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214-102
• • RECEIVED AUG 0 2 2017 Mark Shulman AOGCC Petroleum Engineer P.O.Box 100360 Anchorage,AK 99510-0360 ConocoPhilhps Phone:(907)263-3782 August 1, 2017 woo AUG 0 9 2,- AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests a discussion for clarity on the need of a physical production profile on Kuparuk Well 2M-36 (PTD#214-102) and other recent horizontal wells. The goal is to seek an understanding of the need of a physical production profile survey for a horizontal well that contain both A and C Kuparuk sands which lie directly on top of each other in pressure communication. In AOGCC Conservation Order No. 432D, Rule 9: Productivity profiles section(a) states: "During the first year of production, a production survey shall be run in each well that has multiple sand intervals open to the well bore. (Source CO 173)". It was recently brought to my attention that a physical production profile was not completed on 2M-36. I believe the confusion about the need for the production profile occurred from the novelty of the long horizontal laterals wells in Kuparuk with A and C sands that are in pressure communication of each other. Additionally, the challenges of getting meaningful data by arcuately determining where the flow is producing from. As 2M-36 reached steady state flow, it's total liquid rates was less than—250 BLPD in an—2,500' production lateral. This well produced extremely low flow rates which greatly lowers the profile tools accuracy and increases the error percentage of the tool. We determine the A and C sands splits of the well by reviewing the geological data. We have a number of other wells, that have been recently drilled, that may fall into the same category (1St year profile needed). We are requesting your help in answering the following questions for clarity. Question#1: Does "multiple sands intervals" apply to Kuparuk C-sand and A-sand that lie directly on top of each other which are in pressure communication of each other? Question#2: If a physical production profile is needed, can a geological review be used as a wavier(under CO 432D; Rule. 12)to determine the A-sand/C-sand splits instead of a physical production profile? (especially on low rate wells?) If you have any questions regarding this matter, please contact myself at 263-3782. • • Sincerely, yyMark Shulman Attachments Geological Review of 2M-36 • • Geological Review of 2M-36 t. mg il Y m 'a i N 1 ; ,; .1i t r e m; *± r 3 .:`,,.t: .'-d`,41k,7",.*;i4i,r.dii"11:—..,—. > E. .41,...'..., .-.. , ') _ie.,. '-., s T.1 _ 0. 10) i• i ", �. _ - 'a .. 2 i — ,.., , . , . , ilut.;,,,,,.. , . . 1 — [ 1 2 7 1 6 1 S TE OF ALASKA KRU 2M-36 ALWA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate F Pull Tubing Operations Shutdown E Performed: Suspend n Perforate r Other Stimulate E Alter Casing r Change Approved Program Plug for Redrill r Perforate New Pool r Repair Well f Re-enter Susp Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 214-102 3.Address: 6.API Number: Stratigraphic I Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20691-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25585,25586 KRU 2M-36 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 13013 feet Plugs(measured) None true vertical 6027 feet Junk(measured) None Effective Depth measured 12993 feet Packer(measured) 0 true vertical 6027 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 93 16 131 131 SURFACE 3300 10 3/4 3342 2835 INTERMEDIATE 9479 7 5/8 9518 5978 LINER 3652 41/2 12993 6027 Perforation depth: Measured depth: 9877-12972 MAY 1 8 nib 6 RECEIVE D True Vertical Depth: 6039-6029 SCANNED 1 APR 1 9 2016 Tubing(size,grade,MD,and TVD) 3.5, L-80, 9388 MD, 5944 TVD A v CC Packers&SSSV(type,MD,and TVD) N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9877-12972 Treatment descriptions including volumes used and final pressure: Total Well -8 stages 597,9021bs 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 160 100 110 850 230 Subsequent to operation 696 1500 845 1300 230 14.Attachments(required per 20 AAC 25.070,25.071,&25.253) 15.Well Class after work: Daily Report of Well Operations FExploratory 1 Development F Service Stratigraphic r Copies of Logs and Surveys Run r i� 16.Well Status after work: Oil Gas WDSPL E Printed and Electronic Fracture Stimulation Data F GSTOR r WINJ E WAG E GINJ T SUSP E SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-155 Contact Adam Klem Cad 263-4529 Email Adam.Klemconocophillips.com Printed Name :m Klem Title Completions Engineer SignaturePhone:263-4529 Date 1 : , 11/8,4 1/71 5//i/77, Form 10-404 Revised 5/2015 /i 0ARBDMS LL AP 1 2 'S Submit Original Only • 2M-36 • DTTM JOBTYP SUMMARYOPS START 3/3 FRACTURING DRIFT TBG W/2.66" CENT DOWN TO 9480' SLM; BRUSH D-NIPPLE & SET 2.75" CA-2 PLUG W/GAUGES @ 9327' RKB; DEPLOYED CATCHER SUB W/PULLING TOOL; PULLED GLV'S & SET DV @ 2718' &4504' RKB; PULLED OV©5546' RKB. READY FOR CIRC OUT. 3/5 FRACTURING LOAD WELL WITH CRW SW PUMP 250 BBL CRW SW PUMP 92 BBL DIESEL AND U-TUBE . READY FOR SLICKLINE 3/11 FRACTURING SET DV @ 5545' RKB. MITT (P) & MITIA(F W/COMMUNICATION TO TBG); PULLED DV& BRUSH POCKET @ 5545' RKB; SET DV @ SAME. MITT& MITIA (PASS). IN PRf(RI 3/12 FRACTURING PULLED CATCHER ASSEMBLY @ 9304' SLM; PULLED 2.75" CA-2 PLUG W/GAUGES @ 9326' RKB. LRS TO PERFORM 20 BBL INJECTIVITY TEST. READY FOR FRAC. 3/12 PUMPING INJECTIVITY TEST TRACKING PUMP 25 BBL DOWN TBG ONLY 1BPM = 1500PSI, 1 BBL PUMP AWAY 2BPM = 1800PSI, 4 BBL PUMP AWAY 2BPM= 2300PS1, 6 BBL PUMP AWAY 1.75BPM =2400PSI,10 BBL PUMP AWAY 1.50BPM = 2400PS1, 15 BBL PUMP AWAY 1.40BPM =2400PSI, 25 BBL PUMP AWAY JOB COMPLETE 3/19 FRACTURING PUMPED DATAFRAC AND 8 STAGES OF SLB BROADBAND FRAC. PLACED 597,902LBS OF DESIGNED 667,412LBS. FREEZE PROTECT WELL WITH DIESEL. 3/21 FRACTURING RIH WITH FCO BHA, LIGHT TAG @10905', CLEAN OUT TO 12990' USING SLICK SEAWATER, AND FLOW-VIS SWEEPS. AT ONE POINT WE WERE GETTING BACK ESTIMATED 5-10% SOLIDS AT THE TANKS. CHASED FINAL GEL PILL OOH @ 80%. FREEZE PROTECT WELL TO 2500' ****READY FOR SLICKLINE**** 3/22 FRACTURING TBG OPEN 2.71" DRIFT& BRUSH TBG TO 9800' SLM. SET 2.75 CA-2 PLUG & GAUGES @ 9326' RKB. IN PROGRESS. 3/23 FRACTURING ATTEMT TO TEST CA-2 PLUG @ 9326' RKB, BAIL FRAC SAND FROM TOP OF PLUG @ 9326' RKB, PULLED PRONG, 2.75" CA-2 PLUG BODY W/GAUGES, IN PROGRESS 3/24 FRACTURING SET 2.75 STANDING VLV© 9326' RKB, GOOD TBG TEST. PULLED DV @ 5546' RKB, LOAD TBG & IA WITH 238 BBLS DSL. SET OV @ 5546' RKB, PULLED DV's @ 4504' & 2719' RKB, SET GLV @ 4504' RKB. IN PROGRESS. (ALL LATCHES HEAVILY DAMAGED FROM FRAC) 3/25 FRACTURING SET GLV @ 2719' RKB, GOOD DRAW DOWN TEST ON IA, PULLED 2.75 CAT SV @ 9326' RKB. COMPLETE. • • • Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: 3/19/2016 Job End Date: 3/19/2016 State: Alaska "fir County: Harrison Bay / API Number: 50-103-20691-00-00 Frac Focus Operator Name: ConocoPhillips Company/Burlington Chemical Disclosure Registry Resources Well Name and Number: 2M-36 Longitude: -150.10163200CRC311�i DV`JATfR Latitude: 70.27151700 Datum: NAD83 ail&Gas Federal/Tribal Well: NO True Vertical Depth: 6,025 Total Base Water Volume(gal): 327,727 Total Base Non Water Volume: 0 Hydraulic Fracturing Fluid Composition: Chemical Maximum Maximum Abstract Service Ingredient Ingredient Trade Name Supplier Purpose Ingredients Number —oncentration in concentration in Comments Additive HF Fluid (CAS#) (%by mass)** (%by mass)** YF130FIexD:WF130 Schlumberger Surfactant,Breaker, Crosslinker,Low Temperature Fiber, Diverting Agent,Guar Slurry,Scale Inhibitor, Additive,Bactericide, Propping Agent Water(Including Mix Water NA 81.6281E Supplied by Client)* Ceramic materials and wares, 66402-68-4 94.25531 17.31641 chemicals Distillates,petroleum, 64742-47-8 1.58406 0.29102 hydrotreated light Guar gum 9000-30-0 1.46614 0.26936 Boronatrocalcite 1319-33-1 0.52023 0.09558 Ethylene Glycol 107-21-1 0.51314 0.09427 1,4-Dioxane-2,5-dione,3,6- 9051-89-2 0.38551 0.07082 dimethyl-,(3Rcis)-,polymer with '3S-cis)-3,6-dimethyl- Diammonium 3S-cis)-3,6-dimethyl- Diammonium peroxodisulphate 7727-54-0 0.36432 0.06693 2-Propenoic acid,polymer with 129898-01-7 0.19825 0.03642 sodium phosphinate • • Propan-2-ol 67-63-0 0.0813r. 0.01494 22-butoxyethanol 111-76-2 0.0813. 0.01494 Vinylidene 25038-72-6 0.0789: 0.01451 chloride/methylacrylate zopolymer Alcohol,C11 linear,ethoxylated 34398-01-1 0.0746 0.01372 Sodium hydroxide(impurity) 1310-73-2 0.0689: 0.01267 Magnesium oxide 1309-48-4 0.0621• 0.01142 C12-15 alcohol ethyoxylated 68131-39-5 0.0486 0.00894 Sodium tetraborate 1330-43-4 0.04381 0.00805 Amine treated smectite clay 68153-30-0 0.0407 0.00748 Sodium chloride 7647-14-5 0.0400• 0.00736 Calcium Chloride 10043-52-4 0.0202 0,00372 Fumaric acid 110-17-8 0.0136: 0.00251 3oric acid 10043-35-3 0.0136• 0.00251 Monosodium fumarate 7704-73-6 0.0136: 0.00251 Diatomaceous earth,calcined 91053-39-3 0.0085 0.00157 1-undecanol 112-42-5 0.0065t 0.00118 Silicon Dioxide 7631-86-9 0.0040 0.00075 Magnesium silicate hydrate(talc'14807-96-6 0.00241 0.00044 2,2"-oxydiethanol(impurity) 111-46-6 0.0021• 0.00039 Magnesium nitrate 10377-60-3 0.00171 0.00031 poly(tetrafluoroethylene) 9002-84-0 0.0010' 0.00019 5-chloro-2-methyl-2h- 26172-55-4 0.00091 0.00017 isothiazolol-3-one Magnesium chloride 7786-30-3 0.0008- 0.00016 'Magnesium stearate 557-04-0 0.0008: 0.0001E Oiutan gum 125005-87-0 0.0006: 0.00013 Potassium chloride(impurity) 7447-40-7 0.0006• 0.00012 2-methyl-2h-isothiazol-3-one 2682-20-4 0.0002: 0.00005 Acetic acid,potassium salt 127-08-2 0.0002• 0.00004 Cristobalite 14464-46-1 0.0001 0.00003 Quartz,Crystalline silica 14808-60-7 0.0001 0.00003 Oxirane,2-methyl-,polymer with 72283-36-4 0.0000• 0.00001 oxirane,mono-(9Z)-9- actadecenoate,methyl ether Acetic acid(impurity) 64-19-7 0.0000• 0.00001 Phosphoric acid,dodecyl ester, 39322-78-6 0.0000. potassium salt C13 alcohol ethoxylate 9043-30-5 1,4-Benzenedicarboxylic acid, 9016-88-0 0.0000. polymer with 1,2-ethanediol and a-hydro-w-hydroxypoly(oxy-1,2- ethanediyl) C12 fatty alcohol 112-53-8 2-bromo-2-nitropropane-1,3-diol 52-51-7 r s KUP PROD 2M-36 CnnocoPhiIbp$ ; Well Attributes • Max Angle&MD TD I, A)aska,IOC, Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) Carom l 7h, 501032069100 KUPARUK RIVER UNIT PROD 95.18 12,953.64 13,013.0 °°° Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2M-36,4/19/20162:16:29 PM SSSV:NIPPLE 95 11/21/2015 Last WO: 39.50 1/6/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date •'-------`-- ------------------- --- Last Tag: Rev Reason:FRAC roven 4/19/2016 HANGER;36.2 Y„/.Ty PP „,,,PP-au Casing Strings ,S �,_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).,,Wt/Len(L..Grade Top Thread CONDUCTOR 16 14.000' 38.3 131.0 131.0 164.82 A-106 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WILen(I...Grade Top Thread SURFACE 103/4 9.950 41.8 3,341.7 2,835.3 45.50 L-80 Hydril 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread XO Reducing;70.3 INTERMEDIATE 7 5/8 6.875 38.5 9,517.8 5,978.0 29.70 L-80 Hydri1563 -A-4,4 CONDUCTOR;38.3131.0 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 9,341.4 12,993.0 6,027.6 12.60 L-80 IBTM NIPPLE;516.2 Liner Details Nominal ID Top(ftKB) Top(TVD)MKS) Top Incl(°) Item Des Com (in) 9,341.3 5,929.1 69.68 PACKER BAKER HRD-E SLZXP LINER TOP PACKER-Q125 5.750 GAS LIFT;2,718.7 HYD 563 PIN 9,363.4 , 5,936.6 70.72 NIPPLE BAKER RS PACKOFF SEAL NIPPLE-Q-125 HYD 4.250 563 BOX X BOX 9,365.7 5,937.4 70.83 HANGER BAKER FLEX-LOCK LINER HANGER-0125 HYD 4.840 563 BAKER X PIN 9,376.8 5,940.9 71.35 SEE BAKERR 80-40 SEAL BORE EXT 4.010 SURFACE;41.8-3,341.7 9,751.4 6,020.6 80.73 SWELL BAKER SELF ENERGIZING REACTIVE SWELL 3.940 GAS LIFT;4,504.2 '; PACKER PACKER W/TORQUE RING Tubing Strings GAS LIFT;5,545.9ill" Tubing Description String Ma...ID tin) Top(ftKB) Set Depth(ft...Set Depth(TVD)(.,.Wt(Ib/ft) Grade Top Connection TUBING-4 1/2 x 3 3 112 2.992 36.2 9,388.8 5,944.7 9.30 L-80 EUE -1, 1/2@70.27 Completion Details SLIDING SLEEVE;9,271.4 I I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;9,326.5 36.2 36.2 0.15 HANGER FMC HANGER TYPE"H"BPV 3.958 70.3 70.3 0.29 XO Reducing Crossover 4-1/2"12.6 pp1 L-80 IBT-m x 3-1/2"9.3 ppt 3.000 EUE LOCATOR;9,358.4 5162 516.0 3.62 NIPPLE CAMCO DS NIPPLE 2.875 SPACER SUB;9,358.5 .' _1 9,271.4 5,903.2 66.89 SLIDING BAKER CMU SLIDING SLEEVE W/2.813 DS PROFILE- 2,812 SLEEVE RUN IN CLOSED POSITION I 80.40 TUBE;9,367.3 I ' 9,326.5 5,923.9- 69.02 NIPPLE CAMCO 3 NIPPLE 2.750 �, �� 9,358.4 5,934.9 70.48 LOCATOR BAKER GBH-22 LOCATOR ABOVE 2.88'FROM FULLY 3.000 LOCATED SEALS;9,377.4 9,358.5 5,935.0 70.49 SPACER SUB 80-40 SPACER SUB 3.000 80.40 TUBE;9,379.2 1 9,367.4 5,937.9 70.91 80-40 TUBE 80-40 spacer tube 3.000 9,377.4 5,941.1 71.38 SEALS SEALS 3.000 ■ i I 9,379.2 5,941.7 71.47 80-40 TUBE 80-40 spacer tube 3.000 INTERMEDIATE;38.50,517.6 - . Perforations&Slots Shot Dens Top(TVD) Bbn(ND) (shotslf ns Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 9,876.6 9,886.4 6,039.5 6,040.8 C-4,2M-36 -1/3/2015 PERFP 4 1/2"PERF PUP ,. 9,964.7 9,974.8 6,057.1 6,052.4 A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP 10,547.2 10,557.0 6,070.1 6,070.0 A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP 10,914.2 10,924.3 6,070.3 6,070.2 A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP PERFP;9,876.63,886.4 'Ai! 11,254.6 11,264.7 6,063.3 6,063.1 A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP 11,653.2 11,663.0 11,957.3 11,967.2 6,058.5 6,067.4 6,058.9 C-4,2M-36 1/3/2015 6,067.6 C-4,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP PERFP;9,964.73,974.8 :);e:. PERFP 4 1/2"PERF PUP I 12,443.3 12,453.2 6,065.7 6,065.3 A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP 12,627.0 12,636.8 6,054.7 6,054.0 A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP 12,961.8 12,971.7 6,030.4 6,029.5'A-3,2M-36 1/3/2015 PERFP 4 1/2"PERF PUP PERFP;10,547.2-10,557.0 4 .;il:, I Stimulations&Treatments Min Top Mae Btm Depth Depth Top(TVD) Btm(TVD) PERFP;10,914.2-70,924.3 ;rt). (HKB) (MO) (ftKB) (ftKB) Type Date Com 9,876.6 12,971.7 6,039.5 6,029.5 Sand Frac 3/19/2016 FRAC-PUMPED DATAFRAC AND 8 STAGES OF I SLB BROADBAND FRAC.PLACED 597,902LBS Mandrel Inserts PERFP;11,254.6.11,264.7 St :t.l. Sd on Top(TVD) Valve Latch Port Size TRO Run Sand Free;9,878.8 N Top(ftKB) (HKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn -i 2,718.7 2,503.7 Camco 156AF0 GAS LIFT GLV BK 0.156 1,331.0 3/25/2016 PERFP;11,653.2-11,663.0 • '..t,). 7 2 4,504.2 3,367.3 Camco 143AFO 1 GAS LIFT GLV BK 0.188 1,324.0 3/24/2016 7 3 5,545.9 3,887.5 Camco 140AFO 1 GAS LIFT OV BK 0.250 0.0 3/24/2016 - PERFP;11,957.3-11,9672 ' ,,:In: 7 111 Notes:General&Safety End Date Annotation 3/19/2016 NOTE: PERFP;12,443.3.12,453.2 331E 111 PERFP;12,627.0.12,636.8 - i:Ill) 1 PERFP;12,981.8-12,971.7 .3.1. LINER;9,341.3.12,993.0 `,OF TitF • • y/��s� THE STATE Alaska Oil and Gas F — � of e TT ASK A Conservation Commission tr{ _,_ 333 West Seventh Avenue '11)r".1-11167*- ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 + Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Completions Engineer ConocoPhillips Alaska, Inc. .NNED MM I U t P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-36 Permit to Drill Number: 214-102 Sundry Number: 316-155 Dear Mr. Klem: 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, f7'� Cathy P Foerster Chair DATED this 2(o day of February, 2016. RBDMS LL FEB 2 9 201 • 0 RECEIVED STATE OF ALASKA FEB 2 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 2-13‘ J 1 APPLICATION FOR SUNDRY APPROVALS AOGCC 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 Q • 214-102 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20691-00-00 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2M-36 Will planned perforations require a spacing exception? Yes ❑ No ❑., 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL025585, 25586 • Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13,013' , 6,027' • 12,993' • 6,027' - 5,095 Casing Length Size MD TVD Burst Collapse Structural Conductor 93' 16" 131' 131' Surface 3,299' 10-3/4" 3,342' 2,835' Intermediate 9,479' 7-5/8" 9,517' 5,978' Production Liner 3,652' 4-1/2" 12,993' 6,027' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attached schematic f See attached schematic 3.5" L-80 9,388' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): LEM Installation,no SSSV ' 9,341'MD/5,929'TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: r March 1st,2016 OIL ❑• 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 Adam Klem @ 907-263-4529 Email Adam.Klem@conocophillips.com Printed Name Ada lem Title: Completions Engineer aia 3 els Signature Phone 907-263-4529 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: PRE Prat, IA +est +b 3` 00 r s; . IR PRV set 4 l6Oors t 3\(..t. - 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Ery Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /t — 40 4 APPROVED BY RBDMS L v- FEB 2 9 2016 Approved by: /31/211.47.754...._ COMMISSIONER THE COMMISSION Date: Z- Z —/� �� se 20 z /40fiel/� A , i Submit Form and Form 10-4 3 e`�sed 11/2015 A liIpv+i a d for 12 months from the date of approval. Attac ments in Duplicate -Piti JJ C-F.! 2/Z!)2o(6 -- �Yf • • KUP PROD 2M-36 IF- Con000Pt$llips $ Well AttrIbutes Max Angle E MD TO duw.,,,in, ,/.1G 4P14141I {PIMP Kamer rml *Ad. PO0-4 Mt MKS) Ad et„ttmll r„ Myby 51 13;669':: IKUPARUKRIVER UNIT PP.00 55.42 1 15154 __ c961A4n1 net,r.'1.1 594 Amactaban boa dab K0-9*a`91 121 NaMMC,rtI ... -05,..,..-‘10,4.1741011121,4.:a.• 5SSY N!...E =ass VY- I .ea.0 w- Annan,,,•. E .:44 1 ... StIr1.. _,a:c es _,. F-c u x441411511,44.4 as.Tai.: Rev Rwsc P-.1::3,451T 3 GAUGES <Casing Strings Capin C sencosae '3H 4144 4Pt' 144111414S4 CAW:;PPE: 14T C4 .WC;.. *4Lart :Grat03 314 TTtaaa ❑ 11U 'C1NC OR 14.060 33.3 Ftn Caws C riFticm 58 555 D Sst 'T43 t1IK81 sof C.44P 7754e: tot Coctn 5r21 'attian,s-..Orae 'NS TTtsna SLIP;ArE2E�.�n��.� •:-34 4: 4'.3 2.34-7 :.5:3533 45.5__a: 41-474-::541 �C'NWIFt1ce 00 M: 8 5: 1222Iftnel set C.Ftf PK E; PI DOM jr5l-.. M{t..94644 114 PP. 6941.,6ea 4444 - ir INSEP41=140A'E -_ _ _~ 5.973 - -+r.-241 4s-P.,-P.,NM�.etaar aalsr:• _II y C Cotorlptior OC:1141 IC MI TCF:rho]; set 59145 It! 'sat Cafta tt.41... 444(4. ..s3M. tc4 TAwas URE 4': J 24'A 7270 4_1,41 41.41 T-E. 4. Liner Details T ''rt46: t: T _. T 1 944 r2„s_ 1Y� :'t =.3:_4 56_: c72 0==_ -A- , __.C.'" _ - _ 4. 5 3,355 a _� -.7 > E LC P 4.071 _ 4-0'D aa11aRICf.: 4399] •7_'4 .c.^ Y _ -- _ 2 F,__t.___ 1:45 - E, _ ... " _...,i 1144....irr 4$04.2 111 Tubing Strings PPP-PT 45.64 7'51 CMC¢dlCrt stria Pa.'I6 10 _.7:4 01K111 sat[4!1 5_ sat Cs2tP 7x1:..4.4 ttlrti J- 4.6,4 tc;Canssr e 3 i 4-:2�1 35.2 .=44' . EJE i Completion Details i.,..........,-..__ • I I 9:Tan6C T 22 .. 2222 _. L,.' is, .4A..4_c a ,. - _ _-t 3.956 I =s -_.- 92: 3:D05 ..c#-9K.azst. _4:2 5'4_ 352*0P._6_ ,--_= 2875 44444.414.14 asP :27i.4 5..3.e 55.33 SLIDING EA-4E .7'4 4.'__.3 53 2._J_-?. 2512 SLEEVE ._..V..,.-_-, .v.4 =s 11. _ 2.759 s aoa9,66;aat'.It 5 4 5 5341 __..:.r•P C. _:41..6112 74'1 1=o__' 3.DDD P44.4.371,4 5.225: 749 SPACER5345 22 2 3.305 9,401,56::T1= a 5.2574 5 137 1 77.9-.'5C44nUEE _:-. _ ._: 3.455 IIII 5._75.4 5.54'' 7=.33 SEAL° 16,__ :5:5 5.175.2 3:54'T.. 7 47 -4. - 3.D0: 1 I Perforations&Slotsilk scm Ixl'aime644 8.31.44.12 Data Ts no et,-,n¢; 134117 T.L;58E', err(rtKH, 'r..E.. ',ttKH; 5,4 CCP r T4.4 9.E74.6 3.5344 5115_ 0.i',3 4.251 6 520'5 PERFP 4 =EP=Pi= lir 39347 5.974: 47.:24 A3.241.6 <_. PERFP 4 2 747.2 '0.557.: 777 5.:707 A3 215.36 :321.5 PERFP c=E===__ .5'4.2 ,,9624.: 4 171 3 5.171< K3,29-i6 :12015 PERFP 4'_'=_ __,_ 254.5 `154.7 5 742 3 5 153_ A 29-36 -...1.2075 PERFP __ __ _ EEO5 4.25-l-36 -8'2035 PERFP 4._ 053.2 •...,453.: _. .. _ 7:557.3 1-9672 ': 575•4 4757.. 5-929-^36 '32515 PERFP 4';2 -._ '2443 33 '2 453.2 _755 7 .. 5 221.6 1412015 FERFP 4._=9=1 5__ - .627.0 `2616.5 5 154.7 _154. 4-529.36 7132915 PERFP 4 .:-_ '2,94 9 '2.57'.7 _..2:4 _._21.5 A-3.229-36 7,532515 PE4655 4•.2'==.= v= Mandrel Inserts it N4.;1,V qIq LACI Port ae TKO Kan K r.2':RKH: :'IKE, Maio 1/094 OC OM an 19Pa TX4 {11: 5965 P91 Dab Cr! aaana.'as*rr.9.c<s- 2.7'37 2 573 1:95511 '544"1 3A5 LIFT SLY EK 0.'54 '.295.0 3&2075 7 2 4.514.2 3.2$7.3.Crn.. '434.=: ' SASLIF7 SLY 6K 0./2 '.326.2 3362055 . 5545.66 ...470 C_m:_ '4:A ' SAS LIFT CV ES :251 6 3520'S 7 Notes:General&Safety ,. -_:: VCTE sws1261.0.12.44 I P441114,11.1111414/17.1.7- 8.4.4.44.401.312.11111.1.--- . • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). • • ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2M-36 Well Kuparuk River Unit, Alaska ADL 25586, KRU Tract 68; and ADL 25585, KRU Tract 69 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2M-36 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 18, 2016. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on leases ADL 25586, KRU Tract 68; and ADL 25585, KRU Tract 69 as depicted on Exhibit 1 as follows: Surface Location: 5167' FNL, 22' FEL, Section 28, T11 N, RO8E, UM Target Location: 3886' FNL, 1079' FEL, Section 29, T11 N, RO8E, UM Bottomhole Location: 2608' FNL, 4309' FEL, Section 29, T11 N, RO8E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Paul Wharton Staff Landman cc: Hanna Sylte Rebecca Swensen 2M-36 Hydraulic Fracturing Notice Letteel • February 18, 2016 Page 2 Exhibit 1 17Feb15 ConocoPhillips Alas•(?,Inc. ACL392e29 21u1-36 Lease Plat.. 3 0 1 0.3 0.45 OE ADL025571 ACL2S3533 251-13 T11N R8E 2351-z1 1-05 21-11 21-19 - 251-18 251-20 •. 2a-3E 24..10 'hi_ 6 a1-31 -,5r-3ePe1 25,-1e 6'7) """20:03•x-251-15 1 2M-23 1 ---- --- --- —.. ------ ADLO2 �--- i ti •:e 5.585 y7 ADL 25587 2i1-28 211-27 20-12 I 210-28 2x1-24 A 701 20-30. at.17 v1-22 • 25,-22 _ 251-02 251-09A 2v1-07 2M-14 251-3A 2�1-33 251-32 251-04" 251-32L1 PB1 251-08 251-09 M1-321...1P82 Ivl-32L1-01 `251.35 211L1 A • Frac Point ADL025.593 —Well Trajectory F jq1 ADL0.5589 Open Section T1ON R8E 0112 Mi.Radius - Well Within 1/2 Mi.Radius � ./ '51)Unit Tract Number i_KRU Boundary $ j_KuparukPA BRPC Lease QCPAI Lease 2M-36 Hydraulic Fracturing Notice Letter 40 February 18, 2016 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director TO TH•ASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2M-36 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton. I am have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On or about February 18, 2016, 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 18th day of February, 2016. ()4714- e • G1-41evz.7to� Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 18th day of February,2016, by Paul K.Wharton. STATE OF ALASKA 4, NOTARY PUBLIC NotaryPublic, State of Alaska REBECCA SWENSEN 4 My Commission Expires Aug.27,2016 My Commission Expires: • • Section 2 — Plat 20 AAC 25.283 (a)(2) Plat 1: 2M-36 Landowners 13f¢41: NConocoPhillips 2.r-3e AIas�ca. Inc, .�:_�Lsa2ECa 1 _ease P':a: Ewes tlie Ant __ 21 ACt..2gCFC3 \ \ \ o ; 2'M-13 s( ""m".".."4*.%. * s RSE ti2t#-'21 w \ \\\\26-:‘,11\ ` °! ' 26 I,-,0 20-36 214.05#s sCaL72556t 67 ......."0711.--- AC L 15557 26128 261-27 29-25 -td-12 { t0'2c 2M-2# ,..-- V , /1:71/ 2M-17 —..-,- 33 as 231-4 / '' aii'lagia' \ - - fiif li26t 14 ,_ , . i 3M-33 2 2L Pa12Mja78 apaziiiii ` '"+Y ' .''1„1...0n ,V �,/° '`--- 5 f i 4 3 E r ! • Frac Point C - JWeil Trajectory -V.' X585 Mb open section TIM''. Q 1/2 Mi.Frac Point Radius _ Well Within 112 Mi.Radius _ ,!unt Tract Number L_KRU Boundary a .1 s �J Kuparuk PA, D BRPC Lease D CPA!Lease i • Table 1: Wells within .5 miles WELL NAME API Drill Site STATUS WELL TYPE 2M PERM 1 509993001600 2M PROP OBS 2M-01 501032018500 2M SUSP PROD 2M-02 501032017900 2M ACTIVE INJ 2M-03 501032016000 2M ACTIVE INJ 2M-04 501032018200 2M ACTIVE INJ 2M-05 501032016800 2M ACTIVE INJ 2M-06 501032017600 2M ACTIVE INJ 2M-07 501032017800 2M ACTIVE PROD 2M-08 501032018400 2M ACTIVE PROD 2M-09 501032017700 2M PA INJ 2M-09A 501032017701 2M ACTIVE INJ 2M-10 501032015700 2M ACTIVE PROD 2M-11 501032015900 2M ACTIVE PROD 2M-12 501032018100 2M ACTIVE PROD 2M-13 501032016100 2M ACTIVE PROD 2M-14 501032017300 2M ACTIVE INJ 2M-15 501032015400 2M ACTIVE PROD 2M-16 501032015300 2M ACTIVE INJ 2M-17 501032015000 2M ACTIVE INJ 2M-18 501032015100 2M ACTIVE INJ 2M-19 501032015800 2M ACTIVE INJ 2M-20 501032016900 2M ACTIVE PROD 2M-21 501032015600 2M ACTIVE PROD 2M-22 501032017000 2M ACTIVE PROD 2M-23 501032015500 2M SUSP DISP 2M-24 501032017100 2M ACTIVE PROD 2M-25 501032015200 2M ACTIVE PROD 2M-26 501032017200 2M ACTIVE INJ 2M-27 501032017500 2M ACTIVE INJ 2M-28 501032017400 2M ACTIVE PROD 2M-29 501032018300 2M ACTIVE PROD 2M-30 501032018000 2M ACTIVE INJ 2M-31 501032024100 2M ACTIVE INJ 2M-32 501032018600 2M ACTIVE PROD 2M-32L1 501032018660 2M ACTIVE PROD 2M-32L1-01 501032018661 2M ACTIVE PROD 0 0 2M-32L1PB1 501032018670 2M PA EXPEND 2M-32L1PB2 501032018671 2M PA EXPEND 2M-33 501032024000 2M ACTIVE PROD 2M-34 501032024200 2M ACTIVE INJ 2M-35 501032024300 2M ACTIVE INJ 2M-36PB1 501032069170 2M PA EXPEND • • SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. ,,/ See conclusion of the Aquifer Exception Orc r No. 2 — Milne Point Unit. Which states "Those portions of freshwater aquifers lying dire ttS below Milne Point Unit qualify as exempt freshwate.raquifers under 10 AAC 25 40" / Ai‘.i 7<4fiNflil1144. 'ioci / a» /09.-a) (3i) K " /"_J-/) 7AAcs. vn ilvc 410/ VfrsbG. 1'41 fY1'A &PLCA. 136rAci claNd Iiil, ci•\raity dy.,/, _g, xue,,,,Ax i .ivt, U n i I- Ori o..% cit"..c r Tt L.J . ?u?7 • • SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. • • SECTION 6 — ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(a)(6) Casing & Cement Assessments: The 10-3/4" casing cement pump report on 11/16/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg class G cement and 12 ppg class G tail cement. The plug bumped at 1,060 psi and the floats were checked and they held. The 7-5/8" casing cement report on 12/19/2014 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 2,300 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 11/18/2014 the 10 & 3/4" casing was pressure tested to 3,000 psi. On 12/21/2014 the 7 & 5/8" casing was pressure tested to 3,500 psi. A 1,, The 7 & 5/8" casing will be pressure tested to 3, psi prior to frac'ing. I r eS The 3.5" tubing will be pressure tested to 4,000 psi prior to frac'ing. 3 % do fs\ 2/23/20/‘ Gt.1C t�twf,n) )V ts : -CO 9 pS ; 9 S - iff1, t 1754,r /11 M 35 ad t �+ tri) = 3•44) . 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/" 45.5 L-80 2,090 psi 3,580 psi 7 & 5/8" 29.7 L-80 6,890 psi 4,790 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings 0 • Stimulation Surface Rig-Up i 2 Seed/Tette Tale Teta 1:4 11-::II t:1110 0 yr A • Minimum pressure rating on all surface 101114.11 OC-0811 lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure _ • IA parallel PRV set to 3500 psi Q3 g • Frac pump trip pressure setting are staggered and set below main treating line PRV • Tree saver used on all fracs rated for 15,000 • = psi. • � 4 a- 1!( m xul dund Pap-Of Tar* m`m c w . d OCA Pump Truck Pap-JB Tank ,,,,N Z>'7- 7 H `1 4l N 50310 Frac Pump -NI -' 1"-.1 Frac Pump Frac Pump m `,:-.:<_.1:.. rr.,1 Frac Pump Frac Pump Nal :(j, .:_.. le I Frac Pump • • Stimulation Tree Saver OPEN PosmON CLOSED POSmON (PRIOR TO MANDREL INSERTION` (MANDREL INSERTED) 11/,,FRAC IRON . ,, i r4 f n . i r " i .,r , " r MATER ALERA VE TEO r ....m........ 111 IP" 107,„1111. *04 ii i + 4i MANUAL OPERATED I 414 r r, MASTER VALVE tOt1=.Lr i O it • AiiiiiIM I t Stinger MANDREL i MI L • .,..51 ,, i,..2 A ENT `�` ""GY 1�.,VALVE -I- , .. iOPEN ; :! ■� �y �n� ii%i /I/r.` !� ,ir 17:410 '"' , '1'., \# t PLOW TEE ANO 1 i VENT VALVE 1VELl VALVES IVES i: on'X4 OPEN`- : ,, (fit L , ,: ., It k b is 'II \ CLOSED -i ' . '-'/ .. 4 1k-'.1 ` 4 d, at \v, mu)PACKOff ':'- L,'- ....,A" ASSEMBLY IN 'I' ... PLACE IN TURING N. TUBING �//i r r t 1* • • Wellhead .. , III _...... '',.. Ii7 II lb, /13_11' J ,,, i 1 1 A PARR / ' I I m).• i . /1.11-51140 0&01!TI L atIe i 11,6;dp, ---,..114100 1101111 100 110 iIict riLli T19.1 '10•00.7,' • . :4 I wromX.3.3 it... t i II1Wp \\,?....._....di), V.S43 .........".„, II-!i 4-201 141.3 i ,.., ..„--LIver010 VW :1'1421 II Mir ..,-Imi Min I- -,...:,--11.6400 011401 1.0IT-:' IIII i --5111111. in ing r4 -non mil 1/4 V 1,g,t. It.5, , 1t_ct. if.C.5 • ._•"•• e • .-•AT ! 46f:4NM ir..miv:11...'' .,lic-i;wk.,t1 I i:: . "ir •-•,' ::: I -- I'll':-Cjil I 4. . . a ,.,, ...----14:02%.:0411101111E11.taillr 3771. - ___-- az vis My*101010 Iii 4 11_15v . --TM 0110T ,............. ill IZIir=m7.- WTI,EN 1W!1-0 It ILI I ! IIII --VIVI i swam 110001:I.FLArti,45 I - .,._---- V/33.31.1 I _ I'S MIS 1si I: .•: 77.00 -= 5.174 I I;C:;/'.111L- _ 3,15 Aro' r2.4 •-.. 1 -- E .01.1,0...1,-+Mto01,Da ,.......-Liddei N•0112.16.toci..214.•11.3.. -- 101-1TELOW Ft ILI,VAL ILIS 01 VV. 7171 1_ 1 ------- tC4 1:04r11.:11rorti"'siren I I 1 i.p..UM 0101. iii IV al tallua 717 10 1,0'V{AYH 1 Lil•tie-.41. - ..... 3 Pill(ISIS 0 F kg t, AILAOXA - GEN 5 LC) 16 X Is 1/4 X 7 5/5 X 31/2 *VIII stenrt 0 ram r.,-. tin 0101.199/111 INIVIV41— f•xlv.TE 1110 CtiFIIINTIoL .C11114 0•000erta. 0 A tosr-II sJ1FACE IIELLEA3 LAY3JT, (---, •.1...00.041........."pt=v..r. 1K TIMDIFIL1179 WANE a gmak 0.1.•••”.•4- .....11• . ............. .....M...3.3 31. rt -- um Hamm cavcIALL5p ,----- 1 -.......— =11,.'1%74:1;r"""""•::: — vua WC _. 1•9=7".""r/Ar'.". M111.1•100/101•011f IMIIIIMNIRSIMit Oklkilll CAII3017C510 cs'-- s • SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone consists of both the Kuparuk C and the Kuparuk A sands. The Kuparuk C sand interval is approximately 22' TVT at the heel, with the top of the Kuparuk C at 5882' TVDSS (9769' MD). The Kuparuk A sand is approximately 84'TVT at the heel (based on offset 2M-01 wellbore, as the base Kuparuk A sand are not penetrated in the 2M-36 well), with the top of the Kuparuk A at 5922' TVDSS (9469' MD in 2M-01). The Kuparuk C interval is composed of medium to fine grained sandstone interbedded with mudstone, siltstone, and local sideritic ironstone. The estimated fracture pressure for the Kuparuk C is 13.1 ppg. The Kuparuk A sand is composed of multiple packages of very fine grained, quartz rich sandstone, separated by laterally continuous shale interbeds. The estimated fracture pressure for the Kuparuk A is 13.1 ppg. The overlying confining zone has an overall thickness of 362' TVT (946' MD) and consists of HRZ and Kalubik mudstones. Top HRZ was encountered at 5520' TVDSS (8823' MD), The estimated fracture pressure for the overlying confining layer is 16 ppg. The underlying confining zone consists of the Miluveach interval, a marine shale, approximately 500' TVT (based on offset 2M-01 wellbore, as the Miluveach was not penetrated in the 2M-36 well). The estimated fracture pressure for the Miluveach is -15.5 ppg. The top of the Miluveach is located at approximately 6000' TVDSS at the heel (9577' MD in offset 2M-01 well). 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 confining zone for the 2M-36 frac can be defined as the 1/2 mile radius along the 2M-36 wellbore from the production packer to TD. The plat in Section 2 shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on the cementing records of the following assessments wells, the mechanical integrity of those wells 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: 2M-01: The cement report on 6/14/12 shows that parent wellbore of 2M-01 was plugged. An attempt to sidetrack the well failed so the well is currently plugged and suspended as per AOGCC regulations. 2M-36PB1: The cement report on 12/5/2014 shows that 2M-36PB1 was plugged and abandoned as per state regulations. • S SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are 5 mapped faults that transect the Kuparuk C and A interval and enter the confining zone within one half mile radius of the wellbore trajectory for 2M-36. One fault intersects the 2M-36 wellbore and terminates in the C-37 interval. The C-37 interval consists of shale, siltstone and sandstone lithologies with an estimated fracture pressure as high as -16 ppg. No losses were observed at the fault crossing during drilling of the 2M-36 lateral section. Two faults within the AOR terminate within the confining layer, and two additional faults terminate within the C-37 interval. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. Thickness and fracture pressure for the confining layer is discussed in Section 9. 2M-36 Faults MD SSTVD Throw Fault#1 (A3/A2) 11488' 5917' 45' (DTE) Table 3: Fault Information The effective fracture half-length is estimated to be 356'. All of the fractures will be transverse to the 2M-36 wellbore. Distance of the projected fracture wings to the nearest fault that does not intersect the 2M-36 wellbore is approximately 1200'. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. 410 Plat 2: Fault Analysis E� 13f%btE --------------._._._._._._ ConocoPhillips ant- a Alasa.Inc. Fault Analysis Plat 3.1E 2�1 Tt1N R6E i� 2M-G1 1.f!2s2v • Frac.Point —Fault Within Confining Zone T10.1 R8E ADL 5E Abandoned Well Within 112 Mi.Rad.us Rd7L02558D `vVer within 112 Mi.Radius —Welt Traectory D 112 Mi.Frac Point Radius Q 112 M.Radius i s KRLI Boundary ( Kupanrk PA 9 BRPC Lease DCPAI Lease e .' LI oo v a a N = o0 m a" Q G o m z 13 A 2 N L � a „ 3 v E w o $ E A u A r V' a y, m a E m o v a O E m m E , c N a ti £ H 1 a x n u v n m N m of c @1 z. w m m a o a m co v w t74E V E N D V vi U 0 I- «a L O S N A O. = to" N W t. .a = E tom Z0. ` a a Z. v o a a w O` `w « T a 9 W W d E a u 1 — — — n 0 u u u r O c d N IC' mO i. V 0 N n N m O v v P.• a) • > a) d m 10C E lJ p ov L o m m m m O S' r a as aJ =O m -15.. o O O G v le o a .+ r O CO E a o N f m a z m ;F+ V G oi. m N n 6 a..) r = 0 Vro 'CoCC m Ln `n i, LL V N I-• o as N H d N lil • 0 Z N i O Mi 04 2 3 N N • 1110 SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2M-36 was completed in 2015 as horizontal producer in the Kuparuk A and C sand formations. The well was completed with 3.5" tubing and a 4.5" liner with 10 perforated pups. After pumping each stage, we will pump a "Broadband" pill that plugs off the near wellbore with dissolvable material, allowing a new fracture to initiate in a new perforated interval. Proposed Procedure: Schlumberger Pumping Services: (A & C Sand 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. 8,149 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 40 bbl injection test (WF127 27# linear gel) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 30 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 5,095 psi. III 411 N N O N O Y N OO� N O O O O O ON O Q O Y Y V N O Y N e N N N N N10O YN O N O O ONO YN O YN O F,E--mN oYONN..VdVNN0'YO0ANga,..t,«00f0..,NNm-, ep<[O a TN YNMEo00— mNry 00 . . . . 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''' 44mcoi I Oi i 001! gg i ...........................OWWWWWWQM ''' 4 i i' '° A 0 .. ... ... 22, 22,122Z8St322P.,igr!AP°27,g2322,%222;; LW '!L1111 k'' ''7,3;; '!, E ‘; i ,-4 ' i: ''0Q • • Client: ConocoPhillips Alaska Schlumberger Well: Basin/Field: Kuparuk River Unit State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 3/20/2016 Date Prepared: 2/15/2016 1:59 PM Report ID: RPT-41428 Fluid Name&Volume Additive Additive Description Concentration vcr'ec c F103 Surfactant 1 Gal/1000 Gal 330.0 Gal J475 Breaker 9.6 Lb/1000 Gal 3,150.0 Lb J604 Crosslinker 2.5 Gal/1000 Gal 810.0 Gal J622 Low Temperature Fiber 1.7 Lb/1000 Gal 550.0 Lb YF127FIexD:WF127 327,600 Gal 1660 Diverting Agent 5.3 Lb/1000 Gal 1,750.0 Lb J891 Guar Slurry 6.3 Gal/1000 Gal 2,050.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 650.0 Gal M002 _ Additive 1 Lb/1000 Gal 330.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 108.0 Lb S522-1620 Propping Agent varied concentrations 670,000.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* "'79 % _ 52-51-7 2-bromo-2-nitropropane-1,3-diol <0.00001 % _ 64-19-7 Aceticacid(impurity) <0.0001 % 67-63-0 Propan-2-ol <0.1 % 107-21-1 Ethylene Glycol <0.1 % 110-17-8 Fumaric acid <0.01 % 111-46-6 2,2"-oxydiethanol(impurity) <0.001 % 111-76-2 2-butoxyethanol <0.1 % 112-42-5 1-undecanol <0.01 % 112-53-8 C12 fatty alcohol <0.00001 % 127-08-2 Acetic acid,potassium salt <0.0001 % 557-04-0 Magnesium stearate <0.001 % 1309-48-4 Magnesium oxide <0.01 % 1310-73-2 Sodium hydroxide(impurity) <0.01 % 1319-33-1 Boronatrocalcite <0.1 % 1330-43-4 Sodium tetraborate <0.01 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 7447-40-7 Potassium chloride(impurity) <0.001 % 7631-86-9 Silicon Dioxide <0.001 % 7647-14-5 Sodium chloride <0.01 % 7704-73-6 Monosodium fumarate <0.01 % 7727-54-0 Diammonium peroxodisulphate <0.1 % 7786-30-3 Magnesium chloride <0.001 % 9000-30-0 _ Guar gum <1 % 9002-84-0 poly(tetrafluoroethylene) <0.001 % 9016 88-0 1,4-Benzenedicarboxylic acid,polymer with 1,2-ethanediol and a-hydro-w-hydroxypoly <0.0001 % (oxy-1,2-ethanediyl) 9043-30-5 C13 alcohol ethoxylate <0.00001 % 9051-89-2 1,4-Dioxane-2,5-dione,3,6-dimethyl-,(3Rcis)-,polymer with(3S-cis)-3,6-dimethyl- <0.1 % 10043-35-3 Boric acid <0.01 % 10043-52-4 Calcium Chloride <0.01 % 10377-60-3 Magnesium nitrate <0.001 % 14464-46-1 Cristobalite <0.0001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001 % 14808-60-7 Quartz,Crystalline silica <0.0001 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001 % 34398-01-1 Alcohol,C11 linear,ethoxylated <0.1 % 39322-78-6 Phosphoric acid,dodecyl ester,potassium salt <0.0001 % 64742-47-8 Distillates,petroleum,hydrotreated light <1 % 66402-68-4 Ceramic materials and wares,chemicals "'20 % 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 0 Schlumberger 2016.Used by ConocoPhillips Alaska by permission. Page:1/2 S I Client: ConocoPhillips Alaska SchlumbergerWell: 2M-36 Basin/Field: Kuparuk River Unit State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: 3/20/2016 Date Prepared: 2/15/2016 1:59 PM Report ID: RPT-41428 CAS Number Chemical Name 68153-30-0 Amine treated smectite clay <0.01 % 72283-36-4 Oxirane,2-methyl-,polymer with oxirane,mono-(9Z)-9-octadecenoate,methyl ether <0.0001 % 91053-39-3 Diatomaceous earth,calcined <0.01 % 125005-87-0 Diutan gum <0.001 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1 % otal 100% "Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2016.Used by ConocoPhillips Alaska by permission. Page:2/2 • c co Go a) U � 0 c p 2 co 0 if Ljt- _. n a) L c3) m co 0- Il co M 2 N • 1 CU a�-+ I j 1 CD � 4-J -I--)-I--) 4--+ aCU CI) te.+ ate-+ Q- J J J _) _J j J J J F> 0 ° O 0 0 O O 0 O _ .0 '', _0 }I L L L L f: L '; L L S— C C CO CO CO CD CD ( CD; CD CD to O D U U U U' U U= C240000000 CL N N N N N N i N N . O l 1.0 C.0 kD LO LD LO L CL I %-I T-I r-I %-1 0 0 0 0O 0 0 0 0 0 Ln CO CO 00 O rn m m m m r1 CD Iti IA VII kri E . z. 7 2 M .112 3 J21 iii 0) 0000000000 ` N m m m m m m ; m m m; m CD 4 1- Ce a) Q 1 0) citi E I CU 0 = i t 0 _ 0 0 „ 0 0 0 0 Xs XIX X X ' XIX X x = a� a� a, v a, a a a U)...„ CIO ›.. � ° LL N N N N N N N N NI N N ' N N N ' N N N N ; ri ' r-I CO L. '3 .-1 .—i %-I i %-11 %—ii r-i %—i %-I i u LL vlia LL LL I LL` U- : U- ' LL LL U- " 0LL LA. >- ' >- ›- ›- } Mi i m 44 E a, U 0 CO o CD CO CD CO CD CD CD CD Q r-I N m 1-11 CO CO CL a CU ao ra • • ,� — O � N 0 O ca O M • om0 c > a)-- , I() r O C� �5 -0 CO ge i � � 0 >' C •� (n N E /1 O O Lo to O 'L a) • V J to (O M % � •V O 'er L = fn _ -�-- Cl) p O (n ,0 (6 I ' l l ' o O ,Q. O o_ U (1) c3) = = E I ' Ci) }' 0 c OUB 73 Ca O 13) J _ s u) ON = (n O 7:3 > E �= —:13 ,,,, ca p11 • Q••- CO ca •— m L G) g m 6 E .2 a) � ° -0 4-, 1 2 � • v 0) ' o 2 - • �•- 8= 0ra. Z _oo = - ' 'vvi Li. LI- d >+ -0 C ) L N CO (n - - . = co O c 'O w O s- ci cr. -) L- .C. E =a) 4) f z 75 CD •_ •C L O > •E O V) V) 'a) O O •0 I • S SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. 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From: Klem, Adam [mailto:Adam.Klem@conocophillips.com] Sent: Tuesday, February 23, 2016 3:43 PM To: Wallace, Chris D (DOA) Cc: Loepp, Victoria T(DOA) Subject: RE: Sundry 316-155 Well KRU 2M-36 PTD 2141020 Frac treatment Chris, My apologies. We will pressure test the IA to 3800psi, and hold 3500 psi on the IA during the frac.The IA popoff will be set to 3600psi. From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent:Tuesday, February 23, 2016 3:36 PM To: Klem, Adam <Adam.Klem@conocophillips.com> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: [EXTERNAL]Sundry 316-155 Well KRU 2M-36 PTD 2141020 Frac treatment Adam, We are in the process of reviewing the Sundry Application received by AOGCC on February 23, 2016, with a stated estimated date for commencing operations of March 1, 2016. I read an IA backpressure will be held between 2500 to 3500 psi. I read the IA will be tested to 3500 psi. This doesn't satisfy the test to >110% requirement. IA popoff value is not stated. Please advise of any revised numbers. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. 1 a l l-1-102.. o255y9 ConocoPhillips TRANSMITTAL CONFIDENTIAL VA IA FROM: Sandra D. Lemke,ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 2M-36, 2M-36 PB1 DATE: 06/09/2015 Transmitted_ n 1 Kuparuk River Unit, Alaska 2M-36/2M-36PB1 Li a iss ,( 64-(A 1v f _'T LAS ads'44 1 CD and 1 hardcopy report ��' j r Revised-portion of the log display missing in original distribution- Halliburton-Surface data logging and End of l Well report- mud logging data for 2N-36/2N-36PB1; 01/06/2015; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 each for 2M-36 and 2M-36PB1 n H Formation Evaluation 2" MD a 1Gas ratio 2"MD il Drilling Engineering 2" MD D 11 n I 11 Please promptly sign, scan and return electronically to Sandra.D.LemkenaCOP.com il ii H CC: 2M-36 transmittal folder, production well files, eSearch RECEIVED OP • -ILL , 31 2015 Receipt: - Date: (----- AOGCC ...w....„-, GIS-Technical Data Management I ConocoPhillips !Anchorage, Alaska I Ph: 907165.6947 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Sat*Ep JUL 1 6 2015 June 22, 2015 Commissioner Cathy Foerster a 6) '9—(4 ` Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100QOP• ✓ Anchorage,AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement(one with carbolite) and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, 4/y MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 6/22/2015 1E,1Y,2E,2F,2M,2N,2V,3N&3S Pads Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 1E-32 50029227880000 1971320 15" na 15" na 1.8 6/18/2015 1Y-10 50029209340000 1830510 36' 3.70 13" 5/10/2015 4.6 6/20/2015 2E-02 50029235170000 2140780 9' 0.60 24" 6/14/2015 5.1 6/16/2015 2E-03 50029235090000 2132030 4' 0.62 7" 6/13/2015 3.9 6/16/2015 2E-04 50029235050000 2131680 10' 1.29 19" 6/15/2015 7.7 6/16/2015 2F-20 50029227390000 1970160 6' 0.80 13" 4/20/2015 3 6/20/2015 2F-21 50029223525000 2141360 22" 0.10 22" 4/25/2015 15.3 6/19/2015 2F-22 5002923530000 2141500 64" 1.10 17" 4/25/2015 11.5 6/19/2015 2M-36 50103206910000 2141020 8'7" 0.70 10" 5/23/2015 2.1 6/20/2015 2N-322 50103206780000 2131790 13" na 13" na 2.5 6/19/2015 2V-02 50029210370000 1831610 11" 1.00 14" 5/20/2015 2 6/16/2015 3N-11A 50029215800100 2120950 34' 27 cu.ft carbolite 10" 5/26/2015 2 6/18/2015 3S-620 50103206950000 2141670 6'3" 0.60 12" 4/26/2015 2.6 6/18/2015 Guhl, Meredith D (DOA) From: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com> Sent: Wednesday, May 27, 2015 2:13 PM To: Loepp, Victoria T (DOA); Guhl, Meredith D (DOA) Cc: Lee, David L; Ruff, Chris A Subject: correction to completion report for 2M-36 Victoria and Meredith — We have noticed an error on the completion report for 2M-36 dated 1/22/2015. Should we re-submit a corrected 10-407 or will an email suffice to correct this error? The geologic marker for Kuparuk C4 should be 9769' MD /6023' TVD. Please let us know what we can do to correct this. Thank you, Sharon 263-4612 scANNED JUN 3 0 2015 1 { 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 b direct inspection of the file. _ L4 - L 0 a Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed 7RE AN: OVERSIZED: NOTES: Co r Items: ❑ Maps: Grayscale Items: Vpogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: te5NO Date:542 1//3"-- /s/ 17, p Project Proofing BY: CM2.i.a..„) Date: //c !/J5 ' /s/ t44P Scanning Preparation 7 x 30 = a /o + 3 =TOTAL PAGES a 13 6 ! r (Count does not include cover sheet) BY: Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: a 1 (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES 1/N� /O BY: 41:0 Date: c J` p--1 /v /s/ i V I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO F BY: Maria Date: /s/ Stage 2 Additional Well Reports: elirNO TOTAL PAGES: l2 Digital version appended by: Meredith Michel Date: ✓/9A 11 S isi Final Page Count: Stage 1 + Stage 2: TOTAL PAGES:a% Scanning is complete at this point unless rescanning is required. 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O O J C. C m = CO D E /� O 2 U U 1 u Om c I � j r c,„9O co G �'I O _y M 1 O N a1 1 U U ZJ C (;) } \ }\ E < C o ) E a m N o E 0 I I—C_ t m o C Z o m m c z, N 0 N co CO > «: ° m E I tt c ° 1— E • wc r A Q p co m c coD a ° Yo m c °a Q G n o m O Eo 175 L > E 5 2 0 I A c� Z u) 1 I I N `y 10 m m -° co N p co C z N N 0 To r O \Z) LO 1.0 O O 10 �`}> ' �} ,— aO o p o E O `v c �� T 01 > 1 up u) ›- li o CO cn 10 (0 iTi Er N N 10 0 O O N m W ▪ w- N_ m S I E a) Z N N x ami N •- r) I CO 1° O w co m V p m c m 4 p w Z H c c Z c co C ° p m Q o ° Q o 3 O « c 7..)c U 0 o J C c..)N y ' m !_ U E �O n ' ° ° ( OE 0 o ° o w E o dd p p om a? o 2 a) 0 aGm 0 a 0 0 0 0 0 2 W RECEIVED �l �'-/02 2536i/ MAY052015 S cblumberg er AOGCC Transmittal #: 05MAY15-SPO2 Drilling & Measurements MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2M-36 PB1 **REV-1** Date Dispatched: 5-May-15 Job#: 14AKA0178 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A VISION*Service 2" MD x VISION*Service 2'TVD x VISION*Service 2'TVDSS x VISION*Service 5'MD x VISION*Service 5'TVD x VISION*Service 5'TVDSS x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A Nad27 x As-Built Survey N/A Contents on CD N/A Nad83 x CD 1 Contents on CD N/A Data: DLIS/ASCII **REV-1 > Data Files+ GR*' Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a)conocophillips.com AlaskaPTSPrintCenter(aslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 A,T01307 ^—r (/7/, Received By: !)�� `� Guhl, Meredith D (DOA) From: Elgarico, Richard E [Richard.E.Elgarico@conocophillips.com] Sent: Monday, May 04, 2015 1:40 PM To: Guhl, Meredith D (DOA) Cc: Lemke, Sandra D Subject: RE: KRU 2M-36, PTD 214-102, PB1 Vision Data Meredith, Schlumberger says they have the final files ready and should have them redistributed by tomorrow. Ricky Ricky Elgarico Well Data Associate Technical Data Management Alaska IT (907) 265-6580 From: Elgarico, Richard E Sent: Monday, May 04, 2015 12:32 PM To: 'Guhl, Meredith D (DOA)' Cc: Lemke, Sandra D Subject: RE: KRU 2M-36, PTD 214-102, PB1 Vision Data I sent a follow up inquiry to Schlumberger and will let you know as soon as I hear back from them. Ricky Ricky Elgarico Well Data Associate Technical Data Management Alaska IT (907) 265-6580 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, May 01, 2015 1:55 PM To: Elgarico, Richard E; Lemke, Sandra D Subject: [EXTERNAL]RE: KRU 2M-36, PTD 214-102, PB1 Vision Data Ricky, Have you received the revision yet? Makana is still getting caught up on the backlog from her vacation and I want to make sure it doesn't get missed before I go on vacation. Let me know,and if Schlumberger hasn't sent the revision yet could you please ask them to direct it to me on the transmittal form please? Thanks, Meredith From: Elgarico, Richard E [mailto:Richard.E.Elgarico@conocophillips.com] Sent: Wednesday, April 22, 2015 10:11 AM 1 To: Guhl, Meredith D (DOA); Lemke, Sandra D Subject: RE: KRU 2M-36, PTD 214-102, PB1 Vision Data Good morning Meredith, I have found the field data for this 2M-36 PB1 well and I have verified that it has GR. I can send you a copy of it but this file will have wrong well name and wrong API since it's field data. I have contacted Schlumberger and they are redoing the logs and will be sending a revision to everybody soon. Ricky Ricky Elgarico Well Data Associate Technical Data Management Alaska IT (907) 265-6580 From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Thursday, April 16, 2015 1:54 PM To: Lemke, Sandra D; Elgarico, Richard E Subject: [EXTERNAL]KRU 2M-36, PTD 214-102, PB1 Vision Data Hi Sandra and Ricky, I'm having a bit of a problem with the .LAS and .DLIS files for PB1 Vision data for KRU 2M-36, PTD 214-102.The printed logs show GR values but neither the LAS or the DLIS file has GR values reported in them. Can you help with this, please? Thanks, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Thursday, April 16, 2015 1:54 PM To: 'Lemke, Sandra D'; Elgarico, Richard E Subject: KRU 2M-36, PTD 214-102, PB1 Vision Data Hi Sandra and Ricky, I'm having a bit of a problem with the .LAS and .DLIS files for PB1 Vision data for KRU 2M-36, PTD 214-102.The printed logs show GR values but neither the LAS or the DLIS file has GR values reported in them. Can you help with this, please? Thanks, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1 214102 25544 ConocoPhillips 25545 TRANSMITTAL RECEIVED =GO L DATA 47r- G fif,(i MAR 19 2015 FROM: Sandra D. Lemke, AT03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC AOGCC P.O. Box 100360 333 W. 7`h Ave., suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 DATA LOGGED RE: 2M-36, 2M-36 PB1 M.K.BENDER DATE: 03/18/2015 Transmitted: Kuparuk River Unit, Alaska 2M-36/2M-36PB 1 1 CD and 1 hardcopy report Halliburton-Surface data logging and End of Well report- mud logging data for 2N-36/2N-36PB1; 01/06/2015; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 each for 2M-36 and 2M-36PB1 Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeC&COP.com CC: 2M-36 transmittal folder, production well files, eSearch Receipt:"4424"<-4) O..esc4ie: 1111 , GIS-Technical Data Management I ConocoPhillips 'Anchorage, Alaska I Ph: 907.265.6947 • REG JJVED 2 1 41 n 2 2539Z_ Schlumberger " -O C(ITransmittal#: 10FEB15-SP03 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 2•I t�i2o1 K. BEND R Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2M-36 Date Dispatched: 10-Feb-15 Job#: 14AKA0178 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A PTS Answer Produc SonicVISION BestDT x x 3350-9446ftMD LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf 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:StephanieniPacillo 907-265-6189 AT0 1707 ()/) 4) k._ 15..k _ C Received By: !! v RECEIVED 2 1 4 1 0 2 FEB 10201 2539 Schlumberger AOGCCTransmittal#: 10FEB15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery 2it‘v2oij fv1.K BENDEER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2M-36 Date Dispatched: 10-Feb-15 Job#: 14AKA0178 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2"TVD x x VISION*Service 5'MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x _ Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a)conocophillips.com AlaskaPTSPrintCenter(aslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 , 6,-"eat Received By: � � • 214101 2539 RECEIVED FEB 10 2015 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-36 Definitive Survey Report N A D 2 7 ] 13 January, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36©140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-36 Well Position +NI-S 0.00 usft Northing: 5,948,984.77 usft Latitude: 70°16'18.567 N +EI-W 0.00 usft Easting: 487,817.93 usft Longitude: 150°5 54.693 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-36 Magnetics Model Name Sample Date Declination Dip Angle Field Strength () (1 (nT) BGG M2014 11/7/2014 18.97 80.84 57,564 Design 2M-36 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,270.06 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.49 0.00 0.00 294.00 Survey Program Date 1/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.00 1,130.00 2M-36PB1 Srvy#1-GYD-GC-MS(2M-3 GYD-GC-MS Gyrodata gyrocompassing m/s 11/11/2014 5:57 1,189.55 3,270.06 2M-36PB1 Srvy#2-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2014 6:00 3,365.81 9,476.88 2M-36 Srvy#1-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 1:11 9,553.48 12,953.64 2M-36 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/15/2014 10:1. Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) (%1pp) (ft) Survey Tool Name 39.49 0.00 0.00 39.49 -101.30 0.00 0.00 5,948,984.77 487,817.93 0.00 0.00 UNDEFINED 97.00 0.40 256.40 97.00 -43.79 -0.05 -0.20 5,948,984.72 487,817.73 0.70 0.16 GYD-GC-MS(1) 188.00 0.66 258.57 188.00 47.21 -0.23 -1.02 5,948,984.54 487,816.91 0.29 0.84 GYD-GC-MS(1) 278.00 1.50 353.59 277.98 137.19 0.84 -1.66 5,948,985.61 487,816.27 1.88 1.86 GYD-GC-MS(1) 374.00 1.57 3.93 373.95 233.16 3.40 -1.71 5,948,988.17 487,816.22 0.30 2.94 GYD-GC-MS(1) 470.00 3.33 343.60 469.86 329.07 7.39 -2.40 5,948,992.16 487,815.53 2.02 5.20 GYD-GC-MS(1) 564.00 3.91 343.60 563.67 422.88 13.08 -4.08 5,948,997.86 487,813.87 0.62 9.05 GYD-GC-MS(1) 657.00 4.61 349.66 656.41 515.62 19.80 -5.65 5,949,004.58 487,812.31 0.89 13.21 GYD-GC-MS(1) 753.00 6.06 352.48 752.00 611.21 28.62 -7.00 5,949,013.40 487,810.97 1.53 18.04 GYD-GC-MS(1) 847.00 8.16 349.61 845.27 704.48 40.10 -8.85 5,949,024.88 487,809.14 2.27 24.40 GYD-GC-MS(1) 943.00 11.06 345.45 939.91 799.12 55.72 -12.40 5,949,040.50 487,805.62 3.10 33.99 GYD-GC-MS(1) 1/13/2015 12:30:18PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (11001 (ft) Survey Tool Name 1,037.00 11.05 339.54 1,032.17 891.38 72.89 -17.81 5,949,057.68 487,800.23 1.21 45.92 GYD-GC-MS(1) 1,130.00 11.98 340.75 1,123.30 982.51 90.35 -24.11 5,949,075.15 487,793.97 1.03 58.77 GYD-GC-MS(1) 1,189.55 12.88 341.70 1,181.45 1,040.66 102.49 -28.23 5,949,087.29 487,789.86 1.55 67.48 MWD+IFR-AK-CAZ-SC(2) 1,284.12 15.84 341.23 1,273.06 1,132.27 124.72 -35.70 5,949,109.53 487,782.44 3.13 83.34 MWD+IFR-AK-CAZ-SC(2) 1,379.49 18.29 338.03 1,364.22 1,223.43 150.93 -45.48 5,949,135.75 487,772.69 2.75 102.94 MWD+IFR-AK-CAZ-SC(2) 1,473.73 18.90 334.84 1,453.55 1,312.76 178.46 -57.51 5,949,163.30 487,760.72 1.26 125.12 MWD+IFR-AK-CAZ-SC(2) 1,567.09 20.43 332.70 1,541.46 1,400.67 206.62 -71.41 5,949,191.49 487,746.86 1.81 149.28 MWD+IFR-AK-CAZ-SC(2) 1,661.80 22.52 326.67 1,629.60 1,488.81 236.47 -88.96 5,949,221.36 487,729.36 3.21 177.45 MWD+IFR-AK-CAZ-SC(2) 1,756.34 24.83 319.91 1,716.19 1,575.40 266.80 -111.70 5,949,251.72 487,706.67 3.77 210.56 MWD+IFR-AK-CAZ-SC(2) 1,851.38 25.64 313.44 1,802.18 1,661.39 296.21 -139.48 5,949,281.17 487,678.94 3.02 247.90 MVVD+IFR-AK-CAZ-SC(2) 1,947.09 27.21 304.48 1,887.92 1,747.13 322.85 -172.57 5,949,307.86 487,645.89 4.47 288.97 MVVD+IFR-AK-CAZ-SC(2) 2,040.24 28.97 298.65 1,970.11 1,829.32 345.72 -209.94 5,949,330.80 487,608.57 3.50 332.40 MWD+IFR-AK-CAZ-SC(2) 2,134.21 30.55 295.28 2,051.69 1,910.90 366.84 -251.51 5,949,351.97 487,567.04 2.45 378.97 MWD+IFR-AK-CAZ-SC(2) 2,230.79 32.20 291.54 2,134.15 1,993.36 386.77 -297.64 5,949,371.98 487,520.94 2.64 429.23 MWD+IFR-AK-CAZ-SC(2) 2,323.31 34.82 286.65 2,211.30 2,070.51 403.39 -345.90 5,949,388.68 487,472.72 4.06 480.07 MWD+IFR-AK-CAZ-SC(2) 2,421.48 38.39 285.23 2,290.10 2,149.31 419.44 -402.18 5,949,404.81 487,416.46 3.74 538.01 MW3+IFR-AK-CAZ-SC(2) 2,516.85 41.43 283.48 2,363.25 2,222.46 434.58 -461.45 5,949,420.05 487,357.22 3.40 598.32 MWD+IFR-AK-CAZ-SC(2) 2,607.79 45.83 283.41 2,429.05 2,288.26 449.16 -522.47 5,949,434.73 487,296.24 4.84 659.99 MWD+IFR-AK-CAZ-SC(2) 2,702.41 48.87 282.96 2,493.15 2,352.36 465.03 -590.22 5,949,450,70 487,228.52 3.23 728.34 MWD+IFR-AK-CAZ-SC(2) 2,753.16 52.41 283.63 2,525.33 2,384.54 474.05 -628.40 5,949,459.79 487,190.36 7.05 766.89 MWD+IFR-AK-CAZ-SC(2) 2,796.75 53.90 282.80 2,551.47 2,410.68 482.03 -662.36 5,949,467.82 487,156.41 3.74 801.15 MWD+IFR-AK-CAZ-SC(2) 2,892.13 56.55 278.98 2,605.88 2,465.09 496.78 -739.27 5,949,482.69 487,079.53 4.31 877.42 MWD+IFR-AK-CAZ-SC(2) 2,985.78 58.27 278.81 2,656.32 2,515.53 508.98 -817.22 5,949,495.02 487,001.61 1.84 953.59 MWD+IFR-AK-CAZ-SC(2) 3,080.36 59.34 278.31 2,705.31 2,564.52 521.02 -897.23 5,949,507.19 486,921.63 1.22 1,031.57 MWD+IFR-AK-CAZ-SC(2) 3,174.51 59.40 276.62 2,753.28 2,612.49 531.54 -977.55 5,949,517.84 486,841.34 1.55 1,109.23 MWD+IFR-AK-CAZ-SC(2) 3,270.06 60.47 275.76 2,801.15 2,660.36 540.46 -1,059.76 5,949,526.89 486,759.15 1.36 1,187.96 MWD+IFR-AK-CAZ-SC(2) 3,365.81 62.93 276.90 2,846.54 2,705.75 549.76 -1,143.54 5,949,536.32 466,675.39 2.77 1,268.28 MWD+IFR-AK-CAZ-SC(3) 3,409.80 64.63 275.05 2,865.98 2,725.19 553.86 -1,182.79 5,949,540.49 486,636.16 5.40 1,305.81 MWD+IFR-AK-CAZ-SC(3) 3,468.72 65.81 273.57 2,890.67 2,749.88 557.88 -1,236.13 5,949,544.59 486,582.83 3.04 1,356.17 MWD+IFR-AK-CAZ-SC(3) 3,562.30 66.62 273.77 2,928.42 2,787.63 563.36 -1,321.58 5,949,550.21 486,497.39 0.89 1,436.47 MWD+IFR-AK-CAZ-SC(3) 3,657.43 66.71 273.33 2,966.10 2,825.31 568.77 -1,408.76 5,949,555.76 486,410.23 0.44 1,518.31 MWD+IFR-AK-CAZ-SC(3) 3,751.85 65.31 273.63 3,004.48 2,863.69 574.01 -1,494.87 5,949,561.13 486,324.14 1.51 1,599.10 MWD+IFR-AK-CAZ-SC(3) 3,845.78 65.46 273.77 3,043.61 2,902.82 579.52 -1,580.08 5,949,566.78 486,238.94 0.21 1,679.19 MWD+IFR-AK-CAZ-SC(3) 3,938.23 64.25 273.87 3,082.89 2,942.10 585.09 -1,663.58 5,949,572.49 486,155.46 1.31 1,757.74 MWD+IFR-AK-CAZ-SC(3) 4,035.06 62.27 273.69 3,126.46 2,985.67 590.79 -1,749.87 5,949,578.33 486,069.19 2.05 1,838.88 M1MD+IFR-AK-CAZ-SC(3) 4,130.81 60.74 274.40 3,172.14 3,031.35 596.73 -1,833.80 5,949,584.40 485,985.27 1.73 1,917.97 MWD+IFR-AK-CAZ-SC(3) 4,225.62 58.44 276.24 3,220.13 3,079.34 604.29 -1,915.21 5,949,592.10 485,903.89 2.95 1,995.42 MWD+IFR-AK-CAZ-SC(3) 4,320.24 58.94 278.74 3,269.30 3,128.51 614.83 -1,995.35 5,949,602.77 485,823.77 2.32 2,072.92 MVVD+IFR-AK-CAZ-SC(3) 4,414.64 57.09 282.82 3,319.32 3,178.53 629.77 -2,073.98 5,949,617.83 485,745.17 4.16 2,150.83 MWD+IFR-AK-CAZ-SC(3) 4,508.04 57.40 282.31 3,369.85 3,229.06 646.86 -2,150.65 5,949,635.04 485,668.54 0.57 2,227.82 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:30:18PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36©140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36©140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (") (usft) (usft) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 4,602.79 57.12 280.80 3,421.10 3,280.31 662.83 -2,228.73 5,949,651.13 485,590.50 1.37 2,305.64 MWD+IFR-AK-CAZ-SC(3) 4,696.08 57.17 277.53 3,471.72 3,330.93 675.30 -2,306.08 5,949,663.74 485,513.18 2.94 2,381.38 MWD+IFR-AK-CAZ-SC(3) 4,791.19 58.42 276.22 3,522.41 3,381.62 684.93 -2,385.97 5,949,673.49 485,433.30 1.76 2,458.28 MWD+IFR-AK-CAZ-SC(3) 4,883.67 59.88 276.56 3,569.83 3,429.04 693.77 -2,464.87 5,949,682.46 485,354.43 1.61 2,533.95 MWD+IFR-AK-CAZ-SC(3) 4,979.22 60.80 277.10 3,617.12 3,476.33 703.65 -2,547.31 5,949,692.46 485,272.01 1.08 2,613.28 MWD+IFR-AK-CAZ-SC(3) 5,074.19 62.19 277.66 3,662.44 3,521.65 714.37 -2,630.07 5,949,703.32 485,189.27 1.55 2,693.25 MWD+IFR-AK-CAZ-SC(3) 5,170.10 61.51 278.82 3,707.69 3,566.90 726.48 -2,713.76 5,949,715.57 485,105.61 1.28 2,774.64 MWD+IFR-AK-CAZ-SC(3) 5,263.78 61.74 278.79 3,752.21 3,611.42 739.10 -2,795.22 5,949,728.32 485,024.19 0.25 2,854.18 MWD+IFR-AK-CAZ-SC(3) 5,358.58 61.10 278.20 3,797.56 3,656.77 751.40 -2,877.55 5,949,740.75 484,941.88 0.87 2,934.40 MWD+IFR-AK-CAZ-SC(3) 5,454.10 61.05 278.37 3,843.76 3,702.97 763.45 -2,960.28 5,949,752.93 484,859.18 0.16 3,014.88 MVVD+IFR-AK-CAZ-SC(3) 5,547.64 61.39 278.98 3,888.79 3,748.00 775.81 -3,041.33 5,949,765.43 484,778.16 0.68 3,093.95 MWD+IFR-AK-CAZ-SC(3) 5,641.71 60.88 277.84 3,934.21 3,793.42 787.86 -3,122.83 5,949,777.61 484,696.69 1.19 3,173.30 MWD+IFR-AK-CAZ-SC(3) 5,733.47 61.36 277.88 3,978.52 3,837.73 798.85 -3,202.42 5,949,788.72 484,617.13 0.52 3,250.48 MWD+IFR-AK-CAZ-SC(3) 5,831.19 61.15 280.84 4,025.53 3,884.74 812.78 -3,286.94 5,949,802.79 484,532.63 2.66 3,333.36 MWD+IFR-AK-CAZ-SC(3) 5,925.64 61.18 281.30 4,071.08 3,930.29 828.67 -3,368.14 5,949,818.80 484,451.47 0.43 3,414.00 MWD+IFR-AK-CAZ-SC(3) 6,019.38 61.33 281.24 4,116.16 3,975.37 844.73 -3,448.74 5,949,834.99 484,370.90 0.17 3,494.17 MWD+IFR-AK-CAZ-SC(3) 6,113.82 61.17 281.21 4,161.58 4,020.79 860.85 3,529.96 5,949,851.24 484,289.72 0.17 3,574.92 MVVD+IFR-AK-CAZ-SC(3) 6,209.16 61.08 280.73 4,207.62 4,066.83 876.74 -3,611.92 5,949,867.26 484,207.79 0.45 3,656.25 MWD+IFR-AK-CAZ-SC(3) 6,303.94 61.21 280.32 4,253.36 4,112.57 891.90 -3,693.54 5,949,882.55 484,126.21 0.40 3,736.98 MWD+IFR-AK-CAZ-SC(3) 6,397.65 61.38 280.25 4,298.37 4,157.58 906.57 -3,774.41 5,949,897.36 484,045.37 0.19 3,816.83 MWD+IFR-AK-CAZ-SC(3) 6,492.71 61.07 279.22 4,344.13 4,203.34 920.66 -3,856.53 5,949,911.58 483,963.28 1.00 3,897.58 MWD+IFR-AK-CAZ-SC(3) 6,586.76 61.58 278.90 4,389.26 4,248.47 933.66 -3,938.01 5,949,924.70 483,881.82 0.62 3,977.31 MWD+IFR-AK-CAZ-SC(3) 6,681.04 61.16 278.77 4,434.44 4,293.65 946.37 -4,019.78 5,949,937.54 483,800.08 0.46 4,057.18 MWD+IFR-AK-CAZ-SC(3) 6,775.49 61.04 278.86 4,480.08 4,339.29 959.04 -4,101.49 5,949,950.35 483,718.40 0.15 4,136.98 MWD+IFR-AK-CAZ-SC(3) 6,869.68 61.48 278.95 4,525.37 4,384.58 971.82 -4,183.09 5,949,963.26 483,636.84 0.47 4,216.72 MWD+IFR-AK-CAZ-SC(3) 6,964.94 61.11 279.07 4,571.13 4,430.34 984.91 -4,265.61 5,949,976.48 483,554.34 0.40 4,297.42 MWD+IFR-AK-CAZ-SC(3) 7,060.29 61.28 278.91 4,617.07 4,476.28 997.96 -4,348.13 5,949,989.67 483,471.85 0.23 4,378.13 MWD+IFR-AK-CAZ-SC(3) 7,155.00 61.31 279.05 4,662.56 4,521.77 1,010.93 -4,430.19 5,950,002.77 483,389.83 0.13 4,458.36 MWD+IFR-AK-CAZ-SC(3) 7,250.96 61.13 278.45 4,708.76 4,567.97 1,023.72 -4,513.31 5,950,015.69 483,306.73 0.58 4,539.50 MWD+IFR-AK-CAZ-SC(3) 7,344.69 61.24 278.20 4,753.93 4,613.14 1,035.62 -4,594.57 5,950,027.71 483,225.50 0.26 4,618.57 MWD+IFR-AK-CAZ-SC(3) 7,440.16 61.16 276.89 4,799.93 4,659.14 1,046.60 -4,677.51 5,950,038.83 483,142.59 1.21 4,698.80 MWD+IFR-AK-CAZ-SC(3) 7,534.31 61.18 277.46 4,845.33 4,704.54 1,056.90 -4,759.34 5,950,049.27 483,060.78 0.53 4,777.75 MWD+IFR-AK-CAZ-SC(3) 7,629.36 59.83 278.48 4,892.13 4,751.34 1,068.37 -4,841.27 5,950,060.86 482,978.88 1.70 4,857.26 MWD+IFR-AK-CAZ-SC(3) 7,723.76 58.74 278.78 4,940.34 4,799.55 1,080.54 -4,921.51 5,950,073.17 482,898.67 1.19 4,935.52 MWD+IFR-AK-CAZ-SC(3) 7,819.01 56.17 279.04 4,991.58 4,850.79 1,092.96 -5,000.82 5,950,085.73 482,819.38 2.71 5,013.03 MWD+IFR-AK-CAZ-SC(3) 7,914.03 53.17 278.26 5,046.52 4,905.73 1,104.64 -5,077.45 5,950,097.52 482,742.78 3.23 5,087.78 MWD+IFR-AK-CAZ-SC(3) 8,007.85 51.39 276.56 5,103.92 4,963.13 1,114.23 -5,151.04 5,950,107.22 482,669.22 2.38 5,158.90 MWD+IFR-AK-CAZ-SC(3) 8,102.97 50.54 276.45 5,163.83 5,023.04 1,122.60 -5,224.44 5,950,115.71 482,595.83 0.90 5,229.37 MWD+IFR-AK-CAZ-SC(3) 8,198.21 49.67 276.42 5,224.91 5,084.12 1,130.79 -5,297.05 5,950,124.01 482,523.24 0.91 5,299.03 MWD+IFR-AK-CAZ-SC(3) 8,294.82 46.98 275.86 5,289.14 5,148.35 1,138.51 -5,368.79 5,950,131.85 482,451.52 2.82 5,367.71 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12.30:18PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 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) (°11001 (ft) Survey Tool Name 8,387.38 43.73 273.79 5,354.18 5,213.39 1,144.08 -5,434.39 5,950,137.53 482,385.93 3.85 5,429.91 MWD+IFR-AK-CAZ-SC(3) 8,482.21 41.97 271.80 5,423.70 5,282.91 1,147.25 -5,498.80 5,950,140.80 482,321.54 2.34 5,490.03 MWD+IFR-AK-CAZ-SC(3) 8,576.61 44.49 272.85 5,492.48 5,351.69 1,149.88 -5,563.40 5,950,143.54 482,256.95 2.78 5,550.11 MWD+IFR-AK-CAZ-SC(3) 8,670.39 46.53 275.16 5,558.20 5,417.41 1,154.58 -5,630.12 5,950,148.34 482,190.25 2.80 5,612.98 MWD+IFR-AK-CAZ-SC(3) 8,765.77 47.70 275.56 5,623.11 5,482.32 1,161.11 -5,699.70 5,950,154.98 482,120.68 1.26 5,679.20 MWD+IFR-AK-CAZ-SC(3) 8,858.75 50.04 277.12 5,684.27 5,543.48 1,168.86 -5,769.29 5,950,162.84 482,051.11 2.82 5,745.93 MVVD+IFR-AK-CAZ-SC(3) 8,954.12 52.60 277.87 5,743.87 5,603.08 1,178.58 -5,843.10 5,950,172.68 481,977.33 2.75 5,817.31 MWD+IFR-AK-CAZ-SC(3) 9,048.20 56.63 279.49 5,798.34 5,657.55 1,190.18 -5,918.90 5,950,184.40 481,901.55 4.51 5,891.27 MWD+IFR-AK-CAZ-SC(3) 9,142.26 60.87 280.61 5,847.12 5,706.33 1,204.22 -5,998.05 5,950,198.58 481,822.43 4.62 5,969.30 MWD+IFR-AK-CAZ-SC(3) 9,196.46 63.59 281.11 5,872.37 5,731.58 1,213.26 -6,045.15 5,950,207.69 481,775.35 5.08 6,015.99 MWD+IFR-AK-CAZ-SC(3) 9,236.74 65.56 281.54 5,889.66 5,748.87 1,220.40 -6,080.82 5,950,214.89 481,739.70 4.98 6,051.49 MWD+IFR-AK-CAZ-SC(3) 9,330.91 69.18 281.94 5,925.89 5,785.10 1,238.09 -6,165.90 5,950,232.71 481,654.65 3.86 6,136.41 MVVD+IFR-AK-CAZ-SC(3) 9,379.30 71.48 283.57 5,942.18 5,801.39 1,248.15 -6,210.34 5,950,242.85 481,610.24 5.71 6,181.10 MVVD+IFR-AK-CAZ-SC(3) 9,425.44 73.66 284.20 5,956.00 5,815.21 1,258.72 -6,253.07 5,950,253.48 481,567.53 4.90 6,224.43 MWD+IFR-AK-CAZ-SC(3) 9,476.88 76.65 285.87 5,969.18 5,828.39 1,271.62 -6,301.08 5,950,266.46 481,519.54 6.61 6,273.54 MWD+IFR-AK-CAZ-SC(3) 9,518.00 77.72 287.29 5,978.30 5,837.51 1,283.06 -6,339.51 5,950,277.96 481,481.13 4.26 6,313.30 MWD+IFR-AK-CAZ-SC(4) 7-518"x 9-7/8" 9,553.48 78.65 288.51 5,985.57 5,844.78 1,293.74 -6,372.56 5,950,288.69 481,448.11 4.26 6,347.83 MWD+IFR-AK-CAZ-SC(4) 9,594.43 79.30 287.33 5,993.40 5,852.61 1,306.11 -6,410.80 5,950,301.12 481,409.89 3.24 6,387.80 MWD+IFR-AK-CAZ-SC(4) 9,632.60 79.70 285.84 6,000.35 5,859.56 1,316.82 -6,446.77 5,950,311.89 481,373.94 3.98 6,425.01 MWD+IFR-AK-CAZ-SC(4) 9,727.57 80.50 286.78 6,016.68 5,875.89 1,343.09 -6,536.56 5,950,338.30 481,284.21 1.29 6,517.73 MWD+IFR-AK-CAZ-SC(4) 9,822.18 81.40 286.15 6,031.56 5,890.77 1,369.57 -6,626.16 5,950,364.93 481,194.66 1.16 6,610.35 MWD+IFR-AK-CAZ-SC(4) 9,917.09 82.37 285.50 6,044.96 5,904.17 1,395.19 -6,716.55 5,950,390.69 481,104.31 1.23 6,703.35 MW3+IFR-AK-CAZ-SC(4) 10,012.21 83.19 286.27 6,056.92 5,916.13 1,421.02 -6,807.31 5,950,416.66 481,013.60 1.18 6,796.77 MWD+IFR-AK-CAZ-SC(4) 10,107.07 85.78 285.91 6,066.03 5,925.24 1,447.19 -6,898.03 5,950,442.97 480,922.94 2.76 6,890.29 MWD+IFR-AK-CAZ-SC(4) 10,201.59 87.52 285.86 6,071.55 5,930.76 1,473.01 -6,988.78 5,950,468.94 480,832.24 1.84 6,983.70 MWD+IFR-AK-CAZ-SC(4) 10,296.66 90.64 285.79 6,073.08 5,932.29 1,498.93 -7,080.22 5,950,495.01 480,740.85 3.28 7,077.78 MWD+IFR-AK-CAZ-SC(4) 10,391.75 91.10 286.25 6,071.64 5,930.85 1,525.17 -7,171.61 5,950,521.39 480,649.51 0.68 7,171.93 MWD+IFR-AK-CAZ-SC(4) 10,486.63 90.45 286.12 6,070.35 5,929.56 1,551.62 -7,262.72 5,950,547.98 480,558.45 0.70 7,265.92 MWD+IFR-AK-CAZ-SC(4) 10,581.22 89.97 286.44 6,070.01 5,929.22 1,578.13 -7,353.52 5,950,574.64 480,467.71 0.61 7,359.66 MWD+IFR-AK-CAZ-SC(4) 10,676.50 89.52 290.25 6,070.43 5,929.64 1,608.11 -7,443.94 5,950,604.77 480,377.35 4.03 7,454.45 MWD+IFR-AK-CAZ-SC(4) 10,771.03 89.87 291.23 6,070.93 5,930.14 1,641.59 -7,532.34 5,950,638.38 480,289.01 1.10 7,548.83 MWD+IFR-AK-4AZ-SC(4) 10,865.50 90.35 293.64 6,070.75 5,929.96 1,677.64 -7,619.65 5,950,674.57 480,201.76 2.60 7,643.25 MWD+IFR-AK-CAZ-SC(4) 10,960.54 91.17 295.97 6,069.49 5,928.70 1,717.50 -7,705.91 5,950,714.57 480,115.58 2.60 7,738.27 MWD+IFR-AK-CAZ-SC(4) 11,056.15 91.24 296.74 6,067.48 5,926.69 1,759.94 -7,791.56 5,950,757.14 480,030.00 0.81 7,833.78 MWD+IFR-AK-CAZ-SC(4) 11,150.66 91.24 296.85 6,065.44 5,924.65 1,802.53 -7,875.90 5,950,799.87 479,945.74 0.12 7,928.15 MWD+IFR-AK-CAZ-SC(4) 11,254.24 91.17 296.19 6,063.26 5,922.47 1,848.77 -7,968.56 5,950,846.25 479,853.16 0.64 8,031.61 MWD+IFR-AK-CAZ-SC(4) 11,346.37 91.27 295.72 6,061.30 5,920.51 1,889.09 -8,051.38 5,950,886.69 479,770.42 0.52 8,123.66 MWD+IFR-AK-CAZ-SC(4) 11,434.62 91.51 293.60 6,059.16 5,918.37 1,925.89 -8,131.56 5,950,923.63 479,690.31 2.42 8,211.88 MWD+IFR-AK-CAZ-SC(4) 11,528.89 91.62 293.26 6,056.58 5,915.79 1,963.36 -8,218.02 5,950,961.23 479,603.92 0.38 8,306.11 MWD+IFR-AK-CAZ-SC(4) 1/13/2015 12:30:18PM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36©140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36©140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,623.97 87.64 292.47 6,057.19 5,916.40 2,000.30 -8,305.61 5,950,998.31 479,516.40 4.27 8,401.15 MWD+IFR-AK-CAZ-SC(4) 11,716.10 87.53 294.22 6,061.08 5,920.29 2,036.77 -8,390.12 5,951,034.92 479,431.95 1.90 8,493.19 MWD+IFR-AK-CAZ-SC(4) 11,811.37 88.49 296.46 6,064.39 5,923.60 2,077.52 -8,476.16 5,951,075.80 479,345.98 2.56 8,588.36 MWD+IFR-AK-CAZ-SC(4) 11,908.96 89.01 296.72 6,066.51 5,925.72 2,121.19 -8,563.41 5,951,119.61 479,258.82 0.60 8,685.83 MVVD+IFR-AK-CAZ-SC(4) 12,003.61 89.04 298.20 6,068.13 5,927.34 2,164.83 -8,647.38 5,951,163.38 479,174.92 1.56 8,780.29 MWD+IFR-AK-CAZ-SC(4) 12,098.06 89.32 298.02 6,069.48 5,928.69 2,209.33 -8,730.68 5,951,208.00 479,091.70 0.35 8,874.49 MWD+IFR-AK-CAZ-SC(4) 12,193.90 89.80 296.40 6,070.21 5,929.42 2,253.15 -8,815.91 5,951,251.96 479,006.55 1.76 8,970.17 MWD+IFR-AK-CAZ-SC(4) 12,288.37 90.83 294.01 6,069.69 5,928.90 2,293.38 -8,901.38 5,951,292.32 478,921.16 2.75 9,064.61 MWD+IFR-AK-CAZ-SC(4) 12,380.84 91.55 292.53 6,067.77 5,926.98 2,329.90 -8,986.30 5,951,328.97 478,836.30 1.78 9,157.05 MWD+IFR-AK-CAZ-SC(4) 12,477.63 92.95 290.02 6,063.97 5,923.18 2,364.99 -9,076.42 5,951,364.21 478,746.25 2.97 9,253.65 MWD+IFR-AK-CAZ-SC(4) 12,566.48 93.77 291.00 6,058.76 5,917.97 2,396.06 -9,159.49 5,951,395.41 478,663.24 1.44 9,342.18 MWD+IFR-AK-CAZ-SC(4) 12,663.95 94.51 291.63 6,051.73 5,910.94 2,431.40 -9,250.06 5,951,430.89 478,572.74 1.00 9,439.29 MWD+IFR-AK-CAZ-SC(4) 12,760.21 93.28 292.10 6,045.19 5,904.40 2,467.17 -9,339.18 5,951,466.80 478,483.68 1.37 9,535.26 MWD+IFR-AK-CAZ-SC(4) 12,855.41 94.19 292.97 6,038.99 5,898.20 2,503.57 -9,426.93 5,951,503.35 478,396.01 1.32 9,630.22 MWD+IFR-AK-CAZ-SC(4) 12,953.64 95.18 293.02 6,030.96 5,890.17 2,541.82 -9,517.05 5,951,541.73 478,305.96 1.01 9,728.11 MWD+IFR-AK-CAZ-SC(4) 12.993.00 95.18 293.02 6,027.41 5,886.62 2,557.15 -9,553.13 5,951,557.12 478,269.91 0.00 9,767.30 PROJECTED to TD 4 1/2"x 6-1/2" 13,013.00 95.18 293.02 6,025.61 5,884.82 2,564.94 -9,571.46 5,951,564.94 478,251.59 0.00 9,787.21 PROJECTED to TD Projected to TD 1/13/2015 12:30:18PM Page 6 COMPASS 5000.1 Build 65 214102 25395 RECEIVED FEB 10 2015 FINAL AOGCC � J ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-36 Definitive Survey Report N A D 8 3 13 January, 2015 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2M-36 Well Position +N/-S 0.00 usft Northing: 5,948,734.85 usfl Latitude: 70° 16'17.461 N +E/-W 0.00 usft Easting: 1,627,850.81 usfl Longitude: 150°6'5.878 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 101.30 usft Wellbore 2M-36 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 11/7/2014 18.97 80.84 57,564 Design 2M-36 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,270.06 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.49 0.00 0.00 294.00 Survey Program Date 1/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.00 1,130.00 2M-36PB1 Srvy#1 -GYD-GC-MS(2M-3 GYD-GC-MS Gyrodata gyrocompassing m/s 11/11/2014 5: 1,189.55 3,270.06 2M-36PB1 Srvy#2-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2014 6:1 3,365.81 9,476.88 2M-36 Srvy#1 -MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 1: 9,553.48 12,953.64 2M-36 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/15/2014 10. 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 39.49 0.00 0.00 39.49 -101.30 0.00 0.00 5,948,734.85 1,627,850.81 0.00 0.00 UNDEFINED 97.00 0.40 256.40 97.00 -43.79 -0.05 -0.20 5,948,734.80 1,627,850.61 0.70 0.16 GYD-GC-MS(1) 188.00 0.66 258.57 188.00 47.21 -0.23 -1.02 5,948,734.63 1,627,849.79 0.29 0.84 GYD-GC-MS(1) 278.00 1.50 353.59 277.98 137.19 0.84 -1.66 5,948,735.69 1,627,849.15 1.88 1.86 GYD-GC-MS(1) 374.00 1.57 3.93 373.95 233.16 3.40 -1.71 5,948,738.26 1,627,849.11 0.30 2.94 GYD-GC-MS(1) 470.00 3.33 343.60 469.86 329.07 7.39 -2.40 5,948,742.24 1,627,848.42 2.02 5.20 GYD-GC-MS(1) 564.00 3.91 343.60 563.67 422.88 13.08 -4.08 5,948,747.94 1,627,846.75 0.62 9.05 GYD-GC-MS(1) 657.00 4.61 349.66 656.41 515.62 19.80 -5.65 5,948,754.66 1,627,845.20 0.89 13.21 GYD-GC-MS(1) 753.00 6.06 352.48 752.00 611.21 28.62 -7.00 5,948,763.48 1,627,843.86 1.53 18.04 GYD-GC-MS(1) 847.00 8.16 349.61 845.27 704.48 40.10 -8.85 5,948,774.96 1,627,842.02 2.27 24.40 GYD-GC-MS(1) 943.00 11.06 345.45 939.91 799.12 55.72 -12.40 5,948,790.59 1,627,838.51 3.10 33.99 GYD-GC-MS(1) 1/13/2015 12:54:29PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,037.00 11.05 339.54 1,032.17 891.38 72.89 -17.81 5,948,807.76 1,627,833.12 1.21 45.92 GYD-GC-MS(1) 1,130.00 11.98 340.75 1,123.30 982.51 90.35 -24.11 5,948,825.23 1,627,826.85 1.03 58.77 GYD-GC-MS(1) 1,189.55 12.88 341.70 1,181.45 1,040.66 102.49 -28.23 5,948,837.38 1,627,822.75 1.55 67.48 MWD+IFR-AK-CAZ-SC(2) 1,284.12 15.84 341.23 1,273.06 1,132.27 124.72 -35.70 5,948,859.62 1,627,815.33 3.13 83.34 MWD+IFR-AK-CAZ-SC(2) 1,379.49 18.29 338.03 1,364.22 1,223.43 150.93 -45.48 5,948,885.84 1,627,805.58 2.75 102.94 MWD+IFR-AK-CAZ-SC(2) 1,473.73 18.90 334.84 1,453.55 1,312.76 178.46 -57.51 5,948,913.38 1,627,793.61 1.26 125.12 MWD+IFR-AK-CAZ-SC(2) 1,567.09 20.43 332.70 1,541.46 1,400.67 206.62 -71.41 5,948,941.57 1,627,779.75 1.81 149.28 MWD+IFR-AK-CAZ-SC(2) 1,661.80 22.52 326.67 1,629.60 1,488.81 236.47 -88.96 5,948,971.45 1,627,762.25 3.21 177.45 MWD+IFR-AK-CAZ-SC(2) 1,756.34 24.83 319.91 1,716.19 1,575.40 266.80 -111.70 5,949,001.81 1,627,739.57 3.77 210.56 MWD+IFR-AK-CAZ-SC(2) 1,851.38 25.64 313.44 1,802.18 1,661.39 296.21 -139.48 5,949,031.26 1,627,711.83 3.02 247.90 MWD+IFR-AK-CAZ-SC(2) 1,947.09 27.21 304.48 1,887.92 1,747.13 322.85 -172.57 5,949,057.95 1,627,678.79 4.47 288.97 MWD+IFR-AK-CAZ-SC(2) 2,040.24 28.97 298.65 1,970.11 1,829.32 345.72 -209.94 5,949,080.89 1,627,641.47 3.50 332.40 MWD+IFR-AK-CAZ-SC(2) 2,134.21 30.55 295.28 2,051.69 1,910.90 366.84 -251.51 5,949,102.07 1,627,599.94 2.45 378.97 MWD+IFR-AK-CAZ-SC(2) 2,230.79 32.20 291.54 2,134.15 1,993.36 386.77 -297.64 5,949,122.08 1,627,553.84 2.64 429.23 MWD+IFR-AK-CAZ-SC(2) 2,323.31 34.82 286.65 2,211.30 2,070.51 403.39 -345.90 5,949,138.78 1,627,505.62 4.06 480.07 MWD+IFR-AK-CAZ-SC(2) 2,421.48 38.39 285.23 2,290.10 2,149.31 419.44 -402.18 5,949,154.92 1,627,449.37 3.74 538.01 MWD+IFR-AK-CAZ-SC(2) 2,516.85 41.43 283.48 2,363.25 2,222.46 434.58 -461.45 5,949,170.15 1,627,390.13 3.40 598.32 MWD+IFR-AK-CAZ-SC(2) 2,607.79 45.83 283.41 2,429.05 2,288.26 449.16 -522.47 5,949,184.84 1,627,329.14 4.84 659.99 MWD+IFR-AK-CAZ-SC(2) 2,702.41 48.87 282.96 2,493.15 2,352.36 465.03 -590.22 5,949,200.82 1,627,261.43 3.23 728.34 MWD+IFR-AK-CAZSC(2) 2,753.16 52.41 283.63 2,525.33 2,384.54 474.05 -628.40 5,949,209.91 1,627,223.26 7.05 766.89 MWD+IFR-AK-CAZ-SC(2) 2,796.75 53.90 282.80 2,551.47 2,410.68 482.03 -662.36 5,949,217.93 1,627,189.32 3.74 801.15 MWD+IFR-AK-CAZ-SC(2) 2,892.13 56.55 278.98 2,605.88 2,465.09 496.78 -739.27 5,949,232.81 1,627,112.44 4.31 877.42 MWD+IFR-AK-CAZ-SC(2) 2,985.78 58.27 278.81 2,656.32 2,515.53 508.98 -817.22 5,949,245.14 1,627,034.52 1.84 953.59 MWD+IFR-AK-CAZ-SC(2) 3,080.36 59.34 278.31 2,705.31 2,564.52 521.02 -897.23 5,949,257.32 1,626,954.55 1.22 1,031.57 MWD+IFR-AK-CAZSC(2) 3,174.51 59.40 276.62 2,753.28 2,612.49 531.54 -977.55 5,949,267.97 1,626,874.25 1.55 1,109.23 MWD+IFR-AK-CAZSC(2) 3,270.06 60.47 275.76 2,801.15 2,660.36 540.46 -1,059.76 5,949,277.02 1,626,792.06 1.36 1,187.96 MWD+IFR-AK-CAZSC(2) 3,365.81 62.93 276.90 2,846.54 2,705.75 549.76 -1,143.54 5,949,286.46 1,626,708.30 2.77 1,268.28 MWD+IFR-AK-CAZ-SC(3) 3,409.80 64.63 275.05 2,865.98 2,725.19 553.86 -1,182.79 5,949,290.63 1,626,669.07 5.40 1,305.81 MWD+IFR-AK-CAZ-SC(3) 3,468.72 65.81 273.57 2,890.67 2,749.88 557.88 -1,236.13 5,949,294.74 1,626,615.74 3.04 1,356.17 MWD+IFR-AK-CAZ-SC(3) 3,562.30 66.62 273.77 2,928.42 2,787.63 563.36 -1,321.58 5,949,300.36 1,626,530.30 0.89 1,436.47 MWD+IFR-AK-CAZ-SC(3) 3,657.43 66.71 273.33 2,966.10 2,825.31 568.77 -1,408.76 5,949,305.92 1,626,443.14 0.44 1,518.31 MWD+IFR-AK-CAZ-SC(3) 3,751.85 65.31 273.63 3,004.48 2,863.69 574.01 -1,494.87 5,949,311.29 1,626,357.05 1.51 1,599.10 MWD+IFR-AK-CAZ-SC(3) 3,845.78 65.46 273.77 3,043.61 2,902.82 579.52 -1,580.08 5,949,316.95 1,626,271.85 0.21 1,679.19 MWD+IFR-AK-CAZ-SC(3) 3,938.23 64.25 273.87 3,082.89 2,942.10 585.09 -1,663.58 5,949,322.66 1,626,188.37 1.31 1,757.74 MWD+IFR-AK-CAZ-SC(3) 4,035.06 62.27 273.69 3,126.46 2,985.67 590.79 -1,749.87 5,949,328.51 1,626,102.11 2.05 1,838.88 MWD+IFR-AK-CAZ-SC(3) 4,130.81 60.74 274.40 3,172.14 3,031.35 596.73 -1,833.80 5,949,334.58 1,626,018.19 1.73 1,917.97 MWD+IFR-AK-CAZ-SC(3) 4,225.62 58.44 276.24 3,220.13 3,079.34 604.29 -1,915.21 5,949,342.28 1,625,936.80 2.95 1,995.42 MWD+IFR-AK-CAZ-SC(3) 4,320.24 58.94 278.74 3,269.30 3,128.51 614.83 -1,995.35 5,949,352.95 1,625,856.69 2.32 2,072.92 MWD+IFR-AK-CAZ-SC(3) 4,414.64 57.09 282.82 3,319.32 3,178.53 629.77 -2,073.98 5,949,368.02 1,625,778.09 4.16 2,150.83 MWD+IFR-AK-CAZ-SC(3) 4,508.04 57.40 282.31 3,369.85 3,229.06 646.86 -2,150.65 5,949,385.24 1,625,701.46 0.57 2,227.82 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:54:29PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 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) MOW) (ft) Survey Tool Name 4,602.79 57.12 280.80 3,421.10 3,280.31 662.83 -2,228.73 5,949,401.33 1,625,623.42 1.37 2,305.64 MWD+IFR-AK-CAZSC(3) 4,696.08 57.17 277.53 3,471.72 3,330.93 675.30 -2,306.08 5,949,413.94 1,625,546.09 2.94 2,381.38 MWD+IFR-AK-CAZ-SC(3) 4,791.19 58.42 276.22 3,522.41 3,381.62 684.93 -2,385.97 5,949,423.70 1,625,466.22 1.76 2,458.28 MWD+IFR-AK-CAZ-SC(3) 4,883.67 59.88 276.56 3,569.83 3,429.04 693.77 -2,464.87 5,949,432.66 1,625,387.35 1.61 2,533.95 MWD+IFR-AK-CAZ-SC(3) 4,979.22 60.80 277.10 3,617.12 3,476.33 703.65 -2,547.31 5,949,442.68 1,625,304.93 1.08 2,613.28 MWD+IFR-AK-CAZ-SC(3) 5,074.19 62.19 277.66 3,662.44 3,521.65 714.37 -2,630.07 5,949,453.54 1,625,222.19 1.55 2,693.25 MWD+IFR-AK-CAZ-SC(3) 5,170.10 61.51 278.82 3,707.69 3,566.90 726.48 -2,713.76 5,949,465.79 1,625,138.53 1.28 2,774.64 MWD+IFR-AK-CAZ-SC(3) 5,263.78 61.74 278.79 3,752.21 3,611.42 739.10 -2,795.22 5,949,478.54 1,625,057.11 0.25 2,854.18 MWD+IFR-AK-CAZSC(3) 5,358.58 61.10 278.20 3,797.56 3,656.77 751.40 -2,877.55 5,949,490.98 1,624,974.80 0.87 2,934.40 MWD+IFR-AK-CAZ-SC(3) 5,454.10 61.05 278.37 3,843.76 3,702.97 763.45 -2,960.28 5,949,503.16 1,624,892.10 0.16 3,014.88 MWD+IFR-AK-CAZ-SC(3) 5,547.64 61.39 278.98 3,888.79 3,748.00 775.81 -3,041.33 5,949,515.66 1,624,811.08 0.68 3,093.95 MWD+IFR-AK-CAZ-SC(3) 5,641.71 60.88 277.84 3,934.21 3,793.42 787.86 -3,122.83 5,949,527.85 1,624,729.62 1.19 3,173.30 MWD+IFR-AK-CAZ-SC(3) 5,733.47 61.36 277.88 3,978.52 3,837.73 798.85 -3,202.42 5,949,538.97 1,624,650.05 0.52 3,250.48 MWD+IFR-AK-CAZ-SC(3) 5,831.19 61.15 280.84 4,025.53 3,884.74 812.78 -3,286.94 5,949,553.04 1,624,565.56 2.66 3,333.36 MWD+IFR-AK-CAZ-SC(3) 5,925.64 61.18 281.30 4,071.08 3,930.29 828.67 -3,368.14 5,949,569.06 1,624,484.39 0.43 3,414.00 MWD+IFR-AK-CAZ-SC(3) 6,019.38 61.33 281.24 4,116.16 3,975.37 844.73 -3,448.74 5,949,585.25 1,624,403.82 0.17 3,494.17 MWD+IFR-AK-CAZ-SC(3) 6,113.82 61.17 281.21 4,161.58 4,020.79 860.85 -3,529.96 5,949,601.50 1,624,322.65 0.17 3,574.92 MWD+IFR-AK-CAZ-SC(3) 6,209.16 61.08 280.73 4,207.62 4,066.83 876.74 -3,611.92 5,949,617.53 1,624,240.72 0.45 3,656.25 MWD+IFR-AK-CAZ-SC(3) 6,303.94 61.21 280.32 4,253.36 4,112.57 891.90 -3,693.54 5,949,632.83 1,624,159.14 0.40 3,736.98 MWD+IFR-AK-CAZ-SC(3) 6,397.65 61.38 280.25 4,298.37 4,157.58 906.57 -3,774.41 5,949,647.63 1,624,078.30 0.19 3,816.83 MWD+IFR-AK-CAZ-SC(3) 6,492.71 61.07 279.22 4,344.13 4,203.34 920.66 -3,856.53 5,949,661.86 1,623,996.21 1.00 3,897.58 MWD+IFR-AK-CAZ-SC(3) 6,586.76 61.58 278.90 4,389.26 4,248.47 933.66 -3,938.01 5,949,674.99 1,623,914.75 0.62 3,977.31 MWD+IFR-AK-CAZ-SC(3) 6,681.04 61.16 278.77 4,434.44 4,293.65 946.37 -4,019.78 5,949,687.83 1,623,833.01 0.46 4,057.18 MWD+IFR-AK-CAZ-SC(3) 6,775.49 61.04 278.86 4,480.08 4,339.29 959.04 -4,101.49 5,949,700.64 1,623,751.33 0.15 4,136.98 MWD+IFR-AK-CAZ-SC(3) 6,869.68 61.48 278.95 4,525.37 4,384.58 971.82 -4,183.09 5,949,713.56 1,623,669.77 0.47 4,216.72 MWD+IFR-AK-CAZ-SC(3) 6,964.94 61.11 279.07 4,571.13 4,430.34 984.91 -4,265.61 5,949,726.78 1,623,587.28 0.40 4,297.42 MWD+IFR-AK-CAZ-SC(3) 7,060.29 61.28 278.91 4,617.07 4,476.28 997.96 -4,348.13 5,949,739.97 1,623,504.78 0.23 4,378.13 MWD+IFR-AK-CAZ-SC(3) 7,155.00 61.31 279.05 4,662.56 4,521.77 1,010.93 -4,430.19 5,949,753.07 1,623,422.76 0.13 4,458.36 MWD+IFR-AK-CAZ-SC(3) 7,250.96 61.13 278.45 4,708.76 4,567.97 1,023.72 -4,513.31 5,949,766.01 1,623,339.66 0.58 4,539.50 MWD+IFR-AK-CAZ-SC(3) 7,344.69 61.24 278.20 4,753.93 4,613.14 1,035.62 -4,594.57 5,949,778.03 1,623,258.43 0.26 4,618.57 MWD+IFR-AK-CAZ-SC(3) 7,440.16 61.16 276.89 4,799.93 4,659.14 1,046.60 -4,677.51 5,949,789.15 1,623,175.53 1.21 4,698.80 MWD+IFR-AK-CAZ-SC(3) 7,534.31 61.18 277.46 4,845.33 4,704.54 1,056.90 -4,759.34 5,949,799.59 1,623,093.72 0.53 4,777.75 MWD+IFR-AK-CAZSC(3) 7,629.36 59.83 278.48 4,892.13 4,751.34 1,068.37 -4,841.27 5,949,811.19 1,623,011.81 1.70 4,857.26 MWD+IFR-AK-CAZ-SC(3) 7,723.76 58.74 278.78 4,940.34 4,799.55 1,080.54 -4,921.51 5,949,823.50 1,622,931.61 1.19 4,935.52 MWD+IFR-AK-CAZ-SC(3) 7,819.01 56.17 279.04 4,991.58 4,850.79 1,092.98 -5,000.82 5,949,836.07 1,622,852.32 2.71 5,013.03 MWD+IFR-AK-CAZ-SC(3) 7,914.03 53.17 278.26 5,046.52 4,905.73 1,104.64 -5,077.45 5,949,847.86 1,622,775.72 3.23 5,087.78 MWD+IFR-AK-CAZ-SC(3) 8,007.85 51.39 276.56 5,103.92 4,963.13 1,114.23 -5,151.04 5,949,857.56 1,622,702.16 2.38 5,158.90 MWD+IFR-AK-CAZ-SC(3) 8,102.97 50.54 276.45 5,163.83 5,023.04 1,122.60 -5,224.44 5,949,866.06 1,622,628.77 0.90 5,229.37 MWD+IFR-AK-CAZ-SC(3) 8,198.21 49.67 276.42 5,224.91 5,084.12 1,130.79 -5,297.05 5,949,874.37 1,622,556.18 0.91 5,299.03 MWD+IFR-AK-CAZ-SC(3) 8,294.82 46.98 275.86 5,289.14 5,148.35 1,138.51 -5,368.79 5,949,882.21 1,622,484.46 2.82 5,367.71 MWD+IFR-AK-CAZSC(3) 1/13/2015 12:54:29PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit ND Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 8,387.38 43.73 273.79 5,354.18 5,213.39 1,144.08 -5,434.39 5,949,887.89 1,622,418.88 3.85 5,429.91 MWD+IFR-AK-CAZ-SC(3) 8,482.21 41.97 271.80 5,423.70 5,282.91 1,147.25 -5,498.80 5,949,891.16 1,622,354.48 2.34 5,490.03 MWD+IFR-AK-CAZ-SC(3) 8,576.61 44.49 272.85 5,492.48 5,351.69 1,149.88 -5,563.40 5,949,893.90 1,622,289.90 2.78 5,550.11 MWD+IFR-AK-CAZ-SC(3) 8,670.39 46.53 275.16 5,558.20 5,417.41 1,154.58 -5,630.12 5,949,898.71 1,622,223.19 2.80 5,612.98 MWD+IFR-AK-CAZ-SC(3) 8,765.77 47.70 275.56 5,623.11 5,482.32 1,161.11 -5,699.70 5,949,905.36 1,622,153.63 1.26 5,679.20 MWD+IFR-AK-CAZ-SC(3) 8,858.75 50.04 277.12 5,684.27 5,543.48 1,168.86 -5,769.29 5,949,913.22 1,622,084.05 2.82 5,745.93 MWD+IFR-AK-CAZ-SC(3) 8,954.12 52.60 277.87 5,743.87 5,603.08 1,178.58 -5,843.10 5,949,923.06 1,622,010.27 2.75 5,817.31 MWD+IFR-AK-CAZ-SC(3) 9,048.20 56.63 279.49 5,798.34 5,657.55 1,190.18 -5,918.90 5,949,934.79 1,621,934.50 4.51 5,891.27 MWD+IFR-AK-CAZ-SC(3) 9,142.26 60.87 280.61 5,847.12 5,706.33 1,204.22 -5,998.05 5,949,948.96 1,621,855.37 4.62 5,969.30 MWD+IFR-AK-CAZ-SC(3) 9,196.46 63.59 281.11 5,872.37 5,731.58 1,213.26 -6,045.15 5,949,958.08 1,621,808.30 5.08 6,015.99 MWD+IFR-AK-CAZ-SC(3) 9,236.74 65.56 281.54 5,889.66 5,748.87 1,220.40 -6,080.82 5,949,965.28 1,621,772.65 4.98 6,051.49 MWD+IFR-AK-CAZ-SC(3) 9,330.91 69.18 281.94 5,925.89 5,785.10 1,238.09 -6,165.90 5,949,983.11 1,621,687.60 3.86 6,136.41 MWD+IFR-AK-CAZ-SC(3) 9,379.30 71.48 283.57 5,942.18 5,801.39 1,248.15 -6,210.34 5,949,993.25 1,621,643.18 5.71 6,181.10 MWD+IFR-AK-CAZ-SC(3) 9,425.44 73.66 284.20 5,956.00 5,815.21 1,258.72 -6,253.07 5,950,003.88 1,621,600.47 4.90 6,224.43 MWD+IFR-AK-CAZ-SC(3) 9,476.88 76.65 285.87 5,969.18 5,828.39 1,271.62 -6,301.08 5,950,016.86 1,621,552.49 6.61 6,273.54 MWD+IFR-AK-CAZ-SC(3) 9,518.00 77.72 287.29 5,978.30 5,837.51 1,283.06 -6,339.51 5,950,028.37 1,621,514.08 4.26 6,313.30 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 9,553.48 78.65 288.51 5,985.57 5,844.78 1,293.74 -6,372.56 5,950,039.10 1,621,481.06 4.26 6,347.83 MWD+IFR-AK-CAZ-SC(4) 9,594.43 79.30 287.33 5,993.40 5,852.61 1,306.11 -6,410.80 5,950,051.53 1,621,442.84 3.24 6,387.80 MWD+IFR-AK-CAZ-SC(4) 9,632.60 79.70 285.84 6,000.35 5,859.56 1,316.82 -6,446.77 5,950,062.30 1,621,406.89 3.98 6,425.01 MWD+IFR-AK-CAZ-SC(4) 9,727.57 80.50 286.78 6,016.68 5,875.89 1,343.09 -6,536.56 5,950,088.72 1,621,317.16 1.29 6,517.73 MWD+IFR-AK-CAZ-SC(4) 9,822.18 81.40 286.15 6,031.56 5,890.77 1,369.57 -6,626.16 5,950,115.35 1,621,227.61 1.16 6,610.35 MWD+IFR-AK-CAZ-SC(4) 9,917.09 82.37 285.50 6,044.96 5,904.17 1,395.19 -6,716.55 5,950,141.12 1,621,137.27 1.23 6,703.35 MWD+IFR-AK-CAZ-SC(4) 10,012.21 83.19 286.27 6,056.92 5,916.13 1,421.02 -6,807.31 5,950,167.09 1,621,046.56 1.18 6,796.77 MWD+IFR-AK-CAZSC(4) 10,107.07 85.78 285.91 6,066.03 5,925.24 1,447.19 -6,898.03 5,950,193.41 1,620,955.90 2.76 6,890.29 MWD+IFR-AK-CAZ-SC(4) 10,201.59 87.52 285.86 6,071.55 5,930.76 1,473.01 -6,988.78 5,950,219.38 1,620,865.20 1.84 6,983.70 MWD+IFR-AK-CAZ-SC(4) 10,296.66 90.64 285.79 6,073.08 5,932.29 1,498.93 -7,080.22 5,950,245.45 1,620,773.81 3.28 7,077.78 MWD+IFR-AK-CAZ-SC(4) 10,391.75 91.10 286.25 6,071.64 5,930.85 1,525.17 -7,171.61 5,950,271.84 1,620,682.47 0.68 7,171.93 MWD+IFR-AK-CAZ-SC(4) 10,486.63 90.45 286.12 6,070.35 5,929.56 1,551.62 -7,262.72 5,950,298.43 1,620,591.42 0.70 7,265.92 MWD+IFR-AK-CAZ-SC(4) 10,581.22 89.97 286.44 6,070.01 5,929.22 1,578.13 -7,353.52 5,950,325.10 1,620,500.67 0.61 7,359.66 MWD+IFR-AK-CAZ-SC(4) 10,676.50 89.52 290.25 6,070.43 5,929.64 1,608.11 -7,443.94 5,950,355.23 1,620,410.31 4.03 7,454.45 MWD+IFR-AK-CAZSC(4) 10,771.03 89.87 291.23 6,070.93 5,930.14 1,641.59 -7,532.34 5,950,388.85 1,620,321.98 1.10 7,548.83 MWD+IFR-AK-CAZSC(4) 10,865.50 90.35 293.64 6,070.75 5,929.96 1,677.64 -7,619.65 5,950,425.04 1,620,234.73 2.60 7,643.25 MWD+IFR-AK-CAZ-SC(4) 10,960.54 91.17 295.97 6,069.49 5,928.70 1,717.50 -7,705.91 5,950,465.05 1,620,148.55 2.60 7,738.27 MWD+IFR-AK-CAZ-SC(4) 11,056.15 91.24 296.74 6,067.48 5,926.69 1,759.94 -7,791.56 5,950,507.62 1,620,062.98 0.81 7,833.78 MWD+IFR-AK-CAZ-SC(4) 11,150.66 91.24 296.85 6,065.44 5,924.65 1,802.53 -7,875.90 5,950,550.35 1,619,978.71 0.12 7,928.15 MWD+IFR-AK-CAZ-SC(4) 11,254.24 91.17 296.19 6,063.26 5,922.47 1,848.77 -7,968.56 5,950,596.74 1,619,886.14 0.64 8,031.61 MWD+IFR-AK-CAZ-SC(4) 11,346.37 91.27 295.72 6,061.30 5,920.51 1,889.09 -8,051.38 5,950,637.19 1,619,803.40 0.52 8,123.66 MWD+IFR-AK-CAZ-SC(4) 11,434.62 91.51 293.60 6,059.16 5,918.37 1,925.89 -8,131.56 5,950,674.13 1,619,723.29 2.42 8,211.88 MWD+IFR-AK-CAZSC(4) 11,528.89 91.62 293.26 6,056.58 5,915.79 1,963.36 -8,218.02 5,950,711.74 1,619,636.90 0.38 8,306.11 MWD+IFR-AK-CAZ-SC(4) 1/13/2015 12:54:29PM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,623.97 87.64 292.47 6,057.19 5,916.40 2,000.30 -8,305.61 5,950,748.81 1,619,549.38 4.27 8,401.15 MWD+IFR-AK-CAZ-SC(4) 11,716.10 87.53 294.22 6,061.08 5,920.29 2,036.77 -8,390.12 5,950,785.43 1,619,464.94 1.90 8,493.19 MWD+IFR-AK-CAZ-SC(4) 11,811.37 88.49 296.46 6,064.39 5,923.60 2,077.52 -8,476.16 5,950,826.31 1,619,378.97 2.56 8,588.36 MWD+IFR-AK-CAZ-SC(4) 11,908.96 89.01 296.72 6,066.51 5,925.72 2,121.19 -8,563.41 5,950,870.13 1,619,291.81 0.60 8,685.83 MWD+IFR-AK-CAZ-SC(4) 12,003.61 89.04 298.20 6,068.13 5,927.34 2,164.83 -8,647.38 5,950,913.90 1,619,207.92 1.56 8,780.29 MWD+IFR-AK-CAZ-SC(4) 12,098.06 89.32 298.02 6,069.48 5,928.69 2,209.33 -8,730.68 5,950,958.53 1,619,124.70 0.35 8,874.49 MWD+IFR-AK-CAZ-SC(4) 12,193.90 89.80 296.40 6,070.21 5,929.42 2,253.15 -8,815.91 5,951,002.49 1,619,039.55 1.76 8,970.17 MWD+IFR-AK-CAZ-SC(4) 12,288.37 90.83 294.01 6,069.69 5,928.90 2,293.38 -8,901.38 5,951,042.85 1,618,954.16 2.75 9,064.61 MWD+IFR-AK-CAZ-SC(4) 12,380.84 91.55 292.53 6,067.77 5,926.98 2,329.90 -8,986.30 5,951,079.52 1,618,869.31 1.78 9,157.05 MWD+IFR-AK-CAZ-SC(4) 12,477.63 92.95 290.02 6,063.97 5,923.18 2,364.99 -9,076.42 5,951,114.75 1,618,779.26 2.97 9,253.65 MWD+IFR-AK-CAZ-SC(4) 12,566.48 93.77 291.00 6,058.76 5,917.97 2,396.06 -9,159.49 5,951,145.96 1,618,696.25 1.44 9,342.18 MWD+IFR-AK-CAZ-SC(4) 12,663.95 94.51 291.63 6,051.73 5,910.94 2,431.40 -9,250.06 5,951,181.45 1,618,605.75 1.00 9,439.29 MWD+IFR-AK-CAZ-SC(4) 12,760.21 93.28 292.10 6,045.19 5,904.40 2,467.17 -9,339.18 5,951,217.36 1,618,516.69 1.37 9,535.26 MWD+IFR-AK-CAZ-SC(4) 12,855.41 94.19 292.97 6,038.99 5,898.20 2,503.57 -9,426.93 5,951,253.91 1,618,429.02 1.32 9,630.22 MWD+IFR-AK-CAZ-SC(4) 12,953.64 95.18 293.02 6,030.96 5,890.17 2,541.82 -9,517.05 5,951,292.30 1,618,338.97 1.01 9,728.11 MWD+IFR-AK-CAZ-SC(4) 12,993.00 95.18 293.02 6,027.41 5,886.62 2,557.15 -9,553.13 5,951,307.69 1,618,302.92 0.00 9,767.30 PROJECTED to TD 4 1/2"x 6-1/2" 13,013.00 95.18 293.02 6,025.61 5,884.82 2,564.94 -9,571.46 5,951,315.51 1,618,284.60 0.00 9,787.21 PROJECTED to TD Projected to TD 1/13/2015 12:54:29PM Page 6 COMPASS 5000.1 Build 65 RECJVED 2 1 4 1 02 25394 FEB Y 0 2015 $chlumbernerAoGCC Drilling & Measurements Transmittal#: 10FEB15-SPO2 DATA LOGGED MWD/LWD Log Product Delivery 2 i‘l/2015 M BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2M-36 PB1 Date Dispatched: 10-Feb-15 Job#: 14AKA0178 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x _ VISION*Service 5'MD x _ x VISION*Service 5'TVD x x VISION*Service 2"SSTVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(a�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 17076—e4teeit L Received By: '14/2-ami Dov 214102 25394 RECEIVED FEB 10 2015 FINAL AOGCC NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-36PB1 Definitive Survey Report N A D 2 13 January, 2015 v Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36©140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-36 Well Position +N/-S 0.00 usft Northing: 5,948,984.77 usft Latitude: 70°16'18.567 N +E/-W 0.00 usft Easting: 487,817.93 usft Longitude: 150°5'54.693 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-36PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGG M2014 11/7/2014 18.97 80.84 57,564 Design 2M-36PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.49 Vertical Section: Depth From(ND) +NI-S +E/-W Direction (usft) (usft) (usft) (°) 39.49 0.00 0.00 294.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.00 1,130.00 2M-36PB1 Srvy#1-GYD-GC-MS(2M-3 GYD-GC-MS Gyrodata gyrocompassing m/s 11/11/2014 5:57 1,189.55 3,270.06 2M-36PB1 Srvy#2-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2014 6:00 3,342.00 7,954.98 2M-36PB1 Srvy#3-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/25/2014 11:0: Survey Map Map Vertical MD Inc Azi ND TVDSS +N/S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.49 0.00 0.00 39.49 -101.30 0.00 0.00 5,948,984.77 487,817.93 0.00 0.00 UNDEFINED 97.00 0.40 256.40 97.00 -43.79 -0.05 -0.20 5,948,984.72 487,817.73 0.70 0.16 GYD-GC-MS(1) 188.00 0.66 258.57 188.00 47.21 -0.23 -1.02 5,948,984.54 487,816.91 0.29 0.84 GYD-GC-MS(1) 278.00 1.50 353.59 277.98 137.19 0.84 -1.66 5,948,985.61 487,816.27 1.88 1.86 GYD-GC-MS(1) 374.00 1.57 3.93 373.95 233.16 3.40 -1.71 5,948,988.17 487,816.22 0.30 2.94 GYD-GC-MS(1) 470.00 3.33 343.60 469.86 329.07 7.39 -2.40 5,948,992.16 487,815.53 2.02 5.20 GYD-GC-MS(1) 564.00 3.91 343.60 563.67 422.88 13.08 -4.08 5,948,997.86 487,813.87 0.62 9.05 GYD-GC-MS(1) 657.00 4.61 349.66 656.41 515.62 19.80 -5.65 5,949,004.58 487,812.31 0.89 13.21 GYD-GC-MS(1) 753.00 6.06 352.48 752.00 611.21 28.62 -7.00 5,949,013.40 487,810.97 1.53 18.04 GYD-GC-MS(1) 847.00 8.16 349.61 845.27 704.48 40.10 -8.85 5,949,024.88 487,809.14 2.27 24.40 GYD-GC-MS(1) 943.00 11.06 345.45 939.91 799.12 55.72 -12.40 5,949,040.50 487,805.62 3.10 33.99 GYD-GC-MS(1) 1,037.00 11.05 339.54 1,032.17 891.38 72.89 -17.81 5,949,057.68 487,800.23 1.21 45.92 GYD-GC-MS(1) 1/13/2015 12:39:51PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36©140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36©140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 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 1,130.00 11.98 340.75 1,123.30 982.51 90.35 -24.11 5,949,075.15 487,793.97 1.03 58.77 GYD-GC-MS(1) 1,189.55 12.88 341.70 1,181.45 1,040.66 102.49 -28.23 5,949,087.29 487,789.86 1.55 67.48 MWD+IFR-AK-CAZ-SC(2) 1,284.12 15.84 341.23 1,273.06 1,132.27 124.72 -35.70 5,949,109.53 487,782.44 3.13 83.34 MWD+IFR-AK-CAZ-SC(2) 1,379.49 18.29 338,03 1,364.22 1,223.43 150.93 -45.48 5,949,135.75 487,772.69 2.75 102.94 MWD+IFR-AK-CAZ-SC(2) 1,473.73 18.90 334.84 1,453.55 1,312.76 178.46 -57.51 5,949,163.30 487,760.72 1.26 125.12 MWD+IFR-AK-CAZ-SC(2) 1,567.09 20.43 332.70 1,541.46 1,400.67 206.62 -71.41 5,949,191.49 487,746.86 1.81 149.28 MWD+IFR-AK-CAZ-SC(2) 1,661.80 22.52 326.67 1,629.60 1,488.81 236.47 -88.96 5,949,221.36 487,729.36 3.21 177.45 MWD+IFR-AK-CAZ-SC(2) 1,756.34 24.83 319.91 1,716.19 1,575.40 266.80 -111.70 5,949,251.72 487,706.67 3.77 210.56 MWD+IFR-AK-CAZ-SC(2) 1,851.38 25.64 313.44 1,802.18 1,661.39 296.21 -139.48 5,949,281.17 487,678.94 3.02 247.90 MWD+IFR-AK-CAZ-SC(2) 1,947.09 27.21 304.48 1,887.92 1,747.13 322.85 -172.57 5,949,307.86 487,645.89 4.47 288.97 MWD+IFR-AK-CAZ-SC(2) 2,040.24 28.97 298.65 1,970.11 1,829.32 345.72 -209.94 5,949,330.80 487,608.57 3.50 332.40 MWD+IFR-AK-CAZ-SC(2) 2,134.21 30.55 295.28 2,051.69 1,910.90 366.84 -251.51 5,949,351.97 487,567.04 2.45 378.97 MWD+IFR-AK-CAZ-SC(2) 2,230.79 32.20 291.54 2,134.15 1,993.36 386.77 -297.64 5,949,371.98 487,520.94 2.64 429.23 MWD+IFR-AK-CAZ-SC(2) 2,323.31 34.82 286.65 2,211.30 2,070.51 403.39 -345.90 5,949,388.68 487,472.72 4.06 480.07 MWD+IFR-AK-CAZ-SC(2) 2,421.48 38.39 285.23 2,290.10 2,149.31 419.44 -402.18 5,949,404.81 487,416.46 3.74 538.01 MWD+IFR-AK-CAZ-SC(2) 2,516.85 41.43 283.48 2,363.25 2,222.46 434.58 -461.45 5,949,420.05 487,357.22 3.40 598.32 MWD+IFR-AK-CAZ-SC(2) 2,607.79 45.83 283.41 2,429.05 2,288.26 449.16 -522.47 5,949,43.4.73 487,296.24 4.84 659.99 MWD+IFR-AK-CAZ-SC(2) 2,702.41 48.87 282.96 2,493.15 2,352.36 465.03 -590.22 5,949,450.70 487,228.52 3.23 728.34 MWD+IFR-AK-CAZ-SC(2) 2,753.16 52.41 283.63 2,525.33 2,384.54 474.05 -628.40 5,949,459.79 487,190.36 7.05 766.89 MWD+IFR-AK-CAZ-SC(2) 2,796.75 53.90 282.80 2,551.47 2,410.68 482.03 -662.36 5,949,467.82 487,156.41 3.74 801.15 MWD+IFR-AK-CAZ-SC(2) 2,892.13 56.55 278.98 2,605.88 2,465.09 496.78 -739.27 5,949,482.69 487,079.53 4.31 877.42 MWD+IFR-AK-CAZ-SC(2) 2,985.78 58.27 278.81 2,656.32 2,515,53 508.98 -817.22 5,949,495.02 487,001.61 1.84 953.59 MWD+IFR-AK-CAZ-SC(2) 3,080.36 59.34 278.31 2,705.31 2,564.52 521.02 -897.23 5,949,507.19 486,921.63 1.22 1,031.57 MWD+IFR-AK-CAZ-SC(2) 3,174.51 59.40 276.62 2,753.28 2,612.49 531.54 -977.55 5,949,517.84 486,841.34 1.55 1,109.23 MWD+IFR-AK-CAZ-SC(2) 3,270.06 60.47 275.76 2,801.15 2,660.36 540.46 -1,059.76 5,949,526.89 486,759.15 1.36 1,187.96 MWD+IFR-AK-CAZ-SC(2) 3,342.00 60.79 276.41 2,836.43 2,695.64 547.10 -1,122.10 5,949,533.63 486,696.83 0.90 1,247.61 MWD+IFR-AK-CAZ-SC(3) 10-3/4"x 13-1/2" 3,424.27 61.17 277.15 2,876.34 2,735.55 555.60 -1,193.54 5,949,542.24 486,625.41 0.91 1,316.33 MWD+IFR-AK-CAZ-SC(3) 3,520.07 60.04 276.87 2,923.36 2,782.57 565.78 -1,276.38 5,949,552.56 486,542.60 1.21 1,396.15 MWD+IFR-AK-CAZ-SC(3) 3,613.34 60.17 276,52 2,969.85 2,829.06 575.21 -1,356.68 5,949,562.12 486,462.31 0.35 1,473.35 MWD+IFR-AK-CAZ-SC(3) 3,707.67 59.95 274.99 3,016.93 2,876.14 583.41 -1,438.01 5,949,570.44 486,381.01 1.42 1,550.98 MWD+IFR-AK-CAZ-SC(3) 3,802.22 60.28 271.05 3,064.06 2,923.27 587.72 -1,519.85 5,949,574.89 486,299.18 3.63 1,627.50 MWD+IFR-AK-CAZ-SC(3) 3,896.49 60.24 275.31 3,110.84 2,970.05 592.26 -1,601.55 5,949,579.56 486,217.50 3.92 1,703.98 MWD+IFR-AK-CAZ-SC(3) 3,991.21 60.15 274.67 3,157.92 3,017.13 599.41 -1,683.43 5,949,586.84 486,135.64 0.59 1,781.69 MWD+IFR-AK-CAZ-SC(3) 4,084.96 59.46 274.71 3,205.07 3,064.28 606.03 -1,764.19 5,949,593.60 486,054.90 0.74 1,858.16 MWD+IFR-AK-CAZ-SC(3) 4,179.37 58.02 274,98 3,254.06 3,113.27 612.85 -1,844.60 5,949,600.54 485,974.51 1.54 1,934.39 MWD+IFR-AK-CAZ-SC(3) 4,274.00 58.03 274.34 3,304.17 3,163.38 619.37 -1,924.60 5,949,607.19 485,894.52 0.57 2,010.14 MWD+IFR-AK-CAZ-SC(3) 4,368.13 58.37 273.92 3,353.77 3,212.98 625.13 -2,004.40 5,949,613.08 485,814.74 0.52 2,085.37 MWD+IFR-AK-CAZ-SC(3) 4,463.12 58.28 276.50 3,403.66 3,262.87 632.47 -2,084.89 5,949,620.55 485,734.27 2.31 2,161.89 MWD+IFR-AK-CAZ-SC(3) 4,557.40 57.67 281.18 3,453.67 3,312.88 644.74 -2,163.84 5,949,632.94 485,655.35 4.26 2,239.01 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:39:51PM Page 3 COMPASS 5000.1 Build 65 • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (11W) (ft) Survey Tool Name 4,652.38 57.68 281.22 3,504.46 3,363.67 660.33 -2,242.58 5,949,648.66 485,576.65 0.04 2,317.27 MWD+IFR-AK-CAZ-SC(3) 4,746.36 56.95 281.53 3,555.21 3,414.42 675.93 -2,320.12 5,949,664.38 485,499.14 0.82 2,394.46 MWD+IFR-AK-CAZ-SC(3) 4,841.02 56.91 279.21 3,606.87 3,466.08 690.21 -2,398.14 5,949,678.78 485,421.15 2.05 2,471.54 MWD+IFR-AK-CAZ-SC(3) 4,935.41 57.16 277.37 3,658.23 3,517.44 701.62 -2,476.50 5,949,690.33 485,342.81 1.66 2,547.77 MWD+IFR-AK-CAZ-SC(3) 5,030.19 56.98 277.88 3,709.76 3,568.97 712.18 -2,555.35 5,949,701.01 485,263.99 0.49 2,624.10 MWD+IFR-AK-CAZ-SC(3) 5,123.88 57.16 279.40 3,760.69 3,619.90 723.99 -2,633.09 5,949,712.95 485,186.27 1.38 2,699.92 MWD+IFR-AK-CAZ-SC(3) 5,220.50 57.02 278.75 3,813.19 3,672.40 736.78 -2,713.19 5,949,725.87 485,106.20 0.58 2,778.30 MWD+IFR-AK-CAZ-SC(3) 5,315.07 56.67 276.72 3,864.91 3,724.12 747.44 -2,791.64 5,949,736.65 485,027.78 1.83 2,854.30 MWD+IFR-AK-CAZ-SC(3) 5,409.46 57.07 276.79 3,916.50 3,775.71 756.74 -2,870.13 5,949,746.08 484,949.31 0.43 2,929.79 MWD+IFR-AK-CAZSC(3) 5,502.89 57.51 278.55 3,966.99 3,826.20 767.23 -2,948.04 5,949,756.70 484,871.43 1.65 3,005.23 MWD+IFR-AK-CAZ-SC(3) 5,597.53 57.88 278.51 4,017.57 3,876.78 779.10 -3,027.14 5,949,768.69 484,792.35 0.39 3,082.32 MWD+IFR-AK-CAZ-SC(3) 5,692.74 57.65 278.55 4,068.35 3,927.56 791.05 -3,106.79 5,949,780.76 484,712.73 0.24 3,159.94 MWD+IFR-AK-CAZ-SC(3) 5,787.06 57.52 277.27 4,118.91 3,978.12 802.00 -3,185.65 5,949,791.85 484,633.90 1.15 3,236.44 MVVD+IFR-AK-CAZ-SC(3) 5,882.36 58.02 275.80 4,169.74 4,028.95 811.17 -3,265.74 5,949,801.15 484,553.83 1.41 3,313.34 MWD+IFR-AK-CAZ-SC(3) 5,975.67 58.19 274.51 4,219.04 4,078.25 818.29 -3,34.4.64 5,949,808.39 484,474.95 1.19 3,388.31 MWD+IFR-AK-CAZSC(3) 6,070.59 57.93 275.44 4,269.26 4,128.47 825.28 -3,424.88 5,949,815.50 484,394.73 0.88 3,464.46 MWD+IFR-AK-CAZ-SC(3) 6,163.74 57.76 276.33 4,318.84 4,178.05 833.36 -3,503.33 5,949,823.71 484,316.30 0.83 3,539.41 MWD+IFR-AK-CAZSC(3) 6,259.40 57.68 277.62 4,369.93 4,229.14 843.18 -3,583.60 5,949,833.66 484,236.05 1.14 3,616.74 MWD+IFR-AK-CAZSC(3) 6,355.75 57.98 277.23 4,421.23 4,280.44 853.72 -3,664.48 5,949,844.33 484,155.20 0.46 3,694.90 MWD+IFR-AK-CAZSC(3) 6,448.76 57.97 276.35 4,470.55 4,329.76 863.04 -3,742.78 5,949,853.78 484,076.93 0.80 3,770.23 MWD+IFR-AK-CAZ-SC(3) 6,543.72 57.81 274.98 4,521.03 4,380.24 870.98 -3,822.81 5,949,861.85 483,996.91 1.23 3,846.58 MWD+IFR-AK-CAZSC(3) 6,638.29 57.79 275.13 4,571.42 4,430.63 878.04 -3,902.53 5,949,869.03 483,917.21 0.14 3,922.27 MWD+IFR-AK-CAZ-SC(3) 6,733.97 58.24 276.29 4,622.10 4,481.31 886.11 -3,983.28 5,949,877.24 483,836.49 1.13 3,999.32 MWD+IFR-AK-CAZ-SC(3) 6,829.05 57.75 278.26 4,672.50 4,531.71 896.32 -4,063.25 5,949,887.57 483,756.54 1.83 4,076.53 MVVD+IFR-AK-CAZ-SC(3) 6,924.07 57.37 279.25 4,723.47 4,582.68 908.52 -4,142.51 5,949,899.90 483,677.31 0.97 4,153.90 MWD+IFR-AK-CAZSC(3) 7,018.49 57.20 279.04 4,774.50 4,633.71 921.15 -4,220.94 5,949,912.65 483,598.91 0.26 4,230.68 MWD+IFR-AK-CAZ-SC(3) 7,113.16 57.26 279.81 4,825.74 4,684.95 934.18 -4,299.47 5,949,925.81 483,520.41 0.69 4,307.72 MWD+IFR-AK-CAZSC(3) 7,207.19 57.32 279.53 4,876.56 4,735.77 947.47 -4,377.46 5,949,939.23 483,442.44 0.26 4,384.38 MWD+IFR-AK-CAZ-SC(3) 7,303.81 57.39 279.86 4,928.68 4,787.89 961.17 -4,457.66 5,949,953.06 483,362.28 0.30 4,463.22 MWD+IFR-AK-CAZ-SC(3) 7,397.65 57.32 279.86 4,979.30 4,838.51 974.70 -4,535.50 5,949,966.71 483,284.46 0.07 4,539.84 MWD+IFR-AK-CAZSC(3) 7,494.11 57.35 279.00 5,031.36 4,890.57 988.01 -4,615.61 5,949,980.15 483,204.38 0.75 4,618.43 MWD+IFR-AK-CAZSC(3) 7,584.37 57.28 278.07 5,080.10 4,939.31 999.28 -4,690.73 5,949,991.54 483,129.28 0.87 4,691.64 MWD+IFR-AK-CAZSC(3) 7,682.29 56.83 277.39 5,133.35 4,992.56 1,010.34 -4,772.16 5,950,002.73 483,047.88 0.74 4,770.53 MWD+IFR-AK-CAZSC(3) 7,776.52 57.36 276.01 5,184.55 5,043.76 1,019.56 -4,850.73 5,950,012.08 482,969.34 1.35 4,846.06 M1MD+IFR-AK-CAZSC(3) 7,873.41 57.14 276.99 5,236.96 5,096.17 1,028.79 -4,931.69 5,950,021.43 482,888.40 0.88 4,923.77 MWD+IFR-AK-CAZSC(3) 7,954.98 57.12 276.69 5,281.23 5,140.44 1,036.95 -4,999.72 5,950,029.70 482,820.39 0.31 4,989.23 MWD+IFR-AK-CAZSC(3) 8,018.00 57.12 276.69 5,315.44 5,174.65 1,043.11 -5,052.28 5,950,035.95 482,767.84 0.00 5,039.76 PROJECTED to TD Projected to Bit 1/13/2015 12:39:51PM Page 4 COMPASS 5000.1 Build 65 214102 25394 RECEIVED FEB 10 2015 FINAL OGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-36PB1 Definitive Survey Report N A D 8 3] 13 January, 2015 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2M-36 Well Position +N/-S 0.00 usft Northing: 5,948,734.85 usft Latitude: 70°16'17.461 N +El-W 0.00 usft Easting: 1,627,850.81 usfl Longitude: 150°6'5.878 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-36PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2014 11/7/2014 18.97 80.84 57,564 Design 2M-36PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.49 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.49 0.00 0.00 294.00 Survey Program Date 1/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.00 1,130.00 2M-36PB1 Srvy#1 -GYD-GC-MS(2M-3 GYD-GC-MS Gyrodata gyrocompassing m/s 11/11/2014 5:: 1,189.55 3,270.06 2M-36PB1 Srvy#2-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2014 6:1 3,342.00 7,954.98 2M-36PB1 Srvy#3-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/25/2014 11 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 39.49 0.00 0.00 39.49 -101.30 0.00 0.00 5,948,734.85 1,627,850.81 0.00 0.00 UNDEFINED 97.00 0.40 256.40 97.00 -43.79 -0.05 -0.20 5,948,734.80 1,627,850.61 0.70 0.16 GYD-GC-MS(1) 188.00 0.66 258.57 188.00 47.21 -0.23 -1.02 5,948,734.63 1,627,849.79 0.29 0.84 GYD-GC-MS(1) 278.00 1.50 353.59 277.98 137.19 0.84 -1.66 5,948,735.69 1,627,849.15 1.88 1.86 GYD-GC-MS(1) 374.00 1.57 3.93 373.95 233.16 3.40 -1.71 5,948,738.26 1,627,849.11 0.30 2.94 GYD-GC-MS(1) 470.00 3.33 343.60 469.86 329.07 7.39 -2.40 5,948,742.24 1,627,848.42 2.02 5.20 GYD-GC-MS(1) 564.00 3.91 343.60 563.67 422.88 13.08 -4.08 5,948,747.94 1,627,846.75 0.62 9.05 GYD-GC-MS(1) 657.00 4.61 349.66 656.41 515.62 19.80 -5.65 5,948,754.66 1,627,845.20 0.89 13.21 GYD-GC-MS(1) 753.00 6.06 352.48 752.00 611.21 28.62 -7.00 5,948,763.48 1,627,843.86 1.53 18.04 GYD-GC-MS(1) 847.00 8.16 349.61 845.27 704.48 40.10 -8.85 5,948,774.96 1,627,842.02 2.27 24.40 GYD-GC-MS(1) 943.00 11.06 345.45 939.91 799.12 55.72 -12.40 5,948,790.59 1,627,838.51 3.10 33.99 GYD-GC-MS(1) 1,037.00 11.05 339.54 1,032.17 891.38 72.89 -17.81 5,948,807.76 1,627,833.12 1.21 45.92 GYD-GC-MS(1) 1/13/2015 12:56:59PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 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 1,130.00 11.98 340.75 1,123.30 982.51 90.35 -24.11 5,948,825.23 1,627,826.85 1.03 58.77 GYD-GC-MS(1) 1,189.55 12.88 341.70 1,181.45 1,040.66 102.49 -28.23 5,948,837.38 1,627,822.75 1.55 67.48 MWD+IFR-AK-CAZ-SC(2) 1,284.12 15.84 341.23 1,273.06 1,132.27 124.72 -35.70 5,948,859.62 1,627,815.33 3.13 83.34 MWD+IFR-AK-CAZ-SC(2) 1,379.49 18.29 338.03 1,364.22 1,223.43 150.93 -45.48 5,948,885.84 1,627,805.58 2.75 102.94 MWD+IFR-AK-CAZ-SC(2) 1,473.73 18.90 334.84 1,453.55 1,312.76 178.46 -57.51 5,948,913.38 1,627,793.61 1.26 125.12 MWD+IFR-AK-CAZ-SC(2) 1,567.09 20.43 332.70 1,541.46 1,400.67 206.62 -71.41 5,948,941.57 1,627,779.75 1.81 149.28 MWD+IFR-AK-CAZ-SC(2) 1,661.80 22.52 326.67 1,629.60 1,488.81 236.47 -88.96 5,948,971.45 1,627,762.25 3.21 177.45 MWD+IFR-AK-CAZ-SC(2) 1,756.34 24.83 319.91 1,716.19 1,575.40 266.80 -111.70 5,949,001.81 1,627,739.57 3.77 210.56 MWD+IFR-AK-CAZ-SC(2) 1,851.38 25.64 313.44 1,802.18 1,661.39 296.21 -139.48 5,949,031.26 1,627,711.83 3.02 247.90 MWD+IFR-AK-CAZ-SC(2) 1,947.09 27.21 304.48 1,887.92 1,747.13 322.85 -172.57 5,949,057.95 1,627,678.79 4.47 288.97 MWD+IFR-AK-CAZ-SC(2) 2,040.24 28.97 298.65 1,970.11 1,829.32 345.72 -209.94 5,949,080.89 1,627,641.47 3.50 332.40 MWD+IFR-AK-CAZ-SC(2) 2,134.21 30.55 295.28 2,051.69 1,910.90 366.84 -251.51 5,949,102.07 1,627,599.94 2.45 378.97 MWD+IFR-AK-CAZ-SC(2) 2,230.79 32.20 291.54 2,134.15 1,993.36 386.77 -297.64 5,949,122.08 1,627,553.84 2.64 429.23 MWD+IFR-AK-CAZ-SC(2) 2,323.31 34.82 286.65 2,211.30 2,070.51 403.39 -345.90 5,949,138.78 1,627,505.62 4.06 480.07 MWD+IFR-AK-CAZ-SC(2) 2,421.48 38.39 285.23 2,290.10 2,149.31 419.44 -402.18 5,949,154.92 1,627,449.37 3.74 538.01 MWD+IFR-AK-CAZ-SC(2) 2,516.85 41.43 283.48 2,363.25 2,222.46 434.58 -461.45 5,949,170.15 1,627,390.13 3.40 598.32 MWD+IFR-AK-CAZ-SC(2) 2,607.79 45.83 283.41 2,429.05 2,288.26 449.16 -522.47 5,949,184.84 1,627,329.14 4.84 659.99 MWD+IFR-AK-CAZ-SC(2) 2,702.41 48.87 282.96 2,493.15 2,352.36 465.03 -590.22 5,949,200.82 1,627,261.43 3.23 728.34 MWD+IFR-AK-CAZ-SC(2) 2,753.16 52.41 283.63 2,525.33 2,384.54 474.05 -628.40 5,949,209.91 1,627,223.26 7.05 766.89 MWD+IFR-AK-CAZ-SC(2) 2,796.75 53.90 282.80 2,551.47 2,410.68 482.03 -662.36 5,949,217.93 1,627,189.32 3.74 801.15 MWD+IFR-AK-CAZ-SC(2) 2,892.13 56.55 278.98 2,605.88 2,465.09 496.78 -739.27 5,949,232.81 1,627,112.44 4.31 877.42 MWD+IFR-AK-CAZ-SC(2) 2,985.78 58.27 278.81 2,656.32 2,515.53 508.98 -817.22 5,949,245.14 1,627,034.52 1.84 953.59 MWD+IFR-AK-CAZ-SC(2) 3,080.36 59.34 278.31 2,705.31 2,564.52 521.02 -897.23 5,949,257.32 1,626,954.55 1.22 1,031.57 MWD+IFR-AK-CAZ-SC(2) 3,174.51 59.40 276.62 2,753.28 2,612.49 531.54 -977.55 5,949,267.97 1,626,874.25 1.55 1,109.23 MWD+IFR-AK-CAZ-SC(2) 3,270.06 60.47 275.76 2,801.15 2,660.36 540.46 -1,059.76 5,949,277.02 1,626,792.06 1.36 1,187.96 MWD+IFR-AK-CAZ-SC(2) 3,342.00 60.79 276.41 2,836.43 2,695.64 547.10 -1,122.10 5,949,283.77 1,626,729.74 0.90 1,247.61 MWD+IFR-AK-CAZ-SC(3) 10-3/4"x 13-1/2" 3,424.27 61.17 277.15 2,876.34 2,735.55 555.60 -1,193.54 5,949,292.38 1,626,658.32 0.91 1,316.33 MWD+IFR-AK-CAZ-SC(3) 3,520.07 60.04 276.87 2,923.36 2,782.57 565.78 -1,276.38 5,949,302.71 1,626,575.51 1.21 1,396.15 MWD+IFR-AK-CAZ-SC(3) 3,613.34 60.17 276.52 2,969.85 2,829.06 575.21 -1,356.68 5,949,312.27 1,626,495.22 0.35 1,473.35 MWD+IFR-AK-CAZ-SC(3) 3,707.67 59.95 274.99 3,016.93 2,876.14 583.41 -1,438.01 5,949,320.60 1,626,413.92 1.42 1,550.98 MWD+IFR-AK-CAZ-SC(3) 3,802.22 60.28 271.05 3,064.06 2,923.27 587.72 -1,519.85 5,949,325.05 1,626,332.10 3.63 1,627.50 MWD+IFR-AK-CAZ-SC(3) 3,896.49 60.24 275.31 3,110.84 2,970.05 592.26 -1,601.55 5,949,329.72 1,626,250.41 3.92 1,703.98 MWD+IFR-AK-CAZ-SC(3) 3,991.21 60.15 274.67 3,157.92 3,017.13 599.41 -1,683.43 5,949,337.01 1,626,168.55 0.59 1,781.69 MWD+IFR-AK-CAZ-SC(3) 4,084.96 59.46 274.71 3,205.07 3,064.28 606.03 -1,764.19 5,949,343.77 1,626,087.82 0.74 1,858.16 MWD+IFR-AK-CAZ-SC(3) 4,179.37 58.02 274.98 3,254.06 3,113.27 612.85 -1,844.60 5,949,350.72 1,626,007.42 1.54 1,934.39 MWD+IFR-AK-CAZ-SC(3) 4,274.00 58.03 274.34 3,304.17 3,163.38 619.37 -1,924.60 5,949,357.37 1,625,927.43 0.57 2,010.14 MWD+IFR-AK-CAZ-SC(3) 4,368.13 58.37 273.92 3,353.77 3,212.98 625.13 -2,004.40 5,949,363.27 1,625,847.66 0.52 2,085.37 MWD+IFR-AK-CAZ-SC(3) 4,463.12 58.28 276.50 3,403.66 3,262.87 632.47 -2,084.89 5,949,370.74 1,625,767.18 2.31 2,161.89 MWD+IFR-AK-CAZ-SC(3) 4,557.40 57.67 281.18 3,453.67 3,312.88 644.74 -2,163.84 5,949,383.14 1,625,688.26 4.26 2,239.01 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:56:59PM Page 3 COMPASS 5000.1 Build 65 • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,652.38 57.68 281.22 3,504.46 3,363.67 660.33 -2,242.58 5,949,398.86 1,625,609.56 0.04 2,317.27 MWD+IFR-AK-CAZ-SC(3) 4,746.36 56.95 281.53 3,555.21 3,414.42 675.93 -2,320.12 5,949,414.58 1,625,532.05 0.82 2,394.46 MWD+IFR-AK-CAZ-SC(3) 4,841.02 56.91 279.21 3,606.87 3,466.08 690.21 -2,398.14 5,949,428.99 1,625,454.06 2.05 2,471.54 MWD+IFR-AK-CAZSC(3) 4,935.41 57.16 277.37 3,658.23 3,517.44 701.62 -2,476.50 5,949,440.53 1,625,375.73 1.66 2,547.77 MWD+IFR-AK-CAZSC(3) 5,030.19 56.98 277.88 3,709.76 3,568.97 712.18 -2,555.35 5,949,451.22 1,625,296.91 0.49 2,624.10 MWD+IFR-AK-CAZSC(3) 5,123.88 57.16 279.40 3,760.69 3,619.90 723.99 -2,633.09 5,949,463.16 1,625,219.19 1.38 2,699.92 MWD+IFR-AK-CAZ-SC(3) 5,220.50 57.02 278.75 3,813.19 3,672.40 736.78 -2,713.19 5,949,476.09 1,625,139.13 0.58 2,778.30 MWD+IFR-AK-CAZ-SC(3) 5,315.07 56.67 276.72 3,864.91 3,724.12 747.44 -2,791.64 5,949,486.88 1,625,060.70 1.83 2,854.30 MWD+IFR-AK-CAZ-SC(3) 5,409.46 57.07 276.79 3,916.50 3,775.71 756.74 -2,870.13 5,949,496.31 1,624,982.23 0.43 2,929.79 MWD+IFR-AK-CAZ-SC(3) 5,502.89 57.51 278.55 3,966.99 3,826.20 767.23 -2,948.04 5,949,506.93 1,624,904.35 1.65 3,005.23 MWD+IFR-AK-CAZ-SC(3) 5,597.53 57.88 278.51 4,017.57 3,876.78 779.10 -3,027.14 5,949,518.92 1,624,825.27 0.39 3,082.32 MWD+IFR-AK-CAZ-SC(3) 5,692.74 57.65 278.55 4,068.35 3,927.56 791.05 -3,106.79 5,949,531.00 1,624,745.66 0.24 3,159.94 MWD+IFR-AK-CAZ-SC(3) 5,787.06 57.52 277.27 4,118.91 3,978.12 802.00 -3,185.65 5,949,542.09 1,624,666.82 1.15 3,236.44 MWD+IFR-AK-CAZ-SC(3) 5,882.36 58.02 275.80 4,169.74 4,028.95 811.17 -3,265.74 5,949,551.39 1,624,586.76 1.41 3,313.34 MWD+IFR-AK-CAZ-SC(3) 5,975.67 58.19 274.51 4,219.04 4,078.25 818.29 -3,344.64 5,949,558.64 1,624,507.88 1.19 3,388.31 MWD+IFR-AK-CAZ-SC(3) 6,070.59 57.93 275.44 4,269.26 4,128.47 825.28 -3,424.88 5,949,565.76 1,624,427.65 0.88 3,464.46 MWD+IFR-AK-CAZ-SC(3) 6,163.74 57.76 276.33 4,318.84 4,178.05 833.36 -3,503.33 5,949,573.98 1,624,349.23 0.83 3,539.41 MWD+IFR-AK-CAZ-SC(3) 6,259.40 57.68 277.62 4,369.93 4,229.14 843.18 -3,583.60 5,949,583.93 1,624,268.98 1.14 3,616.74 MWD+IFR-AK-CAZ-SC(3) 6,355.75 57.98 277.23 4,421.23 4,280.44 853.72 -3,664.48 5,949,594.60 1,624,188.13 0.46 3,694.90 MWD+IFR-AK-CAZ-SC(3) 6,448.76 57.97 276.35 4,470.55 4,329.76 863.04 -3,742.78 5,949,604.06 1,624,109.85 0.80 3,770.23 MWD+IFR-AK-CAZ-SC(3) 6,543.72 57.81 274.98 4,521.03 4,380.24 870.98 -3,822.81 5,949,612.13 1,624,029.84 1.23 3,846.58 MWD+IFR-AK-CAZ-SC(3) 6,638.29 57.79 275.13 4,571.42 4,430.63 878.04 -3,902.53 5,949,619.31 1,623,950.14 0.14 3,922.27 MWD+IFR-AK-CAZ-SC(3) 6,733.97 58.24 276.29 4,622.10 4,481.31 886.11 -3,983.28 5,949,627.52 1,623,869.42 1.13 3,999.32 MWD+IFR-AK-CAZ-SC(3) 6,829.05 57.75 278.26 4,672.50 4,531.71 896.32 -4,063.25 5,949,637.86 1,623,789.47 1.83 4,076.53 MWD+IFR-AK-CAZ-SC(3) 6,924.07 57.37 279.25 4,723.47 4,582.68 908.52 -4,142.51 5,949,650.20 1,623,710.24 0.97 4,153.90 MWD+IFR-AK-CAZ-SC(3) 7,018.49 57.20 279.04 4,774.50 4,633.71 921.15 -4,220.94 5,949,662.95 1,623,631.84 0.26 4,230.68 MWD+IFR-AK-CAZ-SC(3) 7,113.16 57.26 279.81 4,825.74 4,684.95 934.18 -4,299.47 5,949,676.12 1,623,553.34 0.69 4,307.72 MWD+IFR-AK-CAZ-SC(3) 7,207.19 57.32 279.53 4,876.56 4,735.77 947.47 -4,377.46 5,949,689.54 1,623,475.37 0.26 4,384.38 MWD+IFR-AK-CAZ-SC(3) 7,303.81 57.39 279.86 4,928.68 4,787.89 961.17 -4,457.66 5,949,703.37 1,623,395.21 0.30 4,463.22 MWD+IFR-AK-CAZ-SC(3) 7,397.65 57.32 279.86 4,979.30 4,838.51 974.70 -4,535.50 5,949,717.03 1,623,317.39 0.07 4,539.84 MWD+IFR-AK-CAZ-SC(3) 7,494.11 57.35 279.00 5,031.36 4,890.57 988.01 -4,615.61 5,949,730.46 1,623,237.32 0.75 4,618.43 MWD+IFR-AK-CAZ-SC(3) 7,584.37 57.28 278.07 5,080.10 4,939.31 999.28 -4,690.73 5,949,741.86 1,623,162.22 0.87 4,691.64 MWD+IFR-AK-CAZ-SC(3) 7,682.29 56.83 277.39 5,133.35 4,992.56 1,010.34 -4,772.16 5,949,753.05 1,623,080.82 0.74 4,770.53 MWD+IFR-AK-CAZSC(3) 7,776.52 57.36 276.01 5,184.55 5,043.76 1,019.56 -4,850.73 5,949,762.41 1,623,002.27 1.35 4,846.06 MWD+IFR-AK-CAZ-SC(3) 7,873.41 57.14 276.99 5,236.96 5,096.17 1,028.79 -4,931.69 5,949,771.77 1,622,921.33 0.88 4,923.77 MWD+I FR-AK-CAZ-SC(3) 7,954.98 57.12 276.69 5,281.23 5,140.44 1,036.95 -4,999.72 5,949,780.04 1,622,853.33 0.31 4,989.23 MWD+IFR-AK-CAZ-SC(3) 8,018.00 57.12 276.69 5,315.44 5,174.65 1,043.11 -5,052.28 5,949,786.29 1,622,800.78 0.00 5,039.76 PROJECTED to TD Projected to Bit 1/13/2015 12.56.59PM Page 4 COMPASS 5000.1 Build 65 RECEIVED STATE OF ALASKA JAN 2 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND Olne la.Well Status: Oil ❑ • Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development E , Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: , January 5,2015 214-102/314-622' 3.Address: 6.Date Spudded: 13.API Number: P. O. Box 100360,Anchorage,AK 99510-0360 , November 10,2014 50-103-20691-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 113'FSL,22'FEL,Sec.28,T11 N, R8E, UM • December 27,2014 KRU 2M-36 and 2M-36PB1 Top of Productive Horizon: 8. KB(ft above MSL): 141'RKB 15.Field/Pool(s): 1465'FSL, 1316'FEL,Sec.29,T11 N, R8E, UM GL(ft above MSL): 101'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2609'FNL,4309'FEL, Sec.29,T11 N, R8E, UM 12993'MD/6027'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-487818 y- 5948985 Zone-4 • 13013'MD/6026'TVD ADL 25585,25586 TPI: x-481244 y- 5950350 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-478252 y- 5951565 Zone-4 nipple @ 516'MD/516'TVD 2672 18.Directional Survey: Yes ❑ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft LISL) 1495'MD/1474'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res 3410'MD/2866'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 164.8# H-40 38' 108' 38' 108' 24" Driven 10.75" 45.5# L-80 42' 3342' 42' 2837' 13.5" 1360 sx Class G, 194 sx Class G 7.625" 29.7&39# L-80&TN-110 38' 9518' 38' 5978' 9.875" 564 sx Class G 4.5" 12.6# L-80 9341' 12993' 5929' 6027' 6.75" 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) r PACKER SET(MD/TVD) 4.5 x 3.5 9358' 9341'MD/5929'TVD perf pups from 9877'-12972'MD 6038'-6029'TVD 9751'MD/6020'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes No •p C 1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED YE.VD isolation plug 1 from 7378-8018 407 sx Class G isolation plug 2 from 6748-7374 407 sx Class G �• ^»+.,, isolation plug 3 from 6210-6748 478 sx Class G isolation plug 4 from 3491-4036 377 sx Class G kick-off plug from 3142-3810 479 sx Class G 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 Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. psi 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No a If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form0-40.7 Revised 10/2012 CONTINUED ON REVERSE Submit original only � i'� v'TL 3/17-/),5- i� l/7./ RBDMSAk JAN 2 6 2015 Li 29. GEOLOGIC MARKERS(List all formations and mar, (countered). 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top - ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1495' 1474' needed,and submit detailed test information per 20 AAC 25 071 Top HRZ 8823' 5661' Top Kalubik 9157' 5854' Kuparuk C4 11322' 6062' Fault(A3 DT/A2 UT) 12003' 6068' 2M-36PB1 N/A total depth 8018' 5315' Formation at total depth: Kuparuk C4 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,cement detail sheets 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: David Lee @ 263-3741 Email David.L.Lee(a�conocophillips.com Printed Name G.Alvord Title A-asfp Drilling-Manager _ Signature rte. 1 — Phone 265-6120 � Date lel' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 s KUP PROD 2M-36 Conoc 'hiliips ; ell Attributes Max Angie&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Eeneor;rtnlhtn 501032069100 KUPARUK RIVER UNIT PROD 95.18 12,953.64 13,013.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-2M-36,3/10/201510.1704 AM SSSV:NIPPLE Last WO: 39.50 1/6/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date --- - HANGER;36.2---2 Last Tag: Rev Reason:GLV C/O,PULL RHC PLUG hipshkf 3/10/2015 yl . -a.Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 14.000 38.3 131.0 131.0 164.82 A-106 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len p...Grade Top Thread SURFACE 103/4 9.950 41.8 3,341.7 2,835.3 45.50 L-80 Hydril 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p,..Grade Top Thread XO Reducing;70.3INTERMEDIATE 75/8 6.875 38.5 9,517.8 5,978.0 29.70 L-80 Hydri1563 ..A.A.,CONDUCTOR;38.3731.0 1111..k. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(i...Grade Top Thread LINER 412 3.958 9,341.4 12,993.0 6,027.6 12.60 L-80 IBTM NIPPLE;516.2 Liner Details Nominal ID il Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 9,341.3 5,929.1 69.68 PACKER BAKER HRD-E SLZXP LINER TOP PACKER-0125 5.750 GAS LIFT;2,718.7 - HYD 563 PIN Ili9,363.4 5,936.6 70.72 NIPPLE 'BAKER RS PACKOFF SEAL NIPPLE-Q-125 HYD 4 250 563 BOX X BOX 9,365.7 5,937.4 70.83 HANGER BAKER FLEX-LOCK LINER HANGER-Q125 HYD 4.840 563 PIN X PIN 9,376.8 5,940.9 71.35 SBE BAKER 80-40 SEAL BORE EXT 4.010 SURFACE;47.83,341.7- 9,751.4 6,020.6 80.73 SWELL BAKER SELF ENERGIZING REACTIVE SWELL 3.940 GAS LIFT;4,504.2 - I PACKER PACKER W/TORQUE RING ` Tubing Strings GAS LIFT; l 5.545.9 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft,.Set Depth(TVD)(...Wt(INtt) Grade Top Connection TUBING-41/2x3 312 2.992 36.2 9,388.8 5,944.7 930 L-80 EUE E PI 12@70.27 Completion Details SLIDING SLEEVE;9,271.4-Hr ] Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not r) Item Des Com (in) NIPPLE;9328.5 I' 36.2 36.2 0.15 HANGER FMC HANGER TYPE"H"BPV ' 3.958 I 70.3 70.3 0.29 XO Reducing Crossover 4-1/2"12.6 ppf L-80 IBT-m x 3-1/2"9.3 ppf 3.000 EUE LOCATOR;9,356.4 516.2 516.0 3.62 NIPPLE CAMCO DS NIPPLE ' 2.875' SPACER SUB;83505 9,271.4 5,903.2 66.89 SLIDING BAKER CMU SLIDING SLEEVE W/2.813 DS PROFILE- ' 2.812 !I s SLEEVE RUN IN CLOSED POSITION 80-40 TUBE;9367.3 1r 9,326.5 5,923.9 69.02 NIPPLE CAMCO D NIPPLE 2.750 9,358.4 5,934.9 70.48 LOCATOR BAKER GBH-22 LOCATOR ABOVE 2.88'FROM FULLY 3.000 LOCATED SEALS,6377.4 • 9,358.5 5,935.0 70.49 SPACER SUB 80-40 SPACER SUB 3.000 80-40 TUBE;9,379.2 a 9,367.4 5,937.9 70.91 80-40 TUBE 80-40 spacer tube 3.000 11„,. 9,377.4 5,941.1 71.38 SEALS SEALS 3.000 I 9,379.2 5,941.7 71.47'80-40 TUBE 80-40 spacer tube 3.000 INTERMEDIATE;38.5-9,517.8Perforations&Slots Shot Dens Top(TVD) Biel(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (MB) Zone Date 1) Type Com iiiir9,876.6 9,886.4 6,039.5 6,040.8 1/3/2015 PERFP 4 1/2"PERF PUP 9,964.7 9,974.8 6,051.1 6,052.4 1/3/2015 PERFP 4 1/2"PERF PUP 10,547.2 10,557.0 6,070.1 6,070.0 1/3/2015 PERFP 4 1/2"PERF PUP _� 10,914.2 10,924.3 6,070.3 6,070.2 1/3/2015 PERFP 41/2"PERF PUP PERFP;9.876.69.886.4 - 11,254.6 11,2647 6,063.3 6,063.1 1/3/2015 PERFP 412"PERF PUP 11,653.2 11,663.0 6,058.5 6,058.9 1/3/2015 PERFP 41/2"PERF PUP 11,957.3 11,967.2 6,067.4' 6,067.6 1/3/2015 PERFP '4 12"PERF PUP PERFP;9,964.7-9,974.8 12,443.3 12,4532 6,065.7 6,065.3 '1/3/2015 PERFP 4 12"PERF PUP 12,627.0 12,636.8 6,054.7 6,054.0 1/3/2015 PERFP 4 12"PERF PUP 12,961.8 12,971.7 6,030.4 6,029.5' 1/3/2015 ' PERFP 4 1/2"PERF PUP - PERFP;10,547.2-10.557.0 Mandrel Inserts St a0 PERFP;10,914.2-10,924.3 en Top(TVD) Valve latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,718.7 2,503.7 Cemco '156AF0 GAS LIFT GLV BK 0.156 1,299.0'3/6/2015 7 2 4,504.2 3,367.3 Cemco 143AF0 1 GAS LIFT GLV BK 0.188 1,326.0 3/6/2015 PERFP;11.254.6.11.264.7 7 3 5,545.9 3,887.5 Cemco 140AFO 1'GAS LIFT OV 'BK 0.250 0.0'3/6/2015 7 PERFP;11.653.2-11063.0- t4� Notes:General&Safety �1.i� End Date Annotation NO1 E: PERFP;11,957,311,967.2 AM PERFP;12,443.312,453.2 - RECEIVEr PERFP;12,627.0-12 636.8 - MAR 2 5 20115 PERFP:12.961.612.9717lfluf- w OGC LINER,9,341.3.12993.0 a c s!/y'`OGCC 2M-36 Pick MD TVDSS BASE PERMAFROST 1495 1335 UGNU C 1385 1229 WEST SAK SAND 2091 1873 WEST SAK BASE 2863 2448 TOP HRZ 8823 5520 TOP KALUBIK 9157 5713 K-1 9355 5793 KUPARUK C 9769 5882 KUPARUK A3 9919 5904 C-4 INTERVAL 11322 5921 LOWER KALUBIK 11539 5916 C-4 INTERVAL 11642 5917 A-3 INTERVAL 12003 5927 Fault (A3 DT/A2 UT) 12147 5929 A-2 INTERVAL 12147 5929 A-3 INTERVAL 12376 5927 C-4 INTERVAL 12960 5889 TD (Kuparuk C4) 13014 5884 MD where entered Top of Fm at TD Fm at TD C4 12960 5880 • KPROD 2M-36 ConocoPhilli�s ' WelVributes • Max Angle&MD TD Alkarinc. Wellbore API/UWI Field Name Wellbore Status Incl(") MD(ftKB) Act Btm(ftKB) (:0,,ocd7tillips 501032069100 KUPARUK RIVER UNIT PROD 95.18 12,953.64 13,013.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2M-36,3/10/2015 10:17:04 AM SSSV:NIPPLE Last WO: 39.50 1/6/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;36.2 Last Tag: Rev Reason:GLV C/O,PULL RHC PLUG hipshkf 3/10/2015 c■ -.,,,,Casing Strings ,' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade lTop Thread CONDUCTOR 16 14.000 38.3 131.0 131.0 164.82 A-106 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 41.8 3,341.7 2,835.3 45.50 L-80 Hydril 563 Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread XO Reducing;70.3 I ¶_ INTERMEDIATE 7 5/8 6.875 38.5 9,517.8 5,978.0 29.70 L-80 Hydri1563 .-",.-^-,CONDUCTOR:38.3-131.0 _ILCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 9,341.4 12,993.0 6,027.6 12.60 L-80 IBTM NIPPLE:516.2 Liner Details Nominal ID Il - Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 9,341.3 5,929.1 69.68 PACKER BAKER HRD-E SLZXP LINER TOP PACKER-Q125 5.750 GAS LIFT;2,718.7 HYD 563 PIN 9,363.4 5,936.6 70.72 NIPPLE ,BAKER RS PACKOFF SEAL NIPPLE-Q-125 HYD 4.250 �. = 563BOXXBOX 9,365.7 5,937.4 70.83 HANGER BAKER FLEX-LOCK LINER HANGER-Q125 HYD 4.840 4.010 563 PIN X PIN 9,376.8 5,940.9 71.35 SBE BAKER 80-40 SEAL BORE EXT SURFACE;41.8-3,341.7 9,751.4 6,020.6 80.73 SWELL BAKER SELF ENERGIZING REACTIVE SWELL 3.940 GAS LIFT;4,5042 PACKER PACKER W/TORQUE RING Tubing Strings GAS LIFT;5,545.9 <--. Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Iblft) Grade Top Connection TUBING-4 1/2 x 3 3 1/2 2.992 36.2 9,388.8 5,944.7 9.30 L-80 EUE 1/2 @ 70.27 Completion Details SLIDING SLEEVE;9,271.4 -j, Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;9,326.5 - 36.2 36.2 0.15 HANGER FMC HANGER TYPE"H"BPV 3.958 70.3 70.3 0.29 XO Reducing Crossover 4-1/2"12.6 ppf L-80 IBT-m x 3-1/2"9.3 ppf 3.000 I EUE LOCATOR;9,358.4 516.2 516.0 3.62 NIPPLE CAMCO DS NIPPLE 2.875 a SPACER SUB:9,358.5 ■ 9,271.4 5,903.2 66.89 SLIDING BAKER CMU SLIDING SLEEVE W/2.813 DS PROFILE- 2.812 SLEEVE RUN IN CLOSED POSITION 80-40 TUBE:9,367.3 !i 1 9,326.5 5,923.9 69.02 NIPPLE CAMCO D NIPPLE 2.750 9,358.4 5,934.9 70.48 LOCATOR BAKER GBH-22 LOCATOR ABOVE 2.88'FROM FULLY 3.000 LOCATED SEALS;9,377.4 >� 9,358.5 5,935.0 70.49 SPACER SUB 80-40 SPACER SUB 3.000 80-40 TUBE;9,379.2IR 9,367.4 5,937.9 70.91 80-40 TUBE 80-40 spacer tube 3.000 9,377.4 5,941.1 71.38 SEALS SEALS 3.000 I 9,379.2 5,941.7 71.47 80-40 TUBE 80-40 spacer tube 3.000 INTERMEDIATE;38.5-9,517.8 ilkPerforations&Slots Shot Dens Top(TVD) Btm(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com liar 9,876.6 9,886.4' 6,039.5 6,040.8 1/3/2015 PERFP 4 1/2"PERF PUP 9,964.7 9,974.8' 6,051.1 6,052.4 1/3/2015 PERFP 4 1/2"PERF PUP 10,547.2' 10,557.0' 6,070.1 6,070.0 1/3/2015 PERFP 4 1/2"PERF PUP 10,914.2 10,924.3 6,070.3 6,070.2 1/3/2015 PERFP 4 1/2"PERF PUP PERFP;9,876.6-9,886.4 11,254.6 11,264.7 6,063.3 6,063.1 1/3/2015 PERFP 41/2"PERE PUP 11,653.2 11,663.0 6,058.5 6,058.9 1/3/2015 PERFP 41/2"PERF PUP 11,957.3 11,967.2 6,067.4 6,067.6 1/3/2015 PERFP 41/2"PERE PUP PERFP;9,964.7-9,974.8 . 12,443.3 12,453.2 6,065.7 6,065.3 1/3/2015 PERFP 41/2"PERF PUP I 12,627.0 12,636.8 6,054.7 6,054.0 1/3/2015 PERFP 4 1/2"PERF PUP 12,961.8 12,971.7 6,030.4 6,029.5 1/3/2015 PERFP 4 1/2"PERF PUP PERFP;10,547.2-10,557.0 ;.1l, I Mandrel Inserts St ati PERFP;10,914.2-10,924.3 s on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type T pe (iny ) (psi) Run Date Com I:: 1 2,718.7 2,503.7 Camco 156AF0 GAS LIFT GLV BK 0.156 1,299.0 3/6/2015 7 2 4,504.2 3,367.3 Camco 143AF0 1 GAS LIFT GLV BK - 0.188 1,326.0 3/6/2015 ME PERFP;11.254.6-11,264.7 . 7 I 3 5,545.9 3,887.5 Camco 140AF0 1 GAS LIFT OV BK 0.250 0.0 3/6/2015 7 Notes: General&Safety PERFP;11,653.2-11,663.0 };: l End Date Annotation NOTE: PERFP:11,957.3-11,967.2 : #;. I 1 PERFP:12.443.3-12,453.2 PERFP;12,627.0-12,636.8 PERFP;12,961.8-12,971.7 LINER;9,341.3-12,993.0 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 2M-36 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 11/9/2014 12:00:00 AM Rig Release: 1/6/2015 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/09/2014 24 hr Summary Finalize training, continue loading 5"drill pipe and HWDP. Fuction test diverter,AOGCC Johnnie Hill witnessed test. 00:00 06:00 6.00 0 0 MIRU MOVE SVRG P Retract cylinders on casing shed moving HPU and strap tank, C/O sub pressure washer pump with spare. Clean hot room. Remove expansion boot on charge pump#2 removed banding material from pump and inspect impeller. C/O expansion boot. Prep to extend diverter line. 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Load and strap 17 jts 5"HWDP and jars in pipe shed. Build ramp and step in cellar, continue housekeeping. 09:00 11:30 2.50 0 0 MIRU MOVE SFTY P Complete modules 5&6 of IFC training for C crew with Conoco safety and drilling reps. 11:30 12:00 0.50 0 0 MIRU MOVE SVRG P Continue housekeeping. SIMOPS- take on mud into rig pits. 12:00 13:00 1.00 0 0 MIRU MOVE SVRG P SPCC walkaround SIMOPS-Take on mud into rig pits. 13:00 14:30 1.50 0 0 MIRU MOVE SFTY P Attend PREP training for B crew with BEAR coach, RLG, Conoco safety and drilling reps. SIMOPS-Safety /critical pick meeting with DDI, CPAI and ASRC to add 16'section of diverter to line. 14:30 15:30 1.00 0 0 MIRU WHDBO BOPE P Perform diverter function and accumulator drawdown test, witnessed by AOGCC Johnnie Hill. Annular closed=29 sec, Knife valve fully open=l3 sec.Accumulator system pressure=3150 psi, Pressure after function=2200 psi,200 psi attained=14 sec, Full pressure attained=56 sec.6 bottle N2 avg=2083 psi. 15:30 17:30 2.00 0 0 MIRU MOVE PULD P M/U 6 stands HWDP, including 1 jt Jars. Rabbit pipe off skate with 2.5" nylon drift. SIMOPS-Remove short section of diverter line and replace with 22'section,adding 16'total to achieve 75'from nearest potential ignition source(Class I Div I light in cellar.) 17:30 22:00 4.50 0 0 MIRU MOVE RURD P Continue with housekeeping, PM's, roll in,strap and tally additional 68 jts 5"DP. Page 1 0164 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 MIRU MOVE PULD P M/U 19 stands and rack back in derrick. 11/10/2014 M/U BHA#1 and clean out conductor. P/U BHA#2 and drill to 327' MD/TVD.Troubleshoot MWD issues, hold pre-spud and diverter drills with crews. 00:00 00:45 0.75 0 0 SURFA( DRILL PULD P Continue to M/U 5"drill pipe stands, total 71 stands in derrick. 00:45 03:00 2.25 0 0 SURFA( DRILL RURD P Mobilize BHA components to rig floor. Clean pipe rack, load and strap BHA in pipe shed. Seal BOP opening with herculite. 03:00 03:30 0.50 0 0 SURFA( DRILL SEQP P Flush surface mud lines with water. Pressure test surface lines to 3500 psi. No leaks, blow down back to pump,verify 4.5 bbl from IBOP to pump HP mud line volume, plus 11 bbl low pressure line volume= 15.5 bbl surface line volume. 03:30 04:30 1.00 0 0 SURFA( DRILL RURD P Re-charge mud pumps,finish loading and mobilizing BHA. 04:30 05:30 1.00 0 0 SURFA( DRILL SFTY P Pre-spud meeting with CPAI Drilling Supervisor, issue H2S monitors to crew. Discuss diverting shallow gas concerns and drill procedures. 05:30 07:00 1.50 0 74 SURFA( DRILL PULD P M/U 13-1/2"BHA as per DD to 40', changed motor bend to 0°to clear conductor. P/U 1 stand HWDP, RIH and tag at 74' MD RKB. 07:00 08:30 1.50 74 74 SURFA( DRILL SFTY P Hold diverter drill with all hands, conduct AAR with rig crew. 08:30 09:00 0.50 74 74 SURFA( DRILL SEQP P Charge and function hole fill and jet pumps,fill conductor with 9.1 ppg Drilplex and check for leaks. Obtain parameters. 09:00 10:00 1.00 74 74 SURFA( DRILL SFTY P Perform rig orientation with truck drivers and supersucker drivers. Establish circulation/reciprocation from 55'to 70'@ 2 bpm, 50 psi. 10:00 12:30 2.50 74 250 SURFA( DRILL DRLG P Clean out conductor from 74'MD to 170.5', drill surface hole to 250'MD ©300 gpm, 300 psi,45 rpm, 1K tq, 1-2K WOB, P/U=55k, S/O=60k, ROT=58k, CBU x 2 at same rates. 12:30 13:30 1.00 250 0 SURFA( DRILL TRIP P POOH on elevators from 250'MD to surface. Remove clay from stabilizers and bit. Change motor deflection to 1.5°. 13:30 14:30 1.00 0 0 SURFA( DRILL PULD P M/U Gyro collar and XO. 14:30 15:00 0.50 0 0 SURFA( DRILL RURD P Upload MWD in pipeshed. 15:00 16:30 1.50 0 230 SURFA( DRILL PULD P M/U telescope,ARC and bottleneck XO. Scribe and orient. 16:30 17:00 0.50 230 230 SURFA( DRILL SRVY P Obtain surveys @ 450 gpm,410 psi. 17:00 20:00 3.00 230 230 SURFA( DRILL SRVY T Troubleshoot MWD/Gyro. Not applying correction to surveys. Page 2 of 64 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 `250 327 SURFA( DRILL DDRL P Continue drilling from 250'to 327'MD ©450 gpm,400 psi, 1-2k WOB, 50 rpm, 1-2k TQ, P/U=80k, S/0=65k, CBU x 2 while pulling stand to 237'. 20:30 21:30 1.00 327 141 SURFA( DRILL TRIP P POOH on elevators from 237'to ADN @ 141'. Monitor well via holefill, no problems noted. 21:30 22:30 1.00 141 141 SURFA( DRILL PULD P PJSM, load RA sources. 22:30 23:30 1.00 141 327 SURFA( DRILL PULD P P/U Drill collars&RIH on 5"HWDP to 327' MD. Monitor well via holefill. 23:30 00:00 0.50 327 327 SURFA( DRILL SRVY T Troubleshoot ADN, no connectivity. 11/11/2014 Trouble shoot ADN,drill 13 1/2"surface hole f/327't/892', build mud volume, continue drilling f/892't/1455'. 00:00 00:30 0.50 327 327 SURFA( DRILL SRVY T Troubleshoot ADN, no connectivity. 00:30 10:00 9.50 327 892 SURFA( DRILL DDRL P Drill 13 1/2"surface hole f/327't/892' MD, 889'TVD,498 GPM, 845 PSI, 80 RPM, TO 4K,WOB 12K, PUW 93K, SOW 96K, ROT 93K. 10:00 13:00 3.00 892 892 SURFA( DRILL COND T Lost 480 bbls of mud f/00:00 t/10:00 hrs. Shut down to build mud and wait on 2 trucks with 580 bbls of mud. Static loss 60 bph. 13:00 00:00 11.00 892 1,459 SURFA( DRILL DDRL P Drill f/892't/1455',total loss of 191 bbls, average 30 bph,f/13:00 hrs t/24:00 hrs. Drill 500 GPM,ON 875 PSI, OFF 780, 80 RPM,TQ 3-4K, WOB 13K, PUW 106K, SOW 99K, ROT 101. TQ 2.5K. AST 3.57,ART 3.9,ADT 7.47, BIT 13.85,JARS 11.5. 11/12/2014 Drill 13 1/2"surface hole f/1459't/1839',shut down and build mud volume,drill f/1839't/2024',shut down and build mud volume,drill f/2024't/2310'. 00:00 08:30 8.50 1,459 1,839 SURFA( DRILL DDRL P Drilling 13 1/2"surface hole f/1459' t/1839', GPM 593, PSI ON 1310, PSI OFF 1150, RPM 90,TQ 6K,WOB 20K, PUW 117K, SOW 109K, ROT 107K. Average 80-100 bbl Loss Rate. 08:30 09:30 1.00 1,839 1,839 SURFA( DRILL COND T Build 100 bbl pit volume before continuing drilling. Pump 5 bbls every 30 minutes @ 4 bpm. 70 bbl static loss. 09:30 12:00 2.50 1,839 2,024 SURFA( DRILL DDRL P Drill surface hole f/1839't12024', PUW 120K, SOW 111K, GPM 596, PSI ON 1200, PSI OFF 1120, RPM 90,TQ 6K, ROT 110K. 100 bbl average mud loss.Total mud loss in 12 hrs 885 bbls. 12:00 15:00 3.00 2,024 2,024 SURFA( DRILL COND T Build mud and wait on trucks to deliver mud. PUW 120K, SOW 111k, pump 5 bbls every 30 minutes @ 2 bpm,282 psi. Mud loss 50 bph. Page 3 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 00:00 9.00 2,024 2,310 SURFA( DRILL DDRL P Drill surface hole f/2024't/2310', GPM 596, PSI ON 1075, PSI OFF 1000, RPM 80,TQ 4-6K,WOB 15K, PUW 113K, SOW 107K, ROT 107K. AST 3.33,ART 1.84,ADT 5.17, BIT 25.26,JARS 22.91. Mud loss 108 bph, mud loss f/12:00 t/2400 hrs 716 bbls. 12:00- 18:00 hrs 90 bph mud loss 18:00-24:00 hrs 115 bph mud loss 11/13/2014 Drill 13 1/2"surface hole f/2310't/2876', pump 80 bbl LCM pill,continue drilling surface f/2876't/3190'. 00:00 06:00 6.00 2,310 2,559 SURFA( DRILL DDRL P Drill 13 1/2"surface hole f/2,310' t/2559', TVD 2398'. GPM 549, RPM 90,TQ 7K,WOB 20K, PSI ON 1320, PSI OFF 1170, PUW 130K, SOW 113K, ROT 120K. Total losses f/00:00 t/05:00 hrs 550 bbls, average loss 110 bph. 06:00 12:00 6.00 2,559 2,783 SURFA( DRILL DDRL P Drill surface hole f/2559't/2783', TVD 2545'. GPM 552, PSI ON 1360, PSI OFF 1120, RPM 90, TQ 8K,WOB 25K, PUW 133K, SOW 113K, ROT 12K. Total fluid loss f/00:00 t/12:00 hrs 1193 bbls, average loss 105 bbls. AST 5.77,ART 2.13,ADT 7.9, BIT 33.16,JARS 30.81. 12:00 16:00 4.00 2,783 2,876 SURFA( DRILL DDRL P Drill surface hole f/2783't/2876',TVD 2598'. GPM 550, PSI ON 1239, PSI OFF 1150, RPM 90,TQ 7-8K, WOB 20K, PUW 128K, SOW 111K, ROT 120K. Mud loss 96 bpm. 16:00 16:30 0.50 2,876 2,876 SURFA( DRILL CIRC P Pump 80 bbl,9.0 ppg, LCM pill @ 345 gpm, 521 psi. Pump pill 1600 stks passed the bit into open hole. 16:30 00:00 7.50 2,876 3,190 SURFA( DRILL DDRL P Drill surface hole f/2876't13190', TVD 2761'. GPM 550, PSI ON 1233, PSI OFF 1127, RPM 100, TQ ON 9K, Off 7K,WOB 25K, PUW 145K, SOW 112K, ROT 120K. AST 4.59,ART 2.67,ADT 7.26, BIT 40.42,JARS 38.07. Total mud loss f/12:00 t/24:00 hrs 1067 bbls.Average loss 88.5 bph. 11/14/2014 Drill 13 1/2"surface hole to 3352'TD. Back ream out of the hole to 1084'and pump LCM pill. Back ream to the DC's 240'and L/D BHA. Prepare to run 10 3/4'casing. 00:00 03:00 3.00 3,190 3,352 SURFA( DRILL DDRL P Drill 13 1/2"surface hole f/3190' t/3352'TD, GPM 550, PSI ON 1310, PSI OFF 1180, RPM 100,TQ ON 8K,TQ OFF 5K,WOB 25K, PUW 135K, SOW 112K, ROT 118K. AST.23,ART 1.96,ADT 2.19, BIT 42.61,JARS 40.26. Page 4 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 06:30 3.50 3,352 3,284 SURFA( CASING CIRC P Circulate minimum of 2 X BU until shakers are clean. Recip pipe and stand back 1 stand every BU. Pumped 24,440 stks(5 BU)to clean mud. 06:30 12:00 5.50 3,284 1,651 SURFA( CASING REAM P Back ream out of the hole f/3255' t/1651', GPM 450, PSI 780, RPM 100.Adjust running speed to hole to returns and losses. Mud loss f/00:00 t/06:00 hrs 69 bph,f/06:00 t/12:00 hrs 36 bph,total loss 626 bbls. 12:00 13:00 1.00 1,651 1,084 SURFA( CASING REAM P Back ream out of the hole f/1651' t/1084', GPM 460, PSI 740, RPM 100,TQ 2-4K, PUW 94K, SOW 96K. 13:00 14:30 1.50 1,084 985 SURFA( CASING CIRC P Spot LCM pill at 1084'to 989'@ 4 bpm,260 psi, pulling speed 22 fpm. 14:30 16:30 2.00 985 240 SURFA( CASING REAM P Back ream out of the hole f/989' t/DC's 240', GPM 463, PSI 740, RPM 80. 16:30 21:00 4.50 240 0 SURFA( CASING PULD P Remove source per SLB, L/D BHA #2 per DD. Clear and clean floor. 21:00 00:00 3.00 0 0 SURFA( CASING RURD P R/U to run10 3/4"casing, make dummy run, P/U Volant tool and all other tools to run casing. 11/15/2014 Trucked new float collar from materials, rig up to run csing, run csing from to 1098', break circulation and lost returns. Continue running casing to 1517,tight hole with minimal returns. Rotate and work pipe to 1600'and pump 50 bbl LCM pill. run casing to 3342', M/U Hanger and circulate BU. 00:00 02:00 2.00 0 48 SURFA( CASING OTHR T Waiting on Float Collar Baffle Landing adaptor. Could not install Landing Adaptor by dropping it down the casing joint. Order new Float Collar so Landing Adaptor can be installed in the Float Collar before making it up on casing joint. 02:00 03:00 1.00 48 176 SURFA( CASING PUTB P Run 10 3/4"casing f/48't/176', pump through float shoe to veryify returns. 03:00 09:00 6.00 176 1,098 SURFA( CASING PUTB P Run casing f/176't/1098'. Break circulation staging pumps.5 bpm.At 7 bpm lost returns backed off to 3 bpm with minimal returns. 3 bpm, 100 psi, 3%returns. 09:00 11:30 2.50 1,098 1,517 SURFA( CASING CIRC T Work tight hole at 1517',20-25K set down weight, no go. Break circulation and attempt to wash obstruction, no go. Rotate with 13K max TQ with 20K set down weight pumping 2 bpm 180 psi. Loss rate 2 bpm. 11:30 14:30 3.00 1,517 1,538 SURFA( CASING CIRC T Work past initial obstruction at 1517' to 1538'.continue to roatate and recipricate casing, 3 bpm 230 psi, minimal returns of.5 bbls. 14:30 17:30 3.00 1,538 1,680 SURFA( CASING CIRC T Continue to work tight hole(/1538' t/1680', rotate at 10 RPM's, 10-13 TQ, 30K set down weight. Pump 50 bbl LCM pill at 1600'. Page 5 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 23:00 5.50 1,680 3,298 SURFA( CASING PUTB P Run casing f/1680't/3298',wash down every 5 joints. 23:00 23:30 0.50 3,298 3,342 SURFA( CASING HOSO P M/U Hanger and down to f/3298' t/3342'at 3 bpm, 340 psi.Tag landing ring 3242', PUW 157K, SOW 107K. 23:30 00:00 0.50 3,342 3,342 SURFA( CEMEN-CIRC P Circulate BU f/3242't3232', 1.5 bpm, 1290 psi, 78 bph mud loss. 11/16/2014 Run 10 3/4"casing to 3342', circulate and condition mud, pump 1st staage cement job. Could not open HES cementer for 2nd stage. ND diverter,tag cement 2.5'in conductor. Install casing and tubing spools,test to 1000 psi for 10 minutes. NU BOPE and prep to test. 00:00 01:00 1.00 3,342 3,342 SURFAt CEMEN-CIRCP Circulate and condition mud, recipricate f/3337't/3342', pump 1.5 bpm, 290 psi, PUW 168K, SOW 112K. 01:00 02:00 1.00 3,342 3,342 SURFA( CEMEN-RURD P R/D the Valont CRT, M/U the 350 ton elevators and HES cement head. 02:00 02:30 0.50 3,342 3,342 SURFA( CEMEN'SFTY P Conduct PJSM for surface casing cement job with WL, HES, and SLB. 02:30 04:00 1.50 3,342 3,342 SURFA( CEMEN-CIRC P Circulate and condition mud, 1.5 bpm, 290 psi, PUW 168K, SOW 112k. 04:00 07:00 3.00 3,342 3,342 SURFA( CEMEN-CMNT P Pressure test cement lines to 400 psi. Pump 50 bbls CW100,4.5 bpm, 400 psi, 8.4 ppg. Pump 50 bbls Mud Push Ilm 3.0 bpm,409 psi. Drop bottom plug and pump 479 bbls lead cement, 5 bpm, 327 psi, 10.7-11.0 ppg. Pump 56.3 bbls of tail cement, 3.3 bpm,66-160 psi, 12.0 ppg. Drop top plug and pump 10 bbls of water to kick out plug and wash lines. 07:00 09:30 2.50 3,342 3,342 SURFA( CEMEN-CMNT P Switch over to rig pumps to displace cement with mud,6.7 bpm, 283 psi. Could not keep rig pumps primed and switch over to SLB to displace, 6.8 bpm, 550 psi. Slow down to 2 bpm, bump plug at 09:11 hrs. Hold 1060 psi for 5 minutes, bleed pressure off and check floats,floats good. 09:30 10:30 1.00 3,342 3,342 SURFA( CEMEN-CMNT P Cutting tank full, pump mud to Vac truck. 10:30 13:00 2.50 3,342 3,342 SURFA( CEMEN-CMNTP Stage 2 surface cement job. Pressure to 2700 psi, HES did not open, bled off pressure. Pressured up 3 times to attempt to open the HES. HES could be partially open, pumped 10 bbls away at 2.5 bpm, 2800 psi, nvever felt the HES shift open. 13:00 15:30 2.50 3,342 3,342 SURFA( CEMEN'CMNT T Drain riser, flush Hydril,valves and DSA. Bleed pressure off of cement head remove cap and drop cancelation plug. M/U cement cap and pressure test to 1500 psi to verify HES Cementer is closed. Page 6 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 19:30 4.00 3,342 3,342 SURFA( WHDBO NUND P N/D diverter, pitcher nipple, riser, diverter tee and pipe.Vac cellar box and remove 4"dump valves from conductor.Tag cement at 2 1/2'in conductor. 19:30 20:30 1.00 3,342 3,342 SURFA(WHDBO WWSP P Install casing and tubing spools as per FMC, pressure test casing spools seals to 1000 psi for 10 minutes. Measure RKB: ULDS= 36.23 LLDS=36.45. 20:30 00:00 3.50 3,342 3,342 SURFA(WHDBO NUND P N/U 13 5/8"5000K BOP's, pdrep for BOPE test. 11/17/2014 N/U BOPE,set test plug,test BOP's, DROPS derrick inspection, IFC training for day crew, P/U BHA and DP,tag HES cancellation plug at 902'and drill out. 00:00 02:30 2.50 0 0 SURFA(WHDBO NUND P N/U BOP's, Strip-O-Matic, choke and kill lines, and jet lines. 02:30 03:00 0.50 0 0 SURFA(WHDBO RURD P Install test plug, R/U test equipment. 03:00 12:00 9.00 0 0 SURFA( WHDBO BOPE P Test BOPE t/250 psi low, 3500 psi high for 5 charted minutes. Manual and Super chokes 250 psi low and 3500 psi high. Test will be done with a 5"DP test joint.Tested Annular preventer, upper and lower rams, choke valves 1-15, manual and Super choke, NCR's,4"valve on kill line, TIW, Dart valve, upper and lower IBOP's. Perform Koomey unit draw down, Koomey pressure 3000, manifold pressure 1500. Fuction Koomey 1660 psi, 22 seconds to build 200 psi, 124 seconds to build to full pressure 3000 psi.Average charge for 6 NO2 bottles 2158 psi.Also perform CPAI and AOGCC Koomey tests. AOGCC wittness test waived by Jeff Jones. 2 failures: change both seals on blind ram doors and a leak on the LRR Door.All replaced and tested. 12:00 13:00 1.00 0 0 SURFA(WHDBO RURD P R/D test equipment, pull test plug, drain stack and install Ware bushing. 13:00 16:00 3.00 0 0 SURFA( RIGMNT SFTY P CPAI DROPS/Doyon/Nov derrick inspection. 16:00 20:00 4.00 0 0 SURFA( CEMEN-SFTY P IFC training for day crew. Conducted by CPAI, Gary Gusthier,Josh Gilleland and RLG. 20:00 22:00 2.00 0 902 SURFA( CEMEN'PULD P P/U BHA#3 as per DD and 6 JTS of DP t/902'. 22:00 00:00 2.00 902 902 SURFA( CEMEN-DRLG P Kelly up and tag the cancelation plug at 902'. Drill plug,405 GPM, 545 psi, RPM 55,TQ 2-6K,WOB 4K. Ream back through H-es Cementer f/910' t/898', no indication of plug present. Page 7 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/18/2014 24 hr summary Run in hole with BHA, break circulation and wash and ream shoe track. Drill out shoe track and shoe. Drill 20'of new hole and CBU for FIT. Perform FIT to 17.4 ppg with 1240 psi. Drill ahead, staging flow rate up when BHA reached new formation. Drill ahead to 3659' MD. 00:00 02:00 2.00 926 1,900 SURFA( CEMEN'PULD P Single in the hole with 5"DP f/926' t/1900'. 02:00 02:30 0.50 1,900 1,900 SURFA( CEMEN-DHEQ P Perform shallow pulse test staging pumps t/485 GPM,860 psi,good test. 02:30 04:00 1.50 1,900 2,014 SURFA( CEMEN-PULD P Continue to single in the hole with 5" DP f/1900't/2914',tag cement stringer at 2014'. 04:00 05:00 1.00 2,014 3,106 SURFA( CEMEN'COCF P Break circulation,stage pumps t/485 gpm,wash and ream f/2914' t/3106'. 940 psi, 50 rpm, TQ 6K. 05:00 06:00 1.00 3,106 3,106 SURFA( CEMEN PRTS P Blow down top drive and RU surface equipment,flush lines and perform casing test to 3000 psi for 30 minutes to chart; Good. 06:00 07:30 1.50 3,106 3,106 SURFA( CEMEN SLPC P PJSM, cut and slip 32'of drilling line. Calibrate depth equipment, block height, MWD depth tracking. 07:30 08:00 0.50 3,106 3,106 SURFA( CEMEN SVRG P Service rig;top drive and drawworks, blocks and crown. 08:00 12:00 4.00 3,106 3,295 SURFA( CEMEN'DRLG P Obtain SPRs,wash and ream from 3106'to 3233'at 550 gpm with 1160 psi.50-70 RPM, 7K torque. Tag cement at 3233',drill out cement with 2-4K WOB, drill plug/baffle adapter at 3254',float and landing collar at 3294'. Drill ahead to 3295' MD,2815' TVD at 505 GPM with 1025 psi, 70 RPM with 7-9K torque and 5-10K WOB. Crew change. 12:00 14:00 2.00 3,295 3,352 SURFA( CEMEN'DRLG P Continue to drill from 3295'to 3340', tag shoe and drill out shoe. Drill out rat hole to 3352'. 14:00 14:30 0.50 3,352 3,372 SURFA( CEMEN"DDRL P Drill 20'of new formation from 3352' to 3372'at 550 GPM with 1160 psi, 65 RPM with 8K torque and 5K WOB. 14:30 15:00 0.50 3,372 3,372 SURFA( CEMEN CIRC P CBU for FIT at 550 GPM with 1140 psi, 50 RPM with 6K torque. 15:00 17:00 2.00 3,372 3,372 SURFA( CEMEN FIT P RU test equipment and perform FIT to 17.4 with 1240 psi,9.0 ppg mud weight at 2848'TVD. 17:00 18:00 1.00 3,372 3,382 INTRM1 DRILL DDRL P Displace well to 9.6 ppg LSND mud while drilling from 3372 to 3382'. 18:00 18:30 0.50 3,382 3,382 INTRM1 DRILL COND P Condition mud in pits and clean pits. Prep for displacement to 9.6 mud. 18:30 19:00 0.50 3,382 3,382 INTRM1 DRILL OWFF P Observe well for flow; Static. Page8of64 Time Logs Date From To Dur S. Depth E.°Depth Phase Code Subcode T Comment 19:00 00:00 5.00 3,382 3,659 INTRM1 DRILL DDRL P Drill ahead from 3385'to 3659'at 650 GPM with 1375 psi, 105 RPM with 7.5K torque, 8K WOB, 10.42 ECD. PU= 134K, SO= 104K, Rot= 116K. ADT=3.99, Bit hours=3.99,Jar= 44.25 hours. 11/19/2014 Drilling ahead to 4466', perform rig repairs on flow riser air boot, resume drilling to 5185'when drilling was stopped for Phase 3 weather. Pump out to the shoe and hold. 00:00 06:00 6.00 3,659 4,051 INTRM1 DRILL DDRL P Drill ahead from 3659'to 4051'at 700 GPM with 1620 psi, 105 RPM with 9-10K torque, 15K WOB and 10.60 ECD. PU= 140K, SO= 110K, Rot= • 120K. 06:00 10:15 4.25 4,051 4,466 INTRM1 DRILL DDRL P Drill ahead from 4051'to 4466'at 750 GPM with 2020 psi, 120 RPM with 8K torque, 13K WOB and 10.87 ECD: PU= 150K, SO= 115K, Rot= 122K. ADT=7.53, bit hours= 11.53, Jars= • 51.78 hours. 10:15 10:45 0.50 4,466 4,466 INTRM1 DRILL SVRG P Service top drive and drawworks. Flow riser boot observed to have slow leak on boot. 10:45 11:00 0.25 4,466 4,466 INTRM1 DRILL SFTY T PJSM for flow riser boot repair. 11:00 12:00 1.00 4,466 4,466 INTRMI DRILL EQRP T Circulate, rotate and reciprocate pipe while repairing flow riser. Shut down pumps, pull power slips, repair riser air boot. Break circulation every 30 minutes during work. 12:00 12:30 0.50 4,466 4,466 INTRM1 DRILL EQRP T Continue to repair leak in flow riser. Install power slips. 12:30 21:00 8.50 4,466 5,185 INTRM1 DRILL DDRL P Resume drilling from 4466'to 5185' at 750 GPM with 2160 psi, 105 RPM with 11K torque, 10K WOB and 10.86 ECD. PU= 169K, SO-117K, Rot=138K. ADT=4.34, Bit hours= 15.77,Jars=56.12 21:00 21:45 0.75 5,185 5,090 INTRMI DRILL REAM T CBU and Back-ream out at 750 GPM with 2230 psi, 90 RPM with 9K torque and 10.79 ECD. 21:45 00:00 2.25 5,090 3,295 INTRM1 DRILL CIRC T Pump out of hole at 650 GPM with 1660 psi at 45 FPM back into shoe to wait out phase 3 weather. 11/20/2014 Wait on Phase 3 weather. Crew change @ 2130 hrs. 00:00 12:00 12.00 3,295 3,295 INTRM1 DRILL SFTY T Wait on Phase 3 weather,circulate across the top of the hole with bit in the shoe. 12:00 18:45 6.75 3,295 3,295 INTRMI DRILL SFTY T Wait on Phase 3 weather,circulate across the top of the hole with bit in the shoe. 18:45 20:15 1.50 3,295 3,295 INTRM1 DRILL SFTY T CBU 2X to roll mud and check condition;good. Pump 250 GPM with 390 psi. L_ Page 9 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 00:00 3.75 3,295 3,295 INTRM1 DRILL SFTY T Wait on Phase 3 weather, circulate across the top of the hole with bit in the shoe. Crew change @ 2130 hrs. Skeleton crew @ rig. 11/21/2014 Wait on Phase 3 weather. Crew change @ 20:30 hrs. 00:00 12:00 12.00 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather,circulate across the top of the hole with bit in the shoe. 12:00 14:15 2.25 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather,circulate across the top of the hole with bit in the shoe. 14:15 16:30 2.25 3,295 3,295 INTRM1 DRILL CIRC T Circulate BU 3X at 254 GPM with 390 psi. 16:30 21:45 5.25 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather,circulate across the top of the hole with bit in the shoe. Crew change @ 2030 hrs. Skeleton crew @ rig. 21:45 00:00 2.25 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather, circulate across the top of the hole with bit in the shoe. 11/22/2014 Released to Phase 1 at 0800. Rally the troops, call for trucks and supplies. Trip in the hole and wash down last stand and drill ahead to 6136'. Change out crews as needed to shift back to straight tours. Rig to high line power at 14:30, off rig generators. 00:00 02:45 2.75 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather,circulate across the top of the hole with bit in the shoe. 02:45 04:15 1.50 3,295 3,295 INTRM1 DRILL CIRC T Circulate BU 2X at 254 GPM with 390 psi. 04:15 09:30 5.25 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather, circulate across the top of the hole with bit in the shoe. 09:30 10:00 0.50 3,295 3,295 INTRM1 DRILL CIRC T Wait on Phase 3 weather, circulate across the top of the hole with bit in the shoe. 10:00 10:45 0.75 3,295 3,296 INTRM1 DRILL CIRC T Wait on Phase 3 weather;wait for trucks to arrive and line up to rig. Circulate; stage pumps up and test MWD at 500 GPM with 1050 psi; Good test. 10:45 12:00 1.25 3,296 5,059 INTRM1 DRILL TRIP T Trip in the hole to 5059'on elevators. Crew change 12:00 12:45 0.75 5,059 5,185 INTRM1 DRILL REAM T Circulate BU while reaming to bottom at 700 GPM with 2100 psi, 120 RPM,20K WOB with 13K torque. 12:45 14:15 1.50 5,185 5,316 INTRM1 DRILL DDRL P Drilling from 5185'to 5316' at 750 GPM with 2370 psi, 120 RPM, 15K WOB with 11K torque. PU= 160K, S0= 121K, Rot= 136K. 14:15 14:27 0.20 5,316 5,316 INTRM1 DRILL OWFF P Rack back one stand and monitor well for 10 minutes; Static. 14:27 14:45 0.30 5,316 5,316 INTRM1 DRILL RURD P Swap rig to high line power from rig power. Page 10 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 18:15 3.50 5,316 5,659 INTRM1 DRILL DDRL P Drilling from 5316'to 5659' at 750 GPM with 2448 psi, 120 RPM, 15K WOB with 11K torque. PU= 178K, SO= 119K, Rot= 136K. 18:15 00:00 5.75 5,659 6,136 INTRM1 DRILL DDRL P Drilling from 5659'to 6136' at 750 GPM with 2507 psi, 120 RPM,20K WOB with 11K torque. PU= 182K, SO= 119K, Rot= 136K. ADT=8.58, Bit hours=24.53,Jars=64.61 hours. Crew change. 11/23/2014 Drill from 6136'to 8018'. Pack-offs while drilling ahead at 6081'6306'and 6405'. Pulled off bottom, decreased pumps and cleared each time,then resumed drilling. Employed mud dilution and high-Vis sweeps to maintain ECD and drilling parameters. At 22:40 the well was shut in;SIDPP=90 psi, SICP=220 psi with a 14 BBL gain in the pits. Make notifications and begin well kill operations. 00:00 06:00 6.00 6,136 6,604 INTRM1 DRILL DDRL P Drill from 6136'to'at750 GPM with 2710 psi, 150 RPM with 12.5K torque. Pack-offs while drilling ahead at 6081'6306'and 6405'. Pulled off bottom,decreased pumps and cleared each time,then resumed drilling. 06:00 12:00 6.00 6,604 7,157 INTRM1 DRILL DDRL P Drilling from 5659'to 6136' at 750 GPM with 2507 psi, 120 RPM, 20K WOB with 11K torque. PU= 182K, SO= 119K, Rot= 136K. ADT=8.58, Bit hours=24.53,Jars=64.61 hours. Crew change. 12:00 16:00 4.00 7,157 7,555 INTRM1 DRILL DDRL P Drilling from 7157'to 7555' at 750 GPM with 3008 psi, 150 RPM, 15K WOB with 15K torque. PU=226K, SO= 127K, Rot= 163K, ECD= 11.25. 16:00 16:30 0.50 7,555 7,555 INTRM1 DRILL CIRC P Rotate and Recip pipe while pumping High-Vis sweep,27 BBL 9.6+ppg at 255 GPM with 560 psi, 150 RPM with 18K torque. 16:30 17:45 1.25 7,555 7,460 INTRM1 DRILL CIRC P Rotate and Recip pipe while pumping at 750 GPM with 2995 psi, 150 RPM, 15K WOB with 15K torque. PU=226K, SO= 127K, Rot= 163K, ECD= 11.25. 17:45 18:00 0.25 7,460 7,555 INTRM1 DRILL TRIP P Run in the hole from 7460'to 7555' on elevators. at 750 GPM with 3008 psi, 150 RPM, 15K WOB with 15K torque. PU=226K, SO= 127K, Rot= 163K, ECD= 11.25. 18:00 22:45 4.75 7,555 8,018 INTRM1 DRILL DDRL P Drilling from 7555.0'to 8018' at 750 GPM with 3010 psi, 150 RPM, 10K WOB with 17K torque. PU=234K, SO= 132K, Rot= 166K. ECD= 10.92. ADT=4.7, Bit hours=37.52,Jars= 77.87 hours. Page 11 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 8,018 7,995 INTRM1 DRILL OWFF T Driller observed 5%flow increase, positioned the drillstring and shut down the pumps. Flow continued and driller shut in the well with the annular at 22:40. SIDPP=90 psi, SICP=220 psi. monitor and record pressures. Pit gain of 14 BELS was realized. Crew change. 11/24/2014 Weight up drill mud to kill weight of 10.1 ppg.Take mud into the pits and weight up same. Mud weight increased to 10.3 ppg during circulations. 00:00 01:30 1.50 7,995 7,995 INTRM1 DRILL OWFF T Monitor well and stage products and take mud into pits. 01:30 09:45 8.25 7,995 7,995 INTRM1 DRILL KLWL T Stage pumps to 2 BPM with kill schedule and continue to pump 10.1 KWF for 9821 strokes. ICP=480 psi-DP. 310 psi-csg. FCP=345 psi dp, 50 psi-csg. Recip pipe every 1.5 hours;free. PU=235K, S0= 124. 09:45 10:00 0.25 7,995 7,995 INTRM1 DRILL OWFF T Shut down pumps and shut in well to monitor pressures, no pressure built. Open super choke and no flow observed, 10:00 10:45 0.75 7,995 7,995 INTRM1 DRILL KLWL T Circulate and weight up to 10.3 ppg. Stage pumps to 10 BPM with 110 psi, 50 RPM with 17K torque. 10:45 11:15 0.50 7,995 7,995 INTRM1 DRILL OWFF T Monitor pressures; SIDPP=60 and SICP=25 psi with 5 BBL gain to pits. 11:15 12:00 0.75 7,995 7,995 INTRM1 DRILL KLWL T Stage pumps to 5 BPM circulating through the open Super choke while weighting up to 10.3 ppg, ICP=460 psi dp, 50 psi-csg. PU=224K, SO= 124K. Crew change. 12:00 15:15 3.25 7,995 7,995 INTRM1 DRILL KLWL T Continue to circulate 10.3 ppg around at 5 BPM. Pumped 12322 strokes. MWT in 10.3+, MWT out 10.4, NP MWT 10.05 ppg. 15:15 15:30 0.25 7,995 7,995 INTRM1 DRILL OWFF T Shut down pumps and monitor pressures while shut in. SIDPP= 130.SICP=60 psi. After 15 minutes; DP=30, CP=0 psi. Open bag,close choke and monitor well. Page 12 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 18:00 2.50 7,995 7,995 INTRM1 DRILL KLWL T Stage pumps from 5 BPM to 10 BPM,work pipe every hour. PU= 203K, SO=140K. @ 5 BPM, 210 GPM, 420 psi, ML gas= 110 units @ 6 BPM, 253 GPM, 505 psi, ML gas=200 units @ 7 BPM, 295 GPM, 610 psi, ML gas=720 units @ 5600 strokes=4648 units @ 8 BPM, 336 GPM, 780 psi, ML gas=4200 units @ 10 BPM,422 GPM, 1075 psi, ML gas=3680 units, ECD= 11.01 Total strokes pumped= 10700. MWT in= 10.3, MWT out 10.4+, NP =9.8+ppg. 18:00 19:15 1.25 7,995 7,995 INTRM1 DRILL KLWL T Rotate and Recip pipe with 11 BPM. ECD= 11.14 @ 11 BPM,463 GPM, 1330 psi, ML gas=694 units RPM= 100 with 14K torque, pumped 7716 strokes. MWT in 10.4, MWT out 10.3+. NP 10.3. 19:15 20.30 1.25 7,995 7,995 INTRM1 DRILL KLWL T Continue to circulate at 12 BPM. ECD= 11.16 @ 12 BPM, 505 GPM, 1520 psi, ML gas=890 units RPM= 100 with 16K torque, pumped 10293 strokes. MWT in 10.4, MWT out 10.4. NP 10.2. 20:30 21.30 1.00 7,995 7,995 INTRM1 DRILL KLWL T Continue to circulate at 18 BPM Surface to Surface with ECD= 11.33 @ 18 BPM, 750 GPM, 2900 psi, ML gas=570 units RPM= 100 with 16K torque, pumped 10293 strokes. MWT in 10.4, MWT out 10.4. NP 10.2. 21:30 22:00 0.50 7,995 7,995 INTRM1 DRILL OWFF T Shut down pumps and monitor well; slight/minimal flow diminishing with time. 22:00 22:30 0.50 7,995 7,995 INTRM1 DRILL KLWL T Continue to circulate at 18 BPM Surface to Surface with ECD= 11.33 @ 18 BPM, 750 GPM, 2900 psi, ML gas=570 units RPM= 100 with 16K torque, pumped 4852 strokes. Observe flow increase and gas show increase; Shut in well to observe; SIDPP=60 psi, SICP=50 psi, 10 BBL pit gain. Shut in well at 22:40 as flow increased from 45%to 70%returm and gas spiked to 7800 units. P. •. Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:00 0.50 7,995 7,995 INTRM1 DRILL OWFF T Monitor pressures of SIDPP and SICP. 23:00 23:15 0.25 7,995 7,995 INTRM1 DRILL KLWL T Pump 10 BBL at 2 BPM to prevent top drive from freezing. Weight up mud pits to 10.5 ppg. 23:15 00:00 0.75 7,995 7,995 INTRM1 DRILL KLWL T Pump 35 BBLs @ 2 BPM for dynamic kill while circulating and weighting up to 10.56 ppg. Crew change. Fluid loses this tour= 18 BBL 11/25/2014 Increase MW to 10.5 ppg,establish circulation thru choke/poorboy observing mud losses to formation. Open well and establish loss rates/monitor gas returns. Pump 45 bbl pill @ 30 ppb, 100 bbl pill at 50 ppb.5-10 ppb LCM in active. Haul mud and LCM to rig. Reduce losses from 50 bph @ 2 bpm to—10 bpm varying.Total losses for day=934 bbl. 00:00 01:30 1.50 7,995 7,995 INTRM1 DRILL OWFF T Continue to monitor DP and CSG pressures, PT surface lines to 600 psi-good. Pump 10 bbl every 30 minutes to prevent topdrive freezeup. Recip pipe every 30 minutes, P/U=230k, S/0=120k.Weight up active system to 10.5 ppg. 01:30 02:15 0.75 7,995 7,995 INTRM1 DRILL CIRC T Begin pumping 10.5 ppg LSND through poor boy @ 2 bpm, ICP=180 psi DP, 0 psi CSG. Get returns after 14 bbl away, lost returns @ 2 bpm, 66 bph. Stage pump up to 3 bpm, 185 psi DP,0 psi CSG,then 4 bpm 235 psi DP, 0 psi CSG. Loss rate @ 4 bpm=96 bph. Shut down pump and close choke. 02:15 03:15 1.00 7,995 7,995 INTRM1 DRILL OWFF T Monitor casing and DP pressure, 0 psi on CSG, 60 psi on DP (Standpipe Hydrostatic). Open superchoke and monitor for flow @ poorboy=0. Decision made to open annular and monitor for flow=0. 03:15 05:15 2.00 7,995 8,009 INTRM1 DRILL CIRC T Circulate while rotate and recip from 8009' MD to 7931' MD stage pumps up. 2 bpm, 100 spi, 6%F/O, 5 rpm, 16k TQ, losses=6 bph. 3 bpm, 180 psi, 12%F/O, 20 rpm, 15k,TQ, losses=12 bph. 4 bpm,260 psi, 18%F/O, losses 54 bph. 6 bpm,410 psi, 20%F/O, losses 151 bph. Observe 3800 units gas on bottoms up. • Page 14 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 12:00 6.75 8,009 8,009 INTRM1 DRILL CIRC T Continue to circulate while recip from 8009'to 7931' MD. Pump 45 bbl LCM Pill @ 6 bpm reduce rate to 2.5 bpm as pill clears bit. 2.5 bpm @ 200 psi, 7%Flow out, Loss rate 57 bph. Adding 10 ppb LCM to active. Increase rate to 3 bpm,210 psi,7% Flow out losses 92 bph. 10:50 hrs reduce rate to 2 bpm 200 psi, 2% flow out losses 48 bph @ 11:30 reduce rate to 1.5 bpm, 180 psi, 1% flow out. Building 100 bbl, 50 ppb pill in pits. P/U=210k, S/O=136K,taken @ 3 bpm pumps on. 12:00 14:30 2.50 8,009 8,009 INTRMI DRILL CIRC T Continue circulate and reciprocate while building pill @ 1.5 bpm, 185 psi. Flow out=Minimal. P/U=215k, S/O=135k. Pumped 18,154 stks total=Gas @ 2067 units. 14:30 20:15 5.75 8,009 8,009 INTRMI DRILL CIRC T Pump 101 bbl of 10.5 ppg, 50 ppb LCM pill. (10 ppb Nut Plug F, 15 ppb Nut Plug M, 15 ppb MIX II M, 10 ppb MIX II C) Pump pill @ 84 gpm, ICP=230 psi, Pill at bit psi=380 psi, FCP=230 psi. Initial flow out=1%, Final flow out=7%. Initial loss rate= 57 bph, Final loss rate= 10 bph. Bottoms up gas=918 units max, background gas reduce to 40 units. 20:15 00:00 3.75 8,009 8,009 INTRM1 DRILL CIRC T Continue pumping @ 2 bpm, reciprocate©400 fph, 260 psi, 7% flow out, P/U=218k, S/O=135k. Background gas reduced to 30 units with occasional spikes up to 1100 units, varying in frequency, cannot correlate to any rig activity. Waiting on additional 10.5 ppg mud volume and LCM to be delivered to build another pill. 11/26/2014 Build and pump100 bbl LCM pill @ 50 ppb, increase active system to 20 ppb LCM. Observe and monitor loss rates and gas in returns @ 10.5 ppg. Observe well flowback 16 bbl total, breathing apparent. CBU no gas on bottoms up. Lost hiline power and restored. Spot 50 ppb, 100 bbl 10.5 ppg pill in open hole. 00:00 02:00 2.00 8,009 8,009 INTRM1 DRILL CIRC T Continue circulae and reciprocate @ 8016-7030'@ 2 bpm 265 psi,7% Flow out, losses @ 19 bph. P/U=218k, S/O=138k. Build 100 bbl LCM @ 50 ppb. 02:00 03:00 1.00 8,009 8,009 INTRM1 DRILL CIRC T Pump 100 bbl 50 ppb pill, (SafeCarb 250, Safecarb 40 and Nut Plug M) 11 ppg @ 2 bpm 7%Flow out. ICP=260 psi, FCP=140 psi. Page 15 of 64 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 10:30 7.50 8,009 8,009 INTRM1 DRILL CIRC T Circ and recip while pumping pill around @ 2 bpm. ICP=140 psi, FCP=460 psi. Loss rate and flow out%vary as pill coming up annulus from 7%-2%flow,4 bph-24 bph losses. Total lost while pumping pill around 166 bbl, averaging 20 bph. Keep pill in active system. Begin adding 20 ppb LCM to active system while pumping/chasing pill. 10:30 10:45 0.25 8,009 8,009 INTRM1 DRILL OWFF T Kill pumps and monitor well , observe 2 bbl flowback in 15 minutes. 10:45 12:00 1.25 8,009 8,009 INTRM1 DRILL CIRC T Circulate 2 bpm, 490 psi 1%flow out. Begin mixing 50 ppb pill#3. 12:00 14:15 2.25 8,009 8,009 INTRM1 DRILL CIRC T Continue C&C @ 2 bpm, 326 psi, minimal flow out, losses 60 bph. Gas=5 units,total strokes pumped 3885. 14:15 14:30 0.25 8,009 8,009 INTRM1 DRILL OWFF T Rig lost highline power. Upon investigation hi-line crew had inadvertently switched utility off.Warm up cats to go to rig power, Hi-line called to turn back on. Monitor well returns trip tank while down. Hi-line restored. Total pit gained in trip tank 3 bbl. Flow reducing indicating breathing occuring. 14:30 16:00 1.50 8,009 8,009 INTRM1 DRILL OWFF T L/D single top stand 77, blow down top drive. Monitor well returs via trip tank, observe slight reducing flow. Total returned to trip tank 13.1 bbl. P/U single and kelly up. 16:00 21:15 5.25 8,009 8,009 INTRM1 DRILL CIRC T Circulate bottoms up @ 2 bpm, 326 psi,2-10%flow out, P/U=225k, 5/O=134k, Total pumped 9910 stks. Most gas noted on BU was @ 1300 stks, 600 units gas. Bottoms up gas 30 units. Losses initial 10 bph, stopped losing and began slight gain (12 bbl total gain while pumping, no increase in flow)in pits due aired up mud, de-gasser running effectively. Adding de-foamer and biocide to mud. 21:15 00:00 2.75 8,009 8,009 INTRM1 DRILL CIRC T PJSM and spot 142 bbl pill, 50 ppb pill,(10 ppb Nut Plug F, 15 ppb Nut Plug M, 15 ppb Mix II M, 10 ppb Mix II C) 10.5 ppg @ 2 bpm. ICP=380 psi, FCP=391 psi. Spot pill in open hole, displace pill out of bit with 1470 stks. P/U=225k, S/O=134k. Prep to pump out of hole to 6600'@ 1500 fph, .5 bpm to mitigate swab effect. Total losses to formation today=367 bbl Cumulative interval losses= 1301 bbl Page 16 of 64 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/27/2014 24 hr Summary Pump out to 6600'after laying in LCM pill. Observe well and soak pill 2 hr. Estabish circ, losses average 47 bph. RIH and circulate losses 62 bph. POOH to 6300'Install TIW/Dart, RIH to 6800 and pump Form-A-Blok pill 111 bbl, no difference in losses. 00:00 02:00 2.00 8,009 6,600 INTRM1 DRILL TRIP T Pump out of hole from 8005' MD to 6600'MD,25 fpm, .5 bpm, 100 psi, 0%flow out. Monitor displacement via pits 2&3. Gained 41 bbl during trip. P/U=197k, S/O=129k. 02:00 02:15 0.25 6,600 6,600 INTRM1 DRILL RURD T Blow down top drive and install TIW valve. 02:15 04:15 2.00 6,600 6,600 INTRM1 DRILL OWFF T Monitor well for flowback, rotate 3 rpm, 11 k TQ, ROT wt=144k. Observe fluid level drop in riser 8"over 40 minutes. Line up and monitor well via trip tank, no losses or gains. 04:15 07:00 2.75 6,600 6,600 INTRMI DRILL CIRC T Circulate while R&R from 6600'MD to 6508' MD @ 2 bpm ICP=290 psi, Minimal flow out, FCP=270 psi,2% flow out. Average loss rate during circulation 47 bph. 07:00 07:15 0.25 6,600 6,600 INTRM1 DRILL OWFF T Blow down topdrive and monitor flowback for 15 min, 2.4 bbl total flowback decreasing trend. 07:15 09:15 2.00 6,600 8,012 INTRM1 DRILL TRIP T TIH on elevators from 6600' MD to 8012'MD. Monitor via pit#2, lost 27 bbl during TIH. P/U=205k, S/O=136k. 09:15 12:00 2.75 8,012 8,012 INTRM1 DRILL CIRC T Circulate while R&R from 8012'MD to 7972'MD @ 2 bpm,40 rpm, 14k TQ. ICP=560 psi, minimal flow out %, FCP=335 psi, minimal flow out %. Comtinue adding 20 ppb LCM to active system. Begin building 110 bbl Form-A-Blok pill per MI rep. Average loss during circulation=62 bph. Total losses for tour=330 bbl. 12:00 14:15 2.25 8,012 8,012 INTRM1 DRILL CIRC T Continue C&C while R&R @ 8012'-7972'MD. 2 bpm, 40 rpm, 14k TQ,330 psi, minimal flow out%. 14:15 18:45 4.50 8,012 6,320 INTRMI DRILL TRIP T Pump out of hole from 8012' MD to 6320'MD with 42 gpm,250 psi, minimal flow out%, P/U=220k, S/O=135k. 18:45 20:30 1.75 6,320 6,320 INTRM1 DRILL RURD T Install TIW valve due drill string flowing back. Blow down top drive, monitor well via TT, no loss/gain. 20:30 21:30 1.00 6,320 6,800 INTRM1 DRILL RURD T Install 5"Dart valve on top of TIW& RIH on elevators from 6320'MD to 6800'MD. Fill drill string with fill up hose. P/U=189k, S/O=128k. Page 17 of 64 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 21:30 23:15 1.75 6,800 6,800 INTRM1 DRILL CIRC T Kelly up,establish circulation(no returns)@ 2 bpm,250 psi. Pump 111 bbl 10.7 ppg Form-A-Blok pill in string. Increase rate to 4 bpm/625 psi @ 885 stks to keep pill moving in surface lines. Chase pill with 1400 stks 10.5 ppg mud, minimal returns throughout job. Pumped 141 bbl, lost 125 bbl. No increase in return flow or pressure. 23:15 00:00 0.75 6,800 6,320 INTRM1 DRILL TRIP T POOH on elevators from 6800'MD to 6320' MD. L/D 5"Dart valve and TIW. P/U=189k, S/O=122k. Gained 8.1 bbl flowback while POOH. Total losses to formation today=755 bbl Cumulative interval losses=2056 bbl 11/28/2014 Circulate FAB pill to formation, RIH to bottom CBU losses 70%. Pump out 10 stands improper fill, RBIH CBU 4 bpm good returns,well giving fluid back and 2500 units gas on bottoms up, as well as 300 units @ 1200 stks. Decide to wt up mud to 10.8 ppg on bottom for TOH. 00:00 03:30 3.50 6,320 6,320 INTRM1 DRILL CIRC T Circulate and reciprocate @ 6320'-6222'MD @ 2 bpm,235 psi, minimal returns. Circulate to push Form A Block pill to potential loss zone, no improvement on flow out or pressure noted.Total strokes pumped=6608.Average loss rate 105 bph. 03:30 03:45 0.25 6,320 6,320 INTRM1 DRILL OWFF T Shut down pump, monitor well for flowback with trip tank,2.2 bbl bled back decreasing trend. Blow down top drive. 03:45 05:30 1.75 6,320 8,012 INTRM1 DRILL TRIP T RIH on elevators from 6320' MD to 8012'MD, monitor displacement with trip tank. Slow running speed to 1500 fph to reduce mud pushed away, 27 bbl lost while RIH. P/U=217k, S/O=132k. 05:30 07:00 1.50 8,012 8,012 INTRM1 DRILL CIRC T Circulate and reciprocate from 8012' MD to 7925' MD, stage pumps up to 450 gpm to turn on MWD tools and downlink XCeed Powerdrive to neutral position, 1135 psi,29%flow out. Total strokes pumped=7073, Loss rate from 450 bph, reduced to 340 bph. 07:00 07:15 0.25 8,012 8,012 INTRM1 DRILL OWFF T Monitor well for flowback via trip tank, 5.3 bbl flowed back decreasing trend. Obtain SPR's. SPR's @ 7993'MD, 5303'TVD, 10.5 ppg, 07:21 hrs #1-20 spm=240 psi,30 spm=280 psi #2-20 spm=240 psi,30 spm=280 psi Page 18 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 08:45 1.50 8,012 7,167 INTRM1 DRILL TRIP T Pump out of hole from 8012' MD to 7167'MD @ 2 bpm, 180 psi, 7%flow out,22 fpm, observe 14 bbl gain on second 5. P/U=206k, S/O=125k. 08:45 12:00 3.25 7,167 7,167 INTRM1 DRILL CIRC T Circulate and recip from 7167'MD to 7127'MD @ 5 bpm, 370 psi, 22% flow out.Total strokes pumped 7950. SPR's @ 7167'MD,4854'TVD, 10.5 ppg, 11:58 am. #1-20 spm=180 psi,30 spm=220 psi #2-20 spm=180 psi, 30 spm=220 psi 12:00 12:30 0.50 7,167 7,167 INTRM1 DRILL OWFF T Monitor wellforflowbackviatriptank, 21.5 bbl bleed back on a decreasing trend. Blow down topdrive. 12:30 13:30 1.00 7,167 8,012 INTRM1 DRILL TRIP T RIH on elevators from 7167'MD to 8012'MD to check for gas/swab. Monitor displacement via trip tank gained 22 bbl, P/U=217k, S/O=132k. 13:30 19:00 5.50 8,012 8,012 INTRM1 DRILL CIRC T CBU while recip @ 3 bpm, 260 psi, 13%flow out. P/U=230k, S/O=132k. Observed gas spike to 2557 units max correlated to the lceburg, 300 units @ 1200 stks, correlated to stage collar.Pumped total 10,243 strokes with full returns, observe slight gain due well breathing back fluid,eventually taper off to 0 gain/loss. 19:00 00:00 5.00 8,012 8,012 INTRM1 DRILL CIRC T Weight up mud from 10.5 ppg to 10.8 ppg, pumping @ 3 bpm, 300 psi. Reduce pump rate to 2 bpm due to dynamic loss of 56 bph max after 10.8 ppg coming up annulus. Reduced to 30 bph @ 2 bpm pump rate. P/U=230k, S/0=130k. Observed mild differential sticking potential as 10.8 ppg almost to surface. Begin rotary 3 rpm to mitigate. Total losses to formation today=873 bbl Cumulative interval losses=2929 bbl • 11/29/2014 Complete weight up to 10.8 ppg, Pump out of hole to HWDP. P/U Baker RTTS packer to test above/below ES cementer, RIH t/1059' MD 00:00 04:30 4.50 18,012 8,012 INTRM1 DRILL CIRC T Circulate and reciprocate while weighting up from 10.5 ppg to 10.8 ppg @ 2 bpm 156 psi. Total strokes pumped 23320, mud weight out 10.7 ppg. P/U=214k, S/O=134k. Page 19 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:15 0.75 8,012 8,012 INTRM1 DRILL OWFF T Obtain SPR's, Blow down top drive and monitor well for 30 minutes. Observe well bleed back in a decreasing trend until well static in 30 min. SPR's @ 8012'MD, 5297'TVD, 10.8 ppg,04:30 hrs #1-20 spm=160 psi, 30 spm=220 psi #2-20 spm=160 psi, 30 spm=200 psi 05:15 12:00 6.75 8,012 4,144 INTRM1 DRILL TRIP T Pump out of hole from 8012'MD,to 4144'MD @ 2.5 bpm,25 fpm, 140 psi,0-4%flow out. Monitor well losses via pits 1-3. P/U=149k, S/0=108k. Losses avg 35-40 bph. 12:00 14:00 2.00 4,144 3,291 INTRM1 DRILL TRIP T Continue to pump out of hole @ 25 fpm, 2.5 bpm 117 psi from 4144'MD to 3291'MD. Monitor displacement via pits 2-3. P/U=135k, S/0=107k. Losses 35 bph. 14:00 15:00 1.00 3,291 3,291 INTRM1 DRILL OWFF T Monitor well inside shoe for 10 minutes @ 3291'MD. Blow down top drive, loss rate 33 bph. Swap over to hiline power. 15:00 16:00 1.00 3,291 3,380 INTRM1 DRILL CIRC T RIH from 3291' MD to 3380'MD, Circulate and reciprocate @ 3 bpm 129 psi, 0%Flow out,40 rpm,4-5k TQ, P/U=106k, S/O=115k, loss rate 130 bph.Total strokes pumped 1131. 16:00 21:00 5.00 3,380 1,401 INTRM1 DRILL TRIP T Continue to pump out of hole from 3380' MD to 1401' MD @ 2.5 bpm, 25 fpm, 121 psi, 5%Flow out, monitor displacement via pits 2-3. 21:00 22:00 1.00 1,401 1,391 INTRM1 DRILL PULD T Lay down Ghost reamer bottom stand#8. 22:00 23:00 1.00 1,391 822 INTRM1 DRILL TRIP T Continue to pump out from 1401'MD to 822' MD. Monitor well for 10 min prior to pulling HWDP into stack. Well static. SIMOPS-Picking up 3%"handling equipment. Load Baker retrievable test packer to rig floor. 23:00 00:00 1.00 822 1,059 INTRM1 DRILL MPSP T PJSM with Baker rep, rig up and running RTTS and testing. P/U and RIH with RTTS to 1059'MD. 11/30/2014 Tested casing to 2000 psi above and below ES cementer @ 900'. L/D BHA,test annular and valves with 5", All rams and annular w/3%. P/U 3%string and RIH to set cement plugs. 00:00 00:30 0.50 1,059 1,622 INTRM1 DRILL MPSP T Continue to RIH with test packer from 1059'MD to 1622'MD. Packer on HWDP, BHA below. Packer COE=880'. P/U=93k, S/O=95k. Monitor displacement with trip tank. Page 20 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:45 1.25 1,622 1,664 INTRM1 DRILL PRTS T Set test packer @ 880'COE and per Baker rep. Fill lines, close annular and test casing above packer to 250 psi low/2000 psi 5 minutes good. Unlatch packer and RIH to 922'COE and set packer.Test to 250 psi low/200 psi high 5 minutes good, Charted all tests. 01:45 03:15 1.50 1,664 737 INTRM1 DRILL MPSP T Pump out of hole from 1664'MD to 737'MD,monitoring displacement with pits 1-3. 03:15 03:45 0.50 737 737 INTRM1 DRILL MPSP T Blow down topdrive and L/D test packer per Baker rep. 03:45 05:15 1.50 737 176 INTRM1 DRILL TRIP T Continue pumping out of hole, racking back HWDP from 737'MD to 176'MD,2.5 bpm,60 psi, 8%flow out. 05:15 07:30 2.25 176 0 INTRM1 DRILL PULD T PJSM, Rack back drill collars and L/D BHA#3 per DD. 07:30 08:00 0.50 0 0 INTRM1 DRILL RURD T Clean and clear rig floor. 08:00 09:00 1.00 0 0 INTRM1 DRILL BOPE T Pull wear bushing and install test plug, R/U to test BOPE, flood lines and perform shell test. 09:00 12:00 3.00 0 0 INTRM1 DRILL BOPE T Test all BOPE components used while performing well kill 250 psi low, 3500 psi high 5 min each on chart with 5"test joint. Superchoke tested 250/2000 psi.Test#1-Annular, CV1, 12, 13, 14, Superchoke and kill HCR, #2-Annular, CV1,6, 12, 13, 14, HCR Kill.#3-Annular, CV1,4, 6, 7, HCR kill. Change to 3'/2'TJ and test#1- Annular, HCR choke and kill,4'/2' IF Dart.#2-Upper rams, HCR choke and kill,4%" IF TIW,#3-Lower rams. Monitor well via trip tank,gained 2.68 bbl. 12:00 14:00 2.00 0 0 INTRM1 DRILL BOPE T Drain stack, pull test plug install wear bushing, RILDS. L/D test joint, Blow down choke, manifold and kill line, blow down test pump. SIMOPS- pull Strip-o-matic, riser,change out upper air boot in Joes box. Troubleshoot link-tilt calibration. Monitor well via trip tank,well static. 14:00 15:00 1.00 0 916 INTRM1 DRILL RURD T Rig up double stack tongs,casing equipment. 15:00 18:00 3.00 3,258 INTRM1 DRILL PULD T PJSM on running 3'/i'tubing, M/U and run 916'3'/2'EUE 9.3#torque all connections to 2200 ft/lbs.Well static. 18:00 21:00 3.00 916 3,258 INTRM1 DRILL TRIP T M/U XO to 4'/2"IF, C/O slip inserts, RIH out of derrick from 916' MD to 3258'MD, Pipe filling on its own, Well static, P/U=89k, S/0=95k. Page 21 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:30 1.50 3,258 3,258 INTRM1 DRILL SLPC T PJSM cut and slip drilling line. Hang blocks, cut and slip 92'. Calibrate block height, MWD,Amphion and Totco. 22:30 00:00 1.50 3,258 3,258 INTRM1 DRILL CIRC T CBU staging pumps up to 5 bpm, 211 gpm, 86 psi,22% Flow out, P/U=89k, S/O=92k, Reciprocate pipe from 3258' MD to 3160'MD. Establish dynamic loss rate 20 bph. 12/01/2014 RIH w/3%"stinger and circulate bottom up plus losses. Pump cement plug#1, pull up to 7378'and circulate clean. Begin POOH to set packer and test BOPE. Begin testing choke manifold and floor valves. 00:00 00:30 0.50 3,258 3,258 INTRM1 DRILL CIRC T Continue to CBU while reciprocating from 3280'-3195'MD @ 5 bpm, 120 psi,22%flow out. MW in=10.5 ppg, out=10.5 ppg. 00:30 01:00 0.50 3,258 3,258 INTRM1 DRILL OWFF T B/D top drive&monitor flowback, 5.38 bbl in 15 min with decreasing trend. 01:00 04:00 3.00 3,258 7,925 INTRM1 DRILL TRIP T TIH on elevators from 3280'-7925' MD, monitor displacement via TT, P/U=170k, S/0=130k. 04:00 04:30 0.50 7,925 8,018 INTRM1 DRILL CIRC T Wash down from 7925'MD to 8018' MD@ 4 bpm, 240 psi, 16%flow out, tag bottom with pumps @ 2 bpm,set 4k 30 psi pressure increase. 04:30 11:15 6.75 8,018 8,018 INTRM1 DRILL CIRC T Circulate while reciprocate from 8018' to 7971'MD staging pumps up. 2 bpm, 185 psi, 3%Flow 3 bpm, 195 psi,2%Flow 4 bpm, 190 psi,6%Flow,average losses 118 bph @ 4 bpm. 11:15 11:45 0.50 8,018 8,016 INTRM1 DRILL OWFF T Monitor flowback, 17.69 bbl in 20 min,decreasing. SIMOPS-swap power off hiline,on rig 3516's. Monitor well via trip tank. SIMOPS-Blow down top drive and R/U cementing head pin. 11:45 12:30 0.75 8,016 8,016 INTRM1 DRILL CIRC T Circulate and recip from 8016'-8006' MD on cement hose 3 bpm, 140 psi, 14%flow out. 12:30 13:30 1.00 8,016 8,016 INTRM1 DRILL CIRC T Shut down pumps, close annular and line up to take returns through choke/poorboy. Establish circulation 2 bpm 106 psi. 13:30 14:00 0.50 8,016 8,016 INTRM1 DRILL CMNT T PJSM, Shut down pumps, line up to SLB cementers. SLB pump 5 bbl water,pressure test lines to 4000 psi 5 min on chart. Page 22 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 8,016 8,016 INTRM1 DRILL CMNT T Pump 30 bbl Mud Push II 12.5 ppg @ 2 bpm, 126 psi returns through choke, shut down,close choke. Break head pin, install wiper ball#1, make up head pin. Open annular, SLB pump 84.9 bbl of 15.8 ppg cement with 2ppb Cement and GasBlok, followed by 4.6 bbl Mud Push II 12.5 ppg @ 3 bpm, 30 psi, 17%flow out. 15:00 16:30 1.50 8,016 8,016 INTRM1 DRILL CMNT T Swap to rig pumps,displace with 115 bbl of 10.8 ppg mud total 1148 strokes @ 3 bpm, ICP=30 psi, until 850 stks away then climb to FCP=306 psi. Blow down cement line to trucks, break head pin and cement lines Clean and clear while observing drill pipe flow slightly,wait to stop. 16:30 18:00 1.50 8,016 7,378 INTRM1 DRILL TRIP T POOH on elevators from 8016'MD to 7378'MD @ 15 fpm, lay down 5'pup, pick up single to get on depth 7378'. Monitor via trip tank. 18:00 21:00 3.00 7,378 7,378 INTRM1 DRILL CIRC T Drop wiper ball#2, M/U to top drive and CBU @ 3 bpm, 170 psi, 10% flow out. 21:00 23:30 2.50 7,378 7,378 INTRM1 DRILL CIRC T Circulate and reciprocate 7378' MD-7282'MD#3 bpm, 172 psi, 10% -4%flow out varying. Losses 70 bph @ 3 bpm. First sign of ph, 10.8 ppg contaminated Mud Push©6530 strokes.Total strokes pumped 9237, shut down, blow down top drive. Total losses to formation today=793 bbl Cumulative interval losses=4730 bbl 23:30 00:00 0.50 7,378 7,378 INTRM1 DRILL BOPE T Rig up and fill choke manifold with water, bleed out air. Shell test choke manifold valves 13,14,15 and 4%Dart valve,4%TIW test 250 low, 3500 hi 5 min each on chart. SIMOPS-Monitor well via trip tank,8 bph static loss. Prep to POOH to casing shoe to set storm packer and test BOPE,AOGCC witnessed. 12/02/2014 POOH to casing shoe and set storm packer. Perform Bi-weekly BOP test,witnessed by AOGCC Bob Noble. Pull packer,establish circulation, dumped 60 bbl MudPush II, and contaminated cement. 00:00 04:30 4.50 7,378 3,185 INTRM1 DRILL TRIP T Pump out of hole from 7378' MD to 3185'MD monitor displacement via pits 2-3. SIMOPS-Continue to pressure test choke manifold to 250/3500 psi, 5 min each charted. Tested valves 3-15, manual choke and auto-choke to 2000 psi. Page 23 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:00 0.50 3,185 3,185 INTRM1 DRILL OWFF T Blow down top drive and monitor well, 1.35 bbl flowback in 35 min then static. 05:00 07:00 2.00 3,185 3,307 INTRM1 WHDBO MPSP T M/U Baker test packer, equalizing valve and twin thread release sub per BOT rep. RIH and set @ 114'COE, (TT @ 3307')attempt to back off, failed. Pulled to surface and set 3 more screws in valve assy, RIH,set and attempt to back off,failed. Pulled to surface again, replaced screws in valve assy and backed off twin thread 1.5 turns, RIH and set,successful back off. L/D running tool. P/U=91k, S/0=91k. Well static slight drop. 07:00 07:30 0.50 3,307 3,307 INTRM1 WHDBO PRTS T Close blinds and pressure test packer to 500 psi,failed.Would not hold any pressure, injecting @ 2 bpm 120 psi. PT surface equipment to verify. Bleed off, open blinds,well flowing back slightly. New equalizing sub on the way from Deadhorse. 07:30 08:30 1.00 3,307 3,307 INTRM1 WHDBO WWWH T Make up stack washer and RIH to wash stack and casing to 95'MD @ 17 bpm, 150 psi,47%flow out, 15 rpm. Cleaned good amount of material from casing and stack. 08:30 09:30 1.00 3,307 3,307 INTRM1 WHDBO SVRG T Wait on test packer, service topdrive and clean rig floor. Well static slight drop. 09:30 10:45 1.25 3,307 3,277 INTRM1 WHDBO MPSP T M/U overshot and RIH,engage and pull test packer, L/D same. M/U new equalizing valve and twin thread sub, RIH and set at 84' MD RKB COE. (TT @ 3277') P/U=91k, S/0=91k. 10:45 11:00 0.25 3,277 3,277 INTRM1 WHDBO PRTS T Close blinds and test packer from above to 500 psi 5 min good. 11:00 12:00 1.00 3,277 3,277 INTRM1 WHDBO RURD T Drain stack, pull wear bushing and set test plug. Flood lines with fresh water and line up for shell test. 12:00 13:30 1.50 3,277 3,277 INTRM1 WHDBO RURD T Continue riggng up for shell test on BOPE,wait for AOGCC inspector Bob Noble.SIMOPS-Open up and inspect Mud Pump#1. Clean rig. Page 24 of 64 Time Logs - Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 17:00 3.50 3,277 3,277 INTRM1 WHDBO BOPE T Perform full bi-weekly BOP test with 5"test joint and 3%test joint. Testing performed to 250/3500 psi 5 min each charted with AOGCC Bob Noble witness. Manual and Auto Choke tested to 250/2000 psi. 5"tested annular, Upper rams, Lower rams. 3%"tested upper rams, lower rams,tested choke valves 1-15, choke and kill manual and HCR valves,4"valve on kill line,4%IF TIW #1,#2,4%"IF Dart, Upper and lower IBOP's. 17:00 17:30 0.50 3,277 3,277 INTRM1 WHDBO BOPE T Perform Accumulator test/drawdown test. System pressure 3000 psi, manifold 1500 psi, pressure after functioning all devices 1600 psi, 200 psi attained=21 seconds, full pressure attained=117 sec. 6 bottle N2 average=2050 psi. Closing times: Annular=23 seconds Upper rams=18 seconds Blinds=16 seconds Lower rams=16 seconds Choke and kill HCR=2 seconds each. 17:30 19:30 2.00 3,277 3,277 INTRM1 WHDBO RURD T Pull test plug,drain stack, install 9.8125"ID wear ring, blow down test pump, choke line and manifold. Monitor well via trip tank-Static 19:30 21:00 1.50 3,277 3,277 INTRM1 DRILL SVRG T C/O saver sub, clean and inspect PS-21's(auto-slips)install slip inserts. SIMOPS-install strip-o-matic, new lines too long, remove same. 21:00 22:30 1.50 3,277 3,197 INTRM1 DRILL MPSP T PJSM on retrieving storm packer with BOT reps. P/U double, M/U overshot, RIH and tag up @ 84'MD. P/U and grease pipe for annular. M/U to top drive, rotate 5 rpm 400 ft/lbs tq, S/O 41k down rotate 6 turns. Observe 1k tq shear on valve, rotate 9 more turns,tq up to 2600 as valve fully opened. Monitor DP pressure 0. Close annular, reduce pressure to 650 psi, open HCR choke, P/U 3" 101k, monitor annulus pressure 0. Open annular observe well static, little9 as bubbles. P/U and confirm releas, POOH and L/D storm packer, valve and overshot per Baker reps. 22:30 23:00 0.50 3,197 3,277 INTRM1 DRILL PULD T P/U stand,double and single making up stand 25. RIH to 3277'MD Page 25 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 3,277 3,277 INTRM1 DRILL CIRC T CBU @ 2 bpm, 86 psi, 26%flow out. Flow increased to 50% @ 550 strokes in due cement/cement contamination in returns. Dump 100 bbl very thick cement contaminate,then observe loss rate return from 40%loss to 0 loss. Total losses to formation today=65 bbl Cumulative interval losses=4795 bbl 12/03/2014 RIH and CBU, set 15.8 ppg plug#2 and 17.0 ppg Kickoff plug#3. Establish circulation to circ out excess cement and MudPush II. 00:00 04:30 4.50 3,277 3,277 INTRM1 DRILL CIRC T Continue CBU @ 3272' MD @ 4 bpm, 90 psi,22%flow out. Mud weight in/out 10.6 ppg,total strokes pumped 2419. Circulate out excess MudPush and cement contamination. Full returns after heavy contaminate out of hole, dumped 40 bbl returns. 04:30 05:00 0.50 3,272 7,350 INTRM1 DRILL TRIP T TIH on elevators with 3'/z'on 5" DP from 3272'-7350'MD,stop and clear mule shoe every 2000'. P/U=168k, S/O=112k. 05:00 07:00 2.00 7,350 7,374 INTRM1 DRILL WASH T Wash down from 7350'MD @ 1 bpm,240 psi minimal flow out.Tag cement plug @ 7374' MD with 5k down wt. Re-tag to confirm. 07:00 07:30 0.50 7,357 0 INTRM1 DRILL CIRC T P/U 10'pup and circulate while recip from 7357'MD to 7313'MD stagfing up pumps. 2 bpm,235 psi, 2%flow out, 26% loss. 3 bpm,240 psi,4%flow out, 68% loss. Back off to 2.5 2.5 bpm,205 psi, 1-2%flow out, 69%loss. 07:30 08:30 1.00 7,357 7,357 INTRM1 DRILL CMNT T Blow down top drive and R/U cement hose. 08:30 09:30 1.00 7,357 7,357 INTRM1 DRILL CMNT T Establish circulation through cement hose,staging up to 1.7 bpm, 190 psi,flow out increasing to 9%. 09:30 11:00 1.50 7,357 7,357 INTRM1 DRILL SFTY T PJSM with rig crew, SLB cement crew and CPAI rep on cementing plug pumping operation. Page 26 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 7,357 7,357 INTRM1 DRILL CMNT T SLB pumped 5 bbl water, PT line to 4000 psi-good. Line up and pump 30 bbl 12.5 ppg MudPush II. Shut down, close annular and break off head pin, load wiper ball. Open annular and SLB pump 85 bbl 17.0 ppg Cement with 2 ppb Cemnet and 2 gal/sx GasBlok @ 3 bpm,chase with 4.6 bbl MudPush II 12.5 ppg,displaced by rig with 102 bbl 10.8 ppg mud @ 8 bpm, 200 psi, 25%flow, reducing to 3 bpm, 111 psi, 20%flow. Total 1017 strokes pumped. 12:00 13:00 1.00 7,357 6,748 INTRM1 DRILL TRIP T Bleed off, check for flow, break off head pin and POOH on elevators @ 20 fph to 6748' MD. 13:00 18:45 5.75 6,748 6,735 INTRM1 DRILL CIRC T Load wiper ball, M/U head pin and stage up pumps to 3 bpm,207 psi, 14%flow out, losses 48 bph decreasing. Reciprocate pipe from 6748'MD to 6735'MD. SIMOPS-PJSM with SLB, Rig crew and CPAI on cement plug#3. 18:45 19:30 0.75 6,735 6,748 INTRMI DRILL CIRC T Continue circulate and reciprocate while SLB batches up 17.0 ppg cement and 12.5 ppg MudPush II. Pumping 3.5 bpm, 175 psi 22%flow out losses decreased to 12 bph. 19:30 21:00 1.50 6,748 6,748 INTRM1 DRILL CMNT T SLB pumped 5 bbl water, PT line to 4000 psi-good. Pumped 30 bbl 12.5 ppg MudPush II,shut down and close annular. Break head pin and load wiper ball. Open annular, SLB pumped 85 bbl 17.0 ppg cement with 2 ppb Cemnet @ 3 bpm, chased with 4.6 bbl MudPush II. Rig displaced with 90 bbl 10.8 ppg mud @ 8 bpm initial 165 psi until pressure started building,then decreased to 3 bpm-179 psi @ 902 stks. 21:00 22:15 1.25 6,748 6,210 INTRM1 DRILL TRIP T R/D head pin, blow down cement line to SLB. POOH @ 20 fpm from 6748' _ to 6210'MD on elevators. __ 22:15 00:00 1.75 6,210 6,210 INTRM1 DRILL CIRC T Load wiper ball, Kelly up and establish circulation,stage pumps up to 3 bpm,240 psi. Loss rate 90 bph. Cement plug in place @ 23:00 hrs. Total losses to formation today=513 bbl Cumulative interval losses=5308 bbl 12/04/2014 Circ out excess cement, OWFF and WOC.Tag cement plug#3 @ 6351' MD. POOH with 3%"stinger to 4508'to prep for plug#4. Page 27 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 6,210 6,210 INTRM1 DRILL CIRC T Continue to circulate and reciprocate post cement job from 6210' MD to 6115 MD @ 3 bpm, ICP=220, 11% Flow out, FCP=170 psi, 17%Flow out. Mud weight in 10.8 ppg, Mud weight out 10.9 ppg.Average loss rate 80 bph, reduced to 20 bph final. 06:00 12:00 6.00 6,210 6,210 INTRM1 DRILL WOC T Monitor well while circulate over well with trip tank, reciprocate pipe. P/U=149k, S/O=111k. SIMOPS service and inspect rig, complete PM's, build and take on mud. 12:00 13:00 1.00 6,210 6,210 INTRM1 DRILL WOC T Continue WOC,Attend meeting with Mike Wheatall, Chip Alvord and Fred Herbert CPAI while monitoring well, .5 bph static loss rate. 13:00 13:30 0.50 6,210 6,351 INTRM1 DRILL CIRC T Establish circulation @ 2 bpm, 17% flow out. RIH and tag cement @ 6351'MD with 5-7k WOB, 100 psi increase in pressure. Re-confirm tag depth. P/U=149k, S/O=112k. Dynamic loss rate 24 bph. 13:30 16:00 2.50 6,351 6,320 INTRM1 DRILL CIRC T Stage pumps up to 5 bpm,227 psi, 29%flow out, reciprocate string from 6320'MD to 6280'MD. Dynamic losses 12 bph. 16:00 16:30 0.50 6,320 6,320 INTRM1 DRILL OWFF T Shutdown and monitor well, diminishing trickle. 16:30 20:30 4.00 6,320 4,508 INTRM1 DRILL TRIP T Pull a stand,well giving fluid back. Pump out from 6320'MD to 4508' MD @ 20 spm 110 psi, 7%flow out, 60 fpm, monitor well displacement 6 bbl over calculated. 20:30 00:00 3.50 4,508 4,508 INTRM1 DRILL CIRC T CBU and reciprocate string @ 4508' MD,stage pumps up to 5 bpm 160 psi,27%flow out, 16 bph dynamic loss. P/U=110k, S/O=97k. SIMOPS- drift jars with 2.115"Well Commander activation ball. 12/05/2014 Spot 83 bbl,50 ppb Gel pill @ 4505-4036'. Pump Cement plug#4,4036'-3491'MD. Pull up,clear string and CBU. 00:00 04:15 4.25 4,508 0 INTRM1 DRILL CIRC T Continue circulating while reciprocating fron 4508' MD-4411'MD @ 5 bpm, 150 psi, 27% Flow out. Continue PM's and rig scrubbing while building 80 bbl Bentonite pill for cement pad.Waiting on cement lab work to be completed. 04:15 06:00 1.75 4,508 4,036 INTRM1 DRILL TRIP T Pump 83 bbl, 10.8 ppg, 50 ppb Bentonite pill to bit, over displace pill in hole 150%v/v while POOH to 4036' MD. Pumping 2 bpm 270 psi, 11%flow, pulling 15 fpm. Page 28 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 10:00 4.00 4,036 4,036 INTRM1 DRILL OWFF T Circulate over top of well with hole fill @ 4033'MD. Monitor for losses- none. Complete PM's, rig up cement hose/head pin to string whiler R/U for cement job. 10:00 10:30 0.50 4,036 4,036 INTRMI DRILL SFTY T PJSM with rig crew, SLB cementers and CPAI pumping cementing plug #4. 10:30 12:00 1.50 4,036 4,036 INTRM1 DRILL CMNT T Establish circulation 2 bpm, 130 psi, 11%flow, batch up cement. 12:00 12:30 0.50 4,036 4,036 INTRM1 DRILL CMNT T Line up SLB, pump 5 bbl water, PT line to 400 psi-good,test trips. 12:30 13:30 1.00 4,036 4,036 INTRM1 DRILL CMNT T SLB pumped 30 bbl 12.5 ppg MudPush II 3 bpm,34 psi, 19%flow out. Shut down, close annular, break head pin and load wiper ball. M/U heads pin, SLB pump 78 bbl 15.8 ppg Cement w/2 ppb Cemnet, 50 psi,21%flow. Chase cement with 5.2 bbl 12.5 ppg MudPush II, displace with rig pumps 10.8 ppg mud @ 8 bpm, 145 psi,24%flow until catch cement, reduce rate to 3 bpm 50 psi total 397 strokes. C I P:13:30. 13:30 15:00 1.50 4,036 3,090 INTRM1 DRILL TRIP T Rig down cement head, blow down. POOH from 4034'MD to 3090'MD @ 15 fpm. Monitor well via trip tank, pull string out above cement @ 15:00 hrs. 15:00 17:00 2.00 3,090 3,090 INTRM1 DRILL CIRC T Insert wiper ball#2, circulate bottom up @ 3 bpm, 85 psi, 11°/0 flow out total 3000 strokes.Total losses 20 bbl. 17:00 22:00 5.00 3,090 3,090 INTRMI DRILL WOC T Wait on cement SIMOPS-Perform derrick inspection, rig maintenance, houskeeping, monitor well via trip tank-static. 22:00 00:00 2.00 3,090 3,090 INTRMI DRILL WOC T Observe 1 bbl gain over 30 minutes. Kill hole fill and flow check well, observe well flowing at 2 bph. Mud weight 10.8 ppg. 12/06/2014 WOC to tag. RIH,wash down and tag @ 3810'MD, confirm. Reduce mud weight from 10.8 ppg to 9.8 ppg. Wait on cementers to pump KO plug#5. 3810'-3142' MD 00:00 03:00 3.00 3,090 3,090 INTRM1 DRILL WOC T Waiting on cement to cure 17 hrs, 8am. CBU @ 3090', stage pumps to 2 bpm 100 psi, 10%flow out 65 psi. Treat mud due cement contamination. Maintain density 10.8 ppg. Observe slight gain in volume while circulating,2 bph well breathing back. 03:00 05:00 2.00 3,090 3,090 INTRM1 DRILL WOC T Monitor well 15 minutes,observe 1.5 bph flow back from well exhaling. Resume pumping 1 bph,45 psi,well continues to exhale 1.5-2 bph. Page 29 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 08:00 3.00 3,090 3,090 INTRM1 DRILL WOC T Blow down top drive,monitor well via trip tank. Observe static gain 1.5 bph. P/U=89k, S/O=86k. 08:00 09:45 1.75 3,090 3,810 INTRM1 DRILL WASH T Break circulation and wash down to tag cement top. Circ @ 2 bpm, 110 psi, 14%flow out. Observe 50 psi increase and 2-3k drag @ 3778'MD. Increase rate to 3 bpm, 175 psi, 20% flow out. Continue wash down and tag TOC @ 3810'MD with 7k set down, 100 psi increase. P/U and re-tag to confirm. P/U=101k, S/O=94k. Monitor displacement with pit#2, 1 bbl over displacement for 7 stands. 09:45 12:00 2.25 3,810 3,810 INTRM1 DRILL CIRC T Circulate and reciprocate from 3746' MD to 3809'MD @ 3 bpm, 135 psi, 20%flow out. Reduce mud weight from 10.8 ppg to 9.8 ppg while waiting on cementers to arrive on location. Mud weight down to 10.5 ppg at 12:00 hrs. 12:00 19:30 7.50 3,810 3,810 INTRM1 DRILL CIRC T Continue reducing mud weight while circulating @ 3 bpm, 110 psi, 20% flow out. Density=9.8 ppg in/out @ 18:00 hrs. 19:30 00:00 4.50 3,810 3,740 INTRM1 DRILL OWFF T Continue to wait on cementers, stand back one stand to perform general cleaning and maintenance. Reciprocate slowly 3740'MD-3709' MD. 12/07/2014 Pump cement plug#5, 3810'-3142'MD. Pull up 10 stands and circulate clean.WOC. Submitted notification to AOGCC to test BOPE on 12/8. 00:00 06:00 6.00 3,740 3,799 INTRM1 DRILL OWFF T Wait on cementers,work pipe every 20 minutes. P/U=105k, S/0=103k. Blow down cement line, service and inspect topdrive, clean and inspect PS-21 slips, housekeeping, clean MP suction screens, service crown. P/U 5'pup, 10'pup and a single to get on depth for cement job 3799' MD. Continue to monitor hole via trip tank observing 2 bph gain. 06:00 09:00 3.00 3,799 3,799 INTRM1 DRILL OWFF T Continue to monitor well via trip tank working pipe every 20 min. 09:00 10:00 1.00 3,799 3,799 INTRM1 DRILL CIRC T Break circulation,stage pumps to 2 bpm, 70 psi,8%flow out. Circulate and reciprocate from 3799'-3784'MD. P/U=104k, S/O=98k. 10:00 10:15 0.25 3,799 3,799 INTRM1 DRILL SFTY T PJSM with SLB, Drilling Crew and CPAI cment plug#5 Page 30 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 11:30 1.25 3,799 3,799 INTRM1 DRILL CMNT T Swap to SLB, pumped 5 bbl water, test to 4000 psi-good. Pumped 30 bbl 12.5 pg MudPush II 3 bpm 75 psi, Shut down,close choke/annular, load wiper ball, R/U. Open choke/annular, pump 85.73 bbl 17.0 ppg cement, 3 bpm 65 psi,swap to 6.2 bbl 12.5 ppg MudPush II. Rig displace with 355 strokes, ICP 200 psi 8 bpm, reduce to 3 bpm 260 psi @ 300 stks. Full returns throughout cement job. 11:30 13:00 1.50 3,799 2,810 INTRM1 DRILL TRIP T Rig down cement line, lay down single and pups to pipe shed. POOH racking back stands at 15 fpm to 2810'MD. Monitor well via trip tank. 13:00 15:00 2.00 2,810 2,810 INTRM1 DRILL CIRC T Load foam wiper ball, M/U top drive, circulate and reciprocate from 2805' MD-2745'MD©4 bpm, 120 psi, 23%flow out. No losses. 15:00 00:00 9.00 2,810 2,810 INTRMI DRILL WOC T Monitor well via trip tank, 0 gain/Ioss.Reciprocate string from 2810'-2745'periodically. P/U=82k, S/O=85k, SIMOPS-clean out cuttings tank, perform MP2 maintenance, general houskeeping, cleaning parts vans. 12/08/2014 Wait on cement and tag with tubing. POOH and L/D.Test BOPE, P/U BHA and RIH to drill out cement to 3292'. 00:00 06:00 6.00 2,810 2,810 INTRM1 DRILL WOC T Continue to wait on cement, reciprocate pipe every 30 minutes from 2807'-2792'MD. P/U=80k, S/O=87k. Continue cleaning rig, C/O butterfly valve on cuttings tank suction in hot room. P/U single and pup joints from pipe shed and lay down same.Load 5"test joint in pipe shed, perform scheduled PM's. 06:00 06:30 0.50 2,810 2,916 INTRM1 DRILL WASH T Break circulation,stage pump to 2 bpm,80 psi, 11%flow out.Wash down from 2807'MD to 2898'MD. Begin taking 2-3k weight and 50 psi increase in pump pressure @ 2898' MD. Increase pump rate to 3.5 bpm, 120 psi, 21%flow out.Wash down tag firm cement 2916'MD TOC with 6k set down. P/U, re-tag and confirm. 06:30 08:00 1.50 2,916 2,916 INTRMI DRILL CIRC T Circulate with reciprocation 2915' MD-2897'MD staging pumps up to 336 gpm, 220 psi, 27%flow out. Continue conditioning mud per Mud Eng due cment contamination.Total strokes pumped=5903. Page 31 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:30 1.50 2,916 913 INTRM1 DRILL TRIP T Blow down top drive, monitor-well static. POOH from 2916'MD to 913' MD, monitor displacement via trip tank. 09:30 10:00 0.50 913 913 INTRM1 DRILL CIRC T Pump 10 bbl, 10.8 ppg dry job. Blow down top drive, C/O slip inserts. 10:00 13:30 3.50 913 0 INTRM1 DRILL PULD T POOH, laying down 3'/i'tubing string 30 joints and mule shoe. 13:30 14:30 1.00 0 0 INTRM1 DRILL RURD T Clean and clear rig floor, rig down casing tools. R/U to M/U BHA#4 cleanout assembly. 14:30 16:00 1.50 0 670 INTRM1 DRILL PULD T Lay down top single off collar stand, M/U collars,stabilizer, bit sub and bit. RIH and P/U collar joint, HWDP/Jars to 670' MD. 16:00 16:45 0.75 670 1,333 INTRM1 DRILL PULD T P/U 5"singles form pipe shed from 670'MD to 1333'MD. 16:45 22:45 6.00 1,333 2,663 INTRM1 DRILL TRIP T RIH out of derrick with 5"DP, breaking every connection inspecting for cement rings. Fill pipe every 2000', monitor proper displacement via trip tank. RIH to 2663'MD tag cement stringer. 22:45 00:00 1.25 2,663 2,943 INTRM1 DRILL DDRL T M/U to stand 22, break circulation stage pumps up to 450 gpm, 875 psi,30 rpm,4-5k Tq, 31%flow out. Ream down to 2916'tag firm cement. Drill cement to 2943'MD, P/U=112k, S/0=105k, ROT=111k,4-5k Tq, Mud weight 9.8 ppg. Crew change. 12/09/2014 Continue to drill cement to 3292', CBU and POOH. LD BHA and test BOPE; Good test.Witness waived by AOGCC John Crisp. PU drilling BHA#5 and RIH to 1484'. 00:00 06:00 6.00 2,943 3,292 INTRM1DRILL DRLG T Drill cement with 500 GPM, 1140 psi,65 RPM with 9K torque at 35K WOB, 35%flow out. Drill cement to 3292' MD, PU=116K, SO=110K, ROT=113K, Mud weight 9.8 ppg. 06:00 07:30 1.50 3,292 3,220 INTRM1 DRILL CIRC T CBU, rotate and recip from 3220'to 3292'with 500 GPM at 1150 psi,65 RPM with 6K torque. Total strokes pumped; 5994. Monitor well; Static. PU= 111K, S0= 105K. 07:30 08:00 0.50 3,220 670 INTRM1 DRILL CIRC T Pump 15 BBL dry job, blow down top drive. 08:00 10:45 2.75 670 0 INTRM1 DRILL TRIP T POOH to 670'and LD BHA#4, rack back HW and stand back 5"DP. LD Stab, subs and bit per SLB DD. 10:45 11:00 0.25 0 0 INTRM1 DRILL RURD T Clean and clear floor. 11:00 12:00 1.00 0 0 INTRM1 WHDBO RURD T Pull wear bushing, set test plug, RU test equipment and flush and fill lines with water and perform body test on stack;Good. Crew change. Page 32 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 0 0 INTRM1 WHDBO BOPE T Test BOPE: Witness waived by AOGCC John Crisp. Perform test 250/3500 psi for all components except manual operated and Super choke tested at 250/2000 psi. Performed all tests with 5"test joint;Annular,2 7/8 x 5 1/2"UPR and LPR,tested choke valves 1-15, manual and Super choke,choke and HCR, Kill manual. 4"valve on Kill line,4"TIW#1 and#2,4"dart, Upper and Lower IBOP. Perform KOOMEY test; mit P=3000 psi, Manifold= 1500 psi,After function P= 1800 psi, Recovery for 200 psi= 21 seconds, Recovery with 1 Elect pump=91 seconds, Closing times; Annular=23, UPR= 18, LPR= 16. Blinds= 16, Choke HCR=2 seconds, Kill HCR=2 seconds. BD top drive. 17:00 18:00 1.00 0 0 INTRM1 WHDBO RURD T PUll test plug and drain stack, BD kill lines,chokes and manifold,test pump. Install wear ring, RILDS, ;LD 5"test joint. 18:00 19:00 1.00 0 0 INTRM1 DRILL RURD T Clean and clear floor, pull PS-21 hydraulic slips insert strip-o-matic, bring on mud to pits. 19:00 21:00 2.00 0 786 INTRM1 DRILL PULD T PU BHA#5; drilling assembly. 21:00 00:00 3.00 786 1,484 INTRMI DRILL TRIP T RIH with DP from derrick from 786'to 1484'for SPT for MWD. Crew change. 12/10/2014 Shallow test MWD;good. RIH,test casing to 12.5 EMW. Slip and Cut drill line and change wash pipe. Drill out and kickoff at 3410'and perform FIT to 12.4 EMW at 3460'. Drill ahead to 3818'. 00:00 00:45 0.75 1,484 1,484 INTRM1 DRILL CIRC T Shallow test MWD; Good test. blow down topdrive. 00:45 02:00 1.25 1,484 3,254 INTRM1 DRILL TRIP T RIH from 1484'to 3254'on trip tank; good displacement. 02:00 02:45 0.75 3,254 3,254 INTRM1 DRILL CIRC T Circulate complete surface to surface after pumping DP volume and found well out of balance. Pump 500 GPM with 1000 psi, 2900 strokes. well balanced, blow down topdrive. 02:45 03:45 1.00 3,254 3,254 INTRM1 DRILL PRTS T PJSM, RU test equipment and Test casing to 12.5 EMW; Good test with 400 psi. 03:45 05:00 1.25 3,254 3,254 INTRMI DRILL SLPC T Slip and cut 34'of drill line. Calibrate depth and block sensors, monitor well with trip tank; Static. 05:00 05:30 0.50 3,254 3,254 INTRM1 DRILL SVRG T Service topdrive and drawworks. 05:30 06:15 0.75 3,254 3,254 INTRM1 DRILL RGRP T Change out swivel packing on topdrive. Page 33 of 64 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 06:15 08:30 2.25 3,254 3,342 INTRM1 DRILL WASH T Obtain SPR's,wash down and tag cement at 3292'. Drill cement from 3292'to 3342'(shoe depth)at 550 GPM with 1190 psi and 90 RPM with 9K torque and 10K WOB. PU= 124K, SO= 108K, Rot= 115K. 08:30 12:00 3.50 3,342 3,410 INTRM1 DRILL DRLG T Drill from 3342'to 3410'at 550 GPM with 1190 psi and 90 RPM with 9K torque and 10K WOB with ECD= 10.38 ppg. PU= 124K, S0= 108K, Rot=115K. ADT= 1.63 hours, Bit hours= 1.63, Jars= 1.63 hours. No losses this tour. SPR @ 3284' MD. 2808'TVD 07:15; 9.9 ppg #1 MP;20/30 SPM=80/100 psi #2 MP;20/30 SPM=80/100 psi Crew change. 12:00 14:00 2.00 3,410 3,460 INTRM1 DRILL DDRL T Drill from 3410'to 3460'at 550 GPM with 1210 psi and 100 RPM with 11K torque and 10K WOB with ECD= 10.5 ppg. PU= 128K, SO= 110K, Rot= 109K. 14:00 14:30 0.50 3,460 3,460 INTRM1 DRILL CIRC T Circulate and condition mud in and out; 9.9 ppg. 14:30 15:00 0.50 3,460 3,250 INTRM1 DRILL TRIP T POOH from 3460'to 3250'. Blow down topdrive. 15:00 16:30 1.50 3,250 3,250 INTRM1 DRILL FIT T PJSM fo FIT, RU test equipment and perform FIT to 12.4 EMW, monitor flow back; 0.5 BBL. RD and blow down all lines. 16:30 17:30 1.00 3,250 3,440 INTRM1 DRILL SRVY T RIH from 3250'to 3440'taking surveys to delineate Kick Off point and departure from cement plug. 17:30 18:00 0.50 3,440 3,440 INTRM1 DRILL CIRC T Circulate displacement for 9.7 ppg mud in and out at 800 GPM with 2038 psi. Obtain SPR's and monitor well; static. 18:00 00:00 6.00 INTRM1 DRILL T Drill from 3460'to 3818'at 550 GPM with 1125 psi and 100 RPM with 10K torque and 10K WOB with ECD= 10.46 ppg. PU= 133K, S0= 109K, Rot= 118K. ADT=3.66 hours, Bit hours=5.29, Jars=5.29 hours. Losses this tour =0 BBLs SPR @ 3459'MD.2887'TVD 18:30; 9.7 ppg #1 MP;20/30 SPM= 105/150 psi #2 MP;20/30 SPM= 100/140 psi Crew change. 12/11/2014 Drill ahead to 5617'in the 9 7/8"intermediate, using dilutions to manage drilling ECD. ECD through the day 10.80 to 11.10 ppg. Low background gas with minor connection gas. Page 34 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 3,818 3,913 INTRMI DRILL DDRL T Drill from 3818'to 3913'at 550 GPM with 1125 psi and 100 RPM with 9K torque and 10K WOB with ECD= 10.58 ppg. PU= 134K, S0= 109K, Rot=118K. 01:15 01:45 0.50 3,913 3,913 INTRM1 DRILL SVRG T Blow down topdrive and grease washpipe. Install TIW for TS MWD 01:45 03:15 1.50 3,913 3,913 INTRM1 DRILL CIRC T Trouble shoot MWD signal and decoding, change out sensor on standpipe. Cycle pumps for reset of tool,downlink and set to different frequency telemetry. 03:15 12:00 8.75 3,913 4,669 INTRM1 DRILL DDRL T Drill from 3913'to 4669'at 650 GPM with 1775 psi and 120 RPM with 9K torque and 12K WOB with ECD= 11.06 ppg. PU=152K, SO= 120K, Rot= 131K. ADT=6.33 hours, Bit hours= 11.62, Jars= 11.62 hours. Losses this tour=0 BBLs SPR @ 4292'MD. 3249'TVD 08:00; 9.7 ppg #1 MP;20/30 SPM= 130/170 psi #2 MP; 20/30 SPM= 130/170 psi Crew change. 12:00 17:45 5.75 4,669 5,140 INTRM1 DRILL DDRL T Drill from 4669'to 5140'at 700 GPM with 2166 psi and 120 RPM with 11K torque and 14K WOB with ECD= 11.06 ppg. PU= 152K, S0= 120K, Rot= 131K. SPR©4762' MD. 3508'TVD 13:30; 9.7 ppg #1 MP;20/30 SPM= 140/180 psi #2 MP;20/30 SPM= 150/190 psi 17:45 18:00 0.25 5,140 5,140 INTRM1 DRILL SVRG T Service rig;grease wash pipe due to excessive vibration on drill pipe while drilling. 18:00 23:45 5.75 5,140 5,617 INTRM1 DRILL DDRL T Drill from 5140'to 5617'at 700 GPM with 2321 psi and 120 RPM with 13K torque and 14K WOB with ECD= 10.94 ppg. PU= 152K, SO= 120K, Rot= 131K. ADT=7.18 hours, Bit hours= 18.80, Jars= 18.80 hours. Losses this tour=0 BBLs SPR @ 5239'MD. 3741'TVD 19:00; 9.7 ppg #1 MP;20/30 SPM= 120/160 psi #2 MP;20/30 SPM= 120/160 psi Crew change. 23:45 00:00 0.25 5,617 5,617 INTRM1 DRILL RURD T PJSM, remove PS-21 slips and install master bushing to protect PS-21 from damage due to excessive vibration on drill pipe while drilling. Page 35 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/12/2014 24 hr Summary Drilling ahead to 7100'with ECD= 11.5 ppg at 750 GPM and 10.1 ppg mud weight. Weighted up mud system from 9.7 to 10.1 ppg 6800'. Continued to weight up to 10.5 ppg, at 7100'circulated to finish weight up. 00:00 06:00 6.00 5,617 6,087 INTRM1 DRILL DDRL T Drill from 5617'to 6087'at 750 GPM with 2650 psi and 120 RPM with 15K torque and 14K WOB with ECD= 11.05 ppg. PU= 188K, SO= 119K, Rot= 140K. 06:00 12:00 6.00 6,087 6,465 INTRM1 DRILL DDRL T Drill from 6087'to 6465'at 750 GPM with 2800 psi and 90 RPM with 13K torque and 16K WOB with ECD= 11.04 ppg. PU= 185K, SO= 125K, Rot= 143K. ADT=8.5 hours, Bit hours=27.3, Jars=27.3 hours. Losses this tour =0 BBLs SPR @ 6276'MD.4240'TVD 08:52; 9.7+ppg #1 MP;20/30 SPM= 120/160 psi #2 MP;20/30 SPM= 120/160 psi Crew change. 12:00 14:30 2.50 6,465 6,636 INTRM1 DRILL DDRL T Drill from 5617'to 6087'at 750 GPM with 2650 psi and 120 RPM with 15K torque and 14K WOB with ECD= 11.05 ppg. PU= 188K, SO= 119K, Rot= 140K. 14:30 16:00 1.50 6,636 6,636 INTRM1 DRILL RGRP T Replace Airboot on low pressure riser. 16:00 23:30 7.50 6,636 7,100 INTRM1 DRILL DDRL T Drill from 6636'to 7100'at 750 GPM with 3080 psi and 100 RPM with 14K torque and 16K WOB with ECD= 11.04 ppg. Drilled from 6996'to 7100' controlling ROP at 50 ft/hr to allow for weight up in the pits to 10.5 ppg, then stopped and circulated to complete weight up. PU=202K, SO= 130K, Rot= 156K. ADT=6.53 hours, Bit hours=33.83, Jars=33.83 hours. Losses this tour=0 BBLs SPR @ 6745'MD.4467'TVD 17:50; 10.0 ppg #1 MP; 20/30 SPM=200/240 psi #2 MP; 20/30 SPM= 180/240 psi Crew change. 23:30 00:00 0.50 7,100 7,100 INTRM1 DRILL CIRC T Circulate and condition mud to weight up to 10.5 ppg in and out. 12/13/2014 Continue to circulate at 7100'and bring mud weight to 10.5 ppg in and out. Resume drilling from 7100'to 8927'. 00:00 00:45 0.75 7,100 7,100 INTRM1 DRILL CIRC T Circulate to bring 10.5 ppg mud around. Take SPRs. Stage pumps and get baseline ECD= 11.71 ppg. SPR @ 7100'MD.4630'TVD 00:30; 10.5 ppg #1 MP; 20/30 SPM= 180/220 psi #2 MP; 20/30 SPM= 180/220 psi Page 36 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 06:00 5.25 7,100 7,508 INTRM1 DRILL DDRL T Drill from 7100'to 7508'at 750 GPM with 3160 psi and 110 RPM with 16K torque and 16K WOB with ECD= 11.90 ppg. PU=206K, S0= 130K, Rot= 160K. 06:00 12:00 6.00 7,508 7,981 INTRM1 DRILL DDRL T Drill from 7508'to 7981'at 750 GPM with 3320 psi and 120 RPM with 17K torque and 16K WOB with ECD= 11.85 ppg. PU=210K, SO= 129K, Rot= 160K. ADT=6.88 hours, Bit hours=40.71, Jars=40.71 hours. Losses this tour=0 BBLs SPR @ 7696'MD,4924'TVD 08:30; 10.5 ppg #1 MP;20/30 SPM= 180/240 psi #2 MP;20/30 SPM= 180/240 psi Crew change. 12:00 12:30 0.50 7,981 8,018 INTRM1 DRILL DDRL T Drill from 7981'to 8018'at 750 GPM with 3100 psi and 120 RPM with 15K torque and 14K WOB with ECD= 11.05 ppg. PU= 188K, S0= 119K, Rot=140K. 12:30 18:45 6.25 8,018 8,550 INTRM1 DRILL DDRL P Drill from 8018'to 8550'at 750 GPM with 3410 psi and 120 RPM with 20K torque and 16K WOB with ECD= 11.85 ppg. PU=235K, SO= 138K, Rot= 179K. SPR @ 8072' MD. 5143'TVD 13:00; 10.5 ppg #1 MP;20/30 SPM=200/260 psi #2 MP; 20/30 SPM=200/240 psi 18:45 19:15 0.50 8,550 8,550 INTRM1 DRILL OTHR T High line power failure; change to cats and warm up for loading to drill ahead. 19:15 00:00 4.75 8,550 8,927 INTRM1 DRILL DDRL P Drill from 8550'to 8927'at 750 GPM with 3320 psi and 120 RPM with 21K torque and 16K WOB with ECD= 11.79 ppg. PU=254K, SO= 143K, Rot= 188K,T off= 19K. ADT=7.11 hours, Bit hours=47.82, Jars=47.82 hours. Losses this tour=0 BBLs SPR @ 8549' MD. 5462'TVD 18:35; 10.5 ppg #1 MP; 20/30 SPM= 180/260 psi #2 MP;20/30 SPM=200/260 psi Crew change. 12/14/2014 Drilling ahead at 750 GPM with 3390 psi, ECD= 11.70 ppg 10.5 ppg mud with an average background gas of 350 units since the top of the HRZ. Drill to 9543', Intermediate TD. During CBU hole packed-off and stalled the rotary. Staged pumps and rotary to work out of the hole. Establish circulation and attempt to return to bottom. Repeated of pack-off and rotary stalls. Work out of the hole 2.5 stands,establish circulation. Page 37 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 8,927 9,304 INTRM1 DRILL DDRL P Drill from 8927'to 9240'with 750 GPM with 3510 psi, ECD= 11.85 ppg with 10.5+ppg mud. Background gas running 300 to 500 units with minimal connection gas above background. Drill with 21K torque and 20K WOB. PU=264K, SO= 149K, Rot= 190K. 06:00 09:15 3.25 9,304 9,543 INTRM1 DRILL DDRL P Drill from 9304'to 9543'at 750 GPM with 3570 psi and 120 RPM with 21K torque and 17K WOB with ECD= 11.75 ppg. PU=264K, S0=140K, Rot= 191K,T off=20K. ADT=5.53 hours, Bit hours=53.35, Jars=53.35 hours. SPR @ 9543'MD. 5989'TVD 09:30; 10.5 ppg #1 MP; 20/30 SPM= 190/250 psi #2 MP; 20/30 SPM=200/250 psi 09:15 11:15 2.00 9,543 9,543 INTRM1 CASING CIRC P Perform SPR's,take delineation surveys and CBU at 750 GPM with 3400 psi, RPM= 120 with 21K torque. Stand one back after each BU Total strokes= 18844. 11:15 12:00 0.75 9,543 9,543 INTRM1 CASING OWFF P Observe well for flow for 30 minutes; Static. Losses this tour= 0 BBL Crew change. 12:00 12:30 0.50 9,543 9,543 INTRM1 CASING RURD P Pull master bushing and install PS-21 slip assembly in rotary table. 12:30 13:00 0.50 9,543 9,492 INTRM1 CASING CIRC P Stage pump to 750 GPM 80 RPM, while pumping and reciprocating the hole packed-off and stalled the rotary. 13:00 14:45 1.75 9,492 9,485 INTRMI CASING CIRC T Work pipe stage pumps and rotary to establish flow with rotary stalls with torque limiter set to 24-25K. 14:45 17:30 2.75 9,485 9,395 INTRM1 CASING CIRC T Vary flow rates and stage to establish flow without rotary. Work string with 40K overpull to progress up the hole while pumping. 17:30 17:45 0.25 9,395 9,485 INTRM1 CASING REAM T Ream down from 9395'to 9485'with 100 RPM and 750 GPM. 17:45 19:15 1.50 9,485 9,395 INTRM1 CASING CIRC T Pump 40 BBL High-vis sweep while rotating and reciprocating from 9485' to 9395'at 750 GPM with 3360 psi, 100 RPM with 21K torque. PU=245K, S0= 140K, Rot= 185K. 19:15 20:30 1.25 9,395 9,530 INTRM1 CASING REAM T REam in the hole with 100 RPM at 550 GPM to 9530' 20:30 22:30 2.00 9,530 9,395 INTRMI CASING CIRC T Attempt to stage pumps with multiple pack-offs. Begin pump staging process again. Pump and pull from 9530'to 9395'working through pack-off by re-establishing flow and working out with 40K overpull. Page 38 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 9,395 9,307 INTRM1 CASING CIRC T Stge pumps without rotary from 0 to 4 BPM (169 GPM)with 440 psi. 12/15/2014 Continue to stage pump rate to recover full flow rate to clean hole after pack-off incidents. CBU 2X with High-vis sweep at 9307'. Pump out to shoe laying in SOLTEX pill. POOH and LD BHA#5. Perform hanger dummy run; Good. Set test plug and RU to test BOPE. 00:00 02:30 2.50 9,211 9,211 INTRM1 CASING CIRC T Stage pumps to establish rate for CBU from 1 to 17 BPM. Stage RPM up to 80 RPM. Strokes for stage up=4600. PU=255K, S0=140K, Rot= 176K. 02:30 05:00 2.50 9,211 9,307 INTRM1 CASING CIRC P CBU at 715 GPM with 3020 psi, RPM=80 with 21K torque. Pump 30 BB: High-vis sweep with—10% increase at the shakers. Total strokes pumped= 12600. 05:00 12:00 7.00 9,307 4,294 INTRM1 CASING TRIP P Pump out of hole spotting 200 BBL SOLTEX pill at 2 BPM with 220 psi while pulling at 15 FPM to 8468'then increased pulling speed to 60 FPM to a depth of 4294'with 120 psi. Crew change. 12:00 13:30 1.50 4,294 3,339 INTRM1 CASING TRIP P Pump out of hole at 2 BPM with 110 psi while pulling at 15 FPM to 8468' then increased pulling speed to 60 FPM to a depth of 4294'with 120 psi. Crew change. 13:30 14:00 0.50 3,339 3,339 INTRM1 CASING OWFF P Rotate and reciprocate pipe while pumping 750 GPM with 2500 psi and 80 RPM with 6K torque. PU= 123K, SO=108K, Rot= 111K. Pumped 5297 strokes. 14:00 14:30 0.50 3,339 3,339 INTRM1 CASING OWFF P Observe well for flow for 30 minutes; Static. 14:30 16:00 1.50 3,339 224 INTRM1 CASING TRIP P POOH on elevators from 3339'to 821'with good hole fill. 16:00 17:15 1.25 821 224 INTRM1 CASING TRIP P POOH from 821'to 224'laying down jars and standing back HWDP. 17:15 20:00 2.75 224 0 INTRM1 CASING PULD P LD BHA#5 per DD and MWD, pull sources and LD same. 20:00 21:00 1.00 0 0 INTRM1 CASING RURD P Clean and clear floor of equipment while flushing stack. 21:00 21:30 0.50 0 0 INTRM1 CASING RURD P Empty stack and PU 5"test joint, remove wear bushing. 21:30 22:30 1.00 0 0 INTRM1 CASING RURD P Remove elevators and PU 7 5/8" joint. PU and MU hanger and perform dummy run; Good. LD same. 22:30 23:00 0.50 0 0 INTRM1 WHDBO RURD P Change out elevators to 5"and PU 5" test joint, set test plug. 23:00 00:00 1.00 0 0 INTRM1 WHDBO RURD P Change out upper rams to 7 5/8" while changing out bales; long and short. 12/16/2014 Test BOPE, RU and run casing per schedule with Volant tool. Run 7 5/8"39#and 29.7#L-80 Hyd 653 to 5208'. Page 39 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 0 0 INTRM1 WHDBO RURD P RU test equipment, MU TIW and Dart valve, pull test plug due to slight suction on the IA when opening. Plug was pulled to verify static and open to atmosphere;static and full. Re-set test plug. Flush lines with H2O. 01:15 07:00 5.75 0 0 INTRM1 WHDBO BOPE P Test BOPE 250/3500 psi 5 minutes each to chart. Test Witness waived by AOGCC Rep. Matthew Herrera. Perform test 250/3500 psi for all components except manual operated and Super choke tested at 250/2000 psi. Performed all tests with 5"test joint;Annular,2 7/8 x 5 1/2"LPR, tested choke valves 1-15,manual and Super choke, choke and HCR, Kill manual. 4"valve on Kill line,4" TIW#1 and#2,4"dart, Upper and Lower IBOP. Perform KOOMEY test; !nit P=3000 psi, Manifold= 1500 psi,After function P= 1800 psi, Recovery for 200 psi= 16 seconds, Recovery to full P=85 seconds, Closing times; Annular=23, UPR= 18, LPR= 16. Blinds= 16, Choke HCR=2 seconds, Kill HCR=2 seconds. BD top drive. 07:00 08:00 1.00 0 0 INTRMI WHDBO RURD P Blow down and RD test equipment, LD test joint and RU caisng equipment, MU Volant tool CRT. Install bales and extensions, Remove Strip-o-matic,verify tally and casing in shed, replace MWD standpipe sensor and housing. 08:00 08:30 0.50 0 0 INTRMI CASING SFTY P Hold PJSM for running csaing with Rig crew, GBR, and Tenaris rep. Discussed safety and running schedule. 08:30 12:00 3.50 0 1,202 INTRM1 CASING PUTB P PU, BakerLok and MU shoe track. Test Floats; Good. PU 7 5/8"39# Hyd 563 L-80 casing and run in the hole; 10 joints with 22,200 torque. Continue with 7 5/8"29.7#Hyd 563 L-80 casing to 1202'with torque= 11,900. Run casing filling on the fly and topping off every 10 joints. PU=64K, SO=74K, Rot=65K. Torque at 10 RPM= 1K. Crew change. 12:00 14:00 2.00 1,202 1,911 INTRM1 CASING PUTB P Run casing per schedule from 1202' to 1911'obtaining rotary parameters every 10 joints at 10 RPM. 14:00 14:15 0.25 1,911 1,911 INTRM1 CASING OTHR P Switch rig power from generators to High line power. Page 40 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 18:00 3.75 1,911 3,217 INTRM1 CASING PUTB P Run casing per schedule from 1911' to 3217'obtaining rotary parameters every 10 joints at 10 RPM. 18:00 19:00 1.00 3,217 3,217 INTRM1 CASING CIRC P Circulate BU staging pumps for parameters; 2 BPM 120 psi 3 BPM 150 psi 4 BPm 180 psi 5 BPM 215 psi 6 BPM 255 psi 7 BPM 310 psi PU= 115K, SO= 110K, Rot= 113K. 10 RPM with 5.5K torque,20 RPm 6K torque, 30 RPM 6.5K torque. 19:00 00:00 5.00 3,217 5,208 INTRM1 CASING PUTB P Run casing per schedule from 3217' to 5208'obtaining rotary parameters every 10 joints at 10 RPM. 12/17/2014 Running casing from 5208'to 8596'. Circulate at 2000' intervals and collect rotary torques every 5 joint after the top of the HRZ. Run casing per running schedule and trip surge schedule based on an 11.9 ppg. Continue to work pipe through pack-off by staging pumps to 4 BPM. 00:00 00:15 0.25 5,208 5,292 INTRM1 CASING PUTB P Run casing per schedule from 5208' to 6812'at 33 FPM,filling on the fly and topping off every 10 joints. Displacement good while running. 00:15 01:30 1.25 5,295 5,335 INTRM1 CASING CIRC P Circulate BU while reciprocating pipe, staging to 7 BPM with 415 psi. Treat mud as returns came back 10.7 ppg,treat to 10.5 ppg in and out. 2BPM300psi/8% 3 BPM 330 psi/16% 4BPm365psi/21% 5 BPM 390 psi/27% 6 BPM 405 psi/32% 7 BPM 415 psi/33% PU= 156K, SO= 125K. 01:30 06:30 5.00 5,335 7,241 INTRM1 CASING PUTB P Run casing per schedule from 5335' to 7241'at 25 FPM,filling on the fly and topping off every 10 joints. Displacement good while running. 06:30 08:00 1.50 7,241 7,241 INTRM1 CASING CIRC P Circulate BU while reciprocating pipe,staging pumps; mud in and out 10.5+ppg 2 BPM 360 psi/7% 3 BPM 415 psi/17% 4 BPm 455 psi/20% 5 BPM 505 psi/26% 6 BPM 545 psi/31% 7 BPM 565 psi/34% PU=203K, S0= 120K. Page 41 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 7,241 8,596 INTRM1 CASING PUTB P Run casing per schedule from 7214' to 8596'at 16.6 FPM, filling on the fly and topping off every 10 joints. Displacement good while running. Obtain torque and drag data every 10 joints; PU=230K, SO= 135K, Rot= 179K with 19K torque at 10 RPM, taking 20K to break and rotate free per Tenaris rep. Crew change. 12:00 12:15 0.25 8,596 8,634 INTRM1 CASING PUTB P Run casing per schedule from 8596' to 8634'at 16.6 FPM, filling on the fly and topping off every 10 joints. Displacement good while running. PU=253K, S0= 130K. 12:15 16:30 4.25 8,634 8,681 INTRM1 CASING CIRC P Circulate while reciprocating pipe, staging pumps; 1 BPM 290 psi/1% FO(Flow out) 1.5 BPM 300 psi/6% 2 BPM 280psi/9% 3 BPM 350 psi/17% 4 BPM 400 psi/23% 4.5 BPM 337 psi/27% 16:30 16:45 0.25 8,681 8,681 INTRM1 CASING CIRC P Obtain T&D parameters;4 BPM with 330 psi,22%FO. Rotate 10 RPM with 25K torque. 16:45 22:30 5.75 8,681 9,136 INTRM1 CASING PUTB P Run casing per schedule from 8681.0' to 9136'at 16.6 FPM,filling on the fly and topping off every 10 joints. Displacement good while running. Obtain torque and drag data every 10 joints; PU=230K, SO= 135K, Rot= 179K with 19K torque at 10 RPM,taking 20K to break and rotate free per Tanaris rep. Crew change. 22:30 00:00 1.50 9,136 9,432 INTRM1 CASING PUTB P Continue to RIH with casing, hit obstruction. Circulate while working through obstruction at 9423', pack-off and work staging pumps and initiate rotation to progress down. 2 BPM 360 psi/8% 3 BPM 415 psi/17% 4 BPm 455 psi/20% 5 BPM 505 psi/26% 6 BPM 545 psi/31% 7 BPM 565 psi/34% PU=203K, SO= 120K. 12/18/2014 Continue to run casing to 8596'Wash from 8825'to 9423'where hit obstruction and packed-off. Circulate with no rotate to work casing to 9440'. 00:00 01:00 1.00 9,432 9,432 INTRM1 CASING CIRC T Continue to run casing to 9423'hit obstruction causing pack-off and 10K down weight. Stage pumps to 4 BPM with 390 psi and work pipe with and without rotary of 10 RPM. Page 42 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 06:00 5.00 9,432 9,440 INTRM1 CASING WASH T Multiple attempts to wash and ream past 9436'varying flow and staging pumps. Use rotary to assist in gaining flow as needed. Wash to 9440'. 06:00 10:00 4.00 9,440 9,490 INTRM1 CASING WASH T Continue to wash from 9440'to 9490' with 1 -2 BPM with 200 to 300 psi, moving and using differential pressure to attain best string speed. Using rotation to regain circulation as needed. 10:00 12:00 2.00 9,490 9,501 INTRM1 CASING PULD P PU and MU hanger and landing joint to wash from 9490'to 9501'. 12:00 18:00 6.00 9,501 9,521 INTRM1 CASING WASH T Continue to wash casing down from 9501'to 9521'with 1.5 BPM with 300-400 psi. Pack-offs; 9503',9508', 9513' 18:00 00:00 6.00 9,521 9,532 INTRM1 CASING WASH T Continue to wash casing down from 9521'to 9532'with 1.5 BPM with 300-350 psi. Pakc-offs; 9524', 9530'. PU=290K, SO= 130K. Crew change. 12/19/2014 Wash casing to bottom and land hanger at 01:20. Work pipe to establish circulate. Establish circulate, stage pumps to 5 BPM with 440 psi and circulate 2X BU. Pump cement 127 BBLs as per program. Hole packed off with—10 BBLs out of the shoe,casing stuck off bottom. Pumped to plug bump. Set casing on E-Slips, cut casing. 00:00 01:30 1.50 9,532 9,534 INTRM1 CASING WASH T Wash down to seat the casing hanger and land casing at 9534'with 1.5 BPM at 350 psi, 7% FO 01:30 03:30 2.00 9,534 9,534 INTRM1 CEMEN-CIRCT Attempt to establish circulation by staging pumps and working pipe to mitigate pack-offs without success. 03:30 07:15 3.75 9,534 9,534 INTRM1 CEMEN'CIRC P Reciprocate pipe to establish circulation, overpull to break at 310K indicated. Stage pumps and establish pumping rates while on hanger. 1 BPM 400 psi/2% 2 BPM 470 psi/11% 3 BPm 465 psi/17% 4BPM535psi/22% 5 BPM 560 psi/27% PU=290K, SO= 130K 07:15 07:45 0.50 9,534 9,534 INTRM1 CEMEN-RURD P Disengage Volant CRT and BD topdrive, RU cement hose. 618 bbls circulated while landed on hanger. Final pressure of 425 psi, pumping 5 bpm. 07:45 08:00 0.25 9,534 9,534 INTRM1 CEMEN SFTY P PJSM with rig team and cementers. Page 43 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:15 1.25 9,534 9,534 INTRM1 CEMEN"CIRC P Establish pump rates with cement hose and obtain parameters. Total of 400 bbls pumped through cement hose,final circ pressure of 510 psi @ 5bpm. 1 BPM 210 psi/2% 2 BPM 260 psi/9% 3 BPm 330 psi/16% 4 BPM 405 psi/23% 5 BPM 505 psi/26% 09:15 09:30 0.25 9,534 9,534 INTRM1 CEMEN-RURD P With SLB pumping, pump 5 BBL CW100 to fill lines and pressure test lines 250/4000 psi; Good. 09:30 10:45 1.25 9,534 9,534 INTRM1 CEMEN-CMNT P With SLB pumping, pump an additional 35 BBL CW100 at 2.9 BPM 490 psi,26%FO. Pump 40 BBLs 12.5 ppg MPII at 4 BPM 480 psi,26% FO. Drop bottom plug at 10:04. Pump 127 BBLs of 15.8 ppg cement at 5 BPM; ICP=490 psi 26% FO. 10:45 12:00 1.25 9,534 9,534 INTRM1 CEMEN-CMNT P Begin working pipe, Break-over 370K PU=280K, SO= 130K Dowell kick out top plug at 11:05 with H2O and switch to rig to displace with 10.5 ppg mud. Pump at 5 BPM 160 psi, 26%FO. At 11:10,43 strokes the rig started displacement at 2 BPM partial returns. 12:00 15:45 3.75 9,527 9,527 INTRM1 CEMEN-CMNT P While attempting to work pipe during cementing with 20K overpull,set down 40K and pipe failed to move. Continued pumping to chase plug at 2 BPM with 10.5 ppg with 650 psi no returns. Obtain circulation at 750 strokes with 3-8%FO 730 psi. Observe psi increase and lose returns at 3070 strokes. Reduced rate to 1 BPM 1400 psi, No returns. stage up pumps to 1.5 BPM 1500 psi, No returns,then stage to 2 BPM 1600 psi with no returns at 3575 strokes. Bump plug at 4203 strokes. Cement in place at 15:30 with FCP= 1800 psi. Increase to 2300 psi and hold for 5 minutes; Good. Bleed off pressure to check floats; Good. PU to 280K. total losses during cementing= 136 BBLs,22 bbl lost prior to cement being at the shoe. 15:45 16:15 0.50 9,527 9,527 INTRM1 CEMEN'RURD P RD cement lines and equipment. Clean cement lines and empty stack of fluids. 16:15 17:45 1.50 9,527 9,527 INTRM1 WHDBOOTHR P Remove nuts from spool, remove air boots from riser and remove PS-21 Page 44 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 18:30 0.75 9,527 9,527 INTRM1 WHDBO WWSP T Install Emergency slips (CPAI MM# 10935403)per FMC rep. 18:30 19:30 1.00 9,527 9,527 INTRM1 WHDBO WWSP T With 280k on the weight indicator, set all weight on the FMC casing slips(240k set on slips)(Blocks 40k), 19:30 22:15 2.75 9,527 0 INTRMI WHDBO CUTP T Cut casing per FMC rep. PU cut joint and hanger. LD same. Lower BOP stack onto casing spool, Cut joint length= 16.95'. 22:15 23:00 0.75 0 0 INTRM1 WHDBO OTHR P LD 7 5/8"Elevators and 4'bale extensions. RD Volant CRT. 23:00 00:00 1.00 0 0 INTRM1 WHDBO WWSP P Install 5"elevators and PU 5"test joint and install FMC 7 5/8"x 10 3/4" packoff(CPAI MM# 11058463) 12/20/2014 Continue to perform wellhead work,assemble stack on well and test packoff; Good. Assembly stack and riser. LD 5"drill pipe. PU 4"DP and stand in derrick. 00:00 02:30 2.50 0 0 INTRM1 WHDBO WWSP P Install packoff and RILDS. LD 5"test joint. Lower and assembly stack, torque all bolts on spool to spec. 02:30 03:30 1.00 0 0 INTRM1 WHDBO PRTS P Fill and test pack-off 250/3800 for 10 minutes each; Good. 03:30 04:00 0.50 0 0 INTRM1 CEMEN-RURD P Change out PS-21 slips for 4". Stage DP thread protectors to the rig floor. 04:00 04:15 0.25 0 0 INTRM1 CEMEN-SFTY P PJSM for laying down 5"DP. 04:15 05:00 0.75 0 0 INTRM1 CEMEN-PULD P LD 5"DP from derrick 1x1 via mouse _hole. 05:00 08:30 3.50 0 0 INTRM1 CEMEN-PULD P LD 5"DP from derrick in singles and doubles staging 36 doubles in the pipe shed. 08:30 12:00 3.50 0 0 INTRM1 CEMEN-PULD P LD 5"DP from derrick 1x1 _Crew change. 12:00 17:15 5.25 0 0 INTRM1 CEMEN-PULD P LD 5"DP from derrick 1x1 via mouse hole. 17:15 17:30 0.25 0 0 INTRMI CEMEN-SFTY P PJSM for changing out saver sub and _top drive PM and service. 17:30 19:00 1.50 0 0 INTRMI CEMEN-RURD P Change out saver sub on top drive while performing top drive PM. 19:00 19:30 0.50 0 0 INTRM1 CEMEN-SVRG P Service rig; grease top drive and blocks. 19:30 00:00 4.50 0 0 INTRM1 CEMEN-PULD P PU 4"DP singles and stand back in derrick. 12/21/2014 Continue to PU 4"DP and stand back. Change upper and lower rams. Test BOPE. PU Clean out BHA, RIH and drill cement. Tag TOC at 9412', drill float collar at 9428'. Shoe depth estimated at 9518'MD. 00:00 02:30 2.50 0 0 INTRMI CEMEN-PULD P PU 4"DP and stand back in the derrick. 02:30 02:45 0.25 0 INTRMI CEMEN-PULD P PU test joint and install test plug, 02:45 04:15 1.50 0 0 INTRM1 CEMEN'RURD P Change rams upper and lower to 2 7/8 x 5 1/2"VBR's. 04:15 05:00 0.75 0 0 INTRM1 CEMEN-BOPE P Perform body test; Good. Test BOPE Page 45 of 64 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05:00 09:30 4.50 0 0 INTRM1 WHDBO BOPE P Test BOPE,witness waived by AOGCC rep Matt Herrera. Perform test 250/3500 psi for all components except manual operated and Super choke tested at 250/2000 psi. Performed all tests with 4"test joint;Annular,2 7/8 x 5 1/2"LPR, tested choke valves 1-15, manual and Super choke, choke and HCR, Kill manual. 4"valve on Kill line,4" TIW#1 and#2,4"dart, Upper and Lower IBOP. Perform KOOMEY test; !nit P=3000 psi, Manifold= 1450 psi,After function P= 1600 psi, Recovery for 200 psi=23 seconds, Recovery to full P=85 seconds, Closing times; Annular=23, UPR= 18, LPR= 17. Blinds= 18, Choke HCR=2 seconds, Kill HCR=2 seconds. Perform CPAI pump performance test;electic pumps 58 seconds, air pumps 141 seconds recovery. 09:30 09:45 0.25 0 0 INTRM1 WHDBO RURD P Blow down top drive, pull test plug, Change out PS-21 slip inserts. 09:45 10:00 0.25 0 0 INTRM1 CEMEN'RURD P RU for 7 5/8"casing test. 10:00 10:45 0.75 0 0 INTRM1 CEMEN-PRTS P Pressure test casing to 3500 psi for 30 minutes to chart. 56 strokes to pressure with 5.6 BBLs bled for returns. 10:45 11:30 0.75 0 0 PROD1 CEMEN"RURD P RD for testing casing and BOPE, blow down choke and kill lines,set wear ring; ID=9 1/16", OD= 10 13/16", L= 1.0'. Install strip-o-matic. 11:30 12:00 0.50 0 41 PROD1 CEMEN"PULD P MU Clean Out BHA#6, 1 collar, stab, bit sub and bit as per SLB DD. 12:00 13:00 1.00 41 291 PROD1 CEMEN-PULD P PU BHA#6 and RIH. Monitor displacement with TT; Good. 13:00 13:15 0.25 291 291 PROD1 CEMEN RURD P Change out inserts fo rhand slips inserts;4". 13:15 20:00 6.75 291 7,692 PROD1 CEMEN-TRIP P Trip in the hole with doubles from 291'to 7692'with good displacement. Fill every 20 and blow down top drive. 20:00 21:00 1.00 7,692 9,021 PROD1 CEMEN TRIP P Continue to trip in the hole from the derrick from 7692'to 9021'with good displacement. Fill every 20 stands. 21:00 22:15 1.25 9,021 9,021 PROD1 CEMEN SLPC P Slip and cut drill line; 104 feet. Calibrate Amphion system, TOTCO and SLB systems. 22:15 22:30 0.25 9,021 9,306 PROD1 CEMEN TRIP P Trip in the hole from 9021'to 9306' with good displacement. 22:30 23:00 0.50 9,306 9,412 PROD1 CEMEN-COCF P Wash in the hole from 9306'to 9412" TOC. Tag up with 3K down weight. Page 46 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 9,412 9,428 PROD1 CEMEN'COCF P Drill cement from 9412 to 9428'at 250 GPM with 1208 psi, 25% FO, 80 RPM with 11K torque, 2K WOB. Tag float collar at 9428'. PU= 165K, SO= 101K, Rot= 117K. Crew change. 12/22/2014 Drill cement to 9493'and CBU. POOH with BHA#6. RU E-Line with WelITec tractor and RIH. Log cement and log TOC at 9275'. Cement approved by AOGCC to drill ahead. PU BHA#7 for drilling and RIH. 00:00 03:06 3.10 9,428 9,493 INTRM1 CEMEN-DRLG P Drill float collar from 9428'to 9430', drill cement from 9430 to 9493'at 250 GPM with 1100 psi,24%FO. Confirm float collar depth with torque and black rubber at the shakers at BU from 9428'. 03:06 04:30 1.40 9,493 9,493 INTRM1 CEMEN-CIRC P CBU at 280 GPM with 1360 psi, 22% FO. Rot and Recip. Total strokes pumped=5785. PU= 178K, SO=96K 04:30 04:45 0.25 9,493 9,493 INTRM1 CEMEN OWFF P Monitor well for 15 minutes: Static. Blow down top drive. 04:45 09:00 4.25 9,493 291 INTRM1 CEMEN-TRIP P Trip out from 9493'to 291'with good displacement. 09:00 10:00 1.00 291 0 INTRM1 CEMEN-PULD P Rack back HW and DC and LD BHA ----INTRM1 #6 per SLB DD and MWD. 10:00 10:15 0.25 0 0 INTRM1 CEMEN-RURD P Clean and clear floor. 10:15 10:30 0.25 0 0 INTRM1 CEMEN'SFTY T PJSM with Halliburton and WeIITec for RU and logging run. 10:30 12:00 1.50 0 0 INTRMI CEMEN-QEVL T Stage tools to the floor and RU wirline equipment. per DDI procedure. Crew change 12:00 13:15 1.25 0 0 INTRM1 CEMEN'QEVL T PU and MU Bond log tools wit tractor per HAL and WellTec reps. 13:15 15:30 2.25 0 9,490 INTRM1 CEMEN QEVL T RIH with VDL to 9490', running from 9372'with tractor to 9490'. 15:30 17:30 2.00 9,490 0 INTRM1 CEMEN-QEVL T Perform logging run from 9490'to 8775'. POOH with VDL and tools. 17:30 18:00 0.50 0 0 INTRM1 CEMEN-QEVLT LD logging tools and leave rigged up for cement evaluation. 18:00 19:00 1.00 0 0 INTRM1 CEMEN"QEVL T Clean and clear rig. Wait on cement evaluation. 19:00 20:00 1.00 0 0 INTRM1 CEMEN-QEVL T With approval from state AOGCC cement job suitable. RD wireline. 20:00 20:30 0.50 0 0 INTRM1 CEMEN-PULD P PU and MU BHA#7 per SLB DD and MWD. 20:30 21:00 0.50 0 0 INTRM1 CEMEN-PULD T LD power drive and replace. 21:00 23:30 2.50 0 396 INTRM1 CEMEN-PULD P PU and MU BHA and RIH with HW and DCs. 23:30 23:45 0.25 396 396 INTRMI CEMEN RURD P Change out slips on the PS-21 to 4". 23:45 00:00 0.25 396 871 INTRM1 CEMEN-TRIP P RIH with BHA#7 from 396'to 871' with good displacement. 12/23/2014 RIH with BHA#7. RU, perform injectivity test and freeze protect with IsoTherm while RIH. Displace to 12.3 ppg mud, drill out 7-5/8"casing.Work thru packoff,jar free. Drill to 9564'MD, C&C for FIT. Page 47 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 871 1,815 INTRM1 CEMEN-TRIP P Trip in hole from 871'MD to 1815' MD, monitor displacement via pit#2. 00:30 01:00 0.50 1,815 1,815 INTRM1 CEMEN-DHEQ P Shallow hole test @ 1815'MD @ 249 gpm, 1190-psi,22%flow out. Good test. Blow down top drive, 01:00 02:00 1.00 1,815 4,192 INTRM1 CEMEN'TRIP P Continue TIH from 1815'MD to 4192' MD monitor displacement via pit#2, fill pipe every 20 stds and blow down top drive. 02:00 05:00 3.00 4,192 8,177 INTRM1 CEMEN'TRIP P Continue TIH from 4192'MD to 8177' MD monitor displacement via pit#2, fill pipe every 20 stands and blow down. SIMOPS-Perform annular flush and freeze protect outer annulus. Flood lines and PT to 3000 psi, perform injectivity test @.7 bpm, observe leak off @ 507 psi. Shut in and monitor 10 min. Flush annulus with 140 bbl rig water, ICP=700 psi 3 bpm, FCP=835 psi 3 bpm. Shut down,swap to LRS to pump 75 bbl ISOTHERM @ 2 bpm ICP=1000 psi, FCP=1200 psi. Shut in with 800 psi on OA Rig down and blow down lines. 05:00 05:45 0.75 8,177 9,411 INTRM1 CEMEN'TRIP P Continue TIH from 8177' MD to 9411' MD, monitor displacement via pit#2. P/U=194k, 5/0=90k. 05:45 06:00 0.25 9,411 9,496 INTRM1 CEMEN-COCF P Wash down from 9411'MD to 9496' MD @ 2 bpm,410 psi, 11%flow out. Tag bottom @ 9496' MD W/O ROT. 06:00 07:30 1.50 9,496 9,496 INTRM1 CEMEN'DISP P Displace well to 12.3 ppg Klashield while rotate and reciprocating from 9493'MD to 9412'MD. Pumped 28 bbl HiVis sweep, chase with 12.3 ppg @ 275 gpm, ICP=2530 psi, FCP=2400 psi,22%flow out, 15 rpm, 7k Tq, P/U=150k, 5/0=104k Total strokes pumped 4908. MW in=12.3 ppg, MW out= 12.1 ppg. 07:30 09:30 2.00 9,496 9,496 INTRM1 CEMEN COND T HiVis sweep returned, shut down pumping due to contaminated mud in mud pump suction lines and cuttings tank disharge lines. Klashield and LSND mixed in cuttings tanks and plugged off line to offload. Clear all surface lines with air,fresh water then mud. 09:30 10:00 0.50 9,496 9,496 INTRM1 CEMEN'COND T Clean under shakers, mud trough and pit surface equipment. Page 48 of 64 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 9,496 9,496 INTRMI CEMEN-CIRC T Circulate while rotate and reciprocate from 9493'MD to 9412'MD while weighting up to 12.3 ppg out @ 215 gpm, 1780 psi,24%flow,20 rpm, 8k TQ, Obtain SPR's. SPR's @ 9489'MD, 5972'TVD, 12.3 ppg, 11:00 hrs #1-20 spm=400 psi, 30 spm=620 psi #2-20 spm=400 psi, 30 spm=620 psi 11:00 12:00 1.00 9,496 9,519 INTRM1 CEMEN-DRLG P Drill out cement from 9493'MD to 9519'MD @ 275 gpm, 26%flow out, 6k WOB, 75 rpm, 9.5k Tq, 2480 psi off bottom. Tag top of shoe at 9519' MD 12:00 12:45 0.75 9,519 9,522 INTRM1 CEMEN DRLG P Continue drilling cement from 9519' MD to just out shoe @ 9522' MD 275 gpm, 26%flow out, 13k WOB, 9.5k Tq.Temporarily detained at 9522' MD, experience packoff with 0%flow out, P/U=150k, S/0=105k, ROT=122k. 12:45 14:45 2.00 9,522 9,522 INTRM1 CEMEN-JAR T Attempt to work free jarring up with 50-75k overpull(failed). Successfully jar free with 100k overpull. 14:45 22:00 7.25 9,522 9,544 INTRM1 CEMEN DRLG P Continue to drill out shoe and rathole from 9522'MD to 9544'MD @ 275 gpm,2483 psi,24%flow out, 0-2k WOB, 150 rpm, 9k TQ, P/U=150k, S/0=105k, ROT=118k. Slowly drill in hole @ 15 fph, minor packoffs occurred @ 9518' MD. Ream through section untill clean no packoffs. 22:00 22:30 0.50 9,544 9,564 INTRM1 CEMEN'DDRL P Drill 6'%2'production hole from 9544' MD to 9564' MD/5988'TVD.275 gpm, 2458 psi,24%flow out, 150 rpm, 9k Tq, 8k WOB, P/U=150k, 5/0=105k, ROT=118k. 22:30 23:15 0.75 9,564 9,564 INTRM1 CEMEN-CIRCP Circulate bottoms up,till 12.3 ppg in/out condition for FIT.2785 gpm, 2460 psi, 24%flow out, 150 rpm, 9k Tq, P/U=150k, S/0=105k, ROT=118k, 23:15 00:00 0.75 9,564 9,503 INTRM1 CEMEN-TRIP P POOH to 9503' MD, blow down and rig up for FIT. Monitor well 10 minutes static. 12/24/2014 Perform FIT to 14.1 ppg, commence drilling 6%2'section to 9655'MD troubleshoot MWD/Periscope issues. POOH for MWD/Periscope. L/D and P/U BHA, RIH to 9505'. 00:00 00:30 0.50 9,503 9,503 INTRMI CEMEN-RURD P Rig up for FIT. Flood lines and close upper pipe rams. 00:30 01:00 0.50 9,503 9,503 INTRM1 CEMEN FIT P Perform FIT @ 9503'MD to 14.1 ppg, pressure up to 575 psi, 12.3 ppg mud, 1.1 bbl pumped, 1.1 bbl bled back. Page 49 of 641 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 03:45 2.75 9,503 9,656 PROD1 DRILL DDRL P Directional drill 6'/2'production hole from 9564'-9656'MD,6005'TVD. 275 gpm, 2550 psi, 25%flow out, 120 rpm, 10k/9k on/off Tq, 11 k WOB, P/U=157k, S/0=99k, ROT=117k, ADT/ART=1.75,Total jar hrs=1.75, Periscope failure @ 9563'MD. Troubleshoot to 9656'and decide to pull for LWD. SPR's @ 9656'MD,6006'TVD, 12.3 ppg,04:25 hrs #1-20 spm=520 psi, 30 spm=740 psi #2-20 spm=520 psi, 30 spm=740 psi 03:45 05:15 1.50 9,656 9,500 PROD1 DRILL REAM T BROOH while logging from 9656'to 9500'to assist troubleshooting LWD. POOH @ 200 fph,275 gpm 2570 psi,25%flow out, 120 rpm, 10k Tq, 05:15 06:00 0.75 9,500 9,500 PROD1 DRILL CIRC T Circulate while R&R to troubleshoot MWD©9500' MD. 275 gpm,2570 psi,25%flow 75 rpm @ 9k Tq. 06:00 06:30 0.50 9,500 9,500 PROD1 DRILL OWFF T Monitor well 30 minutes static. Blow down top drive. 06:30 07:45 1.25 9,500 8,266 PROD1 DRILL TRIP T TOOH on elevators form 9500'-8266' MD, good pipe displacement. 07:45 08:15 0.50 8,266 8,266 PROD1 DRILL CIRC T Kelly up and pump 23 bbl dry job 13.3 ppg. Blow down top drive. 08:15 11:45 3.50 8,266 396 PROD1 DRILL TRIP T Continue POOH to 396'MD BHA. Good displacement via TT. 11:45 12:00 0.25 396 396 PROD1 DRILL RURD T Change out PS-21 inserts to#3 hand slips for handling BHA. 12:00 14:30 2.50 396 0 PROD1 DRILL PULD T L/D BHA#7 per DD/MWD from 396' MD. Monitor well via trip tank. 14:30 15:00 0.50 0 0 PROD1 DRILL RURD T Clean and clear rig floor. 15:00 16:45 1.75 0 396 PROD1 DRILL PULD T P/U BHA#8 per DD/MWD to 396' MD. 16:45 17:00 0.25 396 396 PROD1 DRILL RURD T Change out PS-21 slip inserts to 4". 17:00 17:45 0.75 396 681 PROD1 DRILL PULD T P/U extra 4" DP singles from 396'to 681'. 17:45 23:30 5.75 681 9,410 PROD1 DRILL TRIP T RIH from derrick from 681'to 9410' MD filling pipe every 20 stands. P/U=155k, S/0=94k. Shallow test at 1990'MD, 250 gpm, 1370 psi, 26a% Flow out.-Good. 23:30 00:00 0.50 9,410 9,505 PROD1 DRILL REAM T Stage up pumps and wash down from 9410'MD to 9505'MD.275 gpm-2660 psi, 26%flow out,60 rpm. 12/25/2014 Wash and ream to TD 9656'. Resume drilling 6%"production section @—150 fph, maintain ECD>13.8 ppg EMW,geosteer to 10736'MD,6071'TVD. 00:00 00:45 0.75 9,505 9,515 PROD1 DRILL REAM T Ream down from 9505'MD to 9515' MD @ 275 gpm,2460 psi,26%flow out,60 rpm, 9k Tq. OA pressure @ 00:15 700 psi Page 50 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 01:30 0.75 9,515 9,501 PROD1 DRILL EQRP T Rack back stand @ 9501'MD, blow down top drive,troubleshoot MWD sensor on standpipe due weak signal.Thought to be frozen,found fitting and port not frozen. Change out fitting and replace sensor. SIMOPS-Service blocks and topdrive. 01:30 02:30 1.00 9,501 9,501 PROD1 DRILL CIRC T Stage pumps up in 50 gpm increments and cycle pumps following SLB anti-jamming procedure for Impulse tool. Successfully clear the tool,signal returned. 02:30 04:30 2.00 9,501 9,656 PROD1 DRILL REAM T Ream down from 9501'MD to 9656' MD @ 273 gpm, 2515 psi,27%flow out, 120 rpm,9k Tq, 150 fph. Obtain SPR's. SPR's @ 9630'MD, 6000'TVD. MW=12.3 ppg, 04:23 hrs #1-20 spm=580 psi,30 spm=780 psi #2-20 spm=540 psi,30 spm=780 psi 04:30 12:00 7.50 9,656 9,977 PROD1 DRILL DDRL P Directional drill 6%"section from 9656'MD to 9977' MD,6054'TVD @ 275 gpm, 2560 psi,26%flow, 150 rpm, 11 k/8k on/off Tq, 3-5k WOB, P/U=154k, S/0=104k, ROT=129k, ART/ADT=8.44 hrs,Total jars Hrs= 10.19, ECD=13.6 ppg EMW. OA pressure @ 11:30 760 psi. 12:00 14:15 2.25 9,977 10,167 PROD1 DRILL DDRL P Directional drill from 9977'MD to 10167'MD, 6070'TVD. 274 gpm, 2580 psi,26%flow, 150 rpm, 11 k/8k on/off Tq,4k WOB, P/U=152k, S/0=108k, ROT=125k. SPR's @ 9973'MD,6054'TVD, 12.3 ppg, 12:09 hrs #1-20 spm=480 psi, 30 spm=720 psi #2-20 spm=480 psi, 30 spm=720 psi 14:15 15:30 1.25 10,167 10,167 PROD1 DRILL CIRC P Encounter high(2700)gas units while drilling. R&R per co rep to reduce drilled gas to 300 units. Circulate at 275 gpm, 2550 psi,26% flow, 80 rpm, 8k Tq. 15:30 17:30 2.00 10,167 10,357 PROD1 DRILL DDRL P Directional drill from 10167' MD to 10357'MD,6072'TVD.274 gpm, 2603 psi, 26%flow, 150 rpm, 10k/9k on/off Tq, 9k WOB, P/U=154k, S/0=106k, ROT=128k. 17:30 18:45 1.25 10,357 10,357 PROD1 DRILL CIRC P Encounter high(1400)gas units while drilling. R&R(double backream)per co rep to reduce drilled gas to 275 units. Circulate at 275 gpm, 2660 psi, 27%flow, 80 rpm, 9k Tq. Page 51 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 20:30 1.75 10,357 10,546 PROD1 DRILL DDRL P Directional drill from 10357'MD to 10546' MD, 6070'TVD. 275 gpm, 2690 psi,26%flow, 150 rpm, 11 k/9k on/off Tq, 9k WOB, P/U=155k, S/0=106k, ROT=125k. 20:30 21:45 1.25 10,546 10,546 PROD1 DRILL CIRC P Encounter high(1500)gas units while drilling. R&R(triple backream) per co rep to reduce drilled gas to 430 units. Circulate at 275 gpm, 2660 psi, 27%flow,80 rpm, 9k Tq. SPR's @ 10545'MD,6068'TVD, 12.3 ppg, 21:40 hrs #1-20 spm=510 psi, 30 spm=780 psi #2-20 spm=500 psi,30 spm=780 psi 21:45 00:00 2.25 10,546 10,736 PROD1 DRILL DDRL P Directional drill from 10546'MD to 10736' MD, 6071'TVD.ADT=5.99, Total bit hrs=14.43,Total jar hrs=14.43. 273 gpm, 2673 psi,26% flow, 150 rpm, 11 k/9k on/off Tq, 5k WOB, P/U=158k, 5/0=104k, ROT=127k. 12/26/2014 Continue drilling 6%"production section @—150 fph, maintain ECD>13.8 ppg EMW,geosteer to 11968'MD, 6068'TVD. 00:00 06:00 6.00 10,736 11,260 PROD1 DRILL DDRL P Directional Drill 6'/z'from 10,736'MD to11260' MD,6061'TVD. ECD=13.86 ppg,ADT=3.15, P/U=156k, S/0=102k, ROT=120k, 150 rpm, 274 gpm @ 2770 psi on,2740 psi off,Tq on/off=11-12k/9k,WOB=9k SPR's @ 10926'MD, 6071'TVD, 12.3 ppg, 02:25 hrs #1-20 spm=640 psi,30 spm=820 psi #2-20 spm=600 psi, 30 spm=820 psi OA pressure @ 02:30=740 psi 06:00 12:00 6.00 11,260 11,494 PROD1 DRILL DDRL P Directional Drill 6'/2"from 11260' MD to11494'MD,6038'TVD. ECD=13.85 ppg,ADT=2.78, P/U=151k, S/0=103k, ROT=123k, 150 rpm,276 gpm @ 2795 psi on, 2770 psi off, Tq on/off=12k/9k,WOB=8k Total bit hrs=20.36,Total Jar Hrs=22.11. Max gas observed 1900 units. SPR's @ 11406'MD, 6060'TVD, 12.3 ppg, 10:20 hrs • #1-20 spm=560 psi, 30 spm=820 psi #2-20 spm=540 psi, 30 spm=810 psi Page 52 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 11,494 11,638 PROD1 DRILL DDRL P Directional Drill 6'/2'from 11494 MD to11638'MD, 60569'TVD. ECD=13.68 ppg, P/U=152k, S/O=97k, ROT=122k, 150 rpm,276 gpm @ 2760 psi on,2740 psi off,Tq on/off=12k/9k,WOB=Bk Flow out 23%. SPR's @ 11684'MD,6052'TVD, 12.3 ppg, 19:15 hrs #1-20 spm=540 psi,30 spm=760 psi #2-20 spm=520 psi,30 spm=740 psi 18:00 00:00 6.00 11,638 11,968 PROD1 DRILL DDRL P Directional Drill 6'/z"from 11638' MD to11968' MD,6068'TVD. ECD=13.83 ppg,ADT=8.05 since 12:00, P/U=161k, S/O=93k, ROT=124k, 150 rpm, 276 gpm @ 2787 psi on, 2735 psi off,Tq on/off=12k/10k, WOB=13k Flow out 23%. Total Bit Hrs=28.41,Total Jar Hrs=30.06 SPR's @ 11871'MD,6068'TVD, 12.3 ppg, 22:20 hrs #1-20 spm=530 psi, 30 spm=760 psi #2-20 spm=520 psi, 30 spm=750 psi 12/27/2014 Continue drilling 6'/2'production section from 11968'MD to TD 13013'MD, 6024'TVD. 00:00 04:00 4.00 11,968 12,254 PROD1 DRILL DDRL P Directional Drill 6'/2'from 11968' MD to12254'MD, 6071'TVD. ECD=13.72 ppg,ADT=3.49, P/U=159k, S/O=96k, ROT=123k, 150 rpm, 279 gpm @ 3000 psi on,2990 psi off,Tq on/off=12k/10k,WOB=9k Flow out 24%. SPR's @ 12158'MD, 6076'TVD, 12.3 ppg, 02:50 hrs #1-20 spm=560 psi, 30 spm=820 psi #2-20 spm=560 psi, 30 spm=820 psi 04:00 05:15 1.25 12,254 12,254 PROD1 DRILL CIRC P CBU while R&R to reduce ECD and drilled gas 12254'to 12161'MD @ 280 gpm, 3010 psi,23%flow out, 13.72 ppg ECD,80 rpm, 10k Tq. S/D and monitor well 10 minutes,static, slight trickle. Possibly breathing slightly, no gas on following bottoms up. 05:15 12:00 6.75 12 254 12 539 PROD1 DRILL DDRL P61/2" Directional Drill from 12254'MD to12539' 6060'TVD. ECD=13.72 MD, ppg,ADT=4.23, P/U=164k, S/O=97k, ROT=123k, 150 rpm, 275 gpm @ 3025 psi on, 3015 psi off,Tq on/off=12k/10k,WOB=15k Flow out 24%. Total Bit Hrs=37.88,Total Jar Hrs=37.88 Page 53 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 12,539 12,630 PROD1 DRILL DDRL P Directional Drill 6'/2"from 12539'MD to12630'MD,6060'TVD. ECD=13.56 ppg, P/U=164k, 5/0=97k, ROT=123k, 150 rpm,275 gpm @ 3025 psi on, 3015 psi off,Tq on/off=12k/10k,WOB=15k Flow out 24%. 13:00 14:30 1.50 12,630 12,630 PROD1 DRILL CIRC P CBU while R&R to reduce ECD and drilled gas 12630'to 12537' MD© 270 gpm,2847 psi,23%flow out, 13.45 ppg ECD, 150 rpm, 10k Tq. SPR's @ 12158'MD,6076'TVD, 12.3 ppg, 02:50 hrs #1-20 spm=560 psi, 30 spm=820 psi #2-20 spm=560 psi,30 spm=820 psi 14:30 16:15 1.75 12,630 12,725 PROD1 DRILL DDRL P Directional Drill 6%"from 12630'MD to12725' MD,6047'TVD. ECD=13.68 ppg, P/U=164k, S/0=93k, ROT=124k, 150 rpm, 270 gpm @ 3106 psi on, 3007 psi off, Tq on/off=12k/10k,WOB=17k Flow out 24%. SPR's @ 12633'MD,6059'TVD, 12.3 ppg, 14:30 hrs #1-20 spm=560 psi, 30 spm=830 psi #2-20 spm=560 psi, 30 spm=820 psi 16:15 16:45 0.50 12,725 12,725 PROD1 DRILL CIRC P CBU while R&R to reduce ECD and drilled gas 12639'to 12725'MD @ 270 gpm, 2847 psi,23%flow out, 13.56 ppg ECD, 150 rpm, 11k Tq. Reduce gas out from 850 units to below 500 units. 16:45 18:00 1.25 12,725 12,783 PROD1 DRILL DDRL P Directional Drill 6%"from 12725' MD to12783'MD, 6043'TVD. ECD=13.56 ppg,ADT=2.83, P/U=164k, S/0=94k, ROT=124k, 150 rpm, 270 gpm @ 3140 psi on,3076 psi off,Tq on/off=12k/10k,WOB=18k Flow out 24%.Total Bit Hrs=40.71,Total Jar Hrs=40.71 18:00 00:00 6.00 12,783 13,013 PROD1 DRILL DDRL P Directional Drill 6%"from 12783'MD to13013'MD, 6024'TVD. ECD=13.77 ppg,ADT=3.12, P/U=165k, S/O=90k, ROT=123k, 150 rpm, 280 gpm @ 3301 psi on, 3148 psi off,Tq on/off=14k/10k,WOB=18k Flow out 24%. Total Bit Hrs=43.83,Total Jar Hrs=43.83. 12/28/2014 CBU X 4 at TD, 13013'MD,6024'TVD. Flow check and pump out of hole to shoe @ 280 gpm, pack off temporarily detained @ 9753' MD. Secure extension on BOP test. Pull free into casing and CBU X3. Page 54 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:30 4.50 13,013 12,721 PROD1 CASING CIRC P CBU X 4 while R&R from 13013'to 12731'@ 275 gpm, 2990 psi,23% Flow 150 rpm, 12k Tq, ECD=13.6 ppg, P/U=164k, 5/0=91k, ROT=117k, 10k torque. Pumped total 15458 strokes, reduce rate on downstroke to 250 gpm. Rack back a stand every 1.5 bottoms up to 12731'. OA pressure @ 00:30=740 psi 04:30 05:00 0.50 12,721 12,731 PROD1 CASING OWFF P Blow down topdrive, monitor well 10 minutes slight trickle, 30 minutes static. SPR's @ 12724'MD, 6040'TVD, 12.3 ppg, 05:12 hrs #1-20 spm=560 psi, 30 spm=820 psi #2-20 spm=540 psi, 30 spm=820 psi 05:00 12:00 7.00 12,731 10,356 PROD1 CASING TRIP P Pump out of hole from 12731'MD to 10356' MD @ 275 gpm,2650 psi, 22%flow out, P/U=166k, 5/0=96k, Caslc Disp=12.5 bbl,Actual Disp=14.1 bbl. 15k overpull @ 11763' MD,wiped through. OA pressure @ 12:30 hrs=680 psi, 23:30 hrs=680 12:00 14:00 2.00 10,356 9,820 PROD1 CASING TRIP P Continue to pump out of hole from 10356'MD to 9820'MD @ 275 gpm, 2675 psi, 24%flow out, P/U=160k, 5/0=95k. 14:00 15:00 1.00 9,820 9,880 PROD1 CASING JAR T Observe 20k overpull @ 9820'MD, pump pressure increase to 2950 psi. Observe loss of returns due packoff. P/U to 175k, and slack off to 65k, no movement. Break out top drive, lay down double, Blow down top drive, p/u double S/O to 65k jarring through obstruction,work down to 9880'MD, re-gain circulation. 15:00 16:30 1.50 9,880 9,790 PROD1 CASING CIRC T Circulate and reciprocate from 9877' MD to 9790' MD @ 150 rpm, staging pumps up to 270 gpm,22%flow out, 2593 psi, 10k torque. 16:30 17:30 1.00 9,790 9,648 PROD1 CASING TRIP P Continue to pump out of hole from 9790' MD to 9648'MD @ 270 gpm, 22%flow out, 11k Tq, 2580 psi, 150 rpm,6 ft/min. Packoff @ 9648' MD, 5k overpull and loss of returns. 17:30 20:00 2.50 9,648 9,518 PROD1 CASING JAR I Attempt to work through obstruction and regain circulation, attempt to RIH, stacking weight @9753' MD 5/0=60k.Attempt to POOH, pulling 30-50k over and jarring to get inside casing. P/U=180k, 5/0=60k. SPR's @ 12724'MD,6040'TVD, 12.3 ppg, 20:00 hrs #1-20 spm=560 psi, 30 spm--- Page 55 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 9,518 9,518 PROD1 CASING SVRG P Service top drive, change out shock pin hydrauic hose on top drive. 20:30 23:30 3.00 9,518 9,292 PROD1 CASING CIRC T CBU X 2 while rotate and reciprocate from 9514'MD to 9292'MD staging pups up to 280 gpm,2772 psi,23% flow out,9K Tq, P/U=114k, 5/O=111k, reduce pump rate to 250 gpm on downstroke. Rack back a stand after 1.5 bottoms up. 23:30 00:00 0.50 9,292 9,316 PROD1 CASING MPSP P C/O slip inserts, PJSM P/U and set Baker Retrieve A Matic packer. P/U packer and crossovers, RIH to 9316' MD. 12/29/2014 Made up storm packer and set @ 102'(Bit @ 9425')Perform weekly BOPE test. Pull and L/D packer, RIH and attempt to clean out hole section below shoe. 00:00 01:00 1.00 9,316 9,425 PROD1 CASING MPSP P Continue to M/U storm packer and RIH to 9425' MD. Set packer @ 102' COE per Baker rep. Lay down running tool. 01:00 01:15 0.25 9,425 9,425 PROD1 CASING PRTS P Flood lines, close blind/shaer rams and test storm packer to 250/2000 psi 5 min each charted. 01:151 02:00 0.75 9,425 9,425 PROD1 WHDBO RURD P Drain stack, pull wear bushing and set test plug 02:00 02:30 0.50 9,425 9,425 PROD1 WHDBO BOPE P R/U to test,flood lines and perform body test. 02:30 07:00 4.50 9,425 9,425 PROD1 WHDBO BOPE P Test BOPE 250/3500 5 min ea charted.AOGCC John Crisp waived witness. Tested with 3%",4", and 4'/2'joint annular, UPR, LPR.Tested choke valves 1-15, maual and super choke(2000 psi)choke and kill manual and HCR valves,4"valve on kill line,4"TIW, 4"Dart valve, 3'/2' TIW, 3'/2'Dart valve. Upper and lower IBOP. 07:00 07:30 0.50 9,425 9,425 PROD1 WHDBO BOPE P Performed accumulator test and drawdown. System pressure 3000 psi, manifold 1500 psi, 1650 psi pressure after all function.200 psi=26 seconds with 2 elec pumps, 118 sec full pressure attained with 2 elec and 2 air pumps. Perform CPAI drawdown, isolate bottles,function UPR, LPR and HCR. 3000 psi with 2 elec pumps=54 sec, 3000 psi with 2 air pumps=157 sec. 6 bottle N2 average 2162 psi. 07:30 08:15 0.75 9,425 9,425 PROD1 WHDBO RURD P Pull test plug, set wear bushing, drain stack. Rig down test equipment and blow down choke, kill and top drive. Page 56 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ::Comment 08:15 09:30 1.25 9,425 9,305 PROD1 CASING MPSP P M/U overshot and RIH to packer set depth, Kelly up and open equalizing valve,verify no pressure on DP or CSG side of packer, release and POOH with packer from 102' MD and lay down. 09:30 11:30 2.00 9,305 9,305 PROD1 CASING CIRC P Circulate while R&R from 9305-9215' MD @ 278 gpm, 2600 psi,25%flow out,80 rpm,6k Tq, 11:30 12:00 0.50 9,305 9,305 PROD1 CASING RURD P Blow down top drive, Kelly up and set slips, hang blocks. OA pressure @ 12:30 hrs=650 psi 12:00 14:00 2.00 9,305 9,305 PROD1 CASING SLPC P PJSM-Slip and cut drilling line, cut 90', calibrate block height Totco, Amphion, MWD, monitor well via pit 2. 14:00 14:30 0.50 9,305 9,318 PROD1 CASING SVRG P Greased blocks and top drive, inspected saver sub. 14:30 18:00 3.50 9,318 9,525 PROD1 CASING TRIP T RIH from 9318'MD to 9552'MD on elevators P/U=160k, 5/0=103k, ROT 121k, obstruction @ 9552'MD, S/O 30k.Attempted to work through 3 times, P/U to 9510' MD. Obtained parameters, SPR's, stage pumps up to drilling rate @ 270 gpm,2433 psi, 23%flow out, 150 rpm, 10k-11k Tq. Attempt to wash/ream down through obstruction @ 1 fpm, packed off and torqued up @ 9525' MD. 18:00 22:00 4.00 9,525 10,165 PROD1 CASING REAM T Reduce flow rate and rpm, wash/ream down from 9519'to 10165'@ 168 gpm, 1190 psi, 100 rpm, 8k Tq, 18%flow out. 22:00 00:00 2.00 10,165 9,978 PROD1 CASING TRIP T Pump out of hole from 10165' MD to 9887'MD @ 4 bpm, 1250 psi, 17% flow out,25 fpm.Tight hole @ 10133'. Packoff and lost returns @ 9887'MD, 20k overpull.Jar down to free RIH to 9978'attempt to regain circulation @ 1 bpm, P/U=170k, 5/0=95k, ROT=121k. 12/30/2014 Pull to casing shoe, circulate casing clean, monitor well and pump out to 4000'. Monitor then pull to surface and lay down BHA. R/U to run liner. 00:00 01:00 1.00 9,887 9,500 PROD1 CASING TRIP T Continue POOH from 9887' MD to 9500'MD with 20k overpull, pump.5 bpm 190 psi to mitigate swab. Encounter tight spot @ 9555'pul 35k over.Wipe down 60'and re-pull with 15k over. P/U=175k, S/0=98k. 01:00 02:00 1.00 9,500 9,500 PROD1 CASING CIRC P CBU while R&R from 9500'to 9404', stage pumps up to 280 gpm, 2700 psi,25%flow out, 80 rpm,7k Tq, OA pressure=650 psi @ 02:00 hrs. Page 57 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:45 0.75 9,500 9,500 PROD1 CASING CIRC P Open Well Commander-Drop 1.75" activation ball and pump down @ 84 gpm, 515 psi 8%flow, ball on seat @ 480 stks,stage pressure up per procedure and observe shift open @ 2020 psi. Confirm activation pressure drop 84 gpm=350 psi,280 gpm=1350 psi. 02:45 04:45 2.00 9,500 9,500 PROD1 CASING CIRC P CBU x 3 through Well commander while R&R from 9500' MD to 9404' MD @ 335 gpm, 1800 psi,26%flow out,80 rpm, 7k Tq,Total strokes pumped=8827, P/U=159k, S/0=108k. 04:45 05:30 0.75 9,500 9,500 PROD1 CASING CIRC P Close Well Commander-Drop 1.75" activation ball and pump down @ 84 gpm 335 psi ball on seat @ 480 stks, stage up pressure per procedure onserve shift open @ 2265 psi. Confirm activation 84 gpm=475 psi. 05:30 06:45 1.25 9,500 9,500 PROD1 CASING OWFF P Blow down topdrive, monitor well observed diminishing flowback. 06:45 12:00 5.25 9,500 5,805 PROD1 CASING TRIP P Pump out of hole from 9500' MD to 5805' MD#3 bpm, 540 psi, 6%flow out, 100 fph. Monitor displacement via pits. P/U=105k, 5/0=89k. Calc Disp=17.5 bbl,Actual Disp=17.5 bbl. 12:00 15:00 3.00 5,805 4,000 PROD1 CASING TRIP P Continue pumping out of hole from 5805' MD to 4000'MD @ 3 bpm 535 psi, 12%flow out. P/U=90k, S/0=82k, pulling @ 75 fpm, monitor proper displacment. 15:00 15:30 0.50 4,000 4,000 PROD1 CASING OWFF P Observe well for 10 minutes static. 15:30 16:45 1.25 4,000 3,143 PROD1 CASING TRIP P POOH on elevators from 4000'MD to 3143'MD, 17 fpm, monitor proper displacement via trip tank. 16:45 17:15 0.50 3,143 3,143 PROD1 CASING CIRC P Pump 17 bbl dry job 14.1 ppg, 3 bpm 475 psi,4%flow out, blow down top drive. 17:15 20:15 3.00 3,143 490 PROD1 CASING TRIP P Continue POOH on elevators from 3143'-490'following trip schedule. 17 ft/min-60 ft/min. Monitor proper fill via trip tank. SIMOPS-Pick up liner running equipment. 20:15 20:45 0.50 490 490 PROD1 CASING OWFF P Monitor well-Static. Change out slip inserts. 20:45 23:30 2.75 490 0 PROD1 CASING PULD P PJSM-Lay down BHA per DD/MWD rep. Monitor displacement. Calc fill for trip=32.67 bbl,Actual fill for trip=42.9 bbl. 23:30 00:00 0.50 0 0 COMPZ CASING'RURD P Clean and clear rig floor,send out BHA. Service PS-21 slips 12/31/2014 Rig up and run 10 jts 4W IBTM liner, Phase III weather.XO to DP, RIH 10 stands and stand by and monitor well via trip tank while circulating across top. Page 58 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 0 0 COMPZ CASING RURD P R/U to run liner,verify pipe count& jewelry in pipeshed. Hold PJSM with rig crew for running liner. 01:30 06:30 5.00 0 0 COMPZ CASING PUTB P Make up Silver Bullet shoe on 10' pup. 06:30 07:30 1.00 0 346 COMPZ CASING PUTB P P/U and RIH with 4'/�'L-80 IBTM Liner as per detail to 346'MD Monitor displacement via TT. 07:30 08:00 0.50 346 346 COMPZ CASING RURD T Due to Phase III weather conditions, decision made to XO to 4"DP and RIH 10 stands to monitor well. PJSM - C/O elevators and PS-21 inserts. 08:00 08:30 0.50 346 1,293 COMPZ CASING RUNL T RIH with 4'/2' Liner on 4"drill pipe out of derrick from 346'to 1293'MD. Monitor displacement with trip tank. P/U=54k, 5/0=64k, Install floor valve. 08:30 00:00 15.50 1,293 1,293 COMPZ CASING OWFF T Phase III weather conditions. Circulate across top of hole& monitor well via trip tank. Observe slight loss-3.2 bph 01/01/2015 Wait on weather till 03:30 hrs. Get crews out to start rig ops @ 06:00 hrs. Stand back 10 stands 4"DP, P/U and run 4'/2'liner on 4"drill pipe to 12105'MD. 00:00 03:30 3.50 1,293 1,293 COMPZ CASING OWFF T Phase III weather conditions. Circulate across top of hole& monitor well via trip tank.Observe slight loss-1.2 bph 03:30 07:00 3.50 1,293 1,293 COMPZ CASING OWFF T Circulate across top of hole& monitor well via trip tank.While crew and Baker completion hand gets to rig. OA pressure @ 07:00 hrs=480 psi 07:00 07:30 0.50 1,293 346 COMPZ CASING TRIP T POOH on elevators from 1293'MD to 346'MD, C/O PS-21 slip inserts. 07:30 07:45 0.25 346 346 COMPZ CASING SFTY T PJSM on running 4W liner. 07:45 08:15 0.50 346 346 COMPZ CASING RURD T C/O elevators,verify rig up and pipe/jewelry count. 08:15 12:00 3.75 346 3,066 COMPZ CASING PUTB P P/U and RIH with 4W 12.6#L-80 IBTM as per detail from 346'-3066' MD. Monitor displacement via trip tank. 12:00 13:00 1.00 3,066 3,658 COMPZ CASING PUTB P Continue P/U and RIH with 4'/2'liner per detail from 3066' MD to 3658' MD. P/U=65k, 5/0=71k OA pressure @ 12:30 hrs=480 psi 13:00 15:00 2.00 3,658 3,720 COMPZ CASING OTHR P C/O slip inserts, M/U seal bore, liner hanger and liner top packer. Blend Pal mix pour and set 30 min. Clean and clear rig floor. Page 59 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 18:00 3.00 3,720 7,450 COMPZ CASING RUNL P C/O slip inserts, RIH out of derrick with 4"DP from 3658'-7450' MD @ 90 fpm,filling pipe every 20 stands. SIMOPS-Send out liner running equipment,clean and prep pits for brine displacement. 18:00 19:30 1.50 7,450 9,440 COMPZ CASING RUNL P Continue running liner in hole on 4" DP from 7450'MD-9519'MD @ 90 fpm. 19:30 21:00 1.50 9,440 9,440 COMPZ CASING CIRC P Obtain parameters, circulate surface-surface mud volume while reciprocating pipe from 9440'-9398' MD. Condition mud, stage pumps up to 5 bpm, 825 psi, 22%flow out. Obtain SPR's, P/U=140k, 5/0=100k, ROT=115 @ 10 rpm, 6k TQ,total strokes=3900. SPR's @ 9432'MD, 5959'MD 12.25 ppg,20:40 hrs. #1-20 spm=290 psi, 30 spm=410 psi #2-20 spm=280 psi, 30 spm=410 psi 21:00 00:00 3.00 9,440 12,105 COMPZ CASING RUNL P Continue RIH with 4" DP out of derrick from 9440'MD to 12105' MD. String took 10k @ 9480', P/U and wipe once OK. Took 10k @ 9614' MD, P/U and wipe once OK. 15k @ 9660'MD, P/U and wipe x 4 could not pass, P/U and rotate 90°pass through OK. Calc Disp=19.5 bbl bbl, Actual Disp=19.5 bbl. OA pressure @ 23:30 hrs=480 psi 01/02/2015 Run liner to 12993'. Set liner hanger and liner top packer.Test packer, unsting and displace to 12.3 ppg brine. POOH and L/D running tools. R/U to run upper completion. 00:00 01:00 1.00 12,105 12,558 COMPZ CASING RUNL P Continue RIH with 4%"liner on 4" HWDP from p[ipe shed from 12105-12558' MD P/U=180k, .5/0=88k. 01:00 01:30 0.50 12,558 13,000 COMPZ CASING RUNL P RIH with liner on 4"DP from derrick, 12558'-13000' MD Work through tight spots 12790', 12817', 12911', 12926' up to 20k down weight.Work swell packer into position. P/U=191k, S/O=98k. 01:30 03:15 1.75 13,000 12,993 COMPZ CASING PACK P P/U to depth 12993' MD&drop neutral weoght ball. Pump down @ 3 bpm, 860 psi, 13%flow out. Ball on seat @ 726 stks, pressure up to 2700 psi&slack off to 51k. Pressure up to 4000 psi and perform hydraulic release. P/U and break over @ 163k, pressure up and shear ball seat @ 4800 with test pump. ROT 15 rpm and S/O 40k to set packer. P/U=191k, S/0=96k with liner, P/U=163k, 5/O=113k after release. Page 60 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:45 0.50 12,993 9,329 COMPZ CASING PRTS P R/U test equipment and test packer to 1500 psi for 15 minutes charted. 03:45 04:15 0.50 9,329 9,329 COMPZ CASING RURD P R/D test equipment, rack back a stand. Blow down topdrive. 04:15 06:00 1.75 9,329 9,329 COMPZ WELLPF OWFF P Monitor well,slight flowing back decreasing. SIMOPS=Bring on additional 12.0 ppg brine and weight up to 12.3 ppg. Prep empty pits 1,2,3 for displacement. Hold PJSM with CPAI, MISWACO, Peak truck drivers for displacement. 06:00 07:15 1.25 9,329 9,329 COMPZ WELLPF DISP P Displace well to 12.3 ppg brine while reciprocating 9329'-9239'MD @ 8 bpm, 1450 psi, 26%flow out,total strokes pumped 5220. 07:15 11:00 3.75 9,329 9,270 COMPZ WELLPF OWFF P Blow down topdrive, monitor well flowing back to trip tank. Flow back 17.3 bbl. OA pressure @ 10:30 hrs=510 psi 11:00 12:00 1.00 9,270 9,270 COMPZ WELLPF CIRC T CBU while reciprocating 9270'-9180' MD @ 6 bpm, 890 psi,20%flow out. P/U=172k, S/0=108k.Total strokes=6500, SIMOPS-send out 4Y2'handling equipment. 12:00 15:30 3.50 9,270 9,270 COMPZ WELLPF CIRC T Monitor well for 10 min, observe underbalanced fluid, continue to circulate @ 6 bpm 910 psi, 20%flow out while maintaining 12.3 ppg in/out brine density.Total strokes pumped=7500. 15:30 16:30 1.00 9,270 9,270 COMPZ WELLPF OWFF T Blow down top drive, Monitor well- Static 16:30 21:30 5.00 9,270 0 COMPZ WELLPF TRIP P POOH from 9270'MD, rack back HWDP and DP. Lay down liner running tools per Baker rep. Monitor displacement via TT. Calc Fill=59.12 bbl,Actual Fill=60.8 bbl. 21:30 00:00 2.50 0 0 COMPZ RPCOM RURD P P/U 4"test joint, pull wear ring. Clean and clear rig floor. Send out liner running tools. P/U 3'/z'running equipment. Make up 4'/2'landing joint to hanger per FMC, drain stack and perform dummy run,make marks on landing joint to indicate fully landed. 01/03/2015 Run upper completion to depth,fully locate and space out. P/U hanger and landing jt. Spot inhibitor. 00:00 06:00 6.00 0 3,186 COMPZ RPCOM PUTB P PJSM, Run 3Y2'9.3#L-80 EME-M GL completion per running detail to 3186' MD,torque EUE-M connections to 2240 ft/lbs. C/O joint 9&10 due to damaged threads. Made up seal assy, D nipple w/RHC plug installed, CMU sliding sleeve with RHC plug installed and 120 jts tubing. Page 61 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 3,186 8,466 COMPZ RPCOM PUTB P Continue running completion per detail from 3186'MD to 8466'MD, P/U 3-GLM's, (1 SOV,2-Dummy valve). OA pressure @ 11:30 hrs=450 psi. 12:00 14:00 2.00 8,466 9,317 COMPZ RPCOM PUTB P Continue running completion per detail,to 9317' MD Picking up upper DS nipple 2.875' Last 14 jts drifted to 2.91"on skate. Make up all 3'/2' connections to 2240 ft/lbs. 14:00 15:00 1.00 9,317 9,317 COMPZ RPCOM RURD P Install 180"long bails to make room for a 4"TIW&2 XO's for circulating. 15:00 17:00 2.00 9,317 9,393 COMPZ RPCOM HOSO P M/U joints 297,298, 299 tag no-go 20'in on 299,seal depth 9393.69' with 4k WOB. Calculate space out. 17:00 18:00 1.00 9,393 9,393 COMPZ RPCOM OTHR T Rig lost hiline power,warm up cats and put rig on gen power. Re-assign and start pumps,draw works and topdrive. Double check all hydraulic systems. 18:00 19:00 1.00 9,393 9,341 COMPZ RPCOM CIRC P Pick up out of seal bore, CBU,stage pumps up to 6 bpm, 990 psi. 19:00 21:00 2.00 9,341 9,281 COMPZ RPCOM HOSO P Lay down joints 299,298 and 297. Total 4 joints of 3'/2'left in shed, 8 outside. 21:00 22:00 1.00 9,281 9,315 COMPZ RPCOM HOSO P Drift and M/U 4.18'3'/z'pup, M/U XO to 4'/2'IBT-M and 1 joint 4'/2"IBTM. 22:00 22:30 0.50 9,315 9,315 COMPZ RPCOM THGR P M/U 1502 high pressure circ/test fittings and cement hose to landing joint/hanger on skate. 22:30 23:00 0.50 9,315 9,340 COMPZ RPCOM THGR P P/U hanger/landing joint. Inspect landing joint and install plugs in control line ports. 23:00 00:00 1.00 9,340 9,340 COMPZ RPCOM CRIH P Establish circulation thru landing joint and hanger,stage pumps up to 5 bpm,400 psi. Pump corrosion inhibited brine per program. Pump 124 bbl clean 12.3 ppg brine,211 bbl inhibited 12.3 ppg brine, chase with 45 bbl 12.3 ppg brine. Final 100 strokes, lowered seals into seal bore, observing pressure as seals enter bore©9377', shut down pump. 31/04/2015 Land tubing, RILDS.Test tubing/ann to 3500 charted. Set TWC/test. N/D stack, N/U tree and test. Freeze protect with 93 bbl diesel. U-Tube and set type H BPV. L/D drill pipe. Prep for move. 00:00 00:45 0.75 9,340 9,389 COMPZ RPCOM THGR P Slack off, sting into SBE pumping 2 bpm, observe pressure increase 200 psi @ 9377'MD. Bleed pressure, drain stack. Blow down choke/kill, hole fill and jet lines.With bleeder and IA open, land hanger and RILDS. Tubing landed @ 00:50 9388.81'MD Page 62 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 03:00 2.25 9,389 9,389 COMPZ RPCOM PRTS P Pull hose from pump in sub,drop 1-13/16"ball/rod. M/U hoses to squeeze manifold. Pressure test tubing to 3500 psi-30 minutes charted. Bleed tubing to 2000 psi, pressure test IA to 3500 psi-30 minutes charted. Dump tubing pressure and observe SOV shear @ 2600 psi csg/tbg diff. Bleed all pressure. 03:00 04:00 1.00 9,389 0 COMPZ WHDBO MPSP P Pull landing joint, install TWC per FMC rep. Test same via IA to 2500 psi charted 10 minutes. 04:00 04:45 0.75 0 0 COMPZ WHDBO OWFF P Observe IA static for 30 minutes per program. SIMOPS-blow down mud and injection lines, pull PS-21 slips for cleaning and PM. Flush pits and lines with hot water. 04:45 07:30 2.75 0 0 COMPZ WHDBO NUND P Pull strip-o-matic and pitcher nipple, N/D BOPE 07:30 08:00 0.50 0 0 COMPZ WHDBO NUND P Position tree with jib crane and tuggers on BOP deck, lower to cellar. 08:00 09:00 1.00 0 0 COMPZ WHDBO NUND P Pad operator and FMC verify tree orientation. SIMOPS-Clean lower adapter flange and riser expansion boot, clean floor and BOP deck. P/U thread protectors for 4" DP, PM the PS-21 slips.. 09:00 11:00 2.00 0 0 COMPZ WHDBO NUND P Nipple up tree,Witness FMC test adapter void to 5000 psi-good. SIMOPS-continue cleaning rotary and Joes box equipment. 11:00 13:00 2.00 0 0 COMPZ WHDBO PRTS P Remove tree cap and install pump in sub on top of tree. Fill and test tree to 250/5000 psi 5 min each charted. Rig down and blow down test pump. 13:00 14:00 1.00 0 0 COMPZ WHDBO MPSP P Pull two way check with dry rod. 14:00 15:00 1.00 0 0 COMPZ WHDBO FRZP P Clean and clear cellar of N/U tools. Rig up Tioga in cellar. 15:00 16:00 1.00 0 0 COMPZ WHDBO FRZP P Rig up to freeze protect well, PJSM. Pressure test surface lines. 16:00 17:30 1.50 0 0 COMPZ WHDBO FRZP P Freeze protect well with rig injection pump, pump 93 bbl diesel down IA taking returns out the tubing(via SOV)@ 1.5 bpm, ICP=420 psi, FCP=1055 psi. 17:30 19:00 1.50 0 0 COMPZ WHDBO FRZP P Allow well to U-tube, ITP=800 psi, IIAP=525 psi. U-Tube 90 minutes 500 psi on tubing and IA, leaving 74 bbl in annulus and 19 bbl in tubing. 19:00 20:00 1.00 0 0 COMPZ WHDBO FRZP P Blow down and rig down high pressure circ lines. Page 63 of 64 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:00 2.00 0 0 COMPZ WHDBO MPSP P P/U lubricator, lower into cellar, install on tree. R/U test lines and test lubricator to 1000 psi-good. Install Type H BPV, rig down lubricator. 22:00 23:00 1.00 0 0 COMPZ WHDBO SEQP P Secure well, clean tree, install integral flanges and guages.Well _secured @ 23:00 hrs. 23:00 00:00 1.00 0 0 ,DEMOB MOVE PULD P Install long mousehole in rotary table, Begin laying down stands of 4" HWDP. 31/05/2015 Lay down 4"HWDP,4"drill pipe. Remove pipe from shed. Prep mods for move, scope down and lay down derrick. Fire cold starts, separate parts trailers, pump module and power module. Rig released as 00:00 hrs 1/6/15 00:00 06:00 6.00 0 0 DEMOB MOVE PULD P Continue laying down 4"HWDP 1x1, L/D 4"DP doubles in magazine, • singles to casing shed. SIMOPS- Clean cellar,suck out pit lines. 06:00 12:00 6.00 0 0 DEMOB MOVE PULD P Continue laying down 4"DP singles via mousehole. Change out valves and seats pump#1. Begin to break lines and innerconnects. Start all cold starts. 12:00 16:00 4.00 0 0 DEMOB MOVE PULD P Continue laying down remaining 4" DP. 16:00 18:00 2.00 0 0 DEMOB MOVE RURD P Clear floor of all tool/equipment. L/D mousehole,thread protectors. Pull PS-21's and replace w/master bushing. 18:00 20:00 2.00 0 0 DEMOB MOVE RURD P Prep and move parts trailers. Install links and bridal up. Continue rig down other modules. Blow down service lines and innerconnects. 20:00 21:00 1.00 0 0 DEMOB MOVE RURD P PJSM and scope down derrick. Install jumper for derrick lights. 21:00 22:00 1.00 0 0 DEMOB MOVE RURD P Pin up top drive and blocks into place. Prep floor for lay down. Prep floor to swap to cold starts. Blow down steam. 22:00 00:00 2.00 0 0 DEMOB MOVE RURD P Raise cattle shute, prep to raise C section and lay down derrick. Separate casing shed from sub. Prep pump module and power module for move to 2L. Rig release @ 00:00 hrs 1/6/15 Page 64 of 64 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-36 Definitive Survey Report N A D 2 7] 13 January, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36(g 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-36 Well Position +N/-S 0.00 usft Northing: 5,948,984.77 usft Latitude: 70°16'18.567 N +E/-W 0.00 usft Easting: 487,817.93 usft Longitude: 150°5'54.693 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-36 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 11/7/2014 18.97 80.84 57,564 Design 2M-36 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,270.06 Vertical Section: Depth From(TVD) +NI-S +E/48/ Direction (usft) (usft) (usft) (°) 39.49 0.00 0.00 294.00 Survey Program Date 1/13/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.00 1,130.00 2M-36PB1 Srvy#1-GYD-GC-MS(2M-3 GYD-GC-MS Gyrodata gyrocompassing m/s 11/11/2014 5:57 1,189.55 3,270.06 2M-36PB1 Srvy#2-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2014 6:00 3,365.81 9,476.88 2M-36 Srvy#1-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/12/2014 1:11 9,553.48 12,953.64 2M-36 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/15/2014 10:1. 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 39.49 0.00 0.00 39.49 -101.30 0.00 0.00 5,948,984.77 487,817.93 0.00 0.00 UNDEFINED 97.00 0.40 256.40 97.00 -43.79 -0.05 -0.20 5,948,984.72 487,817.73 0.70 0.16 GYD-GC-MS(1) 188.00 0.66 258.57 188.00 47.21 -0.23 -1.02 5,948,984.54 487,816.91 0.29 0.84 GYD-GC-MS(1) 278.00 1.50 353.59 277.98 137.19 0.84 -1.66 5,948,985.61 487,816.27 1.88 1.86 GYD-GC-MS(1) 374.00 1.57 3.93 373.95 233.16 3.40 -1.71 5,948,988.17 487,816.22 0.30 2.94 GYD-GC-MS(1) 470.00 3.33 343.60 469.86 329.07 7.39 -2.40 5,948,992.16 487,815.53 2.02 5.20 GYD-GC-MS(1) 564.00 3.91 343.60 563.67 422.88 13.08 -4.08 5,948,997.86 487,813.87 0.62 9.05 GYD-GC-MS(1) 657.00 4.61 349.66 656.41 515.62 19.80 -5.65 5,949,004.58 487,812.31 0.89 13.21 GYD-GC-MS(1) 753.00 6.06 352.48 752.00 611.21 28.62 -7.00 5,949,013.40 487,810.97 1.53 18.04 GYD-GC-MS(1) 847.00 8.16 349.61 845.27 704.48 40.10 -8.85 5,949,024.88 487,809.14 2.27 24.40 GYD-GC-MS(1) 943.00 11.06 345.45 939.91 799.12 55.72 -12.40 5,949,040.50 487,805.62 3.10 33.99 GYD-GC-MS(1) 1/13/2015 12:30:18PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,037.00 11.05 339.54 1,032.17 891.38 72.89 -17.81 5,949,057.68 487,800.23 1.21 45.92 GYD-GC-MS(1) 1,130.00 11.98 340.75 1,123.30 982.51 90.35 -24.11 5,949,075.15 487,793.97 1.03 58.77 GYD-GC-MS(1) 1,189.55 12.88 341.70 1,181.45 1,040.66 102.49 -28.23 5,949,087.29 487,789.86 1.55 67.48 MIND+IFR-AK-CAZ-SC(2) 1,284.12 15.84 341.23 1,273.06 1,132.27 124.72 -35.70 5,949,109.53 487,782.44 3.13 83.34 MWD+IFR-AK-CAZ-SC(2) 1,379.49 18.29 338.03 1,364.22 1,223.43 150.93 -45.48 5,949,135.75 487,772.69 2.75 102.94 MWD+IFR-AK-CAZ-SC(2) 1,473.73 18.90 334.84 1,453.55 1,312.76 178.46 -57.51 5,949,163.30 487,760.72 1.26 125.12 MWD+IFR-AK-CAZ-SC(2) 1,567.09 20.43 332.70 1,541.46 1,400.67 206.62 -71.41 5,949,191.49 487,746.86 1.81 14928 MWD+IFR-AK-CAZ-SC(2) 1,661.80 22.52 326.67 1,629.60 1,488.81 236.47 -88.96 5,949,221.36 487,729.36 3.21 177.45 MWD+IFR-AK-CAZ-SC(2) 1,756.34 24.83 319.91 1,716.19 1,575.40 266.80 -111.70 5,949,251.72 487,706.67 3.77 210.56 MWD+IFR-AK-CAZ-SC(2) 1,851.38 25.64 313.44 1,802.18 1,661.39 296.21 -139.48 5,949,281.17 487,678.94 3.02 247.90 MWD+IFR-AK-CAZ-SC(2) 1,947.09 27.21 304.48 1,887.92 1,747.13 322.85 -172.57 5,949,307.86 487,645.89 4.47 288.97 MW3+IFR-AK-CAZ-SC(2) 2,040.24 28.97 298.65 1,970.11 1,829.32 345.72 -209.94 5,949,330.80 487,608.57 3.50 332.40 MW1D+IFR-AK-CAZ-SC(2) 2,134.21 30.55 295.28 2,051.69 1,910.90 366.84 -251.51 5,949,351.97 487,567.04 2.45 378.97 MWD+IFR-AK-CAZ-SC(2) 2,230.79 32.20 291.54 2,134.15 1,993.36 386.77 -297.64 5,949,371.98 487,520.94 2.64 429.23 MWD+IFR-AK-CAZ-SC(2) 2,323.31 34.82 286.65 2,211.30 2,070.51 403.39 -345.90 5,949,388.68 487,472.72 4.06 480.07 MW0+1FR-AK-CAZ-SC(2) 2,421.48 38.39 285.23 2,290.10 2,149.31 419.44 -402.18 5,949,404.81 487,416.46 3.74 538.01 MWD+IFR-AK-CAZ-SC(2) 2,516.85 41.43 283.48 2,363.25 2,222.46 434.58 -461.45 5,949,420.05 487,357.22 3.40 598.32 MWD+IFR-AK-CAZ-SC(2) 2,607.79 45.83 283.41 2,429.05 2,288.26 449.16 -522.47 5,949,434.73 487,296.24 4.84 659.99 MWD+IFR-AK-CAZ-SC(2) 2,702.41 48.87 282.96 2,493.15 2,352.36 465.03 -590.22 5,949,450.70 487,228.52 3.23 728.34 MWD+1FR-AK-CAZ-SC(2) 2,753.16 52.41 283.63 2,525.33 2,384.54 474.05 -628.40 5,949,459.79 487,190.36 7.05 766.89 MW0+IFR-AK-CAZ-SC(2) 2,796.75 53.90 282.80 2,551.47 2,410.68 482.03 -662.36 5,949,467.82 487,156.41 3.74 801.15 MWD+IFR-AK-CAZ-SC(2) 2,892.13 56.55 278.98 2,605.88 2,465.09 496.78 -739.27 5,949,482.69 487,079.53 4.31 877.42 MWD+IFR-AK-CAZ-SC(2) 2,985.78 58.27 278.81 2,656.32 2,515.53 508.98 -817.22 5,949,495.02 487,001.61 1.84 953.59 MWD+IFR-AK-CAZ-SC(2) 3,080.36 59.34 278.31 2,705.31 2,564.52 521.02 -897.23 5,949,507.19 486,921.63 1.22 1,031.57 MWD+1FR-AK-CAZ-SC(2) 3,174.51 59.40 276.62 2,753.28 2,612.49 531.54 -977.55 5,949,517.84 486,841.34 1.55 1,109.23 MWD+IFR-AK-CAZ-SC(2) 3,270.06 60.47 275.76 2,801.15 2,660.36 540.46 -1,059.76 5,949,526.89 486,759.15 1.36 1,187.96 MWD+IFR-AK-CAZ-SC(2) 3,365.81 62.93 276.90 2,846.54 2,705.75 549.76 -1,143.54 5,949,536.32 486,675.39 2.77 1,268.28 MWD+IFR-AK-CAZ-SC(3) 3,409.80 64.63 275.05 2,865.98 2,725.19 553.86 -1,182.79 5,949,540.49 486,636.16 5.40 1,305.81 MW0+1FR-AK-CAZ-SC(3) 3,468.72 65.81 273.57 2,890.67 2,749.88 557.88 -1,236.13 5,949,544.59 486,582.83 3.04 1,356.17 MWD+IFR-AK-CAZ-SC(3) 3,562.30 66.62 273.77 2,928.42 2,787.63 563.36 -1,321.58 5,949,550.21 486,497.39 0.89 1,436.47 MWD+IFR-AK-CAZ-SC(3) 3,657.43 66.71 273.33 2,966.10 2,825.31 568.77 -1,408.76 5,949,555.76 486,410.23 0.44 1,518.31 MWD+IFR-AK-CAZ-SC(3) 3,751.85 65.31 273.63 3,004.48 2,863.69 574.01 -1,494.87 5,949,561.13 486,324.14 1.51 1,599.10 MWD+IFR-AK-CAZ-SC(3) 3,845.78 65.46 273.77 3,043.61 2,902.82 579.52 -1,580.08 5,949,566.78 486,238.94 0.21 1,679.19 MWD+IFR-AK-CAZ-SC(3) 3,938.23 64.25 273,87 3,082.89 2,942.10 585.09 -1,663.58 5,949,572.49 486,155.46 1.31 1,757.74 MWD+IFR-AK-CAZ-SC(3) 4,035.06 62.27 273.69 3,126.46 2,985.67 590.79 -1,749.87 5,949,578.33 486,069.19 2,05 1,838.88 MWD+IFR-AK-CAZ-SC(3) 4,130.81 60.74 274.40 3,172.14 3,031.35 596.73 -1,833.80 5,949,584.40 485,985.27 1.73 1,917.97 MWD+IFR-AK-CAZ-SC(3) 4,225.62 58.44 276.24 3,220.13 3,079.34 604.29 -1,915.21 5,949,592.10 485,903.89 2.95 1,995.42 MVD+IFR-AK-CAZ-SC(3) 4,320.24 58.94 278.74 3,269.30 3,128.51 614.83 -1,995.35 5,949,602.77 485,823.77 2.32 2,072.92 MWD+IFR-AK-CAZ-SC(3) 4,414.64 57.09 282.82 3,319.32 3,178.53 629.77 -2,073.98 5,949,617.83 485,745.17 4.16 2,150.83 MWD+IFR-AK-CAZ-SC(3) 4,508.04 57.40 282.31 3,369.85 3,229.06 646.86 -2,150.65 5,949,635.04 485,668.54 0.57 2,227.82 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:30:18PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 4,602.79 57.12 280.80 3,421.10 3,280.31 662.83 -2,228.73 5,949,651.13 485,590.50 1.37 2,305.64 MWD+IFR-AK-CAZ-SC(3) 4,696.08 57.17 277.53 3,471.72 3,330.93 675.30 -2,306.08 5,949,663.74 485,513.18 2.94 2,381.38 MWD+IFR-AK-CAZ-SC(3) 4,791.19 58.42 276.22 3,522.41 3,381.62 684.93 -2,385.97 5,949,673.49 485,433.30 1.76 2,458.28 MWD+IFR-AK-CAZ-SC(3) 4,883.67 59.88 276.56 3,569.83 3,429.04 693.77 -2,464.87 5,949,682.46 485,354.43 1.61 2,533.95 MW1J+IFR-AK-CAZ-SC(3) 4,979.22 60.80 277.10 3,617.12 3,476.33 703.65 -2,547.31 5,949,692.46 485,272.01 1.08 2,613.28 MW3+IFR-AK-CAZ-SC(3) 5,074.19 62.19 277.66 3,662.44 3,521.65 714.37 -2,630.07 5,949,703.32 485,189.27 1.55 2,693.25 MWD+IFR-AK-CAZ-SC(3) 5,170.10 61.51 278.82 3,707.69 3,566.90 726.48 -2,713.76 5,949,715.57 485,105.61 1.28 2,774.64 MWD+IFR-AK-CAZ-SC(3) 5,263.78 61.74 278.79 3,752.21 3,611.42 739.10 -2,795.22 5,949,728.32 485,024.19 0.25 2,854.18 MWD+IFR-AK-CAZ-SC(3) 5,358.58 61.10 278.20 3,797.56 3,656.77 751.40 -2,877.55 5,949,740.75 484,941.88 0.87 2,934.40 MW3+IFR-AK-CAZ-SC(3) 5,454.10 61.05 278.37 3,843.76 3,702.97 763.45 -2,960.28 5,949,752.93 484,859.18 0.16 3,014.88 MWD+IFR-AK-CAZSC(3) 5,547.64 61.39 278.98 3,888.79 3,748.00 775.81 -3,041.33 5,949,765.43 484,778.16 0.68 3,093.95 MWD+IFR-AK-CAZSC(3) 5,641.71 60.88 277.84 3,934.21 3,793.42 787.86 -3,122.83 5,949,777.61 484,696.69 1.19 3,173.30 MWD+IFR-AK-CAZ-SC(3) 5,733.47 61.36 277.88 3,978.52 3,837.73 798.85 -3,202.42 5,949,788.72 484,617.13 0.52 3,250.48 MWD+IFR-AK-CAZSC(3) 5,831.19 61.15 280.84 4,025.53 3,884.74 812.78 -3,286.94 5,949,802.79 48.4,532.63 2.66 3,333.36 MWD+IFR-AK-CAZ-SC(3) 5,925.64 61.18 281.30 4,071.08 3,930.29 828.67 -3,368.14 5,949,818.80 484,451.47 0.43 3,414.00 MWD+IFR-AK-CAZSC(3) 6,019.38 61.33 281.24 4,116.16 3,975.37 844.73 -3,448.74 5,949,834.99 484,370.90 0.17 3,494.17 MWD+IFR-AK-CAZ-SC(3) 6,113.82 61.17 281.21 4,161.58 4,020.79 860.85 -3,529.96 5,949,851.24 484,289.72 0.17 3,574.92 MWD+IFR-AK-CAZSC(3) 6,209.16 61.08 280.73 4,207.62 4,066.83 876.74 -3,611.92 5,949,867.26 484,207.79 0.45 3,656.25 MWD+IFR-AK-CAZSC(3) 6,303.94 61.21 280.32 4,253.36 4,112.57 891.90 -3,693.54 5,949,882.55 484,126.21 0.40 3,736.98 MWD+IFR-AK-CAZSC(3) 6,397.65 61.38 280.25 4,298.37 4,157.58 906.57 -3,774.41 5,949,897.36 484,045.37 0.19 3,816.83 M1MD+IFR-AK-CAZ-SC(3) 6,492.71 61.07 279.22 4,344.13 4,203.34 920.66 -3,856.53 5,949,911.58 483,963.28 1.00 3,897.58 MWD+IFR-AK-CAZ-SC(3) 6,586.76 61.58 278.90 4,389.26 4,248.47 933.66 -3,938.01 5,949,924.70 483,881.82 0.62 3,977.31 MWD+IFR-AK-CAZSC(3) 6,681,04 61.16 278.77 4,434.44 4,293.65 9.46.37 -4,019.78 5,949,937.54 483,800,08 0.46 4,057.18 MWD+IFR-AK-CAZSC(3) 6,775.49 61.04 278.86 4,480.08 4,339.29 959.04 -4,101.49 5,949,950.35 483,718.40 0.15 4,136.98 MWD+IFR-AK-CAZ-SC(3) 6,869.68 61.48 278.95 4,525.37 4,384.58 971.82 -4,183.09 5,949,963.26 483,636.84 0.47 4,216.72 MWD+IFR-AK-CAZ-SC(3) 6,964.94 61.11 279.07 4,571.13 4,430.34 984.91 -4,265.61 5,949,976.48 483,554.34 0.40 4,297.42 MWD+IFR-AK-CAZ-SC(3) 7,060.29 61.28 278.91 4,617.07 4,476.28 997.96 -4,348.13 5,949,989.67 483,471.85 0.23 4,378.13 MWD+IFR-AK-CAZ-SC(3) 7,155.00 61.31 279.05 4,662.56 4,521.77 1,010.93 -4,430.19 5,950,002.77 483,389.83 0.13 4,458.36 MWD+IFR-AK-CAZ-SC(3) 7,250.96 61.13 278.45 4,708.76 4,567.97 1,023.72 -4,513.31 5,950,015.69 483,306.73 0.58 4,539.50 MWD+IFR-AK-CAZ-SC(3) 7,344.69 61.24 278.20 4,753.93 4,613.14 1,035.62 -4,594.57 5,950,027.71 483,225.50 0.26 4,618.57 MWD+IFR-AK-CAZ-SC(3) 7,440.16 61.16 276.89 4,799.93 4,659.14 1,046.60 -4,677.51 5,950,038.83 483,142.59 1.21 4,698.80 MWD+IFR-AK-CAZ-SC(3) 7,534.31 61.18 277.46 4,845.33 4,704.54 1,056.90 -4,759.34 5,950,049.27 483,060.78 0.53 4,777.75 MWD+IFR-AK-CAZ-SC(3) 7,629.36 59.83 278.48 4,892.13 4,751.34 1,068.37 -4,841.27 5,950,060.86 482,978.88 1.70 4,857.26 MWD+IFR-AK-CAZ-SC(3) 7,723.76 58.74 278.78 4,940.34 4,799.55 1,080.54 -4,921.51 5,950,073.17 482,898.67 1.19 4,935.52 MWD+IFR-AK-CAZ-SC(3) 7,819.01 56.17 279.04 4,991.58 4,850.79 1,092.98 -5,000.82 5,950,085.73 482,819.38 2.71 5,013.03 MWD+IFR-AK-CAZ-SC(3) 7,914.03 53.17 278.26 5,046.52 4,905.73 1,104.64 -5,077.45 5,950,097.52 482,742.78 3.23 5,087.78 MWD+IFR-AK-CAZ-SC(3) 8,007.85 51.39 276.56 5,103.92 4,963.13 1,114.23 -5,151.04 5,950,107.22 482,669.22 2.38 5,158.90 MWD+IFR-AK-CAZ-SC(3) 8,102.97 50.54 276.45 5,163.83 5,023.04 1,122.60 -5,224.44 5,950,115.71 482,595.83 0.90 5,229.37 MIND+IFR-AK-CAZSC(3) 8,198.21 49.67 276.42 5,224.91 5,084.12 1,130.79 -5,297.05 5,950,124.01 482,523.24 0.91 5,299.03 MWD+IFR-AK-CAZ-SC(3) 8,294.82 46.98 275.86 5,289.14 5,148.35 1,138.51 -5,368.79 5,950,131.85 482,451.52 2.82 5,367.71 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:30:18PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°l (usft) (usft) (usft) (usft) (ft) (ft) r1100') (ft) Survey Tool Name 8,387.38 43.73 273.79 5,354.18 5,213.39 1,144.08 -5,434.39 5,950,137.53 482,385.93 3.85 5,429.91 MWD+IFR-AK-CAZ-SC(3) 8,482.21 41.97 271.80 5,423.70 5,282.91 1,147.25 -5,498.80 5,950,140.80 482,321.54 2.34 5,490.03 MWD+IFR-AK-CAZ-SC(3) 8,576.61 44.49 272.85 5,492.48 5,351.69 1,149.88 -5,563.40 5,950,143.54 482,256.95 2.78 5,550.11 MWD+IFR-AK-CAZ-SC(3) 8,670.39 46.53 275.16 5,558.20 5,417.41 1,154.58 -5,630.12 5,950,148.34 482,190.25 2.80 5,612.98 MWD+IFR-AK-CAZ-SC(3) 8,765.77 47.70 275.56 5,623.11 5,482.32 1,161.11 -5,699.70 5,950,154.98 482,120.68 1.26 5,679.20 MWD+IFR-AK-CAZ-SC(3) 8,858.75 50.04 277.12 5,684.27 5,543.48 1,168.86 -5,769.29 5,950,162.84 482,051.11 2.82 5,745.93 MWD+IFR-AK-CAZ-SC(3) 8,954.12 52.60 277.87 5,743.87 5,603.08 1,178.58 -5,843.10 5,950,172.68 481,977.33 2.75 5,817.31 MWD+IFR-AK-CAZ-SC(3) 9,048.20 56.63 279.49 5,798.34 5,657.55 1,190.18 -5,918.90 5,950,184.40 481,901.55 4.51 5,891.27 MWD+IFR-AK-CAZ-SC(3) 9,142.26 60.87 280.61 5,847.12 5,706.33 1,204.22 -5,998.05 5,950,198.58 481,822.43 4.62 5,969.30 MWD+IFR-AK-CAZ-SC(3) 9,196.46 63.59 281.11 5,872.37 5,731.58 1,213.26 -6,045.15 5,950,207.69 481,775.35 5.08 6,015.99 MWD+IFR-AK-CAZSC(3) 9,236.74 65.56 281.54 5,889.66 5,748.87 1,220.40 -6,080.82 5,950,214.89 481,739.70 4.98 6,051.49 MWD+IFR-AK-CAZSC(3) 9,330.91 69.18 281.94 5,925.89 5,785.10 1,238.09 -6,165.90 5,950,232.71 481,654.65 3.86 6,136.41 MWD+IFR-AK-CAZ-SC(3) 9,379.30 71.48 283.57 5,942.18 5,801.39 1,248.15 -6,210.34 5,950,242.85 481,610.24 5.71 6,181.10 MWD+lFR-AK-CAZSC(3) 9,425.44 73.66 284.20 5,956.00 5,815.21 1,258.72 -6,253.07 5,950,253.48 481,567.53 4.90 6,224.43 MWD+iFR-AK-CAZSC(3) 9,476.88 76.65 285.87 5,969.18 5,828.39 1,271.62 -6,301.08 5,950,266.46 481,519.54 6.61 6,273.54 MWD+IFR-AK-CAZSC(3) 9,518.00 77.72 287.29 5,978.30 5,837.51 1,283.06 -6,339.51 5,950,277.96 481,481.13 4.26 6,313.30 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 9,553.48 78.65 288.51 5,985.57 5,844.78 1,293.74 -6,372.56 5,950,288.69 481,448.11 4.26 6,347.83 MWD+IFR-AK-CAZSC(4) 9,594.43 79.30 287.33 5,993.40 5,852.61 1,306.11 -6,410.80 5,950,301.12 481,409.89 3.24 6,387.80 MWD+IFR-AK-CAZ-SC(4) 9,632.60 79.70 285.84 6,000.35 5,859.56 1,316.82 -6,446.77 5,950,311.89 481,373.94 3.98 6,425.01 MWD+IFR-AK-CAZ-SC(4) 9,727.57 80.50 286.78 6,016.68 5,875.89 1,343.09 -6,536.56 5,950,338.30 481,284.21 1.29 6,517.73 MWD+IFR-AK-CAZ-SC(4) 9,822.18 81.40 286.15 6,031.56 5,890.77 1,369.57 -6,626.16 5,950,364.93 481,194.66 1.16 6,610.35 MWD+1FR-AK-CAZSC(4) 9,917.09 82.37 285.50 6,044.96 5,904.17 1,395.19 -6,716.55 5,950,390.69 481,104.31 1.23 6,703.35 MWD+IFR-AK-CAZ-SC(4) 10,012.21 83.19 286.27 6,056.92 5,916.13 1,421.02 -6,807.31 5,950,416.66 481,013.60 1.18 6,796.77 MWD+IFR-AK-CAZ-SC(4) 10,107.07 85.78 285.91 6,066.03 5,925.24 1,447.19 -6,898.03 5,950,442.97 480,922.94 2.76 6,890.29 MWD+IFR-AK-CAZ-SC(4) 10,201.59 87.52 285.86 6,071.55 5,930.76 1,473.01 -6,988.78 5,950,468.94 480,832.24 1.84 6,983.70 MWD+IFR-AK-CAZSC(4) 10,296.66 90.64 285.79 6,073.08 5,932.29 1,498.93 -7,080.22 5,950,495.01 480,740.85 3.28 7,077.78 MVD+IFR-AK-CAZ-SC(4) 10,391.75 91.10 286.25 6,071.64 5,930.85 1,525.17 -7,171.61 5,950,521.39 480,649.51 0.68 7,171.93 MWD+IFR-AK-CAZ-SC(4) 10,486.63 90.45 286.12 6,070.35 5,929.56 1,551.62 -7,262.72 5,950,547.98 480,558.45 0.70 7,265.92 MW3.+iFR-AK-CAZ-SC(4) 10,581.22 89.97 286.44 6,070.01 5,929.22 1,578.13 -7,353.52 5,950,574.64 480,467.71 0.61 7,359.66 MWD+iFR-AK-CAZ-SC(4) 10,676.50 89.52 290.25 6,070.43 5,929.64 1,608.11 -7,443.94 5,950,604.77 480,377.35 4.03 7,454.45 MW0+iFR-AK-CAZ-SC(4) 10,771.03 89.87 291.23 6,070.93 5,930.14 1,641.59 -7,532.34 5,950,638.38 480,289.01 1.10 7,548.83 MIND+iFR-AK-CAZ-SC(4) 10,865.50 90.35 293.64 6,070.75 5,929.96 1,677.64 -7,619.65 5,950,674.57 480,201.76 2.60 7,643.25 MWD+IFR-AK-CAZ-SC(4) 10,960.54 91.17 295.97 6,069.49 5,928.70 1,717.50 -7,705.91 5,950,714.57 480,115.58 2.60 7,738.27 MWD+IFR-AK-CAZ-SC(4) 11,056.15 91.24 296.74 6,067.48 5,926.69 1,759.94 -7,791.56 5,950,757.14 480,030.00 0.81 7,833.78 MND+IFR-AK-CAZ-SC(4) 11,150.66 91.24 296.85 6,065.44 5,924.65 1,802.53 -7,875.90 5,950,799.87 479,945.74 0.12 7,928.15 MWD+IFR-AK-CAZ-SC(4) 11,254.24 91.17 296.19 6,063.26 5,922.47 1,848.77 -7,968.56 5,950,846.25 479,853.16 0.6.4 8,031.61 MWD+IFR-AK-CAZSC(4) 11,346.37 91.27 295.72 6,061.30 5,920.51 1,889.09 -8,051.38 5,950,886.69 479,770.42 0.52 8,123.66 MWD+1FR-AK-CAZSC(4) 11,434.62 91.51 293.60 6,059.16 5,918.37 1,925.89 -8,131.56 5,950,923.63 479,690.31 2.42 8,211.88 MWD+IFR-AK-CAZ-SC(4) 11,528.89 91.62 293.26 6,056.58 5,915.79 1,963.36 -8,218.02 5,950,961.23 479,603.92 0.38 8,306.11 MWD+IFR-AK-CAZ-SC(4) 1/13/2015 12:30:18PM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36 Survey Calculation Method: Minimum Curvature Design: 2M-36 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Az! TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (01100') (ft) Survey Tool Name 11,623.97 87.64 292.47 6,057.19 5,916.40 2,000.30 -8,305.61 5,950,998.31 479,516.40 4.27 8,401.15 MWD+IFR-AK-CA2-SC(4) 11,716.10 87.53 294.22 6,061.08 5,920.29 2,036.77 -8,390.12 5,951,034.92 479,431.95 1.90 8,493.19 MWD+IFR-AK-CAZ-SC(4) 11,811.37 88.49 296,46 6,064.39 5,923.60 2,077.52 -8,476.16 5,951,075.80 479,345.98 2.56 8,588.36 MWD+IFR-AK-CAZ-SC(4) 11,908.96 89.01 296.72 6,066.51 5,925.72 2,121.19 -8,563.41 5,951,119.61 479,258.82 0.60 8,685.83 MWD+IFR-AK-CAZ-SC(4) 12,003.61 89.04 298.20 6,068.13 5,927.34 2,164.83 -8,647.38 5,951,163.38 479,174.92 1.56 8,780.29 MWD+IFR-AK-CAZ-SC(4) 12,098.06 89.32 298.02 6,069.48 5,928.69 2,209.33 -8,730.68 5,951,208.00 479,091.70 0.35 8,874.49 MWD+IFR-AK-CAZ-SC(4) 12,193.90 89.80 296.40 6,070.21 5,929.42 2,253,15 -8,815.91 5,951,251.96 479,006.55 1.76 6,970.17 MW3+IFR-AK-CAZSC(4) 12,288.37 90.83 294.01 6,069.69 5,928.90 2,293.38 -8,901.38 5,951,292.32 478,921.16 2.75 9,064.61 MWD+IFR-AK-CAZ-SC(4) 12,380.84 91.55 292.53 6,067.77 5,926.98 2,329.90 -8,986.30 5,951,328.97 478,836.30 1.78 9,157.05 MWD+IFR-AK-CAZ-SC(4) 12,477.63 92.95 290.02 6,063.97 5,923.18 2,364.99 -9,076.42 5,951,364.21 478,746.25 2.97 9,253.65 MW3+IFR-AK-CAZ-SC(4) 12,566.48 93.77 291.00 6,058.76 5,917.97 2,396.06 -9,159,49 5,951,395.41 478,663.24 1.44 9,342.18 MWD+IFR-AK-CAZ-SC(4) 12,663.95 94.51 291.63 6,051.73 5,910.94 2,431.40 -9,250.06 5,951,430.89 478,572.74 1.00 9,439.29 MWD+IFR-AK-CAZ-SC(4) 12,760.21 93.28 292.10 6,045.19 5,904.40 2,467.17 -9,339.18 5,951,466.80 478,483.68 1.37 9,535.26 MWD+IFR-AK-CAZ-SC(4) 12,855.41 94.19 292.97 6,038.99 5,898.20 2,503.57 -9,426.93 5,951,503.35 478,396.01 1.32 9,630.22 MWD+IFR-AK-CAZSC(4) 12,953.64 95.18 293.02 6,030.96 5,890.17 2,541.82 -9,517.05 5,951,541.73 478,305.96 1.01 9,728.11 MWD+iFR-AK-CAZSC(4) 12,993.00 95.18 293.02 6,027.41 5,886.62 2,557.15 -9,553.13 5,951,557.12 478,269.91 0.00 9,767.30 PROJECTED to TD 4112"x6-112" 13,013.00 95.18 293.02 6,025.61 5,884.82 2,564.94 -9,571.46 5,951,564.94 478,251.59 0.00 9,787.21 PROJECTED to TD Projected to TD 1/13/2015 12:30:18PM Page 6 COMPASS 5000.1 Build 65 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-36PB1 Definitive Survey Report N A D 2 7 13 January, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36©140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2M-36 Well Position +N/-S 0.00 usft Northing: 5,948,984.77 usft Latitude: 70°16'18.567 N +E/-W 0.00 usft Easting: 487,817.93 usft Longitude: 150°5 54.693 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-36PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°l (nT) BGG M2014 11/7/2014 18.97 80.84 57,564 Design 2M-36PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.49 Vertical Section: Depth From(TVD) +NI-S +EI W Direction (usft) (usft) (usft) (°) 39.49 0.00 0.00 294.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 97.00 1,130.00 2M-36PB1 Srvy#1-GYD-GC-MS(2M-3 GYD-GC-MS Gyrodata gyrocompassing m/s 11/11/2014 5:57 1,189.55 3,270.06 2M-36PB1 Srvy#2-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/11/2014 6:00 3,342.00 7,954.98 2M-36PB1 Srvy#3-MWD+IFR-AK-CAZ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/25/2014 11:0: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°I (°) (usft) (usft) (usft) (usft) (ft) (ft) r/100') (ft) Survey Tool Name 39.49 0.00 0.00 39.49 -101.30 0.00 0.00 5,948,984.77 487,817.93 0.00 0.00 UNDEFINED 97.00 0.40 256.40 97.00 -43.79 -0.05 -0.20 5,948,984.72 487,817.73 0.70 0.16 GYD-GC-MS(1) 188.00 0.66 258.57 188.00 47.21 -0.23 -1.02 5,948,984.54 487,816.91 0.29 0.84 GYD-GC-MS(1) 278.00 1.50 353.59 277.98 137.19 0.84 -1.66 5,948,985.61 487,816.27 1.88 1.86 GYD-GC-MS(1) 374.00 1.57 3.93 373.95 233.16 3.40 -1.71 5,948,988.17 487,816.22 0.30 2.94 GYD-GC-MS(1) 470.00 3.33 343.60 469.86 329.07 7.39 -2.40 5,948,992.16 487,815.53 2.02 5.20 GYD-GC-MS(1) 564.00 3.91 343.60 563.67 422.88 13.08 -4.08 5,948,997.86 487,813.87 062 9.05 GYD-GC-MS(1) 657.00 4.61 349.66 656.41 515.62 19.80 -5.65 5,949,004.58 487,812.31 0.89 13.21 GYD-GC-MS(1) 753.00 6.06 352.48 752.00 611.21 28.62 -7.00 5,949,013.40 487,810.97 1.53 18.04 GYD-GC-MS(1) 847.00 8.16 349.61 845.27 704.48 40.10 -8.85 5,949,024.88 487,809.14 2.27 24.40 GYD-GC-MS(1) 943.00 11.06 345.45 939.91 799.12 55.72 -12.40 5,949,040.50 487,805.62 3.10 33.99 GYD-GC-MS(1) 1,037.00 11.05 339.54 1,032.17 891.38 72.89 -17.81 5,949,057.68 487,800.23 1.21 45.92 GYD-GC-MS(1) 1/13/2015 12:39:51PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36 @ 140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36 @ 140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,130.00 11.98 340.75 1,123.30 982.51 90.35 -24.11 5,949,075.15 487,793.97 1.03 58.77 GYD-GC-MS(1) 1,189.55 12.88 341.70 1,181.45 1,040.66 102.49 -28.23 5,949,087.29 487,789.86 1.55 67.48 MWD+IFR-AK-CAZ-SC(2) 1,284.12 15.84 341.23 1,273.06 1,132.27 124.72 -35.70 5,949,109.53 487,782.44 3.13 83.34 MWD+IFR-AK-CAZ-SC(2) 1,379.49 18.29 338.03 1,364.22 1,223.43 150.93 -45.48 5,949,135.75 487,772.69 2.75 102.94 MW3+IFR-AK-CAZ-SC(2) 1,473.73 18.90 334.84 1,453.55 1,312.76 178.46 -57.51 5,949,163.30 487,760.72 1.26 125.12 MWD+IFR-AK-CAZ-SC(2) 1,567.09 20.43 332.70 1,541.46 1,400.67 206.62 -71.41 5,949,191.49 487,746.86 1.81 149.28 MW3+IFR-AK-CAZ-SC(2) 1,661.80 22.52 326.67 1,629.60 1,488.81 236.47 -88,96 5,949,221.36 487,729.36 3.21 177.45 M1ND+IFR-AK-CAZ-SC(2) 1,756.34 24.83 319.91 1,716.19 1,575,40 266.80 -111.70 5,949,251.72 487,706.67 3.77 210.56 MWD+IFR-AK-CAZ-SC(2) 1,851.38 25.64 313.44 1,802.18 1,661.39 296.21 -139.48 5,949,281.17 487,678.94 3.02 247.90 MWD+IFR-AK-CAZ-SC(2) 1,947.09 27.21 304.48 1,887.92 1,747.13 322.85 -172.57 5,949,307.86 487,645.89 4.47 288.97 M1M3+IFR-AK-CAZ-SC(2) 2,040.24 28.97 298.65 1,970.11 1,829.32 3.45.72 -209.94 5,949,330.80 487,608.57 3.50 332.40 MWD+IFR-AK-CAZ-SC(2) 2,134.21 30.55 295.28 2,051.69 1,910.90 366.84 -251.51 5,949,351.97 487,567.04 2.45 378.97 MWD+IFR-AK-CAZ-SC(2) 2,230.79 32.20 291.54 2,134.15 1,993.36 386.77 -297.64 5,949,371.98 487,520.94 2.64 429.23 MWD+IFR-AK-CAZ-SC(2) 2,323.31 34.82 286.65 2,211.30 2,070.51 403.39 -345.90 5,949,388.68 487,472.72 4.06 480.07 MWD+IFR-AK-CAZ-SC(2) 2,421.48 38.39 285.23 2,290.10 2,149.31 419.44 -402.18 5,949,404.81 487,416.46 3.74 538.01 M1N0+1FR-AK-CAZ-SC(2) 2,516.85 41.43 283.48 2,363.25 2,222.46 434.58 -461.45 5,949,420.05 487,357.22 3.40 598.32 MWD+IFR-AK-CAZ-SC(2) 2,607.79 45.83 283.41 2,429.05 2,288.26 4.49.16 -522.47 5,949,434.73 487,296.24 4.84 659.99 MWD+IFR-AK-CAZ-SC(2) 2,702.41 48.87 282.96 2,493.15 2,352.36 465.03 -590.22 5,949,450.70 487,228.52 3.23 728.34 MW3+IFR-AK-CAZ-SC(2) 2,753.16 52.41 283.63 2,525.33 2,384.54 474.05 -628.40 5,949,459.79 487,190.36 7.05 766.89 MWD+IFR-AK-CAZ-SC(2) 2,796.75 53.90 282.80 2,551.47 2,410.68 482.03 -662.36 5,949,467.82 487,156.41 3.74 801.15 MWD+IFR-AK-CAZ-SC(2) 2,892.13 56.55 278.98 2,605.88 2,465.09 496.78 -739.27 5,949,482.69 487,079.53 4.31 877.42 MWD+iFR-AK-CAZ-SC(2) 2,985.78 58.27 278.81 2,656.32 2,515.53 508.98 -817.22 5,949,495.02 487,001.61 1.84 953.59 MWD+IFR-AK-CAZ-SC(2) 3,080.36 59.34 278.31 2,705.31 2,564.52 521.02 -897.23 5,949,507.19 486,921.63 1.22 1,031.57 M1MD+IFR-AK-CAZSC(2) 3,174.51 59.40 276.62 2,753.28 2,612.49 531.54 -977.55 5,949,517.84 486,841.34 1.55 1,109.23 MWD+IFR-AK-CAZ-SC(2) 3,270.06 60.47 275.76 2,801.15 2,660.36 540.46 -1,059.76 5,949,526.89 486,759.15 1.36 1,187.96 MWD+IFR-AK-CAZ-SC(2) 3,342.00 60.79 276.41 2,836.43 2,695.64 547.10 -1,122.10 5,949,533.63 486,696.83 0.90 1,247.61 MWD+IFR-AK-CAZ-SC(3) 10-3/4"x 13-1/2" 3,424.27 61.17 277.15 2,876.34 2,735.55 555.60 -1,193.54 5,949,542.24 486,625.41 0.91 1,316.33 MWD+IFR-AK-CAZ-SC(3) 3,520.07 60.04 276.87 2,923.36 2,782.57 565.78 -1,276.38 5,949,552.56 486,542.60 1.21 1,396.15 MWD+IFR-AK-CAZSC(3) 3,613.34 60.17 276.52 2,969.85 2,829.06 575.21 -1,356.68 5,949,562.12 486,462.31 0.35 1,473.35 MWD+IFR-AK-CAZSC(3) 3,707.67 59.95 274.99 3,016.93 2,876.14 583.41 -1,438.01 5,949,570.44 486,381.01 1.42 1,550.98 MWD+IFR-AK-CAZSC(3) 3,802.22 60.28 271.05 3,064.06 2,923.27 587.72 -1,519.85 5,949,574.89 486,299.18 3.63 1,627.50 MWD+IFR-AK-CAZ-SC(3) 3,896.49 60.24 275.31 3,110.84 2,970.05 592.26 -1,601.55 5,949,579.56 486,217.50 3.92 1,703.98 MWD+IFR-AK-CAZSC(3) 3,991.21 60.15 274.67 3,157.92 3,017.13 599.41 -1,683.43 5,949,586.84 486,135.64 0.59 1,781.69 MWD+IFR-AK-CAZSC(3) 4,084.96 59.46 274.71 3,205.07 3,064.28 606.03 -1,764.19 5,949,593.60 486,054.90 0.74 1,858.16 MWD+iFR-AK-CAZSC(3) 4,179.37 58.02 274.98 3,254.06 3,113.27 612.85 -1,844.60 5,949,600.54 485,974.51 1.54 1,934.39 MWD+iFR-AK-CAZ-SC(3) 4,274.00 58.03 274.34 3,304.17 3,163.38 619.37 -1,924.60 5,949,607.19 485,894.52 0.57 2,010.14 MWD+IFR-AK-CAZSC(3) 4,368.13 58.37 273.92 3,353.77 3,212.98 625.13 -2,004.40 5,949,613.08 485,814.74 0.52 2,085.37 MWD+IFR-AK-CAZ-SC(3) 4,463.12 58.28 276.50 3,403.66 3,262,87 632.47 -2,084.89 5,949,620.55 485,734.27 2.31 2,161.89 MWD+IFR-AK-CAZ-SC(3) 4,557.40 57.67 281.18 3,453.67 3,312.88 644.74 -2,163.84 5,949,632.94 485,655.35 4.26 2,239.01 MWD+IFR-AK-CAZ-SC(3) 1/13/2015 12:39:51PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-36 Project: Kuparuk River Unit TVD Reference: 2M-36©140.79usft(Doyon 25) Site: Kuparuk 2M Pad MD Reference: 2M-36©140.79usft(Doyon 25) Well: 2M-36 North Reference: True Wellbore: 2M-36PB1 Survey Calculation Method: Minimum Curvature Design: 2M-36PB1 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) 01001 (ft) Survey Tool Name 4,652.38 57.68 281.22 3,504.46 3,363.67 660.33 -2,242.58 5,949,648.66 485,576.65 0.04 2,317.27 MWD+IFR-AK-CAZ-SC(3) 4,746.36 56.95 281.53 3,555.21 3,414.42 675.93 -2,320.12 5,949,664.38 485,499.14 0.82 2,394.46 MW3+IFR-AK-CAZ-SC(3) 4,841.02 56.91 279.21 3,606.87 3,466.08 690.21 -2,398.14 5,949,678.78 485,421.15 2.05 2,471.54 MWD+1FR-AK-CAZ-SC(3) 4,935.41 57.16 277.37 3,658.23 3,517.44 701.62 -2,476.50 5,949,690.33 485,342.81 1.66 2,547.77 MWD+IFR-AK-CAZ-SC(3) 5,030.19 56.98 277.88 3,709,76 3,568.97 712.18 -2,555.35 5,949,701.01 485,263.99 0.49 2,624.10 MWD+1FR-AK-CAZ-SC(3) 5,123.88 57.16 279.40 3,760.69 3,619.90 723.99 -2,633.09 5,949,712.95 485,186.27 1.38 2,699.92 MW2+IFR-AK-CAZ-SC(3) 5,220.50 57.02 278.75 3,813.19 3,672.40 736.78 -2,713.19 5,949,725.87 485,106.20 0.58 2,778.30 MWD+IFR-AK-CAZ-SC(3) 5,315.07 56.67 276.72 3,864.91 3,724.12 747.44 -2,791.64 5,949,736.65 485,027.78 1.83 2,854.30 M1D+IFR-AK-CAZ-SC(3) 5,409.46 57.07 276.79 3,916.50 3,775.71 756.74 -2,870.13 5,949,746.08 484,949.31 0.43 2,929.79 MWD+1FR-AK-CAZ-SC(3) 5,502.89 57.51 278.55 3,966.99 3,826.20 767.23 -2,948.04 5,949,756.70 484,871.43 1.65 3,005.23 MWD+1FR-AK-CAZSC(3) 5,597.53 57.88 278.51 4,017.57 3,876.78 779.10 -3,027.14 5,949,768.69 484,792.35 0.39 3,082.32 MWD+IFR-AK-CAZSC(3) 5,692.74 57.65 278.55 4,068.35 3,927.56 791.05 -3,106.79 5,949,780.76 484,712.73 0.24 3,159.94 MWD+IFR-AK-CAZ-SC(3) 5,787.06 57.52 277.27 4,118.91 3,978.12 802.00 -3,185.65 5,949,791.85 484,633.90 1.15 3,236.44 MWD+1FR-AK-CA2-SC(3) 5,882.36 58.02 275.80 4,169.74 4,028.95 811.17 -3,265.74 5,949,801.15 484,553.83 1.41 3,313.34 MWD+1FR-AK-CAZ-SC(3) 5,975.67 58.19 274.51 4,219.04 4,078.25 818.29 -3,344.64 5,949,808.39 484,474.95 1.19 3,388.31 MWD+1FR-AK-CAZSC(3) 6,070.59 57.93 275.44 4,269.26 4,128.47 825.28 -3,424.88 5,949,815.50 484,394.73 0.88 3,464.46 MWD+IFR-AK-CAZ-SC(3) 6,163.74 57.76 276.33 4,318.84 4,178.05 833.36 -3,503.33 5,949,823.71 484,316.30 0.83 3,539.41 MWD+IFR-AK-CAZSC(3) 6,259.40 57.68 277.62 4,369.93 4,229.14 843.18 -3,583.60 5,949,833.66 484,236.05 1.14 3,616.74 MWD+IFR-AK-CAZ-SC(3) 6,355.75 57.98 277.23 4,421.23 4,280.44 853.72 -3,664.48 5,949,844.33 484,155.20 0.46 3,694.90 MWD+IFR-AK-CAZSC(3) 6,448.76 57.97 276.35 4,470.55 4,329.76 863.04 -3,742.78 5,949,853.78 484,076.93 0.80 3,770.23 MWD+1FR-AK-CAZ-SC(3) 6,543.72 57.81 274.98 4,521.03 4,380.24 870.98 -3,822.81 5,949,861.85 483,996.91 1.23 3,846.58 MWD+IFR-AK-CAZ-SC(3) 6,638.29 57.79 275.13 4,571.42 4,430.63 878.04 -3,902.53 5,949,869.03 483,917.21 0.14 3,922.27 MWD+IFR-AK-CAZ-SC(3) 6,733.97 58.24 276.29 4,622.10 4,481.31 886.11 -3,983.28 5,949,877.24 483,836.49 1.13 3,999.32 MWD+1FR-AK-CAZSC(3) I 6,829.05 57.75 278.26 4,672.50 4,531.71 896.32 -4,063.25 5,949,887.57 483,756.54 1.83 4,076.53 MWD+IFR-AK-CAZ-SC(3) 6,924.07 57.37 279.25 4,723.47 4,582,68 908.52 -4,142.51 5,949,899.90 483,677.31 0.97 4,153.90 MWD+IFR-AK-CAZ-SC(3) 7,018.49 57.20 279.04 4,774.50 4,633.71 921.15 -4,220.94 5,949,912.65 483,598.91 0.26 4,230.68 MWD+1FR-AK-CAZ-SC(3) 7,113.16 57.26 279.81 4,825.74 4,684.95 934.18 -4,299.47 5,949,925.81 483,520.41 0.69 4,307.72 MWD+IFR-AK-CAZ-SC(3) I 7,207.19 57.32 279.53 4,876.56 4,735.77 947.47 -4,377.46 5,949,939.23 483,442.44 0.26 4,384.38 MWD+IFR-AK-CAZ-SC(3) 7,303.81 57.39 279.86 4,928.68 4,787.89 961.17 -4,457.66 5,949,953.06 483,362.28 0.30 4,463.22 MWD+IFR-AK-CAZ-SC(3) 7,397.65 57.32 279.86 4,979.30 4,838.51 974.70 -4,535.50 5,949,966.71 483,284.46 0.07 4,539.84 MW0+IFR-AK-CAZ-SC(3) 7,494.11 57.35 279.00 5,031.36 4,890.57 988.01 -4,615.61 5,949,980.15 483,204.38 0.75 4,618.43 MWD+IFR-AK-CAZSC(3) 7,584.37 57.28 278.07 5,080.10 4,939.31 999.28 -4,690.73 5,949,991.54 483,129.28 0.87 4,691.64 MWD+1FR-AK-CAZ-SC(3) 7,682.29 56.83 277.39 5,133.35 4,992.56 1,010.34 -4,772.16 5,950,002.73 483,047.88 0.74 4,770.53 MWD+1FR-AK-CAZ-SC(3) 7,776.52 57.36 276.01 5,184.55 5,043.76 1,019.56 -4,850.73 5,950,012.08 482,969.34 1.35 4,846.06 MWD+1FR-AK-CAZ-SC(3) 7,873.41 57.14 276.99 5,236.96 5,096.17 1,028.79 -4,931.69 5,950,021.43 482,888.40 0.88 4,923.77 MWD+IFR-AK-CAZ-SC(3) l 7,954.98 57.12 276.69 5,281.23 5,140.44 1,036.95 -4,999.72 5,950,029.70 482,820.39 0.31 4,989.23 MWD+IFR-AK-CAZ-SC(3) 8,018.00 57.12 276.69 5,315.44 5,174.65 1,043.11 -5,052.28 5,950,035.95 482,767.84 0.00 5,039.76 PROJECTED to TD Projected to Bit 1/13/2015 12:39:51PM Page 4 COMPASS 5000.1 Build 65 06 Cement Detail Report ►a41110 0 2M-36 ConocoPhillips String: Conductor Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor 2M-36 Comment 16"conductor pipe was driven on 10/11/2014 to 131'. No cement. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 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) Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/20/2015 OS% Cement Detail Report 2M-36 Cort String: Surface Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface 11/16/2014 03:30 11/16/2014 09:11 2M-36 Comment Pressure test cement lines to 400 psi. Pump 50 bbls CW100,4.5 bpm,400 psi,8.4 ppg. Pump 50 bbls Mud Push Ilm 3.0 bpm,409 psi. Drop bottom plug and pump 479 bbls lead cement, 5 bpm,327 psi, 10.7-11.0 ppg. Pump 56.3 bbls of tail cement,3.3 bpm,66-160 psi, 12.0 ppg. Drop top plug and pump 10 bbls of water to kick out plug and wash lines.Switch over to rig pumps to displace cement with mud,6.7 bpm,283 psi.Could not keep rig pumps primed and switch over to SLB to displace,6.8 bpm,550 psi.Slow down to 2 bpm, bump plug at 09:11 hrs. Hold 1060 psi for 5 minutes,bleed pressure off and check floats,floats good. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface 2.5 3,342.0 No No No Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 6 6 550.0 1,060.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Drill Bit 9 7/8 Comment Pressure test cement lines to 400 psi. Pump 50 bbls CW100,4.5 bpm,400 psi,8.4 ppg. Pump 50 bbls Mud Push Ilm 3.0 bpm,409 psi.Drop bottom plug and pump 479 bbls lead cement,5 bpm,327 psi, 10.7-11.0 ppg. Pump 56.3 bbls of tail cement,3.3 bpm,66-160 psi, 12.0 ppg. Drop top plug and pump 10 bbls of water to kick out plug and wash lines. Switch over to rig pumps to displace cement with mud,6.7 bpm,283 psi.Could not keep rig pumps primed and switch over to SLB to displace,6.8 bpm,550 psi.Slow down to 2 bpm, bump plug at 09:11 hrs. Hold 1060 psi for 5 minutes,bleed pressure off and check floats,floats good. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW100 50.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.40 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mudpushll Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead cement 0.0 2,800.0 1,360 G 479.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail 2,800.0 3,342.0 194 G 56.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.63 5.48 12.00 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? Surface No No No Q Pump Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 2,800.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Page 1/2 Report Printed: 1/20/2015 Cement Detail Report 03142M-36 Conoc AL String: Surface Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Mud 0.0 900.0 10.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 9.00 Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 1/20/2015 Cement Detail Report 038 2M-36 C=onocoPhilhps M1LnF� String: Isolation plug#1 Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Isolation plug#1 12/1/2014 13:00 12/1/2014 15:30 2M-36 PB1 Comment Pumped 30 bbl 12.5 ppg Mud Push II,84.9 bbl 15.8 ppg Cement with GasBlok and 2 ppb Cemnet,follow with 4.6 bbl 12.5 MudPush, under displace with115.5 bbl 10.8 ppg mud. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Isolation plug#1 Cement off loss zone 7,378.0 8,018.0 No 0.0 No No Q Pump nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 270.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 30 bbl 12.5 ppg Mud Push II, 84.9 bbl 15.8 ppg Cement with GasBlok and Cement,follow with 4.6 bbl 12.5 MudPush, under displace with115.5 bbl 10.8 ppg mud. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 7,378.0 8,018.0 407 G 84.9 Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.21 15.80 134.0 11.75 Additives Additive Type Concentration Conc Unit label Lost Circulation Additive(Kolite) CEMNET 2.0 lbs/bbl Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.45 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 1/1 Report Printed: 1/20/2015 01111 Cement Detail Report 2M-36 conocOphops A6xka String: Isolation Plug#2 Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Isolation Plug#2 12/3/2014 11:00 12/3/2014 12:30 2M-36 PB1 Comment Pumped 30 bbl 12.5 ppg Mud Push II, 84.9 bbl 15.8 ppg Cement with GasBlok and 2 ppb Cemnet,follow with 4.6 bbl 12.5 MudPush, under displace with102 bbl 10.8 ppg mud. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Isolation Plug#2 6,748.0 7,374.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) 'Rotated? Pipe RPM(rpm) 3 3 3 220.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment SLB pumped 5 bbl water, PT line to 4000 psi-good. Line up and pump 30 bbl 12.5 ppg MudPush II.Shut down,close annular and break off head pin, load wiper ball. Open annular and SLB pump 85 bbl 17.0 ppg Cement with 2 ppb Cemnet and 2 gal/sx GasBlok @ 3 bpm,chase with 4.6 bbl MudPush II 12.5 ppg, displaced by rig with 102 bbl 10.8 ppg mud @ 8 bpm,200 psi,25%flow,reducing to 3 bpm, 111 psi,20%flow.Total 1017 strokes pumped. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 6,748.0 7,374.0 407 G 84.9 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.21 15.80 134.0 11.75 Additives Additive Type Concentration Conc Unit label Lost Circulation Additive CEMNET 2.0 lbs/bbl Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.45 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.1 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 1/1 Report Printed: 1/20/2015 Cement Detail Report 0.;; -2,, 2M-36 ConocoPhillips String: Plug#3 Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Plug#3 12/3/2014 20:00 12/3/2014 21:30 2M-36 PB1 Comment Pumped 30 bbl 12.5 ppg Mud Push II,85.3 bbl 17.0 ppg Cement with 2 ppb Cemnet,follow with 4.6 bbl 12.5 MudPush,under displace with 90 bbl 10.8 ppg mud. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Kickoff plug 6,210.0 6,748.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 179.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6,351.0 Tubing Comment SLB pumped 5 bbl water, PT line to 4000 psi-good. Pumped 30 bbl 12.5 ppg MudPush II,shut down and close annular. Break head pin and load wiper ball. Open annular,SLB pumped 85 bbl 17.0 ppg cement with 2 ppb Cemnet @ 3 bpm,chased with 4.6 bbl MudPush II. Rig displaced with 90 bbl 10.8 ppg mud @ 8 bpm initial 165 psi until pressure started building,then decreased to 3 bpm-179 psi @ 902 stks. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement _ 6,210.0 6,748.0 478 G 85.3 Yield(fe/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.00 3.87 17.00 132.0 11.50 Additives Additive Type Concentration Conc Unit label Lost Circulation Additive Cemnet 2.0 lbs/bbl Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 1.0 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Page 1/1 Report Printed: 1/20/2015 0 f .a Cement Detail Report r 2M-36 ConocoPhillips String: Isolation Plug#4 Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Isolation Plug#4 12/5/2014 12:00 12/5/2014 13:30 2M-36 PB1 Comment Cement pump on top of Bentonite pill 500'long.Pumped 30 bbl 12.5 ppg Mud Push II,78.15 bbl 15.8 ppg Cement with 2 ppb Cemnet,follow with 5.2 bbl 12.5 MudPush,under displace with 40 bbl 10.8 ppg mud. Cement Stages Stage#1 Description 'Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Isolation Plug#4 Abandon wellbore,base 3,491.0 4,036.0 No No No for KOP Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 50.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 3,810.0 Tubing Comment SLB pumped 30 bbl 12.5 ppg MudPush II 3 bpm,34 psi, 19%flow out. Shut down,close annular, break head pin and load wiper ball. M/U heads pin,SLB pump 78 bbl 15.8 ppg Cement w/2 ppb Cemnet,50 psi,21%flow.Chase cement with 5.2 bbl 12.5 ppg MudPush II,displace with rig pumps 10.8 ppg mud @ 8 bpm, 145 psi,24%flow until catch cement, reduce rate to 3 bpm 50 psi total 397 strokes.CIP:13.30. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 3,491.0 4,036.0 377 G 78.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 119.0 7.30 Additives Additive Type Concentration Conc Unit label Lost Circulation Additive CEMNET 2.0 lbs/bbl Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Page 1/1 Report Printed: 1/20/2015 0;3 Cement Detail Report 2M-36 conocoPhaups String: Kickoff Plug Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Kickoff Plug 12/7/2014 10:15 12/7/2014 13:00 2M-36 PB1 Comment Pumped 30 bbl 12.5 ppg Mud Push II,85.73 bbl 17.0 ppg Cement with 2 ppb Cement,follow with 6.2 bbl 12.5 MudPush, under displace with 35 bbl 9.8 ppg mud. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Kickoff Plug Cement 200'up into 3,142.0 3,810.0 No No No surface casing Q Pump Mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 65.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,916.0 Tubing 4,420.0 9 7/8 Comment Pumped 5 bbl water,test to 4000 psi-good. Pumped 30 bbl 12.5 pg MudPush II 3 bpm 75 psi,Shut down,close choke/annular, load wiper ball, R/U.Open choke/annular, pump 85.73 bbl 17.0 ppg cement,3 bpm 65 psi,swap to 6.2 bbl 12.5 ppg MudPush II. Rig displace with 355 strokes, ICP 200 psi 8 bpm, reduce to 3 bpm 260 psi @ 300 stks.Full returns throughout cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 3,140.0 3,810.0 479 G 85.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.00 3.87 17.00 129.0 17.00 Additives Additive Type Concentration Conc Unit label Lost Circulation Additive CEMNET 2.0 lbs/bbl Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 1.0 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.2 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Page 1/1 Report Printed: 1/20/2015 y Cement Detail Report 0 a 2M-36 coilhps ALxka String: Intermediate Job: DRILLING ORIGINAL, 11/9/2014 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate 12/19/2014 09:15 12/19/2014 13:20 2M-36 Comment Pumped 40 BBL CW100,40 BBL 12.5 ppg MP II,pump 127 BBL 15.8ppg cement, push plug out with 10 BBL H20,displace with 10.5 ppg mud. Loss of 136 BBL during job,with casing stuck off hanger. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Cement casing and bring 9,000.0 9,543.0 No 127.0 No No cement to 7250'. Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 3 1,800.0 2,300.0 Yes 14.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 6 1/2 Comment Cement Fluids&Additives j Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Primary Cement 7,250.0 9,534.0 564 G 127.0 Yield ye/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.18 5.29 15.80 54.0 5.00 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 1/1 Report Printed: 1/20/2015 2.14-\o 2 2.52.67 WELL LOG TRANSMITTAL DATA LOGGED t/14/2015 K.BENDER To: Alaska Oil and Gas Conservation Comm. January 13, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 JAN 152015 RE: Radial Cement Bond Log : 2M-36AO�� Run Date: 12/22/2014 O The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-36 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20691-00 Radial Cement Bond Log 1 Color Log 50-103-20691-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Mdzasz44.) 6-e-Azat Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Friday, December 19, 2014 7:28 PM To: Loepp,Victoria T(DOA);Schwartz,Guy L(DOA) Cc: Herbert, Frederick 0;Wheatall, Michael;Alvord, Chip; Bearden,J Daniel; Shultz, Steve (Orbis Engineering,Inc.); Lee, David L; Doyon 25 Company Man; NSK Fld DrIg Supv Subject: 2M-36 Intermediate Update:CBL Follow Up Flag: Follow up Flag Status: Flagged Victoria,Guy, After further evaluation,we have decided to run a CBL to find top of cement before drilling ahead.We will attempt to find top of cement and plan remedial actions if necessary. Kelsey Hallford Sent with Good (www.good.com) From: Hallford, Kelsey Sent: Friday, December 19,2014 8:17:38 PM To: 'victoria.loepp@alaska.gov; 'guy.schwartz@alaska.gov' Cc: Herbert, Frederick 0;Wheatall, Michael;Alvord,Chip (Chip.Alvord@conocophillips.com); Bearden,J Daniel;Shultz, Steve (Orbis Engineering, Inc.); Lee, David L; Doyon 25 Company Man; NSK Fld DrIg Supv Subject:2M-36 Intermediate Update Victoria,Guy, We have run and landed our 7-5/8" intermediate casing per plan to a TD of 9520' MD.We experienced losses during our cement job but will proceed with the program as planned with sonic in our BHA to record top of cement.We will perform an FIT to a 13.8 ppg EMW after drilling out to evaluate the competency of our shoe. If the FIT fails,we will perform a squeeze job to improve our shoe. If we pass the FIT we will continue drilling ahead per plan. Upon TD of the well we will download the recorded sonic data at surface to determine top of cement. We will notify the state to discuss any necessary remedial action if TOC is not adequate. Kelsey Hallford ATO 1578 Drilling Engineer I ConocoPhillips Office:+1-907-265-1577 Cell: +1-907-440-0004 Email: kelsev.hallford@cop.com<mailto:kelsevhallford.hallford@cop.com> 1 I4- -107- Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Monday, December 22,2014 5:29 PM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Cc: Wheatall, Michael;Alvord, Chip; Herbert, Frederick 0; Bearden,1 Daniel; Lee, David L; NSK FId Drlg Supv; Doyon 25 Company Man Subject: 2M-36 CBL Results PTD#214-102 Attachments: 2M-36BP1 WP09 Cement Plug Program.pdf; 2M-36 WP14 Current 12.22.2014.pdf; 2M-36_RBT_22-DEC-2014.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria,Guy, The results of the CBL on 2M-36 and updated schematics are attached. We have found the TOC at 9,275' MD which is 243' MD above the 7-5/8" intermediate casing shoe and corresponds to 559' MD above the Kuparuk C. While the TOC is not as high as originally planned,attempting a remedial perforation/squeeze job would increase risk by compromising the mechanical integrity of the casing. Therefore,with your agreement, based on the quality and TOC,ConocoPhillips believes this cement height provides sufficient zonal isolation to continue operations and drill ahead per the approved well plan. Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsev.hallford(a�cop corn 1 I.: ; l'ii 3411 [7:1E.LZ 7.7-ftiraiiiii I'9 rq i Ell• C-4 EAM L --°- il t : a _ r 1 L 11_: IL: 11 li i- • , .• - : II I t7' . . 't - I! r I 1- :11 1=IIIM=M .MIIIMMIll . -- -.-.. 2- 14. ' '' ' -. ; - . 1 j -- ---- ,,,.... - I 111111 . . i ' • II, , :Tr • 4.- . ,-- ••.. 1.7/7-47.......za...-- INEBEE 41T;r1"- --= Milli .m.7 pr_ ix Fr ois,ilimiut ,.,----..- r ;.:-r ,•14414."- I .7....- _. . - Grass Roots Horizontal A/C Sand Producer ConocoPhillips Current Well Condition 12.22.2014 l J Conductor Q 131' MD GL: 16"62.6#H-40 DrilPlex WBM 9.0-9.3 PPG 13-1/2"Surface Hole Surface Casing: Below West Sak 10-3/4"45.5#L-80 Hydril 563 3,342'MD 2,836'TVD KOP:3,410 ML - LSND WBM 9.7-10.5 PPG Keep up with dilution 9-7/8" Intermediate Hole :.:.:.:.:.:.:........ :. :.....---:�.iSi.�Ate:::€ ..• .. : ....: :. TOG behind casing:9275'MD Intermediate Casing 9.518'MD: 7-5/8"29.7#L-80 Hydril 563 Surface-9093' MD — Shoe track drilled out to 9,493'MD 7-5/8"39#TN110S Hydril 563 9,093'MD–9,518'MD • • 1 Grass Roots Horizontal A/C Sand Producer ConocoPhillips Actual Plug Back Schematic l J Conductor @ 132'MD GL: 16"62.6#H-40 DrilPlex WBM 9.0-9.3 PPG 13-1/2"Surface Hole Surface Casing: Below West Sak 10-3/4"45.5#L-80 Hydril 563 3,342'MD 2,836'TVD Planned KOP:3,392'MD TOC of Plug#5—2,916'MD TOC of Plug#4—3,810'MD 80bbl gel pill LSND WBM TOC of Plug#3—6,351'MD 9.7-10.5PPG Keep up with Dilution 9-7/8"Intermediate Hole Estimated top of cement of Plug #2—6,738'MD Iceber TOC of Plug#1—7,374'MD Hole depth 8,018'MD,5,316TVD HO:i4Sand k 7:: .: A ..:.:.:.:.:.:.:.:::::.:.:.:.:.:.:.:.:.:....:.:.:.:...:.:.:.:.:.......:.:::.::.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:::.:::.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:::.:.:::.:.:.:.:.:.:.:.:.:.:.:. :.:. al4-/oz Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, December 23, 2014 12:18 PM To: 'Klem,Adam' Subject: RE:Sundry Number:314-622, KRU 2M-36 Adam, Both changes are approved. Please include this communication with the approved sundry. 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 Loeppalaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at (907)793-1247 or Victoria.Ferguson@alaska.00v From: Klem, Adam [mailto:Adam.Klem@conocophillips.com] Sent:Tuesday, December 23, 2014 10:59 AM To: Loepp, Victoria T(DOA) Cc: Kurnia, Dadang; Hallford, Kelsey; Lee, David L; Ruff, Chris A Subject: Sundry Number: 314-622, KRU 2M-36 Victoria, As we discussed on the phone,there was some miscommunication with this sundry.We are requesting two minor changes to this sundry. 1. Heel swell packer placement; Pre sundry communication between ConocoPhillips and Guy Schwartz(dated 11/18/14)discussed placing the swell packer at the top of the C sand to provide pressure isolation for the 7 5/8" casing shoe.Somehow, it was submitted in the sundry as the swell packer would be placed at the top of the A sand.To provide better isolation of the shoe,we are requesting permission to place the swell packer at the top of the C sand. 2. 4'A" 12.6#TN-110 liner;The original Bonzai completion required this higher strength pipe in our cemented section of the lateral. Now that we have removed the cemented portion,we no longer require the higher strength TN-110,and are requesting permission to run the whole liner as 12.6#1-80 IBTM . I have attached the sundry with the communications,as well as an updated planned WBD. Thank you for your time and Happy Holidays! 1 Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 2044 Anchorage,AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophillips.com 2 2M-36 Grass Roots Horizontal A/C Sand Producer ConocoPhillips Proposed Wellbore Schematic J > r Conductor To Be Installed: p 16"62.6#H-40 DrilPlez WBM 9.0-9.3 PPG 13-1/2"Surface Hole _ _i W 5O:; : : Surface Casing: Below West Sak A" L. 10-3/4"45.5#L-80 Hydril 563 3,342'MD 2,836'TVD AY J KOP; Cement plugs will be brought back to 3,142' MD,the new hole w will be kicked off at 3,392'MD -SND WBM 9.7-10.5 PPG Keep up with Tubing; Dilution 9,945'3-'/z"9.3#L-80 EUE8RD 9-7/8"Intermediate Hole J TO C:9,275'MD,5905'TVD L Intermediate Casing:Top Set Above C Sand( )6000'TVD 7-5/8",ZXP Liner Top Packer 9,945'MD 7-5/8"29.7#L-80 with Hydril 563 r , 7-58"x 4-W Baker Flex Lock Liner hanger Surface—9,148'MD A ' 7-5/8"39#TN-110 with Hydril 521 9,148-10,148 �Sa�tcE Top:.:.:.:.:.:.:.:.. . . : : : ::: :: 1027.2....... . . . • •.•.-.•...•.•.:.- . . . . . . . . : : : : : : : • : : : ! : :::::::i:i::::: : .6a rc#To j $. S : :;: p : : : :: �i 1 :p . ;?ansa:::: ::::::::::: :::: : : �: :10 396:: : :::::; :••••: 1:•::::(?raduGtie8#lose.: vv. a. i: : :•: : : : : : : : : : : : : : : :, . . . .\ Production Liner; 4-1/2" 12.6#L-80 IBTM Perforated Pups 9,948'-12,774'MD 6,051'TVD 2L4— t0 z Loepp, Victoria T (DOA) From: Hailford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Wednesday, December 24, 2014 6:39 AM To: Loepp,Victoria T (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: [EXTERNAL]Re:2M-36 CBL Results PTD#214-102 Attachments: 2M-36 7.625 inch Casing 14.1 ppg FIT 12-24-14.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, The FIT results are attached. We achieved a 14.1ppg EMW. KH From: Hailford, Kelsey Sent: 23 December 2014 07:33 To: Loepp, Victoria T(DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: [EXTERNAL]Re: 2M-36 CBL Results PTD# 214-102 Thank you.We should have the FIT results this afternoon. KH Sent with Good (www.good.com) From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Monday, December 22, 2014 9:20:07 PM To: Hailford, Kelsey Cc:Schwartz,Guy L(DOA) Subject: [EXTERNAL]Re: 2M-36 CBL Results PTD#214-102 Approval is granted to drill ahead. Please forward FIT results when available. Thanx, Victoria Sent from my iPhone On Dec 22,2014,at 5:29 PM, Hailford, Kelsey<Kelsey.Hallford@conocophillips.com>wrote: Victoria,Guy, 1 The results of the CBL on 2M-36 and updated schematics are attached. We have found the TOC at 9,275' MD which is 243' MD above the 7-5/8" intermediate casing shoe and corresponds to 559' MD above the Kuparuk C. While the TOC is not as high as originally planned,attempting a remedial perforation/squeeze job would increase risk by compromising the mechanical integrity of the casing. Therefore,with your agreement, based on the quality and TOC,ConocoPhillips believes this cement height provides sufficient zonal isolation to continue operations and drill ahead per the approved well plan. Kelsey Hallford Drilling Engineer I ConocoPhillips Office: +1-907-265-1577 Cell: +1-907-440-0004 Email: kelsev.hallford(a�cop corn <2M-36BP1 WP09 Cement Plug Program.pdf <2M-36 WP14 Current 12.22.2014.pdf5 <2M-36 RBT 22-DEC-2014.pdf> 2 / , /1° iir01 . 011.• PiaggivrMIJI,J 4.144441%%414,40" ., „ ,, ,,/ A A /rei,,, "......= ........ _ ,,,, . ,/ i' IS .0000, _____=______=:"iixl ...4411, 4444 . . ,NN- • il 1%; M'isimmizmiraw 4•000 4„,4141'1 , .' / 21...-- 00,1%'.......=ZW,...... .........4%,....4.. 1011 ......=",a,.....Veire ii,W, .#::: if '- .. ro'llili Ow=IM'Am 1 ifte, 4.ki'llibkfrilliA, 4" tillOWA / / 4....,..q...ff,&" soo ,fillageb A/ #.41 ifitiV \\ itillii ellrill 41/1" 64 Olitri" \ , ,', 1.1 4 ..114 ..14 _wd, _ # /ow * wrap - s \ \\,,, -i ' , loph Ittolopodpiegeo e•••••74 .:. .,,,tt \\ \ b-1 14 idIN immet _cf0Aays1/49ARic7_,,:iottostir us : \ tit totitilititiltalk„ :it: q*cliardrillillUi 3 alm sx --------- 11,---_-_ ,\ .,;(), ..1 .44-rrilliiritil ,. , i ‘viiku .mikii„ ,, _ ,,,e „4„. .0 lir 0 *lb" , , , T iik \V- ..***- --_- ;TI: 4 I 017 11411 i, \\ \A % \ 1 1 I 1r ill•2 if # # � 'i "V NVk°n �r�or,Tot •I'11E STATE Alaska Oil and Gas �`\ll/ii�� Conservation Commission ,.4'�-�.. =-i'� °MCAs A ' 333 West Seventh Avenue Ott - Anchorage,Alaska 99501-3572 '15- ( rOVERNOR BILL ` TAI_KFR Main:907.279.1433 4LA5 Fax:907.276.7542 www.aogcc.alaska.gov December 9, 2014 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7017 2120 0004 7782 7499 Mr. G.L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Notice of Violation—Failure to Test BOPE Doyon Rig 25 Kuparuk River Unit 2M-36 (PTD 2141020) Dear Mr. Alvord: ConocoPhillips Alaska Inc. (CPAI) is performing development drilling operations at Kuparuk River Unit (KRU) 2M-36 pursuant to permit-to-drill 2141020, approved on August 15, 2014. During development drilling operations testing of blowout prevention equipment (BOPE) must be completed at intervals not to exceed 14 days between tests. Refer to 20 AAC 25.035. Failure to test BOPE within 14 days is a violation of AOGCC regulations. The BOPE test for the KRU 2M-36 well was required to be completed by December 1 and was accurately acknowledged in the test notice received from the Doyon 25 representative on November 30, 2014 (copy attached). In that notice, current activity was identified as "rigging up to test components used during [a] well control incident". CPAI reported using BOPE for well control on November 23, 2014 while drilling ahead in Kuparuk River Unit 2M-36. An AOGCC Inspector acknowledged receipt of the planned test notice and confirmed he would witness the test. Communications throughout the day (December 1) provided updates as work progressed on Kuparuk River Unit 2M-36 with a common understanding that AOGCC would witness the Doyon 25 BOPE test. During an afternoon phone call, the Inspector requested completion of a BOPE body test before traveling to the rig. No communication was received from the rig crew until the AOGCC Inspector called to find out the status at 4:00 am (December 2) at which time he was told they started testing the choke manifold. The only explanation offered for not contacting the AOGCC Inspector was that he left instructions to call after they complete a body test on the BOPE, and that had not yet been done. The BOPE test was finally commenced with AOGCC witness on December 2 at 1:30 pm. Mr.G.L.Alvord December 9,2014 Page 2 of 3 AOGCC has reviewed the Daily Drilling Reports for November 28 through December 2 as provided by CPAI. The record is clear that Doyon 25 performed a partial BOPE test on November 30, 2014 to address the components previously used for well control purposes.1 It is unclear why Doyon 25 would invest the effort to prepare for a partial test and not complete a full BOPE test that was due the very next day. The Daily Drilling Reports show that Doyon 25 was dealing with some unbalanced well conditions during the week leading up to the BOPE test. A storm packer was set in the well and tested on November 30; this would have isolated the surface from the well's open-hole section allowing the BOPE test to be done in a safe manner. The decision to move forward with setting plugs in the well — as described by the CPAI- representative communicating with the AOGCC Inspector leading up to the test — in lieu of performing a full BOPE test contributed to this BOPE test not meeting its required deadline. Performing a full BOPE test on November 30 would most likely have added only three hours to the partial test and ensured compliance with BOPE test requirements. The December 2 BOPE test report(Form 10-424) noted a start time of 1:30 pm. CPAI submitted a revised BOPE test report on December 3 changing the start time to 11:30 pm on December 1, apparently suggesting that testing the choke manifold valves somehow brings Doyon 25 into compliance. Review of the Daily Drilling Reports shows that CPAI began testing the choke manifold as part of simultaneous operations (monitoring the well after cementing) without contacting the AOGCC Inspector. AOGCC does not allow testing of the choke manifold "off- line" without prior approval, and does not allow such when an Inspector is scheduled to witness the BOPE test. This effort hardly meets the intent of the AOGCC regulation for BOPE testing and past guidance to all operators that strongly encourages taking advantage of testing opportunities to comply with the 14-day window for testing For failing to test BOPE on or before the 14-day anniversary of the previous test and failure to contact the AOGCC Inspector giving him opportunity to witness the commencement of this BOPE test, AOGCC orders the following: - Beginning immediately with the first scheduled BOPE test after receipt of this letter and until further notice, Doyon 25 will test BOPE at intervals not to exceed 7 days between tests. AOGCC will consider short extensions with written justification. In addition, CPAI is requested to provide the following within fourteen days of receipt of this letter(next business day if the due date falls on a weekend or holiday): - Performance test charts for both November 30 and December 2, 2014 BOPE tests; - Policy and procedure that address testing the choke manifold valves "off-line"; - Daily Drilling Reports for November 23 through November 27, 2014; - Description of specific steps that have been or will be taken to prevent recurrence on CPAI operated rigs in Alaska. 'AOGCC received a notice on November 24,2014 that secondary well control equipment had been used to prevent the flow of wellbore fluids from the well on November 23,2014. Additional clarification was provided on November 29,2014. Mr.G.L. Alvord December 9,2014 Page 3 of 3 The information request is made pursuant to 20 AAC 25.300. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue an enforcement action in this matter according to 20 AAC 25.535.Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, y4 /7;; L- Cathy . Foerster Chair, Commissioner Attachment cc: AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Regg, James B (DOA) RSS Feed: AOGCC Inspection Request Posted on: Sunday, November 30, 2014 6:37 AM Author: AOGCC Inspection Request Subject: AOGCC Inspection Request - Submission (2014-11-30 06:36:31) Full article link: http://wwwjotform.com/submission/293170942661153401 Submission Date : 2014-11-30 06:36:31 IP Address : 138.32.11.66 Type of Test Requested: : Requested Time for Inspection : 12-01-2014 10:00 PM Location : Doyon 25, Kuparuk Well 2M-36 Name : Robert Reinhardt E-mail : d25cm@conocophillips.com Phone Number : (907) 659-7501 Company : ConocoPhillips Other Information: : We are due for our 2 week BOP test by the end of the day 12/1. Present operations are rigging up to test components used during well control incident, change to 3%" Ti and test, then P/U tubing stinger to RIH and pump cement plugs/ kickoff plug time permitting. View article... 0-4.4 Zi4 -Z+v Regg, James B (DOA) 176 z44 10 From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Monday, November 24, 2014 3:34 PM ' 'c u(Z4 To: Regg, James B (DOA) Cc: Bettis, Patricia K (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T (DOA) Subject: RE: 2M-36 - 214-102 - Shut In Well Just the annular preventer was used in the well control operation. Any other questions please let me know. David Lee From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, November 24, 2014 10:56 AM To: Lee, David L Cc: Bettis, Patricia K (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: 2M-36 - 214-102 - Shut In Well Was there secondary well control equipment used in addition to the annular preventer? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Bettis, Patricia K (DOA) Sent: Monday, November 24, 2014 9:05 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: FW: 2M-36 - 214-102 - Shut In Well From: Lee, David L [mailto:David.L.Lee@conocophillips.com] Sent: Monday, November 24, 2014 1:39 AM To: Schwartz, Guy L(DOA); Bettis, Patricia K (DOA); Loepp, Victoria T(DOA) Cc: Bearden, J Daniel; Herbert, Frederick 0; Doyon 25 Company Man Subject: RE: 2M-36 - 214-102 - Shut In Well Guy, Patricia and Victoria, I need to correct my shut in pressure measurements. Our initial SIPDD was 90 psi and our SICP was 220 psi. We are weighting up our surface system to 10.1 ppg so that we can circulate that fluid around. 1 Please call with any concerns. David From: Lee, David L Sent: Monday, November 24, 2014 1:05 AM To: Schwartz, Guy L (DOA); patricia.bettis@)alaska.gov; Loepp, Victoria L (DOA) (victoria.loepp(aalaska.gov) Cc: Bearden, Daniel D (J.Daniel.Bearden@conocophillips.com); Herbert, Frederick 0 (Frederick.O.Herbert@conocophillips.com); Doyon 25 Company Man (Doyon25CompanyManOconocophillips.com) Subject: 2M-36 - 214-102 - Shut In Well Morning Guy, Patricia and Victoria, last evening ConocoPhillips was drilling ahead at 8018' MD, 5316'TVD and the driller noticed a 5% increase of flow. At this point we decided to shut the well in by closing our annular preventer. Then well was shut in @ 10:40 pm Sunday November 23. The initial SIDPP was measured 25psi while the SICP was 90 psi. The mud weight we were drilling with was a 9.7ppg. We are currently monitoring our pressures and checking our volumes to determine the size of our gain. If you have any questions please let me know. David Lee 2 K(u,c P7 zI1 (ozo Regg, James B (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Saturday, November 29, 2014 8:58 AM 61t 1 q 14 To: Regg,James B (DOA) Cc: Doyon 25 Company Man; Herbert, Frederick 0; Bearden, J Daniel Subject: RE: 2M-36 - 214-102 - Shut In Well Morning Jim, we are on our way out of the hole now after fighting loss circulation for the last few days. Once out of the hole the following components will be tested as they were used to circulate out the influx. 13-5/8" Annular w/ 5" test joint. HCR valve on the kill line side Components on the choke manifold: Super Choke Valve 1, 4, 6, 7, 12. Will test to 250 psi low and 3500 psi high. Please let me know if you need anything else. Thanks David From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, November 28, 2014 10:00 AM To: Lee, David L Cc: Doyon 25 Company Man; Herbert, Frederick 0; Bearden, J Daniel Subject: [EXTERNAL]RE: 2M-36 - 214-102 - Shut In Well David— No floor safety valves used? No chokes, choke manifold valves used? HCR/manual valves on choke and kill lines (you did circulate the influx out, correct)? Blowout prevention equipment (BOPE) refers to all of this, not just the rams and annular preventer. Anything used must be tested according to AOGCC regulations. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 From: Lee,"David L [mailto:David.L.Lee@conocophillips.com] Sent: Monday, November 24, 2014 3:34 PM To: Regg, James B (DOA) Cc: Bettis, Patricia K (DOA); Roby, David S (DOA); Schwartz, Guy L(DOA); Loepp, Victoria T(DOA) Subject: RE: 2M-36 - 214-102 - Shut In Well Just the annular preventer was used in the well control operation. Any other questions please let me know. David Lee From: Regg, James B (DOA) [mailto:jim.reqg@alaska.gov] Sent: Monday, November 24, 2014 10:56 AM To: Lee, David L Cc: Bettis, Patricia K (DOA); Roby, David S (DOA); Schwartz, Guy L (DOA); Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: 2M-36 - 214-102 - Shut In Well Was there secondary well control equipment used in addition to the annular preventer? Jim Regg Supervisor, Inspections AOGCC 333 W 7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Bettis, Patricia K (DOA) Sent: Monday, November 24, 2014 9:05 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: FW: 2M-36 - 214-102 - Shut In Well From: Lee, David L [mailto:David.L.Lee@conocodhillips.com] Sent: Monday, November 24, 2014 1:39 AM To: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA); Loepp, Victoria T(DOA) Cc: Bearden, J Daniel; Herbert, Frederick 0; Doyon 25 Company Man Subject: RE: 2M-36 - 214-102 - Shut In Well Guy, Patricia and Victoria, I need to correct my shut in pressure measurements. Our initial SIPDD was 90 psi and our SICP was 220 psi. We are weighting up our surface system to 10.1 ppg so that we can circulate that fluid around. Please call with any concerns. David 2 From: Lee, David L Sent: Monday, November 24, 2014 1:05 AM To: Schwartz, Guy L (DOA); patricia.bettis@alaska.gov; Loepp, Victoria L (DOA) (victoria.loeop@ialaska.gov) Cc: Bearden, Daniel D (J.Daniel.Bearden@conocophillips.com); Herbert, Frederick 0 (Frederick.O.Herbert@conocophillips.com); Doyon 25 Company Man (Doyon25CompanyMan@conocophillips.com) Subject: 2M-36 - 214-102 - Shut In Well Morning Guy, Patricia and Victoria, last evening ConocoPhillips was drilling ahead at 8018' MD, 5316'TVD and the driller noticed a 5% increase of flow. At this point we decided to shut the well in by closing our annular preventer. Then well was shut in @ 10:40 pm Sunday November 23. The initial SIDPP was measured 25psi while the SICP was 90 psi. The mud weight we were drilling with was a 9.7ppg. We are currently monitoring our pressures and checking our volumes to determine the size of our gain. If you have any questions please let me know. David Lee 3 . Regg, James B (DOA) From: Rig 25 <rig25@doyondrilling.com> IZI< <it Sent: Sunday, November 30, 2014 6:14 PM IS7(1/�1 To: Regg,James B (DOA); Brooks, Phoebe L(DOA); DOA AO CC Prudhoe Bay Cc: d25cm@conocophillips.com; ahonea@doyondrilling.com Subject: Emailing: Doyon 25 11-30-14 2M-36 Attachments: Doyon 25 11-30-14 2M-36.xlsx «Doyon 25 11-30-14 2M-36.xlsx»Attached is today's BOPE test report Roy Fritts Rig 25 Toolpusher Rig office 907-659-7975 Camp office 907-659-7171 Cell 907-529-1517 rig25@doyondrilling.com 1 . STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION l l' iq BOPE Test Report (2-f I Submit to: jim.reoc aC�,alaska.gov AOGCC Inspectorsalaska.qov phoebe.brooks a(�,alaska qov Contractor: Doyon Rig No.: 25 DATE. 11/30/14 Rig Rep: Fritts/Carlo Rig Phone: 659-7975 Operator: CPAI Op. Phone: 659-7501 Rep. Rizek/Reinhardt E-Mail rig25@doyondrilling.com Well Name: 2M-36 Kuparuk - PTD# 2141020 • Sundry# Operation: Drilling: X Workover. Explor.: Test: Initial: Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3500 " Annular: 250/3500 - Valves: 250/3500 ' MASP: 3217 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8x5000 P - Pit Level Indicators P P #1 Rams 1 2 7/8X5 1/2" P Flow Indicator P P #2 Rams 1 Blind Shear NA Meth Gas Detector NA NA #3 Rams 1 2 7/8x5 1/2 P - H2S Gas Detector NA NA #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln Valves 0 3 1/8x5000 NA Inside Reel valves 0 NA HCR Valves 2 3 1/8x5000 P Kill Line Valves 0 3 1/8x5000 NA Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 NA CHOKE MANIFOLD: Pressure After Closure(psi) NA Quantity Test Result 200 psi Attained(sec) NA No.Valves 7 P - Full Pressure Attained (sec) NA Manual Chokes 0 NA Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (#and psi): NA CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time 3.0 Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to.AOGCC.Inspectors@alaska.gov Remarks: Tested Annular with 5"&3 1/2"test jts. Tested rams#1  with 3 1/2"test jts. Tested choke manifold valves 1,4,6,7,12,13,14. Tested lea 4 1/2 IF FOSV& lea 4 1/2 IF Dart valve. Function tested Hydraulic choke @ 2000 psi. Well was shut in©22.45 on 11-23-14 due to gas influx. This is the first opportunity to test BOPE after well cnntrnl inni1pnt AOGCC Inspection 24 hr Notice No Date/Time Waived By Test Start Date/Time. 11/30/2014 9:00 (date) (time) Witness Test Finish Date/Time: 11/30/2014 12:00 Form 10-424(Revised 06/2014) Doyon 25 11-30-14 2M-36.xlsx FTP L11- -- / oz Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Friday, November 28, 2014 11:27 AM To: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA); Loepp,Victoria T(DOA) Cc: Bearden,J Daniel; Herbert, Frederick 0; Doyon 25 Company Man; Little, Laird D. Subject: 2M-36 - 214-102 - Cement Plugs and SidetrackD Attachments: 2M-36 P&A Plug 2 Plugadvisor v3 11.28.14.pdf;2M-36 KOP Plug 3 Plugadvisor v3 11.28.14.pdf;2M-36 P&A Plug 1 Plugadvisor v3 11.28.14.pdf;2M-36wp10 PlanSummary.pdf Follow Up Flag: Follow up Flag Status: Flagged Morning Guy, Patricia and Victoria, Throughout the week, ConocoPhillips circulated out a kick during a well control situation, and weighted up our system to a 10.5 ppg. During the last few days, we broke down our wellbore and started taking losses. We estimate we broke it down in the iceberg formation which is at a depth of 7050' MD. Over the past few days we have tried to heel our losses by pumping 4 LCM pills and a FORM-A-BLOK pill. The LCM pills and the FORM-A-BLOK pill did not heel our losses. We did see some short term relief of the losses but nothing that would allow us to drill ahead. The decision has been made to pump 3 cement plugs and side track our wellbore. The 3 cement plugs will cover us from 8018' MD back to 6100' MD. Our side track point is going to be at 6300' MD. We are going to re-drill the bottom part of our intermediate section and to a new intermediate casing point that is 750' away from our current planned intermediate casing point. The new intermediate casing point is still along the same azimuth of our current horizontal leg. All we are doing is pushing the casing point out but not adjusting our TD coordinates of the toe of the lateral, effectively shortening our lateral leg by 750'. Please let me know if you have any concerns with the plan forward. We are currently POOH and will be running in hole to pump cement plugs later tonight or tomorrow morning. Attached please find our cement plug program as well as our new directional plan. If you would like to see any other information please let me know. Thanks David From: Lee, David L Sent: Monday, November 24, 2014 1:05 AM To: Schwartz, Guy L(DOA); patricia.bettis@alaska.gov; Loepp, Victoria L(DOA) (victoria.loepp@alaska.gov) Cc: Bearden, Daniel D (J.Daniel.Bearden@conocophillips.com); Herbert, Frederick 0 (Frederick.O.Herbert@conocophillips.com); Doyon 25 Company Man (Dovon25CompanvMan@conocophillips.com) Subject: 2M-36 - 214-102 - Shut In Well Morning Guy, Patricia and Victoria,last evening ConocoPhillips was drilling ahead at 8018' MD, 5316'TVD and the driller noticed a 5%increase of flow. At this point we decided to shut the well in by closing our annular preventer. Then well was shut in @ 10:40 pm Sunday November 23. The initial SIDPP was measured 25psi while the SICP was 90 psi. The 1 Loepp, Victoria T (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, November 28, 2014 1:35 PM To: Loepp,Victoria T(DOA) Subject: Automatic reply:2M-36 - 214-102 - Cement Plugs and Sidetrack Follow Up Flag: Follow up Flag Status: Flagged I am out of the Office starting Friday afternoon(November 21)and will be out of cell and email reach until Saturday November 28th. Going hunting at Montague Is. 3 Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Friday, November 28, 2014 11:27 AM To: Schwartz,Guy L(DOA); Bettis, Patricia K(DOA); Loepp,Victoria T(DOA) Cc: Bearden,J Daniel; Herbert, Frederick 0; Doyon 25 Company Man; Little, Laird D. Subject: 2M-36 - 214-102 - Cement Plugs and SidetrackD Attachments: 2M-36 P&A Plug 2 Plugadvisor v3 11.28.14.pdf;2M-36 KOP Plug 3 Plugadvisor v3 11.28.14.pdf;2M-36 P&A Plug 1 Plugadvisor v3 11.28.14.pdf;2M-36wp10 PlanSummary.pdf Follow Up Flag: Follow up Flag Status: Flagged Morning Guy, Patricia and Victoria, Throughout the week, ConocoPhillips circulated out a kick during a well control situation, and weighted up our system to a 10.5 ppg. During the last few days, we broke down our wellbore and started taking losses. We estimate we broke it down in the iceberg formation which is at a depth of^'7050' MD. Over the past few days we have tried to heel our losses by pumping 4 LCM pills and a FORM-A-BLOK pill. The LCM pills and the FORM-A-BLOK pill did not heel our losses. We did see some short term relief of the losses but nothing that would allow us to drill ahead. The decision has been made to pump 3 cement plugs and side track our wellbore. The 3 cement plugs will cover us from 8018' MD back to 6100' MD. Our side track point is going to be at 6300' MD. We are going to re-drill the bottom part of our intermediate section and to a new intermediate casing point that is 750' away from our current planned intermediate casing point. The new intermediate casing point is still along the same azimuth of our current horizontal leg. All we are doing is pushing the casing point out but not adjusting our TD coordinates of the toe of the lateral, effectively shortening our lateral leg by 750'. Please let me know if you have any concerns with the plan forward. We are currently POOH and will be running in hole to pump cement plugs later tonight or tomorrow morning. Attached please find our cement plug program as well as our new directional plan. If you would like to see any other information please let me know. Thanks David From: Lee, David L Sent: Monday, November 24, 2014 1:05 AM To: Schwartz, Guy L(DOA); patricia.bettis@alaska.gov; Loepp, Victoria L(DOA) (victoria.loepp@alaska.gov) Cc: Bearden, Daniel D (J.Daniel.Bearden@conocophillips.com); Herbert, Frederick 0 (Frederick.O.Herbert@conocophillips.com); Doyon 25 Company Man (Doyon25CompanyMan@conocophillips.com) Subject: 2M-36 - 214-102 - Shut In Well Morning Guy, Patricia and Victoria, last evening ConocoPhillips was drilling ahead at 8018' MD, 5316'ND and the driller noticed a 5%increase of flow. At this point we decided to shut the well in by closing our annular preventer. Then well was shut in @ 10:40 pm Sunday November 23. The initial SIDPP was measured 25psi while the SICP was 90 psi. The 4 Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Monday, November 24, 2014 3:34 PM To: Regg,James B (DOA) Cc: Bettis, Patricia K(DOA); Roby, David S (DOA); Schwartz, Guy L(DOA); Loepp,Victoria T (DOA) Subject: RE:2M-36- 214-102 - Shut In Well Follow Up Flag: Follow up Flag Status: Flagged Just the annular preventer was used in the well control operation. Any other questions please let me know. David Lee From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, November 24, 2014 10:56 AM To: Lee, David L Cc: Bettis, Patricia K(DOA); Roby, David S(DOA); Schwartz, Guy L(DOA); Loepp, Victoria T(DOA) Subject: [EXTERNAL]RE: 2M-36 - 214-102 - Shut In Well Was there secondary well control equipment used in addition to the annular preventer? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Bettis, Patricia K(DOA) Sent: Monday, November 24, 2014 9:05 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: FW: 2M-36 - 214-102 - Shut In Well From: Lee, David L [mailto:David.1.Lee@conocophillips.com] Sent: Monday, November 24, 2014 1:39 AM To: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA); Loepp, Victoria T(DOA) Cc: Bearden,J Daniel; Herbert, Frederick 0; Doyon 25 Company Man Subject: RE: 2M-36 - 214-102 - Shut In Well 1 • Guy, Patricia and Victoria, I need to correct my shut in pressure measurements. Our initial SIPDD was 90 psi and our SICP was 220 psi. We are weighting up our surface system to 10.1 ppg so that we can circulate that fluid around. Please call with any concerns. David From: Lee, David L Sent: Monday, November 24, 2014 1:05 AM To: Schwartz, Guy L(DOA); patricia.bettis@alaska.gov_; Loepp, Victoria L(DOA) (victoria.loeDD@alaska.gov) Cc: Bearden, Daniel D (J.Daniel.Bearden@)conocophillips.com); Herbert, Frederick 0 (Frederick.O.Herbert@conocophillips.com); Doyon 25 Company Man (Doyon25CompanyMan@conocophillips.com) Subject: 2M-36 - 214-102 - Shut In Well Morning Guy, Patricia and Victoria, last evening ConocoPhillips was drilling ahead at 8018' MD, 5316'TVD and the driller noticed a 5%increase of flow. At this point we decided to shut the well in by closing our annular preventer. Then well was shut in @ 10:40 pm Sunday November 23. The initial SIDPP was measured 25psi while the SICP was 90 psi. The mud weight we were drilling with was a 9.7ppg. We are currently monitoring our pressures and checking our volumes to determine the size of our gain. . If you have any questions please let me know. David Lee 2 Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Saturday, November 29, 2014 9:50 AM To: Loepp,Victoria T(DOA) Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA); Bearden,J Daniel; Herbert, Frederick 0; Doyon 25 Company Man; Little, Laird D.;Crews,Jennifer R Subject: RE: 2M-36 - 214-102 -Cement Plugs and SidetrackC Attachments: 2M-36 WP09 Cement Plug Program.pdf;2M-36 NO Bonzai WP10 (After Cement Plugss).pdf Follow Up Flag: Follow up Flag Status: Flagged Morning Victoria, Attached please find two schematics,the first one being the schematic of our cement plug program and formation tops. The second of our new proposed WP10 well accounting for new casing depths. We do have LWD logs (gamma and resistivity)would you like to have a look at those? Please let me know if you have any other questions of concerns. Thanks David From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Friday, November 28, 2014 1:35 PM To: Lee, David L Cc: Bettis, Patricia K(DOA); Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: 2M-36 - 214-102 - Cement Plugs and Sidetrack David, Could you please send a current/proposed wellbore schematic showing formation interval tops and plug locations. Are there any OH logs? 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 Loeppalaska.qov CONFIDENTIALRYNOTICE: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 Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 1 From: Lee, David L [mailto:David.L.Lee@conocophillips.com] Sent: Friday, November 28, 2014 11:27 AM To: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA); Loepp,Victoria T(DOA) Cc: Bearden, 3 Daniel; Herbert, Frederick 0; Doyon 25 Company Man; Little, Laird D. Subject: 2M-36 - 214-102 -Cement Plugs and Sidetrack Morning Guy, Patricia and Victoria, Throughout the week, ConocoPhillips circulated out a kick during a well control situation, and weighted up our system to a 10.5 ppg. During the last few days, we broke down our wellbore and started taking losses. We estimate we broke it down in the iceberg formation which is at a depth of 7050' MD. Over the past few days we have tried to heel our losses by pumping 4 LCM pills and a FORM-A-BLOK pill. The LCM pills and the FORM-A-BLOK pill did not heel our losses. We did see some short term relief of the losses but nothing that would allow us to drill ahead. The decision has been made to pump 3 cement plugs and side track our wellbore. The 3 cement plugs will cover us from 8018' MD back to 6100' MD. Our side track point is going to be at 6300' MD. We are going to re-drill the bottom part of our intermediate section and to a new intermediate casing point that is 750' away from our current planned intermediate casing point. The new intermediate casing point is still along the same azimuth of our current horizontal leg. All we are doing is pushing the casing point out but not adjusting our TD coordinates of the toe of the lateral, effectively shortening our lateral leg by 750'. Please let me know if you have any concerns with the plan forward. We are currently POOH and will be running in hole to pump cement plugs later tonight or tomorrow morning. Attached please find our cement plug program as well as our new directional plan. If you would like to see any other information please let me know. Thanks David From: Lee, David L Sent: Monday, November 24, 2014 1:05 AM To: Schwartz, Guy L(DOA); patricia.bettis@alaska.gov; Loepp, Victoria L(DOA) (victoria.loepp@alaska.gov) Cc: Bearden, Daniel D (].Daniel.Bearden@conocophillips.com); Herbert, Frederick 0 (Frederick.O.Herbert(aconocophillips.com); Doyon 25 Company Man (Doyon25CompanvMan@conocophillips.com) Subject: 2M-36 - 214-102 - Shut In Well Morning Guy, Patricia and Victoria, last evening ConocoPhillips was drilling ahead at 8018' MD, 5316'ND and the driller noticed a 5%increase of flow. At this point we decided to shut the well in by closing our annular preventer. Then well was shut in @ 10:40 pm Sunday November 23. The initial SIDPP was measured 25psi while the SICP was 90 psi. The mud weight we were drilling with was a 9.7ppg. We are currently monitoring our pressures and checking our volumes to determine the size of our gain. If you have any questions please let me know. David Lee 2 • 2M-36 Grass Roots Horizontal A/C Sand Producer ConocoPhillips Proposed Plug Back Schematic Li Conductor To Be Installed: Al - 16"62.6#H-40 DrilPlex WBM 9.0-9.3 PPG 13-1/2"Surface Hole 11witiSt Sak:::,:,:- Surface Casing: Below West Sak — 10-3/4"45.5#L-80 Hydril 563 3,342' MD 2,836'TVD Estimated top of cement of Plug #3—6,100'MD i_SND WBM Kick off point for WP10—6,300'MD,4,932'ND '.6—10.0 PPG Keep up with Dilution 9-7/8"Intermediate Hole Estimated top of cement of Plug #2—6,738'MD Iceberg -r1:01 'M Estimated top of cement of Plug #1—7,378'MD Hole depth 8,018'MD,5,3167VD c, 8 I.r j °'= :::::: ::: iii; ' ° : ° '�`5 ':` E ii 9491'ML?. ............. ATop. € €€**:.: *:'i'€€:::::s s ::::* [:€ €€ ::€:'s:: ::::€:: : ss: :]::::: :::€[€: : ss :ii:�' i::€[? 9 . 2M-36 Grass Roots Horizontal A/C Sand Producer ConocoPhillips Proposed Wellbore Schematic JfJ Conductor To Be Installed: 16"62.6#H-40 ) c DrilPlex WBM 9.0-9.3 PPG 13-1/2"Surface Hole 1 – J : ::::::West SO.. ..: Surface Casing: Below West Sak 10-3/4"45.5#L-80 Hydril 563 '— 3,342' MD 2,836'TVD KOP: Cement plugs will be brought back to 6,100'MD,the new hole J will be kicked off at 6300' MD LSND WBM 10.8 PPG Keep up with Tubing: Dilution 9,945'3-'/z"9.3#L80 EUE8RD 9-7/8" Intermediate Hole _J Estimated top of cement©+1-8000'MD 0llli Intermediate Casing:Top Set Above C Sand 7-5/8',ZXP Liner Top Packer 9,945'MD 7-5/8"29.7#L-80 with Hydril 563 7-5/8"x 4-%"Baker Flex Lock Liner hanger Surface–9,145' MD 7-5/8"39#TN-110 with Hydril 521 — 9,145-10,145 A$ top» 6 3g:OH*itiOgi.i:..:.::: :: ::::::::::::E;::;: ; ;;s; : ;i$ . ` psal ,.:,:, _' .t1 PKtdtit iHoe .: : • :.:_Al 12,0. 1 FI Production Liner: 4-1/2" 12.6#L-80 IBTM 10,445'-12,771'MD 6,051'TVD Perforated Pups 4-1/2" 12.6#TN-110 Hydril 521 9,945'-10,445'MD 2x4- ldZ €. OF TF�� 4_�'\q�//%% 0? IHESTATE :_T a,sk . 0Ilr; _c (._;?s —� =Ar4'' �f . ' s� A ( � It it CG);'-E:I` ,re:f.41111 Cc11,11'Il7 F.E yl�.c'l ,%1,i__--7=--,--__ ��, ti�,� __� _t JUL � ,__ =j --------------- 333 West Seventh Avenue " �,I, GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 v Main. 907.279.1433 OF 4LAS.°' Fax: 907.276.7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-36 Sundry Number: 314-622 Dear Mr. Alvord: 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, 6.4 Cathy . Foerster (4--- Chair DATED this day of November, 2014. Encl. RECEIVED • STATE OF ALASKA NOV 19 2014 • ALASKA OIL AND GAS CONSERVATION COMMISSION OSA \\P-‘119 \P-‘119 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug for Redrili ❑ Perforate New Pool 0 Repair Well 0 Change Approved Program 0/ Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate 0 Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska Inc Exploratory ❑ Development Q • 214102 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 100360 Anchorage,AK 99510-0360 50-103-20691-00-00• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? KQU 2M-36 ' Will planned perforations require a spacing exception? Yes 0 No D 9.Property Designation(Lease Number): 10.Field/Pool(s). t.J. J.Q. c-4..„ v Qr. c.*AA: ADL025585, 25586 % Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth ND(ft): Effective Depth MD(ft). Effective Depth TVD(ft). Plugs(measured): Junk(measured): N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 132' 16" 170.5' 170.5' Surface 3303 5' 10-3/4" 3342' 2837' 5210 psi 2470 psi Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft). N/A I N/AI 12.Attachments: Description Summary of Proposal Q . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑2 • Service ❑ 14.Estimated Date for 21-Nov-14 15.Well Status after proposed work: Commencing Operations: Oil ❑✓ • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: I f f 1-i`f WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: 6�''-� 5 ..A- GSTOR 0 SPLUG Cl17.I hereby certify that the foregoing is trud and correct to the best of my knowledge. Contact David Lee Email david.l.lee aC�conocophillips.com Printed Name G.Alvord 265-6120 Title Alaska Drilling Manager Signature 4.e_oiL Phone Date 1481120M— COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V - CQ22 Plug Integrity 0 BOP Test L/ KMechanical Integrity Test ❑ Location Clearance 0 Other: " 3 50( PS t ���l `S Spacing Exception Required? Yes ❑ NoEl/ Subsequent Form Required: /G—11 6 7 (6c-:,,,,,,9 l✓. r APPROVED BY Approved by: / COMMISSIONER / T COMMISSION Date: f/-2/_ r� �( l t Submit Form and Form 10-403(Revised 10/ 012) 12 months from the date of approval. Attachments in DuplicateA.\..., FABEM- /t.�o,ppftleitNIAILor `2 S NOV 24 2U1 a r ConocoPhillips RECEIVED Alaska N O V 19 2014 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 /►OGCC November 19,2014 /'1�J1� Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to change to plan to the approved program on 2M-36 which we are currently drilling. 2M-36 currently has had its 10-3/4" Hydril 563 L80 45.5# surface casing run and cemented at 3342' MD. As of 0600 this morning ConocoPhillips is drilling the 9-7/8"intermediate section of this well at 4111'MD. The approved permit to drill stated that we were going to drill the intermediate hole section down to 9312' MD and run 7-5/8"Hydril 563 L80 29.7#intermediate casing and cement. The 6-3/4"lateral leg was then going to be drilled and run 4-1/2" IBTM, L80 12.6# from 12852' back to 9800' MD (with perforated pups) and 4-1/2" Hyrdrill 563 TN-110 12.6# from 9800' to 9100'. This liner was going to get cemented in place with a Bonsai cement job to cover the interval from 9800'back to 9100'. The proposed changes to the approved plan are to drill our intermediate hole section down to 9312' MD and run 7- 5/8"39#TN-110 Hydril 563 casing from 9312' back to 8912' and 7-5/8"29.7#L80 Hydril 563 from 8912' back to surface and cement. A 6-1/2" lateral will then be drilled and run 4-1/2" IBTM, L80 12.6# from 12852' back to 9625' MD (with perforated pups) and 4-1/2" Hyrdril 521 TN-110 12.6# from 9625' to 9100'. A swell packer will also be placed at the A sand top. No Bonsai cement job will be pumped. This Sundry is intended to document the proposed change to the program on 2M-36,as well as request approval to proposed change. If you have any questions or require any further information,please contact me at 263-3741. Sincerely, David Lee Drilling Engineer CPAI Drilling and Wells 2M-36 Kuparuk Producer • Change to Approved Procedure (PTD #: 214-102) Current Status 2M-36 currently has had its 10-3/4"Hydril 563 L80 45.5#surface casing run and cemented at 3342' MD. As of 0600 this morning ConocoPhillips is drilling the 9-7/8"intermediate section of this well at 4111' MD Approved Procedure Changes The proposed procedure change is to eliminate the Bonsai cement job in our lateral liner section. If we eliminate the Bonsai cement job we also have to change our intermediate casing design as well as our lateral hole size and lateral liner design to stay within our design limits if we frac the well. Reasoning for Program Change ConocoPhillips is requesting the program change to simplify our lower completion and because of the AOGCC rule 20 AAC 25.030(c)and the AOGCC Kuparuk pool rules,Rule 4(0(2). If ConocoPhillips was to frac 2M-36 we believe that even though our intermediate casing shoe is set above the reservoir, it is still set in our thick confining shale layer and that the Kuparuk sands would fail before our confining layer would fail. As an added barrier we are going to put a swell packer at the top of A sand when we run our lower completion. New Proposed Drilling Program 1. Directionally drill to 7-5/8"casing point at 9312'MD/5981' TVD.Pull out of hole on elevators to the surface casing shoe. 2. Run 7.625",39#TN-110,Hydril 563 casing from 9312'back to 8912' and 7.625",29.7#L80,Hydril 563 from 8912'to surface. Top of cement to be 8300' MD/5478' TVD which corresponds to 1000' above the intermediate casing shoe as there are no hydrocarbon bearing zones. 3. Install wellhead x 7.625"packoff and test to 3500 psi. 4. Flush 10.75"x 7.625"annulus with water,followed by diesel. 5. PU 6.5"PDC Bit and 4.5"drilling assembly,with MWD and LWD logging tools. RIH,clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 6. Drill out cement and 20' of new hole. Perform formation integrity test to 14.0ppg EMW,recording results. Displace hole to lateral drilling KLA-Shield system. 7. Directionally drill 6.5"hole into the Kuparuk C and A sands and to TD at+/- 12852' MD/6044' TVD as per directional plan. 8. POOH to 7.625"shoe. TIH and perform final circulations. Pump out of Hole. 9. PU and run 4-1/2", 12.6#L80 IBTM from 12852' MD back to 9625'MD(with perforated pups)and 4-1/2", 12.6#TN-110 Hydril 21 from 9625'to 9100'with a swell packer at the top of the A sand. 10. Once liner is on bottom hydraulically release the running tool and set the liner hanger 11. Pick up running tool and set the ZXP liner top packer 12. Pressure test liner top packer 13. Circulate the well from WBM to kill weight brine 14. POOH with DP and liner running tool 15. PU 3.5"tubing upper completion 16. Land tubing. Set two wa check P T 1,7 l-° 6,) 17. Nipple down BOPE,nipple up tree and test.Pull two way check. 18. Freeze protect well with diesel by pumping into 3.5"x 7.625"annulus,taking returns from tubing and allowing to equalize. 19. Set two way check and move rig off. 20. No fractured stimulation is planned on 2M-36 unless production results indicate a frac is needed. • 2M-36 Grass Roots Horizontal A/C Sand Producer ConocoPhillips Proposed Wellbore Schematic l , LConductor To Be Installed: 16"62.6#H-40 DrilPlex WBM 9.0-9.3 PPG 13-1/2"Surface Hole Surface Casing: Below West Sak 10-3/4"45.5#L-80 Hydril 563 3,323' MD 2,807'TVD _6ND WBM .6—10.0 PPG Tubing: Keep up with 9200'3-'/z" 9.3#L-80 EUE8RD Dilution "f-7/8" Intermediate Hole J Estimated top of cement @+/_8300'MD 00 Intermediate Casing: Top Set Above C Sand 7-5/8",ZXP Liner Top Packer 9,100'MD 7-5/8"29.7#L-80 with Hydril 563 7.518"x 4-Y"Baker Flex Lock Liner hanger Surface-8,919' MD 7-5/8"39#TN-110 with Hydril 521 8,919-9,319 _ aril Trap:'::::`:: ::: .... •• ,.H:`:` A Salic€Top : '.'. 6 38 AH Swell 1 � "`^ p �kersas 41red • 9525` 6 112 PrOducbo�#Hose, WBM 12U=1-;4FT:S3 \ , HH Production Liner: 4-1/2" 12.6#L-80 IBTM 9625'-12,855' MD 6,051'TVD Perforated Pups 4-1/2" 12.6#TN-110 Hydril 521 9100'-9625' MD • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, November 19, 2014 3:31 PM To: 'Lee, David L'; Loepp,Victoria T(DOA); Bettis, Patricia K(DOA) Cc: Klem,Adam; Bearden,J Daniel;Allsup-Drake, Sharon K Subject: RE:2M-36 Can ConocoPhillips Drop the Bonsai Cement job -214-102 David, As per our discussion you have approval (verbal)to change the completion as proposed in your new sundry(314- 622). CO 173 rule 4 below allows the intermediate casing to be set within 200 ft of the production zone. By using slotted liner below the intermediate casing point(which is well within 200 ft of C sand ) you are essentially completing the well with an OH completion. The addition of a swell packer above the A sand interval will also protect the intermediate casing shoe from overpressure in the case of a possible hydraulic fracture stimulation CO 173.... Rule 4. F(2)open hole completions provided that the casing is set not more than 200 feet above the productive zone. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz©alaska.gov). From: Lee, David L [mailto:David.L.Lee@conocophillips.com] Sent: Wednesday, November 19, 2014 12:50 PM To: Schwartz, Guy L(DOA); Loepp, Victoria T(DOA); Bettis, Patricia K(DOA) Cc: Klem, Adam; Bearden, J Daniel; Allsup-Drake, Sharon K Subject: RE: 2M-36 Can ConocoPhillips Drop the Bonsai Cement job- 214-102 Good afternoon Guy, I have just finished the sundry application for the request to drop our bonsai cement job and it will be sent to the AOGCC this afternoon. In dropping the bonsai cement job our intermediate casing design does change and as we are currently drilling our intermediate hole this change in plan is a timely issue. Can I get verbal/email approval from yourself for the new plan to drop the bonsai? This way we can start to line up the required materials for our intermediate casing job. Thanks David From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@)alaska.gov] Sent:Tuesday, November 18, 2014 3:39 PM To: Lee, David L; Loepp, Victoria T(DOA); Bettis, Patricia K(DOA) Cc: Klem, Adam; Bearden, J Daniel Subject: [EXTERNAL]RE: 2M-36 Can ConocoPhillips Drop the Bonsai Cement job- 214-102 1 David, Please submit a sundry request with your reasoning and explanation for the change to the original completion. Addition of a swell packer just above the C sand would help isolate the casing shoe from downhole pressure as we discussed. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at (907-793-1226) or(Guy.schwartz©alaska.gov). From: Lee, David L [mailto:David.L.Lee@conocophillips.com] Sent: Tuesday, November 18, 2014 6:07 AM To: Schwartz, Guy L(DOA); Loepp, Victoria T(DOA); Bettis, Patricia K(DOA) Cc: Klem,Adam; Bearden, 3 Daniel Subject: 2M-36 Can ConocoPhillips Drop the Bonsai Cement job - 214-102 Good afternoon Guy,Victoria and Patricia, ConocoPhillips is currently drilling 2M-36(just finished our surface section) and will be moving into our intermediate section tomorrow. The current plan is to drill our intermediate section down to be within 50'TVD of our Kuparuk C sand (150' MD)and top set our production interval with our intermediate casing. The intermediate casing shoe would be set in our lower Kalubik shale (confining layer to our reservoir). We would then drill our lateral leg, run our perforated pup liner and perform a bonsai cement job to isolate across the shale section that we left open because we top set. This is indicated in the schematic below and the well overview. The plan is to design the well to be set up to fracture if NEEDED but we are optimistic that no frac will be required but we still designing the well just in case. 2 • 2M-36 Grass Rohs Horimrtal A/C Sand Producer ConocoPhillips Proposed Wellbore Schematic Corxtxtcr To Be hstalled: Il , ` 16"6213N H-40 a IF10 ,'.EC =i.3 PP._ 13-12" Suface Hde -J ..... :: • 2M-36 —Kuparuk A/C Sand Producer U °d 3-ii Pore Hok/Caslrg Pore Preaairel PDi PAD MID Geo Topa tt0'JTI+D' SRe 1140 FracPress.re BHA/Logs Notes 0 Ic 90 5 1 9 11 13 15 N 13.C9'Td-- F tIC 1.5'/16011 13-1/I oieVR+C) u,,/ii„ci0 X 9.0-92ppg +uotr+ 4-4stgHgr . Dalt 1418/1396103/i45.5N Drlllplex Il id 8.4 125 tiWD+GRI U30 Hydtll Syst m ppg ppg RES/PWD/ .1,541/1512 563 Dei/Ne 1 2071/1991 SDP OlesiSac 2562/2372 e ir _.... _ .�.... _ J = _ I 58'Bo 3323' 2.;0;' • • • • i4=' 94 r8' X 9-7 r6' — 7-5/8'29.7k PDCQlIS1516 L130 9ppg BPX-Sm BI} HydrI15633 9.61011 ppg I +Rotary y LSND Ste Mk+ IAI/ D+GRI II3 R ESJP!MD8148/5400 .TOC �g SDP _ 8300 826015460 Tarr ::: : . • „8524l5?6112 . • 9044/5378 HRZ U ............. . Trp Uut 10 ppg :+5'11008 921415%1 UpperKilt bIc 9491I 33? Lorne r Ka li b lc 9319' 9.?3' 6-3/C 962516062 KuparlkC4 I x 1 63/4'POC 6 pH Q.IDE13LUEX oiaal 4L8018T2 t1 1213 ppg Dpecled SYn81)+ Siuelpaakers wi emelt Km-Si 12fPP9 I PDX6+P!iD Penbrakd 8611- +G R lari i Job- _ 12845}aid Hai +Perl9oope Pips KI par.k.2 Mr, 98m' 4-W 12.61, 12.5ppg Leue13+PWD Fai t#1 TN-110 HYD I +NEU+DEN 121150/6083 563(3106- +tee b 00p 92'bo " W .. Pal,. 1 Ai 11S�S1bu 1 1235. 6osi 9811 Trp Wit TOD $ CDP ConocoPhillips is requesting the AOGCC to change the permit to allow us to top set without the bonsai per the AOGCC rule 20 AAC 25.030(c) (5) : (5) production casing must be set and cemented through, into, or just above the production interval; (6) slotted liners, pre-perforated liners, and screens installed below a production packer are considered production equipment and not casing. and the AOGCC Kuparuk pool rules, Rule 4 (f) (2): 2) The commission may approve alternate completion methods such as open hole completions provided that the casing is set not more than 200 feet above the productive zone. We would still want the optionality to FRAC the well if necessary for production reasons with the bonsai cement job removed. The proposed design without the bonsai would look like the schematic below. 4 • Crass Rocts Horizontal A 1C Sand Producer ConocoPhillips Proposed Proposed'WelIbore Schematic Condlctor To Be hstailed : 18"6218#H-40 r-_ PIP' PPG 13-12"SUface HDIe i :dr?e :f�k : i —J Surface Casino:BelowWest.aak 10-3j4"46.5*L-80 Hydrii 563 — 3.33'M D 2,907'TVD D A,6M - Ii.0 PPG Tub m: uE• 11th 12200 3.35"9.3#L- 0 EUE8RD y,"1 htermediate Hde ^-' E 11,.411..1 f:r.•Y•_a"en.4t+.-&:c01.1D htermediate Cadnp:Top Set Pbotie C Sand ` • 7-518 29.7#LEO with Hydril 563 • Surface-8819' MD 7-52'39#TN-1 10(fifth Hydril 583 8,319-9,319 ::::NSand c¢i:=:::::•:•:•:•:•t :&t3"f3M$B!I:;:•:•:_:•:•:;:•:•:;: :•:•:•:•: :•:•:•:•:•:•: _40 • • • • • • • • . . . . . . . . . . . . . . . . : Production Liner: :'. . . . . . . . . . . . . . . . 4112'12.6#L-80 IBTM 9800'-12.866'MD 6.061'TVD Perf crated Pups 4112'1216#C-110 Hydril 5121 9100'-9800'MD Please let me know if you need any further information to aid in the decision process. Thanks David Lee 5 aAA- 3(- P71) ale-loZ ~f ConocoPhillips ConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska A G4ted3i nye feenrfiVOM X'? " V41�.7 =m Tolerable Collision Collision of 2M-36 Kuparuk CIA sand producer with Ike existing Kuparuk 2M-28 well. Risk Worksheet �„ �` ",��� ''�, _ ,iii � . ,,,` .c�. � �`� based on Rev.1-29 Jul 99 Well 2M-36 fails anti-collision with 2M-28 based on WP07. The anti-collision fails with 2M-28 between 100'and 550'. Currently there would be an environmental and HSE risk of hitting the well Use this sheet to describe a wet Interference scenario where QRA since 2M-28 has a shut in tubing pressure of 1600 psi. To eliminate the HSE and environmental may be applicable.Check fust that the scenario really is different risk we will set a deep plug in 2M-28 and bleed off the surface pressure prior to drilling the well. tf from those descrtbed on existing workshee t 2M-36 intersects 2M-28 there would be damage to the 2M-28 well and it would have to be } abandoned and replaced. 2M-36 would also have to be plugged and the surface section redrilled. 1.,•-eisill David Lee ;..,,,.,,Al2, No risk of a well control Issue exists because if 2M-28 is hit,we would be colliding with the well that �� r_ has zero pressure in the tubing(as deep plug set and tested before we drill well). -Ai $a Dan Bearden k.\ trd" S Do the consequences STI3P 411)"O of collision iodide a *Yes • Are the °NO risk to personnel or the consequences environment? of collision � Major risk i 1 1 Parte ` �CeNTIN, °Yes i e _ No HSE risks exist with 2M-36 intersecting 2M-28 while drilling as 2M-28 will have a deep plug set to isolate the reservoir.After plug is set the surface $15,000,000 pressure will also be bleed off. An economic concern exists and it would be the cost of plugging back and sidetracking the surface section that we are drilling as well as the loss of 2M-28(have to abandon the well and drill a replacement well). 'p dtbproabi . ` r t1 C= $15,000,000z 7y mpdrifito er Eg �- .1 Is there a practical way ; ti to substantial) reduce VA-0l , ()Yes y ®No nit iia:A either the probability of -V-Mill? `~� collision or the severity V= $16,900,000 of the consequences? C s plana L�. � ytt., .-,-, '''-' �fal"t V are. + F= 0.01 t -„_ _ t lirr'::_tiwitft,„],..K.:71 V= $0 VF/C= 0.011266667 � --Ir..-� j� '40.;-,r;,taiw if V F - 1 then close approach tolerances need not be set d if 'tnt1 t i l_ °Gto`tottoti roll t C II OF jt hto twetgh he'lis)- r• -ac t,-!,0,4% � r^1t s.. C ' 1 then Tolerable Collision Risk=1 in C 1 V F M= 20 1._ F=1/M= 0.05 Tolerable Collision Risk= 1 in 89 ConocoPhilli s ConocoPhillips Alaska,Inc Drilling Anti-Collision Management Alaska A Tolerable Collision OSA e,` ;eal6e-fkirr° 4W } Collision of 2M-36 Kuparuk C/A sand producer with the existing Kuparuk 2M-03 well. Risk Worksheettpitd }:ft � � owt based on Rev.1-29 Jul 99 Well 2M-36 fails anti-collision with 2M-03 based on WP07. The anti-collision fails with 2M-03 between 550'and 650'. Currently them would be an environmental and HSE risk of hitting the well Use this sheet to describe a well Interference scenario where QRA since 2M-03 has a shut In tubing pressure of 1400 psi.To eliminate the HSE and environmental may be applicable.Check first that the scenario realty Is different risk we will set a deep plug In 2M-03 and bleed off the surface pressure prior to dulling the well. If from those described on existing workshee11 2M-36 intersects 2M-03 there would be damage to the 2M-03 well and it would have to be • r t`�F, abandoned. 2M-36 would also have to be plugged and the surface section redrilied. No risk of a x.`.•=�m'"}�zr + well control issue exists because if 2M-03 Is hit,we would be colliding with the well that has zeroDavid Lee V rm':',.'04:4•0.,,,,-4, a1ik pressure in the tubing(as deep plug set and tested before we drill well). 4P-01 Dan Bearden ,1 i Do the consequences O No of collision include a .Yes Are the Ow i P risk to personnel or the consequences environment? of collision Major risk i l tl e r Yes ItatOr a , a, AlKtaift$tttogr:x w: No HSE risks exist with 2M-36 intersecting 2M-03 while drilling as 2M-03 will have a deep plug set to isolate the reservoir.After plug is set the surface $15,000,000 pressure will also be bleed off. An economic concern exists and it would be the cost of plugging back and sidetracking the surface section that we are drilling as well as the loss of 2M-03(have to abandon the well and dull a replacement well). i' 4 } ca 'M r rr�ilai � M `t�I C= $15,000,000 ix[`�f t 1-.1 . 1i °t4 a e 1 o + r 0 zTMt_ ,,ilei LS'�ti, i ,-w"Y i`1' .t'irftli ` PR"t}'i• ,' eaai. x�' • Is there a practical way oYes to substantially reduce ®rvo t 301PAt 170-1 either the probability of � "C.ran.., collision or the severity V= $16,900,000 of the consequences? hies fkiils-k,. utgn II u th@ e ' 1aII t l rTkLSRtxi)f @rotiR 0--;10440U404000000011441400104102111 j F= 0.01 i tlnt4te tte1€4-4 ` 5 1-1i-i"A V= $0 tt st'~—.'7_' i V F/C= 0.011266667 4 o If V F > 1 then close r4 e'inoettali .71-R--.! ,)fyd t....&-Xi_. aC approach tolerances need not be set I. ri t� tigEtst . r [sf >j 3dtr' ��� s i -x ,�,- ,tom. ��- IT V F lrgl t� ._ � ,, ue ,.; ��� � C < 1 then Tolerable Collision Risk=1 In C/V F M= 20 F=1 /M= 0.05 ` Tolerable Collision Risk= 1 in 89 . 1 `/ ConocoPhil li ps ConocoPhillips Alaska, Inc Drilling Anti-Collision Management Alaska A Tolerable Coll s onets i > a .-• _s '- - ,.graS=- Collision of 2M-36 Kuparuk C/A sand producer with the existing Kuparuk 2M-01 welt. Risk Worksheet '- is - ��_ _ W _ based on Rev.1-29 Jul 99 Well 2M-36 fails anti-cotlision with 2M-01 based on WP07. There is no immediate danger to life or impact on the environment if wet 2M-36 Intersects 2M-01 because 2M-01 is currently shut it and Use this sheet to describe a well interference scenario where QRA un-useable. 2M-36 is the wet replacing 2M-01. If 2M36 Intersects 2M-01 there world be damage may be applicable.Check first that the scenario really is.gifferent to the 2M-01 well but currently it is not being used so there is no major economic toss. 2M-36 from those described on existing workshee� 1 t t would also have to be plugged and the surface section redrtlled. No risk of a well control issue _J exists because if 2M-0l is hit,we would be colliding with the well with kill weight fluid in the hole r>?�� zl '"�I` �` (since 2M-01 Is shut in). • t�E D ,' David Lee r V ' ,Y i ;tg' V Dan Bearden't i Si Do the consequences ® t Are the • "° of collision induce a ®Y� "0 risk to personnel or the consequences environment? of collision Major risk • V> s Ab-kt �,? 0ves No HSE risks exist with 2M-36 intersecting 2M-01 while drilling as 2M-01 is shut in and cemented off. An economic concern exists and it would be the cost $3,000,000 of plugging back and sidetracking the surface section that we are drilling as well as the definite loss of the 2M-01. + y�'q t l ,r .1- 4,��t * 004; C= $3,000,000 ak t •1 Is there a practical way1 pro to substantially reduce �€#tte +IQ ftp either the probability of D ;_1-.0Ifjh011kigidiiiigig collision or the severity V= $16,900,000 of the consequences? /0l lr eJy q�hliB*k'I ljt0'k:l� . .3. ,i hilt . 4. 14 j F= 0.01 Ts ,: V= $0 ' L V F/C= 0.056333333 ,---;.:1 -1.-,.- x r If V F > 1 then close approach tolerances need not be set �'` �Y�. {��y�ti;�t ,�;�T�If1�it� pp IS ii C l�lntlQcryt[ If V F ! --" F S*4—x C < 1 then Tolerable Collision Risk=1 in C 1 V F M= 20 F= 1 /M= 0.05 Tolerable Collision Risk= 1 in 18 y3y rt� ��\� %%% �a HE STATE A. �is%A. :i. E . _ r %_. .moi, r / -i L r°T / ;; M=-:_ __�_1 Wc51 Seienth Avur^uc (.: ()\,'?.R\()R Si: \\ PAR\r.`: 1 Anchc 333 We Ala Ya 99551 3572 \ air 97779 1433 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M-36 ConocoPhillips Alaska, Inc. Permit No: 214-102 Surface Location: 5166' FNL, 24' FEL, Sec. 28, T11N, R08E, UM Bottomhole Location: 2693' FNL, 4193' FEL, Sec. 29, T11N, R08E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, , 1 1 i°41--• "iL" ------ Cathy '. Foerster Chair i DATED this i Jday f August, 2014. STATE OF ALASKA KA OIL AND GAS CONSERVATION COM )N JUL 0 9 201E4 PERMIT TO DRILL 20 AAC 25.005 /g►l^)rV^,/ la Type of Work: 1 b.Proposed Well Class: Development-Oil 0• Service- Winj ❑ Single Zone 0 lc.Specify if ' 1S p,.posed for: Drill 0. Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name. 5. Bond: Blanket 0 , Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No 59-52-180 2M-36 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD. 12846 - TVD: • 6044 Kuparuk River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease�Number). Surface: 5166'FNL 24'FEL,Sec.28 Twn 11N Rng 8E,UM . ADL025585,? .s ac ��AA Kuparuk Oil Pool - Top of Productive Horizon 8.Land Use Permit: 13.Approximate Spud Date: 3939'FNL 1085'FEL,Sec.29 Twn 11N Rng 8E,UM ' ALK2672 11/1/2014 Total Depth: 9.Acres in Property: 410, 14.Distance to Nearest Property: 2693'FNL 4193'FEL,Sec.29 Twn 11N Rng 8E,UM • SOS I -2491 1700' 4b.Location of Well(State Base Plane Coordinates-NAD 27). 10.KB Elevation above MSL:133.5 feet k 15.Distance to Nearest Well Open Surface: x-487816.44 y- 5948985.91 Zone-4 GL Elevation above MSL:105.5 feet - to Same Pool. 400' 16.Deviated wells: Kickoff depth: 450 feet t 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.8 degrees , Downhole: 3888 psi • Surface: 3217 psi , 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 63# H-40 Welded 80' 28' 28' 108' 108' 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 3308' 28' 28' 3308' 2795' 1320 sx 11.0ppg DeepCRETE,205 sx 12.0ppg DeepCRETE 9.875" 7.625" 29.7# L-80 Hydril 563 9312' 28' 28' 9312' 5981' 285 sx 15.8ppg Class'G' 6.75" 4.5" 12 6# L-80 IBTM 3046' 9800' 6071' 12846' 6044' Perforate pups(no cement) ...5) 6 75" 4.5" 12.6# TN-110 Hydril 563 712' 9100' 5899' 9800' 6071' 150 sx 15.8ppg Class'G' II _ 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) yr3,"�" 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 0 Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. David Lee @ 263-3741 Contact david.l.lee@conocophillips.com Email Printed Name G.Alvord Title Alaska Drilling Manager Signature A lit Phone 265-6120 Date 7(6(z 0 14- Commission Use Only Permit to Drill API Number: Permit Approval( See cover letter for other Number: ca 9- 90/. 50- X0.3 �- a0(e9 i - 00 -cc Date: �( I (71-1 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 1[ �J Other: /-j 0 P f-c i.1. f-,- 5----- (.9�0 5 / Samples req'd: Yes❑ No l[ Mud log req'd.Yes❑ No 0 H2S measures: Yes IBI No❑ Directional svy req'd.Yes[Jf No❑ Spacing exception req'd: Yes❑ No1E1 Inclination-only svy req'd:Yes❑ No I APPROVED BY p Approved by: 9COMMISSIONER THE COMMISSION Date: [J -is/ ieihN*Llate Submit ane Form 10-401( evised 10/2012) This permit is2dR of approval(20�►C 25.005(8)) Att hments in Duplicate VIF f/111714 l l /r`( �4 ConocohiIIips Alaska RECEIVED Post Office Box 100360 JUL U 9 2014 Anchorage, Alaska 99510-0360 //�� David Lee Phone (907) 263-3741 AOGCC July 1, 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 2M-36 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore producer well, a horizontal well in the Kuparuk C and A sands.' The expected spud date for 2M-36 is, November 1st, 2014. The Kuparuk in the 2M consists of marine progradational A sands directly overlain by transgressive C sand deposits. The 2M-36 well will be drilled down structure to the northwest with a planned lateral length of approximately 3100', contacting both the C and A reservoir. There is one major fault with a throw anticipated between 35 – 50 feet. There are no known H2S issues associated with the drilling of this well. The well is anticipated to see a reservoir I) pressure of–12.3 ppg equivalent during the drilling of this well. For this reason the well is planned with a Bonsai cement job in the liner section so that the intermediate casing can be top set above the / reservoir. A FIT test to a minimum of 12.5 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 14.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 2M-36. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 2500 psi) and will be tested on a 14 — day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be 2 kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sincerely, r / David Lee Kuparuk Drilling Engineer .iation for Permit to Drill,Well 2M-36 Revision No.0 Saved: 14-Aug-14 Permit It - Kuparuk Well #2M-36 ;; r456 ; rt Application for Permit to Drill Document ,;; MtWeI Maximize, Well V o l kt e Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) • 2 Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 MC 25.005(c)(4) 3 4. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 MC 25.005(c)(5) 3 5. Casing and Cementing Program 3 Requirements of 20 AAC 25.005(c)(6) 3 6. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 7. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (Drilplex AR) 5 Intermediate Hole Mud Program(LSND) 5 Lateral Mud Program(Ku,-Shield) 5 8. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 9. Seismic Analysis 5 Requirements of 20 MC 25.005(c)(10) 5 10.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005(c)(11) 5 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 2M-36 PERMIT.doc Page 1 of 8 Printed:14-Aug-14 'ication for Permit to Drill,Well 2M-36 Revision No.0 Saved'8-Jul-14 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Cement Program Summary 8 Attachment 4 Well Schematic 8 1. Well Name Requirements of 20 AAC 25.005(t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6).For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2M-36 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 5166' FNL 24' FEL Sec. 28 Twn 11N Rng 8E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 133.5'AMSL Northings 5,948,985.9 Eastings: 487,816.4 Pad Elevation 105.5'AMSL Location at Top of Productive Interval 3939' FNL 1085' FEL Sec. 29 Twn 11N Rng 8E UM (Kuparuk"C"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9483' Northings: 5,950,225.9 Eastings:481,475.1 Total Vertical Depth, RKB: 6030' Total Vertical Depth, SS: 5896' Location at Total Depth 2693' FNL 4193'FEL Sec. 29 Twn 11N Rng 8E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12846' Northings: 5,951,479.9 Eastings: 478,367.3 Total Vertical Depth, RKB: 6044' - Total Vertical Depth, SS: 5910' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent weilbores within 200 feet of any portion of the proposed well; 2M-36 PERMIT.doc Page 2 of 8 Printed:8-Jul-14 ORIGINAL lication for Permit to Drill,Well 2M-36 Revision No.0 Saved:8-Jul-14 Please see Attachment 1: Directional Plan 2M-36 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 25.035,20 MC 25.036,or 20 MC 25.037, as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 2M-36. Please see information on the Nabors 9ES blowout prevention equipment placed on file with the Commission. Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Kuparuk sands in the 2M area are 0.64 psi/ft, or 12.3 ppg EMW (equivalent mud weight). Pressures are predicted based on current pressure measurement of shut in injectors on the 2M pad. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the Kuparuk"C/A"sand formation is 3,217 psi, calculated thusly: MPSP = (6,075 ft TVD)(0.64 - 0.11 psi/ft) = 3,217 psi ✓ (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (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: 2M-36 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(1); 2M-36 will be completed with 7-5/8" intermediate casing landed just above the Kuparuk C sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner,pre- perforated liner,or screen to be installed; 2M-36 PERMIT.doc Page 3 of 8 Printed:8-Jul-14 ORIGINAL ication for Permit to Drill,Well 2M-36 Revision No.0 Saved:8-Jul-14 Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 63 H40 Welded 80 28/ 28 108 / 108 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 10.75 13.5 45.5 L-80 Hydril 563 3308 28/ 28 3308/ 2795 1320 sx 11.0 ppg DeepCRETE lead, 205 sx 12.0ppg DeepCRETE Tail • Cement Top planned @ 8300' 7.625 9.875 29.7 L-80 Hydril 563 9312 28/ 28 9312/ 5981 MD/5492'TVD Cemented w/ 285 sx 15.8 ppg Class 4.5 6.75 12.6 L-80 IBTM 3046 9800/ 6071 12846/ 6044 Perforated pups(no cement) 4.5 6.75 12.6 TN- Hydril 563 712 9100/ 5899 9800/ 6071 Bonsai cement job—150 sx 110 15.8ppg Class'G' 6. Diverter System Information Requirements of 20 AAC 25.005(C)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 2M-36 surface hole. Please see diagrams of the Nabors 9ES diverter system on file with the Commission. 2M-36 PERMIT.doc Page 4 of 8 Printed:8-Jul-14 ORIGINAL ication for Permit to Drill,Well 2M-36 Revision No.0 Saved.8-Jul-14 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.' (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25,033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Drilplex AR) Spud to Base Base Permafrost to Permafrost Surface TD Value Value Density(ppg) 9.8-10 ' 9.8-10 Funnel Viscosity 300 200 (seconds) Yield Point 50-80 35-50 (cP) pH 10.8-11.2 10.8-11.2 LSYP 30-50 25-45 Intermediate Hole Mud Program (LSND) 10 3/4"Csg Shoe to 7-5/8"Csg Point Lateral Mud Program (KLA-Shield) Value Value Density(ppg) 9.6 - 10 Density(ppg) 12.5 Fann 35 6 RPM Fann 35 6 RPM (lb/100 ft2) 10 - 12 (lb/100 ft2) 6-8 API Filtrate Fluid Loss <10 (cc/30 min)) 6 (mL/30min) pH 9.5 — 10.0 pH 9.5-10 Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nabors 9ES. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Dnll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 2M-36 PERMIT.doc Page 5 of 8 0RIGINAL Printed:8-Jul-14 lication for Permit to Drill,Well 2M-36 Revision No.0 Saved:8-Jul-14 (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16"insulated conductor to +/- 80' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig Nabors 9ES. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13.5"hole to casing point at +/- 3308' MD/ 2795'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10.75", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 9.875"bit and 7"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 12.5ppg EMW, recording results. 8. Directionally drill to 7-5/8"casing point at 9312' MD/ 5981'TVD. Pull out of hole on elevators to the surface casing shoe. 9. Perform clean out run prior to running casing. 10. Run 7.625", 29.7# L80, Hydril 563 casing to surface. Top of cement to be 8300' MD/ 5478'TVD which corresponds to 1000'above the intermediate casing shoe as there are no hydrocarbon bearing zones. 11. Install wellhead x 7.625" packoff and test to 3500 psi. 12. Flush 10.75"x 7.625"annulus with water, followed by diesel. 13. PU 6.75"PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 14. Drill out cement and 20'of new hole. Perform formation integrity test to 14.0ppg EMW, recording results. Displace hole to lateral drilling KL,-Shield system. 15. Directionally drill 6.75" hole into the Kuparuk C and A sands and to TD at +/- 12846' MD/ 6044'ND as per directional plan. 16. POOH to 7.625"shoe. TIH and perform final circulations. Pump out of Hole. 2M-36 PERMIT.doc Page 6 of EJRIGINAL 8 Printed:8-Jul-14 ication for Permit to Drill,Well 2M-36 Revision No.0 Saved.8-Jul-14 17. PU and run 4-1/2", 12.6# L80 IBTM from 12852' MD back to 9800' MD (with perforated pups) and 4- 1/2", 12.6# TN-110 Hydril 563 from 9800'to 9100'. This liner is a Bonsai liner and will be cemented to cover from 9800' MD back to 9100' MD. 18. Once liner is on bottom circulate and condition mud and prepare for the Bonsai cement job 19. Drop dual wiper plug and latch into reverse plug catcher. Set liner hanger by applying pressure through PPIT, slack off 30K to ensure liner hanger has set 20. Continue to pressure up to release the liner running tool, pick up on drill pipe to confirm running tool is free. 21. Place fillup tool on depth and inflate the ECP (external casing packer) positioned below the top of the Kuparuk A Sand. 22. Position inflation tool across cementing stage tool and open the cementing stage tool just above the ECP with pressure 23. Pump liner cement job with 15.8 ppg Class"G"slurry and 40% excess in open hole which will bring the top of cement above the liner top 24. Without bleeding off pressure, pick up on drill string and close stage tool 25. Set down on drill string to set liner top packer 26. Pick up and reverse fluid into inner string 27. Pressure up inner string to burst drain sub, circulate remaining cement from the inner string the long way 28. Place PPIT tool into liner and pressure test top packer. 29. POOH with liner running tool 30. PU 3.5"tubing upper completion, circulate around with kill weight brine 31. Land tubing. Set BPV 32. Nipple down BOPE, nipple up tree and test. Pull BPV. 33. Freeze protect well with diesel by pumping into 3.5"x 7.625"annulus, taking returns from tubing and allowing to equalize. 34. Set BPV and move rig off. 35. No fractured stimulation is planned on 2M-36 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authonzation under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 2M-36 PERMIT.doc Page 7 of 8 Printed:8-Jul-14 ORIGINAL 'cation for Permit to Drill,Well 2M-36 Revision No.0 Saved:8-Jul-14 Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic 2M-36 PERMIT.doc Page 8 of 8 Printed. 8-Jul-14 D I 2M-36wp08 6.530 Plan Summary SURVEY PROGRAM Dep From Depth To Survey/Plan T 'i�oo� 28.00 1000.00 2M-36wp08 (2M-36) GYD-GC-c -� ` �► 000.00 12845.75 2M 36wp08 (2M-36) MWD+IFR AK CAZ 'AVAI \•j CASING DETAILS _ ..,.4101.!::.__., :,,,,,, , -----!-----.. TVD MD Name Size -. 2795.00 3307.48 10-3/4"x13-1/2" 10-3/4 5980.78 9312.00 7-5/8"x9-7/8" 7-5/8 ...... ......... :'. 6043.50 12845.75 4-1/2"x6-3/4" 4-1/2 0 - T7i�n - 0° 5- W Slrse W Sak 7-5 7A81Z 3 -5 1,0,003/4"x13-1/2" a� Unu i 4� i O 2� 0e� o a g I [�'� Lr)o ro o8 0i cn _ I _ ca y0 O - �� Nc) 5/8"x9-7/8b o 4-1/2"x6-3//' 3ase Pett 18MShtl3-1/2" 1 �� /2"x6-3/4" 00 �o tq° o° a r0 o� A - N i 0 .6a) .-Or u0 , 0 I 1 rill I I 0 0 3000 6000 9000 12000 0 1500 3000 4500 6000 7500 •e i0 co Measured Depth Horizontal E eparture HI 330 30 60 1 I a 300 -4,.: so 1995 2345 - �� in I I wig j - z7a % � zzo 0 30- o - r295 m Sse� � s +_ '� - 8085 A • _ _ .. .... 240 M i�u� 4P:a ^ 120 - ma 108115 11095 0 I I I I I [ 1 1 [ 1 Ili III 210. ".Ars kv -q'.AraLtIfiklig1511e'n,1'4 0 1500 3000 4500 6000 7500 9000 10500 12000 180 12105 - 12495 SECTION DETAILS +)os - 'Ma Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target - 1 28.00 0.00 0.00 28.00 -105.50 0.00 0.00 5948735.99 1627849.32 0.00 0.00 0.00 2 445.00 0.00 0.00 445.00 311.50 0.00 0.00 5948735.99 1627849.32 0.00 0.00 0.00 = 1504��u 3 595.04 2.25 346.00 595.00 461.50 2.86 -0.71 5948738.85 1627848.61 1.50 346.00 1.41 4 1205.89 17.52 346.00 1195.00 1061.50 104.32 -26.01 5948840.34 1627823.49 2.50 0.00 51.61 5 1480.54 20.37 326.63 1455.00 1321.50 184.46 -62.35 5948920.53 1627787.28 2.50 -75.00 107.09 Base Permafrost 6 1580.54 20.37 326.63 1548.74 1415.24 213.53 -81.50 5948949.63 1627768.18 0.00 0.00 132.99 1983.5 7 2893.67 57.49 277.31 2572.60 2439.10 489.83 -795.09 5949227.10 1627055.13 3.50 -62.83 893.31 8 8912.20 57.49 277.31 5807.24 5673.74 1135.62 -5829.25 5949881.23 1622022.55 0.00 0.00 5926.69 W Sak 9 9312.00 70.95 281.46 5980.78 5847.28 1194.90 -6183.39 5949941.10 1621668.55 3.49 16.47 6284.29 -2364.5 10 9332.00 70.95 281.46 5987.31 5853.81 1198.66 -6201.92 5949944.88 1621650.03 0.00 0.00 6303.17 11 9711.86 85.31 285.14 6065.27 5931.77 1284.23 -6562.61 5950031.05 1621289.52 3.90 14.48 6673.76 12 9726.96 85.31 285.14 6066.50 5933.00 1288.16 -6577.14 5950035.00 1621275.00 0.00 0.00 6688.81 2M-36 DL 21Feb14 T1 13 9921.91 89.78 287.07 6074.84 5941.34 1342.16 -6764.20 5950089.31 1621088.04 2.50 23.39 6883.46 14 10295.53 89.78 287.07 6076.25 5942.75 1451.82 -7121.37 5950199.56 1620731.10 0.00 0.00 7256.76 15 10587.85 91.29 294.22 6073.50 5940.00 1554.81 -7394.72 5950302.99 1620457.94 2.50 78.10 7547.29 2M-36 T2 06May14 JC 16 10612.17 91.78 294.22 6072.85 5939.35 1564.78 -7416.90 5950313.00 1620435.79 2.00 0.40 7571.27 17 10708.06 91.78 294.22 6069.88 5936.38 1604.11 -7504.30 5950352.47 1620348.46 0.00 0.00 7665.79 18 10796.88 90.00 294.23 6068.50 5935.00 1640.55 -7585.29 5950389.04 1620267.54 2.00 179.79 7753.37 2M-36 T3 06May14 JC 19 10807.36 89.79 294.22 6068.52 5935.02 1644.85 -7594.84 5950393.35 1620258.00 2.00 -178.58 7763.70 20 11494.21 89.79 294.22 6071.03 5937.53 1926.68 -8221.21 5950676.20 1619632.16 0.00 0.00 8441.06 Base W Sak 21 11552.74 88.62 294.23 6071.84 5938.34 1950.69 -8274.57 5950700.30 1619578.84 2.00 179.75 8498.77 2M-36 T4 06May14 JC 22 11553.09 88.62 294.22 6071.85 5938.35 1950.83 -8274.89 5950700.44 1619578.53 2.00 -95.60 8499.11 23 11764.72 88.62 294.22 6076.95 5943.45 2037.64 -8467.83 5950787.56 1619385.75 0.00 0.00 8707.76 24 11873.75 90.80 294.23 6077.50 5944.00 2082.38 -8567.25 5950832.46 1619286.41 2.00 0.18 8815.28 2M-36 T5 06May14 JC 25 12023.88 90.80 294.23 6075.40 5941.90 2143.98 -8704.15 5950894.29 1619149.64 0.00 0.00 8963.32 26 12123.25 93.78 294.05 6071.44 5937.94 2184.59 -8794.74 5950935.04 1619059.12 3.00 -3.43 9061.25 27 12312.25 93.78 294.05 6058.99 5925.49 2261.45 -8966.96 5951012.18 1618887.04 0.00 0.00 9247.33 28 12388.13 91.50 294.00 6055.50 5922.00 2292.30 -9036.18 5951043.15 1618817.88 3.00 -178.71 9322.11 2M-36 T6 06May14 JC 29 12845.75 91.51 293.99 6043.50 5910.00 2478.34 -9454.12 5951229.87 1618400.30 0.00 -56.89 9773.56 2M-36 17 06May14 JC =Base -55 5p5 Top HRZ ®� {@ C FZ Top A-3 Surface Location Geodetic Datum: North American Datum 1983 Magnets Model: BGGM2013 TM Depth Reference: Plan:28+105.5©a 133.50usft(Nabors 9ES) Magnetic Model Date: 23-Nov-13 System(SS)Reference: Mean Sea Level Magnetic Declination: 19.45° North / Y: 5948735.99 To convert a Magnetic Direction to a True Direction,Add 19.45°East Ground Level/Mud Line: 105.50 East/X: 1627849.32 Rig: Nabors 9ES NO GLOBAL FILTER:Using user defined selection&filtering criteria 0 -sIGINAL 11 N 0 MOM I N CU MMMO a w a '- � `0 N M M co r O Yo L L C tG `V V Y Y a a a r8 0 CRIGINAL -0 Z z « A \\ ` \ q § w / /\ S \\ ) 2 _ k ) . .. k / / ° l \ ) ® \ ) _ co CO 00 < / See \ ƒ m . ») 8 )/ / § 2DD ( ]_1a 0 k § C.) co ] _i \ro A mR. oil II a) W � f k5 - ) k t 13 ) # ) ) 2 � k \ \ G « J2 � - \ 5 E - - 22 � k § 2E � k § 2ao \ \ \ \ � 0 ° § i 2 ww ■ E = o m } CO 3ER E I- � £a / M § 2 W $ k § / 0 z a& ( 9 E o ) a 7 # 2 C .co § 2CV 21 a \ k \ 2 B E k z _ _ _ � ) kj = : § ƒ g ) / e co o00 2 § i a3 E \ } k\ I 2 § § ` k m CO 2 n % t .Co % § /} k m co ; / 0 0. @ ■ a. ~ % a \ \ ) 7f § Q § .. ° . 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ORIGINAL Aimm MD Inc Azi TVD +N/-S +E/-W DLeg TFace Target 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 28 445 2M-36wp08445.00 0.00 0.00 445.00 0.00 0.00 0.00 0.00 3 595.04 2.25 346.00 595.00 2.86 -0.71 1.50 346.00 1.41 445 795 4 1205.89 17.52 346.00 1195.00 104.32 -26.01 2.50 0.00 51.61 28.00 To 12845.75 51480.54 20.37 326.63 1455'00 184.46 -62.35 2.50 -75.00 107.09 795 1195 6 1580.54 20.37 326.63 1548.74 213.53 -81.50 0.00 0.00 132.99 I 7 2893.67 57.49 277.31 2572.60 489.83 -795.09 3.50 -62.83 893.31 8 8912.20 57.49 277.31 5807.24 1135.62 -5829.25 0.00 0.00 5926.69 1 195 1595 16:54,July 07 2014 99312.00 70.95 281.46 5980.78 1194.90 -6183.39 3.49 16.47 6284.29 109332.00 70.95 281.46 5987.31 1198.66 -6201.92 0.00 0.00 6303.17 1595 1995 11 9711.8685.31 285.14 6065.27 1284.23 -6562.61 3.90 14.48 6673.76 aLOBAL FILTER APPIED: 129726.96 85.31 285.14 6066.50 1288.16 -6577.14 0.00 0.00 6688.81 2M-36 DL 21Feb14 T1 1995 - 2395 139921.91 89.78 287.07 6074.84 1342.16 -6764.20 2.50 23.39 6883.46 140295.53 89.78 287.07 6076.25 1451.82 -7121.37 0.00 0.00 7256.76 2395 2795 190587.85 91.29 294.22 6073.50 1554.81 -7394.72 2.50 78.10 7547.29 2M-36 T2 06May14 JC 100612.17 91.78 294.22 6072.85 1564.78 -7416.90 2.00 0.40 7571.27 2795 3182 Depth From Depth To Sunny Flan Tool 1710708.06 91.78 294.22 6069.88 1604.11 -7504.30 0.00 0.00 7665.79 26.00 1000.00 2M-36,08(2r11,36) GYPGCS.5 1000.60 12665.75 20.415,08(2MJ6) MW1:.1F11-accszsC 190796.88 90.00 294.23 6068.50 1640.55 -7585.29 2.00 179.79 7753.37 2M-36 T3 06May14 JC 190807.36 89.79 294.22 6068.52 1644.85 -7594.84 2.00 -178.58 7763.70 3182 3995 CASING DETAILS 201494.21 89.79 294.22 6071.03 1926.68 -8221.21 0.00 0.00 8441.06 2111552.74 88.62 294.23 6071.84 1950.69 -8274.57 2.00 179.75 8498.77 2M-36 T4 06May14 JC 3995 4895 TVD MD Name Size 221553.09 88.62 294.22 6071.85 1950.83 -8274.89 2.00 -95.60 8499.11 2795.00 3307.48 10-3/4"x13-1/2" 10-3/4 231764.72 88.62 294.22 6076.95 2037.64 -8467.83 0.00 0.00 8707.76 4895 - 5695 5980.78 9312.00 7-5/8"x9-7/8" 7-5/8 241873.75 90.80 294.23 6077.50 2082.38 -8567.25 2.00 0.18 8815.28 2M-36 T5 06May14 JC 6043.50 12845.75 4-1/2"x6-3/4" 4-1/2 292023.88 90.80 294.23 6075.40 2143.98 -8704.15 0.00 0.00 8963.32 282123.25 93.78 294.05 6071.44 2184.59 -8794.74 3.00 -3.43 9061.25 5695 6595 2712312.25 93.78 294.05 6058.99 2261.45 -8966.96 0.00 0.00 9247.33 282388.13 91.50 294.00 6055.50 2292.30 -9036.18 3.00 -178.71 9322.11 2M-36 T6 06May14 JC 6595 7395 999645 75 Q1 51 291 99 6.(14.1 511 94711 44 -9454 17 11 nn -56 FM 9779 se 9MAfi T7 neMayl4 I(: 7395 8295 8295 9095 0/360 9095 9960 rR�*�t +doe=i. II : 4P43Eitett• 12884 l•,4 .li�rrel,' 90 ght �w �, ,tom-e?aa= •4ioi 2M-3( )rilling Hazards SIOnimary 13.5" Open Hole / 10.75" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets), pumping out of hole or backreaming as needed. Anti-Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accuracy. Anti-collision concerns with 2M-O 1 (shut in producer with no communication to reservoir), 2M-03 (will shut in producer and set a deep plug prior to drilling) and 2M-28 (will shut in producer and set a deep plug prior to drilling). Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9.875" Open Hole / 7.625" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight to cover expected reservoir pressure Lost circulation Moderate Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets), pumping out or backreaming as needed 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Top setting Pressure the reservoir with intermediate casing. Nearby injectors are shut in to determine what are reservoir pressure is going to be and to bring the reservoir pressure down as low as possible. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible, stabilized BHA Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, control ECD Differential Sticking Moderate Follow mud program, keep pipe moving when able Bonsai Cement Job Moderate``, RNewrro�cendure for ConocoPhillips, Baker has extensive I 1 € G I \I /ti [ Attachment 2-2M-36 Drilling Hazards Summarydoc JS I! LLJJ V {r1 7/8/20148.58.:15AM experience with BP on slope, '''ze Baker experience ,Getting Liner to Bottom Mt, ate Monitor T&D real time for ea_ _ aigns of issues,properly clean hole prior to coming out of hole to run liner, rotation possible if necessary. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out or backreaming if necessary ORIGIN /AL Attachment 2-2M-36 Drilling Hazards Summary.doc 7/8/2014 8:58.15 AM • 2M-36 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casin. (V1 Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 141 Volumes are based on 250%excess in the permafrost and 50%excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2682' MD. Client:CPAI Revision Date:July 1, 2014 Prepared by:Jenna Houston Location:Anchorage,AK Lead Slurry Minimum pump time: -250 min. (pump time plus 120 min.) Phone: (907)263-4207 11 ppg DeepCRETE- 1.91 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@slb.com 0.6381 ft3/ft x 110 x 1.0 (0%excess) = 71 ft3 0.3637 ft3/ft x (1530-110) x 3.50 (250%excess) = 1808 ft3 < TOC at Surface 0.3637 ft3/ft x (2682-1530) x 1.50 (50%excess) = 629 ft3 1808 ft3+629 ft3+71 ft3= 2508 ft3 2508 ft3/1.91 ft3/sk= 1314 sks(1320 sks) Have additional ALC on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 12.0pPg DeepCRETE CRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x (3182-2682) x 1.50 (50%excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/ 1.63 ft3/sk= 195 sks Round up to 205 sks BHST= 79°F, Estimated BHCT=77°F. (Based on 2.1°F/100 ft.from surface) PUMP SCHEDULE < Base of Permafrost at Stage Cumulative 1,530'MD(-1,505'TVD) Pump Rate Stage Time Stage Volume Time (bpm) (bbl) (min) (min) CW100 7.0 50.0 7.1 7.1 MUDPUSH II 7.0 50.0 7.1 14.2 Pause 0.0 0.0 5.0 19.2 < Top of Tail at 11 ppg DeepCRETE 7.0 446.9 63.8 83.0 2682'MD Surface Tail 7.0 56.3 8.0 91 0 DeepCRETE Slurry Pause 0.0 0.0 5.0 96.0 Fresh Water 7.0 10.0 1.4 97.4 Pause 0.0 0.0 5.0 102.4 Mud 8.0 278.3 34.8 137.2 Mud 3.0 10.0 3.3 140.5 < 10 3/4",45.5#casing MUD REMOVAL in 13.5"OH Expected Mud Properties:9.8 ppg, Py<20, Ty<20 Spacer Properties:10.5 ppg MudPUSH* II, Pv= 17-21,Ty=20-25 TD at 3182'MD (2795'TVD) Centralizers: As per CPAI program. Mark of Schlumberger ORIGINAL • 2M-36 Schlumberger CemCADE Preliminary Job Design 7 5/8" Intermediate (V2 Preliminary Job Design based on limited input data.For estimate purposes only. Rig:Doyon 141 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date:June 18,2014 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage,AK Tail Slurry Minimum thickening time: -220 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G +adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@s1b.com 0.2148 ft3/ft x (9300'-8300') x 1.4(40%excess) = 301 ft3 Shoe Volume: 0.2578 ft3/ft x 80'x 1.00 (no excess) = 21 ft3 Totals: 301 ft3+21 ft3= 322 ft3 322 ft3/1.16 ft3/sk= 278 sks(285 sks) BHST= 146 °F, Estimated BHCT= 104 °F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) db..' 10 3/4",45.5#casing CW1 00 6.0 40.0 6.7 6.7 at 3182'MD MUDPUSH II 6.0 40.0 6.7 13.4 Pause 0.0 0.0 5.0 18.4 Tail Slurry 6.0 57.2 9.5 27.9 Pause 0.0 0.0 5.0 32.9 Fresh Water 6.0 10.0 1.7 34.6 Top of Tail at Pause 0.0 0.0 5.0 39.6 end of pumping Mud 6.0 403.3 67.2 106.8 < 8300'MD Mud 3.0 10.0 3.3 110.1 MUD REMOVAL 7 5/8",29.7# Recommended Mud Properties:10.0 ppg, Pv<20, Ty<20. As thin and light as ins 7/8"hole possible to aid in mud removal during cementing. Spacer Properties:12.5 ppg MudPUSH* II, Pv=25- 30, Ty-30 -40 Centralizers: As per CPAi program TD at-9300'MD (5980'TVD) * Mark of Schlumberger ORIGINAL 2M-36Schlumberger CemCADE Preliminary Job Design 4-1/2" Bonzai Liner (V2 Preliminary Job Design based on limited input data.For estimate purposes only. Rig:Nabors 9ES Volume Calculations and Cement Systems Location: Kuparuk - Client:CPAi Revision Date:June 18,2014 Volumes are based on 40%excess. Displacement is calculated with a 4.0"-14.0#drill Prepared by:Jenna Houston pipe using mud. Location:Anchorage,AK Phone:(907)263-4207 Tail Slurry Minimum pump time: -320 min. (pump time plus 230 min +60 min batch) Mobile: (907)943-0094 15.8 ppg Class G +adds- 1.16 ft3/sk email:jhouston2@slb.com Annular Volume: 0.1381 ft3/ft x (9800'-9300') x 1.40 (40%excess) = 98 ft3 < TOC Lap Volume: 8900' MD 0.1474 ft3/ft x (9300'-9100') x 1.00 (no excess) = 30 ft3 Cap Volume: 0.1705 ft3/ft x (9100'-8900') x 1.00 (no excess) = 35 ft3 "Shoe" Volume: -- < Liner Top 0.0325 ft3/ft x 80'x 1.00 (no excess) = 3 ft3 9100' MD Totals: 98 ft3+30 ft3+35 ft3+3 ft3 = 166 ft3 166 ft3/1.16 ft3/sk= 144 sks(-150 sks) 7",29.7#casing At 9300'MD BHST= 146 °F, Estimated BHCT= 118 °F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE 4-1/2", 12.6#liner in 6-3/4" hole Volume Pump Rate Stage Stage Time Cumulative Stage Time (bpm) (min) (bbl) (min) MUDPUSH II 6.0 30.0 5.0 5.0 Tail Slurry 6.0 29.0 4.8 9.8 Fresh Water 6.0 10.0 1.7 11.5 Pause 0.0 0.0 5.0 16.5 Mud 6.0 82.2 13.7 30.2 Mud 3.0 10.0 3.3 33.5 MUD REMOVAL Recommended Mud Properties:12.5 ppg, Pv<20, Ty<20. Spacer Properties:13.5 ppg MudPUSH* II, Pv=20- 25, Ty=35-40 Centralizers: As per CPAi program ECP at 9800'MD (6071'TVD) * Mark of Schlumberger ORIGINAL 2M-36 Grass Roots Horizontal A/C Sand Producer ConocoPhillips Proposed Wellbore Schematic Adam',Clem 5/5/14 Conductor To Be Installed: 16"62.6#H-40 resh Water Spud Mud e-10 PPG 13-1/2"Surface Hole :•:WeSt•Sak•:.:•: Surface Casing:Below West Sak 10-3/4"45.5#L-80 Hydril 563 3,308'MD 2,795'TVD J 3M -10.0 PPG Tubing: ep up with 9200'3-Y2"9.3#L-80 EUE8RD ution 9-7/8"Intermediate Hole 1 Estimated top of cement @f-/-8300'MD Intermediate Casing:Toa Set Above C 7-5/8",ZXP Liner Top Packer 9,100MD Sand -- 7-5/8"x 4-x•Baker Flex Lock Liner hangerflee MB 7-5/8"29.7#L-80 with Hydril 563 Surface-9,312'MD(5,981'TVD), . . . . t e s t+f ? !<?'• astrequiredj:,' t [ [ t t �3)4.• rtiC[t)CiRKttH01� .:.:.: a•:SRPR $arcetCTC20 POy5pheEGP•. J?adkcibalo�cYp/tAsai,[L:c: ., Production Liner: 4-1/2"12.6#L-80 IBTM Perforated Pups 9800'-12,846'MD 6,044'TVD 4-1/2"12.6#TN-110 Hydril 563 9100'-9800'MD R ! GINAL cation for Permit to Drill,Well 2M-36 Revision No.0 Saved: 8-Jul-14 Permit It - West Sak Well 2M-36rot Application 6-,,Permit to Drill Documents • ' 0 a► Ma Well Moxithiz $ Volue Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (1) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information . ' a 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AA C 25.005(c)(4) 3 4. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005 (c)(5) 3 5. Casing and Cementing Program 3 Requirements of 20 AAC 25.005(c)(6) 3 6. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 7. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (Drilplex AR) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (KLA-Shield) 5 8. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 9. Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 10.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005(c)(11) 5 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 2M-36 PERMIT.doc Page 1 of 8 8Printed:8-Jul-14 Ferguson, Victoria L (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Thursday,August 14, 2014 12:36 PM To: Ferguson,Victoria L(DOA) Subject: RE: KRU 2M-36(PTD 214-102) Attachments: 2014081415132966.pdf Follow Up Flag: Follow up Flag Status: Completed Victoria, attached please find page one of the application with "West Sak" Changed to Kuparuk. Steps to minor risk the following wells: 2M-01—is currently shut in and cemented off. If we did hit this well there is no HSE risk or environmental risk as this well is currently awaiting abandonment. 2M-03 -We are going to set a deep plug in 2M-03 and bleed surface pressure off prior to spudding 2M-36. This will isolate the reservoir and prevent any HSE or environmental risk if we did hit the 2M-03 well. 2M-28—We are going to set a deep plug in 2M-28 and bleed surface pressure off prior to spudding 2M-36. This will isolate the reservoir and prevent any HSE or environmental risk if we did hit the 2M-28 well. Please let me know if you need any other information. Thanks David From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Thursday, August 14, 2014 11:33 AM To: Lee, David L Subject: [EXTERNAL]KRU 2M-36(PTD 214-102) David, What steps will you take to minor risk the following major risk failures:2M-01, 2M-03,2M-28 Resend page 1 of your application;current page has"West Sak Well" in the title Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 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: 2m--3( PTD: oC)"] —/0 Z ' Development _Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: g, ► POOL: f� ►V J4 &vJ( . 1'1/4/4.4-- Check 1\✓4 rCheck Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo gB g in also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 ❑CI Ts N a 0 0 N N O Q N O N a a cc m E CO _C Q U 0- .-E- (...) rU E N C 0) 3, a) N -O' I rn 0 v N O co j d > L 0 a N, c4 w a a o o o a ao N 3a .a O N aiS.U °, 3 of C O (a y p ' •c v co O a) O Y 3 N O, N O 0m a a U in 2. .. .3C CO O N CO co , W. a cb 0 Cr) O 7 UO OQ C - NN 0 .. N a L ' CO ., CO 0 O U VM oNM ME Ef,. N a J O N03 O.. O: O -0, _, d I- p p 4 1- fn co N E, iO F w. C • N' o) as cc 2 �� � - �� y� aa)ct c w `n C 7uoi' a o` �' 3 a m _. D - aCD - r rao oi n CO' a a) .a rn co a a) CO - a, 0, = ai 3 a m a Y c m °° o 3Ti co c. o m a 2 4 ci. co C O o C 0. >. O co Q N Y ; cTs � E O. 0) a N. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk Rig: Doyon 25 Date: January 6, 2015 Surface Data Logging End of Well Report 2M-36 2M-36 PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Show Reports 6. Mud Record 7. Bit Record 8. Morning Reports 9. 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 25 Well: 2M-36 & 2M-36 PB1 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20691-00-00 (2M-36) 50-103-20691-70-00 (2M-36 PB1) Sperry Job Number: AK-AM-0901812451 Job Start Date: 07 November 2014 Spud Date: 10 November 2014 Total Depth: 13014’ MD, 6025’ TVD (2M-36) 8018’ MD, 5316’ TVD (2M-36 PB1) North Reference: True Declination: 18.973° Dip Angle: 80.844° Total Field Strength: 57563.726 nT Date Of Magnetic Data: 07 November 2014 Wellhead Coordinates N: North 70° 16’ 17.47229” Wellhead Coordinates W: West 150° 6’ 5.92104“ Drill Floor Elevation 140.790’ Ground Elevation: 101.3’ Permanent Datum: Mean Sea Level SDL Engineers: Danielle Dawson, Todd Wilson, Alexander Paul Kalenuik, Michael LaDouceur, Pascal Poupart SDL Sample Catchers: Autumn Gould, Chris Ward Company Geologist: Jeff McBeth, Matt Smith Company Representatives: Lee Martin, Granville Rizek, Paul Smith, John Haynes, Rob Reinhardt SSDS Unit Number: 125 DAILY SUMMARY 11/17/2014 Test blow out preventer and rig down the blow out preventer testing equipment. Line up choke manifold. Pull test plug, drain stack & set wear bushing. Kelly up and tag cancellation plug at 902' MD. Drill plug with 405 gallons per minute and 545 pounds per square inch. Work through without pump or rotary. No indication of plug present. Run in hole to a depth of 2993’ MD. Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in last 24 hours. 11/18/2014 Run in hole and tag cement stringer at 2902' MD. Drill out cement stinger and continue to run in hole to 3106' MD. Perform casing test. Run in hole to tag cement at 3233’ MD. Drill out cement plus 20 feet of rat hole. Perform FIT test at 3362’ MD and displace wellbore to water based mud. Drill to 3675’ MD. Max Gas: The max gas was 116 units with an average of 47 units. Fluids: There were 0 barrels lost down hole in last 24 hours. 11/19/2014 Drill well from 3675’ MD to 5186’ MD. Pull out of hole to casing shoe due to extreme weather condition. Max Gas: The max gas was 97 units with an average of 58 units. Fluids: There were 0 barrels lost down hole in last 24 hours. 11/20/2014 Remain at casing shoe due to extreme weather condition. Max Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in last 24 hours. 11/21/2014 Remain at casing shoe due to extreme weather condition. Max Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in last 24 hours. 11/22/2014 Tripped back into the hole from the casing shoe at 3346' MD to 5186' MD and drilled from 5186' MD to 6137' MD. Max Gas: The max gas was 289 units with an average of 47 units. Fluids: There were 0 barrels lost down hole in last 24 hours. 11/23/2014 Drilled from 6137' MD to 8018' MD and took a 14 barrel kick at 8018' MD. Max Gas: The max gas was 1215 units with an average of 141 units. Fluids: There were 14 barrels gained in the last 24 hours. 11/24/2014 Circulated water based mud and raised the mud weight to 10.3 pounds per gallon. Experienced second kick while circulating mud, generating a 3 barrel gain. Max Gas: The max gas was 7884 units with an average of 641 units. Fluids: There were 3 barrels gained in the last 24 hours. 11/25/2014 Circulated water based mud at a pump rate of 20 strokes per minute at 7963’ MD while steadily incurring losses. Max Gas: The Max gas was 7884 units with an average of 1389 units. Fluids: There were 934 barrels were lost down hole in the last 24 hours. 11/26/2014 Circulated water based mud at a pump rate of 20 strokes per minute at 7963’ MD while steadily incurring losses. Max Gas: The max gas was 1141 units with an average of 64 units. Fluids: There were 367 barrels were lost down hole in the last 24 hours. 11/27/2014 Circulated water based mud at a pump rate of 20 strokes per minute at 7963’ MD while steadily incurring losses. Pull pipe up to 6500’ MD. Pumped lost circulation material pill. Monitored for returns Max Gas: The max gas was 1038 units with an average of 33 units. Fluids: There were 755 barrels were lost down hole in the last 24 hours. 11/28/2014 Tripped in the hole to a depth of 8014’ MD and circulated water based mud at a pump rate of 20 strokes per minute. Began weighting up water based mud to 10.8 pounds per gallon kill weight. Max Gas: The max gas was 2557 units with an average of 78 units. Fluids: There were 873 barrels lost down hole in the last 24 hours. 11/29/2014 Pull out of hole and attach Retrievamatic test packer above the heavy weight drill pipe. Water based mud loss of 652 barrels while pulling out of hole. Max Gas: The max gas was 173 units with an average of 7 units. Fluids: There were 936 barrels lost down hole in the last 24 hours. 11/30/2014 Tested casing above and below stage collar. Laid down the bottom hole assembly. Test the annular preventer. Trip into hole to place cement plugs. Max Gas: The max gas was 401 units with an average of 7 units. Fluids: There were 72 barrels lost down hole in the last 24 hours. 12/01/2014 Complete trip into the hole to a depth of 8018’ MD. Conditioned mud for cement plugs. Placed first cement plug. Circulate after setting plug. Max Gas: The max gas was 401 units with an average of 7 units. Fluids: There were 793 barrels lost down hole in the last 24 hours. 12/02/2014 Pull out of the hole to set storm packer and test Blowout preventer. Max Gas: The max gas was 249 units with an average of 5 units. Fluids: There were 65 barrels lost down hole in the last 24 hours. 12/03/2014 Trip into the hole and tag top of cement plug #1. Condition mud for cement plug #2. Place cement plug #2. Max Gas: The max gas was 263 units with an average of 14 units. Fluids: There were 513 barrels lost down hole in the last 24 hours. 12/04/2014 Place cement plug #3. Circulate and pull out of hole to 4500' MD and wait for cement to cure. Max Gas: No significant gas was detected. Fluids: There were 517 barrels lost down hole in the last 24 hours. 12/05/2014 Place cement plug #4. Circulate and pull out of hole to 3500’ MD and wait for cement to cure. Max Gas: No significant gas was detected. Fluids: There were 45 barrels lost down hole in the last 24 hours. 12/06/2014 Wait for cement to cure and circulate to decrease mud weight from 10.8 pounds per gallon to 9.8 pounds per gallon. Max Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/07/2014 Pump Cement plug # 5. Wait for cement to cure. Max Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/08/2014 Confirm top of cement at 2910’ MD. Pull out of hole and lay down cement bottom hole assembly. Pick up dumb iron and begin drilling cement out of casing. Max Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/09/2014 Drill Cement to 3292' MD. Pull out of the hole. Test blow out prevention equipment. Pick up drilling bottom hole assembly with measurement while drilling tools. Begin tripping into the hole. Max Gas: No significant gas was detected. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/10/2014 Test Casing to 3000 pounds per square inch. Drill through cement to kick off point at 3410' MD. Perform Formation Integrity Test to 12.5 pounds per gallon. Drill from 3410' MD to 3818' MD. Max gas was connection gas at 272 units. Max Gas: The max gas was 272 units with an average of 81 units Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: A soft, light gray, amorphous claystone with arenaceous inclusions. 12/11/2014 Continued drilling formation form 3818’ MD to 5632’ MD. Max Gas: The max gas was 173 units with an average of 62 units Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: A clear, milky white to gray, very fine to fine grained, sub spherical, sub rounded to sub angular, well sorted, weakly consolidated to unconsolidated, quartz sandstone with poor siliceous cement containing trace amounts of glauconite, platy, sub angular black lithic fragments, and rare pyrite inclusions. 12/12/2014 Continued drilling formation form 5632’ MD to 7100’ MD. Max Gas: The max gas was 655 units with an average of 152 units Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: A milky white, light gray to gray, clear, very fine to fine grain, sub-spherical, sub- rounded to sub-angular, well sorted, poorly consolidated to unconsolidated, poorly to slightly cemented, quartz sandstone that is very silty. 12/13/2014 Continued drilling formation form 7100’ MD to 8927’ MD. Max Gas: The max gas was 916 units with an average of 223 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: Silt is a light gray to gray, moderately firm, sub-angular, moderately to slightly cemented with rare arenaceous inclusions. Shale is gray to dark gray, soft, blocky, flaky, earthy, dull and fissile. 12/14/2014 Drill from a depth of 8927’ MD to intermediate section completion at a depth of 9543’ MD. Perform hole cleaning cycle. Shut down and monitor well. Attempted to work pipe, pipe would not move. Pipe eventually became free, and circulation was established. Washed down and pumped sweep while working the pipe. Staged pumps up and attempted to rotate, but was unsuccessful with rotary. Shut down the rotary and increased the pump rate; observed pack off. Pumps were killed and pressure bled off. Max Gas: The max gas was 3196 units while circulating with an average of 409 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: Shale is gray to dark gray, soft, blocky, flaky, earthy, dull and fissile. 12/15/2014 After working the pipe free and circulating multiple bottoms up and a sweep, Began pulling out of the hole. Laid down the bottom hole assembly and Blow out preventer testing. Max Gas: The max gas was 937 units with an average of 240 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/16/2014 Complete testing of the blow out preventer. Rigged up and started tripping in with 7 ⅝” 29 pound and 39 pound casing. Max Gas: The max gas was 226 units with an average of 26 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/17/2014 Continue tripping into the hole with casing until 7195’ MD, when tight spot was encountered. Broke circulation and worked the pipe through. Max Gas: The max gas was 226 units with an average of 26 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/19/2014 Continue tripping in casing by washing down to a landing depth of 9532' MD. After landing, circulated water based mud at 63 gallons per minute. Rig up cement hose and circulate staging pumps at 1 barrel per minute. Pump cement and receive minimal returns. Perform rig service. Max Gas: The max gas was 1656 units with an average of 283 units. Fluids: There were 137 barrels lost down hole in the last 24 hours. 12/20/2014 Lay down 5" test joint, install packoff. Test packoff. Lay down 5 inch heavy weight drill pipe and 5 inch drill pipe. Pick up 4” drill pipe. Max Gas: The max gas was 0 units with an average of 0 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/21/2014 Make up 4 inch drill pipe into 3 joint stands. Test blow out preventer. Assemble the clean out bottom hole assembly. Pick up 4 inch drill pipe and trip into the hole, filling pipe every 20 stands. Cut and slip drill line. W ash down at 211 gallons per minute. Tag top of cement at 9412’ MD. Max Gas: The max gas was 206 units with an average of 24 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/22/2014 Drill out plug, float collar, and cement from 9428' MD to 9493' MD. Trip out of hole and make up bond log tools. Pull out of the hole while logging from 9490' MD to 8775' MD. Top of cement declared at 9275' MD. Pull out of the hole and lay down logging tools. Pick up and make up the drilling Bottom Hole Assembly and lay down the pressure tool. Begin to trip into the hole with assembly to a depth of to 871' MD. Max Gas: The max gas was 86 units with an average of 6 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/23/2014 Continued running in the hole to 9411' MD. Washed down from 9411' MD to 9496' MD and displace wellbore to Klashield water based mud with 28 barrel spacer. Observe fluctuations of the mud system. Flushed and cleaned out concerned line and equipment. Drill cement from 9496' MD to 9516" MD. Max Gas: The max gas was 484 units with an average of 17 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/24/2014 Perform Formation Integrity Test to 14.1 pound per gallon equivalent mud weight. Drill from 9564' MD to 9655' MD. Encounter a Measurement While Drilling tool failure. Circulate bottoms up. Trip out of the hole to a depth of 8266' MD and pump mud slug. Trip out of hole to surface and lay down bottom hole assembly. Pick up replacement tool. Trip in to 9410' MD. Max Gas: The max gas was 232 units with an average of 17 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: Shale: medium to dark gray, firm with occasional brittle fracture. Platy, noncalcareous, laminations. 12/25/2014 Drill from 9655' MD to 10736' MD at 273 gallons per minute. Max Gas: The max gas was 2794 units with an average of 1091 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: Sandstone: clear to opaque to amber to brown to gray, fine to very fine grained, sub rounded to rounded, well sorted with non-calcareous cement. 12/26/2014 Continue to drill production section from 10736' MD to 11986’ MD. Max Gas: The max gas was 2513 units with an average of 1233 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: Sandstone: clear to opaque to amber to brown to gray to green, medium to very fine grained, rounded to sub angular, poorly sorted with non-calcareous cement and common glauconite. 12/27/2014 Continue to drill production section from 11986' MD to completion of production section at 13014' MD. Max Gas: The max gas was 1360 units with an average of 581 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. Geology: Sandstone: clear to amber to brown to gray, coarse to fine grained, rounded to sub angular, poorly sorted with non-calcareous cement and common glauconite. 12/28/2014 Circulate bottoms up while reciprocating drill string from 13013' MD to 12731' MD. Pull out of the hole while pumping and working drill string in tight spots to 9552’ MD. Max Gas: The max gas was 759 units with an average of 120 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/29/2014 Install equipment for Blowout Preventer test. Perform Blowout Preventer test per ConocoPhillips directive. Circulated at bit depth 9215' MD to condition mud. Perform slip and cut of drill line. Perform rig service. Ream the hole from 9318'MD to 10165' MD. Pulled out of the hole from 10165' MD to 9887' MD and encountered tight spot. Worked drill string through the tight spot. Max Gas: The max gas was 403 units with an average of 51 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/30/2014 Continue to pull out of the hole from 9887' MD to 9500' MD. Encounter resistance at 9555' MD. Circulate bottoms up while reciprocating drill string from 9500' MD to 9404' MD. Activate Well Commander and utilized it for 3 bottoms up. Deactivated Well Commander pumped and pulled out of the hole from 9400' MD to surface. Lay down the bottom hole assembly. Max Gas: The max gas was 117 units with an average of 25 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 12/31/2014 Rig up to perform installation of the 4 ½ inch production liner. Rig is placed on weather hold. Max Gas: The max gas was 0 units with an average of 0 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 01/01/2015 Begin Trip into the hole with the production liner and place liner at 13014’ MD. Set packer. Max Gas: The max gas was 22 units with an average of 12 units. Fluids: There were 0 barrels lost down hole in the last 24 hours. 01/02/2015 Displace well with a 12.3 pound per gallon completion brine. Pull out of the hole. Max Gas: The max gas was 255 units with an average of 10 units. Fluids: There were 29 barrels lost down hole in the last 24 hours. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 5 10 15 20 25 30 35 40 45 50 55 60 65 Me a s u r e d D e p t h Rig Days WELL NAME: 2M-36 & 2M-36 PB1 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-0901812451 07 Nov 2014 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 10-Nov-2014 TD: 27-Dec-2014 Commenced 13.5" Surface Hole Section On Bot: 04:55 10 Nov 2014 TD Surface Hole Section 3352' MD, 2841' TVD Off Bot: 21:50 14 Nov 2014 Commenced 9.875" Intermediate Hole Section On Bot: 07:40 18 Nov 2014 Shut Down Rig Due to Weather 20 Nov 2014 TD PB1 Hole Section 8018' MD, 5316' TVD Off Bot: 22:37 23 Nov 2014 Drill 9.875" Hole to 8018' MD C/O Kick 23 Nov 2014 Commenced 9.875" Intermediate Hole Section On Bot: 11:24 10 Dec 2014 TD Intermediate Hole Section 9543' MD, 5982' TVD Off Bot: 09:04 14 Dec 2014 Landed 7.625" Casing 9544' MD, 5985' TVD 19 Dec 2014 Shut Down Rig Due to Weather 31 Dec 2014 TD Production Hole Section 13014' MD, 6025' TVD Off Bot: 23:30 27 Dec 2014 Days vs. Depth Commenced 6.5" Production Hole Section On Bot: 22:00 23 Dec 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Rig up went well. Rig crew has adapted well to calling out transfers and information concerning the pit volumes. 2M-36 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0901812451 Alaska Doyon 25 Intermediate PB1 Michael LaDouceur 10-Dec-2014 What went as, or better than, planned: Difficulties experienced: H2 generator would not hold pressure. Was replaced with back-up H2 generator. Lost connections to Rigsense (rig wide) which caused loss of data. Communication with the customer was lacking on what was expected and required from SDL personel.This caused confusion and the inability to provide the customer with the services that they desired. Recommendations: Make sure that in the future, the SDL job expectations are clearly defined prior to the drilling process so that we can satisfy the customer's needs. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: CVE pump has been locking up on us every so often due to insuffcient oil within in the pump. The H2 generator began to fail and a trainee had to pressure it up until a backup could be installed. Recommendations: Keep a spare H2 generator in the unit if the gear is available. Squirt oil down CVE line to oil motor to prevent seizing. Ensure oiler drip rate is set it 1 drop/min. Innovations and/or cost savings: Keeping a unit diary helps mudloggers stay focused and on task every hour, and also helps the opposite shift keep up with previous rig activities. Doyon 25 Intermediate Danielle Dawson 18-Dec-2014 What went as, or better than, planned: Sample catchers stayed on task and didn't miss any samples during this section. Communication between mudloggers and rig personnel went very well and no miscommunications occurred. 2M-36 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0901812451 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: There was an issue with either the H2 generator or the 8900 chromo being used. H2 pressure would not hold for the chromatograph, but it would hold for the THA. Replacing the chromo and the H2 generator eventually solved this issue. Recommendations: Having back up gas gear is imperitive. Back up CVE gaskets and O rings are important as well. Emphasize the importance of sieve maintainence to the sample catchers to prevent warped or ripped sieves. Innovations and/or cost savings: Saving samples in the compartment trays really helped us out time-wise while drilling. The geos kept asking us to look back at samples drilled thousands of feet earlier for comparison. Leaving the samples in the trays saved us from pouring samples in and out of the sample envelopes and potentially losing volume. Doyon 25 Production Danielle Dawson 29-Dec-2014 What went as, or better than, planned: The onsite and in town geologists were really happy with our ability to take and send high resolution sample photos. Apparently, the previous mudlogging contractor was unable to perform this service. This really helped communication between town, the onsite geos and the mudloggers. 2M-36 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0901812451 Alaska Surface Data Logging After Action Review Surface Data Logging Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Show Report Report # 1 2M-36 9780 9880 Kuparuk River Unit 6025 6040 ConocoPhillips Alaska, Inc. Danielle Dawson, David Durst Kuparuk C4 Kristen Hannon, Matt Smith 12/30/2014 Interpretation: This interval displays gaseous hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, medium to very fine grain, subrounded to subangular, poorly sorted sand, with traces of pyrite and glauconite. There is no free oil in the sample, even dull yellow sample flourescence, a dull bluewhite streaming flourescence cut, clear cut, a light amount of clear residual ring, and dull bluewhite residual fluorescence ring. Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount None Type Streaming Amount None Amount Trace Distribution Intensity Dull Color Color Brown Intensity Color Straw Residual Flourescence Cut Color Intensity Dull Color Clear Color Blue-White Oil Show Rating Free Oil in Mud 1 Hydrocarbon Ratios 9784 Gas Units 100 Mud Chlorides (mg/L) =144000 8567 2341 6226 11 772 190 582 28 300 77 223 74 119 35 84 259 2 24 0 24 144000 79628 6807 72821 10 8523 1224 7299 26 9821 3539 715 2824 79 Gas Units 1035 Mud Chlorides (mg/L) = 1327 405 922 258 441 159 282 Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios 9847 Gas Units 1119 Mud Chlorides (mg/L) =144000 87757 6807 80950 10 4 9880 Gas Units 1263 Mud Chlorides (mg/L) = 9322 1224 8098 27 3703 715 2988 87 1331 405 926 180 144000 96435 6807 89628 10 450 0 450 9807 1224 8583 27 585 159 426 4070 715 3355 64 1810 405 1405 210 NPH Oil Gas NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1543 1067 476 6705 3412 3293 43 3787 2422 1365 124 107576 48442 59134 9 13035 6276 6759 18 10069 Gas Units 1775 Mud Chlorides (mg/L) =140000 2 17914 6276 11638 14 9302 3412 5890 23 5874 2422 3452 92 1942 1067 875 1 Hydrocarbon Ratios 9975 Gas Units 2429 Mud Chlorides (mg/L) =140000 128872 48442 80430 7 Yellow Intensity Faint Color Clear Yellow Oil Show Rating Free Oil in Mud Color Cut Color Color Light Brown Intensity Dull to Bright Color Yellow Amount 10 Distribution Even Intensity Dull Color Stain Residual Flourescence NoneAmount30-90%Type Streaming Amount Cuttings Analysis: Odor None Fluorescence Cut Fluorescence Residual Cut Kristen Hannon, Matt Smith 1/30/2015 Interpretation: This interval displays gaseous hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to rounded, well sorted sand, with traces of pyrite and rare siderite. There is no free oil in the sample, even brightl yellow sample flourescence, a dull bluewhite streaming flourescence cut, clear cut, a light amount of straw residual ring, and dull bluewhite residual fluorescence ring. Show Report Report # 2 2M-36 9900 10100 Kuparuk River Unit 6043 6066 ConocoPhillips Alaska, Inc. David Durst, Danielle Dawson Kuparuk A3 Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Show Report Report # 3 2M-36 10800 10900 Kuparuk River Unit 6071 6071 ConocoPhillips Alaska, Inc. Danielle Dawson, David Durst Kuparuk A3 Kristen Hannon, Matt Smith 12/30/2013 Interpretation: This interval displays gaseous hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, fine to very fine grain, subrounded to rounded, well sorted sand. There is no free oil in the sample, even dull yellow sample flourescence, a dull bluewhite streaming flourescence cut, clear cut, a light amount of straw residual ring, and bright bluewhite residual fluorescence ring. Cuttings Analysis: Odor Moderate Fluorescence Cut Fluorescence Residual Cut Amount 30-40%Distribution Even Intensity Dull Color Stain Residual Flourescence LightAmount80%Type Streaming Amount Straw Free Oil in Mud Color Cut Color Color Dark Brown Intensity Dull Color Blue-White 109486 30645 78841 8 Yellow Intensity Bright Color Clear Blue-White Oil Show Rating 1 Hydrocarbon Ratios 10800 Gas Units 1845 Mud Chlorides (mg/L) =152000 2 13714 3883 9831 16 6772 1859 4913 38 2999 909 2090 103 1253 490 763 Gas Units 1872 Mud Chlorides (mg/L) =152000 114352 30645 83707 9 13057 3883 9174 19 10834 1160 490 670 6229 1859 4370 45 2753 909 1844 125 Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis X Gas Oil Water Non-Producible Hydrocarbons Hydrocarbon Ratios 152000 75201 30645 44556 9 4293 1859 2434 42 10867 Gas Units 1218 Mud Chlorides (mg/L) = 3 8788 3883 4905 18 1978 909 1069 50 887 0 887 4 152000 104289 30645 73644 7 13736 3883 9853 15 10891 Gas Units 1825 Mud Chlorides (mg/L) = 34 3070 909 2161 89 1317 490 827 6883 1859 5024 NPH Oil Gas NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Stain Amount Danielle Dawson, David Durst Kuparuk C4 Show Report Report # 4 2M-36 11400 11500 Kuparuk River Unit 6060 6058 ConocoPhillips Alaska, Inc. Kristen Hannon, Matt Smith 12/30/2014 Interpretation: This interval displays gaseous hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, medium to very fine grain, subrounded to subangular, poorly sorted sand, with abundant glauconite. There is no free oil in the sample, even dull yellow sample flourescence, a dull bluewhite streaming flourescence cut, clear cut, a light amount of clear residual ring, and dull bluewhite residual fluorescence ring. Odor Moderate Fluorescence Cut Fluorescence Residual Cut 50-70%Type Streaming Amount Cuttings Analysis: Light Pale Straw Color Dark Brown Intensity Dull Color Blue-White Residual Flourescence Cut Color Yellow Intensity Bright Amount 30%Distribution Even Intensity Dull Color Color Clear Color Blue-White Oil Show Rating Free Oil in Mud 1 Hydrocarbon Ratios 11424 Gas Units 1825 Mud Chlorides (mg/L) =143000 94328 4745 89583 9 11318 1091 10227 18 6279 1402 4877 42 3558 1432 2126 86 2 1998 962 1036 143000 100191 4745 95446 9 12102 1091 11011 18 11443 6718 1402 5316 40 Gas Units 1956 Mud Chlorides (mg/L) = 3802 1432 2370 82 2122 962 1160 Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 Hydrocarbon Ratios 11455 Gas Units 1883 Mud Chlorides (mg/L) =143000 95403 4745 90658 9 4 11480 Gas Units 1946 Mud Chlorides (mg/L) = 11326 1091 10235 18 6322 1402 4920 42 3616 1432 2184 48 143000 81669 4745 76924 9 1877 0 1877 9933 1091 8842 18 1766 962 804 5708 1402 4306 37 3507 1432 2075 96 NPH Oil Gas NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 2061 91 1970 93 1067 69 998 9574 140 9434 21 11849 4417 79 4338 47 Gas Units 1571 Mud Chlorides (mg/L) =143000 93909 1164 92745 10 2 1051 69 982 4403 79 4324 49 2037 91 1946 98 97169 1164 96005 10 9644 140 9504 22 1 Hydrocarbon Ratios 11832 Gas Units 1522 Mud Chlorides (mg/L) =143000 Color Clear Color Blue-White Oil Show Rating Free Oil in Mud Cut Color Yellow Intensity Bright Amount Trace Distribution Even Intensity Dull Color Color Brown Intensity Dull Color Blue-White Residual Flourescence Cuttings Analysis: Odor Moderate Fluorescence Cut Fluorescence Residual Cut Stain Amount 80 Type Streaming Amount None Kristen Hannon, Matt Smith 12/30/2014 Interpretation: This interval displays gaseous hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, medium to very fine grain, subrounded to subangular, poorly sorted sand, with abundant glauconite. There is no free oil in the sample, even dull yellow sample flourescence, a dull bluewhite streaming flourescence cut, clear cut, a light amount of clear residual ring, and bright bluewhite residual fluorescence ring. Show Report Report # 5 2M-36 11800 11900 Kuparuk River Unit 6064 6067 ConocoPhillips Alaska, Inc. Danielle Dawson, David Durst Kuparuk C4 Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1130 69 1061 4206 79 4127 36 2129 91 2038 70 143000 75161 1164 73997 9 1082 0 1082 8250 140 8110 18 4 11894 Gas Units 1308 Mud Chlorides (mg/L) = 9427 140 9287 21 4422 79 4343 45 2099 91 2008 83 Hydrocarbon Ratios 11865 Gas Units 1543 Mud Chlorides (mg/L) =143000 91089 1164 89925 10 3 NPH Oil Gas NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons 1757 206 1551 123 780 173 607 8706 446 8260 19 12965 4084 256 3828 48 Gas Units 1300 Mud Chlorides (mg/L) =141700 79068 4560 74508 9 2 419 173 246 1901 256 1645 75 839 206 633 192 51848 4560 47288 12 4489 446 4043 29 1 Hydrocarbon Ratios 12951 Gas Units 796 Mud Chlorides (mg/L) =141700 Color Clear Color Blue-White Oil Show Rating Free Oil in Mud Cut Color Yellow Intensity Bright Amount 30%Distribution Even Intensity Dull Color Straw Color Brown Intensity Dull Color Blue-White Residual Flourescence Cuttings Analysis: Odor Light - Strong Fluorescence Cut Fluorescence Residual Cut Stain Amount 40-80%Type Slow Blooming Amount Faint Kristen Hannon, Matt Smith 12/30/2014 Interpretation: This interval displays gaseous hydrocarbons based upon the gas and chromatograph data collected. It is dominated by unconsolidated, medium to very fine grain, subrounded to subangular, moderately to poorly sorted sand, with traces of pyrite and rare glauconite. There is no free oil in the sample, even dull yellow sample flourescence, a dull bluewhite streaming flourescence cut, clear cut, a light amount of clear residual ring, and bright bluewhite residual fluorescence ring. Show Report Report # 6 2M-36 12950 13000 Kuparuk River Unit 6032 6027 ConocoPhillips Alaska, Inc. Danielle Dawson, David Durst Kuparuk C4 Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Depth ft C1 C1 C1 C1 .C2 C3 C4 C5 Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis x Gas Oil Water Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons 0 0 0 0 0 0 #DIV/0! 0 0 0 #DIV/0! 141700 0 0 0 #DIV/0! 340 0 340 0 0 0 #DIV/0! 4 0 Gas Units 0 Mud Chlorides (mg/L) = 3800 446 3354 39 1466 256 1210 109 642 206 436 140 Hydrocarbon Ratios 12979 Gas Units 759 Mud Chlorides (mg/L) =141700 52178 4560 47618 14 3 NPH Oil Gas NPH 1 10 100 1000 NPH Oil Gas NPH 2M-36 & 2M-36 PB1 ConocoPhillips Alaska, Inc. MI Swaco Doyon 25 AK-XX-0901812451 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++ 10-Nov 350 9.30 88 10 88 72/72/73 10.0 108/98/91/84/72/71 5/-7.0 1/93 0.25 2.80 10.7 11.25 2.32/4.78 140 68 Drilling ahead in surface section 11-Nov 1454 9.10 113 5 113 74/75/79 10.0 123/118/102/95/76/75 4/-10.0 2/88 0.50 2.42 10.8 13.00 2.12/4.58 900 48 Drilling ahead in surface section 12-Nov 2310 9.10 113 5 113 72/68/64 10.0 123/118/102/94/72/67 4/-9.0 1/90 tr 2.70 10.9 10.00 2.48/5.00 900 40 Drilling ahead in surface section 13-Nov 3198 9.20 87 18 87 71/68/66 11.0 123/105/99/94/74/72 2/-11.0 2/87 tr 2.42 10.7 11.25 2.23/4.81 900 40 Drilling ahead in surface section 14-Nov 3352 9.00 101 10 101 67/64/60 10.0 121/111/108/97/69/68 4/-10.0 2/88 0.25 2.60 10.9 11.25 2.49/5.00 900 40 TD surface section, R/U casing 15-Nov 3352 9.00 300 10 101 67/64/61 10.0 121/111/108/97/69/69 4/-10.0 2/89 0.25 2.60 10.9 11.25 2.49/5.01 900 40 RIH with casing, cementing 16-Nov 3352 9.00 101 10 101 67/64/60 10.0 121/111/108/97/69/68 4/-10.0 2/88 tr 2.40 10.4 10.00 2.20/4.60 900 40 Cementing 17-Nov 3352 9.00 101 10 101 67/64/60 10.0 121/111/108/97/69/68 4/-10.0 2/88 tr 2.40 10.4 10.00 2.20/4.60 900 40 BOP testing/RIH 18-Nov 3667 9.60 26 14 26 8/10/12 6.8 54/40/35/27/10/9 1/1 6.0 1/93 -0.45 9.9 3.75 0.41/1.38 600 50 Drilling ahead in intermediate section 19-Nov 5186 9.70 52 15 30 9/17/19 5.4 60/45/38/30/14/12 1/-9.0 3/88 0.25 0.50 10.0 12.50 0.34/1.4 400 40 POOH (weather) 20-Nov 5186 9.70 52 15 30 9/17/19 5.4 60/45/38/30/14/12 1/-9.0 3/88 0.25 0.50 10.0 12.50 0.34/1.4 400 40 Weather hold 21-Nov 5186 9.70 52 15 30 9/17/19 5.4 60/45/38/30/14/12 1/-9.0 3/88 0.25 0.50 10.0 12.50 0.34/1.4 400 40 Weather hold 22-Nov 6135 9.70 53 13 25 8/12/15 4.8 51/38/33/26/11/9 1/-10.0 2/88 0.25 0.40 9.7 22.50 0.30/1 400 40 Drilling ahead in intermediate section 23-Nov 8018 9.90 52 15 25 11/22/35 4.4 55/40/33/26/11/9 1/-10.0 2/88 0.25 0.20 9.6 17.50 0.22/1 400 40 Drilling ahead in intermediate section 24-Nov 8018 10.30 45 15 22 8/15/22 3.7 52/37/30/24/9/8 1/-11.0 2/87 0.25 0.30 9.5 20.00 0.22/.80 400 40 Circulating Kick 25-Nov 8018 10.50 50 17 20 8/14/24 3.8 54/37/28/22/8/7 1/-13.0 1/86 0.25 0.19 9.3 20.00 0.2/.8 400 40 Circulating 26-Nov 8018 10.50 60 24 22 12/18/22 3.6 70/46/36/28/12/10 1/-11.0 1/88 0.25 0.20 9.4 12.50 0.2/1 400 40 Circulating 27-Nov 8018 10.50 57 15 26 10/14/17 5.0 56/41/36/28/11/9 2/-9.5 1/90 0.25 0.20 9.3 10.00 0.15/1.3 650 120 Circulating 28-Nov 8018 10.80 57 15 26 9/13/17 5.0 56/41/36/28/12/10 2/-12.0 1/87 0.25 0.20 9.3 12.00 0.18/1.1 600 100 Circulating 29-Nov 8018 10.80 55 14 24 8/13/16 5.4 52/38/30/23/10/9 2/-11.5 1/88 0.25 0.23 9.4 11.25 0.2/1 550 80 POOH 30-Nov 8018 10.80 53 12 22 8/15/17 5.4 46/34/27/21/10/9 2/-11.5 1/88 0.25 0.22 9.3 10.00 0.18/1 550 80 TIH 1-Dec 8018 10.70 52 11 22 9/12/15 5.6 44/33/25/21/10/9 2/-11.0 1/89 0.25 0.22 9.4 10.00 0.18/1 550 80 TIH set cement plug #1 2-Dec 8018 10.70 55 14 23 10/16/21 5.6 51/37/28/22/11/10 2/-11.0 1/89 0.25 1.00 10.0 0.25 1/1.9 1100 200 Test BOPE 3-Dec 8018 10.70 52 15 17 8/12/14 8.8 47/32/25/20/9/2/-11.0 1/89 trc 1.50 11.0 10.00 1.2/2.3 1100 200 Set cement Plugs 2 & 3 4-Dec 8018 10.80 49 11 18 5/8/12 8.4 40/29/21/18/7/6 2/-11.0 -/89 trc 2.00 10.8 10.00 1.8/2 600 80 Circulate 5-Dec 8018 10.80 50 11 20 8/12/15 8.2 42/31/22/18/8/7 2/-11.5 trc/89 trc 1.40 10.5 7.50 0.8/1.2 600 80 Place Cement Plug #4 6-Dec 8018 9.80 45 10 13 5/8/11 8.8 33/23/15/12/6/5 2/-7.5 -/93 -0.18 9.5 7.50 0.15/50 360 80 Circulate 7-Dec 8018 9.80 44 13 13 7/12/11 10.0 39/26/22/17/8/7 2/-5.0 1/92 -0.50 10.5 5.00 0.4/3.0 400 108 Place cement Plug #5 8-Dec 8018 9.80 41 6 17 7/8/10 10.0 29/23/19/15/7/6 2/-7.0 1/92 -1.20 10.8 5.00 0.8/1.5 400 100 Test BOPE 9-Dec 8018 9.70 44 8 15 7/8/11 7.0 31/23/19/15/8/8 2/-8.0 1/93 -1.10 10.2 5.00 0.7/1.7 460 80 Drill cement 10-Dec 3818 9.70 49 13 19 7/8/11 5.2 45/32/27/20/8/7 2/-7.0 1/92 trc 1.30 10.0 7.50 0.75/1.9 400 80 Drill Ahead 11-Dec 5400 9.70 44 15 20 8/14/22 5.2 50/35/29/22/9/8 1/-9.0 1-91 0.25 1.00 10.4 15.00 0.4/1.5 340 100 Drill Ahead 12-Dec 7004 10.30 51 20 26 11/19/34 4.3 66/46/35/28/8/6 2/-11.0 1/88 0.25 0.90 10.0 20.00 0.30/1.2 400 80 Drill Ahead 13-Dec 8439 10.50 42 17 22 8/18/33 4.2 56/39/33/25/10/8 1/-14.0 2/84 0.25 0.45 9.9 25.00 0.30/1.30 700 60 Drill Ahead 14-Dec 9400 10.50 39 13 25 9/15/24 3.6 51/38/32/25/10/9 2/-14.0 2/84 0.25 0.25 9.4 25.00 0.20/1.75 800 60 Circulate / Trip to Surface 15-Dec 9544 10.50 52 15 26 10/14/18 3.5 56/41/35/28/12/10 2/-13.0 3/84 0.25 0.30 9.5 22.50 0.25/1.50 700 80 Trip to Surface / BOP Test 16-Dec 9544 10.50 46 12 21 8/10/14 3.3 45/33/29/22/9/8 2/-12.0 3/85 0.25 0.15 9.4 22.50 0.13/1.60 550 80 BOP Test / Trip Casing 17-Dec 9544 10.50 42 11 18 7/10/14 3.6 40/29/24/19/7/6 2/-13.0 0.0 0.25 0.10 9.0 22.5 0.05/1.5 600 50 Running Casing 18-Dec 9544 10.6 45 13 21 9/16/22 3.7 47/34/29/22/9/8 2/-13 3/84 0.25 0.02 8.5 21.25 0.01/1.60 500 60 Running Casing 19-Dec 9544 10.6 46 12 20 7/14/21 3.6 44/32/28/22/8/7 1/-13 3/84 0.25 0.02 8.5 21.25 0.01/1.60 500 60 Waiting on cement to cure 20-Dec 9544 10.6 46 12 20 7/13/21 3.6 44/32/28/22/8/7 1/-13 3/84 0.25 0.02 8.4 21.25 0.01/1.60 500 60 PU 4" DP 21-Dec 9544 10.5 46 14 13 6/7/9 4.0 41/27/22/15/6/5 1/-13 3/84 0.25 0.001 7.4 21.25 0.00/0.01 500 120 Drilling float equipment 22-Dec 9544 10.50 50 10 11 4/15/32 4.0 31/21/16/12/4/3 1/-13.0 3/84 0.25 0.001 9.4 21.25 -/0.1 500 120 TIH 23-Dec 9564 12.30 47 19 28 7/9/10 5.0 66/47/39/27/8/7 1/-20.0 2/78 0.00 6.00 10.0 -5.90/9.50 140000 20 Drilling ahead 24-Dec 9655 12.30 50 19 29 8/9/11 4.7 67/48/40/30/9/8 1/-19.0 2/79 0.00 6.00 10.0 -5.90/9.50 132000 10 Drilling Adead 27-Dec-2014 Remarks WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:10-Nov-2014 SPERRY JOB:TD: 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 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++ 25-Dec 10736 12.30 45 18 26 7/9/10 4.4 62/44/36/27/9/7 1/-19.0 2/80 0.00 5.40 9.7 0.80 5.28/8.79 142000 40 Drilling ahead 26-Dec 11986 12.30 44 17 23 7/9/10 4.6 57/40/33/42/8/7 1/-19.2 2/79 0.00 5.90 10.2 3.50 5.72/10.50 146000 80 Drilling ahead 27-Dec 13013 12.30 44 17 23 7/8/10 4.2 57/40/34/24/8/7 1/-21.0 2/77 0.00 6.00 10.0 6.00 5.60/10.52 141700 90 Drilling ahead, TD production section 28-Dec 13013 12.30 44 18 23 7/9/11 4.5 59/41/34/23/7/6 1/-21.0 2/77 0.00 5.40 9.8 7.75 5.10/9.40 141000 100 Ream Out of Hole 29-Dec 13013 12.30 44 18 26 7/8/11 4.6 62/44/36/25/7/6 1/-20.5 2/78 0.00 5.40 9.8 5.00 5.10/9.40 140000 120 BOP Test, Ream Out of Hole 30-Dec 31-Dec 1-Jan 13013 12.30 45 18 24 7/8/11 4.8 60/42/35/24/7/6 1/-20.5 2/78 -5.40 9.8 5.25 5.1/9.4 140000 120 Casing Record Remarks 16" Conductor @ 160' MD, 160'TVD 10.75" Casing @ 3342' MD, 2836'TVD 7.625" Casing @ 9544' MD, 5985'TVD 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 -1 Smith XR+ MillTooth 13.50 160 250 90 2.40 0.994 104.17 1.0 45 300 300 0-0-NO-A-E-I-NO-BHA Drill to P/U full BHA 2 -2 Smith XR+ MillTooth 9.875 250 3352 3102 17.10 0.994 109.28 24.5 91 1180 600 3-4-WT-A-E-I-SD-TD TD Surface Section 3 100 3 Smith MSI 516 PDC 9.880 3352 8018 4666 46.51 0.910 100.32 20.0 150 2800 750 1-2-CT-G-X-I-WT-HP TD Intermediate Section PB1 4 150 4 Smith XR+C MillTooth 9.880 3342 3342 --0.739 --60 1100 500 1-1-WT-A-E-I-WT-BHA Mill out casing 5 200 5 Smith MSI 516 PDC 9.88 3342 9543 6201 53.35 0.910 114.43 19.0 120 3361 750 1-1-WT-A-X-I-NO-TD TD Intermediate Section 6 260 6 Smith MDI 503 PDC 6.50 9543 9543 --0.752 --50 1250 250 0-0-NO-A-X-I-NO-TD Cleanout Run 7 300 7 Smith PDC 6.50 9543 9656 113 1.75 0.752 64.57 17.9 150 2600 277 1-1-WT-A-X-I-NO-DTF Downhole Tool Failure 8 400 8 Smith PDC 6.50 9656 13014 3358 42.00 0.752 80.71 18.0 420 3260 282 2-2-BT-A-X-I-PN/NO-TD TD Production Section WELL NAME:2M-36 & 2M-36 PB1 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901812451 TD:27-Dec-2014 MI Swaco STATE:Alaska RIG:Doyon 25 SPUD:10-Nov-2014 B i t R e c o r d . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 17-Nov-2014 12:00 AM Current Pump & Flow Data: 556 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 9.875Smith PBC Size plug present. Continue to RIH at a depth of 2993'md as of 4 am. Kelly up and tag cancellation plug @902' md. Drill plug w/ 405 gpm , 545 psi. work thru w/o pump or rotary, no indication of 3342' 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) 3187' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type Depth in / out YP (lb/100ft2) CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 RIH PV Footage 0.00 Lee Martin/John Hayne ShClyst TuffGvlCoal cP Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 0' 3352' 0' Max @ ft Current Date: Time: Test BOPE , rig down test equipment . Line up choke manifold. Pull testplud, drain stack & set wear bushing. in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth MBT pH Siltst 406 96 Units* Casing Summary Lithology (%) 9076597599Unit Phone:A.Paul Kalenuik Maximum Report By:Logging Engineers:A.Paul Kalenuik/ Dani Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Cly Bottoms Up Time 240.47 0 CURRENT- 2128 293.48 53.02 CURRENT-18.8 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 11 18-Nov-2014 12:00 AM Current Pump & Flow Data: 1373 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 6.0 9.875 9.60 Smith PBC 9.60 Size rat hole . Perform FIT test and displace wellbore to LSND . Con't to drill ahead. 3342' 100% Gas In Air=10,000 Units69Connection 80 Tools API FL Chromatograph (ppm) 3352' WOB Hydril 10.39 Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type WBM 10.03667'26 Depth in / out YP (lb/100ft2) 9.90 001 00 CementChtSilt C-4i C-4n 24 hr Max Weight 56 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling Ahead PV Footage 0.00 Lee Martin/John Hayne ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 23 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 151.0 Flow In (gpm) Flow In (spm) 3352' 3675' 323' Max @ ft Current 3642'57.5 Date: Time: RIH assy and tag cement stringer @2902'. Drill same and con't to RIH to 3106' md, per form casing test. Drill out cement plus 20' 47 in 1Minimum Depth C-5n 3598' 82.0 C-2 116 SPP (psi) Gallons/stroke TFABit Type Depth 3.852 MBT pH 0 39 0 Siltst 643 152 Units* Casing Summary Lithology (%) 55381 0 9076597599Unit Phone: 18 A.Paul Kalenuik Maximum Report By:Logging Engineers:A.Paul Kalenuik/ Dani Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 245 0 Cly 12733 Bottoms Up Time 264.62 0 CURRENT- 2626 323.61 58.98 CURRENT-17.3 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Con't to drill wellbore from 3675 ftah T/5186 ftah. Currently POOH to shoe due to extreme weather condition. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 5 19-Nov-2014 12:00 AM Current Pump & Flow Data: 1243 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 9.0 9.875 Smith PBC 9.70 Size 3342' 100% Gas In Air=10,000 Units55Connection 21 Tools API FL Chromatograph (ppm) 3352' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 10Background (max) Trip Average 68 Mud Type Lst Type WBM 5.45186'30 Depth in / out YP (lb/100ft2) 10.00 020 00 CementChtSilt C-4i C-4n 24 hr Max Weight 65 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 $3,844.00 $62,788.00 Trip Out To Shoe PV Footage 0.00 Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 15 Gas Summary 0 12 7 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 184.0 Flow In (gpm) Flow In (spm) 3675' 5186' 1511' Max @ ft Current 3748'70.1 Date: Time: 58 in 0Minimum Depth C-5n 3790' 0.0 C-2 97 SPP (psi) Gallons/stroke TFABit Type Depth 12.552 MBT pH 0 11 0 Siltst 623 154 Units* Casing Summary Lithology (%) 16898 22 9076597599Unit Phone: 0 A.Paul Kalenuik Maximum Report By:Logging Engineers:A.Paul Kalenuik/ Dani Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 163 0 Cly 11135 Bottoms Up Time 372.31 0 2306457.9 85.59 15.6 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max)(current) Cly Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone:A.Paul Kalenuik Maximum Report By:Logging Engineers:A.Paul Kalenuik/ Dani Dawson Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.552 C-5nC-2 in Minimum Depth Time: 5186' 5186' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 15 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 WOW PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00WBM5.45186'30 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 UnitsConnection 3342' ConditionBit # 3 9.0 9.875 Smith PBC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Nov-2014 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 400.00 Wait on the weather rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Wait on the weather rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 21-Nov-2014 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 9.0 9.875 Smith PBC 9.70 Size 3342' 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) 3352' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type WBM 5.45186'30 Depth in / out YP (lb/100ft2) 10.00 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 WOW PV Footage 0.00 Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 15 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 5186' 5186' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 12.552 MBT pH Siltst Units* Casing Summary Lithology (%) 9076597599Unit Phone:A.Paul Kalenuik Maximum Report By:Logging Engineers:A.Paul Kalenuik/ Dani Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Cly Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Wait on the weather rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 22-Nov-2014 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 9.0 9.875 Smith PBC 9.70 Size 3342' 100% Gas In Air=10,000 UnitsConnection Tools API FL Chromatograph (ppm) 3352' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type WBM 5.45186'30 Depth in / out YP (lb/100ft2) 10.00 CementChtSilt C-4i C-4n 24 hr Max Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 WOW PV Footage 0.00 Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 15 Gas Summary (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 5186' 5186' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 12.552 MBT pH Siltst Units* Casing Summary Lithology (%) 9076597599Unit Phone:A.Paul Kalenuik Maximum Report By:Logging Engineers:A.Paul Kalenuik/ Dani Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Cly Bottoms Up TimeVolumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 447 0 4425549102 25 Minutes (max)(current) 4882 41 Cly 10119 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 999 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/ Dani Dawson 5175 3583 749 177 Units* Casing Summary Lithology (%) 1 MBT pH 0 2534 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 22.553 C-5n N/A 144.0 C-2 289 in 0 5189'Minimum Depth Time: 47 5186' 6137' 951' Max @ ft Current 3748'150.4 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 251.4 Flow In (gpm) Flow In (spm) Gas Summary 0 2523 1008 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 13 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drillg Ahead PV 24 hr Max Weight 86 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 WBM 4.86135'25 Depth in / out Mud Type Lst Type Average 28940Background (max) Trip 10.6010.87 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 2510 3342' ConditionBit # 3 10.0 9.875 9.70 Smith PBC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.66 Doyon 25 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Nov-2014 12:00 AM Current Pump & Flow Data: 2637 Max 8 Chlorides mg/l 400.00 Trip in hole from casing shoe at 3346' MD to 5186' MD. Drill from 5186' MD to 6137' MD. Max gas was 289 units. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5715764135 33 Minutes (max)(current) 7220 15 Cly 94532 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 382 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/ Dani Dawson 12564 151 749 89 Units* Casing Summary Lithology (%) 78 MBT pH 9 800 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.552 C-5n 7945' 0.0 C-2 1215 in 16 6940'Minimum Depth Time: 141 6137' 8018' 1881' Max @ ft Current 6969'142.2 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 238.5 Flow In (gpm) Flow In (spm) Gas Summary 0 1687 381 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 15 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drillg Ahead PV 24 hr Max Weight 923 Hours C-3 04 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 5316951 WBM 4.48018'25 Depth in / out Mud Type Lst Type Average N/A45Background (max) Trip 10.1211.13 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 Units1065Connection 3503 3342' ConditionBit # 3 10.0 9.875 9.75 Smith PBC 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.70 Doyon 25 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max 425 Chlorides mg/l 400.00 Drilled from 6137' MD to 8018' MD. Took 44 bbl kick at 8018' MD. Currently weighting-up to 10.1ppg. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830764135 33 Minutes (max)(current) 37510 4 Cly 364549 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 3939 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/ Dani Dawson 33498 35 749 89 Units* Casing Summary Lithology (%) 480 MBT pH 5 4947 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.045 C-5n - 0.0 C-2 7884 in 8 -Minimum Depth Time: opened to circulate mud from 1st kick. 641 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 14075 3527 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 15 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating Kick PV 24 hr Max Weight 3024 Hours C-3 08 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 5661516475 WBM 3.78018'22 Depth in / out Mud Type Lst Type Average N/A6Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 21316 3342' ConditionBit # 3 11.0 9.875 10.35 Smith PBC 10.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max 1819 Chlorides mg/l 400.00 Raised mud weight to 10.3 ppg. Took 2nd kick with 3 barrel gain. Max gas of 7884 Units occurred when BOP was rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 10400 23 Cly 147703 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 891 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 86059 135 749 89 Units* Casing Summary Lithology (%) 987 MBT pH 28 1133 18 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.050 C-5n - 0.0 C-2 3878 in 14 -Minimum Depth Time: the past 24hrs is 934 bbls. Max gas was 3878 units and occurred while Circulating. 1389 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 27 2725 742 (current) Granville Rizek/Rob Reinhart ShClyst TuffGvlCoal cP 17 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating PV 24 hr Max Weight 7266 Hours C-3 4152 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.30 7282547651 WBM 3.88018'20 Depth in / out Mud Type Lst Type Average N/A41Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 4700 3342' ConditionBit # 3 13.0 9.875 10.50 Smith PBC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 26-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max 3962 Chlorides mg/l 400.00 Circulate at a bit depth of 7963’ MD while pumping at 20 strokes per min and steadily losing mud. Total loses for rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 6949 50 Cly 83048 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 571 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 5196 720 749 88 Units* Casing Summary Lithology (%) 48 MBT pH 22 928 5 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.560 C-5n - 0.0 C-2 1141 in 9 -Minimum Depth Time: are 367 Barrels. 64 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 2153 527 (current) Granville Rizek/Rob Reinhart ShClyst TuffGvlCoal cP 24 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating PV 24 hr Max Weight 394 Hours C-3 015 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.40 3412031 WBM 3.68018'22 Depth in / out Mud Type Lst Type Average N/A43Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 3645 3342' ConditionBit # 3 11.0 9.875 10.50 Smith PBC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max 187 Chlorides mg/l 400.00 Circulate and treat for losses with LCM. Max Gas was 1141 Units while circulating. Losses for the last 24hrs rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap:Circulate and treat for losses with LCM. Max Gas was 1038 Units while circulating. Losses for the last 24hrs rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 106 28-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 9.5 9.875 10.50 Smith PBC 10.50 Size 3342' 100% Gas In Air=10,000 UnitsN/AConnection 3382 Tools API FL Chromatograph (ppm) 3352' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Type WBM 5.08018'26 Depth in / out YP (lb/100ft2) 9.30 298925 00 CementChtSilt C-4i C-4n 24 hr Max Weight 181 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating PV Footage 0.00 Granville Rizek/Rob Reinhart ShClyst TuffGvlCoal cP 15 Gas Summary 0 2036 499 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 8018' 8018' 0' Max @ ft Current 0.0 Date: Time: are 755 Barrels. 33 in 1 -Minimum Depth C-5n - 0.0 C-2 1038 SPP (psi) Gallons/stroke TFABit Type Depth 10.057 MBT pH 3 860 9 Siltst 749 88 Units* Casing Summary Lithology (%) 342172 34 9076597599Unit Phone: 536 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 6412 5 Cly 76621 Bottoms Up Time 574 0 5830724135 33 Minutes Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 926 0 Cly 10947 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 71 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 6570 0 749 88 Units* Casing Summary Lithology (%) 75 MBT pH 0 118 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.057 C-5n - 0.0 C-2 2557 in 0 -Minimum Depth Time: Began weighting up water based mud to 10.8 pounds per gallon kill weight. . Losses for the last 24hrs are 873 Barrels. 78 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 272 65 (current) Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 15 Footage 0.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating PV 24 hr Max Weight 545 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.30 5418848 WBM 5.08018'26 Depth in / out Mud Type Lst Type Average N/A10Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 3352' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 468 3342' ConditionBit # 3 12.0 9.875 10.65 Smith PBC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 29-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max 285 Chlorides mg/l 600.00 Tripped in the hole to a depth of 8014’ MD and circulated water based mud at a pump rate of 20 strokes per minute. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap:POOH to HWDP. Attach Retrievamatic test packer above HWDP. Lost 652 bbls while POOH. Losses for the last rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 30 30-Nov-2014 12:00 AM Current Pump & Flow Data: 326 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 11.5 9.875 10.70 Smith PBC 10.80 Size 3342' 100% Gas In Air=10,000 UnitsN/AConnection 963 Tools API FL Chromatograph (ppm) 3352' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max) Trip Average 173 Mud Type Lst Type WBM 5.48018'24 Depth in / out YP (lb/100ft2) 9.40 11349 00 CementChtSilt C-4i C-4n 24 hr Max Weight 38 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 POOH PV Footage 0.00 Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 14 Gas Summary 0 856 256 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 8018' 8018' 0' Max @ ft Current 0.0 Date: Time: 24hrs are 936 Barrels. 7 in 0 -Minimum Depth C-5n - 0.0 C-2 173 SPP (psi) Gallons/stroke TFABit Type Depth 11.355 MBT pH 0 334 0 Siltst 749 88 Units* Casing Summary Lithology (%) 12329 0 9076597599Unit Phone: 285 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 1173 0 Cly 7443 Bottoms Up Time 574 0 5830724135 33 Minutes Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap:Tested casing above and below stage collar. Laid down BHA. Performed general maintenance on gas equipment. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 30 1-Dec-2014 12:00 AM Current Pump & Flow Data: 326 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 11.5 9.875 10.80 Smith PBC 10.80 Size 3342' 100% Gas In Air=10,000 UnitsN/AConnection 1616 Tools API FL Chromatograph (ppm) 3352' 8018' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 401 Mud Type Lst Type WBM 5.48018'22 Depth in / out YP (lb/100ft2) 9.30 224718 00 CementChtSilt C-4i C-4n 24 hr Max Weight 30 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Place Cement Plugs PV 4666' Footage Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 12 Gas Summary 0 1004 246 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 8018' 8018' 0' Max @ ft Current 0.0 Date: Time: Tested annular preventer. TIH to place cement plugs. Losses for the last 24hrs are 72 Barrels. 7 in 0 -Minimum Depth C-5n - 0.0 C-2 401 SPP (psi) Gallons/stroke TFABit Type Depth 10.053 MBT pH 0 426 0 Siltst 749 88 Units* Casing Summary Lithology (%) 16156 0 9076597599Unit Phone: 262 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 2853 0 Cly 30626 Bottoms Up Time 574 0 5830724135 33 Minutes Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 8901 0 Cly 126162 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 499 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 19040 0 749 88 Units* Casing Summary Lithology (%) 178 MBT pH 0.910 0 931 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.052 C-5n - 0.0 C-2 1604 in 0 -Minimum Depth Time: Losses for the last 24hrs are 793 Barrels. 234 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 2137 474 (current) Granville Rizek/Rob Reinhardt ShClyst TuffGvlCoal cP 11 4666' Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Place Cement Plugs PV 24 hr Max Weight 1482 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.40 111426103 120.0 WBM 5.68018'22 Depth in / out Mud Type Lst Type Average N/A6Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 4082 3342' ConditionBit # 3 11.0 9.875 10.70 Smith PBC 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 2-Dec-2014 12:00 AM Current Pump & Flow Data: 326 Max 727 Chlorides mg/l 550.00 Complete tripping into hole. Conditioned mud for cement plugs. Place First cement plug. Circulate after setting plug. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 16686 0 Cly 3171 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 268 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 94 0 749 88 Units* Casing Summary Lithology (%) 6 MBT pH 0.910 0 944 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.055 C-5n - 0.0 C-2 249 in 0 -Minimum Depth Time: 5 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 304 784 (current) David Lee/Rob Reinhardt ShClyst TuffGvlCoal cP 16.88 4666' Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 TIH PV 24 hr Max Weight 11 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 8187 120.0 WBM 5.68018'22 Depth in / out Mud Type Lst Type Average N/A2Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 1545 3342' ConditionBit # 3 11.0 9.875 10.70 Smith PBC 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 3-Dec-2014 12:00 AM Current Pump & Flow Data: 326 Max 11 Chlorides mg/l 1100.00 Set storm packer. Test BOP. Losses for the last 24hrs are 65 Barrels. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 1299 0 Cly 18268 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 220 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 1515 0 126 30 Units* Casing Summary Lithology (%) 24 MBT pH 0.910 0 256 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.052 C-5n - 0.0 C-2 263 in 0 -Minimum Depth Time: 14 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 660 199 (current) David Lee/Rob Reinhardt ShClyst TuffGvlCoal cP 15 4666' Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Set Cement Plugs PV 24 hr Max Weight 117 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 11.00 226520 120.0 WBM 8.88018'17 Depth in / out Mud Type Lst Type Average N/A0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 787 3342' ConditionBit # 3 11.0 9.875 10.70 Smith PBC 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Dec-2014 12:00 AM Current Pump & Flow Data: 246 Max 73 Chlorides mg/l 1100.00 TIH. Condition mud for cement plugs. Place cement plugs. Losses for the last 24hrs are 513 Barrels. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap:Circulate and POOH to 4500' MD. Losses for the last 24 hrs is 517 bbls. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 0 5-Dec-2014 12:00 AM Current Pump & Flow Data: 153 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 11.0 9.875 10.80 Smith PBC 10.80 Size 3342' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Type 120.0 WBM 8.48018'18 Depth in / out YP (lb/100ft2) 10.80 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulate PV 4666' Footage 46.51 David Lee/Rob Reinhardt ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 199 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 8018' 8018' 0' Max @ ft Current 0.0 Date: Time: 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 10.049 MBT pH 0.910 0 0 0 Siltst 210 50 Units* Casing Summary Lithology (%) 00 0 9076597599Unit Phone: 220 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 0 0 Cly 0 Bottoms Up Time 574 0 5830724135 33 Minutes Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap:Circulate to drop mud weight from 10.8 ppg to 9.8 ppg. 20 bbls were gained in the last 24 hrs. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 360.00 1 6-Dec-2014 12:00 AM Current Pump & Flow Data: 150 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 7.5 9.875 9.80 Smith PBC 9.80 Size 3342' 100% Gas In Air=10,000 UnitsN/AConnection 3 Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 8Background (max) Trip Average N/A Mud Type Lst Type 120.0 WBM 8.88018'13 Depth in / out YP (lb/100ft2) 9.50 231 00 CementChtSilt C-4i C-4n 24 hr Max Weight 5 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulate PV 4666' Footage 46.51 David Lee/Rob Reinhardt ShClyst TuffGvlCoal cP 10 Gas Summary 0 0 2 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 8018' 8018' 0' Max @ ft Current 0.0 Date: Time: 12 in 0 -Minimum Depth C-5n - 0.0 C-2 54 SPP (psi) Gallons/stroke TFABit Type Depth 7.545 MBT pH 0.910 0 11 0 Siltst 127 30 Units* Casing Summary Lithology (%) 1557 0 9076597599Unit Phone: 2 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 50 0 Cly 5362 Bottoms Up Time 574 0 5830724135 33 Minutes Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 574 0 5830724135 33 Minutes (max)(current) 0 0 Cly 0 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 0 0 127 30 Units* Casing Summary Lithology (%) 0 MBT pH 0.910 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.044 C-5n - 0.0 C-2 0 in 0 -Minimum Depth Time: 0 8018' 8018' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) David Lee/Rob Reinhardt ShClyst TuffGvlCoal cP 13 4666' Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 WOC PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.50 000 120.0 WBM 10.08018'13 Depth in / out Mud Type Lst Type Average N/A0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 0 3342' ConditionBit # 3 7.0 9.875 9.80 Smith PBC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Dec-2014 12:00 AM Current Pump & Flow Data: 150 Max 0 Chlorides mg/l 400.00 Place cement Plug # 5. WOC. No mud gained or lost in the last 24 hrs. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap:Confirm top of cement @ 2910’ MD. POOH and L/D Cement BHA. P/U Dumb Iron and begin drilling cement out of rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 8-Dec-2014 12:00 AM Current Pump & Flow Data: 150 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 3 7.0 9.875 9.80 Smith PBC 9.80 Size 3342' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Type 120.0 WBM 10.03342'13 Depth in / out YP (lb/100ft2) 10.80 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drill Out Cement PV 4666' Footage 46.51 David Lee/Rob Reinhardt ShClyst TuffGvlCoal cP 13 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 3342' 3342' 0' Max @ ft Current 0.0 Date: Time: casing. No mud gained or lost in the last 24 hrs. 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 5.041 MBT pH 0.910 0 0 0 Siltst 127 30 Units* Casing Summary Lithology (%) 00 0 9076597599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 0 0 Cly 0 Bottoms Up Time 217 0 186127760 62 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 217 0 186127760 62 (max)(current) 0 0 Cly 0 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 0 0 127 30 Units* Casing Summary Lithology (%) 0 MBT pH 0.910 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.044 C-5n - 0.0 C-2 0 in 0 -Minimum Depth Time: 24 hrs. 0 3342' 3342' 0' Max @ ft Current 0.0 Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 8 4666' Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 TIH PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.20 000 120.0 WBM 6.03342'15 Depth in / out Mud Type Lst Type Average N/A0Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 0 3342' ConditionBit # 3 7.0 9.875 9.70 Smith PBC 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Dec-2014 12:00 AM Current Pump & Flow Data: 150 Max 0 Chlorides mg/l 460.00 Drill Cement to 3292' MD. POOH. Test BOPE. P/U drilling BHA w/ MWD tools. TIH. No mud gained or lost in the last rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap:Test Casing. Drill through cement to kick off point at 3410' MD. Perform FIT test to 12.5 ppg. Drill from 3410' MD to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 19 10-Dec-2014 12:00 AM Current Pump & Flow Data: 1170 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.59 Doyon 25 Report For: ConditionBit # 3 7.0 9.875 9.70 Smith PBC 9.70 Size 4 3342' 100% Gas In Air=10,000 Units272Connection 153 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 10.3010.45 Avg Min Comments RPM ECD (ppg) ml/30min 81Background (max) Trip Average N/A Mud Type Lst Type 120.0 Smith PBC WBM 5.2 3352' 3811'19 Depth in / out YP (lb/100ft2) 10.00 3105 00 CementChtSilt C-4i C-4n 24 hr Max Weight 74 Hours C-3 100 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling Ahead PV 4666' 9.875 Footage 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 13 Gas Summary 0 78 54 (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: 240.0 Flow In (gpm) Flow In (spm) 3342' 3818' 476' Max @ ft Current 3499'134.0 Date: Time: 3818' MD. No mud gained or lost in the last24 hrs. Max gas was connection gas at 272 units. 85 in 19 3474'Minimum Depth C-5n 3637' 114.0 C-2 272 SPP (psi) Gallons/stroke TFABit Type Depth 7.549 MBT pH 0.910 0 82 0 Siltst 550 129 Units* Casing Summary Lithology (%) 106711 2359 9076597599Unit Phone: 45 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 422 15 Cly 21557 Bottoms Up Time 326 0 324238761 25 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Drilled from 3818' MD to 5632' MD. No mud gained or lost in the last24 hrs. Max gas was connection gas at 173 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 340.00 4 11-Dec-2014 12:00 AM Current Pump & Flow Data: 2330 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 25 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.25 Doyon 25 Report For: ConditionBit # 3 9.0 9.875 9.70 Smith PBC 9.70 Size 4 3342' 100% Gas In Air=10,000 Units173Connection 6 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15.03352' 8018' WOB Hydril 10.3110.84 Avg Min Comments RPM ECD (ppg) ml/30min 50Background (max) Trip Average N/A Mud Type Lst 100% Type 120.0 Smith PBC WBM 5.2 3352' 5400'20 Depth in / out YP (lb/100ft2) 10.40 010 00 CementChtSilt C-4i C-4n 24 hr Max Weight 53 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling Ahead PV 4666' 9.875 Footage 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 15 Gas Summary 0 1 0 (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: 290.0 Flow In (gpm) Flow In (spm) 3818' 5632' 1814' Max @ ft Current 5001'155.0 Date: Time: units. 62 in 17 4654'Minimum Depth C-5n 5048' 125.0 C-2 173 SPP (psi) Gallons/stroke TFABit Type Depth 15.044 MBT pH 0.910 0 1 0 Siltst 698 165 Units* Casing Summary Lithology (%) 15742 3153 9076597599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 95 24 Cly 10541 Bottoms Up Time 456 0 455559294 33 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . # * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 561 0 5585681120 42 (max)(current) 877 0 Cly 79120 Set AtSize 29.7 L80 Grade 10.875'' 9076597599Unit Phone: 10 Michael LaDouceur Maximum Report By:Logging Engineers:Michael LaDouceur/Todd Wilson 20% 11596 0 744 134 Units* Casing Summary Lithology (%) 95 MBT pH 0.910 0 28 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.051 C-5n 6636' 85.0 C-2 655 in 0 7106'Minimum Depth Time: units. 152 5632' 7100' 1468' Max @ ft Current 112.0 Date: Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: 315.0 Flow In (gpm) Flow In (spm) Gas Summary 0 41 13 (current) Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 20 4666' 9.875 Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling Ahead PV 24 hr Max Weight 1012 Hours C-3 80% 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 7221871 107.0 Smith PBC WBM 4.3 3352' 5400'26 Depth in / out Mud Type Lst Type Average N/A185Background (max) Trip 10.3110.84 Avg Min Comments RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15.23352' 8018' WOB Hydril 100% Gas In Air=10,000 Units655Connection 129 4 3342' ConditionBit # 3 11.0 9.875 10.30 Smith PBC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.25 Doyon 25 Report For: Morning Report Report # 26 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 12-Dec-2014 12:00 AM Current Pump & Flow Data: 2771 Max 553 Chlorides mg/l 400.00 Drilled from 5632' MD to 7100' MD. No mud gained or lost in the last24 hrs. Max gas was connection gas at 655 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . # * 24 hr Recap: Drilled from 7100' MD to 8927' MD. No mud gained or lost in the last 24 hrs. Max gas was connection gas at 916 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 700.00 549 13-Dec-2014 12:00 AM Current Pump & Flow Data: 2771 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 27 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.25 Doyon 25 Report For: ConditionBit # 3 14.0 9.875 10.15 Smith PBC 10.50 Size 4 3342' 100% Gas In Air=10,000 Units916Connection 2165 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15.23352' 8018' WOB Hydril 10.3110.84 Avg Min Comments RPM ECD (ppg) ml/30min 910Background (max) Trip Average N/A Mud Type Lst Type 107.0 Smith PBC WBM 4.2 3352' 8439'22 Depth in / out YP (lb/100ft2) 9.90 7522465 63184 CementChtSilt C-4i C-4n 24 hr Max Weight 1307 Hours C-3 90% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling Ahead PV 4666' 9.875 Footage 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 17 Gas Summary 53 674 189 (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: 219.0 Flow In (gpm) Flow In (spm) 7100' 8927' 1827' Max @ ft Current 9059'141.0 Date: Time: units. 223 in 176 8097'Minimum Depth C-5n 8835' 145.0 C-2 916 SPP (psi) Gallons/stroke TFABit Type Depth 25.042 MBT 8940' pH 0.910 450 257 78 Siltst 744 134 Units* Casing Summary Lithology (%) 97 10% 18818 15113 (907) 659-7599Unit Phone: 195 Pascal Poupart Maximum Report By:Logging Engineers:Pascal Poupart/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 5290 1062 Cly 73155 Bottoms Up Time 694 0 6889846152 40 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 738 0 7329901163 149.6 (max)(current) 18953 279 Cly 189501 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 1144 Pascal Poupart Maximum Report By:Logging Engineers:Pascal Poupart/Todd Wilson 20% 18818 4436 207 49 Units* Casing Summary Lithology (%) 97 MBT 9511' pH 0.910 161 1462 35 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 25.039 C-5n 9543' 0.0 C-2 3196 in 166Minimum Depth Time: Drilled from 8927' MD to 9543' MD. TD section at 9:15 am. Cleaning cycle performed. Shutdown and monitor well. Attempt to work 409 got it free, brought pumps up. No mud gained or lost in the last 24hrs. 8927' 9544' 617' Max @ ft Current 9311'135.7 Date: Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: 261.3 Flow In (gpm) Flow In (spm) Gas Summary 37 3794 1093 (current) Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 13 4666' 9.875 Footage 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating & working pipe PV 24 hr Max Weight 1307 Hours C-3 80% 4395 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.40 7522465 107.0 Smith PBC WBM 3.5 3352' 25 Depth in / out Mud Type Lst Type Average N/A166Background (max) Trip 10.2710.80 Avg Min Comments RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15.23352' 8018' WOB Hydril 100% Gas In Air=10,000 Units1134Connection 9261 4 Killed the rotary and increased pump rate but then observed a packoff. Pumps were killed and pressure bled off. Worked the pipe, Washed down and pump sweep while working the pipe. Stage Pumps up and attempted to rotate but was unsuccessful with rotary.. pipe, pipe would not move. Pipe became free, Performed circulation again. Max gas was circulation gas at 3196 Units at 14:05 hrs. 3342' ConditionBit # 3 14.0 9.875 10.55 Smith PBC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.09 Doyon 25 Report For: Morning Report Report # 28 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 14-Dec-2014 12:00 AM Current Pump & Flow Data: 533 Max 549 Chlorides mg/l 800.00 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . #0 * 24 hr Recap:After working the pipe free and circulating around multiple bottoms up and a sweep, the rig then started pulling out rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 700.00 1176 15-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 29 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.09 Doyon 25 Report For: ConditionBit # 3 13.0 9.875 10.50 Smith PBC 10.50 Size 4 play to start the testing of the BOP's. Currently at report time, testing the BOP's. 3342' 100% Gas In Air=10,000 UnitsN/AConnection 3020 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril 10.2710.80 Avg Min Comments RPM ECD (ppg) ml/30min 240Background (max) Trip Average N/A Mud Type Lst Type 110 107.0 Smith PBC WBM 3.5 3352' 9544'26 9544' Depth in / out YP (lb/100ft2) 9.50 317740281 317740 CementChtSilt C-4i C-4n 24 hr Max Weight 1506 Hours C-3 80% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Testing BOP's PV 4666' 9.875 0.910 Footage 60.92 6192' 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 15 Gas Summary 281 1246 397 (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 9544' 9544' 0' Max @ ft Current N/AN/A Date: Time: of the hole. Once the rig was able to get out of the hole, the bottom hole assembly was laid down and procedures were put into 240 in 240 9201'Minimum Depth C-5n 9201' 0.0 C-2 937 SPP (psi) Gallons/stroke TFABit Type Depth 22.552 MBT 9511' pH 0.910 1176 489 257 Siltst 0 0 Units* Casing Summary Lithology (%) 257 20% 9355 9355 (907) 659-7599Unit Phone: 429 Pascal Poupart Maximum Report By:Logging Engineers:Pascal Poupart/Todd Wilson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 6548 1506 Cly 69709 Bottoms Up Time 738 0 7329901163 149.6 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap:Finished up testing the BOP's. Once completed, the rig then rigged up and started running 7 5/8" 29# and 39# rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 N/A 16-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 30 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.09 Doyon 25 Report For: ConditionBit # 3 12.0 9.875 10.50 Smith PBC 10.50 Size 4 3342' 100% Gas In Air=10,000 UnitsN/AConnection N/A Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril 10.2710.80 Avg Min Comments RPM ECD (ppg) ml/30min N/ABackground (max) Trip Average N/A Mud Type Lst Type 110 107.0 Smith PBC WBM 3.3 3352' 9544'21 9544' Depth in / out YP (lb/100ft2) 9.40 N/AN/A N/A N/AN/A CementChtSilt C-4i C-4n 24 hr Max Weight N/A Hours C-3 80% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Testing BOP's PV 4666' 9.875 0.910 Footage 60.92 6192' 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 12 Gas Summary N/A N/A N/A (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 9544' 9544' 0' Max @ ft Current N/AN/A Date: Time: Casing. Currently at report time, still running 7 5/8" Casing. N/A in N/A N/AMinimum Depth C-5n N/A 0.0 C-2 N/A SPP (psi) Gallons/stroke TFABit Type Depth 22.546 MBT 9511' pH 0.910 N/A N/A N/A Siltst 0 0 Units* Casing Summary Lithology (%) N/A 20% N/A N/A (907) 659-7599Unit Phone: N/A Pascal Poupart Maximum Report By:Logging Engineers:Pascal Poupart/Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) N/A N/A Cly N/A Bottoms Up Time 738 0 7329901163 149.6 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap:Continued tripping in the hole with 7 5/8" casing until 7198' where the string started taking more weight. Broke cir- rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 664 17-Dec-2014 12:00 AM Current Pump & Flow Data: 400 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 31 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: n/a Doyon 25 Report For: ConditionBit # 3 13.0 9.875 10.50 Smith PBC 10.60 Size 4 on to 9423'. At that time, the string encountered more obstructions and the string was reattached and circulation and movement through, the string was continued in 9136'. String was then attached up and circulated down through an obstruction and continued difficult to work down, but with circulation and movement techniques, the string was allowed to go through the zones. Once 3342' 100% Gas In Air=10,000 UnitsN/AConnection 2611 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril n/an/a Avg Min Comments RPM ECD (ppg) ml/30min 128Background (max) Trip Average 883 Mud Type Lst Type 110 107.0 Smith PBC WBM 3.6 3352' 9544'18 9544' Depth in / out YP (lb/100ft2) 9.00 7123869 00 CementChtSilt C-4i C-4n 24 hr Max Weight 1445 Hours C-3 80% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Testing BOP's PV 4666' 9.875 0.910 Footage 60.92 6192' 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 11 Gas Summary 0 774 206 (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 9544' 9544' 0' Max @ ft Current N/AN/A Date: Time: culation and work the pipe through, then continued on into the hole. Tripped in until 8634' where upon the string became slightly 128 techniques are in use to get the string through these zones. in 50 9544Minimum Depth C-5n 9544 0.0 C-2 883 SPP (psi) Gallons/stroke TFABit Type Depth 22.542 MBT 9511' pH 0.910 0 353 0 Siltst 148 35 Units* Casing Summary Lithology (%) 98 20% 16599 86 (907) 659-7599Unit Phone: 193 Pascal Poupart Maximum Report By:Logging Engineers:Pascal Poupart/Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 6333 0 Cly 78116 Bottoms Up Time 420 0 4176853433 119.5 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap:Continued Circulating the hole while rotating and moving the pipe from 9401' down, staging the pumps. Attempted rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 1931 18-Dec-2014 12:00 AM Current Pump & Flow Data: 322 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 32 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: n/a Doyon 25 Report For: ConditionBit # 3 13.0 9.875 10.50 Smith PBC 10.60 Size 4 rotating, and moving the pipe towards bottom. Casing is at 9532'MD. No gain or loss in the past 24 hrs. to the string and operations were continued with circulation, rotation, and movement down. Currently at report time, still washing, 3342' 100% Gas In Air=10,000 UnitsN/AConnection 6704 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril n/an/a Avg Min Comments RPM ECD (ppg) ml/30min 404Background (max) Trip Average 2067 Mud Type Lst Type 110 107.0 Smith PBC WBM 3.7 3352' 9544'21 9544' Depth in / out YP (lb/100ft2) 8.50 209734215 95322 CementChtSilt C-4i C-4n 24 hr Max Weight 3981 Hours C-3 80% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Testing BOP's PV 4666' 9.875 0.910 Footage 60.92 6192' 46.51 Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 13 Gas Summary 96 2451 644 (current) Avg to3342' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 9544' 9544' 0' Max @ ft Current N/AN/A Date: Time: to wash down past 9436' and then continued down to 9490'. Once completed down, hanger assembly was made up and attached 476 in 212 9506Minimum Depth C-5n 9510 0.0 C-2 2067 SPP (psi) Gallons/stroke TFABit Type Depth 21.345 MBT 9511' pH 0.910 858 1113 135 Siltst 64 15 Units* Casing Summary Lithology (%) 320 20% 41200 17493 (907) 659-7599Unit Phone: 615 Pascal Poupart Maximum Report By:Logging Engineers:Pascal Poupart/Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 14175 1724 Cly 151594 Bottoms Up Time 420 0 4176853433 119.5 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 423 0 4202859436 - (max)(current) 11655 0 Cly 119298 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 557 Michael Sherry Maximum Report By:Logging Engineers:Michael Sherry / Danielle Dawson 20% 29761 0 - - Units* Casing Summary Lithology (%) 309 MBT - pH 0.910 0 985 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 21.346 C-5n - 0.0 C-2 1656 in 0 -Minimum Depth Time: up cement hose and circulate staging pumps at 1 barrel per minute. Pump cement and receive minimal returns. Perform rig 283 9544' 9544' 0' Max @ ft Current N/AN/A Date: Avg -- Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Gas Summary 0 2149 584 (current) G. Rizek / Paul Smith ShClyst TuffGvlCoal cP 12 4666' 9.875 0.910 Footage 60.92 6192' 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Waiting on cement PV 24 hr Max Weight 3223 Hours C-3 80% 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.50 215732218 110 107.0 Smith PBC WBM 3.6 3352' 9544'20 9544' Depth in / out Mud Type Lst Type Average 16560Background (max) Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril 100% Gas In Air=10,000 Units-Connection 5745 4 service. Lost 137 barrels of mud during cement job. 3342' ConditionBit # 3 13.0 9.875 10.60 Smith PBC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 33 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk ROP ROP (ft/hr) 4.23 @ Mud Data Depth 19-Dec-2014 12:00 AM Current Pump & Flow Data: - Max 1735 Chlorides mg/l 500.00 Continued to wash down casing to landing depth of 9532' MD. After landed, circulated at 63 gallons per minute. Rig rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . #0 * 24 hr Recap:Lay down 5" test joint, install packoff. Test packoff. Lay down 5" heavy wall drill pipe and drill pipe via mouse hole. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 0 20-Dec-2014 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 34 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ConditionBit # 3 13.0 9.875 10.60 Smith PBC 10.60 Size 4 3342' 100% Gas In Air=10,000 Units-Connection 0 Tools - API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril -- Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average 0 Mud Type Lst Type 110 107.0 Smith PBC WBM - 3352' 9544'20 9544' Depth in / out YP (lb/100ft2) 8.40 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 80% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 PU 4" DP PV 4666' 9.875 0.910 Footage 60.92 6192' 46.51 G. Rizek / Paul Smith ShClyst TuffGvlCoal cP 12 Gas Summary 0 0 0 (current) Avg -- Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 9544' 9544' 0' Max @ ft Current N/AN/A Date: Time: Pick up 4” drill pipe. 0 in 0 -Minimum Depth C-5n - 0.0 C-2 0 SPP (psi) Gallons/stroke TFABit Type Depth 21.310.6 MBT - pH 0.910 0 0 0 Siltst - - Units* Casing Summary Lithology (%) 0 20% 0 0 (907) 659-7599Unit Phone: 0 Michael Sherry Maximum Report By:Logging Engineers:Michael Sherry / Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) 0 0 Cly 0 Bottoms Up Time 423 0 4202859436 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 423 0 4202859436 - (max)(current) Hydril 563 2168 0 Cly 9003 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 262 Michael Sherry Maximum Report By:Logging Engineers:Michael Sherry / Danielle Dawson 20% 1260 0 7.625" - - Units* Casing Summary Lithology (%) 61 L80 MBT - pH 0.910 0 374 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 21.346 C-5n - 0.0 C-2 206 in 0 -Minimum Depth Time: Mud Loss/Gain: 0 bbls pipe and trip in the hole, filling pipe every 20 stands. Cut and slip drill line. Wash down at 211 gallons per minute. Tag top of 24 9544' 9544' 0' Max @ ft Current N/AN/A Date: Avg -- Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Gas Summary 0 889 277 (current) G. Rizek / Paul Smith ShClyst TuffGvlCoal cP 14 4666' 9.875 0.910 Footage 60.92 6192' 46.51 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling Float Equipment PV 24 hr Max 29.7 Weight 313 Hours C-3 80% 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 7.40 5115552 110 107.0 Smith PBC WBM 4.0 3352' 9544'13 9544' Depth in / out Mud Type Lst Type Average 060Background (max) Trip -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 15 15.23352' 8018' WOB Hydril 100% Gas In Air=10,000 Units-Connection 1736 4 cement around 9412’ MD. 9518' 3342' ConditionBit # 3 13.0 9.875 10.50 Smith PBC 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 35 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Dec-2014 12:00 AM Current Pump & Flow Data: - Max 265 Chlorides mg/l 500.00 Continue to make up 4" drill pipe. Test blow out preventer. Make up clean out bottom hole assembly. Pick up 4” drill rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . #0 * 24 hr Recap:Continued to drill out plug, float collar, and cement from 9428' MD to 9493' MD. Trip out of hole and make up bond rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500.00 147 22-Dec-2014 12:00 AM Current Pump & Flow Data: - Max Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 36 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ConditionBit # 4 13.0 9.875 10.50 Smith PBC 10.50 Size 5 MD. lay down logging tools. Pick up and madke up the BHA and lay down the pressure tool. Running in the hole from 396' MD to 871' 9518' 3342' 100% Gas In Air=10,000 Units-Connection 714 Tools - API FL Chromatograph (ppm) 153352' 9544' WOB Hydril -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min 8Background (max) Trip Average 0 Mud Type Lst Type 110 Smith PDC WBM 4.0 9544' 9544'11 Depth in / out YP (lb/100ft2) 9.40 5113050 00 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 230 Hours C-3 80% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Tripping in Hole PV 6192' 6.5 0.752 Footage 0.00 0' 60.92 G. Rizek / Paul Smith ShClyst TuffGvlCoal cP 10 Gas Summary 0 457 167 (current) Avg -- Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) 9544' 9544' 0' Max @ ft Current N/AN/A Date: Time: Mud Loss/Gain: 0 bbls log tools. Pulling out of the hole while logging from 9490' MD to 8775' MD. Top of cement estimated at 9275' MD. Pulling of the hole and 6 in 0 -Minimum Depth C-5n - 0.0 C-2 86 SPP (psi) Gallons/stroke TFABit Type Depth 21.350 L80 MBT - pH 0.910 0 167 0 Siltst 7.625" - - Units* Casing Summary Lithology (%) 105 20% 503 10 (907) 659-7599Unit Phone: 174 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Hydril 563 675 0 Cly 1727 Bottoms Up Time 392 0 20244364.77 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 291.83 0 2881437101.69 - (max)(current) Hydril 563 1099 0 Cly 12780 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 33 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson 20% 1675 0 7.625" 0 0 Units* Casing Summary Lithology (%) 41 L80 MBT - pH 0.910 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -47 C-5n - 0.0 C-2 484 in 0 -Minimum Depth Time: Mud Loss/Gain: 0 bbls Klashield with 28 bbl spacer. Observed flocculation of the system. Flushed and cleaned out concerned line and equipment. Drill 17 9544' 9564' 20' Max @ ft Current N/A0.4 Date: Avg -9544' Yesterday's Depth: Current Depth: 24 Hour Progress: 62' Flow In (gpm) Flow In (spm) Gas Summary 0 141 0 (current) G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 19 6192' 6.5 0.752 Footage 0.00 - 60.92 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Drilling out Shoe/Rat Hole PV 24 hr Max 29.7 Weight 217 Hours C-3 80% 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 257618 110 Smith PDC KLASHIELD 5.0 9544' 9564'28 - Depth in / out Mud Type Lst Type Average 2916Background (max) Trip 13.5513.59 Avg Min Comments Intermediate RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 153352' 9544' WOB Hydril 100% Gas In Air=10,000 Units-Connection 387 5 cement from 9496' MD to 9516" MD. Currently drilling shoe and rat hole to 9564' MD. 9518' 3342' ConditionBit # 4 20.0 9.875 12.30 Smith PBC 12.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.61 Doyon 25 Report For: Morning Report Report # 37 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max 104 % Chlorides mg/l 140000.00 Continued running in the hole to 9411' MD. Washed down from 9411' MD to 9496' MD and diplace wellbore to rig Density (ppg) out (sec/qt) Viscosity Cor Solids . . #0 * 24 hr Recap:Tripped in to 9503' MD and performed Formation Integrity Test to 14.1 EMW. Drilled from 9564' MD to 9655' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 132000.00 33 24-Dec-2014 12:00 AM Current Pump & Flow Data: 2550 Max Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 38 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.62 Doyon 25 Report For: ConditionBit # 5 19.0 6.5 12.30 Smith PDC 12.30 Size 6 down to 9450' MD. surface, layed down bottom hole assembly. Picked up and made up replacement tool. Tripped in to 9410' MD. Currently washing 9518' 3342' 100% Gas In Air=10,000 Units-Connection 48 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 13.4913.55 Avg Min Comments Intermediate RPM ECD (ppg) ml/30min 11Background (max) Trip Average 42 Mud Type Lst Type 110 Smith PDC KLASHIELD 4.7 9655' 9655'29 - Depth in / out YP (lb/100ft2) 10.00 0130 00 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 90 Hours C-3 100% Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Tripping in Hole PV 101' 6.5 0.752 Footage -- 1.35 G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 19 Gas Summary 0 18 0 (current) Avg -9544' Yesterday's Depth: Current Depth: 24 Hour Progress: 167' Flow In (gpm) Flow In (spm) 9564' 9655' 91' Max @ ft Current 9651'6.8 Date: Time: Mud Loss/Gain: 0 bbls Experienced MWD tool failure. Circulated bottoms up. Tripped out of hole to 8266' MD and pumped slug. Tripped out of hole to 17 in 0 -Minimum Depth C-5n - 0.0 C-2 232 SPP (psi) Gallons/stroke TFABit Type Depth -50 L80 MBT 9655' pH 0.752 0 4 0 Siltst 7.625" 270 64 Units* Casing Summary Lithology (%) 4 0% 1283 0 (907) 659-7599Unit Phone: 0 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Hydril 563 151 0 Cly 2662 Bottoms Up Time 294.2 0 2921441.2 102.7 44 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap:Continued to drill from 9655' MD to 10736' MD at 273 GPM, 11K max. torque, 3k WOB, SPP max. 2655. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 142000.00 59957 25-Dec-2014 12:00 AM Current Pump & Flow Data: 1946 Max Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 39 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.81 Doyon 25 Report For: ConditionBit # 5 19.0 6.5 12.30 Smith PDC 12.30 Size 6 9518' 3342' 100% Gas In Air=10,000 UnitsConnection 13161 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 13.3413.62 Avg Min Comments Intermediate RPM ECD (ppg) ml/30min 641Background (max) Trip Average - Mud Type Lst 90% Type 110 Smith PDC KLASHIELD 4.4 9655' 10736'26 - Depth in / out YP (lb/100ft2) 9.70 332369783250 4771469 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 60892 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Tripping in Hole PV 101' 6.5 0.752 Footage -- 1.35 G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 18 Gas Summary 434 7389 1651 (current) Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: 331' Flow In (gpm) Flow In (spm) 9655' 10736' 1081' Max @ ft Current 10640'139.0 Date: Time: Mud Loss/Gain: -13 bbls (gas aerated mud) 1091 in 0 10422Minimum Depth C-5n 9961 0.0 C-2 2794 SPP (psi) Gallons/stroke TFABit Type Depth 0.845 L80 MBT - pH 0.752 4676 2696 572 Siltst 7.625" 224 53 Units* Casing Summary Lithology (%) 682259477 90134 (907) 659-7599Unit Phone: 1911 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Hydril 563 20874 10295 Cly 116911 10% Bottoms Up Time 322.3 0 3200485.5 114.4 44 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap:Continue to drill production from 10736' MD to 11986' MD at 150 PRM, 273 GPM, 10k max TQ, 13k WOB, and max rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 146000.00 59957 26-Dec-2014 12:00 AM Current Pump & Flow Data: 2778 Max Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 40 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.88 Doyon 25 Report For: ConditionBit # 5 19.2 6.5 12.30 Smith PDC 12.30 Size 6 9518' 3342' 100% Gas In Air=10,000 UnitsConnection 8694 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 13.3413.72 Avg Min Comments Intermediate RPM ECD (ppg) ml/30min 782Background (max) Trip Average - Mud Type Lst 100% Type 110 Smith PDC KLASHIELD 4.6 9655' 11986'23 - Depth in / out YP (lb/100ft2) 10.20 332369783250 2979 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 60892 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Tripping in Hole PV 101' 6.5 0.752 Footage -- 1.35 G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 17 Gas Summary 17 2963 856 (current) Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: 422' Flow In (gpm) Flow In (spm) 10736' 11986' 1250' Max @ ft Current 11657'118.2 Date: Time: Mud Loss/Gain: 0 bbls downhole SPP of 2783 PSI. 1233 in 42 10766Minimum Depth C-5n 11157 82.0 C-2 2513 SPP (psi) Gallons/stroke TFABit Type Depth 3.544 L80 MBT - pH 0.752 109 1210 16 Siltst 7.625" 275 65 Units* Casing Summary Lithology (%) 682259477 1076 (907) 659-7599Unit Phone: 1026 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Hydril 563 15823 170 Cly 111014 Bottoms Up Time 322.3 0 3200485.5 114.4 44 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap:Continue to drill production from 11986' MD to 13013' MD, TD, at 150 PRM, 273 GPM, 14k max TQ, 23k WOB, and rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 141700.00 1533 27-Dec-2014 12:00 AM Current Pump & Flow Data: 2645 Max Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 41 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 14.00 Doyon 25 Report For: ConditionBit # 5 21.0 6.5 12.30 Smith PDC 12.30 Size 6 9518' 3342' 100% Gas In Air=10,000 UnitsConnection 8694 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 13.5313.79 Avg Min Comments Intermediate RPM ECD (ppg) ml/30min 653Background (max) Trip Average - Mud Type Lst 90% Type 110 Smith PDC KLASHIELD 4.2 9655' 13013'23 - Depth in / out YP (lb/100ft2) 10.00 236667225 2979 CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 3331 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Circulating BU PV 101' 6.5 0.752 Footage -- 1.35 G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 17 Gas Summary 17 2963 856 (current) Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: 161' Flow In (gpm) Flow In (spm) 11986' 13013' 1027' Max @ ft Current 12256'83.1 Date: Time: Mud Loss/Gain: 0 bbls downhole max. SPP of 3089 PSI. 581 in 45 11995Minimum Depth C-5n 12968 0.0 C-2 1360 SPP (psi) Gallons/stroke TFABit Type Depth 6.044 L80 MBT - pH 0.752 109 1210 16 Siltst 7.625" 250 59 Units* Casing Summary Lithology (%) 338 10% 31737 1076 (907) 659-7599Unit Phone: 1026 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson Set AtSize 29.7 L80 Grade 10.875'' (max)(current) Hydril 563 15823 170 Cly 111014 Bottoms Up Time 381.5 0 3788579139.1 58 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 381.5 0 3788579139.1 58 (max)(current) Hydril 563 3503 17 Cly 41742 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 185 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson 10% 31737 83 7.625" 0 0 Units* Casing Summary Lithology (%) 338 L80 MBT - pH 0.752 21 193 6 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 7.844 C-5n - - C-2 759 in 2 -Minimum Depth Time: Mud Loss/Gain: 0 bbls downhole out of the hole from 12731' MD to 9820' MD. Pulled out of the hole from 9820' MD, working drill string in tight spots. Circulate 120 13013' 13013' 0' Max @ ft Current -- Date: Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 2 504 188 (current) G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 18 101' 6.5 0.752 Footage -- 1.35 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Tripping Out of Hole PV 24 hr Max 29.7 Weight 3331 Hours C-3 020 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 236667225 110 Smith PDC KLASHIELD 4.5 9655' 13013'23 - Depth in / out Mud Type Lst 90% Type Average 54315Background (max) Trip -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 100% Gas In Air=10,000 Units-Connection 1517 6 2x bottoms up. Performed flow check: well-static. 9518' 3342' ConditionBit # 5 21.0 6.5 12.30 Smith PDC 12.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 42 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth 28-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max 1533 % Chlorides mg/l 141000.00 Circulate bottoms up while reciprocating drill string from 13013' MD to 12731' MD. Obtained slow pump rates. Pump rig Density (ppg) out (sec/qt) Viscosity Cor Solids . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 381.5 0 3788579139.1 58 (max)(current) Hydril 563 2784 7 Cly 27724 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 135 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson 10% 2100 37 7.625" 0 0 Units* Casing Summary Lithology (%) 18 L80 MBT - pH 0.752 8 186 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.044 C-5n - - C-2 403 in 0 -Minimum Depth Time: Mud Loss/Gain: 0 bbls downhole Circulate at bit depth 9215' MD to condition mud. Performed slip and cut of drill line. Perform rig service. Ream into the hole from 9318' 51 13014' 13014' 0' Max @ ft Current -- Date: Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 445 129 (current) G. Rizek / R. Reinhardt ShClyst TuffGvlCoal cP 18 101' 6.5 0.752 Footage -- 1.35 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Cleanout Run PV 24 hr Max 29.7 Weight 190 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 214619 110 Smith PDC KLASHIELD 4.6 9655' 13013'26 - Depth in / out Mud Type Lst 90% Type Average -34Background (max) Trip -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 100% Gas In Air=10,000 Units-Connection 1258 6 Worked drill string through the tight spot. 9519' MD to 10165' MD at 168 GPM and 18% flow out. Pulled out of the hole from 10165' MD to 9887' MD and encountered tight spot. MD to 9552' MD and encountered resistance. Washed down and reamed through at reduced flow rate and RPM. Ream down from 9518' 3342' ConditionBit # 5 20.5 6.5 12.30 Smith PDC 12.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 43 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth 29-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max 86 % Chlorides mg/l 140000.00 Pick up and make up equipmenet for Blowout Preventer test. Perform Blowout Preventer test per CPAI directive. rig Density (ppg) out (sec/qt) Viscosity Cor Solids . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 381.5 0 3788579139.1 58 (max)(current) Hydril 563 567 0 Cly 7887 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 28 David Durst Maximum Report By:Logging Engineers:David Durst / Danielle Dawson 10% 391 15 7.625" 0 0 Units* Casing Summary Lithology (%) 5 L80 MBT 13014' pH 0.752 0 27 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.345 C-5n - - C-2 117 in 8 -Minimum Depth Time: Mud Loss/Gain: 0 bbls downhole Circulated bottoms up while reciprocating drill string from 9500' MD to 9404' MD at max. 280 GPM. Activated Well Commander and 25 13014' 13014' 0' Max @ ft Current -- Date: Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 79 28 (current) L. Martin / R. Reinhardt ShClyst TuffGvlCoal cP 18 101' 6.5 0.752 Footage -- 1.35 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Prepare to Run Liner PV 24 hr Max 29.7 Weight 42 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 5164 110 Smith PDC KLASHIELD 4.8 9655' 13013'24 - Depth in / out Mud Type Lst 90% Type Average -15Background (max) Trip -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 159554' 9655' WOB Hydril 100% Gas In Air=10,000 Units-Connection 209 6 down BHA. GPM. Pulled out of the hole to 4000' MD and performed flow check: well-static. Continued to pull out of the hole to surface. Laid utilized it for 3 bottoms up at 335 GPM. Deactivated Well Commander and pulled out of the hole from 9400' MD to 5850' MD at 126 9518' 3342' ConditionBit # 5 20.5 6.5 12.30 Smith PDC 12.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 44 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth 30-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max 26 % Chlorides mg/l 140000.00 Continued to pull out of the hole from 9887' MD to 9500' MD. Encountered resistance at 9555' MD, worked drill string. rig Density (ppg) out (sec/qt) Viscosity Cor Solids . . #0 * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 381.5 0 3788579139.1 58 (max)(current) Hydril 563 21 0 Cly 185 Set AtSize 29.7 L80 Grade 10.875'' (907) 659-7599Unit Phone: 21 Michael LaDoucuer Maximum Report By:Logging Engineers:Michael LaDouceur / Danielle Dawson 10% 382 26 7.625" 0 0 Units* Casing Summary Lithology (%) 3 L80 MBT 13014' pH 0.752 0 11 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.345 C-5n - - C-2 22 in 8 -Minimum Depth Time: Mud Loss/Gain: 0 bbls downhole 12 13014' 13014' 0' Max @ ft Current -- Date: Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 33 2 (current) L. Martin / R. Reinhardt ShClyst TuffGvlCoal cP 18 101' 6.5 0.752 Footage 42.00 3359' 1.35 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 TIH W/ liner PV 24 hr Max 29.7 Weight 18 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 1121 420 110 Smith PDC KLASHIELD 4.8 9655' 13013'24 13014' Depth in / out Mud Type Lst 90% Type Average -15Background (max) Trip -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 18 159554' 9655' WOB Hydril 100% Gas In Air=10,000 Units-Connection 30 6 9518' 3342' ConditionBit # 5 20.5 6.5 12.30 Smith PDC 12.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: Morning Report Report # 45 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth 31-Dec-2014 12:00 AM Current Pump & Flow Data: 0 Max 14 % Chlorides mg/l 140000.00 Tripped in hole with production liner. rig Density (ppg) out (sec/qt) Viscosity Cor Solids . . #0 * 24 hr Recap:POOH following landing production liner. Begin to Rig Down SDL. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 9 1-Jan-2015 12:00 AM Current Pump & Flow Data: 0 Max Surface ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 46 Customer: Well: Area: Location: Rig: 2M-36 CPAI North Slope Kuparuk Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 25 Report For: ConditionBit # 5 6.5 12.30 Smith PDC 12.30 Size 6 9518' 3342' 100% Gas In Air=10,000 Units-Connection 399 Tools DGR, RES, Density, Directional API FL Chromatograph (ppm) 18 159554' 9655' WOB Hydril -- Avg Min Comments Intermediate RPM ECD (ppg) ml/30min 6Background (max) Trip Average - Mud Type Lst Liner Type 420 110 Smith PDC Brine 9655' 13013' 13014' Depth in / out YP (lb/100ft2) 151 00 Production CementChtSilt C-4i C-4n 24 hr Max 29.7 Weight 23 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901812451 Completions Prep PV 101' 6.5 0.752 Footage 42.00 3359' 1.35 L. Martin / R. Reinhardt ShClyst TuffGvlCoal cP 12.4 Gas Summary 0 103 30 (current) Avg -9655' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13014' 13014' 0' Max @ ft Current -- Date: Time: Mud Loss/Gain: 29 bbls downhole 10 in 8 -Minimum Depth C-5n - - C-2 255 SPP (psi) Gallons/stroke TFABit Type Depth L80 MBT 13014' pH 0.752 0 40 0 Siltst 7.625" 0 0 Units* Casing Summary Lithology (%) 1454 14 (907) 659-7599Unit Phone: 34 Michael LaDoucuer Maximum Report By:Logging Engineers:Michael LaDouceur / Danielle Dawson Set AtSize 29.7 L80 Grade 13014' 10.875'' 4.50'' (max)(current) Hydril 563 1421 0 Cly 26306 Bottoms Up Time 381.5 0 3788579139.1 58 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes WELL INFORMATION Created On : Jan 29 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2M-36 Job Number :AK-XX-0901812451 Rig Name :Doyon 25 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 97.00 0.40 256.40 97.00 0.08 S 0.33 W 0.27 0.41 188.00 0.66 258.57 188.00 0.26 S 1.15 W 0.95 0.29 278.00 1.50 353.59 277.98 0.81 N 1.79 W 1.97 1.88 374.00 1.57 3.93 373.95 3.37 N 1.84 W 3.05 0.30 470.00 3.33 343.60 469.86 7.36 N 2.54 W 5.31 2.02 564.00 3.91 343.60 563.67 13.05 N 4.21 W 9.16 0.62 657.00 4.61 349.66 656.41 19.77 N 5.78 W 13.32 0.89 753.00 6.06 352.48 752.00 28.59 N 7.14 W 18.15 1.53 847.00 8.16 349.61 845.27 40.07 N 8.99 W 24.51 2.27 943.00 11.06 345.45 939.91 55.69 N 12.53 W 34.10 3.10 1037.00 11.05 339.54 1,032.17 72.86 N 17.95 W 46.03 1.21 1130.00 11.98 340.75 1,123.30 90.32 N 24.24 W 58.88 1.03 1189.55 12.88 341.70 1,181.45 102.46 N 28.37 W 67.59 1.55 1284.12 15.84 341.23 1,273.06 124.69 N 35.83 W 83.45 3.13 1379.49 18.29 338.03 1,364.22 150.89 N 45.62 W 103.05 2.75 1473.73 18.90 334.84 1,453.55 178.42 N 57.64 W 125.23 1.26 1567.09 20.43 332.70 1,541.46 206.59 N 71.54 W 149.39 1.81 1661.80 22.52 326.67 1,629.60 236.44 N 89.09 W 177.56 3.21 1756.34 24.83 319.91 1,716.19 266.76 N 111.83 W 210.67 3.77 1851.38 25.64 313.44 1,802.18 296.17 N 139.62 W 248.01 3.02 1947.09 27.21 304.48 1,887.92 322.81 N 172.71 W 289.08 4.47 2040.24 28.97 298.65 1,970.11 345.69 N 210.07 W 332.51 3.50 2134.21 30.55 295.28 2,051.69 366.80 N 251.64 W 379.08 2.45 2230.79 32.20 291.54 2,134.15 386.74 N 297.78 W 429.33 2.64 2323.31 34.82 286.65 2,211.30 403.36 N 346.03 W 480.18 4.06 2421.48 38.39 285.23 2,290.10 419.41 N 402.32 W 538.12 3.74 2516.85 41.43 283.48 2,363.25 434.54 N 461.59 W 598.43 3.40 2607.79 45.83 283.41 2,429.05 449.13 N 522.60 W 660.10 4.84 2702.41 48.87 282.96 2,493.15 464.99 N 590.36 W 728.45 3.23 2753.16 52.41 283.63 2,525.33 474.02 N 628.53 W 767.00 7.05 INSITE V8.1.10 Page 1Job No:AK-XX-0901812451 Well Name:2M-36 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2796.75 53.90 282.80 2,551.47 481.99 N 662.49 W 801.26 3.74 2892.13 56.55 278.98 2,605.88 496.75 N 739.40 W 877.53 4.31 2985.78 58.27 278.81 2,656.32 508.95 N 817.36 W 953.70 1.84 3080.36 59.34 278.31 2,705.31 520.99 N 897.36 W 1031.68 1.22 3174.51 59.40 276.62 2,753.28 531.51 N 977.68 W 1109.34 1.55 3270.06 60.47 275.76 2,801.15 540.42 N 1,059.89 W 1188.07 1.36 3365.81 62.93 276.90 2,846.54 549.73 N 1,143.68 W 1268.39 2.77 3409.80 64.63 275.05 2,865.98 553.83 N 1,182.92 W 1305.92 5.40 3468.72 65.81 273.57 2,890.67 557.85 N 1,236.26 W 1356.28 3.04 3562.30 66.62 273.77 2,928.41 563.33 N 1,321.72 W 1436.58 0.89 3657.43 66.71 273.33 2,966.10 568.74 N 1,408.90 W 1518.42 0.44 3751.85 65.31 273.63 3,004.48 573.97 N 1,495.00 W 1599.21 1.51 3845.78 65.46 273.77 3,043.61 579.48 N 1,580.22 W 1679.30 0.21 3938.23 64.25 273.87 3,082.89 585.06 N 1,663.72 W 1757.85 1.31 4035.06 62.27 273.69 3,126.46 590.76 N 1,750.00 W 1838.99 2.05 4130.81 60.74 274.40 3,172.14 596.69 N 1,833.94 W 1918.08 1.73 4225.62 58.44 276.24 3,220.13 604.26 N 1,915.34 W 1995.53 2.95 4320.24 58.94 278.74 3,269.30 614.80 N 1,995.48 W 2073.03 2.32 4414.64 57.09 282.82 3,319.32 629.74 N 2,074.12 W 2150.94 4.16 4508.04 57.40 282.31 3,369.85 646.83 N 2,150.78 W 2227.93 0.57 4602.79 57.12 280.80 3,421.10 662.79 N 2,228.86 W 2305.75 1.37 4696.08 57.17 277.53 3,471.72 675.27 N 2,306.21 W 2381.49 2.94 4791.19 58.42 276.22 3,522.41 684.90 N 2,386.11 W 2458.39 1.76 4883.67 59.88 276.56 3,569.83 693.73 N 2,465.01 W 2534.06 1.61 4979.22 60.80 277.10 3,617.12 703.61 N 2,547.45 W 2613.39 1.08 5074.19 62.19 277.66 3,662.44 714.33 N 2,630.21 W 2693.36 1.55 5170.10 61.51 278.82 3,707.69 726.45 N 2,713.90 W 2774.74 1.28 5263.78 61.74 278.79 3,752.21 739.07 N 2,795.35 W 2854.29 0.25 5358.58 61.10 278.20 3,797.56 751.37 N 2,877.69 W 2934.51 0.87 5454.10 61.05 278.37 3,843.76 763.41 N 2,960.42 W 3014.98 0.16 5547.64 61.39 278.98 3,888.79 775.78 N 3,041.46 W 3094.05 0.68 5641.71 60.88 277.84 3,934.21 787.83 N 3,122.96 W 3173.40 1.19 5733.47 61.36 277.88 3,978.52 798.82 N 3,202.55 W 3250.59 0.52 5831.19 61.15 280.84 4,025.53 812.75 N 3,287.08 W 3333.47 2.66 5925.64 61.18 281.30 4,071.08 828.63 N 3,368.28 W 3414.11 0.43 6019.38 61.33 281.24 4,116.16 844.70 N 3,448.88 W 3494.28 0.17 6113.82 61.17 281.21 4,161.58 860.81 N 3,530.09 W 3575.03 0.17 6209.16 61.08 280.73 4,207.62 876.70 N 3,612.05 W 3656.36 0.45 6303.94 61.21 280.32 4,253.36 891.86 N 3,693.67 W 3737.09 0.40 6397.65 61.38 280.25 4,298.37 906.54 N 3,774.54 W 3816.94 0.19 6492.71 61.07 279.22 4,344.13 920.63 N 3,856.66 W 3897.69 1.00 6586.76 61.58 278.90 4,389.26 933.62 N 3,938.15 W 3977.42 0.62 6681.04 61.16 278.77 4,434.44 946.33 N 4,019.92 W 4057.29 0.46 6775.49 61.04 278.86 4,480.08 959.00 N 4,101.63 W 4137.09 0.15 6869.68 61.48 278.95 4,525.37 971.79 N 4,183.22 W 4216.82 0.47 INSITE V8.1.10 Page 2Job No:AK-XX-0901812451 Well Name:2M-36 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6964.94 61.11 279.07 4,571.13 984.87 N 4,265.74 W 4297.53 0.40 7060.29 61.28 278.91 4,617.07 997.93 N 4,348.27 W 4378.23 0.23 7155.00 61.31 279.05 4,662.56 1,010.89 N 4,430.32 W 4458.47 0.13 7250.96 61.13 278.45 4,708.76 1,023.69 N 4,513.45 W 4539.61 0.58 7344.69 61.24 278.20 4,753.93 1,035.58 N 4,594.71 W 4618.68 0.26 7440.16 61.16 276.89 4,799.93 1,046.56 N 4,677.64 W 4698.91 1.21 7534.31 61.18 277.46 4,845.33 1,056.87 N 4,759.47 W 4777.86 0.53 7629.36 59.83 278.48 4,892.13 1,068.33 N 4,841.40 W 4857.37 1.70 7723.76 58.74 278.78 4,940.34 1,080.51 N 4,921.64 W 4935.63 1.19 7819.01 56.17 279.04 4,991.58 1,092.94 N 5,000.96 W 5013.14 2.71 7914.03 53.17 278.26 5,046.52 1,104.61 N 5,077.59 W 5087.89 3.23 8007.85 51.39 276.56 5,103.92 1,114.19 N 5,151.17 W 5159.01 2.38 8102.97 50.54 276.45 5,163.83 1,122.56 N 5,224.58 W 5229.48 0.90 8198.21 49.67 276.42 5,224.91 1,130.75 N 5,297.19 W 5299.14 0.91 8294.82 46.98 275.86 5,289.14 1,138.48 N 5,368.93 W 5367.82 2.82 8387.38 43.73 273.79 5,354.18 1,144.05 N 5,434.53 W 5430.02 3.85 8482.21 41.97 271.80 5,423.71 1,147.21 N 5,498.93 W 5490.14 2.34 8576.61 44.49 272.85 5,492.48 1,149.85 N 5,563.53 W 5550.22 2.78 8670.39 46.53 275.16 5,558.20 1,154.54 N 5,630.25 W 5613.09 2.80 8765.77 47.70 275.56 5,623.11 1,161.07 N 5,699.83 W 5679.31 1.26 8858.75 50.04 277.12 5,684.27 1,168.82 N 5,769.43 W 5746.04 2.82 8954.12 52.60 277.87 5,743.87 1,178.54 N 5,843.23 W 5817.42 2.75 9048.20 56.63 279.49 5,798.34 1,190.14 N 5,919.03 W 5891.38 4.51 9142.26 60.87 280.61 5,847.12 1,204.19 N 5,998.19 W 5969.41 4.62 9196.46 63.59 281.11 5,872.37 1,213.22 N 6,045.28 W 6016.10 5.08 9236.74 65.56 281.54 5,889.67 1,220.37 N 6,080.95 W 6051.59 4.98 9330.91 69.18 281.94 5,925.89 1,238.05 N 6,166.04 W 6136.52 3.86 9379.30 71.48 283.57 5,942.18 1,248.12 N 6,210.47 W 6181.21 5.71 9425.44 73.66 284.20 5,956.00 1,258.68 N 6,253.20 W 6224.54 4.90 9476.88 76.65 285.87 5,969.18 1,271.58 N 6,301.22 W 6273.65 6.61 9553.48 78.65 288.51 5,985.57 1,293.70 N 6,372.69 W 6347.94 4.26 9594.43 79.30 287.33 5,993.40 1,306.07 N 6,410.93 W 6387.91 3.24 9632.60 79.70 285.84 6,000.35 1,316.78 N 6,446.90 W 6425.12 3.98 9727.57 80.50 286.78 6,016.68 1,343.05 N 6,536.69 W 6517.83 1.29 9822.18 81.40 286.15 6,031.56 1,369.53 N 6,626.29 W 6610.46 1.16 9917.09 82.37 285.50 6,044.96 1,395.16 N 6,716.69 W 6703.46 1.23 10012.21 83.19 286.27 6,056.92 1,420.98 N 6,807.45 W 6796.88 1.18 10107.07 85.78 285.91 6,066.03 1,447.15 N 6,898.16 W 6890.40 2.76 10201.59 87.52 285.86 6,071.56 1,472.98 N 6,988.91 W 6983.80 1.84 10296.66 90.64 285.79 6,073.08 1,498.89 N 7,080.36 W 7077.89 3.28 10391.75 91.10 286.25 6,071.64 1,525.13 N 7,171.74 W 7172.04 0.68 10486.63 90.45 286.12 6,070.35 1,551.58 N 7,262.85 W 7266.03 0.70 10581.22 89.97 286.44 6,070.01 1,578.09 N 7,353.65 W 7359.76 0.61 10676.50 89.52 290.25 6,070.43 1,608.08 N 7,444.07 W 7454.56 4.03 10771.03 89.87 291.23 6,070.94 1,641.55 N 7,532.47 W 7548.94 1.10 INSITE V8.1.10 Page 3Job No:AK-XX-0901812451 Well Name:2M-36 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10865.50 90.35 293.64 6,070.75 1,677.60 N 7,619.79 W 7643.36 2.60 10960.54 91.17 295.97 6,069.49 1,717.47 N 7,706.04 W 7738.38 2.60 11056.15 91.24 296.74 6,067.48 1,759.90 N 7,791.70 W 7833.89 0.81 11150.66 91.24 296.85 6,065.44 1,802.50 N 7,876.04 W 7928.26 0.12 11254.24 91.17 296.19 6,063.26 1,848.74 N 7,968.70 W 8031.72 0.64 11346.37 91.27 295.72 6,061.30 1,889.05 N 8,051.52 W 8123.77 0.52 11434.62 91.51 293.60 6,059.16 1,925.86 N 8,131.69 W 8211.99 2.42 11528.89 91.62 293.26 6,056.58 1,963.33 N 8,218.16 W 8306.22 0.38 11623.97 87.64 292.47 6,057.20 2,000.26 N 8,305.74 W 8401.26 4.27 11716.10 87.53 294.22 6,061.08 2,036.74 N 8,390.25 W 8493.29 1.90 11811.37 88.49 296.46 6,064.39 2,077.48 N 8,476.30 W 8588.47 2.56 11908.96 89.01 296.72 6,066.52 2,121.15 N 8,563.55 W 8685.94 0.60 12003.61 89.04 298.20 6,068.13 2,164.79 N 8,647.52 W 8780.40 1.56 12098.06 89.32 298.02 6,069.48 2,209.29 N 8,730.82 W 8874.60 0.35 12193.90 89.80 296.40 6,070.21 2,253.11 N 8,816.05 W 8970.28 1.76 12288.37 90.83 294.01 6,069.69 2,293.34 N 8,901.51 W 9064.72 2.75 12380.84 91.55 292.53 6,067.77 2,329.86 N 8,986.44 W 9157.16 1.78 12477.63 92.95 290.02 6,063.97 2,364.95 N 9,076.55 W 9253.76 2.97 12566.48 93.77 291.00 6,058.77 2,396.03 N 9,159.63 W 9342.29 1.44 12663.95 94.51 291.63 6,051.73 2,431.36 N 9,250.19 W 9439.40 1.00 12760.21 93.28 292.10 6,045.19 2,467.13 N 9,339.32 W 9535.36 1.37 12855.41 94.19 292.97 6,038.99 2,503.53 N 9,427.06 W 9630.33 1.32 12953.64 95.18 293.02 6,030.97 2,541.78 N 9,517.18 W 9728.21 1.01 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 294.00 degrees (True) - A total correction of 18.90 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 12,953.64 feet is 9,850.76 feet along 284.95 degrees (True) INSITE V8.1.10 Page 4Job No:AK-XX-0901812451 Well Name:2M-36 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 5Job No:AK-XX-0901812451 Well Name:2M-36 Survey Report WELL INFORMATION Created On : Jan 29 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2M-36 PB1 Job Number :AK-XX-0901812451 Rig Name :Doyon 25 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 97.00 0.40 256.40 97.00 0.08 S 0.33 W -0.18 0.41 188.00 0.66 258.57 188.00 0.26 S 1.15 W -0.62 0.29 278.00 1.50 353.59 277.98 0.81 N 1.79 W 0.19 1.88 374.00 1.57 3.93 373.95 3.37 N 1.84 W 2.59 0.30 470.00 3.33 343.60 469.86 7.36 N 2.54 W 6.14 2.02 564.00 3.91 343.60 563.67 13.05 N 4.21 W 10.98 0.62 657.00 4.61 349.66 656.41 19.77 N 5.78 W 16.83 0.89 753.00 6.06 352.48 752.00 28.59 N 7.14 W 24.74 1.53 847.00 8.16 349.61 845.27 40.07 N 8.99 W 35.00 2.27 943.00 11.06 345.45 939.91 55.69 N 12.53 W 48.63 3.10 1037.00 11.05 339.54 1,032.17 72.86 N 17.95 W 63.12 1.21 1130.00 11.98 340.75 1,123.30 90.32 N 24.24 W 77.60 1.03 1189.55 12.88 341.70 1,181.45 102.46 N 28.37 W 87.74 1.55 1284.12 15.84 341.23 1,273.06 124.69 N 35.83 W 106.36 3.13 1379.49 18.29 338.03 1,364.22 150.89 N 45.62 W 127.98 2.75 1473.73 18.90 334.84 1,453.55 178.42 N 57.64 W 150.13 1.26 1567.09 20.43 332.70 1,541.46 206.59 N 71.54 W 172.28 1.81 1661.80 22.52 326.67 1,629.60 236.44 N 89.09 W 194.83 3.21 1756.34 24.83 319.91 1,716.19 266.76 N 111.83 W 216.16 3.77 1851.38 25.64 313.44 1,802.18 296.17 N 139.62 W 234.98 3.02 1947.09 27.21 304.48 1,887.92 322.81 N 172.71 W 249.47 4.47 2040.24 28.97 298.65 1,970.11 345.69 N 210.07 W 259.01 3.50 2134.21 30.55 295.28 2,051.69 366.80 N 251.64 W 265.52 2.45 2230.79 32.20 291.54 2,134.15 386.74 N 297.78 W 269.43 2.64 2323.31 34.82 286.65 2,211.30 403.36 N 346.03 W 269.53 4.06 2421.48 38.39 285.23 2,290.10 419.41 N 402.32 W 266.48 3.74 2516.85 41.43 283.48 2,363.25 434.54 N 461.59 W 261.60 3.40 2607.79 45.83 283.41 2,429.05 449.13 N 522.60 W 255.63 4.84 2702.41 48.87 282.96 2,493.15 464.99 N 590.36 W 248.70 3.23 2753.16 52.41 283.63 2,525.33 474.02 N 628.53 W 244.87 7.05 INSITE V8.1.10 Page 1Job No:AK-XX-0901812451 Well Name:2M-36 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2796.75 53.90 282.80 2,551.47 481.99 N 662.49 W 241.41 3.74 2892.13 56.55 278.98 2,605.88 496.75 N 739.40 W 230.46 4.31 2985.78 58.27 278.81 2,656.32 508.95 N 817.36 W 216.75 1.84 3080.36 59.34 278.31 2,705.31 520.99 N 897.36 W 202.23 1.22 3174.51 59.40 276.62 2,753.28 531.51 N 977.68 W 186.17 1.55 3270.06 60.47 275.76 2,801.15 540.42 N 1,059.89 W 167.97 1.36 3424.27 61.17 277.15 2,876.34 555.57 N 1,193.67 W 138.96 0.91 3520.07 60.04 276.87 2,923.36 565.75 N 1,276.51 W 121.77 1.21 3613.34 60.17 276.52 2,969.85 575.18 N 1,356.82 W 104.67 0.35 3707.67 59.95 274.99 3,016.93 583.38 N 1,438.15 W 86.08 1.42 3802.22 60.28 271.05 3,064.05 587.69 N 1,519.99 W 63.65 3.63 3896.49 60.24 275.31 3,110.83 592.23 N 1,601.69 W 41.48 3.92 3991.21 60.15 274.67 3,157.91 599.38 N 1,683.56 W 21.73 0.59 4084.96 59.46 274.71 3,205.06 606.00 N 1,764.32 W 1.84 0.74 4179.37 58.02 274.98 3,254.05 612.82 N 1,844.74 W -17.76 1.54 4274.00 58.03 274.34 3,304.17 619.34 N 1,924.74 W -37.51 0.57 4368.13 58.37 273.92 3,353.77 625.10 N 2,004.53 W -57.91 0.52 4463.12 58.28 276.50 3,403.65 632.44 N 2,085.03 W -77.04 2.31 4557.40 57.67 281.18 3,453.67 644.71 N 2,163.98 W -91.00 4.26 4652.38 57.68 281.22 3,504.46 660.30 N 2,242.71 W -101.76 0.04 4746.36 56.95 281.53 3,555.21 675.89 N 2,320.26 W -112.12 0.82 4841.02 56.91 279.21 3,606.86 690.17 N 2,398.28 W -123.88 2.05 4935.41 57.16 277.37 3,658.23 701.59 N 2,476.64 W -138.46 1.66 5030.19 56.98 277.88 3,709.75 712.14 N 2,555.49 W -154.02 0.49 5123.88 57.16 279.40 3,760.69 723.96 N 2,633.23 W -168.02 1.38 5220.50 57.02 278.75 3,813.18 736.75 N 2,713.33 W -181.86 0.58 5315.07 56.67 276.72 3,864.91 747.41 N 2,791.77 W -197.19 1.83 5409.46 57.07 276.79 3,916.49 756.71 N 2,870.27 W -213.82 0.43 5502.89 57.51 278.55 3,966.98 767.20 N 2,948.17 W -229.13 1.65 5597.53 57.88 278.51 4,017.56 779.07 N 3,027.28 W -243.53 0.39 5692.74 57.65 278.55 4,068.35 791.01 N 3,106.92 W -258.02 0.24 5787.06 57.52 277.27 4,118.91 801.97 N 3,185.79 W -273.20 1.15 5882.36 58.02 275.80 4,169.74 811.14 N 3,265.88 W -290.47 1.41 5975.67 58.19 274.51 4,219.04 818.26 N 3,344.78 W -309.29 1.19 6070.59 57.93 275.44 4,269.26 825.24 N 3,425.02 W -328.67 0.88 6163.74 57.76 276.33 4,318.83 833.33 N 3,503.46 W -346.43 0.83 6259.40 57.68 277.62 4,369.92 843.15 N 3,583.74 W -363.15 1.14 6355.75 57.98 277.23 4,421.22 853.69 N 3,664.61 W -379.37 0.46 6448.76 57.97 276.35 4,470.54 863.01 N 3,742.91 W -395.91 0.80 6543.72 57.81 274.98 4,521.02 870.95 N 3,822.95 W -414.33 1.23 6638.29 57.79 275.13 4,571.42 878.00 N 3,902.66 W -433.48 0.14 6733.97 58.24 276.29 4,622.10 886.08 N 3,983.41 W -451.99 1.13 6829.05 57.75 278.26 4,672.49 896.28 N 4,063.39 W -468.24 1.83 6924.07 57.37 279.25 4,723.46 908.49 N 4,142.64 W -482.37 0.97 7018.49 57.20 279.04 4,774.49 921.11 N 4,221.08 W -495.83 0.26 INSITE V8.1.10 Page 2Job No:AK-XX-0901812451 Well Name:2M-36 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7113.16 57.26 279.81 4,825.74 934.15 N 4,299.60 W -508.93 0.69 7207.19 57.32 279.53 4,876.55 947.44 N 4,377.60 W -521.62 0.26 7303.81 57.39 279.86 4,928.67 961.14 N 4,457.79 W -534.64 0.30 7397.65 57.32 279.86 4,979.29 974.67 N 4,535.64 W -547.05 0.07 7494.11 57.35 279.00 5,031.35 987.97 N 4,615.75 W -560.41 0.75 7584.37 57.28 278.07 5,080.10 999.25 N 4,690.87 W -574.08 0.87 7682.29 56.83 277.39 5,133.35 1,010.30 N 4,772.30 W -590.00 0.74 7776.52 57.36 276.01 5,184.54 1,019.53 N 4,850.87 W -606.72 1.35 7873.41 57.14 276.99 5,236.96 1,028.75 N 4,931.83 W -624.22 0.88 7954.98 57.12 276.69 5,281.23 1,036.91 N 4,999.85 W -638.53 0.31 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 18.90 degrees (True) - A total correction of 18.90 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 7,954.98 feet is 5,106.24 feet along 281.72 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 3Job No:AK-XX-0901812451 Well Name:2M-36 PB1 Survey Report
