Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
215-072
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS E �"VED JUN 14 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ /plae+ta�wn ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Chy�g qt=r m ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well Other: Scale Inhibitor Treatmenp 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development O Exploratory Stratigraphic ❑ Service❑ 215-072 3. Address: PO BOX 100360 6. API Number: Anchorage, AK 99510 50-103-20711-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 932671, 932128 CRU CD5-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Unit / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 18878 feet Plugs measured None feet true vertical 7420 feet Junk measured None feet Effective Depth measured 18878 feet Packer measured 11364 feet true vertical 7420 feet true vertical 7386 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 115' 115' Surface 2291' 10.75" 2327' 2231' Intermediate 11802' 7.625" 11837' 7474' Production Liner 7202' 4.5" 18863' 7421' Perforation depth Measured depth Perf Pups 12503'- 18157' True Vertical depth Perf Pups 7474'- 7436' Tubing (size, grade, measured and true vertical depth) 3.5", L-80, 11686' MD, 7449' TVD Packers and SSSV (type, measured and true vertical depth) Packer -Baker Premier Packer, 11364' MD, 7386' TVD SSSV - None (not required) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 12503'- 18157' MD Treatment descriptions including volumes used and final pressure: Please 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: 393 424 288 1150 323 Subsequent to operation:1 496 416 1 312 1 1618 1 322 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ DevelopmentEl Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Ka lie Plunkett Contact Name: Kaylie Plunkett Authorized Title: Senior Production Engineer Contact Email: Ka Iie.B.Plunkett co .com Authorized Signature: Date: Contact Phone: 265-6450 q Form 10-404 Revised 4/2017 If Vl �/ R BDMS Lbw JUN 1 B 7019 Submit Original Only CD5-04 Scale Inhibition Treatment 5/24/19 —5/25/19 Non -Aqueous Scale Inhibitor Squeeze Job pumped from 1430 hrs on 5/24/19 to 1030 hrs on 5/25/19. LRS = Little Red Services - Initial pressure TBG/IA/OA-887/1064/305 - LRS pumped 290 bbls Diesel/M209/WAW5206 pre -flush at 3.5-3.8 bpm, TBG/IA/OA- 687/1008/195 - LRS pumped 290 bbls 70/30 EG/Water and SCW3001WC scale inhibitor main treatment at 3.0 — 3.5 bpm, TBG/IA/OA — 324/964/132 - LRS pumped 2987 bbls Dead Crude/M209 over -flush at 2.5-3.6 bpm, TBG/IA/OA- 1980/1113/595 - Final pressure TBG/IA/OA-1980/1113/595 Interval treated: 12503'— 18157' MD • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, October 25, 2017 6:05 PM To: Wallace, Chris D (DOA); Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: CRU CD5-02A, CD5-04, and CD5-99A Water Flow in Conductors Chris/Victoria, CRU wells CD5-02A(PTD 216-068),CD5-04(PTD 215-072), and CD5-99A(PTD 216-122) have recently been noted as having water flowing to surface through the surface casing by conductor annulus. CPAI suspects this water to be from the same shallow source water that was encountered on CD5-313 (PTD 215-084),as well as other CD5 wells. We will take initial samples for analysis and collect water at the wellhead to monitor the flow volume. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 • • 2166 -072 ECTIVED Alaska NOV 10 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 r_ i OG October 30, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7h1 Avenue, Suite 100 SCANNED MAk ` N?, Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU).Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404,Report of Sundry Operations. The cement was pumped October 29th 2016. The corrosion inhibitor/sealant was pumped on October 30th 2016. The attached spreadsheet presents the well name,top of cement depth prior to filling,and volumes used on each conductor. Please call Aaron Applehans or Roger Winter at 907-659-7506,if you have any questions. Sincerely, / Aaron Applehans ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 10/30/2016 CD5 PAD 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 CD5-01 50103207360000 2160220 1.33' .17 bbl .66' 10/29/2016 5.1 gal 10/30/2016 CD5-02 50103207370100 2160680 1' .1 bbl .66' 10/29/2016 5 gal 10/30/2016 CD5-03 50103207180000 2151460 1.08' .1 bbl .66' 10/29/2016 5 gal 10/30/2016 (CD5-04 50103207110000 2150720 .875' .07 bbl .66' 10/29/2016 5.1 gal 10/30/2016 CD5-05 50103207120000 2150730 2.25' NA 2.25' 5/29/2016 18 gal 10/30/2016 CD5-07 50103207340000 2160040 1.42' .2 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-08 50103207410000 2160510 4.75' .71 bbl 1.83 10/29/2016 CD5-12 50103207420000 2160520 2.58' .47 bbl 0.66 10/29/2016 5 gal 10/30/2016 CD5-315 50103207160000 2151370 1' .1 bbl 0.66 10/29/2016 5.1 gal 10/30/2016 CD5-21 50103207380000 2160310 .75' .6bbl 0.66 10/29/2016 3.4 gal 10/30/2016 RECEIVED STATE OF ALASKA ALARAOIL AND GAS CONSERVATION COMM ION MAR 14 2016 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon E Plug Perforations[ Fracture Stimulate i'. Pull Tubing 1- Operations Shutdown E Performed: Suspend E Perforate E Other Stimulate r Alter Casing E Change Approved Program- Plug for Redrill rPerforate New Pool E Repair Well E Re-enter Susp Well E i 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 215-072 _ 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20711-00 7.Property Designation(Lease Number): 8.Well Name and Number: ASRC NPR4,ASRC NPR2 CRU CD5-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): , 10.Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 18878 feet Plugs(measured) None true vertical 7421 feet Junk(measured) None Effective Depth measured 18864 feet Packer(measured) 11,364, 11,661 true vertical 7420 feet (true vertical) 7386, 7445 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 115 115 0 0 SURFACE 2291 10 3/4 2327 2231 0 0 INTERMDIATE 11802 7 5/8 11837 7473 0 0 LINER 7202 41/2 18863 7421 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 12,503'-18,157' True Vertical Depth: 7,474-7,436' CANISt Tubing(size,grade,MD,and ND) 3.5, L-80, 11686 MD, 7449 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 11364 MD and 7386 ND PACKER- Baker HRD-E-ZXP liner Top Packer @ 11661 and 7445 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12503-18157 Treatment descriptions including volumes used and final pressure: Total Well- 10 stages 555k placed.....See attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1570 2 823 170 Subsequent to operation 3804 263 1300 208 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r!o Exploratory E Development F Service fl Stratigraphic Copies of Logs and Surveys Run E 16.Well Status after work: Oil P Gas WDSPL la Printed and Electronic Fracture Stimulation Data rGSTOR r WINJ E WAG I- GINJ E SUSP E SPLUG 1- 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: 316-002 Contact Robert Blaknev ta7.265-6417 Email Robert.G.BlaknevCa�conocophillips.com Printed Name Robert Blakney Title Completions Engineer Signature , Phone:265-6417 Date 3 'Iri I Zov,0 ' it k.., fog F obi t 1at Form 10-404 Revised 5/2015 RBDMS E-1-- MAR 4 2016 Submit Original Only • CD5-04 • DTTMS JOBTYP SUMMARYOPS 2/6 FRACTURING PULLED 1" OV @ 11188' RKB. PULLED 1" GLV @ 8008' RKB, REPLACED w/ 1" DGLV. PULLED 1" GLV @ 4112' RKB, REPLACED w/ 1" DGLV. READY FOR CIRC OUT. IN PROGRESS 2/6 FRACTURING PUMPED 400 BBLS CORROSION INHIBITED BRINE FOLLOWED BY 86 BBLS DIESEL DOWN TBG. ALLOWED TBG AND IA TO U-TUBE FOR 1.5 HOURS FOR FREEZE PROTECT OF TBG AND IA. JOB COMPLETE. 2/8 FRACTURING SET 1" DGLV @ 11188' RKB. DRIFT TO 40' SLM w/3.86" G-RING. LRS RIGGING UP TO PERFORM MIT'S. IN PROGRESS 2/8 FRACTURING PERFORM PASSING MIT-T& MIT-IA. PULL 2.81" C.A.T. STANDING VALVE FROM DS NIP @ 11390'RKB. JOB COMPLETE. 2/10 FRACTURING Rigged up stinger and HES frac equipment. Pumped stages 1-4. 264,000 lbs placed. 2/16 FRACTURING Pumped stages 5-10. 555,400 lbs of 16/20 carbolite place. Well is freeze protected and ready for normalling up operations. 2/21 FRACTURING MADE MULTIPLE BRUSH RUNS BRUSHING TBG & MANDRELS, TAG OBSTRUCTION @ 11280' SLM . . (RECOVERED STRIPS OF PLASTIC & PART OF ELEMENT FROM TREE SAVER). RAN 2.5" BAILER. SET 2.81" CAT SV @ 11390' RKB. PULL DV @ 11188' RKB. REPLACE WITH 1/4" OV. PULLED DV's @ 8008' &4112' RKB's. SET 3/16" GLV(TRO 1895) @ 8008' & 3/16" GLV(TRO= 1988) @ 4112' RKB's. MITT TO 2520 psi. **PASS**. PULLED STANDING VLV @ 11390' RKB. **READY FOR FLOW BACK**. • • • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 2/10/2016 Job End Date: 2/16/2016 State: Alaska ;7,,,' 0' County: Harrison Bay Fac API Number: 50-103-20711-00-00 FOCUS Operator Name: ConocoPhillips Company/Burlington Chemecal Disclosure R try Resources Well Name and Number: CD5-04 Longitude: -151.22306900 GROJNDWATER Latitude: 70.31360600 111111111 .� F Datum: NAD83 Qll <3 Federal/Tribal Well: NO True Vertical Depth: 7,420 Total Base Water Volume(gal): 463,227 Total Base Non Water Volume 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Number Concentration in Concentration in Comments (CAS#) Additive HF Fluid (%by mass)** (%by mass)** Sea Water Operator Base Fluid NA NA 100.00000 81.886000ensity=8.540 be-6 MICROBIOCIDE,Halliburton Additive,Biocide, CL-22 UC,CL-31 Breaker,Crosslinker, CROSSLINKER, Gelling Agent, _OSURF-300D,MO- Microbiocide,Non- 67,OPTIFLO-III onic Surfactant,pH DELAYED RELEASE Control Additive BREAKER,SP BREAKER,WG-36 GELLING AGENT NA NA CarboLite 16/20 CarboCeramics Proppant NA NA LVT-200 Penreco Additive NA NA -nts S r,above are subject td Tlr0.1200(i)and appear on aterial Safety Data Sheets(MSDS).Ingre�t"lents shown below are Non-MSDS. Hazardous and Non- Hazardous Ingredients Ceramic materials and wares, 66402-68-4 100.00000 16.92182 chemicals • • ydrotreated Distillate,Light..C9 64742-47-8 100.0000C 0.60161 16 uar gum 9000-30-0 100.0000C 0.25777 ater 7732-18-5 100.0000C 0.14603 :orate salts Confidential 60.0000C 0.06085 •otassium formate 590-29-4 60.0000C 0.06085 thanol 64-17-5 60.0000C 0.04623 •xyalkylated phenolic resin Confidential 30.0000C 0.03082 odium hydroxide 1310-73-2 30.0000C 0.02704 •otassium metaborate 13709-94-9 60.00005 0.02547 eavy aromatic petroleum 64742-94-5 30.0000C 0.02312 aphtha mmonium persulfate 7727-54-0 100.00000 0.01935 :entonite,benzyl(hydrogenated 121888-68-4 5.0000C 0.01289 allow alkyl)dimethylammonium .tearate complex rystalline silica,quartz 14808-60-7 30.00005 0.00591 ured acrylic resin Confidential 30.0000C 0.00581 surfactant mixture Confidential 1.0000C 0.00516 aphthalene 91-20-3 5.0000C 0.00385 •oly(oxy-l,2-ethanediyl),alpha-127087-87-0 5.00000 0.00385 4-n o nyl ph enyl)-omega- ydroxy-,branched silica gel 112926-00-8 1.0000C 0.0025E •otassium hydroxide 1310-58-3 5.0000C 0.00212 '-Bromo-2-nitro-1,3-propanediol 52-51-7 100.0000C 0.00197 odium chloride 7647-14-5 1.0000C 0.00192 -odium carboxymethyl cellulose 9004-32-4 1.0000C 0.00101 crylate polymer Confidential 1.00000 0.00101 Denise Tuck,Halliburton, 3000 N.Sam Houston Pkwy E., Houston,TX 77032,281- 871-6226 odium glycollate 2836-32-0 1.00000 0.00101 ,2,4 Trimethylbenzene 95-63-6 1.00000 0.00077 .odium persulfate 7775-27-1 100.00000 0.00041 rystalline Silica,Quartz 14808-60-7 0.10000 0.00026 .odium sulfate 7757-82-6 0.10000 0.00000 Total Water Volume sources may include fresh water,produced water,and/or recycled water •*Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i)and Appendix D are obtained from suppliers Material Safety Data Sheets(MSDS) WNS PSD CD5-04 ConocoPhi lips '& " Well Attribut Max Angle TD Alaska.Inc, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corp li,igip5 501032071100 ALPINE PROD 94.20 18,878.00 18,878.0 Y_, 1 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 005-04,3/11/20169.46.06 AM SSSV:NIPPLE Last WO: 36.94 6/24/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER:0.0- 111:1Last Tag' Rev Reason:UPDATED FRAC PORT los lehallf 3/1/2016 El asing rings II all II Casing Description CONDUCTOR OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 20 19.000 35.2 1152 115.2 ,hl....I Casing Description OD lin) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' SURFACE 10 3/4 9.950 36.1 2,327.0 2,231.4 45.50 L-80 Hyd 563 U I ���� Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ■A INTERMDIATE 75/8 6.875 34.9 11,836.7 7,473.7 29.70 L80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR,35.2-115.2 LINER 41/2 3.958 11,660.8 18,863.0 7,421.0 12.60 L-80 Hyd 563 V Liner Details 4111 ME Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Rem Des Com (in) NIPPLE;5072 -IL 11,660.8 7,444.8 79.98 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 II 11,680.5 7,448.2 80.09 NIPPLE BAKER RS PACKOFF NIPPLE 4.950 7,448.7 80.11 HANGER BAKER FLEX-LOCK LINER HANGER 4.790 11,693.1 7,450.3 :1 ••-. Cross over,5-1/2"H563 x 4-1/2"H563 L-803.860 12,347.6 92.88 SLEEVE CAMCO SLIDING SLEEVE X PROFILE,OPEN DOWN 2.813 17,481.6 1 ••• FRAC SLEEVE#9,BALL 2.125",2.1ID2.100 suRFACE:351-z327o IIi) ••• FRAC SLEEVE#8,BALL 2.063",2.05"ID1116 13,941.8 7,467.6 89.1 1 FRAC••• FRAC SLEEVE#7,BALL 2.0",1.980ID •8GAS LIFT;411251111 14,629.9 7,477.7 ••• FRAC SLEEVE#6,BALL1.938",1.920"IDI I 90.05 FRAC PORT FRAC SLEEVE#5,BALL 1.875",1.872"ID 1.872 16,043.4 7,462.3 90.50 FRAC PORT FRAC SLEEVE#4,BALL 1.813",1.805"10 1.805 at GAS LIFT,5008.1 ( 16,747A 7,449.4 91.42 FRAC PORT FRAC SLEEVE#3,BALL 1.75",1.7510 1.728 17,453.8 7,440.4 90.22 FRAC PORT FRAC SLEEVE#2,BALL 1.688",1.635"I0- 1.635 Mr BAKERLOK'D lei GAS LIFT,11,188.3 g 18,157.0 7,435.8 90.61 FRAC PORT FRAC SLEEVE#1,BALL 1.625",1.573"ID- 1.573 IR BAKERLOK'D IN Tubing Strings GAUGE;11,307.5 Tubing Description String Ma...ID(inl Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(Ibfft) Grade Top Connection ril TUBING I 31/21 2.992 0.0 11,686.1 7,449.1 9.30 L-80 EUE Completion Details PACKER;11,303.6 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc!Ft Item Des Com (in) 0.0 HANGER FMC ALP HANGER 3.958 gig NIPPLE,11,390.3 --. 117.5 117.5 0.16 XO Reducing XO,4-1/2"HYD563 Box x 3-1/2"EUE 8rd Pin Drifted 2.992 2.91" it 5072 507.2 0.88 NIPPLE CAMCO LANDING DS NIPPLE 2.875 LOCATOR;11,656.7- f 11,307.5 7,372.3 76.10 GAUGE CAMCO SLB SOLID GAUGE MANDREL WITH I-WIRE 2.920 WLEG;11,659.7 f ! 11,363.6 7,385.8 76.12 PACKER BAKER PREMIER PACKER 2.880 l('l'. 11,390.3 7,392.2' 76.56 NIPPLE CAMCO DS LANDING NIPPLE 2.812 k (PULLED 2.81"C.A.T.Standing Valve 2/8/2016) 11,658.7 7,444.4 79.97 LOCATOR LOCATING SUB 3.000 11,659.7 7,444.6 79.98 WLEG BAKER WLEG 2.970 1 i Perforations&Slots Shot Dens INTERMDIATE;34.9-11,836.7 Top(ND) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 1 i 12,502.7 12,506.2 7,474.2 7,474.1 6/20/2015 PERFP Frac Port 13,199.5 13,203 0 7,467.8 7,467.8 6/20/2015 PERFP Frac Port 13,941.8 13,945.3 7,467.6 7,467.6 6/20/2015 PERFP Frac Port 14,629.9 14,633.4 7,477.7 7,477.7 6/20/2015 PERFP Frac Port PERFP;12,502.7-12,508.16/2w2oi 5 PERFP Frac Port 16,043.4 16,046.96/2(1/2015 16,747.4 1• JiI PERFP;13,1585-13,203017,453.8 17,456.5 118.157 1 PERFP;13,941.8-13,945.3 1 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date PERFP;14,629.9-14,833.4 12,503.0 14,630.0 2/10/2016 111 r 91 1 1 . 1• 6111 • "I carbolite ( 1• 820,000 PERFP;15,338.8-15,342.2 ,�..f 1•Carbolite place. I Mandrel Inserts St PERFP;18,043.4-16,048.9 iIll I ati CAMCOI 1s. Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com KBMG 1 GAS LIFT GLV BK 0.188 :12/21/2016 PERFP;16,747.4-18,750.9 )I•.1 2 8,008.1 • KBMG 1 GAS LIFT GLV BK 0.188 • 12/21/2016 CAMCO3 11,188 3 7,343.4 KBMG 1 GAS LIFT OV BK 0.250 11 2/21/2016 PERFP;17,453.8-17,456.5 fl I Notes:General&Safety End Date Annotation NOTE PERFP;18,157.0 p i lit I 1 0 LINER;11,860.7-18,683.0 OF T • � • THE STATE Alaska Oil and Gas of/\ T /\ Conservation Commission - -= KA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF""�me--.•.' � \ .... _._ ..._ _.... Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Robert Blakney Completions Engineer ConocoPhillips Alaska, Inc. �� . ' ' P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-04 Permit to Drill Number: 215-072 Sundry Number: 316-002 Dear Mr. Blakney: 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, P901. Cathy P oerster Chair DATED this /4137-of January, 2016. JL/ RBDMs JAN 15 2018 • 111 RECEIVED STATE OF ALASKA JAN 0 4 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION „� � /1/ / . APPLICATION FOR SUNDRY APPROVALS AOQ 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q , Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory ❑ Development 0. 215-072 .- 3. 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20711-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? , 1 1/f fl CRU CD5-04 Will planned perforations require a spacing exception? Yes ❑ No © J 9.Property Designation(Lease Number): 10.Field/Pool(s): ASRC NPR4, ASRC NPR2 Colville River Unit/Alpine Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): EffectivetiDepth MD: Effective Depth TVD: I MPSP(psi): Plugs(MD): Junk(MD): FM 18,878' 7,421' t7 t>nt3 74 to r 7,000 Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' Surface 2,292' 10-3/4" 2,327' 2,231' Intermediate 11,801' 7-5/8" 11,836' 7,473' Production Liner 18,828' 4-1/2" 18,863' 7,421' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic / See Attached Schematic 3-1/2" L-80 11,686' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM INSTALLATION no SSSV • 11,364'MD,no SSSV 12.Attachments: Proposal Summary E Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 1st,2016 OIL 0 • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Robert Blakney @ 907-265-6417 Email Robert.G.Blakney@conocophillips.com Printed Name Robert Blakney Title Completions Engineer WI f NXXt uktne j t1 -1 120\ko Signature Phone 907-265-6417 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ii `%' , I/) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ (//� Other: Post Initial Injection MIT Req'd? Yes ❑ No LJ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: it, — 4 f> — APPROVED BY Approved by: Se..1P COMMISSIONER THE COMMISSION Date: /—/T"° ���/!/ '?I I t�i� Submit Form and Form 10-403 Rr v ed 11/27 /,4 AUo�e ip li a�io j id(br IRB9 SomJNd�t o „ r,val. / /Attachments in Duplicate WNS OD CD5-04 ConocoPhillips '� .{k r, ,`` Well Attrlbu Max Angl110TD Alaska,IInc. Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm)ftKB) ,„,, ;1,,,, 501032071100 ALPINE PROD 94.20 18,878.00 18,878.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD5-04,12/31/20159:14.18 AM SSSV:NIPPLE Last WO: 36.94 6/24/2015 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date vorocal schematic(actual) Last HANGER;0.0-. : Rev Reason:MANDREL • 1 15 i if as no ngs Top(ftKB3)5 2 Set Depth(ftftiBi)5.2 Set Depth IT1/4)5.. Wt/Len(I...Grade Top Thread 11 1 • ., •• 1 , •111 1 II ' I I C in Descri tion OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' ption OD(in) ID(in). To (ftKB) Set Depth(f;KB) Set Depth(TVD).. Wt/Len(I...Grade TOP Thread I��hl II�iICasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;35.2-115.2 11,660.8 1 1 .1 L-80 Hyd 563 V •AI at Nominal ID 'M 11,660.8 7,444.8 79.98 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 NIPPLE,507.2 III 11,680.5 7,448.2 80.09 NIPPLE BAKER RS PACKOFF NIPPLE 4.950 7,448.7 :1 • 1 11,693.1 12,347.6 7,450.3 80.17 X0 Reducing Cross over,5-1/2"H563 x 4-1/2"H563 L-80 7,481.6 92.88 SLEEVE CAMCO SLIDING SLEEVE X PROFILE,OPEN 3.860 2.813 i i 1DOWN :1 •.• 2.10"ID .t1 1 11 SURFACE;36.1-2,327.0 •1 PORT 1• 1 . 1 11,683.3 13,941.8 7,467.6 89.11 FRAC PORT FRAC SLEEVE#7,BALL 2.0",1.980"ID 3.900 ' GAS LIFT;4,112.5IFI1I1! III11 90.41 FRAC PORT FRAC SLEEVE • 1 . 3.900 i at GAS LIFT;8,008.1 1- 17,453.8 7,440.4 90.22 FRAC PORT FRAC SLEEVE#2,BALL 1.688",1.635"ID- 3.900 Ei BAKERLOK'D • 18,157.0 7,435.8 90.61 FRAC PORT FRAC SLEEVE#1,BALL 1.625",1.573"ID- 3.900 GAS LIFT;11,188.3 i BAKERLOK'D a Tubing Strings iii Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..Set Depth)WO)I...Wt(1b#t) Grade Top Connection GAUGE.11,307.5 �. TUBING 1 31/21 2.9921 0.01 11,686.11 7,449.11 9.301 L-80 I EUE a Completion Details` Nominal ID PACKER;11,363.6 i I I Top(ftKB) Top)TVD)(ftKB) Top Incl(°I Item Des Com (In) I 0.0 HANGER FMC ALP HANGER 3.958 B 117.5 117.5 0.16 XO Reducing X0,4-1/2"HYD563 Box x 3-1/2"EUE 8rd Pin Drifted 2.992 NIPPLE;11,390.3 .. 291" al 507.2 507.2 0.88 NIPPLE CAMCO LANDING DS NIPPLE 2.875 LOCATOR;11,658.7 11,307.5 7,372.3 76.10 GAUGE CAMCO SLB SOLID GAUGE MANDREL WITH I-WIRE 2.920 ■■■■ 11,363.6 7,385,8 76.12 PACKER BAKER PREMIER PACKER 2.880 WLEG;11,659.7 11,390.3 7,392.2 76.56 NIPPLE CAMCO DS LANDING NIPPLE 2.812 11,658.7 7,444.4 79.97 LOCATOR LOCATING SUB 3.000 11,659.7 7,444.6 79,98 WLEG BAKER WLEG 2.970 Perforations&Slots 1 Shot Dens I I TopftKB Btm kKB Top(ftKB D) Bt(ft B(TVD) Zone Date Is ft(shots/ TypeCom l ) I ) 1 ) ) 12,502.7 12,506.2 7,474.2 7,474.1 6/20/2015 PERFP Frac Port INTERMDIATE,34.9-11,836.7 13,199.5 13,203.0 7,467.8 7,467.8 6/20/2015 PERFP Frac Port ' 13,941.8 13,945.3 7,467.6 7,467.6 6/20/2015 PERFP Frac Port 14,629.9 14,633.4 7,477.7 7,477.7 6/20/2015 PERFP Frac Port 15,338.8 15,342.2 7,463.8 7,463.8 6/20/2015 PERFP Frac Port 16,043.4 16,046.9 7,462.3 7,462.3 6/20/2015 PERFP Frac Port PERFP;12,502.7-12,506.1 16,747.4 16,750.9 7,449.4 7,449.3 6/20/2015 PERFP Frac Port 17,453.8 17,456.5 7,440.4 7,440.4 6/20/2015 PERFP Frac Port PERFP,13,199.5-13,203.0 18,157.0 18,157.0 7,435.8 7,435.8 6/20/2015 PERFP Frac Port Mandrel Inserts St ati PERFP,13,941.8-13,9453 on N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 4,112.5 3,412.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,892.0 7/21/2015 PERFP;14,629.9-14,633.4 2 8,008.1 5,639.8 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,844.0 7/21/2015 3 11,188.3 7,343.4 CAMCO KBMG 1 GAS LIFT OV BK ' 0.250 0.0 7/21/2015 D2CK- �n 4� PERFP;15,338.8-15,342.2 Notes:Generef&Safety End Date Annotation NOTE: PERFP,16.043.4-16,046.9 PERFP,16,747.4-16,750.9 PERFP;17,453 8 17,456 5 PERFP,18,157.0 LINER;11,660.7-18,863.0 • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE•ASKA OIL AND GAS CONSERVATION COMISION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Garrett B. Haag Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the CD5-04 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Garrett B. Haag, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Garrett B. Haag. 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 December 15, 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 15th day of December, 2015. J./ Garrett B. Haag/ STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 15th day of December, 2015, by Garrett B. Haag.,b Notary Public, State of Alaska My Commission Expires: fSTATE OF ALASKA Aft:, NOTARY PUBLIC 1 REBECCA SWENSEN �'• ' 1 My Commission Expires Aug.27,2016 • • P.O.BOX 100360 ConocoPhillips ANCHORAGE,ALASKA 99510-0360 Alaska, Inc. Garrett B.Haag,Staff Landman Land Department,ATO 1480 Phone (907)265-6297 Fax (907)263-4966 Garrett.B.Haaggcop.com December 15,2015 VIA CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1)for CD5-04 Well AA-092347,ADL 387208,ASRC NPRA-02,ASRC NPRA-03,ASRC NPRA-04 Colville River Unit,Alaska CPAI Contract No. 203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAP') as Operator and on behalf of the Colville River Unit ("CRU") 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 CD5-04 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about January 6, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional horizontal well on leases, ASRC NPRA-04 and ASRC NPRA- 02 as depicted on Exhibit 1 and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 310 2,497 11N 4E 18 Umiat Heel 2,147 1,693 11N 4E 8 Umiat Bottomhole 1,292 ' 5,068 11N 4E 5 Umiat 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. If you require any additional information,please contact the undersigned. Sincerely, 44a F Garrett B. Haag Staff Landman Attachments: Exhibits 1 &2 • • Exhibit 1 ASRC-NPR1 ConocoPhillips CD5-04 Plat Analysis Alaska Leases 11/05/15 ASRC-NPR3 ASRC PR4 ASRC-NPR2 CS' CDS AA09234 \\444........ oad ASRC- G05 P`ce55 R ADL387208 Legend REFERENCES: Well Data:ConocoPhillips Alaska Well Database ATDB Open Section Surface Facilities:Nuiqsut Pad Published 06/09/15 Well Trajectory o Start of Open Section • Frac Point 0 0.2 0.4 0.6 0.8 Q 1/2 Mile Radius Miles • CPAI Lease • 0 Exhibit 2 Operator&Owner: ConocoPhillips Alaska,Inc. 700 G Street, Suite ATO 1220(Zip 99501) P.O.Box 100360 Anchorage,AK 99510-0360 Attention: Erik Keskula,NS Development Manager Owner(Non-Operator): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver, CO 80202 Attention: Mike Nixson,Director Land-Alaska Landowners: Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa Imm,Resource Development Manager State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage,AK 99501-3560 Attention: Director Surface Owner: Kuukpik Corporation P.O.Box 89187 Nuiqsut,AK 99789 Attention: Mr.Isaac Nukapigak, President • • Section 2 — Plat 20 AAC 25.283 (a)(2) ConocoPhillips CDS-04:Pat A.lalysis Alaska WILLS 1105115 \\ ca 1 \ o ..?y GO n .,./..„:-*" S Legend REFERENCES: We I Data:CorocoPh€flips Alaska .%ell Database ATDB - Neal in lam,aatli5 aropei De tM Surface Facilities:Nuigsut Pad Published 06109115 — %Noselaft.Ranks atTragecvry N — c e Ts katacattry r Cs"Jeti:iEb^so14511 co:_¢.wperbutt r; 0.2 0.4 0.6 0.8 We:: 0 1 2 We RaCluas • . Wells within .5 Miles Well Name API Drill Site Status Well Type CD2-33 501032038100 CD2 PA PROD CD2-78 501032060100 CD2 ACTIVE INJ NUIQSUT 1 501032025300 PA N/A CD5-05 501032071200 CD5 ACTIVE PROD CD5-313 501032071400 CD5 ACTIVE PROD CD5-313PB1 501032071470 CD5 PA N/A CD5-314 501032070700 CD5 SUSP N/A CD5-315 501032071600 CD5 ACTIVE INJ CD5-315PB1 501032071670 CD5 PA N/A • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." S SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: 10 & 3/4" surface casing cement pump report on 5/24/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg DeepCRETE cement lead cement and 15.8 ppg Class G tail cement, and displaced with 10.0 ppg mud. Full returns were seen throughout the job. The plug bumped @ 900 psi and the floats were checked and they held. 7-5/8" casing cement pump report on 6/10/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, and displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 900 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. • • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 5/28/15 the 10 & 3/4" casing was pressure tested to 2,500 psi for 30 mins. On 6/13/15, the 7 & 5/8" casing was pressure tested to 3,500 psi. On 7/10/15 the 3.5" tubing was pressure tested to 3,500 psi. The 3.5" tubing will be pressure tested to 3,500 psi prior to frac'ing. The 7 & 5/8" casing will be pressure tested to 3,500 psi prior to frac'ing. • • SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10 & 3/4" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 7 & 5/8" 39 L-80 9,180 psi 8,820 psi 3.5" 9.3 L-80 (10,160 p 10,540 psi • • Stimulation Surface Rig-Up Y `=j Gleed l Tattle Tale Tank 0041 004 10 ' 3 I H t� N ywT - wt, :a,O U • Minimum pressure rating on all surface ��� it: l. ] treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure _ • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 ‘,2 Y t, psi. r 7 � V L awl dwnd U Pop Off Tank d Dal 0 4w J Pop-Ott Tank Pump Truck CN g a 41 1 C J 41- `Ca'N Frac Pump P ' . Frac Punp Frac Pump r' - i Frac 1=urip Frac Pump [Nal '` 0'/ Fra.;Punp • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON fl /CONNECTWN / kt _44 i * ,.TT,,,,, ..",,REMOTE OPERATED t ! MASTER VALVEeimmommar 1101 6P i. 1 MANUAL OPERATED 0111111111111111111111111111{ O* •Lt IlleF MATTER VALVE nins h� cti fell kti VI MUMStinger I ! MANDREL 1 . L i VENT ..•:Rj�1.111—,—VALVE _ _ `� OPEN 111* '' t1I ;.. :>> :' FLOW TEE AND t ����• � PENT VALVE WELLHEAD ' !11*;+w,t11! VALVES 1 `fr 4 OPEN .' trU . 1 r N ,y i. 1 a.1+4 j, C WELLHEAD + n CLOYED "'8 /\ t tir al QUAD PACKOFP „ ASSEMSLY R+1 "l i PLACE IN TUBING TUBING1pa•ti • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1/2 tubing and 1.75" down 3 t/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75"mandrel 36 bpm • -i .�� - 14U3 CD5-04 Additional Information: Updated to include lower confining zone data 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 Alpine A interval is approximately 30' TVD thick at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 11,817' MD/7,401 TVDSS. The estimated fracture gradient for the Alpine A sandstone is 12.5 ppg. The overlying confining zone consists of approximately 450' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 10,427 MD/6,947' TVDSS. The underlying confining zone consists of approximately 1800' of Kingak shales. The estimated fracture gradient for the Kingak shales is 15-18 ppg. Fracture gradient increases down section. The top of the Kingak interval ranges from —7470' TVDSS at the heel to —7525' TVDSS at the toe of the well (no MD as the Kingak interval was not penetrated in the CD5-04 wellbore). • • SECTION 9 — DATA FOR FRACTURING ZONE AND CONFING ZONES 20 AAC 25.283(a)(9) �,'. CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine A interval is approximately 30' TVD,thick at the heel of the lateral and generally maintaining the same thickness to the toe. The Alpine A sandstone is very fine grained and quartz rich, with a coarsening upward log profile. Top Alpine A is estimated to be at 11,817' MD/7,401 TVDSS. The estimated fracture gradient for the Alpine A sandtone is 12.5 ppg. The overlying confining zone consists of approximately 4 ' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for th iluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encou ered at 10,427 MD/6,947' TVDSS. f • • e r0 I� ` $ # | 2 E 2 to R ! ? 11 R. -It § § t / Ni.. § �� . ` kk 77 ; i § � | k -13 / a. j } J 7 2 ! 2 { } 42 1 221= o.a) .& 0 a) cc 4- > /\ t0two' ƒ CU \C \2 - —\4.4 ƒ! k i ) E @ CO= j\ CO �\ % a -2. V) a) 1,1_ - - \ - \k 4-0 2 2 _ } / \§ u ocZ. CO - -a2 )/ iv o - - -o - co , , !f - 3 8 }/ - \! ) [ o } \ z \ \ \ N { 3 ( 0 — £ a. M ` ` cr B # + ( 9 ] § B B § 5 § a z u • • 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: CD2-33: 9-5/8" casing cement pump report on 8/24/2001 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. The plug bumped at 1,200 psi and the floats were checked and they held. CD2-78: The 7-5/8" casing cement pump report on 8/29/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Class G cement, displaced with 10.7 ppg mud. Full returns were seen throughout the job. Did not bump plug. 410 psi held on cement head. NUIQSUT 1: The 9-5/8" casing cement pump report on 4/04/1998 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg cement. Full returns were seen throughout the job, and the plug bumped. The Nuiqsut 1 was then plugged and abandoned per state regulations on 4/13/1998. CD5-05: The 7-5/8" casing cement pump report on 8/27/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg Qannik Slurry cement, displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug bumped @ 1,700 psi and the floats did not hold. Pressure was held on the cement. CD5-313: The 7-5/8" casing cement pump report on 7/25/2015. The cement job was pumped with 15.8 ppg Class G cement, displaced with 11.1 ppg LSND. The plug bumped at 1,140 psi and the floats held. CD5-314: CD5-314 was plugged and abandoned per state regulations on 5/10/2015. CD5-315: The 7-5/8" casing cement pump report on 10/3/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement and displaced with 11.1 ppg LSND. Full returns were seen throughout the job. The plug did not bump and the floats held, and pressure was held on the cement. • K6vl5 - /loll Pa) 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) Questions 3 & 4 CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that there is one fault or fracture system that transects the Alpine A formation and may enter the confining zone within one half mile radius of the wellbore trajectory for CD5- 04. The mapped fault tips out 500 feet to the north-east of the lateral and was not encountered within the well. There were no lost circulated events encountered in the CD5-04. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent fault will not interfere with containment. Based on our knowledge of the principle stress direction in the Alpine A formation, along with the well path, all of the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. There are no faults that would intersect the fracture wings of the CD5-04 wellbore. Question 5 If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Questions 1, 2, & 3 Drilled Faults Well Depth Depth Vertical Loss Nearest Estimated Distance Name MD (ft) TVDSS (ft) Displacement (bbls/hr) Frac Port Propped XF from (ft) (ft MD) (ft) fault(ft) CD2-78 21,192 7348 <5 80 N/A N/A N/A CD2-33 no faults intersected CD5-05 no faults intersected CD5-04 no faults intersected • SECTION 11 — LOCATION OF, ORIENTATION OF AND G LOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRA SECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subs ace information currently available that there is one fault or fracture system that tran-ects the Alpine A formation and may enter the confining zone within one half mile ra•ius of the wellbore trajectory for CD5-04. The mapped fault tips out 500 feet to the -orth-east of the lateral and was not encountered within the well. CPAI has formed the opi'ion, based on seismic, well and other subsurface information currently available that the apparent fault will not interfere with containment. • • noL3t84ee - CD5-04 Fault Analysis AlasKa 12107115 ASRC-NPR1 ASRC- R4 • ;C-NPR2 ASRC-NPR3 04' • • 4O AAo92347 \ M L7 ASRC- 7 ACL3372'J8 Legend REFERENCES. - Fats It idir Radios Well Data-ConocoPhillips Alaska Well Database ATDB Wells in 11 mi.Radios ofOpen seeor Surface Facilities Nuiqsut Pad Published 06109.115 — wafts$p mi.Radius ofTrajeciory N — WWI Trajectory ® Open Section ,2 lode Opeis Sector Radius 0 0 2 0.4 0.6 0-8 Miles Q -:2 Mile Trajectory Reels, • S SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD5-04 was completed in 2015 as a horizontal producer in the Alpine A formation. The well was completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine A 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 16 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. 1000 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. MIRU Stinger Tree Saver Equipment and HES Frac Equipment. 6. PT Surface lines to 9,000 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Pump the 300 bbl breakdown stage (25# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 20 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. 9. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 10. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7000 psi. • 24 bbls Linear Pad • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 1 • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • • • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 2 • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 3 • 300 bbls HYBOR G Pad • 100 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 100 bbls HYBOR G w/4 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 80 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 4 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 5 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball6 • 300 bbls HYBOR G Pad • • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 7 • 300 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 103 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 8 • 340 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 110 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/ 4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/6 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 7 ppa 16/20 Carbolite • Flush with 15 bbls of linear fluid • Drop ball 9 • 400 bbls HYBOR G Pad • 90 bbls HYBOR G w/ 1 ppa 16/20 Carbolite • 100 bbls HYBOR G w/ 2 ppa 16/20 Carbolite • 110 bbls HYBOR G w/ 3 ppa 16/20 Carbolite • 120 bbls HYBOR G w/4 ppa 16/20 Carbolite • 129 bbls HYBOR G w/ 5 ppa 16/20 Carbolite • 140 bbls HYBOR G w/ 6 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 7 ppa 16/20 Carbolite • 145 bbls HYBOR G w/ 8 ppa 16/20 Carbolite • Flush with 114bbls of linear fluid protect • Total Sand: Approx: 925,000 lbs 16/20 Carbolite Note due to time constraints the hydraulic fracturing treatment might get split into 2 days of pumping. 11. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). b 13, 1 888 888888888888888888888888888888888888888888888888888888, 888888888 8 888 2 3 nnnnnnn 34 2 231333323n312323342313342332, 32323434232, 31212232,32223434123' 31 rvnrvrvnnnn 8 R988888 8 8888882 0 8 0 0 0 0 0 28888219 9 8 8 8 8 8 8 9 9 0 8 9 8 0 9999882 0 9 9 9 0 0 0 0 8 9 9 :2, 2 ,36? o 0066 000 6666666 0000006 0 00 666666 000 66 2 0 0000000 0006606 0000000 6606666 0666600 0000006 6666660 0000006 000 tia888 8888888888888888888888888888888888888888888888888888888888888888888 =a� 60 00006665 5066660000000060006660600000000000000606666660000000066 666 EESS 88 o88S .9.1 2889282238892, 8223889318, 223889 ,282238824 ,% _ 6 6 0 6 6 6 6 6 6 6 6 6 6 0 0 0 0 0 6 6 6 6 6 6 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 6 6 6 6 6 6 6 6 6 6 6 6 6 0 0 0 0 0 6 6 6 6 6 6 6 6 6 6 0 E ° " `. .n 9 0 97. 9 9 0 9 7 9 0 0 0 8 0 m 8 8 � m 8 e 8 o !.,2 S' 6 M 8< 8 1Airg g8$. o $ S oS$ , 08 .: 0 070 . $ o08 0 ! $ o z a - S 8 m Q 6 x � nn T-1 8888880,68888880- 82888808. 88888808, 808 ' ° "8, 808 " " ,, 808. 8. 88 8 8 88 0 m6 v 0 � 771 m c a D e a o g g 8 0 m m m o 2 m m m m m w 2. 8, 8 8 m w w m 2 m m 2 8 8 m w m 8 8 m g 8 m uuO ' a � m m f o $ $ ^ m 8, 4 $ $ 2 3 8, 2 3 `i8, 2, $ 8 < $ 3 0 3 3 2, 2, 2 $ 24 a � $ 3m 2 0 E= 2 3 m,� mmmm ., mmmm � mmmm ., mmmm mm < � a ., mmeeo .. mmaaa � mmeoa .. m "a� nn rvnnnnnnnnnnnrvnnnnnnrvnnnnnnnnnrvrvrvrvnnnrvnnnrvrvnnnnnnnnnnnnrvnnnnnnnnnnnry 8 � l 8888 88888 88888 888888 888 888 88 g m o m m ., n m o m m n m o ui m .4 n m o m m - n m o m m ., n m c m .: N m o m m n m o v m ry gggg 0 3 3 3 3 3 3 3 0 0 3 3 3 3 3 3 3 3 3 3333 ,33 3 3 ',1223 3 3 3 0 0 3 3 3 3 3 3 3 3 3 3 3 ,3 8 33 mrs, m72721-9 -9. :2 -2272791 2727227. 72 7272 -272 :272,r1] P7272 :272 :2 7202 :97- 7_978 72272 -22-Ig' 97 a3 of E3a c QQ dada ° dada aaaad 6666 ° m u2_ 12. 6666 ° 6 66 6 ° dada as 0 0 0 0 0 0 0 0 _ 0 0 0 0 0 0 0 ,_ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 _ 0 0 0 0 0 0 0 ,_ 0 0 0 0 0 0 0 _ 0 0 0 0 0 0 0 ,_ 0 0 0 `^ - aS U EW a 6 n n n n n n n n n n n n n n n ry ry ry ry n n n n n n n n n71 n n n n n n ry n 7 7, 7, n n n n n n n ry n n 71 n n ry 7, 7 n n n c W o 0 27, ti ,. ,. ,.,. n ry n n n n rvn m m m m m m m m o a o 0 0 0 0 0 ; J, h 2 m m 0 m m m m r n n n r r r r m m 2, m m m m m d, A d, Q z Q 9 J 11 C9914'29991@@ J.499191-LS 091 @7 d 112'9SPLL-9'£9611 J.1160SL91'4L4L91.@7 3.116'94091'416091 @a Jo 11Z7PE9 L'9'9£ES1 @7 J.7J 4'E£961'6'6Z914 P d iL 2'246E1 9 146£1@7 J.112( E w PueS V Pues V PueS V poesy Pues V Pues V 1,422 V 1,2122O ueS V d. llenialul Z lenialul E lenialul 4 lenialul S lenialul 9 12/001111 L lenialul 9 lenialul u O 0 U # 1110N 5,-, I 8888 m - aPg ` 88888888 ,, 8888888 ; 8 na- 1 ry ry o 0 \ 0 - „g 0000 000000000 . m - 7o m c0 88888 8888888888 .-', .6, ,,' mE. .. 3 r P, r n n ry ry ry ry ry ry ry ry ry „ 3 n ,_n 88' o 8 E o• 1 ao 0 0 0 0 0 0 0 0 0 da:41 E m 7-.... c. o 0 0 0 0 0 0 0 0 0 -,,- " gmc. . . . 0 = m 9k"'"'m ) b u u -'0 0 0 0 0 0 a 8N, 0 E 0 , in 0 8 > 8 ;,..-- 88888 88888 88 V - a E• 1 3 m ` 2 0 0 0 0 0 0 0 0 0 0 0 0 0 2 m 21;' W m zE E 8 S �� m a 8 0 0 0 0 0 0 0 0 - < c 7 3 F f a MS °: 8887-48 ;188. 2222 S qE8 ,9o0 080 T. - ' g ° 3 LL' • — ., ., ,Vnm m rv ,Vmm `„T; n s c nn E ' n . .. 8 g .. ., ., .. . ., o m = -o v c c c = a \` 6 m Ea ., .. ., ., 888888., 0 0 .. ., m c K m 0 2 .• _ a SLU g . i.H r m 8 N o _ " E 2222 2 ,2222222220 m ' ' 88888 88 O U 6 m ry m o m b r m 'a 8 o '' ''11 ,1Z:202:; 888888 a - 3 v a o EREE , ikkEEEEE 2,' 3 LL <d a d a N a a a a a a a a .4- a o o . i g ,:4 ,1717, '4'47, 7 .71` .:47, 7, 7 ",47 '41 LL - m c 'u . 0 0 m ut N 1, m m m d,j, d b d g d d b d b a a" 0 • h I Q i)ZCI. S'66LEL@7 J.UZ'90SZL'LZOSZL@7 ry u t E y a d PueStl PueSd O 8 S.61enialu1 OL l000Wl l C 0 U Hydraulic Fracturing Fluid Product ComponelTrfnformation Disclosure • Fracture Date 2015-12-07 State: Alaska County: Harrison Bay API Number- 5010320711 CONOCO PHILLIPS Operator Name: NORTH SLOPE EBUS Well Name and Number: CD5-04 Longitude: -151.22 Latitude: 70.31 Long/Lat Projection: Production Type: True Vertical Depth(TVD): 7,530 Total Water Volume(gal)': 389,905 Hydraulic Fracturing Fluid Composition: Chemical .Maximum Abstract Maximum Ingredient', Ingredient Ingredient Mass T'radeName Supplier; Purpose Ingredients Service Concentration in Additive Concentration in lbs Comments Number(CAS (%by mass)** HF Fluid W by #) mass)* Sea Water Operator Base Fluid NA NA 100.00, 77.82378s 3329778 Density=8.540 BA-20 BUFFERING AGENT,BE-6 MICROBIOCIDE,CL- 22 UC,CL-31 Additive,Biocide, CROSSLINKER, Breaker,Buffer, LOSURF-300D,MO-Halliburton Crosslinker,Gelling NA NA 0 NA 67,OPTIFLO-III Agent,Microbiocide, DELAYED Non-ionic Surfactant, RELEASE pH Control Additive BREAKER,SP BREAKER,WG-36 GELLING AGENT CarboLite 16/20 CarboCeramics Proppant NA NA 0 NA 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00069% 30 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00= 0.00138% 59 Acetic acid 64-19-7 30.00-: 0.00508% 218 Denise Tuck, Halliburton,3000 Acrylate polymer Confidential 1.00% 0.00093% 40 N.Sam Houston Pkwy E., Houston, TX 77032,281- . 871-6226 Ammonium acetate 631-61-8 100.00% 0.01695% 726 Ammonium persulfate 7727-54-0 100.00% 0.01823% 780 Bentonite,benzyl(hydrogenated tallow alkyl)dimethylammonium 121888-68-4 5.00% 0.01140% 488 stearate complex Borate salts Confidential 60.00% 0.05569% 2383 Ceramic materials and wares, 66402-68-4 100.00% 21.61150% 924673 chemicals Crystalline silica,quartz 14808-60-7 30.00% 0.00556% 238 Crystalline Silica,Quartz 14808-60-7 0.10% 0.00023% 10 Cured acrylic resin Confidential 30.00% 0.00547% 234 Ethanol 64-17-5 60..004 0.04123% 1765 Guar gum 9000-30-0 100.00€ 0.22806% 9758 Heavy aromatic petroleum naphtha 64742-94-5 30.00% 0.02062% 883 Naphthalene 91-20-3 5.00% 0.00344% 148 Oxyalkylated phenolic resin Confidential 30.00% 0.02799% 1178 Poly(oxy-1,2-ethanediyl),alpha-(4- nonylphenyl)-omega-hydroxy-, 127087-87-0 5.00% 0.00344% 148 branched Potassium formate 590-29-4 60.00% 0.05569 2383 Potassium hydroxide 1310-58-3 5.00% 0.00342. 147 Potassium metaborate 13709-94-9 60.00% 0.04100% 1755 Silica gel 112926-00-8 - 1.00% 0.00228% 98 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00093% 40 Sodiumchloride 7647-14-5 1,00% 0.00163% 70 Sodiumglycollate 2836-32-0 1.00% 0.00093% 40 Sodium hydroxide 1310-73-2 30.00% 0.02092% 896 Sodium persulfate •7775-27-1 100.00% 0.00097% 20 Sodium sulfate 7757-82-6 0.10% 0.00000% 1 Surfactant mixture Confidential 1.00% 0.00456% 196 Water 7732-18-5 100.00% 0.19368% 6150 *Total Water Volume sources may include fresh water,produced water,and/or recycled water _ **Information is based on the maximum potential for concentration and thus the total may be over 100% Note:For Field Development Products(products that begin with FDP),MSDS level only information has been provided. v32 All componentinformation listed was obtained from the supplier's Material Safety Data Sheets(MSDS).As such,the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's(OSHA)regulations govem the criteria for the disclosure of this information.Please note that Federal Law protects"proprietary","trade secret",and"confidential business information"and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.12000)and Appendix D. • • TD. -o Q o a) 2 � � Q, (6 Q u- O -A= • • c ro 0 0 -i ret ret rex el ` 0 r • , 0 J err to ko C r r 0) C 4 0l ` el 'J el el (1 .t fi0 40 at{ • 4-4 Z. 444 CIr � � 41J +ts ' e INIONIMI .t- ca "e '� s,. s. a. tV a) rot 1144 j 4.0 1144.,+P (444 14.4V kJ C,J CI (I) 01 :0 '0 '0 ra ' Cr),- t to sa u % *°.. cc c cc c — v' y 0« "#.• "C3 (ICS ft* a > 13 ec ro r9 fe re r41,e V) v+ G Ali ,a. a a a, 81 LL a a. a, a a, ,titu,, J A. 4 & • Asa' 0 0 0 0 0 ' r, c i J J >. ,> .t> > > > :« "Li." J "J "' rJ, r-J e'J eq rJ N l"$ I S I i f # i I 9 ' �}} 6 1 4,40 •J PUUSI CV C iftiv011 • 0 m 4,4 E m 4,41m `' cr ` t , w ' I I Z 0 0 0 0 0, ' ""'"*r I C , 0) C: .,.4 .®.i .i d 0 Ci cti i z. t C1 L� X3 co r4 ab Pq t0 00 ' ' V J 12a) _ 0 0 0 1.4. 44= EL W 3 U /) 0 000000 =to 41 44 44 at CO g , - . a al Ccc c c c L 0 0 06 0, - 0 0 Q. O. I2., . 401 A "sit!, 0 0 "q x ci 0 44 it Ift )t )tAt t7t. • ft E caa cts tIN sus, cis 411 LA Z 4. 4 /4 V9t091. -Y p 1, Z pees Iv si 40 E • 0 0 I t to toa} toa oo oe,1 vt f i cimiimmermossowir r 2 —'" el ci eti is el e‘4 44 el , i , i c el ti0 erki . 0) a 4. to k 0 V ■ M A. 0 0` (In fti rtt AI 01 IV al ft) ) t„i t„,i tJ tJ 6.3 (1) VJ 4 to C21 (1) CY) DZ Z 44, IL CI. t. ILL. _; c a ") UVA n C C C C C c C 0 • ft) efk Mt PC te at el CO03.; fl. Q. !Ss 0,.. Ct. '� . A� A. A O. A. 11111111 to • v e 1 , t „ u x * '4ti 10000000010004 1 .-4 r+.l to 1 t 03 t1N 44 C at ci at at at' O, to 0 A. 14 £Q G -S` 6t£L 41 C 6 lemalut' r Pc eS If • • J O N '1t N N N It O < O N- CO I- CO O CO C) O) CO Ur CO CO CO O N d- O O CO O > a) a) C6 N C Co a) U NNNNNNNNN CO CO CO CO 0 CO CO CO CO N- - c- r- �, a) a.) a) a) a) a) 0 C a) CC6 n J J J J J J J J J OOOOOOOOOC O Q O .0 .0 .0 .0 .0 .0 .0 .0 . �� O '^ CD Q zv U U U U U U U U U a) ■ Q O T N CO 0 0 N-. CO O limaCD 0 x- U CO 0) N- O0 a) o _0 0) 0) co al N 0 ) 0) N Ua) co CIO a C= C= C C C= C C C 0 CZ SINN= Q N a) a) Cl) O N N a) O '� "O -0 73 -0 73 -0 -0L U a) C6 m C6 C6 C6 C6 C6 C6 LL U) a)cc cc c cccc i i i -0 C6 C6 C6 C6 CO C6 C6 C6 J O 0. 0. 0. 0. 00O. 0. 0) Q Q Q Q Q Q Q Q C }) C6 co 0 0 0 0 0 0 0 0 cin Q Q Q Q Q Q Q Q Q4= (.D O L L 0 CD (LB Q. 00000 (DCo00 C 0 •LL L L L L L L L L L I J O U 0 0 0 0 0 0 0 0 0 0 a) >, >, >, >, >, >, >, >, >, c ' . \ D 222222222 • Lf) Lf) (0 7 * * * * * * * * * * N N 4 NNNNNNNNNN 1$ O Q N CO tt 1.0 CO N-- CO 0I) �- U) • . (1) C cn N N N � � O � ` ' C t C6 D 0 Q O Cll E ILL fn CO O C6 _C) O U C � 41) FCa E cn O a) �0 --_. a) m t3) v hhA cwt) LO .j 0A U) O � wIP -0 4 .L O 0 Q C, ,�. 0 nzt' up N 0) �""' L Cll Z c c_r) U u) L (+) 0 to 4- .O co � O .. c QO � U Ic . mo- 1...n t-r) tr) Ln V• I Q- '0 N. N -. N. U C3 0 to 0 c O L- c (1) CO O Q C6 0 a L � U -0 V N 0 Fes- In In 0 0 0 ■ . Ca O O L " `�, d- "Zr' d- d- Ou cy) CU O L 2 ..., 0 mf) CC1 - -,(13 Cla) .—C .E- 8 ri; O -- LCZ C 7:3 NI CD Q 0 -0 CD Q 2 " Cll S2 d C2 O .c •O Ca O CO L —, cr-i i •— Cll ' C Cll Cll c to -0 0 = '— "O -0 1E O Cn 0 O O vy r • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through PTS until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) • • - co -i -J o Y Y X Y Y Y co Y Y .�I Ea. d a. a. a. a a. C. Q 0 a 0 i o v U CO i•_ U = c Nco 0 o on ar = o 0 LC L s �j a o .� o 0 0 v, N O a`, o 0 v v M o 0 o l��6 1 0 0 a l 3 0 1 on W • c +., c O o ° -°o «' s'ao 3 - � � Q ,-I 4c o-, a V Z fa o `c o 3 0 3 s "_ °J a I u 51,- -a c n to -0 W o . c S- O- N a0 o a N p CI c C 13 Mo 0 ., N ca V.4Uco = om +-, HQ CO r-4 o +' ��-,, cu q n m Ca U v Q E a, Q a o to P 3 o v a .2 -a 5 y- - O = > Q c) U .\ N N z `2 46 = N U N to 3 c a, Q O �-+ h ++ ++ i O ei O. N > C `, '5o ice-, = O y 'C C 0 2 > > 0 bO •N Si O 0V, in 3 3 c w u o " 0 m ca a LA uC • @ C Cl) 4, o -0 ' c •5 E o o ° o to l"I o a -a° o ° -� o o 0 tai lo = N c� o c x �, > v �- co v CI) ,_,.9 o I o Cl)C v Q 'i • ,ten cos "-I 0- o Z 44= . C } v ON > O N i = .� N 0. �' 3 + i Q .a .O p Q cc 000 IA U 44 Z �-+ ,.� cu o a� c °' 3 N •3 O a a� a, i , n O !o v Q -a „ = c -a m O H N Cl., L .4-' L •a -a 0cu O • CO w r+ 3 :c a� v Q o ion 1 . cco ...... O '-' N O 3 O o •L i Q Q O O a a, v V- IA bpco _ U t, �. 0 .-i is 3 a -� o z rn > z 3 +, O z z a a a m U a. o. Q a. a O a c Z CO I a) \ o a a a c H tu e 13 0 mil % o y a s 1 a -a a c_ I V c Cu° aa' CU I a, c o ° acr) s .4-65- >4 D � .z �f a) 'af a) S� `ti N a N +� CA ce to i3 Q a. C c : O o E in -a 00 *a 3 : v v E 4-. v a- o -o . a a U) V a, I a c c 0 3 3 a � lb III E E •i � a- a,a a, — a .b v u , E a v ,„ ;.c -a. N Z o a v v 3 is a u � Q �>. v a � o a V o 1 3 , ... a c a, o v �► - +. a a v a a c a N t ` a t Q a ' v •u v c E ta v o W V1 ° .1::: CI '� ¢ a ` mcU It v m v v E Q °`° v a �'4 0 CD a o o a a a s o e o a o , a o o a ° • o vt. c o 3 y� O C. R O O L. a 4 Q I Q i Q1 U o U a • • N. 0 W lV a▪, m m CO j CO a O. Y Y Y 0 0 ri E a. a. a. V V - T L O co .... U C co O _ -, O I cu _ca o , to 4a 1 o a, +' as -0 C a •V UM mY a=A - _c - a _ -0 c CU • ON -C `+- CLD 7 N 3 _c L O 3 C O i=+ O V Z o • ,,, o �, m C > 0 30 � Cs o > tab :a >0000a) coaio o = Z3 v v CIQ L,nun cm a o o c a ' c O > ,n r-i a, r., C N o n L_ �a c > O . C v 0- N N dm• F- o .r-� .2 -CS a`°i *' 00c ca .7 a, 1.R •- (;) Ln o Q -0 a, =a L -I N `) a, a, -o v i° a; w 0 -3 — :7,.: v U N 'A c _c t Q. N c m c 0 co m ao v — c m- y) E +� y a, a a, c o O. O - ami `~ aA 0 Q c 3 CU c o u o c Q LA = +. _ N a, u n a, -t3 a' t c ai :c a, 2 a, c6 C a-' 'i. a• +� ra a, L Cl) C +' 0 csf ++ O. ate.' L to r-I 3 v Y :C CO c @ •._ NJ o .3 3 C c an m 'i N C• O 1.• U OU `� C `� _ CO N c m N = - 7 v a • > _ _ C v la N L- v) aA iO a C n -C3. = ia NN � RCOnV a+ Ce e) .Y N ' u CN 11) CD O- N Q u Q = Y • "O X Y a, a, @ = w- a, 'a O ' a) " , • b.0 . O a OA > > v c c t a, 0. LL 4, ++ D of I— .L Q G Y Y a. a. O .,..� U +.• 0- z49. C or) a, CL 3- a (,.) r O CD c s; 3 Kio v v 13 Ci o U No c .c t v •0 0 •CU U .� 01 C 0 O aa. N -o O a = V ° a aOJ te, °' °�' 3 o c o c p .0 C y a C u C UU J t co 0 0 0 ") 0 a 0 -0 `n vn 0 COMU U U U a a 3 L.(U °' V aE N ,. a a c .z i C v� a -� v� C i U U • 'a. LA 0 a, o a a o _° c .°, v 3 N Z a o� a y c c *a' = c -a c V V O ` a., 0 0 U C a a 0 0 Q a oma, a°, -12, .... a a U U o .°i = 0 QL. L a :a .° ' •� c ua. ° 4. ° c O Z Q o CO -, a `uo _ ti .c H ' E L) c O• . L 00toL a U 1U 3 0 O Q • • LO [ _ o a) a 0 0 0 0 0 0 0 0 0 0 E U U U U U U U U U U O as i•.. U c N — - ca 4.J GI a c o �C M , c Z.0 as 0. cas 01 O o ,, _ � V Z I _ _ coo o I @ 3 cu `o `�° its a 0 0_ a - Q i m ' • vi C •0 on � - - o o o fl O C 0 c U ~ 0 U' to v to .� 3 o c 2 v aA a L -a -p c u, ii i i ft vv .V N ,^ c a) °' a .� N o a Q I -S a) v o U U co p 4c co � typ " +C m } 4- co U E o. c [o LA c o +' aJ a) � C U o. co vii a"i ` 4 0 v v a L -c-t. L.. `t 0 3 c �= N I as u v u 4-• .� v) •c c N -� m O 3 °C) +, a; c a) s °; ;° a o Q �a V Z ai c o c- as .a C :�. .a o :5 4-•43) c �' o +� o a) o v a) -0 c Cl) ! O _ o a) m CU Q y + an 0 73 5 co o iii x a) U, } o a) s. 1.Un @ W a o `-' ate' c E o +, +. c -a +.. c4 •0 o CD ao U L 3 42 3 2 .E v _ a 1 -aa -aa U� co 2 ° 0 E. =a a IMMNI ,F, a s , v i ' v &.. a, o n QU ° O. U ._ , � c ° o 'a a o I Q zs 3 Q = ° 4.4 LI Qm ce =a. 0 a, �,� c a, v E ., o "'-' .Q 0 000 L) to a v 0 a E a, v ° E a 3 N V !".3 i all o 2 a a v v o .c .Q L Q o 0 0 C ti 43 11O � ? O •2E a a� � ' QN Z t aY io ooL, Q o't) ts. v (Isn 3 `v o tQ °a o ccm ,` IQ W • . Q a c n o O Z 4_. -. -. c,-. s,-. 4, ` � rv4. � a "4 � u'� a!� E oo;N ^ aD � O N � .. ° 0 ° , Ct. o E ° ...1-) Ipj - . GJ . o . . oao 13 a . i - o, o, c s a �, n a o CO 1 CO. c E t a z o U I-, .c U o u t 0 Q w i o a. o 0 0 0 E U U U U L 0 I (o i•_ U = N -- c 0 HO 0 � UO0 ims T -1 a o Gal M• 0 n3 - O N a) V Z in a > I >` O a) O = `L. f ++ m C Y :- to N 't -a 0 as' 1 V •\ X L .13 N gI a to Q N . 0 c QLA o (13 m 2 dA ri O a x C N m o a •s- o N 1 v 0 °' ,71-. a) Z °' 1 do in I .Zr C c a LL f > no E vn a a. U .a.� v O -a -?• = o CO I a a v$._ v., in c Ln °, ° ° ces 64 t-sc ta. O = y i V ` a Xf cn va a 4 ° CA c00L. 0 oo o N ttl v u L. a '� o v °a L► o n :0- • RI o o y Lf0 c v -a -a v aaup -0 a ° oN Z °' oc a Q Z ,. II Z 0 13 O O a Li) w ' iV _n a • 3 • Q av ` is � oo ap° ^ o ' av O Z Zv Z u. Q o nil •..'' c o .2 -6 v. iie co a E I ° l y c cc os v a c 01 Q.) L in ° i; v o o c oct c a o h CL v 40) '4. V) c `n Cc 4 E (3 o ° U v a'aCU ° o s o c'. v c� ._ `4 Q��. of ti. i. p Q 215072 26479 WELL LOG TRANSMITTAL#902819640 DATA LOGGED %1/4/So/2015 M,K.BENDER To: Alaska Oil and Gas Conservation Comm. November 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Nov 24 2oLS RE: Temperature-Pressure Survey: CD5-04 Run Date: 10/9/2015 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 CD5-04 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20711-00-00 Temperature-Pressure Survey 1 Color Log 50-103-20711-00-00 SCANNEE, 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: 907-273-3572 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ,/ �rc�`�,-a�zc� , 0 I Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _c21.5- 07c9,Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: El Other: ❑ Other: BY: .=aria Date: j DI/ g /5"' /s/ 41 • Al Project Proofing BY: lib Date: t d-/ /5 /s/ (Vjf Scanning Preparation V x 30 = 150+ la = TOTAL PAGES [ S c (Count does not include cover sheet) BY: aria Date: f V/5' /s/ Production Scanning Stage 1 "Page Count from Scanned File: I 5 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO 10 BY: Date: /01_1/ g//5— /s/ W(, Stage 9 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: NO5 TOTAL PAGES: 5 Digital version appended by: Meredith'..-'..)(\/SsMichal Date: ( 11 3t((c5 /st Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: a I d-- Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc • • o o 0 oN O . I V N N N U) N r o N 10 - - t -177 Ln co co co Ln Ln L N ❑� ❑N ❑ (> ❑ V ❑ c) E OOO0 • • OU ❑ 1❑ 1❑ I❑ I I C C CCf C C CO 66 - ❑ >- CO QQQ 2 Q 0 y o f o CO 0— o y o f 'O N v)c m 0_J aJ dJ dJ d - CL v)- C )= i .. m- u) .. ( - Ln C) U 1 O I O 1 O 1 O(n 0 5 -° Jt >° > r 5 -° > L > 73 >, - -Cl) (1) 0) Q E I,- I N N M M IIIIId' 'o p a) i) a)Q a) Q a)Q a)Q a>J a) 0 V O V O 'V'0 -1-O •d' O cr O n• 0 Z ?) EJ EJ EJ EJ E I E N O0 oo 90 90 oo 90 90 3 m I m I m I m I m M CD 7 Ln Ln Ln Ln Ln Ln Ln a O cci2 aci2 aci2 c2 cct co ❑� ❑ � ❑� ❑� ❑ � ❑� ❑ � F OC Ct Or I 1 O U O O U J O O Q LL I LL I LL I LL 1 it w it w 11 11 I I 1 1 I I 1 1 I I c m y w (n (n (n (n to L) (n g > > Q - Q Q - Q- Q - Q- Q - N�> N > N > N > to*.= 115"z-,- y dJ a. J 0_ -I 0_-I 0_ -I 0_-I 0_ -I Oz 1 1Q ED_ c wn mmI 1 1 1 1 ❑ :.°• m'6 m F) m N m m n a2ai2a2a2a2a2a2 0 oE cmm m a) ma> mm mCC mOCQ - - w - - - - - a) ❑LY OCL OCC ❑ c ❑ Z -1 LL LL 1 LL I W I LL 1 it I Wcc Z I co 7 N E C 0 C 0 C 0 C 0 C C C'> C ->. C '> E > E > E > E > 0 0 ()2 O _N O N O N O(_n O(_n C O- O•- O •- O•- O= O•- O'- Q Oco o � >1 � >I �>I �>1 )>I >I cco N31' - ) •- - N - - J N V N V N-7 a)'r7 -V C N a) O cal.)) a) N N a) N N N cc QIE WO Wo Wo Wo Wo WOO WLY Ww Ww Wor E3 0C ED or CO EC O co w d cLn Ln in in to to in Ln to in to in Ln a co > 0 0 0 0 0 0 0 0 0 0 0 0 0 Wm y " N N N N N N NN N N N N I m C) � r r r r r r r r Ce Q '., f6 -- CL n n n n n n n n n n n n U III 0 II U (°) o 0 0 Z .-` N CO CO op Q N NLON- h. N- LO CON O cam) COCO a0 00 O0 J °- m \ O. 0 � OI ! N C up 2 CC r Z co N CO n M .1- G O a) m Cr) N N ,-- 0 Net aE a) ra U -CN--11 U m w C) c ° J o Wiz° c Qct CCI ) m a Ln c m SII CO -O S m5 • N TV LY CO clt 0o. V([ J (A = WJ w :-.11.5-3 . _O ` CO J J ❑ Q OC U Ili IQ O n 0 IS U O W E J C2 2 7 CD m m m m m m m m m m m m m m o c E ❑ 0 0 0 0 0 0 0 0 0 0 0 0 NI- Z m m m m m m m m m m m m m 0 Z 0 .... ` ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N > 0 J a) r N- r` N- r` N- N- r N- r` N- r` N- t` w 0 0 0 0 0 0 0 0 0 o 0 o 0 LIi) Q Z s C N m E lu (OD (00( 00 (00 PD COO (OD (OD COO (OD (00 COD (00 N g O p « W G Z N N N N N N N N N N N N N L1' Q O £ £ LL m 00 V co O COW OLL awi c p ami U w LY Z W rn 2 O U U U U U U U U U U U O O Q to J d ❑ C'1 F- S. d -eaw °, c) 0 c) c) c) c) c) ❑ 0 0 0 0 0 0. QO I.-)... T 3 J G I� W W W W W 111 111 W W W W W W • • o o 0 o .F N 9 :_• = 7 N N.o z d� I d • d �I • d E a a a ctix 2 I M a1 N yC• 0 z z in, col 2 2 I I 0I> > > I >I V I I OO > O0 > > •o o Tr O V V 2 2 H H H 1- 2 2 H H H 1- N N N 17'4' 4 Z r omw1 - I 173 73 73 1 Lf)O LCLC — C) CI C)CC) CI n CL)CLO CILn CO CLO C Ln CO C O C a a a CO es O ON OE ON ON ON ON ON ON O O O O O OF z z z z F- Q U_1 0i5 Ut U � U � U � U � U � UT UT UUa UT UT UT v V C <4- 1 1 I I• II. I. I I I. I. I. I.T I. I. I. I. O O o 0 Q� QQ• Q -? Q � Q? Q }' Qw� QE 5 Q � Q � Q2 a5 Q2 OR 0 J d 61 d 0 d 8 d d ;N d N d N d fA d :n L. (n LL y• LL 5 LL :5 LL :) d N O N 0 0 0 I0 I0 IO N 02 O N O N O 2 O N O N O N O N O W O N O N O T U U U -c ui c ui ce - - ai hi ai aaa V . I .- I .- I . I .- I - I I - I I I - - - z LL 1 LL I LL 1 LL LL LL LL LL LL LLZ LL LL LL LLZ LL Li-(/) LL LL LL U) Z. ow ° Z.' 00 00 00 00 00 90 9O 90 90 90 90 90 g N g ° g • 7 '. Es C•> C'> C- C- C- C - C- C - C - C- C- C - C - C — C C) C C C O v- 20 20 2° 2° 2° 2° 2° 2° O° 2° 2° 2° 2° O° 2 ' O O O Q > > > > _ > > _ _ > > >") -.) N ' N ' 7) ° 1 ° I ° I ° I ° I ° I ° Im I ° Im I ° I ° I ° E ° a LN JQ ) a) aNaaV aVV aV V 7 C a , :MCC Wd [BCC wO wO L710 wO EJC. wO MO wO ILO MO MO 110O wU w w w O d '5 '',LC) LC) LC) LC) LC) LO LC) LI) LC) LO LO LO L() LO LO L() CO LO LC) C1- J U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 111 E J N N N N N N N N N N N N N N N N N N N IX 0 r; r; a r; n r; r; r; r; r; r; n n n W Z VJ Vo (7? I Z Q a) D Q CO O N a Vc cs)) U o J a N o . l . L� 0 F Lo- z > N m > CO p w CON V+ J p Q 0 I- U a) Q ° E a 0 z o ' d U E z Ca 03 CO CO @ CO CO CO CO 06 CO CO CO CO CO CO Ca CO CO N I6 03 N @ (0 f6 b' f6 (a N CO CO CO CO CO CO (a CO CO SII • 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CO CO CO CO CO COCD 03 CO CO CO COCOCO CO 03 co CO 03 .o) .o) .o) o) o) •o) 'o) •o) •o) •o) 'o) -o) 'o) 'o) -o) .o) .o) 'o) o) o 01b 0 0 0 0 O 0 0 O 0 0 0 0 0 0 0 0 0 0 N > i1 N N. N. N N N. N. N. N. r` r` r- N- N )` N- n N- N- H o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 La CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO O t N N N N N N N N N N N N N N N N N N N N o co6 Dco o c U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0V O m O OD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d a 2 w w w w w w w w w w w w w w w w w w w • • O - 9 0 (N c _J N CD W C7 1,11 r. oo Z - - v • E p 0 a N J J J • -J 5 o 0 m o m 0 0 0 0 o L.L. v .°' o • m Z C Z 0 Lo Ln in in o 0 0 a) 0. O_ 0. vl G 7 0 m a) o 0 0 0 0 ❑ z J J J J J J J J J ❑ i .(� W o E o. U 0 0 0 0 W WWWWWWO b F- co M M M M F Qj hi Qj Qj J 0 u 0 ❑ L.L. 0 ❑ LL O - Z O v cy co co00O co O Z E E E E Z 2 2 2 2 2 2 2 2 2 D x m m co CO CO CO D m CO CO CO _ L. Z Z Z Z Z Z > a) N LL N N N N N N N N N > F . . . . V V V V. V V V TY 7 NY O 9 9 O O O d' it it it LL O O O O 0 O O O O O 2 Lo ui a LO LO in W N_ _ _ N to U) in in a) MD U) in W ❑ ❑ • ❑ ❑ ❑ ❑ J ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ J "J U U >. U U U U J u) 0) 0UUUUUUUUJ43 V O CD CD Z 0 0aj ai m m m m m aj,- iii 6 6 6 6 6 i0 6ai � Z Il Il 0 jl Il Il Il C) ❑ O� ❑ m ❑ 0 LL E. I1 lL LL Il LL Il LL Il LL O co 0 o y 0 0 0 0 0 w 0 0 o f6 o 0 o 0 o� 0 0 0 0 0 0 0 0 o Uo� N @ E o a o 0 0 0 Wp o co o o a o 0 0 0 00 00 00 00 00 00 00 0 0 n Wp co N N 0 0 0 N CDi �W 0.0 a0i j O N 0-0 N w a0i aai aai CDi CDi N aai N CD .•W LI Q N w w U w w w w N 2 w U w U w S w 2 w Q' w w w w W W W W W N 2 0 N CL J U / O O O O O O O O O O O 000000000 J N N N N N N N N N N N N N N N N N N N N W CL ,- M M CO M M M M M COC\ M M M A/ ° F- n n -NZ' F- n co co co co co co co co co co co 330o co �+ 0 9. 0, 4 W z J 0v o Z 8 - a, F- r.- co $ r`co co n rco — ICC ` 0 0 co o o w a LO c co coto in C r. O O co 00 — O N a E VCA 0 o v "' Q O c4 in 4h a V r ~ L 5 Z o G > N M N Ca re CO m w J- a) t/1 5 o Q ° < c E Q z o d UI E cn m m z co CO m CO CO m m N m CO CO m m CO CO CO CO CO CO m CO m N d f0 f0 f0 co o l0 D co f0 (0 (0 l0 m m m m (0 CO m CO (0 'D 3 N III❑ ❑ ❑ ❑ ❑ ❑ N 0 0 0 0❑ 0 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ N - 1 (0 m m (0 (0 (0 2 m m m m m CO CO CO CO m CO CO CO m 2 r r .. .. .. .. .. .. .. rn rn _rn cm on _rn rn o> on m _rn _rn o> 'En 'En 'En _rn 'Eh _rn 'Eh if) rn ❑ ❑ ❑ ❑ ❑ ❑ J ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ J o N ❑ P- > o 0 0 0 o O O W CO Co Co Co co co Co co co co co Co co Co CD O O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1n CO CO CO CO CO CO CO CO CO CO CO O CO (0 CO CO CO CO CO CO CO (0 N N N N N N N N N N N N N N N N N N N N N N N _ C D c p co U U U U U U U U 0 0 0 0 0 U U U U U U U U U U 0 2ww ❑ Www wwww wwwww wWw ww0. LU ° • al o -- III 9 0 �' O) (a N 9 C \gQ/� N _ s 0 Ili O)a) .0 p Z J >- >- 0) N C c a) o o W o aa) 414 o D as rn m r >. c E O m '�. > 6 rn p= c (n CO 0 p rn c 0 0 ° D D D a- o 4 U d Es E- Q N N iVE E 2 c c c 0 0 J J -c o) .m .o) 9— p_J J J cc o www .`°J C /� Z CO a3 CO C C I(�m' m >fp 00 0p a) N > a3 CO CO? £ as N O } III C N - C o�> > 0 ce e (:),,, Q I..LfnU)JU)W a O N ` 2 a ' u, Q... .0 — m W -I o= U N yNZ aio M u Ce O �a. I'00 a1 C.) i� E a co W Z J d m (� as 0) a V v o '- E _9 E Z N 2 (1) 114C tli 00 o co o a rn ° E C 0 CL ir, co v 0 G p I� co O a) O N a E M v U No C 0 O a) o (3 E u J o c E to a o O en tTi v a F ° N2 E _ o z .1; 0 Z 2 C L., E /� N C - E , W te co N C O E ' P 3 /��/� J a) m c a) ''l V J as N I,, c C Ili O c \ O 7) 3 .0 a rc C agbh a C O O CO 0 Z p N p 13 £ CJ ro 0 2 0 co Z II N (1) N 0 cN V J O (h N '..� O c ^ N '444��`rTTV..\//111 co O E ! 5, GO F- 00 C NII Ce U) m W E a 0 aai N N d '.I W p N L. a yt t o = - > E Z m N W as C W o coa° d Z Q o o Z o I c 0 ++ U O 2 a) .0 _ III J N a) .Q' N A U (� n 3 o a a a) v E ° O d 0 o d o ° aT:°, ) O o aoi °' E c d a 3 z 0 a 0 0 0 c 0 0 I' 215072 REC._ _ 26 08 1 on c Phillips AUG 0 3 201t) DATA LOGGED AOGCCi i`Y M. BENDER TRANSMITTAL o r- 4 .trocZ AA.G 4.zy•rcs- FRDM: Sandra D. Lemke,AT03-0340 TO: Makana Bender ConocoPhilliips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave.,Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska RE: CD5-04 DATE: 07/31/2015 Transmitted: li1 Colville River Unit, Alaska 1 CD5-04 1 N l 1 CD and hardcopy report 11 re r Halliburton-Surface data logging and End of Well report- mud logging data for CD5-04; 06/29/2015; general I information, daily summary, days vs. depth,after action review, mud record,bit record, morning reports,survey reports: ii color log presentations, one set each for wellbore 1 each -color log prints: 0 Formation Evaluation 2"MD A Gas ratio 2"MD 11 Drilling Engineering 2"MD 1 II Ir n 11 111 Please promptly sign,scan and return electronically to Sandra.D,Lemkela GQP.com I ii ii CC: CD5-04 transmittal folder, production well files, eSearch Rec y•'. ✓Q4g -0--, ' / ekeett Date: GIS-Technical Data Management j ConocoPhillips 'Anchorage,Alaska I Ph: 907.265.6947 RECEIVED • STATE OF ALASKA 0 JUI. 23 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND1 G L 1 a.Well Status: 'Oil ❑✓ Gas❑ SPLUG LJ Other ❑ Abandoned ❑ Suspended❑ 1 b.Well Class: 20AAC 25.105 2OAAc 25.110 Development 7 • Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: Service LI Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Sur 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. , Aband.: • 6/2+ 2015 215-072 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,Alaska 99501 5/21/2015 50-103-20711-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 310'FNL, 2497'FEL, Sec. 18,T11N, R4E, UM '6/17/2015 CRU CD5-04 • Top of Productive Interval: 9. KB(ft above MSL): 71' 17. Field/Pool(s): 2175'FNL, 1682'FEL,Sec. 8,T11N, R4E, UM GL(ft above MSL): 34' Colville River Unit/Alpine Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. : LWd U%i ,,,,e 1334' FNL, 145'FWL, Sec. 5,T11N, R4E, UM 18863'MD/7420'TVD 932671,932128 4� 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: l9. - e- : Li Surface: x- 349482 y- 5965899 Zone- 4 '18878'MD/7420'TVD , ASRC NPR4,ASRC NPR2 TPI: x- 355631 y- 5969194 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 352278 y- 5975381 Zone- 4 nipple @ 507'MD/507'TVD 1384'MD/1370'TVD 5. Directional or Inclination Survey: • Yes ❑✓ (attached) No C-] 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) , not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res r 6"' 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 20" 78.6# B 37' 115' 37' 115' 42" 5 cu yds 10.75" 45.5# L-80 36' 2327' 36' 2231' 13.5" 4.0.•1352 sx DeepCRETE,291 sx CI G 7.625" 29.7# L-80 35' 11837' 35' 7474' 9.875 x 11" 442 sx CI G,442 sx CI G 4.5" 12.6# L-80 11661' 18863' 7447' 7420' 6.75" not cemented 24. Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 11686' 11364'MD/7385'TVD sliding sleeve @ 12348'MD/7482'TVD and frac sleeves from 12503'MD to 18156'MD/7436'TVD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. ; j 'n'( k Was hydraulic fracturing used during completion? Yes❑ No 1111 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED t Arvdr..)1 none 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ,--► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate - Form 10-497 R vis d 5/2015 • CONTIN ED ON PAGE 2 RBMS D � P 0 1 2015 Submit ORIGINIAL only 28.CORE DATA Conventional Core Yes ❑ No ❑ Sidewall Cores: I ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. none 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1384' 1370' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. C-30 2426' 2315' K-3 4760' 3783' K-2 5173' 4018' Albian97 5890' 4429' Albian96 7893' 5572' none HRZ 10309' 6952' Kalubik 10709' 7161' Alpine A 11817' 7471' Formation at total depth: Alpine A 31. List of Attachments: Summary of Daily Operations,directional survey,schematics,cement detail reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Will Earhart @ 265-1077 Email: William.C.Earhartacop.com Printed Name: G .Alvord Title: Alaska Drilling Manager Signature: 0 {6 r 0- 1 V°4` Phone: 265-6120 Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only Y WNS PROD CD5-04 ConocoPhillips I Well Attributes • Max Angle&MD TD A1L15ka Ind Wellbore APIIUWI Held Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) arnocePFalhps 501032071100 ALPINE PROD 94.20 18,878.00 18,878.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date CD5-04 7116/20154:41:11 PM SSSV:NIPPLE Last WO: 36.94 6/24/2015 Vertical schematic(actual).:,. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ -HANGER o.o er Last Tag: Rev Reason:NEW WELL smsmith 7/15/2015 ill t[ Casing Strings . CasingDescription OD ID To (ftKB) Set Depth ftKB Set p (TVD)... Wt/Len I .Grade TopThread (in) (in) P( 1 P (ftKB) Depth ( CONDUCTOR 20 35.2 115.2 115.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread nr•+• +++amw.�r SURFACE 10 3/4 9.950 36.1 2,327.0 2,231A 45.50 L-80 Hyd 563 auaar�u+,mauomnnn+u JL Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMDIATE 75/8 6.875 34.9 11,836.7 7,473.7 29.70 L80 BTCM �.hN Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR;35.2-115.2 r LINER 4 1/2 3.958 11,660.8 18,863.0 7,421.0 12.60 L-80 Hyd 563 Liner Details Nominal ID ME Top(ftKB) Top(TVD)(ftKB) Top net(°) Item Des Com (in) MI 11,660.8 7,444.8 79.98 PACKER BAKER HRD-E ZXP LINER TOP PACKER 5.750 NIPPLE;5072 - -_ It 11,680.5 7,448.2 80.09 NIPPLE BAKER RS PACKOFF NIPPLE 4.950 11,683.3 7,448.7 80.11 HANGER BAKER FLEX-LOCK LINER HANGER 4.790 11,693.1 7,450.3 80.17 XO Reducing Cross over,5-1/2"H563 x 4-1/2"H563 L-80 3.860 12,347.6 7,481.6 92.88 SLEEVE CAMCO SLIDING SLEEVE X PROFILE,OPEN 2.813 DOWN 12,502.7 7,474.2 91.80 FRAC PORT FRAC SLEEVE#9,BALL 2.125",2.10"ID 3.900 SURFACE;36.1-2,327.0 13,199.5 7,467.8 90.34 FRAC PORT FRAC SLEEVE#8,BALL 2.063",2.05"ID 3.900 ill 13,941.8- 7,467.6 89.11 FRAC PORT FRAC SLEEVE#7,BALL 2.0",1.980"ID 3.900 GAS LIFT;4112.5 a14,629.9 7,477.7 90.41 FRAC PORT FRAC SLEEVE#6,BALL1.938",1.920"ID 3.900 ill 15,338.8 7,463.8 90.05 FRAC PORT FRAC SLEEVE#5,BALL 1.875",1.872"ID 3.900 c ') 16,043.4 7,462.3 90.50 FRAC PORT FRAC SLEEVE#4,BALL 1.813",1.805"ID 3.900 16,747.4 7,449.4 91.42 FRAC PORT FRAC SLEEVE#3,BALL 1.75",1.75"ID 3.900 GAS LIFT;8,008.1 n. 17,453.8 7,440.4 90.22 FRAC PORT FRAC SLEEVE#2,BALL 1.688",1.635"ID- 3.900 BAKERLOK'D Iff IF 18,157.0 7,435.8 90.61 FRAC PORT FRAC SLEEVE#1,BALL 1.625",1.573"ID- 3.900 GAS LIFT;11,188.3 "' BAKERLOK'D ME 111 Tubing Strings Ill Tubing Description (String Ma...I ID(in) I Top(ftKB) (Set Depth(ft..f Set Depth(TVD)(...I Wt(Ib/ft) I Grade I Top Connection GAS LIFT;11,307.5 TUBING 31/2 2.992 0.0 11,686.11 7,449.1 9.30 L-80 EUE 111 Completion Details I. Nominal ID PACKER;11,363.6 -"- Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (In) 0.0 HANGER FMC ALP HANGER 3.958 all 117.5 117.5 0.16 XO Reducing XO,4-1/2"HYD563 Box s 3-1/2"EUE 8rd Pin Drifted 2.992 NIPPLE;11,390.3 - 2.91" 17-1- ` 507.2 507.2 0.88 NIPPLE CAMCO LANDING DS NIPPLE 2.812 -, 11,363.6 7,385.8 76.12.PACKER BAKER PREMIER PACKER 2.880 LOCATOR;11,658.7 *A1 1 11,390.3 7,392.2 76.56 NIPPLE CAMCO DS LANDING NIPPLE WI RHC PLUG 2.875 WLEG;11659.7 i ii 11,658.7 7,444.4 79.97 LOCATOR LOCATING SUB 3.000 11,659.7 7,444.6 79.98 WLEG BAKER WLEG 2.970 Perforations&Slots 1 I Shot Dens _ Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com a i 12,502.7 12,506.2 7,474.2 7,474.1 6/20/2015 PERFP Frac Port 13,199.5 13,203.0 7,467.8 7,467.8 6/20/2015 PERFP Frac Port INTERMDIATE;34.9-11,836.7 I. 13,941.8 13,945.3 7,467.6 7,467.6 6/20/2015 PERFP Frac Port 14,629.9 14,633.4 7,477.7 7,477.7 6/20/2015 PERFP Frac Port 15,338.8 15,342.2 7,463.8 7,463.8 6/20/2015 PERFP Frac Port 16,043.4 16,046.9 7,462.3 7,462.3 6/20/2015 PERFP Frac Port 16,747.4 16,750.9 7,449.4 7,449.3 6/20/2015 PERFP Frac Port PERFP;12,502.7-12,506.1 I__ 17,453.8 17,456.5 7,440.4 7,440.4 6/20/2015 PERFP Frac Port 18,157.0 18,157.0 7,435.8 7,435.8 6/20/2015 PERFP Frac Port PERFP;13,199.5-13,203.0 'e Mandrel Inserts St all on Top(TVD) Valve Latch Port Size TRO Run PERFP;13,941.8-13,945.3 I-I N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) _ (psi) Run Date Com 1 4,112.5 3,412.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/22/2015 2 8,008.1 5,639.8 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/22/2015 - 3 11,188.3 7,343.4 CAMCO KBMG 1 GAS LIFT SOV BEK-5 0.000 0.0 6/22/2015 DCK-2 PERFP;14629.9-146331 _I 4 11,307.5 7,372.3 CAMCO SGM 1 GAS LIFT GAUG 0.000 0.0 6/22/2015 W/I- E WIRE PERFP;15,338.8-15,342.2 a.I Notes:General&Safety End Date Annotation NOTE PERFP;16,0431-16,046.9 e PERFP;16,7471-16,750.9I- PERFP;17,453.8-17,456.5 I PERFP;18,157.0 I LINER;11,660.7-18363.0 ConocoPhiIlips Time Log & Summary Wei!view Web Reporting Report Well Name: CD5-04 Rig Name: DOYON 19 Job Type: DRILLING ORIGINAL Rig Accept: 5/19/2015 12:00:00 AM Rig Release: 6/24/2015 4:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 35/18/2015 24 hr Summary Prep rig for move. Disconnect service lines. Move pipe shed&pits/motors complex way from sub. Skid floor &raise wind walls. Move rig f/CD5-314 to CD5-04. Spot pits/motors, ball mill&pipe shed.Work on rig acceptance check list. Rig accepted @ 24:00 hrs. 00:00 04:30 4.50 MIRU MOVE MOB P Prep rig for move.B/D H2O&steam. Disconnect service lines between complexes. Move pipe shed& pits/motors complex away from sub. 04:30 07:00 2.50 MIRU MOVE MOB P Skid rig floor into moving postion. Raise wind walls&stompers. 07:00 09:15 2.25 MIRU MOVE MOB P Jack up rig&move rig off well. 09:15 12:00 2.75 MIRU MOVE MOB P Install BOPE landing in mezzanine. Install wind walls. 12:00 18:00 6.00 MIRU MOVE MOB P Spot rig over well CD5-04. Set support feet. Skid rig floor. Spot pits/motors complex, pipe shed& ball mill. 18:00 00:00 6.00 MIRU MOVE MOB P Cont. to spot ball mill&pipe shed. Hook up electrical lines&service lines to sub.Welder work on drain lines. Clean wind walls&rig floor. Work on rig acceptance check list. Test rig gas alarms. Dress shakers &install caps on both mud pumps. Rig accepted @ 24:00 hrs. 05/19/2015 Cont.to dress shakers&prep mud pumps. Install drain lines. Install diverter Koomy lines. Load shed w/DP. Clean&scrub rig. N/U diverter line extension. 00:00 12:00 12.00 MIRU MOVE RURD P Cont. to dress shakers&prep mud pumps to drill. Install drain lines. Scrub&clean rig. Load pipe shed w/5"DP&strap.Welder building diverter extension sections. 12:00 00:00 12.00 MIRU MOVE RURD P Scrub&clean rig. Load pipe shed w/5"DP&HWDP&strap.Welder weld flanges on diverter line extension. Paint in pump room. Install diverter line extensions. 05/20/2015 Cont.to clean rig&N/U diverter line. N/U surface riser&energize Koomy. Function test diverter system. P/U &rack back 20 stds DP, HWDP,jars&NMFC. Dry run hanger. Fill conductor&check for leaks. Pre-spud meeting. M/U BHA#1. 00:00 04:30 4.50 MIRU MOVE RURD P Scrub&clean rig. Install diverter line extensions(diverter line length 259.77'). P/U 5"handle equipment. Barricade off exclusion zone @ end of diverter line. Page 1 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code ` Subcode T Comment 04:30 10:30 6.00 MIRU MOVE NUND P N/U surface riser&flow line. Energize Koomy. 10:30 11:45 1.25 MIRU MOVE BOPE P Perform diverter function test. (39 sec to close annular&3 sec knife valve open, 3000 psi system psi& 1500 psi after closure, 35 sec to first 200 psi& 174 sec to full system psi, 4 bottles @ 1856 psi) 11:45 17:00 5.25 MIRU MOVE PULD P Install mouse hol;e in rotary table. P/U&rack back in derrick 20 stds 5"DP, 6 stands HWDP w/jars, & NMFC. SIMOPS-P/U tools&equip to rig floor. 17:00 18:15 1.25 MIRU MOVE RURD P Set mouse hole to drilling position. Pull bushings. P/U tools&equip to rig floor. 18:15 18:45 0.50 MIRU MOVE RURD P Dry run w/10-3/4"casing hanger. 18:45 19:45 1.00 MIRU MOVE BHAH T PJSM on BHA.Attempt to M/U BHA ¬iced broken keeper in 5" elevators. 19:45 21:45 2.00 MIRU MOVE SEQP P P/U 1 stand DP w/tugger&set in rotary table. Fill stack w/H2O& check for leaks(no leaks). Flush stand pipe&mud pumps w/H2O. Mud pump#2 not working. SIMOPS -C/O 5"elevators. 21:45 22:00 0.25 MIRU MOVE SFTY P PJSM on P/U BHA&pre-spud check list. 22:00 23:00 1.00 MIRU MOVE RURD P Install 2"manifold on conductor speed clamp for black water. Finalize pre-spud check list. SIMOPS- Trouble shoot mud pump#2(loose wire in drilling console) 23:00 23:15 0.25 MIRU MOVE SFTY P Pre-spud meeting with all personnel 23:15 00:00 0.75 0 83 MIRU MOVE BHAH P M/U BHA as per SLB to 83'(mud motor,stabilizer, arc, &MWD) 05/21/2015 M/U 13-1/2" BHA#1. Test mud pumps to 3500 psi(good). Spud in @ 02:15 hrs&drill ahead to 1,463'. Packed off after slide.Work pipe free&attempt to circ. Mud pumps appear to be packed off with gravel. Trouble shoot mud pumps. 00:00 01:45 1.75 83 87 MIRU MOVE BHAH P Cont. M/U BHA as per SLB to 87' (mud motor, stabilizer, arc, &MWD) Scribe&orient motor/MWD. M/U top drive to NMFC 01:45 02:00 0.25 87 87 MIRU MOVE SEQP P Break circulation&test mud pumps to 3500 psi(good) 02:00 02:15 0.25 87 115 MIRU MOVE WASH P Wash in hole w/450 gpm &no rotation f/87'to 115'. Swap over f/fresh H2O to DrillPlex spud mud. 02:15 12:00 9.75 115 654 SURFA( DRILL DDRL P Spud in @ 02:15 hrs. Drill ahead f/115'to 655'MD/654'TVD.ADT= 4.03 hrs,TST= 1.06 hrs. ECD 10.29 ppg, 525 gpm, 830 psi, 50 rpm, 2 k drlg trq, 15-20 WOB 95 k ROT wt Page 2 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 22:30 10.50 654 1,463 SURFA( DRILL DDRL P Drill ahead f/655'to 1,463' MD/ 1,446'TVD.ADT=8.44 hrs,TST= 4.38 hrs. ECD 9.8 ppg, 525 gpm, 950 psi, 50 rpm, 3 drill trq,2.5 off btm trq,20-25 WOB, PU wt 120 k, SO wt 110 k, ROT wt110 k 22:30 23:00 0.50 1,463 1,419 SURFA( DRILL DDRL T Hole packed off while attempting to rotate after a 30'slide.Work pipe free. Pull up out of slide f/1,463'to 1,419'.Attempt to circulate&mud pumps will not pick any fluid. 23:00 00:00 1.00 1,419 1,419 SURFA( DRILL RGRP T Attempt to get mud pumps to pick up fluid. Mud pumps appear to be packed off with pea gravel.After inspection of the shakers, on shaker #2 there was a 3/4"gap in between the screen&shaker deck.There is a significant amount of pea gravel underneath shakers.There is a slight amount of pea gravel strung through out through pits 2,3,4,5&6 35/22/2015 Trouble shoot mud pumps(look for gravel, C/O valve seats&caps)Clean gravel from under shakers&pits. Establish circ w/mud pump#1 &continue work on pump#2&clean pits. @)6:00 hrs resume drilling ahead f/1,463'to TD of 2,342'. 00:00 02:30 2.50 1,419 1,419 SURFA( DRILL RGRP T Trouble shoot mud pumps. Remove gravel&change out bad valves& seats from mud pumps. Clean gravel from underneath shakers&re-dress shakers. Clean pit#5. 02:30 06:00 3.50 1,419 1,463 SURFA( DRILL CIRC T Break circ with mud pump#1 w/400 gpm ©520 psi. Orient high side. Reduce flow rate to 250 gpm&work pipe without rotation&finish working on mud pump#2&finish cleaning pits. Pits&pumps ready to drill @ 06:00 hrs.Wash in hole to 1,463'. 06:00 12:00 6.00 1,463 1,835 SURFA( DRILL DDRL P Drill ahead f/1,463'to 1,835' MD/ 1,795'TVD.ADT=4.81 hrs, TST= 2.53 hrs. ECD 9.88 ppg, 800 gpm, 1820 psi, 50 rpm,4 drill trq, 2.6 off btm trq, 20-25 WOB, PU wt 112 k, SO wt 105 k, ROT wt107 k 12:00 00:00 12.00 1,835 2,342 SURFA( DRILL DDRL P Drill ahead f/1,835'to TD of 2,342' MD/2,243'TVD.ADT=8.88 hrs, TST=4.71 hrs. ECD 10.9 ppg, 750 gpm, 1840 psi, 50 rpm,4.5 drill trq, 2 off btm trq, 15-30 WOB, PU wt 125 k, SO wt 115 k, ROT wt120 k 35/23/2015 Circ hole clean&wt up to 10.0 ppg. F/C. BROOH at full drill parameters f/2,342'to 545'. Drop Gyro. Pump out of hole f/545'to 179'. Rack back NMFC. L/D BHA. Clear&clean floor. R/U casing running tools&equip. Run casing to 125' Page 3 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 2,342 2,342 SURFA( CASING CIRC P Circ and condition mud w/750 gpm @ 1850 psi.w/60 rpm @ 2-3 k trq. Weight up from 9.8 ppg to 10.0 ppg. Pumped 2 nut plug sweeps to gauge hole. First sweep came back 600 stks early. Second sweep came back 400 stks early. 03:30 04:00 0.50 2,342 2,342 SURFA( CASING OWFF P F/C(Static) 04:00 13:15 9.25 2,342 453 SURFA( CASING BKRM P BROOH f/2,342'to 453" Pumped w/750 gpm to base of permafrost @ 1,592. Reduce flow rate to 500 gpm to 453'. Rotated 50-60 rpm @ 2-6 k trq. Hole un-loaded in the permafrost and saw areas of high torque when back reaming through slides. 13:15 14:30 1.25 545 179 SURFA( CASING PMPO P RIH f/453'to 545'&drop Gyro Multishot Tool. Pump put of hole w/100 gpm&no rotation f/545'to 179' 14:30 17:00 2.50 179 0 SURFA( CASING BHAH P Retrieve Gyro tool on top of MWD. Rack back NMFC. L/D BHA#1 as per SLB. (Rig on highline power at 1600 Hrs) 17:00 18:15 1.25 0 0 SURFA( CASING BHAH P Clean&clear floor of BHA tools& equipment. 18:15 22:00 3.75 0 0 SURFA( CASING RURD P R/U to run casing. C/O bails on top drive. C/O bushings in rotary table. M/U Volant CRT. Mount camera in derrick. 22:00 00:00 2.00 0 125 SURFA( CASING PUTB P PJSM. RIH 10-3/4",45.5#, L-80, Casing to 125' (Silver Bullet Shoe, 2 jts, Halliburton F/C, & 1 jt 10-3/4" BTC csg) 35/24/2015 Cont.to run 10-3/4"to 2,329'. Not able to land on hanger. POOH 6 jts to 2,046'. Swap out jts. RIH w/casing f/2,046'&land on hanger @ 2,327'. Circ&cond mud for cement job. Pump cement as per Dowell. 00:00 10:30 10.50 125 2,300 SURFA( CASING PUTB P Cont.to rum 10-3/4"casing f/125'to 2,300'. (Ran 13 jts BTC&41 Hyd 563 total, 1 Centrek centralizer per jt) Work through tight hole f/1,379'to 1,568'. Pump @ 2-4 bpm @ 110- 130 psi. PU wt 110 k, hole in good condition on up stroke. 10:30 14:00 3.50 2,300 2,329 SURFA( CASING HOSO T M/U hanger&landing jt.Attempt to land on hanger&started taking wt @ 2,329'.Attempt to work past 2,329' with no success. Decision made to pull out of hole&reconfigure casing tally. 14:00 14:15 0.25 2,329 2,329 SURFA( CASING RURD T R/U power tongs&350 ton slips. 14:15 14:30 0.25 2,329 2,300 SURFA( CASING RURD T B/O of landing jt w/Volant tool&UD same. 14:30 17:15 2.75 2,300 2,046 SURFA( CASING PULL T POOH&L/D 6 jts of casing f/2,300' to 17:15 18:15 1.00 2,046 2,290 SURFA( CASING PUTB T RIH w/6 new jts of casing f/2,046'to 2,290' Page 4 of 28 Time Logs • • Date From To Dur S. DepthE. Depth Phase Code Subcode T Comment 18:15 19:00 0.75 2,290 2,327 SURFA( CASING HOSO P M/U hanger&landing jt. Break circ w/2.5 bpm @ 150 psi. RIH&land on hanger @ 2,327' 19:00 19:30 0.50 2,327 2,327 SURFA( CEMEN-CIRC P Stage flow rate to 8 bpm @ 340 psi. &circ B/U.Reciprocate pipe 20' 19:30 20:00 0.50 2,327 2,327 SURFA( CEMEN-RURD P R/U cement lines to Volant cement circ swivel. R/D 4'bail extensions& elevators. 20:00 21:45 1.75 2,327 2,327 SURFA( CEMEN-CIRC P Circ&cond mud for cement job w/8 bpm @ 340 psi. Reciprocate pipe 20' P/U wt 145, SO wt 132 21:45 00:00 2.25 2,327 2,327 SURFA( CEMEN-CMNT P PJSM on cementing. Rig pump 100.7 bbls nut plug spacer @ 8 bpm/530 psi. Dowell pump 1 bbl H2O &pressure test to 3000 psi(good). Dowell pump 72.7 bbls 10.5 ppg Mud Push©5 bpm/150 psi. Drop bottom plug. Dowell pumped 300 bbls 11.0 ppg DeepCRETE 1.91 ft3/sk yield lead cement @ 4-6 bpm/250-350 psi as of 24:00 hrs. X5/25/2015 Cont. to pump cement as per Dowell. Displace w/rig&bump plug. CIP @ 1:22 hrs. De-energize knife valve on diverter line. Flush stack&function annular. Shut in well @ 2:00 hrs&monitor psi while W.O.C. Clean& clear floor of casing/cementing tools&equipment. P/U 5" DP&rack back. N/D diverter system. 00:00 01:30 1.50 2,327 2,327 SURFA( CEMEN CMNT P Dowell cont.to pump 159.8 bbls (459.8 bbls total) 11.0 ppg DeepCRETE 1.91 ft3/sk yield lead cement @ 4-6 bpm/250-400 psi. Dowell pump 60.6 bbls 15.8 ppg 1.17 ft3/sx Tail Design cement @ 4 bpm/100 psi. Drop top plug. Dowell pump 20 bbls H2O @ 5.5 bpm/90 psi. Rig displace w/194.9 bbls/1956 stks @ 95%of 10.0 ppg DrillPlex spud mud. Initial 10 bpm @ 840 psi & Final 3 bpm©400 psi. Increase to 500 psi over©900 psi&hold for 5 min. Check floats(good)&F/C (static). Reciprocated pipe 20'stroke with full returns 165 bbls good cement back to surface. CIP @ 1:22 hrs. 01:30 02:00 0.50 2,327 2,327 SURFA( CEMEN-OWFF P De-energize knife valve on diverter line. Flush stack with black water& function annular(3 times).Well shut in @ 2:00 hrs. 02:00 05:30 3.50 0 0 SURFA( CEMEN RURD P R/D Volant CRT. Clean&clear floor of casing/cementing tools& equipment. R/U drilling bails&5" elevators&prep to P/U DP Annulus Pressure= 13 psi 05:30 14:45 9.25 0 0 SURFA( CEMEN PULD P L/D 1 stand of SLB NMFC. P/U & rack back 76 stands of 5"DP Annulus Pressure= 10 psi Page 5 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:15 0.50 0 0 SURFA( CEMEN-SVRG P Service rig&draw works. 15:15 18:45 3.50 0 0 SURFA( CEMEN-PULD P Cont.to P/U&rack back 23 stands of 5" DP Annulus Pressure=5 psi 18:45 19:45 1.00 0 0 SURFA( CEMEN-MPDA P M/U 2 stands of DP&install RCD element. Rack back in derrick. 19:45 20:00 0.25 0 0 SURFA( CEMEN-RURD P Clean&clear fllor. SIMOPS-install roller on skate 20:00 20:45 0.75 0 SURFA( CEMEN-RURD P Confirm 0 psi on under annular. Open annular&F/C(static). Drain stack& L/D landing jt. 20:45 00:00 3.25 SURFA( CEMEN-NUND P R/D diverter system. Remove diverter line&knife valve. R/D riser& annular. 05/26/2015 N/D diverter system. N/U BOPE. R/U flow box, modify Trip nipple length, fill stack with water, check for leaks, stack leaking at top flange of lower pipe ram, RD trip nipple, break BOP connections, inspect and change out API seal ring. NU flow box, flow line and trip nipple. 00:00 04:00 4.00 0 0 SURFA( CEMEN NUND P Cont.to ND riser,Annular and starting spool. Stage wellhead and Alpine speed head/double stud adapter in cellar. 04:00 05:30 1.50 0 0 SURFA( WHDBO NUND P NU wellhead 05:30 08:00 2.50 0 0 SURFA(WHDBO NUND P NU BOPs, RU Alpine speed head/ DSA. 08:00 09:30 1.50 0 0 SURFA(WHDBO NUND P RU Choke and Kill lines on stack 09:30 11:00 1.50 0 0 SURFA( WHDBO NUND P RU double annular valves on wellhead, PU MOD trip nipple to rig floor. 11:00 11:30 0.50 0 0 SURFA( WHDBO NUND P Clear and clean rig floor,double check torque on DSA/speed head. 11:30 13:15 1.75 0 0 SURFA( WHDBO MPDA P RU MPD Flo-box and hoses. Install Trip nipple. 13:15 16:45 3.50 0 0 SURFA(WHDBO MPDA P Remove Trip nipple and modify to fit wellhead BOP stack configuration. Re-install trip nipple, RU Katch-Kan. Remove bales. 16:45 18:45 2.00 0 0 SURFA(WHDBO MPDA P Re-set Trip nipple. Fill BOP stack with water and check for leaks. Leak between Mud Cross and LPRs. Tighten flange bolts but still leaking. 18:45 22:15 3.50 0 0 SURFA( WHDBO NUND T Remove Trip nipple, Flow-box, flowline and break flange connections between pipe rams inspect and change out API seal ring. 22:15 00:00 1.75 0 0 SURFA( WHDBO NUND T NU Flow box,flow line and Trip nipple. 05/27/2015 Change out BOP gasket, NU Flow box,flow line and set trip nipple. Set 5"test plug,fill stack with water and check for leaks. Body test BOPE to 3,000 psi. RU and test BOPE to 250/5,000 psi,test Annular to 250/ 3,500 psi. Test witnessed by Lou Grimaldi of the AOGCC. Test MPD equip. PU/MU BHA#2, RIH, shallow test MWD wash/ream thru cement stringers from 2,162'to 2,233'. CBU and RU to test 10-3/4"surface csg. 00:00 01:00 1.00 0 0 SURFA(WHDBO NUND T Continue to NU Flow box, flow line and Trip nipple. 01:00 01:30 0.50 0 0 SURFA(WHDBO RURD P Set 5"test joint and test plug. Page 6 of 28 4111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 03:30 2.00 0 0 SURFA( WHDBO BOPE P Fill stack and Choke manifold with water and check for leaks. Body test stack to 3,000 psi and check for leaks-good. 03:30 08:30 5.00 0 0 SURFA( WHDBO BOPE P BOPE Test: Test with 5"test joint, Test Annular to 250/3,500 psi for 5 min, Test 3.5"x 6"variable UPRs and 3.5"x 6"variable LPRs to 250/ 5,000 psi. Test choke valves#1 -14, needle valve to 250/3,500 psi for 5 min., HCR Choke and Kill,4" Demco,4"FOSV, dart&needle valves, HCR choke&kill to 250/3500 psi for 5 min.-good. Koomey test; IP=3,000 psi,After close= 1,400 psi,200 psi recovery 35 sec, full recovery 198 sec, N2-4 bottle average=2,050 psi. Function tested BOPE from the remote panel-good. Flush Poor Boy Gas Buster with 3 BPM and perform draw down test on manual and Super chokes to 1,100 psi.Tested gas alarms. Tested PVT and flow meter.- Testing witnessed by Lou Grimaldi of the AOGCC. 08:30 09:15 0.75 0 0 SURFA( WHDBO MPDA P PJSM. RD MPD Trip Nipple and set MPD test plug. 09:15 13:30 4.25 0 0 SURFA( WHDBO MPDA P PJSM. Fill MPD lines with water. Test RCD head, Orbit valve, Lo-Torque valve and Choke valves. SIMOPS: Purge and change TD hydraulic system and change filter. 13:30 15:00 1.50 0 0 SURFA( WHDBO ROPE P RU test equipment and test Auto and Manual IBOP to 250/5,000 psi for 5 min each-good. Could not test earlier due to TD not working 15:00 15:15 0.25 0 0 SURFA( WHDBO RURD P RD test equipment and blow down TD. 15:15 15:45 0.50 0 0 SURFA( WHDBO MPDA P Test MPD chokes and butterfly valve to 1,200 psi. SIMOPS: RU 12'bails and adjust Link-Tilt. 15:45 16:15 0.50 0 0 SURFA( WHDBO MPDA P Blow down MPD equipment and pull MPD test plug. 16:15 16:30 0.25 0 0 SURFA( WHDBO RURD P PU test joint and pull 5"test plug and LD. Pull 10"ID wear ring. 16:30 18:00 1.50 0 0 SURFA( CEMEN-BHAH P PU BHA#2 to rig floor. PU and set mouse hole 18:00 20:45 2.75 0 696 SURFA( CEMEN-BHAH P MU 9-7/8"x 11" RSS and Reamer BHA#2 to 696'. 20:45 21:45 1.00 696 2,012 SURFA( CEMEN-TRIP P RIH from 696'to 2,012'with 5" DP 21:45 23:30 1.75 2,012 2,233 SURFA( CEMEN-COCF P Wash down from 2,012'to 2,162'and tag up on cement stringers continue to wash down to 2,233'at 500-675 gpm, 1,310-2,200 psi, 30 rpm and 2.5-5.5 ft-lb TQ. 23:30 23:45 0.25 2,233 2,205 SURFA( CEMEN CIRC P CBU and stand back partial stand of DP. Page 7 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:45 00:00 0.25 2,205 2,205 SURFA( CEMEN-RURD P RU to test 10-3/4"Surface casing and outer annulus valve. X5/28/2015 Drill 20'of new formation. Displace well to 9.8 ppg LSND mud. Perform LOT to 14.8 ppg EMW. Drill ahead, open reamer and drill 9-7/8"x 11"Intermediate hole section to 3,126'. 00:00 01:00 1.00 2,205 2,205 SURFA( CEMEN-PRTS P Test 10-3/4"casing to 2,500 psi for 30 min.-Good. Bleed off, RD and blow down lines. 01:00 01:15 0.25 2,205 2,234 SURFA( CEMEN-COCF P Wash down from 2,205 to 2,234'and tag up on plug/FC with 525 gpm, _ 1,470 psi, 30 rpm and 3.0K ft-lb TQ. 01:15 04:45 3.50 2,234 2,342 SURFA( CEMEN-DRLG P Drill FC and shoe track and rat hole with 525 gpm, 1,470 psi, 30-45 rpm, 3-6K TQ 04:45 05:15 0.50 2,342 2,362 SURFA( CEMEN-DDRL P Drill 20'new formation to 2,362 with 625 gpm, 1,830 psi, 60 rpm, 4K TQ. ADT=0.47 hr,TVD=2,263' PU= 128K, SO= 118K, ROT= 125K 05:15 05:45 0.50 2,362 2,300 SURFA( CEMEN DISP P PJSM. Displace well from 10.0 ppg DrillPlex spud mud to 9.8 ppg LSND mud at 625 gpm, 1,690 psi, 60 rpm, 4K TQ. POOH to inside 10-3/4"csg. 05:45 06:00 0.25 2,300 2,300 SURFA( CEMEN OWFF P Flow chk-static 06:00 07:00 1.00 2,300 2,300 SURFA( CEMEN-LOT P PJSM. RU test equip and perform LOT to 14.8 ppg EMW with 9.8 ppg LSND and 585 psi surface leak off pressure. Blow down lines and RD test equip. Flow chk-static. 07:00 07:15 0.25 2,300 2,362 INTRM1 DRILL WASH P Wash and ream to bottom at 2,362' with 620 gpm, 1,650 psi, 60 rpm and 4K TQ, 07:15 09:00 1.75 2,362 2,446 INTRM1 DRILL DDRL P Drill new hole from 2,362'to 2,446'. ADT= 1.57 hrs,TVD=2,336' 09:00 09:30 0.50 2,446 2,446 INTRM1 DRILL CIRC P CBU with 400 gpm, 750 psi,60 rpm and 3K TQ. 09:30 10:00 0.50 2,446 2,460 INTRM1 DRILL DDRL P Drill from 2,446'to 2,460'.ADT=0.17 hrs 10:00 10:15 0.25 2,460 2,446 INTRM1 DRILL REAM P POOH from 2,460'to 2,446'to obtain baseline with 800 gpm,2,650 psi, 160 rpm and 3K TQ. MWD turbine rpm at 4,492 rpm with 100%flow and 3K baseline torque. 10:15 10:45 0.50 2,446 2,448 INTRM1 DRILL CIRC P Drop 1.25"reamer activation ball and pump down with 150 gpm, 150 psi, 20 rpm, 2.5K TQ(bit at 2,448' and UR blades at 2,357'). Ball did not seat. Increase flowrate to 300 gpm, 400 psi-no change seen. Increase flow rate to 800 gpm,2,100 psi, 100 rpm and 3.5K TQ. MWD turbine rpm dropped to 4,060 and pressure drop indicated flow diverting thru reamer. Page 8 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:00 0.25 2,448 2,460 INTRM1 DRILL UREM P Ream from 2,448'to 2,453'with 800 gpm, 2,100 psi, 100 rpm 3.5K TQ and tag up on reamed ledges by slacking off 5K lb and PU with 5K lb to confirm reamer is open. Continue to ream down to 2,460'. 11:00 12:00 1.00 2,460 2,540 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 2,460 to 2,540'. ADT=3.08 hrs, TVD=2,414'. PU= 128K, S0= 118K, ROT= 125K, TQ on/off=5.0K/3.5K ft-lb SPRs-2,362'md, 0700 hrs MP#1: 30- 130,40- 180 MP#2: 30- 130,40- 180 12:00 00:00 12.00 2,540 3,126 INTRM1 DRILL DDRL P Drill 9-7/8"x 11" hole from 2,540 to 3,126'. ADT=9.76 hrs, TVD=2,833'. WOB: 12K, RPM: 170-125, 800 gpm,2,100 psi. PU= 132K, SO= 114K, ROT= 120K,TQ on/off=5.5K/ 3.0K ft-lb SPRs-2,362'md, 0700 hrs MP#1: 30- 130,40-180 MP#2: 30- 130,40-180 Spill Drill: 110 sec CRT 35/29/2015 Continue to drill ahead 9-7/8"x 11"Intermediate hole section to 4,179'. 00:00 09:00 9.00 3,126 3,620 INTRM1 DRILL DDRL P Drill 9-7/8"x 11" hole from 3,126 to 3,620'. ADT=7.66 hrs, TVD=3,136'. PU= 140K, SO= 125K, ROT= 129K, TQ on/off=5.5K/4.5K ft-lb, ECD-10.5 ppg SPRs-3,243'md, 0217 hrs MP#1: 30- 160,40-210 MP#2: 30- 170,40-210 09:00 09:30 0.50 3,620 3,620 INTRMI DRILL CIRC T CBU and sweep hole with 34.5 bbl Hi-Vis sweep at 800 gpm,2,360 psi, 140 rpm,4.5K TQ. 09:30 09:45 0.25 3,620 3,620 INTRMI DRILL OWFF T Flow chk-Static 09:45 11:30 1.75 3,620 2,137 INTRM1 DRILL TRIP T POOH to 2,137'while monitoring hole fill. LD GR. PU= 125K, SO= 110K 11:30 12:15 0.75 2,137 2,137 INTRM1 DRILL OWFF P Flow chk-Static. SIMOPs-Clear and clean rig floor, change out 30' mouse hole to 90'MH. 12:15 14:00 1.75 2,137 3,620 INTRM1 DRILL TRIP T RIH from 2,137'to 3,615'and fill pipe. Wash last 5'to btm with 400 gpm, 800 psi, 160 rpm,4.5K TQ Page 9 of 28 Time Logs 4110 • Date From To Dur S. Depth E.Depth Phase Code Subcode -T Comment 14:00 00:00 10.00 3,620 4,179 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 3,620'to 4,179'. Footage-559'. 800 gpm,2450 psi, ECD: 10.55 ppg, PU= 140K, SO= 125K, ROT= 129K, RPM: 180,TQ on/off=5.5K/4.5K ft-lb ADT=8.63 hrs,TVD=3450'. SPRs-3,343'md, 20:30 hrs MP#1: 30-160,40-210 MP#2: 30-160,40-210 Drill: Kick while drilling-56 sec CRT 05/30/2015 Continue to drill ahead 9-7/8"x 11"Intermediate hole section to 5,460'. 00:00 12:00 12.00 4,179 4,867 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 4,179'to 4,867'. Footage-688'. 785 gpm, 2,600 psi, ECD: 10.69 ppg, PU= 150K, SO= 130K, ROT= 138K, RPM: 180, TQ on/off=6.5K/3.3K ft-lb ADT= 10.66 hrs, TVD=3,844'. SPRs-4,556' md, 06:26 hrs MP#1: 30-180,40-230 MP#2: 30-180,40-230 12:00 19:00 7.00 4,867 5,268 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 4,867'to 5,268'. Footage-401'. 788 gpm, 2,530 psi, ECD: 10.48 ppg, PU= 150K, SO= 130K, ROT= 138K, RPM: 180,TQ on/off=6.5K/3.3K ft-lb SPRs-5,247'md, 18:45 hrs MP#1: 30- 170,40-220 MP#2: 30- 170,40-220 19:00 20:00 1.00 5,268 5,268 INTRM1 DRILL FIT P CBU for Qannik OH-FIT at 5,247'md, 4,060'TVD. Close Annular and rotate at 3 rpm to keep pipe moving. Perform FIT with 550 psi surface pressure and 9.9 ppg LSND. FIT= 12.53 ppg EMW at 4,018'TVD(K-2 marker). 20:00 00:00 4.00 5,268 5,460 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 5,268'to 5,460'. Footage- 192'. 788 gpm,2,530 psi, ECD: 10.48 ppg, PU= 158K, SO= 140K, ROT= 145K, RPM: 180,TQ on/off=8.3K/3.8K ft-lb ADT=9.3 hrs, TVD=4,182'. 05/31/2015 Continue to drill ahead 9-7/8"x 11"Intermediate hole section to 6,950'. Page 10 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 5,268 6,280 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 5,268'to 6,280'. Footage-670'. 785 gpm, 2,560 psi, ECD: 10.63 ppg, PU=210K, SO= 150K, ROT= 163K, RPM: 180, TQ on/off= 11.8K/6.1K ft-lb SPRs-6,816'md,23:30 hrs MP#1: 30- 190,40-240 MP#2: 30- 190,40-240 12:00 00:00 12.00 6,280 6,950 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 6,280'to 6,950'. Footage-820'. 785 gpm, 2,560 psi, ECD: 10.71 ppg, PU= 166K, SO= 143K, ROT= 154K, RPM: 180,TQ on/off= 10.0K/4.6K ft-lb SPRs-6,253'md, 11:20 hrs MP#1: 30- 190,40-240 MP#2: 30- 190,40-240 06/01/2015 Continue to drill ahead 9-7/8"x 11" Intermediate hole section to 7,693'. Rotary steerable directional tool not responding. Trouble shoot and confirm tool failure. CBU 00:00 12:00 12.00 6,950 7,366 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 6,950'to 7,666'. Footage-716'. 785 gpm, 2,750 psi, ECD: 10.58 ppg, PU= 195K, SO= 155K, ROT= 170K, RPM: 180,TQ on/off= 13.3K/6.9K ft-lb SPRs-6,816'md, 23:30 hrs MP#1: 30-210,40-260 MP#2: 30-210,40-260 12:00 15:45 3.75 7,366 7,880 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 7,666'to 7,880'. Footage-214'. 788 gpm,2,610 psi, ECD: 10.63 ppg, PU=200K, SO= 160K, ROT= 174K, RPM: 180,TQ on/off= 13.6K/7.9K ft-lb SPRs-6,816'md, 23:30 hrs MP#1: 30-210,40-260 MP#2: 30-210,40-260 15:45 17:00 1.25 7,880 7,891 INTRM1 DRILL DDRL P Drill from 7,880'to 7,891'with no response from RSS directional tool. Trouble shoot. 17:00 17:45 0.75 7,891 7,948 INTRM1 DRILL DDRL P Drill and trouble shoot from 7,891'to 7,948'with no response from RSS directional tool. 17:45 18:45 1.00 7,948 7,983 INTRM1 DRILL DDRL P Survey hole. Drill from 7,948'to 7,983'with no response from RSS directional tool. Confirm tool failure. ADT: 4.73 hr, TVD: 5,625' Page 11 of 28 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 00:00 ' 5.25 7,948 7,983 INTRM1 DRILL CIRC T CBU and reciprocate pipe with 788 gpm, 2,700 psi, 120-180 rpm. Fire Drill-CRT=50 sec 36/02/2015 POOH. CBU at casing shoe. Continue to POOH and handle BHA. RU and test BOPE, RD test equip. PU RSS BHA#3, RIH, shallow test MWD. Continue RIH to TD. 00:00 00:45 0.75 7,948 7,983 INTRM1 DRILL CIRC T Continue to CBU and reciprocate pipe with 788 gpm, 2,700 psi, 120-180 rpm. 00:45 01:15 0.50 7,948 7,983 INTRM1 DRILL OWFF T Flow chk-static SPRs-7,983'md, 00:45 hrs MP#1: 30-210,40-260 MP#2: 30-210,40-260 01:15 06:00 4.75 7,948 2,484 INTRM1 DRILL TRIP T POOH monitoring on trip tank from 7,983'to 2,484'. Take check shot surveys at 2,814', 2,723', 2,629', 2,428'. Note: proper hole fill. PU= 125K, SO= 120K lb 06:00 07:15 1.25 2,484 2,389 INTRM1 DRILL CIRC T CBU with 800 gpm, 2,170 psi, 150 rpm, 2.5-2.0K TQ. Heavy clay conglomerations seen over the shakers. Continue to circulate until clean. Check shot survey at 2,428'. 07:15 08:30 1.25 2,389 696 INTRM1 DRILL TRIP T POOH from 2,389'to top of HWDP at 696'while monitoring hole fill on Trip tank. (zero overpull pulling the UR and BHA inside casing). PU=SO=78K at 696'. 08:30 08:45 0.25 696 696 INTRM1 DRILL OWFF T Flow chk-good. PJSM on handling BHA. 08:45 10:45 2.00 696 0 INTRM1 DRILL BHAH T POOH and rack back BHA, less PowerDrive. 10:45 11:30 0.75 0 0 INTRM1 DRILL WWWH T PJSM, MU stack washer and flush stack with 600 gpm, 250 psi,20 rpm. Blow down TD and mud line. 11:30 13:00 1.50 0 0 INTRM1 WHDBO RURD T Drain stack-Pull wear ring. MU 5" test joint with upper test plug, RIH and set. Fill stack and lines with water. RU test equip and hold PJSM. Page 12 of 28 A Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 18:00 5.00 0 0 INTRM1 WHDBO BOPE T Test BOPE:With 5"test jt,test Annular to 250/2500 psi&chart for 5 min. Test upper 3.5 x 6"VBRs to 250/3,500 psi and hold for 5 minutes each. Choke manifold valves #1, 11, 12, 13, 14, auto/manual IBOPs,4"Demco Kill, valves 9, 11, HCR choke/kill, man choke/kill, needle valve and choke manifold valves#5, 8, 10 to 250/3500 psi for 5 min. Test dart valve,valves 4, 6, 7, FOSV, upper/lower 3-1/2"x 6" VBR's, blind rams to 250/3500 psi for 5 min. Draw down test on man/super choke to 1100 psi. Accumulator test-initial 3000 psi/ 1500 psi after function, 37 sec to first 200 psi and 215 sec to full system pressure.4 bottles average 2,000 psi.Function test BOP remote panel. Calibrate and test Gas alarms. Test witnessing waived by John Crisp of the AOGCC. 18:00 18:30 0.50 0 0 INTRM1 WHDBO RURD T Pull test plug and blow down lines. Set wear ring. 18:30 21:00 2.50 0 696 INTRM1 DRILL BHAH T PJSM, MU 9-7/8"RSS BHA#3 with under-reamer and 5" HWDP to 696' 21:00 22:00 1.00 696 2,295 INTRM1 DRILL TRIP T RIH with 5" DP to 2,295'. 22:00 22:30 0.50 2,295 2,295 INTRM1 DRILL DHEQ T Shallow test MWD with 790 gpm, 2,020 psi-good. Confirmed Under-reamer open. Blow down TD. PU= 123K, SO= 117K lb. 22:30 00:00 1.50 2,295 2,295 INTRM1 DRILL SLPC P PJSM. Slip and cut 45'of drill line. 06/03/2015 Continue RIH to TD. Drill ahead to 9,315'. 00:00 05:00 5.00 2,295 7,948 INTRM1 DRILL TRIP T RIH with 5" DP from 2,295'-7,948', filling pipe every 20 stds. 05:00 05:30 0.50 7,948 7,983 INTRM1 DRILL REAM T Survey, and wash and ream to bottom. 05:30 12:00 6.50 7,983 8,500 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 7,983'to 8,500'. Footage-517'. 795 gpm, 2,670 psi, ECD: 10.71 ppg, PU=205K, S0= 162K, ROT= 180K, RPM: 180,TO on/off= 14K/8.9K ft-lb SPRs-8,041'md, 06:25 hrs MP#1: 30-240,40-280 MP#2: 30-240,40-280 Page 13 of 28 Time Logs III Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 8,500 9,315 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 8,500'to 9,315'. Footage-815'. 790 gpm, 2,520 psi, ECD: 10.45 ppg, PU=205K, S0= 162K, ROT= 180K, RPM: 180,TQ on/off= 14K/8.9K ft-lb ADT: 10.1 hr, TVD: 6,386' SPRs-9,079'md,21:00 hrs MP#1: 30- 190,40-280 MP#2: 30- 190,40-280 06/04/2015 Continue to drill ahead to 9,331'. CBU 2.5X. Flow-chk-static. ND Trip nipple and install MPD element. Drill ahead to 9,832'. Perform Qannik FIT to 12.5 ppg EMW. Replace MPD bearing package. Circ and increase MW from 9.8 to 10.8 ppg. Drill ahead to 10,240'. 00:00 00:15 0.25 9,315 9,331 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 9,315'to 9,331'. Footage- 16'. 795 gpm,2,520 psi ADT: 0.17 hr, TVD:6,394' 00:15 01:45 1.50 9,331 9,331 INTRM1 DRILL CIRC P Pump 40 bbl sweep, CBU 2.5X.with 795 gpm, 2,600 psi, 180 rpm, 15K TQ. PJSM of installing MPD. 01:45 02:00 0.25 9,331 9,331 INTRM1 DRILL OWFF P Flow chk for 15 min-static 02:00 03:00 1.00 9,315 9,315 INTRM1 DRILL MPDA P ND Trip nipple and install MPD element. 03:00 03:15 0.25 9,315 9,331 INTRM1 DRILL REAM P Wash and Ream back to bottom at 9,331'. 03:15 10:00 6.75 9,331 9,832 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 9,331'to 9,832'. Footage-501'. 795 gpm,2,710 psi, ECD: 10.61 ppg, PU=240K, SO= 165K, ROT= 197K, RPM: 180,TQ on/off= 18.6K/12.5K ft-lb ADT: 5.26 hr, TVD: 6,687' SPRs-9,832'md, 10:10 hrs MP#1: 30-220,40-280 MP#2: 30-220,40-280 10:00 11:15 1.25 9,832 9,832 INTRM1 DRILL CIRC P CBU with 795 gpm,2,700 psi, 180 rpm, 15.5- 14K TQ 11:15 12:00 0.75 9,832 9,832 INTRM1 DRILL FIT P RU recording equip. Hold 562 psi with MPD element while rotating at 15 rpm with12.5K TQ. FIT= 12.5 ppg EMW for the Qannik fm-good. RD test equip. 12:00 12:30 0.50 9,832 9,832 INTRM1 DRILL CIRC P Circ at 9,832'with 795 gpm, 2,720 psi, 150 rpm, 14.7K TQ. 12:30 14:45 2.25 9,832 9,832 INTRM1 DRILL CIRC P Continue to circ and increase mud weight from 9.8 to 10.8 ppg with 795 gpm, 2,720-2,950 psi, 150 rpm and 14.7-15.6K TQ. 14:45 15:00 0.25 9,832 9,832 INTRM1 DRILL SFTY P PJSM for change out of RCD bearing Page 14 of 28 Time Logs 411) Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:30 1.50 9,832 9,832 INTRM1 DRILL MPDA T Change out RCD bearing package due to leaking from inner seals and overheating. 16:30 00:00 7.50 9,832 10,240 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 9,832'to 10,240'. Footage-408'. 775 gpm, 3,000 psi, ECD: 11.55 ppg, PU=240K, SO= 165K, ROT= 197K, RPM: 180, TQ on/off= 18.6K/12.5K ft-lb ADT: 5.71 hr, TVD: 6,913' SPRs-9,832' md, 16:00 hrs MP#1: 30-340,40-430 MP#2: 30-370,40-410 06/05/2015 Continue to drill ahead 9-7/8"x 11"Intermediate hole section to 11,530'. 00:00 12:00 12.00 10,240 10,877 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 10,240'to 10,877'. Footage-310'. 770 gpm, 3,250 psi, ECD: 11.60 ppg, PU=280K, SO=160K, ROT=202K RPM: 150, TQ on/off=23.5K/13.5K ft-lb ADT: 9.35 hr, TVD: 7,237' SPRs- 10,492'md, 05:00 hrs MP#1: 30-410,40-490 MP#2: 30-430,40-490 12:00 19:00 7.00 10,877 11,244 INTRMI DRILL DDRL P Drill 9-7/8"x 11"hole from 10,877'to 11,244'. Footage-367'. 770 gpm, 3,400 psi, ECD: 11.60 ppg, PU=300K, SO=160K, ROT=205K, RPM: 150, TQ on/off=24.5K/24.5K ft-lb SPRs- 10,492' md, 05:00 hrs MP#1: 30-410,40-470 MP#2: 30-410,40-470 19:00 20:30 1.50 11,244 11,244 INTRM1 DRILL RGRP T CBU with MP#1 with 376 gpm, 1,120 psi, 110 rpm, 20K TQ. Work on MP#2-Change out gear oil pump coupler and filter. 20:30 00:00 3.50 11,244 11,382 INTRMI DRILL DDRL P Drill 9-7/8"x 11"hole from 11,244'to 11,382'. Footage- 138'. 770 gpm, 3,400 psi, ECD: 11.60 ppg, PU=300K, SO=160K, ROT=205K, RPM: 150,TQ on/off=24.5K/24.5K ft-lb ADT: 8.64 hr, TVD: 7,390' SPRs- 10,492'md, 05:00 hrs MP#1: 30-410,40-470 MP#2: 30-410,40-470 Page 15of28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/06/2015 24 hr Summary Drill 9-7/8"x 11" Intermediate hole to section TD at 11,853'. Drop ball, circulate, close reamer. CBU and clean hole. 00:00 02:00 2.00 11,382 11,457 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 11,382'to 11,457'. Footage-75'. 770 gpm, 3,400 psi, ECD: 11.67 ppg, PU=300K, SO=160K, ROT=205K, RPM: 150,TQ on/off=24.5K/24.5K ft-lb ADT: 8.64 hr,TVD: 7,390' SPRs- 10,492'md, 05:00 hrs MP#1: 30-410,40-470 MP#2: 30-410,40-470 02:00 04:30 2.50 11,457 11,457 INTRM1 DRILL SRVY P Take check shot surveys per JORPS protocol at 11,325'and and 11,230.57'md. Correct surveys. Pump at 775 gpm, 3,350 psi holding 80 psi with MPD. PU=305K, S0= 145K Wash back to TD. 04:30 12:15 7.75 11,457 11,744 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 11,457'to 11,744'. Footage-287', 800 gpm, 3,530 psi, ECD: 11.51 ppg, PU=310K, SO=140K, ROT=200K, RPM: 150, TQ on/off=26K/21.5K ft-lb ADT: 7.85 hr, TVD: 7,459' SPRs- 11,717' md, 11:00 hrs MP#1: 30-265,40-315 MP#2: 30-265,40-315 12:15 15:15 3.00 11,744 11,853 INTRM1 DRILL DDRL P Drill 9-7/8"x 11"hole from 11,744'to 11,853'. Footage-109', 800 gpm, 3,480 psi, ECD: 11.53 ppg, PU=320K, SO=150K, ROT=204K, RPM: 150,TQ on/off=21.7K/19.5K ft-lb ADT: 2.54 hr, TVD: 7,476' 15:15 15:45 0.50 11,853 11,853 INTRM1 CASING CIRC P CBU at 11,843'with 800 gpm, 3,480 psi, 130 rpm, 23.6K TQ 15:45 16:45 1.00 11,853 11,853 INTRM1 CASING CIRC P Drop ball to de-activate under-reamer with 250 gpm, 600 psi, 150 rpm, 16.7K TQ. Reduce pump rate prior to ball seating to 150 gpm. Ball landed on seat, pressured to 1,900 and pressure decreased indicating tool closed. 16:45 00:00 7.25 11,853 11,853 INTRM1 CASING CIRC P CBU with 740 gpm, 3,150-3,190 psi, 150 rpm, 23.5-22.3K TQ.Apply MPD back pressure to maintain 11.4 -11.5 ppg ECD, as wellbore cleaned up. Reciprocate pipe 80'while circulating. Page 16 of 28 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/07/2015 24 hr Summary Continue to CBU and clean hole. Increase MW from 10.8 to 11.4 ppg. POOH and pull tight at 11,622'.Work tight spot, rotate pipe and continue to circ. Decrease MW to 11.1 ppg. POOH working thru tight spot at 11,169'. RIH and work thru tight spot. Continue to POOH thru tight spot to 6,800'md. 00:00 04:45 4.75 11,853 11,853 INTRM1 CASING CIRC P CBU with 740 gpm, 3,150-3,190 psi, 150 rpm, 23.5-22.3K TQ.Apply MPD back pressure to maintain 11.4 - 11.5 ppg ECD, as wellbore cleaned up. Reciprocate pipe 80'while circulating. Note: Returns at shakers decreased from a steady sand/silt flow to a reduced flow of fines. 04:45 10:00 5.25 11,853 11,853 INTRM1 CASING CIRC P Continue to circulate at 600 gpm, 2,280 psi,40 rpm, 15K TQ. and increase mud weight from 10.8 ppg to 11.4 ppg 10:00 10:15 0.25 11,853 11,853 INTRM1 CASING OWFF P Flow chk-static Rotate pipe 15rpms at 17k end of flow check increased torque to 20k 10:15 11:15 1.00 11,853 11,717 INTRM1 CASING TRIP P PU=285K, SO=145K POOH holding back pressure with MPD from 11,853'to 11,620. Pull tight at 11,629'.Work pipe back in hole to 11,717'and work pipe. 11:15 19:00 7.75 11,717 11,717 INTRM1 CASING CIRC T CBU with 125 gpm, 380 psi,40 rpm, 17 TQ and reduce mud weight from 11.4 to 11.1 ppg 19:00 19:15 0.25 11,717 11,717 INTRM1 CASING OWFF P Flow chk-static Rotate at 20rpms 17k tq same through flow check 19:15 00:00 4.75 11,717 6,350 INTRM1 CASING TRIP P POOH from 11,717'to 6,350' holding back pressure with MPD. Tight spots at 11,172', 11,120', 11,028', 8,634'. Wiped thru tight spots and made verification passes. 36/08/2015 Continue to POOH, handle BHA#3. Change rams to 7-5/8"solid body csg rams and test. RU casing equip and run 7-5/8"intermediate csg to 1,185'. 00:00 04:15 4.25 6,350 2,294 INTRM1 CASING TRIP P POOH from 6,350'to 2,327', holding back pressure with MPD.Tight spots at 6,040', 5,982',4,378'.Wiped thru tight spots and made verification passes. Pulled inside 10-3/4"csg with reamer, BHA and bit with no over pull or excess drag. PU= 122K 04:15 04:30 0.25 2,294 2,294 INTRM1 CASING OWFF P Flow chk-static 04:30 05:45 1.25 2,294 786 INTRM1 CASING TRIP P POOH from 2,294'to 786'holding back pressure with MPD. PU=92K 05:45 08:15 2.50 786 786 INTRM1 CASING MPDA P PJSM. Pull RCD head and install Trip nipple. Clear the rig floor. 08:15 09:30 1.25 786 143 INTRM1 CASING PULD P POOH from 786', monitoring on Trip tank. LD HWDP and drilling Jars. Page 17 of 28 4111 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 13:30 4.00 143 0 INTRM1 CASING BHAH P LD reamer and BHA. Clear and clean rig floor. 13:30 13:45 0.25 0 0 INTRM1 CASING SFTY P PJSM on changing BOP ram elements. 13:45 15:15 1.50 0 0 INTRM1 CASING BOPE P Pull wear ring, set test plug, C/O upper rams to 7-5/8"solid body. RU test equip and test UPRs to 250/3,500 psi(good). 15:15 16:00 0.75 0 0 INTRM1 CASING BOPE P Pull test plug, RD test equip and set thin walled WR(10.375"). 16:00 18:00 2.00 0 0 INTRM1 CASING RURD P RU Casing Running Tool and equipment. 18:00 18:15 0.25 0 0 INTRM1 CASING SFTY P PJSM on running 7-5/8"casing. 18:15 00:00 5.75 0 1,185 INTRM1 CASING PUTB P Run 7-5/8",29.7 Ib/ft, L80, BTC-M, R3 casing with"Silver Bullet"FS, FC with Bypass adaptor and Baffle adaptor,thread locking first 4 connections. PU and check floats are holding-ok. CENTs on Jt#1 - 10'from shoe, Jt#2-30'above on stop collar and 1/joint on#3-25. Use Run&Seal thread dope applied with brush and make up to the base of the triangle with and average MU torque=8,000 ft-lb. Fill pipe as run. 06/09/2015 Continue to POOH, handle BHA#3. Change rams to 7-5/8"solid body csg rams and test. RU casing equip and run 7-5/8"intermediate csg to 8,940' 00:00 01:30 1.50 1,185 1,560 INTRM1 CASING PUTB P Run 7-5/8", 29.7 Ib/ft, L80, BTC-M, R3 casing from 1,185'to 1,560' 01:30 02:45 1.25 1,560 1,560 INTRM1 CASING RGRP T Clean pipe skate electrical sensors. Change out blown fuse. 02:45 04:30 1.75 1,560 2,315 INTRM1 CASING PUTB P Run 7-5/8", 29.7 Ib/ft, L80, BTC-M, R3 casing from 1,560'to 2,315'. 04:30 05:00 0.50 2,315 2,315 INTRM1 CASING CIRC P CBU at 10-3/4"csg shoe w/1.5 bpm @ 70 psi.. 05:00 00:00 19.00 2,315 8,940 INTRM1 CASING PUTB P Run 7-5/8", 29.7 Ib/ft, L80, BTC-M, R3 casing from 2,315'to 8,940'(212 jts in the hole) 06/10/2015 Cont.to run 7-5/8"casing&land on hanger© 11,837'. Circ&cond mud for cement job. Cement 1st stage as per Dowell. Circ&cond mud for 2nd stage cement job.. 00:00 11:00 11.00 8,940 11,779 INTRM1 CASING PUTB P RIH 7-5/8"29.7#L-80 BTCM& Hyd 563 f/8940'to 11,779'(Saw significantr excess drag once in HRZ f/10,447')SO wt 120 K 11:00 11:30 0.50 11,779 11,837 INTRM1 CASING HOSO P M/U hanger&P/U landing jt&land casing on depth @ 11,836.73' 11:30 19:15 7.75 11,837 11,837 INTRM1 CEMEN-CIRCP Circ&cond. mud for cement job. Stage flow rate f/.3 bpm @ 540 psi to 8 bpm. ICP @ 675 psi&FCP @ 520 psi. 11.1+ppg in/out<21 YP 19:15 19:30 0.25 11,837 11,837 INTRM1 CEMEN-SFTYP PJSM- 1st stage cement job Page 18 of 28 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 19:30 22:45 3.25 11,837 11,837 INTRM1 CEMEN-CMNTP Cement 1st stage cement as per Dowell. (Dowell pump 1.2 bbls H2O &psi test to 4000 psi(good),40.1 bbls CW 100, 40.1 bbls 12.0 ppg Mud Push II, Drop bypass plug, 88.1 bbls 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement, 1.1 bbls H2O, Drop landing plug, 10.1 bbls H2O) Rig displace with 527.4 bbls 11.1 ppg LSND. ICP=8 bpm @ 600 psi/ FCP 3 bpm @ 410 psi. Pressure up to 900 psi&hold for 5 min. Check floats(good)Cemented with full returns. CIP @ 22:27 hrs. F/C(good) 22:45 00:00 1.25 11,837 11,837 INTRM1 CEMEN-CIRC P Pressure up to 3290 psi @ 64 stks& shear stage collar. Circ&cond mud w/8 bpm @ 530 psi. 11.1+ppg in/out <21 YP 06/11/2015 Cont. to circ for 2 nd stage cement. Pump 2nd stage as per Dowell. R/D cementing hoses. UD landing jt. Retrieve WR. R/D casing tools&equip. L/D 5"DP. P/U 20 stands 4" DP. C/O rams&saver sub. R/U to test BOPE. 00:00'11 00:15 0.25 11,837 11,837 INTRM1 CEMEN-CIRC P Circ&cond mud w/8 bpm @ 530 psi. 11.1+ppg in/out<21 YP 00:15 00:30 0.25 11,837 11,837 INTRMI CEMEN-SFTY P PJSM-2nd stage cement job 00:30 02:45 2.25 11,837 11,837 INTRMI CEMEN'CMNT P Cement 2nd stage cement as per Dowell. (Dowell pump 40.2 bbls CW 100,40.2 bbls 12.0 ppg Mud Push II, 91.4 bbls 15.8 ppg 1.16 ft3/sx yield Qannik Slurry cement, 1.1 bbls H2O, Drop closing plug, 10.1 bbls H2O) Rig displace with 253 bbls 11.1 ppg LSND. ICP=8 bpm @ 340 psi/ FCP 3 bpm @ 290 psi. Pressure up to 1190 psi&close stage collar. Cemented with full returns. CIP @ 2:10 hrs. F/C(good) 02:45 03:15 0.50 0 0 INTRM1 CEMEN-RURD P R/D cement lines& L/D landing jt 03:15 05:30 2.25 0 0 INTRMI CEMEN1/WSP P Attempt to pull wear ring. Damaged wear ring&un-able to pull. Pull wear ring w/spring lock puller. Set pack off as per FMC&test to 5000 psi. 05:30 06:45 1.25 0 0 INTRM1 CEMEN-PULD P L/D 5"DP from derrick via mouse hole 06:45 07:15 0.50 0 0 INTRM1 CEMEN-SVRG P C/O hydraulic oil on top drive 07:15 15:15 8.00 0 0 INTRM1 CEMEN-PULD P L/D 5"DP from derrick via mouse hole. SIMOPS-Dowell perform LOT, flush annulus w/300 bbls H2O& freeze proptect w/82 bbls diesel) 15:15 16:15 1.00 0 0 INTRM1 CEMEN-RURD P R/D 5"elevators&R/U 4"elevators &single jt elevators. Install 90' mouse hole. 16:15 19:45 3.50 0 0 INTRM1 CEMEN-PULD P P/U&rack back 20 stands 4"DP via 90'mouse hole. 19:45 20:15 0.50 0 0 INTRMI CEMEN-MPDA P P/U 1 stand DP for MPD bearing& rack back. Page 19 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 22:15 2.00 0 0 INTRM1 CEMEN-RURD P C/O saver sub on top drive. (SIMOPS -C/O 7-5/8"casing rams to 3-1/2"X 6"VBR's) 22:15 22:45 0.50 0 0 INTRM1 CEMEN-RURD P C/O 90' mouse hole to 30'mouse hole for BHA 22:45 00:00 1.25 0 0 INTRM1 WHDBO RURD P Set test plug&fill choke manifold. R/U to test BOPE. R/U 4"test jt. Fill stack w/H20 06/12/2015 R/U to test BOPE.Test BOPE. M/U 6-3/4" BHA. Single in hole w/4"DP to 5,606'Test casing to 1000 psi. Wash f/5,606'to TOC @ 5,725' Drill out stage collar to 5,726' 00:00 01:45 1.75 0 0 INTRM1 WHDBO RURD P PSI test BOPE&check for leaks. (SIMOPS-change mud bucket rubbers to 4", L/D 5"subs&XO's, install skate roller) 01:45 09:00 7.25 0 0 INTRM1 WHDBO BOPE P Test BOPE w/3 1/2",4"&4-1/2"test jts. (Annular& HCR choke/kill 250/2500 psi&chart for 5 min- passed)(Choke valves#1 - 14, HCR choke/kill, man choke/kill, needle valve,dart valve, FOSV, upper/lower 3 1/2"x 6"VBR's, blind rams to 250/3500 psi for 5 min-passed) Draw down test on man/super choke to 1100 psi.Accumulator test, Int 3075 psi/1450 psi after function,29 sec to first 200 psi&209 sec to full system psi.4 bottles @ 2000 psi. Gas alarms tested.Test witnessed by AOGCC Johnnie Hill 09:00 10:30 1.50 0 0 INTRM1 WHDBO RURD P Blow down lines. Pull test plug& install wear ring. 10:30 10:45 0.25 0 0 INTRM1 CEMEN-RURD P C/O elevatos&prep rig floor. 10:45 13:45 3.00 0 371 INTRM1 CEMEN-BHAH P PJSM-M/U 6-3/4" BHA#4 as per SLB to 371' 13:45 15:00 1.25 371 1,504 INTRM1 CEMEN-PULD P RIH f/371'to 1,504'while picking up 4"DP from pipe shed. 15:00 15:45 0.75 1,504 1,504 INTRM1 CEMEN-DHEQ P Shallow hole test MWD w/220 gpm @ 1080 psi, 60 rpm© 1 k trq (good) 15:45 20:45 5.00 1,504 5,606 INTRMI CEMEN PULD P RIH f/1,504'to 5,606'while picking up 4"DP from pipe shed. 20:45 21:30 0.75 5,606 5,606 INTRMI CEMEN'PRTS P R/U testing equip. Pressure test casing to 1000 psi for 10 min(good). R/D testing equip. 21:30 22:15 0.75 5,606 5,725 INTRM1 CEMEN COCF P Wash in hole with stands from derrick f/5,606'to 5,725'. Tag TOC @ 5,725'. 22:15 00:00 1.75 5,725 5,726 INTRMI CEMEN-DRLG P Drill out cement&stage collar f/5,725'to 5,726'w/175 to 220 gpm @1100- 1390 psi,40-80rpm @4 -6 k trq, 10- 15 WOB PUwt126k, SO wt106k, ROT wt 118k Page 20 of 28 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06/13/2015 24 hr Summary Cont. to drill out stage collar to 5,727.W&R to 5,891'. Rack back 3 stands in derrick. Cont. to RIH to 11,538' while P/U 4"DP. Test casing. Slip&cut drill line. Drill out to 11,873'. Displace to FloPro. Pull inside casing. F/C 00:00 01:30 1.50 5,726 5,727 INTRM1 CEMEN-DRLG P Drill out cement&stage collar f/5,726'to 5,727'w/175 to 220 gpm @1100- 1390 psi,40-80rpm @4 -6 k trq, 10- 15 WOB PU wt 126 k, SO wt 106 k, ROT wt 118 k 01:30 02:45 1.25 5,727 5,891 INTRM1 CEMEN-REAM P W&R f/5,727'to 5,891'w/220 gpm @ 1400 psi, 60 rpm @ 4 k trq.Work thru stage collar 2 times(free) 02:45 03:00 0.25 5,891 5,601 INTRM1 CEMEN-TRIP P POOH f/5,891'to 5,601'(racked back 3 stands) 03:00 12:00 9.00 5,601 11,348 INTRM1 CEMEN PULD P RIH while picking up 4" DP f/5,601'to 11,348'.W&R thru periodic stringers 8,640', 10,388', & 10,950'w/200 gpm @1700 psi,40 rpm @7-11 ktrq. 12:00 13:30 1.50 11,348 11,348 INTRM1 CEMEN-RURD P LID short mouse hole&M/U 90' mouse hole. Remove skate roller. 13:30 14:00 0.50 11,348 11,538 INTRM1 CEMEN-PULD P M/U 2 stands&rack back via 90' mouse hole. 14:00 16:00 2.00 11,538 11,538 INTRM1 CEMEN PRTS P R/U testing equip. &test casing to 3500 psi&chart for 5 min. R/D testing equip. 16:00 17:00 1.00 11,538 11,538 INTRM1 CEMEN-SLPC P Slip&cut 60'drill line 17:00 17:30 0.50 11,538 11,538 INTRM1 CEMEN'SVRG P Service rig, draw works&top drive. 17:30 18:00 0.50 11,538 11,538 INTRM1 CEMEN RURD P Calibrate block height&wt indicator. M/U stand in mouse hole. 18:00 19:30 1.50 11,538 11,698 INTRM1 CEMEN-COCF P PJSM. SPR's.W&R f/11,538'to 11,698'w/220 gpm @ 1970 psi, 60 rpm @ 13 k trq. TOC @ 11,698' 19:30 21:45 2.25 11,698 11,853 INTRM1 CEMEN-DRLG P Drill cement, baffle collar, float collar, shoe track&rat hole f/11,698'to 11,853'w/220 gpm @ 1970 psi, 60 rpm @ 13 k trq. 21:45 22:00 0.25 11,853 11,873 INTRM1 CEMEN-DDRL P Drill 20'new formation f/11,853'to 11,873'MD/7,480'TVD w/250 gpm @ 2750 psi,60 rpm @ 14.5 k trq. ADT 0.37 hrs PU wt 200 k, SO wt 130 k, ROT wt 150 k 22:00 23:30 1.50 11,873 11,824 INTRM1 CEMEN-DISP P Pump 30 bbls spacer&displace hole to new 10.2 ppf FloPro w/250 gpm @ 2750-2190 psi, 60 rpm @ 12-9 k trq. Pull inside 7-5/8"casing shoe @ 11,824' 23:30 00:00 0.50 11,824 11,824 INTRM1 CEMEN-OWFF P SPR's. F/C-slight ooze then static. X6/14/2015 FIT to 12.8 ppg. Install MPD element. Drill ahead 6-3/4"production section f/11,873'to 13,482' 00:00 01:00 1.00 11,824 11,824 INTRM1 CEMEN-FITP R/U&FIT ti 12.8ppg @ 1010 psi. R/D testing equipment. 01:00 03:30 2.50 11,824 11,824 PROD1 DRILL MPDA P Remove trip nipple. M/U soare MPD element bearing&rack back in derrick. Install MPD element bearing &line up chokes&system to drill with MPD. Page 21 of 28 •Time Logs 411 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 11,824 11,873 PROD1 DRILL REAM P W&R f/11,824'to 11,873'w/215 gpm @ 1700 psi, 60 rpm ©9 k trq. 04:00 12:00 8.00 11,873 12,395 PROD1 DRILL DDRL P Drill ahead f/11,873'to 12,395'MD/ 7,479'TVD,ADT 5.81 hrs, ECD 11.48 ppg, 250 gpm, 2300 psi,WOB 15, 150 rpm, PU wt 198 k, SO wt 123 k, ROT wt 154 k, Drill Trq 13, Off Btm Trq 11, 2000 units average drill gas 12:00 00:00 12.00 12,395 13,482 PROD1 DRILL DDRL P Drill ahead f/12,395'to 13,482'MD/ 7,395'TVD,ADT 8.97 hrs, ECD 11.85 ppg, 250 gpm,2580 psi,WOB 10-15, 150 rpm, PU wt 194 k, SO wt 124 k, ROT wt 154 k, Drill Trq 12, Off Btm Trq 8, 7000 units average drill gas 06/15/2015 Drill ahead 6-3/4"production section f/13,482'to 15,550' 00:00 12:00 12.00 13,482 14,493 PROD1 DRILL DDRL P Drill ahead f/13,482'to 14,493' MD/ 7,478'TVD,ADT 8.55 hrs, ECD 11.96 ppg, 250 gpm, 2720 psi,WOB 10-14, 150 rpm, PU wt 195 k, SO wt 122 k, ROT wt 150 k, Drill Trq 12.4, Off Btm Trq 10.2, 7300 units average drill gas 12:00 00:00 12.00 14,493 15,550 PROD1 DRILL DDRL P Drill ahead f/14,493'to 15,550'MD/ 7,464'TVD,ADT 9.54 hrs, ECD 12.09 ppg, 250 gpm,2790 psi,WOB 8- 12, 150 rpm, PU wt 206 k, SO wt 120 k, ROT wt 154 k, Drill Trq 11, Off Btm Trq 8,6500 units average drill gas 06/16/2015 Drill ahead 6-3/4"production section f/15,550'to 17,920' 00:00 12:00 12.00 15,550 16,685 PROD1 DRILL DDRL P Drill ahead f/15,550'to 16,685'MD/ 7,451'TVD,ADT 9.09 hrs, ECD 12.02 ppg, 250 gpm,2910 psi,WOB 10- 14, 150 rpm, PU wt 205 k, SO wt 115 k, ROT wt 154 k, Drill Trq 11.1, Off Btm Trq 8.5, 6500 units average drill gas 12:00 00:00 12.00 16,685 17,920 PROD1 DRILL DDRL P Drill ahead f/16,685'to 17,920' MD/ 7,439'TVD,ADT 8.77 hrs, ECD 12.37 ppg, 250 gpm,3060 psi,WOB 10-15, 150 rpm, PU wt 215 k, SO wt 107 k, ROT wt 154 k, Drill Trq 12, Off Btm Trq 8.5,6000 units average drill gas 06/17/2015 Drill ahead 6-3/4"production section f/17,920'to TD of 18,878'. Circ 1 B/U. Perform formation fingerprint. Cont. to circ clean for 5 B/U. Displace well to 10.9 ppg Brine. 00:00 12:00 12.00 17,920 18,878 PROD1 DRILL DDRL P Drill ahead f/17,920'to 18,878'MD/ • 7,420'TVD,ADT 8.65 hrs, ECD 12.45 ppg,215 gpm,2820 psi,WOB 10-12, 150 rpm, PU wt 205 k, SO wt 105 k, ROT wt 150 k, Drill Trq 12.9, Off Btm Trq 9.5, 6000 units average drill gas Page 22 of 28 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 18,878 18,878 PROD1 CASING CIRC P Circ 1 B/U w/230-275 gpm @ 2960 -3520 psi, 150 gpm © 11 k trq 14:00 14:45 0.75 18,878 18,878 PROD1 CASING OWFF P Perform formation fingerprint while rotating @ 10 rpm. Shut in choke f/15 min&build to 105 psi. Bleed back.8 bbls in 10 min @ 5 bbls/hr. Shut in choke for 14 min&build to 102 psi. 14:45 21:45 7.00 18,878 18,878 PROD1 CASING CIRC P Circ hole clean for 5+ B/U w/275 gpm @ 3520 psi, 150 gpm @ 12 k trq. 21:45 00:00 2.25 18,878 18,878 PROD1 CASING DISP P Displacing well f/10.3 ppg FlowPro to 10.9 ppg NaCI/NaBr Viscosified Brine Based Fluid. Pump 32 bbls spacer&chase with 760 bbls of brine w/250 gpm @ 3000 psi. Slowed pumps to 200 gpm when spacer exiting bit. Initial ECD 12.34 ppg& Final ECD= 11.71 ppg. 06/18/2015 Cont. to displace to 10.9 ppg brine. Perform formation fingerprint. Strip OOH f/18,878' to 13,158'. BROOH f/13,158'to 11,824'. Circ casing clean. F/C. Pump dry job. Strip OOH f/11,824'to 3,490' 00:00 00:15 0.25 18,878 18,878 PROD1 CASING DISP P Finish displacement w/250 gpm @ 1900 psi, 150 rpm @ 9.5 k trq. ECD 10.71 ppg, Obtain SPR's 00:15 00:30 0.25 18,878 18,878 PROD1 CASING OWFF P Perform formation fingerprint while rotating @ 10 rpm. Shut in choke f/10 min. Build to 27 psi after 5 min& then decrease to 12 psi by 10 min. 00:30 04:00 3.50 18,878 16,495 PROD1 CASING TRIP P Strip OOH w/MPD following trip schedule f/18,878'to 16,495'. PU wt 238k/SOwt112k 04:00 04:15 0.25 16,495 16,495 PROD1 CASING OWFF P Shut in chokes&observe for psi increase while rotating @ 10 rpm. No Increase 04:15 08:00 3.75 16,495 13,539 PROD1 CASING TRIP P Strip OOH w/MPD following trip schedule f/16,495'to 13,539'. PU wt 235 k/SO wt 120 k. Drag not decreasing&friction factors diverging. Tight hole @ 14,141', 14,085', 13,835', 13,653', 13,605',& 13,564' 08:00 09:30 1.50 13,539 13,444 PROD1 CASING CIRC P Circ B/U w/275 gpm @ 2200 psi, 150 rpm @ 8 k trq. Rack back 1 stand 09:30 10:00 0.50 13,444 13,158 PROD1 CASING TRIP P Strip OOH w/MPD following trip schedule f/13,444'to 13,158'. PU wt 215 k/SO wt 124 k. Drag not decreasing. 10:00 14:30 4.50 13,158 11,824 PROD1 CASING BKRM P BROOH f/13,158'to 11,824'w/240 gpm© 1900-1700 psi, 150 rpm 8- 6 k trq. 14:30 17:30 3.00 11,824 11,824 PROD1 CASING CIRC P Circ 4 B/U w/275 gpm @ 2150 psi, 120 rpm ©6 k trq. Pumped 2 high vis sweeps to aid in hole cleaning Page 23 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:30 1.00 11,824 11,824 PROD1 CASING OWFF P Shut in chokes&observe for psi increase while rotating @ 10 rpm. No Increase. Line up to cellar tote& monitor well for flow. (Static) 18:30 19:00 0.50 11,824 11,824 PROD1 CASING CIRC P Pump 33 bbls 12.4 ppg dry job. Drop 2.38"hollow drift. B/D top drive 19:00 00:00 5.00 11,824 3,490 PROD1 CASING TRIP P Strip OOH w/MPD following trip schedule f/11,824'to 3,490' 36/19/2015 Cont.to Strip OOH. L/D BHA. P/U&rack back 10 stds HWDP. M/U 4-1/2"liner to 10,519' 00:00 02:00 2.00 3,490 371 PROD1 CASING TRIP P Strip OOH w/MPD following trip schedule f/3,490'to 371' 02:00 04:30 2.50 371 371 PROD1 CASING MPDA P F/C(static). PJSM. Pull MPD element in rotating head. RIH MPD element from derrick&attempt to strip off pipe. (no success). L/D MPD element on single jt to pipe shed. Install trip nipple&L/D stabbing stand. 04:30 05:15 0.75 371 190 PROD1 CASING TRIP P POOH on elevators on TT f/371'to 190'. (replace jars w/single jt 4" HWDP) 05:15 07:30 2.25 190 0 PROD1 CASING BHAH P L/D BHA as per SLB 07:30 09:00 1.50 0 0 PROD1 CASING BHAH P Clean&clear rig floor of BHA tools& erquip. 09:00 10:45 1.75 0 0 COMPZ CASING PULD P P/U&rack back in derrick 30 jts 4" HWDP(10 stands)for weight pipe when running liner. 10:45 18:45 8.00 0 7,166 COMPZ CASING PUTB P PJSM on running liner. Break ff shoe from single jt&M/U to perf pup. M/U &RIH 4 1/2" 12.6#L-80 Hyd 563 liner to 7,166'. (EZ Ream Shoe, Perf Pup, 9 Frac Sleeves, 1 Sliding Sleeve, &Liner hanger/packer) 18:45 20:00 1.25 7,166 7,211 COMPZ CASING OTHR P C/O elevators&M/U liner hanger/packer assembly&running tool. Mix&pour pal mix. M/U XO to 1 stand 4"DP to 7,211'. 20:00 20:15 0.25 7,211 7,211 COMPZ CASING CIRC P Break circ w/4bpm @ 370 psi. PU wt 125 k, SO wt 103 k, ROT wt 117 k, 20 rpm=3.1 k trq, 30 rpm=3.0 trq. SO wt with pumps off 107 k 20:15 00:00 3.75 7,211 10,519 COMPZ CASING RUNL P RIH w/4 1/2" liner on 4"DP f/7,211' to 10,519' 06/20/2015 Cont. to RIH w/Liner on DP to shoe @ 11,837'. break circ. Obtain T&D. RIH w/liner to 18,863'. Displace to 10.9 ppg non-visosified brine. Set hanger/packer&test. POOH&L/D DP to 5,992' 00:00 01:00 1.00 10,519 11,837 COMPZ CASING RUNL P RIH w/4 1/2"liner on 4" DP f/10,519' to 11,837' 01:00 02:00 1.00 11,837 11,837 COMPZ CASING CIRC P Break circ w/4bpm @ 530 psi. PU wt 175k, SOwt125k, ROT wt145k, 20 rpm =5.3 k trq, 30 rpm=4.9 trq. Pumps Off, PU wt 177 k, SO wt 130 k, ROT wt 147 k, 20 rpm =5.2 k trq, 30 rpm=5.1 trq. Page 24 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T -Comment 02:00 09:00 7.00 11,837 18,863 COMPZ CASING RUNL P RIH w/4 1/2" liner on 4" DP f/11,837' to 18,863'(Tag botton @ 18,878' w/10 k WOB, pull liner in tension, P/U 15"to set depth of 18,863') P/U 240 k/SO 120 k 09:00 09:45 0.75 18,863 18,863 COMPZ CASING CIRC P Circ&cond. Stage pumps f/2-6 bpm @ 470- 1400 psi. PJSM on displacement 09:45 12:30 2.75 18,863 18,863 COMPZ CASING DISP P Displace to 10.8 ppg non-viscosified brine. Pump 35 bbls high vis spacer &chase w/700 bbls 10.8 ppg brine w/3-6 bpm @ 430- 1750 psi 12:30 12:45 0.25 18,863 18,863 COMPZ CASING OWFF P F/C(slight drop) 12:45 13:45 1.00 18,863 11,660 COMPZ CASING PACK P Drop ball&pump down w/3 bpm @ 400 psi(ball seated @ 980 stks)Set hanger&release f/HRD. Set liner top packer w/3500 psi. Set down to 70 k, Bleed off psi.Work Up/Down. Rotate 5 rpm to right w/5 k trq&set 30 k. Confirm set. 4 1/2"shoe @ 18,863'/TOL 11,660.7' 13:45 14:30 0.75 11,660 11,660 COMPZ CASING PRTS P Test liner top packer to 2000 psi& chart for 10 min(good). R/D testing equip. 14:30 15:00 0.50 11,660 11,660 COMPZ WELLPF OWFF P F/C(slight drop) 15:00 17:45 2.75 11,660 10,324 COMPZ WELLPF PULD P POOH while L/D 4"DP&HWDP f/11,660'to 10,324' 17:45 18:45 1.00 10,324 10,324 COMPZ WELLPF SLPC P Slip&cut 60'drill line. 18:45 19:15 0.50 10,324 10,324 COMPZ WELLPF SVRG P Service rig&top drive. 19:15 00:00 4.75 10,324 5,992 COMPZ WELLPF PULD P POOH while L/D 4" DP f/10,324'to 5,992 36/21/2015 Cont.to POOH while L/D DP. R/U to run completion. RIH 3 1/2"upper completion to 8,375' 00:00 06:00 6.00 5,992 0 COMPZ WELLPF'PULD P POOH while L/D 4" DP f/5,992 to surface. L/D liner running tools. Calc Hole Fill=70 bbls/Actual Hole Fill= 108 bbls 06:00 06:30 0.50 0 0 COMPZ RPCOM RURD P FMC pull wear ring&set retrievable completion wear ring 06:30 08:45 2.25 0 0 COMPZ RPCOM RURD P Clean&clear floor. P/U tools& equipment to run completion (sheaves, I-Wire, cannon clamps, etc). R/U sheaves. Change out handling equipment. R/U power tongs. (monitor well on TT) 08:45 00:00 15.25 0 8,375 COMPZ RPCOM PUTB P PJSM. Run 3 1/2"upper completion as per detail to 370'. M/U I Wire& test to 5000 psi for 10 min(good). Cont.to run 3 1/2"upper completion as per detail f/370'to 8,375'(Test Wire every 1000') Page 25 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/22/2015 24 hr Summary Cont.to run tubing&land out on no go @ 11,690'. Spot 26 bbls CI Brine. L/D Extra jts of tubing. M/U 4 1/2 tubg&hanger.Terminate I wire. Land on hanger. Set packer&test. Set TWC&test. Flush stak. B/D lines. N/D trip nipple. 00:00 06:00 6.00 8,375 11,663 COMPZ RPCOM PUTB P Cont.to run 3 1/2"upper completion as per detail f/8,375'to 11,690'. Tag no go on TOL. Saw indication of shear pins. (Test I Wire every 1000') POH to 11,663' 06:00 07:15 1.25 11,663 11,663 COMPZ RPCOM CRIH P Spot 26 bbls 10.8 ppg CI Brine f/TOL to bottom of SOV w/2 bpm-5 bpm @ 150-830 psi. 07:15 07:45 0.50 11,663 11,614 COMPZ RPCOM HOSO P POOH&L/D excess 3 1/2"tubing used for space out via beaver slide. M/U 1 jt 3 1/2"EUE,XO, &2 jts 4 1/2"Hyd 563. 07:45 08:45 1.00 11,614 11,614 COMPZ RPCOM RURD P M/U ACME wear ring puller to landing jt B. Pull wear ring. L/D same 08:45 10:00 1.25 11,614 11,614 COMPZ RPCOM THGR P M/U hanger&landing jt A.Align _hanger. 10:00 10:30 0.50 11,614 11,614 COMPZ RPCOM OWFF P F/C for 30 min(flid level droping in annulus)SIMOPS-SLB terminate I wire to hanger 10:30 11:30 1.00 11,614 11,686 COMPZ RPCOM THGR P SLB terminate I wire to hanger&test swedge lock connection to 5000 psi for 5 min (good)RIH&land on hanger @ 11686'. (No go 1.11'from fully located on TOL @ 11,660.75') Drop Ball&Rod 11:30 14:00 2.50 11,686 11,686 COMPZ RPCOM THGR P FMC test hanger seals to 500 psi for 5 min(good). Install TWC&pull landing jt B. Test hanger seals to 250/5000 psi&chart for 10 min (good)SIMOPS-R/D I wire sheave. R/D power tongs. 14:00 16:30 2.50 11,686 11,686 COMPZ RPCOM RURD P Pull TWC. L/D I wire&completion tools&equipment. R/U squeeze manifold&hoses. RIH landing jt B. Test squeeze manifold to 4000 psi (good) 16:30 19:00 2.50 11,686 11,686 COMPZ RPCOM PRTS P Pressure test tubing to 3500 psi (packer set @ 1600 psi). Observe slight pressure loss. Trouble shoot psi loss on surface(good). Confirm no returns on annulus(good). Pressure loss appears to be from fluid leaking by ball&seat. Pressure loss is steady©200 psi drop per 15 _min. 19:00 20:00 1.00 11,686 11,686 COMPZ RPCOM PRTS P ,Pressure up tubing to 2000 psi. 'Pressure up on annulus to 3500 psi &test packer&chart for 30min ((good)Still losing 200 psi per 15 min Ion tubing. Bleed off pressure. Page 26 of 28 Time Logs • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:00 20:30 0.50 11,686 11,686 COMPZ RPCOM PRTS P Pressure up on annulus to 3110 psi &shear SOV on lower GLM. Confirm circulation in both directions w/2bpm @ 550 psi down IOA&w/2bpm @ 500 psi down tubing 20:30 21:45 1.25 11,686 11,686 COMPZ WHDBO MPSP P Install TWC&test TWC in direction of flow to 2500 psi&chart for 15 min. SIMOPS L/D tools&equipment from rig floor. 21:45 23:45 2.00 0 0 COMPZ WHDBO OTHR P L/D landing jt. C/O elevators.M/U 4" dp to stack washer. Flush stack w/fresh H2O. B/D top drive, mud lines&choke/kill lines. L/D 90' mouse hole. 23:45 00:00 0.25 0 0 COMPZ WHDBO MPDA P N/D trip nipple 06/23/2015 N/D BOPE. Terminate I wire through well head. N/U tree&test. Spot CI brine&freeze protect. Install BPV& test. Secure well. L/D 4"DP 00:00 01:30 1.50 0 0 COMPZ!WHDBO MPDA P N/D Flow box, ketch kan, Orbit valve &lo torq. Strip MPD bearing off DP. 01:30 03:45 2.25 0 0 COMPZ WHDBO NUND P N/D BOPE&speed head adaptor& rack back on pedestal. SIMOPS- C/O saver sub on top drive. 03:45 04:30 0.75 0 0 COMPZ WHDBO OTHR P Raise rear wind walls&stage tree in cellar. Clean cellar box&well head. Clean out cellar bow w/super sucker. 04:30 07:15 2.75 0 0 COMPZ WHDBO NUND P SLB/FMC terminate control line thru well head&test(4142 psi @ 161 degrees) N/U tree&test void to 5000 psi/10 min(good)SIMOPS-Prep cellar for move, Clean&clear rig floor. P/U FMC lubricator to rig floor. 07:15 07:45 0.50 0 0 COMPZ WHDBO FRZP P R/U working platform&freeze protect tree. 07:45 09:00 1.25 0 0 COMPZ WHDBO PRTS P Test tree to 250/5000 psi for 10 min (good) 09:00 09:15 0.25 0 0 COMPZ WHDBO MPSP P Pull TWC 09:15 09:45 0.50 0 COMPZ WHDBO CRIH P R/U squeeze mainifold for displacement. 09:45 12:00 2.25 0 0 COMPZ WHDBO CRIH P PT lines to 2500 psi. Pump 345 bbls 10.8 ppg CI Brine down IA w/3.5 bpm @ 1570 psi 12:00 14:00 2.00 0 0 COMPZ WHDBO FRZP P PT lines to 2500 psi. Dowell pump 89.1 bbls diesel freeze protect down IA w/2.2 bpm @ 700- 1050 psi. Let u-tube across squeeze manifold @ 500 psi. Final psi after u-tube 400 psi. 14:00 15:15 1.25 0 0 COMPZ WHDBO OTHR P Shut in well&B/D lines. Install 30' mouse hole. Disconnect service lines in mezzanine. 15:15 17:00 1.75 0 0 COMPZ WHDBO MPSP P R/U lubricator&test. Install BPV& R/D lubricator. Test BPV 2500 psi/15 min. Bleed off psi to 400 psi&shut in well. Page 27 of 28 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:30 1.50 0 0 DEMOB MOVE RURD P B/D lines&secure well. R/D squeeze manifold&hoses. L/D lubricator. Remove tree landing. 18:30 00:00 5.50 0 0 DEMOB MOVE PULD P L/D 46 stands of 4" DP from derrick via mouse hole. Leave 9 stands of 15.7#DP in derrick for next well 36/24/2015 Finish L/D 4" DP. Move ball mill. Rig move check list. Prep to move. Disconnect service lines. B/D H2O. Work on mud pump#2. Prep floor for skid. Swap power off high line&release rig©04:00 hrs 00:00 02:30 2.50 0 0 DEMOB MOVE PULD P L/D 27 stands of 4"DP from derrick via mouse hole. SIMOPS-Move ball mill away from rig @ 01:00 hrs 02:30 03:00 0.50 0 0 DEMOB MOVE RURD P Suffle 5"DP in derrick. Install roller on skate. L/D mouse hole 03:00 04:00 1.00 0 0 DEMOB MOVE RURD P PJSm. Rig move check list. Disconnect service lines. Clean drip pans under rig floor. B/D H2O to sub. Work on mud pump#2(valve& seats) Prep rig floor for skid. Swap power from high line to Gen set. Rig released @ 04:00 hrs. Page 28 of 2E • • Cement Detail Report or f a CD5-04 Conor iPhillips String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/24/2015 22:00 5/25/2015 01:30 CD5-04 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4"Surface 36.2 2,327.0 No Yes Yes Casing 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) 6 3 6 400.0 900.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.2 1,596.0 1,352 DeepCRETE 459.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 0.00 11.00 4.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,596.0 2,327.0 291 G 60.6 Yield(ft5sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.09 0.00 15.80 3.00 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/8/2015 • • Cement Detail Report 00!at CD5-04 ConocoPhilips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/10/2015 20:00 6/11/2015 02:15 CD5-04 Comment Cement Stages Stage#1 Description Objective 'Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Isolate shoe to top of 10,425.0 11,836.7 Yes Yes Yes Cement HRZ Q Pump[nit(bbllm...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 5 410.0 900.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,425.0 11,836.7 442 G 88.1 Yield(fe/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 5.00 1,084.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Isolate Qannik 4,728.0 5,728.0 Yes Yes No Cement Q Pump[nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 5 290.0 1,190.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,727.0 5,727.0 442 G 91.4 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.00 534.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/8/2015 i • Conversion Western North Slope CD5 Alpine West Pad CD5-04 Definitive Survey Report 24 June, 2015 � sl 7,14 • Schlumberger 41) Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-04 Well Position +N/-S 0.00 usft Northing: 5,965,899.27 usft Latitude: 70°18'50.193 N +El-W 0.00 usft Easting: 349,481.63 usft Longitude: 151°13'11.738 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.20 usft Wellbore CD5-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 5/20/2015 18.21 80 77 57,530 Design CD5-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.94 Vertical Section: Depth From(TVD) +N/S +E/-W Direction (usft) (usft); (usft) (0) 0.00 0.00 0.00 333.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 86.20 455.80 CD5-04 Svy1 GYD-GC-MS(CD5-04) GYD-GC-MS Gyrodata gyrocompassing m/s 6/5/2015 5:08:0 475.19 2,271.52 CD5-04 Svy2 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/5/2015 5:14:0 2,365.41 7,919.48 CD5-04 Svy3 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:44: 7,977.75 11,787.61 CD5-04 Svy4 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:46: 11,858.82 18,818.34 CD5-04 Svy5 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:47: 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) (°/100') (ft) Survey Tool Name 36.94 0.00 0.00 36.94 -34.20 0.00 0.00 5,965,899.27 349,481 63 0.00 0.00 UNDEFINED 86.18 0.14 301.48 86.18 15.04 0.03 -0.05 5,965,899.31 349,481.58 0.28 0.05 GYD-GC-MS(1) 178.70 0.21 264.50 178.70 107.56 0.07 -0.32 5,965,899.35 349,481.31 0.14 0.21 GYD-GC-MS(1) 272.29 0.28 243.14 272.29 201.15 -0.05 -0.69 5,965,899.24 349,480.93 0.12 0.27 GYD-GC-MS(1) 364.06 0.16 217.42 364.06 292.92 -0.25 -0.97 5,965,899.04 349,480.65 0.17 0.22 GYD-GC-MS(1) 455.83 0.26 184.48 455.83 384.69 -0.56 -1.06 5,965,898.74 349,480.55 0.17 -0.01 GYD-GC-MS(1) 475.19 0.50 168.89 475.19 404.05 -0.68 -1.05 5,965,898.61 349,480.56 1.34 -0.13 MWD+IFR-AK-CAZ-SC(2) 567.22 1.59 154.88 567.20 496.06 -2.23 -0.43 5,965,897.05 349,481.15 1.21 -1.80 MWD+IFR-AK-CAZ-SC(2) 616.54 2.43 153.55 616.49 545.35 -3.79 0.33 5,965,895.48 349,481.88 1.71 -3.52 MWD+IFR-AK-CAZ-SC(2) 657.80 2.36 149.11 657.71 586.57 -5.30 1.15 5,965,893.95 349,482.67 0.48 -5.25 MWD+IFR-AK-CAZ-SC(2) I 6/24/2015 3:28.27PM Page 2 COMPASS 5000.1 Build 65 iSchlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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) (011001 (ft) Survey Tool Name 752.05 4.17 142.81 751.81 680.67 -9.70 4.22 5,965,889.49 349,485.65 1.95 -10.56 MWD+IFR-AK-CAZ-SC(2) 846.97 6.25 144.42 846.33 775.19 -16.65 9.31 5,965,882.44 349,490.60 2.20 -19.06 MWD+IFR-AK-CAZ-SC(2) 940.06 8.84 143.08 938.61 867.47 -26.49 16.56 5,965,872.46 349,497.65 2.79 -31.12 MWD+IFR-AK-CAZ-SC(2) 1,035.43 10.56 144.87 1,032.61 961.47 -39.50 25.99 5,965,859.26 349,506.82 1.83 -46.99 MWD+IFR-AK-CAZ-SC(2) 1,128.45 12.03 146.30 1,123.83 1,052.69 -54.54 36,27 5,965,844.03 349,516.80 1.61 -65.06 MWD+IFR-AK-CAZSC(2) 1,221.31 13.76 147.05 1,214.34 1,143.20 -71.85 47.65 5,965,826.48 349,527.82 1.87 -85.66 MWD+IFR-AK-CAZ-SC(2) 1,316.18 16.58 145.80 1,305.90 1,234.76 -92.52 61.40 5,965,805.55 349,541.15 2.99 -110.31 MVVD+IFR-AK-CAZ-SC(2) 1,412.36 17.81 144.07 1,397.78 1,326.64 -115.78 77.74 5,965,781.96 349,557.03 1.38 -138.46 MWD+IFR-AK-CAZ-SC(2) 1,507.01 20.62 144.14 1,487.14 1,416.00 -141.02 96.00 5,965,756.37 349,574.78 2.97 -169.23 MWD+IFR-AK-CAZ-SC(2) 1,601.06 22.39 145.61 1,574.64 1,503.50 -169.22 115.82 5,965,727.78 349,594.03 1.97 -203.36 MWD+IFR-AK-CAZ-SC(2) 1,693.77 22.90 138.99 1,660.22 1,589.08 -197.41 137.64 5,965,699.16 349,615.27 2.80 -238.38 MWD+IFR-AK-CAZ-SC(2) 1,785.12 23.45 132.45 1,744.21 1,673.07 -223.09 162.72 5,965,672.98 349,639.83 2.88 -272.65 MWD+IFR-AK-CAZ-SC(2) 1,878.68 25.53 125.78 1,829.37 1,758.23 -247.45 192.82 5,965,648.02 349,669.43 3.70 -308.02 MWD+IFR-AK-CAZ-SC(2) 1,973.10 24.42 115.02 1,915.00 1,843.86 -267.61 227.03 5,965,627.18 349,703.23 4.95 -341.52 MWD+IFR-AK-CAZ-SC(2) 2,067.66 25.09 106.10 2,000.90 1,929.76 -281.45 264.02 5,965,612.61 349,739.93 4.01 -370.63 MWD+IFR-AK-CAZ-SC(2) 2,162.23 26.87 99.91 2,085.93 2,014.79 -290.69 304.35 5,965,602.57 349,780.06 3.43 -397.17 MWD+IFR-AK-CAZ-SC(2) 2,259.78 27.98 94.31 2,172.53 2,101.39 -296.20 348.89 5,965,596.16 349,824.48 2.88 -422.31 MWD+IFR-AK-CAZ-SC(2) 2,271.52 28.24 93.84 2,182.88 2,111.74 -296.60 354.41 5,965,595 66 349,829.99 2.91 -425.17 MWD+IFR-AK-CAZ-SC(2) 2.327.03 29.87 91.61 2,231 41 2,160.27 -297.86 381.33 5,965,593.85 349,856.88 3.53 -438.52 1;;;Gi C1h1iy.. 10-3/4"x 13-1/2" 2,365.41 31.02 90.20 2,264.49 2,193.35 -298.17 400.77 5,965,593.15 349,876.31 3.53 -447.62 MWD+IFR-AK-CAZ-SC(3) 2,424.38 32.03 91.55 2,314.76 2,243.62 -298.64 431.60 5,965,592.06 349,907.12 2.09 -462.04 MWD+IFR-AK-CAZ-SC(3) 2,517.81 34.80 89.04 2,392.74 2,321.60 -298.87 483.04 5,965,590.81 349,958.54 3.31 -485.59 MWD+IFR-AK-CAZ-SC(3) 2,566.25 36.22 84.71 2,432.18 2,361.04 -297.32 511.12 5,965,591.79 349,986.64 5.96 -496.95 MWD+IFR-AK-CAZ-SC(3) 2,613.31 37.63 80.97 2,469.80 2,398.66 -293.78 539.15 5,965,594.77 350,014.74 5.64 -506.53 MWD+IFR-AK-CAZ-SC(3) 2,660.42 38.20 77.76 2,506.97 2,435.83 -288.43 567.60 5,965,599.54 350,043.28 4.36 -514.68 MWD+IFR-AK-CAZ-SC(3) 2,704.07 39.18 72.09 2,541.05 2,469.91 -281.33 593.91 5,965,606.12 350,069.74 8.42 -520.30 MWD+IFR-AK-CAZ-SC(3) 2,751.19 40.52 71.21 2,577.23 2,506.09 -271.82 622.57 5,965,615.05 350,098.58 3.09 -524.83 MWD+IFR-AK-CAZ-SC(3) 2,798.98 42.50 72.29 2,613.02 2,541.88 -261.91 652.65 5,965,624.35 350,128.85 4.41 -529.66 MWD+IFR-AK-CAZ-SC(3) 2,895.36 45.18 73.51 2,682.53 2,611.39 -242.30 716.45 5,965,642.68 350,193.02 2.92 -541.15 MWD+IFR-AK-CAZ-SC(3) 2,988.21 48.44 73.77 2,746.07 2,674.93 -223.24 781.40 5,965,660.44 350,258.34 3.52 -553.65 MWD+IFR-AK-CAZ-SC(3) 3,082.85 51.77 73.58 2,806.76 2,735.62 -202.83 851.07 5,965,679.44 350,328.40 3.52 -567.10 MWD+IFR-AK-CAZ-SC(3) 3,178.61 52.15 73.25 2,865.77 2,794.63 -181.30 923.35 5,965,699.52 350,401.09 0.48 -580.73 MWD+IFR-AK-CAZ-SC(3) 3,273.43 52.23 73.42 2,923.90 2,852.76 -159.82 995.12 5,965,719.55 350,473.27 0.16 -594.17 MWD+IFR-AK-CAZ-SC(3) 3,367.32 52.15 71.32 2,981.46 2,910.32 -137.35 1,065.80 5,965,740.59 350,544.38 1.77 -606.25 MWD+IFR-AK-CAZ-SC(3) 3,462.18 52.24 72.67 3,039.61 2,968.47 -114.19 1,137.08 5,965,762.32 350,616.10 1.13 -617.97 MWD+IFR-AK-CAZ-SC(3) 3,555.95 54.07 73.78 3,095.84 3,024.70 -92.54 1,208.93 5,965,782.53 350,688.36 2.17 -631.29 MWD+IFR-AK-CAZ-SC(3) 3,644.87 55.06 74.48 3,147.39 3,076.25 -72.73 1,278.61 5,965,800.93 350,758.43 1.28 -645.28 MWD+IFR-AK-CAZ-SC(3) 3,739.15 55.55 72.80 3,201.06 3,129.92 -50.89 1,352.98 5,965,821.27 350,833.22 1.55 -659.59 MWD+IFR-AK-CAZ-SC(3) 3,833.30 55.54 70.94 3,254.33 3,183.19 -26.74 1,426.76 5,965,843.94 350,907.46 1.63 -671.56 MWD+IFR-AK-CAZ-SC(3) 3,926.57 55.28 70.04 3,307.28 3,236.14 -1.10 1,499.13 5,965,868.13 350,980.32 0.84 -681.57 MWD+IFR-AK-CAZ-SC(3) 6/24/2015 3:28:27PM Page 3 COMPASS 5000.1 Build 65 III Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94©71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 Database: OAKEDMP2 Survey 1 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 4,020.60 55.52 68.48 3,360.67 3,289.53 26.31 1,571 51 5,965,894.08 351,053.23 1.39 -690.01 MWD+IFR-AK-CAZ-SC(3) 4,115.00 55.30 67.23 3,414.26 3,343.12 55.60 1,643.49 5,965,921.92 351,125.78 1.11 -696.59 MWD+IFR-AK-CAZ-SC(3) 4,208.62 55.05 67.13 3,467.73 3,396.59 85.41 1,714.33 5,965,950.30 351,197.19 0.28 -702.19 MVVD+IFR-AK-CAZ-SC(3) 4,303.28 54.87 67.95 3,522.08 3,450.94 115.02 1,785.95 5,965,978.46 351,269.39 0.73 -708.32 MWD+IFR-AK-CAZ-SC(3) 4,397.20 54.82 68.78 3,576.16 3,505.02 143.33 1,857.33 5,966,005.33 351,341.32 0.72 -715.50 MWD+IFR-AK-CAZ-SC(3) 4,491.83 54.83 69.63 3,630.67 3,559.53 170.79 1,929.64 5,966,031.34 351,414.16 0.73 -723.86 MWD+IFR-AK-CAZ-SC(3) 4,586.53 55.16 71.83 3,685.00 3,613.86 196.39 2,002.86 5,966,055.46 351,487.87 1.93 -734.30 MWD+IFR-AK-CAZ-SC(3) 4,680.72 55.49 73.71 3,738.59 3,667.45 219.33 2,076.84 5,966,076.91 351,562.29 1.68 -747.44 MWD+IFR-AK-CAZ-SC(3) 4,775.17 55.38 73.00 3,792.18 3,721.04 241.60 2,151.35 5,966,097.69 351,637.23 0.63 -761.42 MVVD+IFR-AK-CAZ-SC(3) 4,868.74 55.44 72.15 3,845.30 3,774.16 264.67 2,224.85 5,966,119.27 351,711.17 0.75 -774.24 MWD+IFR-AK-CAZ-SC(3) 4,962.98 55.58 73.26 3,898.66 3,827.52 287.76 2,299.01 5,966,140.87 351,785.77 0.98 -787.33 MWD+IFR-AK-CAZ-SC(3) 5,057.92 55.16 68.66 3,952.63 3,881.49 313.23 2,372.83 5,966,164.85 351,860.08 4.01 -798.15 MWD+IFR-AK-CAZ-SC(3) 5,151.05 55.08 66.11 4,005.90 3,934.76 342.60 2,443.34 5,966,192.80 351,931.16 2.25 -803.99 MWD+IFR-AK-CAZ-SC(3) 5,246.55 55.14 67.14 4,060.52 3,989.38 373.68 2,515.24 5,966,222.43 352,003.67 0.89 -808.95 MWD+IFR-AK-CAZ-SC(3) 5,340.35 54.99 69.39 4,114.24 4,043.10 402.15 2,586.67 5,966,249.47 352,075.64 1.97 -816.00 MWD+IFR-AK-CAZ-SC(3) 5,434.22 55.03 68.24 4,168.07 4,096.93 429.95 2,658.37 5,966,275.81 352,147.88 1.00 -823.79 MWD+IFR-AK-CAZ-SC(3) 5,528.02 54.99 70.41 4,221.86 4,150.72 457.07 2,730.26 5,966,301.49 352,220.30 1.90 -832.26 MWD+IFR-AK-CAZ-SC(3) 5,623.34 54.90 73.38 4,276.62 4,205.48 481.32 2,804.41 5,966,324.25 352,294.91 2.55 -844.32 MWD+IFR-AK-CAZ-SC(3) 5,716.54 55.05 73.05 4,330.11 4,258.97 503.36 2,877.48 5,966,344.81 352,368.41 0.33 -857.85 MWD+IFR-AK-CAZ-SC(3) 5,811.87 55.03 71.28 4,384.74 4,313.60 527.29 2,951.85 5,966,367.24 352,443.23 1.52 -870.30 MWD+IFR-AK-CAZ-SC(3) 5,906.61 54.91 72.00 4,439.12 4,367.98 551.72 3,025.48 5,966,390.20 352,517.33 0.64 -881.95 MWD+IFR-AK-CAZ-SC(3) 6,001.11 54.89 73.72 4,493.46 4,422.32 574.51 3,099.35 5,966,411.50 352,591.64 1.49 -895.19 MWD+IFR-AK-CAZ-SC(3) 6,095.27 55.05 75.32 4,547.51 4,476.37 595.08 3,173.66 5,966,430.58 352,666.34 1.40 -910.59 MWD+IFR-AK-CAZ-SC(3) 6,189.23 55.54 74.06 4,601.01 4,529.87 615.48 3,248.16 5,966,449.48 352,741.23 1.22 -926.23 MWD+IFR-AK-CAZ-SC(3) 6,282.38 55.58 71.54 4,653.70 4,582.56 638.20 3,321.53 5,966,470.71 352,815.04 2.23 -939.31 MWD+IFR-AK-CAZ-SC(3) 6,375.92 55.54 70.18 4,706.60 4,635.46 663.49 3,394.41 5,966,494.54 352,888.40 1.20 -949.86 MWD+IFR-AK-CAZ-SC(3) 6,470.15 55.25 69.37 4,760.11 4,688.97 690.30 3,467.19 5,966,519.88 352,961.70 0.77 -959.01 MWD+IFR-AK-CAZ-SC(3) 6,564.26 54.90 70.24 4,813.99 4,742.85 716.94 3,539.60 5,966,545.06 353,034.63 0.84 -968.15 MWD+IFR-AK-CAZ-SC(3) 6,658.47 54.95 71.11 4,868.13 4,796.99 742.45 3,612.36 5,966,569.11 353,107.87 0.76 -978.45 MWD+IFR-AK-CAZ-SC(3) 6,751.57 55.04 73.02 4,921.54 4,850.40 765.93 3,684.91 5,966,591.13 353,180.87 1.68 -990.46 MWD+IFR-AK-CAZ-SC(3) 6,846.20 54.91 70.78 4,975.86 4,904.72 790.00 3,758.56 5,966,613.72 353,254.98 1.94 -1,002.45 MWD+IFR-AK-CAZ-SC(3) 6,942.62 55.02 70.56 5,031.21 4,960.07 816.14 3,833.06 5,966,638.35 353,329.99 0.22 -1,012.99 MWD+IFR-AK-CAZ-SC(3) 7,037.00 54.90 68.98 5,085.40 5,014.26 842.86 3,905.56 5,966,663.61 353,403.00 1.38 -1,022.10 MWD+IFR-AK-CAZ-SC(3) 7,130.46 54.91 68.23 5,139.13 5,067.99 870.75 3,976.76 5,966,690.07 353,474.74 0.66 -1,029.57 MWD+IFR-AK-CAZ-SC(3) 7,224.78 55.46 70.84 5,192.99 5,121.85 897.82 4,049.30 5,966,715.67 353,547.81 2.35 -1,038.38 MWD+IFR-AK-CAZ-SC(3) 7,319.18 55.38 69.29 5,246.57 5,175.43 924.31 4,122.36 5,966,740.70 353,621.38 1.35 -1,047.94 MWD+IFR-AK-CAZ-SC(3) 7,414.45 55.46 70.53 5,300.64 5,229.50 951.26 4,196.02 5,966,766.16 353,695.56 1.07 -1,057.38 MWD+IFR-AK-CAZ-SC(3) 7,507.70 55.42 71.48 5,353.54 5,282.40 976.25 4,268.64 5,966,789.69 353,768.66 0.84 -1,068.07 MWD+IFR-AK-CAZ-SC(3) 7,602.40 55.39 71.68 5,407.31 5,336.17 1,000.88 4,342.60 5,966,812.83 353,843.09 0.18 -1,079.70 MWD+IFR-AK-CAZ-SC(3) 7,696.71 55.46 71.39 5,460.83 5,389.69 1,025.48 4,416.25 5,966,835.94 353,917.22 0.26 -1,091.23 MWD+IFR-AK-CAZ-SC(3) 6/24/2015 3:28:27PM Page 4 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 Database: OAKEDMP2 Survey 11PlN 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 7,79069 55.25 71.61 5,514.25 5,443.11 1,050.01 4,489.57 5,966,859.00 353,991 01 0.29 -1,102.66 MWD+IFR-AK-CAZ-SC(3) 7,883.95 54.92 71.33 5,567.63 5,496.49 1,074.31 4,562.08 5,966,881.84 354,063.99 0.43 -1,113.92 MWD+IFR-AK-CAZ-SC(3) 7,919.48 54.48 71.01 5,588.16 5,517.02 1,083.67 4,589.53 5,966,890.65 354,091.61 1.44 -1,118.04 MWD+IFR-AK-CAZ-SC(3) 7,977.75 54.20 70.27 5,622.13 5,550.99 1,099.37 4,634.19 5,966,905.44 354,136.58 1.14 -1,124.34 MWD+IFR-AK-CAZ-SC(4) 8,072.31 55.16 70.84 5,676.80 5,605.66 1,125.05 4,706.95 5,966,929.66 354,209.83 1.13 -1,134.48 MWD+IFR-AK-CAZ-SC(4) 8,167.35 55.57 71.46 5,730.82 5,659.68 1,150.31 4,780.95 5,966,953.43 354,284.32 0.69 -1,145.57 MWD+IFR-AK-CAZ-SC(4) 8,261.96 55.25 70.41 5,784.53 5,713.39 1,175.75 4,854.56 5,966,977.39 354,358.42 0.97 -1,156.32 MWD+IFR-AK-CAZ-SC(4) 8,356.04 55.14 70,51 5,838.23 5,767.09 1,201.59 4,927.36 5,967,001.76 354,431.72 0.15 -1,166.35 MWD+IFR-AK-CAZ-SC(4) 8,448.58 55.17 69.92 5,891.10 5,819.96 1,227.30 4,998.83 5,967,026.03 354,503.68 0.52 -1,175.89 MWD+IFR-AK-CAZ-SC(4) 8,543.23 55.58 69.29 5,944.88 5,873.74 1,254.44 5,071.83 5,967,051.70 354,577.21 0.70 -1,184.85 MWD+IFR-AK-CAZ-SC(4) 8,637.60 55.67 68.33 5,998.17 5,927.03 1,282.59 5,144.45 5,967,078.39 354,650.37 0.85 -1,192.73 MWD+IFR-AK-CAZ-SC(4) 8,731.78 55.41 68.04 6,051.46 5,980.32 1,311.45 5,216.54 5,967,105.80 354,723.02 0.38 -1,199.75 MWD+IFR-AK-CAZ-SC(4) 8,826.39 55.17 67.93 6,105.33 6,034.19 1,340.60 5,288.65 5,967,133.50 354,795,69 0.27 -1,206.51 MWD+IFR-AK-CAZ-SC(4) 8,921.26 55.23 68.17 6,159.47 6,088.33 1,369.72 5,360.90 5,967,161.16 354,868.51 0.22 -1,213.37 MWD+IFR-AK-CAZ-SC(4) 9,015.29 55.28 69.33 6,213.07 6,141.93 1,397.73 5,432.91 5,967,187.71 354,941.06 1.02 -1,221.11 MWD+IFR-AK-CAZ-SC(4) 9,106.95 55.02 69.51 6,265.44 6,194.30 1,424.17 5,503.33 5,967,212.73 355,011.99 0.33 -1,229.52 MWD+IFR-AK-CAZ-SC(4) 9,203.16 55.16 66.59 6,320.51 6,249.37 1,453.66 5,576.50 5,967,240.75 355,085.73 2.49 -1,236.46 MWD+IFR-AK-CAZ-SC(4) 9,295.27 54.19 63.80 6,373.78 6,302.64 1,485.17 5,644.71 5,967,270.88 355,154.55 2.69 -1,239.35 MWD+IFR-AK-CAZ-SC(4) 9,391.99 54.00 61.89 6,430.50 6,359.36 1,520.92 5,714.41 5,967,305.23 355,224.95 1.61 -1,239.14 MWD+IFR-AK-CAZ-SC(4) 9,486.28 53.84 59.41 6,486.03 6,414.89 1,556.26 5,780.82 5,967,341.23 355,292.09 2.13 -1,236.02 MWD+IFR-AK-CAZ-SC(4) 9,581.07 53.99 55.42 6,541.88 6,470.74 1,599.51 5,845.35 5,967,381.17 355,357.43 3.41 -1,228.56 MWD+IFR-AK-CAZ-SC(4) 9,675.68 54.70 52.05 6,597.04 6,525.90 1,644.98 5,907.31 5,967,425.38 355,420.28 2.99 -1,216.18 MWD+IFR-AK-CAZ-SC(4) 9,768.98 55.10 48.51 6,650.70 6,579.56 1,693.75 5,966.00 5,967,472.97 355,479.94 3.13 -1,199.37 MWD+IFR-AK-CAZ-SC(4) 9,863.74 55.88 43.78 6,704.40 6,633.26 1,747.83 6,022.27 5,967,525.91 355,537.28 4.19 -1,176.72 MWD+IFR-AK-CAZ-SC(4) 9,958.90 56.08 38.62 6,757.67 6,686.53 1,807.15 6,074.19 5,967,584.17 355,590.37 4.50 -1,147.44 MWD+IFR-AK-CAZ-SC(4) 10,052.51 56.29 31.92 6,809.80 6,738.66 1,870.59 6,119.06 5,967,646.69 355,636.49 5.95 -1,111.28 MWD+IFR-AK-CAZ-SC(4) 10,100.29 56.34 29.62 6,836.31 6,765.17 1,904.75 6,139.39 5,967,680.43 355,657.51 4.01 -1,090.08 MWD+IFR-AK-CAZ-SC(4) 10,146.62 56.31 27.41 6,862.00 6,790.86 1,938.62 6,157.80 5,967,713.93 355,676.59 3.97 -1,068.26 MWD+IFR-AK-CAZ-SC(4) 10,241.44 55.89 22.96 6,914.90 6,843.76 2,009.81 6,191.28 5,967,784.43 355,711.49 3.92 -1,020.03 MWD+IFR-AK-CAZ-SC(4) 10,335.09 56.34 18.23 6,967.14 6,896.00 2,082.56 6,218.61 5,967,856.60 355,740.27 4.22 -967.62 MWD+IFR-AK-CAZ-SC(4) 10,428.10 57.43 15.85 7,017.95 6,946.81 2,157.03 6,241.42 5,967,930.60 355,764.57 2.44 -911.62 MWD+IFR-AK-CAZ-SC(4) 10,522.29 59.40 10.82 7,067.31 6,996.17 2,235.07 6,259.88 5,968,008.25 355,784.59 5.01 -850.46 MWD+IFR-AK-CAZ-SC(4) 10,617.45 59.63 8.04 7,115.59 7,044.45 2,315.96 6,273.32 5,968,088.84 355,799.64 2.53 -784.49 MWD+IFR-AK-CAZ-SC(4) 10,712.08 60.82 5.04 7,162.59 7,091.45 2,397.55 6,282.66 5,968,170.22 355,810.61 3.03 -716.04 MW1J+IFR-AK-CAZ-SC(4) 10,810.41 63.06 2.40 7,208.85 7,137.71 2,484.12 6,288.26 5,968,256.66 355,817.95 3.29 -641.44 MWD+IFR-AK-CAZ-SC(4) 10,900.70 65.52 359.78 7,248.02 7,176.88 2,565.44 6,289.79 5,968,337.93 355,821.11 3.78 -569.68 MWD+IFR-AK-CAZ-SC(4) 10,993.06 68.91 357.58 7,283.79 7,212.65 2,650.55 6,287.81 5,968,423.06 355,820.84 4.28 -492.95 MWD+IFR-AK-CAZ-SC(4) 11,086.91 72.16 355.95 7,315.06 7,243.92 2,738.88 6,282.81 5,968,511.46 355,817.60 3.83 -411.97 MWD+IFR-AK-CAZ-SC(4) 11,181.88 75.13 353.64 7,341.80 7,270.66 2,829.61 6,274.53 5,968,602.33 355,811.15 3.90 -327.37 MWD+IFR-AK-CAZ-SC(4) 11,230.57 76.05 351.23 7,353.92 7,282.78 2,876.36 6,268.32 5,968,649.19 355,805.87 5.15 -282.90 MWD+IFR-AK-CAZ-SC(4) 6/24/2015 3:28:27PM Page 5 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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) ("1100) (ft) Survey Tool Name 11,274 75 76.22 348.91 7,364.51 7,293.37 2,918.60 6,260.92 5,968,691.57 355,799.33 5.11 -241.90 MWD+IFR-AK-CAZ-SC(4) 11,325.21 76.04 346.16 7,376.61 7,305.47 2,966.43 6,250.35 5,968,739.60 355,789.72 5.30 -194.49 MWD+IFR-AK-CAZ-SC(4) 11,370.66 76.13 344.15 7,387.54 7,316.40 3,009.07 6,239.05 5,968,782.46 355,779.27 4.30 -151.36 MWD+IFR-AK-CAZ-SC(4) 11,464.46 78.20 340.06 7,408.38 7,337.24 3,096.08 6,210.94 5,968,870.00 355,752.92 4.79 -61.08 MWD+IFR-AK-CAZ-SC(4) 11,559.02 79.52 338.43 7,426.65 7,355.51 3,182.83 6,178.06 5,968,957.38 355,721.79 2.19 31.14 MWD+IFR-AK-CAZ-SC(4) 11,653.18 79.94 338.00 7,443.44 7,372.30 3,268.86 6,143.67 5,969,044.08 355,689.13 0.63 123.41 MWD+IFR-AK-CAZ-SC(4) 11,746.76 80.47 337.23 7,459.36 7,388.22 3,354.13 6,108.56 5,969,130.03 355,655.74 0.99 215.32 MWD+IFR-AK-CAZ-SC(4) 11,787.61 80.57 336.85 7,466.09 7,394.95 3,391.23 6,092.84 5,969,167.43 355,640.77 0.95 255.51 MWD+IFR-AK-CAZ-SC(4) 11,836.73 81.62 338.28 7,473.69 7,402.55 3,436.08 6,074.32 5,969,212.65 355,623.15 3.59 303.89 IciikWitilrlot5V 7-5/8"x 9-7/8"by 11" 11,858.82 82.10 338.92 7,476.82 7,405.68 3,456.44 6,066.34 5,969,233.16 355,615.58 3.59 325.65 MWD+IFR-AK-CAZ-SC(5) 11,954.94 85.95 338.44 7,486.82 7,415.68 3,545.48 6,031.59 5,969,322.87 355,582.63 4.04 420.76 MWD+IFR-AK-CAZ-SC(5) 12,003.28 87.53 337.43 7,489.57 7,418.43 3,590.20 6,013.46 5,969,367.95 355,565.40 3.88 468.84 MWD+IFR-AK-CAZ-SC(5) 12,050.62 88.99 333.77 7,491.01 7,419.87 3,633.29 5,993.92 5,969,411.41 355,546.72 8.32 516.10 MWD+IFR-AK-CAZ-SC(5) 12,096.96 90.39 336.08 7,491.26 7,420.12 3,675.25 5,974.28 5,969,453.76 355,527.93 5.83 562.41 MWD+IFR-AK-CAZ-SC(5) 12,144.17 91.65 332.36 7,490.42 7,419.28 3,717.75 5,953.75 5,969,496.66 355,508.26 8.32 609.59 MWD+IFR-AK-CAZ-SC(5) 12,240.10 92.69 332.64 7,486.78 7,415.64 3,802.78 5,909.49 5,969,582.55 355,465.72 1.12 705.45 MWD+IFR-AK-CAZ-SC(5) 12,335.16 92.85 331.13 7,482.19 7,411.05 3,886.52 5,864.75 5,969,667.17 355,422.67 1.60 800.38 MWD+IFR-AK-CAZ-SC(5) 12,430.89 93.07 328.79 7,477.25 7,406.11 3,969.28 5,816.89 5,969,750.86 355,376.48 2.45 895.84 MWD+IFR-AK-CAZ-SC(5) 12,526.15 91.39 329.27 7,473.54 7,402.40 4,050.89 5,767.91 5,969,833.43 355,329.15 1.83 990.79 MWD+IFR-AK-CAZ-SC(5) 12,620.63 90.82 328.46 7,471.72 7,400.58 4,131.75 5,719.07 5,969,915.24 355,281.94 1.05 1,085.01 MWD+IFR-AK-CAZ-SC(5) 12,716.49 90.27 328.39 7,470.81 7,399.67 4,213.41 5,668.88 5,969,997.89 355,233.40 0.58 1,180.56 MWD+1FR-AK-CAZ-SC(5) 12,811.66 90.44 327.84 7,470.22 7,399.08 4,294.22 5,618.61 5,970,079.68 355,184.77 0.60 1,275.38 MWD+IFR-AK-CAZ-SC(5) 12,907.34 90.31 328.78 7,469.59 7,398.45 4,375.63 5,568.35 5,970,162.08 355,136.15 0.99 1,370.74 MWD+IFR-AK-CAZ-SC(5) 13,002.43 90.34 329.29 7,469.05 7,397.91 4,457.17 5,519.42 5,970,244.58 355,088.88 0.54 1,465.60 MWD+IFR-AK-CAZ-SC(5) 13,097.19 90.38 329.20 7,468.46 7,397.32 4,538.60 5,470.97 5,970,326.96 355,042.07 0.10 1,560.15 MWD+IFR-AK-CAZ-SC(5) 13,192.34 90.34 330.04 7,467.86 7,396.72 4,620.68 5,422.85 5,970,409.98 354,995.61 0.88 1,655.13 MWD+IFR-AK-CAZ-SC(5) 13,287.66 90.31 329.15 7,467.32 7,396.18 4,702.89 5,374.61 5,970,493.13 354,949.03 0.93 1,750.28 MWD+IFR-AK-CAZ-SC(5) 13,383.21 90.27 328.83 7,466.83 7,395.69 4,784.78 5,325.38 5,970,575.99 354,901.46 0.34 1,845.60 MWD+IFR-AK-CAZ-SC(5) 13,478.68 90.45 328.75 7,466.23 7,395.09 4,866.43 5,275.91 5,970,658.61 354,853.64 0.21 1,940.81 MWD+IFR-AK-CAZ-SC(5) 13,574.78 90.41 327.97 7,465.51 7,394.37 4,948.25 5,225.50 5,970,741.41 354,804.88 0.81 2,036.59 MWD+IFR-AK-CAZ-SC(5) 13,670.67 90.17 326.70 7,465.03 7,393.89 5,028.97 5,173.75 5,970,823.15 354,754.76 1.35 2,132.01 MWD+IFR-AK-CAZ-SC(5) 13,765.05 89.83 325.11 7,465.03 7,393.89 5,107.12 5,120.85 5,970,902.34 354,703.44 1.72 2,225.66 MWD+IFR-AK-CAZ-SC(5) 13,861.43 88.85 324.58 7,466.14 7,395.00 5,185.92 5,065.36 5,970,982.23 354,649.54 1.16 2,321.06 MWD+IFR-AK-CAZ-SC(5) 13,956.92 89.16 323.39 7,467.80 7,396.66 5,263.14 5,009.22 5,971,060.55 354,594.97 1.29 2,415.36 MWD+IFR-AK-CAZ-SC(5) 14,052.20 87.86 323.96 7,470.27 7,399.13 5,339.88 4,952.80 5,971,138.40 354,540.10 1.49 2,509.34 MWD+IFR-AK-CAZ-SC(5) 14,146.65 88.07 324.27 7,473.63 7,402.49 5,416.35 4,897.47 5,971,215.96 354,486.32 0.40 2,602.60 MWD+IFR-AK-CAZ-SC(5) 14,242.02 89.43 323.66 7,475.71 7,404.57 5,493.45 4,841.38 5,971,294.17 354,431.79 1.56 2,696.76 MWD+IFR-AK-CAZ-SC(5) 14,337.84 89.49 325.34 7,476.61 7,405.47 5,571.45 4,785.74 5,971,373.26 354,377.73 1.75 2,791.52 MWD+IFR-AK-CAZ-SC(5) 14,433.63 89.45 325.23 7,477.50 7,406.36 5,650.19 4,731.19 5,971,453.07 354,324.78 0.12 2,886.44 MWD+IFR-AK-CAZ-SC(5) 14,528.60 89.90 324.02 7,478.03 7,406.89 5,727.62 4,676.21 5,971,531.59 354,271.36 1.36 2,980.39 MWD+IFR-AK-CAZ-SC(5) 6/24/2015 3:28:27PM Page 6 COMPASS 5000.1 Build 65 410 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 14,623.53 90.41 325.31 7,477.78 7,406.64 5,805.06 4,621.31 5,971,610.10 354,218.03 1.46 3,074.32 MWD+IFR-AK-CAZ-SC(5) 14,718.57 90.48 326.93 7,477.04 7,405.90 5,883.96 4,568.33 5,971,690.04 354,166.65 1.71 3,168.67 MWD+IFR-AK-CAZ-SC(5) 14,813.45 91.17 327.50 7,475.67 7,404.53 5,963.72 4,516.96 5,971,770.81 354,116.89 0.94 3,263.05 MWD+IFR-AK-CAZ-SC(5) 14,908.17 91.68 328.09 7,473.32 7,402.18 6,043.84 4,466.50 5,971,851.92 354,068.05 0.82 3,357.35 MWD+IFR-AK-CAZ-SC(5) 15,005.03 91.99 329.86 7,470.22 7,399.08 6,126.80 4,416.60 5,971,935.85 354,019.83 1.85 3,453.92 MWD+IFR-AK-CAZ-SC(5) 15,099.85 91.85 331.48 7,467.04 7,395.90 6,209.41 4,370.19 5,972,019.38 353,975.08 1.71 3,548.61 MWD+IFR-AK-CAZ-SC(5) 15,194.76 90.86 330.52 7,464.80 7,393.66 6,292.40 4,324.19 5,972,103.26 353,930.75 1.45 3,643.43 MWD+IFR-AK-CAZ-SC(5) 15,289.95 90.21 331.00 7,463.91 7,392.77 6,375.46 4,277.69 5,972,187.23 353,885.94 0.85 3,738.54 MWD+IFR-AK-CAZ-SC(5) 15,385.57 89.90 332.19 7,463.81 7,392.67 6,459.56 4,232.21 5,972,272.22 353,842.15 1.29 3,834.13 MWD+IFR-AK-CAZ-SC(5) 15,481.41 90.00 334.69 7,463.90 7,392.76 6,545.28 4,189.36 5,972,358.78 353,801.03 2.61 3,929.96 MWD+IFR-AK-CAZ-SC(5) 15,577.24 90.27 334.35 7,463.67 7,392.53 6,631.79 4,148.13 5,972,446.09 353,761.55 0.45 4,025.76 MWD+IFR-AK-CAZ-SC(5) 15,672.86 90.24 332.55 7,463.25 7,392.11 6,717.32 4,105.39 5,972,532.45 353,720.54 1.88 4,121.37 MWD+IFR-AK-CAZ-SC(5) 15,767.90 90.07 332.62 7,462.99 7,391.85 6,801.69 4,061.63 5,972,617.67 353,678.48 0.19 4,216.41 MWD+IFR-AK-CAZ-SC(5) 15,863.55 90.07 334.86 7,462.87 7,391.73 6,887.46 4,019.32 5,972,704.27 353,637.90 2.34 4,312.04 MWD+IFR-AK-CAZ-SC(5) 15,959.16 90.07 335.46 7,462.76 7,391.62 6,974.23 3,979.15 5,972,791.82 353,599.48 0.63 4,407.58 MWD+IFR-AK-CAZ-SC(5) 16,053.65 90.55 336.06 7,462.24 7,391.10 7,060.38 3,940.36 5,972,878.73 353,562.43 0.81 4,501.96 MWD+IFR-AK-CAZ-SC(5) 16,149.69 90.86 337.22 7,461.06 7,389.92 7,148.54 3,902.28 5,972,967.63 353,526.13 1.25 4,597.80 MWD+IFR-AK-CAZ-SC(5) 16,244.80 91.24 336.62 7,459.32 7,388.18 7,236.02 3,865.00 5,973,055.83 353,490.61 0.75 4,692.67 MWD+IFR-AK-CAZ-SC(5) 16,339.52 91.00 335.44 7,457.47 7,386.33 7,322.56 3,826.53 5,973,143.11 353,453.89 1.27 4,787.24 MWD+IFR-AK-CAZ-SC(5) 16,435.31 90.93 334.51 7,455.86 7,384.72 7,409.34 3,786.02 5,973,230.68 353,415.12 0.97 4,882.96 MWD+IFR-AK-CAZ-SC(5) 16,530.34 91.17 333.94 7,454.11 7,382.97 7,494.90 3,744.70 5,973,317.05 353,375.53 0.65 4,977.95 MWD+IFR-AK-CAZ-SC(5) 16,624.65 91.03 332.00 7,452.30 7,381.16 7,578.89 3,701.85 5,973,401.87 353,334.38 2.06 5,072.24 MWD+IFR-AK-CAZ-SC(5) 16,719.72 91.62 329.51 7,450.10 7,378.96 7,661.81 3,655.42 5,973,485.70 353,289.62 2.69 5,167.20 MWD+IFR-AK-CAZ-SC(5) 16,815.82 90.93 329.10 7,447.97 7,376.83 7,744.43 3,606.38 5,973,569.28 353,242.25 0.84 5,263.08 MWD+IFR-AK-CAZ-SC(5) 16,911.12 91.10 326.93 7,446.28 7,375.14 7,825.24 3,555.91 5,973,651.08 353,193.41 2.28 5,357.99 MWD+IFR-AK-CAZ-SC(5) 17,006.56 90.53 326.24 7,444.92 7,373.78 7,904.90 3,503.36 5,973,731.77 353,142.47 0.94 5,452.83 MWD+IFR-AK-CAZ-SC(5) 17,103.41 91.28 325.52 7,443.39 7,372.25 7,985.07 3,449.04 5,973,813.01 353,089.78 1.07 5,548.92 MWD+IFR-AK-CAZ-SC(5) 17,197.56 90.99 323.91 7,441.53 7,370.39 8,061.90 3,394.66 5,973,890.91 353,036.96 1.74 5,642.06 MWD+IFR-AK-CAZ-SC(5) 17,292.54 89.94 321.04 7,440.75 7,369.61 8,137.22 3,336.82 5,973,967.36 352,980.64 3.22 5,735.43 MWD+IFR-AK-CAZ-SC(5) 17,387.17 90.17 323.08 7,440.66 7,369.52 8,211.84 3,278.64 5,974,043.14 352,923.97 2.17 5,828.33 MWD+IFR-AK-CAZ-SC(5) 17,482.45 90.24 324.69 7,440.32 7,369.18 8,288.81 3,222.48 5,974,121.21 352,869.37 1.69 5,922.41 MWD+IFR-AK-CAZ-SC(5) 17,576.01 90.17 326.51 7,439.99 7,368.85 8,366.01 3,169.63 5,974,199.44 352,818.08 1.95 6,015.18 MWD+IFR-AK-CAZ-SC(5) 17,672.94 90.55 327.58 7,439.38 7,368.24 8,447.34 3,116.90 5,974,281.81 352,767.00 1.17 6,111.59 MWD+IFR-AK-CAZ-SC(5) 17,768.78 90.27 328.92 7,438.69 7,367.55 8,528.83 3,066.47 5,974,364.29 352,718.22 1.43 6,207.09 MWD+IFR-AK-CAZ-SC(5) 17,864.16 89.85 331.78 7,438.59 7,367.45 8,611.71 3,019.29 5,974,448.09 352,672.71 3.03 6,302.36 MWD+IFR-AK-CAZ-SC(5) 17,960.66 90.77 332.41 7,438.07 7,366.93 8,696.99 2,974.13 5,974,534.25 352,629.27 1.16 6,398.85 MWD+IFR-AK-CAZ-SC(5) 18,055.16 90.65 334.11 7,436.90 7,365.76 8,781.37 2,931.62 5,974,619.47 352,588.46 1.80 6,493.34 MWD+IFR-AK-CAZ-SC(5) 18,150.49 90.58 335.18 7,435.88 7,364.74 8,867.51 2,890.80 5,974,706.40 352,549.38 1.12 6,588.62 MWD+IFR-AK-CAZ-SC(5) 18,245.34 90.96 335.78 7,434.60 7,363.46 8,953.80 2,851.44 5,974,793.45 352,511.76 0.75 6,683.37 MWD+IFR-AK-CAZ-SC(5) 18,340.88 91.13 337.05 7,432.86 7,361.72 9,041.35 2,813.22 5,974,881.74 352,475.31 1.34 6,778.72 MWD+IFR-AK-CAZ-SC(5) 6/24/2015 3:28:27PM Page 7 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 18,436.02 91.24 337.07 7,430.89 7,359.75 9,128.94 2,776.14 5,974,970.05 352,440.00 0.12 6,873.60 MWD+IFR-AK-CAZ-SC(5) 18,531.47 90.55 336.77 7,429.40 7,358.26 9,216.74 2,738.73 5,975,058.58 352,404.35 0.79 6,968.82 MWD+IFR-AK-CAZ-SC(5) 18,627.69 90.55 337.95 7,428.48 7,357.34 9,305.54 2,701.69 5,975,148.10 352,369.11 1.23 7,064.75 MWD+IFR-AK-CAZ-SC(5) 18,721.67 91.26 338.22 7,426.99 7,355.85 9,392.72 2,666.62 5,975,235.95 352,335.79 0.81 7,158.35 MWD+IFR-AK-CAZ-SC(5) 18,818.34 93.05 336.27 7,423.36 7,352.22 9,481.79 2,629.26 5,975,325.75 352,300.23 2.74 7,254.68 MWD+IFR-AK-CAZ-SC(5) 18,863.00 93.05 336 27 7 .`" �(420.98 7,349.84 9,522.62 2,611.32 5.975,366.93 352,283.11 0.00 7,299.20 • 6,4147 4-1/2"x 6-1/2" 18,878.00 93.05 336.27 7,420.18 7,349.04 9,536.33 2,605.29 5,975,380.76 352.277.35 0.00 7,314.16 PROJECTED to TD 6/24/2015 3:28:27PM Page 8 COMPASS 5000.1 Build 65 • • 0 ...\ Cement Detail Report a CD5-04 ConocoPhillips ht:xkm String: Surface Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/24/2015 22:00 5/25/2015 01:30 CD5-04 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Surface Casing Cement Cement 10 3/4"Surface 36.2 2,327.0 No Yes Yes Casing Q Pump!nit(bbl/m...Q Pump Final(bbll...0 Pump Avg(bbl!... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 400.0 900.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 36.2 1,596.0 1,352 DeepCRETE 459.8 Yield(ft%sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.82 0.00 11.00 4.00 50.0 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 1,596.0 2,327.0 291 G 60.6 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.09 0.00 15.80 3.00 500.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/8/2015 I Cement Detail Report 0.2. 0 CD5-04 ConocoPhillips String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/10/2015 20:00 6/11/2015 02:15 CD5-04 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Isolate shoe to top of 10,425.0 11,836.7 Yes Yes Yes Cement HRZ 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) 8 3 5 410.0 900.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 10,425.0 11,836.7 442 G 88.1 Yield(ft'/sack) Mix H2O Ratio(gallsa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 5.00 1,084.0 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Isolate Qannik 4,728.0 5,728.0 Yes Yes No Cement Q Pump mit(bbl/m...0 Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 8 3 5 290.0 1,190.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,727.0 5,727.0 442 G 91.4 Yield(fN/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.00 534.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 7/8/2015 • • 210072 26 007 chiumberger Transmittal#: 01JUL15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery1/«`2015 o K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD5-04 Date Dispatched: 1-Jul-15 Job#: 15AKA0025 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 6 Contents on CD N/A Scope Resistivity 2"MD x x al� �/ � - ----�_- Scope Resistivity 2"TVDLA..lig:. x x Scope Resistivity 2"TVDSS JUL 01 2015 x x Scope Resistivity 5"MD x _ x Scope Resistivity 5"TVD 1 i aG x x Scope Resistivity 5"TVDSS x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 (),2,,,,,za_oz.a.".../) 6Received By: • • 21 5072 16007 JUL 01 2G1i FINAL AOGCC NADConversion Western North Slope CD5 Alpine West Pad CD5-04 Definitive Survey Report 24 June, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD5-04 Well Position +N/-S 0.00 usft Northing: 5,965,899.27 usft Latitude: 70°18'50.193 N +EI-W 0.00 usft Easting: 349,481.63 usft Longitude: 151°13'11.738 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.20 usft Wellbore CD5-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 5/20/2015 18.21 80.77 57,530 Design CD5-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.94 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 333.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 86.20 455.80 CD5-04 Svy1 GYD-GC-MS(CD5-04) GYD-GC-MS Gyrodata gyrocompassing m/s 6/5/2015 5:08:0 475.19 2,271.52 CD5-04 Svy2 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/5/2015 5:14:0 2,365.41 7,919.48 CD5-04 Svy3 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:44: 7,977.75 11,787.61 CD5-04 Svy4 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:46: 11,858.82 18,818.34 CD5-04 Svy5 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:47: 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 36.94 0.00 0.00 36.94 -34.20 0.00 0.00 5,965,899.27 349.481 63 0.00 0.00 UNDEFINED 86.18 0.14 301.48 86.18 15.04 0.03 -0.05 5,965,899.31 349,481.58 0.28 0.05 GYD-GC-MS(1) 178.70 0.21 264.50 178.70 107.56 0.07 -0.32 5,965,899.35 349,481.31 0.14 0.21 GYD-GC-MS(1) 272.29 0.28 243.14 272.29 201.15 -0.05 -0.69 5,965,899.24 349,480.93 0.12 0.27 GYD-GC-MS(1) 364.06 0.16 217.42 364.06 292.92 -0.25 -0.97 5,965,899.04 349,480.65 0.17 0.22 GYD-GC-MS(1) 455.83 0.26 184.48 455.83 384.69 -0.56 -1.06 5,965,898.74 349,480.55 0.17 -0.01 GY0-GC-MS(1) 475.19 0.50 168.89 475.19 404.05 -0.68 -1.05 5,965,898.61 349,480.56 1.34 -0.13 MWD+IFR-AK-CAZ-SC(2) 567.22 1.59 154.88 567.20 496.06 -2.23 -0.43 5,965,897.05 349,481.15 1.21 -1.80 MWD+IFR-AK-CAZ-SC(2) 616.54 2.43 153.55 616.49 545.35 -3.79 0.33 5,965,895.48 349,481.88 1.71 -3.52 MWD+IFR-AK-CAZ-SC(2) 657.80 2.36 149.11 657.71 586.57 -5.30 1.15 5,965,893.95 349,482.67 0.48 -5.25 MWD+IFR-AK-CAZ-SC(2) 6/24/2015 3:28:27PM Page 2 COMPASS 5000.1 Build 65 • • Sc hl urnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 752.05 4.17 142.81 751.81 680.67 -9.70 4.22 5,965,889.49 349.485.65 1.95 -10.56 MWD+IFR-AK-CAZ-SC(2) 846.97 6.25 144.42 846.33 775.19 -16.65 9.31 5,965,882.44 349,490.60 2.20 -19.06 MWD+IFR-AK-CAZ-SC(2) 940.06 8.84 143.08 938.61 867.47 -26.49 16.56 5,965,872.46 349,497.65 2.79 -31.12 MWD+IFR-AK-CAZ-SC(2) 1,035.43 10.56 144.87 1,032.61 961.47 -39.50 25.99 5,965,859.26 349,506.82 1.83 -46.99 MWD+IFR-AK-CAZ-SC(2) 1,128.45 12.03 146.30 1,123.83 1,052.69 -54.54 36.27 5,965,844.03 349,516.80 1.61 -65.06 MWD+IFR-AK-CAZ-SC(2) 1,221.31 13.76 147.05 1,214.34 1,143.20 -71.85 47.65 5,965,826.48 349,527.82 1.87 -85.66 MWD+IFR-AK-CAZ-SC(2) 1,316.18 16.58 145.80 1,305.90 1,234.76 -92.52 61.40 5,965,805.55 349,541.15 2.99 -110.31 MWD+IFR-AK-CAZ-SC(2) 1,412.36 17.81 144.07 1,397.78 1,326.64 -115.78 77.74 5,965,781.96 349,557.03 1.38 -138.46 MWD+IFR-AK-CAZ-SC(2) 1,507.01 20.62 144.14 1,487.14 1,416.00 -141.02 96.00 5,965,756.37 349,574.78 2.97 -169.23 MWD+IFR-AK-CAZ-SC(2) 1,601.06 22.39 145.61 1,574.64 1,503.50 -169.22 115.82 5,965,727.78 349,594.03 1.97 -203.36 MWD+IFR-AK-CAZ-SC(2) 1,693.77 22.90 138.99 1,660.22 1,589.08 -197.41 137.64 5,965,699.16 349,615.27 2.80 -238.38 MWD+IFR-AK-CAZ-SC(2) 1,785.12 23.45 132.45 1,744.21 1,673.07 -223.09 162.72 5,965,672.98 349,639.83 2.88 -272.65 MWD+IFR-AK-CAZ-SC(2) 1,878.68 25.53 125.78 1,829.37 1,758.23 -247.45 192.82 5,965,648.02 349,669.43 3.70 -308.02 MWD+IFR-AK-CAZ-SC(2) 1,973.10 24.42 115.02 1,915.00 1,843.86 -267.61 227.03 5,965,627.18 349,703.23 4.95 -341.52 MWD+IFR-AK-CAZ-SC(2) 2,067.66 25.09 106.10 2,000.90 1,929.76 -281.45 264.02 5,965,612.61 349,739.93 4.01 -370.63 MWD+IFR-AK-CAZ-SC(2) 2,162.23 26.87 99.91 2,085.93 2,014.79 -290.69 304.35 5,965,602.57 349,780.06 3.43 -397.17 MWD+IFR-AK-CAZ-SC(2) 2,259.78 27.98 94.31 2,172.53 2,101.39 -296.20 348.89 5,965,596.16 349,824.48 2.88 -422.31 MWD+IFR-AK-CAZ-SC(2) 2,271.52 28.24 93.84 2,182.88 2,111.74 -296.60 354.41 5,965,595.66 349,829.99 2.91 -425.17 MWD+IFR-AK-CAZ-SC(2) 2,327.03 29.87 91.61 2,231.41 2,160.27 -297.86 381.33 5,965,593.85 349,856.88 3.53 -438.52 NOT an Actual Survey 10-3/4"x 13-1/2" 2,365.41 31.02 90.20 2,264.49 2,193.35 -298.17 400.77 5,965,593.15 349,876.31 3.53 -447.62 MWD+IFR-AK-CAZ-SC(3) 2,424.38 32.03 91.55 2,314.76 2,243.62 -298.64 431.60 5,965,592.06 349,907.12 2.09 -462.04 MWD+IFR-AK-CAZ-SC(3) 2,517.81 34.80 89.04 2,392.74 2,321.60 -298.87 483.04 5,965,590.81 349,958.54 3.31 -485.59 MWD+IFR-AK-CAZ-SC(3) 2,566.25 36.22 84.71 2,432.18 2,361.04 -297.32 511.12 5,965,591.79 349,986.64 5.96 -496.95 MWD+IFR-AK-CAZ-SC(3) 2,613.31 37.63 80.97 2,469.80 2,398.66 -293.78 539.15 5,965,594.77 350,014.74 5.64 -506.53 MWD+IFR-AK-CAZ-SC(3) 2,660.42 38.20 77.76 2,506.97 2,435.83 -288.43 567.60 5,965,599.54 350,043.28 4.36 -514.68 MWD+IFR-AK-CAZ-SC(3) 2,704.07 39.18 72.09 2,541.05 2,469.91 -281.33 593.91 5,965,606.12 350,069.74 8.42 -520.30 MWD+IFR-AK-CAZ-SC(3) 2,751.19 40.52 71.21 2,577.23 2,506.09 -271.82 622.57 5,965,615.05 350,098.58 3.09 -524.83 MWD+IFR-AK-CAZ-SC(3) 2,798.98 42.50 72.29 2,613.02 2,541.88 -261.91 652.65 5,965,624.35 350,128.85 4.41 -529.66 MWD+IFR-AK-CAZ-SC(3) 2,895.36 45.18 73.51 2,682.53 2,611.39 -242.30 716.45 5,965,642.68 350,193.02 2.92 -541.15 MWD+IFR-AK-CAZ-SC(3) 2,988.21 48.44 73.77 2,746.07 2,674.93 -223.24 781.40 5,965,660.44 350,258.34 3.52 -553.65 MWD+IFR-AK-CAZ-SC(3) 3,082.85 51.77 73.58 2,806.76 2,735.62 -202.83 851.07 5,965,679.44 350,328.40 3.52 -567.10 MWD+IFR-AK-CAZ-SC(3) 3,178.61 52.15 73.25 2,865.77 2,794.63 -181.30 923.35 5,965,699.52 350,401.09 0.48 -580.73 MWD+IFR-AK-CAZ-SC(3) 3,273.43 52.23 73.42 2,923.90 2,852.76 -159.82 995.12 5,965,719.55 350,473.27 0.16 -594.17 MWD+IFR-AK-CAZ-SC(3) 3,367.32 52.15 71.32 2,981.46 2,910.32 -137.35 1,065.80 5,965,740.59 350,544.38 1.77 -606.25 MWD+IFR-AK-CAZ-SC(3) 3,462.18 52.24 72.67 3,039.61 2,968.47 -114.19 1,137.08 5,965,762.32 350,616.10 1.13 -617.97 MWD+IFR-AK-CAZ-SC(3) 3,555.95 54.07 73.78 3,095.84 3,024.70 -92.54 1,208.93 5,965,782.53 350,688.36 2.17 -631.29 MWD+IFR-AK-CAZ-SC(3) 3,644.87 55.06 74.48 3,147.39 3,076.25 -72.73 1,278.61 5,965,800.93 350,758.43 1.28 -645.28 MWD+IFR-AK-CAZ-SC(3) 3,739.15 55.55 72.80 3,201.06 3,129.92 -50.89 1,352.98 5,965,821.27 350,833.22 1.55 -659.59 MWD+IFR-AK-CAZ-SC(3) 3,833.30 55.54 70.94 3,254.33 3,183.19 -26.74 1,426.76 5,965,843.94 350,907.46 1.63 -671.56 MWD+IFR-AK-CAZ-SC(3) 3,926.57 55.28 70.04 3,307.28 3,236.14 -1.10 1,499.13 5,965,868.13 350,980.32 0.84 -681.57 MWD+IFR-AK-CAZ-SC(3) 6/24/2015 3:28:27PM Page 3 COMPASS 5000.1 Build 65 Ill • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 4,020.60 55.52 68.48 3,360.67 3,289.53 26.31 1,571.51 5,965,894.08 351,053.23 1.39 -690.01 MWD+IFR-AK-CAZ-SC(3) 4,115.00 55.30 67.23 3,414.26 3,343.12 55.60 1,643.49 5,965,921.92 351,125.78 1.11 -696.59 MWD+IFR-AK-CAZ-SC(3) 4,208.62 55.05 67.13 3,467.73 3,396.59 85.41 1,714.33 5,965,950.30 351,197.19 0.28 -702.19 MWD+IFR-AK-CAZ-SC(3) 4,303.28 54.87 67.95 3,522.08 3,450.94 115.02 1,785.95 5,965,978.46 351,269.39 0.73 -708.32 MWD+IFR-AK-CAZ-SC(3) 4,397.20 54.82 68.78 3,576.16 3,505.02 143.33 1,857.33 5,966,005.33 351,341.32 0.72 -715.50 MWD+IFR-AK-CAZ-SC(3) 4,491.83 54.83 69.63 3,630.67 3,559.53 170.79 1,929.64 5,966,031.34 351,414.16 0.73 -723.86 MWD+IFR-AK-CAZ-SC(3) 4,586.53 55.16 71.83 3,685.00 3,613.86 196.39 2,002.86 5,966,055.46 351,487.87 1.93 -734.30 MWD+IFR-AK-CAZ-SC(3) 4,680.72 55.49 73.71 3,738.59 3,667.45 219.33 2,076.84 5,966,076.91 351,562.29 1.68 -747.44 MWD+IFR-AK-CAZ-SC(3) 4,775.17 55.38 73.00 3,792.18 3,721.04 241.60 2,151.35 5,966,097.69 351,637.23 0.63 -761.42 MWD+IFR-AK-CAZ-SC(3) 4,868.74 55.44 72.15 3,845.30 3,774.16 264.67 2,224.85 5,966,119.27 351,711.17 0.75 -774.24 MWD+IFR-AK-CAZ-SC(3) 4,962.98 55.58 73.26 3,898.66 3,827.52 287.76 2,299.01 5,966,140.87 351,785.77 0.98 -787.33 MWD+IFR-AK-CAZ-SC(3) 5,057.92 55.16 68.66 3,952.63 3,881.49 313.23 2,372.83 5,966,164.85 351,860.08 4.01 -798.15 MWD+IFR-AK-CAZ-SC(3) 5,151.05 55.08 66.11 4,005.90 3,934.76 342.60 2,443.34 5,966,192.80 351,931.16 2.25 -803.99 MWD+IFR-AK-CAZ-SC(3) 5,246.55 55.14 67.14 4,060.52 3,989.38 373.68 2,515.24 5,966,222.43 352,003.67 0.89 -808.95 MWD+IFR-AK-CAZ-SC(3) 5,340.35 54.99 69.39 4,114.24 4,043.10 402.15 2,586.67 5,966,249.47 352,075.64 1.97 -816.00 MWD+IFR-AK-CAZ-SC(3) 5,434.22 55.03 68.24 4,168.07 4,096.93 429.95 2,658.37 5,966,275.81 352,147.88 1.00 -823.79 MWD+IFR-AK-CAZ-SC(3) 5,528.02 54.99 70.41 4,221.86 4,150.72 457.07 2,730.26 5,966,301.49 352,220.30 1.90 -832.26 MWD+IFR-AK-CAZ-SC(3) 5,623.34 54.90 73.38 4,276.62 4,205.48 481.32 2,804.41 5,966,324.25 352,294.91 2.55 -844.32 MWD+IFR-AK-CAZ-SC(3) 5,716.54 55.05 73.05 4,330.11 4,258.97 503.36 2,877.48 5,966,344.81 352,368.41 0.33 -857.85 MWD+IFR-AK-CAZ-SC(3) 5,811.87 55.03 71.28 4,384.74 4,313.60 527.29 2,951.85 5,966,367.24 352,443.23 1.52 -870.30 MWD+IFR-AK-CAZ-SC(3) 5,906.61 54.91 72.00 4,439.12 4,367.98 551.72 3,025.48 5,966,390.20 352,517.33 0.64 -881.95 MWD+IFR-AK-CAZ-SC(3) 6,001.11 54.89 73.72 4,493.46 4,422.32 574.51 3,099.35 5,966,411.50 352,591.64 1.49 -895.19 MWD+IFR-AK-CAZ-SC(3) 6,095.27 55.05 75.32 4,547.51 4,476.37 595.08 3,173.66 5,966,430.58 352,666.34 1.40 -910.59 MWD+IFR-AK-CAZ-SC(3) 6,189.23 55.54 74.06 4,601.01 4,529.87 615.48 3,248.16 5,966,449.48 352,741.23 1.22 -926.23 MWD+IFR-AK-CAZ-SC(3) 6,282.38 55.58 71.54 4,653.70 4,582.56 638.20 3,321.53 5,966,470.71 352,815.04 2.23 -939.31 MWD+IFR-AK-CAZ-SC(3) 6,375.92 55.54 70.18 4,706.60 4,635.46 663.49 3,394.41 5,966,494.54 352,888.40 1.20 -949.86 MWD+IFR-AK-CAZ-SC(3) 6,470.15 55.25 69.37 4,760.11 4,688.97 690.30 3,467.19 5,966,519.88 352,961.70 0.77 -959.01 MWD+IFR-AK-CAZ-SC(3) 6,564.26 54.90 70.24 4,813.99 4,742.85 716.94 3,539.60 5,966,545.06 353,034.63 0.84 -968.15 MWD+IFR-AK-CAZ-SC(3) 6,658.47 54.95 71.11 4,868.13 4,796.99 742.45 3,612.36 5,966,569.11 353,107.87 0.76 -978.45 MWD+IFR-AK-CAZ-SC(3) 6,751.57 55.04 73.02 4,921.54 4,850.40 765.93 3,684.91 5,966,591.13 353,180.87 1.68 -990.46 MWD+IFR-AK-CAZ-SC(3) 6,846.20 54.91 70.78 4,975.86 4,904.72 790.00 3,758.56 5,966,613.72 353,254.98 1.94 -1,002.45 MWD+IFR-AK-CAZ-SC(3) 6,942.62 55.02 70.56 5,031.21 4,960.07 816.14 3,833.06 5,966,638.35 353,329.99 0.22 -1,012.99 MWD+IFR-AK-CAZ-SC(3) 7,037.00 54.90 68.98 5,085.40 5,014.26 842.86 3,905.56 5,966,663.61 353,403.00 1.38 -1,022.10 MWD+IFR-AK-CAZ-SC(3) 7,130.46 54.91 68.23 5,139.13 5,067.99 870.75 3,976.76 5,966,690.07 353,474.74 0.66 -1,029.57 MWD+IFR-AK-CAZ-SC(3) 7,224.78 55.46 70.84 5,192.99 5,121.85 897.82 4,049.30 5,966,715.67 353,547.81 2.35 -1,038.38 MWD+IFR-AK-CAZ-SC(3) 7,319.18 55.38 69.29 5,246.57 5,175.43 924.31 4,122.36 5,966,740.70 353,621.38 1.35 -1,047.94 MWD+IFR-AK-CAZ-SC(3) 7,414.45 55.46 70.53 5,300.64 5,229.50 951.26 4,196.02 5,966,766,16 353,695.56 1.07 -1,057.38 MWD+IFR-AK-CAZ-SC(3) 7,507.70 55.42 71.48 5,353.54 5,282.40 976.25 4,268.64 5,966,789.69 353,768.66 0.84 -1,068.07 MWD+IFR-AK-CAZ-SC(3) 7,602.40 55.39 71.68 5,407.31 5,336.17 1,000.88 4,342.60 5,966,812.83 353,843.09 0.18 -1,079.70 MWD+IFR-AK-CAZ-SC(3) 7,696.71 55.46 71.39 5,460.83 5,389.69 1,025.48 4,416.25 5,966,835.94 353,917.22 0.26 -1,091.23 MWD+IFR-AK-CAZ-SC(3) 6/24/2015 3:28:27PM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 7,790.69 55.25 71.61 5,514.25 5,443.11 1,050.01 4,489.57 5,966,859.00 353,991 01 0.29 -1,102.66 MWD+IFR-AK-CAZ-SC(3) 7,883.95 54.92 71.33 5,567.63 5,496.49 1,074.31 4,562.08 5,966,881.84 354,063.99 0.43 -1,113.92 MWD+IFR-AK-CAZ-SC(3) 7,919.48 54.48 71.01 5,588.16 5,517.02 1,083.67 4,589.53 5,966,890.65 354,091.61 1.44 -1,118.04 MWD+IFR-AK-CAZ-SC(3) 7,977.75 54.20 70.27 5,622.13 5,550.99 1,099.37 4,634.19 5,966,905.44 354,136.58 1.14 -1,124.34 MWD+IFR-AK-CAZ-SC(4) 8,072.31 55.16 70.84 5,676.80 5,605.66 1,125.05 4,706.95 5,966,929.66 354,209.83 1.13 -1,134.48 MWD+IFR-AK-CAZ-SC(4) 8,167.35 55.57 71.46 5,730.82 5,659.68 1,150.31 4,780.95 5,966,953.43 354,284.32 0.69 -1,145.57 MWD+IFR-AK-CAZ-SC(4) 8,261.96 55.25 70.41 5,784.53 5,713.39 1,175.75 4,854.56 5,966,977.39 354,358.42 0.97 -1,156.32 MWD+IFR-AK-CAZ-SC(4) 8,356.04 55.14 70.51 5,838.23 5,767.09 1,201.59 4,927.36 5,967,001.76 354,431.72 0.15 -1,166.35 MWD+IFR-AK-CAZ-SC(4) 8,448.58 55.17 69.92 5,891.10 5,819.96 1,227.30 4,998.83 5,967,026.03 354,503.68 0.52 -1,175.89 MWD+IFR-AK-CAZ-SC(4) 8,543.23 55.58 69.29 5,944.88 5,873.74 1,254.44 5,071.83 5,967,051.70 354,577.21 0.70 -1,184.85 MWD+IFR-AK-CAZ-SC(4) 8,637.60 55.67 68.33 5,998.17 5,927.03 1,282.59 5,144.45 5,967,078.39 354,650.37 0.85 -1,192.73 MWD+IFR-AK-CAZ-SC(4) 8,731.78 55.41 68.04 6,051.46. 5,980.32 1,311.45 5,216.54 5,967,105.80 354,723.02 0.38 -1,199.75 MWD+IFR-AK-CAZ-SC(4) 8,826.39 55.17 67.93 6,105.33 6,034.19 1,340.60 5,288.65 5,967,133.50 354,795.69 0.27 -1,206.51 MWD+IFR-AK-CAZ-SC(4) 8,921.26 55.23 68,17 6,159.47 6,088.33 1,369.72 5,360.90 5,967,161.16 354,868.51 0.22 -1,213.37 MWD+IFR-AK-CAZ-SC(4) 9,015.29 55.28 69.33 6,213.07 6,141.93 1,397.73 5,432.91 5,967,187.71 354,941.06 1.02 -1,221.11 MWD+IFR-AK-CAZ-SC(4) 9,106.95 55.02 69.51 6,265.44 6,194.30 1,424.17 5,503.33 5,967,212.73 355,011.99 0.33 -1,229.52 MWD+IFR-AK-CAZ-SC(4) 9,203.16 55.16 66.59 6,320.51 6,249.37 1,453.66 5,576.50 5,967,240.75 355,085.73 2.49 -1,236.46 MWD+IFR-AK-CAZ-SC(4) 9,295.27 54.19 63.80 6,373.78 6,302.64 1,485.17 5,644.71 5,967,270.88 355,154.55 2.69 -1,239.35 MWD+IFR-AK-CAZ-SC(4) 9,391.99 54.00 61.89 6,430.50 6,359.36 1,520.92 5,714.41 5,967,305.23 355,224.95 1.61 -1,239.14 MWD+IFR-AK-CAZ-SC(4) 9,486.28 53.84 59.41 6,486.03 6,414.89 1,558.26 5,780.82 5,967,341.23 355,292.09 2.13 -1,236.02 MWD+IFR-AK-CAZ-SC(4) 9,581.07 53.99 55.42 6,541.88 6,470.74 1,599.51 5,845.35 5,967,381.17 355,357.43 3.41 -1,228.56 MWD+IFR-AK-CAZ-SC(4) 9,675.68 54.70 52.05 6,597.04 6,525.90 1,644.98 5,907.31 5,967,425.38 355,420.28 2.99 -1,216.18 MWD+IFR-AK-CAZ-SC(4) 9,768.98 55.10 48.51 6,650.70 6,579.56 1,693.75 5,966.00 5,967,472.97 355,479.94 3.13 -1,199.37 MWD+IFR-AK-CAZ-SC(4) 9,863.74 55.88 43.78 6,704.40 6,633.26 1,747.83 6,022.27 5,967,525.91 355,537.28 4.19 -1,176.72 MWD+IFR-AK-CAZ-SC(4) 9,958.90 56.08 38.62 6,757.67 6,686.53 1,807.15 6,074.19 5,967,584.17 355,590.37 4.50 -1,147.44 MWD+IFR-AK-CAZ-SC(4) 10,052.51 56.29 31.92 6,809.80 6,738.66 1,870.59 6,119.06 5,967,646.69 355,636.49 5.95 -1,111.28 MWD+IFR-AK-CAZ-SC(4) 10,100.29 56.34 29.62 6,836.31 6,765.17 1,904.75 6,139.39 5,967,680.43 355,657.51 4.01 -1,090.08 MWD+IFR-AK-CAZ-SC(4) 10,146.62 56.31 27.41 6,862.00 6,790.86 1,938.62 6,157.80 5,967,713.93 355,676.59 3.97 -1,068.26 MWD+IFR-AK-CAZ-SC(4) 10,241.44 55.89 22.96 6,914.90 6,843.76 2,009.81 6,191.28 5,967,784.43 355,711.49 3.92 -1,020.03 MWD+IFR-AK-CAZ-SC(4) 10,335.09 56.34 18.23 6,967.14 6,896.00 2,082.56 6,218.61 5,967,856.60 355,740.27 4.22 -967.62 MWD+IFR-AK-CAZ-SC(4) 10,428.10 57.43 15.85 7,017.95 6,946.81 2,157.03 6,241.42 5,967,930.60 355,764.57 2.44 -911.62 MWD+IFR-AK-CAZ-SC(4) 10,522.29 59.40 10.82 7,067.31 6,996.17 2,235.07 6,259.88 5,968,008.25 355,784.59 5.01 -850.46 MWD+IFR-AK-CAZ-SC(4) 10,617.45 59.63 8.04 7,115.59 7,044.45 2,315.96 6,273.32 5,968,088.84 355,799.64 2.53 -784.49 MWD+IFR-AK-CAZ-SC(4) 10,712.08 60.82 5.04 7,162.59 7,091.45 2,397.55 6,282.66 5,968,170.22 355,810.61 3.03 -716.04 MWD+IFR-AK-CAZ-SC(4) 10,810.41 63.06 2.40 7,208.85 7,137.71 2,484.12 6,288.26 5,968,256.66 355,817.95 3.29 -641.44 MWD+IFR-AK-CAZ-SC(4) 10,900.70 65.52 359.78 7,248.02 7,176.88 2,565.44 6,289.79 5,968,337.93 355,821.11 3.78 -569.68 MWD+IFR-AK-CAZ-SC(4) 10,993.06 68.91 357.58 7,283.79 7,212.65 2,650.55 6,287.81 5,968,423.06 355,820.84 4.28 -492.95 MWD+IFR-AK-CAZ-SC(4) 11,086.91 72.16 355.95 7,315.06 7,243.92 2,738.88 6,282.81 5,968,511.46 355,817.60 3.83 -411.97 MWD+IFR-AK-CAZ-SC(4) 11,181.88 75.13 353.64 7,341.80 7,270.66 2,829.61 6,274.53 5,968,602.33 355,811.15 3.90 -327.37 MWD+IFR-AK-CAZ-SC(4) 11,230.57 76.05 351.23 7,353.92 7,282.78 2,876.36 6,268.32 5,968,649.19 355,805.87 5.15 -282.90 MWD+IFR-AK-CAZ-SC(4) 6/24/2015 3:28:27PM Page 5 COMPASS 5000.1 Build 65 III III Sc hlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 11,274.75 76.22 348.91 7,364.51 7,293.37 2,918.60 6,260.92 5,968,691.57 355,799.33 5.11 -241.90 MWD+IFR-AK-CAZ-SC(4) 11,325.21 76.04 346.16 7,376.61 7,305.47 2,966.43 6,250.35 5,968,739.60 355,789.72 5.30 -194.49 MWD+IFR-AK-CAZ-SC(4) 11,370.66 76.13 344.15 7,387.54 7,316.40 3,009.07 6,239.05 5,968,782.46 355,779.27 4.30 -151.36 MWD+IFR-AK-CAZ-SC(4) 11,464.46 78.20 340.06 7,408.38 7,337.24 3,096.08 6,210.94 5,968,870.00 355,752.92 4.79 -61.08 MWD+IFR-AK-CAZ-SC(4) 11,559.02 79.52 338.43 7,426.65 7,355.51 3,182.83 6,178.06 5,968,957.38 355,721.79 2.19 31.14 MWD+IFR-AK-CAZ-SC(4) 11,653.18 79.94 338.00 7,443.44 7,372.30 3,268.86 6,143.67 5,969,044.08 355,689.13 0.63 123.41 MWD+IFR-AK-CAZ-SC(4) 11,746.76 80.47 337.23 7,459.36 7,388.22 3,354.13 6,108.56 5,969,130.03 355,655.74 0.99 215.32 MWD+IFR-AK-CAZ-SC(4) 11,787.61 80.57 336.85 7,466.09 7,394.95 3,391 23 6,092.84 5,969,167.43 355,640.77 0.95 255.51 MWD+IFR-AK-CAZ-SC (4) 11,836.73 81.62 338.28 7,473.69 7,402.55 3,436.08 6,074.32 5,969,212.65 355,623.15 3.59 303.89 i.=^"° ,ta,;. k-•, 7-5/8"x 9-7/8"by 11" 11,858.82 82.10 338.92 7,476.82 7,405.68 3,456.44 6,066.34 5,969,233.16 355,615.58 3.59 325.65 MWD+IFR-AK-CAZ-SC(5) 11,954.94 85.95 338.44 7,486.82 7,415.68 3,545.48 6,031.59 5,969,322.87 355,582.63 4.04 420.76 MWD+IFR-AK-CAZ-SC(5) 12,003.28 87.53 337.43 7,489.57 7,418.43 3,590.20 6,013.46 5,969,367.95 355,565.40 3.88 468.84 MWD+IFR-AK-CAZ-SC(5) 12,050.62 88.99 333.77 7,491.01 7,419.87 3,633.29 5,993.92 5,969,411.41 355,546.72 8.32 516.10 MWD+IFR-AK-CAZ-SC(5) 12,096.96 90.39 336.08 7,491.26 7,420.12 3,675.25 5,974.28 5,969,453.76 355,527.93 5.83 562.41 MWD+IFR-AK-CAZ-SC(5) 12,144.17 91.65 332.36 7,490.42 7,419.28 3,717.75 5,953.75 5,969,496.66 355,508.26 8.32 609.59 MWD+IFR-AK-CAZ-SC(5) 12,240.10 92.69 332.64 7,486.78 7,415.64 3,802.78 5,909.49 5,969,582.55 355,465.72 1.12 705.45 MWD+IFR-AK-CAZ-SC(5) 12,335.16 92.85 331.13 7,482.19 7,411.05 3,886.52 5,864.75 5,969,667.17 355,422.67 1.60 800.38 MWD+IFR-AK-CAZ-SC(5) 12,430.89 93.07 328.79 7,477.25 7,406.11 3,969.28 5,816.89 5,969,750.86 355,376.48 2.45 895.84 MWD+IFR-AK-CAZ-SC(5) 12,526.15 91.39 329.27 7,473.54 7,402.40 4,050.89 5,767.91 5,969,833.43 355,329.15 1.83 990.79 MWD+IFR-AK-CAZ-SC(5) 12,620.63 90.82 328.46 7,471.72 7,400.58 4,131.75 5,719.07 5,969,915.24 355,281.94 1.05 1,085.01 MWD+IFR-AK-CAZ-SC(5) 12,716.49 90.27 328.39 7,470.81 7,399.67 4,213.41 5,668.88 5,969,997.89 355,233.40 0.58 1,180.56 MWD+IFR-AK-CAZ-SC(5) 12,811.66 90.44 327.84 7,470.22 7,399.08 4,294.22 5,618.61 5,970,079.68 355,184.77 0.60 1,275.38 MWD+IFR-AK-CAZ-SC(5) 12,907.34 90.31 328.78 7,469.59 7,398.45 4,375.63 5,568.35 5,970,162.08 355,136.15 0.99 1,370.74 MWD+IFR-AK-CAZ-SC(5) 13,002.43 90.34 329.29 7,469.05 7,397.91 4,457.17 5,519.42 5,970,244.58 355,088.88 0.54 1,465.60 MWD+IFR-AK-CAZ-SC(5) 13,097.19 90.38 329.20 7,468.46 7,397.32 4,538.60 5,470.97 5,970,326.96 355,042.07 0.10 1,560.15 MWD+IFR-AK-CAZ-SC(5) 13,192.34 90.34 330.04 7,467.86 7,396.72 4,620.68 5,422.85 5,970,409.98 354,995.61 0.88 1,655.13 MWD+IFR-AK-CAZ-SC(5) 13,287.66 90.31 329.15 7,467.32 7,396.18 4,702.89 5,374.61 5,970,493.13 354,949.03 0.93 1,750.28 MWD+IFR-AK-CAZ-SC(5) 13,383.21 90.27 328.83 7,466.83 7,395.69 4,784.78 5,325.38 5,970,575.99 354,901.46 0.34 1,845.60 MWD+IFR-AK-CAZ-SC(5) 13,478.68 90.45 328.75 7,466.23 7,395.09 4,866.43 5,275.91 5,970,658.61 354,853.64 0.21 1,940.81 MWD+IFR-AK-CAZ-SC(5) 13,574.78 90.41 327.97 7,465.51 7,394.37 4,948.25 5,225.50 5,970,741.41 354,804.88 0.81 2,036.59 MWD+IFR-AK-CAZ-SC(5) 13,670.67 90.17 326.70 7,465.03 7,393.89 5,028.97 5,173.75 5,970,823.15 354,754.76 1.35 2,132.01 MWD+IFR-AK-CAZ-SC(5) 13,765.05 89.83 325.11 7,465.03 7,393.89 5,107.12 5,120.85 5,970,902.34 354,703.44 1.72 2,225.66 MWD+IFR-AK-CAZ-SC(5) 13,861.43 88.85 324.58 7,466.14 7,395.00 5,185.92 5,065.36 5,970,982.23 354,649.54 1.16 2,321.06 MWD+IFR-AK-CAZ-SC(5) 13,956.92 89.16 323.39 7,467.80 7,396.66 5,263.14 5,009.22 5,971,060.55 354,594.97 1.29 2,415.36 MWD+IFR-AK-CAZ-SC(5) 14,052.20 87.86 323.96 7,470.27 7,399.13 5,339.88 4,952.80 5,971,138.40 354,540.10 1.49 2,509.34 MWD+IFR-AK-CAZ-SC(5) 14,146.65 88.07 324.27 7,473.63 7,402.49 5,416.35 4,897.47 5,971,215.96 354,486.32 0.40 2,602.60 MWD+IFR-AK-CAZ-SC(5) 14,242.02 89.43 323.66 7,475.71 7,404.57 5,493.45 4,841.38 5,971,294.17 354,431.79 1.56 2,696.76 MWD+IFR-AK-CAZ-SC(5) 14,337.84 89.49 325.34 7,476.61 7,405.47 5,571.45 4,785.74 5,971,373.26 354,377.73 1.75 2,791.52 MWD+IFR-AK-CAZ-SC(5) 14,433.63 89.45 325.23 7,477.50 7,406.36 5,650.19 4,731.19 5,971,453.07 354,324.78 0.12 2,886.44 MWD+IFR-AK-CAZ-SC(5) 14,528.60 89.90 324.02 7,478.03 7,406.89 5,727.62 4,676.21 5,971,531.59 354,271.36 1.36 2,980.39 MWD+IFR-AK-CAZ-SC(5) 6/24/2015 3:28:27PM Page 6 COMPASS 5000.1 Build 65 III • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 14,623.53 90.41 325.31 7,477.78 7,406.64 5,805.06 4,621.31 5,971,610.10 354,218.03 1.46 3,074.32 MWD+IFR-AK-CAZ-SC(5) 14,718.57 90.48 326.93 7,477.04 7,405.90 5,883.96 4,568.33 5,971,690.04 354,166.65 1.71 3,168.67 MWD+IFR-AK-CAZ-SC(5) 14,813.45 91.17 327.50 7,475.67 7,404.53 5,963.72 4,516.96 5,971,770.81 354,116.89 0.94 3,263.05 MWD+IFR-AK-CAZ-SC(5) 14,908.17 91.68 328.09 7,473.32 7,402.18 6,043.84 4,466.50 5,971,851.92 354,068.05 0.82 3,357.35 MWD+IFR-AK-CAZ-SC(5) 15,005.03 91.99 329.86 7,470.22 7,399.08 6,126.80 4,416.60 5,971,935.85 354,019.83 1.85 3,453.92 MWD+IFR-AK-CAZ-SC(5) 15,099.85 91.85 331.48 7,467.04 7,395.90 6,209.41 4,370.19 5,972,019.38 353,975.08 1.71 3,548.61 MWD+IFR-AK-CAZ-SC(5) 15,194.76 90.86 330.52 7,464.80 7,393.66 6,292.40 4,324.19 5,972,103.26 353,930.75 1.45 3,643.43 MWD+IFR-AK-CAZ-SC(5) 15,289.95 90.21 331.00 7,463.91 7,392.77 6,375.46 4,277.69 5,972,187.23 353,885.94 0.85 3,738.54 MWD+IFR-AK-CAZ-SC(5) 15,385.57 89.90 332.19 7,463.81 7,392.67 6,459.56 4,232.21 5,972,272.22 353,842.15 1.29 3,834.13 MWD+IFR-AK-CAZ-SC(5) 15,481.41 90.00 334.69 7,463.90 7,392.76 6,545.28 4,189.36 5,972,358.78 353,801.03 2.61 3,929.96 MWD+IFR-AK-CAZ-SC(5) 15,577.24 90.27 334.35 7,463.67 7,392.53 6,631.79 4,148.13 5,972,446.09 353,761.55 0.45 4,025.76 MWD+IFR-AK-CAZ-SC(5) 15,672.86 90.24 332.55 7,463.25 7,392.11 6,717.32 4,105.39 5,972,532.45 353,720.54 1.88 4,121.37 MWD+IFR-AK-CAZ-SC(5) 15,767.90 90.07 332.62 7,462.99 7,391.85 6,801.69 4,061.63 5,972,617.67 353,678.48 0.19 4,216.41 MWD+IFR-AK-CAZ-SC(5) 15,863.55 90.07 334.86 7,462.87 7,391.73 6,887.46 4,019.32 5,972,704.27 353,637.90 2.34 4,312.04 MWD+IFR-AK-CAZ-SC(5) 15,959.16 90.07 335.46 7,462.76 7,391.62 6,974.23 3,979.15 5,972,791.82 353,599.48 0.63 4,407.58 MWD+IFR-AK-CAZ-SC(5) 16,053.65 90.55 336.06 7,462.24 7,391.10 7,060.38 3,940.36 5,972,878.73 353,562.43 0.81 4,501.96 MWD+IFR-AK-CAZ-SC(5) 16,149.69 90.86 337.22 7,461.06 7,389.92 7,148.54 3,902.28 5,972,967.63 353,526.13 1.25 4,597.80 MWD+IFR-AK-CAZ-SC(5) 16,244.80 91.24 336.62 7,459.32 7,388.18 7,236.02 3,865.00 5,973,055.83 353,490.61 0.75 4,692.67 MWD+IFR-AK-CAZ-SC(5) 16,339.52 91.00 335.44 7,457.47 7,386.33 7,322.56 3,826.53 5,973,143.11 353,453.89 1.27 4,787.24 MWD+IFR-AK-CAZ-SC(5) 16,435.31 90.93 334.51 7,455.86 7,384.72 7,409.34 3,786.02 5,973,230.68 353,415.12 0.97 4,882.96 MWD+IFR-AK-CAZ-SC(5) 16,530.34 91.17 333.94 7,454.11 7,382.97 7,494.90 3,744.70 5,973,317.05 353,375.53 0.65 4,977.95 MWD+IFR-AK-CAZ-SC(5) 16,624.65 91.03 332.00 7,452.30 7,381.16 7,578.89 3,701.85 5,973,401.87 353,334.38 2.06 5,072.24 MWD+IFR-AK-CAZ-SC(5) 16,719.72 91.62 329.51 7,450.10 7,378.96 7,661.81 3,655.42 5,973,485.70 353,289.62 2.69 5,167.20 MWD+IFR-AK-CAZ-SC(5) 16,815.82 90.93 329.10 7,447.97 7,376.83 7,744.43 3,606.38 5,973,569.28 353,242.25 0.84 5,263.08 MWD+IFR-AK-CAZ-SC(5) 16,911.12 91.10 326.93 7,446.28 7,375.14 7,825.24 3,555.91 5,973,651.08 353,193.41 2.28 5,357.99 MWD+IFR-AK-CAZ-SC(5) 17,006.56 90.53 326.24 7,444.92 7,373.78 7,904.90 3,503.36 5,973,731.77 353,142.47 0.94 5,452.83 MWD+IFR-AK-CAZ-SC(5) 17,103.41 91.28 325.52 7,443.39 7,372.25 7,985.07 3,449.04 5,973,813.01 353,089.78 1.07 5,548.92 MWD+IFR-AK-CAZ-SC(5) 17,197.56 90.99 323.91 7,441.53 7,370.39 8,061.90 3,394.66 5,973,890.91 353,036.96 1.74 5,642.06 MWD+IFR-AK-CAZ-SC(5) 17,292.54 89.94 321.04 7,440.75 7,369.61 8,137.22 3,336.82 5,973,967.36 352,980.64 3.22 5,735.43 MWD+IFR-AK-CAZ-SC(5) 17,387.17 90.17 323.08 7,440.66 7,369.52 8,211.84 3,278.64 5,974,043.14 352,923.97 2.17 5,828.33 MWD+IFR-AK-CAZ-SC(5) 17,482.45 90.24 324.69 7,440.32 7,369.18 8,288.81 3,222.48 5,974,121.21 352,869.37 1.69 5,922.41 MWD+IFR-AK-CAZ-SC(5) 17,576.01 90.17 326.51 7,439.99 7,368.85 8,366.01 3,169.63 5,974,199.44 352,818.08 1.95 6,015.18 MWD+IFR-AK-CAZ-SC(5) 17,672.94 90.55 327.58 7,439.38 7,368.24 8,447.34 3,116.90 5,974,281.81 352,767.00 1.17 6,111.59 MWD+IFR-AK-CAZ-SC(5) 17,768.78 90.27 328.92 7,438.69 7,367.55 8,528.83 3,066.47 5,974,364.29 352,718.22 1.43 6,207.09 MWD+IFR-AK-CAZ-SC(5) 17,864.16 89.85 331.78 7,438.59 7,367.45 8,611.71 3,019.29 5,974,448.09 352,672.71 3.03 6,302.36 MWD+IFR-AK-CAZ-SC(5) 17,960.66 90.77 332.41 7,438.07 7,366.93 8,696.99 2,974.13 5,974,534.25 352,629.27 1.16 6,398.85 MWD+IFR-AK-CAZ-SC(5) 18,055.16 90.65 334.11 7,436.90 7,365.76 8,781.37 2,931.62 5,974,619.47 352,588.46 1.80 6,493.34 MWD+IFR-AK-CAZ-SC(5) 18,150.49 90.58 335.18 7,435.88 7,364.74 8,867.51 2,890.80 5,974,706.40 352,549.38 1.12 6,588.62 MWD+IFR-AK-CAZ-SC(5) 18,245.34 90.96 335.78 7,434.60 7,363.46 8,953.80 2,851.44 5,974,793.45 352,511.76 0.75 6,683.37 MWD+IFR-AK-CAZ-SC(5) 18,340.88 91.13 337.05 7,432.86 7,361.72 9,041.35 2,813.22 5,974,881.74 352,475.31 1.34 6,778.72 MWD+IFR-AK-CAZ-SC(5) 6/24/2015 3:28:27PM Page 7 COMPASS 5000.1 Build 65 • • Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 18,436.02 91.24 337.07 7,430.89 7,359.75 9,128.94 2,776.14 5,974,970.05 352,440.00 0.12 6,873.60 MWD+IFR-AK-CAZ-SC(5) 18,531.47 90.55 336.77 7,429.40 7,358.26 9,216.74 2,738.73 5,975,058.58 352,404.35 0.79 6,968.82 MWD+IFR-AK-CAZ-SC(5) 18,627.69 90.55 337.95 7,428.48 7,357.34 9,305.54 2,701.69 5,975,148.10 352,369.11 1.23 7,064.75 MWD+IFR-AK-CAZ-SC(5) 18,721.67 91.26 338.22 7,426.99 7,355.85 9,392.72 2,666.62 5,975,235.95 352,335.79 0.81 7,158.35 MWD+IFR-AK-CAZ-SC(5) 18,818.34 93.05 336.27 7,423.36 7,352.22 9,481.79 2,629.26 5,975,325.75 352,300.23 2.74 7,254.68 MWD+IFR-AK-CAZ-SC(5) 18,863.00 93.05 336.27 7,420.98 7,349.84 9,522.62 2,611.32 5,975,366.93 352,283.11 0.00 7,299.20 NOT an Actual Survey • 4-1/2"x 6-1/2" 18,878.00 93.05 336.27 7,420.18 7,349.04 9,536.33 2,605.29 5,975,380.76 352,277.35 0.00 7,314.16 PROJECTED to TD 6/24/2015 3:28:27PM Page 8 COMPASS 5000.1 Build 65 • • Y O O Y Q O MI i O O.'V C1 0 ,_ V a) GO F. O O L L w cv O v Y aN a 0, 0.D En 0 0 0 CO O "' A c V vi q p C E o.5.1 !0 UI r is Q O /.. 0 /Q^) g O i O N I; ra N ` 1 ,8 p W O o 0 =OO 'O • .Q v t. J Q m o3a _ m � 0 CO _� c Z E (D o O v. N > i > y y ❑ ° a o 6 m o ti c U "a _ = Q a) oO co _ L c U U 41) m om'a t L O co a a m .—ii a) i- � a) _ et _ Y = aa)13 m LL w a0 us a0 co I.CO LIED E as N Q — ili w co 0 m wti tu (n V.f 0 o_ w U • • O O -o N T O o -O O T a) ._ O MO W C O OmCD 0 O CO % ,goo E ..0,00//v 5 Oo m 0 0 000 o0 N OCa .� tii O W O O N +r 1C N ‘.00i 0 •tr!i / _ 0 0 I0 -o LO N Cn 0 1, o O -O NI 0 O CO O O O O O O I 0 0 0 0 0 0 O 0 0 O 0 CO (ui/�1Sn N 0002) (+)ul oN/(-)ulnoS • i 0 0 -0 a) CD5-04 ... CD5-04wp15.1 _o 1 8878 Lr) C N T- 0 O x I ■ 18000 0 — - _O V N C Tco d 17000 c o N o = 16000 O 0 LoT O 1-5000 0 0 O co –O co co 000171. C O U 0 4) O 13000 U i O00®@$ 0 1 o PT 0' N O 0 O O ODOR -O M in o 0 0 X0 009 d� I (O n 009 0 O. x co LO N �j 0 Q T A LOQ T U x M O r O 0 –o co 0 I 0 I 0 I or 0 I 0I 0 0 0 0 0 (u!/14sn 0051) inclea Jeoi JeA anal • 0 A CD5 04w 15.1 P CD5-04 o O 'Vt:8-7f 0 N W ii 1-8-000 N T O _O O co 0 . 7000 C.) a) CO O O E 1 16000 o 0 o 0 CO co co +r c� 5000 0 O U O N O co c� 00017G .= L I o O 13000 T' 41. 0 006 - CI /Q T s)M A\ -O 1` 00011 O x 009 6 U) O o O O O O 6) O N co in o o u}daa I00Ra0A anal r-- . • • vs. CD5-04wp15.1 Comparison View o_k0° -- - - --- 20"x 42" —0° ,000 10-3/4"x 13-1/2" o 2.0`to 0 ye oo 0 r) i 0 o co 4) In 4? v N o - 7-5/8"x 9-7/8"by 11" 4-1/2"x 6-1/2" o co p�0 ^O DO I o 0 o 0 ad am a-0 v i I I I I i iI I II I IiI I I I I I W I I I I I I I I � I I g I ofI I iI i i o I I991� I I I I 0 850 1700 2550 3400 4250 5100 5950 6800 7650 8500 9350 10200 11050 11900 12750 13600 14450 1-,, 00 c 158— _ — - N - 7 O - -... r .... 105— _ as o_ N CD5-04 m c U 53— - m U I 1 0 I I 1 I 1 I I I I I 1 I I I I I I I I I I 1 I I I 1 I I I I I 1 1 i 0 2250 4500 6750 9000 11250 13500 15750 18000 20250 Measured Depth (3000 usft/in) 1 4 6— I —6 LCU J - Kalubik ,I - I C HRZ 1 II I)i �A m CO I 7-5/8"x 9-7/8"by 11" rn I' cn 0 3— I J —3 1 � ' \1\ilI UJU / 1\il IE ase'ermafrost /I I M I K 2/ AIb9 1 Alb / 1 rl I i I I I I i I I I I I 0VI\ 1 3500 7000 10500 14000 17500 20"x 42" Measured Depth • s wp vs. CD5-04wp15.1 Comparison View Alpine A UJU _ ^ ``'�— - LCU Kalubik 70— K3 K2 AIb97 Alb96 HRZ 7-5/8"x 9-7/8"by 11" —70 c o - m - C30 f-7) E. Base Permafrob _ - l /4x131/2 I I I 0 0 3500 7000 10500 14000 17500 20"x 42" Measured Depth Alpine A C30 LCU Kalubik 7-5/8"x 9-7/8"by 11" HRZ ' - J, Base Pe f ty o3 K3 K2 AIb97 AIb96 - 3'3'/,"x 13- /2" 0— 4=4 I 1 4 v` v ly f ' +`I —0 -20"x 42" it-- ' - 0 3500 7000 10500 14000 17500 Measured Depth _ Base Permafrost UJU _ Kalubik LCU 1 Alpine A - C30 K3 K2 AIb97 AIb96 HRZ - i_0t E 0 -20" 442 10-3/4"x 13-1/2" 7-5/8"x 9-7/8"by 11" - I I 1 1I 1 1 1I I I II i I I I I I I I I I 0 3500 7000 10500 14000 17500 Measured Depth UJU _ - Base Permafrost Alpine A Kalubik LCU - ` C10- K3 K2 AIb97 AIb96 HRZ �, c 0 ', 0— —0 c 3 E R -20"x 42" 4" 3-/2" 7-5 " ,9-7/8"by 11" 10 I I I I I I I II 0 3500 7000 10500 14000 17500 Measured Depth • • 11 5072 25007 RElcoveD JUL 01 ZULi FINAL ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad CD5-04 Definitive Survey Report 24 June, 2015 NAD 83 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94©71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 Database: OAKEDMP2 Project Western North Slope,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 CD5-04 Well Position +N/-S 0.00 usft Northing: 5,965,645.24 usft Latitude: 70°18'48.982 N +E/-W 0.00 usft Easting: 1,489,514.77 usft Longitude: 151°13'23.051 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 34.20 usft Wellbore CD5-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 5/20/2015 18.21 80.77 57,530 Design CD5-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 36.94 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 36.94 0.00 0.00 333.00 Survey Program Date 6/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 86.20 455.80 CD5-04 Svy1 GYD-GC-MS(CD5-04) GYD-GC-MS Gyrodata gyrocompassing m/s 6/5/2015 5:08:0 475.19 2,271.52 CD5-04 Svy2 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/5/2015 5:14:1 2,365.41 7,919.48 CD5-04 Svy3 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:44: 7,977.75 11,787.61 CD5-04 Svy4 SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:46: 11,858.82 18,818.34 CD5-04 SvyS SLB_MWD+GMAG(CD5-0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2015 2:47: Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.94 0.00 0.00 36.94 -34.20 0.00 0.00 5,965,645.24 1,489,514.77 0.00 0.00 UNDEFINED 86.18 0.14 301.48 86.18 15.04 0.03 -0.05 5,965,645.27 1,489,514.72 0.28 0.05 GYD-GC-MS(1) 178.70 0.21 264.50 178.70 107.56 0.07 -0.32 5,965,645.32 1,489,514.46 0.14 0.21 GYD-GC-MS(1) 272.29 0.28 243.14 272.29 201.15 -0.05 -0.69 5,965,645.21 1,489,514.08 0.12 0.27 GYD-GC-MS(1) 364.06 0.16 217.42 364.06 292.92 -0.25 -0.97 5,965,645.01 1,489,513.80 0.17 0.22 GYD-GC-MS(1) 455.83 0.26 184.48 455.83 384.69 -0.56 -1.06 5,965,644.70 1,489,513.70 0.17 -0.01 GYD-GC-MS(1) 475.19 0.50 168.89 475.19 404.05 -0.68 -1.05 5,965,644.58 1,489,513.71 1.34 -0.13 MWD+IFR-AK-CAZ-SC(2) 567.22 1.59 154.88 567.20 496.06 -2.23 -0.43 5,965,643.01 1,489,514.29 1.21 -1.80 MWD+IFR-AK-CAZ-SC(2) 616.54 2.43 153.55 616.49 545.35 -3.79 0.33 5,965,641.44 1,489,515.02 1.71 -3.52 MWD+IFR-AK-CAZ-SC(2) 657.80 2.36 149.11 657.71 586.57 -5.30 1.15 5,965,639.92 1,489,515.81 0.48 -5.25 MWD+IFR-AK-CAZ-SC(2) 6/24/2015 2:49:41PM Page 2 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 752.05 4.17 142.81 751.81 680.67 -9.70 4.22 5,965,635.46 1.489,518.79 1.95 -10.56 MWD+IFR-AK-CAZ-SC(2) 846.97 6.25 144.42 846.33 775.19 -16.65 9.31 5,965,628.41 1,489,523.74 2.20 -19.06 MWD+IFR-AK-CAZ-SC(2) 940.06 8.84 143.08 938.61 867.47 -26.49 16.56 5,965,618.42 1,489,530.79 2.79 -31.12 MWD+IFR-AK-CAZ-SC(2) 1,035.43 10.56 144.87 1,032.61 961.47 -39.50 25.99 5,965,605.23 1,489,539.96 1.83 -46.99 MWD+IFR-AK-CAZ-SC(2) 1,128.45 12.03 146.30 1,123.83 1,052.69 -54.54 36.27 5,965,589.99 1,489,549.94 1.61 -65.06 MWD+IFR-AK-CAZ-SC(2) 1,221.31 13.76 147.05 1,214.34 1,143.20 -71.85 47.65 5,965,572.45 1,489,560.96 1.87 -85.66 MWD+IFR-AK-CAZ-SC(2) 1,316.18 16.58 145.80 1,305.90 1,234.76 -92.52 61.40 5,965,551.51 1,489,574.29 2.99 -110.31 MWD+IFR-AK-CAZ-SC(2) 1,412.36 17.81 144.07 1,397.78 1,326.64 -115.78 77.74 5,965,527.93 1,489,590.16 1.38 -138.46 MWD+IFR-AK-CAZ-SC(2) 1,507.01 20.62 144.14 1,487.14 1,416.00 -141.02 96.00 5,965,502.33 1,489,607.91 2.97 -169.23 MWD+IFR-AK-CAZ-SC(2) 1,601.06 22.39 145.61 1,574.64 1,503.50 -169.22 115.82 5,965,473.74 1,489,627.16 1.97 -203.36 MWD+IFR-AK-CAZ-SC(2) 1,693.77 22.90 138.99 1,660.22 1,589.08 -197.41 137.64 5,965,445.12 1,489,648.40 2.80 -238.38 MWD+IFR-AK-CAZ-SC(2) 1,785.12 23.45 132.45 1,744.21 1,673.07 -223.09 162.72 5,965,418.94 1,489,672.96 2.88 -272.65 MWD+IFR-AK-CAZ-SC(2) 1,878.68 25.53 125.78 1,829.37 1,758.23 -247.45 192.82 5,965,393.98 1,489,702.56 3.70 -308.02 MWD+1FR-AK-CAZ-SC(2) 1,973.10 24.42 115.02 1,915.00 1,843.86 -267.61 227.03 5,965,373.14 1,489,736.36 4.95 -341.52 MWD+IFR-AK-CAZ-SC(2) 2,067.66 25.09 106.10 2,000.90 1,929.76 -281.45 264.02 5,965,358.57 1,489,773.06 4.01 -370.63 MWD+IFR-AK-CAZ-SC(2) 2,162.23 26.87 99.91 2,085.93 2,014.79 -290.69 304.35 5,965,348.52 1,489,813.19 3.43 -397.17 MWD+IFR-AK-CAZ-SC(2) 2,259.78 27.98 94.31 2,172.53 2,101.39 -296.20 348.89 5,965,342.11 1,489,857.61 2.88 -422.31 MWD+IFR-AK-CAZ-SC(2) 2,271.52 28.24 93.84 2,182.88 2,111.74 -296.60 354.41 5,965,341.60 1,489,863.12 2.91 -425.17 MWD+IFR-AK-CAZ-SC(2) 2.327.03 29.87 91.61 2,231.41 2,160.27 -297.86 381.33 5,965,339.79 1,489,890.01 3.53 -438.52 NOT an Actual Survey 10-3/4"x 13-1/2" 2,365.41 31.02 90.20 2,264.49 2,193.35 -298.17 400.77 5,965,339.10 1,489,909.44 3.53 -447.62 MWD+IFR-AK-CAZ-SC(3) 2,424.38 32.03 91.55 2,314.76 2,243.62 -298.64 431.60 5,965,338.00 1,489,940.25 2.09 -462.04 MWD+IFR-AK-CAZ-SC(3) 2,517.81 34.80 89.04 2,392.74 2,321.60 -298.87 483.04 5,965,336.75 1,489,991.67 3.31 -485.59 MWD+IFR-AK-CAZ-SC(3) 2,566.25 36.22 84.71 2,432.18 2,361.04 -297.32 511.12 5,965,337.73 1,490,019.77 5.96 -496.95 MWD+IFR-AK-CAZ-SC(3) 2,613.31 37.63 80.97 2,469.80 2,398.66 -293.78 539.15 5,965,340.71 1,490,047.87 5.64 -506.53 MWD+IFR-AK-CAZ-SC(3) 2,660.42 38.20 77.76 2,506.97 2,435.83 -288.43 567.60 5,965,345.48 1,490,076.41 4.36 -514.68 MWD+IFR-AK-CAZ-SC(3) 2,704.07 39.18 72.09 2,541.05 2,469.91 -281.33 593.91 5,965,352.05 1,490,102.87 8.42 -520.30 MWD+IFR-AK-CAZ-SC(3) 2,751.19 40.52 71.21 2,577.23 2,506.09 -271.82 622.57 5,965,360.98 1,490,131.71 3.09 -524.83 MWD+IFR-AK-CAZ-SC(3) 2,798.98 42.50 72.29 2,613.02 2,541.88 -261.91 652.65 5,965,370.29 1,490,161.98 4.41 -529.66 MWD+IFR-AK-CAZ-SC(3) 2,895.36 45.18 73.51 2,682.53 2,611.39 -242.30 716.45 5,965,388.61 1,490,226.16 2.92 -541.15 MWD+IFR-AK-CAZ-SC(3) 2,988.21 48.44 73.77 2,746.07 2,674.93 -223.24 781.40 5,965,406.36 1,490,291.47 3.52 -553.65 MWD+IFR-AK-CAZ-SC(3) 3,082.85 51.77 73.58 2,806.76 2,735.62 -202.83 851.07 5,965,425.37 1,490,361.53 3.52 -567.10 MWD+IFR-AK-CAZ-SC(3) 3,178.61 52.15 73.25 2,865.77 2,794.63 -181.30 923.35 5,965,445.43 1,490,434.22 0.48 -580.73 MWD+IFR-AK-CAZ-SC(3) 3,273.43 52.23 73.42 2,923.90 2,852.76 -159.82 995.12 5,965,465.47 1,490,506.40 0.16 -594.17 MWD+IFR-AK-CAZ-SC(3) 3,367.32 52.15 71.32 2,981.46 2,910.32 -137.35 1,065.80 5,965,486.51 1,490,577.52 1.77 -606.25 MWD+IFR-AK-CAZ-SC(3) 3,462.18 52.24 72.67 3,039.61 2,968.47 -114.19 1,137.08 5,965,508.23 1,490,649.24 1.13 -617.97 MWD+IFR-AK-CAZ-SC(3) 3,555.95 54.07 73.78 3,095.84 3,024.70 -92.54 1,208.93 5,965,528.43 1,490,721.50 2.17 -631.29 MWD+IFR-AK-CAZ-SC(3) 3,644.87 55.06 74.48 3,147.39 3,076.25 -72.73 1,278.61 5,965,546.83 1,490,791.57 1.28 -645.28 MWD+IFR-AK-CAZ-SC(3) 3,739.15 55.55 72.80 3,201.06 3,129.92 -50.89 1,352.98 5,965,567.17 1,490,866.36 1.55 -659.59 MWD+IFR-AK-CAZ-SC(3) 3,833.30 55.54 70.94 3,254.33 3,183.19 -26.74 1,426.76 5,965,589.84 1,490,940.60 1.63 -671.56 MWD+IFR-AK-CAZ-SC(3) 3,926.57 55.28 70.04 3,307.28 3,236.14 -1.10 1,499.13 5,965,614.02 1,491,013.47 0.84 -681.57 MWD+IFR-AK-CAZ-SC(3) 6/24/2015 2:49:41PM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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) (°/100') (ft) Survey Tool Name 4,020.60 55.52 68.48 3,360.67 3,289.53 26.31 1,571.51 5.965,639.96 1,491,086.38 1.39 -690.01 MWD+IFR-AK-CAZ-SC(3) 4,115.00 55.30 67.23 3,414.26 3,343.12 55.60 1,643.49 5,965,667.80 1,491,158.92 1.11 -696.59 MWD+IFR-AK-CAZ-SC(3) 4,208.62 55.05 67.13 3,467.73 3,396.59 85.41 1,714.33 5,965,696.17 1,491,230.34 0.28 -702.19 MWD+IFR-AK-CAZ-SC(3) 4,303.28 54.87 67.95 3,522.08 3,450.94 115.02 1,785.95 5,965,724.34 1,491,302.54 0.73 -708.32 MWD+IFR-AK-CAZ-SC(3) 4,397.20 54.82 68.78 3,576.16 3,505.02 143.33 1,857.33 5,965,751.21 1,491,374.47 0.72 -715.50 MWD+IFR-AK-CAZ-SC(3) 4,491.83 54.83 69.63 3,630.67 3,559.53 170.79 1,929.64 5,965,777.21 1,491,447.31 0.73 -723.86 MWD+IFR-AK-CAZ-SC(3) 4,586.53 55.16 71.83 3,685.00 3,613.86 196.39 2,002.86 5,965,801.32 1,491,521.02 1.93 -734.30 MWD+IFR-AK-CAZ-SC(3) 4,680.72 55.49 73.71 3,738.59 3,667.45 219.33 2,076.84 5,965,822.77 1,491,595.44 1.68 -747.44 MWD+IFR-AK-CAZ-SC(3) 4,775.17 55.38 73.00 3,792.18 3,721.04 241.60 2,151.35 5,965,843.54 1,491,670.39 0.63 -761.42 MWD+IFR-AK-CAZ-SC(3) 4,868.74 55.44 72.15 3,845.30 3,774.16 264.67 2,224.85 5,965,865.13 1,491,744.32 0.75 -774.24 MWD+IFR-AK-CAZ-SC(3) 4,962.98 55.58 73.26 3,898.66 3,827.52 287.76 2,299.01 5,965,886.72 1,491,818.93 0.98 -787.33 MWD+IFR-AK-CAZ-SC(3) 5,057.92 55.16 68.66 3,952.63 3,881.49 313.23 2,372.83 5,965,910.70 1,491,893.23 4.01 -798.15 MWD+IFR-AK-CAZ-SC(3) 5,151.05 55.08 66.11 4,005.90 3,934.76 342.60 2,443.34 5,965,938.64 1,491,964.32 2.25 -803.99 MWD+IFR-AK-CAZ-SC(3) 5,246.55 55.14 67.14 4,060.52 3,989.38 373.68 2,515.24 5,965,968.27 1,492,036.83 0.89 -808.95 MWD+IFR-AK-CAZ-SC(3) 5,340.35 54.99 69.39 4,114.24 4,043.10 402.15 2,586.67 5,965,995.30 1,492,108.80 1.97 -816.00 MWD+IFR-AK-CAZ-SC(3) 5,434.22 55.03 68.24 4,168.07 4,096.93 429.95 2,658.37 5,966,021.64 1,492,181.05 1.00 -823.79 MWD+IFR-AK-CAZ-SC(3) 5,528.02 54.99 70.41 4,221.86 4,150.72 457.07 2,730.26 5,966,047.32 1,492,253.46 1.90 -832.26 MWD+IFR-AK-CAZ-SC(3) 5,623.34 54.90 73.38 4,276.62 4,205.48 481.32 2,804.41 5,966,070.07 1,492,328.08 2.55 -844.32 MWD+IFR-AK-CAZ-SC(3) 5,716.54 55.05 73.05 4,330.11 4,258.97 503.36 2,877.48 5,966,090.63 1,492,401.57 0.33 -857.85 MWD+IFR-AK-CAZ-SC(3) 5,811.87 55.03 71.28 4,384.74 4,313.60 527.29 2,951.85 5,966,113.06 1,492,476.40 1.52 -870.30 MWD+IFR-AK-CAZ-SC(3) 5,906.61 54.91 72.00 4,439.12 4,367.98 551.72 3,025.48 5,966,136.01 1,492,550.50 0.64 -881.95 MWD+IFR-AK-CAZ-SC(3) 6,001.11 54.89 73.72 4,493.46 4,422.32 574.51 3,099.35 5,966,157.30 1,492,624.81 1.49 -895.19 MWD+IFR-AK-CAZ-SC(3) 6,095.27 55.05 75.32 4,547.51 4,476.37 595.08 3,173.66 5,966,176.38 1,492,699.51 1.40 -910.59 MWD+IFR-AK-CAZ-SC(3) 6,189.23 55.54 74.06 4,601.01 4,529.87 615.48 3,248.16 5,966,195.27 1,492,774.40 1.22 -926.23 MWD+IFR-AK-CAZ-SC(3) 6,282.38 55.58 71.54 4,653.70 4,582.56 638.20 3,321.53 5,966,216.51 1,492,848.21 2.23 -939.31 MWD+IFR-AK-CAZ-SC(3) 6,375.92 55.54 70.18 4,706.60 4,635.46 663.49 3,394.41 5,966,240.33 1,492,921.58 1.20 -949.86 MWD+IFR-AK-CAZ-SC(3) 6,470.15 55.25 69.37 4,760.11 4,688.97 690.30 3,467.19 5,966,265.67 1,492,994.87 0.77 -959.01 MWD+IFR-AK-CAZ-SC(3) 6,564.26 54.90 70.24 4,813.99 4,742.85 716.94 3,539.60 5,966,290.85 1,493,067.80 0.84 -968.15 MWD+IFR-AK-CAZ-SC(3) 6,658.47 54.95 71.11 4,868.13 4,796.99 742.45 3,612.36 5,966,314.89 1,493,141.05 0.76 -978.45 MWD+IFR-AK-CAZ-SC(3) 6,751.57 55.04 73.02 4,921.54 4,850.40 765.93 3,684.91 5,966,336.91 1,493,214.05 1.68 -990.46 MWD+IFR-AK-CAZ-SC(3) 6,846.20 54.91 70.78 4,975.86 4,904.72 790.00 3,758.56 5,966,359.49 1,493,288.17 1.94 -1,002.45 MWD+IFR-AK-CAZ-SC(3) 6,942.62 55.02 70.56 5,031.21 4,960.07 816.14 3,833.06 5,966,384.12 1,493,363.17 0.22 -1,012.99 MWD+IFR-AK-CAZ-SC(3) 7,037.00 54.90 68.98 5-,085.40 5,014.26 842.86 3,905.56 5,966,409.37 1,493,436.19 1.38 -1,022.10 MWD+IFR-AK-CAZ-SC(3) 7,130.46 54.91 68.23 5,139.13 5,067.99 870.75 3,976.76 5,966,435.83 1,493,507.93 0.66 -1,029.57 MWD+IFR-AK-CAZ-SC(3) 7,224.78 55.46 70.84 5,192.99 5,121.85 897.82 4,049.30 5,966,461.43 1,493,580.99 2.35 -1,038.38 MWD+IFR-AK-CAZ-SC(3) 7,319.18 55.38 69.29 5,246.57 5,175.43 924.31 4,122.36 5,966,486.45 1,493,654.57 1.35 -1,047.94 MWD+IFR-AK-CAZ-SC(3) 7,414.45 55.46 70.53 5,300.64 5,229.50 951.26 4,196.02 5,966,511.91 1,493,728.75 1.07 -1,057.38 MWD+IFR-AK-CAZ-SC(3) 7,507.70 55.42 71.48 5,353.54 5,282.40 976.25 4,268.64 5,966,535.44 1,493,801.85 0.84 -1,068.07 MWD+IFR-AK-CAZ-SC(3) 7,602.40 55.39 71.68 5,407.31 5,336.17 1,000.88 4,342.60 5,966,558.58 1,493,876.28 0.18 -1,079.70 MWD+IFR-AK-CAZ-SC(3) 7,696.71 55.46 71.39 5,460.83 5,389.69 1,025.48 4,416.25 5,966,581.68 1,493,950.41 0.26 -1,091.23 MWD+IFR-AK-CAZ-SC(3) 6/24/2015 2:49:41PM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 7,790.69 55.25 71.61 5,514.25 5.443 11 1,050.01 4,489.57 5,966,604.74 1,494,024.21 0.29 -1,102.66 MWD+IFR-AK-CAZ-SC(3) 7,883.95 54.92 71.33 5,567.63 5,496.49 1,074.31 4,562.08 5,966,627.57 1,494,097.18 0.43 -1,113.92 MWD+IFR-AK-CAZ-SC(3) 7,919.48 54.48 71.01 5,588.16 5,517.02 1,083.67 4,589.53 5,966,636.38 1,494,124.81 1.44 -1,118.04 MWD+IFR-AK-CAZ-SC(3) 7,977.75 54.20 70.27 5,622.13 5,550.99 1,099.37 4,634.19 5,966,651.17 1,494,169.78 1.14 -1,124.34 MWD+IFR-AK-CAZ-SC(4) 8,072.31 55.16 70.84 5,676.80 5,605.66 1,125.05 4,706.95 5,966,675.38 1,494,243.03 1.13 -1,134.48 MWD+IFR-AK-CAZ-SC(4) 8,167.35 55.57 71.46 5,730.82 5,659.68 1,150.31 4,780.95 5,966,699.15 1,494,317.52 0.69 -1,145.57 MWD+IFR-AK-CAZ-SC(4) 8,261.96 55.25 70.41 5,784.53 5,713.39 1,175.75 4,854.56 5,966,723.11 1,494,391.62 0.97 -1,156.32 MWD+IFR-AK-CAZ-SC(4) 8,356.04 55.14 70.51 5,838.23 5,767.09 1,201.59 4,927.36 5,966,747.47 1,494,464.92 0.15 -1,166.35 MWD+IFR-AK-CAZ-SC(4) 8,448.58 55.17 69.92 5,891.10 5,819.96 1,227.30 4,998.83 5,966,771.74 1,494,536.88 0.52 -1,175.89 MWD+IFR-AK-CAZ-SC(4) 8,543.23 55.58 69.29 5,944.88 5,873.74 1,254.44 5,071.83 5,966,797.41 1,494,610.41 0.70 -1,184.85 MWD+IFR-AK-CAZ-SC(4) 8,637.60 55.67 68.33 5,998.17 5,927.03 1,282.59 5,144.45 5,966,824.09 1,494,683.58 0.85 -1,192.73 MWD+IFR-AK-CAZ-SC(4) 8,731.78 55.41 68.04 6,051.46 5,980.32 1,311.45 5,216.54 5,966,851.49 1,494,756.23 0.38 -1,199.75 MWD+IFR-AK-CAZ-SC(4) 8,826.39 55.17 67.93 6,105.33 6,034.19 1,340.60 5,288.65 5,966,879.19 1,494,828.90 0.27 -1,206.51 MWD+IFR-AK-CAZ-SC(4) 8,921.26 55.23 68.17 6,159.47 6,088.33 1,369.72 5,360.90 5,966,906.85 1,494,901.72 0.22 -1,213.37 MWD+IFR-AK-CAZ-SC(4) 9,015.29 55.28 69.33 6,213.07 6,141.93 1,397.73 5,432.91 5,966,933.40 1,494,974.27 1.02 -1,221.11 MWD+IFR-AK-CAZ-SC(4) 9,106.95 55.02 69.51 6,265.44 6,194.30 1,424.17 5,503.33 5,966,958.41 1,495,045.20 0.33 -1,229.52 MWD+IFR-AK-CAZ-SC(4) 9,203.16 55.16 66.59 6,320.51 6,249.37 1,453.66 5,576.50 5,966,986.42 1,495,118.94 2.49 -1,236.46 MWD+IFR-AK-CAZ-SC(4) 9,295.27 54.19 63.80 6,373.78 6,302.64 1,485.17 5,644.71 5,967,016.56 1,495,187.76 2.69 -1,239.35 MWD+IFR-AK-CAZ-SC(4) 9,391.99 54.00 61.89 6,430.50 6,359.36 1,520.92 5,714.41 5,967,050.90 1,495,258.17 1.61 -1,239.14 MWD+IFR-AK-CAZ-SC(4) 9,486.28 53.84 59.41 6,486.03 6,414.89 1,558.26 5,780.82 5,967,086.90 1,495,325.31 2.13 -1,236.02 MWD+IFR-AK-CAZ-SC(4) 9,581.07 53.99 55.42 6,541.88 6,470.74 1,599.51 5,845.35 5,967,126.83 1,495,390.65 3.41 -1,228.56 MWD+IFR-AK-CAZ-SC(4) 9,675.68 54.70 52.05 6,597.04 6,525.90 1,644.98 5,907.31 5,967,171.04 1,495,453.51 2.99 -1,216.18 MWD+IFR-AK-CAZ-SC(4) 9,768.98 55.10 48.51 6,650.70 6,579.56 1,693.75 5,966.00 5,967,218.62 1,495,513.16 3.13 -1,199.37 MWD+IFR-AK-CAZ-SC(4) 9,863.74 55.88 43.78 6,704.40 6,633.26 1,747.83 6,022.27 5,967,271.56 1,495,570.50 4.19 -1,176.72 MWD+IFR-AK-CAZ-SC(4) 9,958.90 56.08 38.62 6,757.67 6,686.53 1,807.15 6,074.19 5,967,329.82 1,495,623.60 4.50 -1,147.44 MWD+IFR-AK-CAZ-SC(4) 10,052.51 56.29 31.92 6,809.80 6,738.66 1,870.59 6,119.06 5,967,392.34 1,495,669.73 5.95 -1,111.28 MWD+IFR-AK-CAZ-SC(4) 10,100.29 56.34 29.62 6,836.31 6,765.17 1,904.75 6,139.39 5,967,426.08 1,495,690.75 4.01 -1,090.08 MWD+IFR-AK-CAZ-SC(4) 10,146.62 56.31 27.41 6,862.00 6,790.86 1,938.62 6,157.80 5,967,459.58 1,495,709.83 3.97 -1,068.26 MWD+IFR-AK-CAZ-SC(4) 10,241.44 55.89 22.96 6,914.90 6,843.76 2,009.81 6,191.28 5,967,530.07 1,495,744.73 3.92 -1,020.03 MWD+IFR-AK-CAZ-SC(4) 10,335.09 56.34 18.23 6,967.14 6,896.00 2,082.56 6,218.61 5,967,602.25 1,495,773.51 4.22 -967.62 MWD+IFR-AK-CAZ-SC(4) 10,428.10 57.43 15.85 7,017.95 6,946.81 2,157.03 6,241.42 5,967,676.24 1,495,797.82 2.44 -911.62 MWD+IFR-AK-CAZ-SC(4) 10,522.29 59.40 10.82 7,067.31 6,996.17 2,235.07 6,259.88 5,967,753.89 1,495,817.84 5.01 -850.46 MWD+IFR-AK-CAZ-SC(4) 10,617.45 59.63 8.04 7,115.59 7,044.45 2,315.96 6,273.32 5,967,834.49 1,495,832.90 2.53 -784.49 MWD+IFR-AK-CAZ-SC(4) 10,712.08 60.82 5.04 7,162.59 7,091.45 2,397.55 6,282.66 5,967,915.86 1,495,843.87 3.03 -716.04 MWD+IFR-AK-CAZ-SC(4) 10,810.41 63.06 2.40 7,208.85 7,137.71 2,484.12 6,288.26 5,968,002.30 1,495,851.22 3.29 -641.44 MWD+IFR-AK-CAZ-SC(4) 10,900.70 65.52 359.78 7,248.02 7,176.88 2,565.44 6,289.79 5,968,083.57 1,495,854.38 3.78 -569.68 MWD+IFR-AK-CAZ-SC(4) 10,993.06 68.91 357.58 7,283.79 7,212.65 2,650.55 6,287.81 5,968,168.70 1,495,854.11 4.28 -492.95 MWD+IFR-AK-CAZ-SC(4) 11,086.91 72.16 355.95 7,315.06 7,243.92 2,738.88 6,282.81 5,968,257.10 1,495,850.88 3.83 -411.97 MWD+IFR-AK-CAZ-SC(4) 11,181.88 75.13 353.64 7,341.80 7,270.66 2,829.61 6,274.53 5,968,347.97 1,495,844.43 3.90 -327.37 MWD+IFR-AK-CAZ-SC(4) 11,230.57 76.05 351.23 7,353.92 7,282.78 2,876.36 6,268.32 5,968,394.83 1,495,839.16 5.15 -282.90 MWD+IFR-AK-CAZ-SC(4) 6/24/2015 2:49:41PM Page 5 COMPASS 5000.1 Build 65 III i Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 11.274.75 76.22 348.91 7,364.51 7,293.37 2,918.60 6,260.92 5,968,437.21 1,495,832.62 5.11 -241.90 MWD+IFR-AK-CAZ-SC(4) 11,325.21 76.04 346.16 7,376.61 7,305.47 2,966.43 6,250.35 5,968,485.24 1,495,823.01 5.30 -194.49 MWD+IFR-AK-CAZ-SC(4) 11,370.66 76.13 344.15 7,387.54 7,316.40 3,009.07 6,239.05 5,968,528.10 1,495,812.57 4.30 -151.36 MWD+IFR-AK-CAZ-SC(4) 11,464.46 78.20 340.06 7,408.38 7,337.24 3,096.08 6,210.94 5,968,615.64 1,495,786.22 4.79 -61.08 MWD+IFR-AK-CAZ-SC(4) 11,559.02 79.52 338.43 7,426.65 7,355.51 3,182.83 6,178.06 5,968,703.03 1,495,755.09 2.19 31.14 MWD+IFR-AK-CAZ-SC(4) 11,653.18 79.94 338.00 7,443.44 7,372.30 3,268.86 6,143.67 5,968,789.73 1,495,722.44 0.63 123.41 MWD+IFR-AK-CAZ-SC(4) 11,746.76 80.47 337.23 7,459.36 7,388.22 3,354.13 6,108.56 5,968,875.68 1,495,689.05 0.99 215.32 MWD+IFR-AK-CAZ-SC(4) 11,787.61 80.57 336.85 7,466.09 7,394.95 3,391.23 6,092.84 5,968.913 08 1,495,674.08 0.95 255.51 MWD+IFR-AK-CAZ-SC(4) 11,836.73 81.62 338.28 7,473.69 7,402.55 3,436.08 6,074.32 5,968,958.30 1,495,656.47 3.59 303.89 5 ,v,,„.,r.„y:; 7-5/8"x 9-7/8"by 11" 11,858.82 82.10 338.92 7,476.82 7,405.68 3,456.44 6,066.34 5,968,978.81 1,495,648.90 3.59 325.65 MWD+IFR-AK-CAZ-SC(5) 11,954.94 85.95 338.44 7,486.82 7,415.68 3,545.48 6,031.59 5,969,068.52 1,495,615.95 4.04 420.76 MWD+IFR-AK-CAZ-SC(5) 12,003.28 87.53 337.43 7,489.57 7,418.43 3,590.20 6,013.46 5,969,113.60 1,495,598.72 3.88 468.84 MWD+IFR-AK-CAZ-SC(5) 12,050.62 88.99 333.77 7,491.01 7,419.87 3,633.29 5,993.92 5,969,157.07 1,495,580.05 8.32 516.10 MWD+IFR-AK-CAZ-SC(5) 12,096.96 90.39 336.08 7,491.26 7,420.12 3,675.25 5,974.28 5,969,199.42 1,495,561.26 5.83 562.41 MWD+IFR-AK-CAZ-SC(5) 12,144.17 91.65 332.36 7,490.42 7,419.28 3,717.75 5,953.75 5,969,242.31 1,495,541.60 8.32 609.59 MWD+IFR-AK-CAZ-SC(5) 12,240.10 92.69 332.64 7,486.78 7,415.64 3,802.78 5,909.49 5,969,328.21 1,495,499.05 1.12 705.45 MWD+IFR-AK-CAZ-SC(5) 12,335.16 92.85 331.13 7,482.19 7,411.05 3,886.52 5,864.75 5,969,412.83 1,495,456.01 1.60 800.38 MWD+IFR-AK-CAZ-SC(5) 12,430.89 93.07 328.79 7,477.25 7,406.11 3,969.28 5,816.89 5,969,496.52 1,495,409.83 2.45 895.84 MWD+IFR-AK-CAZ-SC(5) 12,526.15 91.39 329.27 7,473.54 7,402.40 4,050.89 5,767.91 5,969,579.10 1,495,362.50 1.83 990.79 MWD+IFR-AK-CAZ-SC(5) 12,620.63 90.82 328.46 7,471.72 7,400.58 4,131.75 5,719.07 5,969,660.91 1,495,315.30 1.05 1,085.01 MWD+IFR-AK-CAZ-SC(5) 12,716.49 90.27 328.39 7,470.81 7,399.67 4,213.41 5,668.88 5,969,743.56 1,495,266.76 0.58 1,180.56 MWD+IFR-AK-CAZ-SC(5) 12,811.66 90.44 327.84 7,470.22 7,399.08 4,294.22 5,618.61 5,969,825.36 1,495,218.13 0.60 1,275.38 MWD+IFR-AK-CAZ-SC(5) 12,907.34 90.31 328.78 7,469.59 7,398.45 4,375.63 5,568.35 5,969,907.76 1,495,169.52 0.99 1,370.74 MWD+IFR-AK-CAZ-SC(5) 13,002.43 90.34 329.29 7,469.05 7,397.91 4,457.17 5,519.42 5,969,990.25 1,495,122.25 0.54 1,465.60 MWD+IFR-AK-CAZ-SC(5) 13,097.19 90.38 329.20 7,468.46 7,397.32 4,538.60 5,470.97 5,970,072.64 1,495,075.44 0.10 1,560.15 MWD+IFR-AK-CAZ-SC(5) 13,192.34 90.34 330.04 7,467.86 7,396.72 4,620.68 5,422.85 5,970,155.66 1,495,028.98 0.88 1,655.13 MWD+IFR-AK-CAZ-SC(5) 13,287.66 90.31 329.15 7,467.32 7,396.18 4,702.89 5,374.61 5,970,238.82 1,494,982.41 0.93 1,750.28 MWD+IFR-AK-CAZ-SC(5) 13,383.21 90.27 328.83 7,466.83 7,395.69 4,784.78 5,325.38 5,970,321.68 1,494,934.84 0.34 1,845.60 MWD+IFR-AK-CAZ-SC(5) 13,478.68 90.45 328.75 7,466.23 7,395.09 4,866.43 5,275.91 5,970,404.30 1,494,887.03 0.21 1,940.81 MWD+IFR-AK-CAZ-SC(5) 13,574.78 90.41 327.97 7,465.51 7,394.37 4,948.25 5,225.50 5,970,487.10 1,494,838.27 0.81 2,036.59 MWD+IFR-AK-CAZ-SC(5) 13,670.67 90.17 326.70 7,465.03 7,393.89 5,028.97 5,173.75 5,970,568.84 1,494,788.16 1.35 2,132.01 MWD+IFR-AK-CAZ-SC(5) 13,765.05 89.83 325.11 7,465.03 7,393.89 5,107.12 5,120.85 5,970,648.04 1,494,736.84 1.72 2,225.66 MWD+IFR-AK-CAZ-SC(5) 13,861.43 88.85 324.58 7,466.14 7,395.00 5,185.92 5,065.36 5,970,727.93 1,494,682.95 1.16 2,321.06 MWD+IFR-AK-CAZ-SC(5). 13,956.92 89.16 323.39 7,467.80 7,396.66 5,263.14 5,009.22 5,970,806.26 1,494,628.38 1.29 2,415.36 MWD+1FR-AK-CAZ-SC(5) 14,052.20 87.86 323.96 7,470.27 7,399.13 5,339.88 4,952.80 5,970,884.11 1,494,573.51 1.49 2,509.34 MWD+IFR-AK-CAZ-SC(5) 14,146.65 88.07 324.27 7,473.63 7,402.49 5,416.35 4,897.47 5,970,961.67 1,494,519.74 0.40 2,602.60 MWD+IFR-AK-CAZ-SC(5) 14,242.02 89.43 323.66 7,475.71 7,404.57 5,493.45 4,841.38 5,971,039.88 1,494,465.21 1.56 2,696.76 MWD+IFR-AK-CAZ-SC(5) 14,337.84 89.49 325.34 7,476.61 7,405.47 5,571.45 4,785.74 5,971,118.98 1,494,411.16 1.75 2,791.52 MWD+IFR-AK-CAZ-SC(5) 14,433.63 89.45 325.23 7,477.50 7,406.36 5,650.19 4,731.19 5,971,198.79 1,494,358.21 0.12 2,886.44 MWD+IFR-AK-CAZ-SC(5) 14,528.60 89.90 324.02 7,478.03 7,406.89 5,727.62 4,676.21 5,971,277.31 1,494,304.80 1.36 2,980.39 MWD+IFR-AK-CAZ-SC(5) 6/24/2015 2:49:41PM Page 6 COMPASS 5000.1 Build 65 • • Schlurnberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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 14,623.53 90.41 325.31 7,477.78 7:406.64 5,805.06 4,621.31 5,971,355.83 1,494,251.47 1.46 3,074.32 MWD+IFR-AK-CAZ-SC(5) 14,718.57 90.48 326.93 7,477.04 7,405.90 5,883.96 4,568.33 5,971,435.77 1,494,200.09 1.71 3,168.67 MWD+IFR-AK-CAZ-SC(5) 14,813.45 91.17 327.50 7,475.67 7,404.53 5,963.72 4,516.96 5,971,516.54 1,494,150.34 0.94 3,263.05 MWD+IFR-AK-CAZ-SC(5) 14,908.17 91.68 328.09 7,473.32 7,402.18 6,043.84 4,466.50 5,971,597.65 1,494,101.50 0.82 3,357.35 MWD+1FR-AK-CAZ-SC(5) 15,005.03 91.99 329.86 7,470.22 7,399.08 6,126.80 4,416.60 5,971,681.59 1,494,053.28 1.85 3,453.92 MWD+IFR-AK-CAZ-SC(5) 15,099.85 91.85 331.48 7,467.04 7,395.90 6,209.41 4,370.19 5,971,765.11 1,494,008.54 1.71 3,548.61 MWD+IFR-AK-CAZ-SC(5) 15,194.76 90.86 330.52 7,464.80 7,393.66 6,292.40 4,324.19 5,971,849.00 1,493,964.22 1.45 3,643.43 MWD+IFR-AK-CAZ-SC(5) 15,289.95 90.21 331.00 7,463.91 7,392.77 6,375.46 4,277.69 5,971,932.97 1,493,919.41 0.85 3,738.54 MWD+IFR-AK-CAZ-SC(5) 15,385.57 89.90 332.19 7,463.81 7,392.67 6,459.56 4,232.21 5,972,017.97 1,493,875.62 1.29 3,834.13 MWD+1FR-AK-CAZ-SC(5) 15,481.41 90.00 334.69 7,463.90 7,392.76 6,545.28 4,189.36 5,972,104.52 1,493,834.51 2.61 3,929.96 MWD+IFR-AK-CAZ-SC(5) 15,577.24 90.27 334.35 7,463.67 7,392.53 6,631.79 4,148.13 5,972,191.83 1,493,795.03 0.45 4,025.76 MWD+IFR-AK-CAZ-SC(5) 15,672.86 90.24 332.55 7,463.25 7,392.11 6,717.32 4,105.39 5,972,278.20 1,493,754.02 1.88 4,121.37 MWD+IFR-AK-CAZ-SC(5) 15,767.90 90.07 332.62 7,462.99 7,391.85 6,801.69 4,061.63 5,972,363.42 1,493,711.97 0.19 4,216.41 MWD+IFR-AK-CAZ-SC(5) 15,863.55 90.07 334.86 7,462.87 7,391.73 6,887.46 4,019.32 5,972,450.02 1,493,671.39 2.34 4,312.04 MWD+IFR-AK-CAZ-SC(5) 15,959.16 90.07 335.46 7,462.76 7,391.62 6,974.23 3,979.15 5,972,537.57 1,493,632.98 0.63 4,407.58 MWD+IFR-AK-CAZ-SC(5) 16,053.65 90.55 336.06 7,462.24 7,391.10 7,060.38 3,940.36 5,972,624.48 1,493,595.93 0.81 4,501.96 MWD+IFR-AK-CAZ-SC(5) 16,149.69 90.86 337.22 7,461.06 7,389.92 7,148.54 3,902.28 5,972,713.38 1,493,559.64 1.25 4,597.80 MWD+IFR-AK-CAZ-SC(5) 16,244.80 91.24 336.62 7,459.32 7,388.18 7,236.02 3,865.00 5,972,801.59 1,493,524.13 0.75 4,692.67 MWD+1FR-AK-CAZ-SC(5) 16,339.52 91.00 335.44 7,457.47 7,386.33 7,322.56 3,826.53 5,972,888.87 1,493,487.40 1.27 4,787.24 MWD+IFR-AK-CAZ-SC(5) 16,435.31 90.93 334.51 7,455.86 7,384.72 7,409.34 3,786.02 5,972,976.45 1,493,448.64 0.97 4,882.96 MWD+IFR-AK-CAZ-SC(5) 16,530.34 91.17 333.94 7,454.11 7,382.97 7,494.90 3,744.70 5,973,062.82 1,493,409.06 0.65 4,977.95 MWD+IFR-AK-CAZ-SC(5) 16,624.65 91.03 332.00 7,452.30 7,381.16 7,578.89 3,701.85 5,973,147.64 1,493,367.91 2.06 5,072.24 MWD+IFR-AK-CAZ-SC(5) 16,719.72 91.62 329.51 7,450,10 7,378.96 7,661.81 3,655.42 5,973,231.48 1,493,323.16 2.69 5,167.20 MWD+IFR-AK-CAZ-SC(5) 16,815.82 90.93 329.10 7,447.97 7,376.83 7,744.43 3,606.38 5,973,315.05 1,493,275.79 0.84 5,263.08 MWD+IFR-AK-CAZ-SC(5) 16,911.12 91,10 326.93 7,446.28 7,375,14 7,825.24 3,555.91 5,973,396.86 1,493,226.96 2.28 5,357.99 MWD+IFR-AK-CAZ-SC(5) 17,006.56 90.53 326.24 7,444.92 7,373.78 7,904.90 3,503.36 5,973,477.55 1,493,176.02 0.94 5,452.83 MWD+1FR-AK-CAZ-SC(5) 17,103.41 91.28 325.52 7,443.39 7,372.25 7,985.07 3,449.04 5,973,558.79 1,493,123.33 1.07 5,548.92 MWD+IFR-AK-CAZ-SC(5) 17,197.56 90.99 323.91 7,441.53 7,370.39 8,061.90 3,394.66 5,973,636.69 1,493,070.52 1.74 5,642.06 MWD+IFR-AK-CAZ-SC(5) 17,292.54 89.94 321.04 7,440.75 7,369.61 8,137.22 3,336.82 5,973,713.15 1,493,014.20 3.22 5,735.43 MWD+IFR-AK-CAZ-SC(5) 17,387,17 90.17 323.08 7,440.66 7,369.52 8,211.84 3,278.64 5,973,788.93 1,492,957.54 2.17 5,828.33 MWD+IFR-AK-CAZ-SC(5) 17,482.45 90.24 324.69 7,440.32 7,369.18 8,288.81 3,222.48 5,973,867.00 1,492,902.94 1.69 5,922.41 MWD+IFR-AK-CAZ-SC(5) 17,576.01 90.17 326.51 7,439.99 7,368.85 8,366.01 3,169.63 5,973,945.24 1,492,851.65 1.95 6,015.18 MWD+IFR-AK-CAZ-SC(5) 17,672.94 90.55 327.58 7,439.38 7,368.24 8,447.34 3,116.90 5,974,027.60 1,492,800.58 1.17 6,111.59 MWD+IFR-AK-CAZ-SC(5) 17,768.78 90.27 328.92 7,438.69 7,367.55 8,528.83 3,066.47 5,974,110.09 1,492,751,80 1.43 6,207.09 MWD+IFR-AK-CAZ-SC(5) 17,864.16 89.85 331.78 7,438.59 7,367.45 8,611.71 3,019.29 5,974,193.90 1,492,706.30 3.03 6,302.36 MWD+IFR-AK-CAZ-SC(5) 17,960.66 90.77 332.41 7,438.07 7,366.93 8,696.99 2,974.13 5,974,280.06 1,492,662.86 1.16 6,398.85 MWD+IFR-AK-CAZ-SC(5) 18,055,16 90.65 334.11 7,436.90 7,365.76 8,781.37 2,931.62 5,974,365.27 1,492,622.06 1.80 6,493.34 MWD+IFR-AK-CAZ-SC(5) 18,150.49 90.58 335.18 7,435.88 7,364.74 8,867.51 2,890.80 5,974,452.21 1,492,582.98 1.12 6,588.62 MWD+IFR-AK-CAZ-SC(5) 18,245.34 90.96 335.78 7,434.60 7,363.46 8,953.80 2,851.44 5,974,539.27 1,492,545.36 0.75 6,683.37 MWD+IFR-AK-CAZ-SC(5) 18,340.88 91.13 337.05 7,432.86 7,361.72 9,041.35 2,813.22 5,974,627.55 1,492,508.91 1.34 6,778.72 MWD+IFR-AK-CAZ-SC(5) 6/24/2015 2:49:41PM Page 7 COMPASS 5000.1 Build 65 110 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well CD5-04 Project: Western North Slope TVD Reference: CD5-04:34.2+36.94©71.14usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: CD5-04:34.2+36.94 @ 71.14usft(Doyon 19) Well: CD5-04 North Reference: True Wellbore: CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04 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) (°/1001 (ft) Survey Tool Name 18,436.02 91.24 337.07 7,430.89 7,359.75 9,128.94 2,776.14 5,974,715.87 1,492:473.61 0.12 6,873.60 MWD+IFR-AK-CAZ-SC(5) 18,531.47 90.55 336.77 7,429.40 7,358.26 9,216.74 2,738.73 5,974,804.40 1,492,437.97 0.79 6,968.82 MWD+IFR-AK-CAZ-SC(5) 18,627.69 90.55 337.95 7,428.48 7,357.34 9,305.54 2,701.69 5,974,893.92 1,492,402.73 1.23 7,064.75 MWD+IFR-AK-CAZ-SC(5) 18,721.67 91.26 338.22 7,426.99 7,355.85 9,392.72 2,666.62 5,974,981.77 1,492,369.42 0.81 7,158.35 MWD+IFR-AK-CAZ-SC(5) 18,818.34 93.05 336.27 7,423.36 7,352.22 9,481.79 2,629.26 5,975,071.58 1,492,333.86 2.74 7,254.68 MWD+IFR-AK-CAZ-SC(5) 18,863.00 93.05 336.27 7,420.98 7,349.84 9,522.62 2.611 32 5,975,112.75 1.492,316.74 0.00 7.299.20 NOT an A i j 4-1/2"x 6-1/2" 18.878.00 93.05 336.27 7,420.18 7,349.04 9,536.33 2,605.29 5,975,126.58 1,492,310.99 0.00 7,314.16 PROJECTED to TD 6/24/2015 2:49.41PM Page 8 COMPASS 5000.1 Build 65 • • Y O n p Q O C y.% O O v W L5 m a _ O . m _c O vt j L C L - c O V—L ¢ N (.0 Cp d8 N m N g C u, .— p .. qj O O ti w +' ^ g m ui 0) (—NO AQ tv d w co y w 62) d C v mo4 W 43 R c o N 0 ° 2, c TR,_En : z E a`) o CD ���. . a) c v cal s o c 0 c = 4 O U U W d o >. 03 toca.) o p - Uo I- a ooc � co r. aC _ '^ . = Q) = u_ w } 2v) OOa) ° to ooa E fa > As Q — > w to 0 U) CD v) T 0 Q ce Y Ac a) 5 • a 0 0 -o N 1- 0 0 0 -0 0 1- a)a) ._ O 0 C MO W it co Om coco 0 0 3c , 00 E o S s N O o 0 0 50CD N DO' n \ O W O \ N +- O • v •[ r 41. O 0 0 -O N CI 0 O 0 O 0 O I I I coo 0 0 0 0 0 0 O O O O O 0 CO (ui�isn000Z) (+)4 oN/(-)u�nos N 0 • 0 0 0 rn CD5-04 .. • IC D5-04wp15.1 0 o 1 ':878 CN 6 ■O x 18000 O 4.d - _o 0 N T co 117000 cn c o N _o = 16000 vin o 0 in T O 15000 0 0 o ri -O M co 000i'1 r5 C O 0 o O O 13000 r 0 U O O 000$ I = > 0 O 7r O cr) co L1♦ T( D t) O Q OT1 o 0 O M 0 I o1 0 I o1 0 I 0I 0 0 0 0 0 Ln o Ln o in T co(ui,�sn 0051) u}daa Ieoco ian anal • • SI y w o >- CD5-04wp15.1 0 '4 p 7p CD5-04 N T a) W 1$000 iv T O C - V 'O^ co 0 I— 7000 c.) a) cn O —O III 16000 v 0 O O c6 co co c� 5000 0 O t O U O co co 000171- Q) O O 13000 - J. 0 I 00@P 1 - T 0 _oM N. —O 0001 x1 x 009 Co ____ O O O O O O O LC) O Lf) O Ln O-) O N co Lc) co co uldea 1E0RJ8A anal r-- • • vs. CD5-04wp15.1 Comparison View O-e0. _.__ - - _ - 20"x 42" —0' 1080 —_.9,0' 10-3/4"x 13-1/2" co 0 c o Ao 1 A O �— _.__ d a OP o I 7-5/8"x 9-7/8"by 11" 4-1/2"x 6-1'2" so O ..O O0 I 0 0 S p I o 0 O n II i I I I I I I I I I I I - I I I I I I I I I 101 I I O I I pI I ® I O I I OI I I i I I 14 I I 5 1 1 0 850 1700 2550 3400 4250 5100 5950 6800 7650 8500 9350 10200 11050 11900 12750 13600 14450 1 -00 c 158— --- S S IT) c 0 N- c 0 1.c-7j 105-- c`u a CD fn GD5-04 a) c U 53— o m U • 0 II I I I I I I I I I I I I I I I 1 I I I 1 I 1 1 1 1 I 1 1 0 2250 4500 6750 9000 11250 13500 15750 180001 20250 Measured Depth (3000 usft/in) - P 6— I —6 LCU - Kalubik ,� I C\ HRZ l tri�z A> - ,.� 1 - rn I __ _7-5/8"x 9-7/8"by 11" cm ca a 3— I I —3 �/ II\ UJU ,I ' \\, /,\Iii j V V 10-3/"x 13-/ ii A N 11 \,/ V Ease rmafrost 1l ` M I K 2/ AIb9 I (_\,„ / ' 1 I I I I' I I 1 I1 . I I 1 1 I 1 0 3500 7000 10500 14000 17500 20"x 42" Measured Depth • • wp vs. CD5-04wp15.1 Comparison View Alpine A UJU _ _ - _ LCU _� Kalubik 70— K3 K2 Alb97 AIb96 HRZ ,-5/8"x 9-7/8"by 11" —70 c iu - C30 Base Permafros- _ - 10-3/4"x 13-1/2" - 0 - 0 0 3500 7000 10500 14000 17500 20"x 42" Measured Depth Alpine A C30 LCU �- Kalubik 7-5/8"x 9-7/8"by 11" - HRZ - 11\ J, a Base P f -� .,;(1,, K3 K2 AIb97 AIb96 - m J 3/�"�x 13- /� � �� 4 ^ 0— I \y I Hu1 Intn'1 : Y - 0 3500 7000 10500 14000 17500 Measured Depth _ Base Permafrost UJU Kalubik LCU ', Alpine A - C30 K3 K2 AIb97 AIb96 HRZ ` ' i E i i� a 0— Y T �� - —0 d 0 -20"x42' 10-3/4"x 13-1/2" 7-5/8"x 9-7/8"by 11" - I I I 1I I I II i I I 1 I I I 1 I I I I I 0 3500 7000 10500 14000 17500 Measured Depth UJU- - Base Permafrost s Alpine A Kalubik LCU - C K3 K2 AIb97 AIb96 HRZ � i i - c 0 , -- ' ' - ' ' 4, VA/ —0c U -20"x 42" 10- 4" 3-/2" 7-5/8" ,9-7/8"by 11" m 0 v I I I 1 I I I I I I I I I I I I I I 1 1 I I ' 0 3500 7000 10500 14000 17500 Measured Depth • • Bettis, Patricia K (DOA) 71 From: Bettis, Patricia K (DOA) Sent: Friday, May 15, 2015 9:33 AM To: 'Knock, Douglas G'; Dai, Weifeng (Weifeng.Dai@conocophillips.com) Cc: Loepp,Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: CD5-313 Development Well Doug, Thank you for meeting with us on May 14, 2015 to discuss the CD5-314 well. The AOGCC understands that ConocoPhillips plans to drill the CD5-313 well immediately after the CD5-04 well. The CD5- 04 is expected to spud early the week of May 18th and take approximately 35 days to drill. The CD5-313 will be the replacement well for the CD5-314 which was suspended after encountering shallow water flow between 400-530'. ConocoPhillips plans to run a full suite of logs, including neutron, density and mud log,from base of conductor to total depth in the CD5-313 pilot hole. With this understanding, recording of the neutron-density logs within the surface and intermediate holes for CD5-04 and CD5-05 is not required. Running a mud log within CD5-04 and CD5-05 also is not required. Please submit the permit to drill application for CD5-313 as soon as possible. As discussed in the meeting, if CD5-313 is not drilled,the AOGCC will required recording of the neutron, density, mud logs within the CD5-05 well. 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 • • , Tp 215- 6' 7 Loepp, Victoria T (DOA) From: Dai,Weifeng <Weifeng.Dai@conocophillips.com> Sent: Monday, May 11, 2015 1:04 PM To: Bettis, Patricia K(DOA) Cc: Loepp, Victoria T (DOA); Knock, Douglas G;Stinson, Rob D Subject: RE: CD5-Pad Wells Attachments: CD5-314 Suspension Schematic_5.10.15.pdf; CD5-314PB1 LWD and Temp logs.pptx Follow Up Flag: Follow up Flag Status: Completed Good morning, Patricia, Hope you had a good weekend. As you well know, ConocoPhillips continued diagnostic job to locate and kill the water flow from CD5-314 annulus and made significant progress during the weekend when communication was established after cut casing at 440' MD.The cement was pumped and plugged the channel successfully,the well was secured by now. From what we did,we can narrow down the source of water in the range of 440'to 710' MD.The Neutron/Density logs were run in the surface section drilling operation in CD5-314 already. CD5-04 is originally the second well in the pad after CD5-314 but now was forced to move forward to allow sufficient time to put together a new plan to replace the abandoned CD5-314,the CD5-314 replacer is planned to spud right after CD5-04.The Combo LWD log include Neutron/Density will be run in the pilot hole in the replacing well regardless if we run combo log in CD5-04 or not as it provides much better information to log in the near vertical pilot hole through the entire sand than log in a landing hole in CD5-04, let alone the much lesser operation risks, such as BHA with RA source stuck in high angle well. With this being said, ConocoPhillips is hereby apply for the permission to NOT run Neutron/Density in the surface and intermediate hole intervals for the next well CD5-04,we will run mud logging through the well per the state requirement. Please refer to the attached suspension schematic and our geologists'estimation of water source based on current info, please let me know if you have any questions.Thank you for the consideration. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, May 05, 2015 1:53 PM To: Dai, Weifeng Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: CD5-Pad Wells Good afternoon Weifeng, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. Thank you, 1 • . Patricia From: Dai, Weifeng (mailto:Weifeng.Dai@conocophillics.com] Sent:Tuesday, May 05, 2015 1:12 PM To: Bettis, Patricia K(DOA) Cc: Loepp,Victoria T(DOA) Subject: RE:CD5-Pad Wells Hi, Patricia, A quick update on the diagnostic operation for the water flow zone in last few days:we perforated a few intervals(one interval at a time)from the bottom of casing and attempted to establish communication but no indication of any communication so far.Our next zone of interest is right below the base of permafrost which we will perforate and try to build communication. Please refer to the attached PDF file. After secure current well CD5-314, ConocoPhillips is planning to drill CD5-04 which target to the east in adjacent to existing CD2 wells which means little geology uncertainty.The plan after CD5-04 is to use another slot to drill CD5-314 target which is to the south of the pad with much more geology uncertainty, a pilot hole is also planned drilled deeper than in CD5-04 to acquire formation information with combo log. It is more of ConocoPhillips interest to run combo log in this well other than CD5-04. Please advise if the plan above meet requirement of state and let me know if you have any question/comment.Thank you. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, April 29, 2015 2:56 PM To: Dai, Weifeng; Samuell, John G Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]CD5-Pad Wells Good afternoon Weifeng and John, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. For the next CD5 well, CD5-04 or CD5-05, has ConocoPhillips considered setting the surface casing higher? If so,at what height above the C-30 would the casing shoe be set? Thank you, Patricia From: Dai,Weifeng[mailto:Weifeng.Dai@conocophillips.com] Sent:Wednesday,April 29, 2015 1:32 PM 2 • • To: Bettis, Patricia K(DOA) Subject: Mudlog CD5-Pad Hi, Patricia, We will run mudlog in intermediate section as per the request. Please advise if we need run Combo LWD log(include Neutron/Density) in intermediate section BHA in CD5-04 or CD5-05, (we obtained Combo LWD log in surface section in first well CD5-314, so I assume Combo LWD log is not needed for surface section anymore). Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Samuell, John G Sent: Wednesday, April 29, 2015 11:39 AM To: Dai, Weifeng; Earhart, Will C Subject: RN: [EXTERNAL]Mudlog CD5-Pad Fyi Sent with Good(www.good.com) From: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Sent:Wednesday,April 29, 2015 2:14:45 PM To:Samuell,John G Cc: Loepp,Victoria T(DOA) Subject: [EXTERNAL]Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. 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 3 . • S . Q rt r0 O o N n N n' Oro r 0 K (7 0) r-P p = N• r t ( L c cu C) a• � m = o. •u ff •v I f , , , , : , , . I I r . 1 , . , I 0 CO V 01 to .a W m3 O O O O O O O O 0 0 0 O O oo V o Schrader Bluff Prince Creek Z22 '� i ' , 1 1 h rL.M l v "t: N``' r, 1 lr,N,' i l 'c V' M '.Y 'Iri• S' " VV�1', 1 I li 1 Ytt4 Ifs' Y}f �t Y 0. 0 Ul• A i.,,/- t\: t 11 , 1ir'''y ir)r14. . Nii? I I /0 .i q V\I ..,_, 1 UJ. , . t. \; \ fk\Lr\\11\d\ A , ' \\it, kil ,,,, c. ,_., 4-'41 ..' , ', . 1,,,,,t t y oI a u� co / 1 Q m 0 0 _ o o lv n O c• O it n, C (D CD5-314 Kuparuk Producer: Actual SuspensionSchematic — 05.10.15 16 bbl 15.7 ppg D19 RKB-37' AS 1 Cement Plug- 20"Insulated Conductor:116'MD 205'-40' I 4.5bbI 15.7 AS1 Cement Top Job Remove Wellhead ' Conductor x 10-3."Annulus Verify cement at surface in conductor and surface casing Q 0 10-3/4"Baker Mechanic Set Cmt Wire%4'thick cover plate over all casing strings Retainer:205'MD/205'TVD 150 bbl 11&15.7 ppg LC&AS 1 Casing Cut: Cover Plate Diagram: CemenCSqueeze- _ (11.83",21.9"OD Cuts): No returns to surface 235'MD/235'TVD 10-3/4"Baker Mechanic Set Cmt Top View 0 0 i Retainer:413'MD/413'TVD r 42 bbl 15.7 ppg Casing Cut: 0 20" , Arctic Set 1 1 (11.83"OD Cuts): Cement Squeezed- 440'MD/440'TVD r No returns to surface 10-3/4"HES EZ Drill SVB Squeeze Packer w/BP Conversion: O 480'MD/480'TVD Top:607'MD/607'TVD Casing Cut: 13.5 bbl 15.7 ppg (11.83",21.9",31.18"OD Cuts): ArcticSetl Nom710'MD/710'TVD ConocoPhillips Alaska, Inc Cement Plug I ,,i, 10-3/4"HES EZ Drill SVB l C D 5 314 • Squeeze Packer w/BP PTD # 215-039 Q Conversion:750'MD/750'TVD Top:1,065'MD/1,065'TVD t ` API # 50-103-20707-00-00 12.5 bbl 15.7 ppg Casing Cut Arctic Set 1e, (11.83",21.9",31.18"OD Cuts): Cement Plug 1,165'MD/1,161'TVD 01/8"Diameter Weep `= ----------- .---- Hole Drilled In Cover �/ 4 10-3/4"Halliburton EZ Drill SVB Plate / .rY/ Q O Squeeze Packer w/BP - - Conversion:1,195'MD/1,190'TVD __ Top:1,250'MD/1,245'TVD Casing Cut III 17 bbl 15.7 ppg (11.83",21.9",31.18"OD Cuts): Arctic Set 1 1,350'MD/1,342'TVD Cement Plug Perf Intervat:(2 Shots:4-5/8") (1 Shot-3-5/8") '1/2°1 Top:1,374'MD/1,365'TVD -nay Btm:1,395'MD/1,385'TVD Top:1,411'MD/1,400'TVD 34.1 bbl 15.8 ppg Perf Interval:(3 Shots:3-3/8") Qannik Top:1,730'MD/1,696'TVD PIP, Cement Plug .",,,s Btm:1,750'MD/1,714'TVD 10-3/4"Baker Mechanic Set Cmt 0 t Retainer:1,760'MD/1,723'TVD Top:1,787'MD/1,745'TVD iiiii,-.... 10 bbl 15.8 ppg Perf Interval:(1 Shot:3-3/8") Pip- Qannik Top:1,874'MD/1,825'TVD Cement Plug Btm:1,880'MD/1,830'TVD Q r J, 103/4"Baker E-Line Set Cmt Retainer:1,892'MD/1,841'TVD Top:1,912'MD/1,858'TVD pini- 20 bbl 15.8 ppg Perf Intervai:(2 Shots:4-5/8") P., Qannik • Top:2,089'MD/2,010'TVD Cement Plug Btm:2,100'MD/2,019'TVD • Q O 10-3/4"Baker E-Line Set Cmt r Retainer:2,125'MD/2,040'TVD 10-3/4"Baker Mechanical Cmt Q Q ` Retainer:2,405'MD/2,252'TVD i 10-3/4"Casing Shoe: y 2,419.7'MD/2,262.8 TVD at 45.89° 1 15.8 Cement Squeeze 1 9-7/8"Rat Hole: LOT to 14.8 ppg EMW(4/25/2015) 2,450'MD/2,284 TVD at 45° *Not To Scale • • PTP 072 Loepp, Victoria T (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Tuesday, May 05, 2015 1:57 PM To: Bettis, Patricia K (DOA) Cc: Loepp, Victoria T(DOA) Subject: RE:CD5-Pad Wells Follow Up Flag: Follow up Flag Status: Flagged Hi, Patricia, That's what we are doing now, I will keep you and Victoria posted. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K(DOA) [mailto:patricia.bettisPalaska.gov] Sent: Tuesday, May 05, 2015 1:53 PM To: Dai, Weifeng Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: CD5-Pad Wells Good afternoon Weifeng, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. Thank you, Patricia From: Dai,Weifeng[mailto:Weifeng.Dai@conocophillips.com] Sent:Tuesday, May 05,2015 1:12 PM To: Bettis, Patricia K (DOA) Cc: Loepp,Victoria T(DOA) Subject: RE: CD5-Pad Wells Hi, Patricia, A quick update on the diagnostic operation for the water flow zone in last few days:we perforated a few intervals(one interval at a time)from the bottom of casing and attempted to establish communication but no indication of any communication so far. Our next zone of interest is right below the base of permafrost which we will perforate and try to build communication. Please refer to the attached PDF file. After secure current well CD5-314,ConocoPhillips is planning to drill CD5-04 which target to the east in adjacent to existing CD2 wells which means little geology uncertainty.The plan after CD5-04 is to use another slot to drill CD5-314 target which is to the south of the pad with much more geology uncertainty,a pilot hole is also planned drilled deeper 1 • • than in CD5-04 to acquire formation information with combo log. It is more of ConocoPhillips interest to run combo log in this well other than CD5-04. Please advise if the plan above meet requirement of state and let me know if you have any question/comment.Thank you. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K(DOA) [ iailto:patricia.bettis(dalaska.gov] Sent: Wednesday, April 29, 2015 2:56 PM To: Dai, Weifeng; Samuell, John G Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]CD5-Pad Wells Good afternoon Weifeng and John, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. For the next CD5 well,CD5-04 or CD5-05, has ConocoPhillips considered setting the surface casing higher? If so, at what height above the C-30 would the casing shoe be set? Thank you, Patricia From: Dai,Weifeng [ ailto:Weifeng.Dai@conocophillips.com] Sent:Wednesday,April 29, 2015 1:32 PM To: Bettis, Patricia K(DOA) Subject: Mudlog CD5-Pad Hi, Patricia, We will run mudlog in intermediate section as per the request. Please advise if we need run Combo LWD log(include Neutron/Density) in intermediate section BHA in CD5-04 or CD5-05, (we obtained Combo LWD log in surface section in first well CD5-314, so I assume Combo LWD log is not needed for surface section anymore). Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Samuell, John G Sent: Wednesday, April 29, 2015 11:39 AM To: Dai, Weifeng; Earhart, Will C Subject: FW: [EXTERNAL]Mudlog CD5-Pad Fyi 2 . a s • Sent with Good(www.good.com) From: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Sent:Wednesday, April 29,2015 2:14:45 PM To:Samuell,John G Cc: Loepp,Victoria T(DOA) Subject: [EXTERNAL]Mudlog CDS-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. 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. 3 ®F 77.,;- ,e,-\1//7, • • , X1//7, sv THE STATE Alaska Oil and Gas ¶* *P °A..LA Conservation Commission � t y-= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®�"ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov Chip Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit, Alpine Oil Pool, CRU CD5-04 ConocoPhillips Alaska, Inc. Permit No: 215-072 Surface Location: 310' FNL, 2497' FEL, Sec. 18, Ti IN, R4E, UM Bottomhole Location: 1292' FNL, 5068' FEL, Sec. 5, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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 ConocoPhillips Alaska, Inc. in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. H2S analysis of hydrocarbon is required as a condition of approval of the permit to drill application. Mudlog will be recorded from the base of conductor to 7 5/8" casing shoe depth at approximately 11,791' MD (7,440' TVD). This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. • • Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, P9v,-,cL Cathy P. oerster Chair DATED this `day of May, 2015. STATE OF ALASKA APR 1 7 2015 A 'A OIL AND GAS CONSERVATION COME ON PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b. Proposed Well Class: Development-Oil C' . Service- Winj ❑ Single Zone ❑✓ • lc.Specify if well is proposed for: Drill E. Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket E - Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , CRU CD5-04 ' 3.Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 18792 • TVD: . 7394 Colville River Unit • 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Alpine Pool , Surface: 310'FNL,2497' FEL,Sec. 18,T11N, R4E,UM . ASRC NPR4,ASRC NPR2 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2181'FNL, 1780'FEL,Sec.5,T11N, R4E, UM 932671,932128 5/5/5015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1292'FNL,5068'FEL,Sec.5,T11N,R4E, UM . 15,912 AND 12614.53 37,000'to ADL 388466 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above I . 70.3 feet 15. Distance to Nearest Well Open Surface: x- 349481 y- 5965899 Zone- 4 • GL Elevation above I • 34 feet to Same Pool: 1500' 16.Deviated wells: Kickoff depth: . 484 feet 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 90 degrees Downhole: 3,695 Surface: 2,956 ' 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) 42" 20" 94 L-80 Welded 80 30 36 110 110 6 yds. 13-1/2" 10-3/4" 45.5 L-80 H-563/BTC 2467 36 36 2503 2351 1,178 sx 11.2 ppg G,273 sx 15.8 ppg G 9-7/8 x 11" 7-5/8" 29.7 L-80 H-563/BTC 11755 36 36 11791 7440 249 sx 15.8 ppg G 6-3/4" 4-1/2" 12.6 L-80 IBTM 7192 11600 7420 18792 7341 n/a 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 4/17/2015 22. I hereby certify that the foregoing is true and correct. Will Earhart- 265-1077 Contact /t Email William.C.Earhart(a�cop.com Printed Name / • �( L_ 4(Va Title Drilling Manager A Signature /\. ; /(A 0A,_ Phone 265-6120 Date 4/17/2015 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: ° h- D�Z 50- O O oo - Date: . � 1 3- � ill- rs'/t--(/ 20 I S requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: u Other X36 p tc 5 �p r�5 5(-'TC 15 35-&67,5 L / Samples req'd: Yes ❑y No[0 Mud log req'd:Yes❑ No[f u1 +''/- 1 V�lit moi- f-t$C p/'Cs5 tz. H2S measures: Yes No❑ Directional svy req'd:Yes No❑ 4s--- Spacing exception req'd: Yes ❑ No0' Inclination-only svy req'd:Yes❑ No❑' 2 57,0 p5 i APPROVED BY Approved by: (Gy COMMISSIONER THE COMMISSION-PM Date: ��(S ftil ^ t' ����/� Submit Form and Form 10-40(� sed0/212)/� 7 ti i6 vaI nitt.t.h.,from the date of appj val(20 AAC 25.005(g)) Attachments in Duplicate 0/ V V ,�i Y�/3� ConocoPhillips Alaska,Inc. Post Oie Box 10 990 ConocoPhillips Anchorage,Alaska 99510-0360 r] Telephone 907-276-1215 I�� April 17,2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RECEIVED Re: Application for Permit to Drill CRU CD5-04 APR 1 7 2015 Dear Sir or Madam: AOGCC ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore production well from the CD5 drilling pad with rig Doyon 19. The intended spud date for CD5-04 is 7/1/2015. However, in the event the present well being drilled by Doyon 19✓ (CRU CD5-314)finds unsatisfactory results in its pilot hole, it would be desired to move the rig onto to CD5-04 as early as 5/5/15. i CRU CD5-04 is planned to be Alpine A sand producer. The 13-1/2"surface hole will TD above the C-30 sand and then 10-3/4" casing will be set. The intermediate section will be drilled with 9-7/8"x 11"underreamer BHA and Managed Pressure Drilling technology. This hole will be subsequently cased with a 7-5/8"casing string to surface and cemented to 500' above the uppermost hydrocarbon bearing interval. The suface by intermediate casing annulus will then be evaluated for future annular disposal by performing a leak-off test. The 6-3/4"production section will then be horizontally drilled and completed as a Alpine A sand producer. The well will be completed with a 4-1/2"solid liner with frac sleeves across the productive zone and tied back to surface with a 3-1/2"gas- lifted upper completion string. It is the intention of ConocoPhillips to hydruallically fracture CD5-04 at a later date. Please find attached the information required by 20 AAC 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 AAC 25.005(a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 AAC 25.035 (d)(2) 6. Directional drilling/collision avoidance information as required by 20 AAC 25.050(b) 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 AAC 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 Will Earhart at 265-1077 (William.C.EarhartAConocoPhillips.com)or Chip Alvord at 265-6120. Sincerely, cc: CD5-04 Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1720 Chip Alvord ATO 1570 Will Earhart Mandy Pogany ATO 1766 Drilling Engineer Lanston Chin Kuukpik Corp • Applic.for Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 CD5-04 Application for Permit to Drill Document Drilling &wells ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.0050 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005 (c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(I1) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD5-04 APD Page 1 of 15 Printed: 17-Apr-15 Applic.for Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005 (c)(14) 15. Attachments 10 Attachment 1 Cement Summary 11 Attachment 2 Drilling Hazards Summary 11 Attachment 3 Completion Schematic 15 Attachment 4 Directional Plan 16 CD5-04 APD Page 2 of 15 Printed: 17-Apr-15 Applicifor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as CRU CD5-04. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for Location at Surface 310'FNL,2497' FEL, Sec. 18,T11N,R4E,UM NAD 1927 RKB Elevation 70.3' AMSL Northings: 5,965,899 Eastings: 349,481 Pad Elevation 34.0' AMSL Top of Productive Horizon(Heel) 2181'FNL, 1780'FEL, Sec. 5,T11N,R4E,UM NAD 1927 Measured Depth, RKB: 11,791' Northings: 5,969,189 Total Vertical Depth, RKB: 7,440' Eastings: 355,532 Total Vertical Depth, SS: 7,370' Total Depth (Toe) 1292'FNL, 5068'FEL, Sec. 5,T11N,R4E,UM NAD 1927 Measured Depth, RKB: 18,792' Northings: 5,975,421 Total Vertical Depth, RKB: 7,394' Eastings: 352,345 Total Vertical Depth, SS: 7,324' Requirements of 20 AAC 25.050(b) Please see Attachment 4: 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 and diverter schematics on file for Doyon 19. CD5-04 APD Page 3 of 15 Printed: 17-Apr-15 AO ApplicSfor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 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: Casing Size Csg Setting Depth Fracture Pore pressure ASP Drilling (in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 20 110/ 110 10.9 50 51 10.75 2,503/ 2,351 14.5 1,061 1,537 7.625 11,791/7,440 12.5 3,545 2,956 N/A 18,792/7,394 12.5 3,695 N/A PROCEDURE FOR CALCULATING ANTICIPATED SURFACE PRESSURE(ASP) ASP is determined as the lesser of I)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 r Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 319 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 FPP=0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20"conductor ASP=[(FG x 0.052)-0.l] D = [(10.9 x 0.052)-0.1] x 110=51 psi OR ASP=FPP-(0.1 x D) = 1061-(0.1 x 2350')=826 psi 2. Drilling below 10-3/4" surface casing ASP=[(FG x 0.052)-0.1] D = [(14.5 x 0.052)-0.1] x 2350' = 1537 psi OR ASP=FPP-(0.1 x D) =3545-(0.1 x 7440')=2801 psi 3. Drilling below 7-5/8"intermediate casing ASP=[(FG x 0.052)-0.1] D = [(12.5 x 0.052)-0.1]x 7440=4092 psi OR ASP=FPP-(0.1 x D) =3695-(0.1 x 7394')=2956 psi (B)data on potential gas zones; CD5-04 APD Page 4 of 15 Printed: 17-Apr-15 • Applic.for Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 The well bore is not expected to penetrate any gas zones. (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; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) f) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 20 42 94 H-40 Welded 80 30/30 110/ 110 Previously Installed HYD Cement to Surface with 10-3/4 13.5 45.5 L-80 563 X 2,433 36/36 2,503/2,351 1178 sx ASLite Lead 11.2 ppg, BTCM 273 sx Class"G"Tail Slurry 15.8 ppg 9.875 HYD 7-5/8 x11 29.7 L-80 563 X 11,721 36/36 11,791/7,440 249 sx Class G at 15.8 ppg BTCM 4-1/2 6.75 12.6 L-80 IBT-M 7,192 11,600/7,421 18,792/7,394 N/A—uncemented liner with frac sleeves 3-1/2 6.75 9.3 L-80 EUE 11,564 36/36 11,600/7,421 N/A-production tubing 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2). CD5-04 APD Page 5 of 15 Printed: 17-Apr-15 Applid411 for Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate Production Hole Size in. 13.5 9.875 x 11 6.75 Casing Size in. 10.75 7.625 4.5 Density PPG 8.8— 10.0 9.6— 11.5 9.3-9.8 PV cP 30-80 10 10 YP Ib./100 ft2 100-200 20 - 28 10- 15 Funnel Viscosity s/qt. 300 50- 60 40- 50 Initial Gels lb./100 ft2 50 10 6 10 Minute Gels Ib./100 ft2 60 15 8 API Fluid Loss cc/30 min. N.C.— 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0— 12.0 10.0 pH 11.0 9.5- 10.0 9.0-9.5 Surface Hole: A mixed-metal oxide fresh water drilling fluid(Drilplex)will be used for the surface interval. Keep flow line viscosity at±200 sec/qt while drilling and running casing.Reduce viscosity prior to cementing. Maintain mud weight< 10.0 ppg by use of solids control system and dilutions where necessary. Intermediate#1: Fresh water gel/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at or below 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. The mud will be weighted up to 11.5 before pulling out of the hole. Note: Managed Pressure Drilling(MPD)will be utilized for added backpressure to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with a water-based mud drill-in fluid(FloPro)weighted to 9.8 ppg with calcium carbonate and KCl by section TD. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD5-04 APD Page 6 of 15 Printed: 17-Apr-15 • Applicipor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 9. Abnormally Pressured Formation Information (Requirements of20 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 of20AAC 25.005(x)(11)) N/A-Application is not for an offshore well. 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: Completion Schematic. 1. MIRU Doyon 19 onto CD5-04. 2. Rig up and test riser,dewater cellar as needed. 3. Rig up diverter and test. 4. Drill 13.5"hole to the surface casing point as per the directional plan(LWD Program: GR/RES). 5. Run and cement 10-3/4"surface casing to surface. 6. Install BOPE and MPD equipment. / 7. Test BOPE to 250 psi low/3500 psi high. �/ 8. Pick up and run in hole with 9-7/8"x 11"drilling BHA to drill the intermediate pilot hole section. 9. Pressure test casing to 3500 psi. 10. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.0 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 11. Drill 9-7/8"x 11"hole to section TD using Managed Pressure Drilling tmaintain constant bottom hole pressure on connections. 01,0vD n c-ovi 12. Run 7-5/8"casing and cement to 500' above hydrocarbon bearing zones. 13. Test BOPE to 250 psi low/3,500 psi high. 14. Pick up and run in hole with 6-3/4"drilling BHA.Pressure test casing to 3,500 psi. 15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 18 ppg. Minimum required leak-off value is 12.0 ppg EMW. 16. Drill 6-3/4"hole to section TD(LWD Program: GR/Azimuthal Res.). 17. Pull out of hole with drilling BHA. 18. RIH with 4.5"liner completion(solid liner with frac sleeves)on 4"drill pipe. 19. Set liner top packer and release from liner. 20. Displace well to seawater. 21. Run 3.5"upper completion. CD5-04 APD Page 7 of 15 Printed: 17-Apr-15 • Applic.or Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 22. Space out and land hanger. 23. Install 2-way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 24. Install tubing head adapter assembly.Pressure test adapter assembly to 5000 psi.Remove 2-way check. 25. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 26. Shear circulation valve in GLM. 27. Circulate tubing to diesel and install freeze protection in the annulus. 28. Set BPV and secure well. RDMO. CD5-04 APD Page 8 of 15 Printed: 17-Apr-15 Applicator Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Incidental fluids developed from drilling operations on well CD5-04 will be injected into a permitted annulus on the CD5 pad,or the Class 1 disposal well on CD1 pad(CD1-01A). The CD5-04 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include only the Alpine sand based on pre-drill interpretations.There will be 500' of cement fill placed above the top of the Alpine reservoir. Once CD5-04 has been drilled and completed,consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations,per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above,any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. 1 Surface casing will be set near the base of the Schrader Bluff Formation(C-40). These 450-500'thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes.Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection,the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure =(12.0 ppg) *(0.052)*(Surf. Shoe TVD)+ 1,500 psi =(12.0 ppg)*(0.052)*(2351')+ 1,500 psi =2967 psi Pore Pressure = 1,128 psi Therefore Differential=2967—1128= 1839 psi. The internal casing pressure is conservative,since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85%collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85%of Burst 85%of 030 Type Collapse Burst 10-3/4" 45.5 L-80 3 HYD563 2470 psi 2100 psi 5210 psi 4429 psi 10-3/4" 45.5 L-80 3 BTC-M 2470 psi 2100 psi 5210 psi 4429 psi 7-5/8" 29.7 L-80 3 HYD563 4790 psi 4071 psi 6890 psi 5856 psi 7-5/8" 29.7 L-80 3 BTC-M 4790 psi 4071 psi 6890 psi 5856 psi CD5-04 APD Page 9 of 15 Printed: 17-Apr-15 • Applicelfor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 15. Attachments Attachment 1 Cement Summary Attachment 2 Drilling Hazards Summary Attachment 3 Completion Schematic Attachment 4 Directional Plan CD5-04 APD Page 10 of 15 Printed: 17-Apr-15 Applicifor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 Attachment 1 —Cement Summary CD5-04 Cementing Program: CD5-04 wp10 Cementing Schematic 20"94#H-40 Welded Conductor to 110' 10-3/4"45.5#L-80 HYD563 X BTCM 2,503' MD/2,351'TVD @ 37°inc. 9-7/8"x 11" Hole Top of Cement 11,236' MD/7,320'TVD Alpine A 7-5/8"29.7#L-80 HYD563 X BTCM Casing 11,736'MD/7,434'TVD 11,791'MD/7,440'TVD@85° 6-3/4"Hole 4-1/2" Liner 12.6 ppf L80 IBT i• 18,792' MD./.7,.394'TVD @ 90° CD5-04 APD Page 11 of 15 Printed: 17-Apr-15 1111 Applicallor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 10.75" Surface Casing run to 2,503' MD/2,351' TVD Cement from 2503' MD to 2003'(500' of tail)with Class G+Adds. @ 15.8 PPG,and from 2003'to surface with 11.2 ppg Arctic Lite Crete. Assume 250%excess annular volume in permafrost and 50%excess below the permafrost(1608' MD), zero excess in 20"conductor. Lead slurry from 2,003' MD to surface with Arctic Lite Crete @ 11.2 ppg Conductor (110'—0') X 1.3645 ft3/ft X 1.0 (0%excess) = 150 ft3 Permafrost to Conductor (1,608'— 110') X 0.3637 ft3/ft X 3.5 (250%excess) = 1,907 ft3 Top of Tail to Permafrost (2,003'— 1,608')X 0.3637 ft3/ft X 1.5 (50%excess) = 215 ft3 Total Volume = 150 + 1,907 + 215 = 2,272 ft3=> 1,178 sx of 11.2 ppg Arctic Lite Crete @ 1.93 ft3 /sk Tail slurry from 2,470'MD to 1,970'MD with 15.8 ppg Class G + additives Shoe to Top of Tail (2,503'—2,003')X 0.3637 ft3/ft X 1.50 (50%excess) = 273 ft3 Shoe Joint (80')X 0.5400 ft3/ft X 1.0 (0%excess) = 43 ft3 Total Volume = 273 + 43 = 316 ft3 => 273 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8%S002 accelerator @ 1.16 ft3/sk 7.625"Intermediate Casing run to 11,791' MD/7,440' TVD Top of slurry is designed to be at 11,736' MD,which is 500' above the Alpine A.Assume 40%excess annular volume. Tail slurry from 11,791'MD to 11,200'MD with 15.8 ppg Class G + additives Shoe to Top of Cement (11,791'— 11,236)X 0.3428 ft3/ft X 1.40 (40%excess) = 267 ft3 Shoe Joint (80')X 0.2578 ft3/ft X 1.0 (0%excess) = 21 ft3 Total Volume = 267 + 21 = 288 ft3 => 249 sx of 15.8 ppg Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 0.8%S002 accelerator @ 1.16 ft3/sk CD5-04 APD Page 12 of 15 Printed: 17-Apr-15 Applicor Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 Attachment 2— Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 13-1/2" Hole/10-3/4"Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Gyro single shots,traveling cylinder diagrams Monitor well at base of permafrost,increased mud weight,decreased Gas Hydrates Low mud viscosity,increased circulating times,controlled drilling rates, low mud temperatures Running Sands and Gravel Low Maintain planned mud parameters,Increase mud weight,use weighted sweeps. Lost Circulation Low Reduced pump rates,mud rheology,lost circulation material,use of low density cement slurries 9-7/8"x 11"Hole/7-5/8"Casing Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology, lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills,increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers 6-3/4"/4-1/2"Liner Production Interval Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material Hole swabbing on trips Low Annular pressure applied by managed pressure drilling equipment. Abnormal Reservoir Pressure Low Well control drills,increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems, alarms,standard well control practices, mud scavengers a CD5-04 APD Page 13 of 15 Printed:17-Apr-15 Applicalior Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik and instability in the production interval will require higher mud weights and managed pressure drilling in order to stabilize the formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. CD5-04 APD Page 14 of 15 Printed: 17-Apr-15 • Applicator Permit to Drill,Well CRU CD5-04 Saved: 17-Apr-15 Attachment 3—Completion Schematic CD5 -04 Alpine A Producer Wp10 Proposed Schematic l>I 3 Upper Completion: Length 20"94#H-40 Welded 1)4-''/z°12.6#/ft IBT-M Tubing(2 its) �[ € Conductor to 110' XO to 3-Y2'EUE tubing 3)Shallow nipple profile 2)3-'/z°x 1"Camco KBMG GLM (xx°)w/DV 7' 3)3-Y2'x 1"Camco KBMG GLM(xx°)w/DV 7' 4)3-'/='x 1"Camco KBMG GLM(xx°)w/DCK2 7' pinned for 2500 psi casing to tbg shear a • 5)SLB BHP Gauge,Encapsulated I-Wire 1.5' "' w/cannon clamps on every joint ' ': 10-3/4" #L-80ssBTC 6)D nipple 2.812"ID 1.5' '�'� SurfaceaceCasing 7)�/yLEG 1.5' . 2,503'MD/2,351'TVD @ 42° cemented to surface Lower Completion: 8)ZXP Liner Top Packer& Flexlock Liner Hanger 37' XO 5"Hydril 521 Box X 4-%"IBTM pin 9)D nipple 2.750"ID 1.5' 10)4'/i", 12.6#/ft,L-80 IBT-M Liner w/ball actuated frac ports every-750' 11)Ball drop frac sleeves 3-1/2" 9.3#L-80 EUE • 7 5/8"29#L-80 Hyd 563 Intermediate Csg to 11,791'MD/7,440'TVD @85° Perforated Pup Top Reservoir at+i- Alpine A Sand `ail 7434'TVDAll ` 0 0 0 0 o O o 0 0 •0 ...._._.'ssi lii 4'/2"12.6#L-80 Liner 6-3/4"Hole TD w/ball drop frac sleeves 18,792'MD/7,394'TVD CD5-04 APD Page 15 of 15 Printed: 17-Apr-15 • 11) Loepp, Victoria T (DOA) From: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Wednesday,April 29, 2015 8:34 AM To: Loepp, Victoria T (DOA) Subject: RE:CRU CD5-04(PTD 215-072); CRU CD5-05(PTD 215-073) Victoria, Thanks for the email. Included are my responses to your questions. Please let me know if you have any further questions or concerns. 1. The diverter schematics both show a building(?)at the outlet identified as a truck loading area? Please clarify -he labeled :eraiL;i,. Lag pidnned truck unloading area- it's a containment area. It is not installed /et so it will not be in our way when we spud 2. Please provide the length of the diverter line 141 feet of 16" diverter line.This is same amount as what was rigged up on CD5-314(PTD 215-039) Since we do not have enough diverter line to reach out to the tundra on this well (due to the shape of the pad),we intend to restrict access to the rear side of the well row in excess to the 75' radius mandated exclusion zone as the tip of the line will be over the gravel. 3. For CD5-04(PTD 215-072),there is an anti-collision major risk failure with CD2-33. What mitigation measures will be in place to minimize this risk? The well called out CD2-33 was a Plugback abandoned in August 2001.Two open-hole cement plugs were used to isolate the Alpine sands-47.7bbl 15.8ppg"G" cement spotted on bottom @21,454' MD via balanced plug(calculate TOC 20,790'MD). Second plug laid on top of first-52.0bbl 15.8ppg"G" cement for final calculated top of cement of 20,340' MD (7,216'TVDss).Top Alpine C in CD2-33 was interpreted as 20,632' MD (7299'TVDss) We therefore judge the risk of a collision as minimal as the reservoir was competently isolated when abandoned. We will manage the deviation from our corporate anti-collision policy internally via the "Tolerable Collision Risk" process. The same will be completed for the anti-collision issue with exploration well "Nuiqsut 1"that was plugged and abandoned. 4. Please provide mitigation measures planned for dealing with the water that was encountered in CD5-314(PTD 215-039). At this time we are sourcing equipment to facilitate a 2-stage surface cement job along with an external casing- annulus packer to provide additional isolation from the water source on the next surface casing run. We have also discussed moving the surface casing shoe higher if we can confirm the water source is at/below the existing CD5-314 shoe. In the event the shoe depth is altered, we will submit a sundry to approved plan. As of today, we plan to further log CD5-314 to better determine where the water source is coming from. Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earharti conocophillips.com 1 0 • CD5-O4wpl 0 6913 Plan Summary LCU UJU - C30 , 1 Alpine A 5- Kalubik � 1 -5 j, HRZ f.. rase Bermafrost 7-5/8"x 9-7/8" '' FBasal AIb97 AIb96 - j - \ 11 K3 � 1 - 1 - - o / I 1 "I l 1 1 11 I 1 1 I I I I I I 11 D j'�Viip. .� 0 103/4 x 13-1/21600 9000 13500 18000 �' /f/ 120"x 421 Measured Depth 4-1/2"x 6-3/4" \\ N. , o -I20"x 42" Geodetic Datum: North American Datum 1983 0 • . .... p� J10-3/4"x 13-121 Depth Reference: Doyo 3;.9+36.3 @ 70.50usft(Doyon 19) `®7�� o , °$ yo°° o ce o° 10 °o .f?°° I7-08"x 9-7/8"1 4-1/2"x 6-3/4"1 / o °° °°° -- o r I i l I I I l I '<'5," d I r� da o f .l I 36 -- 484 o 2000 4000 6000 800 .100(0 o1200 oo14000 ^' 16001 CD 0.,07 0 Jcos-0.On) - 74 Horizontal Departure CD505.0'CD5 S,7-�• 774 - 1064 �cosae no7i 33bzo l� �I 1.. D5-e v.07 10640.511. 77 - 1344 a f cDs-1p"p01� ► 1344 - 1634 o 60 ��' ✓'� �" 3� Qr .` 0\iti 1634 - 1924 300 .0 ►- i 11�., + ,, 60 1924 - 2214 pn 0.04 fir2214 - 2503 if 0550Mw7 s i � � \`-cosoewo •: 11 Fj 30905164 - 5834 . I �- s�� `I I I , I i I I i i l i I i I I � �'� ,1 �. 7834 - 9334 0 3000 6000 9000 12000 15000 18000 z40� N-• zo � � ��'�;_ 9334 - 10834 ���\� ����-'' / 10834 - 12334 SURVEY PROGRAM ���� Surface Location �````� 2334 - 13834 fe th From Depth To Survey/Plan Tool `4���, p p Pad Elevation:34.20 ,�, o� �.750 13834 - 15344 36.30 850.00 CD5-04wp10(Plan:CD5-04) GYD-GC-SS 2t0` wr\i 5344 6644 850.00 1850.00 CD5-04wp10(Plan:CD5-04) MWD 850.00 2503.05 CD5-04wp10(Plan:CD5-04) MWD+IFR-AK-CAZ-SC CASING DETAILS 180 16844 18344 2503.05 4003.05 CD5-04wp10(Plan:CD5-04) MWD 18344 - 19844 2503.05 11791.86 CD5-04wp10(Plan:CD5-04) MWD+IFR-AK-CAZ-SC TVD MD Name M 11791.86 13291.86 CD5-04wp10(Plan:CD5-04) MWD 180.50 180.50 20"x 42" Magnetic Model: BGGM2014 T 11791.86 18792.44 CD5-04wp1 0(Plan:CD5-04) MWD+IFR-AK-CAZ-SC 2351.50 2503.05 10-3/4"x 13-1/2" Magnetic Model Date: 04-Dec-14 - 7440.50 11791.86 7-5/8"x 9-7/8" Magnetic Declination: 18.46° 7394.50 18792.44 4-1/2"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 18.46°East SECTION DETAILS 1570.5 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 2 484.20 0.00 0.00 484.20 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.61100'DLS,145°TF,for 150.04' Base Permafrost 3 634.24 2.40 145.00 634.20 -2.57 1.80 1.60 145.00 -3.11 Start 2.51100'DLS,0°TF,for 919.15' 4 1553.39 25.38 145.00 1520.50 -182.11 127.52 2.50 0.00 -220.15 Hold for 110.68' -2372.5 5 1664.07 25.38 145.00 1620.50 -220.97 154.73 0.00 0.00 -267.13 Start 3.51100'DLS,-93.65°TF,for 1512.25' 6 3176.32 55.50 69.94 2818.35 -276.73 985.92 3.50 -93.65 -694.16 Hold for 5854.2' 7 9030.52 55.50 69.94 6134.20 1378.13 5517.83 0.00 0.00-1277.12 Start 3.421100'DLS,-104.93°TF,for 2172.33' 8 11202.85 69.00 345.07 7307.46 2881.39 6194.93 3.42 -104.93 -245.10 Hold for 3.22' C30 9 11206.07 69.00 345.07 7308.61 2884.30 6194.16 0.00 0.00 -242.16 Start 3.511100'DLS,-40.77°TF,for 585.79' 10 11791.86 85.00 331.76 7440.50 3411.25 5983.41 3.51 -40.77 323.03 CD5-04 1.Heel 091014 JH Hold for 20' 11 11811.86 85.00 331.76 7442.24 3428.80 5973.99 0.00 0.00 342.95 Start 41100'DLS,0°TF,for 136.12' 12 11947.98 90.44 331.76 7447.65 3548.58 5909.66 4.00 0.00 478.88 Hold for 6844.46' - 13 18792.44 90.44 331.76 7394.50 9578.39 2671.56 0.00 0.00 7321.55 CD5-04 2.Toe 091014 JH TD:18792.44'MD,7394.5'TVD I(377837 -4028.2 Basal K2 -4475.2 AIb97 -5562.1 AIb96 TCR required �� -694- h +" .. ..� -j2 blk is subjectto Chane '` ""�" _7. ,I Alpine A ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Ifeanyi Ifesie Will Earhart • • 14:47,April 17 2015 Easting(5000 ustt/in) CD5- ` .. 02wp07 CD 1\ .'. ,,, D �' C/ e 3 22 CD2-74 , r se1T ` , C.DCS2P01P: CD-03wp0 CD2- \\:; '1 I ' CD i�'` CD g. e.wpo7 :. 1\b.., c\tlia, a �' e D1-47PB1 CD`12wp•`7 �. jy\\ �. .. 1135..7,4:: -, , RD1 CD -21`moi �� � i.. . : P:1 D2-7 Pct ,. �� lSi1-21PB1 I►,, d. � • '.6.'-‘6‘: \ � . .1.‘\• , i 4000 D1 .Pf�136 i A-28P: .0 --1 CD2- ��•�� � , c.4 #CD2-7. 641r Y,a. '� ,! CD2 Alpine Pa. • ', C. .� CD2- _� �.r- CD1-41P1 D 1 . t o .� .sut 1 ' �..2.;�•�-- a ,,\;-= CD -t'1 ..i45PB1 CD2- , ,��•�� � � A... .£D19 IT 26 00 !� �:I,: �0 I�I 1 CD.4.13 iti#107 004-07 / `� C . A 45 1-40 to CD5 Alpine West Pad /'� D2-33' CD2 4' ` Cc- 39 ell Ch -47• . . C D.�1" (' -47 p04 y i. \,8 2-51 Z CD2-,.1q p02 CD CD2- �; 7 CD-58L C. w2-•c CD5-0 • , �! C. �. �.,_59D 56D2-•7 CD5-05wp0• C. D4- 7 "-'c - CD2-61w 6 CD5-08wpe CD4- �� 0-1,,, , +38 p CD5-11wp07 CD 304-.x_'-'` 1 iii CD4 Nanuq Pae CD4-322 I_,��.. r' •'•- ....solo.— ��, e• ,,N— ...7.,., _CD4-3011 CD5-315PB1 wp10 `- ..I` - _ V/�' 1 CD5-314P81w 14 Cp ��r" ' P CD4 ?s�•'..:(�. Ili CD4- \,00# 00111-,,,,/!7/ CD4-290v .4-321 �1•; 1\, 4i (i. \ I a4-291PB `_ \ /.%f C 4 3 CD4-291 CD5-315 wp10 CD5-314wp14 �.•`4,/,,, . , -292 .. otic•!. -;)'56292 9 Easting(5000 ustt/in) I CD5-04wp10 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. �p�Q 10000- 4-1/2" x 6-3/4" CD5-04 2.Toe 091014 JH 8000— )\1 u qsut 000— luigsut 1I 6000- 0 0 N •+ 04000— z 7-5/8" x 9-7/8"- • --__ "75-041.HeeI091014 H n Q 2000— 7000 ww 0 0 • 0 0 0— n, o 20"x 42" n o 0 0 10-3/4" x 13-1/2" -4000 -2000 0 2000 4000 6000 8000 10000 12000 14000 West(-)/East(+) (2000 usft/in) • • CD5-04wp10 Section View 0_ A J L Base Permafrost 20" x 42" -0° 1000 C30 1500— -- - -- 1,i8P K3 m 10-3 x 13-1/2 30 Basal K2 03000— 00, ' 4060 ,, AIb97 6_ p -56-(41--. AIb96 75 4500--- 4t300-:,--/ > 70,0 Kalubik 1 '000 HRZ,' u 0 6000— �C UJU v 90..„p,'o" Alpine A 44. ,',4"0, O ' ' ,-a 0 0 7500— _ " n$- w a' cr., o a/ a CO 7-5/8"x 9-7/8" o g 0 0 ° o ' a-1/2"x@-3/4" O O O O O O O N 253 CD5-04 1.Heel 091014 H Nuiqsut 1 CD5 04 2.Toe 091014 H -3000 -1500 0 1500 3000 4500 6000 7500 9000 Vertical Section at 333.00° (1500 usft/in) ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-04 Plan: CD5-04 Plan: CD5-04wp10 TCR required Report 17 April,2015 11110 • Schlumberger Report Company. ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan.CD5-04 ' Project: Western North Slope TVD Reference: Plan:34.2+36.3©70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Slte CD5 Alpine West Pad Site Position: From: Map Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Well Plan:CD5-04 Well Position +N/-S 0.00 usft +E/-W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 34.20 usft Wellbore Plan:CD5-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 12/4/2014 18.46 80.76 57,543 Design CD5-04wp10 Audit Notes: Version: Phase: PLAN Tie On Depth: 36.30 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 36.30 0.00 0.00 333.00 4/17/2015 3:07.52PM Page 2 COMPASS 5000.1 Build 65 0 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-04 Project: Western North Slope ., TVD Reference: Plan:34.2+36.3 ll 70.50usft(Doyon 19) Site: CD5 Alpine West Pad °4 - •'a.e s ,�`., MD Reference: Plan:34.2+36.3©70.50usft(Doyon 19) Well: Plan:CD5-04 the line before it. North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Survey Tool Program Date 4/17/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 36.30 850.00 CD5-04wp10(Plan:CD5-04) GYD-GC-SS Gyrodata gyro single shots 850.00 1,850.00 CD5-04wp10(Plan:CD5-04) MWD MWD-Standard 850.00 2,503.05 CD5-04wp10(Plan:CD5-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,503.05 4,003.05 CD5-04wp10(Plan:CD5-04) MWD MWD-Standard 2,503.05 11,791.86 CD5-04wp10(Plan:CD5-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11,791.86 13,291.86 CD5-04wp10(Plan:CD5-04) MWD MWD-Standard 11,791.86 18,792.44 CD5-04wp10(Plan:CD5-04) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Multiply by 2.58 - Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace N/S E/W Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (^/10nusft) ("I (usft) (usft) (usft) (usft) 36.30 0.00 0.00 36.30 -34.20 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 29.50 0.00 0.00 0.00 0.00 0.05 1.15 180.50 0.00 0.00 180.50 110.00 0.00 0.00 0.00 0.00 0.19 1.15 20"x 42" 200.00 0.00 0.00 200.00 129.50 0.00 0.00 0.00 0.00 0.19 1.15 300.00 0.00 0.00 300.00 229.50 0.00 0.00 0.00 0.00 0.34 1.15 400.00 0.00 0.00 400.00 329.50 0.00 0.00 0.00 0.00 0.48 1.15 48420 0.00 0.00 484.20 413.70 0.00 0.00 0.00 0.00 0.60 1.15 KOP:Start 1.81100'DLS,145°TF,for 150.04' 500.00 0.25 145.00 500.00 429.50 1.60 145.00 -0.03 0.02 0.62 1.15 600.00 1.85 145.00 599.98 529.48 1.60 0.00 -1.53 1.07 0.65 1.16 634.24 2.40 145.00 634.20 563.70 1.60 0.00 -2.57 1.80 0.67 1.16 Start 2.51100'DLS,0°TF,for 919.15' 700.00 4.04 145.00 699.85 629.35 2.50 0.00 -5.60 3.92 0.72 1.16 800.00 6.54 145.00 799.42 728.92 2.50 0.00 -13.16 922 0.81 1.16 900.00 9.04 145.00 898.48 827.98 2.50 0.00 -2427 16.99 0.87 1.16 1,000.00 11.54 145.00 996.87 926.37 2.50 0.00 -38.91 27.24 0.96 1.16 1,100.00 14.04 145.00 1,094.38 1,023.88 2.50 0.00 -57.05 39.94 1.16 1.15 4/172015 3:07:52PM Page 3 COMPASS 5000.1 Build 65 i • Schlumberger Report Company. CanocoPhillips(Alaska)Inc-WNS Local Co-ordinate Reference: Well Plan CD5-04 Project: Western North Slope ND Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) . Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3(§70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace N/S EAN Let.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I1OOusft) (°) (usft) (usft) (usft) (usft) 1,200.00 16.54 145.00 1,190.83 1,120.33 2.50 0.00 -78.65 55.07 1.47 1.15 1,300.00 19.04 145.00 1286.03 1215.53 2.50 0.00 -103.68 72.60 1.88 1.15 1,400.00 21.54 145.00 1,379.82 1,309.32 2.50 0.00 -132.09 92.49 2.38 1.15 1,500.00 24.04 145.00 1,472.00 1,401.50 2.50 0.00 -163.83 114.71 2.95 1.15 1,553.39 25.38 145.00 1,520.50 1,450.00 2.50 0.00 -182.11 127.52 3.29 1.15 Hold for 110.e8' PRO :�. r 1,600.00 25.38 145.00 1,562.61 1,492.11 0.00 0.00 -198.48 138.97 3.60 1.16 1,608.73 25.38 145.00 1,570.50 1,500.00 0.00 0.00 -201.54 141.12 4.02 1.18 Base Permafrost I 1,664.07 25.38 145.00 1,620.50 1,550.00 0.00 0.00 -220.97 154.73 4.02 1.18 Start 3.5°/100'DLS,-93.65'TF,for 1512.25' 1,700.00 25.33 142.07 1,652.97 1,582.47 3.50 -93.65 -233.34 163.87 4.21 1.19 1,800.00 25.49 133.91 1,743.32 1,672.82 3.50 -91.00 -265.15 192.53 4.63 1.23 1,900.00 26.10 125.98 1,833.39 1,762.89 3.50 -83.63 -293.00 225.84 2.29 120 2,000.00 27.11 118.50 1,922.82 1,852.32 3.50 -76.49 -316.81 263.68 2.41 1.22 2,100.00 28.50 111.60 2,011.29 1,940.79 3.50 -69.80 -336.47 305.90 2.54 1.25 2,200.00 30.20 105.36 2,098.48 2,027.98 3.50 -63.70 -351.92 352.35 2.69 1.27 2,300.00 32.17 99.76 2,184.04 2,113.54 3.50 -58.25 -363.10 402.85 2.86 1.30 2,400.00 34.35 94.78 2,267.67 2,197.17 3.50 -53.46 -369.97 457.21 3.06 1.33 2,500.00 36.72 90.34 2,349.06 2,278.56 3.50 -49.29 -372.49 515.24 3.29 1.36 2,503.05 36.79 90.21 2,3151.50 2,281.00 3.50 -45.68 -372.50 517.07 3.57 1.34 10414"x 13-1/2- 2,529.36 37.44 89.13 2,372.48 2,301.98 3.50 -45.57 -372.41 532.94 3.57 1.34 C30 2,600.00 39.23 86.38 2,427.89 2,357.39 3.50 -44.71 -370.67 576.72 3.57 1.34 2,700.00 41.87 82.83 2,503.87 2,433.37 3.50 -42.55 -364.51 641.41 4.09 1.35 2,800.00 44.60 79.64 2,576.73 2,506.23 3.50 -39.86 -354.02 709.07 4.82 1.38 2,900.00 47.41 76.74 2,646.19 2,575.69 3.50 -37.53 -339.26 779.46 5.72 1.43 4/172015 3:07:52PM Page 4 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-04 Project: Western North Slope TVD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 it 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace NIS EIW Lat.Error Vert Error (usft) (') (`) (usft) (usft) (°I100usft) (°) (use) (usft) (usft) (use) 3,000.00 50.29 74.10 2,711.99 2,641.49 3.50 -35.52 -320.27 852.31 6.75 1.53 3,100.00 53.23 71.67 2,773.88 2,703.38 3.50 -33.78 -297.13 927.35 7.86 1.65 3,176.32 55.50 69.94 2,818.35 2,747.85 3.50 -32.28 -276.73 985.92 8.76 1.77 Hold for 5854.2' 3,200.00 55.50 69.94 2,831.76 2,761.26 0.00 0.00 -270.03 1,004.25 9.06 1.81 3,300.00 55.50 69.94 2,888.40 2,817.90 0.00 0.00 -241.76 1,081.66 10.33 2.01 3,400.00 55.50 69.94 2,945.04 2,874.54 0.00 0.00 -213.50 1,159.07 11.63 2.22 3,500.00 55.50 69.94 3,001.68 2,931.18 0.00 0.00 -185.23 1,236.49 12.93 2.44 3,600.00 55.50 69.94 3,058.32 2,987.82 0.00 0.00 -156.96 1,313.90 14.25 2.66 3,700.00 55.50 69.94 3,114.96 3,044.46 0.00 0.00 -128.69 1,391.31 15.58 2.89 3,800.00 55.50 69.94 3,171.60 3,101.10 0.00 0.00 -100.43 1,468.73 16.92 3.13 3,900.00 55.50 69.94 3,228.24 3,157.74 0.00 0.00 -72.16 1,546.14 18.25 3.37 4,000.00 55.50 69.94 3,284.88 3,214.38 0.00 0.00 -43.89 1,623.55 19.60 3.61 4,100.00 55.50 69.94 3,341.52 3,271.02 0.00 0.00 -1562 1,700.97 8.87 2.33 4,200.00 55.50 69.94 3,398.16 3,327.66 0.00 0.00 12.65 1,778.38 9.38 2.45 4,300.00 55.50 69.94 3,454.81 3,384.31 0.00 0.00 40.91 1,855.79 9.88 2.57 4,400.00 55.50 69.94 3,511.45 3,440.95 0.00 0.00 69.18 1,933.20 10.40 2.69 4,500.00 55.50 69.94 3,568.09 3,497.59 0.00 0.00 97.45 2,010.62 10.91 2.81 4,600.00 55.50 69.94 3,624.73 3,554.23 0.00 0.00 125.72 2,088.03 11.42 2.93 4,700.00 55.50 69.94 3,681.37 3,610.87 0.00 0.00 153,99 2,165.44 11.94 3.06 4,800.00 55.50 69.94 3,738.01 3,667.51 0.00 0.00 182.25 2,242.86 12.46 3.19 4,871.91 55.50 69.94 3,778.74 3,708.24 0.00 0.00 202.58 2,298.53 12.98 3.31 K3 4,900.00 55.50 69.94 3,794.65 3,724.15 0.00 0.00 210.52 2,320.27 12.98 3.31 5,000.00 55.50 69.94 3,851.29 3,780.79 0.00 0.00 238.79 2,397.68 13.50 3.44 5,100.00 55.50 69.94 3,907.93 3,837.43 0.00 0.00 267.06 2,475.09 14.02 3.57 5,200.00 55.50 69.94 3,964.57 3,894.07 0.00 0.00 295.32 2,552.51 14.55 3.69 4/17/2015 3:07:52PM Page 5 COMPASS 5000.1 Build 65 0 • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-04 Project: Western North Slope TVD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 I Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace NIS EIW Lat.Error Vert.Error (use) (°) (°) (usft) (use) (11O8use) (') (use) (usft) (usft) (usft) 5,300.00 55.50 69.94 4,021.21 3,950.71 0.00 0.00 323.59 2,629.92 15.07 3.82 5,312.32 55.50 69.94 4,028.19 3,957.69 0.00 0.00 327.08 2,639.46 15.60 3.95 Basal K2 .: 5,400.00 55.50 69.94 4,077.85 4,007.35 0.00 0.00 351.86 2,707.33 15.60 3.95 • 5,500.00 55.50 69.94 4,134.49 4,063.99 0.00 0.00 380.13 2,784.75 16.12 4.08 ' 5,600.00 55.50 69.94 4,191.13 4,120.63 0.00 0.00 408.40 2,862.16 16.65 4.21 5,700.00 55.50 69.94 4,247.77 4,177.27 0.00 0.00 436.66 2,939.57 17.17 4.34 5,800.00 55.50 69.94 4,304.41 4,233.91 0.00 0.00 464.93 3,016.99 17.70 4.47 5,900.00 55.50 69.94 4,361.06 4,290.56 0.00 0.00 493.20 3,094.40 18.23 4.61 6,000.00 55.50 69.94 4,417.70 4,347.20 0.00 0.00 521.47 3,171.81 18.76 4.74 6,100.00 55.50 69.94 4,474.34 4,403.84 0.00 0.00 549.74 3,249.22 19.29 4.87 6,101.51 55.50 69.94 4,475.19 4,404.69 0.00 0.00 550.16 3,250.39 19.82 5.00 A1b97 6,200.00 55.50 69.94 4,530.98 4,460.48 0.00 0.00 578.00 3,326.64 19.82 5.00• • 6,300.00 55.50 69.94 4,587.62 4,517.12 0.00 0.00 606.27 3,404.05 20.35 5.13 6,400.00 55.50 69.94 4,644.26 4,573.76 0.00 0.00 634.54 3,481.46 20.88 5.26 6,500.00 55.50 69.94 4,700.90 4,630.40 0.00 0.00 662.81 3,558.88 21.41 5.40 6,600.00 55.50 69.94 4,757.54 4,687.04 0.00 0.00 691.07 3,636.29 21.94 5.53 6,700.00 55.50 69.94 4,814.18 4,743.68 0.00 0.00 719.34 3,713.70 22.47 5.66 6,800.00 55.50 69.94 4,870.82 4,800.32 0.00 0.00 747.61 3,791.12 23.00 5.80 6,900.00 55.50 69.94 4,927.46 4,856.96 0.00 0.00 775.88 3,868.53 23.53 5.93 7,000.00 55.50 69.94 4,984.10 4,913.60 0.00 0.00 804.15 3,945.94 24.06 6.06 • 7,100.00 55.50 69.94 5,040.74 4,970.24 0.00 0.00 832.41 4,023.35 24.59 6.20 7,200.00 55.50 69.94 5,097.38 5,026.88 0.00 0.00 860.68 4,100.77 25.12 6.33 7,300.00 55.50 69.94 5,154.02 5,083.52 0.00 0.00 888.95 4,178.18 25.66 6.46 7,400.00 55.50 69.94 5,210.66 5,140.16 0.00 0.00 917.22 4,255.59 26.19 6.60 7,500.00 55.50 69.94 5,267.31 5,196.81 0.00 0.00 945.49 4,333.01 26.72 6.73 4/17/2015 3:07:52PM Page 6 COMPASS 5000.1 Build 65 0 i Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan CD5-04 Project: Western North Slope TVD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Site: CDS Alpine West Pad MD Reference: Plan:34.2+36.3©70.50usft(Doyon 19) ' Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 :. Planned Survey MD Inc AzI(azimuth) TVD TVDSS DLeg TFace N/S EIW Lat.Error Vert.Error (usft) (°) ti (usft) (usft) (°l100usft) (°) (usft) (usft) (usft) (usft) 7,600.00 55.50 69.94 5,323.95 5,253.45 0.00 0.00 973.75 4,410.42 27.25 6.86 7,700.00 55.50 69.94 5,380.59 5,310.09 0.00 0.00 1,002.02 4,487.83 27.79 7.00 7,800.00 55.50 69.94 5,437.23 5,366.73 0.00 0.00 1,030.29 4,56525 28.32 7.13 7,900.00 55.50 69.94 5,493.87 5,423.37 0.00 0.00 1,058.56 4,642.66 28.85 7.27 8,000.00 55.50 69.94 5,550.51 5,480.01 0.00 0.00 1,086.82 4,720.07 29.38 7.40 8,020.48 55.50 69.94 5,562.11 5,491.61 0.00 0.00 1,092.62 4,735.93 29.92 7.53 A8798 8,100.00 55.50 69.94 5,607.15 5,536.65 0.00 0.00 1,115.09 4,797.48 29.92 7.53 8,200.00 55.50 69.94 5,663.79 5,593.29 0.00 0.00 1,143.36 4,874.90 30.45 7.67 8,300.00 55.50 69.94 5,720.43 5,649.93 0.00 0.00 1,171.63 4,952.31 30.98 7.80 8,400.00 55.50 69.94 5,777.07 5,706.57 0.00 0.00 1,199.90 5,029.72 31.52 7.94 8,500.00 55.50 69.94 5,833.71 5,763.21 0.00 0.00 1,228.16 5,107.14 32.05 8.07 8,600.00 55.50 69.94 5,890.35 5,819.85 0.00 0.00 1,256.43 5,184.55 32.58 821 8,700.00 55.50 69.94 5,946.99 5,876.49 0.00 0.00 1,284.70 5,261.96 33.12 8.34 8,800.00 55.50 69.94 6,003.63 5,933.13 0.00 0.00 1,312.97 5,339.37 33.65 8.48 8,900.00 55.50 69.94 6,060.27 5,989.77 0.00 0.00 1,341.24 5,416.79 34.18 8.61 9,000.00 55.50 69.94 6,116.91 6,046.41 0.00 0.00 1,369.50 5,494.20 34.72 8.74 9,030.52 55.50 69.94 6,134.20 6,063.70 0.00 0.00 1,378.13 5,517.83 34.88 8.79 Start 342°I100'DLS,-104.93°TF,for 217233' '.'x "f"''''''''..;,'�.� s °'=.1 s <,. ... = � �1er: � ,:� ° . v. . a"te, `, ' f;�z�r "�, sfi s 9,100.00 54.92 67.14 6,173.85 6,103.35 3.42 -104.93 1,399.00 5,570.92 35.04 8.88 9,200.00 54.20 63.04 6,231.85 6,161.35 3.42 -103.33 1,433.30 5,644.79 35.01 9.01 9,300.00 53.62 58.87 6,290.77 6,220.27 3.42 -100.95 1,472.51 5,715.42 34.78 9.13 9,400.00 53.19 54.65 6,350.40 6,279.90 3.42 -98.50 1,516.50 5,782.55 34.35 9.26 9,500.00 52.91 50.38 6,410.52 6,340.02 3.42 -95.98 1,565.11 5,845.94 33.72 9.38 9,600.00 52.79 46.10 6,470.93 6,400.43 3.42 -93.42 1,618.17 5,905.38 32.88 9.50 9,700.00 52.81 41.81 6,531.41 6,460.91 3 42 -90.83 1,675.49 5,960.64 31.86 9.63 9,800.00 53.00 37.53 6,591.74 6,521.24 3 42 -88.23 1,736.86 6,011.54 30.66 9.75 4/172015 3:07:52PM. Page 7 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc-WNS Local Co-ordinate Reference: Well Plan CD5-04 Project: Western North Slope ND Reference: Plan:34.2+36.3(g 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD NDSS DLeg TFace NIS EIW Lat.Error Vert.Error (usft) O (") (usft) (usft) (1100usf) (°) (usft) (usft) (usft) (usft) 9,900.00 53.33 33.28 6,651.71 6,581 21 3.42 -85.65 1,802.08 6,057.88 29.30 9.87 10,000.00 53.82 29.08 6,711.11 6,640.61 3.42 -83.10 1,870.89 6,099.52 27.80 9.99 10,100.00 54.44 24.93 6,769.72 6,699.22 3.42 -80.61 1,943.07 6,136.29 26.19 10.12 10,200.00 55.21 20.86 6,827.33 6,756.83 3.42 -78.18 2,018.35 6,168.07 24.50 10.24 10,300.00 56.12 16.87 6,883.75 6,813.25 3.42 -75.83 2,096.47 6,194.74 22.74 10.37 10,400.00 57.14 12.97 6,938.77 6,868.27 3.42 -73.58 2,177.15 6,216.22 20.96 10.50 10,486.60 58.13 9.66 6,985.14 6,914.64 3.42 -71.43 2,248.86 6,230.55 19.19 10.62 HRZ 10,500.00 58.29 9.16 6,992.20 6,921.70 3.42 -69.66 2,260.10 6,232.41 19.19 10.62 10,600.00 59.55 5.45 7,043.84 6,973.34 3.42 -69.40 2,345.02 6,243.28 17.46 10.76 10,700.00 60.90 1,83 7,093.51 7,023.01 3.42 -67.48 2,431.62 6,248.77 15.82 10.89 10,748.25 61.59 0.13 7,116.72 7,046.22 3.42 -65.69 2,473.92 6,249.49 14.31 11.03 Kalubik 10,800.00 62.36 358.32 7,141.04 7,070.54 3.42 -64.86 2,519.59 6,248.86 14.31 11.03 10,900.00 63.90 354.90 7,186.25 7,115.75 3.42 -64.02 2,608.61 6,243.57 12.99 11.16 11,000.00 65.51 351.57 7,228.99 7,158.49 3.42 -62.47 2,698.37 6,232.90 11.94 11.31 11,010.81 65.69 351.21 7,233.45 7,162.95 3.42 -61.05 2,708.10 6,231.43 11.21 11.45 LCU 11,100.00 67.20 348.33 7,269.10 7,198.60 3.42 -60.90 2,788.55 6,216.90 11.21 11.45 11,200.00 68.95 345.16 7,306.44 7,235.94 3.42 -59.74 2,878.82 6,195.61 10.86 11.60 11,202.85 69.00 345.07 7,307.46 7,236.96 3.42 -58.56 2,881.39 6,194.93 10.86 11.60 Hold for 3.22' 11,206.07 69.00 345.07 7,308.61 7,238.11 0.00 0.00 2,884.30 6,194.16 10.87 11.60 Start 3.511100'DLS,-40.7r TF,for 585.79' 11,300.00 71.52 342.80 7,340.34 7,269.84 3.51 -40.77 2,969.24 6,169.69 10.91 11.75 11,400.00 74.22 340.46 7,369.80 7,299.30 3.51 -40.01 3,059.92 6,139.57 11.22 11.90 11,446.74 75.49 339.39 7,382.01 7,311.51 3.51 -39.31 3,102.29 6,124.08 11.74 12.06 UJU 4/17/2015 3:07:52PM Page 8 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-04 Project: Western North Slope TVD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace N/S E/W Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°noOusft) (°) (usft) (usft) (usft) (usft) 11,500.00 76.95 338.18 7,394.70 7,324.20 3.51 -39.03 3,150.51 6,105.36 11.74 12.06 11,600.00 79.69 335.95 7,414.95 7,344.45 3.51 -38.75 3,240.67 6,067.19 12.41 12.22 11,700.00 82.45 333.75 7,430.46 7,359.96 3.51 -38.29 3,330.08 6,025.21 13.19 12.38 11,736.88 83.48 332.95 7,434.98 7,364.48 3.51 -37.95 3,362.79 6,008.79 13.99 12.53 Alpine A 11,791.86 85.00 331.76 7,440.50 7,370.00 3.51 -37.86 3,411.25 5,983.41 13.99 12.53 Hold for 20'-7°6r x1-7/11" 11,800.00 85.00 331.76 7,441.21 7,370.71 0.00 0.00 3,418.39 5,979.58 14.00 12.51 11,811.86 85.00 331.76 7,442.24 7,371.74 0.00 0.00 3,428.80 5,973.99 14.01 12.51 Start 4°1100'DLS,0°TF,for 136.12' 11,900.00 88.53 331.76 7,447.22 7,376.72 4.00 0.00 3,506.32 5,932.36 14.16 12.51 11,947.98 90.44 331.76 7,447.65 7,377.15 4.00 0.00 3,548.58 5,909.66 14.29 12.52 Hold for 6844.46' 12,000.00 90.44 331.76 7,447.25 7,376.75 0.00 0.00 3,594.41 5,885.05 14.48 12.53 12,100.00 90.44 331.76 7,446.47 7,375.97 0.00 0.00 3,682.51 5,837.74 14.97 12.56 12,200.00 90.44 331.76 7,445.69 7,375.19 0.00 0.00 3,770.61 5,790.43 15.61 12.59 12,300.00 90.44 331.76 7,444.92 7,374.42 0.00 0.00 3,858.71 5,743.12 16.38 12.64 12,400.00 90.44 331.76 7,444.14 7,373.64 0.00 0.00 3,946.80 5,695.81 17.26 12.70 12,500.00 90.44 331.76 7,443.36 7,372.86 0.00 0.00 4,034.90 5,648.50 18.24 12.77 12,600.00 90.44 331.76 7,442.59 7,372.09 0.00 0.00 4,123.00 5,601.19 19.30 12.85 12,700.00 90.44 331.76 7,441.81 7,371.31 0.00 0.00 4,211.10 5,553.88 20.43 12.94 12,800,00 90.44 331.76 7,441.03 7,370.53 0.00 0.00 4,299.19 5,506.57 21.62 13.04 12,900.00 90.44 331.76 7,440.26 7,369.76 0.00 0.00 4,387.29 5,459.26 22.86 13.14 13,000.00 90.44 331.76 7,439.48 7,368.98 0.00 0.00 4,475.39 5,411.95 24.14 13.26 13,100.00 90.44 331.76 7,438.70 7,368.20 0.00 0.00 4,563.49 5,364.64 25.45 13.39 13,200.00 90.44 331.76 7,437.93 7,367.43 0.00 0.00 4,651.58 5,317.33 26.80 13.52 13,300.00 90.44 331.76 7,437.15 7,366.65 0.00 0.00 4,739.68 5,270.02 16.68 12.79 13,400.00 90,44 331.76 7,436.37 7,365.87 0.00 0.00 4,827.78 5,222.71 17.00 12.83 4/17/2015 3:07:52PM Page 9 COMPASS 5000.1 Build 65 • 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-04 Project: Western North Slope ND Reference: Plan:34.2+36.3(4 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace NIS EIV Lat.Error Vert.Error (usft) (°) () (usft) (usft) (°l10fusft) (°) (usft) (usft) (usft) (usft) 13,500.00 90A4 331.76 7,435.60 7,365.10 0.00 0.00 4,915.88 5,175.40 17.33 12.87 13,600.00 90.44 331.76 7,434.82 7,364.32 0.00 0.00 5,003.97 5,128.09 17.67 12.92 ' 13,700.00 90.44 331.76 7,434.05 7,363.55 0.00 0.00 5,092.07 5,080.78 18.03 12.96 13,800.00 90.44 331.76 7,43327 7,362.77 0.00 0.00 5,180.17 5,033.47 18.40 13.01 13,900.00 90.44 331.76 7,432.49 7,361.99 0.00 0.00 5,268.27 4,986.16 18.78 13.06 14,000.00 90.44 331.76 7,431.72 7,361.22 0.00 0.00 5,356.36 4,938.85 19.17 13.11 14,100.00 90.44 331.76 7,430.94 7,360.44 0.00 0.00 5,444.46 4,891.54 19.57 13.17 14,200.00 90.44 331.76 7,430.16 7,359.66 0.00 0.00 5,532.56 4,844.23 19.97 13.23 14,300.00 90.44 331.76 7,429.39 7,358.89 0.00 0.00 5,620.66 4,796.92 20.39 13.29 14,400.00 90.44 331.76 7,428.61 7,358.11 0.00 0.00 5,708.75 4,749.62 20.81 13.35 14,500.00 90.44 331.76 7,427.83 7,357.33 0.00 0.00 5,796.85 4,702.31 21.24 13.41 14,600.00 90.44 331.76 7,427.06 7,356.56 0.00 0.00 5,884.95 4,655.00 21.67 13.48 14,700.00 90.44 331.76 7,426.28 7,355.78 0.00 0.00 5,973.05 4,607.69 22.12 13.55 14,800.00 90.44 331.76 7,425.50 7,355.00 0.00 0.00 6,061.14 4,560.38 22.57 13.62 14,900.00 90.44 331.76 7,424.73 7,354.23 0.00 0.00 6,149.24 4,513.07 23.02 13.69 15,000.00 90.44 331.76 7,423.95 7,353.45 0.00 0.00 6,237.34 4,465.76 23.48 13.76 15,100.00 90.44 331.76 7,423.17 7,352.67 0.00 0.00 6,325.44 4,418.45 23.94 13.84 15,200.00 90.44 331.76 7,422.40 7,351.90 0.00 0.00 6,413.54 4,371.14 24.41 13.91 15,300.00 90.44 331.76 7,421.62 7,351.12 0.00 0.00 6,501.63 4,323.83 24.89 13.99 15,400.00 90.44 331.76 7,420.84 7,350.34 0.00 0.00 6,589.73 4,276.52 25.37 14.07 15,500.00 90.44 331.76 7,420.07 7,349.57 0.00 0.00 6,677.83 4,229.21 25.85 14.16 15,600.00 90.44 331.76 7,419.29 7,348.79 0.00 0.00 6,765.93 4,181.90 26.33 14.24 15,700.00 90.44 331.76 7,418.51 7,348.01 0.00 0.00 6,854.02 4,134.59 26.82 14.33 15,800.00 90.44 331.76 7,417.74 7,347.24 0.00 0.00 6,942.12 4,087.28 27.32 14.42 15,900.00 90.44 331.76 7,416.96 7,346.46 0.00 0.00 7,030.22 4,039.97 27.81 14.51 16,000.00 90.44 331.76 7,416.18 7,345.68 0.00 0.00 7,118.32 3,992.66 28.31 14.80 16,100.00 90.44 331.76 7,415.41 7,344.91 0.00 0.00 7,206.41 3,945.35 28.81 14.69 4/172015 3:07:52PM Page 10 COMPASS 5000.1 Build 65 III • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan:CD5-04 Project: Western North Slope ND Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace N/S E/W Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) (usft) (usft) (usft) 16,200.00 90.44 331.76 7,414.63 7,344.13 0.00 0.00 7,294.51 3,898.04 29.32 14.79 16,300.00 90.44 331.76 7,413.86 7,343.36 0.00 0.00 7,382.61 3,850.73 29.82 14.88 • 16,400.00 90.44 331.76 7,413.08 7,342.58 0.00 0.00 7,470.71 3,803.42 30.33 14.98 16,500.00 9044 331.76 7,412.30 7,341.80 0.00 0.00 7,558.80 3,756.11 30.85 15.08 • 16,600.00 90.44 331.76 7,411.53 7,341.03 0.00 0.00 7,646.90 3,708.80 31.36 15.18 16,700.00 90.44 331.76 7,410.75 7,340.25 0.00 0.00 7,735.00 3,661.49 31.88 15.28 16,800.00 90.44 331.76 7,409.97 7,339.47 0.00 0.00 7,823.10 3,614.18 32.39 15.39 16,900.00 90.44 331.76 7,409.20 7,338.70 0.00 0.00 7,911.19 3,566.87 32.91 15.49 17,000.00 90.44 331.76 7,408.42 7,337.92 0.00 0.00 7,999.29 3,519.56 33.44 15.60 17,100.00 90.44 331.76 7,407.64 7,337.14 0.00 0.00 8,087.39 3,472.25 33.96 15.71 17,200.00 90.44 331.76 7,406.87 7,336.37 0.00 0.00 8,175.49 3,424.94 34.49 15.82 17,300.00 90.44 331.76 7,406.09 7,335.59 0.00 0.00 8,263.58 3,377.63 35.01 15.93 17,400.00 90.44 331.76 7,405.31 7,334.81 0.00 0.00 8,351.68 3,330.32 35.54 16.04 17,500.00 90.44 331.76 7,404.54 7,334.04 0.00 0.00 8,439.78 3,283.01 36.07 16.15 17,600.00 90.44 331.76 7,403.76 7,333.26 0.00 0.00 8,527.88 3,235.70 36.60 16.27 17,700.00 90.44 331.76 7,402.98 7,332.48 0.00 0.00 8,615.97 3,188.39 37.14 16.38 • 17,800.00 90.44 331.76 7,402.21 7,331.71 0.00 0.00 8,704.07 3,141.08 37.67 16.50 17,900.00 90.44 331.76 7,401.43 7,330.93 0.00 0.00 8,792.17 3,093.77 38.20 16.61 • 18,000.00 90.44 331.76 7,400.65 7,330.15 0.00 0.00 8,880.27 3,046.46 38.74 16.73 18,100.00 9044 331.76 7,399.88 7,329.38 0.00 0.00 8,968.36 2,999.15 39.28 16.85 18,200.00 90.44 331.76 7,399.10 7,328.60 0.00 0.00 9,056.46 2,951.84 39.82 16.97 18,300.00 90.44 331.76 7,398.32 7,327.82 0.00 0.00 9,144.56 2,904.53 40.36 17.10 18,400.00 90.44 331.76 7,397.55 7,327.05 0.00 0.00 9,232.66 2,857.22 40.90 17.22 18,500.00 90.44 331.76 7,396.77 7,326.27 0.00 0.00 9,320.75 2,809.91 41.44 17.34 18,600.00 90.44 331.76 7,395.99 7,325.49 0.00 0.00 9,408.85 2,762.60 41.98 17.47 18,700.00 90.44 331.76 7,395.22 7,324.72 0.00 0.00 9,496.95 2,715.29 42.52 17.59 • • • 4/172015 3:07:52PM Page 11 COMPASS 5000.1 Build 65 • 0 Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS Local Co-ordinate Reference: Well Plan CD5-04 Project: Western North Slope TVD Reference: Plan:34.2+36.3 @ 70.50usf(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan:34.2+36.3 @ 70.50usll(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Planned Survey MD Me Azi(azimuth) TVD TVDSS DLeg TFace WS ENd Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°lloousft) (°) (usft) (usft) (usft) (usft) 18,792,44 90.44 331.76 7,394.50 7,324.00 0.00 0.00 9,578.39 2,671 56 43.03 17.71 TD:18792.44'MD,7394.5'TVD-4-1/2"x 6-3/4" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 0D5-04 1.Heel 091014. 0.00 0.00 7,440.50 3,411.25 5,983.41 5,968,935.47 1,495,564.97 70°19'22.511 N 151°10'28.417 W -plan hits target center -Circle(radius 100.00) CD5-04 2.Toe 091014 JI 0.00 0.00 7,394.50 9,578.39 2,671.56 5,975,167.47 1,492,377.97 70°20'23.186 N 151°12'5.016 W -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 18,792.44 7,394.50 4-1/2"x 6-3/4" 4.500 6.750 2,503.05 2,351.50 10-3/4"x 13-1/2" 10.750 13.500 180.50 180.50 20"x 42" 20.000 42.000 11,791.86 7,440.50 7-5/8"x 9-7/8" 7.625 9.875 4/17/2015 3:07:52PM Page 12 COMPASS 5000.1 Build 65 • • Schlumberger Report Company: ConocoPhillips(Alaska)Inc.-WNS ""' " '' """'"" "` ` "' 'liffi Local Co-ordinate Reference: Well Plan:CD5-04 Project: Westem North Slope TVD Reference: Plan:34.2+36.3 @ 70.50usft(Doyon 19) Site: CD5 Alpine West Pad MD Reference: Plan.34.2+36.3 @ 70.50usft(Doyon 19) Well: Plan:CD5-04 North Reference: True Wellbore: Plan:CD5-04 Survey Calculation Method: Minimum Curvature Design: CD5-04wp10 Database: OAKEDMP2 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1 1,608.73 1,570.50 Base Permafrost 11,736.88 7,434.98 Alpine A 8,020.48 5,562.11 A1b96 10,486.60 6,985.14 HRZ 6,101.51 4,475.19 A1b97 11,010.81 7,233.45 LCU 5,312.32 4,028.19 Basal K2 4,871.91 3,778.74 K3 11,446.74 7,382.01 UJU 2,529.36 2,372.48 C30 10,748.25 7,116.72 Kalubik Plan Annotations ,.,.,,ss,.....,:�3^dtxtix.:ku : ... ,> 3 ,.^t 6�.., M. war 1. �d'W a x'*= Measured Vertical Local Coordinates Depth Depth +N/-S +EJ-W (usft) (usft) (usft) (usft) Comment 484.20 484.20 0.00 0.00 KOP:Start 1.6°/100'DLS,145°TF,for 150.04' 634.24 634.20 -2.57 1.80 Start 2.5°/100'DLS,0°TF,for 919.15' 1,553.39 1,520.50 -182.11 127.52 Hold for 110.68' 1,664.07 1,620.50 -220.97 154.73 Start 3.5°/100'DLS,-93.65°TF,for 1512.25' 3,176.32 2,818.35 -276.73 985.92 Hold for 5854.2' 9,030.52 6,134.20 1,378.13 5,517.83 Start 3.42°/100'DLS,-104.93°TF,for 2172.33' 11,202.85 7,307.46 2,881.39 6,194.93 Hold for 3.22' 11206.07 7,308.61 2,884.30 6,194.16 Start 3.51°/100'DLS,40.77°TF,for 585.79' 11,791.86 7,440.50 3,411.25 5,983.41 Hold for20' 11,811.86 7,442.24 3,428.80 5,973.99 Start 4°/100'DLS,0°TF,for 136.12' 11,947.98 7,447.65 3,548.58 5,909.66 Hold for 6844.46' 18,792.44 7,394.50 9,578.39 2,671.56 TD 18792.44'MD,7394.5'TVD Checked By: Approved By: Date: 4/17/1015 3:07:52PM Page 13 COMPASS 5000.1 Build 65 • s ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD5 Alpine West Pad Plan: CD5-04 Plan: CD5-04 CD5-04wp10 Clearance Summary Anticollision Report 17April,2015 TCR required Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: CD5 Alpine West Pad-Plan:CD5-04-Plan:CD5-04-CD5-04wp10 Well Coordinates: 5,965,645.41 N,1,489,514.65 E(70°18'48.98"N,151°13'23.05"W) Datum Height: Plan:34.2+36.3 70.50usft(Doyon 19) Scan Range: 0.00 to 18,792.44 usft.Measured Depth. Scan Radius is 2,075.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 65 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Scan Type: 25.00 1111 41110 ConocoPhillips(Alaska)Inc.-WNS Western North Slope Anticollision Report for Plan: CD5-04-CD5-O4wp1O Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: CD5 Alpine West Pad-Plan:CD5-04-Plan:CD5-04-CD5-04wp10 Scan Range: 0.00 to 18,792.44 usft.Measured Depth. Scan Radius is 2,075.61 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft CD2 Alpine Pad CD2-33-CD2-33-CD2-33 iCP required 11111.1.11 IIIIIIII VIM j,; 10,947* ILII -149.40 1111#9,140 it, 0.415 Centre Distance AI CD2-33-CD2-33-CD2-33 IT 1O CD2-78-CD2-78-CD2-78 14,430.24 1,338.74 14,430.24 1,135.91 18,925.00 6.600 Centre Distance Pass-Major Risk CD2-78-CD2-78-CD2-78 14,505.22 1,339.67 14,505.22 1,135.14 19,000.00 6.550 Clearance Factor Pass-Major Risk CDS Alpine West Pad Plan:CD5-01-Plan:CD5-01-CD5-01wp07 334.20 60.00 334.20 54.15 300.00 10.258 Centre Distance Pass-Major Risk Plan:CD5-01-Plan:CD5-01-CD5-01wp07 434.19 60.89 434.19 53.30 400.00 8.022 Clearance Factor Pass-Major Risk Plan:CD5-02-Plan:CD5-02-CD5-02wp07 384.20 40.00 384.20 33.28 350.00 5.950 Centre Distance Pass-Major Risk Plan:CD5-02-Plan:CD5-02-CD5-02wp07 559.32 41.17 559.32 31.58 525.00 4.294 Clearance Factor Pass-Major Risk Plan:CD5-03-Plan CD5-03-CD5-03wp07 484.19 19.97 484.19 11.51 450.00 2.360 Centre Distance Pass-Major Risk Plan:CD5-03-Plan CD5-03-CD5-03wp07 584.12 20.36 584.12 10.41 550.00 2.046 Clearance Factor Pass-Major Risk Plan:CD5-05-Plan CD5-05-CD5-05wp09 474.90 20.00 474.90 11.57 475.00 2.371 Centre Distance Pass-Major Risk Plan:CD5-05-Plan CD5-05-CD5-05wp09 599.63 20.65 599.63 10.33 600.00 2.002 Clearance Factor Pass-Major Risk Plan:CD5-06-Plan:CD5-06-CD5-06wp07 484.20 40.00 484.20 31.53 450.00 4.723 Centre Distance Pass-Major Risk Plan:CD5-06-Plan:CD5-06-CD5-06wp07 633.59 41.09 633.59 30.38 600.00 3.838 Clearance Factor Pass-Major Risk Plan:CD5-07-Plan:CD5-07-CD5-07wp07 484.20 60.00 484.20 51.53 450.00 7.084 Centre Distance Pass-Major Risk Plan:CD5-07-Plan:CD5-07-CD5-07wp07 1,248.49 66.49 1,248.49 47.00 1,225.00 3.412 Clearance Factor Pass-Major Risk Plan:CD5-08-Plan:CD5-08-CD5-08wp07 484.20 80.01 484.20 71.54 450.00 9.446 Centre Distance Pass-Major Risk Plan:CD5-08-Plan:CD5-08-CD5-08wp07 633.08 81.03 633.08 70.33 600.00 7.573 Clearance Factor Pass-Major Risk Plan:CD5-09-Plan:CD5-09-CD5-09wp07 384.20 100.01 384.20 9329 350.00 14.876 Centre Distance Pass-Major Risk Plan:CD5-09-Plan:CD5-09-CD5-09wp07 533.69 100.84 533.69 91.64 500.00 10.963 Clearance Factor Pass-Major Risk Plan:CD5-10-Plan:CD5-10-CD5-10wp07 1,483.82 108.73 1,483.82 84.74 1,475.00 4.533 Clearance Factor Pass-Major Risk Plan:CD5-11-Plan:CD5-11-CD5-11wp07 484.20 140.01 484.20 131.54 450.00 16.530 Centre Distance Pass-Major Risk Plan:CD5-11-Plan:CD5-11-CD5-11wp07 632.31 141.01 632.31 130.32 600.00 13.189 Clearance Factor Pass-Major Risk Plan:CD5-12-Plan:CD5-12-CD5-12wp07 384.20 160.01 384.20 153.29 350.00 23.800 Centre Distance Pass-Major Risk Plan:CD5-12-Plan:CD5-12-CD5-12wp07 533.43 160.82 533.43 151.62 500.00 17.489 Clearance Factor Pass-Major Risk Plan:CD5-13-Plan:CD5-13-CD5-13wp07 2,000.00 156.37 2,000.00 124.99 2,025.00 4.983 Centre Distance Pass-Major Risk 17 April,2015- 14:36 Page 2 of 6 COMPASS • • ConocoPhillips(Alaska)Inc.-WNS Western North Slope Anticollision Report for Plan: CD5-04-CD5-04wp1O Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:CD5 Alpine West Pad-Plan:CD5-04-Plan:CD5-04-CD5-04wp10 Scan Range: 0.00 to 18,792.44 usft.Measured Depth. Scan Radius is 2,075.61 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft Plan:CD5-13-Plan:CD5-13-CD5-13wp07 2,025.30 156.44 2,025.30 124.80 2,050.00 4.945 Clearance Factor Pass-Major Risk Plan:CD5-314-Plan:CD5-314-CD5-314wp14 475.00 199.79 475.00 191.36 475.00 23.680 Centre Distance Pass-Major Risk Plan:CD5-314-Plan:CD5-314-CD5-314wp14 598.00 200.44 598.00 190.44 600.00 20.037 Clearance Factor Pass-Major Risk Plan:CD5-314-Plan:CD5-314PB1-CD5-314PB1wp1 475.00 199.79 475.00 191.36 475.00 23.680 Centre Distance Pass-Major Risk Plan:CD5-314-Plan:CD5-314PB1-CD5-314PB1wp1 598.00 200.44 598.00 190.44 600.00 20.037 Clearance Factor Pass-Major Risk Plan:CD5-315-Plan:CD5-315-CD5-315 wp10 484.20 220.02 484.20 211.55 450.00 25.975 Centre Distance Pass-Major Risk Plan:CD5-315-Plan:CD5-315-CD5-315 wp10 631.30 221.00 631.30 210.32 600.00 20.693 Clearance Factor Pass-Major Risk Plan:CD5-315-Plan:CD5-315PB1-CD5-315PB1 wp 484.20 220.02 484.20 211.55 450.00 25.975 Centre Distance Pass-Major Risk Plan:CD5-315-Plan:CD5-315PB1-CD5-315P01 wp 631.30 221.00 631.30 210.32 600.00 20.693 Clearance Factor Pass-Major Risk WNS(Various) Nuigsut 1-Nuigsut 1-Nuigsut 1 -TCR required 16,227.23 168.43 16,227.23 14.37 7,400.00 1.093 Clearance Factor Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 36.30 850.00 CD5-04wp10 GYD-GC-SS 850.00 1,850.00 CD5-04wp10 MWD 850.00 2,503.05 CD5-04wp10 MWD+IFR-AK-CAZ-SC 2,503.05 4,003.05 CD5-04wp10 MWD 2,503.05 11,791.86 CD5-04wp10 MWD+IFR-AK-CAZ-SC 11,791.86 13,291.86 CD5-04wp10 MWD 11,791.86 18,792.44 CD5-04wp10 MWD+IFR-AK-CAZ-SC 17 April,2015- 14:36 Page 3 of 6 COMPASS I 0 CD5-04w 10 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. a , a o o TCR required S.�34M ab 4 4 m) O U O U 8 0 0 4 300 1!I Ji I llllllll,IIP l IIIIIIIFlr Illlli 1II II, II. IC E• llllllllllll�ll' �I 111111 ro II ro u) 111 „,,IIIIIIIIIIIIIIwilll��1'1111H ,111 E 150 1111111 I P'dom11mll CS) ..wlllllllooull'lpll1 Cl l IIII III" o �����0111IIl11PIiPI IIII IIII 0) ., III' ��,IIIIIIIIu11110 � I IIII o „,liIll111111id,i Ill O „IIII,II III ..„,,,edI iniullllllll:lllllli,' IIII 'I/ ik ISI Equivelant Magnetic Distance 0 3000 6000 9000 12000 15000 18000 Displayed interval could be less than entire well:Measured Depth 36.30 To 18792.44 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations, interval:25.00 Depth Range From: 36.30 To 18792.44 Results Limited By: Centre Distance: 2075.61 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 850.00 CD5-04wp10 (Plan: CD5-04) GYD-GC-SS 850.00 1850.00 CD5-04wp10 (Plan: CD5-04) MWD 850.00 2503.05 CD5-04wp10 (Plan: CD5-04) MWD+IFR-AK-CAZ-SC 2503.05 4003.05 CD5-04wp10 (Plan: CD5-04) MWD 2503.05 11791.86 CD5-04wp10 (Plan: CD5-04) MWD+IFR-AK-CAZ-SC 11791.86 13291.86 CD5-04wp10 (Plan: CD5-04) MWD 11791.86 18792.44 CD5-04wp10 (Plan: CD5-04) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 180.50 180.50 20" x 42" 20.000 2351.50 2503.05 10-3/4" x 13-1/2" 10.750 7440.50 11791.86 7-5/8" x 9-7/8" 7.625 7394.50 18792.44 4-1/2"x 6-3/4" 4.500 LEGEND —A— CD2-33,CD2-33,CD2-33 V2 $ Plan:CD5-07,Plan:CD5-07,CD5-07wp07 VO —I— Plan:CD5-314,Plan:CD5-314,CDS-314wp14 VO - CD2-78,CD2-78,CD2-78 VO —X— Plan:CD5-08,Plan:CD5-08,CD5-08wp07 VO -B- Plan:CD5-314,Plan:CD5314PB1,CD5-314PB1wp14 VO - Plan:CD5-01,Plan:CD5-01,CD5-01wp07 VO —X— Plan:CD5-09,Plan:CD5-09,CD5-09wp07 VO —49— Plan:CD5-315,Plan:CD5-315,CDS-315 wp10 VO —X— Plan:CD5-02,Plan:CD5-02,CD5-02wp07 VO —I— Plan:CD5-10,Plan:CD5-10,CD5-10wp07 VO —13— Plan:CD5-315,Plan:CD5315PB1,CD5-315PB1 wp10 VO - Plan:CD5-03,Plan CD5-03,CD5-03wp07 VO -0-- Plan:CD5-11,Plan:CD5-11,CD5-11wp07 VO -6- Nuiqsut 1,Nuigsut 1,Nuigsut 1 VO - Plan:CD5-05,Plan CD5-05,CD5-05wp09 VO -e-- Plan:CD5-12,Plan:CD5-12,CD5-12wp07 VO -9- CD5-04wp10 —e— Plan:CD5-06,Plan:CD5-06,CD5-06wp07 VO -9-- Plan:CD5-13,Plan:CD5-13,CD5-13wp07 VO I 1111111 CD5-04w 10 Ladder View pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. n n S n a ill -, 0003 u1 0 Lh 06du O 0 0 00 60— f is i coas 1 1 iIil, ?Illr'l I30— . -10 o- c) A,I 1 a) Magnetic( lilt/ 0) Equtvelt Distance V -ie_119.Il _. _... 1111111110 1111 I I 1111 1111 1 1 1 1 1 0 500 1000 1500 2000 2500 3000 3500 Displayed interval could be less than entire well:Measured Depth 36.30 To 18792.44 ANTI-COLLISION SETTINGS Interpolation Method: MD+Stations,interval:25.00 Depth Range From: 36.30 To 18792.44 Results Limited By: Centre Distance: 2075.61 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 36.30 850.00 CD5-04wp10 (Plan: CD5-04) GYD-GC-SS 850.00 1850.00 CD5-04wp10 (Plan: CD5-04) MWD 850.00 2503.05 CD5-04wp10 (Plan: CD5-04) MWD+IFR-AK-CAZ-SC 2503.05 4003.05 CD5-04wp10 (Plan: CD5-04) MWD 2503.05 11791.86 CD5-04wp10 (Plan: CD5-04) MWD+IFR-AK-CAZ-SC 11791.86 13291.86 CD5-04wp10 (Plan: CD5-04) MWD 11791.86 18792.44 CD5-04wp10 (Plan: CD5-04) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 180.50 180.50 20"x 42" 20.000 2351.50 2503.05 10-3/4" x 13-1/2" 10.750 7440.50 11791.86 7-5/8" x 9-7/8" 7.625 7394.50 18792.44 4-1/2"x 6-3/4" 4.500 LEGEND CD2-33,CD2-33,CD2-33 V2 $- Plan:CD5-07,Plan:CD5-07,CD5-07wp07 VO —I— Plan:CD5-314,Plan:CD5-314,CD5-314wp14 VO - CD2-78,CD2-78,CD2-78 VO —X— Plan:CD5-08,Plan:CD5-08,CD5-08wp07 VO -9- Plan:CD5-314,Plan:CD5314PB1,CD5-314PB1wp14 VO Plan:CD5-01,Plan:CD5-01,CD5-01wp07 VO - Plan:CD5-09,Plan:CD5-09,CD5-09wp07 V0 -s- Plan:CD5-315,Plan:CD5315,CD5-315 wp10 VO --X— Plan:CD5-02,Plan:CD5-02,CD5-02wp07 VO —X— Plan:CD5-10,Plan:CD5-10,CD5-10wp07 VO -e- Plan:CD5-315,Plan:CD5-315PB1,CD5-315PB1 wp10 VO --A— Plan:CD5-03,Plan CD5-03,CD5-03wp07 VO -49— Plan:CD5-11,Plan:CD5-11,CD5-11wp07 VO -- Nuiqsut 1,Nuiqsut 1,Nuiqsut 1 VO - Plan:CD5-05,Plan CD5-05,CD5-05wp09 VO -e- Plan:CD5-12,Plan:CD5-12,CD5-12wp07 VO -9- CD5-04wp10 —19— Plan:CD5-06,Plan:CD5-06,CD5-06wp07 VO $- Plan:CD5-13,Plan:CD5-13,CD5-13wp07 VO Inc Azi TVD +N/-S .I.E/-W Dleg TFace Target 4.ib 4b4 3 0.00 0.00 36.30 0.00 0.00 0.00 0.00 . C D5-04wp 10 484. 0.00 0.00 484.20 634.24 2.40 145.00 634.20 0.00 -2.57 0.00 0.00 0.00 .00 1.80 1.60 145.00 -3.11 484 774 1553.39 25.38 145.00 1520.50 -182.11 127.52 2.50 0.00 -220.15 774 1064 36.30 To 18792.44 1664.07 25.38 145.00 1620.50 -220.97 154.73 0.00 0.00 -267.13 3176.32 55.50 69.94 2818.35 -276.73 985.92 3.50 -93.65 -694.16 9030.52 55.50 69.94 6134.20 1378.13 5517.83 0.00 0.00 -1277.12 1064 1344 11202.85 69.00 345.07 7307.46 2881.39 6194.93 3.42 -104.93 -245.10 14:38,April 17 2015 11206.07 69.00 345.07 7308.61 2884.30 6194.16 0.00 0.00 -242.16 1344 1634 11791.86 85.00 331.76 7440.50 3411.25 5983.41 3.51 -40.77 323.03 CD5-04 1 Heel 091014 JH 11811.86 85.00 331.76 7442.24 3428.80 5973.99 0.00 0.00 342.95 SURVEY PROGRAM 11947.98 90.44 331.76 7447.65 3548.58 5909.66 4.00 0.00 478.88 1634 1924 800 oDepth SurvayPlan 18792.44 90.44 331.76 7394.50 9578.39 2671.56 0.00 0.00 7321.55 CD5-04 2 Toe 091014 JH Frm To Tool 1924 2214 36.30 35000 C05,047.010(Plan C05-041 GYD-GC-SS 850 00 1850 00 claseaaroo(Kan-ens-04)MWD 80000 2503 05 ceseawnlo(Plan-0125-04)MWD41FR-AK-C1.-SC 2550.05 4050.05 C05-0474p10(P4*-005-04)MWD 2214 2503 2503.05 11191 86 C125-04wp10(Plan-CDS.)MWD4IFFI-AK-CAZ-SC 11191 BO 13291 86 C125-04wp10(Plan C125-04)MWD 11781 86 18782 41 CD5e.p10(Plan CD5-06)MWDar11-88-C,4..30 2503 3174 CASING DETAILS 3174 3834 TVD MD Name Size 3834 4504 180.50 180.50 20"x 42" 20.000 2351.50 2503.05 10-3/4"x 13-1/2" 10.750 4504 5164 7440.50 11791.86 7-5/8"x 9-7/8" 7.625 7394 50 18792.44 4-1/2•x 6-3/4" 4.500 5164 5834 5834 " 6504 6504 -"''-"-• 7164 TCR required . 7164 7834 -4 D5--'. "rasitP.Q:',' .-1-7 4 D5-01 w p071 b i 30#/330 FET,,,/afrArr.o44f,It.IP,tI....:-77i-L3.la4.-.1T4.4.4,„A-k.:,ro,I2.,4,,-:,'0-,.-,1,.'614..a•E'.-.1.N„._',,,,,TI.N,-:....t$t4:,,,i,.l.,..1,.,..g4....,i:.;.f"-,'.-•3 - -14110\,-.----5•-e=t.0.. ..... 3 0 9334 - 91038334 4 = , - ,.,‘ 2! .. 'c, Nr124 - 10834 12334 ' ''''. 44r,e,0 0.--, 4'' VIA AZ ' 1 -"--,-. I.\.,,,,. 4 •44,4 ), 15344 16844 )444-.1:". -N4r,A., . 4,,fiti,..51.1,4.,l'."--0,..s.- 0, „ivb ---- 1,,,•%.',,-,. - ,..\-",4N r- , 60/300_40-0fir,etity fffejlkW 1011,44;k1%4-4'1*ti ,..\\ \ \ * 60 18344 19844 = .iw-i 0 ...-- '.*A.:.•''s,. - , i 1ot,' l4v,fiee..? .,:. ). I,,Vr,,,:_`7g'A;r41,4.-..i1y,7:'it_.:t,7.-,70,-,l_-'t.1•,Mr4141„*",„::.te.4.#,-,,.,s44.1,.._c1..s.".4..4.m.,`,;1P.:y../.4,.;1,:.1....,7'.A,4r.f,;..:,,',..,f1:M4,gi,kD1:,44,,-,,.,;4,:,.4*;!.i0S..;$;•'.1',4c1,... it%.,,*-,,4‘,',I:,-„I„'A'N•.4r:4.*)4,!,::.,,A-p'i,4.:,.17V1%;14i.:s0*1.!;0.:.ti.0s,,:4--dtti1l.tkei,-2177lr,.4i.;;:42t:‘'.:!t::t1J;;ia'•,.-'..:,:S.':_Y7,;!-,'4'41,'.5t!,.-'-i'.:,.k,.,4e4,g,7i4.n,ce,'.0..,:.7:k.i.,.:,:r0ir74l'f!,.-.;,:e.I:t•.lld-t4,,V.Yi-l-4I44.P.7i.A,v1:t-g0V1'a0".V%k.„..%4,-1Atk4fY,',-'.•z;W,a:•I,.r;4v'!1,V,.1,_1.1.;7,.:;.,':,i:,1.4%',-1.:..:,4 '.:i4T10.j,i,.zi:.#.-.(/(0-;i.-.5)..7.4$„i,,,,-0;,V..1.$4•,',''.:t,,T;\, ,kt'sA._,t•z.9...i,-.vVi.-..'",'•:.t;.',.:',\.4`\\.4,\:, 1 s •\\ '\\ \,,1\ \'\ \,\1 \\ 4 \ \\ \ \ \ ` , \ \ 'A \ 1 \\ \ 90/270iiIm ?: tIt1 1 \ 1 \ 90 VO'•4::-..-. 614$.:1V,;:;'; .' • .''""','," S.4 4:44.:011•.:.'. / / .,•::,.....‘ \.-A. Numsut 1,:-.„..."?.....- .._ ... _,. I AtkiNke...i.'1-......`"A•ma 10 - Ad , /:./,-- .. / .N ,. ,voki -\\\v s. - A, - is„• 1... 'ft...,...."%-s.:-.--'-Z-31 . ....rofjpooefir ":---',/..././ '''.//// /' k* A 1 k ,:k ,.:41.,>-.4,147-4,,,•-•-..-.:04-.4=1:„.161.-;/„.._.... ,.- ;„ , , , ,,,,,,s, • 4,-;...,,,,s, •-,,,-..4......01-,!=z,--, „=-.4,-...-.. ,/ !&N 1 .-•il ,,:--•v• .4,,,, ,7,..--,:::,:.-_--,Iikrife.=_.---it',-..4,..••••••, 7 / , 41 Y *N•`,..s S;"--zt,4-11.-2 riTra 9 'I:I-Art, /, k 4\ ''''' , 41,'•4•14:::-.-.41L-NV:"..v..--,Ple-sti-24-..:-.1,,,!....-.0.-vt,.. -, /' ' N 4, -z*•... 1, 4.,74...-.--4-1-17-1.--Tize,Ara-,Tavalosk.re-11.:-... , -/ %.„„s%,-,..,.......ty...44,,,,„„,ro.,-........,_..„1,-...-.....-.....v.....,-..-.z,,;,....,„,„......s.I.... • Ns,- ,:.--,...--...,,--,.----Ir-.1:-.--.4:tr......"r.`ra..-•,--;11.4%.•." *. '"'" --Z--».. ' 'IV.441'0410-t.:41i74:=1".•"..4....:=S040:. t.._...t-6,-..,;. , ..,4- .4:41t.,„1.1,,,e...-01staire"..'...ra6,...re,p-NISkir:!At--.....1,00-IP'-•...,.! -150/210 %%V.-40;;;;-,...„_-.4.1*.,-.....:zw--v2r--tor---z...•%-.....0......„1: -.0 150 - 2.1nr*--46°.r...v0,J.:,----•,140'- '..7 -"*.irearaii-Ar.rarria•=1;. -,... -180/180 .-,s- CD",CO2 Kt CO2 93 02 ntr Plan 01803.Plan cos 09,085 030.01 VO -x- -Ms.Plan 005.00.005-000441 00 4A". Plan 005.12.Plan 005 IR.086-I00441 00 -t 04 005316,P.085.315.005 315,10 00 -4- 002,10,CORM,002-70 00 + Plan 00505.PlaA CO5-05.C0505,3%.VO 44 *0000005.,4106CO.&00,09,01 80 .4B- Plan CO5.1 3.Plan 005 13,005 13,07 00 ÷ Plan.006.315.ane 005-915401 005-015001 w010 00 ÷ Plan 005.01,PLen 0.05-01.005.012507 VO .09 P,an 00508.Plan OM OS.005-08•60/00 4." 006 000.10 Pan 00510.00548801 VO 4- 064 006.314.702 005-312.C05.91.014 VO lte 040011 I.NMI,swpw 1 vo 44" 4400CD.,Nen 085-04 000064441 03 9" 7106 005.07.Plan C05.07.CD5.0101,01 00 ••••• Plan CDS II,0501 505 II,005 11,01 80 9" P87 050814,Plan 005 014061,CO5-31.1P1315014 00 .13. 046046010 Inc Azi TVD + + N/-S E/-W Dleg TFace Target .Sb 4234 3 0.00 0.00 36.30 0.00 0.00 0.00 0.00 �0 CD5-046010 464.20 0.00 0.00 484.20 0.00 0.00 0.00 0.00 0.00 484 774 634.24 2.40 145.00 634.20 -2.57 1.80 1.60 145.00 -3.11 36.30 To 18792.44 1553.39 25.38 145.00 1520.50 -182.11 127.52 2.50 0.00 -220.15 774 1064 1664.07 25.38 145.00 1620.50 -220.97 154.73 0.00 0.00 -267.13 3176.32 55.50 69.94 2818.35 -276.73 985.92 3.50 -93.65 -694.16 9030.52 55.50 69.94 613420 1378.13 5517.83 0.00 0.00 -1277.12 1064 1344 11202.85 69.00 345.07 7307.46 2881.39 6194.93 3.42 -104.93 -245.10 14:38,April 17 2015 11206.07 69.00 345.07 7308.61 2884.30 6194.16 0.00 0.00 -242.16 1344 1634 11791.86 85.00 331.76 7440.50 3411.25 5983.41 3.51 -40.77 323.03 CD5-041.Heel 091014 JH 11811.86 85.00 331.76 7442.24 3428.80 5973.99 0.00 0.00 342.95 1634 1924 SURVEY PROGRAM 11947.98 90.44 331.76 7447.65 3548.58 5909.66 4.00 0.00 478.88 30801 From Depth en Survey/Plan roof 18792.44 90.44 331.76 7394.50 9578.39 2671.56 0.00 0.00 7321.55 CD5-04 2.Toe 091014 JH 3630 650.00 C05.04,10(Plan:CD5-04)GeD-GC-SS 1924 2214 850.00 1850.00 CDS-04,10(PMn:CD5-O4)MWD 85000 2509.05 CDS-04,10(Plow CD5-O4)MW0"I816-AK-CA2-SC 2501.05 400305 CD5-04,10(Plan.C13504)MWD 2214 2503 2503.05 11791 06 C135.04,10(Plan:CD5-04)MWD"IPR.4K-CAZ-SC 11791 66 13281.06 CD5a436p10(Plan:CD5-04)MWD 11791.86 18792.44 C05a48p10(PMn:CDS04)MWD.IpR-AK-CAZ-SC 2503 3174 CASING DETAILS 3174 3834 TVD MD Name Slze 3834 '"" 4504 180.50 180.50 20"x 42" 20.000 2351.50 2503.05 10-3/4"x 13-1/2" 10.750 7440.50 11791.86 7-5/8"x 9-7/8" 7.625 4504 5164 7394.50 18792.44 4-1/2"x 6-3/4" 4.500 5164 5834 5834 6504 TCR required 0/360 6504 7164 r=ry-Thi.,.,�..., .. 7164 7834 �. -�:�q►w�. 7834 - 9334 op-, -- ' '�__ ,..'`.tet-'� -30/330 • ' �0�� �_` 30 9334 " 10834 �/ ♦/%•oma � . �:. �` `o, 1 ai0 =1. 2. �t� .`�,.7`\ 10834 12334 �_!;. i.�� z Em.� .�;�t��!��.. -..4,,, � Sys 12334 13834 ��,9rT-r�7, i /•'i ��JWy:..� \ . k !� 13834 15344 ��,, � a� .T 416 4� 1. �. I�.����I/i�� �s ��.��•.....---,....,..-_,. .......--,........4%..... q, . `�"� �``1� 15344 16844 J A;r i -41 it .:+��.V����p_ N, A7��4.....:- .** - r'��y �. I� /.Niii �.\0.� ���-�� �1 i •. 16844 18344 -60/ :4i1t ' 7:gi '' rA+4!".4WJAKOSTO lie, ��r�:41, � .mo i _ ��A��a. :.-.`�����6 4�1���� ,, , 60 18344 19844 fir.. ii#0 SV�s. \�% p ap\,400 t�'_ "gyp 7 e• lreW ����Al.. �. �i1 4OVZ►4, `V. Ai... , P.�+♦ ale,:,1 o O+ app i Pt i i g.--,- -.4•041111V441.4 MIIIIWArry0 4/14 40, 4.. .rornittile,-t1-,•••:ONO.''' \' 11.4- ' s.21' ITV; • 14 400%�.,.%-.:11614.4.140,00 D1' 'h . Nom' uy� �2 ,�, �) 11111111 90/270 vy �.( ��1 `/"�--�. 'it'.n -.`-,' 90 'vy�� rApt a i ..air"JJ gli ;4 J � \.'1.11#04i,„,i'lMS. 4A$E,''klIA,100,__ _ OiltkNrn.......\_ u `, w ;; III I' *okiimiolo..„„ ,,I#0,„,,404ftwor: ',. ...... .......... .. ...., ' e., // aa;2k_041l Q 4., \,%•-w-..'4-?-''a ,fry \S4\8 ` i ,��.-moi/ ��,moi •-120/240 �� �. 1� 120 Ikk -150/210 ��� """�=� 150 -180/180 -e• -tr ."eDSOC6200p�.00542.60700 -2 642.007V0 0. 2..3703 ->E- Plan c05.aaw507V0 $ ;,*00700 a 0.R -Ran 611609.0000 -8- M -0050,.0050,.00700 •e 00...307 0 + " 00610600700 4- M., 6" -a• 06061611.6.01.1' 1,3 61000.0 P1."00602,A-00602.00602600700 8 01.800507.01..00,07.00507.00700 Plan 00611.Flan.005II,0061,.00700 $ Mart 065470,767 005014061.0050, .0 011 9 00606.010 • 0 14146;April 172015Easting(5000 usft/in) , , I . 1 111111III , , , , I , J , h , I_.,.._, 1_ , I , , I , , I , , , , I , , , i I 111111111111111 II 11111111111111111 �,■y CD5-02wp07 CD 03wp07 CD AR.,e.wp'7 — CD 12ww7 _ cD2-78 CD2 Alpine Pad — 4CD 04wp 0 — C• e :e i D 1 Di .sut 1 - Z C -O 7 _ kt S7 g= CD5 Alpine West Padkii � -o t— —c0 z° _ - ' CD5-01 wp07 CD5-05wp09 CD5-08wp07 - _ CD5-11 wp07 CD4 Nanuq Pad — CD5-315PB1 wp10 — CD5-314PB1wp14 - CD5-315 wp10 CD5-314wp14 - 111111111111111111111111 III ! ! I1 IIIIIIIIIII1111111111 , TI11111111111111111111111 11 1 IIIII Easting(5000 usft/in) AC Flipbook Errors Report Pool Report • • 14:57,April 17 2015 WELLBORE TARGET DETAILS(MAP COORDINATES) CD5-04wp10 Name 7VD Shape CD5-041.Hee10910t4 JH 7440.50 Circle(Radius:1p0.00)O00) CD5-04 2.Toe 091014 JH 7394.50 Circle(Radius:100.00) Quarter Mile View CD5-0/1.Heel 091014JHGrde 7440.50 Circle(Radius:1320.00) CD5-04 2 T 09101 091014 JH Circle 739450 Circle(Radius:1320.00) 12000 024 V. _v. _ _ v.- 12000 21y G9wwili Gp2 19 11111 10000 9Q01a Rao _ G�,yh IMO G04 t7 �1 D x,8000 G° VA = m O Nuiqsut 1 a WO$OGP1GQ20N 6000 � '111,\ 1 al 1 =-54000 4G Ao 02.(nCD2-470 naA� w , .�I 2000-4 - / . \ �o 3,9 11 p3 0 G,9Z GO' 0 2000 4000 6000 8000 10000 12000 14000 16000 West(-1/East(+1 (2000 usft/inl O 14:56,April 17 ZO1S WELLBORE TARGET DETAILS(MAP CO-ORDINATES) CD 5-04w p 10 CDS ,HeN 09101•4 JH 17444D0.50 Circle(Radius:100.00) CDS-04 21ue 091014 JH 739450 Circle(Radius'.10000) Quarter Mile View CDS-04 2144091014 Code 7394.50 Circle(Radius.1320.00) CDS-041..Toe 09 101 JH Circle od 7440.50 Circle(Radius.1320.00) • 12000 • 10000 �o._ ca 8000 Nuigsut 1 +6000 _c 0 Z 4000 0 w 2000 •0 0 2000 4000 6000 8000 10000 12000 14000 16000 West(-1/East(+1 (2000 usft/in) • • CD5-04wp10 3-D View . AIb97 CD5-O4wpl AIb96 Nuigsul ® 221:11 1„ UJU AlpineA • CD5-04wp10 Surface Location . 'C2) 101044mii CPAI Coordinate Converter * From: To: Datum: 1NAD83 • Region: (alaska ..7_1 Datum: (NAD27 Region: (alaska • C Latitude/Longitude (Decimal Degrees C Latitude/Longitude (Decimal Degrees 1 UTM Zone: South IC UTM Zone: Ern—True E South 1 a State Plane Zone: Units: State Plane Zone: Units: LITs:ii—cl Legal De, t: Legal Description(NAD27 only) Starting Coordinates: i Legal Description X: (1489514.65 Township: Lou1 Range: 1004 11---; Y: 15965645.41 Meridian: u Section:(18 (310.05967 [Fir j (2497.4940 i Transform I Quit ;. Help CD5-04wp10 Intermediate Casing I tn. CPAI Coordinate Converter From: To: Datum, 1NAD83 j Region: (alaska 2j Datum: (NAD27 zi Region: (alaska C Latitude/Longitude (Decimal Degrees Latitude/Longitude (Decimal Degrees UTM Zone: South UTM Zone: (True E South c• State Plane Zone: 1411, Units: 11171EA. r. State Plane Zone: Units: 1-6;67;1 Description IPIAD27 onlyj 6' Legal Description(NAD27 only) Starting Coordinates: Legal Description X: (149556497 Township: 1011 ifT-"" j Range: 11-75-4 lE Y: 15968935.47 Meridian: lu „ Section:18 11E--- 12181.6224 FELj 11780.5615 Transform Quit J Help • • CD5-04wp10 TD M. CPAI Coordinate Converter 1 (=:i + t I From: To: _ i —{ Datum: 1NAD83 Region: alaska + Datum: jNAD27 +1 Region: Ialaska Latitude/Longitude 'Decimal Degrees t__ Latitude/Longitude IDecimat Degrees zi UTM Zone: 1 (— South C UTM Zone: True !l South State Plane Zone: 1-4—,.--1 Units: us ft State Plane Zone: True + Units: ,usft _'` vrjai Descsipticr51tJ .::._ _-t,; t: Legal Description(NAD27 only) ___.]1 Starting Coordinates: Legal Description X: 11492377.97 Township: 1011 N Range: 1004 ICE t Y: 15975167.47 Meridian: u Section:15 l ITRE—C1 11292.2374 FEL 15068.1441 I I i Transform _ Quit Help 1 • Tollerable Collision Risk Worksheet TCR required As - built "REV DATE BY CK APP • DESCRIPTION REV DATE BY APP DESCRIPTION 1 ##/##15 CZ DB C.A. UPDATED PER K150003ACS ALL CONDUCTOR ARE LOCATED IN PROTRACTED SEC. 18, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST. WELL 'Y' 'X' LAT.(N) LONG.(W) FNL FWL GND PAD CD5-x01 27.6 34.1 CD5-x02 28.1 34.1 CD5-x03 28.4 34.1 CD5-x04 26.6 34.2 CD5-x05 28.1 34.3 CD5-x06 27.7 34.3 CD5-x07 27.9 34.3 CD5-x08 28.1 34.3 CD5-x09 27.3 34.2 CD5-x10 28.1 34.1 CD5-x11 27.9 34.1 CD5-x12 28.0 34.1 CD5-x13 26.1 34.2 CD5-x14 5,965,591.356 1,489,322.327 70' 18' 48.414" 151' 13' 28.633" 368' 2240' 27.6 34.2 CD5-x15 26.8 34.2 NOTES: KUUKPIK COORDINATES1. 2. SHOWN ELEVATIONS SHOWNARERBRITI HEON RP PETROLEUM MEAN E ALASKA STATE PSEA ELEVEL E 3 BP.M.S..L4, NAD 8 .,.E ■-.�u�c Alpine Survey Office yV ALPINE MODULE:CD50 UNIT: CD ConocoPhillips ALPINE PROJECT CD-5 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 14-12-09-1C ##/##/15 CE-CD50-### 1 OF 3 1 41.11.Z-S0-1,10Z VN1M331 31 31404641906VA VV 100 L00L0S000 B . :=// 1. tC !a _ A,e_ 1 m C3 Mt LU CN2 CC , 8 3 ffi e .-1'f CO = N s fn ' is sC�_. A >ugwme yo I 1p55 0.0 u 30arav3p �GGE 63d 1! �r - - 9111nroa .IQ;?4; 1 .'49 i ga s tE )Opal ( I '� Egg r .e-sr 1 c I I III 1I I � - 1 - a� < _ -F ■1■11WEE 7E�■■■ , r 1 w: IF IC) — v I tom @\ — ' � • 1- a - T # _ -4 .pox- us — u iirtf r 2 glom al — t,'1,,, ( ��l N `e-io% -— III4•" . o a k cTOm - 7 \�� aI 0 - —' e tom \ 4/' lL rn 10 eio%—►. 1 3 d �n -4 11 10m - ■11 0 m "a ,liom•- a -I U' Z L 81 lois -� —\._—— —lc—__ Q ]1 •O . --.-7E -- N Cl lOm �i. G 0. ♦l los - to O L To lOm --®—— k a` SI 17-1 — -i &,' o -1 ap� In t wof G CP Y C.) W K K 0 < _ 4 J • W N i.-.1 E as gg g €U€€€€€ €€€€€€€€ 111;IRI< AO!1 it • g a 888$ 888Y88 IV I • a a • M I i4 i__, U ' g 4 Itg 1 & — 86 b y c� tpi 1I!I flflh OgilioRyggOARghl g §888888Ei88888B88!e 1 • jLS ' ` end 9 covi PROPOSED WELLS CPAI OPERATED UNIT ...--...„,_ s..))_ Operator � L38846� ,� C-1 CPAI LEASE with ADL#, and Filet CQ QcS' 300634 ' Q o COL ILL� E `� RIVEI4 UNIT ASRC-NP 1 ASRC-NPR2 ASRC-NP ASRC-NPR 0O s r \\C" S` �0Q0—AADL387207 c5932191 � 47 58 Nf R - . ► CD 01 \ c-) 0 fic5O AA092347 ! SRC-NP- QIIII\` Qc3`340758 i t� 1 'ti. �` '1/4DL380075 32034 A � -NPR2 �DL380077 V2036 AA09234 ADL38720 340757 d _ 932193 atASRC- PR4 n 1►� 7(31,„ ConocoPhillips f Alaska, Inc. Proposed CD5 Wells With N Leases 3-19-2015 AA081817 0 0.5 1 932552 1 -1 Miles • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday,April 28, 2015 11:21 AM To: 'william.c.earhart@cop.com' Subject: CRU CD5-04(PTD 215-072);CRU CD5-05(PTD 215-073) Will, 1. The diverter schematics both show a building(?)at the outlet identified as a truck loading area?Please clarify 2. Please provide the length of the diverter line 3. For CD5-04(PTD 215-072),there is an anti-collision major risk failure with CD2-33. What mitigation measures will be in place to minimize this risk? 4. Please provide mitigation measures planned for dealing with the water that was encountered in CD5-314(PTD 215-039). 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.Loepp(a alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loem@alaska.gov 1 • Bettis, Patricia K (DOA) ?Th h vs-o From: Bettis, Patricia K (DOA) Sent: Wednesday, April 29, 2015 11:15 AM To: John.G.Samuell@conocophillips.com Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. 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.bettispalaska.gov. 1 • Bettis, Patricia K (DOA) From: Dai, Weifeng <Weifeng.Dai@conocophillips.com> Sent: Wednesday,April 29, 2015 3:13 PM To: Bettis, Patricia K (DOA); Samuell,John G Cc: Loepp, Victoria T (DOA) Subject: RE: CD5-Pad Wells Patricia, Yes,we are considering setting the surface casing higher, current plan is to set surface casing at+/-2,120' TVD, C-30 is about 2,305'TVD, so roughly 185' higher than C30. Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, April 29, 2015 2:56 PM To: Dai, Weifeng; Samuell, John G Cc: Loepp, Victoria T(DOA) Subject: [EXTERNAL]CD5-Pad Wells Good afternoon Weifeng and John, Until ConocoPhillips sorts out the water issue, the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. For the next CDS well, CD5-04 or CD5-05, has ConocoPhillips considered setting the surface casing higher? If so,at what height above the C-30 would the casing shoe be set? Thank you, Patricia From: Dai,Weifeng [mailto:Weifeng.Dai@conocophillips.com] Sent: Wednesday, April 29, 2015 1:32 PM To: Bettis, Patricia K (DOA) Subject: Mudlog CD5-Pad Hi, Patricia, We will run mudlog in intermediate section as per the request. Please advise if we need run Combo LWD log (include Neutron/Density) in intermediate section BHA in CD5-04 or CD5-05, (we obtained Combo LWD log in surface section in first well CD5-314, so I assume Combo LWD log is not needed for surface section anymore). Weifeng 1 1 r • • Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Samuell, John G Sent: Wednesday, April 29, 2015 11:39 AM To: Dai, Weifeng; Earhart, Will C Subject: FW: [EXTERNAL]Mudlog CD5-Pad Fyi Sent with Good (www.good.conl) From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Wednesday, April 29, 2015 2:14:45 PM To: Samuell,John G Cc: Loepp,Victoria T(DOA) Subject: [EXTERNAL]Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. 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.bettisPalaska.gov. 2 • • Bettis, Patricia K (DOA) aL5 — a-77Z From: Bettis, Patricia K (DOA) Sent: Wednesday, April 29, 2015 2:56 PM To: 'Dai, Weifeng';John.G.Samuell@conocophillips.com Cc: Loepp, Victoria T (DOA) (victoria.loepp@alaska.gov) Subject: CD5-Pad Wells Good afternoon Weifeng and John, Until ConocoPhillips sorts out the water issue,the Combo LWD log should include the Neutron/Density in the surface and intermediate hole intervals for the CD5-04 and CD5-05 wells. For the next CD5 well, CD5-04 or CD5-05, has ConocoPhillips considered setting the surface casing higher? If so, at what height above the C-30 would the casing shoe be set? Thank you, Patricia From: Dai, Weifeng [mailto:Weifeng.Dai@conocophillips.com] Sent:Wednesday, April 29, 2015 1:32 PM To: Bettis, Patricia K (DOA) Subject: Mudlog CD5-Pad Hi, Patricia, We will run mudlog in intermediate section as per the request. Please advise if we need run Combo LWD log(include Neutron/Density) in intermediate section BHA in CD5-04 or CD5-05, (we obtained Combo LWD log in surface section in first well CD5-314, so I assume Combo LWD log is not needed for surface section anymore). Weifeng Office:(907)-263-4324 Cell Phone:(907)-342-9508 From: Samuell, John G Sent: Wednesday, April 29, 2015 11:39 AM To: Dai, Weifeng; Earhart, Will C Subject: FW: [EXTERNAL]Mudlog CD5-Pad Fyi Sent with Good(www.good.corn) 1 • From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Wednesday,April 29, 2015 2:14:45 PM To:Samuel!,John G Cc: Loepp,Victoria T(DOA) Subject: [EXTERNAL]Mudlog CD5-Pad Good morning John, I understand that ConocoPhillips may move off of CD5-314 without drilling to TD due to surface hole conditions. The AOGCC requires a mudlog to be run on the first well drilled on a new drill pad. Therefore, if ConocoPhillips plans on drilling either the CD5-04 or CD5-05 next, please run a mudlog from base of conductor to 7 5/8" casing shoe depth. Mudlog will not have to be run on the horizontal production hole interval. 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: Earhart,Will C <William.C.Earhart@conocophillips.com> Sent: Tuesday, April 21, 2015 1:26 PM To: Bettis, Patricia K (DOA) Subject: RE: CD5-04: Permit to Drill Application Patricia, We plan to run gamma and resistivity LWD in the 9-7/8" intermediate sections on CD5-05. This will be the same for CD5-04 intermediate, as well. Sorry for missing that information. Thanks Will Will Earhart Drilling Engineer-ConocoPhillips Alaska,Inc William.C.Earhart@conocophillips.com ATO-1706 Office:+1.907.265.1077 Mobile:+1.540.448.1789 • From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, April 21, 2015 1:12 PM To: Earhart, Will C Subject: [EXTERNAL]CD5-04: Permit to Drill Application Good afternoon Will, For the 9 7/8" inch intermediate hole, what logs does ConocoPhillips plan to run? The proposed drilling program discusses the logging progam for the surface hole and the production hole, but there is no LWD program mentioned for the intermediate hole. 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: Tuesday, April 21, 2015 1:12 PM To: 'William.C.Earhart@ConocoPhillips.com' Subject: CD5-04: Permit to Drill Application Good afternoon Will, For the 9 7/8" inch intermediate hole, what logs does ConocoPhillips plan to run? The proposed drilling program discusses the logging progam for the surface hole and the production hole, but there is no LWD program mentioned for the intermediate hole. 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 • • 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. ! • TRANSMITTAL LETTER CHECKLIST WELL NAME: c12 L , c66--- PTD: 2 -PTD: AAS s Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: l i4'6 ?Ct/6,1-- POOL: CO /ud/ R)V4LAr / 1 E t �✓ Check Box for Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are / also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, Vcomposite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. HZS 6,A sis cir on is f- w'1 eS v- Cznc_1,1) � LLt oi;"- Revised 2/2015 f m lob e�x, y !I, 9 t b ( �90 ). • • 0 Co , . , a°)) a : : : : , : : : ° • co a oo - c, • C co 0, a 0O 0. U' 'd 3 : co, n 0. C �, 0, _ N' VW, O in .,0 0eE CD 00 01 y s O N a ° ° CY N. 4 Qi, a CO E p O o Co m' 0 m 0 _ m, 0. 7 3 CO ° In o, �, a o a) 3, o' 3 y -, c cD iii > o rn '3, o N k°� c ;5 o) a • O, g V T O Z cc c O. y co -3, >O >O (0 M, a ` � p, 4 Z U, �, 'C. �' EO, a) a •C a .N, O, Co, 2, 0; V D �, in °) „_, m, Co , E, O, a u) a) , > , Q' _- �, _, b 0, a 0 ay N t 0 o �n' ° .°.. ca . _, ° 0 o c a o. a?. a m. M. m, w, m • a, w J' , Z, 'C 0 C, 0, �� Co E, 0� 0 CO _� C' c� Ti)', t, a: u) m CO, N, v m, °� v, v, co m, , 3, 7' N m m v1 O E Nm@m . mE U ° N m o c o. m O U, O, L, 3, V, CO m' M a) m' ° V W N 0 0 ° a, • 0 d', (L> w 7, V, U, >, u) ••y, 0, Co, co, -p a t0 CU (n, p, J, m, m, 2, '0, aY N' csi0, - €, m, m, N, 0, , �, Z Q, U 5, �, �, a o U = ,co0 - o, a . E, E' a Co ' 0 a) 0 : , p, �, v, 0, ,E, 0' 0 _ a) x (.0 m' o ° • Z L, 0, 0dO m, c, co ,, oa < .? CO 2: _ 1 W N, 0O W LL U' U U U �' iE Q. W Q Q a): cup) ii)) N, N: CO, N, hi)) N, am> aa) Q, Q, a N N, N, o, O, aai, N, < N, N, N: N, a) N, a) N < O 0: < < < ' 0.4) Z; Z > >• > > >- > > >' > > } � Z Z Z >- >- > Z Z > > Z � > >- > >- > > � Z Z } Z Z Z. > m N i° T a E, 3. - 0' O, ° c t' o 0 °, x o : : ', 0 3 o U a�, as, _ o' 0 C, N Z, 0 m >ii Q' � v, 4 -8' m o', � c�' �, m v, ti �, m, c,O3 cN C. >, ay N,C. 0 U0, N, dc, - 30, d', .'O, N, N kr) -5 co 0 Fe• U 8:,' z t, O) ` Z, y, O, 7 3 0, uy c' 0) -c C u> 7, ..+ u> 7' Q' u) 0 m' .. O V, O, m, a 0 `, m, m, 0 0 0) aa), 4., .0 C N, c .' O w Z v a c °' o' °' �' >, r-, p °, _>, v, 4 2, y vi c o o °,0 J Q M, .00' c, C E� ate- N O C c, 0, •1. ~. w„ c 0 , o(S .0+, �_ C m, +L-• O) �. N, �, d C O J fl -,°�, °, �, -° $, �. �. y o o, a aoi, CY 'a ami, 2, 0 y d ° m 3 > m Y co m u) > a`> 5 c, as To' Q. m „, v o, 0, .0 -°o m, m, c, o > > °' v co Y f° ° o' o, N ° E' �' f6' �' > ° w E a c> ° m, •O - 0 O m, c, m. .- _ 5 c; n Z' o; . E T 3' m 0, m' t m 3 wm•„ 7, a. N l°, O m, t. t, -, f° O, V, m, O G, a) 0, M, N 0, _c 0 ° a> O d �, C O, .T 3, 1 LL O`' c' co• n' m, o` a m, •3', •§', �): ill. a) .., 'o v,' '5 m 3 m' d o o. m y, 4 •- 5 m o, 3, , 2: m, °', U O• d a c, t� 13 - >', 0' a .a v, V, > `o •j a> O' a C• ' V y, v� N, (a° 0'f O D) C 0 a 0 -" a> n. J E' -0, 0 (° m O J; U 0, m m 0' m E' V, 0' C, Y, m, °', C) m' @, m Df o, w, v), C, �, C, `O, co, O, • J 0 m a m, -° a' 0 m m 7 7 d �, m, O: �; m _ 'O m y a E, C, U N, " u> O G L V ., a a a o) d' a c; a =' r- • ai a m m m m co as O a) mf >, 3, 2, -°' N �'' o, d 'O = 0, U, co, E, 0, 0, O, 3, O. m as, . C. 7, 7, 0 Y vi r> .3 0 m o' •0 . c, -0- -a a @ m (° c a a m, m, as, m, 3, c, c a a as c c' CO a o. ° O m, :?, > o °) LLO - Co .D _, a, 0 -0 E' c Co .0 .0 a, ami , 0 y 'm' o v >, .N Co _c 3 ami -° o' co .- o, m c', E. c', 0 E U C E, �, aa) m, 0 as V, 0, _c C c, . 3 7 as' (°' S m = 7 v' m a) 0 a CO, CP CO coi c la'. Z >, c 3' v (� v �' o oy ° v y v, m, o. o. m, `o, m, viE v, c9 C, },, m, 0, 0, 0, m, - N, O ' a °', N. 0, 7 U > > 3', C 7 `> 7 N', C w. w, ai >'' u)' m Q m, �° �.. o c°im, 7 �, a) E a v' @' H 1- 1- Crg > d, a, _Na a'' c) E', m, y', m c m J U co ,_E m' o ' coo, v a a as: €, m m, 3' °' o; n' g g �' m' v m v, v c O, o, L, ° a m m m m, o, z n ', ', u>, o O a a' U, ', ¢', a, U (n U, U v U ¢ Q o', m, m, U, ', �'', 2: 00_, p' w, c�, p E N N N N _ __ w coI co M CO(O I` a0 0) O N M - l0 CO CO OCV N co NI' 10 N M 'C 10 CO r co 0) O � 0 N N N CO N N N 0 M COM M M M M COM M M � a; O w 0 Y O • p c O N O N O 0)•0 Ce N ° 0) 0 N ° 0 �/ d UJ o `-ea T a) E \ N E. m 0' ° J C a c m a ° 0. m U O a F 0 a 1.- Q a s w a > 0 Q a I Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically • organize this category of infor I ration. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Alpine Rig: Doyon 19 Date: June 29, 2015 Surface Data Logging End of Well Report CD5-04 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 19 Well: CD5-04 Field: Alpine Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20711-00-00 Sperry Job Number: AK-AM-0902423999 Job Start Date: 18 May 2015 Spud Date: 21 May 2015 Total Depth: 18878’ MD, 7420’ TVD North Reference: True Declination: 18.21° Dip Angle: 80.77° Total Field Strength: 57529.66 nT Date Of Magnetic Data: 20 May 2015 Wellhead Coordinates N: North 70° 18’ 48.984” Wellhead Coordinates W: West 151° 13’ 23.055“ Drill Floor Elevation 71.14’ Ground Elevation: 34.20’ Permanent Datum: Mean Sea Level SDL Engineers: Ashlee Charters, Connor Murray, Sonny Tiger, David Durst SDL Sample Catchers: Geoffrey Yenter, Stanford Alexander, Mario Luescher, Enoc Velez-Martinez Company Geologist: Jennifer Hoyt Company Representatives: Rick Bjorhus, Kenny Harding, Adam Dorr, Dan Lowe SSDS Unit Number: 109 DAILY SUMMARY 05/18/2015 SDL on location. Spot and set mudlogging shack. Began rigging up, Legacy gas trap, and ran gas line to the unit. 05/19/2015 Finished rigging up unit and gas equipment. Calibrated gas equipment using 10%, 20%, and 99% methane, and blend gas. 5” Drill Pipe(DP) and 5” Heavy W eight Drill Pipe(HWDP) loaded in pipe shed and strapped. Rig floor and mezzanine cleaned. 05/20/2015 Continued Rig Up. Picked up and racked back 5” DP. Began to makeup BHA. Conducted Pre- Spud safety meeting. 05/21/2015 Made up BHA, filled lines and pressure tested mud lines, stand pipe, and Kelly hose to 3500 PSI. Tagged bottom of Conductor at 114’ MD and displaced hole to Drilplex AR mud. Drilled ahead from conductor to 1463’ MD before packing off. The pipe was worked free and pulled to 1419’ MD but unable to pump. Began troubleshooting rig pumps. Gas: The max gas was 13 units and the average drilling background gas was 2 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/22/2015 Continued to troubleshoot rig pumps while cleaning shakers and mud pits and rotating pipe periodically. Established circulation and reciprocated pipe. Drilled ahead from 1463’ MD to Surface section TD at 2342’ MD. Gas: The max gas was 29 units and the average drilling background gas was 12 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/23/2015 Circulated and weight up mud to 10.0 ppg before pumping 2x 34bbl nut plug sweep to gauge hole size. Back reamed out of hole from 2342’ to 453’ MD and run back in to 545’ to drop gyro. Pulled out of hole and laid down BHA. Cleaned rig floor and rigged up to run casing. Performed Pre job safety meeting before beginning to run in with 10 ¾” casing. Gas: The max gas was 35 units and the average drilling background gas was 6 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/24/2015 Run in hole with 10 ¾” casing to 2329’ MD before taking weight. Pumped up to 6 BPM in an attempt to get casing shoe to planned landing point at 2336’ MD. Laid down 6 joints of casing and re-madeup Hanger and Landing Joint so casing could be landed at 2327’ MD. Circulated and reciprocated while staging pumps to 8 BPM and rigging up cement equipment. Pre Job Safety Meeting for cement job was performed before pumping 100 bbl 10 ppg nut plug with rig pumps. Surface Lines were then pressure tested to 3500 PSI before pumping a 72 bbl 10.5 ppg Mud Push spacer, dropping the bottom plug, and beginning to pump the 11 ppg cement. Gas: The max gas was 16 units and the average background gas was 2 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/25/2015 Pumped 459.8 bbls of 11 ppg cement followed by 60.6 bbls of 15.8 bbls tail cement before chasing with 20 bbls of 8.3 ppg water and 10 ppg mud with rig pumps. After bumping the top plug, pressure was increased to 900 PSI and held for 5 minutes. The well was observed for flow and was static. 165 bbls of cement returned to surface. The riser was then flushed with black water, Volant was rigged down and casing tools were laid down. Serviced top drive, installed RCD element, rigged down diverter, and R/B 5” DP. Gas: There was no gas data to report. Fluids: There was 0 barrels of water based mud lost down hole. 05/26/2015 Rigged down riser, annular, and starting head and N/U wellhead and BOPE. Rigged up Choke and kill lines and double annular valves on wellhead. Rigged up MPD flo-box and trip nipple and fill BOPE. A leak was discovered between the lower rams and mud cross. N/D Trip nipple, flow box, flow line and break flange to inspect. N/U flow-box, flow line, and trip nipple. Gas: There was no gas data to report. Fluids: There was 0 barrels of water based mud lost down hole. 05/27/2015 N/U MPD flo-box, flo-line, and drains. The stack and choke manifold were filled with water with no leaks found. The BOPE, MPD equipment, and IBOP were all tested. Test equipment was rigged down and BHA #2 was M/U and tripped in hole. Ran in hole with 5” DP to 2012’ MD and wash down to 2233’ MD. B/U was circulated and casing testing equipment was rigged up. Gas: The max gas was 6 units and the average background gas was 2 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/28/2015 Casing was tested to 2500 PSI for 30 minutes and charted. The shoe track was then drilled out and the well was displaced to 9.8 ppg LSND mud. The well was observed for flow and was static. A FIT was performed to 14.8 ppg EMW after which the well was again observed for flow and was still static. Drilled ahead to 2448’ MD and opened the under reamer. Drilled ahead to 3126’ MD. Gas: The max gas was 81 units and the average background gas was 26 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/29/2015 Drilled ahead to 3620’ MD and pumped 34 bbl 11.8 ppg high vis sweep. Observed well for flow (static). Short trip to 2137’ MD to lay down ghost reamer. Ran in hole to bottom and drilled ahead to 4179’ MD. Gas: The max gas was 126 units and the average background gas was 35 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/30/2015 Drilled Ahead from 4179’ MD to 5268’ MD and performed FIT to 12.53 ppg EMW. Drilled Ahead from 5268’ MD to 5460’ MD. Gas: The max gas was 1073 units and the average background gas was 77 units. Fluids: There was 0 barrels of water based mud lost down hole. 05/31/2015 Drilled Ahead from 5460’ MD to 6950’ MD. Gas: The max gas was 97 units and the average background gas was 50 units. Fluids: There was 4 barrels of water based mud lost down hole. 06/01/2015 Drilled Ahead from 6950’ MD to 7983’ MD, circulated and conditioned mud and began tripping out of hole. Gas: The max gas was 73 units and the average background gas was 46 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/02/2015 Tested BOP, Tripped in hole from 696’ to 2295’, Cut and Slip Drill Line, Lubricated rig and serviced top drive. Gas: The max gas was 6 units and the average background gas was 2 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/03/2015 Ran in hole to 7983’ MD, continued to drill ahead to 9315’ MD, worked on centrifuge. Gas: The max gas was 104 units, a trip gas of 464 units and the average background gas was 43 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/04/2015 Drilled ahead from 9315' MD to 10226' MD, Rigged up and perform FIT to 12.5 ppg for 5 minutes, weight up mud to 10.8 ppg. Gas: The max gas was 616 units and the average background gas was 136 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/05/2015 Drilled ahead from 10226’ MD to 11387’ MD. Changed out gear oil pump, coupler and filter on mud pump 2. Gas: The max gas was 537 units and the average background gas was 132 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/06/2015 Drilled ahead from 11387’ MD to Intermediate TD at 11853’ MD, 7477’ TVD and circulated 12 bottoms up. Gas: The max gas was 2729 units and the average background gas was 155 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/07/2015 Continued to circulate and condition 12 bottoms up, weight up from 10.8 ppg to 11.1 ppg, weight up again from 11.1 to 11.4 ppg. POOH from 11853’ MD to 11620’ MD, pull tight. Cut mud weight from 11.4 to 11.1 ppg, continued to POOH. Gas: The max gas was 174 units and the average background gas was 93 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/8/2015 POOH, lay down BHA and run in with 7 5/8" casing. Gas: The max gas was 8 units and the average background gas was 5 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/9/2015 Continue to run in with 7 5/8" casing. Gas: The max gas was 131 units and the average background gas was 70 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/10/2015 Continue to run in and land 7 5/8" casing at 11837' MD. Circulate and condition mud. Rig up cement line Gas: The max gas was 1278 units and the average background gas was 70 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/11/2015 Performed 2nd stage cement. Set pack off and test to 5000psi for 10 min. Laid down 5" DP. Rigged and test BOPE. Gas: The max gas was 30 units and the average background gas was 10 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/12/2015 Test BOPE. Made up BHA. RIH with 4" DP to 1504 for shallow test. RIH to 5606' to test casing to 1000psi for 10 minutes. Began drilling out cement. Gas: The max gas was 30 units and the average background gas was 10 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/13/2015 Wash and ream out stage collar. RIH with 4" DP to 11583' MD. Test casing to 3500psi for 30 minutes. Wash and ream from 11583' MD to 11698' MD. Drill out shoe track to 11853' MD. Drill 20' of new hole to 11873' MD. Gas: The max gas was 927 units and the average background gas was 13 units. Fluids: There was 0 barrels of water based mud lost down hole. 06/14/2015 Perform FIT to 12.8 ppg. Wash and ream to 11837' MD. Drill from 11873' to 13482' MD, 7395' TVD. Gas: The max gas was 9899 units and the average background gas was 5788 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: Samples have been mainly fine to very fine grained white to clear to tan sandstone; Subrounded to subangular, moderate to well sorted, with weak calcareous cement. Trace pyrite and rare glauconite. 06/15/2015 Rotary drilling from 13482' MD to 15550' MD, 7464' TVD. Gas: The max gas was 8846 units and the average background gas was 7010 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: Samples have been mainly fine to very fine grained white to clear to tan sandstone; Subrounded to subangular, moderate to well sorted, with weak calcareous cement. Trace pyrite and rare glauconite. 06/16/2015 Rotary drilling from 13482' MD to 15550' MD. Gas: The max gas was 9159 units and the average background gas was 5322 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: Samples have been mainly fine to very fine grained white to clear to tan sandstone; Subrounded to subangular, moderate to well sorted, with weak calcareous cement. Trace pyrite and rare glauconite. 06/17/2015 Drilled ahead from 17920’ MD to TD at 18878' MD. Circulate bottoms up, then obtain formation fingerprint and continue to circulate. Pumped a 32 bbl spacer and displaced to 10.9 ppg NaCl/NaBr Brine. Gas: The max gas was 8300 units and the average background gas was 5555 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: Samples have been mainly fine to very fine grained white to clear to tan sandstone; Subrounded to subangular, moderate to well sorted, with weak calcareous cement. Trace pyrite and rare glauconite. 06/18/2015 Continued displacement to 10.9 ppg brine, then obtained formation fingerprint. Tripped out of the hole to 13539' MD and circulated one bottoms up. Tripped out of the hole to 13158' MD. Back reamed out of the hole to 11824' MD, with tight spots at 14141' MD, 14085' MD, 13835' MD, 13653' MD, 13564' MD, 13477' MD. Circulated 4 bottoms up, then pumped 2 35 bbl high viscosity sweeps. Performed a flow check, well was static. Pumped 32 bbls of 12.4 ppg dry job mud then tripped out of the hole to 3641' MD. Gas: The max gas was 209 units and the average background gas was 16 units. Fluids: There was 70 barrels of water based mud lost down hole. 06/19/2015 Continue to trip out of the hole to 371' MD. Install trip nipple, pull out of the hole and lay down BHA. Pick up and stand back 60 joints of HWDP. Run 4.5" liner to 7166' MD. Change out elevators, Make up liner hanger. Continue to RIH with 4.5" Liner on 4" DP to 9958' MD. Gas: The max gas was 10 units and the average background gas was 4 units. Fluids: There was 25 barrels of water based mud lost down hole. 06/20/2015 Continued to run in the hole with 4.5" liner to 11749' MD, circulate liner volume. Continued to run in the hole to 18878' MD, displace to ppg brine. Pumped 35 bbl high viscosity spacer, followed by 700 bbls of 10.8 ppg brine. Dropped ball and set hanger. Set liner top packer. Tested packer for 10 mins. Flow check (slight drop), pull out of the hole to 10324' MD. Slip and cut drill line. Pull out of the hole to 5992' MD. Gas: The max gas was 684 units and the average background gas was 26 units. Fluids: There was 39 barrels of water based mud lost down hole. 06/21/2015 Continued to pull out of the hole and lay down 4" DP. Pulled wear ring. Rigged up and ran in the hole with 3.5" tubing to 8058' MD. Gas: The max gas was 6 units and the average background gas was 3 units. Fluids: There was 59 barrels of water based mud lost down hole. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 0 5 10 15 20 25 30 35 40 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: CD5-04 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: MI Swaco RIG: Doyon 19 SPERRY JOB: AK-XX-0902423999 Days vs. Depth 18 May 2015 Sperry SDL Arrived on Location LOCATION: Alpine AREA: North Slope Borough STATE: Alaska SPUD: 21-May-2015 TD: 17-Jun-2015 Drill 9.785" hole to 7983' POOH to test BOPs 02 Jun 2015 Landed 4.5" Liner 18863' MD, 7420' TVD 20 June 2015 Commenced 13.5" Surface Hole Section On Bot: 02:25 21 May 2015 TD Surface Hole Section 2342' MD, 2245' TVD Off Bot: 23:56 22 May 2015 Commenced 9.785" Intermediate Hole Section On Bot: 04:49 28 May 2015 TD Intermediate Hole Section 11853' MD, 7477' TVD Off Bot: 14:55 06 Jun 2015 Landed 10.75" Casing 2327' MD, 2231' TVD 24 May 2015 Landed 7.625" Casing 11837' MD, 7477' TVD 06 Jun 2015 Commenced 6.75" Production Hole Section On Bot: 21:52 13 June 2015 TD Production Hole Section 18878' MD, 7420' TVD Off Bot: 11:57 17Jun 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: While drilling through the surface section during the permafrost area we had a lot of gravel coming up causing it to get in our gas trap and breaking a few beater bars. Recommendations: While drilling through heavy gravel areas be on the pits more, spraying the trap and to listen for gravel inside it. If inside, turn off and clean gravel out. Innovations and/or cost savings: N/A Doyon 19 Surface Hole Ashlee Charters 26-May-2015 What went as, or better than, planned: Drilling went very well, with great communicates between all parties, including our sample catchers getting with the rig engineer and mud engineer about taking mud samples, when and how. CD5-04 Alpine ConocoPhillips North Slope Borough -XX-0902423999 Alaska Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION:Intermediate Hole Section EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: During the intermediate section we didn’t encounter much gas. We would do bag test to verify our equipment was working correctly. When we started drilling in the Alpine A formation, we started seeing gas showing that our equipment was working correctly. Recommendations: Continue doing bag test during connections to show that our equipment is working properly. Innovations and/or cost savings: N/A Doyon 19 Ashlee Charters 9-Jun-2015 What went as, or better than, planned: Gas equipment worked properly. We received a new specilaized bag and valve system for our bag tests and upon its first use it made it much easier to maintain an air-tight seal when filling the bag with methane and when performing the bag test in the pits. CD5-04 Alpine ConocoPhillips North Slope Borough -XX-0902423999 Alaska Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: Our UPS power supply backup that powers our computers and gas gear failed during drilling causing us to lose several hours of drilling and gas data. Recommendations: In the future, our unit should be equipped with 2 separate functioning UPS' so that if one fails, the computers and gas gear can be switched over quickly to minimize data loss. Innovations and/or cost savings: N/A Doyon 19 Production Connor Murray 20-Jun-2015 What went as, or better than, planned: Cooperation and teamwork between Sperry, the rig, and CPAI personnel was excellent. When we experienced a UPS power failure, the CPAI company man on tour quickly found a temporary replacement for our unit so we could get our equipment back online. CD5-04 Alpine ConocoPhillips North Slope Borough AK-AM-0902423999 Alaska Surface Data Logging After Action Review Surface Data Logging CD5-04 ConocoPhillips Alaska, Inc MI Swaco Doyon 19 AK-AM-0902423999 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++ 19-May 0 8.80 -14 22 22/25/25 -50/36/31/27/20/20 -4.0 1/95 -1.68 10.8 -1.15/1.95 2600 160 Rigging Up 20-May 0 8.80 -12 25 24/29/30 -49/37/33/29/22/22 -4.0 1/95 -1.69 10.8 8.3 1.15/2.00 1100 160 Rigging Up, Pre-Spud 21-May 1279 8.90 -9 55 43/43/46 -73/64/62/57/42/42 -4.0 1/95 TR 1.75 10.9 8.8 1.68/3.29 2300 120 Drilled from Conductor to 1463' MD 22-May 2206 9.80 -10 40 44/65/69 9.0 60/50/48/43/35/35 1/-10.0 1/89 0.10 2.18 10.9 12.50 2.12/3.00 2200 80 TD Surface Section 23-May 2342 10.00 -15 53 54/72/80 9.9 83/68/61/55/46/46 1/-11.0 1/88 0.10 2.10 10.9 16.25 1.96/2.90 2100 80 TOOH, RU Casing Equipment 24-May 2342 10.00 -15 19 24/33/48 9.7 49/34/31/25/12/12 1/-11.0 1/88 1.00 2.00 10.9 16.25 1.84/3.10 2100 80 RIH w/ Casing, Cement casing 25-May 2342 10.00 -18 7 3/10/11 9.1 43/25/18/11/3/3 1/-11.0 1/88 0.10 2.10 9.5 16.25 1.58/5.50 2100 160 Finish Cement, R/D Diverter 26-May 2342 10.00 -19 9 5/8/10 9.5 47/28/20/13/3/3 1/-11.0 1/88 0.10 2.12 9.7 16.25 1.78/5.50 2000 160 N/U Wellhead and BOPE 27-May 2342 9.80 58 14 22 10/13/14 4.7 50/36/31/23/9/9 1/-6.0 1/93 -0.43 9.8 1.500 0.40/2.60 800 60 Test BOPE, M/U BHA, TIH 28-May 3061 9.80 55 16 35 16/24/28 4.6 67/51/44/30/16/16 1/-9.0 1/90 -0.43 9.8 8.750 .41/2.60 2800 60 Drill Out Shoe, Drill Ahead 29-May 4010 9.80 48 12 23 11/16/19 4.5 47/35/31/23/11/11 1/-8.0 2/90 -0.41 9.8 13.75 0.38/1.76 1900 60 Short trip to remove GRs, Drill Ahead 30-May 5314 9.90 44 13 27 13/20/23 4.0 53/40/35/28/12/12 1/-11.0 2/87 -0.24 9.6 19.3 0.23/1.41 1500 60 Drilled Ahead to 5460' MD 31-May 6789 9.90 42 11 23 11/13/17 4.4 45/34/30/25/11/11 1/-10.0 2/88 -0.20 9.6 13.0 0.18/1.12 1500 60 Drilled Ahead to 6950' MD 1-Jun 7983 9.90 40 9 24 11/14/16 4.3 42/33/29/24/11/11 1/-10.5 2/88 -0.15 9.9 13.8 0.14/1.20 1000 60 Circulating 2-Jun 7983 9.90 40 9 18 10/11/13 5.2 36/27/24/20/10/9 1/-11.0 2/87 -0.12 9.6 14.0 0.10/1.15 1000 60 Slip and Cut Drill Line 3-Jun 9078 9.80 39 10 29 10/11/12 4.1 49/39/30/26/10/10 1/-11.0 2/87 -0.50 9.7 13.8 .45/1.5 600 60 Drilling Ahead to 9315' MD 4-Jun 10085 10.80 40 11 29 12/16/19 3.2 51/40/35/23/13/12 1/1 13.5 2/85 -0.32 9.7 12.5 0.3./1.5 1000 60 Drilling Ahead to 10226' MD 5-Jun 11255 10.80 39 12 29 13/16/21 3.2 53/41/35/28/13/13 1/-14.0 2/84 -0.20 9.7 18.8 0.2/1.6 800 60 Drilling ahead to 11387' MD 6-Jun 11853 10.80 38 12 22 11/14/16 3.3 46/34/29/23/11/11 1/-15.0 3/82 -0.24 9.6 16.3 0.21/1.3 1000 60 TD Intermediate at 11853' MD 7-Jun 11853 11.10 40 13 28 13/16/17 5.2 54/41/36/29/13/13 1/-14 3/84 -0.25 9.9 16.25 0.24/1.50 1,000 60 POOH 8-Jun 11853 11.10 42 11 25 11/14/15 3.2 47/36/31/25/11/11 1/-14 3/84 -0.25 9.8 16.25 0.2/1.40 1,000 60 Run in with 7 5/8" casing 9-Jun 11853 11.10 46 12 28 12/14/17 3.0 52/40/34/26/12/12 1/-14 2/84 -0.25 9.8 16.25 0.21/1.40 1,000 60 Continue to run 7 5/8" casing 10-Jun 11853 11.10 41 12 20 10/11/13 2.9 44/32/27/21/10/10 1/-16 2/82 -0.25 9.5 17.50 0.21/1.50 1,000 60 Land and Cement Casing 11-Jun 11853 11.10 51 7 28 10/13/14 3.6 42/35/30/24/10/10 1/-14 2/84 TR 0.24 9.5 17.50 0.21/1.55 1,000 80 BOP test RU 12-Jun 11853 11.10 54 7 28 10/12/13 3.8 42/35/31/23/10/10 1/-14 2/84 TR 0.26 9.6 17.50 0.22/1.60 1,000 80 Test BOP, MU BHA, RIH 13-Jun 11853 11.10 54 16 27 12/23/27 3.9 59/43/38/29/13/12 1/-14 3/83 TR 0.28 10.8 17.50 0.24/1.90 1,000 100 Drill shoe track 14-Jun 13252 10.20 52 17 24 15/17/18 3.5 58/41/38/30/14/14 1/2 13 3/85 TR 1.10 9.5 2.50 1.00/2.90 145,000 40 Displace to 10.2 MW, FIT, drill ahead 15-Jun 15273 10.30 52 15 29 14/17/19 3.9 59/44/38/30/14/13 1/2 14 3/84 TR 0.90 9.3 3.75 0.80/2.90 105,000 40 Drill Ahead 16-Jun 17607 10.30 55 18 26 11/14/16 3.5 62/44/37/28/11/10 1/2 14 3/84 0.1 1.00 9.1 2.25 0.90/1.70 104,000 40 Drill Ahead 17-Jun 18878 10.70 37 9 8 3/4/4 -26/17/14/10/3/3 --------188,000 -TD Prod Sec, Displace to 10.9 Brine 18-Jun 18878 10.90 40 10 14 5/6/6 -34/24/10/15/5/5 --------182,000 -TOOH 19-Jun 18878 10.90 39 11 9 4/5/5 -31/20/17/12/4/4 --------184,000 -Running 4.5" Liner 20-Jun 18878 10.80 27 -------------180,000 POOH 21-Jun 18878 10.80 27 -------------184,000 -Running 3.5" tubing 22-Jun 18878 10.80 27 -------------184,000 Nipple Down Stack Casing Record Remarks 20" Conductor @ 116' MD, 116' TVD 10.75" Casing @ 2327' MD, 2231' TVD 7.625" Casing @ 11837' MD, 7477' TVD 4.5" Liner @ 18863' MD, 7420' TVD WELL NAME:LOCATION:Alpine OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:21-May-15 SPERRY JOB:TD:17-Jun-15 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 1 100 1 Mill Tooth / Hughes VM-3 13.5"116 2342 2228 33.36 0.994 33.4 4.8 48 735 859 1-1-WT-A-E-I-NO-TD Surface Section TD 2 200 2 PDC / Smith MSi516 9.88 2342 7983 5641 84.57 1.086 74.9 38 182 1826 836 2-4-BT-A-X-I-CT-DMF Intermediate Section - POOH to test BOPs 3 300 3 PDC / Smith MSi516 9.88 7983 11853 3870 55.14 0.094 80.0 15 162 3572 817 1-1-ER-A-X-I-CT-TD Intermediate Section TD 4 400 4 PDC / DBS MM55 6.75 11853 18878 7025 60.25 0.383 116.6 25 150 3060 260 1-1-BT-T-X-ER-TD Production Section TD WELL NAME:CD5-04 LOCATION:Alpine OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO: SPERRY JOB:AK-AM-0902423999 TD: MI Swaco STATE: 17-Jun-15 Alaska RIG:Doyon 19 SPUD:21-May-15 B i t R e c o r d . . * 24 hr Recap:Finished rigging up unit and gas equipment. Calibrated gas equipment using 10%, 20%, and 99% methane, and rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 19-May-2015 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Chlorides Morning Report Report # 1 Customer: Well: Area: Location: Rig: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 96% Rig Activity: - Doyon 19 Report For: 8.80 Size Job No.: Daily Charges: Total Charges: MWD Summary ConditionBit # 100% Gas In Air=10,000 UnitsConnection Tools - API FL Chromatograph (ppm) WOB -- Avg Min Comments RPM ECD (ppg) ml/30min NABackground (max) Trip Average Mud Type Lst Type DRILPLEX0' Depth in / out 8.80 YP (lb/100ft2) 4.0 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AM-AK-902423999 Rigging Up PV Footage K. Harding/A. Dorr ShClyst TuffGvlCoal cP NA Gas Summary (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) - - - Max @ ft Current -- Date: Time: blend gas. 5” DP and 5” HWDP loaded in pipe shed and strapped. Rig floor and mezzanine cleaned. NA in NA NAMinimum Depth C-5n NA - C-2 NA SPP (psi) Gallons/stroke TFABit Type Depth 2600.0010.80 MBT - pH Siltst - - Units* Casing Summary Lithology (%) 907-670-4347Unit Phone:C. Murray Maximum Report By:Logging Engineers:A.Charters/C. Murray Set AtSize Grade (max)(current) Cly Bottoms Up Time ------ 22 NA14NA Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time ------ Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) (current) Cly Volumes Set AtSize Grade 907-670-4347Unit Phone:C. Murray Maximum Report By:Logging Engineers:A.Charters/C. Murray Siltst - - Units* Casing Summary Lithology (%) 10.80 MBT - pH 25 NA12NA NA - C-2 NA NAMinimum Depth C-5n NA NA - - - Max @ ft Current -- Date: Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke (current) cP 8.3 Gas Summary in TFABit Type 1100.00 ShClyst TuffGvlCoal Footage Ss (ppb Eq) C-1 C-5i AM-AK-902423999 Rigging Up/Pre-Spud PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n 8.80 YP (lb/100ft2)Mud Type Lst Type Average Background (max) Trip (max) RPM ECD (ppg) ml/30min NA DRILPLEX -- Avg Min Comments Depth in / out 4.0 Tools - API FL Chromatograph (ppm) WOB =10,000 UnitsConnection ConditionBit # 8.80 Size Job No.: Daily Charges: Total Charges: MWD Summary NA Avg to- ConocoPhillips, Alaska North Slope, AK Alpine 96% Rig Activity: - Doyon 19 Report For:K. Harding/A. Dorr Depth Chlorides Morning Report Report # 2 Customer: Well: Area: Location: Rig: CD5-04 ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-May-2015 12:00 AM Current Pump & Flow Data: - Max 100% Gas In Air mg/l Continued Rig Up. Picked up and racked back 5” DP. Began to makeup BHA. Conducted Pre-Spud safety meeting. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/l 0 0 21-May-2015 12:00 AM Current Pump & Flow Data: 0 Max 100% Gas In Air ROP ROP (ft/hr) 4.23 @ Mud Data Depth Depth Chlorides Morning Report Report # 3 Customer: Well: Area: Location: Rig: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 96% Rig Activity: - Doyon 19 Report For:K. Harding/A. Dorr 8.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 1279' Avg to114' Condition - Bit # 13.5" 0 pipe was worked free and pulled to 1419’ MD but unable to pump. Began troubleshooting rig pumps. Made up BHA, filled lines and pressure tested mud lines, stand pipe, and Kelly hose to 3500 PSI. Tagged bottom of 10,000 Units8Connection 0 Tools GR/RES/PWD/DENS/NEUT API FL Chromatograph (ppm) -114' - WOB -- Avg Min Comments Depth in / out 4.0 RPM ECD (ppg) ml/30min 2 - DRILPLEX =Background (max)Trip (max) Average NA Mud Type Lst Type 8.90 YP (lb/100ft2) 00 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AM-AK-902423999 Troubleshooting Pumps PV - TuffGvlCoal Footage cP 8.8 Gas Summary in TFABit Type 2300.00 0 0 (current) Yesterday's Depth: Current Depth: 24 Hour Progress: 369.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 0' 1463' 1463' Max @ ft Current 125'91.0 Date: Fluids: 0 bbls lost downhole Conductor at 114’ MD and displaced hole to Drilplex AR mud. Drilled ahead from conductor to 1463’ MD before packing off. The 2 1 1374Minimum Depth C-5n 0 0 0 0 1342 0.0 C-2 13 10.90 MBT 1463' pH 0.994 55 NA9NA 0 0 Units* Casing Summary Lithology (%) 122 141 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers:A.Charters/C. Murray Set AtSize Grade (current) 0 0 Cly 1315 Volumes Bottoms Up Time -31339 20930307 Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 1 Milled Tooth Siltst ShClyst . . * 24 hr Recap: Lag Correction (bbls) Bottoms Up Strokes 1 Milled Tooth Siltst ShClyst Volumes Bottoms Up Time 223537834140343 Hole Capacity (bbls) Drillstring Capacity (bbls) 0 Cly 4886 Annular Volume (bbls) Size Grade 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers:A.Charters/C. Murray 1432 156 757 179 Units* Casing Summary Lithology (%) MBT 2342' pH 0.994 40 9.010NA 2153 0.0 C-2 29 1465Minimum Depth C-5n 0 0 0 0 Fluids: 0 bbls lost downhole Established circulation and reciprocated pipe. Drilled ahead from 1463’ MD to Surface section TD @ 2342’ MD. 8 2 1463' 2342' 879' Max @ ft Current 1484'48.3 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 218.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 0 (current) 14 Gas Summary in TFABit Type 2200.0010.90 Set At cP 12.5 C-5i AM-AK-902423999 TD'd Surface Section PV - TuffGvlCoal 24 hr Max Weight 7 Hours C-3 (ppb Eq) CementChtSilt C-4i C-4nC-1 YP (lb/100ft2) 00 0 Mud Type Lst Type 9.80 Ss Average NA (max) Trip (max)(current) 12 - DRILPLEX =Background Min Comments Depth in / out 10.0 RPM ECD (ppg) ml/30min Tools GR/RES/PWD/DENS/NEUT API FL Chromatograph (ppm) -114' - WOB 10,000 Units11Connection 0 0 0 0 Continued to troubleshoot rig pumps while cleaning shakers and mud pits and rotating pipe periodically. Condition - Bit # 13.5" Footage 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 2206' Avg to1463' 96% Rig Activity: - Doyon 19 Report For:K. Harding/A. Dorr -- Avg Morning Report Report # 4 Customer: Well: Area: Location: Rig: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine ROP ROP (ft/hr) 4.23 @ Mud Data Depth Chlorides 22-May-2015 12:00 AM Current Pump & Flow Data: 410 Max 100% Gas In Air 1 0 mg/lDepth rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/lDepth 6 0 23-May-2015 12:00 AM Current Pump & Flow Data: 0 Max 100% Gas In Air Mud Data Depth Chlorides ConocoPhillips, Alaska North Slope, AK Alpine ROP ROP (ft/hr) K. Harding/A. Dorr -- Avg Morning Report Report # 5 Customer: Well: Area: Location: Rig: MWD Summary 2342' Avg to- 96% - 4.23 @ 10.00 Size Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 casing. Performed PJSM before beginning to run in with 10 ¾” casing. Circulate and weight up mud to 10.0 ppg before pumping 2x 34bbl nut plug sweeps to gauge hole size. BROOH ConditionBit # 13.5" 10,000 UnitsNAConnection 20 0 0 ml/30min Tools - API FL Chromatograph (ppm) 114' 2342' Min Comments Depth in / out 11.0 RPM ECD (ppg) (current) NA DRILPLEX =Background 35 (max)Trip (max) 10.00 Ss Average 0 Mud Type Lst Type 000 CementChtSilt C-4i C-4nC-1 24 hr Max Weight 15 Hours C-3 (ppb Eq) AM-AK-902423999 Running in 10 3/4" Casing PV 2228' YP (lb/100ft2) WOBFootage cP 0.1 C-5i TuffGvlCoal Gas Summary in TFABit Type 2100.0010.90 Set At (current) 70 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 2342' 2342' 0' Max @ ft Current -- Date: Fluids: 0 bbls lost downhole from 2342’ to 453’ MD and run back in to 545’ to drop gyro. POOH and laid down BHA. Cleaned rig floor and rigged up to run 6 3 Depth C-5n 0 0 0 0 0NA - C-2 35 MBT - pH 0.994 53 9.915NA NA 0 0 Units* Casing Summary Lithology (%) Minimum 1034 29 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers:A.Charters/C. Murray Size Grade 0 Cly 5897 Annular Volume (bbls)Volumes Bottoms Up Time --414 --- Hole Capacity (bbls) Drillstring Capacity (bbls) Lag Correction (bbls) Bottoms Up Strokes 1 Milled Tooth Siltst ShClyst . . * 24 hr Recap: 1 Milled Tooth Siltst ShClystChtSilt 2342' Volumes Bottoms Up Time --414 -- Cly 2645 Annular Volume (bbls) - Hole Capacity (bbls) Drillstring Capacity (bbls) A.Charters/C. Murray GradeType - 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers: Depth Minimum 200 -NA 0 0 Units* Casing Summary Lithology (%) Size MBT - pH 0.994 19 9.715- NA - C-2 16 C-5n - 0 -- 00 Fluids: 0 bbls lost downhole planned landing point @ 2336’ MD. LD 6 joints of casing and re-madeup Hanger and Landing Joint so casing could be landed @ 2 0 2342' 2342' 0' Max @ ft Current -- Date: Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Set At (current) 10 Footage Gas Summary in TFABit Type 2100.0010.90 AM-AK-902423999 Pumping Cement PV 2228' YP 24 hr Max Weight (ppb Eq)cP 16.3 Hours 33.36 (lb/100ft2) TuffGvlCoal Cement C-1 C-3 0 C-4i C-4n C-5i 0 - Mud Type Lst Average 0 (max)Trip (max)(current) 3 60.0 DRILPLEX =Background Min Comments Depth in / out 11.0 RPM ECD (ppg) WOB API FL Chromatograph (ppm) 4.8114' 10.90 Ss - 0 Lag Correction (bbls) Bottoms Up Strokes 0 before pumping a 72 bbl 10.5 ppg Mud Push spacer, dropping the bottom plug, and beginning to pump the 11 ppg cement. was performed before pumping 100 bbl 10 ppg nut plug with rig pumps. Surface Lines were then pressure tested to 3500 PSI 2327’ MD. Circulated and reciprocated while staging pumps to 8 BPM and rigging up cement equipment. PJSM for cement job RIH with 10 ¾” casing to 2329’ MD before taking weight. Pumped up to 6 BPM in an attempt to get casing shoe to Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 2342' Avg to- 96% - 4.23 @ ml/30min K. Harding/A. Dorr -- Avg Morning Report Report # 6 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools - Chlorides 0 0 24-May-2015 12:00 AM Current Pump & Flow Data: 0 Max 100% Gas In Air10,000 UnitsNAConnection16 mg/lDepth 10.90 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/lDepth 10.00 Size 10,000 UnitsNAConnection- 25-May-2015 12:00 AM Current Pump & Flow Data: 0 Max Surface 100% Gas In Air Chlorides -- Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools ml/30min K. Harding/A. Dorr -- Avg Morning Report Report # 7 Customer: Well: Area: Location:Alpine 2327' Avg to- 96% - 4.23 @ Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK black water, Volant was R/D and casing tools were L/D. Serviced top drive, installed RCD element, R/D diverter, and R/B 5” DP. minutes. The well was observed for flow and was static. 165 bbls of cement returned to surface. The riser was then flushed with Pumped 459.8 bbls of 11 ppg cement followed by 60.6 bbls of 15.8 bbls tail cement before chasing with 20 bbls of 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" - 10.00 Ss - - Lag Correction (bbls) Bottoms Up Strokes Min Comments Depth in / out 11.0 RPM ECD (ppg) WOB (current) - 60.0 DRILPLEX BTC-M / H563 =Background - (max)Trip (max) Average Mud Type Lst Chromatograph (ppm) 4.8 - C-4i C-4n C-5i - - TuffGvlCoal Cement C-1 C-3 24 hr Max Weight (ppb Eq)cP 16.3 Hours 33.36 (lb/100ft2) AM-AK-902423999 R/D Diverter PV 2228' YP - Gas Summary in TFABit Type 2100.009.50 Set At (current) - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 2342' 2342' 0' Max @ ft Current -- Date: Fluids: 0 bbls lost downhole 8.3 ppg water and 10 ppg mud with rig pumps. After bumping the top plug, pressure was increased to 900 PSI and held for 5 - - C-5n - - -- --NA - C-2 - - pH 0.994 7 9.118- Footage API FL 114' 0 0 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT Depth Minimum - - 907-670-4347Unit Phone: - C. Murray Maximum Report By:Logging Engineers: NA A.Charters/C. Murray Grade 10 3/4" Type - Cly - Annular Volume (bbls) - Hole Capacity (bbls) Drillstring Capacity (bbls)Volumes Bottoms Up Time --224 -- 1 Milled Tooth Siltst ShClystChtSilt 2342' . . * 24 hr Recap: 1 Milled Tooth Siltst ShClystChtSilt 2342' Volumes Bottoms Up Time --224 -- Cly - Annular Volume (bbls) - Hole Capacity (bbls) Drillstring Capacity (bbls) A.Charters/C. Murray Grade 10 3/4" Type - 907-670-4347Unit Phone: - C. Murray Maximum Report By:Logging Engineers: NA Depth Minimum - - 0 0 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT - pH 0.994 9 9.519- Footage API FL 114' NA - C-2 - C-5n - - -- -- Fluids: 0 bbls lost downhole valves on wellhead. R/U MPD flo-box and trip nipple and fill BOPE. A leak was discovered between the lower rams and mud cross. - - 2342' 2342' 0' Max @ ft Current -- Date: Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Set At (current) - Gas Summary in TFABit Type 2000.009.70 AM-AK-902423999 N/U Flow-Box PV 2228' YP - 24 hr Max Weight (ppb Eq)cP 16.3 Hours 33.36 (lb/100ft2) TuffGvlCoal Cement C-1 C-3 - C-4i C-4n C-5i - - Mud Type Lst Chromatograph (ppm) 4.8 Average - (max)Trip (max)(current) - 60.0 DRILPLEX BTC-M / H563 =Background Min Comments Depth in / out 11.0 RPM ECD (ppg) WOB 10.00 Ss - - Lag Correction (bbls) Bottoms Up Strokes - N/D Trip nipple, flow box, flow line and break flange to inspect. N/U flow-box, flow line, and trip nipple. R/D riser, annular, and starting head and N/U wellhead and BOPE. R/U Choke and kill lines and double annular 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 2327' Avg to- 96% - 4.23 @ ml/30min K. Harding/A. Dorr -- Avg Morning Report Report # 8 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides -- 26-May-2015 12:00 AM Current Pump & Flow Data: 0 Max Surface 100% Gas In Air10,000 UnitsNAConnection- mg/lDepth 10.00 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/lDepth 9.80 Size 10,000 UnitsNAConnection6 27-May-2015 12:00 AM Current Pump & Flow Data: 0 Max Surface 100% Gas In Air Chlorides -- Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools ml/30min K. Harding/A. Dorr -- Avg Morning Report Report # 9 Customer: Well: Area: Location:Alpine 2327' Avg to- 96% - 4.23 @ Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK with 5” DP to 2012’ MD and wash down to 2233’ MD. B/U was circulated and casing testing equipment was rigged up. N/U MPD flo-box, flo-line, and drains. The stack and choke manifold were filled with water with no leaks found. The 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" - 9.80 Ss - - Lag Correction (bbls) Bottoms Up Strokes Min Comments Depth in / out 6.0 RPM ECD (ppg) WOB (current) 2 60.0 DRILPLEX BTC-M / H563 =Background - (max)Trip (max) Average Mud Type Lst Chromatograph (ppm) 4.8 - C-4i C-4n C-5i - - TuffGvlCoal Cement C-1 C-3 24 hr Max Weight (ppb Eq)cP 1.5 Hours 33.36 (lb/100ft2) AM-AK-902423999 Pressure Testing Casing PV 2228' YP - Gas Summary in TFABit Type 800.009.80 Set At (current) - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 2342' 2342' 0' Max @ ft Current -- Date: Fluids: 0 bbls lost downhole BOPE, MPD equipment, and IBOP were all tested. Test equipment was rigged down and BHA #2 was M/U and tripped in hole. RIH 2 1 C-5n - - -- --NA - C-2 6 - pH 0.994 22 4.71458 Footage API FL 114' 0 0 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT Depth Minimum - - 907-670-4347Unit Phone: - C. Murray Maximum Report By:Logging Engineers: NA A.Charters/C. Murray Grade 10 3/4" Type - Cly - Annular Volume (bbls) 158 Hole Capacity (bbls) Drillstring Capacity (bbls)Volumes Bottoms Up Time -33205 15810 1 Milled Tooth Siltst ShClystChtSilt 2342' . . * 24 hr Recap: 1 Milled Tooth 2 PDC Siltst ShClystChtSilt 2342' Volumes Bottoms Up Time 125027622450 Cly 7664 Annular Volume (bbls) 226 Hole Capacity (bbls) Drillstring Capacity (bbls) A.Charters/C. Murray Grade 10 3/4" Type 0 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers: 2487 Depth Minimum 2771 25 808 190 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT 3126' pH 0.994 35 4.61655 Footage API FL 114' 2737 77.5 C-2 81 C-5n 0 16 0 0 087 Fluids: 0 bbls lost downhole displaced to 9.8 ppg LSND mud. The well was observed for flow and was static. A FIT was performed to 14.8 ppg EMW after which 26 2 2342' 3126' 784' Max @ ft Current 2504'44.9 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 133.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Set At (current) 165 Gas Summary in TFABit Type 2800.009.80 - AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT 24 hr Max Weight (ppb Eq)cP 8.8 Hours 33.36 (lb/100ft2) TuffGvlCoal Cement C-1 C-3 0 C-4i C-4n C-5i 20 0 Mud Type Lst Chromatograph (ppm) - 4.8 Average 0 (max) Trip (max)(current) 23 - 60.0 LSND BTC-M / H563 =Background Min Comments 2342' - Depth in / out 9.0 RPM ECD (ppg) WOB 9.80 Ss 0 8 Lag Correction (bbls) Bottoms Up Strokes 1 3126’ MD. the well was again observed for flow and was still static. Drilled ahead to 2448’ MD and opened the underreamer. Drilled ahead to Casing was tested to 2500 PSI for 30 minutes and charted. The shoe track was then drilled out and the well was 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 1.086 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 3061' Avg to2342' 96% - 4.23 @ ml/30min K. Harding/D. Lowe -- Avg Morning Report Report # 10 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides 10 1 28-May-2015 12:00 AM Current Pump & Flow Data: 374 Max Surface 100% Gas In Air10,000 UnitsNAConnectionNA mg/lDepth - 9.80 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 1 Milled Tooth 2 PDC Siltst ShClystChtSilt 2342' Volumes Bottoms Up Time (min) 186937330230 Cly 11743 Annular Volume (bbls) 304 Hole Capacity (bbls) Drillstring Capacity (bbls) A.Charters/C. Murray Grade 10 3/4" Type 48 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers: 3417 Depth Minimum 3407 2923 800 191 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT 4179' pH 0.994 23 4.51248 Footage API FL 114' 3202 83.5 C-2 126 C-5n 19 24 2 0 12133 Fluids: 0 bbls lost downhole 2137’ MD to L/D ghost reamer. RIH to bottom and drill ahead to 4179’ MD. 35 3 3126' 4179' 1053' Max @ ft Current 3131'48.0 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 134.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Set At (current) 182 Gas Summary in TFABit Type 1900.009.80 - AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT 24 hr Max Weight (ppb Eq)cP 13.8 Hours 33.36 (lb/100ft2) TuffGvlCoal Cement C-1 C-3 0 C-4i C-4n C-5i 52 0 Mud Type Lst Chromatograph (ppm) - 4.8 Average 0 (max) Trip (max)(current) 32 - 60.0 LSND BTC-M / H563 =Background Min Comments 2342' - Depth in / out 8.0 RPM ECD (ppg) WOB 9.80 Ss 3 33 Lag Correction (bbls) Bottoms Up Strokes 3 Drilled ahead to 3620’ MD and pumped 34 bbl 11.8 ppg high vis sweep. Observed well for flow (static). Short trip to 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 1.086 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 4010' Avg to3126' 96% - 4.23 @ ml/30min K. Harding/D. Lowe -- Avg Morning Report Report # 11 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides 20 2 29-May-2015 12:00 AM Current Pump & Flow Data: 2601 Max Surface 100% Gas In Air10,000 UnitsNAConnectionNA mg/lDepth - 9.80 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids %mg/lDepth - 9.90 Size 10,000 UnitsNAConnectionNA 30-May-2015 12:00 AM Current Pump & Flow Data: 2602 Max Surface 100% Gas In Air Chlorides 143 21 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools ml/30min K. Harding/D. Lowe -- Avg Morning Report Report # 12 Customer: Well: Area: Location:Alpine 5314' Avg to4179' 96% - 4.23 @ 1.086 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Drilled Ahead from 4179’ MD to 5268’ MD and performed FIT to 12.53 ppg EMW. Drilled Ahead from 5268’ MD to 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 54 9.90 Ss 10 850 Lag Correction (bbls) Bottoms Up Strokes Min Comments 2342' - Depth in / out 11.0 RPM ECD (ppg) WOB (current) 34 - 60.0 LSND BTC-M / H563 =Background 16 (max) Trip (max) Average Mud Type Lst Chromatograph (ppm) - 4.8 13 C-4i C-4n C-5i 289 4 TuffGvlCoal Cement C-1 C-3 24 hr Max Weight (ppb Eq)cP 19.3 Hours 33.36 (lb/100ft2) - AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT Gas Summary in TFABit Type 1500.009.60 Set At (current) 3760 Yesterday's Depth: Current Depth: 24 Hour Progress: 138.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 4179' 5460' 1281' Max @ ft Current 5124'53.8 Date: Fluids: 0 bbls lost downhole 5460’ MD. 77 4 C-5n 21 330 4 3 21419575192 80.8 C-2 1073 5460' pH 0.994 27 4.01344 Footage API FL 114' 795 188 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT Depth Minimum 6177 1670 907-670-4347Unit Phone: 244 C. Murray Maximum Report By:Logging Engineers: 4185 A.Charters/C. Murray Grade 10 3/4" Type 61 Cly 65979 Annular Volume (bbls) 395 Hole Capacity (bbls) Drillstring Capacity (bbls)Volumes Bottoms Up Time (min) 219148639270 1 Milled Tooth 2 PDC Siltst ShClystChtSilt 2342' . . * 24 hr Recap: 1 Milled Tooth 2 PDC Siltst ShClystChtSilt 2342' Volumes Bottoms Up Time (min) 2711762150000 Cly 8191 Annular Volume (bbls) 504 Hole Capacity (bbls) Drillstring Capacity (bbls) A.Charters/C. Murray Grade 10 3/4" Type 13 907-670-4347Unit Phone: 0 C. Murray Maximum Report By:Logging Engineers: 6889 Depth Minimum 4802 1229 795 188 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT 6950' pH 0.994 23 4.41142 Footage API FL 114' 5617 61.0 C-2 97 C-5n 6 5 1 0 032 Fluids: 4 bbls lost downhole 50 3 5460' 6950' 1490' Max @ ft Current 6819'64.1 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 128.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Set At (current) 163 Gas Summary in TFABit Type 1500.009.60 - AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT 24 hr Max Weight (ppb Eq)cP 13.0 Hours 33.36 (lb/100ft2) TuffGvlCoal Cement C-1 C-3 0 C-4i C-4n C-5i 59 0 Mud Type Lst Chromatograph (ppm) - 4.8 Average 0 (max)Trip (max)(current) 49 - 60.0 LSND BTC-M / H563 =Background Min Comments 2342' - Depth in / out 10.0 RPM ECD (ppg) WOB 9.90 Ss 1 8 Lag Correction (bbls) Bottoms Up Strokes 6 Drilled Ahead from 5460’ MD to 6950’ MD. 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 1.086 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 6789' Avg to5460' 96% - 4.23 @ ml/30min K. Harding/D. Lowe -- Avg Morning Report Report # 13 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides 20 3 31-May-2015 12:00 AM Current Pump & Flow Data: 2655 Max Surface 100% Gas In Air10,000 UnitsNAConnectionNA mg/lDepth - 9.90 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 1 Milled Tooth 2 PDC Siltst ShClystChtSilt 2342' Volumes Bottoms Up Time (min) 3013671457300 Cly 7026 Annular Volume (bbls) 578 Hole Capacity (bbls) Drillstring Capacity (bbls) A.Charters/S.Tiger Grade 10 3/4" Type 47 907-670-4347Unit Phone: 0 S.Tiger Maximum Report By:Logging Engineers: 7925 Depth Minimum 4392 2604 795 188 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT 6950' pH 0.994 24 4.3940 Footage API FL 114' 7190 C-2 73 C-5n 35 5 5 0 039 Fluids: 0 bbls lost downhole 46 10 6950' 7983' 1033' Max @ ft Current 7954' Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 86.0 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Set At (current) 91 Gas Summary in TFABit Type 1000.009.90 - AM-AK-902423999 Circulate PV 2228' YP GR/RES/PWD/DENS/NEUT 24 hr Max Weight (ppb Eq)cP 13.8 Hours 33.36 (lb/100ft2) TuffGvlCoal Cement C-1 C-3 0 C-4i C-4n C-5i 66 0 Mud Type Lst Chromatograph (ppm) - 4.8 Average 0 (max) Trip (max)(current) 20 - 60.0 LSND BTC-M / H563 =Background Min Comments 2342' - Depth in / out 10.5 RPM ECD (ppg) WOB 10.00 Ss 10 7 Lag Correction (bbls) Bottoms Up Strokes 10 Drilled Ahead from 5950' MD to 7983' MD and currently circulate and conditioning mud. 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 1.086 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine 7983' Avg to5460' 96% - 4.23 @ ml/30min K. Harding/D. Lowe -- Avg Morning Report Report # 14 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides 41 5 1-Jun-2015 12:00 AM Current Pump & Flow Data: 2655 Max Surface 100% Gas In Air10,000 UnitsNAConnectionNA mg/lDepth - 9.90 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: % 9.90 Size rig Density (ppg) out (sec/qt) Viscosity Cor Solids Depth 10,000 UnitsNAConnectionNA 2-Jun-2015 12:00 AM Current Pump & Flow Data: 2655 Max Surface 100% Gas In Air mg/l Chlorides 41 5 ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools D. Bjorhus/D. Lowe -- Avg Morning Report Report # 15 Customer: Well: Area: Location: Rig: 7983' Avg to5460' 96% - 4.23 @ ml/30min Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Alpine Test BOP, TIH from 696' to 2295', cut and slip drill line, lubricate rig and service top drive. 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 1.086 10 9.90 Ss 10 7 Lag Correction (bbls) Bottoms Up Strokes - Min Comments 2342' - Depth in / out 11.0 RPM ECD (ppg) WOB 20 - 60.0 LSND BTC-M / H563 =Background 0 Trip Average Mud Type Lst Chromatograph (ppm) - 4.8 0 C-4i C-4n C-5i 66 0 TuffGvlCoal Cement C-1 C-3 24 hr Max Weight (ppb Eq)cP 14.0 Hours 33.36 (lb/100ft2) - AM-AK-902423999 TIH PV 2228' YP GR/RES/PWD/DENS/NEUT Gas Summary in TFABit Type 1000.009.60 (current) 91 Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 7983' 7983' 0' Max @ ft Current Date: Fluids: 0 bbls lost downhole 46 10 C-5n 35 5 5 0 0397190 C-2 73 6950' pH 0.994 18 5.2940 Footage API FL 114' 795 188 Units* Casing Summary Lithology (%) Size 45.5#L80 MBT Minimum 4392 2604 907-670-4347Unit Phone: 0 S.Tiger Maximum Report By:Logging Engineers: 7925 A.Charters/S.Tiger Grade 10 3/4" Type 47 7026 Annular Volume (bbls) 578 Hole Capacity (bbls) Drillstring Capacity (bbls) Depth Volumes Bottoms Up Time (min) 3013671457300 ShClystChtSilt 2342' 2342' 1 Milled Tooth 2 PDC Siltst Cly Set At 7983' 5641'24 172 2-4-BT-A-X-I-CT-DTF2PDC9.875 1.086 84.57 . . * 24 hr Recap: 172 2-4-BT-A-X-I-CT-DTF2PDC9.875 1.086 84.57 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' mg/lDepth - 9.80 Size 10,000 UnitsNAConnection464' 3-Jun-2015 12:00 AM Current Pump & Flow Data: 461 Max Surface 100% Gas In Air Chlorides 94 14 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools ml/30min R. Bjorhus/D. Lowe 10.4310.53 AvgECD (ppg) 24 hr Max 129.0 Flow In (gpm) Morning Report Report # 16 Customer: Well: Area: Location:Alpine Yesterday's Depth: Current Depth: 24 Hour Progress: 9078' Avg to6950' 96% 10.63 4.23 @ Min 0.049 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Drilled ahead from 7983' MD to 9315' MD. 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 32 10.10 Ss 16 142 Lag Correction (bbls) Bottoms Up Strokes Comments 2342' - Depth in / out 11.0 RPMWOB 2342' 5641' 54 - 60.0 LSND BTC-M / H563 =Background 0 Trip Average Mud Type Lst Chromatograph (ppm) - 4.8 3 C-4i C-4n C-5i 123 0 Cement C-1 C-3 cP 13.8 Hours 33.36 (lb/100ft2) - 24 AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT Set At in TFABit Type 600.009.70 Weight (ppb Eq) 343 C-5n Gas Summary TuffGvlCoal Time: SPP (psi) Gallons/stroke 7983' 9315' 1332' Max @ ft Current 8423'102.0 Date: 801 191 Flow In (spm) Fluids: 0 bbls lost downhole 43 22 43 55 7 0 293168467 90.0 C-2 104' 7948' pH 0.994 29 4.11039 Footage API FL 114' Casing Summary Lithology (%) Size 45.5# Type (current) L80 MBT Depth Minimum Grade 10 3/4" 5546 2083 57 907-670-4347Unit Phone: 34 S.Tiger Maximum Report By:Logging Engineers: 8042 A.Charters/S.Tiger Cly 11349 Annular Volume (bbls) 615.66 Hole Capacity (bbls) Drillstring Capacity (bbls) Units* Volumes Bottoms Up Time (min) 42141.79757 799795 1 Milled Tooth 3 PDC Siltst ShClystChtSilt 2342' . . * 24 hr Recap: 1 Milled Tooth 3 PDC Siltst ShClystChtSilt 2342' Bottoms Up Time (min) 47175.7972.42 870795780.15 Hole Capacity (bbls) Drillstring Capacity (bbls) Units* Volumes 907-670-4347Unit Phone: 135 S.Tiger Maximum Report By:Logging Engineers: 10170 A.Charters/S.Tiger 10433 1201 160 L80 MBT Depth Minimum GradeSize 45.5# Type 10 3/4" pH 0.994 29 3.21140 Footage API FL 114' cP 94.0 C-2 616 7948' Casing Summary Lithology (%) 47 1462588967356098 6239254 374 48 2839 183 Flow In (spm) Fluids: 0 bbls lost downhole ppg. 123 10226' 911' Max @ ft Current 9459'98.0 Date: Time: SPP (psi) Gallons/stroke 778 Gas Summary TuffGvlCoal Cement (current) Annular Volume (bbls) in TFABit Type 1000.009.70 Weight (ppb Eq) AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT Set At 12.5 Hours 33.36 (lb/100ft2) - 24 C-1 C-3 C-5n Cly 46 C-4i C-4n C-5i 628 Mud Type Lst Chromatograph (ppm) - 4.8 Average 55 Trip136 - 60.0 LSND BTC-M / H563 =Background Comments 2342' - Depth in / out 13.5 RPMWOB 2342' 5641' 10.90 Ss 166 667 Lag Correction (bbls) Bottoms Up Strokes 32 Drilled ahead from 9315' MD to 10226' MD, Rig up and perform FIT to 12.5 ppg for 5 minutes, weight up mud to 10.8 . 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 0.049 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK 10085' Avg to6950' 96% 11.5 4.23 @ Min Morning Report Report # 17 Customer: Well: Area: Location:Alpine Yesterday's Depth: Current Depth: 24 Hour Progress: 9315' Tools ml/30min R. Bjorhus/D. Lowe 10.5811.04 AvgECD (ppg) 24 hr Max 126.0 Flow In (gpm) 75 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Chlorides 533 4-Jun-2015 12:00 AM Current Pump & Flow Data: 3255 Max Surface 100% Gas In Air Size 10,000 Units149ConnectionN/A mg/lDepth - 10.80 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983'172 2-4-BT-A-X-I-CT-DTF2PDC9.875 1.086 84.57 . . * 24 hr Recap: 1 Milled Tooth 3 PDC Siltst ShClystChtSilt 2342' Bottoms Up Time (min) 521961065958495869 Hole Capacity (bbls) Drillstring Capacity (bbls) Units* Volumes 907-670-4347Unit Phone: 105 S.Tiger Maximum Report By:Logging Engineers: 11154 A.Charters/S.Tiger 11329 6243 465 L80 MBT Depth Minimum GradeSize 45.5# Type 10 3/4" pH 0.994 29 3.21239 Footage API FL 114' cP 45.0 C-2 537 11387' Casing Summary Lithology (%) 47 11618131070843637 6486483 216 91 2932 186 Flow In (spm) Fluids: 0 bbls lost downhole 132 11387' 1161' Max @ ft Current 10588'76.0 Date: Time: SPP (psi) Gallons/stroke 787 Gas Summary TuffGvlCoal Cement (current) Annular Volume (bbls) in TFABit Type 800.009.70 Weight (ppb Eq) AM-AK-902423999 Drilling Ahead PV 2228' YP GR/RES/PWD/DENS/NEUT Set At 18.8 Hours 33.36 (lb/100ft2) - 24 C-1 C-3 C-5n Cly 74 C-4i C-4n C-5i 868 Mud Type Lst Chromatograph (ppm) - 4.8 Average 57 Trip81 - 60.0 LSND BTC-M / H563 =Background Comments 2342' - Depth in / out 14.0 RPMWOB 2342' 5641' 10.90 Ss 189 492 Lag Correction (bbls) Bottoms Up Strokes 239 Drilled ahead from 10226' MD to11387' MD, changed out gear oil pump, coupler and filter on mud pump 2 . 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 0.049 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK 11255' Avg to10266' 96% 11.7 4.23 @ Min Morning Report Report # 18 Customer: Well: Area: Location:Alpine Yesterday's Depth: Current Depth: 24 Hour Progress: 10226' Tools ml/30min R. Bjorhus/D. Lowe 10.5611.63 AvgECD (ppg) 24 hr Max 117.0 Flow In (gpm) 120 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Chlorides 748 5-Jun-2015 12:00 AM Current Pump & Flow Data: 3536 Max Surface 100% Gas In Air Size 10,000 Units149ConnectionN/A mg/lDepth - 10.80 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983'172 2-4-BT-A-X-I-CT-DTF2PDC9.875 1.086 84.57 . . * 24 hr Recap: 1 Milled Tooth 3 PDC Siltst ShClystChtSilt 2342' Bottoms Up Time (min) 562041109992795905 Hole Capacity (bbls) Drillstring Capacity (bbls) Units* Volumes 907-670-4347Unit Phone: 1683 S.Tiger Maximum Report By:Logging Engineers: 11406 A.Charters/S.Tiger 64 155 16401 4653 327 Set At L80 MBT Depth Minimum Grade API FL 114' cP Size 45.5# Type 10 3/4" 0.994 22 3.31238 Footage - C-2 2729 11853' Casing Summary Lithology (%) 50 17081626310708105033 45351 2643 59 13982 176 Flow In (spm) Chromatograph (ppm) - 4.8 Fluids: 0 bbls lost downhole 292 11805' 418' Max @ ft Current 11624'49.0 Date: Time: SPP (psi) Gallons/stroke 744 Gas Summary TuffGvlCoal Cement (current) Annular Volume (bbls) in TFABit Type 1000.009.60 Weight (ppb Eq) AM-AK-902423999 Circulate PV 2228' YP GR/RES/PWD/DENS/NEUT 16.3 Hours 33.36 (lb/100ft2) - 24 C-1 C-3 C-5n Cly 287 C-4i C-4n C-5i 1902 Mud Type Lst Average 295 Trip - 60.0 LSND BTC-M / H563 =Background Comments 2342' - Depth in / out 15.0 RPMWOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF 10.80 Ss 155 6291 Lag Correction (bbls) Bottoms Up Strokes 1011 Drilled ahead from 11387' MD to TD intermediate section at 11853' MD, 7477' TVD and circulate until 12 bottoms up. 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 0.049 Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Current Depth: 24 Hour Progress: 11387' 11853' Avg to11387' 96% 11.61 24 hr Max 113.0 Flow In (gpm) Morning Report Report # 19 Customer: Well: Area: Location:Alpine Yesterday's Depth: ml/30min R. Bjorhus/D. Lowe 11.4811.55 AvgECD (ppg) 4.23 @ Min pH Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides 2182 377 5-Jun-2015 12:00 AM Current Pump & Flow Data: 3324 Max Surface 100% Gas In Air1581ConnectionN/A mg/lDepth - 10.80 Size Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983'2 PDC 9.875 1.086 84.57 rig 10,000 Units . . * 24 hr Recap: 2 PDC 9.875 1.086 84.57 rig 10,000 Units Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' mg/lDepth - 11.10 Size N/AConnectionN/A 7-Jun-2015 12:00 AM Current Pump & Flow Data: 645 Max Surface 100% Gas In Air Chlorides 260 52 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools ml/30min R. Bjorhus/D. Lowe -- AvgECD (ppg) 4.23 @ Min pH 24 hr Max - Flow In (gpm) Morning Report Report # 20 Customer: Well: Area: Location:Alpine Yesterday's Depth: Current Depth: 24 Hour Progress: 11387' 11853' Avg to11387' 96% - Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Continued to circulate and condition 12 bottoms up, weight up from 10.8 ppg to 11.1ppg weight up again from 11.1 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" -9.875 0.049 152 11.10 Ss 44 347 Lag Correction (bbls) Bottoms Up Strokes - Depth in / out 14.0 RPMWOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF - 60.0 LSND BTC-M / H563 =Background Comments 2342' Trip Average 94 C-5i 242 Mud Type Lst C-5n Cly 71 C-4i C-4n (lb/100ft2) - 24 C-1 C-3 AM-AK-902423999 POOH PV 2228' YP GR/RES/PWD/DENS/NEUT 16.3 Hours in TFABit Type 1000.009.90 Weight (ppb Eq) Gas Summary TuffGvlCoal Cement (current) Annular Volume (bbls) Time: SPP (psi) Gallons/stroke 228 11387' 0' Max @ ft Current -- Date: Fluids: 0 bbls lost downhole to 11.4. POOH from 11853' MD to 11620' MD, pull tight. Cut mud weight from 11.4 to 11.1 ppg, continue to POOH. 93 110 17 516 53 Flow In (spm) Chromatograph (ppm) - 4.8 18 177549-6397 2374 - C-2 174 11853' Casing Summary Lithology (%) 0.994 28 2.91340 Footage 33.36 API FL 114' cP Size 45.5# Type 10 3/4" Set At L80 MBT Depth Minimum Grade 3900 1021 66 Maximum Report By:Logging Engineers: - A.Charters/S.Tiger 24 5 Units* Volumes 907-670-4347Unit Phone: 224 S.Tiger Bottoms Up Time (min) 562041109992795905 Hole Capacity (bbls) Drillstring Capacity (bbls) 1 Milled Tooth 3 PDC Siltst ShClystChtSilt 2342' . . * 24 hr Recap: 11853' 3870'15 162 1-1-ER-A-X-I-CT-TD3PDC9.875 0.049 55.14 7983' 1 Milled Tooth 4 Siltst ShClystChtSilt 2342' Bottoms Up Time (min) 562041109992795905 Hole Capacity (bbls) Drillstring Capacity (bbls) Units* Volumes 907-670-4347Unit Phone: 0 S.Tiger Maximum Report By:Logging Engineers: - A.Charters/S.Tiger 3 3 147 118 9 Set At L80 MBT Depth Minimum Grade API FL 114' cP Size 45.5# Type 10 3/4" 0.994 25 3.21142 Footage 33.36 - C-2 8 11853' Casing Summary Lithology (%) 0 015-177 011 3 0 14 - Flow In (spm) Chromatograph (ppm) 4.8 Fluids: 0 bbls lost downhole Max gas of 8 units was noted while running casing and was pumped on for about 15 minutes. 5 11387' 0' Max @ ft Current -- Date: Time: SPP (psi) Gallons/stroke - Gas Summary TuffGvlCoal Cement (current) Annular Volume (bbls) in TFABit Type 1000.009.80 Weight (ppb Eq) AM-AK-902423999 Run in Casing PV 2228' YP GR/RES/PWD/DENS/NEUT 16.3 Hours (lb/100ft2) 24 C-1 C-3 C-5n Cly 0 C-4i C-4n C-5i 12 Mud Type Lst Average 0 (max) Trip (max)(current) 60.0 LSND BTC-M / H563 =Background Comments Depth in / out 14.0 RPMWOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF 11.10 Ss 7 10 Lag Correction (bbls) Bottoms Up Strokes 11 POOH, lay down BHA and run in with 7 5/8" casing. Monitoring gas and pit volumes. 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Current Depth: 24 Hour Progress: 11387' 11853' Avg to11387' 96% - 24 hr Max - Flow In (gpm) Morning Report Report # 21 Customer: Well: Area: Location:Alpine Yesterday's Depth: ml/30min R. Bjorhus/D. Lowe -- AvgECD (ppg) 4.23 @ Min pH Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary Tools Chlorides 17 4 8-Jun-2015 12:00 AM Current Pump & Flow Data: - Max Surface 100% Gas In AirN/AConnectionN/A mg/lDepth 11.10 Size Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983'2 PDC 9.875 1.086 84.57 rig 10,000 Units . . * 24 hr Recap: rig 10,000 Units Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' Depth 2 ConnectionN/A mg/l 11.10 Size PDC 100% Gas In AirN/A 9-Jun-2015 12:00 AM Current Pump & Flow Data: - Max Surface ChloridespH -- 52 11 23 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary D. Lutrick/ A. Dorr AvgECD (ppg) 4.23 @ MinTools 24 hr Max - Flow In (gpm) Morning Report Report # 22 Customer: Well: Area: Location:Alpine Yesterday's Depth: Current Depth: 24 Hour Progress: 11853' 11853' Avg to11387' 96% - Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK (max) Continue to run in with 7 5/8" casing 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5"60.0 11.10 Ss 3 75 Lag Correction (bbls) Bottoms Up Strokes 0 14.0 RPMWOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF ml/30min (current) LSND BTC-M / H563 =Background Comments Trip (max) 7 Cly Average Lst Depth in / out 9.875 C-4i C-4n C-5i 21253 C-1 C-3 C-5n 1-1-ER-A-X-I-CT-TD AM-AK-902423999 Run in Casing PV 2228' YP 15 162 16.3 Hours 1000.009.80 Weight GvlCoal Cement (current) Annular Volume (bbls) Time: SPP (psi) Gallons/stroke - 11853' 0' Max @ ft Current -- Date: 0 Fluids: 0 bbls lost downhole Continue to monitor gas and pit volumes. 40 - Flow In (spm) Chromatograph (ppm) 4.8 Gas Summary Tuff -16221 040 424131 3.01246 Footage 33.36 24 - 11853' in TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT 10 3/4" 28 L80 MBT Size 7983' 11853' 3870' (lb/100ft2) 45.5# Depth 992795905 C-2 38 Grade API FL Maximum Units* 0.994 5756 76 0 62 Report By:Logging Engineers: - C. Murray/S.Tiger 3 70 Minimum Volumes 907-670-4347Unit Phone: 20 S.Tiger 562041109 ShClystChtSilt 2342' Bottoms Up Time (min) Hole Capacity (bbls) Drillstring Capacity (bbls) Set At 4 Siltst 114' Casing Summary Lithology (%) 3 Type PDC 9.875 0.049 55.14 1 Milled Tooth 1.086 84.57 . . * 24 hr Recap: 1 Milled Tooth 1.086 84.57 4 Siltst 114' Casing Summary Lithology (%) 11837' MD 3 7 5/8" Type Silt 2342' Bottoms Up Time (min) Hole Capacity (bbls) Drillstring Capacity (bbls) Set At PDC 9.875 0.049 907-670-4347Unit Phone: 133 S.Tiger 562041109 Report By:Logging Engineers: - C. Murray/S.Tiger 6 70 Minimum 22552 96 8 565 Grade API FL Maximum Units* 0.994 Depth 992795905 C-2 478 MBT Size 7983' 11853' 3870' (lb/100ft2) 55.14 - - in TFABit Type cPMud Type (ppb Eq) 1278 2.91241 Footage 33.36 24 0124 5764 4.8 Gas Summary Tuff 10 3/4"L8045.5# Volumes Fluids: 0 bbls lost downhole Continue to monitor gas and pit volumes, max gas of 1278 units occurred while circulating and conditioning mud. 179 11853' 0' Max @ ft Current -- Date: - Time: SPP (psi) Gallons/stroke - 0 Flow In (spm) Chromatograph (ppm) (current) Annular Volume (bbls) - L-8029.7# Weight GvlCoal CementShClyst 15 162 17.5 Hours 1000.009.5020 1-1-ER-A-X-I-CT-TD AM-AK-902423999 Cement Casing PV 2228' YP C-1 C-3 C-5nC-4i C-4n C-5i 1803746102268 Depth in / out 9.875 BTC-M / H563 Cht Cly Average Lst Trip (max) 20 (current) LSND BTC-M / H563 =Background Comments 19 16.0 RPMWOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF ml/30min 60.0 11.10 Ss Intermediate 8 483 Lag Correction (bbls) Bottoms Up Strokes (max) Continue to run in and land 7 5/8" casing at 11837' MD. Circulate and condition mud. Rig up cement line 2327' MD Condition 1-1-WT-A-E-I-NOTD Bit # 13.5" Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: CD5-04 ConocoPhillips, Alaska North Slope, AK Current Depth: 24 Hour Progress: 11853' 11853' Avg to- 96% - 24 hr Max - Flow In (gpm) Morning Report Report # 23 Customer: Well: Area: Location:Alpine Yesterday's Depth: AvgECD (ppg) 4.23 @ MinTools Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary D. Lutrick/ A. Dorr 287 39 77 10-Jun-2015 12:00 AM Current Pump & Flow Data: - Max Surface ChloridespH -- mg/l 11.10 Size PDC 100% Gas In AirN/A Depth 2 ConnectionN/A Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units . . * 24 hr Recap: rig 10,000 Units Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' Depth 2 ConnectionN/A 11.10 Size PDC 100% Gas In AirN/A 12:00 AM Current Pump & Flow Data: - Max Surface ChloridespH -- mg/l 15 4 14 Rig: ROP ROP (ft/hr) Mud Data DepthMWD Summary D. Lutrick/ A. Dorr AvgECD (ppg) 4.23 @ MinTools Morning Report Report # 24 Customer: Well: Area: Location:Alpine Yesterday's Depth: 11-Jun-2015 11853' Avg to- 96% - 24 hr Max - Flow In (gpm) CD5-04 ConocoPhillips, Alaska North Slope, AK Current Depth: 24 Hour Progress: 11853' Bit # 13.5" Job No.: Daily Charges: Total Charges: Rig Activity: Doyon 19 Report For: Continue to monitor gas, pit volumes and calibrate gas equipment. (max) Performed 2nd stage cement. Set pack off and test to 5000psi for 10 min. Laid down 5" DP. Rigged and test 11.10 Ss Intermediate 3 80 Lag Correction (bbls) Bottoms Up Strokes 2327' MD 0 14.0 RPMWOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF ml/30min (current) LSND BTC-M / H563 =Background Comments Trip (max) 5 Cht Cly Average 2279 Depth in / out 9.875 C-1 C-3 C-5n AM-AK-902423999 Test BOP PV 2228' YP BTC-M / H563 162 17.5 Hours 1000.009.5028 1-1-ER-A-X-I-CT-TD 60.0 Condition 1-1-WT-A-E-I-NOTD L-8029.7# Weight GvlCoal CementShClystLst - C-4i C-4n C-5i Time: SPP (psi) Gallons/stroke - 0 Flow In (spm) Chromatograph (ppm) 11853' 0' Max @ ft Current -- Date: - Fluids: 0 bbls lost downhole BOPE. 10 Gas Summary Tuff 10 3/4"L8045.5# Volumes (current) Annular Volume (bbls) 030 118 2813830 3.6751 Footage 33.36 24 - - in TFABit Type cPMud Type (ppb Eq) MBT Size 7983' 11853' 3870' (lb/100ft2) 55.14 4.8 15 Depth 992795905 C-2 28 Grade API FL Maximum Units* 0.994 Minimum 145 28 0 8 - C. Murray/S.Tiger 3 3 907-670-4347Unit Phone: 28 S.Tiger 562041109 Report By:Logging Engineers: Bottoms Up Time (min) Hole Capacity (bbls) Drillstring Capacity (bbls) Set At PDC 9.875 0.049 Siltst 114' Casing Summary Lithology (%) 11837' MD 3 7 5/8" Type Silt 2342' 1 Milled Tooth 1.086 84.57 4 . . * 24 hr Recap: 4 PDC PDC 11837' MD 3 7 5/8" Type Silt 2342' 1 Milled Tooth 1.086 84.57 Bottoms Up Time (min) Hole Capacity (bbls) Drillstring Capacity (bbls) Set At PDC 9.875 0.049 907-670-4347Unit Phone: 0 S.Tiger 3475.43545 Report By:Logging Engineers: - C. Murray/S.Tiger 3 4 Minimum 91 13 0 16 Grade API FL Maximum Units* 0.994 Depth 17360365.18 C-2 7 Size 7983' 11853' 3870' (lb/100ft2) 55.14 4.8 15 114' TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT 6 3.8754 Footage 33.36 24 0 18 531 10 3/4"L8045.5# Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) Fluids: 0 bbls lost downhole minutes. Began drilling out cement. 5 11853' 0' Max @ ft Current -- Date: 49 Time: SPP (psi) Gallons/stroke 207 0 Flow In (spm) Chromatograph (ppm) - C-4i C-4n C-5i Weight GvlCoal CementShClystLst Surface Tuff 162 17.5 Hours 1000.009.6028 1-1-ER-A-X-I-CT-TD 60.0 Condition 1-1-WT-A-E-I-NOTD AM-AK-902423999 Drill Out Cement Stage PV 2228' YP 9.875 6.75 0.383 C-1 C-3 C-5n BTC-M / H563 L-8029.7# Trip 114 Gas Summary 04 11853' Average (max) LSND BTC-M / H563 =Background Comments WOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF Cht Cly ml/30min Depth in / out Ss Intermediate 4 18 Lag Correction (bbls) Bottoms Up Strokes North Slope, AK Monitoring gas and pit volumes. (max) Test BOPE. Made up BHA. RIH with 4" DP to 1504 for shallow test. RIH to 5606' to test casing to 1000psi for 10 (current) 11853' Job No.: Daily Charges: Total Charges: Rig Activity: Report For: 2327' MD 5 14.0 96% - 24 hr Max - Flow In (gpm) Avg - - Alpine Yesterday's Depth: 12-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: 24 Hour Progress: 11853' Doyon 19Rig: ROP ROP (ft/hr) 12:00 AM Morning Report Report # 25 Customer: Well: Area: Location: R. Bjorhus/ A. Dorr Current Pump & Flow Data: 308 Max Chlorides ECD (ppg) 4.23 @ MinTools Mud Data DepthMWD Summary to11853' Bit # 13.5" 29 6 18 3 pH -- mg/l 11.10 Size 11.10 RPM in 100% Gas In AirN/A Depth 2 ConnectionN/A Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units . . * 24 hr Recap: rig 10,000 Units Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983'2 Connection927 100% Gas In AirN/A -- mg/l 11.10 Size 11.10 RPM in 87 15 43 17 pH MWD Summary to11853' Bit # 13.5" Depth R. Bjorhus/ A. Dorr Current Pump & Flow Data: - Max Chlorides ECD (ppg) 4.23 @ MinTools Rig: ROP ROP (ft/hr) 12:00 AM Morning Report Report # 26 Customer: Well: Area: Location:Alpine Yesterday's Depth: 13-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: 24 Hour Progress: 11853' Doyon 19 96% - 24 hr Max 84.0 Flow In (gpm) Avg - 11873' 11853' Job No.: Daily Charges: Total Charges: Rig Activity: Report For: 2327' MD 21 14.0 North Slope, AK Displace well to 10.2 ppg. Flow check well . (max) Wash and ream out stage collar. RIH with 4" DP to 11583' MD. Test casing to 3500psi for 30 minutes. (current) Cht Cly ml/30min Depth in / out Ss Intermediate 8 2087 Lag Correction (bbls) WOB 2342' 5641'172 2-4-BT-A-X-I-CT-DTF Bottoms Up Strokes (max) LSND BTC-M / H563 =Background Comments Average Trip 63770 Gas Summary 010 C-5n BTC-M / H563 L-8029.7# 11853'0.383 C-1 C-3 60.0 Condition 1-1-WT-A-E-I-NOTD AM-AK-902423999 Flow check well PV 2228' YP Surface Tuff 162 17.5 Hours 1000.0010.8027 1-1-ER-A-X-I-CT-TD GvlCoal CementShClystLst 11873 C-4i C-4n C-5i Time: SPP (psi) Gallons/stroke - 0 Flow In (spm) Chromatograph (ppm) 11873' 20' Max @ ft Current 11858'67.0 Date: - Fluids: 0 bbls lost downhole Wash and ream from 11583' MD to 11698' MD. Drill out shoe track to 11853' MD. Drill 20' of new hole to 11873' MD 13 L8045.5# Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) Weight 0 7438 4177214927 3.91654 Footage 33.36 24 TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data Depth 3870' (lb/100ft2) 55.14 4.8 15 114' Depth 35790365 C-2 955 Grade API FL Maximum Units* 0.994 Minimum 499 43 5 82 - C. Murray/S.Tiger 3 6 907-670-4347Unit Phone: 371 S.Tiger -75546 Report By:Logging Engineers: Bottoms Up Time (min) Hole Capacity (bbls) Drillstring Capacity (bbls) Set At PDC 9.875 0.049 Silt 2342' 1 Milled Tooth 1.086 84.57 Size 7983' 11853' 10 3/4" 4 PDC PDC 11837' MD 3 7 5/8" Type 9.875 6.75 . . * 24 hr Recap: 4 PDC - PDC 11837' MD 3 7 5/8" Type 9.875 6.75 Silt 2342' 1 Milled Tooth 1.086 84.57 Size 7983' 11853' Hole Capacity (bbls) Drillstring Capacity (bbls) Set At PDC 9.875 0.049 10 3/4" 907-670-4347Unit Phone: 3240 D. Durst 66143620 Report By:Logging Engineers: 12125 C. Murray / D. Durst 14 8747 Minimum 249148 1216 146 35766 Grade API FL Maximum Units* 0.994 Depth 40130404 C-2 6627 (lb/100ft2) 55.14 - 4.8 15 114' TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data Depth 9899 3.51752 Footage 33.36 - 24 - 23 52148 341751467 L8045.5# Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) W eight Fluids: 0 bbls lost downhole 5788 13536' 1663' Max @ ft Current 13158'118.0 Date: 59 Time: SPP (psi) Gallons/stroke 250 27 Flow In (spm) Chromatograph (ppm) 12435 C-4i C-4n C-5i GvlCoal CementShClystLst 162 2.5 Hours 145,0009.5024 1-1-ER-A-X-I-CT-TD3870' 60.0 Condition 1-1-WT-A-E-I-NOTD AM-AK-902423999 Drilling Ahead PV 2228' YP C-1 C-3 5% Bottoms Up Time (min) - BTC-M / H563 L-8029.7# 11853'-0.383 Trip 365366 95% Gas Summary 46160 Average (max) LSND BTC-M / H563 =Background Comments 2342' 5641'172 2-4-BT-A-X-I-CT-DTF Bottoms Up Strokes Surface TuffSs Intermediate 91 15114 Lag Correction (bbls) C-5n (max) Perform FIT to 12.8 ppg. Wash and ream to 11837' MD. Drill from 11873' to 13482' MD, 7395' TVD. (current) Job No.: Daily Charges: Total Charges: Rig Activity: Report For: 2327' MD 3509 13.0 North Slope, AK 96% 11.88 24 hr Max 476.0 Flow In (gpm) Avg 117.0 13536' Alpine Yesterday's Depth: 14-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: 24 Hour Progress: 11873' Doyon 19Rig: ROP ROP (ft/hr) 12:00 AM Morning Report Report # 27 Customer: Well: Area: Location: R. Bjorhus/ A. Dorr Current Pump & Flow Data: 2722 Max Chlorides ECD (ppg) 4.23 @ MinToolsMWD Summary to11873' Bit # 13.5" Depth 5722 13714 3545 pH Cht Cly ml/30min Depth in / out 11.1011.55 mg/l 10.20 Size 10.20 RPM in WOB 100% Gas In Air- 2 Connection- 54365 Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units . . * 24 hr Recap: 11853' 4 PDC - PDC 11837' MD 3 7 5/8" Type 9.875 1 Milled Tooth 1.086 84.57 Size 7983' 6.75 Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt Unit Phone: 8591 D. Durst 76165709 Report By:Logging Engineers:C. Murray / D. Durst 96 7880 907-670-4347 Minimum 401714 3281 409 55397 Grade API FL Maximum Units* 0.994 Depth 45830462 C-2 12889 (lb/100ft2) 55.14 - 4.8 15 114' - 2342' 5641' 2342' TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data Depth 8846 3.91552 Footage 33.36 - 24 - 875287374 507 312 31585 Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) Weight Hole Capacity (bbls) Drillstring Capacity (bbls) Fluids: 0 bbls lost downhole 7010 15552' 2016' Max @ ft Current 14404'116.0 Date: 60 Time: SPP (psi) Gallons/stroke 254 119 Flow In (spm) Chromatograph (ppm) 13560 C-4i C-4n C-5i 73390 Condition GvlCoal CementShClystLst L8045.5# 24 Hour Progress: 13536' 162 3.8 Hours 105,0009.3029 1-1-ER-A-X-I-CT-TD3870' Bottoms Up Time (min) 1-1-WT-A-E-I-NOTD AM-AK-902423999 Drilling Ahead PV 2228' 197 BTC-M / H563 L-8029.7# 11853'- C-1 C-3 494727 95% Gas Summary 5% Trip =Background Comments Average 2-4-BT-A-X-I-CT-DTF Bottoms Up Strokes Surface Tuff Intermediate Lag Correction (bbls) BTC-M / H563 C-5n (max) to13536' (max) Rotary drilling from 13482' MD to 15550' MD, 7464' TVD. (current) 7263 14.0 North Slope, AK 96% - 24 hr Max 142.0 Flow In (gpm) Avg 15552' Alpine Yesterday's Depth: 15-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Morning Report Report # 28 Customer: Well: Area: Location: 127.0 Daily Charges: Total Charges: Rig Activity: Report For: @ MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary 22193 R. Bjorhus/ A. Dorr Current Pump & Flow Data: 2967 Max Chlorides ECD (ppg) 4.23 Bit # 13.5" Depth 15273' 2327' MD FLOPRO NT pH Cht Cly ml/30min Depth in / out 2 172 YP 60.0 -- mg/l 10.30 Size 10.30 RPM in WOB 100% Gas In Air- 6336 Connection- 9142 8714701 119165 Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units . . * 24 hr Recap: % 7983' rig 10,000 Units 46409 Density (ppg) out (sec/qt) Viscosity Cor Solids - 7211 016623 100% Gas In Air- 5378 11.9512.09 mg/l 10.30 Size 10.30 RPM in WOB pH Cht Cly ml/30min Depth in / out 2 172 YP 60.0 Bit # 13.5" Depth 17607' 2327' MD FLOPRO NT K. Harding/ A. Dorr Current Pump & Flow Data: 3249 Max Chlorides ECD (ppg) 4.23 @ MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary Morning Report Report # 29 Customer: Well: Area: Location: 129.0 Daily Charges: Total Charges: Rig Activity: Report For: 17916' Alpine Yesterday's Depth: 16-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: 10848 14.0 North Slope, AK 96% 12.15 24 hr Max 172.0 Flow In (gpm) Avg to15552' (max) Drilling ahead from 15550' MD to 17916' MD. (current)(max) 2-4-BT-A-X-I-CT-DTF Bottoms Up Strokes Surface Tuff Intermediate Lag Correction (bbls) BTC-M / H563 Background Comments Average Trip = 15861 Connection C-5nC-1 C-3 446624 100% Gas Summary BTC-M / H563 L-8029.7# 11853'- Bottoms Up Time (min) 1-1-W T-A-E-I-NOTD AM-AK-902423999 Drilling Ahead PV 2228' 24 Hour Progress: 15552' 162 2.3 Hours 104,0009.7026 1-1-ER-A-X-I-CT-TD3870' Condition GvlCoal CementShClystLst L-8045.5# 16030 C-4i C-4n C-5i 60136 Time: SPP (psi) Gallons/stroke 254 0 Flow In (spm) Chromatograph (ppm) 17916' 2364' Max @ ft Current 17047'138.0 Date: 60 Fluids: 0 bbls lost downhole 5322 Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) 667268644 22 22 235199159 3.51855 Footage 33.36 - 24 - TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data Depth (lb/100ft2) 55.14 - 4.8 15 114' - 2342' 5641' 2342' Depth 52500529 C-2 9596 Grade API FL Maximum Units* 0.994 907-670-4347 Minimum 224624 33 733 2650 35721 0 Unit Phone: 67709 D. Durst 88190813 Report By:Logging Engineers:C. Murray / D. Durst Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt 1 Milled Tooth 1.086 84.57 Size 7983' 6.75 11853' 4 PDC - PDC 11837' MD 3 7 5/8" Type 9.875 . . * 24 hr Recap: 11853' 4 PDC - PDC 11837' MD 3 7 5/8" Type 9.875 1 Milled Tooth 1.086 84.57 Size 7983' 6.75 Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt Unit Phone: 7817 D. Durst 92200856 Report By:Logging Engineers:C. Murray / D. Durst 86 200 34334 91 907-670-4347 Minimum 236048 1335 255 Grade API FL Maximum Units* 0.994 Depth 55220556 C-2 12596 (lb/100ft2) 55.14 - 4.8 15 114' - 2342' 5641' 2342' TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data Depth 8300 -937 Footage 33.36 - 24 - 802688596 373 203 29405 Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) Fluids: 0 bbls lost downhole circulate. Pump 32 bbl spacer and displace to 10.9 ppg NaCl/NaBr Brine. 5555 18878' 962' Max @ ft Current 17923'114.5 Date: 60 Time: SPP (psi) Gallons/stroke 254 70 Flow In (spm) Chromatograph (ppm) 18257 C-4i C-4n C-5i 71560 Condition GvlCoal CementShClystLst L-8045.5# 24 Hour Progress: 17916' 162 - Hours 188,000-8 1-1-ER-A-X-I-CT-TD3870' Bottoms Up Time (min) 1-1-W T-A-E-I-NOTD AM-AK-902423999 Displace to Brine PV 2228' BTC-M / H563 L-8029.7# 11853'- C-3 456061 Gas Summary C-5n Trip = 15374 ConnectionBackground Comments Average 2-4-BT-A-X-I-CT-DTF Bottoms Up Strokes Surface Tuff Intermediate Lag Correction (bbls) BTC-M / H563 (max) to17916' (max) Drilled ahead from 17920 'MD to TD of 18878' MD'. Circulate B/U, obtain formation fingerprint, continue to (current) 4542 - North Slope, AK 96% 24 hr Max 134.6 Flow In (gpm) Avg 18878' Alpine Yesterday's Depth: 17-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Morning Report Report # 30 Customer: Well: Area: Location: - Daily Charges: Total Charges: Rig Activity: Report For: @ MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary K. Harding/ A. Dorr Current Pump & Flow Data: 2146 Max Chlorides ECD (ppg) 4.23 Bit # 13.5" Depth 18878' 2327' MD FLOPRO NT C-1 pH Cht Cly ml/30min Depth in / out 2 172 YP 60.0 mg/l 10.70 Size 10.30 RPM in WOB 100% Gas In Air- 4519 - 6377 7018168 42019 Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units . . * 24 hr Recap: PDC 11837' MD 3 7 5/8" Type 9.875 1 Milled Tooth 1.086 84.57 Size 7983' 6.754PDC - Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt Unit Phone: 208 D. Durst 92200856 Report By:Logging Engineers:C. Murray / D. Durst 4 29 0 907-670-4347 Minimum 114 0 0 Grade API FL Maximum Units* 0.994 Depth 55220556 C-2 74 Depth (lb/100ft2) 55.14 - 4.8 15 114' - 2342' 5641' - TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data 1040 Footage 33.36 - 24 2342' 11853' 247 0 0 279209 4 Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) Fluids: 70 bbls lost downhole OOH to 13158' MD. BROOH to 11824' MD, with tight spots at 14141' MD, 14085' MD, 13835' MD, 13653' MD, 13564' MD, 13477' 16 0' Max @ ft Current -- Date: 47 SPP (psi) Gallons/stroke 199 0 Flow In (spm) Chromatograph (ppm) - C-4i C-4n C-5i 167 168 Clyst Lst L-8045.5# 162 - Hours 182,000-14 1-1-ER-A-X-I-CT-TD3870' Condition - 1-1-WT-A-E-I-NOTD AM-AK-902423999 Tripping Out of the Hole PV 2228' 24 Hour Progress: 18878' 11853'- Bottoms Up Time (min) GvlCoal Cement C-3 816 Gas Summary 209 C-5n 3 100% Gas In AirTrip= 26 Connection Comments Average BTC-M / H563 L-8029.7# Bottoms Up Strokes Surface Tuff Intermediate Lag Correction (bbls) BTC-M / H563 Sh MD. Circulate 4x B/U, pump 2x 35 bbl high vis sweeps. Flow check (static). Pump 32 bbs 12.4 bbl dry job. Trip OOH to 3641' MD. (max) Background - to - (max) Continue displacement to 10.9 ppg brine. Obtain formation fingerprint. Trip OOH to 13539' MD. Circulate B/U. Trip (current) @ - North Slope, AK 96% - 24 hr Max - Flow In (gpm) Avg Alpine Yesterday's Depth: 18-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Time: 18878' Morning Report Report # 31 Customer: Well: Area: Location: - Daily Charges: Total Charges: Rig Activity: Report For: MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary K. Harding/ A. Dorr Current Pump & Flow Data: 424 Max Chlorides ECD (ppg) 4.23 Bit # 13.5" Depth 18878' 2327' MD NaCl/NaBr 10.90 Size 10.90 in C-1 pH Cht Cly ml/30min Depth in / out 2 172 YP 60.0 - - mg/l RPMWOB 2-4-BT-A-X-I-CT-DTF - 38 0- 42 Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units . . * 24 hr Recap: % 7983' rig 10,000 Units 0 Density (ppg) out (sec/qt) Viscosity Cor Solids 0 0- 2-4-BT-A-X-I-CT-DMF - 0 - - mg/l RPMWOB C-1 pH Cht Cly ml/30min Depth in / out 2 Bit # 13.5" Depth 18878' 2327' MD NaCl/NaBr 10.90 Size 10.90 in K. Harding/ A. Dorr Current Pump & Flow Data: 0 Max Chlorides ECD (ppg) 4.23 MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary Morning Report Report # 32 Customer: Well: Area: Location: - Daily Charges: Total Charges: Rig Activity: Report For: Alpine Yesterday's Depth: 19-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Time: 18878' @ - North Slope, AK 96% - 24 hr Max - Flow In (gpm) Avg - to - (max) Continue to trip OOH to 371' MD. Install trip nipple, POOH and L/D BHA. P/U and stand back 60 joints of HWDP. Run (current)(max) Background Surface Tuff Intermediate Lag Correction (bbls) BTC-M / H563 Sh Average BTC-M / H563 L-8029.7# Bottoms Up Strokes Trip = 0 Connection C-5n 0 100% Gas In Air C-3 24 Gas Summary 24 Hour Progress: 18878' 11853'1-1-BT-T-X-ER-TD GvlCoal Cement AM-AK-902423999 Running 4.5" Liner PV 2228' YP 184,000-9 1-1-ER-A-X-I-CT-TD3870' Condition - 1-1-WT-A-E-I-NO-TD 172 60.0 Lst L-8045.5# 162 Bottoms Up Time (min) Comments - C-4i C-4n C-5i 7 4 Gallons/stroke 0 0 Flow In (spm) Chromatograph (ppm) Clyst 0' Max @ ft Current -- Date: 0 SPP (psi) Fluids: 25 bbls lost downhole 4.5" liner to 7166' MD. Change out elevators, M/U liner hanger. Continue to RIH with 4.5" Liner on 4" DP to 9958' MD. 4 Volumes (current) Annular Volume (bbls) Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) 9 0 0 1210 1 1139 Footage 33.36 7025' 24 2342' 11853' - Hours 150 TFABit Type cPMud Type (ppb Eq) GR/RES/PWD/DENS/NEUT MBT Mud Data Depth (lb/100ft2) 55.14 25 4.8 15 114' 18878' 2342' 5641' Depth 32720556 C-2 4 Grade API FL Maximum Units* 0.994 907-670-4347 Minimum 2 0 0 5 0 0 10 Unit Phone: 0 D. Durst --856 Report By:Logging Engineers:C. Murray / D. Durst Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt 1 Mill Tooth 1.086 84.57 Size 7983' 6.754PDC 60.25 PDC 11837' MD 3 7 5/8" Type 9.875 . . * 24 hr Recap: % 7983' rig 10,000 Units 177 Density (ppg) out (sec/qt) Viscosity Cor Solids 20 0-0 - 11 - - mg/l RPMWOB 180,000- C-1 pH Cht Cly ml/30min Depth in / out 2 Bit # 13.5" Depth 18878' 2327' MD / 2232' TVD NaCl/NaBr 10.80 Size 10.80 in K. Harding/ A. Dorr Current Pump & Flow Data: 0 Max Chlorides ECD (ppg) 4.23 MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary Morning Report Report # 33 Customer: Well: Area: Location: - Daily Charges: Total Charges: Rig Activity: Report For: Alpine Yesterday's Depth: 20-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Time: 18878' @ - North Slope, AK 96% - 24 hr Max - Flow In (gpm) Avg - to - (max) Continue to RIH with 4.5" liner to 11749' MD, circulate liner volume. Continue to RIH to 18878' MD, displace to 10.8 (current) packer. Test packer for 10 mins. Flow check (slight drop), POOH to 10324' MD. Slip and cut drill line. POOH to 5992' MD. (max) Background H563 Surface Casing 12.6# Tuff Intermediate Casing Lag Correction (bbls) BTC-M / H563 Sh Lst L-80 Average BTC-M / H563 L-8029.7# Bottoms Up Strokes Trip = 53 Connection C-5n 13 100% Gas In Air C-3 24644 Gas Summary 24 Hour Progress: 18878' 11853'1-1-BT-T-X-ER-TD GvlCoal Cement AM-AK-902423999 POOH PV 2228' YP - 1-1-ER-A-X-I-CT-TD3870' Condition - 1-1-WT-A-E-I-NO-TD 172 60.0 - 2-4-BT-A-X-I-CT-DMF 45.5# Production Liner 162 Bottoms Up Time (min) Comments 150 55.14 - C-4i C-4n C-5i 6771 3066104 Gallons/stroke 0 0 Flow In (spm) Chromatograph (ppm) Clyst 0' Max @ ft Current -- Date: 0 SPP (psi) Fluids: 39 bbls lost downhole ppg brine. Pumped 35 bbl high viscosity spacer, followed by 700 bbls of 10.8 ppg brine. Drop ball and set hanger. Set liner top 26 Volumes (current) Annular Volume (bbls) 4.5" Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) 0 1545684 2 27 Footage 33.36 7025' 24 2342' 11853' - HoursTFABit Type cPMud Type (ppb Eq) - MBT Mud Data Depth (lb/100ft2) 25 4.8 15 114' 18878' 2342' 5641' Depth 32720556 C-2 648 Grade L-8018863' MD / 7420' TVD API FL Maximum Units* 0.994 907-670-4347 Minimum 621 0 0 4 181 0 684 Unit Phone: 308 D. Durst --856 Report By:Logging Engineers:C. Murray / D. Durst Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt 1 Mill Tooth 1.086 84.57 Size 7983' 6.754PDC 60.25 PDC 11837' MD / 7474' TVD 3 7 5/8" Type 9.875 . . * 24 hr Recap: % 7983' rig 10,000 Units 0 Density (ppg) out (sec/qt) Viscosity Cor Solids 0 0-0 - 0 - - mg/l RPMWOB 184,000- C-1 pH Cht Cly ml/30min Depth in / out 2 Bit # 13.5" Depth 18878' 2327' MD / 2232' TVD NaCl/NaBr 10.80 Size 10.80 in K. Harding/ A. Dorr Current Pump & Flow Data: 0 Max Chlorides ECD (ppg) 4.23 MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary Morning Report Report # 34 Customer: Well: Area: Location: - Daily Charges: Total Charges: Rig Activity: Report For: Alpine Yesterday's Depth: 21-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Time: 18878' @ - North Slope, AK 96% - 24 hr Max - Flow In (gpm) Avg - to - (max) Continue to POOH and L/D 4" DP. Pull wear ring. R/U and RIH with 3.5" tubing to 8058' MD. (current)(max) Background H563 Surface Casing 12.6# Tuff Intermediate Casing Lag Correction (bbls) BTC-M / H563 Sh Lst L-80 Average BTC-M / H563 L-8029.7# Bottoms Up Strokes Trip = 0 Connection C-5n 0 100% Gas In Air C-3 50 Gas Summary 24 Hour Progress: 18878' 11853'1-1-BT-T-X-ER-TD GvlCoal Cement AM-AK-902423999 Running 3.5" Tubing PV 2228' YP - 1-1-ER-A-X-I-CT-TD3870' Condition - 1-1-WT-A-E-I-NO-TD 172 60.0 - 2-4-BT-A-X-I-CT-DMF 45.5# Production Liner 162 Bottoms Up Time (min) Comments 150 55.14 - C-4i C-4n C-5i 14 015 Gallons/stroke 0 0 Flow In (spm) Chromatograph (ppm) Clyst 0' Max @ ft Current -- Date: 0 SPP (psi) Fluids: 59 bbls lost downhole 3 Volumes (current) Annular Volume (bbls) 4.5" Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) 0 136 1 27 Footage 33.36 7025' 24 2342' 11853' - HoursTFABit Type cPMud Type (ppb Eq) - MBT Mud Data Depth (lb/100ft2) 25 4.8 15 114' 18878' 2342' 5641' Depth 32720556 C-2 0 Grade L-8018863' MD / 7420' TVD API FL Maximum Units* 0.994 907-670-4347 Minimum 1 0 0 3 0 0 6 Unit Phone: 4 D. Durst --856 Report By:Logging Engineers:C. Murray / D. Durst Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt 1 Mill Tooth 1.086 84.57 Size 7983' 6.754PDC 60.25 PDC 11837' MD / 7474' TVD 3 7 5/8" Type 9.875 . . * 24 hr Recap: PDC 11837' MD / 7474' TVD 3 7 5/8" Type 9.875 1 Mill Tooth 1.086 84.57 Size 7983' 6.754PDC 60.25 Set At PDC 9.875 0.049 10 3/4" 0.383 Ss Silt Unit Phone: 0 D. Durst --856 Report By:Logging Engineers:C. Murray / D. Durst 0 0 0 0 907-670-4347 Minimum 0 0 0 Grade L-8018863' MD / 7420' TVD API FL Maximum Units* 0.994 Depth 32720556 C-2 0 25 4.8 15 114' 18878' 2342' 5641' Bit Type cPMud Type (ppb Eq) - MBT Mud Data Depth (lb/100ft2) 27 Footage 33.36 7025' 24 2342' 11853' - HoursTFA 0 00 0 Volumes (current) Annular Volume (bbls) 4.5" Siltst Casing Summary Lithology (%) W eight Hole Capacity (bbls) Drillstring Capacity (bbls) Fluids: 124 bbls lost downhole Inhibited brine. Make up hanger. RIH and land tubing at 11686' MD. (1' off fully located) Test hanger seals, tubing, and IA. Shear 0 0' Max @ ft Current -- Date: 0 SPP (psi) Gallons/stroke 0 0 Flow In (spm) Chromatograph (ppm) Clyst - C-4i C-4n C-5i 0 00 45.5# Production Liner 162 Bottoms Up Time (min) Comments 150 55.14 1-1-ER-A-X-I-CT-TD3870' Condition - 1-1-WT-A-E-I-NO-TD 172 60.0 - 2-4-BT-A-X-I-CT-DMF AM-AK-902423999 N/D Stack PV 2228' YP - 24 Hour Progress: 18878' 11853'1-1-BT-T-X-ER-TD GvlCoal Cement 0 Gas Summary C-5n 0 100% Gas In Air C-3 Trip = 0 Connection Average BTC-M / H563 L-8029.7# Bottoms Up Strokes H563 Surface Casing 12.6# Tuff Intermediate Casing Lag Correction (bbls) BTC-M / H563 Sh Lst L-80 SOV, install TWC and test. Flush stack. Nipple down stack. (max) Background - to - (max) Continue to RIH with 3.5" tubing to 11687' MD, tag no go, POOH to 11663' MDPump 26 bbls of 10.8 Corosion (current) @ - North Slope, AK 96% - 24 hr Max - Flow In (gpm) Avg Alpine Yesterday's Depth: 22-Jun-2015 CD5-04 ConocoPhillips, Alaska Avg Current Depth: Job No.: Time: 18878' Morning Report Report # 35 Customer: Well: Area: Location: - Daily Charges: Total Charges: Rig Activity: Report For: MinTools Rig: ROP ROP (ft/hr) 12:00 AMDoyon 19 MWD Summary K. Harding/ A. Dorr Current Pump & Flow Data: 0 Max Chlorides ECD (ppg) 4.23 Bit # 13.5" Depth 18878' 2327' MD / 2232' TVD NaCl/NaBr 10.80 Size 10.80 in C-1 pH Cht Cly ml/30min Depth in / out 2 - - mg/l RPMWOB 184,000- - 00 0-0 0 Density (ppg) out (sec/qt) Viscosity Cor Solids % 7983' rig 10,000 Units WELL INFORMATION Created On : Jul 14 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :CD5-04 Job Number :-XX-0902423999 Rig Name :Doyon 19 Field Name :Alpine 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') 86.20 0.14 301.48 86.20 0.05 N 0.09 W 0.05 0.16 178.70 0.21 264.50 178.70 0.10 N 0.35 W 0.10 0.14 272.30 0.28 243.14 272.30 0.02 S 0.73 W -0.02 0.12 364.10 0.16 217.42 364.10 0.23 S 1.01 W -0.23 0.17 455.80 0.26 184.48 455.80 0.53 S 1.10 W -0.53 0.17 475.19 0.50 168.89 475.19 0.66 S 1.09 W -0.66 1.34 567.22 1.59 154.88 567.20 2.21 S 0.47 W -2.21 1.21 616.54 2.43 153.55 616.49 3.77 S 0.29 E -3.77 1.71 657.80 2.36 149.11 657.71 5.28 S 1.11 E -5.28 0.48 752.05 4.17 142.81 751.81 9.67 S 4.18 E -9.67 1.95 846.97 6.25 144.42 846.33 16.63 S 9.27 E -16.63 2.20 940.06 8.84 143.08 938.61 26.47 S 16.52 E -26.47 2.79 1035.43 10.56 144.87 1,032.61 39.47 S 25.95 E -39.47 1.83 1128.45 12.03 146.30 1,123.83 54.51 S 36.23 E -54.51 1.61 1221.31 13.76 147.05 1,214.34 71.83 S 47.61 E -71.83 1.87 1316.18 16.58 145.80 1,305.90 92.50 S 61.36 E -92.50 2.99 1412.36 17.81 144.07 1,397.78 115.76 S 77.70 E -115.76 1.38 1507.01 20.62 144.14 1,487.14 140.99 S 95.97 E -140.99 2.97 1601.06 22.39 145.61 1,574.64 169.20 S 115.79 E -169.20 1.97 1693.77 22.90 138.99 1,660.22 197.38 S 137.60 E -197.38 2.80 1785.12 23.45 132.45 1,744.21 223.07 S 162.68 E -223.07 2.88 1878.68 25.53 125.78 1,829.37 247.43 S 192.78 E -247.43 3.70 1973.10 24.42 115.02 1,915.00 267.59 S 226.99 E -267.59 4.95 2067.66 25.09 106.10 2,000.90 281.42 S 263.98 E -281.42 4.01 2162.23 26.87 99.91 2,085.93 290.66 S 304.31 E -290.66 3.43 2259.78 27.98 94.31 2,172.53 296.18 S 348.85 E -296.18 2.88 2271.52 28.24 93.84 2,182.88 296.57 S 354.37 E -296.57 2.91 2365.41 31.02 90.20 2,264.49 298.14 S 400.74 E -298.14 3.53 2424.38 32.03 91.55 2,314.76 298.62 S 431.56 E -298.62 2.09 2517.81 34.80 89.04 2,392.74 298.84 S 483.00 E -298.84 3.31 INSITE V8.3.0 Page 1Job No:-XX-0902423999 Well Name:CD5-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2566.25 36.22 84.71 2,432.18 297.29 S 511.08 E -297.29 5.96 2613.31 37.63 80.97 2,469.80 293.75 S 539.11 E -293.75 5.64 2660.42 38.20 77.76 2,506.97 288.41 S 567.56 E -288.41 4.36 2704.07 39.18 72.09 2,541.05 281.30 S 593.88 E -281.30 8.42 2751.19 40.52 71.21 2,577.23 271.80 S 622.53 E -271.80 3.09 2798.98 42.50 72.29 2,613.02 261.88 S 652.61 E -261.88 4.41 2895.36 45.18 73.51 2,682.53 242.27 S 716.41 E -242.27 2.92 2988.21 48.44 73.77 2,746.07 223.21 S 781.36 E -223.21 3.52 3082.85 51.77 73.58 2,806.76 202.80 S 851.03 E -202.80 3.52 3178.61 52.15 73.25 2,865.77 181.28 S 923.31 E -181.28 0.48 3273.43 52.23 73.42 2,923.90 159.79 S 995.08 E -159.79 0.16 3367.32 52.15 71.32 2,981.46 137.33 S 1,065.77 E -137.33 1.77 3462.18 52.24 72.67 3,039.61 114.16 S 1,137.04 E -114.16 1.13 3555.95 54.07 73.78 3,095.84 92.52 S 1,208.89 E -92.52 2.17 3644.87 55.06 74.48 3,147.39 72.71 S 1,278.57 E -72.71 1.28 3739.15 55.55 72.80 3,201.06 50.87 S 1,352.95 E -50.87 1.55 3833.30 55.54 70.94 3,254.33 26.72 S 1,426.72 E -26.72 1.63 3926.57 55.28 70.04 3,307.28 1.07 S 1,499.09 E -1.07 0.84 4020.60 55.52 68.48 3,360.67 26.34 N 1,571.47 E 26.34 1.39 4115.00 55.30 67.23 3,414.27 55.63 N 1,643.45 E 55.63 1.11 4208.62 55.05 67.13 3,467.73 85.43 N 1,714.29 E 85.43 0.28 4303.28 54.87 67.95 3,522.08 115.04 N 1,785.91 E 115.04 0.73 4397.20 54.82 68.78 3,576.16 143.36 N 1,857.29 E 143.36 0.72 4491.83 54.83 69.63 3,630.67 170.82 N 1,929.60 E 170.82 0.73 4586.53 55.16 71.83 3,685.00 196.41 N 2,002.82 E 196.41 1.93 4680.72 55.49 73.71 3,738.59 219.35 N 2,076.80 E 219.35 1.68 4775.17 55.38 73.00 3,792.18 241.63 N 2,151.31 E 241.63 0.63 4868.74 55.44 72.15 3,845.30 264.70 N 2,224.81 E 264.70 0.75 4962.98 55.58 73.26 3,898.66 287.79 N 2,298.97 E 287.79 0.98 5057.92 55.16 68.66 3,952.63 313.25 N 2,372.79 E 313.25 4.01 5151.05 55.08 66.11 4,005.90 342.63 N 2,443.30 E 342.63 2.25 5246.55 55.14 67.14 4,060.52 373.70 N 2,515.21 E 373.70 0.89 5340.35 54.99 69.39 4,114.24 402.18 N 2,586.63 E 402.18 1.97 5434.22 55.03 68.24 4,168.07 429.97 N 2,658.33 E 429.97 1.00 5528.02 54.99 70.41 4,221.87 457.10 N 2,730.22 E 457.10 1.90 5623.34 54.90 73.38 4,276.62 481.34 N 2,804.37 E 481.34 2.55 5716.54 55.05 73.05 4,330.11 503.38 N 2,877.44 E 503.38 0.33 5811.87 55.03 71.28 4,384.74 527.31 N 2,951.81 E 527.31 1.52 5906.61 54.91 72.00 4,439.12 551.75 N 3,025.44 E 551.75 0.64 6001.11 54.89 73.72 4,493.46 574.53 N 3,099.32 E 574.53 1.49 6095.27 55.05 75.32 4,547.51 595.11 N 3,173.62 E 595.11 1.40 6189.23 55.54 74.06 4,601.01 615.51 N 3,248.12 E 615.51 1.22 6282.38 55.58 71.54 4,653.70 638.22 N 3,321.49 E 638.22 2.23 6375.92 55.54 70.18 4,706.60 663.51 N 3,394.37 E 663.51 1.20 6470.15 55.25 69.37 4,760.11 690.32 N 3,467.15 E 690.32 0.77 INSITE V8.3.0 Page 2Job No:-XX-0902423999 Well Name:CD5-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6564.26 54.90 70.24 4,813.99 716.96 N 3,539.56 E 716.96 0.84 6658.47 54.95 71.11 4,868.13 742.48 N 3,612.32 E 742.48 0.76 6751.57 55.04 73.02 4,921.54 765.96 N 3,684.87 E 765.96 1.68 6846.20 54.91 70.78 4,975.86 790.03 N 3,758.52 E 790.03 1.94 6942.62 55.02 70.56 5,031.21 816.16 N 3,833.02 E 816.16 0.22 7037.00 54.90 68.98 5,085.40 842.88 N 3,905.52 E 842.88 1.38 7130.46 54.91 68.23 5,139.13 870.77 N 3,976.72 E 870.77 0.66 7224.78 55.46 70.84 5,192.99 897.84 N 4,049.26 E 897.84 2.35 7319.18 55.38 69.29 5,246.57 924.34 N 4,122.32 E 924.34 1.35 7414.45 55.46 70.53 5,300.64 951.28 N 4,195.98 E 951.28 1.07 7507.70 55.42 71.48 5,353.54 976.28 N 4,268.60 E 976.28 0.84 7602.40 55.39 71.68 5,407.31 1,000.91 N 4,342.56 E 1000.91 0.18 7696.71 55.46 71.39 5,460.83 1,025.50 N 4,416.21 E 1025.50 0.26 7790.69 55.25 71.61 5,514.26 1,050.04 N 4,489.53 E 1050.04 0.29 7883.95 54.92 71.33 5,567.63 1,074.34 N 4,562.04 E 1074.34 0.43 7919.48 54.48 71.01 5,588.17 1,083.70 N 4,589.49 E 1083.70 1.44 7977.75 54.20 70.27 5,622.14 1,099.39 N 4,634.15 E 1099.39 1.14 8072.31 55.16 70.84 5,676.80 1,125.07 N 4,706.91 E 1125.07 1.13 8167.35 55.57 71.46 5,730.82 1,150.34 N 4,780.91 E 1150.34 0.69 8261.96 55.25 70.41 5,784.53 1,175.78 N 4,854.52 E 1175.78 0.97 8356.04 55.14 70.51 5,838.23 1,201.61 N 4,927.32 E 1201.61 0.15 8448.58 55.17 69.92 5,891.10 1,227.32 N 4,998.79 E 1227.32 0.52 8543.23 55.58 69.29 5,944.89 1,254.46 N 5,071.79 E 1254.46 0.70 8637.60 55.67 68.33 5,998.17 1,282.62 N 5,144.41 E 1282.62 0.85 8731.78 55.41 68.04 6,051.46 1,311.47 N 5,216.50 E 1311.47 0.38 8826.39 55.17 67.93 6,105.33 1,340.63 N 5,288.61 E 1340.63 0.27 8921.26 55.23 68.17 6,159.47 1,369.75 N 5,360.86 E 1369.75 0.22 9015.29 55.28 69.33 6,213.07 1,397.75 N 5,432.87 E 1397.75 1.02 9106.95 55.02 69.51 6,265.44 1,424.19 N 5,503.29 E 1424.19 0.33 9203.16 55.16 66.59 6,320.51 1,453.68 N 5,576.46 E 1453.68 2.49 9295.27 54.19 63.80 6,373.78 1,485.19 N 5,644.67 E 1485.19 2.69 9391.99 54.00 61.89 6,430.50 1,520.94 N 5,714.37 E 1520.94 1.61 9486.28 53.84 59.41 6,486.04 1,558.29 N 5,780.78 E 1558.29 2.13 9581.07 53.99 55.42 6,541.88 1,599.53 N 5,845.31 E 1599.53 3.41 9675.68 54.70 52.05 6,597.04 1,645.00 N 5,907.27 E 1645.00 2.99 9768.98 55.10 48.51 6,650.70 1,693.77 N 5,965.96 E 1693.77 3.13 9863.74 55.88 43.78 6,704.40 1,747.86 N 6,022.23 E 1747.86 4.19 9958.90 56.08 38.62 6,757.67 1,807.17 N 6,074.15 E 1807.17 4.50 10052.51 56.29 31.92 6,809.81 1,870.62 N 6,119.02 E 1870.62 5.95 10100.29 56.34 29.62 6,836.31 1,904.77 N 6,139.35 E 1904.77 4.01 10146.62 56.31 27.41 6,862.00 1,938.65 N 6,157.76 E 1938.65 3.97 10241.44 55.89 22.96 6,914.90 2,009.84 N 6,191.24 E 2009.84 3.92 10335.09 56.34 18.23 6,967.14 2,082.58 N 6,218.57 E 2082.58 4.22 10428.10 57.43 15.85 7,017.95 2,157.06 N 6,241.38 E 2157.06 2.44 10522.29 59.40 10.82 7,067.31 2,235.10 N 6,259.84 E 2235.10 5.01 INSITE V8.3.0 Page 3Job No:-XX-0902423999 Well Name:CD5-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10617.45 59.63 8.04 7,115.59 2,315.98 N 6,273.28 E 2315.98 2.53 10712.08 60.82 5.04 7,162.59 2,397.57 N 6,282.62 E 2397.57 3.03 10810.41 63.06 2.40 7,208.85 2,484.14 N 6,288.23 E 2484.14 3.29 10900.70 65.52 359.78 7,248.02 2,565.47 N 6,289.75 E 2565.47 3.78 10993.06 68.91 357.58 7,283.79 2,650.58 N 6,287.77 E 2650.58 4.28 11086.91 72.16 355.95 7,315.06 2,738.90 N 6,282.77 E 2738.91 3.83 11181.88 75.13 353.64 7,341.80 2,829.64 N 6,274.49 E 2829.64 3.90 11230.57 76.05 351.23 7,353.92 2,876.38 N 6,268.28 E 2876.38 5.15 11274.75 76.22 348.91 7,364.51 2,918.63 N 6,260.88 E 2918.63 5.11 11325.21 76.04 346.16 7,376.61 2,966.46 N 6,250.31 E 2966.46 5.30 11370.66 76.13 344.15 7,387.54 3,009.10 N 6,239.01 E 3009.10 4.30 11464.46 78.20 340.06 7,408.38 3,096.10 N 6,210.90 E 3096.10 4.79 11559.02 79.52 338.43 7,426.65 3,182.85 N 6,178.02 E 3182.85 2.19 11653.18 79.94 338.00 7,443.44 3,268.89 N 6,143.63 E 3268.89 0.63 11746.76 80.47 337.23 7,459.36 3,354.15 N 6,108.52 E 3354.15 0.99 11787.61 80.57 336.85 7,466.09 3,391.25 N 6,092.80 E 3391.25 0.95 11858.82 82.10 338.92 7,476.82 3,456.46 N 6,066.30 E 3456.46 3.59 11954.94 85.95 338.44 7,486.82 3,545.50 N 6,031.55 E 3545.50 4.04 12003.28 87.53 337.43 7,489.57 3,590.23 N 6,013.42 E 3590.23 3.88 12050.62 88.99 333.77 7,491.01 3,633.31 N 5,993.88 E 3633.31 8.32 12096.96 90.39 336.08 7,491.26 3,675.28 N 5,974.24 E 3675.28 5.83 12144.17 91.65 332.36 7,490.42 3,717.78 N 5,953.71 E 3717.78 8.32 12240.10 92.69 332.64 7,486.79 3,802.80 N 5,909.45 E 3802.80 1.12 12335.16 92.85 331.13 7,482.19 3,886.55 N 5,864.71 E 3886.55 1.60 12430.89 93.07 328.79 7,477.25 3,969.30 N 5,816.85 E 3969.30 2.45 12526.15 91.39 329.27 7,473.54 4,050.92 N 5,767.87 E 4050.92 1.83 12620.63 90.82 328.46 7,471.72 4,131.77 N 5,719.03 E 4131.77 1.05 12716.49 90.27 328.39 7,470.81 4,213.43 N 5,668.84 E 4213.43 0.58 12811.66 90.44 327.84 7,470.22 4,294.24 N 5,618.57 E 4294.24 0.60 12907.34 90.31 328.78 7,469.59 4,375.65 N 5,568.31 E 4375.65 0.99 13002.43 90.34 329.29 7,469.05 4,457.19 N 5,519.38 E 4457.19 0.54 13097.19 90.38 329.20 7,468.46 4,538.62 N 5,470.93 E 4538.62 0.10 13192.34 90.34 330.04 7,467.86 4,620.70 N 5,422.81 E 4620.70 0.88 13287.66 90.31 329.15 7,467.32 4,702.91 N 5,374.57 E 4702.91 0.93 13383.21 90.27 328.83 7,466.83 4,784.81 N 5,325.34 E 4784.81 0.34 13478.68 90.45 328.75 7,466.23 4,866.46 N 5,275.87 E 4866.46 0.21 13574.78 90.41 327.97 7,465.51 4,948.27 N 5,225.46 E 4948.27 0.81 13670.67 90.17 326.70 7,465.03 5,028.99 N 5,173.71 E 5028.99 1.35 13765.05 89.83 325.11 7,465.03 5,107.15 N 5,120.80 E 5107.15 1.72 13861.43 88.85 324.58 7,466.14 5,185.94 N 5,065.31 E 5185.94 1.16 13956.92 89.16 323.39 7,467.80 5,263.16 N 5,009.18 E 5263.16 1.29 14052.20 87.86 323.96 7,470.27 5,339.90 N 4,952.76 E 5339.90 1.49 14146.65 88.07 324.27 7,473.63 5,416.37 N 4,897.43 E 5416.37 0.40 14242.02 89.43 323.66 7,475.71 5,493.48 N 4,841.34 E 5493.48 1.56 14337.84 89.49 325.34 7,476.61 5,571.48 N 4,785.70 E 5571.48 1.75 INSITE V8.3.0 Page 4Job No:-XX-0902423999 Well Name:CD5-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14433.63 89.45 325.23 7,477.50 5,650.21 N 4,731.15 E 5650.21 0.12 14528.60 89.90 324.02 7,478.04 5,727.65 N 4,676.17 E 5727.65 1.36 14623.53 90.41 325.31 7,477.78 5,805.09 N 4,621.27 E 5805.09 1.46 14718.57 90.48 326.93 7,477.04 5,883.98 N 4,568.29 E 5883.98 1.71 14813.45 91.17 327.50 7,475.68 5,963.74 N 4,516.92 E 5963.74 0.94 14908.17 91.68 328.09 7,473.32 6,043.86 N 4,466.46 E 6043.86 0.82 15005.03 91.99 329.86 7,470.22 6,126.82 N 4,416.56 E 6126.82 1.85 15099.85 91.85 331.48 7,467.04 6,209.44 N 4,370.14 E 6209.44 1.71 15194.76 90.86 330.52 7,464.80 6,292.42 N 4,324.14 E 6292.42 1.45 15289.95 90.21 331.00 7,463.91 6,375.48 N 4,277.65 E 6375.48 0.85 15385.57 89.90 332.19 7,463.82 6,459.58 N 4,232.16 E 6459.58 1.29 15481.41 90.00 334.69 7,463.90 6,545.30 N 4,189.31 E 6545.30 2.61 15577.24 90.27 334.35 7,463.67 6,631.81 N 4,148.09 E 6631.81 0.45 15672.86 90.24 332.55 7,463.25 6,717.34 N 4,105.35 E 6717.34 1.88 15767.90 90.07 332.62 7,462.99 6,801.71 N 4,061.59 E 6801.71 0.19 15863.55 90.07 334.86 7,462.88 6,887.48 N 4,019.27 E 6887.48 2.34 15959.16 90.07 335.46 7,462.76 6,974.25 N 3,979.11 E 6974.25 0.63 16053.65 90.55 336.06 7,462.25 7,060.40 N 3,940.31 E 7060.40 0.81 16149.69 90.86 337.22 7,461.06 7,148.56 N 3,902.24 E 7148.56 1.25 16244.80 91.24 336.62 7,459.32 7,236.05 N 3,864.96 E 7236.05 0.75 16339.52 91.00 335.44 7,457.47 7,322.58 N 3,826.49 E 7322.58 1.27 16435.31 90.93 334.51 7,455.86 7,409.36 N 3,785.97 E 7409.36 0.97 16530.34 91.17 333.94 7,454.12 7,494.92 N 3,744.66 E 7494.92 0.65 16624.65 91.03 332.00 7,452.31 7,578.91 N 3,701.81 E 7578.91 2.06 16719.72 91.62 329.51 7,450.11 7,661.84 N 3,655.38 E 7661.84 2.69 16815.82 90.93 329.10 7,447.97 7,744.45 N 3,606.33 E 7744.45 0.84 16911.12 91.10 326.93 7,446.28 7,825.27 N 3,555.86 E 7825.27 2.28 17006.56 90.53 326.24 7,444.92 7,904.92 N 3,503.31 E 7904.92 0.94 17103.41 91.28 325.52 7,443.39 7,985.09 N 3,448.99 E 7985.09 1.07 17197.56 90.99 323.91 7,441.53 8,061.92 N 3,394.62 E 8061.92 1.74 17292.54 89.94 321.04 7,440.76 8,137.24 N 3,336.78 E 8137.24 3.22 17387.17 90.17 323.08 7,440.67 8,211.87 N 3,278.60 E 8211.87 2.17 17482.45 90.24 324.69 7,440.33 8,288.83 N 3,222.44 E 8288.83 1.69 17576.01 90.17 326.51 7,439.99 8,366.03 N 3,169.58 E 8366.03 1.95 17672.94 90.55 327.58 7,439.38 8,447.36 N 3,116.86 E 8447.36 1.17 17768.78 90.27 328.92 7,438.70 8,528.85 N 3,066.43 E 8528.85 1.43 17864.16 89.85 331.78 7,438.60 8,611.73 N 3,019.25 E 8611.73 3.03 17960.66 90.77 332.41 7,438.07 8,697.01 N 2,974.09 E 8697.01 1.16 18055.16 90.65 334.11 7,436.90 8,781.40 N 2,931.57 E 8781.40 1.80 18150.49 90.58 335.18 7,435.88 8,867.54 N 2,890.75 E 8867.54 1.12 18245.34 90.96 335.78 7,434.60 8,953.82 N 2,851.39 E 8953.82 0.75 18340.88 91.13 337.05 7,432.86 9,041.37 N 2,813.17 E 9041.37 1.34 18436.02 91.24 337.07 7,430.89 9,128.96 N 2,776.10 E 9128.96 0.12 18531.47 90.55 336.77 7,429.40 9,216.76 N 2,738.69 E 9216.76 0.79 18627.69 90.55 337.95 7,428.48 9,305.56 N 2,701.65 E 9305.56 1.23 INSITE V8.3.0 Page 5Job No:-XX-0902423999 Well Name:CD5-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 18721.67 91.26 338.22 7,427.00 9,392.74 N 2,666.58 E 9392.74 0.81 18818.34 93.05 336.27 7,423.36 9,481.81 N 2,629.22 E 9481.81 2.74 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 18,818.34 feet is 9,839.59 feet along 15.50 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 V8.3.0 Page 6Job No:-XX-0902423999 Well Name:CD5-04 Survey Report
