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214-144
P 7ro • Sylte, Hanna 2 8 8 4 9 From: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Sent: Tuesday, November 28, 2017 10:27 AM To: Sylte, Hanna Subject: [EXTERNAL]KRU 2N-336 (PTD 2141440) Sundry 315-063 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. SCANNED r u RBDIVIS DEC 0 6 2017 eo v�cc� • • RECEIVED ConocoP illip OCT 2 3 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 cliq Mg 1 12O1 September 28, 2015 Commissioner Cathy Foerster N 33,6 Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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, }c:�6776. Martin Walters ConocoPhillips Well Integrity Projects Supervisor t • • 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 1 STATE OF ALASKA ALL OIL AND GAS CONSERVATION COASSION REPORT OF SUNDRY WELL OPERATIONS 2 8 8 4 9 1.Operations Performed: Abandon r Repair w ell17 Frac Stimulation p Plug Perforations Perforate �® Other ,r Alter Casing f Pull Tubing r Stimulate- Frac Waiver Time Extension fl Change Approved Program rOperat. Shutdown r Stimulate-Other ' Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p- Exploratory fl 214-144-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20693-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 375074 KRU 2N-336 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 12229 feet Plugs(measured) none true vertical 5384 feet Junk(measured) none Effective Depth measured 12220' feet Packer(measured) 7845, 7939 true vertical 5383' feet (true vertical) 4936,4971 Casing Length Size MD TVD Burst Collapse CONDUCTOR 105 16 133 133 SURFACE 2611 10.75 2638 2289 INTERMEDIATE 8075 7.625 8104 5033 LINER 4292 4.5 12220 5383 RECEIVED scANNED ; ,� .R ,'t APR 10 2015 Perforation depth: Measured depth: none /D3CC True Vertical Depth: none Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 7933 MD,4969 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 7845 MD and 4936 TVD PACKER-ZXP LINER TOP PACKER @ 7929 MD and 4971 TVD NIPPLE-DS NIPPLE @ 492 MD and 492 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9268'-11792' Treatment descriptions including volumes used and final pressure: 944844#of 16/20 frac sand pumped 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 rx Service r Stratigraphic 16.Well Status after work: Oil Fi Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG 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: 315-063 Contact Xuegin Yang a,265-6342 Email Xuequi.Yanq anconocophillips.com Printed Name Xue ui Ya Title Sr. Completion Engineer Signature Phone:265-6342 Date /� `els v RBDMS/ APR 1 0 y15 (---v)‘-/ / z_/6/2_o,, eo re.c_e, t1-1011_ Form 10-404 Revised 10/2012 Submit Original Only t E KUP PROD • 2N-336 ConocoP1 fillips ; Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(ft)(B) Act Btm(ftKB) ccmtin,illps 501032069300 TARN PARTICIPATING AREA PROD 91.33 11,978.50 12,229.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2N-336,3/19/20159:19-.09 AM SSSV:NIPPLE Last WO: 28.79 2/1/2015 Vertical schematic(actual) - ------ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag' Rev Reason:FRAC hipshkf 3/19/2015 Casing Strings Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 14.000 28.0 133.0 133.0 115.00 Welded • Casing XO Reducing;60.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread SURFACE 103/4 9.950 27.0 2,638.0 2,289.3 45.50 L-80 Hyd 563 .Ah-0.CONDUCTOR;28.0-133.0 Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth)TID(...Wt/Len(I...Grade -Top Thread INTERMEDIATE 75/8 6.875 28.7 8,104.0 5,032.6 29.70 L-80 Hyd 563 NIPPLE;492.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(TVD)...Wt/Len(I...Grade Top Thread W LINER 41/2 3.958 7,928.0 12,220.0 5,382.9 1260 C-110/L- Hydril 521/ 80 IBT-M 0' Liner Details SURFACE;27.0-2,638.0-, ` Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) GAS LIFT;3,003.4 7,928.0 4,967.0 67.82 SETTING SLV HRD SETTING SLEEVE 5.750 7,939.2 4,971.2 67.84 PACKER ZXP LINER TOP PACKER 4.810 7,950.0 4,975.3 67.86 NIPPLE RS PACK OFF SEAL NIPPLE 4.250 GAS LIFT;4,878.8 11 7,952.3 4,976.2 67.86 HANGER FLEX LOCK LINER HANGER 4.790 9,045.4 5,285.0 82.55 SWELL SWELL PACKER H-SELF ENERGIZE REACTIVE 3.980 GAS LIFT;6,258.8 PACKER 9,268.6 5,303.5 87.36 FRAC SLV EXPRESS FRAC SLEEVE#7(2.073"BALL SEAT) 2.073 GAS LIFT;7,2720 9,449.6 5,311.1 87.31 SWELL SWELL PACKER G-SELF ENERGIZE REACTIVE 3.940 • PACKER 9,632.7 5,320.2 86.95 FRAC SLV EXPRESS FRAC SLEEVE#6(2.063"BALL SEAT) 2.063 9,854.1 5,332.8 86.36 SWELL SWELL PACKER F-SELF ENERGIZE REACTIVE 3.910 GAS LIFT;7,732.7 PACKER Sim 10,038.5 5,336.5 90.66 FRAC SLV EXPRESS FRAC SLEEVE#5(1.948"BALL SEAT) 1.948 SLIDING SLEEVE;7,790.8- 10217.8 5,336.0 89.58 SWELL SWELL PACKER E-SELF ENERGIZE REACTIVE 3.930 PACKER y.. 10,401.0 5,338.3 88.88 FRAC SLV EXPRESS FRAC SLEEVE#4(1.823"BALL SEAT) 1.823 PACKER;7,6454 I::'- 10,621.6 5,341.7 89.21 SWELL SWELL PACKER D-SELF ENERGIZE REACTIVE 3.930 11 PACKER NIPPLE;7,904.5 A: 10,845.7 5,345.4 89.01 FRAC SLV EXPRESS FRAC SLEEVE#3(1.698"BALL SEAT) 1.698 LOCATOR;7,922.1 11,066.6 5,349.4 89.12 SWELL SWELL PACKER C-SELF ENERGIZE REACTIVE 3.940 PACKER MULE SHOE;7,932.2 11,210.0 5,351.9 88.87 FRAC SLV EXPRESS FRAC SLEEVE#2(1.573"BALL SEAT) 1.573 • 11,390.2 5,356.6 88.24 SWELL PACKER SWELL PACKER B-SELF ENERGIZE REACTIVE 3.940 - 11,613.4 5,366.2 87.58 FRAC SLV EXPRESS FRAC SLEEVE#1(1.448"BALL SEAT) 1.448 11,792.8 5,366.6 90.43 SWELL SWELL PACKER A-SELF ENERGIZE REACTIVE 3.920 i PACKER INTERMEDIATE;28.78,104.0-, l Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection . - TUBING-4 1/2 x 3 3 1/2 2.968 25.1 7,933.2 4,968.9 9.30 L-80 EUE 8rd-M 1/2 @60.21 Completion Details Nominal ID I I Top(ftKB) Top(TVD)(ftKB) Top Incl 13 Item Des Corn (in) 25.1 25.1 0.00 HANGER CAMERCON CCL TUBING HANGER 3.900 60.2 60.2 020 Casing XO 4-1/2"IBT-M Box x 3-1/2"EUE 8rd Pin Crossover sub 2.968 - ' Reducing I 492.4 492.4 0.67 NIPPLE DS NIPPLE 2.875 I • 7,790.8 4,915.0 67.51 SLIDING SLIDING SLEEVE DS PROFILE BOT 2.813 SLEEVE 7,845.4 4,935.7 67.73 PACKER BAKER PREMIER PACKER 2.880 7,904.5 4,958.1 67.79 NIPPLE D NIPPLE(RHC PLUG PULLED 3/2/15) 2.750 7,922.1 4,964.8 67.81 LOCATOR OD FLUTED NO GO SUB 2.968 I 7,932.2 4.968.6 67.83 MULE SHOE MULE SHOE W/LEG 3.000 Stimulations&Treatments Min Top ' Max Btm Depth Depth Top(TVD) Btm(WD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,845.0 11,792.0 5,345.4 5,366.6 Hydraulic 3/14/2015 PUMPED 287,760#OF 16/20 FRAC SAND INTO Fracture FIRST 3 STAGES Hydraulic Fracture;9,268.0 9,268.0 11,792.0 5,303.5 5,366.6 Hydraulic 3/17/2015 PUMPED 657,084#OF 16/20 FRANC SAND INTO Fracture FINAL 5 STAGES Mandrel Inserts St ati I N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (p8) Run Date Corn 1 3,003.4 2,492.3 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 1.000 0.0 1/28/2015 2 4,878.8 3,493.6 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 1.000 0.0 1/28/2015 3 6,258.8 4,182.5 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 1.000 0.0 1282015 4 7272.0 4,691.1 CAMCO KBMG 5.39 GAS LIFT DMY BK-5 1.000 0.0 1/28/2015 s s 5 7,732.7 4,892.5 CAMCO KBMG 5.39 GAS LIFT DMY BEK 0.000 0.0 2/28/2015 DCK-2 Hydraulic Fracture;10,845.0 Notes:General&Safety End Date Annotation NOTE: ,: LINER;7,928.0-12,220.0 2N-336 WELL WORK SUMMA, • DATE SUMMARY 2/28/2015 STAND BY FOR SNOW REMOVAL & HARDLINE CREW. SET DV @ 7733' RKB; GOOD TBG TEST. PHASE 3 WX MOVED IN RAPIDLY. SECURE WELL & EQUIPMENT. HUNKER DOWN IN UNIT&WAIT OUT STORM. 3/2/2015 STAND BY FOR SNOW REMOVAL. TBG & IA MITs PASSED. PULLED 2.75 CA-2 EQUALIZING PRONG & PLUG BODY @ 7905' RKB. LRS PUMPED 30 BBL DSL INJECTIVITY TEST: 5 BPM @ 1500 PSI; SEE PUMP REPORT. READY FOR FRAC. 3/14/2015 Performed fracture stimulation treatment© 20 bpm placing 287,760#of 16/20 frac sand into the first 3 stages. Well freeze protected w/20 bbls of diesel. Will reload for second half of frac. 3/17/2015 Performed fracture stimulation treatment @ 20 bpm placing 657,084#of 16/20 frac sand into the final 5 stages. Well freeze protected w/20 bbl's of diesel. 4/2/2015 TRAVEL FROM 3S PAD TO 2N, MIRU CTU #4, RIH TO DRY TAG 1ST FRAC SLEEVE AT 9242' CTMD, C/O WITH NIGHT CREW, JOB IN PROGRESS. 4/2/2015 MILLED 7 FRAC SLEEVES TO 11,586' CTMD USING SLICK DIESEL WITH 776 AND DIESEL GEL. BACK REAMED THROUGH ALL SLEEVES 3 TIMES AND DRY DRIFTED ALL SLEEVES. JOB IN PROGRESS. 4/3/2015 NIGHT CREW MILLED ALL 7 FRAC SLEEVES, FCO DOWN TO 12100' CTMD, PUMP FINAL 20 BBL GEL SWEEP AND CHASE OOH WHILE MAINTAINING 1:1 RETURNS, WASHING ALL GLM'S WHILE POOH, WELL F/P WITH DIESEL TO 12100' CTMD, READY FOR S/L, JOB IN PROGRESS. 4/4/2015 TAG @ 7969' RKB WITH 1.75" SAMPLE BAILER & MEASURED BHP @ 7939' RKB, IN PROGRESS. SBHP OF 2044 PSI MEASURED 4/5/2015 BRUSH n' FLUSH TO D-NIPPLE @ 7904' RKB; SET 2.75" CSV @ 7904' RKB; PULLED DV'S @ 7732' & 3003' RKB; SET OV @ 7732' RKB & GLV @ 3003' RKB. IN PROGRESS. 4/6/2015 MIT TBG TO 3000 PSI MIT PASSED JOB COMPLETED • i 0 0 0 0 0 0 0 0 0 0 c o 0 0 0 0 0 0 0 0 0 0 0 +, 0 -p r-LC) Cn N co LO N CO CO CO 00 O d Es O MMcocoS) ti CO N CO Cco co Co N LO LO CO Cc) 7r co co O cCOt LO LO Lrr fCr-- 00 ti �t co co co co = LL N N N O O O O O O O 3c- cu c V = CN- N O O O O O O O O O O ct2Ecco ' 0 0 0 0 0 0 0 0 0 0 0 c * 0 0 0 0 0 0 0 0 0 0 0 .L.. O d :- , .- NCO 00OM ! U. 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N O .c C R ° L C c - O -c.., C Cn `-o 'C- p p ° ?� 7 ,E3• E EC) s� -ccs E G o 2 as E aia c. 0 zN E cC E a > 9 c� o c E a i c•` Ca co c o cn • a0 `ate a0 =a Go in 0 ct c0 c2 sc\i • 2 Q °s�. Ln .Y.2 0_ •EN C0 •7.0 0 c ° L L p O (n .r o U (a 0 O O L • Q- U L ° L ° _ a) a) } 2 Q-C Q- C 2 cn LU U L 0U d ° ° ° ca L • O O a ;L 73 .a T `)2 2 N C O -0 O 0 C ° ° CN C O 0) (a -0 °- N ° o E UE M O 7 0 'cC O- L p .E E o w c c CZ CC 'x -O C cp Cl) CO a) Q E E co o Q c U4-• C '� •O (_ 0 C ° C its 0 >" O OC� E co • (n CI)c E ° L E ° c a) oO L .E o 0 = M 1-0 O C ° O Cn ' •E ° 17; p ° o a) E -- co O a N , 0 ° co -,7 C3 — p- E Q .• (aO -t E L _c _ 2 O � O O O 4 a 2 0 -o 6 U F 7 (U = C C) -I- x 3 Q CC I U°) 0 • Client: ConocoPhillips Alaska Inc. Schiumberg Well:n 2N-336 Basin/Field: Colville-Prudhoe Basin/ Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Post-Job Well Completed: 3/17/2015 Date Prepared: 3/27/2015 1:51 PM Report ID: RPT-35882 Fluid Name&Volume Additive Additive Description Concentration Volume B882 Guar Polymer Slurry 6.4 Gal/1000 Gal 2,616.0 Gal F103 Surfactant 1.1 Gal/1000 Gal 454.0 Gal J475 Breaker 8.4 Lb/1000 Gal 3,410.0 Lb YF127ST:WF127 406,854 Gal J532 Crosslinker 5.3 Gal/1000 Gal 2,150.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 802.0 Gal M002 Additive 1.4 Lb/1000 Gal 577.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 141.0 Lb S522-1620 Propping Agent varied concentrations 975,580.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction - Water(Including Mix Water Supplied by Client)* 76.77665 % 66402-68-4 Ceramic materials and wares,chemicals 22.28327 % 64742-47-8 Distillates(petroleum),hydrotreated light 0.27389 % 9000-30-0 Guar gum 0.24692 % 56-81-5 1,2,3-Propanetriol 0.11475 % 1303-96-4 Sodium tetraborate decahydrate 0.06885 % 7727-54-0 Diammonium peroxodisulphate 0.06352 % 107-21-1 Ethylene glycol 0.03663 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 0.03426 % 111-76-2 2-butoxyethanol 0.01558 % 67-63-0 Propan-2-ol 0.01558 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.01377 % 1310-73-2 Sodium hydroxide(impurity) 0.01336 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) 0.00779% 68131-39-5 C12-15 alcohol ethyoxylated 0.00779 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) 0.00779 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite 0.00713 % 7647-14-5 Sodium chloride(impurity) 0.00692 % 7631-86-9 Silicon Dioxide 0.00439 % 10043-52-4 Calcium Chloride 0.00350 % 108-32-7 4-methyl-1,3-dioxolan-2-one 0.00219 % 91053-39-3 Diatomaceous earth,calcined 0.00161 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00042 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00037 % 10377-60-3 Magnesium nitrate 0.00032 % 68153-30-0 Amine treated smectite clay 0.00027 % 9002-84-0 poly(tetrafluoroethylene) 0.00018 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one 0.00017 % 7786-30-3 Magnesium chloride 0.00016 % 7447-40-7 Potassium chloride(impurity) 0.00011 % 2682-20-4 2-methyl-2h-isothiazol-3-one 0.00005 % 14808-60-7 Crystalline silica(impurity) 0.00003 % 14464-46-1 Cristobalite 0.00003 % Total 100% *Mix water is supplied by the client.Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. 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Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Xolor Items: ❑ Maps: upo.grayscale Items: pe s: ❑ Poor Quality Originals: ❑ Other: ❑ Other: rl'iBY: CMDate: ! / /s/ Project Proofing BY: Date: _ /s/ 44 1 Scanning Preparation 5 x 30 = c 50. + =TOTAL PAGES 159' (Count does not include cover sheet) ilap �BY: Date: Li_ ai /s/ 1 Production Scanning t20 Stage 1 Page Count from Scanned File: 1 (Count does include covers et) Page Count Matches Number in Scanning Preparation: YES NO BY: lirip Date: illcg,I 15- /s/ 04 Vt'1f3 Stage I If NO in stage 1, page(s) discrepancies were ound: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 411' NO TOTAL PAGES: 11 • / Digital version appended by: Meredith Michal Date: 1/(0)a/f c isi IP Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: cao/ Scanning is complete at this point unless rescanning is required. 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C J O 2 0 0 C d O Cl) r O a) O in Tx E E 1 ® co V U o } lc) 1 E o acl M C E a a. r `Z U I— r c E I-_ 10• _ N `o C z N L Co o co co C z' c > Co M > ')i C ai E Ca 2 .E 0 F E Ym w 3 m o co 0fn U 0) co co Q C C 0 1 a _• _0 g m CO o o E 0. a o a `° 0 Z a) 0 > 1 CI E 0 a 2 Q la z d V 3 v 0 ® N N co O M O) : - 2 O ku > m H c m .0 WE CO O o N o W 0 C N a) Ta. o a' 0 C ` = w '> E E z N �, a) N N co O d' a) m CW,) 0 Q? a)m D N z N C Z C f0 O N 0 0 • o Q o o 2 o p c C U g •2 0 J •) o a C m G 0 •0) d rn •0 L7 E 0 O a o 5 a s 0 E a p - LL E 2 o E m E E a 2 3 i 0 a 0 C.) 0 a ° 0 0 21 41 44 • 25467 ncc Prllli RECEIVED MAR 0 4 2015 TRANSMITTAL CONFIDFNTIAG D7ere' Nor 114 Th AOGCC FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7`h Ave., suite 100 LOG ND€ Anchorage AK 99510-0360 Anchorage, Alaska 99501 M.K.BER RE: 2N-336 DATE: 02/27/2015 Transmitted: Kuparuk River Unit, Alaska 2N-336 1 CD and 1 hardcopy report Halliburton-Surface data logging and End of well report- mud logging data for 2N-336; 01/27/2015; 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 Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.LemkeC5COP.com CC: 2N-336 transmittal folder, production well files, eSearch Receipt: I'22dLL 7.Ot.► 17) 6.€4teeetDat 11A1 ` . GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 RECEIVED • STATE OF ALASKA FEB 1 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANDCC la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development O Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ Stratigraphic Test Eli 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: •January 30,2015 214-144/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 •December 29,2014 50-103-20693-00• 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 113'FNL,982'FEL,Sec.3,T9N,R7E,UM •January 23,2015 KRU 2N-336 , Top of Productive Horizon: 8. KB(ft above MSL): 146.5'RKB 15.Field/Pool(s): 1993'FNL, 616'FEL,Sec.4,T9N,R7E, UM GL(ft above MSL): 117.7'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 841'FNL, 167'FWL,Sec. 10,T9N, R7E, UM 12220'MD/5383'TVD Tarn Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-460611 y- 5911896 Zone-4 •12229'MD/5384'TVD ADL 375074 TPI: x-455691 y- 5910043 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-456458 y- 5905911 Zone-4 nipple @ 492'MD/492'TVD 4293 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) 1108'MD/1103'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res/Neutron/Density, Sonic, Periscope 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# 1.031"wall 29' 105' 29' 105' 24" driven 10.75" 45.5# L-80 27' 2638' 27' 2289' 13.5" 1044 sx DeepCRETE,224 sx DeepCRETE 7.625" 29.7# L-80 26' 7764' 26' 4905' 9.875" 710 sx GasBLOK 7.625" 39# TN-110SS 7764' 8104' 4905' 5033' 9.875" included in above 4.5" 12.6# TN-110SS/L-80 7928' 12220' 4967' 5383' 6.5" uncemented liner 24.Open to production or injection? Yes Q 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/ND) 3.5 7931' 7845'MD/4936'TVD uncemented liner from 7968'-12220'MD 4982'-5383'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No } COMP DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1.I 1 2 none 2Int 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No a 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 Revised 10/2012 CONTINUED ON REVERSE '/46 42--(1l13- Sub it original only V rG. 3//q/i 5 .e 3d,#:5--- RBDMSJ\ FEB 13 2015 G 29 GEOLOGIC MARKERS(List all formations and mar. !countered) 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results Attach separate sheets to this form,if Permafrost-Bottom 1108' 1103' needed,and submit detailed test information per 20 AAC 25 071. Campanian Sand 3069' 2529' Iceberg 6509' 4308' Top Bermuda 8363' 5124' Heel Target 9064' 5287' N/A Formation at total depth: Bermuda 31. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,cement detail reports 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. _„?IS I Contact: Steve Shultz @ 263-4297 Email- Steve.Shultzcontractor.conocophillips corn Printed Name G. L.Alvord /es-/715,4 Title Alaska Drilling Manager Signature 'fes CAPhone 265-6120 Date -47-/C 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 2N-336 Trip (Prognosed and Actual Depths) Casing Shoes,Lateral Windows,Lateral Total Depths, Sidetracks,Markers,Formation Tops and Faults Top./Marker I MD-prognosis I TVD-prog I TVDSS-prog I Comment I MD actual I TVD actual TVDSS I -.-tc Prcgresis I Comment 13-112"2N-336 Surface Section(prognosed depthser wp03) 10 3,4 Casing Shoe I 2 544 I 2 300 I -2 154 I I 2 638 I 2 290 I -2 114 I -10 I shallow 9-718"2N-336 Intermediate Section(prognosed depths per wp03) 0-80 2 960 2 476 -2 330 2 967 2 472 -2 326 -4 shallow Campanian Sand 3 055 2 529' -2 383 3 069 2 529 -2 383 -- deep C-50 5 290 3 705 -3 559' 5 396' 3 753 -3 607 48 deep C-40 5 815 3 969 -3 823' 5 818' 3 963' -3 817 -6 shallow 0-37 6 129 4 127 -3 981 6 125' 4 116 -3 970 -11 shallow Iceberg 6 443 4 286 -4 140 6 509' 4 308 -4 162 22 deep T-7 7 335 4 732 -1 586 7 334 4 721 -4 575 -11 shallow T-4 1 7 846 4 955 -4 809 7 856 4 940 -4 794 -15 shallow 7.5'8"Casing Shoe - -- -- - 8 104' 5 033 -4 887 -- -- Intermediate TD 8 181 5 076 -4 930 8 114 5 035 -4 889 -41 shallow 6-112"2N-336 Production Lateral Section(prognosed depths per wp03) Top Berm Target 8 481 5 166 -5 020 8 363 6 124 -4 978 -42 shallow Top Sets Berm 8 854 5 263 -5 117 8 584 5 192 -5 046 -71 shallow Heel Target 9 228 5 316 -5 170 9 064 5 287 -5 141 -29 shallow TD Toe Target 11 732 5 421 -5 275 , RECEIVED FEB 1 9 2015 Tarn 2N-336 Trip -.•p103) CC Grass Roots Topset Horizontal Muttl-Starpe Frac'd Producer —. a•••19 ConocoMilip Proposed Wellbore Schematic CAMERON 4 .;tree,top),:int tr.4;$ 12 6,V IBM, n .e 17Ver .•:frir 1.1.1C equprren1) Shuits VIiir2di 5 _ { 1 le Existing Cemented Conductor: 16 62 6#H-40 78 MO Unica OS Nipple 2. 7 ' 500'MD 13-112"Surface Hole —i 3',".1"Canicc Ktit1C3 k:z Surface Casing: — Actual Surface Hole — 10-3/4"45.5,1 L-BO Hydril 563 Total Depth 2,638'MD 12,289TVD 2,648' MD i 2,295'TVD 3 v.1"Cameo KBMIG —J A, . . . . . . . . SND 6.10.0 PPG Tubing: ''TP IT'"h 3'1"-1" BF/':.-- ' ' 71 34/3"8.3k L-80 EUE8RD ilution 4-W l2.6#L-80 IBTM top joint to surface — ••,:,El--. •, 9-718"Intermediate Hole 4 &CO 1Cp V WW1 a 4,-5,30u.kip i 4.03'abut!C-37) 3 1,'-1"Cantu) 7,7-1 KINAG,V'OCK.2 50V --\ I C4i0i1i 4.6.P 0,04.00 j.4.*i;.iim.; . : : :::::-:-: : : : : : : :.:.:.:.:.:•:•:,:•:.:•.•:•:•:•.•.• . . . , . . . . . . , . . . . . . .•. . . . . .•. .•.•.•.•.•.•.•.,.....•. .•.•.•.•...•.•,•.•. . ...•...•.•.•.•.•.•.•.•.•.•.•... . Dakar CMU Siiiiinq Skew CLOSED vd 23112 Cameo D5'Prank.@ 7790'MD . .';:.' .+7N 15')1 7-ST,Daly=Prettier Packer 3 l',"Cameo D .11:- 1.i.:..,i 7m4i.kip Nipple 2.13'.cin 7-Fefr x 4.-1i kialor Roc Lrxic Lace twrgri- .... 7 UP irwr 14p piKier ,,,o'RS Ni ppl e, 7 9136'MD Actual Intermediate Casing Depth: 978r Actual Total Depth L-80&400'TN110SS 39#-all 8,114'MO/5 036'IVO(Cii 70' Hydril 563 connections of lidliwr.m... .1.1',..1- *?•11":...11...... ....... .........:............8104.................1.i.........i:....:I;:: .. ::...:...:.... . . . :::::::::•:•:•:::•:•:•:•:•:•:•: •. 04:.:i:.:: ::.::.:.:::.:.:4 'MD15 033'TVD 0)WY' . . . . . :::::::::::i:*;::::.: ::.:*;:..•1.L.::•. : ....\,„ • • • . • •••••• ••• I °In"'11°41.S* 111 ilfiiikil::6A1P0iiiiiiiNilitt::::‹. ••• • • • •-• ••.•. . . . . . . . .• •.•.• •.•.•.•.•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:::;.• 1.111 IIII IIIII 1111 MI 0 0 0 0 0 0 .•.•. a:.i i Aliciilil.1.1F4(OFiiit:06.04:ti:i.::PiP;;Pi;k ki:r.1010iIi?.!?::i :::i::.::.::j2i4440iok ino,00133'? is 3)iii000.1?iiitifyir:131641:::.*:::::::Y.::::.:::::i*::::::::.::::::::::::::•:4:iir:11:43.0:18.6.1::•:*::::iiliz,45,..koiaOlvb::::: ,O:4.:-:::g:Pj :.3.97:Sjl.ti'3j:::.::::::::::iiiii::::::::::::::::i::.::.:i:::.:.::::: ,00r:00;igte:*j::i::.:i:i:i:i::::::::i: :i::iii::::::i:::::::. '2 ConocoPhiIIips Time Log & Summary FEB' 19 2015 Wellview Web Reporting Report A 1G CC Well Name: 2N-336 Rig Name: NABORS 9ES Job Type: DRILLING ORIGINAL Rig Accept: 12/27/2014 12:00:00 PM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/27/2014 24 hr Summary Rig was released from 2N-337 C at 12:00 hrs/moving to 2N-336. 12:00 15:00 3.00 MIRU MOVE RURD P Rig released from 2N-337C at 12:00 hrs/moving rig to 2N-336. Prep for Rig move. 15:00 16:00 1.00 MIRU MOVE OTHR T Suspend operations for clean up of 1 qt spill in secondary containment. Vac truck hose flash froze,when the operator pulled the Cam Lok ears open diesel sprayed on his clothes and ran down into secondary containment. Discussed working extreme cold temperatures, observations for froze bite 16:00 18:30 2.50 MIRU MOVE MOB P Continue to pull pit section away from sub base. Clean and clear location. 18:30 20:30 2.00 MIRU MOVE MOB P Pull rig off well and remove equipment from around well. 20:30 00:00 3.50 MIRU MOVE MOB P Prep 2N-336 for pulling rig over well 12/28/2014 Spot rig over 2N-336 and R/U, Rig accepted at 06:00 hrs. Test starting head, N/U diverter and load 5"DP, HWDP and DC into the pipe shed. 00:00 06:00 6.00 MIRU MOVE RURD P Pull sub over well,set down and marry up pit module.Spot cuttings box and diesel tank. Berm up all containments and completePre-spud check list. Accept Nabors 9es at 06:00 hrs 06:00 09:00 3.00 MIRU MOVE SEQP P Test Lower starting head seals at 250-psi for 10 minutes-good test. Test upper o-ring seal-failed -allow to set and warm up for 1.5 hrs-Re test and passed. 09:00 12:00 3.00 MIRU MOVE RURD P Install 4"annulus valves onto conductor. NU diverter Tee. Take on mud to the pits, prep pipe shed for 5" drill pipe and Schlumberger BHA assemblies. 12:00 15:00 3.00 MIRU MOVE NUND P Discuss working in extreme cold and using the buddy system. NU diverter and rig up lines. 15:00 20:00 5.00 MIRU MOVE NUND P NU diverter,4"valves and riser, continue to load pits with spud mud. 20:00 00:00 4.00 MIRU MOVE NUND P Finish NU of diverter, Load 60 joints of 5"DP, 17 joints of HWDP,Jars and 3 joints of DC. Page 1 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/29/2014 24 hr Summary Install diverter, riser, build containment and test. Circulate through pits and test#1 mud pump. PU and stand back 5"DP and 5"HWDP in the derrick. PU BHA#1 and drill f/surface to 252'. PU 13 1/2"bit,motor and smart tools. 00:00 03:00 3.00 MIRU MOVE RURD P R/U diverter line and build containment. Finish loading containment in pipe shed. 03:00 08:00 5.00 MIRU MOVE PULD P P/U 5"DP and 5" HWDP and stand it back in the derrick. 08:00 09:00 1.00 MIRU MOVE BOPE P Function test diverter, diverter valve/ 9 seconds to open dieverter valve/ 20 seconds to close diverter. 09:00 15:30 6.50 MIRU MOVE RURD P Install final section of diverter line.1.0. Circulate mud through pits and test mud pump#1. 15:30 16:30 1.00 MIRU MOVE PULD P P/U BHA#1 /dumb iron for drill out/ 13 1/2"bit Bit sub XO 1 std-5" HWDP. 16:30 19:00 2.50 48 99 SURFA( DRILL DRLG P Drill surface f/48' t/99' GPM 300 PSI 150 RPM 40 WOB 5 k PUW 37 k SOW 37 k Bit hrs 1.54 Mud wt 9.6 Vis 300. 19:00 20:30 1.50 SURFAC DRILL PULD P Rack back 1 std of HWDP/PU 3 jts of 7"flex DC/ PU 1 std of HWDP. 20:30 22:30 2.00 99 251 SURFA( DRILL DDRL P Drill f/99' t/251' WOB 5- 10 k GPM 600 PSI 650 RPM 70 PUW 48k SOW48k ROT 48k Mud wt 9.6 Bit hrs 1.54. 22:30 00:00 1.50 SURFAt DRILL PULD P PU BHA#2 Bit/ Motor/Smart tools. 12/30/2014 MU BHA#2-RIH&take gyro surveys @ 121'&217'-Drilled 13 1/2"hole f/251'to 1274'(Obseved 9637 units of Hydrate gas @ 1228')-POOH f/1274'to 909'on elevartors-Back ream f/956'to 399'(to have well in safe condition due to pending phase 3 weather conditions 00:00 04:00 4.00 40 121 SURFA( DRILL PULD P Continue MU BHA#2-MU bit- Scribe MWD&Gyro 04:00 06:30 2.50 121 251 SURFA( DRILL SRVY P Take gyro survey @ 121'-Pump @ 500 gpm's @ 580 psi-RIH to 217'& take gyro survey-pump @ 500 gpm @ 580 psi-RIH to 251' 06:30 12:00 5.50 251 675 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/251' to 675'MD ADT-2.88 hrs. =ART-2.38 hrs. AST-.5 hrs. WOB 15 k GPM 500 @ 780 psi RPM 50 String wt. PU 70 SO 65 ROT 70 Torque on/off btm.- 3/1 k ft/lbs 12:00 19:30 7.50 675 1,274 SURFA( DRILL DDRL P Drilled 13 1/2"hole f/675'to 1274' MD 1268'TVD ADT-5.04 hrs=ART-2.26 hrs.AST -2.78 WOB 15/20 k GPM 600 to 630 @ 1225 to 1320 psi String wt PU 91 SO 85 ROT 86 Torque on/off btm.-3/1 k ft/lbs Observed 9637 units gas @ 1228' Page 2 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 1,274 956 SURFA( DRILL TRIP T POOH f/1274'to 956'-PU wt 91 SO wt 85-25k over pull @1019'& 997'-35 k over pull @ 909'-unable to work thru tight spot @ 909'-RIH to 956' Note: Pulling out of hole due to Phase conditions(Phase 3 pending) 20:30 00:00 3.50 956 399 SURFA( DRILL REAM T POOH back reaming f/956'to 399' @ 400 gpm @ 480 psi w/40 rpm's @ 12 k torque-PU wt 91 SO wt 78 Rot wt 78-Slight packing opff& torque @ 876' 12/31/2014 Finish L/D BHA,Wait on weather phase 3 weather conditions, monitor well on trip tank. 00:00 03:30 3.50 399 0 SURFA( DRILL PULD T L/D BHA Secure well, Monitor on trip tank 03:30 12:00 8.50 0 0 SURFA( DRILL OWFF T Phase 3 weather, monitor well on trip _tank, all work suspended 12:00 00:00 12.00 0 0 SURFA( DRILL OWFF T Phase 3 weather, monitor well on trip tank, all work suspended 01/01/2015 Cont.to wait on weather(Phase 3 lifted @ 0400 hrs)Dig out rig from blow-PU BHA#3(same as#2 w/o gyro pulse probe)-RIH to 920'Wash&ream f/920'to 1274'-Drill 13 1/2"hole f/1274'to 1804'-Repair mud pump 00:00 04:00 4.00 0 0 SURFA( DRILL OWFF T Phase 3 weather-monitor well on trip tank-all work suspended 04:00 08:00 4.00 0 0 SURFA( DRILL OTHR T Phase 3 lifted-Dig out rig from blowing snow-Prep to PUI BHA- Remove probe from Gyro pulse tool 08:00 12:00 4.00 0 217 SURFA( DRILL PULD T MU BHA#3-bit, motor, NM stab, XO,XO, Gyro pulse collar, TeleScope,ARC,XO, NM stab,XO, 3 NM flex DC's to 217' 12:00 13:30 1.50 217 920 SURFA( DRILL TRIP T RIH w/BHA f/217'to 920'-running HWDP jars&2 stds 5"DP f/derrick -tight spot f/920'to 956'-Pull up to 920' 13:30 15:00 1.50 920 1,274 SURFA( DRILL REAM T Wash&Ream f/920'to 1274'w/600 gpm @15 psi w/60 rpm's w/4 to 6 k torque-Rot wt. 75 PU wt 85 SO wt 78-Survey @ 1274' 15:00 18:00 3.00 1,274 1,513 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1274' to 1513' MD 1495'TVD ADT- 1.65 hrs.=ART- AST-1.23 hrs ART-.42 hrs. WOB 15 k RPM's 60 GPM 600 @ 1300 psi String wt. PU 90 SO 85 Rot 85 Torque on/off btm.-4 to 5/3.5 k ft/lbs Page 3 of 28 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 18:00 22:00 4.00 1,513 1,804 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1513' to 1804'MD 1747'TVD ADT-2.76 hrs. =AST-2.19 hrs. ART-.57 hrs. WOB 10/15 k RPM's 45 GPM 630 @ 1660 psi String wt. PU 97 SO 88 Rot 90 Torque on/off btm.-4.5/3.5 k ft/lbs 22:00 00:00 2.00 1,804 1,804 SURFA( DRILL RGRP T Repair mud pump#2-change valve &seat 01/02/2015 Drilled 13 1/2"hole f/1804'to 2596'-Repair drag chain-Drill to 2648'-Circ up samples @ 2606'&2648'- Flow check-BROOH f/2648'to 2392' 00:00 12:00 12.00 1,804 2,098 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/1804' to 2425' MD 2174'TVD ADT-7.11 hrs. =ART-1.9 hrs. AST-5.17 hrs WOB 15 k RPM's 60 GPM 630 to 650 @ 1590 to 1750 psi String wt PU 100 SO 90 ROT 95 Torque on/off btm.-6.5/4 k ft/lbs 12:00 16:00 4.00 2,098 2,596 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/2425' to 2596' MD WOB 10 to 20 k RPM 60 GPM 650 @ 1750 psi String wt. PU 102 SO 92 ROT 96 Torque on/off btm.-6 to 8/4 to 5 k ft/Ibs 16:00 19:00 3.00 2,596 2,596 SURFA( DRILL RGRP T Repair drag chain in pit room 19:00 22:00 3.00 2,596 2,648 SURFA( DRILL DDRL P Drilled 13 1/2"hole w/motor f/2596' to 2648' MD 2295'TVD ADT-3.21 hrs(f/noon to 2130 hrs) WOB 10 to 20 k RPM 60 GPM 650 @ 1750 psi String wt PU 102 SO 92 ROT 96 Torque on/off btm.-6 to 8/4 to 5 k ft/lbs Note; Circulated btms up samples @ 2606'&2648'for Geo 22:00 22:30 0.50 2,648 2,648 SURFA( CASING OWFF P Pump up survey-Flow check- Grease wash pipe 22:30 00:00 1.50 2,648 2,392 SURFA( CASING CIRC P Circ 3 X btms up[@ 650 gpm @ 1380 psi w/60 rpm's w/5 k torque- Standing back 1 std/btms up f/ 2648'to 2392'- PU wt 100 SO wt 60 Rot wt. 94 01/03/2015 Cont. BROOH f/2390'to 217'-LD BHA-Made dummy run w/csg hanger-RU to Run 10 3/4"csg-Ran 10 3/4"csg to 1247' Page 4 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 2,392 835 SURFA( CASING REAM P Cont. BROOH f/2390'to 1521'@ 600 gpm @ 1350 psi w/60 rpm's w/ 4to6ktorque-Rot wt85-PUwt 90-SO wt 80-Worked thru tight spots @ 1930'& 1590'-BROOH f/ 1521'to 835'@ 400 gpm @ 715 psi w/60 rpm's w/2 to 4 k torque-Rot wt 75-PU wt 80-SO wt 70 06:00 09:00 3.00 835 271 SURFA( CASING REAM P Cont. BROOH f/835'to 271'@ 400 gpm @ 460 psi w/60 rpm's w/1 k torque-Rot wt 65-Pu wt 65-SO wt 60- Flow checked well @ top of HWDP-Well Static-Blow down TD -Stood back flex DC's 09:00 12:00 3.00 271 0 SURFA( CASING PULD P LD BHA#3 12:00 16:00 4.00 0 0 SURFA( CASING RURD P Clear rig floor of BHA tools-PU hanger&landing jt&make dummy run-RU Volant CRT-spider& elevators 16:00 16:30 0.50 0 0 SURFA( CASING SFTY P Held PJSM on running 10 3/4" casing 16:30 00:00 7.50 0 1,247 SURFA( CASING PUTB P Ran 10 3/4"45.5#L-80 Hydril 563 casing as follows:Weatherford float shoe-2 jts csg-Weatherford float collar-2 jts csg-to 166'-filled pipe and checked floats-all connections made up w/BakerLoc-Installed 2 bow spring centralizers on shoe jt w/ stop rings-1 bow spring centralizer on jts 2 to 4-Continue to run csg f/ 166'to 1247'(30 jts total in hole of 63 to run)installed bow spring centralizers on each jt over collars 01/04/2015 Cont. RIH w/10 3/4"csg to 1373'-Circ btms up-Continue RIOH w/10 3/4"csg-MU hanger&landing jt.- land csg w/shoe @ 2638'-Circ&cond mud-Cmt csg w/355 bbls leamd&65 bbls tail-CIP @ 1600 hrs- RD f/cmt job-NU diverter system-cleaning pits 00:00 00:30 0.50 1,247 1,373 SURFA( CASING PUTB P Cont. RIH w/10 3/4"45.5#L-80 Hydril 563 csg f/1247'to 1373'(33 jts total in hole) UP wt 90 SO wt 65 -Installed bow spring centralizers on each jt across coupling 00:30 01:30 1.00 1,373 1,373 SURFA( CASING CIRC P Establish circ&stage pump up to 4 bbls/min @ 150 psi-Circ btms up - PU wt 90 SO wt 70 01:30 05:45 4.25 1,373 2,638 SURFA( CASING PUTB P Cont. RIH w/10 3/4"45.4#L-80 Hydril 563 csg f/1373'to 2606'(63 jts total in hole)MU Cameron fluted casing hanger&landing jt.-Landed casing on landing ring w/shoe @ 2638.42' MD-2291'TVD w/Float collar @ 2555.5' MD-2248'TVD- Installed bow spring centralizers on each jt over coupling(total centralizers 63)-Made up casing to 18.6 k(Target+ 15%)-PU wt 145 SO wt 80 Page 5 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:30 0.75 2,638 2,638 SURFA( CEMEN-RURD P RD Volant CRT-MU Cement head& lines 06:30 13:00 6.50 2,638 2,638 SURFA( CEMEN'CIRC P Establish circ @ 3 bbls/min @ 290 psi-Stage up pump @ 4 bbls/min @ 341 psi @ 5 bbls/min @ 370 psi @ 6 bbls/min @ 460 psi-circ&condition mud for cmt job-Spot vac trks& Super Suckers for cmt job-final circ rate 6 bbls/min @ 360 psi-PU wt 140 SO wt 100 13:00 16:00 3.00 2,638 2,638 SURFA( CEMEN-CMNT P Cemented 10 3/4"casing as follows: Pumped 5 bbls 10.5 ppg MudPush II -Tested lines to 3000 psi-Pumped 95 bbls 10.5 ppg MudPush II @ 5 bbls/min @ 125 psi-Dropped btm plug-Mixed&pumped 369 bbls 11.0 ppg DeepCRETE lead slurry @ 6.4 bbl/min @ 350 psi-Observed MudPush to surface @ 369 bbls lead pumped-Switched to tail slurry- Pumped 64.72 bbls 12.0 ppg DeepCRETE @ 4.4 bbls/min @ 300 psi-Dropped top plug w/10 bbls water-Switched over to rig pump& dispalced w/245.7 bbls 9.6 ppg spud mud-Bumped plug-Held pressure for 5 mins.-bled off-floats held- CIP @ 1600 hrs.-full returns throughout job observed 51 bbls of 11.0 ppg cnmt to surface 16:00 17:00 1.00 2,638 2,638 SURFA( CEMEN'RURD P RD cmt lines&cmt head-RD 350 T slips and bail extensions 17:00 00:00 7.00 2,638 2,638 SURFA( WHDBO NUND P LD landing jt.-Remove knife valve f/ diverter-MU sack washer&Flush diverter-Remove diverter lines- Clean up rig floor f/cmt job-Remove diverter bolts 01/05/2015 NU Diverter&Cameron starting head-NU BOPE-Test BOPE-Blow down Choke manifold-choke&kill lines-LD test plug-Set wear bushing-Attempt to blow down TD-Kelly hose ice plug-Break hose f/goose neck-Blow air through TD(OK) rig up to retest TD IBOP's-thawing kelly hose 00:00 06:00 6.00 0 0 SURFA(WHDBO NUND P Clean out under rotary table w/super sucker-Pump out fluid f/riser diverter Hydril&diverter Tee-ND riser f/top of diverter-Prep to pull diverter hydril&Tee f/Cameron starting head-Cleaning pits 06:00 09:30 3.50 0 0 SURFA( WHDBO NUND P Bring tree into cellar&hang back- Remove diverter Hydril&Tee&set on stand in cellar-Remove 4"valve f/ conductor Page 6 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 15:00 5.50 0 0 SURFA(WHDBO NUND P De-energize slips on starting head& remove f/conductor-clean seals on hanger neck-PU&install wellhead (Pad operator verified wellhead oriention)Tested seals to 5000 psi for 10 mins-Set test plug-install working valves on OA&IA-Obtain RKB measurements-Top wellhead- 24.98' Upper LDS 25.1' Lower LDS 26.12'-GL 28.79'all f/rotary bushing 15:00 17:30 2.50 0 0 SURFA( WHDBO NUND P NU BOP stack-Install riser&flow line-Install Koomy lines on Hydril - Install kill line-RKB's Hydril 10.94' Top pipe rams 14.97'Blind rams 16.85'Btm pipe rams 20.75' 17:30 18:00 0.50 0 0 SURFA( WHDBO BOPE P Grease choke manifold-fill stack& choke maniflold-Body test stack& flanges to 3500 psi-Good test no leaks 18:00 22:30 4.50 0 0 SURFA( WHDBO BOPE P Test BOPE-Tested choke manifold valves-choke&kill line valves-4" Demco on kill line-Floor safety& dart valves-TD IBOPs'-Blind rams- Upper&lower pipe rams to 250& 3500 psi-Test Annualr to 250& 2500 psi-Tested w/5"test jt- Tested manual&super chokes to 1100 psi-Performed accumulator recovery test-Start pressure 2900 psi-Function pipe rams-Annular& HCR's-1700 psi-start elec. pump 200 psi in 30 secs.open air valve- full charge in 150 secs. -CPAI test- 2500 psi w/air pump in 201 secs- Full change w/elec. pump in 105 secs. -N2 bottles 2062 psi average- Witnessing of test waived by 22:30 00:00 1.50 0 0 SURFA( WHDBO RURD P Blow down choke manifold-Blow down kill line-drain stack-Pull test plug-Install wear bushing(10"ID) Attempt to blow down TD-Kelly hose frozen up-Remove kelly hose f/goose neck on top drive-blow ai r through TD-clear-RU to retest TIJ IBOP's-thawing kelly hose 01/06/2015 R/D BOP test equipment-P/U 123 jts of 5" DP and stand it back-Rig down time/free ice plug from Kelly hose and goose neck-Prep rig to P/U BHA#4. 00:00 01:30 1.50 0 0 SURFA( WHDBO RURD P R/D BOP test equipment 01:30 12:00 10.50 0 0 SURFA( CEMEN-PULD P P/U and stand back 102 jts(34 stds) 5"DP. Loaded pits with new LSND mud. 12:00 13:30 1.50 0 0 SURFA( CEMEN-PULD P P/U and stand back 21 jts(7 stds)5" DP Page 7 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 23:30 10.00 0 0 SURFA( CEMENT RGRP T Rig downtime/Kelly hose froze during BOPE test. Remove Kelly hose from goose neck and free ice plug. 10 Hrs Total down time. 23:30 00:00 0.50 0 0 SURFA( CEMENT RURD P Prep rig to P/U BHA#4. 01/07/2015 P/U 9 7/8"Intermediate Rotary Steerable BHA#4-P/U 5"DP-RIH to 1512'and shallow test MWD- Continue P/U 5"DP-RIH to 2423'-Circulate B/U and pressure test 10 3/4"casing to 3000 psi for 30 minutes -Clean out cement to the F/C-Drill cement to the shoe 2638'-Drill 20'of new hole 2668'-Perform FIT/mud wt 9.6 ppg Shut in pressure 800 psi /EMW 16.2 ppg-D/D to 2710'. 00:00 03:30 3.50 0 727 SURFA( CEMENT PULD P P/U 9 7/8"Intermediate Rotary Steerable BHA#4 03:30 05:00 1.50 727 1,512 SURFA( CEMENT PULD P P/U 5"DP and RIH f/727' t/1512' PUW 85 k SOW 75 k. 05:00 06:00 1.00 1,512 1,512 SURFA( CEMENT DHEQ P Shallow Pulse test MWD 300 GPM 400 PS I@ 400 GPM 712 PSI @ 500 GPM 1038 PSI. 06:00 07:30 1.50 1,512 2,423 SURFA( CEMENT PULD P Continue to P/U 5"DP f/1512' t/ 2423' PUW 100 k SOW 80 k. 07:30 08:30 1.00 2,423 2,423 SURFA( CEMENT SLPC P Slip and cut 65'of drilling line/ Calibrate block position. 08:30 09:00 0.50 2,423 2,423 SURFA( CEMENT SVRG P Service rig/TD/DW/Crown 09:00 10:30 1.50 2,423 2,423 SURFA( CEMENTCIRCP Circulate B/U 430 GPM 915 PSI PUW 100 k SOW 80 k 10:30 12:00 1.50 2,423 2,423 SURFA( CEMENT PRTS P Pressure test 10 3/4"casing to 3000 psi/30 minutes/Good test. 12:00 13:00 1.00 2,423 2,423 SURFA( CEMENT DHEQ P Circulate 400 GPM to calibrate ECOSCOPE per MWD. SPR taken at 13:00 hrs 2665'MD 2313'TVD Pump#1 2 BPM 90 psi 3 BPM 120 psi Pump#2 2 BPM 80 psi 3 BPM 110 psi 13:00 14:30 1.50 2,423 2,556 SURFA( CEMENT COCF P Clean out cement to FC 2556' WOB 1-2 k 455 GPM 1000 PSI ON 960 PSI OFF 40 RPM 5-7 k TQ ON 6 k TQ OFF PUW 105 k SOW 80 k RTW 92 k 14:30 19:00 4.50 2,556 2,648 SURFA( CEMENT DRLG P Drill cement f/2556' t/Shoe 2648' WOB 5-10 k 455 GPM 1000 PSI ON 960 PSI OFF RPM 40-50 TQ ON5-9k TQ OFF 5-6k PUW105 k SOW75k RWT92k. 19:00 20:00 1.00 2,648 2,668 SURFA( CEMENT DDRL P Drilled 20'new hole f/2648'to 2668' WOB 5-10 k 455 GPM 1000 PSI ON 960 PSI OFF RPM 40-50 TO ON 5-9 k TO OFF 5-6 k PUW105 k SOW 75 k RWT 92 k. 20:00 20:30 0.50 2,668 2,578 SURFA( CEMENT CIRC P Circulate and condition mud/Pump B/U for FIT. 500 GPM 1050 PSI RPM 45 PUW 103 k SOW 80 k. Rack 1 std back into casing. 20:30 21:00 0.50 2,578 2,578 SURFA( CEMENT FIT P Perform Formation Integrity Test/ Pump 7 SPM @ .5 BPM Pump 11 stks-.9 bbls-Shut-in at 800 psi- EMW 16.2 ppg Page 8 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:30 0.50 2,578 2,578 INTRM1 DRILL SFTY P Safety Meeting/R/D test equipment and displace with LSND mud. 21:30 22:00 0.50 2,578 2,578 INTRM1 DRILL SVRG P Service rig/adjust Kelly hose/R/D test equipment. 22:00 23:00 1.00 2,578 2,668 INTRM1 DRILL DISP P Displace well with 9.6 ppg LSND mud 495 GPM 932 PSI 40 RPM Pump 40 bbl HI-VIS spacer before displacement of LSND mud. 23:00 00:00 1.00 2,668 2,710 INTRM1 DRILL DDRL P Directional drill f/2668' t/2710' WOB 5 k 600 GPM 1235 PSI ON 1215 PSI OFF 70 RPM TQ ON 6-7 k TQ OFF 5-6 k PUW 105 k SOW 80 k RWT 92 k ART.55 HRS ADT .55 HRS AST 0 BIT.55 HRS JARS 63.70 HRS. SPR taken at 23:00 HRS 2668'MD 2313'TVD Pump#1 2 BPM 90 PSI 3 BPM 120 PSI Pump#2 2 BPM 80 PSI 3 BPM 110 PSI MW 9.6 ppg 31/08/2015 Drill 9 7/8"Intermediate hole with Rotary Steerable BHA#4 f/2710' t/4578'-Pump HI-VIS Sweeps every 300' 00:00 12:00 12.00 2,710 3,740 INTRM1 DRILL DDRL P Drill f/2710' t/f3740' WOB 10 k GPM 650 PSI ON 1560 PSI OFF 1510 RPM 130 TQ ON 8.5 k TQ OFF 6.5 k PUW 120 k SOW 88 k RWT 100 k ADT 7.5 hrs BIT 7.6 hrs JARS 70.75 SPR taken at 08:20 hrs 3459' MD 2732'TVD MW 9.6 ppg ECD 10.6 PP9. Pump#1 @ 2 BPM 130 psi @ 3 BPM 150 psi Pump#2 @ 2 BPM 130 psi @ 3 _ BPM 150 psi 12:00 00:00 12.00 3,740 4,578 INTRM1 DRILL DDRL P Drill f/3740' t/4578' TVD 3347' WOB 8-12 k GPM 650 PSI ON 1830 PSI OFF 1800 RPM 140 TQ ON 10.8 K TQ OFF 9.5k PUW 135 k SOW 94 k RWT 108 k ADT 6.99 hrs Bit 14.59 hrs JARS 77.74 hrs SPR taken at 20:30 hrs 4306'MD 3303'TVD Pump#1 @ 2 BPM 100 psi @ 3 BPM 130 psi Pump#2 @ 2 BPM 90 psi @ 3 BPM 130 psi Pump HI-VIS Sweeps every 300'/ Mud wt 9.6 PPg/ECD 10.5- 10.7 PP9. 01/09/2015 Drill f/4578' t/5623'-Short trip/POOH f/5623' t/3271'-back ream f/3271' t/ 2705'(through Campanion) POOH t/2611'and circulate/pump 20 bbl HI-VIS Sweep. Page 9of28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 4,578 5,342 INTRM1 DRILL DDRL P Drill f/4578' t/5342' TVD 3347' WOB 8-15 k GPM 650 PSI ON 1960 PSI OFF 1915 RPM 150 TQ ON 12-14 k TQ OFF 10-13 k PUW 150k SOW98k RWT115k ART 6.35 ADT 6.35 hrs Bit 20.94 hrs JARS 84.09 hrs SPR taken at 10:30 hrs 5243'MD 3677'TVD Pump#1 @ 2 BPM 130 psi @ 3 BPM 170 psi Pump#2 @2 BPM 130 psi @3 BPM 170 psi Pump HI-VIS Sweeps every 300'/ Mud wt 9.6 PPg/ECD 10.6-10.8 ppg. GAS 50-80 units 12:00 16:30 4.50 5,342 5,623 INTRM1 DRILL DDRL P Drill f/5342' t/5623' TVD 3347' WOB 8-15 k GPM 650 PSI ON 1960 PSI OFF 1915 RPM 150 TQ ON 14-16 k TQ OFF 11-13 k PUW 150 k SOW 99 k RWT 118 k ART 6.35 ADT 6.35 hrs Bit 20.94 hrs JARS 84.09 hrs SPR taken at 16:30 hrs 5623' MD 3866'TVD Pump#1 @ 2 BPM 140 psi @ 3 BPM 180 psi Pump#2 @ 2 BPM 140 psi @ 3 BPM 180 psi Pump HI-VIS Sweeps every 300'/ Mud wt 9.6 PPg/ECD 10.6- 10.8 ppg Gas 50-80 units ADT 2.26 ART 2.26 Bit 23.3 JARS 86.38 16:30 17:00 0.50 5,623 5,530 INTRM1 DRILL REAM P Back ream f/5624' t/5530' GPM 650 RPM 80 PSI 1850 PUW 150 k SOW 99 k RWT 118 k. Circulate B/U-Monitor well for 10 minutes. 17:00 20:00 3.00 5,530 3,271 INTRM1 DRILL WPRT P Short trip to the Shoe/POOH with elevators f/5530' V 3271' PUW 125 k SOW 90 k/monitor well for swabbing 20:00 23:00 3.00 3,271 2,611 INTRM1 DRILL REAM P Back ream f/3271' t/2611' GPM 500 RPM 60 PSI 1150 PUW 120 k SOW 90 k RWT 96 k/back ream through the Campanian to the 10 3/4"casing Shoe @ 2638'. 23:00 00:00 1.00 2,611 2,611 INTRM1 DRILL CIRC P Circulate/pump HI-VIS Sweep and circulate until shakers are clean. PUW 100 k SOW 80 k PSI 1052 GPM 494 BPM 12. 01/10/2015 Circulate at the Shoe/2638' until shakers are clean-RIH to 5,254'-MWD/MAD pass at 4,170"and 5,070'- Ream and wash to bottom 5,623'-Drill f/5,623't/6,198'. 00:00 00:30 0.50 2,611 2,611 INTRM1 DRILL CIRC P Continue to circulate at the Shoe 2638' until shakers are clean. PUW 100 k SOW 80 k PSI 1052 GPM 500 BPM 12 Page 10 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:00 0.50 2,611 2,611 INTRM1 DRILL SVRG P Service TD/Crown/DW/back wrench on TD. 01:00 05:00 4.00 2,611 5,254 INTRM1 DRILL WPRT P TIH f/2611' t/5254' PUW 98 k SOW 88k-MAD pass f/4105' t/ 4170 and f/5025' t/5070' PSI 1285 GPM 500 BPM 12. PUW 131 k SOW 110k. 05:00 07:30 2.50 5,254 5,623 INTRM1 DRILL REAM P Ream and wash to bottom f/5254' t/ 5623'-Pump HI-VIS Sweep Surface to Survace before drilling. PSI 840 GPM 126 BPM 3 PUW 147 k SOW 97 k. 07:30 12:00 4.50 5,623 5,767 INTRM1 DRILL DDRL P Drill f/5623' t/5767' TVD 3938' WOB 15-20 k GPM 650 PSI ON 2130 PSI OFF 1973 RPM 150 TO 'ON 11 K TQ OFF 11 k PUW 160 k SOW 105 k RWT 119 k ADT 3.91 hrs Bit 27.14 hrs JARS 90.29 hrs- Pumped 25 bbl DRILLZONE Sweep 70%returns to shakers. 12:00 00:00 12.00 5,767 6,198 INTRM1 DRILL DDRL P Drill f/5767' t/6198' TVD 4151' WOB 5-18 k GPM 650-700 PSI ON 2400 PSI OFF 2100 RPM 150 TQ ON9-12k TQ OFF 5-8k PUW 140 k SOW 112 k RWT 123 k ART 7.51 ADT 7.51 hrs Bit 34.65 hrs JARS 97.8 hrs SPR taken at 23:00 hrs 6198' MD 4151'TVD Pump#1 @ 2 BPM 120 psi @ 3 BPM 170 psi Pump#2 @ 2 BPM 120 psi @ 3 BPM 170 psi Pump Nut Plug Sweeps every as needed for bit balling/Mud wt 9.6 PPg/ECD 10.4- 10.6 ppg Gas 40-70 units 31/11/2015 Drill f/6198't/7823'-Pump HI-VIS Sweeps every 300'/Dilute as needed. 00:00 12:00 12.00 6,198 6,973 INTRM1 DRILL DDRL P Drill f/6198" t/6973' TVD 4536' WOB 15 k GPM 650 PSI ON 2090 PSI OFF 2060 RPM 110 TQ ON 15 k TQ OFF 10 k PUW 160 k SOW 118 k RWT 130 k ART 8.08 hrs ADT 8.08 hrs Bit 42.73 hrs JARS 105.88 hrs SPR taken at 11:15 hrs 6944'MD 4518'TVD Pump#1 @ 2 BPM 190 psi @ 3 BPM 230 psi Pump#2 @ 2 BPM 190 psi @ 3 BPM 240 psi Mud wt 9.6 ppg/ECD 10.4- 10.6 ppg Gas 60-700 units Page 11 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 6,973 7,823 INTRM1 DRILL DDRL P Drill f/6973" U 7823' TVD 4536' WOB 10-15 k GPM 700 PSI ON 2550 PSI OFF 2500 RPM 120 TQ ON 14-17 k TQ OFF 8-11 k PUW 160 k SOW 123 k RWT 135 k ART 6.78 hrs ADT 6.78 hrs Bit 4951 hrs JARS 112.66 hrs SPR taken at 21:30 hrs 7509' MD 4801'TVD Pump#1 @ 2 BPM 150 psi @ 3 BPM 200 psi Pump#2 @ 2 BPM 160 psi @ 3 BPM 200 psi Mud wt 9.6 ppg/ECD 10.7-11.0 ppg Gas 60-700 units HI-VIS Sweeps every 300'/Dilute as needed 31/12/2015 TD well 8,114'-Circulate to condition hole-Pump out of the hole f/8,014' U 2,500'. 00:00 06:00 6.00 7,823 8,114 INTRM1 DRILL DDRL P Drill ft 7823' U 8114' TVD 5035' WOB 10 k GPM 650 PSI ON 2400 PSI OFF 2325 RPM 120 TQ ON 14 k TQ OFF 10 k PUW 173 k SOW 124 k RWT 141 k ART 3,53 hrs ADT 3,53 hrs Bit 53.04 hrs JARS 124.66 hrs SPR taken at 06:00hrs 8118'MD 5035'TVD Pump#1 @ 2 BPM 180 psi @ 3 BPM 230 psi Pump#2 @ 2 BPM 180 psi @ 3 BPM 240 psi Mud wt 9.7 ppg/ECD 10.8 06:00 09:00 3.00 8,114 7,782 INTRM1 CASING CIRC P Circulate and pump HI-VIS sweeps until shakers clean-Rack back 1 stand every BU f/8114' U 7782'- PSI 2300 GPM 650 RPM 120 PUW 140k SOW 130k RWT137 k. 09:00 09:15 0.25 7,782 7,782 INTRM1 CASING OWFF P Monitor well for 15 mins.-Static 09:15 10:30 1.25 7,782 7,509 INTRM1 CASING TRIP P POOH on elevators f/7782' U 7509' -PUW 175 k SOW 120 k-Pulled over 20 k at 7533'. 10:30 14:30 4.00 7,509 6,661 INTRM1 CASING TRIP P Pump out of the hole f/7509' U 5600'-PSI 350 GPM 123 BPM 3 PUW 140 k SOW 100 k-Calc hole fill 10.06 bbls-Actual hole fill 11.0 bbls. 14:30 15:30 1.00 6,661 5,600 INTRM1 CASING CIRC P Circulate and condition mud at 5600' -GPM 660 PUW 140 k SOW 100 k RWT 116 k TQ 10 k RPM 100 ECD 11.2-10.8 GAS at BU 247 units. Page 12 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:30 1.00 5,600 5,300 INTRMI CASING TRIP P Line upon TT and POOH on elevators f/5600' t/5300'- Swabbing and tight spots- Attempted to work throgh tight spots, no go,still swabbing. 16:30 23:00 6.50 5,300 2,500 INTRMI CASING TRIP P Pump out of the hole f/5300' t/ 2500'-PS 1225-300 GPM 123 BPM 3 PUW 105 k SOW 79 k- Calc hole fill 21.7 bbls-Actual hole fill 36 bbls.-Work pipe slowly due to packing off. 23:00 00:00 1.00 2,500 2,500 INTRM1 CASING CIRC P Circulate BU at 2511'-SPM 160 BPM 560 PSI 1400 RPM 100 TQ 4-5 k RWT 91 k-Pump 40 bbl HI- VIS Sweep-35%cuttings increase over shakers at BU. 31/13/2015 POOH laying down 5"DP to 1696'-crew dropped hammer down hole-Drain stack&attempt to fish hammer f/top of wear bushing along sdie of 5"DP-No luck-Cont.to POOH laying down 5"DP& 10 jts HWDP to 200'-Observed 5k over pull-Drain stack&attempt to fish hammer-Recovered hammer-Finish LD BHA#4 -RIH w/15 stds 5"DP f/derrick 00:00 02:30 2.50 2,500 2,500 INTRM1 CASING CIRC P Circ @ 2500'@ 560 gpm @ 1344 psi w/99 rpm's-Pump 15 bbls dry job- PU wt 90 So wt 90 Rot wt. 90- Blow down TD 02:30 03:30 1.00 2,500 1,696 INTRM1 CASING PULD P POOH&LD 5" DP f/2500'to 1696'- 03:30 04:00 0.50 1,696 1,696 INTRM1 CASING RURD P Held PJSM to remove blower hose- crew dropped hammer down well- Drain stack-Observed hammer @ wear bushing 04:00 08:30 4.50 1,696 1,696 INTRM1 CASING FISH T MU fishing tool and attempt to fish out hammer f/top of wear bushing along side of drill string-Unable to retrieve hammer 08:30 15:30 7.00 1,696 200 INTRM1 CASING PULD P Continue POOH&LD 5"DP f/1696' to 200' -LD all 5"DP& 10 jts HWDP-pulling slow Observed 5 k over pull-stopped pulling 15:30 18:30 3.00 200 200 INTRM1 CASING FISH T Drain stack&Observed hammer at top of wear bushing along side of 5" HWDP-attempt to recover hammer- used magnet on Tee bar-No luck- MU snear on 30'of conduit and worked over hammer handle- recovered hammer-LD fishing tool 18:30 22:30 4.00 200 0 INTRM1 CASING PULD P LD 2 jts HWDP-LD MN flex DC's- Remove RA sources f/MWD tool- Finish LD BHA tools-Clean&clean up rig floor 22:30 00:00 1.50 0 1,413 INTRMI CASING TRIP P RIH w/15 stds 5"DP f/derrick to 1413'-PUwt58 SO wt 50- 31/14/2015 Cont.to LD 5"DP-Pull WB-Flush stack-Change upper pipe rams for 7 5/8"csg&test-RU to run csg -PJSM-Run 7 5/8"csg 00:00 06:00 6.00 0 0 INTRM1 CASING PULD P Finish laying down 30 stds 5"DP 06:00 08:00 2.00 0 0 INTRMI CASING WWWH P MU stack washer&flush stack-RU &pull wear bushing Page 13 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:00 2.00 0 0 INTRM1 CASING BOPE P Change upper 3 1/2"x 6"VBR to 7 5/8"solid body pipe ram 10:00 13:30 3.50 0 0 INTRM1 CASING BOPE P MU &Set test plug-RU to test rams -fill stack-Test 7 5/8" rams to 250 &3500 psi-Tested Annular to 250& 2500 psi w. 7 5/8"test jt.(Good test) Pull test plug& LD test jt-drain stack 13:30 14:30 1.00 INTRM1 CASING RURD P PU 7 5/8"casing hanger&landing jt and made dummy run w/hanger- Pull&LD landing jt&csg hanger 14:30 16:30 2.00 0 0 INTRM1 CASING RURD P -Remove short bails&install long bails-PU casing spider&MU Volant CRT-MU floor safety valve to the 7 5/8" Hydril XO-Load reamining 7 5/8"casing into pipe shed 16:30 17:00 0.50 0 0 INTRM1 CASING SFTY P Held PJSM on running 7 5/8"csg w/ crew&third party hands 17:00 00:00 7.00 0 567 INTRM1 CASING PUTB P Ran 7 5/8"39#TN 110 SS Hydril 563&29.7#L-80 Hydril 563 casing as follows: Float shoe(Ray's Oil Tools sliver bullet)2 jts 39# TN110SS csg- Float collar( Ray Oil Tools)- 1 jt 39#TN110SS to 90.59'- Had to change out jts#2&4- damaged seal area on pin ends- Made up first 4 connections w/ BakerLoc-Installed 2 Bow spring centralizer on shoe jt& 1 Hydro Form centralizer on jts. 2 to 4-Filled pipe&checked floats pipe drained Had problem w/Volant CRT-guide nose wouldn't pass into the 39#pipe -Pulled off guide and tried to stab cup into csg-No-Go OD on top of cup 6 5/8"-Made up jts 2 to 4 with rig tongs as per Tenairs service hand -Rigged up casing tong and ran remaining 6 jts of 39#TN110SS csg f/90.59'to 437.99. -Made up XO f/ 39#TN110SS to 29.7#L-80 563 Hydril-PU 1st jt of L-80 Hydril 563& made up w/Volant CRT-RD casing tongs- Filled pipe on jt#11 and established circulation-Cont. RIH w/ 29.7#L-80 Hydril 563 csg f/437.99' to 567.94'- 13 jts total in hole- Installed 1 hydroform centrailzer on each jt f/#5 to# 13-PUwt52 k SO wt 46 k-MU toroque on 39# 22,200 ft/lbs-MU torque on 29.7# 11,900-target MU + 15% 31/15/2015 Continue to RIH w/7-5/8 casing from 567-ft MD to 2,610-ft MD, CBU, Continue to RIH to 4,550-ft MD, CBU, Cont to RIH w/7 5/8"csg f/4550'to 6565'(154 jts total in hole) Page 14 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 567 3,411 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hydril 563 csg f/567'to 3411'(80 jts total in hole) -Changed out jt.#25 (bad box)PU wt 106 k SO wt 86 k- MU torque 11.9 k-Installed 1 Hydro Form centralizer per jt f//#13 to#59 -Calc displacement 27.6 bbls- Actual displacement 26 bbls. 12:00 15:30 3.50 3,411 4,550 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hydril 563 csg f/3411'to 4550'( 107 jts total in hole)PU wt 130 k SO wt 100 k-Calc. displacement 16.56 bbls Actual 16.4 bbls 15:30 17:30 2.00 4,550 4,550 INTRM1 CASING CIRC P Establish circ&circ btms up+@ 2.3 bbls/min @ 215 psi-Final rate 2.3 bbls/min @ 215 psi-mud wt in& out 9.7 ppg-PU wt 130 k SO wt 100k 17:30 00:00 6.50 4,550 6,565 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hydril 563 csg f/4550'to 6565'(154 jts total in hole)PU wt 172 k SO wt 150 k-Installed 1 HydroForm centralizer on every other jt f/# 125 to 153-Calc dispalcement 22.6 bbls Actual 22.5 bbls-LD Jt#107(bad box0&Jt#108(bad Pin) 31/16/2015 Finished RIH w/7 5/8"csg-MU hanger&landing jt&land csg w/shoe @ 8104'-RD CRT-RU Cmt head& lines-Cemt. 7 5/8"csg-WOC(floats didn't hold) RD cmt herad&LD lanbding jt. Set&test pack-off- Change out bails 00:00 02:00 2.00 6,565 6,565 INTRM1,CASING CIRC P Establish circ&circ btms up+stage pump up to 4.5 bbls/min @ 235 psi- 9.7 ppg mud in&out- 02:00 07:30 5.50 6,565 8,114 INTRM1 CASING PUTB P Cont. RIH w/7 5/8"29.7#L-80 Hydril 563 csg f/6565'-8072'(189 jts total in hole) PU Jt#190&tag btm@8114' 07:30 09:30 2.00 8,114 8,114 INTRM1 CEMEN-CIRC P Establish circ-Circ @ 2 bbls.min @ 400 psi 09:30 10:15 0.75 8,114 8,104 INTRM1 CASING HOSO P LD jt.#190-MU Cameron fluted mandrel hanger&landing jt-Land csging w/shoe @ 8104'- 10:15 11:00 0.75 8,104 8,104 INTRM1 CEMEN-RURD P RD Volant CRT-RU cmt head& lines 11:00 13:30 2.50 8,104 8,104 INTRM1 CEMEN-CIRC P Circ&cond. for cmt job-stage pump to 6 bbls/min @ 600 psi Held Pre job meeting w/crew&third party hands on cmtjob Page 15 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 16:30 3.00 8,104 8,104 INTRM1 CEMEN-CMNT P Cemented 7 5/8"casing as follows: Pumped 5 bbls CW 100-Tested lines to 4500 psi-Pumped 35 bbls/ CW100 @ 6 bbls/min @ 900 psi- Pumped 42 bbls 11.5 ppg MudPush II @ 5.5 bbls/min @ 890 psi-Line up valves on cmt head to drop btm plug -Mixed&pumped 151 bbls tail slurry(Class G+GASBLOK)@ 15.8 ppg @ 6 bbls/min @ 1650 psi- Dropped top plug w/10 bbls water f/ Dowell-Switched to rig pumps& displaced cmt w/356.8 bbls 9.7 ppg LSND mud @ 6 bbls/min 782 psi- slow pumps to 3.5 bbls/min for last 21.7 bbls of displacement-Bumped plug w/1500 psi-bled off pressure to check floats-Floats not holding- pressure up to 1100 psi&shut in head-CIP @ 1610 hrs. Reciprocated pipe until last 56 bbls of displacement-Full returns throughout job 16:30 21:00 4.50 0 0 INTRM1 CEMEN-WOC T Wait on cmt-Monitor pressure- bled off pressure-floats holding-RD line&cmt head-LD landing jt 21:00 23:30 2.50 0 0 INTRM1 CEMEN-WWSP P RU setting tool&pack-off-set pack off&test to 5000 psi for 10 mins. (Good Test)-Pull running tool 23:30 00:00 0.50 0 0 INTRM1 CEMEN-RURD P RD long bails&install short bails 31/17/2015 Change upper pipe rams-change TD saver sub-LD 5" DP f/derrick-Test upper pipe rams&Annular w/4" test jt. -Set WB-Load pipe shed w/240 jts 4"DP-PU 4"DP f/shed&RIH to 1051' 00:00 04:00 4.00 0 0 INTRM1 CEMEN-RURD P Finish LD long bails&install short bails-Changed top piope rams f/7 5/8"solid body to 2 7/8"x 5"- Change saver sub in TD f/4 1/2"IF to 4"HT-40-Inspect&change gribber dies 04:00 10:00 6.00 0 0 INTRMI CEMEN'PULD P LD kelly hose-LD 28 stds 5"DP f/ derrick-RU kelly hose 10:00 13:30 3.50 0 0 INTRMI CEMEN-BOPE P Chnage elevators f/5"to 4"-Set test plug-Fill BOP stack w/water-Test upper pipe rams to 250&3500 psi- Tested Annular to 250&2500 psi w/ 4"test jt.-Pull test plug-drain stack-Install short wear bushing- Blow down lines 13:30 21:30 8.00 0 0 INTRM1 CEMEN-RURD P Load pipe shed w/240 jts 4" DP& strap pipe-change handling equipment f/5"to 4"-Cleanning mud pits 21:30 00:00 2.50 0 1,051 INTRM1 CEMEN PULD P PU 4"DP f/shed&RIH to 1051'(33 jts of 240 to pick up) 01/18/2015 Cont. PU 4"DP f/pipe shed&RIH to 7635'-Preform freeze protect on OA-POOH w/4"DP&sdt back in derrick-RU&Test BOPE Page 16 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 10:00 10.00 1,051 7,635 INTRM1 CEMEN-PULD P Cont.picking up 4"DP f/shed&RIH f/1051'to 7635' 10:00 13:30 3.50 7,635 7,635 INTRM1 CEMEN'FRZP P Conduct Sim-ops and RU Little Red to OA&test lines to 2000 psi- Pumped 96 bbls fresh water @ 3 bbls/min @ 800 psi w/rig pump- Switched over to Little Red& pumped 101 bbls Isotherm @ 2 bbls/min @ 600 to 900 psi Shut down and close in OA-Blow down lines-RD 13:30 17:30 4.00 7,635 0 INTRM1 CEMEN-TRIPP POOH w/4" DP&std back in derrick(80 stds)PU wt 130 k SO wt77k 17:30 18:30 1.00 0 0 INTRM1 WHDBO RURD P RU&pull wear bushing-Set test plug-RU to test BOPE 18:30 00:00 5.50 0 0 INTRM1 WHDBO BOPE P Tested BOPE as follows:Tested blind rams-Choke manifold valves- Choke&kill line valves-4"Demco valve on kill line-Floor safety&dart valves- TD IBOP's-Upper&Lower pipe rams to 250&3500 psi-Tested Annular to 250&2500 psi w//4"test jt.-Tested manual&Hyd chokes to 1100 psi-Performed accumulator recovery test(start pressure 2900 psi -function rams 1600 psi-start elect. pump 200 psi increase in 38 sec's. back to full charge in 172 sec's.)Change out Demco valve on kill line&Dart valve Witnessing of test waived by Jeff Jones AOGCC 01/19/2015 Cont.w/BOP test-Set WB-Service rig-Loaded and preped MWD tools in pipe shed-MU BHA#5-RIH to 4232'picking up 4"DP-Cont. RIH w/stds f/derrick to 6800'-turned on Sonic tool @ 4515'to gather daat on 7 5/8"cmt job 00:00 03:00 3.00 0 0 INTRM1 WHDBO BOPE P Cont.w/BOP test-Tested annular w/4 1/2"&3 1/2"test jts to 250& 2500 psi-Tested Upper 2 7/8'x 5" VB R w/4 1/2"&3 1/2"test jts to 250&3500 psi-Tested Lower 3 1/2" x 6"VBR w/4 1/2"&3 1/2"test jts. to 250&3500 psi-Tested valves on test spool to 250&3500 psi Witnessing of test waived by Jeff Jones AOGCC 03:00 04:00 1.00 0 0 INTRM1 WHDBO RURD P Pull test plug-Set wear bushing- Blow down lines&chole manifold 04:00 05:00 1.00 0 0 INTRM1 CEMEN'RGRP P Change Wash pipe in TD(change out of critical path) 05:00 07:00 2.00 0 0 INTRM1 CEMEN SVRG P Pull riser&install air boot-Service TD,draw works, Iron roughneck SIMOPS 07:00 09:00 2.00 0 0 INTRM1 CEMEN'WAIT T SLB working on BHA tools in pipe shed 09:00 09:30 0.50 0 0 INTRM1 CEMEN SFTY P PJSM w/rig crew, DD, &MWD on making up BHA#5 Page 17 of 28 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:30 13:00 3.50 0 517 INTRM1 CEMEN-PULD P MU BHA#5- 6 1/2"bit (SKH513M-A1C)Power Drive w/ ported float-Periscope-Impulse- Sonic Scope-ADNVision-Install RA sources in MWD tool(3)NM flex DC's-Well Commander-XO-4 jts. HWDP-Jars-4 jts. HWDP to 517' PUwt 46k SOwt45k • 13:00 14:00 1.00 517 1,469 INTRM1 CEMEN PULD P RIH w/BHA-picking up 4"DP f/ shed to 1469'-PU wt 61 k SO wt 57 k 14:00 14:30 0.50 1,469 1,469 INTRMI CEMEN'DHEQ P Shallow pulse test MWD tools @ 5 bbls/min @ 1340 psi 14:30 17:30 3.00 1,469 4,232 INTRM1 CEMEN-PULD P Cont. RIH w/BHA f/1469'to 4232'- Picking up remaining 4"DP f/shed- PUwt96k SOwt65k 17:30 18:00 0.50 4,232 4,515 INTRM1 CEMEN-TRIP P RIH w/stds f/derrick f/4232'to 4515' 18:00 19:00 1.00 4,515 4,515 INTRM1 CEMEN'DLOG P Turn on Sonic tool-circulating @ 5 bbls/min @ 1420 psi-Blow down TD 19:00 00:00 5.00 4,515 6,800 INTRM1 CEMEN DLOG P RIH f/4515'to 6800'@ 900 ft/hr to gather Sonic data for cement job on 7 5/8"csg 01/20/2015 RIH f/6,800-ft to 7983-ft @ 900'/hr obtaining Sonic data for CBL-(tagged top of cmt)Circ bmts up-RU& test csg to 3000 psi for 30 mins-S&C drill line-Drilled shoe track&20'new hole-Performed LOT to 15.9 ppg EMW- 00:00 03:30 3.50 6,800 7,849 INTRM1 CEMEN'DLOG P Cont. RIH @ 900 ft/hr to obtain Sonic data for cmt job f/69=800'to 7849'- PUwt140k SO wt75k 03:30 04:00 0.50 7,849 7,983 INTRM1 CEMEN"COCF P Wash&ream f/7846'to 7983' (tagged top of cmt)@ 5 bbls/min @ 1593 psi w/30 rpm's-PU wt 110 k SOwt100k ROT wt110k 04:00 05:30 1.50 7,983 7,849 INTRM1 CEMEN-CIRC P Circ btms up+@ 5 bbls/min @ 1593 psi-Pull back to 7849' 05:30 06:30 1.00 7,849 7,849 INTRMI CEMEN PRTS T RU&test 7 5/8"casing to 3000 psi for 30 mins-lost 300 psi-bled off- blow down lines&RD 06:30 07:30 1.00 7,849 7,849 INTRM1 CEMEN"CIRC T Circulate surface to surface @ 5 bbls/min @ 1593 psi-to retest csg 07:30 09:00 1.50 7,849 7,849 INTRM1 CEMEN-PRTS P RU&test 7 5/8"casing to 3000 psi for 30 mins. (Good test)bled off- blow down lines&RD 09:00 10:30 1.50 7,849 7,849 INTRM1 CEMEN DHEQ P Circ&test MWD tools as per SLB @ 220 gpm @ 1737 psi 10:30 13:00 2.50 7,849 7,849 INTRM1 CEMEN SLPC P Slip&cut drill line 91-ft-Inspect TD -Grease draw works&replace absorb-Service&grease TD-Set block height _ 13:00 18:00 5.00 7,849 8,120 INTRM1 CEMEN-DRLG P Drill out cmt in shoe track 7983'to 8120'-WOB 5/10 k 220 gpm @ 1840 psi-60 rpms @ 12/13 k torque -ADT.36 hrs Page 18 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 21:30 3.50 8,120 8,139 INTRM1 CEMEN-DDRL P Drilled new hole f/8120'to 8139' MD -5045 TVD ADT-.91 hrs. WOB 5 to 10 k RPM 60 GPM 220 @ 1840 psi String wt-PU 148 SO 76 ROT 106 Torque on/off btm-13.8/13 ft/lbs 21:30 22:30 1.00 8,139 8,139 INTRM1 CEMEN-FIT P RU&perform FIT/LOT to 15.9 ppg EMW w/9.7 ppg mud @ 1620 psi @ 5033'TVD-leak-off occured @ 1620 psi 22:30 00:00 1.50 8,139 8,139 PROD1 DRILL OTHR P Clean pill&pit#4 to mix sweep for mud change over 01/21/2015 Empty&clean pill pit&pit 4-Mix Hi-Vis pill-Displace well f/9.7 ppg LSND to 9.8 ppg Klashield mud- Drilled 6 1/2"hole w/RSR f/8139'to 9208' Top of Bermuda pick by Geo @ 8584'MD 00:00 02:30 2.50 8,139 8,139 PROD1 DRILL COND P Pull LSND mud f/pill pit&pit 4- Clean pits-Mix Hi-vis pill for mud displacement in pill pit 02:30 06:00 3.50 8,139 8,139 PROD1 DRILL DISP P Displace well f/9.7 LSND to 9.8 ppg KLA Shield-pumped 40 bbls hi-vis pill followed by 9.7 ppg KLAShield mud @ 5 bbls/min @ 1637 psi w/40 rpm's w/13 k torque- PU wt 160 SO wt 75 ROT wt 163-Shut down &clean up shakers&possume belly -Monitor well for flow 06:00 12:00 6.00 8,139 8,486 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/8139'to 8486'MD 5156'TVD ADT-4.3 hrs -Footage 347' ECD- 10.75 ppg WOB 10 k RPM 100 GPM 245 @ 1928 psi String wt--PU 148 SO 81 ROT 105 Torque on/off btm.-10/8 k ft/lbs SPR's @ 0600 hrs @ 8139' #1 2 bbls/min @ 350 psi 3 bbls/min @ 560 psi #2 2 bbls/min @ 360 psi 3 bbls/min @ 560 psi Page 19 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 8,486 8,922 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/8486'to 8922'MD 5265'TVD ADT-4.33 hrs Footage-436' ECD-10.7 ppg WOB 10 k RPM 130 GPM 240 @ 1940 psi String wt. PU 150 SO 81 ROT 107 Torque on/off btm.-13/12 k fUlbs SPR's @ 1330 hrs 8613'MD #1 2 bbls/min @ 410 psi 3 bbls/min @ 640 psi #2 2 bbls/min @ 360 psi 3 bbls/min @ 580 psi 18:00 00:00 6.00 8,922 9,208 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/8922'to 9208'MD 5301'TVD ADT-4.14 hrs Footage-286' ECD-10.77 ppg WOB 5 k RPM 130 GPM 240 @ 1970 psi String wt. PU 149 SO 84 ROT 105 Torque on/off btm.- 12.9/10 k fUlbs SPR's @ 2300 hrs @ 9183' #1 2 bbls/mion @ 450 psi 3 bbls/min @ 650 psi #2 2 bbls/min @ 430 psi 3 bbls./min @ 630 psi 01/22/2015 Drilled 6 1/2"hole w/RSS f/9208'to 11085' 00:00 12:00 12.00 9,208 9,982 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/9208'to 9982'MD 5341'TVD ADT- 10.35 hrs Footage- 774' ECD- 11.2 ppg WOB 15 k RPM 160 GPM 240 @ 2185 psi String wt PU 143 SO 88 ROT 101 Torque on/off btm.- 12/10 k fUlbs SPR'@ 0630 hrs. @ 9563' #1 2 bbls/min @ 500 psi 3 bbls/min @ 690 psi #2 2 bbls/min @ 480 psi 3 bbls/min @ 660 psi Page 20 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 9,982 10,515 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/9982'to 10,515'MD 5341'TVD ADT-3.1 hrs Footage-533' ECD-11.07 ppg WOB 10/15 k RPM 160 GPM 240 @ 2175 psi String wt. PU 142 SO 85 ROT 103 Torque on/off btm.-12.9/9 k ft/lbs SPR;s @ 1330 hrs @ 10,134' #1 2 bbls/min @ 470 psi 3 bbls/min @ 700 psi #2 2 bbls/min @ 460 psi 3 bbls/min @ 690 psi 18:00 00:00 6.00 10,515 11,085 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/10,515' to 11,085'MD 5349'TVD ADT- 3.22 hrs. Footage-570' ECD-11.04 ppg WOB 15 k RPM 160 GPM 240 @2185 psi String wt PU 143 SO 84 ROT 104 Torque on/off btm.- 12.6/9 k ft/lbs SPR's @ 2358 hrs @ 11085' MD #1 2 bbls/min @ 540 psi 3 bbls/min @ 700 psi #2 2 bbls/min @ 500 psi 3 bbls/min @ 680 psi 01/23/2015 Drilled 6 1/2"hole w/RSS f/11085'to 12,229'MD 5384'TVD(TD of Section)Circ 3 X btms up -Made 240 bbl whole mud dilution-Flow ck(static) 00:00 06:00 6.00 11,085 11,517 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/11,085' to 11,517'MD 5360'TVD ADT-4.1 hrs Footage-432' ECD - 11.02 ppg WOB 10 k RPM 150 GPM 240 @ 2290 psi String wt- PU 149 SO 85 ROT 105 Torque on/off btm.-12.7/8.9 k ft/lbs SPR's @ 0600 hrs @ 11,563' MD #1 2 bbls/min @ 500 psi 3 bbls/min @ 720 psi #2 2 bbls/min @ 510 psi 3 bbls/min @ 750 psi i Page 21 of 28 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 11:00 5.00 11,517 11,847 PROD1 DRILL DDRL P Drilled 6 1/2"hole w/RSS f/11517' to 11,847'MD 5366'TVD ADT-2.63 hrs Footage-330' ECD-11.1 ppg WOB 10 k RPM 150 GPM 240 @ 2244 psi String wt. - PU 150 SO 83 ROT 103 Torque on/of btm.-12.5/9.5 k ft/lbs SPR's @ 10:30 hrs @ 11847' #1 2 bbls/min @ 500 psi 3 bbls/min @ 740 psi #2 2 bbls/min @ 480 psi 3 bbls/min @ 740 psi 11:00 12:00 1.00 11,847 11,467 PROD1 DRILL BKRM X BROOH f/11,847;to 11,467'@ 220 gpm@ 1960 psi w/100 rpm @ 8.8 k -ROT wt 103 12:00 13:00 1.00 11,467 11,847 PROD1 DRILL PULD X RIH f/11,467'to 11,847'-picking up 12 jts 4"DP -PU wt 140 SO wt 86 13:00 18:00 5.00 11,847 12,229 PROD1 DRILL DDRL X Drilled 6 1/2"hole w/RSS f/11,847' • to 12,229'MD 5384'TVD ADT-3.28 hrs Footage-382' ECD-11.0 ppg WOB 10 k RPM 150 GPM 240 @ 2255 psi String wt-PU 147 SO 81 ROT 104 Torque on/off btm.-13.8/9.5 k ft/lbs SPR's @ 1800 hrs @ 12,229' #1 2 bbls/min @ 460 psi 3 bbls/min @ 700 psi #2 2 bbls/min @ 470 psi 3 bbls/min @ 710 psi 18:00 21:00 3.00 12,229 11,849 PROD1 CASING CIRC P Circ 2 X btms up+@ 220 gpm @ 1900 psi w/100 rpm's w/8/9 k torque-Std back 1 std DP every 30 mins f/12,229'to 11,849'-Flow ck (well static) 21:00 00:00 3.00 11,849 11,658 PROD1 CASING CIRC P Cont. circ&condition mud-pumped 240 bbl whole mud dilution @ 225 pgm @ 1910 psi w/80 rpm w/8/9 k torque-PU wt 147 SO wt 81 ROT wt 104-Stood back 1 std to 11,658' -Flow ck(well Static) 31/24/2015 BROOH f/11,658'to 8044'-Circ inside 7 5/8"csg-Drop rabbit-POOH on elevators to 517'-Held safety stand-LD BHA-RU to run 4 1/2"liner Page 22 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 11,658 9,373 PROD1 CASING BKRM P BROOH f/11,658'to 9373'@ 900'/ hr@ 225 gpm @ 1980 psi w/80 rpm's w/9 k torque-PU wt 145 SO wt 70 ROT wt 110 -FCP 1855 psi-F PU wt 135 SO wt 80 Rot wt 105 06:00 09:30 3.50 9,373 8,040 PROD1 CASING BKRM P BROOH f/9373'to 8040'@ 900'/hr. @ 225 gpm @ 1850 psi W/90 rpm's w/6ktorque-IPU wt135 ISO 80 IROT 105-F PU 123 FSO 83 ROT 100 -Dropped 2 7/16"hollow rabbit on Std#84 09:30 10:00 0.50 8,040 8,040 PROD1 CASING OWFF P Monitor well(Static)SIMOPS service TD&DWs 10:00 11:00 1.00 8,040 7,944 PROD1 CASING CIRC P Circ 2X btms up @ 220 gpm @ 1680 psi w/40 RPM's W/5.4 k torque- PU wt 123 SO wt 83 Rot wt 100- Std back 1 std DP to 7944' 11:00 17:00 6.00 7,944 517 PROD1 CASING TRIP P Flow ck(static)POOH on elevators f/ 7944'to 517' - PU wt 123 SO wt 89-Hole taking proper fill 17:00 18:00 1.00 517 517 PROD1 CASING SFTY P Held Safety stand down-Discussed recent incidents in D&W- 18:00 22:00 4.00 517 0 PROD1 CASING BHAH P LD BHA#5-Clean&clear rig floor of BHA tools 22:00 23:00 1.00 0 0 COMPZ CASING WWWH P Pull wear bushing-PU stack wash& flush stack-Reinstall wear bushing 23:00 00:00 1.00 0 0 COMPZ CASING RURD P RU to run 4 1/2"liner 01/25/2015 Finish RU to run liner-Ran 4/12"liner-MU hanger-RIH w/liner on 4"DP-Circ @ 7 5/8"shoe-Cont. RIH w/liner 00:00 02:00 2.00 0 0 COMPZ CASING RURD P Finish rigging up to run 4 1/2"liner- move swell packers,frac sleeves, 10 jts C-110 Hydril, &liner hanger f/ long side to short side of pipe shed- PJSM on reunning liner 02:00 03:00 1.00 10,486 COMPZ CASING OTHR P PU Baker Flex Lock liner hanger assembly/ZXP liner top packer to 4292'-Mix&spot PAL mix into liner setting sleeve 03:00 12:00 9.00 0 4,292 COMPZ CASING PUTS P Ran 4 1/2" 12.6#L-80 IBTM&4 1/2" 12.6#C-110 Hydril 521 w/Orange peel shoe, Peri pup, 7 Baker Express Frac sleeves, 8 swell packers, OX pup f/4 1/2"IBT(P)x 4 1/2"Hydril 521 9B)as per running order-PU Baker Flex Lock liner hanger assembly/ZXP liner top packer to 4292'-Mix&spot PAL mix into liner setting sleeve 12:00 12:30 0.50 4,292 4,292 COMPZ CASING RURD P RD GBR casing running equipment- RU to RIH w/liner on 4"DP 12:30 13:30 1.00 4,292 4,292 COMPZ CASING CIRC P Circ liner volume @ 5.5 bbls/min @ 304 psi -PUwt71 Sowt61 13:30 18:30 5.00 4,292 8,079 COMPZ CASING RUNL P RIH w/4 1/2"liner on 4" DP f/derrick f/4291'to 8079'@ 90'/min running speed-SO wt 82 k Page 23 of 28 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 21:00 2.50 8,079 8,079 COMPZ CASING CIRC P Circ 2 X btms up @ 4.5 bbls.min @ 418 psi-Obtained torque valves 10 rpm's 3.7 k torque&20 rpms @ 3.9 ktorque-Rot wt95-PUwt110 SO wt 84 21:00 00:00 3.00 8,079 10,486 COMPZ CASING RUNL P Cont. RIH w/4 1/2" liner on 4"DP f/ 8079'to 10,486'-SO wt 78 k 01/26/2015 Cont. RIH w/4 1/2"liner onDP-Tag btm @ 12,229'-PU to setting depth 12,220'-Set hanger&ZXP packer- Pull above liner top w/tools-Circ btms up-Change over to 9.8 ppg brine-POOH LD 4"DP&running tool 00:00 03:00 3.00 10,486 12,220 COMPZ CASING RUNL P RIH w/4 1/2"liner on 4"DP f/ 10,486'to 12,203'-PU wt. 145 SO wt 80-Calc displacement 10.4 bbls/ Acutal 11 bbls-PU 1 single of 4"DP -RIH w/liner f/12203'&tag btm @ 12,229'-PU liner to setting depth 12,220' 03:00 04:00 1.00 12,220 12,222 COMPZ CASING PACK P Drop 1.5"OD ball&pump down to ball seat-@ 3 bbls/min @ 635 psi- ball on seat-pressure up to 3060 psi to set liner hanger-Slack off&set 50 k down(hanger set)bleed off pressure-PU to 120 k-running tool is released-Pressure up to 4200 psi to shear out ball seat(didn't shear) bleed off pressure-Slack off&set ZXP liner top packer(observed shear @ surface) 04:00 04:30 0.50 7,928 7,928 COMPZ CASING PACK P Engage TD&rotate @ 20 rpm's @ 4.3 k torque-Slack off&set down 40 k w/dog sub to ensure ZXP packer is set 04:30 05:00 0.50 7,928 7,928 COMPZ CASING PRTS P Close top pipe rams&pressure up on annulus to 2000 psi for 10 mins. - Good test on ZXP packer 05:00 05:45 0.75 7,928 7,894 COMPZ CASING PULD P Pull up&LD 3 jts 4"DP to 7894' PU wt 120 05:45 06:30 0.75 7,894 7,894 COMPZ WELLPF CIRC P Circ btms up @ 7894'@ 5 bbls/min @ 585 psi-Blow down TD 06:30 07:00 0.50 7,894 7,894 COMPZ WELLPF OWFF P Monitor well for 30 mins.-(Well static) 07:00 08:30 1.50 7,894 7,130 COMPZ WELLPF PULD P Remove blower hose-POOH&LD 4"DP f/7894'to 7130'(24 jts)-hole took proper fill 08:30 09:30 1.00 7,130 7,894 COMPZ WELLPF TRIP P RIH w/DP f/derrick f/7130'to 7894' 09:30 09:45 0.25 7,894 7,894 COMPZ WELLPF SFTY P PJSM on mud change over Page24of28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 7,894 7,894 COMPZ WELLPF DISP P Change well over f/9.8 ppg Kla-Shield to 9.8 ppg brine-Pumped 47 bbls high vis sweep followed by 9.8 ppg brine @ 5 bbls/min @ 535 psi SPR's 7894' #1 2 bbls/min @ 90 psi 3 bbls/min @ 190 psi #2 2 bbls/min @ 90 psi 3 bbls/min @ 190 psi 12:00 15:30 3.50 7,894 7,894 COMPZ WELLPF COND P Blow down TD-clean mud system out after brine displacement-change shaker screens-clean TT-SIMOPs -monitor well 15:30 23:30 8.00 7,894 0 COMPZ WELLPF PULD P POOH f/7894'-laying down 4"DP 23:30 00:00 0.50 0 0 COMPZ WELLPF BHAH P LD Baker liner running tool-Clean& clear rig floor 01/27/2015 RIH w/4"DP f/derrick(32 stds)-Slip&cut drilline-POOH&LD 4"DP-RU&3 1/2"completion to 5000' 00:00 03:30 3.50 0 3,066 COMPZ WELLPF TRIP P RIH w/32 stds of 4"DP f/derrick to 3066' 03:30 04:00 0.50 3,066 3,066 COMPZ WELLPF OWFF P Monitor well-Well static-SIMOPs held PJSM on S&C drill line 04:00 06:30 2.50 3,066 3,066 COMPZ WELLPF SLPC P Slip&cut drill line 73'-adjust block height-Service rig 06:30 10:00 3.50 3,066 0 COMPZ WELLPF PULD P POOH&LD 4"DP- 10:00 10:30 0.50 0 0 COMPZ RPCOM RURD P Bring tbg running equipment to rig floor 10:30 11:30 1.00 0 0 COMPZ RPCOM RURD P RU&Pull wear bushing 11:30 13:00 1.50 0 0 COMPZ RPCOM WWWH P PU stack washer& flush stack-LD wash tool-Blow down TD-clean up rig floor 13:00 15:00 2.00 0 0 COMPZ RPCOM RURD P RU to run 3 1/2"Completion-Load completion equipment in pipe shed& place in reuuning order 15:00 15:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running 3 1/2"completion 15:15 00:00 8.75 0 5,000 COMPZ RPCOM PUTB P Ran 3 1/2"upper completion as follows: Baker Shear indicating WLEG assembly-"D"nipple w/ RHC plug installed w/3 1/2"9.3# L-80 EUE pup jts-1 jt 3 1/2"9.3# L-80 EUE 8 rd tbg-Baker Preimer packer assembly-1 jt 3 1/2"tbg- Baker CMU sliding sleeve assembly w/DS profile-1 jt 3 1/2"tbg- Camco GLM KBMG w/DCK shear valve-14 jts 3 1/2"tbg-Camco GLM w/dummy valve-32 jts 3 1/2" tbg-Camco GLM w/dummy valve- 44 jts.3 1/2"tbg-Camco GLM w/ dummy valve-60 jts 3 1/2"tbg- Camco GLM w/dummy valve-2 jts. 3 1/2"tbg to 5000' Page 25 of 28 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/28/2015 24 hr Summary Cont. RIH w/3 1/2"completion- 00:00 05:30 5.50 5,000 7,848 COMPZ RPCOM PUTB P Cont. RIH w/3 1/2"completion f/ 5000'to 7848'-78 jts 3 1/2"tbg-DS nipple assembly-13 jts 3 1/2"tbg 05:30 08:00 2.50 7,848 7,908 COMPZ RPCOM HOSO P Pick up 3 jts 3 1/2"tbg&RIH to 7934'-Observed locator shear& land on NO-GO-PU 3'off fully located-LD the 3 jts used to obtain space out-PU 3 1/2"space out pups.8.16', 10.19', &4.16'(22.51"- MU XO(3 1/2"EUE to 4 1/2"IBT)-1 jt 4 1/2" 12.6#tbg(31.18')Cameron tbg hanger w/4 1/2"pup jt(3.93') 08:00 09:30 1.50 7,908 7,908 COMPZ RPCOM CRIH P Pumped 12 bbls 9.8 ppg inhibited brine @ 3 bbls/min @ 250 psi- displace out tbg tail @ 7908' 09:30 10:00 0.50 7,908 7,933 COMPZ RPCOM THGR P Land tbg hanger in wellhead w/tbg tail @ 7933.19'-Run in LDS&test haqnger to 5000 psi for 10 mins. 10:00 10:30 0.50 7,933 7,933 COMPZ RPCOM PACK P Drop rod/ball assmebly-Pressure up on tbg to 2600 psi to set packer 10:30 12:00 1.50 7,933 7,933 COMPZ RPCOM PRTS P Pressure up on tbg to 3500 psi& test for 30 mins.-Pressure bled off to 1100 psi in 15 mins. -trouble shoot leak-Change out lo torque valve-Drain fluid f/top of hanger to check if landing jt. connection leaking 12:00 13:30 1.50 7,933 7,933 COMPZ RPCOM PRTS T RU&attempt to test to 3500 psi- pressure not holding-Bleed off pressure-blow down lines 13:30 14:00 0.50 7,933 7,933 COMPZ RPCOM WAIT T Wait on slick line unit 14:00 14:15 0.25 7,933 7,933 COMPZ RPCOM SLKL T PJSM on RU slick line&lubricator 14:15 16:00 1.75 7,933 7,933 COMPZ RPCOM SLKL T RU slick line lubricator&shelves 16:00 17:00 1.00 7,933 7,933 COMPZ RPCOM SFTY P Held Safety stand down w/rig crew, MIK, Baker&Halliburton crews- Discussed recent hand injuries, safety alerts- 17:00 20:30 3.50 7,933 7,933 COMPZ RPCOM SLKL T Cont. RU slick line 20:30 21:00 0.50 7,933 7,933 COMPZ RPCOM SLKL T RU&Test slick line lubricator to 1000 psi 21:00 00:00 3.00 7,933 7,933 COMPZ RPCOM SLKL T RIH w/slick line to fish rod/ball assembly-Engage assembly-pull up off seat-pumped 2 bbls to flush seat-Attempt to retest tbg to 3500 psi-No Good-POOH w/tools& rod/ball assembly 31/29/2015 Pull RHC plug-Set CA-2 plug in D nipple-Test tbg to 3500 psi for 15 min(GOOD)-RD slick line-Held safety stand down w/night crew-RU&test tbg&IA to 3500 psi for 30 mins.-Shear valve in GLM-set z& test TWC-ND BOP-NU Tree- Page 26 of 28 I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 COMPZ RPCOM SLKL T RIH w/pulling tool for RHC plug-Pull RHC-POOH-MU CA2 plug&RIH set in D nipple-Tested tbg to 3500 for 15 mins(Good) POOH w/slick line 04:00 05:30 1.50 COMPZ RPCOM SLKL T RD slick line lubricator&sheaves- Clear floor of slick line equipment 05:30 06:00 0.50 COMPZ RPCOM PRTS T RU&test tbg to 3500 psi for 30 mins. (GOOD test) 06:00 07:00 1.00 COMPZ RPCOM SFTY P Held safety stand down w/night crew -Discussed recent hand injuries, safety alerts-Committing to incident free operation 07:00 09:00 2.00 COMPZ RPCOM PRTS P RU&test tbg to 3500 psi for 30 mins -bled down to 2000 psi-Pressure up on IA to 3500 psi&test for 30 mins.-Bled off tgb pressure& sheared SV in lower GLM-Bled off pressure 09:00 09:30 0.50 COMPZ WHDBO MPSP P LD landing jt. RIH&set BPV in tbg hanger- 09:30 10:00 0.50 COMPZ WHDBO MPSP P Pressure up on IA to 1500 psi to test BPV in direction of flow 10:00 17:30 7.50 COMPZ WHDBO OTHR P Flush surface lines, Blow down TD, Kill line, Secondary kill, and choke lines in prepration to ND stack- clean out under rotary table-suck out mouse hole, blow down pumps 17:30 19:30 2.00 COMPZ WHDBO NUND P NU BOP-LD mouse hole pull riserpull riser&change saver sub 19:30 00:00 4.50 COMPZ WHDBO NUND P NU adapter&test to 5000 psi for 10 mins. -NU tree-turn swab valve 180°for orientation as per 2N Drill Site operator 01/30/2015 Test tree-Pumped 94 bbls diesel down IA&U tube into tbg freeze protect-Set BPV-WOW&trucks for rig move 00:00 01:30 1.50 COMPZ WHDBO PRTS P Fill tree w/diesel&test to 5000 psi for 10 mins. 01:30 02:30 1.00 COMPZ WHDBO MPSP P RU&pull TWC 02:30 04:00 1.50 COMPZ WHDBO FRZP P RU lines to annulus&tbg-Run return line to cuttings tank-Blow thru all lines w/air to insure no ice plugs 04:00 04:15 0.25 COMPZ WHDBO SFTY P PJSM on pumping freeze protect 04:15 06:30 2.25 COMPZ WHDBO FRZP P LRS tested lines to 2500 psi- Pumped 94 bbls diesel down Al- staged pump to 2 bbls/min @ 900 psi-fianl pressure 2 bbl/min @ 1300 psi-Shut in tree-Blow down line- RD LRS-Open Al &Tbg&let diesel U tube f/Al to tbg-shut in tree 06:30 09:00 2.50 COMPZ WHDBO MPSP P RU Cameron lubricator&test to 1000 psi-Set Tpye H BPV-Final tbg pressure 200 psi-Final Al pressure 220 psi-Final OA 270 psi- RD lubricator Page 27 of 28 f Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 DEMOB MOVE RURD P Secure tree-Install tree cap, Remove rig valves f/OA&IA- Replace w/flanges&gauges-Puill down cutting box&cellar box-RD hoses to cuttings tank 12:00 00:00 12.00 DEMOB MOVE WAIT T Field went to phase 2 conditions- unable to get trucks for move- Remove berm f/cuttings tank- Remove cuttings box-Change out drive bearing on drag chain-Install rotary table dog on ODS-Prep shops&camp for move-Remove sub rack-Pull elevator rackoff-Prep floor to lay over derrick-Remove tongs-Remove drag chain 31/31/2015 Wait on weather(phase 2)and trucks for move-Cont.to prep rig for move-Prpe camp&shops for move- Rig off high line-Cont.work on drag chain bearing-Trucks on location @ 1800 hrs. -Load up shop&office camp-Loads left 2n pad @ 2230 hrs.-Released rig©0000 hrs 00:00 18:00 18.00 DEMOB MOVE WAIT T Cont.to work on drag chain-Change oil in TD-prep rig floor to lay over derrick-Pre shops&office camp to move-Rig off high line-pull electric lines-Trucks on location @ 1800 hrs.-Laod out 1 shop building and rig up truck to office camp-frist 2 loads on the road©2030 hrs. Released rig @ 0000 hrs 2/1/15 18:00 00:00 6.00 DEMOB MOVE MOB P Load out Office&shop.first two loads to mob to new location Page 28 of 28 RECEIVED FEB 1 9 2015 AOGCC NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-336 Definitive Survey Report N A D 2 7 ] 03 February, 2015 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKE D M P2 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 2N-336 Well Position +N/-S 0.00 usft Northing: 5,911,896.05 usft Latitude: 70°10'12.850 N +EI-W 0.00 usft Easting: 460,611.09 usft Longitude: 150°19'1.214 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.70 usft Wellbore 2N-336 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°l (nT) BGGM2014 1/1/2015 18.78 80.75 57,545 Design 2N-336 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 28.79 0.00 0.00 217.53 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.31 812.72 2N-336 Srvy#1-GYD-GC-SS(2N-336) GYD-GC-SS Gyrodata gyro single shots 12/30/2014 3:11 872.03 2,565.72 2N-336 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/31/2014 11:0, 2,637.50 2,637.50 2N-336 Srvy#3-INC+TREND(2N-336) INC+TREND Inclinometer+known azi trend 1/22/2015 4:16: 2,726.85 8,042.34 2N-336 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/22/2015 4:18: 8,138.83 8,138.83 2N-336 Srvy#5-INC+TREND(2N-336) INC+TREND Inclinometer+known azi trend 2/2/2015 9:49:0 8,167.47 12,165.64 2N-336 Srvy#6-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/2/2015 5:38:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 28.79 0.00 0.00 28.79 -117.70 0.00 0.00 5,911,896.05 460,611.09 0.00 0.00 UNDEFINED 80.31 0.33 166.71 80.31 -66.18 -0.14 0.03 5,911,895.91 460,611.12 0.64 0.09 GYD-GC-SS(1) 173.21 0.24 134.35 173.21 26.72 -0.54 0.23 5,911,895.51 460,611.32 0.19 0.29 GYD-GC-SS(1) 261.23 0.18 138.40 261.23 114.74 -0.77 0.46 5,911,895.27 460,611.54 0.07 0.33 GYD-GC-SS(1) 351.09 0.25 185.99 351.09 204.60 -1.07 0.53 5,911,894.97 460,611.61 0.21 0.53 GYD-GC-SS(1) 441.78 0.26 208.74 441.78 295.29 -1.45 0.41 5,911,894.60 460,611.49 0.11 0.90 GYD-GC-SS(1) 533.29 1.00 204.42 533.28 386.79 -2.36 -0.02 5,911,893.69 460,611.06 0.81 1.88 GYD-GC-SS(1) 628.11 2.72 203.30 628.05 481.56 -5.18 -1.25 5,911,890.88 460,609.81 1.81 4.87 GYD-GC-SS(1) 718.13 3.91 206.81 717.91 571.42 -9.88 -3.48 5,911,886.19 460,607.56 1.34 9.96 GYD-GC-SS(1) 812.72 5.27 220.58 812.20 665.71 -16.06 -7.76 5,911,880.03 460,603.24 1.84 17.46 GYD-GC-SS(1) 2/3/2015 9::17:05AM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1 (1 (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 872.05 6.10 223.21 871.24 724.75 -20.43 -11.69 5,911,875.69 460,599.29 1.47 23.32 MWD+IFR-AK-CAZ-SC(2) 965.77 7.39 230.23 964.31 817.82 -27.91 -19.73 5,911,868.24 460,591.21 1.63 34.16 MWD+IFR-AK-CAZ-SC(2) 1,059.87 8.90 241.10 1,057,46 910.97 -35.30 -30.76 5,911,860.91 460,580.15 2.29 46.73 MWD+IFR-AK-CAZ-SC(2) 1,154.76 9.89 247.51 1,151.08 1,004.59 -41.97 -44.71 5,911,854.32 460,566.16 1.52 60.52 MWD+IFR-AK-CAZ-SC(2) 1,249.86 11.75 248.86 1,244.49 1,098.00 -48.58 -61.29 5,911,847.79 460,549.55 1.97 75.87 MWD+IFR-AK-CAZ-SC(2) 1,344.22 17.65 253.28 1,335.72 1,189.23 -56.17 -83.98 5,911,840.32 460,526.83 6.36 95.70 MWD+IFR-AK-CAZ-SC(2) 1,437.50 22.54 256.24 1,423.30 1,276.81 -64.50 -114.90 5,911,832.16 460,495.86 5.35 121.15 MWD+IFR-AK-CAZ-SC(2) 1,529.91 24,01 255.72 1,508,19 1,361.70 -73.35 -150.33 5,911,823.49 460,460.39 1.61 149.74 MWD+IFR-AK-CAZ-SC(2) 1,625.50 26.71 254.08 1,594.56 1,448.07 -84.04 -189.84 5,911,813.01 460,420.83 2.92 182.29 MWD+IFR-AK-CAZ-SC(2) 1,718.78 33.38 254.74 1,675.26 1,528.77 -96.56 -234.81 5,911,800.72 460,375.80 7.16 219.61 MWD+IFR-AK-CAZ-SC(2) 1,813.70 3.4.57 255.42 1,753.97 1,607.48 -110.21 -286.06 5,911,787.34 460,324,48 1.32 261.66 MWD+IFR-AK-CAZ-SC(2) 1,908.78 39.03 255.46 1,830.09 1,683.60 -124.52 -341.18 5,911,773.32 460,269.30 4.69 306.59 MWD+IFR-AK-CAZ-SC(2) 2,002.11 42,44 253.95 1,900.80 1,754.31 -140,61 -399.90 5,911,757.53 460,210.50 3.80 355.12 MWD+IFR-AK-CAZ-SC(2) 2,098.09 45.92 252.31 1,969.62 1,823.13 -160.05 -463.89 5,911,738.43 460,146.41 3.82 409.52 MW2+IFR-AK-CAZSC(2) 2,192,03 50.14 252.52 2,032.43 1,885.94 -181.14 -530.46 5,911,717.69 460,079.74 4.50 466.79 MWD+IFR-AK-CAZSC(2) 2,285.42 52.55 254.15 2,090.76 1,944.27 -202.04 -600.32 5,911,697.16 460,009.78 2.92 525.92 MWD+IFR-AK-CAZ-SC(2) 2,379.89 56.13 257.10 2,145.83 1,999.34 -221.04 -674,66 5,911,678.54 459,935.35 4,56 586.28 MWD+IFR-AK-CAZ-SC(2) 2,473.67 56.91 259.25 2,197.57 2,051.08 -237.06 -751.21 5,911,662.92 459,858.72 2.09 645.62 MWD+IFR-AK-CAZ-SC(2) 2,565.72 55.83 258.30 2,248.55 2,102.06 -251.98 -826,39 5,911,648.40 459,783,48 1.45 703.24 MWD+IFR-AK-CAZ-SC(2) 2,637.50 55.45 258.00 2,289.06 2,142.57 -264.15 -884.38 5,911,636.54 459,725.43 0.63 748.22 INC+TREND(3) 2,638.00 55.46 258.01 2,289.35 2,142.86 -264.23 -884.78 5,911,636.45 459,725.03 1.74 748.53 MWD+IFR-AK-CAZ-SC(4) 10 3/4"x 13-1/2 2,726.85 56.38 259.50 2,339.14 2,192.65 -278.58 -956.96 5,911,622.48 459,652.79 1.74 803.88 MWD+IFR-AK-CAZ-SC(4) 2,820.74 56.30 258.42 2,391,18 2,244.69 -293.54 -1,033.66 5,911,607.92 459,576.02 0.96 862.47 MWD+IFR-AK-CAZ-SC(4) 2,915.51 56.42 257.35 2,443.68 2,297.19 -310.10 -1,110.80 5,911,591.77 459,498.80 0.95 922.59 MWD+IFR-AK-CAZ-SC(4) 3,009.72 56.38 257.65 2,495.82 2,349.33 -327.08 -1,187.41 5,911,575.18 459,422.11 0.27 982.73 MWD+IFR-AK-CAZ-SC(4) 3,104.04 56.34 257.81 2,548.07 2,401.58 -343,77 -1,264.14 5,911,558.90 459,345.30 0.15 1,042.71 MWD+IFR-AK-CAZ-SC(4) 3,198.87 56.39 258.01 2,600.59 2,454.10 -360.31 -1,341.34 5,911,542.76 459,268.02 0.18 1,102.85 MWD+IFR-AK-CAZ-SC(4) 3,291.90 56.39 257.68 2,652,09 2,505.60 -376.62 -1,417.08 5,911,526.84 459,192.20 0.30 1,161.93 MWD+IFR-AK-CAZSC(4) 3,387.09 56.43 257.36 2,704.75 2,558.26 -393.76 -1,494.50 5,911,510.11 459,114.70 0.28 1,222.68 MWD+IFR-AK-CAZ-SC(4) 3,479.92 56.46 258.28 2,756.06 2,609.57 -410.08 -1,570.12 5,911,494.19 459,039.01 0.83 1,281.69 MWD+IFR-AK-CAZ-SC(4) 3,573.89 56.44 258.55 2,808.00 2,661.51 -425.81 -1,646.84 5,911,478.86 458,962.22 0.24 1,340.89 MWD+IFR-AK-CAZ-SC(4) 3,667.93 56.44 258.73 2,859.98 2,713.49 -441.24 -1,723.67 5,911,463.83 458,885.32 0.16 1,399.94 MWD+IFR-AK-CAZSC(4) 3,763.73 56.20 257.57 2,913.11 2,766.62 -457.61 -1,801.69 5,911,447,87 458,807.22 1.04 1,460.45 MWD+IFR-AK-CAZSC(4) 3,857.07 56.36 257.21 2,964.93 2,818.44 -474.56 -1,877.45 5,911,431.31 458,731.38 0.36 1,520.04 MWD+IFR-AK-CAZSC(4) 3,950.82 56.50 257.43 3,016.77 2,870.28 -491.71 -1,953.66 5,911,414.57 458,655,09 0.25 1,580.06 MWD+IFR-AK-CAZ-SC(4) 4,044.76 57.48 256.30 3,067.95 2,921.46 509.61 -2,030.37 5,911,397.06 458,578.29 1.45 1,640.99 MWD+IFR-AK-CAZ-SC(4) 4,138.88 58.54 257.26 3,117.81 2,971.32 -527.86 -2,108.08 5,911,379.22 458,500.50 1.42 1,702.81 MWD+IFR-AK-CAZSC(4) 4,234.59 59.41 257.77 3,167.14 3,020.65 -545.59 -2,188.16 5,911,361.91 458,420.34 1.02 1,765.65 M1MD+IFR-AK-CAZSC(4) 4,329.71 59.35 256.40 3,215.59 3,069.10 -563.89 -2,267.94 5,911,344.03 458,340.47 1.24 1,828.76 MWD+IFR-AK-CAZ-SC(4) 2/3/2015 9:17:05AM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) C) C) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,422.25 59.42 257.28 3,262.72 3,116.23 -582.02 -2,345.49 5,911,326.30 458,262.83 0.82 1,890.38 MWD+IFR-AK-CAZ-SC(4) 4,518.36 59.53 257.76 3,311.53 3,165.04 -599.91 -2,426.32 5,911,308.84 458,181.91 0.45 1,953.81 MWD+IFR-AK-CAZ-SC(4) 4,613.71 59.38 258.10 3,359.99 3,213.50 -617.08 -2,506.62 5,911,292.08 458,101.53 0.35 2,016.34 MWD+IFR-AK-CAZ-SC(4) 4,705.90 59.79 256.96 3,406.66 3,260.17 -634.25 -2,584.25 5,911,275.32 458,023.83 1.16 2,077.24 MWD+1FR-AK-CAZ-SC(4) 4,802.60 59.81 257.18 3,455.31 3,308.82 -652.95 -2,665.70 5,911,257.05 457,942.28 0.20 2,141.70 MWD+IFR-AK-CAZ-SC(4) 4,891.99 59.78 257.07 3,500.28 3,353.79 -670.16 -2,741.02 5,911,240.23 457,866.89 0.11 2,201.23 MW3+IFR-AK-CAZ-SC(4) 4,987.21 59.90 257.32 3,548.12 3,401.63 -688.41 -2,821.30 5,911,222.40 457,786.52 0.26 2,264.60 MWD+IFR-AK-CAZ-SC(4) 5,080.96 59.85 256.32 3,595.17 3,448.68 -706.90 -2,900.25 5,911,204.32 457,707.48 0.92 2,327.36 MWD+IFR-AK-CAZ-SC(4) 5,174.37 59.78 256.96 3,642.14 3,495.65 -725.56 -2,978.81 5,911,186.08 457,628.84 0.60 2,390.01 MWD+IFR-AK-CAZ-SC(4) 5,269.15 59.93 257.60 3,689.73 3,543.24 -743.60 -3,058.76 5,911,168.45 457,548.80 0.60 2,453.02 M1MD+IFR-AK-CAZ-SC(4) 5,363.31 60.06 257.79 3,736.82 3,590.33 -760.98 -3,138.42 5,911,151.49 457,469.05 0.22 2,515.34 MW3+IFR-AK-CAZ-SC(4) 5,457.07 59.92 257.94 3,783.72 3,637.23 -778.05 -3,217.80 5,911,134.84 457,389.60 0.20 2,577.23 MWD+IFR-AK-CAZ-SC(4) 5,552.09 60.06 259.91 3,831.24 3,684.75 -793.85 -3,298.54 5,911,119.45 457,308.78 1.80 2,638.95 MWD+IFR-AK-CAZ-SC(4) 5,644.80 60.40 260.21 3,877.28 3,730.79 -807.74 -3,377.81 5,911,105.98 457,229.45 0.46 2,698.25 MWD+IFR-AK-CAZ-SC(4) 5,740.44 60.18 261.13 3,924.68 3,778.19 -821.21 -3,459.78 5,911,092.94 457,147.42 0.87 2,758.86 MWD+IFR-AK-CAZ-SC(4) 5,833.98 60.05 261.44 3,971.28 3,824.79 -833.50 -3,539.94 5,911,081.07 457,067.20 0.32 2,817.44 MWD+IFR-AK-CAZ-SC(4) 5,926.92 59.97 260.56 4,017.74 3,871.25 -846.09 -3,619.45 5,911,068.89 456,987.6.4 0.82 2,875.86 MWD+IFR-AK-CAZ-SC(4) 6,021.59 60.35 259.72 4,064.85 3,918.36 -860.15 -3,700.35 5,911,055.25 456,906.67 0.87 2,936.30 MWD+IFR-AK-CAZ-SC(4) 6,116.59 60.82 259.78 4,111.50 3,965.01 -874.88 3,781.78 5,911,040.95 456,825.17 0.50 2,997.58 MWD+IFR-AK-CAZ-SC(4) 6,210.34 59.70 258.78 4,158.01 4,011.52 -890.02 -3,861.76 5,911,026.23 456,745.12 1.51 3,058.31 MWD+IFR-AK-CAZ-SC(4) 6,304.83 59.67 253.59 4,205.73 4,059.24 -909.48 -3,940.93 5,911,007.18 456,665.86 4.74 3,121.97 MWD+IFR-AK-CAZ-SC(4) 6,399.48 60.06 246.84 4,253.29 4,106.80 -937.18 -4,017.89 5,910,979.89 456,588.77 6.18 3,190.81 MWD+IFR-AK-CAZ-SC(4) 6,493.63 60.02 242.78 4,300.32 4,153.83 -971.88 -4,091.67 5,910,945.57 456,514.81 3.74 3,263.29 MWD+IFR-AK-CAZ-SC(4) 6,587.16 60.51 241.11 4,346.71 4,200.22 -1,010.08 -4,163.34 5,910,907.75 456,442.95 1.64 3,337.24 MWD+IFR-AK-CAZ-SC(4) 6,682.10 60.72 239.99 4,393.30 4,246.81 -1,050.75 -4,235.37 5,910,867.46 456,370.72 1.05 3,413.37 MWD+IFR-AK-CAZ-SC(4) 6,776.16 60.67 238.48 4,439.34 4,292.85 -1,092.71 -4,305.85 5,910,825.88 456,300.03 1.40 3,489.58 MWD+1FR-AK-CAZ-SC(4) 6,869.75 60.21 236.96 4,485.51 4,339.02 -1,136.18 -4,374.68 5,910,782.77 456,230.99 1.50 3,565.98 MWD+IFR-AK-CAZ-SC(4) 6,965.04 59.58 235.86 4,533.31 4,386.82 -1,181.78 -4,443.35 5,910,737.52 456,162.09 1.20 3,643.98 MWD+IFR-AK-CAZ-SC(4) 7,058.52 58.60 233.30 4,581.33 4,434.84 -1,228.25 -4,508.70 5,910,691.40 456,096.49 2.57 3,720.64 MWD+IFR-AK-CAZ-SC(4) 7,153.20 58.82 228.13 4,630.53 4,484.04 -1,279.46 -4,571.29 5,910,640.53 456,033.65 4.67 3,799.38 MWD+IFR-AK-CAZ-SC(4) 7,247.98 59.68 222.10 4,679.03 4,532.54 -1,336.91 -4,628.95 5,910,583.38 455,975.70 5.54 3,880.07 MWD+1FR-AK-CAZ-SC(4) 7,341.72 61.69 216.72 4,724.95 4,578.46 -1,400.05 -4,680.78 5,910,520.52 455,923.54 5.44 3,961.71 MWD+IFR-AK-CAZ-SC(4) 7,436.76 63.58 211.71 4,768.65 4,622.16 -1,469.83 -4,728.19 5,910,450.99 455,875.77 5.09 4,045.93 MWD+IFR-AK-CAZ-SC(4) 7,530.50 64.41 208.96 4,809.76 4,663.27 -1,542.54 -4,770.73 5,910,378.51 455,832.86 2.78 4,129.50 MWD+IFR-AK-CAZ-SC(4) 7,625.30 65.88 206.80 4,849.61 4,703.12 -1,618.57 -4,810.94 5,910,302.70 455,792.26 2.58 4,214.29 MW3+IFR-AK-CAZ-SC(4) 7,719.61 66.90 203.37 4,887.39 4,740.90 -1,696.82 -4,847.56 5,910,224.65 455,755.24 3.50 4,298.66 MWD+IFR-AK-CAZ-SC(4) 7,812.55 67.70 198.96 4,923.27 4,776.78 -1,776.75 -4,878.50 5,910,144.88 455,723.89 4.46 4,380.90 MWD+IFR-AK-CAZ-SC(4) 7,907.39 67.79 196.05 4,959.19 4,812.70 -1,860.45 -4,904.90 5,910,061.33 455,697.05 2.84 4,463.35 MWD+IFR-AK-CAZSC(4) 8,001.24 67.94 194.05 4,994.56 4,848.07 -1,944.40 -4,927.47 5,909,977.51 455,674.05 1.98 4,543.67 MWD+IFR-AK-CAZ-SC(4) 8,042.34 68.13 192.82 5,009.93 4,863.44 -1,981.47 -4,936.32 5,909,940.49 455,665.00 2.81 4,578.47 MWD+IFR-AK-CAZ-SC(4) 2/3/2015 9:17:05AM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 01001 (ft) Survey Tool Name 8,104.00 68.66 191.01 5,032.64 4,886.15 -2,037.56 3,948,16 5,909,884.47 455,652.88 2.86 4,630.16 INC+TREND(5) 7-5/8"x 9-718" 8,138.83 68.97 190.00 5,045.22 4,898.73 -2,069.49 -4,954.08 5,909,852.57 455,646.79 2.86 4,659.09 INC+TREND(5) 8,167.47 68.94 188.56 5,055.51 4,909.02 -2,095.87 -4,958.39 5,909,826.22 455,642.34 4.69 4,682.64 MWD+IFR-AK-CAZ-SC(6) 8,261.77 69.37 186.97 5,089.07 4,942.58 -2,183.19 -4,970.30 5,909,738.97 455,629.98 1.64 4,759.13 M1MD+IFR-AK-CAZSC(6) 8,356.85 70.11 183.51 5,122.00 4,975.51 -2,272.00 -4,978.43 5,909,650.22 455,621.38 3.50 4,834.52 MWD+IFR-AK-CAZSC(6) 8,454.39 71.85 179.46 5,153.80 5,007.31 -2,364.15 -4,980.81 5,909,558.08 455,618.53 4.31 4,909.05 MWD+IFR-AK-CAZ-SC(6) 8,548.51 73.68 178.28 5,181.68 5,035.19 -2,454.02 -4,979.03 5,909,468.21 455,619.84 2.28 4,979.23 MWD+IFR-AK-CAZ-SC(6) 8,642.56 75.96 178.10 5,206.31 5,059.82 -2,544.74 -4,976.16 5,909,377.49 455,622.24 2.43 5,049.43 MWD+IFR-AK-CAZSC(6) 8,738.21 77.94 177.38 5,227.91 5,081.42 -2,637.84 -4,972.49 5,909,284.38 455,625.43 2.20 5,121.02 MWD+IFR-AK-CAZ-SC(6) 8,833.71 78.14 176.41 5,247.70 5,101.21 -2,731.13 -4,967.42 5,909,191,08 455,630.00 1.02 5,191.92 MWD+IFR-AK-CAZSC(6) 8,928.04 79.07 174.59 5,266.34 5,119.85 -2,823.31 -4,960.17 5,909,098.87 455,636.78 2.13 5,260.60 MWD+IFR-AK-CAZ-SC(6) 9,024.95 82.00 172.59 5,282.27 5,135.78 -2,918.29 -4,949.49 5,909,003.85 455,646.96 3.64 5,329.42 MWD+IFR-AK-CAZ-SC(6) 9,118.81 84.53 170.55 5,293.28 5,146.79 -3,010.48 3,935.82 5,908,911.59 455,660.15 3.45 5,394.20 MW3+IFR-AK-CAZ-SC(6) 9,215.22 86.63 168.27 5,300.71 5,154.22 -3,104.95 -4,918.16 5,908,817.04 455,677.32 3.21 5,458.36 MWD+IFR-AK-CAZ-SC(6) 9,311.62 87.95 168.52 5,305.27 5,158.78 -3,199.28 -4,898.79 5,908,722.63 455,696.20 1.39 5,521.36 MWD+IFR-AK-CAZ-SC(6) 9,405.72 87.42 166.70 5,309.07 5,162.58 -3,291.11 -4,878.61 5,908,630.70 455,715.89 2.01 5,581.90 MWD+IFR-AK-CAZSC(6) 9,500.29 87.18 165.50 5,313.53 5,167.04 -3,382.80 -4,855.92 5,908,538.90 455,738.10 1.29 5,640.79 MWD+IFR-AK-CAZSC(6) 9,594.80 87.14 166.06 5,318.21 5,171.72 -3,474.30 -4,832.73 5,908,447.28 455,760.81 0.59 5,699.23 MWD+IFR-AK-CAZ-SC(6) 9,690.06 86.66 166.69 5,323.36 5,176.87 -3,566.75 -4,810.33 5,908,354.74 455,782.73 0.83 5,758.89 MWD+IFR-AK-CAZ-SC(6) 9,785.61 86.87 166.16 5,328.75 5,182.26 -3,659.48 -4,787.93 5,908,261.90 455,804.64 0.60 5,818.79 MWD+IFR-AK-CAZSC(6) 9,880.30 86.17 167.40 5,334.50 5,188.01 -3,751.49 -4,766.32 5,908,169.79 455,825.77 1.50 5,878.59 MWD+IFR-AK-CAZSC(6) 9,974.77 90.61 164.98 5,337.15 5,190.66 -3,843.16 -4,743.78 5,908,078.01 455,847.83 5.35 5,937.56 MWD+IFR-AK-CAZ-SC(6) 10,071.44 90.68 162.58 5,336.07 5,189.58 -3,935.97 -4,716.79 5,907,985.07 455,874.34 2.48 5,994.72 MWD+IFR-AK-CAZ-SC(6) 10,164.24 89.79 161.50 5,335.68 5,189.19 -4,024.24 -4,688.17 5,907,896.65 455,902.50 1.51 6,047.29 MWD+IFR-AK-CAZ-SC(6) 10,260.87 89.41 162.18 5,336.36 5,189.87 4,116.06 -4,658.06 5,907,804.69 455,932.13 0.81 6,101.76 MWD+IFR-AK-CAZ-SC(6) 10,357.49 89.20 163.63 5,337.53 5,191.04 -4,208.40 -4,629.66 5,907,712.21 455,960.05 1.52 6,157.69 MWD+IFR-AK-CAZ-SC(6) 10,452.66 88.50 164.77 5,339.44 5,192.95 -4,299.95 -4,603.75 5,907,620.54 455,985.47 1.41 6,214.51 MWD+IFR-AK-CAZ-SC(6) 10,545.31 89.66 166,06 5,340.93 5,194.44 -4,389.60 -4,580.42 5,907,530.77 456,008.33 1.87 6,271.39 MWD+IFR-AK-CAZSC(6) 10,640.27 89.10 166.86 5,341.96 5,195.47 -4,481.92 -4,558.19 5,907,438.36 456,030.08 1.03 6,331.06 MWD+IFR-AK-CAZSC(6) 10,733.43 89.00 166.16 5,343.50 5,197.01 -4,572.49 -4,536.46 5,907,347.68 456,051.33 0.76 6,389.65 MVD+IFR-AK-CAZ-SC(6) 10,828.60 89.07 166.72 5,345.10 5,198.61 -4,665.00 -4,514.15 5,907,255.07 456,073.16 0.59 6,449.42 MWD+iFR-AK-CAZ-SC(6) 10,927.00 88.72 164.87 5,347.00 5,200.51 -4,760.37 -4,490.01 5,907,159.58 456,096.80 1.91 6,510.35 MWD+IFR-AK-CAZSC(6) 11,022.93 89.20 164.62 5,348.74 5,202.25 -4,852.90 -4,464.77 5,907,066.93 456,121.55 0.56 6,568.36 MWD+IFR-AK-CA2SC(6) 11,118.09 89.03 164.82 5,350.21 5,203.72 -4,944.69 -4,439.70 5,906,975.02 456,146.15 0.28 6,625.87 MWD+iFR-AK-CAZ-SC(6) 11,213.77 88.86 162.94 5,351.97 5,205.48 -5,036.59 -4,413.14 5,906,882.99 456,172.23 1.97 6,682.57 MW3+IFR-AK-CAZ-SC(6) 11,309.99 88.41 162.81 5,354.27 5,207.78 -5,128.51 -4,384.81 5,906,790.93 456,200.07 0.49 6,738.21 MWD+IFR-AK-CAZSC(6) 11,404.89 88.21 161.58 5,357.07 5,210.58 -5,218.83 -4,355.81 5,906,700.48 456,228.60 1.31 6,792.17 MWD+IFR-AK-CAZ-SC(6) 11,500.99 87.42 162.22 5,360.73 5,214.24 -5,310.10 -4,325.98 5,906,609.05 456,257.96 1.06 6,846.38 MWD+IFR-AK-CAZ-SC(6) 11,596.67 86.94 162.16 5,365.44 5,218.95 -5,401.09 -4,296.75 5,906,517.93 456,286.71 0.51 6,900.73 MWD+IFR-AK-CAZ-SC(6) 2/3/2015 9:17:05AM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,691.75 90.61 162.11 5,367.47 5,220.98 5,491.55 -4,267.59 5,906,427.33 456,315.39 3.86 6,954.70 MWD+IFR-AK-CAZ-SC(6) 11,781.85 90.37 162.96 5,366.70 5,220.21 -5,577.49 -4,240.55 5,906,341.25 456,341.98 0.98 7,006.39 MWD+IFR-AK-CAZSC(6) 11,882.60 90.88 164.04 5,365.60 5,219.11 -5,674.08 -4,211.94 5,906,244.52 456,370.09 1.19 7,065.56 MWD+IFR-AK-CAZSC(6) 11,978.50 91.33 164.14 5,363.75 5,217.26 -5,766.29 -4,185.65 5,906,152.19 456,395.89 0.48 7,122.67 MWD+IFR-AK-CAZ-SC(6) 12,073.89 87.51 164.40 5,364.72 5,218.23 -5,858.09 -4,159.80 5,906,060.27 456,421.26 4.01 7,179.72 MND+IFR-AK-CA2SC(6) 12,165.64 80.69 166.33 5,374.14 5,227.65 -5,946.33 -4,136.75 5,905,971.91 456,443.86 7.72 7,235.66 MWD+IFR-AK-CAZ-SC(6) 12,220.00 80.69 166.33 5,382.94 5,236.45 5,998.46 -4,124.07 5,905,919.73 456,456.26 0.00 7,269.27 PROJECTED to TD 4 1/2"x 6-1/2" 12,229.00 80.69 166.33 5,384.39 5,237.90 5,007.09 -4,121.97 5,905,911.09 456,458.31 0.00 7,274.83 PROJECTED to TD Projected to TD 2/3/2015 9:17:05AM Page 6 COMPASS 5000.1 Build 65 RECEIVED Cement Detail Report FEB 19 2015 2N-336 . rvs AOGCC ConocoPhil l 1ps String: Intermediate Casing Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 1/16/2015 13:30 1/16/2015 16:30 2N-336 Comment Cemented 7 5/8"casing as follows: Pumped 5 bbls CW 100-Tested lines to 4500 psi-Pumped 35 bbls/CW100 @ 6 bbls/min©900 psi-Pumped 42 bbls 11.5 ppg MudPush II @ 5.5 bbls/min @ 890 psi-Line up valves on cmt head to drop btm plug-Mixed&pumped 151 bbls tail slurry(Class G+GASBLOK)@ 15.8 ppg @ 6 bbls/min© 1650 psi-Dropped top plug w/10 bbls water f/Dowell-Switched to rig pumps&displaced cmt w/356.8 bbls 9.7 ppg LSND mud @ 6 bbls/min 782 psi-slow pumps to 3.5 bbls/min for last 21.7 bbls of displacement-Bumped plug w/1500 psi-bled off pressure to check floats-Floats not holding -pressure up to 1100 psi&shut in head-CIP @ 1610 hrs. Reciprocated pipe until last 56 bbls of displacement-Full returns throughout job Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing 5,603.0 8,104.0 No Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 4 6 800.0 1,500.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 5,603.0 8,104.0 710 G 151.0 Yield(Wlsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.22 15.80 Additives Additive Type Concentration Conc Unit label Acelerator(Calcium Chloride) D186 gal/sx Additive Type Concentration Conc Unit label GASBLOK D600 G gal/sx Additive Type 'Concentration Conc Unit label Antifoam DO-47 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 %BWOC Page 1/1 Report Printed: 2/17/2015 RECEIVED 0'=' Cement Detail Report FEB 19 2015 2N-336 AOGCC Gonocilhps String: Surface Casing Cement _ Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/4/2015 13:00 1/4/2015 16:00 2N-336 Comment Cemented 10 3/4"casing as follows: Pumped 5 bbls 10.5 ppg MudPush II-Tested lines to 3000 psi-Pumped 95 bbls 10.5 ppg MudPush II @ 5 bbls/min @ 125 psi-Dropped btm plug-Mixed&pumped 369 bbls 11.0 ppg DeepCRETE lead slurry @ 6.4 bbl/min @ 350 psi-Observed MudPush to surface @ 369 bbls lead pumped-Switched to tail slurry-Pumped 64.72 bbls 12.0 ppg DeepCRETE @ 4.4 bbls/min @ 300 psi-Dropped top plug w/10 bbls water-Switched over to rig pump&dispalced w/245.7 bbls 9.6 ppg spud mud @ 3 bbls/min @ 350 psi Bumped plug w/850 psi -Held pressure for 5 mins.-bled off-floats held- CIP @ 1600 hrs.-full returns throughout job observed 51 bbls of 11.0 ppg cnmt to surface Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 28.0 2,638.0 No Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) -Rotated? Pipe RPM(rpm) 6 3 6 350.0 850.0 Yes 25.00 No _ Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 0.0 2,144.0 1,044 G 355.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.91 6.95 11.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,144.0 2,638.0 224 G 64.7 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.63 5.50 12.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/17/2015 ......-_..-. . RECEIVED 21 41 44 FEB 13 2015 2 5 4 0 0 AnCC SchlumbergerDrilling & Measurements Transmittal#: 13FEB15-SP01 DATA LOGGED MWD/LWD Log Product Delivery vv't/2criS M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2N-336 Date Dispatched: 13-Feb-15 Job#: 14AKA0143 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 cni conocophillips.com AlaskaPTSPrintCenter(c�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 7) ,,tufza,,z44..) o_e_oteszt Received By: 214144 25400 RECEIVED FINAL FEB 13 2015 AOGCC NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-336 Definitive Survey Report N D 2 7 03 February, 2015 Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 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 2N-336 Well Position +N/-S 0.00 usft Northing: 5,911,896.05 usft Latitude: 70°10'12.850 N +E/-W 0.00 usft Easting: 460,611.09 usft Longitude: 150°19'1.214 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.70 usft Wellbore 2N-336 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGG M2014 1/1/2015 18.78 80.75 57,545 I Design 2N-336 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 28.79 0.00 0.00 217.53 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.31 812.72 2N-336 Srvy#1-GYD-GC-SS(2N-336) GYD-GC-SS Gyrodata gyro single shots 12/30/2014 3:1' 872.03 2,565.72 2N-336 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/31/2014 11:0, 2,637.50 2,637.50 2N-336 Srvy#3-INC+TREND(2N-336) INC+TREND Inclinometer+known azi trend 1/22/2015 4:16: 2,726.85 8,042.34 2N-336 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/22/2015 4:18: 8,138.83 8,138.83 2N-336 Srvy#5-INC+TREND(2N-336) INC+TREND Inclinometer+known azi trend 2/2/2015 9:49:0 8,167.47 12,165.64 2N-336 Srvy#6-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/2/2015 5:38:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (') C) (usft) (usft) (usft) (usft) (ft) (ft) C/1001 (ft) Survey Tool Name 28.79 0.00 0.00 28.79 -117.70 0.00 0.00 5,911,896.05 460,611.09 0.00 0.00 UNDEFINED 80.31 0.33 166.71 80.31 -66.18 -0.14 0.03 5,911,895.91 460,611.12 0.64 0.09 GYD-GC-SS(1) 173.21 0.24 134.35 173.21 26.72 -0.54 0.23 5,911,895.51 460,611.32 0.19 0.29 GYD-GC-SS(1) 261.23 0.18 138.40 261.23 114.74 -0.77 0.46 5,911,895.27 460,611.54 0.07 0.33 GYD-GC-SS(1) 351.09 0.25 185.99 351.09 204.60 -1.07 0.53 5,911,894.97 460,611.61 0.21 0.53 GYD-GC-SS(1) 441.78 0.26 208.74 441.78 295.29 -1.45 0.41 5,911,894.60 460,611.49 0.11 0.90 GYD-GC-SS(1) 533.29 1.00 204.42 533.28 386.79 -2.36 -0.02 5,911,893.69 460,611.06 0.81 1.88 GYD-GC-SS(1) 628.11 2.72 203.30 628.05 481.56 -5.18 -1.25 5,911,890.88 460,609.81 1.81 4.87 GYD-GC-SS(1) 718.13 3.91 206.81 717.91 571.42 -9.88 -3.48 5,911,886.19 460,607.56 1.34 9.96 GYD-GC-SS(1) 812.72 5.27 220.58 812.20 665.71 -16.06 -7.76 5,911,880.03 460,603.24 1.84 17.46 GYD-GC-SS(1) 2/3/2015 9:17:05AM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +Ei-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (n) (1100f) (n) Survey Tool Name 872.05 6.10 223.21 871.24 724.75 -20.43 -11.69 5,911,875.69 460,599.29 1.47 23.32 MWD+IFR-AK-CAZSC(2) 965.77 7.39 230.23 964.31 817.82 -27.91 -19.73 5,911,868.24 460,591.21 1.63 34.16 MWD+IFR-AK-CAZSC(2) 1,059.87 8.90 241.10 1,057.46 910.97 -35.30 -30.76 5,911,860.91 460,580.15 2.29 46.73 MWD+IFR-AK-CAZ-SC(2) 1,154.76 9.89 247.51 1,151.08 1,004.59 -41.97 -44.71 5,911,854.32 460,566.16 1.52 60.52 MWD+IFR-AK-CAZ-SC(2) 1,249.86 11.75 248.86 1,244.49 1,098.00 -48.58 -61.29 5,911,847.79 460,549.55 1.97 75.87 MWD+IFR-AK-CAZ-SC(2) 1,344.22 17.65 253.28 1,335.72 1,189.23 -56.17 -83.98 5,911,840.32 460,526.83 6.36 95.70 MWD+IFR-AK-CAZSC(2) 1,437.50 22.54 256.24 1,423.30 1,276.81 -64.50 -114.90 5,911,832.16 460,495.86 5.35 121.15 MWD+IFR-AK-CAZ-SC(2) 1,529.91 24.01 255.72 1,508.19 1,361.70 -73.35 -150.33 5,911,823.49 460,460.39 1.61 149.74 MWD+IFR-AK-CAZ-SC(2) 1,625.50 26.71 254.08 1,594.56 1,448.07 -84.04 -189.84 5,911,813.01 460,420.83 2.92 182.29 MWD+IFR-AK-CAZ-SC(2) 1,718.78 33.38 254.74 1,675.26 1,528.77 -96.56 -234.81 5,911,800.72 460,375.80 7.16 219.61 MWD+IFR-AK-CAZ-SC(2) 1,813.70 34.57 255,42 1,753.97 1,607.48 -110.21 -286.06 5,911,787.34 460,324.48 1.32 261.66 MWD+IFR-AK-CAZ-SC(2) 1,908.78 39.03 255.46 1,830.09 1,683.60 -124.52 -341.18 5,911,773.32 460,269.30 4.69 306.59 MWD+IFR-AK-CAZ-SC(2) 2,002.11 42.44 253.95 1,900.80 1,754.31 -140.61 -399.90 5,911,757.53 460,210.50 3.80 355.12 MWD+IFR-AK-CAZ-SC(2) 2,098.09 45.92 252.31 1,969.62 1,823.13 -160.05 -463.89 5,911,738.43 460,146.41 3.82 409.52 MWD+IFR-AK-CAZ-SC(2) 2,192.03 50.14 252.52 2,032.43 1,885.94 -181.14 -530.46 5,911,717.69 460,079.74 4.50 466.79 MWD+IFR-AK-CAZSC(2) 2,285.42 52.55 254.15 2,090.76 1,944.27 -202.04 -600.32 5,911,697.16 460,009.78 2.92 525.92 MWD+IFR-AK-CAZSC(2) 2,379.89 56.13 257.10 2,145.83 1,999.34 -221.04 -674.66 5,911,678.54 459,935.35 4.56 586.28 MWD+IFR-AK-CAZSC(2) 2,473.67 56.91 259.25 2,197.57 2,051.08 -237.06 -751.21 5,911,662.92 459,858.72 2.09 645.62 MWD+IFR-AK-CAZSC(2) 2,565.72 55.83 258.30 2,248.55 2,102.06 -251.98 -826.39 5,911,648.40 459,783.48 1.45 703.24 MWD+IFR-AK-CAZSC(2) 2,637.50 55.45 258.00 2,289.06 2,142.57 -264.15 -884.38 5,911,636.54 459,725.43 0.63 748.22 INC+TREND(3) 2,638.00 55.46 258.01 2,289.35 2,142.86 -264.23 -884.78 5,911,636.45 459,725.03 1.74 748.53 MWD+IFR-AK-CAZSC(4) 10 3/4"x 13-1/2 2,726.85 56.38 259.50 2,339.14 2,192.65 -278.58 -956.96 5,911,622.48 459,652.79 1.74 803.88 MWD+IFR-AK-CAZ-SC(4) 2,820.74 56.30 258.42 2,391.18 2,244.69 -293.54 -1,033.66 5,911,607.92 459,576.02 0.96 862.47 MWD+IFR-AK-CAZSC(4) 2,915.51 56.42 257.35 2,443.68 2,297.19 -310.10 -1,110.80 5,911,591.77 459,498.80 0.95 922.59 MWD+IFR-AK-CAZSC(4) 3,009.72 56.38 257.65 2,495.82 2,349.33 -327.08 -1,187.41 5,911,575.18 459,422.11 0.27 982.73 M1ND+IFR-AK-CAZSC(4) 3,104.04 56.34 257.81 2,548.07 2,401.58 -343.77 -1,264.14 5,911,558.90 459,345.30 0.15 1,042.71 MWD+IFR-AK-CAZ-SC(4) 3,198.87 56.39 258.01 2,600.59 2,454.10 -360.31 -1,341.34 5,911,542.76 459,268.02 0.18 1,102.85 MWD+IFR-AK-CAZSC(4) 3,291.90 56.39 257.68 2,652.09 2,505.60 -376.62 -1,417.08 5,911,526.84 459,192.20 0.30 1,161.93 MWD+IFR-AK-CAZSC(4) 3,387.09 56.43 257.36 2,704.75 2,558.26 -393.76 -1,494.50 5,911,510.11 459,114.70 0.28 1,222.68 MWD+IFR-AK-CAZSC(4) 3,479.92 56.46 258.28 2,756.06 2,609.57 -410.08 -1,570.12 5,911,494.19 459,039.01 0.83 1,281.69 MWD+IFR-AK-CAZSC(4) 3,573.89 56.44 258.55 2,808.00 2,661.51 -425.81 -1,646.84 5,911,478.86 458,962.22 0.24 1,340.89 MWD+IFR-AK-CAZ-SC(4) 3,667.93 56.44 258.73 2,859.98 2,713.49 -441.24 -1,723.67 5,911,463.83 458,885.32 0.16 1,399.94 MWD+IFR-AK-CAZSC(4) 3,763.73 56.20 257.57 2,913.11 2,766.62 -457.61 -1,801.69 5,911,447.87 458,807.22 1.04 1,460.45 MWD+IFR-AK-CAZ-SC(4) 3,857.07 56.36 257.21 2,964.93 2,818.44 -474.56 -1,877.45 5,911,431.31 458,731.38 0.36 1,520.04 MWD+IFR-AK-CAZSC(4) 3,950.82 56.50 257.43 3,016.77 2,870.28 -491.71 -1,953.66 5,911,414.57 458,655.09 0.25 1,580.06 MWD+IFR-AK-CAZ-SC(4) 4,044.76 57.48 256.30 3,067.95 2,921.46 -509.61 -2,030.37 5,911,397.06 458,578.29 1.45 1,640.99 MWD+IFR-AK-CAZ-SC(4) 4,138.88 58.54 257.26 3,117.81 2,971.32 -527.86 -2,108.08 5,911,379.22 458,500.50 1.42 1,702.81 MWD+IFR-AK-CAZ-SC(4) 4,234.59 59.41 257.77 3,167.14 3,020.65 -545.59 -2,188.16 5,911,361.91 458,420.34 1.02 1,765.65 MWD+IFR-AK-CAZ-SC(4) 4,329.71 59.35 256.40 3,215.59 3,069.10 -563.89 -2,267.94 5,911,344.03 458,340.47 1.24 1,828.76 MWD+IFR-AK-CAZSC(4) 2/3/2015 9:17 05AM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc AzI TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 4,422.25 59.42 257.28 3,262.72 3,116.23 -582.02 -2,345.49 5,911,326.30 458,262.83 0.82 1,890.38 MWD+IFR-AK-CAZ-SC(4) 4,518.36 59.53 257.76 3,311.53 3,165.04 -599.91 -2,426.32 5,911,308.84 458,181.91 0.45 1,953.81 MWD+IFR-AK-CAZ-SC(4) 4,613.71 59.38 258.10 3,359.99 3,213.50 -617.08 -2,506.62 5,911,292.08 458,101.53 0.35 2,016.34 MWD+IFR-AK-CAZ-SC(4) 4,705.90 59.79 256.96 3,406.66 3,260.17 -634.25 -2,584.25 5,911,275.32 458,023.83 1.16 2,077.24 MWD+IFR-AK-CAZ-SC(4) 4,802.60 59.81 257.18 3,455.31 3,308.82 -652.95 -2,665.70 5,911,257.05 457,942.28 0.20 2,141.70 MWD+IFR-AK-CAZ-SC(4) 4,891.99 59.78 257.07 3,500.28 3,353.79 -670.16 -2,741.02 5,911,240.23 457,866.89 0.11 2,201.23 MWD+IFR-AK-CAZ-SC(4) 4,987.21 59.90 257.32 3,548.12 3,401.63 -688.41 -2,821.30 5,911,222.40 457,786.52 0.26 2,264.60 MWD+IFR-AK-CAZ-SC(4) 5,080.96 59.85 256.32 3,595.17 3,448.68 -706.90 -2,900.25 5,911,204.32 457,707.48 0.92 2,327.36 MWD+IFR-AK-CAZ-SC(4) 5,174.37 59.78 256.96 3,642.14 3,495.65 -725.56 -2,978.81 5,911,186.08 457,628.84 0.60 2,390.01 MWD+IFR-AK-CAZ-SC(4) 5,269.15 59.93 257.60 3,689.73 3,543.24 -743.60 -3,058.76 5,911,168.45 457,548.80 0.60 2,453.02 MWD+IFR-AK-CAZSC(4) 5,363.31 60.06 257.79 3,736.82 3,590.33 -760.98 -3,138.42 5,911,151.49 457,469.05 0.22 2,515.34 MWD+IFR-AK-CAZSC(4) 5,457.07 59.92 257.94 3,783.72 3,637.23 -778.05 -3,217.80 5,911,134.84 457,389.60 0.20 2,577.23 MWD+IFR-AK-CAZSC(4) 5,552.09 60.06 259.91 3,831.24 3,684.75 -793.85 -3,298.54 5,911,119.45 457,308.78 1.80 2,638.95 MWD+IFR-AK-CAZSC(4) 5,644.80 60.40 260.21 3,877.28 3,730.79 -807.74 -3,377.81 5,911,105.98 457,229.45 0.46 2,698.25 MWD+IFR-AK-CAZ-SC(4) 5,740.44 60.18 261.13 3,924.68 3,778.19 -821.21 -3,459.78 5,911,092.94 457,147.42 0.87 2,758.86 MWD+IFR-AK-CAZSC(4) 5,833.98 60.05 261.44 3,971.28 3,824.79 -833.50 -3,539.94 5,911,081.07 457,067.20 0.32 2,817.44 MWD+IFR-AK-CAZSC(4) 5,926.92 59.97 260.56 4,017.74 3,871.25 -846.09 -3,619.45 5,911,068.89 456,987.64 0.82 2,875.86 MWD+IFR-AK-CAZ-SC(4) 6,021.59 60.35 259.72 4,064.85 3,918.36 -860.15 -3,700.35 5,911,055.25 456,906.67 0.87 2,936.30 MWD+IFR-AK-CAZSC(4) 6,116.59 60.82 259.78 4,111.50 3,965.01 -874.88 -3,781.78 5,911,040.95 456,825.17 0.50 2,997.58 MWD+IFR-AK-CAZ-SC(4) 6,210.34 59.70 258.78 4,158.01 4,011.52 -890.02 -3,861.76 5,911,026.23 456,745.12 1.51 3,058.31 MWD+IFR-AK-CAZ-SC(4) 6,304.83 59.67 253.59 4,205.73 4,059.24 -909.48 -3,940.93 5,911,007.18 456,665.86 4.74 3,121.97 MWD+IFR-AK-CAZSC(4) 6,399.48 60.06 246.84 4,253.29 4,106.80 -937.18 -4,017.89 5,910,979.89 456,588.77 6.18 3,190.81 MWD+IFR-AK-CAZSC(4) 6,493.63 60.02 242.78 4,300.32 4,153.83 -971.88 -4,091.67 5,910,945.57 456,514.81 3.74 3,263.29 MWD+IFR-AK-CAZSC(4) 6,587.16 60.51 241.11 4,346.71 4,200.22 -1,010.08 -4,163.34 5,910,907.75 456,442.95 1.64 3,337.24 MWD+IFR-AK-CAZSC(4) 6,682.10 60.72 239.99 4,393.30 4,246.81 -1,050.75 -4,235.37 5,910,867.46 456,370.72 1.05 3,413.37 MWD+IFR-AK-CAZ-SC(4) 6,776.16 60.67 238.48 4,439.34 4,292.85 -1,092.71 -4,305.85 5,910,825.88 456,300.03 1.40 3,489.58 MWD+IFR-AK-CAZ-SC(4) 6,869.75 60.21 236.96 4,485.51 4,339.02 -1,136.18 -4,374.68 5,910,782.77 456,230.99 1.50 3,565.98 MWD+IFR-AK-CAZSC(4) 6,965.04 59.58 235.86 4,533.31 4,386.82 -1,181.78 -4,443.35 5,910,737.52 456,162.09 1.20 3,643.98 MWD+IFR-AK-CAZ-SC(4) 7,058.52 58.60 233.30 4,581.33 4,434.84 -1,228.25 -4,508.70 5,910,691.40 456,096.49 2.57 3,720.64 MWD+IFR-AK-CAZ-SC(4) 7,153.20 58.82 228.13 4,630.53 4,484.04 -1,279.46 -4,571.29 5,910,640.53 456,033.65 4.67 3,799.38 MWD+IFR-AK-CAZ-SC(4) 7,247.98 59.68 222.10 4,679.03 4,532.54 -1,336.91 -4,628.95 5,910,583.38 455,975.70 5.54 3,880.07 MWD+IFR-AK-CAZSC(4) 7,341.72 61.69 216.72 4,724.95 4,578.46 -1,400.05 -4,680.78 5,910,520.52 455,923.54 5.44 3,961.71 MWD+IFR-AK-CAZSC(4) 7,436.76 63.58 211.71 4,768.65 4,622.16 -1,469.83 -4,728.19 5,910,450.99 455,875.77 5.09 4,045.93 MWD+IFR-AK-CAZ-SC(4) 7,530.50 64.41 208.96 4,809.76 4,663.27 -1,542.54 -4,770.73 5,910,378.51 455,832.86 2.78 4,129.50 MWD+IFR-AK-CAZSC(4) 7,625.30 65.88 206.80 4,849.61 4,703.12 -1,618.57 -4,810.94 5,910,302.70 455,792.26 2.58 4,214.29 MWD+IFR-AK-CAZSC(4) 7,719.61 66.90 203.37 4,887.39 4,740.90 -1,696.82 -4,847.56 5,910,224.65 455,755.24 3.50 4,298.66 MWD+IFR-AK-CAZSC(4) 7,812.55 67.70 198.96 4,923.27 4,776.78 -1,776.75 -4,878.50 5,910,144.88 455,723.89 4.46 4,380.90 MWD+IFR-AK-CAZSC(4) 7,907.39 67.79 196.05 4,959.19 4,812.70 -1,860.45 -4,904.90 5,910,061.33 455,697.05 2.84 4,463.35 MWD+IFR-AK-CAZSC(4) 8,001.24 67.94 194.05 4,994.56 4,848.07 -1,944.40 -4,927.47 5,909,977.51 455,674.05 1.98 4,543.67 MWD+IFR-AK-CAZ-SC(4) 8,042.34 68.13 192.82 5,009.93 4,863.44 -1,981.47 -4,936.32 5,909,940.49 455,665.00 2.81 4,578.47 MWD+IFR-AK-CAZ-SC(4) 2/3/2015 9:17:05AM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual la 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Az( TVD TVDSS +N/S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 8,104.00 68.66 191.01 5,032.64 4,886.15 -2,037.56 -4,948.16 5,909,884.47 455,652.88 2.86 4,630.16 INC+TREND(5) 7-5/8"x 9-7/8" 8,138.83 68.97 190.00 5,045.22 4,898.73 -2,069.49 -4,954.08 5,909,852.57 455,646.79 2.86 4,659.09 INC+TREND(5) 8,167.47 68.94 188.56 5,055.51 4,909.02 -2,095.87 -4,958.39 5,909,826.22 455,642.34 4.69 4,682.64 MWD+IFR-AK-CAZ-SC(6) 8,261.77 69.37 186.97 5,089.07 4,942.58 -2,183.19 -4,970.30 5,909,738.97 455,629.98 1.64 4,759.13 MWD+IFR-AK-CAZ-SC(6) 8,356.85 70.11 183.51 5,122.00 4,975.51 -2,272.00 -4,978.43 5,909,650.22 455,621.38 3.50 4,834.52 M1MD+IFR-AK-CAZ-SC(6) 8,454.39 71.85 179.46 5,153.80 5,007.31 -2,364.15 -4,980.81 5,909,558.08 455,618.53 4.31 4,909.05 MWD+IFR-AK-CAZ-SC(6) 8,548.51 73.68 178.28 5,181.68 5,035.19 -2,454.02 -4,979.03 5,909,468.21 455,619.84 2.28 4,979.23 MWD+IFR-AK-CAZ-SC(6) 8,642.56 75.96 178.10 5,206.31 5,059.82 -2,544.74 -4,976.16 5,909,377.49 455,622.24 2.43 5,049.43 MWD+IFR-AK-CAZ-SC(6) 8,738.21 77.94 177.38 5,227.91 5,081.42 -2,637.84 -4,972.49 5,909,284.38 455,625.43 2.20 5,121.02 MWD+IFR-AK-CAZ-SC(6) 8,833.71 78.14 176.41 5,247.70 5,101.21 -2,731.13 -4,967.42 5,909,191.08 455,630.00 1.02 5,191.92 MWD+IFR-AK-CAZ-SC(6) 8,928.04 79.07 174.59 5,266.34 5,119.85 -2,823.31 -4,960.17 5,909,098.87 455,636.78 2.13 5,260.60 MWD+IFR-AK-CAZ-SC(6) 9,024.95 82.00 172.59 5,282.27 5,135.78 -2,918.29 -4,949.49 5,909,003.85 455,646.96 3.64 5,329.42 MWD+IFR-AK-CAZ-SC(6) 9,118.81 84.53 170.55 5,293.28 5,146.79 -3,010.48 -4,935.82 5,908,911.59 455,660.15 3.45 5,394.20 MWD+IFR-AK-CAZ-SC(6) 9,215.22 86.63 168.27 5,300.71 5,154.22 -3,104.95 -4,918.16 5,908,817.04 455,677.32 3.21 5,458.36 MWD+IFR-AK-CAZ-SC(6) 9,311.62 87.95 168.52 5,305.27 5,158.78 -3,199.28 -4,898.79 5,908,722.63 455,696.20 1.39 5,521.36 MWD+IFR-AK-CAZ-SC(6) 9,405.72 87.42 166.70 5,309.07 5,162.58 -3,291.11 -4,878.61 5,908,630.70 455,715.89 2.01 5,581.90 MWD+IFR-AK-CAZ-SC(6) 9,500.29 87.18 165.50 5,313.53 5,167.04 -3,382.80 -4,855.92 5,908,538.90 455,738.10 1.29 5,640.79 MWD+IFR-AK-CAZ-SC(6) 9,594.80 87.14 166.06 5,318.21 5,171.72 -3,474.30 -4,832.73 5,908,447.28 455,760.81 0.59 5,699.23 MWD+IFR-AK-CAZ-SC(6) 9,690.06 86.66 166.69 5,323.36 5,176.87 -3,566.75 -4,810.33 5,908,354.74 455,782.73 0.83 5,758.89 MWD+IFR-AK-CAZ-SC(6) 9,785.61 86.87 166.16 5,328.75 5,182.26 -3,659.48 -4,787.93 5,908,261.90 455,804.64 0.60 5,818.79 MWD+IFR-AK-CAZ-SC(6) 9,880.30 86.17 167.40 5,334.50 5,188.01 -3,751.49 -4,766.32 5,908,169.79 455,825.77 1.50 5,878.59 MWD+IFR-AK-CAZ-SC(6) 9,974.77 90.61 164.98 5,337.15 5,190.66 -3,843.16 -4,743.78 5,908,078.01 455,847.83 5.35 5,937.56 MWD+IFR-AK-CAZ-SC(6) 10,071.44 90.68 162.58 5,336.07 5,189.58 -3,935.97 -4,716.79 5,907,985.07 455,874.34 2.48 5,994.72 MWD+IFR-AK-CAZ-SC(6) 10,164.24 89.79 161.50 5,335.68 5,189.19 -4,024.24 -4,688.17 5,907,896.65 455,902.50 1.51 6,047.29 MWD+IFR-AK-CAZSC(6) 10,260.87 89.41 162.18 5,336.36 5,189.87 -4,116.06 -4,658.06 5,907,804.69 455,932.13 0.81 6,101.76 MWD+IFR-AK-CAZSC(6) 10,357.49 89.20 163.63 5,337.53 5,191.04 -4,208.40 -4,629.66 5,907,712.21 455,960.05 1.52 6,157.69 MWD+IFR-AK-CAZSC(6) 10,452.66 88.50 164.77 5,339.44 5,192.95 -4,299.95 -4,603.75 5,907,620.54 455,985.47 1.41 6,214.51 MWD+IFR-AK-CAZSC(6) 10,545.31 89.66 166.06 5,340.93 5,194.44 -4,389.60 -4,580.42 5,907,530.77 456,008.33 1.87 6,271.39 MWD+IFR-AK-CAZSC(6) 10,640.27 89.10 166.86 5,341.96 5,195.47 -4,481.92 -4,558.19 5,907,438.36 456,030.08 1.03 6,331.06 MWD+IFR-AK-CAZSC(6) 10,733.43 89.00 166.16 5,343.50 5,197.01 -4,572.49 -4,536.46 5,907,347.68 456,051.33 0.76 6,389.65 MWD+IFR-AK-CAZSC(6) 10,628.60 89.07 166.72 5,345.10 5,198.61 -4,665.00 -4,514.15 5,907,255.07 456,073.16 0.59 6,449.42 MWD+IFR-AK-CAZSC(6) 10,927.00 88.72 164.87 5,347.00 5,200.51 -4,760.37 -4,490.01 5,907,159.58 456,096.80 1.91 6,510.35 MWD+IFR-AK-CAZSC(6) 11,022.93 89.20 164.62 5,348.74 5,202.25 -4,852.90 -4,464.77 5,907,066.93 456,121.55 0.56 6,568.36 MWD+IFR-AK-CAZSC(6) 11,118.09 89.03 164.82 5,350.21 5,203.72 -4,944.69 -4,439.70 5,906,975.02 456,146.15 0.28 6,625.87 MWD+IFR-AK-CAZSC(6) 11,213.77 88.86 162.94 5,351.97 5,205.48 -5,036.59 -4,413.14 5,906,882.99 456,172.23 1.97 6,682.57 MWD+IFR-AK-CAZSC(6) 11,309.99 88.41 162.81 5,354.27 5,207.78 -5,128.51 -4,384.81 5,906,790.93 456,200.07 0.49 6,738.21 MWD+IFR-AK-CAZSC(6) 11,404.89 88.21 161.58 5,357.07 5,210.58 -5,218.83 -4,355.81 5,906,700.48 456,228.60 1.31 6,792.17 MWD+IFR-AK-CAZSC(6) 11,500.99 87.42 162.22 5,360.73 5,214.24 -5,310.10 -4,325.98 5,906,609.05 456,257.96 1.06 6,846.38 MWD+IFR-AK-CAZSC(6) 11,596.67 86.94 162.16 5,365.44 5,218.95 -5,401.09 -4,296.75 5,906,517.93 456,286.71 0.51 6,900.73 MWD+IFR-AK-CAZSC(6) 2/3/2015 9:17:05AM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual©146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1 (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,691.75 90.61 162.11 5,367.47 5,220.98 -5,491.55 -4,267.59 5,906,427.33 456,315.39 3.86 6,954.70 MWD+IFR-AK-CAZ-SC(6) 11,781.85 90.37 162.96 5,366.70 5,220.21 -5,577.49 -4,240.55 5,906,341.25 456,341.98 0.98 7,006.39 MWD+IFR-AK-CAZ-SC(6) 11,882.60 90.88 164.04 5,365.60 5,219.11 -5,674.08 -4,211.94 5,906,244.52 456,370.09 1.19 7,065.56 MWD+IFR-AK-CAZ-SC(6) 11,978.50 91.33 164.14 5,363.75 5,217.26 -5,766.29 -4,185.65 5,906,152.19 456,395.89 0.48 7,122.67 MWD+IFR-AK-CAZ-SC(6) 12,073.89 87.51 164.40 5,364.72 5,218.23 -5,858.09 -4,159.80 5,906,060.27 456,421.26 4.01 7,179.72 MWD+IFR-AK-CAZ-SC(6) 12,165.64 80.69 166.33 5,374.14 5,227.65 -5,946.33 -4,136.75 5,905,971.91 456,443.86 7.72 7,235.66 MWD+IFR-AK-CAZ-SC(6) 12,220.00 80.69 166.33 5,382.94 5,236.45 -5,998.46 -4,124.07 5,905,919.73 456,456.26 0.00 7,269.27 PROJECTED to TD 4 112"x 6-1/2" 12,229.00 80.69 166.33 5,384.39 5,237.90 -6,007.09 -4,121.97 5,905,911.09 456,458.31 0.00 7,274.83 PROJECTED to TD Projected to TD 2/3/2015 9:17:05AM Page 6 COMPASS 5000.1 Build 65 214144 25400 RECEIVED FEB 13 2015 AOGCC FINAL , ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2N Pad 2N-336 Definitive Survey Report IN A D 8 3 02 February, 2015 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 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 2N-336 Well Position +N/-S 0.00 usft Northing: 5,911,644.99 usft Latitude: 70°10'11.707 N +El-W 0.00 usft Easting: 1,600,645.19 usft Longitude: 150°19'12.331 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.70 usft Wellbore 2N-336 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (') (nT) BGG M2014 1/1/2015 18.78 80.75 57,545 Design 2N-336 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 28.79 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 28.79 0.00 0.00 217.53 Survey Program Date 2/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 80.31 812.72 2N-336 Srvy#1-GYD-GC-SS(2N-336) GYD-GC-SS Gyrodata gyro single shots 12/30/2014 3:12 872.03 2,565.72 2N-336 Srvy#2-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/31/2014 11:0, 2,637.50 2,637.50 2N-336 Srvy#3-INC+TREND(2N-336) INC+TREND Inclinometer+known azi trend 1/22/2015 4:16: 2,726.85 8,042.34 2N-336 Srvy#4-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/22/2015 4:18: 8,138.83 8,138.83 2N-336 Srvy#5-INC+TREND(2N-336) INC+TREND Inclinometer+known azi trend 2/2/2015 9:49:1 8,167.47 12,165.64 2N-336 Srvy#6-MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/2/2015 5:38:5 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 28.79 0.00 0.00 28.79 -117.70 0.00 0.00 5,911,644.99 1,600,645.19 0.00 0.00 UNDEFINED 80.31 0.33 166.71 80.31 -66.18 -0.14 0.03 5,911,644.85 1,600,645.22 0.64 0.09 GYD-GC-SS(1) 173.21 0.24 134.35 173.21 26.72 -0.54 0.23 5,911,644.45 1,600,645.42 0.19 0.29 GYD-GC-SS(1) 261.23 0.18 138.40 261.23 114.74 -0.77 0.46 5,911,644.21 1,600,645.64 0.07 0.33 GYD-GC-SS(1) 351.09 0.25 185.99 351.09 204.60 -1.07 0.53 5,911,643.91 1,600,645.72 0.21 0.53 GYD-GC-SS(1) 441.78 0.26 208.74 441.78 295.29 -1.45 0.41 5,911,643.54 1,600,645.59 0.11 0.90 GYD-GC-SS(1) 533.29 1.00 204.42 533.28 386.79 -2.36 -0.02 5,911,642.63 1,600,645.16 0.81 1.88 GYD-GC-SS(1) 628.11 2.72 203.30 628.05 481.56 -5.18 -1.25 5,911,639.82 1,600,643.91 1.81 4.87 GYD-GC-SS(1) 718.13 3.91 206.81 717.91 571.42 -9.88 -3.48 5,911,635.13 1,600,641.66 1.34 9.96 GYD-GC-SS(1) 812.72 5.27 220.58 812.20 665.71 -16.06 -7.76 5,911,628.97 1,600,637.35 1.84 17.46 GYD-GC-SS(1) 2/2/2015 5:49:58PM Page 2 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual©146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual i 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (watt) (°) (°) (usft) (usft) (waft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 872.05 6.10 223.21 871,24 724.75 -20.43 -11.69 5,911,624.63 1,600,633.39 1.47 23.32 MWD+IFR-AK-CAZSC(2) 965.77 7.39 230.23 964.31 817.82 -27.91 -19.73 5,911,617.19 1,600,625.31 1.63 34.16 MWD+IFR-AK-CAZ-SC(2) 1,059.87 8.90 241.10 1,057.46 910.97 -35.30 -30.76 5,911,609.85 1,600,614.25 2.29 46.73 MWD+IFR-AK-CAZSC(2) 1,154.76 9.89 247.51 1,151.08 1,004.59 -41.97 -44.71 5,911,603.26 1,600,600.26 1.52 60.52 MWD+IFR-AK-CAZSC(2) 1,249.86 11.75 248.86 1,244.49 1,098.00 -48.58 -61.29 5,911,596.73 1,600,583.65 1.97 75.87 MWD+IFR-AK-CAZSC(2) 1,344.22 17.65 253.28 1,335.72 1,189.23 -56.17 -83.98 5,911,589.27 1,600,560.93 6.36 95.70 MWD+IFR-AK-CAZSC(2) 1,437.50 22.54 256.24 1,423.30 1,276.81 -64.50 -114.90 5,911,581.10 1,600,529.96 5.35 121.15 MWD+IFR-AK-CAZSC(2) 1,529.91 24.01 255.72 1,508.19 1,361.70 -73.35 -150.33 5,911,572.44 1,600,494.49 1.61 149.74 MWD+IFR-AK-CAZSC(2) 1,625.50 26.71 254.08 1,594.56 1,448.07 -84.04 -189.84 5,911,561.96 1,600,454.93 2.92 182.29 MWD+IFR-AK-CAZ-SC(2) 1,718.78 33.38 254.74 1,675.26 1,528.77 -96.56 -234.81 5,911,549.68 1,600,409.90 7.16 219.61 MWD+IFR-AK-CAZ-SC(2) 1,813.70 34.57 255.42 1,753.97 1,607.48 -110.21 -286.06 5,911,536.30 1,600,358.58 1.32 261.66 MWD+IFR-AK-CAZ-SC(2) 1,908.78 39.03 255.46 1,830.09 1,683.60 -124.52 -341.18 5,911,522.27 1,600,303.40 4.69 306.59 MWD+IFR-AK-CAZ-SC(2) 2,002.11 42.44 253.95 1,900.80 1,754.31 -140.61 -399.90 5,911,506.49 1,600,244.59 3.80 355.12 MWD+IFR-AK-CAZ-SC(2) 2,098.09 45.92 252.31 1,969.62 1,823.13 -160.05 -463.89 5,911,487.40 1,600,180.51 3.82 409.52 MWD+IFR-AK-CAZ-SC(2) 2N-Anna(wp01) 2,192.03 50.14 252.52 2,032.43 1,885.94 -181.14 -530.46 5,911,466.66 1,600,113.84 4.50 466.79 MWD+IFR-AK-CAZ-SC(2) 2,285.42 52.55 254.15 2,090.76 1,944.27 -202.04 -600.32 5,911,446.13 1,600,043.87 2.92 525.92 MWD+IFR-AK-CAZ-SC(2) 2,379.89 56.13 257.10 2,145.83 1,999.34 -221.04 -674.66 5,911,427.52 1,599,969.44 4.56 586.28 MWD+IFR-AK-CAZ-SC(2) 2,473.67 56.91 259.25 2,197.57 2,051.08 -237.06 -751.21 5,911,411.90 1,599,892.82 2.09 645.62 MWD+IFR-AK-CAZSC(2) 2,565.72 55.83 258.30 2,248.55 2,102.06 -251.98 -826.39 5,911,397.38 1,599,817.57 1.45 703.24 MWD+IFR-AK-CAZSC(2) 2,637.50 55.45 258.00 2,289.06 2,142.57 -264.15 -884.38 5,911,385.52 1,599,759.52 0.63 748.22 INC+TREND(3) 2,638.00 55.46 258.01 2,289.35 2,142.86 -264.23 -884.78 5,911,385.44 1,599,759.12 1.74 748.53 MWD+IFR-AK-CAZSC(4) 10 3/4"x 13-1/2 2,726.85 56.38 259.50 2,339.14 2,192.65 -278.58 -956.96 5,911,371.47 1,599,686.88 1.74 803.88 MWD+IFR-AK-CAZSC(4) 2,820.74 56.30 258.42 2,391.18 2,244.69 -293.54 -1,033.66 5,911,356.91 1,599,610.11 0.96 862.47 MWD+IFR-AK-CAZSC(4) 2,915.51 56.42 257.35 2,443.68 2,297.19 -310.10 -1,110.80 5,911,340.76 1,599,532.89 0.95 922.59 MWD+IFR-AK-CAZSC(4) 3,009.72 56.38 257.65 2,495.82 2,349.33 -327.08 -1,187.41 5,911,324.18 1,599,456.20 0.27 982.73 MWD+IFR-AK-CAZ-SC(4) 3,104.04 56.34 257.81 2,548.07 2,401.58 -343.77 -1,264.14 5,911,307.90 1,599,379.39 0.15 1,042.71 MWD+IFR-AK-CAZ-SC(4) 3,198.87 56.39 258.01 2,600.59 2,454.10 360.31 -1,341.34 5,911,291.77 1,599,302.11 0.18 1,102.85 MWD+IFR-AK-CAZ-SC(4) 3,291.90 56.39 257.68 2,652.09 2,505.60 -376.62 -1,417.08 5,911,275.86 1,599,226.29 0.30 1,161.93 MWD+IFR-AK-CAZ-SC(4) 3,387.09 56.43 257.36 2,704.75 2,558.26 -393.76 -1,494.50 5,911,259.13 1,599,148.79 0.28 1,222.68 MWD+IFR-AK-CAZSC(4) 3,479.92 56.46 258.28 2,756.06 2,609.57 -410.08 -1,570.12 5,911,243.21 1,599,073.09 0.83 1,281.69 MWD+IFR-AK-CAZ-SC(4) 3,573.89 56.44 258.55 2,808.00 2,661.51 -425.81 -1,646.84 5,911,227.89 1,598,996.30 0.24 1,340.89 MWD+IFR-AK-CAZSC(4) 3,667.93 56.44 258.73 2,859.98 2,713.49 -441.24 -1,723.67 5,911,212.85 1,598,919.40 0.16 1,399.94 MWD+IFR-AK-CAZ-SC(4) 3,763.73 56.20 257.57 2,913.11 2,766.62 -457.61 -1,801.69 5,911,196.90 1,598,841.30 1.04 1,460.45 MWD+IFR-AK-CAZ-SC(4) 3,857.07 56.36 257.21 2,964.93 2,818.44 -474.56 -1,877.45 5,911,180.35 1,598,765.46 0.36 1,520.04 MWD+IFR-AK-CAZ-SC(4) 3,950.82 56.50 257.43 3,016.77 2,870.28 -491.71 -1,953.66 5,911,163.60 1,598,689.17 0.25 1,580.06 MWD+IFR-AK-CAZ-SC(4) 4,044.76 57.48 256.30 3,067.95 2,921.46 -509.61 -2,030.37 5,911,146.10 1,598,612.37 1.45 1,640.99 MWD+IFR-AK-CAZ-SC(4) 4,093.99 58.03 256.80 3,094.21 2,947.72 -519.29 -2,070.86 5,911,136.64 1,598,571.83 1.42 1,673.34 MWD+IFR-AK-CAZ-SC(4) 2n-336 WP02 2/2/2015 5:49:58PM Page 3 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual(fp 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Ail TVD TVDSS +N-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,138.88 58.54 257.26 3,117.81 2,971.32 -527.86 -2,108.08 5,911,128.26 1,598,534.57 1.42 1,702.81 MWD+IFR-AK-CAZ-SC(4) 4,234.59 59.41 257.77 3,167.14 3,020.65 -545.59 -2,188.16 5,911,110.96 1,598,454.41 1.02 1,765.65 MWD+IFR-AK-CAZ-SC(4) 4,329.71 59.35 256.40 3,215.59 3,069.10 -563.89 -2,267.94 5,911,093.08 1,598,374.54 1.24 1,828.76 MWD+IFR-AK-CAZ-SC(4) 4,422.25 59.42 257.28 3,262.72 3,116.23 -582.02 -2,345.49 5,911,075.36 1,598,296.91 0.82 1,890.38 MWD+IFR-AK-CAZ-SC(4) 4,518.36 59.53 257.76 3,311.53 3,165.04 -599.91 -2,426.32 5,911,057.90 1,598,215.99 0.45 1,953.81 MWD+IFR-AK-CAZ-SC(4) 4,613.71 59.38 258.10 3,359.99 3,213.50 -617.08 -2,506.62 5,911,041.15 1,598,135.60 0.35 2,016.34 MWD+IFR-AK-CAZ-SC(4) 4,705.90 59.79 256.96 3,406.66 3,260.17 -634.25 -2,584.25 5,911,024.39 1,598,057.90 1.16 2,077.24 MWD+IFR-AK-CAZ-SC(4) 4,802.60 59.81 257.18 3,455.31 3,308.82 -652.95 -2,665.70 5,911,006.12 1,597,976.35 0.20 2,141.70 MWD+IFR-AK-CAZ-SC(4) 4,891.99 59.78 257.07 3,500.28 3,353.79 -670.16 -2,741.02 5,910,989.31 1,597,900.96 0.11 2,201.23 MWD+IFR-AK-CAZ-SC(4) 4,987.21 59.90 257.32 3,548.12 3,401.63 -688.41 -2,821.30 5,910,971.48 1,597,820.59 0.26 2,264.60 MWD+IFR-AK-CAZ-SC(4) 5,080.96 59.85 256.32 3,595.17 3,448.68 -706.90 -2,900.25 5,910,953.41 1,597,741.55 0.92 2,327.36 MWD+IFR-AK-CAZSC(4) 5,174.37 59.78 256.96 3,642.14 3,495.65 -725.56 -2,978.81 5,910,935.17 1,597,662.90 0.60 2,390.01 MWD+IFR-AK-CAZSC(4) 5,269.15 59.93 257.60 3,689.73 3,543.24 -743.60 -3,058.76 5,910,917.54 1,597,582.87 0.60 2,453.02 MWD+IFR-AK-CAZSC(4) 5,363.31 60.06 257.79 3,736.82 3,590.33 -760.98 -3,138.42 5,910,900.59 1,597,503.12 0.22 2,515.34 MWD+IFR-AK-CAZSC(4) 5,457.07 59.92 257.94 3,783.72 3,637.23 -778.05 -3,217.80 5,910,883.94 1,597,423.66 0.20 2,577.23 MWD+IFR-AK-CAZSC(4) 5,552.09 60.06 259.91 3,831.24 3,684.75 -793.85 -3,298.54 5,910,868.56 1,597,342.85 1.80 2,638.95 MWD+IFR-AK-CAZ-SC(4) 5,644.80 60.40 260.21 3,877.28 3,730.79 -807.74 -3,377.81 5,910,855.09 1,597,263.51 0.46 2,698.25 MWD+IFR-AK-CAZ-SC(4) 5,740.44 60.18 261.13 3,924.68 3,778.19 -821.21 -3,459.78 5,910,842.05 1,597,181.49 0.87 2,758.86 MWD+IFR-AK-CAZ-SC(4) 5,833.98 60.05 261.44 3,971.28 3,824.79 -833.50 3,539.94 5,910,830.19 1,597,101.26 0.32 2,817.44 MWD+IFR-AK-CAZ-SC(4) 5,926.92 59.97 260.56 4,017.74 3,871.25 -846.09 -3,619.45 5,910,818.02 1,597,021.70 0.82 2,875.86 MWD+IFR-AK-CAZ-SC(4) 6,021.59 60.35 259.72 4,064.85 3,918.36 -860.15 -3,700.35 5,910,804.38 1,596,940.73 0.87 2,936.30 MWD+IFR-AK-CAZSC(4) 6,116.59 60.82 259.78 4,111.50 3,965.01 -874.88 -3,781.78 5,910,790.08 1,596,859.23 0.50 2,997.58 MWD+IFR-AK-CAZ-SC(4) 6,210.34 59.70 258.78 4,158.01 4,011.52 -890.02 -3,861.76 5,910,775.37 1,596,779.18 1.51 3,058.31 MWD+IFR-AK-CAZ-SC(4) 6,304.83 59.67 253.59 4,205.73 4,059.24 -909.48 -3,940.93 5,910,756.32 1,596,699.92 4.74 3,121.97 MVVD+IFR-AK-CAZ-SC(4) 6,399.48 60.06 246.84 4,253.29 4,106.80 -937.18 -4,017.89 5,910,729.03 1,596,622.83 6.18 3,190.81 MWD+IFR-AK-CAZ-SC(4) 6,493.63 60.02 242.78 4,300.32 4,153.83 -971.88 -4,091.67 5,910,694.72 1,596,548.87 3.74 3,263.29 MWD+IFR-AK-CAZ-SC(4) 6,587.16 60.51 241.11 4,346.71 4,200.22 -1,010.08 -4,163.34 5,910,656.90 1,596,477.01 1.64 3,337.24 MWD+IFR-AK-CAZ-SC(4) 6,682.10 60.72 239.99 4,393.30 4,246.81 -1,050.75 -4,235.37 5,910,616.61 1,596,404.77 1.05 3,413.37 MWD+IFR-AK-CAZ-SC(4) 6,776.16 60.67 238.48 4,439.34 4,292.85 -1,092.71 -4,305.85 5,910,575.03 1,596,334.08 1.40 3,489.58 MWD+IFR-AK-CAZSC(4) 6,869.75 60.21 236.96 4,485.51 4,339.02 -1,136.18 -4,374.68 5,910,531.93 1,596,265.03 1.50 3,565.98 MW10+1FR-AK-CAZSC(4) 6,965.04 59.58 235.86 4,533.31 4,386.82 -1,181.78 -4,443.35 5,910,486.69 1,596,196.13 1.20 3,643.98 MWD+IFR-AK-CAZSC(4) 7,058.52 58.60 233.30 4,581.33 4,434.84 -1,228.25 -4,508.70 5,910,440.57 1,596,130.54 2.57 3,720.64 MWD+IFR-AK-CAZSC(4) 7,153.20 58.82 228.13 4,630.53 4,484.04 -1,279.46 -4,571.29 5,910,389.70 1,596,067.69 4.67 3,799.38 MWD+IFR-AK-CAZSC(4) 7,247.98 59.68 222.10 4,679.03 4,532.54 -1,336.91 -4,628.95 5,910,332.55 1,596,009.73 5.54 3,880.07 MWD+IFR-AK-CAZSC(4) 7,341.72 61.69 216.72 4,724.95 4,578.46 -1,400.05 -4,680.78 5,910,269.70 1,595,957.58 5.44 3,961.71 MWD+IFR-AK-CAZSC(4) 7,436.76 63.58 211.71 4,768.65 4,622.16 -1,469.83 -4,728.19 5,910,200.17 1,595,909.80 5.09 4,045.93 MWD+IFR-AK-CAZSC(4) 7,530.50 64.41 208.96 4,809.76 4,663.27 -1,542.54 -4,770.73 5,910,127.70 1,595,866.89 2.78 4,129.50 MWD+IFR-AK-CAZSC(4) 7,625.30 65.88 206.80 4,849.61 4,703.12 -1,618.57 -4,810.94 5,910,051.88 1,595,826.28 2.58 4,214.29 MWD+IFR-AK-CAZ-SC(4) 7,719.61 66.90 203.37 4,887.39 4,740.90 -1,696.82 -4,847.56 5,909,973.83 1,595,789.25 3.50 4,298.66 MWD+IFR-AK-CAZ-SC(4) 7,812.55 67.70 198.96 4,923.27 4,776.78 -1,776.75 -4,878.50 5,909,894.07 1,595,757.90 4.46 4,380.90 MWD+IFR-AK-CAZ-SC(4) 2/2/2015 5:49.58PM Page 4 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual©146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Axi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (') (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,907.39 67.79 196.05 4,959.19 4,812.70 -1,860.45 -4,904.90 5,909,810.52 1,595,731.07 2.84 4,463.35 MWD+IFR-AK-CAZ-SC(4) 8,001.24 67.94 194.05 4,994.56 4,848.07 -1,944.40 -4,927.47 5,909,726.70 1,595,708.06 1.98 4,543.67 MWD+IFR-AK-CAZ-SC(4) 8,042.34 68.13 192.82 5,009.93 4,863.44 -1,981.47 -4,936.32 5,909,689.68 1,595,699.01 2.81 4,578.47 MWD+IFR-AK-CAZ-SC(4) 8,104.00 68.66 191.01 5,032.64 4,886.15 -2,037.56 -4,948.16 5,909,633.66 1,595,686.88 2.86 4,630.16 INC+TREND(5) 7-5/8"x 9-7/8" 8,138.83 68.97 190.00 5,045.22 4,898.73 -2,069.49 -4,954.08 5,909,601.76 1,595,680.79 2.86 4,659.09 INC+TREND(5) 8,167.47 68.94 188.56 5,055.51 4,909.02 -2,095.87 -4,958.39 5,909,575.41 1,595,676.34 4.69 4,682.64 MWD+IFR-AK-CAZ-SC(6) 8,261.77 69.37 186.97 5,089.07 4,942.58 -2,183.19 -4,970.30 5,909,488.16 1,595,663.98 1.64 4,759.13 MWD+IFR-AK-CAZ-SC(6) 8,356.85 70.11 183.51 5,122.00 4,975.51 -2,272.00 -4,978.43 5,909,399.41 1,595,655.37 3.50 4,834.52 MWD+IFR-AK-CAZ-SC(6) 8,454.39 71.85 179.46 5,153.80 5,007.31 -2,364.15 -4,980.81 5,909,307.27 1,595,652.52 4.31 4,909.05 MWD+IFR-AK-CAZSC(6) 8,548.51 73.68 178.28 5,181.68 5,035.19 -2,454.02 -4,979.03 5,909,217.40 1,595,653.82 2.28 4,979.23 MWD+IFR-AK-CAZ-SC(6) 8,642.56 75.96 178.10 5,206.31 5,059.82 -2,544.74 -4,976.16 5,909,126.68 1,595,656.21 2.43 5,049.43 MWD+IFR-AK-CAZ-SC(6) 8,738.21 77.94 177.38 5,227.91 5,081.42 -2,637.84 -4,972.49 5,909,033.57 1,595,659.40 2.20 5,121.02 MWD+IFR-AK-CAZ-SC(6) 8,833.71 78.14 176.41 5,247.70 5,101.21 -2,731.13 -4,967.42 5,908,940.27 1,595,663.97 1.02 5,191.92 MWD+IFR-AK-CAZ-SC(6) 8,928.04 79.07 174.59 5,266.34 5,119.85 -2,823.31 -4,960.17 5,908,848.06 1,595,670.74 2.13 5,260.60 MWD+IFR-AK-CAZ-SC(6) 9,024.95 82.00 172.59 5,282.27 5,135.78 -2,918.29 -4,949.49 5,908,753.04 1,595,680.92 3.64 5,329.42 MWD+IFR-AK-CAZ-SC(6) 9,118.81 84.53 170.55 5,293.28 5,146.79 -3,010.48 -4,935.82 5,908,660.78 1,595,694.10 3.45 5,394.20 MWD+IFR-AK-CAZ-SC(6) 9,215.22 86.63 168.27 5,300.71 5,154.22 -3,104.95 -4,918.16 5,908,566.23 1,595,711.27 3.21 5,458.36 MWD+IFR-AK-CAZ-SC(6) 9,251.01 87.12 168.36 5,302.66 5,156.17 -3,139.95 -4,910.92 5,908,531.19 1,595,718.32 1.39 5,481.71 MWD+IFR-AK-CAZ-SC(6) 2N-336 Heel EB 28Mar14 9,311.62 87.95 168.52 5,305.27 5,158.78 -3,199.28 -4,898.79 5,908,471.81 1,595,730.14 1.39 5,521.36 MWD+IFR-AK-CAZSC(6) 9,405.72 87.42 166.70 5,309.07 5,162.58 -3,291.11 -4,878.61 5,908,379.89 1,595,749.83 2.01 5,581.90 MWD+IFR-AK-CAZSC(6) 9,500.29 87.18 165.50 5,313.53 5,167.04 -3,382.80 -4,855.92 5,908,288.08 1,595,772.04 1.29 5,640.79 MWD+IFR-AK-CAZ-SC(6) 9,594.80 87.14 166.06 5,318.21 5,171.72 -3,474.30 -4,832.73 5,908,196.47 1,595,794.74 0.59 5,699.23 MWD+IFR-AK-CAZSC(6) 9,690.06 86.66 166.69 5,323.36 5,176.87 -3,566.75 -4,810.33 5,908,103.92 1,595,816.66 0.83 5,758.89 MWD+IFR-AK-CAZSC(6) 9,785.61 86.87 166.16 5,328.75 5,182.26 -3,659.48 -4,787.93 5,908,011.08 1,595,838.56 0.60 5,818.79 MWD+IFR-AK-CAZSC(6) 9,880.30 86.17 167.40 5,334.50 5,188.01 -3,751.49 -4,766.32 5,907,918.97 1,595,859.69 1.50 5,878.59 MWD+IFR-AK-CAZSC(6) 9,974.77 90.61 164.98 5,337.15 5,190.66 -3,843.16 -4,743.78 5,907,827.19 1,595,881.74 5.35 5,937.56 MWD+IFR-AK-CAZ-SC(6) 10,071.44 90.68 162.58 5,336.07 5,189.58 -3,935.97 -4,716.79 5,907,734.25 1,595,908.25 2.48 5,994.72 MWD+IFR-AK-CAZ-SC(6) 10,164.24 89.79 161.50 5,335.68 5,189.19 -4,024.24 -4,688.17 5,907,645.83 1,595,936.40 1.51 6,047.29 MWD+IFR-AK-CAZSC(6) 10,260.87 89.41 162.18 5,336.36 5,189.87 -4,116.06 -4,658.06 5,907,553.87 1,595,966.03 0.81 6,101.76 MWD+IFR-AK-CAZ-SC(6) 10,357.49 89.20 163.63 5,337.53 5,191.04 -4,208.40 -4,629.66 5,907,461.39 1,595,993.94 1.52 6,157.69 MWD+IFR-AK-CAZ-SC(6) 10,452.66 88.50 164.77 5,339.44 5,192.95 -4,299.95 -4,603.75 5,907,369.71 1,596,019.36 1.41 6,214.51 MWD+IFR-AK-CAZ-SC(6) 10,545.31 89.66 166.06 5,340.93 5,194.44 -4,389.60 -4,580.42 5,907,279.95 1,596,042.21 1.87 6,271.39 MWD+IFR-AK-CAZ-SC(6) 10,640.27 89.10 166.86 5,341.96 5,195.47 -4,481.92 -4,558.19 5,907,187.53 1,596,063.96 1.03 6,331.06 MWD+IFR-AK-CAZ-SC(6) 10,733.43 89.00 166.16 5,343.50 5,197.01 -4,572.49 -4,536.46 5,907,096.85 1,596,085.21 0.76 6,389.65 M1,ND+IFR-AK-CAZSC(6) 10,828.60 89.07 166.72 5,345.10 5,198.61 -4,665.00 -4,514.15 5,907,004.24 1,596,107.03 0.59 6,449.42 MWD+IFR-AK-CAZSC(6) 10,927.00 88.72 164.87 5,347.00 5,200.51 -4,760.37 -4,490.01 5,906,908.75 1,596,130.67 1.91 6,510.35 MWD+IFR-AK-CAZSC(6) 11,022.93 89.20 164.62 5,348.74 5,202.25 -4,852.90 -4,464.77 5,906,816.09 1,596,155.41 0.56 6,568.36 MWD+IFR-AK-CAZSC(6) 11,118.09 89.03 164.82 5,350.21 5,203.72 -4,944.69 -4,439.70 5,906,724.19 1,596,180.00 0.28 6,625.87 MW0+1FR-AK-CAZSC(6) 2/2/2015 5:19:58PM Page 5 COMPASS 5000.1 Build 65 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-336 Project: Kuparuk River Unit TVD Reference: 2N-336 Actual 146.49usft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: 2N-336 Actual @ 146.49usft(Nabors 9ES) Well: 2N-336 North Reference: True Wellbore: 2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336 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) (•/1001 (ft) Survey Tool Name 11,213.77 88.86 162.94 5,351.97 5,205.48 -5,036.59 -4,413.14 5,906,632.16 1,596,206.08 1.97 6,682.57 MWD+IFR-AK-CAZ-SC(6) 11,309.99 88.41 162.81 5,354.27 5,207.78 -5,128.51 -4,384.81 5,906,540.09 1,596,233.92 0.49 6,738.21 MWD+IFR-AK-CAZ-SC(6) 11,404.89 88.21 161.58 5,357.07 5,210.58 -5,218.83 -4,355.81 5,906,449.64 1,596,262.44 1.31 6,792.17 MWD+IFR-AK-CAZ-SC(6) 11,500.99 87.42 162.22 5,360.73 5,214.24 -5,310.10 -4,325.98 5,906,358.21 1,596,291.79 1.06 6,846.38 MWD+IFR-AK-CAZ-SC(6) 11,596.67 86.94 162.16 5,365.44 5,218.95 -5,401.09 -4,296.75 5,906,267.09 1,596,320.54 0.51 6,900.73 MWD+IFR-AK-CAZ-SC(6) 11,691.75 90.61 162.11 5,367.47 5,220.98 -5,491.55 -4,267.59 5,906,176.48 1,596,349.22 3.86 6,954.70 MWD+IFR-AK-CAZ-SC(6) 11,751.88 90.45 162.68 5,366.91 5,220.42 -5,548.86 -4,249.40 5,906,119.08 1,596,367.11 0.98 6,989.08 MWD+IFR-AK-CAZ-SC(6) 2N-336 Toe 28Mar14 EB 11,781.85 90.37 162.96 5,366.70 5,220.21 -5,577.49 -4,240.55 5,906,090.41 1,596,375.81 0.98 7,006.39 MWD+IFR-AK-CAZ-SC(6) . 11,882.60 90.88 164.04 5,365.60 5,219.11 -5,674.08 -4,211.94 5,905,993.68 1,596,403.91 1.19 7,065.56 MWD+IFR-AK-CAZ-SC(6) 11,978.50 91.33 164.14 5,363.75 5,217.26 -5,766.29 -4,185.65 5,905,901.34 1,596,429.70 0.48 7,122.67 MWD+IFR-AK-CAZ-SC(6) ' 12,073.89 87.51 164.40 5,364.72 5,218.23 -5,858.09 -4,159.80 5,905,809.42 1,596,455.07 4.01 7,179.72 MWD+IFR-AK-CAZ-SC(6) 12,165.64 80.69 166.33 5,374.14 5,227.65 -5,946.33 -4,136.75 5,905,721.06 1,596,477.66 7.72 7,235.66 MWD+IFR-AK-CAZ-SC(6) 12,220.00 80.69 166.33 5,382.94 5,236.45 -5,998.46 -4,124.07 5,905,668.88 1,596,490.06 0.00 7,269.27 PROJECTED to TD 41/2"x 6-1/2" 12.229.00 80.69 166.33 5,384.39 5,237.90 -6,007.09 -4,121.97 5,905,660.24 1,596,492.12 0.00 7,274.83 PROJECTED to TD Projected to TD 2/2/2015 5 49 58PM Page 6 COMPASS 5000.1 Build 65 E �.IVED 1 4 1 4 4 FEB 132015 25 40 1 Schlumberger AOGCC Drilling & Measurements Transmittal#: 13FEB15-SPO2 DATA LOGGED MWD/LWD Log Product Delivery Z n' ..i K.BENDEENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2N-336 Date Dispatched: 13-Feb-15 Job#: 14AKA0143 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 4500' -8050' MD LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data:DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.Rosot conocophillips.com AlaskaPTSPrintCenter(c�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 i/iJ,,a4get.fruk..4) Received By: 6_,e‘vreet OF Tk THE STATE 7 Alaska Oil and Gas � of-ALASKA Conservation Commission :-- — _01333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALAS• Main: 907 279.1433 Fax. 907.276 7542 www.aogcc.alaska gov Xueqin Yang Sr. Completions Engineer aI ' -- l 4 ConocoPhillips Alaska, Inc. 1 "f P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2N-336 Sundry Number: 315-063 Dear Mr. Yang: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED thisJC'\ day of February, 2015 Encl. RECEIVED STATE OF ALASKA FEB 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Wet ❑ Stimulate ❑., Alter Casing ❑ 'Frac Stir ❑Q 1 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips,Alaska,Inc Exploratory ❑ Development Q 214-144 3 Address: Stratigraphic ❑ Service ❑ 6.API Number P.O.Box 100360,Anchorage,Alaska 99510 50-103-20693-00 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No E KRU 2N-336 9.Property Designation(Lease Number). 10.Field/Pool(s). ADL 375074 Kuraruk 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). 12,220 5,384 9,260 5,303 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 16" 120' 120' Surface 2,616' 10-3/4" 2,644' 2,300' 5,210 psi 2,470 psi Intermediate Production 6,541' 7-5/8" 8,104' 5,030' 6,890 psi 4,790 psi Liner 4260' 4-1/2" 12,220' 5,384' Perforation Depth MD(ft). Perforation Depth TVD(ft). Tubing Size: Tubing Grade. Tubing MD(ft). N/A N/A 3-1/2" L80 7,932 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) 3-1/2"X 7-5/8"Production Packer 7,845 MD, 4,938 TVD 12.Attachments' Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations. 2/15/2015 Oil Q Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Xueqin Yang @ 265-6342 Email xueciin.yanq(a,conocophillips.com Printed Name Xueqin Yang Title Sr Completions Engineer Signature /Ct (,�' Phone 265-6342 Date 2_7'6 /-7-D is - l' COMMISSION USE ONLY Conditions of approval. Notify Commission so that a representative may witness Sundry Number: -- ` O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Pry/ fr)reo0'r✓7Q. f/'O - c-cL /// red te, t/ze Fr-44FoG u5 (Esti-7 /Cm / DIic /e, 5//'c r 15tr- (A-- 1n-Lv, Frac Fc' ct . Dr- a c WC// a 5 !^,-ye,f 'Cs-,--, r-h117s G f ao /1-4C 25- 2- 13 . Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /a —4 d 4- � APPROVED BY ! Approved by. �. �� COMMISSIONER THE COMMISSION Date: 1 I� �l�J '`M1 I4S Submit Form and Form 10-403(Revised 10/2012) GfidiaG4NsAilf 12 months from the e of approval.� Attachments in Duplicate ITL 21/6 /3- RBDM /n��.�o / / FEB 1 1 2015 2N-336 hydraulic Fracturing Stimulation Sundry Application SECTION 1—AFFIDAVIT 20 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). CPAI ConocoPhillips Alaska, Inc. Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2N-336 Kuparuk River Unit, Alaska ADL 375074, KRU Tract 136 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 2N-336 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about February 9, 2015. This Notice is being provided pursuant to 20 AAC 25.283, made effective January, 2015. The Well has been drilled as a directional well on lease ADL 375074, KRU Tract 136 as depicted on Exhibit 1 as follows: Surface Location: 113' FNL, 982' FEL, Section 3, TO9N, RO7E, UM Target Location: 2568' FNL, 708' FEL, Section 4, TO9N, RO7E, UM Bottomhole Location: 388'FNL, 5258' FEL, Section 10, TO9N, RO7E, UM Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, Paul Wharton Staff Landman cc: Xue Qin Yang . 2N-336 Hydraulic Fracturing Notice Letter February 5, 2015 Page 2 Exhibit 1 i ihl 130, \` I 'L 31 TAI N 2 07L. 20I 2�, . 2L ` �' X31 -3:1°624. ®� 4�5 L-3 24 GL-326 ) \. I f .,- 2 1 L•330 AiN-3 ►-316 �N-315 , r<-305 28 2N-30827 I 26 5 )`375108 2n-314 r. 305A ADL380053 ADL380054 ,T1 ON , 7 I 2N-302 CPAI, CPAI, ,;8 BP � 1307 N 311 2N 2i BPXA, , -IEVRON, 2N-318' = I ?N-31. avR C pp EXXON MOBIL A ,, Ni I "y2N 311 —•.,_Iv, / /2001 ,6 \ 1/31/2003 N3 / 134 1/31/2003 I 2N3rN 7\ . I 132 21;7!31133 � N-; 1/2 mile radius from .d 32 J II 33 � a 1 / s� 2N-336 Well }N I r►-320 \_. ` - 5 ,' N z // — �� ni ,__ - ?N�332PBk-3?Q 2ry�5 ''`✓??��6"'i' 'L d�1i � V3 N_. II 331 — 2,4-322?ni.3gg 2,v_33z 39?'�3o_ : jr8.3 5448-1‘17_,3_ 2N-.-- 2N-3311 Gc.� A°" 349q ?�3?6. it N-333 2w-kK . .,. —. -IP s . I 1TARN 4 N_-358 1 r' .- 43 2Nans,. rr . 1 T i ZN.S37 ', ✓,-" 1 135 4 ,,, I 2�� 3' _ livJ-� 35 2► �! • 1746 • ,7c I ADL393982 75075 .�N0 ...lir!., r' 1 CPAI, PAI, x° 1 BPXA, XA, - "N, Ell Kup ruk 1 CHEVRON, -I VRON a ? • MOBIL � ' �� EXXON21�11102IL ID /31/2001 / 2N-336 U it 1 1 165 - An:. T9N ' 1 ,0 1i 12 • 1 1 1 Well Legend I el 15 ADL390984 ADL390983 • PRODUCTION • ADL392358 I ConocoPhillips INJECTION REPSOL, CIi PLUGGED and 70&:148, ABANDONED GMT, EXE t Kuparuk River Unit Sources: ,'4 2N-336 ConocoPhillips Alaska Inc. 9/30/`023 business records and Qp 11 ,.., Paul Wharton Inec.,edor J.A.Lauruhn 23E public records ° �-aca F,.Nem* 16012002800 I opt. 2-4-15 PL l" I. , ° zz I 70&148 2N-336 Hydraulic Fracturing Notice Letter February 5, 2015 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Patrick J. Wolfe, NS Development Manager Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. Robert Kinnear Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Glenn Fredrick ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Gilbert Wong Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director • TO THE ALASKA OIL AND GAS CONSERVATION COMinuSSION 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 2N-336 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 February 5, 2015, CPAI sent a copy of the Notice by certified mail to the last known address of all 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 5th day of February,2015. Vim, 1 Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 5th day of February, 2015, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA +,". ' NOTARY PUBLIC REBECCA SWENSEN IMy Commission Expires Aug.27,2016 • 2N-336 hydraulic Fracturing Stimulation Sundry Application SECTION 2— PLAT 20 AAC 25.283 (a) (2) ADL380054 ADL380053 T10NR7E . •••2N ADL390982 • • ADL 75074 T9NR7E Legend Wells Intersecting Radius Proposed Reservoir Section •°••Proposed Well Injection Lineaments Reservoir Section 1/2 Mile Radius Well Trajectory 1/2 Mile Radius Drill Site Primary Road AK Leases CPAI ADL392358 REPSOL ADNR Protracted Sections QBLM Townships REFERENCES. Nkll Data:ConocoPhillipsAlaska Wells DatabaseATD6 ConocoPhi11ips Surface Facilities:North Slope 6K Survey 725/12 Published 3/20/13 Alaska Statewide Gil 8 Gas Leases 1/12/2115 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Wkter Wells are in the Kuparuk River Unit. 2N-336 Plat Analysis No Potable Water Aquifers are in the Kuparuk River Unit NN\ 1/19/2015 0.5 J Mks IV i3SFFAC m.d GSR 1,11:C15 CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application WELL_NAME API BUS_AREA_I BUB_ID FIELD_NAME FLUID_TYPE PERMIT_NUM STATUS WELL_ID WELL_TYPE 2N-306 501032049000 TARN DB KUP TARN PARTICIPATING AREA MWAG 204-062 ACTIVE 2N-306 INJ 2N-311 501032049100 TARN DB KUP TARN PARTICIPATING AREA 204-063 PA 2N-311 PROD 2N-311A 501032049101 TARN DB KUP TARN PARTICIPATING AREA OIL 206-179 ACTIVE 2N-311 PROD 2N-333 501032052500 TARNDB KUP TARN PARTICIPATING AREA OIL 206-025 ACTIVE 2N-333 PROD 2N-342 501032054700 TARNDB KUP TARN PARTICIPATING AREA OIL 207-068 ACTIVE 2N-342 PROD 2N-327 501032054800 TARNDB KUP TARN PARTICIPATING AREA OIL 207-069 ACTIVE 2N-327 PROD 2N-310 501032054900 TARNDB KUP TARN PARTICIPATING AREA MWAG 207-090 ACTIVE 2N-310 INJ 2N-350A 501032038901 TARNDB KUP TARN PARTICIPATING AREA OIL 214-111-0 ACTIVE 2N-350 PROD 2N-304PB1 501032038270 TARNDB KUP TARN PARTICIPATING AREA OIL 201-130 PA 2N-304 EXPEND 2N-322 501032067800 TARNDB KUP TARN PARTICIPATING AREA OIL 213-179-0 ACTIVE 2N-322 PROD 2N-322PB1 501032067870 TARNDB KUP TARN PARTICIPATING AREA 213-179-0 PA 2N-322 EXPEND 2N-322PB2 501032067871 TARN DB KUP TARN PARTICIPATING AREA 213-179-0 PA 2N-322 EXPEND 2N-336 501032069300 TARN DB KUP TARN PARTICIPATING AREA OIL 214-144-0 PROP 2N-336 PROD 2N-319A 501032027101 TARN DB KUP TARN PARTICIPATING AREA OIL 214-119-0 ACTIVE 2N-319 PROD 2N-337 501032026200 TARN DB KUP TARN PARTICIPATING AREA 198-102 PA 2N-337 PROD 2N-337A 501032026201 TARN DB KUP TARN PARTICIPATING AREA OIL 198-122 PA 2N-337 PROD 2N-337B 501032026202 TARN DB KUP TARN PARTICIPATING AREA OIL 206-163 PA 2N-337 PROD 2N-337C 501032026203 TARN DB KUP TARN PARTICIPATING AREA 214-121-0 PROP 2N-337 SVC 2N-350 501032038900 TARN DB KUP TARN PARTICIPATING AREA OIL 201-175 PA 2N-350 PROD 2N-303A 501032035201 TARN DB KUP TARN PARTICIPATING AREA OIL 214-088-0 ACTIVE 2N-303 PROD 2N-323 501032025800 TARN DB KUP TARN PARTICIPATING AREA OIL 198-071 PA 2N-323 PROD 2N-303 501032035200 TARN DB KUP TARN PARTICIPATING AREA OIL 200-169 PA 2N-303 PROD 2N-319 501032027100 TARN DB KUP TARN PARTICIPATING AREA OIL 198-197 PA 2N-319 PROD 2N-347 501032033700 TARN DB KUP TARN PARTICIPATING AREA OIL 200-063 ACTIVE 2N-347 PROD 2N-332 501032034000 TARN DB KUP TARN PARTICIPATING AREA OIL 200-079 ACTIVE 2N-332 PROD 2N-332PB1 501032034070 TARNDB KUP TARN PARTICIPATING AREA 200-079 PA 2N-332 EXPEND 2N-316 501032034200 TARNDB KUP TARN PARTICIPATING AREA OIL 200-090 ACTIVE 2N-316 PROD 2N-318 501032034300 TARNDB KUP TARN PARTICIPATING AREA OIL 200-100 PA 2N-318 PROD 2N-318A 501032034301 TARNDB KUP TARN PARTICIPATING AREA OIL 209-022 ACTIVE 2N-318 PROD 2N-349 501032034500 TARNDB KUP TARN PARTICIPATING AREA 200-111 PA 2N-349 PROD 2N-349A 501032034501 TARNDB KUP TARN PARTICIPATING AREA MWAG 200-139 ACTIVE 2N-349 INJ 2N-329 501032025700 TARNDB KUP TARN PARTICIPATING AREA OIL 198-067 ACTIVE 2N-329 PROD 2N-348 501032038400 TARNDB KUP TARN PARTICIPATING AREA MWAG 201-142 ACTIVE 2N-348 INJ 2N-302 501032038000 TARNDB KUP TARN PARTICIPATING AREA MWAG 201-115 ACTIVE 2N-302 INJ 2N-304 501032038200 TARN DB KUP TARN PARTICIPATING AREA OIL 201-130 ACTIVE 2N-304 PROD 2N-323A 501032025801 TARN DB KUP TARN PARTICIPATING AREA OIL 213-159-0 ACTIVE 2N-323 PROD 2N-313 501032025900 TARN DB KUP TARN PARTICIPATING AREA OIL 198-091 ACTIVE 2N-313 PROD 2N-305 501032034900 TARN DB KUP TARN PARTICIPATING AREA OIL 200-135 PA 2N-305 PROD 2N-305A 501032034901 TARN DB KUP TARN PARTICIPATING AREA OIL 208-202 ACTIVE 2N-305 PROD 2N-326 501032035100 TARN DB KUP TARN PARTICIPATING AREA MWAG 200-155 ACTIVE 2N-326 INJ 2N-314 501032035500 TARN DB KUP TARN PARTICIPATING AREA MWAG 200-193 ACTIVE 2N-314 INJ 2N-331 501032026500 TARNDB KUP TARN PARTICIPATING AREA MWAG 198-117 ACTIVE 2N-331 INJ 2N-343 501032026000 TARNDB KUP TARN PARTICIPATING AREA MWAG 198-092 ACTIVE 2N-343 INJ 2N-339 501032026100 TARNDB KUP TARN PARTICIPATING AREA OIL 198-100 ACTIVE 2N-339 PROD 2N-341 501032026300 TARNDB KUP TARN PARTICIPATING AREA OIL 198-103 ACTIVE 2N-341 PROD 2N-345 501032026400 TARNDB KUP TARN PARTICIPATING AREA OIL 198-113 PA 2N-345 PROD 2N-345A 501032026401 TARN DB KUP TARN PARTICIPATING AREA OIL 204-034 ACTIVE 2N-345 PROD 2N-317 501032026600 TARN DB KUP TARN PARTICIPATING AREA OIL 198-143 ACTIVE 2N-317 PROD 2N-321 501032026700 TARN DB KUP TARN PARTICIPATING AREA 198-148 PA 2N-321 INJ 2N-321A 501032026701 TARN DB KUP TARN PARTICIPATING AREA MWAG 198-173 ACTIVE 2N-321 INJ 2N-325 501032026900 TARN DB KUP TARN PARTICIPATING AREA MWAG 198-163 ACTIVE 2N-325 INJ 2N-315 501032027000 TARN DB KUP TARN PARTICIPATING AREA OIL 198-190 ACTIVE 2N-315 PROD 2N-335 501032027400 TARNDB KUP TARN PARTICIPATING AREA MWAG 198-204 ACTIVE 2N-335 INJ 2N-320 501032028700 TARNDB KUP TARN PARTICIPATING AREA OIL 199-001 ACTIVE 2N-320 PROD 2N-308 501032028800 TARNDB KUP TARN PARTICIPATING AREA MWAG 199-010 ACTIVE 2N-308 INJ 2N-307 501032029000 TARNDB KUP TARN PARTICIPATING AREA MWAG 199-017 ACTIVE 2N-307 INJ 2N-309 501032029300 TARN DB KUP TARN PARTICIPATING AREA MWAG 199-021 ACTIVE 2N-309 INJ Well data sourced from ConocoPhillips Alaska Wells Database ATDB CPAI AUTHENTICATED US GOVERNMENT INFORMATION GPO §147.101 40 CFR Ch. 1 (7-1-13 Edition) (d) The Program Description and any (iii)Middle Ground Shoal Field. other materials submitted as part of (iv)Trading Bay Field. the original application or as supple- (3) The portions of aquifers on the ments thereto. North Slope described by a '/4 mile area [51 FR 16684, May 6, 1986, as amended at 56 beyond and lying directly below the FR 9411,Mar.6,1991] Kuparuk River Unit oil and gas pro- ducing field. §147.101 EPA-administered program. (a) Contents. The UIC program in the §147.103 Existing Class I, II (except State of Alaska for Class I, III, IV, and enhanced storage)recoveryaand hydro- carbon and III wells au- V wells, and for all classes of wells on thorized by rule. Indian lands, is administered by EPA. Maximum injection pressure. The This program consists of the UIC pro- gram requirements of 40 CFR parts 124, owner or operator shall limit injection 144, 146, 148, and any additional require- pressure to the lesser of: ments set forth in the remainder of (a) A value which will not exceed the this subpart. Injection well owners and operating requirements of §144.28(f)(3) operators, and EPA shall comply with (i)or(ii)as applicable; or these requirements. (b)A value for well head pressure cal- (b) Effective dates. The effective date culated by using the following formula: of the UIC program for all non-Class II Pm=(0.733-0.433 Sg)d wells in Alaska and for all wells on In- dian lands,is June 25, 1984. where: Pm=injection pressure at the well head in [52 FR 17680, May 11, 1987, as amended at 56 pounds per square inch FR 9412,Mar.6,1991] Sg=specific gravity of inject fluid(unitless) 147.102 Aquifer exemptions. d=injection depth in feet. (a) This section identifies any §147.104 Existing Class II enhanced aquifers or their portions exempted in recovery and hydrocarbon storage accordance with §§144.7(b) and 146.4 of wells authorized by rule. this chapter at the time of program (a) Maximum injection pressure. (1) To promulgation. EPA may in the future meet the operating requirements of exempt other aquifers or portions, ac- §144.28(f)(3)(ii) (A) and (B) of this chap- cording to applicable procedures, with- ter, the owner or operator: out codifying such exemptions in this (i) Shall use an injection pressure no section. An updated list of exemptions greater than the pressure established will be maintained in the Regional of- by the Regional Administrator for the fice. field or formation in which the well is (b) The following aquifers are ex- located. The Regional Administrator empted in accordance with the provi- shall establish maximum injection sions of§§144.7(b)and 146.4 of this chap- pressures after notice, opportunity for ter for Class II injection activities comment, and opportunity for a public only: hearing, according to the provisions of (1) The portions of aquifers in the part 124, subpart A of this chapter, and Kenai Peninsula, greater than the indi- will inform owners and operators in cated depths below the ground surface, writing of the applicable maximum and described by a 1/4 mile area beyond pressure; or and lying directly below the following (ii) May inject at pressures greater oil and gas producing fields: than those specified in paragraph (i) Swanson River Field-1700 feet. (a)(1)(i) of this section for the field or (ii) Beaver Creek Field-1650 feet. formation in which he is operating pro- (iii)Kenai Gas Field-1300 feet. vided he submits a request in writing (2) The portion of aquifers beneath to the Regional Administrator, and Cook Inlet described by a 1/4 mile area demonstrates to the satisfaction of the beyond and lying directly below the Regional Administrator that such in- following oil and gas producing fields: jection pressure will not violate the re- (i)Granite Point. quirement of §144.28(f)(3)(ii) (A) and (ii)McArthur River Field. (B). The Regional Administrator may 890 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 3—FRESHWATER AQUIFERS 20 AAC.25.283 (a) (3) There are no freshwater aquifers orJunderground sources of drinking water within a one-half mile radius of the currsarst or proposed wellbore trajectory. See conclusion of the Aquifer Exception Order No. 2–Milne Point Unit. Which states "Those portions of fr-dshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwtr aquifers under 10 AAC 25.440" r SL/7._ ci lye. !off CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 4—PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283 (a) (4) There are no water wells located within 1/2 mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application 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. CPAI • 2N-336 hydraulic Fracturing Stimulation Sundry Application SECTION 6—CASING & CEMENT ASSESSMENTS 20 AAC 25.283 (a) (6) 2N-336: 10-3/4" Casing cement job was pumped on 1/4/2015 as designed. Pumped 369 bbls 11.0 ppg DeepCRETE lead slurry and 64.72 bbls 12.0 ppg DeepCRETE tail slurry, bumped plug, hold pressure for 5 minutes, bleed off, float hold, full return through job, 51 bbls 11.0 ppg cement return to surface. On 01/07/2015, pressure tested 3,000psi by 30 minutes,good test. 7-5/8" Casing cement job was pumped on 1/16/2015 as designed. Mixed & pumped 15.8 ppg (Class G +GASBLOK) cement slurry and displaced with 9.7 ppg mud. Bumped plug w/ 1500 psi- bled off pressure to check floats- Floats not holding- pressure up to 1100 psi &shut in head— CIP; full returns throughout job.TOC is estimated as+/-5,600'--600' above Iceburger top. On 1/20/2015, 7-5/8" casing was tested 3,000psi and hold pressure for 30 minutes,good test. 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. CPAI • 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 7—PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASING AND TUBING INSTALLED IN THE WELL 20 AAC 15.281 (a) (7) • On 01/07/2015, 10-3/4" casing was pressure tested 3,000psi by 30 minutes, good test. • On 1/20/2015, 7-5/8" casing was tested 3,000psi and hold pressure for 30 minutes, good test. • On 1/29/2015 the 3.5" tubing was pressure tested to 3,500psi for 30 mins and it passed. • The 3.5"tubing will be pressure tested to 3,500 psi prior to fracturing. • The 7-5/8" casing will be pressure tested to 3,500 psi prior to fracturing. CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 8—PRESSURE RATING AND SCHEMATICS FOR THE WELLBORE,WELLHEAD, BOPE AND TREATING HEAD 20 AAC 15.281 (a) (8) Casing/Tubing Size Weight Grade API Burst API Collapse (inch) (Ib/ft) (psi) (psi) 10%" 45.5 L80 5,210 2,470 7%" 29.7 L80 6,890 4,790 7%" 39 TN110SS 11,480 10,370 4%" 12.6 L80 8,430 7,500 4%" 12.6 C110 11,590 9,200 3%%" 9.3 L80 10,160 10,530 CPAI • 2N-336 Hydraulic Fracturing Stimulation Sundry Application Stimulation Surface Rig-Up a z Bleed/Tattle 104 0"411 \' ' Tale Tank lir CO As 20 A 1/ 4) mb 0 g - • Minimum pressure rating on all surface treating lines 10,000 psi X004 00110 • Main treating line PRV is set to 95%of max treating pressure m • IA parallel PRV set to 3500 psi 11�®:4 • Frac pump trip pressure setting are 03 3 01 staggered and set below main treating line PRV N T a, v 46. i� `' c 1104 — a E H rtt i j tit►! ji Y A N 4mui dwwnd 0 Pcp-Off Tank a`, d E N c a, Da Pump Truck Pop-Ofl Tank aN um`om .74004 F-J L J R N N E 0 W O Frac Pump +j}— — Frac Pump Frac Pump {- -- N — Frac Pump Frac Pump -Aki— — } Frac Pump CPAI • 2N-336 Hydraulic Fracturing Stimulation Sundry Application Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON CONNECTION i i �� , .4-'n r „rt„. /REMOTE OPERATED ( ,,, MASTER VALVE I Oat rO, M ' i Ir\/�� MANUAL OPERATED M` MASTER VALVE s.► 1•1111111.11111•11111111 MiOn•Me• / Stinger / Stinger 11 17.„.„..„_____,,,MANDREL 4.1 L. 9 VENT `•=®I.11---VALVE I \ OPEN Iii tut iii /i, kk:0 I A��\,,' FLOW TEE AND - iiy�m_��01 VENT VALVE WELLHEAD _. ti. - ;i,...1- WELLHEAD ,• _.•- F ._ .. VALVES t6, 1 CLOSED _' I -i .,„ = OUAD PACKOF F H.., ''''4.4).,,, 4., ASSEMBLY IN � im ' 4 tt PLACE IN TUBING t TUBING ri. r • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 41/2 tubing and 1.75" down 31/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm CPAI - 2N-336 Hydraulic Fracturing Stimulation Sundry Application Tarn 2N-336 Trip Grass Roo'S Topeot Norizon'al Multl-Stage Frac'cl Prorlucsl ConoeoPhillips Final Wellbore Schematic 4tMF on?. - • .- ,:c.._e^:L:- :X 5-v c'C:e4 3.er'7••'ac e^JJD^1e^:'. -Jt _ ___ - J16"Existing Cemented Conductor. 1e"82.5#B-35 120"MD 3•:'Clmoc DE I NIOPA 2.576' tB.MD 13-1l2"Surface Hole Surface Casing- 10-314"45.5#L-80 HydnI 563 s -t'canoD r.BMo 2.644'MD,'2,300'TVD g5e'' 3.0C3 MD a wroan:3n Top 3,060'MD r:,sir-,,c I 1 3':'-1'Camoo KaelO 4.57fMD rtr'ate1 tc cf ce'••ert C•-E'SC,3 UC €37 ax.eeT C���-37 �,h 3 r Camoo rano1:11 3-+W 9.3#L-80 EUE8RD 11.626-14D4W 12.6#L-80 IBTM top joint to surface 3•:'.1'Camoo KBM4 7,271110 ill 3 -1'^ar,oc r:HMO 9-7/8"Intermediate Hole DC).-3.CC v,7.'s MC TD:8,114'MD 15,035'TVD s'69c CI ;2C Baser CAW S.ctrog S+eeve CLOSED a'_.912 Cama CS "rte.-.'97 AID 3 :'Camcc= 3 5 e 7 E.5'.Salts Prerrter Ratter NICGO 276'r {>>. i��.� '.e:4 MD 7-SS'r 4-'.o'Sur Fel tact Lter ttmmer Mt.ecr-a NLE? = _ - DCF'ref to patter.7,93414D 7.ea_ MC a,RS Nape.7.953 LID j)nterrmediate Casing Toperh 1 Allh. 7-518"NJ/ft.-80 fa 7.864'8 440'TN 11 OSS 39#ft 8.104'—all Hydr>ll 563 connections .• ' kr'R1.nnino DD Baker tWeer ` Liner 113' Pacaarc.Sea:n total 6-1/2"Production Hole 'cLGSti*ELO Heel: 10.0 PPG 41:2' 12.3# IF . . 111 i--I ■ H521 C-}10 r. ... • ■ ■ ■ . t ■ ■ C 1 Production Liner t®91`: f 1 2' 123#L 3C IBTM Bator Frac Vane, Perforated sub Bermuda Pore Pressure - Batn Fra boil drill to TO with 9-8€i mud. MD to 12.220'MD uat to 1.446-.7ea @ 12,010' 4.i17C'TVDto5,384'TVD in"4' CPAI • 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 9—DATA FPR FRACTURING ZONE AND CONFINING ZONES 20 AAC 15.281 (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 212' TVT (1617' MD)thick at the heel and approximately 80' TVT at the toe of the well, with the top of the Bermuda starting at 8,363' MD/5,124'TVD. The Bermuda is a mix of laminated shale, siltstone, and sandstone. The confining zone of the C-37 to the T-3 is approximately 994' TVT(2,201' MD) thick, with the top of the C-37 starting at 6,133' MD/3,974'TVD. The C-37 to the T-3 is a mix of shale, siltstone, and sandstone lithologies. The estimated fracture gradient for the Bermuda is 14-15 ppg. CPAI • 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 10—LOCATION, PRIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFIN9nZONE 20 AAC 15.281 (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: 2N-337: 5-1/2" casing run and cemented on 12/15/2014.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with15.8ppg Class G cement, displaced with mud. Full returns were seen throughout the job.The plug bumped @ 1,200 psi and the floats were checked and they held. On 12/17/2014, 5 1/2" casing was pressure tested to 3,000 psi for 30 minutes,good test. 2N-335: 5-1/2" casing run and cemented on 10/19/1998.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with15.8ppg Class G cement, displaced with mud. Reciprocated pipe and full returns were seen throughout the job.The plug bumped @ 2,000 psi and the floats were checked and they held. On same day, 5 1/2" casing was pressure tested to 3,500 psi for 30 minutes,good test. 2N-339: 5-1/2" casing run and cemented on 5/29/1998.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with15.8ppg Class G cement, displaced with mud.The plug bumped and the floats were checked and they held. On 5/30/1998, 5 1/2" casing was pressure tested to 3,500 psi for 30 minutes,good test. 2N-350:7" casing run and cemented on 10/5/2014.The cement job report shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with15.8ppg Class G cement, displaced with mud. Reciprocated pipe and full returns were seen throughout the job.The plug bumped @ 1,250 psi and the floats were checked and they held. On 10/8/2014, 5 1/2" casing was pressure tested to 3,000 psi for 30 minutes, good test. 2N-341: 5-1/2" casing run and cemented on 7/5/1998.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with15.8ppg Class G cement, displaced with mud.The plug bumped with 190psi over than displacement pressure. On 7/6/1998, 5 1/2" casing was pressure tested to 3,500 psi for 30 minutes,good test. 2N-343: 7" casing run and cemented on 5/17/1998.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with15.8ppg Class G cement, displaced with mud.The plug bumped. On 5/18/1998, 7" casing was pressure tested to 3,500 psi for 30 minutes,good test. CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application 2N-333: 7" casing run and cemented on 3/16/2006.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with15.8ppg Class G cement, displaced with mud.The plug bumped with 1,800psi and the floats were checked. On 3/17/2006, 7" casing was pressure tested to 3,500 psi for 30 minutes,good test. 2N-319: 5-1/2" casing run and cemented on 11/9/2014.The cement job report shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with12.0ppg LiteCrete cement,displaced with mud.The plug bumped with 2,200psi and the floats were checked and hold. On 11/11/2014, 5 1/2" casing was pressure tested to 3,500 psi for 30 minutes,good test. CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 11—LOCATION OF,®RIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE COWING ZONES 20 AAC 15.281 (a) (11) Of1.&1/.-2 CPAI has formed the opinion, based on seismic, well, and subsurface information currently available that there is no known fault or fracture that transects the confining zone within one half mile radius of the wellbore trajectory for 2N-336. CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application ADL380054 ADL38C T10N R7E . .• ADL390982 • Kuparuk River Unit VIII ADL 75074 T9N R7E f Legend Proposed Reservoir Section ••••Proposed Well Well Trajectory 1/2 Mile Radius Or11 Site Primary Road CPAI Operated Units AK Leases CPAI REPSOL Alaska Protracted Sections [1=11BLM Townships REFERENCES Nkat Data'ConocoPhillips Alaska Wells Database ATDB ConoeoPhi I I i ps Surface Facilities:North Slope 6K Survey 7/25/12 Published 3!20113 Alaska Statewide Oil B Gas Leases 1112r2015 Alaska,Inc. Water Well Data DNR-Groundwater Division >No Potable Wafer Wells are in the Kuparuk River Una N 2N-336 Plat Analysis >No Potable Water Aquifers are a the Kuparuk River Unit /I\V 2/4/2015 .43.3e,AA<m=a csa:4.015 CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application SECTION 12—PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 15.281 (a) (12) 2N-336 was drilled and completed in January 2015 as a horizontal producer in the Bermuda formation. The well will has an approximately 4,120' horizontal placed in the Burmuda sand and completed with 3.5" tubing and a 4.5" liner with a pressure activated sleeve at the toe and 7 ball actuated sliding sleeves and swellable packers between each sleeve. We will drop a ball (progressively getting larger) for each stage frac job, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Part II Proposed Procedure: Schlumberger Pumping Services: (Bermuda sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 23 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1002 F seawater (approx. 9,734 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU SLB Frac Equipment capable of 20 BPM @ 6000 psi, with a minimum of 1 stand-by pump, primed and pressure tested. See appendix for pumping equipment layout. 7. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 8. PT Surface lines to 9,000 psi using a Pressure test fluid. 9. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 10. Pressure up and maintain 2,500psi on the IA. 11. Pump the 133bb1 DataFrac 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 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. Perform hard shutdown, monitor pressure. Then followed with a crosslinked gel Calibration test as the pumping schedule. 12. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 13. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 7,150 psi. CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application Stage 1 • 360 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 120 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 130 bbls YF127ST w/4 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 6 ppa 16/20 Carbolite • Drop ball 1.5" ball, displace 15 bbls X-link gel Stage 2 • 360 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 120 bbls YF127ST w/3 ppa 16/20 Carbolite • 130 bbls YF127ST w/4 ppa 16/20 Carbolite • 140 bbls YF127ST w/5 ppa 16/20 Carbolite • 140 bbls YF127ST w/6 ppa 16/20 Carbolite • Drop ball 1.625" ball, displace 12 bbls X-link gel Stage 3 • 360 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 120 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 130 bbls YF127ST w/4 ppa 16/20 Carbolite • 140 bbls YF127ST w/5 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 6 ppa 16/20 Carbolite • Drop ball 1.750" ball, displace 12 bbls X-link gel Stage 4 • 410 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3pp a 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 130 bbls YF127ST w/6 ppa 16/20 Carbolite • 140 bbls YF127ST w/7 ppa 16/20 Carbolite • Drop ball 1.875" ball, displace 12 bbls X-link gel Stage 5 CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application • 410 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 130 bbls YF127ST w/ 6 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 7 ppa 16/20 Carbolite • Drop ball 2.000" ball, displace 12 bbls X-link gel Stage 6 • 410 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/5 ppa 16/20 Carbolite • 130 bbls YF127ST w/6 ppa 16/20 Carbolite • 140 bbls YF127ST w/7 ppa 16/20 Carbolite • Drop ball 2.063" ball, displace 12 bbls X-link gel Stage 7 • 490 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/5 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 6 ppa 16/20 Carbolite • 140 bbls YF127ST w/ 7 ppa 16/20 Carbolite • 150 bbls YF127ST w/8 ppa 16/20 Carbolite • Drop ball 2.125" ball, displace 12 bbls X-link gel Stage 8 • 490 bbls YF127ST Pad • 100 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF127ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF127ST w/3 ppa 16/20 Carbolite • 120 bbls YF127ST w/4 ppa 16/20 Carbolite • 130 bbls YF127ST w/5 ppa 16/20 Carbolite • 140 bbls YF127ST w/6 ppa 16/20 Carbolite • 140 bbls YF127ST w/7 ppa 16/20 Carbolite CPAI 2N-336 Hydraulic Fracturing Stimulation Sundry Application • 150 bbls YF127ST w/8 ppa 16/20 Carbolite • Flush with 68 bbls linear fluid (WF127) and 17 bbls freeze protect • Total Sand: Approx. 973,015 lbs 16/20 Carbolite 14. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 15. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 16. Well is ready for Post Frac well prep for flowback, the main Post Frac operation steps are: • Coiled tubing to clean the fill from tubing and milling the frac balls and ball seats. • Slickline to pull SOV, set CA-2 plug in 2.75" No-go Nipple. Displace IA with diesel, and replace the dummy valves as designed gas lift valves. • Conduct MIT test in tubing; pull CA-2 Plug from 2.75" XN nipple. 17. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) CPAI Y ` • ATTACHMENT 1:PUMP SCHEDULE Activity ZX02 MAWP Slurry Rate 20 Highest Pump Trip Proppant Densly 2.74 Well Name 2N-336 Network number 10360214 Nitrogen PRV Annulus Pressure Fluid Type YF127ST Proppant Used 1620CarboUte STEP STAGE COMMENTS FLUID PUMP CF DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps. PUMP TIME a TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker STAGE CUM (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LES) (LBS) (BBL) (BBL) (#IMgal) (hh:mm:ss) (hh:mm:es) t Injection test WF127 20 20.0 133 133 5596 5596 133 133 8.0 00:06:39 00:06:39 Hard shutdown;monitor mamma. 0.0 00:30:00 00:36:39 2 Pad YF127ST 20 20.0 80 213 3360 8956 80 213 8.0 00:04:00 00:40:39 3 1 Sand YF127ST 20 19.2 50 263 2100 11056 2012 2012 t620carboub 48 261 8.0 00:02:30 00:43:09 4 Spacer YF127ST 20 20.0 80 343 3360 14416 80 341 8.0 00:04:00 00:47:09 5 Displacement WF127 20 20.0 133 476 5596 20012 133 474 8.0 00:06:39 00:53:48 Hard shutdown;monitor pressure. FLUID PUMP CF DIRTY VOLUME PROPPANT CLEAN VOLUME Encaps PUMP TIME STEP ST GE AVERAGE COMMENTS TYPE RATE RATE STAGE CUM STAGE CUM STAGE CUM SIZE GROSS CUM Breaker STAGE CUM A PPA (BPM) (BPM) (BBL) (BBL) (GAL) (GAL) (LBS) (LBS) (BBL) (BBL) (4Mga1) (BBL) (BBL) 6 PAD YF127ST 20 20.0 360 836 15120 35132 0 2012 0 360 834 8.0 00:18:00 00:18:00 ' 7 1 FLAT YF127ST 20 19.2 100 936 4200 39332 4024 6,036 term citreous 96 930 9.0 00:05:00 00:23:00 8 2 FLAT YF7275T 20 18.4 100 1036 4200 43532 7724 13,760 1620c.rboLae 92 1022 9.0 00:05:00 00:28:00 9 3 FLAT YF127ST 20 17.7 120 1156 5040 48572 13365 27,125 1620carboul. 106 1128 9.0 00:06:00 00:34:00 • 10 4 FLAT YF7275T 20 17.0 130 1286 5460 54032 18587 45,712 1620 Cr6o,M 111 1239 10.0 00:06:30 00:40:30 11 5 FLAT YF127ST 20 16.4 140 1426 5880 59912 24122 69,834 1420Grbolb 115 _ 1354 11.0 00:07:00 00:47:30 12 6 FLAT YF127ST 20 15.8 140 1566 5880 65792 27943 97,777 1420068m.s 111 1465 12.0 00:07:00 00:54:30 13 Ball 1.0' DISPLACE YF127ST 20 20.0 15 1581 630 66422 0 97,777 15 1480 8.0 00:00:45 00:55:15 14 PAD YF12751 20 20.0 360 1941 15120 81542 0 97,777 360 1840 8.0 00:18:00 01:13:15 15 1 FLAT YF127ST 20 19.2 100 2041 4200 85742 4024 101,801 1H0CarMIA. 96 1935 9.0 00:05:00 01:18:15 16 2 FLAT YF1275T 20 18.4 100 2141 4200 89942 7724 109,525 teas Cream 92 2027 9.0 00:05:00 01:23:15 17 3 FLAT YF127ST 20 17.7 120 2261 5040 94982 13365 122,890 teas Grb.LN _ 106 2133 9.0 00:06:00 01:29:15 18 4 FLAT YF127ST 20 17.0 130 2391 5460 100442 18587 141,477 11620086olw 111 2244 10.0 00:06:30 01:35:45 19 5 FIAT YF127ST 20 16.4 140 2531 5880 106322 24122 165,599 1660 CrbmL 115 2359 11.0 00:07:00 01:42:45 20 6 FIAT YF127ST 20 15.8 140 2671 5880 112202 27943 193,542 16/20CarbW2e 111 2470 12.0 00:07:00 01:49:45 • 21 Ball 1.625" DISPLACE YF127ST 20 20.0 12 2683 504 112706 0 193,542 12 2482 8.0 00:00:36 01:50:21 22 PAD YF127ST 20 20.0 360 3043 15120 127826 0 193,542 360 2842 8.0 00:18:00 02:08:21 23 1 FLAT YF127ST 20 19.2 100 3143 4200 132026 4024 197,566 11200960(9. 96 2938 9.0 00:05:00 02:13:21 24 2 FLAT YF127ST 20 18.4 100 3243 4200 136226 7724 205,290 1668CrbxAs 92 3030 9.0 00:05:00 02:18:21 25 3 FLAT YF127ST 20 17.7 120 3363 5040 141266 13365 218,655 teas Cowles 106 3136 9.0 00:06:00 02:24:21 26 4 FLAT YF127ST 20 17.0 130 3493 5460 146726 18587 237,242 10,40068e1.44 111 3246 10.0 00:06:30 02:30:51 27 5 FIAT YF127ST 20 16.4 140 3633 5880 152606 24122 261,364 1620CrNM0. 115 3361 11.0 00:07:00 02:37:51 28 6 FLAT YF127ST 20 15.8 140 3773 5880 158486 27943 289,307 IRMO Owing*. 111 3472 12.0 00:07:00 02:44:51 29 Ball 1.750" DISPLACE YF127ST 20 20.0 12 3785 504 158990 0 289,307 12 3484 8.0 00:00:36 02:45:27 30 PAD YF12751 20 20.0 410 4195 17220 176210 0 289,307 410 3894 8.0 00:20:30 03:05:57 31 1 FLAT YF12751 20 19.2 100 4295 4200 180410 4024 293,331 tSrmcrbelas 96 3990 8.0 00:05:00 03:10:57 32 2 FLAT YF127ST 20 18.4 100 4395 4200 184610 7724 301,055 1420 Canada 92 4082 9.0 00:05:00 03:15:57 33 3 FLAT YF127ST 20 17.7 110 4505 4620 189230 12252 313,306 14200960(9. 97 4179 9.0 00:05:30 03:21:27 34 4 FLAT YF127ST 20 17.0 120 4625 5040 194270 17157 330,463 1129088489. 102 4281 9.0 00:06:00 03:27:27 35 5 FLAT 7F7275T 20 16.4 130 4755 5460 199730 22399 352,862 i 40cr6mae 107 4388 10.0 00:06:30 03:33:57 36 6 FLAT YF127ST 20 15.8 130 4885 5460 205190 25947 378,810 too caroms 103 4491 11.0 00:06:30 03:40:27 ' 37 7 FLAT YF127ST 20 15.3 140 5025 5880 211070 31508 410,318 ismaCrbab 107 4598 12.0 00:07:00 03:47:27 38 Ball 1.875" DISPLACE YF127ST 20 20.0 12 5037 504 211574 0 410,318 12 4610 8.0 00:00:36 03:48:03 ' 39 PAD YF127ST 20 20.0 410 5447 17220 228794 0 410,318 410 5020 8.0 00:20:30 04:08:33 40 1 FLAT YF127ST 20 192 100 5547 4200 232994 4024 414,342 1420 Garbo/le 96 5116 8.0 00:05:00 04:13:33 • 41 2 FLAT YF127ST 20 18.4 100 5647 4200 237194 7724 422,066 term comm. 92 5208 9.0 00:05:00 04:18:33 42 3 FLAT YF127ST 20 17.7 110 5757 4620 241814 12252 434,317 1424 areas* 97 5305 9.0 00:05:30 04:24:03 43 4 FLAT YF127ST 20 17.0 120 5877 5040 246854 17157 451,474 is=con's* 102 5407 9.0 000600 04:30:03 44 5 FLAT YF127ST 20 16.4 130 6007 5460 252314 22399 473,873 1e20 commas 107 5514 10.0 00:0610 04:36:33 45 6 FIAT YF127ST 20 15.8 130 6137 5460 257774 25947 499,820 Iwo CsrbMus 103 5617 11.0 00:06:30 04:43:03 46 7 FLAT YF127ST 20 15.3 140 6277 5880 263654 31508 531,329 Iwo amass 107 5724 12.0 00:07:00 04:50:03 47 Ball 2.000" DISPLACE YF127ST 20 20.0 12 6289 504 264158 0 531,329 12 5736 8.0 000036 04:50:39 48 PAD YF12751 20 20.0 410 6699 17220 281378 0 531,329 410 6146 8.0 00:20:30 05:11:09 49 1 FLAT YF127ST 20 19.2 100 6799 4200 285578 4024 535,352 Imo cream 96 6242 8.0 00:05:00 05:16:09 50 2 FIAT YF127ST 20 18.4 100 6899 4200 289778 7724 543,076 14486880p 92 6334 9.0 00:0500 0521:09 51 3 FLAT YF127ST 20 17.7 110 7009 4620 294398 12252 555,328 1624 creels 97 6431 9.0 00:05:30 05:26:39 52 4 FLAT YF127ST 20 17.0 120 7129 5040 299438 17157 572,485 1520 crbolp 102 6533 10.0 00:06:00 05:32:39 53 5 FLAT YF127ST 20 164 130 7259 5460 304898 22399 594,884 tom 60000lb 107 6640 11.0 00:0630 05:39:09 54 6 FLAT YF127ST 20 15.8 130 7389 5460 310358 25947 620,831 IRMO 800Omb 103 6743 12.0 00:06:30 05:4519 55 7 FIAT YF127ST 20 15.3 140 7529 5880 316238 31508 652,339 term Commie 107 6850 12.0 00:07:00 05:52:39 56 Ball2.063" DISPLACE YF127ST 20 20 12 7541 504 316742 0 652,339 12 6862 8.0 00:00:36 05:53:15 57 PAD YF127ST 20 20.0 490 8031 20580 337322 0 652,339 490 7352 8.0 00:2430 06:17:45 • 59 1 FIAT YF127ST 20 192 100 8131 4200 341522 4024 656,363 1e20 comas. 96 7448 8.0 00:05:00 06:22:45 59 2 FIAT YF127ST 20 18.4 100 8231 4200 345722 7724 664,087 1620 Caremb 92 7540 9.0 000600 06:27:45 60 3 FLAT YF127ST 20 17.7 110 8341 4620 350342 12252 676,339 1620 cremes 97 7637 9.0 00:05:30 06:33:15 61 4 FIAT YF127ST 20 17.0 120 8461 5040 355382 17157 693,496 1429 Cr60W 102 7739 9.0 00:06:00 06:39:15 62 5 FIAT YF127ST 20 164 130 8591 5460 360842 22399 715,895 1420 09649s 107 7846 10.0 00:06:30 06:45:45 63 6 FLAT YF127ST 20 15.8 140 8731 5880 366722 27943 743,838 142200888(1a 111 7956 11.0 00:07:00 06:52:45 64 7 FLAT YF127ST 20 15.3 140 8871 5880 372602 31508 775,346 16200r880a 107 8064 12.0 00:07:00 06:59:45 65 8 FLAT YF72751 20 14.8 150 9021 6300 378902 37331 812,677 1420CrRmas 111 8175 12.0 00:07:30 07:07:15 66 Ball 2.125" DISPLACE YF127ST 20 20.0 12 9033 504 379406 0 812,677 12 8187 8.0 00:00:36 07:07:51 • 67 PAD YF127ST 20 20.0 490 9523 20580 399986 0 812,677 490 8677 8.0 00:2430 07:32:21 68 1 FLAT YF127ST 20 19.2 100 9623 4200 404186 4024 816,701 18296880Ya 100 8777 8.0 00:05:00 07:37:21 69 2 FLAT YF127ST 20 18.4 100 9723 4200 408386 7724 824,425 162009emas 100 8877 9.0 00:05:00 07:42:21 70 3 FLAT YF127ST 20 17.7 110 9833 4620 413006 12252 836,677 two CrexM 110 8987 9.0 00:05:30 07:47:51 71 4 FLAT YF127ST 20 17.0 120 9953 5040 418046 17157 853,833 ism Grba110 120 9107 9.0 00:06:00 07:53:51 72 5 FLAT YF127ST 20 16.4 130 10083 5460 423506 22399 876,232 1920096e12a 130 9237 10.0 00:06:30 08:0021 73 6 FLAT YF127ST 20 15.8 140 10223 5880 429386 27943 904,176 1420 096m94 140 9377 11.0 00:07:00 08:0721 74 7 FLAT YF12751 20 15.3 140 10363 5880 435266 31508 935,684 ism crease 140 9517 12.0 00:07:00 08:14:21 • 75 8 FLAT YF72751 20 14.8 150 10513 6300 441566 37331 973,015 umcutous 150 9667 12.0 00:07:30 08:21:51 76 FLUSH WF127 20 20.0 68 10581 2839 444405 68 9734 16.0 00:03:22 08:25:13 77 FLUSH Freezeprotect 20 20.0 17 10598 731 445136 17 9752 00:00:52 08:26:05 TOTALS 10,598.48 973,014.82 9752 08126:05 SD andoDtaln isms.5mInSIP. WATER VOL FLUSH INFORMATION WELL AND TREATING PRESSURE INFORMATION WELL AND RESERVOIR INFORMATION DA3FRAC- 474 bbls VOL TO TOP PORT-88.8 DIP GRADIENT. 0.74 BHP.4005 psi TVD Peri.H.V. MAIN JOB- 9260 bbls Extra 450 bbls -UNDERFI USI.22 FLUD SG- 1.03 .TBG FBIC.3960 psi TOTAL JOB- 9734 bbls FLUSH VOL=85 FRCTION LOSS. 0.33 .PERF FRIG 0000 psi 10184 bbls -with contingency 140 TOTb9 Tai. 8031 -HYDHEAG 2417 psi Awl.Through Perls-88° GENERAL JOB INFO ND BTM SLEEVE- 5412 EST.MAXWHP.5547 pal Well Azknuth(IMarth)-165• TANKS REQUIRED PIPE TIME(min).44 MD FIRST SLEEVE- 12000 22.63 n-450 bM per tank pumpable PAD/SLURRY RATIO Per05EV. TOTALS FOR 7 STAGES Stage 133% Stage6 33% UPP.TUBING SIZE. 3.5000 0.0087 bARn Stage 33% Stage? 33% Reservoir Pressure-2900 Water 10184 bbls Stage 333% Stage8 33% Permeadlty. )(link fluid 9400 bbls Stage 033% CASING SIZE- 4.5000 0.0152 bbl.41 Temperature-142 Linear fluid 334 bbls Stage 533 Proppant 973,015 lb DIesel 70 bbls Pump time 0526:05 hh:mm:ss Stage Ports MD DAptac4 Stage Ports MD DIsplact M275 68 lb namm It volume Seat Size nanw R volume Seat Size J475 3,790 lb Stage 1 12000 1302 bbls P-sleeve Stage 7 9665 94.7 bbls 2210 0047 113 gal Stage 2 11600 1242 5515 1.448 Stage 8 9275 88.8 bbls 2.073 L065 819 gal Stage 3 11200 118.1 Obis 1.573 F103 410 gal Stage 4 10820 1123 bbls 1.698 J532 1,988 gal Stage 5 10440 1065 558 1.823 M002 TED lb Stage 6 10055 100.7 bbLs 1.948 8882 2,580 gal • • v2Y2015 Client: ConocoPhillips Alaska Inc. Schlumberger Well: 2N-336 Basin/Field: Colville-Prudhoe Basin Tarn State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 1/23/2015 5:35 PM Report ID: RPT-34143 Fluid Name&Volume Additive Additive Description Concentration Volum B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 2,580.0 Gal D047 AntiFoam Agent 0.3 Gal/1000 Gal 113.0 Gal F103 Surfactant 1 Gal/1000 Gal 410.0 Gal J475 Breaker 9.3 Lb/1000 Gal 3,790.0 Lb YF127ST,WF127 408,842 Gal J532 Crosslinker 4.9 Gal/1000 Gal 1,988.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 819.0 Gal M002 Additive 0.6 Lb/1000 Gal 239.0 Lb M275 Bactericide 0.2 Lb/1000 Gal 68.0 Lb S522-1620 Propping Agent varied concentrations 973,015.0 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 % 7727-54-0 Diammonium peroxodisulphate <0.1 % 1303-96-4 Sodium tetraborate decahydrate <0.1 % 107-21-1 Ethylene glycol <0.1% 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate <0.1% 25322-69-4 Polypropylene glycol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1% 111-76-2 2-butoxyethanol <0.1% 67-63-0 Propan-2-ol <0.1% 7647-14-5 Sodium chloride <0.01% 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01% 68131-39-5 C12-15 alcohol ethyoxylated <0.01% 34398-01-1(7E0) Linear C11 alcohol ethoxylate(leo) <0.01% 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) <0.01% 1310-73-2 Sodium hydroxide(impurity) <0.01% 7631-86-9 Silicon Dioxide <0.01% 10043-52-4 CALCIUM CHLORIDE <0.01 % 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01 % 91053-39-3 Diatomaceous earth,calcined <0.001 % 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 111-46-6 2,2"-oxydiethanol(impurity) <0.001% 68153-30-0 Amine treated smectite clay <0.001% 9002-84-0 poly(tetrafluoroethylene) <0.001% 10377-60-3 Magnesium nitrate <0.001% 7447-40-7 Potassium chloride(impurity) <0.001 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.0001 % 7786-30-3 Magnesium chloride <0.0001 % 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001 % 14808-60-7 Crystalline silica(impurity) <0.0001 % 14464-46-1 Cristobalite <0.0001 % Total 100% *Mix water is supplied by the client..Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. 0 Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. 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A p oZ19- -14- Loepp, Victoria T (DOA) From: Bearden,J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Friday,January 23, 2015 9:32 AM To: Loepp,Victoria T(DOA) I gt Subject: RE:Tarn 2N-336(PTD#241-144)Verbal approval to extend BHL Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria. One question,from my understanding, no additional paperwork is required so long as the extension is under 500', other than the normal post well completion reports (capturing this change)that are due within 30 days of end of well. Thank you for clarification on this, Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, January 23, 2015 9:23 AM To: Bearden,3 Daniel Subject: [EXTERNAL]RE: Tarn 2N-336 (PTD# 241-144)Verbal approval to extend BHL Daniel, Verbal approval is granted per 20AAC25.015(b)(2)to extend the BHL by not more than 500' as outlined below. Please submit a 10-403 with this approved change within 3 days. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp@alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeap@alaska.gov 1 From: Bearden, 3 Daniel [mailto:J.Daniel.Bearden@conocophillips.com] Sent: Friday, January 23, 2015 8:20 AM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Cc: Alvord, Chip; Doherty, Patrick D; Manoppo, Elan Rizaldi; Guo, Haibin; Shultz, Steve(Orbis Engineering, Inc.); Brunswick, Scott A Subject: Tarn 2N-336(PTD# 241-144) Victoria/Guy, This note is to inform you that ConocoPhillips will extend the permitted and approved bottom-hole location of 2N-336 (PTD#241-144) by up to, but no more than 500'in the lateral direction per 20 AAC 25.015. While drilling this Bermuda interval,we have encountered more net pay response than previously interpreted via seismic AVO response. We wish to continue drilling to increase the well productivity and extend our net pay map accordingly for identification of future drilling targets. Please let me know if you have any questions. Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell 2 ,+� OF rot Alaska Oil and Gas 47:\ I'1iL SIAIL ALASKA. Conservation Commission _ 333 West Seventh Avenue , � — — �_ Anchorage,Alaska 99501-3572 r4 1V E RNO k hu i VN-A l R 1P Main:907.279.1433 O . Fax:907.276.7542 A LA6 www.aogcc.alaska.gov G.L. Alvord • Alaska Drilling Manager ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-336 ConocoPhillips Alaska, Inc. Permit No: 214-144 revised Surface Location: 113' FNL, 982' FEL, Sec. 3, T9N, R7E, UM Bottomhole Location: 388' FNL, 5258' FEL, Sec. 10, T9N, R7E,UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ate./ Cathy P. Foerster Chair DATED this day of December,2014. 0 (, 201► STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . AOGCC PERMIT TO DRILL 20 AAC 25.005 1a.Type of Work: lb.Proposed Well Class: Development-Oil Q Service-Winj ❑ Single Zone Q 1c.Specify if well is proposed for: Drill Q Lateral ❑ Stratigraphic Test❑ Development-Gas❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry El Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket L__i Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2N-336 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 11732' ND: 5420' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 113'FNL,982'FEL,Sec.3,T9N,R7E,UM ADL 375074 Tarn Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2568'FNL,708'FEL,Sec.4,T9N,R7E,UM 4293 10/31/2014 Total Depth: 9.Acres in Property: 14.Distance to 388'FNL,5258'FEL,Sec. 10,T9N, R7E,UM 2560 Nearest Property <1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 145.7 feet 15.Distance to Nearest Well Open Surface:x- 460611 y- 5911896 Zone- 4 GL Elevation above MSL: 117.7 feet to Same Pool: 2N-345,275 16 Deviated wells: Kickoff depth: 600 ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) 23.73 e s r Maximum Hole Angle: 88° deg Downhole:2900 psig Surface:23 sig !TL t z-J /t f 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 164.8# B-35 Welded 92' surf surf 120' 120' driven 13.5" 10.75" 45.5# L-80 Hyd563 2616' surf surf 2644' 2300' 1010 sx LiteCRETE,205 sx LiteCRETE 9.875" 7.625" 29.7# L-80 Hyd563 7882' surf surf 7910' 4980' 700 sx GasBLOK 9.875" 7.625" 39# rN-110S. Hyd563 500' 7681' 4887' 8181' 5076' same as above 6.5" 4.5" 12.6# rN-110S: IBTM 729' 8031' 5024' 8760' 5241' uncemented liner 6.5" 4.5" 12.6# L-80 IBTM 2972' 8760' 5241' 11732' 5421' uncemented liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft) Junk(measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 1=1 Time v.Depth Plot III Shallow Hazard Analysis 111 Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 MC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Email Steve.Shultz@contractor.cop.com Printed Name G. L. Alvord' Title Alaska Drilling Manager Signature �C6f Phone:265-6120 Date i a-IA -..z 0 t 9 Commission Use Only Permit to Drillll- /1 API Number: Permit Approval See cover letter Number: 2/4 I' '/ 50-s -2.0(p° -0 O-.00 Date: \C) - t- L \i_ for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed rn thane,gas hydrates,or gas contained in shales: 4 Other:/.3D p 1--e-571- fo 35-0o psi Samples req'd: Yes ❑ No Mud log req'd: Yes❑ No[. 1fr7 n 1-/4 s' f-c 5 t fo 2,5-00 ps r H2S measures: Yes j No Directional svy req'd: Yes FA No❑ C QL e'rr c 2 L,r'va 1 r r-t - Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No[2' re q,vl rd _ APPROVED BY THE Approved by COMMISSIONER COMMISSION Date: 1 2 ^ S •-/ cl Form 10-Ani IR ise���01) T R i f DIY ftrr\hohsrromtheof apco1I(20 AAC 25.005(g)) ( It J� I\YI f/-\► - i -- i Application fo' nit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-14 2N-336 Application for Permit to Drill Document 0 ',46--, ; r,t ConocoPhillips ` Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (t)) Error! Bookmark not defined. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 3 ASP CALCULATIONS 3 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 4 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)) 6 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)) 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 (Requirements of 20 AAC 25.005 (c)(14)) 8 2N-336 APD Page 1 of 14 Printed:4-Dec-14 Application fo -lit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-14 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program 1. Well Name (Requirments of 20 AAC 25.005(t)) The well for which this application is submitted will be designated as 2N-336 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 at Tarn. The rig will drill a 13-1/2"surface hole and case with 10-3/4" L-80 with premium connections. It is requested that the 9-7/8" intermediate section will be drilled to 8,181' MD/5,076' TVD which is +/-336' MD/ 100' TVD above the Bermuda sand. The 7-5/8" intermediate casing needs to be run and cemented in place at this point. The reason for this change is due to a geologic anomaly found in a close offset well (2N-339). After correlating the open hole logs, an unidentified sand was found just above the Bermuda. If we were to set the 7 5/8" casing into this sand, it could have detrimental consequences for obtaining the LOT needed for drilling the well. Therefore, we would like to set the 7-5/8" intermediate casing higher by 100' TVD than the original prescribed 50'. A 6-1/2" bit will be run to drill the horizontal lateral portion of the well and 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 112.94' FNL, 981.86' FEL, Sec 3, T9N, R7E, UM NAD 1927 RKB Elevation 145.7'AMSL Northings: 5,911,895.97 Eastings: 460,611.04 Pad Elevation 117.7'AMSL Location at 7 5/8" Intermediate Csg Pt. 2,249.2' FNL, 676.0' FEL, Sec 04, T09N, R7E, UM Nad 1927 Measured Depth, RKB: 8,181' Northings: 5,909,787.50 Eastings: 455,629.59 Total Vertical Depth, RKB: 5,076' Total Vertical Depth, SS: 4,930' Location at Top of Productive 2,568.1' FNL, 707.5' FEL, Sec 4, T09N, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 8,517' Northings: 5,909,468.77 Eastings:455596.87 Total Vertical Depth, RKB: 5,176' Total Vertical Depth, SS: 5,030' Location at Total Depth 388.4' FNL, 5,258.25' FEL, Sec 10, T09N, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 11,732' Northings: 5,906,364.21 Eastings: 456,314.67 Total Vertical Depth, RKB: 5,420' Total Vertical Depth, SS: 5,275' 2N-336 APD Page 2 of 14 Printed:4-Dec-14 Application fc nit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-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 Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: ' I Casing Csg Setting Fracture Pore ASP Size Marker Depth Gradient pressure Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 Surface 120/ 120 10.9 52 68 10-3/4 100' TVD 2,644/2,300 14.5 1,028 1,504 over C-80 7-5/8 T 3.1 8,181 /5,076 / 15 2,334 2,358 4-1/2 T2 11,732/5,421 15 2,900 2,358 • Pore pressures above the Bermuda calculated with a seawater gradient of 8.6 ppg • Pore pressure in the Burmuda is estimated at a maximum of 2,900 psi • NOTE: The Nabors 9ES 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: 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 120' = 68 psi 2N-336 APD Page 3 of 14 Printed:4-Dec-14 Application fc nit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-14 OR ASP = FPP—(0.1 x D) =1,028—(0.1 x 2,300') = 798 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1]x 2,300' = 1,504 psi OR ASP = FPP—(0.1 x D) =2,301 —(0.1 x 5,076') = 1,787 psi 3. Drilling below intermediate casing (7-5/8") ASP = [(FG x 0.052)—0.1] D = [(15 x 0.052)—0.1]x 5,076' = 3,452 psi OR ASP = FPP—(0.1 x D) =2,900—(0.1 x 5,076') = 2,393 psi (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C)Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The most recent SBHPs from offset wells producing wells are: 2N-339: 1,229 psig; 2N-345A: 1,622 psi;; 2N-343: 2,945 psi; 2N-319; 2,617 psi and 2N-327: 1,157 psi. The most recent SBHPs for the offset injection wells are: 2N-325: 3,141 psi; 2N-337B: 3,709 psi and 2N-349A: 3,208 psi. Prior to drilling well 2N-336, further offset well pressure surveillance will occur and offset injectors may be shut-in to manage pattern pressures. The Tarn reservoir model predicts the 2N-336 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 or lower pressure as it is drilled closer to the higher pressured offset injectors and depleted producers. The upper limit of reservoir pressure is estimated at 2,900 psig, but continued pressure monitoring will occur prior to spudding well 2N-336. S. 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. 2N-336 APD Page 4 of 14 Printed. 4-Dec-14 Application fc nit to Drill,Well 2N-336 Revision#1 • Saved:4-Dec-14 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 Weide 92' Surf 120'/120' Driven Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,616' Surf 2,644/2,300' 1010 sx 11.0 ppg LiteCRETE Lead 205 sx 12.0 ppg LiteCRETE tail 7-5/8 9-7/8 29.7 L-80 Hydril 7,653' Surf 7,681'/4,887' 563 Cement Top planned @ 5,600'MD/ 3,861'TVD. Cemented w/ 7-5/8 9-7/8 39 TN- Hydril 500' 7,681'/4,887' 8,181'/5,076' 700 sx GasBLOK Class"G"15.8 ppg 110SS 563 4 1/2 6 1/2 12.6 TN- Hydril 730' 8,031'/5,024' 8,760'/5,241' 110SS 521 Uncemented Liner 41/2 61/2 12.6 L-80 IBTM 2,972' 8,760'/5,241' 11,732'/5,421' Casing / Liner Design: 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 7 5/8" 39.0 TN-110SS 3 Hyd563 10,370 psi 8,815 psi 11480 psi 9,758 psi 4 '/" 12.6 TN-110SS 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 4 %" 12.6 L-80 3 IBTM 9,200 psi 7,820 psi 11590 psi 9,852 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(C)(7)) Please reference diverter schematic on file for Nabors 9ES. 2N-336 APD Page 5 of 14 Printed:4-Dec-14 Application fc uit to Drill,Well 2N-336 Revision#1 • Saved:4-Dec-14 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-112" Liner Density 9.5 - 10 ppg 9.6— 10.0 ppg 10.0- 11.0 ppg YP 60-80 18-28 18-28 Funnel Viscosity (sec) 75—250 40-55 45-55 PV 20-60 20-25 20-25 Initial Gels 10-35 4—8 5-9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water / gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.5 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight above 9.5 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 10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 2N-336 APD Page 6of14 Printed:4-Dec-14 Application fc nit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-14 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nabors 9ES on 2N-336 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs out on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor 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(2,644' MD/2,300' 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 to 8,181' MD/5,076' TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)with on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5"drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenaris110SS with Hydril 563 connections on the intermediate casing to 8,181' MD/5,076' TVD and cement in place with a minimum of 500' of cement above the C-37 formation. 13. MU 6-1/2" bit and RIH on 4" drill pipe. 14. Directionally drill a 6-1/2" hole to 11,732' MD/5,421' TVD. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Stethoscope) for navigational monitoring and formation data gathering. 15. POOH and RU casing crew and cementers. 16. MU and run a 4-1/2" liner as follows: a. 4-1/2" shoe b. 4-1/2", 12.6#, L-80, BTCM liner(+/-2,972')with swell packers and frac sleeves c. 4-1/2", 12.6#,TN110SS,Hydril 563 liner(+/-730') d. Liner hanger 17. Once on bottom, circulate, then drop plug in drill pipe, circulate, land plug and pressure up, shear out inner plug. 18. Pressure up and set liner hanger, continue to pressure up and release the running tool 19. Pick up 30 feet to expose setting dogs, slack off on drill string until setting dogs engage liner top, set down to set the ZXP liner top packer on top of the liner hanger. 2N-336 APD Page 7 of 14 Printed:4-Dec-14 Application fc lit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-14 20. PU 10 feet on drill pipe without pulling the seals out of the RS nipple and pressure test liner top packer, change over well to brine, POOH and LD 4" drill pipe 21. Run 3-1/2"completion tubing with premier packer and seals and set packer at+/- 7,981' MD/5,006' TVD. 22. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 19. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1 B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program Attachment 5 Top Set Comparison to 2N-339 2N-336 APD Page 8 of 14 Printed:4-Dec-14 Application fc lit to Drill,Well 2N-336 Revision#1 • Saved:4-Dec-14 Attachment 1 —Directional Plan 2N-336 APD Page 9 of 14 Printed:4-Dec-14 Application fc lit to Drill,Well 2N-336 Revision#1 • Saved:4-Dec-14 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2N-336 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. 2N-336 APD Page 10 of 14 Printed:4-Dec-14 • Application fc nit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-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 2N-336 well plan. Anti-collision analysis indicates the following separation factors between the planned 2N-336 well plan and the following existing wellbore. 2N-345 (Separation Factor= 1.476, 88.7' separation ellipse to ellipse at a depth of 4,650' 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 topset to 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. 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. 2N-336 APD Page 11 of 14 Printed:4-Dec-14 Application fc lit to Drill,Well 2N-336 Revision#1 , . Saved:4-Dec-14 Attachment 3- Proposed Well Schematic 1 Tarn 2N-336 Trip , Grass Roots Topset Horizontal Multi-Stacie treed Producer ConocoPhillips Proposed Wellbore Schematic CAMERON 4 .,...tre,s,Ity I:int is 4W'12.60 MM.ctcmel avvt0-,r tac eq.eprren:1 :4,1117 It:L(1(1'2614 J el l 1 16 Existing Cemented Conductor: 16"62.64 H-40 78MD :itl:',L•' 3'.,"Cainco OS Ripple 2.875" 500*M0 13-112"Surface Hole Drilipinx " G --NJ 3 WCarnce Ktl. Aws 9.8 PPG Surface Casing: 3 14*4"Cameo KEMAL. lir 1 0-3/4 45.5#L-80 Hydril 563 2.644'MD.'2,300'TVD @ 56' ,.. a%Ns"Cameo KfitAG I . . . . . . . . . . . . . ... , ••••. .•.•.•.•.•.• •.•.•.•.•.•.•.•.•...•.•.•.•.•.•.•.•—•.•—•. .•. .•.•.•. . . . ...SND Tubing: up will' 3 1.1"4"Cameo KONG3-W 9.3#L-80 EUE8RD :Alittiro 4-W 12.6k L-80 IBTM top joint to surface 9-718"Intermediate Hole f-nrnated top 0 ciormt 0-t.-5543*M1) 15CCr above C17: 3 11.--r etinict: .7-1 KLIMG.1"13-CK,2 — SOV . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . iceberg Top PAO'.Mg:4:10 TOO: :.:.: : ..::::::::::::::::::::::::::::::::•:•:•:•:•:•:•:•:::::::::::::::::::::1 . . . . . ... . . . . . . nAkAr CMU sliding Sleeve CLOSED Vid nor anal 'DS'Profile If/aix-rve Packet Al '••r1- 3 5..x 7...•,'9',Balker Pierrier P-xer pope I-AT;x 44$'Baker Flax Lock Lew hanger 7 7 imp lree lop peclter vd RS Nipple, E 031'MD 1 ' Intermediate Casing Topset: 7-518"29.74 L-80&400'TN1lOSS 394-all i Hydril 563 connections 7<orifiarroada a Si7'11.T.,S•7ff ral 8,181'MP,'5 fr.76'Tyr)(.j 7f .-.-. ., "::::•:•:•:•:•:•:•:•:•:- •:•:•:. .... .....-*:..,•*:•:••••: ':::::::::::::::::::!•!‘lof11910ti!eP4'1Kfc-i)2..Pririlti0140 IIO::::::: ::•:•:•:•:•:•::::::::::: :::::: :w4rtiF.:*„..::. •:•:::i:i::::::::::::::::::::::::::::::::::::.::::.:i:i::::::: :::::::::::::::':::::::::::: iq i).i.4::Ii00::::: :::::: •••.::4164:111::::i:. 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H521eLlip::\,, 0 0 0 ___ :::•:::•:•:•:•:•:•:•:•:: •:•:•:•.:.:::::::.:.:::::.. ---. ir-----i -••:••:::::::::::::::::• ::::::::•:•:•:•:•:•:•:•:•::,...,__ -::•.:)!1,9ilicJOPP.....,ro:Ptift. .:gSts:0.(.0..r.i. §.?(9:::..:::.-:i:i:::iki:tio:14:00-Roopite::..::::::::::::::::::. -...-::.•:•:•:•:•:•:•:•:•••:•:•:•:•:•:.:•:•:•:•: •::::. ?i0:4*0.0Yr.ar0Y:O. .:;::i:':::'::.:: :*:..:.':.*::i:::*:.:.: :H:.:4=V2r':1216i.th4f0)8T03::*:::::::::::::',..*:,'•;••••._•::.,•-•::::::::::: : :.i.:::0.4„;2•0,_. 3.9 3.P.Oiiiiiiii:iiiii::iiMii:::::Miiiij$i;tiM13iikt41;74.Zrytijiiiii,&,,r(r9j914.7. !'...!!';: : ': D!() .:•F•4 'ii'N9:164).:M::*: ::::::ii.:iiiHiiii.:§,62:4'it5:4 .0..rrittf 2N-336 APD Page 12 of 14 Printed:4-Dec-14 Application fc 'lit to Drill,Well 2N-336 Revision#1 Saved:4-Dec-14 Attachment 4—Cement Summary 10-3/4" Surface Casing Cement Job Cement 103/4" casing from shoe @ 2,644' MD to 2,300' MD (500' of fill) with 12 PPG LiteCrete, and from 2,144'to surface with 11 PPG Arctic LiteCRETE. Assume 250%excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,108'MD),zero excess in 16"conductor. Lead Slurry: (78')x 0.638 ft3/ft x 1.0(0%excess)=50 ft3 (1,108'—78')x 0.364 ft3/ft x 3.5(250%excess)=1312 ft3 above permafrost (2,144'—1,108') x 0.364 ft3/ft x 1.5(50%excess)=565 ft3 below permafrost Total volume=50 ft3+1312 ft3+565 ft3=1,927 ft3=>1009 Sx @ 1.91 ft3/sk System: 1010 Sx Arctic LiteCRETE @ 11 PPG (343 bbls) Tail Slurry: (2,644'—2,144')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 System: 205 Sx LiteCRETE @ 12 PPG (56 bbls) 7-518" Intermediate Casing Cement Job Cement 7%" casing from shoe @ 8,181 MD to 5,603' MD(minimum of 500' above the top of the C-37 with 15.8 PPG Class G w/GasBLOK.Assume 40%excess in the open hole volume. Slurry: (8,181'—5,603')x 0.215 ft3/ft x 1.40(40%excess)=775 ft3 in open hole 80'shoe track x 0.258 ft3/ft x 1.0(0%excess)=20.6 ft3 Total volume=775 ft3+20.6 ft3=797 ft3=>6815x @ 1.17 ft3/sk System: ^'700 Sx Class G @ 15.8 PPG (142 bbls) 2N-336 APD Page 13 of 14 Printed:4-Dec-14 • Resistivity 2N-336 Top comparison arison on 2N-339 Gamma Ray p GAPI TVDSS MD Filled >_8.5 (ft.) ohmm 0 200 1 1001 ' 14 . H;4T-5 I ,moi — 7300- -' -4750 -,- 'yru"..! - 7350 - $ l 20 2N•19 -_.4:00 2N-325 - 7400 - E L. 2N-332PB1te, - --T 4.1 WM 2N•29 w /E50 ti- 7450 — 8 Zone had a 15.8 ppg 2N-3345A ;N�og°o m40 oo•' .. EMW on recent FIT o�m o pG�go --7500- 2N-343 ae " - 7550 - T 4 a . 2N-339 I- -337B. • 2N27 - 9000 0 - +°� 7600- T 3.1 i0A_Wp03 92°° CO 9e°° . T-3_ a 2N-337A 9soo y Top Bermuda OS - 7650 - 2N-337 ioo To •5t00-, - ,o°0 2N-336 - l oo: 7700- >>600 �.. 2N-336 WP03 i I •5C50 -_ - ' N - — 7750 - 0.0 0.5 `' E `r—._I - Mile 5 5100-L 7800- -,- 7850 - 3150 -,_ -.— r, Tann T-2 r Base Bermuda 2N-339 ' :iiia I ConocoPhillips TRANSMITTAL LETTER CHECKLIST WELL NAME: /<A(& Q/U-33 PTD: 0)hi iliIf 4 Development Service Exploratory Straiigraphi Test Non-Conventional FIELD: il,,pc,Ai( P\iskAz." POOL: KApc,,,p, Z Vi...ir) / G.,kn, 0."i Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by / (Company Name) in the attached application,the following well logs are Well Loggingalso required for this well: RequirementsPer Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 To O) 0 a) 0 N 0 a) o m a) 0) c c 0 Q o. 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O aa)); o ) U° z; >, c2; c2; • a ° m a ' o 3, C) o �, o ami; w w, y Y, ai, O a E a) co ui U E co 0-5' o' .E o 1) o' a; -oo a a �, E as Co 45 3 E co o, m 2; 2; 2' m, - 03 a 'o c 0, 0; 0 a a a) CO aa) a) o 1.00 � a _ 0 � �; �; co .•-; 00' aa U �' <fa_ z; U, in U U U' UQ °; Q , o' mmc5 � o2,, a; o coco0 nl m a 1 E `- N co 11) CO I� CO 0) 0 CN N CO CN CO CO h CO 0) 0 0) N CO CO CO P CO O p N CO O O W O O N N N N N N N N N N CO CO CO CO CO M CO M CO CO U o C O y 0 O U O V Oin O 0 O OO N Cn 7 CO OE 0 N N d O U O 1E C J O - 0 a a s w` Q > a ° 0 I 1c /% THE STATE .Alas a i,s,_ ar-Itd Cm.E N �1ys, J , ,� of A 1 A (-- V I = 4, - ' sl __= --- 333 Wes'. Seventh Avenue �� i'= GOVERNOR SEAN P,SRN1;1 1 Anchorage, Alaska 99501 3572 t/a:n 907 279 I X33 G. Alvord Alaska Drilling Manager 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-336 ConocoPhillips Alaska, Inc. Permit No: 214-144 Surface Location: 113' FNL, 982' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 388' FNL, 5258' FEL, SEC. 10, T9N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, /1 ;77-i-01 -- Cathy P. oerster �� Chair �% DATED this day of October, 2014. RECEIVED STATE OF ALASKA SEP 18 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGQ6 20 AAC 25.005 1 a.Type of Work lb Proposed Well Class Development-Oil Q N Service-Winj ❑ Single Zone Q• 1c.Specify if well isproposed for. Drill E, Lateral El Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry[I Exploratory ❑ Service-WAG ❑ Service-Disp El Geothermal :111 Shale Gas ❑ 2 Operator Name 5 Bond .U Blanket u Single Well 11.Well Nae and Number ConocoPhillips Alaska, Inc • Bond No. 59-52-180 . 10\tk. 2N-336 i 3 Address 6 Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 . MD: 11732' . TVD: 5420' . ,' Kuparuk River Field t 4a Location of Well(Governmental Section). 7.Property Designation(Lease Number). Surface: 113'FNL,982'FEL,Sec.3,T9N,R7E, UM ' ADL 375074 • Tarn Oil Pool Top of Productive Horizon. 8 Land Use Permit 13 Approximate Spud Date 2568'FNL,708'FEL,Sec.4,T9N, R7E, UM , 4293 10/31/2014 Total Depth 9 Acres in Property 7 Ita 14.Distance to 388'FNL,5258'FEL,Sec. 10,T9N, R7E,UM ` -5�g 0,5100 Nearest Property <1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSI-' , 145 7 feet 15 Distance to Nearest Well Open Surface:x- 460611 y- 5911896 Zone- 4 , GL Elevation above MSL: , 117.7 feet to Same Pool 2N-345,275 16 Deviated wells. Kickoff depth: ` 600 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle , 88° deg Downhole.2900 psig • Surface:2358 psig , 18.Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c f or sacks Hole Casing Weight Grade Coupling Length MD TVD° MD TVD (including stage data) 24" 16" 164.8# B-35 Welded 92' surf surf 120' 120' driven 13.5" 10.75" 45.5# L-80 Hyd563 2616' surf surf 2644' 2300' 1010 sx LiteCRETE,205 sx LiteCRETE 9.875" 7.625" 29.7# L-80 Hyd563 7882' surf surf 7910' 4980' 750 sx GasBLOK 9 875" 7.625" 39# TN-110S; Hyd563 500' 7910' 4978' 8410' 5146' same as above 6.5" 4.5" 12.6# TN-110S. IBTM 500' 82,60' 5101' 8760' 5241' uncemented liner i 6.5" 4 5" 12 6# L-80 IBTM 2972' 8760' 5241' 11732' 5421' uncemented liner 19 PRESENT WELL CONDITION SUMM RY ��. (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft) Total Depth TVD(ft) Plugs(meas Effective Depth MD(ft) Effective Depth TVD(ft) Junk(measured) Casing Length Size / CementVolume MD TVD Conductor/Structural \ 5,\A.17 Surface Intermediate Production \4 ‘YYY"' Perforation Depth MD(ft). Perforation Depth TVD(ft). 20 Attachments Property Plat L El >BOP Sketch❑ Drilling Prograrr Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 MC 25.050 requirements ❑ 21 Verbal Approval Commission Representative Date c.>" S 22 I hereby certify that the foregoing is true and correct Contact Steve Shultz @ 263-4297 Email Steve Shultz ancontractor.cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature 46 O' Phone:265-6120 Date 1(-t(z" (f- Commission Use Only Permit to Drill API Number Permit Approval I See cover letter Number �1 , - I y 9 50-103-,,Q cO 93 _ 00 -00 I Date. i() 1 L 14 for other requirements dCondition of approval. If box is checked,well may not be used to explore for,test,or produce coalbed m hane,gas hydrates,or gas contained in shales Other: cop /cs t t'o 3.5-cop s I • Samples req'd: Yes No [ Mud log req'd: Yes No ►[' fl-vt n v l 4 r is 5 f 1-o Z 50 o P S i ri H2S measures: Yes No Directional svy req'd: Yes No❑ C 0 1- o✓ C '-'i l z-� r� � � ���acing exception req'd: Yes El No Inclination-only svy req'd: Yes❑ No[� ,�'D�-'/( ) APP E ZaL Approv -401 Rew d 10/201 ` T ermit�OSMalNER frotNALOS9, ate( ) P 9 I VL /0/(9p /te e( tor_r Post Office Box 100360 ConocoPhillips Anchorage,Alaska 99510-0360 Phone(907)263-4297 Email: steve.shultz( ,contractor.conocophillips.com September 17, 2014 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 SEP 18 2014 Re: Application for Permit to Drill 2N-336 Dear Sir or Madam: AOGCC ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well slot 2N-336 from the Tarn 2N drilling pad. This well is intended to be a producing well from the Bermuda horizon. The intended spud date for this well is October 31st,2014 using Nabors 9ES. When the Nabors 9ES rig moves onto 2N-336,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 bit will be made up and the intermediate casing drilled out.A 6'/2' horizontal lateral will be drilled to TD and once the drill string is pulled a 4-1/2"production liner with swell packers and frac sleeves will be slid in position for future frac operations.The final upper completion will consist of 3%"tubing complete with gas lift equipment. Please find attached the information required by 20 ACC 25.005(a)and (c)for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed Completion Diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. Cementing Program Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Steve Shultz at 263-4297. Sincerely, Steve Shultz Drilling Engineer Attachments / ation for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 2N-336 Application for Permit to Drill Document okmrork ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 3 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 6 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 7 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 8 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 (Requirements of 20 AAC 25.005 (c)(14)) 9 2N-336 APD Page 1 of 14 0RIGINAL Printed: 17-Sep-14 f tion for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program 2N-336 APD Page 2 of 14 3RIGINAL Printed: 17-Sep-14 P ition for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 1. Well Name (Requirements of 20 AAC 25.005 09) The well for which this application is submitted will be designated as 2N-336. 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 at Tarn. The 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" bit will be run to drill the horizontal lateral portion of the well and 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 112.94' FNL, 981.86' FEL, Sec 3, T9N, R7E, UM NAD 1927 RKB Elevation 145.7' AMSL Northings: 5,911,895.97 Eastings: 460,611.04 Pad Elevation 117.7'AMSL Location at 7 5/8" Intermediate Csg Pt. 2,465.8' FNL, 702.2' FEL, Sec 04, TO9N, R7E, UM Nad 1927 Measured Depth, RKB: 8,410' Northings: 5,909,571.00 Eastings: 455,602.57 Total Vertical Depth, RKB: 5,145' Total Vertical Depth, SS: 5,000' Location at Top of Productive 2,568.1' FNL, 707.5' FEL, Sec 4, TO9N, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 8,517' Northings: 5,909,468.77 Eastings:455596.87 Total Vertical Depth, RKB: 5,176' Total Vertical Depth, SS: 5,030' Location at Total Depth 388.4' FNL, 5,258.25' FEL, Sec 10, TO9N, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 11,732' Northings: 5,906,364.21 Eastings: 456,314.67 Total Vertical Depth, RKB: 5,420' Total Vertical Depth, SS: 5,275' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: 2N-336 APD Page 3 of 14 ORIGINAL Printed: 17-Sep-14 A tion for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 Casing Csg Setting Fracture Pore ASP Size Marker Depth Gradient pressure MD/TVD(ft) (lbs. /gal) (psi) Drilling (in)) (psi) 16 Surface 120/ 120 10.9 52 68 10-3/4 100' TVD 2,644/2,300 14.5 1,028 1,504 over C-80 7-5/8 T 3.1 8,410/5,146 15 2,334 2,358 4-1/2 T2 11,732/5,421 15 2,900 2,358 • Pore pressures above the Bermuda calculated with a seawater gradient of 8.6 ppg • Pore pressure in the Burmuda is estimated at a maximum of 2,900 psi • NOTE: The Nabors 9ES 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: 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor(16") ASP = [(FG x 0.052)—0.1] D = [(10.9 x 0.052)—0.1]x 120' = 68 psi OR ASP = FPP—(0.1 x D) =1,028—(0.1 x 2,300') = 798 psi 2. Drilling below surface casing (10-3/4") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2,300' = 1,504 psi OR ASP = FPP—(0.1 x D) =2,301 —(0.1 x 5,146') = 1,787 psi 3. Drilling below intermediate casing (7-5/8") ASP = [(FG x 0.052)—0.1] D = [(15 x 0.052)—0.1]x 5,421' = 3,686 psi OR ASP = FPP—(0.1 x D) =2,900—(0.1 x 5,421') = 2,358 psi 2N-336 APD Page 4 of 14 ORIGINAL Printed: 17-Sep-14 ation for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The most recent SBHPs from offset wells producing wells are: 2N-339: 1,229 psig; 2N-345A: 1,622 psi;; 2N-343: 2,945 psi; 2N-319; 2,617 psi and 2N-327: 1,157 psi. The most recent SBHPs for the offset injection wells are: 2N-325: 3,141 psi; 2N-337B: 3,709 psi and 2N-349A: 3,208 psi. Prior to drilling well 2N-336, further offset well pressure surveillance will occur and offset injectors may be shut-in to manage pattern pressures. The Tarn reservoir model predicts the 2N-336 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 or lower pressure as it is drilled closer to the higher pressured offset injectors and depleted producers. The upper limit of reservoir pressure is estimated at 2,900 psig,/but continued pressure monitoring will occur prior to spudding well 2N-336. 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. 2N-336 APD Page 5 of 14 ORIGIN n L Printed: 17-Sep-14 / tion for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 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) (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 164.8 B-35 Wade 92' Surf 120'/120' Driven Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,616' Surf 2,644/2,300' 1010 sx 11.0 ppg LiteCRETE Lead 205 sx 12.0 ppg LiteCRETE tail 7-5/8 9-7/8 29.7 L-80 Hydril 7,882' Surf 7,910'/4,980' 563 Cement Top planned @ 5,600'MD/ 3,861'TVD. Cemented w/ 7-5/8 9-7/8 39 TN- Hydril 500' 7,910'/4,978' 8,410'/5,146' 750 sx GasBLOK Class"G"15.8 ppg 110SS 563 TN- 4 1/2 6 1/2 12.6 110SS IBTM 500' 8,260'/5,101' 8,760"/5,241' Uncemented Liner 41/2 61/2 12.6 L-80 IBTM 2,972' 8,760'/5,241' 11,732'/5,421' Casing / Liner Design: 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 7 5/8" 39.0 TN-110SS 3 Hyd563 10,370 psi 8,815 psi 11480 psi 9,758 psi 4 %2" 12.6 TN-110SS 3 IBTM 7,500 psi 6,375 psi 8,440 psi 7,174 psi 4 '/2" 12.6 L-80 3 IBTM 9,200 psi 7,820 psi 11590 psi 9,852 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 2N-336 APD Page 6 of 14 Printed: 17-Sep-14 u R I G I N A L A Rion for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and seawater-based LSND mud systems having the following properties: Surface Intermediate Production 13-1/2" hole 9-7/8" hole 6-1/2" hole 10-3/4" Casing 7-5/8" Casing 4-1/2" Liner Density 9.5 - 10 ppg 9.6— 10.0 ppg 10.0 - 11.0 ppg YP 60-80 18-28 18-28 Funnel Viscosity(sec) 75—250 40-55 45-55 PV 20 -60 20 -25 20 -25 Initial Gels 10 - 35 4—8 5 -9 10 minute gels <18 <4 API Filtrate NC—8.0-10 cc/30 min 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 8.5—9.0 <12 <5 PH 9.0-9.5 9-9.5 9.3- 10 Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water / gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.5 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight above 9.5 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 10.0 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 2N-336 APD Page 7 of 14 ORIGINAL Printed: 17-Sep-14 , ation for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nabors 9ES on 2N-336 existing 16" conductor. 2. NU and function test diverter system and prepare 9.6 ppg fresh water spud mud. 3. Place warning signs out on location indicating the rig has diverter equipment rigged up. 4. Cleanout to below the conductor 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(2,644' MD/2,300' 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 to 8,410' MD/5,146' TVD. Run MWD/LWD logging tools in drill string (GR/RES/NEUT/DENS/PWD)with on-site mud logging and field geologist for directional monitoring and formation data gathering. 11. Circulate bottoms up to clean hole, POOH and lay down 5" drill pipe. 12. RU and run 7-5/8", 29.7#and 39#, L-80 and Tenarisi l oSS with Hydril 563 connections on the intermediate casing to 8,410' MD/5,146' TVD and cement in place with a minimum of 500' of cement above the C-37 formation. 13. MU 6-1/2" bit and RIH on 4" drill pipe. 14. Directionally drill a 6-1/2" hole to 11,732' MD/5,421' TVD. Run MWD/LWD logging tools in drill string (GR/RES/Neut/DENS/PWD/Periscope/Stethoscope)for navigational monitoring and formation data / gathering. 15. POOH and RU casing crew and cementers. 16. MU and run a 4-1/2" liner as follows: a. 4-1/2" shoe b. 4-1/2", 12.6#, L-80, BTCM liner(+/-2,972')with swell packers and frac sleeves c. 4-1/2", 12.6#,TN11 OSS,Hydril 563 liner(+/-500') d. Liner hanger 17. Once on bottom, circulate, then drop plug in drill pipe, circulate, land plug and pressure up, shear out inner plug. 18. Pressure up and set liner hanger, continue to pressure up and release the running tool 19. Pick up 30 feet to expose setting dogs, slack off on drill string until setting dogs engage liner top, set down to set the ZXP liner top packer on top of the liner hanger. 2N-336 APD ^ I G I N A tL Page 8of14 (U� Printed: 17-Sep-14 P ition for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 20. PU 10 feet on drill pipe without pulling the seals out of the RS nipple and pressure test liner top packer, change over well to brine, POOH and LD 4" drill pipe 21. Run 3-1/2"completion tubing with premier packer and seals and set packer at+/- 8,200' MD/5,082' TVD. 22. ND BOP and NU tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic Attachment 4 Cementing Program 2N-336 APD Page 9 of 14 U u I \ A L Printed: 17-Sep-14 , . . ..- .. .., „--,,:-,,'-1/4 • ----------\\\ .". r:'''''*t 7::5:';'':::''.,''..:3.,:4r.:7,41:::!:7„,v,,,f:,.,147':114,'::::*:it.:2,•';i.;4:44i:11';'','"1.,:'.71:4llit:':z:'",':_..:31::H:74E*8 ::H4_..:;:r::*:.,'.:::*':';!.:''''*:: 'r7:''4'r7'r:"''.:::.:*':';4:7*t*'. ..,, • 7 .,,,,,*' .'.., „ -. ,r•=,1.••"- ,,,• \''. ______--- .... a i.-.;c:k.:,•.,',/14!.;..,. 4 sohii, ..4„,-.40. •. , • • ,- ' '' 527"sr, -,s3ali, ..-1,-, - '.,7‘,..,,',.. • 1¢;,`,,, , - ";•7, • .,,,.' •:,,,.,:i•.,,,,- ' . ' ,.,,..,,„; ,. 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' .!.,.-., ,-- - . ... .-- 2N-336wp03 6.575 Plan Summary SURVEY PROGRAM Depth From Depth To Survey/Plan Tool �` ', 28.00 1000.00 2N-336wp03(Plan:2N-336) GYD-GC-SS !- ,, - �_ -��i//,` 1000.00 2500.00 2N 336wp03(Plan:2N-336) MWD � '• __ 1000.00 2644.30 2N 336wp03(Plan:2N-336) MWD+IFR AK CAZ LC /i- '�. 2644.30 4144.30 2N-336wp03(Plan:2N-336) MWD "`' 2644.30 8410.04 2N-336wp03(Plan:2N-336) MWD+IFR-AK-CAZ-SC 8410.04 9910.04 2N-336wp03(Plan:2N-336) MWD _ 8410.0411731.71 2N-336wp03(Plan:2N-336) MWD+IFR-AK-CAZ-SC CASING DETAILS TVD MD Name Size 2300.00 2644.30 10-3/4"x13-1/2" 10-3/4 5145.70 8410.04 7-5/8"x9-7/8" 7-5/8 5420.7011731.71 4-1/2"x 6-1/2" 4-1/2 0 Top Berm 0° 10-3/4"x13-1/2" _ 10-3/4"x13-1/2" I 1r; 5 I C-80 Campanian C-40 I -5 1,4:...c) ' 1 I T-7 7-5/8"x9-7/6" o > 0 7-5/8"x9-7/8" > - 1 rr I i I o • oh oco 0 o I 4-1/2"x 6-1/2" N 11 b e co _ ` ...... 1 r.-.._____L___,1 -^1 r - 01 00 I 0) I / C-50 1 O 0 I _turn ......... r 1 1.C ..✓. 4-1/2"x 6-1/2L rO 00 b o 00 01 a o r/ ‘1 �� 137 , 11 0 $ o co o11 n r r o 1 l r 1 I / J j o 0 I I I I' I 1 I I I I I I I I I I 0 0 3000 6000 9000 12000 0 1500 3000 4500 6000 7500 9000 Measured Depth Horizontal Departure Y 0 o 1A�ll I. ., s6(wpo-{1 j ss •� i1i� �9°D - :T. •°q )1,4' I II��I ICS , 300 iE►:.:„..,iifk:i......ii:..1...41....,-.045.1!;:.., Ja ��l��f'doe � ye - d _ �!ItZl! • )11'.111• 1111' F r.MA �" tell►d� t'.r•1. xv 3a 35 OS 4 WS s - E 30- P ��0 270�!407 ��4 \,I�.. -_ IP' E -'Wirdl • 240 ' ', qt \� 120 U - I imos - mos 0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 210 V' • 150 0 1500 3000 4500 6000 7500 9000 180 SECTION DETAILS 'r45 - 'r" Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target 1 28.00 0.00 0.00 28.00 -117.70 0.00 0.00 5911644.91 1600645.15 0.00 0.00 0.00 =NO 2 504.70 0.00 0.00 504.70 359.00 0.00 0.00 5911644.91 1600645.15 0.00 0.00 0.00 3 680.06 2.63 200.00 680.00 534.30 -3.78 -1.38 5911641.14 1600643.76 1.50 200.00 3.84 4 1311.21 17.58 243.60 1300.00 1154.30 -60.14 -92.29 5911585.26 1600552.56 2.50 50.00 103.92 5 2435.08 56.17 258.31 2183.52 2037.82 -237.25 -726.54 5911411.50 1599917.45 3.50 19.44 630.76 6 3965.91 56.17 258.31 3035.81 2890.11 -495.00 -1971.77 5911160.32 1598671.01 0.00 0.00 1593.76 7 4082.95 59.81 257.18 3097.84 2952.14 -516.09 -2068.72 5911139.75 1598573.95 3.22 -14.99 1669.55 2n-336 WP02 8 6236.66 59.81 257.18 4180.88 4035.18 -929.15-3883.91 5910736.27 1596756.80 0.00 0.00 3102.94 9 8390.00 73.60 184.00 5140.04 4994.34 -2332.42 -4995.18 5909339.00 1595638.27 3.14 -96.49 4892.74 10 8436.00 73.60 184.00 5153.03 5007.33 -2376.44 -4998.26 5909295.00 1595634.96 0.00 0.00 4929.53 Campanian 11 8530.40 73.84 180.57 5179.50 5033.80 -2466.97 -5001.87 5909204.51 1595630.86 3.50 -86.40 5003.51 12 8661.82 73.84 180.57 5216.09 5070.39 -2593.19 -5003.12 5909078.30 1595628.97 0.00 0.00 5104.37 13 9228.31 86.00 164.63 5315.70 5170.00 -3143.17 -4930.19 5908528.00 1595699.00 3.50 -53.86 5496.08 2N-336 Heel EB 28Mar14 14 9282.09 87.61 164.63 5318.70 5173.00 -3194.95 -4915.96 5908476.15 1595712.96 3.00 0.17 5528.47 15 11731.71 87.61 164.63 5420.70 5275.00 -5554.96 -4267.44 5906113.00 1596349.00 0.00 0.00 7004.90 2N-336 Toe 28Mar14 EB -3776.7 C-50 -3954.7 C-40 -4113.7 C-37 -4751.7 T-7 -51?&?Berm Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 TM Magnetic Model Date: 15-Jul-14 Depth Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) gA System SS Reference: Mean Sea Level Magnetic Magnetic DirDecliection a1True North /Y: 5911644.91 ( ) To convert a Direction to a True Direction,Add 18.98°East Ground Level/Mud Line: 117.70 CS East/X: 1600645.15 Rig: Nabors 9ES GLOBAL FILTE APPLIED:All wellpaths within 200'+100/1000 of reference UKIGINAL I' ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2N Pad Plan: 2N-336 Plan: 2N-336 Plan: 2N-336wp03 Plan Summary 19 May,2014 ORGU\ AL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 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 2N Pad Site Position: Northing: 5,911,719.15 ft Latitude: 70°10'12.453 N From: Map Easting: 1,600,966.34 ft Longitude: 150°19'3.037 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30° Well Plan:2N-336 Well Position +N/-S 0.00 ft Northing: 5,911,644.91 11 Latitude: 70°10'11.706 N +E/-W 0.00 ft Easting: 1,600,645.15 ft Longitude: 150°19'12.332 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 117.70 ft Wellbore Plan:2N-336 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 11 (nT) BGGM2013 7/15/2014 18.98 80.75 57,576 Design 2N-336wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From(ND) ON/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 217.53 5192014 9.32:09AM Page 2 COMPASS 2003.16 Build 69 RIGINAL 2N-336wp03 Plan View 0 0 00 0 0 0 0 0 -900 0 10-3/4"x13-1/2" 0 Ob -1800 8000 0 7-5/8"x9-7/8"-- ' p700 g000 Z X3600 0p00 -4500 0 000 2�3ggvap03 5400 4-1/2"x 6-1/2" 1{732 -6300 -5400 -4500 -3600 -2700 -1800 -900 0 900 West(-)/East(+) (900 ft/in) ORIGINAL 2N-336wp03 Section View 0- 00 900- -1000 300 10-3/4"x13-1/2" E1800- .PC)- C-80 o 0 a ,� Campanian 02700- o 0 �o U 0� ho ° C-50 3600- oo C-40 fs 2'4-336wp03 /600 C-37 opt° 4-1/2"x 6-1/2" 4500- ^,0o T-7 0o 0Top Berm __ o o o N 0 co o ° 0` 6o- i= 5400- 7-5/8"x9-7/8" 0 900 1800 2700 3600 4500 5400 6300 7200 Vertical Section at 217.53°(900 ft/in) OIGI \ AL 1 arla2 14 Easting(2500 ft/in) AC wells ONLY 2N-316 2N-322wp09 - - (NOT a Spider) H ' -318 -2N-322PB1wp09 ` — 2 3 ;A — 2N-321 2N-321A _ N-326 - - 2N-323A - - 2N-323 — -332 -320 �\\N 2N-330P81 (wp02) — �.�2PB _ ca - Z acs/ 348 347 -345A .c, ..4..4,.°. `_\ 2N-330(wp02)=-1° ����� / 2N324wp03 —ra o - N-350 a.3 C Z— 21` 327- N-3. Cwp03 335 2N-35.� — %714 •11, 2N-349B(wp01) 2N-337 - 2N-336wp03 - `2N-342 wp08 actuals final , I „ , , i , . , , I , , . , 1 , „ , I „ „ I , , „ I , , „ i , , , , i , , , 1 I I I I 1 I I 11 , I 11 I , , , i , , Ili „ „ I , , . , 1 , , , i , , , , I , , , , I , Easting(2500 ft/in) ORIGINAL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit ND Reference: Plan:117.7+28 @ 145.708(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.708(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Survey Tool Program Date 5/19/2014 From To (ft) (ft) Survey(Wellbore) Tool Name Description 28.00 1,000.00 2N-336wp03(Plan:2N-336) GYD-GC-SS Gyrodata gyro single shots 1,000.00 2,500.00 2N-336wp03(Plan:2N-336) MWD MWD-Standard 1,000.00 2,644.30 2N-336wp03(Plan:2N-336) MWD+IFR-AK-CAZ-LC MWD+IFR AK CAZ LC Sperry 2,844.30 4,144.30 2N-338wp03(Plan:2N-336) MWD MWD-Standard 2,644.30 8,410.04 2N-336wp03(Plan:2N-336) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,410.04 9,910.04 2N-336wp03(Plan:2N-336) MWD MWD-Standard 8,410.04 11,731.71 2N-336wp03(Plan:2N-336) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi ND TVDSS ()Leg TFace Northing Easting Lat.Error Vert.Error (ft) l°) (°I (ft) (ft) (^t100ft) (°I (ft) (ft) (ft) (ft) 28.00 0.00 0.00 28.00 -117.70 0.00 0.00 5,911,644.91 1,600,645.15 0.00 0.00 100.00 0.00 0.00 100.00 -45.70 0.00 0.00 5,911,644.91 1,600,645.15 0.05 1.15 200.00 0.00 0.00 200.00 54.30 0.00 0.00 5,911,644.91 1,600,645.15 0.20 1.15 300.00 0.00 0.00 300.00 154.30 0.00 0.00 5,911,644.91 1,600,645.15 0.34 1.15 400.00 0.00 0.00 400.00 254.30 0.00 0.00 5,911,644.91 1,600,645.15 0.49 1.15 500.00 0.00 0.00 500.00 354.30 0.00 0.00 5,911,644.91 1,600,645.15 0.63 1.15 504.70 0.00 0.00 504.70 359.00 0.00 0.00 5,911,644.91 1,600,645.15 0.64 1.15 Start Build 1.50 600.00 1.43 200.00 599.99 454.29 1.50 200.00 5,911,643.80 1,600,644.74 0.72 1.16 680.06 2.63 200.00 680.00 534.30 1.50 0.00 5,911,641.14 1,600,643.76 0.74 1.16 Start DLS 2.50 TFO 50.00 700.00 2.98 207.38 699.91 554.21 2.50 50.00 5,911,640.25 1,600,643.36 0.75 1.16 800.00 5.10 226.77 799.66 653.96 2.50 42.63 5,911,634.92 1,600,638.90 0.83 1.16 900.00 7.47 234.40 899.06 753.36 2.50 23.28 5,911,628.14 1,600,630.34 0.93 1.16 1,000.00 9.90 238.34 997.91 852.21 2.50 15.70 5,911,619.91 1,600,617.70 1.05 1.16 1,100.00 12.35 240.73 1,096.02 950.32 2.50 11.80 5,911,610.26 1,600,601.00 1.13 1.16 1,200.00 14.82 242.33 1,193.21 1,047.51 2.50 9.46 5,911,599.19 1,600,580.28 1.25 1.15 1,300.00 17.30 243.49 1,289.30 1,143.60 2.50 7.90 5,911,586.74 1,600,555.58 1.49 1.15 5/19/2014 9:32:09AM Page 3 COMPASS 2003.16 Build 69 JRIGINAL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.7011(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (ft) p) (°) (ft) (ft) (°/100ft) (1 (ft) (ft) (ft) (ft) 1,311.21 17.58 243.60 1,300.00 1,154.30 2.50 6.79 5,911,585.26 1,600,552.56 1.52 1.14 Start DLS 3.50 TFO 19.44 1,400.00 20.54 248.54 1,383.91 1,238.21 3.50 19.44 5,911,573.24 1,600,526.19 1.86 1.14 1,500.00 23.91 249.02 1,476.47 1,330.77 3.50 16.65 5,911,559.18 1,600,491.10 2.35 1.14 1,600.00 27.32 250.91 1,566.63 1,420.93 3.50 14.36 5,911,544.63 1,600,450.41 2.96 1.14 1,700.00 30.74 252.41 1,654.06 1,508.36 3.50 12.65 5,911,529.64 1,600,404.27 3.69 1.15 1,800.00 34.18 253.63 1,738.43 1,592.73 3.50 11.34 5,911,514.26 1,600,352.87 4.51 1.17 1,900.00 37.63 254.66 1,819.42 1,873.72 3.50 10.31 5,911,498.56 1,600,296.39 5.43 1.21 2,000.00 41.08 255.53 1,896.73 1,751.03 3.50 9.48 5,911,482.60 1,600,235.04 6.45 1.28 2,100.00 44.54 256.30 1,970.08 1,824.38 3.50 8.80 5,911,466.42 1,600,169.05 7.55 1.37 2,200.00 48.01 258.97 2,039.19 1,893.49 3.50 8.24 5,911,450.10 1,600,098.67 8.73 1.50 2,300.00 51.48 257.57 2,103.80 1,958.10 3.50 7.77 5,911,433.69 1,600,024.16 9.99 1.66 2,400.00 54.95 258.12 2,163.68 2,017.98 3.50 7.38 5,911,417.26 1,599,945.80 11.31 1.85 2,435.08 56.17 258.31 2,183.52 2,037.82 3.50 7.05 5,911,411.50 1,599,917.45 11.78 1.91 Start 1530.83 hold at 2435.08 MD • 2,500.00 56.17 258.31 2,219.66 2,073.96 0.00 0.00 5,911,400.85 1,599,864.59 12.68 2.06 2,600.00 56.17 258.31 2,275.34 2,129.64 0.00 0.00 5,911,384.44 1,599,783.17 7.19 1.50 2,644.30 56.17 258.31 2,300.00 2,154.30 0.00 0.00 5,911,377.17 f,599,747.10 7.19 1.50 103/4"x13-1/2" 2,700.00 56.17 258.31 2,331.01 2,185.31 0.00 0.00 5,911,368.03 1,599,701.75 7.74 1.52 2,800.00 56.17 258.31 2,386.69 2,240.99 0.00 0.00 5,911,351.63 1,599,620.32 8.34 1.57 2,900.00 56.17 258.31 2,442.36 2,296.66 0.00 0.00 5,911,335.22 1,599,538.90 9.11 1.66 2,963.47 56.17 258.31 2,477.70 2,332.00 0.00 0.00 5,911,324.80 1,599,487.22 9.11 1.66 C-80 3,000.00 56.17 258.31 2,498.04 2,352,34 0.00 0.00 5,911,318.81 1,599,457.48 10.02 1.78 3,060.46 56.17 258.31 2,531.70 2,386.00 0.00 0.00 5,911,308.89 1,599,408.25 10.02 1.78 Campanian 3,100.00 56.17 258.31 2,553.71 2,408.01 0.00 0.00 5,911,302.40 1,599,376.06 11.03 1.93 5/1912014 9:32:09AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (ft) (°) (°) (ft) (ft) (1/100ft) (°) (ft) (ft) (ft) (ft) 3,200.00 56.17 258.31 2,609.39 2,463.69 0.00 0.00 5911,285.99 1,599,294.63 12.12 2.10 3,300.00 56.17 258.31 2,665.06 2,519.36 0.00 0.00 5,911,269.59 1,599,213.21 13.27 2.28 3,400.00 56.17 258.31 2,720.74 2,575.04 0.00 0.00 5,911,253.18 1,599,131.79 14.46 2.48 3,500.00 58.17 258.31 2,776.41 2,630.71 0.00 0.00 5,911,236,77 1,599,050.36 15.69 2.70 3,600.00 56.17 258.31 2,832.09 2,886.39 0.00 0.00 5,911,220.36 1,598,968.94 16.94 2.91 3,700.00 56.17 258.31 2,887.76 2,742.06 0.00 0.00 5,911,203.95 1,598,887.52 18.22 3.14 3,800.00 56.17 258.31 2,943.44 2,797.74 0.00 0.00 5,911,187.54 1,598,806.10 19.51 3.37 3,900.00 56.17 258.31 2,999.11 2,853.41 0.00 0.00 5,911,171.14 1,598,724.67 20.82 3.60 3,965.91 56.17 258.31 3,035.81 2,890.11 0.00 0.00 5,911,160.32 1,598,671.01 21.68 3.76 Start DLS 3.22 TFO-14.99 4,000.00 57.23 257.97 3,054.53 2,908.83 3.22 -14.99 5,911,154.81 1,598,643.10 22.13 3.84 4,082.95 59.81 257.18 3,097.84 2,952.14 3.22 -14.80 5,911,139.75 1,598,573.95 23.23 4.04 Start 2153.71 hold at 4082.95 MD-2n-336 W P02 4,100.00 59.81 257.18 3,106.42 2,960.72 0.00 0.00 5,911,136.56 1,598,559.56 23.46 4.09 4,200.00 59.81 257.18 3,156.70 3,011.00 0.00 0.00 5,911,117.82 1,598,475.19 12.49 2.64 4,300.00 59.81 257.18 3,206.99 3,061.29 0.00 0.00 5,911,099.09 1,598,390.82 12.95 2.76 4,400.00 59.81 257.18 3,257.28 3,111.58 0.00 0.00 5,911,080.35 1,598,306.44 13.41 2.88 4,500.00 59.81 257.18 3,307.56 3,161.86 0.00 0.00 5,911,081.62 1,598,222.07 13.89 3.01 4,600.00 59.81 257.18 3,357.85 3,212.15 0.00 0.00 5,911,042.88 1,598,137.70 14.37 3.14 4,700.00 59.81 257.18 3,408.14 3,262.44 0.00 0.00 5,911,024.15 1,598,053.32 14.86 3.27 4,800.00 59.81 257.18 3,458.42 3,312.72 0.00 0.00 5,911,005.42 1,597,968.95 15.35 3.40 4,900.00 59.81 257.18 3,508.71 3,363.01 0.00 0.00 5,910,986.68 1,597,884.58 15.84 3.53 5,000.00 59.81 257.18 3,559.00 3,413.30 0.00 0.00 5,910,967.95 1,597,800.21 16.35 3.66 5,100.00 59.81 257.18 3,609.28 3,463.58 0.00 0.00 5,910,949.21 1,597,715.83 16.85 3.79 5,200.00 59.81 257.18 3,659.57 3,513.87 0.00 0.00 5,910,930.48 1,597,631.46 17.36 3.93 5,300.00 59.81 257.18 3,709.86 3,564.16 0.00 0.00 5,910,911.74 1,597,547.09 17.87 4.06 5,400.00 59.81 257.18 3,760.14 3,614.44 0.00 0.00 5,910,893.01 1,597,462.71 18.39 4.20 5/192014 9:32:09AM Page 5 COMPASS 2003.16 Build 69 ORGNAL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Planned Survey MD Inc Azi ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (ft) (°) l") (ft) (ft) p/100ft) 11 (it) (ft) (ft) (ft) 5,432.92 59.81 257.18 3,776.70 3,631.00 0.00 0.00 5,910,886.84 1,597,434.94 18.39 4.20 C50 5,500.00 59.81 257.18 3,810.43 3,684.73 0.00 0.00 5,910,874.28 1,597,378.34 18.90 4.33 5,600.00 59.81 257.18 3,860.72 3,715.02 0.00 0.00 5,910,855.54 1,597,293.97 19.42 4.47 5,700.00 59.81 257.18 3,911.01 3,765.31 0.00 0.00 5,910,836.81 1,597,209.60 19.95 4.61 5,786.89 59.81 257.18 3,954.70 3,809.00 0.00 0.00 5,910,820.53 1,597,136.28 19.95 4.61 C-40 5,800.00 59.81 257.18 3,961.29 3,815.59 0.00 0.00 5,910,818.07 1,597,125.22 20.47 4.74 5,900.00 59.81 257.18 4,011.58 3,865.88 0.00 0.00 5,910,799.34 1,597,040.85 21.00 4.88 6,000.00 59.81 257.18 4,061.87 3,916.17 0.00 0.00 5,910,780.61 1,596,956.48 21.53 5.02 6,100.00 59.81 257.18 4,112.15 3,966.45 0.00 0.00 5,910,761.87 1,596,872.10 22.06 5.16 6,103.08 59.81 257.18 4,113.70 3,968.00 0.00 0.00 5,910,761.30 1,596,869.51 22.06 5.16 C-37 6,200.00 59.81 257.18 4,162.44 4,016.74 0.00 0.00 5,910,743.14 1,596,787.73 22.59 5.30 6,236.66 59.81 257.18 4,180.88 4,035.18 0.00 0.00 5,910,736.27 1,596,756.80 22.78 5.35 Start DLS 3.14 TFO-96.49 6,300.00 59.61 254.89 4,212.83 4,067.13 3.14 -96.49 5,910,723.35 1,596,703.67 23.06 5.44 6,400.00 59.36 251.26 4,263.62 4,117.92 3.14 -95.33 5,910,698.72 1,596,621.15 23.31 5.57 6,500.00 59.22 247.62 4,314.69 4,168.99 3.14 -93.49 5,910,668.96 1,596,540.51 23.46 5.71 6,600.00 59.19 243.96 4,365.90 4,220.20 3.14 -91.63 5,910,634.16 1,596,462.01 23.51 5.84 6,700.00 59.25 240.31 4,417.09 4,271.39 3.14 -89.76 5,910,594.42 1,596,385.88 23.47 598 6,800.00 59.42 236.67 4,468.11 4,322.41 3.14 -87.89 5,910,549.87 1,596,312.34 23.33 6.11 6,900.00 59.68 233.05 4,518.80 4,373.10 3.14 -88.03 5,910,500.63 1,596,241.61 23.10 6.25 7,000.00 60.05 229.44 4,569.02 4,423.32 3.14 -84.19 5,910,446.86 1,596,173.91 22.77 6.39 7,100.00 60.51 225.87 4,618.60 4,472.90 3.14 -82.39 5,910,388.72 1,596,109.43 22.37 6.52 7,200.00 61.07 222.33 4,667.41 4,521.71 3.14 -80.61 5,910,326.38 1,596,048.38 21.89 6.66 7,300.00 61.72 218.84 4,715.29 4,569.59 3.14 -78.89 5,910,260.02 1,595,990.94 21.34 6.80 5/19/2014 9:32:09AM Page 6 COMPASS 2003.16 Build 69 ORIGINAL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28(41145.708(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.708(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Northing Fasting Lat.Error Vert.Error (ft( (l 1°) (ft) (ft) r/tooft) r) (ft) (ft) (ft) (ft) 7,377.55 62.29 216.16 4,751.70 4,606.00 3.14 -7721 5,910,205.92 1,595,948.98 21.34 6.80 T-7 7,400.00 62.46 215.39 4,762.11 4,616.41 3.14 -75.96 5,910,189.85 1,595,937.27 20.73 6.94 7,500.00 63.28 211.99 4,807.72 4,662.02 3.14 -75.60 5,910,116.07 1,595,887.54 20.07 7.08 7,600.00 64.18 208.64 4,851.99 4,706.29 3.14 -74.05 5,910,038.92 1,595,841.90 19.37 723 7,700.00 65.16 205.34 4,894.78 4,749.08 3.14 -72.56 5,909,958.61 1,595,800.48 18.64 7.37 7,800.00 66.21 202.09 4,935.96 4,790.26 3.14 -71.15 5,909,875.39 1,595,763.42 17.88 7.52 7,900.00 67.32 198.90 4,975.42 4,829.72 3.14 -69.82 5,909,789.51 1,595,730.80 17.12 7.67 8,000.00 68.50 195.76 5,013.03 4,867.33 3.14 -68.58 5,909,701.22 1,595,702.75 16.36 7.82 8,100.00 69.73 192.68 5,048.69 4,902.99 3.14 -67.38 5,909,610.80 1,595,679.34 15.61 7.97 8,200,00 71.02 189.64 5,082.27 4,936.57 3.14 -66.28 5,909,518.51 1,595,660.64 14.89 8.13 8,300.00 72.36 186.65 5,113.69 4,967.99 3.14 -65.26 5,909,424.62 1,595,646.70 14.21 8.28 8,390.00 73.60 184.00 5,140.04 4,994.34 3.14 -64.32 5,909,339.00 1,595,638.27 13.64 8.42 Start 48.00 hold at 8390.00 MD 8,400.00 73.60 184.00 5,142.87 4,997.17 0.00 0.00 5,909,329.43 1,595,637.55 13.68 8.44 8,410.04 73.60 184.00 5,145.70 5,000.00 0.00 0.00 5,909,319.83 1,595,636.83 13.68 8.44 7-518"x9-7/8" 8,436.00 73.60 184.00 5,153.03 5,007.33 0.00 0.00 5,909,295.00 1,595,634.96 13.87 8.44 Start DLS 3.50 TFO-86.40 8,500.00 73.75 181.67 5,171.02 5,025.32 3.50 -86.40 5,909,233.68 1,595,631.60 13.54 8.44 8,516.75 73.80 181.06 5,175.70 5,030.00 3.50 -85.74 5,909,217.60 1,595,631.14 13.54 8.44 Top Berm 8,530.40 73.84 180.57 5,179.50 5,033.80 3.50 -85.57 5,909,204.51 1,595,630.88 13.40 8.44 Start 131.43 hold.at 8530.40 MD 8,600.00 73.84 180.57 5,198.88 5,053.18 0.00 0.00 5,909,137.67 1,595,629.87 13.97 8.46 8,661.82 73.84 180.57 5,216.09 5,070.39 0.00 0.00 5,909,078.30 1,595,628.97 14.51 8.48 Start DLS 3.50 7F0.53.86 8,700.00 74.63 179.45 5,226.47 5,080.77 3.50 -53.86 5,909,041.57 1,595,628.77 14.47 8.49 5/19/2014 9:32:09AM Page 7 COMPASS 2003.16 Build 69 ORGNAL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.700(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Planned Survey MD Inc Azi ND TVDSS DLeg TFace Northing Easting Lat.Error Vert.Error (ft) (°) 1°) (ft) (ft) (°llooft) 1°I (ft) (ft) (ft) (ft) 8,800.00 76.72 176.56 5,251.21 5,105.51 3.50 -53.55 5,908,944.74 1,595,631.65 14.50 8.54 8,900.00 78.85 173.71 5,272.37 5,126.67 3.50 -52.84 5,908,847.34 1,595,639.44 14.67 8.60 9,000.00 81.01 170.91 5,289.85 5,144.15 3.50 -52.24 5,908,749.73 1,595,652.10 14.98 8.67 9,100.00 83.19 168.15 5,303.61 5,157.91 3.50 -51.75 5,908652.26 1,595,669.59 15.42 8.76 9,200.00 85.38 165.40 5,313.57 5,167.87 3.50 -51.37 5,908,555.30 1,595,691.85 15.98 8.87 9,228.31 86.00 164.63 5,315.70 5,170.00 3.50 -51.09 5,908,528.00 1,595,699.00 16.15 8.90 Start DLS 3.00 TFO 0.17-2N-336 Heel ES 28Mar14 9,282.09 87.61 164.63 5,318.70 5,173.00 3.00 0.17 5,908,476.15 1,595,712.96 16.15 8.90 Start 2449.62 hold at 9282.09 MD 9,300.00 87.61 164.63 5,319.44 5,173.74 0.00 0.00 5,908,458.88 1,595,717.61 17.09 8.98 9,400.00 87.61 164.63 5,323.61 5,177.91 0.00 0.00 5,908,362.41 1,595,743.57 18.36 9.12 9,500.00 87.61 16463 5,327.77 5,182.07 0.00 0.00 5,908,265.94 1,595,769.54 19.68 9.26 9,600.00 87.61 164.63 5,331.93 5,186.23 0.00 0.00 5,908,169.47 1,595,795.50 21.02 9.42 9,700.00 87.61 164.63 5,336.10 5,190.40 0.00 0.00 5,908,073.00 1,595,821.47 22.39 9.59 9,800.00 87.61 164.63 5,340.26 5,194.56 0.00 0.00 5,907,976.53 1,595,847.43 23.79 9.77 9,900.00 87.61 164.63 5,344.43 5,198.73 0.00 0.00 5,907,880.06 1,595,873.40 25.19 9.96 10,000.00 87.81 164.63 5,348.59 5,202.89 0.00 0.00 5,907,783.59 1,595,899.36 13.14 8.88 10,100.00 87.61 164.63 5,352.75 5,207.05 0.00 0.00 5,907,687.12 1,595,925.33 13.58 8.94 10,200.00 87.61 164.63 5,356.92 5,211.22 0.00 0.00 5,907,590.65 1,595,951.29 14.02 9.00 10,300.00 87.61 164.63 5,361.08 5,215.38 0.00 0.00 5,907,494.18 1,595,977.26 14.48 9.06 10,400.00 87.61 164.63 5,365.25 5,219.55 0.00 0.00 5,907,397.70 1,596,003.22 14.94 9.13 10,500.00 87.61 164.63 5,369.41 5223.71 0.00 0.00 5,907,301.23 1,596,029.19 15.41 9.20 10,600.00 87.61 164.63 5,373.57 5,227.87 0.00 0.00 5,907,204.76 1,596,055.15 15.88 9.27 10,700.00 87.61 164.63 5,377.74 5,232.04 0.00 0.00 5,907,108.29 1,598,081.12 16.37 9.35 10,800.00 87.81 164.63 5,381.90 5,236.20 0.00 0.00 5,907,011.82 1,596,107.08 16.86 9.42 10,900.00 87.81 164.63 5,386.07 5,240.37 0.00 0.00 5,906,915.35 1,596,133.05 17.35 9.51 11,000.00 87.61 164.63 5,390.23 5,244.53 0.00 0.00 5,906,818.88 1,596,159.01 17.85 9.59 5/192014 9:32:09AM Page 8 COMPASS 2003.16 Build 69 ORIGI \ AL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit ND Reference: Plan:117.7+28 @ 145.708(Nabors 9ES) Site: Kupamk 2N Pad MD Reference: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Planned Survey MD Inc Azi ND TVDSS Dleg TFace Northing Easting Lat.Error Vert.Error (ft) (°) (°) (ft) (ft) (°1100ft) (°) (ft) (ft) (ft) (ft) 11,100.00 87.61 164.63 5,394.40 5,248.70 0.00 0.00 5,906,722.41 1,596,184.98 18.35 9.68 11,200.00 87.61 164.63 5,398.56 5,252.86 0.00 0.00 5,906,625.94 1,596,210.94 18.86 9.76 11,300.00 87.61 164.63 5,402.72 5,257.02 0.00 0.00 5,906,529.47 1,596,236.91 19.37 9.86 11,400.00 87.61 164.63 5,406.89 5,261.19 0.00 0.00 5,906,433.00 1,596,262.87 19.88 9.95 11,500.00 87.61 164.63 5,411.05 5,265.35 0.00 0.00 5,906,336.53 1,596,288.84 20.40 10.05 11,600.00 87.61 164.63 5,415.22 5,269.52 0.00 0.00 5,906,240.06 1,596,314.80 20.92 10.14 11,700.00 87.61 164.63 5,419.38 5,273.68 0.00 0.00 5,906,143.59 1,596,340.77 21.44 10.25 11,731.71 87.61 164.63 5,420.70 - 5,275.00 0.00 0.00 5,906,113.00 1,598,349.00 21.44 10.25 TD at/1731.71-4-112"x 6-1/2"-2N-336 Toe 28Mar14 EB Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2N-336 Toe 28Mar14 EE 0.00 0.00 5,420.70 -5,554.96 -4,267.44 5,906,113.00 1,596,349.00 70'9'17.059 N 150°21'15.872 W -plan hits target center -Point 2n-336 WP02 0.00 0.00 3,097.84 -516.09 -2,068.72 5,911,139.75 1,598,573.95 70°10'6.627 N 150°20'12.260 W -plan hits target center -Point 2N-336 Heel EB 28Mar1 0.00 0.00 5,315.70 -3,143.17 -4,930.19 5,908,528.00 1,595,699.00 70°9'40.776 N 150°21'35.104 W -plan hits target center -Point 5/192014 9:32:09AM Page 9 COMPASS 2003.16 Build 69 ORIG1 \ AL Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit TVD Reference: Plan:117.7+28©145.70ft(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28 @ 145.708(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,644.30 2,300.00 10-3/4"x13-1/2" 10-3/4 13-1/2 8,410.04 5,145.70 7-5/8"x9-7/8" 7-5/8 9-7/8 11,731.71 5,420.70 4-1/2"x6-1/2" 4-1/2 6-1/2 Formations Measured Vertical Dip Depth Depth Dip Direction (ft) (R) Name Lithology r) r) 5,432.92 3,776.70 C-50 0.00 6,103.08 4,113.70 C-37 0.00 8,516.75 5,175.70 Top Berm 0.00 5,786.89 3,954.70 C-40 0.00 2,963.47 2,477.70 C-80 0.00 3,060.46 2,531.70 Campanian 0.00 7,377.55 4,751.70 T-7 0.00 5/192014 9:32:09AM Page 10 COMPASS 2003.16 Build 69 Plan Summary Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well Plan:2N-336 Project: Kuparuk River Unit ND Reference: Plan:117.7+28 t 145.705(Nabors 9ES) Site: Kuparuk 2N Pad MD Reference: Plan:117.7+28(9 145.705(Nabors 9ES) Well: Plan:2N-336 North Reference: True Wellbore: Plan:2N-336 Survey Calculation Method: Minimum Curvature Design: 2N-336wp03 Database: EDM Alaska Prod v16 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W )4 (ft) (ft) (ft) (ft) Comment 504.70 504.70 0.00 0.00 Start Build 1.50 680.06 680.00 -3.78 -1.38 Start DLS 2.50 TFO 50.00 1,311.21 1,300.00 -60.14 -92.29 Start DLS 3.50 TFO 19.44 2,435.08 2,183.52 -237.25 -726.54 Start 1530.83 hold at 2435.08 MD 3,965.91 3,035.81 -495.00 -1,971.77 Start DLS 3.22 TFO-14.99 4,082.95 3,097.84 -516.09 -2,068.72 Start 2153.71 hold at 4082.95 MD 6,236.66 4,180.88 -929.15 -3,883.91 Start DLS 3.14 TFO-96.49 8,390.00 5,140.04 -2,332.42 -4,995.18 Start 46.00 hold at 8390.00 MD 8,436.00 5,153.03 -2,376.44 -4,998.26 Start DLS 3.50 TFO-86.40 8,530.40 5,179.50 -2,466.97 -5,001.87 Start 131.43 hold at 8530.40 MD 8,661.82 5,216.09 -2,593.19 -5,003.12 Start DLS 3.50 TFO-53.86 9,228.31 5,315.70 -3,143.17 -4,930.19 Start DLS 3.00 TFO 0.17 9,282.09 5,318.70 -3,194.95 -4,915.96 Start 2449.62 hold at 9282.09 MD 11,731.71 5,420.70 -5,554.96 -4,267.44 TD at 11731.71 Checked By: Approved By: Date: 5/192014 9:32:09AM Page 11 COMPASS 2003.16 Build 69 • OR ! GI \ AL ConocoPhillips (Alaska) Inc. -Kup2 ;! Kuparuk River Unit Kuparuk 2N Pad Plan: 2N-336 Plan: 2N-336 2N-336wp03 iClearance Summary Ls a . P Anticollision Report 19 May,2014 lEi Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) k Reference Design: Kuparuk 2N Pad-Plan:2N-336-Plan:2N-336-2N-336wp03 1. 0( Well Coordinates: 5,911,644.91 N,1,600,645.15 E(70°10'11.71"N,150°19'12.33"W) . 111 E Datum Height: Plan:117.7+28 @ 145.70ft(Nabors 9ES) Scan Range:0.00 to 11,731.71 ft.Measured Depth. Scan Radius is 1,370.37 ft.Clearance Factor cutoff is Unlimited.Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build:69 Scan Type: GLOBAL FILTER APPLIED:All wellpaths within 2004 100/1000 of reference Scan Type: 25.00 ORGNAL ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2N-336 -2N-336wp03 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2N Pad-Plan:2N-336-Plan:2N-336-2N-336wp03 Scan Range:0.00 to 11,731.71 ft.Measured Depth. Scan Radius is 1,370.37 ft.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 (ft) (ft) (ft) (ft) ft *Kuparuk 2N Pad 2N-337-2N-337-2N-337 271.90 14.63 271.90 10.32 275.00 3.396 Centre Distance Pass-Major Risk 2N-337-2N-337-2N-337 346.87 15.24 346.87 9.71 350.00 2.755 Clearance Factor Pass-Major Risk 2N-337-2N-337A-2N-337A 271.90 14.63 271.90 10.19 275.00 3.297 Centre Distance Pass-Major Risk 2N-337-2N-337A-2N-337A 346.87 15.24 346.87 9.58 350.00 2.692 Clearance Factor Pass-Major Risk 2N337-Plan:2N-337B(wp01)-2N-337Bwp04 269.79 14.39 269.79 9.67 275.00 3.046 Centre Distance Pass-Major Risk 2N-337-Plan:2N-337B(wp01)-2N-337Bwp04 344.77 15.04 344.77 9.00 350.00 2.490 Clearance Factor Pass-Major Risk 2N-342-2N-342-2N-342 wp08 actuals final 1,084.48 82.25 1,084.48 64.77 1,075.00 4.706 Clearance Factor Pass-Major Risk Kuparuk 2N Pad 2N-316-2N-316-2N-316 785.66 274.05 785.66 259.74 825.00 19.151 Centre Distance Pass-Major Risk 2N-316-2N-316-2N-316 806.73 274.30 806.73 259.47 850.00 18.491 Clearance Factor Pass-Major Risk 2N-318-2N-318-2N-318 793.02 242.10 793.02 229.27 825.00 18.864 Centre Distance Pass-Major Risk 2N-318-2N-318-2N-318 815.09 242.20 815.09 229.02 850.00 18.371 Clearance Factor Pass-Major Risk 2N-318-2N-318A-2N-318A 808.98 242.14 808.98 229.05 850.00 18.504 Centre Distance Pass-Major Risk 2N-318-2N-318A-2N-318A 831.05 242.48 831.05 229.03 875.00 18.035 Clearance Factor Pass-Major Risk 2N-319-2N-319-2N-319 496.89 253.12 496.89 244.81 500.00 30.444 Centre Distance Pass-Major Risk 2N-319-2N-319-2N-319 617.82 253.95 617.82 243.85 625.00 25.141 Clearance Factor Pass-Major Risk 2N-319-Plan:2N-319A-2N-319Awp03 496.89 253.12 496.89 244.94 500.00 30.928 Centre Distance Pass-Major Risk 2N-319-Plan:2N-319A-2N-319Awp03 617.82 253.95 617.82 243.98 625.00 25.469 Clearance Factor Pass-Major Risk 2N-320-2N-320-2N-320 816.48 228.56 816.48 215.14 850.00 17.024 Centre Distance Pass-Major Risk 2N-320-2N-320-2N-320 883.65 229.19 883.65 214.51 925.00 15.607 Clearance Factor Pass-Major Risk 2N-321-2N-321-2N-321 706.28 200.12 706.28 188.03 725.00 16.554 Centre Distance Pass-Major Risk 2N-321-2N-321-2N-321 728.36 200.47 728.36 188.00 750.00 16.079 Clearance Factor Pass-Major Risk 2N-321-2N-321A-2N-321A 706.28 200.12 706.28 188.03 725.00 16.554 Centre Distance Pass-Major Risk 2N-321-2N-321A-2N-321A 728.36 200.47 728.36 188.00 750.00 16.079 Clearance Factor Pass-Major Risk 2N-323-2N-323-2N-323 794.12 159.64 794.12 146.05 825.00 11.751 Clearance Factor Pass-Major Risk 2N-323-2N-323A-2N-323A 793.88 160.28 793.88 146.69 825.00 11.789 Clearance Factor Pass-Major Risk 2N-325-2N-325-2N-325 496.86 159.56 496.86 151.15 500.00 18.975 Centre Distance Pass-Major Risk 19 May,2014- 9:35 Page 2 of 7 COMPASS J -R ! A L ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2N-336-2N-336wp03 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:Kuparuk 2N Pad-Plan:2N-336-Plan:2N-336-2N-336wp03 Scan Range:0.00 to 11,731.71 ft.Measured Depth. Scan Radius is 1,370.37 ft.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 (ft) (ft) (ft) (ft) ft 2N-325-2N-325-2N-325 570.36 160.03 570.36 150.51 575.00 16.818 Clearance Factor Pass-Major Risk 2N-326-2N-326-2N-326 792.68 99.50 792.68 85.78 825.00 7.250 Clearance Factor Pass-Major Risk 2N-327-2N-327-2N-327 786.23 109.28 786.23 95.32 800.00 7.828 Centre Distance Pass-Major Risk 2N-327-2N-327-2N-327 809.99 109.33 809.99 95.06 825.00 7.664 Clearance Factor Pass-Major Risk 2N-329-2N-329-2N-329 904.35 85.93 904.35 70.21 925.00 5.466 Centre Distance Pass-Major Risk 2N-329-2N-329-2N-329 951.13 86.69 951.13 69.70 975.00 5.104 Clearance Factor Pass-Major Risk 2N-331-2N-331-2N-331 690.07 49.23 690.07 37.65 700.00 4.253 Clearance Factor Pass-Major Risk 2N-332-2N-332-2N-332 663.05 24.18 663.05 13.14 675.00 2.190 Centre Distance Pass-Major Risk 2N-332-2N-332-2N-332 687.18 24.33 687.18 12.83 700.00 2.116 Clearance Factor Pass-Major Risk 2N-332-2N-332PB1-2N-332PB1 663.05 24.18 663.05 13.14 675.00 2.190 Centre Distance Pass-Major Risk 2N-332-2N-332PB1-2N-332PB1 687.18 24.33 687.18 12.83 700.00 2.116 Clearance Factor Pass-Major Risk 2N-333-2N-333-2N-333 713.36 35.91 713.36 22.19 725.00 2.618 Centre Distance Pass-Major Risk 2N-333-2N-333-2N-333 737.90 36.25 737.90 22.19 750.00 2.577 Clearance Factor Pass-Major Risk 2N-335-2N-335-2N-335 46.90 14.91 46.90 13.65 50.00 11.770 Centre Distance Pass-Major Risk 2N-335-2N-335-2N-335 496.82 18.75 496.82 10.32 500.00 2.224 Clearance Factor Pass-Major Risk 2N-337-2N-337-2N-337 271.89 14.39 271.89 9.90 275.00 3.202 Centre Distance Pass-Major Risk 2N-337-2N-337-2N-337 346.87 15.08 346.87 9.33 350.00 2.624 Clearance Factor Pass-Major Risk 2N-337-2N-337A-2N-337A 271.89 14.39 271.89 9.90 275.00 3.202 Centre Distance Pass-Major Risk 2N-337-2N-337A-2N-337A 346.87 15.08 346.87 9.33 350.00 2.624 Clearance Factor Pass-Major Risk 2N-337-2N-3376-2N-337B 269.62 14.39 269.62 9.93 275.00 3.229 Centre Distance Pass-Major Risk 2N-337-2N-337B-2N-337B 344.60 15.04 344.60 9.33 350.00 2.634 Clearance Factor Pass-Major Risk 2N-337-Plan:2N-337C-2N-337Cwp03 271.79 14.39 271.79 9.90 275.00 3.203 Centre Distance Pass-Major Risk 2N-337-Plan:2N-337C-2N-337Cwp03 346.77 15.08 346.77 9.33 350.00 2.624 Clearance Factor Pass-Major Risk 2N-339-2N-339-2N-339 346.88 42.81 346.88 36.91 350.00 7.260 Centre Distance Pass-Major Risk 2N-339-2N-339-2N-339 396.85 43.25 396.85 36.53 400.00 6.437 Clearance Factor Pass-Major Risk 2N-341-2N-341-2N-341 96.90 75.57 96.90 73.77 100.00 41.926 Centre Distance Pass-Major Risk 2N-341-2N-341-2N-341 371.86 77.23 371.86 70.92 375.00 12240 Clearance Factor Pass-Major Risk 2N-342-2N-342-2N-342 1,086.22 82.39 1,086.22 63.88 1,075.00 4.450 Clearance Factor Pass-Major Risk 2N-343-2N-343-2N-343 296.90 104.80 296.90 99,60 300.00 20.140 Centre Distance Pass-Major Risk 2N-343-2N-343-2N-343 346.90 105.17 346.90 99.15 350.00 17.469 Clearance Factor Pass-Major Risk 19 May,2014- 9:35 Page 3 of 7 COMPASS IGINAL ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2N-336-2N-336wp03 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design: Kuparuk 2N Pad-Plan:2N-336-Plan:2N-336-2N-336wp03 Scan Range:0.00 to 11,731.71 ft.Measured Depth. Scan Radius is 1,370.37 ft.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 (ft) (ft) (ft) (ft) ft 2N-345-2N-345-2N-345 46.90 135.10 46.90 133.97 50.00 118.831 Centre Distance Pass-Major Risk 2N-345-2N-345-2N-345 4,827.77 275.02 4,827.77 88.66 4,650.00 1.476 Clearance Factor Pass-Major Risk 2N-345-2N-345A-2N-345A 44.70 135.10 44.70 134.00 50.00 121.973 Centre Distance Pass-Major Risk 2N-345-2N-345A-2N-345A 4,825.60 274.83 4,825.60 87.60 4,650.00 1.468 Clearance Factor Pass-Major Risk 2N-347-2N-347-2N-347 40.12 165.07 40.12 163.89 50.00 140.420 Centre Distance Pass-Major Risk 2N-347-2N-347-2N-347 340.11 166.31 340.11 160.55 350.00 28.895 Clearance Factor Pass-Major Risk 2N-348-2N-348-2N-348 191.80 180.20 191.80 176.47 200.00 48.386 Centre Distance Pass-Major Risk 2N-348-2N-348-2N-348 391.78 181.56 391.78 173.92 400.00 23.759 Clearance Factor Pass-Major Risk 2N-349-2N-349-2N-349 1,684.34 68.69 1,684.34 37.89 1,650.00 2.230 Clearance Factor Pass-Major Risk 2N-349-2N-349A-2N-349A 1,684.34 68.69 1,684.34 37.89 1,650.00 2.230 Clearance Factor Pass-Major Risk 2N-349-Plan:2N-349B-2N-349B(wp01) 1,684.34 68.69 1,684.34 37.89 1,650.00 2.230 Clearance Factor Pass-Major Risk 2N-350-2N-350-2N-350 342.17 207.17 342.17 200.58 350.00 31.461 Centre Distance Pass-Major Risk 2N-350-2N-350-2N-350 367.17 207.53 367.17 200.46 375.00 29.336 Clearance Factor Pass-Major Risk 2N-350-Plan:2N-350A-2N-350Awp03 342.17 207.17 342.17 200.58 350.00 31.461 Centre Distance Pass-Major Risk 2N-350-Plan:2N-350A-2N-350Awp03 367.17 207.53 367.17 200.46 375.00 29.336 Clearance Factor Pass-Major Risk Plan:2N-322(Lexington)-2N-322-2N-322wp09 398.40 209.92 398.40 202.71 400.00 29.080 Centre Distance Pass-Major Risk Plan:2N-322(Lexington)-2N-322-2N-322wp09 498.39 210.52 498.39 201.70 500.00 23.867 Clearance Factor Pass-Major Risk Plan:2N-322(Lexington)-2N-322PB1-2N-322PB1wp 398.40 209.92 398.40 202.71 400.00 29.080 Centre Distance Pass-Major Risk Plan:2N-322(Lexington)-2N-322PB1-2N-322PB1wp 498.39 210.52 498.39 201.70 500.00 23.867 Clearance Factor Pass-Major Risk Prelim:2N-324(Purple)-2N-324-2N324wp03 286.40 179.79 286.40 174.07 300.00 31.432 Centre Distance Pass-Major Risk Prelim:2N-324(Purple)-2N-324-2N324wp03 411.31 181.01 411.31 172.84 425.00 22.155 Clearance Factor Pass-Major Risk Prelim:2N-330(Peggy)-2N-330-2N-330(wp02) 684.07 86.10 684.07 72.96 700.00 6.552 Centre Distance Pass-Major Risk Prelim:2N-330(Peggy)-2N-330-2N-330(wp02) 732.27 86.46 732.27 72.47 750.00 6.177 Clearance Factor Pass-Major Risk Prelim:2N-330(Peggy)-2N-330PB1-2N-330PB1(wp 684.07 86.10 684.07 72.96 700.00 6.552 Centre Distance Pass-Major Risk Prelim:2N-330(Peggy)-2N-330PB1-2N-330PB1(wp 732.27 86.46 732.27 72.47 750.00 6.177 Clearance Factor Pass-Major Risk 19 May,2014- 9:35 Page 4 of 7 COMPASS 3 RIGIN AL ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2N-336 -2N-336wp03 Survey tool program From To Survey/Plan Survey Tool (ft) (TO 28.00 1,000.00 2N-336wp03 GYD-GC-SS 1,000.00 2,500.00 2N-336wp03 MWD 1,000.00 2,644.30 2N-336wp03 MWD+IFR-AK-CAZ-LC 2,644.30 4,144.30 2N-336wp03 MWD 2,644.30 8,410.04 2N-336wp03 MWD+IFR-AK-CAZ-SC 8,410.04 9,910.04 2N-336wp03 MWD 8,410.04 11,731.71 2N-336wp03 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor=Distance Between Profiles/(Distance Between Profiles-Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 19 May,2014- 9:35 Page 5 of 7 COMPASS ORIGI \ AL ConocoPhillips(Alaska)Inc.-Ku p2 Kuparuk River Unit Anticollision Report for Plan: 2N-336-2N-336wp03 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan:117.7+28 @ 145.708(Nabors 9ES). Northing and Easting are relative to Plan:2N-336. Coordinate System is US State Plane 1983,Alaska Zone 4. Central Meridian is-150.00°,Grid Convergence at Surface is:-0.30°. LN-s19,Plan:LIW31VA,dN-.3 19W147U3 VU Ladder Plot $2N-320,2N-320,2N-320 V2 $2N-321,2N321,2N-321 V2 -, _ $2N-321,2N-321A2N321AV4 �,, i.t r'• t/:I �' �: 11 11 11 $2N!_323,2N!_323,2f�323V2 li 11 '1` cp. rloC,,,o, r� ,1 ° II ,; .vk' , $2N323,2N-323A2N1-323AV0 C 1200 I. i' ',�I11 1) I) 'i r`,r f 2N-325,2N-325,2N-325 V2 111 i rfifir L , r I, ,> 0 r,'.1 i 1 f 7/, _ 1r1 -4-2N-326,2N-326,2N-326 V3 O r( 11 r'II /1�%1///t:>/: 1 1 /l -E-2N-327,2N327,2N-327V13 � j� i ��7��i1�./S Iii �.0,' �- fr, I, 1%I {� -1--- •_ 1 .J _1 -J----.- $2N-329,2N-329,2N-329 V2 1 C II III `II r,',1,,,.•,, 1 -iI I) r Y. -- 'e 1Ii O —3-2Nl-331,2N-331,2NJ-331 V2 I,I, :sir/ve., 94 * :fit `�., Eli I '�% �i1� /•�• 4I f 2N-332,2N-332.2N1-332 V6 oa 800 r,, i!,r!J1 �-2N332,2N332PB1,2N332PB1 V4 � 1; f '��'I i��'i � ��.��-'" -�(-2N-333,2fw333,2NJ-333V4 i�r •:'i�/i�, �' ' 3.2N-335,2Nl 335,2N-335 V2 �; , C r. ; ,„.t t -4 2NJ337,zN1337,2N337V1 U 7-,',I. / -4-2N337,2N1-337A,2N1-337AV1 o 400 'f *�j� r, 7• ---)-2N337,2N33713,2N-337BV5 1.r ` /rte 1 r� -4-2N-337,Plan:2N337C,2N337Cv„p03VO '11) = , ...1, = i -�2N-339,2N-339,2N-339 V8 0) _ 4di .,. i • J ____J____ "f 2N-341,2N-341,2N-341 V9 U -�`e'..i, ., , i -9-2N-342,2N-342,2N-342 V3 "fir.:44't I —3-2N-343,2N-343,2N-343V11 0 - $2N345,2N-345,2N345V1 0 2000 4000 6000 8000 10000 -4)-2N-345,2N-345A2N-345AV2 Measured Depth(2000f/in) 9 2N-347,2N-347,2N-347V10 $2N-348,2N-348.2N-348V18 19 May,2014- 9:35 Page 6 of 7 COMPASS J IGINAL ConocoPhillips(Alaska)Inc.-Kup2 Kuparuk River Unit Anticollision Report for Plan: 2N-336-2N-336wp03 Clearance Factor Plot: Measured Depth versus Separation(Clearance)Factor - (■r ►� IF -- - - _ - --2N-319,Plan:2N-319A,2N319Awp03VO - r I -(1-. -9-2N-320,2N-320,2N-320 V2 10.00- - rI}'•' _...I �l' ' - ---- _.__. - _- - -- -$2N-321,2N-321,2N-321 V2 I I�ri -� 1 11 - �_ Ili :, - -,--.--- ill 11,-- ° 2N321,2N-321AAV4 r " A " .+. �. r ,i'',, _ II C l\ -- $2N-323,2N-323,2N-323 V2 e.75 � f •��� �,��■ t � I �- ; $2N-323,2N-323A 2N-323A VO {{ /� ZI--""^:�_�J i �-2N-325,2N-325,2N325V2V0 ]!l i`r, i►\; I "� , -1E-2N-326,2N326,2N326V3 7.50— — ! S _ ��'( 1 If l.� •. �'�`� 11 I -_-2N327,2N-327,2N327V13 - i 1% if,..=� v :.) o it i1/,. •4.4!,-::-.- d .. $2N-329,2N-329,2N329V2 us N A ( ,11,:,, f �� -$2N-331,2N-331,2N331 V2 6.25- I�.d 1'ti L 1. :"_� ...... o - � �1 0f -t••2N-332,2N-332,2N-332 V6 1D i EEffiE2PBiv4 PB1V4iiYs (`1,1�; m rj j : :::I ��® rj 1 D I- �� ej �� - - 1 I - $2N337,2N-337A,2N337AV1 i 11 1 ,,j °iii 1 �i IDS' -e-2N-337,2N-337B,2N-337B V5 rj -a-2N-337,Plan:2N-337C,2N337Cwp03VO 250- .�1, O Ij ... I-. �'- 4E 2N-3392N-339,2N-339V8 - .,.; =•tj 2N-341,2N-341,2N-341V9 _'" , -$2N-342,2N-342,2N342V3 125- __-.. _ -_. $2N-343,2N-343,2N-343 V11 - - $2N-345,2N345,2N-345V1 0.00 1111 i l l l $2N-345,2N-345A, 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 "'0'2N347,21'l-347,2N347 V10 Measured Depth(2000fVn) $2N-348,2N-348,2N-348 V18 19 May,2014- 9:35 Page 7 of 7 COMPASS • ' NAL • SecILMD Inc Azi TVD +W-S -E/-W DLeg TFace epee Target 1 8.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0 28 505 2N-336Wp03 2 680.06 0.00. 200.00 504.700 0.00 -1.38 1 0 200.00 S8a 4 1311.21 17.58 243.60 1300.00 -60.14 -92.29 2.50 50.00 103.92 505 905 28.00 To 11731.71 5 2435.08 56.17 258.31 2183.52 -237.25 -726.54 3.50 19.44 630.76 6 3965.91 56.17 258.31 3035.81 -495.00 -1971.77 0.00 0.00 1593.76 905 1405 7 4082.95 59.81 257.18 3097.84 -516.09 -2068.72 3.22 -14.99 1669.55 2n-336 WP02 8 6236.66 59.81 257.18 4180.88 -929.15 -3883.91 0.00 0.00 3102.94 1405 1805 9:37,ii 19 2014 I 9 8390.00 73.60 184.00 5140.04 -2332.42 -4995.18 3.14 -96.49 4892.74 10 8436.00 73.60 184.00 5153.03 -2376.44 -4998.26 0.00 0.00 4929.53 1805 2205 11 8530.40 73.84 180.57 5179.50 -2466.97 -5001.87 3.50 -86.40 5003.51 12 8661.82 73.84 180.57 5216.09 -2593.19 -5003.12 0.00 0.00 5104.37 139228.31 86.0 164.63 5315.70 -3143.17 -4930.19 3.50 C LOBAL FILTER APPLIED: A 14 9282.09 87.61 3.86 164.63 5318.70 -3194.95 -4915.96 3.00 50.117 558.487 2N336 Heel EB 28Mar14 2205 2605 15 11731.71 87.61 164.63 5420.70 -5554.96 -4267.44 0.00 0.00 7004.90 2N-336 Toe 28Mar14 EB 2605 3105 2 Neill From Depth To Survey:Plan Tool 3105 505 20.00 1000.00 2N-336,03(PIan:2.3361 GYD-GCSS 1000.00 2500.00 2N-336,03(Plan:211336) MWO 1000.00 2644 30 214J36w003(Plan:21-336) MWO.IF1I-88-CA2.LC 3505 4305 2644.30 4144.30 2N-336wp03(Plan.211336) MWD 2641.30 6410.04 2NJ36,03(Plan:2N-336) MWD.IFe1811-CA2.SC 0410.04 0910.04 21133603(Plan.21-336) MWD 4305 5105 w, 9410.04 11731.71 2/4-336,03(Plan:211336) MWD.IFA-8.8CAZSC CASING DETAILS 5105 5905 TVD MD Name Size 5905 6805 2300.00 2644.30 103/4"x13-12" 10-3/4 5145.70 8410.04 7-5/8"x9-7/8" 7-5/8 6805 7605 5420.70 11731.71 4-1/2"x 6-12" 4-1/2 7605 -- 8405 8405 9205 .7211 0/360 9205 _ 10005 �N3 10005 10305 , /4,'14,4L ., ti J- ` 10305 10605 ''' ® 10605 10905 -I -30/330 • 2 ;n • 30 12N-349B '�" v.,„tp ••' 00'1 IQ�iNI\ -� , N 349 l „., ..\,\ ' �= r t+11•�t B(WPD1 10905 11205 4\\\ �jj1�1 �9/i13s� �.o�®Ii���)��gisi �. 11205 11505 ---",`''''..,%/1\ 1+'rs.S1 -;� 2 -1 y�Niwr1. ••��lia ® , ', ,-,,,,,,-4, {„N- 9,J �An �1 1 1.1 4;11! r i►• � �w�ri4�t�` � �i>`..4 ''',N, 11505 I` '1 11505 11805 \h\Y4./Xx,7V\ �1' 0141q:0;,'.. i.P..i18'rl/-N-,,i'4�,\n.4.v**W' �W ....., ,,. .....„. ...„„,..,,,,,,..,....„. ..„•:„ N-332PB1 -c-;,Z !, \I 1 '4 r. 11 ) ;, ..'NV/4l� 1• 1 ri f.h;r •„ •••Q1 11805 12105 ��\ r 14.�, sird 1 4f:� i��� y, � ► 0 , \ 12105 12413 -60/300 • ' �x , ^rte '''' '� ; 041.4r.,t 4y\ ��9'1-i 'aj . L g/ia \ ,..x."--" ;�� +• .,- , �' .1 . yye , •( ���\\®S 921Ailko�r ri,},` f+q �• `` 60 k J'' .a .I✓ �` v �` 1 �i��tli'40/1 10.1 1/41on ♦�'40 a iN ......... •y• N.330PB1(wp02 2N-333---- '',;'1°.,1� i= ♦ �,, 1 10 �. ,��`r,��`I1,�ki� ►746 . J .�,�i� IOW'���a��. �4gw1�-�i�s aai��JII(tar+P�,�;r�Q�`•v�1®r.'r'���:• i ,... to,,,,my,A 11/2 ♦.• �` rI al ni r.• ►fit �J'As ssaP Ib�/I4tarotot. ��,3it .a�t��ilte e��d� `"d r�� ♦. 1►1 v..t.( , J , . 11 'I 1:- fr r � '"464. 41` r Il,�r (� h`4 I2Nti930(wp02� �� I d 1s i�� �6. 344 �. I 1 �vk 1 t .�gitin /t-'��`�.$��;t'„.i Lam` a! ., re ■ �i.���j' 10„; k .41 2-41/1"4 . 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Alaill't 150 N337Cwp0 n=., N-337Bwu04 12N-340teN-342 wp08 actuals final' -e- a. -6 4,4 -O. m 26,774.2343372 VI a4 349.2.3194.2.3194 V5 t 2113,2.3372.263374 01 $ 264 323.2643234.2643222 33 -6 243376.24376 3vs 3 2o- „0 33 63436 11 -$ at 211. 326,.8243376.1.06 -} m0M643r- " z24731C,267233 .4, 24 a1e03320,360,2.350 V9 -A- 4,4 634ew37«.' 33 Pew -I- 2.326,26724,6 2726.3 3€ 4,4 44.4 3,02.00333 $ 4,4 } 4,4 } 26 .4. a 63220..'emz24322.223a.e0633 -N- at $ 4,4 $ 24 -8- 632211.6i16e1..322P61.M32P6I.69V2 -} 2. -2633111. $ 24 $ 2713.7 -e- P 263241P06.1.2.a24.2w246Pm w 2i 6319,263/2 veva � .2632,2.- VII P,gym..3302722.1.22333,.2333*ON33 332. 211, 0- 132 2.32,2.26322y:µ�V3 - 232.2.335 2N337.,2.33212211y42,1393 Va ratI L$ _ . IPo9216733Pa,2 33386, 33 -4).- 1N 46 ation for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 Attachment 2— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2N-336 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. 2N-336 APD Page 11 of 14 Printed: 17-Sep-14 / ation for Permit to Drill,Well 2N-336 Saved: 17-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 2N-336 well plan. Anti-collision analysis indicates the following separation factors between the planned 2N-336 well plan and the following existing wellbore. 2N-345 (Separation Factor= 1.476, 88.7' separation ellipse to ellipse at a depth of 4,650' 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 topset to 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. 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. 2N-336 APD ORIGINAL Page 12 of 14 I\�tl Printed: 17-Sep-14 / ation for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 Attachment 3- Proposed Well Schematic Tarn 2N-336 Trip .11'.- • • Grass Roots Topset Horizontal Multi-Stage Freed Producer COnOCOPIIIIIIPS Proposed Wellbore Schematic CAMERON it f.4"tree.tep joint is it-lic 12f Il371.1 crota,eti ovet.:fur 1-ac en.narren2) Bearden Ate2b14 F , ,,a 1,,,.. L FsL 16 Existing Cemented Conductor: 16"62 60 H-40 _._ 78'MD da 3',"Careen DS 11=1, hippie 2 E•75* OO 13-1/2" 13-1/2"Surface Hole iiipiox .; Fps A-, Lam tte WOG Surface Casing: 10-3.'4'45.5#L-80 Hydril 563 — 2.644'MD/2,300'TVD(4!56' i 3 V'Como IMO ,. . . . . . . 'iD .1• In 0 PPCi :, Tubing P up with SW C ,,amcoMMG "" 3-W 9.34 L-80 EUE8RD ition 4-1/2"12.64 L-80 IBTM top joint to surface 9.718"Intermediate Hole Estimated tp oet WWII CE l''-56(13MD (5Cif above C-37; 3'V Cameo MG . . . . . . . . . . . . . . . . . . . . . . . . . . . ...... li.ebOloP O.R0eY MP z4*TO: : :. . . . . . . . . . . ., . , . , " " " " " ' • • • • - • •.•.•. . . . . .•.•. . . . . ...k.cm..1v11,3 Sian.cream...2 412-Carreto T3 Prano 'rr atlyerP..,c, I it?'x mar,Raker Prerrirs Packer 3,213'HD 3 Tii'COMO D Nipple 2,75' mi Raga 4-tii'Raker Flak Leek Lmr hanger ..•:, ZXP twill()pili7lier ve RS Nipple t AO'LID Intermediate Casing Topset with Bonzai: 7-5/8.29.70 L-80&300'1 N110SS 39#-all Hydril 563 connections , Ter:,a Rantuida.RFA7'.14ME•Tfi"T...11 . . . . _ . 8 411Y MD/5.146"TVD i., 74' :::::::::::::::::::•:•:•: :•:::•:•:•:•:•:•::. !4dihit?3.0613.3%*dii*til.f*4i,:iet:112i!OrilittiM60041 :.: --:•:•:•:•:•:•:•:•:•:•:•:: :::::::::::::::::: ':::::::::::::•:•::: ::::: ::::: :::::i:::::i::::::::::•:•:•::::::::::::::::::::::::: :10:9-.04:::: :*:::. 0 0 0 0 0 nomm -m 11 \\...,.. .. .......... ....................... .... _ : :i!:7,,,.;.:•:,:i...,...,:i....,•'...!: ... ...,:L:n.,...:„.:,.....: ...„,: :,:,:.- :,,,„: :;.k• :,,...;-;,.... ;,,.... -a,•.,..... ••••••••••••••••••••••••••••••••:•••••••••:•:•:•:•:•:•:•:•:•:•:•••:•:•:•:•::::: iir.:•,....!..:c.:41 .!--.I.,.:,:.--”.........!,t-.!-:•.,,stlint,fftp.•, .15:ii,:i....::::.... ]iti.twcooty44-1,300:0:t3t1: :::...::::.......:::iiviii : :i ii.:00•4500.1-!!'!'fi*.:0 .::::: :::• :!.:- !:•: :::::.:•:::•.:: : :.:•.i... 4- :27i12-,01:4910:tpi :;-:; :.•,i::.i,:i..:i.im T- @*2Aa :2M;'il';'.i:;: ::: ::: ::::::::::::::::::::::::::::§.4elii.:.3iitoi6•5Agi!titi*]: :]: ::..7-T::i: :]:H:i: 2N-336 Apo Page 13 of 14 oR \ G\ NAL Printed: 17-Sep-14 M E tion for Permit to Drill,Well 2N-336 Saved: 17-Sep-14 Attachment 4—Cement Summary 10-3/4" Surface Casing Cement Job Cement 103/4" casing from shoe @ 2,644' MD to 2,300' MD (500' of fill) with 12 PPG LiteCrete, and from 2,144'to surface with 11 PPG Arctic LiteCRETE. Assume 250%excess annular volume in permafrost and 50% excess below the permafrost(Base Perm is 1,108'MD),zero excess in 16"conductor. Lead Slurry: (78')x 0.638 ft3/ft x 1.0(0%excess)=50 ft3 (1,108'—78')x 0.364 ft3/ft x 3.5(250%excess)=1312 ft3 above permafrost (2,144'—1,108') x 0.364 ft3/ft x 1.5(50%excess)=565 ft3 below permafrost Total volume=50 ft3+1312 ft3+565 ft3=1,927 ft3=>1009 Sx @ 1.91 ft3/sk System: ^'1010 Sx Arctic LiteCRETE @ 11 PPG (343 bbls) Tail Slurry: (2,644'—2,144')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 System: 205 Sx LiteCRETE @ 12 PPG (56 bbls) 7-5/8" Intermediate Casing Cement Job Cement 7%"casing from shoe @ 8,410 MD to 5,603' MD (minimum of 500' above the top of the C-37 with 15.8 PPG Class G w/GasBLOK.Assume 40%excess in the open hole volume. Slurry: (8,410'—5,603')x 0.215 ft3/ft x 1.40(40%excess)=845 ft3 in open hole 80'shoe track x 0.258 ft3/ft x 1.0(0%excess)=20.6 ft3 Total volume=845 ft3+20.6 ft3=865.6 ft3=>740Sx @ 1.17 ft3/sk System: "'750 Sx Class G @ 15.8 PPG (154 bbls) 2N-336 APD ORIGINAL Printed 7-Sep-14 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent Wednesday, October 08,2014 9:26 AM To: 'Shultz, Steve(Orbis Engineering,Inc.)' Cc: Bearden,J Daniel (J.Daniel.Bearden@conocophillips.com) Subject: RE: KRU 2N-336(PTD 214-144) Diverter Route Schematic On diverter schematics, if possible,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 From: Shultz, Steve(Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillips.com] Sent:Thursday, October 02, 2014 10:17 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2N-336(PTD 214-144) Diverter Route Schematic Victoria, Let me know if this is sufficient. Steve From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Tuesday, September 30, 2014 2:08 PM To: Shultz, Steve (Orbis Engineering, Inc.) Cc: Bearden,3 Daniel Subject: [EXTERNAL]KRU 2N-336(PTD 214-144) Diverter Route Schematic Steve, Please provide a diverter route schematic showing the rig on the pad and the route with approximate dimensions for the diverter. This will have to be a part of all PTD application submissions in the future. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria ferqusonCa.alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 1 • •k,.... gx O • N l rirt,z,:. ..r�yLi, i ,.Vt e ;:.., N �. >'�` I, ,,NL}'` (1 \ nLz ' . .,syN. t c •:',.., , .I ` N . , 0) 1 C'x w 111 t. • •zV -: al,,,,,..-,..., t N o� ' lto =�; k `; \_ i. T` S .Y =• 1. \-�. �� V C r N. rf` ' 1�4T -.47 1, 8y v.uv .I GT • 3s • 2 azz�n�� ) x • �,. p' " . ;ZAMW F r:.9nLN :Z�,�Y f w .. i .:.-.....•...--,, NL iz�� }a¢ztMt+ 1 pt Nva l _ 1 i09-1 .0 L ,:' 1 U`tir �as�L ..ZL _,---)- vs �- — Loepp, Victoria T (DOA) From: Shultz, Steve(Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Wednesday,October 08,2014 9:20 AM To: Loepp,Victoria T(DOA) Cc: Jolley, Liz C; Bearden,J Daniel Subject: RE: Permiting for 2N-336 Trip We are looking at October 16, 2014. Thanks, Steve From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, October 08, 2014 9:13 AM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]RE: Permiting for 2N-336 Trip Yes, what is the new spud date? From: Shultz, Steve(Orbis Engineering, Inc.) [mailto:Steve.Shultz@contractor.conocophillips.com] Sent: Wednesday, October 08, 2014 9:02 AM To: Loepp, Victoria T(DOA) Cc: Jolley, Liz C; Bearden, J Daniel Subject: Permiting for 2N-336 Trip Victoria, Due to complications with our two reentry wells(2N-319 and 2N-337),the asset is looking to move 2N-336 Trip ahead in the drilling schedule and the rig could be moving to the well in a week(October 141. Would it be possible to have our 2N-336 permit reviewed early for approval? Thanks, Steve 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: /4IkU\ )4U-3•Yp PTD: 2114 - Iyy V Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: RI'`I'E,S POOL: /Lf(&J � v'/c,r- CA,fn 04 Check Box for Appropriate Letter/ Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Loggingalso required for this well: ✓ Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 (0 N °) 0 a) 0- N N_ 0 0 ..o m N 7 °) N C C Q coL U a N a) 2 C W c 30 7" E a) m a n a.- > _O Q co o O LL OM a a 0 R N L N Oi L" N O 0 ° OU 3 In Ca c E O P.O o o a -a o) 0 0 m - 0 3 • N a m a) N 7 L 0 3 L N o c a m 3 W co O L -° N co as 'O U U 0 C N co a • a) >, L = a) .0 3 _o C 3 7 a0 0 - O c n M @ @ 3. C a) C p Q CO D 7 a) 'O O- .) N 0 _ N co >O cc x ° =p a) > N N 2 a)co n F- o- 2 w' Z O O C L o ° • N (O O 7 6) > m -a. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk Rig: Nabors 9ES Date: January 27, 2015 Surface Data Logging End of Well Report 2N-336 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: Nabors 9ES Well: 2N-336 Field: Kuparuk River Unit Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20693-00-00 Sperry Job Number: AK-XX-0901987902 Job Start Date: 28 December 2014 Spud Date: 29 December 2014 Total Depth: 12229’ MD, 5384’ TVD North Reference: True Declination: 18.790° Dip Angle: 80.753° Total Field Strength: 57545.353 nT Date Of Magnetic Data: 01 January 2015 Wellhead Coordinates N: North 70° 10’ 11.706” Wellhead Coordinates W: West 150° 19’ 12.332“ Drill Floor Elevation 146.49’ Ground Elevation: 119.12’ Permanent Datum: Mean Sea Level SDL Engineers: Jake Hansen, Leigh Ann Rasher, Hilary Garney SDL Sample Catchers: Mario Luescher, Kyle Wiseman, Christopher Medeiros, Javier Valdovinos-Sierra Company Geologist: Barry Wright, Jeff McBeth Company Representatives: Josh Riley, Don Mickey, Randy Dolcater SSDS Unit Number: 121 DAILY SUMMARY 12/28/2014 Began to rig up the rig and the unit per company man, then the pre-spud checklist was ran through from which the diverter system was nipple up. From there the upper and lower seals on the stating head were tested and 4 inch annulus valves on the conductor were installed. The pits began to take on mud and the pipe shed loaded 30 joints of 5 inch drill pipe. 12/29/2014 Began to pick up 5 inch drill pipe and rack it back into the derrick. Function tested the annular and knife valve, which took 9 seconds to open up and 20 seconds to close the annulus. The diverter was nippled down and chained securely and prepared to install the final section of the line. The rig then began the circulate and condition test up to 2900 pounds per square inch while moving fluids into the pits. Nippled up last diverter over the tundra and began to make up the bottom hole assembly which drilled from 99’ MD to 251’ MD. Gas: 30 units maximum and 6 units average Fluid: 0 bbls lost/gain down hole Geology: light gray, white, translucent to transparent, green, black, dull yellow sand that is coarse grained, sub-angular to sub-rounded, well sorted with abundant glauconite, trace mica and is slightly calcareous. 12/30/2014 Drilled ahead to 1274’ MD and circulated bottoms up while pumping a Hi-Vis sweep around from which drill pipe was pulled out to around 680’ MD. The rig encountered increase drag while pulling out so they rig began back reaming while pumping the rest of the way out of the hole to 250’ MD. The weather began to deteriorate rapidly and the decision was made to wait on weather since it was phase 3. Gas: 9637 units maximum and 307 units average Fluid: 34 bbls lost down hole Geology: white, clear, translucent to transparent, light to medium to dark gray light to medium green, fine to very fine grained, well sorted, sub-angular to sub-rounded unconsolidated sand with trace glauconite chert, and siltstone. 12/31/2014 The bottom hole assembly and drill pipe are out of the hole still waiting on the weather to improve. Gas: 60 units maximum and 3 units average Fluid: 0 bbls lost/gain down hole Geology: No samples were collected due to weather 01/01/2015 After the weather improved, we picked up the bottom hole assembly and drill pipe then tripped back into the hole to 1273’ MD. The mud was conditioned and drilling continued. Gas: 2202 units maximum and 385 units average Fluid: 18 bbls lost down hole Geology: light to medium gray, blocky, soft, clay with abundant interbedded unconsolidated sand that is moderately silty with trace glauconite. 01/02/2015 Drilled ahead to 2,606’ MD and circulated bottoms up where it was determined that the surface casing shoe was not reached so we drilled ahead to 2648’ MD and circulated bottoms up. This was the TD for the surface section. After circulating and conditioning the hole we began to back ream out. Gas: 860 units maximum and 315 units average Fluid: 0 bbls lost/gain down hole Geology: clear, white, black, green, light to medium gray, opaque to translucent, medium to fine grained, sub-angular to sub-rounded, moderately sorted unconsolidated sand with moderate glauconite mixed with light to medium gray, plastic, soft, very amorphous clay that is slightly silty. 01/03/2015 Began running 10-3/4” surface casing while keeping the hole filled and pumped down every 10th joint. Gas: 813 units maximum and 41 units average Fluid: 0 bbls lost/gain down hole 01/04/2015 Finished running 10-3/4” surface casing while circulating bottoms up at 1300’ MD and 2611’ MD then prepared for the cement job. The mud was circulated and conditioned prior to rigging up and performing the cement job. After the surface casing was cemented, the rig began to clean the pits and nipple up the blow out preventers for the intermediate and production sections. Gas: 781 units maximum and 31 units average Fluid: 0 bbls lost/gain down hole 01/05/2015 Nippled up and down the diverter system and cleaned out the rotary table. The tree was then brought into the cellar where it was hung. The rig then installed the well head, cleaned the seals and set the well head. Afterwards the cellar was prepared along with the well head and began to test the well head and seals. The test plugs and working valves were also installed. The blowout preventers was then nippled up and prepped then tested. Gas: No gas recorded Fluid: 0 bbls lost/gain down hole 01/06/2015 The blowout preventers were tested and passed. Afterwards, 5” drill pipe was being picked up while performing rig maintenance on the Kelly hose and top drive. Then began to prepare bottom hole assembly number 4. Gas: No gas recorded Fluid: 0 bbls lost/gain down hole 01/07/2015 Picked up bottom hole assembly number 4 and ran into the hole to 1512’ MD to perform a shallow hole test MWD tools. The continued to run into the hole to 2423’ MD and cut and slipped the drill line. The rig was then serviced afterwards the mud was circulated and conditioned until it was clean. The casing was then pressure tested to 3000 pounds per square inch for 30 minutes then continued to wash and ream into the hole from 2423’ MD to 2545’ MD. The cement was drilled out and 20 feet of new formation was drilled to 2668’ MD. The mud was circulated and conditioned then the formation integrity test was performed to 15.5 equivalent mud weight. The top drive was then serviced and mud was displaced to 9.6 pounds per gallon LSND then began to drill head from 2668’ MD to 2710’ MD. Gas: 34 units maximum and 15 units average Fluid: 0 bbls lost/gain down hole Geology: Light gray, soft and amorphous clay with unconsolidated clear, translucent to transparent white abd black, very fine to fine grained sub angular to sub rounded sand and siltstone. 01/08/2015 Control drilled ahead from 2710’ MD to 4589’ MD. Gas: 212 units maximum and 50 units average Fluid: 0 bbls lost/gain down hole Geology: Medium brown to medium and dark gray, friable and soft, very well sorted, moderately cemented siltstone with rare shell fragments along with unconsolidated sand and clay. 01/09/2015 Drilled ahead from 4589’ MD to 5625’ MD, then began a short trip back to the surface casing shoe and circulated bottoms up. Gas: 97 units maximum and 51 units average Fluid: 0 bbls lost/gain down hole Geology: Medium to dark brown, medium to dark gray, friable and soft, very well sorted, well cemented siltstone with abundant clay, trace amounts of unconsolidated sand and shell fragments. 01/10/2015 Circulated at shoe then began to run back into the hole to 5625’ MD and continued to control drill ahead in the intermediate section from 5625’ MD to 6220’ MD. Gas: 252 units maximum and 60 units average Fluid: 0 bbls lost/gain down hole Geology: Dark to light gray/black, plastic and soft, amorphous and blocky, hydrophilic, slightly laminated clay with abundant firm medium gray claystone fragments and abundant pyrite. 01/11/2015 Continued to control drill from 6220’ MD to 7927’ MD Gas: 1494 units maximum and 110 units average Fluid: 0 bbls lost/gain down hole Geology: Translucent to transparent, clear and white, fine to very fine grained sandstone with intervals of gray to brown siltstone and clay. 01/12/2015 Continued to drill ahead from 7927’ MD to intermediate TD of 8114’ MD. Pump sweep and begin to back ream out of the hole. Gas: 175 units maximum and 91 units average Fluid: 0 bbls lost/gain down hole Geology: Light grey to dark grey with light brown, plastic to soft hardness, amorphous texture, slight laminated, trace firm med grey siltstone fragments. 01/13/2015 Circulated hole clean at shoe then continued to pull out of the hole and begin to fish for dropped hammer. Laid down bottom hole assembly #4 and 5” drill pipe. Gas: 23 units while back reaming out of the hole Fluid: 0 bbls lost/gain down hole 01/14/2015 Continued to pull of the hole and lay down 5” drill pipe. Rigged up and tested the blowout preventers. Rigged up and ran in the hole with 7-5/8” casing. Gas: No gas recorded Fluid: 0 bbls lost/gain down hole 01/15/2015 Continued to run in the hole with 7-5/8” casing. Circulated and conditioned mud at 4551’ MD to get 9.7 mud weight in and out. Gas: 41 units while back reaming out of the hole Fluid: 0 bbls lost/gain down hole 01/16/2015 Circulated and conditioned mud at 6565' MD. Run in hole with 7-5/8" casing. Circulated and conditioned mud to keep 9.7 mud weight in and out. Made up landing joint and hanger then circulated and conditioned mud for cement job. Pumped cement job and the floats didn’t hold. Rigged up and pressure tested up to 1150 pounds per square inch, then monitored well while waiting on cement. Gas: No gas was recorded Fluid: 0 bbls lost/gain down hole 01/17/2015 Changed out rams and laid down 5" drill pipe. Installed, tested and plugged then flooded the blowout preventers with water. Tested top rams to 3500 pounds per square inch and annular to 2500 pounds per square inch. Loaded 4" drill pipe into the shed and then began to pick up 4" drill pipe while cleaning out the pits. Gas: No gas recorded. Fluid: 0 bbls lost/gain down hole 01/18/2015 Continued to pick up 4" drill pipe. Freeze protected the well and tested the blowout preventers. Gas: No gas was recorded. Fluid: 0 bbls lost/gain down hole 01/19/2015 Continued to test the blowout preventers. Rigged down test equipment and began to pick up bottom hole assembly #5 and ran into the hole with drill pipe to 1469' MD and shallow hole tested MWD tools. Continued to run drill pipe into the hole to 4232' MD then once at 4515' MD, the sonic tool was turned on for logging then continued to trip into the hole. Gas: No gas was recorded. Fluid: 0 bbls lost/gain down hole 01/20/2015 Tripped into the hole while filling pipe every 2000' and reaming and washing out the hole from 7849' MD to 7983' MD until the cement was tagged. Circulated and conditioned mud. Pressure tested casing to 3000 pounds per square inch for 30 minutes. Cut and slip drill pipe and serviced the rig. Drilled ahead from 7983' MD to 8139' MD and performed formation integrity test to 15.9 pounds per gallon. Began to prepare mud for displacement. Gas: No gas was recorded. Fluid: 0 bbls lost down hole. 01/21/2015 Displaced mud to 9.8 pounds per gallon Klashield. Drilled ahead from 8139' MD to 9232' MD.. Gas: Max gas was 2488 units and average gas was 395 units. Fluid: 52 bbls lost down hole Geology: Samples have consisted of 65%-90% light brown to light gray siltstone with 10%- 35% siltstone. 01/22/2015 Drilled ahead from 9232’ MD to 11082’ MD. Gas: Max Gas was 6161 units and average was 1588 units Fluid: 0 bbls lost down hole Geology: Samples have consisted of sand with sandstone fragments and siltstone. 01/23/2015 Drilled ahead from 11085’ MD to 11847’ MD and then began to wash and ream the hole. Picked up 12 more joints of drill pipe then continued to drill ahead to a TD of 12229’ MD. Washed and reamed the hole while the mud was circulated and conditioned. Monitored the well for 10 minutes and it was static. Gas: Max Gas was 2840 units and average was 684 units Fluid: 0 bbls lost down hole Geology: Samples have consisted of sandstone with siltstone fragments present. 01/24/2015 Backreamed from TD of 12229’ MD to inside the casing shoe from which the well was monitored for flow but it was static then circulated bottoms up while conditioning and cleaning out the casing. Then began to pull out of the hole on elevators and laid down bottom hole assembly #5 and drill pipe. Gas: Max Gas was 117 units and average was 19 units Fluid: 0 bbls lost down hole. 01/25/2015 Began to run into the hole with 4.5” liner from surface to 3181’ MD from which the well was monitored on the trip tank while watching for swabbing. Then the hanger assembly was made up along with 4” drill pipe and continued to run into the hole to 8079’ MD and circulated two bottoms up before continuing into the hole. Gas: Max Gas was 23 units and average was 3 units Fluid: 0 bbls lost down hole. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 0 5 10 15 20 25 30 35 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2N-336 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: MI Swaco RIG: Nabors 9ES SPERRY JOB: AK-XX-0901987902 Days vs. Depth 28 December 2014 Sperry SDL Arrived on Location LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 29-Dec-2014 TD: 23-Jan-2015 Commenced 13.5" Surface Hole Section On Bot: 17:49 29 Dec 2014 TD Surface Hole Section 2648' MD, 2648' TVD Off Bot: 21:22 02 Jan 2015 Commenced 9 7/8" Intermediate Hole Section On Bot: 19:05 07 Jan 2015 Landed 10.75" Casing 2638' MD, 2290' TVD 04 Jan 2015 Short Trip to Shoe Off Bot: 16:30 09 Jan 2015 On Bot: 07:43 10 Jan 2015 Landed 7.625" Casing 8104' MD, 5032' TVD 16 Jan 2015 TD Intermediate Hole Section 8114' MD, 5036' TVD Off Bot: 05:10 12 Jan 2015 Commenced 6.5" Production Hole Section On Bot: 17:14 20 Jan 2015 TD Production Hole Section 12229' MD, 5384' TVD Off Bot: 18:04 23 Jan 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The flow in the possum belly did not stay consistent and the gas trap had to be raised or lowered several times throughout the section. The gas trap also kept getting clogged with clay cuttings. Recommendations: Talk to the pit watcher or driller and make sure the pit watcher rinses out the possum belly at connections. Innovations and/or cost savings: N/A Nabors 9ES Surface Leigh Ann Rasher 2-Jan-2015 What went as, or better than, planned: No major difficulties were experienced with INSITE or gas equipment. 2N-336 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0901987902 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: Canrig RigWatch froze a few times while drilling. The chromatograph also flamed out and stopped cycling which caused a gap in chromatograph data. Recommendations: Keep an eye on the chromatograph at all times. Innovations and/or cost savings: N/A Nabors 9ES Intermediate Leigh Ann Rasher 15-Jan-2015 What went as, or better than, planned: No major difficulties were experienced. The gas trap level was somewhat consistent after drilling the first few thousand feet. 2N-336 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0901987902 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: We had to do a bit adjustment and the chromatograph flamed out creating some missing data but the issue was caught and handled to the best of our abilities. Recommendations: Keep a pipe tally to keep track of depth to minimize bit depth corrections. Innovations and/or cost savings: N/A Nabors 9ES Production Hilary Garney 26-Jan-2015 What went as, or better than, planned: When issues with the chromatograph and having to do a bit adjustment came up, the crew dealt with the issues while keeping the right people in the loop. 2N-336 Kuparuk River Unit ConocoPhillips Alaska, Inc.North Slope Borough AK-XX-0901987902 Alaska Surface Data Logging After Action Review 2N-336 ConocoPhillips Alaska, Inc. MI Swaco Nabors 9ES AK-XX-0901987902 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++ 28-Dec 0 9.60 57 12 18 9/22/27 42/30/24/17/8/7 1/-6.0 0/94 -0.07 9.3 5.0 -/---Spud Mud / Rig Move 29-Dec 250 9.70 153 18 43 38/61/68 79/61/54/47/33/32 5/-7.0 1/93 0.20 0.10 9.3 7.5 0.00/0.00 540 -Preparing to Spud 30-Dec 1274 9.70 151 18 42 40/60/69 78/60/54/47/33/31 5/-8.0 1/92 0.20 -9.2 7.5 0.05/0.50 1500 40 TOH due to Weather 31-Dec 1274 9.60 151 17 41 42/58/69 20.0 75/58/51/45/30/28 5/-7.0 -/93 0.50 0.50 9.1 27.5 0.05/0.50 1800 40 Hold for Weather 1-Jan 1804 9.80 225 36 81 47/62/78 20.0 153/117/99/83/52/50 5/-9.0 -/91 0.20 -9.0 27.5 0.05/0.50 2800 40 Drilling Ahead in Surface Section 2-Jan 2648 9.70 275 34 57 40/72/92 18.0 125/91/75/56/41/39 5/-8.0 -/92 0.25 0.08 9.0 37.0 0.05/2.00 2800 40 TD Surface Section 3-Jan 2648 9.70 325 36 70 23/55/83 -142/106/88/64/30/28 3/-9.0 -/91 0.25 0.02 9.0 25.0 0.03/0.05 800 40 Running 10-3/4" Surface Casing 4-Jan 2648 9.80 95 28 27 6/9/13 8.0 83/55/38/25/10/9 2/-8.0 -/92 0.25 -8.4 27.5 0.01/0.30 900 40 Cemented Surface Casing 5-Jan 2648 9.80 97 29 26 7/10/15 8.0 84/55/37/25/10/9 2/-8.0 -/92 0.25 -8.3 27.5 0.01/0.29 900 40 Test BOP stack 6-Jan 2648 9.80 105 31 28 6/8'/12 8.0 90/59/45/32/10/9 2/-8.0 -/92 0.25 -8.3 27.5 0.00/0.20 900 40 P/U BHA #4 7-Jan 2648 9.60 50 11 8 6/7/9 8.0 30/19/15/11/6/5 2/-7.0 -/93 0.50 1.60 9.2 25.0 0.60/2.10 900 120 Drilling Ahead in Intermediate Section 8-Jan 4460 9.60 47 13 22 9/15/22 4.8 48/35/27/21/10/9 1/-7.0 4/89 0.25 1.00 9.8 12.5 0.40/1.70 4200 80 Drilling Ahead in Intermediate Section 9-Jan 5625 9.60 48 15 20 10/17/24 4.8 50/35/29/22/11/10 1/-7.0 3/90 0.25 0.70 9.8 20.0 0.35/1.00 4000 80 Short Trip 10-Jan 6150 9.60 46 13 20 9/14/19 4.5 46/33/28/21/10/9 1/-7.0 4/89 0.25 0.40 9.7 12.5 0.40/1.30 3400 80 Drilling Ahead in Intermediate Section 11-Jan 7810 9.60 46 12 20 9/12/15 4.2 44/32/26/21/10/9 1/-7.0 4/89 0.25 0.40 9.8 15.0 0.30/1.10 2600 80 Drilling Ahead in Intermediate Section 12-Jan 8114 9.70 45 10 20 9/12/15 4.2 40/30/26/20/10/9 1/-8.0 4/88 0.25 0.20 9.5 17.5 0.15/1.10 2400 80 BROOH 13-Jan 8114 9.70 48 13 20 9/12/15 4.2 46/33/27/22/10/9 1/-8.0 4/88 0.25 0.20 9.5 17.5 0.15/0.90 2400 80 L/D 5" DP 14-Jan 8114 9.70 45 11 21 9/10/12 4.3 43/32/26/22/10/9 1/-8.0 4/88 0.25 0.20 9.5 17.5 0.15/0.90 2400 80 RIH 7-5/8" Csg 15-Jan 8114 9.70 45 11 16 10/12/14 4.2 38/27/23/18/9/7 1/-8.0 4/88 0.25 0.15 9.2 17.5 0.20/0.80 2400 80 RIH 7-5/8" Csg 16-Jan 8114 9.70 46 10 17 10/12/16 4.2 37/27/23/18/8/6 1/-8.0 4/88 0.25 0.10 9.2 17.5 0.15/0.80 2400 80 L/D Cmt Equip 17-Jan 8114 9.70 45 9 18 10/12/17 4.2 36/27/23/18/8/6 1/-8.0 4/88 0.25 0.10 9.2 17.5 0.15/0.80 2400 80 P/U 4" DP 18-Jan 8114 9.70 45 9 17 10/12/18 4.3 35/26/22/16/8/6 1/-8.0 4/88 0.25 0.10 9.1 17.5 0.15/0.80 2400 80 Testing BOPs 19-Jan 8114 9.70 46 9 17 10/12/18 4.3 35/26/21/16/8/6 1/-8.0 4/88 0.25 0.10 9.1 17.5 0.15/0.80 2400 80 Trip In Hole 20-Jan 8139 9.70 44 10 17 9/20/26 4.2 37/27/22/18/7/6 1/-8.0 4/88 0.25 1.10 10.5 17.5 0.80/2.30 2400 80 Displacement Prep 21-Jan 9085 9.80 43 11 18 8/10/10 3.7 40/29/25/19/8/7 1/2 8.0 2/90 -3.80 10.0 2.5 3.40/9.20 43000 80 Drilling Production 22-Jan 10845 9.90 43 13 20 9/11/15 3.4 46/33/28/21/8/6 1/-8.5 3/89 0.25 2.90 9.8 3.75 3.10/7.80 62000 80 Drilling Production 23-Jan 12229 9.80 43 11 18 7/9/10 3.9 40/29/24/18/7/6 1/-8.5 4/88 0.25 2.70 9.9 3.8 3.10/7.20 66000 80 TD Production Section 24-Jan 12229 9.80 43 10 17 7/9/9 3.4 37/27/22/17/6/5 1/2 8.5 4/88 0.25 2.80 10.0 5.0 3.30/7.30 60000 80 RU to Run 4.5" Liner 25-Jan 12229 9.80 43 10 15 7/9/9 3.4 35/25/21/15/7/6 1/-8.5 4/88 0.25 2.80 10.0 5.0 3.30/7.3 60000 80 RIH w/ 4.5" Liner Casing Record WELL NAME:LOCATION: Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:29-Dec-2014 SPERRY JOB:TD:23-Jan-2015 Remarks 16" Conductor @ 78' MD, 78' TVD 10.75" Casing @ 2638' MD, 2290' TVD 7.625" Casing @ 8104' MD, 5032' TVD W a t e r a n d O i l B a s e d M u d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 SLB XR+ Milltooth 13-1/2 78 251 146 1.50 0.994 94.8 0 ----P/U BHA #1 2 200 2 SLB XR+ Milltooth 13-1/2 251 1274 1023 7.90 0.994 129.0 15 60 1250 630 0-0-N0-A-E-I-NO-WC POOH due to Weather 3 300 2RR SLB XR+ Milltooth 13-1/2 1274 2648 1374 14.70 0.994 93.3 20 60 1750 630 1-1-CT-M-E-1-NO-TD TD Surface Section 4 400 3 NOV SKH516D PDC 9-7/8"2648 8114 5466 53.00 0.994 103.1 15 150 2450 650 1-1-WT-A-X-IN-NO-TD TD Intermediate Section 5 500 4 NOV SKH516D PDC 6.5"8114 12229 4115 39.40 0.383 104.4 9 117 1243 234 2-2-CT-N-X-IN-NO-TD TD Production Section WELL NAME:2N-336 LOCATION: Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901987902 TD:23-Jan-2015 MI Swaco STATE:Alaska RIG:Nabors 9ES SPUD:29-Dec-2014 B i t R e c o r d . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 0' pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.057 C-5n 0' 0.0 C-2 0 in 0 0'Minimum Depth Time: spu check list nipple up diverter system. Test upper and lower seals on stating head install 4" annulus valves on conductor. 0 0' 0' 0' Max @ ft Current 0'0.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R.Dolcator / J. Riley ShClyst TuffGvlCoal cP 12 Footage Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A P/U Drill Pipe PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.30 000 Spud 10.00'18 Depth in / out Mud Type Lst Type Average N/A0Background (max)Trip 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 instal last diverter stick stab riser install 4" valve on conductor. Nipple up diverter tee take on mud to pits. Prep pipe shed. Load 30 joints 5" drill pipe in shed. Nipple up and down diverter system ConditionBit # 0.09.609.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2N-337C ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 2.96 @ Mud Data Depth 28-Dec-2014 24:00 Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 0.00 Rig up spot sub over well. Spot pits to sub spot cuttings tank diesel fuel tank. Berm all containments complete pre Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Nipple up diverter system build containment from start to the end of the diverter line. Pick up drill pipe PJSM pick up Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 540.00 0 29-Dec-2014 24:00 Current Pump & Flow Data: 9 Max ROP ROP (ft/hr) 2.96 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 0.00 Nabors 9ES Report For: ConditionBit # 1 7.0 13.5 9.70 Mill Tooth Smith 9.70 Size diverter over tundra. Pick up BHA PJSM make up dumb iron drill to 99' MD. Make up BHA drill from 99' MD to 251' MD to install final section of line. Circulate and condition test MP1 to 2900 psi move fluid in pits. Nipple up diverter system install last valve 9 sec to open knife valve 20 seconds to close annular. Nipple down diverter system secure diverter with chains and prepare 78' 100% Gas In Air=10,000 Units30Connection 0 Tools API FL Chromatograph (ppm) 0' WOB Conductor 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average N/A Mud Type Lst 100 Type Spud 20.0140'43 Depth in / out YP (lb/100ft2) 9.30 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A P/U BHA PV 251' Footage R.Dolcator / J. Riley ShClyst TuffGvlCoal cP 18 Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 205.0 Flow In (gpm) Flow In (spm) 0' 251' 251' Max @ ft Current 235'105.0 Date: Time: 60 joints of 5" drill pipe and rack it back in the derick. Pick up 17 joints of HWDP test diverter PJSM function test annular and knife 6 in 3 199'Minimum Depth C-5n 242' 0.0 C-2 30 SPP (psi) Gallons/stroke TFABit Type Depth 7.5153 MBT 251' pH 0 0 0 Siltst 0 0 Units* Casing Summary Lithology (%) 0873 35 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 62.6 Grade 16.00'' (max)(current) 0 0 Cly 4264 . . * 24 hr Recap:Drilled to 1274' MD. Circulated bottoms up, pumped a Hi-Vis sweep around and pull out to +/- 680' MD. Encounter Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 1500.00 0 30-Dec-2014 24:00 Current Pump & Flow Data: 9 Max ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 0.00 Nabors 9ES Report For: ConditionBit # 1 8.0 13.5 9.70 Mill Tooth Smith 9.70 Size 78' 100% Gas In Air=10,000 Units8086Connection 0 Tools API FL Chromatograph (ppm) 0' WOB Conductor 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 3Background (max)Trip Average N/A Mud Type Lst 90 Type Spud 20.01274'42 Depth in / out YP (lb/100ft2) 9.20 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 10 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 N/A N/A POOH PV 1273' Footage D.Mickey / J. Riley ShClyst TuffGvlCoal cP 18 Gas Summary 0 0 0 (current) Avg to251' Yesterday's Depth: Current Depth: 24 Hour Progress: 285.0 Flow In (gpm) Flow In (spm) 251' 1273' 1022' Max @ ft Current 583'47.0 Date: Time: increase drag. Back reamed while pumping the rest of the way out to +/- 250' MD. Wait on weather as conditions are now Phase 3 307 in 3 199'Minimum Depth C-5n 1228' 0.0 C-2 9637 SPP (psi) Gallons/stroke TFABit Type Depth 7.5151 MBT 1273' pH 0 0 0 Siltst 0 0 Units* Casing Summary Lithology (%) 036313 154 (907)659-7092Unit Phone: 0 J. Hansen Maximum Report By:Logging Engineers:J. Hansen / L. Wilson Set AtSize 62.6 Grade 16.00'' (max)(current) 0 0 Cly 291897 . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize 62.6 Grade 16.00'' (907)659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 1273' pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 7.5151 C-5n - 0.0 C-2 60 in 0 -Minimum Depth Time: 3 1273' 1273' 0' Max @ ft Current 0'0.0 Date: Avg to1273' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D.Mickey / J. Riley ShClyst TuffGvlCoal cP 18 1273' Footage 10 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 WOW PV 24 hr Max Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.20 000 Spud 20.01274'42 Depth in / out Mud Type Lst 90 Type Average N/A1Background (max) Trip 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 0' W OB Conductor 100% Gas In Air=10,000 UnitsN/AConnection 0 78' ConditionBit # 1 8.0 13.5 9.70 Mill Tooth Smith 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 0.00 Nabors 9ES Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 3.49 @ Mud Data Depth 31-Dec-2014 24:00 Current Pump & Flow Data: 10 Max 0 Chlorides mg/l 1500.00 Currently still out of the hole and waiting on the weather. Still in phase 3 conditions at time of report. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Tripped back into the hole to 1274' MD and continued drilling surface section after conditioning mud. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2800.00 0 1-Jan-2015 24:00 Current Pump & Flow Data: 712 Max ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 0.00 Nabors 9ES Report For: ConditionBit # 1 9.0 13.5 9.90 Mill Tooth Smith 9.80 Size 2 78' 100% Gas In Air=10,000 Units1006Connection 0 Tools API FL Chromatograph (ppm) 105' 251' W OB Conductor 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min 250Background (max) Trip Average N/A Mud Type Lst Type Mud Motor Spud 20.0 251' 1804'81 Depth in / out YP (lb/100ft2) 9.00 000 00 CementCht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 100 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Drilling Ahead PV 146' 13.5 0.994 Footage 1.50 D.Mickey / J. Riley ShClyst TuffGvlCoal cP 36 Gas Summary 0 0 0 (current) Avg to 251' Yesterday's Depth: Current Depth: 24 Hour Progress: 452.0 Flow In (gpm) Flow In (spm) 1273' 1803' 530' Max @ ft Current 1516'148.0 Date: Time: 385 in 0 -Minimum Depth C-5n 1299' 0.0 C-2 2202 SPP (psi) Gallons/stroke TFABit Type Depth 27.5225 MBT - pH 0.994 0 0 0 Siltst 394 113 Units* Casing Summary Lithology (%) 040494 0 (907)659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:J. Hansen / H. Garney Set AtSize 62.6 Grade 16.00'' (max)(current) 0 0 Cly 225119 . . * 24 hr Recap: (max)(current) 0 0 Cly 82985 Set AtSize 62.6 Grade 16.00'' (907)659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:L. Rasher / H. Garney 33035 414 600 172 Units* Casing Summary Lithology (%) 0 MBT - pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 37.0275 C-5n 1990' 0.0 C-2 860 in 4 2530'Minimum Depth Time: yet. Continued to drill ahead to 2,648' MD and circulated bottoms up and conditioned the hole. It was determined that the TD 315 1803' 2648' 845' Max @ ft Current 2269'107.0 Date: Avg to 251' Yesterday's Depth: Current Depth: 24 Hour Progress: 280.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D.Mickey / J. Riley ShClyst TuffGvlCoal cP 34 146' 13.5 0.994 Footage 1.50 70 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 TD Surface Section PV 24 hr Max Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 9.00 000 Mud Motor Spud 18.0 251' 2648'57 Depth in / out Mud Type Lst 30 Type Average N/A80Background (max) Trip 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 105' 251' W OB Conductor 100% Gas In Air=10,000 Units491Connection 0 2 for the surface section was reached. Currently back reaming out of the hole. 78' ConditionBit # 1 8.0 13.5 9.70 Mill Tooth Smith 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 0.00 Nabors 9ES Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 3.49 @ Mud Data Depth 2-Jan-2015 24:00 Current Pump & Flow Data: 1370 Max 0 Chlorides mg/l 2800.00 Drilled ahead to 2,606' MD and circulated bottoms up with the sample proving that the casing point was not reached Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: seen at the shakers. Lost some mud while the hole unloaded. Finished bach reaming out of the hole and began rigging up to run (current) Background Minimum 10-3/4" casing. Logging Engineers: Drilled to TD of 2648' MD and circulated bottoms up. Began to back ream out of the hole with a large influx of cuttings Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 0 3-Jan-2015 24:00 Current Pump & Flow Data: 0 Max 1-1-CT-M-E-1-NO-TD ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 0.00 Nabors 9ES Report For: ConditionBit # 1 9.0 13.5 9.70 Mill Tooth Smith 9.70 Size 2 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 20 105' 251' W OB Conductor 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min N/A (max) Trip Average 813 Mud Type Lst Type 60Mud Motor Spud 0.0 251' 2648'70 2648' Depth in / out YP (lb/100ft2) 9.00 000 00 CementCht Silt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Running 10-3/4" Casing PV 146' 13.5 0.994 Footage 14.70 2397' 1.50 D.Mickey / J. Riley ShClyst TuffGvlCoal cP 36 Gas Summary 0 0 0 (current) Avg to 251' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 2648' 2648' 0' Max @ ft Current -0.0 Date: Time: 41 in 0 - Depth C-5n - 0.0 C-2 813 SPP (psi) Gallons/stroke TFABit Type Depth 25.0325 MBT 2648' pH 0.994 0 0 0 Siltst 0 0 Units* Casing Summary Lithology (%) 04195 0 (907)659-7092Unit Phone: 0 H. Garney Maximum Report By:L. Rasher / H. Garney Set AtSize 62.6 Grade 16.00'' (max) 0 0 Cly 82258 . . * 24 hr Recap: Cly 77959 16.00'' (max) Surface 0 0 0 H. Garney Maximum Report By:L. Rasher / H. Garney 3395 0 10.75" 0 0 Units* Casing Summary Lithology (%) Set AtSize 62.6 0 0 0 Siltst 0 27.595 MBT 2648' pH 0.994 Grade 781 SPP (psi) Gallons/stroke TFABit Type Depth - Depth C-5n - 0.0 C-2 Time: 31 in 0 2648' 2648' 0' Max @ ft Current -0.0 Date: Avg to 251' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D.Mickey / J. Riley ShClyst TuffGvlCoal cP 28 13.5 0.994 Footage 14.70 2397' 1.50 Ss (ppb Eq) C-1 C-5i AK-AM-0901889899 Cemented Casing PV 24 hr Max 38.9 Weight 0 Hours C-3 00 CementCht Silt C-4i C-4n YP (lb/100ft2) 8.40 000 60Mud Motor Spud 0.0 251' 2648'27 2648' Depth in / out Mud Type Lst Type Average 781 (max) Trip 0.000.00 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gyro Pulse API FL Chromatograph (ppm) 20 105' 251' W OB Conductor 2 251' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Bit # 1 8.0 13.5 9.80 Mill Tooth Smith 9.80 Size 146' Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: 0.00 Nabors 9ES Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope ROP ROP (ft/hr) 3.49 @ Mud Data Depth Condition 4-Jan-2015 24:00 Current Pump & Flow Data: 0 Max 1-1-CT-M-E-1-NO-TD 0 mg/l 900.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides Logging Engineers:(907)659-7092Unit Phone: surface section then rigged down cement equipment. Currently cleaning pits and nippling up BOP stack. (current) Background Minimum Finished running 10-3/4" casing . Rigged down casing equipment and rigged up for cement job. Cemented the N/A . . * 24 hr Recap: (max)(current) Hydril 0 0 Cly 0 Set AtSize 62.6 H-40 Grade 16.00'' (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney 0 0 10.75" Units* Casing Summary Lithology (%) 0 L-80 MBT 2648' pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 27.597 C-5n - C-2 in -Minimum Depth Time: Install well head, clean seals and set well head. Prepare cellar and wellhead, test seals, install test plug & working valves. N/U 2648' 2648' 0' Max @ ft Current Date: Avg to2648' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) D.Mickey / J. Riley ShClyst TuffGvlCoal cP 29 1023' 13.5 0.994 Footage 14.70 1374' 7.90 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Test BOP PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 8.30 000 60 60.0 SLB XR+ Mill Tooth Spud 8.0 1274' 2648'26 2648' Depth in / out Mud Type Lst Type Average N/ABackground (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 20 15.0251' 1274' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 2RR BOP & prep for BOP test. Test BOPs. 2636' 78' Condition 0-0-NO-A-E-I-NO-WC Bit # 1RR 8.0 13.5SLB XR+ Mill Tooth 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope 1-1-CT-M-E-1-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 5-Jan-2015 24:00 Current Pump & Flow Data: Max 0 Chlorides mg/l 900.00 Nipple up/down diverter sys & clean out roataty table. Nipple up/down diverter sys & bring in tree to cellar & hang. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Complete BOP test. P/U 5" DP. Perform rig maintenance. Prep to P/U BHA #4. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 900.00 0 6-Jan-2015 24:00 Current Pump & Flow Data: Max 1-1-CT-M-E-1-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 0-0-NO-A-E-I-NO-WC Bit # 1RR 8.0 13.5SLB XR+ Mill Tooth 9.80 Size 2RR 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 20 15.0251' 1274' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max)Trip Average N/A Mud Type Lst Type 60 60.0 SLB XR+ Mill Tooth Spud 8.0 1274' 2648'28 2648' Depth in / out YP (lb/100ft2) 8.30 000 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-0901987902 $5,115 $53,410.00 Prep to P/U BHA #4 PV 1023' 13.5 0.994 Footage 14.70 1374' 7.90 D.Mickey / J. Riley ShClyst TuffGvlCoal cP 31 Gas Summary 0 0 0 (current) Avg to2648' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 2648' 2648' 0' Max @ ft Current Date: Time: in -Minimum Depth C-5n - C-2 SPP (psi) Gallons/stroke TFABit Type Depth 27.5105 L-80 MBT 2648' pH 0.994 0 0 0 Siltst 10.75" Units* Casing Summary Lithology (%) 00 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney Set AtSize 62.6 H-40 Grade 16.00'' (max)(current) Hydril 0 0 Cly 0 . . * 24 hr Recap:P/U BHA #4. RIH to 1512' MD & SHT MWD tools. Cont to RIH to 2423' MD. Cut & slip drill line. Service rig & circ and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 0 7-Jan-2015 24:00 Current Pump & Flow Data: 1249 Max Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 13.5SLB XR+ Mill Tooth Size 3 20% sltst. 2668' MD to 2710' MD. Max gas observed was 34u @ 2662' MD. Sample consisted of 50% lt gry-sft- amor cly & 30% uncons snd & 2668' MD. Circ & cond mud & perform FIT to 15.5 EMW. Service top drive. Displace mud to 9.6 ppg LSND. Begin to drill ahead f/ 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools X6.75 Power Drive, Ecoscope, TeleScope API FL Chromatograph (ppm) 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min 15Background (max)Trip Average N/A Mud Type Lst 40 Type 60 NOV SKH516D MT 2648' Depth in / out YP (lb/100ft2) 000 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 0 Hours C-3 40 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Drill 9-7/8" Section PV 1374' 9.875 0.994 Footage 14.70 J. Haynes / J. Riley ShClyst TuffGvlCoal cP Gas Summary 0 0 0 (current) Avg to2648' Yesterday's Depth: Current Depth: 24 Hour Progress: 125.1 Flow In (gpm) Flow In (spm) 2648' 2710' 62' Max @ ft Current 2682'87.8 Date: Time: cond mud until clean. Pressure test csg to 3000 psi. Ream/wash in hole f/ 2423' MD to 2545' MD. Drill out cmt & 20' of new hole to 15 in 4 2696'Minimum Depth C-5n 2662' 103.7 C-2 34 SPP (psi) Gallons/stroke TFABit Type Depth L-80 MBT 2710' pH 0.994 0 0 0 Siltst 10.75" 596 171 Units* Casing Summary Lithology (%) 01826 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney Set AtSize 62.6 H-40 Grade 16.00'' (max)(current) Hydril 0 0 Cly 5295 20 . . * 24 hr Recap:Cont drill ahead f/ 2710' MD to 4589' MD. Max gas observed was 212u @ 3074' MD. Samples have consisted of Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 4200.00 5 8-Jan-2015 24:00 Current Pump & Flow Data: 1525 Max Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 7.0 13.5 9.70 SLB XR+ Mill Tooth 9.60 Size 3 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 8 Tools X6.75 Power Drive, Ecoscope, TeleScope API FL Chromatograph (ppm) 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min 12Background (max) Trip Average N/A Mud Type Lst 30 Type 60 NOV SKH516D MT LSND 4.8 2648' 4460'22 Depth in / out YP (lb/100ft2) 9.80 000 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 50 Hours C-3 50 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Drill 9-7/8" Section PV 1374' 9.875 0.994 Footage 14.70 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 13 Gas Summary 0 5 15 (current) Avg to2710' Yesterday's Depth: Current Depth: 24 Hour Progress: 273.3 Flow In (gpm) Flow In (spm) 2710' 4589' 1879' Max @ ft Current 3669'145.5 Date: Time: mainly lt gry-brn cly & sltst with an interval of mainly sst w/ 10%-30% cly & sltst f/ 3500' MD to 4100' MD. 50 in 0 2710'Minimum Depth C-5n 3074' 99.6 C-2 212 SPP (psi) Gallons/stroke TFABit Type Depth 12.547 L-80 MBT 4589' pH 0.994 0 5 0 Siltst 10.75" 569 165 Units* Casing Summary Lithology (%) 06707 67 (907)659-7092Unit Phone: 15 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney Set AtSize 62.6 H-40 Grade 16.00'' (max)(current) Hydril 113 0 Cly 24244 20 . . * 24 hr Recap: (max)(current) Hydril 129 0 Cly 12856 70 Set AtSize 62.6 H-40 Grade 16.00'' (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney 5802 42 10.75" 492 141 Units* Casing Summary Lithology (%) 3 L-80 MBT 5625' pH 0.994 0 5 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 20.048 C-5n 5367' C-2 97 in 0 5139'Minimum Depth Time: Samples have consisted of mainly brn-med gry, sft-frm sltst w/ abd cly & 10%-30% sst. 51 4589' 5625' 1036' Max @ ft Current 5108'145.5 Date: Avg to4589' Yesterday's Depth: Current Depth: 24 Hour Progress: 258.2 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) J. Haynes / J. Riley ShClyst TuffGvlCoal cP 15 1374' 9.875 0.994 Footage 14.70 30 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Short Trip PV 24 hr Max 45.5 Weight 82 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 000 60 NOV SKH516D MT LSND 4.8 2648' 5625'20 Depth in / out Mud Type Lst Type Average N/A33Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools X6.75 Power Drive, Ecoscope, TeleScope API FL Chromatograph (ppm) 201274' 2648' WOB 100% Gas In Air=10,000 UnitsN/AConnection 18 3 2636' 78' Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 7.0 13.5SLB XR+ Mill Tooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 9-Jan-2015 24:00 Current Pump & Flow Data: 1068 Max 12 Chlorides mg/l 4000.00 Drill ahead f/ 4589' MD to 5625' MD. Short trip to csg shoe & circ. Max gas observed was 97u @ 5367' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Circ @ shoe & RIH to 5625' MD. Cont to drill ahead through intermediate section f/ 5625' MD to 6220' MD. Max gas Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 3400.00 70 10-Jan-2015 24:00 Current Pump & Flow Data: 2311 Max Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 7.0 13.5SLB XR+ Mill Tooth 9.60 Size 3 & cly & clr-trnsl-mky wh, vf-f gr, uncons sst from/ 6000' MD to 6200' MD. 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 51 Tools X6.75 Power Drive, Ecoscope, TeleScope API FL Chromatograph (ppm) 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min 47Background (max)Trip Average 252 Mud Type Lst 40 Type 60 NOV SKH516D MT LSND 4.5 2648' 6150'20 Depth in / out YP (lb/100ft2) 9.70 0110 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 228 Hours C-3 60 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Drilling 10-3/4" Hole PV 1374' 9.875 0.994 Footage 14.70 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 13 Gas Summary 0 7 0 (current) Avg to5625' Yesterday's Depth: Current Depth: 24 Hour Progress: 175.1 Flow In (gpm) Flow In (spm) 5625' 6220' 595' Max @ ft Current 5909'66.9 Date: Time: observed was 115u @ 5843' MD and 252u while RIH. Samples have consisted of predominately cly & sltst f/ 5625' MD to 6000' MD 60 in 4 6177'Minimum Depth C-5n 5843' 38.9 C-2 115 SPP (psi) Gallons/stroke TFABit Type Depth 12.546 L-80 MBT 6220' pH 0.994 0 11 0 Siltst 10.75" 680 195 Units* Casing Summary Lithology (%) 156253 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney Set AtSize 62.6 H-40 Grade 16.00'' (max)(current) Hydril 347 0 Cly 13989 . . * 24 hr Recap: (max)(current) Hydril 5073 0 Cly 125289 70 Set AtSize 62.6 H-40 Grade 16.00'' (907)659-7092Unit Phone: 96 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney 15028 90 10.75" 659 189 Units* Casing Summary Lithology (%) 16 L-80 MBT 7927' pH 0.994 0 198 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 15.046 C-5n 6578' 83.2 C-2 1494 in 4 6379'Minimum Depth Time: mainly trnsl-clr-wh, vf-f gr sst w/ intervals of gry-br stlst & cly. 110 6220' 7927' 1707' Max @ ft Current 7416'137.1 Date: Avg to6220' Yesterday's Depth: Current Depth: 24 Hour Progress: 377.4 Flow In (gpm) Flow In (spm) Gas Summary 0 409 92 (current) J. Haynes / J. Riley ShClyst TuffGvlCoal cP 12 1374' 9.875 0.994 Footage 14.70 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Drilling 10-3/4" Hole PV 24 hr Max 45.5 Weight 523 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 0340 60 NOV SKH516D MT LSND 4.2 2648' 7810'20 Depth in / out Mud Type Lst 30 Type Average 51Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools X6.75 Power Drive, Ecoscope, TeleScope API FL Chromatograph (ppm) 201274' 2648' WOB 100% Gas In Air=10,000 UnitsN/AConnection 1766 3 2636' 78' Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 7.0 13.5SLB XR+ Mill Tooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 11-Jan-2015 24:00 Current Pump & Flow Data: 2327 Max 156 Chlorides mg/l 2600.00 Cont to drill ahead f/ 6220' MD to 7927' MD. Max gas observed was 1494u @ 6578' MD. Samples have consisted of Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 7927' MD to intermediate TD of 8114' MD. Pump sweep & begin to BROOH. The max gas observed Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2400.00 208 12-Jan-2015 24:00 Current Pump & Flow Data: 1341 Max Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size 3 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 350 Tools X6.75 Power Drive, Ecoscope, TeleScope API FL Chromatograph (ppm) 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min 42Background (max)Trip Average 247 Mud Type Lst 10 Type 60 NOV SKH516D MT LSND 4.2 2648' 8114'20 Depth in / out YP (lb/100ft2) 9.50 227623 00 CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 365 Hours C-3 60 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 BROOH PV 1374' 9.875 0.994 Footage 14.70 J. Haynes / J. Riley ShClyst TuffGvlCoal cP 10 Gas Summary 0 124 31 (current) Avg to7927' Yesterday's Depth: Current Depth: 24 Hour Progress: 111.3 Flow In (gpm) Flow In (spm) 7927' 8114' 187' Max @ ft Current 7985'85.8 Date: Time: was 175u @ 7957' MD & 247u while BROOH. Samples consisted mainly of 60%-80% sltst w/ some sst & cly. 91 in 4 7945'Minimum Depth C-5n 7957' C-2 175 SPP (psi) Gallons/stroke TFABit Type Depth 17.545 L-80 MBT 8114' pH 0.994 0 64 0 Siltst 10.75" 558 160 Units* Casing Summary Lithology (%) 409278 112 (907)659-7092Unit Phone: 31 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / H. Garney Set AtSize 62.6 H-40 Grade 16.00'' (max)(current) Hydril 628 5 Cly 17843 30 . . * 24 hr Recap: (max)(current) Hydril 0 0 Cly 0 Set AtSize 62.6 H-40 Grade 16.00'' 7-5/8" (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen 0 0 10.75" Units* Casing Summary Lithology (%) 0 L-80 MBT pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.548 C-5nC-2 in Minimum Depth Time: was 23u while POOH. 8114' 8114' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 13 1374' 9.875 0.994 Footage 53.00 5466' 14.70 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 L/D 5" DP PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 000 1500 60 NOV SKH516D PDC LSND 4.2 2648' 8114'20 8114' Depth in / out Mud Type Lst Type Average 23Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 3 2636' 78' Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 17 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 13-Jan-2015 24:00 Current Pump & Flow Data: Max 0 Chlorides mg/l 2400.00 Circ hole clean at shoe. Cont to POOH & fish for dropped hammer. L/D BHA #4. L/D 5" DP. The max gas observed Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont POOH & L/D DP. R/U & test BOPs. R/U & RIH w/ 7-5/8" csg. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2400.00 0 14-Jan-2015 24:00 Current Pump & Flow Data: Max 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 18 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size 3 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Type 1500 60 NOV SKH516D PDC LSND 4.3 2648' 8114'21 8114' Depth in / out YP (lb/100ft2) 9.50 000 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-0901987902 RIH 7-5/8" Csg PV 1374' 9.875 0.994 Footage 53.00 5466' 14.70 R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 11 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 8114' 8114' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 17.545 L-80 MBT pH 0.994 0 0 0 Siltst 10.75" Units* Casing Summary Lithology (%) 00 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen Set AtSize 62.6 H-40 Grade 16.00'' 7-5/8" (max)(current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max)(current) Hydril 0 0 Cly 0 Set AtSize 62.6 H-40 Grade 16.00'' 7-5/8" (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen 0 0 10.75" Units* Casing Summary Lithology (%) 0 L-80 MBT pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.545 C-5nC-2 in Minimum Depth Time: circ. 8114' 8114' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 11 1374' 9.875 0.994 Footage 53.00 5466' 14.70 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 RIH 7-5/8" Csg PV 24 hr Max 45.5 Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.20 000 1500 60 NOV SKH516D PDC LSND 4.2 2648' 8114'16 8114' Depth in / out Mud Type Lst Type Average 41Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 3 2636' 78' Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 15-Jan-2015 24:00 Current Pump & Flow Data: Max 0 Chlorides mg/l 2400.00 Cont to RIH w/ 7-5/8" csg. Circ & cond mud @ 4551' MD to get 9.7 MW in & out. Max gas observed was 41u while Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Circ & cond mud @ 6565' MD. RIH w/ 7-5/8" csg. Circ & cond mud to keep 9.7 MW in/out. M/U landing jt & hanger. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2400.00 0 16-Jan-2015 24:00 Current Pump & Flow Data: Max 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size 3 wait on cmt. Max gas seen was 311u while RIH w/ csg. 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average 311 Mud Type Lst Type 1500 60 NOV SKH516D PDC LSND 4.2 2648' 8114'17 8114' Depth in / out YP (lb/100ft2) 9.20 000 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-0901987902 L/D Cmt Equip PV 1374' 9.875 0.994 Footage 53.00 5466' 14.70 R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 10 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 8114' 8114' 0' Max @ ft Current Date: Time: Circ & cond mud for cmt job. Pump cmt, floats didn’t hold. R/U and hold pressure and pressured up to 1150psi. Monitor and in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 17.546 L-80 MBT pH 0.994 0 0 0 Siltst 10.75" Units* Casing Summary Lithology (%) 00 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen Set AtSize 62.6 H-40 Grade 16.00'' 7-5/8" (max)(current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max)(current) Hydril 0 0 Cly 0 Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen 0 0 10.75" Units* Casing Summary Lithology (%) 0 L-80 MBT pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.545 C-5nC-2 in Minimum Depth Time: Load 4" DP into shed & P/U 4" DP. Clean pits. 8114' 8114' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 0 0 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 9 1374' 9.875 0.994 Footage 53.00 5466' 14.70 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 P/U 4" DP PV 24 hr Max 45.5 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.20 000 1500 60 NOV SKH516D PDC LSND 4.2 2648' 8114'18 8114' Depth in / out Mud Type Lst Hydril 563 Type Average Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 3 2636' 78' Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 17-Jan-2015 24:00 Current Pump & Flow Data: Max 0 Chlorides mg/l 2400.00 C/O rams. L/D 5" DP. Install test plug & flood BOP w/ water. Test top rams to 3500 psi and annular to 2500 psi. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Cont P/U 4" DP. Freeze protect well. Test BOPs. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2400.00 0 18-Jan-2015 24:00 Current Pump & Flow Data: Max 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 22 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size 3 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min Background (max) Trip Average Mud Type Lst Hydril 563 Type 1500 60 NOV SKH516D PDC LSND 4.3 2648' 8114'17 8114' Depth in / out YP (lb/100ft2) 9.10 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Test BOPs PV 1374' 9.875 0.994 Footage 53.00 5466' 14.70 R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 9 29.7 Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 8114' 8114' 0' Max @ ft Current Date: Time: in Minimum Depth C-5nC-2 SPP (psi) Gallons/stroke TFABit Type Depth 17.545 L-80 MBT pH 0.994 0 0 0 Siltst 10.75" Units* Casing Summary Lithology (%) 00 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (max)(current) Hydril 0 0 Cly 0 . . * 24 hr Recap: (max)(current) Hydril 0 0 Cly 0 Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen 0 0 10.75" Units* Casing Summary Lithology (%) 0 L-80 MBT pH 0.994 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 17.546 C-5nC-2 in Minimum Depth Time: to 4515' MD and turn on sonic tool for logging. Cont to TIH. 8114' 8114' 0' Max @ ft Current Date: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 0 0 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 9 1374' 9.875 0.994 Footage 53.00 5466' 14.70 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 RIH w/ BHA #5 PV 24 hr Max 45.5 Weight 0 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.10 000 1500 60 NOV SKH516D PDC LSND 4.3 2648' 8114'17 8114' Depth in / out Mud Type Lst Hydril 563 Type Average Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 15 201274' 2648' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 3 2636' 78' Condition 1-1-CT-M-E-1-NO-TD Bit # 2RR 8.0 13.5SLB XR+ Mill Tooth 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope 1-1-WT-A-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 19-Jan-2015 24:00 Current Pump & Flow Data: Max 0 Chlorides mg/l 2400.00 Cont test BOPs. R/D test equip. P/U BHA #5 & P/U DP to 1469' MD & SHT MWD tools. P/U DP to 4232' MD. TIH Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:TIH & fill pipe every 2000'. Ream/wash f/ 7849' MD to 7983' MD & tag cmt. Circ & cond mud. Pressure test csg to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 2400.00 4 20-Jan-2015 24:00 Current Pump & Flow Data: 0 Max Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-WT-A-X-IN-NO-TD Bit # 3 8.0 9.875NOV SKH516D PDC 9.70 Size 4 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools 475 PDX6, Periscope, Impulse, SonicScope, adnVision API FL Chromatograph (ppm) 152648' 8114' WOB Avg Min Comments Surface RPM ECD (ppg) ml/30min 3Background (max) Trip Average Mud Type Lst Hydril 563 Type 1500 NOV SKH513M-A1C PDC LSND 4.3 8114' 8114'17 Depth in / out YP (lb/100ft2) 9.10 000 00 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Prep to displace mud PV 5466' 6.5 0.383 Footage 53.00 R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 9 29.7 Gas Summary 0 0 0 (current) Avg to8114' Yesterday's Depth: Current Depth: 24 Hour Progress: 98.8 Flow In (gpm) Flow In (spm) 8114' 8139' 25' Max @ ft Current 8115'45.6 Date: Time: 3000 psi for 30 min. Cut & slip drill line & service rig. Drill f/ 7983' MD to 8139' MD. Perform FIT to 15.9 ppg. Prep to displace mud. 5 in 3 8114'Minimum Depth C-5n 8134' 0.0 C-2 20 SPP (psi) Gallons/stroke TFABit Type Depth 17.546 L-80 MBT 8139' pH 0.994 0 0 0 Siltst 10.75" 0 0 Units* Casing Summary Lithology (%) 048 0 (907)659-7092Unit Phone: 0 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (max)(current) Hydril 0 0 Cly 2201 . . * 24 hr Recap: (max)(current) Hydril 13488 1793 Cly 151191 Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (907)659-7092Unit Phone: 1498 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen 70 22893 0 10.75" 283 81 Units* Casing Summary Lithology (%) 378 L-80 MBT 9232' pH 0.994 0 1681 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.543 C-5n 9161' 70.9 C-2 2488 in 0 8799'Minimum Depth Time: Samples have consisted of 65%-90% lt brn-lt gry sltst w/ 10%-35% sst. 395 8139' 9232' 1093' Max @ ft Current 9088'96.7 Date: Avg to8139' Yesterday's Depth: Current Depth: 24 Hour Progress: 328.0 Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 5337 1091 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 11 5466' 6.5 0.383 Footage 53.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Drilling 6.5" Hole PV 24 hr Max 45.5 Weight 2409 Hours C-3 0515 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 10.00 4211281297 1500 NOV SKH513M-A1C PDC Kla-shield 3.7 8114' 9085'18 Depth in / out Mud Type Lst 30 Hydril 563 Type Average 223Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools 475 PDX6, Periscope, Impulse, SonicScope, adnVision API FL Chromatograph (ppm) 152648' 8114' WOB Welded 100% Gas In Air=10,000 UnitsN/AConnection 12719 4 2636' 78' Condition 1-1-WT-A-X-IN-NO-TD Bit # 3 8.0 9.875 9.80 NOV SKH516D PDC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 21-Jan-2015 24:00 Current Pump & Flow Data: 1961 Max 2508 Chlorides mg/l 43000.00 Displace mud to 9.8 ppg Klashield. Drill ahead f/ 8139' MD to 9232' MD. Max gas observed was 2488u @ 9161' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drill ahead f/ 9232' MD to 11082' MD. Max gas observed was 6161u @ 9850' MD. Samples have consisted of mainly Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 62000.00 8604 22-Jan-2015 24:00 Current Pump & Flow Data: 1884 Max Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-WT-A-X-IN-NO-TD Bit # 3 8.5 9.875 9.90 NOV SKH516D PDC 9.90 Size 4 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 21429 Tools 475 PDX6, Periscope, Impulse, SonicScope, adnVision API FL Chromatograph (ppm) 152648' 8114' WOB Welded Avg Min Comments Surface RPM ECD (ppg) ml/30min 405Background (max) Trip Average Mud Type Lst 90 Hydril 563 Type 1500 NOV SKH513M-A1C PDC Kla-shield 3.4 8114' 10845'20 Depth in / out YP (lb/100ft2) 9.80 139843111006 1324 Intermediate CementChtSilt C-4i C-4n 24 hr Max 45.5 Weight 7839 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 Drilling 6.5" Hole PV 5466' 6.5 0.383 Footage 53.00 R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 13 29.7 Gas Summary 0 8721 1775 (current) Avg to9232' Yesterday's Depth: Current Depth: 24 Hour Progress: 333.3 Flow In (gpm) Flow In (spm) 9232' 11082' 1850' Max @ ft Current 10509'146.0 Date: Time: sd w/ sst frag and sltst. 1588 in 0 10706'Minimum Depth C-5n 9850' 114.9 C-2 6161 SPP (psi) Gallons/stroke TFABit Type Depth 3.843 L-80 MBT 11082' pH 0.994 22 2893 5 Siltst 10.75" 255 73 Units* Casing Summary Lithology (%) 1386 10 102777 96 (907)659-7092Unit Phone: 2371 L. Rasher Maximum Report By:Logging Engineers:L. Rasher / J. Hansen Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (max)(current) Hydril 23848 0 Cly 326990 . . * 24 hr Recap: (max)(current) Hydril 13089 0 Cly 193448 Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (907)659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:H. Garney / J. Hansen 30 53693 41 10.75" 269 77 Units* Casing Summary Lithology (%) 939 L-80 MBT 12230' pH 0.994 0 2402 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.843 C-5n 10987' - C-2 2840 in 4 11827'Minimum Depth Time: and drilled ahead to TD of 12229' MD. Washed and reamed to 11849' MD. Circulated and conditioned the hole to 11658' MD. 684 11082' 12230' 1148' Max @ ft Current 12134'139.0 Date: Avg to11082' Yesterday's Depth: Current Depth: 24 Hour Progress: 343.0 Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 7250 1032 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 11 5466' 6.5 0.383 Footage 53.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 TD Production Hole PV 24 hr Max 45.5 Weight 3658 Hours C-3 00 Intermediate CementChtSilt C-4i C-4n YP (lb/100ft2) 9.90 10522828759 1500 NOV SKH513M-A1C PDC Kla-shield 3.9 8114' 122230'18 Depth in / out Mud Type Lst 70 Hydril 563 Type Average 18081Background (max)Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools 475 PDX6, Periscope, Impulse, SonicScope, adnVision API FL Chromatograph (ppm) 152648' 8114' WOB Welded 100% Gas In Air=10,000 UnitsN/AConnection 14620 4 Dumped and diluted the mud system then monitored the well for 10 mins, static. 2636' 78' Condition 1-1-WT-A-X-IN-NO-TD Bit # 3 8.5 9.875 9.80 NOV SKH516D PDC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 23-Jan-2015 24:00 Current Pump & Flow Data: 1924 Max 4476 Chlorides mg/l 66000.00 Drilled ahead from 11085' MD to 11847' MD then washed and reamed the hole. Picked up 12 joints of drill pipe Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Backreamed out of the hole to the shoe then circulated bottoms up after flow checking the well. Then pulled out of Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 60000.00 148 24-Jan-2015 24:00 Current Pump & Flow Data: - Max 2-2-CT-N-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth Morning Report Report # 28 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Condition 1-1-WT-A-X-IN-NO-TD Bit # 3 8.5 9.875 9.80 NOV SKH516D PDC 9.80 Size 4 2636' 78' 100% Gas In Air=10,000 UnitsN/AConnection 472 Tools 475 PDX6, Periscope, Impulse, SonicScope, adnVision API FL Chromatograph (ppm) 9 152648' 8114' WOB Welded Avg Min Comments Surface RPM ECD (ppg) ml/30min 0Background (max) Trip Average 117 Mud Type Lst Hydril 563 Type 117 1500 NOV SKH513M-A1C PDC Kla-shield 3.4 8114' 12229'17 12229' Depth in / out YP (lb/100ft2) 10.00 01540 00 Intermediate CementCht Silt C-4i C-4n 24 hr Max 45.5 Weight 101 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 TOH, L/D BHA PV 5466' 6.5 0.383 Footage 130.00 4115' 53.00 R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 10 29.7 Gas Summary 0 366 118 (current) Avg to12230' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 12230' 12230' 0' Max @ ft Current -- Date: Time: Pulled out on elevators and laid down BHA. 19 in 0 -Minimum Depth C-5n - - C-2 117 SPP (psi) Gallons/stroke TFABit Type Depth 5.043 L-80 MBT 12230' pH 0.994 0 114 0 Siltst 10.75" - - Units* Casing Summary Lithology (%) 461869 0 (907)659-7092Unit Phone: 0 H. Garney Maximum Report By:Logging Engineers:H. Garney / J. Hansen Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (max)(current) Hydril 288 0 Cly 2022 . . * 24 hr Recap: (max)(current) Hydril 64 0 Cly 1286 Set AtSize 62.6 H-40 Grade L-808104' 16.00'' 7-5/8" (907)659-7092Unit Phone: 38 H. Garney Maximum Report By:Logging Engineers:H. Garney / J. Hansen 34 0 10.75" - - Units* Casing Summary Lithology (%) 2 L-80 MBT 12230' pH 0.994 0 27 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 5.043 C-5n - - C-2 23 in 0 -Minimum Depth Time: the hole. Made up the hanger assembly. Circulated and conditioned then continued to trip into the hole to 8079' MD and 3 12230' 12230' 0' Max @ ft Current -- Date: Avg to12230' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.7 Gas Summary 0 96 0 (current) R. Dolcater/ D. Mickey ShClyst TuffGvlCoal cP 10 5466' 6.5 0.383 Footage 130.00 4115' 53.00 Ss (ppb Eq) C-1 C-5i AK-AM-0901987902 RIH w/ 4.5" Liner PV 24 hr Max 45.5 Weight 1 Hours C-3 00 Intermediate CementCht Silt C-4i C-4n YP (lb/100ft2) 10.00 390 117 1500 NOV SKH513M-A1C PDC Kla-shield 3.4 8114' 12229'15 12229' Depth in / out Mud Type Lst Hydril 563 Type Average 00Background (max) Trip Avg Min Comments Surface RPM ECD (ppg) ml/30min Tools 475 PDX6, Periscope, Impulse, SonicScope, adnVision API FL Chromatograph (ppm) 9 152648' 8114' WOB Welded 100% Gas In Air=10,000 UnitsN/AConnection 90 4 circulated 2 bottoms up then continued to trip in the hole. 2636' 78' Condition 1-1-WT-A-X-IN-NO-TD Bit # 3 8.5 9.875 9.80 NOV SKH516D PDC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: Nabors 9ES Report For: Morning Report Report # 29 Customer: Well: Area: Location: Rig: 2N-336 ConocoPhillips Alaska Inc. Tarn Kuparuk - North Slope 2-2-CT-N-X-IN-NO-TD Conductor ROP ROP (ft/hr) 3.49 @ Mud Data Depth 25-Jan-2015 24:00 Current Pump & Flow Data: - Max 5 Chlorides mg/l 60000.00 Began running 4.5" completion liner from surface to 3181' MD. Monitored well on the trip tank while running into Density (ppg) out (sec/qt) Viscosity Cor Solids % WELL INFORMATION Created On : Feb 19 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2N-336 Job Number :AK-XX-0901987902 Rig Name :Nabors 9ES Field Name :Tarn 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 0.00 200.00 0.00 0.00 N 0.00 E 0.00 0.00 80.31 0.33 166.71 80.31 0.23 S 0.05 E 0.15 0.41 173.39 0.24 134.35 173.39 0.62 S 0.25 E 0.34 0.19 261.23 0.18 138.40 261.23 0.85 S 0.48 E 0.39 0.07 351.09 0.25 185.99 351.09 1.15 S 0.55 E 0.59 0.21 441.78 0.26 208.74 441.78 1.53 S 0.43 E 0.96 0.11 533.29 1.00 204.42 533.28 2.44 S 0.00 E 1.95 0.81 628.11 2.72 203.30 628.05 5.26 S 1.23 W 4.94 1.81 718.13 3.91 206.81 717.91 9.96 S 3.46 W 10.04 1.34 812.72 5.27 220.58 812.20 16.14 S 7.74 W 17.55 1.84 872.05 6.10 223.21 871.24 20.51 S 11.67 W 23.40 1.47 965.77 7.39 230.23 964.31 27.99 S 19.71 W 34.22 1.63 1059.87 8.90 241.10 1,057.46 35.38 S 30.74 W 46.76 2.29 1154.76 9.89 247.51 1,151.08 42.05 S 44.70 W 60.48 1.52 1249.86 11.75 248.86 1,244.49 48.66 S 61.27 W 75.74 1.97 1344.22 17.65 253.28 1,335.72 56.25 S 83.96 W 95.45 6.36 1437.50 22.54 256.24 1,423.30 64.58 S 114.89 W 120.71 5.35 1529.91 24.01 255.72 1,508.19 73.43 S 150.31 W 149.10 1.61 1625.50 26.71 254.08 1,594.56 84.12 S 189.82 W 181.42 2.92 1718.78 33.38 254.74 1,675.26 96.64 S 234.79 W 218.48 7.16 1813.70 34.57 255.42 1,753.97 110.29 S 286.05 W 260.23 1.32 1908.78 39.03 255.46 1,830.09 124.60 S 341.16 W 304.83 4.69 2002.11 42.44 253.95 1,900.80 140.69 S 399.88 W 353.02 3.80 2098.09 45.92 252.31 1,969.62 160.13 S 463.87 W 407.05 3.82 2192.03 50.14 252.52 2,032.43 181.22 S 530.44 W 463.96 4.50 2285.42 52.55 254.15 2,090.76 202.12 S 600.30 W 522.69 2.92 2379.89 56.13 257.10 2,145.83 221.12 S 674.64 W 582.61 4.56 2473.67 56.91 259.25 2,197.57 237.14 S 751.19 W 641.47 2.09 2565.72 55.83 258.30 2,248.55 252.06 S 826.37 W 698.63 1.45 2637.50 55.45 258.00 2,289.06 264.23 S 884.36 W 743.24 0.63 INSITE V8.1.10 Page 1Job No:AK-XX-0901987902 Well Name:2N-336 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2726.85 56.36 259.50 2,339.15 278.66 S 956.93 W 798.44 1.72 2820.74 56.31 258.42 2,391.20 293.62 S 1,033.62 W 856.55 0.96 2915.51 56.42 257.35 2,443.69 310.18 S 1,110.77 W 916.20 0.95 3009.72 56.38 257.65 2,495.83 327.16 S 1,187.38 W 975.87 0.27 3104.04 56.35 257.81 2,548.07 343.85 S 1,264.11 W 1035.38 0.14 3198.87 56.39 258.01 2,600.59 360.39 S 1,341.32 W 1095.05 0.18 3291.90 56.39 257.68 2,652.09 376.70 S 1,417.06 W 1153.66 0.30 3387.09 56.44 257.36 2,704.74 393.84 S 1,494.49 W 1213.94 0.28 3479.92 56.46 258.28 2,756.05 410.16 S 1,570.11 W 1272.49 0.83 3573.89 56.44 258.55 2,807.98 425.89 S 1,646.83 W 1331.22 0.24 3667.93 56.43 258.73 2,859.98 441.33 S 1,723.65 W 1389.78 0.16 3763.73 56.21 257.57 2,913.10 457.69 S 1,801.67 W 1449.80 1.03 3950.82 56.52 257.43 3,016.73 491.41 S 1,953.75 W 1568.25 0.18 4044.76 57.48 256.30 3,067.90 509.32 S 2,030.47 W 1628.72 1.44 4138.88 58.53 257.26 3,117.77 527.57 S 2,108.17 W 1690.06 1.41 4234.59 59.39 257.77 3,167.12 545.29 S 2,188.24 W 1752.40 1.01 4329.71 59.35 256.40 3,215.58 563.59 S 2,268.01 W 1815.02 1.24 4422.25 59.42 257.28 3,262.71 581.72 S 2,345.56 W 1876.17 0.82 4518.36 59.53 257.76 3,311.53 599.61 S 2,426.39 W 1939.11 0.45 4613.71 59.40 258.10 3,359.97 616.78 S 2,506.70 W 2001.15 0.34 4705.90 59.79 256.96 3,406.63 633.95 S 2,584.34 W 2061.59 1.15 4802.60 59.81 257.18 3,455.27 652.65 S 2,665.79 W 2125.54 0.20 4891.99 59.79 257.07 3,500.24 669.87 S 2,741.11 W 2184.62 0.11 4987.21 59.90 257.32 3,548.07 688.12 S 2,821.39 W 2247.51 0.25 5080.96 59.85 256.32 3,595.12 706.60 S 2,900.34 W 2309.79 0.92 5174.37 59.78 256.96 3,642.09 725.26 S 2,978.90 W 2371.97 0.60 5269.15 59.93 257.60 3,689.69 743.31 S 3,058.85 W 2434.49 0.61 5363.31 60.05 257.79 3,736.78 760.68 S 3,138.52 W 2496.31 0.22 5457.07 59.93 257.94 3,783.68 777.75 S 3,217.89 W 2557.71 0.19 5552.09 60.06 259.91 3,831.20 793.56 S 3,298.64 W 2618.93 1.80 5644.80 60.38 260.21 3,877.24 807.45 S 3,377.90 W 2677.72 0.44 5740.44 60.18 261.13 3,924.66 820.91 S 3,459.86 W 2737.80 0.86 5833.98 60.05 261.44 3,971.27 833.20 S 3,540.02 W 2795.86 0.32 5926.92 59.98 260.56 4,017.71 845.79 S 3,619.53 W 2853.77 0.82 6021.59 60.36 259.72 4,064.81 859.86 S 3,700.44 W 2913.69 0.87 6116.59 60.79 259.78 4,111.48 874.58 S 3,781.87 W 2974.45 0.46 6210.34 59.73 258.78 4,157.98 889.72 S 3,861.85 W 3034.68 1.46 6304.83 59.67 253.59 4,205.68 909.19 S 3,941.03 W 3097.88 4.74 6399.48 60.04 246.84 4,253.26 936.88 S 4,017.97 W 3166.30 6.18 6493.63 60.03 242.78 4,300.30 971.58 S 4,091.76 W 3238.42 3.74 6587.16 60.51 241.11 4,346.68 1,009.78 S 4,163.43 W 3312.06 1.63 6682.10 60.72 239.99 4,393.27 1,050.46 S 4,235.46 W 3387.90 1.05 6776.16 60.66 238.48 4,439.31 1,092.41 S 4,305.94 W 3463.81 1.40 6869.75 60.20 236.96 4,485.50 1,135.88 S 4,374.75 W 3539.94 1.50 6965.04 59.57 235.86 4,533.31 1,181.48 S 4,443.42 W 3617.68 1.20 INSITE V8.1.10 Page 2Job No:AK-XX-0901987902 Well Name:2N-336 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7058.52 58.63 233.30 4,581.32 1,227.95 S 4,508.78 W 3694.13 2.56 7153.20 58.83 228.13 4,630.49 1,279.17 S 4,571.38 W 3772.71 4.67 7247.98 59.70 222.10 4,678.97 1,336.63 S 4,629.05 W 3853.31 5.54 7341.72 61.68 216.72 4,724.88 1,399.77 S 4,680.88 W 3934.93 5.43 7436.76 63.56 211.71 4,768.61 1,469.54 S 4,728.29 W 4019.18 5.08 7530.50 64.42 208.96 4,809.72 1,542.24 S 4,770.82 W 4102.84 2.79 7625.30 65.86 206.80 4,849.58 1,618.27 S 4,811.03 W 4187.76 2.57 7719.61 66.90 203.37 4,887.37 1,696.52 S 4,847.65 W 4272.29 3.51 7812.55 67.68 198.96 4,923.27 1,776.45 S 4,878.59 W 4354.74 4.46 7907.39 67.79 196.05 4,959.21 1,860.14 S 4,904.98 W 4437.47 2.84 8001.24 67.94 194.05 4,994.57 1,944.09 S 4,927.55 W 4518.09 1.98 8042.34 68.11 192.82 5,009.95 1,981.16 S 4,936.41 W 4553.03 2.81 8138.33 68.97 190.00 5,045.08 2,068.72 S 4,954.07 W 4633.58 2.88 8167.47 68.94 188.56 5,055.54 2,095.56 S 4,958.46 W 4657.66 4.61 8261.77 69.37 186.97 5,089.10 2,182.87 S 4,970.36 W 4734.56 1.64 8356.85 70.11 183.51 5,122.03 2,271.68 S 4,978.50 W 4810.38 3.50 8454.39 71.85 179.46 5,153.83 2,363.84 S 4,980.87 W 4885.41 4.31 8548.51 73.68 178.28 5,181.72 2,453.71 S 4,979.10 W 4956.11 2.28 8642.56 75.96 178.10 5,206.34 2,544.42 S 4,976.23 W 5026.84 2.43 8738.21 77.94 177.38 5,227.94 2,637.53 S 4,972.55 W 5098.98 2.20 8833.71 78.14 176.41 5,247.73 2,730.82 S 4,967.49 W 5170.44 1.02 8928.04 79.07 174.59 5,266.37 2,823.00 S 4,960.23 W 5239.69 2.13 9024.95 82.00 172.59 5,282.31 2,917.97 S 4,949.56 W 5309.11 3.64 9118.81 84.53 170.55 5,293.31 3,010.16 S 4,935.89 W 5374.52 3.45 9215.22 86.63 168.27 5,300.75 3,104.64 S 4,918.22 W 5439.33 3.21 9311.62 87.95 168.52 5,305.30 3,198.96 S 4,898.85 W 5503.01 1.39 9405.72 87.42 166.70 5,309.10 3,290.79 S 4,878.68 W 5564.20 2.01 9500.29 87.18 165.50 5,313.56 3,382.49 S 4,855.99 W 5623.78 1.29 9594.80 87.14 166.06 5,318.24 3,473.99 S 4,832.80 W 5682.90 0.59 9690.06 86.66 166.69 5,323.39 3,566.43 S 4,810.39 W 5743.24 0.83 9785.61 86.87 166.16 5,328.79 3,659.16 S 4,788.00 W 5803.83 0.60 9880.30 86.17 167.40 5,334.53 3,751.17 S 4,766.39 W 5864.30 1.50 9974.77 90.61 164.98 5,337.19 3,842.84 S 4,743.85 W 5923.95 5.35 10071.44 90.68 162.58 5,336.10 3,935.65 S 4,716.85 W 5981.82 2.48 10164.24 89.79 161.50 5,335.72 4,023.93 S 4,688.24 W 6035.10 1.51 10260.87 89.41 162.18 5,336.39 4,115.74 S 4,658.12 W 6090.30 0.81 10357.49 89.20 163.63 5,337.57 4,208.08 S 4,629.72 W 6146.96 1.52 10452.66 88.50 164.77 5,339.48 4,299.64 S 4,603.82 W 6204.49 1.41 10545.31 89.66 166.06 5,340.96 4,389.29 S 4,580.49 W 6262.05 1.87 10640.27 89.10 166.86 5,341.99 4,481.60 S 4,558.26 W 6322.39 1.03 10733.43 89.00 166.16 5,343.54 4,572.18 S 4,536.53 W 6381.65 0.76 10828.60 89.07 166.72 5,345.14 4,664.68 S 4,514.22 W 6442.10 0.59 10927.00 88.72 164.87 5,347.04 4,760.05 S 4,490.08 W 6503.74 1.91 11022.93 89.20 164.62 5,348.78 4,852.58 S 4,464.84 W 6562.45 0.56 11118.09 89.03 164.82 5,350.25 4,944.37 S 4,439.77 W 6620.67 0.28 INSITE V8.1.10 Page 3Job No:AK-XX-0901987902 Well Name:2N-336 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11213.77 88.86 162.94 5,352.01 5,036.27 S 4,413.21 W 6678.08 1.97 11309.99 88.41 162.81 5,354.30 5,128.20 S 4,384.88 W 6734.45 0.49 11404.89 88.21 161.58 5,357.10 5,218.51 S 4,355.88 W 6789.12 1.31 11500.99 87.42 162.22 5,360.76 5,309.79 S 4,326.04 W 6844.06 1.06 11596.67 86.94 162.16 5,365.47 5,400.77 S 4,296.81 W 6899.13 0.51 11691.75 90.61 162.11 5,367.50 5,491.23 S 4,267.66 W 6953.83 3.86 11781.85 90.37 162.96 5,366.73 5,577.17 S 4,240.62 W 7006.19 0.98 11882.60 90.88 164.04 5,365.63 5,673.77 S 4,212.00 W 7066.12 1.19 11978.50 91.33 164.14 5,363.79 5,765.97 S 4,185.72 W 7123.94 0.48 12073.89 87.51 164.40 5,364.75 5,857.77 S 4,159.87 W 7181.69 4.01 12165.64 80.69 166.33 5,374.18 5,946.01 S 4,136.81 W 7238.29 7.72 12229.00 80.69 166.33 5,384.43 6,006.77 S 4,122.04 W 7277.92 0.00 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 217.00 degrees (True) - A total correction of 18.78 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 12,229.00 feet is 7,285.08 feet along 214.46 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 4Job No:AK-XX-0901987902 Well Name:2N-336 Survey Report
