 . 1 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 4 3. 8 8 2. 1 - 13 3 41 5 7 . 6 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 4 0. 0 - 13 4 41 8 8 . 5 3. 9 5 8 3. 9 9 0. 0 1 0. 4 0. 0 1 0. 4 3. 8 7 2. 2 - 13 5 42 1 9 . 5 3. 9 5 8 3. 9 8 0. 0 2 0. 8 0. 0 1 0. 6 3. 9 1 0. 8 - 13 6 42 5 0 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 4 0. 0 - 13 7 42 8 2 . 0 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 3 0. 0 - 13 8 43 1 3 . 1 3. 9 5 8 3. 9 7 0. 0 2 0. 8 0. 0 2 0. 9 3. 9 1 0. 7 - 13 9 43 4 4 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 7 3. 8 9 2. 4 - 14 0 43 7 4 . 9 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 4 0. 0 - 14 1 44 0 5 . 6 3. 9 5 8 3. 9 9 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 3 0. 5 - 14 2 44 3 6 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 3 0. 0 - 14 3 44 6 7 . 4 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 2 0. 0 - 14 4 44 9 8 . 5 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 3 0. 3 - 14 5 45 3 0 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 3 0. 3 - 14 6 45 6 1 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 7 3. 9 1 0. 6 - 14 7 45 9 2 . 7 3. 9 5 8 3. 9 5 0. 0 2 0. 8 0. 0 1 0. 4 3. 9 2 0. 1 - 14 8 46 2 3 . 6 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 6 3. 9 3 0. 0 - 14 9 46 5 4 . 4 3. 9 5 8 3. 9 8 0. 0 1 0. 4 0. 0 1 0. 4 3. 8 7 3. 8 - 15 0 46 8 5 . 7 3. 9 5 8 3. 9 9 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 2 0. 1 - 15 1 47 1 7 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 3 0. 5 - 15 2 47 4 7 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 8 0. 0 1 0. 4 3. 9 3 0. 1 - 15 3 47 7 9 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 0 1. 0 - 15 4 48 0 9 . 5 3. 9 5 8 3. 9 7 0. 0 2 0. 9 0. 0 1 0. 4 3. 9 4 0. 0 - 15 5 48 4 0 . 9 3. 9 5 8 3. 9 8 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 4 0. 0 - 15 6 48 7 1 . 2 3. 9 5 8 3. 9 8 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 1 0. 4 - 15 7 49 0 2 . 1 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 4 0. 2 - 15 8 49 3 3 . 5 3. 9 5 8 3. 9 6 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 3 0. 4 - 15 9 49 6 4 . 4 3. 9 5 8 3. 9 6 0. 0 1 0. 7 0. 0 1 0. 6 3. 9 1 0. 8 - 15 9 . 0 1 49 9 5 . 0 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 4 3. 8 7 1. 6 PU P : - 15 9 . 0 2 50 0 4 . 9 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 15 9 . 0 3 50 1 2 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 1 1. 0 PU P : - 16 0 50 2 1 . 9 3. 9 5 8 4. 0 0 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 1 0. 7 - 16 1 50 5 3 . 1 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 9 - 16 2 50 8 4 . 2 3. 9 5 8 3. 9 5 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 2 0. 5 - 16 3 51 1 5 . 7 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 1. 0 - [1 8 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 16 4 51 4 7 . 0 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 0 0. 6 - 16 5 51 7 8 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 8 8 1. 0 - 16 5 . 0 1 52 0 9 . 5 3. 9 6 - - - - - - - X- O V E R : N o t A n a l y s e d 16 6 52 1 1 . 7 3. 9 5 8 3. 9 5 0. 0 2 0. 8 0. 0 1 0. 3 3. 9 0 0. 7 - 16 7 52 5 3 . 7 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 3 0. 4 - 16 8 52 9 4 . 7 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 0 0. 4 - 16 9 53 3 6 . 6 3. 9 5 8 3. 9 4 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 2 0. 7 - 17 0 53 7 8 . 0 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 0 0. 2 - 17 1 54 1 9 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 1 0. 3 - 17 2 54 6 0 . 8 3. 9 5 8 3. 9 8 0. 0 1 0. 6 0. 0 1 0. 5 3. 9 2 0. 6 - 17 3 55 0 2 . 6 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 5 - 17 4 55 4 4 . 2 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 5 3. 9 0 0. 7 - 17 5 55 8 6 . 3 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 0 0. 3 - 17 6 56 2 8 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 3 0. 3 - 17 7 56 7 0 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 4 - 17 8 57 1 1 . 6 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 0 0. 5 - 17 9 57 5 3 . 1 3. 9 5 8 3. 9 6 0. 0 2 0. 8 0. 0 1 0. 4 3. 8 9 0. 7 - 18 0 57 9 4 . 6 3. 9 5 8 3. 9 6 0. 0 1 0. 7 0. 0 1 0. 3 3. 8 9 0. 5 - 18 1 58 3 5 . 9 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 3 0. 3 - 18 2 58 7 7 . 5 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 4 - 18 3 59 1 9 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 3 0. 0 - 18 4 59 6 0 . 9 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 2 0. 1 - 18 5 60 0 2 . 5 3. 9 5 8 3. 9 4 0. 0 1 0. 4 0. 0 1 0. 5 3. 9 2 0. 5 - 18 6 60 4 4 . 3 3. 9 5 8 3. 9 3 0. 0 2 1. 0 0. 0 1 0. 3 3. 9 1 0. 6 Li g h t D e p o s i t s ; 18 7 60 8 6 . 1 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 2 0. 5 - 18 8 61 2 7 . 3 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 4 - 18 9 61 6 9 . 1 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 0 0. 2 3. 9 2 0. 1 - 19 0 62 1 0 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 3 0. 4 - 19 1 62 5 2 . 5 3. 9 5 8 3. 9 6 0. 0 2 0. 8 0. 0 1 0. 3 3. 9 1 0. 4 - 19 2 62 9 3 . 7 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 4 - 19 3 63 3 5 . 5 3. 9 5 8 3. 9 5 0. 0 2 0. 8 0. 0 1 0. 3 3. 9 2 0. 6 - 19 4 63 7 7 . 3 3. 9 5 8 3. 9 8 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 2 0. 4 - 19 5 64 1 8 . 8 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 4 - 19 6 64 6 0 . 3 3. 9 5 8 3. 9 8 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 3 0. 1 - 19 7 65 0 1 . 5 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 2 0. 4 - [1 9 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 19 7 . 0 1 65 4 3 . 2 3. 9 5 8 3. 9 3 0. 0 1 0. 7 0. 0 1 0. 3 3. 8 7 2. 3 PU P : - 19 7 . 0 2 65 5 3 . 0 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 19 7 . 0 3 65 6 0 . 2 3. 9 5 8 3. 9 1 0. 0 1 0. 7 0. 0 1 0. 6 3. 8 5 3. 4 PU P : - 19 8 65 6 9 . 7 3. 9 5 8 3. 9 6 0. 0 2 1. 0 0. 0 1 0. 5 3. 9 1 1. 5 Li g h t D e p o s i t s ; 19 9 66 1 1 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 2 0. 2 - 20 0 66 5 2 . 4 3. 9 5 8 3. 9 4 0. 0 1 0. 6 0. 0 1 0. 3 3. 9 1 0. 7 - 20 1 66 9 3 . 4 3. 9 5 8 3. 9 4 0. 0 2 0. 8 0. 0 1 0. 8 3. 9 0 0. 9 - 20 2 67 3 5 . 2 3. 9 5 8 3. 9 3 0. 0 1 0. 7 0. 0 1 0. 7 3. 9 2 0. 5 - 20 3 67 7 6 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 0 0. 2 3. 9 1 0. 6 - 20 4 68 1 8 . 5 3. 9 5 8 3. 9 8 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 4 - 20 5 68 6 0 . 3 3. 9 5 8 3. 9 3 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 9 - 20 6 69 0 2 . 2 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 6 - 20 7 69 4 4 . 0 3. 9 5 8 3. 9 8 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 5 - 20 8 69 8 5 . 2 3. 9 5 8 3. 9 3 0. 0 2 0. 8 0. 0 1 0. 5 3. 9 2 0. 7 - 20 9 70 2 7 . 0 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 6 - 21 0 70 6 8 . 2 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 7 - 21 1 71 0 9 . 8 3. 9 5 8 3. 9 2 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 0 1. 2 - 21 2 71 5 1 . 6 3. 9 5 8 3. 9 5 0. 0 1 0. 3 0. 0 1 0. 4 3. 9 2 0. 7 - 21 3 71 9 2 . 8 3. 9 5 8 3. 9 8 0. 0 3 1. 7 0. 0 1 0. 4 3. 9 2 0. 2 Li g h t D e p o s i t s ; 21 4 72 3 3 . 9 3. 9 5 8 3. 9 7 0. 0 1 0. 6 0. 0 1 0. 3 3. 9 1 0. 5 - 21 5 72 7 5 . 2 3. 9 5 8 3. 9 5 0. 0 1 0. 7 0. 0 0 0. 2 3. 9 0 0. 6 - 21 6 73 1 6 . 8 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 7 3. 9 1 0. 7 - 21 7 73 5 8 . 4 3. 9 5 8 3. 9 7 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 1 0. 8 - 21 8 74 0 0 . 1 3. 9 5 8 3. 9 4 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 5 - 21 9 74 3 7 . 6 3. 9 5 8 3. 9 3 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 5 - 22 0 74 7 9 . 2 3. 9 5 8 3. 9 7 0. 0 2 1. 0 0. 0 1 0. 3 3. 9 2 0. 9 - 22 1 75 1 9 . 5 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 1 0. 4 - 22 2 75 6 1 . 2 3. 9 5 8 3. 9 4 0. 0 1 0. 7 0. 0 1 0. 4 3. 8 9 0. 7 - 22 3 76 0 2 . 7 3. 9 5 8 3. 9 6 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 6 - 22 4 76 4 4 . 8 3. 9 5 8 3. 9 4 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 0 0. 6 - 22 5 76 8 6 . 4 3. 9 5 8 3. 9 3 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 2 0. 3 - 22 6 77 2 7 . 7 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 4 3. 9 2 0. 3 - 22 6 . 0 1 77 6 9 . 3 3. 9 5 8 3. 9 2 0. 0 1 0. 7 0. 0 1 0. 6 3. 8 5 4. 1 PU P : - 22 6 . 0 2 77 7 9 . 2 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 22 6 . 0 3 77 8 6 . 2 3. 9 5 8 3. 9 4 0. 0 3 1. 6 0. 0 1 0. 3 3. 8 7 2. 4 PU P : L i g h t D e p o s i t s ; [2 0 ] MI T J o i n t T a b u l a t i o n S h e e t ( P r o j e c t i o n ) Da t a : f i e l d / w e l l / r u n 1 / p a s s 9 . 1 S u r v e y D a t e : 0 5 / 2 4 / 2 0 1 5 Lo c a t i o n : U S A Jo i n t De p t h ft No m I D in Mo d e I D in Pr o j e c t i o n Bo d y in % Co u p l i n g in % Mi n I D in Ar e a Lo s s % Pr o j e c t i o n D e s c r i p t i o n ConstrictionProjection Profile (%)01 0 0 22 7 77 9 5 . 9 3. 9 5 8 3. 9 7 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 0. 6 - 22 8 78 3 7 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 7 - 22 9 78 7 9 . 9 3. 9 5 8 3. 9 6 0. 0 1 0. 6 0. 0 1 0. 3 3. 9 2 0. 8 - 23 0 79 2 1 . 5 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 6 - 23 1 79 6 3 . 3 3. 9 5 8 3. 9 6 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 0 0. 7 - 23 2 80 0 5 . 3 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 2 0. 5 - 23 3 80 4 7 . 3 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 5 3. 9 0 0. 8 - 23 4 80 8 8 . 8 3. 9 5 8 3. 9 3 0. 0 2 0. 8 0. 0 1 0. 3 3. 9 1 1. 1 - 23 5 81 3 0 . 8 3. 9 5 8 3. 9 3 0. 0 1 0. 5 0. 0 1 0. 3 3. 9 1 0. 9 - 23 6 81 7 2 . 6 3. 9 5 8 3. 9 4 0. 0 2 1. 2 0. 0 1 0. 3 3. 9 1 1. 0 Li g h t D e p o s i t s ; 23 7 82 1 4 . 2 3. 9 5 8 3. 9 7 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 1 1. 0 - 23 8 82 5 6 . 4 3. 9 5 8 3. 9 4 0. 0 1 0. 5 0. 0 1 0. 3 3. 8 9 1. 0 - 23 9 82 9 8 . 4 3. 9 5 8 3. 9 2 0. 0 1 0. 6 0. 0 1 0. 3 3. 9 1 0. 8 - 24 0 83 4 0 . 2 3. 9 5 8 3. 9 4 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 9 0. 6 - 24 1 83 8 1 . 2 3. 9 5 8 3. 9 9 0. 0 1 0. 7 0. 0 1 0. 5 3. 9 4 0. 0 - 24 2 84 2 1 . 8 3. 9 5 8 3. 9 4 0. 0 1 0. 7 0. 0 1 0. 3 3. 9 3 0. 0 - 24 3 84 6 2 . 8 3. 9 5 8 3. 9 4 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 2 0. 9 - 24 4 85 0 4 . 3 3. 9 5 8 3. 9 3 0. 0 1 0. 5 0. 0 1 0. 3 3. 8 9 0. 8 - 24 5 85 4 6 . 3 3. 9 5 8 3. 9 2 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 1 1. 0 - 24 6 85 8 8 . 0 3. 9 5 8 3. 9 4 0. 0 1 0. 5 0. 0 1 0. 4 3. 8 9 0. 8 - 24 7 86 2 9 . 8 3. 9 5 8 3. 9 3 0. 0 1 0. 7 0. 0 1 0. 4 3. 8 8 1. 1 - 24 8 86 7 1 . 6 3. 9 5 8 3. 9 2 0. 0 1 0. 7 0. 0 1 0. 4 3. 9 0 1. 1 - 24 9 87 1 3 . 4 3. 9 5 8 3. 9 6 0. 0 1 0. 6 0. 0 1 0. 4 3. 9 0 0. 7 - 25 0 87 5 4 . 9 3. 9 5 8 3. 9 5 0. 0 1 0. 5 0. 0 1 0. 4 3. 9 1 0. 8 - 25 0 . 0 1 87 9 6 . 3 3. 9 5 8 3. 8 9 0. 0 5 2. 3 0. 0 1 0. 3 3. 8 1 3. 2 PU P : L i g h t D e p o s i t s ; 25 0 . 0 2 88 0 6 . 1 3. 9 6 - - - - - - - GL M : N o t A n a l y s e d 25 0 . 0 3 88 1 3 . 4 3. 9 5 8 3. 9 1 0. 0 3 1. 7 0. 0 1 0. 4 3. 8 3 3. 0 PU P : L i g h t D e p o s i t s ; 25 1 88 2 2 . 9 3. 9 5 8 3. 9 5 0. 0 1 0. 4 0. 0 1 0. 3 3. 9 0 1. 3 - 25 2 88 6 5 . 0 3. 9 5 8 3. 9 4 0. 0 2 0. 8 0. 0 1 0. 3 3. 8 9 1. 4 - 25 2 . 0 1 89 0 6 . 2 3. 9 6 - - - - - - - IN V A L I D C A L I P E R F I N G E R S : N o t A n a l y s e d [21] Pipe Cross-Section View Penetration damage in Joint 226.03 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Penetration Depth Sensor 10.40% (0.03in) 7788.48ft MIT 8 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.94in [22] Pipe Cross-Section View Penetration damage in Joint 197.01 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Penetration Depth Sensor 9.96% (0.03in) 6550.80ft MIT 15 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.93in [23] Pipe Cross-Section View Penetration damage in Joint 96.01 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Penetration Depth Sensor 9.33% (0.03in) 3025.39ft MIT 4 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.97in [24] Pipe Cross-Section View Metal loss in Joint 1 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Metal Loss Depth 3.2% 32.66ft Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.97in [25] Pipe Cross-Section View Metal loss in Joint 126 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Metal Loss Depth 3.0% 3940.54ft (Coupling) Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.98in [26] Pipe Cross-Section View Metal loss in Joint 91 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Metal Loss Depth 2.9% 2832.11ft (Coupling) Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 4.00in [27] Pipe Cross-Section View Projection in Joint 250.01 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Projection Depth Sensor 2.32% (0.05in) 8804.28ft MIT 23 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.89in [28] Pipe Cross-Section View Projection in Joint 96.03 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Projection Depth Sensor 2.00% (0.04in) 3037.00ft MIT 5 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.98in [29] Pipe Cross-Section View Projection in Joint 250.03 Company Field Well Country County State Analysed By Survey Date ConocoPhillips Alaska Tract Operation Monitor 02 3S-620 USA North Slope Alaska C. Gullett 05/24/2015 Section Data Projection Depth Sensor 1.72% (0.03in) 8815.57ft MIT 23 Joint Data Nominal Measured ID OD Thickness 3.96in 4.50in 0.27in 3.91in
