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214-151
• PTD 264-16- / Sylte, Hanna 2 8 8 5 1 From: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Sent: Tuesday, November 28, 2017 10:27 AM To: Sylte, Hanna Subject: [EXTERNAL]KRU 2L-308 (PTD 2141510) Sundry 315-120 Fracture Stimulation - Electronic Submission of Chemical Disclosure Required Hanna, A review of submitted 10-404 's (Report of Sundry Well Operations) is showing that we do not have an electronic submission as required by our regulations AOGCC regulations 20 AAC 25.283(i) states: (i) Before submitting a Report of Sundry Well Operations under(h) of this section,the operator shall (1) post information required by the Interstate Oil and Gas Compact Commission and the Ground Water Protection Council on the FracFocus Chemical Disclosure Registry,or its successor database, maintained on the Internet by those organizations; and (2)file a printed copy and electronic copy of that information, in a format acceptable to the commission and as an attachment with the Report of Sundry Well Operations. I have verified the information has been entered and is visible on the fracfocus.org website. Thank you. I do not see the required electronic copy of the Chemical Disclosure information with the 10-404?The electronic version can be a pdf of the fracfocus information, an excel spreadsheet or similar that details each chemical and CAS number used in the operation. Please provide a CD with the data or reply back with an explanation of how/when this electronic copy was transmitted to AOGCC? Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907) 276-7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. RECEIVED DEL 0 6 2017 SCANNED AOGCC RBDMS L ; 0 e 2017 ccccv:,ek, • • ConocoPhillips DECEIVE® JAN 142016 TRANSMITTAL AOGCC --M7f1PJfkgkgrigeM4;LA/07_ FROM: Sandra D. Lemke,ATO14-1412 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC R.U. Box 100360 333 W. 7th Ave. #100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: 2L-308 DATE: 01/12/2016 Transmitted: If Kuparuk River Unit, Alaska 12L-308 11 CD of final report w/log images i (redistribution to include gas chrom data missing from original distribution in February 2015) jl Halliburton Surface data Logging-End of well report for 2L-308; 02/13/2015; ; general information, daily summary, II days vs, depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one N set each for wellbore (a uff Formation log-CVE gas extraction-MD Gas ratio-CVE gas extraction-MD 2L" 30S Chyp fklatirrA- La S I Drilling dynamics-CVE gas extraction-MD l n 2✓-go6 ECD contains Final log files, End of well report,final LAS exports, log viewers Please promptly sign, scan and return electronically to Sandra.D.LemkeC�COP.com CC: 2L-308 transmittal folder, production well files, eSearch /p4/4:2 Receipt: A � . , Date: .two - - GI5-Technical Data Management 1 ConocoPhillips j Anchorage,Alaska j Ph;907.2656947 SCANNED JUN 0 3 2016 • RECENT OCT 232015 ConocoPh i I I i ps Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 28, 2015 soot' ate - ` sl Commissioner Cathy Foerster a L- 3 a3' Alaska Oil& Gas Commission 333 West 7t'Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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, -- /27C?Ad&V---- Martin Walters ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-316 50103203420000 2000900 13" N/A 13" N/A 5.95 9/25/2015 2N-333 50103205250000 2060250 19" N/A 19" N/A 5.1 9/25/2015 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 _ 9/25/2015 (,'2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COM ION 2 $ 8 5 1 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell rRug Perforations r PerforateOther Frac Treatment Alter Casing r Pull Tubing Ir Stimulate-Frac ' Waiver r Time Extension fl Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Row Exploratory r 214-151-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20694-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380052,380051,25603 KRU 2L-308 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 17095 feet Plugs(measured) none true vertical 5484 feet Junk(measured) none Effective Depth measured 17095 feet Packer(measured) 13499, 13611 true vertical 5484 feet (true vertical) 5326, 5357 Casing Length Size MD TVD Burst Collapse CONDUCTOR 92 16 120 120 SURFACE 2560 10.75 2599 2312 INTERMEDIATE 13725 7.625 13763 5399 LINER 3484 4.5 17095 5484 RECEIVED E APR 13 2015 Perforation depth: Measured depth: frac ports from 14139-17085 True Vertical Depth: 5465-5484 SCANNED DEC 1 5 2017 AOGCC Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 13625 MD, 5361 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER @ 13499 MD and 5326 ND PACKER-BAKER HRD-3 ZXP LINER TOP PACKER @ 13611 MD and 5357 TVD NIPPLE-CAMCO DS NIPPLE @ 525 MD and 525 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13870-17076 Treatment descriptions including volumes used and final pressure: pumped total 953740#of 60/40 sand 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run _ Exploratory r Development r Service 1 Stratigraphic 16.Well Status after work: Oil P Gas fl WDSPL ll Daily Report of Well Operations XXX GSTOR WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-120 Contact dam Klem Cad 263-4529 Email Adam.Klem c(D.conocophillips.com Printed Name Adam Kiem Title Sr. Completions Engineer Signature Phone:263-4529 Date Viv/e5. r— RBDMS4. APP 1 3 2015 ep tctitie01- (2,15'1.1q-- Form 2j. /.17'Form 10-404 Revised 10/2012 OD/-J I Z,/6/2.0. i 7 Submit Original Only i KUP PROD , 2L-308 ConocoPhillips a Well Attributes Max Angle&MD TD Al'Ska,Inc.. Wellbore API/UW1 Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cau.Slaaps 501032069400 TARN PARTICIPATING AREA PROD 17,095.0 "". Continent H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 21.-308.45/201512,50:17 PM SSSV:NIPPLE Last WO: 40.00 2/14/2015 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER'358 L Last Tag: Rev Reason: FRAC DATA hipshkf 4/5/2015 "II Casing Strings II .""-Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 13.940 40.0 150.0 150.0 65.00 A106 Casing Description -OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 39.0 2,599.4 2,312.2 45.50 L-80 TSH 563 _. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade -Top Thread INTERMEDIATE 75/8 6.875 37.9 13,762.8 5,398.9 29.70 L-80 Hydri1563 A.A., CONDUCTOR;40.0-150.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread LINER-51/2x41/2@ 41/2 3.958 13,611.1 17,095.0 5,484.4 12.60 L-80 IBTM J 13645.13 NIPPLE;525.4 ' ,. J Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1) Item Des Com (in) 13,611.1 5,356.7 73.87 PACKER BAKER HRD-3 ZXP LINER TOP PACKER 4.830 SURFACE;39.1-2.599.4 13,633.3 5,362.9 73.82 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.240 13,635.7 5,363.5 73.82 HANGER BAKER FLEX-LOCK LINER HANGER 4.850 GAS LIFT;3,100.3 13,645.1 5,366.2 73.80 XO Reducing 5.5"Hyd 563 box x 4.5"Hyd 521 pin Crossover 3.910 Coupling GAS LIFT;7.096.313,870.0 5,425.5 77.62 SWELL BAKER SWELL PACKER-G 3.958 PACKER M 14,139.4 5,465.1 83.37 FRAC PORT FRAC SLEEVE(2.063"BALL)#6 3.840 GAS LIFT;9.678.514,406.4 5,495.1 84.76 SWELL BAKER SWELL PACKER-F 3.958 PACKER 14,674.3 5,507.8 91.14 FRAC PORT FRAC SLEEVE(2.000"BALL)#5 3.840 GAS LIFT;11517.0 14,909.3 5,501.2 90.95 SWELL BAKER SWELL PACKER-E 3.958 PACKER GAS LIFT;12,897.5 • ; 15,147.6 5,501.6 90.42 FRAC PORT FRAC SLEEVE(1.938"BALL)#4 3.840 15,380.3 5,497.7 90.41 SWELL BAKER SWELL PACKER-D 3.958 PACKER 15,620.4 5,5012' 88.36 FRAC PORT FRAC SLEEVE(1.813"BALL)#3 3.840 SLEEVE;13,449.1 15,855.6 5,499.0 91.08 SWELL BAKER SWELL PACKER-C 3.958 PACKER GAUGE;13,473.4 16,097.1 5,499.9 89.51 FRAC PORT FRAC SLEEVE(1.688"BALL)#2 3.840 Ui PACKER;13.498.7 16,331.5 5,499.3 90.51 SWELL BAKER SWELL PACKER-B 3.958 PACKER 16,569.3 5,495.8 90.84 FRAC PORT FRAC SLEEVE(1.563"BALL)#1 3.840 NIPPLE;13588.9 16,804.9 5,492.1 91.51 SWELL BAKER SWELL PACKER-A 3.958 LOCATOR;15606.6 PACKER SUB;13,607.6 Tubing Strings r.. a Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(1b/ft) Grade Top Connection MULE SHOE;13,624.1 TUBING-41/2x3 31/2 2.992 35.8 13,625.1 5,360.6 9.30 L-80 EUE8rd 1,`. '� 1/2 @70.40 P "� °I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) e 35.8 35.8 0.00 HANGER CAMERON TUBING HANGER 3.900 70.4 70.4 0.11 XO Reducing Crossover 4 1/2"IBTM b x 3 1/2"EUE8rd p 2.992 INTERMEDIATE;37.9-13,7628 525.4 525.1 4.21 NIPPLE CAMCO DS NIPPLE 2.875 .�. - 13,449.1 5,311.4 73.34 SLEEVE BAKER CMU SLIDING SLEEVE-CLOSED POSITION 2.810 13,473.4 5,318.3 73.44 GAUGE SLB GAUGE CARRIER 2.913 13,498.7 5,325.5 73.63 PACKER BAKER PREMIER PACKER 2.880 PERFP;14,139.4-14,142.1 t t 13,588.9 5,350.6 73.91 NIPPLE CAMCO D NIPPLE 2.750 13,606.6 5,355.5 73.88'LOCATOR BAKER SHEAR FLUTED NO GO LOCATOR 3.000 13,607.6 5,355.7 73.87 SUB BAKER SHEAR LOCATOR SUB 3.000 13.624.1 5.360.3 73.84 MULE SHOE BAKER SHEAR TYPE WLEG 3.000 PERFP;14,674.3-14,677.0 I Perforations&Slots Sand Frac;13,870.0 Shot Dens • '�• ' Top(NO) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 14,139.4 14,142.1 5,465.1 5,465.5 2/11/2015 PERFP Frac Port PERFP;15,147.6-15.150.3 I 14,674.3 14,677.0 5,507.8 5,507.7 2/11/2015 PERFP Frac Port 15,147.6 15,150.3 5,501.6 5,501.6 2/11/2015 PERFP Frac Port .. . . . 15,620.4 15,623.2 5,501.2 5,501.3 2/11/2015 PERFP Frac Port 16,097.1 16,099.8 5,499.9 5,500.0 2/11/2015 PERFP Frac Port 16,569.0 16,572.0 5,495.8 5,495.7 2/11/2015 PERFP Frac Port PERFP;15,620.4-15623.2 17,075.5 17,085.3 5,484.4 5,484.4- 2/11/2015 PERFP Perforated Pup Stimulations&Treatments Min Top Max Stet Depth Depth Top(TVD) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com PERFP;16,097.0.16,099.8 i '1 15,855.6 17,075.5 5,499.0 5,484.4 Sand Frac 3/22/2015 Pumped 376,155#of 16/20 frac sand into first 3 t stages @ 20 bpm. 13,870.0 15,855.6 5,425.5 5,499.0 Sand Frac 3/24/2015 Pumped 577,585@ of 60/40 frac sand in 1-8 ppa concentrations in last 4 stages. Mandrel Inserts Sand Frac;15,855.6 St ati PERFP;16569.0.16572.0 t N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com f 3,100.3 2,503.3 CAMCO •KBMG 1 GAS LIFT GLV BK 0.188 1,626.0 3/30/2015 _ 2 7,096.3 3,597.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/13/2015 3 9,678.5 4,303.6 CAMCO •KBMG 1 GAS LIFT DMY BK 0.000 0.0 3/15/2015 DCK-2 PERFP;17,075.577,085.3 4 11,517.0' 4,804.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 2/13/2015 LINER-512 x41/26 13645.13;15611.1-17,0950 KUP PROD • 2L-308 ConocoPhillips Ai;1;ka.i;1;:., -•- 2L-308,4/5/201512:50:18 PM Vertical schematic(actual) HANGER, HA ;3 35.8- 8•iE_•P-u1 r:13- Mandrel Inserts Top(ND)I Valve Latch Port Size TRO Run N Top(ftKB) (565) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com IOtt= 5 12,897.5 5,174.2 CAMCO KBMG 1 GAS LIFT OV BK 0.313 0.0 3/30/20)5 Notes:General&Safety .A.A1 CONDUCTOR;40,0-150.0 i.,, End Date Annotation NOTE NIPPLE;525.4 I c t SURFACE;39.1-2,599.4 GAS LIFT;3,100.3 GAS LIFT;7,096.3 GAS LIFT,9,678.5 GAS LIFT;11517.0 GAS LIFT;12.897.5 1 SLEEVE;13,449.1- GAUGE;13,473.4 in PACKER;13,498.7 -. - NIPPLE;13,588.9 1, LOCATOR;13,606.6 SUB;13,607.6 E I• ,- MULE SHOE;13,624.1 ,'Or- , INTERMEDIATE;37.9-13,762.8 - PERFP 14,139.4-14,142.1 PERFP;14,674.3-14.677.0 Send Frac;13,870.0 PERFP;15.147.6-15.150.3 PERFP;15,620,4-15,623.2 PERFP;16,097.0-16,099.8 Sand Frac;15.8556 PERFP;16,569,0-16,572,0 PERFP;17,075.5-17.0853, LINER-5120412® 13645,13;13,611,1-17095.01 �2L-308 FRAC SUMMARY • DATE SUMMARY 3/13/2015 WEATHER& MECHANICAL DELAYED START. UNABLE TO OPEN WELLHOUSE ROOF DOORS DUE TO SCAFFOLDING ERECTED FOR FRAC. IN PROGRESS. 3/14/2015 DELAYED START DUE TO SPINE ROAD CLOSURE. SET BAITED 2" RS ON BALL& ROD @ 13,537' SLM. IN PROGRESS. 3/15/2015 PULLED SOV @ 9678' RKB, PUMPED 9 BBLS DIESEL TO FLUID PACK TBG/IA. SET DV @ 9678' RKB. MIT IA TO 3500 PSI, PASSED. MIT TBG TO 4000 PSI, PASSED. PULLED CATCHER ASSY'AND BALL n' ROD @ 13,540'SLM. IN PROGRESS. 3/16/2015 PULLED RHC @ 13,589' RKB. MEASURED BHP @ 14,061' RKB: MAX PSI 2840. WORKED 3.905" CENT TO 6'SLM, THEN DRIFTED WITH SAME. READY FOR FRAC. 3/22/2015 Performed fracture stimulation treatment @ 20 bpm placing 376,155#of 16/20 frac sand into the first 3 stages. Well freeze protected w/ 17 bbl's of diesel. Reload S/W and Sand for next 4 stages. 3/24/2015 Performed last 4 last stages of fracture treatment thru ball-drop actuated sleeves @ 15,620', 15,147', 14,674', & 14,139' placing 577,585# total of 60/40 frac sand in 1-8 ppa concentrations. Well freeze protected w/21 bbls diesel. Note: Will attach copy of SLB treatment when available. 3/26/2015 RIH WITH MOTOR&MILL, ENCOUNTERED FIRST FRAC SAND AT 8000'CTMD, FCO DOWN TO FIRST FRAC SLEEVE AT 14,139' RKB, UNABLE TO STALL MOTOR ON FIRST SLEEVE, HEAVY UP WEIGHTS PUH. AT 7890'CTMD WE PULLED 28K AND THE WEIGHT DROPPED BACK OFF TO 10K, POOH TO INSPECT BHA. FOUND 6K PSI BURST DISC WAS RUPTURED. RAN 2.63" OD VENTURI TO 14115'CTMD, LIGHT TAG, POOH WITH VENTURI 3/27/2015 VENTURI RUN YIELDED APPROX 1 GAL OF FRAC SAND WITH COIL SHAVINGS AND SMALL PCS OF METAL. 2ND MILLING RUN; UNABLE TO GET ANY MOTOR WORK. PULLED TO CHECK BHA, FOUND THE MOTOR WAS NOT WORKING, CUT 50'OF COIL, CHANGE PACKOFFS &CHAIN INSPECTION. 3RD MILLING RUN; MILLED THROUGH SLEEVES 1, 2, AND 3, PUMPED GEL SWEEPS. MADE 3 BACK REAM PASSES AND DRY DRIFTED EACH SLEEVE. MADE SHORT TRIP TO 9957' CTMD, PUMPED GEL SWEEP. ATTEMPT TO MILL SLEEVE 4, UNABLE TO SEE MOTOR WORK OR GET A STALL. POOH TO CHECK BHA. 3/28/2015 INSPECTED BHA#4, FOUND 5K RUPTURE DISC WAS BURST, MOTOR WON'T TURN, FRAC SAND INSIDE THE MOTOR. RIH WITH NEW MOTOR AND MILL TO COMPLETE MILLING OF FINAL 3 FRAC SLEEVES, MADE 3 REAMING PASSES AND A DRY DRIFT ON EACH, FCO AS DEEP AS POSSIBLE TO 16,800' CTMD, CHASE FINAL GEL OOH AT 70%, F/P TO 16,800', READY FOR S/L, JOB IN PROGRESS. 3/29/2015 DRIFTED TBG TO 13940' SLM (80+ DEG DEVIATION)WITH 2-1/2" BAILER; RECOVERED FRAC SAND. MEASURED BHP @ 13930' SLM: 2523 PSI. SET 2.75" SV @ 13588' RKB. PULLED DV @ 12897' RKB. DISPLACE IA WITH 400 BBL DSL. IN PROGRESS. CREW CHANGE WITH UNIT 142. 3/30/2015 FINISH LOADING IA WITH 392 BBL DSL. SET OV @ 12898' RKB. PULLED DV&SET GLV @ 3100' RKB. MIT TBG 3000 PSI, GOOD. PULLED 2.75 SV @ 13588' RKB. COMPLETE. • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cal_ 4.. - 4 S 1 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: Color Items: ❑ Maps: /ayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: rviPBY: Maria Date: ' 1 7/15' /s/ Project Proofing BY: digSP Date: i,: .../ 7/15-- /s/ Kr Scanning Preparation (0 x 30 = I go + 1 7 = TOTAL PAGES 1 / 7 (Count does not include cover sheet) BY: 1210 Date: �.5 /s/ u Production Scanning Stage 1 Page Count from Scanned File: 115 (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: 1P Date: // /S' /s/ F(V1f Stage 1 If NO in stage 1, page(s) discrepancies were ound: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 41; NO TOTAL PAGES55 Digital version appended by: Meredit Michal Date: 12.( ((t, /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: a53 Scanning is complete at this point unless rescanning is required. 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Guhl, Meredith D (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Tuesday, October 06, 2015 4:21 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2L-308, PTD 214-151, Complete List of Geologic Markers Required Hi Meredith, Here are additional formation tops I was able to find. 10-407 Geologic Markers in 2L-308 Name MD TVD C-80 3,081 2,498' Campanian Sand 3,317 2,559' C50 8,122 3,880 C40 9,454 4,242 C-37 10,335 4,483' Iceberg 10,551 4,542' Top Berm Target 13,813 5,412' Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, October 06, 2015 4:00 PM To: Bearden, J Daniel Cc: Bettis, Patricia K(DOA) Subject: [EXTERNAL]KRU 2L-308, PTD 214-151, Complete List of Geologic Markers Required Daniel, During a review of the 10-407 form submitted for KRU 2L-308, PTD 214-151,completed 2/15/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Campanian and the Top Bermuda are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 13, 2015. If you have any questions, please contact me. • i Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 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.guhlPalaska.gov. 2 a Ilk ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 9/28/2015 2N&2L PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-336 50103206930000 2141440 Surface N/A 8" N/A 3.4 9/25/2015 2L-308 50103206940000 2141510 35" 0.10 16" 9/11/2015 4.25 9/25/2015 2L-314 50103206860000 2140230 24" 0.20 15" 9/11/2015 4.25 9/25/2015 2L-316 50103207040000 2150060 Surface NA 15" NA 3.4 9/25/2015 2L-328 50103206980000 2141890 12" NA 12" NA 4.25 9/25/2015 RECEIVED • STATE OF ALASKA 1110 MAR 11 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. 1tc(; la.Well Status: Oil O . Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development O • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: 'February 15,2015 214-151 / 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 •January 10,2015 50-103-20694-00-Do ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 161'FNL,617'FEL,Sec.22,T1ON, R7E, UM •February 8,2015 KRU 2L-308 Top of Productive Horizon: 8. KB(ft above MSL): 155'RKB 15.Field/Pool(s): 2499'FSL,68'FEL,Sec. 13,T1ON,R7E, UM GL(ft above MSL): 115'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 287'FNL, 1231'FWL,Sec. 19,T1 ON,R8E, UM 17095'MD/5484'TVD Tarn Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-461034 y- 5927685 Zone-4 •17095'MD/5484'TVD ADL 380052,380051,25603 • TPI: x-472152 y- 5930295 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-473440 y- 5927505 Zone-4 nipple @ 525'MD/525'TVD 4602 18.Directional Survey: Yes ❑ • No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1425'MD/1400'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, Neutron, Porosity • not applicable 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 164.8# A-106-B 40' 120' 40' 120' 20" no cement,driven 10.75" 45.5# L-80 39' 2599' 39' 2312' 13.5" 1165 sx LiteCRETE,205 sx LiteCRETE 7.625" 29.7# L-80 37.7' 13324' 37.7' 5274' 9.875" 1017 sx Class G 7.625" 39# TN110SS 13324' 13763' 5274' 5399' 9.875" included above 4.5" 12.6# L-80 13611' 17095' 5355' 5484' 6.5" swell packers and frac sleeve 24.Open to production or injection? Yes a No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 13625' 13499'MD/5326'TVD and pert pup from 17078'-17082'MD 5484-5484'TVD 13611'MD/5357'TVD ----PLEPy( - 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No❑ Z(1_d115' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED jnone J„ 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on post-rig well work Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407}2eyised 10/2012v7„L q/ �,ij _ , REVERSTcBpMs3k APR 1 0 20 f'bmit original only 29. GEOLOGIC MARKERS(List all formations and mar•ncountered): 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 1425' 1400' needed,and submit detailed test information per 20 AAC 25.071. Campanian 3317' 2559' Top Bermuda 13813' 5412' N/A Formation at total depth: Bermuda 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,directional survey, cement detail reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Bearden @ 263-4864 E ail: J.Daniel.Beardenconocophillips.com Printed Name G. L.Alvordr j Alaska Drilling Manager Signature ( �a_r-- hone 265-6120 Date 3 5 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • • Guhl, Meredith D (DOA) From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Tuesday, October 06, 2015 4:21 PM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2L-308, PTD 214-151, Complete List of Geologic Markers Required Hi Meredith, Here are additional formation tops I was able to find. 10-407 Geologic Markers in 2L-308 Name MD TVD C-80 3,081 2,498' Campanian Sand 3,317 2,559' C50 8,122 3,880 C40 9,454 4,242 C-37 10,335 4,483' Iceberg 10,551 4,542' Top Berm Target 13,813 5,412' Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, October 06, 2015 4:00 PM To: Bearden, J Daniel Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2L-308, PTD 214-151, Complete List of Geologic Markers Required Daniel, During a review of the 10-407 form submitted for KRU 2L-308, PTD 214-151, completed 2/15/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Campanian and the Top Bermuda are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 13, 2015. If you have any questions, please contact me. 1 Thank you, • • Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, 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 2L-308 Bertha �' AS-BUILT Wellbore Schematic Grass Roots Topset•arn Hole Horizontal Multi-Stacie Frac'd ProducerOnOCOPhil'i CAMERON 4-1/2"tree,top joint is 4-'W 12.6#IBTM,crossed over(for frac equipment) Bearden 2/14/2015 Conductor: 16" 165#Heavy Wall 3 W Camco DS Nipple 2.875" 500'MD/500'TVD .. / DrillPlex / 13-1/2"Surface Hole 9.6 PPG 3%"x1"Ca mco KBMG ////// / ,- Surface Casing: / 10-3/4"45.5#L-80 Hydril 563 2,599' MD/2,313'TVD @ 630 3%"x 1"Camco KBMGari Campanrari,Top 3.31':9.MD.(2560`1tvr ..'. LSND 9.6-10.0 PPG 3%"x1"Cameo KBMG Tubing: Keep up with 3-'/2"9.3#L-80 EUE8RD Dilution 4-'/2" 12.6#L-80 IBTM top joint to surface 9-7/8" Intermediate Hole 3%"x 1"Camco KBMG /� ! Top of cement @ 9,530'MD (per SLB Sonic 2/4/2015) 3%"x1"Camco KBMG �f / Iceberg Top.10 551 MD(4542 TVD) � 2.812"Cam olCMU idDS'Profile 0'aboving Sleeve CLOSEe w/ g g ii Down hole au a 13,473'MD production packer -/ 3.5"x 7-5/8",Baker Premier Packer 13,498'MD /x / 7-5/8",ZXP Liner Top Packer 13,611'MD 3%"Camco D nipple nogo 2.75 • L( / 7-5/8"x 4-W Baker Flex Lock Liner hanger w/RS Nipple, 13,635'MD Intermediate Casing Topset: 7-5/8"29.7#L-80&300'TN110SS 39#—all qsat Hydril 563 connections -'Top of Bermuda 13,812MD(5,412'TVD) 13.76 '.1' P?5.399'TV_D 0,7. .`'......5 7 RaKet Il pkets 'ss 11 .; 8:1 .:.:Pradlctoti:kivil a: : K18.hi0ld 30 # Pr: O O �.O...� � I O O O B.g00Ut" si3r8 s! i mHiH:ii......9. .pp 5 ; ii ,HHHii: mHHHiH.: H :i::iHi Hi HiHProduction Liner @ 900: 4-1/2" 12.6#L-80 IBTM (w/torque rings to rotate in liner to TD) 13,583' MD to 17,095' MD Perf'd pup joint for 5,359'TVD to 5,500'TVD circulation • • .. .. ConocoPhillips Time Log & Summary We/!view Web Reporting Report Well Name: 2L-308 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 1/9/2015 12:00:00 AM Rig Release: 2/15/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/06/2015 24 hr Summary Move Pits, Pump and Power modules to 2L pad. Move pipe shed away from sub and stage for move. Move sub off well and stage to allow pipe shed past. 00:00 07:00 7.00 0 0 MIRU MOVE MOB P Stage Casing, Power and pump module via stompers to move. Move pump and power modules to 2L pad. Prep rig floor, roog, and BOP deck for skidding floor. Pin and raise cellar for move, skid rig floor and lower derrick. 07:00 12:00 5.00 0 0 MIRU MOVE MOB P Walk Pit module from sub and move to 2L pad(10:30)and stage modules on pad. Remove snow and mats to stage pipe shed. Move sub off well via stompers, Move sub off well using stompers due uneven pad; unable to move with truck or cat. Prep location for rig arrival. Crew change. 12:00 17:00 5.00 0 0 MIRU MOVE MOB P Continue to walk casing shed and pipe shed away from sub and haul pipe shed to 2L. Attempt to move sub with truck and cat without success. remove jeep. PU handyBerm and herculite. 17:00 00:00 7.00 0 0 MIRU MOVE MOB P Replace pin on jeep and swap Hydrill with crane. Stomp sub into position to allow pipeshed to pass. Wait on change outs for DSO and 9ES crews. Crew change. 31/07/2015 Move pipe shed, casing shed to 2L and move drilling sub to 2L. Spot sub over well and move in other modules and prep location. 00:00 08:00 8.00 0 0 MIRU MOVE MOB P Move pipe shed and casing shed to 2L pad and stage. Move sub to 2L 08:00. 08:00 12:00 4.00 0 MIRU MOVE MOB P Move Sub to 2L pad. Finish laying mats on location and stage sub on mats. Place herculite on cellar area and start walking sub. Move mats and equipment and supplies from 2M to 2L. Move shop cold start to 2L. Crew change. 12:00 15:00 3.00 MIRU MOVE MOB P Spot and level sub, place herculite for casing and pipe shed. 15:00 17:00 2.00 MIRU MOVE MOB P Spot pipe shed and align with sub. Page 1 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:00 3.00 MIRU MOVE MOB P Raise sub and walk pipe shed under to position. Set mats and back pit module into place. Blew stomper hose, replace same. 20:00 00:00 4.00 MIRU MOVE MOB P Continue to walk pipe shed and pin to sub. continue to place mats for other modules. Crew change. 01/08/2015 Continue to spot modules around sub and assemble and hook up interconnects. Warm rig and Scope derrick. Load and process 10 3/4"casing and shoe track. Energize wellhead dual seals and test; Good. RU surface bag. Accept rig at 1/9/2015 00:00 00:00 06:00 6.00 MIRU MOVE MOB P Continue to set mats and position modules. Shim front of pipe shed, stage casing shed on mats with trucks. Stomper pipe shed and shim, raise and pin derrick, skid floor to well centerline. Raise cattle chute, lower C-section,walk pits into sub,shim and attach lines and interconnects. 06:00 12:00 6.00 MIRU MOVE MOB P Hook up electrical interconnects and change out stomper#2, crib and secure cellar,walk pump module into pit complex,walk power unit to pump unit. hook up interconnect and supply steam to rig. Swap rig from cold starts to rig generators. Move control panel on adjacent well and align diverter line for clearance as per CPAI rep. Crew change. 12:00 16:00 4.00 MIRU MOVE RURD P Continue with RU of interconnect lines in pump and pit modules. Continue to chain steam around to rig modules. Prep pits to take on fluids. Inspect derrick for scoping procedure. Unpin topdrive and blocks. Pin bridle yokes for scoping. Scope derrick. RD from scoping. Work stoppage for injury. 16:00 16:30 0.50 MIRU MOVE SFTY P Safety stand down for injury during rigging down bridle yoke. Discussion of incident and discussion of mitigation and hazard assessment before, during and after job execution. Stress on communication and hand placement during all operations. 16:30 18:00 1.50 MIRU MOVE RURD P Install 4"dummy valves on well head and continue to RU cellar. Spot Mudlogger shack. Page2of52 Time Logs I • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 MIRU MOVE RURD P Install rubber wear pad for Kelly hose and girt, install air heater on 20" conductor starting head. Load 10 3/4"casing in shed, Cameron Rep energized well head dual seals. PU 17"surface riser,take on load of Spud mud at 23:00. 01/09/2015 Continue to RU surface bag and RU riser. Process 10 3/4"casing in shed. Move equipment from 2M. Stage BHA and tools in pipe shed. Take mud into pits. Derrick inspection; Good. service crown and assemble Kelly hose for TD. Assemble diverter line, function test bag and knife valve; Good. Perform Diverter test witnessed by Johnnie Hill AOGCC rep. PU 5"drill pipe. 00:00 02:00 2.00 MIRU MOVE RURD P Accept rig at 1/9/2015 00:00 PU surface bag, stage diverter, clean and clear of snow and check for debris. Hook up Mud Logger shack to power to warm and finish RU. Crew change. 02:00 06:00 4.00 MIRU MOVE NUND P Continue to rig up bag,torque bolts and install riser. Strap and drift casing in shed. NU bell guide flange atop bag, install flow line and Joe's box,Torque all bolts from cellar up. Service crown and perform derrick inspection. MU kelly hose and install safety cables for top drive. 06:00 14:00 8.00 MIRU MOVE NUND P Modify pinser nipple, CO saver sub to 4 1/2"IF, install backer rod and secure Joe's box, Install jet and hole fill lines, install pinser nipple. NU diverter line with 87'from nearest ignition source. PU 5" DP doubles, RIH and tag at 42'. Crew change. 14:00 17:30 3.50 MIRU MOVE RURD P Energize Koomey and fuction test bag and knife valve: Good. Clean and clear floor. Continue to assemble diverter line. Mudlogger shack up and tested. 17:30 19:30 2.00 MIRU MOVE WASH P PU and MU 13 1/2"bit and clean out ice plug from 42'to 62'then RIH to insure enough hole to PU and MU stands from doubles. LD same and blow down top drive. 19:30 21:30 2.00 MIRU MOVE PULD P PU and MU stands from shed, tag bottom at 98'. 21:30 22:30 1.00 MIRU MOVE BOPE P Empty stack and conduct Diverter test. Test witnessed by AOGCC rep Johnnie Hill. Annular closing time= 36 sec. Knife valve open time=17 sec. Koomey Drawdown test; IP= 3000 psi, after function=2400 psi. 200 psi recovery=9 sec, Full recovery=29 sec. 3060 psi 6 bottle average. 22:30 23:00 0.50 MIRU MOVE BOPE P Test all gas alarms per AOGCC rep.; Good. Page 3 of 52 J Time Logs 1110 . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 MIRU MOVE PULD P Continue to PU and MU stands from doubles and stands back in derrick. 01/10/2015 PU DP and HWDP. PU Clean Out BHA#1. Hold Pre-Spud meeting. Drill to 220', POOH and PU Drilling assembly and directional drill ahead to 492'. 00:00 02:00 2.00 MIRU MOVE PULD P Continue to PU drill pipe and HWDP and stand back. Crew change. 02:00 04:00 2.00 0 35 MIRU MOVE PULD P Continue to PU HWDP and stand in derrick. PU Motor and put in rotary table, secure and call for meeting. 04:00 04:30 0.50 35 35 MIRU MOVE SFTY P Hold Pre-Spud meeting; Discuss Bertha well with emphasis on the surface section and the hazards we might encounter. Discussed safety and planning as our tools to complete this well moving forward. 04:30 05:45 1.25 35 98 MIRU MOVE PULD P MU Clean Out BHA as per DD and MWD. 05:45 06:00 0.25 98 98 MIRU MOVE RURD P Fill, check for leaks and test all lines to 3500 psi; Good. 06:00 08:30 2.50 98 220 SURFA( DRILL DDRL P Drill 13 1/2"surface hole with straight motor to make hole for drilling BHA to 220'. 500 GPM with 550 psi,60 RPM with 2K torque and 4K WOB. PU=46K, SO=53K, Rot=52K. ART,ADT, Ttl bit=0.75 hours. 08:30 09:00 0.50 220 35 SURFA( DRILL TRIP P POOH from 220'to motor, 35'. 09:00 12:00 3.00 35 120 SURFA( DRILL PULD P Check bit; good and MU BHA#2 as per DD and MWD. Adjust motor bend from 0 to 1.5°bend. Scribe BHA and RIH to 120'. Hold Pre-Spud meeting with on-coming crew with pertinent discussions. Crew change. Losses for tour=0 BBL 12:00 12:30 0.50 120 12 SURFA( DRILL SRVY P Kelly up and perform Gyro surveys at 120'. 12:30 13:30 1.00 120 220 SURFA( DRILL TRIP P Trip in the hole from 120'to 220'. 13:30 14:00 0.50 220 220 SURFA( DRILL SRVY P Kelly up and perform Gyro surveys at 220'. 14:00 15:30 1.50 220 322 SURFA( DRILL DDRL P Drill ahead steering to kick off well and build inclination and obtain direction. Drill from 220'to 322'at 420 GPM with 320 psi, 70 RPM with 1K torque and 12K WOB. PU=70K, SO=70K, Rot=68K. 15:30 16:00 0.50 322 305 SURFA( DRILL TRIP P POOH 322'to 305',to swap power to High Line. 16:00 16:15 0.25 305 305 SURFA( DRILL OTHR P Swap rig to High Line power Page 4of52 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 20:15 4.00 305 305 SURFA( DRILL RGRP T Trouble shoot mud pump#1 inability to pump DrilPlex mud. Clean screens and pods of all debris restrictions. Combination of the thickness of the mud and the debris restrictions would not let the pumps achieve prime and operate properly. 20:15 20:45 0.50 305 305 SURFA( DRILL SVRG P Grease and service top drive. 20:45 21:30 0.75 305 305 SURFA( DRILL SRVY P Obtain Gyro surveys at 305'. 21:30 00:00 2.50 305 492 SURFA( DRILL DDRL P Run to bottom and drill ahead from 322'to 492'at 500 GPM with 620 psi,60 RPM with 2K torque and 12K WOB. PU=83K, SO=70K, Rot= 68K. AST=0.71,ART= 1.0,ADT= 1.71, Ttl bit hours=2.46. Crew change. Losses for tour=75 BBL 31/11/2015 Drilling ahead from 492'to 2122', building inclination and steering to plan. Peak gas drilling through hydrates 6391 units at 1399'. 00:00 06:00 6.00 492 869 SURFA( DRILL DDRL P Drill from 492' to 817'at 450 GPM with 950 psi, 60 RPM with 4K torque and 20K WOB. Poff=700 psi, PU= 82K, SO=95K, Rot=78K. 06:00 12:00 6.00 869 1,203 SURFA( DRILL DDRL P Drill from 869'to 1203'at 450 GPM with 950 psi, 60 RPM with 6K torque and 25K WOB. Poff=780 psi, PU= 88K, SO=97K, Rot=92K. AST=4.57, ART= 1.47,ADT=6.04,Ttl bit hours=8.5,Jars=8.5 hours. Crew change. Losses for tour=66 BBL, Ttl loss= 141 BBL 12:00 18:00 6.00 1,203 1,719 SURFA( DRILL DDRL P Drill from 1203'to 1719'at 650 GPM with 1488 psi, 60 RPM with 5K torque and 20K WOB. Poff= 1280 psi, PU=98K, SO= 106K, Rot= 101K. AST= 1.78,ART= 1.67,ADT= 3.54, Ttl bit hours= 11.95, Jars= 11.95 hours. 18:00 00:00 6.00 1,719 2,122 SURFA( DRILL DDRL P Drill from 1719'to 2122'at 650 GPM with 1575 psi, 60 RPM with 5K torque and 28K WOB. Poff= 1375 psi, PU= 105K, SO= 108K, Rot= 104K. AST=2.65,ART=0.83,ADT= 3.39, Ttl bit hours= 15.29,Jars= 15.29 hours. Crew change. Losses for tour=47 BBL, Ttl loss= 187 BBL Page 6 of 52 Time Logs 410 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11 01/12/2015 24 hr Summary Drill ahead to drill to 2609', 2322'TVD, CBU and check sample per Geologist and called TD. CBU X3, BROOH to 290'while obtaining delineation surveys for JORPS. 00:00 07:00 7.00 2,122 2,609 SURFA( DRILL DDRL P Drill from 2122'to 2609'MD/2322' TVD'at 650 GPM with 1640 psi,60 RPM with 7K torque and 24K WOB, Poff= 1375 psi and ECD= 10.87 ppg. PU= 108K, SO= 107K, Rot= 109K. AST=2.55,ART= 1.94,ADT=4.49, Ttl bit hours= 19.78,Jars= 19.78 hours. 07:00 10:00 3.00 2,609 2,380 SURFA( CASING CIRC P CBU for GEO to check sample wit Rot and Recip from 2609'to 2565'at 650 GPM with 1420 psi, 54%FO, 60 RPM with 4K torque. TD confirmed by Geo, continue to CBU and with each BU rack a stand back in the derrick 10:00 10:30 0.50 2,380 2,380 SURFA( CASING OWFF P Observe well for flow; Static. Blow down top drive. 10:30 11:00 0.50 2,380 2,380 SURFA( CASING SVRG P Service rig and grease blocks and top drive. 11:00 12:00 1.00 2,380 2,380 SURFA( CASING RGRP T PJSM, change out IBOP as it had washed out and saver sub. Normal wear and tear. Crew change. Losses this tour=0 BBL,Ttl losses= 187 BBL 12:00 12:30 0.50 2,380 2,380 SURFA( CASING RGRP T Install and secure all safety wire and bolts on the SS and IBOP upper and lower. 12:30 18:00 5.50 2,380 1,500 SURFA( CASING REAM P Back-ream from 2380'to 1500'at 650 GPM with 1375 psi, 55%FO, 60 RPM with 3.5K torque. PU= 107K, SO= 105K, Rot= 103K. Perform delineation surveys at2521', 1953', and 1859'. 18:00 00:00 6.00 1,500 212 SURFA( CASING REAM P Back-ream from 1500'to 212'at 400 GPM with 630 to 390 psi,40% FO, 60 RPM with 3K torque. PU=95K, S0=93K, Rot=93K. Perform delineation surveys at 1156'and 821'. Crew change. Losses this tour=0 BBL,Ttl losses= 187 BBL 01/13/2015 POOH to BHA and LD. Make dummy run with hanger; Good. RU to run casing. 00:00 00:15 0.25 307 212 SURFA( CASING REAM P Continue to BROOH to 307'to 212' at 400 GPM with 380 psi,40%FO, 60 RPM with 3K torque, 00:15 03:00 2.75 212 0 SURFA( CASING PULD P Blow down top drive. LD BHA#2 per DD and MWD. POOH with drill collars and stand back in derrick and LD BHA. Page 6 of 52 Time Logs 110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:00 1.00 0 0 SURFA( CASING RURD P PU and MU landing joint to hanger. Thaw out 4"cellar dump valve and drain stack. Perform dummy run with hanger, landing at 39'. LD landing joint. Clean and clear floor. 04:00 07:00 3.00 0 0 SURFA( CASING RURD P RU casing equipment; RD medium bales,and change out link tilt clamps to long bales and install on top drive,MU Volant CRT to top drive, stage bow spring centralizers to rig floor and verify casing count and running order in the pipe shed. 07:00 07:30 0.50 0 0 SURFA( CASING SFTY P PJSM for running surface casing with crew,Tenaris rep, and GBR. 07:30 12:00 4.50 0 1,009 SURFA( CEMEN"PUTB P Run 10 3/4"45.5#L-80 Hyd 563 Surface casing per detail to 1009', torque connections to 18,600 ft/lb. Fill pipe on the fly and topping off every 10 joints. Crew change. 12:00 17:00 5.00 1,009 2,557 SURFA( CEMEN-PUTB P Run 10 3/4"45.5#L-80 Hyd 563 Surface casing per detail from 1009' to 2477',torque connections to 18,600 ft/lb. Unsuccessful MU on joint#60. LD joints#59 and#60. MU joints#65 and#66,then joint# 61 and RIH to 2557'(Total of 64 joints were run). 40 BBL loss while running casing. 17:00 17:30 0.50 2,557 2,599 SURFA( CEMEN-HOSO P PU and MU Cameron casing hanger to landing joint. RIH and land at 2599', set on landing ring. PU= 144K, SO= 106K. 17:30 18:15 0.75 2,599 2,574 SURFA( CEMEN'CIRC P Stage pumps to 4 BPM ICP=118 psi, FCP= 163 psi, 26%FO, making 25' strokes at 10 Strokes per hour. Total pump strokes= 1723. 18:15 18:30 0.25 2,574 2,599 SURFA( CEMEN RURD P Blow down top drive and RU cement lines. 18:30 00:00 5.50 2,599 2,599 SURFA( CEMEN CIRC P Circulate and condition mud; stage pumps from 4 BPM to 8 BPM at 300 psi with 25%FO, making 25'strokes at 10 Strokes per hour. Circulate and condition mud from; MW=9.9, pH= 10.6, PV= 17,YP= 35, 10s=39, 10m=49. to final circulations; MW=10.0, pH=10.3, PV=17,YP= 11, 10s=10, 10m=29. Crew change. Losses 24 hours=40 BBL Total losses=227 BBL X1/14/2015 Perform cement job with 125 BBL losses and 40.4 BBLS cement back to surface. Bump and test plug; Good. CIP 05:30, TOC at 5.125'below starting head with 4"outlets 2.5'below. ND diverter and NU stack. Page 7 of 52 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 2,599 2,599 SURFA( CEMEN-CIRC P Circulate and condition mud; stage pumps 9 BPM at 380 psi with 25% FO, making 25'strokes at 10 Strokes per hour. 00:30 01:30 1.00 2,599 2,599 SURFA( CEMEN-CIRCP Circulate and condition mud;stage pumps 8 BPM at 300 psi with 25% FO,making 25'strokes at 10 Strokes per hour,while trucks and pits ready for cement job. Note:2638 BBL circulated after casing was on bottom.2104 BBL was pumped @ 8 BPM. 01:30 02:00 0.50 2,599 2,599 SURFA( CEMEN-RURD P RU and check all lines for cement job. Replace seal in Demco valve on manifold. Dowell pump 10 BBL water to test cement lines to 3500 psi; Good. 02:00 02:30 0.50 2,599 2,599 SURFA( CEMEN"CMNT P Dowell pumps Mud push II, 10.5 ppg with red dye. Pump 98.5 BBL at 5.45 BPM with 140 psi averages. PU wt 144K, SO wt 120K 02:30 03:45 1.25 2,599 2,599 SURFA( CEMEN CMNT P Dowell pumps Lead cement 398.7 BBL, 11.0 ppg 1.92 cuft/sx yield at 7 BPM with ICP=288 psi,Average= 305 psi and FCP=440 psi. At 80 BBL away; PU=147K, S0= 120K. With 250 BBL away Lead reached the shoe with 127 psi and pressure spike was seen as the bottom plug reached and opened at the shoe. At 290 BBL away the red dye in the Mud Push II was seen at the shakers. This was—20 BBL early when compared to calculated gauge hole. PU= 133K, S0=85K with last foot to hanger S0=57K. Decision to leave on the hanger and finish pumping cement. 03:45 04:00 0.25 2,599 2,599 SURFA( CEMEN CMNT P Dowell pumps Tail cement 60.7 BBL, 12.0 ppg 1.66 cuft/sx yield at 7 BPM with 295 psi average. 04:00 04:15 0.25 2,599 2,599 SURFA( CEMEN-CMNT P Drop top plug and kick out with 10 BBL water pumped by Dowell with a peak pressure of 568 psi and 8 BPM rate and returns were lost. Note:At the time of losses, mud push with red dye was still returning from the hole. Returns with slightly higher PH than mud push. �.,_ � Page 8 of 62 Time Logs 4111 J Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:15 05:30 1.25 2,599 2,599 SURFA( CEMEN-CMNT P Switched to rig pumps and chased plug with 9.8 ppg Drilplex mud at 7 BPM,staging down to 4 BPM with no returns. At100 BBL away returns were diverted to the(2)cellar 4" valves in an attempt to regain returns without success. Flow path for returns was switched from the pits to the cellar and with the Tail at the shoe, -182 BBL away partial returns started in the cellar with some red dye from the Mud Push II. At 190 BBL away 11.0 ppg full returns were weighed in the cellar. The pumping was shut down once to switch Super Suckers as the first was filled. After pumping down the cellar,the sample was weighed @ 11.1 ppg.The final sample before the plug was bumped was weighed at 11.3 ppg of Lead cement. The plug was bumped 22 strokes short of calculated strokes (232.58 BBL), 1000 psi was held for 5 minutes and bled off and the float checked good. CIP at 05:30 hours. Note:40.4 BBL of good 11.0 ppg Lead cement was returned from the well into the cellar with 125 BBL losses. Note: Returns had packed off between the flutes of the landing ring and the hanger. 05:30 07:00 1.50 2,599 0 SURFA( CEMEN-RURD P RD cement equipment, clean cellar and RD cement lines. Pull and LD landing joint. RD Volant CRT. 07:00 12:00 5.00 0 0 SURFA( CEMEN-NUND P Clean and ND Joe's box, bag, diverter T and ND diverter line. Clean and clear rigfloor. Open ram doors and inspect rams; Good. Crew change. 12:00 12:30 0.50 0 0 SURFA( CEMEN-NUND P Remove slip adapter flange on conductor/diverter. 12:30 13:45 1.25 0 0 SURFA(WHDBO NUND P Install MBS on surface hanger as per Cameron,torque grub screws to 400 ft/lbs. 13:45 14:15 0.50 0 0 SURFA( WHDBO NUND P Test T103 Hanger two 0-ring seals to 5000 psi for 15 minutes; Good. Witness of test by Rig Supervisor. Page 9 of 52 Time Logs • 111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:00 1.75 0 0 SURFA(WHDBO NUND P Re-orient tubing spool as per Cameron rep,torque flange bolts to 1700 ft/lbs. Note:Alignment of wellhead was OK'd by DOS Mike Alston as far as valve handle orientation. Note: Checked level of cement in the conductor-The 4"valves are 2.5' below the top of the landing ring, TOC was no more than 2.5'below the outlets. TOC 5' 1-1/2"below starting head. 16:00 23:00 7.00 0 0 SURFA( WHDBO NUND P Install 2' 13 5/8"x 11"spool, 14" spool. Install BOP stack.Torque all connections to 1700 ft/lbs. SIMOPS; Install Joe's box and seal, install flow line, low pressure riser, and PS-21. Change out long bales to medium bales. 23:00 00:00 1.00 0 0 SURFA(WHDBO RURD P PU 5"test joint and install test plug. 01/15/2015 Test BOPE witness waived by AOGCC rep John Crisp. PU and stand back 5"drill pipe. 00:00 00:30 0.50 0 0 SURFA( WHDBO RURD P Continue to Fill lines,stack and purge air 00:30 01:00 0.50 0 0 SURFA( WHDBO RURD T Test pump frozen,thaw and function test;good. Apply pressure to stack for body and chase down leaks; tighten bolts on stack and ram doors. 01:00 05:30 4.50 0 0 SURFA( WHDBO BOPE P Test BOPE 250/3500 5 min each charted.AOGCC John Crisp waived witness.Tested with 5"joint annular, UPR, LPR. Tested choke valves 1-15, manual and super choke(2000 psi)choke and kill manual and HCR valves,4"valve on kill line,2-4"TIW, 4 1/2"Dart valve. Upper and lower IBOP. 05:30 06:30 1.00 0 0 SURFA(WHDBO BOPE P Performed accumulator test and drawdown. System pressure 3000 psi, manifold 1500 psi, 1700 psi pressure after all function.200 psi=17 seconds with 2 elect pumps, 89 sec full pressure attained with 2 elect and 2 air pumps. Perform CPAI drawdown, isolate bottles,function UPR, LPR and HCR. 3000 psi with 2 elect pumps=49 sec,2700 psi with 2 air pumps=211 sec. 6 bottle N2 average 2017 psi. 06:30 07:15 0.75 0 0 SURFA( WHDBO RURD P Blow down and RD test equipment, pull test plug and drain stack. Install 10"ID wear bushing, LD test joint. 07:15 07:30 0.25 0 0 SURFA( CEMEN-SFTY P PJSM for picking up 5"DP and racking back in derrick. Page 10 of 52 Time Logs I41) Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:30 11:00 3.50 0 2,366 SURFA( CEMEN-PULD P Change to 5"DP insert,verify pipe count,and RIH with singles from shed to 2366'. 11:00 12:00 1.00 2,366 1,233 SURFA( CEMEN-TRIPP POOH racking DP in derrick. Crew change. 12:00 13:30 1.50 1,233 0 SURFA( CEMEN-TRIP P POOH racking DP in derrick. Observe proper fill. 13:30 15:30 2.00 0 2,340 SURFA( CEMEN-PULD P RIH with singles from shed. 15:30 17:30 2.00 2,340 0 SURFA( CEMEN-TRIPP POOH racking DP in derrick. Observe proper fill. 17:30 20:15 2.75 0 2,366 SURFA( CEMEN-PULD P RIH with singles from shed. 20:15 21:30 1.25 2,366 0 SURFA( CEMEN-TRIPP POOH racking DP in derrick. Observe proper fill. 21:30 00:00 2.50 0 2,365 SURFA( CEMEN-PULD P RIH with singles from shed. 31/16/2015 Continue to stand back 5"DP. PU and MU BHA#3 drilling assembly and RIH with singles from shed. Tag TOC at 2508'. Perform casing test to 3000 psi for 30 minutes to chart:good. Drill to 2519'. POOH to investigate pressure drop to surface. Inspect pipe and BHA with no conclusion. MU BHA and RIH. 00:00 01:15 1.25 2,365 0 SURFA( CEMEN-TRIPP POOH racking DP in derrick. Observe proper fill. 01:15 02:30 1.25 0 0 SURFA( CEMEN RURD P Clean and clear floor. Stage BHA to rig floor and stage in pipe shed for PU. 02:30 05:15 2.75 0 753 SURFA( CEMEN-PULD P PU and MU BHA#3 and drill collars and HWDP to 598'. Install RA sources, change out jars, change out slip inserts and RIH with BHA to 753'. 05:15 06:00 0.75 753 1,512 SURFA( CEMEN'PULD P RIH with singles from the shed from 753'to 1512'. 06:00 06:30 0.50 1,512 1,512 SURFA( CEMEN-DHEQ P Perform shallow pulse test on MWD tools; operation good with 607 GPM with 1600 psi,44%FO, BD top drive. PU= 101 K,. SO=94K. 06:30 07:00 0.50 1,512 1,512 SURFA( CEMEN SVRG P Service rig and top drive. 07:00 08:00 1.00 2,460 2,460 SURFA( CEMEN-PULD P Continue to RIH with singles from 1512'to 2460'. 08:00 10:00 2.00 2,460 2,460 SURFA( CEMEN-SLPC P Slip and cut 88'drilling line, slip on same, inspect top drive and blocks. Calibrate Totco,Amphion and MWD block height. Crew change. 10:00 11:00 1.00 2,460 2,460 SURFA( CEMEN'CIRC P Circulate surface to surface, confition mud per MI rep, staging pumps to 600 GPM with 1730 psi,42% FO, TTL strokes pumped=7173. Page 11 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 2,460 2,460 SURFA( CEMEN-PRTS P Perform casing test: Blow down kelly hose. RU head pin and high pressure hoses and 1502 valve with fittings for casing test. Open Kill line and fill lines, verify ability to pump both ways. Close upper VBR and pressure up to 3000 psi with 32 strokes for 30 minutes to chart; Good. Bleed back 2.5 BBL. RD test equipment and blow down all lines. 12:00 13:00 1.00 2,460 2,508 SURFA( CEMEN-COCF P Kelly up and wash down to tag cement at 2508'. 13:00 15:15 2.25 2,508 2,519 SURFA( CEMEN DRLG P Drill cement and tag plugs at 2516' and drill to 2519'at 460 GPM with 1152 psi, 33% FO. Increase to 600 GPM with 1775 psi,44% FO, 6-12K WOB,40 RPM with 6-9K torque. P= 113K, SO= 102K. Observe 500 psi drop in standpipe pressure. 15:15 15:45 0.50 2,516 2,516 SURFA( CEMEN SEQP T Test surface equipment and lines with 1000 psi; Good. Suspect washout somewhere in the string. Decision to POOH. 15:45 16:15 0.50 2,516 2,460 SURFA( CEMEN-TRIPT POOH from 2516'to 2460', blow down top drive. clean suction MP suction screens as precautionary trouble-shooting. 16:15 17:15 1.00 2,460 2,460 SURFA( CEMEN CIRC T Trouble-shooting P loss: Drop Well Commander ball to open circ sub. chase with 2 BPM at 50 psi, increase to 1000 psi held 30 seconds, increase to 1500 psi held 60 seconds, increase to 2000 psi held 60 seconds, open WC at 2230 psi. circulate at 600 GPM with 460 psi. Drop closing ball and pump down with 2 BPM at 47 psi. Rotate and reciprocate 60 RPM to assist ball to seat in WC. Stage pressure 1000, 1500,2000 psi,WC closed at 2110 psi. Establish circulation at 600 GPM with 1190 psi: Good. Drill string tested good. P Drop suspected below the WC in BHA. 17:15 18:15 1.00 2,460 1,200 SURFA( CEMEN-TRIPT PJSM for POOH. POOH from 2460' to 1200'with proper fill observed. 18:15 19:00 0.75 1,200 1,200 SURFA( CEMEN CIRC T Establish circulation at 600 GPM with 1085 psi, 35% FO. Trouble-shoot pressures and decision made to pull out of the hole and check all P drop possibilities within the BHA. 19:00 20:30 1.50 1,200 192 SURFA( CEMEN-TRIPT POOH from 1200'to 192', observe proper fill. Page 12 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:15 0.75 192 0 SURFA( CEMEN-PULD T PJSM for RA source removal. Remove RA sources from collar. Inspect WC sub; Good. LD WC. Inspect BHA; bit; Good, MWD collars; Good, Restrictor jet in Power drinve. BHA in good shape. Decision made Well Engineer and WSL to TIH and drill ahead. 21:15 22:15 1.00 0 754 SURFA( CEMEN'PULD T PJSM for RA source installation. Install RA sources and PU WC sub and TIH with BHA. 22:15 23:00 0.75 754 1,512 SURFA( CEMEN-TRIPT Trip in the hole from 754'to 1512'for SPT of MWD. 23:00 00:00 1.00 1,512 1,512 SURFA( CEMEN"DHEQ T Shallow pulse test MWD with 600 GPM with 1100 psi, 36%FO; Good test. Blow down top drive. 01/17/2015 RIH to 2517'and drill out shoe track. 20'of new hole to 2629'and displace well to 9.7 ppg LSND drilling mud. RU,then perform FIT test to 16 ppg EMW; Good. RD,finish preparing fluid in pits, Drill 9-7/8" intermediate from 2629'to 3950'. 00:00 00:30 0.50 1,512 2,460 SURFA( CEMEN'TRIP T Trip in the hole from 1512'to 2460' with proper hole displacement observed. During trip in, pumps were taken apart and the valve seats were found to have some rocks lodged in the valve seats causing washout of the seats. Pressure returned to system on next pumping activity. 00:30 00:45 0.25 2,460 2,517 SURFA( CEMEN-WASH T Wash down the last stand and tag plug at 2517',stage pumps up to 600 GPM with 1630 psi, 42% FO. 00:45 03:00 2.25 2,517 2,519 SURFA( CEMEN'DRLG P Drill plugs 2517'to 2519'at 600 GPM with 1750 psi,42%FO,40-60 RPM with 4-8K torque, 5-15K WOB. 03:00 03:15 0.25 2,519 2,599 SURFA( CEMEN"DRLG P Drill cement from 2519' to shoe at 2599'at 600 GPM with 1670 psi, 42%FO, 5K WOB, 60 RPM with 5-7K torque. 03:15 04:00 0.75 2,599 2,600 SURFA( CEMEN DRLG P Drill shoe from 2599' to 2600'at 600 GPM with 1670 psi,42% FO, 5K WOB, 60 RPM with 8K torque. 04:00 04:15 0.25 2,600 2,609 SURFA( CEMEN DRLG P Drill cement in rat hole from 2600'to 2609', at 600 GPM with 1750 psi, 42% FO, 5K WOB, 60 RPM with 8K torque. 04:15 04:30 0.25 2,609 2,629 SURFA( CEMEN"DDRL P Drill new hole from 2609'to 2629', at 600 GPM with 1750 psi,42% FO, 5K WOB,60 RPM with 8K torque. 04:30 05:00 0.50 2,629 2,629 SURFA( CEMEN CIRC P Circulate BU+(249 BBL), prior to displacing to new 9.7 ppg LSND mud. Pumping 597 GPM w/1650 psi,41%flow out. Rotate 60 rpm w/ 6.5k ft lbs of torque. PU wt 114k, SO wt 99k. Page 13of52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 06:00 1.00 2,629 2,629 SURFA( CEMEN-DISP P Displace to new drilling 9.7 ppg LSND mud. Pumping 500 GPM w/ 1070 psi, 38%flow out. Rotate 60 rpm w/6k ft lbs of torque. PU wt 114k, SO wt 99k. 06:00 06:30 0.50 2,629 2,552 SURFA( CEMEN-CIRC P Obtain SPR's; 9.7 ppg mud, #1 mp; 20 spm = 100 psi 30 spm= 130 psi. #2 mp; 20 spm = 90 psi 30 spm= 120 psi. Stand back a stand, blow down the top drive. 06:30 07:00 0.50 2,552 2,552 SURFAC CEMEN-RURD P Rig up for LOT/FIT test. Pump down kill line and drill pipe. Close annular, Rig up chart recorder. 07:00 07:15 0.25 2,552 2,552 SURFAC CEMEN-FIT P Perform FIT to 16 ppg EMW. Charted test. 10-3/4"shoe @ 2599.4'MD, 2312.1'TVD. Rat hole to 2609' MD, 2317'TVD, new 9-7/8"hole to 2629' MD, 2326.8'TVD. Mud used for test was 9.7 ppg new LSND. Pressure to 790 psi. Picked 760 psi as the Leak off point= 16 ppg. Pumped 1.2 BBL, bled back 0.9 BBL. 07:15 08:00 0.75 2,552 2,552 INTRM1 DRILL RURD P Rig down testing equipment. Blow down lines. Clean floor. PU a stand of 5"drill pipe. Finish preparing pits, bring on more 9.7 ppg LSND mud from vac trucks. 08:00 12:00 4.00 2,552 2,950 INTRM1 DRILL DDRL P Drill 9-7/8"Intermediate hole f/2629' to 2950' (2463'TVD). Pumping 651 GPM w/1730 psi,44%flow out. Off bottom 1720 psi, Rotating 120 rpm w/7k ft lbs of torque.WOB 7k. ECD's 10.71ppg. PU wt 112k, SO wt 100k, Rot wt 103k. ART 2.65 hrs, Total bit hrs 2.65, Jar hrs 2.65. Crew change. 12:00 18:00 6.00 2,950 3,497 INTRM1 DRILL DDRL P Drill from 2950'to 3497'at 650 GPM with 1959 psi,44%FO, Off bottom 1720 psi, 110 RPM with 6-9K ft lbs of torque,WOB 9K and ECD 11.20 ppg. PU= 112K, SO= 101K, Rot= 103K, off bottom 7K torque. ART= 4.16,ADT=4.16, Total bit hours 6.81, Jar hours 6.81. Obtain SPR's; 9.7 ppg mud, 3490' MD, 2604'TVD #1 mp; 20 spm = 160 psi 30 spm = 200 psi. #2 mp; 20 spm = 160 psi 30spm = 180 psi. Page 14 of 52 Time Logs • Date From To Dur S. Death E.-Depth--,Phase Code Subcode T Comment 18:00 00:00 6.00 3,497 3,950 INTRM1 DRILL DDRL P Drill from 3497'to 3950'at 650 GPM with 1959 psi,44%FO, Off bottom 1720 psi, 110 RPM with 6-9K ft lbs of torque,WOB 9K and ECD 11.12 ppg. PU= 112K, SO= 101K, Rot= 103K, off bottom 6K torque. ART= 3.32,ADT=3.32,Total bit hours 10.13,Jar hours 10.13. Pump 40 BBL High Vis sweep at 3818'with 10%increase at the shakers, and 0.2 ppg ECD relief after the sweep was out. 01/18/2015 Drill ahead from 3950'to 4155', pump high vis sweep with 50% increase and CBU+3X(10278 strokes). Pull on elevators to the shoe and CBU. TIH, Circulate and condition mud, stage pumps and clean hole with increased cuttings at the shakers with high ECD as pumps staged up. Continue drilling to 5385', pumping High Vis sweeps every—300'with average 15%increase in cuttings at the shakers. 00:00 02:15 2.25 3,950 4,155 INTRM1 DRILL DDRL P Drill from 3950'to 4155'at 650 GPM with 2115 psi,44%FO, Off bottom 2050 psi, 110 RPM with 8K ft lbs of torque,WOB 9K and ECD 11.29 ppg. PU= 110K, S0= 101K, Rot= 107K. ART=3.32,ADT=3.32, Total bit hours 10.13,Jar hours 10.13. Obtain SPR's; 9.7 ppg mud, 3966' MD, 2732'TVD #1 mp;20 spm = 160 psi 30 spm= 200 psi. #2 mp; 20 spm = 160 psi 30 spm= 180 psi. 02:15 03:45 1.50 4,155 3,989 INTRM1 DRILL CIRC P Pump High Vis sweep 45 BBL, Circulate at 650 GPM with 2110 psi, 60 RPM wit 6K torque. 50% increase in cutting with sweep to surface. 03:45 04:00 0.25 3,989 3,989 INTRM1 DRILL OWFF P Observe well for flow; Static. Blow down top drive. 04:00 05:30 1.50 3,989 2,549 INTRM1 DRILL WPRT P Trip out on elevators at 20 to 40 ft/min.with pull weight of 125K average. Slow to 20 ft/min over the Campanion from 3319-3360'. One spot with 30K overpull at 3100'. Pull through,wipe down and average pull weight through next time. Continue to pulling up and into shoe. Dispalcement Calculated=8.8 BBL, actual=9.4 BBL. 05:30 06:15 0.75 2,549 2,460 INTRM1 DRILL CIRC P Circulate BU to clean up casing; recip and rotate in casing at 650 GPM with 1870 psi,45%FO,40 RPM with 4.5K torque. Total strokes pumped 4455; mud in and out 9.7 PPg. 06:15 06:30 0.25 2,460 2,460 INTRM1 DRILL RURD P Blow down top drive. 06:30 07:00 0.50 2,460 2,460 INTRM1 DRILL SVRG P Service top drive,drawworks and crown. Page. 15 of 52 _� Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:00 1.00 2,460 4,106 INTRM1 DRILL WPRT P Trrip in the hole from 2460'to 4061'. Dispalcement Calculated= 10.2 BBL, actual= 10.0 BBL. 08:00 10:30 2.50 4,106 4,155 INTRM1 DRILL CIRC P Circulate; recip and rotate staging pumps up to 650 GPM with 2310 psi, 45%FO, 100 RPM with 5.5K torque. Observe major increase in cutting with FO increase to 91%max. Peak gas observed=520 units at BU strokes. Pump 45 BBL high vis sweep at 4060'. Total strokes pumped 13727; mud in and out 9.8 ppg. 10:30 12:00 1.50 4,155 4,345 INTRM1 DRILL DDRL P Drill from 4155'to 4345'at 650 GPM with 2150 psi, 44% FO, Off bottom 2140 psi, 100 RPM with 8K ft lbs of torque,WOB 9K and ECD 10.76 ppg. PU= 111K, SO= 103K, Rot= 105K. ART= 1.37,ADT= 1.37,Total bit hours 12.85, Jar hours 12.85. Crew change. 12:00 18:00 6.00 4,345 4,885 INTRM1 DRILL DDRL P Drill from 4345'to 4885'at 650 GPM with 2260 psi,45%FO, Off bottom 2250 psi, 100 RPM with 7K ft lbs of torque,WOB 12K and ECD 10.99 ppg. PU= 119K, SO= 107K, Rot= 112K. ART=3.73,ADT=3.73, Total bit hours 16.58, Jar hours 16.58. Pump 45 BBL High Vis sweep at 4723'> 14:25 Obtain SPR's; 9.7 ppg mud, 4533'MD, 2886'TVD #1 mp; 20 spm = 160 psi 30 spm= 200 psi. #2 mp; 20 spm = 160 psi 30 spm= 180 psi. 18:00 00:00 6.00 4,885 5,385 INTRM1 DRILL DDRL P Drill from 4885'to 5385'at 650 GPM with 2238 psi, 45% FO, Off bottom 2312 psi, 120 RPM with 10K ft lbs of torque, WOB 8K and ECD 11.10 ppg. PU= 121K, SO= 108K, Rot= 113K. ART=3.75,ADT=3.75, Total bit hours 20.33, Jar hours 20.33. Pump 45 BBL High Vis sweep at 5010'> 19:30 Obtain SPR's; 9.7+ppg mud, 5007' MD, 3017'TVD #1 mp; 20 spm = 180 psi 30 spm = 220 psi. #2 mp; 20 spm = 180 psi 30 spm = 220 psi. Crew change. 01/19/2015 Drilling ahead to 6143', CBU 2X and perform wiper trip to 3875', circulate hole clean and TIH. Circulate 2X BU with initial high ECDs, stage pumps and clean hole and drill ahead to 6900'control drilling and sweeping hole every 300'. Page 16 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:15 8.25 5,385 6,143 INTRM1 DRILL DDRL P Drill from 5385'to 6143'at 650 GPM with 2320 psi, 46% FO, Off bottom 2310 psi, 120 RPM with 12K ft lbs of torque,WOB 8K and ECD 11.40 ppg. PU= 133K, SO=97K, Rot= 119K. Summary of sweeps to date: 3800' 50%increase at shakers 4155' 40%before the short trip After the short trip as seen on the books 2.5 hours of circulating was needed to clean the hole. With 200-350 psi increase in our pressures when we reached bottom. The hole unloaded on the shakers and we had to stage the pumps up to move the cuttings. When we got the pumps high enough for the MWD PWD to work the first ECD was 12.1 ppg. Staging the pumps and continuing to circulate brought pressures and ECD's back to drilling range. 4155' 10%after the short trip 4511' 30% 4790' 15% 5010' 15% 5393' 15% 5733' 10%. 08:15 10:00 1.75 6,143 5,385 INTRM1 DRILL REAM P Circulate; recip and rotate from 6143' to 5385'at 650 GPM with 2420 psi, 46% FO, 135 RPM with 9K torque, ECD 11.41 ppg. mud weight in and out=9.6 ppg, ECD= 11.11 ppg. 10:00 10:15 0.25 5,385 5,385 INTRM1 DRILL OWFF P Observe well for flow: Static. 10:15 12:00 1.75 5,385 3,875 INTRM1 DRILL WPRT P POOH on elevators from 5385'to 3875'. Displacement calculated= 13.6 BBL, Actual= 19.6 BBL. Crew change. 12:00 13:00 1.00 3,875 3,875 INTRM1 DRILL CIRC P Circulate while recip and rotating at 650 GPM with1901 ppsi,ECD= 10.72,45% FO. 13:00 14:00 1.00 3,875 5,957 INTRM1 DRILL WPRT P TIH on elevators to 6143'. PU= 135K, SO=107K. Page 17 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:30 1.50 5,957 6,134 INTRM1 DRILL REAM P Ream to bottom from 5957'to 6134' staging pumps from 3 BPM to 16 BPM;650 GPM with 2332 psi,45% FO, ECD= 10.85, RPM 100 with 8K torque. PU= 135K, SO= 107K, Rot= 119K. ECD spike noted of 12.09 ppg at 2259 strokes. Total strokes pumped 7894. 15:20 Obtain SPR's; 9.7+ppg mud, 6141'MD, 3316'TVD #1 mp; 20 spm=200 psi 30 spm= 240 psi. #2 mp; 20 spm= 180 psi 30 spm= 240 psi. 15:30 00:00 8.50 6,134 6,900 INTRM1 DRILL DDRL P Drill from 6134'to 6900'at 650 GPM with 2238 psi,45%FO, Off bottom 2312 psi, 120 RPM with 10K ft lbs of torque,WOB 8K and ECD 11.10 ppg. PU= 140K, SO= 111K, Rot= 123K. ART=5.28,ADT=5.28, Total bit hours 31.08,Jar hours 31.08. 21:20 Obtain SPR's;9.6 ppg mud, 6713'MD, 3489'TVD #1 mp;20 spm =200 psi 30 spm= 260 psi. #2 mp;20 spm =200 psi 30 spm= 260 psi. Crew change. 31/20- 015 Drill ahead to 8134'.Wiper trip to 5957'pumping and circulating hole clean. TIH and blend 580 bbls of new 9.6 ppg mud into system. Drill Ahead to 8418'control drilling and sweeping hole every 500'. __ 00:00 06:00 6.00 6,900 7,471 INTRM1 DRILL DDRL P Drill from 6900'to 7471'at 675 GPM with 2780 psi,45%FO, Off bottom 2760 psi, 140 RPM with 13K ft lbs of torque,WOB 8K and ECD 11.39 ppg. PU= 143K, SO= 117K, Rot= 125K. ART=4.07,ADT=4.07, 00:39 Obtain SPR's;9.6+ppg mud, 6997'MD, 3570'TVD #1 mp;20 spm =240 psi 30 spm= 280 psi. #2 mp;20 spm =240 psi 30 spm= 280 psi. 06:00 12:00 6.00 7,471 8,039 INTRM1 DRILL DDRL P Drill from 7471'to 8039'at 675 GPM with 2920 psi,45% FO, Off bottom 2910 psi, 140 RPM with 12K ft lbs of torque,WOB 8K and ECD 11.45 ppg. PU= 155K, SO= 119K, Rot= 130K. ART=4.10,ADT=4.10, Total bit hours 39.25, Jar hours 39.25. 27:00 Obtain SPR's; 9.7 ppg mud, 7564' MD, 3725'TVD #1 mp; 20 spm=230 psi 30 spm= 280 psi. #2 mp; 20 spm=230 psi 30 spm= 280 psi. Crew change. Page 18 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 8,039 8,134 INTRM1 DRILL DDRL P Drill from 8039'to 8134'at 675 GPM with 2900 psi,46%FO, Off bottom 2875 psi, 140 RPM with 14K ft lbs of torque,WOB 9K and ECD 11.36 ppg. PU= 156K, SO= 119K, Rot= 131K,TQ= 10K. ART=0.66,ADT= 0.66,Total bit hours 39.91,Jar hours 39.91. 13:00 Obtain SPR's; 9.7 ppg mud, 7564'MD, 3725'TVD #1 mp; 20 spm=230 psi 30 spm= 280 psi. #2 mp;20 spm=230 psi 30 spm= 280 psi. 13:00 13:45 0.75 8,134 8,034 INTRMI DRILL CIRC P Rotate and Recip from 8134'to 8034' MD.675 GPM with 2750 psi,46% FO, 140 RPM with 10K ft lbs of torque, PU= 156K, SO= 119K, Rot= 131K,TQ= 10K. 790 bbls pumped. 13:45 14:00 0.25 8,034 8,034 INTRM1 DRILL OWFF P Monitor Well. Static 14:00 18:00 4.00 8,034 5,957 INTRMI DRILL REAM P Circulate and Rotate from 8034'to 5970' MD at 675 gpm,2750 psi,46% FO, 135 RPM, 10k TQ. PU = 140k, SO=95k. 18:00 18:30 0.50 5,957 5,957 INTRM1 DRILL SVRG P Service Rig. Grease Top Drive and Blocks. 18:30 19:30 1.00 5,957 7,944 INTRM1 DRILL WPRT P Trip in on elevators from 5957'to 7944'MD. PU= 152k, SO= 116k. 19:30 21:00 1.50 7,944 8,133 INTRMI DRILL REAM P Rotate and Recip from 7944'to 8133' MD while circulating hole and blending new 9.6 ppg mud. Stage Pumps from 400 gpm, 550 psi to 675 gpm, 2411 psi. FO=46%, 140 RPM, TQ= 10k, ECD= 10.92 ppg (max ECD 11.04 ppg). 735 bbls pumped. 21:00 00:00 3.00 8,133 8,418 INTRM1 DRILL DDRL P Drill from 8133'to 8418 MD, 3960 TVD'at 675 GPM with 2640 psi,46% FO, Off bottom 2561 psi, 140 RPM with 14K ft lbs of torque,WOB 7K and ECD 10.92 ppg. PU= 162K, SO= 116K, Rot= 132K. ART=2.01, ADT=2.01,Total bit hours 41.92,Jar hours 41.92. 21:45 Obtain SPR's;9.7 ppg mud, 7564' MD, 3725'TVD #1 mp; 20 spm=220 psi 30 spm= 260 psi. #2 mp;20 spm=220 psi 30 spm= 260 psi. Crew change. 01/21/2015 Drilling ahead to 9551'.Wiper trip to 7941'pumping and circulating hole clean(packoff and hole unloads during trip). TIH and blend 580 bbls of new 9.6 ppg mud into system. Drill Ahead to 9741'control drilling Page 19 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 8,418 8,986 INTRM1 DRILL DDRL P Drill from 8418'to 8986' MD,4113' TVD at 675 GPM with 2935 psi, 45% FO, Off bottom 2930 psi, 140 RPM with 14K ft lbs of torque,WOB 11K and ECD 11.54 ppg. PU= 160K, SO= 118K, Rot= 134K, TQ=9K. ART=3.96,ADT=3.96. 01:02 Obtain SPR's; 9.7 ppg mud, 8513' MD, 3986'TVD #1 mp; 20 spm =200 psi 30 spm= 260 psi. #2 mp; 20 spm =210 psi 30 spm = 260 psi. 06:00 12:00 6.00 8,986 9,494 INTRM1 DRILL DDRL P Drill from 8986'to 9494'at 675 GPM with 3070 psi, 45% FO, Off bottom 3050 psi, 140 RPM with 14K ft lbs of torque,WOB 11K and ECD 11.61 ppg. PU= 170K, S0= 120K, Rot= 137K. ART=3.90,ADT=3.90, Total bit hours 49.78, Jar hours 49.78. 07:05 Obtain SPR's; 9.7+ppg mud, 9080' MD,4140'TVD #1 mp; 20 spm =260 psi 30 spm = 330 psi. #2 mp; 20 spm =260 psi 30 spm = 330 psi. Crew change. 12:00 13:00 1.00 9,494 9,551 INTRM1 DRILL DDRL P Drill from 9494'to 9551'MD,4268' TVD at 675 GPM with 3125 psi, 46% FO, Off bottom 3020 psi, 140 RPM with 12K ft lbs of torque,WOB 9K and ECD 11.42 ppg. PU= 174K, SO= 120K, Rot= 137K,TQ= 10K. ART=0.57,ADT=0.57. Total Bit hours=50.35; Jar Hours=50.35. 12:40 Obtain SPR's; 9.7 ppg mud, 9550'MD,4268'TVD #1 mp; 20 spm =300 psi 30 spm= 360 psi. #2 mp; 20 spm =320 psi 30 spm= 380 psi. 13:00 16:00 3.00 9,551 8,145 INTRM1 DRILL REAM P Circulate and Rotate from 9551'to 8145'MD at 675 gpm, 3125 psi,46% FO, 140 RPM, 12k TQ. PU = 174k, SO= 120k, ROT= 137k. Observe packoff at 8145' MD. Pressure spike to 3400 psi,Torque spiked and Top Drive stalled. Driller caught immediately, excellent job monitoring parameters. Mud weight out had increased to 9.9 ppg. 16:00 16:30 0.50 8,145 8,231 INTRM1 DRILL WPRT P Run in hole without pumps or rotation from 8145'to 8231' MD. PU = 160k, SO=95k. Page 20 of ii2 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 8,231 7,941 INTRM1 DRILL REAM P Circulate and Rotate from 8231'to 7941'MD. Pumps staged up from 350 gpm @ 1136 psi to 675 gpm @ 3108 psi,46% FO, 140 RPM, Ilk TQ. PU = 140k, SO=95k. Large clumps of cuttings and sticky clay clumps began unloading from hole 8100'and continued until cleaning up during last stand. 17:30 18:30 1.00 7,941 9,365 INTRM1 DRILL WPRT P Trip in from 7941'to 9365'MD. UP= 166k, SO= 105k. 18:30 20:30 2.00 9,365 9,551 INTRM1 DRILL CIRC P Rotate and Recip last 3 stands while dumping and diluting system with 580 bbls of 9.6 ppg mud. Pumps staged up from 350 gpm @ 1136 psi to 675 gpm @ 2980 psi, FO=46%, RPM= 140, TQ off= 10-12k, PU= 168k, SO= 120k, ROT= 142k,TQ on= 12k. 1049 bbls pumped. 20:30 22:00 1.50 9,551 9,678 INTRM1 DRILL DDRL P Drill from 9551'to 9678'MD,4304' TVD at 675 GPM with 2590 psi,46% FO, Off bottom 2640 psi, 140 RPM with 15K ft lbs of torque,WOB 9K and ECD 10.86 ppg. 20:30 Obtain SPR's; 9.6 ppg mud, 9550'MD,4268'TVD #1 mp;20 spm=240 psi 30 spm= 300 psi. #2 mp;20 spm =220 psi 30 spm= 280 psi. 22:00 22:30 0.50 9,678 9,678 INTRM1 DRILL SVRG P Service Rig: Mud Pump#2 pulsation dampener gasket replaced. 22:30 00:00 1.50 9,678 9,741 INTRM1 DRILL DDRL P Drill from 9678'to 9741 MD,4319' TVD'at 675 GPM with 2675 psi, 46% FO, Off bottom 2667 psi, 140 RPM with 15K ft lbs of torque,WOB 9K and ECD 10.86 ppg. PU= 172K, SO= 118K, Rot= 139K. ART=1.36, ADT= 1.36,Total bit hours 51.71,Jar hours 51.71. Crew change. 31/22/2015 Pump BU x2. Monitor well. Pump/Rotate out of hole to 2455'. Clean inside casing to 2365'MD with well commander tool. PU storm packer and hang off string beneath. Clean stack. Pull Wear ring and set test plug. Test BOPE witness waived by AOGCC rep Matt Herrera. 00:00 01:30 1.50 9,741 9,551 INTRM1 DRILL CIRC P Circulate 2 BU while Rotating and Recip from 9741'to 9551'MD at 675 gpm @ 2650 psi. FO=46%, RPM= 140,TQ off= 12-14k Mud weight in/out 9.6 ppg. 00:30 Obtain SPR's; 9.6 ppg mud, 9450' MD,4241'TVD #1 mp;20 spm=240 psi 30 spm= 300 psi. #2 mp;20 spm=220 psi 30 spm= 280 psi. 01:30 01:45 0.25 9,551 9,551 INTRM1 DRILL OWFF P Monitor well. Static Page 21 of 52 Time Logs . Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 14:45 13.00 9,551 2,600 INTRM1 DRILL BKRM P Circulate and Rotate from 9551'to 2600'MD.675 gpm, 2250 psi, FO 44%, 140 rpm, TQ 6.5k. FCP 2075 psi, FO 46%, TQ 5k. 14:45 15:30 0.75 2,600 2,455 INTRM1 DRILL CIRC P Rotate and Recip while circulating BU from 2600'to 2455'MD. 675 gpm, 2075 psi,43-45% FO,40 rpm, TQ 3-4k, UP 105k, DN 103k, ROT 105k.416 bbls pumped. 15:30 18:30 3.00 2,455 2,362 INTRM1 DRILL CIRC P Drop 2.115"OD ball to open well commander. Pump at 85gpm, 145 psi, FO= 16%. Ball on seat after 149 strokes. Pressure to 1000 psi, hold 1 min,to 1500 psi. hold 30 sec, stage to 2500 psi and observe unsuccessful shear. Pressure to 3005 psi and observe pressure bleed to 25 psi. Pump at 675 gpm,2050 psi, FO=46%to confirm communication with MWD tools, observe communication with MWD indicating failed attempt to shift well commander open. Drop second 2.115"OD ball to open well commander. Ball on seat after 70 strokes. Pressure Up to 1000 psi, 1500 psi, 2000 psi, 2500 psi holding each for 1 min. Increase to 3000 psi and observe well commander open at 2936 psi. Pump 675 gpm, 914 psi, FO=46% no communication with MWD tools indicating successful shift open. Wash from 2550' MD to 2365'MD inside casing. Observed significant cuttings and clay across shakers. Continued until cuttings cleaned up. Drop 2.115"OD ball to close well commander tool, 85 gpm, FO= 10%, 50 psi. Ball on seat at 66 strokes, Pressure up to 1000 psi, 1500 psi, 2000 psi,2500 psi holding each for 1 min. Increase to 3000 psi and observe well commander close at 2918 psi. Pump at 675 gpm, 2018 psi, FO=46%, observe comunication with MWD tools,well commander closed. UP= 107k, SO = 105k. 18:30 20:30 2.00 2,362 2,448 INTRM1 WHDBO MPSP P PU and RIH with Baker Hughes Model B Retrievamatic Storm Packer. Observe packer scraping cake on surface casing. Pull storm packer out and clean off(repeat 2 more times)until casing clean. Set Storm Packer(center of element at 68' MD). POOH and LD running tool. 20:30 21:00 0.50 2,448 2,448 INTRM1 WHDBO PRTS P Pressure Test Storm Packer to 500 psi for 5 min. Good test. Charted. Page 22 of 52 Time Logs 411, 4111/ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 2,448 2,448 INTRM1 WHDBO WWWH P Clean stack and wellhead with jetting tool. Continue until cuttings cleaned up on shakers. 21:30 22:30 1.00 2,448 2,448 INTRM1 WHDBO RURD P Pull Wear Ring. Set Test Plug. Rig Up all lines and test equipment, valves and test joint. Fill stack and lines with water. 22:30 00:00 1.50 2,448 2,448 INTRM1 WHDBO BOPE P Test BOPE 250/3500 5 min each charted.AOGCC Matt Herrera waived witness.Tested with 5"joint annular, UPR, LPR. Tested choke valves 1-15, manual and super choke (2000 psi)choke and kill manual and HCR valves,4"valve on kill line, 2-4" TIW,4 1/2"Dart valve. Upper and lower IBOP. 01/23/2015 Test BOPE witness waived by AOGCC rep Matt Herrera. Pull test plug. Dummy Run Hanger. Set wear ring (10.00"ID). Retrieve Storm Packer. Slip and Cut Drilling Line.Trip in hole. Circulate out old mud to new 9.6 ppg mud. Drill ahead. 00:00 02:00 2.00 2,448 2,448 INTRM1 WHDBO BOPE P Continue to Test BOPE 250/3500 5 min each charted.AOGCC Matt Herrera waived witness.Tested with 5"joint annular, UPR, LPR. Tested choke valves 1-15, manual and super choke(2000 psi)choke and kill manual and HCR valves,4"valve on kill line, 2-4"TIW,4 1/2"Dart valve. Upper and lower IBOP. Performed accumulator test and drawdown. System pressure 2950 psi, manifold 1425 psi, 1700 psi pressure after all function.200 psi=17 seconds with 2 elect pumps, 90 sec full pressure attained with 2 elect and 2 air pumps. Perform CPAI drawdown, isolate bottles,function UPR, LPR and HCR. 3000 psi with 2 elect pumps=52 sec,2700 psi with 2 air pumps=150 sec.6 bottle N2 average 1975 psi. 02:00 03:30 1.50 2,448 2,448 INTRM1 WHDBO RURD P Rig Down test equipment,test valves/joint. Pull Test plug. Dummy Run Intermediate Hanger. Run and set Wear Ring(10.00"ID). 03:30 06:45 3.25 2,448 2,362 INTRM1 WHDBO MPSP P RIH with Storm Packer retrieval tool, wash down over storm packer to ensure clean.Attempt to screw in and engage storm packer, rocks and debris preventing from getting retrieval tool screwed into it. Continue to Wash over and attempt to engage storm packer. Engage Packer and open equalizing valve, verify no pressure. Release storm packer and verify no pressure. Pull out of the hole w/Baker storm packer. Page 23 of 52 Time Logs 41 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:00 0.25 2,362 2,460 INTRMI DRILL PULD P Pickup a double of 5"drill pipe from the pipe shed, RIH. Pick up a single from the pipe shed, RIH. Both had been laid down when setting the storm packer. 07:00 08:30 1.50 2,460 2,460 INTRM1 DRILL SLPC P Slip and Cut 102"of 1-3/8"6x19 Extra improved plow steel Drilling Line. Monitor well on pit#2. 08:30 09:00 0.50 2,460 2,460 INTRM1 DRILL SVRG P Service rig and top drive. 09:00 09:30 0.50 2,460 2,460 INTRM1 DRILL OTHR P Calibrate block height w/Amphion, Totco and Schlumberger MWD. 09:30 12:00 2.50 2,460 6,420 INTRMI DRILL TRIP P Trip in the hole f/2460'to 6420', filling pipe every 20 stands. Monitor well on pits#2. Calc displacement 28.8 bbls, actual 28.5 bbls. 12:00 14:45 2.75 6,420 9,365 INTRMI DRILL TRIP P Trip in the hole f/6420"to 9365', filling pipe every 20 stands. Monitor well on pits#2. 14:45 16:45 2.00 9,365 9,740 INTRM1 DRILL REAM P Wash and precautionary ream f/ 9365'to 9740'. Pumping 500 gpm w/ 1535 psi, 37%flow out. Rotate120 rpm w/12.5k ft lbs of torque. SIMOPS: New mud displacement, 9.6 ppg LSND. Pumped 849 bbls. 16:45 18:00 1.25 9,740 9,825 INTRM1 DRILL DDRL P Drill from 9741'to 9825' MD,4343' TVD at 675 GPM with 2440 psi,46% FO, Off bottom 2225 psi 11k torque, 140 RPM with WOB 11K, 16K torque and ECD 10.60 ppg. PU = 180k, SO = 118k, Rot= 140k,ART/ADT= 0.67, Total bit=53.16, Total Jars= 53.16. Sand and clay returns. 16:40 Obtain SPR's;9.6+ppg mud, 9791'MD,4320'TVD #1 mp; 20 spm = 180 psi 30 spm= 240 psi. #2 mp; 20 spm = 180 psi 30 spm= 240 psi. 18:00 19:30 1.50 9,825 9,929 INTRM1 DRILL DDRL P Drill from 9825'to 9929'MD,4371' TVD at 673 GPM with 2440 psi,46% FO, Off bottom 2433 psi 11k torque, 140 RPM with WOB 7K, 16K torque and ECD 10.77 ppg. 19:30 20:00 0.50 9,929 9,929 INTRM1 DRILL SVRG P Service rig mud pumps. 20:00 00:00 4.00 9,929 10,309 INTRM1 DRILL DDRL P Drill from 9825'to 10309'MD,4476' TVD at GPM with 2440 psi,46%FO, Off bottom 2433 psi 11k torque, 140 RPM with WOB 7K, 16K torque and ECD 10.77 ppg.ART/ADT=2.61, Total bit=55.77,Total Jars=55.77. 01/24/2015 Drilled to 10891'MD. Could not drill past spot. Trip out of hole. Page 24 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 10,309 10,849 INTRM1 DRILL ',DDRL P Drill from 10309'to 10849' MD,675 GPM with 2570 psi, 44% FO, Off :bottom 2560 psi 12k torque, 140 RPM with WOB 8k, 16k torque and ECD 10.81 ppg.AST/ART/ADT: 3.8 hours,Total Bit/jar hours: 59.57 hours. Flow check as we entered Iceberg and once tool had entered formation(37'MD deeper). No flow (static). 01:00 Obtain SPR's; 9.6+ppg mud, 10464' MD,4502'TVD #1 mp: 20 spm =220 psi 30 spm= 260 psi. #2 mp: 20 spm =220 psi 30 spm= 260 psi. 06:00 11:30 5.50 10,849 10,889 INTRM1 DRILL DDRL P Drill from 10849'to 10889' MD,675 GPM with 2560 psi, 44% FO, Off bottom 2560 psi 12k torque, 70 RPM with WOB 8k, 17k torque and ECD 10.40 ppg.AST/ART/ADT:4.13 hours, Total Bit/jar hours: 63.70 hours. Hard formation encountered at 10889' MD. Drilled at different rpm, pump rates, WOB, Torques to try and make headway. 11:30 11:45 0.25 10,889 10,691 INTRM1 DRILL BKRM P Backream from 10889'to 10691' MD at 675 gpm,2580 psi,43% FO, 120 rpm, 15k torque. 11:45 12:00 0.25 10,691 10,785 INTRM1 DRILL CIRC P Ream and Wash 10691'to 10785' MD at 590 gpm,2080 psi, 39% FO, 120 rpm, 15k torque. 12:00 18:00 6.00 10,785 10,889 INTRM1 DRILL DDRL P Slowly drill from 10785'to 10889' MD at 673 gpm,2685 psi,42% FO, 140 rpm, 11-20k Torque, 2-22k WOB. Slow progress made, continue to change parameters regularly to find a spot which will allow bit to dig better. Contact CPAI Engineer and Superintendent to talk about options. Continue to work on spot. 18:00 21:00 3.00 10,889 10,891 INTRM1 DRILL DDRL P Continue Drilling 10889'to 10891' MD at 676 gpm,2580 psi,42% FO, 140 rpm, 14-16k Torque, 36k WOB, ECD 10.50, Off Bottom 2575 psi, PU = 182k, SO= 127k, ROT= 148k, 12k torque.ART/ADT=6.02, Total Bit/Jar hours=65.59. Pump 32 ppg nut plug pill w/SAPP to aid bit balling, also add lubes, showing minimal decrease in torque, no other positive signs. Contact CPAI Engineer and Superintendent to talk about options. Decision made to come out of hole and inspect/change bit and change out BHA components. Page 25 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 10,891 10,891 INTRM1 DRILL SRVY T Obtain bottom hole survey. Command sent to zero powerdrive BHA component. 21:25 Obtain SPR's; 9.6 ppg mud, 10891' MD,4631'TVD #1 mp:2 spm =220 psi; 30 spm = 270 psi #2 mp:2 spm =220 psi; 30 spm = 270 psi 21:30 22:15 0.75 10,891 10,407 INTRM1 DRILL PMPO T Trip out of hole while pumping from 10891'to 10407' MD @ 126 gpm, 275 psi, 17%FO. No overpull noted. Hole taking correct fill. 22:15 22:30 0.25 10,407 10,407 INTRM1 DRILL OWFF T Monitor well. Static. SIMOPS: Blow Down Top Drive. 22:30 00:00 1.50 10,407 9,271 INTRM1 DRILL TRIP T Trip out of hole on elevator. No drag issues noted. 31/25/2015 Trip out of hole. LD BHA#3. PU BHA#4(replace MWD and directional tools and bit). Trip in hole. 00:00 01:00 1.00 9,271 8,419 INTRM1 DRILL TRIP T Trip out of hole on elevators from 9217'to 8419'MD. Hole taking correct fill. 01:00 01:15 0.25 8,419 8,419 INTRM1 DRILL CIRC T Pump dry job. 01:15 04:00 2.75 8,419 3,301 INTRM1 DRILL TRIP T Trip out of hole from 8419'to 3301'MD. Hole taking correct fill. 04:00 04:30 0.50 3,301 3,301 INTRM1 DRILL OWFF T Monitor well once above Campanian Sand. Static 04:30 04:45 0.25 3,301 2,545 INTRM1 DRILL TRIP T Trip out of hole from 3301'to 2545' MD(inside shoe) 04:45 05:00 0.25 2,545 2,545 INTRM1 DRILL OWFF T Monitor well at shoe. Static. 05:00 06:00 1.00 2,545 754 INTRM1 DRILL TRIP T Trip out of hole from 2545'to HWDP. 06:00 06:15 0.25 754 754 INTRM1 DRILL OWFF T Monitor well at BHA. Static 06:15 09:00 2.75 754 0 INTRM1 DRILL BHAH T Lay Down BHA#3 per Directional Driller. 09:00 09:30 0.50 0 0 INTRMI DRILL RURD T Clean and Clear Rig Floor. 09:30 10:00 0.50 0 0 INTRMI DRILL SFTY T Safety Stand Down with all rig personnel and all 3rd party on Drum incident and focusing on our safety culture.AAR on LSND swap. 10:00 11:45 1.75 0 753 INTRM1 DRILL BHAH T Make Up BHA#4 per Directional Driller. 11:45 12:00 0.25 753 753 INTRM1 DRILL RURD T Change Out Slip Inserts to 5"type. 12:00 12:15 0.25 753 847 INTRM1 DRILL PULD T Pick up and Make Up 3 Drill Pipe singles. 12:15 14:00 1.75 847 2,550 INTRM1 DRILL TRIP T Trip in the hole from derrick to 2550'. 14:00 15:00 1.00 2,550 2,550 INTRM1 DRILL CIRC T Perform shallow hole test. Stage pumps to 675 gpm, 1820 psi,43% FO, Recip string while circulating Surface to Surface. Returns thick and heavy, ECDs 10.26, Circulate a total of 575 bbls. 15:00 15:15 0.25 2,550 2,550 INTRM1 DRILL SFTY T PJSM on slip and cut of drilling line. Page 26 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 17:00 1.75 2,550 2,550 INTRM1 DRILL SLPC T Slip and cut(50')of drilling line. SIMOPS: Monitor well via trip tank. Calibrate Amphion,Totco and SLB eqpt. 17:00 18:00 1.00 2,550 2,550 INTRM1 DRILL SFTY T Safety Stand Down with all rig personnel on Drum incident and focusing on our safety culture. 18:00 00:00 6.00 2,550 10,120 INTRM1 DRILL TRIP T Trip in hole with BHA#4 from 2550' to 10120' MD. Fill every 20 stands. Trip displacement correct. Tight spot encountered 8505'MD. Tight on Stand#83. Pick up, break over and work down. 12k drag. No other issues on trip, hole to bottom in good shape. 01/26/2015 Trip to bottom (10888'MD). Drilled ahead to 11445'MD 00:00 01:30 1.50 10,120 10,784 INTRM1 DRILL TRIP T Trip in hole from 10210'to 10781' MD. 01:30 02:15 0.75 10,784 10,888 INTRM1 DRILL WASH T Wash down last stand. Stage up pumps. SIMOPS: ensure MWD tools online and check ECD reading (10.77). 02:00 Obtain SPR's; 9.8 ppg mud, 10870' MD,4629'TVD #1 mp: 20 spm =320 psi; 30 spm= 380 psi. #2 mp; 20 spm =320 psi; 30 spm= 380 psi. 02:15 10:30 8.25 10,888 10,888 INTRM1 DRILL DDRL T Tag Bottom at 10888' MD. Drill on hard spot @ 10880'MD. Regularly change parameters of rpm, pump rate,WOB. 10:30 10:45 0.25 10,888 10,808 INTRM1 DRILL PULD T Rack back 1 stand and pick up single joint of 5"Drill Pipe. 10:45 12:00 1.25 10,808 10,888 INTRM1 DRILL REAM T Rotate and Recip From 10808'to 10888'MD @ 675 gpm,2650 psi, 44%FO, 100 rpm, 14k Torque. 12:00 14:45 2.75 10,888 10,891 INTRM1 DRILL DDRL T Work string and continue to work on spot and areas that developed at 10857'and 10826'MD from working same area for extended time. Attempt to spud 10k,20k, 30k, break through at 38k. 14:45 16:30 1.75 10,891 10,891 INTRM1 DRILL REAM P Continue to work stand through spot to ensure no ledges and best possible hole conditions for continued drilling ahead. 16:30 18:00 1.50 10,891 11,010 INTRM1 DRILL DDRL P Drill 9 7/8"Intermediate hole form 10891'to 11010'MD.673 gpm,2600 psi,43% FO, 110 rpm, 11-12k Torque, 2k WOB, ECD 10.32, Off Bottom =2625 psi, PU= 180k, SO = 130k,ART/ADT= 1.4,Total Bit hours=7.24,Total Jar hours=72.83. Page 27 of 52 Time Logs , • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 11,010 11,445 INTRM1 DRILL DDRL P Drill 9 7/8"Intermediate hole form 11010'to 11445'MD. 673 gpm, 2770 psi,43%FO, 140 rpm, 17k Torque, 10k WOB, ECD 10.58, Off Bottom= 2779 psi, PU= 181k, SO= 130k, ROT= 153k, 12k Free Torque, ART/ADT=3.55, Total Bit hours= 10.79,Total Jar hours=76.38. 20:45 Obtain SPR's; 9.6 ppg mud, 11225' MD,4709'TVD #1 mp;20 spm =220 psi 30 spm= 270 psi. #2 mp; 20 spm =220 psi 30 spm= 270 psi. Crew Change 31/27/2015 Directional drill from 11,445'MD to 12,847'MD. Increase mud density from 9.6 ppg to 9.9 ppg to address connection gas. 00:00 06:15 6.25 11,445 12,012 INTRM1 DRILL DDRL P Directional drill from 11,445'MD to 12,102' MD, 4943'TVD.675 gpm, 2722 psi,44% Flow out, 140 rpm,Tq on/off=18k/14k, 8k WOB, ECD=10.58 ppg, P/U=196k, S/O=132k, ROT=150k.ADT=4.32, Total bit hrs=15.11, Total jar hrs=80.7. SPR's @ 11,540'MD,4809'TVD, 9.65 ppg, 01:08 hrs. #1-20 spm=230 psi.30 spm=280 psi #2-20 spm=230 psi, 30 spm=270 psi SPR's @ 11,822'MD,4890'TVD, 9.65 ppg, 04:00 hrs #1-20 spm=220 psi, 30 spm=280 psi #2-20 spm=220 psi, 30 spm=270 psi 06:15 08:15 2.00 12,012 12,012 INTRM1 DRILL CIRC T Observe gas units rising,circulate while R&R from 12,012'-11,914' MD @ 675 gpm, 2850 psi,45%flow out, 140 rpm, 14k tq. Observe max gas of 7225 units,correlating to Iceburg sand stringer @ 11,930'MD. Level off to 2800 units background gas with 9.6 ppg mud weight. Panc 28 of 52' Time Logs r • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 12:00 3.75 12,012 12,200 INTRM1 DRILL DDRL P Directional drill from 12,012' MD to 12,200' MD, 4995'TVD.675 gpm, 2805 psi,45% Flow out, 140 rpm,Tq on/off=17k/14k, 10k WOB, ECD=10.7 ppg, P/U=198k, S/0=130k, ROT=151k. ADT=1.72, Total bit hrs=16.83, Total jar hrs=82.42. Observe max gas of 7349 units @ 12,031', again correlating to Iceberg. Decision to weight up active system to 9.7+while drilling ahead. Observe max gas of 8422 units @ 12,130' MD 12:00 14:00 2.00 12,200 12,200 INTRM1 DRILL CIRC T Increase mud weight to 9.8 ppg due to gas cut mud, 8.9 ppg non-pressurized scale.Weight up system while pumping 669 gpm, 2905 psi, 45%flow out, 140 rpm, 14k tq, reciprocate from 12,106'to 12,200' MD. Obtain new kill rate pressures. SPR's @ 12,200'MD,4994'TVD, 9.8 ppg, 13:40 hrs. #1-20 spm=210 psi, 30 spm=270 psi #2-20 spm=210 psi, 30 spm=270 psi 14:00 14:30 0.50 12,200 12,254 INTRM1 DRILL DDRL P Directional drill from 12,200' MD to 12,254' MD, 5008'TVD. 665 gpm, 2886 psi,43% Flow out, 140 rpm,Tq on/off=17k/14k, 10k WOB, ECD=10.76 ppg, P/U=200, S/O=125k, ROT=152k.ADT=.35, Total bit hrs=17.18, Total jar hrs=82.77. SPR's @ 12,254'MD, 5008'TVD, 9.8 ppg, 13:40 hrs #1-20 spm=210 psi, 30 spm=270 psi #2-20 spm=210 psi, 30 spm=270 psi 14:30 15:00 0.50 12,254 12,254 INTRM1 DRILL CIRC T Observe well packoff during Powerdrive downlink, pump pressure spiked to 3500 psi, ECD=13.6 ppg, Tq=20k, P/U off bottom, and reduce pump rate until stablized, reciprocate string from 12,252' MD to 12,200' IMD. Page 29 c` Time Logs 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 17:30 2.50 12,254 12,388 INTRM1 DRILL DDRL P Directional drill from 12,254'MD to 12,388'MD,TVD. 673 gpm, 2965 psi,43% Flow out, 140 rpm, Tq on/off=17k/15k, 5k WOB, ECD=10.82 ppg, Observe short spikes in gas units, up to 6900 units, appears to be connection gas. Background gas down to 300-500 units max.Weight up active system to 9.9 ppg, reduce speed of backream(850-400 fph)to evaluate effect on gas spikes. 17:30 00:00 6.50 12,388 12,847 INTRMI DRILL DDRL P Directional drill from 12,388' MD to 12,847' MD, 5159'TVD. 673 gpm, 3178 psi, 43% Flow out, 130 rpm,Tq on/off=18k/15k, 7k WOB, ECD=11.08 ppg, P/U=200, S/O=127k, ROT=149k.ADT=5.24, Total bit hrs=22.42, Total jar hrs=88.01. SPR's @ 12,765' MD, 5138'TVD, 9.95 ppg, 23:16 hrs. #1-20 spm=250 psi, 30 spm=300 psi #2-20 spm=240 psi, 30 spm=300 psi 01/28/2015 Directional drill from 12,847' MD to TD 13,775' MD, 5401'TVD. CBU and weight up to 10.2 ppg. Begin backreaming out, observe connection gas. Continue out @ 1.5 fpm tp 13,243'MD,weighting up to 10.6 ppg. Send notice to AOGCC for BOP testing 1-29-15 00:00 06:00 6.00 12,847 13,240 INTRMI DRILL DDRL P Directional drill from 12,847' MD to 13,240' MD, 5257'TVD. 673 gpm, 3120 psi, 45% Flow out, 130 rpm,Tq on/off=19.5k/14k, 7k WOB, ECD=11.03 ppg, P/U=202, S/O=132k, ROT=156k.ADT=4.09, Total bit hrs=26.51, Total jar hrs=92.1. SPR's @ 13,240'MD, 5257'TVD, 9.9 ppg, 06:00 hrs. #1-20 spm=250 psi,30 spm=320 psi #2-20 spm=250 psi, 30 spm=320 psi 06:00 12:00 6.00 13,240 13,618 INTRM1 DRILL DDRL P Directional drill from 13,320'MD to 13,618'MD, 5359'TVD. 670 gpm, 3487 psi,45% Flow out, 130 rpm, Tq on/off=20k/15k, 8k WOB, ECD=11.33 ppg, P/U=210, 5/0=120k, ROT=159k.ADT=3.89, Total bit hrs=30.4, Total jar hrs=95.99. SPR's @ 13,240'MD, 5257'TVD, 9.9 ppg,06:00 hrs. Page 30 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:15 2.25 13,618 13,770 INTRM1 DRILL DDRL P Directional drill from 13,618' MD to 13,770' MD, 5400'TVD.672 gpm, 3324 psi,46% Flow out, 130 rpm,Tq on/off=20k/15k, 8k WOB, ECD=11.46 ppg, P/U=207, S/O=128k, ROT=159k. Max gas units seen 3450 units, connection gas. Background gas remains 200-300 units. Increase mud density to 10.2 ppg while drilling. 14:15 15:15 1.00 13,770 13,770 INTRM1 DRILL CIRC P CBU @ 664 gpm, 3420 psi, 130 rpm, 18k Tq to catch samples @ 9662 stks and 11162 stks. Decision to drill ahead additional 10'per Geo. 15:15 15:30 0.25 13,770 13,775 INTRM1 DRILL DDRL P Directional drill from 13,770' MD to 13,775' MD, 5401'TVD. 672 gpm, 3324 psi,46% Flow out, 130 rpm,Tq on/off=20k/15k, 8k WOB, ECD=11.46 ppg, P/U=207, S/O=128k, ROT=159k.ADT=1.44, Total bit hrs=31.84, Total jar hrs=97.43. Combined from 13,618' MD. SPR's @ 13,775'MD, 5401'TVD, 10.2 ppg, 15:35 hrs. #1-20 spm=260 psi, 30 spm=340 psi #2-20 spm=260 psi, 30 spm=340 psi 15:30 18:00 2.50 13,775 13,662 INTRM1 CASING BKRM P CBU @ 665 gpm, 3439 psi, 130 rpm, 17k Tq, pulling @ 3 fpm. Obtain survey and SPR's before coming off bottom. Begin to stand back a stand every bottoms up. Observe connection gas up to 4900 units, decision to weight up system to 10.6 ppg based on drilling ECD gas trends. 18:00 00:00 6.00 13,662 13,243 INTRM1 CASING BKRM P Continue backreaming out of hole slowly, MAD passing from 13622' MD to 13243' MD.Weight up system from 10.2 ppg to 10.6 ppg while pulling 1.5 fpm, 130 rpm, 17k Tq,665 gpm, 3345 psi, 44%flow out, no losses, no tight spots. 01/29/2015 Backream/MAD pass out to 10,300' MD, CBUx3 observe well static and attempt to POOH. Pull tight @ 10,248', continue backreaming out to 9549'. Updated AOGCC for BOP testing 1-30-15 Page 31 of 52 Time Logs s • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 13,243 13,054 INTRM1 CASING BKRM P Continue backreaming out of hole© 90 fph while circulating 9 bottoms up. MAD passing @ 90 fph while weighting up to 10.6 ppg on the fly from 13243' MD to 13054' MD due connection gas. Pumping 675 gpm, 3485 psi,46%flow out, 130 rpm, 17k Tq. Mud weight in/out 10.6 ppg. Obtain SPR's, P/U=203k, S/0=109k, ROT=156k. SPR's @ 13055' MD, 5214'TVD, 10.6 ppg, 02:45 hrs #1-20 spm=200 psi, 30 spm=300 psi #2-20 spm=200 psi, 30 spm=290 psi 03:00 05:00 2.00 13,054 12,420 INTRM1 CASING BKRM P BROOH, MAD passing @ 600 fph from 13054' MD to 12420' MD, 625 gpm, 3040 psi,44%flow out, 130 rpm, 17k Tq. Observe 600 units of gas at bottoms up(11,052 stks)after 10 minute monitor. Decision made to weight up to 10.7 ppg. 05:00 07:45 2.75 12,420 12,200 INTRM1 CASING BKRM P Continue BROOH, reduce speed to 90 fph while increasing density to 10.7 ppg from 12420' MD to 12200' MD, 575 gpm, 2700 psi,40%flow out, 130 rpm, 17k Tq, Mud weight in/out 10.7 ppg, obtain SPR's. SPR's @ 12203' MD,4995'TVD, 10.7 ppg, 07:45 hrs #1-20 spm=200 psi, 30 spm=280 psi #2-20 spm=200 psi, 30-spm=280 psi 07:45 12:00 4.25 12,200 11,452 INTRM1 CASING BKRM P BROOH while MAD pass @ 600 fph, 12200' MD to 11452'MD, 575 gpm, 2650 psi, 40%flow out, 140 rpm, 17k Tq. 12:00 18:00 6.00 11,452 10,300 INTRM1 CASING BKRM P Continue BROOH/MAD pass @ 600 fph from 11452' MD to 10300'MD, 4473'TVD @ 648 gpm, 3247 psi, 140 rpm, 16k tq, ECD=11.62 ppg, wiping tight spots @ 10973' MD, 10888' MD, 10784' MD,10608' MD, 10595' MD, 10463' MD. Reaming then sliding through each with no pump or rotary. 18:00 20:30 2.50 10,300 10,300 INTRM1 CASING CIRC P CBU x 3,total 23000 stks, @ 650-675 gpm, 140-160 rpm, 2907 psi, reciprocate string from 10311' MD to 10230' MD. ECD=11.52-11.6 ppg EMW. 20:30 21:00 0.50 10,300 10,300 INTRM1 CASING OWFF P Blow down topdrive, monitor well for 30 minutes-Static. P/U=180k, S/0=120k. P, Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 10,300 10,248 INTRM1 CASING PULD P Attempt to POOH sideways on elevators from 10311' MD, lay 1 double down to pipe shed, pull tight @ 10,248'MD. Pulled 30k over P/U weight unable to move pipe up. Slack off, kelly up and establish circulation. 21:30 00:00 2.50 10,248 9,549 INTRMI CASING BKRM P Continue BROOH from 10248'MD to 10216'MD, L/D single for even stands. BROOH from 10216' MD to 9549'MD,648 gpm,3065 psi,44% flow out, 140 rpm 13k Tq, pulling approx 40 fpm no packoff issues. 01/30/2015 Continue to backream out to 7275' MD. POOH on elevators to 4238'. Backream out to 4063'. POOH on elevators to shoe. Clean casing with well commander. Monitor hole,static. POOH on elevators to BHA. Lay Down BHA. Test BOPE per AOGCC and CPAI requirements,witnessed by AOGCC Representative Johnnie Hill. 00:00 04:15 4.25 9,549 8,420 INTRMI CASING BKRM P Continue Backreaming out of hole from 9549'to 8265' MD at 650 gpm, 2860 psi, 44% FO, 140 rpm, 13k Torque,40 FPM pulling speed. Encounter tight spots @ 8345'to 8320' MD. Ream 3 times. Rub down without pumps or rotation. Encounter tight spot at 8301'to 8265'MD. Unable to Ream through area. Attempt to pull through with 200 gpm and no rotary, pull 40 k over 3 times. Decision made to RIH 1 stand and circulate. 04:15 05:15 1.00 8,420 8,325 INTRM1 CASING CIRC T CBU while Rotate and Recip from 8420'to 8325'MD at 700 gpm @ 3210 psi, 47% FO, 160 rpm, 11k Torque. 05:15 07:15 2.00 8,325 8,199 INTRM1 CASING BKRM P Attempt to Backream From 8325'to 8199' MD at 650 gpm,2960 psi,44% FO, 140 rpm, 12k Torque,. Encounter-/+ 140 psi packoffs @ 8233'and 8199'MD.Attempt to work through with reduced flow rate. 07:15 08:00 0.75 8,199 8,225 INTRM1 CASING CIRC T CBU while Rotating and Recip from 8320'to 8225'MD at 690 gpm, 3170 psi,47% FO, 160 rpm, 12k Torque. 08:00 11:00 3.00 8,225 7,275 INTRMI CASING BKRM P Backeream form 8225'to 7275' MD at 660 gpm, 2860 psi,44% FO, 130 rpm, 12k Torque. Encountered 400 psi packoff @ 8265' MD. Run back through and clean up(hole fill trending to 5 bbls/5 stands). 11:00 12:00 1.00 7,275 5,764 INTRM1 CASING TRIP P TOOH on elevators. Hole taking slightly more fill than calculated (4 bbls/5 stands average). 12:00 12:30 0.50 5,764 4,238 INTRM1 CASING TRIP P TOOH on elevators.Well taking proper fill. Page 33 of 52 Time Logs ! l Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:30 1.00 4,238 4,063 INTRM1 CASING BKRM P Kelly Up, establish parameters after pulling 40k over @ 4238'MD. Backream from 4238'to 4063'MD at 650 gpm, 2550 psi,46% FO, 130 rpm, 9k Torque.Wipe tight spot without rotation. 13:30 15:00 1.50 4,063 2,554 INTRM1 CASING TRIP P POOH on elevators from 4063'to 2554' MD.Well taking slightly more fluid than calculated fill. No tight spots. 15:00 16:00 1.00 2,554 2,554 INTRM1 CASING CIRC P Open well commander with 2.115" activation ball. Staging pressure up 1000, 1500,2000 psi.Well Commander opens @ 2150 psi. CBU (x2)at 800 gpm, 1235 psi, 54% FO, 60 rpm, 2K Torque. Recip pipe from 2554'to 2460' MD. Drop second ball to close Well Commander. Stage up 1000, 1500,2000,2500, 3000 psi. Shift seen @ 3200 psi but indications are that well commander is still open. Decision made to POOH. 16:00 16:30 0.50 2,554 2,554 INTRM1 CASING OWFF P Monitor well. Static, No gains, no losses. 16:30 18:15 1.75 2,554 753 INTRM1 CASING TRIP P TOOH to BHA.Well taking slightly more fluid that calculated. 18:15 18:30 0.25 753 753 INTRM1 CASING OWFF P Monitor well prior to BHA. Static. 18:30 20:00 1.50 753 0 INTRM1 CASING BHAH P Stand Back HWDP and Jars, C/O slip inserts, LD Well Commander to rig floor, LD Saver Sub and Drill Collars, Lay down sources in MWD tools, LD MWD tools, Ecosope, Pull and break out bit, LD Pony collar and power drive. 20:00 21:30 1.50 0 0 INTRM1 CASING BHAH P Clean and clear rig floor. LD Well Commander, Pony collars and Misc BHA tools. 21:30 23:00 1.50 0 0 INTRM1 WHDBO RURD P Rig Up equipment and lines to test BOPE. Drain Stack, Pull Wear Bushing, Install Test Plug. 23:00 00:00 1.00 0 0 INTRM1 WHDBO BOPE P Test BOPE per AOGCC and CPAI regulations.Test witnessed by AOGCC Representative Johnnie Hill. Test all components to 250/3500 psi. Test with 5"and 7 5/8"test joints. 31/31/2015 Complete BOPE test. R/U and run 7 5/8"casing to 5183'MD, circulate @ casing shoe and 4600' MD casing volume. Page 34 of 52 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 INTRMI WHDBO BOPE P Test all BOPE to 250/3500 psi 5 min ea charted.AOGCC Johnnie Hill witnessed test. 5"test joint tested annular, 2-7/8"x5%"lower rams, 7-5/8"test joint tested annular, 7-5/8"upper rams, tested choke valves 1-15, manual and super choke (2000 psi), choke and kill manuals and HCRs.4"valve on kill line, 5" TIW#1, 5"Dart valve, upper and lower!BOP, blind rams. 04:00 04:30 0.50 0 0 INTRM1 WHDBO BOPE P Performed Koomey test. System pressure=3000 psi, Manifold pressure=1500 psi, Pressure after function all rams=1800 psi,200 psi attained=20 sec,full pressure attained=91 sec.6 bottle N2 average 2088 psi. Closing times:Annular=23 sec, UPR=18 sec, Blinds 16 sec, LPR= 16 sec, Choke HCR=2 sec, Kill HCR=2 sec. 04:30 05:15 0.75 0 0 INTRM1 WHDBO RURD P Blow down and rig down all test equipment, pull test plug, blow down hole fill line and rig down. 05:15 07:30 2.25 0 0 INTRM1 CASING RURD P Rig up casing equipment,tongs and Volant CRT. SIMOPS=pull strip-o-matic and CIO air boots on flow line nipple.Verify pipe and centrilizer count. 07:30 08:00 0.50 0 0 INTRMI CASING SVRG P Serrvice and inspect top drive. 08:00 10:00 2.00 0 0 INTRM1 CASING RGRP T Mobilize master bushings and inserts to rig floor, C/O with PS-21 slips due to locked up hydraulic valve. 10:00 12:00 2.00 0 328 INTRM1 CASING PUTB P PJSM, M/U 7-5/8"shoe track,test floats-Good. Run 7-5/8"39#TN110S Hydril 563 casing to 328'MD, filling on the fly with fill up hose, 1 centralizer per joint. 12:00 17:30 5.50 328 2,601 INTRM1 CASING PUTB P Continue running 7-5/8"L-80 Hydril 563 casing as per detail from 328' MD to 2601'MD, filling on the fly,top off every 10 joints with Volant CRT. Trip sheet trending 2 bbl gain per 10, 4 bbl calculated. Tenaris thread hand inspecting each connection, run one centralizer per joint for#1-#93. 17:30 18:00 0.50 2,601 2,601 INTRMI CASING CIRC P CBU inside casing shoe,stage pumps up to 7 bpm, 189 psi, 27% flow out, no losses while circulating. 18:00 22:00 4.00 2,601 4,623 INTRM1 CASING PUTB P Continue RIH from 2601'MD to 4623' MD. Slow running speed from 70 fpm to 45 fpm due pushing fluid away. Good displacement @ 45 fph. 22:00 23:00 1.00 4,623 4,623 INTRMI CASING CIRC P CBU @ 4623' MD, stage pumps up to 6 bpm, full circulation pump total 2600 stks, 260 psi 29%flow out. Page 35 of 52 Time Logs • • I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 4,623 5,183 INTRM1 CASING PUTB P Continue RIH with casing from 4623' MD to 5183' MD,good displacement. 02/01/2015 Continue running 7-5/8"casing to joint 328, CBU prior to P/U hanger per program. 3 bad joints swapped out. Ran total 10 jts 39#, 318 jts 29.7#, 120 centralizers. 00:00 03:00 3.00 5,183 6,808 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 5183'MD to 6808' MD, filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3 03:00 04:30 1.50 6,808 6,808 INTRM1 CASING CIRC P Circulate casing volume while reciprocating from 6767' MD,to 6808' MD,stage pumps up to 6 bpm, 300 psi,29%flow out. condition mud to 10.7 ppg in/out.2 bpm=200 psi 13%, 3 bpm=220 psi 19%,4 bpm=245 psi 25%, 5 bpm=275 psi 28%. FCP @ 6 bpm=265 psi 27%,total strokes pumped 4071. 04:30 08:15 3.75 6,808 8,873 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 6808'MD to 8873' MD,filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3 08:15 09:30 1.25 8,873 8,873 INTRM1 CASING CIRC P Circulate bottoms up while reciprocating from 8840'MD,to 8873' MD, stage pumps up to 6 bpm, 385 psi, 33%flow out. Condition mud to 10.7 ppg in/out.2 bpm=250 psi 13%, 3 bpm=280 psi 21%,4 bpm=310 psi 26%, 5 bpm=345 psi 30%. FCP @ 6 bpm=380 psi 28%,total strokes pumped 3900. P/U @ 2 bpm=200k, S/O=95k. 09:30 10:30 1.00 8,873 9,328 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 8873'MD to 9328' MD, filling on the fly and topping off every 10 jts, identified bad joint pin seal area joint#222. 10:30 11:00 0.50 9,328 9,328 INTRM1 CASING PULD T L/D jt#222(41.71')replace with joint #A(43.08')Circulate @ 2 bpm while swapping out joints. 11:00 13:15 2.25 9,328 10,520 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 9328' MD to 10,520' MD,filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3. Identify bad joint pin seal area joint#251. 13:15 13:30 0.25 10,520 10,520 INTRM1 CASING PULD T L/D jt#251 (41.60')replace with joint #G(37.89')Circulate @ 3.5 bpm while swapping out joints. Page 36 of 52 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:30 1.00 10,520 10,930 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 10520'MD to 10,930'MD 45-60 fpm, filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3. 14:30 15:30 1.00 10,930 10,930 INTRM1 CASING CIRC P Circulate bottoms up while reciprocating from 10900'MD,to 10930'MD, stage pumps up to 6 bpm. P/U @ 3 bpm=208k, S/O @ 3 bpm=108k. Mostly sand on shakers. 15:30 18:30 3.00 10,930 12,302 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 10,930' MD to 12,302' MD 45-60 fpm, filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3. 18:30 20:00 1.50 12,302 12,302 INTRM1 CASING CIRC P Circulate bottoms up while reciprocating from 12302' MD,to 12270' MD, stage pumps up to 6 bpm 503 psi, 33%flow out. Mostly sand on shakers. 20:00 21:30 1.50 12,302 13,271 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 12,302' MD to 13,271'MD 45-60 fpm, filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3. Bad threads on joint#318. 21:30 22:00 0.50 13,271 13,271 INTRM1 CASING PULD T L/D jt#318(42.63')replace with joint #B(43.25')Circulate @ 4 bpm 420 psi,25%flow while swapping out joints. 22:00 22:30 0.50 13,271 13,724 INTRM1 CASING PUTB P Continue running 7-5/8"29.7#L-80 Hydril 563 intermediate casing per running order from 13,271'MD to 13,724'MD 45-60 fpm, filling on the fly and topping off every 10 jts. Monitor displacement with pits 2-3. Total 328 joints, 120 centralizers, no problems, no tight spots, no losses. 22:30 00:00 1.50 13,724 13,724 INTRM1 CASING CIRC P Circulate bottoms up staging pumps up to 6 bpm, 251 psi,27%flow out, P/U=250k, 5/0=105k with pumps on. 32/02/2015 P/U hanger and condition for cement, R/U and cement casing.Annular flush and Freeze Protect, L/D 5"DP. Send AOGCC notification for testing 2/3/15. 00:00 00:15 0.25 13,724 13,724 INTRM1 CASING CIRC P Continue CBU while reciprocating from 13,680'to 13,720'MD 6 bpm, 625 psi,29%flow, P/U=250k, S/0=105k,total strokes 5525. 00:15 00:45 0.50 13,724 13,763 INTRM1 CASING HOSO P Drain stack, P/U and M/U hanger and landing joint. Land casing with Cameron rep to verify landing. Page 37 of 52 Time Logs ! Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:45 03:00 2.25 13,763 13,763 INTRM1 CEMEN-CIRC P CBU staging pumps up to 7 bpm, 545 psi, 30%flow out while reciprocating casing from 13,762'to 13,747'MD. P/U=240k, S/0=105k, total strokes pumped 6200. 03:00 03:45 0.75 13,763 13,763 INTRM1 CEMEN-RURD P Blow down top drive, M/U cement hose. 03:45 05:15 1.50 13,763 13,763 INTRM1 CEMEN-CIRC P Continue circulating via cement hose while SLB rigged up. 7 bpm,675 psi, 29%flow out. P/U=250k, S/O=110k, total strokes 7530. 05:15 05:45 0.50 13,763 13,763 INTRM1 CEMEN-SFTY P PJSM on cementing operations with SLB, MI,WSL and Doyon crew. 05:45 10:00 4.25 13,763 13,763 INTRM1 CEMEN CMNT P Swap to SLB, pump 5 bbl CW100, test trips @ 3000 psi,test to 4000 psi-good. Pump remaining 35 bbl CW100 @ 5 bpm,530 psi, pump 38.6 bbl MudPush II @ 11.5 ppg,4.7 bpm,470 psi. Drop bottom plug, SLB pumped 214.8 bbl 15.8 ppg Cement, 5.5 bpm, 500 psi. Shut down drop top plug, SLB kick out with 10 bbl water, rig displaced with 6143 stks 10.7 ppg LSND. Bump plug @ 800 psi FCP, increase to 1300 psi and hold 5 min. Check floats-good. CIP @ 10:00. 10:00 11:00 1.00 13,763 13,763 INTRM1 CEMEN-RURD P R/D and B/D cement hose and Volant CRT, clean and clear rig floor. Send out casing running equipment. 11:00 12:00 1.00 13,763 13,763 INTRMI CEMEN WWSP P Drain stack, P/U stand of 5" HWDP, M/U 7-5/8"packoff, set packoff. 12:00 13:30 1.50 13,763 0 INTRM1 CEMEN-WWSP P Cameron set and test packoff to 250 psi low, 500 psi hi 10 minutes. 13:30 14:30 1.00 0 0 INTRM1 CEMEN-RURD P Lay down running tool, rack back stand HWDP, C/O slip inserts, hang blocks. 14:30 15:30 1.00 0 0 INTRM1 CEMEN SLPC P PJSM, slip and cut 102'drilling line, 13 wraps. SIMOPS-B/D cement line and clean valves. 15:30 16:00 0.50 0 0 INTRMI CEMEN-SLPC P Calibrate Amphion and Totco hookload&block height. 16:00 17:00 1.00 0 0 INTRM1 CEMEN-RURD P Set test plug and set mousehole in rotary table for laying down pipe 17:00 18:00 1.00 0 0 INTRM1 CEMEN PULD P PJSM, L/D DP from derrick, L/D doubles into pipeshed tubs, singles outside. 18:00 22:30 4.50 0 0 INTRM1 CEMEN-PULD P Continue laying down doubles(20) and singles, SIMOPS R/U on 10-3/4' x 7-5/8"annulus. Perform annular flush 103 bbl @ 2.5 bpm.Achieve injection rate 2.5 bpm, 1047 psi. Shut in static pressure 480 psi. Page 38 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 INTRM1 CEMEN-PULD P Rig up Little Red, perform freeze protection. Pumped 88 bbl ISOTHERM,stage pumps up to 2.7 bpm, 2000 psi FCP. SIMOPs; Continue laying down drill pipe, doubles(30), stands(53), 6 stands HWDP and jars. 02/03/2015 Continue to LD 5"DP. Change out saver sub and elevators. PU and stand back 4"drill pipe. Stage BHA components to rigfloor. RU for BOP test and perform body test; Good. 00:00 06:00 6.00 0 INTRM1 CEMEN-PULD P Continue to LD 5"drill pipe via mouse hole(48 stands). SIMOPs; change out UPR rams to 2 7/8"x 5 1/2"VBRs, clean pits,finish cleaning suction manifold on mud pumps. 06:00 10:45 4.75 INTRM1 CEMEN-PULD P Continue to LD 5"drill pipe via mouse hole(86 stands), LD mouse hole. SIMOPs; remove shaker bed on#3. 10:45 12:00 1.25 INTRM1 CEMEN-RURD P Change out saver sub from 4 1/2"IF to XT-39, grease IBOP. OA at 12:00=460 psi. Crew change. 12:00 13:00 1.00 INTRMI CEMEN RURD P Continue, finish change out of saver sub from 4 1/2"IF to XT-39. 13:00 14:00 1.00 INTRM1 CEMEN'RURD P PU 5" DP and pull test plug, pump out stack and set wear ring. SIMOPs; continue work with shaker bed for pits. 14:00 15:30 1.50 INTRM1 CEMEN-RURD P LD 5"DP and change out elevators, slip inserts, install Strip-O-matic, PU 4"DP double and install mule shoe, test slips and Strip-O-matic. 15:30 16:00 0.50 INTRM1 CEMEN-SVRG P Remove rotary table cover;function and inspect HYD motors, lines fittings, grease all zerts, clean and inspect seals, pressure wash and wipe out. Re-install cover. 16:00 17:00 1.00 INTRMI CEMEN BHAH P PU BHA components and stage to rig floor. 17:00 20:45 3.75 INTRM1 CEMEN PULD P PU 4"drill pipe,drifting with 2.25" drift. Monitor well via trip tank. 20:45 22:30 1.75 INTRM1 CEMEN-TRIP P Pull out and stand back 4" DP, 38 stands. 22:30 23:30 1.00 INTRM1 WHDBO RURD P PU 4"test joint, pull wear ring, set test plug. 23:30 00:00 0.50 INTRM1 WHDBO RURD P RU to test BOPE, install pump-in sub to test joint, MU floor valves,fill stack and manifold and perform body test; Good. Crew change. 02/04/2015 Complete BOP testing.Test witness waived by AOGCC John Crisp. RD testing equipment. PU and MU BHA#4. PU 4"drill pipe from shed to 9300'and turn on MWD to log TOC, continue TIH with singles from the shed. Page 39 of 52 Time Logs , Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 INTRM1 WHDBO BOPE P Test BOPE; 250/3500 psi to chart with 4"and 4 1/2"test joints, 2-7/8"x5'/z'lower rams,4 1/2"test joint tested annular, 2-7/8"x5'/z' upper rams,tested choke valves 1-15, manual and super choke(2000 psi), choke and kill manuals and HCRs.4"valve on kill line,4"TIW #1,4"Dart 3 1/2" IF TIW, 3 1/2"IF Dart valve, upper and lower IBOP, blind rams. Performed Koomey test: System pressure=3000 psi, Manifold pressure=1500 psi, Pressure after function all rams=1700 psi, 200 psi attained=19 sec,full pressure attained=101 sec. 6 bottle N2 average 1992 psi. Closing times:Annular=23 sec, UPR=18 sec, Blinds 16 sec, LPR= 16 sec, Choke HCR=2 sec, Kill HCR=2 sec. 04:00 04:45 0.75 0 0 INTRMI WHDBO RURD P RD testing equipment; pull test plug and LD test joint. 04:45 05:30 0.75 0 0 INTRM1 CEMEN-RGRP T Change out air boot on flow nipple. 05:30 06:00 0.50 0 0 INTRM1 CEMEN-SVRG P Service rig;top drive and inspect same, inspect blocks. SIMOPS; change out air boot on riser. 06:00 07:00 1.00 0 0 INTRMI CEMEN-BHAH P Stage tools, HW and BHA in shed. Put steam on the Impulse tool to enable programming due to temperature of pipe shed(-35F outside). 07:00 07:12 0.20 0 0 INTRMI CEMEN-SFTY P PJSM for BHA MU and PU. 07:12 09:00 1.80 0 138 INTRM1 CEMEN-BHAH P PU and MU BHA through MWD tools. 09:00 09:45 0.75 138 138 INTRM1 CEMEN-BHAH P Load radioactive sources. 09:45 11:30 1.75 138 521 INTRM1 CEMEN-BHAH P PU and MU NMDC,WC sub, HWDP and jars. 11:30 12:00 0.50 521 964 INTRM1 CEMEN-PULD P C/O slips and RIH with doubles from shed from 521'to 964'. OA psi at 12:00=340. Crew change. 12:00 13:00 1.00 964 1,496 INTRM1 CEMEN-PULD P RIH with doubles from shed from 964' to 1496. 13:00 13:30 0.50 1,496 1,496 INTRMI CEMEN-DHEQ P Shallow test MWD; Good. 13:30 15:45 2.25 1,496 4,316 INTRM1 CEMEN'PULD P Continue to PU double from the shed from 1496'to 4316'. 15:45 23:00 7.25 4,316 9,240 INTRM1 CEMEN-PULD P RIH with singles from the shed from 4316'to 9240'. 23:00 00:00 1.00 9,240 9,240 INTRMI CEMEN-CIRCP Circulate to condition mud to downlink and turn on MWD tool to log TOC. 02/05/2015 Single in the hole performing sonic logging for TOC at 16 ft/min. Perform 3000 psi casing test for 30 minutes; Good. Drill shoe track and 20 of new hole to 13795'and displace to new mud. C&C for FIT test. Page 40 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 9,240 11,580 INTRM1 CEMEN-PULD P RIH with singles from the shed from 9240'to 11,580'at 880 ft/hr for logging to delineate the TOC. Re-calibrate depth tracking systems; rig and MWD. OA pressure=500 psi @ 0600. 06:00 10:15 4.25 11,580 13,522 INTRMI CEMEN-PULD P RIH with singles from the shed from 11,580'to 13522'at 880 ft/hr for logging to delineate the TOC. 10:15 11:30 1.25 13,522 13,522 INTRM1 CEMEN CIRC P Circulate string volume with rotary and recip from 13428'to 13518', staging pumps to 220 GPM with 2450 psi, 25% FO, 50 RPM with 8.5 torque. PU= 140K, S0=95K, Rot= 122K. Total strokes pumped 1770. Obtain SPR and blow down top drive. 11:30 12:00 0.50 13,522 13,522 INTRM1 CEMEN RURD P RU to test casing,flush lines,test lines'Good. Crew change. 12:00 13:00 1.00 13,522 13,522 INTRM1 CEMEN-PRTS P Test casing to 3000 psi for 30 minutes to chart. Good test. 13:00 13:30 0.50 13,522 13,671 INTRMI CEMEN COCF P Wash in the hole to tag cement from 13522'to 13671'. Tag plugs at 13671'with 4K down weight, PU and confirm depth. 13:30 14:45 1.25 13,671 13,711 INTRM1 CEMEN-DRLG P Drill plugs and float collar with 180 GPM with 1780 ps, 27% FO,40 RPM with 8K torque. 14:45 18:15 3.50 13,711 13,711 INTRM1 CEMEN CIRC T Circulate out thick clabbered mud, MWD lost signal, high torque and string movement needed to keep rotating, Thick mud filling flowline, continue to circulate and condition mud at 220 GPM with 2460 psi, 29% FO,40 RPM with 8K torque, At bottoms up with 220 GPM 3306 psi, 25%FO,40 RPM with 16K torque. 18:15 19:00 0.75 13,711 13,764 INTRM1 CEMEN-REAM T Wash and ream from 13711'to 13764' with 220 GPM 3200 psi, 23% FO,40 RPM with 15K torque. 19:00 19:45 0.75 13,764 13,775 INTRM1 CEMEN DRLG P Drill out shoe(13,764')to 13775'at 220 GPM with 3025 psi, 22%FO, 60 RPM with 16K torque,4-10K WOB 19:45 20:15 0.50 13,775 13,795 INTRM1 CEMEN-DDRL P Drill new hole from 13775'to 13795' at 220 GPM with 3025 psi, 22% FO, 60 RPM with 16K torque,4-14K WOB. 20:15 22:45 2.50 13,795 13,795 INTRMI CEMEN-DISP P Displace hole to new drilling mud; 10.0 ppg having to slow the pumps to 190 GPM with 2010 psi, 80 RPM iwth 15K torque. Vac trucks freezing having to divert returns to pits. 22:45 00:00 1.25 13,795 13,795 INTRM1 CEMEN'CIRC P Circulate and condition new mud for FIT test to 10.0 in and out for FIT 32/06/2015 RU and perform FIT to 15.7 EMW. Clean pits and chase old mud from all lines and pumps. Bring on new mud. Drill ahead to 14,658'. Page 41 of 52 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 00:45 0.75 13,795 13,795 INTRM1 CEMEN-CIRC P Circulate and condition mud for FIT. RU for testing. 00:45 01:30 0.75 13,795 13,795 INTRM1 CEMEN-FIT P Perform FIT to 15.7 EMW with 10.0 ppg mud. 01:30 05:30 4.00 13,795 13,795 PROD1 DRILL CIRC T Circulate and condition mud,take old mud off rig and clean pits of old clabbered mud. Circulate old clabbered mud from flow line, shaker sumps,troughs, suction and discharge lines and pumps with water and Desco pills. 02:00 Crew change. 05:30 06:00 0.50 13,795 13,795 PROD1 DRILL REAM P Wash in the hole from 13711 to 13795'with 240 GPM with 1900 psi, 30%FO, 60 RPM with 12 torque. PU= 165K, SO=85K, Rot= 112K. 06:00 12:00 6.00 13,795 14,184 PROD1 DRILL DDRL P Drill from 13795'to 14184'with 240 GPM with 2410 psi, 31% FO, 120 RPM with 13.5K torque, 15K WOB, ECD= 11.23. PU= 176K, SO=82K, Rot= 115K. ADT/ART=4.18, Bit hours=4.38, Jar hours=4.38. SIMOPS; clean pits of old mud. OAP=590 psi 15:00 12:00 14:00 2.00 14,184 14,245 PROD1 DRILL DDRL P Drill from 14184'to 14245'with 240 GPM with 2350 psi, 31% FO, 120 RPM with 12K torque, 15K WOB, ECD= 11.38. PU= 165K, SO=92K, Rot= 114K. 14:00 16:00 2.00 14,245 14,245 PROD1 DRILL CIRC T Trouble-shoot MWD signal loss. Cycle pumps,vary flow and attempt downlinks. 16:00 20:00 4.00 14,245 14,467 PROD1 DRILL DDRL P Drill from 14245'to 14467'with 240 GPM with 2472 psi, 30%FO, 110 RPM with 12K torque, 15K WOB, ECD= 11.47. PU= 155K, SO=95K, Rot= 121K. ADT/ART=2.97, Bit hours=7.8,Jar hours=7.8. 20:00 20:45 0.75 14,467 14,467 PROD1 DRILL OTHR P Preventative maintenance step to swap out frozen transducer from standpipe. 20:45 00:00 3.25 14,467 14,658 PROD1 DRILL DDRL P Drill from 14467'to 14658'with 240 GPM with 2472 psi, 30% FO, 110 RPM with 12K torque, 15K WOB, ECD= 11.47. PU= 155K, SO=95K, Rot= 121K. ADT/ART=2.97, Bit hours=7.8,Jar hours=7.8. 02/07/2015 Drill ahead to 16,084'. Geo-steering to remain in the Bermuda formation. ECD building from 11.6 to 11.9 EMW. Drilling with expected parameter changes. 00:00 03:00 3.00 14,658 14,845 PROD1 DRILL DDRL P Drill from 14658'to 14845'with 240 GPM with 2460 psi,29% FO, 110 RPM with 13K torque, 12K WOB, ECD= 11.62. PU= 145K, SO=94K, Rot= 125K. 03:00 03:45 0.75 14,845 14,845 PROD1 DRILL CIRC T Troubleshoot rig pumps Page 42 of 52 Time Logs 11111 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:45 04:30 0.75 14,845 14,940 PROD1 DRILL DDRL P Drilling14845'to 14940'with 240 GPM with 2420 psi,29% FO, 110 RPM with 13K torque, 13K WOB, 04:30 05:15 0.75 14,940 14,940 PROD1 DRILL CIRC P DD downlink off bottom, confirm downlink acceptance prior to geosteering ahead. 05:15 06:00 0.75 14,940 14,991 PROD1 DRILL DDRL P Drill from 14940'to 14991'with 240 GPM with 2460 psi, 29% FO, 110 RPM with 13K torque, 12K WOB, ECD= 11.62. PU= 145K, SO=92K, Rot= 123K. 06:00 10:00 4.00 14,991 15,225 PROD1 DRILL DDRL P Drill from 14991'to 15225'with 240 GPM with 2490 psi,28%FO, 110 RPM with 13K torque, 15K WOB, ECD= 11.66. PU= 149K, SO=92K, Rot= 120K. SIMOPS; mobilize shaker bed to pits and to shakers. 10:00 10:45 0.75 15,225 15,225 PROD1 DRILL CIRC P DD downlink off bottom, confirm downlink acceptance prior to geosteering ahead. 10:45 12:00 1.25 15,225 15,323 PROD1 DRILL DDRL P Drill from 15225'to 15323'with 240 GPM with 2490 psi,28% FO, 110 RPM with 13K torque, 15K WOB, ECD= 11.66. PU= 149K, SO=92K, Rot= 120K. ADT/ART=6.11, Bit hours= 15.28, Jar hours= 15.28. SIMOPS; mobilize shaker bed to pits and to shakers. Crew change. 12:00 14:30 2.50 15,323 15,510 PROD1 DRILL DDRL P Drill from 15323'to 15664'with 240 GPM with 2580 psi, 30% FO, 110 RPM with 14K torque, 12K WOB, ECD= 11.66. PU= 171K, SO=80K, Rot= 126K. ADT/ART=2.41, Bit hours= 17.69, Jar hours= 17.69. 14:30 15:30 1.00 15,510 15,510 PROD1 DRILL CIRC P Tool missed downlink commands due to attenuated signal, resent commands with 20-25%flow variation. Also DD downlinked off bottom, confirm downlink acceptance prior to geosteering ahead. 15:30 18:00 2.50 15,510 15,664 PROD1 DRILL DDRL P Drill from 15323'to 15664'with 240 GPM with 2580 psi, 30%FO, 110 RPM with 14K torque, 12K WOB, ECD= 11.66. PU= 171K, SO=80K, Rot= 126K. ADT/ART=2.41, Bit hours= 17.69,Jar hours= 17.69. 18:00 00:00 6.00 15,664 16,084 PROD1 DRILL DDRL P Drill from 15664'to 16084'with 240 GPM with 2640 psi, 30% FO, 120 RPM with 13K torque, 12K WOB, ECD= 11.66. PU= 171K, SO=80K, Rot= 126K. ADT/ART=2.41, Bit hours= 17.69, Jar hours= 17.69. OAP=640 psi Crew change. 02/08/2015 Drilling ahead at 16,507'at report time. Drill to TD at 17,095'per Geologist. CBU 3X and BROOH to shoe. Drop Well Commander ball and open circ sub. Page 43 of 52 Time Logs III Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 16,084 16,556 PROD1 DRILL DDRL P Drill from 16084'to 16556'with 240 GPM with 2705 psi, 31% FO, 130 RPM with 13K torque, 12K WOB, ECD= 12.00. PU= 161K, S0=82K, Rot= 125K. From 00:00 MWD could not downlink from the MWD/DD computers all downlinks had to be done manually from the driller's console. OAP=510 @ 0030 hours 06:00 11:30 5.50 16,556 17,095 PROD1 DRILL DDRL P Drill from 16556'to 17095'with 240 GPM with 2785 psi, 30%FO, 130 RPM with 13K torque, 10K WOB, ECD= 12.16. PU= 171K, S0=80K, Rot= 126K. ART/ADT=7.22, Bit hours=28.03, Jars hours=28.03. 11:30 12:00 0.50 17,095 17,095 PROD1 CASING SRVY P • Obtain TD survey, SPR's and begin CBU. OAP 600 psi @ 1200 hours Crew change. 12:00 16:15 4.25 17,095 16,827 PROD1 CASING CIRC P Circulate BU at 240 GPM with 2760 psi,30%FO, RPM 130 with 10.5K torque. PU= 162K, S0=84K, Rot= 116K. Total strokes pumped 15051. 16:15 16:45 0.50 16,827 16,827 PROD1 CASING OWFF P Blow down top drive and observe well for flow; Static. 16:45 23:00 6.25 16,827 13,307 PROD1 CASING BKRM P BROOH from 16827'to 13307'at 240 GPM with ICP 2740 psi, FCP 2440 psi. 23:00 23:45 0.75 13,307 13,307 PROD1 CASING CIRC P Drop ball to open Well Commander circ sub; open at 1500 psi. Confirm open with pressure comparison. 23:45 00:00 0.25 13,307 13,307 PROD1 CASING CIRC P Circulate BU with circ sub open at 340 GPM with 2000 psi, 70 RPM with 8K torque, 30%FO. PU= 141K, SO= 105K. OAP=510 psi©0000 hours. Crew change. 02/09/2015 CBU 2X with circ sub open,drop ball and close WC sub. Cut and slip drill line, Pump out to 29.7#casing. Drop rabbit and POOH on elevators. LD BHA. Test BOPE: Test witness waived by Jeff Jones AOGCC rep. Test BOPE; 250/3500 psi to chart with 3 1/2",4"and 4 1/2"test joints, 2-7/8"x5'/z'upper and lower rams. RU to run 4 1.2"liner. 00:00 01:30 1.50 13,307 13,709 PROD1 CASING CIRC P CBU 2X with WC circ sub open with rotation and recip from 13615'to 13709'at 340 GPM with 1990 psi, 39%FO, 80 RPM with 8K torque for 8469 strokes. 01:30 02:30 1.00 13,709 13,709 PROD1 CASING CIRC P Drop ball to close WC and pump down at 2 BPM with 490 psi, 10% FO, ball on seat with 733 strokes. Increase pressure to 1000 psi and hold for 30 seconds,then increse pressurewith WC shifting closed at 1500 psi. Confirmed WC closed with 240 GPM with 2130 psi. Page 44 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:00 0.50 13,709 13,709 PROD1 CASING OWFF P Observe well for flow; Static. SIMOPs; PJSM for slip and cut. Hang blocks for S&C. 03:00 04:30 1.50 13,709 13,709 PROD1 CASING SLPC P Slip and cut drill line,68 feet. Calibrate depth systems and monitor well via trip tank; Static. 04:30 05:00 0.50 13,709 13,709 PROD1 CASING SVRG P Service top drive and block, check corn. 05:00 05:30 0.50 13,709 13,329 PROD1 CASING PMPO P Pump out of the hole to pull into the #29.7 casing,from 13709'to 13329' at 2 BPM with 290 psi and 5%FO. 05:30 06:00 0.50 13,329 13,329 PROD1 CASING RURD P Drop 2.4"rabbit with 100'of wire, pump dry job and blow down top drive. 06:00 12:00 6.00 13,329 995 PROD1 CASING TRIP P POOH on elevators from 13329'to 995'with proper displacement. OAP=400 psi at 1130. Crew change. 11 BBLs loss this tour. 12:00 13:00 1.00 995 521 PROD1 CASING TRIP P POOH on elevators from 995'to 521' with proper displacement. 13:00 15:30 2.50 521 0 PROD1 CASING BHAH P Change out slip inserts,to hand slips. LD BHA#5 as per SLB DD and MWD. 15:30 17:00 1.50 0 0 COMPZ CASING BHAH P Clean and clear floor of BHA components. SIMOPs; rise out stack with flush tool. 17:00 17:30 0.50 0 0 COMPZ WHDBO RURD P Pull wear bushing and install test plug. SIMOPs; MU 3 1/2"floor valve and dart. MU XT39 floor valves and dart. 17:30 18:00 0.50 0 0 COMPZ WHDBO RURD P RU for BOP testing. 18:00 22:30 4.50 0 0 COMPZ WHDBO BOPE P Test witness waived by Jeff Jones AOGCC rep. Test BOPE; 250/3500 psi to chart with 3 1/2",4"and 4 1/2" test joints, 2-7/8"x5'/2'lower rams,4 1/2"test joint tested annular, 2-7/8"x5'/z"upper rams,tested choke valves 1-15, manual and super choke(2000 psi), choke and kill manuals and HCRs.4"valve on kill line,4"TIW#1,4" Dart 3 1/2"IF TIW, 3 1/2" IF Dart valve, upper and lower IBOP, blind rams. Performed Koomey test: System pressure =3000 psi, Manifold pressure=1500 psi, Pressure after function all rams=1700 psi, 200 psi attained=20 sec,full pressure attained=95 sec. 6 bottle N2 average 2004 psi. Closing times:Annular=24 sec, UPR=17 sec, Blinds 18 sec, LPR= 18 sec, Choke HCR=2 sec, Kill HCR=2 sec. 22:30 23:00 0.50 0 0 COMPZ WHDBO RURD P Pull test plug and install 10"wear bushing. i Page 45 of 52 J Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ CASING RURD P RU to run 4 1/2"liner. 02/10/2015 Continue to RU to run 4 1/2"liner, prep pipe shed and stage completion. Running liner per running order. 00:00 02:00 2.00 0 0 COMPZ CASING RURD P RU to run 4 1/2"liner, verify jewelry, jewelry position and staging, pipe counts. 02:00 10:30 8.50 0 3,494 COMPZ CASING PUTB P MU Orange Peel assembly and run liner per running detail. PU and MU 102 joints with 1 Perf pup, 7 swell packers, and 6 4 1/2" Frac sleeves. 10:30 11:30 1.00 3,494 3,494 COMPZ CASING RURD P Change out elevators to run in hole with drill pipe. PU hanger and MU Baker running tool as per Baker rep. MU up hanger assembly,drain stack, mix and pour PAL mix. Allow to set up. SIMOPs; PU drill pipe that would not rabbit on the way out of the hole and rabbit from the derrick. 11:30 12:00 0.50 3,494 3,772 COMPZ CASING RUNL P Change out slip inserts to 4". RIH with 4 1/2" 12.6#, L-80 liner on drill pipe. 12:00 14:15 2.25 3,772 3,772 COMPZ CASING CIRC T Circulate to attempt to balance mud at 5 BPM, 211 GPM with 315 psi. 29%FO 14:15 00:00 9.75 3,772 12,795 COMPZ CASING RUNL P Continue to RIH with 4 1/2"liner on drillpipe from 3772'to 12795'. Kelly up on each stand to prevent over flow of mud during running. 02/11/2015 Continue to run 4 1/2"liner per running order. Circulate at the shoe to condition mud in casing. RIH with liner to 16607'then lubricate liner down with 0.5 BPM minimizing rotation to TD. Set liner at 17093',displace to KW brine and POOH sideways. 00:00 01:15 1.25 12,795 13,744 COMPZ CASING RUNL P Continue to RIH with 4 1/2"liner on drill pipe from 12795'to 13744'. Kelly up on each stand to prevent over flow of mud during running. Proper displacement observed. 01:15 05:00 3.75 13,744 13,744 COMPZ CASING CIRC P Circulate BU 2X staging pumps to 1 BPM with 440 psi,2% FO, 2 BPM with 560 psi, 3 BPM with 415 psi,4- 880 psi, 5-970 psi with 27% FO. FCP at 4.8 BPM with 1005 psi, 26% FO, PU= 145K, SO=95K, Rot= 10K. 5 RPM=7.3K torque, 10 RPM =7.8K torque. 05:00 08:00 3.00 13,744 15,831 COMPZ CASING RUNL P Continue to RIH with 4 1/2" liner on drill pipe from 13744'to 15831'. Kelly up on each stand to prevent overflow. Proper displacement observed. 08:00 11:00 3.00 15,831 16,697 COMPZ CASING RUNL P RIH with 4"HWDP drill pipe. RIH from 15831'to 16260'and work tight hole to 16607. Begin pumping 0.5 BPM with 510 psi to lubricate liner to 16697'. PU= 185K, SO=84K. Page 46 of 52 Time Logs 110 Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:00 12:00 1.00 16,697 16,856 COMPZ CASING RUNL P Continue to lubricate down liner with 0.5 BPM with 510 psi, 1% FO. PU= 185K, SO=84. Lubricate down from 16697'to 16856'. Proper displacement observed. OAP=210 psi @ 0030 hours Crew change. 12:00 13:00 1.00 16,856 17,095 COMPZ CASING RUNL P Continue to lubricate down liner with 0.5 BPM with 510 psi, 1%FO. PU= 185K, S0=84. Lubricate down from 16856'to 17095'on stand#135; 56' in on stand. Work string to find stretch at 9'. 13:00 14:15 1.25 17,095 17,093 COMPZ CASING CIRC P Set liner on depth at 17093'per Baker rep and Company rep. Circulate liner and drill pipe volume, staging pumps and pumping 2184 strokes; 18% FO. 0.5 BPM =555 psi 1 BPM =780 psi 2 BPM= 1008 psi 14:15 15:30 1.25 17,093 17,093 COMPZ CASING PACK P Drop ball and pump down with 3 BPM with 1002 psi, 19%FO. Pressure up to 2133 psi and hold for 5 minutes, PU 80K and SO 45K and pressure up to 2845 psi and hold with 60 down weight, 3 minutes then bleed off, failed to release. Pressure up to 3024 psi and hold, bleed, failed to release. Work up 224K and down 50K with 3200 psi hold, bleed and release with 166K pull indicated. Pick up 6 feet rotate and shear. Put 94K down to confirm packer set; Good. 15:30 15:45 0.25 17,093 17,093 COMPZ CASING PRTS P Test liner ZXP to 3000 psi for 10 minutes to chart; Good. 15:45 16:00 0.25 17,093 17,093 COMPZ WELLPF CIRC P Pressure up drill string to 4100 psi to shear ball seat. 16:00 16:15 0.25 17,093 13,620 COMPZ WELLPF CIRC P PU 10'to pull RS packoff and circulate tie back clean. End of liner running tools @ 13620'. 16:15 16:45 0.50 13,620 13,620 COMPZ WELLPF CIRC P Circulate and stage pumps to 8 BPM with 2186 psi. total strokes pumped 1841 (184 bbls). Hold Pre job safety meeting on displacement to 10.2 ppg NACL brine. 16:45 17:15 0.50 13,620 13,620 COMPZ WELLPF DISP P Displace hole with KW brine 10.2 ppg. 17:15 18:30 1.25 13,620 13,620 COMPZ WELLPF CIRC P Circulate and stage pumps to 10 BPM with 3156 psi. total strokes pumped 1841. 18:30 19:00 0.50 13,620 13,620 COMPZ WELLPF OWFF P BD top drive and observe well; Static. SIMOPs; clean shakers and pits. Page 47 of 52 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 21:00 2.00 13,620 13,620 COMPZ WELLPF CIRC P Circulate and recip pipe while cleaning casing with KW brine.at 513 GPM with 4020 psi, 39%FO, PU= 158K, SO= 100K. Pump 13063 total strokes(1311 bbls). 21:00 21:30 0.50 13,620 13,247 COMPZ WELLPF PULD P BD top drive and LD 4"DP in doubles from 13620'to 13247'. 21:30 22:30 1.00 13,247 12,380 COMPZ WELLPF PULD P LD 4"HWDP from 13247'to 12380'. 22:30 00:00 1.50 12,380 9,724 COMPZ WELLPF PULD P LD 4"DP from 12380'to 9724'with proper fill during trip. OAP=350 psi at 1230 hours Crew change 02/12/2015 Continue to LD drill pipe. RU for running 3 1/2"9.3#, L-80 EUE 8rnd tubing. PJSM and run completion per running detail. Terminate TEC wire to DH gauge, test good 00:00 03:00 3.00 9,724 6,027 COMPZ WELLPF PULD P Continue to LD DP from 9724'to 5620'. 03:00 03:30 0.50 6,027 6,027 COMPZ WELLPF RGRP T Change out link-tilt cylinder, function test; Good 03:30 04:00 0.50 6,027 6,027 COMPZ WELLPF SVRG P Service rig and top drive. 04:00 10:45 6.75 6,027 0 COMPZ WELLPF PULD P Continue to LD DP from 6027'to surface with proper fill. 10:45 11:15 0.50 0 0 COMPZ WELLPF BHAH P LD Baker running tools and change out slip inserts. Indication of shear and set of ZXP with running tool. 11:15 12:00 0.75 0 569 COMPZ WELLPF TRIP P Change out slip inserts and RIH with DP from derrick. Crew change. OAP=360 psi @ 0600 12:00 13:30 1.50 569 3,780 COMPZ WELLPF TRIP P RIH with 4" DP from derrick from 569' to 3780'. 13:30 17:15 3.75 3,780 0 COMPZ WELLPF PULD P LD 4" DP from 3780'to surface with proper fill observed. 17:15 18:00 0.75 0 0 COMPZ RPCOM RURD P RU and pull wear bushing. 18:00 19:00 1.00 0 0 COMPZ RPCOM WWWH P PU and wash out stack. LD stack washing tool, and blow down top drive. 19:00 20:00 1.00 0 0 COMPZ RPCOM PUTB P PU and MU Cameron tubing hanger and landing joint and perform dummy run, mark landing joint and LD. 20:00 21:30 1.50 0 0 COMPZ RPCOM RURD P RU to run 3 1/2"9.3#L-80 EUE 8rnd tubing. Monitor well while rigging up via TT. 21:30 22:00 0.50 0 0 COMPZ RPCOM SFTY P Hold PJSM with crew, Baker reps and SLB reps. Discuss pinch points, overhead loads, hand safety, procedure and running order for completion. 22:00 23:00 1.00 0 151 COMPZ RPCOM PUTB P PU tubing and RIH to 151'with WLEG, Locator, 2.75""D"nipple w/ RHC plug body, Baker Premier Packer and SLB DH gauge. 23:00 00:00 1.00 151 151 COMPZ RPCOM PRTS P Terminate TEC wire and pressure test gauge per SLB rep to 5000 psi for 10 minutes; Good. Page 48 of 52 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/13/2015 24 hr Summary Continue to PU and run 3 1/2"9.3#, L-80 EUE 8rnd tubing testing TEC and gauge operation every 1000'to 11335'with GLM#1 to#5. 00:00 10:00 10.00 151 4,453 COMPZI RPCOM PUTB P PU 3 1/2"9.3#, L-80 EUE 8rnd tubing with I-Wire and clamping every joint with 1/2 clamps on both sides of mandrels. Test gauge at 28 joints in; Good. Continue to PU and run tubing per running detail testing every 1000'. Run tubing to 4453'. Torque on connections 2240 ft-lbs. PU and MU GLM#1 to#3 with SOV. Crew change 10:00 12:00 2.00 4,453 5,410 COMPZ RPCOM PUTB P PU 3 1/2"9.3#, L-80 EUE 8rnd tubing with I-Wire and clamping every joint with 1/2 clamps on both sides of mandrels. Continue to PU and run tubing per running detail testing every 1000'. Run tubing to 5410'. Torque on connections 2240 ft-lbs. Crew change Loss of 7 BBL this tour. 12:00 22:00 10.00 5,410 10,507 COMPZ RPCOM PUTB P PU 3 1/2"9.3#, L-80 EUE 8rnd tubing with I-Wire and clamping every joint with 1/2 clamps on both sides of mandrels. Continue to PU and run tubing per running detail testing every 1000'. Run tubing to 10507'. Torque on connections 2240 ft-lbs. PU and MU GLM#4. Crew change 22:00 00:00 2.00 10,507 11,335 COMPZ RPCOM PUTB P PU 3 1/2"9.3#, L-80 EUE 8rnd tubing with I-Wire and clamping every joint with 1/2 clamps on both sides of mandrels. Continue to PU and run tubing per running detail testing every 1000'. Run tubing to 11335'. Torque on connections 2240 ft-lbs. PU and MU GLM#5. 02/14/2015 Continue to PU and run 3 1/2"9.3#, L-80 EUE 8rnd tubing and DS Nipple to 13327'. Space out and assemble hanger, MU TEC wire termination with feed through. Pump 154 BBLs CI,chase and place. Land hanger and RILDS. Test seals to 5000 psi; Good. Drop ball and rod, pump down to seat. Test tubing and IA to 3500 psi; Good. Shear SOV(3200 psi)and check flow both ways. Set BPV and test 1500 psi; Good. ND BOPE and NU adapter,test flange; Good to 5000 psi. SLB tie in TEC I-wire and test; Good. 00:00 04:00 4.00 11,335 13,541 COMPZ RPCOM PUTB P PU 3 1/2"9.3#, L-80 EUE 8rnd tubing with I-Wire and clamping every joint with 1/2 clamps on both sides of mandrels. Continue to PU and run tubing per running detail testing every 1000'. Run tubing to 13327'. Torque on connections 2240 ft-lbs. PU and MU DS Nipple. Page Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 04:30 0.50 13,541 13,546 COMPZ RPCOM HOSO P MU and RIH w/joints#432,#433 and #434 to tag up at 26.13'in on#434. No-Go at 13628'with 10K. SO to block weight to shear screws and verify tag at 26' in on#434. PU and verify tag again; Good. Calculate space-out and LD joints#434 to #432. PU= 114K, SO=60K. 04:30 06:15 1.75 13,546 13,546 COMPZ RPCOM HOSO P PU and MU space-out pups; 10.24' and 2.30',XO,4.5"joint, hanger pup and hanger to landing joint. 06:15 07:00 0.75 13,546 13,546 COMPZ RPCOM THGR P Splice TEC I-Wire though hanger and peform TP to 5000 psi; Good. 07:00 07:30 0.50 13,546 13,546 COMPZ RPCOM SFTY P PJSM for pumping corrosion inhibitor, RU for pumping. 07:30 09:00 1.50 13,546 13,624 COMPZ RPCOM CRIH P RIH to 3'above hanger and pump CI CRW-132 brine 154 BBL and chase with 80.2 BBL of clean brine. ICP at 3 BPM 435 psi, 14%FO, FCP at 3 BPM 415 psi, 14%FO. 09:00 09:30 0.50 13,624 13,627 COMPZ RPCOM THGR P Land hanger and RILDS with 400 ft-lbs torque per Cameron rep. 09:30 10:00 0.50 13,627 13,627 COMPZ RPCOM THGR P PT hanger seals to 5000 psi for 15 minutes,witnessed by CPAI rep Granville Rizek. 10:00 10:45 0.75 13,627 13,627 COMPZ RPCOM PACK P Drop ball and rod, let fall for 45 minutes. RU tubing and IA tests. Swap rig from high line to generators. Ball and rod length=9.28'with ball diameter of 1.30". Drop witnessed by Company rep. 10:45 12:00 1.25 13,627 13,627 COMPZ RPCOM PRTS P Perform pressure test on tubing to 3500 psi for 30 minutes to chart. Observe 80 psi fall off during test; Good. Bleed tubing to 1575 psi and pressure up IA to 3500 psi. Crew change. 6 BBL loss this tour. OAP=310 at 0800 hours. 12:00 12:45 0.75 13,627 13,627 COMPZ RPCOM PRTS P Continue perform pressure test on IA to 3500 psi with 15 psi loss during 30 minutes to chart. Bleed IA to 0 psi and bleed tubing to 0 psi. 5.7 BBL to pressure to 3500 psi. 12:45 13:45 1.00 13,627 13,627 COMPZ RPCOM OTHR P Pressure up on IA to 3200 psi to shear SOV. Circulate both ways to check SOV position. Reverse at 2 BPM with 1345 psi, forward 1.5 BPM with 700 psi decresing to 40 psi. Bleed off all pressure to 0 psi both sides. 13:45 14:30 0.75 13,627 0 COMPZ RPCOM RURD P LD landing joint, blow down all lines, pump out BOP stack. 14:30 15:15 0.75 0 0 COMPZ WHDBO MPSP P Set per Cameron'H'profile BPV. Pressure test BPV to 1500 psi for 15 minutes to chart; Good. 3.4 BBL to pressure to 1500 psi. Page 50 of 52 Time Logs 4110 I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 15:30 0.25 0 COMPZ WHDBO SFTY P PJSM for ND BOPE. 15:30 20:30 5.00 COMPZ WHDBO NUND P ND BOPE, blow down lines, pump out stack, pull PS-21 slip system, clean Joe's flow box. ND low pressure flow nipple, ND BOP stack ND 13 5/8"riser and stow on BOP deck, ND DSA, ND 13 5/8"x11" spool. 20:30 22:15 1.75 COMPZ WHDBO NUND P Clean up tubing hanger and adapter spool,clean out cellar box, MU Otis flange lifting cap to adapter spool. 22:15 23:30 1.25 COMPZ WHDBO NUND P NU adapter spool,torque adapter flange bolts to 2540 ft-lbs, Cameron test adapter flange to 5000 psi for 15 minutes test witnessed by Company rep Paul Smith. ND Otis flange. 23:30 00:00 0.50 COMPZ WHDBO NUND P SLB Camco tie-in TEC I-wire connection to adapter flange. Orient Swab valve 180°per 2L DSO Eric Cafmeyer. 32/15/2015 NU tree and test same. Orientation verified by 2L DSO. Perform tree test. Pull dart and TWC valve, pump Freeze Protect; 86 BBL, allow to equalize. Install BPV"H"style per Cameron. RDMO well. AOP=310 psi, IAP=50 psi,Tubing=0 psi. Rig Release at 12:00 2/15/2015 00:00 00:15 0.25 0 COMPZ WHDBO OTHR P Test TEC I-wire; Good. Finger print gauge and TEC I-wire to DH gauge. 00:15 02:15 2.00 COMPZ WHDBO NUND P NU tree and MU wing valve,torque same. 02:15 05:30 3.25 COMPZ WHDBO PRTS P Pressure test tree to 5000 psi; Good test with 80 psi loss for 15 minutes to chart. 05:30 06:30 1.00 COMPZ WHDBO MPSP P Pull dart and TWC as per Cameron wellhead tech. 06:30 08:00 1.50 COMPZ WHDBO FRZP P RU for freeze protect,test surface lines to 3000 psi. Freeze Protect well with 86 BBL of diesel at 1.5 BPM with ICP=410 psi and FCP= 690 psi. 08:00 10:15 2.25 COMPZ WHDBO FRZP P Put IA and tubing in communication and allow to equalize. TIP=0 psi, IAIP=420 psi. After 120 minutes; TP=285 psi, IA=285 psi. Bleed both IA and tubing to 140 psi and observe no pressure build. Depth of diesel 2014'MD, 1930'TVD. RD tubing hoses and blow down lines. SIMOPs; Remove Kelly hose, install bridle yokes and bridle lines. Prep to scope derrick for move. 10:15 11:30 1.25 COMPZ WHDBO MPSP P PU lubricator and test to 1500 psi; Good. Lubricate type'h'BPV per Cameron. Obtain final pressures before installation of BPV. LD lubricator. Page 51 of 52 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 DEMOB MOVE RURD P RDMO well. AOP=310 psi, IAP=50 psi, Tubing=0 psi. Rig Release at 12:00 2/15/2015 Perform derrick inspection prior to scoping derrick. RD, scope down derrick and break interconnects. Split casing module, power module and pump from pits and move pit module away from sub. Page 52 of 52 • • NADConversion Kuparuk River Unit Kuparuk 2L Pad 2L-308 Definitive Survey Report NAD 27 17 February, 2015 III Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: . 114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 2L-308(Bertha) Well Position +N/-S 0.00 usft Northing: 5,927,685.10 usfi Latitude: 70°12'48.171 N +E/-W 0.00 usft Easting: 461,034.21 usfi Longitude: 150°18'51.316 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 114.80 usft Wellbore 2L-308 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 12/12/2014 18.82 80.78 57,551 Design 2L-308 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.00 Vertical Section: Depth From(TVD) a +N/-S +E/-W Direction (usft) al ,, (usft) (usft) (°) 40.00 0.00 0.00 72.00 - ni 4' Iso- ' Survey Program Date ,I �� (,1 ill 1 From To ,� , , (usft) (usft) Survey(Wellbore) Tool Name Descriptionia7 ,. ! Survey Date 78.83 918.14 2L-308 Srvy#1-GYD-GC-SS(2L-308) GYD-GC-SS Gyrodata gyro single shots 1/13/2015 2:3: 977.46 2,531.61 2L-308 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/13/2015 3:0. 2,676.20 13,704.01 2L-308 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/29/2015 12:2 13,797.81 17,032.45 2L-308 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2015 2:2. k ( umum iuux�wimai i u :i 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 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,685.10 461,034.21 0.00 0.00 UNDEFINED 78.83 0.14 147.35 78.83 -75.97 -0.04 0.03 5,927,685.06 461,034.23 0.36 0.01 GYD-GC-SS(1) 171.15 0.21 126.12 171.15 16.35 -0.23 0.22 5,927,684.86 461,034.43 0.10 0.14 GYD-GC-SS(1) 260.49 0.45 29.56 260.49 105.69 -0.03 0.53 5,927,685.07 461,034.74 0.58 0.49 GYD-GC-SS(1) 352.21 2.39 23.92 352.18 197.38 2.04 1.48 5,927,687.13 461,035.70 2.12 2.04 GYD-GC-SS(1) 447.52 3.21 11.57 447.37 292.57 6.47 2.82 5,927,691.55 461,037.06 1.06 4.68 GYD-GC-SS(1) 541.92 4.42 15.67 541.56 386.76 12.56 4.34 5,927,697.63 461,038.61 1.31 8.00 GYD-GC-SS(1) 635.72 5.26 15.07 635.03 480.23 20.19 6.43 5,927,705.26 461,040.74 0.90 12.35 GYD-GC-SS(1) 729.80 7.08 20.18 728.56 573.76 29.80 9.55 5,927,714.85 461,043.91 2.02 18.29 GYD-GC-SS(1) 779.90 9.30 20.43 778.14 623.34 36.49 12.03 5,927,721.52 461,046.42 4.43 22.72 GYD-GC-SS(1) 825.45 12.03 21.93 822.90 668.10 44.34 15.09 5,927,729.36 461,049.52 6.02 28.05 GYD-GC-SS(1) 918.14 15.37 25.49 912.94 758.14 64.40 23.98 5,927,749.37 461,058.52 3.71 42.71 GYD-GC-SS(1) 977.46 16.52 25.98 969.98 815.18 79.08 31.06 5,927,764.01 461,065.67 1.95 53.98 MWD+IFR-AK-CAZ-SC(2) 1,072.80 16.76 35.79 1,061.35 906.55 102.42 45.04 5,927,787.27 461,079.77 2.95 74.49 MWD+IFR-AK-CAZ-SC(2) 1,166.54 16.25 46.66 1,151.25 996.45 122.39 62.49 5,927,807.15 461,097.32 3.33 97.25 MWD+IFR-AK-CAZ-SC(2) 2/17/2015 9:28:49AM Page 2 COMPASS 5000.1 Build 65 • Definitive Survey Report • Company: NADConversion Local Co-ordinate`Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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) (°/100') (ft) Survey Tool Name 1,261.19 16.42 50.04 1,242.08 1,087.28 140.07 82.38 5,927,824.73 461,117.30 1.02 121.63 MWD+IFR-AK-CAZ-SC(2) 1,355.54 16.06 53.84 1,332.67 1,177.87 156.33 103.13 5,927,840.88 461,138.14 1.19 146.40 MWD+IFR-AK-CAZ-SC(2) 1,450.13 16.38 61.36 1,423.50 1,268.70 170.45 125.41 5,927,854.88 461,160.48 2.24 171.94 MWD+IFR-AK-CAZ-SC(2) 1,544.61 17.87 66.40 1,513.79 1,358.99 182.64 150.38 5,927,866.94 461,185.52 2.22 199.46 MWD+IFR-AK-CAZ-SC(2) 1,637.82 21.17 71.08 1,601.64 1,446.84 193.82 179.42 5,927,877.98 461,214.61 3.92 230.53 MWD+IFR-AK-CAZ-SC(2) 1,733.75 24.41 73.02 1,690.07 1,535.27 205.23 214.77 5,927,889.20 461,250.02 3.47 267.68 MWD+IFR-AK-CAZ-SC(2) 1,782.85 26.99 73.56 1,734.31 1,579.51 211.35 235.17 5,927,895.21 461,270.44 5.28 288.97 MWD+IFR-AK-CAZ-SC(2) 1,827.89 29.53 74.35 1,773.98 1,619.18 217.24 255.66 5,927,900.99 461,290.96 5.70 310.28 MWD+IFR-AK-CAZ-SC(2) 1,876.68 32.16 75.76 1,815.86 1,661.06 223.68 279.83 5,927,907.31 461,315.16 5.59 335.25 MWD+IFR-AK-CAZ-SC(2) 1,922.33 34.21 75.69 1,854.07 1,699.27 229.84 304.04 5,927,913.34 461,339.40 4.49 360.19 MWD+IFR-AK-CAZ-SC(2) 1,967.54 36.31 77.28 1,890.98 1,736.18 235.93 329.42 5,927,919.30 461,364.81 5.07 386.20 MWD+IFR-AK-CAZ-SC(2) 2,016.69 38.07 77.82 1,930.13 1,775.33 242.33 358.43 5,927,925.55 461,393.85 3.64 415.77 MWD+IFR-AK-CAZ-SC(2) 2,111.56 41.45 77.86 2,003.05 1,848.25 255.11 417.74 5,927,938.02 461,453.21 3.56 476.12 MWD+IFR-AK-CAZ-SC(2) 2,206.28 44.15 76.99 2,072.55 1,917.75 269.13 480.54 5,927,951.72 461,516.08 2.92 540.18 MWD+IFR-AK-CAZ-SC(2) 2,300.34 48.02 74.02 2,137.78 1,982.98 286.14 546.10 5,927,968.39 461,581.72 4.70 607.79 MWD+IFR-AK-CAZ-SC(2) 2,395.33 50.82 73.63 2,199.57 2,044.77 306.24 615.38 5,927,988.13 461,651.10 2.96 679.89 MWD+IFR-AK-CAZ-SC(2) 2,444.66 54.35 75.55 2,229.54 2,074.74 316.63 653.15 5,927,998.33 461,688.91 7.79 719.02 MWD+IFR-AK-CAZ-SC(2) 2,490.27 55.89 75.33 2,255.62 2,100.82 326.04 689.36 5,928,007.55 461,725.17 3.40 756.37 MWD+IFR-AK-CAZ-SC(2) 2,531.61 59.09 76.51 2,277.83 2,123.03 334.51 723.17 5,928,015.84 461,759.02 8.11 791.15 MWD+IFR-AK-CAZ-SC(2) 2,599.00 60.00 76.43 2,311.99 2,157.19 348.11 779.65 5,928,029.14 461,815.57 1.36 849.06 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,676.20 61.05 76.33 2,349.97 2,195.17 363.94 844.97 5,928,044.63 461,880.96 1.36 916.07 MWD+IFR-AK-CAZ-SC(3) 2,769.53 64.18 76.40 2,392.89 2,238.09 383.47 925.49 5,928,063.75 461,961.58 3.35 998.69 MWD+IFR-AK-CAZ-SC(3) 2,859.83 68.05 75.04 2,429.45 2,274.65 403.84 1,005.49 5,928,083.71 462,041.67 4.50 1,081.07 MWD+IFR-AK-CAZ-SC(3) 2,953.89 71.73 74.48 2,461.79 2,306.99 427.06 1,090.69 5,928,106.49 462,126.98 3.95 1,169.28 MWD+IFR-AK-CAZ-SC(3) 3,048.34 74.21 73.91 2,489.45 2,334.65 451.66 1,177.58 5,928,130.63 462,213.98 2.69 1,259.51 MWD+IFR-AK-CAZ-SC(3) 3,143.12 75.37 74.30 2,514.31 2,359.51 476.71 1,265.54 5,928,155.22 462,302.06 1.29 1,350.91 MWD+IFR-AK-CAZ-SC(3) 3,237.18 74.81 74.22 2,538.51 2,383.71 501.36 1,353.02 5,928,179.43 462,389.67 0.60 1,441.73 MWD+IFR-AK-CAZ-SC(3) 3,333.38 75.04 74.75 2,563.53 2,408.73 526.21 1,442.53 5,928,203.81 462,479.29 0.58 1,534.53 MWD+IFR-AK-CAZ-SC(3) 3,426.52 74.89 75.19 2,587.70 2,432.90 549.54 1,529.40 5,928,226.68 462,566.27 0.48 1,624.36 MWD+IFR-AK-CAZ-SC(3) 3,520.96 74.33 75.24 2,612.76 2,457.96 572.77 1,617.44 5,928,249.46 462,654.42 0.60 1,715.27 MWD+IFR-AK-CAZ-SC(3) 3,615.49 74.45 76.00 2,638.20 2,483.40 595.38 1,705.63 5,928,271.61 462,742.72 0.78 1,806.13 MWD+IFR-AK-CAZ-SC(3) 3,713.36 74.28 75.73 2,664.57 2,509.77 618.40 1,797.02 5,928,294.16 462,834.22 0.32 1,900.17 MWD+IFR-AK-CAZ-SC(3) 3,801.83 74.33 74.88 2,688.51 2,533.71 640.00 1,879.41 5,928,315.33 462,916.71 0.93 1,985.20 MWD+IFR-AK-CAZ-SC(3) 3,896.78 74.22 73.83 2,714.24 2,559.44 664.65 1,967.42 5,928,339.52 463,004.84 1.07 2,076.51 MWD+IFR-AK-CAZ-SC(3) 3,990.57 74.36 72.16 2,739.64 2,584.84 691.06 2,053.75 5,928,365.48 463,091.30 1.72 2,166.78 MWD+IFR-AK-CAZ-SC(3) 4,084.36 74.40 71.21 2,764.89 2,610.09 719.44 2,139.50 5,928,393.42 463,177.18 0.98 2,257.11 MWD+IFR-AK-CAZ-SC(3) 4,178.54 74.39 70.70 2,790.23 2,635.43 749.04 2,225.25 5,928,422.57 463,263.07 0.52 2,347.80 MWD+IFR-AK-CAZ-SC(3) 4,273.84 74.30 71.89 2,815.94 2,661.14 778.47 2,312.16 5,928,451.55 463,350.13 1.21 2,439.56 MWD+IFR-AK-CAZ-SC(3) 4,369.09 74.27 74.29 2,841.75 2,686.95 805.13 2,399.88 5,928,477.76 463,437.97 2.43 2,531.22 MWD+IFR-AK-CAZ-SC(3) 4,462.91 73.80 74.20 2,867.55 2,712.75 829.63 2,486.69 5,928,501.80 463,524.90 0.51 2,621.35 MWD+IFR-AK-CAZ-SC(3) 4,557.75 73.85 75.21 2,893.97 2,739.17 853.65 2,574.55 5,928,525.37 463,612.88 1.02 2,712.34 MWD+IFR-AK-CAZ-SC(3) 4,653.01 73.74 75.19 2,920.56 2,765.76 877.02 2,662.99 5,928,548.28 463,701.43 0.12 2,803.67 MWD+IFR-AK-CAZ-SC(3) 4,747.08 73.27 75.83 2,947.26 2,792.46 899.59 2,750.32 5,928,570.40 463,788.86 0.82 2,893.70 MWD+IFR-AK-CAZ-SC(3) 2/17/2015 9:28:49AM Page 3 COMPASS 5000.1 Build 65 • • Definitive Survey Report ryM II mini i i Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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) (°/100') (ft) Survey Tool Name 4,842.59 73.29 74.87 2,974.74 2,819.94 922.72 2,838.82 5,928,593.07 463,877.47 0.96 2,985.01 MWD+IFR-AK-CAZ-SC(3) 4,936.09 73.27 73.90 3,001.64 2,846.84 946.83 2,925.06 5,928,616.73 463,963.82 0.99 3,074.48 MWD+IFR-AK-CAZ-SC(3) 5,031.09 73.30 72.82 3,028.97 2,874.17 972.88 3,012.23 5,928,642.33 464,051.12 1.09 3,165.44 MWD+IFR-AK-CAZ-SC(3) 5,125.66 73.83 71.88 3,055.72 2,900.92 1,000.38 3,098.67 5,928,669.38 464,137.69 1.11 3,256.14 MWD+IFR-AK-CAZ-SC(3) 5,220.44 74.31 70.84 3,081.74 2,926.94 1,029.51 3,185.02 5,928,698.06 464,224.19 1.17 3,347.27 MWD+IFR-AK-CAZ-SC(3) 5,315.54 74.33 71.11 3,107.44 2,952.64 1,059.36 3,271.58 5,928,727.46 464,310.89 0.27 3,438.82 MWD+IFR-AK-CAZ-SC(3) 5,409.67 74.31 71.39 3,132.88 2,978.08 1,088.49 3,357.40 5,928,756.14 464,396.85 0.29 3,529.44 MWD+IFR-AK-CAZ-SC(3) 5,504.42 74.36 71.15 3,158.46 3,003.66 1,117.79 3,443.80 5,928,784.99 464,483.39 0.25 3,620.66 MWD+IFR-AK-CAZ-SC(3) 5,598.32 74.31 71.40 3,183.82 3,029.02 1,146.81 3,529.43 5,928,813.57 464,569.16 0.26 3,711.07 MWD+IFR-AK-CAZ-SC(3) 5,693.20 74.28 73.27 3,209.50 3,054.70 1,174.53 3,616.45 5,928,840.83 464,656.32 1.90 3,802.40 MWD+IFR-AK-CAZ-SC(3) 5,788.33 74.42 73.91 3,235.17 3,080.37 1,200.41 3,704.32 5,928,866.26 464,744.31 0.66 3,893.97 MWD+I FR-AK-CAZ-SC(3) 5,883.37 74.31 74.47 3,260.78 3,105.98 1,225.34 3,792.38 5,928,890.73 464,832.49 0.58 3,985.42 MWD+IFR-AK-CAZ-SC(3) 5,977.51 74.30 74.40 3,286.25 3,131.45 1,249.66 3,879.69 5,928,914.60 464,919.91 0.07 4,075.97 MWD+IFR-AK-CAZ-SC(3) 6,072.19 74.28 74.73 3,311.88 3,157.08 1,273.92 3,967.55 5,928,938.40 465,007.89 0.34 4,167.02 MWD+IFR-AK-CAZ-SC(3) 6,167.31 74.51 74.53 3,337.47 3,182.67 1,298.20 4,055.88 5,928,962.22 465,096.34 0.32 4,258.54 MWD+IFR-AK-CAZ-SC(3) 6,262.20 74.01 75.04 3,363.21 3,208.41 1,322.17 4,144.01 5,928,985.74 465,184.58 0.74 4,349.76 MWD+IFR-AK-CAZ-SC(3) 6,358.03 73.59 75.47 3,389.95 3,235.15 1,345.59 4,233.01 5,929,008.70 465,273.69 0.61 4,441.64 MWD+I FR-AK-CAZ-SC(3) 6,451.44 73.56 74.16 3,416.36 3,261.56 1,369.06 4,319.47 5,929,031.72 465,360.27 1.35 4,531.13 MWD+IFR-AK-CAZ-SC(3) 6,546.47 73.59 73.92 3,443.23 3,288.43 1,394.12 4,407.11 5,929,056.32 465,448.02 0.24 4,622.22 MWD+IFR-AK-CAZ-SC(3) 6,641.55 73.54 73.37 3,470.13 3,315.33 1,419.80 4,494.62 5,929,081.55 465,535.65 0.56 4,713.38 MWD+IFR-AK-CAZ-SC(3) 6,736.94 73.59 72.48 3,497.12 3,342.32 1,446.67 4,582.08 5,929,107.96 465,623.24 0.90 4,804.86 MWD+IFR-AK-CAZ-SC(3) 6,830.94 73.54 72.00 3,523.72 3,368.92 1,474.17 4,667.94 5,929,135.01 465,709.23 0.49 4,895.02 MWD+IFR-AK-CAZ-SC(3) 6,926.96 73.65 71.27 3,550.84 3,396.04 1,503.19 4,755.36 5,929,163.58 465,796.79 0.74 4,987.12 MWD+IFR-AK-CAZ-SC(3) 7,021.18 74.13 70.99 3,576.98 3,422.18 1,532.47 4,841.01 5,929,192.41 465,882.59 0.58 5,077.63 MWD+IFR-AK-CAZ-SC(3) 7,115.64 74.10 71.10 3,602.83 3,448.03 1,561.98 4,926.94 5,929,221.48 465,968.66 0.12 5,168.47 MWD+IFR-AK-CAZ-SC(3) 7,209.72 74.07 72.26 3,628.63 3,473.83 1,590.41 5,012.82 5,929,249.47 466,054.68 1.19 5,258.94 MWD+IFR-AK-CAZ-SC(3) 7,305.70 74.04 73.10 3,655.00 3,500.20 1,617.89 5,100.93 5,929,276.49 466,142.91 0.84 5,351.22 MWD+IFR-AK-CAZ-SC(3) 7,399.54 74.11 73.22 3,680.75 3,525.95 1,644.03 5,187.30 5,929,302.18 466,229.41 0.14 5,441.44 MWD+I FR-AK-CAZ-SC(3) 7,494.36 74.01 74.08 3,706.79 3,551.99 1,669.70 5,274.78 5,929,327.39 466,317.02 0.88 5,532.58 MWD+IFR-AK-CAZ-SC(3) 7,589.20 74.04 73.80 3,732.89 3,578.09 1,694.92 5,362.40 5,929,352.16 466,404.76 0.29 5,623.70 MWD+IFR-AK-CAZ-SC(3) 7,684.95 73.95 73.55 3,759.29 3,604.49 1,720.79 5,450.73 5,929,377.57 466,493.21 0.27 5,715.70 MWD+IFR-AK-CAZ-SC(3) 7,779.59 74.05 72.99 3,785.38 3,630.58 1,746.98 5,537.85 5,929,403.31 466,580.46 0.58 5,806.65 MWD+IFR-AK-CAZ-SC(3) 7,874.02 74.07 73.85 3,811.31 3,656.51 1,772.89 5,624.87 5,929,428.76 466,667.60 0.88 5,897.43 MWD+IFR-AK-CAZ-SC(3) 7,968.10 74.07 73.98 3,837.13 3,682.33 1,797.95 5,711.80 5,929,453.38 466,754.65 0.13 5,987.84 MWD+IFR-AK-CAZ-SC(3) 8,062.53 74.10 74.07 3,863.03 3,708.23 1,822.95 5,799.10 5,929,477.92 466,842.07 0.10 6,078.60 MWD+IFR-AK-CAZ-SC(3) 8,157.11 74.04 73.99 3,888.99 3,734.19 1,847.97 5,886.54 5,929,502.49 466,929.63 0.10 6,169.49 MWD+I FR-AK-CAZ-SC(3) 8,252.61 74.01 73.18 3,915.27 3,760.47 1,873.91 5,974.61 5,929,527.97 467,017.82 0.82 6,261.26 MWD+IFR-AK-CAZ-SC(3) 8,347.05 74.04 72.47 3,941.26 3,786.46 1,900.72 6,061.35 5,929,554.33 467,104.69 0.72 6,352.04 MWD+IFR-AK-CAZ-SC(3) 8,442.45 74.52 71.95 3,967.11 3,812.31 1,928.78 6,148.79 5,929,581.94 467,192.27 0.73 6,443.88 MWD+IFR-AK-CAZ-SC(3) 8,536.17 74.55 72.26 3,992.10 3,837.30 1,956.54 6,234.75 5,929,609.24 467,278.36 0.32 6,534.20 MWD+IF R-AK-CAZ-SC(3) 8,631.70 74.60 73.05 4,017.51 3,862.71 1,983.99 6,322.65 5,929,636.24 467,366.39 0.80 6,626.28 MWD+IFR-AK-CAZ-SC(3) 8,727.55 74.63 74.42 4,042.94 3,888.14 2,009.87 6,411.36 5,929,661.66 467,455.23 1.38 6,718.65 MWD+IFR-AK-CAZ-SC(3) 8,821.58 74.07 76.24 4,068.31 3,913.51 2,032.80 6,498.95 5,929,684.14 467,542.92 1.96 6,809.04 MWD+IFR-AK-CAZ-SC(3) 8,915.47 74.07 77.62 4,094.08 3,939.28 2,053.22 6,586.89 5,929,704.10 467,630.96 1.41 6,898.99 MWD+IFR-AK-CAZ-SC(3) 2/17/2015 9:28:49AM Page 4 COMPASS 5000.1 Build 65 • Definitive Survey Report ort Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 9,009.09 74.07 77.68 4,119.77 3,964.97 2,072.48 6,674.84 5,929,722.90 467,718.99 0.06 6,988.58 MWD+IFR-AK-CAZ-SC(3) 9,104.13 74.04 77.16 4,145.88 3,991.08 2,092.38 6,764.02 5,929,742.34 467,808.28 0.53 7,079.55 MWD+IFR-AK-CAZ-SC(3) 9,198.53 74.10 75.25 4,171.79 4,016.99 2,114.02 6,852.18 5,929,763.53 467,896.53 1.95 7,170.08 MWD+I FR-AK-CAZ-SC(3) 9,292.04 74.07 73.57 4,197.44 4,042.64 2,138.19 6,938.79 5,929,787.24 467,983.26 1.73 7,259.92 MWD+IFR-AK-CAZ-SC(3) 9,386.03 73.95 73.41 4,223.33 4,068.53 2,163.87 7,025.42 5,929,812.47 468,070.01 0.21 7,350.24 MWD+IFR-AK-CAZ-SC(3) 9,480.30 74.07 73.76 4,249.30 4,094.50 2,189.48 7,112.35 5,929,837.63 468,157.06 0.38 7,440.83 MWD+IFR-AK-CAZ-SC(3) 9,575.43 74.13 73.76 4,275.36 4,120.56 2,215.06 7,200.19 5,929,862.76 468,245.02 0.06 7,532.28 MWD+IFR-AK-CAZ-SC(3) 9,669.96 74.10 72.63 4,301.23 4,146.43 2,241.35 7,287.22 5,929,888.59 468,332.18 1.15 7,623.18 MWD+IFR-AK-CAZ-SC(3) 9,763.63 74.04 72.70 4,326.94 4,172.14 2,268.19 7,373.20 5,929,914.98 468,418.29 0.10 7,713.24 MWD+IFR-AK-CAZ-SC(3) 9,858.60 74.13 72.76 4,352.98 4,198.18 2,295.30 7,460.42 5,929,941.64 468,505.64 0.11 7,804.56 MWD+IFR-AK-CAZ-SC(3) 9,954.88 74.10 72.65 4,379.33 4,224.53 2,322.83 7,548.83 5,929,968.71 468,594.19 0.11 7,897.16 MWD+IFR-AK-CAZ-SC(3) 10,049.51 74.16 72.74 4,405.21 4,250.41 2,349.91 7,635.74 5,929,995.34 468,681.22 0.11 7,988.18 MWD+IFR-AK-CAZ-SC(3) 10,143.83 74.15 73.09 4,430.96 4,276.16 2,376.56 7,722.47 5,930,021.55 468,768.08 0.36 8,078.90 MWD+IFR-AK-CAZ-SC(3) 10,239.02 74.21 73.34 4,456.91 4,302.11 2,403.01 7,810.15 5,930,047.54 468,855.89 0.26 8,170.47 MWD+IFR-AK-CAZ-SC(3) 10,333.73 74.19 73.62 4,482.70 4,327.90 2,428.92 7,897.52 5,930,073.00 468,943.38 0.29 8,261.57 MWD+IFR-AK-CAZ-SC(3) 10,428.03 74.12 73.92 4,508.45 4,353.65 2,454.28 7,984.62 5,930,097.90 469,030.60 0.31 8,352.24 MWD+IFR-AK-CAZ-SC(3) 10,523.21 74.09 74.57 4,534.52 4,379.72 2,479.13 8,072.72 5,930,122.30 469,118.82 0.66 8,443.71 MWD+IFR-AK-CAZ-SC(3) 10,617.65 74.10 73.78 4,560.40 4,405.60 2,503.90 8,160.10 5,930,146.61 469,206.32 0.80 8,534.47 MWD+IFR-AK-CAZ-SC(3) 10,712.39 74.04 73.57 4,586.40 4,431.60 2,529.51 8,247.53 5,930,171.77 469,293.87 0.22 8,625.53 MWD+IFR-AK-CAZ-SC(3) 10,807.80 74.10 73.66 4,612.59 4,457.79 2,555.39 8,335.55 5,930,197.19 469,382.02 0.11 8,717.24 MWD+IFR-AK-CAZ-SC(3) 10,900.85 73.90 73.65 4,638.24 4,483.44 2,580.56 8,421.38 5,930,221.92 469,467.97 0.22 8,806.65 MWD+IFR-AK-CAZ-SC(3) 10,994.59 74.61 73.60 4,663.67 4,508.87 2,606.00 8,507.95 5,930,246.90 469,554.65 0.76 8,896.84 MWD+IFR-AK-CAZ-SC(3) 11,091.02 74.48 73.69 4,689.37 4,534.57 2,632.17 8,597.13 5,930,272.61 469,643.96 0.16 8,989.74 MWD+I FR-AK-CAZ-SC(3) 11,185.19 74.67 73.71 4,714.42 4,559.62 2,657.65 8,684.26 5,930,297.64 469,731.21 0.20 9,080.48 MWD+IFR-AK-CAZ-SC(3) 11,279.47 74.14 74.14 4,739.76 4,584.96 2,682.79 8,771.52 5,930,322.33 469,818.59 0.71 9,171.24 MWD+IFR-AK-CAZ-SC(3) 11,374.49 74.22 73.27 4,765.67 4,610.87 2,708.44 8,859.26 5,930,347.52 469,906.46 0.88 9,262.61 MWD+IFR-AK-CAZ-SC(3) 11,470.49 74.24 72.33 4,791.76 4,636.96 2,735.76 8,947.52 5,930,374.38 469,994.84 0.94 9,354.99 MWD+IF R-AK-CAZ-SC(3) 11,562.72 74.15 72.01 4,816.88 4,662.08 2,762.93 9,032.00 5,930,401.12 470,079.46 0.35 9,443.73 MWD+IFR-AK-CAZ-SC(3) 11,657.13 73.61 71.88 4,843.09 4,688.29 2,791.04 9,118.23 5,930,428.78 470,165.82 0.59 9,534.43 MWD+IFR-AK-CAZ-SC(3) 11,752.19 73.71 72.03 4,869.83 4,715.03 2,819.30 9,204.96 5,930,456.58 470,252.69 0.18 9,625.65 MWD+I FR-AK-CAZ-SC(3) 11,846.95 73.74 72.34 4,896.39 4,741.59 2,847.13 9,291.56 5,930,483.96 470,339.43 0.32 9,716.61 MWD+I FR-AK-CAZ-SC(3) 11,942.07 73.71 73.11 4,923.05 4,768.25 2,874.25 9,378.75 5,930,510.63 470,426.75 0.78 9,807.91 MWD+I FR-AK-CAZ-SC(3) 12,036.36 73.64 74.06 4,949.55 4,794.75 2,899.82 9,465.55 5,930,535.75 470,513.67 0.97 9,898.37 MWD+IFR-AK-CAZ-SC(3) 12,129.96 74.16 74.31 4,975.51 4,820.71 2,924.32 9,552.08 5,930,559.80 470,600.31 0.61 9,988.23 MWD+IFR-AK-CAZ-SC(3) 12,224.88 74.89 76.01 5,000.84 4,846.04 2,947.75 9,640.50 5,930,582.77 470,688.84 1.89 10,079.57 MWD+IF R-AK-CAZ-SC(3) 12,319.96 75.25 78.53 5,025.34 4,870.54 2,967.99 9,730.10 5,930,602.55 470,778.54 2.59 10,171.04 MWD+IFR-AK-CAZ-SC(3) 12,413.37 75.37 80.68 5,049.03 4,894.23 2,984.29 9,818.97 5,930,618.39 470,867.48 2.23 10,260.59 MWD+IFR-AK-CAZ-SC(3) 12,507.42 75.25 83.49 5,072.88 4,918.08 2,996.82 9,909.07 5,930,630.45 470,957.64 2.89 10,350.15 MWD+IFR-AK-CAZ-SC(3) 12,602.52 75.25 86.52 5,097.10 4,942.30 3,004.83 10,000.67 5,930,637.98 471,049.27 3.08 10,439.75 MWD+IFR-AK-CAZ-SC(3) 12,696.15 75.21 90.55 5,120.98 4,966.18 3,007.14 10,091.16 5,930,639.83 471,139.76 4.16 10,526.52 MWD+IFR-AK-CAZ-SC(3) 12,791.71 74.43 94.95 5,146.01 4,991.21 3,002.72 10,183.25 5,930,634.94 471,231.82 4.52 10,612.74 MWD+IFR-AK-CAZ-SC(3) 12,885.33 74.67 99.04 5,170.96 5,016.16 2,991.74 10,272.80 5,930,623.49 471,321.30 4.22 10,694.51 MWD+IFR-AK-CAZ-SC(3) 12,980.98 75.76 104.25 5,195.39 5,040.59 2,973.07 10,363.34 5,930,604.35 471,411.73 5.39 10,774.85 MWD+IFR-AK-CAZ-SC(3) 13,076.00 76.25 108.09 5,218.37 5,063.57 2,947.39 10,451.87 5,930,578.23 471,500.12 3.96 10,851.11 MWD+IFR-AK-CAZ-SC(3) 2/17/2015 9:28:49AM Page 5 COMPASS 5000.1 Build 65 • Definitive Survey Report • Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 Database:migio, OAKEDMP2 11•111111111 -...mmagmmEmmounnum,„1;,,, �- .-.-®-�31 �I'"i nyidN9LYAa3RssPu ��tt0.tfttt�MlLa�8®ifi ttttt� oCa�t';.Id4P.� t� a Survey r ' M��NI1� "KP m a 'I�ip��iDih�i�mi9Pihiir `Atglorlp 1 Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section ki111111 (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,169.88 76.60 110.46 5,240.41 5,085.61 2,917.27 10,538.00 5,930,547.66 471,586.09 2.48 10,923.72 MWD+IFR-AK-CAZ-SC(3) 13,264.84 76.41 113.35 5,262.58 5,107.78 2,882.82 10,623.67 5,930,512.78 471,671.57 2.97 10,994.55 MWD+I FR-AK-CAZ-SC(3) 13,359.14 74.37 115.29 5,286.36 5,131.56 2,845.26 10,706.81 5,930,474.78 471,754.51 2.94 11,062.02 MWD+IFR-AK-CAZ-SC(3) 13,453.88 73.29 115.83 5,312.75 5,157.95 2,806.00 10,788.90 5,930,435.11 471,836.38 1.26 11,127.95 MWD+I FR-AK-CAZ-SC(3) 13,547.72 74.00 114.37 5,339.17 5,184.37 2,767.80 10,870.44 5,930,396.50 471,917.72 1.67 11,193.70 MWD+IFR-AK-CAZ-SC(3) 13,643.13 73.80 112.67 5,365.63 5,210.83 2,731.22 10,954.49 5,930,359.49 472,001.57 1.72 11,262.33 MWD+IFR-AK-CAZ-SC(3) 13,704.01 73.68 113.10 5,382.68 5,227.88 2,708.50 11,008.33 5,930,336.49 472,055.29 0.71 11,306.52 MWD+I FR-AK-CAZ-SC(3) 13,763.00 74.28 112.65 5,398.96 5,244.16 2,686.46 11,060.57 5,930,314.18 472,107.41 1.26 11,349.39 MWD+IFR-AK-CAZ-SC(4) 7-5/8"_x 9-7/8" 13,797.81 74.64 112.38 5,408.28 5,253.48 2,673.62 11,091.55 5,930,301.18 472,138.32 1.26 11,374.89 MWD+IFR-AK-CAZ-SC(4) 13,838.49 76.39 113.54 5,418.46 5,263.66 2,658.25 11,127.82 5,930,285.63 472,174.50 5.11 11,404.63 MWD+1FR-AK-CAZ-SC(4) 13,889.76 78.39 114.46 5,429.65 5,274.85 2,637.90 11,173.52 5,930,265.05 472,220.09 4.28 11,441.81 MWD+I F R-AK-CAZ-SC(4) 13,933.91 80.03 115.68 5,437.92 5,283.12 2,619.52 11,212.80 5,930,246.47 472,259.28 4.60 11,473.49 MWD+IFR-AK-CAZ-SC(4) 13,985.41 81.77 116.39 5,446.06 5,291.26 2,597.20 11,258.49 5,930,223.92 472,304.85 3.64 11,510.04 MWD+I FR-AK-CAZ-SC(4) 14,029.41 82.64 116.65 5,452.03 5,297.23 2,577.74 11,297.50 5,930,204.25 472,343.75 2.06 11,541.12 MWD+IFR-AK-CAZ-SC(4) 14,076.37 83.16 118.09 5,457.83 5,303.03 2,556.32 11,338.88 5,930,182.62 472,385.01 3.24 11,573.86 MWD+I FR-AK-CAZ-SC(4) 14,122.04 83.47 120.24 5,463.15 5,308.35 2,534.21 11,378.49 5,930,160.31 472,424.50 4.72 11,604.70 MWD+I FR-AK-CAZ-SC(4) 14,175.05 83.16 121.69 5,469.32 5,314.52 2,507.12 11,423.63 5,930,132.99 472,469.50 2.78 11,639.26 MWD+I FR-AK-CAZ-SC(4) 14,218.79 83.02 123.65 5,474.58 5,319.78 2,483.69 11,460.18 5,930,109.37 472,505.93 4.46 11,666.78 MWD+IFR-AK-CAZ-SC(4) 14,274.96 83.29 125.46 5,481.28 5,326.48 2,452.06 11,506.11 5,930,077.50 472,551.69 3.24 11,700.69 MWD+I FR-AK-CAZ-SC(4) 14,313.24 83.71 126.49 5,485.61 5,330.81 2,429.71 11,536.89 5,930,055.01 472,582.35 2.89 11,723.06 MWD+IFR-AK-CAZ-SC(4) 14,359.42 84.09 128.21 5,490.52 5,335.72 2,401.86 11,573.39 5,930,026.96 472,618.70 3.79 11,749.16 MWD+IF R-AK-CAZ-SC(4) 14,403.73 84.71 129.33 5,494.84 5,340.04 2,374.24 11,607.77 5,929,999.18 472,652.94 2.88 11,773.33 MWD+IFR-AK-CAZ-SC(4) 14,462.19 85.81 132.29 5,499.68 5,344.88 2,336.17 11,651.86 5,929,960.88 472,696.82 5.39 11,803.49 MWD+I FR-AK-CAZ-SC(4) 14,503.00 86.05 133.24 5,502.57 5,347.77 2,308.53 11,681.75 5,929,933.09 472,726.56 2.40 11,823.38 MWD+I FR-AK-CAZ-SC(4) 14,551.46 86.48 133.84 5,505.73 5,350.93 2,275.22 11,716.80 5,929,899.60 472,761.44 1.52 11,846.42 MWD+I FR-AK-CAZ-SC(4) 14,575.53 87.35 134.04 5,507.03 5,352.23 2,258.54 11,734.11 5,929,882.84 472,778.66 3.71 11,857.73 MWD+IFR-AK-CAZ-SC(4) 14,597.83 88.13 134.81 5,507.90 5,353.10 2,242.94 11,750.02 5,929,867.16 472,794.49 4.91 11,868.04 MWD+IF R-AK-CAZ-SC(4) 14,646.52 90.95 138.27 5,508.30 5,353.50 2,207.61 11,783.50 5,929,831.66 472,827.79 9.17 11,888.96 MWD+IF R-AK-CAZ-SC(4) 14,693.86 91.27 139.04 5,507.38 5,352.58 2,172.08 11,814.77 5,929,795.97 472,858.86 1.76 11,907.72 MWD+I FR-AK-CAZ-SC(4) 14,788.91 92.12 140.04 5,504.57 5,349.77 2,099.79 11,876.42 5,929,723.37 472,920.14 1.38 11,944.02 MWD+I FR-AK-CAZ-SC(4) 14,883.75 91.30 144.55 5,501.74 5,346.94 2,024.81 11,934.38 5,929,648.10 472,977.70 4.83 11,975.97 MWD+I FR-AK-CAZ-SC(4) 14,977.27 90.00 148.32 5,500.67 5,345.87 1,946.91 11,986.07 5,929,569.93 473,028.99 4.26 12,001.06 MWD+IF R-AK-CAZ-SC(4) 15,028.25 89.91 152.57 5,500.71 5,345.91 1,902.57 12,011.21 5,929,525.47 473,053.90 8.34 12,011.27 MWD+IFR-AK-CAZ-SC(4) 15,072.51 88.76 152.64 5,501.23 5,346.43 1,863.28 12,031.58 5,929,486.08 473,074.06 2.60 12,018.49 MWD+IF R-AK-CAZ-SC(4) 15,123.59 90.10 154.50 5,501.74 5,346.94 1,817.54 12,054.31 5,929,440.23 473,096.55 4.49 12,025.98 MWD+I FR-AK-CAZ-SC(4) 15,167.12 90.68 156.29 5,501.44 5,346.64 1,777.97 12,072.43 5,929,400.57 473,114.47 4.32 12,030.99 MWD+I FR-AK-CAZ-SC(4) 15,219.12 91.13 160.26 5,500.62 5,345.82 1,729.67 12,091.67 5,929,352.18 473,133.46 7.68 12,034.36 MWD+IFR-AK-CAZ-SC(4) 15,259.65 90.91 161.76 5,499.90 5,345.10 1,691.36 12,104.86 5,929,313.80 473,146.44 3.74 12,035.06 MWD+I FR-AK-CAZ-SC(4) I 15,312.55 91.63 165.09 5,498.72 5,343.92 1,640.68 12,119.94 5,929,263.05 473,161.27 6.44 12,033.75 MWD+IFR-AK-CAZ-SC(4) 15,345.47 90.77 165.75 5,498.03 5,343.23 1,608.82 12,128.23 5,929,231.16 473,169.39 3.29 12,031.79 MWD+IFR-AK-CAZ-SC(4) 15,403.85 90.17 167.84 5,497.56 5,342.76 1,551.99 12,141.56 5,929,174.26 473,182.43 3.72 12,026.91 MWD+IFR-AK-CAZ-SC(4) 15,448.32 90.05 169.65 5,497.47 5,342.67 1,508.38 12,150.24 5,929,130.61 473,190.88 4.08 12,021.68 MWD+I FR-AK-CAZ-S C(4) 15,509.91 88.14 171.73 5,498.44 5,343.64 1,447.61 12,160.20 5,929,069.80 473,200.53 4.58 12,012.38 MWD+1FR-AK-CAZ-SC(4) 2/17/2015 9:28:49AM Page 6 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig: 114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 Database .., OAKEDMP2 111 IIIENIEMEREM Survey ,,,,p1111[110 Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100) (ft) Survey Tool Name 15,541.03 88.84 171.43 5,499.26 5,344.46 1,416.84 12,164.76 5,929,039.01 473,204.92 2.45 12,007.20 MWD+IFR-AK-CAZ-SC(4) 15,636.05 88.26 171.45 5,501.67 5,346.87 1,322.91 12,178.90 5,928,945.01 473,218.57 0.61 11,991.62 MWD+IFR-AK-CAZ-SC(4) 15,737.59 91.42 171.76 5,501.95 5,347.15 1,222.47 12,193.72 5,928,844.51 473,232.88 3.13 11,974.68 MWD+IFR-AK-CAZ-SC(4) 15,832.23 91.51 172.10 5,499.53 5,344.73 1,128.80 12,207.00 5,928,750.78 473,245.67 0.37 11,958.37 MWD+IFR-AK-CAZ-SC(4) 15,927.16 89.78 173.31 5,498.46 5,343.66 1,034.65 12,219.06 5,928,656.58 473,257.24 2.22 11,940.74 MWD+IFR-AK-CAZ-SC(4) 16,022.15 89.35 173.98 5,499.18 5,344.38 940.25 12,229.57 5,928,562.13 473,267.26 0.84 11,921.56 MWD+IFR-AK-CAZ-SC(4) 16,118.12 89.55 173.47 5,500.11 5,345.31 844.86 12,240.06 5,928,466.70 473,277.26 0.57 11,902.06 MWD+IFR-AK-CAZ-SC(4) 16,211.70 90.34 174.10 5,500.20 5,345.40 751.83 12,250.19 5,928,373.63 473,286.91 1.08 11,882.95 MWD+IFR-AK-CAZ-SC(4) 16,306.38 90.44 175.75 5,499.55 5,344.75 657.52 12,258.56 5,928,279.29 473,294.80 1.75 11,861 77 MWD+IFR-AK-CAZ-SC(4) 16,402.33 90.72 174.50 5,498.58 5,343.78 561.93 12,266.72 5,928,183.66 473,302.46 1.33 11,839.99 MWD+IFR-AK-CAZ-SC(4) 16,495.86 91.16 169.88 5,497.04 5,342.24 469.30 12,279.42 5,928,090.98 473,314.68 4.96 11,823.45 MWD+IFR-AK-CAZ-SC(4) 16,589.74 90.75 169.18 5,495.48 5,340.68 377.00 12,296.48 5,927,998.60 473,331.26 0.86 11,811.15 MWD+IFR-AK-CAZ-SC(4) 16,685.28 90.72 166.83 5,494.25 5,339.45 283.56 12,316.33 5,927,905.07 473,350.63 2.46 11,801.15 MWD+IFR-AK-CAZ-SC(4) 16,780.79 91.20 166.71 5,492.65 5,337.85 190.60 12,338.19 5,927,812.01 473,372.00 0.52 11,793.21 MWD+IFR-AK-CAZ-SC(4) 16,875.56 92.43 166.32 5,489.65 5,334.85 98.49 12,360.27 5,927,719.79 473,393.61 1.36 11,785.75 MWD+IFR-AK-CAZ-SC(4) 16,970.27 92.31 168.20 5,485.73 5,330.93 6.19 12,381.14 5,927,627.40 473,414.00 1.99 11,777.08 MWD+IFR-AK-CAZ-SC(4) 17,032.45 90.04 167.49 5,484.46 5,329.66 -54.57 12,394.23 5,927,566.57 473,426.77 3.83 11,770.75 MWD+IFR-AK-CAZ-SC(4) 17,093.00 90.04 167.49 5,484.42 5,329.62 -113.69 12,407.35 5,927,507.40 473,439.58 0.00 11,764.96 4 112"x 6-1/2" 17,095.00 90.04 167.49 5,484.42 5,329.62 -115.64 12,407.78 5,927,505.44 473,440.01 0.00 11,764.77 PROJECTED to TD 2/17/2015 9:28:49AM Page 7 COMPASS 5000.1 Build 65 i • 0 Cement Detail Report 2L-308 Cana hiiiips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/6/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/14/2015 02:00 1/14/2015 05:22 2L-308 Comment Land 10-3/4"45.5 ppf L-80 Hyd 563 csg at 2599'. PU= 144K, SO= 106K. Stage pumps to 4 BPM ICP=118 psi, FCP= 163 psi,26%FO,making 25'strokes at 10 Strokes/hr. Pumped 173.5 BBL mud. Blow down top drive, RU cement lines. Circ&cond mud: stage pumps from 4 BPM to 8 BPM at 300 psi with 25%FO, making 25'strokes @ 10 strokes/hr. Circ and cond mud from; MW=9.9, pH= 10.6, PV= 17,YP=35, l0s=39, 10m=49. Final mud properties=MW=10.0, pH=10 3, PV=17,YP= 11, 10s=10, 10m=29. Note:Ciirculated 2638 total BBL prior to cement job,2104 BBL was @ 8 BPM or more. Dowell pump 10 BBL water-test to 3500 psi. Pump Mud push II, 10.5 ppg with red dye. Pump 98.5 BBL at 5.45 BPM with 140 psi averages. PU wt 144K,SO wt 120K. Dowell pumps Lead cement 398.7 BBL, 11.0 ppg 1.92 cufUsx yield at 7 BPM with ICP=288 psi,Average=305 psi and FCP=440 psi. At 80 BBL away; PU=147K, SO=120K. With 250 BBL away Lead reached the shoe. At 290 BBL away the red dye in the Mud Push II was seen at the shakers. This was-20 BBL early when compared to calculated gauge hole. PU= 133K, SO=85K with last foot to hanger SO=57K. Decision to leave on the hanger and quit recip. Pump Tail cement 60.7 BBL, 12.0 ppg 1.66 cufUsx yield at 7 BPM with 295 psi average. Drop top plug, kick out with 10 BBL water with a peak pressure of 568 psi and 8 BPM rate--returns were lost. Note:At the time of losses, mud push with red dye was still returning f/hole w/slightly higher PH than MudPush. Switched to rig pumps,chased plug with 9.8 ppg Drilplex mud at 7 BPM, staging down to 4 BPM with no returns. At100 BBL away returns were diverted to the cellar with Tail cement at the shoe,-182 BBL away partial returns started in the cellar with some red dye.At 190 BBL away 11.0 ppg full returns were seen in the cellar.Total of 40.4 BBL good cement from the well,when bumped plug pumping 3bpm final of 450 psi, increased to 1000 psi. Held 5 min. Bled off,floats held,CIP 0522 hrs 1/14/2015. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface casing cement Cement surface casing 44.0 2,599.0 No 40.4 Yes Yes 10 3/4" 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) 7 3 7 450.0 1,000.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,508.0 Drill Bit 2,599.0 9 7/8 Comment Land 10-3/4"45.5 ppf L-80 Hyd 563 csg at 2599'. PU= 144K,SO= 106K. Stage pumps to 4 BPM ICP=118 psi, FCP= 163 psi,26%FO,making 25'strokes at 10 Strokes/hr. Pumped 173.5 BBL mud. Blow down top drive,RU cement lines.Circ&cond mud:stage pumps from 4 BPM to 8 BPM at 300 psi with 25% FO, making 25'strokes @ 10 strokes/hr. Circ and cond mud from; MW=9.9, pH=10.6, PV= 17,YP=35, 10s=39, 10m=49. Final mud properties=MW=10.0, pH=10.3, PV=17,YP= 11, 10s=10, 10m=29. Note:Ciirculated 2638 total BBL prior to cement job,2104 BBL was @ 8 BPM or more. Dowell pump 10 BBL water-test to 3500 psi. Pump Mud push II, 10.5 ppg with red dye. Pump 98.5 BBL at 5.45 BPM with 140 psi averages. PU wt 144K, SO wt 120K. Dowell pumps Lead cement 398.7 BBL, 11.0 ppg 1.92 cufUsx yield at 7 BPM with ICP=288 psi,Average=305 psi and FCP=440 psi. At 80 BBL away; PU=147K, SO=120K. With 250 BBL away Lead reached the shoe. At 290 BBL away the red dye in the Mud Push II was seen at the shakers. This was-20 BBL early when compared to calculated gauge hole. PU= 133K, SO=85K with last foot to hanger S0=57K. Decision to leave on the hanger and quit recip. Pump Tail cement 60.7 BBL, 12.0 ppg 1.66 cufUsx yield at 7 BPM with 295 psi average. Drop top plug, kick out with 10 BBL water with a peak pressure of 568 psi and 8 BPM rate--returns were lost. Note:At the time of losses,mud push with red dye was still returning f/hole w/slightly higher PH than MudPush. Switched to rig pumps,chased plug with 9.8 ppg Drilplex mud at 7 BPM,staging down to 4 BPM with no returns. At100 BBL away returns were diverted to the cellar with Tail cement at the shoe, -182 BBL away partial returns started in the cellar with some red dye.At 190 BBL away 11.0 ppg full returns were seen in the cellar.Total of 40.4 BBL good cement from the well,when bumped plug pumping 3bpm final of 450 psi, increased to 1000 psi. Held 5 min. Bled off,floats held,CIP 0522 hrs 1/14/2015. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 44.2 2,100.0 1,165 LiteCRETE 398.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.92 6.90 11.00 4.35 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.07 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Conc Unit label D185 Dispersant LT 0.07 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPushll 0.0 0.0 Flush 98.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.'s) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Page 1/2 Report Printed: 3/2/2015 • • ! .t 6 Cement Detail Report 03' 2L-308 ConocoPhillips String: Surface Casing Cement Job: DRILLING ORIGINAL, 1/6/2015 00:00 Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,100.0 2,599.0 205 LiteCRETE 60.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) 'Thickening Time(hr) CmprStr 1(psi) 1.66 5.87 12.00 4.28 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.07 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Conc Unit label D185 Dispersant LT 0.06 gal/sx Page 2/2 Report Printed: 3/2/2015 • 0 -L;0 Cement Detail Report 2L-308 Coillips String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 1/6/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/2/2015 07:00 2/2/2015 10:00 2L-308 Comment SLB pumped 5 bbl CW100,test trips @ 3000 psi,test to 4000 psi-good. Pump remaining 35 bbl CW100©5 bpm, 530 psi, pump 38.6 bbl MudPush II© 11.5 ppg,4.7 bpm,470 psi. Drop bottom plug,SLB pumped 214.8 bbl 15.8 ppg Cement,5.5 bpm,500 psi.Shut down drop top plug, SLB kick out with 10 bbl water, rig displaced with 6143 stks 10.7 ppg LSND. Bump plug @ 800 psi FCP, increase to 1300 psi and hold 5 min. Check floats-good. CIP @ 10:00. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement intermediate, 9,835.0 13,672.0 No Yes Yes Cement isolate C-37 Q Pump'nit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 6 6 757.0 800.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Stopped reciprocating @ 5800 stks,landed and bumped plug @ 6143 stks. Cement Fluids 8,Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 9,835.0 13,775.0 1,017 G 214.8 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.25 15.80 98.0 6.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Antifoam D047 0.09 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.6 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.1 %BWOC Additive Type Concentration Conc Unit label Inorganic Accelerator D186 0.13 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 1/1 Report Printed: 3/2/2015 4,41111 ) IV7,1 THE STATE Alaska Oil and Gas •� di , ofA T A..sKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov Adam Klem Sr. Completions Engineer ConocoPhillips Alaska, Inc. 02Itiqb 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-308 Sundry Number: 315-120 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, t9sL Cathy . Foerster Chair DATED this (0 day of March, 2015 Encl. STATE OF ALASKA RECEIVED • .KA OIL AND GAS CONSERVATION COM1OSION MAR 0 3 2015 APPLICATION FOR SUNDRY APPROVALS P-TS 35 J IS 20 AAC25.280 AOGCC 1.Type of Request: Abandon [ Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend fl Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate For Alter casing E Other:Frac Treatment a+ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development ri„ 214-151-0 ° 3.Address: Stratigraphic r Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20694-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No W. KRU 2L-308 , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380052,380051,25603, Kuparuk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17095 ' 5484 . 17095', 5484' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 92 16 120' 120' SURFACE 2560 10.75" 2599' 2312' INTERMEDIATE 13725 7.625" 13763' 5399' LINER 3484 4.5" 17095' 5484' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): pert pups from 17078-17082 5484-5484 3.5 L-80 13625 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER -BAKER PREMIER PACKER MD=13499 TVD=5326 • PACKER-FLEX LOCK PACKER MD=13611 TVD=5357 NIPPLE-CAMCO DS LANIDING NIPPLE MD=525 TVD=525 12.Attachments: Description Summary of Proposal r�- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory rStratigraphic l Development f ' Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/6/2015 Oil417 i Gas r WDSPL fl Suspended r 16.Verbal Approval: Date: WIN J r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Adam Klem @ 263-4529 Email: Adam.Klem(a)conocophillips.com Printed Name Ada,A,lem Title: Sr. Completions Engineer Signature d° ,i Phone:263-4529 Date 3/0///. Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315-1 2.0 Plug Integritylr BOP Test r Mechanical Integrity Test,, Location Clearance r Other: 1905+ II40r mak(0Y1 ret(Area .TriO 'Q. FracFoc-cS Ch&rvA.CR/\ 1)1ic(Osuce Ri jis 0.)“..w. 'P0.0 rbc.v> . ori elr/�s oft—Lr re ,re+ n*S of ,20 /}�4C o2S ,ZV . ���111 Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: VD— 4 0 1-- APPROVED BY / Approved by:aZ-e/ r /V-Phil COMMISSIONER THE COMMISSION Date:3-6 (5_ 7 Approved application is valid tor 12 months trom the date of approval. ? ibbilk- Form 10-403(Revised 10/2012) ^ - CW 3/3/AC Submit Form and Attac m is in Duplicate 1/77-1/77- 711/5- RBD VA gl k ,344...)-6 �2'(' • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). ! • TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2L-308 Well ) under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K. Wharton. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283 (1)CPAI prepared the attached Notice of Operations("Notice"). 4. On or about February 24, 2015, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 24th day of February, 2015. LL Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 24th day of February, 2015, by Paul K.Wharton. r `ter. : ., . : .rti= " Notary Public, State of Alaska My Commission Expires: 1 STATE OF ALASKA ; NOTARY PUBLICnow^ REBECCA SWENSEN -Q anKs My Commission Expires Aug.27,2016 • • ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com Date: February 24, 2015 To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2L-308 Kuparuk River Unit, Alaska Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2L-308 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 24, 2015. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well on lease ADL 380052, KRU Tract 130; ADL 380051, KRU Tract 131; and ADL 25603, KRU Tract 90 as depicted on Exhibit 1 as follows: Surface Location: 160' FNL, 617' FEL, Section 22, T1ON, RO7E, UM Target Location: 2924' FNL, 4850' FEL, Section 18, T1ON, RO8E, UM Bottomhole Location: 277'FNL, 3853' FEL, Section 19, T1ON, 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, OLL) ' b(f6"°n-ef, Paul Wharton Staff Landman cc: Adam Klem 9 • 2L-308 Hydraulic Fracturing Notice Letter February 23, 2015 Page 2 Exhibit 1 6130/2012r<2 �,�, i' T11 N`8 ""_ © 69 31 2ii _ . ` ADL390680 upa CARACOL, r... m •W.S, ADL390681 TP, , 1;1VG 1 ADLO CARACOL, -6.-: MUSTANG OP, `` I C�, , #15, TP, / BP' , ISP USTANG OP, �// ----, 6/30/20 2- 74 CHEV-ON, f34 MEP I EXXON 1 OBI 6/30/2012 _Sou ei"1 ■ 3r211 9114 } , M jou ea / mile radius from U 'tj 2L-308 Well Ffupa ruk PA j 10NR8• 16 ,.' r PA I r L3:,. 111 111 ;3 so 17 CP' , o� 3cf'4 1 4P- OSP81 ADLO 5603 BP '`, ,til 2L CP h IEV ON, 057L 31 R:;:ilb,- 306 BP ON =11 9 y�_329 DS-2,, l M... HEV'ON, j� 8EYXO - e- 2L-30130 ofr "'�Lrr- t- 2�-t°a so 3/27/ 984 1 fi � BP ,� L-304 1 �, fE L 11 �, � _ �� ON MOB/22 w ' 1/34/20.03 131 N s124. I + i °' L-32 �t 307 �.z 41- 309 L d.2PB 1 L-3 < ? L-317 paru.k --- ) L-.-'2aL' 2L-3 1Ve, 7a h 3 -L,"`09 N-3 nit L-321 N-315 27 J i,-305 26 25 z 2N-308w i� —ADIA45608 29 DL3 0054 I: .*5A 2N 32 \ADL38#053 I C P•I, r7 2N- 2P�1 CP I, BP •, B1 Well Legend LN-N3-13111,,,4/1 =BP , CHEV•ON, :` EV-ON IPPI . •. „ • : PRODUCTION 2 1 INJECTION 3I t fil '1 131 '+ ConocoPhillips ,l N- 03 . -:04- PLUGGED and N-3I.A ABANDONED ,306 h Kuparuk River Unit Ip,; 3' 2L-308 Sources: -.'"--.33, ConocoPhillips Alaska Inc. C business records and onym..- Paul Wharton IPrepndby. LauruhnlRoso public records !I , FlleNam.: 15012002600 2L-308 I o.,.. 2-4-19 • S 2L-308 Hydraulic Fracturing Notice Letter February 23, 2015 Page 3 Exhibit 2 Mineral Owners: Kuparuk River Unit Lands Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Patrick J. Wolfe, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong ADL 390680 Operator Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 Non-Operators Caracol Petroleum LLC c/o Brooks Range Petroleum Corporation • • 2L-308 Hydraulic Fracturing Notice Letter February 23, 2015 Page 4 510 L Street, Suite 601 Anchorage, AK 99501 TP North Slope Development LLC c/o Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 Mustang Operations Company c/o Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 MEP Alaska LLC do Brooks Range Petroleum Corporation 510 L Street, Suite 601 Anchorage, AK 99501 Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director I S Section 2 — Plat 20 AAC 25.283 (a)(2) Southern Miluveach Unit ADL390681!ADL390680 ADL025590 DL02 ADL380062 5603 ya+• l , tiz'p %ape+ 2.\-- t 48 22305 " 2 110 71-319 ADL380051 C a 31z `b," 'h3 -43y x-� a_ )))3104-3'))...._____L_\------- 1 44' � I--Q,,-3,1. 'p� �\ Fya4:fi / 2L-304 4'4 s� c S.9. \ / /,.d T1 ON RiE T101N 080 Kuparuk ADL380054 River ADL025608 Unit Legend ADL380053 I®Open Section —Wklls Within Trajectory Radius .---Trajectory Wells in 1/2 Mile Open Radius Producer:Ott ggqg ® INJ:MWAG CPA]Operated Units 1 ®Other Operated Units Alaska Protracted Sections nBLM Townships a REFERENCES: y/ Nb0 Data:ConocoPhillipsAlaska Wells DatabaseATDa ConocoPhillips Surface Facilities:North Slope OK Survey 7/25112 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. N 2L-308 Plot Anaystto >No Potable Water Aquifers ain the Kuparuk River Unit A Wells 2/12/2015 re 05 • r Well Permit Well Name API PA Unit Number Status Type 2L-03 501032039800 KRU KUP 201-239 OPSH PROD 2L-301 501032058800 TARNDB KUP 208-192 ACTIVE INJ 2L-304 501032061300 TARNDB KUP 210-011 ACTIVE PROD 2L-305 501032027900 TARNDB KUP 198-240 ACTIVE INJ 2L-306 501032063000 TARNDB KUP 210-182-0 ACTIVE PROD 2L-306PB1 501032063070 TARNDB KUP 210-182-0 PA EXPEND 2L-307 501032028400 TARNDB KUP 198-256 ACTIVE PROD 2L-307L1 501032028460 TARNDB KUP 211-093-0 ACTIVE PROD 2L-307L2 501032028461 TARNDB KUP 211-094-0 ACTIVE PROD 2L-307L2- 01 501032028462 TARNDB KUP 211-136-0 ACTIVE PROD 2L-309 501032052100 TARNDB KUP 205-210 ACTIVE PROD 2L-309PB1 501032052170 TARNDB KUP 205-210 PA EXPEND 2L-310 501032061600 TARNDB KUP 210-028-0 ACTIVE INJ 2L-311 501032046900 TARNDB KUP 203-155 ACTIVE PROD 2L-312 501032062600 TARNDB KUP 210-164-0 ACTIVE PROD 2L-313 501032027700 TARNDB KUP 198-219 ACTIVE PROD 2L-314 501032068600 TARNDB KUP 214-023-0 ACTIVE PROD 2L-314PB1 501032068670 TARNDB KUP 214-023-0 PA EXPEND 2L-315 501032027600 TARNDB KUP 198-218 ACTIVE PROD 2L-317 501032033600 TARNDB KUP 200-060 PA PROD 2L-317A 501032033601 TARNDB KUP 200-210 ACTIVE INJ 2L-318 501032068100 TARNDB KUP 213-183-0 ACTIVE INJ 2L-319 501032055200 TARNDB KUP 207-112 ACTIVE INJ 2L-320 501032062700 TARNDB KUP 210-166-0 ACTIVE PROD 2L-320PB1 501032062770 TARNDB KUP 210-166-0 PA EXPEND 2L-320PB2 501032062771 TARNDB KUP 210-166-0 PA EXPEND 2L-321 501032028600 TARNDB KUP 198-262 ACTIVE PROD 2L-322 501032062800 TARNDB KUP 210-174-0 PA PROD 2L-322A 501032062801 TARNDB KUP 213-167-0 ACTIVE PROD 2L-322PB1 501032062870 TARNDB KUP 210-174-0 PA EXPEND 2L-323 501032028200 TARNDB KUP 198-251 ACTIVE INJ 2L-325 501032027500 TARNDB KUP 198-209 ACTIVE PROD 2L-326 501032059700 TARNDB KUP 209-027 ACTIVE PROD 2L-327 501032054200 TARNDB KUP 207-008 ACTIVE PROD 2L-329 501032027200 TARNDB KUP 198-198 PA PROD 2L-329A 501032027201 TARNDB KUP 198-225 ACTIVE INJ 2L-330 501032055400 TARNDB KUP 207-128 ACTIVE PROD • S 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 Order No. 2 — Milne Point Unit. Which states "Those .7 portions of freshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwater aquifers under 10 AAC 25.440" • S SECTION 4 — PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current orro osed wellbore p p trajectory and fracturing interval. A water well sampling plan is not applicable. • S 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: 2L-308: 10 & 3/4" casing cement pump report on 1/14/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.8 ppg mud. Returns we lost after dropping the plug to start displacement, then full returns were seen for the rest of the job. The plug bumped @ 1,000 psi and the floats were checked and they held. 7 & 5/8" casing cement pump report on 2/2/2015 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.7 ppg mud. Full returns were seen throughout the job. The plug bumped @ 800 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. i 0 • SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 1/16/2015 the10 & 3/4" casing was pressure tested to 3000 psi for 30 mins. On 2/5/2015 the 7 & 5/8" casing was pressure tested to 3000 psi for 30 mins. On 2/14/2015 the 7 & 5/8" casing and production packer were pressure tested to 3500 psi for 30 mins On 2/14/2015 the 3.5" tubing was pressure tested to 3500 psi for 30 mins. i S SECTION 8— PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collaspe 10 3/4" 45.5 L-80 5,210 psi 2,470 psi 7 5/8" 29.7 L-80 6,890 psi 4,790 psi 7 5/8" 39 TN-110 SS 12,620 psi 11,060 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi • S Stimulation Surface Rig-Up 3 Bleed/Tattle Tale Tank KA CA #ea0 w t 1 a> `/ 1 AL d I.1 U • Minimum pressure rating on all surface INCA KA 11101 treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure • IA parallel PRV set to 3500 psi CD = 000:4 • 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. 5 N N = } PVI - `ca Kcruy dwnd U Pop-Oft Tank E N Pop-Off Tank #tot Pump Truck C N d G Q. F J U C 54 J [li a Frac Pump [`„41 - -{ H/r-s Frac Pump a2 Frac Pump - N Frac Pump Frac Pump - -- - Frac Pump • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO!MANDREL INSERTION) (LiA'+;DREL INSERTED) n ,FRAC IRON I CONNECTION i.._ i i OM ft. T i tl „REMOTE OPERATED i -� MASTER VALVE ... ® 41 ItIlFrel II. O.ISju l_121 pMANUAL OPERATED ����' 1...$1#4....., MASTER VALVE iiltr.11 tlT.1 ot iAVIAN iii 6` 4111111:11111116 / Stinger I HI MANDREL I ^I I 111116111 \.i VENT �.:0 I$41----VALVE ,.=.: \\ OPEN i my oat aikm, YA ' ��§ _ _ • �• 01 •4� VA.1 7 FLOW TEE AND r^..- '$ % D • VENT VALVE WELLHEAD # ' � ii j."*;rlll VALVES I `, 1.7 4. OPEN #1",-.-,� a ,"" Mg T4 WELLHEAD VALVES ; j"1 CLOSED ---,.'? _ �.- ? _ 1 `✓. I ,,,,,,,•:.t.: *-,..•,, .}a ..., QUAD PACKOFF ASSEMBLY IN � 4 IPLACE IN TUBING I.i '' .e.1 TUBING ?a' • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 I/2 tubing and 1.75" down 3 1/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm • • Tam 2L-308 Bertha Grass Roots Tooset Pilot Hole Horizontal Multi-Stage Frac'd Producer Conoc©Phill�ps AS-BUILT Wellbore Schematic 1� 1 �7 CAMERON 4-W tree top joint is 4-W 12.6#IBTM,crossed over(for frac equipment) J I. J Bearden 2/14/2015 Conductor xrt, 16"62.6#HW-40 3875' DS Nipple 2.875 Effi 500'61131000'TVD 4 +I DriliPlex 13-112"Surface Hole �Ef 9.6 PP0 3%`x1"Cameo K861G Surface Casing: 10-3/4"45.5#L-80 Hydril 563 2,599'MD/2,313'TVD t 63° 3 555`o 1" moo KEMIG Campanian Top 3,315 MD,t2,soe `s LSND 0.6-10.0ppG 3Wxt-camcoKe61G Tktbinq: Keep up with 3-W 9.3#L-80 EUE8RD Dilution 4-W 12.6#L-80 IBTM top joint to surface 9-718"Intermediate Hole 35x1"Cemco.K8L1G EJTop of cement @ 9,530'MD (per SLB Sonic 2/4/2015)'• 31x1 r 08010 Iceberg Tnp 113 1'MD(asgz 1] Baker CMU Siding Sleeve CLOSED w/ FT 2.812"Camco'DS'Profile 10'above , - Down hole gauge—13,473'MD production packerII3.5"x 7-5/8",Baker Premier Packer 13,498'MD —, 3„Cameo D nipple nogo 2.75" can 7-58",ZXP Liner Top Packer 13;611'MD 7-5/8"x 4-W Baker Flex Lock Liner hanger w/RS Nipple, 13,635'MD Intermediate Casing Topset: 7-5/8"29.7#L-80&300'TN 110SS.9#—all Hydril 563 connections Ton of Betimuda 13.8174D(5,412'TVD1 13.763'.IV)D/5,399'11(12A.75°....:.:.......:. ,pewoction Haste 46 :-I s f€ »> f . MI A O 0 0 0 0 0 III 1111--- .:.:.:.:................................................................................:...:................. Production Uner(d)90": 4-1/2"12.6#L-80 IBTM(twi torque rings to rotate in Mer to TD) PerPd pupjoint for 13,583'MD to 17,095'MD 5,359'TVD to 5,500'TVD circulation le • SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that the fracturing zone, the Bermuda interval, is approximately 123' TVT (1,081' MD) thick at the heel and approximately 135' TVT at the toe of the well, with the top of the Bermuda starting at 13,812' MD/5,412' TVD. The Bermuda is a mix of laminated shale, siltstone, and sandstone with an estimated fracture pressure of—13.5 ppg. The confining zone of the C-37 to the T-3 is approximately 897' TVT(3,360' MD) thick, with the top of the C-37 starting at 10,332' MD/4,482' TVD. The C-37 to the T-3 is a mix of shale, siltstone, and sandstone lithologies with an estimated fracture pressure as high as —16 ppg. SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 2L-304: 7 5/8" casing cement pump report on 4/18/2010 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 8.6 ppg seawater. Full returns were seen throughout the displacement. The plug bumped @ 1,800 psi and the floats were checked and they held. 2L-319: 7" by 4.5" casing cement pump report on 10/25/2007 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 9.7 ppg drilling mud. There was no comment on returns, except that no cement was seen at surface. The plug did not bump, but the floats held. The CBL shows the TOC at 12,188'MD (5258' TVD). • • 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 there is one fault that transects the confining zone within one half mile radius of the wellbore trajectory for 2L-308. The northeast striking fault is approximately 2,160' from the nearest perforated zone in 2L-308. With expected induced fracture half-length of—316', the nearest induced fractures will be — 1,844' from where the fault intersects the reservoir. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent fault will not interfere with containment. • • / , Southern '` Miluveach Unit / A0L390681 I ADL390680 ADL025,590 N. ADL380052i 5603— 2L'30a j 2L 319 --- ADL380059 \\ 2L-304 1 T1ON R7E y �� T10N R8E — Kuparuk ADL3 0054 RiverADL025608 Unit I 1 Legend / 1 Q Fault in Radius $ l Open Section ADL380053 ®Trajectory Wells in 1/2 Mile Open Radius Producer:Oil INJ:MWAG \ . CPAI Operated Units ®Other Operated Units 'Alaska Protracted Sections nBLM Townships y 111/2 Mile Open Radius t 1/2 Mile Trajectory Radius REFERENCES: Vtlell Data:ConocoPhillipsAlaska Wells DatabaseATDB ConocoPhillips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil 8 Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Kuparuk River Unit. 2L-308 Plat Anaysis >No Potable Water Aquifers are in the Kuparuk River Unit Faults 3/2/2015 0.5 0 Moes 3s82OFracLeasenud 055 2/42015 * Map view depiction of seismically mapped faults and sub-seismic inferred faults (orientation unknown) from drilling data faults located within 1/2 mile radius of the reservoir well section (highlighted in red) in which the hydraulic fracture is planned. • • SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 2L-308 was completed in 2015 as horizontal producer in the Bermuda formation. The well was completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1st stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2nd stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Schlumberger Pumping Services: (Bermuda Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 22 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 9971 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test A Pop off syste fT ensure lines are clear and all components are functioning properly. 9. Pump the 171 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 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 @ 20bpm with a maximum expected treating pressure of 7489 psi. Stage 1 • 410 bbls YF127ST Pad • 125 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF125ST w/2 ppa 16/20 Carbolite • 150 bbls YF125ST w/3 ppa 16/20 Carbolite • 160 bbls YF125ST w/4 ppa 16/20 Carbolite • 180 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF125ST w/6 ppa 16/20 Carbolite • Drop ball 1 Stage 2 • 410 bbls YF127ST Pad • • • 125 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF125ST w/2 ppa 16/20 Carbolite • 150 bbls YF125ST w/3 ppa 16/20 Carbolite • 160 bbls YF125ST w/4 ppa 16/20 Carbolite • 180 bbls YF125ST w/5 ppa 16/20 Carbolite • 200 bbls YF125ST w/6 ppa 16/20 Carbolite • Drop ball 2 Stage 3 • 410 bbls YF127ST Pad • 125 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF125ST w/2 ppa 16/20 Carbolite • 150 bbls YF125ST w/ 3 ppa 16/20 Carbolite • 160 bbls YF125ST w/4 ppa 16/20 Carbolite • 180 bbls YF125ST w/5 ppa 16/20 Carbolite • 200 bbls YF125ST w/6 ppa 16/20 Carbolite • Drop ball 3 Stage 4 • 410 bbls YF127ST Pad • 125 bbls YF125ST w/ 1 ppa 16/20 Carbolite • 125 bbls YF125ST w/2 ppa 16/20 Carbolite • 150 bbls YF125ST w/3 ppa 16/20 Carbolite • 160 bbls YF125ST w/4 ppa 16/20 Carbolite • 180 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 200 bbls YF125ST w/ 6 ppa 16/20 Carbolite • Drop ball 4 Stage 5 • 450 bbls YF127ST Pad • 120 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF127ST w/2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF127ST w/4 ppa 16/20 Carbolite • 110 bbls YF127ST w/5 ppa 16/20 Carbolite • 120 bbls YF127ST w/6 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 8 ppa 16/20 Carbolite • Drop ball 5 Stage 6 • 450 bbls YF127ST Pad • 120 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 120 bbls YF127ST w/2 ppa 16/20 Carbolite • 110 bbls YF127ST w/3 ppa 16/20 Carbolite • 110 bbls YF127ST w/4 ppa 16/20 Carbolite • 110 bbls YF127ST w/5 ppa 16/20 Carbolite • 120 bbls YF127ST w/6 ppa 16/20 Carbolite • • • 130 bbls YF127ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 8 ppa 16/20 Carbolite • Drop ball 6 Stage 7 • 450 bbls YF127ST Pad • 120 bbls YF127ST w/ 1 ppa 16/20 Carbolate • 120 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 110 bbls YF127ST w/4 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 120 bbls YF127ST w/ 6 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 7 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 8 ppa 16/20 Carbolite • Flush with 56 bbls of linear fluid (YF127ST) • Flush with 56 bbls of linear fluid (WF127) and freeze protect • Total Sand: Approx. 950,054 lbs 16/20 Carbolite 12. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 13. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). ` • S ATTACHMENT I:PUMP SCHEDULE MAWP Slurry Rate 20 Highest Pump Trip Proppant Density 2.74 Well Name 2L308 AFE Nitrogen PRV Annulus Pressure Fluid Type YF127ST Proppant Used 18120 CarboLile STEP STAGE COMMENTS FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. # # TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (f#MgH( 1 Injection test WF127 20 20.0 171 171 7187 7187 171 171 8.0 Hard shutdown;monitor pressure. 0.0 2 Pad YF127ST 20 20.0 80 251 3360 10547 80 251 8.0 3 1 Sand YF127ST 20 19.2 50 301 2100 12647 2012 2012 lens Cutouts 48 299 8.0 4 Spacer YF127ST 20 20.0 80 381 3360 16007 80 379 8.0 5 Displacement WF127 20 20.0 171 552 7187 23194 171 550 8.0 Hard shutdown;monitor pressure. FLUID PUMP CF DIRTY VOLUME DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. STEP ST GE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker # PPA (BPM) (BPM( (BBL) (BBL) (GAL) (GAL) (LOS) (LBS) (BBL) (BBL) (#1M901) 8 PAD YF127ST 20 20.0 410 962 17220 40414 0 2012 0 410 960 8.0 7 1 FLAT YF127ST 20 19.2 125 1087 5250 45664 5030 7,042 16/20 CarboLfa 120 1060 9.0 8 2 FLAT YF127ST 20 18.4 125 1212 5250 50914 9655 16,697 tH006arboute 115 1195 10.0 9 3 FLAT YF127ST 20 17.7 150 1362 6300 57214 16707 33,404 169e0arbOUte 133 1327 11.0 10 4 FLAT YF127ST 20 17.0 160 1522 6720 63934 22876 56,279 16/29 carboure 136 1464 12.0 11 5 FLAT. YF127ST 20 16.4 160 1702 7560 71494 31014 87,293 HO cameos 148 1611 13.0 12 6 FLAT YF127ST 20 15.8 200 1902 8400 79894 39919 127.212 ten60arbOL8n 158 1770 14.0 13 Ball 1.51" DISPLACE YF127ST 20 20.0 10 1912 420 80314 0 127.212 10 1780 8.0 14 PAD YF127ST 20 20.0 410 2322 17220 97534 0 127,212 410 2190 8.0 15 1 FLAT YF127ST 20 19.2 125 2447 5250 102784 5030 132.242 16120 Carbaia 120 2309 9.0 16 2 FLAT YF127ST 20 18.4 125 2572 5250 108034 9655 141,897 16120 CorboUte 115 2424 10.0 17 3 FLAT YF127ST 20 17.7 150 2722 6300 114334 16707 158,604 lsrz0 Cabala 133 2557 11.0 10 4 FLAT YF127ST 20 17.0 160 2882 6720 121054 22876 181,479 16120 CoboUle 136 2693 12.0 19 5 FLAT YF127ST 20 16.4 180 3062 7560 128614 31014 212,494 ions Carboua 148 2841 13.0 20 6' FLAT YF127ST 20 15.8 200 3262 8400 137014 39919 252,412 16/200.aPoajte 158 2999 14.0 21 Ball 1.635" DISPLACE YF127ST 20 20.0 10 3272 420 137434 0 252,412 10 3009 8.0 22 PAD YF127ST 20 20.0 410 3682 17220 154654 0 252,412 410 3419 8.0 23 1 FLAT YF127ST 20 19.2 125 3807 5250 159904 5030 257,442 I0120 Cartaua 120 3539 9.0 24 2 FLAT YF127ST 20 18.4 125 3932 5250 165154 9655 267,097 t5rz6 cabala 115 3654 10.0 25 3 FLAT YF127ST 20 17.7 150 4082 6300 171454 16707 283,804 torso LaMothe 133 3787 11.0 26 4 FLAT YF127ST 20 17.0 160 4242 6720 178174 22876 306,680 16/20 Carboua 136 3923 12.0 27 5 FLAT YF127ST 20 16.4 180 4422 7560 185734 31014 337,694 16x0 arboule 148 4070 13.0 28 6 FLAT YF127ST 20 15.8 200 4622 8400 194134 39919 377,612 169000rboUa 158 4229 14.0 29 Ball 1.76" DISPLACE YF127ST 20 20.0 10 4632 420 194554 0 377,612 10 4239 8.0 30 PAD YF127ST 20 20.0 410 5042 17220 211774 0 377,612 410 4649 8.0 31 1 FLAT YF127ST 20 19.2 125 5167 5250 217024 5030 382,642 16/20 carbaua 120 4769 9.0 32 2 FLAT YF127ST 20 18.4 125 5292 5250 222274 9655 392,297 1620 Cart/tithe 115 4883 10.0 33 3 FLAT YF127ST 20 17.7 150 5442 6300 228574 16707 409,004 1612002.Seute 133 5016 11.0 34 4 FLAT YF127ST 20 17.0 160 5602 6720 235294 22876 431,880 16YDscarmuts 136 5152 12.0 35 5 FLAT YF12751 20 16.4 180 5782 7560 242854 31014 462,894 16120 Cae0eUt.'. 148 5300 13.0 36 6 FLAT YF127S1 20 15.8 200 5982 8400 251254 39919 502,813 memCarmua 158 5458 14.0 53 Ball 1.805" DISPLACE YF127ST 25 25 10 5992 420 251674 0 502,813 10 5468 8.0 54 PAD YF127ST 25 25.0 450 6442 18900 270574 0 502.813 450 5918 8.0 55 1 FLAT YF127ST 25 24.0 120 6562 5040 275614 4829 507,641 165e Cabana 115 6033 9.0 56 ..2 FLAT YF127ST 25 23.0 120 6682 5040 280654 9269 516,910 16120 CarboLile 110 6144 10.0 57 3 FLAT YF127ST 25 22.1 110 8792 4620 285274 12252 529,162 16rz8CarboUte 97 6241 11.0 58 4 FLAT YF127ST 25 21.3 110 6902 4620 289894 15727 544,889 16120 CarboLile 94 6335 12.0 59 5 FLAT YF127ST 25 20.5 110 7012 4620 294514 18953 563,842 maseaeba;le 90 6425 13.0 60 6 FLAT YF12751 25 19.8 120 7132 5040 299554 23951 587,793 16noCarbolite 95 6520 13.0 61 7 FLAT YF12751 25 19.1 130 7262 5460 305014 29258 617,051 tsrz000rboIge 100 6619 14.0 62 8 FLAT YF12731 25 18.5 140 7402 5880 310894 34842 651,893 lS200adwuIe 104 6723 14.0 63 Ba))1.940" DISPLACE YF12701 25 25.0 10 7412 420 311314 0 651,893 10 6733 8.0 64 PAD YF127ST 25 25.0 450 7862 18900 330214 0 651,893 450 7183 8.0 65 1 FLAT YF12751 25 24.011 120 7982 5040 335254 4829 656,722 isms carbnLtle 120 7303 9.0 66 2 FLAT YF127ST 25 23.0 120 8102 5040 340294 9269 665,990 16x70 Ca/balite 120 7423 10.0 67 3 FLAT YF12751 25 22.1 110 8212 4620 344914 12252 678,242 16/20 carboute 110 7533 11.0 68 4 FLAT YF127ST 25 21.3 110 8322 4620 349534 15727 693,969 16/24 carboUa 110 7643 12.0 09 5 FLAT YF127ST 25 20.5 110 8432 4620 354154 18953 712,922 i6900arb0L1le 110 7753 13.0 7D 6 FLAT YF127ST 25 19.8 120 8552 5040 359194 23951 736,873 1620caeb0Lia 120 7873 13.0 71 7 FLAT YF127S1 25 19.1 130 8682 5460 364654 29258 766,131 1600 Caboule 130 8003 14.0 72 8 FLAT YF127ST 25 18.5 140 8822 5880 370534 34842 800,973 t6ROCaeba.ia 140 8143 14.0 93 Ball 2.010" DISPLACE YF127ST 25 25 10 8832 420 370954 0 800,973 10 8153 8.0 94 PAD YF127S1 25 25.0 450 9282 18900 389854 0 800,973 450 8603 8.0 95 1 FLAT YF127ST 25 24.0 to 120 9402 5040 394894 4829 805,802 1620 cabala 115 8718 9.0 96 2 FLAT YF127ST 25 23.0 128 9522 5040 399934 9269 815,071 tormcarbaJa 110 8828 10.0 97 3 FLAT YF127ST 25 22.1 110 9632 , 4620 404554 12252 827,322 16120Carbata 97 8926 11.0 98 4 FLAT YF127ST 25 21.3 110 9742 4620 409174 15727 843,050 16120Carballe 94 9019 12.0 99 5 FLAT YF127ST 25 20.5 110 9852 4620 413794 18953 862,003 16Imearbolite 90 9109 13.0 100 6 FLAT YF127ST 25 19.8 120 9972 , 5040 418834 23951 885,954 was Carbothe 95 9204 13.0 101 7 FLAT YF127ST 25 19.1 130 10102 5460 424294 29258 915,211 16/200arboUle 100 9304 14.0 102 8 FLAT YF127ST 25 18.5 140 10242 5880 430174 34842 950,054 16m0CarboUte 104 9408 14.0 103 FLUSH YF127ST 25 25.0 56 10299 2370 432544 56 9464 16.0 104 FLUSH WF127 25 25.0 56 10355 2370 434914 56 9521 16.0_ 105 FLUSH Freezeprotect 25 25.0 . 19 10374 804 435718 19 9540 _ TOTALS 10374 950054 9540 SD and obtain ISIP S 5 min SIP. WATER VOL FLUSH INFORMATION WELL AND TREATING PRESSURE INFORMATION MODEL AND FRAC.ORIENTATION INFORMATION DataFRAC= 550 bbls VOL TO TOP Farr=1135.1 ISIP GRADIENT= 0.76 BHP=4152 psi IVO Pert H,R= MAIN JOB= 8970 bbls Germ 450 bbis -UNOERFLUSHO 3.0 FLUID SG= 1.030 +TBG FRIG=4663 psi TOTAL JOB= 9521 bbls FLUSH VOL=132 FRICTION LOSS= 0.2798 0 PERF FR1L=0300 psi 9971 bbls -with contingency MD TO Tb9 Tail= 13114 .HYD HEAD=2440 psi Angle Through Parrs= GENERAL JOB INFO NO BTM SLEEVE= 5463 EST.MAX WHP=6675 psi Wee Azimuth(Moab). TANKS REQUIRED PIPE TIME(min)=6.8 MD FIRST SLEEVE= 16666 alMi..• 22.16 <=450 bit per tank pumpable PAD/SLURRY RATIO Stage 1 30% Stage 6 32% Stage 230% Stage7 32% TOTALS FOR 11 STAGES Stage 3 30% Stage 8 UPPER TUBING SIZE' 3.5000 0.0087 bbAJR Porosity= Stage 4 30% Stage9 MIDDLE TUBING SIZE= bbls./ft Water 9971 bbls Stage 532% Stage 10 LOWER TUBING SIZE= bus./8 Reservoir Pressure=3400 Xltnk fluid 9178 bbls Stage Ports MD Displac4 LENGTH MIDDLE TBG= Penreabd0y= Linear fluid 399 bbls name ft volume Seat Sine LENGTH LOWER TBG= Temperature=160 Proppant 960,064 lb Stage 16666 168.1 bbls Perf Sub CASING SIZE= 4.5000 0.0162 bbAJS Diesel 57 bbls • Stage2 16310 162.7 bbls 1.61 J475 3,122 lb Stage 3 16953 157.3 bole 1.636 • • Punp time 07154:45 hh:mm:ss Stage4 16697 151.9 bole 1.760 • Stage 5 15211 196.0 bbls 1.886 • J475 3,122 IS Stage 6 14864 140.6 bbls 1.948 LOSS 801 gal Stage7 14498 135.1 bbis 2.010 F103 401 gal J532 1,927 gal M002 TBD lb 8882 2,524 gal 0302-15 • • Client: ConocoPhillips Alaska Inc. Schlumberger Well: 2L-308 Basin/Field: Colville-Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 2/9/2015 4:40 PM Report ID: RPT-34605 Fluid Name&Volume Additive Additive Description Concentration Volume B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 2,530.0 Gal D047 AntiFoam Agent 0.2 Gal/1000 Gal 80.0 Gal F103 Surfactant 1 Gal/1000 Gal 400.0 Gal J218 Breaker 0.1 Lb/1000 Gal 25.0 Lb YF1275T:WF127 402,234 Gal J475 Breaker 7.8 Lb/1000 Gal 3,130.0 Lb J532 Crosslinker 4.8 Gal/1000 Gal 1,930.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 800.0 Gal M002 Additive 0.6 Lb/1000 Gal 240.0 Lb M275 Bactericide 0.6 Lb/1000 Gal 235.0 Lb S522-1620 Propping Agent varied concentrations 950,054.0 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)* -77% 66402-68-4 Ceramic materials and wares,chemicals "'22% 64742-47-8 Distillates(petroleum),hydrotreated light <1% 9000-30-0 Guar gum <1% 56-81-5 1,2,3-Propanetriol <1% 1303-96-4 Sodium tetraborate decahydrate <0.1% 7727-54-0 Diammonium peroxidisulphate <0.1% 107-21-1 Ethylene glycol <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 25322-69-4 Polypropylene glycol <0.1% 67-63-0 Propan-2-ol <0.1% 111-76-2 2-butoxyethanol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1% 7647-14-5 Sodium chloride <0.01% 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01% 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01% 68131-39-5 C12-15 alcohol ethyoxylated <0.01% 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) <0.01% 1310-73-2 Sodium hydroxide(impurity) <0.01% 7631-86-9 Silicon Dioxide <0.01% 10043-52-4 CALCIUM CHLORIDE <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01% 10377-60-3 Magnesium nitrate <0.001% 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 111-46-6 2,2"-oxydiethanol(impurity) <0.001% 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001% 7786-30-3 Magnesium chloride <0.001% 68153-30-0 Amine treated smectite clay <0.001 % 9002-84-0 poly(tetrafluoroethylene) <0.001% 7447-40-7 Potassium chloride(impurity) <0.001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001% 14808-60-7 Crystalline silica(impurity) <0.0001% 14464-46-1 Cristobalite <0.0001% Total 100% t 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. O -t 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. Page:1/1 • • a) o) co 17.' I-5 2 28 co o -a 2U 4 5 Li.. ca COO cr) J CN • • o = a. 00000000 I- V 3 o •— •N ri •v •0 0• •o o 0 0 0 CD CD NNNNNN L CO CO CO O CSO O N T- O N 4) (1) 4) 4) 4) 4) 5 J J J J J J C 73R U o U U o U w, 0) - > ■ monni U) _ ca _� _Q III) d C N N N N N N N N (1)aii ♦ N CO _0 O 0 0) 76 CO a, `� r.--- CI) O C:) r- e) :a E a oN CO coNCO ti oN o N O 0) N 07 CO O U (IIIZ cu E cocoN- N- N- N- N- N- co N- N 1111 Z NNNNNNN L- = r >- r r r >- � 3 UM= IT. O E r' (Q R E 0 CD CD 0 0 0 CD 0 a re .Q N N N N N N N N r _ ^' -0 a a < < Q__ < Imo- N 0 QE a O Q IL CL CL N m R O O o O O O LL r Z r N (`') V' O O L � S' U • 4- N O - u) = So ,i (6 O U c L , 4••• CCS u) O N 1.1 c — ; m, a) 0):4= CD IX) 0) 0)5 -o C6 ir) in M N - -?-• C C •� CO N E 'L — N •c O -Cu a) D11111 C E u) U U) Cl) Ea) ' (13c o 4- ..~O ca C 0U 0 =' O o_ — oc E 8 LL — a) }, = U uj c6 a) H O 0 C Cl)0 co 0 0• CCS O F- m L4-, a) . . CC� �; .4_79 L 2 ED. L c ,� V 0) N p c13 0 vacva �" a o , 0.' i- ' L L -0 -0 a) Z � 0 0 c ,�. O u_ CD � L. L CO c 2 u9 To To Q. _,CL I L W -0 0) " C6 C6 a) = Sawa E 'a) � -4 c a.) a) C c/ o 0 = •— o -0 — � ov) U) 000 � F- E EE . • • SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to a disposal well until they are clean enough for production.) 0 21 4151 25466 ConocoPhillips DATA LOGGED TRANSMITTAL3 /5ini5 KBENDER RECEIVED i. . IAL DA No fl Co 6\6L '6J m6ak#IAR 04 2015 FROM: Sandra D. Lemke, ATO14-1412 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC AOGCC P.O. Box 100360 333 W. 7th Ave. #100 !rl V Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539 RE: 2L-308 DATE: 02/28/2015 Transmitted: Kuparuk River Unit, Alaska 2L-308 1 hardcopy report and 1 CD of final report w/log images Halliburton Surface Data Logging- End of well report for 2L-308; 02/13/2015; ; 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 Formation log -CVE gas extraction - MD Gas ratio -CVE gas extraction - MD Drilling dynamics -CVE gas extraction - MD CD contains Final log files, End of well report, final LAS exports, log viewers Please promptly sign, scan and return electronically to Sandra.D.LemkeCOP.com CC: 2L-308 transmittal folder, production well files, eSearch Receipt: I 2 t4 -'i) 5e4C: m " GIS-Technical Data Management I ConocoPhillips !Anchorage, Alaska I Ph: 90Z265.6947 • 21 41 51 ii EC IVEL 25 43 1 FEB 19 2201``5 Schlumberger AOGCv Transmittal#: 19FEB15-SP02 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery BENDER KV M.K.BENDE Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2L-308 Date Dispatched: 19-Feb-15 Job#: 14AKA0120 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 Top of Cement x x 9150'to 13900' LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A Nad27 As-Built Survey N/A Contents on CD N/A Nad83 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 AlaskaPTSPrintCenter@slb.com Catherine Roso Attn: Stephanie Pacillo 907-265-6189 ATO 1707 � 6..�%�G_"' Received By: 2 1 41 51 i giECEIVED 2 5 4 3 0 FEB 19 2015 Schlumberger AOGCC Drilling & Measurements Transmittal#: 19FEB15-SPO1 DATA LOGGED MWD/LWD Log Product Delivery z /%9/2015 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2L-308 Date Dispatched: 19-Feb-15 Job#: 14AKA0120 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©conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn: Stephanie Pacillo 907-265-6189 ATO 1707 7),),Lit_frut.„ 6Received By: 1 4 • • 214151 25 430 RECEIVED FEB 1 9 2015 AOGCC FINAL NADConversion NADConversion Kuparuk River Unit Kuparuk 2L Pad 2L-308 Definitive Survey Report NAD 27 17 February, 2015 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 2L-308(Bertha) Well Position +N/-S 0.00 usft Northing: 5,927,685.10 usft Latitude: 70°12'48.171 N +EI-W 0.00 usft Easting: 461,034.21 usft Longitude: 150°18'51.316 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 114.80 usft Wellbore 2L-308 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2014 12/12/2014 18.82 80.78 57,551 Design 2L-308 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 40.00 0.00 0.00 72.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.83 918.14 2L-308 Srvy#1-GYD-GC-SS(2L-308) GYD-GC-SS Gyrodata gyro single shots 1/13/2015 2:3: 977.46 2,531.61 2L-308 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/13/2015 3:0 2,676.20 13,704.01 2L-308 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/29/2015 12:2 13,797.81 17,032.45 2L-308 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2015 2:2 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 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,685.10 461,034.21 0.00 0.00 UNDEFINED 78.83 0.14 147.35 78.83 -75.97 -0.04 0.03 5,927,685.06 461,034.23 0.36 0.01 GYD-GC-SS(1) 171.15 0.21 126.12 171.15 16.35 -0.23 0.22 5,927,684.86 461,034.43 0.10 0.14 GYD-GC-SS(1) 260.49 0.45 29.56 260.49 105.69 -0.03 0.53 5,927,685.07 461,034.74 0.58 0.49 GYD-GC-SS(1) 352.21 2.39 23.92 352.18 197.38 2.04 1.48 5,927,687.13 461,035.70 2.12 2.04 GYD-GC-SS(1) 447.52 3.21 11.57 447.37 292.57 6.47 2.82 5,927,691.55 461,037.06 1.06 4.68 GYD-GC-SS(1) 541.92 4.42 15.67 541.56 386.76 12.56 4.34 5,927,697.63 461,038.61 1.31 8.00 GYD-GC-SS(1) 635.72 5.26 15.07 635.03 480.23 20.19 6.43 5,927,705.26 461,040.74 0.90 12.35 GYD-GC-SS(1) 729.80 7.08 20.18 728.56 573.76 29.80 9.55 5,927,714.85 461,043.91 2.02 18.29 GYD-GC-SS(1) 779.90 9.30 20.43 778.14 623.34 36.49 12.03 5,927,721.52 461,046.42 4.43 22.72 GYD-GC-SS(1) 825.45 12.03 21.93 822.90 668.10 44.34 15.09 5,927,729.36 461,049.52 6.02 28.05 GYD-GC-SS(1) 918.14 15.37 25.49 912.94 758.14 64.40 23.98 5,927,749.37 461,058.52 3.71 42.71 GYD-GC-SS(1) 977.46 16.52 25.98 969.98 815.18 79.08 31.06 5,927,764.01 461,065.67 1.95 53.98 MWD+IFR-AK-CAZ-SC(2) 1,072.80 16.76 35.79 1,061.35 906.55 102.42 45.04 5,927,787.27 461,079.77 2.95 74.49 MWD+IFR-AK-CAZ-SC(2) 1,166.54 16.25 46.66 1,151.25 996.45 122.39 62.49 5,927,807.15 461,097.32 3.33 97.25 MWD+IFR-AK-CAZ-SC(2) 2/17/2015 9:28:49AM Page 2 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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) (°/100') (ft) Survey Tool Name 1,261.19 16.42 50.04 1,242.08 1,087.28 140.07 82.38 5,927,824.73 461,117.30 1.02 121.63 MWD+IFR-AK-CAZ-SC(2) 1,355.54 16.06 53.84 1,332.67 1,177.87 156.33 103.13 5,927,840.88 461,138.14 1.19 146.40 MWD+IFR-AK-CAZ-SC(2) 1,450.13 16.38 61.36 1,423.50 1,268.70 170.45 125.41 5,927,854.88 461,160.48 2.24 171.94 MWD+IFR-AK-CAZ-SC(2) 1,544.61 17.87 66.40 1,513.79 1,358.99 182.64 150.38 5,927,866.94 461,185.52 2.22 199.46 MWD+IFR-AK-CAZ-SC(2) 1,637.82 21.17 71.08 1,601.64 1,446.84 193.82 179.42 5,927,877.98 461,214.61 3.92 230.53 MWD+IFR-AK-CAZ-SC(2) 1,733.75 24.41 73.02 1,690.07 1,535.27 205.23 214.77 5,927,889.20 461,250.02 3.47 267.68 MWD+IFR-AK-CAZ-SC(2) 1,782.85 26.99 73.56 1,734.31 1,579.51 211.35 235.17 5,927,895.21 461,270.44 5.28 288.97 MWD+IFR-AK-CAZ-SC(2) 1,827.89 29.53 74.35 1,773.98 1,619.18 217.24 255.66 5,927,900.99 461,290.96 5.70 310.28 MWD+IFR-AK-CAZ-SC(2) 1,876.68 32.16 75.76 1,815.86 1,661.06 223.68 279.83 5,927,907.31 461,315.16 5.59 335.25 MWD+IFR-AK-CAZ-SC(2) 1,922.33 34.21 75.69 1,854.07 1,699.27 229.84 304.04 5,927,913.34 461,339.40 4.49 360.19 MWD+IFR-AK-CAZ-SC(2) 1,967.54 36.31 77.28 1,890.98 1,736.18 235.93 329.42 5,927,919.30 461,364.81 5.07 386.20 MWD+IFR-AK-CAZ-SC(2) 2,016.69 38.07 77.82 1,930.13 1,775.33 242.33 358.43 5,927,925.55 461,393.85 3.64 415.77 MWD+IFR-AK-CAZ-SC(2) 2,111.56 41.45 77.86 2,003.05 1,848.25 255.11 417.74 5,927,938.02 461,453.21 3.56 476.12 MWD+IFR-AK-CAZ-SC(2) 2,206.28 44.15 76.99 2,072.55 1,917.75 269.13 480.54 5,927,951.72 461,516.08 2.92 540.18 MWD+IFR-AK-CAZ-SC(2) 2,300.34 48.02 74.02 2,137.78 1,982.98 286.14 546.10 5,927,968.39 461,581.72 4.70 607.79 MWD+I FR-AK-CAZ-SC(2) 2,395.33 50.82 73.63 2,199.57 2,044.77 306.24 615.38 5,927,988.13 461,651.10 2.96 679.89 MWD+IFR-AK-CAZ-SC(2) 2,444.66 54.35 75.55 2,229.54 2,074.74 316.63 653.15 5,927,998.33 461,688.91 7.79 719.02 MWD+IFR-AK-CAZ-SC(2) 2,490.27 55.89 75.33 2,255.62 2,100.82 326.04 689.36 5,928,007.55 461,725.17 3.40 756.37 MWD+IFR-AK-CAZ-SC(2) 2,531.61 59.09 76.51 2,277.83 2,123.03 334.51 723.17 5,928,015.84 461,759.02 8.11 791.15 MWD+IFR-AK-CAZ-SC(2) 2,599.00 60.00 76.43 2,311.99 2.157.19 348.11 779.65 5,928,029.14 461,815.57 1.36 849.06 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,676.20 61.05 76.33 2,349.97 2,195.17 363.94 844.97 5,928,044.63 461,880.96 1.36 916.07 MWD+IFR-AK-CAZ-SC(3) 2,769.53 64.18 76.40 2,392.89 2,238.09 383.47 925.49 5,928,063.75 461,961.58 3.35 998.69 MWD+IFR-AK-CAZ-SC(3) 2,859.83 68.05 75.04 2,429.45 2,274.65 403.84 1,005.49 5,928,083.71 462,041.67 4.50 1,081.07 MWD+IFR-AK-CAZ-SC(3) 2,953.89 71.73 74.48 2,461.79 2,306.99 427.06 1,090.69 5,928,106.49 462,126.98 3.95 1,169.28 MWD+IFR-AK-CAZSC(3) 3,048.34 74.21 73.91 2,489.45 2,334.65 451.66 1,177.58 5,928,130.63 462,213.98 2.69 1,259.51 MWD+IFR-AK-CAZ-SC(3) 3,143.12 75.37 74.30 2,514.31 2,359.51 476.71 1,265.54 5,928,155.22 462,302.06 1.29 1,350.91 MWD+IFR-AK-CAZ-SC(3) 3,237.18 74.81 74.22 2,538.51 2,383.71 501.36 1,353.02 5,928,179.43 462,389.67 0.60 1,441.73 MWD+IFR-AK-CAZ-SC(3) 3,333.38 75.04 74.75 2,563.53 2,408.73 526.21 1,442.53 5,928,203.81 462,479.29 0.58 1,534.53 MWD+IFR-AK-CAZ-SC(3) 3,426.52 74.89 75.19 2,587.70 2,432.90 549.54 1,529.40 5,928,226.68 462,566.27 0.48 1,624.36 MWD+IFR-AK-CAZ-SC(3) 3,520.96 74.33 75.24 2,612.76 2,457.96 572.77 1,617.44 5,928,249.46 462,654.42 0.60 1,715.27 MWD+IFR-AK-CAZ-SC(3) 3,615.49 74.45 76.00 2,638.20 2,483.40 595.38 1,705.63 5,928,271.61 462,742.72 0.78 1,806.13 MWD+IFR-AK-CAZ-SC(3) 3,713.36 74.28 75.73 2,664.57 2,509.77 618.40 1,797.02 5,928,294.16 462,834.22 0.32 1,900.17 MWD+IFR-AK-CAZ-SC(3) 3,801.83 74.33 74.88 2,688.51 2,533.71 640.00 1,879.41 5,928,315.33 462,916.71 0.93 1,985.20 MWD+IFR-AK-CAZ-SC(3) 3,896.78 74.22 73.83 2,714.24 2,559.44 664.65 1,967.42 5,928,339.52 463,004.84 1.07 2,076.51 MWD+IFR-AK-CAZ-SC(3) 3,990.57 74.36 72.16 2,739.64 2,584.84 691.06 2,053.75 5,928,365.48 463,091.30 1.72 2,166.78 MWD+IFR-AK-CAZ-SC(3) 4,084.36 74.40 71.21 2,764.89 2,610.09 719.44 2,139.50 5,928,393.42 463,177.18 0.98 2,257.11 MWD+IFR-AK-CAZ-SC(3) 4,178.54 74.39 70.70 2,790.23 2,635.43 749.04 2,225.25 5,928,422.57 463,263.07 0.52 2,347.80 MWD+IFR-AK-CAZ-SC(3) 4,273.84 74.30 71.89 2,815.94 2,661.14 778.47 2,312.16 5,928,451.55 463,350.13 1.21 2,439.56 MWD+IFR-AK-CAZ-SC(3) 4,369.09 74.27 74.29 2,841.75 2,686.95 805.13 2,399.88 5,928,477.76 463,437.97 2.43 2,531.22 MWD+IFR-AK-CAZ-SC(3) 4,462.91 73.80 74.20 2,867.55 2,712.75 829.63 2,486.69 5,928,501.80 463,524.90 0.51 2,621.35 MWD+IFR-AK-CAZ-SC(3) 4,557.75 73.85 75.21 2,893.97 2,739.17 853.65 2,574.55 5,928,525.37 463,612.88 1.02 2,712.34 MWD+IFR-AK-CAZ-SC(3) 4,653.01 73.74 75.19 2,920.56 2,765.76 877.02 2,662.99 5,928,548.28 463,701.43 0.12 2,803.67 MWD+IFR-AK-CAZ-SC(3) 4,747.08 73.27 75.83 2,947.26 2,792.46 899.59 2,750.32 5,928,570.40 463,788.86 0.82 2,893.70 MWD+IFR-AK-CAZ-SC(3) 2/17/2015 9:28:49AM Page 3 COMPASS 5000.1 Build 65 • • . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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) (°I100') (ft) Survey Tool Name 4,842.59 73.29 74.87 2,974.74 2,819.94 922.72 2,838.82 5,928,593.07 463,877.47 0.96 2,985.01 MWD+IFR-AK-CAZ-SC(3) 4,936.09 73.27 73.90 3,001.64 2,846.84 946.83 2,925.06 5,928,616.73 463,963.82 0.99 3,074.48 MWD+IFR-AK-CAZ-SC(3) 5,031.09 73.30 72.82 3,028.97 2,874.17 972.88 3,012.23 5,928,642.33 464,051.12 1.09 3,165.44 MWD+I FR-AK-CAZ-SC(3) 5,125.66 73.83 71.88 3,055.72 2,900.92 1,000.38 3,098.67 5,928,669.38 464,137.69 1.11 3,256.14 MWD+I FR-AK-CAZ-SC(3) 5,220.44 74.31 70.84 3,081.74 2,926.94 1,029.51 3,185.02 5,928,698.06 464,224.19 1.17 3,347.27 MWD+IFR-AK-CAZ-SC(3) 5,315.54 74.33 71.11 3,107.44 2,952.64 1,059.36 3,271.58 5,928,727.46 464,310.89 0.27 3,438.82 MWD+I FR-AK-CAZ-SC(3) 5,409.67 74.31 71.39 3,132.88 2,978.08 1,088.49 3,357.40 5,928,756.14 464,396.85 0.29 3,529.44 MWD+IFR-AK-CAZ-SC(3) 5,504.42 74.36 71.15 3,158.46 3,003.66 1,117.79 3,443.80 5,928,784.99 464,483.39 0.25 3,620.66 MWD+IFR-AK-CAZ-SC(3) 5,598.32 74.31 71.40 3,183.82 3,029.02 1,146.81 3,529.43 5,928,813.57 464,569.16 0.26 3,711.07 MWD+IFR-AK-CAZ-SC(3) 5,693.20 74.28 73.27 3,209.50 3,054.70 1,174.53 3,616.45 5,928,840.83 464,656.32 1.90 3,802.40 MW D+I FR-AK-CAZ-SC(3) 5,788.33 74.42 73.91 3,235.17 3,080.37 1,200.41 3,704.32 5,928,866.26 464,744.31 0.66 3,893.97 MWD+I FR-AK-CAZ-SC(3) 5,883.37 74.31 74.47 3,260.78 3,105.98 1,225.34 3,792.38 5,928,890.73 464,832.49 0.58 3,985.42 MWD+IFR-AK-CAZ-SC(3) 5,977.51 74.30 74.40 3,286.25 3,131.45 1,249.66 3,879.69 5,928,914.60 464,919.91 0.07 4,075.97 MWD+IFR-AK-CAZ-SC(3) 6,072.19 74.28 74.73 3,311.88 3,157.08 1,273.92 3,967.55 5,928,938.40 465,007.89 0.34 4,167.02 MWD+IFR-AK-CAZ-SC(3) 6,167.31 74.51 74.53 3,337.47 3,182.67 1,298.20 4,055.88 5,928,962.22 465,096.34 0.32 4,258.54 MWD+IFR-AK-CAZ-SC(3) 6,262.20 74.01 75.04 3,363.21 3,208.41 1,322.17 4,144.01 5,928,985.74 465,184.58 0.74 4,349.76 MWD+IFR-AK-CAZ-SC(3) 6,358.03 73.59 75.47 3,389.95 3,235.15 1,345.59 4,233.01 5,929,008.70 465,273.69 0.61 4,441.64 MW D+I FR-AK-CAZ-SC(3) 6,451.44 73.56 74.16 3,416.36 3,261.56 1,369.06 4,319.47 5,929,031.72 465,360.27 1.35 4,531.13 MWD+IFR-AK-CAZ-SC(3) 6,546.47 73.59 73.92 3,443.23 3,288.43 1,394.12 4,407.11 5,929,056.32 465,448.02 0.24 4,622.22 MW D+I FR-AK-CAZ-SC(3) 6,641.55 73.54 73.37 3,470.13 3,315.33 1,419.80 4,494.62 5,929,081.55 465,535.65 0.56 4,713.38 MWD+IFR-AK-CAZ-SC(3) 6,736.94 73.59 72.48 3,497.12 3,342.32 1,446.67 4,582.08 5,929,107.96 465,623.24 0.90 4,804.86 MWD+IFR-AK-CAZ-SC(3) 6,830.94 73.54 72.00 3,523.72 3,368.92 1,474,17 4,667.94 5,929,135.01 465,709.23 0.49 4,895.02 MWD+I FR-AK-CAZ-SC(3) 6,926.96 73.65 71.27 3,550.84 3,396.04 1,503.19 4,755.36 5,929,163.58 465,796.79 0.74 4,987.12 MWD+IFR-AK-CAZ-SC(3) 7,021.18 74.13 70.99 3,576.98 3,422.18 1,532.47 4,841.01 5,929,192.41 465,882.59 0.58 5,077.63 MWD+I FR-AK-CAZ-SC(3) 7,115.64 74.10 71.10 3,602.83 3,448.03 1,561.98 4,926.94 5,929,221.48 465,968.66 0.12 5,168.47 MW D+I FR-AK-CAZ-SC(3) 7,209.72 74.07 72.26 3,628.63 3,473.83 1,590.41 5,012.82 5,929,249.47 466,054.68 1.19 5,258.94 MWD+IFR-AK-CAZ-SC(3) 7,305.70 74.04 73.10 3,655.00 3,500.20 1,617.89 5,100.93 5,929,276.49 466,142.91 0.84 5,351.22 MWD+IFR-AK-CAZ-SC(3) 7,399.54 74.11 73.22 3,680.75 3,525.95 1,644.03 5,187.30 5,929,302.18 466,229.41 0.14 5,441.44 MWD+IFR-AK-CAZ-SC(3) 7,494.36 74.01 74.08 3,706.79 3,551.99 1,669.70 5,274.78 5,929,327.39 466,317.02 0.88 5,532.58 MW D+I FR-AK-CAZ-SC(3) 7,589.20 74.04 73.80 3,732.89 3,578.09 1,694.92 5,362.40 5,929,352.16 466,404.76 0.29 5,623.70 MWD+IFR-AK-CAZ-SC(3) 7,684.95 73.95 73.55 3,759.29 3,604.49 1,720.79 5,450.73 5,929,377.57 466,493.21 0.27 5,715.70 MWD+IFR-AK-CAZ-SC(3) 7,779.59 74.05 72.99 3,785.38 3,630.58 1,746.98 5,537.85 5,929,403.31 466,580.46 0.58 5,806.65 MWD+IFR-AK-CAZ-SC(3) 7,874.02 74.07 73.85 3,811.31 3,656.51 1,772.89 5,624.87 5,929,428.76 466,667.60 0.88 5,897.43 MWD+I FR-AK-CAZ-SC(3) 7,968.10 74.07 73.98 3,837.13 3,682.33 1,797.95 5,711.80 5,929,453.38 466,754.65 0.13 5,987.84 MW D+IFR-AK-CAZ-SC(3) 8,062.53 74.10 74.07 3,863.03 3,708.23 1,822.95 5,799.10 5,929,477.92 466,842.07 0.10 6,078.60 MWD+IFR-AK-CAZ-SC(3) 8,157.11 74.04 73.99 3,888.99 3,734.19 1,847.97 5,886.54 5,929,502.49 466,929.63 0.10 6,169.49 MWD+I FR-AK-CAZ-SC(3) 8,252.61 74.01 73.18 3,915.27 3,760.47 1,873.91 5,974.61 5,929,527.97 467,017.82 0.82 6,261.26 MWD+IFR-AK-CAZ-SC(3) 8,347.05 74.04 72.47 3,941.26 3,786.46 1,900.72 6,061.35 5,929,554.33 467,104.69 0.72 6,352.04 MWD+I FR-AK-CAZ-SC(3) 8,442.45 74.52 71.95 3,967.11 3,812.31 1,928.78 6,148.79 5,929,581.94 467,192.27 0.73 6,443.88 MWD+IFR-AK-CAZ-SC(3) 8,536.17 74.55 72.26 3,992.10 3,837.30 1,956.54 6,234.75 5,929,609.24 467,278.36 0.32 6,534.20 MWD+IFR-AK-CAZ-SC(3) 8,631.70 74.60 73.05 4,017.51 3,862.71 1,983.99 6,322.65 5,929,636.24 467,366.39 0.80 6,626.28 MW D+I FR-AK-CAZ-SC(3) 8,727.55 74.63 74.42 4,042.94 3,888.14 2,009.87 6,411.36 5,929,661.66 467,455.23 1.38 6,718.65 MWD+I FR-AK-CAZ-SC(3) 8,821.58 74.07 76.24 4,068.31 3,913.51 2,032.80 6,498.95 5,929,684.14 467,542.92 1.96 6,809.04 MWD+IFR-AK-CAZ-SC(3) 8,915.47 74.07 77.62 4,094.08 3,939.28 2,053.22 6,586.89 5,929,704.10 467,630.96 1.41 6,898.99 MWD+IFR-AK-CAZ-SC(3) 2/17/2015 9:28:49AM Page 4 COMPASS 5000.1 Build 65 • • . Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 9,009.09 74.07 77.68 4,119.77 3,964.97 2,072.48 6,674.84 5,929,722.90 467,718.99 0.06 6,988.58 MWD+IFR-AK-CAZ-SC(3) 9,104.13 74.04 77.16 4,145.88 3,991.08 2,092.38 6,764.02 5,929,742.34 467,808.28 0.53 7,079.55 MWD+IFR-AK-CAZ-SC(3) 9,198.53 74.10 75.25 4,171.79 4,016.99 2,114.02 6,852.18 5,929,763.53 467,896.53 1.95 7,170.08 MWD+IFR-AK-CAZ-SC(3) 9,292.04 74.07 73.57 4,197.44 4,042.64 2,138.19 6,938.79 5,929,787.24 467,983.26 1.73 7,259.92 MWD+IFR-AK-CAZ-SC(3) 9,386.03 73.95 73.41 4,223.33 4,068.53 2,163.87 7,025.42 5,929,812.47 468,070.01 0.21 7,350.24 MWD+I FR-AK-CAZ-SC(3) 9,480.30 74.07 73.76 4,249.30 4,094.50 2,189.48 7,112.35 5,929,837.63 468,157.06 0.38 7,440.83 MWD+I FR-AK-CAZ-SC(3) 9,575.43 74.13 73.76 4,275.36 4,120.56 2,215.06 7,200.19 5,929,862.76 468,245.02 0.06 7,532.28 MWD+IFR-AK-CAZ-SC(3) 9,669.96 74.10 72.63 4,301.23 4,146.43 2,241.35 7,287.22 5,929,888.59 468,332.18 1.15 7,623.18 MWD+IFR-AK-CAZ-SC(3) 9,763.63 74.04 72.70 4,326.94 4,172.14 2,268.19 7,373.20 5,929,914.98 468,418.29 0.10 7,713.24 MWD+IFR-AK-CAZ-SC(3) 9,858.60 74.13 72.76 4,352.98 4,198.18 2,295.30 7,460.42 5,929,941.64 468,505.64 0.11 7,804.56 MWD+I FR-AK-CAZ-SC(3) 9,954.88 74.10 72.65 4,379.33 4,224.53 2,322.83 7,548.83 5,929,968.71 468,594.19 0.11 7,897.16 MW D+I FR-AK-CAZ-SC(3) 10,049.51 74.16 72.74 4,405.21 4,250.41 2,349.91 7,635.74 5,929,995.34 468,681.22 0.11 7,988.18 MWD+I FR-AK-CAZ-SC(3) 10,143.83 74.15 73.09 4,430.96 4,276.16 2,376.56 7,722.47 5,930,021.55 468,768.08 0.36 8,078.90 MWD+I FR-AK-CAZ-SC(3) 10,239.02 74.21 73.34 4,456.91 4,302.11 2,403.01 7,810.15 5,930,047.54 468,855.89 0.26 8,170.47 MW D+I FR-AK-CAZ-SC(3) 10,333.73 74.19 73.62 4,482.70 4,327.90 2,428.92 7,897.52 5,930,073.00 468,943.38 0.29 8,261.57 MWD+IFR-AK-CAZ-SC(3) 10,428.03 74.12 73.92 4,508.45 4,353.65 2,454.28 7,984.62 5,930,097.90 469,030.60 0.31 8,352.24 MWD+IFR-AK-CAZ-SC(3) 10,523.21 74.09 74.57 4,534.52 4,379.72 2,479.13 8,072.72 5,930,122.30 469,118.82 0.66 8,443.71 MWD+IFR-AK-CAZ-SC(3) 10,617.65 74.10 73.78 4,560.40 4,405.60 2,503.90 8,160.10 5,930,146.61 469,206.32 0.80 8,534.47 MWD+IFR-AK-CAZ-SC(3) 10,712.39 74.04 73.57 4,586.40 4,431.60 2,529.51 8,247.53 5,930,171.77 469,293.87 0.22 8,625.53 MWD+IFR-AK-CAZ-SC(3) 10,807.80 74.10 73.66 4,612.59 4,457.79 2,555.39 8,335.55 5,930,197.19 469,382.02 0.11 8,717.24 MWD+I FR-AK-CAZ-SC(3) 10,900.85 73.90 73.65 4,638.24 4,483.44 2,580.56 8,421.38 5,930,221.92 469,467.97 0.22 8,806.65 MWD+IFR-AK-CAZ-SC(3) 10,994.59 74.61 73.60 4,663.67 4,508.87 2,606.00 8,507.95 5,930,246.90 469,554.65 0.76 8,896.84 MWD+IFR-AK-CAZ-SC(3) 11,091.02 74.48 73.69 4,689.37 4,534.57 2,632.17 8,597.13 5,930,272.61 469,643.96 0.16 8,989.74 MWD+IFR-AK-CAZ-SC(3) 11,185.19 74.67 73.71 4,714.42 4,559.62 2,657.65 8,684.26 5,930,297.64 469,731.21 0.20 9,080.48 MW D+I FR-AK-CAZ-SC(3) 11,279.47 74.14 74.14 4,739.76 4,584.96 2,682.79 8,771.52 5,930,322.33 469,818.59 0.71 9,171.24 MWD+IFR-AK-CAZ-SC(3) 11,374.49 74.22 73.27 4,765.67 4,610.87 2,708.44 8,859.26 5,930,347.52 469,906.46 0.88 9,262.61 MWD+IFR-AK-CAZ-SC(3) 11,470.49 74.24 72.33 4,791.76 4,636.96 2,735.76 8,947.52 5,930,374.38 469,994.84 0.94 9,354.99 MWD+I FR-AK-CAZ-SC(3) 11,562.72 74.15 72.01 4,816.88 4,662.08 2,762.93 9,032.00 5,930,401.12 470,079.46 0.35 9,443.73 MW D+IFR-AK-CAZ-SC(3) 11,657.13 73.61 71.88 4,843.09 4,688.29 2,791.04 9,118.23 5,930,428.78 470,165.82 0.59 9,534.43 MWD+IFR-AK-CAZ-SC(3) 11,752.19 73.71 72.03 4,869.83 4,715.03 2,819.30 9,204.96 5,930,456.58 470,252.69 0.18 9,625.65 MWD+I FR-AK-CAZ-SC(3) 11,846.95 73.74 72.34 4,896.39 4,741.59 2,847.13 9,291.56 5,930,483.96 470,339.43 0.32 9,716.61 MWD+I FR-AK-CAZ-SC(3) 11,942.07 73.71 73.11 4,923.05 4,768.25 2,874.25 9,378.75 5,930,510.63 470,426.75 0.78 9,807.91 MWD+I FR-AK-CAZ-SC(3) 12,036.36 73.64 74.06 4,949.55 4,794.75 2,899.82 9,465.55 5,930,535.75 470,513.67 0.97 9,898.37 MWD+IFR-AK-CAZ-SC(3) 12,129.96 74.16 74.31 4,975.51 4,820.71 2,924.32 9,552.08 5,930,559.80 470,600.31 0.61 9,988.23 MWD+IFR-AK-CAZ-SC(3) 12,224.88 74.89 76.01 5,000.84 4,846.04 2,947.75 9,640.50 5,930,582.77 470,688.84 1.89 10,079.57 MWD+IFR-AK-CAZ-SC(3) 12,319.96 75.25 78.53 5,025.34 4,870.54 2,967.99 9,730.10 5,930,602.55 470,778.54 2.59 10,171.04 MWD+IFR-AK-CAZ-SC(3) 12,413.37 75.37 80.68 5,049.03 4,894.23 2,984.29 9,818.97 5,930,618.39 470,867.48 2.23 10,260.59 MWD+IFR-AK-CAZ-SC(3) 12,507.42 75.25 83.49 5,072.88 4,918.08 2,996.82 9,909.07 5,930,630.45 470,957.64 2.89 10,350.15 MWD+IFR-AK-CAZ-SC(3) 12,602.52 75.25 86.52 5,097.10 4,942.30 3,004.83 10,000.67 5,930,637.98 471,049.27 3.08 10,439.75 MWD+I FR-AK-CAZ-SC(3) 12,696.15 75.21 90.55 5,120.98 4,966.18 3,007.14 10,091.16 5,930,639.83 471,139.76 4.16 10,526.52 MWD+I FR-AK-CAZ-SC(3) 12,791.71 74.43 94.95 5,146.01 4,991.21 3,002.72 10,183.25 5,930,634.94 471,231.82 4.52 10,612.74 MWD+IFR-AK-CAZ-SC(3) 12,885.33 74.67 99.04 5,170.96 5,016.16 2,991.74 10,272.80 5,930,623.49 471,321.30 4.22 10,694.51 MWD+I FR-AK-CAZ-SC(3) 12,980.98 75.76 104.25 5,195.39 5,040.59 2,973.07 10,363.34 5,930,604.35 471,411.73 5.39 10,774.85 MWD+IFR-AK-CAZ-SC(3) 13,076.00 76.25 108.09 5,218.37 5,063.57 2,947.39 10,451.87 5,930,578.23 471,500.12 3.96 10,851.11 MWD+IFR-AK-CAZ-SC(3) 2/17/2015 9:28:49AM Page 5 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 13,169.88 76.60 110.46 5,240.41 5,085.61 2,917.27 10,538.00 5,930,547.66 471,586.09 2.48 10,923.72 MWD+IFR-AK-CAZ-SC(3) 13,264.84 76.41 113.35 5,262.58 5,107.78 2,882.82 10,623.67 5,930,512.78 471,671.57 2.97 10,994.55 MWD+IFR-AK-CAZ-SC(3) 13,359.14 74.37 115.29 5,286.36 5,131.56 2,845.26 10,706.81 5,930,474.78 471,754.51 2.94 11,062.02 MWD+IFR-AK-CAZ-SC(3) 13,453.88 73.29 115.83 5,312.75 5,157.95 2,806.00 10,788.90 5,930,435.11 471,836.38 1.26 11,127.95 MWD+IFR-AK-CAZ-SC(3) 13,547.72 74.00 114.37 5,339.17 5,184.37 2,767.80 10,870.44 5,930,396.50 471,917.72 1.67 11,193.70 MWD+IFR-AK-CAZ-SC(3) 13,643.13 73.80 112.67 5,365.63 5,210.83 2,731.22 10,954.49 5,930,359.49 472,001.57 1.72 11,262.33 MWD+IFR-AK-CAZ-SC(3) 13,704.01 73.68 113.10 5,382.68 5,227.88 2,708.50 11,008.33 5,930,336.49 472,055.29 0.71 11,306.52 MWD+I FR-AK-CAZ-SC(3) 13,763.00 74.28 112.65 5,398.96 5,244.16 2,686.46 11,060.57 5,930,314.18 472,107.41 1.26 11,349.39 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 13,797.81 74.64 112.38 5,408.28 5,253.48 2,673.62 11,091.55 5,930,301.18 472,138.32 1.26 11,374.89 MWD+IFR-AK-CAZ-SC(4) 13,838.49 76.39 113.54 5,418.46 5,263.66 2,658.25 11,127.82 5,930,285.63 472,174.50 5.11 11,404.63 MWD+IFR-AK-CAZ-SC(4) 13,889.76 78.39 114.46 5,429.65 5,274.85 2,637.90 11,173.52 5,930,265.05 472,220.09 4.28 11,441.81 MWD+IF R-AK-CAZ-SC(4) 13,933.91 80.03 115.68 5,437.92 5,283.12 2,619.52 11,212.80 5,930,246.47 472,259.28 4.60 11,473.49 MWD+I F R-AK-CAZ-SC(4) 13,985.41 81.77 116.39 5,446.06 5,291.26 2,597.20 11,258.49 5,930,223.92 472,304.85 3.64 11,510.04 MW D+I FR-AK-CAZ-SC(4) 14,029.41 82.64 116.65 5,452.03 5,297.23 2,577.74 11,297.50 5,930,204.25 472,343.75 2.06 11,541.12 MWD+IFR-AK-CAZ-SC(4) 14,076.37 83.16 118.09 5,457.83 5,303.03 2,556.32 11,338.88 5,930,182.62 472,385.01 3.24 11,573.86 MWD+I FR-AK-CAZ-SC(4) 14,122.04 83.47 120.24 5,463.15 5,308.35 2,534.21 11,378.49 5,930,160.31 472,424.50 4.72 11,604.70 MW D+I F R-AK-CAZ-SC(4) 14,175.05 83.16 121.69 5,469.32 5,314.52 2,507.12 11,423.63 5,930,132.99 472,469.50 2.78 11,639.26 MWD+IFR-AK-CAZ-SC(4) 14,218.79 83.02 123.65 5,474.58 5,319.78 2,483.69 11,460.18 5,930,109.37 472,505.93 4.46 11,666.78 MWD+IFR-AK-CAZ-SC(4) 14,274.96 83.29 125.46 5,481.28 5,326.48 2,452.06 11,506.11 5,930,077.50 472,551.69 3.24 11,700.69 MWD+IFR-AK-CAZ-SC(4) 14,313.24 83.71 126.49 5,485.61 5,330.81 2,429.71 11,536.89 5,930,055.01 472,582.35 2.89 11,723.06 MWD+IFR-AK-CAZ-SC(4) 14,359.42 84.09 128.21 5,490.52 5,335.72 2,401.86 11,573.39 5,930,026.96 472,618.70 3.79 11,749.16 MWD+IFR-AK-CAZ-SC(4) 14,403.73 84.71 129.33 5,494.84 5,340.04 2,374.24 11,607.77 5,929,999.18 472,652.94 2.88 11,773.33 MWD+IFR-AK-CAZ-SC(4) 14,462.19 85.81 132.29 5,499.68 5,344.88 2,336.17 11,651.86 5,929,960.88 472,696.82 5.39 11,803.49 MWD+I F R-AK-CAZ-SC(4) 14,503.00 86.05 133.24 5,502.57 5,347.77 2,308.53 11,681.75 5,929,933.09 472,726.56 2.40 11,823.38 MWD+IFR-AK-CAZ-SC(4) 14,551.46 86.48 133.84 5,505.73 5,350.93 2,275.22 11,716.80 5,929,899.60 472,761.44 1.52 11,846.42 MWD+IFR-AK-CAZ-SC(4) 14,575.53 87.35 134.04 5,507.03 5,352.23 2,258.54 11,734.11 5,929,882.84 472,778.66 3.71 11,857.73 MWD+IFR-AK-CAZ-SC(4) 14,597.83 88.13 134.81 5,507.90 5,353.10 2,242.94 11,750.02 5,929,867.16 472,794.49 4.91 11,868.04 MWD+IFR-AK-CAZ-SC(4) 14,646.52 90.95 138.27 5,508.30 5,353.50 2,207.61 11,783.50 5,929,831.66 472,827.79 9.17 11,888.96 MWD+IFR-AK-CAZ-SC(4) 14,693.86 91.27 139.04 5,507.38 5,352.58 2,172.08 11,814.77 5,929,795.97 472,858.86 1.76 11,907.72 MWD+I F R-AK-CAZ-SC(4) 14,788.91 92.12 140.04 5,504.57 5,349.77 2,099.79 11,876.42 5,929,723.37 472,920.14 1.38 11,944.02 MWD+IFR-AK-CAZ-SC(4) 14,883.75 91.30 144.55 5,501.74 5,346.94 2,024.81 11,934.38 5,929,648.10 472,977.70 4.83 11,975.97 MWD+IFR-AK-CAZ-SC(4) 14,977.27 90.00 148.32 5,500.67 5,345.87 1,946.91 11,986.07 5,929,569.93 473,028.99 4.26 12,001.06 MWD+IF R-AK-CAZ-SC(4) 15,028.25 89.91 152.57 5,500.71 5,345.91 1,902.57 12,011.21 5,929,525.47 473,053.90 8.34 12,011.27 MWD+IFR-AK-CAZ-SC(4) 15,072.51 88.76 152.64 5,501.23 5,346.43 1,863.28 12,031.58 5,929,486.08 473,074.06 2.60 12,018.49 MWD+IFR-AK-CAZ-SC(4) 15,123.59 90.10 154.50 5,501.74 5,346.94 1,817.54 12,054.31 5,929,440.23 473,096.55 4.49 12,025.98 MW D+I FR-AK-CAZ-SC(4) 15,167.12 90.68 156.29 5,501.44 5,346.64 1,777.97 12,072.43 5,929,400.57 473,114.47 4.32 12,030.99 MWD+I F R-AK-CAZ-SC(4) 15,219.12 91.13 160.26 5,500.62 5,345.82 1,729.67 12,091.67 5,929,352.18 473,133.46 7.68 12,034.36 MWD+I FR-AK-CAZ-SC(4) 15,259.65 90.91 161.76 5,499.90 5,345.10 1,691.36 12,104.86 5,929,313.80 473,146.44 3.74 12,035.06 MWD+I F R-AK-CAZ-SC(4) 15,312.55 91.63 165.09 5,498.72 5,343.92 1,640.68 12,119.94 5,929,263.05 473,161.27 6.44 12,033.75 MWD+IFR-AK-CAZ-SC(4) 15,345.47 90.77 165.75 5,498.03 5,343.23 1,608.82 12,128.23 5,929,231.16 473,169.39 3.29 12,031.79 MWD+IFR-AK-CAZ-SC(4) 15,403.85 90.17 167.84 5,497.56 5,342.76 1,551.99 12,141.56 5,929,174.26 473,182.43 3.72 12,026.91 MWD+IFR-AK-CAZ-SC(4) 15,448.32 90.05 169.65 5,497.47 5,342.67 1,508.38 12,150.24 5,929,130.61 473,190.88 4.08 12,021.68 MWD+IFR-AK-CAZSC(4) 15,509.91 88.14 171.73 5,498.44 5,343.64 1,447.61 12,160.20 5,929,069.80 473,200.53 4.58 12,012.38 MWD+IFR-AK-CAZ-SC(4) 2/17/2015 9:28:49AM Page 6 COMPASS 5000.1 Build 65 • • - Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 15,541.03 88.84 171.43 5,499.26 5,344.46 1,416.84 12,164.76 5,929,039.01 473,204.92 2.45 12,007.20 MWD+IFR-AK-CAZ-SC(4) 15,636.05 88.26 171.45 5,501.67 5,346.87 1,322.91 12,178.90 5,928,945.01 473,218.57 0.61 11,991.62 MWD+IFR-AK-CAZ-SC(4) 15,737.59 91.42 171.76 5,501.95 5,347.15 1,222.47 12,193.72 5,928,844.51 473,232.88 3.13 11,974.68 MWD+IFR-AK-CAZ-SC(4) 15,832.23 91.51 172.10 5,499.53 5,344.73 1,128.80 12,207.00 5,928,750.78 473,245.67 0.37 11,958.37 MWD+IFR-AK-CAZ-SC(4) 15,927.16 89.78 173.31 5,498.46 5,343.66 1,034.65 12,219.06 5,928,656.58 473,257.24 2.22 11,940.74 MWD+IFR-AK-CAZ-SC(4) 16,022.15 89.35 173.98 5,499.18 5,344.38 940.25 12,229.57 5,928,562.13 473,267.26 0.84 11,921.56 MWD+IFR-AK-CAZ-SC(4) 16,118.12 89.55 173.47 5,500.11 5,345.31 844.86 12,240.06 5,928,466.70 473,277.26 0.57 11,902.06 MWD+IFR-AK-CAZ-SC(4) 16,211.70 90.34 174.10 5,500.20 5,345.40 751.83 12,250.19 5,928,373.63 473,286.91 1.08 11,882.95 MWD+IFR-AK-CAZ-SC(4) 16,306.38 90.44 175.75 5,499.55 5,344.75 657.52 12,258.56 5,928,279.29 473,294.80 1.75 11,861.77 MWD+IFR-AK-CAZ-SC(4) 16,402.33 90.72 174.50 5,498.58 5,343.78 561.93 12,266.72 5,928,183.66 473,302.46 1.33 11,839.99 MWD+IFR-AK-CAZ-SC(4) 16,495.86 91.16 169.88 5,497.04 5,342.24 469.30 12,279.42 5,928,090.98 473,314.68 4.96 11,823.45 MWD+IFR-AK-CAZ-SC(4) 16,589.74 90.75 169.18 5,495.48 5,340.68 377.00 12,296.48 5,927,998.60 473,331.26 0.86 11,811.15 MWD+IFR-AK-CAZ-SC(4) 16,685.28 90.72 166.83 5,494.25 5,339.45 283.56 12,316.33 5,927,905.07 473,350.63 2.46 11,801.15 MWD+IFR-AK-CAZ-SC(4) 16,780.79 91.20 166.71 5,492.65 5,337.85 190.60 12,338.19 5,927,812.01 473,372.00 0.52 11,793.21 MWD+IFR-AK-CAZ-SC(4) 16,875.56 92.43 166.32 5,489.65 5,334.85 98.49 12,360.27 5,927,719.79 473,393.61 1.36 11,785.75 MWD+IFR-AK-CAZ-SC(4) 16,970.27 92.31 168.20 5,485.73 5,330.93 6.19 12,381.14 5,927,627.40 473,414.00 1.99 11,777.08 MWD+IFR-AK-CAZ-SC(4) 17,032.45 90.04 167.49 5,484.46 5,329.66 -54.57 12,394.23 5,927,566.57 473,426.77 3.83 11,770.75 MWD+IFR-AK-CAZ-SC(4) 17,093.00 90.04 167.49 5,484.42 5,329.62 -113.69 12,407.35 5,927,507.40 473,439.58 0.00 11,764.96 4 1/2"x 6-1/2" 17,095.00 90.04 167.49 5,484.42 5,329.62 -115.64 12,407.78 5,927,505.44 473,440.01 0.00 11,764.77 PROJECTED to TD 2117/2015 9:28:49AM Page 7 COMPASS 5000.1 Build 65 214151 • 25 430 RECEIVED FEB 19 2015 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad 2L-308 Definitive Survey Report NAD 83 16 February, 2015 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 2L-308(Bertha) Well Position +N/-S 0.00 usft Northing: 5,927,434.32 usft Latitude: 70°12'47.036 N +EI-W 0.00 usft Easting: 1,601,067.95 usft Longitude: 150°19'2.466 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 114.80 usft Wellbore 2L-308 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) 1 I BGG M2014 12/12/2014 18.82 80.78 57,551 Design 2L-308 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 40.00 0.00 0,00 72.00 Survey Program Date 2/16/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 78.83 918.14 2L-308 Srvy#1-GYD-GC-SS(2L-308) GYD-GC-SS Gyrodata gyro single shots 1/13/2015 2:35: 977.46 2,531.61 2L-308 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/13/2015 3:08:. 2,676.20 13,704.01 2L-308 Srvy#3-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/29/2015 12:22 13,797.81 17,032.45 2L-308 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/16/2015 2:28: Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 40.00 0.00 0.00 40.00 -114.80 0.00 0.00 5,927,434.32 1,601,067.95 0.00 0.00 UNDEFINED 78.83 0.14 147.35 78.83 -75.97 -0.04 0.03 5,927,434.28 1,601,067.98 0.36 0.01 GYD-GC-SS(1) 171.15 0.21 126.12 171.15 16.35 -0.23 0.22 5,927,434.08 1,601,068.17 0.10 0.14 GYD-GC-SS(1) 260.49 0.45 29.56 260.49 105.69 -0.03 0.53 5,927,434.29 1,601,068.48 0.58 0.49 GYD-GC-SS(1) 352.21 2.39 23.92 352.18 197.38 2.04 1.48 5,927,436.35 1,601,069.44 2.12 2.04 GYD-GC-SS(1) 447.52 3.21 11.57 447.37 292.57 6.47 2.82 5,927,440.77 1,601,070.81 1.06 4.68 GYD-GC-SS(1) 541.92 4.42 15.67 541.56 386.76 12.56 4.34 5,927,446.85 1,601,072.35 1.31 8.00 GYD-GC-SS(1) 635.72 5.26 15.07 635.03 480.23 20.19 6.43 5,927,454.47 1,601,074.48 0.90 12.35 GYD-GC-SS(1) 729.80 7.08 20.18 728.56 573.76 29.80 9.55 5,927,464.06 1,601,077.66 2.02 18.29 GYD-GC-SS(1) 779.90 9.30 20.43 778.14 623.34 36.49 12.03 5,927,470.74 1,601,080.17 4.43 22.72 GYD-GC-SS(1) 825.45 12.03 21.93 822.90 668.10 44.34 15.09 5,927,478.58 1,601,083.27 6.02 28.05 GYD-GC-SS(1) 2/16/2015 3:20:59PM Page 2 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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) (°/100') (ft) Survey Tool Name 918.14 15.37 25.49 912.94 758.14 64.40 23.98 5,927,498.59 1,601,092.27 3.71 42.71 GYD-GC-SS(1) 977.46 16.52 25.98 969.98 815.18 79.08 31.06 5,927,513.23 1,601,099.42 1.95 53.98 MWD+IFR-AK-CAZ-SC(2) 1,072.80 16.76 35.79 1,061.35 906.55 102.42 45.04 5,927,536.49 1,601,113.52 2.95 74.49 MWD+IFR-AK-CAZ-SC(2) 1,166.54 16.25 46.66 1,151.25 996.45 122.39 62.49 5,927,556.37 1,601,131.07 3.33 97.25 MWD+IFR-AK-CAZ-SC(2) 1,261.19 16.42 50.04 1,242.08 1,087.28 140.07 82.38 5,927,573.94 1,601,151.05 1.02 121.63 MWD+IFR-AK-CAZ-SC(2) 1,355.54 16.06 53.84 1,332.67 1,177.87 156.33 103.13 5,927,590.10 1,601,171.89 1.19 146.40 MWD+IFR-AK-CAZ-SC(2) 1,450.13 16.38 61.36 1,423.50 1,268.70 170.45 125.41 5,927,604.10 1,601,194.23 2.24 171.94 MWD+IFR-AK-CAZ-SC(2) 1,544.61 17.87 66.40 1,513.79 1,358.99 182.64 150.38 5,927,616.15 1,601,219.27 2.22 199.46 MWD+IFR-AK-CAZ-SC(2) 1,637.82 21.17 71.08 1,601.64 1,446.84 193.82 179.42 5,927,627.19 1,601,248.36 3.92 230.53 MWD+IFR-AK-CAZ-SC(2) 1,733.75 24.41 73.02 1,690.07 1,535.27 205.23 214.77 5,927,638.41 1,601,283.77 3.47 267.68 MWD+IFR-AK-CAZ-SC(2) 1,782.85 26.99 73.56 1,734.31 1,579.51 211.35 235.17 5,927,644.42 1,601,304.19 5.28 288.97 MWD+IFR-AK-CAZ-SC(2) 1,827.89 29.53 74.35 1,773.98 1,619.18 217.24 255.66 5,927,650.20 1,601,324.71 5.70 310.28 MWD+IFR-AK-CAZ-SC(2) 1,876.68 32.16 75.76 1,815.86 1,661.06 223.68 279.83 5,927,656.51 1,601,348.91 5.59 335.25 MWD+IFR-AK-CAZ-SC(2) 1,922.33 34.21 75.69 1,854.07 1,699.27 229.84 304.04 5,927,662.55 1,601,373.16 4.49 360.19 MVVD+IFR-AK-CAZ-SC(2) 1,967.54 36.31 77.28 1,890.98 1,736.18 235.93 329.42 5,927,668.50 1,601,398.56 5.07 386.20 MWD+IFR-AK-CAZ-SC(2) 2,016.69 38.07 77.82 1,930.13 1,775.33 242.33 358.43 5,927,674.75 1,601,427.60 3.64 415.77 MWD+IFR-AK-CAZ-SC(2) 2,111.56 41.45 77.86 2,003.05 1,848.25 255.11 417.74 5,927,687.22 1,601,486.97 3.56 476.12 MWD+IFR-AK-CAZ-SC(2) 2,206.28 44.15 76.99 2,072.55 1,917.75 269.13 480.54 5,927,700.92 1,601,549.84 2.92 540.18 MW0+1FR-AK-CAZ-SC(2) 2,300.34 48.02 74.02 2,137.78 1,982.98 286.14 546.10 5,927,717.58 1,601,615.48 4.70 607.79 MWD+IFR-AK-CAZ-SC(2) 2,395.33 50.82 73.63 2,199.57 2,044.77 306.24 615.38 5,927,737.32 1,601,684.86 2.96 679.89 MWD+IFR-AK-CAZ-SC(2) 2,444.66 54.35 75.55 2,229.54 2,074.74 316.63 653.15 5,927,747.51 1,601,722.67 7.79 719.02 MWD+IFR-AK-CAZ-SC(2) 2,490.27 55.89 75.33 2,255.62 2,100.82 326.04 689.36 5,927,756.73 1,601,758.93 3.40 756.37 MWD+IFR-AK-CAZ-SC(2) 2,531.61 59.09 76.51 2,277.83 2,123.03 334.51 723.17 5,927,765.03 1,601,792.78 8.11 791.15 MWD+IFR-AK-CAZ-SC(2) 2,599.00 60.00 76.43 2,311.99 2,157.19 348.11 779.65 5,927,778.32 1,601,849.33 1.36 849.06 MW3+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,676.20 61.05 76.33 2,349.97 2,195.17 363.94 844.97 5,927,793.81 1,601,914.72 1.36 916.07 MWD+IFR-AK-CAZ-SC(3) 2,769.53 64.18 76.40 2,392.89 2,238.09 383.47 925.49 5,927,812.92 1,601,995.34 3.35 998.69 MWD+IFR-AK-CAZ-SC(3) 2,859.83 68.05 75.04 2,429.45 2,274.65 403.84 1,005.49 5,927,832.88 1,602,075.43 4.50 1,081.07 MWD+IFR-AK-CAZ-SC(3) 2,953.89 71.73 74.48 2,461.79 2,306.99 427.06 1,090.69 5,927,855.65 1,602,160.74 3.95 1,169.28 MWD+IFR-AK-CAZ-SC(3) 3,048.34 74.21 73.91 2,489.45 2,334.65 451.66 1,177.58 5,927,879.79 1,602,247.75 2.69 1,259.51 MWD+IFR-AK-CAZ-SC(3) 3,143.12 75.37 74.30 2,514.31 2,359.51 476.71 1,265.54 5,927,904.38 1,602,335.83 1.29 1,350.91 MWD+IFR-AK-CAZSC(3) 3,237.18 74.81 74.22 2,538.51 2,383.71 501.36 1,353.02 5,927,928.58 1,602,423.43 0.60 1,441.73 MWD+IFR-AK-CAZSC(3) 3,333.38 75.04 74.75 2,563.53 2,408.73 526.21 1,442.53 5,927,952.95 1,602,513.06 0.58 1,534.53 MWD+IFR-AK-CAZSC(3) 3,426.52 74.89 75.19 2,587.70 2,432.90 549.54 1,529.40 5,927,975.82 1,602,600.04 0.48 1,624.36 MWD+IFR-AK-CAZ-SC(3) 3,520.96 74.33 75.24 2,612.76 2,457.96 572.77 1,617.44 5,927,998.60 1,602,688.19 0.60 1,715.27 MWD+IFR-AK-CAZ-SC(3) 3,615.49 74.45 76.00 2,638.20 2,483.40 595.38 1,705.63 5,928,020.75 1,602,776.49 0.78 1,806.13 MVVD+IFR-AK-CAZ-SC(3) 3,713.36 74.28 75.73 2,664.57 2,509.77 618.40 1,797.02 5,928,043.29 1,602,868.00 0.32 1,900.17 MWD+IFR-AK-CAZ-SC(3) 3,801.83 74.33 74.88 2,688.51 2,533.71 640.00 1,879.41 5,928,064.46 1,602,950.48 0.93 1,985.20 MWD+IFR-AK-CAZSC(3) 3,896.78 74.22 73.83 2,714.24 2,559.44 664.65 1,967.42 5,928,088.64 1,603,038.61 1.07 2,076.51 MWD+IFR-AK-CAZSC(3) 3,990.57 74.36 72.16 2,739.64 2,584.84 691.06 2,053.75 5,928,114.60 1,603,125.07 1.72 2,166.78 MWD+IFR-AK-CAZSC(3) 2/16/2015 3:20.59PM Page 3 COMPASS 5000.1 Build 65 III • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40©154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 4,084.36 74.40 71.21 2,764.89 2,610.09 719.44 2,139.50 5,928,142.53 1,603,210.96 0.98 2,257.11 MWD+IFR-AK-CAZ-SC(3) 4,178.54 74.39 70.70 2,790.23 2,635.43 749.04 2,225.25 5,928,171.68 1,603,296.85 0.52 2,347.80 MWD+IFR-AK-CAZ-SC(3) 4,273.84 74.30 71.89 2,815.94 2,661.14 778.47 2,312.16 5,928,200.65 1,603,383.91 1.21 2,439.56 MWD+IFR-AK-CAZ-SC(3) 4,369.09 74.27 74.29 2,841.75 2,686.95 805.13 2,399.88 5,928,226.86 1,603,471.76 2.43 2,531.22 MWD+IFR-AK-CAZ-SC(3) 4,462.91 73.80 74.20 2,867.55 2,712.75 829.63 2,486.69 5,928,250.89 1,603,558.69 0.51 2,621.35 MWD+IFR-AK-CAZ-SC(3) 4,557.75 73.85 75.21 2,893.97 2,739.17 853.65 2,574.55 5,928,274.46 1,603,646.66 1.02 2,712.34 MWD+IFR-AK-CAZ-SC(3) 4,653.01 73.74 75.19 2,920.56 2,765.76 877.02 2,662.99 5,928,297.36 1,603,735.21 0.12 2,803.67 MWD+IFR-AK-CAZ-SC(3) 4,747.08 73.27 75.83 2,947.26 2,792.46 899.59 2,750.32 5,928,319.48 1,603,822.65 0.82 2,893.70 MWD+IFR-AK-CAZ-SC(3) 4,842.59 73.29 74.87 2,974.74 2,819.94 922.72 2,838.82 5,928,342.15 1,603,911.26 0.96 2,985.01 MWD+IFR-AK-CAZ-SC(3) 4,936.09 73.27 73.90 3,001.64 2,846.84 946.83 2,925.06 5,928,365.80 1,603,997.61 0.99 3,074.48 MWD+IFR-AK-CAZ-SC(3) 5,031.09 73.30 72.82 3,028.97 2,874.17 972.88 3,012.23 5,928,391.39 1,604,084.91 1.09 3,165.44 MWD+IFR-AK-CAZ-SC(3) 5,125.66 73.83 71.88 3,055.72 2,900.92 1,000.38 3,098.67 5,928,418.44 1,604,171.48 1.11 3,256.14 MVVD+IFR-AK-CAZ-SC(3) 5,220.44 74.31 70.84 3,081.74 2,926.94 1,029.51 3,185.02 5,928,447.12 1,604,257.98 1.17 3,347.27 MWD+IFR-AK-CAZ-SC(3) 5,315.54 74.33 71.11 3,107.44 2,952.64 1,059.36 3,271.58 5,928,476.51 1,604,344.69 0.27 3,438.82 MWD+IFR-AK-CAZ-SC(3) 5,409.67 74.31 71.39 3,132.88 2,978.08 1,088.49 3,357.40 5,928,505.19 1,604,430.65 0.29 3,529.44 MWD+IFR-AK-CAZSC(3) 5,504.42 74.36 71.15 3,158.46 3,003.66 1,117.79 3,443.80 5,928,534.04 1,604,517.19 0.25 3,620.66 MVVD+IFR-AK-CAZ-SC(3) 5,598.32 74.31 71.40 3,183.82 3,029.02 1,146.81 3,529.43 5,928,562.61 1,604,602.96 0.26 3,711.07 MWD+IFR-AK-CAZSC(3) 5,693.20 74.28 73.27 3,209.50 3,054.70 1,174.53 3,616.45 5,928,589.87 1,604,690.12 1.90 3,802.40 MWD+IFR-AK-CAZ-SC(3) 5,788.33 74.42 73.91 3,235.17 3,080.37 1,200.41 3,704.32 5,928,615.29 1,604,778.12 0.66 3,893.97 MWD+IFR-AK-CAZSC(3) 5,883.37 74.31 74.47 3,260.78 3,105.98 1,225.34 3,792.38 5,928,639.76 1,604,866.30 0.58 3,985.42 MWD+IFR-AK-CAZSC(3) 5,977.51 74.30 74.40 3,286.25 3,131.45 1,249.66 3,879.69 5,928,663.62 1,604,953.72 0.07 4,075.97 MW3+IFR-AK-CAZ-SC(3) 6,072.19 74.28 74.73 3,311.88 3,157.08 1,273.92 3,967.55 5,928,687.42 1,605,041.69 0.34 4,167.02 MWD+IFR-AK-CAZ-SC(3) 6,167.31 74.51 74.53 3,337.47 3,182.67 1,298.20 4,055.88 5,928,711.24 1,605,130.15 0.32 4,258.54 MWD+IFR-AK-CAZ-SC(3) 6,262.20 74.01 75.04 3,363.21 3,208.41 1,322.17 4,144.01 5,928,734.75 1,605,218.39 0.74 4,349.76 MWD+IFR-AK-CAZ-SC(3) 6,358.03 73.59 75.47 3,389.95 3,235.15 1,345.59 4,233.01 5,928,757.70 1,605,307.50 0.61 4,441.64 MVVD+IFR-AK-CAZ-SC(3) 6,451.44 73.56 74.16 3,416.36 3,261.56 1,369.06 4,319.47 5,928,780.72 1,605,394.08 1.35 4,531.13 MWD+IFR-AK-CAZ-SC(3) 6,546.47 73.59 73.92 3,443.23 3,288.43 1,394.12 4,407.11 5,928,805.32 1,605,481.84 0.24 4,622.22 MWD+IFR-AK-CAZ-SC(3) 6,641.55 73.54 73.37 3,470.13 3,315.33 1,419.80 4,494.62 5,928,830.54 1,605,569.46 0.56 4,713.38 MVVD+IFR-AK-CAZ-SC(3) 6,736.94 73.59 72.48 3,497.12 3,342.32 1,446.67 4,582.08 5,928,856.95 1,605,657.05 0.90 4,804.86 MWD+IFR-AK-CAZ-SC(3) 6,830,94 73.54 72.00 3,523.72 3,368.92 1,474.17 4,667.94 5,928,884.00 1,605,743.05 0.49 4,895.02 MWD+IFR-AK-CAZ-SC(3) 6,926.96 73.65 71.27 3,550.84 3,396.04 1,503.19 4,755.36 5,928,912.56 1,605,830.61 0.74 4,987.12 MWD+IFR-AK-CAZ-SC(3) 7,021.18 74.13 70.99 3,576.98 3,422.18 1,532.47 4,841.01 5,928,941.39 1,605,916.41 0.58 5,077.63 MWD+IFR-AK-CAZ-SC(3) 7,115.64 74.10 71.10 3,602.83 3,448.03 1,561.98 4,926.94 5,928,970.45 1,606,002.48 0.12 5,168.47 MWD+IFR-AK-CAZ-SC(3) 7,209.72 74.07 72.26 3,628.63 3,473.83 1,590.41 5,012.82 5,928,998.43 1,606,088.50 1.19 5,258.94 MWD+IFR-AK-CAZ-SC(3) 7,305.70 74.04 73.10 3,655.00 3,500.20 1,617.89 5,100.93 5,929,025.45 1,606,176.74 0.84 5,351.22 MWD+IFR-AK-CAZ-SC(3) 7,399.54 74.11 73.22 3,680.75 3,525.95 1,644.03 5,187.30 5,929,051.13 1,606,263.23 0.14 5,441.44 MWD+IFR-AK-CAZ-SC(3) 7,494.36 74.01 74.08 3,706.79 3,551.99 1,669.70 5,274.78 5,929,076.34 1,606,350.84 0.88 5,532.58 MWD+IFR-AK-CAZ-SC(3) 7,589.20 74.04 73.80 3,732.89 3,578.09 1,694.92 5,362.40 5,929,101.11 1,606,438.58 0.29 5,623.70 MWD+IFR-AK-CAZSC(3) 7,684.95 73.95 73.55 3,759.29 3,604.49 1,720.79 5,450.73 5,929,126.51 1,606,527.04 0.27 5,715.70 MWD+IFR-AK-CAZ-SC(3) 7,779.59 74.05 72.99 3,785.38 3,630.58 1,746.98 5,537.85 5,929,152.24 1,606,614.29 0.58 5,806.65 MWD+IFR-AK-CAZ-SC(3) 2/16/2015 3:20:59PM Page 4 COMPASS 5000.1 Build 65 III • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40©154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +VAN Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) r1100') (ft) Survey Tool Name 7,874.02 74.07 73.85 3,811.31 3,656.51 1,772.89 5,624.87 5,929,177.70 1,606,701.43 0.88 5,897.43 MWD+IFR-AK-CAZ-SC(3) 7,968.10 74.07 73.98 3,837.13 3,682.33 1,797.95 5,711.80 5,929,202.31 1,606,788.48 0.13 5,987.84 M1IvD+IFR-AK-CAZ-SC(3) 8,062.53 74.10 74.07 3,863.03 3,708.23 1,822.95 5,799.10 5,929,226.84 1,606,875.90 0.10 6,078.60 MWD+IFR-AK-CAZ-SC(3) 8,157.11 74.04 73.99 3,888.99 3,734.19 1,847.97 5,886.54 5,929,251.41 1,606,963.46 0.10 6,169.49 MWD+IFR-AK-CAZ-SC(3) 8,252.61 74.01 73.18 3,915.27 3,760.47 1,873.91 5,974.61 5,929,276.89 1,607,051.66 0.82 6,261.26 MWD+IFR-AK-CAZ-SC(3) 8,347.05 74.04 72.47 3,941.26 3,786.46 1,900.72 6,061.35 5,929,303.24 1,607,138.53 0.72 6,352.04 MWD+IFR-AK-CAZ-SC(3) 8,442.45 74.52 71.95 3,967.11 3,812.31 1,928.78 6,148.79 5,929,330.84 1,607,226.11 0.73 6,443.88 MWD+IFR-AK-CAZ-SC(3) 8,536.17 74.55 72.26 3,992.10 3,837.30 1,956.54 6,234.75 5,929,358.15 1,607,312.20 0.32 6,534.20 MWD+IFR-AK-CAZ-SC(3) 8,631.70 74.60 73.05 4,017.51 3,862.71 1,983.99 6,322.65 5,929,385.14 1,607,400.23 0.80 6,626.28 MWD+IFR-AK-CAZ-SC(3) 8,727.55 74.63 74.42 4,042.94 3,888.14 2,009.87 6,411.36 5,929,410.56 1,607,489.07 1.38 6,718.65 MW1D+IFR-AK-CAZ-SC(3) 8,821.58 74.07 76.24 4,068.31 3,913.51 2,032.80 6,498.95 5,929,433.03 1,607,576.77 1.96 6,809.04 MWD+IFR-AK-CAZ-SC(3) 8,915.47 74.07 77.62 4,094.08 3,939.28 2,053.22 6,586.89 5,929,452.98 1,607,664.81 1.41 6,898.99 MWD+IFR-AK-CAZ-SC(3) 9,009.09 74.07 77.68 4,119.77 3,964.97 2,072.48 6,674.84 5,929,471.78 1,607,752.84 0.06 6,988.58 MWD+IFR-AK-CAZ-SC(3) 9,104.13 74.04 77.16 4,145.88 3,991.08 2,092.38 6,764.02 5,929,491.22 1,607,842.12 0.53 7,079.55 MWD+IFR-AK-CAZ-SC(3) 9,198.53 74.10 75.25 4,171.79 4,016.99 2,114.02 6,852.18 5,929,512.40 1,607,930.38 1.95 7,170.08 MWD+IFR-AK-CAZ-SC(3) 9,292.04 74.07 73.57 4,197.44 4,042.64 2,138.19 6,938.79 5,929,536.11 1,608,017.11 1.73 7,259.92 MWD+IFR-AK-CAZ-SC(3) 9,386.03 73.95 73.41 4,223.33 4,068.53 2,163.87 7,025.42 5,929,561.33 1,608,103.86 0.21 7,350.24 MWD+IFR-AK-CAZ-SC(3) 9,480.30 74.07 73.76 4,249.30 4,094.50 2,189.48 7,112.35 5,929,586.49 1,608,190.91 0.38 7,440.83 MVVD+IFR-AK-CAZ-SC(3) 9,575.43 74.13 73.76 4,275.36 4,120.56 2,215.06 7,200.19 5,929,611.61 1,608,278.88 0.06 7,532.28 MWD+IFR-AK-CAZ-SC(3) 9,669.96 74.10 72.63 4,301.23 4,146.43 2,241.35 7,287.22 5,929,637.44 1,608,366.04 1.15 7,623.18 MWD+IFR-AK-CAZ-SC(3) 9,763.63 74.04 72.70 4,326.94 4,172.14 2,268.19 7,373.20 5,929,663.83 1,608,452.15 0.10 7,713.24 MWD+IFR-AK-CAZ-SC(3) 9,858.60 74.13 72.76 4,352.98 4,198.18 2,295.30 7,460.42 5,929,690.48 1,608,539.49 0.11 7,804.56 MWD+IFR-AK-CAZ-SC(3) 9,954.88 74.10 72.65 4,379.33 4,224.53 2,322.83 7,548.83 5,929,717.55 1,608,628.04 0.11 7,897.16 MWD+IFR-AK-CAZ-SC(3) 10,049.51 74.16 72.74 4,405.21 4,250.41 2,349.91 7,635.74 5,929,744.17 1,608,715.08 0.11 7,988.18 MWD+IFR-AK-CAZ-SC(3) 10,143.83 74.15 73.09 4,430.96 4,276.16 2,376.56 7,722.47 5,929,770.37 1,608,801.94 0.36 8,078.90 MWD+IFR-AK-CAZ-SC(3) 10,239.02 74.21 73.34 4,456.91 4,302.11 2,403.01 7,810.15 5,929,796.36 1,608,889.75 0.26 8,170.47 MWD+IFR-AK-CAZ-SC(3) 10,333.73 74.19 73.62 4,482.70 4,327.90 2,428.92 7,897.52 5,929,821.82 1,608,977.25 0.29 8,261.57 MWD+IFR-AK-CAZ-SC(3) 10,428.03 74.12 73.92 4,508.45 4,353.65 2,454.28 7,984.62 5,929,846.71 1,609,064.47 0.31 8,352.24 MWD+IFR-AK-CAZ-SC(3) 10,523.21 74.09 74.57 4,534.52 4,379.72 2,479.13 8,072.72 5,929,871.11 1,609,152.69 0.66 8,443.71 MWD+IFR-AK-CAZ-SC(3) 10,617.65 74.10 73.78 4,560.40 4,405.60 2,503.90 8,160.10 5,929,895.42 1,609,240.19 0.80 8,534.47 MWD+IFR-AK-CAZ-SC(3) 10,712.39 74.04 73.57 4,586.40 4,431.60 2,529.51 8,247.53 5,929,920.57 1,609,327.74 0.22 8,625.53 MWD+IFR-AK-CAZ-SC(3) 10,807.80 74.10 73.66 4,612.59 4,457.79 2,555.39 8,335.55 5,929,945.98 1,609,415.89 0.11 8,717.24 MWD+IFR-AK-CAZ-SC(3) 10,900.85 73.90 73.65 4,638.24 4,483.44 2,580.56 8,421.38 5,929,970.71 1,609,501.84 0.22 8,806.65 MWD+IFR-AK-CAZ-SC(3) 10,994.59 74.61 73.60 4,663.67 4,508.87 2,606.00 8,507.95 5,929,995.69 1,609,588.53 0.76 8,896.84 MWD+IFR-AK-CAZ-SC(3) 11,091.02 74.48 73.69 4,689.37 4,534.57 2,632.17 8,597.13 5,930,021.39 1,609,677.83 0.16 8,989.74 MWD+IFR-AK-CAZ-SC(3) 11,185.19 74.67 73.71 4,714.42 4,559.62 2,657.65 8,684.26 5,930,046.41 1,609,765.09 0.20 9,080.48 MWD+IFR-AK-CAZ-SC(3) 11,279.47 74.14 74.14 4,739.76 4,584.96 2,682.79 8,771.52 5,930,071.10 1,609,852.47 0.71 9,171.24 MW3+IFR-AK-CAZ-SC(3) 11,374.49 74.22 73.27 4,765.67 4,610.87 2,708.44 8,859.26 5,930,096.29 1,609,940.34 0.88 9,262.61 MWD+IFR-AK-CAZ-SC(3) 11,470.49 74.24 72.33 4,791.76 4,636.96 2,735.76 8,947.52 5,930,123.15 1,610,028.72 0.94 9,354.99 MWD+IFR-AK-CAZ-SC(3) 11,562.72 74.15 72.01 4,816.88 4,662.08 2,762.93 9,032.00 5,930,149.88 1,610,113.34 0.35 9,443.73 MWD+IFR-AK-CAZ-SC(3) 2/16/2015 3:20:59PM Page 5 COMPASS 5000.1 Build 65 • • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Coordinate Reference: Well 2L-308(Bertha) Project Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 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 11,657.13 73.61 71.88 4,843.09 4,688.29 2,791.04 9,118.23 5,930,177.53 1,610,199.70 0.59 9,534.43 MWD+IFR-AK-CAZ-SC(3) 11,752.19 73.71 72.03 4,869.83 4,715.03 2,819.30 9,204.96 5,930,205.34 1,610,286.58 0.18 9,625.65 MWD+IFR-AK-CAZ-SC(3) 11,846.95 73.74 72.34 4,896.39 4,741.59 2,847.13 9,291.56 5,930,232.71 1,610,373.31 0.32 9,716.61 MWD+IFR-AK-CAZ-SC(3) 11,942.07 73.71 73.11 4,923.05 4,768.25 2,874.25 9,378.75 5,930,259.37 1,610,460.63 0.78 9,807.91 MWD+IFR-AK-CAZ-SC(3) 12,036.36 73.64 74.06 4,949.55 4,794.75 2,899.82 9,465.55 5,930,284.48 1,610,547.55 0.97 9,898.37 MWD+IFR-AK-CAZ-SC(3) 12,129.96 74.16 74.31 4,975.51 4,820.71 2,924.32 9,552.08 5,930,308.54 1,610,634.20 0.61 9,988.23 MWD+IFR-AK-CAZ-SC(3) 12,224.88 74.89 76.01 5,000.84 4,846.04 2,947.75 9,640.50 5,930,331.50 1,610,722.73 1.89 10,079.57 MWD+IFR-AK-CAZ-SC(3) 12,319.96 75.25 78.53 5,025.34 4,870.54 2,967.99 9,730.10 5,930,351.27 1,610,812.43 2.59 10,171.04 MWD+IFR-AK-CAZ-SC(3) 12,413.37 75.37 80.68 5,049.03 4,894.23 2,984.29 9,818.97 5,930,367.11 1,610,901.38 2.23 10,260.59 MWD+IFR-AK-CAZ-SC(3) 12,507.42 75.25 83.49 5,072.88 4,918.08 2,996.82 9,909.07 5,930,379.17 1,610,991.53 2.89 10,350.15 MWD+IFR-AK-CAZ-SC(3) 12,602.52 75.25 86.52 5,097.10 4,942.30 3,004.83 10,000.67 5,930,386.69 1.611,083.17 3.08 10,439.75 MWD+IFR-AK-CAZ-SC(3) 12,696.15 75.21 90.55 5,120.98 4,966.18 3,007.14 10,091.16 5,930,388.54 1,611,173.65 4.16 10,526.52 MWD+IFR-AK-CAZ-SC(3) 12,791.71 74.43 94.95 5,146.01 4,991.21 3,002.72 10,183.25 5,930,383.64 1,611,265.71 4.52 10,612.74 MWD+IFR-AK-CAZ-SC(3) 12,885.33 74.67 99.04 5,170.96 5,016.16 2,991.74 10,272.80 5,930,372.19 1,611,355.19 4.22 10,694.51 MW1D+IFR-AK-CAZ-SC(3) 12,980.98 75.76 104.25 5,195.39 5,040.59 2,973.07 10,363.34 5,930,353.05 1,611,445.62 5.39 10,774.85 MWD+IFR-AK-CAZ-SC(3) 13,076.00 76.25 108.09 5,218.37 5,063.57 2,947.39 10,451.87 5,930,326.91 1,611,534.01 3.96 10,851.11 MWD+IFR-AK-CAZ-SC(3) 13,169.88 76.60 110.46 5,240.41 5,085.61 2,917.27 10,538.00 5,930,296.34 1,611,619.98 2.48 10,923.72 MWD+IFR-AK-CAZ-SC(3) 13,264.84 76.41 113.35 5,262.58 5,107.78 2,882.82 10,623.67 5,930,261.46 1,611,705.45 2.97 10,994.55 MWD+IFR-AK-CAZ-SC(3) 13,359.14 74.37 115.29 5,286.36 5,131.56 2,845.26 10,706.81 5,930,223.46 1,611,788.39 2.94 11,062.02 MWD+IFR-AK-CAZ-SC(3) 13,453.88 73.29 115.83 5,312.75 5,157.95 2,806.00 10,788.90 5,930,183.78 1,611,870.27 1.26 11,127.95 MWD+IFR-AK-CAZ-SC(3) 13,547.72 74.00 114.37 5,339.17 5,184.37 2,767.80 10,870.44 5,930,145.17 1,611,951.60 1.67 11,193.70 MWD+IFR-AK-CAZ-SC(3) 13,643.13 73.80 112.67 5,365.63 5,210.83 2,731.22 10,954.49 5,930,108.15 1,612,035.44 1.72 11,262.33 MWD+IFR-AK-CAZ-SC(3) 13,704.01 73.68 113.10 5,382.68 5,227.88 2,708.50 11,008.33 5,930,085.14 1,612,089.16 0.71 11,306.52 MWD+IFR-AK-CAZ-SC(3) 13,763.00 74.28 112.65 5,398.96 5,244.16 2,686.46 11,060.57 5,930,062.84 1,612,141.28 1.26 11,349.39 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 13,797.81 74.64 112.38 5,408.28 5,253.48 2,673.62 11,091.55 5,930,049.84 1,612,172.20 1.26 11,374.89 MWD+IFR-AK-CAZ-SC(4) 13,838.49 76.39 113.54 5,418.46 5,263.66 2,658.25 11,127.82 5,930,034.28 1,612,208.38 5.11 11,404.63 MWD+IFR-AK-CAZ-SC(4) 13,889.76 78.39 114.46 5,429.65 5,274.85 2,637.90 11,173.52 5,930,013.70 1,612,253.97 4.28 11,441.81 MVVD+IFR-AK-CAZ-SC(4) 13,933.91 80.03 115.68 5,437.92 5,283.12 2,619.52 11,212.80 5,929,995.12 1,612,293.15 4.60 11,473.49 MVVD+IFR-AK-CAZ-SC(4) 13,985.41 81.77 116.39 5,446.06 5,291.26 2,597.20 11,258.49 5,929,972.56 1,612,338.72 3.64 11,510.04 MWD+IFR-AK-CAZ-SC(4) 14,029.41 82.64 116.65 5,452.03 5,297.23 2,577.74 11,297.50 5,929,952.90 1,612,377.62 2.06 11,541.12 MW1J+IFR-AK-CAZ-SC(4) 14,076.37 83.16 118.09 5,457.83 5,303.03 2,556.32 11,338.88 5,929,931.26 1,612,418.88 3.24 11,573.86 MWD+IFR-AK-CAZ-SC(4) 14,122.04 83.47 120.24 5,463.15 5,308.35 2,534.21 11,378.49 5,929,908.95 1,612,458.37 4.72 11,604.70 MVVD+IFR-AK-CAZ-SC(4) 14,175.05 83.16 121.69 5,469.32 5,314.52 2,507.12 11,423.63 5,929,881.63 1,612,503.37 2.78 11,639.26 MWD+IFR-AK-CAZ-SC(4) 14,218.79 83.02 123.65 5,474.58 5,319.78 2,483.69 11,460.18 5,929,858.01 1,612,539.79 4.46 11,666.78 MWD+IFR-AK-CAZ-SC(4) 14,274.96 83.29 125.46 5,481.28 5,326.48 2,452.06 11,506.11 5,929,826.14 1,612,585.55 3.24 11,700.69 MWD+IFR-AK-CAZ-SC(4) 14,313.24 83.71 126.49 5,485.61 5,330.81 2,429.71 11,536.89 5,929,803.64 1,612,616.21 2.89 11,723.06 MWD+IFR-AK-CAZ-SC(4) 14,359.42 84.09 128.21 5,490.52 5,335.72 2,401.86 11,573.39 5,929,775.59 1,612,652.56 3.79 11,749.16 MWD+IFR-AK-CAZ-SC(4) 14,403.73 84.71 129.33 5,494.84 5,340.04 2,374.24 11,607.77 5,929,747.80 1,612,686.80 2.88 11,773.33 MWD+IFR-AK-CAZ-SC(4) 14,462.19 85.81 132.29 5,499.68 5,344.88 2,336.17 11,651.86 5,929,709.51 1,612,730.68 5.39 11,803.49 MWD+IFR-AK-CAZ-SC(4) 14,503.00 86.05 133.24 5,502.57 5,347.77 2,308.53 11,681.75 5,929,681.71 1,612,760.42 2.40 11,823.38 MWD+IFR-AK-CAZ-SC(4) 2/16/2015 3:20:59PM Page 6 COMPASS 5000.1 Build 65 • • 11) Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Rig:114.8+40 @ 154.80usft(Doyon 25) Well: 2L-308(Bertha) North Reference: True Wellbore: 2L-308 Survey Calculation Method: Minimum Curvature Design: 2L-308 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 14,551.46 86.48 133.84 5,505.73 5,350.93 2,275.22 11,716.80 5,929,648.22 1,612,795.30 1.52 11,846.42 MWD+IFR-AK-CAZ-SC(4) 14,575.53 87.35 134.04 5,507.03 5,352.23 2,258.54 11,734.11 5,929,631.46 1,612,812.51 3.71 11,857.73 MWD+IFR-AK-CAZ-SC(4) 14,597.83 88.13 134.81 5,507.90 5,353.10 2,242.94 11,750.02 5,929,615.78 1,612,828.34 4.91 11,868.04 MWD+IFR-AK-CAZ-SC(4) 14,646.52 90.95 138.27 5,508.30 5,353.50 2,207.61 11,783.50 5,929,580.28 1,612,861.64 9.17 11,888.96 MWD+IFR-AK-CAZ-SC(4) 14,693.86 91.27 139.04 5,507.38 5,352.58 2,172.08 11,814.77 5,929,544.59 1,612,892.71 1.76 11,907.72 MWD+IFR-AK-CAZ-SC(4) 14,788.91 92.12 140.04 5,504.57 5,349.77 2,099.79 11,876.42 5,929,471.99 1,612,953.98 1.38 11,944.02 MVVD+IFR-AK-CAZ-SC(4) 14,883.75 91.30 144.55 5,501.74 5,346.94 2,024.81 11,934.38 5,929,396.71 1,613,011.55 4.83 11,975.97 MWD+IFR-AK-CAZ-SC(4) 14,977.27 90.00 148.32 5,500.67 5,345.87 1,946.91 11,986.07 5,929,318.54 1,613,062.83 4.26 12,001.06 MWD+IFR-AK-CAZ-SC(4) 15,028.25 89.91 152.57 5,500.71 5,345.91 1,902.57 12,011.21 5,929,274.08 1,613,087.73 8.34 12,011.27 MWD+IFR-AK-CAZ-SC(4) 15,072.51 88.76 152.64 5,501.23 5,346.43 1,863.28 12,031.58 5,929,234.69 1,613,107.89 2.60 12,018.49 MWD+IFR-AK-CAZ-SC(4) 15,123.59 90.10 154.50 5,501.74 5,346.94 1,817.54 12,054.31 5,929,188.84 1,613,130.38 4.49 12,025.98 MVVD+IFR-AK-CAZ-SC(4) 15,167.12 90.68 156.29 5,501.44 5,346.64 1,777.97 12,072.43 5,929,149.17 1,613,148.30 4.32 12,030.99 MWD+IFR-AK-CAZ-SC(4) 15,219.12 91.13 160.26 5,500.62 5,345.82 1,729.67 12,091.67 5,929,100.79 1,613,167.28 7.68 12,034.36 MWD+IFR-AK-CAZ-SC(4) 15,259.65 90.91 161.76 5,499.90 5,345.10 1,691.36 12,104.86 5,929,062.41 1,613,180.27 3.74 12,035.06 MWD+IFR-AK-CAZ-SC(4) 15,312.55 91.63 165.09 5,498.72 5,343.92 1,640.68 12,119.94 5,929,011.65 1,613,195.09 6.44 12,033.75 MWD+IFR-AK-CAZ-SC(4) 15,345.47 90.77 165.75 5,498.03 5,343.23 1,608.82 12,128.23 5,928,979.76 1,613,203.21 3.29 12,031.79 MWD+IFR-AK-CAZ-SC(4) 15,403.85 90.17 167.84 5,497.56 5,342.76 1,551.99 12,141.56 5,928,922.86 1,613,216.24 3.72 12,026.91 MWD+IFR-AK-CAZ-SC(4) 15,448.32 90.05 169.65 5,497.47 5,342.67 1,508.38 12,150.24 5,928,879.21 1,613,224.70 4.08 12,021.68 MWD+IFR-AK-CAZ-SC(4) 15,509.91 88.14 171.73 5,498.44 5,343.64 1,447.61 12,160.20 5,928,818.40 1,613,234.34 4.58 12,012.38 MWD+IFR-AK-CAZ-SC(4) 15,541.03 88.84 171.43 5,499.26 5,344.46 1,416.84 12,164.76 5,928,787.61 1,613,238.73 2.45 12,007.20 MWD+IFR-AK-CAZ-SC(4) 15,636.05 88.26 171.45 5,501.67 5,346.87 1,322.91 12,178.90 5,928,693.61 1,613,252.38 0.61 11,991.62 MWD+IFR-AK-CAZ-SC(4) 15,737.59 91.42 171.76 5,501.95 5,347.15 1,222.47 12,193.72 5,928,593.11 1,613,266.68 3.13 11,974.68 MWD+IFR-AK-CAZ-SC(4) 15,832.23 91.51 172.10 5,499.53 5,344.73 1,128.80 12,207.00 5,928,499.38 1,613,279.47 0.37 11,958.37 MWD+IFR-AK-CAZ-SC(4) 15,927.16 89.78 173.31 5,498.46 5,343.66 1,034.65 12,219.06 5,928,405.18 1,613,291.03 2.22 11,940.74 MWD+IFR-AK-CAZ-SC(4) 16,022.15 89.35 173.98 5,499.18 5,344.38 940.25 12,229.57 5,928,310.73 1,613,301.05 0.84 11,921.56 MWD+IFR-AK-CAZ-SC(4) 16,118.12 89.55 173.47 5,500.11 5,345.31 844.86 12,240.06 5,928,215.29 1,613,311.04 0.57 11,902.06 MWD+IFR-AK-CAZ-SC(4) 16,211.70 90.34 174.10 5,500.20 5,345.40 751.83 12,250.19 5,928,122.22 1,613,320.69 1.08 11,882.95 MWD+IFR-AK-CAZ-SC(4) 16,306.38 90.44 175.75 5,499.55 5,344.75 657.52 12,258.56 5,928,027.89 1,613,328.57 1.75 11,861.77 MVVD+IFR-AK-CAZ-SC(4) 16,402.33 90.72 174.50 5,498.58 5,343.78 561.93 12,266.72 5,927,932.26 1,613,336.22 1.33 11,839.99 MWD+IFR-AK-CAZ-SC(4) 16,495.86 91.16 169.88 5,497.04 5,342.24 469,30 12,279.42 5,927,839.58 1,613,348.44 4.96 11,823.45 MWD+IFR-AK-CAZ-SC(4) 16,589.74 90.75 169.18 5,495.48 5,340.68 377.00 12,296.48 5,927,747.20 1,613,365.02 0.86 11,811.15 MVVD+IFR-AK-CAZ-SC(4) 16,685.28 90.72 166.83 5,494.25 5,339.45 283.56 12,316.33 5,927,653.66 1,613,384.38 2.46 11,801.15 MWD+IFR-AK-CAZ-SC(4) 16,780.79 91.20 166.71 5,492.65 5,337.85 190.60 12,338.19 5,927,560.60 1,613,405.75 0.52 11,793.21 MWD+IFR-AK-CAZ-SC(4) 16,875.56 92.43 166.32 5,489.65 5,334.85 98.49 12,360.27 5,927,468.38 1,613,427.36 1.36 11,785.75 MWD+IFR-AK-CAZ-SC(4) 16,970.27 92.31 168.20 5,485.73 5,330.93 6.19 12,381.14 5,927,375.99 1,613,447.74 1.99 11,777.08 MWD+IFR-AK-CAZ-SC(4) 17,032.45 90.04 167.49 5,484.46 5,329.66 -54.57 12,394.23 5,927,315.16 1,613,460.51 3.83 11,770.75 MWD+IFR-AK-CAZ-SC(4) 17,093.00 90.04 167.49 5,484.42 5,329.62 -113.69 12,407.35 5,927,255.99 1,613,473.32 0.00 11,764.96 4 1/2"x 6-1/2" 17,095.00 90.04 167.49 5,484.42 5,329.62 -115.64 12,407.78 5,927,254.03 1,613,473.74 0.00 11,764.77 PROJECTED to TD 2/16/2015 3:20:59PM Page 7 COMPASS 5000.1 Build 65 mea.. ®7._TW...n,.,s...... .,. �. . _<., 0 ........... .. 0 .2.., F � ���A0/��%�a THE STATE J.-A_�.,r�C < �� _ �� . mss,,"��� � �, 14142,7L-_-_:-_-::',A - 333 Well Seventh Avenue ,T (7aOVI;IRI OR S1 AN k�ARNr,IL Anchorage, Alaska 99501 3572 Mom: 907.279 1433 Liz C. Jolley Supervising Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2L-308 ConocoPhillips Alaska, Inc. Permit No: 214-151 Surface Location: 160.376' F7 LFNL, 3885.88' FEL SEC. 19, SEC. 22, oT10NER8E, UM ,UM Bottomhole Location: 395.05 Dear Ms. Jolley: Enclosed is the approved application for permit to drill the above referenced development well. he ilo hole In accordance with 20 AAC 25.005(f), all records,La308PHdata and logs acquired for and API numbert50-p103t20694-70t bbe clearly differentiated in both well name KR 00 from records, data and logs acquired for well KRU 2L-308. 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 es not e bauteen o ize col duIn ting onfilling operations until all other required permits and approvals 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, ---V-1-4 /99J-e.v374- -- Cathy . Foerster Chair DATED this le-day of October,2014. • STATE OF ALASKA . RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 6 2014 PERMIT TO DRILL 20 AAC 25.005 AOGCC 1 a.Type of Work: lb.Proposed Well Class: Development-Oil 2, Service- Winj ❑ Single Zone Q , 1c.Specify if well is proposed for: Drill 0% Lateral ❑ Stratigraphic Test ❑ Development-Gasp Service-Supply ❑ Multiple Zone ❑ Coalbed Gas❑ Gas Hydrates❑ Redrill❑ Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q. Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 • MUs, 2L-308• 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16954 a TVD: •5466 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Tarn Oil Pool„ Surface: 160.376'FNL,616.818'FEL,SEC.22,T10N,R7E,UM , ADL 380052,380051,&25603 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2839.23'FNL,112.648'FEL,SEC.13,T10N,R7E,UM ' 4602 11/15/2014 Total Depth:395.057'FNL, 3885.88'FEL,Sec 19,T10N, R8E,UM 4 9.Acres in Property: 14. Distance to Nearest Property: 2560,2560,&2512 1170'to ADL 380051 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I •156.6 feet 15. Distance to Nearest Well Open Surface: x- 461034 y- 5927684.94 Zone- • 4 GL Elevation above I -117.1 feet to Same Pool: 2L-309 SF=1.514 16.Deviated wells: Kickoff depth: .400 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: •90.36 degrees Downhole: 3,180• Surface: 2,641 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) 20" 16" welded 92' 28' 28' 120' 120' to be installed 13-1/2" 10-3/4" 45.5# L-80 Hyd563 2668' 28' 28' 2707' 236(p i 1143 sx 11#lead,194 sx 12#tail 9-7/8" 7-5/8" 29.7# L-80 Hyd563 12927' 28' 28' 12966' 5208' 936 Class G 15.8# 9-7/8" 7-5/8" 39# TN110SS Hyd563 300' 12966' 5208' 13266'/ 5279' 6-1/2" 4-1/2" 12.6# L-80 IBTM 3838' 13116' 5240' 16954' 5466' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q • Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q • 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 9/24/2014 22. I hereby certify that the foregoing is true and correct. Daniel Bearden 263-4864 Contact j.daniel.bearden(a�COP.com F-02 c.4tip Email Printed Name Liz C.Jolley kvfo Title Supervising Drilling Engineer Signature k6.C:2Phone 265-6247 Date 1 • 2.S. '/.� Commission Use Only Permit to Drill n( API Number: Permit Approval See cover letter for other Number: cQ1 - 15 Q(Q ( 50-003- ) 9y 00 -OC2, Date: \p �,( -ALL \ ` requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalt meth24,gas hydrates,or gas contained inert ales: ,� r� Other: o p fc s f '-o 3 5-0 p p S 1 Samples req'd: Yes jf Nq• ] Mud log req'd:Ye c1 N Lc �/4 h rt v/4 r t-e S /- ¢o .2 Sa O ip$ t H25 measures: Yes❑ N Directional svy req'd:Yeti NLld I / e Z3 L rcq Li,- c/ O v, r rl i y L' a Jt '{5pacing exception req'd: Yes NoL�LJ Inclination-only svy req'd:Yes No 9. -^� APPROVED BY Approved by: \ a f,, icGititt AR! THE COMMISSION Date:/Q-/`ji i6/i5// ,.i '\ i.•+ ?11)1 iLZ 11 11 Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25$$.0 5(g)) Attachments in Duplicate .6 r .7' • • Post Office Box 100360 ConocoPhillips Anchorage,Alaska 99510-0360 Phone(907)263-4864 Email: i.daniel.bearden(&conocophillips.com September 22, 2014 RECEIVED Alaska Oil and Gas Conservation Commission RECEIVED y 333 West 7th Avenue, Suite 100 SEP 2 6 2014 Anchorage,Alaska 99501 (� Re: Application for Permit to Drill 2L-308 AOGCC e DGCC Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 2L-308 from the Tarn 2L drilling pad. This well is intended to be a horizontal producing well from the Bermuda/ horizon. The intended spud date for this well is November 15th, 2014 using Doyon 25. I When the Doyon 25 rig moves onto 2L-308,the proposed plan is to nipple up and test the diverter system utilizing the existing 16" conductor, spud the well with a 13-1/2" bit, drill to the surface casing point,then run and cement the 10-3/4"45.5#L-80 Hydril 563 surface casing in place. A 9-7/8"bit will be made up and the surface casing drilled out. The well will then be drilled down to the intermediate casing point(topsetting the Bermuda)where a string of 7-5/8"29.7#L-80 Hydril 563 casing will be run and cemented in place. A 6-1/2" planned pilot hole into the Bermuda will be drilled for reservoir navigation and data collection. This pilot hole/ will be plugged back with a cement kickoff plug and a 6-1/2"bit will be run to drill the horizontal lateral portion of the well to TD. A 4-1/2" production liner with swell packers and frac sleeves will be slid in position for future frac operations. Finally,the upper completion will consist of 3-1/2"gaslifted tubing. Please find attached the information required by 20 ACC 25.005(a)and(c)for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Dan Bearden at 263- 4864. Sinpr� ly, '''. S ed--(citL______ Da iel Bearden Drilling Engineer Attachments ORIGINAL • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 I 2L-308 Application for Permit to Drill Document Co ocoPfiillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 6 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 (Requirements of 20 AAC 25.005 (c)(14)) 7 1811\IAL 21 of 14 APD Page 1 Printed:23-Sep-14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Proposed Well Schematic 8 HNAL 2L-308 APD Page 2 of 14 Printed:23-Sep-14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2L-308. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a horizontal producer to improve Bermuda oil recovery and pattern sweep efficiency in the newly discovered pay from the 2010 seismic program at Tarn. The Doyon 25 rig will drill a 13-1/2" surface hole and case with 10-3/4" L-80 with premium connections. The 9-7/8" intermediate section will be drilled to +/- 150' MD above the Bermuda sand, and 7-5/8"top-set casing will be run. A 6- 1/2" planned pilot hole into the Bermuda will be drilled for reservoir navigation and data collection. This pilot hole will be plugged back with a cement kickoff plug and a 6-1/2" bit will be run to drill the horizontal lateral portion of the well. A 4-1/2" production liner, equipped with swell packers and frac sleeves will be run into the open hole for the lower completion. Finally, a 3-1/2" gaslifted tubing assembly will be run for the upper completion. Location at Surface 160.376' FNL, 616.818' FEL, Sec 22, T1ON, R7E, UM ' NAD 1927 RKB Elevation 156.6'AMSL Northings: 5,927,684.94 Eastings: 461,034.15 Pad Elevation 117.1'AMSL Location at 7 5/8" Intermediate Csg Pt. 2,565.18' FNL, 553.33' FEL, Sec 13, T1ON, R7E, UM Nad 1927 Measured Depth, RKB: 13,266' Northings: 5,930,512.47 Eastings:471,667.06 Total Vertical Depth, RKB: 5,279' Total Vertical Depth, SS: 5,122' Location at Total Depth on 2,838.91' FNL, 4,986.82' FEL, Sec 18, T1ON, R8E, UM Pilot Hole Nad 1927 Measured Depth, RKB: 14,066' Northings: 5,930,236.39 Eastings:472,304.25 Total Vertical Depth, RKB: 5,655' Total Vertical Depth, SS: 5,498' Location at Top of Productive 2,839.23' FNL, 112.648' FEL, Sec 13, T1ON, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 13,799' Northings: 5,930,236.81 Eastings:472,106.69 Total Vertical Depth, RKB: 5,391' Total Vertical Depth, SS: 5,234' Location at Total Depth 395.057' FNL, 3,885.88' FEL, Sec 19, T1ON, R8E, UM (Toe) Nad 1927 Measured Depth, RKB: 16,954' Northings: 5,927,396.57 Eastings: 473,406.47 Total Vertical Depth, RKB: 5,466' Total Vertical Depth, SS: 5,309' } h 2L-308 APD ORIGINAL Printed 23-Sep-14 14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 25. f 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: • NOTE: The Doyon 25 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: The maximum potential surface pressure (MPSP) while drilling 2L-308 is calculated using an estimated reservoir pressure of 3,180 psig (11.3 ppg)1, a gas gradient of 0.10 psi/ft, and the estimated depth of the Bermuda formation at 5,394' TVD. 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. MPSP/MASP calculation ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1]x 5,394' = 3,528 psi OR ASP = FPP—(0.1 x D) =3,180—(0.1 x 5,394') = 2,641 psi (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. 2L-308 APD Page 4 of 14 Printed:23-Sep-14 U R I ,.� ! N A L • S Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 (C)Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The Tarn reservoir model predicts the 2L-308 will find reservoir pressure at or near original reservoir pressure of 2,000 to 2,400 psig at the heel of the well with the potential for higher pressures as we drill out towards the current injectors. The upper limit of reservoir pressure we are planning for is 3,180 psig and we will continue to monitor pressures as the spud date approaches. 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 164.8 B-35 Welded 92' Surf 120'/120' Driven Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,668' Surf 2,707/2,366' 1,143 sx ASC Lead 11 ppg 194 sx Tail Slurry 12 ppg 7-5/8 9-7/8 29.7 L-80 Hydril 12,927' Surf 12,966'/5,208' 563 Cement Top planned @ 9,700'MD/ TN- 4,312'TVD. Cemented w/ 7-5/8 9-7/8 39 110S H56311 300' 12,966'/5,208' 13,266'/5,279' 936 sx GasBLOK Class G 15.8 ppg S N/A,will have swell packers&frac 4 1/2 6 1/2 12.6 L-80 IBTM 3,838' 13,116'/5,240' 16,954'/5,466' sleeves Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 4.5" 12.6 L-80 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Doyon 25. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(C)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: 2L-308 APD Page 5 0114 Printed:23-Sep-14 ORIGINAL • S Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.6 - 10 ppg 9.6— 10.0 ppg 10.4 - 11.0 ppg YP 60- 80 18-28 12- 18 Funnel Viscosity(sec) 75—250 40-55 PV 20-60 20-25 18-22 Initial Gels 10-35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Chlorides <1000 9.0— 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND water-based mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND/KLASHIELD water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.4 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 2L-308 APD Page 6 of 14 Printed:23-Sep-14 ORIGINAL • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 25 on 2L-308 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor to get 13-1/2" BHA below ground level. 5. Spud and directionally drill 13-1/2" hole to the 10-3/4" surface casing point(2,707' MD/2,366'TVD) according to the directional plan. Run MWD/LWD logging tools in drill string (GR/RES/PWD/Gyro'/ while drilling) and on-site mud logging for directional monitoring and formation data gathering. 6. Run and cement 10-3/4"45.5#L-80 Hydril 563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job if losses do not occur. Displace cement with mud. Perform top job if required to bring cement to surface. 7. Nipple down diverter and install wellhead and test to 5000 psi. Notify State 24 hrs prior to BOPE test. Nipple up BOPE and test to 3,500 psi. Record results. ,✓ 8. Shut in BOP's and pressure test surface casing to 3,000 psi per AOGCC regulations. Record results. 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 10. Directionally drill 9-7/8" intermediate hole t9 13,266' MD/5,279'TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD7with on-site mud logging and field geologist for directional ✓ monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to TD and cement in place with a minimum of 500' of cement above the C37 formation. 13. MU 6-1/2" bit and RIH on 4" drill pipe. 14. Directionally drill a 6-1/2" pilot hole to 14,066' MD/5,655'TVD. Run MWD/LWD logging tools in drill string (GR/RES/Newt/DENS/PWD/Periscope/Stethoscope/Sonicscope for CBL evaluation)for / navigational monitoring and formation data gathering. POOH 15. Run back in with 3-1/2" cement stinger to 14,066' MD and lay a cement kickoff plug back to 200' inside the 7-5/8" casing shoe. 16. Pick up same directional BHA (used to drill pilot hole) with 4" drill pipe, RIH,jump plug below the 7- 5/8" shoe, and drill a 6-1/2" production hole to 16,954' MD/5,466' TVD as per directional program. 17. POOH, and RU casing crew and cementers. 18. MU and run a 4-1/2" liner to TD and set the ZXP liner top packer on top of the Flex Lock liner hanger leaving a 150' liner lap. 19. Perform a pressure test on the liner top packer, POOH and LD 4" drill pipe 20. Run 3-1/2" completion tubing with premier packer and seals and set packer at +/- 13,066' MD/5,225' TVD. 21. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class ll disposal well (1R-18 or new facilities at DS1 B).d All cuttings generated will be hauled to the Prudhoe 2L-308 APD Page 7 of 14 ORI G I N A L Printed:23-Sep-14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic OIGINAL2L-308 Printed 23-Sep-14 PD • S Loepp, Victoria T (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday, October 09, 2014 1:47 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-308(PTD 214-151) Mud Weight Attachments: 2L-308 Pad Areal Photograph.pdf Hi Victoria, I am waiting on Doyon to provide me with a diverter schematic that accompanies Rig 25. Attached is a pad areal the displays the requested infrastructure within a 100' radius of the diverter discharge. Due to a possibility that the diverter cannot be routed north (under existing cable tray)we are analyzing an alternative diverter route, as displayed in the attached PDF. The reservoir engineering department has done a good job at providing us a range of expected pore pressures,with a most likely midpoint. In the case of planned well 2L-308,we have been provided with a range of 2350—3,180 psi (8.4— 11.3 ppg)with a most likely pressure of 2,600 psi (9.3 ppg). Our plan is to weight up to 10.4 ppg prior to penetrating the Bermuda reservoir and immediately perform a 30-minute flowcheck,and also flowcheck during connections. Based on what we see,we will add or dilute weight accordingly. We will have MI place tanks on location with kill weight fluid of 11.5 ppg and have additional barite on location to cover any extra needed weight. The robust design of top-setting the reservoir at Tarn mitigates the hazard of encountering high (or low) Bermuda pressure because the shallow weak zones(Campanian/Iceberg)will be behind pipe prior to Bermuda penetration. Thanks, and I hope to send you the Doyon 25 diverter schematic soon. Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Loepp, Victoria T(DOA) [ ailto:victoria.loepp@alaska.gov] Sent: Thursday, October 09, 2014 1:25 PM To: Bearden, J Daniel Subject: [EXTERNAL]RE: KRU 2L-308(PTD 214-151) Mud Weight Daniel, The reservoir pressure at the Bermuda formation is estimated at 3180 psi(11.3 ppg). Is the planned mud weight for the production hole of 10.4 to 11.0ppg adequate? Thanx, Victoria From: Loepp, Victoria T(DOA) Sent: Wednesday, October 08, 2014 2:37 PM To: Bearden, J Daniel (J.Daniel.Bearden@conocophillips.com) Subject: KRU 2L-308(PTD 214-151)Aerial View of Diverter route and area 1 • • Daniel, On diverter schematics, would like to see the diverter route on an aerial that shows all the buildings, roads and flowlines,at a minimum within about 100'of the diverter route and discharge. Thanx, Victoria Please note new name and new email address. Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 • • ConocoPhillips . f • , laska . .. { � "' cJ 0 rC2Lca• �� 'L s -., ,,;,„1tL,,,,,,,,q --- a £. R Lei„ �.z t _ L i F p; d t- _.1 tin ui ,, tl <nL L' a c. ` F2 ,azv ' _ �,,. nyZt1� a 414,iiii!:,,,,,„-*:.ieuYc AL ,.. ilk ,' iiep t 1 , , , -R l: 4. ' e rbc KUPAFII A3O7 1 adtus 'V ., ,-,. ,xs, —,`' 3 i f 3 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Attachment 1 —Directional Plan LJ IGNAL p-3008 of 14 APD Printed:23-Sep-14 ! • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2L-308 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/2" Hole /4-1/2" Horizontal Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. R2L-308 APD ® I in I N A L Printed g 23 -14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 2L-308 well plan. Anti-collision analysis indicates the following separation factors between the planned 2L-308 well plan and the following existing wellbores. 2L-309 (Separation Factor= 1.514, 13.3' center to center at a depth of 457' MD) 2L-310 (Separation Factor= 1.873, 18.70' center to center at a depth of 588' MD) 2L-305 (Separation Factor= 1.901, 45.15' center to center at a depth of 1,320' MD) Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset1to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. Mandatory flow checks will be performed upon penetration and when tripping out of suspected gas or overpressured zones such as the Campanian, Iceberg, and Bermuda intervals. 7 Lower Shale Stability: Unstable shale and ash in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 2L-308 APD ORIGINAL Printed:23-Sep-14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Attachment 3—Proposed Well Schematic Tarn 2L-308 Bertha 11'- Grass Roots Topset Pilot Hole Horizontal Multi-Stage Freed Producer co ConoUl�1p5 Proposed Wellbore Schematic 1,�,f J 'CAMERON 4-L 'tree,top joint is 4-V,-_12.64 IBTM,crossed over(for frac equipment) 77 l Bearden 9,23201413.1/2"Surface Hole Conductor To Be Installed: 16"62.6#H-40 3`I Carom DS Nixie 2.875" j 13 SIP MD!(GD TVD DrillPlex 9,6 PPG —J 314'41'Cameo KSMG Surface Casing: 10-314"45.5#L-80 Hydril 563 2,707'MD/2,366'TVD @ 63` Ph'x1.Campo KSMC Campanian Top 3,345'MD{2,5i2Tu6 LSND J 3.6-10.0PPG 3We1.camcoic8MG Tubing: Keep up with 3-W 9.3#L-80 EUE8RD Dilution 4-'/a"12.6#L-80 IBTM top joint to surface 9-7/8"Intermediate Hole 3 Vi r Carom KDMG ':;J _ Estimated top of cement @+1-9,700'MD (500'above C37) 3'5"x i'Canto*MG Iceberg Top 14,693:14p$,ae7 Tvo) III :: Baker CMU Sliding Sleeve CLOSED w! 2.812'Camco'DS'Profile 10'above Down hole gauge-12,800'MD production packer ■ 3.5"x 7-5'8",Baker Premier Packer 13066'MD 3%'Cameo 0 nipple nogo 2.75' 7-5,8",ZXP Liner Top Packer 13,116'MD 7-518"x 4-'.4"Baker Flex Lock Liner hanger wr RS Nipple. 13 116'MD Intermediate Casing Topset with Bonzai: Ail 7-5/8"29.7#L-80 8r TN 110SS 39# all »,„unnecti, Top d Bermuda 13,512'MD(5 394'TVD) 13,266'.MD/5,279'TVD @ 76° P :: ', *M':. ':•:: ]::. ly\\ '\,,:iiMiHWt*I.1.*4.0.iiiiii*.fiiiii::iMiiii*-j&j4ii4:tiiiiiii H:O.,i ! : E :::: 8'fa.' 0 0 0 0 0 0 ill Iii Nlr.711111-11111F-111117.IIIIIIICI :::B2rmtit a Poore:Pressure:-:E:p:ct lecreasi:g pt ss i'e:: '''. .. • :4•-- ..::::::::::::::::::::::::::::::::::::::: '. 3 1. 2•i..0.1)'1:8(3 ''i')::::: ::::::::::::::: :::::::::::::::::::::::::::: Production Liner 0 90 : 4-112"12.6#L-80 IBTM(w/torque rings to rotate in liner to TD) perf'd pupjoint for 13,116'MD to 16,954'MD 5,212'TVD to 5,466'TVD circulation 2L-308 APD Page-S op 14 CjksIGINAL Printed:23-Sep-14 • • Application for Permit to Drill,Well 2L-308 Saved:23-Sep-14 Attachment 4—Cement Summary 10-3/4" Surface Casing Cement Job Cement 10-3/4" casing from shoe @ 2,707' MD to 2,207' MD (500' of fill) with 12 PPG LiteCrete, and from 2,207' to surface with 11.0 PPG Arctic LiteCRETE. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (Base Perm is 1,478' MD), zero excess in 16" conductor. Lead Slurry: (120')x 0.638 ft3/ft x 1.0 (0% excess) = 77 ft3 (1,478'— 120') x 0.364 ft3/ft x 3.5 (250% excess) = 1730 ft3 above permafrost (2,207'— 1,478)x 0.364 ft3/ft x 1.5 (50% excess) = 398 ft3 below permafrost Total volume=77 ft3+ 1730 ft3+398 ft3= 2205 ft3=> 1,143 Sx @ 1.93 ft3/sk Lead: 1,143 Sx Arctic LiteCRETE @ 11.0 PPG Tail Slurry: (2,707'—2,207') x 0.364 ft3/ft x 1.5 (50% excess) =273 ft3 annular volume 80' x 0.54 ft3/ft=43.2 ft3 shoe track volume Total volume=273 ft3 +43.2 ft3= 316.2 ft3 => 194 Sx @ 1.63 ft3/sk Tail: 194 Sx LiteCRETE @ 12.0 PPG 7-5/8" Intermediate Casing Cement Job Cement 7-5/8" casing from shoe @ 13,266' MD to 9,700' MD (minimum of 500' above the top of the Pool C37)with Class G +Adds @ 15.8 PPG. Assume 40% excess in the open hole volume. Lead Slurry: (13,266'—9,700') x 0.215 ft3/ft x 1.40 (40% excess) = 1074 ft3 in open hole 80' shoe track x 0.258 ft3/ft x 1.0 (0% excess) =20.6 ft3 Total volume= 1074 ft3+20.6 ft3= 1095 ft3=> 936 Sx @ 1.17 ft3/sk Total: 936 Sx Class G @ 15.8 PPG 6-1/2" Pilot Hole P&A/Kickoff Plug Cement 6-1/2" hole from TD @ 14,066' MD up to 200' inside 7-5/8" intermediate casing shoe with 17 ppg Class G +adds. Assume 50% excess in the open hole volume. Slurry: (14,066'— 13,066') x 0.2305 ft3/ft x 1.50 (50% excess) = 346 ft3 in open hole 200' inside shoe x 0.239 ft3/ft x 1.0 (0% excess) =47.9 ft3 Total volume= 346 ft3 +47.9 ft3 => 394 ft3=> 394 Sx @ 1.0 ft3/sk Total: 394 Sx Class G @ 17 PPG 2L-308 APD Page 13 of 14 Printed:23-Sep-14 IGINAL • •ke�►vi,c ?I2.y'iN 1343 2L-3O8PBlwpO5 6.770 Plan Summary ovw SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1300.00 GYD-GC-SS 1300.00 2706.00 MWD \ ii' 1300.00 2706.00 MWD+IFR-AK-CAZ-SC 2706.00 3800.00 MWD ` \) 2706.00 13266.26 M W D+I FR-AK-CAZ-SC � 4,11„ 13266.26 14065.73 MWD `�, 13266.26 14065.73 MWD+IFR-AK-CAZ-SC `� \` CASING DETAILS ``\,; '„ TVD MD Name Size i 2366.44 2707.20 10-3/4" x 13-1/2" 10-3/4 ', 5278.88 13266.25 7-5/8"X 9-7/8" 7-5/8 5655.00 14065.73 4-1/2"x 6-1/2" 4-1/2 0 0° 10-3/4"x 13-1/2" 10-3/4"x 13-1/2" 7-5/8"X 9-7/8" 4-1/2"x 6-1/2" 35 ° 4-1/2"x 6-1/ C-90 Iceberg T4 iop Bermuda o 0 5- PFrost _5 0 0 0 0 7-5/8"X 9-7/8" z C-80 C-50 C-40 Fault > ` ,, o > r vo 0 0 o T7- - �_ if Camp_SST 7 Mase Bermuda CO m o o N o 1, a 0 - Too Berm&is o __. -__._. �^ ,oSo �. , �I - rn 0 1 i r " ) + 0 0 2000 4000 6000 8000 10000 12000 0 3500 7000 10500 14000 Horizontal Departure Measured Depth 0 '1,117 I .__-_, 330 N 60- .. / li 1�I - 30 _ Ilk '��1 - Y pie 1700 - 2119 - (n I iI ill k I '45.:901.91f."? s �� .., '1"'"i2700 _ < 00 ` ri- I 2L-308 wp05 AI V.V. .4)2 ° -- - ----- 270 ' ' 90 woo eto, - ASAI.I10600 .1 11101 SI •j' 240 4��tu0,2 13266 - 11199 of 11900 '113. 11266 13500 - 10,01 0 .' 1 i I I I 1 i i I I I I 1 I 1 I 1 I 1 i I I I I 1I210 "� uu om''''''d13900 - 13/00 13700 19800 0 2000 4000 6000 8000 10000 12000 14000180 SECTION DETAILS Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing 160iI�Q DLeg TFace VSec Target 1 39.50 0.00 0.00 39.50 -117.10 0.00 0.00 5927434.16 0.00 0.00 0.00 2 315.00 0.00 0.00 315.00 158.40 0.00 0.00 5927434 16 1601067.89 0.00 0.00 0.00 3 550.15 3.53 10.00 550.00 393.40 7.13 1.26 5927441.28 1601069.18 1.50 10.00 3.40 4 903.84 12.28 20.78 900.00 743.40 53.11 16.52 5927487.17 1601084.69 2.50 15.00 32.12 5 1099.97 15.33 37.04 1090.52 933.92 93.32 39.55 5927527.27 1601107.92 2.50 60.00 66.45 6 1420.00 18.62 63.55 1397.02 1240.42 149.94 110.90 5927583.50 1601179.56 2.60 80.00 151.81 7 1520.00 18.62 63.55 1491.78 1335.18 164.16 139.49 5927597.58 1601208.22 0.00 0.00 183.39 8 2706.00 63.37 77.92 2365.90 2209.30 370.38 865.92 5927799.98 1601935.64 3.83 18.13 937.99 9 2736.00 63.37 77.92 2379.35 2222.75 375.99 892.14 5927805.46 1601961.89 0.00 0.00 964.66 10 3023.51 74.11 73.48 2483.51 2326.91 442.41 1151.22 5927870.52 1602221.29 4.00 -21.91 1231.59 11 12172.01 74.11 73.48 4989.05 4832.45 2943.78 9586.90 5930327.65 1610669.05 0.00 0.00 10027.36 12 13266.26 76.35 113.08 5278.88 5122.28 2882.65 10619.22 5930261.15 1611700.95 3.50 92.02 10990.27 2L-308 wp04Int Csg 13 13296.26 76.35 113.08 5285.96 5129.36 2871.22 10646.04 5930249.58 1611727.71 0.00 0.00 11012.25 14 14065.73 45.57 113.08 5655.00 5498.40 2610.66 11257.53 5929985.86 1612337.76 4.00 180.00 11513.28 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2014 TM Depth Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Magnetic Model Date: 05-Dec-14 4Eb_A System(SS)Reference: Mean Sea Level Magneticgnc DirectionDeclination: a True North /Y: 5927434.16 To convert a Magnetic to a True Direction,Add 18.83°East Ground Level/Mud Line: 117.10 East/X: 1601067.89 Rig: Doyon 25 GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference • I ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-308 (Bertha) Plan: 2L-308PB1 Plan: 2L-308PB1wp05 Plan Summary 22 September,2014 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan.2L-308(Bertha) Project: Kuparuk River Unit ND Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 2L Pad Site Position: Northing: 5,927,444.35 usft Latitude: 70°12'47.137 N From: Map Fasting: 1,601,111.65 usft Longitude: 150°19'1.199 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.30° Well Plan:2L-308(Bertha) Well Position +NI-S 0.00 usft Northing: 5,927,434.16 usft Latitude: 701 12'47.035 N +El-W 0.00 usft Easting: 1,601,067.89 usft Longitude: 150°19'2.468 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.10 usft Wellbore Plan:2L-308PB1 • Magnetics Model Name Sample Date Declination Dip Angle Field Strength 11 11 (nT) BGGM2014 12/5/2014 18.83 80.78 57,551 Design 2L-308PB1wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.50 0.00 0.00 72.00 9222014 2:59:07PM _ COMPASS 5000.1 Build 61 0 i 2L-308PB1 wp05 Plan View 6000 7-5/8" X 9-7/8" 4500 o' 0 _ - ®® 000 � °6 D 0 0 0 0 Lo o o 0 T d oo o 500- 10-3/4" x 13-1/2" 0 4-1/2"x 6-1/2" o 0 0 Z o J d 0 0 o o t� 0 Q ea- 42 co n) ti -1500- -3000 0 1500 3000 4500 6000 7500 9000 10500 12000 West(-)/East(+) (1500 usfflin) • • 2L-308PB1 wp05 Section View -1500- 0- A 0° c 1000 1500- 00 o ° o 0 o o o 10-3/4" x 13-1/2" h o 0 3000- 0 0 0 0 0 N. v o ^ UQD O o _ O O N OO O N o o 2 4500- o , 0) be 7-5/8" X 9-7/8" 6000- 4-1/2"x 6-1/2" Ota .\449 OOe� 7500- I I I I I -- --_ I I I 0 1500 3000 4500 6000 7500 9000 10500 12000 Vertical Section at 72.00°(1500 usft/in) • • 15:18,September 22 2014 Easting(2500 usft/in) I 1 � � � 1 ) 111 1111111111111IIIII1IIIIII11 „ I1 „ 111111111111111111111111111111111111111111 AC wells ONLY (NOT a Spider) - 2S-14wp05[Whale] — _ 2L-03 Kuparuk 2L Pad Plan: Kuparuk 2S Pad 2L 308P61wp05 —Z 0 ca _ 2L-306P61 _ s _ 3 O -al or _ / 2L-319 N 06 0 a- - o C i tik, _ Z _ —__ 2L-308 wp05 = x \\\`-2 - - 2L-310 _ 2L-305 �� 2L-311 2L-304 2L-316PB1wp03 - -`L-307 _ 2L-318 2L-3 • 1111/4- , pp .-2�-3- 0':1 - L-322 2L-301 2L-302(wp01) - L-316wp04 L-323 2L-317A - 2L-325 - 2L-320 2L-302L1 (wp01) - 2L-322A 2L-321 _ -2I-309 111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111I Easting(2500 usft/in) 0 S Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 la 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5(4)156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Survey Tool Program Date 9/22/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,300.00 2L-308PB1wp05(Plan:2L-308PB1) GYD-GC-SS Gyrodata gyro single shots 1,300.00 2,706.00 2L-308PB1wp05(Plan:2L-308PB1) MWD MWD-Standard 1,300.00 2,706.00 2L-308PB1wp05(Plan:2L-308PB1) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC I 2,706.00 3,800.00 2L-308PB1wp05(Plan:2L-308PB1) MWD MWD-Standard 2,706.00 13,266.26 2L-308PB1wp05(Plan:2L-308PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,266.26 14,065.73 2L-308PB1wp05(Plan:2L-308PB1) MWD MWD-Standard 13,266.26 14,065.73 2L-308PB1wp05(Plan:2L-308PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (soft) (°) (°) If (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 39.50 0.00 0.00 39.50 -117.10 0.00 0.00 5,927,434.16 1,601,067.89 0.00 0.00 100.00 0.00 0.00 100.00 -56.60 0.00 0.00 5,927,434.16 1,601,067.89 0.04 1.15 200.00 0.00 0.00 200.00 43.40 0.00 0.00 5,927,434.16 1,601,067.89 0.19 1.15 300.00 0.00 0.00 300.00 143.40 0.00 0.00 5,927,434.16 1,601,067.89 0.33 1.15 315.00 0.00 0.00 315.00 158.40 0.00 0.00 5,927,434.16 1,601,067.89 0.36 1.15 KOP:DLS 1.5 TFO 10 400.00 1.27 10.00 399.99 243.39 1.50 10.00 5,927,435.09 1,601,068.06 0.48 1.15 500.00 2.77 10.00 499.93 343.33 1.50 0.00 5,927,438.57 1,601,068.69 0.62 1.15 550.15 3.53 10.00 550.00 393.40 1.50 0.00 5,927,441.28 1,601,069.18 0.70 1.15 Start DLS 2.50 TFO 15.00 600.00 4.74 13.90 599.72 443.12 2.50 15.00 5,927,444.78 1,601,069.96 0.77 1.15 700.00 7.21 17.74 699.17 542.57 2.50 11.11 5,927,454.76 1,601,072.92 0.92 1.15 800.00 9.70 19.62 798.08 641.48 2.50 7.29 5,927,468.65 1,601,077.74 1.08 1.15 900.00 12.19 20.74 896.25 739.65 2.50 5.42 5,927,486.42 1,601,084.40 1.24 1.15 903.84 12.28 20.78 900.00 743.40 2.50 4.33 5,927,487.17 1,601,084.69 1.25 1.15 Start DLS 2.50 TFO 60.00 1,000.00 13.64 29.64 993.72 837.12 2.50 60.00 5,927,506.55 1,601,094.03 1.42 1.15 9222014 2:59:07PM Page 3 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Fasting Lat.Error Vert.Error (usft) (°) (°) (usft) )usft) (°l100usft) (°) (usft) (usft) (usft) (usft) 1.099.97 15.33 37.04 1,090.52 933.92 2.50 51.36 5,927,527.27 1,601,107.92 1.60 1.15 Start DLS 2.60 TFO 80.00 1,100.00 15.33 37.04 1,090.55 933.95 0.00 0.00 5,927,527.27 1,601,107.93 1.60 1.15 1200.00 15.98 46.39 1,186.85 1,030.25 2.60 80.00 5,927,54722 1,601,125.96 1.78 1.16 1,300.00 17.00 54.82 1,282.75 1,126.15 2.60 71.00 5,927,565.03 1,601,147.97 1.96 1.17 1,400.00 18.33 62.20 1,378.05 1,221.45 2.60 62.91 5,927,580.65 1,601,173.91 2.06 1.17 1,420.00 18.62 63.55 1,397.02 1,240.42 2.60 55.88 5,927,583.50 1,601,179.56 2.07 1.17 Start 100.00 hold at 1420.00 MD 1,477.60 18.62 63.55 1,451.60 1,295.00 0.00 0.00 5,927,591.61 1,601,196.07 2.16 1.18 PFrost 1,500.00 18.62 63.55 1,472.83 1,316.23 0.00 0.00 5,927,594.76 1,601,202.49 2.16 1.18 1,520.00 18.62 63.55 1,491.78 1,335.18 0.00 0.00 5,927,597.58 1,601,208.22 2.19 1.18 Start DLS 3.83 TFO 18.13 1,600.00 21.56 66.15 1,566.91 1,410.31 3.83 18.13 5,927,609.08 1,601,233.16 2.37 1.18 1,700.00 25.27 68.58 1,658.66 1,502.06 3.83 15.69 5,927,624.12 1,601,269.92 2.72 1.17 1,800.00 29.01 70.42 1,747.64 1,591.04 3.83 13.46 5,927,639.82 1,601,312.73 3.24 1.17 1,900.00 32.77 71.87 1,833.44 1,676.84 3.83 11.82 5,927,656.13 1,601,361.39 3.90 1.18 2,000.00 36.55 73.05 1,915.68 1,759.08 3.83 10.58 5,927,672.95 1,601,415.70 4.70 1.21 2,100.00 40.33 74.03 1,994.00 1,837.40 3.83 9.61 5,927,690.23 1,601,475.39 5.62 1.26 2,200.00 44.12 74.88 2,068.03 1,911.43 3.83 8.83 5,927,707.88 1,601,540.22 6.66 1.33 2,300.00 47.92 75.82 2,137.46 1,980.86 3.83 8.21 5,927,725.82 1,601,609.88 7.80 1.44 2,400.00 51.72 76.27 2,201.97 2,045.37 3.83 7.69 5,927,743.97 1,601,684.08 9.03 1.59 2,481.32 54.81 76.75 2,250.60 2,094.00 3.83 7.27 5,927,758.83 1,601,747.52 10.34 1.77 C-90 2,500.00 55.53 76.86 2,261.27 2,104.67 3.83 6.98 5,927,762.26 1,601,762.46 10.34 1.77 2,600.00 59.33 77.40 2,315.09 2,158.49 3.83 6.92 5,927,780.59 1,601,844.69 11.72 1.98 2,700.00 63.14 77.89 2,363.20 2,206.60 3.83 6.63 5,927,798.89 1,601,930.39 13.17 2.23 9/222014 2:59:07PM Page 4 COMPASS 5000.1 Build 61 • 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Fasting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (ustt) (ustt) (usft) (usft) 2,706.00 63.37 77.92 2,365.90 2,209.30 3.83 6.40 5,927,799.98 1,601,935.64 13.25 2.24 Start 30.00 hold at 2706.00 MD 2,707.20 63.37 77.92 2,366.44 2,209.84 0.00 0.00 5,927,800.20 1,601,936.68 5.79 1.41 10314"x 13-112' 2,736.00 63.37 77.92 2,379.35 2,222.75 0.00 0.00 5,927,805.46 1,601,961.89 5.79 1.41 Start DLS 4.00 TFO-21.91 2,800.00 65.75 76.87 2,406.84 2,250.24 4.00 -21.91 5,927,817.78 1,602,018.34 6.20 1.42 2,900.00 69.48 75.31 2,444.92 2,288.32 4.00 -21.46 5,927,839.55 1,602,108.18 7.09 1.49 3,000.00 73.22 73.82 2,476.89 2,320.29 4.00 -20.86 5,927,864.29 1,602,199.61 8.20 1.63 3,023.51 74.11 73.48 2,483.51 2,326.91 4.00 -20.39 5,927,870.52 1,602,221.29 848 1.67 Start 9148.50 hold at 3023.51 MD 3,100.00 74.11 73.48 2,504.46 2,347.86 0.00 0.00 5,927,891.07 1,602,291.92 945 1.83 3,126.09 74.11 73.48 2,511.60 2,355.00 0.00 0.00 5,927,898.07 1,602,316.01 10.79 2.07 C-80 3,200.00 74.11 73.48 2,531.84 2,375.24 0.00 0.00 5,927,917.93 1,602,384.26 10.79 2.07 3,300.00 74.11 73.48 2,559.23 2,402.63 0.00 0.00 5,927,944.78 1,602,476.60 12.19 2.34 3,345.17 74.11 73.48 2,571.60 2,415.00 0.00 0.00 5,927,956.91 1,602,518.31 13.63 2.63 Camp SST 3,400.00 74.11 73.48 2,586.62 2,430.02 0.00 0.00 5,927,971.64 1,602,568.94 13.63 2.63 3,500.00 74.11 73.48 2,614.01 2,457.41 0.00 0.00 5,927,998.50 1,602,661.28 15.10 2.93 3,600.00 74.11 73.48 2,641.39 2,484.79 0.00 0.00 5,928,025.36 1,602,753.62 16.59 3.23 3,700.00 74.11 73.48 2,668.78 2,512.18 0.00 0.00 5,928,052.22 1,602,845.96 18.10 3.55 3,800.00 74.11 73.48 2,696.17 2,539.57 0.00 0.00 5,928,079.07 1,602,938.30 19.62 3.86 3,900.00 74.11 73.48 2,723.56 2,566.96 0.00 0.00 5,928,105.93 1,603,030.64 9.99 2.40 4,000.00 74.11 73.48 2,750.94 2,594.34 0.00 0.00 5,928,132.79 1,603,122.98 10.48 2.54 4,100.00 74.11 73.48 2,778.33 2,621.73 0.00 0.00 5,928,159.65 1,603,215.33 10.98 2.69 4,200.00 74.11 73.48 2,805.72 2,649.12 0.00 0.00 5,928,186.51 1,603,307.67 11.49 2.83 4,300.00 74.11 73.48 2,833.10 2,676.50 0.00 0.00 5,928,213.37 1,603,400.01 12.00 2.98 9222014 2:59:07PM Page 5 COMPASS 5000.1 Build 61 S • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit ND Reference: Plan:117.1+39.5(a3 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 Q 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (') (°l (usft) (usft) )1100usft) (°) (usft) (usft) (usft) (usft) 4400.00 74.11 73.48 2,860.49 2,703.89 0.00 0.00 5,928,240.22 1,603,492.35 12.53 3.14 4,500.00 74.11 73.48 2,887.88 2,731.28 0.00 0.00 5,928,267.08 1,603,584.69 13.05 3.29 4,600.00 74.11 73.48 2,915.27 2,758.67 0.00 0.00 5,928,293.94 1,603,677.03 13.58 3.44 4,700.00 74.11 73.48 2,942.65 2,786.05 0.00 0.00 5,928,320.80 1,603,769.37 14.12 3.60 4,800.00 74.11 73.48 2,970.04 2,813.44 0.00 0.00 5,928,347.66 1,603,861.71 14.66 3,76 4,900.00 74.11 73.48 2,997.43 2,840.83 0.00 0.00 5,928,374.51 1,603,954.05 15.20 3.92 5,000.00 74.11 73.48 3,024.82 2,868.22 0.00 0.00 5,928,401.37 1,604,046.39 15.74 4.08 5,100.00 74.11 73.48 3,052.20 2,895.60 0.00 0.00 5,928,428.23 1,604,138.73 16.29 4.24 5,200.00 - 74.11 73.48 3,079.59 2,922.99 0.00 0.00 5,928,455.09 1,604,231.07 16.84 4.40 5,300.00 74.11 73.48 3,106.98 2,950.38 0.00 0.00 5,928,481.95 1,604,323.41 17.39 4.56 5,400.00 74.11 73.48 3,134.37 2,977.77 0.00 0.00 5,928,508.81 1,604,415.75 17.94 4.72 5,500.00 74.11 73.48 3,161.75 3,005.15 0.00 0.00 5,928,535.66 1,604,508.09 18.50 4.88 5,600.00 74.11 73.48 3,189.14 3,032.54 0.00 0.00 5,928,562.52 1,604,600.43 19.06 5.05 5,700.00 74.11 73.48 3,216.53 3,059.93 0.00 0.00 5,928,589.38 1,604,692.77 19.62 5.21 5,800.00 74.11 73.48 3,243.92 3,087.32 0.00 0.00 5,928,616.24 1,604,785.11 20.18 5.38 5,900.00 74.11 73.48 3,271.30 3,114.70 0.00 0.00 5,928,643.10 1,604,877.45 20.74 5.54 6,000.00 74.11 73.48 3,298.69 3,142.09 0.00 0.00 5,928,669.95 1,604,969.79 21.30 5.70 8,100.00 74.11 73.48 3,326.08 3,169.48 0.00 0.00 5,928,696.81 1,605,062.13 21.87 5.87 6,200.00 74.11 73.48 3,353.47 3,196.87 0.00 0.00 5,928,723.67 1,605,154.47 22.43 6.03 6,300.00 74.11 73.48 3,380.85 3,224.25 0.00 0.00 5,928,750.53 1,605,246.81 23.00 6.20 6,400.00 74.11 73.48 3,408.24 3,251.64 0.00 0.00 5,928,777.39 1,605,339.15 23.56 6.38 6,500.00 74.11 73.48 3,435.63 3,279.03 0.00 0.00 5,928,804.25 1,605,431.49 24.13 6.53 6,600.00 74.11 73.48 3,463.02 3,306.42 0.00 0.00 5,928,831.10 1,605,523.83 24.70 6.70 6,700.00 74.11 73.48 3,490.40 3,333.80 0.00 0.00 5,928,857.96 1,605,616.18 25.27 6.86 6,800.00 74.11 73.48 3,517.79 3,361.19 0.00 0.00 5,928,884.82 1,605,708.52 25.84 7.03 6,900.00 74.11 73.48 3,545.18 3,388.58 0.00 0.00 5,928,911.68 1,605,800.86 26.41 7.19 7,000.00 74.11 73.48 3,572.57 3,415.97 0.00 0.00 5,928,938.54 1,605,893.20 26.98 7.36 9/222014 2:59:07PM Page 6 COMPASS 5000.1 Build 61 0 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Fasting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°1100usft) (°) (usft) (usft) (usft) (usft) 7,100.00 74.11 73.48 3,599.95 3,443.35 0.00 0.00 5,928,965.39 1,605,985.54 27.55 7.53 7,200.00 74.11 73.48 3,627.34 3,470.74 0.00 0.00 5,928,992.25 1,606,077.88 28.12 7.69 7,300.00 74.11 73.48 3,654.73 3,498.13 0.00 0.00 5,929,019.11 1,606,170.22 28.69 7.86 7,400.00 74.11 73.48 3,682.12 3,525.52 0.00 0.00 5,929,045.97 1,606,262.56 29.26 8.03 7,500.00 74.11 73.48 3,709.50 3,552.90 0.00 0.00 5,929,072.83 1,606,354.90 29.84 8.20 7,600.00 74.11 73.48 3,736.89 3,580.29 0.00 0.00 5,929,09969 1,606,447.24 3041 8.36 7,700.00 74.11 73.48 3,764.28 3,607.68 0.00 0.00 5,929,126.54 1,606,539.58 30.98 8.53 7,775.43 74.11 73.48 3,784.94 3,628.34 0.00 0.00 5,929,146.80 1,606,609.23 31.56 8.70 C-50 7,800.00 74.11 73.48 3,791.67 3,635.07 0.00 0.00 5,929,153.40 1,606,631.92 31.56 8.70 7,900.00 74.11 73.48 3,819.05 3,662.45 0.00 0.00 5,929,180.26 1,606,724.26 32.13 8.87 8,000.00 74.11 73.48 3,846.44 3,689.84 0.00 0.00 5,929,207.12 1,606,816.60 32.71 9.03 8,100.00 74.11 73.48 3,873.83 3,717.23 0.00 0.00 5,929,233.98 1,606,908.94 33.28 9.20 8,200.00 74.11 73.48 3,901.22 3,744.62 0.00 0.00 5,929,260.83 1,607,001.28 33.86 9.37 8,300.00 74.11 73.48 3,928.60 3,772.00 0.00 0.00 5,929,287.69 1,607,093.62 34.43 9.54 8,400.00 74.11 73.48 3,955.99 3,799.39 0.00 0.00 5,929,314.55 1,607,185.96 35.01 9.70 8,500.00 74.11 73.48 3,983.38 3,826.78 0.00 0.00 5,929,341.41 1,607,278.30 35.59 9.87 8,600.00 74.11 73.48 4,010.77 3,854.17 0.00 0.00 5,929,368.27 1,607,370.64 36.16 10.04 8,700.00 74.11 73.48 4,038.15 3,881.55 0.00 0.00 5,929,395.13 1,607,462.98 36.74 10.21 8,80000 74.11 73.48 4,065.54 3,908.94 0.00 0.00 5,929,421.98 1,607,555.32 37.31 10.38 8,900.00 74.11 73.48 4,092.93 3,936.33 0.00 0.00 5,929,448.84 1,607,647.66 37.89 10.54 9,000.00 74.11 73.48 4,120.32 3,963.72 0.00 0.00 5,929,475.70 1,607,740.00 38.47 10.71 9,100.00 74.11 73.48 4,147.70 3,991.10 0.00 0.00 5,929,502.56 1,607,832.34 39.05 10.88 9,200.00 74.11 73.48 4,175.09 4,018.49 0.00 0.00 5,929,529.42 1,607,924.69 39.62 11.05 9,222.36 74.11 73.48 4,181.21 4,024.61 0.00 0.00 5,929,535.42 1,607,945.33 40.20 11.22 C-40 9,300.00 74.11 73.48 4,202.48 4,045.88 0.00 0.00 5,929,556.27 1,608,017.03 40.20 11.22 9222014 2:59:07PM Page 7 COMPASS 5000.1 Build 61 0 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 I 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5©156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Fasting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°I100usft) (°) (usft) (usft) (usft) (ustt) , 9,400.00 74.11 73.48 4,229.87 4,073.27 0.00 0.00 5,929,583.13 1,608,109.37 40.78 11.38 9,500.00 74.11 73.48 4,257.25 4,100.65 0.00 0.00 5,929,609.99 1,608,201.71 41.36 11.55 9,600.00 74.11 73.48 4,284.64 4,128.04 0.00 0.00 5,929,636.85 1,608,294.05 41.93 11.72 9,700.00 74.11 73.48 4,312.03 4,155.43 0.00 0.00 5,929,663.71 1,608,386.39 42.51 11.89 9,800.00 74.11 73.48 4,339.42 4,182.82 0.00 0.00 5,929,690.57 1,608,478.73 43.09 12.06 9,900.00 74.11 73.48 4,366.80 4,210.20 0.00 0.00 5,929,717.42 1,608,571.07 43.67 12.23 10,000.00 74.11 73.48 4,394.19 4,237.59 0.00 0.00 5,929,744.28 1,608,663.41 44.25 12.39 10,100.00 74.11 73.48 4,421.58 4,264.98 0.00 0.00 5,929,771.14 1,608,755.75 44.83 12.56 10,200.00 74.11 73.48 4,448.97 4,292.37 0.00 0.00 5,929,796.00 1,608,848.09 45.41 12.73 10,212.34 74.11 73.48 4,452.34 4,295.74 0.00 0.00 5,929,801.31 1,608,859.48 45.98 12.90 C-37 10,300.00 74.11 73.48 4,476.35 4,319.75 0.00 0.00 5,929,824.86 1,608,940.43 45.98 12.90 10,400.00 74.11 73.48 4,503.74 4,347.14 0.00 0.00 5,929,851.71 1,609,032.77 46.56 13.07 10,500.00 74.11 73.48 4,531.13 4,374.53 0.00 0.00 5,929,878.57 1,609,125.11 47.14 13.24 10,593.01 74.11 73.48 4,556.60 4,400.00 0.00 0.00 5,929,903.55 1,609,210.99 47.72 13.41 Iceberg 10,600.00 74.11 73.48 4,558.51 4,401.91 0.00 0.00 5,929,905.43 1,609,217.45 47.72 13.41 10,700.00 74.11 73.48 4,585.90 4,429.30 0.00 0.00 5,929,932.29 1,609,309.79 48.30 13.57 10,800.00 74.11 73.48 4,613.29 4,45669 0.00 0.00 5,929,959.15 1,609,402.13 48.88 13.74 10,900.00 74.11 73.48 4,640.68 4,484.08 0.00 0.00 5,929,986.01 1,609,494.47 49.46 13.91 11,000.00 74.11 73.48 4,668.06 4,511.46 0.00 0.00 5,930,012.86 1609,586.81 50.04 14.08 11,100.00 74.11 73.48 4,695.45 4,538.85 0.00 0.00 5,930,039.72 1,609,679.15 50.62 14.25 11,199.13 74.11 73.48 4,722.60 4,566.00 0.00 0.00 5,930,066.35 1,609,770.69 51.20 14.42 Fault 11,200.00 74.11 73.48 4,722.84 4,566.24 0.00 0.00 5,930,066.58 1,609,771.49 51.20 14.42 11,300.00 74.11 73.48 4,750.23 4,593.63 0.00 0.00 5,930,093.44 1,609,863.83 51.78 14.59 11,400.00 74.11 73.48 4,777.61 4,621.01 0.00 0.00 5,930,120.30 1,609,956.17 52.36 14.76 11,500.00 74.11 73.48 4,805.00 4,648.40 0.00 0.00 5,930,147.15 1,610,048.51 52.94 14.92 9/22/2014 2:59:07PM Page 8 COMPASS 50004 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5(§156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5(d 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PBlwp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) (°) (°) (usft) (usft) (°ll Oousft) (°) (usft) (usft) (usft) (usft) 11,600.00 74.11 73.48 4,832.39 4,675.79 0.00 0.00 5,930,174.01 1,610,140.85 53.52 15.09 11,700.00 74.11 73.48 4,859.78 4,703.18 0.00 0.00 5,930,200.87 1,610,233.19 54.10 15.26 11,800.00 74.11 73.48 4,887.16 4,730.56 0.00 0.00 5,930,227.73 1,610,325.54 54.68 15.43 11,900.00 74.11 73.48 4,914.55 4,757.95 0.00 0.00 5,930,254.59 1,610,417.88 55.26 15.60 12,000.00 74.11 73.48 4,941.94 4,785.34 0.00 0.00 5,930,281.45 1,610,510.22 55.84 15.77 12,100.00 74.11 73.48 4,969.33 4,812.73 0.00 0.00 5,930,308.30 1,610,602.56 56.42 15.94 12,172.01 74.11 73.48 4,989.05 4,832.45 0.00 0.00 5,930,327.65 1,610,669.05 56.84 16.06 Start DLS 3.50 TFO 92.02 12,200.00 74.07 74.50 4,996.72 4,840.12 3.50 92.02 5,930,334.93 1,610,694.96 56.98 16.11 12,300.00 74.00 78.14 5,024.24 4,867.64 3.50 91.75 5,930,357.17 1,610,788.47 57.29 16.27 12,400.00 73.98 81.78 5,051.83 4,895.23 3.50 90.74 5,930,373.43 1,610,883.17 57.37 16.44 12,417.30 73.99 82.41 5,056.60 4,900.00 3.50 89.74 5,930,375.63 1,610,899.66 57.23 16.61 T7 12,500.00 74.03 85.42 5,079.39 4,922.79 3.50 89.57 5,930,383.64 1,610,978.73 57.23 16.61 12,600.00 74.14 89.06 5,106.82 4,950.22 3.50 88.74 5,930,387.78 1,611,074.78 56.87 16.78 12,700.00 74.30 92.69 5,134.03 4,977.43 3.50 87.74 5,930,385.79 1,611,170.96 56.29 16.94 12,794.86 74.52 96.13 5,159.52 5,002.92 3.50 86.75 5,930,378.28 1,611,262.00 55.49 17.11 T4.1 12,800.00 74.53 96.32 5,160.89 5,004.29 3.50 85.82 5,930,377.72 1,611,266.92 55.49 17.11 12,900.00 74.82 99.94 5,187.33 5,030.73 3.50 85.78 5,930,363.59 1,611,362.30 54.48 17.28 13,000.00 75.16 103.54 5,213.23 5,056.63 3.50 84.82 5,930,343.44 1,611,456.73 53.26 17.45 13,100.00 75.57 107.14 5,238.51 5,081.91 3.50 83.89 5,930,317.37 1,611,549.88 51.84 17.61 13,200.00 76.02 110.72 5,263.06 5,106.46 3.50 82.98 5,930,285.45 1,611,641.39 50.22 17.78 13,266.25 76.35 113.08 5,278.88 5,122.28 3.50 82.10 5,930,261.15 1,611,700.94 49.05 17.90 7-518"X 9-718" 13,266.26 76.35 113.08 5,278.88 5,122.28 3.50 81.53 5,930,261.15 1,611,700.95 49.05 17.90 Start 30.00 hold at 13266.26 MD 9222014 2:59:07PM Page 9 COMPASS 50001 Build 61 • 0 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (usft) p) (°) (usft) (usft) (°1100usft) p) (usft) (usft) (usft) (usft) 13,296.26 76.35 113.08 5,285.96 5,129.36 0.00 0.00 5,930,249.58 1,611,727.71 49.21 17.91 Start DLS 4.00 TFO 180.00 13,300.00 76.20 113.08 5,286.85 5,130.25 4.00 -180.00 5,930,248.14 1,611,731.04 49.24 17.91 13,400.00 72.20 113.08 5,314.07 5,157.47 4.00 -180.00 5,930,209.97 1,611,819.34 49.91 17.92 13,500.00 68.20 113.08 5,347.94 5,191.34 4.00 -180.00 5,930,172.65 1,611,905.68 50.61 17.93 13,600.00 64.20 113.08 5,388.28 5,231.68 4.00 -180.00 5,930,136.35 1,611,989.64 51.33 17.95 13,612.11 63.72 113.08 5,393.60 5,237.00 4.00 -180.00 5,930,132.03 1,611,999.63 52.07 17.97 Top Bermuda 13,700.00 60.20 113.08 5,434.91 5,278.31 4.00 -180.00 5,930,101.26 1,612,070.81 52.07 17.97 13,720.45 59.38 113.08 5,445.20 5,288.60 4.00 -180.00 5,930,094.25 1,612,087.03 52.81 17.99 Top Berm Seis 13,800.00 56.20 113.08 5,487.60 5,331.00 4.00 -180.00 5,930,067.55 1,612,148.80 52.81 17.99 13,821.34 55.35 113.08 5,499.60 5,343.00 4.00 -180.00 5,930,060.55 1,612,164.99 53.54 18.02 Base Bermuda 13,859.31 53.83 113.08 5,521.60 5,365.00 4.00 -180.00 5,930,048.27 1,612,193.39 53.54 18.02 C-35 13,900.00 52.20 113.08 5,546.08 5,389.48 4.00 -180.00 5,930,035.37 1,612,223.22 53.54 18.02 14,000.00 48.20 113.08 5,610.08 5,453.48 4.00 -180.00 5,930,004.90 1,612,293.72 54.26 18.05 14,065.73 45.57 113.08 5,855.00 5,498.40 4.00 -180.00 5,929,985.86 1,612,337.76 50.62 17.97 TD at 14065.73-4-1/2"x 6-112" 9/22/2014 2:59:07PM Page 10 COMPASS 50061 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Fasting -Shape (°) (°) (usft) (usft) (usft) or (usft) (usft) Latitude Longitude 2L-308 Heel 102213 EB 0.00 0.00 5,478.73 1,742.65 11,631.33 5,929,116.00 1,612,707.00 70°13'4.086 N 150°13'24.716 W -plan misses target center by 961.38usft at 14065.73usft MD(5655.00 TVD,2610.66 N,11257.52 E) -Point 2L-308 wp04 Int Csg 0.00 0.00 5,278.88 2,882.65 10,619.22 5,930,261.15 1,611,700.95 70°13'15.313 N 150°13'54.059 W -plan hits target center -Point 2L-308 Toe 102213 EB 0.00 0.00 5,465.73 -223.70 12,374.66 5,927,146.00 1,613,440.00 70°12'44.735 N 150°13'3.225 W -plan misses target center by 3052.44usft at 14065.73usft MD(5655.00 TVD,2610.66 N,11257.52 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (unit) Name pr ,.. () ("1 2,707.20 2,366.44 10-3/4"x13-1/2" 10-3/4 13-1/2 13,266.25 5,278.88 7-5/8"X 9-7/8" 7-5/8 9-7/8 14,065.73 5,655.00 4-1/2"x6-1/2" 4-1/2 6-1/2 9222014 2:59:07PM Page 11 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit TVD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 @ 156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Formations Measured Vertical Dip Depth Depth Dip Direction (usft) ,: (usft) Name Lithology (°) (°) 9,222.36,., 4,181.21 C-40 0.00 13,859.31 5,521.60 C-35 0.00 3,345.17 2,571.60 Camp_SST 0.00 10,212.34 4,452.34 C-37 0.00 13,612.11 5,393.60 Top Bermuda 0.00 7,775.43 3,784.94 C-50 0.00 12,417.30 5,056.60 T7 0.00 2,481.32 2,250.60 C-90 0.00 13,821.34 5,499.60 Base Bermuda 0.00 3,126:09 2,511.60 C-80 0.00 12,794.86 5,159.52 T4.1 0.00 11,199.13 4,722.60 Fault 0.00 13,720.45 5,445.20 Top Berm Seis 0.00 10,593.01 4,556.60 Iceberg 0.00 1,477.60 1,451.60 PFrost 0.00 9/222014 2:59:07PM Page 12 COMPASS 5000.1 Build 61 • • Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2L-308(Bertha) Project: Kuparuk River Unit ND Reference: Plan:117.1+39.51 156.60usft(Doyon 25) Site: Kuparuk 2L Pad MD Reference: Plan:117.1+39.5 CO156.60usft(Doyon 25) Well: Plan:2L-308(Bertha) North Reference: True Wellbore: Plan:2L-308PB1 Survey Calculation Method: Minimum Curvature Design: 2L-308PB1wp05 Database: EDM Alaska Prod Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (usft) (usft) (usft) (usft) Comment 2-= ',.§9° �i ,� ' °` � '".. ;' '':v < "r ` r�� ,��,-,ew„� �,. fuer-;;? _, ,vx �.�.,x. .. -2,e.-,w e�„_e 315.00 315.00 0.00 0.00 KOP:DLS 1.5 TFO$10 550.15 550.00 7.13 1.26 Start DLS 2.50 TFO 15.00 903.84 900.00 53.11 16.52 Start DLS 2.50 TFO 60.00 1,099.97 1,090.52 93.32 39.55 Start DLS 2.60 TFO 80.00 1,420.00 1,397.02 149.94 110.90 Start 100.00 hold at 1420.00 MD 1,520.00 1,491.78 164.16 139.49 Star(DLS 3.83 TFO 18.13 2,706.00 2,365.90 370.38 865.92 Start 30.00 hold at 2706.00 MD 2,736.00 2,379.35 375.99 892.14 Start DLS 4.00 TFO-21.91 3,023.51 2,483.51 442.41 1,151.22 Start 9148.50 hold at 3023.51 MD 12,172.01 4,989.05 2,943.78 9,586.90 Start DLS 3.50 TFO 92.02 13,266.26 5,278.88 2,882.65 10,619.22 Start 30.00 hold at 13266.26 MD 13,296.26 5,285.96 2,871.22 10,646.04 Star(DLS 4.00 TFO 180.00 14,065.73 5,655.00 2,610.66 11,257.53 TD at 14065.73 Checked By: Approved By: Date: 9122/201S 2 59 07572 Page 13 COMPASS 5000.1 Build 61 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-308 (Bertha) Plan: 2L-308PB1 2L-308PB1 wp05 Clearance Summary Anticollision Report 22 September,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1wp05 Well Coordinates: 5,927,434.16 N,1,601,067.89 E(70°12'47.03"N,150°19'02.47"W) Datum Height: Plan:117.1+39.5 156.60usft(Doyon 25) Scan Range: 0.00 to 14,065.73 usft.Measured Depth. Scan Radius is 1,602.62 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 61 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 2004-100/1000 of reference Scan Type: 25.00 ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-308(Bertha) -2L-308PB1wpO5 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1wp05 Scan Range: 0.00 to 14,065.73 usft.Measured Depth. Scan Radius is 1,602.62 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) )usft) (usft) (usft) usft Kuparuk 2L Pad 2L-03-2L-03-2L-03 112.00 74.97 112.00 72.97 100.00 37.517 Centre Distance Pass-Major Risk 2L-03-2L-03-2L-03 311.99 75.89 311.99 70.59 300.00 14.305 Clearance Factor Pass-Major Risk 2L-301-2L-301-2L-301 313.53 103.62 313.53 97.42 300.00 16.728 Centre Distance Pass-Major Risk 2L-301-2L-301-2L-301 488.77 104.72 488.77 95.06 475.00 10.839 Clearance Factor Pass-Major Risk 2L-304-2L-304-2L-304 41.70 60.12 41.70 59.08 27.28 57.974 Centre Distance Pass-Major Risk 2L-304-2L-304-2L-304 264.42 60.71 264.42 56.15 250.00 13.305 Clearance Factor Pass-Major Risk 2L-305-2L-305-2L-305 662.33 43.94 662.33 33.31 650.00 4.132 Centre Distance Pass-Major Risk 2L-305-2L-305-2L-305 1,319.97 45.15 1,319.97 21.39 1,300.00 1.901 Clearance Factor Pass-Major Risk 2L-306(Stella)-2L-306-2L-306 251.45 29.18 251.45 24.72 250.00 6.543 Centre Distance Pass-Major Risk 2L-306(Stella)-2L-306-2L-306 276.45 29.24 276.45 24.37 275.00 6.004 Clearance Factor Pass-Major Risk 2L-306(Stella)-2L-306PB1-2L-306PB1 251.45 29.18 251.45 24.72 250.00 6.543 Centre Distance Pass-Major Risk 2L-306(Stella)-2L-306PB1-2L-306PB1 276.45 29.24 276.45 24.37 275.00 6.004 Clearance Factor Pass-Major Risk 2L-307-2L-307-2L-307 156.60 15.17 156.60 12.67 152.05 6.055 Centre Distance Pass-Major Risk 2L-307-2L-307-2L-307 279.54 15.92 279.54 11.44 275.00 3.554 Clearance Factor Pass-Major Risk 2L-307-2L-307L1-2L-307L1 156.60 15.17 156.60 12.67 152.05 6.055 Centre Distance Pass-Major Risk 2L-307-2L-307L1-2L-307L1 279.54 15.92 279.54 11.44 275.00 3.554 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-2L-307L2 156.60 15.17 156.60 12.67 152.05 6.055 Centre Distance Pass-Major Risk 2L-307-2L-307L2-2L-307L2 279.54 15.92 279.54 11.44 275.00 3.554 Clearance Factor Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 156.60 15.17 156.60 12.67 152.05 6.055 Centre Distance Pass-Major Risk 2L-307-2L-307L2-01-2L-307L2-01 279.54 15.92 279.54 11.44 275.00 3.554 Clearance Factor Pass-Major Risk 2L-309-2L-309-2L-309 406.98 12.82 406.98 5.01 400.00 1.641 Centre Distance Pass-Major Risk 2L-309-2L-309-2L-309 456.74 13.27 456.74 4.51 450.00 1.514 Clearance Factor Pass-Major Risk 2L-309-2L-309PB1-2L-309P91 406.98 12.82 406.98 4.96 400.00 1.631 Centre Distance Pass-Major Risk 2L-309-2L-309PB1-2L-309PB1 456.74 13.27 456.74 4.46 450.00 1.506 Clearance Factor Pass-Major Risk 2L-310-2L-310-2L-310 588.03 18.70 588.03 8.72 575.00 1.873 Clearance Factor Pass-Major Risk 2L-311-2L-311-2L-311 561.14 39.79 561.14 30.56 550.00 4.311 Centre Distance Pass-Major Risk 2L-311-2L-311-2L-311 585.57 40.10 585.57 30.46 575.00 4.160 Clearance Factor Pass-Major Risk 2L-312(Cassidy)-2L-312-2L-312 917.17 49.68 917.17 31.95 925.00 2.801 Centre Distance Pass-Major Risk 22 September,2014- 15:01 Page 2 of 7 COMPASS 0 0 ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-308(Bertha)-2L-3O8PB1wpO5 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 2L Pad-Plan:2L-308(Bertha)-Plan:2L-308PB1-2L308PB1wp05 Scan Range:0.00 to 14,065.73 usft.Measured Depth. Scan Radius is 1,602.62 usft.Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2L-312(Cassidy)-2L-312-2L-312 941.55 49.92 941.55 31.70 950.00 2.741 Clearance Factor Pass-Major Risk 2L-313-2L-313-2L-313 156.60 74.80 156.60 72.43 146.05 31.484 Centre Distance Pass-Major Risk 2L-313-2L-313-2L-313 484.11 76.17 484.11 68.50 475.00 9.927 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 877.62 89.84 877.62 74.90 875.00 6.013 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314-2L-314 925.96 90.31 925.96 74.51 925.00 5.717 Clearance Factor Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 877.62 89.84 877.62 74.90 875.00 6.013 Centre Distance Pass-Major Risk 2L-314(Tarawa)-2L-314PB1-2L-314PB1 925.96 90.31 925.96 74.51 925.00 5.717 Clearance Factor Pass-Major Risk 2L-315-2L-315-2L-315 156.60 105.06 156.60 102.68 146.10 44.219 Centre Distance Pass-Major Risk 2L-315-2L-315-2L-315 310.49 106.62 310.49 101.73 300.00 21.805 Clearance Factor Pass-Major Risk 2L-317-2L-317-2L-317 642.60 118.82 642.60 107.61 650.00 10.600 Centre Distance Pass-Major Risk 2L-317-2L-317-2L-317 665.91 118.94 665.91 107.23 675.00 10.161 Clearance Factor Pass-Major Risk 2L-317-2L-317A-2L-317A 642.60 118.82 642.60 107.61 650.00 10.600 Centre Distance Pass-Major Risk 2L-317-2L-317A-2L-317A 665.91 118.94 665.91 107.23 675.00 10.161 Clearance Factor Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 509.47 149.20 509.47 140.63 500.00 17.410 Centre Distance Pass-Major Risk 2L-318(Libra)-2L-318-2L-318 605.38 149.79 605.38 139.58 600.00 14.670 Clearance Factor Pass-Major Risk 2L-319-2L-319-2L-319 1,233.27 108.68 1,233.27 86.31 1,275.00 4.857 Centre Distance Pass-Major Risk 2L-319-2L-319-2L-319 1,256.61 109.00 1,256.61 86.08 1,300.00 4.756 Clearance Factor Pass-Major Risk 2L-320-2L-320-2L-320 569.58 172.80 569.58 161.65 575.00 15.508 Centre Distance Pass-Major Risk 2L-320-2L-320-2L-320 640.33 173.60 640.33 161.04 650.00 13.820 Clearance Factor Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 569.58 172.80 569.58 161.65 575.00 15.508 Centre Distance Pass-Major Risk 2L-320-2L-320PB1-2L-320PB1 640.33 173.60 640.33 161.04 650.00 13.820 Clearance Factor Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 569.58 172.80 569.58 161.65 575.00 15.508 Centre Distance Pass-Major Risk 2L-320-2L-320PB2-2L-320PB2 640.33 173.60 640.33 161.04 650.00 13.820 Clearance Factor Pass-Major Risk 2L-321-2L-321-2L-321 359.58 194.00 359.58 188.35 350.00 34.306 Centre Distance Pass-Major Risk 2L-321-2L-321-2L-321 481.93 194.97 481.93 187.29 475.00 25.377 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322-2L-322 326.52 209.26 326.52 202.93 325.00 33.041 Centre Distance Pass-Major Risk 2L-322(North)-2L-322-2L-322 448.45 210.58 448.45 201.83 450.00 24.078 Clearance Factor Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 337.34 209.27 337.34 202.72 325.00 31.965 Centre Distance Pass-Major Risk 2L-322(North)-2L-322A-2L-322A 434.89 210.30 434.89 201.82 425.00 24.809 Clearance Factor Pass-Major Risk 2L-323-2L-323-2L-323 359.47 224.54 359.47 218.72 350.00 38.559 Centre Distance Pass-Major Risk 22 September,2014- 15:01 Page 3 of 7 COMPASS 0 1110 ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-308(Bertha) -2L-308PB1wp05 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2L Pad-Plan:2L-308(Bertha)-Plan:2L-308PB1-2L-308PB1wp05 Scan Range:0.00 to 14,065.73 usft.Measured Depth. Scan Radius is 1,602.62 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name-Wellbore Name-Design (usft) (usft) (usft) (usft) usft 2L-323-2L-323-2L-323 481.56 225.71 481.56 217.87 475.00 28.792 Clearance Factor Pass-Major Risk 2L-325-2L-325-2L-325 156.60 254.96 156.60 252.46 146.20 101.736 Centre Distance Pass-Major Risk 2L-325-2L-325-2L-325 235.39 255.68 235.39 251.96 225.00 68.768 Clearance Factor Pass-Major Risk Plan:2L-308(Bertha)-Plan:2L-308-2L-308 wp05 ® ® ® ® ® - Plan:2L-316-Plan:2L-316-2L-316wp04 311.50 120.07 311.50 114.55 300.00 21.771 Centre Distance Pass-Major Risk Plan:2L-316-Plan:2L-316-2L-316wp04 558.30 122.00 558.30 112.16 550.00 12.394 Clearance Factor Pass-Major Risk Plan:2L-316-Plan:2L-316PB1-2L-316PB1wp03 311.50 120.07 311.50 114.55 300.00 21.771 Centre Distance Pass-Major Risk Plan:2L-316-Plan:2L-316PB1-2L-316PB1wp03 558.30 122.00 558.30 112.16 550.00 12.394 Clearance Factor Pass-Major Risk Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 299.50 89.99 299.50 84.74 300.00 17.133 Centre Distance Pass-Major Risk Prelim:2L-302(Langley)-2L-302-2L-302(wp01) 375.04 90.57 375.04 84.09 375.00 13.974 Clearance Factor Pass-Major Risk Prelim:2L-302(Langley)-2L-302L1-2L-302L1(wp01 299.50 89.99 299.50 84.74 300.00 17.133 Centre Distance Pass-Major Risk Prelim:2L-302(Langley)-2L-302L1-2L-302L1(wp01 375.04 90.57 375.04 84.09 375.00 13.974 Clearance Factor Pass-Major Risk Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.50 1,300.00 2L-308PB1wp05 GYD-GC-SS 1,300.00 2,706.00 2L-308PB1wp05 MWD 1,300.00 2,706.00 2L-308PB1wp05 MWD+IFR-AK-CAZ-SC 2,706.00 3,800.00 2L-308PB1wp05 MWD 2,706.00 13,266.26 2L-308PB1wp05 MWD+IFR-AK-CAZ-SC 13,266.26 14,065.73 2L-308PB1wp05 MWD 13,266.26 14,065.73 2L-308PB1wp05 MWD+IFR-AK-CAZ-SC 22 September,2014- 15:01 Page 4 of 7 COMPASS • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-308 (Bertha)-2L-308PB1wp05 Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 22 September,2014- 15:01 Page 5 of 7 COMPASS • ! ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-308(Bertha)-2L-308PB1wp05 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan 117.1+39.5 @ 156.60usft(Doyon 25). Northing and Fasting are relative to Plan:2L-308(Bertha). Coordinate System is US State Plane 1983,Alaska Zone 4. Central Meridian is-150.00°,Grid Convergence at Surface is:-0.30°. -ei—LLJUb(JE•lta),2LJUU,LL-6Ub VU Ladder Plot +2L-306(StIIa),2L306PB1,2L-306PB1VU -ief-2L-307,2L-307,2L-307 V2 3—2L-307,2L-307L1,2L-307L1 VO $2L-307,2L-3071.2,2L-307L2 VO ir` I. t, A '$2L-307,2L-307L2-01,2L-307L2-01 VO 1500 ° (' r� /� 2L-309,2L-309,2L-309 V5 ' � ���. r; i -tom O „if,/f �� ^t II rn lii + �; (ii, $2L309,2L-309PB1,2L-309PB1V6 7 0 & i ?-t r4 ,lL ® $2L-310,2L-310,2L-310 VO in tiet�1ri le i� i i +',,: $2L-311,2L-311,2L-311 VO G••f�`I &'P Il'4 /� ;`'_+ �� $2L-312(Cassdy),2L-312,2E-312 VO m �—2L-313,2L-313,2E-313V2 2 1000 ���,i ;, � ',�• ` u r� ; -$r 2L314(Taraae),2L-314,2E-314 VO it N+I!`t ����II ++"+ A 1L $2L-314(farama),2L-314PB1,2L-314PB1 VO " o !� i ',` !Fli J $2L-315,2L-315,2E-315V2 N :C f/�eP�li" ', ` of ' a $2L-317,2L-317,2L-317 V2 N it.�i4;/ll � ^,a� '�;<�` �, /� $2L-317,2E-317A,2L-317AV6 U 500 4lI'!,A 4si = "Sr 2L-318(Libra),2L-318,2E-318VO -E 2L-319,2L-319,2L-319 V4 N i!�': I!', VA ,: & $2L-320,2L-320,2L-320V0c ,a;g4 ' g17a 1,III w- J $2L-320,2L-320PB1,2L-320PB1 V0 f.4 $2L320,2L-320P62,2L-320P62V0 %;.t. I -N-2L-321,2L-321,2L-321 V2 - I I -0-2L-322(North),2L-322,2L-322V0 0 2500 5000 7500 10000 12500 $2L-322(North),2L-322A,2L-322AV0 Measured Depth(2500 usft/in) -$2L323,2L-323,2L-323 V2 -4-2L-325.2L-325,2L-325 V2 22 September,2014- 15:01 Page 6 of 7 COMPASS • • ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2L-308(Bertha) -2L-308PB1wp05 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor - 1, O : ii VO �1iiVI, �It9,,,a' 10,i ♦ 0 I ' -�2L306(SLIIe),2L$08PB 2L-L306PB1 VO 1 /Y) .1i -az.* /I� ..___. -__..._ -_.. 2L-307,2L-307,2E-307V210.00 '�li ii + I� 2L-307,2E-307L1,2L-307L1V0 i 8.75 II�'t l) I' �r ni/I SVA 2L307,2L307L2,2L-307L2V0 r Ili �!'l� ,7 ,_-,_ - .-_.. ' __-___- - - __-__. _-_-... $2L-307,2L-307L2-01,2L-307L201 VO 51�61 rj1,r YA . $2L-309,2L-309,2L-309 V5 �t / q I •.'1 j- -a 'I► -}2L309,2L309PB1,2L309PB1 V6 7.50 ll !' ? ..�._ - '' . ':�" .A -�2L310,2L310,2L310V0 1',�II 11�� , ..!\ I A hI -X-2L-311,2E-311,2L311 VO !� I �' �. i, $2L-312(Cassidy),2L-312,2L-312 V0 (.1 6.25 it - ' 64a•� \ /i _. .._ is 'I I! r n - A. �`� • i, -�2L313,2L313,2L-313 V2 - .'�,ri' \ TJ i �tY- -Z-2L-314(Tarawa),2L-314,2L-314V0 ' - f w i5 5.00 ,,,,/ � ------i -_ _....__ i.�, ..,,�.-- -.e�ei. �.._ -_--_- -.. -.. $2L314(Tarawa),2L314P61,2L-314PB1V0 •: Al \ I\ -1r 2L-315,2L-3162L-315 V2 a I/ I I e4 L� -}2L-317,2L-317,2L-317 V2 N 3.75 1 11 II° - /1 + - ± $2L-317,2L-317A,2L317AV6 �i�'\ �\ ; r _ 4 -r}-2L318(Libra),2L318,2L318V0 1;1 �rr/► �� /�, -)�2L-319,2L-319,2L-319 V4 2 50- :r�\ /6. 1 -- _ q� 4.\ / $2L320,2L320,2L-320V0 \ /� f - 4 2L320,2L320PB1,2L320PB1 VO - -, i k' 1 $2L-320,2L320PB2,2L320PB2V0 1.25- :_i _. -- - ♦-2L321,2L-321,2E-321 V2 2L-322(Norlh),2L322,2L-322V0 0.00 iii 1i1 ; i , 11 i1i ii ii ii ii ifi YY $2L-322(North),2L-322A,2L-322AV0 0 1250 2500 3750 5000 6250 7500 8750 10000 11250 12500 13750 15000 -0 2L323,2L-323,2L323 V2 Measued Depth(25100 fin) 2L-325,2L-325,2L-325 V2 22 September,2014- 15:01 Page 7 of 7 COMPASS • • ConocoPhillips 2 L-308 P B 1 wp05 Schlumberger Alaska am a Orb N N fil Tr, CN',1 ! (7 J - 2, 11 2, 2, J e, N N N NV N N N N / N r,; I, I.'III, I i •"'■em1111111111 1IIIIII�p ��-...2 111.11110 1111111)11P164i.•..�uu.■�rA -Ad .. . Fir r -.gm ,...I ,,u1�1,, _1111■ 111111[10 �►�II it I I� N o 11111' ��041hr..1 41111iiiiallik1511,111111116. Fir %ill pp 41411 � / i�l �- � 7��--Eguivelant Magnetic Distance i i 0 i I I I 1 I I I ( I I I I I I I I I I I I I I I I 1 1 1 0 400 800 1200 1600 2000 2400 Displayed Interval could be less than entire raptured Depth 39.50 To 14065.73 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 39.50 To 14065.73 Results Limited By: Centre Distance: 1602.62 GLOBAL FILTER APPLIED:All weilpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1300.00 2L-308PB1wp05(Plan: 2L-308PB1) GYD-GC-SS 1300.00 2706.00 2L-308PB1wp05(Plan: 2L-308PB1) MWD 1300.00 2706.00 2L-308PB1wp05(Plan: 2L-308PB1) MWD+IFR-AK-CAZ-SC 2706.00 3800.00 2L-308PB1wp05(Plan: 2L-308PB1) MWD 2706.00 13266.26 2L-308PB1wp05(Plan: 2L-308PB1) MWD+IFR-AK-CAZ-SC 13266.26 14065.73 2L-308PB1wp05(Plan:2L-308PB1) MWD 13266.26 14065.73 2L-308PB1wp05(Plan: 2L-308PB1) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2366.44 2707.20 10-3/4" x 13-1/2" 10-3/4 5278.88 13266.25 7-5/8"X 9-7/8" 7-5/8 5655.00 14065.73 4-1/2"x 6-1/2" 4-1/2 LEGEND _0- 2L-03,2L-03,2L-03 V2 -X- 2L-311,2L-311,2L-311 VO X 2L-321,2L-321,2L-321 V2 -X- 2L-301,2L-301,2L-301 VO -13- 2L-312(Cassidy),2L-312,2L-312 VO -0- 2L-322(North),2L-322,2L-322 VO -X- 2L-304,2L-304,2L-304 VO --I- 2L-313,2L-313,2L-313 V2 0 2L-322(North),2L-322A,2L-322A VO --A- 2L-305,2L-305,2L-305 V2 2L-314(Tarawa),2L-314,2L-314 VO 0 2L-323,2L-323,2L-323 V2 -A-- 2L-306(Stella),2L-306,2L-306 VO -E- 2L-314(Tarawa),2L-314PB1,2L-314PB1 VO -g- 2L-325,2L-325,2L-325 V2 2L-306(Stella),2L-306PB1,2L-306PB1 VO 2L-315,2L-315,2L-315 V2 -e-- Plan:2L-308(Bertha),Plan:2L-308,2L-308 wp05 VO -A- 2L-307,2L-307,2L-307 V2 - 2L-317,2L-317,2L-317 V2 Q Plan:2L-316,Plan:2L-316,2L-316wp04 VO 2L-307,2L-307L1,2L-307L1 VO -E- 2L-317,2L-317A,2L-317A V6 $ Plan:2L-316,Plan:2L-316PB1,2L-316PB1 wp03 VO -X- 2L-307,2L-307L2,2L-307L2 VO -A- 2L-318(Libra),2L-318,2L-318 VO -0- Prelim:2L-302(Langley),2L-302,2L-302(wp01)VO -9-- 2L-307,2L-307L2-01,2L-307L2-01 VO -X- 2L-319,2L-319,2L-319 V4 -e- Prelim:2L-302(Langley),2L-302L1,2L-302L1(wp01)VO -A- 2L-309,2L-309,2L-309 V5 $ 2L-320,2L-320,2L-320 VO -e- Plan:2S-14,Plan:2S-14,2S-14wp05[Whale]VO 2L-309,2L-309PB1,2L-309PB1 V6 -5'- 2L-320,2L-320PB1,2L-320PB1 VO $- 2L-308PB1wp05 2L-310,2L-310,2L-310 VO 0 2L-320,2L-320PB2,2L-320PB2 VO MD Inc Azi TVD +N/-S +E/-W DLeg TFace Target 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 40 315 21.-308PB1w 05 2 315.00 0.00 0.00 315.00 0.00 0.00 0.00 0.00 000 3 550.15 3.53 10.00 550.00 7.13 1.26 1.50 10.00 3.40 315 700 4 903.84 12.28 20.78 900.00 53.11 16.52 2.50 15.00 32.12 39.50 To 14065.73 51099.97 15.33 37.04 1090.52 93.32 39.55 2.50 60.00 66.45 700 1000 6 1420.00 18.62 63.55 1397.02 149.94 110.90 2.60 80.00 151.81 71520.00 18.62 63.55 1491.78 164.16 139.49 0.00 0.00 183.39 8 2706.00 63.37 77.92 2365.90 370.38 865.92 3.83 18.13 937.99 1000 1300 15:04,September 22 2014 ( 92736.00 63.37 77.92 2379.35 375.99 892.14 0.00 0.00 964.66 103023.51 74.11 73.48 2483.51 442.41 1151.22 4.00 -21.91 1231.59 1300 1700 1112172.0174.11 73.48 4989.05 2943.78 9586.90 0.00 0.0010027.36 OBAL FILTER APPLIED: A 123266.26 76.35 113.08 5278.88 2882.65 10619.22 3.50 92.0210990.27 2L-308 wp04 Int Csg 1700 2000 133296.26 76.35 113.08 5285.96 2871.22 10646.04 0.00 0.0011012.25 144065.73 45.57 113.08 5655.00 2610.66 11257.53 4.00 180.0011513.28 2000 2400 2400 - 2700 Depth From Depth To Survey/Plan Tool 3950 1300.00 2L308P01wp05(Plan:2L-308P1111)GVOGC-SS 1300.00 2706.00 21.-30814141 wp05(Plan:2130614511)MWO 2700 4000 1300.00 2706.00 21.-30814511 wp05(Plan:21-30614511)MW19415111-AK-CALSC 2706.00 3600.00 21--308PStwp05(Plan:21-30614511)MWO 2706.00 13286.26 21.-308PS1wp05(Plan:2L-306P431)MWD.IFS/AK/CA2/SC 4000 5300 13266.26 14065.73 XS o0Petwpos(Plan:2L-30811511)MWO 13266.26 14065.73 2,308P511w05(Plan:2L-308P5111MWO4I5e-11K-CALSC 5300 6700 CASING DETAILS 6700 8000 TVD MD Name Size 2366.44 2707.20 10-3/4"x 13-1/2" 10-3/4 8000 9300 5278.88 13266.25 7-5/8"X 9-7/8" 7-5/8 5655.00 14065.73 4-1/2"x 6-1/2" 4-1/2 9300 10600 10600 - 11900 0/360 11900 13266 illilow r 13266 13400 -•80//�//h�% j '�w®'s71 ��4�, 30 13400 13500 30/330 ��i nrii, :Idi t l///N74/j/i!� 1,4 � 2L-30 13500 13600 4102...07.50„,47% „,04. 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CO 2 OL N O co cu f+ N JUm x N as � T _ Tr N O N O 2 I I 1 I N E O O O O O O 1 a O O O O O N O O O O O `SD '71" CV(ui/�lsn 000 ) (+)u�aoN/(-)gJnos NI ORIGINAL ! 0 REV DATE DY CK APP DESCRIPTION REV DATE DY CK APP DESCRIPTION 1 01/28/14 JAH RKD SHOW WELLS 302-308 0 ti i- T,, ,...,=25 Q 1 30 29 28 7 4G� o 6 I e DS 2M° 34 ►o = 1 Mile r 5, c 3/ 0\ *O t F T11NR7E d a ,_ . 0� ilk T1ONR7E / p 4111 c61 ....-• - C) 0 D 41N e 3 •Ci Mil ,., .,f _ , )1 �� • v ... , ��Q t'� j 10 1? 2 7.•' .? B 9 10 c\. ri THIS ' : �P PROJECT ' MILUVEACHAt - RIVER i ------ BRIDGE `� :El / 13 13 A. 17 6 5 DS 2L C.' I. _ _____ t d �4 >� �:, d 4D 19 20 21 22 IP ' 11 q ilk c2 Ilk ° 0 10°P. d 0 0 . °O a cO 27 26 1� (g) ,6111�a0 2- . 2 i' 1111 � % o ° I. 1 _ .6 _ ') riqcyot 1.— — ' 4 ' � "t .��c,R M4ch' 36 31 ° 32 1 „----3-* 0 34 (9 e� DS 2 °k\ T1ONR7E ,03,1/ 61.„ THIS PROJECT IS LOCATEDLOUNSBURY IN HARRISON BAY A-1 & ASSOCIATES, INC. QUADRANGLE ''ri`Y�N' ENGINEERS PLANNERS AREA:2L MODULE: XXXX UNIT: D2 ConocoPhilli s DS2L WELLS 302 & 308 Alaska, Inc. PERMIT EXHIBIT CADD FILE NO. I DRAWING NO. PART: REV: LK212D59 01/09/14 -,, . NSK 6.212—d59 1 of 6 1 R 1 4,d' ! I REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 01/28/14 JAH RKD SHOW WELLS 302-308 LEGEND • EXISTING CONDUCTOR LOCATION O PROPOSED WELL W/ EXISTING CONDUCTOR ® PROPOSED WELL W/ NO CONDUCTOR Section l Corner T1ON, 1514 22 2 tA • fN N t0 y41 0 W�y0•° u W yi®OO LLm v i 0�01r, U N Ct' CII t Cd N t N QR,U' 91E2� \\\\ SCALE: 1"-200' WELLS ARE LOCATED IN PROTRACTED SECTION 22, T1ON, R7E UMIAT MERIDIAN WELL A.S.P.s GEOGRAPHIC GEOGRAPHIC SECTIOFFSETS ELEVATIONS NO. NAD 27 NAD 83 NAD 27 NAD 83 F.N.L. F.E.L 0.G. PAD ** 302 N: 5,927,705.19 N:5,927,454.41 LAT: 70' 12' 48.37" LAT: 70' 12' 47.24" 140' 529' 108.6' 116.0' E: 461,121.84 E:1S601,155.58 LONG: 150' 18' 48.77" LONG: 150' 18' 59.92" ** 308 N: 5.927,684.94 N:5,927.434.16 LAT: 70' 12' 48.17" LAT: 70' 12' 47.03" 161' 617' 108.6' 117.1' F. 461.034.15 E:1 601.067.89 LONG: 150' 18' 51.32' LONG: 150' 19' 02.47" ** PLAN CONDUCTOR LOCATION NOTES: 1) Basis of location and elevation is Drill Site 2L monumentation per Lounsbury & Associates. 2) Elevations are B.P.M.S.L.. 3) Drill Site 2—L Grid North is rotated 13' West from A.S.P. Grid North. LOUNSBURY & ASSOCIATES, INC. ,.P GVFYOHS ENGINEERS {'I.ANNE,N; AREA:2L MODULE: XXXX UNIT: D2 ConocoPhillips 302L&WELLS 08 Alaska, Inc. PERMIT EXHIBIT CADD FILE NO. DRAWING NO. PART: REV: LK6212D59 01/09/14 NSK 6.212—d59. 2 OF 6 1 IA ! • • Loepp, Victoria T (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Thursday, October 09, 2014 1:47 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2L-308(PTD 214-151) Mud Weight Attachments: 2L-308 Pad Areal Photograph.pdf Hi Victoria, I am waiting on Doyon to provide me with a diverter schematic that accompanies Rig 25. Attached is a pad areal the displays the requested infrastructure within a 100' radius of the diverter discharge. Due to a possibility that the diverter cannot be routed north (under existing cable tray)we are analyzing an alternative diverter route, as displayed in the attached PDF. The reservoir engineering department has done a good job at providing us a range of expected pore pressures,with a most likely midpoint. In the case of planned well 2L-308,we have been provided with a range of 2350—3,180 psi (8.4— 11.3 ppg) with a most likely pressure of 2,600 psi (9.3 ppg). Our plan is to weight up to 10.4 ppg prior to penetrating the Bermuda reservoir and immediately perform a 30-minute flowcheck,and also flowcheck during connections. Based on what we see,we will add or dilute weight accordingly. We will have MI place tanks on location with kill weight fluid of 11.5 ppg and have additional barite on location to cover any extra needed weight. The robust design of top-setting the reservoir at Tarn mitigates the hazard of encountering high (or low) Bermuda pressure because the shallow weak zones(Campanian/Iceberg)will be behind pipe prior to Bermuda penetration. Thanks, and I hope to send you the Doyon 25 diverter schematic soon. Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Loepp, Victoria T(DOA) [ ] Sent: Thursday, October 09, 2014 1:25 PM To: Bearden, J Daniel Subject: [EXTERNAL]RE: KRU 2L-308(PTD 214-151) Mud Weight Daniel, The reservoir pressure at the Bermuda formation is estimated at 3180 psi(11.3 ppg ). Is the planned mud weight for the production hole of 10.4 to 11.Oppg adequate? Thanx, Victoria From: Loepp, Victoria T(DOA) Sent: Wednesday, October 08, 2014 2:37 PM To: Bearden, 3 Daniel (i.Daniel.Bearden@conocophillips.com) Subject: KRU 2L-308(PTD 214-151)Aerial View of Diverter route and area • • Daniel, On diverter schematics, would like to see the diverter route on an aerial that shows all the buildings, roads and flowlines, at a minimum within about 100' of the diverter route and discharge. Thanx, Victoria Please note new name and new email address. 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.LoermAalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 ! • ConocoPhillips I ifi' 20 N fKvra` � . s v , d t '';7,---,-:,-41.-A4- FsysP l' ; . Y LI 4: 4 - _ n zR 2 vo i e + � ^N r. -2` �1 2t R°i li,r w tC X28 x Rn fMV� xt L •i, w47' r - L t-n5 - • L 'fid.; 0 • 0 \ . \a "A • ,' , � ,,,,,,,,,,,,ii,,,., ^ ". +'x ash. �� e '•A4,•,•"'",{,•;',.••:,..',"1"-.1,-.;.T 0� �+� 9 x. 444, v 4 3n. k r �\ • h 1 1 1 f °, r Bettis, Patricia K (DOA) From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Monday, September 29, 2014 7:02 AM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2L-308PH1 Attachments: 2L-308PB1wp05 - Plan Summary.pdf Hi Patricia, Please find attached the wellbore directional plan for the pilot hole. Thanks, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, September 26, 2014 4:03 PM To: Bearden, 3 Daniel Subject: [EXTERNAL]KRU 2L-308PH1 Good afternoon Daniel, Although the AOGCC does not permit a plan pilot hole, we do enter the wellbore survey into our database for reference. Please submit the wellbore survey for the proposed KRU 2L-308PH1 well. This survey information may be e-mailed to me. Thank you and have a great weekend, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • i Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, September 26, 2014 4:03 PM To: j.daniel.bearden@COP.com Subject: KRU 2L-308PH1 Good afternoon Daniel, Although the AOGCC does not permit a plan pilot hole, we do enter the wellbore survey into our database for reference. Please submit the wellbore survey for the proposed KRU 2L-308PH1 well. This survey information may be e-mailed to me. Thank you and have a great weekend, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. i ! TRANSMITTAL LETTER CHECKLIST WELL NAME: KS( L- 36O PTD: o� y )S Development Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: g.yooru.lc I�,iJL c- POOL: 1`l�p� J�� �1+�t� +1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PCR 11 Q.L— 3 O PH) and API number (50- /03- O(p 9 Li - z0 - 60 ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Logging also required for this well: Requirements sPer Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 5/2013 s • Ei r_ To0 a) n 0 OU C c '3 _0 as 3 E n0 o, 0. Q a sc CL a o L L c 12 o �' 3 0- 3 o Y. 0' o c Z• 0 co ° •0 - E. 0 c o v. -0 d0 a m, as. -a� >, L 0 o z E .° 0 �, 0 v. 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Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 25 Date: February 13, 2015 Surface Data Logging End of Well Report 2L-308 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska Inc. Rig: Doyon 25 Well: 2L-308 (BERTHA) Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20694-00-00 Sperry Job Number: AK-AM-0902024895 Job Start Date: 07 January 2015 Spud Date: 10 January 2015 Total Depth: 17095’ MD, 5485’ TVD North Reference: True Declination: 18.82° Dip Angle: 80.78° Total Field Strength: 57,550 nT Date Of Magnetic Data: 12 December 2014 Wellhead Coordinates N: North 70° 12’ 47.03” Wellhead Coordinates W: West 150° 19’ 2.47“ Drill Floor Elevation 39.5’ Ground Elevation: 114.8’ Permanent Datum: Mean Sea Level SDL Engineers: Todd A. Wilson, Danielle Dawson, Michael LaDouceur, Macy Williams SDL Sample Catchers: Jacob Robertson, Roy Brendible III, Macy Williams, Elijah Callan, Enoc Velez-Martinez, Brian Winn Company Geologist: Kelly Umlauf Company Representatives: Lee Martin, Granville Rizek, Paul Smith, John Haynes, Edward Oglesby, Rob Reinhardt SSDS Unit Number: 125 DAILY SUMMARY 01/09/2015 SDL continues on location from previous well. Spot and set mudlogging shack. Wait on the unit to warm up before rigging up. Pipe shed was loaded with drill pipe and heavy weight drill pipe. Began rigging up CVE and ran gas line to the unit. Rig up network connection with WITS. 01/10/2015 Spudded well and continued to drill ahead to 492’ MD. Gas: The max gas was 112 units at 356’ MD and the average drilling gas was 22 units. Fluids: There was 75 barrels of water based mud lost down hole. 01/11/2015 Continue to drill ahead from 492’ MD to 2127’ MD. Gas: The max gas was 339 units at 1399’ MD and the average drilling gas was 339 units. Fluids: There was 113 barrels of water based mud lost down hole. Geology: Claystone: gray - dark gray, soft, thick, gritty, easily hydrated, cohesive, highly malleable, clumpy, carbonaceous, with clear to milky, fine to very fine grained, sub spherical, sub rounded, well sorted, unconsolidated arenaceous inclusions with a trace amount of glauconite, pyrite, calcite, and black lithic fragments. 01/12/2015 Complete surface section at TD of 2609’ MD. Back ream and circulate out of the hole. Gas: The max gas was 1639 units while circulating and the average gas was 214 units. Fluids: There was 0 barrels of water based mud lost down hole. Geology: Claystone: gray-light gray, brown, soft, thick, cohesive, highly malleable, clumpy, carbonaceous, and arenaceous. 01/13/2015 Land casing at 2609’ MD. Condition water based mud for cementing and rig up cementers. Gas: The max gas was 1307 units while circulating and the average gas was 39 units. Fluids: There was 40 barrels of water based mud lost down hole. 01/14/2015 Cement surface casing. Rig down cementers, break down diverter and rig up BOP stack. Gas: There was no gas observed. Fluids: There was 125 barrels of water based mud lost down hole. 01/15/2015 Make up drill pipe. Gas: There was no gas observed. Fluids: There were no losses downhole. 01/16/2015 Make up BHA, run in hole with 5” drill pipe. Cut and slip drill line. Circulate and condition mud. Drill cement from 2508’ MD to 2516’ MD. Drill cement plugs. Pull out of the hole from 2519’ MD to 2460’ MD. Test well commander ball and pull out of the hole. Pick up BHA and run in hole with 5” drill pipe. Gas: There was no gas observed. Fluids: There were no losses downhole. 01/17/2015 Trip in hole, tag cement and drill cement plugs to 2519’ MD. Drill cement to shoe. Displace mud to LSND and performed FIT. Drill ahead to 3967’ MD. Gas: The max gas was 114 units while drilling and the average gas was 53 units Fluids: There were no losses downhole. Geology: Claystone: gray-light gray, brown, soft, thick, cohesive, highly malleable, clumpy, carbonaceous, and arenaceous. 01/18/2015 Drill ahead from 3967’ MD to 4155’ MD. Pump a high viscosity sweep and circulate. Pulled out of hole from 3970’ MD to 2555’ MD and circulated while rotating and reciprocating pipe. Continue drilling ahead to 4885’ MD and pump another high viscosity sweep. Gas: The max gas was 521 units while tripping, the maximum drilling gas was 118 units and the average gas was 54 units Fluids: There were no losses downhole. Geology: Sandstone: Milky white to opaque, light gray to gray, brown, very fine grained, round to sub-rounded, very well sorted, unconsolidated, slightly calcareous, with occasional mica, pyrite and glauconite. 01/19/2015 Drilled intermediate from 5368’ MD to 6924’ MD. Pumped high viscosity sweeps at 5390’ MD, 5710’ MD and 6045’ MD. Circulated while rotating and reciprocating pipe. Performed short trip from 5966’ MD. Continued drilling ahead and pumped another two high viscosity sweeps at 6427’ MD and 6810’ MD. Gas: The max gas was 326 units while tripping, the maximum drilling gas was 73 units and the average gas was 47 units Fluids: There were no losses downhole. Geology: Siltstone: Light gray to black, light brown to brown, moderately firm to firm, blocky, calcareous, trace Shale 01/20/2015 Drilled from 6924’ MD to 7471’ MD and pumped high viscosity sweeps at 7120’ MD, and 7390’ MD. Continued drilling to 8134’ MD and then began wiper trip while reciprocating and rotating to 5957’ MD. Tripped in hole and blend new 9.6 ppg mud at bottom. Continued drilling intermediate to 8416’ MD. Gas: The max gas was 140 units and the average gas was 58 units. Fluids: There were no losses downhole. Geology: Shale: Gray to black, light brown to brown, fissile, silty, calcareous, moderately hard, tabular, sub-angular to angular, earthy texture 01/21/2015 Drilled from 8183' MD to 9551' MD. Back reamed out of hole from 9551' MD to 7941' MD. Run in hole to 9365' MD. Rotated and reciprocated while dumping and diluting mud. Continued drilling to 9741' MD Gas: The max gas was 323 units while tripping, the maximum drilling gas was 205 units and the average gas was 97 units. Fluids: There were no losses downhole. Geology: Shale: Light to medium gray, light brown to brown, fissile, calcareous, mottled, tabular, sub-angular to angular, arenaceous, occasionally tuffaceous 01/22/2015 Back reaming out of hole from 4064' MD to 2600' MD. Rotate and reciprocate from 2600'MD to 2555' MD. Circulate bottoms up then continue to rotate and reciprocate from 2555' MD to 2455' MD. Open Well Commander. Rotate and reciprocate from 2555' MD to2365' MD. Close Well Commander. Begin testing BOPE. Gas: The max gas was 197 units while tripping and the average gas was 97 units. Fluids: There were no losses downhole. 01/23/2015 Complete BOP Test and blow down choke, kill, and top drive lines. Pull test plug and perform dummy run with landing joint and hanger. Set bushing and retrieve storm pack. Running in hole from 2460' MD to 9365' MD. Displace mud and continue drilling ahead. Gas: The max gas was 224 units while drilling and 219 u while tripping. The average gas was 118 units. Fluids: There were no losses downhole. Geology: Siltstone: Light to medium gray, light brown to brown, cream, opaque, predominately soft, unconsolidated in places, very silty to very fine grain, subangular to subround, slightly calcareous, very arenaceous, moderately argillaceous 01/24/2015 Drilled to 10889' MD. Back reaming out of hole from 10889' MD to 10691' MD then ream and wash back to bottom. Progress minimal. Pump sweeps. Little to no changes in torque. Pull out of hole from 10889'. Gas: The max gas was 381 units while drilling and the average gas was 106 units. Fluids: There were no losses downhole. 01/25/2015 Tripped out of the hole on elevators. Circulate/Condition mud. Cut/Slip drill line. Running in the hole and encountered tight spot at 8550' MD. Continue running in the hole. Gas: The max gas was 138 units while tripping in the hole and the average gas was 6 units. Fluids: There were 17.5 losses downhole. 01/26/2015 Continue run in hole to 10784' MD. Wash and ream from 10784' MD to 10888' MD. Tag Bottom and drilling ahead. Work drill string and ream throug h possible ledges seen. Troubleshoot weight on bit. Orders to spud to bottom, break through hard spot, and continue drilling ahead. Gas: The max gas was 882 units with an average of 142 units Fluids: No losses down hole Geology: 90% sandstone, 10% siltstone 01/27/2015 Drill ahead to 12012' MD and observe rising gas. Circulate out while rotating and reciprocating pipe. Continue drilling to 12200' MD and observe rising gas. Weight up mud and continue drilling ahead. Well pack off during powerdrive downlink. Pull off bottom due to spikes in pump pressure and ECD's. Rates stabilize and continue drilling ahead. Gas: The max gas was 8506 units with an average of 1133 units Fluids: No losses down hole Geology: 90% sandstone, 10% siltstone 01/28/2015 Continue drilling ahead from 12847' MD to TD 13770' MD. Circulate bottoms up. Obtain survey and SPR's before coming off bottom. Back reaming out of hole from 13770' MD. Gas: The max gas was 6767 units with an average of 355 units Fluids: No losses down hole 01/29/2015 Continue to backream out of hole with Mad Pass. Observe 600 u of gas, monitor well, and weight up mud system. Continue to backream out of hole. Encounter tight spots at 10608' MD, 10595' MD, and 10463' MD. Ream and slide without rotation and pumps off. Circulate bottoms up 3x and reciprocated pipe. Monitor well, continue backream out of hole. Gas: The max gas was 1373 units with an average of 104 units Fluids: No losses down hole 01/30/2015 Continue backream out of hole. Encounter tight spots from 8345' MD - 8320' MD and ream 3x. Encounter another tight spot at 8301' MD - 8265' MD, unable to ream through. Circulate and backream out of hole. Pack off at 8233' MD and 8199' MD and circulate bottoms. Continue backream out of hole. Drop activation ball and start pull out of hole. Test BOP. Gas: The max gas was 225 units with an average of 30 units Fluids: No losses down hole 01/31/2015 Finish BOP testing, pull test plug, and start running 7 5/8" casing. Circulate bottoms up inside the shoe. Continue running in the hole with 7 5/8" casing. Gas: The max gas was115 units with an average of 12 units Fluids: No losses down hole 02/01/2015 Continue running 7 5/8" casing from 5183' MD filling every 10 joints. circulate bottoms up at 10930' MD and 12302' MD. Continue running in hole with casing from 13271' MD. Gas: The max gas was 312 units with an average of 38 units Fluids: No losses down hole 02/02/2015 Continue running 7 5/8" casing from 5183' MD filling every 10 joints. Circulate bottoms up at 10930' MD and 12302' MD. Continue running in hole with casing from 13271' MD. Gas: The max gas was 312 units with an average of 38 units Fluids: No losses down hole 02/03/2015 Finish laying down 5" drill pipe. Remove rotary table and pick up BHA tools. Run in hole and rack back 4" drill pipe. Test BOP Gas: No gas was observed Fluids: No losses down hole 02/04/2015 Finish BOP test, pull test plug, and set wear bushing. Service equipment and begin picking up BHA #5. Begin to run in hole with 4" DP doubles to 4316' MD. From 4316' MD continue running in hole with 4" DP singles filling every 20 stands and monitoring the well. Gas: The max gas was 14 units with an average of 2 units 02/05/2015 Continue running in hole from 11580' MD to 13522' MD. Circulate while rotating, and reciprocating pipe. Begin casing test, MAD pass, and drill out plugs. Encounter mud problems and MWD tool signal lost. Rotate and reciprocate pipe. Tag shoe and drill 20' of formation. Begin swapping mud. Gas: The max gas was 21 units with an average of 6 units Fluids: No losses down hole 02/06/2015 Perform Formation Integrity Test (FIT).Tag cement at 13975’ MD. Begin drilling ahead. Troubleshoot MWD, change out standpipe sensor. Continue drilling ahead. Gas: The max gas was 2662 units with an average of 481 units Fluids: No losses down hole Geology: Sandstone: Light gray to tan to amber to cream-white to opaque, predominately moderately to poorly consolidated, fine to very fine grained, sub angular to sub rounded, very calcareous. SHOW: slight odor, trace strain, 10% patchy dull yellow fluorescence, streaming faint blue-white cut fluorescence, pale straw cut, clear residue, bright blue-white residue fluorescence. 02/07/2015 Continue drilling ahead from 14655' MD to 16084' MD. Gas: The max gas was 3414 units with an average of 1456 units Fluids: No losses down hole Geology: Sandstone: Black-gray to tan to amber to cream-white to opaque, predominately moderately to poorly consolidated, fine to very fine grained, sub angular to sub rounded, very calcareous, trace mica. SHOW: slight odor, trace strain, 20% even dull yellow fluorescence, streaming faint blue-white cut fluorescence, pale straw cut, clear residue, bright blue-white residue fluorescence. 02/08/2015 Continue drilling ahead to TD at 17095’ MD. Weighted up mud to 10.2 ppg for trip margin. Circulated and rotated 3 bottom ups, standing back one stand at each bottoms up. Monitor well to be static. Back reamed out of the hole and stopped at 13075’ MD. Open Well Commander. Rotated and reciprocated, and circulated 2 bottom ups. Gas: The max gas was 3356 units with an average of 1805 units Fluids: No losses down hole Geology: Sandstone: Black-gray to tan to amber to cream-white to opaque, predominately moderately to poorly consolidated, occasionally tightly consolidated, fine to very fine grained, very well sorted, sub angular to sub rounded, very calcareous, very silty. SHOW: slight odor, trace strain, 20% even dull yellow fluorescence, blooming faint blue-white cut fluorescence, pale straw cut, clear residue, faint white residue fluorescence. 02/09/2015 Cut and slip drill line. Pull out of the hole. Test BOPE. Pull test plug and install wear ring. Make up 4.5 inch liner. Gas: The max gas was 228 units with an average of 100 units Fluids: There was 15 barrels of water based mud lost down hole. 02/10/2015 Run in the hole with 4.5 inch liner running tools on 4 inch drill pipe. Gas: No gases were detected. Fluids: No losses down hole. 02/11/2015 Continue running in the hole with 4.5 inch Liner, kelly up each stand. Circulate 2 bottoms up at the shoe. Continue to run in the hole with 4.5 inch liner, circulate hole staging pumps up. Drop 1.5 inch outside diameter ball and pump on seat. Seat was confirmed. Attempted to pick up and failed. Made a second attempt to pick up and was successfully released and packer was set. Pressured up on the drill string and sheared ball seat. Circulate tie back clean. Increased rate then pumped Hi viscosity spacer. Displace well with 10.2 pounds per gallon KCL/NaCl Brine. Lay down 4 inch heavy weight drill pipe and 4 inch drill pipe. Gas: The max gas was 400 units with an average of 52 units Fluids: There was 6 barrels of water based mud lost down hole. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 0 5 10 15 20 25 30 35 40 Me a s u r e d D e p t h Rig Days WELL NAME: 2L-308 (Bertha) OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-092024895 Days vs. Depth 06 Jan 2015 Sperry SDL remained on location from previous well 10 Jan 2015 Sperry SDL Services Online LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 10-Jan-2015 TD: 08-Feb-2015 TD Surface Hole Section 2609' MD, 2316' TVD Off Bot: 06:55 12 Jan 2015 Commenced 13.5" Surface Hole Section On Bot: 06:13 10 Jan 2015 Landed 10.75" Casing 2597' MD, 2311' TVD 13 Jan 2015 Commenced 9.875" Intermediate Hole Section On Bot: 04:21 17 Jan 2015 Drill 9.875" hole to 9740' BROOH to test BOPE 22 Jan 2015 POOH to Change Bit 25 Jan 2015 TD Intermediate Hole Section 13775' MD, 5404' TVD Off Bot: 15:53 28 Jan 2015 Commenced 6.5" Production Hole Section On Bot:19:28 05 Feb 2015 Landed 7.625" Casing 13764' MD, 5400' TVD 01 Feb 2015 Landed 4.5" Liner 17093' MD, 5485' TVD 11 Feb 2015 TD Production Hole Section 17095' MD, 5485' TVD Off Bot: 11:13 8 Feb 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: 1.) During the rig move, diesel was sent through the flow line and some was trapped in the degasser. This caused a issue with gas readings to be high when there was no flow after startup of equipment. 2.) When the unit was in transport from last well, equipment within the unit underwent cosmetic damage. 3.) The chromatograph system experienced glitches in which data peaks were calculated as zero ppm throughout . Recommendations: 1.) Check all lines and resevoirs once rig has moved to ensure no contaminents have enterd the system. 2.) If possible be present when unit is being moved. 3.) Reset iris configurations, possibly change 8900 to backup to try and solve the problem with the chromatograph data. Innovations and/or cost savings: N/A Doyon 25 Surface Michael LaDouceur 13-Jan-2015 What went as, or better than, planned: Rig up went very well. All eqiupment maintanence was completed before rigging down creating no delays or issues when rigging up. 2L-308 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0902024895 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: The chromatograph in use had issues with occassionally writing bad data points. Recommendations: Switch to the backup GC before drilling the production section to avoid writing bad data points and send GC in use to Deadhorse for flow calibration. Innovations and/or cost savings: The 24 hour ROC has been invaluable. Continued access to 24 hour help will improve service quality. Doyon 25 Intermediate Danielle Dawson 29-Jan-2015 What went as, or better than, planned: Sampling went very well; no samples were missed. The CVE ran flawlessly and no gas data was missed due to equipment issues. Communication with the geologist, company men and rig personnel went smoothly. Calling out gas over the Giatronics helped the drillers, as they did stop to circulate out high gas. 2L-308 (BERTHA)Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0902024895 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: Experienced difficulties with chromatograph acknowledging C-1. Recommendations: If chromatograph does not recognize C-1 peak, change the "Min Peak Width" within the configuration settings. Innovations and/or cost savings: N/A Doyon 25 Production Todd A. Wilson 12-Feb-2015 What went as, or better than, planned: INSITE worked very well for this hole section. No surface data was missed. 2L-308 (BERTHA)Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0902024895 Alaska Surface Data Logging After Action Review 2L-308 (BERTHA) ConocoPhillips Alaska, Inc. MI Swaco Doyon 25 AK-XX-0902024895 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-Jan 399 9.30 300 11 35 24/19/17 10.0 57/46/41/37/28/27 4/-8.0 0 -1.80 10.8 10.0 1.70/3.45 2000 40 Drilling Ahead 11-Jan 1925 9.80 300 8 39 39/55/56 10.0 55/47/44/37/29/29 4/-9.0 0 0.50 1.95 10.7 11.3 1.9/4.1 1100 40 Drilling Ahead 12-Jan 2610 10.10 300 8 31 33/63/81 9.3 47/39/36/31/22/22 5/-9.5 2/89 2.00 2.50 10.6 13.8 2.4/5.8 1000 40 TD surface section 13-Jan 2610 10.00 300 14 12 8/25/34 9.3 40/26/20/14/4/4 4/-9.5 2/89 1.50 1.20 10.2 15.0 1.0/3.7 900 60 Land Casing 14-Jan 2610 9.90 -20 10 6/18/26 8.7 50/30/23/14/3/3 4/-10.0 1/89 2.00 1.10 10.1 17.5 1/3.8 900 20 Run Casing 15-Jan 2610 9.90 -20 10 6/18/26 8.7 50/30/23/14/3/3 4/-10.0 1/89 2.00 1.10 10.1 17.5 1/3.8 900 20 M/U 5" Drill pipe 16-Jan 2610 9.80 -11 6 2/13/19 8.7 28/17/13/8/2/1 4/-10.0 1/89 2.00 1.10 10.1 17.5 1/3.8 900 20 TIH 17-Jan 3800 9.70 53 18 29 12/18/23 4.0 65/47/40/30/13/12 2/-7.0 1/30 tr 0.68 10.4 13.8 .48/1.5 900 20 Drilling Ahead 18-Jan 5084 9.70 54 19 27 10/14/19 3.8 65/46/39/30/18/10 2/-8.0 4/88 1.00 0.40 10.2 18.8 0.3/1.20 600 20 Drilling Ahead 19-Jan 6924 9.60 50 16 28 12/14/19 4.0 60/44/37/29/13/12 2/-7.0 3/90 1.00 0.40 10.2 16.3 .22/.95 600 40 Drilling Ahead 20-Jan 8183 9.70 51 15 26 10/16/20 3.9 56/41/35/27/11/10 2/-8.0 1/45 0.75 0.25 10.0 16.3 .20/.90 550 60 Drilling Ahead 21-Jan 9740 9.70 54 12 22 8/11/14 4.3 46/34/29/22/9/7 2/-7.0 1/30 0.50 0.35 10.0 12.5 .22/1.0 500 20 Drilling Ahead 22-Jan 9740 9.70 45 13 19 7/9/11 4.0 45/32/26/19/8/7 -6.0 1/46 0.50 0.38 10.0 25.0 .36/.9 500 40 BROOH/BOP Testing 23-Jan 10260 9.60 47 9 23 8/9/10 6.4 41/32/27/20/7/6 -5.0 3/92 0.50 0.31 9.7 7.5 .29/.62 900 0 Drilling Ahead 24-Jan 10891 9.60 43 8 21 6/7/9 3.7 37/29/26/19/7/6 -11.0 3/86 0.25 0.24 9.6 13.8 .18/1.32 1700 40 POOH 25-Jan 10891 9.60 49 11 19 7/8/9 3.9 41/30/26/20/9/7 -8 3/89 0.5 0.45 9.5 20 .28/1.3 1200 80 RIH/Drilling Ahead 26-Jan 11345 9.60 44 16 18 6/7/9 3.5 36/27/28/65/44/1 1 8.0 1/22 0.25 0.37 9.8 15.0 .40/1.41 800 80 Drilling Ahead 27-Jan 12765 9.60 44 11 19 6/8/11 2.8 41/30/26/20/8/7 1 8 4/88 0.25 0.58 9.5 17.5 .22/1.03 900 40 Drilling Ahead 28-Jan 13770 10.40 46 11 21 8/9/14 2.6 43/32/27/21/8/7 1 13.0 1/28 tr 0.42 9.5 18.8 .39/1.4 850 40 BROOH 29-Jan 13775 10.70 45 11 21 6/11/14 2.8 47/34/28/21/45/2 1 12.0 4/85 tr 0.38 9.5 18.8 .25/1.20 800 40 BROOH 30-Jan 13775 10.7 47 16 23 8/12/16 2.6 53/39/31/22/8/7 1 12 3/85 tr 0.35 9.7 18.75 .25/1.25 1250 40 POOH 31-Jan 13775 10.7 49 15 25 9/11/16 2.9 55/40/33/24/9/8 1 13 3/84 tr 0.33 9.5 18.75 .24/1.18 950 40 RIH 7 5/8" Casing 1-Feb 13775 10.75 58 14 23 10/13/17 3 51/37/32/25/9/8 1 13 3/84 tr 0.31 9.5 20 .27/1.12 950 40 RIH 7 5/8" Casing/Land Casing 2-Feb 13775 10.7 50 16 16 9/12/15 3 48/32/27/17/9/8 1/-13 3/84 tr 0.12 8.7 12.5 .05/1.47 1100 40 Cementing 3-Feb 13775 10.7 87 16 23 8/15/22 -55/39/32/23/8/7 1/-12 3/85 tr -8.2 12.5 .00/1.50 1100 40 P/U 4" DP/ BOP Test 4-Feb 13775 10.7 48 16 23 8/15/22 3 55/39/32/23/8/7 1/-12 3/85 tr 0.38 9 18.75 0.26/1.32 1100 40 RIH 4" DP 5-Feb 13795 10 60 17 22 9/16/24 3 56/39/33/26/9/8 1/-12 3/85 tr 0.38 8.9 20 0.26/1.32 1100 40 Drilling Ahead 6-Feb 14650 10 52 11 22 6/7/8 3.2 44/33/26/20/7/6 1/1 10 2/88 tr 6.95 10 1.875 3.92/8.85 127000 80 Drilling Ahead 7-Feb 15890 10 50 14 23 6/8/9 2.5 51/37/31/23/8/7 1/1 10.5 2/88 0.25 6.3 10 2.5 4.20/7.60 126500 80 Drilling Ahead 8-Feb 17095 10.2 48 12 26 6/8/10 2.1 50/38/31/23/7/6 1/1 11.5 2/87 0.25 5.7 10 2.75 4.50/7.80 125500 120 TD Production Section 9-Feb 17095 10.2 48 12 24 6/8/10 2.2 48/36/28/21/7/6 1/1 11.5 2/87 0.25 5.6 10 2.75 4.00/8.80 125500 120 TOOH 10-Feb 17095 10.2 48 14 22 6/8/9 2.1 50/36/29/22/7/6 1/1 11 2/87 0.28 5.6 10 2.75 3.80/8.60 126000 120 RIH w/ 4.5" Liner 11-Feb 17095 10.2 28 -------------126500 -L/D 4" DP Casing Record 7.625" Casing @ 13764' MD, 5400' TVD Remarks 16" Conductor @ 120' MD, 120' TVD 10.75" Casing @ 2599' MD, 2311' TVD 4.5" Liner @ 17093' MD, 5485'TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:10-Jan-2015 SPERRY JOB:TD:8-Feb-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 2 100 2 Baker MXL-1X 13.50 120 2609 2489 63.82 0.994 67.9 30 70 1680 650 11-WT-AEI-PN-TD Surface 3 200 3 Halliburton PDC 9.88 2609 10891 8282 73.00 0.991 113.5 52 141 3030 675 1-2-CT-S-X-1-NOPR POOH to change bit 4 400 4 Halliburton PDC 9.88 10891 13775 2884 31.86 0.991 99.8 33 140 3161 673 1-1-WT-A-X-I-TD Intermediate 5 500 5 NOV PDC 6.50 13775 17095 3320 74.11 0.383 118.3 32 130 2763 241 1-1-WT-A-X-I-NOTD Production WELL NAME:2L-308 (BERTHA)LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902024895 TD:8-Feb-2015 MI Swaco STATE:Alaska RIG:Doyon 25 SPUD:10-Jan-2015 B i t R e c o r d . . * 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 Grade 907-659-7599Unit Phone:Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur Units* Casing Summary Lithology (%) MBT pH Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.8 C-5nC-2 in Minimum Depth Time: 0' 0' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary (current) Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 11 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Preperations to Spud Hole PV 24 hr Max Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 11.00Drilplex10.00'51 Depth in / out Mud Type Lst Type Average Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsConnection ConditionBit # 4.09.509.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Jan-2015 12:00 AM Current Pump & Flow Data: Max Chlorides mg/l 300.00 Rigging up unit and preparing for upcoming hole section. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Spud well and drill Ahead in formation from 120' MD to 492' MD. 75 bbls were lost downhole in the past 24hrs. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2000.00 0 10-Jan-2015 12:00 AM Current Pump & Flow Data: 735 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.07 Doyon 25 Report For: ConditionBit # 1 8.0 13.5 9.30 Mill 9.30 Size 100% Gas In Air=10,000 Units-Connection 0 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 120' WOB 10.5811.13 Avg Min Comments RPM ECD (ppg) ml/30min 12Background (max) Trip Average - Mud Type Lst Type Drilplex 4.0399'35 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-0902024895 Drilling Ahead PV Footage Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to120' Yesterday's Depth: Current Depth: 24 Hour Progress: 283.2 Flow In (gpm) Flow In (spm) 120' 492' 372' Max @ ft Current 217'126.1 Date: Time: 22 in 6 490'Minimum Depth C-5n 356' 37.5 C-2 112 SPP (psi) Gallons/stroke TFABit Type Depth 10.0300 MBT pH 0 0 0 Siltst 503 119 Units* Casing Summary Lithology (%) 01360 83 907-659-7599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur Set AtSize Grade (max)(current) 0 0 Cly 12533 Bottoms Up Time 76.23 0 84195.7 7.24 7 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 327 0 325438534 22 (max)(current) 0 0 Cly 490962 Set AtSize Grade 907-659-7599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur 30714 46 503 119 Units* Casing Summary Lithology (%) 0 MBT pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 11.3300 C-5n 1399' 127.0 C-2 6391 in 6 676'Minimum Depth Time: 339 492' 2127' 1635' Max @ ft Current 1655'162.0 Date: Avg to120' Yesterday's Depth: Current Depth: 24 Hour Progress: 327.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 8 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.70 000 Drilplex 10.01925'39 Depth in / out Mud Type Lst Type Average -168Background (max) Trip 10.0510.74 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 120' WOB 100% Gas In Air=10,000 Units1075Connection 100 0 ConditionBit # 1 9.0 13.5 9.80 Mill 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.74 Doyon 25 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Jan-2015 12:00 AM Current Pump & Flow Data: 735 Max 0 Chlorides mg/l 1100.00 Drill Ahead in formation from 492' MD to ' MD. 113 bbls were lost downhole in the past 24hrs. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap: Drill Ahead in formation from 2127' MD to 2609' MD at TD. Back reamed and surveyed out of hole. Max formation rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1000.00 5 12-Jan-2015 12:00 AM Current Pump & Flow Data: 350 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ConditionBit # 1 9.5 13.5 10.10 Mill 10.10 Size 100% Gas In Air=10,000 Units650Connection 80 15 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 120' WOB Avg Min Comments RPM ECD (ppg) ml/30min 6Background (max)Trip Average 1639 Mud Type Lst 20 Type Drilplex 9.32610'31 Depth in / out YP (lb/100ft2) 10.60 112 00 CementChtSilt C-4i C-4n 24 hr Max Weight 29 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 L/D BHA PV Footage Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 8 Gas Summary 0 6 10 (current) Avg to120' Yesterday's Depth: Current Depth: 24 Hour Progress: 262.0 Flow In (gpm) Flow In (spm) 2127' 2609' 482' Max @ ft Current 2292'147.0 Date: Time: gas while drilling was connection gas of 650 units at a depth of 2463' MD. 0 bbls were lost downhole in the past 24hrs. 214 in 3 -Minimum Depth C-5n - C-2 1639 SPP (psi) Gallons/stroke TFABit Type Depth 13.8300 MBT 2609' pH 0 21 0 Siltst 203 48 Units* Casing Summary Lithology (%) 625863 48 907-659-7599Unit Phone: 5 Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur Set AtSize Grade (max)(current) 81 0 Cly 175351 Bottoms Up Time 402 0 399247042 83 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . * 24 hr Recap: Set casing at 2609' MD. Rigged up cementers. 40 bbls were lost downhole in the past 24hrs. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 900.00 0 13-Jan-2015 12:00 AM Current Pump & Flow Data: 362 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 9.5 13.5 10.00 Mill 10.00 Size 2609' 120' 100% Gas In Air=10,000 UnitsConnection 0 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 120' 2609' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min 30Background (max) Trip Average 1307 Mud Type Lst Type Drilplex 9.32610'12 Depth in / out YP (lb/100ft2) 10.20 000 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Prep for Cement PV 2489' Footage Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 14 Gas Summary 0 0 0 (current) Avg to120' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2609' 2609' 0' Max @ ft Current Date: Time: 39 in 3 -Minimum Depth C-5n - C-2 1307 SPP (psi) Gallons/stroke TFABit Type Depth 15.0300 MBT 2609' pH 0 0 0 Siltst 10.75" 279 66 Units* Casing Summary Lithology (%) 04945 366 907-659-7599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 0 0 Cly 138351 Bottoms Up Time 402 0 272152642 41.2 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 251 02510 (max)(current) Surface 0 0 Cly 0 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur 0 0 10.75" 0 0 Units* Casing Summary Lithology (%) 0 MBT pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.5N/A C-5n - C-2 in -Minimum Depth Time: downhole in the past 24hrs. 2609' 2609' 0' Max @ ft Current Date: Avg to2609' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 20 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 R/U BOP Stack PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.10 000 70.0 Drilplex 8.72610'10 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 UnitsConnection 0 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 10.0 13.5 9.90 Mill 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 14-Jan-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 900.00 Cement in Surface casing. Rig Down Cementers. Breakdown Diverter. Rig up BOP Stack. 125 bbls were lost 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 251 02510 (max)(current) Surface 0 0 Cly 0 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 0 Michael LaDouceur Maximum Report By:Logging Engineers:Todd Wilson\ Michael LaDouceur 0 0 10.75" 0 0 Units* Casing Summary Lithology (%) 0 MBT pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.5N/A C-5n - C-2 in -Minimum Depth Time: 2609' 2609' 0' Max @ ft Current Date: Avg to2609' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 20 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 M/U Drill pipe PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.10 000 70.0 Drilplex 8.72610'10 Depth in / out Mud Type Lst Type Average Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 UnitsConnection 0 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 10.0 13.5 9.90 Mill 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Jan-2015 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 900.00 M/U Drill pipe. 0 bbls were lost downhole in the past 24hrs. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Make up BHA, run in hole with 5" DP. Cut and slip drill line. Circulate and condition mud. Drill cement from 2508' MD rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 900 16-Jan-2015 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 10.0 13.5 9.80 Mill 9.80 Size hole with 5" DP. 2609' 120' 100% Gas In Air=10,000 UnitsConnection Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor Avg Min Comments RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 70.0 Drilplex 8.72610'6 Depth in / out YP (lb/100ft2) 10.10 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 RIH w/ 5" DP PV 2383' Footage 63.82 Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 11 Gas Summary (current) Avg to2609' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2609' 2609' 0' Max @ ft Current Date: Time: to 2516' MD. Drill cement plugs. POOH from 2519' MD to 2460' MD. Test well commander ball and POOH. Pick up BHA and run in in N/A -Minimum Depth C-5n - C-2 N/A SPP (psi) Gallons/stroke TFABit Type Depth 17.5N/A MBT pH 0.994 Siltst 10.75" 0 0 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson Set AtSize 385.4 Grade 16.00'' (max)(current) Surface Cly Bottoms Up Time 189 025145 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 292.8 0 2909389.14 71.54 20 (max)(current) Surface 201 0 Cly 8226 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson 10 4194 139 10.75" 647 153 Units* Casing Summary Lithology (%) 8 MBT 3967' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 13.853 C-5n 3346' 148.0 C-2 114 in 5 3010'Minimum Depth Time: ahead to 3967' MD. 0 bbls lost in past 24 hours. 53 2609' 3967' 1358' Max @ ft Current 3707'60.0 Date: Avg to2609' Yesterday's Depth: Current Depth: 24 Hour Progress: 303.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 18 2383' Footage 63.82 70 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 24 hr Max 45.5 Weight 45 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.40 080 70.0 LSND 4.03800'29 Depth in / out Mud Type Lst 20 Type Average 3720Background (max) Trip 10.2610.85 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units46Connection 32 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 7.0 13.5 9.70 Mill 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.18 Doyon 25 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 17-Jan-2015 12:00 AM Current Pump & Flow Data: 1997 Max 8 Chlorides mg/l 900 TIH, tag and drill plugs to 2519' MD. Drillled cement to shoe. Displaced mud to LSND and performed FIT. Drilled rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Drilled ahead from 3967' MD to 4155' MD. Pumped a high viscosity sweep and circulated. Pulled out of the hole from rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600 4 18-Jan-2015 12:00 AM Current Pump & Flow Data: 2167 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.34 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 8.0 13.5 9.75 Mill 9.70 Size another high viscosity sweep. Currently drilling ahead. 2609' 120' 100% Gas In Air=10,000 Units97Connection 24 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.5110.93 Avg Min Comments RPM ECD (ppg) ml/30min 45Background (max)Trip Average 521 Mud Type Lst 80 Type 70.0 LSND 3.85084'27 Depth in / out YP (lb/100ft2) 10.20 000 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 56 Hours C-3 10 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 2383' Footage 63.82 Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 19 Gas Summary 0 0 0 (current) Avg to3967' Yesterday's Depth: Current Depth: 24 Hour Progress: 217.0 Flow In (gpm) Flow In (spm) 3967' 5368' 1401' Max @ ft Current 5031'147.0 Date: Time: 3970' MD to 2555' MD and circulated while rotating and reciprocating pipe. Continued drilling ahead to 4885' MD and pumped 54 The maximum drilling gas was 118 units and occurred at a depth of 4502' MD. in 5 4219'Minimum Depth C-5n 4156' 137.0 C-2 521 SPP (psi) Gallons/stroke TFABit Type Depth 18.854 MBT 5368' pH 0.994 0 0 0 Siltst 10.75" 651 154 Units* Casing Summary Lithology (%) 0 10 4292 166 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 421 25 Cly 36075 Bottoms Up Time 386.95 0 3849481.97 95.02 30 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 496.69 0 4936619.08 122.39 65 (max)(current) Surface 346 0 Cly 22988 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson 70 3735 146 10.75" 315 75 Units* Casing Summary Lithology (%) 0 MBT 5368' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 16.350 C-5n 6146' 170.0 C-2 326 in 5 6691'Minimum Depth Time: MD. Circulated while rotating and reciprocating pipe. Performed short trip from 5966' MD to 3875' MD. Continued drilling ahead 47 The maximum drilling gas was 73 units and occurred at a depth of 6903' MD. 5368' 6924' 1556' Max @ ft Current 6510'146.0 Date: Avg to5368' Yesterday's Depth: Current Depth: 24 Hour Progress: 181.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 16 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 24 hr Max 45.5 Weight 67 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.20 000 70.0 LSND 4.06695'28 Depth in / out Mud Type Lst 30 Type Average 32667Background (max)Trip 10.6911.17 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units97Connection 23 and pumped another two high viscosity sweeps at 6427' MD and 6810' MD. 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 7.0 13.5 9.65 Mill 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.55 Doyon 25 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 19-Jan-2015 12:00 AM Current Pump & Flow Data: 2628 Max 7 Chlorides mg/l 600 Drilled intermediate from 5368' MD to 6924' MD. Pumped high viscosity sweeps at 5390' MD, 5710' MD and 6045' rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Drilled from 6924' MD to 7471' MD and pumped high viscosity sweeps at 7120' MD and 7390' MD. Continued drilling rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550 4 20-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.55 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 8.0 13.5 9.65 Mill 9.70 Size intermediate to 8416' MD. while reciprocating and rotating to 5957' MD. Tripped in hole and blend new 9.6 ppg mud at bottom. Continued drilling 2609' 120' 100% Gas In Air=10,000 Units140Connection 82 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.6911.17 Avg Min Comments RPM ECD (ppg) ml/30min 47Background (max) Trip Average 118 Mud Type Lst Type 70.0 LSND 3.98183'26 Depth in / out YP (lb/100ft2) 10.00 000 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 132 Hours C-3 80 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 15 Gas Summary 0 24 0 (current) Avg to6924' Yesterday's Depth: Current Depth: 24 Hour Progress: 235.0 Flow In (gpm) Flow In (spm) 6924' 8183' 1259' Max @ ft Current 7098'145.0 Date: Time: to 8039' MD and pumped another a high viscosity sweep at 7690' MD. Continued drilling to 8134' MD and then began wiper trip 58 in 6 8000'Minimum Depth C-5n 8043' 136.0 C-2 140 SPP (psi) Gallons/stroke TFABit Type Depth 16.351 MBT 8183' pH 0.994 0 39 0 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 5 20 4412 344 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 396 14 Cly 10133 Bottoms Up Time 586.56 0 5829731.37 144.81 38 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 697.44 0 6931869.9 172.46 44 (max)(current) Surface 816 30 Cly 11447 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 49 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson 6085 285 10.75" 674 159 Units* Casing Summary Lithology (%) 37 MBT 8183' pH 0.994 17 111 5 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.554 C-5n 9683' 166.0 C-2 205 in 11 9636'Minimum Depth Time: Rotated and reciprocated while dumping and diluting mud. Continued drilling to 9741' MD 97 8183' 9740' 1557' Max @ ft Current 9070'146.0 Date: Avg to6924' Yesterday's Depth: Current Depth: 24 Hour Progress: 203.0 Flow In (gpm) Flow In (spm) Gas Summary 0 91 35 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 12 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 BROOH PV 24 hr Max 45.5 Weight 341 Hours C-3 100 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 5267 70.0 LSND 3.99603'22 Depth in / out Mud Type Lst Type Average 323150Background (max) Trip 10.7311.25 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 363 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 7.0 13.5 9.60 Mill 9.55 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.88 Doyon 25 Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max 111 Chlorides mg/l 500 Drilled from 8183' MD to 9551' MD. Back reamed out of hole from 9551' MD to 7941' MD. Run in hole to 9365' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:BROOH from 4064' MD to 2600' MD. Rotate and reciprocate from 2600'MD to 2555' MD. Circulate bottoms up then rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 500 136 22-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.88 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 6.0 13.5 9.85 Mill 9.70 Size 2365' MD. Close Well Commander. Began testing BOP. 2609' 120' 100% Gas In Air=10,000 Units-Connection 488 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.7311.25 Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average 197 Mud Type Lst Type 70.0 LSND 4.09740'19 Depth in / out YP (lb/100ft2) 10.00 53715 065 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 227 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 BOP Testing PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 13 Gas Summary 0 103 67 (current) Avg to6924' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 9740' 9740' 0' Max @ ft Current Date: Time: continue to rotate and reciprocate from 2555' MD to 2455' MD. Open Well Commander. Rotate and reciprocate from 2555' MD to 45 in 4 -Minimum Depth C-5n - C-2 197 SPP (psi) Gallons/stroke TFABit Type Depth 25.045 MBT 8183' pH 0.994 236 134 80 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 462679 2928 907-659-7599Unit Phone: 5 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 912 343 Cly 9142 Bottoms Up Time 697.44 0 6931869.9 172.46 44 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 697.44 0 6931869.9 172.46 44 (max)(current) Surface 977 9 Cly 19385 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson 70 13223 254 10.75" 674 159 Units* Casing Summary Lithology (%) 33 MBT 10260' pH 0.994 3 61 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 7.547 C-5n 10124' 115.0 C-2 224 in 6 9760'Minimum Depth Time: landing joint and hanger. Set bushing and retrieve storm pack. RIH from 2460' MD to 9365' MD. Displace mud and continue 118 9740' 10260' 520' Max @ ft Current 10031'85.0 Date: Avg to9744' Yesterday's Depth: Current Depth: 24 Hour Progress: 226.0 Flow In (gpm) Flow In (spm) Gas Summary 0 61 14 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 9 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 24 hr Max 45.5 Weight 613 Hours C-3 30 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 1323 70.0 LSND 6.410260'23 Depth in / out Mud Type Lst Type Average 219150Background (max) Trip 10.4310.67 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 377 drilling ahead. 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 5.0 13.5 9.75 Mill 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.81 Doyon 25 Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max 214 Chlorides mg/l 900 Complete BOP Test and blowdown choke, kill, and top drive lines. Pull test plug and perform dummy run with rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Drilled to 10889' MD. BROOH from 10889' MD to 10691' MD then ream and wash back to bottom. Progress minimal. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1700 318 24-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.86 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 11.0 13.5 9.65 Mill 9.60 Size 2609' 120' 100% Gas In Air=10,000 Units381Connection 438 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.4010.77 Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average - Mud Type Lst Type 70.0 LSND 3.710891'21 Depth in / out YP (lb/100ft2) 9.60 57613 014 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 686 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 POOH PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 8 Gas Summary 0 116 24 (current) Avg to10260' Yesterday's Depth: Current Depth: 24 Hour Progress: 226.0 Flow In (gpm) Flow In (spm) 10260' 10891' 631' Max @ ft Current 10031'85.0 Date: Time: Pump sweeps. Little to no changes in torque. POOH from 10889'. 106 in 10 10791'Minimum Depth C-5n 10877' - C-2 381 SPP (psi) Gallons/stroke TFABit Type Depth 13.843 MBT 10891' pH 0.994 40 63 7 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 5611752 1124 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 972 77 Cly 15774 Bottoms Up Time 779.41 0 7745972.32 192.9 - 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 762.09 0 7573946.13 184.04 - (max)(current) Surface 156 6 Cly 18351 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 0 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson 2284 26 10.75" 674 159 Units* Casing Summary Lithology (%) 355 MBT 10891' pH 0.994 0 12 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.049 C-5n - - C-2 138 in 2 -Minimum Depth Time: Continue RIH. 6 10891' 10891' 0' Max @ ft Current -- Date: Avg to10891' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 20 0 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 11 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 TIH PV 24 hr Max 45.5 Weight 961 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 109344120 70.0 LSND 3.910891'19 Depth in / out Mud Type Lst Type Average 138-Background (max)Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 51 Losses for the Day: 17.5 bbls 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 8.0 13.5 9.65 Mill 9.60 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: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max 412 Chlorides mg/l 1200 TOOH on elevators. Circulate/Condition mud. Cut/Slip drill line. RIH and encountered tight spot at 8550' MD. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Continue RIH to 10784' MD. Wash and ream from 10784' MD to 10888' MD. Tag Bottom and drilling ahead. Work rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800 696 26-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.59 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 8.0 13.5 9.75 Mill 9.00 Size continue drilling ahead. 2609' 120' 100% Gas In Air=10,000 Units572Connection 4052 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.3210.48 Avg Min Comments RPM ECD (ppg) ml/30min 108Background (max) Trip Average 642 Mud Type Lst 90 Type 70.0 LSND 3.511345'18 Depth in / out YP (lb/100ft2) 9.80 119325104 019 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 921 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 16.27 Gas Summary 0 1425 384 (current) Avg to10891' Yesterday's Depth: Current Depth: 24 Hour Progress: 161.0 Flow In (gpm) Flow In (spm) 10891' 11365' 474' Max @ ft Current 11084'122.0 Date: Time: drillstring and ream through possible ledges seen. Trouble shoot WOB. Orders to spud to bottom, break through hard spot, and 142 in 10 11375'Minimum Depth C-5n 10971' 104.0 C-2 882 SPP (psi) Gallons/stroke TFABit Type Depth 15.044 MBT 11365' pH 0.994 19 675 7 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 149 10 10490 421 907-659-7599Unit Phone: 401 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 5925 25 Cly 56203 Bottoms Up Time 801.03 0 7960994.8 193.77 49 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 893.1 250 88751109.89 216.79 73 (max)(current) Surface 33818 25 Cly 337075 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 4928 Danielle Dawson Maximum Report By:Logging Engineers:Todd Wilson\ Danielle Dawson 80 55856 421 10.75" 674 159 Units* Casing Summary Lithology (%) 1586 MBT 12765' pH 0.994 19 10928 7 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.544 C-5n 10971' 109.0 C-2 8506 in 10 11375'Minimum Depth Time: drilling to 12200' MD and observe rising gas. Weight up mud and continue drilling ahead. Well pack off during powerdrive down 1133 11365' 12765' 1400' Max @ ft Current 12039'127.0 Date: Avg to11365' Yesterday's Depth: Current Depth: 24 Hour Progress: 175.0 Flow In (gpm) Flow In (spm) Gas Summary 0 27369 4663 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 11 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 24 hr Max 45.5 Weight 5298 Hours C-3 019 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 9444061840 70.0 LSND 2.812765'19 Depth in / out Mud Type Lst 20 Type Average -126Background (max) Trip 10.4410.73 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units8506Connection 24539 link. Pull off bottom due to spikes in pump pressure and ECD's. Rates stabilize and continue drilling ahead. 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 8.0 13.5 10.00 Mill 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.86 Doyon 25 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max 3584 Chlorides mg/l 900 Drill ahead to 12012' MD and observe rising gas. Circulate out while rotating and reciprocating pipe. Continue rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Continue drilling ahead from 12847' MD to TD 13770' MD. Circulate bottoms up. Obtain survey and SPR's before rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 850 1309 28-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 13.0 13.5 10.60 Mill 10.40 Size 2609' 120' 100% Gas In Air=10,000 Units6767Connection 19722 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min 165Background (max)Trip Average - Mud Type Lst Type 70.0 LSND 2.613770'21 Depth in / out YP (lb/100ft2) 9.50 6611759520 8353009 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 1618 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 BROOH PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 11 Gas Summary 682 18741 3105 (current) Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: 213.0 Flow In (gpm) Flow In (spm) 12765' 13770' 1005' Max @ ft Current 13716'99.0 Date: Time: coming off bottom. BROOH from 13770' MD. 355 in 27 13246'Minimum Depth C-5n 13338' - C-2 6767 SPP (psi) Gallons/stroke TFABit Type Depth 18.846 MBT 13770' pH 0.994 3051 7703 1162 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 59216038 61488 907-659-7599Unit Phone: 3345 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 30448 5376 Cly 310491 Bottoms Up Time 963.71 250 95771198.15 234.44 72 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . * 24 hr Recap:Continue BROOH with Mad Pass. Observe 600 u of gas, monitor well, and weight up mud system. Continue to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800 315 29-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 12.0 13.5 10.75 Mill 10.70 Size bottoms up 3x and reciprocated pipe. Monitor well, then continue BROOH. 2609' 120' 100% Gas In Air=10,000 Units-Connection 4539 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min 50Background (max)Trip Average 1373 Mud Type Lst Type 70.0 LSND 2.813775'21 Depth in / out YP (lb/100ft2) 9.50 185401136 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 416 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 BROOH PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 11.13 Gas Summary 0 4697 916 (current) Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13775' 13775' 0' Max @ ft Current -- Date: Time: BROOH. Encounter tight spots at 10608' MD, 10595' MD, and 10463' MD. Ream and slide without rotation and pumps off. Circulate 104 in 5 -Minimum Depth C-5n - - C-2 1373 SPP (psi) Gallons/stroke TFABit Type Depth 18.845 MBT 13775' pH 0.994 0 1907 0 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 1364956 30 907-659-7599Unit Phone: 1039 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 7041 0 Cly 69525 Bottoms Up Time 963.71 250 95771198.15 234.44 72 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 963.71 250 95771198.15 234.44 72 (max)(current) Surface 110 0 Cly 1855 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 48 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams 998 15 10.75" 674 159 Units* Casing Summary Lithology (%) 10 MBT 13775' pH 0.994 0 25 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 18.847 C-5n - - C-2 225 in 3 -Minimum Depth Time: 8301' MD - 8265' MD. Unable to ream through. Circulate and BROOH. Pack off at 8233' MD and 8199' MD and circulate bottoms. 30 13775' 13775' 0' Max @ ft Current -- Date: Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 64 3 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 16 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 POOH PV 24 hr Max 45.5 Weight 41 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 192712 70.0 LSND 2.613775'23 Depth in / out Mud Type Lst Type Average -5Background (max) Trip 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 73 Continue BROOH. Drop activation ball and start POOH. Test BOP. 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 12.0 13.5 10.70 Mill 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 30-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max 27 Chlorides mg/l 1250 Continue BROOH. Encounter tight spots from 8345' MD - 8320' MD and ream 3x. Encounter another tight spot at rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Finish BOP testing, pull test plug, and start running 7 5/8" casing. Circulate bottoms up inside the shoe. Continue rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 950 3 31-Jan-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 13.0 13.5 10.70 Mill 10.70 Size 2609' 120' 100% Gas In Air=10,000 Units-Connection 26 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min n/aBackground (max) Trip Average - Mud Type Lst Type 70.0 LSND 2.913775'25 Depth in / out YP (lb/100ft2) 9.50 030 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 13 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Running Casing PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 15 Gas Summary 0 27 0 (current) Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13775' 13775' 0' Max @ ft Current -- Date: Time: running in the hole with 7 5/8" casing. 12 in 2 -Minimum Depth C-5n - - C-2 115 SPP (psi) Gallons/stroke TFABit Type Depth 18.849 MBT 13775' pH 0.994 0 11 0 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 11289 15 907-659-7599Unit Phone: 0 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 133 0 Cly 15075 Bottoms Up Time 963.71 250 95771198.15 234.44 72 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 963.71 250 95771198.15 234.44 72 (max)(current) Surface 655 0 Cly 15606 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 6 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams 4277 61 10.75" 674 159 Units* Casing Summary Lithology (%) 14 MBT 13775' pH 0.994 0 67 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.058 C-5n - - C-2 312 in 1 -Minimum Depth Time: MD. Cotinue running in hole with casing from 13271' MD. 38 13775' 13775' 0' Max @ ft Current -- Date: Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 129 34 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 14 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Cementing PV 24 hr Max 45.5 Weight 141 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 8306 70.0 LSND 3.013775'23 Depth in / out Mud Type Lst Type Average -n/aBackground (max) Trip 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 246 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 13.0 13.5 10.75 Mill 10.75 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 1-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max 52 Chlorides mg/l 950 Continue running 7 5/8" casing from 5183' MD filling every 10 joints. Cirulate bottoms up at 10930' MD and 12302' 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 963.71 250 95771198.15 234.44 72 (max)(current) Surface 1621 0 Cly 28691 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 129 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams 5404 17 10.75" 674 159 Units* Casing Summary Lithology (%) 41 MBT 13775' pH 0.994 0 152 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.550 C-5n - - C-2 289 in 1 -Minimum Depth Time: plug, and displace cement. Rig down cementers and clean rig. Slip and cut drill line. Begin laying down 5" drill pipe. 33 13775' 13775' 0' Max @ ft Current -- Date: Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 384 110 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 16 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 $5,006.44 $130,679.88 Cementing/Laying down DP PV 24 hr Max 45.5 Weight 333 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.70 3310027 70.0 LSND 3.013775'16 Depth in / out Mud Type Lst Type Average -n/aBackground (max) Trip 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 728 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 13.0 13.5 10.70 Mill 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 2-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max 169 Chlorides mg/l 1100 Circulate bottoms up at 13762' MD. Land casing, blow down topdrive, and rig up cementers. Test equipment, drop 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 530 0 52731161.67 631.01 72 (max)(current) Surface Cly Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone:Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams 10.75" 674 159 Units* Casing Summary Lithology (%) MBT 13775' pH 0.994 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 12.587 C-5n - - C-2 n/a in n/a -Minimum Depth Time: Test BOP. n/a 13775' 13775' 0' Max @ ft Current -- Date: Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 16 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 P/U 4" DP / BOP Test PV 24 hr Max 45.5 Weight Hours C-3 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.20 70.0 LSND 3.013775'23 Depth in / out Mud Type Lst Type Average -n/aBackground (max) Trip 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 12.0 13.5 10.70 Mill 10.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Morning Report Report # 26 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 3-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max Chlorides mg/l 1100 Finish laying down 5" drill pipe. Remove rotary table and pick up BHA tools. Run in hole and rackback 4" drill pipe. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap:Finish BOP test, pull test plug, and set wear bushing. Service equipment and begin picking up BHA #5. Begin to run rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1100 3 4-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 27 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Condition 11-WT-AEI-PN-TD Bit # 1 12.0 13.5 10.70 Mill 10.70 Size monitoring the well. 2609' 120' 100% Gas In Air=10,000 Units-Connection 76 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min n/aBackground (max) Trip Average - Mud Type Lst Type 70.0 LSND 3.013775'23 Depth in / out YP (lb/100ft2) 9.00 121 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 3 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 RIH 4" DP (Singles) PV 2383' Footage 63.82 Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP 16 Gas Summary 0 61 2 (current) Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13775' 13775' 0' Max @ ft Current -- Date: Time: in hole with 4" DP doubles to 4316' MD. From 4316' MD continue running in hole with 4" DP singles filling every 20 stands and 2 in 1 -Minimum Depth C-5n - - C-2 14 SPP (psi) Gallons/stroke TFABit Type Depth 18.848 MBT 13775' pH 0.994 0 25 0 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 132 21 907-659-7599Unit Phone: 23 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 16.00'' (max)(current) Surface 111 0 Cly 975 Bottoms Up Time 530 0 52731161.67 631.01 72 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 530 0 52731161.67 631.01 72 (max)(current) Surface 180 0 Cly 1322 Set AtSize 385.4 Grade 16.00'' 907-659-7599Unit Phone: 38 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams 157 14 10.75" 674 159 Units* Casing Summary Lithology (%) 9 MBT 13775' pH 0.994 0 42 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth -- C-5n - - C-2 21 in 1 -Minimum Depth Time: casing test, MAD pass, and drill out plugs. Encounter mud problems and MWD tool signal lost. Rotate and reciprocate pipe. Tag 6 13775' 13793' 18' Max @ ft Current -- Date: Avg to12765' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 101 28 (current) Granville Rizek/Edward Oglesby ShClyst TuffGvlCoal cP - 2383' Footage 63.82 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 RIH 4" DP/Test Casing PV 24 hr Max 45.5 Weight 26 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) - 10169 70.0 LSND --- Depth in / out Mud Type Lst Type Average -n/aBackground (max) Trip 10.9011.14 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 30.0226' 2609' WOB Conductor 100% Gas In Air=10,000 Units-Connection 134 shoe and drill 20' of formation. Begin swapping mud. 2609' 120' Condition 11-WT-AEI-PN-TD Bit # 1 - 13.5 - Mill - Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.49 Doyon 25 Report For: Morning Report Report # 28 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad ROP ROP (ft/hr) 4.23 @ Mud Data Depth 5-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max 21 Chlorides mg/l - Continue running in hole from 11580' MD to 13522' MD. Circulate while rotating, and reciprocating pipe. Begin rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . * 24 hr Recap: 140 1-1-WT-A-X-I-NOTD 30.0 70.0 11-WT-AEI-PN-TD 3 PDC 9 7/8 0.991 31.86 10891' 13775' 1 Mill 13.5 0.994 63.82 226' Perform FIT. Tag cement at 13795' MD. Began drilling ahead. Troubleshoot MWD, change out standpipe sensor. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 127000 2357 6-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 29 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.59 Doyon 25 Report For: Condition 1-2-CT-S-X-1-NOPR Bit # 2 10.0 9 7/8 10.00 PDC 10.00 Size 4 2609' 120' 100% Gas In Air=10,000 Units-Connection 13339 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 2609' 10891' WOB Conductor 11.1311.33 Avg Min Comments RPM ECD (ppg) ml/30min 198Background (max)Trip Average - Mud Type Lst 80 Intermediate Type 141.0 Kla-Shield 3.214650'22 Depth in / out YP (lb/100ft2) 10.00 2721114230 413 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 2900 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 8282' Footage 73.00 2609' 2383' 2884' Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 11 29.7 Gas Summary 5 6653 1665 (current) Avg to13775' Yesterday's Depth: Current Depth: 24 Hour Progress: 213.0 Flow In (gpm) Flow In (spm) 13793' 14655' 862' Max @ ft Current 14618'132.0 Date: Time: Continue drilling ahead. 481 in 3 13806'Minimum Depth C-5n 14596' 157.0 C-2 2662 SPP (psi) Gallons/stroke TFABit Type Depth 1.952 MBT 14808' pH 0.991 5 2223 0 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 375 20 22015 145 907-659-7599Unit Phone: 1877 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 13764' 16.00'' 7 5/8" (max)(current) Surface 15534 16 Cly 109925 Bottoms Up Time 449.46 0 4466607.04 157.58 80 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . * 24 hr Recap: 140 1-1-WT-A-X-I-NOTD 30.0 70.0 11-WT-AEI-PN-TD 3 PDC 9 7/8 0.991 31.86 10891' 13775' 1 Mill 13.5 0.994 63.82 226' Perform FIT. Tag cement at 13795' MD. Began drilling ahead. Troubleshoot MWD, change out standpipe sensor. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 127000 2357 6-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 30 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.59 Doyon 25 Report For: Condition 1-2-CT-S-X-1-NOPR Bit # 2 10.0 9 7/8 10.00 PDC 10.00 Size 4 2609' 120' 100% Gas In Air=10,000 Units-Connection 13339 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 2609' 10891' WOB Conductor 11.1311.33 Avg Min Comments RPM ECD (ppg) ml/30min 198Background (max)Trip Average - Mud Type Lst 80 Intermediate Type 141.0 Kla-Shield 3.214650'22 Depth in / out YP (lb/100ft2) 10.00 2721114230 413 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 2900 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 Drilling Ahead PV 8282' Footage 73.00 2609' 2383' 2884' Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 11 29.7 Gas Summary 5 6653 1665 (current) Avg to13775' Yesterday's Depth: Current Depth: 24 Hour Progress: 213.0 Flow In (gpm) Flow In (spm) 13793' 14655' 862' Max @ ft Current 14618'132.0 Date: Time: Continue drilling ahead. 481 in 3 13806'Minimum Depth C-5n 14596' 157.0 C-2 2662 SPP (psi) Gallons/stroke TFABit Type Depth 1.952 MBT 14808' pH 0.991 5 2223 0 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 375 20 22015 145 907-659-7599Unit Phone: 1877 Macy Williams Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 13764' 16.00'' 7 5/8" (max)(current) Surface 15534 16 Cly 109925 Bottoms Up Time 449.46 0 4466607.04 157.58 80 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . * 24 hr Recap: 30.0 70.0 11-WT-AEI-PN-TD 0.991 31.86 10891' 140 1-1-WT-A-X-I-NOTD13775' 1 Mill 13.5 0.994 63.82 226' 3 PDC 9 7/8 Continued drilling ahead to TD at 17095' MD. Weighted up mud to 10.2 ppg for trip margin. Circulated and rotated rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 125500 7941 8-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 31 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.26 Doyon 25 Report For: Condition 1-2-CT-S-X-1-NOPR Bit # 2 11.5 9 7/8 10.20 PDC 10.20 Size 4 at 13705' MD. Opened Well Commander. Rotated and reciprocated, and circulated 2 bottom ups. 2609' 120' 100% Gas In Air=10,000 Units-Connection 16760 Tools Gamma, Res, ECD, Directional API FL Chromatograph (ppm) 2609' 10891' WOB Conductor 11.5612.01 Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average - Mud Type Lst 90 Intermediate Type 141.0 Kla-Shield 2.117095'26 Depth in / out YP (lb/100ft2) 10.00 208946001378 12245 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 8843 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 BROOH PV 8282' Footage 73.00 2609' 2383' 2884' Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 12 29.7 Gas Summary 84 8384 2201 (current) Avg to13775' Yesterday's Depth: Current Depth: 24 Hour Progress: 180.0 Flow In (gpm) Flow In (spm) 16084' 17095' 1011' Max @ ft Current 16574'147.8 Date: Time: 3 bottom ups, standing back one stand at each bottom's up. Monitored well to be static. Back reamed out of the hole and stopped 1805 in 138 15714'Minimum Depth C-5n 16259' - C-2 3356 SPP (psi) Gallons/stroke TFABit Type Depth 2.848 MBT 17095' pH 0.991 485 2851 76 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 1565 10 56736 2188 907-659-7599Unit Phone: 2949 Danielle Dawson Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 13764' 16.00'' 7 5/8" (max)(current) Surface 18853 431 Cly 113756 Bottoms Up Time 487.1 0 48443660.37 173.07 90 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 485.01 0 4820685.18 200.17 (max)(current) Surface N/A 0 Cly N/A Set AtSize 385.4 Grade 13764' 16.00'' 7 5/8" 907-659-7599Unit Phone: N/A Danielle Dawson Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams 136 42 10.75" 674 159 Units* Casing Summary Lithology (%) 81 MBT 17095' pH 0.991 0 N/A 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.848 C-5n - - C-2 288 in 15 -Minimum Depth Time: 100 17095' 17095' 0' Max @ ft Current -- Date: Avg to13775' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 N/A N/A (current) Lee Martin/Paul Smith ShClyst TuffGvlCoal cP 12 Footage 73.00 2609' 2383' 2884' Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 R/U to RIH w/ 4.5" liner PV 24 hr Max 45.5 Weight 125 Hours C-3 011 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 226228143 141.0 Kla-Shield 2.217095'24 Depth in / out Mud Type Lst Intermediate Type Average 288-Background (max)Trip Chromatograph (ppm) 2609' 10891' WOB Conductor Comments RPM 100% Gas In Air=10,000 Units-Connection N/A 4 2609' 120' 1-2-CT-S-X-1-NOPR Bit # 2 11.5 9 7/8 10.20 PDC 10.20 Size 8282' 96% Rig Activity: - Doyon 25 Report For: Tools Gamma, Res, ECD, Directional -- TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary Depth Morning Report Report # 32 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips ROP ROP (ft/hr) 4.23 @ Mud Data API FL Avg MinECD (ppg) 9-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max 106 125500 Condition Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/lml/30min 3 PDC 9 7/8 Cut and slip drill line. Pull out of the hole. Test BOPE. Pull test plug and install wear ring. Make up 4.5" liner. rig 1 Mill 13.5 0.994 63.82 226' 30.0 70.0 11-WT-AEI-PN-TD 0.991 31.86 10891' 140 1-1-WT-A-X-I-NOTD13775' . * 24 hr Recap: 31.86 10891' 140 1-1-WT-A-X-I-NOTD13775' 1 Mill 13.5 0.994 63.82 226' 3 PDC 9 7/8 Run in the hole with 4.5" liner running tools on 4" drill pipe. rig out (sec/qt) Viscosity Cor Solids % Chlorides mg/lml/30min 10-Feb-2015 12:00 AM Current Pump & Flow Data: 2700 Max 126000 Condition 30.0 70.0 4.23 @ Mud Data API FL Avg MinECD (ppg) Density (ppg) Depth Morning Report Report # 33 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Job No.: Daily Charges: Total Charges: MWD Summary ROP ROP (ft/hr) 96% Rig Activity: - Doyon 25 Report For: Tools Gamma, Res, ECD, Directional -- 11.0 9 7/8 10.20 PDC 10.20 Size 8282' 11-WT-AEI-PN-TD 2609' 120' 1-2-CT-S-X-1-NOPR Bit # 2 100% Gas In Air=10,000 Units-Connection Chromatograph (ppm) 2609' 10891' WOB Conductor Comments RPM -Background (max)Trip Average - Mud Type Lst Intermediate Type 141.0 Kla-Shield 2.117095'22 Depth in / out 4 (lb/100ft2) 10.00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0902024895 RIH w/ 4.5" liner/4" DP PV Footage 73.00 2609' 2383' 2884'0.991 Granville Rizek/Paul Smith ShClyst TuffGvlCoal cP 14 29.7 Gas Summary (current) Avg to13775' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 17095' 17095' 0' Max @ ft Current -- Date: Time: - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.848 YPMBT 17095' pH 0.991 Siltst 10.75" 674 159 Units* Casing Summary Lithology (%) 907-659-7599Unit Phone:Danielle Dawson Maximum Report By:Logging Engineers:Danielle Dawson \ Macy Williams Set AtSize 385.4 Grade 13764' 16.00'' 7 5/8" (max)(current) Surface Cly Bottoms Up Time 485.01 0 4820685.18 200.17 N/A Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . * 24 hr Recap: 0 4820 N/A C-5n 695 200.17 Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) 42- Grade 13764' 16.00'' 7 5/8" Surface Intermediate Type Conductor Logging Engineers:Todd A. Wilson \ Danielle Dawson Set AtSize N/A 0 485.01 907-659-7599Unit Phone: N/A Todd A. Wilson Maximum 0 Report By: 159 Units* Casing Summary Lithology (%) 81 MBT 17095' pH 0.991 0 N/A 0 Siltst 29.7 - C-2 400 in - Continue to run in the hole with 4.5 inch liner, circulate hole staging pumps up. Drop 1.5 inch outside diameter ball and pump 52 drill pipe. 125 400 17095' 17095' 0' Max @ ft 0 N/A N/A Gallons/stroke - Current -- Date: 96% Rig Activity:11-Feb-2015 12:00 AM Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Granville Rizek/Paul Smith Time: SPP (psi)674 C-5iDepth Gas Summary Cly Lag Correction (bbls) Bottoms Up Strokes (current) Volumes Bottoms Up Time Footage 73.00 2609' 2383' 0.991 TFA Ss (ppb Eq) C-1 Mud Type KCL/NaC Depth Clyst Hours C-3 AK-AM-0902024895 L/D 4" DP PV - Comments RPM 011 Cement 45.5 TuffGvlCoalCht Silt C-4i LstSh 4 (lb/100ft2) - 226228143 Weight 10.75" 385.4 Average (max) Trip (max)(current) -Background 136 141.02609' 10891' WOB Depth in / out 100% Gas In Air=10,000 Units-Connection N/A Hi viscosity spacer. Displaced well to 10.2 pounds per gallon KCL/NaCl Brine. Lay down 4 inch heavy weight drill pipe and 4 inch and packer was set. Pressured up on the drill string and sheared ball seat. Circulated tie back clean. Increased rate, then pumped 11-WT-AEI-PN-TD 17095'- on seat. Seat was confirmed. Attempted to pick up and failed. Made a second attempt to pick up and was successfully released 2609' 120' 1-2-CT-S-X-1-NOPR Bit # 2 9 7/8 10.20 PDC 10.20 Size 8282' - Bit Type 28 Doyon 25 Report For: Tools Gamma, Res, ECD, Directional - - @ 4.23 13775' Job No.: Daily Charges: Total Charges: MWD Summary ROP ROP (ft/hr) 24 hr MaxAvg Morning Report Report # 34 Customer: Well: Area: Location: Rig: 2L-308 Conoco Phillips TARN 2L Pad Mud Data API FL Avg MinECD (ppg) Density (ppg) to Depth YP Current Pump & Flow Data: 2700 Max 126500 Condition 30.0 70.0 - - 106 Chromatograph (ppm) C-4n Minimum out (sec/qt) Viscosity Cor Solids % Chlorides mg/lml/30mincP 3 PDC 9 7/8 Continue running in the hole with 4.5 inch Liner, kelly up each stand. Circulate 2 bottoms up at the shoe. rig 1 Mill 13.5 0.994 63.82 226' 31.86 10891' 140 1-1-WT-A-X-I-NOTD13775' 2884' WELL INFORMATION Created On : Feb 20 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2L-308 (BERTHA) Job Number :AK-XX-0902024895 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') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 78.83 0.14 147.49 78.83 0.08 S 0.05 E 0.03 0.18 171.15 0.21 126.12 171.15 0.28 S 0.25 E 0.16 0.10 260.49 0.45 29.56 260.49 0.07 S 0.55 E 0.51 0.58 352.21 2.39 23.92 352.18 1.99 N 1.51 E 2.00 2.12 447.52 3.21 11.57 447.37 6.43 N 2.85 E 4.51 1.06 541.92 4.42 15.67 541.56 12.52 N 4.36 E 7.64 1.31 635.72 5.26 15.07 635.03 20.15 N 6.46 E 11.76 0.90 729.80 7.08 20.18 728.56 29.76 N 9.58 E 17.41 2.02 779.90 9.30 20.43 778.14 36.45 N 12.06 E 21.64 4.43 825.45 12.03 21.93 822.90 44.30 N 15.11 E 26.74 6.02 918.14 15.37 25.49 912.94 64.36 N 24.01 E 40.82 3.71 977.46 16.52 25.98 969.98 79.04 N 31.09 E 51.67 1.95 1072.80 16.76 35.79 1,061.35 102.38 N 45.07 E 71.54 2.95 1166.54 16.25 46.66 1,151.25 122.35 N 62.52 E 93.82 3.33 1261.19 16.42 50.04 1,242.08 140.03 N 82.40 E 117.81 1.02 1355.54 16.06 53.84 1,332.67 156.29 N 103.16 E 142.24 1.19 1450.13 16.38 61.36 1,423.50 170.41 N 125.43 E 167.54 2.24 1544.61 17.87 66.40 1,513.79 182.60 N 150.41 E 194.91 2.22 1637.82 21.17 71.08 1,601.64 193.78 N 179.45 E 225.91 3.92 1733.75 24.41 73.02 1,690.07 205.19 N 214.80 E 263.04 3.47 1782.85 26.99 73.56 1,734.31 211.31 N 235.19 E 284.33 5.28 1827.89 29.53 74.35 1,773.98 217.20 N 255.69 E 305.65 5.70 1876.68 32.16 75.76 1,815.86 223.64 N 279.86 E 330.66 5.59 1922.33 34.21 75.69 1,854.07 229.80 N 304.07 E 355.63 4.49 1967.54 36.31 77.28 1,890.98 235.89 N 329.44 E 381.70 5.07 2016.69 38.07 77.82 1,930.13 242.29 N 358.45 E 411.35 3.64 2111.56 41.45 77.86 2,003.05 255.07 N 417.76 E 471.88 3.56 2206.28 44.15 76.99 2,072.55 269.09 N 480.56 E 536.12 2.92 2300.34 48.02 74.02 2,137.78 286.10 N 546.12 E 603.83 4.70 INSITE V8.1.10 Page 1Job No:AK-XX-0902024895 Well Name:2L-308 (BERTHA)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2395.33 50.82 73.63 2,199.57 306.20 N 615.40 E 675.96 2.96 2444.66 54.35 75.55 2,229.54 316.59 N 653.17 E 715.13 7.79 2490.27 55.89 75.33 2,255.62 326.00 N 689.38 E 752.54 3.40 2531.61 59.09 76.51 2,277.83 334.47 N 723.20 E 787.37 8.11 2676.20 61.01 76.36 2,350.02 363.86 N 844.98 E 912.54 1.33 2769.53 64.14 76.43 2,393.00 383.34 N 925.48 E 995.29 3.35 2859.83 68.05 75.06 2,429.58 403.68 N 1,005.47 E 1077.79 4.55 2953.89 71.73 74.49 2,461.92 426.87 N 1,090.68 E 1166.09 3.95 3048.34 74.21 73.91 2,489.58 451.46 N 1,177.57 E 1256.39 2.69 3143.12 75.37 74.30 2,514.44 476.51 N 1,265.53 E 1347.85 1.29 3237.18 74.81 74.21 2,538.64 501.17 N 1,353.01 E 1438.74 0.60 3333.38 75.04 74.75 2,563.66 526.03 N 1,442.52 E 1531.63 0.59 3426.52 74.89 75.20 2,587.83 549.35 N 1,529.39 E 1621.57 0.49 3520.96 74.33 75.25 2,612.89 572.57 N 1,617.44 E 1712.60 0.60 3615.49 74.45 76.02 2,638.33 595.16 N 1,705.63 E 1803.61 0.79 3713.36 74.27 75.76 2,664.71 618.13 N 1,797.03 E 1897.80 0.32 3801.83 74.33 74.90 2,688.65 639.70 N 1,879.43 E 1982.95 0.94 3896.78 74.21 73.84 2,714.39 664.32 N 1,967.44 E 2074.34 1.08 3990.57 74.36 72.16 2,739.80 690.72 N 2,053.77 E 2164.60 1.73 4084.36 74.40 71.20 2,765.05 719.11 N 2,139.52 E 2254.85 0.99 4178.54 74.39 70.72 2,790.39 748.70 N 2,225.27 E 2345.43 0.49 4273.84 74.30 71.90 2,816.11 778.11 N 2,312.19 E 2437.10 1.20 4369.09 74.27 74.30 2,841.91 804.76 N 2,399.91 E 2528.77 2.43 4462.91 73.80 74.20 2,867.71 829.25 N 2,486.73 E 2618.97 0.51 4557.75 73.85 75.21 2,894.13 853.27 N 2,574.59 E 2710.04 1.02 4653.01 73.74 75.19 2,920.72 876.64 N 2,663.03 E 2801.50 0.12 4747.08 73.27 75.84 2,947.43 899.20 N 2,750.36 E 2891.67 0.83 4842.59 73.29 74.87 2,974.91 922.33 N 2,838.86 E 2983.11 0.97 4936.09 73.26 73.90 3,001.81 946.43 N 2,925.09 E 3072.65 0.99 5031.09 73.29 72.83 3,029.15 972.47 N 3,012.27 E 3163.63 1.08 5125.66 73.83 71.89 3,055.92 999.96 N 3,098.70 E 3254.29 1.11 5220.44 74.30 70.84 3,081.94 1,029.08 N 3,185.06 E 3345.33 1.18 5315.54 74.33 71.12 3,107.65 1,058.92 N 3,271.62 E 3436.76 0.29 5409.67 74.31 71.40 3,133.09 1,088.04 N 3,357.44 E 3527.29 0.29 5504.42 74.36 71.16 3,158.67 1,117.32 N 3,443.85 E 3618.41 0.25 5598.32 74.30 71.41 3,184.04 1,146.33 N 3,529.48 E 3708.72 0.26 5693.20 74.28 73.29 3,209.73 1,174.02 N 3,616.51 E 3800.02 1.91 5788.33 74.42 73.92 3,235.39 1,199.88 N 3,704.39 E 3891.62 0.65 5883.37 74.31 74.48 3,261.01 1,224.80 N 3,792.45 E 3983.14 0.58 5977.51 74.30 74.40 3,286.47 1,249.11 N 3,879.76 E 4073.77 0.08 6072.19 74.27 74.73 3,312.12 1,273.36 N 3,967.61 E 4164.90 0.34 6167.31 74.51 74.54 3,337.71 1,297.64 N 4,055.95 E 4256.51 0.32 6262.20 74.01 75.05 3,363.45 1,321.59 N 4,144.09 E 4347.83 0.74 6358.03 73.59 75.48 3,390.19 1,345.00 N 4,233.08 E 4439.83 0.61 6451.44 73.56 74.17 3,416.60 1,368.45 N 4,319.56 E 4529.42 1.35 INSITE V8.1.10 Page 2Job No:AK-XX-0902024895 Well Name:2L-308 (BERTHA)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6546.47 73.59 73.92 3,443.47 1,393.51 N 4,407.20 E 4620.57 0.25 6641.55 73.54 73.37 3,470.37 1,419.19 N 4,494.70 E 4711.76 0.56 6736.94 73.59 72.49 3,497.36 1,446.04 N 4,582.16 E 4803.24 0.89 6830.94 73.54 72.01 3,523.96 1,473.53 N 4,668.03 E 4893.36 0.49 6926.96 73.65 71.28 3,551.08 1,502.54 N 4,755.45 E 4985.39 0.74 7021.18 74.13 71.01 3,577.22 1,531.79 N 4,841.11 E 5075.80 0.58 7115.64 74.10 71.12 3,603.08 1,561.27 N 4,927.05 E 5166.53 0.12 7209.72 74.07 72.28 3,628.88 1,589.68 N 5,012.95 E 5256.93 1.19 7305.70 74.04 73.12 3,655.24 1,617.12 N 5,101.06 E 5349.19 0.84 7399.54 74.10 73.24 3,681.00 1,643.23 N 5,187.43 E 5439.42 0.14 7494.36 74.01 74.10 3,707.05 1,668.87 N 5,274.93 E 5530.59 0.88 7589.20 74.04 73.80 3,733.15 1,694.08 N 5,362.55 E 5621.77 0.31 7684.95 73.95 73.56 3,759.55 1,719.94 N 5,450.88 E 5713.80 0.26 7779.59 74.04 73.00 3,785.64 1,746.11 N 5,538.01 E 5804.77 0.58 7874.02 74.07 73.86 3,811.59 1,772.01 N 5,625.03 E 5895.56 0.88 7968.10 74.07 73.98 3,837.41 1,797.06 N 5,711.96 E 5986.02 0.12 8062.53 74.10 74.08 3,863.30 1,822.05 N 5,799.26 E 6076.83 0.11 8157.11 74.04 74.01 3,889.26 1,847.05 N 5,886.71 E 6167.78 0.10 8252.61 74.01 73.19 3,915.54 1,872.97 N 5,974.78 E 6259.59 0.83 8347.05 74.04 72.48 3,941.54 1,899.76 N 6,061.53 E 6350.37 0.72 8442.45 74.52 71.95 3,967.38 1,927.81 N 6,148.97 E 6442.15 0.73 8536.17 74.55 72.26 3,992.37 1,955.57 N 6,234.93 E 6532.43 0.32 8631.70 74.60 73.05 4,017.78 1,983.02 N 6,322.83 E 6624.49 0.80 8727.55 74.63 74.42 4,043.21 2,008.91 N 6,411.55 E 6716.90 1.38 8821.58 74.07 76.26 4,068.58 2,031.82 N 6,499.14 E 6807.42 1.98 8915.47 74.07 77.65 4,094.35 2,052.20 N 6,587.09 E 6897.58 1.42 9009.09 74.07 77.71 4,120.05 2,071.41 N 6,675.04 E 6987.42 0.06 9104.13 74.04 77.21 4,146.15 2,091.25 N 6,764.24 E 7078.64 0.51 9198.53 74.10 75.31 4,172.07 2,112.81 N 6,852.42 E 7169.33 1.94 9292.04 74.07 73.61 4,197.71 2,136.90 N 6,939.05 E 7259.25 1.75 9386.03 73.95 73.41 4,223.60 2,162.55 N 7,025.69 E 7349.60 0.24 9480.30 74.06 73.47 4,249.58 2,188.38 N 7,112.55 E 7440.22 0.13 9575.43 74.12 73.84 4,275.66 2,214.12 N 7,200.34 E 7531.70 0.38 9669.96 74.10 72.63 4,301.54 2,240.35 N 7,287.39 E 7622.61 1.23 9763.63 74.04 72.59 4,327.25 2,267.27 N 7,373.35 E 7712.66 0.08 9858.60 74.13 72.65 4,353.29 2,294.55 N 7,460.51 E 7803.96 0.11 9954.88 74.10 72.53 4,379.64 2,322.26 N 7,548.87 E 7896.54 0.12 10049.51 74.16 72.63 4,405.52 2,349.51 N 7,635.72 E 7987.53 0.12 10143.83 74.15 72.97 4,431.27 2,376.34 N 7,722.39 E 8078.25 0.35 10239.02 74.21 73.22 4,457.22 2,402.97 N 7,810.02 E 8169.82 0.26 10333.73 74.19 73.50 4,483.01 2,429.06 N 7,897.34 E 8260.95 0.29 10428.03 74.13 73.80 4,508.75 2,454.60 N 7,984.39 E 8351.66 0.31 10523.21 74.10 74.45 4,534.80 2,479.64 N 8,072.44 E 8443.21 0.66 10617.65 74.10 73.66 4,560.67 2,504.59 N 8,159.77 E 8534.04 0.80 10712.39 74.04 73.45 4,586.68 2,530.38 N 8,247.15 E 8625.13 0.22 INSITE V8.1.10 Page 3Job No:AK-XX-0902024895 Well Name:2L-308 (BERTHA)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10807.80 74.10 73.55 4,612.86 2,556.44 N 8,335.11 E 8716.88 0.12 10900.85 73.93 72.96 4,638.49 2,582.21 N 8,420.77 E 8806.32 0.64 10994.59 74.60 73.65 4,663.91 2,608.13 N 8,507.20 E 8896.54 1.01 11091.02 74.49 73.23 4,689.61 2,634.62 N 8,596.28 E 8989.48 0.44 11185.19 74.64 74.48 4,714.67 2,659.86 N 8,683.47 E 9080.25 1.29 11279.47 74.15 74.05 4,740.03 2,684.49 N 8,770.88 E 9171.05 0.68 11374.49 74.22 73.18 4,765.93 2,710.28 N 8,858.59 E 9262.47 0.88 11470.49 74.24 72.29 4,792.02 2,737.70 N 8,946.81 E 9354.84 0.89 11562.72 74.15 71.97 4,817.14 2,764.93 N 9,031.27 E 9443.53 0.35 11657.13 73.62 71.79 4,843.34 2,793.14 N 9,117.47 E 9534.17 0.59 11752.19 73.71 71.91 4,870.08 2,821.55 N 9,204.16 E 9625.33 0.15 11846.95 73.74 72.28 4,896.64 2,849.52 N 9,290.71 E 9716.24 0.38 11942.07 73.70 73.03 4,923.30 2,876.74 N 9,377.87 E 9807.52 0.76 12036.36 73.65 73.90 4,949.81 2,902.49 N 9,464.61 E 9898.00 0.89 12129.96 74.16 74.12 4,975.75 2,927.27 N 9,551.06 E 9987.93 0.59 12224.88 74.89 75.88 5,001.08 2,950.94 N 9,639.42 E 10079.39 1.95 12319.96 75.25 78.33 5,025.58 2,971.44 N 9,728.97 E 10171.12 2.52 12413.37 75.37 80.66 5,049.27 2,987.91 N 9,817.80 E 10261.06 2.42 12507.42 75.25 83.50 5,073.13 3,000.44 N 9,907.90 E 10351.12 2.92 12602.52 75.25 86.71 5,097.35 3,008.29 N 9,999.52 E 10441.35 3.26 12696.15 75.19 90.82 5,121.24 3,010.24 N 10,090.01 E 10528.87 4.24 12791.71 74.46 95.02 5,146.27 3,005.55 N 10,182.09 E 10616.09 4.31 12885.33 74.69 99.04 5,171.18 2,994.51 N 10,271.64 E 10699.13 4.15 12980.98 75.75 104.25 5,195.59 2,975.84 N 10,362.18 E 10781.02 5.38 13076.00 76.25 108.09 5,218.59 2,950.16 N 10,450.71 E 10859.04 3.96 13169.88 76.60 110.46 5,240.63 2,920.04 N 10,536.85 E 10933.54 2.48 13264.84 76.37 113.35 5,262.82 2,885.60 N 10,622.50 E 11006.38 2.97 13359.14 74.39 115.29 5,286.63 2,848.03 N 10,705.64 E 11075.95 2.89 13453.88 73.33 115.83 5,312.96 2,808.77 N 10,787.74 E 11144.04 1.25 13547.72 73.98 114.37 5,339.37 2,770.57 N 10,869.28 E 11211.90 1.65 13643.13 73.80 112.67 5,365.85 2,733.99 N 10,953.33 E 11282.61 1.72 13704.01 73.68 113.10 5,382.90 2,711.27 N 11,007.17 E 11328.10 0.71 13797.81 74.64 112.38 5,408.50 2,676.39 N 11,090.40 E 11398.48 1.26 13838.49 76.39 113.54 5,418.67 2,661.02 N 11,126.66 E 11429.11 5.11 13889.76 78.39 114.46 5,429.87 2,640.67 N 11,172.36 E 11467.43 4.28 13933.91 80.03 115.68 5,438.13 2,622.29 N 11,211.64 E 11500.13 4.60 13985.41 81.77 116.39 5,446.28 2,599.97 N 11,257.33 E 11537.89 3.64 14029.41 82.64 116.65 5,452.24 2,580.51 N 11,296.34 E 11570.02 2.06 14076.37 83.16 118.09 5,458.05 2,559.09 N 11,337.72 E 11603.90 3.24 14122.04 83.47 120.24 5,463.37 2,536.98 N 11,377.33 E 11635.88 4.72 14175.05 83.16 121.69 5,469.54 2,509.89 N 11,422.47 E 11671.81 2.78 14218.79 83.02 123.65 5,474.80 2,486.46 N 11,459.02 E 11700.48 4.46 14274.96 83.29 125.46 5,481.49 2,454.82 N 11,504.95 E 11735.91 3.24 14313.24 83.71 126.49 5,485.83 2,432.48 N 11,535.73 E 11759.34 2.89 14359.42 84.09 128.21 5,490.74 2,404.63 N 11,572.23 E 11786.75 3.79 INSITE V8.1.10 Page 4Job No:AK-XX-0902024895 Well Name:2L-308 (BERTHA)Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14403.73 84.71 129.33 5,495.06 2,377.01 N 11,606.61 E 11812.19 2.88 14462.19 85.81 132.29 5,499.89 2,338.94 N 11,650.70 E 11844.07 5.39 14503.00 86.05 133.24 5,502.79 2,311.30 N 11,680.59 E 11865.18 2.40 14551.46 86.48 133.84 5,505.95 2,277.99 N 11,715.64 E 11889.70 1.52 14575.53 87.35 134.04 5,507.24 2,261.31 N 11,732.95 E 11901.74 3.71 14597.83 88.13 134.81 5,508.12 2,245.71 N 11,748.86 E 11912.73 4.91 14646.52 90.95 138.27 5,508.51 2,210.38 N 11,782.34 E 11935.18 9.17 14693.86 91.27 139.04 5,507.59 2,174.85 N 11,813.61 E 11955.44 1.76 14788.91 92.12 140.04 5,504.78 2,102.56 N 11,875.26 E 11994.78 1.38 14883.75 91.30 144.55 5,501.95 2,027.58 N 11,933.22 E 12029.83 4.83 14977.27 90.00 148.32 5,500.89 1,949.68 N 11,984.91 E 12058.04 4.26 15028.25 89.91 152.57 5,500.93 1,905.34 N 12,010.06 E 12069.99 8.34 15072.51 88.76 152.64 5,501.44 1,866.05 N 12,030.42 E 12078.73 2.60 15123.59 90.10 154.50 5,501.95 1,820.31 N 12,053.15 E 12087.98 4.49 15167.12 90.68 156.29 5,501.66 1,780.73 N 12,071.27 E 12094.49 4.32 15219.12 91.13 160.26 5,500.83 1,732.44 N 12,090.52 E 12099.68 7.68 15259.65 90.91 161.76 5,500.11 1,694.13 N 12,103.70 E 12101.79 3.74 15312.55 91.63 165.09 5,498.94 1,643.45 N 12,118.79 E 12102.32 6.44 15345.47 90.77 165.75 5,498.25 1,611.59 N 12,127.07 E 12101.50 3.29 15403.85 90.17 167.84 5,497.77 1,554.76 N 12,140.41 E 12098.66 3.72 15448.32 90.05 169.65 5,497.69 1,511.15 N 12,149.09 E 12094.98 4.08 15509.91 88.14 171.73 5,498.66 1,450.38 N 12,159.05 E 12087.81 4.58 15541.03 88.84 171.43 5,499.48 1,419.61 N 12,163.60 E 12083.70 2.45 15636.05 88.26 171.45 5,501.88 1,325.68 N 12,177.74 E 12071.40 0.61 15737.59 91.42 171.76 5,502.17 1,225.24 N 12,192.56 E 12057.97 3.13 15832.23 91.51 172.10 5,499.75 1,131.57 N 12,205.85 E 12044.92 0.37 15927.16 89.78 173.31 5,498.68 1,037.42 N 12,217.90 E 12030.55 2.22 16022.15 89.35 173.98 5,499.40 943.02 N 12,228.41 E 12014.63 0.84 16118.12 89.55 173.47 5,500.32 847.63 N 12,238.90 E 11998.42 0.57 16211.70 90.34 174.10 5,500.41 754.60 N 12,249.03 E 11982.52 1.08 16306.38 90.44 175.75 5,499.77 660.29 N 12,257.41 E 11964.58 1.75 16402.33 90.72 174.50 5,498.79 564.70 N 12,265.56 E 11946.07 1.33 16495.86 91.16 169.88 5,497.26 472.07 N 12,278.27 E 11932.75 4.96 16589.74 90.75 169.18 5,495.69 379.77 N 12,295.32 E 11923.70 0.86 16685.28 90.72 166.83 5,494.47 286.33 N 12,315.18 E 11917.03 2.46 16780.79 91.20 166.71 5,492.87 193.37 N 12,337.03 E 11912.41 0.52 16875.56 92.43 166.32 5,489.87 101.26 N 12,359.12 E 11908.26 1.36 16970.27 92.31 168.20 5,485.95 8.96 N 12,379.99 E 11902.88 1.99 17032.45 90.04 167.49 5,484.68 51.81 S 12,393.08 E 11898.71 3.82 INSITE V8.1.10 Page 5Job No:AK-XX-0902024895 Well Name:2L-308 (BERTHA)Survey Report 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 74.00 degrees (True) - A total correction of 0.00 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 17,032.45 feet is 12,393.18 feet along 90.24 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 6Job No:AK-XX-0902024895 Well Name:2L-308 (BERTHA)Survey Report
